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Home My WebLink About202-222Originated: Delivered to:29ͲNovͲ23 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & PerforatingAttn.:Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd. Anchorage, Alaska99501 Anchorage, Alaska 99518 Office: 907Ͳ275Ͳ2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concernstotheattention of the sender above WELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL # 11CͲ22 50Ͳ029Ͳ23127Ͳ00 908965028 Kuparuk River Multi Finger Caliper Field & Processed 20ͲNovͲ23 0 1 21DͲ38 50Ͳ029Ͳ22961Ͳ00 908965029 Kuparuk River Multi Finger Caliper Field & Processed 21ͲNovͲ23 0 1 31JͲ107 50Ͳ029Ͳ23366Ͳ00 n/a Kuparuk River Packer Setting Record FieldͲFinal 9ͲOctͲ23 0 1 41LͲ03A 50Ͳ029Ͳ21182Ͳ01 908347301 Kuparuk River Multi Finger Caliper Field & Processed 7ͲJanͲ23 0 1 52LͲ313 50Ͳ103Ͳ20277Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 26ͲNovͲ23 0 1 62MͲ24 50Ͳ103Ͳ20171Ͳ00 n/a Kuparuk River Patch Setting Record FieldͲFinal 21ͲDecͲ22 0 1 72PͲ415A 50Ͳ103Ͳ20383Ͳ01 n/a Kuparuk River Plug Setting Record FieldͲFinal 7ͲOctͲ23 0 1 82PͲ417 50Ͳ103Ͳ20375Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 6ͲOctͲ23 0 1 92PͲ420 50Ͳ103Ͳ20391Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 5ͲOctͲ23 0 1 10 2VͲ05 50Ͳ029Ͳ21051Ͳ00 n/a Kuparuk River Plug Setting Record FieldͲFinal 19ͲJulͲ23 0 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: 1. 1C-22 PTD:202-222 T38179 2.1D-38 PTD: 200-077 T38180 3. 1J-107 PTD: 207-107 T38181 4. 1L-03A PTD: 199-037 T38182 5. 2L-313 PTD: 198-219 T38183 6. 2M-24 PTD: 192-050 T38184 7. 2P-415A PTD: 201-226 T38185 8. 2P-417 PTD: 201-069 T38186 9. 2P-420 PTD: 201-182 T38187 10. 2V-05 PTD: 183-176 T38188 12/1/2023 11CͲ22 50Ͳ029Ͳ23127Ͳ00 908965028 Kuparuk River Multi Finger Caliper Field &Processed 20ͲNovͲ23 0 1 Kayla Junke Digitally signed by Kayla Junke Date: 2023.12.01 12:25:47 -09'00' CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Wallace, Chris D (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 1C-22 (PTD 202-222) Report of suspect IA pressure increase Date:Wednesday, June 7, 2023 7:35:11 AM Attachments:AnnComm Surveillance TIO for 1C-22.pdf From: Byrne, Jan <Jan.Byrne@conocophillips.com> Sent: Friday, June 2, 2023 9:29 AM To: Wallace, Chris D (OGC) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 1C-22 (PTD 202-222) Report of suspect IA pressure increase Chris, KRU 1C-22 (PTD 202-222) was reported by Operations yesterday to have unexplained IA pressure increase despite being bleed multiple times. The well was shut in and freeze protected. DHD will perform initial diagnostics today including a MITIA and pack off tests. If all testing passes the well may be brought on injection for a 30-day monitor period with additional diagnostics. If the MITIA fails, the well will remain shut in and further diagnostics will be performed to diagnose the communication source. A 90-day TIO trend and wellbore schematic are attached. Please let me know if you disagree or have any questions with this plan. Regards, Jan Byrne Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6471 | M: (808) 345-6886 1C-22 90-Day Bleed History WELL DATE STR-PRES END-PRES DIF-PRES CASING 1C-22 2023-05-31 2000 1000 -1000 IA Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: 14,361.0 6/11/2014 1C-22 hipshkf Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: UPDATE PATCH DETAILS & ADDED LEAK 7/11/2020 1C-22 pproven Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 29.0 Set Depth (ftKB) 108.0 Set Depth (TVD) … 108.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.83 Top (ftKB) 28.0 Set Depth (ftKB) 9,472.9 Set Depth (TVD) … 4,510.3 Wt/Len (l… 40.00 Grade L-80 Top Thread BTC-MD Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 26.0 Set Depth (ftKB) 14,609.4 Set Depth (TVD) … 6,815.2 Wt/Len (l… 26.00 Grade L-80 Top Thread BTC-MD Tubing Strings Tubing Description TUBING String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 22.9 Set Depth (ft… 14,074.2 Set Depth (TVD) (… 6,447.0 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE8RDMOD Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 22.9 22.9 0.00 HANGER 3.5" GMC GEN 5 TUBING HANGER 3.500 504.2 504.0 4.80 NIPPLE CAMCO DS LANDING NIPPLE w/ 2.875" NO GO PROFILE 2.875 13,981.8 6,389.6 52.52 NIPPLE CAMCO DS NIPPLE w/ 2.813" NO GO PROFILE 2.813 14,020.0 6,413.1 51.89 SEAL ASSY 3.000 14,023.0 6,414.9 51.82 PBR BAKER 3.5" 80-40 PBR, PINNED 30K SHEAR KBH-22 ANCHOR; spaced out 3' from fully inserted 2.980 14,047.3 6,430.0 51.22 PACKER BAKER SAB-3 PACKER w/ MILLOUT EXTENSION 3.250 14,066.3 6,442.0 50.74 NIPPLE CAMCO D NIPPLE w/ 2.75" NO GO PROFILE 2.750 14,073.3 6,446.4 50.57 WLEG BAKER WIRELINE RE-ENTRY GUIDE w/ SHEAROUT SUB; SHEARED OUT @ 4100 PSI 2.990 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 10,236. 0 4,804.0 66.96 PACKER - PATCH - UPR P2P Patch Packer (w/ 15.5' Spacer Pipe and Anchor Latch - OAL 21') 9/2/2018 1.625 CPP35186 10,240. 0 4,805.5 66.95 SPACER / ANCHOR LATCH P-110 15.5' Spacer Pipe and Anchor Latch 9/2/2018 1.600 CPAL35094 10,245. 0 4,807.5 66.95 LEAK - TUBING LEAK @ 10245' W/ Spinner & Temp. LOG 5/21/2015 10,256. 0 4,811.8 66.94 PACKER - PATCH - LWR P2P Patch Packer OAL 4' 9/2/2018 1.625 CPP35179 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Linked Zone Date Shot Dens (shots/ft )Type Com 14,340.0 14,365.0 6,627.2 6,644.7 C-4, 1C-22 1/16/2003 6.0 IPERF 2.5" PJ, 60 deg. phase Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 13,935.9 6,361.9 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 4/14/2003 5:00 Notes: General & Safety End Date Annotation 8/13/2010 NOTE: View Schematic w/ Alaska Schematic9.0 1C-22, 7/11/2020 5:01:17 PM Vertical schematic (actual) PRODUCTION; 26.0-14,609.4 IPERF; 14,340.0-14,365.0 PACKER; 14,047.3 GAS LIFT; 13,935.9 PACKER - PATCH - LWR; 10,256.0 SPACER / ANCHOR LATCH; 10,240.0 LEAK - TUBING; 10,245.0 PACKER - PATCH - UPR; 10,236.0 SURFACE; 28.0-9,472.9 NIPPLE; 504.2 CONDUCTOR; 29.0-108.0 KUP INJ KB-Grd (ft) 35.49 Rig Release Date 12/28/2002 1C-22 ... TD Act Btm (ftKB) 14,620.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292312700 Wellbore Status INJ Max Angle & MD Incl (°) 70.05 MD (ftKB) 2,036.61 WELLNAME WELLBORE1C-22 Annotation LAST WO: End DateH2S (ppm) DateComment SSSV: NIPPLE MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, June 13, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1C-22 KUPARUK RIV UNIT 1C-22 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/13/2022 1C-22 50-029-23127-00-00 202-222-0 W SPT 6430 2022220 1608 2502 2502 2497 2500 400 430 420 420 4YRTST P Austin McLeod 5/13/2022 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1C-22 Inspection Date: Tubing OA Packer Depth 1160 1810 1800 1790IA 2500 420 45 Min 1790 60 Min Rel Insp Num: Insp Num:mitSAM220514075038 BBL Pumped:1.1 BBL Returned:1.1 Monday, June 13, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.06.14 09:34:05 -08'00' ZO2.-22Z WELL LOG TRANSMITTAL DATA LOGGED (t)/14/2015 K BENDER To: Alaska Oil and Gas Conservation Comm. June 2, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECERIED JUN 0 4 2015 RE: Multi Finger Caliper (MFC)/Leak Detect Log: 1C-22 Run Date: 05/27/2015 and 05/21/2015 AOGCC The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1C-22 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-23127-00 Leak Detect Log 1 Color Log 50-029-23127-00 SCANNE JUL 1 4 Z015 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: , ) ) , Image Project Well History File Cover Page 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. ~O~ ~~~Well History File Identifier Page Count from Scanned File: I a Lf (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES Helen ~ Date: 31 ð~ If NO in stage 1, page(s) discrepancies were found: YES Organizing (done) D Two-sided 11I111111I111111111 RESCAN ~olor Items: D Greyscale Items: DIGITAL DATA D Diskettes, No. D Other, No/Type: o Poor Quality Originals: o Other: NOTES: BY: Helen (Maria ) Project Proofing BY: Helen ~~ Scanning Preparation BY: Helen~ if- x 30 = 1M Production Scanning Stage 1 BY: Stage 1 BY: Helen Maria Scanning is complete at this point unless rescanning is required. ReScanned BY: Helen Maria Comments about this file: ~scan Needed OVERSIZED (Scannable) o Maps: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: o Other:: , Date: Ô 30 OS-- 151 :() W1 I J Date:C 00 ~ OS-lsl rnp + I ð = ~-OTAL =>AGES /33 (Count d06ls not in~lude cover sheet) \/\ I1f. Date:'ð ?I) o~) 151 r r ~ I NO OS"' 151 NO Vl1 ,0 Date: 151 11111111111111 11111111111111111 Date: 151 Quality Checked 1111111111111111111 • MEMORANDUM To: Jim Regg ? Q~ ~/Z~'t~, P.I. Supervisor `~ FROM: John Crisp Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Tuesday, May 25, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1C-22 KIJPARilK RIV UNIT 1C-22 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv,~~- Comm Well Name: KUPARUK RIV UNIT 1C-22 API Well Number: 50-029-23127-00-00 Inspector Name: John Crisp Insp Num: mitJCr100524061625 Permit Number: 202-222-0 Inspection Date: 5/21/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well tc-2i 'fTYPe Inj.~N TVD 6aso '' IA 920 2z~ z16o lao '~ ~ ~ I----~ --.- p.T.D Zo22220' TypeTest j SPT ~ Test pst 1607 ~~~ QA 380 i 560 ~ 560 560 InterVal4YRTST p~F P ~ Tubing 575 570 570 ~ ~ 250 Notes: 2.5 bbls pumped for test. No problems witnessed. - Tuesday, May 25, 2010 Page 1 of 1 ConocoPhltips a P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Apri14, 2010 Mr. Dan Seamount Alaska Oil and Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Dan Seamount: • ~~N~/I APR ~ 7 2010 ~ia~ca Oil ~ Gas Cons. /~++~ rl f C~~ ~ d~- ~~ Over the last couple of weeks we have been scanning our data base to confirm we were up to date on our sealant 10-404's. In doing so, we discovered the 10-404 notifications for Wells 1C- 22, 2X-04, 3J-07 and 3J-16 were missing. Please accept our apology for not sending them in a timely manner. The attached spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Roger Winter at 907-659-7506, if you have any questions. Sinc ely, ~ Roger Winter ConocoPhillips Well Integrity Field Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 4/4110 1 C-22.2X-04.3J-07 & 3J-16 Well Name API # PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1C-22 50029231270000 2022220 NA NA NA NA 42.5 7/112007 2X-04 50029209950000 1831180 SF NA 6" NA 30 5/12/2007 3J-07A 50029214380100 2010980 13' 2.75 1'4" 6/8/2008 9.77 6/21/2008 3J-16 50029214980000 1852900 36'2" 6.25 2'7" 6/8/2008 7.65 6/21/2008 MEMORANDUM It State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ~ , K'û, /, 5- f /" '0/ . C(tl , ¡ 'l/L'V DATE: Wednesday, May 17,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IC-22 KUPARUK RIV UNIT IC-22 ...",.:,r" ~<Y' J.;-.O,...·· FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv_~1I3Æ- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT IC-22 API Well Number 50-029-23127-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS060515061021 Permit Number: 202-222-0 Inspection Date: 5/14/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ! lC-22 Type Inj. i w i TVD ¡ 1 --- 6430 IA 1450 2070 2060 2060 ¡ I ! P.T. i 2022220 :TypeTest ¡ SPT ] Test psi 1607.5 OA ! 520 600 i 600 600 i ì i , Tubing ¡ 1725 , 1725 1725 1725 Interval 4YRTST P/F P i Notes Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity. . '''Jr\PíJ ',~('. ",1'1.\,,-,(:0 J UN 1 ,Ii t.\J '"' ~"",tI"'U y,nt.;. Wednesday, May 17, 2006 Page I of I . . ... "P.-~ MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_ Inserts\Microfilm _ Marker.doc Log/ Data Type ;iog" :.Log c--(' Log \, Rpt ~ED /LOg ( --t Log Log \! Log ~L09 i Rpt ~g ~ J Ío 1=0,0 ÀÒ~ 1-- DATA SUBMITTAL COMPLIANCE REPORT 2/1/2005 Permit to Drill 2022220 Well Name/No. KUPARUK RIV UNIT 1C-22 ~ MD 14620' TVD 6822 Completion Date 1/16/2003 V Completion Status 1WINJ Current Status 1WINJ --- --- -- ------ -~~ ----- ----~ REQUIRED INFORMATION Mud Log No Samples No -- -- - -------- ------- DATA INFORMATION Types Electric or Other Logs Run: GRlRes/Dens-Neutron, SCMT Well Log Information: Electr Digital Dataset Med/Frmt Number Name -----------.-- rDensity Gamma Ray ~Neutron LIS Verification C ~1479 ._L~~.~õn ¡"'Neutron i ¡Induction/Resistivity Density /' i Induction/Resistivity ~ Gamma Ray Directional Survey U Cement Evaluation £Pérforation -- ---------- --- Well Cores/Samples Information: Name Interval Start Stop Operator CONOCOPHILLlPS ALASKA INC JJ1U\.J 7/~~~ API Nb. 60·029-23127-00-00 ~..~___.~r...".)-" , (~_UI~-2 _ Directional surv«~:) (data taken from Logs Portion of Master Well Data Maint) .-- Log Log Run Scale Media No 25 Blu 1 25 Blu 25 Blu Interval OH / Start Stop CH Received 138 14620 ~ØáSei.) 1,\1/1 0/2003 138 14620 ~ \t 1/10/2003 ~*' 138 14620 e'â"se 1/10/2003 Comments 25 25 25 25 25 138 14620 Case 1/10/2003 138 14620 Case 1/10/2003 138 14620 Case 1/10/2003 138 14620 Case 1/10/2003 138 14620 Case 1/10/2003 138 14620 Case 1/10/2003 138 14620 Case 1/1 0/2003 0 14620 Open 1/21/2003 Elevation Reference was measured from Mean Sea Level ----. 13900 14511 Case 2/14/2003 13890 14464 Case 217/2003 Sample Set Number Comments Blu Blu Blu Blu Blu 5 5 Col Blu Sent Received Permit to Drill 2022220 MD 14620 TVD 6822 ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? ..- Y I N ~ Analysis Received? -XJ-N- ---------- ---- Comments: - --- ------- ------------ -------- Compliance Reviewed By: ~ DATA SUBMITTAL COMPLIANCE REPORT 2/1/2005 Well Name/No. KUPARUK RIV UNIT 1 C-22 QperatorCONOCOPHILLlPS ALASKA INC Completion Date 1/16/2003 Completion Status 1WINJ Daily History Received? Formation Tops ~~ API No. 50-029-23127-00-00 Current Status 1WINJ &IN (J/N Date: UIC Y ~ (1 ((/~ ÀJM.) j.--~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1 . Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation D or Final 0 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added Previous totals (bbls): 4a. Well Class: Stratigraphic D Service 0 Development D Exploratory D 4b. Well Status: Oil D Gas D WAGD GINJ D WINJ D WDSPL D 5a. Sundry number: 5b. Sundry approval date: 303-014 / 303-125 (h)(3) Other Commission approved substances (include descriptions in block 12) 1/24/2003 Volume (bbls): Number of days disposal occurred 20031 1st 26944 100 0 27044 26 2003 1 2nd 21827 100 0 21927 25 2003 1 3rd 0 0 0 0 0 2003 14th 0 0 0 0 0 Total Ending Volume 48771 200 0 48971 51 (bbls): 11. Attach: Disposal Performance Data: Pressure vs. Time D Step Rate Test D Other (Explain) D 12. Remarks and Approved Substances Description(s): I hereby certify that the foregoing is true and correct to the best of my knowledge. ~r-_ . 1~ - Signature: _' --I \ ~ Printed Name: \,<-t<"'__~? ~Q-"'o..>' Title: Form 10-423 Rev. 9/2003 Date: ~ ~~\) \'~-- INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 8. API Number: 202-222 1 C-22 50-029-23127 -00 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: ~ 3/2/2003 1 C-190, 1 C-174 3/31/2003 4/2/2003 5/12/2003 1C-174, 1C-178, 1C-19 ,---- Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. ~ ( { G 10 y Lc:" .~ 2 bS- b"-6 3 0 Phone Number: Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 26944 100 0 27044 26 3/2/2003 3/31/2003 1 C-190, 1 C-17 4 21827 100 0 21927 25 4/2/2003 5/12/2003 1C-174, 1C-178, 1C-19 0 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: 4a. Well Class: Stratigraphic D Service 0 Development D Exploratory D 4b. Well Status: Oil D Gas D WAGD GINJ D WINJ D WDSPL D 5a. Sundry number: 5b. Sundry approval date: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation of Disposal 0 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added 303-014 / 303-125 (h)(3) Other Commission approved substances (include descriptions in block 12) 1/24/2003 Volume (bbls): Number of days disposal occurred Previous totals (bbls): 2003 /1 st 2003 / 2nd 2003 / 3rd 2003 / 4th Total Ending Volume (bbls): 200 o 48971 48771 11. Attach: Disposal Performance Data: Other (Explain) D 12. Remarks and Approved Substances Description(s): Pressure vs. Time D Step Rate Test D I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~ ~-"¡, l ~ Printed Name: ~ ".,( 7 ~ ""'~ Title: Date: ~ 4O-S \- e. eI\. _ L-e.-""cJ Form 1 0-423 Rev. 9/2003 INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 8. API Number: 202-222 1 C-22 50-029-23127 -00 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: , ./ - ~ .--' 51 Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. \Iu (oy Phone Number: Uó:> b"8~o Submit in Duplicate ') JPcl- d-~~) ConocoPhiUips Alaska,Jnc. TU BI NG (0-14074. OD:3.500, 10:2.992) SURFACE (0-9473. OD:9.625, Wt40.00) ~ODUCTION (0-14620. OD:7.000, Wt:26.00) NIP (13982-13983, OD:4.520) PBR (14023-14024, OD:5.870) NIP (14066-14007, OD:4.500) WLEG (14073-14074. 00:4.510) Perf (14340-14365) SHOE (14609-14610, OD:7.000) Al I.! I I ",I~-iìl . i:, , [I 1 L Annular Fluid: ReFerence Log: RKB 28' Last Tag' 14389 Last Tag Date: 4/14/2003 Casing String - ALL STRINGS Description Size CONDUCTOR 16.000 SURFACE 9.625 PRODUCTION 7.000 TLJbing'String ,¡, Untitled Size 1 Top I Bottom 3.500 0 14074 Perforations Summary Interval I TVD I Zone 14340 - 14365 6627 - 6645 C-4 Gas Lift MandrelsNalves St MD TVD Man Man Mfr Type 6362 CAMCO I'vfv1G 1 C-22 API: 500292312700 SSSV Type: Nipple Type 23 HANGER 504 NIP 13982 NIP 14023 PBR 14047 6430 PACKER 14066 6442 NIP 14073 6447 WLEG KRU 1 C-22 Well Type: INJ Orig 12/28/2002 Completion' Last W/O: Ref Log Date: TO: 14620 ftKB Max Hole Angle: 70 deg (ã>. 2037 Angle @ TS: 45 deg @ 14327 Angle @ TO: 46 deg @ 14620 Rev Reason: Tag. GLV design Last Update: 4/1612003 Top Bottom TVD Wt Grade Thread 0 108 108 62.50 H-40 WELD 0 9473 4510 40.00 L-80 BTC-MD 0 14620 14620 26.00 L-80 BTC-MD TVD Wt I Grade I Thread 6447 9.30 L-80 EUE8rdMOD I Status I Ft SPF Date I Type I Comment 25 6 1/16/2003 IPERF 2.5" PJ, 60 deg. phase V Mfr V Type VOD Latch Port TRO Date Vlv Run Cmnt DMY 1.5 RK 0.000 0 4/14/2003 (1 ) Description 3.5" GMC GEN 5 TBG HANGER CAMCO 'OS' LANDING NIPPLE WITH NO GO PROFILE CAMCO 'OS' NIPPLE WINO GO PROFILE BAKER 3.5" 80-40 PBR, PINNED 30K SHEAR KBH-22 ANCHOR; spaced out 3' from fully inserted BAKER SAB-3 PACKER W/MILLOUT EXTENSION CAMCO '0' NIPPLE WINO GO PROFILE BAKER WIRELlNE RE-ENTRY GUIDE W/SHEAROUT SUB; SHEARED OUT @4100 psi ID 3.500 2.875 2.813 2.980 3.250 2.750 2.990 6.151 14609 6815 SHOE General Notes Date Note 12/27/200~ Tree: FMC GEN V 11" 5K 3" 5000 K Tree Cap Connection: OTIS 3" f)Od--dd~ Annufar Disposal during the second quarter of 2003: h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes 3S-10 9972 100 0 10072 388 21204 31664 March April 3S-21,3S-08,3S-23 2003 2003 lC-22 21553 100 0 21653 0 27044 48697 March May lC-190, lC-174, lC-178, lC-19 2003 2003 Puviaq #1 5063 100 0 5163 0 4731 9894 March April Puviaq 1 ) 2003 2003 CD2-46 31393 100 0 31493 371 0 31864 April May 2003 CD2-51, CD2-12 2003 3S-16 31006 100 0 31106 357 0 31463 April May 2003 3S-23, 3S-17, 3S-06, 3S-16 2003 Hansen 1 47382 100 0 47482 0 67796 115278 J an uary June 2003 Hansen, Hansen 1 A 2002 lC-19 31325 100 0 31425 0 0 31425 May 2003 June 2003 lC-184, lC-170, lC-172 3S-08B 31610 100 0 31710 290 0 32000 May 2003 June 2003 3S-24, 3S-03, 3S-19 CD2-19 30860 100 0 30960 377 0 31337 May 2003 June 2003 CD2-58, CD2-52 CD2-41 3900 100 0 4000 377 0 4377 June 2003 June 2003 CD2-20 3S-17A 4559 100 0 4659 361 5020 5020 June 2003 June 2003 3S-19 Total Volumes into Annulifor which Disposal Authorization Expired during the second quarter 2003: ) Freeze Protect Total Volume Start End Source Wells Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus CD2-17 17709 100 0 372 18181 Open, Freeze Protected May 2002 Feb 2003 CD2-08, CD2-48, CD2- 46 CD2-32 31337 100 0 379 31816 Open, Freeze Protected June 2002 July 2002 CD2-19, CD2-41, CD2- 23 CD2-50 31530 100 0 370 32000 Open, Freeze Protected July 2002 Sept 2002 CD2-41, CD2- 38 ID-ll 32102 100 0 235 32437 Open, Freeze Protected May 2002 June 2002 1 D-l 03 lC-18 32251 100 0 373 32724 Open, Freeze Protected June 2002 July 2002 1 C-I 04 I' ) MEMORANDUM ) i , State of Alaska Alaska Oil and Gas Conservation Commission ~4I- TO: Randy Ruedrich Ì\¡ '1. Commissioner ~\~\07 ~~~~ THRU: Tom Maunder '\ Petroleum Engineer DATE: April 30, 2003 SUBJECT: Mechanical Integrity Tests Conoco\Phillips 1-C pad 1 C-22, PTD #202-2220 FROM: Lou Grimaldi KRU Petroleum Inspector Kuparuk River Field NON· CONFIDENTIAL Well 1 C-22 P.T.D. 2022220 Notes: Initial test. Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Inj. Type test s P Packer T.V.D. Test psi Depth 6430 1608 Tubing Casing Pretest 350 350 Initial 350 1800 15 Min. 30 Min. 350 350 1760 1750 Interval P/F I f Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover 0= Other (describe in notes) Test's Details I arrived 1 C pad earlier than arranged to look over the Multi-Phase meter setup being evaluated for allocation. The :MIT test crew showed during this inspection and started rigging up. When I finished my meter inspection I moved over to 1 e- 22 and began the :MIT test. The fIrst attempt at the test did not go well due to the rig initiating annular injection on the OA. The thermal effects played havoc with the IA pressure and the test was aborted. I spoke with the injection operator and requested that he maintain the present pump rate and once temps had stabilized, the test was restarted. The above results showed the IA to have integrity. M.I.T.'s performed: One Attachments: Number of Failures: None Total Time during tests: 2 hours cc: Jerry Detlefs M IT report form 5/12/00 L.G. MIT KRU 1C-22 04-29-03 LG.xls 5/7/2003 · t ~, ~ ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Tom_Maunder@admin.state.ak.usandBob_Fleckenstein@admin.state.ak.us ~1 )\'1\Ò~ OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk - KRU - 1 C 04/29/03 APC - Sauvageau flD ~ ,u>U1 S ) Lou Grimaldi Packer Depth Pretest Initial 15 Min. 30 Min. Well 1C-22 Type Inj S T.V.D. 6430 Tubing d.:JD 3S-Ð 3:rCJ .3.5-D Interval I P.T.D. 2022220 Type Test P Test psi 1608 Casing 3 :ro l~(' t) -0 /7 ~D /7=,D P/F f' Notes: Initial MITIA. HA~ 10 ,RGS"ÎIt'R:' TL.:>--rþ¡)~ i ott ¡"T;)'Ð /~./~ /?,3.