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HomeMy WebLinkAbout199-046ORIGINATED 12/17/2019 ALASKA E -LINE SERVICES 11012019 42260 Kenai Spur Hwy PO BOX 1481- Kenai, Alaska 99611 RECEIVED Alpine PH: (907) 283-7374 FAX: (907) 283-7378 3 1 6 9 6 DEC 19 2019 DFLIVERABLE DESCRIPTION BP North Slope 0 0 0 EOA, PBOC, PRB-20 (Office 109) D&C Wells Project Aids 900 E. Benson Blbd. - Anchorage, AK 99508 -onoco Phillips Alaska Inc. 1 0 0 %ttn: NSK-69 700 G Street anchorage, Alaska 99501 NOGCC 0 0 1 NTTN: Natural Resources Technician II Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 - Anchorage, AK 99501-3539 )NR 0 0 1 %ttn: Garrett Brown -Geologist I )NR, Division of Oil & Gas 350 West 7th Ave, Suite #1100 - Anchorage, AK 99501 Please return via e-mail a copy to both Alaska E -Line Services and ConocgqPhillips Alaska: ConocoPhillips April 29, 2019 Mr. Peter Contreras Supervisor, Ground Water Protection Unit U.S. Environmental Protection Agency 1200 Sixth Avenue, Suite 155, OCE -101 Seattle, WA 98101 ,0-o4V Lynn DeGeorge Alpine Environmental Coordinator Alpine Operations CPA HSE -ALP 14 P.O. Box 196860 Anchorage, Alaska 9951"105 Phone 907.670.4200 RE: Class I Well Permit #AK -11010-B (CD1-01A), Permit to Drill No. 212-099 Class I Well Permit #AK -11003-C (WD -02), Permit to Drill No. 99-258 Biannual Report—C142018 and 01 2019 Dear Mr. Contreras, Ot E 41 E Gam' iAY C 2 2019 /A0GCC On behalf of ConocoPhillips Alaska, Inc., I submit to you the Alpine Class I Well Report for Q4 2018 and Q1 2019 for Class I Wells CD1-01A (AK-11010-13)and WD -02 (AK -1 1003-C). Pursuant to requirements in Part ILE of the subject permits, the following information is provided: • Report Certification • EPA Form 7520-8, Injection Well Monitoring Report • Graphical plots of continuous injection pressure and rate monitoring • Raw monitoring data in electronic format • Physical, chemical, and other relevant characteristics of injected fluid • Summary of significant well maintenance • Mechanical integrity test results • Other reports and back-up information • Any other test required by the Director If you have any questions regarding this report, or if you need additional information, please contact me at the above telephone number or address. Sincerely, w Z- Lynn DeGeorge Alpine Environmental Coordinator Statement of Certification This report is hereby certified In accordance with the requirements of Part I.E.15 of the Environmental Protection Agency Permits AK -11010-B and AK -11003-C. I certify under the penalty of law that this document and all attachments were prepared under my direction or supervision in accordance with a system designed to assure that qualified personnel properly gather and evaluate the Information submitted. Based on my inquiry of the person or persons who manage the system, or those persons directly responsible for gathering the information, the information is, to the best of my knowledge and belief, true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possibility of fine and imprisonment for knowing violations. h zi 90 iq J n Hentges Date Manager Western North Slope Operations ConomPhillips Alaska, Inc. EPA Form 7520-8 Permit Number AK -11010-B CDI-01A October 2018 — December 2018 1iEPA United States Environmental Protection Agency Washington, DC W460 Injection Well Monitoring Report 2018 Month Month Month Injection Pressure (PSIG) 1. Minimum 2. Average 3. Maximum October November December 1,176 1,931 0 2,376 2,770 2,650 3,928 4,042 3,587 InjacHon Rate (GagMin) 1. Minimum 2 Average 3. Midmun 0.0 0.0 0.0 28.3 31.8 28A 143.7 261.3 144.8 Annular Pressure (PSIG) 1. Minimum 2. Average 3. Madmum 109 60 12 425 355 240 794 554 484 Injection Volume (Gel) 1. Monthly ToIal 2, Yearly CumulatIve 1,263,700 1,374,337 1,268,365 14,701,215 16,075,553 17,343,918 Temperature (FO) 1. Minimum Z Average 3. Madmum not required not required not required not required not required not required not required not required not required pH I. Minimum 2 Average 3. Madmum not required not required not required not required not required not required not required not required not required Other Name and Address of Permittee ConocoPhilli s Alaska, Inc., P.O. Box 100360, Anchorage, Alaska, 99510-0360 Permil Number AK -11010-8 Name and Offidel Tile (Places type orpnor) Ilnur MuetaSn, Production Optimization Coordinator Signature Dal.SiSigned —/ (12 'le1 EPA Fann ]fi20A (rev. 401) role - form recreated by CPAI M allow data only, we Pc (COI -01A) Note.' Please be advised that minimum injection pressures represent the minimum pressure observed at the wellhead during the applicable reporting period. A minimum injection pressure of greater than zero is possible (due to static pressure on the tubing string) even though there is no active injection into the well. Also, please be advised that the maximum injection rate shown in the report represents a maximum data point collected during the applicable reporting period. EPA Form 7520-8 Permit Number AK -1 1010-B CD1-01A January 2019 — March 2019 /y�y � 1/EPA United States Emkonmental Protection Agency N1eeMngton. DC 204(10 Injection Well Monitoring Report 2019 Month Month Month InjecOon Prewure(PSIG) 1. Minimum 2. Average 3. Medmum January Februwy March 166 0 0 2,703 2,787 3,027 3,953 3,932 4,042 Injection Rate (GaYMin) 1. Minimum 2. Average 3. Madmum 0.0 0.0 0.0 35.4 41.7 36.3 159.6 146.3 147.3 Annular Pressure (PSIG) 1. Mlnlmum 2. Average 3. Madman 0 2 0 152 150 224 474 558 4,366 Injection Volume (Gal) 1. MwthNTotal 2, Yearly Cumulative 1,577,893 1,679,915 1,615,308 1,577,893 3,257,809 4,873,117 Temperature (Fp) 1. Minimum 2. Average 3. Maximum not required not required not required not required not required not required not required not required not required pH 1. Minimum 2. Average 3. Madmum not required not required not required not required not required not required not required not required not required Other Name and Adhees of Permittee ConocoPhilli s Alaska, Inc., P.O. Box 100360, Anchorage. Alaska, 99510-0360 Peril Number AK -11010-B Name and Official Ttie(Please type orprinn Ilnur Mustafin, Production Optimization Coordinator Signature Date Sig/ned � ` 2 EPA Form 752e -a (rev. 9-91) nee, - form recreated by CPA to allox data entry via PG (CCI -01A) Note. Please be advised that minimum injection pressures represent the minimum pressure observed at the wellhead during the applicable reporting period. A minimum injection pressure of greater than zero is possible (due to static pressure on the tubing string) even though there is no active injection into the well. Also, please be advised that the maximum injection rate shown in the report represents a maximum data point collected during the applicable reporting period. Injection Pressure and Rate Monitoring Permit Number AK -11010-B CD1-01A Clarification of Data Date Time Comments 12/06/18 03:48 — 12:58 hrs Replaced check valve in flowline upstream of Surface Safety Valve 02/02/19— 02/03/19 19:52 —11:51 hrs Replaced spool piece of flowline upstream of Surface Safety Valve 03/01/19 08:13 hrs Performed Preventative Maintenance work on transmitters and gauges CD1-OlA 1017/2018 Through 10/10/2018 11:59:59 PM CD1-01A 10M V2018 Through 10/2012018 11:69:59 PM ILM 1-0 1 1X1[1 150[1 1. t ISO 1A 1 17-0 t ib t 16 1 2YCct CD1-01A 1012112018 Through 1018112018 11:69:59 PM 100 nA en t0 60 a 9 so 2 .0 as 20 10 OA too WO &0 ao 9.0 F so 4c .A 30 20 1.0 0A 100 00 80 10 Co 50 aA 30 20 1.0 00 CD141A 111112018 Through 11/1012018 11:89:89 PM ��Rntin MReutm am Rex �h� ,I I U 11 nun 1 ini I—LI _ 1Nw 2 N 3Nw 4 -Nm S.Nw SNd 7 -Nm AMm B.Nw 16Nm CD1-01A 11/11/2018 Through 11@01201811:59:59 PM 11-Nw 12Nw 13Nw 1"N I". I&Nw 1044w 1&Nw 1M. 20Nw CD7-81A 11/2112018 Through 11(3012018 11:59:59 PM too 0.0 so To eo So co 3.0 20 to 100 YD 9D 7.0 sa SD L C 10 ; 30 2.0 to 00 too 9.0 9.o 2.0 0.0 5 So d 1.0 3.0 2A 1.0 04 CD1.01A 1211/2018 Through 1211012018 11:59:59 PM —Nm....m yam n.0 lw•-hn.n-::..i... —ab. wa. 00 1-0 2-0x ]Oec 40ac 5-Oc &Or 7�5-0a 0.Dx 10-0so CD1.01A 12M112018 Through 121201201511:59:59 PM YAG 1000 0500 0000 u T zsaG y� 83W0 ,wo 1000 500 0 CD1-01A 1 212112 01 8 Through 121511201811:59:59 PM F�Nn..um ��m mssim N^� —am qm —m.ve l 100 sG 5.0 >0 to 5n ao . as zA 14 0.0 CD1-01A 1/112019 Through 1/10/2019 11:59:59 PM I. 2Jan 3JLn LJan sAn Nin ?� 0. n loJm 45 aaSD 3= 3= 4 2500 3 L 200D n 1500 1000 SOD 0 11 C01 -01A 1111/2019 Through 1/2012019 11:59:59 PM CD1-01A 112112019 Through 11311201911:59:59 PM ■�I■►'1■ITI lip No .� ...� I,. 3,0 11111111111111 111101111 ��II7'II1II1I1III Ioil, I RIM ■lill 'lllllll�l 7111.111, ., II�II��I�I� �li�ill�i ��` jI sill■I I. 2Jan 3JLn LJan sAn Nin ?� 0. n loJm 45 aaSD 3= 3= 4 2500 3 L 200D n 1500 1000 SOD 0 11 C01 -01A 1111/2019 Through 1/2012019 11:59:59 PM CD1-01A 112112019 Through 11311201911:59:59 PM 214M n& 23 w 2LJ 3&Ja 2&Js 27Jw 2BJan 2&Jm 3&Jw 31-Jm to.o 94 9.0 7.0 e.D SA 40 30 2.0 to OA 100 9A 9.0 74 SA 54 IA 39 2A 10 OA Ima 9n B.0 7A OA m Sn IA & 3.0 2A 1A Db ■�I■►'1■ITI lip No .� � 111101111 ��II7'II1II1I1III Ioil, I RIM ■lill 'lllllll�l 7111.111, 214M n& 23 w 2LJ 3&Ja 2&Js 27Jw 2BJan 2&Jm 3&Jw 31-Jm to.o 94 9.0 7.0 e.D SA 40 30 2.0 to OA 100 9A 9.0 74 SA 54 IA 39 2A 10 OA Ima 9n B.0 7A OA m Sn IA & 3.0 2A 1A Db CD1-01A 21112019 Through 21101201911:99:69 PM 1{eb 2i ]Feb 4�Feb 5 -re 6Feb ]FM 9 b &FN W. CD1.01A 2111/2019 Through 2/2012019 11:59:59 PM CD1-01A 212112019 Through 22912019 11:59:59 PM mo 9.0 9.0 zp 9.0 so oA . ao 24 to o9 toa 90 90 zo pA f 5.0 $� 4,0 so zo 10 oA 100 9.a 9A zo 9.0 So �,p u 30 2.0 1.0 00 m1wo W, ................ WHIPSf � I 1. 1{eb 2i ]Feb 4�Feb 5 -re 6Feb ]FM 9 b &FN W. CD1.01A 2111/2019 Through 2/2012019 11:59:59 PM CD1-01A 212112019 Through 22912019 11:59:59 PM mo 9.0 9.0 zp 9.0 so oA . ao 24 to o9 toa 90 90 zo pA f 5.0 $� 4,0 so zo 10 oA 100 9.a 9A zo 9.0 So �,p u 30 2.0 1.0 00 4600 4COi 3500 ][N g E 2000 d 1500 1000 Sao 0 1-Ny 2My 3AW I -My 5My &My )iM &IM PM. 10.Mer CDt-0tA 31112019 Through 3/10!2019 11:69:69 PM CD7.91A 3/11/2919 Through 3/20Im1911:59:59 PM Ilri , I IL''I III I�i17V I �:� �I11'111'i�lllill�illil�lililll'lil� �IIIIIIII!�I�dlllll�!ILII�II IYIY III. CD1-0tA 3/21/2919 Through 3/31/2019 11:59:59 PM 214 ar 2b r 2War 24 r 2 w 2 r 27 -My 2"ar 2 Mar "W 314 10.0 9.0 8.9 ).0 CO 5A 44 3.0 2A to DA ,DD 90 66 )A 6.0 f 50 4A 30 2.0 ,A DA 1A0 9A 6A ).0 0.0 f 50 4.0 3A 2.0 1A DA Summary of Significant Well Maintenance Permit Number AK -1 1010-B CD1-01A Date Description of Work EPA WITNESSED WATER FLOW LOG. NO INDICATION OF FLOW BEHIND CASING ABOVE PERFORATIONS. LOG SPINNER UP DOWN. 03/07/2019 40/80/120 FPM UP/DOWN, PUMPING 2.5 BBLS/MIN. PERFORM SPINNER STATIONS 9665, 9556, 9474, 9515, 9310. EPA WITNESSED (JASON SELITSCH/ EVAN OSBORNE) MIT -IA 03/06/2019 PASSED TO 4200 PSI. EPA WITNESSED TAG FILL EST. 9726' RKB. LOG CALIPER FROM 9625' 03/06/2019 RKB TO SURFACE. **GOOD DATA**. COMPLETE. PERFORMED FILL CLEANOUT FROM 9587' CTMD TO HARD TAG 9760' CTMD WITH SLICK SEAWATER AND DUO -VIS GEL SWEEPS AT 1.6 01/23/2019 BPM. MAINTAINED 1:1 RETURNS, LIGHT TO MODERATE SOLIDS IN RETURNS WITH SOME PEA SIZED SOLIDS. FREEZE PROTECTED TO 2500', TURN WELL OVER TO MI WIF FOR INJECTION ATTEMPT FILL CLEANOUT, TAGGED FILL AT 9587' CTMD, PUMPED 15 BBL WATER BASED GEL TO COIL AND PRESSURED UP TO 4200 PSI 01/22/2019 AT 0.3 BPM. POOH TO TROUBLESHOOT. SUSPECT PROBLEM WITH THE GEL OR NOZZLE PARTIALLY PLUGGED. RESTART IN THE AM TAG FILL @ 9504' RKB WITH 1.75" S.BAILER & 2.43" CENT. 12/22/2018 **RECOVERED SAMPLE OF MUD**. COMPLETE. Mechanical Integrity Testing Results Permit Number AK -1 1010-B CD1-01A United States Environmental Protection Agency Region 10 1200 Sixth Avenue, Suite 900 SenlOe. WA 98101 MECHANICAL INTEGRITY TEST(MIT)FORM Potillty well Permit No. I PTD No, IF CorlocoPhillips Alaska - Alpine/CRU CRU CD I -01A AK -11010-,5 1 211099 Injector MITType R Test Type Test Date ciao1 W Std. Annular Pressure Test(SAPT) 3/6/2019 Regd Test Prcsssure (psi) Ambient Temperature (F) Pecker Depth: Test Interval/Comments MD/TVD 4,200 20' 9793'/8M3 One Year Cycle , Iq P IN]. OR 51: 51 JBPD OR TIME SI: 6:00 AM 6• R TEST FLUID TYPE: Olestl BBIS fIUIDAWED: 35 E M I T PRE�MO PRESSURES E TIME 18:00 TUBING (Psi) 30M INNER ANNULUS(psi) 230 OUTERANNULLIS(Psl) 420 EPA Reps: // /J AOGCC Rep: Operator Rep: walvtd, e. eixbr �Pressure`must show stabilitin�te*ncy. See conditions of permit for specific criteria. Extend test duration to 60 minutes, it necessary, to eliminate thermal effects (on -s edslon Per Inspector). STARTTIME: RECORDED PRESSURES (P51) RESULT Manufacturer Type 18:13 INITIAL 15MIN 30 IN45 MIN 60 MIN T TUBING 3100 3080 30&0 E INNER ANNULUS 4,220 4,170 4,160 PASS 11 5 OUTER ANNULUS 630 630 630 T LOSS so 10 G COMMENTS: Permit Criteria as rolbws;(1) Total fess most be kss than IDs at the eM -fl W emoute test& Returns 12) Pressure fess In lost 15 minutes most be Ins than 33% of total kss. This MOW reflects results as (1),11%, 3,5 bM & 12). 16.7% EPA Reps: // /J AOGCC Rep: Operator Rep: walvtd, e. eixbr �Pressure`must show stabilitin�te*ncy. See conditions of permit for specific criteria. Extend test duration to 60 minutes, it necessary, to eliminate thermal effects (on -s edslon Per Inspector). Manufacturer Type Calibration Date MISC A TUBING Ashcroft Analog,%-Sk 1/29/2019 U INNER ANNUWS Ashcrok Analog, 0.51, 1/29/2019 G OUTER ANNULUS Ashcroft Analog, 0-3k 1/30/2019 E OTHER 5 OTHERCOMMENTS: ORD Personnel; Matt Miller/ Andrew Hembree EPA Reps: // /J AOGCC Rep: Operator Rep: walvtd, e. eixbr �Pressure`must show stabilitin�te*ncy. See conditions of permit for specific criteria. Extend test duration to 60 minutes, it necessary, to eliminate thermal effects (on -s edslon Per Inspector). EPA Form 7520-8 Permit Number AK -1 1003-C WD -02 October 2018 — December 2018 United States EmArnameaWl Protection Agency �'XiEPA Washingban,DC 20460 Injection Well Monitoring Report 2018 Montle Month Month Injection Pressure (PSIG) 1. Minimum 2. Average 3. Madmum October November December 1,245 1,147 1,348 1,509 1,530 1,571 1,719 1,751 1,758 Injection Rate (Gal/Min) 1. Minimum 2. Average 3. Maximum 0.0 0.0 0.0 25.4 26.5 29.3 155.6 76.3 88.3 Annular Pressure (PSIG) 1. Minimum 2. Average 3. Maaimum 728 673 759 899 884 935 1,021 1,024 1,101 Injection Volume (Gal) 1. Monthryrotal 2. Yearly Cumulative 1,135,147 1,145,742 1,307,776 13,444,376 14,590,119 15,897,895 Temperature (FO) 1. Minimum 2. Average 3. Mexvnum not required not required not required not required not required not required not required not required not required pH 1. Minimum 2. Average 3. Mabmum not required not required not required not required not required not required not required not required not required Other Name end Address of Permittee ConocoPhillips Alaska, Inc., P.O. Box 100360, Anchorage, Alaska, 99510-0360 Permit Number AK -11003-C Name anal Official Idle (Pease type orpnnn Ilnur Mustalm, Production Optimization Coordinator Signatu Dale Signed [ Z 4 9 EPA Form 7520-6 (rev. &91) We - brm resealed by CPAI to allay date entry As PC (W 02) Note: Please be advised that minimum injection pressures represent the minimum pressure observed at the wellhead during the applicable reporting period. A minimum injection pressure of greater than zero is possible (due to static pressure on the tubing string) even though there is no active injection into the well. Also, please be advised that the maximum injection rate shown in the report represents a maximum data point collected during the applicable reporting period. EPA Form 7520-8 Permit Number AK -1 1003-C WD -02 January 2019 — March 2019 United States Environmental Protection Agency %%EC�A Washington, OC 20460 PA Injection Well Monitoring Report 2019 Month Month Month Injection Pressure(PSIG) 1. Minimum 2. Average 3. Maximum January February March 1,386 1,381 -10 1,613 1,600 1,497 1,771 1,773 2,576 Injection Rate (Ga[ Min) 1. Midmum 2 Average 3. Maximum 0.0 0.0 0.0 33.1 31.1 31.4 63.4 63.9 96.3 Annular Pressure (PSIG) 1. Minimum 2. Average 3. Madmum 652 822 691 934 985 971 1,110 1,114 1,183 Injection Volume (Gal) 1. Mondtiy Total 2 Yearly Cumulative 1,477,222 1,252,167 1,399,200 1,477,222 2,729,390 4,128,590 Temperature (FO) I. Mirimum 2. Average 3. Maximum not required not required not required not required not required not required not required not required not required pH 1. Minimum 2. Average 3. Maldmum not required not required not required not required not required not required not required not required not required Other Name and Address or Pemitles ConocoPhilli s Alaska, Inc., P.O. Box 100360, Anchorage, Alaska, 99510-0360 Permit Number AK -11003-C Name and Official Title (Please type miumt)Sigrmtu Ilnur Mustafin, Production Optimization Coordinator Bate Signed 0! 2 EPA Form 7526d(mv. 9-91) note.tormre tedby CPMtodi wdalaenhyvla PC(W ) Note: Please be advised that minimum injection pressures represent the minimum pressure observed at the wellhead during the applicable reporting period. A minimum injection pressure of greater than zero is possible (due to static pressure on the tubing string) even though there is no active injection into the well. Also, please be advised that the maximum injection rate shown in the report represents a maximum data point collected during the applicable reporting period. Injection Pressure and Rate Monitoring Permit Number AK -1 1003-C WD -02 Clarification of Data Date Time I Comments Nothing to report Wo -0210/112018 Through 101102018 11:59:59 PM W"2 1011112018 Through 10/2012019 11:59:59 PM WD -02101212019 Through 101812918 11:59:59 PM 2400 2 t 20h1 V1 l 20 k MIX, 920[1 3i t 100 ep ep �o e0 U m Ip u 30 20 vo 0p 22m 21CIe1 6600 5[W 35x9 3 1500 1x66 600 0 1Jm 3JRn 31n JNn ¢Nn 6Jm ]Jan B -Jen 0 N 10Jn WD -02 111112019 Through 1/2012019 11:59:59 PM WD -02 11112019 Through 1110/2019 11:59:69 PM r-.m WR 11m "um —wv� —6m R,w —RRV Rw j 100 9.0 6A >9 6.0 60 6A LL 3,0 3A 14 OA 11Jr 1Nan 13Jan 1LJm lw_ 16Jm 17J. 18Jm IPJ. 2041n WD-02112IM19 Through 11111201911:99:59 PM �Ir1Pm IRnR �Mn%s 13M —MRm —emVM —PbzRN 100 9,0 90 )A 60 50 a L a9 n 00 2A 10 00 100 9.0 8.0 1.0 00 5.0 E rc t.0 1.0 3A lA OA 30W 25m 2 2500 1M3 SCO 0 liW 210 }FFD 4FC6 SieD SFM ]SFW 8{.D 0.FeD 16Fep WD -02 2111/2019 Through 2/20/2019 11:59:59 PM �Ip hFa lYn MnF�Ff IM DYFw NNRW—FM'flYl l 3500 3000 2500 g 2a0o a ISW 1a00 s00 0 I1{tl 12Stl 13Ftl IKtl IKtl 16FW 174tl t"tl tKtl MFW WD -02 211/2019 Through 211012019 11:59:59 PM 100 0D so ]o 00 F 50 A 3 3D 2D 19 00 WD -02 2212019 Through 212812019 11:59:69 PM —ip FFF u.a �mFs twa —iN F.r —amaze —Fu.as IDO c0 80 ]0 6.0 f 50 a F0 � 30 20 10 00 lao YD !D ?z ao 5o ao 30 2.0 +0 00 WD -02 31112019 Through 3110/2019 11:69:59 PM —ham lann—nnnhroum —,Mpm —un w.e. —FlwM 1 -Mx DMa JMat FMa SMx B'S1x �-Mr B -M: 0-0tr tOMar WD -02 3/1112019 Through 3120/2019 11:59:59 PM I 11. Ma, RM.r 1]". 1 11. SNa, inWr n#a, IB -M., IBMs 2omx WD -02 312112019 Through 313112019 11:59:59 PM 0 2,LY, 22Mu 2Y 1 26Ma 2SW, 26Mer 21-M., 26Mu 2P1Mr 20.Mfr 3~ III, .� a�.r --m_ (pill 11� �1 .,Tip �, IN 1 -Mx DMa JMat FMa SMx B'S1x �-Mr B -M: 0-0tr tOMar WD -02 3/1112019 Through 3120/2019 11:59:59 PM I 11. Ma, RM.r 1]". 1 11. SNa, inWr n#a, IB -M., IBMs 2omx WD -02 312112019 Through 313112019 11:59:59 PM 0 2,LY, 22Mu 2Y 1 26Ma 2SW, 26Mer 21-M., 26Mu 2P1Mr 20.Mfr 3~ Summary of Significant Well Maintenance Permit Number AK -1 1003-C WD -02 Date Description of Work 03/07/2019 EPA WITNESSED (JASON SELITSCH/EVAN OSBORNE) MIT -IA PASSED TO 3510 PSI. 03/07/2019 TAGGED @ 9888' RKB (EPA WITNESSED). COMPLETE. Mechanical Integrity Testing Results Permit Number AK -1 1003-C WD -02 '^• United States Environmental Protection Agency I Region 10 •�F!d 1200 Sixth Aven ue, So ite 900 Seattle, WA 9810( MECHANICAL INTEGRITY TEST (MIT) FORM Facility I Well Permit No. PTD No. ConacoPhilliIRS Alaska - Alpine/CRU CRU WD -02 AK -11003-8 198-258 Infector MITType e Packr Depth: MD/ Tivro Test Type Test Date Class IA Std. Annular Pressure Test(SAPT) 3/7/2019 Req'd Test PfessSare(psl) Amblent Temperature(l) e Packr Depth: MD/ Tivro Test Interval/Comments 3,500 HI' 932V No One year Cycle P IJ1 OR 51: 51 JBPD OR TIME 51: 3/6/7019 AM It TEST FL!!!a JBBISFLLRDADDEDR 3 E M I T PRE -MIT PRESSURES E ME 6:37 TUBING (psi) 1060 INNERANNULUS(psi) 1140 OUTER ANNULUS (psi) 535 EPA Rep: AOGCC Rep: Operator Rep: Bixby eliminate thermal effects (an-sltpAecision per Inspector). STARTTIME: RECORDED PRESSURES (PSI) RESULT Calibration Date MISC 6:36 AM INITIAL ISMIN 30MIN 45 MIN 60MIN T TUBING 1060 1060 1060 E INNER ANNULUS 3,510 1 3,440 1 3,430 1PASS 5 OUTERANNULUS 540 S60 SW T LOSS 70 1 10 COMMENTS: Permit tousle as inflame, (1) Total loss most be less than IM at the end of a 30 minute test. a Returns (2) Pressure loss in last 15 minutes must be less than 33% of Who loss. This MNlA reflex(, sew its as (1), 3.0 bbl 2%, A(1,12.S% EPA Rep: AOGCC Rep: Operator Rep: Bixby eliminate thermal effects (an-sltpAecision per Inspector). Manufa,tvrer Type/Snip/Inc Calibration Date MISC A TUBING Ashcroft Analog, 0-Sk 1/29/1019 U INNERANNULUS I Ashcroft Analog, U-51, 1/19/2019 G OUTER ANNULUS Ashwlt Analog 0-31, 1/30/2019 OTHER 5 OTHER COMMENTS: On 3-6-19, LRS Pumped 200 BBI Bleach down the cutting for displacement followed by 25 BBL diesel for freeze protect. DHD Personnel; Matt Miller /Andrew Hembree 17 EPA Rep: AOGCC Rep: Operator Rep: Bixby eliminate thermal effects (an-sltpAecision per Inspector). Injected Fluid Characteristics Permit Number AK -11 1003-C (WD -02) Permit Number AK -1 1010-B (CD1-01A) Class I UIC Waste Analysis Sampling — 2018 & 2019 Non -Exempt Typical Waste StreamsNon-Exempt' Sources Location/Date Sampled Sample Result Sewage / sludge (Grey Waste water plant treated effluent 1/24/19 Passed water) K -Pad Effluent 9/6/18 Passed 4/14/18 Passed 1/8/18 Passed Sump fluids/ Sump solids J8 Shop Sump fluids 6/18/18 Passed J8 Shop Sump solids 6/18/18 Passed Glycol / heat exchange J8 Shop Glycol 1/14/19 Passed media D19 Rig Glycol 6/18/18 Passed 2/4/18 Passed Parts Washer D19 2/10/19 Passed 2/4/18 Passed Photo processor fluid KAKAVIK Not generated N/A Non-exempt spill clean-up ACS spill bin solids and liquids 2/1/18 Passed 5/24/18 Passed 7/18/18 Passed 10/16/18 Passed Hydrotest fluid Operations Hydrotest Water 5/30/18 Passed (water or glycol only) Boiler blow down D19 Boiler Blowdown 1/14/19 Passed 2/4/18 Passed Off spec product No off spec product generated as a waste Not generated N/A Non-exempt drilling, well No non-exempt drilling, well work materials Not generated N/A work materials generated as a waste— nothing to sample Turbine wash water E2 Turbine Wash Water 7/23/18 Passed Contained snow / ponded J6/J7 containment 7/1/18 Passed water Non-exempt rinsate/ wash Tank Rinsate—WAW5206 Not generated N/A water Well Strainer solids MI Strainer Solids 6/26/18 Passed Car Wash sump solids and Truck Wash Station Liquids 8/1/18 Passed liquids Truck Wash Station Solids - 8/1/18 1 Passed I. Note that similar wastes may be RCRA exempt, depending on waste -generating process. Raw Data Permit Number AK -1 1003-C (WD -02) Permit Number AK -1 1010-B (CD1-01A) Please see accompanying CD for raw data Other Reports Permit Number AK -1 1003-C (WD -02) Permit Number AK -11010-B (CD1-01A) No Other Reports Included • Page 1 of 2 • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, January 16, 2013 8:54 AM To: 'Bearden, Daniel D' Cc: Wallace, Chris D (DOA); Senden, R. Tyler Subject: RE: CD1 -01 (PTD 199 -046) Dan, Thanks for the updated info. In the future make sure any wellhead changes (wellhead swaps or packoff change outs) are included in the sundry or PTD application. After looking at the wellhead diagram it appears the 40" tall section which includes the horizontal outlet, IA valves and tubing hanger was changed out for a new Gen II. My first instinct was to think that you were completely changing out the out lower wellhead section for 7" casing (where the 7" casing lockdown pins are located) which was not the case. Can you confirm that for me? Guy Schwartz SCANNED APR 342013 Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Bearden, Daniel D [mailto:J.Daniel .Bearden @conocophillips.com] Sent: Tuesday, January 15, 2013 3:42 PM To: Schwartz, Guy L (DOA) Cc: Wallace, Chris D (DOA); Senden, R. Tyler Subject: RE: CD1 -01 (PTD 199 -046) Guy, Attached is FMC's drawing of our new FMC Gen II installed on CD1 -01A. The drilling program had a note to inspect the existing 7" casing packoff in the wellhead housing. Upon inspection, it was found to be not compromised. However, to provide the Asset with a brand new well with many years of future utility, it was decided to change out the wellhead. I've also included a schematic of the As -built CD1 -01 Rig Abandonment (immediately prior to starting on the Sidetrack PTD #212 -099). Let me know if this answers your questions, Daniel Bearden Drilling Engineer ConocoPhillips, Alaska 907 - 263 -4864 work 907 - 602 -7068 cell From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Tuesday, January 15, 2013 2:51 PM To: Bearden, Daniel D Cc: Wallace, Chris D (DOA) Subject: [EXTERNAL]RE: CD1 -01 (PTD 199 -046) Dan, 1/16/2013 • • Page 2 of 2 Also, the wellhead was swapped from FMC Gen I to II. This should have been part of the procedure from the rig operation. It was not on the Sundry 312 -276 or the drilling procedure. The fact that this is a high profile Class 1 disposal well should also flag that any wellhead changes should be discussed with the Commission. I assume this a 11" 5000 psi unihead? Though I am not sure what the difference is from Gen I to II ... Please supply a new wellhead drawing w/ injection tree ... I have some generic ones on file but we should have exatly what is on this well for our wellfile. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Schwartz, Guy L (DOA) Sent: Tuesday, January 15, 2013 2:21 PM To: 'Bearden, Daniel D' Subject: CD1 -01 (PTD 199- 046) Danny, I got the P & A report for CD1 -01. It should include a current schematic showing actual cement placement just before the sidetrack. The proposed schematic is close but please submit a updated vs. so I can put in the well file. Also , in this case a lot of rig work was part of the P & A .... Up to drilling the surface plug and starting the sidetrack for CD1 -01A.. I copied the daily log from the other 407 (CD1 -01A ) for those days but in the future make sure all the relevant work ( daily reports) is included for the P & A report. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 1/16/2013 •olville River Field Actual CD1 -01 Alpine Injector Rig Abandonment Schematic RKB - GL = 37' Bearden - 1/15/13 iiiii A € € 's , 16" Conductor to 114' ^ LfiA . Port Collar TAM n y^ n Pt �� J I / -Y (Q 1000' � / 7� 1(6. '5 , Top of cement plug @ 2078' MD (57 bbl Class G @ 17.0 ppg) Cut #2 @ 2259' MD 9 �. �b �i'iIiiiiii?' :111:11::::::: 7" Casing • • 9 -5/8" 36# J -55 BTCM .... ! t?l (. � Surface Casing @ 2411' MD / 2395' TVD ` < `: 10: :i cemented to surface 7" Casing Cut #1 @ 2,650' MD lilk 4 CIBP at 2,720' MD 9.8 non KCI /NaC! bring' 4 Cut 4.5" Tubing @ 2,913' MD 100 bbls Dead crude freeze protect on top of KWF. Well loaded from top of cement plug with ,. , .1 } , 150 bbls corrosion inhibited 12.2 ppg KWf (top 4150' MD). Top of tubing P &A plug @ 5,792' SLM 20 bbls 15.8 Class G pumped at 7,160' MD into TBG 8/12/12 _Top of casing P &A plug @ - 6,084' MD 20 bbls 15.8 Class G pumped into IA 8/12/12 15.8 ppg Class G cement Baker S -3 Packer @ 7179' MD. TOC @ +/ -6800' / 6611' TVD ,` (top quality cement from "4111" T to / USIT /28 99 9 � 44i i 'l."�. :_::. „ » > : 6-1/8” Openhole completion interval '*V 1 i 1 Ptllttl 800 2 iiiitillin Well TD at 10289' MD / 6954' TVD 7" 26# L -80 BTC Mod Production Casing @ 7752' MD / 6991' TVD @ 94 deg • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL C ❑ MPLETIO ❑ COMPLETION OR ❑ RECO AND LOG la. Well Status: oil ❑ 20AAC 25.105 20AAC 25.110 1 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No. of Completions: /,t 5.13 Service El ' Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. o Aband.• October 3, 2012 199 - 046 / 312 - 276 3. Address: 6. ate Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 May 31, 1999 50 103 - 20299 - 00 - 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 222' FNL, 2708' FEL, Sec. 5, T11N, R5E, UM June 27, 1999 CD1 - 01 - Top of Productive Horizon: 8. KB (ft above MSL): , 56' RKB 15. Field /Pool(s): 1102' FSL, 2424' FEL, Sec. 32, T12N, R5E, UM GL (ft above MSL): , 37' AMSL . Colville River Field . Total Depth: 9. Plug Back Depth (MD + TVD): 1569' FNL, 1501' FWL, Sec. 32, T12N, R5E, UM • 2078' MD / 2062' TVD Alpine Oil Pool' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: , Surface: x 386000 y 5975905 Zone 4 10289' MD / 6954' TVD ADL 25559, 25558 TPI: x - 386299 y - 5977224 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 384976 y 5979853 Zone 4 nipple @ 1017' MD / 1010' TVD na 18. Directional Survey: Yes ❑ No 0 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A • (ft MSL) ' 1574' MD / 1556' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re - drill /Lateral Top Window MD/TVD none not applicable 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H -40 36' 121' 36' 121' 42" 9 cu yds High Early 9.625" 36# J -55 38' 2411' 38' 2395' 12.25" 520 sx ASIII LW, 230 sx Class G 7" 26# L -80 35' 7752' 35' 6991' 8.5" 165 sx Class G 24. Open to production or injection? Yes ❑ No 0 If Yes, list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) none none open hole completion 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. RECEIVED hydraulic fracturing used during completion? Yes ❑ No 0 DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED NOV 2 8 2012 retainer@ 7260' aoP) 664rcement ( 4 ®GCC 2078' -2719' 318 sx Class G 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) plugged Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS - OIL RATIO Test Period - -> Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No Q Sidewall Cores Acquired? Yes ❑ No El If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. NONE tiaC NOV 2 810 . 1 Form 10-407 Revised 10/2012 CONTINUED ON REVERSE ( • ! j 1, Submit original onl 29. GEOLOGIC MARKERS (List all formations and ma fR@fs encountered): 30. • FORMATION TESTS NAME MD TVD Well tested? ri Yes 0 No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1574' 1556' needed, and submit detailed test information per 20 AAC 25.071. not applicable N/A Formation at total depth: na 31. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Dan Bearden @ 263 - 4864 Email: J.Daniel.Bearden ceconocoohillios.com _1 Di Printed Name G. L. Alvord Title: Alaska Drilling Manager /// Signature / . 6, at Phone 265 - 6120 Date (t1 12 // 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. Submit a well schematic diagram with each 10-407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item la: Classification of Service wells: Gas injection, water injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 10/2012 • -01 Pre Rig Well Work Summary DATE SUMMARY 7/24/12 PULLED A -1 INJ. VALVE (HWS -30) @ 1013' RKB, DRIFT TBG TO 7481' SLM, TAG XN © 7255' RKB, MEASURED BHP @ 7501' RKB / 7205' RKB (MAX PSI 4362 / TEMP 142.04 *F), ATTEMPT TO SET CAT SV. IN PROGRESS 7/25/12 BRUSH & FLUSH TBG_,SE T CAT SV IN XN NIP @ 7255' RKB, MIT TBG. PASSED, MIT -IA PASSED, BAILED FILL ON CAT SV. IN PROGRESS. 7/26/12 BAILED FILL ON TOP OF CAT SV, PULLED CAT SV © 7255' RKB. COMPLETE. 8/4/12 MOBILIZE TO ALPINE CAMP, PREP EQUIPMENT FOR CD1 -01 8/5/12 PERFORATED TUBING 7172' -7178' AND 7163' -7168' WITH 2" CIRCULATION CHARGES, 4 SPF, 0 DEG PHASED. POSITIVE INDICATION OF TUBING /IA COMMUNICATION 8/12/12 RIH, LOCATED XN NPL @7250' CTMD, CORRECT DEPTH TO 7255' RKB, SET RETAINER AT 7260' RKB, RIH W/ BHA #2, STAB INTO RETAINER AT 7260' RKB, PERFORM INJECTIVITY TEST @ 2 BPM/2150 CTP, PUMPED 66 TOTAL BBLS CMT, 25 BBLS CMT BELOW RETAINER, UNSTING AND PUMP 20 BBLS CMT INTO THE IA, LAY IN 21 BBLS CMT IN TBG FROM 7260' TO 5835' RKB HOLDING 1:1 RETURNS, F/P TBG FROM 3000', READY FOR SLICKLINE, JOB IN PROGRESS. CEMENT REPORT IN ATTACHMENTS. 8/14/12 STATE WITNESSED MIT -T TO 2140 psi. LOST 140 psi IN 30 MIN. * *PASS * *. MIT -IA TO 2200 psi. LOST 140 psi IN 30 MIN. TAG CEMENT TOP A 5792' SLM w/ 2.71" CENT & 1.75" S.BAILER. OBTAINED SAMPLE. GAUGE TBG TO 3.795" TO 5788' SLM. READY FOR E -LINE. 8/15/12 SHOT HOLES IN TUBING AT A DEPTH OF 5725' -5730' US(NG 2" X 5' GUN LOADED WITH 6 SPF, 60 DEG PHASING, BIG HOLE CIRCULATION CHARGES. TUBING AND IA PRESSURES EQUALIZED AFTER SHOT WAS MADE VERIFING HOLES. WILL RETURN TOMORROW TO MAKE TUBING CUT. LRS WILL CIRCULATE 150 BARRELS OF CORROSION INHIBITED 12.2 PPG KWF THROUGH HOLES. FOLLOWED BY 100 BBLS DEAD CRUDE FOR FREEZE PROTECT. 8/16/12 CUT 4.5" TUBING USING RADIAL CUTTING TORCH (RCT 2937 -200) AT A DEPTH OF 2900'. USED EMA TO DEPLOY ANCHOR SYSTEM. INDICATIONS ON SURFACE LOOKED LIKE A POSITIVE CUT. RIG WILL HAVE TO VERIFY. • • ConocoPhillips Time Log & Summary We!Mew Web Reporting Rep Well Name: CD1 - 01 Rig Name: DOYON 19 Job Type: DRILLING SIDETRACK Rig Accept: 9/25/2012 6:00:00 PM Rig Release: 10/30/2012 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09/24/2012 24 hr Summary Shut down hi -line power, disconnect, blow down steam and water, pull Hi line cable. Move MI Swaco ball mill to end of pad, move pits /motors, skid rig floor, move mats, PU windwalls in cellar and feet under canter lever, Move rig forward off of well CD1 -22B to clear the cellar area. Prepare to take down side cellar wind walls, to be replaced with other side windwalls to fit 10' spaced wells centers. 18:00 19:45 1.75 0 0 MIRU MOVE RURD P Shut down Hi -Line power, disconnect. Blow down steam and water, pull high line cable. 19:45 21:00 1.25 0 0 MIRU MOVE SKID P Skid rig floor off of cantilever to center of module. Move and set mats. 21:00 21:30 0.50 0 0 MIRU MOVE MOB P Move MI Swaco Ball mill to end of pad. Prepare to move Pits /motors to end of pad. 21:30 23:00 1.50 0 0 MIRU MOVE MOB P Move Pits and motors to end of pad by well CD1 -01. Pick up cellar wind walls. Pick up feet under cantilever. 23:00 23:30 0.50 0 0 MIRU MOVE MOB P Jack up, then drive sub ahead to clear cellar of the well row. 23:30 00:00 0.50 0 0 MIRU MOVE RURD P Prepare to remove upper side windwalls in the cellar. Will install windwalls in cellar area which work for 10' well spacing. 09/25/2012 PJSM, work on hanging windwalls in cellar area f/ 10' spaced well, continue moving rig f/ CD1 -22B to CD1 -01, spot over hole, set down, skid rig to drilling position, move pits /mtrs, rig up service lines, move MI Swaco ball mill. Rig up double valves on both annulus's, Rig up tiger tank and 2" hardline. Test lubricator to 250/2000 psi. Pull BPV, close master valve. Rig down lubricator. Continue to rig up lines f/ displacement. Rig accepted @ 1800 hrs 9/25/2012. Tubing press was 150 psi, bled down to zero. IA was 220 psi, OA was 600 psi. Rig floor to ground level was 36.29', lower lock down screws was 33.90', upper lockdown screws 31.92'. 00:00 00:15 0.25 0 0 MIRU MOVE SFTY P Pre job safety meeting on working windwalls in cellar area of rig. 00:15 01:30 1.25 0 0 MIRU MOVE RURD P Remove upper side windwalls in the cellar. Will install windwalls in cellar area which work for 10' well spacing. 01:30 01:45 0.25 0 0 MIRU MOVE SFTY P Pre job safety meeting on installing wind wallas which work on 10' spaced wells. 01:45 10:30 8.75 0 0 MIRU MOVE RURD P Install wind walls in cellar, using loader and man lifts. 10:30 10:45 0.25 0 0 MIRU MOVE SFTY P Pre job safety meeting on moving rig to CD1 -01. 10:45 12:00 1.25 0 0 MIRU MOVE MOB P Jack up Rig, move from in front of CD1 -22B to CD1 -01. 12:00 15:00 3.00 0 0 MIRU MOVE MOB P Turn tires, spot sub over well. Shim up sub to level. Page 1 of 41 • Time Logs Date From To Dur S. Depth E. Depth Phase Code _Subcode T Comment 15:00 16:00 1.00 0 0 MIRU MOVE RURD P Set support feet under cantilever - preload same. Lower cellar back wind walls. 16:00 16:15 0.25 0 0 MIRU MOVE SFTY P Pre job safety meeting on skidding rig floor and moving pits /mtrs. 16:15 17:00 0.75 0 0 MIRU MOVE SKID P Skid rig floor to drilling position. 17:00 17:45 0.75 0 0 MIRU MOVE MOB P Continue to move pits and motors. Set down 17:45 18:00 0.25 0 0 MIRU MOVE RURD P Hooking up steam, mud and water lines. Rig accepted @ 1800 hrs on 9 -25 -2012. 18:00 19:30 1.50 0 0 MIRU MOVE RURD P Continue to hook up service lines. Rig on hi -line @ 1915 hrs. Sim Ops: PJSM on moving MI Swaco Ball mill. 19:30 22:00 2.50 0 0 MIRU MOVE RURD P Prepare Pits and mud pumps for fluids. Sim ops: Move and set MI Swaco ball mill. Set @ 2000 hrs. Install double valves on the IA and OA. Install tree work platform. Rig up 2" hardline f/ IA to choke skid, then to tiger tank. Rig bleed line to the pits. Load 219 bbls of 9.8 ppg brine into pits. 22:00 23:15 1.25 0 0 SLOT WELCTL DHEQ P Rig up FMC lubricator, test to 250 psi low and 2000 psi high. Hold each test 5 minutes. Chart test. RKB to upper LDS= 31.97, LLDS= 33.90', GL= 36.29' Tubing pressure = 150 psi, IA pressure 220 psi, OA pressure = 600 psi. 23:15 00:00 0.75 0 0 SLOT WELCTL MPSP P Retrieve BPV, lubricator guage reading 150 psi. Bleed 150 psi (gas) f/ tubing to zero. Close master valve. Rig down lubricator. Install tree cap w/ 2" 1502 union. 