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200-171
Im Project Well History File Cow~:~age XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. RESCAN DIGITAL DATA ~' OVERSIZED (Scannable) Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other, No/Type · [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) n Other: [] Logs of various kinds NOTES: [] Other Project Proofing BY; BEVERLY ROBIN VINCENT SHERYL~~,NINDY sca"'nning Preparation BY: BEVERLY ROBIN VINCENT SHERYL ~INDY Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ~" YES NO BEVER' OBIN INCENT BY': ~,~ SHERYL MARIA WINDY Stage2 IFNO,NSTAGEI,PAGE(S) D,SCREP~WEREFOUND:~~~/~~NO RESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: IS/ Quality Checked 12/10/02Rev3NOTScanned.wpd a ~- ~~ . Tf~'~411/~fT1`~4L ~. ~. ProActive Diagnostic Services, Inc. To: State of Alaska - AOGCC Christine Mahnken 333 West 7th Ave Suite 100 Anchorage, Alaska 99501 (907J 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTTj The technical data listed below ks being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska], Inc. Petrotechnical Data Center Attn: Andy Farmer LR2-1 900 E. Benson Blvd Anchorage, Alaska 99508 and ao~_~7f ~~~~~ IV~I~ ~ 6 2007 ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8951 1 J Csaliper report 22-0ct~07 CD1-10 EDE 50-103-20353-(JO _ :~ ,. f s 2) ~ ' a ~ i Signed : Date ~ , ~ ~,rss:~,,i~„ 1A .. nn 5 Print Name: .~Ll~ ~ ; ~-~ % ~ ~ U ~ l^ ~(, ~n J P.v~ PROAC7NE DInGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORY RD SURE C, ANCNORAl3E, AK 99518 PNONE: (907)245-8951 FAX: (907)245$895Z E-IAAIL : ~dsarac~~r~eCc~re~erra~r°s~g.~~srrb WEBSRE : vvv~,v.~aes~®r~B®~ ~~rba D:\Master_Copy_00_PDSANC-ZO~c~Z Word\Disfribution\TransrtuVat Sheets\ltansmit_Original New.doc CD 1-10 (PTD 2001710) Suspect Tx~communication • Page 1 of 1 Regg, James B (DOA} From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Wednesday, October 24, 2007 4:06 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj; ALP DS Lead/Simops Coord; Smith, Timothy S; Schneider, Tim S. Subject: CD1-10 (PTD 2001710) Suspect TxIA communication Attachments: CD1-10 schematic.pdf; CD1-10 90 day TIO plot.gif Tom & Jim, Gas lifted producer CD1-10 (PTD 2001710) was reported on 10/23/07 with suspected TxIA communicatiol~(. The Drillsite Operator unsuccessfully attempted to bleed the IA down. The IA pressure before the bleed attempt was 1959 psi. Slickline will trouble shoot the GLV's and repair if possible. Attached is a schematic and a 90 day TIO plot. Please let me know if you have any questions. «CD1-10 schematic.pdf» «CD1-10 90 day TIO plot.gif» Brent Rogers Problem Wells Supervisor 659-7224 '~~~~ ~ NC1~ ~. ~_ SOD? 10/30/2007 r~ . ~ • • file:///CJtempll'emporary%2Ulmemel%20Files/OLK24/CDI-IU%2U9U%2Uday°i 20TI0%20ploi.gifl U/3U/2W7 8:32:21 AM " '~ ~ ALPINE ~; j C©nlt~cs~Ph,"tllips A~a~ka,'lnc. ... ~~ -- - -j CDi-10 _ _ - CONDUCTOR - ~ (0-114, ~ ~ I I oD:ls.ooo, Wt:62.58) ~. CD1-10 API: 501032035300 Well T e: PROD An le TS: de SSSV Type: WRDP Orig Completion: 12/9/2000 Angle @ TD: 90 deg @ 11693 Annular Fluid: Last W/O: Rev Reason: Reset WRDP Reference L Ref Lo Date: Last U date: 611 012 0 0 4 Last Ta TD: 11693 ftKB Last Tag Date: _ _ Max Hole Anate: 93 deq (a~ 8059 sssv ~ Casing 3trin~-ALL_ I ~ (1719-1720, - - OD:3.812) NIP (1719-1720, ~ - OD:6.062) Descri tion Size To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 114 114 62.58 H-40 WELDED SURF CASING 9.625 0 2422 2389 36.00 J-55 BTC-MOD PROD CASING 7.000 0 7909 6939 26.00 L-80 BTCM OPEN HOLE 6.125 7909 11693 11693 0.00 Gas Lift MandrelNalva , 1 (3563-3564, >'G I I i :~ Gas Lift MandrelNalve (56135614, „r..:._... _. Gas Lift MandrelNalve 3 (7389-7390, NIP ; r --- (7492-7493, OD:5.000) r ' TUBING ~_ _J (0-7633, OD:4.500, ID:3.958) ~I PKR (7546-7547, OD:5.970) NIP - (7622-7623, ' OD:5.000) WLEG ~~- (7633-7634, OD:5.000) PROD CASING (0-7909, OD:7.000, Wt:26.00) 1 1 ~ 1~ OPEN HOLE ~ 1 (7909-11693, 1 , OD:6.125) ~ 1 I , Tublr~ 500 ~ TUBIN TOP - -67633 ~ T D ~ Swi;ii L~~ii~P TIBTMd - - . . ~ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 ~l March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 aa~NED APR 1 0 2007 aoo-I'll Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells ftom 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 ftom 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, ~~C Jerry Dethlefs ConocoPhillips Well Integrity Proj Supervisor Attachment . . 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 2/16/2007 Alpine Field March 31,2007 F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE Jds u. ~ co'~ ( t \ WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: AOGCC 333 West 7th Ave. Ste. 1 00 Anchorage, AK 99501-3539 RE: Distribution - Final Print(s] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 WELL DATE loG TYPE DIGITAL OR CD-ROM 1 MYLAR / SEPIA FILM 1 BLUE LINE PRINT(S) REPORT OR BLUE LINE Open Hole 1 Res. Eva!. CH 1 1 1 Mech. CH CD1-10 3-6-04 Caliper Survey 1 Rpt or 1 Color Signed: ~c:\_~~\. ~ ~'-\:) Ñ~ t'-^""- DatREC[IVED MAR 2 2 2004 Alaska Oil & Gas coRs. CommiIion Anchof8D6 Print Name: PRoAcTivE DÎAGNOSTic SERviCES, INc., PO Box 1 }b9 STAffORd TX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com RBDMS RD MAR< 2"5' Mf C)OO~) -t( Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: Pipe2 Desc.: Pipe2 Use: ConocoPhillips March 6, 2004 5369 2 4.5" 12.6 lb. L-80 Tubing 7" 26 lb. L-BO Liner Well: Field: State: API No.: Top Log Intvl1.: Bot. Log Intvl1.: Top Log Intvl1.: Bot. Log IntvI1.: CD 1-10 Alpine Alaska 50-1 03-20353-00 Surface 7,633 Ft. (MD) 7,634 Ft. (MD) 7,704 Ft. (MD) Inspection Type: Corrosion Monitoring Inspection COMMENTS: This log is tied into the WLEG @ 7,633' (Driller's Depth). This log was run to assess the condition of the tubing with respect to changes in corrosive damage since the prior log run on August 1, 2003. Heavy deposits were recorded in the liner, just below the tubing tail and that information has been included in this report. This is the second time a PDS caliper has been run on this well. A comparison between this log and the previous log run on this well indicates little or no increase in corrosive damages during the period between caliper logs. A detailed comparison of the corrosive damage recorded between the previous and current caliper logs indicates almost no change «+0.001") in the average maximum penetration recorded in each joint throughout the tubing string. Three significant instances of a "loss of corrosion" (deeper maximum penetration recorded in the previous log) occur in joints 128.3, 147 and 169.3 - ranging from a 0.035" to 0.048" decrease in the maximum recorded penetration, A review of the data from the previous log, coupled with a direct comparison of the recordings from these joints in the current log indicate that the deposits recorded in these intervals in the previous log contributed to an exaggeration of the actual damage to the tubing. The deposits acted to create an artificial base starting approximately 0.03" from the actual pipe wall, resulting in pit depth measurements that include the thickness of the deposits, and some penetration into the pipe wall. Our comparative analysis indicates that the actual damage in these joints was closer to the values recorded in the current log at the time that the previous log was run. A Consecutive Log Comparison graph, illustrating the distribution of the difference in previous and current maximum recorded penetration values is included in this report. The caliper recordings indicate that the 4.5" tubing is in good to fair condition. A 23% wall penetration is recorded in a line of corrosion in joint 172 @ 7,496', No significant areas of cross-sectional wall loss are recorded. Deposits restrict the I.D. to 3.71" in joint 174.2 @ 7630', The 7" liner logged appears to be in good to fair condition with respect to corrosive damage. A 36% wall penetration is recorded in the first joint logged @ 7641'. The damage appears in the form of corrosion. No other significant wall penetrations or areas of cross-sectional wall loss are recorded throughout the liner logged, Deposits are recorded throughout the liner logged, restricting the I.D. to 5.36" @ 7,666' in joint 2. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Pages of this report, RBDMS RD ProActive Diagnostic Services, Inc. / PoD. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog,com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 RECEIVED MAR 2 2 2004 Alaska Oil & Gas QmS. COmmiIion -- .AnMnnœ MAR 2 5 2004 4.5" TUBING - MAXIMUM RECORDED WALL PENETRATIONS: Line Corrosion ( 23%) Jt. 172 @ 7,496 Ft. (MD) No other significant wall penetrations (> 19%) are recorded throughout the tubing. 4.5" TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 6%) are recorded throughout the tubing. 4.5" TUBING - MAXIMUM RECORDED ID RESTRICTIONS: Deposits Lt. Deposits Lt. Deposits Lt, Deposits Lt. Deposits Minimum I.D. = 3.71" Minimum I.D. = 3.75" Minimum I.D. = 3.76" Minimum I.D. = 3.78" Minimum 1.0,::: 3,79" Jt. Jt. Jt. Jt. Jt. 174.2 @ 174 @ 129 @ 172.3 @ 173 @ 7,630 Ft. (MD) 7,617 Ft. (MD) 5,626 Ft. (MD) 7,548 Ft. (MD) 7,586 Ft. (MD) 7" LINER - MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 17%) are recorded throughout the liner logged. 7" LINER - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 10%) are recorded throughout the liner logged. 7" LINER - MAXIMUM RECORDED ID RESTRICTIONS: Deposits Deposits Deposits Minimum I.D. ::: 5.76" Minimum I.D. = 5.82" Minimum I.D, = 5,84" Jt. Jt. Jt. 21 19 20 @ @ @ 9,177 Ft. (MD) 9,112 Ft. (MD) 9,145 Ft. (MD) - No other significant I.D. restrictions are recorded throughout the liner logged. I Field Engineer: N. Kesseru Analyst: M. Lawrence / J. Burton Witness: M. Cheney ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 WeB: Field: Company: Country: I Tubing: Nom.OD 4.5 ins CD 1-10 Alpine Co no co Phillips USA Weight 12.6 ppf Grade & Thread L-80 Penetration and Metal loss (% wall) - penetration body 150 100 50 0 0 to l')fo 1 to 100,1" - metal loss body 10 to 20 to 40 to over 20% 40% 85% 85% Number of joints analysed (tQtal = 185J pene. 1 143 40 1 0 loss 11 7 68 0 0 0 --- 30 Damage Configuration ( body) 20 10 0 isolated pitting general corrosion line corrosion hole / poss ible hole ring corrosion Number of joints damaged (total = 29) 24 1 4 0 0 0 0 PDS ReportOverview Body. Region Analysis Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: Nom.lD 3.958 ins March 6, 2004 MFC 40 No. 00432 2.75 40 M. Lawrence Upper len. 1.2 ins Lower len. 1.2 ins Nom. Upset 4.5 ins Damage Profile (% wall) - penetration body 0 1 - metal loss body 50 100 1 -I i I 49 GLM 1 l 97 GLM 2 145 GLM 3 Bottom of Survey = 174.3 Analysis Overview page 2 ~ Well: Field: Company: Country: Survey Dates: CD 1-10 Alpine ConocoPhillips USA August 8, 2003 - March 6, 2004 PDS Caliper Consecutive Log Comparison Tool. MFC 40 No. 00432 Tool Size: 2.75 inches Tubing 1.0.: 3.958 inches Tubing 0.0.: 4.5 inches Wall Thickness: 0.271 inches Differences in Maximum Recorded Penetrations Between Current & Previous Lð Decrease in Max. Recorded Pen. ... CD .CI E ~ z .... c Õ .., -100 -80 -60 -40 Difference in Maximum Recorded Penetration (mils) Increase in Max. Recorded Pen. 58. ~ 6i: . 70~ r ~:ç- 1~ -20 0 20 40 60 80 100 0.24 0.19 -;- 4J ..c u :§. ..c Q. 4J Q 0.14' .., ¡¡: 0.09 cEas. Well: Field: Company: Country: Survey Date: 10 Percent Probability of Hole 20 50 CD 1-10 Alpine ConocoPhillips USA March 6, 2004 '00 PDS Caliper Statistical Evaluation Report Tool: Tool Size: Tubing 1.0.: Tubing 0.0.: Wall Thickness: 85% Wall Thickness Sa~ety ':acor Line ------- -------.- r---------? -------- 0.04 0.1 Average Rank 0 10 MFC 40 No. 00432 2.75 inches 3.958 inches 4.5 inches 0.271 inches Standard Deviation of 0.002 Maximum Probable Penetration* 0.060 inches (22.0 % Wall Thickness) Percent Probability of Recording a Hole* Less than 10% . Derived tram data wIth average rank value less than or equal to 20. 100 PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 \Nei!: CD 1-10 Body Wall: 0.271 in Field: Alpine Upset Wall: 0.271 in Company: ConocoPhillips Nominal I.D.: 3.958 in Country: USA Survey Date: March 6, 2004 Joint Depth Pen. Pen. Pen. Metal Min. Damage Profile I No. (Ft.) Upset Body % Loss I.D. Comments (%wall) (Ins.) (Ins.) % (Ins.) 0 50 100 1 24 0 0.02 8 1 3.93 --- I 2 68 0 0.01 2 2 3.91 i I 3 109 0 0.01 4 1 3.92 ~ 4 150 0 0.02 8 1 3.94 5 194 0 0.01 3 1 3.92 ~ 6 235 0 0.02 8 1 3.92 7 279 0 0.02 9 1 3.93 II!! 8 323 0 0.02 9 1 3.89 ì!III 9 367 0 0.01 3 1 3.93 10 411 0 0.01 2 1 3.91 11 452 0 0.01 2 1 3.91 12 493 0 0.01 4 1 3.93 13 534 0 0.00 1 1 3.91 14 576 0 0.01 4 1 3.91 15 617 0 0.01 4 1 3.92 16 657 0 0.01 5 1 3.92 17 698 0 0.01 4 1 3.87 18 742 0 0.01 4 1 3.92 19 786 0 0.02 8 1 3.92 20 830 0 0.01 3 1 3.92 21 .871 0 0.01 3 1 3.92 22 915 0 0.02 8 2 3.88 23 'l58 0 0.02 8 1 3.91 24 1002 0 0.01 4 2 3.85 25 1045 0 0.02 8 1 3.91 26 1089 0 0.02 8 1 3.94 27 1133 0 0.03 11 1 3.92 28 1177 0 0.01 3 1 3.92 29 1221 0 0.03 10 1 3.90 30 1265 0 0.03 9 1 3.90 31 1309 0 0.03 10 1 3.92 32 1353 0 0.02 9 I 3.93 33 1397 0 0.02 9 1 3.91 34 1441 0 0.02 9 1 3.90 35 1485 0 0.01 3 1 3.91 36 1529 0 0.03 10 1 3.91 37 1573 0 0.01 2 1 3.88 38 1614 0 0.02 8 1 3.91 39 1656 0 .0.03 11 1 3.93 Shallow pitting. I 39.1 1700 0 0.01 4 1 3.92 PUP 39.2 1710 0 0 0 0 3.81 SSSV 39.3 1715 0 0.02 7 '1. 3.91 PUP 40 1725 0 0.01 3 1 3.91 41 1768 0 0.02 8 2 3.89 42 1811 0 0.01 4 1 3.92 43 1855 0 0.03 10 1 3.91 44 1899 0 0.03 9 1 3.90 45 1943 0 0.02 9 1 3.91 ~~ 1987 0 0.02 9 1 3.92 47 2031 0 0.03 11 1 3.91 I Penetration Body Metal Loss Body Page 1 PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppt L-80 Well: CD 1-10 Body Wall: 0.271 in Field: Alpine Upset Wall: 0.271 in Company: ConocoPhillips Nominal 1.0.: 3.958 in Country: USA Survey Date: March 6, 2004 I Joint ! Depth Pen. Pen. Pen. Metal Min. I Damage Profile ! No. (Ft.) Upset Body % Loss 1.0. Comments (%wall) (Ins.) (Ins.) % (Ins.) 0 50 100 48 2075 0 0.01 5 1 3.91 r 49 2119 0 0.03 10 2 3.84 50 2159 0 0.03 9 2 3.89 51 2203 0 0.03 11 1 3.91 52 2247 0 0.02 9 1 3.92 53 2288 0 0.03 10 1 3.88 54 2330 0 0.04 13 1 3.91 Shallow pitting. 55 2372 0 0.02 9 2 3.90 56 2416 0 0.03 13 1 3.84 Shallow pitting. 57 2459 0 0.02 9 1 3.89 It. Deposits. 58 2501 0 0.02 8 1 3.89 59 2547 0 0.03 10 1 3.88 60 2588 0 0.02 9 1 3.89 61 2632 0 0.02 8 1 3.90 ~62 ~ 2673 0 0.03 10 1 3.87 I 63 2718 0 0.03 10 2 3.85 I 64 2760 0 0.02 8 1 3.91 65 2804 0 0.02 9 1 3.89 66 2848 0 0.02 8 1 3.88 67 2892 0 0.04 15 2 3.90 Shallow pitting. 68 2936 0 0.03 11 2 3.85 69 2977 0 0.02 8 1 3.91 70 3021 0 0.03 10 I 3.89 71 3064 0 0.03 11 2 3.90 72 3109 0 0.03 9 2 3.90 73 3153 0 0.02 6 1 3.91 74 3197 0 0.03 10 2 3.91 75 3241 0 0.02 8 1 3.91 76 3285 0 0.03 11 2 3.90 77 3329 0 0.02 9 -- 2 3.89 78 3372 0 0.03 12 1 3.91 Shallow pitting. 79 3416 0 0.02 I 9 1 3.89 80 3459 0 0.02 9 1 3.91 81 3503 0 0.03 10 1 3.87 81.1 3547 0 0.02 8 1 3.88 PUP 81.2 3556 0 0 0 0 N/A GlM 1 (Latch @ 10:30) 81.3 3563 0 0.01 4 I 3.89 PUP 82 3573 0 0.01 4 2 3.87 83 3617 0 0.02 9 2 3.83 Deposits. 84 3657 0 0.03 10 2 3.90 85 3701 0 0.03 10 1 3.90 86 3745 0 0.02 9 1 3.88 87 3787 0 0.03 10 1 3.88 88 3830 0 0.03 13 1 3.89 Shaliow pitting. 89 3875 0 0.02 9 1 3.89 90 3919 0 0.01 4 1 3.89 91 3963 0 0.03 10 1 3.88 92 4007 0 0.02 8 2 3.89 93 4050 0 0:02 9 2 3.88 94 4095 0 0.01 5 1 3.89 I Penetration Body Metal loss Body Page 2 PDS REPORT JOINT TABULATION SHEET Pipe: 45 in 12.6 ppf L-80 Well: CD 1-10 Body Wall: 0.271 in Field: Alpine Upset Wall: 0.271 in Company: ConocoPhìllips ì>Jominal I.D.: 3.958 in Country: USA Survey Date: March 6, 2004 joint Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body 'Yo Loss !.D. Comments (%wall) (Ins.) (Ins.) % (Ins.) 0 50 100 95 4139 0 0.02 9 1 3.85 96 4183 0 0.03 12 I 3.87 Shailow pitting. 97 4227 0 0.01 4 1 3.87 98 4271 0 0.02 8 2 3.90 99 4315 0 0.03 11 1 3.86 100 4356 0 0.03 10 1 3.87 101 4400 0 0.01 3 1 3.89 102 4444 0 0.02 8 1 3.89 103 4488 0 0.01 4 1 3.91 104 4532 0 0.03 to 1 3.89 105 4576 0 0.03 9 2 3.83 to6 4619 0 0.03 to 1 3.87 to7 4663 0 0.02 8 1 3.89 to8 4707 0 0.02 9 1 3.89 to9 4751 0 0.03 1 1 2 3.90 lto 4795 0 0.03 to 3 3.89 ~Jl 4839 0 0.04 14 1 3.88 Shallow pitting. 112 4879 0 0.02 8 1 3.82 113 4922 0 0.02 8 1 3.88 114 4966 0 0.03 10 1 3.88 115 50to 0 0.04 13 1 3.84 Shallow pitting. 