~"·S!_-?.:~_._.,"__,_,__,_,__. roll µ.NU i (} «-. IA-.cr r: <:..1', ¿:;µ 7' J7 ¿ p!..HA ~ £,.;:-.,t:' C cIS Well Type Inj T.V.D. Tubing P.T.D. Type Test Test psi 1500 Casing Notes: Interval P/F Well Type Inj T.V.D. Tubing P.T.D. Type Test T est psi 1500 Casing Notes: Well Type Inj T.V.D. Tubing P.T.D. Type Test T est psi 1500 Casing Notes: Well Type Inj T.V.D. Tubing P.T.D. Type Test T est psi 1500 Casing Notes: Test Details: Interval P/F Interval P/F Interval P/F TYPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during W orkover 0= Other (describe in notes) MIT Report Form Revised: 05/19/02 MIT KRU 1 C-22 04-29-03.xls 4/29/2003 . ) ~ TUBING (0-14074, OD:3.500, ID:2.992) SURFACE (0-9473, OD:9.625, Wt4O.00) ~OOUCTION (0-14620, OD:7.000, Wt26.00) NIP (13982-13983, OD:4.520) PBR (14O~14024, OD:5.870) NIP (14066-14007, OD:4.500) WlEG (14073-14074, 00:4.510) Perf (14340-14365) SHOE (14609-14610, 00:7.000) ) ç'ø.,'()~q;I?'bill~þ~"'~'~:~l<~, ...Ih¢~ Annular Fluid: Reference Log: RKB 28' Last Tag: 14389 Last Tag Date: 4/14/2003 CasingStñng . ,ALL STRINGS Descñption Size CONDUCTOR 16.000 SURFACE 9.625 PRODUCTION 7.000 Tubing' String ',;, Untitled Size I Top 3.500 0 Pènoratiò'ns Summaiy , ' Interval I TVD I Zone 14340 -14365 6627 - 6645 C-4 Gas Lift'MandrelsNålvës St MD TVD Man Man Mfr Type CAMCO Mv1G 1 13936 6362 1. Sheared Other ljïÚg$',;equip;,etc.;;. JEWELRY;, Depth TVD Type 23 23 HANGER 504 504 NIP 13982 6390 NIP 14023 6415 PBR 1 C~22 API: 500292312700 SSSV Type: Nipple 14047 6430 14066 6442 14073 6447 PACKER NIP WLEG ) KRU 1 C-22 Well Type: INJ Orig 12/28/2002 Completion: Last W/O: Ref Log Date: TO: 14620 ftKB Max Hole Angle: 70 deg ~ 2037 Angle ~ TS: 45 deg @ 14327 Angle@TD: 46 deg @ 14620 Rev Reason: Tag, GLV design Last Update: 4/16/2003 Bottom 14074 Top Bottom TVD Wt Grade Thread 0 108 108 62.50 H-40 WELD 0 9473 4510 40.00 L-80 BTC-MD 0 14620 14620 26.00 L-80 BTC-MD TVD Wt I Grade I Thread 6447 9.30 L-80 EUE8rdMOD <,' .', 1, I Status 1Ft SPF I Date I Type I Comment 25 6 1/16/2003 IPERF 2.5" PJ, 60 deg. phase . -. . ~ . - ~ -~. . ~ .'" ~, " . - . ~: -" '~ 'r . : ..,~ .".: I':' .", . -,':. 'r V Mfr V Type V OD Latch Port TRO Vlv Cmnt (1 ) Date Run 4/14/2003 DMY RK o 1.5 0.000 Description 3.5" GMC GEN 5 TBG HANGER CAMCO 'DS' LANDING NIPPLE WITH NO GO PROFILE CAMCO 'OS' NIPPLE WINO GO PROFILE BAKER 3.5" 80-40 PBR, PINNED 30K SHEAR KBH-22 ANCHOR; spaced out 3' from fully inserted BAKER SAB-3 PACKER WIMILLOUT EXTENSION CAMCO 'D' NIPPLE WINO GO PROFILE BAKER WIRELlNE RE-ENTRY GUIDE W/SHEAROUT SUB; SHEARED OUT @41 00 psi ID 3.500 2.875 2.813 2.980 3.250 2.750 2.990 14609 6815 SHOE Gentmil'Nôtes:. ;-. " .- Date Note 12127/200~ Tree: FMC GEN V 11" 5K 3" 5000 K Tree Cap Connection: OTIS 3" 6.151 . I .' ~ ~ : ConocJi)hillips ) Post Office Box 100360 Anchorage, Alaska 99510-0360 Steve McKeever Phone (907) 265-6826 Email: Steve.McKeever@conocophillips.com April 18, 2003 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Sundry Application for Waiver of Volume Requirement for Annular Disposal, We1l1C-22 Dear Commissioners: With the attached Application for Sundry Approvals, ConocoPhillips Alaska, Inc. hereby applies for a waiver to the volume limitation of the regulations for annular disposal for disposal into the annulus of well 1 C-22. ConocoPhillips has a valid, current Sundry Permit for annular disposal in this well (Sundry # 303- 014, issued January 24, 2003) and has thus far disposed of +/- 34,000 barrels in this well. We would like authority to continue to dispose of additional fluids (up to 50,000 barrels) to avoid the expense and additional environmental risk of hauling and disposing of fluids at the 1 R-18 Class II disposal well. The additional 15,000 barrels of requested volume will likely enable us to complete drilling operations on 1 C-178 and drill and complete 1 C-19, another Kuparuk well to be completed with an annulus, for which we intend to request a permit for annular disposal. For data on the integrity of 1 C-22 for annular disposal, please refer to the original Application for Sundry Approvals, submitted on 1/17/03. Attached to this application please find two graphs for the annular disposal to date in Well 1 C-22. One graph is of total fluid disposed in 1 C-22 over time, and the other graph is disposal pressures over time. Thank you for your consideration of this request. If you have any questions or require any further information, please contact me at 265-6826. Sincerely, /' j .-y/ _---f? /:f(·0~ \.../-"V / ! Steve McKeever Senior Drilling Engineer RECEIVED APR 1 8 2003 Alaska Oil & Gas Cons. Commission Anchorage O~'1""!'I'~ ' ~I' , . ~,1 . 'U i {J J\ .. ) ) Note to File Kuparuk lC-22.. .202-222.. .303-125 Request to Increase Annular Disposal Volume This document considers a request by ConocoPhillips for an exception to the 35000 bbl annular disposal volume limitation specified at 20 AAC 25.080 (d) (1). CP's request is analyzed and a recommendation is made to approve their request. ConocoPhillips has applied for approval to increase the allowable volume of drilling waste into the subject wells surface casing annulus. CP requests to increase the allowed volume from 35000 bbls to 50000 bbls. The reason for the increase is that lC-22 is the only remaining available annulus on DS 1 C and CP desires to complete the present well lC-178 and lC-178Ll as well as another Kuparuk welllC-19. Of late CP has been drilling West Sak wells that cannot accommodate annular disposal since they often do not have an annulus. CP has a valid approval for annular disposal in lC-22, sundry 303-014 that was approved January 24, 2003. In support of their request, CP has provided a pressure plot that presents discreet pressure values recorded through the course of their disposal operations in lC-22. In general their pressure infonnation shows a slight decreasing trend as disposal has occurred over the past 6 - 7 weeks. The pressure infonnation indicates that the disposal operation is perfonning satisfactorily. When the original application was analyzed, Winton concluded that the surface casing had been adequately cemented and that the leak off test was satisfactory. There are no other wells within 14 mile of the 1 C-22 surface casing shoe. CP does have the option of hauling the waste to their Class II disposal well, 1 R -18 which is approximately 8 miles away. While this can be accomplished, hauling the waste does not contribute to the proper environmental management of the drilling waste and could actually increase the risk by requiring over road transport that would otherwise not be required. Based on the demonstrated satisfactory operation of the disposal operation in 1 C- 22 and the needless transportation risk associated with hauling the waste to lR-18, I recommend that ConocoPhillips' request be approved. h~) ~~under, :~~( Sr. Petroleum Engineer April 18, 2003 ) k~(¿ "'7fP vf Irtl e ) STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Abandon: Suspend: Alter casing: _ Repa~lI: Change approved program: Pull tubing: 2. Name of Operator /J/ / / · A I / Co ,vOc 0 fI"/}, / I ~ nlçs~ I Þc 3. Address PO. ßð-,< /00360 / A oNe:. lo; cy A kf Kc: 4. Location of well at surface .. /Sti'.J I F/bt.. / /327 J ,cI1.JL) Sèc /2 7// Af t< IDt£. i U M At top of productive interval / , 2/06 I rN(¡ 2305 'FlVL) ~et, s> rl /1\1 R II £1 UM At effective depth At total deptb... Ç>' 'F ' ~ _ r,...,. ;¡ 1 ð ¿O/o /lJL. / 2'1'9.3 ,l?WL) ~c 0) II/,'J ~ II ~ UM 12. Present well condition summary Total depth: measured true vertical Cemented Measured depth ?'1'ó SX Arc/f ú~f¿ I '3ðl 117'1 ð'tf¿' ,4fyc:i~s;.1 ¿,ff" ,/ 57 ß'ð~ C I~s.$ G¡ /~I 3rtJ - /~ 3'GJ" /o/() I true vertical t:, 6 2 '7 / __ ~ b 0/ S I "Tv /:J Tubing (size, grade, and measured depth) :?~ I~ 9..3 ~ ¿-Fo <é1 /~o 7'1 I Packers and SSSV (type and measured depth) ~c ~ 5'el' @ I~o '1' 7 Description summary of proposal: ~ 1. Type of Request: 99S/0 oAO-3'O Effective depth: µ¡ 620 feet C::>8"22. feet Iq62 0 feet 6f22 feet measured true vertical Casing itruotural- Conductor Surface Intern,ediatc Production Liner Perforation depth: Length 13f J Size /6"/IXSo " 9~?3 '---q-Sg/I 1~S'fl I 7 I' measured A.lo /-< 13. Attachements 14. Estimated date for commencing 9Ptlr~i9n . ¥ / &fl°"3 16. If proposal well verbally approved: Operation shutdown: Plugging: _ Variance: 5. Type of well: Development: Exploratory: Stratigraphic: Service: Re-enter suspended well: _ Time extension: Stimulate: Perfora-¡;- Other: A..,IU /;" ¡f/,J ,or,; / 6. Datum elevatio~r KB) ~ 7. 2 ¿: Þ!S'L 7. Unit or Property name /é'-t ,ð4'-t.. f ~ ~ø..1 U ~/:¡ 8. Well number 2 / c- 2.. feet 5<'>< 9. Permit number 202- '22 '2. Plugs (measured) 10. API number 50~ 029- '23/2'7 11. Field/Pool , J K~'-wK ~,urX he//¡ k~t:-/(,f CJ, I ¡.:Ø;() / Junk (measured) True vertical depth /5?'/ 9~7/ ' ~rlY , b?/S/ 1~~7 I ~ S'//,c Detailed operations program: BOP sketch: 15. Status of well classification as: Oil: Gas: Suspended: Name of approver Date approved Service:)<tX 17. I hereby certify that the fOreg~ is true and correct to the best of my knowledge. Signed: d!J/I19~ Title: (f II t /o:~ - 5;-; FOR COMMISSION USE ONLY ¿)r,liÑ/ ß'J'~~ ý'¡;r~.! Date: Conditions of approval: Notify Commission so representative may witness Approval No. 3D3-J;)..~ Plug integrity_ BOP Test_ Location clearance_, \\--. -IVC D . Mechanical Integrity Tes'---- Subsequent form r<>quired 1 0- ~. ~¿ \:,\-0 ~ ".,:¡ \0 \" (Jì o.'-.j\\~~\ L~ ~ \) '~C0\(j~~ .ç~J\ \(-)d- \ ~ \~~w:~s.("C, +ò5C~:)ro \:'~\~PR 1 8 2003 Approved by order of the Commissioner L-.~ ,/ Form 10-403 Rev 06/15/88 ~~~ 01!/~~~1~1 j' ~ '1 f' . J' .j I "'1 I i ,II ,,. Alaska Oil & Gas Cons. Commission Anchorage Oate If? <¡¡I 0 3 sU~",ftTIð'P~W1E Commissioner \R8DMS afl C) :J:1 ~-~~'J r: 04! ':) -"'- ....., ~.. ~~...<.,,-:~ ""=. ,.£~ r-- 35,000 30,000 25,000 20,000 (/) :c ED 15,000 - 10,000 5,000 --------- Total Fluid Injected on 1 C-22 (Annular) .....~-_. .-. ...- __ - ._ - __~_ . ___ __.........-......_.. ._u. -----------------------------------------------------------------------------------------------~ ===================================================================~ --------------------------------------------------------------¡(:T. Ai"··'·,·,·,·, ," =======================================================-~-~,,'»> '.....' " ,." <,. ------------------------------------------------...... ..'.. "",' - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -/ ,,", ""·>···i< ."',',." /', ..",'.. .....'...,"', .... ','.'.,.'....'.','. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 7.'" 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'.,...'..' ,.".',,',"'.,..,' .',....,".,. ""..>,..'..., ..'.,.... '...',.'. '," ,,",...' ... ....... .','" "",... .". ",' .'.'... ..,..:..... '"."... ','." --------------------------- --------------------------- --------------------------- - - - - - -- - - - - - - - - - - - - - - - - - - - - --------------------------- ~~ --------------------------- -------------------------- ~ --------------------------- --------------------------- --------------------------- --------------------------- --------------------------- --~------------------------ --~------------------------ --.------------------------- --------------------------- --------- -_____-0____----------------- ------- --------------------------- ------ ---- -- -- ------- ----------- - - -- ----------------------------- - - -- - - .- - - - - - - - - - - - - ._~-------------------------- - -- - - - - - - - - - - - - - - - - - - - - - - - - - .~ o ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ß ~ ~ ~ ~ ß ~ ~ # ~ ß # ~ ~ ~ ~ oJ v ~t:X ~((j ~~ ~,,(j ~.:.. v ~"t:X ~,,((j ~,,~ ~rv(j ~~v ~rv ~rv((j ~1> ~~(j ~" . I ~~ ~~ '{V(j '{V(j ~Oj ~<o ~~ ~~ ~(j ~(j ~~ ~Oj Date C ::t:J ~,.", ,.,,"" ~,~: ~-) ..,.. , ,,~.:._-~ ....- ,J-~ r-- 2500 Annular Injection for 1 C-22 . Static Pressure = mu Injection Pressure - - Linear (Static Pressure) I -~----------------------------------------------------------------------------------------------------- --------------------------------------------------------------------------------------------------------- - ------------------------------------------------------------------------------------------------------ 2000 - - --.--- ------------------------------------------------------------------------------------------------ (/I ! 1500 ::::J (/I (/I Q) ... c.. ... ca :; mmmm_mmmm_mmmm_m_ ê 1000 <C Didn't displace annulus with diesel when well was finished and had solids fall out, had to work pressures to get injection started ---------------------------------------------------- -'" ---------------------------------------------------- ------------------------------------------------- ----------------------------------------------- - ------------------------------------------------------------------------- -------------------------- -~------------------------------------------------------------------------------------------------- -------------------------------------------------------------------------------------------------- 500 -------------------------------------------------------------------------------------------------------- ----- ------~-------------------------------------------------------------------------------------- '~ -------.----------------------------------------------------------------------------------------------- --------------~---------------------------------------------------------------------------------------- ----------------------------------------------------------------------------------------------------- o I 28-Feb 5-Mar 10-Mar 20-Mar 25-Mar 30-Mar 14-Apr 4-Apr 9-Apr 15-Mar Date ~mailing: 1 C-22 .xls ) ') Subject: Emailing: 1C-22 .xls 'dD~ - è1 d d- Date: Thu, 17 Apr 2003 15:34:45 -0800 From: "Steven M Shultz" <Steven.M.Shultz@conocophillips.com> To: tom_maunder@admin.state.ak.us, "Steve McKeever" <smckeev@ppco.com> Tom, I dug up the data for annular injection on 1 C-22 since March 1 st. Since the pressures tend to vary with flow rate I tended to use values from 2 bbls/min since that is what we like to inject with. Do you think we can utilize 1 C-22 for additional injection until we finish drilling 1 C-178 which will take about a week and a half. We would probably inject an additional 6000 to 8000 bbls giving us a total of +/-40,000 bbls for annular injection. Thanks Steve (See attached file: 1 C-22 .xls) :WI¡\««'W.'W.':.-\'·"'''''''««V'_''~Y'A; 'II.' ~"Ý'A""'~"'WI"Y'-:' ""'¡(V""'¡'~'¡~'¡«'.""""'¡\WIIII.*"WI...«:..w.«ol""'¡"\«W«««'''''''';'¡WAWAWllj/AW'¡W""'..(ill.V'IIWIJlV'I.......I.\" '...~"\«V'«,«'.,«.¡«W^"IIWI.",¡..Y'I.WiN'A,\W.\«~.w...vW.y'llA'..yW/N'^..VI<. Name: 1 C-22 .xls! i: ~1C-22 .XIS! Type: EXCEL File (application/msexcel): ii""",, ",¡E,~c,~,d,~~~:~a~~~~'#'M"""'" " " "", "V',,,,,,,,,,,, '" "",..""","1 1 of 1 4/18/2003 6:55 AM -- ~ 35000 30000 25000 20000 tn :ë m 15000 10000 5000 Total Fluid Injected on 1 C-22 (Annular) o ~~O:> ~~O:> ~~O:> ~~O:> ~~O:> ~~O:> ~~O:> ~~O:> ~~O:> ~~O:> ~~O:> ~~O:> ~~O:> ~~O:> ~~O:> ~~O:> ~~O:> ~~O:> ~~O:> ~~O:> ~ ~ ø ø ~ ~ ~ ~ ø ø ~ ~ ø ø ~ ~ # # ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Date ~/ '-" Annular Disposal during theftrst quarter of2003: h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes 3S-l8 31501 100 0 31601 306 0 31907 January March 3S-15, 3S-16, 3S-22, 3S-08 2003 2003 3S-07 13415 100 0 13515 216 18255 31986 Dec 2002 Jan 2003 3S-10, 3S-15, 3S-09, 3S-14 CD2-48 20144 100 0 20244 375 11381 32000 Dec 2002 Feb 2003 CD2-45, CD2-35, CD2-08, CD2-28 CD2-l7 2647 100 0 2747 372 15062 18181 May 2002 Feb 2003 CD2-08, CD2-48, CD2-46 CD2-22 30773 100 0 30873 380 0 31253 Feb 2003 March CD2-08, CD2-36, CD2-51 l 2003 \ 3S-l0 21104 100 0 21204 388 0 21592 March March 3S-21,3S-08 2003 2003 lC-22 26944 100 0 27044 0 0 27044 March March 1 C-190, 1 C-17 4 2003 2003 Puviaq #1 4616 100 0 4716 15 0 4731 March March Puviaq 1 2003 2003 Total Volumes into Annulifor which Disposal Authorization Expired during the first quarter 2003: Freeze Protect Total Volume Start End Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus 2P-420 9479 100 0 150 9729 Open, Freeze Protected April 2002 May 2002 CD2-34 22895 100 0 372 23367 Open, Freeze Protected October Dec 2002 2002 2P-4l5A 31181 100 0 52 31333 Open, Freeze Protected March 2002 April 2002 CD2-26 29146 100 0 380 29626 Open, Freeze Protected September October 2002 2002 CD2-49 27474 100 0 386 27960 Open, Freeze Protected April 2002 May 2002 Source Wells 2P-427, Heavenly CD2-13, CD2-37, CD2- 35 2P-441, 2P-431, Grizzly, 2P-422A, 2P-427, Heavenly CD2-38, CD2-44, CD2- 29, CD2-13 CD2-50, CD2-46, CD2- 22 ~ECEIVED ( Qj ~ iJ Alaska Oil & Gas Cons. Conmission 9..J Anchorage 9J APR 1 6 2003 0r co 'ð Annular Disposal during the first quarter of 2003: I .~ h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells d Well Name Volume Volume Volume Quarter , Protect Total Total Date Date (1) Volumes '. 0 3S-15, 3S-16, 3S-22, 3S-08 3S-18 31501 100 31601 306 0 31907 January March 2003 2003 3S-07 13415 100 0 13515 216 18255 31986 Dec 2002 J an 2003 3S-10, 3S-15, 3S-09, 3S-14 CD2-48 20144 100 0 20244 375 11381 32000 Dec 2002 Feb 2003 CD2-45, CD2-35, CD2-08, CD2-28 'I( CD2-17 2647 100 0 2747 372 15062 18181 May 2002 Feb 2003 CD2-08, CD2-48, CD2-46 k CD2-22 30773 100 0 30873 380 0 31253 ' Feb 2003 March CD2.:08, CD2-36, CD2-51 2003 3S-10 21104 100 0 21204 388 0 21592 March March 3S-21,3S-08 2003 2003 1 C.22 26944 100 0 27044 0 0 27044 March March lC-190,lC-174 2003 2003 Total Volumes into Annulifor which Disposal Authorization Expired during the first quarter 2003: Freeze Protect Total Volume Start End Source Wells Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus 2P-420 9479 100 0 150 9729 Open, Freeze Protected April 2002 May 2002 2P-427, Heavenly CD2-34 22895 100 0 372 23367 Open, Freeze Protected October Dec 2002 C02-13, CD2-37, CD2- 2002 35 t 2P-415A 31181 100 0 52 31333 Open, Freeze Protected March 2002 April 2002 2P-441, 2P-431, Grizzly, 2P-422A, 2P-427, Heavenly CD2-26 29146 100 0 380 29626 Open, Freeze Protected September October C02-38, CD2-44, CD2- 2002 2002 29, CD2-13 CD2-49 27474 100 0 386 27960 Open, Freeze Protected April 2002 May 2002 C02-50, CD2-46, CD2- 22 02/06/03 Schlumbel'gel' NO. 2490 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Sepia CD Color 1C-22 aD~~d~ 23042 35-09 aaa,dQ5 23004 SCMT 5CMT 01/12/03 12/23/02 1 1 ""'--' S'GNEd~ ~) RECEIVED DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. FEB 0 7 2003 Alaska Off & Gas Cons. Commlseion Anchorage Schlumberger NO. 2840 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth 01/31/03 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Well Job # Log Description Date BL Sepia 1 R-14 liS,,/ '5 J LEAK DETECTION LOG 01/09/03 1 2G-15 J 84.. r& , LEAK DETECTION LOG 01/08/03 1 1 G-11 ~3"J? ( LEAK DETECTION LOG 01/10/03 1 1A-08 11 'if-D'-lD LEAK DETECTION LOG 01/07/03 1 2U-02 J~...OOS LEAK DETECTION LOG 01/11/03 1 2N-349A dOD -1:3 '1 INJECTION PROFILE 12/20/02 1 3S-09 ~..a05 JEWELRY LOG/PSP 12/24/02 1 1C-22 aOd·~~';; PERF RECORD & POST PERF SBHP 01/17/03 1 3S-10 ~d "d3~ PERF/JEWELRY/PSP 01/15/03 1 1Y-21 I 3'" IOd STATIC PRESSITEMP LOG 01/14/03 1 1 Y -34 1'1 5"O'¡ I STATIC PRESSITEMP LOG 01/14/03 1 SIG~ ~~ DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Kuparuk CD Color '-=-' ~~/ REC;:IVED FEB 07 2003 Alaetœ 0tI & Gas Cons. Cornmieeion Anchorage ) '), Randy Thomas Greater Kuparuk Team Leader Drilling & Wells ConocóP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 January 29, 2003 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 1 C-22 (202-222) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations on the Kuparuk well 1 C-22. If you have any questions regarding this matter, please contact Shane Cloninger at 265-6829. Sincerely, C\~\~ R. Thomas Greater Kuparuk Team Leader CPAI Drilling RL T /skad 'I , .,~,. , -, '", ~"'j ') STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Service 0 Injector !roëA~~ 7. Permit Number ,'1!.. vøn~" '," '~\ 202-2221 \~' f~~'lr 8. ~~~~~;~~127 , ", " " ,. U. ,I , ...:.:~~ 9. Unit or lease Name ~oC" ""·'I~'··~'.·':'··'~' ~",~7" ;,~:~;"',~"; I~~~~'" ~~ ~~:~"'!'.I.' .,"\~\~~;~~:¡~~~I~ 1593' FNL, 1327' FWL, Sec. 12, T11N, R10E, UM¡ ~~.:";:,}:~",:;\':'<i 4, (ASP: 562335, 5968646') At Top Producing Interval 1 ~.L./Î ¿- __I? t . 2106' FNL, 2303' FWL, Sec. 5, T11N, R11E, UM ;",::~tt:HY~,H¡P:']) ~ (ASP. 573439, 5973513) At Total Depth ~ ~ ' 2018' FNL, 2493' FWL, Sec. 5, T11 N, R11 E, UM t:::::>,..~"....::..