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198-173
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, December 9, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 2N-321A KUPARUK RIV U TARN 2N-321A Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 12/09/2022 2N-321A 50-103-20267-01-00 198-173-0 G SPT 4912 1981730 1500 3400 3400 3400 3400 50 60 60 60 4YRTST P Austin McLeod 10/10/2022 MITIA 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-321A Inspection Date: Tubing OA Packer Depth 1255 2010 1985 1985IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM221010190851 BBL Pumped:0.4 BBL Returned:0.4 Friday, December 9, 2022 Page 1 of 1 5HJJ-DPHV% 2*& )URP :HOO,QWHJULW\6SHFLDOLVW&3) Q #FRQRFRSKLOOLSVFRP! 6HQW :HGQHVGD\$XJXVW 30 7R 5HJJ-DPHV% 2*& :DOODFH&KULV' 2*& %URRNV3KRHEH/ 2*& '2$$2*&&3UXGKRH%D\ 6XEMHFW &3$,IRUPVIRU6,LQMHFWRUVRQ$XJ $WWDFKPHQWV 0,7.5813$'6,7(676[OV[ 0,7.58/ $6,7(67[OV[ 0,7.588 6,7(67[OV[ ůůͲWůĞĂƐĞƐĞĞƚŚĞϭϬͲϰϮϲĨŽƌŵƐĨŽƌƚŚĞƐŚƵƚŝŶ͕ŶŽŶͲǁŝƚŶĞƐƐĞĚD/dͲ/ƐƉĞƌĨŽƌŵĞĚŽŶϮƵŐϮϬϮϮ͘WůĞĂƐĞůĞƚŵĞŬŶŽǁŝĨ LJŽƵŚĂǀĞĂŶLJƋƵĞƐƚŝŽŶƐŽƌĐŽŶĐĞƌŶƐ͘ 'XVW\)UHHERUQ :HOO,QWHJULW\6SHFLDOLVW &RQRFR3KLOOLSV$ODVND,QF 2IILFHSKRQH &HOOSKRQH &$87,21 7KLVHPDLORULJLQDWHGIURPRXWVLGHWKH6WDWHRI$ODVNDPDLOV\VWHP'RQRWFOLFNOLQNVRURSHQ DWWDFKPHQWVXQOHVV\RXUHFRJQL]HWKHVHQGHUDQGNQRZWKHFRQWHQWLVVDIH .581$ 37' Submit to: OOPERATOR: FIEL DD // UNITT // PAD: DATE: OPERATORR REP: AOGCCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2070900 Type Inj N Tubing 10 140 140 140 Type Test P Packer TVD 5004 BBL Pump 1.9 IA 85 1800 1750 1750 Interval 4 Test psi 1500 BBL Return 1.9 OA 0 0 0 0 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1981730 Type Inj N Tubing 1645 1650 1645 1645 Type Test P Packer TVD 4903 BBL Pump 2.4 IA 225 2510 2460 2440 Interval 4 Test psi 1500 BBL Return 1.7 OA 140 150 150 150 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1981170 Type Inj N Tubing 1460 1450 1450 1430 Type Test P Packer TVD 4770 BBL Pump 1.4 IA 360 2200 2140 2130 Interval 4 Test psi 1500 BBL Return 1.4 OA 240 430 430 430 Result P Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 2011420 Type Inj N Tubing 650 650 650 650 Type Test P Packer TVD 4375 BBL Pump 2.1 IA 410 1800 1750 1740 Interval 4 Test psi 1500 BBL Return 2.1 OA 230 360 350 350 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMec h an i c all In t eg r ityy Tes t jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes: Notes: 2N-310 2N-321A 2N-348 Notes: 2N-331 Notes: ConocoPhillips Alaska Inc, Kuparuk / KRU / 2N Pad N/A Hembree / Hills 08/02/22 Form 10-426 (Revised 01/2017)2022-0802_MIT_KRU_2N-pad_4wells 9 9 9 9 9 9 9 - 5HJJ 2N-321A • V OF Tit 0,1� \ \II /77 THE STATE Alaska i S " �`~ �'`ii °ALASKA Conservation Commission 1•11‘ ,_ , - ,67,...;,: , ,,> GOVERNOR SEAN PARNELL 333 West Seventh Avenue R: p Anchorage, Alaska 99501 -3572 F ALAS Main: 907.279.1433 \.). { Z Fax: 907.276.7542 rj Martin Walters N V �v Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 \01-_____,i1-13 Anchorage, AK 99510 Re: Kuparuk River Field, Tarn Oil Pool, 2N -321A Sundry Number: 313 -308 Dear Mr. Walters: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ale4 Cathy P. oerster _ L Chair 54 DATED this2iI day of June, 2013. Encl. ~ STATE OF ALASKA xV ! ,. , .' " , A OIL AND GAS CONSERVATION COM•SION �' ` rz Or .' 3 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 #:`.4i ,P i (; 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Apptdvec)`Program r Suspend r Plug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdow n r Re -enter Susp. Well r Stimulate r Alter casing r Other: Conductor Extension I✓ • 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 198 -173 • 3. Address: 6. API Number: Stratigraphic r Service Fr., P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20267 -01 . 7. If perforating, What 8. Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No r 2N - 321A . 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0380054 • Kuparuk River Field / Tarn Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): • 10027 • 5430 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 108' 108' 1640 630 SURFACE 3832 7 -5/8 3861' 2294' 6890 4790 PRODUCTION 9301 5 -1/2 9330' 4919' 7000 4990 PRODUCTION 671 3 -1/2 10001' 5410' 10160 10540 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9531 -9542, 9574 -9594, 9600 -9613, 5067 -5075, 5099 -5114, 5119 -5128, 5135- 9622 -9634, 9642 -9659, 9664 -9682, 5144, 5149 -5162, 5166 -5179, 5189 -5203, 3.5 L -80 9324 9696 - 9716,9724 -9734 5209 -5217 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) BAKER 80 -40 CASING SEAL ASSEMBLY • MD= 9307 TVD= 4903 CAMCO DB NIPPLE 6 MD = 483 TVD = 482 12. Attachments: Description Summary of Proposal . r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 7/1/2013 Oil r Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r , Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Martin Walters / MJ Loveland Email: N1878acop.com Printed Name Martin Walters Title: Well Integrity Projects Supervisor Signature /17M/1 Z 62,2� — Phone: 659 -7043 Date: 06/13/13 Commission Use Only Sundry Number: :3k 3 - 34 Conditions of approval: Notify Commission so that a representative may witness /� - v Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: ,! RBDMS JUN 26 2( Spacing Exception Required? Yes ❑ No 1 Subsequent Form Required: / t _ d [1-- P 7 � APPROVED BY Approved by: cit,.. vve�a u a Ccl t MISSIONER THECOMMISSION I Date: 4 - 2 `' aeli Ltrkivii is v u 12 nluni6 tw in the talc v aNNiuva . Form 10 -403 (Revised 10/2012) Submit Form and Attachme Duplicate \ b V[,, &fit /t3 ORIGINML ����� ' , � CJi:! ConocoP A0 CI cr; Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 June 13, 2013 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Commissioner Seamount: Enclosed please find the 10 -403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 2N-321A, PTD 198 -173 conductor extension. Please contact Martin Walters or MJ Loveland at 659 -7043 if you have any questions. Sincerely, 76127? Martin Walters ConocoPhillips Well Integrity Projects Supervisor . • • INV ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 ConocoPhillips Alaska, Inc. Kuparuk Well 2N -321A (PTD 198 -173) SUNDRY NOTICE 10 -403 APPROVAL REQUEST June 13, 2013 This application for Sundry approval for Kuparuk well 2N-321A is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to SC. At some point during normal operations the conductor subsided about 10 1 /4 ". With approval, the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 1 2. Examine surface casing for any corrosion damage. 3. Extend the conductor to starter head and fill the void with cement and top off with sealant. 4. File 10 -404 with the AOGCC post repair. NSK Well Integrity Projects Supervisor r KUP 2N 321A 1 • ConocoPhillip5 Well Attributes Max Angle & MD ITD Wellbore API /UWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (kKB) co ,,,,,,,,,,, _ Alaska, Inc. 501032026701 TARN PARTICIPATING AREA INJ 70.59 3,377.49 10,027.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date " "' SSSV: NIPPLE Last WO: 34.79 8/24/1998 Well Confi9 2N -321A, 12420121.39:26 PM - -- -- Schemata- Actual Annotation Depth (kKB) 'End Date Annotation Last Mod ... End Date Last Tag: SLM 9,593.0 9/7/2008 Rev Reason: WELL REVIEW _ osborl 1/24/2012 Casing Strings., Casing Description String 0... String ID ... Top (kKB) Set Depth (1... Set Depth (TVD) String Wt... String ... String Top Thrd HANGER. 23 A CONDUCTOR 16 15.500 29.1 108.0 108.0 62.58 H WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd SURFACE 75/8 6.875 29.1 3,861.0 2,294.7 29.70 1 BTC - MOD Casing Description String D 310.0 0... String ID Top (ftKB) Set(f... Set Dep Depth ... String Wt... String... String Top Thrd WINDOW Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 5.5 5 1/2 4.950 27.5 10,000.8 5,410.7 15.50 L -80 LTC -MOD "x3.5" @ 9330' Tubing Strings Tubing Description String 0... String ID ... ITop (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 31/2 2.992 1 23.0 9,324.0 4,915.1 9.30 L -80 EUE8RDMOD , CONDUCTOR, - Completion Details 29- 108 -- -- --- - Top Depth 1 To (TVD) Top Incl Nomi... WI NDOW'A', Top (ftKB) ( (°) Item Description Comment ID (in) 300.310 23.0 23.0 -0.71 HANGER FMC GEN V 5M TUBING HANGER 3.500 yam. 483.4 482.4 8.98 NIPPLE CAMCO DB NIPPLE 2.875 a NIPPLE, 483 9,195.1 4,824.8 47.25 SLEEVE -C BAKER CMU SLIDING SLEEVE w/ DB PROFILE; CLOSED 11/29/1998 2.813 Eli 9,298.9 4,896.9 43.76 NIPPLE CAMCO D NIPPLE NO GO 2.750 9,306.0 4,902.0 43.67 LOCATOR BAKER LOCATOR 2.985 9,307.5 4,903.1 43.65 SEAL ASSY BAKER 80-40 CASING SEAL ASSEMBLY 2.985 Perforations & Slots Shot . Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (en- Type Comment 9,531.0 9,542.0 5,067.7 5,075.9 S8, 2N -321A 11/26/1998 6.0 IPERF 2.5" HC/DP, 60 deg ph 9,574.0 9,594.0 5,099.7 5,114.5 S8, 2N -321A 11/24/1998 6.0 IPERF 2.5" HC/DP, 60 deg ph 9,600.0 9,613.0 5,119.0 5,128.6 S8, S7, 2N -321A 11/26/1998 6.0 IPERF 2.5" HC/DP, 60 deg ph SURFACE, , ♦ A, 9,622.0 9,634.0 5,135.2 5,144.0 S7, 2N -321A 11/26/1998 6.0 IPERF 2.5" HC/DP, 60 deg ph 29 - 3,861 9,642.0 9,659.0 5,149.9 5,162.4 S7, 2N - 321A 11/25/1998 6.0 IPERF 2.5" HC/DP, 60 deg ph SLEEVE - C, 9,195 9,664.0 9,682.0 5,166.0 5,179.3 S5, S3, 2N -321A 11/26/1998 6.0 IPERF 2.5" HC/DP, 60 deg ph 9,696.0 9,716.0 5,189.6 5,203.9 S5, S3, 2N -321A 11/25/1998 6.0 IPERF 2.5" HC/DP, 60 deg ph 9,724.0 9,734.0 5,209.8 5,217.2 S3, 2N -321A 11/25/1998 6.0 IPERF 2.5" HC /DP, 60 deg ph GAS LIFT, Notes: General & Safety_ 8,245 End Date Annotation 8/30/1998 NOTE: WELL SIDETRACKED TO 'A' 11/3/1998 NOTE: Cement drillout 9700' - 9850' CTM NIPPLE, 9,299 ,tl IL LOCATOR, 9.306 SEAL ASSY, 9,307 IPERF, C.:, EFT 9,531-9,542 IPERF,_ - 9,574_9,594 =- - IPERF, - _ 9,600-9,613 - IPERF, 9,622 -9634 - ▪ - IPERF, 9,642 - 9,659 - -- Mandrel Details _ Top Depth Top Port IPERF, (TVD) Incl OD Valve Latch Size TRO Run 9'664-9,682 Stn Top (ftKB) (ftKB) (°) Make Model (In) Sery Type Type (in) (psi) Run Date Com... 1 9,245.7 4,859.3 44.47 CAMCO KBG - 2 - 9 1 GAS LIFT DMY INT 0.000 0.0 8/30/1998 IPERF, -- 9,6969,716 IPERF.;;= 9,724-9.734 PRODUCTION 5.5 "n35° 9330'. 28. 10,001 TD (2N- 321A), 10,027 • 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) `l ~12~~ ~ Subject: RE: State MITIA test results for 2N pad on 8/24/10 ~~ ~ ~ (-7 Follow Up Flag: Follow up Flag Status: Red «r/l ?_t.1-32 ~f-~ 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 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 :~ ti ~ t) ,i; ;~~:-. 333 W.7th Avenue, Suite 100 ~ ~ ~+.A~~~'~"~"r 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@alaska.gov OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. ~ ~j~~ It u Kuparuk /KRU / 2N ~`~~ 08/24/10 Ives/Mouser AES Packer De th Pretest Initial 15 Min. 30 Min. Well 2N-302 T e In'. W TVD 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 TVD 5,174' Tubin 2,150 2,150 2,150 2,150 Interval 4 P.T.D. 2040620 T e test 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 TVD 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 TVD 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 TVD 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 X2,250 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 TVD 4,770' Tubin 1,460 1,460 1,460 1,460 Interval 4 P.T.D. 1981170 T e test 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 TVD 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 TVD 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 TVD 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 Well 2N-349A T e In'. G TVD 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 2,250 P/F P Notes: OA 150 250 250 250 Well 2N-325 T e In'. W TVD 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 TYPEINJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting w =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R = Intemal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT KRU 2N Pad 08-24-10 Revisedl.xls . . Conoc;pí,illips Alaska Rë.Cf!\VE.O SEP 1 2 2007 . ion A1aska Oi\ & Gas Cons. Cornrmss Anchorage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 07, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 SCANNED SEP 12 Z007 qlò- \'13 , ~~~"3~\ 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 5,2007. 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. Sincerely, \. ~~~/~ ~end ConocoPhillips Well Integrity Field Supervisor ~ . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 917/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitorl Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft oal 2N-320 199-001 4" nla 4" nla 2 9/5/2007 2N-321 198-173 6" nla 6" nla 2 9/5/2007 2N-323 198-071 1" nla 1" nla 1 9/5/2007 2N-325 198-163 10" nla 10" nla 2 9/5/2007 2N-326 200-155 9" nla 9" nla 3.5 9/5/2007 2N-337 206-163 6" nla 6" nla 1 9/5/2007 2N-339 198-100 8" nla 8" nla 2.5 9/5/2007 2N-341 198-103 3" nla 3" nla 1 9/5/2007 2N-342 207-068 18" nla 18" nla 4.5 9/5/2007 2N-343 198-092 4" nla 4" nla 2 9/5/2007 2N-345 204-034 9" nla 9" nla 3.5 9/5/2007 MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday, August 09, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLlPS ALASKA INC 2N-321A KUPARUK RIV U TARN 2N-321A Jim Regg P.I. Supervisor 171· '.". (:?/. ,-,¡ -/ . "e11 f.,) I 'C:{ Ü\V FROM: Chuck Scheve Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Well Name: KUPARUK RIV U TARN 2N-32I API Well Number 50-103-20267-01-00 ^ Insp Num: mitCS060808190005 Permit Number: 198-173-0 Rei Insp N um ~/ ,1tJ \~ Reviewed By: P.l. Suprv:íi3t2-- Comm Inspector Name: Chuck Scheve Inspection Date: 8/8/2006 450 1910 I Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. 1890 I 1890 I , I I I 390 I , +-~'~-~-r~--- 1 2900 I I Packer Depth Well I 2N-321A [Type Inj. [ G i TVD 4915 I !: ~-~- P.T. I [981730 iTypeTest I SP.'J. Test psi I 1500 Interval 4YR~. PIF P 1 IA I I lOA I Tubing I I ~ 200 390 I 2900 2900 --L Notes Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity. SCANNSD AUG 2 42006 Wednesday, August 09, 2006 -- 390 2900 Page I of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille O. Taylor (.~ DATE: August 3, 2002 Chair -/'5; SUBJECT: Mechanical Integrity Tests Phillips Alaska THRU: Tom Maunder ~,~ P.I. Supervisor 2N Pad FROM: John Crisp Petroleum Inspector Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min, ..We,,I 2N-307 IType,ni.[ c I T.V.D. I' 5141 I Tubing[ 31g0 1'3150 I 3150 I 3200 I~nterva~[ 4 P.T.D,[ 1990170 [Typetest[ P, ITestpsi[ 1500 [Casing[ 2275 i' ,2900 I 2900 I 29'00 I P/F I ~P' Notes: WellI 2N~321A ITypelnJ. I S ! T.V.D. 14915 I T'ubing'l 1700 i 1700 I 1700 I 1700 Ilntervall '4' P.T.D.I 1981730 ITypet,estl P ITestpsil 1500 [,Casingi 100 I 2150 I 2150, I 2150 I PIE I E Notes: WellI 2N-325 P.T.D.~ 1981630 Notes: wel!l 2N-331 P.T.D.I 1981170 Notes: Well! 2N-343 P.T.D.I 1980920 Notes: IYypemj.! G IT'v'D'I =~o I,~'nte'rva, l mypetestI P ITest,,psiI 1500 I Casingl 1075I 1950i 1940I 1940,1 P,!F [, _.P I Typemj.I 'S J T,V,D. I 4770 I Tubingl 1675 '1 '16~5'1 '167~ I ~575' Jinterv'a~I 4" TypetestI',P ITestl~siI ,150,0,1Casing! 600 I '2025,1,'2025 I 2025 ITypelnj.I G I T.v.D. I 4938I ubingl 2550 12550 12550 I' 2550 linterva, l4 Typ'etestI .... P 'lTes{psil 1500 Casing'I, 2000I ,2925I, ,.2925 I 29251 P/F I ~P, Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to PAYs Kuparuk River Field to witness 4 year MIT's on 2N Pad. No failures witnessed, M.I.T.'s performed: S_ Attachments: Number of Failures: 0_ Total Time during tests: 4 ,.hrs. CC: ~I~NNED .~UG 1 ~ 2D02 MIT report form 5/12/00 L.G. 020803-MIT KRU 2N JC.xls 8/5/2002 Well comi iiance Report File on Left side of folder 198-173-0 KUPARUK RIV U TARN 2N-321A 50- 103-20267-01 PHILLIPS ALASKA1NC MD 10027 ~'~ TVD 05430 ' Completion Date: ~8 Completed Status: 1W1NJ Current: WAGIN Microfilm Roll / - Roll 2 / -- Name Interval c 9498 ~ I SCHLUM CNTD 12/26/99 L CBL/SCMT ~ FINAL 9150-9834 L CNTD~-~j FINAL 200-9850 12/26/99 L DORJCNP/SLD-MD ~"'~iNAL 3880-10028 L DGR/CNP/SLD-TVD/~FINAL 2302-5430 Sent Received T/C/D CH 4/17/00 4/28/00 CH 2 12/21/98 1/5/98 CH 5 4/17/00 4/28/00 ~,-O{2 OH 12/16/98 12/17/98 OH 12/16/98 12/17/98 L DGR/EWR4-MD ..~- FINAL 3880-10028 L DGR/EWR4-TVD~ FINAL 2302-5430 OH 12/16/98 12/17/98 OH 12/16/98 12/17/98 L GR-TEM/PRES L-'"~ L INJ P_..----~-- L INJP-PSP ~ L INJP-STAT PROF --~-~- L MI INJP FINAL 50-9800 4/11/00 FINAL 4-9800 4/12/00 FINAL 9450-9818 7/10/99 FINAL 9450-9778 9/17/99 FINAL 9450-9800 L MI INJP-SPIN/TEMc.~'~INAL PRES 9092-9789 2/5/00 L MI INJP-TEM/PRES ~'~'~NAL 9450-9800 5/25/99 L 'RST WFL ~ FINAL 3700-9790 9/25/99 R GYRO CONT.MULT1'~'~''~- GYRODATA TBNG 0-9175 R SRVYCALC ~ . BHI 5211.19-10028. Daily Well Ops Was the well cored? yes no CH 5 4/20/O0 CH 5 4/27/00 CH 5 8/11/99 CH 5 9/30/99 CH 2 1/20/99 CH 2 2/17/00 CH 5 6/15/99 CH 5 10/6/99 CH OH Are Dry Ditch Samples Required? ye,s Analysis Description Received? yes no 4/28/00 5/12/oo 8/19/99 9/30/99 1/21/99 2/25/00 6/23/99 10/13/99 1/8/99 1/8/99 12/16/98 12/18/98 no And Received? yes no Sample Set # Comments: Tuesday, August 01, 2000 Page 1 of 1 4/27/00 Schlumberger NO. 121413 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print 2N-321A ~(/C..- INJECTION LOG 000412 I 1 2N-325 /,{/E-- INJECTION LOG 000414 I 1 3F-01 PRODUCTION PROFILE 000415 I 1 3F-05 PRODUCTION PROFILE 000416 I 1 · _ I%. L ~. I-- ! v UAY 1 2 2000 SIGNEI DATE: Alaska 0il & Gas Cons. uummissl0rl Anchorage Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. 4~2O~OO Schlumberger NO. 121394 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print 2N-321A ~-~.1 4.. GAMMA RAY BASELINE 000411 I 1 2N-325 ~L, =GAMMA RAY BASELINE 000411 I 1 ,., -- ---,, ~1, I! f'X p~l FIV l'U APR 2 8 ~000 SlGNE DATE: Alaska 0il & Gas C0~s. Anchorage Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317, Thank you. 4/17/00 /'¢?' Schlumberger NO. 121376 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print CD 3H-05 20148 USIT 000326 1 2N-321A ~(,[ ~ 20042 CNTD '.~-- "~ ~ ~'~' 991226 I 1 1 R .[:(-~ F-._ iV. . _': ~'") APR 28 2000 SIGNE ( DATE: Naska 0ii & Gas C~s. ~0..'mssi0n Anchorage Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you, Apr-la-g0 04:48 1, Type of request From-KUP WELLS CNST PROJ +907-659-?'314 T-a09 STATI~ OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMIS$10~ APPLICATION FOR SUNDRY APPROVALS P,03/04 F-SIS Abandon Suspend __ Operation Shutdown Reenter eqsp~d¢cl well Aher casing ~ Change approved program 2. Name of Operator; ARCO Alaska, Inc. Repair well __ Plt~gging Pull tubing __ Variance Address: P.O, Box100860 Anchorage, AK 99810.0360 4. I..~¢ation of well at surface: 61' FNL. 763' FEL, Sec 3, TgN, R7E, UM At top of produclJve interval: 209' FI,IL, 669' FEL, Sec 35, T1ON, R71~, UM At effeclive depth: 134' FNL, 721' FEI., Sec 33, T10N, RTE, UM At lotal depth; Be' FNL, 860' FEL, Sec 28. T10N, R7E. UM 12, Present well conditlolq summary Total Depth: measured truo vertical F__]leclive Deplh: measured Irue vertical ¢ aa in g Length $12e Conductor 11 O' 1fl" SurfAce 3861' 7,5/8' Produclion 931 O' 5.5' X Liner 676' 3- ~/2" Type et Well: Dovelopmen! Exp~ommrv 8e~i~a 10027' feet .~30' 1eel 9872' feet 5318' leer Cemented 10 cu. Yds High Early 364 sx ASlll LW 238 sx ASI 60 s× Class G 220 sx Class G Perforation Depth 9531'-9542' MD 9574'-9594' MD 9642'.9659' MD 9696'-97'16' MD 9724'-9734' MD 9600'-9613' MD 9822'.96,34' MD 96G4'-9682' MD Tubing (size, grade, and measured depth) 9-1/2". 9.3#, L-80, Tubing @ 9324' MD, Packers and SSSV (type and meaeured depth) Baker Casing Seal Assby @ 9324' MD 13. Attachments 5068'-5076' '~/D 5100'.5115' TVD 51 SOL 5162' TVD 5190'.5204' 'I-VD $210'-5217' TVD {~119'-5129' TVD $13S'-$144' TVD S166'-5179' TVD m~rrle ex'Jerisiorl __ Stimulate 6. Datum of elevation (DF or KB feet}: -I 26,75' RKB 7, Unit er Praperty: Kuparuk River Uni~ 8. Well ItL~mber:. 