116 5051 0 0.03 12 2 3.88 Shallow pitting. 117 5092 0 0.04 17 3.88 Shallow pitting. 118 5136 0 0.02 9 1 3.83 119 5178 0 0.01 4 2 3.88 120 5219 0 0.02 9 3 3.88 121 5260 0 0.02 8 1 3.89 122 5301 0 0.01 4 1 3.89 123 5343 0 0.01 5 1 3.88 1 124 5384 0 0.01 4 1 3.86 125 5425 0 0.03 11 2 3.89 126 5469 0 0.03 13 1 3.84 Shallow pitting. 127 5512 0 0.03 to 2 3.88 128 5556 0 0.03 to 1 3.89 128.1 5600 0 0.01 5 3 3.89 PUP i 128.2 5608 0 0 0 0 N/A GLM 2 (Latch @ 5:00) 128.3 5616 0 0.03 10 2 3.81 PUP Lt. Deposits. 129 5626 0 0.01 4 2 3.76 Lt. Deposits. 130 5665 0 0.02 9 1 3.87 111 5707 0 0.01 5 1 3.89 132 5748 0 0.01 3 1 3.88 133 5787 0 0.01 6 1 3.86 134 5828 0 0.01 5 1 3.86 î35 5870 0 0.01 3 1 3.88 136 5911 0 0.02 6 2 3.89 137 5953 0 0.02 9 1 3.88 138 5994 0 0.01 3 1 3.86 139 6035 0 0.02 9 2 3.86 140 6077 0 0.02 8 1 3.88 141 6118 0 0.01 4 1 3.82 I Penetration Body Metal Loss Body Page 3 Pipe: BQqy Wall: Upset Wall: NominaII.D.: Joint No. 142 143 144 145 146 147 148 149 150 151 152 153 ~~ 154- 155 156 157 158 159 160 161 I 162 163 164 165 166 167 168 169 169.1 169.2 169.3 170 171 171.1 172 172.1 172.2 172.3 173 __174 174.1 ~.1 74.2 174.3 PDS REPORTjOINT TABULATION SHEET 4.5 in 12.6 ppf L-BO 0.271 in 0.271 in 3.958 in Depth (Ft.) 6160 6201 6244 6287 6330 6374 6417 6461 6505 6549 6593 6637 . ~..§Q.~ 6724 6768 6812 6855 6899 6943 6987 7031 7073 7117 7161 7204 724S 7291 7332 7376 7385 7393 7403 7448 7490 7491 7534 7544 7548 7557 7589 7617 7622 7631 Pen. Upset (Ins.) 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0.02 0.02 a 0.03 0 Pen. Body (Ins.) 0.02 6 0.02 8 0.02 8 0.02 9 0.02 8 0.02 8 0.02 9 0.Q3 10 0.02 8 0.02 9 0.03 12 0.03 10 O.Q;L 10 0.03 10 0.04 14 0.03 12 0.03 10 0.03 11 0.03 13 0.03 10 0.03 11 0.03 10 0.03 11 0.04 14 0.04 14 OJJ3 10 0.03 13 0.04 15 0.03 10 0 0 0.03 11 0.04 15 0.04 15 0 0 0.06 23 0.04 15 0 0 0.04 15 0.05 19 0.04 15 0 0 0.05 18 0 0 Pen. Metal % loss % 1 2 1 2 2 3 3 2 2 2 2 1 2 3 Min. I.D. (Ins.) 3.SS 3.83 3.89 3.89 3.86 3.85 3.86 3.89 3.87 3.86 3.89 3.88 3.86 3.87 3.87 3.85 3.87 3.87 3.86 3.87 3.82 3.86 3.84 3.83 3.85 3.S? 3.86 3.83 3.83 N/A 3.83 3.85 3.83 3.81 3.81 3.81 3.88 3.78 3.79 3.75 3.73 3.71 N/A ') L 3 2 2 2 2 3 3 3 3 3 2 4 3 3 0 4 4 4 0 4 4 0 5 6 1 0 0 0 Well: Field: Company: Country: Survey Date: CD 1-10 Alpine ConocoPhillips USA March 6, 2004 Comments Shallow pitting. Shallow pitting. Shallow pitting. Lt. Deposits. Shallow pitting. Shallow pitting. Shallow pitting. Shallow pitting. Shallow pitting. Shallow pitting. PUP GLM 3 (Latch @ 1 :00) PUP Lt. Deposits. Shailow pitting. Shallow pitting. Lt. Deposits. X NIP Line corrosion. Lt. Deposits. PUP Shallow pitting. PACKER PUP Line shallow corrosion. Lt. Deposits. Shallow corrosion. Lt. Deposits. Line shallow corrQsion. Lt. Deposits. XN NIP PUP Line shallow corrosion. Deposits. WLEG Page 4 Damage Profile I (%wall) 0 50 100 I Penetration Body Metal Loss Body PDS Report Cross Sections Well: Field: Company: Country: ~ubing: Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: March 6, 2004 MFC 40 No. 00432 2.75 40 M. Lawrence CD 1-10 Alpine ConocoPhillips USA 4.5 ins 12.6 ppf L-80 Cross Section for Joint 172 at depth 7495.65 ft Tool speed = 62 NominallD = 3.958 Nominal OD = 4.500 Remaining wall area = 97 'Va Tool deviation = 21 Q Finger 24 Penetration = 0.062 ins Line Corrosion 0.06 ins = 23% Wall Penetration HIGH SIDE = UP Cross Sections page 1 PDS.Report Cross.Sections Well: Field: Company: Country: Tubing: CD 1-10 Alpine ConocoPhillips USA 4.5 ins 12.6 ppf L-80 Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: Marc:h6, 2004 MFC 40 No. 00432 2.75 40 M. Lawrence CrossSectíon for joint 174.2 at depth 7630.4 it Tool sþeed"=72 NominallD '" 3.958 Nominal OD = 4.500 Remaining wall = 100 % Tool deviation 0 Finger 25 Projection = -0.21 ins Deposits Minimum I.D. "= 3.71 ins HIGH SIDE = UP Cross Sections page 2 PDS REPORT JOINT TABULATION SHEET Pipe: Body Wall: Upset Wall: Nominall.D.: 7. in 26.0 ppt L-BO 0.362 in 0.362 in 6.276 in Well: Field: Company: Country: Survey Date: CD 1-10 Alpine ConocoPhillips USA March 6, 2004 Joint Depth Pen. Pen. Pen. Metal Min. No. (Ft.) Upset Body % Loss 1.0. Comments (Ins.) (Ins.) % (Ins.) 1 7632 0.10 0.13 36 6 5.70 Corrosion. Deposits. 2 7662 0.02 0.02 6 6 I 5.36 Deposits. 3 7703 0.05 0.03 8 0 5.39 Deposits. Damage Profile (%wall) 0 50 100 IIIIIII I Penetration Body Metal Loss Body Page 1 PDS Report Cross Sections Well: Field: Company: Country: Tubing: CD 1-10 Alpine ConocoPhillips USA 7 ins 26 ppf L-80 Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: March 6, 2004 MFC 40 No. 00432 2.75 40 M. Lawrence Cross Section for Joint 1 at depth 7640.81 ft Tool speed = 71 Nominal ID = 6.276 Nominal OD = 7.000 Remaining wall area = 95 (Yo Tool deviation = 30 0 Finger 20 Penetration = 0.131 ins Corrosion 0.13 ins = 36% Wall Penetration HIGH SIDE = UP Cross Sections page 1 We]]: Field: Company: Country: Tubing: CD 1-10 Alpine ConocoPhillips USA 7 ins 26 ppf L-80 Cross Section for joint 2 at depth 7665.5 ft Tool speed = 69 NominallD = 6.276 Nominal OD = 7.000 Remaining wall area = 98 % Tool deviation = 39 0 PDS Report Cross Sections Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: March 6, 2004 MFC 40 No. 00432 2.75 40 M. Lawrence Finger 19 Projection = -0.876 ins Deposits Minimurn I.D. = 5.36 ins HIGH SIDE = UP Cross Sections page 2 PDS Report Cross Sections Well: Field: Company: Country: Tubing: CD 1-10 Alpine ConocoPhillips USA 7 ins 26 ppf L-80 Survey Date: Tool Type: Tool Size: No. of Fingers: Analyst: March 61 2004 MFC 40 No. 00432 2.75 40 M. Lawrence Cross Section for Joint 3 at depth 7703.93ß ft Tool spl3ed =.11 Nominal 10= 6.276 Upset 00 = 7.000 Remainingwall area = 100 'Yo In upset region Tool deviation = 37 0 Finger 5 Projection = -0.621 ins Deposits Minimum 1.0. = 5..39 ins HIGH SIDE = UP Cross Sections page 3 PHilliPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 003.812) Ga5Uít \IandreiNaivE 1{35ß3564, 00:5.984) Gas uft mdnJlDummy Valve 2 (5613<5614, 005984) Gas Uti mdrellDummy Valve 3 I=Q7~Q() \,~~,~~, 00:5.984) NIP (7492-7493, 005.000) PKR (7546-7547, 005970) NIP (7622-7623, 00:5.000) \I\ILEG (7633-76J4, 00:5.000) nn~n / c"vu- CASING (0-7900. 00:7000, \1\11:26.00) API: 501032035300 WRDP Annular Fluid: Reference Log: Last Tag: SURFCASING PROD CASING OPEN HOLE ALPINE CD1..10 PROD Orig 12/9/2000 Completion: Last WIG: Ref Log Date: TD: 11693ftKB 93 8059 Angle @ TS: deg @ Angle @ TD: 90 deg @ 1 Rev Reason: GLV LastUpdate: 5/2/2001 Max Size Top Bottom TVD Wt Grade 16.000 0 114 114 62.58 H-40 WELDED 9.625 0 2422 2389 36.00 J-55 BTC-MOD 7.000 0 7909 6939 26.00 L-80 BTCM 6.125 7909 11693 11693 0.00 Bottom TVD Wt Grade Thread 7633 6871 12.60 L-80 iBTM Man V Mfr V Type VOD Latch Port TRO Mfr Type 1 3563 3386 CAMCO KBG-2 CAMCO OV 1.0 BK 0.250 0 2 5613 5194 CAMCO KBG-2 CAMCO DMY 1.0 BK 0.000 0 3 7389 6734 CAMCO KBG-2 CAMCO DMY 1.0 BK 0.000 0 1719 1719 7492 7546 7622 7633 6829 6866 6871 Date Vlv Run Cmnt 12/15/200C 12/8/2000 3/24/2001 Description CAMCO BAL-O LANDING NIPPLE CAMCO WRDP-2 (HSS-242) SET 8/8/2002 HES 'X' NIPPLE BAKER 4.5 xl" 'S-3' PACKER HES 'XN' NIPPLE BAKER WIRELINE ENTRY GUIDE ID 3.812 2.125 3.813 3.875 3.725 3.875 c:tJ I -/0 ( AnnY.!!Ll!!jection Permit Required Documents: ef 9-5/8" Casing Detail Fi/' 9-5/8" Cementing Details !J' Daily Drilling Report from Surface casing cement job g 9-5/8" Initial Casing Shoe Test ¡r' 7" Casing Detail ~7" Cementing Details ¡¡(" Daily Drilling Report from Intermediate casing cement job ~ Formation Adequacy for Annular Injection Test é"" r.~'""""""-".. JAN 11 (;) ?OO'¡ ....1 . ,::~¡',"u~.,.: I' j i) t. ~' .;,..IJ..iI""'~""'I""'.'L...,. -,- ..;;.<'"..,. ......... ..-.~ ~.' 800-- l1-l ( Casing Detail 9 5/8/1 Surface Casino ( Well: CD1-10 Date: 11128/00 ; .PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.60 FMC Gen V Hanger 2.31 36.60 Jts 3 to 57 55 Jts 9-5/811 36# J-55 BTC Csg 2299.57 38.91 Davis Lynch Float Collar 1.55 2338.48 Jts 1 to 2 2 Jts 9-5/811 36# J-55 BTC Csg 80.12 2340.03 Davis Lynch Float Shoe 1.73 2420.15 2421.88 TD 12 1/411 Surface Hole 2430.00 RUN TOTAL 33 BOWSPRING CENTRALIZERS - 1 per jt on Jt #1 - #12 (On stop rings of Jt #1, #2 & #3) and over collars on jts.14,16,18,20,22,24,26,28,30 l 32,34,36,38,40,42,44,46,48,50,52,54. Use Best-a-Life 2000 pipe dope Remarks: Up Wt - 155k On Wt - 150k Block Wt - 75k Supervisor: David Burley ( ~PHILLIPS Alaska, Inc. ~ A Slbsidiary of PHILLIPS PETROLELM COMPANY if CASING TALLY WELL NUMBER: TUBING DESCRIPTION: DATE: CD1-10 9 5/8'" 36# L-80 BTC 11/28/00 PAGE: RIG: 1 of 2 Doyon 19 Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 1 :~::::¡~:ig~"j¡Ij 26 42,e.9 5 1 I 41 .83 76 101 126 151 176 I 2 :¡::::¡¡::If~g¡¡¡j:¡¡ 27 40,91 52 ::::¡:::¡i.j~~M:f¡¡: 77 102 127 152 177 3 :¡::¡Ilj~I~:¡¡:¡: 28 ¡:¡:j::IIJil::¡:}: 53 42.22 78 103 128 153 178 4 :~::¡¡j¡¡¡I~ij;l¡¡¡::¡: 29 42.35 54 ¡::¡¡:::¡ig~gl¡:¡:::¡ 79 104 129 154 179 5 ~1¡¡¡1¡¡¡1~~~1¡¡~:::1:¡ 30 ~¡I1::¡¡I~:I~:::¡I: 55 42,56 80 105 130 155 180 6 ~tti.jPU?~¡~¡ 31 42.29 56 39,18 81 106 131 156 181 ":':':':',' ,', ,~, ,',' ,':':':' ,',',',',',',',',',',',',',',',',',',',' 7 ;¡~¡¡¡¡¡¡ii~~ji¡¡¡¡¡¡¡ 32 I¡¡¡¡¡:¡IIIII:: 57 36,41 82 107 132 157 182 ::::::'::':"" ,~:,;:",,::::::,: ,..'.."............', 8 IIiiJit~¡:¡~¡~ 33 41 .83 58 42-:48 83 108 133 158 183 9 :¡:~tig~,jfj¡! 34 ¡::::¡¡¡~¡1~~1j:~¡¡::¡¡:: 59 ~ 84 109 134 159 184 10 :¡:j:m:i.i~j¡1tm:¡ 35 42,67 60 ~ 85 1 10 135 160 185 ,',',',',',',',',',',','....,',',',',',' 1 1 ¡~:::Iij~~:i¡¡¡j:¡:¡ 36 ~:¡¡::¡::Mi~jM1::¡:::¡ 61 ~ 86 1 1 1 136 161 186 12 :¡::¡¡~¡:i~~j~~¡:¡:¡:¡ 37 42.85 62 42-:38 87 1 12 137 162 187 13 42.80 38 :¡~:::¡::¡¡I~~iI¡¡::~¡ 63 42-:-84 88 1 13 138 163 188 14 ¡¡::¡¡~¡:¡i¡~i~¡::¡¡¡:: 39 42.32 64 44-;94 89 1 14 139 164 189 15 42.30 40 ::::¡¡::¡¡jl~~j::::¡I: 65 ~ 90 1 15 140 165 1 90 16 ¡ttiIi~~H¡¡:¡t 41 42.47 66 42;7é 91 1 16 141 166 191 ,','"",',',',',',',',',',',',',',',',' 17 42.63 42 ¡:::I¡¡j~~~:I~I::¡¡¡ 67 4&G8 92 1 17 142 167 192 1 8 ¡¡{tiåijá¡~¡~¡¡¡ 43 42.71 68 ~ 93 1 18 143 168 1 93 :':':':';',', '~" :':':':' ,',',',',',',',',',',',',',',',',',',',' 1 9 42.06 44 ¡:¡¡¡:I:~i~~I¡:¡::: 69 94 1 19 144 169 194 20 ¡:¡¡¡::¡¡ii¡¡I+:~:~:¡: 45 42.18 70 95 120 145 170 195 ::::~:¡::;:""",:~:",:::,,:::::¡::: 21 42.00 46 ¡:¡:~¡:¡~¡¡~~~iji::I¡¡j: 71 96 121 146 171 196 22 ¡::::¡¡::i~~I::::¡¡j¡ 47 42,31 72 97 122 147 172 1 97 23 42.01 48 ~¡¡:¡:¡:Mi~:ii¡:¡¡¡:¡¡¡: 73 98 123 148 173 198 24 !¡:::::¡:ii~~j,:::I¡ 49 42,80 74 99 124 149 174 199 25 42.29 50 ::¡:¡::I~i~~#¡::¡¡::::: 75 100 125 150 175 200 Tot 1033.55 Tot 1063,71 Tot 751,27 Tot Tot Tot Tot Tot TOTAL LENGTH THIS PAGE = 2848,53 DIRECTIONS: TOTAL JOINTS THIS PAGE = 68 FLOAT SHOE 1,73 FLOAT COLLAR 1,55 HANGER 2,31 RKB 36,6 Shaded cells indicate centralizer placement. ( It Phillips Alaska Drilling Cementing Details Well Name: CD1.10 Report Date: 11/2812000 Report Number: 3 Rig Name: Doyon 19 AFC No.: 998C16 Field: Alpine Casing Size Hole Diameter: Angle thN KRU: Shoe Depth: lC Depth: % washout: 9-518 12.1/4 na 2422 2339 Centnllizers State type used. intervals covered and spacing Comments: Ran centralizers 1 per Joint on Joints # 1.12, and every other Joint on ifs 14-54 for a total of 33 centralizers. 12.1/4" X 9-518" Bowsprtngs Mud Weight: PV(prtor cond): PV(after cond): VP(prtor cond): VP(after cond): Comments: 9.8 PPG 19 15 57 11 Gels before: Gels after: Total Volume Circulated: 60/88/94 4/23/27 980 BBlS Wash 0 Type: Volume: Weight: Comments: Water 40 BBlS 8.4 Blozan wI Nutplug Marker Spacer 0 Type: Volume: Weight: Comments: ARCO 845 50 BBlS 10.5 PPG lead Cement 0 Type: Mix wtr temp: No. of Sacks: Weight: Yield: Comments: AS III LIte 70 384 10.7 PPG 4.44 Additives: 30% DO53, 0.6% D046, 1.5.~ D079, 1.5% 5001,50% D124, 9% BWOW DO44. Tall Cement 0 Type: Mix wtr temp: No, of Sacks: Weight: Yield: Comments: G 70 231 15.8 PPG 1.17 Additives: 0.2% D046, 0.3% D065, 1.0% 5001. Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. WI. Up: Comments: 10 BPM 8.10 BPM 155 Reciprocation length: Reciprocation speed: Str. Wt. Down: 25' 20 FPM 150 Theoretical Displacement: Actual Displacement: Str. WI. In mud: 180.8 BBlS 180.8 BBlS Calculated top of cement: CP: Bumped plug: Floats held: Surface Date:11/28/00 V Y Time:1222 hrs Remarks:Staged pump rate up to 10 BPM and cond mud. Mixed and pumped lead cement @ 7.9 BPM, tall @ 5 bpm. Reciprocated pipe untllliast 30 bbls of displacement, had 110 bbls of 10.7 PPG cement returns to surface, full returns throughout. Cement Company: Rig Contractor: Approved By: Dowell DOYON David Burley ( AFC No. 998C1e Date 11/28/2000 Phillips Alaska Drilling RptNo 3 ( Daily Drilling Report Rig Accept. hrs Days Since AccepUEst: 2.2 / 2.5 11/27/200008:30:00 PM Well: CD1-10 Depth (MDfTVD) Con~ctor:[H)YON Dally Cost $ 290730 Rig Name: Doyon 19 Last Csg: 90518" @ 2422' Operation At 0600: RIH w/ BHA #2. Upcoming Operations: Test casing, clean out cement, LOT, Change over, Drill ahead. ~(W;' MUD DATA MUD TYPE LSND WEIGHT 9.5ppg VISCOSITY 44sqc DRiLUNG DATA DEPTH BIT NO, 1 ROTWT PUWT PVIYP 8/14 GELS 7/9/10 APIWL 8.0 HTHP WL ml130 mln SOLIDS 5.0% HOLE VOLUME 176bbl MBT 14 ph 9.0 LGS 4.8% SOWT AVG DRAG MAX DRAG TRO BTM TRO OFF PUMP PRES 1750 11950 I I PUMP NO 11211 LINER SZ 5.51ell SPM 1 7317411 PIT VOL 250 GPM2 558111 CAlLY MUD $7098 SPS 1 "' TOTAL MUD $11485 COMPANY MI SPP1 III MUD WT III 08:00 AM 10:30 AM 10:30 AM 12:30 PM 12:30 PM 02:30 PM 02:30 PM 07:00 PM 07:00 PM 12:00 AM 24.00 SIZE 12-1/4 MAKE HTC TYPE MXC1 SERIAL NO L97DJ DEPTH OUT 2430 DEPTH IN 114 FOOTAGE 2316 ADT/AST 11.5/3.4 WOB2 15 - 30 RPM1 155.235 TFA 0.546 BIT DATA BIT NO, SIZE MAKE TYPE SERIAL NO DEPTH OUT DEPTH IN FOOTAGE ADT/AST 1 WOB2 - RPM 1 - TFA JETS JETS 101121121181111111 BIT COST DULL 2141RGIG GRADE E 1 SD TD BIT COST DULL III GRADE III ,::~OI'"SCODE'" iI::,~ ',8,PLE\,sECT,' GIRt SURF TRIP_OUT SURF BHA SURF RUN_COMP SURF 2.50 CIRC SERVICE PERSONNEL TOTAL 49 'B,I'IA~DESCR'eTJQN'ii\¡:\'4~'<i~~: ¡" ':',',c I BIT/M1 XL@1.2INMSTAB/NMPONY/MWD/N MST AB/3NMCSDC'S/XO/3HWDP/JARS/26HWDP ,:> ;;~~J:!,i~~;:,r ::";":),~i;4-::-~ŸfKk:~~e':,*H~:\~":;'./('J',:i~..;¡:,,;~~~,;,, ,f: :~"DRIl:CBIP-l=:,QAT: i:;} '\' '~>:,,;j:;,¡;i¡);¡,':\!:4il;:(':,:::r,,;'.:~Ziif.':' M.g3:g;;¡;:\\?~ BHA NO 2 "OD, ' , ,ID.. ,WEIGHT GRADE, CONNECTION" CLASS 2, ',;L;~NGTH,' BHA LENGTH 1073.82 5 II 4.281 19.5 G105 4.1/2 I.F. DATE LAST INSPECTED: HOURS ON JARS: 12.5 ~:)i£.r,MEi.i?rH¡i'~J:.I\ID,'FU ~:,..:~ "HOURS:",'.' 12:00 AM 12:30 AM 0.50 12:30 AM 02:00 AM 1.50 02:00 AM 03:30 AM 1.50 03:30'AM 08:00 AM 4.50 2.00 CMT_CSG 2.00 OTHER 4.50 NU_ND BOPE 5.00 Daily Drilling Report: CD1-10 11/28/2000 SURF SURF SURF SURF SURF 2430/2397 Prey Depth MD: 2430 Cum Cost $ 492832 Next Csg: 7" @ 7932' EH&S ACCIDENT (non-spill) N EMPLOYER SPILL N TYPE VOLUME (gallons) LAST SAFETY MTG 11/28/2000 , ,~ , " , ' ,,' " .' , , :' ',.INJÊëj¡:ON INJECTION WELL CD1-42 SOURCE WELL CD1-10 RATE (bpm) 4.0 PRESSURE (psi) 1200 INJECTION FLUIDS Water Base Muds 1570 Brine 250 Cement 120 Diesel 20 ~ TOTAL VOL.(bbl) 1960, i TOT FOR WELL (bbl) 25979 '.IPI:IASEOPS Making Hole Making Hole Making Hole Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Rig Relase - hrs: Progress: 0 Est Cost To Date $ 551006 Shoe Test: DRILLS/BOP., DATA LAST BOPiDIVERT LAST BOP/DRILL TST 11/23/2000 11/2312000 LAST H2S DRILL 11/20/2000 LAST CONFINED SPACE LAST FIRE DRILL 11/15/2000 LAST SPILL DRILL 11/20/2000 ,,>,<,~::::,:': "", ,':FUEI+':'~~T:~,~;:~:~';i:i':~:;};;~i~~[':\ FUEL USED 3957 DRILL WATER USED- eelS , , POTABLE WATER '.:,.'::' USED - BBLS :',:'>::' ::::;~:','::;: ': ~E~~Trr~'t~~+Å:,;:t'..:..',.~:'t./,:tfti,' TEMP of ~ 1275 105 WIND SPEED 4 WIND DIRECTION 270° CHILL FACTOR of -9.00 PHILLIPS PERSONNEL 1 CONTRACTOR PERSONNEL 26 MISC PERSONNEL 5 17 ':"" ~'I'i ':,:;"',,:<,,,::,/oeERA..TloNS:FR,OM 0000 -,OOPP';"":';" '::":\;,;,;:~'¡'i', Clrc hole clean. monitor well, static, POH, no problems, max overpull 25k. Lay down BHA and clear tools from floor. PJSM. RU and run 57 Joints of 9.5/8" casing. Cond mud, LD fill tool, MU cement head and continue to cond mud. PJSM. Test lines to 2500 psi. pumped 40 bbls vls'd FW w/nutplug for marker and 50 bbls of 10.5 ppg spacer. Cemented casing with 384 sxs of led and 231 sxs of tall slurry. Dlsp. wI 20 bbls FW and 160.8 bbls of mud, bumped plugs. floats held. Full returns throughout with 110 bbls of 10.7 ppg cement returns to surface. CIP @ 1222 hrs. Flush surface equipment, LD LJ and change running tools to 5". MU wash tool and wash annular preventor and riser. ND Dlvertor system. Install and test casing head to 1000 psi. NU BOPE. Install test plug Test BOPE to 250/3500 psi annular 250/2500. John Spalding (AOGCC) waived witnessing test. Page 1 CASING .