09/26/2012 RU 2" lines to displace freeze protect fluid to 9.8 NaCI brine. PT lines to 2000 psi. PJSM, RU standpipe and kelly hose back up in the derrick. PJSM, Displace out 100 bbls dead crude with 143 bbls of 125 deg seawater and 110 bbls 9.8 brine through tbg cut at 2900'. Monitor tbg and annulus for 30 mins. Well is static. Install BPV. Pressure annulus to 1500 psi for 10 mins to test BPV -Good. PJSM, ND tree, Install blanking plug. MU Landing jt. Counted 8 turns to screw into blanking plug. Mark landing jt at rotary table. Remove landing jt. NU BOPE, RU/Test BOPE w/ 4 -1/2" test joint(witness of test waived by AOGCC insp Bob Noble). R/D test joint, Pull blanking plug, Pull BPV. 00:00 01:30 1.50 0 0 SLOT WELCTL RURD P Rig jap 2" hardlines to displace freeze, protect crude to 9.8 ppg NaCI brine. 01:30 01:45 0.25 0 0 SLOT WELCTL SFTY P Pre job safety meeting on testing lines to 2000 psi (Tubing and annulus lines to tiger tank). 01:45 02:00 0.25 0 0 SLOT WELCTL PRTS P Test lines to tubing (master valve closed), test line to tiger tank. Test to 2000 psi f/ 5 minutes. Chart tests. 02:00 02:15 0.25 0 0 SLOT WELCTL SFTY P Pre job safety meeting on installing stand pipe and kelly hose back in the derrick. Heating water f/ 70 deg to 125 deg. Page 2 of 41 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:15 07:45 5.50 0 0 SLOT WELCTI RURD P Install stand pipe w/ extra fitting for Baker on the next well. Connect Kelly hose to the standpipe. Heating water for flush ahead of 9.8 ppb NaCI brine. 07:45 08:00 0.25 0 0 SLOT WELCTL SFTY P PJSM on displacing well to brine. 08:00 10:00 2.00 0 0 SLOT WELCTICIRC P Displace out 100 bbls dead crude with 143 bbls of 125 deg seawater and 110 bbls 9.8 brine through tbg cut at 2900'. 10:00 10:30 0.50 0 0 SLOT WELCTL OWFF P Monitor tbg and annulus for 30 mins. Well is static. 10:30 11:15 0.75 0 0 SLOT WELCTI OTHR P Blow down and RD lines to tiger tank. 11:15 12:00 0.75 0 0 SLOT WELCTI DHEQ P Install BPV. Pressure annulus to 1500 psi for 10 mins to test BPV. Good test. 12:00 12:15 0.25 0 0 SLOT WHDBO SFTY P PJSM on ND tree. 12:15 13:15 1.00 0 0 SLOT WHDBO NUND P RD hardlines. ND tree. 13:15 13:45 0.50 0 0 SLOT WHDBO OTHR P Install blanking plug. MU Landing jt. Counted 8 turns to screw into blanking plug. Mark landing jt at rotary table. Remove landing jt. 13:45 14:00 0.25 0 0 SLOT WHDBO SFTY P PJSM on NU BOPE. 14:00 16:15 2.25 0 0 SLOT WHDBO NUND P NU BOP's. Change out 3" camlock for drain hose. Install riser, flowline, hole fill lines and turnbuckles. 16:15 16:30 0.25 0 0 SLOT WHDBO SFTY P Pre job safety meeting on rig up and test ing BOPE. 16:30 17:00 0.50 0 0 SLOT WHDBO RURD P Rig up for BOPE test. Page 3 of 41 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 23:00 6.00 0 0 SLOT WHDBO BOPE P_ Test BOPE w/ 4 -1/2" test ioint. Witness of test waived by AOGCC inspector Bob Noble. Tested annular to 250 psi low and 2500 psi high. Tested all valves in the choke manifold, kill line valves (including 4" Demco), choke lines valves, top and bottom pipe rams and blind rams to 250 psi low and 4000 psi high. Tested upper IBOP and manual IBOP on the top drive. Tested the full open floor safety valve and IBOP to 250 psi and 4000 psi. All tests were held f/ 5 minutes. Charted tests. Tested the accumulator: Full charge 295 psi, after closure 1500 psi, 200 # build up in 42 sec, full charge in 213 seconds. Perform Poor Boy gas buster flush, then pumped through both chokes in the choke manifold, restricting flow @ 1 bpm- choking flow to 1000 psi. Check PVT system for trip tank and pit #6. Alarms worked. Flow indicator woked. Electrician tested methane and H2S alarms on the rig. 23:00 23:15 0.25 0 0 SLOT WHDBO RURD P Blow down choke manifold and testing equipment. Line up choke in drilling position. 23:15 00:00 0.75 0 0 SLOT WHDBO PULL P Engage FMC blanking Plug, turn 16 turns to the left, remove blanking plug. PU dry rod to pull FMC BPV. Pull BPV. 09/27/2012 RU /MU landing jt "A ", BOLDS, unseat FMC hanger w/ 120k, monitor- static, PU /LD FMC hanger, MU x -o, test kelly hose to 3500 psi, circ 155 bbls, POOH UD 91 jts of 4 -1/2" 12.6 ppf L -80 tubing+ pup -DB nipple -pup+ 16.69' cut jt (2912.84' SLM). Clear floor, monitor- static, drain stack RU/Test top & bottom rams + annular w/ 4" test jt, test accumulator. RD test equip, set wear bushing. MU BHA #1 (7" scraper, RIH to 2762', circ, POOH, LD scraper, MU 7" CIBP (BHA #2), RIH set w /center of element © 2720', test to 2550 psi -good, CBU, POOH, UD scraper, MU 7" casing cutter (BHA #3). 00:00 00:15 0.25 0 0 SLOT RPCOM SFTY P Pre job safety meeting on rigging up to UD tubing. 00:15 00:30 0.25 0 0 SLOT RPCOM RURD P Install 4 -1/2" tubing elevators. Install mouse hole. Rig up tubing tongs. 00:30 00:45 0.25 0 0 SLOT WHDBO OTHR P Pick up/ make up landing joint "A ". Screw into FMC 4 -1/2" hanger. Back out lock down screws. 00:45 01:00 0.25 2,912 SLOT RPCOM PULL P Pick up on 4 -1/2" 12.6 ppf L -80 IBT -m tubing, pulled free w/ 120k. then fell off to 98k. 01:00 01:15 0.25 2,912 2,869 SLOT RPCOM PULL P Pre job safety meeting. Pull hanger to the floor. Lay down landing joint "A ". Lay down hanger. 01:15 01:30 0.25 2,869 2,869 SLOT RPCOM SFTY P Pre job safety meeting. Page 4 of 41 Time Logs Date From To Dur S. Death E. Death Phase Code Subcode T Comment 01:30 02:00 0.50 2,869 2,869 SLOT RPCOM CIRC P Make up crossover f/ 4 -1/2" IBT to 4" XT39. Make a top drive connection. Test kelly hose to 3500 psi. Circulate @ 7 bpm w/ 210 psi, 8 bpm w/ 300 psi and final of 10 bpm w/ 320 psi. Circulated 155 bbls. Break crossover, blow down the top drive. 02:00 02:15 0.25 2,869 2,869 SLOT RPCOM SFTY P Pre job safety meeting. 02:15 05:00 2.75 2,869 0 SLOT RPCOM PULL P Pull out of the hole w/ 4 -1/2" 12.6 ppf L -80 completion f/ 2869' . Monitor well on the trip tank. Recovered 91 full jts, pup -DB nipple -pup + 16.69' cut off joint (total length RKB+ hanger+ 91 jts, pup /DB nipple /pup+ cut off jt = 2912.84' SLM). 05:00 05:45 0.75 0 0 SLOT RPCOM RURD P Clean and clear rig floor. Rig down tubing handling equipment. 05:45 06:00 0.25 0 0 SLOT WHDBO OWFF P Monitor well- static. Drain stack, install FMC upper test plug. 06:00 06:15 0.25 0 0 SLOT WHDBO SFTY P Pre job safety meeting. 06:15 06:30 0.25 0 0 SLOT WHDBO RURD P Rig up to test BOPE w/ 4" test joint. 06:30 08:15 1.75 0 0 SLOT WHDBO BOPE P Test BOPE w/ 4" test joint. Test the annular to 250 psi low and 2500 psi high. Test top pipe rams and lower pipe rams to 250 psi low and 2500 psi high. Hold each test f/ 5 minutes. Charted tests. Tested accumulator. Rig down testing equipment. 08:15 09:00 0.75 0 0 SLOT WHDBO OTHR P Pull test plug. Install wear bushing with 9" ID. 09:00 10:30 1.50 0 0 SLOT CSGRC' PULD P Moblilize BHA components to rig floor. 10:30 11:30 1.00 0 191 SLOT CSGRC' PULD P MU 7" scraper BHA to 191'. 11:30 13:15 1.75 191 2,762 SLOT CSGRC' TRIP P RIH with scraper assemble on 4" DP to 2762'. 13:15 14:00 0.75 2,762 2,762 SLOT CSGRC' CIRC P Circulate at 600 gpm -1900 spi - 20 rpms from 2762 to 2667'. Up wt 112k - Dn wt 110k. Torque - 4k 14:00 14:15 0.25 2,762 2,762 SLOT CSGRC' OTHR P Flow check well - Static. Blow down top drive. 14:15 15:45 1.50 2,762 191 SLOT CSGRC' TRIP P POH on trip tank from 2762' to 191'. 15:45 16:00 0.25 191 0 SLOT CSGRC' PULD P Lay down 7" scraper. PU Baker K -1 Mech Cement retainer to rig floor. 16:00 16:15 0.25 0 0 SLOT CSGRC' SFTY P Pre job safety meeting on PU /MU Baker K -1 cement retainer (CIBP). 16:15 19:30 3.25 0 2,676 SLOT CSGRC' TRIP P Make up 5.7" OD cement retainer, (� Run in the hole to 2721' (center of Cif '✓ element @ 2720'). PU wt 112k, SO wt 110k. Rotate 10 turns to the right w/ 4k ft lbs of torque. Pull 30k over to 142k, Slack off 30k to 80k, repeat a total of 3 times, PU to neutral, rotate 10 more turns. Pick up f/ 2720' to 2676'. Page 5 of 41 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:30 19:45 0.25 2,676 2,676 SLOT CSGRC' SFTY P Pre job safety meeting on rig up to test. OA pressure 700 psi. 19:45 20:15 0.50 2,676 2,676 SLOT CSGRC' RURD P Rig up to test CIBP to 2500 psi. 20:15 20:45 0.50 2,676 2,676 SLOT CSGRC' DHEQ P Test 7" CIBP and 7" casing, pumping down the drill string and through the kill line. Pressure to 2650 psi, held for 8 minutes, realized that a 10 minute test was not performed, shut back in w/ 2550 psi on test. Continued to test f/ 10 minutes with 2550 psi. Charted test w/ no bleed off. 20:45 21:00 0.25 2,676 2,676 SLOT CSGRC' CIRC P Circulate bottom's up, pumping 588 gpm w/ 1870 psi. 21:00 21:30 0.50 2,676 2,676 SLOT CSGRC' RURD P Blow down lines. Rig down testing equipemnt. Monitor well- static. 21:30 23:15 1.75 2,676 0 SLOT CSGRC' TRIP P Trip out of the hole f/ 2676' to Baker running tool. 23:15 00:00 0.75 0 0 SLOT CSGRC' PULD P Lay down running tool (BHA #2). Pick up/ make up BHA #3 (Casing cutter). OA pressure @ 2315 hrs was 275 psi. 09/28/2012 RIH w/ BHA #3(7" casing cutter), cut casing @ 2650' & 2250', displ 9 -5/8" x 7" to 9.8 ppg NaCI, monitor well - static, POOH, UD cutter, change top pipe rams to 4 -1/2" x 7 ", test top pipe and annular w/ 7" & 5 ", replace kill line HCR valve , test HCR w/ 5 ", test floor safety valve & IBOP, Pull FMC 7" packoff, install thin wear bushing, MU 7" casing spear BHA. 00:00 00:15 0.25 0 0 SLOT CSGRC' SFTY P Pre job safety meeting on running in the hole w/ Baker casing cutter. 00:15 01:15 1.00 0 2,719 SLOT CSGRC' TRIP P Trip in w/ casing cutter to 2719'. PU 110k, SO wt 105k. 01:15 01:30 0.25 2,719 2,719 SLOT CSGRC' TRIP P Tap the CIBP w/ casing cutter A 2719'. 01:30 02:00 0.50 2,719 2,650 SLOT CSGRC' TRIP P Set back stand # 29 f/ 2719' to 2679'. Make a top drive connection, then pick up to 2583', slack off to 2609', start pumping 2.5 bpm w/ 240 psi, slack off to locate a collar @ 2621'. Shut down pump, then slack off to 2655', start pumps @ 2.5 bpm w/ 240 psi to locate a collar @ 2661'. r on depth Get cutters o dep @ 2650'. Bleed OA from 275 psi to 150 psi. 02:00 02:15 0.25 2,650 2,650 SLOT CSGRC' CPBO P ': Rotate 8 Cut 7" casing @ 2650 tat 80 rpm w/ 5k ft Ibs of torque. Pumping 5 bpm w/ 840 psi initial. OA pressure 150 psi. PU wt 110k, SO wt 105k, Rot wt 105k. 02:15 02:30 0.25 2,650 2,202 SLOT CSGRC' TRIP P Flow check- static. No change in OA pressure. POOH on the trip tank, standing back stands # 28, 27,26,25. Make a top drive connection on stand # 24 @ 2292'. Pick up to 2202'. Page 6 of 41 • Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 02:30 02:45 0.25 2,202 2,250 SLOT CSGRC' TRIP P Slack off to 2212', start pumps @ 2.5 bpm w/ 220 psi. Locate collar @ 2224', stop pumps, slack off to 2250', start pumping 2.5 bpm w/ 220 psi, slack off to locate a collar @ 2259'. Pick up to place cutter @ 2250'. 02:45 03:15 0.50 2,250 2,250 SLOT CSGRC' CPBO P Cut 7" casing @ 2250': Rotate 80 rpm w/ 5k ft Ibs of torque. Pumping 5 bpm w/ 840 psi. Once cut was made pressure dropped to 160 psi. OA was 200 psi before and after cut pressure increased to 380 psi. 03:15 03:30 0.25 2,250 2,250 SLOT CSGRC' OWFF P Monitor well, slight drop ( "U" tubing to annulus). 03:30 03:45 0.25 2,250 2,250 SLOT CSGRC' SFTY P Pre job safety meeting on displacment of fluids in the 9 -5/8" x 7" annuls @ 2250'. 03:45 04:15 0.50 2,250 2,250 SLOT CSGRC' CIRC P Displace freeze protect fluids from the 9 -5/8" x 7" annulus to 9.8 NaCL brine. Close the annular, Pump 150 bbls of 9.8 ppg NaCI brine (125 deg), down the drill pipe, taking returns to the tiger tank from the OA. Pumping 5 bpm w/ initial circ pressure of 160 psi, final circ pressure 420 psi. Gained 150 bis of fluid in the tiger tank. 04:15 04:30 0.25 2,250 2,250 SLOT CSGRC' OWFF P Monitor drill pipe and annulus pressure to be zero. Blow down lines to the tiger tank. 04:30 04:45 0.25 2,250 2,250 SLOT CSGRC' OWFF P Open annular, close NCR kill, then flow check f/ 10 minutes- static. 04:45 05:00 0.25 2,250 2,197 SLOT CSGRC'OTHR P Blow down the top drive and kill line. 05:00 05:15 0.25 2,197 2,197 SLOT CSGRC' SFTY P Pre job safety meeting on POOH w/ Baker casing cutter. 05:15 06:15 1.00 2,197 194 SLOT CSGRC' TRIP P POOH from 2197' to 194'. 06:15 06:30 0.25 194 194 SLOT CSGRC' OWFF P Monitor well f/ 10 minutes- statci. 06:30 06:45 0.25 194 8 SLOT CSGRC' TRIP P Continue to POOH f/ 194' to 8' 06:45 07:00 0.25 8 0 SLOT CSGRC' PULD P Lay down Baker 7" casing cutter. 07:00 07:30 0.50 0 0 SLOT CSGRC' PULD P Clean floor. Pick up Baker 7" Spear assembly. Lay down 4" handling equipment. Pick up 5" handling equipment. 07:30 07:45 0.25 0 0 SLOT WHDBO SFTY P Pre job safety meeting on changing top pipe rams f/ 3 -1/2" x 6" to 4 -1/2" x 7 ". Change saver sub on the top drive to 4 -1/2" IF. 07:45 10:00 2.25 0 0 SLOT WHDBO RURD P Change top pipe rams f/ 3 -1/2" x 6" to 4 -1/2" x 7 ". Change saver sub on the top drive to 4 -1/2" IF. 10:00 10:30 0.50 0 0 SLOT WHDBO RURD P Pull FMC 9" ID wear bushing. Set test plug. 10:30 10:45 0.25 0 0 SLOT WHDBO RURD P Rig up to test BOPE. Page 7 of 41 Time Logs Date From To Dur S. Death E. Death Phase _Code Subcode _ T Comment 10:45 12:00 1.25 0 0 SLOT WHDBO BOPE P Test annular w/ 5" test joint to 250 psi low and 2500 psi high. Hold each _ test f/ 5 minutes. Chart test. 12:00 14:30 2.50 0 0 SLOT WHDBO BOPE P Test top pipe rams w/ 5" test joint, test HCR choke and HCR kill line. Test annular w/ 7" test joint to 250 psi and 2500 psi. Test top pipe rams w/ 7" test joint to 250 psi low and 4000 psi high. Hold each test f/ 5 minutes. Chart tests. Note: HCR on kill line side leaked. Used HCR valve on choke side and manual valve on the kill side to perform tests. 14:30 14:45 0.25 0 0 SLOT RIGMNT SFTY T Pre job safety meeting on changing out failed HCR on the kill line side. 14:45 19:00 4.25 0 0 SLOT RIGMNT RGRP T Change out HCR valve on the kill line (failed test). 19:00 19:30 0.50 0 0 SLOT WHDBO RURD P RU to test w/ 5" test joint. Fill stack w/ water. Work air out of system. 19:30 20:30 1.00 0 0 SLOT WHDBO BOPE P Test top pipe rams w/ 5" test joint, test 4" demco mud line, test floor safety valve, dart valve. Test to 250 psi low and 4000 psi high. Hold tests f/ 5 minutes. Chart test. 20:30 20:45 0.25 0 0 SLOT WHDBO RURD P Blow down lines, rig down testing equipment. 20:45 22:45 2.00 0 0 SLOT WHDBO OTHR P Pull FMC upper test plug. BOLDS, Pull FMC packoff- pulled 50k (no go) (alignment pin f/ tubing hanger not backed out fully), inspect and replace alignment pin f/ tubing hanger, pull packoff. 22:45 23:00 0.25 0 SLOT WHDBO OTHR P Install thin wall wear bushing (casing running wear ring), run in lockdown ✓ screws. 23:00 23:15 0.25 0 0 SLOT CSGRC' PULD P Pick up Baker tools to floor f/ BHA #4 (Spear assembly). 23:15 23:15 0.00 0 0 SLOT CSGRC' SFTY P Pre job safety meeting. 23:15 00:00 0.75 0 18 SLOT CSGRC' PULD P Make up BHA #4 (7" spear assembly): Bull nose, spear packoff assembly, 5 -3/4" ITCO Spear, spear extention, stop sub w/ 7 -1/2" OD ring, x -o sub, pup jt to 18.47' 09/29/2012 Engage fish (7" casing hanger), PU 4', circ 3 BU, Pull hanger to floor, UD spear and hanger, monitor well on the trip tank- static, RU /LD 53 jts 7" + cut off jt (26.62')(top of remaining fish @ 2249.42' SLM), Rig down casing tools, RU to test lower pipe rams w/ 5" test joint w/ lower test plug- test alignment pin on wellhead. MU spear BHA #5, Tag w/ stop @ TAM port collar, rotate through, con't RIH, engage TOF @ 2250', Jar free, monitor well- static- then flowing, Shut in well @ 1320 hrs. Circulate BU through choke, Weight up LSND mud to 10.5 ppg KWM, displ 9.8 ppg NaCL brine w/ 10.5 ppg kill weight mud. 00:00 00:15 0.25 18 2,246 SLOT CSGRC' FISH P Engage 7" casing w/ Baker spear, Pick up to 120k, then pull 4' to 2246' 00:15 00:30 0.25 2,246 2,246 SLOT CSGRC' CIRC P Circulate 3 bottom's up, pumping 755 gpm w/ 540 psi. Circulated till hole was clean. Page 8 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 01:00 0.50 2,246 2,214 SLOT CSGRC' OWFF P Monitor well on the trip tank - static. Pull hanger to the floor, lay down Baker spear assembly. Lay down FMC casing hanger. 01:00 02:00 1.00 2,214 2,214 SLOT CSGRC' RURD P Rig up to lay down 7" casing. Monitor well on the trip tank- static. 02:00 02:15 0.25 2,214 2,214 SLOT CSGRC' SFTY P Pre job safety meeting on laying down 7" 26 •pf L -80 BTC -m casing. 02:15 05:00 2.75 2,214 0 SLOT CSGRC' PULL P Lay down 53 jts + cut off jt (26.62'). Strap of 53 jts of casing (2187.05') in the shed+ cut off 26.62 + RKB33.90' + Hngr 1.85' = 2249.42' SLM. 05:00 05:30 0.50 0 0 SLOT CSGRC' RURD P Rig down 7" casing tools. Monitor well on the trip tank - static. 05:30 06:00 0.50 0 0 SLOT WHDBO RURD P Drain stack, pull wear bushing, set lower test plug, Rig up to test. 06:00 06:45 0.75 0 0 SLOT WHDBO BOPE P Test lower pipe rams (3 -1/2" x 6 ") w/ 5" test joint. Test well head alignment pin f/ tubing hanger to 250 psi low and 4000 psi high f/ 5 minutes. Chart test. 06:45 07:15 0.50 0 0 SLOT WHDBO RURD P Pull FMC lower test plug, install thin wall (casing running) wear bushing. Rig down test equipment. 07:15 07:30 0.25 0 0 SLOT CSGRC' SFTY P Pre job safety meeting on picking up BHA #5( spear 7" casing) 07:30 09:00 1.50 0 35 SLOT CSGRC' PULD P Pickup -make up Baker spear assembly to 35'. 09:00 10:00 1.00 35 232 SLOT CSGRC' TRIP P Pick up/ make up 6 -1/4" drill collars f/ pipe shed f/ 35' to 232'. 10:00 12:00 2.00 232 1,545 SLOT CSGRC' TRIP P Trip in the hole w/ 5" drill pipe f/ 232' to 1023', took wt (Spear stop @ TAM port collar -csg tally depth of TAM @ 1012.24'). Rotate through TAM collar w/ 1 -2 rpm and 2.5k ft Ibs of torque. Continue trip in to 1545'. 12:00 12:45 0.75 1,545 2,250 SLOT CSGRC' TRIP P Continue trip in f/ 1545' to 2250'. PU wt 125k, SO wt 125k. 12:45 13:15 0.50 2,250 2,595 SLOT CSGRC' FISH P Engage 7" fish (TOF @ 2250'). Circ 3 bpm w/ 60 psi, Jar fish: 110k down, 225 -275 up. Pull free w/ 300k on weight indicator after 17 jar licks. Pull fish up hole to 2595' 13:15 13:30 0.25 2,595 2,595 SLOT CSGRC' OWFF T Flow check well- static, then flowing. Shut in well w/ top pipe rams @ 1320 hrs. AOGCC was notified. 13:30 14:00 0.50 2,595 2,595 SLOT CSGRC' KLWL T Pump 2.8 bpm to fill stand pipe and see pressure. Record initial shut in prerssures. Drill pipe 60 psi, casing 20 psi. 14:00 14:15 0.25 2,595 2,595 SLOT CSGRC' KLWL T Circulate through choke, pumping 3 bpm- pressured up to 900 psi on the drill pipe. 70 psi on casing. Shut down and close in well. Bleed off to 120 psi. Page 9 of 41 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:15 16:00 1.75 2,595 2,595 SLOT CSGRC' KLWL T Circulate, pumping 1 bpm w/ 190 psi 170 psi on casing. Pumped 1200 strokes. Gained 2 bbls, shut in well. 16:00 17:00 1.00 2,595 2,595 SLOT CSGRC' KLWL T Monitor well: 40 psi on drill pipe. 30 psi on casing. Drill pipe increased to 50 psi. 40 psi on casing. Bled casing to zero. Shut in well. 17:00 22:30 5.50 2,595 2,595 SLOT CSGRC' KLWL T Monitor pressures: Initial Drill pipe 60 psi, casing 50 psi. Casing pressure increased to 80 psi. Bring 10.1 ppg LSND mud into pits, weight up to 10.5 ppg. 22:30 22:45 0.25 2,595 2,595 SLOT CSGRC' SFTY T Pre job safety meeting on puming _ 10.5 KWM through choke. 22:45 00:00 1.25 2,595 2,595 SLOT CSGRC' KLWL T Open choke, start pumping 1 bpm w/ initial 140 psi, once KWM was to the bit, maintain 80 -90 dp pressure. 09/30/2012 Displ 9.8 ppg NaCL brine w/ 10.5 ppg kill weight mud through choke manifold, monitor- static, open well, circ BU, monitor - static, POOH - pumping 2 bpm w/ 7" casing f/ 2595' to 2405', circ & monitor well until satisfied well is static, POOH w/ fish ('400' of 7" casing) on trip tank f/ 2405', monitored well @ 1841' & 899' & 622 ". PJSM, then Lay down BHA, disengage spear f/ fish, LD (399.41' SLM) 7" casing (9 jts+ 2 cut off jts). Break and lay down Baker fishing tools, clear floor, close blind rams, change top rams, test BOPE. 00:00 03:00 3.00 2,595 2,595 SLOT CSGRC' KLWL T Continue to Kill well w/ 10.5 ppg LSND mud, pumping 1 bpm w/ initial 80 -90 psi dp prerssure. After 10.5 ppg mud was back to the pits, increased flow rate to 2 bpm w/ 190 to 240 psi on drill pipe, 10 -20 psi on choke. Pumped a total of 290 bbls KWM. Shut down pumps, shut in dp 50 psi (stand all the way up), casing zero. Monitor f/ 5 minutes- no change. Open choke @ 0249 hrs- no flow. 03:00 03:15 0.25 2,595 2,595 SLOT CSGRC' KLWL T Open top pipe rams. Break off and set back a stand of 5" drill pipe. 03:15 04:30 1.25 2,595 2,595 SLOT CSGRC' KLWL T Break circulation, attempt slow pump rate @ 3 bpm (Started to pack off), slowed down back to 2 bpm w/ 140 psi. Circulate bottom's up @ 2 bpm w/ 140 psi. 04:30 05:00 0.50 2,595 2,595 SLOT CSGRC' KLWL T Observe well- static. 05:00 05:30 0.50 2,595 2,405 SLOT CSGRC' KLWL T Pump out f/ 2595' to 2405', pumping 2 bpm w/ 140 psi. while pulling a stand f/ 2499' to 2405' increased rate to 2.5 bpm w/ 100 psi. Once inside of surface casing @ 2411' pressure fell off. 05:30 06:15 0.75 2,405 2,405 SLOT CSGRC' KLWL T Circulate and condition mud, circulate 2 BU's, stage pumps up to 8 bpm w/ 210 psi. Some gas on first bottom's up. 06:15 06:30 0.25 2,405 2,405 SLOT CSGRC' KLWL T Monitor well- slight ooze. 06:30 07:00 0.50 2,405 2,405 SLOT CSGRC' KLWL T Circulate bottom's up, pumping 8 bpm w/ 200 psi Page 10 of 41 Time Logs Date From To Dur S. Depth E. Depth Phase _Code Subcode T Comment 07:00 07:30 0.50 2,405 2,405 SLOT CSGRC' KLWL T Monitor well. Slight flow for 25 min. Then static. Gas /air perculating out of mud. 07:30 07:45 0.25 2,405 2,405 SLOT CSGRC' KLWL T CBU at 8 bpm -200 psi. Mud return mud smoothed out after 52 bbls. No _ gas at bottoms up. 07:45 08:45 1.00 2,405 2,405 SLOT CSGRC' KLWL T Monitor well. Slight flow for 25 min. Gas/ air perculating out of mud. Well static for 35 min. 08:45 09:15 0.50 2,405 2,405 SLOT CSGRC' CIRC P CBU at 8 bpm -200 psi. Mud return mud smoothed out after 52 bbls. No gas at bottoms up. 09:15 09:45 0.50 2,405 2,405 SLOT CSGRC' OWFF P Monitor well. Slight flow for 25 min. Gas / air perculating out of mud. Blow down top drive. 09:45 10:45 1.00 2,405 1,841 SLOT CSGRC' TRIP P POH on trip tank from 2405' to 1841'. 10:45 11:00 0.25 1,841 1,841 SLOT CSGRC' OWFF P Monitor well. Static 11:00 12:00 1.00 1,841 1,182 SLOT CSGRC' TRIP P POH on trip tank from 1841' to 1182'. 12:00 12:30 0.50 1,182 899 SLOT CSGRC' TRIP P POH on trip tank from 1182' to 899'. 12:30 13:00 0.50 899 899 SLOT CSGRC' OWFF P Flow check well- static. Rig up 7" casing equipment. 13:00 13:30 0.50 899 622 SLOT CSGRC' TRIP P POOH on trip tank f/ 899' to 622'. 13:30 13:45 0.25 622 622 SLOT CSGRC' SFTY P Pre job safety meeting on laying down Baker spear BHA & laying down 7" casing. 13:45 15:00 1.25 622 400 SLOT CSGRC' PULD P Lay down Baker BHA. Release spear from fish (Fish= 399.41' SLM -- 9 jts + 2 cut off jts (8.11 & 29.42')). 15:00 16:30 1.50 400 0 SLOT CSGRC' PULD P Lay down 7" 26 ppf L -80 BTC -m casing. (399.41' SLM- 9 jts + 2 cut off jts (8.11 & 29.42')). 16:30 16:45 0.25 0 0 SLOT CSGRC' OWFF P Monitor well - static. 16:45 17:15 0.50 0 0 SLOT CSGRC' RURD P Rig down casing equipment. 17:15 17:45 0.50 0 0 SLOT CSGRC' PULD P Pick up Baker spear assembly. Break all connections and lay down. 17:45 19:00 1.25 0 SLOT CSGRC' PULD P Clear rig floor of Baker fishing tools. 19:00 19:15 0.25 SLOT CSGRC' SFTY P Pre job safety meeting. 19:15 21:00 1.75 SLOT WHDBO OTHR P Change top pipe rams f/ 4 -1/2" x 7" to 3 -1/2" x 6 ". 21:00 21:15 0.25 SLOT WHDBO SFTY P Pre job safety meeting on rigging up to test BOPE. 21:15 22:15 1.00 SLOT WHDBO RURD P Rig up to test BOPE, fill lines. 22:15 00:00 1.75 SLOT WHDBO BOPE P Test BOPE: Test top pipe rams w/ 5" test joint, test valves # 1, #3, #6, and #9 in choke manifold. test kill line (� HCR to 250 psi low and 4000 psi high. Install 3 -1/2" test joint: Test top pipe, bottom pipe, HCR kill line and HCR choke line to 250 psi low and 4000 psi high. Test annular to 250 psi low and 2500 psi high. All tests held f/ 5 minutes. Charted tests. Page 11 of 41 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10/01/2012 24 hr Summary Rig down test equip, RU /PU 3 -1/2" cementing stinger, PJSM, MU 3 -1/2" w/ mule shoe & x -o's to 953', Change elevators, trip in w/ 5" drill pipe f/ 953' to 2626', tag w/ 5k, PU to 2610', make top drive connection, circ- packing off, PU to 2456', circ, wash down f/ 2456' to 2719' cleaning up hole, PJSM, RU/ pump balanced plug 17 ppg cement KOP w/ 57 bbls cement, POOH to 2078' slow, circ to clean up pipe and hole, dumped contaminated mud, POOH to 953', UD 3 -1/2" cement string, monitor well f/ 30 min- static, clear floor of tools, PJSM, RIH w/ 2 stands of 6 -1/4" DC's, 3 stands of 5" HWDP, MU Baker Model "B" retrievamatic w/ twin thread and rotational equalizing valve, RIH w/ 75' of 5" DP, set packer w/ top © 81.37', release and POOH w/ 5" dp. PJSM, RU/Test packer to 500 psi- chart test -good. Prep to ND BOPE /NU FMC Gen II wellhead. 00:00 00:30 0.50 0 0 SLOT WHDBO RURD P Rig down testing equipment. Pull lower test plug. Blow down choke line and choke manifold. 00:30 01:00 0.50 0 0 SLOT PLUG RURD P Rig up to run 3 -1/2" 9.3 ppf L -80 cement stinger. 01:00 01:30 0.50 0 0 SLOT PLUG SFTY P Pre job safety meeting on picking up /running in the hole w/ 3 -1/2" cement stinger. 01:30 02:45 1.25 0 953 SLOT PLUG PULD P Make up 3 -1/2" mule shoe +30 jts 3 -1/2" 9.3 ppf L -80 EUE -m + two crossovers to 953'. 02:45 03:30 0.75 953 953 SLOT PLUG RURD P Change elevators f/ 3 -1/2" YT to 5" drill pipe. 03:30 04:45 1.25 953 2,626 SLOT PLUG TRIP P Trip in the hole w/ cement stinger on 5" drill pipe from the derrick f/ 953' to 2626'. Tagged w/ 5k. PU wt 110k, SO wt 105k. 04:45 05:00 0.25 2,626 2,456 SLOT PLUG TRIP P Pick up f/ 2626' to 2610', make a top drive connection. Break circulation w/ 2 bpm w 70 psi, increase rate to 5 bpm, started packing off. Shut down pumps, Pull out of the hole to 2456'. 05:00 05:45 0.75 2,456 2,485 SLOT PLUG CIRC P Establish circulation @ 2456, pumping 8 bpm w/ 200 psi., started getting gas back to surface, reduced rate to 3 bpm w/ 80 psi. After bottoms up staged rate up to 8 bpm - 200psi. Wash from 2452' to 2485'. 05:45 06:45 1.00 2,485 2,547 SLOT PLUG WASH P Wash from 2485' to 2547'. Pumping 8 bpm w/ 200 psi. Large amount of shale and clay at shakers. 06:45 08:30 1.75 2,547 2,547 SLOT PLUG CIRC P Reciprocate stand. Stage pumps from 8 to 17 bpm - 600 psi. Large amount of shale and clay at shakers. 08:30 10:15 1.75 2,547 2,719 SLOT PLUG WASH P Wash from 2547' to top of CIBP at 2719' at 17 bpm - 620 psi. Tagged top of 7" stump at 2650'. Rotate pipe 1/2 round to work muleshoe into stump. 10:15 12:00 1.75 2,719 2,719 SLOT PLUG CIRC P Circulate hole clean at 17 bpm - 620 psi. Clean out down to the CIBP @ 2719'. 12:00 12:15 0.25 2,719 2,719 SLOT PLUG SFTY P Pre job safety meeting on cement kick off plug. Continue circulating 17 bpm w/ 620 psi. 12:15 12:30 0.25 2,719 2,719 SLOT PLUG RURD P Lay down a single. Pick up 12.07' pup joint to place mule shoe at the CIBP in the 7" @ 2719'.. Blow down the top drive. Page 12 of 41 • • Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 12:30 12:45 0.25 2,719 2,719 SLOT PLUG RURD P Rig up cementing equipment on rig floor. 12:45 13:00 0.25 2,719 2,719 SLOT PLUG PRTS P Dowell fill lines w/ water. Test lines to 2500 psi -good. 13:00 13:38 0.64 2,719 2,719 SLOT PLUG CMNT P Dowell mix mudPush @ 12 ppg, pump 12.04 bbls MudPush @ 4 bpm, mix and pump 56.71 bbls 17 - ppg cement ((yield 1 cuft/sx, mix water 3.870 gl /sx, 318 sx total) (additives: .2% D046 Antifoam, 1% D065 BWOC dispersant, .2% BWOC D167 Fluid loss)) @ 4 -3 bpm, follow w/ 1.7 bbls 12 ppg MudPush @ 3.5 bpm, chase to rig floor. 13:38 13:44 0.11 2,719 2,719 SLOT PLUG DISP P Rig dispalce cement w/ 10.5 ppg mud, pumping 5 -8 bpm w/ 90 -213 psi. Pumped to equalization (25 bbls pumped). Cement in place @ 1337 hrs 10 -1 -2012. 13:44 14:29 0.75 2,719 2,078 SLOT PLUG TRIP P Rig down cement head & 12' pup joint. MU single. POOH f/ 2719' to 2078' slowly. Monitor well on the trip tank. 14:29 15:14 0.75 2,078 2,078 SLOT PLUG CIRC P Install 4.95" OD nerf ball to clean drill pipe and stinger. Circulate hole clean, pumping 9.5 bpm w/ 230 psi. Dumped cement contaminated mud. 15:14 15:29 0.25 2,078 2,078 SLOT PLUG OWFF P Monitor well- static. Blow down the top drive. 15:29 16:29 1.00 2,078 953 SLOT PLUG TRIP P Trip out of the hole w/ cement stinger f/ 2078' to 953' 16:29 16:44 0.25 953 953 SLOT PLUG SFTY P Pre job safety meeting on rigging up j to handle and lay down 3 -1/2" 9.3 ppf L -80 cementing string. 16:44 17:29 0.75 953 953 SLOT PLUG RURD P Rig up 3 -1/2" tubing handline equipment. 17:29 18:44 1.25 953 0 SLOT PLUG PULD P Break off x -o's. Pull out of the hole laying down 953' of 3 -1/2" 9.3 ppf L -80 tubing + mule shoe. 18:44 19:14 0.50 0 0 SLOT PLUG OWFF P Monitor well f/ 30minutes- static. 19:14 19:44 0.50 0 0 SLOT PLUG PULD P Clear floor of tools. 19:44 19:59 0.25 0 0 SLOT WHDBO SFTY P Pre job safety meeting on BHA to RIH w/ 9.625" storm packer. 19:59 21:59 2.00 0 0 SLOT WHDBO TRIP P Make up 2 stands of 6 -1/4" drill collar, 3 stands of 5" HWDP, Baker Model "B" Retievamatic assembly, RIH on a stand of 5" drill pipe to 81.37' from rig floor. Bottom of string © 563.38'. SO wt 95k: 25k hanging on packer. Turn to the right 1 turn. Pick up to 110k, SO to block weight. Center of packer element @ 96.37'. Rotate to the right 10 turns, POOH w/ stand of 5" drill pipe, disconnecting @ twin thread safety joint. Page 13 of 41 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:59 22:29 0.50 0 0 SLOT WHDBO SFTY P Pre job safety meeting on testing Baker model "B" Retievamatic storm packer to 500 psi w/ BOP test pump. 22:29 22:44 0.25 0 0 SLOT WHDBO RURD P Rig up testing equipment. Pump through hose to cellar to fill line. Attach hose to annulus, pressure test line to 1000 psi -good. Open annulus valve, pump into well, confirm fluid moving down the flow line. Shut blind rams. 22:44 22:59 0.25 0 0 SLOT WHDBO DHEQ P Test w/ BOP test pump against blind rams, kill line & choke line HCR valves to 500 psi. Took less than 15 seconds (2.15 gallons) to achieve 500 psi (pump output 8.6 gallon /min). Hold f/ 15 minutes- lost 5 psi- good test. 22:59 23:14 0.25 0 0 SLOT WHDBO RURD P Bleed off pressure, open blind rams, rig down testing equipment. „ A 23:14 23:59 0.75 0 0 SLOT WHDBO RURD P Prepare to nipple down BOPE to change out FMC Genl wellhead for a new FMC Gen 11 wellhead. _ I 0 Note: Lockdown screw measurements will change and height of wellhead will be 1.5' taller. 10/02/2012 Nipple down BOP, then FMC Gen I wellhead, NU FMC Gen II well head, then BOPE and body test wellhead 250/4000 psi, retrieve storm packer, test 9 -5/8" casing /cement to 2500 psi for 30 min, PU and stand back 5" DP, change out upper pipe rams to 4 -1/2" x 7 ". 00:00 00:30 0.50 0 0 SLOT WHDBO SFTY P Pre job safety meeting on nippling down BOPE. 00:30 01:45 1.25 0 0 SLOT WHDBO NUND P Pull mouse hole, nipple down riser. 01:45 03:00 1.25 0 0 SLOT WHDBO NUND P Remove Actuator & annulus valves 03:00 03:45 0.75 0 0 SLOT WHDBO NUND P Stand back & secure BOP stack 03:45 05:45 2.00 0 0 SLOT WHDBO NUND P ND FMC Gen I wellhead - NU FMC Gen II wellhead - Test to 1000 psi for 10 mms Install actuator & annular valves 05:45 08:15 2.50 0 0 SLOT WHDBO NUND P NU BOPE stack - riser - hole fill & drain lines 08:15 09:00 0.75 0 0 SLOT WHDBO OTHR P Set test plug - fill line - RU to test 09:00 09:30 0.50 0 0 SLOT WHDBO PRTS P Body test wellhead - Choke line & outter annulus valve to 250 & 4000 . psi for 5 mins. 09:30 10:15 0.75 0 0 SLOT WHDBO OTHR P Pull test plug & set wear bushing (10" id) 10:15 11:15 1.00 0 0 SLOT WHDBOOTHR P MU strom packer retrieving tool - RIH & retrieve storm packer - LD packer & ret. tool 11:15 12:00 0.75 0 0 SLOT WHDBO PULD P Std. back HWDP & LD DC's which were ran below the storm packer 12:00 13:00 1.00 0 0 INTRM1 DRILL OTHR P Clean up rig floor - Halliburton gyro hands calibrate gyro 13:00 13:15 0.25 0 0 INTRM1 DRILL SFTY P PJSM on testing casing Page 14 of 41 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:15 14:30 1.25 0 0 INTRM1 DRILL PRTS P Fill lines - Test 9 5/8" 36# casing to 2500 psi for 30 mins.(Good Test ) bleed off pressure & rig down 14:30 14:45 0.25 0 0 INTRM1 DRILL SFTY P PJSM on picking up 5" DP 14:45 22:00 7.25 0 0 INTRMI DRILL PULD P PU & stand back 5" DP f/ pipe shed via mouse hole 22:00 22:30 0.50 0 0 INTRMI DRILL SFTY P PJSM on pull wear ring 22:30 00:00 1.50 0 0 INTRMI WHDBO OTHR P Change out upper pipe rams from 3 -1/2" x 6" to 4 -1/2" x 7 ". -- Simops -- Adjust standpipe and kelly hose gooseneck in drk 10/03/2012 Test BOPE, MU Sperry motor BHA, RIH, slip and cut drilling line, drill soft to firm cmt from 2314' to 2450' md, Obtain Gyro TF, kick off, sliding from 2450' to 2487', C BU 00:00 06:30 6.50 0 0 INTRM1 WHDBO BOPE P Held PJSM on test BOPE - RU to test - Test BOPE w/ 5" and 7" test joint. Witness of test waived by AOGCC inspector Jeff Jones. Tested annular to 250 psi low and 2500 psi high. Tested all valves in the choke manifold, kill line valves (including 4" Demco), choke lines valves, top and bottom pipe rams and blind rams to Ind p 250 psi low and 4000 psi high. t Tested upper IBOP and manual IBOP on the top drive. Tested the full open floor safety valve and IBOP to 250 psi and 4000 psi. All tests were held f/ 5 minutes. Charted tests. Tested the accumulator: Full charge 3050 psi, after closure 1500 psi, 200 # build up in 31 sec, full charge in 188 seconds. Pumped through both chokes in the choke manifold, restricting flow - choking flow to 1500 psi. Check PVT system for trip tank and pit#6. Alarms worked. Flow indicator woked. 06:30 07:00 0.50 0 0 INTRM1 WHDBO OTHR P Pull test plug - Install long wear bushing (10" ID) 07:00 07:15 0.25 0 0 INTRM1 WHDBO OTHR P Blow down lines - Line up choke manifold for drilling 07:15 07:30 0.25 0 0 INTRM1 DRILL SFTY P Held PJSM on MU BHA 07:30 10:00 2.50 0 138 INTRM1 DRILL PULD P MU BHA # 6 (8 3/4" motor 7 MWD tools - PDC bit (FM65M) 7" Sperry Drill lobe 7/8 - 6.0 stg. - stab- DM collar - XO - DGR collar - ERW -P4 collar - PWD - HCIM - XO - ALD collar - CTN collar - XO - XO - BAT collar - TM HOC - float sub - UBHO - to 138' 10:00 10:45 0.75 138 138 INTRMI DRILL OTHR P Plug in & up load MWD Page 15 of 41 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:45 11:00 0.25 138 138 INTRMI DRILL CIRC P Test kelly hose to 3500 psi - Shallow test MWD tools @ 550 gpm @ 990 psi (tool pulsing but too much noise to detect) 11:00 11:15 0.25 138 138 INTRM1 DRILL OTHR P Blow down TD - Clean up rig floor 11:15 11:45 0.50 138 138 INTRMI DRILL OTHR P PJSM, Toad nuke sources 11:45 12:00 0.25 138 231 INTRMI DRILL PULD P RIH with NMDC's from shed 12:00 12:30 0.50 231 691 INTRM1 DRILL TRIP P RIH from 231' to 691' with 5" DP from derrick 12:30 13:00 0.50 691 691 INTRM1 DRILL CIRC P Shallow pulse test MWD with 550 gpm, 1150 psi, ok 13:00 13:30 0.50 691 691 INTRM1 DRILL RURD P PJSM, RU Sperry wireline, PU gyro tool 13:30 15:00 1.50 691 2,012 INTRM1 DRILL TRIP P RIH from 691' to 2012', (no resistance thru port collar) 15:00 15:15 0.25 2,012 2,012 INTRM1 DRILL SFTY P PJSM on slip and cut drilling line. 15:15 16:45 1.50 2,012 2,012 INTRM1 DRILL SLPC P Slip and cut drilling line 16:45 17:45 1.00 2,012 2,389 INTRMI DRILL WASH P Wash from 2012' to 2389', no hard cement. 550 gpm, 1270 psi. 17:45 18:15 0.50 2,389 2,389 INTRM1 DRILL CIRC P CBU, Tots of soft cement across shakers 18:15 18:45 0.50 2,389 2,461 INTRM1 CEMEN" DRLG P Drill cement from 2389' to kick- off point at 2461', firm cement. 500 gpm, 1030 psi, 30 rpm, 5K tq. 18:45 19:15 0.50 2,461 2,461 INTRM1 DRILL CIRC P CBU, cement at shakers firm 19:15 20:15 1.00 2,461 2,461 INTRM1 DRILL SRVY P Gyro survey at 2422' bit depth for tool face, gyro tagged early, discovered pipe tally error in BHA, actual depth 91' shallower at 2331'. C Ej 20:15 21:30 1.25 2,389 2,450 INTRMI CEMEN" DRLG P Drill firm cement from 2369' to 2450', kick -off point. 500 gpm, 1100 psi, 40 C1/41 rpm, 6K tq. Max WOB seen, 5K at 120' /hr. 21:30 22:30 1.00 2,461 2,461 INTRM1 DRILL SRVY P Gyro survey for TF at 2425' bit depth. 