2N-$21A 9. Permit Ilumber: 98.173 10. APl number: J ~0~0108-20267-1 111. Re'Id/Pool: JKuparuk River Reld/Tam Oi~ Pool Measured depth ~0' 3881' True vertical depth 110' 2295' 9310' 10001' .q410' sp! spt spt spt spt ORIGINAL RECEIVED APR 1 0 2000 AladmOtl & Gas Cons. C0mmission Descr. l~ion summary of proposal X 14. Estimated date for commencing operation 4/8/2000 Run RA Tracer down Inner Annulus De, ]aired operations program. 16. If i~opesal was verbally approved ]lair Wondzell 4/~/00 ~ Name of apprever Date approved 17. I hereby certify that the forgoing Is true and correct t~ the best of my knowledge. BO P sketcl~ jla,Status of well classification as: I Oil_ Gas ~ Suspended__ Inj_nclOr -- / (~"~/- - FOR COMMISSION USE Conditions of approval; Notify Cornisslon so represenliflve may witness Plug integrely ~ BOP test _ Locati~ clearance M~h~nlcal integre, y ,est _ Subsequen, ,cfm r~uired 1~ __.__ ORIGINAL SIGNED BY ~prov~ by ~rder of the Commi$sionm Rob~ N Form 10-403 Rev 06/15188 SUBMIT IN TRIPLICATE Apr-lO-O0 04:4F From-KUP WELLS CNST PROJ +907-$$9-?'314 T-OOg P.04/04 F-BiS ,, Altacllment I ~ Kuparuk Well 2N-321A ARCO Alaska, lnc. is seeking AOGCC approval to inject RA material in the outer annulus of Tam injectors 2N-325 and 2N-321A as part of an ongoing program to diagnose how injection fluids are being transported to producer 2N-345. AAI initiated Tarn MI injection during late 98. A water injection test was conducted during the summer of 99. At the time of the test, no Tarn producer had experienced MI breakthrough. After approximately three weeks of water injection, water production was observed in 2N-345. Water tracer suggested that 2N-321A, and possibly 2N-325, were communicating with producer 2N-345.(See net pay map below for well locations.) Given that (I) no previous MI break through had been detected, (2) the quick water breakthrough time, and (3)the location of injector 2N- 32 lA relative to producer 2N-345, communication through the reservoir was difficult to explain. One possibility was that the transport path of injected fluids to 2N-345 involved channeling up the outside 2N-321A?s casing, through a shallow zone (where 2N-321A and 2N-325 wellbores are closer together), and down the outside of 2N-345?s casing to its open perforations. A variety of injection logs and production logs were subsequently mn; however, they all fa/led to detect channeling. Fmxhermore, there were no elevated pressures Jn the annuli of any Tarn wells indicating communication with injected fluids. After completing the water injection test, MI injection at Tarn was resumed. Well tests on 2N- 345 were closely monitored for any sign of MI breakthrough. MI breakthrough in 2N-345 has recently been confirmed. Proposal The RA injection proposal is two-fold. First, we plan to inject RA material (i.e., Iodine 1317 which has a half-life of 8.5 days) down the surface casing by production casing annulus of injectors 2N-32 lA and 2N-325. The purpose of this is to identify the "weak zone" that breaks down during annular pump-ins. (This will be the zone that cuttings are injected into during annular disposal operations.) This information will be used to help formulate drilling plans of future wells. We know that this "weak zone" is not transporting injected fluids To 2N-345. We can pump diesel into the "weak zone" at pressures that range between 700 psi and 1200 psi. After completing pumping operations, the outer annulus pressures bleed down. If the "weak zone" were transporting injection fluids, it would be at an elevated pressure (-3000 psi). This elevated pressure is not consistent with the relatively low pressure outer annulus pump-ins and subsequent pressure bleed-offs. Second, we plan to inject solid RA tagged particles (i.e., Antimony and Scandium. which have half-lives in the 60 - 80 days range) into the outer annulus and then let gravity allow these panicles to settle. The purpose of this is to identify the deepest point that is in hydraulic communication with the outer annulus. This information will also be used to help formulate drilling plans of future wells. RECEIVED APR 1 0 2000 Aia~ 011 & Gas Cons. ~mm~ion Re: Tam RA Injezion . • Subject: Re: Tarn RA Injection 2M -3457- Date: Wed, 05 Apr 2000 15:11:01 -0800 From: Blair Wondzell<blair_wondzell@admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: Lamont C Frazer <LFRAZER@mail.aai.arco.com> A 3 Lamont, Thanks for the data. As we discussed, I think this request should be by a 10-403. Contingent on your furnishing a 403 to this office by Monday, so that the work can start this weekend. Blair Wondzell, 4/5/00. Lamont C Frazer wrote: April 10, I am giving you verbal approval > Blair, > As per our phone discussion on 4/4/00, we are seeking AOGCC approval to inject > RA material in the outer annulus of Tarn injectors 2N-325 and 2N -321A as part of > an ongoing program to diagnose how injection fluids are being transported to > producer 2N-345. For your convenience, the original e-mail message on this > subject and a brief update of recent data collection activities are provided > below. > Data Collection Update > Gas tracers indicate that a small fraction of MI injection from wells 2N-325, • 2N-331 and 2N -321A is transported to 2N-345 within a few days. The logging > program outlined below has not provided any indication of out of zone injection, > with one exception --the CNL run in injector 2N -321A indicated that the Iceberg > interval in the near -wellbore region of this injector has increased its gas/MI > saturation since the well was drilled. At this point in time, it remains > unclear as to how injection fluids are being transported to 2N-345. > Schematics of injectors 2N -321A & 2N-325 and fracture stimulated producer 2N-345 > are also shown below. Logs suggest good cement bonding up to the crossover in > 2N-325. (Cement bonding above the crossover is unknown.) Logs suggest that > 2N -321A and 2N-345 both have some degradation in cement bonding prior to > reaching their crossovers. > Producer Logging > * Production > - DEFT (2N-345) > - Water Flow Log (2N-345) > * Behind Pipe Flow Evaluation > - CNL (2N-345) > - Noise (2N-345) > - Cement Evaluation Log (2N-345) > Injector Logging > * Water Injection > - Spinners (2N-307, 2N -321A, 2N-325, 2N-331 & 2N-343) > - Temperature (2N -321A, 2N-325 & 2N-343) > - Borax PAT (2N-325 & 2N-343) > - Near -Wellbore Iodine 131 RA Tracer (2N -321A, 2N-325 & 2N-343) > * Gas Injection > - Spinners (2N-307, 2AI-321A, 2N-325, 2N-331 & 2N-343) > - CNL (2N -321A, 2N-325 & 2N-331) > (Embedded image moved to f`le: pic17230.pcx) 1 of3 4/5/003:11 PM Re: Tam RA Injection > Proposal > The RA injection proposal is two -fold. First, we plan to i-ject RA material > (i.e., Iodine 131, which has a half-life of 8.5 days) down c..e surface casing by > production casing annulus of injectors 2N -321A and 21N-325. .he purpose of this > is to identify the "weak zone" that breaks down during annular pump -ins. (This > will be the zone that cuttings are injected into during annular disposal > operations.) This information will be used to help formulate drilling plans of > future wells. We know that this "weak zone" is not transpor_ing injected fluids > to 2N-345. We can pump diesel into the "weak zone" at pressures that range > between 700 psi and 1200 psi. After completing pumping operations, the outer > annulus pressures bleed down. If the "weak zone" were transporting injection > fluids, it would be at an elevated pressure (3000 psi). This elevated pressure > is not consistent with the relatively low pressure outer annulus pump -ins and > subsequent pressure bleed -offs. > Second, we plan to inject solid RA tagged particles (i.e.,--timonv and > Scandium, which have half-lives in the 60 - 80 days range) =.to the outer > annulus and then let gravity allow these particles to settle. The purpose of > this is to identify the deepest point that is in hydraulic communication with > the outer annulus. This information will also be used to help formulate > drilling plans of future wells. > if you have any questions, or would like additional information on this subject, > please contact either myself (263-4530) or Ryan Stramp (265-6806). We would > welcome an opportunity to meet with you to discuss the matter in more detail. > Sincerely, > Lamont Frazer > AAI Tarn Reservoir Engineer > ---- Forwarded by Lamont C Frazer/AAI/ARCO on 04/05/2000 09:08 > AM ---------------- > Lamont C Frazer > 01/11/2000 04:14 PM > To: Blair_ Wondzell@admin.state.ak.us > cc: Ryan L Stramp/AAI/ARCO@ARCO > Subject: Tarn Injection > Blair, > As per our phone discussion on 1/10/00, this e-mail message crovides a brief > description outlining events relating to the production of ':jetted fluids in > Tarn producer 2N-345. The reason for alerting the AOGCC to tris situation is > that it ----------------- > ?s possible that out of zone injection may be involved in the transport > of injected fluids to 2N-345. > Background > AAI initiated Tarn MI injection during late ?98. A water in-'ection test was > conducted during the summer of ?99. At the time of the test, no Tarn producer > had experienced MI breakthrough. After approximately three :seeks of water > injection, water production was observed in 2N-345. Water tracers suggested > chat 2N -321A, and possibly 2N-325, were communicating with producer 2N-345. > (See net pay map below for well locations.) Given that (1) -o previous MI > breakthrough had been detected, (2) the quick water breakthrough time, and (3) > the location of injector 2N -321A relative to producer 2N-345, communication > through the reservoir was difficult to explain. One possibility was that the 2 of 3 4/5/00 3:12 PM Re: Tarn RA Injection • • > transport path of injected fluids to 2N-345 involved channeling up the outside > 2N-321A?s casing, through a shallow zone (where 2N -321A and 2N-325 wellbores are > closer together), and down the outside of 2N-345?s casing to its open > perforations. A variety of injection logs and production logs were subsequently > run; however, they all failed to detect channeling. Furthermore, there were no > elevated pressures in the annuli of any Tarn wells indicating communication with > injected fluids. > After completing the water injection test, MI injection at Tarn was resumed. > Well tests on 2N-345 were closely monitored for any sign of MI breakthrough. MI > breakthrough in 2N-345 has recently been confirmed. > Ongoing Diagnosis > A comprehensive plan has been developed to help understand the transport path of > injected fluids to 2N-345. Ongoing activities include (1) additional logging, > (2) use of gas tracers and (3) attempting to inject into the outer annuli of > Tarn wells to determine whether they remain open to shallow horizons. > If you have any questions, or would like additional information on this subject, > please contact either myself (263-4530) or Ryan Stramp (265-6806). We would > welcome an opportunity to meet with you to discuss the matter in more detail. > Sincerely, > Lamont Frazer > AAI Tarn Reservoir Engineer > (Embedded image moved to file: pic00589.pcx) > ------------------------------------------------------------------------ > Name: picl7230.pcx > picl7230.pcx Type: PCX Image Document (applicat ion/x-unknown -con tent -type-PCXlmage. Document) > Encoding: base64 > Name: pic00589.pcx > pic00589.pex Type: PCX Image Document (application/x-unknown -con tent -type-PCXlmage. Document) > Encoding: base64 3 of 3 4/5/00 3:12 PM 2N -321A • 2N-325 • 2N-345 0 2L -M -D.S. 2L IL--Z29A 1 MR 6 M 41 L� -- 5R n Th i fo 2N D.S. Ams ■ TAMA ow -2�- 2N-wN 2* -337A ew FM WIMS !17AI Ulm 7�le 2 -AJ 1,0q 9cr 2 Al - 3-Z /;I A V- s Y,5 - L Schlumberger NO. 121203 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print 2L-323 Lkt ~-- MEM INJECTION PROFILE 000204 I 1 2N-307 i MI INJECTION PROFILE 000203 I 1 2N-321A~%, MEM INJECTION PROFILE 000205 I 1 2N-325 MI INJECTION PROFILE 000206 I 1 31-06 L~t (L_- INJECTION PROFILE 000207 I 1 3J-17 PRODUCTION PROFILE 000208 I 1 3M-07 LLt r.___ INJECTION PROFILE 000207 I 1 ~ F~" r"lt/ri'\ -- DATE: / Alaska Oil & Gas ~'' ~' _~ncJ'~oragt~ Please sign and return e copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. ~nanK you. 2/17/00 ARCO Alaska, Inc. ' Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 15, 1999 Ms. Wendv Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage. Alaska 99501-3192 Re: Kuparuk Area Annular Injection, Third Quarter, 1999 Dear Ms. Mahan' Please find reported below volumes injected into surface casing by production casing annuli during the third quarter of 1999, as well as total volumes injected into annuli for which injection authorization expired during the third quarter of 1999. Ammlar h~,jection during the third quarter of 1999: h(1) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total 1C-25 520 100 0 620 34316 34936 CD1-40 20079 100 0 20179 12171 32350 CD1-01 4905 100 0 5005 0 5005 1C-23 24865 100 0 24965 9605 34570 CD1-23 16079 100 , 0 16179 16719 CD1-37 17173 100 0 17273 0 17273 CD1-39 3917 i00 0 4017 0 4017 1D-12 4305 I00 ~ 0 i 4405 ' 0 4405 Total Vohmzes into Annuli for which Injection Authorization Expired during the quarter Total I Total h(2) I Total h(3) Volume Total h(1) ~ Well Name Volume ~ : Volume I Volume ~ Injected Status of Annulus ! 100 0 32640 Open, Freeze Protected 1D-09 32540 [ 2N-337A 30539 100 0 30639 [ Open, Freeze Protected 2N-313 32758 i 100 . 0 32858 [ Open, Freeze Protected 2N-321A 27507 I, 100 ] 0 27607 [ Open, Freeze Protected Please call me at 263-4603 should you have Sincerelv. Paul Mazzolini Drilling Team Leader any questions. ; ECEiVED . ~las~a 0il & Gas Cons. Commission Ancn0ra~e CC' Mike Zanghi Paul Mazzolini Randy Thomas Kuparuk Environmental: Engel / Snodgrass Morrison and Winfree Sharon Allsup-Drake Well Files Ms. Wendy Mahan AOGCC Third Quarter 1999 Annular Injection Report Page Two Re: Tarn Water Injection Subject: Re: Tarn Water Injection Date: Fri, 2 Jul 1999 16:20:37 -0900 From: "Erickson&Versteeg" <N1177@mail.aai.arco.com> To: Blair Wondzell <Blair_Wondzell~admin.state.ak.us> Thank you for the quick turnaround on the verbal approval. We'll be following up next week to address final approval issues. Hans Blair Wondzell <Blair_Wondzell@admin.state.ak.us> on 07/02/99 03:00:55 PM To: Erickson&Versteeg/AAI/ARCO cc: Subject: Re: Tarn Water Injection Hans, I hereby give you verbal approval to step-rate test these wells during the week of July 5 to July 11. This approval does not include the water injection progarm recently requested by letter. Blair Wondzell Erickson&Versteeg wrote: > > The wells which will be injected into initially are 2N-321A, 2N-325 and 2N-343. ~ ~--~ans > > Blair Wondzell <Blair Wondzell@admin.state.ak.us> on 07/02/99 02:28:30 PM -- > > To: Erickson&Versteeg/AAI/ARCO > cc: > Subject: Re: Tarn Water Injection > > Hans, > I need the well names of those you plan to test. > Blair > > Erickson&Versteeg wrote: > > > > Blair, > > > > Per our phone conversation, ARCO Alaska Inc is requesting verbal approval to > > initiate water injection at Tarn while review of an Application for Sundry > > Approval is in progress. > > > > Water injection capability at Tarn is expected as early as 7/5/99. ARCO > Alaska > > Inc proposes to ini'tially conduct facility start-up activities and conduct > step > > rate tests on specific wells. After approximately 4 days of injection, the > > wells will be shut-in for surface pressure falloff tests. Ail injection will > be > > ceased at this time. Verbal approval is requested to conduct these initial > > activities. Injection will not be resumed until final approval is obtained > from > > The Commission. Data will be available to The Commission upon request. > > > > Please contact me if you have additional questions. > > 1 of 2 7/15/99 11:30 AM Schlumberger NO. 12843 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Corem Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print CD 2L-307 FBHP/TEMP SURVEY 990919 I 1 2N-321A ~ c_ RSTWATER FLOW LOG 990925 I 1 2N-325 i~.6 <._. RST WATER FLOW LOG 990924 I 1 2N-343 Ct. I ~- RST WATER FLOW LOG 990923 I 1 3G-26 =~_q~L{ ~ 99346 AIT/GPIT 990816 1 3G-26 99346 AIT/GR/CCL 990816 I 1 3G-26 99346 CONTINUOUS SURVEY W/GPIT 990816 I I 10~6~99 1999 ~ 04{ & ~s C~ns. ¢onnrni~0n Please sign and return one copy o{ this transmittal to Sherrie at the above address or fax Io (907) 5{31-8317. Schlumberger NO. 12823 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN' Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk,West Sak,Tarn Color Well Job # Log Description Date BL Sepia Print 2N-321A L~.~(.-- INJECTION & STATIC PROFILE 990917 I 1 3G-26 STATIC PRESSURE SURVEY 990912 I 1 31-12 DEPTH DETERMINATION LOG 990914 I 1 30-07 (.,'-4 C_- INJECTION PROFILE 990922 I 1 2T-210 99367 CBI_JSCMT 990918 I SIGNED: DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. /nam('you. " 9/30/99 8/11/99 Schlumberger NO. 12742 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Tarn Pool Kuparuk,Tabasco Pool Color Well Job # Log Description Date BL Sepia Print 1A-10 iJ~.l (-.- INJECTION PROFILE 990719 I 1 1A-11 ~t I ~ INJECTION PROFILE 990707 I 1 1Y-10 [~! (._ MI INJECTION PROFILE 990716 I 1 2A-03 {.X.t ~ INJECTION PROFILE W/PSP 990708 I 1 2M-20 PRODUCTION PROFILE 990702 I I . 2M-30 ~ ~ INJECTION PROFILE W/PSP 990722 I 1 2N-321A L~..T ~ INJECTION & STATIC PROF W/PSP 990710 I 1 2N-325 ~ i ~ INJECTION & STATIC PROF W/PSP 990709 I 1 2N-335 PRODUCTION PROFILE 990705 I 1 2T-28 ~l~.l ~ MEMORY INJECTION PROFILE 990715 I 1 2T-202 PRODUCTION PROFILE 990706 I 1 2T-210 STATIC BOTTOM HOLE PRESS SURVEY 990721 I 1 2X-10 PROD PROFILE & GAS LIFT SURVEY 990708 I 1 3H-12 ~v4. T C--- INJECTION PROFILE 990706 I 1 3J-04 L,~,l ~ INJECTION PROFILE W/PSP 990724 I 1 13J-05 L,~.I C.~ INJECTION PROFILE W/PSP 990725 I 1 !3M-04 STATIC BoI-rOM HOLE PRESS LOG 990701 I 1 , ,, 3M-29 STATIC BOTTOM HOLE PRESS LOG 990701 I I , , SIGNED:~~~"~ ...... DATE: ,,---,J'l~i I Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank:~i3~'~.0~'~, 6/15/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12648 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Sepia 1A-25 PRODUCTION PROFILE 990520 1 1 1L-03 LJ¥ (--., CEMENT RETAINER SETTING RECORD 990502 1 1 1L-03 CBT 990511 I 1 2A-19 PRODUCTION PROFILE LOG 990603 1 1 2A-21 [,(j c_~ WATER INJECTION PROFILE 990530 I 1 2K-08 FLOWING BH PRESS/TEMP LOG 990529 I 1 2N-307 STATIC BHP PRESS/TEMP LOG 990505 1 2N-321A {.4.1 (-~ MI INJECTION PROFILE 990525 I 1 2U-02 PRODUCTION PROFILE 990525 ] 2U-15 ~q.~Ho~ PRODUCTION PROFILE 990517 1 1 2V-04 Lc/C~ INJECTION PROFILE 990519 I 1 2V-15 PRODUCTION PROFILE 990608 ] ] 2X-12A PRODUCTION PROFILE W/DEFT 990524 1 ] , , 2X-13 PRODUCTION PROFILE LOG 990607 1 1 2Z-07 PRODUCTION PROFILE 990521 ] ] 2Z-10 PRODUCTION PROFILE 990522 1 1 3M-20 6(./C_- INJECTION PROFILE 990515 1 1 3N-01 GAS LIFT SURVEY 990515 1 1 30-12 ¼/C_~ WATER INJECTION PROFILE 990531 I 1 ~ H, 1'T q SIGNED: ( , //~_~f,- DATE: Please sign and return one copy of this transmiflal to Sherrie at the above address. Thank you. ..... - STATE OF ALASKA ~ ' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate__ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _X 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development ~ 26' RKB 3. Address: Exploratory ~ 7. Unit or Property: P.O. Box 100360 Stratagrapic Anchorage, AK 99510-0360 Service X Kuparuk River Unit 4. Location of well at surface: 8. Well number: 61' FNL, 763' FEL, Sec 3, T9N, R7E, UM 2N-321A At top of productive interval: 9. Permit number/approval number: 209' FNL, 669' FEL, Sec 33, T10N, R7E, UM 98-173/399-029 At effective depth: 10. APl number: 134' FNL, 721' FEL, Sec 33, T10N, R7E, UM 50-103-20267-01 At total depth: 11. Field/Pool: 86' FNL, 860' FEL, Sec 28, T10N, R7E, UM Kuparuk River Field / Tarn Oil Pool 12. Present well condition summary Total Depth: measured 10027 feet Plugs (measured) None true vertical 5430 feet Effective Deptt measured 9872 feet Junk(measured) None true vertical 5318 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 100' 16" 10 cu yds High Early 110' 110' Surface 3832' 7-5/8" 364 Sx AS III LW & 3861' 2295' 238 Sx AS I Production 9973' 7" 60 Sx Class G & 9310' 4905' 220 Sx Class G Liner 676' 3-1/2" 10001' 5410' Perforation Depth measured 9531 '-9542'; 9574'-9594'; 9600'-9613', 9622'-9634', 9642'-9659'; 9664'-9682', 9696'-9716', 9724'-9734' true vertical 5068'-5076'; 5100'-5115'; 5119'-5129', 5135'-5t 44', 5150'-5162'; 5166'-5179', 5190'-5204', 5210'-5217' :~;"~ ~ ,~. Tubing (size, grade, and measured depth) 3-1/2", 9.3 Ib/ft, L-80 @ 9324' ~ ? ~.. Packers and SSSV (type and measured depth) :~'~,'~ Baker Casing Seal Assby @ 9324'; SSSV: None 13. Stimulation or cement squeeze summary /,tllObOl,~rro_.