~3T and FORMATION INTEGRITY TEST Well Name: CD1-10 11/29/00 Supervisor: D. Burley Date: Reason(s) for test: 0 Initial Casing Shoe Test 0 Formation Adequacy for Annular Injection 0 Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9 5/8", 36#, J-55, BTC CSG Casing Setting Depth: Hole Depth: 2,450' TMD 2,416' TVD 2,422' TMD 2,390' TVD Mud Weight: 9.6 ppg 28' Length of Open Hole Section: EMW= = Leak-off Press. + Mud Weight 0.052 x TVD 780 psi 0,052 x 2,390' ,/ EMW for open hole section = 15.9 ppg + 9.6 ppg Used cement unit Ria pump used Pump output = 0.0997 bps 2,800 psi 2,600 psi 2.400 psi 2,200 psi 2,000 psi 1,800 psi w 1,600 psi eo:: ::> ~ 1.400 psi w g: 1.200 psi 1.000 psi 800 psi 600 psi 400 psi 200 psi 0 psi 0 NO #2 Ruid Pumped = 1.6 bbls Fluid Bled Back = 1.3 bbls --- LEAK-OFF TEST ~CASING TEST ~'- LOT SHUT IN TIME ~ CASING TEST SHUT IN TIME -+- TIME LINE >;i""'X""'t~~<'}o""""f7,t""'i~ 10 20 30 STROKES 40 50 NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above Modified by Scott Reynolds LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE í - --- --- - ---- - - i --- ----- - - - - - - - ¡- ----------:-- - -- i : : 0 : 0 pSI : '- --------------~ u_-----------.....---------------, I I I . I : : 1.0 : 10 pSI: :-----------------I---------------i-----------------f : : 2.0 : 20 psi: :-----_u_-----I- ---------------i--_u ------------f : : 3.0 : 40 psi: :- --- - - - --- -- u- - 4- - -- -- - ----- - - - -{- - ------ --- -- -- - -f : : 4.0 : 70 psi: :-----------_u_-~------------~------------_u-t ¡ ¡ 5.0 ! 110 psi! ,..--------------..------------.,..----------------, ! I 6.0 ! 180 psi! ,..- --_u - u_-----..------------ u.,..---------------, ¡ ¡ 7.0 ! 240 psi I 0- - - -- - - - - - u u_-.. -- --- - ----- - - -..------- - ---- - -- - - 0 ¡ ¡ 8.0 ¡ 320 psi ¡ 0- -- - - - - -- --- - -- -.. ---- -- - --- -- - - - ..-------- - ------- -. ! ¡ 9.0 ¡ 390 psi ¡ ... -- --- - -- - - - - -- - .--- - - -- --- --- ---------- -- ---- ---0 ! ! 10.0 ! 460 psi! "'--_u- _u u _u_.u_-----------",,----------------o ¡ ! 11.0 ! 530 psi ¡ '----------------~---------------"""---------------' I I I . I : : 12.0 : 600 pSI: '- -- --- -- - - - - - - - -~ -- ---- - --------.... ---- - - -- ------- -, I , , . I : : 13.0 : 650 pSI: :--_u_----------I---------------'i-----------------t : : 14.0 : 695 psi: :- ------ - - - --- ----I - - -- - -- - ----- - -i- --- - - ------ -----f : : 15.0 : 740 psi: :- ---------------4 -------------~-----------------f : : 16.0 : 780 psi: :---------------4--------------~----------------. I , , I I I I I I I I I ,..------ - --------.,--------------.,..----------------, I I I I I I , I , I I I r---------------..-----------_u....--------- - - -----, I , , I I I , I , , I I 0- -- --- -- - - --- ---.. ------- - - -- -- - -..- - ---- - ---- ----- - 0 , , I I , , , I I I I I ...---_u_--------.---------------..----------------o I , , , I . I I I , . . "'u_-_u_-------.----------------------------_u+ , , , . I , I I I , I , I---------------~, _._n______.~__~_.nm___m____~ I , , , , , 60 I , : SHUT IN TIME I SHUT IN PRESSURE L.._-------------~--------------------------_u- . 0 0 .' , 780 . I : . mtn : : pSI: 1---------;----1---------------1-----_u_----;---1 I 1.0 mtn , I 650 pSI I :---- --------- --4 --- --- - - - - - - ---i-- - - - - - -- ------ f : 2.0 min : : 620 psi: :- -- - - -- - - ----- --4 ----- --- -- -~- - -- - - - --------- - f : 3.0 min : : 610 psi: :-- -- - - ----- - - ~ ---- -- -- -- - - -1- - -- -- ----- -----t ¡ 4.0 min ! ! 610 psi! ,..-------------- -.,---------------.,..--------------, ¡ 5.0 min ¡ ¡ 600 psi ¡ ,..---------------..---------------....----------------, I 6 0 . I I 590 . I : . mtn : : pSI: o-------------_u..-_u_----------..----------------o I 70 .. . 590 . I : . mtn : : pSI: o-------------_uof_u---------------------------o I 8 0 . I , 590 . . : . mln : : pSI: 0--- ---- - --- - - - --. -- - -- - ---- - - -- ---- ----- -- - -- --0 I 9 0 . I I 580 . I : . mtn : : pSI: 1----- -- ----- - -.. ---- -- - -- - ---- ~- -- -- ---- -- - - - --0 j 10.0 min j ! 580 psi ¡ '--- --------- ----~_u u_---------",- u_------ --- ----, GPHILLIPS AlaSKa, Inc, A Slbsidiary of PHILLIPS PETROLElt.1 COMPANY CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ¡------- --------j------ ----- ---õ----------- ;-----¡ : : 0 stks: 0 pSI : '------------ ----..--- ----- ---- ---..----------- -----.. I I I . I : : 2 stks : 50 pSI: '-- --------------t u_---- --- -----t- ----------- ----; ¡ : 4 stks : 230 psi: ,_--__-- ---------t-------- u - - --- t- -------_u- - - - -; ! : 6 stks : 440 psi: :- ---------------f-_u ------ ---- -f - ----- -- -- - ---- --I : : 8 stks : 680 psi: :- ------ -- -------t------------ -_of ------------ -- u 4 ! I 10 stks ¡ 900 psi! .------- -- -------.,---------------., -----------------. ! ! 12 stks ! 1 ,120 psi! ,..- --------- -----.,---------------.,----------- -----..., I I 14 stks ¡ 1,300 ps¡~~' ... ------ ------- --.,------------- --., -_u ---------- 1 ! 16 stks ¡ 1 ,500 PSI ... u_--- --------- + - -------------+ ----------------.. ! ¡ 18 stks ! 1 ,700 psi ¡ 0-------- ----- - - - +--------------+----------------.. ! ! 20 stks ! 1 ,920 psi ¡ ... ---- -----------..--------------- 0 u---------- -- --.. ! ! 22 stks ! 2,170 psi ¡ '-u_------------"---------------'----------------" ¡ ¡ 24 stks ¡ 2,420 psi! '----------------"--- ------------..- ---------------.. I , I . I : : 25 stks : 2,550 pSI: ;-- ------_u -- ---t------- --- -- - --t- --- ------------; I I I I 1- ------ -- - ------t---------- -- --- t - -- - -- - ----- - - - - ~ I I I I I I I I :----------- -- ---f--- - - -- - - - -----f---- -- -------- - --! I I I I I , I I :---- --- ---- -- ---f --- - - - - - -- -----f------ -- -- -------4 I I I , I I I I I I I I ...----- ----- -----.,----- --- ---- ---.,-- - u --- - - - - ----..., , I I I I I , . I I I I ,..- -------- uu --.,---- -- ---- -----.,------ -- ----- - --..., I I I I I I , I I I , I , I : SHUT IN TIME: SHUT IN PRESSURE O-------------of---------------"-----------------' ¡ 0.0 min ¡ ! 2,550 psi! ...--------------+---------------+- _u_- ----------.. ¡ 1.0 min ! ! 2,550 psi ¡ ...---------------+-------- -- --- --..-----------------+ ¡ 2.0 min ¡ ! 2,540 psi ¡ ...--------------..-------- - --- ---..----------------+ ¡ 3.0 min ! ! 2,530 ps""'" '-------------- --"-_u ------ ---- - ..------------- ¡ 4.0 min ¡ ¡ 2,530 P&. :----------------t---------------t----------------; : 5.0 min : : 2,530 psi: :---------------- t-- - - -- ---------t---- ---------- --; : 6.0 min : : 2,530 psi: :----------------f--- ----- - - -- ---+-----------------1 : 7.0 min : : 2,530 psi: -u_------------t---------------f----------------4 ¡ 8.0 min ! ! 2,520 psi! ,.. ------_u_--- -- .,---------------.,-- ----------_u_..., ¡ 9.0 min ! ¡ 2,520 psi ¡ ,..-----_u_-----.,-- ---------- ---.,------------- ---..., ! 10.0 min ! ¡ 2,520 psi ¡ ...---------------+ ----- ---------.,------ -------- --..., ! 15.0 min ! ¡ 2,510 psi ¡ 0---------------+---------- -----+-------------- --.. ! 20.0 min ¡ ¡ 2,500 psi ¡ 0---------- ------+-------- -- -----+---------------.. ! 25.0 min ! ¡ 2,490 psi ¡ ...---------------"---------------0-- ---_u_--- -----+ ¡ 30.0 min ! ¡ 2,490 psi! '------- - -- ------..-- ---- -- ----- --,----------------.. NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY rI' WJPf ( t , ; PHilliPS Alaska, Inc. m A Subsidiary of PHILLIPS PETROLEUM COMPANY Casing Detail 7" Intermediate Casina ~ \ Well: Date: CD1-10 '2/3/00 i j DEPTH VI. Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to LDS 34.20 FMC 1111 X T' Hanger 1.75 34.20 Jts 3 to 195 193 Jts 711 26# L-80 BTCM Csg 7787.03 35.95 711 Davis Lynch Float Collar 1.06 7822.98 Jts1to2 2 Jts T' 26# L-80 BTCM Csg 83.20 7824.04 711 Davis Lynch Float Shoe 1.38 7907.24 7908.62 Top of Alpine @ 7710' MD. 1 straight blade centralizer per jt #1 - #18 1 spiral blade centralizer every other jt #137 - #193 Total - 47 centralizers . ) - Joints #196 - #208 Use Best-a-Life 2000 pipe dape Remarks: Up Wt - 260k On Wt - 190k Supervisor: David Burley .PHILLIPS Alaska: inC. ~ A Subsidiary of PHILLIPS PETROLEUtv1 COMPANY \ CASING TALLY WELL NUMBER: TUBING DESCRIPTION: DATE: CD1-10 711, 26# L-80 BTCM 12/03/00 PAGE: RIG: 1 of 2 Doyon 19 Column 1 No Feet 1 41.44 2 41 ,76 3 38,84 4 38,11 5 41 .68 6 41.44 7 41 55 8 40.69 9 3935 10 11 41,72 41 ..4.5 12 13 14 15 1û 1 ¡" 40,74 40 ;'~1 40:55 41 68 41,45 41,6H 18 II t .39 40.';'2 19 20 2\ 22 40 ~'4 '10 ?9 40,-3U 23 frO ¡' 4 24 40 ~:? 25 Ii \ 4.~ Tot 1021,64 Tot Column 2 No Feet 26 41 "/1 41.74 27 28 41 15 29 4086 30 41 ~~(i 31 41 64 39,14 32 ,.,. .:.." 4'::' (¡f~ 34 4:: 7,) ~5 . ,. -" "..1 I -' ,. .. ",.~ .. " 3~~ 81 r'-' ~,. 41 ,6~'} ~;8 4:.~ ,'~ì "'C' .: .: ~J tm ~O 11:: e~1 ~1 ¡t, 1 1(" 4? 1" ,",.. .., .:. ",' ,~3 .1C:' ~'.: 44 4~:' 7~-:ì 4b ,~:~' 71 4fi /,:':' 4.1 47 ~:) 04 ~8 4" ., , "T'", ~,.. 49 :~:' :::i ::~' ," -. .." .~ I ~: I': 1014,24 Tot TOTAL LENGTH THIS PAGE = Column 3 No Feet 51 ~ì7 89 Column 4 No Feet 76 77 4016 41.44 " I:;~ 132 1003.43 Tot 1026,37 Tot Column 5 No Feet 101 4207 Column 6 No Feet 126 4 ~ 11 Column 7 No Feet 151 40.10 152 37,61 153 4.0,71 154 .~J,21 Column 8 No Feet 176 ~û,E¡8 r:.? ..c.. ~;8 48 38,78 78 41 69 102 103 4J 08 .1076 127 128 4073 4063 15~1 :,,9.71 177 <0.69 -,., ~., r:::1'1 .;... 3714 ~-:ìB 40 "7(4 I w 41,67 104 ,1~ 69 129 4070 40,72 156 41 25 4.0.45 178 3868 c.1~ ".. 55 3877 80 81 82 B~~ 41 41 10~ 106 ~-:ì9,64 3949 4:) 54 1~~O 1:,1 40 AI 157 158 4134 179 180 37,47 4072 57 ~'Ì3 36 4077 4089 40213 8~ 4(- € [¡ 107 IJß 4:) ï~:' 13? 110 ~, I 1~£' 4'()1~ 41 69 - 181 182 '°,69 ::,[l ~ß 11 85 42,f!2 1 ::-:.;. ,1] 6[¡ 1 ~;3 4,) :.::; 16G 161 40.13 ::0 85 18~~ S8.68 !:s: ~-:.~ l(i 86 41 49 11 Ü 11 1 112 4-:"\ ~;8 40 ì~~ ,..~ -.- -'.. I:~ 1~,4 ..~.) ~ 2 162 4~,99 4').12 184 185 N°, :-:: (~ .'... ". w la. iO ,.., t:,J 3£~ 58 87 es 4() :;:} 4 1 ~i:; 11 ~:I £: ::~ n H 1~,5 4058 1 ~13 1£;t1. ':.0 '7,1 ..... , I .. 18-3 187 ~1 65 ..... ..,'" "~}, , '" 61 4032 89 110 63 114 4'J,7! 13t) 40 ~71 165 40 I:' - -- r32 .:u 5(3 p.:) 4: 51 115 4) 7C 137 4070 1~E) 4:) Q,. 1BB "::H~~~ ,'"., ~h' 40 lO C'" ..1 4<:. 5G I {) .~:. ,'1 1:,e 41J,5B 1-:7 4 ~ .:~6 189 I.:; :29 64 ':':~),ï3 Ð? .1~~ 57 117 11 S ,., Q ..,. ,~_. ;:¿, ,.. ~ ,.." "'.. ., ...." ,. ,. 139 40 .46 158 4) 00 1 £:(:, ,., ...,., '~~ ," :::-. 1.2 œ~ 0-:: w.., I, 1 G8 1 H? ~ìß,51 1,~C ""~j 5~~ 1m;. 40.65 1 ~ 1 ," C'. -..., "'w',' I t:ù 1,0 02 .1~~ 41 911 . - ,..~ 'i'....' ¿o 12(; 40 ¡'O 1.11 4tQ,74 1,'C ~~5,OO - 1£:2 !.::',4~ ~... t, ,..., (:u ,"" 39 !) 1 ~¡5 4: 4'3 1?1 ~~::;, 1"1 142 3:) 1 ~~ 1 ¡'1 1~},81 .- 193 '-0,71, ~... ",'::' '-0,55 c'" .:~) 41 4:~ 122 ,... ,..c .~~') c..~ 143 t1û 7.1 172 t..J 02 H?11 ':3 1 G ,'0 41,82 ~~7 ,.." ... 1 .,~.~ I 12:~ 3,3 ,~4 1..1.1 145 4 ).ï~i , -,. ¡ ,. .: ,m,2;~ - 195 4 L:;U 71 41 l)4 !:'o8 112 ~:'2 .,. , I,::., ~~:- 2;;' 40,74 ,- 14~: 4054 17.; ,1 J 2'~ H;6 ~, 9 ..4H -,... . ,::.. 43m~ £:9 .1'~' ;:;..J ,...- , ,:~ ':: r'-' I" " .:. .~ 14:- 39.35 1':"'5 ::8,(:;;:' H.: 7 ~~9,ß~ .,.. I ..~ .10 72 1~ :,: ,~~~, ~ oJ 987.57 Tot 14~ ¡t, J f1E~ 1002.10 Tot ' :~CI . ..... '::':-', ¡" . . I ., .12 -1-1 1 ~¡~: '10 02 ' ",.. , :~:~ ., ..'" -: ,l..~'..' 8070.46 ,:;- , ~.., "I", ~.=-, '1'.., .,'" r,' ., .~..'.. ~~¡.~, :,,:.:.:. 1012.63 Tot .- 1002.48 DIRECTIONS: TOTAL JOINTS THIS PAGE = 200 FLOAT SHOE 1,38 FLOAT COLLAR 1.06 HANGER 1.75 RKB 34,56 Joints 196 thru 208 stay out. (13 left in shed) Shaded cells indicate positive standoff centralizer placement. (I PHILLIPS Alaska~ Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY { CASING TALLY WELL NUMBER: TUBING DESCRIPTION: DA TE: CD1-10 711, 26# L-80 BTCM 12/03/00 PAGE: RIG: 2 of 2 Doyon 19 Column 9 Column 10 Column 11 Column 12 Column 13 Column 14 Column 15 Column 16 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 201 a7:êé 226 251 276 301 326 351 376 202 39:éG 227 252 277 302 327 352 377 203 4G:-7G 228 253 278 303 328 353 378 204 ~ 229 254 279 304 329 354 379 205 ~ 230 255 280 305 330 355 380 206 4M4 231 256 281 306 331 356 381 207 ~ 232 257 282 307 332 357 382 208 a94+ 233 258 283 308 333 358 383 209 234 259 284 309 334 359 384 210 235 260 285 310 335 360 385 211 236 261 286 311 336 361 386 212 237 262 287 312 337 362 387 )213 238 263 288 313 338 363 388 214 239 264 289 314 339 364 389 215 240 265 290 315 340 365 390 216 241 266 291 316 341 366 391 217 242 267 292 317 342 367 392 218 243 268 293 318 343 368 393 219 244 269 294 319 344 369 394 220 245 270 295 320 345 370 395 221 246 271 296 321 346 371 396 222 247 272 297 322 347 372 397 223 248 273 298 323 348 373 398 224 249 274 299 324 349 374 399 225 250 275 300 325 350 375 400 Tot 318.14 Tot Tot Tot Tot Tot Tot Tot TOTAL LENGTH THIS PAGE = 318.14 TOTAL LENGTH = 8388,60 DIRECTIONS: TOTAL JOINTS THIS PAGE = 8.00 TOTAL JOINTS = 208,00 AVERAGE JT= 40,33 ( ( Ph11" AI k D 11" c r D t "I I IpS as a rI Ing ernen Ing e als Well Name: CD1-10 Report Date: 12/0312000 Report Number. 8 Ria Name: Dovon 19 AFC No,: 998C16 Field: Casing Size Hole Diameter: Angle thru KRU: Shoe Depth: LC Depth: % washout: 7" 8.5 7909 7823 Centralizers State type used, intervals covered and spacing Comments: (18) 8-318" X 7" straight blade positive standoff and (29) 8-318" X 7" spiral positive standoff centralizers. Mud Weight: PV(prior cond): PV(after cond): YP(prior cond): YP(after con d): Comments: 9,8 10 9 23 17 Gels before: Gels after. Total Volume Circulated: 11/13114 719/11 700 BBLS Wash 0 Type: Volume: Weight: 'Comments: ARCO Wash 20 8.4 $p¡lcer 0 Type: Volume: Weight: Comments: ARCO B45 50 12.5 PPG .Lead Cement 0 Type: Mix wtr temp: No. of Sacks: Weight: Yield: Comments: Additives: Tall Cement 0 Type: Mix wtr temp: No, of Sacks: Weight: Yield: Comments: G 70 128 15.8 1.15 Additives: 0.2% DO46, 0.25% D065, 0.25% D800, 0.18% D167 Displacement 0 Rate(before tail at shoe): Rate(tall around shoe): Str, WI. Up: Comments: 7.5 8.5 260 Reciprocation length: Reciprocation speed: Str. WI. Down: 30 15 190 Theoretical Displacement: Actual Displacement: Str, WI. in mud: 299.3 BBlS 299.3 BBLS Calculated top of cement: CP: Bumped plug: Floats held: 7210 Date:12/3I00 YES YES TIme:1530 hrs. Remarks: Reciprocated casing untllliast 20 bbls of displacement, bumped plugs to 1200 psi, 500 psi over final displacement pressure. Cement Company: Rig Contractor: Approved By: Dowell DOYON D. Burley ( AFC NO. 118C16 Phillips Alaska Drilling RptNo 8 WEIGHT 9.7000 VISCOSITY 40sqc PVNP 8/17 GELS 7 18/10 APIWL 5.5 HTHP WL 14mll3O min SOLIDS 8.0% HOLE VOLUME 279bbl MBT 17.5 ph 8.5 LGS 6.0% \ ! PIT VOL 10 DAILY MUD $3945 TOTAL MUD $69680 COMPANY MI Date 12/0312000 Depth (MDITVD) Dally Cost $ 269862 Last Csg: 905/8" (B¡ 2422' ;Dßla;,UNG~DATA "'."'. DEPTH BIT NO, ROT wr puwr SOWT AVG DRAG MAX DRAG TRQ BTM TRQ OFF PUMP PRES III PUMP NO 11211 LINER SZ 5.51611 SPM 1 III GPM2 III SPS 1 30140130140 SPP 1 III MUD wr III SIZE MAKE TYPE SERIAL NO DEPTH OUT DEPTH IN FOOTAGE ADTIAST I WOB2 - RPM 1 . TFA JETS 11111 BIT COST DULL III GRADE III )'- ( Daily Drilling Report Rig Accept - hrs Dsys Since AccepVEst: 7.2 I 8.5 11/261200008:30:00 PM Rig Relsse - hrs: 7919/6940 Prev Depth MD: 7919 Cum Cost $ 1288828 Next Csg: 7" @ 7932' . ,." '8ITD~IA" BIT NO, SIZE MAKE TYPE SERIAL NO DEPTH OUT DEPTH IN FOOTAGE ADTIAST I WOB2 - RPM 1 - TFA JETS IIIII BIT COST DULL III GRADE III Progress: 0 Est Cost To Date $ 1512637 Shoe Test: 15.9 z..DO I[ .}, Well: CD1.10 Contractor: DOYON Rio Name: DOyon 19 Operation At 0600: RIH with BHA 14. Upcoming OperaUons: Test casing, clean out cement, LOT, change over to 9.4 ppg Flo.Pro and drill ahead. ~A'" MUD TYPE LSND I i(è, Q~ '1 ~ .', .' EH&S,: ,', /,>'~;;!;{ , , ACCIDENT (non-spill) LAST BOPIDIVERT N TST 12/03/2000 LAST H2S DRILL 11/20/2000 LAST CONFINED SPACE " ,QP;DA:TA>.!,:, LAST BOP/DRILL 11/23/2000 EMPLOYER LAST FIRE DRILL 11/29/2000 LAST SPILL DRILL 11/20/2000 SPILL N TYPE , FUEL,& WATE~' .. .. . , VOLUME (gallons) FUEL USED 3655 LAST SAFETY MTG DRILL WATER USED- 12/23/2000 BBLS ,i"'" ,', ';>" POTABLE WATER , INjec1;ôN ' , USED - BBLS INJECTION WELL CD1-42 SOURCE WELL CD1-10 RATE (bpm) 4 PRESSURE (psi) 1340 INJECTION FLUIDS 300 97 ,: .