22:30 23:15 0.75 2,450 2,487 INTRM1 DRILL DDRL P Kick -off from 2450' md, slide 37' to 2487', 500 gpm, 1100 psi, 8 -12K WOB. MWD survey shows may have V rotated off plug. ' 1 23:15 23:30 0.25 2,487 2,393 INTRM1 DRILL TRIP P POOH to 2393', into casing for FIT ICJ 23:30 00:00 0.50 2,393 2,393 INTRM1 DRILL CIRC P Circulate to even MW, 9.8 ppg i° 10/04/2012 Perform LOT to 14.3 ppg EMW, Drill 8 -3/4" hole to 3998' md. 00:00 00:45 0.75 2,393 2,393 INTRM1 DRILL LOT P RU for FIT. Attempt FIT to 16.0 ppg. Leaked off at 14.3 ppg EMW. - RD - Blow down lines Page 16 of 41 • • C2t-C.n1 -or +cjv40 Regg, James B (DOA) From: Doyon 19 Company Man [doyon1 @conocophillips.com] � �/ el6 Sent: Saturday, September 29, 2012 6:42 PM c v To: DOA AOGCC Prudhoe Bay Cc: Bearden, Daniel D Subject: Doyon 19 Well Control Shut in well and weighting up mud from 9.8 to 10.5 to kill well. 9 -29 -12 13:22 hrs CD1 -01 Alpine 199 -046 Doyon 19 Donnie Lutrick / Granville Rizek Cut 7" csg at 2650' and 2250'. POH and LD 2250' 7" csg. RIH and spear fish. - Jar 400' csg free. Monitor well. Had slight flow out annulus. Shut well in. SIDP - 80 psi. SICP - 30 psi. CBU on choke. SIDP - 50 psi. SICP - 60 psi. = 10.3 kill wt Prepping to weight up to 10.5. Used upper pipe rams and hydraulic choke Well control Will be changing upper pipe rams when out of hole with fish and testing to 250 / 4000 psi Donnie Lutrick & Granville Rizek Rig Supervisors Doyon 19 907 -670- 4300 jPe 013 scoNED • v9 9 - WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 17, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 SCANNED APR 3 0 2013 RE: Perforating Record/Tubing Cut Record: CD 1 -01 Run Date: 8/16/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD1 -01 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 103- 20299 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 Klinton Wood @halliburton.com , G Date: \o t\ \'/i Signed: — ' 4 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ` �,,� Ci/�4 DATE: August 14, 2012 P. I. Supervisor � FROM: John Crisp, SUBJECT: P &A Report CRU CD1 -01 Petroleum Inspector CPAI — Sundry #312 -276 PTD 199 -046 August 14, 2012: I traveled to Conoco /Phillips Alaska CRU Alpine CD1 -01to witness wire line tag of cement in tubing & MITT & MITIA to verify cementing of the perforations & protect the permanent packer from reservoir for abandonment of production zone for Rig Sidetrack. Halliburton Slick line was R/U to RIH with1 3 /4" sample bailer with 2.71" centralizer when I arrived on location. Possible cement stringers were encountered @ approximately 5780'. Sample Bailer with 2.71" centralizer was then worked down to failure @ 5792' MD. After POOH with WL I requested MITT performed before another run was made with sample bailer & smaller centralizer. MITT was successful to a pressure of 2000 psi. Sample Bailer with 2.495" centralizer was RIH to failure at the approximate depth of 5792' MD. Successful MITIA was witnessed prior to Inspector departure from Alpine. Sundry 312 -276 has current well status as Service Well. Well class after proposed work is classified as Service. I will attempt to document MITT & MITIA in RBDMS. Summary: I witnessed successful cement plug tag in tubing @ 5792' MD on CD1 -01. Cement top was required to be at or above 5900' MD. Successful MITT & MITIA were witnessed. Attachments: Photos of sample from bailer on first run with WL & from second - run WL. Non - Confidential APR fl B rIV SreAkt P &A CRU CD1 -01 08 -14 -12 • • Plug Tag - CRU CD1 -01 (CPAI) PTD 1990460 Photos by AOGCC Inspector J. Crisp 8/14/2012 filler4 '. ill ' liff4. , , +v ( 40.1k k ipit 10 1 1 ?6 , It w Sample Bailer Run #1 ..." ..... . . , , _ . . ..- , - - . , k. . I' . 4944 A - - - , - , P &A CRU CD1 -01 08 -14 -12 • • 4 11111411111111 ‘ ., A ,, Sample Bailer . x _ Run #2 A 4 1 r t ft I 1 a i w _ 1 1 —a �{ I v T i "" r ' TT- - iii \ %.- 141- ' 44 ` . ''''.: 7i P &A CRU CD1 -01 08 -14 -12 • • ,--)9 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 6, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 SCANNED APR 3 0 2013 RE: Perforating Record: CD 1 -01 Run Date: 8/5/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 CD1 -01 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50 -103- 20299 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 Klinton Wood @halliburton.com Date: \D( /\ Z Signed: Y/6'efak , • • SEAN PARNELL, GOVERNOR L ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 R. Tyler Senden Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 0 t44 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD 1 -01 Sundry Number: 312 -276 Dear Mr. Senden: SLOWED AUG 0 Z 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, Cathy . Foerster Chaff DATED this day of August, 2012. Encl. 0 41v RECEIVED 9,1 STATE OF ALASKA g JUL 2 5 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION o7S S /(1 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill El • Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations 0 . Perforate ❑ Pull Tubing 0 • Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska Inc. Development Exploratory IIV 199 -046 3. A Stratigraphic ❑ fr v Service 6. API Number: P.O. Box 100360, Anchorage, Alaska 't 6. 50- 103 - 20299 -00 . 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No El CD1 -01 • 9. Property Designation (Lease Number): j> 10. Field / Pool(s): ADL 25550 A v r ,Al)(- Z55 / • L.-4 " Colville River Field / Alpine Oil Pool 11. PRESENT WELL CONDITION SUMMARY - DOYON 19 RKB Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,289. 6,954 • 10,289 6,984 Casing Length Size MD TVD Burst Collapse Structural Conductor 84 16' 121 121 1,640 630 Surface 2375 9 -5/8" 2411 2,395 5,750 3,090 Production 7715 7" 7752 6,991 7,250 5,410 Tubing 7258 4 -1/2" 7290 6938 8,425 7,496 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): open hole 7752'- 10289' 6.125" open hole 6991 -6954' 4 -1/2" L -80 7,290 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker S3 Packer and Camco Al SSSV Packer set at 7180' MD (6,885 TVD) -- SSSV set at 1,013' MD (1,006' TVD) 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: .,/f.•- 3v ,� - Detailed Operations Program El BOP Sketch ❑ Exploratory ❑ Development , • Service ❑y 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 8/15/2012 Oil ❑ Gas ❑ WDSPL ❑ Suspended 0 16. Verbal Approval: Date: n/a WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact R. Tyler Senden 265 -1544 Printed N e R. Tyler Senden Title Wells Engineer Signature Phone 907- 265 -1544 Date 7/25/2012 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 2.- 2 6 Plug Integrity V BOP Test LJ1 Mechanical Integrity Test ❑ Location Clearance ❑ Other: 4 PAL W Of �'S & D Psi t4h fri, ‘ ` 1 G - A l te-Y- d - pf . dy reou`..� le-e-1_ Z-a / 1/I C_- Z S, (rZ C.4 Subsequent Form Required: / 0` 1 07 n APPROVED BY Approved bya f 4COMMISSIONER THE COMMISSION Date: g - 2_ /2_ Form 10 -403 Revised 1/2010 '� A UG 0 3 2O1 1 � � ubmit • Du licate OR1GiNAL ^5 • • CD1 -01 Abandonment The following procedure will be used to isolate the perforations and protect the permanent packer from the reservoir. The well will be sidetracked under a separate Sundry and permit to drill. ?�- This work will be conducted as soon as Sundry approval is granted. n��Sf fV�_ 1. Obtain SBHP and passing MIT's of the tubing and inner annulus. 2. Shoot squeeze perfs above the packer at 7180' MD. 3. Run in hole and set inflatable cement retainer below packer. 4. Pump 25 bbls of 15.8 ppg Class G cement through retainer and into open hole. 5. After 25 bbls into the open hole pull up and squeeze 20 bbls of the same 15.8 ppg Class G cement into the IA above the packer. 6. Lay in 20 bbls of cement on top of the retainer (est. TOC at 5900' MD). 7. Tag cement top. 8. PT tubing and IA to 2000 #. Notify Inspector before PT. 9. Punch tubing above the cement top. 10. Circulate in corrosion inhibited XX.X (wt. to be determined from SBHP in step 1) ppg mud (based on last SBHP) and diesel freeze protect. 11. Equalize tubing to ensure freeze protect on both tubing and IA. 12. Cut tubing at -2900'. 13. Set back pressure valve in preparation for the rig. The rig will move onto the well within days completing this work. Their initial decompletion and casing pulling steps are as follows. The work beyond what is detailed below will be covered in the Permit to Drill. 1. MIRU Doyon 19. 2. Test 7" casing, 7" casing pack off and BPV through inner annulus to 2,000 psi for 10 minutes, chart PT. 3. Test tree adaptor to 5,000 psi. 4)4 4. Pull BPV. 4 I\ 5. Circulate diesel freeze protect over to 10.8 ppg kill weight mud through tree, taking returns to tiger �? a tank. U 6. Set BPV and test through inner annulus to 1,500 psi. 7. Set blanking plug. ^� 7.3°.(L- 8. Nipple down tree. Lcoo Y� 9. Nipple up BOPE and test to 250 /,3.500 - psi with 4" & 4.5 ". 10. Remove blanking plug and BPV. 11. Pull 4 -1/2" tubing (pre -cut at -2,900 MD). 12. Pressure test lower rams with 3.5" (cement stinger) and 4" (drillpipe) test joints. 13. Run in hole with CIBP on 4" drillpipe and set at -2,700' MD. PT to 2,500 psi. 14. Run in hole with mechanical casing cutter on 4" drillpipe and cut casing at 2,650' & 2,250' MD. 15. Flush 7" x 9 -5/8" annulus with 10.9 ppg kill weight brine taking returns to tiger tank. 16. Swap 3.5" x 6" rams to 7" casing rams and pressure test to 250/ &b psi. 17. Pull 7" casing to surface and lay down. 18. Swap 7" casing rams to 3.5" x 6" rams and pressure test. 19. RIH with 3.5" cement stinger and set cement kick off plug from the top of bridge plug to 200 ft inside the surface shoe. 20. P/U directional drilling BHA and RIH. Tag TOC and pressure test surface casing and kick off plug to 2,500 psi. 21. Ready to move into drilling phase • under new PTD. 4dT • 0047 ;'Opea /4/(44 Is" 4� oFfs� pro�,cCrS 49c N2 41/t ti� i Ad' Oi dlr, -° &ccoke>r , °�k t I n t �t,'f 44;(1 t w; : �a f' S f al l f A �, �rd cot a %M �k� itGf aU for bracky r/ • • Page 1 of 1 c.onOCOPhi11ip5 General Well Work Request Form Well: CD1 -01 Budget Category: Type: Injector Job Scope: Cement Squeeze (After drilling Ops) -; Date: 7/17/12 WBS: From: Ty Senden Network Number: 10338425 Phone: 265 -1544, 982 -3996 Estimated Cost: DSE: Michael Dammeyer NOB: DSE Phone: 265 -6548, 265 -6548 SETCIM Shut -in Reason Code: 364 Workover / Sidetrack Job Types: Slickline E -line Coil Tubing Other Gauge Tbg I (Other (Describe) I 'Other (Describe) I I SBHP /PBU (Panex /Amerada)I I I I I Cement Plugs /Squeezes I Objectives Abandon the existing injection interval. Prepare for a rig sidetrack below the surface casing shoe. Job Concerns Procedure Slickline: 1. RU slickline and drift tubing to A -1 injection valve at 1031' RKB. Pull the A -1 injection valve. 2. RIH and tag fill. 3. RIH with tandem panex gauges and obtain SBHP as deep as possible and then 100' TVD uphole. 4. RIH and set plug or SV in XN nipple at 7255' RKB. 5. MIT tubing to 2500 psi. Bleed off tubing to 1500 psi and MIT -IA to 2500 psi. 6. Pull plug or SV. E -Line: 1. Log packer assembly with CCL from nipple at 7255' RKB up across the packer. Identify tubing punch location just above packer. 2. Shoot 8' of 2" OD tubing punch in tubing just above packer. (Either 2, 4' punches or 1, 8' punch.) 3. Pressure up (or bleed off) IA and verify that the IA is in communication with the TBG and formation. 4. Establish pump rate -2 BPM through tubing punches. 5. RDMO once the holes are determined satisfactory. Otherwise, re -punch (same interval, same sized tubing punch). Coiled Tubing: 1. Set a 3 -3/8" Baker inflatable cement retainer (w/ internal check valve to prevent fluid flow from below when un- stung) near the 3.725" nipple at 7255' RKB. j 2. RIH and sting into retainer. J 3. Confirm open hole will take fluid by pumping 50 bbls of SW. 4. Pump 25 bbls of 15.8 ppg Class G cement through retainer. Un -sting from retainer. PUH above the holes in tubing. Open surface IA casing valve, close tubing side choke, and begin taking returns from the IA. Pump an additional 20 bbls of cement, taking all returns from the IA. After the 20 bbls have been pumped, close IA at surface and begin pulling out of hole, laying in 20 bbls of cement in the 4.5" tubing. 5. After cement has been pumped and equipment washed up lay in diesel freeze protect from 2000' to surface. 6. RDMO. Slickline: 1. Gauge tubing to top of cement at -5900' MD (20 bbl in 4.5" tubing is -1300' of cement above retainer). 2. PT tubing to 2000 #. 3. PT IA to 2000 #. 4. RDMO. E -Line: 1. RIH with tubing punch to top of cement at -5900' and punch holes in tubing. 2. Circulate in 150 bbls of corrosion inhibited XX.X ppg mud (as determined from SBHP in slickline step #3) followed by 100 bbls of diesel (or crude). Jumper IA to tubing and let diesel /crude u -tube. 3. RIH with Jet Cutter and cut 4.5" tubing at -2900' RKB ( -500' below surface casing at 2411'). Don't cut in the middle of a connection. 4. Pressure up (or bleed off) tbg to confirm communication has been made. 5. RDMO. CD1 -01 Abandonment 07 -16 -12 vl.xls • • • Colville River Field CD1 -01 Alpine Producer Rig Abandonment All Depths using RKB of 42.79' Updated — 7/30/12 A 16" Conductor to 114' Top of Cement Plug @ 2250' MD / 2250' TVD � `` 6 i 9 -5/8" 36 ppf J -55 BTCM ""'_..:,., Surface Casing ::;:iii €iEfi[:�€ 9 `s?::::€ <::::::: @ 2411' MD / 2395' TVD cemented to surface 11°1:' 7" Casing Stub @ 2,650' MD MI IIII CIBP at 2,700' MD ■ Cut 4.5" Tubing @ 2,900' MD Well loaded from top of cement plug to CIBP with inhibited KWF mud. J Top of P&A plug @ — 5,900' MD ' — \\ 15.8 ppg Class G cement Baker S -3 Packer @ 7180' MD. O c-' 15-z- X3 3 Y,,, ezo 1 300d�` �4 - 1 - _ Well TDat / € , ....... € € € > € € € € €€ ::::: : €::: ::::::: : : ::11:: 1: :11 ::::; 10468 MD / .::::: ii:::; : :::::::1 :II . ::::::::::::::::::: I;IIII x::::::::::;1111 7061' TVD 7" 26 ppf L -80 BTC Mod Production Casing @ 7752' MD / 6993' TVD @ 89 deg fir• 4 WNS • CD1 -01 ConocOPhjlljps Mr, Well Attributes , Max Angle & MD TD Alaska, Inc. Wellbore APIIUWI Field Name Well Status .Intl (°) MD (MB) Act Mtn (11KB) - -- 501032029900 ' ALPINE INJ 1 94.98 7,697.41 10,289.0 Comment 1428 (ppm) Date Annotation End Date KB-Oat (1q Rig Release Date ... Well Config: - CDi -01, 1/8r20128'18'49 SSSV. NIPPLE Last WO: 42.79 6/29/1999 Schematic - Actual Annotation Depth End Date Annotation Last Mod ... End Date Last Tag: Rev Reason: RESET INJ VALVE ninam , Casing Strings Casing Description String 0... String ID... Top (IB(B) Set Depth (f... Set Depth (TVD)... Ong Wt... String... String Top Thrd - -- CONDUCTOR 16 15.062 36.6 114.0 114.0 62.58 H WELDED Casing Description String 0... String ID ... Top (11KB) Set Depth (f... Set Depth (TVD) ... String WI... String ... String Top Thrd HANGER, 32 SURFACE 9 5/8 8.921 36.6 2,411.7 2,395.3 36.00 J - 55 BTC Casing Desmiption String 0... String ID ... Top (BKB) Set Depth (f... Set Depth (WD)... String Wt... String ... String Top Thrd r PRODUCTION 7 6.276 34.4 7,751.9 6,993.0 26.00 L BTCM Caning Description String 0... String ID ._ Top (1B(B) Set Depth (f... Set Depth (WD)... String Wt. String . String Top That OPEN HOLE 6 1/8 6.125 7,752.0 10,289.0 6,953.7 IA ` . Tub! Strings Tubing Description String 0... String ID... Top (RKB) Sri Depth (1... Set Depth (ND)... String Wt... Siting ... String Top That TUBING 41/2 3.958 32.4 7,289.7 6,937.7 12.60 L-80 IBTM 'Completion Details Top Depth (WD) Top Ind Nomi... CONDUCTOR, 17 P Top (*KB) (IIKB) P) Item DaseriDescription Comment ID (In) 32.4 32.4 -0.48 HANGER FMC TUBING HANGER 4.500 1,013.1 1,005.7 11.10 NIPPLE CAMCO DB LANDING NIPPLE 3.812 7,179.7 6,885.2 56.96 PACKER BAKER S-3 PACKER 3.875 7,255.8 6,922.0 63.44 NIPPLE HES XN LANDING NIPPLE 3.725 - - - -- - - -- 37 - 114 7,288.3 6,937.1 66.24 WLEG WIRELINE RE -ENTRY GUIDE 3.875 Other In Hole reline retrievabie_plugS, valves : pumps, fish, etc.) Top Depth i (ND) Top moat Top (11KB) (BKB) r) Description Comment Run Data ID (In) 1,013 1,005.7 11.10 VALVE A -1 INJECTION VALVE ON 3.81 DB LOCK (HWS -30) 1/7/2012 1.125 Notes: General & Safety End Date Annotation 1/28/2011 NOTE: View Schematic W/ Alaska Schernatic9.0 AVLVE, 1 4- - ` - _ -- - NIPPLE, 1,013 ♦ j • 1 I SURFACE, I 37 -2,412 t t PACKER, 7,180 I ti NIPPLE, 7,256 WLEG, 7,288 - - -- 1 PRODUCTION, Al [ 34 -7,752 ._ — OPEN HOLE, — 7,75210,289 - TD (C01 -01), - 10,2W -_. _....... • • • Page 1 of 1 Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and r,,j operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redd'!" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. file: //F: \Daily_Document Record \Procedures_ Instructions \FW INTENT PLUG for RE- DRI... 4/6/2012 ~ MEMORANDUM To: Jim Regg P.L Supervisor ~ ~ ~ ~~~Z, ~~ FROM: Bob Noble Petroleum Inspector ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, June 22, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CDI-Ol COLVILLE RIV L1NIT CDl-O] Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~ Comm Well Name: COLVILLE RN LTNIT CD1-O1 Insp Num: mitRCN090617201416 Rel Insp Num: API Well Number: 50-103-20299-00-00 permit Number: 199-046-0 ~ Inspector Name: Bob Noble Inspection Date: 6/13/2009 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We~~ ~ CDl-Ol Type Inj. W 'I'~ 6885 IA 200 2500 2440 2440 ~ p.T.D 1990460 TypeTest SPT Test psi 2500 ~A 550 575 575 575 Interval 4YRTST p~F P ~ Tubing 1565 1565 1565 ]565 Notes: ~ ,~r/~~ ~5~ (~~SW~ IZ21 ~~~ ~ ... ~: ~ ~°~ i:~:~ ` l ~'. ~ ° ; 1~~i; Monday, June 22, 2009 Page 1 of 1 . . ~ ConocoPhilIi ps Alaska i~PR :. J .·3 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Oil B. 633 C,¡¡mmissjDn ;~m::~m'3[ì1d March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ib Avenue, Suite 100 Anchorage, AK 99501 ~lo qq'" D \, Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells trom the Alpine field (ALP). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water ffom 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. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, SCANNED APR 0 9 2007 ~~C Jerry Dethlefs ConocoPhillips Well Integrity Proj Supervisor Attacmnent . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal CD1-1 199-046 26" 0.3 6" 4/16/2003 3 2/17/2007 CD1-2 200-172 54" 0.6 5" 4/16/2003 2.7 2/17/2007 CD1-3 199-120 9'2" 1.4 14" 4/16/2003 6.5 2/17/2007 CD1-4 200-117 84" 1.0 9" 4/16/2003 4.3 2/17/2007 CD1-5 199-128 56" 0.6 30" 4/16/2003 14 2/17/2007 CD1-6 200-083 4" na 4" na 2 2/17/2007 CD1-8 204-059 6" na 6" na 8 2/17/2007 CD1-9 200-071 6" na 6" na 3 2/16/2007 CD1-10 200-171 18" na 18" na 8.5 2/16/2007 CD1-12 204-205 4" na 4" na 2 3/8/2007 CD1-14 201-038 4" na 4" na 1 3/8/2007 CD1-16 199-094 14'7" 2.0 6" 4/16/2003 3 2/16/2007 CD1-17 200-145 8'9" 1.2 8" 4/16/2003 3.5 2/16/2007 CD1-18 204-206 4" na 4" na 1 3/8/2007 CD1-19 200-040 10" na 10" na 3 3/8/2007 CD1-20 204-240 6" na 6" na 2 3/8/2007 CD1-21 201-006 14' 1.8 8" 4/16/2003 3.7 2/16/2007 CD1-22 200-110 25" 0.3 4" 4/16/2003 1 3/8/2007 CD1-23 199-063 15' 2.1 8" 4/16/2003 3.7 2/16/2007 CD1-24 199-026 27" 0.3 6" 4/16/2003 2.8 2/16/2007 CD1-25 200-008 76" 0.8 18" 4/16/2003 8.4 2/16/2007 CD1-26 199-088 6" na 6" na 3 2/19/2007 CD1-27 200-006 16'8" 2.6 4" 4/16/2003 1.8 2/16/2007 CD1-28 200-199 6" na 6" na 3 2/16/2007 CD1-29 200-215 4" na 4" na 1.8 2/16/2007 CD1-30 200-132 9' 1.4 6" 4/16/2003 3 2/16/2007 CD1-31 200-118 6" na 6" na 3 2/19/2007 CD1-32 199-104 8'6" 1.2 5" 4/16/2003 2.3 2/16/2007 CD1-33 200-212 54" 0.6 10" 4/16/2003 4.7 2/16/2007 CD1-34 200-043 38' 5.7 8" 4/16/2003 3.7 2/16/2007 CD1-35 199-038 4" na 4" na 1 3/8/2007 CD1-36 199-112 15'10 2.3 8" 4/16/2003 3.7 2/16/2007 CD1-37 199-067 8" na 8" na 4 2/19/2007 CD1-38 200-003 48" 0.5 4" 4/16/2003 1.5 3/8/2007 CD1-39 199-080 4" na 4" na 1 3/8/2007 CD1-40 199-044 4" na 4" na 1.8 2/16/2007 CD1-41 200-017 12" na 12" na 5.6 2/16/2007 CD1-42 199-119 74" 0.8 6" 4/16/2003 2.8 2/16/2007 CD1-43 200-106 8" na 8" na 3.7 2/16/2007 CD1-44 200-055 10" na 10" na 4.7 2/16/2007 CD1-45 199-101 4" na 4" na 2 2/19/2007 CD1-46 204-024 36" na 36" na 16.9 211612007 Alpine Field March 31,2007 ConocoPhillips Alaska, Inc. Surface Casing by Conductor Annulus Cement Top-Off Alpine Field, CD-1 CD-2 WELLS DEPTH VOLUME TYPE SACKS .... BBLS Cement CD1-1 2.25' 0.3 WI 1.8 -- CD1-2 4' 0.6 WI 3.6 -- -- CD1-3 10' 1.4 MI 8.5 ', -- CD1-4 7.33' 1 P 6.0 CD1-5 4' 0,6 MI 3.6 CD1-6 10.42' 1.4 Gl 8.5 CD1-16 14.33' 2 WI 12.1 -- CD1-17 8.75' 1.2 P 7.2 CD1-21 13' 1.8 MI 10.9 CD1-22 1.83' 0.3 P 1.8 -- CD1-23 15.42' 2.1 MI 12.7 -- CD1-24 2' 0.3 P 1.8 CD1-25 5.66' 0.8 P 4.8 CD1-27 18.83' 2.6 P 15.7 CD1-28 .......... -~.-~5' .................... ~ ..... P 6.0 CD1-32 8.33' 1.2 P 7.2 CD1-34 41.83' 5.7 P 34.4 CD1-36 16.75' 2.3 WI 13.9 CD1-38 3.5' 0.5 P 3.0 CD1-42 5.83' 0.8 MI 4.8 -- CD2-16 11.66' 1.6 INJ 9.7 CD2-17 18' 2.5 INJ 15.1 CD2-19 11.66' 1.6 P 9.7 CD2-22 13.5' 1.8 INJ 10.9 CD2-25 27.25' 3.7 P 22.3 CD2-26 10.42' 1.4 INJ 8.5 CD2-32 8.5' 1.2 INJ 7.2 CD2-33 ,.- 7' 1 P 6.0 CD2-34 4' 0.6 P 3.6 CD2-41 11.83' 1.6 P 9.7 CD2-46 7.42' 1 INJ 6.0 CD2-48 10.33' 1.4 INJ 8.5 CD2-49 9.33' 1.3 INJ 7.8 CD2-50 1.66' 0.25 P 1.5 ConocOPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 23, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were filled with cement to the top of the conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place. In the fall of 2002, CD1-23 was reported to have a "wobbly" tree. The top of cement was measured at 15- feet below the top of the conductor. Plans were made to stabilize the wellhead by top-filling cement later in the winter when the ice road to Alpine had been installed. Since that is considerable effort and expense for pumping a small load of cement, a survey was made of each conductor to see if voids were present. A list of 34 wells was put together that would need additional cement. The top-fill operation was started on April 15th and was completed on April 16th, 2003. Dowell- Schlumberger batch-mixed Arctic Set I cement to 15.7 ppg in a blender. The cement was pumped via high-pressure hose into the conductor. The cement was brought to the top of conductor on each well. The blender/pump and hose worked down the line, filling the identified wells until the list was completed. The attached spreadsheet presents the well name, top of cement depth prior to filling, and the number of sacks used on each conductor. Please call MJ Loveland or Nina Woods at 907-659-7224, or me at 659-7043 if you have any questions. Sincerely, Jerry Dethlefs ConocoPhillips Problem Well Supervisor Attachment Alpine Cement Top Fill Subject: Alpine Cement Top Fill Date: Wed, 23 Apr 2003 17:38:26-0800 From: "Jerry C Dethlefs" <Jerry. C.Dethlefs@conocophillips.com> To: Tom Maunder <tom_maunder@admin.state.ak.us> CC: "n1617" <n1617@conocophillips.com> Tom: Attached is a letter and spreadsheet with the data mentioned in the previous email. Thanks for the relief on all the Sundry's! Let me know if you need additional information. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska(See attached file: AOGCC ALPINE cement top outs 04-16-03.xls)(See attached file: Cement Top Fill AOGCC Letter 04-23-03.doc) Tom Maunder <tom_maunder@admin.state.ak.us> 04/23/2003 12:51 PM To: Jerry C Dethlefs/PPCO@Phillips CC: Subject: Re: Sundry's for topping off cement Hi Jerry, I agree Jerry that individual 404's aren't necessary. Send a "global document" with the information you list. There should also be some sort of introduction that describes why you did what you did and how you did it. Tom Jerry C Dethlefs wrote: > Tom: Last week we had a cement crew go down the line at Alpine, top filling > the conductors with cement. I believe 34 wells were treated. Chuck Scheve > and John Crisp were notified but declined to witness when we told them what > we were doing. Some time past we had agreed to submit a 10-404 for this > kind of work. Due to the number of these, is a 10-404 needed on each well? > I don't want to commit the time to doing this if it is not necessary; > 10-404's are time consuming to prepare. Would a list of the jobs suffice, > or something similar? We have the well numbers, depth to cement top, and > sacks used to fill the void. My proposal would not affect future > submissions of 10-404's for this work. What do you think? Thanks! > Jerry Dethlefs (See attached file: tom_maunder.vcf) 1 of ~.~"O/~E~' ~¥ ~ 0 2003 4/24/2003 7:55 AM Alpine Cement Top Fill r--.. Name: AOGCC ALPINE cement top outs 04-16-03.xlsI ~ AOGCC ALPINE cement top outs 04-16-03.xls Type-. EXCEL File (application/msexcel) ......................................................................................... _.Encoding-._base64 .............................................................................. DCement Top Fill AOGCC Letter 04-23-03.doc Name: Cement Top Fill AOGCC Letter 04-23-03.doc' Type: WlNWORD File (application/msword) Encoding: base64 Tom Maunder <tom maunder~admin.state.ak, us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2 of ~OAt'~E~' ~ ~ 0 2_003 4/24/2003 7:55 AM 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 Convert from Producer to WAG 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 220' FNL, 2706' FEL, Sec. 5, T11N, R5E, UM 5. Type of Well: Development _ Exploratory __ Stratigraphic _ Service_X (asp's 386000, 5975905) 6. Datum elevation (DF or KB feet) RKB 37' feet 7. Unit or Property name Colville River Unit 8. Well number CD1-01 At top of productive interval 1102' FSL, 2424' FEL, Sec. 32, T12N, R5E, UM At effective depth At total depth 1566' FNL, 3779' FEL, Sec. 32, T12N, R5E, UM (asp's 384975, 5979854) 9. Permit number / approval number 199-046 / 10. APl number 50-103-20299 11. Field / Pool Alpine Oil Pool / Colville River Field 12. Present well condition summary Total depth: measured true vertical 10289 6954 feet feet Plugs (measured) Effective depth: measured true vertical 10289 feet 6954 feet Junk (measured) Casing CONDUCTOR SURF CASING PROD CASING OPEN HOLE OPEN HOLE Length 114' 2411' 7752' Size 16" 9-5/8" 7" Cemented Measured Depth True vertical Depth 9 cu. Yds. High Early 1 14' 121' 520 sx AS III LW, 230 sx Class G 2411' 2395' 165 sx Class G 7752' 6991' Perforation depth: measured open hole 7752' - 10289' true vertical open hole 6991' - 6954' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 Tbg @ 7290' MD. /, · Packers & SSSV (type & measured depth) BAKER S~3 PACKER @ 7180' MD. WSRV CAMCO A-1 INJECTION VALVE, ORIFICE 1.125" - SET 7/19/00 @ 1013' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl Representative Daily Average Production or Iniection Data Gas-Mcf Water-Bbl NA Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil __ Gas __ Suspended __ Service _WAG Injector XX 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signcehrd,.s Pierso~/~ Title Alpine Engineer Questions? Call Chris Pierson 265-6112 Date Prepared by Sharon ,Al/sup-Drake 263-4612 6C;ANNED MAY Z 9 2002: Fnrm 1 ~-/tCizt R~.v {3R/1.R/RR ,, JAN 31 2002 SUBMIT IN DUPLICATE Ms. Wendy Mahan AOGCC Third Quarter 2000 Annular Injection Report Page Two Total Volumes into Annuli for which Injection Authorization Expired during, the third quarter 2000: ............................. ~ ............. j ............. ~otal ~ ' Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus CD1-39 31408 100 0 31508 Open, Freeze Protected 1D-12 32791 100 0 32891 Open, Freeze Protected CD1-37 32487 100 0 32587 Open, Freeze Protected CD1-23 33886 100 0 33986 Open, Freeze Protected CD1-01 5121 100 0 5221 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC2 Marty Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kuparuk Environmental: Engel / Snodgrass B. Morrison and M. Winfree Sharon Allsup-Drake Well Files 199-046-0 COLVILLE RIV UNIT CD1-01 50- 103-20299-00 Roll #1: Start: Stop Roll #2: Start Stop MD 102_8_9_?; TVD 06954 '"Completion Da~"~28/99-Completed Status: 1-OIL PHILLIPS ALASKA INC Current: T Name c 9280 C...-'~ c 9388 L ADN-M D~--e"~- L ADNoMD L ADN-TVD .~-''''~" L ADN-TVD L BHCS/GR L CDR-MD L CDR-TVD L PEX-NDT L RAB-MD L RAB-TVD L USIT R SRVY CALC R SRVY RPT R SRVY RPT Interval Sent Received 2-12 SCHLUM IMP-CDR/ADN OH 8/t9/99 8/19/99 2 SCHLUM CDR/ADN-PDC REV 2 OH 11/12/99 11/23/99 FlNAL 6610-9930 Oil 8/19/99 8/19/99 FINAL 5940-9030 REV 2 Oil 2/5 11/12/99 11/23/99 FINAL 6450-7000 OH 8/19/99 8/19/99 FINAL 6500-6950 REV 2 OH 2/5 11/12/99 11/23/99 ~ FINAL 2411-7310 PB1 OH 8/4/99 8/13/99 FINAL 2350-10280 OH 8/19/99 8/19/99 FINAL 2350-7000 OH 8/19/99 8/19/99 L CMR / FINAL 2411-7310 PB1 OH 8/4/99 8/13/99 L INJ TEST-PSP{,~'"'~ FINAL 6614-10252 CH 5 4/11/00 4/28/00 L PEX-AIT '-~AL 2411-7310 PB1 OH 8/4/99 8/13/99 L PEX-AIT/BHCS/CMR (..FA4¢A~'~400-7130 PB1 OH 5 8/4/99 8/13/99 FINAL 2411-7310 PBI OH 8/4/99 8/13/99 /.,,,.'P~'AL 2416-7327 PBI OH 8/4/99 8/13/99 ~~NA{. 2400-7130 PB1 OH 8/4/99 8/13/99 ~ -.-.=-~--'~N'~'-~43~-~C~)-6270-7454 6/28/99 CH 5 7/15/99 7/26/99 6B~5850.68-10289. PB1 OH 10/6/99 10/7/99 /~HL~jM 115-10289. OH 7/10/99 7/15/99 ~M3C~JM 115-7305 PILOT HOLE OH 7/13/99 7/13/99 T/C/D Wednesday, May 02, 2001 Page 1 of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser ~?~- \.~? DATE: March 30, 2001 Chairman ~:jr~~UBJECT:~ Mechanical Integdty Tests THRU: Tom Maunder Phillips P.I. Supervisor CDIAlpine t,t. [~,-O \ COlvilte River Unit FROM: Chuck Scheve Alpine Petroleum Inspector NON- CONFIDENTIAL . , , , Packer. Depth ,, Prete~t,, JniUa.! 15Min. 3,oMin. , , , CD!~,I. ITYPeinj~I STM I T.v.D..! 68~5 I Tu~ngl _450.1 '4501 450 !..4~0 ~i'n.t~, I I I l'~"lTyP~t~tlPITestpsii !721 lcasingl 350 I2000 !. 2000I2000I P~.,. I.P I I Notes: P.T.D_.I Notes: , W~,l Notes: , .P;T.0.1 !Notes: .... w~l Notes: P.T.0.1 Notes: vv'~lI cm4~ I Yy~;'nJ. I' s '.1. T,~/.Di_I6'~33 I'Tubi_'ng_.) 450' I" ~:~0 ! 4501 I 4~0 l'.t~_!i .._l P.T.D.I 199-094.lTypetesti. P ITmtpsj. I. 1.683 I.Cas!ngl 0 I-1.800 ,I !,800. I.,1800 I P/F I P Notes: ' , ..... ~ ~ , 'weq cm49 ]Typ~lnj. I ,, N J ,T.V.D,. I ~2b LTubingi 2200 ! 2200'! 22OO 1.2200 lintava~l ~ Notes: Class 2 disposal well w",lCD1'23 I T~'Pel,n,i'l "'1' T.V:D. I ~7~ I Tu~n~ I 2~ I' 2~o !" 2~' I' 250 I~nterva~t '~ P:T'D'I 'i99-063 I'Tyr~e. t&l p J T~stPSiI 'lSSD I Casingl 'o"1'19oo ! ~9oo I ~00o i' P/F I _P Notes: This well failed a ,previous test 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 Pre~ure Test R= Internal RadioaclJve Trac~ Survey A= TempemtureAnomaly Survey D= Differential Temperature Test hltervat != Initial Test 4= Four Year Cycle v= Required by Variance (3= O~he~ (describe in no~) Tset's Details I traveled to the Phillips Alpine location and witnessed the ~~.es~ ~ 9 in'eetion wells. All pretest pressures were observed for 1 hour+ while waiting for pumping equipment to arrive and were found to be stable. A standard annulus pressure test was then performed with all 9 wells demonstrafin~ _~xt mechanical integri~. M.l.T.'s pertormed: _.9 Number ot Failuresf _~ Total Time during tests: Attachments: cc; MIT report form 5112100 L.G. 010330-MIT Alpine-CS 4/4/01 PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 October 13, 2000 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, Third Quarter, 2000 Dear Ms. Mahan: Please find reposed below the volumes injected into surface casing by ~uct~on casing annuli during the third queer of 2000, as well as total volumes injected into annuli for w~ch injection authorization expired during the thrd queer of 2000. Annular Injection during the third quarter of 2000: h(1) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total CD1-45 5036 100 0 5136 365 5501 CD1-03 33505 100 0 33605 385 33990 1D-14 33916 100 0 34016 1487.5 35503.6 CD1-25 24860 100 0 24960 8627 33587 2N-341 13544 100 0 13644 20506 34150 2N-335 25395 100 0 25495 0 25495 2N-347 14666 100 0 14766 340 15106 1D-38 33907 100 0 34007 0 34007 1D-30 30492 100 0 30592 0 30592 2N-318 220 100 0 320 0 320 2N-316 240 100 0 340 0 340 CD1-43 285 100 0 385 0 385 'iD'loB 1.Do - IG 'LOO.. oqO' Ms. Wendy Mahan AOGCC Third Quarter 2000 Annular Injection Report Page Two Total Volume: into Annuli for which Injection Authorization Expired during the third quarter 2000: Total Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus CD1-39 31408 100 0 31508 Open, Freeze Protected 1D-12 32791 100 0 32891 Open, Freeze Protected CD1-37 32487 100 0 32587 Open, Freeze Protected CD 1-23 33886 100 0 33986 Open, Freeze Protected CD1-01 5121 100 0 5221 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC: Marry Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kuparuk Environmental: Engel / Snodgrass B. Morrison and M. Winfree Sharon Allsup-Drake Well Files STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate X Plugging _ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__X RKB 37 feet 3. Address Explorato~._ 7. Unit or Property name P. O. Box 100360 Stratigraphic._ Anchorage, AK 99510-0360 Service__ Colville River Unit 4. Location of well at surface 8. Well number 222' FNL, 2572' FWL, Sec. 5, T11N, R5E, UM CD1-01 At top of productive interval 9. Permit number / approval number 1102' FSL, 2424' FEL, SEC. 32, T12N, R5E, UM 199-046/300-067 At effective depth 10. APl number 50-103-20299 At total depth 11. Field / Pool 1569' FNL, 1501' FWL, Sec. 32, T12N, R5E, UM Colville River Field/Alpine Oil Pool 12. Present well condition summary Total depth: measured 10289 feet Plugs (measured) true vertical 6954 feet Effective depth: measured 10289 feet Junk(measured) true vertical 6954 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 84' 16" 9 CU YDS High Early 121' 121' SURFACE 2374' 9-5/8" 520 sx AS III LW, 230 sx Class G 2411' 2395' PRODUCTION 7715' 7" 165 sx Class G 7752' 6991' Perforation depth: measured openhole completion 7752' - 10289' D ~ ~% ~ true vertical openhole completion 6991'-6954' MAY 0 3 2000 ITubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 Tbg @ 7290' MD. ~8.~8 0~i ~ ~-8S Packers & 8S8V (type & measured depth) BAKER S-3 PAOKER @ 7180' MD. OAMOO A-1 8SSV @ 1013' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data C)il-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation - - Subsequent to operation - 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run ~ Daily Report of Well Operations ~X Oil .__X Gas __ Suspended __ Service _Gas Injection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed . Title ARCO Engineering Supervisor Date '~_'__ Michael D. Erin Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE CD1-01 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 03/23/00 03/24/00 03~25~0O 03/20/00 03/31/00 04/01/00 04/02/00 04~03~00 MIRU CTU. Completed a tubing wash by circulating a 30 bbl. caustic pill from the 7" shoe back to surface at 1.8 bpm. Washed to TD with 9.2 ppg brine and circulated a 10 bbl. surfactant pill around to clean the openhole. Washed and rotated through the openhole to clean up drilled solids with brine. Tag TD. Layed in approximately 115 bbl. of BJ Mudzyme breaker in the openhole. Pulled out of hole to allow breaker to soak. Freeze protected wellbore with 38 bbl. diesel. No activity - allow enzyme breaker to soak. MIRU CTU. Trip to bottom and wash out spent Mudzyme with seawater at 2.3 bpm. Lay in formic acid across the openhole interval. Allow to briefly soak and then wash and spray the openhole with remainder of 8% formic acid. Total acid volume 180 bbl. Over flush with 250 bbl. seawater at 2.5 bpm. Perform step rate test BPM Inj Press 0.33 370 0.50 520 0.75 655 1.0 815 1.5 895 2.0 950 2.5 1010 3.0 1080 Fracture Gradient break observed at 1.1 bpm - (0.56 psi/ft) Freeze protected the well with 35 bbl. diesel. RDMO CTU. Clear ice from tree with hot oil. RU Slickline. Run and set tandem pressure gauges in XN below the packer. RD. RU DS frac equipment. Begin pumping pulse test at 0930 hrs - pumping seawater @ 5.1 bpm. Continue pumping continuously at 5.1 bpm, 1180 psi - daily total 7344 bbl., cum total 11,781 bbl. Continue pumping continuously at 5.1 bpm - daily total 7344 bbl., cum total 19,125 bbl. Continue pumping, rates inch up to 5.2 bpm, 1180 psi - daily total 4613 bbl., cum when shut down due to diesel engine failure 23,738 bbl. Wait 1 hour and finish pumping 30 bbl. diesel freeze protection. RDMO DS. 2000 cc: w/enclosures Mr. Kenneth A. Boyd, Director Alaska Department of Natural Resources Division of Oil & Gas 3601 C Street, Suite 1380 Anchorage, Alaska 99503-5948 Ms. Teresa Imm, Resource Development Manager Arctic Slope Regional Corporation 301 Arctic Slope Avenue, Suite 300 Anchorage, Alaska 99518-3035 Mr. Isaac Nukapigak, President Kuukpik Corporation PO Box 187 Nuiqsut, Alaska 99789-0187 Mrs. Catherine Lively Anadarko Petroleum Corporation PO Box 1330 Houston, Texas 77251-1330 4/11/00 Schlumberger NO. 121366 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: Alpine (Cased Hole) Color Well Job # Log Description Date BL Sepia Prints CD WD-2 (.//(~ TEMPERATURE SURVEY 000401 I 1 WD-2 TEMPERATURE SURVEY 000404 I 1 CD1-01 INJ PULSE TEST LOG/MEM PSP 000327 I 1 Kl",.EIV L APR 2 8 2000 SIGNED:~)~ DATE: Naska 0ii & Gas ~..u,mmssi0n .__.Anchorage Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. T.~,fIK yOU. STATE OF ALASKA ALA,~KA OIL AND GAS CONSERVATION COMMISSION~-y-' APPLICATION FOR SUNDRY APPROVALS 7. Type of request: Abandon _ Suspend__ Operation Shutdown __ Reenter suspended well__ Alter casing __ Repair well __ Plugging __ Time extension __ Stimulate X Change approved program __ Pull tubing __ Variance__ Perforate __ Other__ 2. Name of Operator: 5. Type of Welh 6. Datum of elevation (DF or KB feet): ARCO Alaska, Inc. Development_X 37' RKB feet 3. Address: Exploratory__ 7. Unit or Property: P.O. Box 100360, Anchorage, Ak, 99510-0360 Stratagrapic__ Colville River Unit Service __ 4. Location of well at surface: !8. Well number: CD1-01 222' FNL & 2572' FWL of Sec 5, T11N, R5E, UM At top of productive interval: 9. Permit number: 99-46 V/' 1102' FSL & 2424' FEL of Sec 32, T12N, R5E, UM At effective depth: 10. APl number: 50-103-20299-00 *,/" At total depth: 11. Field/Pool: Colville River Field 1569' FNL & 1501' FWL of Sec 32, T12N, R5E, UM Alpine Oil Pool 12. Present well condition summary Total Depth: truemeasuredvertical 10289 feet ¢/~6954 feet ~/ Plugs (measured) N/A Effective Depth: measured 10289 feet Junk (measured) N/A true vertical 6954 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 121 feet 16" 9 yd3 High Early 121 feet 121 feet Surface 2412 feet 9-5/8" 520 sxAS III LW 2412 feet 2395 feet 230 sx Class G Intermediate 7752 feet 7" 165 sx Class G 7752 feet 6991 feet Perforation Depth measured Openhole 7752'- 10289' T:-' ::x ::: i: '~:~_~ ?