~ N/A Intervals treated (measured)0RIE INAL 9531 '-9542'; 9574'-9594'; 9600'-9613', 9622'-9634', 9642'-9659'; 9664'-9682', 9696'-9716', 9724'-9734' Treatment description including volumes used and final pressure Performed water injection test into MI well. 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 10000 0 0 2419 Subsequent to operation 0 15500 0 0 2375 15. Attachments see attachment 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _ Oil _ Gas _ Suspended _ Service _X ! 7. I hereby certify that the foreg~g is true and correct to the best of my knowledge. Signed (~~_~ ~~,~'~ Title: Production Engineering Supervisor Date SUBMIT IN DUPLICATE~ Form 10-404 Rev 06/15/88 Attachment I -~ Report of Sundry Well Operations Tarn Well 2N-321A Permit Number 399-029 ARCO Alaska, Inc has completed a water injection test on MI injection well 2N-321A. 3394 bbls of water was injected into the well between the dates of April 3 and April 8, 1999.2N-321A was returned to MI injection service after the test. ARCO Alaska, Inc. Post Office Bo;.. o0360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 April 9, 1999 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, First Quarter, 1999 Dear Ms. Mahan: Please find reported below volumes injected into surface casing by production casing annuli during the first quarter of 1999, as well as total volumes injected into annuli for which injection authorization expired during the first quarter of 1999. Annular h~jection during the first quarter of 1999: h(1) ] h(2) h(3) Total for Previous New Well Name Volumet Volume Volume Quarter Total Total 2N-315 25326 100 0 25426 See Note #1 below 25426 2L-325 8397 100 0 8497 11883 20380 2N-321A 27507 [ 100 0 27607 0 27607 3K-23 15 I 0 0 15 0 15 3K-25 4202 ~ 100 0 4302 0 4302 1C-15 16695 100 0 16795 0 16795 2L-313 8554 ] 100 0 8654 0 8654 Note #1: Well # 2N-315. The previously reported volume of 220 barrels was pumped into this annulus during the drilling of the well. This was the vohtme required to flush and freez, e protect tire annulus during initial drilling operations, not a volume of disposal~luids injected prior to the receipt oJ' authorizatitm t'or annular injection. Total Volumes into Annuli for which Injection Authorigation Expired during the quarter Total [ Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected [ Status of Annulus 1C-12 34995 100 0 35095 I Open, Freeze Protected 1 C- 13 26800 100 0 26900t Open. Freeze Protected Additionally, to prevent any possible confusion regarding previous reports of volumes injected, and to insure that the State's records are in agreement with ARCO's, we would like to repeat and supplement information we provided with our letter of February 26,1999. The information below is only for those wells for which injection volumes may not have been properly reported at the time of injection. Again, these volumes are the same as those reported with our February 26th letter, and are only reported here again for the sake of clarity. ARCO Alaska. mc. ts a Sabs~diary ot Atlantic Richfield Ccmpany AR3B-~J00S-C Ms. Wendy Mahan AOGCC First Quarter 1999 Annular Injection Report Page Two ~ i Total Total h(1) Total h(2) Total h(3) i Volume Current Status of Well Name Volume Volume Volume i Injected Annulus 2A-22 16749 100 0 i 16849 , Open, Freeze Protected 2F-19 20725 100 0 i 20825 . Open, Freeze Protected 3K-27 37173 100 0 i 37273 Open, Freeze Protected 3K-26 33970 100 0 i 34070 [ Open, Freeze Protected 1E-31 33645 100 0il 33745ti Open, Freeze Protected 1E-32 45205 100 0 45305 ! Open, Freeze Protected 3Q-22 6245 100 0 ! 6345 Open, Freeze Protected 1Q-24 23158 100 0 i 23258 Open, Freeze Protected 1Q-26 25931 100 0 i 26031 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC' Mike Zanghi Paul Mazzolini Randy Thomas Kuparuk Environmental: Engel / Snodgrass Morrison and Winfree Sharon Allsup-Drake Steve McKeever Well Files STATE OF ALASKA ~ _~ASKA OIL AND GAS CONSERVATION COMMISSION ~._~_,. APPLICATION FOR SUNDRY APPROVALS '1. Type of request: Abandon __ Suspend __ Operation Shutdown__ Reenter suspended well__ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate __ Change approved program _X_ Pull tubing __ Variance __ Perforate ~ Other__ ~2. Name of Operator: 5. Type of Well: 6. Datum of elavation {DF or KB feet): ARCO Alaska, Inc. Development ~1, 25.75' RKB 3. Address: Exploratory ~ 7. Unit or Property: P.O. Box 100360 Stratagrapic ~ Kuparuk River Unit Anchorage, AK 99510-0360 Service~ 4, Location of well at sur[ace: 8. Well number: 61' FNL, 763' FEL, Sec 3, TDN, R7E, UM 2N-321A At top of productive interval: 9. Permit number: 209' FNL, 669' FEL, Sec 33, T10N, R7E, UM 98-173 At effective depth: 10. APl number: 134' FNL, 721' FEL, Sec 33, T10N, R7E, UM 50-0103-20267-1 At total depth: '11. Field/Pool: 86' FNL, 860' FEL, Sec 28, T10N, R7E, UM Kuparuk River FieldFFarn Oil Pool 12. Present well condition summary Total Depth: measured 10027' feet true vertical 5430' feet Effective Depth: measured 9872' feet true vertical 5318' feet Casing Length Size Cemented Measured depth True vertical depth Conductor 110' 16" 10 cu. Yds High Early 110' 110' Surface 3861' 7-5/8" 364 sx ASIII LW 3861' 2295' 238 sx ASI 60 sx Class G Production 9310' 5.5" X 220 sx Class G 9310' 4905' Liner 676' 3-1/2" 10001' 5410' Perforation Depth 9531'-9542' MD 5068'-5076' 'I'VD 6spf 0 F~ I G i i~,~,! ~AL 9574'-9594' MD 5100'-5115' TVD 6 spf 9642'-9659' MD 5150'-5162' TVD 6 spf 9696'-9716' MD 5190'-5204' 'rVD 6 spf 9724'-9734' MD 5210'-5217' 'I'VD 6 spf 9600'-9613' MD 5119'-5129' 'I'VD 6 spf 9622'-9634' MD 5135'-5144' 'I'VD 6 spf 9664'-9682' MD 5166'-5179' TVD 6spf Tubing (size, grade, and measured depth) i;~ i ~.~.~=~i:;' !~-~ 'i ~ ~i !; !"~-i !ii 3-1/2", 9.3~¢, L-80, Tubing @ 9324' MD. Packers and SSSV (type and measured depth) ¢ d ~'~;_~.~ Baker Casing Seal Assby @ 9324' MD 13. Attachments Description summary of proposal _X Detailed operations program __ BOP sketch _ 14. Estimated date for commencing operation 15. Status of well classification as: 2/27/99 Oil _ Gas ~ Suspended __ 16. If proposal was verbally approved Name of approver Date approved Service: Injector 17. I hereby certify that the forgoing Is true and correct to the best of my knowledge. ' FOR COMMISSION USE ONLY Conditions c~/pproval: Notify Comission so r P ' ' e may witness IApproval ~-,~ Plug integrety_ BOP test__ Location clearance __ Mechanical integrety test__ Subsequent form required 10- ~O~'~· Approved by order of the Commissioner ~r~h~rl' N ~hdstenson Commissioner Date ........ ~UlcIMI I IN I I'~II-'LI(..;A I I-orm 1u-4u;.¢, I~ev uf511~1~5~ _v~d, Go~P~ Attachment 1 Description of Proposal Tarn Well 2N-321A ARCO Alaska is hereby requesting Commission approval for temporary injection of water into Well 2N-321A. Well 2N-321A was classified as an Injector on the Form 10- 407 Completion Report and had been on MI injection service since start-up. ARCO Alaska Inc. is evaluating the viability of MWAG EOR for the Tarn reservoir and proposes a short term trucked water injection test on Well 2N-321A as the first step in determining its long term feasibility. After completing a 1-2 week injection test on Well 2N-321A it will be returned to MI injection service. Pending evaluation of the test results, ARCO Alaska, Inc. will notify the Commission of the preferred longer term well disposition. ARCO Alaska, Inc. Kuparuk Operations Post Office Box 196105 Anchorage, Alaska 99519-6105 Telephone 907 659 2821 February 18, 1999 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in triplicate is an Application for Sundry Approval (Form following Tarn well. 10-403) on the Well 2N-321A Action Change Approved Program Your review and notification to us of approval status for our sundry change request would be appreciated by February 25, 1999. Pending approval, we anticipate commencing water injection operations February 27, 1999. If you have any questions, please call me at 265-6806. Sincerely, n Stramp Tarn Coordinator Attachments Well Files (attach only) ARCO Alaska. Inc. is a Subsidiary of Atlantic Richfield Company 1/20/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12257 Company Alaska Oil & Gas Cons Comm Attn: Loft Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk/Tarn Pool Well Job # Log Description Date BL Sepia 2B-01 PRODUCTION PROFILE 990114 1 1 2M-18 ~ ~ C.-.. MI INJECTION PROFILE 990105 I 1 2W-10 LLt C... MI INJECTION PROFILE 990102 ] 1 3N-05 LL! C__. INJECTION PROFILE 981212 I 1 2N-321A MI INJECTION PROFILE 990103 I ] 2N-331 MI INJECTION PROFILE 990104 I 1 Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. 12/21/98 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12181 Company Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Sepia D- 110 CBL-SCMT 981020 1 1 2L-329A CBL-SCMT 981122 1 1 2L-329A PRODUCTION LOG 981205 1 1 2L-329A PRODUCTION LOG 981207 1 1 2N-321A CBL-SCMT 981109 1 1 2N-325 CBL-SCMT 981108 1 1 2N-325 MI INJECTION PROFILE 981205 1 1 2N-331 CBL-SCMT 981123 1 1 E-35 CEMENT MAPPING LOG 981203 1 I -35 PRODUCTION LOG 981208 1 1 E;36 STATIC PRESS/TEMP 981123 1 1 1G-16 {~-~C~ MI INJECTION PROFILE 981202 1 1 1Q-07 STATIC PRESS/TEMP 981119 1 1 Y- 15A CBL-SCMT 981109 1 1 2M-34 ~._. MI INJECTION PROFILE 981110 1 1 2W-12 PRODUCTION PROFILE 981028 1 1 3F-04 ~I ~ MI INJECTION PROFILE 981203 1 1 3F-12 I~C. MI INJECTION PROFILE 981204 1 1 3F- 19 RST WFL & GLS 981 i03 1 1 3G-03 PROD PROFILE W/DEFT 981104 1 1 ~'.~ii~:~i! ~ii~ ~?"~: i',.~i.' ~'i~ .?' ~iii~ ~ .... 3K-25 LLI [ ~, INJECTION PROFILE 981014 1 1 t~ ~..~,=..~;"~.......~ '~' ;~'.,~,,~ .. 3K-26 ~ ------ ~--~___. INJECTION PROFILE 981014 1 1 SIGNE DATE: Please sign and ~~t~e co-pyz~f this transmittal to Sherrie at the above address. Thank you. / ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 16, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2N-321A (Permit No. 98-173) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 2N-321A. If there are any questions, please call 263-4603. Sincerely, P. Mazzolini Tarn Drilling Team Leader AAI Drilling PM/skad STATE OF ALASKA _-~.ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL E~ GAS E~] SUSPENDED E~] ABANDONED~ SERVICE [~ Ln~ector 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 98-173 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20267-01 4 Location of well at surface 9 Unit or Lease Name 61' FNL, 763' FEL, Sec. 3, T9N, R7E, UM'~i' :!ii':i;i:.;I :..i.i ~i 'i~: ~! Kuparuk River Unit AtTopProduoinglnte~a. ~.¢~~;'~--- '---. : ~~~ , 10 WellNumber 209' F~L, 669' FEL, Sec. 33, T10N, R7E, UM ~~~ 2N-321A At Total Depth ,~.. ~.; / 11 Field and Pool 86' FSL, 860' FEL, Sec. 28, T10N, R7E, UM .... ~ KUPARUK RIVER 5 Elevation in feet (indi~te KB, DF, etc.) ~ 6 Lease Designation and Serial No. Tarn Oil Pool RKB 28'~ ADL 380054 ALK 4602 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. J 15 Water Depth, if offshore 16 No. of Completions 15-Aug-98 27-Aug-98 29-Aug-98~ NA feet MSL 1 17 Total Depth (MD+~D) 18 Plug Back Depth (MD+~D) 19 Directional Su~ey 20 Depth where SSSV set 21 Thickness of permafrost 10027' MD & 5430' ~D 9872' MD & 5318' ~D YES ~ NO ~ N/A feet MD 1050' APPROX 22 Type Electric or Other Logs Run GR/Res, SCMT 23 CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE ~ GRADE TOP BTM HOLE SIZE CEMENT RECORD 16" 62.5¢ H-40 SURF. 110' 24" 10 cu yds High Eady 7.625" 29.7¢ L-80 SURF. 3861' 9.875" ~364 sx AS III LW, 238 sx AS I, 60 sx Class G 5.5" x 15.5¢ L-80 SURF. 9310' 6.75" 220 sx Class G 3.5" 9.3¢ L-80 9310' 10001' 6.75" (included above) 24 Pedorations open to Production (MD+~D of Top and BoSom and 25 TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 9531'-9542' MD 5068'-5076' ~D 6 spf 3.5" 9324' 9310' 9574'-9594' MD 5100'-5115' ~D 6 spf 9642'-9659' MD 5150'-5162' ~D 6 spf 26 ACID, FRACTURE, CEMEN 9696'-9716' MD 5190'-5204' ~D 6 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9724'-9734' MD 5210'-5217' ~D 6 spf N/A N/A 9600'-9613' MD 5119'-5129' ~D 6 spf 9622'-9634' MD 5135'-5144' ~D 6 spf 9664'-9682' MD 5166'-5179' ~D 6 spf 27 PRODUCTION TEST Date First Production Method of Operation (FIowing,iNJECTORgas li~, etc.) Date of Test Hours Tested PRODUCTION FOF',OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE ~ GAS-OIL RATIO I TEST PERIOD Flow Tubing Casing Pressure CALCU~TED OIL-BBL GAS-MCF WATER-BBL OIL GRAVIS-APl (corr) Press. 24-HOUR RATE: 28 CORE DATA Brief description of lithology, porosi~, fractures, apparent dips and presen~ of oil, gas or water. Submit ~re chips. N/A - - Submit in duplicate Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 9. : ' 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. T3 9524' 5063' T2 9752' 5231' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Drilling Reports, Directional Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~4~2 /~"~~---~'~*~ Title '~j.G,T~, J~'~4~'~¢.. DATE Prepared by Name/Number Sharon AIIsup-Drake/263-4612 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 11/18/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:2N-321A WELL_ID: AK9477A TYPE: AFC: AK9477A STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER I/NIT SPUD:08/15/98 START COMP: RIG:RIG # 141 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20267-01 08/24/98 (D1) TD: 0'( 0) SUPV:D.BURLEY MW: 9.1 VISC: 41 PV/YP: 13/12 TIME DRILLING KICKOFF PLUG $ 5385' APIWL: 5.5 Plugged back 6.75" hole from 11526' Pumped balanced plug 5200' 08/25/98 (D2) MW: 9.1 VISC: 44 PV/YP: 15/14 APIWL: 7.8 TD: 7407'(740?) STARTING WIPER TRIP FOR FOOTAGE DRILLED. SUPV:D.BURLEY~,q Wash down from 4980' to 5355' Drill from 5400' to 7407' 08/26/98 (D3) TD: 9408'(2001) SUPV:D.BURLEY MW: 9.3 VISC: 43 PV/YP: 11/13 DRILL 6-3/4" HOLE FROM 9800' Drill from 7407' to 9408' APIWL: 6.0 08/27/98 (D4) TD:10027' (619) SUPV:D.BURLEY MW: 9.8 VISC: 49 PV/YP: 13/16 RU TO RUN CASING. Drill from 9408' to 10027' APIWL: 4.8 08/28/98 (D5) TD:10027' ( 0 SUPV:D.BURLEY MW: 9.8 VISC: 44 PV/YP: 12/ 9 RUN 3-1/2" COMPLETION. Run 3.5" x 5.5" casing. Cement casing. APIWL: 4.8 08/29/98 (D6) TD:10027' ( 0 SUPV:D.BURLEY MW: 8.5 VISC: 28 PV/YP: 0/ 0 BEGIN RIG MOVE TO 2N-331. APIWL: 0.0 Run 3.5" completion. Planned shut down to connect high line control and monitor box to rig SCR system. Continue to run 3.5" completion. 08/30/98 (D7) TD:10027' ( 0 SUPV:D.BURLEY MW: 0.0 VISC: RELEASED RIG ~ 0600 HRS. 0 PV/YP: 0/ 0 APIWL: 0.0 ND BOPE and install adaptor flange and master valve and test to 5000 psi. Release rig @ 0600 hfs, 8/30/98. 0 I:! I I-I-- I I~ G WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs December 16, 1998 2N-321A, AK-MM-80338 1 LDWG formatted Disc with verification listing. API#: 50-103-20267-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATFACHED COPY OF THE TRANSMH'FAL LETTER TO THE ATYENTION OF: Sperry-Stm Drilling Service Attn: Ali Turker 5631 Silverado Way, Suite G. Anchora~e,_Alask.~ 995[& DEC 17 1998 Date: 3Jas~a Oii 0. 5.~ ~;un~. C;o;'nmission ~chorage Sign~ 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company WELL LOG TRANSMITYAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs December 16, 1998 2N-321A, AK-MM-80338 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of~ Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, ~G, Anchorage, AK 99518 2N-321A: 2"x 5" MD Resistivity & Gamma Ray Logs: 50-103-20267-01 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-103-20267-01 2"x 5"MD Neutron & Density Logs: 50-103-20267-01 2"x 5" TVD Neutron & Density Logs: 50-103-20267-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia DEC 17 i99:,3 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 273-3500 · Fax (907) 273-3535 A Halliburton Company " SURVEY CALCULATION AND FIELD WORKSHEET ~ Job No. 0451-00153 Sidetrack No. 1 Page 1 of 3 ,~1~~1~ Company ARCO ALASKA, INC. Rig Contractor & No. DOYON DRILLING CO. - #141 Field TARN DEVELOPMENT FIELD Well Name & No. TARN DRILLSITE 2N/321 Survey Section Name Definitive Survey BHI Rep. RANDY LANTZ J~Nl"r~~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord, N/S -60,46 Grid Correction 0.000 Depths Measured From: RKB ~] MSL[--1 SSE Target Description Target Coord. ENV Slot Coord. ENV -763.34 Magn. Declination 26.840 Calculation Method MINIMUM CURVATURE Target Direction (DD) Buil~Walk\DL per: 10Oftl~ 30mi'-j 10m0 Vert. Sec. Azim. 302.89 Magn, to Map Corr. 28.840 Map North to: OTHFR SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FI') (F'F) (FO (FO (Per 100 FO Drop (-) Left (-) MWD 5211,1 9 69,85 303.74 2804,54 3852.47 2193.10 -3168.48 TIE IN POINT 25-AUG-98 MWD 5286.37 69.58 304.59 75.18 2830.60 3922.03 2232.70 -3226.83 1.12 -0.36 1.13 4 3/4' M1XL 1.2 DEG AKO '~ 25-AUG-98 MW[3 5386.49 66.98 307.06 100.12 2867.66 4014.91 2287.12 -3302.24 3.46 -2.60 2.47 25-AUG-98 MWD 5479.29 65.80 305.75 92,80 2904.83 4099.77 2337.58 -3370.67 1.81 -1.27 -1.41 25-AUG-98 MWD 5572.68 66.25 305.09 93.39 2942.77 4185.02 2387.04 -3440.21 0.81 0.48 -0.71 25-AUG-98 MWD 5666.65 66.78 305.40 93.97 2980.22 4271.13 2436.77 -3510.60 0.64 0.56 0.33 25-AUG-98 MWD 5760.33 67.18 304.93 93.68 3016.86 4357.29 2486.43 -3581.08 0.63 0.43 -0.50 25-AUG-98 MWD 5853.83 66.22 307.21 93.50 3053.84 4443.02 2536.98 -3650.49 2.46 -1.03 2.44 25-AUG-98 MWD 5946.86 63.72 309.05 93.03 3093.20 4526.95 2589.01 -3716.80 3.23 -2.69 1.98 25-AUG-98 MWD 6041.87 62.05 309.85 95.01 3136.51 4610.96 2642.74 -3782.10 1.91 -1.76 0.84 25-AUG-98 MWD 6135.97 61.08 309.85 94.10 3181.31 4693.10 2695.76 -3845.62 1.03 -1.03 0.00 25-AUG-98 MWD 6228.24 60.59 313.75 92.27 3226.29 4772.68 2749.44 -3905.68 3.73 -0.53 4.23 25-AUG-98 MWD 6322.19 59.87 316.68 93.95 3272.95 4852.34 2807.31 -3963.12 2.81 -0.77 3.12 25-AUG-98 MWD 6416.99 59.48 316.85 94.80 3320,81 4931.78 2866.93 -4019.17 0.44 -0.41 0.18 ~, 25-AUG-98 MWD 6512.21 60.29 320.78 95.22 3368.60 5010.96 2928.90 -4073.38 3.67 0.85 4.13 25-AUG-98 MWD 6604.94 59.64 324.18 92.73 3415.02 5086.57 2992.56 -4122.27 3.25 -0.70 3.67 25-AUG-98 MWD 6702.32 59.76 327.46 97.38 3464.16 5163.99 3062.10 -4169.50 2.91 0.12 3.37 25-AUG-98 MWD 6795.76 58.78 329.27 93.44 3511.91 5236.50 3130.47 -4211.63 1.97 -1.05 1.94 25-AUG-98 MWD 6890.43 57.91 330.95 94.67 3561.60 5308.16 3200.33 -4251.79 1,77 -0.92 1.77 25-AUG-98 MWD 6983.44 57.80 331.90 93.01 3611.09 5377.34 3269.49 -4289.45 0.87 -0.12 1.02 25-AUG-98 MWD 7079,49 57.68 332.33 96.05 3662.36 5448.23 3341.28 -4327.44 0.40 -0.12 0.45 25-AUG-98 MWD 7172.63 57.36 332.30 93.14 3712.37 5516.66 3410.86 -4363.95 0.34 -0.34 -0.03 25-AUG-98 MWD 7265.84 56.67 334.54 93.21 3763.12 5584.00 3480.77 -4398.93 2,15 -0.74 2.40 25-AUG-98 MWD 7360.85 56.44 335.80 95.01 3815.49 5651.03 3552.72 -4432.22 1.13 -0.24 1.33 .l__ II SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-00153 Sidetrack No. 1 Page 2 of 3 Company ARCO AI._~SK~, INC. Rig Contractor & No. DOYEN DRILLING CO. - #141 Field TARN DEVELOPMENT FIELD Well Name & No. TARN DRILLSITE 2N/321 Survey Section Name Definitive Survey BHI Rep. RANDY LANTZ ~~ WELL DATA Target TVD (F'r) Target Coord. N/S Slot Coord. N/S -60.46 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~] SS~ Target Description Target Coord. ENV Slot Coord. E/W -763.34 Magn. Declination 26.840 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft~ 30mD 10m[~ Vert. Sec. Azim. 302.89 Magn. to Map Corr. 26.840 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length 'rVD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (F-r) (DD) (DD) (FT) (FT) (FT) (FT) (Per 100 F-I') Drop (-) Left (-) -- 26-AUG-98 MWD 7455.37 56.23 335.47 94.52 3867.88 5717.19 3624.38 -4464.68 0.37 -0.22 -0.35 _ , 26-AUG-98 MWD 7549.47 55.69 335.17 94.10 3920.56 5783.01 3695.23 -4497.24 0.63 -0.57 -0.32 -- 26-AUG-98 MWD 7643.01 57.20 337.17 93.54 3972.26 5848.16 3766.53 -4528.72 2.40 1.61 2.14 26-AUG-98 MWD 7737.69 57.41 336.08 94.68 4023.41 5914.42 3839.67 -4560.33 0.99 0.22 -1.15 26-AUG-98 MWD 7829.51 57.48 337.21 91.82 4072.82 5978.77 3910.72 -4591.01 1.04 0.08 1.23 ,,. 