~EArHE~ &:, , PERSONNEL DATA .. TEMP 'F -13 WIND SPEED 17 WIND DIRECTION 50° CHILL FACTOR of -52.38 Water Base Muds 1140 Diesel 10 PHILLIPS PERSONNEL 1 0 0 CONTRACTOR PERSONNEL 25 0 TOTAL VOL (bbl) 1150 TOT FOR WELL (bbl) 30134 MISC PERSONNEL 5 SERVICE PERSONNEL 16 TOTAL B~A".Q,E~PRIPT'ON:+"~ ',:,.' " , I BIT/M1XL@1.2/NMSTAB/NMPONY/MWD/NMSTAB/3NMCSDC'SIXO/3HWDP/JARS/26HWDP >:: ,\,:'! ,<~, :!: :'::'~ :t:,:' ~;,i::'i~":.';'::<,.,;,.': ":::'~ X,..':<,~'::::-:~.;J:?J~',\',>'::,;". :,ÐRfIll:;PAB.E;'pA.rAr:::}~)fi;!i!!dr~i!,X:; ,::"" : ,:': ,\..' '),,:,: ;"",':,.' ;:~ :;;,~;"/"I,;i:,;(E~:~ ':~'&;; OD ID WEIGHT GRADE CONNECTION CLASS 2 ' LENGTH 5" 4.281 19.5 G105 4-112 I.F. BHA NO BHA LENGTH DATE LAST INSPECTED: HOURS ON JARS: 52.8 ~'i'fJ3:1Mþ;,:<~J:.,:..;\ENP,,'1 ','-:" HOURS ".',: QPS,CODE ' 12:00 AM 01:30 AM 1.50 OTHER 01:30 AM 02:30 AM 02:30 AM 05:00 AM 05:00 AM 06:00 AM 06:00 AM 08:30 AM 08:30 AM 09:00 AM 09:00 AM 12:00 PM 12:00 PM 02:00 PM 02:00 PM 03:30 PM 03:30 PM 05:00 PM 3 1011.5 1.00 CASG 2.50 RUN_CSG CIRC 1.00 2.50 RUN_CSG CIRC 0.50 3.00 RUN_CSG CIRC 2.00 1.50 CMT_CSG 1.50 CASG Daily Drilling Report: CD1-10 12/03/2000 47 Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing Casing and Cementing ': I' "", ,,' OP'ERATlo.~SFROfl("oooo',~:ooQo' :' :.:...,.,:~:, Clear tools from floor, wash through stack and wellhead, change wear bushIng to run 7" casing. RU to run 7" casing, PJSM. P1 ',: HOL:.E SECT "'It:'H~SEOPS P1 Making Hole Pi Pi P1 Pi P1 Pi Pi Pi Run 7" casing to 2956'. Clrc and cond mud. Run 7" casing to 5421', CBU. Run casing to 7909', attempted to clrc hole with fill-up tool, unable. LD fill tool and MU cement head. Staged pump up to 1.5 bpm and cond mud for cementing. Casing and Cementing Tested lines to 3500 psi - pumped 20 bbls of wash and 50 bbls of 12.5 ppg spacer. Cemented casing with 128 sxs of tall slurry. dlsp. wI 20 bbls of FW and 219.3 bbls of mud. Plugs bumped - CIP @ 1530 hrs. LO cement head - balls and LJ. - Pull wear bushing. Page 1 ( 05:00 PM 06:00 PM 1.00 OTHER 06:00 PM 07:00 PM 1.00 OTHER 07:00 PM 12:00 AM 5.00 BOPE 24.00 Pi Casing and Cementing Casing and Cementing Casing and Cementing ( Install and test packoff to 5000 psi for 10 min. Changed top rams to 6" X 3.112" and saver sub on TO to 3.112 IF. Ru and Test BOPE I choke manifold and surface safety valves to 25013500 . annular to 2500. Chuck Scheve (AOGCC) waived witnessing test. '\ J Daily Drilling Report: CD1-10 12/03/2000 Pi Pi Supervisor: DAVID P. BURLEY Page 2 CASING. ...dT and FORMATION INTEGRITY TEST Well Name: CD1-10 Date: 12/4/00 Supervisor: D.Burley Reason(s) for test: 0 Initial Casing Shoe Test 0 Formation Adequacy for Annular Injection 0 Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 95/811 36# J-55 BTC X 7" 26# L-80 BTMC Hole Depth: TOC 7,210' TMD 6,499' TVD Casing Setting Depth: 2,422' TMD 2,390' TVD Mud Weight: 9.8 ppg 4,788' Length of Open Hole Section: EMW= Leak-off Press. + Mud Weight 0.052 x TVD 737 psi 0,052 x 2,390' ./ + 9.8 ppg = EMW for open hole section = 15.7 ppg Ri Pump output = bbls pumped Fluid Pumped = 10.0 bbls Fluid Bled Back = 0.0 bbls ~ 500 psi => CI) CI) w , IX 400 psi £:I.. 900 psi 800 ps I I I I I I I ~ I I I "" ~ r- ,-", '" ...."..., I " ~ II:IME LIN~ , ONE MINUTE TICKS, , I / ' -4,-""",", f>---- T I ",.---<;--.. --,".-., I If J I ~ LEAK-OFF TEST I -'-CASING TEST I I ----§- LOT SHUT IN TIME I ! - ~ CASING TEST SHUT IN TIME ___L ...II I -+-TIME LINE I L r- i I ~. I 700 ps' 6OOps 300 psi 200 ps 100 psi 0 psi 0 16 18 20 10 12 BARRELS 14 2 6 8 .4 NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above Modified by Scott Reynolds LEAK-OFF DATA MINUTES FOR LOT eeLS PRESSURE i ---------------¡--- ------------¡-----------:-----¡ : 0 : 0 pSI: 1..---- ------- ----~------------ --_J.-----------------' I I . I : : 0.4 I 36 pSI: - --- ------- ----- t------------ ----\-----------------1 : : 0.8 : 41 psi: :----------------i---------------i-----------------I : : 1.3 : 41 psi: :-- - -------------i ------- --------i-----------------f I : 1.6 : 56 psi: :----------- -- - --i ---------------4------- ----------; ! ¡ 1.9 ¡ 76 psi ¡ ,..----- - ------ - --..---------------.,..----------------, ¡ ! 2.5 ! 162 psi! ,..---------------..---------------.,..----------------, ! ! 3.1 ! 253 psi ¡ ..------------ - -1---------------"----------------' ! ¡ 3.7 ! 369 psi ¡ ..---------------~----------------t----------------t ¡ ¡ 4.3 ¡ 495 psi ¡ r----------- ---T -----4.9-----Y---621-p-š¡-- ¡ 1---- ------------..- ----- --_u_----t---------------- -, I I I 73 . I : : 5.5 : 2 pSI I I----------------"--------------_J.-----------------' I I I . , : : 6.1 : 732 pSI: 1..--- - -----------~--------------_J.-_--------------' I I I . I : : 6.4 : 722 pSI: :----------- -----i----------------\-----------------I : : 7.0 I 692 psi: :----------------i---------------i----------------I : : 7.5 : 702 psi I :----------------~---------------i-----------------f : : 8.0 : 732 psi I :----------------~--------------. -----------------. ! ! 8.5 ! 722 psi! r---------------..-------------""----------------' ! ¡ 9.0 ! 737 psi ¡ "---------------1-------------""---------------' : : 9.5 : 722 Psi: . I I I ..- - ---- - - - - - - ---1-- -- -- -- - - ----t---- ------ -- --. ! ! 10.0 ! 727 psi ¡ ..---------------~----------------t-----------------t I I I I I I I . , I I I 1-- -------------------------t--- --------------t I I , I I I , I , , I , 1--------------- . . ----- , , I , , , , , . I I I 22 , I : SHUT IN TIME: SHUT IN PRESSURE I.._-----------~---------------------------------- I 00 . I I 727 . I : . mln : : pSI: :---------------t---------------+---------------t : 1.0 min : : 621 psi: ~--------7----1---------- -----1-------- ----:---f I 2.0 mln I I 616 pSI I :----------------i---------------i----------------f : 3.0 min : : 606 psi: :----------------~---------------4----------------. ¡ 4.0 min ! ! 596 psi ¡ ,....--------------..------- -------.,..----------------, ¡ 5.0 min ¡ ! 586 psi! ..- ------ -------..----------- ---..-----------------, ! 6.0 min ! ! 581 psi! "--------------1---------------"----------------' ¡ 7.0 min ¡ ! 570 psi ¡ ..--------------~---------------..-----------------t I 8 0 ., , 560 . I : . mln : : pSI: ..-------------~---- --- --------..-----------------t I 9 0 .. I 550 . I : . mln : : pSI: 1-------- --------..----- --- -------..-----------------t ¡ 10.0 min ! ! 545 psi! '------------- ---~--- ----- ----- ---'- -------- - -------. 8PHILLIPS AlaSK'a, Inc. A Slbsidiary of PHilLIPS PETROlELM COMPANY CASING TEST DATA MINUTES FOR eSG TEST STROKES PRESSURE ¡---- - - ---------¡--------------- ¡--- - ------ -:-----¡ : : 0 stks: 0 pSI : I.. -- ---- ---------~-- ---- ---- -----..----- ------- -- --..I I I I I I I , , I I , I :-- ----- --- ------t -- ------ -- -----t--- ---- - - --- -----I I I I I I I I :------------- - - - t -- - - - - - ---- ---- t -- -- ---- - ------ --I I I I I I I I :------- - -- u - -- - t - - - -- -- -- -- ---- t -- -- ---- -- - ------1 I , I I I I I , :- ----- - - -- - -- --- t-- --- - - -- - - ----t - -- ------ -- --- --..; I , I I I I I , I I I I ,.. -- ---- ----- - ---T --- -- 0 - - - - - - --- T- - -- - - - -- - - - ----.., I I I I I I I I I I I I ,..------ - - - -- --- -T -- -------- -- -- - T -- ---- -- --- --- - -..., I I I ~~ I I I . I I I ,..------ ---- - - -- -T-- - ----- ------- T-- ---- ---- -- - -' I I I I , I I I I ,..------ - -- -- ----T-- ----- - -- - - ---T -- --- - --- - -- -- - nf I I I I I , I I I I I I ...- ------ -- - --- - - t- ---- -- ------- - t- - --- ---- - - - -- --... I , , , , I I , , I I I ...----- -- - -- --- -- .&-- - ---- - - -- ---- t- - --- ---- - u_- --... I I , I , I I , I I I '--- ----- --------..------ - - - -- ____"0 ---- - - - - --------' I I I I I I I I I I I '- -- ----- - -------~----- - - ---- -_u.. - -- -- - --- --- -- --..I I I , , I I , , I :---- -- -------- --t----- - - - --- ----t- ---- - - -- - - - - - - --I I , I I I I I I :-- ----------- - - -t -- ------ -------t------ - - ------ ---I I I I , ~------- -- --- -- -+ - - - -- --------- -+------ ----- --- ---i I I I , I I I I :------- - - ----- --t----- -- - -- - -- --t------ -- - - -- -----} I I I I I I I I I I I I ,..- ------ ----- ---T -- - ----- -- -----T------ -- --- --- --.., , I I I , I I I , I I I ,..-- - ---- - -- --- --..- -- ---- - - - --- --..--- -- - - --- --- ---..., , I , I I I I I I I I I I , : SHUT IN TIME: SHUT IN PRESSURE ...---------------T-- ---- --- ------..----------------, . 00 . I I 0 . I : . mln : : pSI: t---------------t-------_u -- ---t----------------'" ¡ 1.0min ! ¡ ¡ ,----------------.&-------------- -..------------- ----' ! 2.0min ! ¡ ! '- u ------------..----- -------- - - ..-- --- -- --- u ---;4 ¡ 3.0 min ! ! ' Co~, '--_u_----------"------ -- -------..- ---- --------- ! 4.0min ¡ ¡ :----------------t---- ---- -------t- u -- --- - - -- -----I : 5.0min : : : 1-------------- --t---- -- -- -- -----t- - - -- - - - - --- - ----I : 6.0min : : : :----- -----------t---- - - -- -- -----t- ---- --- - --- -- - --I : 7.0min I : : :---------- ------t---- ---- -- -- ---t------ -- ---------1 ¡ 8.0min ¡ ¡ ¡ ,..----- -- -- - -- ---T ---- ----- --- ---T-- ---- ----------.., ¡ 9.0min ! ! ! ,..--- u- ---- -- - - - T -- - -- - --- ------ ..----- - - - --- - - ---..., ! 10.0 min ¡ ! ¡ ,..------ ------- --T----- - - - -------.- -- - -- -- --------..., ! 15.0 min ¡ ¡ ¡ ... ------- ------- -T------ - - - - -- ---T---- - - ---- ------... ¡ 20.0 min ¡ ¡ ¡ ...---------------t - ------- ---- --- t------ -- -- ------... ¡ 25.0 min ! ¡ ! ... ----- - - - ---- ---t------------ ---t ---- -- -----------' ! 30.0 min ! ¡ ! '-- ----------- - - -~ --- -- - ---- -- - - -~ ---- - --- ------- -..I NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY W LL LOG ,,. TRANSMITTAL ProActive Diagnostic Services, Inc. To~ AOGCC 333 West 7th Ave. Ste. 1 O0 Anchorage, AK 99501-3539 RE · Distribution - Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of' Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT[S} OR CD-ROM FILM BLUE LINE Open Hole I 1 1 Res. Eval. CH I 1 1 Mech. CH CD 1-10 8-1-03 Caliper Survey ~I~D'_, Q~'~ I Rpt or ""~ I Color Print Name: Date · ProActive Diagnostic Services, Inc., Po Box i 369 Stafford TX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds~memorylog.com Website: www.memorylog.com Memory Multi-Finger Caliper Log Results Summary Company: ConocoPhillips Well: Log Date: August 1, 2003 Field: Log No.: 5169 State: Run No.: 1 APl No.: Pipe1 Desc.: 4.5" 12.6 lb. L-80 IBT Top Log Intvll.: Pipe1 Use: Tubing Bot. Log Intvll.: CD 1-10 Alpine Alaska 50-103-20353-00 Surface 7,622 Ft. (MD) Inspection Type · Corrosive & Mechanical Damage Inspection COMMENTS - This log is tied into the XN Nip @ 7,622' (Driller's Depth). This log was run to assess the condition of the tubing with respect to corrosive and mechanical damages. The 4.5" tubing logged appears to be in good to fair condition with respect to corrosive damage. Wall penetrations from 21% to 27% are recorded in 8 joints throughout the tubing. The damage appears in the forms of Isolated Pitting and Line Corrosion. The remainder and majority of the tubing logged appears to be in good condition. No significant areas of cross-sectional wall loss or I.D. restrictions are recorded. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. MAXIMUM RECORDED WALL PENETRATIONS: Isolated Pitting (27%) Jt. 128.3 @ 5,624 Ft. (MD) Isolated Pitting (25%) Jr. 169.3 @ 7,395 Ft. (MD) Line Corrosion (24%) Jt. 174 @ 7,617 Ft. (MD) Line Corrosion (23%) Jt. 172 @ 7,531 Ft. (MD) Isolated Pitting (21%) Jr. 169 @ 7,378 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS ' No significant areas of cross-sectional wall loss (> 8%) are recorded throughout the interval logged. MAXIMUM RECORDED ID RESTRICTIONS ' No significant I.D. restrictions are recorded throughout the interval logged Field Engineer: S. Adcock Analyst: M. Lawrence Witness: T. Johns ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281.) or (888) 565-9085 Fax: (281) 565-:[369 E-mail: PDS{~hmemorylog.com Pruclhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 6~9-z314 taDS Report Overview Body Region Analysis Tubing: Nora.OD Weigh~ Grade & Ihread Nora.ti) Noi~il (]p~i ~ipper ]en. Lowe/]eh. '4:~ !!!~ ! ~:6 EP~ L-80 IBT 3.958 h~s 42~ ~ns 1.2 k~s 1.2 h~s , Penetration and Metal Loss (% wall) 50i 0i-- 0 to 1 to 10 to 20 to 40 to ove~ 1% 10% 20% 40% 85% 85% 20 0 Damage Configuration ( body ) , Damage Profile (% wall) penetration body ~ metal Mss bod, 0 50 GLM I 49 Gl M 2 GLM 3 1 O0 Ana}ysis Overview page 2 Well: Field: Company: Country: Survey Date: CD t-10 Alpine ConocoPhillips USA August 1, 2003 PDS Caliper Statistical Evaluation Report Tool: MFC 40 No. 99493 Tool Size: 2.75 inches Tubing I.D.: 3.958 inches Tubing O.D.: 4.5 inches Wall Thickness: 0.271 inches 0.24 0.t9 0.14 0.09 0.04 0.1 Percent Probability of Hole 10 20 50 00 , I -[ - i II standard Deviation ~__~~ I 85% ~/all T} ickness Sal~el ~ ~a clor Line of I 0.003 1! I I , ' I I , [ , 1 10 100 Average Rank Maximum Probable Penetration* 0.077 inches (28.4 % Wall Thickness) Percent Probability of Recording a Hole* Less than 10% * Derived from data with average rank value less than or equal to 20. PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in 12.6 ppf L-80 IBT Well: CD 1 10 Body Wall: 0.271 in Field: Alpine Upset Wall: 0.271 in Company; ConocoPhi[lips Nominal LD.: 3,958 in Country: USA Smve¥ Date: August 1. 2003 joint Depth No. (Ft,) pset l 21 0 2 65 0 3 [ 107 0 5 6 7 8 9 Pen. Pen. Pen. i Metal [ Mm. Damage Profile Body % Loss [ I.D. Comments (Ins.) % i (tns.) 0.01 [ 2 i I 3.94 i 148 0 320 0 i 0.02 8 364 0 0.03 10 I 3.94 3.92 Shallow pitting. 21 i 869 1/.02 9 l 22 ,[ 913 0 0.01 4 2 i 3.88 23 [ 955 1) 0.02 8 I 3.92 24 [ 999 I) 0.01 2 [ 2 3.87 [ 26 i 1087 0 i 0.02 8 [ [ i 3.93 27 [ t131 0 002 9 i 392 ] 28 [ 1175 (L [ 0.01 4 ... I [ 3.92 2(3 i 1219 0 )02 8 [ 1 3.91 30 12t3 0 i O.03 l0 ! I i 3.92 ~2 1351 0 0.01 4 I [ 3.92 33 [395 0 002 8 I [ 39 34 I439 0 0,02 8 [ I ] 3.90 [ ~5 [ 1483 0 0.00 [ I ~ 3.92 36 ] 1:,27 0 i 0.()~ 8 ~ 1 3.92 ~7 1571 0 [ 0.01 4 2 [ ~88 38 [ 1612 0 I 0.01 4 39 [ 1654 0 i 0.02 [ 9 [ ] 3.92 39A 1698 0 [ 0.01 4 I 3.92 39.2 i~ ~ ~ 0 0 ~ [ 3.8[ 42 i~6 ~ ~ 0.(H 5 I 3.92 ] 0 0,04 [ [4 L 2 ] 390 44 ] 1898 ] 0 0.03 10 [ , 3.91 (% wall) 50 1 O0 iJ Page 1 PDS REPORT JOINT TABULATION SHEET Pipe: 4.5 in [2.6 ppf D80 IBT Well: CD 140 Body Wall: 0.27 [ in Field: Alpine Upset Walk 0.271 in Company: ConocoPhil]ips Nomba! I.D.: 3.958 in Country: USA Survey Date: August 1,200~ joint ~ Depth ' Pen. [ Pen. [ Pen. ~Meta[ Min. No. (Ft.) Upset [ Body [ % Loss I.D. (bs.) [ (Ins.) I % ([ns,) 48 [ 2O73 . t) . 0.02 49 [ 2 [ [ 7 0 (3.03 51 ] 22O2 o 0.02 52 [ 2246 0 0.02 8 I 3.91 __53 i 2287 0 0.0~ 8 ] 3.87 54 [ 2328 0 0.03 10 [ I [ 3.91 55 [ 237 0 0.02 ~ [ 56 j 2415 0 0.02 [ 8~ I 3.83 Damage Profile Comments (% wail) [ 0 50 1 O0 2 ] :~.88 , 57 [ 2458 0 0.02 [ 6 ~ ! 58 2502 0 0.02 [ 8 ] I 3.88 59 i 2545 0 0,0¢ [ 1[ [ I 3.88 0 0.02 [ , 6t [ 263[ 0 . 0.03 [ ]0 j 0 . 3.90 ()g [ 2672 0 0.03 ] ]() ] ] 3.88 64 2758 0 0,03 9ii 65 2802 0 i 0.01 4 1 3.90 67 2890 0 0.02 8 j ~ 3.91 , (,8 2%4 0 003 ~) l 69 2976 0 0.02 8 [ I 3.9~ 7O ~019 0 0.0[ 6 [ I . 3.91 71 ~(363 0 0.03_ II 1 3.89 72 , 3107 = 0 0.03 ~ 9 2 ~8~ . 73 3151 0 0.02 6 2 74 3195 0 [30] , 10 t 3.90 75 3239 0 [ 0.03 12 I ~.88 Sha[[ow pitting. 76 [ 328~ 0 0.03 I1 [ 388 Shallow pitting. 77 [ 3327 0 0.CB l~ I 3.88 - ~b~[lQ~pi~ing~ 78 [ 337l 0 002 [ 8 79 [ 3415 0 0.01 2 1 3,88 80 [ 3458 0 0.01 4 t 3.9~ 81 j 3502 0 [ 0.0~ 1~ 1 3.87 5hall)war nz 81.[ [ 3546 0 0.03 {1 1 3.87 PUP 81,2 3553 0 0 0 0 , N]A GLM 81.3 3563 0 C02 8 2 ] 3.88 i PUP 82 [ 357¢ 0 ~ 0.02 6 1 370t ~ ()~55 8 i 3 86 j 3745 87 3786 0 i 0. o2 9 i 3 i 3.91 0 ] 0,02 8 [ 2 3.91 0.03 Il 3 I 3.92 o i o.o3 1o 3 i ~o i 0 0.02 8 [ 3 ] 3.91 o 0.05 '. ioI 3 j 3.91 0 j 002 [ 9 [ 2 [ 3.91 89 [ 3874 90 [ 3918 9I [ 3962 92 , 4006 93 4050 94 4094 Page 2 PDS REPORT JOINT-fABULATION SHEET Pipe: 4,5 in 12,6 ppf US0 IBt- Well: CD 1 I0 Body Wall: 0.271 in Field: A!pine Upset Wall: 0.271 in Company: ConocoPhi[[ips Nominal I.D.: 3.958 in Cotlntry: USA Survev Date: August l, 2003 Damage Profile No. (Ft) Upset Body [ % Loss I.D. Comments 14q [ 6245 0 i 0.03 146 63~2 0 0.02 [ 9 2 3.89 [47 148 ~57 6814 0 ) 0~ l ~ . 