-:~j (ASP: 573629, 5973604) 5. Elevation in feet (indicate KB, DF, etc.) 6. lease Designation and Serial No. RKB 28' ADL 28242 ALK 2292 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 15. Water Depth, if offshore 16. No. of Completions December 24, 2002' De~emh'4r ~, 2olf¿ ¡-;(". rÖ ~J.,.. N/A feet MSL 1 18. Plug Back Depth (MD + TVD) 19. Directional Survey 20. Depth where SSSV set 14620' MD 16822' TVD YES 0 No D N/A 1. Status of well Oil 0 Gas 0 2. Name of Operator ConocoPhillips Alaska, Inc. 3. Address o Abandoned D Suspended P. O. Box 100360, Anchorage, AK 99510-0360 4. location of well at surface 12. Date Spudded December 7,2002' 17. Total Depth (MD + TVD) 14620' MD /6822' TVD 22. Type Electric or Other logs Run GR/Res/Dens-Neutron, SCMT 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 138' Surface 9471' CASING SIZE WT. PER FT. 30" X 16" 62.5# 9.625" 40# GRADE B L-80 HOLE SIZE 42" 348 sx ArcticCrete Classification of Service Well Kuparuk River Unit 10. Well Number 1 C-22 11. Field and Pool Kuparuk Oil Pool Kuparuk River Field 21. Thickness of Permafrost feet MD 2479' CEMENTING RECORD AMOUNT PUllED 12.25" Stage 1: 382 bbls AS III Lite & 183.6 bbls Class G Stage 2: 500 bbls AS III Lite & 12 bbls AS I 51.5 bbls Class G 7" 26# L-80 Surface 14620' 8.5" 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) 25. SIZE 3.5" 14340' - 14365' MD 6627' - 6645' TVD 6 spf TUBING RECORD DEPTH SET (MD) 14074' PACKER SET (MD) 14047' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27. Date First Production N/A PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) injector Production for Oll-BBl GAS-MCF Test Period> Calculated Oll-BBl WATER-BBl Date of Test N/A Flow Tubing press. xxx psi 28. Hours Tested WATER-BBl Casing Pressure GAS-MCF 24-Hour Rate> CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. N/A Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE .....\ n a :"'"'\ ~ 1\ , t1¡ ~ ' ~ L.,. ~ G ~.. 'i :~ \ I l \ [ 11 ~ \ N \, "Ii \; Ï:~ (..\ ,.,,-' H U "-,,,,f i ~ \,; t ~ 'v._ RBDMS BFl CHOKE SIZE GAS-Oil RATIO Oil GRAVITY - API (corr) " (' C~- \JI Submit in duplicate ÆB 1 I 2003 29. ) 30. ) GEOLOGIC MARKERS FORMATION TESTS NAME MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. Kuparuk C Kuparuk D 14327' 14261' 6618' 6572' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Shane Cloninger 265-6829 Signed \ ~~ Randy Thomas rme Kuparuk Team Leader Date '¿(-y fo ~ Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 1 0-407 ) ) CÖnocOPhillipsAlaska Operations ,.Summary.Re.port N/U Pre-stacked Divertor system on 1 C-22. Fill pits wI H20 to mix spud mud. Unload & sort 8" BHA tools. Load BHA in pipeshed. Dress Shakers for spud. Load pipeshed wi 5" DP, HWDP. Build cuttings containment berm. Mix Spud mud. Load Pipe shed wi 300 jts. 5" 19.50 'G' drill pipe. Mixing spud mud while loading & picking up dp. Pick up 5" drill pipe & stand in derrick. (300 Jts.) Test diverter,gas detectors, pit volume & flow indicators. (Witnessed by AOGCC John Crisp.) Pick up 29 jts. 5" HWDP, 1 set jars & stand in derrick. Pick up 2 stands 8" dc,s & stand in derrick. String up new drlg. line. (PJSM prior to string up) Pick up BHA tools & handling equipment-calibrate depth tracking, Make up BHA #1 re conf motor, Program & orient MWD. Flood conductor-check for leaks-test surface equipment. Drlg. 12.25" surface hole from 138' to 177'. Stand back HWDP-pick up stand of 8" nmdc. Drlg. from 177' to 210'. (Heavy gravel running into conveyor, clean out same.) ADT= .15 hrs. Up wt. 55k, Dn wt. 50k, Rot wt 55k. Torque on bttm 0 ft/lbs off bttm 0 fl/lbs. PP 950 psi @ 588 gpm. Drlg. from 210' to 277'. Trip to pick up 8" Monel drill collars. Drlg. from 277' to 306'. POH for mwd failure-change out mwd-program & initiate-RIH. Drlg. from 306' to 2663'. (TVD 1848') High Hydrates concentration @ 1198 MD-1174 TVD. AST-7.6 ART-5.2 P/U wt. 98k-S/o wt. 68k RT wt. 85k. Tq. on bottom 7-11 k. Tq off bottom 3-8k. RPM 72 Motor rpm 190. Wt. on bit 25-35 PP 2350 635 GPM Jar hrs. 11.05. Drlg. from 2663 to 2757 (TVD 1881) ART = .33 Hrs Pump weighted sweep & circ. hole clean. PJSM=Observe well-pump dry job & POH to DC,S. (20K over pull @ 1980'-worked same-freed up.) Lay down Steel DC,S & stand back NMDC,S. Down load MWD & lay Down MWD & Motor. Make up Auto Track-BHA & RIH to 590'. Test Auto Track wi Baker & downlink Test. RIH WI BHA #2-no problems. Cautios Wash & Ream 40' to bottom-No Fill-CBU-Poor decoding on Auto Track-change data rate. (no Bottoms up Gas.) Drlg. From 2767 To 4111'- ART = 7.67 Hrs. WOB 5-12K-RPM 150-SPM 190-GPM 800-PSI 2550-PU wt 1 05K-SO wt73K-RW 88K-Tq on bottom 3-13K-Off bottom 3-7K. (Pumped 30 BBL. Weighted sweep @ 4000'.) Dir Drlg 4111' to 4820' MD (2691' TVD) ADT = 7.4 hrs. PP 2470 psi @ 800 gpm. Torque off bttm 5-7k ft/lbs, on bttm 5-13k ft/bs. 150 RPM's, WOB 8-20k. Up wt. 11 Ok, Dn wt 72k Rot wt 88k. Tool Failed - MWD pulsar failed to signal - "*Note, Failure occured while pumping the second 20 bbl lube & wall nut pill for suspected Bit Balling. Each Pill consisted of 25-30 gal BDF 263 & 15 ppb wall-nut (med) 20 bbl mud. 2.00 DRILL OTHR SURFAC Trouble shoot pulsar problem - Varied drilling parameters - cycle tools several times,downlinked tools, pumped 20 bbl fresh water flush - NO response from tools Legal Well Name: 1 C-22 Common Well Name: 1 C-22 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date Fröm';To HöursCode Sub Pha.se COde 12/6/2002 15:00 - 17:00 2.00 MOVE RIGUP 17:00 - 20:00 3.00 MOVE RIGUP 20:00 - 21 :00 1.00 MOVE RIGUP 21 :00 - 00:00 3.00 MOVE RIGUP 1217/2002 00:00 - 02:00 2.00 MOVE OTHR RIGUP 02:00 - 11 :00 9.00 MOVE OTHR RIGUP 11 :00 - 12:00 1.00 MOVE OTHR RIGUP 12:00 - 13:30 1.50 MOVE OTHR RIGUP 13:30 - 15:00 1.50 MOVE OTHR RIGUP 15:00 - 18:00 3.00 MOVE OTHR RIGUP 18:00 - 21 :30 3.50 MOVE OTHR RIGUP 21 :30 - 22:00 0.50 MOVE OTHR RIGUP 22:00 - 22:30 0.50 DRILL DRLG SURFAC 22:30 - 23:00 0.50 DRILL PULD SURFAC 23:00 - 00:00 1.00 DRILL DRLG SURFAC 12/8/2002 00:00 - 01 :00 1.00 DRILL DRLG SURFAC 01 :00 - 02:00 1.00 DRILL TRIP SURFAC 02:00 - 02:30 0.50 DRILL DRLG SURFAC 02:30 - 06:00 3.50 DRILL TRIP SURFAC 06:00 - 00:00 18.00 DRILL DRLG SURFAC 12/9/2002 00:00 - 00:30 0.50 DRILL DRLG SURFAC 00:30 - 02:30 2.00 DRILL CIRC SURFAC 02:30 - 04:30 2.00 DRILL TRIP SURFAC 04:30 - 05:30 1.00 DRILL PULD SURFAC 05:30 - 07:00 1.50 DRILL PULD SURFAC 07:00 - 10:00 3.00 DRILL PULD SURFAC 10:00 - 11 :00 1.00 DRILL TRIP SURFAC 11 :00 - 11 :30 0.50 DRILL REAM SURFAC 11 :30 - 00:00 12.50 DRILL DRLG SURFAC 12/1 0/2002 00:00 - 10:00 10.00 DRILL DRLG SURFAC 10:00 - 12:00 Start: 12/6/2002 Rig Release: Rig Number: Spud Date: 12/7/2002 End: Group: Description, of Operations Printed: 1/10/2003 1 :08:02 PM ) ) çonocoPhillipsAlaska ' Page 2 018 Oþèratlons Sl.immary Rèport Legal Well Name: 1 C-22 Common Well Name: 1 C-22 Spud Date: 12/7/2002 Event Name: ROT - DRILLING Start: 12/6/2002 End: Contractor Name: n1334@ppco.com Rig Release: Group: Rig Name: Doyon 141 Rig Number: Date Frorn-To Hours Code Sub Description of Operations Code 12/1 0/2002 12:00 - 13:00 1.00 DRILL TRIP SURFAC SB Std - Trouble shoot MWD & Cycle tools @ 4761' 13:00 - 14:30 1.50 DRILL TRIP SURFAC Obs well - Static - TOH to 4297' - No Swab - Pump dry job- TOH - 3925' to 3865' 30K overpulls max. 14:30 - 16:00 1.50 DRILL TRIP SURFAC Wash & Bk Ream 3925' to 3830' - CBU -Rot 120 rpm , pump 800 gpm- Cont circu clean 16:00 - 18:30 2.50 DRILL TRIP SURFAC Pump OH @ 800 gpm - 3830' to 2532' - 30K overpull @ 2532' 18:30 - 21 :00 2.50 DRILL CIRC SURFAC Rot & Circu hole - 2532' to 2439' - Rot 120 rpm, pump 800 gpm - Had large amount of cutting thru 3 BUs,After 4 th BU cutting had cleaned up 21 :00 - 22:30 1.50 DRILL TRIP SURFAC POH Backing reaming as needed 2439' to 1792' - Rot 110 rpm ,pumping 800 gpm - Bad section 1978' - 1885' Slow go - No increase of cutting over shakers,small volume 22:30 - 23:00 0.50 DRILL TRIP SURFAC Pump OH 1792' to 1607' Max overpulls 15K 23:00 - 00:00 1.00 DRILL TRIP SURFAC TOH to HWDP - No excess drag - No Swab 12/11/2002 00:00 - 01 :00 1.00 DRILL TRIP SURFAC TOH w/HWDP & Jars - 25K overpull @ 650' - work clean 01 :00 - 02:30 1.50 DRILL TRIP SURFAC Std Bk NMDCs, Bk Bit, UD Stab & Fit Sub - UD Auto-Trak ....Note.... HTC HCR 606 PDC Bit Sr# 7101570 had 26 out of 49 cutters damaged.Suspected gravel damage?? 02:30 - 04:00 1.50 DRILL TRIP SURFAC P/U New Auto-Trak, M/U Bit, UpLoad MWD - P/U Fit Sub, Stab & Run 1 std NMDCs 04:00 - 07:00 3.00 DRILL TRIP SURFAC TIH - Shallow Test MWD @ 750' "OK" - Con't TIH to 4470' - Dn wt drag 5-15 K gradually increased to 20K @ 4470' 07:00 - 08:00 1.00 DRILL REAM SURFAC Wash & Ream 4470' to 4820' - Pump 800 GPM - Rot 120 RPM - Wash to Bttm WO any problems 08:00 - 08:30 0.50 DRILL CIRC SURFAC Circu & Cont - Shakers Clean 08:30 - 12:00 3.50 DRILL DRLG SURFAC Drlg 12? hole F/ 4820' to 5039' MD ( 2777' TVD) ADT = 1.9 hrs. PP 2600 psi @ 802 gpm, P/ Stks 96/94, Troq off bttm 7-14 ftllbs, on bttm 5-17 ftllbs, 120 RPM, WOB 20-25 K, Up wt 135 K, Dn wt 71 K, Rot wt 94 K. 12:00 - 00:00 12.00 DRILL DRLG SURFAC Drlg 12? hole F/ 5039' to 6040' MD ( 3169' TVD) ADT = 8.85 hrs. PP 2620 @ 800 gpm, P Stks 95/95, Troq off bttm 9-16 ftllbs, on bttm 13-17 ftllbs, 140 RPM, WOB 15-25 K, Up wt 150 K, Dn wt 72 K, Rot wt 100 K. 12/12/2002 00:00 - 09:00 9.00 DRILL DRLG SURFAC Drlg 12? hole 6040' to 6711' MD ( 3433' TVD) ADT = 5.75 hrs , PP 2810 @ 806 gpm, P Stks 95/95, Troq off bttm 13-14 ftllbs, on bttm 13-15 ftllbs, 140 RPM, WOB 15/25 K, Up wt 156, Dn wt 80 K, Rot wt 101 K. ....Note.... Adding lubricate EZ Glide & BDF 263 to mud to minimize Troq & Drag 09:00 - 12:00 3.00 DRILL CIRC SURFAC Circu & Cont - Circu downlink to ribs IN, Work Std, Survey - Pump 35 bbl Hi-Density sweep - Circu until clean ( 2 ? BUs) - Monitor well - Static- Slite show of gas hydrates showing in mud - pump dry job - Blow dn Top Drive. 12:00 - 13:00 1.00 DRILL WIPR SURFAC TOH - 30 K overpull @ 6140' 13:00 - 16:00 3.00 DRILL WIPR SURFAC Bk Ream 6246' to 4761 - No excess Troq - Pump 800 gpm, 80 RPMs 16:00 - 17:00 1.00 DRILL WIPR SURFAC TIH to 6616' - No excess drag 17:00 - 17:30 0.50 DRILL REAM SURFAC Wash & Ream last std to Bttm 6616' to 6711' - No fill - No gas - Stage up circu 17:30 - 00:00 6.50 DRILL DRLG SURFAC Drlg 12? hole 6711' to 7200' MD ( 3623' TVD) ADT = 4.75 hrs , PP 2950 @ 806 gpm, P Stks 95/95, Troq off bttm 12-16 ftllbs, on bttm 12-17 ftllbs, 140 RPM, WOB 15/25 K, Up wt 160 K, Dn wt 82 K, Rot wt 106 K. 12/13/2002 00:00 - 12:00 12.00 DRILL DRLG SURFAC Drlg 12? hole 7200' to 7715' MD ( 3824' TVD) ADT = 7.3 hrs , PP 3000 @ 806gpm, P Stks 95/95, Troq off bttm 12-18 ftllbs, on bttm 15-22 ftIIbs, 150 RPM, WOB 10/25 K, Up wt 175, Dn wt 75 K, Rot wt 110 K. Bariod Calcu ECDs 9.93 ppg @ Bit,9.66 ppg@ Shoe Printed: 1/10/2003 1 :08:02 PM ') ) ConocþPhillips Alaska OpE!ratiöns$ummélry Report Legal Well Name: 1 C-22 Common Well Name: 1 C-22 Spud Date: 12n /2002 Event Name: ROT - DRILLING Start: 12/6/2002 End: Contractor Name: n1334@ppco.com Rig Release: Group: Rig Name: Doyon 141 Rig Number: Date From-To Ho u rs Code SÚb Phase Code 12/13/2002 12:00 - 00:00 12.00 DRILL DRLG SURFAC Drlg 12? hole 7715' to 8250' MD ( 4033' TVD) ADT = 10.45 hrs , PP 3050 @ 806gpm, P Stks 95/95, Troq off bttm 11-17 ft/lbs, on bttm 12-22 ft/lbs, 140 RPM, WOB 10/30 K, Up wt 180, Dn wt 80 K, Rot wt 115 K. - Pump Hi Density sweep @ 8200' - **Note** Adding lubricate EZ Glide & BDF 263 to mud to minimize Troq & Drag **Note** Log showed Top West Sak 7985' MD (3926' TVD) 12/14/2002 00:00 - 12:00 12.00 DRILL DRLG SURFAC Drlg 12? hole 8250' to 8900' MD ( 4287' TVD) ADT = 8.45 hrs , PP 3250 @ 806gpm, P Stks 95/95, Troq off bttm 16-17 ft/lbs, on bttm 15-20 ft/lbs, 130 RPM, WOB 20-35 K, Up wt 185, Dn wt 86 K, Rot wt 122 K. Bariod Calcu ECDs 9.93 ppg @ Bit,9.65 ppg@ Shoe 25 bbl Hi Density sweeps pumped @ 8290' & 8754' 12:00 - 00:00 12.00 DRILL DRLG SURFAC Drlg 12? hole 8900' to 9425' MD (4492' TVD) ADT= 9.05 hrs, PP 3350 @ 806gpm, P Stks 95/95, Troq off bttm 15-19 ft/lbs, on bttm 15-24 ft/lbs, 130 RPM, WOB 20-35 K, Up wt 195, Dn wt 90 K, Rot wt 126 K. Bariod Calcu ECDs 9.93 ppg @ Bit,9.65 ppg@ Shoe 25 bbl Hi Density sweep pumped @ 9126' **Special Note** It should be noted for future records that Doyon 141 was very close to its" MAXIMUM POWER AVAIILABLE from the electric system (On SCRs). A small amount more could have been obtained for service, but it was minimal. Using the well parameters we have at this time ( TD 9481') we are very close to being MAXED OUT powerwise. 12/1 512002 00:00 - 01 :00 1.00 DRILL DRLG SURFAC Drlg 12? hole 9425' to 9481' MD (4514' TVD) ADT= .75 hrs , PP 3350 @ 800gpm, P Stks 93/93, Troq off bttm 16-19 ft/lbs, on bttm 17-23 ft/lbs, 130 RPM, WOB 25-35 K, Up wt 195, Dn wt 90 K, Rot wt 126 K. Bariod Calcu ECDs 9.93 ppg @ Bit,9.65 ppg@ Shoe 01 :00 - 04:00 3.00 DRILL CIRC SURFAC Circu & Condt - Surv - downlink Autotrak" ribs in" - Pump 50 bbl Hi Density sweep - Circu clean - Good show cutting on BU- Recip DP at all times- SB 1 stdlhr - Circu @ 800 gpm, 80 RPMs(Max Baker recommendation wi ribs in)- Circu Total 27,000 stks = 2? BUs 04:00 - 12:00 8.00 DRILL WIPR SURFAC BK Ream OH 9481' to 5785' - 70 RPMs , Pump 800 gpm ( Tight spots wi 10-15 K over pull & stalling TD @ 8660, 8638, 8295, 8238, 8161, 8143,8124,7990,7852,7769. Worked all tight spots until clean. Pulled wi normal drag (5-8 K) once into West Sak .Had one minor tight spot @ 6890' ,worked clean. 12:00 - 16:30 4.50 DRILL WIPR SURFAC Bk Ream OH, 5785' to 2625' , 70 RPMs, Pump 800 gpm 16:30 - 17:00 0.50 DRILL CIRC SURFAC Circu & Condt - Circu Hole Clean - Rot & Recip DP 2625' to 2718',80 RPMs , Pump 800 gpm . Had large amount of cutting to surface- Circu clean 17:00 - 18:30 1.50 DRILL WIPR SURFAC Bk Ream OH 2625' to 1696' , 70 RPMs , Pump 800 gpm - Normai drag 5-8 K 18:30 - 20:00 1.50 DRILL WIPR SURFAC TOH on Elevators- No excess drag - Small tight spot @ 606' - worked clean **Note** Torq & Drag information was recorded on TOH per Well Plan instructions. 20:00 - 21 :30 1.50 DRILL WIPR SURFAC SB HWDP & 1 std NMDCs - Bk Bit - UD BHA #3 21 :30 - 22:00 0.50 DRILL PULD SURFAC Remove UD BHA components off Rig floor - Clean & Wash Rig floor 22:00 - 22:30 0.50 RIGMNT RSRV SURFAC Service Top Drive - Inspc TD saver sub 22:30 - 23:00 0.50 DRILL PULD SURFAC P/U HO -Stab - M/U BHA #4 ( Clean Out Assy) 23:00 - 00:00 1.00 DRILL TRIP SURFAC TI H to 2000' +1- - No problems 12/16/2002 00:00 - 03:00 3.00 DRILL WIPR SURFAC TIH wi BHA#4 ( HO Assy fl C/O run) Fill every 25 stds - Tight @ 7500' - M/U TD - Wash & Ream tight hole 7450' to 7546' until clean. Stage up Printed: 1/10/2003 1 :08:02 PM ) ') qdnocoPhillips Alaska Operatiol1sSuml11aryR~port pumps slowly, 120 RPMs Circu & Cond Mud - Cuttings & very thick mud to surface - Circu and treat mud until clean. Rot & Recip at all times. Con't to stage pumps up slowly to 800 gpm, 150 RPMs. Circu clean Can't TIH to 9481' (TD) No tight hole - No fill Circu & Cond Mud - Pump 35 bbl Hi Density Sweep ( 3 sx walnut marker) Circu & Cond hole to prep for 750 bbl New mud to be spotted on Bttm. Circu total 36,600 stks, 190 SPM, 150 RPMs Spot 750 bbl New Mud on bttm per well plan. Mud pre-mixed @ Bariod, 0.75 ppd Barazan D YP 15, 3 ppd Dextrid, ph 9.0(w/caustic), Wt 9.5 ppg, 3.5% EZ glide, 0.5% BDF-263. The Rig mixed on the fly 15 ppb Steel Seal & added 0.5% EP Mudlube. Displaced New Mud w/71.6 bbl. Calu Top NM @ 4000'. New Mud will cover bttm 5150' OH. Monitor well (Static) - Pump dry job - Blow dn TD TOH on elevators - No excess drag, No swab to 6700', 30 K overpull - Bk ream 6700' to 6600', P 80 SPM, 70 RPMs, work until clean- Pumped well treated mud wI reaming. Can't TOH on elevators - No excess drag,No swab to 920'. 25 K overpull. Bk ream 920' to 638', P 100 spm ,70-100 RPMs. Problem seemed to work up hole with high torq and stalling TD at times.Once above 638' no more problems were encountered. Section was worked until clean - SIB HWDP UD BHA #4 , Stab, 3 monels,NB Stab & Bk HO - Clear all tools from Rig floor R/U to Run 9.625" , 40# L-80 BTC Csg Pre Job Safety Meeting Run 9.625' 40# L-80 csg to 3000' - Csg run slow wI low Dn wt (40- 45 K) - Full returns at all times. Circu BU X 2 -Very thick mud to surface - Stage pump stks up slowly to minimize ECDs - Rate 6 BPM - ( Pre circu , Up wt 125 K, Dn wt 55 K, Post circu Up wt 120 K , Dn wt 75 K TIH wI 9.625 csg to 3000' to 5941' - Csg ran well- No tight hole - Full returns Circu BU - Thick mud to surface - Stage pumps up slowly to 6 BPM Run 9.625' 40# L-80 csg to 5941' to 9473' - Csg ran well - No tight hole - Full returns Bk Circu wI Franks fill tool- RID Franks Tool - Blow dn TD - R/U CMT head Circu & Condition Mud per well plan - Stage pump stks up slowly to 8 bpm - Recip csg 10-12' PJSM wI Crew & all contractors - Pump CMT Stage 1 , Pumped 5 bbls CW 100 , Pressure Test lines to 4000 psi, pump 45 bbls CW 100, 50 bbls 10.5 ppg MudPush, 381 bbls 10.7 ppg Lead(500 sks), 175.5 bbls 12.0ppg Tail (440 sks)Drop Plug, pump 10 water, Displace wI Rig pumps @ 8 BPM - Slowed rate to 5 bpm @ 6700 stks for bump - Bump plug wI 6963 stks (Calic bump 6990 stks) @ 95% eft (27 stks early) **Note** Rate was reduced to 5 bpm for 200 stks for plug to pass thru Stage tool.(2000 to 2200 stks of displacement) ****Note**** 12 bbls into pumping Tail CMT rig had a wash out in the "TEE" of the CMT standpipe coming from cellar. Pumping was stopped and a by-pass hose rigged up complete cmt job. Total shutdown time 11 min (11 :45 - 11: 56 PM) 2.00 CEMENT PUMP SURFAC Con't Pump CMT Stage 1 ,175.5 bbls 12.0ppg Tail (440 sks)Drop Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-22 1 C-22 ROT - DRILLING n1334@ppco.com Doyon 141 Date Süb ' From-To Hours Code Code Phase 12/16/2002 00:00 - 03:00 3.00 DRILL WIPR SURFAC 03:00 - 04:30 1.50 DRILL CIRC SURFAC 04:30 - 05:30 1.00 DRILL WIPR SURFAC 05:30 - 10:00 4.50 DRILL CIRC SURFAC 10:00 - 12:00 2.00 DRILL CIRC SURFAC 12:00 - 12:30 0.50 DRILL TRIP SURFAC 12:30 - 19:30 7.00 DRILL TRIP SURFAC 19:30 - 22:00 2.50 DRILL TRIP SURFAC 22:00 - 23:00 1.00 DRILL TRIP SURFAC 23:00 - 00:00 1.00 CASE RUNC SURFAC 12/1 7/2002 00:00 - 00:30 0.50 CASE SFTY SURFAC 00:30 - 05:00 4.50 CASE RUNC SURFAC 05:00 - 06:00 1.00 CASE CIRC SURFAC 06:00 - 09:30 3.50 CASE RUNC SURFAC 09:30 - 11 :00 1.50 CASE CIRC SURFAC 11 :00 - 15:30 4.50 CASE RUNC SURFAC 15:30 - 16:30 1.00 CASE CIRC SURFAC 16:30 - 22:00 5.50 CEMENTCIRC SURFAC 22:00 - 00:00 2.00 CEMENT PUMP SURFAC 12/18/2002 00:00 - 02:00 Page 4 of,8 Start: 12/6/2002 Rig Release: Rig Number: Spud Date: 12/7/2002 End: Group: Description of Operations Printed: 1/10/2003 1:08:02 PM ) ) .çonocoPhillip$ Alaska Pages of 8 ()peratiol'1sSum rnaryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-22 1 C-22 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 12/6/2002 Rig Release: Rig Number: Spud Date: 12/7/2002 End: Group: Date Sub From.. To HoursCöde Code Phase Description of Opera.tions 12/18/2002 00:00 - 02:00 2.00 CEMENT PUMP SURFAC Plug, pump 10 bbl tub wash up water, Displace wI Rig pumps @ 8 BPM - Slowed rate to 5 bpm @ 6700 stks for bump - Bump plug wI 6963 stks (Calic bump 6990 stks) @ 95% eff (27 stks early) Bump plug to 1350 psi (500 over bump psi) full returns for complete job, Recip csg 5800 stks into displ - CI P 02.05 AM 12/18/02 02:00 - 05:00 3.00 CEMENTCIRC SURFAC Check float (Held) - Pressure up to 2830 psi and sheared stage tool open- Circu out CMT & Contaminated Mud (350 bbls total circu) 05:00 - 07:20 2.33 CEMENT PUMP SURFAC Pump Stage 2 Cmt - Pump 5 bbls CW100,test lines to 4000 psi,pump 15 bbls CW100, 492 bbls(645 sks) 10.7ppg Lead,12 bbls( 75 sks) 15.7ppg Tail Drop top plug, KO with 10 bbl tub wash up. Displace wI Rig pumps @ 8 BPM , slow to 5 BPM to bump plug. Pressure to 1800 to CLOSE stage tool CIP 07:30 AM 12/18/02200 bbls CMT contaiminated mud to surface. Had 70+ bbls 10.7 ppg CMT to surface. Bleed off - Stage tool closed. Full retuns thru complete job. 07:20 - 09:30 2.17 CEMENT PULD SURFAC RID Dowell - UD Landing Jt - UD Csg Equip 09:30 - 12:00 2.50 WELLSR NUND SURFAC N/D Diverter System 12:00 - 13:00 1.00 WELLSR NUND SURFAC N/U & Orient Csg Head - Test metal to metal seal & Csg head 1000 psi fl 10 min "ok" 13:00 - 16:00 3.00 WELLSR NUND SURFAC N/U BOPs - Install bails on TD 16:00 - 21 :00 5.00 WELCTL BOPE SURFAC Test BOPs & Choke Manif - Annular 250/3500 psi, All other equip 250/5000 psi.5 min each. AOGCC Rep Chuck Scheve witnessed test. 21 :00 - 00:00 3.00 WELCTL BOPE SURFAC ** Note*'" Top pipe VBRs failed, installed 5" DP rams(test ok), Door seal on blind rams (ODS) failed ,repaired(test ok),# 5 valve on choke manif failed, Mechanic lubed,cycled and serviced valve,(test ok) *'" Note*'" Because of these delays rig lost 3.00 hrs making repairs after failed test. 12/19/2002 00:00 - 00:30 0.50 WELCTL BOPE SURFAC Con't Test BOPs - Retest #5 valve on Choke manif after repair - Test 2501 5000 psi (OK) 00:30 - 01 :00 0.50 WELCTL BOPE SURFAC Pull Test Plug - Install wear bushing - UD test jt 01 :00 - 05:00 4.00 DRILL PULD PROD P/U BHA # 5 - P/U Motor(Mach 1XL AKO 1.2?), Bit, LWD, XO, Stab, MWD, Initialize MWD,Orient. Hold Radiation source PJSM, Install sources. P/U XO, 3 NMDCs, XO, 2 stds HWDP - Pulse test MWD "OK" 05:00 - 07:00 2.00 DRILL TRIP PROD TIH to 2878' picking up singles (5" DP) from pipe shed. Tag CMT @ 2878' 07:00 - 10:00 3.00 DRILL DRLG PROD Test Csg to 2000 psi "OK" - C/O CMT - Drill stage tool per procedure in well plan, P 400 gpm, 60 RPMs, 2-5 K WOB - Ream area 2878' to 2890' X 3 - ReTest Csg 2000 psi "OK" 10:00 - 13:30 3.50 DRILL TRIP PROD Con't TIH to 5376' - Fill DP 13:30 - 14:30 1.00 RIGMNT RSRV PROD Slip & Cut Drlg Line ( 85' cut) - Serv Rig & Top Drive 14:30 - 16:00 1.50 DRILL TRIP PROD TIH from 5376' to 8997' 16:00 - 17:00 1.00 DRILL CIRC PROD Circu & Condt - P 400 gpm, 1500 psi 17:00 - 18:00 1.00 CASE MIT PROD R/U Test 9.625" Csg - Test to 3500 psi fl 30 min - Chart for AOGCC After 30 min loss 20 psi - RID test lines 18:00 - 20:30 2.50 WELCTL SFTY PROD PJSM - Held Stripping drill wI Edwards crew. Stripped in 2 stds DP. Hands each had a turn bleeding off 200 psi working pressure wI choke. Held Post safety meeting, all question from crew members were answered concerning Stripping procedure. 