26-AUG-98 MWD 7920.65 57.96 336.02 91.14 4121.49 6042.85 3981.44 -4621.59 1.22 0.53 -1.31 26-AUG-98 MWD 8015.40 58.34 335.39 94.75 4171.49 6110.49 4054.80 -4654.71 0.69 0.40 -0.66 I .... 26-AUG-98 MWD 8109.31 59.02 335.46 93.91 4220.31 6178.13 4127.76 -4688.07 0.73 0.72 0.07 26-AUG-98 MWD 8201.41 59.17 334.66 92.10 4267.61 6245.02 4199.41 -4721.39 0.76 0.16 -0.87 26-AUG-98 MWD 8294.68 57.91 335.50 93.27 4316.29 6312.35 4271.56 -4754.92 1.55 -1.35 0.90 26-AUG-98 MWD 8390.35 56.67 334.77 95.67 4367.99 6380.43 4344.59 -4788.76 1.45 -1.30 -0.76 26-AUG-98 MWD 8483.94 57.31 335.52 93.59 4418.98 6446.80 4415.81 -4821.75 0.96 0.68 0.80 26-AUG-98 MWD 8577.89 57.88 333.91 93.95 4469.32 6514.19 4487.52 -4855.63 1.57 0.61 -1.71 26-AUG-98 MWD 8671.50 58.63 334.18 93.61 4518.58 6582.31 4559.10 -4890.47 0.84 0.80 0.29 /' -- 26-AUG-98 MWD 8766.59 57.41 334.06 95.09 4568.94 6651.28 4631.67 -4925.67 1.29 -1.28 -0.13 26-AUG-98 MWD 8857.94 56.26 332.34 91.35 4618.91 6717.29 4699.92 -4960.14 2.02 -1.26 -1.88 26-AUG-98 MWD 8953.69 53.98 331.38 95.75 4673.67 6786.00 4769.18 -4997.18 2.52 -2.38 -1.00 26-AUG-98 MWD 9047.77 52.43 332.19 94.08 4730.01 6851.96 4835.56 -5032.80 1.79 -1.65 0.86 26-AUG-98 MWD 9142.42 49.39 333.11 94.65 4789.69 6915.73 4900.80 -5066.56 3.30 -3.21 0.97 26,AUG-98 MWD 9235.83 46.07 331.74 93.41 4852.51 6975.85 4962.07 -5098.53 3.72 -3.55 -1.47 , 26-AUG-98 MWD 9329.05 43.36 331 ;96 93.22 4918.75 7033.23 5019.89 -5129.47 2.91 -2.91 0.24 27-AUG-98 MWD 9425.20 42.08 329.00 96.15 4989.39 7091.02 5076.65 -5161.59 2.48 -1.33 -3.08 27-AUG-98 MWD 9517.59 42.07 330.46 92.39 5057.97 7146.26 5130.11 -5192.79 1.06 -0.01 1.58 27-AUG-98 MWD 9610.37 42.48 328.66 92.78 5126.63 7202.03 5183.92 -5224.41 1.38 0.44 -1.94 i ~' " SURVEY CALCULATION AND FIELD WORKSHEET Job No. 0451-00153 Sidetrack No. 1 Page 3 of 3 ~11~1~11~ Company ARCO ALASKA, INC. Rig Contractor & No. DOYEN DRILLING CO. - #141 Field TARN DEVELOPMENT FIELD Well Name & No. TARN DRILLSITE 2N/321 Survey Section Name Definitive Survey BHI Rep. RANDY LANTZ j~j~r~~ WELL DATA Target TVD (FT) Target Coord. N/S Slot Coord. N/S -60.46 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SS[~ Target Description Target Coord. E/W Slot Coord. E/W -763.34 Magn. Declination 26.840 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft~ 30m0 10m[~ Vert. Sec. Azim. 302.89 Magn. to Map Corr. 26.840 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (F'r) (DD) (DD) (FT) (FI') (FT) (F'T) (Per 100 FT) Drop (-) Left (-) 27-AUG-98 MWD 9707.81 42.93 328.47 97.44 5198.23 7261.59 5240.30 -5258.88 0.48 0.46 -0.19 -- 27-AUG-98 MWD 9801.44 43.31 328.19 93.63 5266.57 7319.38 5294.77 -5292.48 0.45 0.41 -0.30 27-AUG-98 MWD 9895.76 43.84 326.42 94.32 5334.91 7378.58 5349.48 -5327.60 1.41 0.56 -1.88 27-AUG-98 MWD 9949.29 43.80 327.69 53.53 5373.53 7412.39 5380.58 -5347.76 1.64 -0.07 2.37 27-AUG-98 MWD 10028.00 43.80 327.69 78.71 5430.34 7461.85 5426.62 -5376.88 0.00 0.00 0.00 Projected Data - NO SURVEY ,. __ ., i ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1 (2N-321A(W4-6)) WELL JOB SCOPE JOB NUMBER " 2N-321A PERFORATE, PERF SUPPORT 0902981619.2 DATE DAILY WORK UNIT NUMBER 11/24/98 PERFORATE DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 5 NO YES SWS-ELMORE KRALICK FIELD AFC# CC# Signed ESTIMATE K85112 Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSI 200 PSI 0 PSI 0 PSII 0 PSII 0 PSI DAILY SUMMARY PERFORATE W/2.5" HC/DP/6 SPF/60 DEGREE PHASED FROM 9574' - 9594'[Perf] I TIME LOG ENTRY 15:00 MIRU SWS 16:00 P/T BOP AND LUB TO 3000 PSI 16:30 RIH W/CCI/SAFE SYSTEM/20' 2 1/2" HC/6 SPF/DP/60 DEGREE PHASED W/5' ROLLER STEM ON BOTTOM 17:30 NOTE 3' DIFFERENCE BETWEEN SCMT AND MWD LOG - CORRECT TO GAMMA 3'+ 17:45 SHOOT 9574' - 9594' CORRECTED W/200 PSI OVERBALANCE - RIH TO CHECK TAG DEPTH AND STOP BELOW BOTTOM PERF @ 9785' 18:45 POOH - ALL SHOTS FIRED 20:00 RDFN ARCO Alaska, Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT ~ K1 (2 N-321A(W4-6)) WELL JOB SCOPE JOB N'UMBER " 2N-321A PERFORATE, PERF SUPPORT 0902981619.2 DATE DAILY WORK UNIT NUMBER 11/25/98 PERFORATE DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR 6 NO YES SWS-ELMORE GOBER FIELD AFC# CC# Signed ESTIMATE K85112 180KNU2TN Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 200 PSI 200 PSI 0 PSI 0 PSII 0 PSII 0 PSI DALLY SUMMARY PERFORATE W/2.5" HC/6 SPF/DP/60 DEGREE PHASING - PERF INTERVAL 9724'-9734', 9696'-9716', AND 9642'-9659' USING MWD LOG AS REFERENCE[Pert'] TIME LOG ENTRY 08:00 RU BOP AND LUBRICATOR - PRESSURE TEST TO 3500 PSI 08:45 RIH W/10' 2.5" HC/6 SPF/DP/60 DEGREE PHASING/SAFE SYSTEM/5' ROLLER STEM ON BOTTOM - TIE IN TO CCL ON SCMT LOG - ADD 3' TO SCMT DEPTH TO GET MWD DEPTH - PERF 9724'-9734' - POOH - ALL SHOTS FIRED 12:00 RIH W/20' GUN SAME AS ABOVE - TIE IN W/SCMT USING 3' CORRECTION - PERF 9696'-9716' - POOH - ALL SHOTS FIRED 14:30 RIH W/17' GUN SAME AS ABOVE - TIE IN W/SCMT USING 3' CORRECTION - PERF 9642'-9659' - POOH - ALL SHOTS FIRED 18:00 RDFN ARCO Alaska, Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT '' K1 (2N-321A(W4-6)) WELL JOB SCOPE JOB I~UMBER ' " 2N-321A PERFORATE. PERF SUPPORT 0902981619.2 DATE DAILY WORK UNIT NUMBER 11/26/98 PERF 2128 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 7 YESI YES SWS-JOHNSON KRALICK FIELD AFC# CC# Signed ESTIMATE K85112 180KNU2TN Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann , Initial Outer Ann , Final Outer Ann 0 PSI 200 PSI 0 PSI 0 PSIII0 PSI 0 PSI DAILY SUMMARY IPERF W/2.5" HC/6 SPF/DP/60 DEGREE PHASING FROM 9664'- 9682'/9622'-9634'/9600'-9613'/9531'-9542'- SHOT WITH 200 PSI OVERBALANCE ON WELL - PERF JOB COMPLETE[Perf] TIME LOG ENTRY 07:00 MIRU SWS 08:00 TGSM AND P/T TO 3000 PSI 08:30 RIH W/CCL/SAFE GUN/ROLLERS AND 2.5" HC GUNS 6 SPF/DP/60 DEGREE PHASED TO PERF @ 9664' - 9682' - PRESSURE WELL TO 200 PSI TO SHOOT OVERBALANCED 09:30 POOH ALL SHOTS FIRED 10:00 RIH W/SAME TO SHOOT 9622' - 9634' - POOH ALL SHOTS FIRED 13:00 RIH W/SAME TO SHOOT 9600'- 9613' - POOH ALL SHOTS FIRED 16:30 RIH W/SAME TO SHOOT 9531'- 9542'- POOH ALL SHOTS FIRED 19:00 RDMO SCHLUMBERGER - ALL ZONES PERF'D PER PROCEDURE ORIGINAL ARCO ALASKA INC. DRILLSITE 2N, WELL NO. 2N-321A TARN POOL, KUPARUK RIVER UNIT, ALASKA Gyro Continuous Multishot Survey Inside 3.5" TUBING Survey date: 07 - NOVEMBER, 1998 Job number: AK1198GCE506 CONTENTS JOB NUMBER' AK1198GCE506 1. DISCUSSION, SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS = INRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT 1. DISCUSSION , SURVEY CERTIFICATION SHEET DISCUSSION JOB NUMBER · AK1198GCE506 Tool 761 was run in WELL# 2N-321A on SCHLUMBERGER 7/32" wireline inside 3.5" TUBING. The survey was completed without any problems. SURVEY CERTIFICATION SHEET JOB NUMBER: AK1198GCE506 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the original data obtained at the wellsite. Checked by :- JACK E. MAY OPERATIONS MANAGER 2. SURVEY DETAILS SURVEY DETAILS JOB NUMBER: AK1198GCE506 CLIENT: ARCO ALASKA INC. RIG: SCHLUMBERGER LOCATION: DRILLSITE 2N WELL: 2N-321A LATITUDE: 70.25 N LONGITUDE: 149.8 W SURVEY DATE: SURVEY TYPE : 07 - NOVEMBER, 1998 GYRO CONTINUOUS MULTISHOT DEPTH REFERENCE: ROTARY TABLE ELEVATION 147.3' MAX. SURVEY DEPTH: 9175' SURVEY TIED ONTO: N/A SURVEY INTERVAL: 0-9175' APl NUMBER: TARGET DIRECTION: 050-103-20267-01 302.89 GRID CORRECTION: N/A CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: TOM STODDARD 3. INRUN SURVEY LISTING A Gyro d a t a D i r e c t i ona i Survey for ARCO ALASKA INC. WELL: 2N-321A, 3.5" Location: DRILLSITE 2N, TARN POOL, ALASKA Job Number: AKl198GCE506 Run Date: 7-Nov-98 14:38:25 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.250000 deg. N Sub-sea Correction from Vertical Reference: 147.3 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 302.890 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gy r o da t a D i r e c t i o na i Survey ARCO ALASKA INC. WELL: 2N-321A, 3.5" Location: DRILLSITE 2N, Job Number: AKl198GCES06 MEASURED DEPTH feet I N C L AZIMUTH deg. deg. 0 100 200 300 40O 5OO 6OO 700 750 8OO 850 900 950 1000 1050 1100 1150 1200 1250 1300 1350 1400 1450 1500 1550 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 0.00 0.00 .91 317.89 1.08 317.84 2.03 315.54 5.22 311.69 9.13 311.95 11.99 311.84 14.36 318.49 15.64 318.86 16.76 318.84 17.56 318.60 18.99 318.51 20.77 318.65 23.73 318.86 26.26 318.91 29.64 319.31 32.53 319.09 34.05 318.88 37.23 317.92 38.95 317.14 40.86 316.53 42.34 315.98 44.11 ,315.94 46.66 315.89 51.01 315.92 TARN POOL, ALASKA DOGLEG VERTICAL SUBSEA VERTICAL SEVERITY DEPTH DEPTH SECTION deg./ feet feet feet 100 ft. 0.00 0.0 -147.3 0.0 .91 100.0 -47.3 .8 · 18 200.0 52.7 2.4 · 95 299.9 152.6 5.1 3.19 399.7 252.4 11.3 3.91 498.9 351.6 2.86 597.2 449.9 2.81 694.6 547.3 2.57 742.9 595.6 2.24 790.9 643.6 1.61 838.7 691.4 2.85 886.2 738.9 3.57 933.2 785.9 5.92 979.4 832.1 5.05 1024.8 877.5 6.77 1068.9 921.6 5.80 1111.7 964.4 3.05 1153.5 1006.2 6.46 1194.2 1046.9 3.58 1233.5 1086.2 3.90 1271.9 1124.6 3.04 1309.2 1161.9 3.54 1345.7 1198.4 5.09 1380.8 1233.5 8.71 1413.7 1266.4 Page CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 23.6 41.7 63.9 76.4 89.8 104.0 119.1 135.5 153.7 174.0 196.5 221.2 247.6 275.7 305.5 336.7 369.0 402.3 437.0 473.7 0.0 0.0 .8 317.9 2.5 317.9 5.2 317.1 11.6 314.7 24.0 313.2 42.4 312.7 65.1 313.6 78.0 314.5 91.9 315.1 106.6 315.6 122.3 316.0 139.3 316.3 158.2 316.6 179.3 316.9 202.7 317.1 228.5 317.4 255.9 317.5 285.1 317.6 315.9 317.6 348.0 317.5 381.2 317.4 415.4 317.3 451.0 317.2 488.6 317.1 0.0 N 0.0 E .6 N .5 W 1.9 N 1.7 W 3.8 N 3.6 W 8.1 N 8.2 W 16.5 N 17.5 W 28.7 N 31.2 W 44.9 N 47.1 W 54.6 N 55.7 W 65.1 N 64.8 W 76.2 N 74.6 W 88.0 N 84.9 W 100.7 N 96.2 W 114.9 N 108.7 W 130.9~ N 122.6 W 148.6 N 137.9 W 168.1 N 154.8 W 188.8 N 172.8 W 210.6 N 192.1 W 233.3 N 212.9 W 256.7 N 234.9 W 280.7 N 257.8 W 305.3 N 281.7 W 330.9 N 306.4 W 357.9 N 332.6 W A Gy r o da t a D i r e c t i ona i S u rvey ARCO ALASKA INC. WELL: 2N-321A, 3.5" Location: DRILLSITE 2N, Job Number: AKl198GCES06 TARN POOL, ALASKA MEASURED I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. 1600.0 54.73 316.10 7.45 1650.0 57.70 316.29 5.93 1700.0 58.53 316.07 1.70 1750.0 61.47 314.37 6.57 1800.0 64.38 311.81 7.40 1850.0 65.63 310.43 3.53 1900.0 67.26 308.04 5.48 1950.0 67.85 306.72 2.70 2000.0 68.40 305.85 1.96 2050.0 68.72 305.38 1.09 2100.0 68.00 302.66 5.26 2150.0 67.64 301.67 1.96 2200.0 67.74 301.62 .22 2250.0 68.13 301.57 .79 2300.0 68.06 301.71 .29 2350.0 68.26 301.74 2400.0 68.61 301.92 2450.0 68.82 302.01 2500.0 69.14 301.99 2550.0 69.07 302.19 2600.0 69.34 301.43 2650.0 68.66 299.52 2700.0 68.81 299.44 2750.0 68.57 299.43 2800.0 68.61 299.53 .40 .78 .44 .65 .41 1.53 3.82 .34 .50 .20 VERTICAL SUBSEA VERTICAL DEPTH DEPTH SECTION feet feet feet 1443.9 1471.7 1498.1 1523.1 1545.8 1567.0 1587.0 1606.0 1624.7 1642.9 1661.4 1680.3 1699.2 1718.0 1736.7 1755.3 1773.6 1791.8 1809.7 1827.6 1845.3 1863.2 1881.4 1899.5 1917.8 1296.6 512.5 1324.4 552.9 1350.8 594.2 1375.8 636.5 1398.5 680.3 1419.7 725.2 1439.7 770.7 1458.7 816.8 1477.4 863.1 1495.6 909.6 CLOSURE DIST. AZIMUTH feet deg. 528.5 317.0 570.0 317.0 612.5 316.9 655.7 316.8 700.2 316.6 745.3 316.2 790.8 315.8 836.5 315.4 882.4 314.9 928.3 314.4 Page 1514.1 956.1 974.1 313.9 1533.0 1002.4 1019.4 313.4 1551.9 1048.6 1064.8 312.9 1570.7 1094.9 1110.3 312.4 1589.4 1141.3 1155.9 312.0 HORIZONTAL COORDINATES feet 1608.0 1187.7 1201.6 311.6 1626.3 1234.2 1247.4 311.2 1644.5 1280.8 1293.4 310.9 1662.4 1327.5 1339.5 310.6 1680.3 1374.2 1385.8 310.3 1698.0 1420.9 1432.0 310.0 1715,9 1467.5 1478.1 309.7 1734.1 1514.0 1523.9 309.4 1752.2 1560.5 1569.8 309.1 1770.5 1607.0 1615.7 308.8 386.6 N 360.3 W 416.6 N 389.0 W 447.2 N 418.4 W 477.9 N 448.9 W 508.3 N 481.5 W 538.1 N 515.6 W 567.1 N 551.1 W 595.2 N 587.8 W 622.6 N 625.2 W 649.7 N 663.1 W 675.7 N 701.6 W 700.4 N 740.8 W 724.7 N 780.1 W 748.9 N 819.6 W 773.3~N 859.1 W 797.7 N 898.6 W 822.2 N 938.1 W 846.9 N 977.6 W 871.6 N 1017.2 W 896.4 N 1056.8 W 921.1 N 1096.5 W 944.7 N 1136.7 W 967.7 N 1177.3 W 990.6 N 1217.9 W 1013.5 N 1258.4 W A Gyro da t a D i r e c t i o na i Survey ARCO ALASKA INC. WELL: 2N-321A, 3.5" Location: DRILLSITE 2N, Job Number: AKl198GCES06 MEASURED I N C L AZIMUTH DEPTH feet deg. deg. 2850.0 68.96 299.59 2900.0 69.17 299.73 2950.0 68.83 299.62 3000.0 69.46 299.75 3050.0 69.34 299.76 3100.0 69.23 299.92 3150.0 69.32 300.01 3200.0 69.54 300.05 3250.0 69.96 300.05 3300.0 69.98 300.09 3350.0 70.27 300.24 3400.0 70.63 300.34 3450.0 69.61 299.29 3500.0 68.56 297.48 3550.0 68.54 297.40 3600.0 68.87 297.32 3650.0 69.15 297.20 3700.0 68.97 297.15 3750.0 69.14 297.01 3800.0 69.13 296.94 3850.0 69.06 297.17 3900.0 69.70 297.59 3950.0 69.63 297.88 4000.0 69.00 298.56 4050.0 67.34 299.51 TARN POOL, ALASKA DOGLEG VERTICAL SUBSEA VERTICAL SEVERITY DEPTH DEPTH SECTION deg./ feet feet feet 100 ft. CLOSURE DIST. AZIMUTH feet deg. Page 3 .72 1935.9 1788.6 1653.5 1661.8 308.6 .48 1953.7 1806.4 1700.2 1707.9 308.3 .70 1971.7 1824.4 1746.8 1754.1 308.1 1.28 1989.5 1842.2 1793.4 1800.3 307.9 .25 2007.1 1859.8 1840.2 1846.6 307.7 HORIZONTAL COORDINATES feet 1036.5 N 1298.9 1059.6 N 1339.5 1082.7 N 1380.1 1105.8 N 1420.7 1129.0 N 1461.3 .44 2288.8 2141.5 2586.6 2588.6 305.1 1488.4 N 2117.9 W 1.49 2306.4 2159.1 2633.2 2635.0 305.0 1509.9 N 2159.4 W .55 2323.8 2176.5 2679.9 2681.5 304.8 1531.7 N 2200.9 W 1.79 2341.4 2194.1 2726.5 2727.9 304.7 1553.8 N 2242.2 W 3.75 2360.0 2212.7 2772.8 2774.1 304.6 1576.3 N 2282.7 W .69 2199.5 2052.2 2354.3 2357.6 305.9 1382.0 N 1910.0 W .59 2217.4 2070.1 2400.8 2403.7 305.7 1403.3 N 1951.5 W ?" .38 2235.2 2087.9 2447.3 2449.9 305.6 1424.7 N 1993.1 W .43 2253.1 2105.8 2493.7 2496.1 305.4 1445.9 N 2034.7 W .12 2270.9 2123.6 2540.2 2542.3 305.2 1467.1 N 2076.3 W .65 2111.4 1964.1 2121.1 2125.7 306.7 1269.7 N 1704.8 W .76 2128.2 1980.9 2168.1 2172.5 306.5 1293.5 N 1745.5 W 2.85 2145.2 1997.9 2215.1 2219.2 306.4 1316.9 N 1786.3 W 3.98 2163.0 2015.7 2261.6 2265.5 306.2 1339.1 N 1827.4 W .15 2181.3 2034.0 2308.0 2311.5 306.1 1360.5~' N 1868.7 W .36 2024.7 1877.4 1886.9 1893.0 307.5 1152.3 N 1501.9 W .24 2042.4 1895.1 1933.6 1939.4 307.3 1175.7 N 1542.4 W .44 2060.0 1912.7 1980.3 1985.8 307.1 1199.1 N 1582.9 W .84 2077.3 1930.0 2027.2 2032.4 307.0 1222.6 N 1623.5 W .08 2094.4 1947.1 2074.1 2079.0 306.8 1246.1 N 1664.2 W A Gyro d a t a D i r e c t i ona i S u rvey ARCO ALASKA INC. WELL: 2N-321A, 3.5" Location: DRILLSITE 2N, Job Number: AKl198GCE506 MEASURED DEPTH feet I N C L AZIMUTH deg. deg. 4100.0 4150.0 4200.0 4250.0 4300.0 4350.0 4400.0 4450.0 4500.0 4550.0 4600.0 4650.0 4700.0 4750.0 4800.0 4850.0 49O0.O 4950.0 5000.0 5050.0 5100.0 5150.0 5200.0 5250.0 5300.0 66.80 300.88 66.34 302.36 66.31 303.81 66.53 304.62 66.25 305.10 66.48 305.25 66.25 305.24 66.29 305.49 67.27 305.56 66.88 305.44 66.97 305.43 66.83 305.51 66.63 305.46 67.99 305.07 67.96 304.80 68.46 304.64 68.01 304.44 68.29 304.25 68.49 304.28 69.31 304.29 69.91 304.20 69.99 304.15 69.76 304.00 69.81 304.01 69.23 304.14 TARN POOL, ALASKA DOGLEG VERTICAL SUBSEA VERTICAL SEVERITY DEPTH DEPTH SECTION deg./ feet feet feet 100 ft. 2.75 2379.5 2232.2 2818.8 2.86 2399.4 2252.1 2864.7 2.67 2419.5 2272.2 2910.5 1.54 2439.5 2292.2 2956.3 1.04 2459.5 2312.2 3002.1 .53 2479.5 2332.2 3047.9 .47 2499.6 2352.3 3093.6 .48 2519.7 2372.4 3139.4 1.95 2539.4 2392.1 3185.3 .81 2558.9 2411.6 3231.3 .18 2578.5 2431.2 3277.2 .31 2598.1 2450.8 3323.2 .41 2617.8 2470.5 3369.1 2.80 2637.1 2489.8 3415.1 .51 2655.9 2508.6 3461.5 1.06 2674.4 2527.1 3507.9 .98 2693.0 2545.7 3554.3 .67 2711.6 2564.3 3600.7 · 39 2730.0 2582.7 3647.2 1.65 2748.0 2600.7 3693.8 1.22 2765.4 2618.1 3740.6 · 18 2782.6 2635.3 3787.6 .54 2799.8 2652.5 3834.5 .11 2817.0 2669.7 3881.5 1.20 2834.5 2687.2 3928.3 Page CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 2820.0 304.6 2865.9 304.5 2911.6 304.5 2957.5 304.5 3003.3 304.5 3049.1 304.5 3094.9 304.5 3140.6 304.5 3186.6 304.5 3232.6 304.5 3278.6 304.6 3324.6 304.6 3370.5 304.6 3416.7 304.6 3463.0 304.6 3509.4 304.6 3555.9 304.6 3602.3 304.6 3648.8 304.6 3695.4 304.6 3742.3 304.6 3789.2 304.6 3836.2 304.6 3883.1 304.6 3930.0 304.6 , 1599.5 N 2322.5 W 1623.5 N 2361.6 W 1648.5 N 2400.0 W 1674.3 N 2437.9 W 1700.5 N 2475.5 W 1726.9 N 2512.9 W 1753.3 N 2550.3 W 1779.8 N 2587.6 W 1806.5 N 2625.0 W 1833.2 N 2662.5 W 1859.9 N 2700.0 W 1886.6 N 2737.5 W 1913.3 N 2774.9 W 1939.9 N 2812.5 W 1966.4~ N 2850.5 W 1992.9 N 2888.7 W 2019.2 N 2926.9 W 'i[ 2045.4 N 2965.3 W 2071.6 N 3003.7 W 2097.8 N 3042.2 W 2124.2 N 3081.0 W 2150.6 N 3119.8 W 2176.9 N 3158.7 W 2203.1 N 3197.6 W 2229.4 N 3236.4 W A Gyro d a t a D i r e c t i ona i S u rvey ARCO ALASKA INC. WELL: 2N-321A, 3.5" Location: DRILLSITE 2N, Job Number: AKl198GCE506 MEASURED I N C L AZIMUTH DEPTH feet deg. deg. 5350.0 69.17 304.27 5400.0 66.35 305.58 5450.0 65.44 305.58 5500.0 65.83 305.57 5550.0 65.89 305.51 5600.0 66.36 305.49 5650.0 66.53 305.47 5700.0 66.69 305.24 5750.0 67.19 305.27 5800.0 67.33 305.05 5850.0 66.65 306.31 5900.0 65.44 307.46 5950.0 63.77 308.41 6000.0 63.29 308.70 6050.0 61.98 309.24 6100.0 61.97 309.47 6150.0 61.22 311.11 6200.0 60.99 311.55 6250.0 60.31 313.67 6300.0 60.14 314.65 6350.0 59.81 316.29 6400.0 59.73 316.91 6450.0 59.47 318.51 6500.0 60.02 319.58 6550.0 60.10 321.64 TARN POOL, ALASKA DOGLEG VERTICAL SUBSEA VERTICAL SEVERITY DEPTH DEPTH SECTION deg./ feet feet feet 100 ft. .27 2852.3 6.12 2871.2 1.83 2891.6 .78 2912.3 .17 2932.7 .94 2953.0 .35 2972.9 .52 2992.8 1.01 3012.4 .50 3031.7 2.68 3051.2 3.20 3071.5 3.76 3093.0 1.09 3115.3 2.79 3138.2 .42 3161.7 3.25 3185.5 .89 3209.7 3.95 3234.2 1.74 3259.0 2.90 3284.0 1.08 3309.2 2.82 3334.5 2.14 3359.7 3.58 3384.7 Page 5 CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 2705.0 3975.0 2723.9 4021.3 2744.3 4066.8 2765.0 4112.3 2785.4 4157.9 2805.7 4203.6 2825.6 4249.4 2845.5 4295.2 2865.1 4341.2 2884.4 4387.3 2903.9 4433.2 2924.2 4478.8 2945.7 4523.8 2968.0 4568.3 2990.9 4612.5 3014.4 4656.4 3038.2 4700.0 3062.4 4743.3 3086.9 4786.2 3111.7 4828.8 3136.7 4871.0 3161.9 4913.0 3187.2 4954.7 3212.4 4996.2 3237.4 5037.4 3976.7 304.6 4023.0 304.6 4068.6 304.6 4114.1 304 . 6 4159.8 304.6 4205.5 304.6 4251.3 304.6 4297.2 304.6 4343.2 304.6 4389.3 304.6 4435.3 304.6 4481.0 304.7 4526.1 304.7 4570.7 304.7 4615.0 304.8 4659.0 304.8 4702.8 304.9 4746.3 304.9 4789.5 305.0 4832.3 305.1 4874.9 305.2 4917.3 305.3 4959.4 305.4 5001.4 305.5 5043.2 305.6 2255.7 N 2282.2 N 2308.7 N 2335.2 N 2361.7 N 2388.3 N 2414.9 N 2441.4 N 2468.0 N 2494.5 N 2521.4 N 2548.8 N 2576.6 N 2604.5 N 2632.4~ N 2660.4 N 2688.8 N 2717.7 N 2747.2 N 2777.5 N 2808.3 N 2839.7 N 2871.6 N 2904.2 N 2937.7 N 3275.1 3313.0 3350.1 3387.2 3424.3 3461.5 3498.8 3536.3 3573.8 3611.5 3648 3685 3721 3756 3790 3824.7 W 3858.3 W~'," 3891.2 W 3923.2 W 3954.4 W 3984.7 W 4014 . 4 W 4043 . 