2 3.9] ~b~ilow Pi~tin.q: ~62 i 7033 3.8, 163 ] 7075 i 3.~ ] Shailo~pit/in~, 164 7118 0 ~ 303 i l0 : [ 3.9) [ I65 i 7162 0 0.05 i 17 [ 3.88 Shal[owpittiq~: 166 [ 7205 0 ] 004 i 13 [ L89 [ Sha[iowpilling. 67 7250 0 [ 0.04 13 i L89 Shallow p~ttmg. 169 7334 (~ ~;~6 2 ~ 2_ 3]~ iS~;kt(~.ts~it{i,~K. It. Deposits 1(,9. I 7379 ~ 13 I 2 [ $~i7 ~ PIJ~i34~lP~Pil!~]g 169.2 71385 0 ~69.} 7~95 170 [ 7405 3.89 k Isolated pittin~ ]IZ[ [ 7449 0 0.05~ 18 ~ Line shallow corrosion. 50 100[ PDS REPORT/OINT TABULATION SHEET Pipe: 4.5 in [2.6 ppf [ 80 IBT WeJ[: CD lq0 Body Wail: 0.27 [ in Field: Alpine Upset Wa[!: 0.27I in Company: ConocoPhi[Jips NomMal I,D.: 3.958 [11 COLIrltty: USA Survey Date: August l, 20B3 I02 103 4488 0 [ 0.02 8 3 104 4532 0 ] 0.B3 [0 ~ 2 105 4576 0 [ 0.03 10 2 106 4620 0 [ 0.02 8 2 107 4664 0 1o8 47O8 0 109 . 4752 0 0.04 13 3 3 [ L92 ' 2 i 3.92 4444 I 0 i 0,02 , 8 2 i 3.92 , 3.90 3.93 3.83 Lgo 3.93 3.92 [ Shal[ow pitting. 110 4795 0 ] 0.02 [ 9 ] 3 3.91 t 11t 4839 0 [ 0.03 ] 12 i 2 3.9[ i Sha[[owpittinz. [12 48B0 0 i O.0l 4 2 ~ 3.88 ] 113 4922 114 4966 115 5010 116 5051 [ 117 5091 llB 5136 [ [19 [ 5179 __.! ,~g i 5220 121 5260 122 [ 530I 123 5343 124 5384 0.02 8 2 ~.92 0o2 g 2 ~,9o i 0,02 8 i ~ 3.89 ().0[ g } ) 3.91 0.0I 5 [ 2 3.92 1 0.02 9 [ ~ [ .91 [ 125 5425 126 5470 0 127 5512 0 t 28 555(~ 0 I28.1 5601 0 ~28.2 5610 I28.3 5617 129 [ 5627 0 [ 30 [ 5667 o 0.04 J ~ [ ~ [ 3:84 i Sba!logy pitting, LL Deposits. 0.02 _ 8 [ 3 ] 3,91 ] (~,0;) !2 [ 2 i 391 i ShaJJ°wPit~ing 0,01 4 [ 3 ] 392 [ PUP 0 0 N/A GLM 2 (Latch @ 5:00) 0.0I ~ ~ 2 i 3.86 j LL Deposits. 140 6078 I 0 (02 i 8 2 i 3.91 Page 3 PDS Report Cross Sect]ohs We]]: CD 1-10 Survey Date: Augus( 1, 2003 FieJd: Alpine 'fool Type: MFC 40 No. 99493 Company: CenocoPhi}lips Tool Size: 2.7S Country: USA No, o1' Fingers: 40 Tubing: 4:3 !rls J2:~pp~ LB0 lief Ana~yst~ M I_gwmn~e Cross Section for Joint 128.3 at depth 5623.73 ft Too] speed - 68 Nominal ID- 3,9S8 Nominal OD = 4,500 Remainir~g wa]] area = 99 % Too] deviation = 16 ° Finger 32 Penetration = 0,074 ins Isolated Pitting 0.07 ins = 27% Wall Penelration I tlGI I SIDE = UP Cross Sedions page 1 PDS Report Cross Sections Well: CD 1.10 Survey Date: August l, 2003 Field: Alpine Tool Type: MFC 40 No. 99493 Company: ConocoPhiJlips Tool Size: 2.75 Country: USA No, of Fingers: 40 l-c!bingj ~:5 !ns 12.6 ]apl LS~ !B'!' Ana[yst~ M. LawEer~ce Cross Section for }oint 169.3 at depth 7394.88 ft ~ 1'oo[ speed - 70 Nominal iD- 3.958 Nominal OD - 4.500 Remaining wall area = 97 % Tool deviation - 19 ° Finger 36 Penetration=O,O69ins Iso]ated Pilting HIGH SIDE = UP Cross Sections page 2 Permit to Drill 2001710 MD 11673 ~ TVD DATA SUBMITTAL COMPLIANCE REPORT 111612003 Well Name/No. COLVILLE RIV UNIT CD1-10 Operator CONOCOPHILLIPS ALASKA INC 6967 ~' Completion Dat 12/9/2000 - Completion Statu 1-OIL Current Status 1-OIL APl No. 50-t03-20353-00-00 UIC N _ - . REQUIRED INFORMATION Mud Log N.__Qo Sample N._Qo Directional Survey N__~o DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fmt Log Log Run Name Scale Media No Interval OH I Start Stop CH 2430 11693 Open (data taken from Logs Portion of Master Well Data Maint Dataset Received Number Comments 2/26/2001 09930 ~-~-0~-1 '~(~9:~' - '(~.~ R R C C L L L L ED D Pro Production~ Lo Pro Production ~ ~ey Report 9930 .~rray Res 2/5 2/5 BM 0 11693 FINAL 2430 11693 oh FINAL 2422 11646 oh FINAL 2422 11646 oh 1 7640 9534 Case I 7640 9534 Case 1/9/2001 0-11693 Paper Copy 2/26/2001 9930 ~430-11693 Digital Data ~3 ,v'~//~'' 2/26/2001 2422-11646 BL, Sepia 2/26/2001 2422-11646 BL, Sepia 8/22/2002 10996~,,-'''''~ 8/22/2002 . Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y Chips Received? Analysis R~.nP. iv~.d? . Start Interval Stop Dataset Sent Received Number Daily History Received? ~,~N Formation Tops (~/N Comments Comments: Compliance Reviewed By: Date: WELL LOG TRANSMITTAL II- ProActive Diagnostic Services, Inc. AOGCC 333 West 7th Ave. Ste. 1 O0 Anchorage, AK 99501-3539 RE: Distribution - Final Print{s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Joey Burton / Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 S~afford, TX 77497 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT(S) OR CD-ROM FILM BLUE LINE Open Hole I I 1 CO 1-10 7/31/02 Res. Eval. CH ~ ~~,.'...'~,~ ~~ Mech. CH Caliper Survey I FlPt or I Color Signed: Date' , Print Name: PRoActive Diagnostic Services, lac., 3 IO K STREEt Suite 200, Anchoraqe, AK 99501 Phone:(907) 245-8951 Fax:(907) 245-8952 E-mail: pdsanchorage~memorylog.eom Website: www'.memorvlog.com MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, ~~ \ ~\ DATE: Commissioner ~.~0\ ' THRU: Tom Maunder, P. I. Supervisor FROM: Chuck Scheve; SUBJECT: ' Petroleum Inspector March 30, 2001 Safety Valve Tests Colville River Unit CD1 Pad Friday. March 30. 2001: I traveled to the Phillips Alaska's Alpine Field and witnessed a portion of the safety valve system tests on CD1. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 8 wells and 24 components with no failures observed. The Rosemount Iow-pressure switches (located in the manifold building) performed very well tripping at the set point on all wells tested. The.. surface, safety., valves on these wells o .pe. rate very slowly...probably due to .being exposed to the.. elements and the. length..of the control line from the..hyd panel to the wellhead. '" Gary Saltenreick conducted the testing today he demonstrated a good working. knowledge of the system and was a pleasure to work with. ,Summa,w: I witnessed a portion of the 'semi-annual SVS testing at the CD1 Pad in the Alpine Field. CRU CD1 Pad, 8 wells, 24 components, 0 failures Atta, ch ,rn~,,nt: SVS CRU CD1 Pad 3-3001 CS X Unclassified ILl . I_ II Confidential (Unclassified if doc. Removed) SVS CRU CD1 3-30-01 CS ( ( Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Operator Rep: Jack Kralick AOC ¢ Rep: "' Chuc k seiaeve i1_ iii J Submitted By: Chuck Scheve Separator psi: LPS 143 Date: 3/30/01 I-xES Well Permit Separ Set L/P Test Test Test Date on, WAG, CmJ, Number ..Number PSI PSI T ri'p Code Code Code Passed GAS or CYCLE CDI'01 1990460 ..... ' ....... CDi-06 2000830 ........ ' ......... · ........ 11 CD1-09 2000710 CDI-13 1990520 · .............. . · .,,.,~ ~,,r'r~-'~: ' i'990940 ....... ' .... ' ................. 'CDI'17 2001450 '143 ' 100 .... 100 " P P P ........... oIL CDl'-E2A '2001i00'" 143 i'00 100 p p P '. oiL CD1-24 1.990260 1~3 "100! ... 100 " P P P"" ' ........ OIL CDI'-~ 2000080 "'i43 100 100 'P' ' 'P ' P ....... 0iL CD1-27 2000060, ,i" ' CD1-30 2001320 em............. ' ............... -32 1991040 ~"' CD1-34 2000430 ....................... " cD1,'3S '" 1990j80 143 106 'i00 P "' P P:' ' : ....... 0IL i i i ' ' " - ' ." ' - : I1 . . i , i ,, , . .. ;__ ,,...~. CD1-38 2000030 CD1-40 1990440 ' "' i i i . i il il ii . i il i i i i i i I ii l.l i Ii _ i CD 1-41 2000170 . · i , , i il i. i i i i i CD1-43 2001060 liti CD 1-44 '. 2000550 _ t , ' = ' CD 1-04 2001170 143 1'00 i 00 P P P ' OIL ''' . . ii i I ii i i i j . I .... i -~'- - z0017i0: ' .... i',~3 I00 100 P P P OIL ½ ; ...., . . . . CD1-29 .. "143 .... '100 100 P P 'P OIL Wells: 8 Components: 24 Failures: 0 Failure Rate: 0.00% i [ i i [ [ - . . ii ii ,i - -. i i iii. _i i ' ' ! ' ' -' ' - ......... :? - - . .... . - i ii i . _ iiii RJF 1/16/01 .. Page 1 ofl 010330-SVS CRU CD1-CS Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 9O7 Company: Alaska Oil & Gas Cons Corem Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine (Open Hole) 1/25/01 Color Well Job # Log Description Date BL Sepia Prints CD CD1-10 21022 M10,1MP & CDR LWD (PDC) 001208 1 ;CD1-10 21022 MD ARRAY RES (PDC) 001208 I 1 CD1-10 21022 TVD ARRAY RES (PDC) 001208 I 1 CD1-28 PB1 21023 ADN & CDR LWD (PDC) 001218 1 CD1-28 PB1 21023 MD ADN (PDC) 001215 I 1 CD1-28 PB1 21023 TVD ADN (PDC) 001215 I 1 CD1-28 PB1 21023 MD CDR (PDC) 001215 I 1 CD1-28 PB1 21023 TVD CDR (PDC) 001215 I 1 CD1-28 21024 IADN, CDR, IMP LWD (PDC) 001222 1 CD1-28 21024 :MD ADN4 (PDC) 001222 I 1 CD1-28 21024 ;MD ARRAY RES (PDC) 001222 I 1 CD1-28 21024 TVD ARRAY RES (PDC) 001222 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. i' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Sewice Well Oil r~ Gas D Suspended [~ Abandoned [~ Service r~ 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. 200-171 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-103-20353-00 4. Location of well at surface ~ 'i':.,'=.,i?~....:.~.;-!...,~.~. ~ i'[~'[[(:~ 9. Unit or Lease Name 286' FNL, 2510' FWL, Sec. 5, T11 N, R5E, UM (ASP: 385936, 5975841) ',,....~.,:.-" ~ VV~ Colville River Unit At Top Producing Interval /"~_-~OO 10. Well Number 1385' FSL, 915' FEL, Sec. 32, T12N, R5E, UM (ASP:387809, 5977485) ...................-'~ -'-- -.."- ',, -"...? }~[,~t~ CD1-10 At Total Depth .... '.~...~--i.__ 11. Field and Pool 2110' FNL, 957' FWL, Sec. 4, T11N, R5E, UM (ASP: 389639, 5973962) .............................. Colville River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Alpine Oil Pool RKB 36 feetI ADL 25558/25559 / ALK 372095 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions November 27, 2000 December 7, 2000 December 9, 2000 I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey ~20. Depth where SSSV set 21. Thickness of Permafrost 11693'MD/6967'TVD 11693'MD/6967'TVD YES r'~ No DI 1719, feetUD 15,56' 22. Type Electric or Other Logs Run GR/Res 23. CASING, LINER AND CEMENTING RECORD SEFrlNG DEPTH MD ~ CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 Surface 114' 42" 10 cu yds Portland Type 3 9.625" 36# J-55 Surface 2422' 12.25" 384 sx AS III Lite & 231 sx Class G 7' 26# L-80 Surface 7909' 8.5" 128 sx Class G 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) 'PACKER SET (MD) 4.5" 7634' 7546' Open Hole completion 6.125" OH from 7909'-11693' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL 'CHOKE SIZE ~GAS-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.RECEIVED JI N 1 200 Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ORIGINAL Submit in duplicate 29. ~, 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Alpine D 7664' 6884' Top Alpine 7713' 6901' N/A REceIVED JAN ] $ 200! Alaska Oil & Gas Cons A/~chorag-e' Cornrnission 31. LIST OF ATTACHMENTS Summary of Daily Operalions, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Scott Reynolds 265-6253 Signed ,~,,~./~.,. (. v~.,,~ Title Alpine Drillin!:l Team Leader Date .~ '"J G. C. Alvord Prepared by Sharon AIIsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ORISI L Date: 01/12/01 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:CDi-10 STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: COLVILLE RIVER UNIT SPUD:il/27/00 START COMP: RIG:DOYON 19 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20353-00 11/26/00 (D1) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 0/0 ( 0) DRILLING 12-1/4" HOLE FROM 540' SUPV:DAVID P. BURLEY PJSM. Move rig subbase and center over well. Accepted rig @ 2030 hrs. 11/26/00. NU diverter system. 11/27/00 (D2) MW: 9.8 VISC: 185 PV/YP: 23/66 APIWL: 18.0 TD/TVD: 2430/2397 (2430) RUNNING 9-5/8" CASING. SUPV:DAVID P. BURLEY Perform diverter test. Held prespud meeting. Drill 12.25" hole from 114' to 2430' Pumped high vis pill and circ hole clean, increased mud wt. to 9.8 ppg. Monitor well, wiped hole to 1485'. circ and cond mud. 11/28/00 (D3) MW: 9.5 VISC: 44 PV/YP: 8/14 APIWL: 8.0 TD/TVD: 2430/2397 ( 0) RIH W/ BHA ~2. SUPV:DAVID P. BURLEY Circ hole clean, monitor well, static. POH. PJSM. Run 9-5/8" casing. Cond mud. PJSM. Pump cement. Bumped plugs, floats held. ND diverter system. NU BOPE and test to 250/3500 psi. 11/29/00 (D4) MW: 9.6 VISC: 43 PV/YP: 10/17 APIWL: 7.4 TD/TVD: 3924/3703 (1494) WIPER TRIP TO SHOE. SUPV:DAVID P. BURLEY Tested IBOPs to 250/3500 psi. RIH, wash down from 2300' to 2334'. Circ and cond mud. Drill out cement and float equipment from 2334' to 2422', drilled 20' of new hole to 2450'. Circ hole clean. Perform LOT, 15.9 EMW. Change well over to 9.6 ppg LSND mud. Drill 8.5" hole from 2450' to 3924' 11/30/00 (D5) MW: 9.6 VISC: 42 PV/YP: 10/16 APIWL: 4.6 TD/TVD: 6658/6107 (2734) POH FOR BHA CHANGE. SUPV:DAVID P. BURLEY Drill from 3924' to 4497'. Pump sweep and circ hole clean. Monitor well, static. Wipe hole to shoe, no problems. RIH, precautionary ream last 90'. Drill from 4497' to 6658' RECEIVED JAN 1 9 Z001 Alaska Oil & Gas Cons. Commission Anchorage Date: 01/12/01 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 12/01/00 (D6) MW: 9.6 VISC: 41 PV/YP: 9/20 APIWL: 4.0 TD/TVD: 7415/6757 ( 757) DRILLING AHEAD FROM 7642' SUPV:DAVID P. BURLEY Drill from 6658' to 6780'. Pump high/low/high sweeps and circ hole clean. Monitor well, static. POH. RIH to 6790', precautionary ream last 90'. Drill from 6780' to 7415' 12/02/00 (D7) MW: 9.8 VISC: 44 PV/YP: 9/23 APIWL: 4.2 TD/TVD: 7919/6940 ( 504) RUNNING 7" CASING. SUPV:DAVID P. BURLEY Drill from 7415' to 7919'. Pump high/low/high sweeps and circ hole clean, monitor well, static. Short trip to 6587' Pump sweeps and circ hole clean, monitor well, static. POH. 12/03/00 (D8) MW: 9.7 VISC: 40 PV/YP: 8/17 APIWL: 5.5 TD/TVD: 7919/6940 ( 0) RIH WITH BHA #4. SUPV:DAVID P. BURLEY RU to run 7" casing. PJSM. Run 7" casing. Circ and cond mud. Pump cement. Plugs bumped. Install and test packoff to 5000 psi. Test BOPE to 250/3500 psi. 12/04/00 (D9) MW: 9.2 VISC: 49 PV/YP: 11/23 APIWL: 3.2 TD/TVD: 8305/6936 ( 386) TRIPPING FOR MWD FAILURE. SUPV:DAVID P. BURLEY RIH, tag cement @ 7770'. Clean out cement to 7818'. Circ and cond mud. test casing to 3500 psi. Clean out cement and float equipment, drill 20' of new hole to 7939'. Circ hole clean. Perform FIT to 12.5 ppg. change well over to 9.2 ppg Flo-Pro. Drill from 7939'-8305' 12/05/00 (D10) MW: 9.2 VISC: 50 PV/YP: 10/27 APIWL: 4.2 TD/TVD: 8971/6934 (666) DRILLING AHEAD @ 9400' SUPV:DAVID P. BURLEY CBU, monitor well, static. Pumped out to 7350', no problems, monitor well. POH. RIH to 7833'. RIH, precautionary ream from 7939' to 8270'. Drill from 8305' to 8971' 12/06/00 (Dll) MW: 9.2 VISC: 50 PV/YP: 10/26 APIWL: 3.6 TD/TVD:10470/6953 (1499) DRILLING @ 10660 SUPV:DON MICKEY Drill 6-1/8" hole from 8971' to 10470'. Circ hi vis sweep for wiper trip. Monitor well, wiper trip from 10470' to 9995' 12/07/00 (D12) MW: 9.2 VISC: 54 PV/YP: 10/30 APIWL: 3.8 TD/TVD:l1693/6965 (1223) PREP TO CHANGE WELL OVER TO 9.2 PPG BRINE SUPV:DON MICKEY Continue wiper trip, pump out to 8095'. Monitor well, RIH from 8095' to 10470'. Drill 6.125" hole from 10470' to 11693'. Pump hi vis sweep, monitor well. WiDer triDfrom RECEIVED JAN i 9 ZOO1 Alaska Oil & Gas Cons. Commission Anchorage Date: 01/12/01 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 12/08/00 (D13) TD/TVD:l1693/6965 ( SUPV:DON MICKEY MW: 9.2 VISC: 29 PV/YP: 0/ 0 0)LANDING 4 1/2" TBG APIWL: 0.0 Continue wiper trip, pumping out from 10290' to 7894', monitor well. RIH from 7894' to 11600'. Safety ream from 11600' to 11693' Circ hi vis sweep. PJSM. Change well over to 9.2 ppg brine. Monitor well, hole taking 120 bbls/hr. Spot hi vis pill. Pull 20 stds to 9823', hole still taking 92 bbl/hr. Spot hi vis pill. Pull 23 stds to 7608'. Monitor well, hole taking 10 bbl/hr. Pump LCM pill. R/U to run 4.5" completion. PJSM. RIH w/4.5" tubing. 12/09/00 (DI4) MW: 16.4 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:l1693/6965 ( 0) RIG RELEASED SUPV:DON MICKEY Finish RIH w/4.5" tubing. PJSM. N/D BOPE. N/U tree and test to 5000 psi. Set packer. Pump brine and diesel. Set BPV. Secure tree. Release rig @ 1700 hrs. 12/9/00 J/IN 1 9 ZOO1 Alaska Oil & Gas Cons. Commission AnChorage ANADRILL SCHLUMBERGER Survey report Client ................... : Phillips Alaska, Inc Field .................... : Colville River Well ..................... : CDi-10 API number ............... : 50-103-20353-00 Engineer ................. : Nutter COUNTY: .................. : Doyon 19 STATE: ................... : Alaska Survey calculation methods Method for positions ..... : Minimum curvature Method for DLS ........... : Mason & Taylor Depth reference Permanent datum .......... : Mean Sea Level Depth reference .......... : Drill Tally GL above permanent ....... : 19.50 ft KB above permanent ....... : Top Drive DF above permanent ....... : 56.10 ft 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: 151.94 degrees [(c)2000 Anadrill IDEAL ID6_lC_08] 8-Dec-2000 11:00:45 Page 1 of 5 Spud date ................ : 27-Nov-00 Last survey date ......... : 08-Dec-00 Total accepted surveys...: 121 MD of first survey ....... : 0.00 ft MD of last survey ........ : 11693.00 ft Geomagnetic data Magnetic model ........... : BGGM version 2000 Magnetic date ............ : 27-Nov-2000 Magnetic field strength..: 1147.19 HCNT Magnetic dec (+E/W-) ..... : 25.58 degrees Magnetic dip ............. : 80.55 degrees MWD survey Reference Criteria Reference G .............. : 1002.68 mGal Reference H .............. : 1147.19 HCNT Reference Dip ............ : 80.55 degrees Tolerance of G ........... : (+/-) 2.50 mGal Tolerance of H ........... : (+/-) 6.00 HCNT Tolerance of Dip ......... : (+/-) 0.45 degrees Corrections Magnetic dec (+E/W-) ..... : 25.58 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 25.58 degrees (Total az corr = magnetic dec - grid cony) Sag applied (Y/N) ........ : No degree: 0.00 < ANADRILL SCHLUMBERGER Survey Report 8-Dec-2000 11:00:45 Page 2 of 5 Seq Measured Incl Azimuth Course S depth angle angle length - (ft) (deg) (deg) (ft) 1 0.00 0.00 0.00 0.00 2 114.00 0.00 0.00 114.00 3 292.35 0.67 289.11 178.35 4 471.00 0.68 230.84 178.65 5 654.00 1.18 223.06 183.00 6 742.00 1.41 228.32 88.00 7 833.00 0.59 221.44 91.00 8 923.00 0.06 100.95 90.00 9 1109.00 0.19 110.13 186.00 10 1299.00 0.32 140.77 190.00 11 1393.00 1.78 56.36 94.00 12 1489.00 4.52 47.23 96.00 13 1584.00 6.48 47.54 95.00 14 1680.00 7.75 41.53 96.00 15 1775.00 9.11 34.90 95.00 16 1870.00 10.61 34.49 95.00 17 1965.00 12.69 36.58 95.00 18 2061.00 15.71 38.34 96.00 19 2156.00 18.40 40.27 95.00 20 2252.00 21.09 40.53 96.00 21 2369.00 23.84 39.18 117.00 22 2529.00 28.07 35.75 160.00 23 2720.00 29.29 35.39 191.00 24 2910.00 29.93 35.72 190.00 25 3100.00 29.89 34.06 190.00 26 3291.00 30.19 33.19 191.00 27 3481.00 28.76 36.60 190.00 28 3671.00 28.57 36.80 190.00 29 3860.00 28.08 36.57 189.00 30 4053.00 28.43 36.99 193.00 RECEIVED JAN 1 9 ZOO1 AI~ C)il & Gas Cons. Commission TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) 100f) 0.00 0.00 0.00 0.00 114.00 0.00 0.00 0.00 292.35 -0.76 0.34 -0.99 470.99 -1.33 0.01 -2.79 653.96 -0.51 -2.05 -4.92 741.94 0.04 -3.43 -6.35 832.92 0.47 -4.53 -7.50 922.92 0.66 -4.88 -7.76 1108.92 0.95 -5.01 -7.37 1298.92 1.71 -5.53 -6.74 1392.90 1.82 -4.92 -5.36 1488.75 0.72 -1.53 -1.34 1583.31 -1.57 4.64 5.36 1678.57 -5.17 13.14 13.65 1772.54 -10.83 24.10 22.20 O.00 0.00 0.00 0.00 1.04 289.11 2.79 270.28 5.33 247.41 7.22 241.62 8.76 238.88 9.17 237.81 8.91 235.81 8.72 230.65 7.28 227.44 2.03 221.28 7.09 49.16 18.95 46.10 32.77 42.65 1866.14 -18.28 37.48 31.46 48.93 40.01 1959.17 -26.78 53.07 42.63 68.07 38.77 2052.23 -36.50 71.74 56.98 91.61 38.46 2143.05 -47.19 93.27 74.65 119.47 38.67 2233.39 -59.09 117.96 95.67 151.88 39.04 2341.50 -75.92 152.30 124.30 196.58 39.22 2485.34 -105.06 207.94 166.74 266.54 38.73 2652.91 -145.78 282.50 220.06 358.09 37.92 2818.09 -187.50 358.87 274.65 451.91 37.43 2982.79 -230.58 436.58 328.83 546.56 36.99 3148.13 -275.93 516.20 381.78 642.04 36.49 3313.55 -318.48 592.88 435.19 735.46 36.28 3480.26 -357.34 665.95 489.66 826.59 36.33 3646.63 -395.60 737.87 543.23 916.27 36.36 3816.64 -434.44 811.04 597.94 1007.63 36.40 0.00 0.00 0.38 0.37 0.28 0.29 0.91 0.69 0.07 0.10 1.89 2.89 2.06 1.53 1.76 1.58 2.23 3.18 2.89 2.80 2.39 2.80 0.65 0.35 0.44 0.28 1.16 0.11 0.27 0.21 Srvy tool type TIP MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD HWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD Tool qual type 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 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 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 8-Dec-2000 11:00:45 Page 3 of 5 Seq Measured Incl Azimuth Course ~ depth angle angle length - (ft) (deg) (deg) (ft) TVD Vertical Displ Displ Total At DLS depth section +N/S- +E/W- displ Azim (deg/ (ft) (ft) (ft) (ft) (ft) (deg) i00f) 31 4244.00 27.96 35.70 191.00 3984.98 -473.42 883.72 32 4434.00 27.94 34.74 190.00 4152.81 -513.46 956.47 33 4624.00 27.20 38.34 190.00 4321.25 -551.19 1027.11 34 4814.00 27.08 38.05 190.00 4490.33 -586.09 1095.23 35 5004.00 27.33 38.50 190.00 4659.31 -620.96 1163.42 651.42 702.78 755.08 808.68 862.48 1097.87 1186.90 1274.80 1361.43 1448.25 36 5194.00 28.50 36.49 190.00 4827.21 -657.79 1234.00 916.60 1537.17 37 5384.00 28.11 36.34 190.00 4994.49 -696.61 1306.50 970.08 1627.27 38 5575.00 30.05 36.25 191.00 5161.40 -736.78 1381.32 1025.02 1720.09 39 5765.00 29.98 36.02 190.00 5325.92 -778.16 1458.08 1081.07 1815.13 40 5956.00 29.16 33.56 191.00 5492.05 -821.14 1535.46 1134.86 1909.33 41 6146.00 29.34 36.01 190.00 5657.83 -863.49 1611.69 1187.82 2002.11 42 6336.00 28.73 36.18 190.00 5823.95 -903.70 1686.20 1242.14 2094.32 43 6527.00 28.50 35.43 191.00 5991.62 -943.99 1760.38 1295.66 2185.79 44 6717.00 28.38 34.48 190.00 6158.69 -985.04 1834.54 1347.50 2276.25 45 6806.99 27.82 42.03 89.99 6238.10 -1002.06 1867.78 1373.68 2318.53 1384.42 1396.43 1409.10 1422.82 1436.63 46 6839.00 27.88 50.09 32.01 6266.41 -1006.14 1878.13 47 6871.00 27.86 56.93 32.00 6294.71 -1008.33 1887.02 48 6902.00 27.91 65.42 31.00 6322.12 -1008.52 1893.99 49 6934.00 27.22 70.67 32.00 6350.49 -1006.96 1899.53 50 6966.00 27.05 71.57 32.00 6378.97 -1004.63 1904.25 2333.24 2347.52 2360.67 2373.32 2385.39 51 6998.00 27.09 70.97 32.00 6407.47 -1002.27 1908.93 1450.42 2397.44 52 7030.00 26.54 76.09 32.00 6436.03 -999.38 1913.02 1464.25 2409.08 53 7062.00 26.05 81.28 32.00 6464.72 -995.30 1915.81 1478.14 2419.75 54 7092.00 26.09 87.21 30.00 6491.67 -990.31 1917.13 1491.24 2428.82 55 7124.00 26.97 94.03 32.00 6520.31 -983.44 1916.96 1505.51 2437.48 56 7156.00 28.60 101.02 32.00 6548.63 -974.76 1914.98 1520.27 2445.08 57 7188.00 30.33 105.92 32.00 6576.49 -964.32 1911.30 1535.56 2451.74 58 7220.00 32.82 109.62 32.00 6603.75 -952.29 1906.17 1551.51 2457.78 59 7252.00 34.93 112.69 32.00 6630.32 -938.78 1899.73 1568.13 2463.33 60 7282.00 37.63 115.58 30.00 6654.51 -924.75 1892.46 1584.32 2468.09 RECEIVED Srvy tool type 36.40 0.40 MWD 36.31 0.24 MWD 36.32 0.96 MWD 36.44 0.09 MWD 36.55 0.17 MWD 36.60 0.79 MWD 36.59 0.21 MWD 36.58 1.02 MWD 36.55 0.07 MWD 36.47 0.77 MWD JAN 1 9 ZOO1 Oil & Gas Cons. Commission 36.39 0.64 MWD 36.38 0.32 MWD 36.35 0.22 MWD 36.30 0.25 MWD 36.33 4.00 MWD 36.39 11.76 36.50 9.99 36.65 12.80 36.83 7.89 37.03 1.39 MWD MWD MWD MWD MWD 37.23 0.86 MWD 37.43 7.42 MWD 37.65 7.34 MWD 37.88 8.68 MWD 38.14 9.90 MWD 38.45 11.38 38.78 9.27 39.14 9.86 39.54 8.49 39.94 10.65 MWD MWD MWD MWD MWD Tool qual type 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 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 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 8-Dec-2000 11:00:45 Page 4 of 5 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total # depth angle angle length depth section +N/S- +E/W- displ - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) 61 7314.00 39.83 117.34 32.00 6679.47 -908.45 1883.53 1602.24 2472.82 62 7350.00 42.84 120.74 36.00 6706.50 -888.48 1871.98 1623.00 2477.59 63 7378.00 44.39 122.61 28.00 6726.77 -871.80 1861.83 1639.44 2480.76 64 7410.00 47.63 125.21 32.00 6749.00 -851.48 1848.98 1658.53 2483.84 65 7442.00 50.69 126.71 32.00 6769.92 -829.71 1834.76 1678.12 2486.45 66 7473.00 53.43 128.91 31.00 67 7506.00 56.47 130.54 33.00 68 7538.01 58.53 131.68 32.01 69 7570.00 59.37 132.27 31.99 70 7601.00 62.04 134.60 31.00 71 7633.00 64.56 136.36 32.00 72 7663.00 67.53 138.11 30.00 73 7696.00 69.90 139.93 33.00 74 7728.00 72.30 141.24 32.00 75 7758.00 73.78 142.93 30.00 76 7791.00 76.01 144.17 33.00 77 7822.00 78.83 145.30 31.00 78 7852.00 82.03 145.79 30.00 79 7936.00 89.73 141.59 84.00 80 7967.00 90.55 142.51 31.00 6788.98 -807.40 1819.77 1697.42 2488.54 6807.93 -782.39 1802.50 1718.19 2490.22 6825.13 -757.16 1784.75 1738.53 2491.55 6841.63 -731.40 1766.42 1758.91 2492.79 6856.80 -705.77 1747.83 1778.53 2493.61 6871.18 -678.35 1727.45 1798.57 2493.78 6883.36 -651.84 1707.32 1817.18 2493.40 6895.34 -621.87 1684.11 1837.34 2492.39 6905.70 -592.19 1660.72 1856.55 2490.94 6914.45 -563.92 1638.08 1874.18 2489.15 6923.05 6929.80 6934.79 6940.82 6940.75 81 8059.00 92.74 146.95 92.00 6938.11 82 8156.00 91.20 149.80 97.00 6934.77 83 8252.00 89.62 152.99 96.00 6934.08 84 8348.00 89.97 154.24 96.00 6934.43 85 8441.00 88.56 151.82 93.00 6935.62 86 8534.00 88.87 152.01 93.00 6937.71 87 8630.00 89.55 152.12 96.00 6939.03 88 8727.00 91.47 153.90 97.00 6938.17 89 8820.00 91.89 154.93 93.00 6935.44 90 8918.00 90.07 155.86 98.00 6933.76 RECEIVED JAN i 9 Z001 -532.41 1612.45 1893.11 2486.74 -502.39 1587.75 1910.58 2484.20 -473.00 1563.36 1927.31 2481.66 -390.16 1495.92 1976.89 2479.08 -359.63 1471.48 1995.95 2479.73 -268.42 1396.42 2049.04 2479.62 -171.68 1313.88 2099.86 2477.04 -75.70 1229.62 2145.81 2473.15 20.26 1143.62 2188.47 2469.27 113.22 1060.75 2230.64 2470.01 206.20 978.72 2274.42 2476.06 302.19 893.92 2319.38 2485.69 399.'16 807.49 2363.40 2497.54 492.03 723.65 2403.55 2510.12 589.83 634.56 2444.34 2525.37 At DLS Srvy Azim (deg/ tool (deg) 100f) type 40.39 7.69 MWD 40.93 10.43 MWD 41.37 7.20 MWD 41.89 11.69 MWD 42.45 10.20 MWD 43.01 10.46 43.63 10.06 44.25 7.10 44.88 3.06 45.50 10.82 46.16 9.28 MWD 46.79 11.24 MWD 47.49 8.83 MWD 48.19 8.44 MWD 48.85 7.31 MWD 49.58 7.67 MWD 50.27 9.77 MWD 50.95 10.79 MWD 52.88 10.43 IMP 53.60 3.98 IMP 55.73 5.38 IMP 57.97 3.34 IMP 60.19 3.71 IMP 62.41 1.35 IMP 64.57 3.01 IMP 66.72 0.39 IMP 68.92 0.72 IMP 71.14 2.70 IMP 73.24 1.20 IMP 75.45 2.09 IMP Tool qual type 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 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 6-axis 6-axis 6-axis 6-axis ANADRILL SCHLUMBERGER Survey Report 8-Dec-2000 11:00:45 Page 5 of 5 Seq Measured Incl Azimuth Course TVD Vertical Displ' Displ Total At DLS Srvy Tool $ depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) lOOf) type type 91 9010.00 89.97 154.01 92.00 6933.73 681.70 551.23 2483.31 2543.76 77.48 2.01 IMP 6-axis 92 9106.00 89.52 152.71 96.00 6934.16 777.67 465.43 2526.36 2568.87 79.56 1.43 IMP 6-axis 93 9202.00 89.25 152.38 96.00 6935.19 873.66 380.24 2570.62 2598.59 81.59 0.44 IMP 6-axis 94 9296.00 88.87 151.81 94.00 6936.73 967.65 297.18 2614.60 2631.44 83.52 0.73 IMP 6-axis 95 9393.00 89.55 152.08 97.00 6938.07 1064.64 211.59 2660.22 2668.62 85.45 0.75 IMP 6-axis 96 9488.00 89.79 151.02 95.00 6938.62 1159.63 128.07 2705.47 2708.50 87.29 1.14 IMP 6-axis 97 9584.00 90.10 151.65 96.00 6938.71 1255.63 43.83 2751.52 2751.87 89.09 0.73 IMP 6-axis 98 9675.00 89.52 153.38 91.00 6939.01 1346.62 -36.89 2793.52 2793.76 90.76 2.01 IMP 6-axis 99 9767.00 90.00 154.89 92.00 6939.39 1438.55' -119.67 2833.65 2836.18 92.42 1.72 IMP 6-axis 100 9862.00 88.08 154.07 95.00 6940.99 1533.43 -205.39 2874.57 2881.90 94.09 2.20 IMP 6-axis 101 9956.00 88.39 151.87 94.00 6943.88 1627.37 -289.07 2917.27 2931.56 95.66 2.36 IMP 6-axis 102 10049.00 88.63 153.64 93.00 '6946.30 1720.32 -371.73 2959.83 2983.08 97.16 1.92 IMP 6-axis 103 10140.00 87.80 154.01 91.00 6949.13 1811.23 -453.35 2999.95 3034.01 98.59 1.00 IMP 6-axis 104 10232.00 88.11 151.97 92.00 6952.42 1903.t5 -535.26 3041.70 3088.44 99.98 2.24 IMP 6-axis 105 10321.00 89.11 153.31 89.00 6954.58 1992.11 -614.28 3082.59 3143.20 101.27 1.88 IMP 6-axis 106 10415.00 90.75 153.80 94.00 6954.69 2086.07 -698.44 3124.45 3201.57 102.60 1.82 IMP 6-axis 107 10510.00 91.99 153.30 95.00 6952.42 2181.01 -783.47 3166.76 3262.24 103.90 1.41 IMP 6-axis 108 10601.00 90.31 151.88 91.00 6950.59 2271.98 -864.23 3208.65 3323.00 105.07 2.41 IMP 6-axis 109 10694.00 90.17 154.70 93.00 6950.20 2364.94 -947.29 3250.45 3385.67 106.25 3.04 IMP 6-axis 110 10786.00 89.83 151.29 92.00 6950.20 2456.91 -1029.25 3292.21 3449.35 107.36 3.72 IMP 6-axis 111 10879.00 89.11 150.18 93.00 6951.06 2549.89 -1110.37 3337.67 3517.53 108.40 1.42 IMP 6-axis 112 10972.00 87.67 151.18 93.00 6953.68 2642.82 -1191.43 3383.20 3586.85 109.40 1.88 IMP 6-axis 113 11064.00 88.04 150.90 92.00 6957.12 2734.75 -1271.86 3427.71 3656.07 110.36 0.50 IMP 6-axis 114 11157.00 88.46 152.04 93.00 6959.96 2827.70 -1353.53 3472.11 3726.60 111.30 1.31 IMP 6-axis 115 11249.00 88.56 150.80 92.00 6962.35 2919.66 -1434.29 3516.10 3797.39 112.19 1.35 IMP 6-axis 116 11339.00 88.87 150.72 90.00 6964.37 3009.62 -1512.81 3560.05 3868.15 113.02 0.36 IMP 6-axis 117 11429.00 89.18 149.74 90.00 6965.90 3099.57 -1590.92 3604.73 3940.19 113.81 1.14 IMP 6-axis 118 11519.00 89.49 152.06 90.00 6966.95 3189.54 -1669.54 3648.50 4012.35 114.59 2.60 IMP 6-axis 119 11614.00 90.07 152.03 95.00 6967.31 3284.54 -1753.46 3693.03 4088.17 115.40 0.61 IMP 6-axis 120 11638.00 90.21 150.77 24.00 6967.25 3308.54 -1774.53 3704.52 4107.61 115.60 5.28 IMP 6-axis 121 11693.00 90.21 150.77 55.00 6967.05 3363.52 -1822.53 3731.38 4152.68 116.03 0.00 Manual Proj. MWD/LWD Log Product Delivery Customer Phillips Alaska Inc. Dispatched To: AOGCC Well No CD1-10 Date Dispatche 24-Dec-00 Installation/Rig Doyon 19 Dispatched By: Nate Rose LOG Run No. Scale Original Film No Of Prints No of Floppies No of Tapes Surveys (Paper) 2 By: ~ Please sign and return to: Received Anadrill LWD Division 3940 Arctic Bird, Suits 300 Anchorage, Alaska 99503 NRosel @anchorage.oilfield.slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, Dec '97 ALASKA OIL AND GAS CONSERVATION COPlPllSSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Chip Alvord Drilling Team Leader Phillips Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Colville River Unit CD 1-10 Phillips Alaska, Inc. Permit No: 200-171 Sur Loc: 286'FNL, 2510'FWL, Sec. 5, T1 IN, RSE, UM Btmhole Loc. 2111'FNL, 961'FWL, Sec. 4, T1 IN, RSE, UM Dear Mr. Alvord: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE J~O~/IISSION DATED this / ~ ~ day of November, 2000 dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 October 12, 2000 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Application for Permit to Drill CD1-10 Dear Sirs: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore production well from the Alpine CD1 drilling pad. The intended spud date for this well is November 26, 2000. It is intended that Doyon Rig 19 be used to drill the well. CD1-10 will be drilled to penetrate the Alpine sand horizontally. 7" casing will then be run and cemented in place. A horizontal section will then be drilled and the well completed as an open hole producer. At the end of the work program, 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. A proposed drilling program, including a request for approval of annular pumping operations. 4. A drilling fluids program summary. 5. Proposed completion diagram. 6. Proposed completion diagram with open hole isolation options. 7. Pressure information as required by 20 ACC 25.035 (d)(2). 8. Proposed cementing program and calculations. 9. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). 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 questions or require further information, please contact Scott Reynolds at 265-6253 or Chip Alvord at 265-6120. Scott D. Reynolds Drilling Engineer Attachments CC: CD1-10 Well File / Sharon AIIsup Drake Chip Alvord Mike Erwin Gracie Stefanescu Lanston Chin ATO 1530 ANO 382 ANO 384 Anadarko - Houston Kuukpik Corporation e-mail · Tommy_Thompson @ anadarko.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Ddll 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 PHILLIPS 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 25558/25559/~7~O~/5",~ 4. Location of well at surface 7. Unit or property Name ' 11. Type Bond (see 20 AAC 25.025) 286' FNL, 2510' FWL, Sec.5, T11N, R5E, UM Colville River Unit Statewide At target (=7" casing point ) 8. Well number Number 1201' FSL, 791' FEL, Sec. 32, T12N, R5E, UM CD1-10 #U-630610 At total depth 9. Approximate spud date Amount 2111' FNL~ 961' FWL, Sec. 4, T11N, R5E, UM 11/26/00 $200,000' 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and 'rVD) Property line Alpine CD1- 09 11693' MD Crosses Sec. 5 to feet 8.7' @ 300' Feet 2560 6976' TVD feet Sec 4 T11 N 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 1500' feet Maximum hole angle 90.4° Maximum su~ace 2449 psig At total depth (TVD) 3131 at psig 6920' TVD.SS 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casin~l Wei~lht Grade Couplin~l Len~lth MD TVD MD TVD (include sta~le data) 42" 16" 62.5# H-40 Weld 77' 37' 37' 114' 114' Pre-installed 12.25" 9.625" 36# J-55 BTC 2400' 37' 37' 2437' 2400' 480 Sx Arcticset III L & 230 Sx Class G 8.5" 7" 26# ' L-80 BTC-M 7905' 37' 37' 7942' 6948' 118 sx Class G N/A 4.5" 12.6# L-80 I BT-M 7568' 32' 32' 7600' 6856' 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 Cemented Measured depth True Vertical depth Structural ..... ' .... :.... ~'1 ' ' .... :! :~ ,,.