20:30 - 22:30 2.00 DRILL DRLG PROD Tag CMT @ 9346' - Drill baffell @ 9349', CMT, FC, FS & 20' new hole fl 9481' to 9501' MD ( 4521' TVD) - Used procedure from well plan to drill out all equip. P 450 gpm, 80 rpms ,2 - 5 K WOB 22:30 - 00:00 1.50 DRILL CIRC PROD Displace hole over to new LSND mud per well plan. MW 9.3 ppg, Vis 47, PV 10, YP 15, Gels 4/5/5 12/20/2002 00:00 - 00:30 0.50 DRILL CIRC PROD Con't CIO mud to New LSND system, 9.3ppg, Vis 47, PV 10, YP 15, Printed: 1/10/2003 1 :08:02 PM ) ) ConocoPhillipSAlaska Page60f 8 Opèrati()n~iSurnmaryReport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-22 1 C-22 ROT - DRILLING n1334@ppco.com Doyon 141 Date 'Sub From-To Hours Code Code Phase 12/20/2002 00:00 - 00:30 00:30 - 01 :30 0.50 DRILL CIRC PROD 1.00 DRILL LOT PROD 01 :30 - 12:00 10.50 DRILL DRLG PROD 12:00 - DRILL DRLG PROD 12/21/2002 00:00 - 12:00 12.00 DRILL DRLG PROD 12:00 - 15:00 3.00 DRILL DRLG PROD 15:00 - 17:00 2.00 DRILL CIRC PROD 17:00 - 18:00 1.00 DRILL TRIP PROD 18:00 - 18:30 0.50 WELCTL OBSV PROD 18:30 - 20:00 1.50 DRILL TRIP PROD 20:00 - 20:30 0.50 WELCTL OBSV PROD 20:30 - 22:00 1.50 DRILL TRIP PROD 22:00 - 00:00 2.00 DRILL CIRC PROD 12/22/2002 00:00 - 02:30 2.50 DRILL CIRC PROD 02:30 - 03:00 0.50 DRILL OBSV PROD 03:00 - 04:00 1.00 DRILL TRIP PROD 04:00 - 05:30 1.50 DRILL TRIP PROD 05:30 - 06:30 1.00 DRILL OBSV PROD 06:30 - 10:30 4.00 DRILL TRIP PROD 10:30 - 12:00 1.50 DRILL TRIP PROD 12:00 - 13:00 1.00 DRILL TRIP PROD 13:00 - 17:00 4.00 DRILL TRIP PROD 17:00 - 23:00 6.00 DRILL TRIP PROD Start: 12/6/2002 Rig Release: Rig Number: Spud Date: 12/7/2002 End: Group: Description of Operations Gels 4/5/5 - C/O rate 10 bpm, 80 RPMs Pull to shoe - Preform LOT per GKA procedure. Calcu 16.0 EMW 9.3 ppg ,9473' MD, 4511' TVD = 1572 psi @ Surface - Pump rate 8 spm , @ 50 stks in,1560 psi had leak off, Continued to pump 3 bbls per procedure to 82 stks/ 1240psi, shut down pumps, held for 10 min, final PSI 720 psi. Fill out LOT/FIT test sheet EMW = 14.7 ppg Dir Drlg & Slide 9501' to 10,400' MD ( 4869' TVD) ART 6.0 hrs, AST 0.0 hrs , PP 2100 psi, Rate 546 gpm, WOB 8-13 K, RPMs 100. Up wt 173 K, Dn wt 112 K, Rot wt 134 K, Trq on bttm 13-14 K ftllbs, off bttm 13-14 Kftllbs h..NOTE.... @ 10,018' all LWD signal. Directional tools still working properly.After conferring with well engr & stepup TL it was decided to drill ahead to 13,000' MD MAX, @ that time or before if needed Rig will TOH and replace LWD tools. Dir Drlg & Slide 10,400' to 11560' MD ( 5323' TVD) ART 6.2 hrs, AST 2.0 hrs - PP 2500psi, Rate 546 gpm, WOB 10-15 K, RPMs 100, Up wt 185, Dn wt 110 K, Rot 130 K, Trq on bttm 17 K ft/lbs, off bttm 17 K ftllbs Dir Drlg & Slide 8? hole - 11560 to 12440' MD ( 5673' TVD) ART 6.9 hrs , AST 0.7 hrs , PP 2730, PR 65/65 spm (546 gpm) Rot 100 RPMs, Up wt 210 K, Dn wt 108 K, Rot wt 140 K, Trq on bttm 12/14 K ftllbs, off bttm 14 K ftllbs Dir Drlg & Slide 8? hole - 12440' to 12708' MD (5781' TVD) ART 2.8 hrs , AST 0.0 hrs , PP 2730, PR 65/65 spm (546 gpm) Rot 100 RPMs, Up wt 210 K, Dn wt 110 K, Rot wt 141 K, Trq on bttm 15/17 K ft/lbs, off bttm 12 K ft/lbs Circu & Condition hole - Rate 550 gpm, Rot 100 RPMs, Circu BU X 2? Observe well- Blow dn TD - TOH to 11318' Observe well - Pump dry job TOH to 9368' Monitor Well @ 9.625 shoe- Observe 20 min - Had very slight flow - Hole fill was determined to be less than calcu. TI H to BTTM - Appeared to be correct displacement on TI H CBU (Calcu BU stks 6820) - Rate 120 spm , RPMs 100, Recip DP 90' at all times - SB 1 std per/hr. Gas cut mud to surface 6000 stks in on BU - Low cut to 8.8ppg - Length of cut 1250 stks - BU had a good show of cutting to surface. Wt up Mud 9.3ppg to 9.7ppg , PR 546 gpm, 80 RPMs (per Baker request) - Std Bk 1 std/hr Monitor well (Static) -Blow dn TD TOH 10 stds to 11,768' - No excess drag - No swab - Monitor well (Static) TOH to Csg shoe @ 9473' - No excess drag - No swab - Calcu fill to shoe 26.25 bbls, Actual 31.5 bbls Monitor well - Very slight flow,decreasing to 0 - Well (static) TOH to HWDP - Monitor well 1 0 min (Static) Std Bk HWDP & Jars - PJSM Rad. Sources - Std Bk NMDCs - Remove sources Plug in to MWD - Trouble shoot short (confirmed short in CAP module) UD same - Drain Motor, Brk Bit, UD Motor & stab ( 3/8" movement in lower bearing) P/U BHA#6 - P/U Motor, bit, MWD, PJSM Rad. sources, Install sources - Test MWDs "OK" TIH to 12,613' (Brk circu @ shoe - Fill DP every 20 stds )- Record Up Printed: 1/10/2003 1 :08:02 PM .) ) ConocoPblllipsAlaska Page Tof 8 .Operations,Sunll11ary <Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-22 1 C-22 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 12/6/2002 Rig Release: Rig Number: Spud Date: 12/7/2002 End: Group: Date Sub Frorn- To Hours Code Code Phase Description of Operations 12/22/2002 17:00 - 23:00 6.00 DRILL TRIP PROD & Dn wts every 20 stds after fill. 23:00 - 23:30 0.50 DRILL REAM PROD Wash & Ream 12,613' to 12708' - Ck shot Srv on Bttm 23:30 - 00:00 0.50 DRILL DRLG PROD Dir Drlg & Slide 8?" hole 12708' to 12718' MD ( 5786' TVD) ART 0.0 hrs , AST 0.4 hrs, PP 2350, PRate 504 gpm, Rot 135, Trq off bttm 14 K ft/lbs, On bttm 15 K , Up wt 215 K, Dn wt11 0, Rot wt 135 K 12/23/2002 00:00 - 12:00 12.00 DRILL DRLG PROD Dir Drlg & Slide 8?" hole 12,718' to 13,390' MD ( 6064' TVD) ART 6.5 hrs , AST 1.5 hrs, PP 3000, PRate 504 gpm, WOB 15-25 K, Rot 100 RPMs, Trq off bttm 16 K ftllbs, On bttm 17 K , Up wt 220 K, Dn wt115, Rot wt 142 K . ECDs 11.35ppg bttm, 11.16ppg @ shoe 12:00 - 00:00 12.00 DRILL DRLG PROD Dir Drlg & Slide 8?" hole 13,390' to 14,050' MD ( 6430' TVD) ART 6.2 hrs, AST 2.6 hrs, PP 3100, PRate 504 gpm, WOB 20-25 K, Rot 100 RPMs, Trq off bttm 16 K ftllbs, On bttm 17 K , Up wt 220 K, Dn wt115, Rot wt 142 K . ECDs 11.46ppg bttm, 11.20ppg @ shoe 12/24/2002 00:00 - 12:00 12.00 DRILL DRLG PROD Drlg. from 14050 to 14620. TD (TVD 6822') PUW 245K=SOW 125K RW 165K= TQ 22K on 21 K off. SPR #1 30-630# #2 30 SPM 500#. 12:00 - 15:00 3.00 DRILL CIRC PROD Circ. & Condo @ 500 GPM-1 00 RPM. Pump weighted sweep & CBU X 2. 15:00 - 19:00 4.00 DRILL WIPR PROD Observe well=blow down top drive=POH 10 stands=observe well=pump drive job=blow down top drive=POH into shoe @ 9452-observe well. 19:00 - 20:30 1.50 DRILL OTHR PROD Slip & cut 110' drlg. line. Service top drive & blocks. 20:30 - 23:00 2.50 DRILL WIPR PROD RIH to Bottom @ 14620'=fill pipe every 20 stands. 23:00 - 00:00 1.00 DRILL CIRC PROD Circ. & Condo @ 500 GPM,s 100 RPM,s. 12/25/2002 00:00 - 03:30 3.50 DRILL CIRC PROD Circ. Condition mud for csg. Build mud wt. to 10.5# & spot lube pill. 03:30 - 05:00 1.50 DRILL TRIP PROD Observe well-poh 10 stands-observe well & pump pill. 05:00 - 08:30 3.50 DRILL TRIP PROD POH-stand back 73 stands 5" dp. 08:30 - 13:30 5.00 DRILL PULD PROD POH-Laying down 219 jts. 5" dp. 13:30 - 17:00 3.50 DRILL PULD PROD Observe well-lay down hwdp-jars-nmdc,s-mwd-motor-remove source-clear floor. 17:00 - 18:30 1.50 DRILL OTHR PROD Pull wear ring-install test plug-change top rams to 7"-test same-change out bails on top drive-make up circ. tool. 18:30 - CASE RUNC PROD PJSM=rig up & run 7" csg. as per program. 12/26/2002 00:00 - 01 :00 1.00 CASE RUNC PROD Run 7" csg. to 4500'. 01 :00 - 01 :30 0.50 CASE CIRC PROD Circ. capacity of csg. @ 4500'. 01 :30 - 05:30 4.00 CASE RUNC PROD Run 7" csg. to 9400'. 05:30 - 06:30 1.00 CASE CIRC PROD Circ. capcity of csg. @ 9400'. 06:30 - 11 :30 5.00 CASE RUNC PROD Run 7" csg. to 14609'. 11 :30 - 16:00 4.50 CASE CIRC PROD Circ. & condition mud @ 14609' w/ partial returns @ 3 bpm 600 psi mix barofiber & stage pumps up to 6 bpm 800psi gained full returns total mud loss 33 bbls. 16:00 - 16:30 0.50 CASE OTHR PROD Rig down fill up tool-blow down top drive-make up cement head. 16:30 - 17:30 1.00 CASE CIRC PROD Circ. & condo @ 6 bpm w/ full returns=take on seawater. 17:30 - 20:00 2.50 CEMENT PUMP PROD PJSM=Pump spacers & cement as per program. Bump plug on calculated strokes-to 500# over pump pressure-bleed off-floats held. 20:00 - 20:30 0.50 CEMENTOTHR PROD Rig down cement head & landing jt. 20:30 - 21 :00 0.50 CEMENTOTHR PROD Install packoff-test to 5000# 10 mins.-set test plug. 21 :00 - 23:00 2.00 CMPLTN OTHR PROD Change top rams to 3.5" X 6"-test doors to 2000#-change bails on top drive-clear floor. 23:00 - 00:00 1.00 CMPL TN RUNT PROD Rig up to run 3.5" completion. 12/27/2002 00:00 - 00:30 0.50 CMPL TN OTHR CMPL TN Service rig & skate for running completion. 00:30 - 12:00 11.50 CMPL TN RUNT CMPL TN PJSM=Run 446 jts. 3.5" 9.3# L-80 EUE 8rd mod tbg. w/ nipples-packer-pbr- & glm. 12:00-14:00 2.00 CMPL TN CIRC CMPL TN Pump 125 bbls. seawater @ 3 bpm-280# Pick up wt. 122k Slackoff wt. 55k. Printed: 1/10/2003 1:08:02 PM ) ) ConocoPhillips Alaska Page 8 ot8 Operations Summary Report Legal Well Name: 1 C-22 Common Well Name: 1 C-22 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From-To Hours '". Sub Phase Code Code 12/27/2002 14:00 - 15:30 1.50 CMPL TN PCKR CMPL TN 15:30 - 16:00 0.50 CMPL TN CIRC CMPL TN 16:00 - 17:30 1.50 CMPL TN SOHO CMPL TN 17:30 - 19:00 1.50 CMPL TN NUND CMPL TN 19:00 - 21 :00 2.00 CMPL TN NUND CMPL TN 21 :00 - 23:30 2.50 CMPL TN DEQT CMPL TN 23:30 - 00:00 0.50 CMPLTN CIRC CMPL TN 12/28/2002 00:00 - 00:30 0.50 CMPL TN CIRC CMPL TN 00:30 - 01 :00 0.50 CMPL TN OTHR CMPL TN 01 :00 - 02:00 1.00 CMPL TN FRZP CMPL TN 02:00 - 03:30 1.50 CMPL TN OTHR CMPL TN 03:30 - 04:30 1.00 CMPL TN FRZP CMPL TN 04:30 - 08:00 3.50 CMPL TN OTHR CMPL TN 08:00 - 10:00 2.00 CMPL TN OTHR CMPL TN 10:00 - 11 :00 1.00 CMPL TN OTHR CMPL TN 11 :00 - 12:00 1.00 CMPL TN OTHR CMPL TN Start: 12/6/2002 Rig Release: Rig Number: Spud Date: 12/7/2002 End: Group: 'Description of Operations Drop ball & pump down @ 1 bpm as per baker rep. Set packer wI 2500# @ 14047' Shear out ball @ 4000#. Shear pbr & sting out. Circ. 180 bbls. clean seawater @ 6 bpm 1060#. Make up hanger & landing jt.=land hanger-rilds-Iay down landing jt.-set 2 way check. N/D bope. N/U adapter flange & tree-test adapter to 5000# 10 mins. ok=test tree 5000# 10 mins. ok. Pull 2 way check. Rig up & test tbg. to 3500# 30 mins. Chart same=bleed to 1500# test annulus 3500# 30 mins. chart same. Bleed tbg. & shear rpv. Rig up & pump 270 bbls. seawater wI inhibitor down annulus taking returns out tbg. Finish pumping seawater wI inhibitor down 3.5" X 7" annulus. Perform LOT on 9 5/8" X 7" annulus=EMW 13.7#. Freeze protect 3.5" X 7" annulus wI 80 bbls. diesel. 'U' Tube annulus & tbg. while laying down 5" dp. Freeze protect 9 5/8" X 7" annulus wI 80 bbls. diesel. while laying down 5" dp. Continue laying down total of 219 jts. 5" dp out of derrick. Set BPV & secure well=150# on 9 5/8" X 7" annulus. Cut & slip 70' drlg. line. Prepare rig for move to 2 G Pad. (release rig @ 1200 hrs. 12-28-02) Printed: 1/10/2003 1 :08:02 PM Date 01/10103 01/11/03 01/12/03 01/16/03 01/17103 ') ) 1 C-22 Event H ¡story Comment DRIFTED TBG 2.73" & TAGGED @ 145211 RKB. PULLED OCR @ 149361 RKB. LOAD IA & TBG WI 490 BBLS DIESEL. SET 1/4" OV @ 149361 RKB. PIT TBG GOOD. IN PROGRESS. [TAG, GLV, PT TBG-CSG] DRIFTED TBG 221 X 2.5 HC DMY GUN TO 145001 SLM. PIT TBG 2500 PSI, GOOD. [PERF, PT TBG-CSG] RAN SCMT-BB, TAGGED PBTD @ 145211 MD. WELL DIFFICULT TO DECEND 10900' TO 138001 DUE TO DEVIATION, MADE JEWELRY LOG WITH PRESSI TEMP. LOGGED MAIN PASS UP @ 1800 FPM WI 1000 PSI WHP, FOUND GOOD CEMENT FROM 143301 UP TO TBG TAIL. PRESSURED UP WELL TO 4300 PSI, LOGGED REPEAT UP PASS TD TO 139001. VERIFIED GOOD CEMENT. NO BIG CHANGE BY PRESSURING UP WHo POOH, RDMO LEFT WELL SI. PERFORATED 143401 TO 143651, 6 SPF POWERJET, 60 DEG PHASING. WHTP PRIOR TO PERF=50 PSI; ... AFTER=650 PSI. ON WAY OOH, TS STUCK ACROSS BOPSIMASTERISW AB; WAS NECESSARY TO PUMP INTO WELL IN ORDER TO FREE UP (STEADY 0.5 BPM @ 2800 PSI ). STATIC BHP COMPLETED PER PROCEDURE - PREP UNIT FOR DOYON 141 [PRESSURE DATA] Page 1 of 1 1/20/2003 ) ) ConocoPhillips Alaska, Inc. Pad 1C 22 slot #22 Kuparuk River Unit North Slope, Alaska SUR V E Y LIS TIN G by Baker Hughes INTEQ Your ref Our ref License MWD <0-14620'> svy6813 Date printed Date created Last revised 14-Jan-2003 8-Dec-2002 26-Dec-2002 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.173,w149 30 19.124 Slot location is n70 19 29.508,w149 29 40.347 Slot Grid coordinates are N 5968646.480, E 562334.930 Slot local coordinates are 1592.65 S 1328.52 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ConocoPhillips Alaska, Inc. Pad IC,22 Kuparuk River Unit, North Slope, Alaska Measured Inclin Depth Degrees 0.00 138.00 201.80 294.34 385.46 474.12 564.54 654.74 746.46 837.60 928.00 1017.19 1108.42 1201.36 1294.10 1387.14 1479.39 1572.61 1663.83 1757.33 1851.14 1944.06 2036.62 2129.15 2223.59 2316.36 2408.06 2501.54 2593.98 2685.75 2776.02 2868.70 2963.01 3055.56 3147.58 3241.12 3332.56 3426.22 3518.57 3607.74 3704.86 3798.44 3890.51 3982.55 4075.71 4111.00 4169.03 4262.55 4354.07 4447.60 0.00 0.00 0.45 0.15 1. 69 4.12 6.15 10.58 16.06 20.20 23.24 28.04 35.90 43.75 44.97 45.28 49.23 53.09 58.90 62.18 61.78 65.91 70.05 67.74 69.11 68.25 67.29 66.78 66.95 68.51 68.07 66.91 66.96 66.88 66.98 66.96 66.82 66.89 66.73 66.86 66.95 67.22 66.98 66.93 66.82 66.87 66.95 66.97 66.98 66.65 Azimuth Degrees 0.00 0.00 241. 80 72.09 67.47 69.21 69.38 69.80 66.51 68.76 68.80 70.20 71.88 72.03 70.69 72.38 72.87 71.27 69.64 70.05 68.58 66.21 65.01 64.22 67.01 67.49 67.77 65.42 65.65 64.85 64.11 64.48 64.53 64.25 63.96 62.40 64.52 64.43 65.97 65.73 66.87 67.65 70.00 69.40 70.09 69.21 67.77 69.78 68.53 68.10 True Vert Depth 0.00 138.00 201. 80 294.34 385.44 473.98 564.04 653.25 742.47 829.07 913.04 993.43 1070.76 1142.08 1208.39 1274.04 1336.64 1395.09 1446.09 1492.07 1536.14 1577.10 1611.79 1645.11 1679.84 1713.57 1748.26 1784.74 1821.06 1855.84 1889.23 1924.71 1961.66 1997.95 2034.00 2070.60 2106.49 2143.31 2179.67 2214.81 2252.91 2289.34 2325.18 2361. 20 2397.79 2411. 67 2434.43 2471.04 2506.83 2543.66 R E C TAN G U L A R COO R DIN ATE S O.OOS O.OOS 0.12S 0.25S 0.30N 1.93N 4.79N 9.35N 17.32N 28.05N 40 . 1 6N 53.63N 69.24N 87.66N 108.39N 129.27N 14 9 . 48N 171.86N 197.18N 225.22N 254.47N 286.55N 321.99N 358.98N 395.23N 428.65N 460.96N 495.14N 530.34N 565.90N 602.03N 639.17N 676.52N 713.32N 750.29N 789.13N 826.71N 863.82N 899.42N 932.95N 968.86N 1002.18N 1032.81N 1062.20N 1091.86N 1103.14N 1122.71N 1153. 86N 1183.84N 1215.60N O.OOE O.OOE 0.22W 0.43W 0.93E 5.11E 12.69E 24.98E 44.54E 70.78E 101. 96E 138.11E 183.78E 240.33E 301.77E 364.30E 428.95E 498.00E 569.22E 645.64E 723.11E 800.07E 878.20E 956.18E 1036.16E 1115.86E 1194.35E 1273.34E 1350.71E 1427.83E 1503.51E 1580.66E 1658.98E 1735.75E 1811.91E 1888.74E 1963.97E 2041. 69E 2118.74E 2193.52E 2275.32E 2354.82E 2433.90E 2513.33E 2593.71E 2624.13E 2673.79E 2754.01E 2832.72E 2912.61E SURVEY LISTING Page 1 Your ref MWD <0-14620'> Last revised 26-Dec-2002 Dogleg Deg/lOOft 0.00 0.00 0.71 0.65 1. 69 0.00 0.00 -0.25 -0.49 0.97 Vert Sect G RID COO R D S Easting Northing 562334.93 562334.93 562334.71 562334.51 562335.86 562340.03 562347.57 562359.84 562379.32 562405.47 562436.55 562472.59 562518.12 562574.52 562635.78 562698.13 562762.61 562831.47 562902.47 562978.65 563055.88 563132.57 563210.40 563288.07 563367.75 563447.16 563525.38 563604.08 563681.15 563757.97 563833.36 563910.19 563988.19 564064.66 564140.51 564217.01 564291.93 564369.33 564446.09 564520.59 564602.09 564681.30 564760.12 564839.30 564919.43 564949.75 564999.25 565079.20 565157.66 565237.29 5968646.48 5968646.48 5968646.36 5968646.22 5968646.79 5968648.45 5968651.37 5968656.03 5968664.16 5968675.10 5968687.46 5968701.23 5968717.20 5968736.08 5968757.31 5968778.69 5968799.43 5968822.36 5968848.26 5968876.92 5968906.80 5968939.49 5968975.56 5969013.19 5969050.08 5969084.15 5969117.09 5969151.91 5969187.74 5969223.91 5969260.66 5969298.41 5969336.39 5969373.82 5969411.40 5969450.86 5969489.04 5969526.78 5969563.01 5969597.14 5969633.71 5969667.67 5969698.95 5969728.97 5969759.28 5969770.81 5969790.78 5969822.58 5969853.19 5969885.60 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #22 and TVD from RKB (Doyon 141) (87.10 Ft above mean sea level). Bottom hole distance is 12333.79 on azimuth 66.77 degrees from wellhead. Vertical section is from wellhead on azimuth 66.78 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 2.74 2.25 4.91 6.03 4.61 5.46 13.55 26.65 47.76 76.11 3.36 5.42 8.67 8.45 1. 66 109.54 148.07 196.19 255.43 320.06 1. 33 4.30 4.35 6.54 3.53 385.76 453.14 525.42 600.85 682.13 1. 45 5.00 4.63 2.62 3.11 764.86 848.24 934.01 1020.26 1108.05 1. 04 1. 08 2.38 0.29 1. 88 1194.47 1279.34 1365.41 1450.39 1535.28 0.90 1. 30 0.07 0.29 0.31 1619.08 1704.62 1791. 32 1876.39 1960.96 1. 53 2.14 0.12 1. 54 0.29 2046.87 2130.82 2216.87 2301. 73 2383.67 1. 08 0.82 2.37 0.60 0.69 2473.00 2559.19 2643.95 2728.53 2814.09 2.29 2.29 1. 98 1. 26 0.55 2846.50 2899.85 2985.85 3070.01 3155.95 ConocoPhillips Alaska, Inc. Pad 1C,22 Kuparuk River Unit, North Slope, Alaska Measured Inclin Depth Degrees 4541.74 4634.80 4726.59 4813.23 4906.25 5003.98 5096.89 5190.18 5282.56 5376.61 5469.59 5562.59 5653.80 5746.87 5839.20 5932.71 6025.42 6117.57 6211.44 6303.74 6396.77 6489.45 6582.51 6674.30 6769.25 6861.51 6954.46 7048.31 7140.44 7230.51 7324.40 7415.10 7510.15 7603.45 7697.15 7790.44 7882.88 7975.77 8069.37 8162.21 8254.58 8347.90 8440.36 8532.41 8625.81 8719.30 8811 .12 8904.40 8997.40 9089.72 66.76 66.66 66.80 66.88 66.91 66.65 66.97 67.08 66.99 67.00 66.83 66.75 66.89 66.74 66.97 67.01 66.88 67.04 66.64 66.61 67.07 66.38 66.94 67.33 67.25 66.80 67.35 67.22 67.06 67.41 67.00 67.30 66.68 66.79 67.21 67.24 67.05 66.87 67.07 67.02 66.80 66.92 67.49 67.01 66.94 66.75 67.16 66.95 66.99 66.88 Azimuth Degrees 69.94 70.70 70.56 70.02 70.11 69.94 69.07 68.00 67.09 66.18 65.26 64.86 64.34 63.94 63.09 63.98 64.51 64.89 65.87 65.85 66.26 66.78 66.78 66.51 66.35 66.68 65.75 65.46 65.61 66.02 66.44 66.11 66.05 66.12 66.96 65.94 66.96 66.54 66.29 65.95 66.24 66.43 66.36 66.37 66.43 66.04 64.79 65.42 66.36 65.84 True Vert Depth 2580.89 2617.68 2653.95 2688.02 2724.53 2763.06 2799.64 2836.06 2872.10 2908.86 2945.32 2981.97 3017.87 3054.51 3090.80 3127.36 3163.66 3199.73 3236.65 3273.27 3309.86 3346.48 3383.35 3419.01 3455.67 3491.68 3527.89 3564.13 3599.92 3634.77 3671.15 3706.37 3743.53 3780.38 3816.99 3853.10 3889.01 3925.36 3961. 98 3998.19 4034.41 4071.09 4106.91 4142.51 4179.04 4215.80 4251.74 4288.11 4324.49 4360.66 R E C TAN G U L A R COO R DIN ATE S 1246.56N 1275.35N 1303.31N 1330.18N 1359.35N 1390.03N 1419.93N 1451.36N 1483.85N 1518.18N 1553.35N 1589.40N 1625.36N 1662.68N 1700.54N 1738.89N 1775.96N 1812.20N 1848.16N 1882.81N 1917.52N 1951.44N 1985.13N 2018.66N 2053.68N 2087.53N 2122.06N 2157.81N 2192.97N 2227.00N 2261. 89N 2295.51N 2330.99N 2365.73N 2400.07N 2434.44N 2468.47N 2502.21N 2536.68N 2571. 29N 2605.72N 2640.16N 2674.29N 2708.33N 2742.74N 2777.38N 2812.53N 2848.69N 2883.65N 2918.07N 2993.34E 3073.83E 3153.38E 3228.37E 3308.80E 3393.21E 3473.20E 3553.14E 3631.74E 3711.21E 3789.18E 3866.68E 3942.43E 4019.41E 4095.40E 4172.45E 4249.28E 4325.94E 4404.40E 4481.72E 4559.89E 4637.98E 4716.50E 4794.15E 4874.43E 4952.33E 5030.67E 5109.51E 5186.78E 5262.54E 5341.76E 5418.28E 5498.25E 5576.60E 5655.73E 5734.58E 5812.66E 5891.20E 5970.15E 6048.31E 6126.00E 6204.59E 6282.70E 6360.47E 6439.24E 6517.91E 6594.74E 6672 . 65E 6750.77E 6828.43E ) SURVEY LISTING Page 2 Your ref MWD <0-14620'> Last revised 26-Dec-2002 Dogleg Deg /100 ft 1. 80 0.76 0.21 0.58 0.09 3242.35 3327.66 3411.79 3491.30 3576.72 Vert Sect G RID Easting COO R D S Northing 5969917.21 5969946.65 5969975.26 5970002.73 5970032.55 5970063.92 5970094.46 5970126.54 5970159.66 5970194.64 5970230.44 5970267.10 5970303.68 5970341.62 5970380.09 5970419.07 5970456.76 5970493.61 5970530.20 5970565.48 5970600.82 5970635.37 5970669.69 5970703.85 5970739.52 5970774.00 5970809.16 5970845.55 5970881. 33 5970915.97 5970951.50 5970985.75 5971021.86 5971057.24 5971092.22 5971127.22 5971161.89 5971196.26 5971231.37 5971266.60 5971301.66 5971336.74 5971371.50 5971406.16 5971441.21 5971476.49 5971512.26 5971549.05 5971584.64 5971619.68 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #22 and TVD from RKB (Doyon 141) (87.10 Ft above mean sea level). Bottom hole distance is 12333.79 on azimuth 66.77 degrees from wellhead. Vertical section is from wellhead on azimuth 66.78 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 0.31 0.93 1. 06 0.91 0.89 3666.39 3751. 69 3837.54 3922.59 4009.16 0.93 0.40 0.55 0.43 0.88 4094.68 4180.11 4263.90 4349.36 4434.12 0.88 0.54 0.42 1. 05 0.04 4520.05 4605.27 4690.02 4776.29 4861.01 0.64 0.91 0.60 0.50 0.18 4946.53 5031.67 5117.11 5201.69 5289.28 0.59 1.10 0.32 0.23 0.57 5374.22 5459.82 5546.37 5631. 25 5714.29 0.60 0.47 0.65 0.14 0.94 5800.84 5884.42 5971.90 6057.61 6143.86 1. 01 1. 04 0.46 0.33 0.34 6229.87 6315.05 6400.53 6486.67 6572.15 0.37 0.23 0.62 0.52 0.10 6657.11 6742.92 6828.16 6913.05 6999.00 0.43 1. 33 0.66 0.93 0.53 7084.96 7169.42 7255.29 7340.86 7425.80 565317.75 565397.99 565477.30 565552.07 565632.25 565716.40 565796 .14 565875.81 565954.14 566033.32 566111.00 566188.20 566263.64 566340.31 566415.98 566492.71 566569.22 566645.59 566723.74 566800.76 566878.64 566956.44 567034.68 567112.05 567192.03 567269.65 567347.70 567426.24 567503.22 567578.69 567657.61 567733.85 567813.52 567891.58 567970.42 568048.98 568126.78 568205.03 568283.68 568361. 