4 W 4071.7 W 4099.2 W A Gyro da t a D i r e c t i ona i Survey ARCO ALASKA INC. WELL: 2N-321A, 3.5" Location: DRILLSITE 2N, Job Number: AKl198GCE506 MEASURED I N C L AZIMUTH DEPTH feet deg. deg. 6600.0 59.94 322.91 6650.0 59.68 324.53 6700.0 59.44 326.00 6750.0 59.62 326.91 6800.0 58.54 328.58 6850.0 58.85 329.30 6900.0 57.79 331.23 6950.0 57.45 331.55 7000.0 57.75 331.51 7050.0 57.57 331.56 7100.0 57.44 332.43 7150.0 57.19 332.69 7200.0 56.92 332.66 7250.0 56.84 333.17 7300.0 56.23 334.91 7350.0 56.27 335.02 7400.0 56.28 335.06 7450.0 56.01 335.19 7500.0 56.00 335.30 7550.0 55.66 335.41 7600.0 55.49 335.53 7650.0 57.03 335.53 7700.0 57.17 335.69 7750.0 57.40 335.85 7800.0 57.18 335.97 TARN POOL, ALASKA DOGLEG VERTICAL SUBSEA VERTICAL SEVERITY DEPTH DEPTH SECTION deg./ feet feet feet 100 ft. 2.22 3409.7 3262.4 5078.3 2.84 3434.8 3287.5 5118.7 2.58 3460.1 3312.8 5158.5 1.61 3485.5 3338.2 5198.0 3.58 3511.2 3363.9 5237.0 1.37 3537.2 3389.9 5275.3 3.91 3563.4 3416.1 5313.1 .87 3590.2 3442.9 5350.2 .60 3617.0 3469.7 5387.3 .37 3643.8 3496.5 5424.4 1.50 3670.6 3523.3 .67 3697.6 3550.3 .55 3724.8 3577.5 .86 3752.1 3604.8 3.15 3779.7 3632.4 .20 3807.5 3660.2 .07 3835.2 3687.9 .57 3863.1 3715.8 .18 3891.0 3743.7 .71 3919.1 3771.8 5461.2 5497.8 5534.2 5570.4 5606.1 Page 6 CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 5641.4 5676.6 5711.7 5746.7 5781.6 .40 3947.4 3800.1 5816.4 3.09 3975.2 3827.9 5851.4 · 38 4002.3 3855.0 5886.7 .54 4029.4 3882.1 5922.0 .49 4056.4 3909.1 5957.3 5084.7 305.8 5125.8 305.9 5166.5 306.1 5206.9 306.2 5246.9 306.4 5286.4 306.6 5325.3 306.8 5363.8 307.0 5402.2 307.1 5440.7 307.3 5479.0 307.5 5517.2 307.7 5555.3 307.9 5593.2 308.1 5630.8 308.2 5667.9 308.4 5705.1 308.6 5742.3 308.8 5779.5 309.0 5816.6 309.2 5853.6 309.4 5890.9 309.5 5928.6 309.7 5966.5 309.9 6004.3 310.1 2972.0 N 4125.7 W 3006.8 N 4151.3 W 3042.2 N 4175.9 W 3078.1 N 4199.7 W 3114.4 N 4222.6 W 3151.0 N 4244.6 W 3188.0 N 4265.7 W 3225.0 N 4285.9 W 3262.1 N 4306.1 W 3299.3 N 4326.2 W 3336.5 N 3373.8 N 3411.1 N 3448.4 N 3485.9 N 3523.6 N 3561.3 N 3599.0 N 3636.6 N 3674.2 N 3711.7 N 3749.6 N 3787.8 N 3826.2 N 3864.6 N 4346.0 W 4365.4 W 4384.6 W 4403.7 W 4422.0 W 4439.6 W 4457.1 W('· 4474 . 6 W 4491 . 9 W 4509 . 2 W 4526 . 3 W 4543.5 W 4560.9 W 4578 . 1 W 4595 . 3 W A Gyro da t a D i r e c t i o na I Survey ARCO ALASKA INC. WELL: 2N-321A, 3.5" Location: DRILLSITE 2N, Job Number: AKl198GCE506 MEASURED I N C L AZIMUTH DEPTH feet deg. deg. 7850.0 57.28 336.02 7900.0 57.74 335.99 7950.0 57.83 335.84 8000.0 58.29 335.78 8050.0 58.67 335.87 8100.0 58.76 335.91 8150.0 58.99 335.97 8200.0 58.93 335.88 8250.0 59.60 335.92 8300.0 58.07 335.72 8350.0 57.54 335.49 8400.0 57.01 335.42 8450.0 56.68 335.37 8500.0 57.23 335.41 8550.0 57.68 335.32 8600.0 57.78 335.26 8650.0 58.60 335.31 8700.0 58.44 335.07 8750.0 58.41 334.80 8800.0 57.25 333.98 8850.0 56.69 333.23 8900.0 56.07 332.08 8950.0 54.66 331.97 9000.0 53.62 331.20 9050.0 52.72 330.66 TARN POOL, ALASKA DOGLEG VERTICAL SUBSEA VERTICAL SEVERITY DEPTH DEPTH SECTION deg./ feet feet feet 100 ft. .23 4083.4 3936.1 5992.5 .92 4110.3 3963.0 6027.8 .31 4136.9 3989.6 6063.3 .91 4163.4 4016.1 6098.9 .79 4189.5 4042.2 6134.7 .18 4215.5 4068.2 6170.5 .48 4241.4 4094.1 6206.4 .20 4267.1 4119.8 6242.3 1.33 4292.7 4145.4 6278.4 3.08 4318.6 4171.3 6314.3 1.13 4345.2 4197.9 6349.9 1.06 4372.2 4224.9 6385.3 .66 4399.6 4252.3 6420.6 1.09 4426.8 4279.5 6456,0 .92 4453.7 4306.4 6491.5 .22 4480.4 4333.1 6527.2 1.65 4506.8 4359.5 6563.1 .52 4532.9 4385.6 6599.2 .46 4559.1 4411.8 6635.3 2.69 4585.7 4438.4 6671.4 1.70 4612.9 4465.6 6707.4 2.28. 4640.6 4493.3 6743.5 2.82 4669.0 4521.7 6779.5 2.43 4698.3 4551.0 6815.0 1.99 4728.3 4581.0 6850.3 Page 7 CLOSURE DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 6042.1 310.2 6080.1 310.4 6118.4 310.6 6156.8 310.7 6195.4 310.9 6234.2 311.1 6273.0 311.2 6312.0 311.4 6351.1 311.6 6390.1 311.7 6428.9 311.9 6467.4 312.0 6505.9 312.2 6544.4 312.3 6583.2 312.5 6622.2 312.6 6661.4 312.7 6700.9 312.9 6740.4 313.0 6779.8 313.2 6819.1 313.3 6858.4 313.4 6897.4 313.5 6935.9 313.6 6974.1 313.7 3903.0 N 4612.4 W 3941.5 N 4629.6 W 3980.1 N 4646.8 W 4018.8 N 4664.2 W 4057.7 N 4681.7 W 4096.7 N 4699.1 W 4135.8 N 4716.6 W 4174.9 N 4734.0 W 4214.1 N 4751.6 W 4253.2 N 4769.1 W 4291.7 N 4786.6 W 4330.0 N 4804.1 W 4368.0 N 4821.5 W 4406.1 N 4839.0 W 4444.4~ N 4856.5 W 4482.8 N 4874.2 W 4521.4 N 4892.0 W i'" 4560.1 N 4909.9 W" 4598.7 N 4927.9 W 4636.9 N 4946.2 W 4674.4 N 4964.8 W 4711.4 N 4984.0 W 4747.8 N 5003.3 W 4783.4 N 5022.5 W 4818.4 N 5042.0 W A Gyro da t a D i r e c t i o na I Survey ARCO ALASKA INC. WELL: 2N-321A, 3.5" Location: DRILLSITE 2N, Job Number: AKl198GCE506 MEASURED DEPTH feet I N C L AZIMUTH deg. deg. 9100.0 51.51 330.85 9150.0 49.44 330.91 9175.0 47.21 330.81 Final Station Closure: TARN POOL, ALASKA Page DOGLEG VERTICAL SUBSEA VERTICAL CLOSURE SEVERITY DEPTH DEPTH SECTION DIST. AZIMUTH deg./ feet feet feet feet deg. 100 ft. 2.46 4759..0 4611.7 4.14 4790.8 4643.5 8.90 4807.4 4660.1 Distance: 7066.59 ft 6885.2 7011.9 313.8 6919.3 7048.7 313.9 6935.8 7066.6 313.9 Az: 313.93 deg. HORIZONTAL COORDINATES feet 4852.8 N 5061.3 W 4886.5 N 5080.0 W 4902.8 N 5089.1 W A Gyro da t a D i r e c t i o na i Survey for ARCO ALASKA INC. WELL: 2N-321A, 3.5" Location: DRILLSITE 2N, TARN POOL, ALASKA Job Number: AKl198GCE506SS Run Date: 7-Nov-98 14:38:25 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.250000 deg. N Sub-sea Correction from Vertical Reference: 147.3 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 302.890 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyro da t a D i r e c t i o n a i S u rvey ARCO ALASKA INC. WELL: 2N-321A, 3.5" Location: DRILLSITE 2N, TARN POOL, Job Number: AKl198GCES06SS ALASKA SUBSEA I N C L AZIMUTH DOGLEG DEPTH SEVERITY feet deg. deg. deg./ 100 ft. VERTICAL VERTICAL CLOSURE DEPTH SECTION DIST. AZIMUTH feet feet feet deg. -147.3 0.00 0.00 0.00 0.0 .99 317.87 .56 100.0 1.53 316.75 .54 200.0 3.54 313.71 2.01 300.0 7.09 311.81 3.54 0.0 147.3 247.3 347.3 447.3 400.0 10.54 311.89 3.40 500.0 13.21 315.26 2.83 600.0 15.74 318.86 2.54 700.0 17.82 318.58 1.84 800.0 21.67 318.71 4.29 547.3 647.3 747.3 847.3 947.3 900.0 27.98 319.11 5.93 1000.0 33.83 318.91 3.46 1100.0 39.64 316.92 3.69 1200.0 44.23 315.94 3.62 1300.0 55.10 316.13 7.26 1047.3 1147.3 1247.3 1347.3 1447.3 1400.0 64.47 311.72 7.13 1500.0 68.55 304.73 2.07 1600.0 68.18 301.73 .35 1700.0 69.27 301.22 1.78 1800.0 69.10 299.68 .57 1547.3 1647.3 1747.3 1847.3 1947.3 1900.0 69.38 300.02 .30 2000.0 69.48 299.07 2.99 2100.0 69.08 297.05 .41 2200.0 68.47 298.86 2.41 2300.0 66.42 304.81 1.35 2047.3 2147.3 2247.3 2347.3 2447.3 0.0 0.0 0.0 1.6 2.5 317.9 3.7 5.2 317.5 8.0 11.6 316.0 17.2 24.0 314.0 32.5 42.4 312.9 53.2 65.1 313.2 77.6 91.9 314.5 106.7 122.3 315.7 141.0 158.2 316.4 185.5 202.7 317.0 243.7 255.9 317.5 316.7 348.0 317.6 403.9 451.0 317.3 517.5 570.0 317.0 683.4 745.3 316.5 920.6 974.1 314.3 1167.8 1201.6 311.8 1426.1 1478.1 310.0 1683.3 1707.9 308.4 1946.5 1985.8 307.3 2220.7 2265.5 306.4 2478.6 2496.1 305.5 2741.2 2774.1 304.7 2974.2 3003.3 304.5 Page HORIZONTAL COORDINATES feet 0.0 N 0.0 E 1.2 N 1.1 W 2.8 N 2.6 W 5.9 N 5.8 W 12.1 N 12.7 W 22.5 N 24.2 W 37.0 N 39.4 W 55.6 N 56.5 W 78.3 N 76.4 W 105.1 N 100.0 W 139.9 N 130.4 W 185.7 N 170.1 W 241.8 N 220.8 W 306.5 N 282.8 W 390.3 N 363.8 W 510.4 N 483.8 W 655.9 N 672.2 W 787.2 N 881.7 W 923.7 N 1101.0 W 1051.2 N 1324.9 W 1182.2 N 1553.6 W 1319.5 N 1791.2 W 1439.0 N 2021.1 W 1560.9 N 2255.0 W 1684.6 N 2452.6 W A Gyro d a t a D i r e c t i ona i Survey ARCO ALASKA INC. WELL: 2N-321A, 3.5" Location: DRILLSITE 2N, TARN POOL, Job Number: AKl198GCE506SS ALASKA SUBSEA I N C L AZIMUTH DOGLEG VERTICAL VERTICAL CLOSURE DEPTH SEVERITY DEPTH SECTION DIST. AZIMUTH feet deg. deg. deg./ feet feet feet deg. 100 ft. 2400.0 67.11 305.51 1.49 2500.0 67.97 304.93 1.56 2600.0 69.28 304.29 1.60 2700.0 69.18 304.23 .53 2800.0 66.23 305.49 .72 2547.3 2647.3 2747.3 2847.3 2947.3 2900.0 66.79 306.05 2.24 3000.0 61.98 309.33 1.88 3100.0 60.22 314.19 2.78 3200.0 59.75 319.05 2.48 3300.0 59.56 325.25 2.71 3047.3 3147.3 3247.3 3347.3 3447.3 3400.0 58.44 330.04 2.35 3500.0 57.55 331.67 .52 3600.0 56.86 333.08 .80 3700.0 56.16 335.12 .29 3800.0 55.49 335.53 .40 3547.3 3647.3 3747.3 3847.3 3947.3 3900.0 57.25 335.93 .51 4000.0 58.01 335.82 .55 4100.0 58.98 335.95 .42 4200.0 57.50 335.48 1.12 4300.0 57.57 335.34 .96 4047.3 4147.3 4247.3 4347.3 4447.3 4400.0 58.43 334.92 .49 4500.0 55.74 332.05 2.41 4600.0 51.97 330.78 2.28 4660.1 47.21 330.81 8.90 4547.3 4647.3 4747.3 4807.4 Final Station Closure: Distance: 7066.59 ft 3203.9 3232.6 304.5 3440.3 3463.0 304.6 3692.0 3695.4 304.6 3961.9 3976.7 304.6 4190.8 4205.5 304.6 4424.0 4435.3 304.6 4629.4 4659.0 304.8 4808.7 4832.3 305.0 4975.7 5001.4 305.4 5138.3 5166.5 306.0 5289.9 5325.3 306.7 5429.2 5479.0 307.4 5564.0 5593.2 308.0 5691.8 5742.3 308.7 5816.3 5853.6 309.4 5945.5 6004.3 310.0 6077.3 6156.8 310.6 6214.7 6312.0 311.3 6352.6 6467.4 311.9 6483.0 6583.2 312.4 6619.0 6740.4 313.0 6752.0 6897.4 313.4 6871.9 7011.9 313.8 6935.8 7066.6 313.9 Az: 313.93 deg. Page HORIZONTAL COORDINATES feet 1817.3 N 2640.2 W 1954.3 N 2833.2 W 2096.8 N 3040.7 W 2248.3 N 3264.2 W 2380.9 N 3451.1 W 2516.0 N 3641.4 W 2643.2 N 3803.8 W 2763.2 N 3939.7 W 2888.1 N 4057.8 W 3024.3 N 4163.4 W 3165.3 N 4252.7 W 3304.2 N 4328.8 W 3441.8 N 4400.3 W 3577.6 N 4464.7 W 3711.6 N 4526.3 W 3851.7 N 4589.5 W 3995.3 N 4653.6 W 4144.8 N 4720.6 W 4294.7 N 4788.0 W 4435.3 N 4852.3 W 4581.4 N 4919.8 W 4720.0 N 4988.5 W 4839.7 N 5053.9 W 4902.8 N 5089.1 W 4. QUALITY CONTROL QUALITY CONTROL REPORT JOB NUMBER: AK1198GCE506 TOOL NUMBER: 761 MAXIMUM GYRO TEMPERATURE: 74.40 C MAXIMUM AMBIENT TEMPERATURE: 48.6 C MAXIMUM INCLINATION: 70.87 AVERAGE AZIMUTH: 313.93 WIRELINE REZERO VALUE: O! REZERO ERROR / K: N/A CALIBRATION USED FOR FIELD SURVEY: 2714 CALIBRATION USED FOR FINAL SURVEY: 2765 PRE JOB MASS BALANCE OFFSET CHECK: POST JOB MASS BALANCE OFFSET CHECK~: USED O.O/N/A CONTINUOUS -.75 -1.28 CONDITION OF SHOCK WATCHES UPON ARRIVAL AT RIG: UPON COMPLETION OF SURVEY: UPON RETURN TO ATLAS: OK OK OK BOTTOM LINE COMPARISIONS M.D. INC AZIMUTH TVD NORTHING EASTING MWD FINAL SURVEY 9142 49.39 333.11 4789.0 4901.0 5067.0 9150 49.44 330.91 4790.8 4886.5 5080.0 FUNCTION TEST JOB NUMBER: AK1198GCE506 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ft 1 2 3 4 5 700 14.36 14.36 14.36 14.36 14.36 AZIMUTH M.D. ft 1 2 3 4 5 700 318.49 318.35 318.56 318.36 318.39 5. EQUIPMENT AND CHRONOLOGICAL REPORT EQUIPMENT REPORT JOB NUMBER: AK1198GCE506 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 761 GYRO SECTION DATA SECTION POWER SECTION COMPUTER A0149 POWER SUPPLY C0111 PRINTER C0083 INTERFACE A0433 A0085 A0079 A0143 BACKUP TOOL No. 789 GYRO SECTION DATA SECTION POWER SECTION COMPUTER A0057 POWER SUPPLY C0089 PRINTER C0086 INTERFACE A0467 A0107 A0029 A0055 WIRELINE COMPANY: SCHLUMBERGER CABLE SIZE: 7/32" RUNNING GEAR 2.25" HOUSING w/ ECCENTRIC BAR TOTAL LENGTH OF TOOL: 26' MAXIMUM O.D.: 2.25" INCHES TOTAL WEIGHT OF TOOL: 210 POUNDS CHRONOLOGICAL REPORT JOB NUMBER: AK1198GCE506 FRIDAY, 11/06/98 12:00 CHECK TOOLS, STANDBY SATURDAY, 1 05:00 07:00 09:00 09:30 13:30 14:45 15:15 16:00 1/07/98 TO LOCATION MU TOOL RU SCHLUMBERGER, WARM UP TOOL PICK UP GYRO RIH SURVEY IN TO 9175' SURVEY OUT LD TOOL. RUN GYRO ON 2N-325 SUNDAY, 11/08/98 22:00 PROCESS SURVEY Re: Tam ,PA InJection Subject: Re: Tarn RA Injection Date: Wed, 05 Apr 2000 15:11:01 -0800 From: Blair Wondzell <blair wondzell~admin.state.ak.us> Organization: State of Alaska, Dept of Admin, Oil & Gas To: Lamont C Frazer <LFRAZER~mail.aai.arco.com> Lamont, Thanks for the data. As we discussed, I think this request should be by a 10-403. Contingent on your furnishing a 403 to this office by Monday, April 10, I am giving you verbal approval so that the work can start this weekend. Blair Wondzell, 4/5/00. Lamont C Frazer wrote: > Blair, > As per our phone discussion on 4/4/00, we are seeking AOGCC approval to inject > RA material in the outer annulus of Tarn injectors 2N-325 and 2N-321A as part of > an ongoing program to diagnose how injection fluids are being transported to > producer 2N-345. For your convenience, the original e-mail message on this > subject and a brief update of recent data collection activities are provided > below. > Data Collection Update > Gas tracers indicate that a small fraction of MI injection from wells 2N-325, > 2N-331 and 2N-321A is transported to 2N-345 within a few days. The logging > program outlined below has not provided any indication of out of zone injection, > with one exception--the CNL run in injector 2N-321A indicated that the Iceberg > interval in the near-wellbore region of this injector has increased its gas~Mi > saturation since the well was drilled. At this point in time, it remains > unclear as to how injection fluids are being transported to 2N-345. > Schematics of injectors 2N-321A & 2N-325 and fracture stimulated producer 2N-345 > are also shown below. Logs suggest good cement bonding up to the crossover in > 2N-325. (Cement bonding above the crossover is unknown.) Logs suggest that > 2N-321A and 2N-345 both have some degradation in cement bonding prior to > reaching their crossovers. > Producer Logging * Production - DEFT (2N-345) - ~ater Flow Log (2N-345) * Behind Pipe Flow Evaluation - CNL (£N-345) - Noise (2N-345) > - Cement Evaluation Log (2N-345) > Injector Logging > * Nater Injection > - Spinners (2N-307, 2N-321A, 2N-325, 2N-331 & 2N-343) > - Temperature (2N-321A, 2N-325 & 2N-343) > - Borax PNL (2N-3£5 & 2N-343) > - Near-Wellbore Iodine 131 RA Tracer (2N-321A, 2N-325 & 2N-343) > * Gas Injection > -Spinners (2N-307, 2N-321A, 2N-325, 2N-331 & 2N-343) > - CNL (2N-321A, 2N-325 & 2N-331) > (Embedded image moved to Eile: pic17230.pcx) 1 of 3 4/5/00 3:11 PM Re: Tam ~P~ InJection Proposal The RA injection proposal is two-fold. First, we plan to inject RA material (i.e., Iodine 131, which has a half-life of 8.5 days) down the surface casing by production casing annulus of injectors 2N-321A and 2N-325. The purpose of this is to identify the "weak zone" that breaks down during annular pump-ins. (This will be the zone that cuttings are injected into during annular disposal operations.) This information will be used to help formulate drilling plans of future wells. We know that this "weak zone" is not transporting injected fluids to 2N-345. We can pump diesel into the "weak zone" at pressures that range between 700 psi and 1200 psi. After completing pumping operations, the outer annulus pressures bleed down. If the "weak zone" were transporting injection fluids, it would be at an elevated pressure (-3000 psi). This elevated pressure is not consistent with the relatively low pressure outer annulus pump-ins and subsequent pressure bleed-offs. Second, we plan to inject solid RA tagged particles (i.e., Antimony and Scandium, which have half-lives in the 60 - 80 days range) into the outer annulus and then let gravity allow these particles to settle. The purpose of this is to identify the deepest point that is in hydraulic communication with the outer annulus. This information will also be used to help formulate drilling plans of future wells. If you have any questions, or would like additional information on this subject, please contact either myself (263-4530) or Ryan Stramp (265-6806). We ~ould welcome an opportunity to meet with you to discuss the matter in more detail. Sincerely, Lamont Frazer AAI Tarn Reservoir Engineer Forwarded by Lamont C Frazer/AAI/ARCO on 04/05/2000 09:08 Lamont C Frazer 01/11/2000 04:14 PM To: Blair ~ondzellOadmin.state.ak.us -- cc: Ryan L Stramp/A_AI/ARCOOARCO Subject: Tarn Injection Blair, As per our phone discussion on 1/10/00, this e-mail message provides a brief description outlining events relating to the production of injected fluids in Tarn producer 2N-345. The reason for alerting the AOGCC to this situation is that it > ?s possible that out of zone injection may be involved in the transport > of injected fluids to 2N-345. > Background > AAI initiated Tarn MI injection during late ?98. A water injection test was > conducted during the summer of ?99. At the time of the test, no Tarn producer > had experienced MI breakthrough. After approximately three weeks of water > injection, water production was observed in 2N-345. Water tracers suggested > that 2N-321A, and possibly 2N-325, were communicating with producer 2N-345. > (See net pay map below for well locations.) Given that (1) no previous Mi > breakthrough had been detected, (2) the quick water breakthrough time, and (3) > the location of injector 2N-321A relative to producer 2N-345, communication > through the reservoir was difficult to explain. One possibility was that the 2 of 3 4/5/00 3:12 PM Re: Tarn ~ Injection > transport path of injected fluids to 2N-345 involved channeling up the outside > 2N-321A?s casing, through a shallow zone (where 2N-321A and 2N-325 wellbores are > closer together), and down the outside of 2N-345?s casing to its open > perforations. A variety of injection logs and production logs were subsequently > run; however, they all failed to detect channeling. Furthermore, there were no > elevated pressures in the annuli of any Tarn wells indicating communication with > injected fluids. > After completing the water injection test, MI injection at Tarn was resumed. > Well tests on 2N-345 were closely monitored for any sign of MI breakthrough. MI > breakthrough in 2N-345 has recently been confirmed. > Ongoing Diagnosis > A comprehensive plan has been developed to help understand the transport path of > injected fluids to 2N-345. Ongoing activities include (1) additional logging, > (2) use of gas tracers and (3) attempting to inject into the outer annuli of > Tarn wells to determine whether they remain open to shallow horizons. > If you have any questions, or would like additional information on this subject, > please contact either myself (263-4530) or Ryan Stramp (265-6806). We would > welcome an opportunity to meet with you to discuss the matter in more detail. > Sincerely, > Lamont Frazer > AAI Tarn Reservoir Engineer > (Embedded image moved to file: picOO589.pc×) > Name: pic17230.pcx > pic17230.pcx Type: PCX Image Document ( app l i ca t i on/x - un kn own - con ten t - type -PCXIma ge. Do cumen t) > Encoding: base64 > Name: picOO589.pcx > picOO589.pcx Type: PCX Image Document ( app l i ca t i on /x -unknown -con ten t - type-PCXIma ge . Documen t) > Encoding: base64 3 of 3 4/5/00 3:12 PM 2N~32~A 2N-325 2N-345 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon m Alter casing m Change approved program __ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 61' FNL, 763' FEL, Sec. 3, T9N, R7E, UM At top of productive interval 128' FNL, 713' FEL, Sec. 33, T10N, R7E, UM At effective depth Suspend_ At total depth 134' FSL, 842' FEL, Sec.28, T10N, RTE, UM 12. Present well condition summary Total Depth: measured (approx) true vertical Repair well_ Plugging__ Pull tubing __ 5. Type of Well: Development Exploratory ~ Stratigraphic ~ Service Operation Shutdown _ Re-enter suspended well _ Time extension_ Stimulate_ Variance_ Perforate_ Other X Annular Iniection 6. Datum elevation (DF or KB) 28' RKB feet 7. Unit or Property name Kuparuk River Field/Tarn Oil Pool 8. Well number 2N-321A 9. Permit number 98-173 10. APl number 50-103-20267-01 11. Field/Pool Kuparuk River Field/Tarn Oil Pool 11,526' feet Plugs (measured) 5241' feet Effective depth: measured (approx) true vertical 9904' feet Junk (measured) 4478' feet None Casing Length Size Structural Conductor 90' 16" Surface 3833' 7.625" Intermediate Production 9282' Liner 691' 5.5"x 3.5" Cemented 10 CY High Early 110 sx AS111/254 Cl G 238 Class G/60 AS I 220 sx Class G Measured depth True vertical depth 118' 118' 3861' 2295' 9310' 4259' 1OOO1' 4516' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) 3.5", 9.3#, L-80 @ 9324' Packers and SSSV (type and measured depth) Baker CSR @ 9310' 13. Attachments Description summary of proposal __ Detailed operation program __ Contact Paul Mazzolini at 265-4603 with any questions. LOT test, surface cement details and casing detail sheets 14. Estimated date for commencing operation 15. Status of well classification as: · September 1998 Oil. X Gas__ 16. If proposal was verbally approved Name of approver Date approved Service __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'~_~ ~Y'/~~:'.