~'~ true vertical Openhole 6991'- 6954' . Tubing (size, grade, and measured depth) 4-1/2", 12.6 ppf, L-80 IBT-Mod @ 7,289' MD Packers and SSSV (type and measured depth) 4-1/2" x 7" Baker S-3 @ 7,179' MD .: .. 4-1/2" Camco A-1 SSSV in DB-6 nipple @ 1,013' MD 13. Attachments Description summary of proposal X Detailed operations program BOP sketch_X 14. Estimated date for commencing operation 15. Status of well classification as: March 22, 2000 ~ Gas__ Suspended__ 16. If proposal was verbally approved Name of approver Date approved Service ~' ~,.~.~ 17. I hereby certify that the forgoing is true and correct to the best of my knowledge. Signed//")~~C~l~ ~ Title: Alpine StaffEngineer Date FOR COMMISSION USE ONLY Conditions of approval: Notify Comission so representitive may witness Approval No. Plug integrety BOP test_~ iI~ _ - Location clearance__ ' Mechanical integretytest'~_ Subsequent form required 10- ~'~(~1, pc~,~.c,...~'t~.~,~.¢~_¢~.~.\'~,~.,~¢,.%~,~. '~.~'~ ~'~-~-~\~-~ ,L~pJC-~if'4At ~SiGNED BY' ,mq¢,6 O°9~j Approved by order of the Commissioner ~Cl~.l~..f~ i" ~.-;.IFiri.~t,l~,O~ .~r~~ /~3~'~ ~9~mmissioner Date ~ Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE Stimulation Procedure Colville River Field CDI-O1 Conversion operations will commence following ice road construction on or about March 22, 2000. Completion is expected on or about April 15, 2000. This procedure is designed to clean out and stimulate a newly drilled WAG well for injection. The goal is to remove remnant drill cuttings, filter cake and polymer from the openhole completion. In the process additional surveillance logging will provide insight into the performance of the cleaning procedure and the effective injection length of the wellbore. 1. RU coil tubing unit. GIH with jet nozzle into the 6-1/8" open hole to circulate and wash the hole clean of debris or sand with seawater or brine. 2. Circulate around a caustic pill consisting of approximately 40 bbl. of Arco's Caustic SL, chased by seawater or brine. 3. Spot +/-150 bbl. ofMudzyme S/X Breaker m/xed in a 9.2 ppg KCL base fluid in the openhole interval. 4. POOH and allow the breaker to soak for 16-24 hours. 5. GIH with coil and an openhole test packer and displace out the Mudzyme Breaker with an 8% formic acid solution in 9.2 ppg KC1. 6. Set the packer within 100' of the toe of the wellbore and break down the formation with seawater or brine. 7. Release the packer and POOH. 8. GIH with coil tubing conveyed memory production logging tools and perform a spinner survey to identify effective injection length of the wellbore. 9. POOH and RD coil tubing. 10. RU slickline. Install tandem pressure recording gauges in the XN nipple below the packer. 11. Pump an injection test of approximately 10-20,000 bbl. of fluid. 12. Pull the pressure gauges after 90-120 days. cc: w/enclosures Mr. Kenneth A. Boyd, Director Alaska Department of Natural Resources Division of Oil & Gas 3601 C Street, Suite 1380 Anchorage, Alaska 99503-5948 Ms. Teresa Imm, Resource Development Manager Arctic Slope Regional Corporation 301 Arctic Slope Avenue, Suite 300 Anchorage, Alaska 99518-3035 Mr. Isaac Nukapigak, President Kuukpik Corporation PO Box 187 Nuiqsut, Alaska 99789-0187 Mrs. Catherine Lively Anadarko Petroleum Corporation PO Box 1330 Houston, Texas 77251-1330 RECEIVED MAR 1 6 2000 Alaska Oil & Gas Cons. Commissior, Anchorage Alpine Field CL I-01 Injection Complet 16" Conductor to 114' MD RKB - GL = 37' APl 50-103-20299-00 -5/8" TAM crt Collar @1012' 4-1/2" Camco "A-I" SSSV (2.125" ID) in DB-6 Lock (3.812" ID) @ 1,013' MD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2411' MD/2395' TVD cemented to surface Packer Fluid mix: 9.2 ppg KCI Brine with EC-1124A and +/-1000' diesel cap in tubing and casing 4-1/2" 12.6 ppf L-80 IBT Mod. tubing (Jet Lube Run'n'Seal) Pilot hole mented with g starting at 5900' MD TOC +/- 6800' MD i per USIT 7/28/99 RECEIVED MAR 1 6 2000 Alaska 0il & 6as Cons. Commission Anchorage 1 - Baker S-3 Packer (3.875" ID) at 7180'MD / 6829' TVDSS - 58 deg 2 - 4-1/2" joints (2) blank tubing 3 - HES "XN" (3.725" ID) LN at 7256' MD 4 - 4-1/2" joint tubing (1) 5 - 4-1/2" WLEG at 7290' MD 6-1/8" Openhole TD @ 10289' MD 6954'-I-VD 7" 26 ppf L-80 BTC Mod Production Casing @ 7752'MD / 6991' TVD (94 deg) Updated 7/6/99 C T Drilling Wellhead Detail ~ CT Injector Head Methanol Injection tis 7" WLA Quick ~ ' I onnect --'-- I - 1 Annular BOP (Hydril),7-1/16' ID 5,000 psi working pressure -- Alignment Guide Flange . ~,1 I ,~ ~5') ~ ~ ~ Cutters or 7-1/16', 5M Ram Type Dual ~- ~ ~ ~ Combination Cutter/Blinds .- .. . Gate BOPE ~ k.~ ~ Slip / Pipe rams Flanged ~-~re Hesislan! ManlualTal~ ~ Kelly Hose to Dual HCR Choke Manifold ~_~~-"-'~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure ~ I "-' 7' Riser Manual Valves Drilling sPool 7-1/16', 5M by 7-1/16', 5M Ram Type Dual Gate BOPE Manual over Hydraulic ~ 7-1/16' ID with Pipe/Slip Rams Manual Master Valve 0.458' (5.5') 2' Pump-In Hanger Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold 9-5/8' Annulus . 13-3/8 Annulus RECEIVED ~AR ~ 6 ~000 Alaska 0il & ~s C.~in~. G0mmiss~or Anchorage ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 24, 2000 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Revised Kuparuk Area Annular Injection, Fourth Quarter, 1999 Dear Ms. Mahan: Oil & '.-~ ~,~,~ oons. Commission Anchorage Please find reported below the volumes injected into surface casing by production casing annuli during the fourth quarter of 1999, as well as total volumes injected into annuli for which injection authorization expired during the fourth quarter of 1999. Annular Injection during th '. fourth quarter of 1999: h(1) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total CD 1-37 15214 100 0 15314 17273 32587 CD1-39 27391 100 0 27491 4017 31508 ID- 12 27089 100 0 27189 5702 32891 CDI-16 28925 100 0 29025 0 29025 CD1-32 7449 100 0 7549 0 7549 CD 1-03 285 100 0 385 0 385 CD 1-42 287 100 0 387 0 387 CD1-40 20 0 0 20 32649 32669 CD 1-45 274 100 0 374 0 374 CD 1-36 293 100 0 393 0 393 CD1-35 217 100 0 317 0 317 CD1-23 20 0 0 20 17085 17105 CDI-13 89 100 0 189 0 189 CD1-01 20 0 0 20 5201 5221 Total Volumes into Annuli for which Injection Authorization Expired during the fourth quarter ] Total Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected ] Status of Annulus ~ Open, Freeze Protected 2N-315 25326 100 0 25426 2L-329A 33971 100 0 34071 I Open, Freeze Protected I ~ Open, Freeze Protected 2L-325 20280 100 0 20380 ! Open, Freeze Protected 2L-313 12433 100 0 12533 Ms. Wendy Mahan AOGCC Fourth Quarter 1999 Annular Injection Report Page Two 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 Momson and Winfree Sharon Allsup-Drake Well Files Scblmberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 12928 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 11 / 12/99 Field: Alpine Color Well Job # Log Description Date BL Sepia Prints CD CD1-24 (REPROCESSED) ~t4.. 99215 CDR/A~N (~'DC) ~ 6]"~ [~ 990503 1 CD1-24 (REPROCESSED) / 99215 ADN 990503 I 1 CD1-24 (REPROCESSED),,~ 99215 ADN TVD 990503 I 1 CD1-40 (REPROCESSED) 99251 A.DN/CDR (PDC) ~ ~t'~'~ 99052'/ 1 CD1-40 (REPROCESSED) 99251 ADN 99052'/ I 1 =CD1-40 (REPROCESSED) 99251 ~DN ~ 99052'/ I 1 !CD1-01 (REPROCESSED) 99286 CDR/ADN (PDC) ~_ ~~ 990626 1 CD1-01 ,(REPROCESSED) 99286 ADN 990626 I 1 iCD1-01 (REPROCESSED) 99286 ADN TVD 990626 I 1 CD1-13 99~,03 SCMT 991001 I Ala~i~a Oil & Gas Oo.~,, Coi,'~mi!~i~i,,:~ ~ Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. ~llC~Ol'i~[¥~ ARCO Alaska, inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 15, 1999 Ms. Wend,,, Mahan Natural Resource Manager Alaska Oil and Cdas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re' Kuparuk Area Annular Injection, Third Quarter, 1999 Dear Ms. Mahan' 99'51 99- 44- 'hq-}+ 99- 6-x - ~9- g'9 - Please find reported below volumes injected into surf'ace 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. Am~ttlar b!/ection during the third quarter of !999: Well Name 1C-25 CD1-40 CD1-01 1C-23 CD1-23 CD1-37 CD1-39 1D-12 h(1) Volume 520 20079 4905 24865 16079 17173 3917 h(2) Volume 100 i00 100 100 100 100 100 4305 100 h(3) Volume Total for I Previous QuarterI' Total ~ 34316 620 [ 20179 5005 24965 16179 17273 4017 4405 12171 9605 New Total 34936 32350 5005 34570 16719 17273 4017 ' 4405 Total Vohmte, Well Name 1D-09 into Ammli for which b~./ection Authorization Expired during the quarter Total h(1) Volume 32540 Total h(2) Volume 100 Total h(3) Volume Total Volume Injected 32640 30639 Status of Annulus Open, Freeze Protected Open, Freeze Protected 2N-337A 30539 100 2N-313 32758 100 0 i 32858 Open, Freeze Protected 2N-321A 27507 100 0 , 27607 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely. Paul Mazzolini -~ i~ ~ : , ~r ~-. ,~ ', Drilling Team Leader .xncn0ra-ae CC' Mike Zang. hi 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 _ STATE OF ALASKA ..... ~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~1. Status of well Classification of Service Well Oil [~] Gas [] Suspended FI Abandoned D Service D 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 99-46 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-103-20299 4. Location of well at surface .f~ ................... 9. Unit or Lease Name ' .-;~i:.-"~::~!! .:. . . .. Colville River Unit 222' FNL, 2572' FWL, Sec. 5, T11N, R5E, UM ~ - ': AtTop Producing Interval " ! "'~ ~i"'; Li~ ~'-" ~'"'~'"~ ~;i~ 10. Well Number 1102' FSL 2424' FEL Sec 32 T12N RSE UM'r"',, !'/~"~~-' ...... '"4 ¥'~d~ L~'!¢Zi. ~ ~ CD1-01 At Total Depth r ,,4~ -z i 11. Field and Pool ! ,1569 FNL, 1501' FWL, Sec. 32, T12N, R5E, UM ............. ~ ....... .~:: ii~i ~ Colville River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Alpine Oil Pool 37' RKB feetI ADL 25558 12. Date Spudded 13. Date T.D. Reached ..1..4. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions · May31, 1999 June27, 1999 x,, June28, 1999I N/A feetMSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional ~urvey 20..Depth where SSSVset 2!. Thickness of Permafrost 102¢89' M D / 6954' TVD 10289' M D / 6954' TVD YES' ~ No FI '",; N/A feet MD '~. 862' 22. Type Electric or ~Dther Logs Run GR/Res/Neut/Dens 23. CASING, LINER AND CEMENTING RECORD SE3-FING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO-II-OM HOLE SIZE CEMENTING RECORD/ AMOUNT PULLED 16" 62.5# H-40 Surface 121' 42" 9 cu yds High Early ~,- 9.625" 36# J-55 Surface 2412' 12.25" 520 sx AS III LW, 230 sx Class G :~' 7" 26# L-80 Surface 7752' 8.5" 165 sx Class G . "~ 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE IDEPTH SET (MD) PACKER SET (MD) 4.5" 7289' 7179' open hole completion 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7" casing squeezed 2 times:19.5 bb115.8 ppg cement and 8 bbls cement 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Waiting on production facility start-up Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO I Test Period > Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) 24-Hour Rate > 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKERS NAME Alpine D Base Alpine MEAS. DEPTH 7259' 7530' FO RMATION TESTS TRUE VERT. DEPTH 6925' 6996' Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby ce,~ify that the following is true and correct to the best of my knowledge. Signed~ ~--~~ Title Drilling Team Leader DtChesterv' ' ~ Date INSTRUCTIONS Prepared by Sharon Aflsup-Drake General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval repoded in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL)or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Fo rm 10-407 Date: 08/23/99 ARCO ALASKA INC. WELL SIIMMARY REPORT Page: 1 WELL:CD1-01 WELL_ID: 998B09 TYPE: STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: ALPINE SPUD:05/31/99 START COMP: RIG:DOYON 19 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20299-00 05/30/99 (D1) TD/TVD: 121/121 SUPV:MIKE WHITELEY MW: 8.7 VISC: 210 PV/YP: 14/31 (121) DRILLING AT 500' APIWL: 13.6 Move rig from CD1-40 to CD1-01. Accept rig @ 1900 hrs. 5/30/99. Function test diverter. UPCOMING OPERATIONS:DRILL 05/31/99 (D2) TD/TVD: 1888/121 SUPV:MIKE WHITELEY MW: 9.6 VISC: 180 PV/YP: 16/45 (1767) DRILLING AT 2300' APIWL: 8.8 Drilled from 295' to 1396'. Getting weak signal on MWD. POH to check MWD. Drill from 1396' to 2280' UPCOMING OPERATIONS: DRILL TO CASING POINT 06/01/99 (D3) MW: 9.6 VISC: 68 PV/YP: 22/18 APIWL: 10.0 TD/TVD: 2416/2400 ( 528) CIP @ 0520 HRS. LD CMT HEAD AND LANDING JT SUPV:MIKE WHITELEY Drill from 1888'- 2416' POOH to 500' Swabbing. RIH, wipe thru tight hole from 760'-1000'.PJSM. Ran 9-5/8" casing. UPCOMING OPERATIONS:ND / NU 06/02/99 (D4) MW: 9.4 VISC: 45 PV/YP: 14/ 0 APIWL: 7.5 TD/TVD: 2416/2400 ( 0) DRILLING AHEAD AT 2,685' SUPV:MIKE WHITELEY PJSM. Pump cement for 9-5/8" casing. RIH to 2000'o Kick while tripping drill followed by well kill drill. UPCOMING OPERATIONS:DRILL / SHORT TRIP 06/03/99 (D5) MW: 9.6 VISC: 44 PV/YP: 925/ 0 TD/TVD: 4680/4662 (2264) DRILLING AHEAD AT 4900' SUPV:MIKE WHITELEY APIWL: 5.0 Test 9-5/8" casing to 2500 psi, held. Drill out pluts, float collar and cement to 2400' Drill out shoe and 20' new hole to 2436'. Performed FIT test, EMW=15.0 ppg. Drill from 2436'-4204'. POOH to 9-5/8" shoe, slight swabbing. CBU, gas cut mud from bottom. Drill from 4204'-4680' UPCOMING OPERATIONS:DRILL TO 6,600'. TRIP FOR BHA CHANGE. 06/04/99 (D6) MW: 9.7 VISC: 40 PV/YP: 8/24 APIWL: 6.5 TD/TVD: 6181/6080 (1501) DRILLING AHEAD AT 6,576' SUPV:MIKE WHITELEY Drill from 4608' to 6181' UPCOMING OPERATIONS:TRIP FOR BHA AT 6,448'TVD - CLEAN PITS Date: 08/23/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 06/05/99 (D7) MW: 9.9 VISC: 45 PV/YP: 11/28 APIWL: 5.8 TD/TVD: 6576/6448 ( 395 DISPLACING HOLE WITH CORING FLUID SUPV:MIKE WHITELEY Drill from 6181' to 6576'. Log with R_AB tool from 6516'-6576' UPCOMING OPERATIONS:DRILL TO CORE POINT 06/06/99 (DS) MW: 9.9 VISC: 82 PV/YP: 38/25 APIWL: 2.8 TD/TVD: 7018/6862 ( 442) DRILLED TO CORE POINT AT 7,098'o MAKING WIPER TRIP AT SUPV:MIKE WHITELEY Circ and cond mud and hole, fill pit 9.8 ppg coring fluid for change out. Pump high vis KC1 spacer. Displace hole with 9.8 ppg coring fluid. Drill from 6576'-7018' UPCOMING OPERATIONS:POOH FOR CORE BARREL 06/07/99 (Dg) MW: 10.2 VISC: 157 PV/YP: 51/41 APIWL: 2.2 TD/TVD: 7106/6944 ( 88) CORRING ALPINE SD AT 7,181' SUPV:MIKE WHITELEY Drill from 7018' to core point at 7098'. CBU. Slight swabbing. PJSM. Make up 90' core barrel. RIH. Core from 7098'-7106' UPCOMING OPERATIONS:POOH WITH CORE BARREL. 06/08/99 (D10) MW: 9.8 VISC: 65 PV/YP: 24/ 0 APIWL: 3.5 TD/TVD: 7183/7016 ( 77) TD'D @ 7,331'. CIRC AND COND MUD AND HOLE FOR OH LOGS SUPV:MIKE WHITELEY Finish coring Alpine sand from 7106' to 7183.5'. POOH with core barrel. UPCOMING OPERATIONS:POOH - LOG 06/09/99 (Dll) MW: 9.8 VISC: 84 PV/YP: 25/23 APIWL: 3.5 TD/TVD: 7331/7154 (148) WL LOGS SUPV:DONALD LUTRICK MAD pass f/7080'-7183' Drilling from 7183'-7331'. PJSM. RIH. Unable to work tools below 3875' Wash and ream from 3700'-3986' UPCOMING OPERATIONS:SET CEMENT PLUGS 06/10/99 (D12) MW: 9.9 VISC: 64 PV/YP: 20/19 APIWL: 4.0 TD/TVD: 7331/7154 ( 0) WASH DOWN TO FIND TOC SUPV:DONALD LUTRICK Circ and condition mud for cement plugs. PJSM. Pump cement. Est TOC at 6970' Pump cement. Est TOC at 5800' UPCOMING OPERATIONS:SIDETRACK Date: 08/23/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 06/11/99 (D13) TD/TVD: 7331/7154 SUPV:DONALD LUTRICK MW: 9.8 VISC: 49 PV/YP: 15/14 0) PREP TO DRILL CEMENT APIWL: 6.0 Tag firm cement at 5940'. Attempt to sidetrack at 45 deg. with no success. Time drill at several depths from 5940' to 6104' Circ and condition mud for balanced plug. PJSM. Pump cement and mud to balance plug. UPCOMING OPERATIONS:SIDETRACK 06/12/99 (D14) TD/TVD: 6207/6097 ( SUPV:DONALD LUTRICK MW: 9.9 VISC: 51 PV/YP: 15/18 0) DRLG AT 6400' APIWL: 7.8 RIH. Hit bridge at 3028'. Wash and ream from 3028' to 3220'. Wash and ream from 5533' to 5844' Drill out firm cement from 5844' to 5900' Time drill and sidetrack well 5900' to 5930' Drilling from 5930' to 6207' UPCOMING OPERATIONS:BHA CHANGE AT 6800' 06/13/99 (D15) MW: 9.8 VISC: 68 PV/YP: 24/25 TD/TVD: 6765/6581 ( 558) DRLG AT 6800' SUPV:DONALD LUTRICK Drill from 6207' to 6765' UPCOMING OPERATIONS:BUILD TO HORIZONTAL APIWL: 5.3 06/14/99 (D16) MW: 9.8 VISC: 65 PV/YP: 19/24 APIWL: 5.8 TD/TVD: 7253/6935 (488) DRLG SUPV:DONALD LUTRICK Ream from 6229' to 6324'. MAD pass from 6748' to 6765' Drilling from 6765' to 7253' UPCOMING OPERATIONS:WIPERTRIP & TD INTERMEDIATE 06/15/99 (D17) MW: 9.9 VISC: 82 PV/YP: 23/31 APIWL: 5.0 TD/TVD: 7461/6984 ( 208) DRLG AT 7570' SUPV:DONALD LUTRICK Drilling from 7253' to 7461'. Having problem sliding. Indication of underguage bit. UPCOMING OPERATIONS:TD WELL 06/16/99 (D18) MW: 9.8 VISC: 61 PV/YP: 20/28 APIWL: 5.4 TD/TVD: 7762/6995 (301) RIH W/ 7" CSG SUPV:DONALD LUTRICK Ream from 6350' to 6410'. No problems. RIH to 7350' Ream from 7300' to 7461' Drilling from 7461' to 7762' UPCOMING OPERATIONS:CEMENT/TEST BOPE 06/17/99 (D19) TD/TVD: 7762/6995 ( SUPV:DONALD LUTRICK MW: 9.8 VISC: 55 PV/YP: 15/25 0) MU BHA RIH w/ 7" casing. Pump cement. UPCOMING OPERATIONS:PU DP- DRILL FE - LOT APIWL: 6.5 Date: 08/23/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 06/18/99 (D20) TD/TVD: 7762/6995 ( SUPV:DONALD LUTRICK MW: 9.8 VISC: 88 PV/YP: 14/24 0) SWAP MUD TO FLO-PR0 APIWL: 5.4 Test BOPE to 300/3500 psi. Safety meeting. RIH w/3.5" DP. UPCOMING OPERATIONS:DRILL HORIZONTAL 06/19/99 (D21) MW: 9.7 VISC: 50 PV/YP: 7/41 TD/TVD: 7782/6990 ( 20) POH W/ MULESHOE SUPV:DONALD LUTRICK AP IWL: 6.5 RIH to 7561'. Test casing to 3500 psi. Drill out float collar, float shoe and 20' new hole to 7782'. No firm cement in shoe it. CBU. Attempt FIT. Formation taking fluid at 11 ppg. UPCOMING OPERATIONS:DRILL CEMENT AND LOT 06/20/99 (D22) MW: 9.7 VISC: 52 PV/YP: 7/40 APIWL: 6.5 TD/TVD: 7782/6990 ( 0) TRIP IN W/ MULESHOE SUPV:DONALD LUTRICK Pump cement. Squeeze cement. Clean out cement to 7782' PJSM. UPCOMING OPERATIONS:RE-SQUEEZE SHOE 06/21/99 (D23) MW: 9.7 VISC: 45 PV/YP: 9/12 APIWL: 9.0 TD/TVD: 7782/6990 ( 0) DRILLING CEMENT SUPV:DONALD LUTRICK/ WINFREE Perform leak off test. Test lines to 3500 psi spot plug. UPCOMING OPERATIONS:DRILL OUT CMT, DO LOT, TRIP FOR BHA 06/22/99 (D24) MW: 9.2 VISC: 49 PV/YP: 8/25 APIWL: 5.0 TD/TVD: 7852/6990 ( 70) DRILLING AHEAD SUPV:M. WINFREE Wash and ream to 7313' Drilling cement 7313' to 7782'. FIT test to 11.4 ppg. Drilling 7782' to 7800' FIT test to 11.5. Drill rotate and slide from 7800't0 7852' UPCOMING OPERATIONS:DRILLING AHEAD 06/23/99 (D25) MW: 9.2 VISC: 60 PV/YP: 13/42 TD/TVD: 8538/6975 ( 686) DRILLING AHEAD AT 8775' SUPV:MIKE WHITELEY Drill from 7852' to 8538' UPCOMING OPERATIONS:DRILL / SHORT TRIP APIWL: 5.0 06/24/99 (D26) MW: 9.2 VISC: 60 PV/YP: 14/42 TD/TVD: 9078/6971 ( 540) MAKE UP BHA SUPV:MIKE WHITELEY APIWL: 4.0 Drill from 8538' to 8832' Circ clean for short trip, attempt to change MWD to slower data rate mode. Unsuccessful. Made shor trip to 7" shoe. No problems, hole in good shape. Drill from 8832' to 9078'. MAD pass LWD's from 7830'-7765' UPCOMING OPERATIONS:TRIP IN HOLE - DRILL Date: 08/23/99 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 5 06/25/99 (D27) MW: 9.3 VISC: 60 PV/YP: 14/45 APIWL: 3.7 TD/TVD: 9627/6965 ( 549) DRILLING AHEAD AT 9,840. SUPV:MIKE WHITELEY Test BOP's to 250/3500 psi. Drill from 9078' to 9624' UPCOMING OPERATIONS:DRILL 06/26/99 (D28) MW: 9.2 VISC: 65 PV/YP: 14/42 TD/TVD: 9930/6960 ( 303) TD'S AT 10289'. CIRC HOLE CLEAN SUPV:MIKE WHITELEY APIWL: 3 . 6 Drilled from 9624' to 9930' Pulled 7 stands, hole not taking correct fill. Circ bottoms up, no gas/oil. Check flow. Slight flow. Then stable. RIH w/PDC bit. UPCOMING OPERATIONS:POOH - LD BHA - RIH OPEN ENDED TO DISPLACE WITH 9.2 PPG KCL BRINE 06/27/99 (D29) MW: 9.2 VISC: 65 PV/YP: 15/46 TD/TVD:10289/6953 ( 359) POOH L.D. 3 1/2" DP SUPV:MIKE WHITELEY APIWL: 3.4 Finish running in hole to 9910', no problems. Drill from 9930' to 10289'. Pump sweep around. Pumped out first 10 stands. POOH slow. Hole taking correct fill. Hole in good shape. PJSM. Spill drill. Displaced 6.125" OH with 9.2 ppg KCL water. UPCOMING OPERATIONS:RUN USIT LOG AND COMPLETION ASSEMBLEY 06/28/99 (D30) MW: 9.2 VISC: 25 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:10289/6953 ( 0) U-TUBE DIESEL FREEZE PROTECTION SUPV:MIKE WHITELEY POOH to 7700' Observe well, static. Finish displacing well to 9.2 ppg brine. Well stable. PJSM. Ran USIT log from 7450'-6400'. Run 4.5" tubing. UPCOMING OPERATIONS:SET / TEST PACKER 06/29/99 (D31) MW: 9.2 VISC: 25 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:10289/6953 ( 0) RIG RELEASED @ 2300 HRS 6-29-99 SUPV:MIKE WHITELEY Landed tubing. Freeze protect well. ND BOP's. NU tree and test to 5000 psi. Set packer at 7179' Rig release ~ 2300 hrs. 6/29/99. UPCOMING OPERATIONS:MOVE RIG TO CDi-13 PETI OLI U ]I= VICI:::S November 10, 1999 1 Mr. Douglas Knock ARCO Alaska, Inc. 700 G Street Anchorage, Alaska 99510 Subject: Core Analysis Study Alpine CD 1-01 Well File: DAL-99133 Dear Mr. Knock: Core Laboratories' Advanced Technology Center in Carrollton (Dallas), Texas is pleased to present the final report for a core analysis study performed on core matedal recovered from the referenced well. Preliminary information was provided to the client as it became available. A project summary, description of laboratory procedures, and presentation of results are provided within. Seven copies of this final report have been issued. We appreciate this opportunity to have been of service to Arco Alaska, Inc. Please contact us at (972) 466-2673 if you should have any questions regarding this report, or if we may be of further assistance. Sincerely yours, Paul R. Martin Petrophysics Supervisor Dallas Advanced Technology Center 7 copies: addressee ~.-~ Core Laboratories, Inc, 1875 Monetary Lane, Carrollton, Texas 75006-7012, (972) 466-2673, F~ (972) 323-3930, E-mail ~coreiabusa.com Arco Alaska, Inc. File: DAL-99133 PROJECT PARTICIPANTS Basic Properties Dean-Stark Fluid Saturations: Porosity and Permeability Measurements: Project Coordination, Data Evaluation, and Report Preparation: Final Report Review:. Jacque R. Brown Lynn M. Antwine Stephen M. Hoff Paul R. Martin Gary Potter Core Laboratories Arco Alaska, Inc. File: DAL-99133 TABLE OF CONTENTS SECTION 1' SECTION 2: SECTION 3' SECTION 4: SECTION 5: PROJECT SUMMARY LABORATORY PROCEDURES HORIZONTAL PLUG AND DEAN-STARK SATURATIONS DATA 800 & 2400 psi Net Overburden VERTICAL PLUG DATA 800 & 2400 psi Net Overburden GRAIN DENSITY Core Laboratories ARCO Alaska, Inc. File: DAL-99133 SECTION PROJECT SUMMARY Core Laboratories Arco Alaska, Inc. File: DAL-99133 PROJECT SUMMARY Core Reception and Processing-Carrollton, Texas The core processing was performed according to a procedural protocol outlined by Arco Alaska, inc (attached). 81 horizontal and 41 vertical core plugs were cut for routine core properties analysis. Procedures followed are listed in the Laboratory Program section of this report. Laboratory Program Routine plug samples were analyzed in strict accordance with Arco Alaska's protocol described in the laboratory procedures. The horizontal and vertical plugs were subjected to Dean-Stark saturation determination, tracer analysis, cleaning and drying, permeability, porosity and grain density measurements. Laboratory procedures are described in Section 2 and test results are presented in Sections 3 through 5. A summary of sample selection is listed belov~. ROUTINE HORIZONTAL PLUGS ROUTINE VERTICAL PLUGS 81 41 SPECIAL ROUTINE HORIZONTAL PLUGS Preliminary data results were provided to the client on a regular basis. A preliminary core analysis report provided including all horizontal plug permeability and porosity, grain density, saturation data. Core Laboratories ARCO Alaska, Inc. File: DAL-99133 SECTION 2 LABORATORY PROCEDURES Core Laboratories Arco Alaska, Inc. File: DAL-99133 LABORATORY PROCEDURES Laboratory analytical and quality control procedures used during the analysis of the core from the Alpine CD1-01 Well followed the procedural guidelines set forth by Arco Alaska, Inc. Any modifications or additions to the written protocol were by request or by approval of Arco Alaska, Inc. or AEPT Piano. Dean-Stark Analysis Each Dean-Stark flask and associated glassware were cleaned and dried before use. The condenser, core chamber and flask were rinsed 5 times with 20cc of fresh reagent grade toluene before adding toluene to the apparatus for pre-boiling. The sidearm was checked for water and pure toluene was transferred from sidearm to flask, the sidearm was then dried. Each core plug sample was weighed to 0.001 g, placed in a predded and relabeled glass thimble and weighed again. Each plug and thimble was then loaded into the Dean-Stark apparatus. The system was sealed with Teflon tape to prevent leakage and capped with desiccant to prevent the introduction of condensed atmospheric water. Water volume in each Dean-Stark receiving tube was monitored during the toluene refluxing until stabilization. A wire was used to swab off any water droplets from the neck of the condenser. A record of time and water volumes was kept for each sample. Dean Stark extraction time for each sample was approximately 48 hours. After extraction, the flask and contents were removed. The toluene in the side arm was removed and added to the flask. The water recovered in the side arm was removed and poured into a storage bottle, sealed, and labeled for D20 tracer analysis. After the Dean Stark process the plugs were loaded into individual extraction units for complete hydrocarbon and salt removal using chloroform-methanol azeotrope. The plugs remained in individual units for a minimum of one week followed by a minimum of 24 hours with fresh azeotrope to vedfy that they were completely clean. Sample Drying Each core plug and thimble was dded in a convection oven at 240°F for four hours, followed by 24 hours drying in a vacuum oven at 240°F. Sample weights were monitored approximately every 4 to 24 hours until weight stabilization (+/- .01 g) was achieved. After drying, each plug and thimble was allowed to cool in a desiccator and then weighed to 0.001 g. Eac_h plug was removed from its thimble, brushed to remove residual dust, labeled and reweighed. Grain Volume Determination Grain volumes were measured using the Boyle's law AutoporosimeterTM which was calibrated and checked with a known volume stainless steel disk and quartz check plug (2.65 g/cc) before each run. Plug samples were kept in a desiccator until ready for grain volume measurement. After every five samples, a steel check disk was measured to ensure correct equipment operation. Equipment recalibration was performed a minimum of twice a day or as needed. Grain densities (gm/cc) were calculated using the dry sample weight (gm) and grain volume data (cc Core Laboratories Arco Alaska, Inc. File: DAL-99133 Ii II II l, II 11 .I Grain Density Grain densities were calculated from observed data using the formula: GD = DW ~-~-,,~ ,~ ~ ^~ GV ,".i-'~-~ ~: 8 LOw where: DW = Dry weight, gm ~.~,-~ t;~z:~ 6~:~s, t;~::t~SC:~o~'~ GV = Grain volume, cc '~'~"~'~:~" Grain volumes and grain densities are reported on the routine core properties summary in Section 5. Plug Porosity and Permeability Measurements by CMS-300TM Horizontal and vertical plug samples were measured for permeability and porosity by the CMS-300 at 800 and 3500 psi net overburden. Before each group of samples was run, a standard system leak test was performed to ensure correct equipment operation. Calibrated, known volume check cylinders were run before and with each carousel suite of samples. The Klinkenberg (slip corrected) permeability for each plug sample was determined as a function of pressure decay (helium blow-down). A reference cell of known volume charged the sample with helium. A downstream valve vented the sample to atmosphere, and the change in pressure with time was monitored. The multiple flow regime data allowed the determination of Klinkenberg permeability of the sample, a calculated air permeability, along with parameters helium slip factor (b) and the inertial resistance factor (1~) beta. Any plug with permeability to air of 3000 md or more was remeasured using the Autopermeameter (a steady-state device), which has greater accuracy in measuring higher permeability samples, and the Autopermeameter data was reported. Porosity for each plug sample was calculated using Boyle's law by the CMS-300~ with grain volume and pore volume by: O = (PV · 100) / (PV + GV) where: 2~ = PV = GV = Porosity, percent Pore volume at net confining pressure, cc Grain volume, cc Data was downloaded to diskette, imported to the cole analysis report software, and preliminary data printouts were provided to the client regularly. Samples unsuitable for CMS-300TM testing were subjected to ambient condition porosity and profile (probe) permeability testing and are noted in the tabular data. Fluid Saturation Calculations The observed Dean Stark weights and produced water volumes were combined with the measured pore volume data to calculate in situ oil and water saturations for each sample. A summary of all measured and calculated data for the horizontal plugs is presented in tabular and graphical formats in Section 3; vertical plug data appear in Section 4. Water saturation is calculated from the volume of water recovered dudng the Dean Stark distillation. The water volume is not corrected for salt content and is expressed at standard conditions (1 atmosphere and 60°F. The oil saturation is derived from the weight loss during the Dean Stark distillation and Core Laboratories II Arco Alaska, Inc. File: DAL-99133 subsequent solvent cleaning adjusted for the mass of water recovered. An oil density of 0.790 gm/mi is used in the oil saturation calculation unless an alternative value is provided by the client. For the 13-06 core an oil density value of 0.898 gm/mi was provided and used in the calculation of oil saturation. Tracers were added to the ddlling fluid to monitor the invasion of the core by the ddlling fluids. D20 was used in the ddlling mud. The Dean Stark water removed from the side arm and the ddlling fluid filtrate were analyzed for Deuterium Oxide content. Knowledge of these D20 concentrations allowed calculation of filtrate invasion in plugs. Filtate saturation can be calculated using the formulas listed below:. The filtrate volume must first be calculated using the formula below: Filtrate fraction = D20 ~a~e - D20 b~=kg~r~ / D20 m~ -D20 background Once the filtrate fraction is determined, a filtrate corrected water saturation can be calculated using the formula below: Filtrate corrected Water Saturation = Odginal water saturation x ( 1 - Filtrate fraction) And the filtrate saturation ( as reported on the tables) can be determined using the formula below:. Filtrate saturation = Odginal water saturation - Filtrated Corrected Saturation Core Laboratories id : d , mi ARCO ALASKA, INC. Alpine CD 1-0t /? ROUTINE CORE ANALYSIS INCLUDING TRACER DATA File: D^L-99133 800 psi 2400 psi 800 psi 2400 psi He PV Grain Porosity I Water I Oil I Fluid I He PV Porosity I Water I Oil I Fluid "ID20, ppm Mud Filtrate Background Invasion Corrected Corrected Sample Depth, 800psi Volume, 800 psi I Saturation, I Saturation, I Saturation. 12400 psi 2400 psi ISaturatlon.lSaturation,ISaturation,I D20 Analyses. D20 Value, factor Water Water Number feet cc cc I percent I percent I percent ~ cc I percent I percent I percent I ppm ppm F Saturation, Saturation, ' %PV %Pr I 7102 5.30 37.01 12.52 93.1 2.98 96.1 4.74 11.36 103.96 3.33 107.29 148.1 899.4 2 7103.1 5.84 37.11 13.60 94.4 5.94 100.4 5.35 12.60 103.12 6.48 109.60 148.3 899.4 3 7104.1 4.08 38.40 9.59 90.9 4.19 95.1 3.76 8.91 98.61 4.55 103.16 150.7 899.4 4 7105.1 6.46 36.17 15.15 94.5 5.10 99.6 6.02 14.27 101.38 5.47 106.85 147.4 899.4 5 7106.1 6.39 32.58 16.39 93.7 3.84 97.6 6.02 15.59 99~53 4.08 103.61 147.5 899.4 6 7107.1 5.68 36.33 13.51 98.4 2.22 100.6 5.42 12.99 103.01 2.33 105.33 147.4 899.4 7 7108.5 7.13 36.26 16.44 45.4 32.04 77.4 6.86 15.91 47.20 33.30 80.50 326.7 913.7 8 7109.1 8.91 34.47 20.54 38.7 34.88 73.6 8.64 20.04 39.96 35.98 75.94 323.3 913.7 9 7110.1 9.66 34.07 22.10 22.2 41.57 63.7 9.41 21.64 22.78 42.69 65.47 288.9 913.7 10 7111.1 9.12 34.33 20.98 22.9 37.73 60.6 8.91 20.60 23.42 38.61 62.04 238 913.7 11 7112.1 9.35 34.15 21.50 18.3 42.99 61.3 9.14 21.12 18.77 43.98 62.75 222.9 913.7 12 7113.1 9.65 33.93 22.15 15.2 40.73 56.0 9.38 21.65 15.70 41.93 57.63 211.2 913.7 13 7114.1 9.82 34.24 22.29 11.7 43.02 54.7 9.57 21.85 11.97 44.13 56.10 182.8 913.7 14 7115 7.35 36.06 16.94 26.3 40.17 66.5 7.07 16.40 27.39 41.76 69.14 212.4 913.7 15 7116.1 9.48 33.35 22.12 19.1 37.48 56.5 9.21 21.64 19.62 38.56 58.18 243.6 913.7 16 7117.1 8.94 34.25 20.70 19.3 46.93 66.2 8.65 20.16 19.96 48.50 68.46 201.9 913.7 17 7118.1 8.95 34.55 20.57 18.0 ~41.58 59.6 8.62 19.97 18.66 43.15 61.81 209.2 914.4 18 7119.1 9.37 34.02 21.59 16.2 45.05 61.2 9.13 21.15 16.60 46.24 62.84 155 914.4 19 7120.3 8.54 34.70 19.75 19.5 39.70 59.2 8.23 19.16 20.22 41.21 .61.44 157.7 914.4 20 7121.1 8.98 33.73 21.03 18.8 41.63 60.5 8.72 20.55 19.39 42.87 62.26 154.5 914.4 21 7122.1 8.85 33.04 21.13 16.9 39.44 56.4 8.64 20.72 17.35 40.42 57.77 153.4 914.4 22 7123.1 9.20 33.84 21.38 17.7 35.58 53.2 8.98 20.98 18.09 36.43 54.52 157.9 914.4 23 7124.1 8.12 36.02 18.40 29.1 29.04 58.1 7.83 17.86 30.17 30.12 60.29 156.8 914.4 24 7125.1 7.99 35.96 18.18 26.1 35.31 61.4 7.71 17.66 27.04 36.59 63.63 153.1 914.4 25 7126.1 8.97 35.48 20.19 9.9 0.74 10.7 8.68 19.86 10.28 0.77 11.05 154.5 914.4 26 7127.1 8.78 35.09 20.01 22.0 6.20 28.2 8.48 19.46 22.78 6.42 29.19 154.8 914.4 27 7128.1 9.35 34.29 21.42 19.3 71.63 90.9 9.07 20.92 19.91 73.82 93.73 156.9 892.6 28 7129.1 8.36 34.85 19.34 28.3 28.49 56.8 8.07 18.80 29.34 29.50 58.84 150.1 892.6 29 7130.1 6.26 36.98 14.49 42.6 20.63 63.3 5.98 13.93 44.62 21.59 66.20 149.3 892.6 30 7131.1 8.60 34.95 19.75 23.4 34.50 57.9 8.34 19.26 24.17 35.60 59.76 150.3 892.6 31 7132.1 8.69 34.91 19.92 26.6 31.65 58.3 8.43 19.45 27.41 32.60 60.02 155.2 892.6 32 7133.1 7.93 35.58 18.23 32.2 28.08 60.2 7.68 17.75 33.24 29.03 62.26 199 892.6 33 7134.1 8.06 35.56 18.48 24.8 36.15 60.9 7.82 18.02 25.59 37.30 62.88 158 892.6 34 7135.1 8.46 34.71 19.60 24.7 36.06 60.7 8.18 19.07 25.52 37.30 62.82 151.7 892.6 35 7136.1 8.01 35.45 18.43 31.2 27.10 58.3 7.73 17.91 32.29 28.07 60.36 151.5 892.6 36 7137.1 8.62 34.41 20.03 23.0 32.07 55.1 8.34 19.52 23.75 33.13 56.88 157.6 892.6 37 7138.1 7.88 35.63 18.11 28.4 33.91 62.3 7.62 17.62 29.38 35.08 64.46 155.2 928 38 7139.1 8.45 35.59 19.19 29.4 27.80 57.2 8.16 18.66 30.47 28.79 59.26 151.9 928 39 7140.1 8.24 35.58 18.80 31.0 27.99 59.0 7.95 18.27 32.11 28.98 61.09 153.6 928 40 7141.1 8.72 34.48 20.17 25.2 28.89 54.1 8.43 19.63 26.05 29.88 55.93 153.6 928 41 7142.3 8.08 35.83 18.40 31.4 28.93 60.3 7.81 17.89 32.49 29.94 62.43 161.9 928 42 7143.1 7.52 36.58 17.05 25.5 34.93 60.5 7.26 16.56 26.45 36.19 62.65 149.7 928 139.6 0.1647 77.75 86.84 139.6 0.1649 78.87 86.12 139.6 0.1676 75.67 82.09 139.6 0.1639 79.02 84.76 139.6 0.1640 78.36 83.21 139.6 0.1639 82.29 86.12 139.6 0.3576 29.17 30.32 139.6 0.3538 25.03 25.82 139.6 0.3162 15.17 15.58 139.6 0.2605 16.93 17.32 139.6 0.2440 13.87 14.19 139.6 0.2311 11.72 12.07 139.6 0.2001 9.33 9.57 139.6 0.2325 20.22 21.02 139.6 0.2666 13.98 14.39 139~6 0.2210 15.04 15.55 139.6 0.2288 13.86 14.39 139.6 0.1695 13.43 13.78 139.6 0.1725 16.12 16.74 139.6 0.1690 15.65 16.12 139.6 0.1678 14.09 14.44 139.6 0.1727 14.62 14.97 139.6 0.1715 24.10 24.99 139.6 0.1674 21.72 22.51 139.6 0.1690 8.26 8.54 139.6 0.1693 18.28 18.92 139.6 0.1758 15.92 16.41 139.6 0.1682 23.57 24.41 139.6 0.1673 35.50 37.15 139.6 0.1684 19.48 20.10 139.6 0.1739 21.98 22.65 139.6 0.2229 24.99 25.83 139.6 0.1770 20.41 21.06 139.6 0.1700 20.47 21.18 139.6 0.1697 25.88 26.81 139~6 0.1766 18.93 19.56 139~6 0.1672 23.65 24.47. 