56 568438.95 568517.26 568595.08 568672.56 568751.04 568829.42 568905.95 568983.57 569061.39 569138.76 ) ConocoPhillips Alaska, Inc. Pad 1C,22 Kuparuk River Unit,North Slope, Alaska Measured Inclin Depth Degrees 9183.16 9275.75 9368.67 9444.74 9567.74 9649.63 9742.05 9835.40 9928.78 10021.33 10113.34 10206.30 10300.61 10393.96 10487.43 10580.76 10673.50 10766.29 10859.45 10951. 44 11043.84 11136.47 11229.84 11323.12 11416.21 11508.54 11600.96 11693.05 11786.21 11859.88 11971. 07 12065.71 12159.45 12251. 48 12344.31 12438.58 12529.88 12623.74 12716.07 12807.84 12899.56 12993.25 13087.54 13182.53 13273.24 13366.73 13458.66 13552.02 13644.13 13735.23 67.01 67.09 66.94 67.10 67.49 67.46 67.50 67.48 67.35 67.33 67.36 66.98 66.91 66.62 66.51 66.29 66.95 67.71 67.56 67.48 67.40 67.09 66.86 66.91 66.42 66.41 66.26 66.40 66.44 66.56 66.28 65.82 66.91 66.84 67.12 66.84 66.39 65.77 65.84 66.53 66.27 66.25 66.46 66.36 63.98 61.54 59.95 59.30 56.54 56.04 Azimuth Degrees 65.75 65.83 66.20 66.21 66.56 66.36 67.67 66.26 66.30 67.12 65.20 67.01 65.69 68.20 70.34 69.61 68.51 67.79 67.30 67.67 68.10 69.30 67.89 66.49 64.79 64.22 65.32 65.48 65.00 63.93 63.80 63.39 65.31 66.25 68.62 68.49 69.25 69.25 67.42 63.84 65.73 67.04 65.52 66.05 66.01 67.54 67.24 67.51 67.82 67.69 True Vert Depth 4397.25 4433.36 4469.64 4499.34 4546.82 4578 .19 4613.59 4649.33 4685.19 4720.85 4756.29 4792.36 4829.30 4866.13 4903.30 4940.67 4977.47 5013.24 5048.68 5083.86 5119.31 5155.14 5191. 66 5228.28 5265.15 5302.10 5339.19 5376.17 5413.43 5442.81 5487.29 5525.71 5563.29 5599.43 5635.74 5672.60 5708.84 5746.90 5784.74 5821. 81 5858.53 5896.25 5934.07 5972 . 08 6010.17 6052.96 6097.89 6145.10 6194.01 6244.57 R E C TAN G U L A R COO R DIN ATE S 2953.32N 2988.28N 3023.06N 3051. 31N 3096.76N 3126.98N 3160.31N 3194.05N 3228.74N 3262.51N 3296.82N 3331. 53N 3366.34N 3399.93N 3430.28N 3459.57N 3489.99N 3521. 86N 3554.76N 3587.31N 3619.44N 3650.47N 3681.83N 3715.08N 3750.34N 3786.76N 3822.84N 3857.95N 3893.71N 3922.83N 3967.72N 4006.18N 4043.35N 4078.07N 4110.85N 4142.57N 41 72 . 78N 4203.18N 4234.27N 4268.91N 4304.71N 4339.07N 4373.81N 4409.52N 4442.96N 4475.75N 4506.58N 4537.57N 4567.22N 4595.91N 6906.85E 6984.61E 7062.77E 7126.85E 7230.81E 7300.16E 7378.75E 7458.11E 7537.05E 7615.49E 7693.15E 7771.48E 7850.97E 7929.89E 8010.09E 8090.44E 8169.94E 8249.41E 8329.03E 8407.55E 8486.60E 8566.19E 8646.19E 8725.27E 8803.13E 8879.51E 8956.08E 9032.77E 9110.30E 9171. 26E 9262.75E 9340.21E 9417.62E 9494.81E 9573.70E 9654.45E 9732.62E 9812.85E 9891.12E 9967.57E 10043.61E 10122.19E 10201.26E 10280.65E 10355.87E 10432.24E 10506.28E 10580.63E 10652.81E 10722.95E Dogleg Deg /100 ft SURVEY LISTING Your ref Last revised 0.16 0.12 0.40 0.21 0.41 7511.76 7597.01 7682.54 7752.57 7866.04 ) Page 3 MWD <0-14620'> 26-Dec-2002 Vert Sect G RID Easting COO R D S Northing 5971655.56 5971691.16 5971726.56 5971755.33 5971801.63 5971832.40 5971866.37 5971900.75 5971936.07 5971970.47 5972005.42 5972040.75 5972076.21 5972110.43 5972141.44 5972171.37 5972202.44 5972234.95 5972268.50 5972301.68 5972334.44 5972366.11 5972398.12 5972432.01 5972467.90 5972504.93 5972541.63 5972577.36 5972613.75 5972643.36 5972688.99 5972728.07 5972765.86 5972801.21 5972834.63 5972867.00 5972897.84 5972928.89 5972960.61 5972995.87 5973032.29 5973067.27 5973102.66 5973139.00 5973173.05 5973206.46 5973237.89 5973269.47 5973299.71 5973328.97 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #22 and TVD from RKB (Doyon 141) (87.10 Ft above mean sea level). Bottom hole distance is 12333.79 on azimuth 66.77 degrees from wellhead. Vertical section is from wellhead on azimuth 66.78 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 0.23 1. 31 1. 40 0.14 0.82 7941.68 8027.05 8113.28 8199.50 8284.90 1. 93 1. 84 1. 29 2.49 2.10 8369.81 8455.47 8542.24 8628.01 8713.69 0.75 1. 30 1. 09 0.51 0.38 8799.08 8884.13 8969.73 9055.87 9140.86 0.44 1. 24 1. 41 1. 38 1. 76 9226.18 9311. 55 9397.43 9483.22 9568.67 0.57 1.10 0.22 0.47 1. 34 9653.23 9737.82 9822.14 9907.49 9974.99 0.27 10076.77 0.63 10163.12 2.21 10248.92 0.94 10333.54 2.37 10418.96 0.32 10505.68 0.91 10589.43 0.66 10675.15 1.81 10759.33 3.65 10843.25 1.91 10927.24 1.28 11013.00 1.49 11099.37 0.52 11186.41 2.62 11268.72 2.99 11351.83 1.75 11432.03 0.7411512.57 3.01 11590.60 0.56 11666.37 569216.88 569294.35 569372.21 569436.05 569539.64 569608.73 569687.04 569766.12 569844.76 569922.92 570000.29 570078.33 570157.52 570236.16 570316.10 570396.21 570475.45 570554.65 570633.99 570712.24 570791.02 570870.34 570950.07 571028.87 571106.44 571182.51 571258.78 571335.17 571412.40 571473.12 571564.23 571641.37 571718.47 571795.36 571873.98 571954.47 572032.37 572112.35 572190.35 572266.52 572342.25 572420.54 572499.32 572578.41 572653.35 572729.45 572803.22 572877.31 572949.24 573019.14 ) ,) ConocoPhillips Alaska, Inc. SURVEY LISTING Page 4 Pad 1C,22 Your ref MWD <0-14620'> Kuparuk River Unit, North Slope, Alaska Last revised 26-Dec-2002 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G RID C o 0 R D S Depth Degrees Degrees Depth C 0 0 R D I N A T E S Deg/100ft Sect Easting Northing 13829.39 53.79 67.66 6298.69 4625.18N 10794.22E 2.39 11743.40 573090.16 5973358.81 13921.93 53.41 67.69 6353.60 4653.47N 10863.13E 0.41 11817.88 573158.83 5973387.66 14014.05 52.04 66.56 6409.40 4681.96N 10930.66E 1. 78 11891.18 573226.12 5973416.69 14107.69 49.72 67.07 6468.47 4710.56N 10997.44E 2.51 11963.82 573292.66 5973445.84 14200.71 47.02 66.63 6530.26 4737.89N 11061.36E 2.92 12033.34 573356.35 5973473.68 14293.76 45.35 65.54 6594.68 4765.10N 11122.74E 1. 98 12100.47 573417.50 5973501.38 14385.47 45.37 64.13 6659.12 4792.85N 11181.80E 1. 09 12165.69 573476.33 5973529.61 14479.36 45.63 65.63 6724.93 4821.27N 11242.43E 1.17 12232.61 573536.72 5973558.52 14542.54 46.15 64.91 6768.91 4840.25N 11283.63E 1.16 12277.96 573577.76 5973577.83 14620.00 46.15 64.91 6822.57 4863.94N 11334.22E 0.00 12333.79 573628.15 5973601.93 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #22 and TVD from RKB (Doyon 141) (87.10 Ft above mean sea level). Bottom hole distance is 12333.79 on azimuth 66.77 degrees from wellhead. Vertical section is from wellhead on azimuth 66.78 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ) ) ConocoPhillips Alaska, Inc. Pad lC,22 Kuparuk River Unit, North Slope, Alaska SURVEY LISTING Page 5 Your ref MWD <0-14620'> Last revised : 26-Dec-2002 Comments in wellpath -------------------- -------------------- MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 4111. 00 2411. 67 1103.14N 2624.13E here Targets associated with this wellpath ------------------------------------- ------------------------------------- Target name Geographic Location T.V.D. Rectangular Coordinates Revised ----------------------------------------------------------------------------------------------------------- lC-A Hardline pt#1 2 573325.000,5974150.000,0.0000 6499.10 5414.51N 11035.51E 31-0ct-2002 1C-A Hardline Pt#2 2 573624.000,5973916.000,0.0000 6499.10 5178.06N 11332.62E 31-0ct-2002 1C-A Hardline Pt#3 2 574137.000,5973550.000,0.0000 6499.10 4807.87N 11842.68E 31-0ct-2002 1C-A Hardline Pt#4 2 574460.000,5973440.000,0.0000 6499.10 4695.23N 12164.81E 31-0ct-2002 1C-A Hardline Pt# 5 2 574480.000,5973124.000,0.0000 6499.10 4379.05N 12182.24E 31-0ct-2002 1C-A C4 TGT RVSD 13 573407.000,5973504.000,0.0000 6578.10 4767.80N 11112 . 26E 17-Sep-2002 ) ConocóP'hillips ) Post Office Box 100360 Anchorage, Alaska 99510-0360 Steve Shultz Phone(907)263-4620 Fax: (907) 265-1535 Email: steven.n.shultz(â¿conocophillips.com January 15,2003 Alaska Oil and Gas Conservation Commission 222 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Application for Sundry Approval for Annular Disposal of DrillingW aste on Well 1 C-22 Dear Sir: ConocPhillips Alaska, Inc. hereby requests that 1 C-22 be permitted for annular pumping of fluids occurring as a result of drilling operation, per regulation 20 ACC 25.080. It is intended to begin annular disposal Operation on 1 C-J.9Ö'" as soon as possible. 'Z.:l..... Please slthe attached form 10-403 and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Surface Casing Description 4. Surface Casing Cementing Report and Daily Drilling Reports during cement ops 5. Casing and Formation Integrity Report (LOT at surface casing shoe) 6. Production Casing Description 7. Production Casing Cementing Report and Daily Drilling Report during cement ops 8. Plan View of Existing Adjacent Wells 9. Plan View of Existing and Planned Adjacent Vv'eHs 10. Pressure Integrity Test If you have any questions or require further information, please contact Steve Shultz at 263- 4620 in the Conoco/Phillips office. S, l~E- n/ _ d JI~ Steve Shultz ~ Drilling Consultant ') STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ) \J...l 4- Å- !Ai- ð Ðts Il~i I 0'3 '1z.~/ù7 I{ ~<l-IÓ0 1. Type of request: APPLICATION FOR SUNDRY APPROVALS Abandon Suspend _ Alter casing _ Repair well _ Change approved program _ 2. Name of Operator ConocoPhillips Alaska, Inc. 3_ Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1593' FNL, 1327' FWL, Sec. 12, T11 N, R10E, UM At top of productive interval 2106' FNL, 2303' FWL, Sec. 5, T11N, R11E, UM At effective depth At total depth 2018' FNL, 24~;3' FWL, Sec. 5, T11 N, R11 E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 14620 6822 14620 6822 Casing Conductor Surface Length 138' 9443' Size 30" x 16" 9.625" Surface Production 14581' 7" Perforation depth: measured No Perforations true vertical No Perforations Tubing (size, grade, and measured depth 3.5",9.3#, L-80 @ 14074' Packers & SSSV (type & measured depth) packer set @ 14047' no SSSV 13. Attachments Description summary of proposal _X 14. Estimated date for commencing operation /' February 1, 2003 16. If proposal was verbally approved Operational shutdown _ Plugging _ Pull tubing _ 5. Type of Well: Development _ Exploratory _ Stratigraphic _ , Service _XX / (asp's 562335,5968646) (asp's 573439,5973513) (asp's 573629,5973604) feet Plugs (measured) feet feet Junk (measured) feet Cemented 348 sx Arctic Crete 1 st Stage: 382 bbls AS III Lite & 183.6 bbls Class G 2nd Stage: 500 bbls AS III Lite & 12 bbls AS I 51.5 bbls Class G Re-enter suspended well _ Time extension Stimulate Variance _ Perforate 6. Datum elevation (DF or KB feet) RKB 28 feet 7. Unit or Property name Other _XX Annular Disposal Kuparuk River Unit 8. Well number 1 C-22 ,,/ 9. Permit number / approval number 202-222 /' 10. API number 50-029-23127 11. Field / Pool Kuparuk River Field/Kuparuk Oil Pool Measured Depth 138' 9471' True vertical Depth 138' 4514' 14609' 6815' RECEJ\fED ~t~N 1 -¡ 2003 A1asl\a Oil & Gas Cons. Commission AnchofCige BOP sketch Detailed operations program! 15. Status of well classification as: Oil /" Name of approver Date approved Service _XX 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. i ~~ \~ ~ Signed - Randy Thomas Title: Kuparuk Team Leader FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP Test Location clearance Mechanical Integrity Test _ Subsequent form required 10- Approved by order of the Commission ORIGINAL SIGNED M L. Pill BY RBDMS BFt Form 10-403 Rev 06/15/88 · ,Jß.N2 7 2003 , ,'\ \ \ ~ ¿ ~ Gas Suspended _ Questions? Call Steve Shultz 263-4620 V \ ')/03 Date Prepared by Sharon Allsup-Drake I Approval no:v~O J<-I tZ >{.e~'" 1- ".Q. '\¡¡U<t1.i-ÍLt ~ dt ~ pv- ~"'- \ . , , Commissioner Date \ ~ 4 D 1:1 SUBMIT IN TRIPLICATE ') ) Annullar Disposal Transmittal Form-WelllC-22 A. B. Designation of well to receive drilling wastes: The depth to the base of freshwater aquifers and permafrost, if present. A stratigraphic description of the interval exposed to the open annulus and other information sufficient to support a commission finding that the waste will be confined and will not come to the surface or contaminate freshwater. A list of all publicly recorded wells within one- quarter mile and all publicly recorded water wells within one mile of the well to receive drilling waste. C. D. E. Identify the types and maximum volume of waste to be disposed of and the estimated density of the waste slurry. F. An estimate of maximum anticipated pressure at the outer casing shoe during annular disposal operations and calculations showing how this value was determined. Details that show the shoe of the outer casing is set below the base of any freshwater aquifer and permafrost, if present, and cemented with sufficient cement to provide zone isolation: Details that show the inner and outer casing strings have sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations: Any addition data required by the Commission to confirm containment of drilling wastes: G. H. I. I C-22 No Aquifers/Base of Permafrost=±2479' /' MDI1788'TVD From the 9 5/8" shoe to the Cement top all that is open is interbedded claystone, siltstone and shale with occasional minor non- hydrocarbon bearing sands. /' See attached horizontal plane clearance report and plot indicating that there are no wells /" within a quarter of a mile from the 9 5/8" surface casing shoe, There are no water wells within one mile of the IC Pad. Types of waste can be drilling mud, drilling cuttings, cement-contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, domestic waste water, and any added water needed to facilitate pumping of drilling mud or drilling cuttings. Maximum volume to be pumped is 35,000 bbls. /' Maximum anticipated pressure at casing shoe during disposal operation is 2,596 psi. See. attached calculation page. /' See Attached: cementing reports, LOT/FIT reports and casing reports. See attached casing summary sheet and calculation pages. 9481' MD 4514' TVD Well: lC-22 Date: 1/14/03 ~ ~ 9 5/8" Surface Csg /' ------------------------- ~~ 3 V2" TbO" 1=> Production 14,536' MD CSO" 6,822' TVD~O 7" ) ') Assumptions ~'/--"/ Maximum injection pressure 0 150 si Maximum density of the inject! ûld is 13.0 ppg Pore pressure at the 9 5/8" casing shoe is .4316 psilft Column of Gas to Bottom Mandrel with no gas lift pressure Maximum Pressure at Surface Shoe Max Disposal MW a·O ppg I Max. Pressure @ 9 5/8" Shoe 259 ~/psi ./ (Max Pressure=Max Disposal Press + (Max Disposal .Ó52)(TVD)-(Fluid Wt. On Backside)(.052)(TVD» /' (LOT performed on surface casing shoe to 14.7 PPG MWE or 1260 psi) . !/-ft/~· P$ ", 'iSc.¡y fç.t Production Casin2 Size Wt. Grade Collapse @ 100% Collapse @ 85% Gas Depth (TVD of bottom GLM) Gas Gradient Max Disposal Pressure Collapse Pump Pressure in 9 5/8" Annulus · No header pressure Column of gas to last GLM · No gas lift pressure · 13.0 ppg mud in annulus Maximum Mud Weight (to collapse casing with 1500 psi pump pressure) 7.000 In. 26.00 lbs. L-80 5410 psi 4599 psi 4650 ft. 0.11 ppg 1500 psi 1970 psi &7vg/ C Intermediate Casing Collapse MMW= Pc@85%+(Gas Gradient)(Gas TVD)-Max.Disposal Pressure (TVD) (.052) Surface Casin2 Size Wt. Grade Burst @ 100% Burst @ 85% Fluid Weight on Backside Max Disposal Pressure Maximum Surface Burst Pressure 13.0 ppg mud in annulus Maximum Mud Weight (to burst casing with 1500 psi pump) 9.625 In. 40.00 1bs. L-80 5750 psi 4888 psi 8.33 ppg 1500 psi 3792 psi ./ 22.8 ppg Surface Casing Burst MMW= Pb@ 85% +(Fluid Weight on Backside)(.052)(TVD)-Max Disposal Press (.052)(TVD) WELL: 1C-22 DATE: 12/17/02 1 OF 1 PAGES LENGTH DEPTH TOPS ) ) Casing Detail 9-5/8" surface casino CaNaCa PHilliPS Alaska, Inc. # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN DOYON RT to LR = 28.00 Above RKB 5.23' 9 5/8" Landing Joint ( 33.23 total) RKB HRG FMC Flutted Mandrel hanger jts.156-222 9 5/8" I 40#, L-80 BTC-MOD ST Weatherford Gemoeo Mo 754 stage emt tool jts 3-155 95/8",40#, L-80 BTC-MOD Landing baffle in Top of Jt#3 (9348.91') FC Float Collar jts 1-2 9 5/8" I 40#, L-80 BTC-MOD FS Float Shoe BTM OF SHOE @-----»»> TD of 12 1/4" hole = 9481.00'MD Total Centralizers Used 2 TOTAL - Bow Spring Centralizers 43 TOTAL, HES Rigid Centralizers 9 5/8" X 12" 4 Stop Collars 2 - Run Bow spring Cent on Jt 1 & 3 - Middle of jt on stop rings 9 - Cent in center of jt 2 & jts 4 - 11 ( float between collars) 32 - Cent every other jt 13 thru jt 75 2 -Cent in the center of jt,on stop rings above and below stage tool. Jts 155 & 156. **Hanger goes in the top of joint # 222 **Fill on the fly and Top off every 5 joints **Baker Lok all connections from the Top of the FC down ** Break Circu at 3000' & 6000' and condt mud to 80 Vis ** Stage up pumps to minimize surge ** Control running speed to minimize surge. 28.00 1.68 2858.13 2.83 6498.32 1.49 80.76 1.71 28.00 29.68 2887.81 2890.64 9388.96 9390.45 9471.21 9472.92 Remarks: String Weights with Blocks: 365 k Up, 70k On, 35k Blocks. Ran 222 joints of casing. Drifted casing with 8.679" plastic rabbit. Used Best-a-Life 2000 thread compound on all connections. DOYON 141 Drilling Supervisor: Fred Herbert / Dearl Gladden ) ) Service Contract Receipt IclllamblPllP SCHLUMBERGER TECHNOLOGY CORPORATION --------.--- ~~::~~..t,: ::,'~~1~Ø7 ,",',',,' \¡~~i,pl~;rRICT ,,' ,:~:,:!¡'!:¡,~1,~t1Jiqø2:1Iþel, 1:,30:øO::e~ ~MFWE~OCATION),,~I!I:I!;;li!i~IIII:~!ì2Ì17i2Ò02 Tim. ,2~ , ,I'M '·':.l~'" ;,1':., ,I,:."" ','II,II~1 ;;:~tJ!\I"'~I!':,. ',I, ',';:7' ;',; ",' TI",o ,"I~· :' ~,~,IjI,~~T:",:"",illll,lllïl!i:i'i Iii.""", I,J~ttl~P'~ " "''''''I';'~~~' ,PM , '1~i:S::~nlUl, Þ~:;I:~QN¡iil!,::I,I,,~ ,', Da", tit,' ,," ,. ': '::~,' ;)/, 1 Jnon,'\ "',' 11\")' ,^ "\Jitne" ,.' I,' ,',:f¡:h,,:,:,~:t~~Ø:,Ò(),::~i.,' ,.~~~r[.~~~;~~,F.~:~,¡~.. "",," -,.1:' "'1,,,1 ,!'" I "'I.I""'I'~;"'II~~~~ :.', ~ I., ,r .' '. ,I' I ,~."I '.." ~~,~ ':ijEiW':~',:"éÃt1õN':',:: :':_,:' "I 1~ ä:~øö~ 'Ti~ """"I",gíQO;dó'iiÀM, : :~Ii;'\: 'i :"~";"::~"~;i' iiXII<' ','::;!; 'i'i:':' " I I I, I I I ~,~ I I"" I, 'I:~ .:' ',,'!' ,'1 :$~œ~g:':~~~~!~r, ',~,illi "W1~O~2 l'~ "'1:ø~~ø,:qQ:':~M Senñoelnsüuctions Job allocation $ 80,500.00 Material cost $ 101,397.02 Total job cost $ 181,897.02 Invoice Mailing Address: ConocoPhillips Alaska Inc. ATTN: ACCOUNTS PAYABLE 10027561 CountyJParishlBlock Beechey Point Customer or Authorized Representative KUPARUK Wester, Don . THE ESTIMATED CHARGES AND DATA SHOWN BELOW ARE SUBJECT TO CORRECTION BY SCHLUMBERGER. I, "",' "I'''I''I'¡'~i!.!:''11 ""',' "" II [,1:: ",',:'1',' II":"', '''I'I:' "",': ,'i':' ! "',""" ':':",: ,',I' t'i,II 1111' t~~~," 1I1,llil'-"::"¡¡, ~u]=~\i:!J:::, · ¡I' I, ':"'1 '1""'11"""""1'1",;,,,:1: 1,,'i'I' 1'1':1 ,I, 111¡":¡I'II:lII'Q' "~I~I;;:'¡ww~ 'I'I' '1"'~Î'"I~i,' II \"II'i~iIo'" 'WII~(¡¡,j¡:JiJ:I"li"II'I,".":1 ,ii' l'I'Hi':¡::I~I"I,I:",I""" '1I'l'I" I ",''''~!':;':¡i:¡¡i.¡JI~ I.,'; 11',11: :,' ","1 ANCHORAGE, AK US Customer PO Well Field Services 102871096 110031326 59200002 59703000 Products 57998000 B809 0031 0046 0065 D079 0110 0149 0827 0962 M045 --.-.--- Contract Service Description Cementing - Cem Surface Casing RIg AFE 041-CMT1 AK02-0001 Doyon 141 Legal Location StatelProvlnce 1C 22 AK Casing Cmnt 9001-9500' 1 st 4 hr Cementing Work, Variable Charge Mileage, All Other Equipment Personnel Equip Qper Non-Service Time 1 EA 0.00 0.0% 0.00 1 JOB 2,159.00 0.0% 2,159.00 180 MI 0.00 0.0% 0.00 114 HR 0.00 0.0% 0.00 Services Subtotal: 2,159.00 Discount: 0.00 Estimated Total (USD): 2,159.00 2 EA 325.68 0.0% 6,51.36 211900 LB Q.25 0.0% 52,975.00 5758 LB 0.16 0.0% 921.28 248 LB 0.94 0.0% 233.12 414 LB 0.80 0.0% 331.20 206 LB 0.60 0.0% 123.60 250 GA 6.46 0.0% 1,615.00 331 LB 3.91 0.0% 1,294.21 70 BL 10.33 0.0% 723.10 605 CW 70.20 0.0% 42,471.00 5 GA 11.63 0.0% 58.15 Products Subtotal: 101,397.02 Discount: 0.00 Estimated Total (USD): 101,397.02 Fluid marker, Red dye ARCTICSET* Lite III Cement B809 Barite 031 Antifoam Agent, All Purpose D46 Dispersant, TIC 065 Extender, Chemical D79 Retarder, Cement 0110 MUDPUSH (R) XL Laminar 0149 Chemical Wash CW100 0827 CemCRETE Blend 0962 Antifoam Agent M45 103,556.02 0.00 Total (Before Discount): Discount: Special Discount: Estimated Discounted Total (USD): 103,556.02 Se Ilumberger .....---....-.........-,.... Well Field Engineer Country Time 22:08:37 23:11:05 00:13:33 01:16:01 02: 18:29 03:20: 57 04:23:25 ) Cement Job Report 1C-22 .' .,.,_w _. ._ .._._.'_~' .....~,."...~. ... .,.. ___.___..~'.,' ...".._. ._. .__..........,...".............. ...._. _ ... ,..._,.w.. ,'"_",_._, ...._.'.....'. .. .."._. ._,__._. .__. ..____..._.,.._. ~_. Kuparuk Rick Gallegos United States __ ..__ --..-·--------------·.---·'·0_-- Pressure ~n Client SIR No. Job Type Job Date ') CemCAT v1.0 _. ., ......_._.__.......... ". .____.__.,__,_.__"__h. n_,,__"__. ._.._...."..h"'."..". "._ .'__....'.__ -..' .,.,.."...' '-"'.'-""'"'' ConocoPhilllps 2201044867 9.625 Surface 12-17-2002 ------.--,... ,...' Rate Density ___0._.___________ -.--..-...-----..---..--r-----------.-----.-.--...----·.______.n_.__.__"n_____.."~_~__~_"".._._._._... .~__..._.·~.._~_þ.__·__·~"____~"~_·OR__."~·______,____·__..__ _. _., ~"__'_"___.,,__._._ ".__n____..._._,. u,,_.~_._. ... ..._.,_,_.._. ,,,...,... _0" .,.-._.. ~".. Rig PSI Messages r ~ ..211Io, ~ þ.-- " sattey meeting Start Job start CW 100 Stop Pumping Pressure Test lines Bleed Off Pressure CONT. CW 100 Reset Total, Vol = 49.38 bbl Start MudPush Reset Total, Vol = 44.87 bbl Start Lead cmt Slurry temp 65 degrees Reset Total, Vol = 381.29 bbl Start Tall cememt Shutdown fix leak In celler ~ ..... ~ ~ ( ~ ~ t Reset Total, Vol = 183.64 bbl 10 BBLS Water Turn over to rig pumps Reset Total, Vol = 7.00 bbl Stroke tot 2000 Increase Pump Rate Lead cmt coming up backside -Þ Tail cmt turning corner Red dye back at 5400 strokes Reduce pump rate Bumped at 6963 strokes Check floats Pressure up on stage tool Break circulation Safety meeting 05:25:53 ~ \ Fill lines ~ ~ l Pressure Test Lines I Bleed Off Pressure start CW 100 ! Reset Total, Vol = 19.63 bbl Start lead cmt Slurry temp 75 degrees , ¡-- 06:28:21 I Getting red dye In returns , ~ l - Reset Total, Vol = 500.22 bbl start tail slurry Start Pumping Water Start Displacement Stop Pumping Rig Pumps To Displace 07:30:50 Bump plug w/2067 strokes Bleed pressure off Rig down hh:mm:ss 2500 3333 4167 5000 0.0 1.7 3.3 5,0 6.7 10.0 15 25 833 1667 2500 3333 ~167 5000 12/181200207:30:50 PSI ---- BIM LB/G PSI .