__., Title Tarn Drilling Team Leader Date ~ ~ FOR COMMISSION USE ONLY BOP sketch __ X Suspended__ Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test Location clearance Mechanical Integrity Test_ Subsequent-form require 10- ~ .:~9ned By Approved by the order of the Commission Form 10-403 Rev 06/15/88 ~aViO W. Juii~lsto~ Commissioner IApproval No ..... Date S/~ %'~,_ / SUBMIT I~ TRI~LIC'ATb ARCO Alaska, Inc. Cementing Details Well Name: 2N 321 Report Date: 08/21~ Report Number. 8 Rig Name: DOYON 141 AFC No.: AK9477 Field: Tarn Casing Size Hole Diameter. Angle ~ru KRU: I Shoe Depth: LC Depth: % washout: 7-518 9-7/8 nlaI 3861 3737 Centralizers State type used, intervals covered and spacing Comments: 42 Gemeco Bow Spring centTalizers, placement on casing detail. Mud Weigl'rl: PV(prior cond): PV(alter cond): I YP(pdor cond): YP(after con(I): Comments: 10.2 28 28I 21 15 Gels before: Gels after:. Total Volume Circulated: 5117 3/4 780 bbls Wash 0 Type: Volume: Weight: Comments: Spacer 0 Type: Volume: Weight: Comments: ARCO 30 bbls 130 bbls 10.5 110.5 1st stage/2nd stage ' Lead Cement 0 Type: I Mix wtr temp: No. of Sacks: I Weight: Yield: Comments: AS III LWI 70 1101254I 10.5 4.42 I st stage/2nd stage Additives: standard blend Tail Cement 0 Type: I M~(wtrtemp: I No. ofSacks: I Welgh~: I Yield: Comments: G 70 - 238 160 15.81 ¶ 5.7 1.1 710.93 1st stage/2nd stage Additives: 2nd stage tail, ar'dc set 1. , Displacement 0 Rate(before tail at shoe): Rats(tail around shoe): Str. Wt_ Up: Comments: 8 bpm 16 bpm 8 bpm 14 bpm 1st stage I ?.rid stage Reciprocation length: Reciprocation speed: Str. Wt_ Down: 20 15fpm Theoretical Displacement: Actual Displacemen'c Str. Wt_ in mud: 171.51 68.6 172.21 67.5 , Calculated top of cement' CP: Bumped plug: Floats held: Surface thru stage collar ~ 1495'. Date:8/8/98 yes yes 'Rme:0233 hrs Remarks:l st stage: Staged pumps up to 8 bpm and cond mud, pumped 5 bbls water, 30 bbls of spacer, 86.5 bbls of lead and 49.5 bbls of tail meat. Displaced with 25 bbls of wash up water, 78 bbls of mud, 28 bbls of spacer and 41.2 bbls of mud. Opened stage tool with 2660 psi, had full returns while circulating and cementing. 2nd stage: conditioned mud at 8 bpm, pumped 5 bbls of water, 30 bbls of spacer, 200 blls of lead and 10 bbls tail cement. Displaced 25 bbls of wash up water and 42.5 of mud. Had 80 bbls of 10.5 ppg cement returns at surface, full returns throughout. Cement Company:. Rig Contractor;. Approved By:. DS ' DOYON D.BURLEY Casing Detail 7.$/8" Surface Casing WELL: TARN 2N-321 ARCO Alaska, Inc. DATE: 8/16/98 Subsidiary of Atlantic Richfield Company 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS Doyon 141 RT to LR= 29.10 29.10 7 5/8" Landing Joint 34' OA. 29.10 FMC GEN V- Prudhoe 7 5/8" Csg Hgr 2.39 29.10 58-91 7 5/8", 29.7#, L-80 BTC-MOD 1424.39 31.49 Jt #57 7 5/8", 29.7#, L-80 BTC-MOD (Thread Locked Collar) 39.39 1455.88 Gemeco 7 5/8" Stage Collar (BAKE, RLOK) 2.78 1495.27 Jt. #56 7 5/8", 29.7#, L-80 BTC-MOD 0-hread Locked Colla,r~) 42.43 1498.05 its. 3-55 7 5/8",29.7#, L-80 BTC-MOD (shutoff baffle on top of jt #3, BAKERLOI 2234.86 1540.48 Gemeco Float Collar 1.33 3775.34 jts 1-2 7 5/8", 29.7#, L-80 BTC-MOD 82.86 3776.67 Gemeco Float Shoe 1.50 3859.53 3861.03 Insert baffle (~ 3737.06 42 Gemeco Bow Spring CENTRALIZERS Run centralizers in center of Jts. 1, 2, over stop collars every collar thru Jt. # 15=every 3rd collar to surface. 1 above & 1 below stage collar. Remarks: String Weights with Blocks: 100K~ Up,651~ Dn,121~ Blocks. Ran 91 joints of casing. Ddfted casing with 6.750 plastic rabbit. Used Arctic Grade APl Modified No Lead thread compound on all connections. Casing is non-coated. Doyon 141 Drilling Supervisor: M. C. HElM CASING TEST and LEAK OFF TEST Well Name: 2N-321 Supervisor: D.P. BURLEY Date: 8122198 Casing Size and Description: Casing Setting Depth: 7 5/8", 29.7 ppf, L-80, BTC 3861 TMD 2,295' TVD Mud Weight: 9.2 pptil Hole Depth: 4,371' TVD EMW = Leak-off Press. + MW 0.052 x TVD 640 psi + 9.2 ppg EMW LOT = (0.052 x 4,371') = 12.0 ppg Fluid Pumped = 5.5 bbl Pump output = 0.1000 bps lied back 1.5 bbls after test. ~JTIME LINE 2,300 psi ...................... J 'ONE MINUTE ..... I Fi Iq' ~ ~ FrT~ n nq ~ 1 -~ i ~qq 1 i i fl a I I I J ~ ~ I ~ I I T~ I Il ~'~ "". R-rT'Tmq-T"~TT'~'iT'ITi'TMTIT[~'3, ~, J, I, ~. ITE~, i. J, J, l, i, J, J, ~, J, J, J. I, J. J, J. ~, l'i'l "'I-FI ~';o:"4;H t tt~f Ii ~ ~ ~r~~~Z2i:i'r~'~'~'~'~'~'~'~'~'~'~'~'~'~'~'~'~'~'~'~'~'~'~ ~ n ~'ooo :~l F'TI'T1-FI'T[T~-TII i - - I i I I I I I I I i i I I I I I I I I'T I I I I .'___r. Fr'T'] ¥1q-l'-I I I I I1~ I I ill I I I I I I ltl I I I I I I I Iq l ITl I ~ I I I I I I I ~ I I I (soo-,~ M~E~ I I I I I II I ~/ I IIIIJ 1~////I , / / I /1 II// I II I II I I I I ~'~oo2,~ l-F~q~-~l"-fl-T] I-1 I i 1T-i I I [ II ] I Il flI I"TT1-TFnTFI-TTT-I~q I I I Il 7uu psi .................................... ~.-- L 400 p~ ~. L...~.~ ~ ~ ~ ~ ;~';.~;~:'-~'--'' ' ' -'--.' '--'-' '-' ....... · nn.,, ~ ~~ [~T~ F~ ~ FC~ ~] I ~TT~ ~ ~ I'i~',~''~:¥,,','~,>:~,4 [ [~q CFI ]~ I Il ~ I I ,~,, ~-~"'~T'F~-[T]TI-TfT~-%I 'i'll I~ II !~]!~ FT I I ]E Il II II II ~[t~l ~1 "~i, Ft-lq-TT-FI~FT]TTTTTTFI I ~ II ~ I'1 1"i"-~ ~ ~ I"1 I ~ I I I-I I I I! !'/ I~ I I ~ t kkkkkkkk kkk~ kkkkkkkkkkkk~kkkkkkk~kk~k~kk ~kkk~kkkkst~st STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE I' ................... [ .... ..o..s.!.k..s. ........... .o.~.s.! ...... ! 2 stks 90 ~sl ................... ~ .... I~l~i[~' .... ] .... ~1~ ~[ .... ................... t .... -~"~i~- .... 1 .... ~'~'ii~[ .... ................... ! .... '~"~iiiii .... i .... ii'iiiiF'! ................... i .... i~'iiiiii""! .... iif~'~'n"iii'"i ...............................................! 12 ~tk~ 1 440 ~S~ ................... I .... i'i'iiii('i""l .... ................... I .... ii'iiii'i'"'! .... iif~1'~l"'i, ................... ~ .... ~'~'~i~'~'--I .... ~¥~'~['--~, ................... t-'"i~'iiii,'i""l .... ................... ?"-ii'iiiiii"--! .... iiay~.iir"! ................... i .... ii'iii'&""! .... ii~'~'~.~i"'] ................... ,,' .... ~'~'~iii~--"~ .... :::::::::::::::::::::::::::::::::::::::::::::::::::::: 30 stks 600 ~.sl i ................... f .... ~'~'iiik'~' ........ ~i~'~'ii~['"! ................... ['"'i~'~iiiii' ........ iii~i'~.~.i'"~ :::::::::::::::::::::::::::::::::: ::::~:~[:::] 550 ~sl I ................... :___.~.o..:.L~.:.... ::::~.~:o..:~.E::l ....................... . .S.S...s.t..k..s.... SHUT IN TIME! 'SHOT IN PRESSURE 00min ] 540osi .... .................. .... '~."d%Tr~ .................... ! .... ~t'~'~r" ~ .... '&'d%ih- .................... l .... .... '~:U%% .... l ................. 1 .... ~a'a-p"~r'-I ,-----------.-----15 0 mln ;""-'""-'-'"1l ...... 350'"'"Ds[ ...... 1, .... ................ i .... ................... , .... ..... ; .......... 4 .................. ~, .... '-"-'-"J'":"'! 8 0 min ' . 3411 Dsm , .... '~'.~'~- .................... 1 .... ~'~'~["'1 "'To~'~"~ ..... , :::E::~.~:~_:~[:::] CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE [ ........................ ~.s..~.s. .......... .o..p.?L ..... I 2 stks ..... .8. p..l~.S. I ..... ! ::::::::::::::::::::::::::::::::::::: 1~o ~m [ ........................ p...s.t~ ..... :::::~..~::K~J::::I i 8 stks 570 [si .................. ! .... T~"iTi~' ....... -~-~-:~:~j .... ! f .................. i .... ;l'i-'~i'li~' ....... 'ti~iil':~:~i .... ! l ....... ~ .......... I .... Ta'*a:~'---i--¥,-o'~ii ~-a---! :::::::::::::::::::::::::::::::::::::::::::::::::::::: ~ ....................... .t .~.~.~.~. ...... !:.:].o..o..P.7!.. t ...................... ~.o.~.t~.~. ....... 1,..4.o..o..R7!.. I 22 stks ....1.;.~.O..O..p.?..I... r ....................... ~f'~i'li~' .... ...1,..~.s..°..R.s!.. ! ....................... i~l"~iii .... 1,830 Esi r ....................... ~"~i'~' ....... ~;~'~'i~a'"l SHUT IN TIME' SHUT IN PRESSURE 0,0 rain ' * l 2,010nsi , t' ................. ~.o m~. r-£~'~.~"l '""~:O%rrT .... 3.0 rain .............. T":'I'~§'~ ' ~&'l" 'i ..... ~"'d"~i'r~' ................... T":f;§'~ii'ii~i'"! .... --;,~,'-"",': ............ ..',.'~'.',,,",,- - '1' ........... L ...... I .... 5,0 mln .._.L...1.,_.9.8.~.p...sJ...I 6.0 min i 1,980 Esl ..... Y.~-r~ i"r~' .................... T"T;~'~'~):" ..... ~:'8%%' .................. ~"¥;~'~-~a--- ::::~:.~' m.:::i~::::~ ::::::::::::::::::::::::::::: 10.0 min , ! 1,960 Esi .... f~;d'~Tr;"': · 1- ........... f,, ...... '"~:d'~T~"' :1,95o psi : '"~)."b"~T~ .................... ~': .............. 1,940 pSI I"'"I '"§~;d';~'r~ ................ T"¥,'f~;iirii~T"! NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: 2N-321 Supervisor: D.P.BURLEY Date: 8119198 Casing Size and Description: Casing Setting Depth: Mud Weight: Hole Depth: LOT = 9.1 ppg 2,309' TVD 830 psi (0.052 x 2,309') Fluid Pumped = 1.1 bbl 7 5/8", 29.7 ppf, L-80, BTC 3861 TMD 2,295' TVD EMW = Leak-off Press. + MW 0,052 x TVD + 9.1 ppg EMW = 16.0 ppg Pump output = 0.1000 bps TiME LINE 2,3oo psi.......................................... - ~ ONE MINUTE 2,200 psi............................... : 1,800 psi...................................... ~ ................................ 1,700 psi ~ [ 1,600 psi 1,500 psi ................................~ .........- U.I 1,400 psi ........................ ~ ................................ , ~.~ 1,300 psi ................................. 1,200 psi r .... ~ ~ uoo,,~ .Ti_- ........ ~'..................................... _ IZ t,ooo psi ....... ~ r .............................~- LEAK-OFF TEST ~- 9oo psi ~' .... J. CASING TEST 8oo ,,~ r'"' ~ _ ~-"-"'~. .... , ....... _- ~_ ~ ........... ~-. LOT SHUT IN TIME IF' "~':~; .......... I:"~.',~,, . ..... .~ CASING TEST SHUT IN TIME 700 psi §OOp$1.--r---- I~"-- = 4- TIME LINE 5oo psi -~.................................... ~oo p$1 ....... ~ p ................................. 2oo,,i-. :~ ¥ ................................. ~ .............. ~oo,,,~ "r ........................ :'""i ........................................... ! ..... {':': :: .......... : ..... _-Z ..... '-': 0 psi 0 2 4 e 8 10 12 14 16 1~ 20 22 24. 26 28 30 32 34 36 38 40 42 44 46 48 50 52 54 56 58 §0 62 64 os §8 70 72 74 7§ ?$ 80 82 84 86 stk stk st~ s~k s~ s~ s[k stk sl~ s['k stk 91k slk slk s~k stk st~ s~k stk st~ sl~ 6~ 6~ s~k sb~ stk st~ Ck stk st~ $~ slk stk s~k s~k Btk stk stk stk stl< stk stk stt< stk STROKES , LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE r .................. i .... T'a[~' .... i ..... ;~'¢¢;i .... ! r .................. r .... -~-~i[~- .... i ..... ~-~-~i .... 'i I- .................. ~ ..... -----= ....... i, ..... ="'- ..... r .... L .................. : .... .'~...s..~.K..S. .... : ..... .~.?.~.s.L .... j i 4 stks 100 p. sl ................... r .... 'a'~i[~' .... '] .... ................... t .... '~"a[~' .... ! .... ~',~'~-~;i-'-i ................... f .................. t .......... ~ ....... I 7 stks : 360 psi ........................~ '~-~;ii~_~' .... i .... i~¥~-~a"' ] ................... I .... i'~';ii~'~""l .... ~J'O'~.~i'"! ................... ! .... ¥~'~i~'~'"'i .... ~'~'~a"'l :::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::::::::::::::::::::::: :::::::::::::::::::::::::::::::::::::: SHUT IN TIME,[ SHUT IN PRESSURE .... .... ............. ~.u mLn' : , y. : "--2'.b-~ih-"'[ ............... ] .... ~'~'~i"' i ""'~:5-~;,;.; .... [ ............... i .... ~'~'~['"~ :"'~:~'~'":t ' ""'8'.6'~i~ / ' I 760psi ! 7.0min [ i 7SOp. si ""'§:§%i;; .... ~ ................ / .... f~t'~'~.~[ .... j'"~."o-m% .... : ................ ! .... ¥~'o'~i .... "To':~i~*'"[ ............. ! .... f;~'~' CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ...................................... ~ .................. ......................... .O...s.~.k..s. .... ! ..... .o..p..s!. ..... 2 stks ! 80 ~si 1 .................................... ! 6stks +: .......... 390~si . 8stks i 570~si ................... ~ .... Y~"a'~'-'T'"~'~"~'a .... ................... I .... Y~"a'~""t""~";,'~i .... ................... ~ .... ................... ; .... .................. ~, .... .1 22stks i 1,$00Esl .................. , .... ~..~i-[~---i--y;~.~.Ea---j .................. ! .... ~iF~i-~----i--[6iii.[~i--., ::::::::::::::::::::::::::::::::::::::::::::::::::::::::: , ~SHUT IN TIMEi SHUT IN PRESSURE .... 676'~B .... T r'"~. 6Td'~i'"i ""~'~"~'~"" ' "~*~'~ --I 1.0 min t '~'~ ..... ~ZO-rrn% .... '~' l "T;§'§ii'~i'"' ..... ~Ta"r~r~'"" ................ 4,0 min .[. 1,980 Esi .... '~'.6%% .... ', .............. :"Y;§'~ir[a"' '.::::EC~r_C::' ............... !::):;.~:~EE..~:(::' 7.0min , i 1,970psl 8.0 rain ,"" ':1'~§~ '~"i'" 10.0 min j 1,960 [si '~-~;~Fr;' : "'T"~';§'~i~'~E" ----;~,'; ....... 4 ............. + ................. ....2.9,.o...m.j.n.... ~. ............... i..!,..~.s..o._R.sL. ..2..%o_mj?_, .............. !..!,..~.o..mL. 30.Omin ! 1,940psi NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION August 26, 1998 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Paul Mazzolini Tam Drilling Team Leader ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 2N-32 lA ARCO Alaska, Inc. Permit No. 98-173 Sur. Loc. 60'FNL, 763'FEL, Sec. 3, T9N, R7E, UM Btmnhole Loc. 134'FSL, 842'FEL, Sec. 28, T10N, R7E, UM Dear Mr. Mazzolini: 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. Annular disposal of drilling waste will not be approved until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling wastes will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission on Form 10-403 prior to the start of disposal operations. 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. David W. Joh~ Chairman ~ BY ORDER OF THE COMMISSION dlffEnclosures cc: Department of Fish & Game, Itabitat Section ,~xqo encl. Department of Enviromnental Conservation w/o encl. STATE OF ALASKA ALASI<,~-~'OIL AND GAS CONSERVATION COMMIS~'iON PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Ddll X Reddll / lb Type of Well Exploratory E StratigraphicTest F~ Development Oil X Re-Entry F Deepen [~[ Service E Development Gas E~ Single Zone X Multiple Zone E~ 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 28', Pad 121' feet Kuparuk River Field 3. Address 6. Property Designation Tarn Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 380054, ALK 4602 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 60' FNL, 763' FEL, Sec. 3, T9N, R7E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 128' FNL, 713' FEL, Sec. 33, T10N, R7E, UM 2N-321A #U-630610 At total depth 9. Approximate spud date Amount 134' FSL, 842' FEL, Sec. 28, T10N, R7E, UM 8/25/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2N-323 10055' MD 128' @ Target feet 30' @ 0' feet 2560 5440' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 68.8° Maximum surface 1357 psig At total depth (TVD) 2300 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 90' 28' 28' 118' 118' _+200 CF 9.875" 7.625" 29.7# L-80 BTC MOB 3851' 28' 28' 3879' 2300' 1.110 Sx Arcticset III L & 240 Sx Class G 2. 260 sx ASIIIL & 60 sx ASI 6.75" 5.5" 15.5# L-80 LTC-M 9293' 28' 28' 9321' 4922' 230 sx Class G 6.75" 3.5" 9.3# L-80 8rd EUE 734' 9321' 4922' 10055' 5440' (included above) 19. To be completed for Reddll, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing ConductorStructural Length Size Ce~en~,dc. ., ~i'" IV E D Measured depth True Vertical depth Surface Intermediate ~irn°edruotiOn AUGORIGINAL Perforation depth: measured true vertical Alaska 0, & was fJa,s. C0mmiSS]! . Anchorage 20. Attachments Filing fee X Property plat r~ BoP Sketch X DiverterSketch X Drilling program X Drilling fluid program X Timevs depth plot C~ Refraction analysis F. Seabed report ~ 20AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~'~¢,~,,,t,~,,~ , Title Tarn Drilling Team Leader Date ~//'~"~/~f~ ' 0 ~ Commission Use Only I~ermit Number I APl number I Approval date ~_~] / ISee c°ver letter f°r ~?,-~///,~',.~ 50- /~ ~ '- .~ ~' ~ ~ ~'"' ~ / 2(,¢ ~;~ ot.~thher requirements Co~ditions of approval Samples required ~., Yes ~'. No MudlDg requ.red E~ Yes~.~! No Hydrogen sulfidemeasures F~ Yes J~' No Directional surveyrequired .,~ Yes F~ No Required working pressure for MOPE 2M r~ aM E 5M ~ 10M E 15M Other: David0riginaIw. Signed By Johnston by order of Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 t mit in triplicate ARCO Alaska, Inc. DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU 2N 321 A Drillinq Fluid Properties: Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to surface casin~l point 9.0-10.2 ppg 15-35 25-50 70-120' 10-25 15-40 5-7 9.5-10 _+10% Drill out to TD 8.5 - 10.0 ppg 12-24 15-30 45-60 2-6 4-8 4-6 through Tarn 9.0-10 <11% Drillinq Fluid System' Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Degasser Pit 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 surface casing leak-off of 13.5 ppg ErvlW (0.70 psi/fi) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 1,660 psi. Therefore ARCO will test the BOP equipment to 3,500 psi after setting surface casing. MASP = (2,300 ft)(0.70 - 0.11) = 1,357 psi Based on offset well data, reservoir pressures in the Tarn sands in the vicinity of 2N pad are expected to be -2,350 psi (0.50 psi/fi). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.5 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 5,100'. Well Proximity Risks: ARCO Alaska, Inc. The nearest well to 2N-321 A is 2N-323. The wells are 628' from each other at a depth of 5500'. Drillinc~ Area Risks: The primary risk in the 2N 321 A drilling area is shallow gas below the permafrost. Therefore the surface hole will need to be drilled with weighted mud (9.8 - 10.2 ppg) to avoid underbalancing the hole. Another observed problem in the area is lost circulation] at around 3,300' TVD and in the Tarn formation. Analysis of pressure data from offset wells shows that a mud weight of 9.6-10.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement the well. The 9-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 // ppg upon drilling out of the casing. Annular Pumpin_cl 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 iniected 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 321 A 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. We request that 2N 321 A be permitted 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 ARCO Alaska, Inc. 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 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 Type 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 51/2" 15.5 L-80 3 LTC-Mod 4,990 psi 4,242 psi 7,000 psi 5,950 psi 3Y2" 9.3 L-80 2 8rd EUE Mod 10,530 psi8,951 psi 10,160 psi8,636 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). ARCO Alaska, Inc. DOYON 141 13-5/8" 5,000 PSI BOP COMPONENTS 3" 5,000 psi WP OCT MANUAL GATE V KILL LINE / 3" 5,000 psi WP Shaffer GATE VALVE w/hydraulic actuator / J / DSA 13-5/8" 5,000 psi WP x 11" 3,000 psi WP \ 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 13-5/8" 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 ~!_iC~~T~~raulic actuat°r I-~..~ 3" 5,000 psi WP OCT 13-5/8" 5,000 psi WP DRILLING SPOOL '~~ w/two 3" 5M psi WP outlets SINGLE 13-5/8" 5,000 psi WP, HYDRIL MPL BOP w/pipe rams ARCO Alaska, In . ............ Sfructure : Tarn Drill Site 2N Well : 321 lField : Torn Development Field Location : North Slope, sko Creo[ed by jones Dote plotted : 24-Aug-98 Plot Reference is 521A Version ~1. Coordinates are in feet reference slot jl521. J True Vertical Depths ~ RKB (Ooyon 141). i~'~ I WELL PROFILE DATA ..... Point ..... kid Inc Dir TVD North East V. Sect Deg/lO0 KOP 5500.00 68.54 302.19 2907.85 2540.27 -5,394.48 4121.22 0.00 End o{ Orop/'[urn 7010.6`3 56.97 333.77 3612.26 `3305.29 -4290.10 5`397.