139.6 0.1637 24.60 25.48 139.6 0.1655 25.87 26.79 139.6 0.1655 21.01 21.74 139.6 0.1745 25.92 26.82 139.6 0.1613 21.42 22.19 ARCO ALASKA, INC. Alpine CD 1-0t ROUTINE CORE ANALYSIS INCLUDING TRACER DATA File: DAL-99133 Sample Depth, 'Number feet 800 psi 2400 psi He PV Grain P°r°sityl water I Oil I Fluid I He PV PorosityI Water I Oil I I~luid ID20' 800psi Volume, 800 psi I Saturation,~ Saturation, I Saturation, 12400 psi 2400 psi ~Saturation,lSaturation,lSaturation,~ cc cc I percent I percent I perce.n! J cc I percent I percent. ~ percentI ppm Mud Filtrate Background Invasion D20 Analyses, D20 Value, factor ppm ppm F 800 psi 2400 psi Corrected Corrected Water Water Saturation, Saturation, % PV % PV 43 7144.1 7.43 36.34 16.97 23.3 36.89 60.2 7.16 16.47 24.18 38.23 62.42 44 7145.1 6.63 36.46 15.39 33.2 31.77 65.0 6.37 14.87 34.56 33.07 67.63 45 7146.1 8.49 34.58 19.71 23.3 36.69 60.0 8.22 19.21 24.08 37.87 61.95 46 7147.1 9.68 34.15 22.09 26.0 36.41 62.4 9.40 21.58 26.77 37.50 64.28 47 7148.1 9.03 35.02 20.50 20.9 35.60 56.5 8.76 20.01 21.56 36.71 58.27 48 7149.1 8.00 35.41 18.43 25.6 37.56 63.2 7.72 17.89 26.53 38.94 65.46 49 7150.1 7.76 38.10 17.69 26.2 29.36 55.8 7.49 17.19 27.16 30.40 57.57 50 7151.6 9.11 34.41 20.93 19.4 35.93 55.4 8.85 20.46 20.00 36.98 56.97 51 7152.1 9.60 34.10 21.96 18.2 36.22 54.4 9.34 21.51 18.64 37.20 55.84 52 7153.2 9.23 33.96 21.37 17.5 39.14 56.6 8.98 20.91 17.98 40.23 58.19 53 7154.1 9.41 33.97 21.69 17.7 37.43 55.1 9.13 21.19 18.20 38.57 56.77 54 7155.1 9.04 34.19 20.91 23.9 40.65 64.5 8.80 20.47 24.53 41.75 66.29 55 7156.1 9.21 33.50 21.57 17.6 41.14 58.8 8.94 21.06 18.16 42.42 60.57 56 7157.1 9.35 34.13 21.51 19.7 40.72 60.4 9.11 21.06 20.22 41.82 62.04 57 7158.1 9.00 34.22 20.83 25.1 36.24 61.3 8.73 20.33 25.88 37.37 63.24 58 7159.1 5.65 38.92 12.68 52.7 22.41 75.1 5.33 12.05 55.87 23.75 79.62 59 7160.1 4.05 40.03 9.19 84.6 ~ 3.02 87.7 3.66 8.37 93.74 3.34 97.08 60 7161.1 5.58 37.68 12.90 61.4 17.04 78.4 5.31 12.36 64.43 17.89 82.32 61 7162.1 5.00 38.87 11.41 68.4 19.94 88.4 4.73 10.85 72.39 21.10 93.49 62 7163.1 8.01 36.18 18.13 34.4 34.53 68.9 7.71 17.57 35.72 35.88 71.60 63 7164.2 5.50 38.24 12.57 61.9 16.54 78.4 5.21 11.99 65.32 17.47 82.79 64 7165.2 5.66 37.48 13.11 57.1 20.72 77.8 5.36 12.51 60.26 21.86 82.13 65 7166.5 5.93 37.99 13.50 56.8 21.51 78.3 5.67 12.98 59.37 22.51 81.88 66 7167.1 5.34 38.16 12.28 64.1 19.16 83.3 4.97 11.53 68.90 20.59 89.49 67 7168.1 5.26 37.45 12.32 60.1 25.36 85.4 4.93 11.63 64.13 27.08 91.21 68 7169.1 5.02 37.73 11.74 74.9 15.43 90.3 4.62 10.91 81.32 16.76 98.08 69 7170 5.18 38.14 11.96 52.4 31.88 84.2 4.81 11.19 56.45 34.37 90.82 70 7171.2 4.89 37.74 11.48 80.0 5.72 85.7 4.44 10.53 88.10 6.30 94.40 71 7172.1 4.78 38.27 11.10 45.8 53.21 99.0 4.40 10.31 49.76 57.81 107.57 72 7173.1 4.98 38.67 11.41 77.1 9.92 87.1 4.53 10.49 84.81 10.91 95.72 73 7174.1 4.63 39.30 10.54 61.9 36.18 98.1 4.24 9.75 67.55 39.47 107.02 74 7175.1 5.11 38.96 11.60 83.5 0.95 84.4 4.78 10.88 89.71 1.02 90.73 75 7176.1 4.92 38.78 11.25 82.0 6.68 88.7 4.59 10.58 87.89 7.15 95.04 76 7177.1 4.93 38.39 11.39 71.8 13.66 85.5 4.54 10.58 78.01 14.83 92.85 77 7178.1 4.85 39.12 11.02 72.1 20.96 93.0 4.50 10.31 77.66 22.58 100.24 78 7179.1 4.56 38.35 10.62 89.0 2.77 91.8 4.18 9.84 98.99 3.02 100.01 79 7180.3 4.55 39.54 10.31 90.0 0.24 90.3 4.12 9.44 99.29 0.27 99.56 80 7181.1 4.52 39.10 10.36 89.6 0.48 90.1 4.15 9.60 97.56 0.52 98.08 81 7182.1 4.42 39.24 10.12 93.5 0.70 94.2 4.01 9.26 103.09 0.77 103.86 151.2 162.1 169.7 278.6 182 177.8 164.6 168.5 171.9 163.3 164.6 195.7 164.6 163.9 211.5 152.8 147.8 148.3 169.4 154.2 153.1 150.6 155.9 154.5 152.4 162.2 162.8 198.9 154.3 162.2 154.5 164.1 150.7 152.1 152.3 159.5 148.2 147.8 147.6 928 139.6 0.1629 19.53 20.24 928 139.6 0.1747 27.41 28.53 928 139.6 0.1829 19.07 19.68 928 139.6 0.3002 18.19 18.74 938.3 139.6 0.1940 18.85 17.38 938.3 139.6 0.1895 20.74 21.50 938.3 139.6 0.1754 21.63 22.40 938.3 139.6 0.1796 15.94 16.41 938.3 139.6 0.1832 14.83 15.23 938.3 139.6 0.1740 14.43 14.83 938.3 139.6 0.1754 14.56 15.01 938.3 139.6 0.2086 18.90 19.42 938.3 139.6 0.1754 14.52 14.97 938.3 139.6 0.1747 16.25 16.69 892.9 139.6 0.2369 19.15 19.75 892.9 139.6 0.1711 43.70 46.31 892.9 139.6 0.1655 70.63 78.22 892.9 139.6 0.1661 51.18 53.73 892.9 139.6 0.1897 55.44 58.66 892.9 139.6 0.1727 28.44 29.55 892.9 139.6 0.1715 51.26 54.12 892.9 139.6 0.1687 47.48 50.10 892.9 139.6 0.1748 46.84 49.01 892.9 139.6 0.1730 53.03 56.98 936.5 139.6 0.1627 50.29 53.70 936.5 139.6 0.1732 61.89 67.24 936.5 139.6 0.1738 43.26 46.64 936.5 139.6 0.2124 62.97 69.39 936.5 139.6 0.1648 36.26 41.56 936.5 139.6 0.1732 63.78 70.12 936.5 139.6 0.1650 51.70 56.40 936.5 139.6 0.1752 68.84 73.99 936.5 139.6 0.1609 68.84 73.74 936.5 139.6 0.1624 60.18 65.34 904.5 139.6 0.1684 59.95 64.58 904.5 139.6 0.1763 73.34 79.89 904.5 139.6 0.1638 75.30 83.02' 904.5 139.6 0.1634 74.95 81.62 904.5 139.6 0.1632 78.25 86.27 :m mi Im / C,.:3 r.) 8 ~.'U~SUMMARY OF PERMEABILITY AND POROSn'YMEASUREMENTS 1 7102 800 12.5 1 7102 2400 11.4 2 7103.1 800 13.6 2 7103.1 2400 12.6 3 7104.1 800 9.6 3 7104,1 2400 8.9 4 7105.1 800 15.2 4 7105.1 2400 14.3 5 7106.1 800 16.4 5 7106.1 2400 15.6 6 7107.1 800 13.5 6 7107.1 2400 13.0 7 7108.5 800 16.4 7 7108.5 2400 15.9 8 7109.1 800 20.5 8 7109.1 2400 20.0 9 7110.1 800 22,1 9 7110.1 2400 21,6 10 7111,1 800 21,0 10 7111.1 2400 20,6 11 7112,1 800 21.5 11 7112.1 2400 21.1 12 7113.1 800 22.2 12 7113.1 2400 21,7 13 7114.1 800 22.3 13 7114.1 2400 21.9 14 7115 800 16,9 14 7115 2400 16.4 15 7116.1 800 22.1 15 7116.1 2400 21.6 16 7117.1 800 20.7 16 7117.1 2400 20.2 17 7118.1 800 20.6 17 7118.1 2400 20,0 18 711g, 1 800 21,6 18 7119.1 2400 21.2 19 7120.29 800 19.8 19 7120.29 2400 19.2 20 7121.1 800 21.0 20 7121.1 2400 20.6 21 7122.1 800 21.1 21 7122.1 2400 20.7 22 7123.1 800 21.4 22 7123.1 2400 21.0 23 7124.1 800 18.4 2.3 7124.1 2400 17.9 24 7125.1 800 18.2 24 7125.1 2400 17.7 25 7126.1 800 20.2 25 71Z6.1 2400 19.7 26 7127.1 808 20.0 Kair Kinf md md 0.0434 0.0334 0.0082 0.00411 0.0719 0.0639 0.0095 0.00634 1.07 0.83 0.0973 0.0524 0.181 0.159 0.0275 0.0180 4.78 4.57 0.449 0.375 0.0576 0.0291 0.0255 0.0102 0.936 0,686 0.781 0.570 7.65 6.51 7.25 6.17 17.6 15.4 16.8 14.8 10.9 9.31 10.5 8.99 17.4 15.3 16,8 14.8 25.4 22.6 24,3 21.6 43.5 39.5 41.7 37.9 6.44 5.48 3.53 2.88 43.1 39.3 41.6 37.9 23.5 20.9 22.2 19.8 20.5 18,1 19.3 17.1 20.6 18.3 lg.g - 17.6 10.1 8.58 9.37 8.01 15.6 13.7 14.8 12.9 22.4 20.0 21.5 19.2 29.1 26.3 28,1 25.4 5.80 4.82 5.39 4,49 4.51 3.70 4.17 3.43 10.5 9.03 9.84 8.45 11.1 9.60 File: DAL-99133 Grain Alpha Density ' ~m~== factor psi ff-I microns 2.33E+01 1.70E+13 1.71E+03 7.74E+01 2.98E+14 3.75E+03 9.26E+00 8.47E+11 1.71E+02 3.67E+01 2.69E+14 5.24E+03 1.84E+01 9.83E+10 2.36E+02 5.34E+01 7.36E+12 1,09E+03 9.36E-',-00 1.07E+ll 5.42E+01 3.68E+01 6.20E+13 3.46E+03 2.60E+00 4.40E+10 5.82E+02 1.1IE+O1 2.13E+12 2,28E+03 7.68E+01 1.31E+13 1.21E+03 1.18E+02 8.82E+13 2.76E+03 2.30E+01 2.29E+11 5.05E+02 2.33E+01 3.31E+11 6.09E+02 9.56E+00 1.04E+09 2.19E+01 9.56E+00 1,12E+09 2.24E+01 7.24E+00 2.76E+08 1.38E+01 7.21E+00 3.03E+08 1.44E+01 8.98E+00 4.92E+08 1.48E+01 8.86E+00 5.66E+08 1.64E+01 7.37E+00 2.30E+08 1.14E+O1 7.37E+00 2,43E+08 1.16E+O1 6.42E-H)O 6.96E+-07 5.09E+00 6.46E+00 7.53E+07 5.25E+00 4.98E+00 4.17E+07 5.33E+00 5.03E+00 4.36E+07 5.34E+00 9.64E+00 1.10E+IO 1.gOE+02 1,25E+01 1.28E+10 1.16E+02 4.80E+00 5.15E+07 6.53E+00 4.84E+00 5.35E+07 6.54E+00 6.43E+C)0 1.04E+08 7.01E+00 6.45E+00 1.13E+08 7,23E+00 6.79E+00 2.03E+08 1.19E+O1 6.73E+00 2.21E+08 1,22E+01 6.63E+00 1.81E+08 1.07E+O1 6,60E+00 1.98E+08 1.12E+O1 9.29E+00 6,85E+08 1.gOE+O1 9,19E+00 7.66E+08 1.98E+01 7.51E+00 3.08E+08 1.36E+01 7.50E+00 3.29E+08 1.37E+01 6.22E+00 9.75E+07 6.28E+00 6.23E+00 9.87E+07 6.10E+O0 5.40E+00 8.53E+07 7.25E+00 5.41E+00 8.98E+07 7.35E+00 1.14E+O1 1.78E+09 2.78E+01 1.12E+O1 2.05E+09 2.96E+01 1.24E+01 3.08E+09 3.68E+0I 1.22E+01 3.58E+09 3.96E+01 8.99E+00 5.69E+D8 1.66E+01 8.89E+00 6.53E+08 1.78E+01 8.52E+00 5.68E+08 1.76E+01 2.7091 2.7091 2.7221 2.7221 2.7498 2.7498 2.7426 2.7426 2.6~9 2.6~9 2.7203 2.7203 2.7071 2.7071 2.6889 2,6889 2.6781 2.6781 2.6589 2.6589 2.6564' 2.6564 2.6~3 2.6~3 2.63~ 2.63~ 2.6497 2.6497 2.654 2.654 2.6514 2.6514 2.6531 2.6531 2.6525 2.6525 2.6523 2.6523 2.6554 2,6554 2.6651 2.6651 2.6555 2.6555 2.6478 Core Laboratories II SUMMARY OF PERMEABILITY AND POROSITY MEASUREMENTS Arco Alaska. Inc. Alpine CD1-01 is=,oiTi co.,.,.,I_.,, ,o_% ml 26 7127.1 2400 19.5 27 7128.1 800 21.4 27 7128.1 2400 20.9 28 7129.1 800 19.3 28 7129.1 2400 18.8 29 7130.1 800 14.5 29 7130.1 2400 13.9 30 7131.1 800 19.8 30 7131.1 2400 19.3 31 7132.1 800 19.9 31 7132.1 2400 19.5 32 7133.1 800 18.2 32 7133.1 2400 17.8 33 7134.1 800 18.5 33 7134.1 2400 18.0 34 7135.1 800 19.6 34 7135.1 2400 19.1 35 7136.1 800 18.4 35 7136.1 2400 17.9 36 7137.1 800 20.0 36 7137.1 2400 19.5 37 7138.1 800 18.1 37 7138.1 2400 17.6 38 7139.1 800 19.2 38 7139.1 2400 18.7 39 7140.1 800 18.8 39 7140.1 2400 18.3 40 7141,1 800 20.2 40 7141.1 2400 19.6 41 7142,29 800 18.4 41 7142.29 2400 17.9 42 7143.1 800 17.1 42 7143.1 2400 16,6 43 7144.1 800 17.0 43 7144.1 2400 16.5 44 7145.1 800 15.4 44 7145.1 2400 14.9 45 7146.1 800 19.7 45 7146.1 2400 19.2 46 7147.1 800 22.1 46 7147,1 2400 21.6 47 7148,1 800 20.5 47 7148.1 2400 20.0 48 7149.1 800 18.4 48 7149.1 2400 17.9 49 7150.1 800 17.7 49 7150.1 2400 17.2 50 7151.6 800 20.9 50 7151.6 2400 20.5 51 7152.1 800 22.0 51 7152.1 2400 21.5 Kalr Kinf factor md md psi 10.4 9.02 8.44E+00 23.0 20.5 6.23E+00 21.8 19.5 6.21E+00 7.75 6.60 9.51E+00 7.25 6.20 9.33E+00 0.472 0.311 3.46E+01 0.4 0 0.290 2.53E+01 8,82 7.51 9.44E+00 8.27 7.06 9.32E+00 10.5 9.00 9.01E+O0 9.84 8.45 8.86E+00 4.38 3,55 1.34E+01 4.02 3.26 1.32E+01 4,33 3.54 1.28E+01 4. 0 3.28 1.25E+01 8.71 7.41 9.51E+00 8.13 6.94 9,32E+00 3.74 3,02 1.37E+01 3.44 2.79 1.34E+01 15,8 14.0 6.861:+00 15.0 13.3 6.79E+00 5.39 4.51 1.10E+01 4.99 4.19 1.07E+01 11.4 9.90 8.13E+00 10.7 9.31 8.00E+O0 10.9 9,51 8.03E+00 10,2 8.87 7.891:+00 17.8 15.7 7.04E+00 16.8 14.9 6.96E+00 6.97 5.87 1.03E+01 6.44 5,44 1.01E+01 4.26 3.49 1.26E+01 3.89 3.20 1.23E+01 3.09 2.45 1.50E+O1 2.86 _ 2.30 1.42E+01 1.90 '1.46 1.80E+O1 1.67 1.29 1.75E+01 25.4 22.9 5.58E+00 23.9 21.6 5.53E+00 65.9 61.4 3.57E+00 62.7 58.4 3.54E+00 38.9 35.4 4.91E+00 36.9 33.6 4.87E+00 11.3 9.75 8.26E+00 10.5 9.12 8.11E+00 10.2 8.76 8.72E-H)O 9.41 8.13 8.50E+00 51.6 47.5 4.14E+00 49.3 45.5 4.13E+(X) 74.6 69.7 3.44E+00 71.7 66.9 3.48E+00 File: DAL-99133 Grain ] Beta A~pha Density ft-1 microns gms/cc 6.18E+0~ 1.80E+0! 2.6478 1.04E+08 6.92E+00 2.6567 1.18E+08 7.42E+00 2.6567 9.93E+08 2.12E+01 2.6554 1.16E+09 2.33E+01 2,6554 1,09E+12 1.09E+03 2.6522 5.34E+12 4.99E+03 2.6622 9.12E+C~ 2.21E+01 2.6534 1.OOE+09 2.28E+01 2.6534 6.771:+08 1.97E+01 2.6587 7.74E+08 2.11E+01 2.6587 3.06E+09 3.51E+01 2,6624 3.56E+09 3.74E+01 2.6624 3.35E+09 3.83E+01 2.6592 3.90E+09 4,13E+01 2.6592 9.41E+08 2.25E+01 2.659 1.09E+09 2.45E+01 2,659 4.00E+09 3.91E+01 2.6625 4.81E+09 4.33E+01 2.6625 3.22E+08 1.46E+01 2.6701 3.47E+08 1.49E+01 2.6701 2,16E+09 3.15E+01 2.6752 2.55E+09 3.45E+01 2.6752 5.38E+08 1.72E+01 2.6638 6.01E+08 1.81E+O1 2.6538 6.68E+08 2.05E+01 2.6711 7.54E+08 2.16E+01 2.6711 2.58E+08 1.31E+01 2.6531 2.83E+08 1.36E+01 2.6531 1.63E+09 3.09E+01 2.6771 1.90E+09 3.34E+01 2.6771 3.19E+09 3,59E+01 2.6592 3.97E+09 4.09E+01 2.6592 5.73E+09 4.54E+01 2.6602 1.34E+10 9.95E+01 2.6602 4.01E+10 1.89E+02 2.6741 5.26E+10 2.19E+02 2.6741 1.77E+08 1.31E+01 2.6615 1.97E+08 1.37E+01 2.6515 5.00E+07 9.93E+00 2.6553 5.49E+07 1.04E+01 2.6553 8.67E+07 9.92E+00 2.6563 9,57E+07 1.04E+01 2.6563 5.89E+~ 1.85E+01 2.6529 6.53E+0~ 1.92E+01 2.6529 7.39E+08 2.09E+01 2.6684 8.54E+08 2.24E+01 2.6684 5.22E+07 8.02E+00 2.6539 5.67E+07 8.32E+00 2.6539 3.40E+07 7.65E+00 2,6557 3.61E+07 7.80E+00 2.6557 Core Laboratories mi im SUMMARY OF PERMEABILITY AND POROSITY MEASUREMENTS Arco Alaska. Inc. Alpine CD1-01 Kair ! Kinf md md File: DAL-99133 factor Beta Alpha Density psi fi-1 microns gms/cc J 52 7153.2 800 21.4 52 7153.2 2400 20.9 53 7154.1 800 21.7 53 7154.1 2400 21.2 54 7155.1 800 20.9 54 7155.1 2~)0 20.5 55 7156.1 800 21.6 55 7156.1 2,:100 21.1 56 7157.1 800 21.5 56 7157.1 2400 21.1 57 7158.1 800 20.8 57 7158.1 2400 20.3 58 7159.1 800 12.7 58 7159.1 2400 12.1 59 7160.1 800 9.2 59 7160.1 2400 8.4 60 7161.1 800 12.9 60 7161.1 2400 12,4 61 7162.1 800 11.4 61 7162.1 2400 10.9 62 7163,1 800 18.1 62 7163.1 2400 17.6 63 7164.2 800 12.6 63 7164,2 2400 12.0 64 7165.2 800 13.1 64 7165.2 2400 12.5 65 7166.5 800 13.5 65 7166.5 2400 13.0 66 7167.1 800 12.3 66 7167.1 2400 11.5 67 7168.1 800 12.3 67 7168.1 2400 11.6 68 7169.1 800 11.7 68 7169.1 2400 10.9 69 7170 800 12.0 69 7170 2400 11.2 70 7171.2 800 11.5 70 7171.2 2400 10,5 71 7172.1 800 11.1 71 7172.1 2400 10.3 72 7173.1 800 11.4 72 7173.1 2400 10.5 73 7174.1 800 10,5 73 7174.1 2400 9.8 74 7175.1 800 11.6 74 7175.1 2400 10.9 75 7176.1 800 11.3 75 7176.1 2400 10.6 76 7177.1 800 11.4 76 7177.1 2400 10.6 58.5 56,0 62.4 59.9 47.6 45.6 56.7 54.4 41.0 39.3 24.4 23,2 1.67 1.22 0.0724 0.0130 0.0649 0.0396 0.0564 0.0249 0.799 0.671 0.0621 0.0264 0.0898 0.0465 0.0872 0.0550 0.188 0.0405 0.55O 0.0563 0.274 0.0366 2.25 0.219 0.1B1 0.0257 0.170 0.0253 1.22 0.180 0.110 0.0203 0.0796 0.0259 0.0489 0.0146 0.0589 O,O1B8 54.3 51.9 58.1 55.8 43.8 42.0 52.6 50,5 37.5 35.9 21.9 20.9 1.42 1.08 0.0531 0.00624 0.0302 0.0163 0.0281 0.0094 0.558 0,470 0.0322 0.0099 0.0489 0.0198 0.0418 0.0247 0.171 0.0203 0.500 0.0387 0.258 0.0216 1.83 0.135 0.150 0.0110 0.I10 0.0133 1.05 0.122 0.0720 0.00898 0.0437 0.0109 0.0250 0.00508 0.0330 0.00928 3.75E+00 4.32E+07 7.58E+00 3.7gE+O0 4.5715+07 7,66E+00 3.64E+00 3.90E+07 7.33E+00 3.63E+00 4.17E+07 7,51E+00 4.25E+00 5.91E+07 8.37E+00 4.26E+00 6.30E+07 8.56E+00 3.78E+00 4.8415+07 8.24E+00 3.76E+00 5.17E+07 8.4445+00 4.69E+00 6.14E+07 7.43E+00 4.68E+00 6.57E+07 7.61E+00 5.78E+00 1.18E+08 8.35E+00 5.76E+00 1.28E+08 8.66E+00 1.05E+01 4.55E+10 2.0715+02 7.95E+00 4.37E+I0 1.51E+02 2.72E+01 5.67E+12 9.03E+02 8.06E+01 1.15E+14 2.14E+03 8.94E+01 2.65E+13 2.54E+03 1.11E+02 2.60E+13 1.34E+03 7.86E+01 1.48E+I3 1.23E+03 1.30E+02 7.50E+13 2m20E+03 2.76E+01 3.24E+11 5.80~+02 2.75E+01 4.86E+11 7.33E+02 7.22E+01 2.01E+13 1.89E+03 1.305+02 6.09E+13 1.87E+03 6.29E+01 1.87E+13 2.86E+03 1.0215+02 1.23E+13 7.56E+02 8.24E+01 7.47E+12 9.92E+02 9.35E+01 2.02E+13 1.57E+03 7.07E+00 4.67E+11 2.37E+02 6.89E+01 5.06E+13 3.01E+03 6.50E+{X) 7.70E+10 9.86E+01 2.94E+01 1.04E+13 1,20E+03 4.15E+00 1.12E+11 8.54E+01 4.66~+01 6.5715+12 4.48E+02 1.36E+01 2.85E+10 1.52E+02 3.70E+01 1,66E+12 6.41E+02 1.45E+01 9.31E+11 4.14E+02 9.32E+01 8.52E+13 2.99E+03 3.93E+01 2.12E+12 7.01E+02 6.45E+01 4.54E+13 1.79E+03 9.765+00 1.23E+12 3.43E+03 2.93E+01 4.01E+ll 1.47E+02 3.83E+01 3,91E+12 7.61E+02 9.26E+01 2.3215+14 6.38E+03 6.25E+01 1,62E+13 2.18E+03 1.04E+02 3,31E+13 1.16E+03 7.51E+01 4,33E+13 3.345+03 1.47E+02 1.06E+14 1.65E+03 6.08E-',-01 1.OOE+13 1.73E+03 7.93E+01 3.16E+15 9.18E+04 2.6675 2.6675 2.664 2.664 2.6737 2.6737 2.6785 2.6785 2,672 2.672 2.6636 2.6636 2.7192 2.7192 2.6639 2.6639 2.6727 2.6727 2.6733 2.6733 2.6703 2.6703 2.6729 2.6729 2.6678 2.6678 2,6676 2.6676 2.6725 2.6725 2.6804 2.6804 2.6798 2.6798 2.6767 2.6767 2.6845 2.6845 2.6762 2.6762 2.6754 2.6754 2.6734 2.6734 2.6877 2.6877 2.6701 2.6701 2.6787 2.6787 Core Laboratories SUMMARY OF PERMEABILITY AND POROSITY MEASUREMENTS Arco Alaska. Inc. Alpine CD1-01 I 77 7178.1 800 11.0 77 7178.1 2400 10.3 78 7179,1 800 10.6 78 7179.1 2400 9.8 79 7180.29 800 10.3 79 7180.29 2400 9.4 80 7181,1 800 10.4 80 7181.1 2400 9,6 B1 71B2.1 800 10.1 81 7182.1 2400 9.3 Kair Kinf md md 0,117 0.0219 0.0505 0.0133 0.0438 0.0103 0.109 0.0225 0.474 0.0326 0.0929 0.0103 0.0271 0.00495 0.0253 0.00397 0.0663 0.0162 0.379 0.0143 File: DAL-99133 factor Beta Alpha Density psi fbi microns ~msYcc 1.86E+01 3.13E+12 7.BSE+02 2.6786 8.18E+0~. 1.28E+15 4.01E+04 2.6786 6.78E+01 6.62E+13 5.06E+03 2.7048 1.33E+02 1.14E+14 1,76E+03 2,7048 5.80E+01 3.12E+13 2,261~+03 2,6823 1.2F:d~+02 3.13E+14 3.SNSE-l-03 2.F:~323 4.74E+01 4.$2E+12 9.16E-H~2 2.6962 2.89E+01 6.25E+13 3.07E+03 2.6962 1.6yqq~+O1 2.10E+12 2.03F+03 2.697 8.38E+01 $.62E+13 2.48E+03 2.697 1{ Il I{ Core Laboratories .] .i .i -) -] J 100000 PERMEABILITY TO AIR VERSUS POROSITY Alpine CD 1-01 Well 10000 1000 100 10 0.1 0.01 0.001 0.0001 i i I f i i 0 4 8 12 16 20 24 28 Porosity, percent Core Laboratories ,i -! ARCO Alaska, Inc. File: DAL-99133 SECTION 4 VERTICAL PLUG DATA Core Laboratories Arco Alaska, Inc. Alpine CD1-01 Vertical Plug Dean Stark Data File: DAL-99133 ISample I Numbed Sample Depth, feet Permeability to Air, Porosity, millidarcys, percent Water Saturation, percent PV Oil I Total Saturation,I Saturation, percent, PVI percent PV Pore Volume, CC Grain Volume, CC Dry Grain Weight, Density, cjrams ~m./.cc lV 3V 5V 7V 9V 11V 13V 15V 17V 19V 21V 23V 25V 27V 29V 31V 33V 35V 37V 39V 41V 43V 45V 7102.25 7104.25 7106.25 7108.64 7110.25 7112.25 7114.25 7116.25 7418.25 74 20.45 7122.25 7124.25 7126.25 7128.25 7130.25 7132.25 7134.25 7136.25 7138.25 7140.25 7142.14 7144.25 7146.25 0.0266 15.3 96.1 3.8 99.9 6.668 0.0306 12.0 96.3 5.7 102.0 5.227 0.0363 15.6 93.8 5.2 99.0 6.851 1.89 17.1 54.3 19.0 73.3 7.804 7.93 21.5 26.4 31.7 58.1 9.545 33.5 22.3 23.5 32.1 55.6 9.972 41.3 22,5 16.4 37.6 54.0 9.856 39,5 22,4 22.1 34.8 56.9 9.971 9.05 20.1 17.8 44.3 62.1 8.948 3.95 18.7 23.5 36.5 60.0 8.557 21.2 21.1 22.2 32.0 54.2 9.404 3,22 18,2 49.8 2.9 52.7 8.008 11.5 21.0 19.0 35.6 54.6 9.262 18.2 21.3 21.5 34.2 55.7 9.578 0.486 15.8 34.1 27.2 61.3 7.064 4.50 19.5 29.6 29.0 58.5 8.780 1.85 18.2 24.8 33.7 58.5 8.039 2.74 18.2 26.7 35.0 61.7 8.305 2.41 17.5 27.7 35.6 63.2 7.907 5.53 18.6 25.6 34.7 60.3 8.288 3.09 18.9 28.0 34.1 62.1 8.531 1.79 16.7 10.2 53.8 64.0 7.588 23.6 20.5 23,4 36.6 60.0 9.186 36.982 100.671 2.722 38.267 112.888 2.950 37.148 102.830 2.768 37.823 103.548 2.738 34.822 94.184 2.705 34.808 92.678 2.663 33.856 90.165 2.663 34.535 91.616 2.653 35.661 94.615 2.653 37.196 98.949 2.660 35.128 93.422 2.660 35.926 95.669 2.663 34.945 92.722 2.653 35.300 93.820 2.658 37.579 100.053 2.662 36.150 96.243 2.662 36.205 96.276 2.659 37.211 99.200 2.666 37.207 99.793 2.682 36.237 96.654 2.667 36.589 97.700 2.670 37.841 100.813 2.664 35.600 95.004 2.669 Core Laboratories, Inc. mm m m m m m m m m mmm~ m mmmm~ --,-, m mm, m m m Arco Alaska, Inc. Alpine CD1-01 ISample I Numbed Sample Permeability Depth, feet to Air, Porosity, millidarcys percent Vertical Plug Dean Stark Data Water Saturation, percent PV Oil I Total Saturation,I Saturation, percent PVI percent PV 47V 7148.25 49V 7150.25 51V 7152.25 53V 7154.25 55V 7156.25 57V 7158.25 59V 7160.25 61V 7162.25 63V 7164.35 65V 7166.64 67V 7168.25 69V 7170.20 71V 7172.25 73V 7174.25 75V 7176.25 77V 7178.25 79V 7180.14 81V 7182.25 45.0 21.5 11.2 19.1 29.9 21.0 62.6 22.2 52.2 21.4 19.9 21.5 O.0100 10.9 0.0437 14.4 0.0188 12.1 0.0231 12.8 0.0173 12.2 0.0145 11.0 0.0152 10.4 0.00585 9.9 0.0130 11.2 0.0131 10.8 0.00682 10.1 0.00434 9.8 19.4 35.6 55.0 26.6 33.0 59.5 21.3 36.0 57.3 16.8 38.4 55.1 21.5 35.7 57.1 23.6 34.4 58.0 74.2 4.6 78.8 50.3 27.3 77.6 70.7 15.4 86.1 59.8 23.3 83.1 71.2 15.7 86.9 74.6 16.3 90.9 85.9 10.4 96.3 90.9 5.1 96.0 74.1 14.0 88.1 88.7 6.6 95.2 83.7 13.8 97.5 94.1 1.4 95.6 Pore Volume, CC Grain Volume, CC 9.673 8.481 9.406 0.150 9.592 9.624 3.667 4.929 5.490 5.826 5.477 4.914 4.555 4.404 3.509 4.914 3.727 3.992 35.218 35.904 35.399 35.477 35.290 35.173 29.832 29.396 39.924 39.666 39.321 39.740 39.136 39.914 27.751 40.529 33.181 36.579 File: DAL-99133 Dry Weight, grams 93.693 96.148 94.661 94.741 94.120 93.654 .79.790 78.388 106.715 106.066 105.344 106.548 104.977 106.587 74.634 108.486 88.996 98.439 Grain Density, gm/cc 2.660 2.678 2.674 2.670 2.667 2.663 2.675 2.667 2.673 2.674 2.679 2.681 2.682 2.670 2.689 2.677 2.682 2.691 Core Laboratories, Inc. ii d d ii il d d d Arco Alaska. Inc. Alpine CD1-01 iv 7102.25 1v 7102.25 3v 7104.25 3v 7104.25 5V 7106.25 5v 7106.25 7v 7108.64 7v 7108.64 9V 7110.25 9v 7110.25 11v 7112.25 11v 7112.25 13v 7114.25 13¥ 7114.25 15V 7116.25 15v 7116.25 17V 7118.25 lTV 7118.25 19V 7120.45 19V 7120.45 21V 7122.25 21V 7122.25 23V 7124.25 23V 7124.25 25V 7126.25 25V 7126.25 27V 7128.25 27V 7128.25 29V 7130.25 29V 7130.25 31V 7132.25 31V 7132.25 33V 7134.25 33V 7134.25 35V 7136.25 35V 7136.25 37V 7138.25 37V 7138.25 39V 7140.25 39V 7140.25 41V 7142.14 41V 7142.14 43V 7144.25 43V 7144.25 45V 7146.25 45%/ 7146.25 47V 7148.25 47V 7148.25 49V 7150.25 49V 7150.25 51V 7152.25 SUMMARY OF VERTICAL PERMEABILITY AND POROSITY MEASUREMENTS File: DAL-99133 Stres_e Kinf Kair factor psi % md md psi 800 15.3 0.0266 0.0170 4.54E+O1 2400 14.4 0.00601 0.00365 5.22.E+01 800 12.0 0.0306 0,0248 1.87E+01 2400 11.3 0.00555 0.00203 1.36E+02 800 15.6 0.0363 0.0214 5.58E+01 2400 14.9 0.0101 0.00589 5.78E+01 800 17.1 1.89 1.51 1.51E+O1 2400 16.7 1.73 1.39 1.50F+01 800 21.5 7.93 6.68 1.035+01 2400 21.1 7.55 6.36 1.03E+O1 800 22.3 33.5 30.1 5,68E+00 2400 21,8 32.4 29.1 5,71E+00 800 22.6 41.3 37.4 5.24E+00 2400 22.1 39.5 35.7 5.27E+(X) 800 22.4 39.5 35.8 5.08E+00 2400 21.9 37.7 34.1 5.13E+O0 800 20.1 9.05 7.65 9.92E+00 2400 19.5 8.37 7.12 9.60E+00 800 18.7 3.95 3.17 1.42E+01 2400 18.2 3.59 2.89 1.38E+01 800 21.1 21,2 18.7 6.95E+00 2400 20.7 20.1 17.8 6.87E-H30 800 18.2 3.22 2.54 1.54E+01 2400 17.7 2.94 2.36 1.44E+01 800 21.0 11.5 9.8 9.11E+O0 2400 20.5 10.8 9.3 8.96E+00 800 21.3 18.2 16.1 7.02E+00 2400 20.9 17.3 15.2 6.9IE+00 800 15.8 0.486 0.318 3.52E+01 2400 15.3 0.397 0.261 3.46E+01 800 19.5 4.50 3.66 1.31E+01 2400 19.0 4.08 3.33 1.28E+01 800 18.2 1.85 1.36 2.18E+01 2400 17.7 1.62 1.20 2.155+01 800 18.3 2.74 2.16 1.56E+01 2400 17.7 2.44 1.94 1.53E+01 800 17.5 2.41 1.90 1.60E+01 2400 17.0 2.14 1.69 1.57E-+01 800 18.6 5.53 4.55 1.20E+01 2400 18.1 5.01 4.15 1.17E+01 800 18.9 3.09 2.44 1.56E+01 2400 18.4 2.71 2.16 1,51E+01 800 16.7 1.79 1.36 1.87E+01 2400 16.2 1.57 1,21 1.82E+01 800 20.5 23.6 21.1 5.98E+00 2400 20.0 22.1 19.8 5.93E+00 800 21.6 45.0 41.2 4.55E+00 2400 21.1 42,9 39.3 4,56E+00 800 19.1 11.2 9.7 8.24E+00 2400 18.6 10,3 9.0 7.94E+00 800 21.0 29.9 27.1 5.31E+00 i Grain Alpha { Dens{by{ microns J gmsicc I 7,80E+02 2,722 2,73E+04 2,722 2.30E+03 2,950 1.49E+04 2.950 1.78E+03 2.768 1.49E+04 2.768 1.90E+02 2.738 1.97E+02 2.738 2.60E+01 2.705 2.77E+01 2.705 5.74E+00 2.663 5.90E+00 2.663 6.03E+00 2.663 6,14E+00 2.663 6.46E+00 2.653 6.75E+00 2.653 1.82E+01 2.653 2.06E+01 2.653 4.83E+01 2.660 5.16E+01 2.660 1.40E+01 2.660 1.46E+01 2.66O 4.60E+01 2.663 1.04E+02 2.663 1.76E+01 2.653 1.88E+01 2.653 1.50E+01 2.658 1.58E+01 2,658 9.46E+02 2.662 1.28E+03 2.662 4.34E+01 2.662 4.70E+01 2.662 1.84E+02 2.659 1,96E+02 2.659 1.25E+02 2.666 1.32E+02 2.666 1.38E-1-02 2.682 1.45E+02 2.682 3.55E+01 2.667 3.85E+01 2.667 9,09E+01 2.670 1.00E+02 2.670 1.66E+02 2.664 1.79E+02 2.664 1.39E+01 2.669 1.48E+01 2.669 9.07E+00 2.660 9.24E+00 2.660 2.16F+01 2.678 2.37E+01 2.678 1.13E+O1 2.674 ft-1 1.50E+13 2.44E+15 3.11E+13 2.48E+15 2.69E+13 8.23E+14 3,90E+10 4.40E+10 1,21E+09 1,35E+09 5.90E+07 6.27E+07 4.99E+07 5.33E+07 5.58E+07 6.11E+07 7.36E+08 8.95E+08 4.73E+09 5.53E+09 2.33E+08 2.55E+08 5.61E+09 1.36E+10 5.53E+08 6.31E+08 2.89E+08 3.21E+08 9.37E+11 1.52E+12 3.69E+09 4.37E+09 4.19E+10 5.10E+lO 1.81E+lO 2.11E+10 2.26E+10 2.66E+10 2.43E+09 2.87E+09 1.16E+IO 1.44E+10 3.80E+10 4.59E+10 2.04E+08 2.31E+08 6.81E+07 7.29E+07 6.95E+08 8.16E+08 1.30E+08 Core Laboratories Ii: II Arco Alaska, Inc. Alpine CD1-01 51V 7152.25 53V 7154.25 53V 7154.25 55V 7156.25 551/ 7156.25 57V 7158.25 57V 7158.25 59V 7160.25 59V 7160.25 61V 7162.25 61V 7162.25 63V 7164.35 63V 7164.35 65V 7166.64 65t/ 7166.64 67V 7168.25 671/ 7168.25 69V 7170.2 69V 7170.2 71V 7172.25 71V 7172.25 73V 7174.25 73V 7174.25 75V 7176.25 75V 7176.25 77V 7178.25 77V 7178.25 79V 7180.14 79V 7180.14 81V 7182.25 81V 7182.25 SUMMARY OF VERTICAL PERMEABILITY AND POROSITY MEASUREMENTS 24OO 20.5 28.3 800 22.3 62.6 24O0 21.7 60.0 800 21.4 52.2 2'~0 20.9 50.0 800 21.5 19.9 2460 21.1 18.8 800 11.0 0.0100 2400 9.8 0.00599 800 14.4 0.0437 2400 13.6 0.0227 800 12.1 0.0188 2400 11.3 0.0103 800 12.8 0.0231 2,t00 12.1 0.0115 800 12.2 0.0173 2400 11.5 0.00933 800 11.0 0.0145 2400 10.1 0.00554 800 10.4 0.0152 2400 9.6 0.00547 800 9.9 0.00585 2400 9.0 0.00241 800 11.2 0.0130 2'~0 10.4 0.00~93 800 10.8 0.0131 2400 10.3 0.00647 800 10.1 0.00682 2400 9.4 0.00352 800 9.8 0.00434 2400 8.6 0.00143 Kair factor Beta md psi fi-1 25.6 5.29E-H)O 1.42E+08 58.0 3.85E+00 4.32E+07 55.5 3.89E+00 4.58E+07 48.1 4.13E+00 5.57E+07 46.2 4.13E+00 6.00E+07 17.5 7.05E+00 2.54E+08 16.6 6.90E+00 2.91E+08 0.00325 1.89E+02 7.21E+14 0.00205 1.75E+02 4.45E+14 0.0219 7.94E+01 5.73E+14 0.00830 1.38E+02 9.08E+13 0.00888 9.44E+01 1.98E+15 0.00405 1.32E+02 4.05E+15 0.0111 9.01E+01 3.08E+15 0.00378 1.71E+02 2.3~+15 0.00704 1.26E+02 9.4~+14 0.00341 1.49E+02 6.77E+13 0.00655 1.04E+02 5.35E+15 0.00220 1.31E+02 2.50E+16 0.00772 8.35E+01 2.22E+14 0.00355 4.62E+01 3.21E+16 0.00308 8.19E+01 2.96~+15 0.000848 1.67E+02 1.19E+16 0.00819 5.04E+01 2.39E+16 0.00190 1.36E+02 3.54E+16 0.00561 1.17E+02 2.67E+14 0.00247 1.41E+02 7.97E+13 0.00299 1.17E+02 8.34E+14 0.00134 1.49E+02 1.35E+15 0.00229 8.35E+01 8.42E-+13 0.000467 1.91E+02 3.39E+16 ' File: DAL-99133 microns I 9ms/~ I 1.18E+O1 2.674 8.09E+00 2.671 8.24E+00 2.671 8.67E+00 2.667 8.95E+00 2.667 1.44E+01 2.663 1.56E+01 2.663 7.50E+03 2.675 2.94E+03 2.675 3.77E+04 2.667 2.39E+03 2.667 5.40E+04 2.673 5.25E+04 2.673 1.03E+05 2.674 2.77E+04 2.674 2.05E+04 2.679 7.41E+02 2.679 1.07E+05 2.681 1.77E+05 2.681 5.28E+03 2.682 3.67E+05 2.682 2.87E+04 2.670 3.12E+04 2.670 5.86E+05 2.689 2.16E+05 2.689 4.75E+03 2.677 6.19E+02 2.677 7.96E+03 2.682 5.73E+03 2.682 6.06E+02 2.691 5.14E+04 2.691 ii Core Laboratories SUMMARY OF VERTICAL PERMEABILITY AND POROSITY MEASUREMENTS Arco Alaska, Inc. Alpine CD1-01 51V 7152.25 2,~X) 20.5 53V 7154.25 800 22.3 53V 7154.25 2400 21.7 55V 7156.25 800 21.4 551/ 7156.25 2400 20.9 57V 7158.25 800 21.5 57V 7158.25 2400 21.1 59V 7160.25 800 11.0 59V 7160.25 2400 9.8 61V 7162.25 800 14.4 61V 7162.25 2400 13.6 63t/ 7164.35 800 12.1 63V 7164.35 2400 11.3 65V 7166.64 800 12.8 65V 7166.64 2400 12.1 67V 7168.25 800 12.2 671/ 7168.25 2400 11.5 69V 7170.2 800 11.0 69V 7170.2 2400 10.1 71V 7172.25 800 10.4 71V 7172.25 2400 9.6 ~ 7174.25 800 9.9 73V 7174.25 2400 9.0 751/ 7176.25 800 11.2 75V 7176.25 2400 10.4 77V 7178.25 800 10.8 77V 7178.25 2400 10.3 79V 7180.14 800 10.1 79V 7180.14 2400 9.4 81V 7182.25 800 9.8 81V 7182.25 2400 8~6 Kinf Kair factor Be~a ' File: DAL-99133 iGrain A~pha I Density I .ms~ i md md 28.3 62.6 60.0 52.2 50.0 19.9 18,8 0.0100 0.00599 0.0437 0.0227 0.0188 0.0103 0.0231 0.0115 0.0173 0.00933 0.0145 0.00554 0.0152 0.00547 0.00585 0.00241 0.0130 0.00493 0.0131 0.00647 0.00682 0.00352 0.00434 0.00143 58.0 55.5 48.1 46.2 17.5 16.6 0.00325 0.00205 0.0219 0.00830 0.00888 0.00405 0.0111 0.00378 0.00704 0.00341 0.00655 0.00220 0.00772 0.00355 0.00308 0.000848 0.00819 0.00190 0.00561 0.00247 0.00299 0.00134 0.00229 O.OO0467 psi fi-1 microns 5.2_.qE+O0 1.42E+08 1.18E+01 2,674 3.85E+CX) 4.32E+07 8.09E+00 2,671 3.89E-,,-00 4.58E+07 8.24E+00 2.671 4.13E+00 5.57E+07 8.67E+00 2.667 4.13E+00 6.00E+07 8.95E-,,-00 2,667 7,05E+00 2.54E+08 1.44E+01 2.663 6.90E+00 2.91E+08 1.56E+01 2.663 1.89E+02 7.21E+14 7.50E+03 2.675 1.75E+02 4.45E+14 2.94E+03 2.675 7.94E+01 5.73E+14 3.77E+04 2.667 1.38E+02 9.08E+13 2.39E+03 2.667 9.44E+01 1.98E+15 5.40E+04 2.673 1.32E+02 4.05E+15 5.25E+04 2.673 9.01E+01 3.08E+15 1.03E+05 2.674 1.71E+02 2.30E+15 2.77E+04 2.674 1.26E+02 9.40E+14 2.05E+04 2.679 1.49E+02 6.77E+13 7.41E+02 2.679 1.04E+02 5.35E+15 1.07E+05 2.681 1.31E+02 2.50E+16 1.77E+05 2.681 8.35E+01 2.22E+14 5.28E+03 2.682 4.62E-H)1 3.21E+16 3.67E+05 2.682 8.19E+01 2.96E+15 2.87E+04 2.670 1.67E+02 1.19E+16 3.12E+04 2.670 5.04E+01 2.39E+16 5.86E+05 2.689 1.36E+02 3.54E+16 2.16E+05 2.689 1.17E+02 2.67E+14 4.75F+03 2.677 1.41E+02 7.97E+13 6.19E+02 2.677 1.17E+02 8.34E+14 7.96E+03 2.682 1.49E+02 1.35E+15 5.73E+03 2.682 8.35E+01 8.42E+13 6.06E+02 2.691 1.91E+02 3.39E+16 5.14E+04 2.691 Core Laboratories Arco Alaska, Inc. Alpine CD1-01 Horizontal Plug Grain Volume Data File: DAL-99133 Sample Number Sample Depth, feet Dry Weight, gm Grain Volume, Grain Density, gm/cc Length, Diameter, mi 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 59 60 61 62 63 64 65 66 67 68 69 7O 71 72 73 74 75 76 77 78 79 80 81 7145.10 7146.10 7147.10 7148.10 7149.10 7150.10 7151.60 7152.10 7153.20 7154.10 7155.10 7156.10 7157.10 7158.10 7159.10 7160.10 7161.10 7162.10 7163.10 7164.20 7165.20 7166.50 7167.10 7168.10 7169.10 7170.00 7171.20 7172.10 7173.10 7174.10 7175.10 7176.10 7177.10 7178.10 7179.10 7180.30 7181.10 7182.10 97.485 92.042 91.018 93.03 93.93 96.34 91.662 90.908 90.585 9O.486 91.404 89.726 91.195 91.15 105.83 106.623 100.699 103.901 96.606 102.212 99.993 101.351 101.977 100.386 101.103 102.091 101.323 102.427 103.457 105.05'2 104.726 103.547 102.834 104.801 103.739 106.064 105.425 105.B33 36.4552 2.674 34.5828 2.661 34.1492 2.665 35.0222 2.656 35,4066 2.653 36,1046 2.668 34.409 2.664 34.1032 2.666 33.9592 2.667 33.966 2.664 34.1861 2.674 33.4985 2.679 34.1294 2.672 34.22O9 2.664 38.9202 2.719 40.025 2.664 37.6769 2.673 38.8658 2.673 36.1773 2.670 38.2399 2.673 37.4816 2.668 37.9932 2.668 38.1583 2.672 37.4512 2.680 37.7282 2.680 38.141 2.677 37.7442 2.684 38.2739 2.676 38.67 2.675 39.2953 2.673 38.9648 2.688 38.7805 2.670 38.3902 2.679 39.1247 2.679 38.3543 2.705 39.5428 2.682 39.102 2.696 39.2416 2.697 3.941 3.727 3.937 3.726 4.011 3.725 4.026 3.728 3.951 3.729 4.005 3.73 3.976 3.73 3.993 3.729 3.947 3.727 3.963 3.728 3.955 3.728 3.918 3.727 3.981 3.728 3.955 3.729 4.068 3.724 4.031 3.719 3.961 3.723 4.025 3.72 4.044 3.723 4.016 3.72 3.945 3.723 4.019 3.725 3.979 3.721 3.923 3.718 3.924 3.714 3.962 3.722 3.889 3.717 3.943 3.718 3.991 3.725 4.025 3.719 4.04 3.719 4.005 3.722 3.964 3.72 4.O34 3.722 3.936 3.719 4.03 3.723 4 3.72 3.986 3.718 Core Laboratories Arco Alaska, Inc. Alpine CD1-01 Horizontal Plug Grain Volume Data File: DAL-99133 Sample Number Sample Depth, feet Dry Weight, gm Grain Volume, Grain Density, gm/cc Length, Diameter, m 1 m 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 59 60 61 62 63 64 65 67 68 69 7O 71 72 73 74 75 76 77 78 79 8O 81 7145.10 7146.10 7147.10 7148.10 7149.10 7150.10 7151.60 7152.10 7153.20 7154.10 7155.10 7156.10 7157,10 7158,10 7159,10 7160,10 7161,10 7162,10 7163.10 7164.20 7165.20 7166.50 7167.10 7168.10 7169.10 7170.00 7171.20 7172.10 7173.10 7174.10 7175.10 7176.10 7177.10 7178.10 7179.10 7180.30 7181.10 7182.10 97.485 92.042 91.018 93.03 93.93 96.34 91.662 90.908 90.585 90,486 91,404 89.726 91.195 91.15 105.83 106.623 100.699 103.901 96.606 102.212 99.993 101.351 101.977 100.386 101.103 102.091 101.323 102.427 103.457 105.052 104.726 103.547 102.834 104.801 103.739 106.064 105.425 105.833 36.4552 2.674 34.5828 2.661 34.1492 2.665 35.0222 2.656 35.4066 2.653 36.1046 2.668 34.409 2.664 34.1032 2.666 33.9592 2.667 33.966 2.664 34.1861 2.674 33.4985 2.679 34.1294 2.672 34.2209 2.664 38.9202 2.719 40.025 2.664 37.6769 2.673 38.8658 2.673 36.1773 2.670 38.2399 2.673 37.4816 2.668 37.9932 2.668 38.1583 2.672 37.4512 2.680 37.7282 2.680 38.14I 2.677 37.7442 2.684 38.2739 2.676 38.67 2.675 39.2953 2.673 38.9648 2.688 38.7805 2.670 38.3902 2.679 39.1247 2.679 38.3543 2.705 39.5428 2.682 39.102 2.696 39.2416 2.697 3.941 3.727 3.937 3.726 4.011 3.725 4.026 3.728 3.951 3.729 4.005 3.73 3.976 3.73 3.993 3.729 3.947 3.727 3.963 3.728 3.955 3.728 3.918 3.727 3.981 3.728 3.955 3.729 4.068 3.724 4.031 3.719 3.961 3.723 4.025 3.72 4.044 3.723 4.016 3.72 3.945 3.723 4.019 3.725 3.979 3.721 3.923 3.718 3.924 3.714 3.962 3.722 3.889 3.717 3.943 3.718 3.991 3.725 4.025 3.719 4.04 3.719 4.005 3.722 3.964 3.72 4.034 3.722 3.936 3.719 4.03 3.723 4 3.72 3.986 3.718 Core Laboratories Arco Alaska, Inc. Alpine CD1-01 Sample Number Sample Depth, feet Vertical Plug Grain Volume Data File: Dry Weight, gm Grain Volume, Grain Density, gm/cc Length, cm Diameter, DAL-99133 Area, cm2 1V 3V 5V 7V 9V 11V 13V E315V 17%/ 19V 21V 23V 25V 27V 29V 31V 33V 35V 37V 3gv 41V 43V 45V 47V 49V 51V 53V 55V 57V 59V 61V 63V 65V 67V 6gV 71V 73V 75'V 77V 79V 81V 7102.25 7104.25 7106.25 7108.64. 7110.25 7112.25 7114.25 7116.25 7118.25 7120.45 7122.25 7124.25 7126.25 7128.25 7130.25 7132.25 7134.25 7136.25 7138.25 7140.25 7142.14 7144.25 7146.25 7148.25 7150.25 7152.25 7154.25 7156.25 7158.25 7160.25 7162.25 7164.35 7166.64 7168.25 7170.2 7172.25 7174.25 7176.25 7178.25 7180.14 7182.25 100.671 112.888 102.83 103.548 94.184 92.678 90.165 91.616 94.615 98.949 93.422 95.669 92.722 93.82 100.053 96.243 96.276 99.2 99.793 96.654 97.7 100.813 95.004 93.693 96.148 94.661 94.741 94.12 93.654 79.79 78.388 106.715 106.066 105.344 106.548 104.977 106.587 74.634 108.486 88.996 98.439 36.9819 38.2667 37.1477 37.8234 34.8217 34.8082 33.8555 34.5354 35.6612 37.1962 35.1275 35.9255 34.9449 35.3002 37.5793 36.1502 36.2052 37.2108 37.2072 36.2372 36.5885 37.8414 35.5996 35.2181 35.904 35.3994 35.4772 35.2898 35.1725 29.8318 29.3956 39.9238 39.666 39.3206 39.7402 39.1361 39.9143 27.7514 40.5289 33.1809 36.5789 2.722 2.950 2.768 2.738 2.705 2.663 2.663 2.653 2.653 2.660 2.660 2.663 2.653 2.658 2.662 2.662 2.659 2.666 2.682 2.667 2.670 2.664 2.669 2.660 2.678 2.674 2.670 2.667 2.663 2.675 2.667 2.673 2.674 2.679 2.681 2.682 2.670 2.689 2.677 2.682 2.691 3.906 3.87 3.955 4.059 3.949 3.983 3.881 3.962 3.97 4.069 3.965 3.901 3.925 4.004 3.957 3.99 3.929 4.032 3.999 3,957 4.008 4.028 3.991 3.996 3.943 3.984 4.052 3.986 3.983 2.971 3.058 4.04 4,042 3.981 3.973 3.893 3.95 2.796 4.048 3.291 3.623 3.768 3.778 3.772 3.781 3.783 3.782 3.781 3.782 3.782 3.784 3.783 3.781 3.783 3.782 3.782 3.782 3.784 3.784 3.785 3.784 3.783 3.785 3.784 3.785 3.785 3.782 3.784 3.784 3.783 3.777 3.78 3.779 3.78 3.78 3.78 3.776 3.779 3.78 3.777 3.776 3.777 Core Laboratories [ ' " SURVEY CALCULATION AND FIELD WORKSHEET Job.o. 0451  Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling - Rig: #19 ...... Field ALPINE Well Name & No. CD#1/1PB1 / 1 Survey Section Name ANADRILL MWD BHI Rep. HARSTAD / SEYLER ~i~rL~l~ WELL DATA __-, Target TVD (F'r) Target Coord. N/S Slot Coorcl. N/S -222.00 Grid Correction 0.000 Depths Measurecl From: RKB ~ MSL~ SS~ Target Description Target Coord. E/W Slot Coord. E/W 2572.00 Magn. Declination 26.350 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft[~ 30mE~ lomr-] Vert. Sec. Azim. 3.70 Magn. to Map Corr. 26,350 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 (FT) (DD) (DD) (F--I~ (F-~ (FT) (FT) (Per 100 FT) Drop (-) Left (-) MWD 5850.68 21.97 357.70 5773.87 576.05 576.57 4.82 TIE IN POINT 12-JUN-99 MWD 5946.86 23.72 3.80 96.18 5862.51 612.93 613.86 5.38 3.06 1.82 6.34 6 3/4" M1X 1.4 DEG AKO '" 12-JU N-99 MWD 6042.15 26.01 13.30 95.29 5949.00 652.71 653.34 11.46 4.82 2.40 9.97 12-JUN-99 MWD 6137.69 26.41 22.80 95.54 6034.76 693.47 693.33 24.52 4.41 0.42 9.94 _. -- 13-JUN-99 MWD 6232.77 26.34 22.60 95.08 6119.94 733.40 732.29 40.82 0.12 -0.07 -0.21 13-JUN-99 MWD 6327.79 27.78 32.60 95.02 6204.60 772.75 770.43 60.86 5.02 1.52 10.52 13-JUN-99 MWD 6422.65 27.90 36.60 94.86 6288.49 810.75 806.88 86.01 1.97 0.13 4.22 13-JUN-99 MWD 6517.52 29.91 36.50 94.87 6371.53 849.27 843.71 113.31 2.12 2.12 -0.11 13-J U N-99 MWD 6612.53 30.79 37.30 95.01 6453.52 889.43 882.10 142.14 1.02 0.93 0.84 13-JUN-99 MWD 6708.12 33.13 34.40 95.59 6534.62 ' 932.28 923.12 171.73 2.93 2.45 -3.03 14-JU N-99 MWD 6762.32 32.85 33.40 54.20 6580.08 957.79 947.62 188.19 1.13 -0.52 -1.85 14-juN-99 MWD 6824.40 35.54 26.60 62.08 6631.45 989.05 977.82 205.55 7.52 4.33 -10.95 14-JUN-99 MWD 6919.84 38.20 20.90 95.44 6707.81 1042,82 1030.22 228.51 4.54 2.79 -5.97 14-JU N-99 MWD 7014.85 43.85 13.60 95.01 6779.50 1103.39 1089.73 246.75 7.79 5.95 -7.68 14-JU N-99 MWD 7109.90 50.40 7.60 95.05 6844.17 1172.46 1158.14 259.35 8.29 6.89 -6.31 15-JUN-99 MWD 7205.22 59.14 7.30 95.32 6899.10 1250.08 1235.27 269.43 9.17 9.17 -0.31 -- 15-JUN-99 MWD 7300.33 67.27 3.10 95.11 6941.96 1334.86 1319.73 277.00 9.41 8.55 -4.42 15-JUN-99 MWD 7394.81 75.40 355.70 94.48 6972.21 1423.96 1409.09 275.93 11.36 8.60 -7.83 16-JU N-99 MWD 7489.45 81.66 352.50 94.64 6991.02 1515.34 1501.28 266.37 7.40 6.61 -3.38 16-J U N-99 MWD 7584.12 89.12 345.00 94.67 6998.64 1606.38 1593.70 247.96 11.15 7.88 -7.92 -- 16~JUN-99 MWD 7680.13 93.37 342.70 96.01 6996.55 1696.63 1685.87 221.27 5.03 4.43 -2.40 16-JUN-99 MWD 7697.40 94.98 342.10, 17.27 ' 6995.29 1712.68 1702.29 216.06 9.95 9.32 -3.47 22-JUN-99 MWD 7841.18 93.77 341.90 143.78 6984.33 1845.88 1838.63 171.76 0.85 -0.84 -0.14 4 3/4" M1/XL 1.2 DEG AKO , 23-J UN-99 MWD 7938.04 91.78 341.10 96.86 6979.64 1935.45 1930.37 141.06 2.21 -2.05 -0.83 ~I ........ SURVEY CALCULATIONAND FIELD WORKSHEET Job No. 0451-05285 Sidetrack No, 1 Page 2 of 3  Company ARCO ALASKA, INC. Rig Contractor & No. Doyen Drilling - Rig: #19 Field ALPINE Well Name & No. CD#1/1PB1 / 1 Survey Section Name ANADRILL MWD BHI Rep. HARSTAD / SEYLER ~llrr~i~ WELL DATA Target TVD . (F'r) Target Coord. N/S Slot Coord. N/S -222.00 Grid Correction 0,000 Depths Measured From: RKB ~ MSL D SS[~ Target Description Target Coord. E/W Slot Coord. E/W 2572.00 Magn. Declination 26,350 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: lOOft[~ 30m~ 1OmO Vert. Sec. Azim. 3.70 Magn. to Map Corr. 26.350 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) (FT) (FT) (FT) (Per 100 FT) Drop (-) Left (-) -- 23-JUN-99 MWD 8034.62 90.55 335.30 96.58 6977.67 2022.56 2019.98 105.22 6.14 -1.27 -6.01 23-J U N-99 MWD 8130.18 90.48 334.20 95.56 6976.81 2106.18 2106.41 64.46 1.15 -0.07 -1.15 I- .