---,--- 1-2f18/~G2-~:4ï ) ) ScbluDlbøpglr Customer Cementing Service Report Job Number Well ConocoPhillips Alaska Ine, Location (legal) 1C 22 ..----,._-~_._-_._.__._-~-~--~'.__._-,.._._----,._-_...-...---.-.----- Field Formation NamelType KUPARUK County State/Province ~-"-------~--~"-"-"--------~'-~ .-...--......_._----..-._._-~ Schlumberger Location 2201044867 Job Start Deviation Prudhoe Bay, AK Bit Size Well MD 2002-Dec-17 Well TVD BHP in 9,452 ft 7,500 ft BHCT Pore Press. Gradient BHST __________._.,_____~_~.~~_~.~~_~~~!___,,_____.__._n_. ___.____,._.___.."_..__._._~~..,,. ".......__n__________.____.____. p~~ Well Master: 0630461651 API! UWI: Rig Name Drilled For Service Via Doyon 141 Oil Land Offshore Zone Well Class Well Type New Workover .. .~._-_....._,_._._.._._-_._-,., -"_._._._-_...~._._.,"---,--_.. ....-..-....-..- -,.-...,_._----..----- ----_.------ -,.-,.--.,..- .... ---..-- Drilling Fluid Type Bentonite Max. Density Plastic Vii cp 30 9.4 Ib/gal Service Line Job Type Cementing Cem Surface Casing Max. Allowed Tubing Pressure Max. Allowed Ann. Pressure WellHead Connection psi psi Double cement hea Service Instructions Job allocation $ 80,500.00 Material cost $ 101,397.02 Total job cost $ 181,897.02 CasinglTubing Secured ~ Lift Pressure: 5196 psi Pipe Rotated 0 47 Top rlUgs: Double 1 Hole Volume Circulated prior to Cementing ~ 2 Pipe Reciprocated~ ¡Bottom Plugs: 0 No. Centralizers: Cement Head Type: Job Scheduled For: Arrived on Location: Leave Location: 2002-Dec-17 14:00 2002-Dec-18 9:00 Depth, ft 91°F 65 OF psi/ft .Cas~rijiLin¡,.T---·--"---'"'-..-..---....----·--·'"'--··· Size, in Weight, IbItt Grade Thread 9452 9.625 40 L80 BTC .---.----..-- ._-~..__._..__. Depth, ___,,~_JMþ~91º"U¡I~iPe·..· Size, in Weight, Ibltt Thread Grade :,.Pt~~~n:~lg~~,~~~ Top, ft Bottom, ft spf No. of Shots Total Interval ft Diameter Treat Down in Packer Depth Displacement Packer Type Casing Tubing Vol. bbl ft OpenHole Vol Casing Vol. Annular Vol. bbl 716 bbl Casing Tools Shoe Type: Float Shoe Depth: 9473 ft Stage Tool Type: Stage Tool Depth: Collar Type: Collar Depth: 527 bbl Squeeze Job Squeeze Type Tool Type: Tool Depth: Tail Pipe Size: Tail Pipe Depth: Sqz Total Vol: bbl ft in ft bbl 2888 ft Float 9390 ft 2002-Dec-17 22:09 260 8.28 1.8 0.8 301 0 0 saftey meeting 2002-Dec-17 22:09 274 8.28 1.8 0.9 274 0 0 Start Job 2002-Dec-17 22:10 301 8.28 2.2 1.6 1020 0 0 start CW 1 00 2002-Dec-17 22:11 265 8.28 0.0 5.1 649 0 0 Stop Pumping 2002-Dec-17 22:11 210 8.28 0.0 5.1 347 0 0 Pressure Test Lines 2002-Dec-17 22:13 3455 8.29 0.0 5.1 2860 0 0 Bleed Off Pressure 2002-Dec-17 22:14 155 8.29 0.0 5.1 137 0 0 CONT. CW 100 2002-Dec-17 22:25 205 8.16 0.0 50.2 187 0 0 Reset Total, Vol = 49.38 bbl 2002-Dec-17 22:26 278 10.69 0.0 0.0 205 0 0 Start MudPush 2002-Dec-17 22:45 297 10.60 1.8 45.0 196 0 0 Reset Total, Vol = 44.87 bbl 2002-Dec-17 22:45 347 11.46 2.8 0.5 219 0 0 Start Lead cmt 2002-Dec-17 23:09 617 10.72 7.3 174.1 173 0 0 Slurry temp 65 degrees 2002-Dec-17 23:38 553 10.59 7.2 382.1 63 0 0 Reset Total, Vol = 381.29 bbl 2002-Dec-17 23:39 553 10.66 7.3 2.3 104 0 0 Start Tail cememt 2002-Dec-17 23:44 178 12.53 0.0 13.5 -33 0 0 Shutdown fix leak in celler 2002-Dec-18 0:26 127 8.63 3.6 185.6 22 0 0 Reset Total, Vol = 183.64 bbl 2002-Dec-18 0:27 146 8.31 5.1 2.2 36 0 0 10 BBLS Water 2002-Dec-18 0:30 127 8.28 0.0 10.3 219 0 0 Turn over tò rig pumps 2002-Dec-18 0:30 127 8.28 0.0 10.3 223 0 0 Reset Total, Vol = 10.3 bbl 2002-Dec-18 0:56 146 8.23 0.0 0.0 210 0 0 Stroke tot 2000 2002-Dec-18 1:00 146 8.26 0.0 0.0 352 0 0 Increase Pump Rate 2002-Dec-18 1:03 178 8.22 0.0 q.Q ~~~ 0 0 Lead cmt coming up backside Dee 1 ~,2qq? WRS3 v3.~p2-SR Page 1 of 2 ) ') " -'---'-'-~.,~-,...._~""._.~. ._.,.,~,--~._,-".,"_.~ -.'--.'.~-"-.---.~----...-"".-."--"_._-~--.---.-....'..."..,--_.........,_...." ,,_..'_.._~,-."_._--'._-._------------_.,,_._"- ._-..__.'-,---_._-,,~,.,,~_._.~-~.~----.---~....'-----_..-_.._.-_....__._-_..,,-,,---_.,,_.._-~.._-----_._._...__.~,.-.--.......- Well Field Service Date Customer 1C #22 "---oãtë------'-Tlme ' CMT TREAT PRES KUPARUK 02351-Dec-17 ConocoPhillips Alaska Inc. Job Number 2201044867 ------.---'----.- CMTDENS MM RATE MM VOLUME -'WHP ·--------ò------~---_·_-ö-·,-_·_--'----·-- Message 24hr clock psi Iblg.1 bbVmh'l bbl psi o o 2002-Dec-18 1 :38 100 -0.00 0.0 0.0 713 0 0 Tail cmt turning corner _..,.___,. _.______________.,___,____~___..___ _".___ ·_.____n____.__.__ .___.._________...'___~.,_,__._.._....__.~ 2002-0ec-18 1 :41 95 -0.00 0.0 0.0 754 0 0 Pumping --.-,---..---..--- 2002-0ec-18 1 :57 100 -0.00 0.0 0.0 736 0 0 Reduce pump rate 2002-0ec-18 2:07 100 -0.00 0.0 0.0 1276 0 0 Bumped at 6963 strokes 2002-Dec-18 2:08 100 -0.00 0.0 0.0 567 0 0 Check floats _~E~_~~:.~,~.~~.,__~~_.__,"__~~,______~·O~.___. _'"_'"~:"~__ ,_." ___.~~__,_ "' _"__",_...1~~~__.,_." _______~____,_,_.__._~,_"_,__Pressure up_~~.!!~!!~_~~~!_"..___,___ 2002-Dec-18 2:15 100 -0.00 0.0 0.0 150 0 0 Break circulation 2002-Dec-18 4:24 104 -0.00 _____~~___ 0.0 278 0 0 Safety meeting __________.________"', 2002-Dec-18 5:24 109 8.26 0.0 0.0 45 0 0 Fill lines -.---,-- 2002-0ec-18 5:28 4055 8.28 0.0 5.0 3176 0 0 Pressure Test Lines 2002-Dec-1a' 5:28 4046 8.28 0.0 5.0 3176 0 0 Bleed Off Pressure 2002-Dec-18 5:29 168 8.28 0.9 5.2 86 0 0 start CW 100 2002-0ec-18 5:35 146 10.46 0.0 20.1 54 0 0 ResetTotal,Vol=19.63 bbl 2002-Dec-18 5:35 274 10.63 4.4 1.1 146 0 0 Start lead cmt -~-----'.'-_.-__..'.._~_'.__....._ __..~.._.~..._".,_...._.._. ,_,,_,_._.._._._.._.,_~,_.. .._..._..._._.__.~"_~.~._.,..__._ ,..______,,, ,. ~...~,,__._. .,.._...... ·._n.·_·....._......_..... ._-.~" .._..~.,,_.__'._.. .. _,... _...,_._ ..._,_._~._,,_._ _.________ø..._,. ..__.~,._...__....__,._.._,.__ _.___.... __. 2002-Dec-18 5:41 471 10.70 7.1 33.3 201 0 0 Slurry temp 75 degrees 2002-0ec-18 6:31 558 10.72 7.4 404.2 274 0 0 Getting red dye in returns 2002-Dec-18 6:44 292 11.52 3.7 502.3 155 0 0 ResetTotal,Vol=500.22 bbl 2002-Dec-186:45 200 14.62 1.1 2.5 114 0 0 start tail slurry 2002-0ec-18 6:52 562 9.47 4.6 13.0 315 0 0 Drop top plug /10 bbls water 2002-0ec-18 6:52 471 8.38 6.4 14.9 265 0 0 Start Displacement 2002-0ec-18 6:54 150 8.31 0.0 22.4 77 0 0 Stop Pumping 2002-0ec-18 6:54 150 8.31 0.0 22.4 72 0 0 Rig Pumps To Displace 2002-Dec-18 7:28 155 8.25 0.0 22.4 1665 0 0 Bump plug w/2067 strokes 2002-Dec-18 7:30 118 8.20 0.0 22.4 571 0 0 Bleed pressure off 2002-Dec-18 7:30 118 8.25 0.0 22.4 223 0 0 Rig down Slurry Average Pump Rates, N2 Mud bpm Maximum Rate Total Slurry Volume of Fluid Injected, bbl Mud Spacer N2 6 I I 7.5 Treating Pressure Summary, psi Final Average Bump Plug to Breakdown I Breakdown Fluid Volume Density Maximum 1670 1665 2800 L bblL Ib/gal 200 bbl % 1061 bbl bbl 75 of ~ Cement Circulated to Suñace? Volume o Washed Thru Peñs To ft Avg. N2 Percent Designed Slurry Volume Displacement Mix Water Temp Customer or Authorized Representative Schlumberger Supervisor Wester, Don Richard Gallegos o CirculationLost ~ Job Completed Dee 18,2002 WRS3 v3.302-SR Page 2 of 2 I Fluid No : pak surl293 Company : Phillips Well Data Job Type BHST Starting Temperature Starting Pressure Composition Code Dry phase contents G D079 S001 D046 D065 D124(0.69) D053 Wet phase contents Fresh water D044 I Slurry Density Base Fluid Conc. Rheology Fann Readings (rpm) 300 200 100 60 30 6 3 10 sec 1 min 10 min Thickening Time Consistency 70 Be POD: Batch Mix Time: Casing 80 degF 80 degF 315 psi ') Requested by : Rick G Well Name : 1C-22 Depth BHCT Time to Temperature Time to Pressure Lot Number Cone. 1.500 %BWOC 1.500 %BWOC 0.600 %BWOC 0.500 %BWOC 43.100 %BWOC 30.000 %BWOC 9.000 %BWOW 10.70Ib/gal Porosity 19.386 gaVsk Mix Fluid At 70 degF I ( deg) 19 14 10 8 6 5 4 Pv : 14.145 cP Ty : 4.87 Ibf/100ft2 Time 06:00 hr:mn at ) Schlumberger Cement Test Report ASL Location : Doyon 141 Field : Kuparuk 112/17/02 FIELD BLEND 9452.0 ft 80 degF 00:19 hr:mn 00:19 hr:mn TVD BHP Heating Rate 2600.0 ft 1530 psi' -0.00 degF/min 62.3% 19.934 gaVsk Yield 4.28 ft3/sk At 80 degF I (deg) 32 25 17 15 12 8· 7 pv : 22.120 cp Ty: 10.06 Ibf/100ft2 ,,\,é, ",.,'.",. ) ,.- ¡::, ~PH~HM~'"'~~ ~~~~r~ ;~N"'~~NT'AL , ' ': 1",' . . I Fluid No : pak surt294 Company: bp Well Data Job Type BHST Starting Temperature Starting Pressure Composition Code Dry phase contents CEMPlus Blend D079 D046 D065 I Wet phase contents Fresh water I Slurry Density Base Fluid Conc. Rheolo,gy Fann Readings (rpm) 300 200 100 60 30 6 3 10 see 1 min 10 min Thickening Time Consistency 30 Bc 70 Bc 1 00 Be POD: Batch Mix Time: Plug 80 degF 80 degF 315 psi 12.00Ib/gal 7.445 gallsk ) Requested by : Rick G Well Name : 1 C-22 Depth BHCT Time to Temperature Time to Pressure Lot Number Cone. 0.450 %BWOC 0.600 %BWOC 1.000 %BWOC Porosity Mix Fluid At 70 degF / (deg) 140 103 71 57 53 22 20 pv : 99.109 cP Ty : 39.33 Ibf/1 00ft2 Time 03:27 hr:mn 03:49 hr:mn 04:24 hr:mn at ) Schlumberger Cement Test Report Location : Doyon 141 Field : Kuparuk 112/17/02 FIELD BLEND 9452.0 ft 80 degF 00:19 hr:mn 00:19 hr:mn TVD BHP Heating Rate 2600.0 ft 1530 psi -0.00 degF/min 100.0 % 7.445 gallsk Yield 2.24 ft3/sk At 80 degF / (deg) 143 105 65 49 38 22 20 pv : 117.329 cP Ty: 26.04 IbY100ft2 SCHLUMBERGER DOWELL CONFIDENTIAL I Fluid No : pak surt295 Company : Phillips Well Data Job Type BHST Starting Temperature Starting Pressure Composition Code Dry phase contents Arcticset I D013 I Wet phase contents Fresh water I Slurry Density Base Fluid Cone. Rheology Fann Readings (rpm) 300 200 100 60 30 6 3 10 see 1 min 10min Thickening Time Consistency 100 Be POD: Batch Mix Time: ) ) SchlulDberger Cement Test Report fI~¿IIC Jé.·r r Requested by : Rick G Well Name : 1 C-22 112/1.7/02 FIELD BLEND Location : Doyon 141 Field : Kuparuk Casing 80 degF 80 degF 315 psi Depth BHCT Time to Temperature Time to Pressure 2600.0 ft 1530 psi 9452.0 ft 80 degF 00:19 hr:mn 00:19 hr:mn TVD BHP Heating Rate Lot Number Cone. 0.150 %BWOC 15.70Ib/gal Porosity 51.1 % Yield 0.93 ft3/sk 3.550 gallsk Mix Fluid 3.550 gallsk At 70 degF / At 80 degF / (de g) ( deg) 77 107 56 75 30 40 20 27 13 16 8 8 6 6 . Pv : 72.126 cP Ty : 6.11 Ibf/100ft2 Pv : 1 01.801 eP Ty : 6.15 Ibf/100ft2 Time 04:35 hr:mn ..' at Doyon 141 ) ) Page 1 of 2 ~. ¢J ~ ~ ConocòPt,illips ConocoPhillips Alaska Daily Drillin2 Report Well Sidetrack AFE 24 H rs TMD TVD DFS REPT NO. DATE ProQ 1C-22 1C-22 10027561 0' 9,481' 4,514' 11 12 12/17/02 Supervisor Fred Herbert / Proposed TMD Dearl Gladdden 14,536' Pressure Test(s) Rig Name Doyon 141 Field Name t),ª,Uy,.,çQ.$,t. $167,154 Type I Date I TMD I TVD I MW I Press I Tot. press I EMW $1,753,111 110'10'10 ppg I 0 psi I 0.00 psi 10.00 ppg Kuparuk River Cumulative Cost Current Status Event Code 24 HR Forecast CMT 9.625' Last Safety Csg - Pumping Meeting Stage 2 OOR Incident 1st 24 hrs? No 12/16/02 BOP Tst (Last I Next) Rig Accept: 12/6/02@ 15:00 RiQ Release: @ : CMT 9.625' Surface Csg - N/D Oiverter -N/U BOPs Last Survey 12/15/02 TMD: INC: Azi m: 66.21 Last Casing 16 (in) @ 138 Next Casing 9,445 67.1 o (in) @ 0 ,º.p~.rª.ti.º.ns......s.º.m.m.ª.r.y. . . Time Start End From To Hours Phase Activity SubcodeClass Trouble Depth Depth Operation 00:0000:30 0.50 SURFAC CASE SFTY P 0' 0' Pre Job Safety Meeting Run 9.625' 40# L-80 csg to 00:3005:00 4.50 SURFAC CASE RUNC P 0' 3,000' ~~O~~ (~~g_r~~ ~)~ F~IIOW returns at all times. Circu BU X 2 -Very thick mud to surface - Stage pump stks up slowly to minimize ECOs - 05:0006:00 1.00 SURFAC CASE CIRC P 3,000' 3,000' Rate 6 BPM - ( Pre circu , Up wt 125 K, Dn wt 55 K, Post circu Up wt 120 K , Dn wt 75 K TIH w/ 9.625 csg to 3000' to 06:0009:30 3.50 SURFAC CASE RUNC P 3,000' 5,941' 5941' - Csg ran well - No tight hole - Full returns Circu BU - Thick mud to 09:3011:00 1.50 SURFAC CASE CIRC P 5,941' 5,941' surface - Stage pumps up slowly to 6 BPM Run 9.625' 40# L-80 csg to 11:0015:30 4.50 SURFAC CASE RUNC P 5,941' 9,473' 5941' to 9473' - Csg ran well - No tight hole - Full returns Bk Circu w/ Franks fill tool - 15:3016:30 1.00 SURFAC CASE CIRC P 9,473' 9,473' R/O Franks Tool - Blow dn TO - R/U CMT head Circu & Condition Mud per 16:3022:00 5.50 SURFAC CEMENT CIRC P 9,473' 9,473' well plan - Stage pump stks up slowly to 8 bpm - Recip http://bizak/drilling/cgi-bin/reports/daily .asp?rig=Doyon 141 12/18/2002 Doyon 141 ') ) Page 2 of2 csg 10-12' 22:0000:00 2.00 SURFAC CEMENT PUMP 24 Hr. Sum: 9,473' 0' Mud Data Mud 10sec / 10 FlowLine Drilling Company Type Density FV PV /YP min / 30 min WL/HTHPMBT PH Temp Solids Gels 0 0 0/0 0/0/0 0/0 0 0 0 0 ~ ,~ http://bizak/drilling/cgi-bin/reports/daily .asp?rig=Doyon 141 12/18/2002 PAl Daily Drilling ) " ) Page 1 of 2 ~ ¢ ~ Q .., ConocòPhillips ConocoPhillips Alaska Daily Drillin2 Report Well Sidetrack AFE 24 H rs TMD TVD DFS REPT NO. DATE ProQ lC-22 lC-22 10027561 0' 9,481' 4,514' 12 13 12/18/02 Supervisor Don Wester/ Proposed TMD Dearl Gladdden 14,536' Pressure Test(s) TIH w/ BHA Last Safety #5 Meeting 12/18/02 Type I Date I TMD I TVD I MW I Press I Tot. press I EMW 110'10'10 ppglO psilO.OO psilO.OO ppg BOP Tst (Last I Next) Rig Accept: 12/6/02@ 15:00 RiQ Release: @ : Rig Name Doyon 141 Field Name Current Status Event Code 24 HR Forecast Dª..Uy....Ç.Q$..t. $518,063 Kuparuk River Cumulative Cost $2,207,765 ODR Incident 1st 24 hrs? No TIH - DO Stg Tool - TIH to Pg Cat @ 9349' - Test Csg Last Survey 12/15/02 TMD: INC: Azim: 66.21 Last Casing 16 (in) @ 138 Next Casing 9,445 67.1 o (in) @ 0 .ºn~rª.ti.ºn$......S.\Un,Ulªry. . . Time Start End From To Hours Phase Activity Subcode Class Trouble Depth Depth Operation Can't Pump CMT Stage 1 , 175.5 bbls 12.0ppg Tail (440 sks)Drop Plug, pump 10 bbl tub washup water, Displace w/ Rig pumps @ 8 BPM - Slowed rate to 5 bpm @ 00:0002:00 2.00 SURFAC CEMENT PUMP P 9,473' 9 473,6700 stks for bump - Bump , plug w/ 6963 stks (Calic bump 6990 stks) @ 95% eff ( 27 stks early) Bump plug to 1350 psi (500 over bump psi) full returns for complete job, Recip csg 5800 stks into displ - CIP 02.05 AM 12/18/02 Check float (Held) - Pressure up to 2830 psi and sheared 02:0005:00 3.00 SURFAC CEMENT CIRC P 9,473' 9,473' stage tool open- Circu out CMT & Contaminated Mud ( 350 bbls total circu) 05:0007:20 2.33 SURFAC CEMENT . PUMP P 9,473' Pump Stage 2 Cmt - Pump 5 bbls CW100,test lines to 4000 psi, pump 15 bbls 2 888' CW100, 492 bbls(645 sks) , 10.7ppg Lead,12 bbls( 75 sks) 15.7ppg Tail Drop top plug, KO with 10 bbl tub wash up. Displace w/ Rig pumps @ 8 BPM , slow to 5 http://bizak/drilling/cgi-bin/reports/daily.asp?wellname= 1 C%2D22&reportdate= 12/18/02 12/20/2002 PAl Daily Drilling ) 07:2009:30 2.17 SURFAC CEMENT PULD P 2,888' 0' 09:3012:00 2.50 SURFAC WELLSR NUND P 0' 0' 12:00 13:00 1.00 SURFAC WELLSR NUND P 0' 0' 13:0016:00 3.00 SURFAC WELLSR NUND P 0' 0' 16:0021:00 5.00 SURFAC WELCTL BOPE P 0' 0' 21:0000:00 3.00 SURFAC WELCTL BOPE 0' Np EQIP 24 Hr. Run Csg - Cire & Condt - CMT Csg Sum: Date Injection Volume Destination Source 12/18/02 1C-22 2,820 1R-18 ) Page 2 of 2 BPM to bump plug. Pressure to 1800 to CLOSE stage tool CIP 07:30 AM 12/18/02 200 bbls CMT contalminated mud to surface. Had 70+ bbls 10.7 ppg CMT to surface. Bleed off - Stage tool closed. Full retuns thru complete job. RID Dowell - LID Landing Jt - LID C5g Equip N/D Diverter System N/U & Orient Csg Head - Test metal to metal seal & Csg head 1000 psi f/l0 min "ok" N/U BOPs - Install bails on TD Test BOPs & Choke Manif - Annular 250/3500 psi, All other equip 250/5000 psi.5 min each. AOGCC Rep Chuck Scheve witnessed test. ** Note** Top pipe VBRs failed, installed 5" DP rams (test ok), Door seal on blind rams (ODS) failed ,repaired (test ok),# 5 valve on choke 0' manif failed,Mechanic lubed,cycled and serviced valve,(test ok) ** Note** Because of these delays rig lost 3.00 hrs making repairs after failed test. Cumulative for 1R-18 = 75,047 Mud Data Mud D . 10sec / 10 Flowline Drilling Company T enslty FV PV /YP min / 30 min WL/HTHPMBT PH ype Gels Temp Solids Baroid Polymer 9.3 42 9/12 4/4/6 8.8/0 0.1 9 0 0.2 ~^ ^~ http://bizak/drilling/cgi-bin/reports/daily.asp?wellname= 1 C%2D22&reportdate= 12/18/02 12/20/2002 ,PAl Daily Drilling ) ) Page 1 of 2 r- ¢ ~ c) ~ " ConocoPhillips Alaska ConocÕÞhillips Daily Drillin2 Report Well Sidetrack Network 24 H rs TMD TVD DFS REPT NO. DATE Proq 1C-22 1C-22 10027561 0' 9,481' 4,514' 13 14 12/19/02 Supervisor Don Wester/ Proposed TMD Dearl Gladdden 14,536' Pressure Test(s) Drlg 8? hole @ Last Safety 9900' Meeting 12/19/02 Type I Date I TMD I TVD I MW I Press I Tot. press I EMW 110'10'10 ppglO psilO.OO psilO.OO ppg BOP Tst (Lastl Next) 12/18/02 112/25/02 Rig Accept: 12/6/02@ 15:00 Riq Release: @ : Rig Name Doyon 141 Field . Name Current Status Event Code 24 HR Forecast D.ª.Hy....,Ç,Q$..t. $122,119 Kuparuk River Cumulative Cost $2,329,884 ODR Incident 1st 24 hrs? No Drlg - Wiper Trip as needed - Drlg Last Survey 12/15/02 TMD: INC: Azi m: Last Casing Next Casing o (in) @ 0 9,445 67.1 66.21 16 (in) @ 138 14:3016:00 1.50 .º.p~rª.ti..ºn.~""S.ºmmª..ry. . . Time Start End Hours Phase Activity Subcode Class Trouble Depth Depth Operation Can't Test BOPs - Retest #5 0' valve on Choke manif after repair - Test 250/ 5000 psi (OK) 0' Pull Test Plug - Install wear bushing - LID test jt P/U BHA # 5 - P/U Motor (Mach 1XL AKO 1.2?), Bit, LWD, XO, Stab, MWD, 386' Initialize MWD,Orient. Hold Radiation source PJSM, Install sources. P/U XO, 3 NMDCs, XO, 2 stds HWDP - Pulse test MWD "OK" TIH to 2878' picking up 386' 2,878' singles (5" DP) from pipe shed. Tag CMT @ 2878' Test Csg to 2000 psi "OK" - C/O CMT - Drill stage tool per 2,878' 2 900' procedure in well plan, P 400 , gpm, 60 RPMs, 2-5 K WOB - Ream area 2878' to 2890' X 3 - ReTest Csg 2000 psi "OK" 2,900' 5,376' Can't TIH to 5376' - Fill DP 5,376' 5 376' Slip & Cut Drlg Line ( 85' cut) , - Serv Rig & Top Drive 5,376' 8,997' TIH from 5376' to 8997' BOPE P 0' From To 00:0000:30 0.50 SURFAC WELCTL 00:3001:00 0.50 SURFAC WELCTL BOPE P 0' 01:0005:00 4.00 PROD DRILL PULD P 0' 05:0007:00 2.00 PROD DRILL TRIP P 07:0010:00 3.00 PROD DRILL DRLG P 10:00 13:30 3.50 PROD DRILL TRIP P 13:3014:30 1.00 PROD RIGMNT RSRV P PROD DRILL TRIP P http://bizak/drilling/cgi-bin/reports/ daily .asp 1/6/2003 P AI Daily Drilling ) 16:0017:00 1.00 PROD DRILL CIRC P 8,997' 17:00 18:00 1.00 PROD CASE MIT P 8,997' ') Page 2 of2 20:3022:30 2.00 PROD DRILL DRLG P 9,185' 8 997' Clrcu & Condt - P 400 gpm, , 1500 psi R/U Test 9.625" Csg - Test to 8 997' 3500 psi fl 30 min - Chart for , AOGCC After 30 min loss 20 psi - R/D test lines PJSM - Held Stripping drill wI Edwards crew. Stripped in 2 stds DP. Hands each had a turn bleeding off 200 psi 9,185' working pressure w/ choke. Held Post safety meeting, all question from crew members were answered concerning Stripping procedure. Tag CMT @ 9346' - Drill baffell @ 9349', CMT, FC, FS & 20' new hole fl 9481' to 9 SOl' 9501' MD ( 4521' TVD) - , Used procedure from well plan to drill out all equip. P 450 gpm, 80 rpms , 2 - 5 K WOB Displace hole over to new 9 SOl' LSND mud per well plan. MW , 9.3 ppg, Vis 47, PV 10, YP 15, Gels 4/5/5 18:0020:30 2.50 PROD WELCTL SFTY P 8,997' 22:3000:00 1.50 PROD DRILL CIRC P 9,501' 24 Hr. Complete BOP Test - P/U BHA #5 - TIH - Drlg out ST- Test C5g - Drlg 20' - C/O New Mud Sum: Date Source Injection Volume Desti nation 12/19/02 lC-22 225 lR-18 Cumulative for lR-18 = 84, 170 Mud Data Mud 10sec / 10 Flowline Drilling Company Density FV PV /YP min / 30 min WL/HTHPMBT PH Type Gels Temp Solids Baroid LSND 9.3 47 10 / 15 4/5/5 6.8/0 0.1 10.1 0 0 Bits B"t/R S" M f T Serial Jets or TFA Depth D t I I-O-D-L-B-G- I un Ize anu. ype No. In a e n O-R 5/1 8.5 HYCA DS70FNPV 200347 /0.40625/0.40625/0.40625 9481' 12/19/02 2-3-~;~~~D-l- ~ -~ http://bizak/drilling/c gi -bin/reports/daily .asp 1/6/2003 'PAl Daily Drilling ,'\ '} Page 1 of 3 r- ConocòPhilUps Well Sidetrack lC-22 lC-22 ¢I ~ Q ConocoPhillips Alaska Daily Drillin2 Report Network 24 Hrs TMD TVD Proq 10027561 2,079' 11,560' 5,323' -, DFS 14 REPT NO. 15 DATE 12/20/02 Supervisor Don Wester/ Proposed TMD Dearl Gladdden 14,536' Pressure Test(s) Rig Name Doyon 141 Field Name Qª,Uv..mt..Q,$t $172,272 Type I Date I TMD I TVD I MW I Press I Tot. press I EMW FIT 112/20/0219473'14511'19.3 ppgl1560 $2,502,156 psI13,739.34 ps1115.96 ppg BOP Tst (Last I Next) 12/18/02 112/25/02 Rig Accept: 12/6/02@ 15:00 Riq Release: @ : 12/20/02 Kuparuk River Cumulative Cost Current Status Event Code 24 HR Forecast Dlr Drlg 8?" Last Safety hole @ 12034' Meeting MD ODR Incident 1st 24 hrs? No Drlg - Wiper Trip 12,500 - 12,700 - TOH - C/O LWD Last Survey 12/20/02 TMD: INC: Azim: Last Casing Next Casing 11,416 66.42 64.79 9.625 (in) @ 9473 7 (in) @ 14536 01:3012:00 10.50 PROD Operations Summary . . Time Start End Hours Phase Activity Subcode Class Trouble Depth Depth Operation Can't C/O mud to New LSND 9,501' 9 SOl' system, 9.3ppg, Vis 47, PV , 10, YP 15, Gels 4/5/5 - C/O rate 10 bpm, 80 RPMs Pull to shoe - Preform LOT per GKA procedure. Calcu 16.0 EMW 9.3 ppg , 9473' MD, 4511' TVD = 1572 psi @ Surface - Pump rate 8 spm , 9,501' 9 SOl' @ 50 stks in,1560 psi had , leak off, Continued to pump 3 bbls per procedure to 82 stks/ 1240psi, shut down pumps, held for 10 min, final PSI 720 psi. Fill out LOT/FIT test sheet EMW = 14.7 ppg Dir Drlg & Slide 9501' to 10,400' MD ( 4869' TVD) ART 6.0 hrs, AST 0.0 hrs , PP 2100 