~' 'i ".': ~ ~. :i ~ ......... .' Conductor ii~"';t'., i' '~ ~"~!. .~' ~':' :".:~.".":'..' Surface Intermediate 0RI$1NAL Production 0 ~ ~'"~ '''~ Liner ~' Perforation depth: measured . true vertical ? ~..<.."~' ~, ,'.' ~i::'. :' "'",::'~:'~ ".."~ .'.'-':/','''' '!' ''!''::;:~ .'?.:.;;;.i:,i.:,i ,;.:'..' :. ,~,,,.,~..,.~ ~ ;. ,.:.:, ,...,~ 20. Attachments Filing fee X Property plat BOP Sketch ........... Diverter Sketch 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 ~ ~.~.. ~ Title Drilling Team Leader Date ,/ Commission Use Only Permit Number I APl number I I · ~1~"' ~' ~ ~' 50- /~ ,,~ ,,~.,)~;,~- {~ Approvalj:l~te.../~...~ See cover letter for - Other requirements Conditions of approval Samples required Yes ~ Mud log required Yes Hydrogen sulfide measures Yes i~)~-~irecti°nal survey required l~'~'es~ No Required .working pressure for BOPE 2M 3M 5M 10M 15M Other: '5~"OO~'~', ~'~{::~ '~"~¢~5~- ORJGJ~JAL SIGNE~ ~¥ byorderof I/' Approved by D Tavlnr ¢~,~,,,~_~ commissioner the commission Date Form 10-401 Rev. 7-24-89 i~Ul I| Submit in triplicate Alpine: CDI-IO Procedure 1. Install diverter. Move on Doyon 19. Function test diverter. . . 5. 6. 7, 8. . 11. 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 h°le. Perform leak off test. Drill 8-1/2" hole to the 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. Minimum acceptable leak off for drilling ahead is 11.5 ppg EMW. Drill 6 1/8" horizontal section to well TD, 12. 13. 14. 15. 16, 17. 18. Contingency - set open hole isolation equipment 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 Y:~, 12.6 #, L-80 tubing with SSSV nipple, gas lift mandrels and production packer. Land hanger. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 psi / 30 mins. Shear out valve in lowermost gas lift mandrel. Circulate tubing to diesel and install freeze protection in the annulus 19. 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. CD1-09 will be the closest well to CD1-10 (10.1 at 100' MD). Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 8.7' at 300' MD. Drillin.q Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: The 6 1/8" wellbore may cross a small fault, roughly 1500-2000' from casing point. Loss circulation is possible. In the event losses are encountered, conventional LCM treatments will be used. 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. Annular Pumpin_~ Operations: Incidental fluids developed from drilling operations on well CD1-10 will be injected into the annulus of a permitted well. The CD1-10 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. 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 CD1-10 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 AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (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 CD1-10 DRILLING FLUID PROGRAM SPUD to Intermediate hole to 7" Production Hole 9-5/8"surface casing casing point - 8 1/~,, Section - 6 1/8" point- 12 ~" Density 8.8 - 9.6 ppg 9.6 - 9.8 ppg 9.2 ppg PV 10-25 10-15 YP 20 - 60 15 - 25 25 - 30 Funnel Viscosity 100 - 200 Initial Gels 4 - 8 10 - 15 10 minute gels <18 12 - 20 APl Filtrate NC - 10 cc / 30 min 4 - 12 cc/30 min (drilling) HPHT Fluid Loss at 160 12 - 14 cc/30 min PH 8.5 - 9.0 9.0 - 10.0 9.0 - 9.5 KCL 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: Fresh water gel / 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 9.8 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. 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% KCl, with _+ 30PPB calcium carbonate bridging material to minimize formation damage. FIo-Vis Polymer and DuaI-FIo starch will be used for viscosity and fluid loss control respectively. Colville River Field ( CD1-10 Production Well Completion Plan 16" Conductor to 114' Updated 10/12/00 4-1/2" Camco BAL-O SSSV Nipple (3.812" ID) at 1700' TVD - Isolation Sleeve with DB-6 No-Go Lock (3,812" OD) run in profile - Dual 1/4" x 0.049" s/s control lines 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2437' MD / 2400' TVD cemented to surface End thermal centralizers, @ 2400' TVD WRDP-2 SSSV (2.125"1D) w/DB-6 No-Go Lock (3.812" OD) - to be installed later Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK~2 Latch 4-1/2" 12.6 ppf L-80 IBT Mod. R3 tubing run with Jet Lube Run'n'Seal pipe dope Packer Fluid mix: 9.6 ppg KCI Brine with 2000' TVD diesel cap Tubing Supended with diesel to lowest GLM Start thermal centralizers. 1 per joint from 4500' TVD Camco KBG-2 GLM (3.909" ID) at 5200' TVD for E Dummy with 1" BK-2 Latch Camco KBG-2 GLM (3.909" ID) & 1" Camco DCK-2 Shear Valve ~nned' for casing side shear @ +/- 2000 psi set 2 joints above the X landing nipple Baker $3 Packer at +/- 7512' MD TOC @ +/- 7276' MD (500' MD above top Alpine) Top Alpine at 7776' MD / 6923' TVD Completion MD TVD Tubing Hanger 32' 32' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco BAL-O SSSV Nipple 1700' 1700' End thermal centralizers 2437' 2400' 4-1/2", 12.6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 3578' 3400' 4-1/2", 12.6#/ft, IBT-Mod Tubing Start thermal centralizers. 4830' 4500' (1 per joint) Camco KBG-2 GLM (3,909" ID) 5629' $200' 4-1/2", 12,6#/ft, IBT-Mod Tubing Camco KBG-2 GLM (3.909" ID) 7402' 6736' 4-1/2" tubing joints (2) HES "X" (3,813" ID) 7461' 6775' 4-1/2" tubing joint (1) Baker S3 Packer 7512' 6809' 4-1/2" tubing joint (2) HES "XN" (3.725" ID) 7588' 6850' 4-1/2" 10' pup joint WEG (+/- 60 deg) 7600' 6856' Well TD at 11,693' MD / 6976' TVD .... ":" .' . ~"':"' ~' "; .... :"...: :' ;":':~'1... · ;.' . :., ", ..... ; .' ',' 1'.. '""1 i.,:, .. ~.-.~.-m-,---..~__.-.,.-.?-~.-...-~. _4 ',: ,. "... ' "~.;.. ' .. ', r...,,.,. :.. ,.. 7" 26 ppf L-80 BTC Mod Production Casing @ 7942' MD / 6948' TVD @ 88 deg (' Colville River Field ,i CDI-IO Production Well Completion Plan Formation Isolation Contingency Options 16" Conductor to 114' 4-1/2" Camco BAL-O SSSV Nipple (3.812" ID), WRDP-2 SSSV (2,25" ID) and DB-6 No-Go Lock (3,812" OD) with dual 1/4" x 0,049" s/s control line @ 1700' TVD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2437' MD / 2400' TVD cemented to surface End thermal centralizers. @ 240O' TVD Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-2 Latch 4-1/2" 12,6 ppf L-80 IBT Mod, R3 tubing run with Jet Lube Run'n'Seal pipe dope Start thermal centralizers. 1 per joint from 4500' TVD Camco KBG-2 GLM (3.909" ID) at 5200' TVD for E Dummy with 1" BK-2 Latch Updated 10/12/00 (A) Bonzai ECP Assembly - Baker ZXP Packer (4.75" ID) - Baker HMC Liner Hanger - ×O to IBT-Mod - blank 4-1/2" joints (TBD) - Cementing Valve - Baker Payzone ECP (mud inflated) -Landing Collar - 4-1/2" joint (1- 2) blank - Guide Shoe (B) Open Hole Scab Liner - Baker Payzone ECP (cement inflated) - 4-1/2" joints (TBD) blank tbg - Baker Payzone ECP (cement inflated) - Baker Model XL-10 ECP (anchor) - Muleshoe / Entry Guide (C) Open Hole Bridge Plug Assembly - Baker Payzone ECP (cement inflated) -XO -Float Collar - 4-1/2" Float Shoe TOC @ +/- 7276' MD (500' MD above top Alpine) Camco KBG-2 GLM (3.909" ID) & 1" Camco DCK-2 Shear Valve Pinned for casing side shear @ 2000 psi ...~~et 2 joints above the X landing nipple ~'\~; Well TD at ~ ~t~ Baker S3 Packer set at +/- 7512' 11,693' MD I ........ 'm ....... .... ! 7" 26 ppf L-80 BTC Mod Production Casing @ 7942' MD / 6948' TVD @ 88deg CD1-10 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 this well: Casing Size Csg Setting Fracture Pore pressure ASP Drilling (in) Depth Gradient (lbs./ (psi) (psi) MD/TVD(ft) gal) 16 114 / 114 10.9 52 53 9 5/8 2437 / 2400 14.2 1086 1532 7" 7942 / 6948 16.0 3144 2449 N/A 11693 / 6976 16.0 3157 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) - 0.1ID Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in Ib./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 Drilling below conductor casing (16") ASP = [(FG x 0.052)-0.1} D = [(10.9 x 0,052)-0.1] x 114 = 53 psi OR ASP = FPP - (0.1 x D) = 1086 - (0.1 x 2400') = 846 psi 2. Drilling below surface casing (9 5/8") ASP = ASP = [(FG x 0.052)-0.1} D [(14.2 x 0.052) - 0.1] x 2400 = 1532 psi OR FPP - (0.1 x D) 3144 - (0.1 x 6948) = 2449 psi 3. Drilling below intermediate casing (7") ASP = FPP - (0.1 x D) = 3144 - (0.1 x 6948') = 2449 psi Alpine CD1-10 ANTICIPATED PORE PRESSURE, MUD WEIGHT, AND FRACTURE GRADIENT 500 -500 -1500 -2500 -3500 ~4500 -5500 -6500 -7500 10 11 12 13 14 EQUIVALENT MUD WEIGHT 15 16 17 Alpine, CD1-10 Well Cementinq Requirements 9 518" Surface Casing run to 2437 MD ! 2400' TVD. Cement from 2437' MD to 1937' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 1937' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 50% excess below the permafrost. Lead slurry: (1937'-1556') X 0.3132 ft3/ft X 1.5 (50% excess) = 179 ft3 below permafrost 1556' X 0.3132 ft3/ft X 4 (300% excess) -~ 1949.4 ft3 above permafrost Total volume = 179 + 1949.4 = 2128.4 ft° => 480 Sx @ 4.44 ft3/sk System: Tail slurry: 480 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% BWOW1 D044 freeze suppressant 500' X 0.3132 ft3/ft X 1.5 (50% excess) = 234.9 ft3 annular volume 80' X 0.4341 ft~/ft = 34.7 ft~ 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 ftS/sk 7" Intermediate Casing run to 7942 MD / 6948' TVD Cement from 7942' MD to +/- 7276' MD (minimum 500' MD above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: (7942' - 7276') X 0.1268 ft3/ft X 1.4 (40% excess) = 118.2 ft3 annular volume 80' X 0.2148 ft3/ft = 17.2 ft~ shoe joint volume Total volume = 118.2 + 17.2 = 135.4 ft3 => 118 Sx @ 1.15 ft~/sk System: 118 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.15 ft3/sk 1 By Weight Of mix Water, all other additives are BWOCement Structure: CD~I I~: 1 FTeld: Alpine Field Loccrtlan: North Slope, AlaskaI East (feet) -> 500 0 500 SOO 9130 12~0 1500 1800 2100 24~ 2700 3000 3300 3600 39~0 ! 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 36.89 AZIMUTH 2375' (TO TARGET) *~Plane of Proposal,e, TRUE Begin Albian-97 A ),ne I TARDET LOCATION: Target - Csg Pt J 1201' FSL, 791' FEL SEC. 32, T12N, RSE EOC g 5/8 Casing Pt C-30 Base Permafrost KOP West Sak SURFACE LOCATION: 266' FNL, 2510' FWL SEC. 5, T11N, R5E Begln Final Drop 'EOC Base Alpine TD LOCATION: I TD - Csg Pt 2111' FNL, g61' FWL I SEC. 4, T11N, R5E 3300 3OOO 27O0 24OO 2100 1 BOO 1500 12oo Z 0 900 ~ 600 --~ 30O 6OO 1200 1500 1800 2100 Phillips Alaska, Inc. Structure: CDt~I Well: 10 Reid: Alpine Field LeGation: North Slope. Alaska 1200 1800 2000 240O 280O 5200 36O0 4OOO 44O0 48OO 5200 5600 6OOO 6400 68OO 7200 400 ~ RKB Elevation: 56' West Sak 36.89 AZIMUTH 2375' (TO TARGET) ***Plane of Pmposal*** KOP Base Permafrost 3.00 6.00 g.o0 DIS: 3.00 deg per 100 ft 12.00 15.0O 18.00 21.00 C-40 24.00 27.00 30 97(CC8- Casing Pt C-20 1~-3 K-2 TANGENT ANGLE 28.65 DEG Nbian-g7 Begin Bid/Tm to Albian-96 DIS: 9.00 deg per 100 ft 0 45.74 K- 1 TD - Cs9 P*t Pt i i i i i f i i i i i i i i i i i 0 400 800 1200 1600 2000 2400 2800 5200 Verficol Section (feet) -> Azimuth 56.89 with reference 0.00 S, 0.00 E from slot #10 Phillips Alaska, Inc. Structure: CD~I Well: 10 Reid: Alpine Reid Location: NoHh Slope, Alaska ! 51.94 AZIMUTH 3367' (TO TD) ***Plane of Propoaal***, 5800 8000 8200 Q) 6400 ,4.- (~ 8800 >. '~ 6800 I V 7000 Nbian-g7 ~ Alblan-g6 /Begin Bid/I'm to Tgt 28 78 28.30 ~ 28.58 }[ DLS: g.o0 dog per 100 ft .~3.05 ~ H~ 38.95~ K 1 45.7~ I - ~ · TARGET ANGLE 88 DEG TANGENT ANGLE 90.39 DEG FINAL ANGLE 89.33 DEG 7200 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 i i i I I i i i i i i i i i i i i i 1200 1000 800 800 400 200 0 200 400 6IX) 800 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 Vertical Section (feet) -> Azimuth 151.94 with reference 0.00 S, 0.00 E from slot ~10 by bmlahael For: S l~eynold~ Dote plotted: 11 Phillips Alaska, Inc. Sfrucfure: CO~l Field: Alpine Field Well: 10 Location: Norlh Slope, Alaska Point West Sak KOP Base Permafrost C-40 C-30 9 5/8 Casing Pt EOC C-20 K-3 K-2 Albian-97 Albian-96 Begin Bid/Tm to TgtW HRZ K-1 LCU Miluveach A Alpine D Alpine TargeL - Csg Pt EOC Begin Final Drop EOC Base Alpine TD - Csg Pt PROFILE MD 1046.00 1500.00 1556.01 2196.52 2452.65 2457.16 2455.12 2848.49 4055.65 4301.43 6358.33 6762.87 6831.80 7211.41 7388.11 7557.08 7700.26 7717.20 7776.56 7942.22 8180.77 901 6.72 9122.20 9722.1.3 1693.31 COMMENT DATA Inc Dir TVD North East V. Sect Deg/1 O0 0.00 36,89 1046,00 0.00 0.00 0.00 0,00 0,00 36.89 1500.00 0,00 0.00 0.00 0.00 1.68 36.89 1556.00 0.66 0.49 0.82 5.00 20.89 36.89 2181.00 100.41 75.55 125.54 3.00 27.98 56.89 2396.00 178.54 155.99 225.22 5.00 28.11 56.89 2400.00 180.24 155.27 225.35 5.00 28.65 36.89 2415.81 187.07 140.39 233.89 3.00 28.65 36.89 2761.00 337.94 253.62 422.52 0.00 28.65 36.89 3801.00 792.46 594.74 990.81 0.00 28.65 36.89 4036,00 895.17 671.82 1119.22 0.00 28.65 36.89 5841.00 1684.03 1263.85 2105.54 0.00 28.65 36.89 6196.00 1839.18 1380.29 2299.52 0.00 28.65 36.89 6256.48 1865.62 1400.13 2332.57 0,00 33.66 1 05.48 6591.00 1911.71 1560.94 2465.97 9.00 44.90 1 23.45 6728.00 1863.96 1 660.80 2487.72 9.00 55.86 133.53 6823.00 1792.18 1749.78 2483.73 9.00 68.58 141,86 6899.00 1685.35 1846.18 2456.15 9.00 69.92 142.63 6905.00 1672.83 1 855.88 2451.96 9.00 74.64 145.22 6923.00 1627.29 1889.03 2455.44 9.00 88.00 151.98 6948.00 1487.65 1974.07 2574.81 9.00 90.39 151.98 6951.36 1277.10 2086.11 2275.67 1.00 90,39 151.98 6945.74 559.14 2478.80 1919.18 0.00 89.35 151.94 6946.00 446,04 2528.59 1874.48 1.00 89..35 151.94 6955.00 -85.51 2810.61 1620.55 0.00 89.33 151.94 6976.00 -1822.60 3737.91 786.09 0.00 Phillips Alaska, Inc. Location: North Slope, Alaska Structure: Field: Alpine Field ' -320 330 340 1500 350 TRUE NORTH 0 20 30 40 50 290 28O 80 270 2 0 90 260 100 25O 10 240 :00 190 1200 15O 140 1 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well c~ ~ ~e~ For: S Reynolds1 Dat~ ~: 1 I-~-~ I ~ ~m b ~1-10 V~. 310 · 300, · · 290 320 330 Phillips Alaska, Inc. Sfrucfure: CD#I Field: Alpine Field Well: 10 Location: North Slops, Alaska 340 TRUE NORTH 350 0 7O 10 2O 3O zoo 40 5OO tO0 .e-5bO · 500 50 o 60 7O 280 8O 27O 9O 26O 100 250 110 240 120 =o~20 ~ ~oo 210 206' 500 90( 140 1 lOO 180 170 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well Phillips Alaska, Inc. Structure: CDt1 Field: Alpine Fleld Well: 10 Location: North Slope, Alaeka East (feet) -> 12OD 1400 1600 1 BOO 20130 2200 2400 2600 2800 3000 3200 3400 3.800 3800 4DOD 6948 .~100 411 12oo /00~00 1000 5700 35O0 611 39OO 1600 1400 1200 1000 80O 80O 6OO 4OO 2OO 2O0 4OO 1000 1200 14.00 1600 1800 20OO 9700 39(X] 3900 43OO 2700 2900 3100 3500 3700 5900 EG00 3500 5700 5100 4100 4.3,00 4.50O 3900 43O0 4.500 4900 5100 5700 5300 3900 4100 4300 4,500 4700 100 4900 4G00 5100 5300 '~00 5500 6976 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 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 East (feet) -> 600 2OO 20O 400 I 600 800 1000 1200 1400 1600 1800 2000 4000 Phillips Alaska, Inc. Structure: CD#I Well: 10 Field: Alpine Field Location: North Slope. Alaska East (feet) -> 600 700 500 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2200~~00 2100 200O 1900 /1 O0 1800 1700 1500 6500 ~oo' 6900 ~ 51'00 ~ ~500 · 5300~ ~ ~900 · · '~, 3700 · · '~ 6900 · · · 25OO 2400 23OO 2100 1900 ~ 4~00 r 5300 . ~'3300 1400 ';100 ' 1400 · · ,~100 1~00 ~900 1~00 · · ~7oo , ;?oo 1800 1700 Z 0 1600 ~Y' 1500 I~ . ~900 1200 ,' ~ 1100 1200 1100 4500 1000 ,~700 o,.4~00 1000 900 - 900 ~ '2500 . .- 4~ ~0 ~00 ~oo ..~0o soo 700 · 800 700 800 g00 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 East (feet) -> 160 200 240 g60 Phillips Alaska, Inc. Structure: CD#I Field: Alpine Field Well: 10 Location: North Slope, Alaska East (feet) -> 280 320 ,360 400 440 4~0 520 560 840 680 720 980 920 88O 8OO 760 720 68O 64O 6OO 56O 520 48O 44O 400 360 320 28O 240 160 200 ,540O ,5§00 5600 5700 5800 5900 60O0 3400~' · 3300/ 3200f · · · ~loo/ · 3000/ · · 29DD,~' 2800 · · 2700 · · · · e '1800 280 3600, 240 ,, hoo .,.2~o ., 2~oo 320 360 4OO 44O 48O East (feet) -> 3700 6200 , iaaa · . o2~o 33OO 3800 6300 6400 ,5000 · · · · .2~oo 920 880 3600 3900 64O ]400 1300 200 8O0 1100 1000 Xgo0 760 720 650{7s'~100 680 A 600 ~j. 560 ~ 52O 480 ..