__ 23-JUN-99 MWD 8226.14 89.76 329.70 95.96 6976.61 2187.75 2191.07 19.35 4.75 -0.75 -4.69 23-J U N-99 MWD 8321.99 90.62 328.60 95.85 6976.29 2266.70 2273.36 -29.80 1.46 0.90 -1.15 -- -- 23-JUN-99 MWD 8419.26 90.27 328.00 97.27 6975.54 2345.98 2356.11 -80.92 0.71 -0.36 -0.62 23-JU N-99 MWD 8515.79 90.14 328.30 96.53 6975.19 2424.52 2438.11 -131.85 0.34 -0.13 0,31 -- 23-J UN-99 MWD 8610.50 90.03 328.20 94.71 6975.05 2501.67 2518.65 -181.69 0.16 -0.12 -0.11 --__ 24-J U N-99 MWD 8709.18 90.03 328.50 98.68 6975.00 2582.16 2602.65 -233.47 0.30 0.00 0.30 -- 24-JUN-99 MWD 8805.18 90.00 326.30 96.00 6974.98 2659.52 2683.52 -285.19 2.29 -0.03 -2.29 24-JUN-99 MWD 8901.78 90.31 329.20 96.60 6974.72 2737.71 2765.21 -336.73 3.02 0.32 3.00 .._ 24-JUN-99 MWD 8997.47 91.23 327.40 95.69 6973.43 2815.70 2846.61 -387.01 2.11 0.96 -1.88 25-J U N-99 MWD 9092.93 91.48 326.40 95.46 6971.17 2892.12 2926.56 -439.12 1.08 0.26 -1.05 25-J UN-99 MWD 9190.00 90.03 325.90 97.07 6969.89 2969.07 3007.16 -493.19 1.58 -1.49 -0.52 - 25-J U N-99 MWD 9284.51 90.69 327.90 94.51 6969.30 3044.74 3086.33 -544.79 2.23 0.70 2.12 ___ 25-J UN-99 MWD 9380.38 90.17 326.50 95.87 6968.58 3121.80 3166.91 -596.73 1.56 -0.54 -1.46 25-JUN-99 MWD 9477.70 90.48 327.10 97.32 6968.03 3199.62 3248.34 -650.01 0.69 0.32 0.62 -- 25-JUN-99 MWD 9573.45 90.89 327.80 95.75 6966.88 3276.84 3329.05 -701.53 0.85 0.43 0.73 26-JUN-99 MWD 9669.46 91.10 327.20 96.01 6965.22 3354.30 3410.01 -753.10 0.66 0.22 -0.62 26-JUN-99 MWD 9766.75 91.23 326.70 97.29 6963.24 3432.24 3491.54 -806.15 0.53 0.13 -0.51 26-JUN-99 MWD 9863.84 90.99 326.00 97.09 6961.36 3509.40 3572.34 -859.94 0.76 -0.25 -0.72 26-J UN-99 MWD 9933.87 91.10 328.70 70.03 6960.08 3565.79 3631.29 -897.71 3.86 0.16 3.86 -- 27~JUN-99 MWD 10029.70 90.93 328.40 95.83 6958.38 3644.13 3713,03 -947.71 0,36 -0,18 -0.31 27-JUN-99 MWD 10125.41 90.93 327.60 95.71 6956.83 3721.85 3794.19 -998.42 0.84 0100 -0.84 27-JU N-99 MWD 10221.29 91.17 328.00 95.88 6955.07 3799.50 3875.30 -1049.50 0.49 0.25 0.42 " SURVEY CALCULATION AND FIELD WORKSHEET i Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling - Rig: #19 F'mid ALPINE Well Name & No. CD#1/1PB1 / 1 Survey Section Name ANADRILL MWD BH! Rep. HARSTAD / SEYLER IN"r~~ WELL DATA Target TVD · (F'r) Target Coord. N/S Slot Coord. N/S -222.00 Grid Correction 0.000 Depths Measured From: RKB · Target Description Target Coord. E/W Slot Coord. E/W 2572.00 Magn. Declination 26.350 Calculation Method MINIMUM CURVATUR Target Direction (DO) Buil~Walk\DL per: 1OOft~ 30m~ 10m~] Vert. Sec. Azim. 3.70 Magn. to Map Corr. 26.350 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(+) / $(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FT) (F'r) (FT) (F-T~ (Per ~00 F'r)Drop (-) Left (-) 27-JUN-99 MWD 10289.00 91.17 328.00 67.71 6953.69 3854.48 3932.71 -1085.37 0.00 0.00 0.00 Projected Data - NO SURVEY I __ ___ ___ __ __ _. I __ -- -- __ -- .... Schlumberger NO. 12758 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: Alpine (Open Hole) Color Well Job # Log Description Date BL Sepia Prints CD CD1-01 '~' ~,.~ 0 99286 CDPJADN/IMPULSE 990627 1 CD1-01 99286 VISION 475 MD 990626 1 1 CD1-01 99286 VISION 475 TVD 990626 I 1 ,, CD1-01 99286 VISION 475 MD 990627 I 1 CD1-01 99286 VISION 475 TVD 990627 I 1 8/19/99 SIGNED DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thane you. ANADRILL SCHLUMBERGER Survey report ~7-Jun=9~ Q7~5~:40 Page Clien~.~.~..~..~.~.~.,.~.! ARCO Alaska{ InF. ~ Colvi%le Rive¥ !CD1-0% ; 50-103-$0299-00 ! Leafs~edt COU~T¥:i~ . r . . ~ .. ~ . ~. ~. ~ . ~.; North S%ope Bereu~gh STATE~.}.~..~..,.~. ~.~.~.; Alask~ ,~ , ---~- Spryey calculat~oD Metho~ ~o[ p~si~iQns.~.~.:! MinimDm cUrya~u[e Method {oy D~S.~.~.~.~.~.~ Mason & Tayi!ov ---~- Dip~h reference -~-~ ....... ~-~-~-~-r-~-m Permanent datum~.~.~.~.~.~ GROUN~ LEVEL Depth' r~ferencei'~'~'~'~'~ GL ~b~v~ perNan¢n~.~.,.~.'; 19.50{t KB ~b@v~ perNanen~ ~ ~ ? '~ Top Drive DF ~bev~ per~an¢n~.~.~.~.~ 55.78ft .... ~- Vertical section erigin---~-~-~-r-n-~-= Latitude !+N/S-!.~.~.~.'~.~ ~.O0 ft Departure (+E/W~)~.~.,.~.~ 0.O0 ft .... ~- Platform reference point Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W'),., ..... : -999.25 ft Azimuth from ro~ary table to target: 3.70 degrees ORIGINAL = """IVED Last survey date~.,.r.~.~: 27-Jun-99 To~a% accepted s~rveys,.,: 1!1 . MD. of firs~ ~u[vey~.~.~.i: '115~00 ft ,,lt~15 1999 MD: o~ last! s~rve~.~.~. ~-~-~.. : Geom~gne~iG ~a~a ---,-,---,-,-,--.,-,-,-,. .. Magnetic mod~l.~.~.:~.~.~.~: B~G~ ye[sion 1~98 Magnetic d~te..~.?.i.~.~: 14-'Ju~-1999 ~agn~tic f~eid~ s~rength 1144'106 HGNT Magnetic d~c (+E/W~)~.~.~: 26~34 degrees ~a~n~tic d~p~.~.~.~.r ~ ~ '80rSQ dDg[ees ~-~-~ MWD ~uyv~y Reference ~e~eyence ~.~.~.~.~..~., ~: ~e~eyence H'~'~'~','~'~ ,: Refeyence Dip.~.~.,.~., ~: To~eyance Qf G,.~.,.~.~ ~: To~eyance of H~.,.,.~., ,: Tolerance of Dip,.~.,., ,: C~i~e~i$ ~--~-~-r- 1002,68 m6al t144,06 H~NT 80~50 degrees (+/~) 3~00 mGal (+/?) 7,0Q HCNT (+/-) 0.30 degrees CorrectiQns ~-~- .... Magnetic dec (+E/W~),.,.,: 26,34 degrees Grid convergence (+E/W-),: 0~00 degrees Total az c~rr (+E/W-) .... : 26.34 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........ : No degree: 0.00 [ (c)1999 Anadrill' IDEAL ID5 0C 03R] ANADRILL SCHLUMBERGER Survey Report ~7~Jun-99 07:~5:4Q ,page 2 of 5 =~= ~=~=~=~= ~=~=== ===~=~= ~=~=~= ~=~=~=~= seq Measured Inc1 A~imu~h Course TVD # ~epth angle angle ~eng~h ~epth ? If~) <~eg) tdegl (~tI lf~) =~= ~=~=~=~= ~=~==~ =~=~=~= ~=~=~= ~=~=~=~= i li~.Oo 0.o0 o~o 0.0o ~ 2 %99.00 0.49 i92~i 84.00 %99.0© 3 290.25 {.29 355~8 9!.30 ~90.~9 4 380.75 3.52 359~1 90.50 38Q.71 5 469.74 5.98 3~4 88.90 469.30 6 553.17 8.25 6~3 7 ~50.~i 9.0~ 3i5 8 739.~0 $.9~ 1,8 9 82~.~3 :9.9~ 3~1 10 918.90 9.97 0~8 ~1 1Q06.74 1 12 1097.$7 1 ~3 1192.45 1 ~4 i~87.~6 i !5 i~80.go !6 1477.93 17 157~.99 18 166~.01 !9 1764.11 R0 1859.71 83.,50 9~.90 8~.~o 8~.~o 9Q.~O 558.!5 647.85 736.05 823.65 ~lS.08 ~.10 1~1 87.~0 999.40 1.1~ 0,8 90.70 1~88.40 1.0~ 0,8 9~.00 1i8!.62 0.8~ 1~2 95.~0 1275.19 9.22 3~9,6 9~.~0 1~66.27 8.07 357~5 97.70 146~.86 5.97 357,4 9~.10 1~58.23 4.14 356~1 95.00 1~52.86 2.47 354,1 95.10 1747.80 0.64 3~2,3 95.60 1843.36 21 1954.86 0.87 330,6 95.20 22 2049.76 0.87 330.7 94.90 23 2145.16 1.00 320~4 95.40 24 2239.93 0.99 309,0 94.70 25 2334.89 0.91 314,7 95.00 23.80 66.70 97.10 94.30 95.00 26 2358.68 0.87 325.2 27 2425.40 0.75 321.2 28 2522.50 0.80 333,2 29 2616.77 0.80 337.1 30 2711.85 0.77 330,3 1938.55 2033.44 2128.83 2223.51 2318.50 2342.30 2408.99 2506.08 2600.37 2695.36 =~=~=~=~ Ver~i~a1 Disp~ D$spl sectio~ +N/S~ +E/W- (~t>i If~) =~=~=~m~ ==~=~=~===~=~=~= 0.~0 ~0~00 ~.00 ~0.36 +0~3~ -0.08 o.28 4.~6 4~09 -0.35 !i.4i 11.4~ -0.12 21.74 21 7~ 0.80 36.31 : 36;25 ~.02 ~0.23 ~011~ ~ 64.77 ~4~7Q $.:So 80.47 80i3~ 3.83 96,.S0 ~6~4~ 4.~0 113.~ 1~3i9~ ~.39 132.22 132~20 4.65 1~0.31 150,3Q 4.96 i66.4:i i~6i48 5.09 181.Q3 181~10 4.74 192.71 192~85 4.22 2oi.~2 2~i,i~ j.76 206.44 2~6~66 3.32 208.s0 2~9i06 2.7i 209.74 210.05 1.96 210.95 211.31 1.26 212.16 212.58 0.37 213.24 213.73 -0.79 214.20 214,78 -1.96 214.47 215.06 -2.20 215.19 215.82 -2.76 216.24 2t6-~92 -3.47 217.40 218.11 -4.02 218.52 219.28 -4.60 ~ota% At ~isp% A~im (StI (deg: =~=~=~===~=~=~= 0.0o 0.0o 0.~6 0.37 ~.%0 ~55.~0 1~.44 359.A0 DL$ (~e~/ lOO~) '0.0o 0.58 ~.93 2.~7 2.79 2!.75 g.lO 36..$1 : S.20 50.~3 ~.05 64.28 2.:~2 80.48 .~.73 2.75 0.93 0.34 ~.~0 0.44 S~vy t0ol type --_____~--~_ TTP ~D I~D FInD lVlWD I~D 96.53 g.44 !.29 MWD $14.Ol a.gl 0.O8 MWD ~32.~8 8.01 0.!1 MWD ~50.~8 ~.89 O.~l MWD ~6~.~0 1.75 l.~0 MWD !81.16 !.50 1.22 ~WD !9~.~8 ~.~5 ~.19 MWD ~01.~3 ~.07 1.93 MWD 206.68 0.~2 1.76 ~D ~09.08 0.74 2.13 ~D 210.06 0.54 0.35 211.31 0.34 0.00 212.58 0.10 0.22 213.73 359.79 0.21 214.79 359.48 0.13 215.07 359.41 215.83 359.27 216.94 359.08 218.15 358.94 219.32 358.80 0.70 0.2o 0.17 0.06 0.10 MWD MWD MWD MWD MWD MWD M MWD MWD MWD MWD T~o~ q~a~ type 6-ax~s C-axis 6-axis 6-axis 6-~x~s ~-~x,is 6-~x~s 6-~xis ¢-ax!s 6-~xts 6-~xis 6-ax~s 6-~xis 6-~x~s 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)1999 Anadrill IDEAL ID5 0C 03R] -- -- ANADRILL SCHLUMBERGER Survey Repo[t 27~Jun-99 07:55:40 page 3 of 5 seq Measured Inc~ ATimu~h =~= ~=~===~= ~=~=~ =~=~=~= 31 2806.$5 0.63 382,7 32 2903.73 0.57 389r5 33 2997-73 Q.6g 328~3 ~4 3093.%0 0.75 355,7 35 3188.34 0.74 332,8 36 3283.20 0.70 328~3 ~7 3~78.87 Q.8~ 3~2,4 S8 3473.~8 P'78 3~9,9 39 3568.80 0.6~ 340,2 ~0 3663.74 Q.~ 3~2,1 length (~tl 9~.50 97.40 9~.0o 95.4o 95.2o 9;.~o 95.70 9.4 .'70 9~.~o 9A.90 ,J. 1 3759.47 0.4.~ 42 3,854.26 0.-50 43 395Q.31 0.3~ 44 404~.64 0-49 45 4t4;[.47 O.~ TVD ~e~t~ ~=~=;=~= 278~.86 2887.25 298~.25 3076.64 3!7~.83 46 4236.26 0.49 ¢,7 4331.38 0.55 48 4426.42 0.,50 49 4521.85 50 4615.76 0.46 3266;.72 3262.. 41 3~53.!:~1 3552.30 3647.~9 12r2 9~.~0 3742.99 8~8 9~.80 3¢37.79 ~4,0 9~.00 3933.78 ~4,6 94.30 4028.08 ~0~7 96.90 412~.98 37,7 9A.f10 4~19.77 24~8 9~.10 4~14.fl7 5,5 95.00 4409.87 4~9 9~.50 4505.36 358~0 93.90 4599.26 51 4711.09 0.93 7,8 95.30 52 4806.14 6.07 21,4 95.00 53 4901.12 8.52 22~1 95.00 54 4996.69 12.65 19,8 95.60 55 5091.91 17.39 9~3 95.20 4694.55 4789.34 4883.57 4977.52 5069.46 =~=~=~=; VCr~i~a~ ~ectiop 259.45 220.25 221.09 222.10 223.18 ==~=~=~=~=~=~==~= ~i~pl D%spl %N/S +E/w- (~)~ (~ti -~==~= ,~==~===~==~==~== 220'2~ -~.~3 22108 -5.80 22196 -6~33 223'0% -6.88 224.13 -7.~2 224.21 2~ 5.:. 34 2~6' ~5 207.62 2¢8.53 2~9.~4 2~0.!2 2~0.82 2~1.50 2~2.29 233.Q0 233.76 234.~0 235.4'5 236.2.4 225;19 226~36 287;6~ 228i7Q 229i62 230t45 221;28 2~1192 222158 2~3,3~ 234~03 2~4;77 235160 236143 227i22 237.39 242.95 254.41 271.20 295.39 =~=~=~=~=~=~=== To~a~ At ~isp~ A~im (ftI ldCg1 =~=~=~===~=~=~= Z20.~o $58.~4 22~.%6 $58.~0 ~2a.95 223.!2 35~.~3 22~.25 238~38 243~82 255.02 271.44 295,30 DLS (de~/ 1'Oo~) 0.~8 0.!o 0.!2 0.12 0.04 -8.02 ~25.~4 ~57.~6 0.06 -8.55 ~20.~3 357.84 0.21 -8.97 827.78 357.74 0.05 -~.37 ~20.'89 $57.65 0.17 -~.69 ~29.84 357.58 0.06 -9.76 ~30.66 $5~.58 0.30 -9.61 83~.43 357.¢2 Q.Q6 -9.~3 232.11 357.67 0.~9 -9.21 232.76 357.73 0.16 -8.~8 233.52 357.~2 Q.~5 -8.42 834.18 357.94 0.07 -~.98 23~.9© 350.05 0.~4 -7.75 235.72 358.~2 -7.67 236.56 35~.~4 0.Q1 -~.65 237.35 358.~5 0.08 -7.F6 23~.49 358.18 0.51 -5.62 243.88 358.68 5.44 -1.14 255.02 359.74 2.58 5.08 27!.48 1.07 4.34 10.91 295.50 2.12 5.72 56 5187.24 20.83 358,8 95.30 5159.52 326.46 326.31 12.86 57 5280.97 20.69 359,4 93.80 5247.23 359.60 359i56 12.34 58 537~.91 22.58 358,9 95.90 5'336.37 394.85 394,91 1~.81 59 5472.32 21.81 358.2 95.40 5424.70 430.74 430.93 10.90 60 5567.21 23.44 357.6 94.90 5512.29 467.06 467.42 9.55 s~vy type _--~=_- ,~D ~D M~D M~D M~D MWD MWD M~D MWD ~D M~ID ~D M~D M~D MWD ~MWD MWD MiND MWD MWD MWD MWD MWD MWD 326.57 2.26 5.09 MWD 359.77 1.97 0.27 MWD -395.09 1.71 1.98 'HWD 431.07 1.45 0.85 MWD 467.51 1.17 1.73 MWD T~o~ q~a~ type ~=~=~= 6-ax±s 6-axis 6-axis 6-axis 6-axes 6-ax¢s 6-axis 6-8~is 6-~xis 6-~x~s 6-~x~s 6--~X!S 6-~xis 6-~xis 6-aXiS 6-~x!s 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [ (c)1999 Anadrill IDEAL ID5 0C 03R] ANAD~BI~L SCHLUMBERGER Survey Revolt =~= ~=~=~=~= ~=~==~ =~=~=~= ==~=~= seq Measured Incl A~imu~h ~o~r~e ~ ~epth angl~ anale length r lf~) <4eg! !deg1 =~= ~=~=~=~= ~=~==~ =~=~=~= ~=~=~= 61 566Q.83 2Z.9~ 357~7 93.60 ~2 5755.68 22.38 357~2 94.90 63 5~50.68 21.97 357~7 95.Q0 64 5946.86 23.72 3~8 9~.~0 65 6042.15 26.01 13,3 95.20 66 6137.69 26.41 ~2 ? 8 95.60 ~7 6~32.77 26.34 22~6 9.5.~.0 68 6~27.,79 27.7~ :32~6 9~.QO 69 6'422.65 2~. 9Q 36~ 6 94.80 VO 6517.~2 29.9~ 36~5 9A.~O 71 6612. ~3 3Q. 7,9 ~7~ 3 95.00 72 6~08.12 33.13 ~4~4 95.~0 73 6762.$2 3Z.8~ 33,4 54.20 74 6824.40 3'~.5~ 26,6 62.10 75 691~.84 38.20 20,9 95.40 76 7014.85 77 7109.90 78 7Z05.~2 79 7300.$3 80 7394.81 43.8~ !3~6 9~.~0 50.4~ 7~6 95.Q0 59.14 7,3 95.30 67.27 3~1 95.10 75.40 355~7 94.50 81.66 352,5 94.70 89.12 345.0 94.60 93.37 342.7 96.Q0 94.98 342,1 17.30 93.77 341,9 143.80 81 7489.45 82 7584.12 83 7680.13 84 7697.40 85 7841.18 86 7938.04 91.78 341.1 96.80 87 8034.62 90.55 335,3 96.60 88 8130.18 90.48 334.2 95.60 89 8226.14 89.76 329.7 95.90 90 8321.99 90..62 328.6 95.90 TVD ~ep~n ~=~=%-~- 559~.33 568~.91 5773.89 5~6~.5s 5948.95 6034.76 6~o~. ~o 6~8~.~4 6571.51 645~.49 6534.60 658o.06 663!.44 6707.78 6~79.53 6844.17 6~99.09 6941.94 6972.20 6991.02 6998.63 6996.55 6995.29 6984.32 6979.63 6977.67 6976.81 6976.61 6976.29 27~Jun-99 07:55:40 Vcrtica~ ~e~o~ =~=~=~=~ 5~3.7o 54o.o~ 575.68 6~2.94 652.69 Di~pl D$spl : ~N/S~ +~/W- {f~) (~t1 ~=~=~=~=;=~=~=~= 5~4,2~ ~.04 540.75 ~.42 576.57 4.82 613.87 5.38 653.31 11.46 693.46 733.~1 8'~0.72 849.26 889.4~ 932.27 957.77 989.Q5 ~i0~2.79 693.33 732~3Q '770~4$ 843,70 : 882~08 92311% 947~6~ ~o~oi~ ?age 4 of 5 Total At ~i~p% ADim (~tI Ideg1 =~=~=~===~=~=~= ~o4.3o , ~40.79 0.68 576.59 0.48 613.89 653.41 1.00 !103.42 i172.46 1250.~6 1334.83 1423.95 1515.39 1606.36 1696.60 1712.68 1845.90 1089~77 ~235~25 1319170 !4~9'0~ 1501.33 1593.68 1685.84 1702.28 1838.65 DLS 10o~) -~-~=- 0.55 0.61 O.~8 3.06 4.83 1935.41 2022.54 21'06.19 2187.72 2266.70 1930.33 2019.96 ~106.42 2191.04 2273.37 24.52 693.76 2.03 4.40 40.83 733.44 3.19 0.12 6Q.86 .77~.~3 4.52 5.02 8~.~9 81~.42 6.08 1.97 $15.31 851.~8 7.~5 2.12 $42.!3 89~.46 9.!5 1.02 $71.72 93~.95 10.~4 2.93 ~88.18 966.~1 1~.23 ~.~3 $0~.~5 999.~9 1!.87 7.52 ~28.50 1055.,,?--.3 12.~51 4.54 ~46.76 259.36 ~69.43 277.00 275.93 266.37 247.96 22!.28 216.06 171.75 141.08 105.22 : 64.45 19.36 -29.81 Srvy to~l type M~D MWD MWD MWD MWD MWD MWD M~D MWD MWD i' MWD M~D 111~.35 18.76 7.78 MWD 1186.82 la.62 8.3© MWD 1264.29 la. S0 9.17 MWD 1348.46 11.85 9.41 MWD 1435.84 I!.Q8 11.35 MWD 1524.78 10.06 7.39 MWD 1612.85 8.84 11.16 MWD 1700.30 7.48 5.03 MWD 1715.94 7.23 9.93 MWD 1846.65 5.34 0.85 MWD 1935.48 4.18 2.22 MWD 2022.70 2.98 6.14 MWD 2107.41 t.75 1.15 MWD 2191.12 0.51 4.75 MWD 2273.56 359.25 1.46 MWD ~=~=~= qua~ typ~ ~-a×~s ~-~x~s 6-~x$s ~-ax%s 6-ax$s 6-ax~s ~-~x~s 6-~x~$ ~-~x~s 6-axSs 6-~x$s 6-ax~s 6-~x$s 6-ax$s 6-~x$s 6-axis 6-ax~s 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)1999 Anadrill IDEAL ID5 0C 03R] -- -- ANADRILL $CHLUMBERSER Survey Repo[t 27~Jun-99 07:55:40 page 5 of 5 ..... ~=~=~== ~=~=== =~=~=== ~=~=~= ~=~=~=~= Seq M~asu~ed Incl A~imuth ~ourse : TyD # d~p~h angle angle %ength depth - (ft)' (deg! (dDg! (~t1 ---~ =~=~=~=~ ~=~=:~ =~=~=~= ~=~=~= ~=~=~=~= 91 84!9~26 90.27 328i0 97.~0 6975.53 92 8515~79 90.14 328i3 9~.50 6~75.19 93 86~0i50 90.05 3~8r2 94.70 6~7~.05 94 8709,18 90.03 328~5 98.70 6974.99 95 8805.18 90.00 326.3 96.00 6974.97 96 8901.78 90.31 329 97 ~9~7~47 9~.2~ 3~7 98 9092~95 91.4p 3.26 9~ 9~o~o~ 90.o~ 3~5 10~ 92~4~5% 9Q.69 327 ~0~ 9380~38 90.1! 326 %02 9477~70 90.4~ 3:27 ~05 9573~4~ 90,89 327 104 9669~46 9~.10 327 %0~ 97~6~75 9~.2~ 326 ~0~ 9863,8g 90.99 326 %07 99~3~87 9!.10 328 !08 100~9~70 90.93 328 ~09 10195~4! 90.93 327 ~1~ 10221~29 91.17 328 ,2 9~.~0 6974.71 14 95.70 6973.42 i4 9~.40 ! 6~71.~7 ~9 97.~0 696:~.89 ~9 9'~.~0 6~69.29 ~5 9~.90 6968.57 rl 97.$0 6968.02 r8 9~.80 6966.88 r2 96.00 696~.~1 r7 97.~0 696~.~3 ,0 97.~0 696~.35 ~7 70.10 6960.07 ~4 9~.80 6958.38 ~6 95.70 6956.82 ,0 9~.~0 6955.07 Projected to TD i'1! ~10289;00 91.17 328,0 67.70 6953.68 Ver~iGa! se~ti0~ (~t). =~===~=~ 2346.Q1 24~4.5~ 2659.54 2737.73 ~892.09 29'69'.~? 3044.73 ~'99.6~ ~276.87 ~3~4.~3 ~432.20 3509.37 ~5¢5.81 3644.13 3721.84 ~799.51 -----~:~=~=~=~=~=~= Disp! D$spl %N/S~ +E/W- 23~6~i~ ~80.'~4 2438:i~ -~3~.S6 ~602:6~ 2765,22 ~8~6 63 29~6 55 ~i~6~9~ : 3572 31 ~631~32, $7~3~o~ -336.75 -$87.03 -~39.~1 -~93.~9 -~96.74 -~5~).02 -70~1.56 -75:~.~L3 -~06.~3 -1~59.92 $794 18 -998.41 3875~3! ~i049.~i ,. 3854.47 3932.71 -1085.38 :~=;=~=~=~:;=~= :~=;= ==~:= To~a~ At DL8 SrvY ~i$p$ A~im (deg/ t~ol : (~tI ldegI 100[) type =~=~=~===~=~=~= ===== ==~== 2357.54 35~.03 0.71 YfWD 2~4~.~8 35~.~0 0.34 ~ 2525.19 $55.87 0.16 Nfwn 2615.~2 35A.~7 0.$0 MWD 2698.65 353.93 2.29 ~4WD 2785.~5 353.06 3.02 /V~WD 287~.~2 35~.~6 ~.%1 /YIWD 295.9.~9 35~.47 1.08 MWD 3'047.'$3 350.69 1.58 ~D 3~34.03 $4~.p9 2.23 ~D 3~2~.66 349.~3 ~.~6 ~WD 3'$1~.74 $48.~8 0.69 ,F/WD 340~.~0 $4~.~0 0.85 ~fWD 349~.22 347.55 Q.66 MWD 3583.~5 $47.QO Q.~3 MWD 3674.$5 ~46.47 0.?6 MWD 3740.64 $46.~1 3.85 MWD 383~.07 ~45.68 0.36 MWD 3923.~4 345.26 0.84 MWD 4014.91 34~.85 0.49 MWD 4079.74 344.57 0.00 MWD M -- TQo~ qua~ type ~=~=~= ~-axis ~-~xis 6-axis ~-ax~s 6-axis ~-~×~s 6-~x!s 6-~×~s ~-,~xis 6-~x~s 6-~x!s 6-~×~ 6-~x~s 6-~x!s 6-ax~s 6-~×~ 6-~xis 6-~x±s 6-axis [(c)1999 Anadrill IDEAL ID5 0C 03R] Client ................... : ARCO Alaska Inc. Field .................... : Colville River Well ..................... : CD1-01PH API number ............... : 50-103-20299-70 Engineer ................. : Dammeyer COUNTY: .................. : North Slope Borough STATE: ................... : Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference ...... Permanent datum .......... : Mean Sea Level Depth reference .......... : Rig Floor GL above permanent ....... : 19.20 KB above permanent ....... : Top Drive DF above permanent ....... : 55.78 ..... Vertical section origin Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point Latitude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 1.68 degrees ANADRI LL SCHLUMBERGER Survey report 29-Jun-99 18:44:42 Page Spud date ................ : 30-May-99 Last survey date ......... : 09-Jun-99 Total accepted surveys...: 79 MD of first survey ....... : 115.00 ft MD of last survey ...... : 7305.41 ft 1 of 4 Geomagnetic data .......... Magnetic model ........... : BGGM version 1998 Magnetic date ............ : 08-Ju1-1998 Magnetic field strength..: 1144.06 HCNT Magnetic dec (+E/W-) ..... : 26.35 degrees Magnetic dip ............. : 80.50 degrees MWD survey Reference Criteria Reference G .............. : 1002 68 mGal Reference H .............. : 1144 06 HCNT Reference Dip ............ : 80 50 degrees Tolerance of G ........... : (+/-) 3 00 mGal Tolerance of H ........... : (+/-) 7 00 HCNT Tolerance of Dip ......... : (+/-) 0 30 degrees Corrections Magnetic dec (+E/W-) ..... : 26.35 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 26.35 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........ : No degree: 0.00 ORIGINAL R CE VED ,IUL 1 ?5 1999 Alaska Oil Gas Cons, Commission [(c)1999 Anadrill IDEAL ID5_0C_03R] ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course ~ depth angle angle length - (ft) (deg) (deg) (ft) 1 115.00 0.00 0.0 0.00 2 199.00 0.49 192.1 84.00 3 290.25 1.29 355.8 91.30 4 380.75 3.52 359.1 90.50 5 469.74 5.98 3.4 88.90 6 553.17 8.25 6.3 83.50 7 650.11 9.05 3.5 96.90 8 739.30 8.91 1.8 89.20 9 828.13 9.95 3.1 88.80 10 918.90 9.97 0.8 90.80 11 1006.74 11.10 1.1 12 1097.37 11.14 0.8 13 1192.45 11.04 0.8 14 1287.66 10.86 1.2 15 1380.20 9.22 359.6 87.80 90.70 95.00 95.30 92.50 16 1477.93 8.07 357.5 97.70 17 1573.99 5.97 357.4 96.10 18 1669.01 4.14 356.1 95.00 19 1764.11 2.47 354.1 95.10 20 1859.71 0.64 312.3 95.60 21 1954.86 0.87 330.6 95.20 22 2049.76 0.87 330.7 94.90 23 2145.16 1.00 320.4 95.40 24 2239.93 0.99 309.0 94.70 25 2334.89 0.91 314.7 95.00 26 2358.68 0.87 325.2 23.80 27 2425.40 0.75 321.2 66.70 28 2522.50 0.80 333.2 97.10 29 2616.77 0.80 337.1 94.30 30 2711.85 0.77 330.3 95.00 29-Jun-99 18:44:42 __ TVD Vertical Displ Displ depth section +N/S- +E/W- (ft) (ft) (ft) (ft) Page 115.00 199.00 290.29 380.71 469.30 2 of 4 Total At DLS Srvy Tool displ Azim (deg/ tool qual (ft) (deg) 100f) type type 0.00 0.00 0.00 0.00 0.00 0.00 -0.35 -0.35 -0.08 0.36 192.10 0.58 0.29 0.29 -0.23 0.37 321.49 1.93 4.07 4.09 -0.35 4.10 355.10 2.47 11.43 11.44 -0.12 11.44 359.40 2.79 552.15 21.75 21.74 0.80 647.95 36.30 36.25 2.02 736.05 50.22 50.16 2.67 823.65 64.76 64.70 3.30 913.08 80.47 80.39 3.83 999.40 96.52 96.44 4.10 1088.40 114.01 113.93 4.39 1181.62 132.28 132.20 4.65 1275.19 150.38 150.30 4.96 1366.27 166.50 166.42 5.09 1462.86 181.16 181.10 4.74 1558.23 192.88 192.83 4.22 1652.86 201.22 201.19 3.76 1747.80 206.66 206.66 3.32 1843.36 209.05 209.06 2.71 21.75 2.10 2.75 36.31 3.20 0.93 50.23 3.05 0.34 64.78 2.92 1.20 80.48 2.73 0.44 1938.55 210.02 210.05 1.96 2033.44 211.25 211.31 1.26 2128.83 212.50 212.58 0.37 2223.51 213.62 213.73 -0.79 2318.50 214.63 214.78 -1.96 96.53 2.44 1.29 114.01 2.21 0.08 132.28 2.01 0.11 150.38 1.89 0.21 166.50 1.75 1.80 181.16 1.50 1.22 192.88 1.25 2.19 201.23 1.07 1.93 206.68 0.92 1.76 209.08 0.74 2.13 210.06 0.54 0.35 211.31 0.34 0.00 212.58 0.10 0.22 213.73 359.79 0.21 214.79 359.48 0.13 214.90 215.06 -2.20 215.07 359.41 0.70 215.64 215.82 -2.76 215.83 359.27 0.20 216.72 216.92 -3.47 216.94 359.08 0.17 217.90 218.11 -4.02 218.15 358.94 0.06 219.05 219.28 -4.60 219.32 358.80 0.10 2342.30 2408.99 2506.08 2600.37 2695.36 TIP - MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis MWD_M - MWD 6-axis MWD 6-axis MWD 6-axis MWD 6-axis [(c)1999 Anadrill IDEAL ID5 0C 03R] ANADRILL SCHLUMBERGER Survey Report Seq Measured Incl Azimuth Course ~ depth angle angle length - (ft) (deg) (deg) (ft) 31 2806.35 0.63 322.7 32 2903.73 0.57 329.5 33 2997.73 0.68 328.3 34 3093.10 0.75 335.7 35 3188.34 0.74 332.8 94.50 97.40 94.00 95.40 95.20 36 3283.20 0.74 328.3 37 3378.87 0.81 342.4 38 3473.58 0.78 339.9 39 3568.80 0.62 340.2 40 3663.74 0.57 342.1 94 95 94 95 94 .9O .70 .70 .20 .90 41 3759.47 0.45 12.2 42 3854.26 0.50 8.8 43 3950.31 0.36 24.0 44 4044.64 0.49 14.6 45 4141.47 0.51 30.7 95 94 96 94 96 .8O .80 .00 .30 .90 46 4236.26 0.49 37.7 47 4331.38 0.55 24.8 48 4426.42 0.50 5.5 49 4521.85 0.51 4.9 50 4615.76 0.46 358.0 94 95 95 95 93 .80 .10 .00 .50 .90 51 4711.09 0.93 7.8 52 4806.14 6.07 21.4 53 4901.12 8.52 22.1 54 4996.69 12.65 19.8 55 5091.91 17.39 9.3 95 95 95 95 95 .3O .00 .00 .60 .20 56 5187.24 20.83 358.8 57 5280.97 20.69 359.4 58 5376.91 22.58 358.9 59 5472.32 21.81 358.2 60 5567.21 23.44 357.6 95 93 95 95 94 .3O .80 .90 .40 .90 TVD depth (ft) 2789 2887 2981 3076 3171 3266 3362 3457 3552 3647 3742 3837 3933 4028 4124 4219 4314 4409 4505 4599 4694 4789 4883 4977 5069 5159 5247 5336 5424 5512 29-Jun-99 18:44:42 Page 3 of 4 Vertical Displ Displ Total At DLS Srvy Tool section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (ft) (ft) (ft) (deg) 100f) type type .86 219.99 .25 220.82 .25 221.68 .64 222.72 .83 223.81 .72 224.86 .41 226.02 .11 227.25 .30 228.33 .19 229.25 .99 230.07 .79 230.85 .78 231.54 .08 232.21 .98 232.99 .77 233.69 .87 234.43 .87 235.27 .36 236.11 .26 236.90 220.24 -5.23 221.08 -5.80 221.96 -6.33 223.01 -6.88 224.13 -7.42 225.19 -8.02 226.36 -8.55 227.61 -8.97 228.70 -9.37 229.63 -9.69 230.45 -9.76 231.23 -9.61 231.92 -9.43 232.58 -9.21 233.35 -8.88 234.03 -8.42 234.77 -7.98 235.60 -7.75 236.43 -7.67 237.23 -7.65 238.38 -7.56 243.82 -5.62 255.02 -1.14 271.44 5.08 295.30 10.91 326.31 12.86 359.56 12.34 394.91 11.81 430.93 10.90 467.42 9.55 .55 238.05 .34 243.55 .57 254.87 .52 271.47 .46 295.49 220.30 358 221.16 358 222.05 358 223.12 358 224.25 358 225.34 357 226.53 357 227.78 357 228.89 357 229.84 357 230.66 357 231.43 357 232.11 357 232.76 357 233.52 357 234.18 357 234.90 358 235.72 358 236.56 358 237.35 358 238.49 358 243.88 358 255.02 359 271.48 1 295.50 2 326.57 359.77 395.09 431.07 467.51 .52 326.55 .23 359.76 .37 395.09 .70 431.07 .29 467.50 .64 0.18 MWD 6-axis .50 0.10 MWD 6-axis .37 0.12 MWD 6-axis .23 0.12 MWD 6-axis .10 0.04 MWD 6-axis .96 0.06 MWD 6-axis .84 0.21 MWD 6-axis .74 0.05 MWD 6-axis .65 0.17 MWD 6-axis .58 0.06 MWD 6-axis .58 0.30 MWD 6-axis .62 0.06 MWD 6-axis .67 0.19 MWD 6-axis .73 0.16 MWD 6-axis .82 0.15 MWD 6-axis .94 0.07 MWD 6-axis .05 0.14 MWD 6-axis .12 0.19 MWD 6-axis .14 0.01 MWD 6-axis .15 0.08 MWD 6-axis .18 0.51 MWD 6-axis .68 5.44 MWD 6-axis .74 2.58 PrWD 6-axis .07 4.34 MWD 6-axis .12 5.72 MWD 6-axis 2.26 5.09 MWD 6-axis 1.97 0.27 MWD 6-axis 1.71 1.98 MWD 6-axis 1.45 0.85 MWD 6-axis 1.17 1.73 MWD 6-axis [(c)1999 Anadrill IDEAL ID5_0C_03R] ANADRILL SCHLUMBERGER Survey Report 29-Jun-99 18:44:42 Page 4 of 4 Seq Measured Incl Azimuth Course # depth angle angle length - (ft) (deg) (deg) (ft) 61 5660.83 22.93 357.7 62 5755.68 22.38 357.2 63 5850.68 21.97 357.7 64 5946.42 21.44 357.4 65 6042.19 20.95 357.3 66 6136.58 22.19 357.5 67 6231.83 21.85 357.4 68 6327.67 21.27 357.4 69 6422.55 21.77 357.5 70 6512.46 20.91 356.7 71 6619.05 20.72 357.2 72 6713.90 20.83 0.3 73 6809.55 20.44 1.7 74 6904.00 20.71 2.9 75 6999.00 20.98 4.7 76 7072.19 21.06 5.1 77 7159.88 21.41 5.8 78 7255.70 21.69 5.6 79 7305.41 21.54 6.1 93.60 94.90 95.00 95.70 95.80 94.40 95.20 95.90 94.80 90.00 106.50 94.90 95.70 94.40 95.00 73 .20 87.70 95.80 49.70 TVD Vertical Displ Displ depth section +N/S- +E/W- (ft) (ft) (ft) (ft) 5598.33 5685.91 5773.89 5862.80 5952.12 6039.91 6128.16 6217.35 6305.54 6389.37 6488.92 6577.65 6667.21 6755.59 6844.38 6912.70 6994.45 7083.55 7129.76 504.25 504.24 8.04 540.71 540.75 6.42 576.47 576.57 4.82 611.77 611.93 3.31 646.30 646.53 1.71 680.91 681.20 0.13 716.51 716.86 -1.45 751.65 752.06 -3.05 786.33 786.80 -4.60 818.98 819.51 -6.25 856.69 857.30 -8.27 890.30 890.94 -9.00 924.02 924.66 -8.41 957.19 957.81 -7.08 990.97 991.54 -4.84 1017.18 1048.88 1083.98 1102.24 1017.70 -2.59 1049.32 0.43 1084.33 3.92 1102.54 5.79 Total At DLS Srvy Tool displ Azim (deg/ tool qual (ft) (deg) 100f) type type 504.30 0.91 0.55 MWD 6-axis 540.79 0.68 0.61 MWD 6-axis 576.59 0.48 0.48 MWD 6-axis 611.94 0.31 0.57 MWD 6-axis 646.53 0.15 0.51 MWD 6-axis 681.20 0.01 1.32 MWD 6-axis 716.86 359.88 0.36 MWD 6-axis 752.07 359.77 0.60 MWD 6-axis 786.82 359.67 0.53 MWD 6-axis 819.54 359.56 1.01 MWD 6-axis 857.34 359.45 0.24 MWD 6-axis 890.99 359.42 1.16 MWD 6-axis 924.70 359.48 0.66 MWD 6-axis 957.84 359.58 0.53 MWD 6-axis 991.55 359.72 0.73 MWD 6-axis 1017.70 359.85 0.22 MWD 6-axis 1049.32 0.02 0.49 MWD 6-axis 1084.34 0.21 0.30 MWD 6-axis 1102.56 0.30 0.48 MWD 6-axis [(c)1999 Anadrill IDEAL ID5 0C 03R] 8/4/99 Schlumberger NO. 12732 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: Alpine (Cased Hole) Color Well Job # Log Description Date BL Sepia Prints CD Ps]. 99254, LDWG OH EDIT .c~ c:~ ,q~_t*./~ 9906].0 1 CD].-01 CD1-01 PSi 99254, PEX-AIT 990610 I 1 CD1-01 PB1 99254, PEX-DENSITY NEUTRON 990610 I 1 CD1-01 PS1 99254, BHC SONIC 990610 I 1 CD1-01 PS1 99254, CMR 990610 I 1 CD1-01 PB1 99254, PEX-TVD 990610 I 1 CD1-01 PB1 99254, RAB 990609 I 1 CD1-0]. PB1 99254, RAB TVD 990609 I 1 i,;.,i? !~;' i' ~'~ Ii,;:' i"i~, ,,~' ii.'..',;;, ~'" '~i~ SIGNE . DATE: ..~'.~1~,~,,~ ''~ ['Iii. ~, l i~'!~:!~ L',,;.:.~rli~..~,.~.,,... ~,'..itt Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. 7/15/99 Schlumberger No. 12691 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: Alpine (Cased Hole) Color Well Job # Log Description Date BL Sepia Prints CD CD1-24 99270 SCMT 990612 1 CD1-01 99277 USlT 990628 1 !ii"~,l, ili ....... ~¥' 7"" i! '~' ~ ~ ...... ,""~. SIGNE D.('~.~ ~/~ ~ DATE: ,J~Jl .... Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Th~;~{~ Anadrill MWD/LWD Log Product Delivery Customer Arco Alaska, Inc. Dispatched To: AOGCC Well No CD1-01 Date Dispatche 10-Ju1-99 Installation/Rig Doyen 19 Dispatched By: Joey LeBlanc LOG Run No. Scale Original Film No Of Prints No of Floppies No of Tapes Perform Letter 2 Surveys (Paper) 2 ~/..~ ~ _ Received B" .'~~/~(,~'~_ Please sign and return to: Anadrill LWD Division 3940 Arctic BIvd Anchorage, Alaska 99503 Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 Core Laboratories - Alaska From: Core Laboratories 600 W. 58th Ave., Unit D Anchorage, Alaska 99518 To: Alaska Oil & Gas Conservation Commissio~ 3001 Porcupine Drive Anchorage, Alaska 99501 Date: ~-Jul-99 Well Name: ARCO ALASKA ALPINE CD1-01 Number of Samples: Contact: GERRY VAN KOOTEN Description of Material: Core Chip Samples Depths: 7098-7182.5 Sent By: Received By: Core Laboratories EC IVED STATE OF ALASKA - , ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend _ Operation Shutdown __ Re-enter suspended well _ Alter casing __ Repair well _ Plugging __ Time extension Stimulate _ Change approved program m Pull tubing__ Variance_ P~'rforate_ Other X Annular Iniection 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development X_ ARCO Alaska, Inc. Exploratory ~ 56' RKB feet 3. Address Stratigraphic m 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 service m Oolville River Field 4. Location of well at surface 8. Well number 222' FNL, 2572' FWL, Sec. 5, T11N, R5E, UM CD1-01 . At target 9. Permit number 1391' FSL, 2459' FEL, Sec. 32, T12N, R5E, UM 99-46 At effective depth 10. APl number 50-103-20299 - At total depth 11. Field/Pool 1569' FNL, 1501' FWL, Sec. 32, T12N, R5E, UM Colville River Field/Alpine Oil Pool 12. Present well condition summary Total Depth: measured 10289' feet Well drilled to TD and completed. true vertical 6954' feet Effective depth: measured 10289' feet Open hole completion. true vertical 6954' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 77' 16" 10 cu.yd Portland III 114' 114' Surface 2374' 9.625" 520 sx ASIIILW 2411' 2395' & 230 Class G Intermediate 7715' 7" 165 sx Class G 7752' 6991' Production Liner CD1-01 has been completed as an open hole injector. It is intended that the 9-5/8" x 7" casing annulus be us'ed for injection of associated drilling waste as per the previously applied for annular waste disposal permit application. 13. Attachments Description summary of proposal __ Detailed operation program . BOP sketch __ Contact Brian Robertson at 265-6034 with any questions. LOT tesst, surface cement details and casing detail sheets, CQL X 14. Estimated date for commencing operation 15. Status of well classification as: July 03, 1999 Oil X Gas __ Suspended __ 16. If proposal was verbally approved Name of approver Date approved Service __ 17. I hereby certify tha~Ihe foregoing is true and correct to the best of my knowledge. Signed -~,,4.,~Uy / ~¢¥'. Title Alpine Drilling Team Leader Date 1/"' / FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness IApproval No. ,'"~ Plug integrity_ BOP Test_ Location clearance I,,..,, ~ ~" 11 ~ Mechanical Integrity Test_ Subsequent form require 10-__ ~--'e.p~/--o-Cr'/~/~c~-~],Jo-¢,~-I, iApproved by the order of the Commission ORIGINAL_ , ,., ,,,_SIGNED.._, BY._ Commissioner Date ~:~ --[ ~;~ -- ,~ ~' Form 10-403 Rev 06/15/88 Robed N. Chds[en~u~ SUBMIT IN TRIPLI£ ~TE RECEIVED jUL 02 1 999 Naska 0il & Gas Cor~ A~-~ch0rage ARCO Alaska, Inc. Post Office Box 100360 Anchorage Alaska 99510-0360 Telephone 907 276 1215 June 30, 1999 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Sundry Approval to Enable Annular Disposal of Drilling Waste on well: CD1-01 Dear Sirs' ARCO Alaska, Inc. hereby requests that CD1=01 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is requested that this application be considered at your earliest available opportunity since there is currently only one other well permitted / capable of receiving fluid. i Please find attached form 10-403 and other pertinent information as follows: , 2. 3. 4. 5. 6. 7. Form 10-403 Surface Casing Description Surface Casing Cementing Report Casing and Formation Test Integrity Report (LOT at surface casing shoe) Casing and Formation Test Integrity Report (LOT at prognosed injection zone) CD1-01 Well Suspension Schematic. USIT (cement quality log). Two formation integrity tests have been conducted. The first was carried out after drilling out the surface casing shoe and was interpreted as a 15 ppg EMW leak off to the formation. The second test was carried out down the 7" x 9-5/8" annulus after cementing the 7" casing. This was interpreted as a 15.4 ppg EMW leak off (referenced to the surface casing shoe depth) and is consistent with our interpretation of the injection zone fracture strength. In addition, the attached USIT log demonstrates that good quality cement bond was achieved past the planned top of cement at 6800' MD. The Alpine sand is therefore isolated as per regulations. If you have any questions or require further information, please contact Brian Robertson at 265-6034 or Doug Chester at 263-4792. Sincerely, · Brian RobeSon Senior Drilling Engineer CC, CD1-01 Well File Sharon AIIsup-Drake Doug Chester Alpine Files ATO- 1054 ANO-382 ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company AR3B-6003-C Casing Detail g $/8" Osg Detail WELL: CD1-01 ARCO Alaska, Inc. DATE: 6/1/99 Subsidiary of Atlantic Richfield Company 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS .. Doyon 19 RT to landing ring = 36.57' 36.57 FMC Gen V mandrel Hgr 2.20 36.57 25 JTS 9 5/8", 36#, J-55 BTC Jt#35 - Jt #59 973.47 38.77 9 5/8" TAM port collar 2.94 1012.24 ,, 32 jts 9 5/8" 36# J-55 BTC csg Jt #3 & Jt 34 1307.56 1015.18 9 5/8" Davis Lynch Float Collar 1.58 2322.74 . 2 its 9 5/8" 36# J-55 BTC csg Jt #1 & Jt #2 85.68 2324.32 9 5/8" Davis Lynch Float Shoe 1.74 2410.00 2411.74 TD>>> 2416,00 Rathole>>> 4.26 35 Gemeco Bow Spring CENTRALIZERS Run centralizers in center of Jts. 1,2, over stop collars and over casing collars on Jts. 3-12 and over collars of every 2nd it to surface. ,. Run port collar between Jt #34 and #35 1 straight blade centralizer on Jt#34 and Jt#35 Used Best-o-Life 2000 thread compound -- Remarks: Doyon 19 Drilling Supervisor; MIKE WHITELEY ARCO Alaska, Inc. Cementing Details Well Name: CD1-01 Report Date: 06/01/99 Report Number: 3 Rig Name: Doyon 19 AFC No.: 998B09 Field: COALVlLLE RIVER Casing Size 9 $/8 H°le Diameter:112,25 Angle thru KRU:i Shoe Depth:2411 LC Depth:2322 I °/owashout:200 Centralizers State type used, intervals covered and spacing Comments: RAN 35 BOWSPRING CENTRAUZERS. IN CENTER OF JTS#1&#2. OVER STOP COLLARS ON JTS #3-~12 AND EVERY 2ND JT TO SURFACE. Mud Weight: PV(prior cond): PV(after cond): I YP(prior cond): YP(after cond): Comments: 9.6 24 22I 44 18 Gels before: Gels after: Total Volume Circulated: 44/52/74 19/36/51+ 700 Wash 0 Type: Volume: Weight: Commenls: ARCO Wash 50 8.4 50 BBLS WATER WITH 2# BIOZAN - 3SX NUT PLUG Spacer 0 Type: . - Volume: Weight: Comments: ARCO Spacer 150 10.5 Lead Cement 0 Type: Mix wtr tamp: No. of Sa(~ks: I Weight: Yield: Comments: ASlII 75 520I 10.7 4.44 Additives: D053 -30%, D046 - 0.6%, D079 - 1.5%, S001 - 1.5%, D124 - 50.0%, D044 - 9.0%. Comments:TailCement 0 G Tyl~e: { Mixwtrtemp: I Ne. of Sacks: 75 230 Weight: 1 $.8 Yield: 1.1 S Additives: DO46 - 0.2%, D065 - 0.3%, S001 - 1.0% Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 7.8 7.8 lS0 Reciprocation length: Reciprocation speed: Str. Wt. Down: 25 60FPM 130 Theoretical Displacement: Actual Displacement: Str. Wt. in mud: 179 179 70000 Calculated top of cement: CP: Bumped plug: Floats held: SURFACE Date:6-2-99 YES YES Time:0520 Remarks: , Cement Company: DS Approved By: MIKE WHITELEY IRig Contractor: DOYON CASING TEST and FORMATION INTEGRITY TEST Well Name: CD1-01 Reason(s) for test: Date: 6/3/99 Supervisor: MI~,~ WHITELEY [] Initial Casing Shoe Test [] Formation Adequancy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" 36# J-55 BTC CSG Casing Setting Depth: 2,411'TMD 2395 TVD Mud Weight: 9.4 ppg Hole Depth: 2,436' TMD 2,420' TVD Length of Open Hole: 25' 700 700 psi EMW = 0.052 x 2411 + Mud Weight '-0.052 x 2,420' + 9.4 ppg EMW = 15.0 ppg Pump output = .101 BPS Fluid Pumped = ..9 bbl BLED BACK =.Sbbl :TIMELINE 2800 ps, .......... l-T- ....................... l ...................................................................... i-,,Z O:NE MiNuTE TICKS 2 700 psi ....................................................................... 26o0 si 1-J~ , ,,~ .......................... J, J, J,I .... ' P ' ' ........... i'J ........ r ............ i .................... !'''] .... 2,500 p~ ....... t'-- :-- I j~'-' ~ ..... ~--:~r~ ~ ~¥. ~ ~ ..~: ~ .......................................................................... .J ........... 2,400 psi .... . ....................... J ............ [ ................. ' :..-. r ............... I 2,300 psi ................... J , ................ / ..... '"-- -~ ........ J 1,600 psi ....... 1,500 psi .............. --J -  1,400 psi ............ 1,3oo psi .............. :-'"' I- ....................................................................................................................................................................... 1,200 psi ........ ~ I-' ....................................................... 1,1OO psi .---- ~F ........................................... 7--- ........... 1,000 psi ............. ; ....................... : ........................ ; ........................................... ~ --~ ...... ; -- -- .... ........ .................................................... [_x ............ 87o~ r~ ......."- --1 't-J::::?t'zz'~'~Tt-T t ................ -~ ....................... -'~- LEAK-OFF TEST : - 6OO psi 500 psi- ir./~ ............................... __ ........... ~-": ............ : .............................. LOT SHUT IN TIME 4oo psi ...... -'1 ~- , ...................... 3oo psi --ii ............................................................................ ~=-- CASING TEST SHUT IN TIME ..... 200psi-~t ................................ ; TIME LINE --- loopsi ~.~'- ................................................................................................... ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~,~ .... 