psi, Rate 546 gpm, WOB 8-13 K, RPMs 100. Up 9,501' 10,400'wt 173 K, Dn wt 112 K, Rot wt 134 K, Trq on bttm 13-14 K ft/lbs, off bttm 13-14 K ft/lbs ***NOTE** @ 10,018' all LWD signal. Directional tools still working DRILL CIRC P From To 00:0000:30 0.50 PROD 00:3001:30 1.00 PROD DRILL LOT P DRILL DRLG P http://bizak/drilling/cgi-bin/reports/daily.asp?wellname= 1 C% 2D22&reportdate= 12/20/02 1/6/2003 'PAl Daily Drilling ) ) Page 2 of 3 properly.After conferring with well engr & stepup TL it was decided to drill ahead to 13,000' MD MAX, @ that time or before if needed Rig will TOH and replace LWD tools. Dir Drlg & Slide 10,400' to 11560' MD ( 5323' TVD) ART 6.2 hrs, AST 2.0 hrs - PP 12:00 0.00 PROD DRILL DRLG P 10 400' 11 560' 2500psi, Rate 546 gpm, WOB , , 10-15 K, RPMs 100, Up wt 185, Dn wt 110 K, Rot 130 K, Trq on bttm 17 K ft/lbs, off bttm 17 K ft/lbs 24 Hr. Preform LOT - Dir Drlg & Slide Sum: Surveys MD Incl. Azimuth TVD N/S Cum E/W Cum V. DogLeg Build Section Deg/100' 9,567.74 67.49 66.56 4,546.81 3,096.77 7,230.81 7866.04 0.41 0.32 9,649.63 67.46 66.36 4,578.18 3,126.98 7,300.16 7941.68 0.23 -0.04 9,742.05 67.5 67.67 4,613.58 3,160.31 7,378.75 8027.05 1.31 0.04 9,835.40 67.48 66.26 4,649.32 3,194.06 7,458.11 8113.29 1.4 -0.02 9,928.78 67.35 66.3 4,685.18 3,228.74 7,537.05 8199.5 0.14 -0.14 10,021.33 67.33 67.12 4,720.84 3,262.51 7,615.49 8284.91 0.82 -0.02 10,113.34 67.36 65.2 4,756.28 3,296.82 7,693.16 8369.81 1.93 0.03 10,206.30 66.98 67.01 4,792.35 3,331.53 7,771.48 8455.47 1.84 -0.41 10,300.61 66.91 65.69 4,829.29 3,366.34 7,850.97 8542.25 1.29 -0.07 10,393.96 66.62 68.2 4,866.12 3,399.93 7,929.89 8628.02 2.49 -0.31 10,487.43 66.51 70.34 4,903.30 3,430.28 8,010.09 8713.69 2.1 -0.12 10,580.76 66.29 69.61 4,940.66 3,459.57 8,090.44 8799.08 0.75 -0.24 10,673.50 66.95 68.51 4,977.47 3,489.99 8,169.95 8884.14 1.3 0.71 10,766.29 67.71 67.79 5,013.23 3,521.86 8,249.41 8969.73 1.09 0.82 10,859.45 67.56 67.3 5,048.68 3,554.77 8,329.03 9055.87 0.51 -0.16 10,951.44 67.48 67.67 5,083.85 3,587.31 8,407.55 9140.87 0.38 -0.09 11,043.84 67.4 68.1 5,119.30 3,619.44 8,486.61 9226.18 0.44 -0.09 11,136.47 67.09 69.3 5,155.13 3,650.47 8,566.19 9311.55 1.24 -0.33 11,229.84 66.86 67.89 5,191.65 3,681.83 8,646.19 9397.44 1.41 -0.25 11,323.12 66.91 66.49 5,228.27 3,715.08 8,725.27 9483.22 1.38 0.05 11,416.21 66.42 64.79 5,265.15 3,750.34 8,803.13 9568.68 1.76 -0.53 Date Source Injection Volume Destination 12/20/02 lC-22 1,160 lR-18 Cumulative for lR-18 = 84,170 Mud Company T Density FV ype Mud Data 10sec / 10 PV /YP min / 30 min Gels WL/HTHP MBT PH Flowline Drilling Temp Solids Baroid Non- Disp. LS o o 0/0 0/0/0 0/0 o o o o Bits http://bizak/drilling/cgi-bin/reports/daily.asp?wellname= 1 C%2D22&reportdate= 12/20/02 1/6/2003 -PAl Daily Drilling ') ) Page 3 of 3 Bit/Run Size Manuf. Type Serial Jets or TFA Depth Date In I-O-D-L-B-G- No. In Q-R 5/1 8.5 HYCA DS70FNPV 200347 /0.40625/0.40625/0.40625 9481' 12/19/02 2-3-~T~~~;D-1- ~ ~ http://bizak/ drilling/c gi -bin/reports/daily. asp ?wellname= 1 C % 2D22&reportdate= 12/20/02 1/6/2003 PRESSURE INTEGRITY TEST PHILLIPS Alaska, Inc. Well Name: 1 C-22 I Rig: Doyon 141 I Date: 12/19/2002 Drilling Supervisor: Don Wester I Dearl Gladden I Pump used: I #1 Mud Pump Type of Test: I Casing Shoe Test LOT/FIT ....1 Pumping down I drillpipe. Hole Size: i 8-1/2" · Casing Shoe Depth I Hole Depth RKB-CHF: 24.9 Ft 9,473 Ft-MD 4,511 Ft-TVD 9,501 Ft-MD 4,521 Ft-TVD Casin~ Size and Description: USE PICK LIST ...1 Casin~ Test Pressure Inte~rityTest Mud Weight: 9.5 ppg Mud Weight: 9.3 ppg Mud 10 min Gel; 5.0 Lb/100 Ft2 Mud 10 min Gel: 5.0 Lb/100 Ft2 Test Pressure: 3,500 psi Rotating Weight: 125 Lbs Rotating Weight: 125 Lbs BlockslTop Drive Weight: 34 Lbs BlockslTop Drive Weight: 34 Lbs Desired PIT EMW: 16.0 ppg Estimates for Test: 0 bbls Estimates for Test: 1572 psi 1·1 L ~ EMW = Leak-off Pressure + Mud Weight = 1260 0.052 x TVD 0.052 x 4511 + 9.3 EMW at 9473 Ft-MD (4511 Ft- TVD) = 14.7 ppg Comments: !~:,i !:', /, lJ!IC ~,', ~ I T' ' I I 4 5 Barrels 6 8 9 ___LEAK-OFF TEST o bbls PIT 15 Second Shut-in Pressure, psi Fill in FIT Columns ==> f Lost 10 psi during test, held 99.7% of test pressure. .... .u~ I I ~ ! ¡ , r i r I &.";:, i ; t"$' I I ~ I ! ~~ I I : r 10 o 5 10 1 5 20 25 30 Shut-In time, Minutes o PIT Point I Volume Input Pump Rate: 8.0 Strk/min 1- ... 0.1 000 Bbls/Strk ... Pressure Integrity Test !. Casing Test Pumping Bbls psi o 40 0.4 190 0.8 340 1.2 490 1 .6 640 2 790 2.4 940 2.8 1090 3.2 1240 3.6 1390 4 1 540 4.4 1690 4.8 1840 5.2 1990 5.6 2140 6 2290 6.4 2440 6.8 2590 7.2 2740 7.6 2890 8 3040 8.4 3190 8.8 3340 9.2 3490 9.4 3580 . 4000 - 3500 - 3000 - L.LJ 2500 ,;. a::: ::::J U') 2000· U') L.LJ a:: a.. 1 500 - 1000· 500· 0 0 2 ~CASING TEST Pumped 9.4 tsbls ;... Shut-in Pumping Shut-in Min psi Bbls psi Min psi 0 3580 0 60 0 1180 1 3580 0.4 190 0.25 2 3580 0.6 270 0.5 3 3575 0.8 340 11 4 3575 1 410 1.5 --/ 5 3575 1.2 490 2 6 3575 1.4 560 2.5 7 3575 1.6 640 3 8 3570 1.8 710 3.5 9 3570 2 780 4 10 3570 2.4 910 4.5 15 3570 2.8 1020 5 20 3570 3.2 1140 5.5 25 3570 3.6 1260 6 30 3570 4 1370 6.5 4.4 1480 7 4.8 1550 7.5 5 1560 8 5.4 1490 8.5 5.8 1350 91 6.2 1270 9.51 6.6 1250 10 7 1240 "--,,J 7.4 1240 7.8 1240 8.2 1235 Volume Bled Back 8.6 tsbls Volume Bled Back 2.3 tsbls ) ) CASING DETAIL KUPARUK INJECTOR WELL:Test Well DATE: 12/25/02 1 OF 1 PAGES LENGTH DEPTH TOPS ConocoPhilliDS # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN 3-344 Doyon RiQ 141 Rotary Table to LandinQ rinQ 7" HanQer 7" ,26#, L-80, BTC-M CSQ 7" Float Collar 7" ,26#, L-80, BTC-M CSQ 7" Float Shoe 26.00 2.02 14497.14 1.30 81.51 1.46 26.00 28.02 14525.16 14526.46 14607.97 14609.43 14620.00 1-2 Jts 10' of RAT HOLE Shoe TOTAL DEPTH 8.5" HOLE Centralizers Install one 8 1/2" X 7" BowsprinQ centralizer in the middle of the first 5 joints on stop rinQs, Then 2 8 1/2" X 7" BowsprinQ centralizer I on the Next 10 joints w/ stop rinQ in middle of joint and float centralizer Then back to 1 81/2" X 7" BowsprinQ centralizer in the middle of the next 5 joint on stop rinQs in the middle of joint. CenterinQ Guides Run one 7" X 8 3/8" CenterinQ Quide joints #2, 4, 5, 6, & 7 Run one 7" X 8 3/8" CenterinQ Quide every third joint from surface down 500' Joints # 330, 333, 336, 339 & 342 Remarks: String weight up 290K Down weight 90K, Block 35K . Ran 344 joints of casing. Drifted casing and hanger with 6.151" platic rabbit. Used Arctic grade API Mondified No Lead thread compound on all connections. Doyon 141 Drilling Supervisor: Don Wester / Dear! G!anden ) ) Schlumb¡BPgør Cementing Service Report Customer Job Nurnber 1C 22 CbnócoPhillip$Alas~a Inc. Location (legal) Schlumberger Location 2201044872 Job Start Well Field Formation Name/Type -~._-,---_._._------,--_._._.._-,_._-._----,_.----- KUPARUK -~_._---- -'---'-"'---'-'~"--'-"-""--'--"--'-"-----'-- County State/Province Beechey Point Well Master: 0630461651 API/UWI: "----...---".-----.--.---.---.,. Rig Name Drilled For Doyon 141 Injection Land 14609 7 26 L-80 BTC _."_____.___..___.___.___.,_.____________._.__.__ ____....,.____..,_'.__._.____.....,.___._.___..__.__.____._....,__._____.___n_...__.,._._..__..,______,______.__.____.._ ,.__..,_.__..___.___.____.._....___._.,_._._ _u,__________. Offshore Zone Well Class Well Type Tubing/Drill Pipe Size, In Weight, Ibltt Grade AK Service Via ----_._---,----~. Deviation Prudhoe Bay, AK Bit Size Well MD 2002-Dec-26 Well TVD BHP in 14,609 ft 6,822 ft -----.---.-.......-------------.-.--.-----..-....------------,-_._--- BHST BHCT Pore Press. Gradient psi 155 of 80 OF psi/ft ------ ,.._.__.__.____..__.__.____ç~~~'l~!E!~~L_.. __.,_..._._"_....._.____.____.. Depth, ft Size, In Weight, Ibltt Grade Thread .___.__._.__._._____~,_.__._._..,__.___w___ ------ ---- ----'- ----- -~._------------_.- ..-.---. -- Drilling Fluid Type Polymer _"_w_..·_____·,·"·_____,__ _..._ Service Line New Development Max. Density Plastic VI: Cp 121b/gal 19 ----,,-_..-.-.----_.__.. Depth, Thread Job Type __.._.__.__._..__..____.__.__. ._.___.__..._ ___,._~__..____.___.__w·_.·_ _,_~._____._____~_ _..______...~____._______._._"__.. 'w__.__.____.__ ___.. -------------------- ----.-----.- -------- Cem Prod Casing Peñorations/Open Hole _ ..._ _ ___ _ _.______ ,_.__ ~_ w_ _._ _ .__ ___.__ ._._ d _ .w . . __. _.___ __ _..._. "...w._n_ _ _. .___ ___W'___.'u. __ .__._ . ____._ ._._... _. .. __._.._.. ___ . ___.. __, _ ..n_ "_. ._. Max. Allowed Ann. Pressure WellHead Connection Top, ft Bottom, ft spf No. of Shots Total Interval Cementing __ ___ _ _._.___. _.._.___.____ _w.w_.__. Max. Allowed Tubing Pressure psi psi _______...__._____,.__...._____. .____~_ _...__.w____._~_______...~.______ Service Instructions Job allocation $ 80,500.00 Material cost $ 11,730.34 Total job cost $ 92,230.34 Double cement hea --..---..--------...-.---.----- ._"- ------.--..-.---.- -----...-----.---.. ft ._u____._ ~_.___.~_.__..__ ____._._____.__ _._.....__.__._._....,_.__.___.._._,~_____._.__~ .__...___~.__.__.____ Casing/Tubing Secured ~ Lift Pressure: psi 1 Hole Volume Circulated prior to Cementing ~ bbl 559.5 bbl Casing Tools Shoe Type: Float Shoe Depth: 14609 ft Stage Tool Type: -- --.-------.--.----.- Stage Tool Depth: ft "". ,_.._._.._".._--~_..- --,-,-'"_..'"-_..~_..~_.~..-. Collar Type: Float -.-------_...- ._--_._..._-~ -.-,..--..---..---.----.- 2002-Dec-26 20:30 Collar Depth: 14524 ft WHP 0 Pipe Rotated D Pipe Reclprocated~ No. Centralizers: Top tlUgs: 1 JBottom Plugs: -,.---.....-.------,.---.----.-----.-------.--.-.------ -,---..-.-.---------- Cement Head Type: Double -_._..-._,_._._.~_.-._--_._. -.- ..--- - ---_._.._..__...._,_....~.__._-------. _.~--- Job Scheduled For: Arrived on Location: 2002-Dec-26 12:30 --- -----..--..-------.- Leave Location: Date Time Treating Flow Räte Density Volume Pressure 24hr clock psi bbllmln Ib/gal bbl ..._._-~.__._.._. . -..-.--..---.---- 2002-Dec-26 17:22 109 0.0 8.30 0.0 123 0 0 ..w________.._,_______. ______ ___~__.__.~__.._"._,._.._.__.___ _...._._ _'w_·._.._______~_.,___·._,_,______.._·_._______·_._·_-___ _.______.___~_._" ._~_."._,..._._""...____.._ .______. -__,______. __'''__'_''_ ,.___.~ 2002-Dec-26 17:23 2002-Dec-26 17:23 2002-Dec-26 17:23 2002-Dec-26 17:24 2002-Dec-26 17:25 2002-Dec-26 17:26 2002-Dec-26 17:27 2002-Dec-26 17:27 498 3.0 8.30 2002-Dec-26 17:27 512 i 3.3 8.30 2002=-6eë~26- -17-:28--- 649---r '-¡~----··_·_-8.30 =~~~ec-2~~~~~==_-~~-!__,J,___~_~,_ 8.30 2002-Dec-26 17:30 I "'20Ò2-=Dec-26 17:30 --297'---1' 0.0 2002-Dec-26 17:30 4375 0.0 2002-Dec-26 17:31 2002-Dec-26 17:31 4078 0.0 8.31 10.1 3959 0 0 __..____..______._._ - ________ ._____..._..____,___..__._______._ ._._~._.______.~___...__._.____. ___n._.___.·~______ _____..__,____~._..__. _,____~.____.____.._._____.._______ __.~_._____ ___ ___ ____.__..__ _3~~~~~~:~6_ ,!?~~_~ __~~____.L_,_~~__~_~~n__L_~~~__,_____!~~__ __.___~,__, _ ,_~___,_ __,____________._ 2002-Dec-26 17:32 _____._'__w _,___ 2002-Dec-26 17:32 205 0.0 8.31 10.1 _~ - - - ____.____.._"" . - _.__.__._._..___n _.....____.. _~~O~-D_~_~~3~__~!~~3..,,_,_E3!_~,_:__._.~..!__,___.~~3~_ :,____ _12.7 _~~O_2~g~~.:~6_,~!~33___, ,__!~_~_._. ,__, _~:.~.____,_,~·_~_1..._L'__m1?,~ ,____.____ 109 109 109 118 466 0.0 0.0 0.0 0.0 3.1 Dec29,2002 WRS3 v3.302-SR 8.30 8.30 8.30 8.30 8.30 0.0 0.0 0.0 0.0 1.4 psi 123 123 123 40 324 Diameter ...·,..._..__.._._.___._._,__.,,__W_~_._____. _.._._.,..__...______._ Treat Down in Packer Depth Displacement Packer Type Casing Tubing Vol. 556 bbl ft Casing Vol. Annular Vol. Open Hole Vol 517 bbl Squeeze Job Squeeze Type Tool Type: Tool Depth: Tall Pipe Size: bbl ft in ,. .....- _. -.--..."'--..--.--...--......--.--.,,- Tall Pipe Depth: ft bbl ..-.--.... _.~._- ....--------.-.---- Sqz Total Vol: Message o o ---~----_._------ Safety meeting 0 0 0 0 0 0 0 0 0 0 start CW100 3.6 356 0 0 4.4 365 0 0 -------"--.-.-. ---.----.---. -.----..--..-.----- --.----.--- .-.---..-.---..------ ----------, ---~ 8.5 507 0 0 _._..._--------_.~._._------_. 10.1 214 0 0 8.30 8.31 10.1 10.1 -.---- - ---------- 214 4261 132 439 -.----.. _._--.---- 503 ---.----.- Pressure Test Lines n___.___.._. __________~.__.______._.____,,__ -----.---.---.- -.--- ----- o o o o Bleed Off Pressure cont. CW100 o o o o - '--...-.- -----.--.--.- ._,-_._---- o ....-,---.--. -..-.--.-.- o -'~_. -_.._._---,_._~...- - -. .-------.-.---- -.-..- ---''''~'- ._~._---_._-_...__._.._-". - Page 1 of 4 ) ') Well Field Service Date Customer 1C #22 KUPARUK 02360-Dec-26 ConocoPhillips Alaska Inc. Dàte Time Treating Flow Rate Density Volume Pressure 24hr clock psi bbllmln Ib/gal bbl psi Job Number 2201044872 2002-Dec-26 17:34 796 5.0 8.31 22.2 549 0 0 2002-Dec-26 17:35 910 5.9 8.31 27.5 613 0 0 -----.-------.----..-- ..----.-.---.---"-" ---.------.-.--....--.------.-----.----.-------.----,-------.-,-----. -_._--~_._-,_..-. ---,-----.,.-.----..----------.... --..-...--..---.-.....--...-..-.-..-...,-.... 2002-Dec-26 17:36 928 5.8 8.31 33.4 645 0 0 .-_.--~.._._.._-_.._-_.._-~-_., ._~..__.._--._"'_._---- ---.----.----.-.-..-.---.-..-.-.- -- ---"'-_.,.._-----,-_._--~-_._-- ---------- --------_._--.--- .--. .---------. ....--.-.--.-.-.----..----------------.---........--.---.--....,--"."- 2002-Dec-26 17:38 741 4.1 8.30 38.9 558 0 0 --..-----,---- ---------.,..-----.--.-- .-----------.---.-.------..--.---, 2002-Dec-26 17:39 361 0.0 8.30 40.0 274 0 0 _0-"--"-'·-'-"---'--'''-'--- ___.___~___.______..___._.__.___.._.._.__....._.__..__- -----------. ~--..,.----_-- .-------.--,------.,,--.,----..-.-.-..--..,...........~..-.-- ,__~~g~=_~~_?=~~__ _1~_~~_~ ___________.___________________ ________________,_,_ _______,__,_____ _______,__ ____,__________..___.________.______I?!.?.P_~~~?_~_!'-~~_,_______,__.,___,___.____ 2002-Dec-26 17:39 333 0.0 8.30 40.0 242 0 0 --_.~,_....__.__.._.-._-,- ....---....-- --,---_. -.-,. --..---".-.-.-. -.-------.-..-".-..".-.--..- -..--.-,-.--- -- ...-.....--.----.--.----.-..-.-- ._---,-_._-,_.. _....,,_._,--_..._----"'_._._._."_._..,--,~._._-_...,._--.---...---..- 2002-Dec-26 17:40 315 0.0 8.30 40.0 233 0 0 ....-,-----,-----...-.-." .--.-...-.--.--------.---..--...---.....--,----.----.-.--..----------.--- ------..-.--.------..-..--.--..-.--.------...,.-.---.-.--_..._..,.._.__.~-_._--- 2002-Dec-26 17:40 310 0.0 8.30 40.0 228 0 0 -..-..-.-.-.---.--....-..--."... ..-.-' --..-..--.-.....-- --"---~--".._--"---,,._. ""---~-.-.._,,- -.--..--- ~ -- - --- -.- - .-..-.---.-.-- ..-- . ._.,,~-_._.,,-_._-- . ..~.._--_.- ------- . .----.-.---.-.-----. -..-.---.-.-.--.--- .--...---- ..-----..-- .----.-.-..----..-- 2002-Dec-26 17:40 start mud push 2002-Dec-26 17:41 580 3.9 11.58 40.8 434 0 0 ----..__._--_._.-.~ -.-.-. --..--.. .._"'" -..,.- --.- -.... ,---_. --.. ...." _."..~~.._- ..-----_. ._.~_.__._...-._-"...._....~..__. .--...-----, - ._........~. - -.~_.- -.-.. -.,.-----..-.. .~--,---- '--'-""'- _...._~..- ..- .-......"._,..-.. ,_.......~...__..."'. ...-"...-.- --'-'--'--~"- ,- ,.--. 2002-Dec-26 17:41 919 5.7 11.89 44.4 613 0 0 _..__. __ __, .___.._ ..._ _ ......_.....___. .~..__ __._......_...._~_.____. -..~_.,__._... .._.""_'_._'_ __._......__'"._~__.__ ._._ ~ _~M_.._.__._..__.~_. ___._.~h.._._~.________.._'"___,,_w._,___..__,,_.....___.. _...,_. _..~. _..__._...___~___...,' ._._...~_._.___ 2002-Dec-26 17:41 Reset Total, Vol = 44.37 bbl ...__.______.__.~".._.._._~.... _..._._.__ __._.._.._..__.._.._~~__..~____.____..____ __...~..._..._...,_._,__ .___.__...__...,_.__.__.._ . .___._ _.......______M ___._..,_.__.___.____""__, ...______.__.____.__._.__.._______"...__..____. 2002-Dec-26 17:42 947 5.7 11.89 46.0 649 0 0 __'__'''''''M _......,,_.__._..__ _.__.._ ...".. __._~.,__._..__......_...,,__.- _____._.._."'__......_..._.. _._.__··._.._,_·~_._u._ ...u...._._...........~ ..... _ _....__._,__,,_._..__....'_M'· ,,,....~.~....~._.. ___,.,.....__.__,. ._ ......_,_. ._._,..._".___,,_..._. __.._.._,........______._. ..._._...__........_._ ...,.~...~__.____.....__..~.. ~._.__. 2002-Dec-26 17:43 905 5.2 11.89 51.6 622 0 0 _.._ _...._._......_.__.._,,_.____~.. _h...___...... ._._. ._. ...~._...._...~_..___._._.____._ _...._·_.,_~.'..M_·___'.__·__· .____.__".,____.___._____.___.___ ._._~.___,~_.___~_ ._._.__._._._..__.._"~_ _.____~..___..~__. ,_ .__._.._.__._._....._____.____...___.__.__.._._. __._._.____.._ 2002-Dec-26 17:44 896 5.2 11.90 56.8 626 0 0 _.___..._.~._._._____...,_..._ ..".... ~"."_"....~....__.._,, "_,___._,,._ ___.__,__ .__ .... ..._..._.._'_._._.__'___n ._.__,..._.____.___.___._..._..___"'"'_.____._ ,,____...___._.___~ ~._.._~__ .._._..._.._____._ .____.-_.__,._____._.._.._ '__._._"_'__ ..___w.... _ ,_._,....._..._..... .__......_ ..___...__.._.~.._.___.._._.._..._ 2002-Dec-26 17:45 791 5.2 11.90 62.0 512 0 0 --. -_.~._._.,'_..._.__.".,,',.._..- - . ...--.-- ".- ,-.-- ~... ...--...-..--..----.-..--.----......-----..--. - -----.-.-.-----.---- -----------,- -.--.-..-..---- .--------.--..---...-..--------..--...----.---.--.--.--..-.---.--.---- 2002-Dec-26 17:46 892 5.4 11.90 67.4 626 0 0 2002-Dec-26 17:47 896 5.5 11.90 72.9 613 0 0 2002-Dec-26 17:48 873 5.6 11.90 78.5 590 0 0 2002-Dec-26 17:49 851 5.5 11.91 84.0 576 0 0 2002-Dec-26 17:50 828 5.4 11.91 89.5 562 0 0 2002-Dec-26 17:50 2002-Dec-26 17:50 2002-Dec-26 17:51 2002-Dec-26 17:51 -~"-_...._._"_...._-...,...._,..-.,,.._--.. ...-..- -- ~..-.- ----.---".--...-..-.-.-.. 2002-Dec-26 17:51 1020 - ...----..-....-..--...--... .-....-...,". 2002-Dec-26 17:52 1093 ..~- ...-.."-- .._...~_.._-.--- .~..... ..~- - .-- - - -.-. -...-,..-...".. ..-.-. _~~g~~~~~=-~.?.., _~.!.:~~_u__..._____,...__,._,...._____ ,,__________ .,__________ ,_________,__._._ ___ ,_,..,.,___ ,'.__'.._____,___ ?_~u..~rr~~.~P..~_~__~,~~ ~~~~_ .___, 2002-Dec-26 17:52 1093 5.1 15.91 101.4 581 0 0 .._._____..._....____...__._ __.._._~_._.._ ._.... .w._.,·.,,_.·__..__·~_~_______·"'_···_·,,__ _._~ _____ _.__._____ .__._ 2002-Dec-26 17:53 1079 5.4 15.91 105.4 585 0 0 __..___.__..._,,_~_._.._._ ___..,.__."" _.._ ..__..__".__.. ...,.._._"..~___,__._._._~__.. _.. _._ _. __.._._'___ __..,·._..__._.·_..___"M·__._....______..._. _.._.__.. ..,_ _..._.__... ._.___."".... ._._...__..__..,_ ._"_.__.,, ._".._.....~__"...._ _.____.__~.___,~....___._,__._."". ._'___.__"..._._"._'_..~_ ..... 2002-Dec-26 17:54 1079 5.4 15.91 110.8 544 0 0 -... --_..__...._,-~--.- -.-- .---- .-----. -,-..-. - _."..._~._------_.._.. .-----.-...,,----. -..----.--..-.- .-----..-....---- ..-----.--.- --_.-.----------- ------._-_._.__._-------"._._~,._.."'--_._-_._-_._._._.--..--- 2002-Dec-26 17:55 1084 5.5 15.91 116.2 544 0 0 ~ .____._.___...____.._~._. ___. __.., _W'.'~' __.._"_.____.._...__..____.__.__.__,."'_...._ _.. .._. _...._... .._.._.__..._..___. __...'"__._..._ ..__.._._.. ._..__,_,..._.__..__ .__.. ___,_w....._ .._ ....___ _ . ._._. _.~__,,_ '___'_~_' ..,,_.._._....._...,,_ __ _.___.__~,,_.,___,_~. .._.__.__..___, ._...._._ 2002-Dec-26 17:56 1006 5.4 15.91 121.6 521 0 0 2002-Dec-26 17:57 1002 5.4 15.91 127.1 475 0 0 2002-Dec-26 17:58 970 5.4 15.91 132.5 448 0 0 2002-Dec-26 17:59 919 5.5 15.91 138.0 411 0 0 2002-Dec-26 18:00 205 2.2 15.91 141.6 118 0 0 2002-Dec-26 18:01 182 2.3 15.91 143.9 82 0 0 2002-Dec-26 18:01 2002-Dec-26 18:01 146 0.0 14.23 145.1 63 0 0 2002-Dec-26 18:02 173 1.4 13.31 145.2 141 0 0 -~---., -.---- -- ----'--,.--.-' --- - --------.. 2002-Dec-26 18:02 Flush lines -.---.---- -.-..---..-.....---,,----.-- ----.-- ----.- .---..-----. .. .--- - ---.. - .-.-..----. --.--.-----.----..,-.--.---. 2002-Dec-26 18:02 173 1.6 11.61 145.2 59 0 0 ___.._~_,_._._._...__._._ _ .._.~__.___.__.__.___ _~...__________.________.__Io.__.__________________________.___ _ ._._..__.. _.__._. ________.___~._ _"...__.__.__,___.._.__ .____ ,~~~3-D~~::.~~,~~:0~ __~~ _8" _, .____~~~_,.,_ _ ..,___~~~?____L.._~~_~~.__,___._~.~__. ____~__ ". 0 2002-Dec-26 18:04 118 . 0.0 8.35 147.1 31 0 0 2002-Dec-26 18:05 132 0.0 8.34 147.1 63 0 0 2002-Dec-26 18:06 132 0.0 8.34 147.1 155 0 0 2002-Dec-26 18:06 _·___h_.,_ __._.___.._. ._._._...___._,_ ________.._. ____._._._____.__.__ .---.....- ,--_......_--.___ ~- ----.--- ..,,~._- . - .~._.-- --.-- -,--,.- 2002-Dec-26 18:06 136 0.0 8.34 147.1 214 0 ~ __~ --·--·--·--·0---------·--- __..__________.___ __~_..._._._.__.._ ___.__ ___ 2002-Dec-26 18:06 ___~___'W__________ ~___..__ ___..____.__._._._ _._ ._~ _____._.__ .____.__. "'-_'___'__'_' - ----.--.--.---.----~ -'-- ..---..----- .-..---,-- --,- -",------- 2002-Dec-26 18:06 0.0 8.34 147.1 480 2Õ02~-Öec=-:Ù3 'Tá:-õi-----'-- ;-' -0-:0·---- 8.34 147.1 443 .._._,,-~.__...._-_._-, - 2002-Dec-26 18:08 0.0 8.32 147.1 494 Reset Total, Vol = 49.31 bbl 805 988 5.2 5.2 15.56 15.88 93.7 94.9 535 562 o o o o Start Cement Slurry ___..__ _ .___"'__'_ '_._._~'.__."_'___._' __.u_.__. 5.2 5.2 15.88 - - ---"-.-.-..-..-...-- .- 15.91 95.0 100.1 590 - --- -. -..-.- .-..-- ".--.--- 585 o o o o h_ _.". __. _.._,______,_..... .....__.._ ._"".__.,,_. . --.----. - -.....-. .."--~.-- -.-,,-....-..-.---. ...._---....... -- -....--.-- _._,...._~ .-----.-.-------- Reset Total, Vol = 51.41 bbl --.._~-".~.,,_._- -----. -.-. .--.--.-.- -. -- ,-,,-.--.,,---~------ Drop Top Plug -'-'-- ---------...----,,---.-..---.-----.-.-...--- o _._-.- ,,- ---- ..-- ------- .-...-----"'" '"--.-.-.--- Rig Pumps To Displace o o o o o o .- -.-----.- -,-~..~_."._,--- __,._ --....-.....-...1.-.-- .__.____.... __.. ._..____.._..___.._. .__ ._"._.__ ___._ ----...--. --..-. Dec 29,2002 WRS3 v3.302-SR Page 2 of 4 ) ) Well Field Service Date Customer Job Number 1C #22 KUPARUK 02360-Dec-26 ConocoPhillips Alaska Inc. 2201044872 Date Time Treating Flow Rate Density Volume WHP 0 0 Message Pressure 24 hr clock psi bbllmln Ib/gal bbl 0 2002-Dec-26 18:09 109 0.0 8.32 147.1 558 0 0 2002-Dec-26 18:10 196 0.0 7.99 147.1 567 0 0 _.._'_..,---_.,-_._-~.