`32 2.00 End of Hold 8722.74 56.97 35.3.77 ¢545.52 4-592.86 -4924.55 6629.27 0.00 End of Drop/Turn 9321.19 45.00 353.77 4921.58 5009.20 -5129.70 7027.62 2.00 Target 2N-319 Rsvd 12- 9641.40 45.00 333.77 5148.00 5212.30 -5229.79 7221.95 0.00 End of Hold 9854.95 45.00 .35.5.77 5299.00 5347.74 -5296.53 7:~51.55 0.00 T.O. & End of Hold 10054.95 45.00 335.77 54-40.42 54-74-.60 -5359.05 74-72.93 0.00 <- Wesf (feel) 5700 5400 5100 4800 4500 4200 ,3900 5600 `3300 I I I I I I I I I I I I I I I I I 2700 3000 3300 3600 3900 '-~ 4.200 .-- 4500 480O I V 5100 5400 570O 6OOO 3600 3900 4200 4.500 4800 5100 5400 5700 6000 6300 6600 6900 7200 7500 /~:.00 Vertical Section (feet) -> ~ ~TD - Casing Point .... ~ KOP - Sidetrack Point ~ C35 o/.ao ~ /\ "NT2 - Base Bermuda 65'7163.~ BLS: 2.00 deg per 100 ft ( ~)~R~-E~o-~ ~iedrmBfc~Ud° 58.1 1 ",%, ~ klceberg Interval End Drp & Turn to Target 57.02 '",, ~ ..... '-,, ~ Begin Final Angle Drop ' :' ' '--..,5~,42 q.~ .,,,o~ 0 '-,, , Iceberg Interval -,v-,, \ DLS: 2.00 deg per 100 ft %\ 51.1:5.2'42 ~ k 050 ',,, 47.42 "-,,,_ End Angle Drop 45 42 ""% '' T4 ~ kEnd Orp & Turn tol'orget "\ T3 -- Top Bermuda ',, TARGET - Mid Berrnudo T2 - Base Bermuda ',,, 2N-319 Rsvd 12-Aug-98 "-,,,,, ,, ~ o',~'~"~.. '-'--'-Y---T-'--q---I I -I'~--I"'-- I 'F'--'-~T--I I 1 I 1--'1 I "-I I '~l'~f--'~T I' I f I '-r---"- I . Azimufh 302.89 with reference 0.00 N, 0.00 W from sial //321 57OO 54OO 51 O0 48OO 4500 4200 I Z o 3900 3600 CD 3300 3000 2700 2400 2100 ARCO Alaska, Inc. Tarn Drill Site 2N 321 slot #321 Tarn Development Field North Slope, Alaska 3-D M I N I M U M D I S T A N C E C L E A R A N C E INCLUDING POSITION UNCERTAINTIES Baker Hughes INTEQ REPORT Your ref : 321A Version #1 Our ref : prop3124 License : Date printed : 24-Aug-98 Date created : 23-Aug-98 Last revised : 24-Aug-98 Field is centred on nT0 12 49.742,w150 18 33.414 Structure is centred on nT0 10 13.955,w150 18 32.772 Slot location is nT0 10 13.360,w150 18 54.886 Slot Grid coord/nates are N 5911946.745, E 460829.757 Slot local coord/nates are 60.46 S 763.34 W Projection type= alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limlted to clearances less than 500 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 we11path Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. PMSS <0-9553'>,,323,Tarn Drill Site 2N 23-Jul-98 )309.1( 5500.0 8427.0 PMSS <0-8239'>,,339,Tarn Drill Site 2N 1-J~u~-98 )3299.8( 5500.0 9792.0 PMSS <O-9690'>,,329,Tarn Drill Site 2N 28-May-98 )1347.4( 5500.0 8211.0 P~SS <0-9631'>,,343,Tarn Drill Site 2N 28-May-98 )2621.2( 5500.0 9744.0 PMSS <7090-10245'>,,337A, Tarn Drill Site 2N 29-Jul-98 )3700.6( 5500.0 7734.0 PMSS <0-10655'>,,337,Tarn Drill Site 2N 18-Jun-98 )3700.6( 5500.0 7734.0 PMSS <O-7431'),,345,Tarn Drill Site 2N 21-Jul-98 }2483.2( 5500.0 5500.0 PMSS <O-12339~>,,341,Tarn Drill Site 2N 15-Jul-98 )2525.4( 5500.0 9411.0 PMSS <0-8500t>,,317,Tarn Drill Site 2N 14-Aug-98 )1159.9( 5500.0 7350.0 PMSS <O-9134'>,,313,Tarn Drill Site 2N 4-Aug-98 )1436.5( 9717.0 9717.0 PMSS ¢0-11526~>,,321,Tarn Drill Site 2N 24-Aug-98 )0.0( 6409.2 9915.0 ARCO Alaska, Inc. Tarn Dr~11 Site 2N, 321 Tarn Development Field, North Slope, Alaska C~EARANCE LISTING Page 1 Your ref : 321A Version $1 Last revised : 24-Aug-98 Reference we11path Object we11path : PMSS <0-9553'>,,323,Tarn Drill Site 2N M.D. T.V.D. Rect Coordinates M.D. T.V.D. Horiz Min'm Ellipse Rect Coorchtnates Bearing Dist Sep'n 5739.7 3000.0 5978.0 3100.0 6199.8 3200.0 6409.2 3300.0 6609.1 3400.0 2465.4N 3576.9W 5601.3 2601.8N 3744.7W 5845.4 2738.5N 3887.8W 6071.1 2875.6N 4010.5W 6277.4 3012.9N 4115.7W 6463.7 3316.9 1876.9N 3666.3W 188.6 674.5 )335.6( 3436.4 1970.7N 3857.4W 190.1 724.0 )354.5( 3543.8 2060.2N &034.6W 192.2 774.5 )363.9( 3641.3 2145.7N 4195.0W 194.2 826.6 )368.7( 3726.6 2222.0N 4342.1W 196.0 885.2 )371.0( 6801.6 3500.0 3150.5N 4205.6W 6646.2 6988.1 3600.0 3288.4N 4281.7W 6809.5 7171.6 3700.0 3426.3N 4349.7W 6986.1 7355.0 3500.0 3564.3N 4417.7W 7124.5 7538.5 3900.0 3702.3N 4485.7W 7281.5 3811.0 2298.8N 4484.3W 198.1 948.6 )375.7( 3888.5 2368.3N 4610.3W 199.7 1015.7 )389.9( 3970.9 2444.4N 4746.6W 202.0 1093.2 )410.7( 4035.3 2504.2N 4853.6W 202.3 1170.1 )446.8( 4109.1 2571.3N &97&.SW 203.4 1249.8 )490.5( All data is in feet unless otherwise stated. Casing d~mensions are not included. Coordinates from slot #321 and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Vertical section is from N 0.00 W 0.00 on azimuth 302.89 degrees. Calculation uses the m/nimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. CLEARANCE LISTING Page 2 Tarn Drill Site 2N, 321 Your re£ : 321A Version Tarn Development Field,North Slope, Alaska Last revised : 24-Aug-98 Reference wellpath Object wellpath = PMSS <O-11526',,,321,Tarn Drill Site 2N Horiz Min'm Ellipse M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Sep'n 5739.7 3000.0 2465.4N 3576.9W 5739.3 2992.7 2458.4N 3584.5W 226.9 12.7 )0.0( 5978.0 3100.0 2601.8N 3744.7W 5975.6 3078.6 2571.9N 3773.1W 223.5 46.4 )0.0( 6199.8 3200.0 2738.5N 3887.8W 6192.2 3157.5 2678.8N 3944.1W 223.3 92.4 )0.0( 6409.2 3300.0 2875.6N 4010.5W 6390.0 3224.8 2777.5N 4101.8W 223.0 153.? )0.0( 6609.1 3400.0 3012.9N 4115.7W 6576.7 3288.4 2869.1N 4251.5W 223.4 227.2 )18.0( 6801.6 3500.0 3150.5N 4205.6W 6747.8 3346.7 2953.0N 4388.8W 222.8 309.9 )56.1( 6988.1 3600.0 3288.4N 4281.7W 6913.0 3404.2 3031.?N 4522.1W 223.1 402.6 )100.0( 7171.6 3700.0 3426.3N 4349.7W 7069.6 3457.7 3108.8N 4647.5W 223.2 498.2 )150.2( 7355.0 3800.0 3564.3N 4417.7W 7224.2 3510.2 3184.6N 4771.6W 223.0 594.4 )202.9( 7538.5 3900.0 3702.3N 4485.7W 7379.9 3562.5 3261.2N 4896.7W 223.0 690.9 )257.4{ 7722.0 4000.0 3840.2N 4553.7W 7531.6 3614.0 3335.2N 5018.7W 222.6 787.6 )313.9( 7905.4 4100.0 3978.2N 4621.7W 7676.0 3662.3 3404.5N 5135.8W 221.9 886.0 )374.6( 8088.9 4200.0 4116.2N 4689.7W 7840.7 3720.7 3481.2N 5269.4W 222.4 984.4 )430.7( 8272.3 4300.0 4254.1N 4757.6W 7985.7 3774.6 3546.3N 5387.1W 221.6 1083.2 )491.5( All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #321 and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Vertical section is from N 0.00 W 0.00 on azimuth 302.89 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N 321 slot #321 Tarn Development Field North Slope, Alaska PROPOSAL LISTING INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : 321A Version #1 Our ref : prop3124 License : Date printed : 24-Aug-98 Date created : 23-Aug-98 Last revised : 24-Aug-98 Field is centred on nT0 12 49.742,w150 18 33.414 Structure is centred on nT0 10 13.955,w150 18 32.772 Slot location is nT0 10 13.360,w150 18 54.886 Slot Grid coordinates are N 5911946.745, E 460829.757 Slot local coordinates are 60.46 S 763.34 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska, Inc. Tarn Drill Site 2N,321 Tarn Development Field,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O 0 R D I N A T E S 5500.00 68.54 302.19 2907.85 2340.27 N 3394.48 W 5600.00 67.58 304.08 2945.21 2390.97 N 3472.15 W 5700.00 66.63 306.00 2984.12 2443.85 N 3547.57 W 5800.00 65.71 307.94 3024.53 2498.85 N 3620.65 W 5900.00 64.81 309.90 3066.38 2555.90 N 3691.31 W PROPOSAL LISTING Page 1 Your ref : 321A Version #1 Last revised : 24-Aug-98 Dogleg Vert Deg/100ft Sect 0.00 4121.22 KOP - Sidetrack Point 2.00 4213.97 2.00 4306.02 2.00 4397.26 2.00 4487.57 6000.00 63.94 311.90 3109.63 2614.93 N 3759.46 W 2.00 4576.85 6100.00 63.10 313.93 3154.21 2675.87 N 3825.01 W 2.00 4664.99 6200.00 62.29 315.99 3200.09 2738.64 N 3887.89 W 2.00 4751.88 6300.00 61.51 318.07 3247.20 2803.18 N 3948.02 W 2.00 4837.41 6400.00 60.76 320.19 3295.48 2869.39 N 4005.32 W 2.00 4921.48 6500.00 60.04 322.34 3344.88 2937.20 N 4059.72 W 2.00 5003.99 6600.00 59.36 324.52 3395.34 3006.53 N 4111.17 W 2.00 5084.84 6700.00 58.72 326.72 3446.79 3077.30 N 4159.59 W 2.00 5163.93 6800.00 58.11 328.96 3499.17 3149.40 N 4204.93 W 2.00 5241.15 6900.00 57.55 331.23 3552.42 3222.77 N 4247.13 W 2.00 5316.43 7000.00 57.02 333.52 3606.47 3297.31 N 4286.14 W 2.00 5389.66 7010.63 56.97 333.77 3612.26 3305.29 N 4290.10 W 2.00 5397.32 End Drp & Turn to Target 7219.29 56.97 333.77 3726.00 3462.21 N 4367.42 W 0.00 5547.47 C50 7500.00 56.97 333.77 3879.01 3673.32 N 4471.44 W 0.00 5749.45 7575.20 56.97 333.77 3920.00 3729.87 N 4499.31 W 0.00 5803.56 C40 8000.00 56.97 333.77 4151.56 4049.33 N 4656.73 W 0.00 6109.22 8500.00 56.97 333.77 4424.10 4425.35 N 4842.01 W 0.00 6468.99 8722.74 56.97 333.77 4545.52 4592.86 N 4924.55 W 0.00 6629.27 Begin Final Angle Drop 8800.00 55.42 333.77 4588.50 4650.44 N 4952.92 W 2.00 6684.36 8900.00 53.42 333.77 4646.68 4723.40 N 4988.87 W 2.00 6754.17 8927.22 52.88 333.77 4663.00 4742.94 N 4998.50 W 2.00 6772.86 Iceberg Interval 9000.00 51.42 333.77 4707.65 4794.49 N 5023.90 W 2.00 6822.18 9100.00 49.42 333.77 4771.36 4863.62 N 5057.97 W 2.00 6888.33 9200.00 47.42 333.77 4837.72 4930.72 N 5091.03 W 2.00 6952.54 9300.00 45.42 333.77 4906.65 4995.70 N 5123.06 W 2.00 7014.71 9321.19 45.00 333.77 4921.58 5009.20 N 5129.70 W 2.00 7027.62 End Angle Drop 9378.36 45.00 333.77 4962.00 5045.45 N 5147.57 W 0.00 7062.31 T4 9500.00 45.00 333.77 5048.01 5122.61 N 5185.59 W 0.00 7136.14 9521.19 45.00 333.77 5063.00 5136.05 N 5192.22 W 0.00 7149.00 T3 - Top Bermuda 9641.39 45.00 333.77 5147.99 5212.29 N 5229.78 W 0.00 7221.94 TARGET - Mid Bermuda 9641.40 45.00 333.77 5148.00 5212.30 N 5229.79 W 0.00 7221.95 2N-319 Rsvd 12-Aug-98 9761.61 45.00 333.77 5233.00 5288.54 N 5267.36 W 0.00 7294.91 T2 - Base Bermuda 9854.95 45.00 333.77 5299.00 5347.74 N 5296.53 W 0.00 7351.55 C35 10000.00 45.00 333.77 5401.57 5439.75 N 5341.87 W 0.00 7439.58 10054.95 45.00 333.77 5440.42 5474.60 N 5359.05 W 0.00 7472.93 TD - Casing Point All data is in feet unless otherwise stated. Coordinates from slot #321 and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 7660.98 on azimuth 315.61 degrees from wellhead. Total Dogleg for wellpath is 42.18 degrees. Vertical section is from N 0.00 W 0.00 on azimuth 302.89 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N, 321 Tarn Development Field, North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : 321A Version #1 Last revised : 24-Aug-98 Comments in wellpath MD TVD Rectangular Coords. Comment 5500.00 2907.85 2340.27 N 3394.48 W KOP - Sidetrack Point 7010.63 3612.26 3305.29 N 4290.10 W End Drp & Turn to Target 7219.29 3726.00 3462.21 N 4367.42 W C50 7575.20 3920.00 3729.87 N 4499.31 W C40 8722.74 4545.52 4592.86 N 4924.55 W Begin Final Angle Drop 8927.22 4663.00 4742.94 N 4998.50 W Iceberg Interval 9321.19 4921.58 5009.20 N 5129.70 W End Angle Drop 9378.36 4962.00 5045.45 N 5147.57 W T4 9521.19 5063.00 5136.05 N 5192.22 W T3 - Top Bermuda 9641.39 5147.99 5212.29 N 5229.78 W TARGET - Mid Bermuda 9641.40 5148.00 5212.30 N 5229.79 W 2N-319 Rsvd 12-Aug-98 9761.61 5233.00 5288.54 N 5267.36 W T2 - Base Bermuda 9854.95 5299.00 5347.74 N 5296.53 W C35 10054.95 5440.42 5474.60 N 5359.05 W TD - Casing Point Casing positions in string 'A' == ========================= = Top MD Top TVD Rectangular Coords. Bot MD BOt TVD Rectangular Coords. Casing n/a 2907.85 2340.27N 3394.48W n/a 2907.85 2340.27N 3394.48W 7 5/8" Casing n/a 2907.85 2340.27N 3394.48W 10055.00 5440.42 5474.60N 5359.05W 5 1/2" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 2N-319 Rsvd 12-Aug-9 455627.000,5917185.000,2.0000 5148.00 5212.30N 5229.79W 6-Aug-97 ARCO Alaska, Inc. Tarn Drill Site 2N,321 Tarn Development Field,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D i N A T E S 5500.00 68.54 302.19 2907.85 2279.81 N 4157.82 W 5600.00 67.58 304.08 2945.21 2330.51 N 4235.48 W 5700.00 66.63 306.00 2984.12 2383.39 N 4310.91 W 5800.00 65.71 307.94 3024.53 2438.39 N 4383.99 W 5900.00 64.81 309.90 3066.38 2495.44 N 4454.65 W ~ROPOSAL LISTING Page 1 Your ref : 321A Version #1 Last revised : 24-Aug-98 Dogleg Vert Deg/100ft Sect 0.00 4121.22 KOP - Sidetrack Point 2.00 4213.97 2.00 4306.02 2.00 4397.26 2.00 4487.57 6000.00 63.94 311.90 3109.63 2554.47 N 4522.80 W 2.00 4576.85 6100.00 63.10 313.93 3154.21 2615.41 N 4588.35 W 2.00 4664.99 6200.00 62.29 315.99 3200.09 2678.18 N 4651.23 W 2.00 4751.88 6300.00 61.51 318.07 3247.20 2742.72 N 4711.35 W 2.00 4837.41 6400.00 60.76 320.19 3295.48 2808.93 N 4768.65 W 2.00 4921.48 6500.00 60.04 322.34 3344.88 2876.74 N 4823.06 W 2.00 5003.99 6600.00 59.36 324.52 3395.34 2946.07 N 4874.51 W 2.00 5084.84 6700.00 58.72 326.72 3446.79 3016.84 N 4922.93 W 2.00 5163.93 6800.00 58.11 328.96 3499.17 3088.94 N 4968.27 W 2.00 5241.15 6900.00 57.55 331.23 3552.42 3162.31 N 5010.47 W 2.00 5316.43 7000.00 57.02 333.52 3606.47 3236.85 N 5049.48 W 2.00 5389.66 7010.63 56.97 333.77 3612.26 3244.83 N 5053.43 W 2.00 5397.32 End Dzl0 & Turn to Target 7219.29 56.97 333.77 3726.00 3401.76 N 5130.76 W 0.00 5547.47 C50 7500.00 56.97 333.77 3879.01 3612.86 N 5234.78 W 0.00 5749.45 7575.20 56.97 333.77 3920.00 3669.41 N 5262.64 W 0.00 5803.56 C40 8000.00 56.97 333.77 4151.56 3988.87 N 5420.06 W 0.00 6109.22 8500.00 56.97 333.77 4424.10 4364.89 N 5605.35 W 0.00 6468.99 8722.74 56.97 333.77 4545.52 4532.40 N 5687.89 W 0.00 6629.27 Begin Final Angle Drop 8800.00 55.42 333.77 4588.50 4589.98 N 5716.26 W 2.00 6684.36 8900.00 53.42 333.77 4646.68 4662.94 N 5752.21 W 2.00 6754.17 8927.22 52.88 333.77 4663.00 4682.48 N 5761.84 W 2.00 6772.86 Iceberg Interval 9000.00 51.42 333.77 4707.65 4734.03 N 5787.24 W 2.00 6822.18 9100.00 49.42 333.77 4771.36 4803.16 N 5821.31 W 2.00 6888.33 9200.00 47.42 333.77 4837.72 4870.26 N 5854.37 W 2.00 6952.54 9300.00 45.42 333.77 4906.65 4935.24 N 5886.39 W 2.00 7014.71 9321.19 45.00 333.77 4921.58 4948.74 N 5893.04 W 2.00 7027.62 End Angle Drop 9378.36 45.00 333.77 4962.00 4984.99 N 5910.91 W 0.00 7062.31 T4 9500.00 45.00 333.77 5048.01 5062.15 N 5948.93 W 0.00 7136.14 9521.19 45.00 333.77 5063.00 5075.59 N 5955.55 W 0.00 7149.00 T3 - Top Bermuda 9641.39 45.00 333.77 5147.99 5151.83 N 5993.12 W 0.00 7221.94 TARGET - Mid Bermuda 9641.40 45.00 333.77 5148.00 5151.84 N 5993.12 W 0.00 7221.95 2N-319 Rsvd 12-Aug-98 9761.61 45.00 333.77 5233.00 5228.08 N 6030.70 W 0.00 7294.91 T2 - Base Bermuda 9854.95 45.00 333.77 5299.00 5287.28 N 6059.87 W 0.00 7351.55 C35 10000.00 45.00 333.77 5401.57 5379.29 N 6105.21 W 0.00 7439.58 10054.95 45.00 333.77 5440.42 5414.14 N 6122.38 W 0.00 7472.93 TD - Casing Point All data is in feet unless otherwise stated. Coordinates from SE Corner of Sec. 34, T10N, R7E and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 7660.98 on azimuth 315.61 degrees from wellhead. Total Dogleg for wellpath is 42.18 degrees. Vertical section is from S 60.46 W 763.34 on azimuth 302.89 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N,321 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : 321A Version #1 Last revised : 24-Aug-98 Comments in wellpath MD TVD Rectangular Coords. Comment 5500.00 2907.85 2279 81 N 4157.82 W KOP - Sidetrack Point 7010.63 3612.26 3244 7219.29 3726.00 3401 7575.20 3920.00 3669 8722.74 4545.52 4532 8927.22 4663.00 4682 9321.19 4921.58 4948 9378.36 4962.00 4984 9521.19 5063.00 5075 9641.39 5147.99 5151 9641.40 5148.00 5151. 9761.61 5233.00 5228. 9854.95 5299.00 5287. 10054.95 5440.42 5414. 83 N 5053.43 W End DrD & Turn to Target 76 N 5130.76 W C50 41 N 5262.64 W C40 40 N 5687.89 W Begin Final Angle Drop 48 N 5761.84 W Iceberg Interval 74 N 5893.04 W End Angle Drop 99 N 5910.91 W T4 59 N 5955.55 W T3 - Top Bermuda 83 N 5993.12 W TARGET - Mid Bermuda 84 N 5993.12 W 2N-319 Rsvd 12-Aug-98 08 N 6030.70 W T2 - Base Bermuda 28 N 6059.87 W C35 14 N 6122.38 W TD - Casing Point Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing n/a 2907.85 2279.81N 4157.82W n/a 2907.85 2279.81N 4157.82W 7 5/8" Casing n/a 2907.85 2279.81N 4157.82W 10055.00 5440.42 5414.14N 6122.38W 5 1/2" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 2N-319 Rsvd 12-Aug-9 455627.000,5917185.000,2.0000 5148.00 5151.84N 5993.12W 6-Aug-97 ARCO Alaska, Inc. Tarn Drill Site 2N,321 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref ~ 321A Version #1 Last revised : 24-Aug-98 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C 00 R D S Depth Degrees Degrees Depth C O O R D I N A T E S Deg/100ft Sect Easting Northing 5500.00 68.54 302.19 2907.85 2340.27N 3394.48W 0.00 4121.22 457447.53 5914303.98 5600.00 67.58 304.08 2945.21 2390.97N 3472.15W 2.00 4213.97 457370.13 5914355.06 5700.00 66.63 306.00 2984.12 2443.85N 3547.57W 2.00 4306.02 457294.98 5914408.32 5800.00 65.71 307.94 3024.53 2498.85N 3620.65W 2.00 4397.26 457222.19 5914463.69 5900.00 64.81 309.90 3066.38 2555.90N 3691.31W 2.00 4487.57 457151.82 5914521.09 6000.00 63.94 311.90 3109.63 2614.93N 3759.46W 2.00 4576.85 457083.98 5914580.46 6100.00 63.10 313.93 3154.21 2675.87N 3825.01W 2.00 4664.99 457018.75 5914641.72 6200.00 62.29 315.99 3200.09 2738.64N 3887.89W 2.00 4751.88 456956.20 5914704.81 6300.00 61.51 318.07 3247.20 2803.18N 3948.02W 2.00 4837.41 456896.40 5914769.64 6400.00 60.76 320.19 3295.48 2869.39N 4005.32W 2.00 4921.48 456839.45 5914836.14 6500.00 60.04 322.34 3344.88 2937.20N 4059.72W 2.00 5003.99 456785.39 5914904.22 6600.00 59.36 324.52 3395.34 3006.53N 4111.17W 2.00 5084.84 456734.30 5914973.81 6700.00 58.72 326.72 3446.79 3077.30N 4159.59W 2.00 5163.93 456686.25 5915044.81 6800.00 58.11 328.96 3499.17 3149.40N 4204.93W 2.00 5241.15 456641.28 5915117.14 6900.00 57.55 331.23 3552.42 3222.77N 4247.13W 2.00 5316.43 456599.45 5915190.71 7000.00 57.02 333.52 3606.47 3297.31N 4286.14W 2.00 5389.66 456560.82 5915265.43 7010.63 56.97 333.77 3612.26 3305.29N 4290.10W 2.00 5397.32 456556.91 5915273.44 7219.29 56.97 333.77 3726.00 3462.21N 4367.42W 0.00 5547.4? 