0 psi 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 42 44 46 48 5O 52 54 ~6 58 60 62 64 66 68 70 72 74 76 78 80 82 stk stk slk stk stk stk stk stk stk stk stk stk stk slk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk stk slk stk $1k stk stk stk stk STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE .............................. ' ............... .... .................. -~-~-~ ...... ~-~--~-~--- ___- ............... _3._.s. Lk.s_. L _~.8..°...p~L. ................... _4._?.Lk..~. ...... .4..o..o...R~.i .... ................... .s...s.t..~.s. ....... ~l.0._.p~i .... ................ 6 stks 620 psi 7stks ~ 720 psi ................... '~'~'~E~- ..... i~;f~'-i;~i--- I ............... ..i ............... i I ............................... ..i , ................................ .i ................. , , ............... j ............... j ................. ............... ! ............... i ................. SHUT IN TIME SHUT IN PRESSURE ...............................0.0 min I'"~;i6'~)'~i'" _.&.o...m_.i.n. .................. !._..8.1.o__Rs., .... 2.0 min i ?80 psi ' .......... -.- ................... i ............. ': .... 3.0 mm I ~ 7'50 ---~16'Bi'~"I ............... 1-"~;ia'-~';i .... 5.0 min ~ 740 psi '"616'~iii--! ............... i-"~§6"1;~i CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE 2stksj 130psi 4stksi 250 psi ................... .................. '~'~iiE;": ---f~6-~;~i'"' ................... _to___s_Lk..s._ ! __92_o._R.s_i___ · -~ ., 12 stks j 1,060 psi 14 stks ! 1,200 psi 16 stks J 1,370 psi .................. ¥~-ai~;-l-~';~-~-~-i;~;i-' ................ ................. '~'~'~iE~'"[--l';~-f6~i;i" ................. ._~_~.t~.s._l..2.,_2..~.o._p..s.L, ................ ..~.?..s.!.k..s.__i. ~,.s._°..°_P_s.L .............. .............. L ............................. _t SHUT IN TIME SHUT IN PRESSURE L..5.-.o_.m.L.n. .................... ~,__4.?.°._P..S.L L.!g:.o....m. Lg................. 2,450 psi 15.0 min 2,450 psi 25.0 min 2,450 psi. F§6'.'6'~B'* ................. ~;;i~'6"~;i- ! , ~ .............. ~ ............................... .............. i .............................. ! 8.0 min ~ 720 psi .... 1'3 .......................... min I"-:~66"1~'~1--' j, ............................................. .............. ~ ............... ~ ................. j- .............. -r ................................. ._.1..7__.m. Ln. .................. L.7..O..O.. _P?_]. _. '. L .............................................. NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING '-,~ST and FORMATION INTEGRITY TEST Well Name: CD1-01 Date: 6/18/99 Supervisor: Donald Lutrick Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequancy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8" 36# J-55 BTC CSG X 7" 26# L-80 BTCM CSG Casing Setting Depth: 2,411'TMD 2,395' TVD Hole Depth: 7,762' TMD 6,995' TVD Mud Weight: 9.8 ppg Length of Open Hole: 4,388' 702 700 psi EMW = + Mud Weight = + 9.8 ppg 0.052 x 2411 0.o52 x 6,995' EMW = 15.4 ppg Pump output = .020 BPS Fluid Pumped = 7.0 bbl ..... Used cement unit BLED BACK = 800 psi 700 psi 600 psi 500 psi -- 400 psi I~. 300 psi 200 psi 100 psi 0 psi O.Obbls 1.0bbls 2.0bbls 3.0bbls 4.0bbls 5.0bbls 6.0bbls 7.0bbls 8.0bbls 9.0bbls lO.Obbls ll.Obbls 12.0bb15 13.0bbls 14.0bbls 15.0bbls BBLS LEAK-OFF DATA MINUTES FOR LOT BBLS PRESSURE ................... .O....S..b..bJ..s._l .... ~.__p_.sj .... 1.Obbl$ ! 192psi .1.5bbls j 298 psi 2.5 bbls i 485 psi ................ 3.0 bbl$ ] 560 3.5 bbls J 656 psi ................. ,i'.-(i-i:;i;i;-l-"~-f,"~;i .... .................. .5.-_.S..b__b_Ls__l____S__~.?_.P_s.i .... 6.0bbls ! 591 psi ................. i~:g"~i;i~'-l---g~'f~"/,-~i'--, ! | CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ............... T .............,~ ................ 1 i.. .............. ~ .............. ..i. ................ ::::::::::::::::::::::::::::::::::::::::::::::::',. ' i i 4- ' ............... i' .............. I' , i_ .............. .J_ .............................. ............... ~.~ .............................. iZZiiZii!ZZZZiiiZZiZiiZi ............... .' .............. .L ................ ............... -j- .............. + SHUT IN TIME SHUT IN PRESSUR '--6:'b'-r~'FB"T .............. '" ................ i i 1 0 min I I .,. ' .... ,.'- ...........L .............. .L .............. t .............................. ~, : j , 2.0 min I J . 0.0 min 591 psi j .___4_..o...m..i.n.__L .............. ..! ................ 3.0 min 480 psi j ............... l .................... ....6.:.o._.m.j.n. ...................... .4..s._s._p..s.!___i 7.0 min 450 psi j -'§i~'Ffii;.;"l ............... 1-'-;i;1'6'~';i"-1 .j.o.:9_?. ................. ]....4..~..o.p..sj__l 6.0 minj "-'f'-.'6-~i~-- ,i' .............. T ................ '--~-.~';~"t .............. t ................ .............. t ................ NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KE' ... Colville River Field CD1-01 Injection Well- as built 16" Conductor @ 114' MD RKB - GL = 37' 9-5/8' TAM Port Collar @1000' Camco 4-1/2 .... DB" Nipple (3.812" ID) with Model "Al" Injection Valve (2.125" ID) at 1013' MD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2411' MD / 2395' TVD cemented to surface 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing run with Jet Lube Run'ri'Seal pipe dope CD1-01 (PH)- cement kick off plug at 5900' MD Packer Fluid: 9.2 ppg KCL brine with diesel to 1200' Tubing tail to include: 4-1/2" Tbg Joints (2) HES "XN" (3.725" ID) 4-1/2" Tbg Joint (1) and WLEG Note-Baker-lock all components TOC @ +/-6800' MD/ 6611' TVD (top quality cement f/ USIT log) Baker Model S-3 Packer (3.875" ID) at 7179' MD (set 58 deg in build section) TD at 10289' MD / 6954' TVD 6-1/8" Openhole completion interval 7" 26 ppf L-80 BTC Mod Production Casing @ 7752' MD / 6991' TVD (94 deg) Updated 6/28/99 FACSiMII.E TRA_NS~AL SI~-ET DATE: TO: Daily Drilling Report ARCO Alaska, Inc. ggllB0g 10~/02/8g 4 10&/~g/~Jg 07:00:00 Rig Rela;a · hr;; ., I~ , P~: ~ Cont~or: DOYON " Dat~ Cost $150~ ~ C~'st $ ~16~05 '"E~ Cost To Da~ $ ~0~0 Rig Name: Ooyo~ 19" ~'~'sg: g ~' · 2.411; Ne~C~g: 7"" $boe~'~t: ~A ~eraUon Al ~: DRILL~ AHaB AT u~om~ng ~e~Uons: DRILL 1 5~ TRIP "MUD DATA ~ILLING DAT~ [, "' ~ b~T,~ '" ,,,,EH&S ' ~,ILL~OP DATA .... MUD ~PE OEPTH ~IT NO. BIT NO. INClDE~ ~S~'BOP~WERT ~ST BOP~RILL LSND 2418 2RR NA N TST ....... ~ .... WEIGHT ROT ~ 5 Z~ ~1~ EMPLo~R ~ST H~S DRILL L~ST ~RE DRILL VISCO~I~ ~PU ~ :MAK~ MAKe' SPILL "~ ~ST CONPlNE~ "' ~ST SPILL DRILL 4S~q~ H~ N 5PACE 0~31~ ........ PV~P SO ~ ~P~ ~E ~PE .... FUEL & ~4 / GELS ~VG DRAG SE~L NO SERIAL NO V~LUME ~L U~"" 1319 ~/10/t2 032040~ APl WL M~ DRAG ~PTH OUT DEP~ O~ ~ SAF~ ~" ORIEL WA~ER U~ED- ?,s o~a~ HTHP WE ...... TRO BTM ~EP~ ~N DE~ IN "' ,POTA~ WA~R 0reV30 m~ 2416 ,~J[C~ON USED - BBL~ SOLIDS TRQ OFF' ' FOOTAGE "' F~AGE INJEC~ON WELL ~"~ER & 6.S%.,., o ,, ~D1-1~ ,.~ERSO~ DATA HOLE VOLUME PUMP PR~S ADT/AST ADT/~T SOURCE WELL T~MP ~F ~ST. Bb~l I ) I 0 / 0 / CDI~I MST '"~ PUMP NO W0B ~ " W08 2 ~TE (b~m) W}ND S~ED 0 4s.o 1 121 I ~- ~h LINGR SZ ePMT ~"~ ~ ~SSUR~ (ps~) WiNO DIaEC~ON ~,S ale11 LGS SP~ I T~A ..... :TFA IN~'~C~ON FLUIDS CHILL FACTO~ ~ ~S.OO s,o% II I W~fer ~n~e MUd~ 440 . ,,. .,. ,., PIT VOL GPM 2 JETS JETS Fresh W8ter ARCO PERSONNEL 40 OAILY MUD ~S I ., BIT COST ~BI~ COST Ol~er . CONTRACTOR o ~OTaL MUD S~P I DULL .... ~OULL TOT~ VOL ~bl) MtSO PGRSONNEL ~z~7 ~111 III III ~4~ COMPanY MUD ~ GRADE ~RA~ TOT FOR ~LL ~1) SER~E MI e,411 I I I I I II ~TS~ PER--NEE TOT~ 35 12:00 AM 03~30 AM ~.;O OIRC SURF Casing ~ ~RC AND ~N~ON MUD AND HOLE FOR CMT JOB. Ce~ntln~ ~LL fl~RNg, RECIPICA~D PIPE. ?HI~D MUD. PJSM, 0~80 AM 05:30 AM 3.~ CEME~ SURF C~ng en~ P~PED ~ BB~ BLOWN SPACER ~H N~ PLUG. Ce~nling T~D UNES, OOW~ C~D 9 ~' CSG PUMPING AT 10.7 PPG, 4? D~ CL "G" TAIL AT lS,a PPG, D~P~CED ~H ~.8 PPG ~D AT 8 BPM. ~ECIPICA~D / FULL RE~RNS - PLUG BUMPED. ~RC ~ BBLS OF PPG TO 10.e PPG C~ ~ SUR~AC~. ~P AT 0~0 HRS. O~ME~ ~TAflD~G AT Og:3O AM 06;30 AM 1.M CASG SURF C.~Ing end LAY DOWN C~ HEAD A~ LANOI~ ~- Ce~ln~ ~6:30 AM 08:~ AM f,s0 NU NO Pl ~het WASN O~ DI~R~R. N.D. DIVER~R ~Y~EM. 08:00 AM ~:00 AM 1.00 PRB~ PI ~r M~AL SEAL DAMAGED IN WELLHEAD · PREP ~LLHEAO FOR I~TAL~ON. ~:00 AM 10:00 AM 1,00 NU..ND Pl ~her INSTALL 11".~ ~C ~IHEAD, ~ST ~ 1,000 PSI, HELD. lO:0O AM 12:~ PM 2,00 ~ND p1 ~ner N.U. BOP'S. OBSERVERED HYD.OIL INSIDE Daily Drilling Report; CD1-01 06/02./99 12:00 PM 03:30 PM IORI~_9OP~_ BOPE 07:00 PM 08:30 PM 1.50 0B,'30 PM 00:30 PM 1.00 0g.'3O PM 10:00 PM 0,50 TRIP_IN 10:00 PM 10:30 PM O.§0 OTHER 10:30 ~M 11:00 PM 0,50 TRIP_IN 11 ;00 PM 12:00 AM 1.00 TEST 24.00 P1 Pl Meki~j Hole M&kln9 Hot= Making Ho;e M~kJn~ Hole Meking Hole TEST PISTON ~EALS I~1 ANI'~/I,~,R WITH 12~0 P,~! ~ 0P~ AND CLOgED PO~I~ON POR t0 M~. NO L~AK, RU TO ~gT. ~$? BOP'5 TO ~50 PSI LOW AND 35M Pgl WAIYED BY JO~N ~PA~ING ~ A~G~ ~ LEAKS. PUREED T~T PLUG AND $~ W~R ~NG. C~ DRILLING UNE AND SEmitE TOP DRW~ MA~ UP ~HA~. ~,s' P~ ~4" OD ~A~ ~ AKO-l~ MOTOR ~D/GR, O~I~OLS AND SURFACE ~T, RIH TO E0~', ~CK ~IL; ~IPPING DRILL ;OE~O~D BY WELL KIEL DRILL. O~LLER~ M~OD. ~IH - WASH TO ~C, AT 2322', CI;C FOR CSG ~ST, TEST~ g~' CSQ TO E~0 ~1 FOR 30 MIN. LO~T $0 PSI, Supervisor: MIKE WHI?ELEY Daily Drilling Report: C;D1-01 06/0~99 Page 2 ARCO Alaska, inc. Daily Drilling Report i Well; CDEV1 O~ (MD~D) ~E~g~ ;Pr~ De~ M~ ~62 Prorate: O C~lraclor: OO~ON O~ily Cast $ 21~89 O~ Co~t $ ~27~ ~st Co,~ ~ Dele $ 2250~ ,--- Operation At ~: MU aHA ,,,,. , ,-, upcoming Operations: PU DP- ~111FE - LOT MUD DATA '"~ILLING DATA ~'ff OAT~ .... EH&~ ..... ORIL[~OP"~ATA MUD ~PE ~'~PTH BIT NO. BIT NO, INCIOE~ ~ST B~mlVERT ~$T BOP~RILL L~NO 7 N TST ........ W~IGHT ROT ~ SIZE SIZ~ EMPLOYER ~ST H2$ DRI~ ~ST FIRE g,8~g ........ 8,5 .... 0~1~ ,,, 55~cVISC°Sl~ Pu ~ MAK~HTC MAKE :SPILLN SPACE'ST CONFINED ~sT'sPILL DRILL~ ~ ...... 50 ~ ~PS W~E ~P~ ~ · W~T~R 1~/2~ GELS '~G DRAG SERIAL N0 ~RI~ NO VOLUME '~ FUEL USED e / ~6 / t~ HStYU nP~ WL M~"DRAG DE~H O~ DEPTH OUT ~ST S~E~ MTG DRILL WATER USE~- l~mu~ m~n 74e~ I~EC~ON USED - BBL~ ... SOLIDS TRQ OFF FOOTAGe POOTAGE INJECTION ~LL ~ER & 13,~% 301 C~ 40 PERSONAL DATA HOLE ~ME PUMP PRES AOT/AS~ ' ADT/AST SOURCE WBLL ITE~F 35 48~bl I I ! 8.7 / 7.s / CDJ~t MBT PUMP NO WOe 2 '" WOB 2 RA~'~pm) ~ND SPEED 14 ph .... LINER 8Z RPM 1 RPM 1 ~E~URE (p~i) WIND DIREC~ON 340' e,o elell TO-mm [GS ....... SPM 1 ~F~ TFA '" INJECTION FLUIDS CHILL FACTOR =F ~.s% III Ws~er ge~ Muds 874 PIT V~ GP'~' ~ i J ET5 ~TS FreoM W~ter .... ARCO PERSONNE~ ~oe III ~sl~sl~;I I I IIIII G0 Diesel DAIL~'~UD ,SPS ~ '" B~TCOST BI~'~OST CONTOUR 2~ Ss~ III 1~3s 0 ..... PERSONNEL TOTAL M~ SPP 1 D~[L DU~ "' TOTAL VOL {bb~) MISC PER3ONNEL $22S336 II1 ;~l~lerl III ~OMPANY MUO WT .... GRAD~ GRA~E TOT FOR ~LL ~'~- SE~C~ Mt 9.81 e,81 I a I a ( o Ita I I I 71~0 PERi. EL TOT~ TIME ! ENO" ~OU~ I CPS COOE"'[ HOL~ ~ECT [PHASE ~S I .... OPERA~ONS FROM ~- 0~ 12:00 AM 01 ;gO AM t.O0 TRIP_OUT P1 Maklw~ H~le CO~' PO~. Mon~or well ~t eh~. o~ ~ AM 03:00 AM ~.~0 eHA P1 Ma~ng flole LO BHA, Reme~ ~eur~. O~eed t~l~- 03:~ AM 04:30 AM 1.S0 CASG Pl ~n~ and Pull ~ar ~shl~, MU F~o~ fl~ u~ 1~1, RU I~ ~g ~, Ce~ntiflg PJSM 04:30 AM OB:OD AM g. S0 CASG Pl Laming and RIH w/7" ca9 to 2~6', c~line 08:~0 AM 10:30 AM 2.00 ~A~G P1 ~e~g and RIH wi 7' ~g ~ Ce~n~ng ~ O:aO AM 11:00 AM o.so CIRC Pl MaRine Ho~ C~U ~ 1 :go AM 0t ~00 PM ~.oa CASG ~l Ca~iwn ead RIH w/1" ~g 10 c~ntlng 01 :~ PM o2:oa ~ 1,~ Cleo ps e~ming and C~U 0~:oo PM ~:~ PM 2,00 CAS~ Pl C~{ng ;nd RIH w/7" ~g tm ~. ~hed F 8~' lo 7010' ~nd 7210' Ce~ln~ to 72t9'). . C~nflng 2n~ ~oms ~. ~ln ~ck mud, Dmily Drilling Floport: CD1-01 06/17/gg Page 1 ~?:30 PM 09:00 PM !.aD CEMENT Ig:00 PM 0~:30 PM 0,,~0 C&SG 24,00 Pl Pl Cem~(ing Casing end Cerrentin9 Ce~lng n~d Cer~rfling c,~sing and Ceding TeJ~t lines to 3500 p~i. Pump 20 bble wash H20 an~ 285 b~e m~. D~p~ wi ce~nt un~. Did Ret RO ee~nt ~, LO ~. Ingtall packoff end tel! to 5009 la~l, OK. Set test plug, Chlng~ Tarot {e 3 1/2". S~per~sor, gQ~ALO Lb*TRICK Daily Dr;lllng Report: CD1-01 06/17/99 Page 2 ARCO Alaska, Inc. Cementing Details Weii N.~me: 001-O1 Rrvport Det.: I~/'l?/g~ Ri~ .N~x~,, ~:,__O.~yOn lg _ AFC NO.: 99B~0~J 7" g.~ g~ d~0 at ~ ~52 7~68 ....... Commenls: .............. Mud Weight: PV(prim cond): PV(afl.r rend}: YP~r mad): Ye(after tend): Comment~: 9.9 20 15 ., G~I~ ~oPe. ~l~ nfl~t~ T0t~l V~lume Circulated: Wn~h 0 ~: Volume: Oommgnl~: ARCO 2~ ~.~ ............... S~c~r ~ Ty~.; Volume: Wei~t: Comments: ARCO S~c~r 50 12,5 L.Bd C.m~nt 0 Typ~: M~ ~r romP: No. ~ ~e: W~i~t: Yi~l~: Commenls: ............. ..... Yall Ct~m 0 T~; I M~ ~r lamp: No. of Sacks: W.i~t: Yield: Commanlm G 70 165 1~.~ 1.15 ,~,,,. Ad~tive~: ...... ,,,, ,. ........... ... Dllplace~nl O Rate.lore t~tl 3{ ehoe}[ R=t;(~;il a~und shoe): Sir. Cammnnl~: 6.7 6.7 ~4Ok ,...,. .... R~pro~ti~ I~gth: R~ro~ll 15 10 fpm 175R ~or~i~t Displa~menl: Actual Obpl~menl: ~lr. Wt. ~ mud: . ,,.,, , Time:20:42 ., .......... _ R~rke:He~ ~lt ~rn~ lhrougho~ J~b. Ne fl~ back afle~ shut ~own i i1,11, I i1~. Illl.. STATE OF ALASKA ~- ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend _ Alter casing __ Repair well _ Change approved program X Operation Shutdown i Re-enter suspended well _ Plugging __ Time extension_ Stimulate_ Pull tubing__ Variance_ Perforate_ Other _ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X_ Exploratory I Stratigraphic __ Service 6. Datum elevation (DF or KB) 57' RKB feet 7. Unit or Property name Colville River Field 4. Location of well at surface 222' FNL, 2572' FWL, Sec. 5, T11N, R5E, UM At target 1400' FSL, 2597' FEL, Sec. 32, T12N, R5E, UM At effective depth At total depth 591' FNL, 943' FWL, Sec. 32, T12N, R5E, UM (requested change) 8. Well number CD1-01 9. Permit number 99-46 10. APl number 50-103-20299 11. Field/Pool Colville River Field/Alpine Oil Pool 12. Present well condition summary To be drilled. CD1-01 is due to spud on 28th May 1999. Permission to modify the drilling plan, by extending the proposed horizontal section to the above TD coordinates, is requested. In addition, it is requested that we are permitted to modify current leak off / casing shoe integrity testing procedures to include a leak off test into the proposed injection annulus after running 7" casing and prior to freeze protecting. In combination with the integrity test done after drilling 20 ft out of the surface casing, it will possible to obtain good data regarding the difference between injection zone fracture pressure and the tested casing shoe integrity pressure. 13. Attachments Description summary of proposal X Detailed operation program X Contact Doug Chester at 263-4792 with any questions. Well Schematics X BOP sketch __ 14. Estimated date for commencing operation May 28, 1999 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas__ Suspended__ Service Signed ~ Title Alpine Drilling Team Leader FOR COMMISSION USE ONLY Date Conditions of app~val: Notify Commission so representative may witness Plug integrity _ BOP Test ~ Location clearance Mechanical Integrity Test_ Subsequent form require 10- ORIGINAL SIGNED BY Approved by the order of the Commission P~obert N. Cl~ristenson Commissioner IIAppr°val No~p~.O 7 f Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE ORIGINAL Anchora%: ARCO Alaska, Inc. · Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 27,1999 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Sundry Approval to Enable a Change of Planned Bottom Hole Co- ordinates on Well: CD1-01 Dear Sirs: ARCO Alaska, Inc. hereby requests permission to modify the drilling plan on well CD1-01 to enable an extension of the planned horizontal length. This will change the planned TD co- ordinates as approved within Permit to Drill 99-46. It is anticipated that the well will spud on the 28th May 1999. This addition of approximately 1500 ft of horizontal section does not impact proximity to other nearby wells. This change will allow better delineation of the Northern part of the Alpine sand. We would also like to request permission to modify our current leak off test practices on the Alpine development wells. We have been consistently seeing a 16 ppg EMW formation / cement integrity test at the 9-5/8" surface casing shoe and have then been drilling ahead 60 to 80 ft to obtain a leak off test into the prognosed annulus injection zone. We propose to change to the following: , Drill 20 ft out of the 9-5/8" casing and carry out an FIT to 16 ppg (or leak off test to some lesser value). Assuming an acceptable test is obtained, continue to drill and case off the intermediate section. Carry out a second leak off test down the 9-5/8" x 7" casing annulus prior to freeze protecting. We believe that this would verify both casing shoe integrity and the fracture strength of the annulus injection zone in the most expeditious manner. It would also better simulate annular injection conditions. Please find attached form 10-403 and other pertinent information to support the above two proposals. The information is as follows: . 2. 3. 4. 5. Form 10-403 Revised program outline, highlighting the above changes. Revised drawing of the CD1-01 (PH) pilot hole prior to sidetracking. Revised completion diagram drawing. Revised directional drilling information as required by 20 ACC 25.050. If you have any questions or require further information, please contact Doug Chester at 263- 4792. Sincerely, .¢. ~,i~/ Brian Robertson Senior Drilling Engineer CC, CD1-19 Well File Sharon AIIsup-Drake Doug Chester Alpine Files ATO- 1 O54 ANO-382 ORIGINAL 2. Program Outline (Changing'from original application in bold). . 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. Note: Install diverter and function test. Move on Doyon 19. Drill 12 1/4 inch hole to the surface casing point as per the directional plan. Run and cement 9 5/8 surface casing. N/D diverter. Install casing head. Install and test BOPE to 3500 psi. Pressure test casing to 2500 psi. Drill out 20' of new hole. Perform leak off test. Stop at a 16 ppg EMW FIT if no leak off. Drill 8 1/2 hole to +/- 10' from the top of the Alpine sand. Cut a minimum of 90ft core through the Alpine. Drill 8 1/2" rathole to a point 150' below the base of the Alpine Sand. R/U and run open hole logs from TD to above the Albian sands. Set 400 ft cement plug #1 from TD to +/- 7007' (+/- 164' above the Alpine Sand). Set 400 ft cement plug #2 from +/- 6200' to 5800'. Dress off plug #2. Kick off at +/- 5965' and drill sidetrack to intermediate casing point in the Alpine Reservoir. Run and cement 7 inch casing as per program. Top of cement 500 feet above Alpine reservoir as per Rule 20 AC 25.030. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. BOPE test to 3500 psi. Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Drill 6 1/8" horizontal section to well TD (approximately 3500' of horizontal length). Contingency- set ECP scab liner or slotted liner if required (due to unconsolidated formation or wellbore having moved out of the Alpine reservoir sand). Displace well to brine and pull out of hole. Run 4 Y2, 12.6 #, L-80 tubing with production packer. Land hanger. ' ..... "': .... "-~' Circulate in inhibited brine and diesel freeze protection. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. Install BPV. Nipple down BOP. Install tubing head adapter assembly. Remove BPV. Install test plug. Pressure test adapter assembly to 5000 psi. Remove test plug. Set BPV and secure well. Move rig off. This well (and all other injectors) will be logged through tubing with a CB~G~CCL to determine cement isolation above the top of the Alpine. This will be done after the rig moves off location. 3.0 Colville River Field CD1-01 (PH) Pilot Hole - Prior to Sidetracking RKB-GL= 37' 9.8 ppg drilling mud in hole I Wellhead 1 ," Conductor to 114' ili 9-5/8 36 ppfJ-55BTC Surface Casing Cement Plug Updated 5/26/99 @ 2418' MD / 2400' TVD cemented to surface Top of cement plug dressed off to 5965' MD / 5880' TVD (+/- 26 deg inc.) Base of Plug #2 at +/- 6200' Top of Cement Plug #1 at +/- 7007' Top Alpine Reservoir at 7171' MD / 6960' TVD (+/- 26 deg inc.) Pilot Hole TD at 7407' MD / 7171' TVD (+/- 26 deg inc.) 4.0 CD1 -01 . . f Colville River Field Injection Well Completion Plan 16" Conductor @ 114' MD RKB-GL=37' 9-5/8' TAM Port Collar @1000' Camco 4-1/2 .... DB" Nipple (3.812" ID) with Model "Al" Injection Valve (2.125" ID) at 1000' MD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2418' MD / 2400' TVD cemented to surface 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing run with Jet Lube Run'n'Seal pipe dope CD1-01 (PH)- cement kick off plug at +/- 5965' MD Packer Fluid: 9.2 ppg KCL brine with diesel to 1200' Tubing tail to include: 4-1/2" Tbg Joints (2) HES "XN" (3.725" ID) 4-1/2" Tbg Joint (1) and WLEG Note-Baker-lock all components TOC @ +/-6893' MD/ 6668' TVD (500' MD above Alpine) Baker Model S-3 Packer (3.875" ID) at +/- 7200' MD (set 60-65 deg in build section) TDat 11352' MD/ 6936' TVD .... ~'~;;:iiiii!;i;ili;;;,~,,,, .......-~ ............................................................................................................................................................................................... 6-1/8II Openhole completion interval 7" 26 ppf L-80 BTC Mod Production Casing @ 7822' MD / 6981' TVD (91.6 deg) Updated 5/26/99 56OO 58OO 6000 6200 6400 6600 6800 7000 7200 7400 ARCO Alaska, Inc. Structure : CD#1 Well: 1 Field : Alpine Field Location : North Slope, Alaska 6,75 S~detreck Tie-In Pt 27.69 28.90 DLS: 3.00 deg per 100 ft 30.35 31.99 ~ 33.80 EOC "<b<3 3.7 AZIMUTH ***PI~NF OF ~ROPOSA[_*** TARGET ANGLE 91.55 DEG *** 1ST SECTION*** Created by jones For: B Robert. son Dote plotted : 25-Moy-1999 Plot Reference rs I Versron ~4. Co0rdlnotes ere In feet reference slot ~1. True Vedicol Depth ...... f~ =~_~i~R~ (Do>on 1~19), INTEQ TARGET ANGLE 89.53 DEG ***2ND SECTION*** i i ~ i i i i i i i i i i i ~ i i i i i i i i i i ii i ii i i i i i i i ~ i I i i i i i i i i i i i 400 600 800 1000 1200 1400 1600 1800 2000 2200 2400 2800 2800 5000 3200 5400 3600 5800 4000 4200 4400 4800 4800 5000 5200 54(~ Vertical Section (feet) -> Azimuth 5.70 with reference 0.00 N, 0.00 E from slot #1 IN'r~Q 24UU 5400 5100 4800 4500 4200 3900 5600 3300 3000 2700 2400 2100 1800 1500 ARc'O Alaska, i, nc:-" Sfrucfure : CD#1 Well : Field : Alpine Field Locafion : Norfh Slope, Alaska 1200 <- Wesf (feel) 30 1800 1500 1200 900 600 300 0 300 600 900 1200 1500 I I I I I I I I I I I I I I I I I I I I I I I 5400 TD LOCATION: I 591' FNL, 943' F-WL 5100 TD SEC. 32, T12N, RSE 4800 3.7 AZIMUTH 1793' (TO TARGET //Z) ***PLANE OF PROPOSAL*** 4200 3900 End Angle Drop IntrmPt - Bgn Drp 3600 3300 TARGET LOCATION: 1574' FSL, 2591' FWL TGT - CsgPt - EOC Begin Angle Drop 1§00 SEC. 32, T12N, RSE End Angle Buil( DpstPt / EOT Alpine 1500 TaT - DEEPEST PT LOCATION: }f~l~jnveeoUch A 1400' FSL, 2597' FEL ~ ~ LCU 1200 SEC. 32, T12N, RSE $K-1/ //BH~gTin Bid & Tm to Tgt 900 /EOC go0 600 Sidetrack 'Re-In Pt 600 , 300 300 9 5/8 Casing Pt~ 0 0 /, ,, ~,:' , .,, ~. 300 ,.;;i~(;ho i':!'[ 300 600 600 [ i [ i i i i i i i i i i i i i i [ i i i i i i i 2400 21 O0 1800 1500 1200 900 600 300 0 300 600 900 1200 1500 <- Wesf (feet) 3000 2400 2100 Cr. ot.~ by lo".. For: B Robert. son{ -' Dora plotted: 25-1,loy-1999 Plot Referen~ la 1 Vision ~4. ~ordlnat~ are In lilt r~erence slot ~1. True Ver[icol Dlpths a~R~ (~. ARCO Alaska, Inc. Structure: CD#1 Well : 1 Field: Alpine Field Location : Nor"ih Slope, Alaska PROFILE COMMENT DATA Point MD Inc Sidetrack Tie-In Pt 5965.00 26.46 EOC 6529.02 34.55 HRZ 6767.96 54.55 Begin Bid & Trn to To ?E~,/V 6805.05 54.55 K-1 7031.38 46.35 LCU 7183.99 56.71 Miluveach A 7287.50 64.25 Alpine D 7342.22 68.34 Alpine 7592.51 72.14 Base Alpine 7530.35 82.71 TGT - DpstPt / EOT 7624.66 90.00 End Angle Build 7661.36 95.30 Be9in Angle Drop 7802.51 95.50 TGT - CsgPt - EOC 7821.75 91.56 IntrmPt - Bgn Drp 9850.45 91.55 End Angle Drop 9985.57 89.55 TD 11551.55 89.53 Dir TVD North East 2.13 5879.88 578.62 13.21 52.19 6368.73 840.76 103.31 32.19 6566.00 954.86 175.14 52.19 6596.62 972.57 186.29 6.39 6770.00 1109.43 229.89 354.83 6865.00 1228.38 230.29 348.55 6916.00 1517.55 217.09 345.53 6938.00 1366.1 6 205.83 342.92 6955.00 1411.68 192.95 356.25 6985.00 1557.44 145.97 331.89 6991.00 1 622.02 104.83 331.89 6989.94 1 654.37 87.55 331.89 6981.82 1778.49 21.25 551.94 6981.00 1795.61 '12.12 551.94 6926.00 5585.14 -941.91 332.00 6924.73 5704.42 - 1005.41 332.00 6936.00 4910.47 - 1 646.67 V. Sect Deg/1 O0 578.26 0.00 845.67 5.00 964.17 0.00 982.56 0.00 1121.94 9.00 1240.68 9.00 1328.61 9.00 1376.59 9.O0 1421.19 9.,.u 1545.65 9.00 1625.40 9.00 1656.58 9.00 1776.16 0.00 1792.65 9.00 3516.93 0.00 5631.87 1.5O 4794.05 0.00 IC~d by jone~ For: B Rober~son[ Dote plot[ed: 25-May-1999 C~'nat~ o~ in feat Tree Ve~icol Depths o~RKB 5250 5000 4750 4500 4250 4000 5750 3500 5250 A I ~ooo 2750 2500 2250 2000 1750 1500 1250 100o 750 500 250 At JO Alaska, Structure : CD#1 Field : Alpine Field Well: 1 Location : North Slope, Alaska <- West (feet) 1750 1500 1250 1000 750 500 250 0 250 500 750 1000 1250 1500 1750 I I I I I I I I I I I I I I I I I I I I I I I I I I I I E~ T.D. & Target - 6936.00 Tvd, 4910.47 N, 1646.67 W \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ ~. Target - 6926.00 Tvd, 3585.15 N, 941.91 W \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ Target - 6981.00 Tvd, 1795.62 N, 12.11 E ~ \ Target - 6991.00 Tvd, 1622.03 N, 104.85 E \R, 6900 71 6900 6700? 65oo~ 6~oo~ 2100 5900 '6500 6100 5100 1900 4900 [ ~500 3900 6900 O0 700 i i i i i i 750 , 1500 1250 1000 750 500 250 0 250 500 750 1000 1250 1500 1750 <- West (feet) {ALU:,: 5250 5000 4750 4500 4250 4000 5750 5500 5250 ~ooo I Z 0 2750 ~ 2500 --~ --I- 1750 1500 1250 1000 750 500 250 2000 2250 ARCO Alaska, Inc. C~1 1 slot #1 Alpine Field North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : I Version Cf4 Our ref : prop3147 License : Date printed : 25-May-99 Date created : 21-Sep-98 Last revised : 25-May-99 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w150 56 46.041 Slot location is n70 20 34.922,w150 55 30.868 Slot Grid coordinates are N 5975904.937, E 385999.975 Slot local coordinates are 221.01 S 2573.16 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wel 1 path PMSS <0-7502'>,,Bergs1 13 Version#4, 40 VersionS5, PMSS <0-???'>, PMSS <0-8168'>, PMSS <0-10796'> PMSS <0-10548'> PMSS <0-10255'>, PMSS <0-9714'>, Bergschrund #1 13, CD#i 40, CD#1 40, CD,fl 35.CD~1 ,24, CD~i ,19, CD#1 WD2 ,CD#1 22,CD#1 Closest approach with 3-D Minimum Distance method Last revised Distance 18-Jun-98 1669.1 9-May-99 120.1 17-May-99 390.0 24-May-99 390.0 14-May-99 339.8 5-May-99 230.0 22-Apr-99 158.9 13-Apr-99 774.4 1-Apr-99 138.1 M.D. 8800 0 250 0 250 0 100 0 100 0 100 0 1671 4 2800 0 4300 0 Diverging from M.D. 8800.0 250.0 250.0 100.0 7630.8 100.0 8800.O 2800.0 8700.0 TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION May 21, 1999 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Doug Chester Drilling Team Leader ARCO Alaska. Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Colville River Unit CD 14) 1 ARCO Alaska, Inc. Permit No: 99-46 Sur Loc: 222'FNL, 2572'FWL. SEC. 05, T1 iN, R05E, UM Btmhole Loc. 1916'FNL. 1643'FWL, SEC. 32, T12N, R05E, UM Dear Mr. Chester: Enclosed is the approved apphcation for permit to drill the above referenced well. Annular disposal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the reqtfirements of 20 AAC 25.080 are met. Annular disposal of drilling waste ~411 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. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site CD 1 must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one 3:ear. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) 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  ope pager at 659-3607. ~°ym~issj~e~ F T ~'~~C ISSION dlf/Enclosures cc; Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Consen'ation w-lo encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill } lb Type of Well Exploratory Stratigraphic Test Development Oil X Re-Entry DeepenI Service Development Gas Single Zone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. DF 56' feet Colville River Field 3. Address 6. Property Designation Alpine Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25558 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 222' FNL, 2572' FWL, Sec.5, T11N, R5E, UM Colville River Unit Statewide At base of productive interval (=@ TARGET ) 8. Well number Number 1400' FSL, 2597' FEL, Sec. 32, T12N, R5E, UM CD1-01 #U-630610 At total depth 9. Approximate spud date Amount 1916' FNL, 1643' FWL, Sec. 32, T12N, R5E, UM 5/24/99 $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 Alpine CD1-22 9,810' MD 222' at surface feet 138' @ 4300' feet 2560 6,896' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 4652' feet Maximum hole angle 94° Maximum surface 2447 psig At total depth (TVD) 3215 at psig 70O0' TVD.SS 18. Casing program Settin~l Depth size Specifications Top Bottom Quantib/of cement Hole Casin~l Wei~lht Grade Couplin~ Length MD TVD MD TVD (include stage data) 42" 16" 62.5# H-40 Weld 84' 37' 37' 121' 121' Pre-installed 12.25" 9.625" 36# J-55 BTC 2381' 37' 37' 2418' 2400' 477 Sx Arcticset III L & 230 Sx Class G 8.5" 7" 26# L-80 BTC-M 7744' 37' 37' 7781' 6946' 160 sx Class G N/A 4.5" 12.6# L-80 IBT-M 7163' 37' 37' 7200' 6860' Tubing 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size C§~~ ~~'~A~f~, ~? ~ .~%~ Measured depth True Vertical depth Structural i~i.~ ~ ~. ~ ~,¢' ~? ~ Conductor 7%, &~ %¢ ~., ~ ..; ~-~. SurfaceORIGINAL Intermediate Liner Perforation depth: truemeasuredvertical ¢ ~a,~:,~ 0ii & Gas .Cons, Gor~i~iS~k 20. Attachments Filing fee X Property plat BOP Sketch DiverterSketch Drilling program X Drilling fluid program X Time vs depth plot Refraction analysis Seabed report 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~ / (4~¢. p, (~[4~ ~¢,4~ ~'l~'~J ' Title Drilling Team Leader Date Commission Use Only I ?,? I i seecover letter for Permi r ~,~ APl50. ~/~:~number~% ~ ~ ~ ~,. Approval date ~'~ c~ [ - c~ o~ Other requirements_ Condit~orCs of approval Samples required Yes ~ Mud Icg required Yes Hydrogen sulfide measures Yes ~ rectional survey required (Yes '~ No Required working pressure for BOPE 2M 3M 5M 10M ' - 15M Other: ,o, .rof 2l! Approved by David W. Johnston Commissioner the commission Date ...... Form 10-401 Rev. 7-24-89 ~ cate Alpine: CD1-01 PH (Pilot Hole) &~D1-01 , 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. Procedure Move in drilling rig. Install diverter and function test. (16" conductor pre-installed) Drill 12 1/4 inch hole to the surface casing point as per the directional plan. Run and cement 9 5/8 surface casing. Install and test BOPE to 3500 psi. Pressure test casing to 2500 psi. Drill out 20' of new hole. Perform leak off test. Drill 8 Y2" hole to +/- 10' from the top of the Alpine Sand. Cut a minimum of 90ft core through the Alpine. Drill 8 1/2" rathole to a point 150' below the base of the Alpine Sand. Rig up and run open hole logs from TD to above the HRZ Shale. Set 400 ft cement plug #1 from TD to +/- 6965' (+/- 150' above the Alpine Sand). Set 400 ft cement plug #2 from +/- 6200' to 5800'. Dress off plug #2. Kick off at +/- 5910' and drill sidetrack to intermediate casing point in the Alpine Reservoir. Run and cement 7 inch casing as per program. Top of cement 500 feet above Alpine reservoir as per Rule 20 AC 25.030. Freeze protect casing annulus and casing. BOPE test to 3500 psi. Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Drill 6 1/8" horizontal section to well TD. Contingency - set ECP scab liner or slotted liner if required (due to unconsolidated formation or wellbore having moved out of the Alpine reservoir sand). Displace well to brine and pull out of hole. Run 4 Y2, 12.6 #, L-80 tubing with production packer. Land hanger. Circulate in inhibited brine and diesel freeze protection. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. Install BPV. Nipple down BOP. Install tubing head adapter assembly. Remove BPV. Install test plug. Pressure test adapter assembly to 5000 psi. Remove test plug. Set BPV and secure well. Move rig off. Well Proximity Risks: .... Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD1-22 will be the closest well to CD1-01 (138.1' at 4300' MD). Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 105.3' at 4300' MD. Drillinq Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting within the Alpine reservoir section is considered to be the most likely cause of lost circulation. There is a small fault with approximately 10' of throw prognosed at 250' north of the bottom hole location. The closest offset well, CD1-22 also encountered considerable losses within the Alpine reservoir. Addition of LCM will be required to cure losses. Good drilling practices will be followed to ensure that mechanically induced losses are kept to a minimum. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. There is potential for differential sticking in the reservoir. The BHA design and 9.2 ppg mud weight have been developed to minimize this potential. However; vigilance through careful adherence to the directional plan will be required to ensure that wellbore geometry does not aggravate the potential for differential sticking. Annular Pumpinq OI3erations: Incidental fluids developed from drilling operations on well CD1-01(PH) & 01 will be injected into the annulus of a permitted well. The CD1-01 surface/intermediate casing annulus will be filled with diesel after setting intermediate casing. The only significant hydrocarbon zone is the Alpine reservoir and there will be 500' of cement fill above the top of the Alpine as per regulations. We request that CD1-01 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. As stated above, 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 at the base of the Schrader Bluff Formation (C-30). These 450-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. 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 AC)GCC. 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) * (2400') + 1,500 psi = 2,998 psi Pore Pressure - 1,086 psi Therefore Differential = 2998 - 1086 = 1912 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate 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 9-5/8" 36 J-55 3 BTC 2,020 psi 1,717 psi 3,520 psi 2,992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi CD1-01 (PH) & CD1-01 DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point- 8 W' Section - 6 1/8" point- 12 ¼" (including coring of pilot hole) Density 8.8 - 9.6 ppg 9.4 - 10.0 ppg 9.2 ppg PV 10 - 25 12 -18 YP 20 - 60 15 - 25 35 - 45 Funnel Viscosity 100 - 200 Initial Gels 4 - 8 18 - 22 10 minute gels <18 23 - 27 APl Filtrate NC - 10 cc / 30 min 4 - 12 cc/30 min (drilling) < 5 cc/30 min (coring) HPHT Fluid Loss at 160 8.5 - 9.0 9.0- 10.0 <10 cc/30 min PH 9.0 - 9.5 KCL 3-6 % 6 % Surface Hole: A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Keep flowline viscosity at _+ 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: KCI/polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the Alpine is penetrated. Maintain mud weight at or below 10 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of Iow drill solids (by diluting as required) will all be important in maintaining wellbore stability. Treat mud with fluid loss additives prior to coring. Production Hole Section: The horizontal production interval will be drilled with a M-I FIo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with _+ 30PPB calcium carbonate bridging material to minimize formation damage. FIo-Vis Polymer and FIo-Trol starch will be used for viscosity and fluid loss control respectively. Colville River Field CD1-01 (PH) Pilot Hole- Prior to Sidetracking 9.8 ppg drilling mud in hole I Cement Plug Wellhead 16 Conductor to 121' ii~!i~ 5" ~1 9- /8 36ppfJ-55BTC ~ Surface Casing @ 2418' MD / 2400' TVD cemented to surface Top of cement plug dressed off to 5910' MD / 5824' TVD (+/- 26 deg inc.) Base of Plug #2 at +/- 6200' Top of Cement Plug #1 at +/- 6965' Top Alpine Reservoir at 7124' MD / 6917' TVD (+/- 26 deg inc.) Pilot Hole TD at 7365' MD / 7134' TVD (+/- 26 deg inc.) Updated 5/17/99 CD1-01 Colville River Field Injection Well Completion Plan 16" Conductor @ 121' MD 9-5/8' TAM Port Collar @1000' Camco 4-1/2 .... DB" Nipple (3.812" ID) with Model "Al" Injection Valve (2.125" ID) at 1000' MD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2418' MD / 2400' TVD cemented to surface 4-1/2" 12.6 ppf L-80 IBT Mod. R2 tubing run with Jet Lube Run'n'Seal pipe dope CD1-01 (PH)- cement kick off plug at +/- 5910' MD Packer Fluid: 9.2 ppg KCL brine with diesel to 1200' Tubing tail to include: 4-1/2" Tbg Joints (2) HES "XN" (3.725" ID) 4-1/2" Tbg Joint (1) and WLEG Note-Baker-lock all components TOC @ +/-6840' MD / 6621' TVD "~'~ (500' MD above Alpine) Baker Model S-3 Packer (3.875' ID) at +/- 7200' MD (set 60-65 deg in build section) TD at 9810' MD / 6.896~...TVD ........................... 