-2~'00 440 . e. 2~0 4O0 360 320 28O 240 520 560 600 640 680 720 iPhillips Alaska, Inc 1200 1400 1600 1800 2000 lBO0 1000 6O0 4O0 2O0 0 20O East (feet) -> 6100 5900 3900 8948 5500 9700 4300 3go0 3900 2700 2900 3100 5500 3700 5900 ~'~' .... .,,oo , .4500 1600 1400 lO00 1200 East (fee)) -> 0 /Phillips Alaska, Inc. East (feel) -> Eesf (feel) -> /800 0 Z 1900 1800 1700 iPhillips Alaska, fne. ~5500 A - East (feet) -> 400 ,,,4o ,~8o ~ 5~o 560 ~oo 3500 520 - 48O 280 240 · 200 240 280 520 560 40O /x - 800 0 40O 520 60 ¢0 20 /h o ~ 1100 20 60 ¢0 20 Phillips Alaska, Inc. Structure : CD#1 Well : I0 I Field : Alpine FJetd Location: North Slope, Alaskai East (feet) ·,,,2200 1000 ~ 900 1200 ~oo ,' 80o / 180 160 200 220 300 ~ 280 / 6OO East (feet) -> 20 1600 1700 40 60 z ,520 300. Phillips Alaska, Inc Sfrucfure : CD#1 Well: I0 j 33O 540 TRUE NORTH 350 0 7O 2O \ ~30 ~S00 40 ~oo 50 6O 290 7O 280 8O 270 9O 260 100 250 !10 240 I20 ~250 ,500 Normal Plane Travelling Cylinder - Feet 180 14.0 1500 1so .... . All depths shown are Measured depths on Reference Well -3.20 JO 300 290 Phillips Alaska, Inc Structure: CD#1 Well : 10 TRUE NORTH \ 20 ! 5O 280 8O 270 2 0 90 260 lO0 25O 24O 10 20 500 190 1 140 Normal Plane Travelling Cylinder - Feet All depths shown ere Measured depths on Reference Well Phillips Alaska, Inc. CD%1 10 slot ~10 Alpine Field North Slope, Alaska PROPOSAL LISTING Baker Hughes INTBQ Your ref : CD1-10 Version#4 Our ref : prop3034 License : Date printed : 11-0ct-2000 Date created : 1-Ju1-1998 Last revised : 11-Oct-2000 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred on nT0 20 37.100,w150 56 46.041 Slot location is nT0 20 34.287,w150 55 32.703 Slot Grid coordinates are N 5975841.362, E 385936.194 Slot local coordinates are 285.58 S 2510.37 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Phillips Alaska, Inc. CD%1,10 Alpine Field,North Slope, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 0.00 0.00 0.00 0.00 100.00 0.00 36.89 100.00 200.00 0.00 36.89 200.00 300.00 0.00 36.89 300.00 400.00 0.00 36.89 400.00 500.00 0.00 36.89 500.00 600.00 0.00 36.89 600.00 700.00 0.00 36.89 700.00 800.00 0.00 36.89 800.00 900.00 0.00 36.89 900.00 1000.00 0.00 36.89 1000.00 1046.00 0.00 36.89 1046.00 1100.00 0.00 36.89 1100.00 1200.00 0.00 36.89 1200.00 1300.00 0.00 36.89 1300.00 1400.00 0.00 36.89 1400.00 1500.00 0.00 36.89 1500.00 1556.01 1.68 36.89 1556.00 1600.00 3.00 36.89 1599.95 1700.00 6.00 36.89 1699.63 1800.00 9.00 36.89 1798.77 1900.00 12.00 36.89 1897.08 2000.00 15.00 36.89 1994.31 2100.00 18.00 36.89 2090.18 2196.32 20.89 36.89 2181.00 2200.00 21.00 36.89 2184.43 2300.00 24.00 36.89 2276.81 2400.00 27.00 36.89 2367.06 2432.63 27.98 36.89 2396.00 2437.16 28.11 36.89 2400.00 2455.12 28.65 36.89 2415.81 2500.00 28.65 36.89 2455.19 2848.49 28.65 36.89 2761.00 3000.00 28.65 36.89 2893.95 3500.00 28.65 36.89 3332.72 4000.00 28.65 36.89 3771.49 4033.63 28.65 36.89 3801.00 4301.43 28.65 36.89 4036.00 4500.00 28.65 36.89 4210.25 5000.00 28.65 36.89 4649.02 5500.00 28.65 36.89 5087.79 6000.00 28.65 36.89 5526.55 6358.33 28.65 36.89 5841.00 6500.00 28.65 36.89 5965.32 6762.87 28.65 36.89 6196.00 6831.80 28.65 36.89 6256.48 6900.00 26.78 49.48 6316.91 7000.00 26.30 69.68 6406.56 7100.00 28.58 88.66 6495.47 7200.00 33.05 103.98 6581.47 PROPOSAL LISTING Page 1 Your ref : CD1-10 Version#4 Last revised : 11-0ct-2000 R E C T A N G U L A R Dogleg Vert C O 0 R D I N A T E S Deg/100ft Sect 0.00 S 0.00 E 0.00 0.00 0.00 S 0.00 E 0.00 0.00 0.00 S 0.00 E 0.00 0.00 0.00 S 0.00 B 0.00 0.00 0.00 S 0.00 E 0.00 0.00 0.00 S 0.00 E 0.00 0.00 0.00 $ 0.00 E 0.00 0.00 0.00 S 0.00 E 0.00 0.00 0.00 S 0.00 E 0.00 0.00 0.00 S 0.00 E 0.00 0.00 0.00 S 0.00 E 0.00 0.00 0.00 S 0.00 E 0.00 0.00 West Sak 0.00 S 0.00 E 0.00 0.00 0.00 S 0.00 E 0.00 0.00 0.00 S 0.00 E 0.00 0.00 0.00 S 0.00 E 0.00 0.00 0.00 S 0.00 E 0.00 0.00 KOP 0.66 N 0.49 E 3.00 0.82 Base Permafrost 2.09 N 1.57 B 3.00 2.62 8.37 N 6.28 E 3.00 10.46 18.81 N 14.11 E 3.00 23.51 33.38 N 25.05 E 3.00 41.74 52.05 N 39.06 E 3.00 65.08 74.76 N 56.11 E 3.00 93.48 100.41 N 75.35 E 3.00 125.54 C-40 101.46 N 76.14 E 3.00 126.85 132.06 N 99.11 E 3.00 165.12 166.49 N 124.95 E 3.00 208.16 178.54 N 133.99 E 3.00 223.22 C-30 180.24 N 135.27 E 3.00 225.35 9 5/8" Casing Pt 187.07 N 140.39 E 3.00 233.89 E0C 204.28 N 153.31 E 0.00 255.41 337.94 N 253.62 E 0.00 422.52 C-20 396.04 N 297.23 E 0.00 495.17 587.80 N 441.14 E 0.00 734.93 779.56 N 585.06 E 0.00 974.68 792.46 N 594.74 E 0.00 990.81 895.17 N 671.82 E 0.00 1119.22 K-2 971.32 N 728.97 E 0.00 1214.44 1163.08 N 872.89 E 0.00 1454.20 1354.85 N 1016.80 E 0.00 1693.96 1546.61 N 1160.72 E 0.00 1933.71 1684.03 N 1263.85 E 0.00 2105.54 Albian-97 1738.37 N 1304.63 E 0.00 2173.47 1839.18 N 1380.29 E 0.00 2299.52 Albian-96 1865.62 N 1400.13 E 0.00 2332.57 Begin Bld/Trn to Tgt 1888.70 N 1421.65 E 9.00 2363.95 1911.08 N 1459.63 E 9.00 2404.65 1919.35 N 1504.40 E 9.00 2438.14 1913.30 N 1554.88 E 9.00 2463.60 Ail data is in feet unless otherwise stated. Coordinates from slot #10 and TVD ~rom Estimated RKB (56.00 Ft above mean sea level). Bottom hole distance is 4158.60 on azimuth 115.99 degrees from wellhead. Total Dogleg for wellpath is 132.03 degrees. Vertical section is from S 0.00 E 0.00 on azimuth 36.89 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. CD%1,10 Alpine Field,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S 7211.41 33.66 105.48 6591.00 1911.71N 1560.94E 7300.00 38.95 115.58 6662.43 1893.10N 1609.80E 7388.11 44.90 123.45 6728.00 1863.96N 1660.80E 7400.00 45.74 124.39 6736.36 1859.24N 1667.82E 7500.00 53.06 131.30 6801.45 1812.54N 1727.51E 7537.08 55.86 133.53 6823.00 1792.18N 1749.78E 7600.00 60.70 136.98 6856.07 1754.16N 1787.41E 7700.00 68.56 141.85 6898.90 1685.54N 1846.03E 7700.26 68.58 141.86 6899.00 1685.35N 1846.18E 7717.20 69.92 142.63 6905.00 1672.83N 1855.88E 7776.36 74.64 145.22 6923.00 1627.29N 1889.03E 7800.00 76.54 146.22 6928.88 1608.37N 1901.93E 7900.00 84.59 150.30 6945.27 1524.55N 1953.74E 7942.22 88.00 151.98 6948.00 1487.65N 1974.07B 7942.24 88.00 151.98 6948.00 1487.64N 1974.08E 8042.24 89.00 151.98 6950.62 1399.39N 2021.04E 8142.24 90.00 151.98 6951.49 1311.12N 2068.01E 8180.77 90.39 151.98 6951.36 1277.10N 2086.11E 8500.00 90.39 1S1.98 6949.21 995.29 N 2236.07E 9000.00 90.39 151.98 6945.85 553.90 N 2470.95B 9016.72 90.39 151.98 6945.74 539.14N 2478.80E 9100.00 89.55 151.95 6945.78 465.64N 2517.95E 9122.18 89.33 151.94 6946.00 446.06N 2528.38E 9122.20 89.33 151.94 6946.00 446.04N 2528.39E 9500.00 89.33 151.94 6950.41 112.69N 2706.11E 9722.13 89.33 151.94 6953.00 83.31 S 2810.61E 10000.00 89.33 151.94 6956.24 328.49 S 2941.33E 10500.00 89.33 151.94 6962.08 769.67 S 3176.54E 11000.00 89.33 151.94 6967.91 1210.85S 3411.75E 11500.00 89.33 151.94 6973.74 1652.03S 3646.97E 11693.31 89.33 151.94 6976.00 1822.60 S 3737.91 E 11693.33 89.33 151.94 6976.00 1822.62 S 3737.91 E PROPOSAL LISTING Page 2 Your ref : CD1-10 Version#4 Last revised : 11-0ct-2000 Dogleg Vert Deg/100ft Sect 9.00 2465.97 HRZ 9.00 2480.41 9.00 2487.72K-1 9.00 2488.16 9.00 2486.64 9.00 2483.73LCU 9.00 2475.91 9.00 2456.21 9.00 2456.15 Miluveach A 9.00 2451.96 Alpine D 9.00 2435.44 Alpine 9.00 2428.05 9.00 2392.11 9.00 2374.81 Target - Csg Pt 9.00 2374.80 CD1-10 Tgt/CsgPt Rvsd21-Sep-00 1.00 2332.41 1.00 2290.00 1.00 2273.67 EOC 0.00 2138.29 0.00 1926.27 0.00 1919.18 Begin Final Drop 1.00 1883.89 1.00 1874.49 E0C 1.00 1874.48 CD1-10 IntermPt Rvsd21-Sep-00 0.00 1714.56 0.00 1620.53 Base Alplne 0.00 1502.90 0.00 1291.24 0.00 1079.58 0.00 867.93 0.00 786.09 TD - Csg Pt 0.00 786.09 CD1-10 Toe Rvsd 21-Sep-00 Ail data is in feet unless otherwise stated. Coordinates from slot %10 and TVD from Estimated RKB (56.00 Ft above mean sea level). Bottom hole distance is 4158.60 on azimuth 115.99 degrees from wellhead. Total Dogleg for wellpath is 132.03 degrees. Vertical section is from S 0.00 E 0.00 on azimuth 36.89 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. CD#l,10 Alpine Field,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : CDi-10 Version#4 Last revised : 11-0ct-2000 Comments in wellpath ==================== MD TVD Rectangular Coords. Comment 1046.00 1046.00 0.00 S 0.00 E West Sak 1500.00 1500.00 0.00 S 0.00 E KOP 1556.01 1556.00 0.66 N 0.49 E Base Permafrost 2196.32 2181.00 100.41 N 75.35 E C-40 2432.63 2396.00 178.54 N 133.99 E C-30 2437.16 2400.00 180.24 N 135.27 E 9 5/8u Casing Pt 2455.12 2415.81 187.07 N 140.39 E EOC 2848.49 2761.00 337.94 N 253.62 E C-20 4033.63 3801.00 792.46 N 594.74 E K-3 4301.43 4036.00 895.17 N 671.82 E K-2 6358.33 5841.00 1684.03 N 1263.85 E Albian-97 6762.87 6196.00 1839.18 N 1380.29 E Albian-96 6831.80 6256.48 1865.62 N 1400.13 E Begin Bld/Trn to Tgt 7211.41 6591.00 1911.71 N 1560.94 E HRZ 7388.11 6728.00 1863.96 N 1660.80 E K-1 7537.08 6823.00 1792.18 N 1749.78 E LCU 7700.26 6899.00 1685.35 N 1846.18 E Miluveach A 7717.20 6905.00 1672.83 N 1855.88 E Alpine D 7776.36 6923.00 1627.29 N 1889.03 E Alpine 7942.22 6948.00 1487.65 N 1974.07 E Target - Csg Pt 7942.24 6948.00 1487.64 N 1974.08 E CD1-10 Tgt/CsgPt Rvsd21-Sep-00 8180.77 6951.36 1277.10 N 2086.11 E EOC 9016.72 6945.74 539.14 N 2478.80 E Begin Final Drop 9122.18 6946.00 446.06 N 2528.38 E EOC 9122.20 6946.00 446.04 N 2528.39 E CD1-10 IntermPt Rvsd21-Sep-00 9722.13 6953.00 83.31 S 2810.61 E Base Alpine 11693.31 6976.00 1822.60 S 3737.91 E TD - Csg Pt 11693.33 6976.00 1822.62 S 3737.91 E CD1-10 Toe Rvsd 21-Sep-00 Casing positions in string ============================== Top MD Top TVD Rectangular Coords. Bot MD BotTVD Rectangular Coords. Casing 0.00 0.00 0.00S 0.00E 2437.16 2400.00 180.24N 135.27E 9 5/8' Casing 0.00 0.00 0.00S 0.00B 7942.24 6948.00 1487.64N 1974.08E 7' Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised CD1-10 Tgt/CsgPt Rvs 387933.000,5977298.000,0.0000 6948.00 1487.64N 1974.08B 19-Jun-1998 CD1-10 IntermPt Rvsd 388471.000,5976248.000,0.0000 6946.00 446.04N 2528.39E 21-Sep-1998 CD1-10 Toe Rvsd 21-S 389645.000,5973961.000,2.0000 6976.00 1822.62S 3737.91E 19-Jun-1998 Phillips Alaska, Inc. CD#1 10 slot #10 Alpine Field North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE REPORT INCLUDING POSITION UNCERTAINTIES Baker Hughes INTEQ Your ref : CD1-10 Version#4 Our ref : prop3034 License : Date printed : 11-0ct-2000 Date created : 1-Ju1-1998 Last revised : 11-0ct-2000 Field is centred on nT0 20 37.100,w150 51 37.53 Structure is centred on nT0 20 37.100,w150 56 46.041 Slot location is nT0 20 34.287,w150 55 32.703 Slot Grid coordinates are N 5975841.362, E 385936.194 Slot local coordinates are 285.58 S 2510.37 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet Proximities will incorporate eilipses- when survey tools are defined for both wells. Ellipse separation in reverse brackets, e.g. )10.2(, where available. DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath 4 Version%11,,4,CD#1 CD1-30 Version%6,,30,CD~1 PMSS <8965 - 12850'>,,30,CD#1 PMSS <565 - 9505'>,,30PHl,CD#1 PMSS <0-11300'>,,13,CD%1 PMSS <0-7331'>,,1PH1,CD%1 PMSS <5946 - 10289'>,,1,CD#1 PMSS iFR <0 - 15350'>,,9,CD#1 PMSS <0-11934'>,,gPH, CD%1 PMSS <0-12055'>,,40,CD91 PMSS <0-9236'>,,22,CD%1 PMSS <763 - 7440'>,,36PH2,CD%1 PMSS <6600 - 10654'>,,36,CD#1 PMSS <472 - 1545'>,,36PH1,CD#1 PMSS <7182 - 11170'>,,41,CD~1 PMSS <475 - 8166'>,,41PH1,CD#1 CD1-21 Version %3,,21,CD#1 CD1-15 Version %2,,15,CD%1 PMSS <0-11492'>,,27,CD%1 PMSS <562 - 12134'>,,37,CD#1 PMSS <0-9357'>,,16PH1,CD%1 PMSS <8393 - 12600'>,,16,CD#1 PMSS <0-10224'>,,39PH1,CD#1 PMSS <9146 - 13289'>,,39,CD%1 PMSS <832 - 12147'>,,25,CD#1 PMSS <9081 - 12811'>,,44,CD%1 [=MSS <297 - 9882'>,,44PE1,CD#1 PMSS <476 - 11190'>,,34,CD#1 PMSS <0-10897'>,,3,CD#1 PMSS <0-10548'>,,19,CD#1 PMSS <2827 - 11956'>,,19A, CD91 CD1-33 Version #4,,33,CD#1 CD1-28 Version ~5,,28,CD%1 CD1-20 Version %3,,20,CD91 PMSS <0-8350'>,,26PH1,CD%1 Closest a~l~roach with 3-D Minimum Distance method Last revised Distance 17-Jul-2000 )58.6( 25-Sep-2000 6375.8 1-0ct-2000 )199.1( 25-Sep-2000 )199.1( 27-Sep-2000 )27.4( 29-Feb-2000 )88.7( 27-Jun-1999 )88.7( 5-Sep-2000 )8.7( 14-Jul-2000 )9.3( 5-Sep-2000 )299.1( 11-~ul-2000 )76.5( 4-Jan-2000 )259.3( 22-Dec-1999 )259.3( 4-Jan-2000 )259.3( 3-Apr-2000 )308.1( 26-Mar-2000 )308.1( 10-Aug-1999 )108.3( 5-Apr-2000 )40.2( 16-Mar-2000 )168.7( 26-Aug-1999 )268.1( 4-Jan-2000 )53.6( 25-0ct-1999 )53.6( 4-Jan-2000 )288.2( 22-Sep-1999 )288.2( 15-Mar-2000 )146.5( 23-May-2000 )339.3( 23-May-2000 )339.3( 11-May-2000 )237.8( 4-Jan-2000 )68.4( 6-Apr-2000 )88.3( 30-Apr-2000 )88.3( 11-Aug-1999 )227.4( 13-Jan-2000 )164.7( 10-Aug-1999 )98.4( 6-Mar-2000 )159.2( M.D. Diverging from M.D. 300.0 5620.0 100.0 100.0 400.0 300 0 300 0 300 0 200 0 200 0 7361 0 100 0 100 0 100 0 200 0 200 0 300 0 1100 0 200 0 300 0 600 0 600 0 500.0 500.0 400.0 200.0 200.0 300,0 300,0 500.0 500.0 600.0 1509.3 400.0 200.0 11693.3 5620.0 8520.0 8520.0 11693.3 2520.0 7259.1 8580.0 8680.0 11540.0 7361.0 100.0 100.0 8600.0 8092.2 8092.2 8460.0 4520.0 11693.3 11693.3 11693.3 11693.3 9880.0 9880.0 11693.3 8800.0 8800.0 8720.0 11693.3 500.0 500.0 11693.3 11693.3 9083.3 11693.3 PMSS <775§-11134'>,,26,CD#1 PGMS <0-10255'>,,WD2,CD#1 PMSS <0-8844'>,045PH1,CD#1 PMSS <7950-11950'>,,45,CD#1 PMSS <654 - 10956'>,,38PB1,CD#1 PMSS <9876 - 12240'>,,38,CD#1 PMSS <0-13450'>,,35,CD#1 PMSS <10803-13706'>,,24,CD#1 PMSS <0-11608'>,,42,CD#1 PMSS <10013' - 14353'>,,32,CD#1 PMSS <0-11067'>,,32PHi,CD#1 PMSS <8464-11500'>,,22,CD#1 PMSS <384 - 14477'>,,23,CD#1 PMSS <12550 - 16023'>,,6,CD#1 PMSS <0-13308'>,,6PH, CD#1 PMSS <0-12921'>,,43,CD#1 PMSS <473 - 14364'>,,31,CD#1 PMSS <0-10504'>,,SPH1,CD#1 PMSS <9499 - 14515'>,,5,CD#1 CD1-2 Version#11,,2,CD#1 CD1-17 Version#8,,17,CD#1 PMSS (IFR) <564 - ???'>,,17,CD#1 1-Nov-1999 28-Jun-1999 4-Jan-2000 16-Nov-1999 13-Feb-2000 14-Feb-2000 24-Jul-2000 7-Aug-2000 23-Dec-1999 12-Dec-1999 4-jan-2000 il-Aug-2000 29-Aug-2000 21-Aug-2000 21-Aug-2000 31-Au~-2000 14-SED-2000 23-Jan-2000 23-Jan-2000 10-0ct-2000 27-Sep-2000 11-0ct-2000 )159.2( )53.8( )348.7( )348.7( )277.9( )277.9( )248.7( )113.6( )318.9( )217.4( )217.4( )76.5( )113.5( )38.1( )38.1( )329.7( )194.4( )47.5( )47.5( )78.5( )67.2( )64.3( 200.0 4200.0 200.0 200.0 200.0 200.0 200.0 1000.0 200.0 400.0 400.0 7361.0 800.0 600.0 600.0 100.0 900.0 300.0 300.0 300.0 800.0 600.0 11693.3 8620.0 8660.0 8660.0 11200.0 11200.0 10400.0 11560.0 8960.0 7906.0 7906.0 7361.0 11520.0 9520.0 9520.0 8900.0 8092.2 300.0 11693.3 8280.0 10200.0 10200.0 ELL PERMIT CHECKLIST . COMPAN~ELL NAME ~ ON/OFF SHORE ADMINIS__.~TRATION 1. Permit fee attached .......................... 2. Lease number appropriate~ ~ ,~ ~.i,-~././O- .~ ~/ 3. Unique well name and.number ............. ~ ~ . . ~ 4. Well located in a defined pbol .................. APPR DATE ENGINEERING 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 ............ ' ....... · N 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. ~d..equ~ate well.bore s.epar.a, tio, p. ropos, e.d. ............. 23. u a,vener reqmrea, aoes n meet regmafions ..... tW'J N ' ' 24. Drilling fluid program schematic & equip list adequate .... ~ ~ N II/~_ p~~ 25. BOPEs, do they meet regulation ................ ('~N .... '-"-7''' ' 26. BOPE press rating appropriate; test to '~,~r~ ~ ~)sig. I 27. Choke manifold complies w/APl RP-53 (May 84) ........ ~ N ' ~ - 28. Work will occur without operation shutdown ........... ~ N... . ' i 29. Is presence of H2S gas probable ................. y _ G¥ . 30. Permit can be issued wlo hydrogen sulfide measures ..... - ~ ' . 31. Data presented on potential overpressure zones ....... ,- ~, ~ . 32. Seismic analysis of shallow gas zones .......... '.". ~ ~ Y N . AP_PR DATE 33. Seabed condition survey (if off-shore) ....... '. · · ~ - Y N . ...~_/o.R.~ -C~/5) 34. Contact name/phone for weekly progress reports [ex, tory only] Y N ' . ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... APPR DATE (B) will not contaminate freshwater; or cause drilling waste .... to surface; w~ ~ (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and ~ (Ii!) will not circumvent 20 AAC 25.252 or 20 AAC. 25.412. GEOLOGY: Y N ~Z,~oo*o''· ,, Y N Y N ENGINEERING: UICIAnnular COMMISSION: 'Comments/Instructions ' . : ' ,' 0 c:\msoffiCe\wordian~diana\checklist (rev. 02/17100)