456480.39 5915430.74 7500.00 56.97 333.77 3879.01 3673.32N 4471.44W 0.00 5749.45 456377.45 5915642.34 7575.20 56.97 333.77 3920.00 3729.87N 4499.31W 0.00 5803.56 456349.88 5915699.03 8000.00 56.97 333.77 4151.56 4049.33N 4656.73W 0.00 6109.22 456194.10 5916019.26 8500.00 56.97 333.77 4424.10 4425.35N 4842.01W 0.00 6468.99 456010.74 5916396.17 8722.74 56.97 333.77 4545.52 4592.86N 4924.55W 0.00 6629.27 455929.06 5916564.08 8800.00 55.42 333.77 4588.50 4650.44N 4952.92W 2.00 6684.36 455900.98 5916621.81 8900.00 53.42 333.77 4646.68 4723.40N 4988.87W 2.00 6754.17 455865.41 5916694.93 8927.22 52.88 333.77 4663.00 4742.94N 4998.50W 2.00 6772.86 455855.88 5916714.52 9000.00 51.42 333.77 4707.65 4794.49N 5023.90W 2.00 6822.18 455830.74 5916766.19 9100.00 49.42 333.77 4771.36 4863.62N 5057.97W 2.00 6888.33 455797.03 5916835.49 9200.00 47.42 333.77 4837.72 4930.72N 5091.03W 2.00 6952.54 455764.31 5916902.75 9300.00 45.42 333.77 4906.65 4995.70N 5123.06W 2.00 7014.71 455732.62 5916967.89 9321.19 45.00 333.77 4921.58 5009.20N 5129.70W 2.00 7027.62 455?26.04 5916981.41 9378.36 45.00 333.77 4962.00 5045.45N 5147.57W 0.00 7062.31 455708.36 5917017.76 9500.00 45.00 333.77 5048.01 5122.61N 5185.59W 0.00 7136.14 455670.74 5917095.10 9521.19 45.00 333.77 5063.00 5136.05N 5192.22W 0.00 7149.00 455664.18 5917108.57 9641.39 45.00 333.77 5147.99 5212.29N 5229.78W 0.00 7221.94 455627.00 5917184.99 9641.40 45.00 333.77 5148.00 5212.30N 5229.79W 0.00 7221.95 455627.00 5917185.00 9761.61 45.00 333.77 5233.00 5288.54N 5267.36W 0.00 7294.91 455589.82 5917261.43 9854.95 45.00 333.77 5299.00 5347.74N 5296.53W 0.00 7351.55 455560.95 5917320.77 10000.00 45.00 333.77 5401.57 5439.75N 5341.87W 0.00 7439.58 455516.08 5917412.99 10054.95 45.00 333.77 5440.42 5474.60N 5359.05W 0.00 7472.93 455499.09 5917447.93 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #321 and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 7660.98 on azimuth 315.61 degrees from wellhead. Total Dogleg for wellpath is 42.18 degrees. Vertical section is from N 0.00 W 0.00 on azimuth 302.89 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N, 321 Tarn Development Field, North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : 321A Version #1 Last revised : 24-Aug-98 Comments in wellpath MD TVD Rectangular Coords. Comment 5500.00 2907.85 2340.27N 3394.48W KOP - Sidetrack Point 7010.63 3612.26 3305.29N 4290.10W End Drp & Turn to Target 7219.29 3726.00 3462.21N 4367.42W C50 7575.20 3920.00 3729.87N 4499.31W C40 8722.74 4545.52 4592.86N 4924.55W Begin Final Angle Drop 8927.22 4663.00 4742.94N 4998.50W Iceberg Interval 9321.19 4921.58 5009.20N 5129.70W End Angle Drop 9378.36 4962.00 5045.45N 5147.57W T4 9521.19 5063.00 5136.05N 5192.22W T3 - Top Bermuda 9641.39 5147.99 5212.29N 5229.78W TARGET - Mid Bermuda 9641.40 5148.00 5212.30N 5229.79W 2N-319 Rsvd 12-Aug-98 9761.61 5233.00 5288.54N 5267.36W T2 - Base Bermuda 9854.95 5299.00 5347.74N 5296.53W C35 10054.95 5440.42 5474.60N 5359.05W TD - Casing Point Casing positions in string 'A' ___============= ======= Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing n/a 2907.85 2340.27N 3394.48W n/a 2907.85 2340.27N 3394.48W 7 5/8" Casing n/a 2907.85 2340.27N 3394.48W 10055.00 5440.42 5474.60N 5359.05W 5 1/2" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 2N-319 Rsvd 12-Aug-9 455627.000,5917185.000,2.0000 5148.00 5212.30N 5229.79W 6-Aug-97 ARCO Alaska, Inc. Tarn Drill Site 2N,321 Tarn Development Field,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G Depth Degrees Degrees Depth C O O R D I N 5500.00 68.54 302.19 2907.85 2340.27 N 5600.00 67.58 304.08 2945.21 2390.97 N 5700.00 66.63 306.00 2984.12 2443.85 N 5800.00 65.71 307.94 3024.53 2498.85 N 5900.00 64.81 309.90 3066.38 2555.90 N 6000.00 63.94 311.90 3109.63 2614.93 N 6100.00 63.10 313.93 3154.21 2675.87 N 6200.00 62.29 315.99 3200.09 2738.64 N 6300.00 61.51 318.07 3247.20 2803.18 N 6400.00 60.76 320.19 3295.48 2869.39 N 6500.00 60.04 322.34 3344.88 2937.20 N 6600.00 59.36 324.52 3395.34 3006.53 N 6700.00 58.72 326.72 3446.79 3077.30 N 6800.00 58.11 328.96 3499.17 3149.40 N 6900.00 57.55 331.23 3552.42 3222.77 N PROPOSAL LISTING Page 1 Your ref : 321A Version 91 Last revised : 24-Aug-98 ULAR ATES Vert Ellipse Semi Axes Minor Sect Major Minor Vert. Azi. 3394.48 W 4121.22 301.49 22.02 40.47 303.76 3472.15 W 4213.97 308.46 22.42 41.40 303.77 3547.57 W 4306.02 315.22 22.84 42.32 303.82 3620.65 W 4397.26 321.75 23.27 43.22 303.90 3691.31 W 4487.57 328.04 23.70 44.11 304.02 3759.46 W 4576.85 3825.01 W 4664.99 3887.89 W 4751.88 3948.02 W 4837.41 4005.32 W 4921.48 334.10 24.15 44.99 304.16 339.90 24.61 45.86 304.33 345.44 25.07 46.71 304.52 350.73 25.55 47.56 304.73 355.75 26.03 48.39 304.95 4059.72 W 5003.99 360.50 26.52 49.21 305.19 4111.17 W 5084.84 364.99 27.02 50.02 305.44 4159.59 W 5163.93 369.20 27.53 50.82 305.69 4204.93 W 5241.15 373.15 28.06 51.61 305.95 4247.13 W 5316.43 376.83 28.60 52.39 306.22 7000.00 57.02 333.52 3606.47 3297.31 N 4286.14 W 5389.66 380.25 29.15 53.17 306.48 7010.63 56.97 333.77 3612.26 3305.29 N 4290.10 W 5397.32 380.61 29.21 53.25 306.51 7219.29 56.97 333.77 3726.00 3462.21 N 4367.42 W 5547.47 387.75 30.41 54.86 307.04 7500.00 56.97 333.77 3879.01 3673.32 N 4471.44 W 5749.45 397.36 32.02 57.03 307.75 7575.20 56.97 333.77 3920.00 3729.87 N 4499.31 W 5803.56 399.97 32.46 57.61 307.93 8000.00 56.97 333.77 4151.56 4049.33 N 4656.73 W 6109.22 414.72 34.96 60.89 308.93 8500.00 56.97 333.77 4424.10 4425.35 N 4842.01 W 6468.99 432.30 37.94 64.75 310.01 8722.74 56.97 333.77 4545.52 4592.86 N 4924.55 W 6629.27 440.19 39.26 66.47 310.47 8800.00 55.42 333.77 4588.50 4650.44 N 4952.92 W 6684.36 442.86 39.73 67.04 310.62 8900.00 53.42 333.77 4646.68 4723.40 N 4988.87 W 6754.17 446.19 40.34 67.76 310.81 8927.22 52.88 333.77 4663.00 4742.94 N 4998.50 W 6772.86 447.06 40.51 67.94 310.85 9000.00 51.42 333.77 4707.65 4794.49 N 5023.90 W 6822.18 449.39 40.97 68.44 310.98 9100.00 49.42 333.77 4771.36 4863.62 N 5057.97 W 6888.33 452.45 41.60 69.08 311.15 9200.00 47.42 333.77 4837.72 4930.72 N 5091.03 W 6952.54 455.37 42.23 69.69 311.30 9300.00 45.42 333.77 4906.65 4995.70 N 5123.06 W 7014.71 458.16 42.87 70.26 311.45 9321.19 45.00 333.77 4921.58 5009.20 N 5129.70 W 7027.62 458.74 43.01 70.38 311.48 9378.36 45.00 333.77 4962.00 5045.45 N 5147.57 W 7062.31 460.32 43.37 70.70 311.56 9500.00 45.00 333.77 5048.01 5122.61 N 5185.59 W 7136.14 463.67 44.15 71.39 311.73 9521.19 45.00 333.77 5063.00 5136.05 N 5192.22 W 7149.00 464.26 44.29 71.51 311.76 9641.39 45.00 333.77 5147.99 5212.29 N 5229.78 W 7221.94 467.59 45.05 72.19 311.93 9641.40 45.00 333.77 5148.00 5212.30 N 5229.79 W 7221.95 467.59 45.05 72.19 311.93 9761.61 45.00 333.77 5233.00 5288.54 N 5267.36 W 7294.91 470.92 45.82 72.87 312.09 9854.95 45.00 333.77 5299.00 5347.74 N 5296.53 W 7351.55 473.51 46.41 73.40 312.22 10000.00 45.00 333.77 5401.57 5439.75 N 5341.87 W 7439.58 477.55 47.33 74.22 312.42 10054.95 45.00 333.77 5440.42 5474.60 N 5359.05 W 7472.93 479.08 47.68 74.53 312.49 All data is in feet unless otherwise stated. Coordinates from slot #321 and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 7660.98 on azimuth 315.61 degrees from wellhead. Vertical section is from N 0.00 W 0.00 on azimuth 302.89 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes iNTEQ ARCO Alaska, Inc. Tarn Drill Site 2N, 321 Tarn Development Field,North Slope, Alaska PROPOSAL LISTIN~ Page 2 Your ref : 321A Version #1 Last revised : 24-Aug-98 POSITION UNCERTAINTY SUMMARY Depth Position Uncertainty From To Survey Tool Error Model Major Minor Vert. 0 5500 ARCO (H.A. Mag) User specified 301.49 22.02 40.47 5500 10055 ARCO (H.A. Mag) User specified 479.08 47.68 74.53 1. Ellipse dimensions are half axis. 2. Casing dimensions are not included. 3. Ellipses are calculated on 2.58 standard deviations. 4. Uncertainty calculations start at drill depth zero. 5. Surface position uncertainty is not included. 6. Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trakmanual. Comments in wellpath MD TVD Rectangular Coords. Comment 5500.00 2907.85 2340.27 N 3394.48 W KOP - Sidetrack Point 7010 63 7219 29 7575 20 8722 74 8927 22 9321 19 9378 36 9521 19 9641.39 9641.40 9761.61 9854.95 10054.95 3612 3726 3920 4545 4663 00 4921 58 4962 00 5063 00 5147.99 5148.00 5233.00 5299.00 5440.42 26 O0 O0 52 3305.29 N 4290.10 W End Drp & Turn to Target 3462.21 N 4367.42 W C50 3729.87 N 4499.31 W C40 4592.86 N 4924.55 W Begin Final Angle Drop 4742.94 N 4998.50 W Iceberg Interval 5009.20 N 5129.70 W End Angle Drop 5045.45 N 5147.57 W T4 5136.05 N 5192.22 W T3 - Top Bermuda 5212.29 N 5229.78 W TARGET - Mid Bermuda 5212.30 N 5229.79 W 2N-319 Rsvd 12-Aug-98 5288.54 N 5267.36 W T2 - Base Bermuda 5347.74 N 5296.53 W C35 5474.60 N 5359.05 W TD - Casing Point Casing positions in string 'A' ====================== Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing n/a 2907.85 2340.27N 3394.48W n/a 2907.85 2340.27N 3394.48W 7 5/8" Casing n/a 2907.85 2340.27N 3394.48W 10055.00 5440.42 5474.60N 5359.05W 5 1/2" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 2N-319 Rsvd 12-Aug-9 455627.000,5917185.000,2.0000 5148.00 5212.30N 5229.79W 6-Aug-97 ARCO Alaska, Inc. ...t Post Office Box 100360 Anchorage, Alaska 99510-0360 August 24, 1998 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re~ Application for Permit to Drill KRU 2N-321A Surface Location: 60' FNL 763' FEI_ Sec 3 TgN R7E, UM Target Location: 128' FNL, 713' FEL Sec. 33, T10N, R7E, UM Bottom Hole Location: 134' FSL, 842' FEL Sec. 28, T10N, R7E, UM Dear Commissioner Johnston, ARCO Alaska, Inc. hereby files this Application for Permit to Drill a development well in the Tarn area, KRU 2N-321A, located approximately seven miles southwest of the Kuparuk River Unit's 2M Drillsite. This well will be a sidetrack form the 2N 321 wellbore which has surface casing set at 3861' MD, The well is accessed via a new gravel road originating at 2M Pad. Doyon Rig 141 will drill the well. If commercial, the well will completed with Doyon 141 also. 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 either 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, ARCO 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 ARC©'s designated contacts for reporting responsibilities to the Commission: RECEIVED ARCO Alaska, lnc~ is a Subsidiary of AtlanticRichfieldCompany AUG 25 't998 Ala~ 0il & Gas Cons. comm~ss~u' Anchorage David W. Johnst~7, Application for Permit to Drill Page 2 KRU 2N-319 1) Completion Report (20 AAC 25.070) 2) Geologic Data and Logs Doug Hastings, Geologist (20 AAC 25.071) If you have questions or require additional information, please contact Tom Brassfield at 265-6377 or me at 263-4603 in our Anchorage office. Sincerely, Paul Mazzolini Drilling Team Leader Exploration / Tarn Development Group Attachments cc: KRU 2N-321 Well File Sharon Allsup-Drake, Drilling Technologist 263-4612 265-6967 RECEIVED AJ~ka Oil & Gas Cons. Cor~r~ss~o~, Anchorage , ARCO Alaska, Inc. ~ GENERAL DRILLING AND COMPLETION PROCEDURE KUPARUK RIVER FIELD - PRODUCER KRU 2N 321 A (Sidetrack) NOTE: 2N 321 A will be sidetracked form the 2N 321 wellbore at approximately 5500' MD as indicated in the attached directional plat. The original 2N 321 wellbore was P&A'd with a cement plug from 11,526' MD to 10,921' MD. A kickoff plug was set from 5550' MD to 5200' MD. The 2N 321A wellbore becomes a standard Tarn drilling operation with a new bottom hole location. 1. Drill 6-3/4" 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. 9. Pressure test casing to 3,500 psi. 10. 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. 11. ND BOPE and install production tree. 12. Secure well. Rig down and move out. · WELL PERMIT CHECKLIST FIELD & POOL ADMINISTRATION , 7. 8. 9. 10. 11. D ,-'rE , 12. .¢~"~.,?_~//'~' 13. Permit fee attached ....................... Lease number appropriate ................... Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Perrnit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... ENGINEERING 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. APPR DATE 26. 27. 28. Conductor string provided ................... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg ........ CMT will cover all known productive horizons .......... Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. If a re-drill, has a 10-403 for abandonrnent been approved. Adequate wellbore separation proposed ............. If diveder required, does it meet regulations .......... Drilling fluid program schematic & equip list adequate ..... BOPEs, do they meet regulation ................ BOPE press rating appropriate; test to ..¢"'O o r_~ psig. Choke manifold complies w/APl RP-53 (May 84) ........ Work will occur without operation shutdown ........... N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N ~N (~N GEOLOGY 29. Is presence of H2S gas probable ................. Y ~ ........................................................................................................................................................................................... 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N~Y N .................................................................................................................................. 31. Data presented on potential overpressure zones ....... Y~ ~ /.__~._; 32. Seismic analysis of shallow gas zones. ' ~ ........................................................................................................................................................................................... 33. Seabed condition survey (if off-shore) ............. 34. Contact name/phone for weekly progress repods ....... // Y N ..................................................................................................................................................................... [exploratory only] ANNULAR DISPOSAL 35. 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; _W~ ...... .~_~.. (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. N N NN GEOLOGY: ENGINEERING' UlC/Annular COMMISSION: JDH _/ RNC ~ CO Comments/Instructions: McheMist Iov 05/29/98 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 Mon Dec 14 16:15:15 1998 Reel Header Service name ............. LISTPE Date ..................... 98/12/14 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 98/12/14 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT, MWD/M3~D LOGS WELL NAME: API NUMBER: OPEP~ATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA TARN POOL JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: MWD RUN 2 AK-MM-80338 R. KRELL D. BURLEY DEC 17 !998 501032026701 A~chorage .. ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 14-DEC-98 MWD RUN 3 AK-MM-80338 K. FERGUSON D. BURLEY 3 09N 07E 60 763 148.80 147 . 30 120.90 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 108.0 9.875 7.625 3861.0 6.750 10028.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 3. MWD RUNS 2 AND 3 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR), ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND STABILIZED LITHO-DENSITY (SLD) . 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE E-MAIL MESSAGE FROM DOUG HASTINGS OF ARCO ALASKA, INC. ON 22 OCTOBER, 1998. SPERRY-SUN MWD DATA IS PRIMARY DEPTH CONTROL (PDC) FOR WELL 2N-321A. 5. NO THERMAL NEUTRON POROSITY DATA (CTN) AVAILABLE FROM MWD RUN 2 DUE TO TOOL FAILURE. 6. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10028'MD, 5430'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED COMPENSATED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX-FIXED HOLE SIZE). SNNA = SMOOTHED AVERAGE NEAR DETECTORS' COUNT RATES. SNFA = SMOOTHED AVERAGE OF FAR DETECTORS' COUNT RATES. SBD2 = SMOOTHED BULK DENSITY - COMPENSATED. SC02 = SMOOTHED STANDOFF CORRECTION. SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. COMPENSATED THERMAL NEUTRON POROSITY PROCESSING PAIAAMETERS: FIXED HOLE SIZE: 6.75" MUD WEIGHT: 9.2 TO 9.5 PPG MUD SALINITY: 300-750 PPM CHLORIDES FORMATION WATER SALINITY: 19149 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/12/14 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 FET 3800 RPD 3800 RPM 3800 RPS 3800 RPX 3800 GR 3800 ROP 3800 PEF 3848 DRHO 3848 RHOB 3848 FCNT 5355 NCNT 5355 NPHI 5355 $ BASELINE CURVE FOR SHIFTS: DEPTH STOP DEPTH 0 9940.5 0 9940.5 0 9940.5 0 9940.5 0 9940.5 0 9933.5 0 10027.5 0 9909.5 0 9909.5 0 9909.5 5 9893.5 5 9893.5 5 9893.5 CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH -- 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 MERGED MAIN PASS. $ BIT RUN NO MERGE TOP MERGE BASE 2 3880.0 5355.0 3 5355.0 10028.0 Absent value ...................... -999.25 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 OHMM 4 1 68 FCNT MWD CNTS 4 1 68 NCNT MWD CNTS 4 1 68 RHOB MWD G/C3 4 1 68 DRHO MWD G/C3 4 1 68 PEF MWD BARN 4 1 68 NPHI MWD PU-S 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 DEPT ROP GR RPX RPS RPM RPD FET FCNT NCNT RHOB DRHO PEF NPHI Min 3800 0 06 39 12 1 O5 1 16 0 64 0 17 0 47 150.7 19833.8 -44.38 -43.96 1.68 12.37 Max Mean Nsam 10027.5 6913.75 12456 6739.45 233.959 12456 259.5 122.188 12268 1236.22 4.95427 12282 1236.65 5.12799 12282 2000 14.8927 12282 2000 12.6159 12282 121.77 2.28837 12282 1000.44 224.916 9077 41759.7 24680.9 9077 3.19 2.30991 12124 0.88 0.0549274 12124 6.69 2.82574 12124 52.58 39.0792 9077 First Reading 3800 3800 3800 3800 3800 3800 3800 3800 5355.5 5355.5 3848 3848 3848 5355.5 Last Reading 10027 5 10027 5 9933 5 9940 5 9940 5 9940 5 9940 5 9940 5 9893 5 9893 5 9909 5 9909.5 9909.5 9893.5 First Reading For Entire File .......... 3800 Last Reading For Entire File ........... 10027.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/12/14 Maximum Physical Record..65535 File Type ................ LO Next Pile Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/12/14 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 STOP DEPTH FET 3800 0 5355.0 RPD 3800 0 5355.0 RPM 3800 0 5355.0 RPS 3800 0 5355 0 RPX 3800 0 5355 0 GR 3800 0 5355 0 ROP 3800 0 5355 0 PEF 3848 0 5355 0 DRHO 3848 0 5355 0 RHOB 3848 0 5355 0 $ LOG HEADER DATA DATE LOGGED: 23-AUG-98 SOFTWARE SURFACE SOFTWARE VERSION: INSITE 3.2.12.3 DOWNHOLE SOFTWARE VERSION: CIM 5.46,SP4 5.16,SLD 10.83 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 5355.0 TOP LOG INTERVAL (FT) : 3880.0 BOTTOM LOG INTERVAL (FT) : 5355.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 57.3 MAXIMUM ANGLE: 70.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : TOOL NUMBER P1070GRM4 P1070GRM4 P1070GRM4 P1070GRM4 6.750 6.8 BOREHOLE CONDITIONS MUD TYPE: MTJD DENSITY (LB/G) : MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPER3ATURE (DEGF) MUD AT MEASURED TEMPEP~ATURE (MT) : MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 LSND 9.20 45.0 9.0 350 7.6 3.400 2.190 1.850 5.800 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 2 FT/H 4 1 68 4 2 GR MWD 2 API 4 1 68 8 3 RPX MWD 2 OHMM 4 1 68 12 4 RPS MWD 2 OHMM 4 1 68 16 5 RPM MWD 2 OHMM 4 1 68 20 6 RPD MWD 2 OHMM 4 1 68 24 7 FET MWD 2 HOUR 4 1 68 28 8 RHOB MWD 2 G/C3 4 1 68 32 9 PEF MWD 2 BAR/q 4 1 68 36 10 DRHO MWD 2 G/C3 4 1 68 40 11 48.2 First Name Min Max Mean Nsam Reading DEPT 3800 5355 4577.5 3111 3800 ROP 0.28 1915.77 240.388 3111 3800 GR 39.12 175.08 107.611 3111 3800 RPX 2.41 1236.22 5.86009 3111 3800 Last Reading 5355 5355 5355 5355 RPS RPM RPD FET RHOB PEF DRHO 1 33 0 64 0 17 0 48 1 58 1 89 -0 04 1236.65 6.20729 2000 45.1303 2000 35.7406 101.98 5.95797 2.95 2.20616 6.69 2.87065 0.88 0.0665174 3111 3111 3111 3111 3015 3015 3015 38O0 3800 3800 3800 3848 3848 3848 5355 5355 5355 5355 5355 5355 5355 First Reading For Entire File .......... 3800 Last Reading For Entire File ........... 5355 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/12/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/12/14 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE PEF DRHO RHOB FCNT NCNT NPHI FET RPX RPM RPS RPX GR 3 .5000 START DEPTH 5355 5 5355 5 5355 5 5355 5 5355 5 5355 5 5355 5 5355 5 5355 5 5355.5 5355.5 5355.5 STOP DEPTH 9909.5 9909.5 9909.5 9893.5 9893.5 9893 5 9940 5 9940 5 9940 5 9940 5 9940 5 9933 5 ROP 5355.5 LOG HEADER DATA DATE LOGGED: 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: 10027.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD 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 27-AUG-98 INSITE 3.2.12.3 CIM 5.46,SP4 5.16,SLD 10.83 MEMORY 10028.0 5355.0 10028.0 42.1 69.6 TOOL NUMBER P1070GRM4 P1070GRM4 P1070GRM4 P1070GRM4 6.750 6.8 LSND 9.30 43.0 9.8 600 6.0 2.900 1.522 1.800 5.300 53.7 .5 Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined At, sent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 DRHO MWD 3 G/C3 4 1 ROP MWD 3 FT/H 4 1 GR MWD 3 API 4 1 RPX MWD 3 OHMM 4 1 RPS MWD 3 OHMM 4 1 RPM MWD 3 OHMM 4 1 RPD MWD 3 OHMM 4 1 FET MWD 3 HOUR 4 1 FCNT MWD 3 CNTS 4 1 NCNT MWD 3 CNTS 4 1 RHOB MWD 3 G/C3 4 1 PEF MWD 3 BARN 4 1 NPHI MWD 3 PU-S 4 1 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 68 32 9 68 36 10 68 40 11 68 44 12 68 48 13 68 52 14 Name Min DEPT 5355.5 DRHO -43.96 ROP 0.06 GR 51.66 RPX 1.05 RPS 1.16 RPM 1.1 RPD 1.15 FET 0.47 FCNT 150.7 NCNT 19833.8 RHOB -44.38 PEF 1.68 NPHI 12.37 Max 10027.5 0.86 6739.45 259.5 39 59 36 89 32 38 33 26 121 77 1000 44 41759.7 3.19 6.28 52.58 Mean Nsam 7691.5 9345 0.0510912 9109 231.818 9345 127.141 9157 4.647 9171 4.76187 9171 4.63539 9171 4.77146 9171 1.04356 9171 224.916 9077 24680.9 9077 2.34425 9109 2.81088 9109 39.0792 9077 First Reading 5355 5 5355 5 5355 5 5355 5 5355 5 5355 5 5355 5 5355.5 5355.5 5355.5 5355.5 5355.5 5355.5 5355.5 Last Reading 10027 5 9909 5 10027 5 9933 5 9940 5 9940 5 9940 5 9940.5 9940.5 9893.5 9893.5 9909.5 9909.5 9893.5 First Reading For Entire File .......... 5355.5 Last Reading For Entire File ........... 10027.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/12/14 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/12/14 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 98/12/14 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Services Technical Services Physical EOF Physical EOF End Of LIS File