6-1/8" Openhole completion interval 7" 26 ppf L-80 BTC Mod Production Casing @ 7781' MD / 6946' TVB (90 deg) Updated 5i17/99 Colville River Field CD1-01 Completion with Isolation Contingency Options 16" Conductor @ 121' MD 9-5/8' TAM Port Collar @1000' Camco 4-1/2 .... DB" Nipple (3.812" ID) with Model "Al" Injection Valve (2.125" ID) at 1000' MD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2418' MD / 2400' TVD cemented to surface Packer Fluid: 9.2 ppg KCL brine with diesel to 1200' CD1-01 (PH)- cement kick off plug at +/- 5910' MD TOC @ +/-6840' ME) 6621' TVD (500' MD above Alpin Tubing tail to include: 4-1/2" Tbg Joints (2) HES 'XN' (3.725" ID) 4-1/2" Tbg Joint (1) and WLEG Note-Baker-lock all components 4-1/2" 12.6 ppf L-80 IBT Mod. R2 8rd tubing run with Jet Lube Run'n'Seal pipe dope Hydraulic Set Liner Hanger Packer Assembly Baker SLZXP Packer (4.75" ID) ,b, lank joi,,nts (2) -HE$ XN (3.725 ID) LN (D- blank 4-1/2" joints (TBD) (~)- Baker Payzone ECP (~) - 4-1/2" joint (1) blank (~)- wireline entry guide with ECP cement inflated Baker Model S-3 Packer (3.875' ID) at +/- 7200' MD (set 60-65 deg in build section) Open Hole Scab Liner ([~)- Baker Payzone ECP (~- 4-1/2" joints (TBD) blank tbg with centralizers as required (~)- Baker Model XL-10 ECP with ECP's cement inflated Open Hole Bridge Plug (~) - Baker Payzone ECP (~- 4-1/2" joints (TBD) blank tbg and centralizers as required (~ - 4-1/2" guide shoe with ECP's cement inflated .......... ...u_. ........... ...................................... ............ .V. .... : 7" 26 ppf L-80 BTC Mod Production Casing @ 7781' MD / 6946' TVD (90 deg) TD at 9810' MD / 6896' TVD Updated 5/17/99 CD1-01 .... ~ PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c ) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of the Alpine CD1-01 well' Casing Size Csg Setting Fracture Pore pressure ASP Drilling (in) Depth Gradient (lbs./ (psi) (psi) MD/TVD(ft) gal) 16 121 / 121 10.9 52 56 9 5/8 2418 / 2400 14.2 1086 1532 7" 7781 / 6946 16.0 3142 2447 N/A 9810 / 6896 16.0 3120 N/A · NOTE: Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to 3500 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]D Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb./gal 0.052 = Conversion from lb./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP= FPP- (0.1x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1 } D = [(10.9 x 0.052) - 0.1] x 121 = 56 psi OR ASP = FPP - (0.1 x D) = 1086 - (0.1 x 2400') = 846 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1} D = [(14.2 x 0.052) - 0.1] x 2400 = 1532 psi OR ASP = FPP - (0.1 x D) = 3142 - (0.1 x 6946') = 2447 psi 3. Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3142 - (0.1 x 6946') = 2447 psi Alpine CD1-01 ANTICIPATED PORE PRESSURE, MUD WEIGHT, AND FRACTURE GRADIENT 5OO -500 -1500 -2500 ~ -3500 PR -4500 -5500 -6500 ~7500 8 9 10 11 12 13 14 15 16 17 EQUIVALENT MUD WEIGHT Alpin'eTCD1-01 Well Cementinq Require~.=nts 9 5/8" Surface Casing run to 2418' MD/2400' TVD, TAM port Collar @ +/- 1000' MD Cement from 2418' MD to 1918' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 1918' to surface with Arctic Set Lite 3. Assume 500% excess annular volume in permafrost and 50% excess below the permafrost. Lead slurry: (1918'-862') X 0.3132 ft3/ft X 1.5 (50% excess) = 496.1 ft3 below permafrost 862' X 0.3132 ft3/ft X 6 (500% excess) = 1619.9 ft3 above permafrost Total volume = 496.1 + 1619.9 = 2116.0 ft3 => 477 Sx @ 4.44 ft3/sk System: Tail slurry: 477 sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 ft3/sk, Class G + 30% D053 thixotropic additive, 0.6% D046 antifoamer, 1.5% D079 extender, 1.5% S001 accelerator, 50% D124 extender and 9% BWOW~ D044 freeze suppressant 500' X 0.3132 ft3/ft X 1.5 (50% excess) = 234.9 ft3 annular volume 80' X 0.4341 ft3/ft = 34.7 ft3 shoe joint volume Total volume = 234.9 + 34.7 = 269.6 ft3 => 230 Sx @ 1.17 ft3/sk System: 230 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% S001 accelerator @ 15.8 PPG yielding 1.17 ft3/sk 7" Intermediate Casing run to 7781' MD ! 6946' TVD Cement from 7781' MD to +/- 6840' MD (minimum 500' MD above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: (7781'- 6840')o X 0.1268 ft3/ft X 1.4 (40% excess) = 167.0 ft3 annular volume 80' X 0.2148 ft°/ft = 17.2 ft3 shoe joint volume Total volume = 167.0 + 17.2 = 184.2 ft3 => 160 Sx @ 1.15 ft3/sk System: 160 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder o 3 and 0.18 Yo D167 fluid loss additive @ 15.8 PPG yielding 1.15 ft/sk CD1-01 (PH) Cement Plug #1: 7365' MD to 6965' MD = 400'. Cement from 7365' MD (CD1-01 (PH) total depth) to 6965' MD (159' MD above the top of the Alpine formation) with Class G + additives @ 15.8 ppg. Assume 15% excess on open hole volume. Slurry: 400' X 0.3941 ft3/ft X 1.15 (15% excess) = 181.3 ft3 => 158 Sx @ 1.15 ft~/sk CD1-01 (PH) Cement Plug #2: 6200' MD to 5800' MD = 400'. Cement from 6200' MD to 5800' MD (159' MD above the top of the Alpine formation) with Class G + additives @ 17 ppg. Assume 15% excess on open hole volume. Slurry: 400' X 0.3941 ft3/ft X 1.15 (15% excess) = 181.3 ft~ => 182sx @ 1.00 ft3/sk ~ By Weight Of mix Water, all other additives are BWOCement 55O 35O 700 1050 1400 1750 2100 2450 2800 $150 3500 3850 4200 ,,550 4900 5250 5600 5950 6300 6650 7000- 7350- C50 J, 1 AR-CO Alaska, Field : Alpine Field LooatJon: North Slope, AlaskaJ / RrB ElevoUon: 56' Begin Directional Nudge 3.00 6.00 DLS: 3.00 deg per 100 ft 9.00 End Angle Build NUDGE ANGLE Permafrost 10 DEG West Sok 9.00 7.50 6.00 4.50 3.00 1.50 Begin Angle Drop DLS: 1.50 deg per 100 ft End Angle Drop C40 80 East (feet) -> 0 80 I I I I I 9 5/8 Casing Pt I TD LOCATION: 999' FSL, 2608' FWL ~ SEC. 52, T12N, RSE Kingok E* Bose Alpine F TARGET #lm Begin LCU ~ Turn to Tgt/ K-2} TARGET LOCATION: { 894' FSL, 2609' FWL SEC. 32, T12N, RSE C20 K-2 1.68 AZIMUTH 1116' (TO TARGET) ***PLANE OF PROPOSAL*** 160 TO - Nuiqsut Kingok D HRZ Albion-g8 KOP 5.00 6.00  9.00 DL$: 3.00 deg per 100 ft 12.00 15.00 18.00 21.00 4.00 TANGENT ANGLE A,b an-g725.82 DEG Albion -96 HRZ K-2 . Miluveoch A ~ Begin Turn to Tgt ~ ~-~'. [ARGE.T. Jl ~ ~p~ne , Base. AIl~ine ~. KinoaK TD --Ki~%a~suDt ~ ~ E Albion-97 i i ii i i m i i i i 550 0 350 700 1050 1400 1750 Vertical Section (feet) -> Azimuth 1.68 wlth referenoe 0.00 N, 0.00 E from slot 9 5/8 Casing Pt, EOC Begin Angle Drop West Sok Permafrost End Angle Build SURFACE LOCATION: 222' FNL, 2572' FWL SEC. 5, T11N, R5E 1280 1200 1120 1040 , · 960 880 800 720 I z o 5~ --~ 48O 400 52O 240 160 80 Creoted by janes For: B Rober~on Date plotted: 5-Moy-199g Plot Reference is 1PH Version #5. Coordinates are Tn feet reference slot ~1. True VerUcal Depths ore reference RKB (Doyon #19). INTEQ ARCO Alaska, Inc. Structure : CD#1 Field : Alpine Field Well : 1PH Location : North Slope, Alaska Point Begin Directional Nudge End Angle Build Permafrost West Sak Begin Angle Drop End Angle Drop C40 C30 9 5/8 Casing Pt C20 K-3 K-2 KOP EOC Albion-97 Albion-96 HRZ K-2 LCU Miluveach A Begin Turn t.o Tgt Alpine D TARGET #1 Alpine Bose Alpine Kingak E Kingak D TD - Nuiqsut MD 250.00 600.00 862.35 1045.41 1300.00 2000.00 2198.59 241 3.59 2417.59 2788.59 3823.59 4058.59 4651.50 5512.22 5923.49 6245.66 6667.81 6907.77 7013.31 7079.96 7080.53 7105.51 7124.38 7124.40 7179.94 7236.60 7303.26 7365.46 PROFILE ]nc 0.00 10.50 10.50 10.50 10.50 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0 O0 25 82 25 82 25 82 25 82 25 82 25.82 25.82 25.82 25.82 25.82 25.82 25.82 25.82 25.82 25.82 COMMENT Dir 0.00 0.00 0.00 0.00 0.00 0.00 2.13 2.13 2.13 213 213 213 213 213 213 213 213 213 2.13 2.13 2.13 0.41 359.11 359.11 359.11 359.11 359.11 359.11 TVD 250.00 598.04 856.00 1036.00. 1286.52 1982.41 2181.00 2396.00 2400 O0 2771 O0 5806 O0 4041 O0 4655 91 5465 79 5836 O0 6126.00 6506.00 6722.00 6817.00 6877.00 6877.51 6900.00 6916.99 6917.00 6967.00 7018.00 7078.00 7133.99 DATA North 0.00 31.98 79.79 113.15 159.55 223.51 223.51 223.51, 223.51 223.51 223.51 223.51 223.51 414.06 593.08 733.31 917.06 1021.50 1067.44 1096.45 1096.70 1107.58 1115.80 1115.80 1140. O0 1164.67 1193.70 1220.79 East 0.00 0.00 0.00 0.00 0.00 0.0,0, 0.00 0.00 0.00 0.00 0.00 0.00 o:oo 7.09 13.75 18.96 25.79 29.68 31.39 32.47 32.48 32.72 32.68 32.68 32.31 31.92 31.47 31.05 V. Sect 0.00 31.97 79.76 .113.10 159.48 223.41 223.41 223.41 223.41 223.41 223.41 223.41 223.41 41 4.09 593 23 733 55 917 42 1021 93 1 067 90 1 096 93 1097 18 1108 06 111627 111 6.28 1140.45 1165.11 1194.11 1221.18 Deg/lO0 0.00 ? 3 O.uo 0.00 0.00 1.50 0.00 0.00 0.00 0.00 0,00 0.00 0.00 5.00 0.00 t'" ~.,0 0.00 0.00 0.00 0.00 0.00 3.00 3.00 3.00 0.00 0.00 0.00 0.00 ARCO Alaska, Inc. CD~i 1PH slot #1 Alpine Field North S1 ope, A1 aska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 1PH Version#5 Our ref : prop3144 License : Date printed : 6-May-99 Date created : 20-Sep-98 Last revised : 5-May-99 Field is centred on n70 20 37,100,w150 51 37.53 Structure is centred on n70 20 37.100,w150 56 46.041 Slot location is n70 20 34.922,w150 55 30.868 Slot Grid coordinates are N 5975904.937, E 385999.975 Slot local coordinates are 221.01 S 2573.16 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath PMSS <0-9714'>,,22,CD~1 PMSS <0-10255'>,,WD2,CD#1 PMSS <0-10796'>,,24,CD~1 PMSS <0-10548'>,,19,CD~1 PMSS <0-7502'>,,Bergsl,Bergschrund #1 Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 1-Apr-99 138.1 4300.0 4300.0 13-Apr-99 774.4 2800.0 2800.0 5-May-99 230.0 100.0 100.0 22-Apr-99 158.9 1671.4 1671.4 18-Jun-98 2406.1 7365.5 7365.5 5460 ARCO Alaska, Inc. Structure : CD#1 Well : 1 Field : Alpine Field Location : North Slope, Alaska 559O 5720 585O 5980 6110 6240 6370 6500 6630 ¥ 6760 6890 7020 7150 7280 Sldetrock Tie-in Pt 26.50 27.5,5 3.7 AZIMUTH 1793' (TO TARGET) ***PLANE OF PROPSAL*** b~ Jon,e For: t] Robertaon] Dote plotted: 6-M~y-1999 Plot R~ference Is 1 Version Coordinotaa ore In fe~lt reference slot 28.81 DLS: 5.00 decJ per 100 fi 50.52 52.02 EOC TARGET ANGLE 91.41 DEG i i i i i i i i i i i i i i i i i i i i i i i i i ii i ii i i i i i i i i i i i i i i i i i i i i i 590 520 850 780 910 1040 1170 1500 1430 1560 1690 1820 1950 2080 2210 2540 2470 2600 2730 2860 2990 5120 3250 5580 3510 56zl Vertical Section (feet) -> Azimuth 5.70 with reference 0.00 N, 0.00 E from slot #1 ~ w ~m~, For: ~ Robertson I~tm plotted: 6-~-19~ P~t ~anca [m I Ve~n I~rtQ 3800 3600 5400 3200 $000 2800 2600 2400 2200 I 2000 800 I ARCO Alaska, Inc.- Structure: CD#1 Well I Field : Alpine Field Location : North Slope, Alaskal t'- 1600 0 Z 1400 1200 1000 800 6O0 400 2O0 200 <- West (feel) 1600 1400 1200 1000 800 600 400 200 0 200 400 600 800 1000 I I I I I I I I I I I I I I I I I I I I I I I I TD LOCATION: [ 1916' FNL, 1643' FWL SEC. 52, T12N, R5E 3.7 AZIMUTH 793' (TO TARGET) ***PLANE OF PROPOSAL*** TGT/ 7 CsgPt - EO( ~ LOCATION: 1574' FSL, 2591' F'WL SEC. 52, T12N, R5E TARGET - Deepest Po;n[ Albion -97 3egin Angle Drop End Angle Build Alpine Alpine D Miluveoch A LCU K-1 HRZ in Bid &: Trn to Tgi Sldetrock Tie-In Pt 9 5/8 Cos[rig Pt i i i i ii i i i i i i i i i ii i ii i i [ i i 1600 1400 1200 1000 800 600 400 200 0 200 400 600 800 1000 3800 3600 3400 5200 5000 2800 2600 2400 2200 2000 I 1800 1600 140O 1200 100o 800 60O 400 2OO 200 Z 0 <- West (feet) c,~t~ ~ jo.~ For: lq Robertaon[ oote plotted: ~-~-~999 P[~ Ref~nce Is I V~on ~5. ] C~[not~ om In feet mf~n~ slot ~1. I T~e V~icoI Oepthl ~~B (Oolon 4200 4000 5800 5600 3400 5200 5000 2800 2600 '~' 2400 2200 0 Z 2000 1800 160O 1400 1200 1000 800 600 400 AISC0 Alaska, Inc-, Structure: CD#1 Field : Alpine Field Well: 1 Location : North Slope, Alaska <- West (feet)' East (feet) -> 1200 1000 800 600 400 200 0 200 400 600 800 1000 1200 I I I I I I I I I I I I I I I I I I I I I I I I I \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ \ 5900 \ \ \ 210/~'5900 \~ ~./~5700 1200 1000 800 600 400 200 0 200 400 600 800 1000 1200 \ \ \ \ \ \ \ \ \ \ \ 6900x ?700 /6100 ,,/ ,oo 6700 257 15700 / 5500 6500 /6500 6100 ~6100 1500'"~"~'~00 - i i i i i i i i i i <- West (feet)' East (feet) -> 4200 40O0 3800 3600 3400 3200 5000 2800 2600 24O0 2200 2000 1800 1600 1400 1200 1000 800 6OO 400 c,~i.d by Jo.-- For: B Robertson D~ie plotled: 6-M~y-1999 Plot Rs[Irsnce Is I Version ~3. C~rdlnat~s are in f~t rlferen~ sl~ ~1. ITru. V. rt;col ~pth .... ~KB (D~n ,19). ARCO Alaska, Inc. Structure : CD#1 Field : Alpine Field Well: 1 Location : North Slope, Alaska Point Sidetrack Tie-In Pt EOC HRZ Begin Bid & Trn to Tgt K-1 LCU Miluveach A Alpine D Alpine TARGET - Deepest Pt End Angle Build Begin Angle Drop TGT / 7 CsgPt - EOC TD PROFILE COMMENT MD Inc Dir TVD 25.82 5910.00 33.30 6469.58 33.30 6748.25 33.30 6754.35 45.16 6978.98 DATA North East 2.13 5823.86 587.19 13.53 33.11 6313.08 839.43 102.60 33.11 6546.00 967.56 186.17 33.11 6551.09 970.36 188.00 6.82 6726.00 11 02.47 231.59 7127.33 55.27 355.41 6821.00 1215.96 232.97 7245.68 63.79 348.35 6880.00 1315.01 218.57 7297.38 67.84 345.45 6902.00 1362.71 207.45 7340.15 71.10 343.26 6917.00 1401.27 196.64 7584.04 90.00 331.89 6957.00 1 622.01 104.84 7625.72 93.75 531.89 6955.64 7755.20 93.75 331.89 6947.17 7781.18 91.41 331.94 6946.00 9809.75 1 658.75 85.21 1772.71 24.53 1795.60 12.12 91.41 331.94 6896.00 3585.14 -941.91 V. Sect Deg/lO0 586.84 0.00 844.30 3.00 977.56 0.00 980.47 0.00 1115.11 9.00 1228.46 9.00 1326.57 1373.25 9.00 1411.03 9.00 1625.59 9.00 1660.79 9.00 1770.59 0.00 1792.65 9.O0 3516.93 0.00 ARCO Alaska, Inc. CD~i 1 slot #1 A1 pi ne Fi el d North Slope, Alaska SUMMARY CLEARANCE by Baker Hughes INTEQ REPORT Your ref : i Version#3 Our ref : prop3147 License : Date printed : 6-May-99 Date created : 21-Sep-98 Last revised : 6-May-99 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on n70 20 37.100,w150 56 46.041 Slot location is n70 20 34.922,w150 55 30.868 Slot Grid coordinates are N 5975904.937, E 385999.975 Slot local coordinates are 221.01 S 2573.16 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wel 1 path PMSS <0-7502'>,,Bergsl,Bergschrund #1 PMSS <0-10548'>,,19,CD~1 PMSS <0-10796'>,,24,CD#1 PMSS <0-10255'>,,WD2,CD~l PMSS <0-9714'>,,22,CD#1 Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 18-Jun-98 1668.2 8710.0 8710.0 22-Apr-99 158.9 1671.4 8710.0 5-May-99 230.0 100.0 100.0 13-Apr-99 774.4 2800.0 2800.0 1-Apr-99 138.1 4300.0 8700.0 ~ ~4/~o/,, ~,~ ,;,~ ~,.~...^~OO~ACS.. · ALPINE FACI~ VICINITY MAP NOT TO SCALE ~ 70+6 9 0 + ~ ~ ~3 +0,2 ~ ~ ~5 o+ + 23+e 22 25++24 31 0+30 / 33°+32 35+o 3~ 4~++4o LEGEND 43++42 45+°44 + NEW CONDUCTOR LOCATION ~ / o PLAN CONDUCTOR LOCATION , % / F/.~ ~ ASSOCIATSS, INC. . ABCO Alaska, Inc. a~ ~u.~[ PROJECT ~ CD1 ~ CONDUCTORS Subsidiory of Atlontic Richfield Compony AS-BUILT LOCA~ONS L~3~ 3/5/99 ,CE-CDlO-663D1 P( ALL CONDUCTORS ARE' LOCATED IN SEC '5, T 11 N',~R 5 E, UMIAT MERIDIAN Sec Line O/S Well 'Y' 'X' Lot. (N) Lan FNL FWL Gnd Pod CD1-1 5,975,904.92 385,999.99 70' 20' ~4.~22" 150' 55' .~0.i~68" 222' 2,572' 13.0' 19.5' CD1-2 5,975,897.89 385,992.91 70' 20' 34.852" 150' 55' 31.071" 229' 2,565' 13.0' 19.5' CD1-3 5,975,890.99 385,985.82 70' 20' 34.783" 150' 55' 31.275" 236' 2,558' 13.1' 19.'5' CD1-4 5,975,88..3.83 385,978.79 70' 20' 34.711" 150" 55' 31.478" 243' 2,551' 13.2' 19.5' CD1-5 5,975,876.67 585,971.58 70' 20' `54.640" 150' 55' `31.685" 251' 2,544' 13.,3' 19.5' CD1-6 5,975,869.89 .585,964.8,3 70' 20' 54.572" 150' 55' 51.879" 258' 2,5`38' 15.4' 19.5' CD1-7 CD1-8 CD1-9 5,975,848.42 385,945.41 70' 20' 34..358" 150' 55' .32.495" 279' 2,517' 1.5.1' 19.5' CDI-IO 5,975,841.`54 385,9.56.18 70' 20' 54.287" 150'. 55' `32.70`3" 286' 2,51-0' 1.:5.0' 19.5' CD1-11 CD1-12 CD1-13 5,975,820.00 .585,915.06 70' 20' 34.074" 150' 55' `3`3.`311" 508' 2,489' 12.7' 19.5' CD1-14 5,975,812.97 .585,908.00 70' 20' .54.004" 150' 55' `3`3.514" `315' 2,482' 12.6' 19.5' CD1-15 CD1-16 5,975,798.86 `585,894.08 70" 20' `3.5.86.3" 150' 55' `3`3.914" `3.50' 2,468' 12.4' 19.5' CD1-17 5,975,791.81 `585,886.84 70' 20' .3,3.79,3" 150' 55' ,34.12,3" ,3`37' 2,461' 12.5' 19.5' CD1-18 5,975,784.91 .7)85,879.88 70' 20' `5`5.724" 150' 55' `34.`32,3" ,344' 2,454' 12.2' 19.5' CD1-19 5,975,777.92 `585,872.81 70' 20' 3.3.654" 150' 55' `34.526" .351' 2,447' 12.1' 19.5' CD1-20 '5,975,770.66 .585,865.67 70' 20' `5`5.581" 150' 55' `34.7`32" .358' 2,440' 12.0' 19.5' CD1-21 5,975,76.5.76 `585,858.49 70" 20' .5`3.512" 150' 55' ,34.9,38" ,365' 2,4,3,3' 11.9' 19.5' *CD1-22 5,975,756.46 .:585,851.10 70' 20' .3`3.440" 150' 55' 54.151" `37`3' 2,426' 11.9' 19.5' CD1-2`5 5,975,749.`51 `585,844.44 70' 20' `5,3..368" 150' 55' ,35.,342" 580' 2,419' 12.0' 19.5' CD1-24 5t975,742.40 `585,8`57.`50 70' 20' `3.5.299" 150' 55' `35.548" .587' 2,412~ 12.2' 19.5' CD1-25 5,975,7`35..34 .585,8`50.26 70' 20' .33.229" 150' 55' `55.750" `394' 2,405' 12.4' 19.5' CD1-26 5,975,728.10 `585,82`5.14 70' 20' `33.156" 150' 55' `35.955" 401' 2,598' 12.6' 19.5' CD1-27 5,975,721.21 .585,816.08 70' 20' .5`5.088" 150' 55' `36.158" 408' 2,.:591' 12.8' 19.5' CD1-28 5,975,714.15 `585,809.10 70' 20' `3.3.017" 150' 55' 36...559" 416'. 2,.584' 1,3.0' 19.5'1 CD1-29 5,975,707.14 `585,802.20 70' 20' `52.947" 150' 55' `36.558" 422' 2,.577' 1`3.2' 19.5' CD1-`50 5,975,700.17 `585,794.75 70' 20' `52.877" 150' 55' `36.772" 4`50' 2,`570' 15.4' 19.5' CD1 -..31 CD1-32 5,975,685.92 .585,780.68 70' 20' .52.7.55" 150' 55' `37.177" 444' 2,.556' 1`3.2' 19.5' CD1 -`5.5 CD1 -.54 CD1-`55 5,975,664.72 `585,759.6.5 70' 20' `52.524" 150' 55' `37.782" 466' 2,`3.35' 12.9' 19.5' CD1-`56 5,975,657.49 .585,752.52 70' 20' .52.451" 150' 55' .57.987" 47..5' 2,.528' 12.8' 19.5' CD1-`57. 5,975,650.51 .585,745.40 70' 20' `32.`381" 150' 55' `38.191" 480' 2,`521' 12.7' 19.5' CD1-`58 5,975,64.5.79 `585,7`38.44 70' 20' .32.,315" 150' 55' ,38.`391" 487' 2,314' 12.6' 19.5' CD1-`59 5,975,656..54 `585,7`31..57 70'. 20' .32.240" 150' 55' `38.595" 495' 2,`507' 12.5' 19.5' CD1-40 5,975,629.19 `585,724..52 70' 20' `32.168" 150' 55' `38.797" 502' 2,.500' '12.4' 19.5' CD1-41 5,975,622.`57 `585,717.40 70' 20' `32.101" 150' 55' .38.997" 509' 2,29,3' 1-2..:3' 19.5' CD1-'42 5,975,615.01 .585,710.21 70' 20' `52.027" 150' 55' `39.204" 516' 2,286' 12.2' 19.5' CD1-4`5 5,975,607.6.5 `385,702.97 70' 20' ,31.954" 150' 55' ,39.412" 52,3' 2,279' 12.1' 19.5' CD1-44 CD1-45 5,975,59.5.74 .585,689.04 70' 20' .51.815" 150' 55' ,39.81,3" 5.58' 2,265' 12.0' 19.5' * CD1-22 CONDUCTOR WAS AS-BUILT 2/11/98. LOUNSBURY & ASSOCIATES, INC.' E~NEERS PLANNERS SURVEYORS ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company CADD FILE NO. DRAV~NG NO: REV: LK66.SD1 1 ALPINE PROJECT CD1 WELL-CONDUCTORS AS-BUILT LOCATIONS SHEET: CE-CD10-663D1 2 or 3 1¢°/ 9,1MRTI AJRI I DESCRIPTION A99001ACS DESCRIPTION NOTES 1. ALL COORDINATES ARE ALASKA STATE PLANE, ZONE 4, NAD 27. 2. ELEVATIONS ARE BRITISH PETROLEUM MEAN SEA LEVEL. ORIGINAL GROUND ELEVATIONS ARE INTERPOLATED FROM MICHAEL BAKER dR. DWG. CE-CDIO-102, SHT 1, REV. O. . `3. BASIS OF LOCATION AND ELEVATION ARE TEMPORARY ALPINE MONUMENTS `3 & 4 BY LOUNSBURY & ASSOCIATES. 4. DATE OF SURVEY: WELL CONDUCTORS 10, 13, 14, & 16-19' WERE AS-BUILT 3/10/99, REF.FIELD BOOK L99-20, PAGES 3-11. CONDUCTORS 1-.3 WERE AS-BUILT 3/25/99, REF: FIELD BOOK L99-24, PG. 28-.31, CONDUCTORS 4-6, 9, 20, 21, 23-`30, & 35 WERE AS-BUILT 3/29/99, REF: FIELD BOOK L99-2`3, PG. 65, 67-7`3. CONDUCTORS 36-43, & 45 WERE AS-BUILT 4/6, 4/9/99, REF: FIELD BOOK L99-26, PG. .35-38, & 48. SURVEYOR'S CER TIFICA TE I HEREBY CERTIFY THAT lAM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE. OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPER VTSION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF 4/09/99. LOUNSBURY' ASSOCIATES, INC. E~NEERS PLANNERS SURVEYORS ARCO Alaska, Inc. Subsidiory of Atlontic Richfield Compony CADD FILE NO. I I DRAWlNG NO: ALPINE PROJECT CD1 WELL CONDUCTORS AS-BUILT LOCATIONS CE-C'D10-66301 I SHEET:3 REV: 1 ARCO Alaska, Inc. Post Office B6~, 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 18, 1999 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Drill CD1-01 Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore injection well from the Alpine CD1 drilling pad. The intended spud date for this well is May 24, 1999. It is intended that Doyon Rig 19 be used to drill the well. The well will be drilled to the top of the Alpine Sand at an inclination approximately 26©. The Alpine Sand will be cored to provide reservoir management and geological information. The well will be plugged back to a position that will allow the final well path objectives to be met. The well will then be sidetracked to enable a horizontal penetration of the Alpine reservoir. After setting 7" intermediate casing the horizontal section will be drilled and the well completed as an open hole injector completion. Upon completion, the well will be closed in awaiting field start up. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. Plat, identifying the surface location of the proposed CD1-01 well. 4. A proposed drilling program, including a request for approval of annular pumping operations. 5. A drilling fluids program summary. 6. CD1-01 (PH) Pilot Hole Status prior to sidetracking. 7. Proposed completion diagram. 8. Proposed completion diagram with open hole isolation options. 9. Pressure information as required by 20 ACC 25.035 (d)(2). 10. Proposed cementing program and calculations. 11. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). This will cover the plan from the CDI-01PH (pilot hole) and the final CD1-01 production hole. Information pertinent to this application that is presently on file at the AOGCC is: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. If you have any question~,.or require further information, please c ...... ~act Brian Robertson at 265-6034 or Doug Chester at 263-4792. Sincerely, Brian Robertson Senior Drilling Engineer Attachments CC; CD1-01 Well File / Sharon AIIsup Drake Doug Chester Mike Erwin Gracie Stefanescu Lanston Chin ATO 1054 ANO 382 ANO 384 Anadarko - Houston Kuukpik Corporation r~ r , r , r , r ~ r: r/ r. r, F, r, F r' CORE LABORATORIES WATER CHEMISTRY ALPINE CD 1-01 WELL Performed for: ARCO ALASKA, INC. P.O. Box 100360 700 G STREET ANCHORAGE, ALASKA 99510-0360 March 31, 2000 Performed by: Core Laboratories, Inc. Advanced Technology Center Rock Properties Laboratory 1875 Monetary Drive Carrollton, Texas 75006 File: DAL- 00037 The analytical results or interpretations contained in this report are based upon information and material supplied by the client for whose exclusive and confidential use this report has been made. The analytical results, opinions or interpretations expressed represent the best judgment of Core Laboratories. Core Laboratories, however, makes no warranty or representations, express or implied, of any type and expressly disclaims same to the productivity, proper operations or profitableness of any oil, gas, coal, or other mineral property, well or sand in connection with which such report is used or relied upon for any reason whatsoever. This report shall not be reproduced in whole or in part without the written consent of Core Laboratories. March 31, 2000 CORE LABORATORIES Mr. Mike D. Erwin Arco Alaska, Inc. P.O. Box 100360 700 G Street Anchorage, Alaska 99510-0360 Subject: Water Chemistry Report Alpine CD 1-01 Well File: DAL-00037 r.. Mr. Erwin: Twelve core plugs were cut from a one-foot section of preserved, slabbed core matedal from the Alpine CD 1-01 Well to provide additional insight in the ion composition of the formation brine present in the reservoir. This experiment involved the use of core petrophysics, radioactive isotope analysis, and aqueous ion chromatography analysis. Integration of these technologies provided a means of reconstructing the brine chemistry of the reservoir. This document format consists of: · Procedures · Results · Discussion · Data Appendix If you have questions regarding the enclosed information, please do not hesitate to contact me. Sincerely, Paul R. Martin Petrophysics Supervisor Dallas Advanced Technology Center 3 copies: addressee F~ F r r r:, r r r r r Arco Alaska, Inc. Alpine CD 1-01 File: DAL 00037 PROCEDURES , , . , , . Upon arrival to Carrollton the core material was depreserved and plugged with humidified nitrogen. Twelve plugs were taken, approximately one per inch. After plugging the samples were faced square, weighed, and then placed into clean Dean Stark extraction units and extracted using reagent grade Toluene. After cleaning and extracting, the water distilled from the cores was carefully measured and transferred to a glass vial and sent to the Stable Isotope Laboratory at Southern Methodist University for Deuterium Oxide tracer analysis. The core plugs were dded in a vacuum oven to constant weight (+/- 0.01 gram), and then measured for their physical properties using the CMS 300. Following physical Properties measurements the plugs were carefully crushed to grain size, reweighed, and leached with 60 grams of deionized water. Following leaching, the plug-water slurry was filtered and the filtrate was sent out for ion chromatography analysis identifying the ionic species present in the formation brine. 7. The ions present in the formation brine were calculated using the formula below: Ionrock = Ion~eachwater X Leachwaterw,~ght X Plug Wt.d~ Dean Stark wateGn~ X Crushed Rock wt.~m Core Laboratories r , Arco Alaska, Inc. Alpine CD 1-01 File: DAL 00037 r RESULTS The results from this study are contained in three sections in the appendix of this report. These sections are: · Summary · D20 Analysis · Mud and Core Plug Ion Analysis r ~ Summary The summary section of the appendix contains a table with core physical properties including: · Pore Volume · Porosity · Klinkenberg Permeability · Air Permeability · Grain Density r, Measured at 1000psi and 2400psi. It also contains Dean Stark Extraction data and the Deuterium Oxide content of the Dean Stark water, the mud filtrate, and the background. Additionally present in this table are the leach water data including weights and ion analyses from Peak Analytical Inc. Finally present in the summary is the reconstructed bdne chemistry for the Alpine CD 1-01 cores measured in this study. This is on the third pa.qe of the summary table. D20 Analysis The D20 Analysis section of the appendix contains the D20 analysis sheets provided by: r, r, r~ Stable Isotope Laboratory Department of Geological Sciences Southern Methodist University Dallas, Texas 75275 Mud and Core Plug Ion Analysis The ion chromatographic data for the ddlling fluid filtrate and also for the leach water extraction of the crushed core plugs are displayed in the third section of the appendix. These results were provided by: Peak Analytical Inc. #40aktree Friendswood, Texas 77546 Core Laboratories r ~ , r, r, r, Arco Alaska, Inc. Alpine CD 1-01 File: DAL 00037 DISCUSSION The Alpine CD 1-01 core was taken early to mid 1999. The core material has been preserved and stored in Alaska. The interval selected for this study was chosen because of its Iow invasion properties when initially tested for routine core properties. In the mean time this core has sat in the warehouse in Alaska for months. Plugs were cut for this work in February 2000. Analysis for invasion (using D20) indicated about 30 to 40 percent invasion by mud filtrate. This value differs from the original data which showed invasion of 18% by mud filtrate. Invasion by the mud filtrate will affect the results of this study. Invasion by mud filtrate is further confirmed by examining the ion analysis in the reconstructed water chemistry. Potassium concentrations of 5000ppm do not naturally occur in formation waters. However, when a KCL mud is used as a drilling fluid, invasion of KCL into the formation can contribute to high potassium content in the reconstructed formation brine analysis. High sulfate content in leach waters in generally the result of pyrite oxidation during the leaching process. Sulfate concentrations of 4000 to 5000 ppm in formation water are unusual. The reconstructed formation brine chloride content of 28,000 ppm is probably a little high due to the invasion by KCL. Very likely the chlodde content is closer to 24,000 to 26,000 ppm in the formation water. As stated above, invasion by mud filtrate will affect the results of this study. Additional tests such as these implemented eady in the testing phase of coring will have much better results. This is pretty good data, but it could have been much better if it was implemented 6 or 7 months ago with this core. Core Laboratories Arco Alaska, Inc. File: DAL-00037 APPENDIX SECTION 1 DATA SUMMARY r r, Core Laboratories r.. ALPINE CD1-01 WATER CHEMISTRY RECONSTRUCTION ARCO Alaska, Inc. Alpine CD 1-01 Well File: DAL-00037 Depth, Ft. I1000 psi Confining Stress ~ore VolumelPorosity% Permeability, mD cc I KlinkenbergI Air I Pore Volume cc 2400 psi Confining Stress Porosity% IPermeability, mD KlinkenbergI Air I D.S. Grain DensityWater Gm/cc cc o.s. Water I D-S.I gram Water 7128 4.3 19.9 6.7 7.94 4.16 19.4 6.31 7.45 2.652 1 1.04 4l, 7128.1 4.66 21.3 12 13.8 4.51 20.8 11.5 13.1 2.652 1.05 1.01 422.4 7128.2 4.58 20.7 11.9 13.7 4.44 20.2 11.3 13 2.65 1.05 1.03 423.5 7128.3 4.66 21.6 12.1 13.9 4.5 21 11.6 13.2 2.649 0.98 1 422.5 7128.4 4.56 19.7 6.86 8.07 4.41 19.2 6.47 7.59 2.649 1.15 1.16 423.6 7128.5 4.95 19.3 5.05 6.02 4.79 18.8 4.75 5.64 2.649 1.2 1.15 422.8 7128.6 5.2 20.3 7.49 8.85 5.02 19.8 7.05 8.26 2.64 1.38' 1.38 386.6 7128.6 5.2 20.6 11.3 13.1 5.04 20.1 10.8 12.4 2.649 1.18 1.12 422.1 7128.8 5.07 20.2 9.47 11 4.91 19.7 8.96 10.4 2.656 1.15 1.14 422.2 7128.9 5.05 19.8 7.52 8.87 4.89 19.3 7.23 8.47 2.655 1.15 1.15 423.8 7129 5.26 20.4 7.11 8.39 5.1 19.9 6.66 7.84 2.648 1.25 1.17 422.6 7129.1 4.98 19.5 5.03 6.05 4.82 19 4.68 5.61 2.652 1.21 1.2 423.3 Core Laboratories ALPINE CD1-01 WATER CHEMISTRY RECONSTRUCTION -(continued) ARCO Alaska, Inc. Alpine CD 1-01 Well File: DAL-00037 D20 D20 Filtrate Crushed D.S. Bottle Total'wt. Leach Leach water ion analysis (,from Peak Analytical) Depth, Ft. mud Backgrnd Fraction Rock wt. lplug wt. Wt. bottle + Waterwt. chloridesulfate Isodium Ipotassium ImagnesiurJcalcium Filtrate grams grams grams water+rock grams mg/L. mg/LI mg/LI mg/L I mg/L ~ mc, ilL 7128 892.6 139.6 0.3716 45.81 45.91 37.94 143.77 60.02 444.69 79.02 347.42 85.04 1.66 9.32 7128.1 892.6 139.6 0.3756 45.57 45.65 36.21 141.78 60 469.05 54.27 321.81 78.98 1.64 9.15 7128.2 892.6 139.6 0.3770 46.48 46.56 35.9 142.39 60.01 507.76 56.83 339.78 94.65 1.66 9.29 7128.3 892.6 139.6 0.3757 44.89 44.96 37.38 142.28 60.01 465.64 55.04 317.7 92.23 1.64 9.23 7128.4 892.6 139.6 0.3772 49,16 49.26 37.73 146.9 60.01 546.43 67.1 377.06 101.03 1.31 9.09 7128.5 892.6 139,6 0.3761 54.83 54.98 37.97 152.8 60 531.99 96.98 393.77 101.19 1.66 10.25 7128,6 892.6 139.6 0.3280 53.77 53.91 37.75 151.52 60 474.45 422.6 390.3 101.22 7.99 32.7 7128.6 892.6 139.6 0.3752 53.12 53.21 37.74 150.87 60.01 488.55 74.63 343.21 79.33 1.56 8.46 7128.8 892.6 139,6 0.3753 53.1 53.18 37.7 150.81 60.01 525,17 87.1 373.85 101.08 1.85 9.27 7128.9 892,6 139.6 0.3774 54.37 54.48 36.16 150.55 60.02 528.65 109.39 387.15 103.71 2,53 11.11 7129 892.6 139.6 0.3758 54.13 54.36 37.72 151.84 59.99 574.22 73.62 395.31 106.45 1.46 9.84 7129.1 892.6 139.6 0.3768 54.28 54.45 37.93 152.21 60 536.74 80.79 386.54 105.5 1.66 9.47 Core Laboratories ALPINE CD1-01 WATER CHEMISTRY RECONSTRUCTION -(continued) ARCO Alaska, Inc. Alpine CD 1-01 Well File: DAL-00037 Calculated water ion analysis Depth, Ft. chloride sulfate Isodium lpotassium magnesiur calcium mg/L mg!LI mcj/LI mg/L mcj/L mg/L 7128 25720 4570 20094 4919 96 539 7128.1 27913 3230 19151 4699 98 545 7128.2 29634 3317 19830 5524 97 542 7128.3 27987 3308 19095 5543 99 555 7128.4 28326 3478 19546 5237 68 471 7128.5 27832 5074 20601 5294 87 536 7128.6 20682 18422 17014 4412 348 1425 7128.6 26221 4005 18420 4258 84 454 7128.8 27687 4592 19709 5329 98 489 7128.9 27647 5721 20247 5424 132 581 7129 29567 3791 20355 5481 75 507 7129.1 26921 4052 19388 5292 83 475 Core Laboratories Arco Alaska, Inc. File: DAL-00037 ~ , APPENDIX SECTION 2 D20 ANALYSIS ~ Core Laboratories , r ~ Robert Patterson Core Laboratories Dallas Advanced Technology Center Carrollton, Texas 75006 972-466-2673 (phone) 972-323-3930 (FAX) 12 samples for D/H, received 2/24/00. D/H (SMOW) = 0.0001558 SMU Core Labs SD ppm Sample# Sample# (SMOW) Repeat Deuterium Repeat CL 12-1 1 1691.6 1691.9 419.4 419.4 CL 12-2 2 1711.2 422.4 CL 12-3 3 1718.4 423.5 CL 12-4 4 1711.8 422.5 CL 12-5 5 1718.8 423.6 CL 12-6 6 1713.7 1716.1 422.8 423.2 CL 12-7 7 1481.5 1479.6 386.6 386.3 CL 12-8 8 1709.0 422.1 CL 12-9 9 1709.9 422.2 CL 12-10 10 1720.3 423.8 CL 12-11 11 1712.4 1707.4 422.6 421.8 CL 12-12 12 1716.9 423.3 ,,, r , Arco Alaska, Inc. File: DAL-00037 APPENDIX SECTION 3 MUD AND CORE PLUG ION ANALYSIS r r r ,, Core Laboratories r~ I 1 .j I' , i , I. Peak Analytical, Inc. Core Laboratory Lab Report 200-1262 March 9, 2000 Flouride mglL Chloride Bromide Nitrate Sulfate mglL mglL mg/L mglL 444.69 nd nd 79.02 469.05 nd nd 54.27 507.76 nd nd 56,83 465.64 nd nd 55,04 546,43 nd nd 67.10 531,'99 ........ n'~l- ........~d ........... {6;98 ._,..4.7.4_,.4.5 ..... nd nd 422.60 488,55 nd nd 74.63 nd nd 87.10 5~e,6~' ....... 'n~i ....... nd 109.39 574,22 nd nd 73.62 nd nd nd nd nd nd nd nd 525.17 nd nd ~15 L'-~i-~'2' ................ '~- ...... ~3-~:~)'9 '" ~P1~'#12 ..... nd "535.761 Mean - 536.735 nd nd nd nd 80.229 81.358 80,794 ........ - QC 1.017 4.776 QC Value 1.000 5,000 % Recov..ery .............._101_...:.700 95,520 1.042 1,000 104.200 1.000 1.000 103.800 103.700 Sample ' Lithium mglL Sodium 15btassium 'Magnesium inglE ..... __.mi]ii.. ..... mglL Calcium "~'t'r'or~m Barium mg/L . .m..~/_.L .... mg/L SPL #1 ~SPL#3 SPL#4 'SPL #5 SPL #6 SPL #7 SPL #8 SPL #9 SPL#1 SPL #1 nd 347.420 nd 321,810 nd 339,778 , nd 317,695 nd '-'~77.055 ' ''851035 ..... 1.655 78.957 1.640 9~.6~6 1.655 92.233 1.638 101.032 1,314 101,188 1.657 101,223 ~.994 79.326 1.562 101.077 1.846 103,709 2.531 106,45 1.46 nd 393.773 nd 390.304 nd 343.211 nd 373.845 0 nd 387.148 1 nd 395.31 9.318 nd nd 9,145 nd nd 9.294 nd nd 9.233 nd nd 9.082 nd nd 10.252 nd nd 32.699 ....... ~d nd 8,464 nd nd 91~'~ ~ ' nd .... nd 11,111 nd nd 9,84 ......... nd "'~d SPL #12 nd 386.66 SPL #12 nd 386.43 Mean - 386.54 104.66 1.69 108.35 1,63 105.50 1.66 9.50 nd ..... nd 9.45 nd nd 9.47 - - QC-" 5,022 5.361 '15'.-9-¢'?" 0,981 0.972 ' --~)'.978 '"~5.970 Q(SValue 1.000' 5.000 1.ooo 1.ooo 1.ooo 1.ooo 1.ooo %-I~ecovery 102.200 107,2'20 97.70.0~ .... 98.100 97.200 ___9'~.§00 .... 9~/.'~00 r Peak Analytical, Inc. .. ..~ample. Al_pin~ 'cl:).l:o 1'? 128' (Dal-99.1~.3:~)'" Alpine. CDI-01 7128' (Da1:~99133) Mean ., ~C QC Value .,_ % Re.c.o_very Flouride Chloride ' m_glL _ mg/.L_... Core La bo_ra_tory ....... Lab_R..e.p°rt 20_..0't2~___ .......... _March 1_4_~. 2000 .............. Br--omide .... Nitr--ate " Sulfate -' Bari~Jm ' -- 7.18 -" ~.~.379 '* 157,075 ' n~l' 7.74 25.002 159,212 net 7,4.~9 i.~. ~_5.191__-.. 1~8.144 '~;: -' 1-.081 -- 1.05~ '"'1.024 .... 1:018 '" '1.000 .... 1,oob -' 1.oo0~ 11000 '~08.100 ..... 105,'~-00 ~--;102.40~) 101.800 , P~'assiam_._'~.Magn.e.~ium' '.~alciu.m.i" StrOntium __'"-mglL .. , .m_91L .. rog/L_ .... .~g/L 13.692 32503,161 13.148 32422.827..~ 13,420 , 32462.994 '-~.'021 .... 4,96~" 1.ooo '-' 5.o~o '--'102.10'6"- 99,3-80 Sample'~ ' Alpine CDI-01 7128'_(Dal-991.3.3~. Alpine gDl-'01 712_8' (Dal-991.,,33) Mean ' QC Value .Recovery 0.34 1.056 1.000 105,600 Lithium Sodium -' . _i--' mg/_L_'" i -m--g'/L 0,337 2599.520 0.338 2617.612 2608,57 5,028 5.000 100.560 I 3265§~',~04 ' 5'--9.545 - 2391655 19,751 33144.884 60.007 243.133 18.494 ' :J2--899.19'-- 59.78 -~;41.39-- 1~112 0.969 1.037 1.074 1.106 -- ~.ooo-- i~0o "' 1.oob -' 1.ooo' -~6.900 --'103~'f00 ' -107.40'0 '~10.600~ Post-it" Fax Note 7671 ,, l,.o u. !../qn [-,--h ''' 0':'i'¢-'- - lPhone ft Fax # ARCO Alaska, Inc. Kuparuk Unit Disbursement Account P.O. Box 102776 Anchorage, AK 99510-2776 PAY TO THE ORDER OF: The First National:Bank of Chicago-0710 Chieago~ Illinois Payable Through Republic Bank Shelbyville, Kentucky CHECK NUMBER 230096194 73-426 839 APRIL 30, 1999 0997587 ALASKA DEPT OF:REVENUE ALASKA OIL & GAS CONSERVATION COMMI 3001 PORCUPINE DRIVE *** VOID AFTER 90 DAYS **~ , : : . EXACTLY ***********'100 DOLLARS AND O0 CENTS $*********** 100.00 TRACE NUMBER: 230096194 ,' ;~ ~.OOCir= ;~cih,' "-OP. ~.c30h 2F= 2~-' OCiCi? SR ?,' · , WELL PERMIT CHECKLIST COMPANY ~*Tv~_~j WELL NAME~/~/~ 4/- cb ! PROGRAM: exp dev ~' redrll ~ serv ~ wellbore seg ~ann. disposal para req ~ FIELD & POOL / ~.. c3 /~ C) INIT CLASS _/~,,, / ADMINISTRATION 1. /~R DATE ENGINEERING Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... GEOL AREA N (~N (~)N (~N I ON/OFF SHORE GEOLOGY APPR DATE~ ANNULAR DISPOSAL APPR DATE 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to '~) O(~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N/ 31. Data presented on potential overpressure zones ....... Y 32. Seismic analysis of shallow gas zones ............. Y//N 33. Seabed condition survey (if off-shore) ............. ~ N 34. Contact name/phone for weekly progress reports [exploratory one,fi Y N 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N .(B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEE[~IN~: UIC/Annular RP~--,' BEVV~~ WM DW~ JDH~.----"-' RNC COMMISSION: Comments/Instructions: c:\msoffice\wordian\diana\checklist