~_.._. ---..----..- --------_._.._-_..,-'"..._---"'------._._-~----_.- ----,----_.'- ..-----.----,-------.-.."--...--.-.-, ..__._..,..---"._.__._-,----------~_..-- ---_.._-,-~----~-._--_._._...,---,--,-----~ ~_..._.-- 2002-Dec-26 18:11 123 0.0 8.22 147.1 617 0 0 __"'_"U_W'____W__ .__.._.__ ._...._,._.._.__.__ .__ ___..__._____ ..._ _.____.___.,~.~_......___. .__..____...__..___.__. __.__,.,._._..,...,~_,__,_ ...._ .._..__~.,_..'_ ".,._"____. _h__'_''''''__'____'_ ..__..._.,____...._,,_. __ .__.__,_. ". _._.__._._,____._____~_.._~_______~___.____.__.,_ 2002-Dec-26 18:17 274 0.0 8.29 147.1 759 0 0 ---,---------.-,- --.--..-.-- ---.-.--"....-...---..-..-.----------..----.-----.------..-- 2002-Dec-26 18:18 141 0.0 8.28 147.1 768 0 0 -------- -- ---- _._-_._--_._---,~-,----_. ..--,-...-.-,.-----" -~,..- -..--.....,....-.-.---,,----..- ---_._--,----,_._~-_.._. .,-..-.------..,----., --..--."..--.------..---,-- ---.-.-.. -,-..--------..-.---,---...-....,..'--.....-,--- 2002-Dec-26 18:19 118 0.0 8.11 147.1 759 0 0 ----,,---.--,.-.---. ,--.--..-,--..--'..."..--...-..--.- -- .. ..--.-..-...,,--.----.,.- --...--------.---,.--..-. -""--"--'-'--'-"- ---.--------".-.,. -..-..--..-.-...-.--.,---.-.--, ---.--.---,.-----.----.-,..-.-....--"----.....-----... 2002-Dec-26 18:20 233 0.0 7.85 147.1 782 0 0 - ---.---_., -,,--"-'.. ----..----.-...-....------------ -"...._-"..._-,-_.._,.,,,-,.- ..__.__.,-._--...._~..__._-,- .----.-....----.-.---- ,..-...----- --------, .--.,--.-.-..--.-.------..-------,-.,-----.-.---...---.--.--..-,-...-.-.,.--,--,. 2002-Dec-26 18:21 146 0.0 8.27 147.1 768 0 0 ---,-..-.---...,...,---.--'-'--- -,-_._._~-_._--_...__._._...._,_._- --.---.-.-.--- ---..-- 2002-Dec-26 18:22 182 0.0 8.11 147.1 782 0 0 .--.----.--,----.-- ,-.--- ---"----'-- -_..__._--_.__.~._... -.-.- _..-..-.~_._._---_. --,,_. ... .-. ,- ....-.-.. ,~. ....- -'--' ._- .- '-"'---' --""--"-- --.--..- -",..~'..- ..._,--.. -.---.- ---'--'--'---' - . -.---,-..,-.-.-.-.. -....------.--. ---.-.~~"--_.'-""-'-".-.". -. ....,..-" . ---...-- 2002-Dec-26 18:23 136 0.0 8.27 147.1 782 0 0 2002-Dec-26 18:24 255 0.0 8.15 147.1 764 0 0 -.-----."'--,- ..._-,---_._---- ,-,_.. _....~--_.._------- -,-.---------.--.--..--,- . --.. --~_._-.._._~---_. - .,-.-.--..------.----,.- -----.-,,-.---- -- ---.-~-~_._--,.._--- ----,.--.- _._,.,_._._--_...._.__.__.__.,_.~--~-_._--------~._--_.-~._'"- 2002-Dec-26 18:25 173 0.0 8.26 147.1 791 0 0 -._-,,_._--~_._,_...'.__.._._-- .----,.--- -----.-----..-----,-.-..------.------ 2002-Dec-26 18:26 484 0.0 8.25 147.1 787 0 0 --..-.--'''---.----.-''---' ---,.-----,----..-....".-.,,-.-.--- ,-..----.-.--- _._,~._.__.._.-_.- .-.- .,...-..-...--.. ,-_..",--- -'-'''-'--"-' --,_.- _._-,---"~--_.._-- ._----~-_._--..---- -.------,----------,-.-...--,---...--..-.......-..,.,-..._~-". 2002-Dec-26 18:27 132 0.0 8.27 147.1 805 0 0 --..------,. -"..._~..._._-,._----_.__._,--,_...._"--' "----_...-..._~--_._--._..__._,-_...._. ----.-- -----..------.- --'-~---'-'----'--- 2002-Dec-26 18:28 109 0.0 8.25 147.1 819 0 0 ------..-.-.- ---",.-....-. ._~ -_._,..~..,-_.,....- . ~-.----, ..-.-- ....-..-..-., .---,.,-...,.--... -..----- .-,---".-,,-.-.-... ....--.-.--- --.---"...-.-,----.-.---'" --"._----- -_.._~._-- -, ,-..--.-.--.--.--,,---- -----.---.--..,---.- .. .-- ....,.-.-.----,-..,.-. .-- .---,--.--,.---.-,----.---.----.--.-- 2002-Dec-26 18:44 104 0.0 -0.00 147.1 892 0 0 .-..-.,--.,-..,,-,..--...-, -..-...,.---,-.------ ,-.....--,..---...-- 2002-Dec-26 18:45 109 0.0 7.84 147.1 869 0 0 -..------".._-_..~,--_._~-,_..,--- -~.._,.__._-,.- ---..-...".--,-.-.--.- .. "'-._-"-.-~-'----- -,-~.- ~. -" -..-.----..----.-- -..---.-- .._,--,,----~. ,,_..-,. 2002-Dec-26 18:46 127 0.0 0.11 147.1 896 0 0 2002-Dec-26 18:47 118 0.0 -0.00 147.1 901 0 0 2002-Dec-26 18:48 104 0.0 -0.00 147.1 892 0 0 2002-Dec-26 19:04 109 0.0 -0.00 147.1 910 0 0 2002-Dec-26 19:05 109 0.0 -0.00 147.1 979 0 0 2002-Dec-26 19:16 114 0.0 -6.25 147.1 1002 0 0 2002-Dec-26 19:17 114 0.0 -6.25 147.1 983 0 0 2002-Dec-26 19:18 114 0.0 -6.25 147.1 919 0 0 2002-Dec-26 19:19 114 0.0 -6.25 147.1 919 0 0 n_'_..__..__'__'.'_'''__' _...,. . __._____ ___n" ___._..,_,__,,_..___,,_.._..__ 2002-Dec-26 19:20 114 0.0 -6.25 147.1 910 0 0 ..--.---...--,---.,--,-..-,--...,- --..-------,." -'-""--"- ~..-_.-..,..._--_._-.--,-" --,-..-...--".".,,-..,....,.-- ,,_.. --",-...._, ._'.~".__..._,--- .,- ..---.--.-.. - ---~ . --,-.---...".-- ,._--~.~---,,- 2002-Dec-26 19:21 114 0.0 -6.25 147.1 924 0 0 -'"~--'-"-'--'. ..~'''~-_.- ,_.. ------, .--- ._,- - - ...--.--,,-..-. -- -,_._--.~.._, ,.,...--.---- ~--_.._.- -- - - . ---.-. .---.....-- ,.-, , ,_.-- - --,-_.- 2002-Dec-26 19:22 114 0.0 -6.25 147.1 933 0 0 ---~_._- -----"._---- -----.-..,----.-.-. ._._-_.._..~_._.~,._- 2002-Dec-26 19:23 114 0.0 -6.25 147.1 979 0 0 _._____.._._...__,__..__.______ _"______. .._.~__ ,..._~_..._____.._____.___ _._ . ....._.___,,__,___.___,_,__.._.._..._..___ .,,__ __.. ...~. .._.._,_._.__... ._...___...____ .___.__..___ ___,__._._....__,.___._. ... .__...___._...____..______ ____.__".___._, _,__..,___.,__.__..._...". ..___._.__._w____,___ 2002-Dec-26 19:24 114 0.0 -6.25 147.1 1066 0 0 --"--' --_.__._.._._-~,,_..,-, "'..-...-.---" -- ----..-"'''-.-...--"..---.-"..---'-- .---..-- ,-_..._-~._------- -~..- .-,---------..--.-, - .---,-_..._-, -. ..-.".-,- -----.--,--.----.. ------."..-.-- --'..-. .,---..---..-.- - '-'---'--- "-'-- --- ---....------...-,-..--'''-, ~ 2002-Dec-26 19:32 114 0.0 -6.25 147.1 1363 0 0 __.._._.__ _.._____ _....___.._,_,..__ _______.__. ._____._.._...___ ___ "'__'__"__~"___'''_'_''_'_'_ __.__.____ _____~___... .."....__,______, _. .".__ __", __.... _".. .__ _.._..________ ,__........,,_..... _____ ,._~ ,._.... _____ _._,_ . ,_n,__,______ __ _____,_..._._",,_____ _... 2002-Dec-26 19:33 114 0.0 -6.25 147.1 1405 0 0 - --_..,- --------"-_.__.--,..._-,~.-----._-----,, .--.---'.'.---.---.--' ".--._-...._.~..-.._-,--- -------.---.--..--- - ----_._-,- -.------ --~. ----. --,,- -- -..- _.._,_._._--,---_..._.--.~--- ..-. ,--.--,.--..-..-- 2002-Dec-26 19:34 114 0.0 -6.25 147.1 1427 0 0 2002-Dec-26 19:35 114 0.0 -6.25 147.1 1478 0 0 2002-Dec-26 19:36 114 0.0 -6.25 147.1 1533 0 0 2002-Dec-26 19:37 114 0.0 -6.25 147.1 1556 0 0 2002-Dec-26 19:38 114 0.0 -6.25 147.1 1578 0 0 2002-Dec-26 19:39 114 0.0 -6.25 147.1 2132 0 0 2002-Dec-26 19:40 2002-Dec-26 19:40 2002-Dec-26 19:40 ____~u._..___._,__,__,~__ ____,___,_ 2002-Dec-26 19:41 ---------.-...--..- ---~,-- 2002-Dec-26 19:41 114 0.0 -6.25 _________.__' _,_,,_.._. ,_,,___ _____'-_.. _____~___O__._ __...._~_ .__________.__._ 2002-Dec-26 19:41 114 0.0 -6.25 114 114 0.0 0.0 -6.25 -6.25 o o 147.1 I 147.1 -T--'-------' ., '-:'--1-47:'1' --" ---'Z1'Ó9-- --- 0 '-r--14i1---- - 1853 0 2105 2109 ~_.~~- - ----..---..-. -.-----...- --...-.....--- o ~---~--_.__.__..,._--- o ~ -,--'----_._--,-.--- D-ec 29,2002 WRS3 v3.302-SR ------------------- -- --_. .-.-..,-------..-.-.-----.---..- ---,,_.-. .--.---.,- --.----....- _.~.__._,-,,--_.,-,_. _ -.--- _.._--,-~_. -_._.._,...__..~._..._- ..__._..._".._--~-- ,." , .,.-.-..,.. - .... ..... -- ~--~-- .-.,----.- "-'-'-"'- .._-,... --. .. --,. .~-_.-... .-_.._'.--,,--- -"--"-'-" ----....- - ___,.__" 'u_ __._____.._..,.."._.._.~_.._____"'_ __..._._.__ Bjump plug with 5548 strokes o o ._~-- -,-_.,._.~-_._--,-_._--_._----~---~ Check floats _u_ __,__,.._,_._______.~ ___ . .,-_. -----.-- -.- Page 3 of 4 ) ) Date 1C #22 Time Treätlng Pressure KUPARUK Service Date 02360-Dec-26 Customer ConocoPhillips Alaska Inc. Job Number 2201044872 Well Field Flow Rate Density Maximum Rate Total Slurry Volume of Fluid Injected, bbl Mud Spacer N2 Slurry Average Pump Rates, N2 Mud bpm ____.. ___'.·_'_U""_H". ___"__,l_,__________,_J__________l_________________,,______,.___ Treating Pressure Summary, psi Final Average Bump Plug to Breakdown 51 __ ____J________~~__________J__,___~~_,__,______L__,.___.__,________ Breakdown Fluid Maximum Volume Density 75 bbl 1____, D Cement Circulated to Surface? Volume D Washed Thru Perfs To Ib/gal 228 bbl .___________,_ ",.. ..1.",,______ ,_____,___,_l,____,.._________l__~~~_____J,_______ ..__,_ Avg. N2 Percent Designed Slurry Volume Displacement Mix Water Temp % 48 bbl bbl OF ft ..,___,.__.~._..__."...._'__'H_ "..._ _____.".'"_._..._,,__.._.___"._.______'._H._._._____..___0.," _____ _..___.___.__n __.... _._..___._._.___...._ Customer or Authorized Representative Schlumberger Supervisor Wester, Don Richard Gallegos [] Circulation Lost I~I Job Completed ____._.__.__..~__..__._...__.,__._._.__._._H........H_._...____.'''.__.._._".___._____..___._.__________.___..._ _______.~.___.._._ ON '___'."'_'._'.'__...__._._..w_..".._.'__.___,___.___'_"_'_."~'M__'_'.__M"M___~_~__'._ ."..._.~,_~...~.__.._,_ ,_._"______._u__ _.._~_______...'_. _,. .._. . _.___ _..'.M__."'._ ...._.__._.,_..,_ ____".__.__._."" Dee 29.2002 WRS3 v3,302-SR Page 4 of 4 12/29/2002 11:35:09 Bjump plug with 5548 strokes Check floats Stopped Acquisition Reset Total, Vol = 51.41 bbl Flush lines Drop Top Plug Rig Pumps To Displace Reset Total, Vol = 49.31 bbl Start Cement Slurry Slurry temp 81 degrees Drop Bottom Plug start mud push Reset Total, Vol = 44.37 bbl start CW100 Pressure Test Lines Bleed Off Pressure cont. CW100 Safety meeting Messages PSI 6000 3000 lS.O 0.')0 \. t ~ ~ ¿ LB/G 20,0 B,O 5,0 r - Rig floor PSI 15,0 _._______.'._...~~_ A"'"'"____'__"" ___.___.__..... . __."...________,______._.__.__,__..".~_~"'''__ _ ____________., .______.....____ "__.__ Density - '-'--'---'--'- ""-"-'-'--.'"-'.'-'-'.- __,__. ._._.__.._...._.._ ___-,.0____- ",'''__.'.'__0.__..._.__'_ CemCAT v1.Q 12-26-2002 7" longstring COl1ocoPhillips 2201044872 ) Client SIR No. Job Type Job Date ~ 5.3 ~ 1 I L-., -------- B/M 2,7 6000 0,00 i i ~ - Rate _.- '.'-"-~-_."--"" __._ ____..__,__.____n_.___ _____._.....________.______.._..__...__._____._.__.... Job Report ) 3000 r - Pressure -PSI 0,00 hh:mm:ss 19:42:11 19:33:00 19:23:00 19:13:00 19:03:00 18:53:00 18:43:00 18:03:00 ¡r 18:13:00 ;1 18:23:00 it 18:33:00 "" > , 17:53:00 i~ I~ 17:43:00 17:33:00 17:22:58 Time .-.- ".-.----------..---.-'..---.---..-,,--.--.----.----.' ....-. - ....-.. .. Engineer Country Kuparuk Rick Gallegos United States n_'_."_~_.'" _.,_ ._.,___ ~..h. 1C-22 Well Field --_..~---..__.--_. SchlulDberger PAl Daily Drilling ) ) Page 1 of 2 ~ ConocòPhiUips Well Sidetrack Q ~ C> ConocoPhillips Alaska Daily Drillin2 Report Network 24 Hrs TMD TVD Proq --, DFS REPT NO. 1C-22 1C-22 10027561 0' 14,620' 6,822' 20 21 DATE 12/26/02 Supervisor Don Wester/ Proposed TMD M.C. Heim 14,536' Pressure Test(s) Rig Name Doyon 141 Field Name Current Status Event Code 24 HR Forecast Dª'.Uy....t.Q,$,t $416,336 Type I Date I TMD I TVD I MW I Press I Tot. press I EMW FIT 112/20/0219473'14511'19.3 ppgl1560 $3,573,185 psiI3,739.34 ps1115.96 ppg BOP Tst (Last I Next) 12/18/02 112/25/02 Rig Accept: 12/6/02@ 15:00 Riq Release: @ : 12/26/02 Kuparuk River Cumulative Cost Running 3.5" completion Last Safety Meeting ODR Incident 1st 24 hrs? No Finish running completion-land same-lay down 73 stds. 5" dp Last Survey TMD: INC: Azim: Last Casing 9.625 (in) @ 9473 Next Casing 12/24/02 14,620 46.15 64.91 7 (in) @ 14536 º.D.e.r.ª.t..i.º.n.~.....s.º,m,m.ª.ry. From To . . Time Start End Operation Hours Phase Activity Subcode Class Trouble Depth Depth 00:0001:00 1.00 PROD CASE RUNC P 0' 0' Run 7" csg. to 4500'. 01:0001:30 0.50 PROD CASE CIRC P 0' 0' Circ. capacity of csg. @ 4500'. 01:3005:30 4.00 PROD CASE RUNC P 0' 0' Run 7" csg. to 9400'. 05:3006:30 1.00 PROD CASE CIRC P 0' 0' Circ. capcity of csg. @ 9400'. 06:3011:30 5.00 PROD CASE RUNC P 0' 0' Run 7" csg. to 14609'. Circ. & condition mud @ 14609' w/ partial returns @ 3 11:3016:00 4.50 PROD CASE CIRC P 0' 14 620' bpm 600 psi mix barofiber & , stage pumps up to 6 bpm 800psi gained full returns total mud loss 33 bbls. Rig down fill up tool-blow 16:0016:30 0.50 PROD CASE OTHR P 14,620' 0' down top drive-make up cement head. 16:3017:30 1.00 PROD CASE CIRC P 14,620' 0' Cire. & condo @ 6 bpm w/ full returns=take on seawater. PJSM=Pump spacers & cement as per program. 17:3020:00 2.50 PROD CEMENT PUMP P 14,620' 0' Bump plug on calculated strokes-to 500# over pump pressure-bleed off-floats held. 20:0020:30 0.50 PROD CEMENT OTHR P 14,620' 0' Rig down cement head & landing jt. http://bizak/drilling/cgi-bin/reports/daily .asp ?wellname= 1 C%2D22&reportdate= 12/26/02 1/6/2003 , PAl Daily Drilling ) ) Page 2 of2 20:3021:00 0.50 PROD CEMENT OTHR P 14,620' 0' Install packoff-test to 5000# 10 mlns.-set test plug. Change top rams to 3.5" X 21:0023:00 2.00 PROD CMPLTN OTHR P 14,620' 0' 6"-test doors to 2000#- change bails on top drive- clear floor. 23:0000:00 1.00 PROD CMPLTN RUNT P 14,620' 0' Rig up to run 3.5" completion. 24 Hr. Run & cement 7" csg.-rig up & run completion. Sum: Date Source Inje,ç,ti.Q.u Volume Destination 12/26/02 1C-22 963 1R-18 Cumulative for 1R-18 = 84,170 Mud Data Mud D "t 10sec I 10 Flowline Drilling Company T ens. y FV PV /VP min / 30 min WL/HTHPMBT PH ype Gels Temp Solids Baroid Non- 10.5 46 17 /15 5/7/9 3.5 /10 17 9.6 0 2.5 Disp. LS Baroid Non- 10.5 46 17 /15 5/8/10 3.4/ 9.8 17 9.8 0 2.5 Disp. LS ~, ,,~ http://bizakldrilling/cgi-bin/reports/daily .asp ?wellname= 1 C%2D22&reportdate= 12/26/02 1/6/2003 1/4 illile R(ldillS oj' lC1-22 Ue 9-5/8" Csg PI (@ 9473' kID /4510' TVD) / . (lVofVells witllinH 1/4 iJfile R(ldill~ Reference Azimuth Angle [deg] vs Centre to Centre Separation [500ft/in] _/ 90 '---' 0.000 COMP.'J<-Y DETAILS Phillips Alaska Inc. FngineeñDg Kuparuk Calculation Method: Minimum CmvaIure Error Sy;;ùm: ISCWSA Scan Melhod: Horizoot8I Plane Error Surfàce: Elipticol + Casiug Warning Method: Rules Based Origin Origin +W-S +FJ-W 0,000 0.000 66.77° V.S<cIion Angle Slartiug From TVD WELLPATH DETAILS 1C-21 Doyon 141 RKB ~ 60' MSL 6O.000JI Rig: Re£Da!um: 180 B-,-, ~/--- ~150 1333 o A~ïI-COLLlSION SETTINGS Interpolation Method:TVD Interval: 1.000 Depth Range From: 4510_000 To: 4512.000 Maximum Range: 1658.800 Reference: Definitive Survey 270 I.oIIgiIude 5101 ~623:!4,1IO 70'19-J9,344N 149'19'40,108W N/A WELL DETAILS Latitude , 1250 -1333 1000 750 500 250 -0 250 - 500 750 1000 -1333 1250 Eu!ing Nam< +NI·S +FJ-W NortIBng IC-22 1124.418 -27.909 ~96%.\6,50 _~ Jo&:nI~ _.- IlI"'2:I'ê~ ,.... A..'ì'I1-<.UUlSIO~ SFrIISGS ==~:m~ff.Q ~ ¡fftoo ~~ 1658.8:0 ~De~Si::Ye)· ---- '=" C*-_JillililllClllCIr<azo --"""^ .=æ æ..:;. b(Ðobz; .xs_ID)oI:!It. ....~-= - ~' - 1/4 lyfile Radius of 1 C-22 ... 9-5/8" Csg Pt (@ 9473' lWD/4510' TVD) (.1\[0 Wells within 1/4 Mile Radius) Rcfi::rence Azimuth Angle [degJ \"i Centre to Cerd:rc Separation [SOOftTm) ~-------~--- Well Name: 1 C-22 I Rig: Drilling Supervisor: Don Wester I Dink Heim Type of Test: other - See Comments Hole Size: ! 8-1/2" : ... RKB-CHF: 24.9 Ft Casin~ Size and Description: Casin~ Test Mud Weight: Mud 10 min Gel: Test Pressure: Rotating Weight: BlockslTop Drive Weight: Estimates for Test: PRESSURE INTEGRITY TEST PHILLIPS Alaska, Inc. Doyon 141 I Date: 12/2712002 I Pump used: I #1 Mud Pump ... : ...1 Pumping down I drillpipe. ... Casing Shoe Depth I Hole Depth 9,473 Ft-MD 4,511 Ft-TVD 14,620 Ft-MD 6,822 Ft-TVD ! USE PICK LIST ! ...1 8.4 ppg Lb/100 Ft2 3,500 psi 125 Lbs 34 Lbs o bbls Pressure Inte~rityT est Mud Weight: 10.5 ppg Mud 10 min Gel: 5.8 Lb/100 Ft2 Rotating Weight: 125 Lbs BlockslTop Drive Weight: 34 Lbs Desired PIT EMW: 16.0 ppg Estimates for Test: 1290 psi 1...1 1.7 bbls I' i... EMW = Leak-off Pressure + Mud Weight = 780 0.052 x TVD 0.052 x 4511 + 10.5 EMW at 9473 Ft-MD (4511 Ft-TVD) = 13.8 PIT 15 Second Shut-in Pressure, psi 625 1 000 - - . --r8. · · I!I · · · · ;--fl I I I I i I ~~1t~~ LJ.J c:: ::J U) U) LJ.J c:: c.. 500· . o o 2 4 8 5 10 15 20 25 Shut-In time, Minutes o PIT Point I Volume Input Pump Rate: [ Barrels r... 0.1 000 Bbls/Strk ... 8.0 Strkjmin ... Casing Test Pressure Integrity Test Pumping Shut-in Pumping Shut-in Bbls psi Min psi Bbls psi Min psi 0 0 150 0 630 1 0.5 520 0.25 625 2 1 620 0.5 625 3 1.5 650 1 620 4 2 680 1.5 ~ 5 2.5 700 2 6 3 700 2.5 7 3.5 700 3 8 4 710 3.5 9 4.5 720 4 10 5 740 4.5 15 5.5 760 5 20 6 780 .Þ 5.5 25 6.5 760 6 30 7 760 6.5 7.5 760 7 8 760 7.5 8.5 750 8 9 750 01=\ o.v 9.5 750 91 5701 10 750 9.5 I 10 570: ~ 30 ~CASING TEST Volume Bled Back 0.0 ~bls _l::SblS LO I w/1 0.5# mud Prior to freeze protect Well had 150# back pressure prior to pumping. Injectivity test for 7" X 9-5/8" annulus Vo ume Bled Back I::Sbls Comments: 10 12 6 o Barrels ~ LEAK-OFF TEST ) ) Note to File Well 1 C-22 PTO 202-222 Sundry 303-014 ConocoPhillips Alaska, Inc. requests approval for annular disposal in the subject well. This note analyzes information submitted by the applicant and recom- mends approving this request for annular disposal. 1 C-22 9-5/8" surface casing was cemented with 882 bbls lead cement followed by 196 bbls tail cement in two stages, totaling about 2240/0 excess second stage cement relative to gauge well bore. 70 bbls of lead cement circulated to surface during initial placement, with full circulating returns. Successful placement of such volumes of cement indicates that 1 C-22's surface casing is adequately ce- mented. The formation below the 9-5/8" casing shoe supported a 14.7 ppg EMW leak off test. Applied pressure dropped 460 psi (from 1180 psi) during a 10 minute ob- servation. An injectivity test prior to setting 7" casing showed a pressure gradient of 13.8 ppg EMW referenced to the 9-5/8" casing shoe. During this test, pres- sure reached a maximum of 780 psi. The pressure then stabilized and shut in pressure varied between 630 psi and 570 psi over 10 minutes. There are no wells within 1 C-22's AOR. Based upon information submitted, AOGCC recommends approval of Conoco- Phillips's request for annular disposal in Well 1 C-22 (PTO 202-222). V,.j 6 Æ- , l "Z-\ l 0 ~ ~ Robert Crandall Sr. Petroleum Geologist Winton Au bert Sr. Petroleum Engineer AOGCC ) ') a oa-a~;<. Transmittal Form '&1. BAKER HUGHES INTEQ Anchorage GEOScience Center To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie Reference: 1C-22 ~ Contains the following: ! 1 LDWG Compact Disc (Includes Graphic Image files) 1 LDWG lister summary 1 blueline - MPR Measured Depth Log 1 blueline - MPR TVD Log 1 blueline - CCN-ORD Measured Depth Log 1 blueline - CCN-ORD TVD Log LAC Job#: 392634 Sent By: Gl~n ~~ . Receive6o/- (~ Date: J an 10, 2003 Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 R' 3=C~r.:I\IE' ~i ~" e_1 ~'r~' Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 I~" I., .,.=~:.:,;;'~~:~:;:,: ." ,,: .1, t~:-""'::' ,. ~;; :,IÞtØ:I'~",,~' ,--: ,_,~'!\ 1Iftt(,. ¡~~:--:~:::,¡;-::~~--_:::~: "',,,..w ¡ i-----------.§~,~;:;;;~>,~------------ ~~2:.~~:.~'~~'~~~,~,~;~~.~~;.~;~~.~.~~:~~;; i::7;"~.,~{. ~'~___~~__:: iI''''''''''';'''';· ¡.-: '~, :_"::-.. ! r\~' 1 ,', ...."\ r ", i v}""!'~ i', L:.\.) ¡-~-- {I,;':4'l'Ì<1': "'r :~ ""-; '., .' "'L', . i \.........,,; "... _ ............. ~ ,"'," "~'_..;;'~!r.hl~-tton ;V:rh',~?i:' L_,.,,__________.. ) ~1~jŒ Œ~ !Æ:!Æ~æ!Æ ) AI1ASIiA OIL AND GAS CONSERVATION COMMISSION / / TONY KNOWLES, GOVERNOR 333 W. TH AVENUE, SUITE 100 ANCHORAGE,' ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Kuparuk Team Leader ConocoPhllips Alaska P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 1C-22 ConocoPhllips Alaska Permit No: 202-222 Surface Location: 1593' FNL, 1327' FWL, SEC. 12, T11N, R10E, UM Bottomhole Location: 2032' FNL, 2463' FWL, SEC. 5, TI1N, RIlE, UM Dear Mr. Thomas: -þP Enclosed is the approved application for permit to¡édrill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~?~ Michael L. Bill Commissioner BY ORDER OF THE COMMISSION DATED this ~/!! day of November, 2002 cc: Department of Fish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. ") ConocóPhil·lips ) Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Fax: (907) 265-1535 Email: rlthomas@ppco.com November 15, 2002 Cammy Oechsli Taylor, Chair Alaska Oil and Gas Conservation Commission 333 West ih Avenue Suite 1 00 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill, injector 1 C-22 Dear Commissioner Taylor: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore service well, KRU 1 C-22, a development well. Please find attached for the review of the Commission the information required by 20 ACC 25.005 (c). If you have any questions or require any further information, please contact Shane Cloninger at 265- 6829. Sincerely, ~~~ Randy Thomas GKA Drilling Team Leader RECEIVED NOV 1 5 2002 ~UP on & Gas (;)ons. comm\sslon Anchorage ë'~') I, \' ~¡ '\ Ii 1\ : '"\ " ,\ ! 1 ~6h ."ittl0z.. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ) ') 1 a. Type of work: Drill ~ Redrill U Re-entry DDeepen 0 2. Name of Operator ConocoPhillips Alaska, 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1593' FNL, 1327' FWL, Sec. 12, T11N, R10E, UM At top of productive interval 2116' FNL, 2270' FWL, Sec. 5, T11 N, R11 E, UM At total depth 2032' FNL, 2463' FWL, Sec. 5, T11 N, R11 E, UM 12. Distance to nearest property line 13. Distance to nearest well I 2032' @ TD feet 1 C-23 @ 84' @ 300' 16. To be completed for deviated wells Kickoff depth: 250 MD 18. Casing program size PERMIT TO DRILL 20 AAC 25.005 1b. Type of well.,/' Exploratory U Stratigraphic Test Service 0 Development Gas 0 Single Zone 5. Datum elevation (DF or KB) 88' AMSL U o Development Oil U Multiple Zone 0 10. Field and Pool feet 6. Property Designation ADL 28242 ALK 2292 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) Kuparuk River Unit Statewide 8. Well number Number 1 C-22 #59-52-180 9. Approximate spud date /' Amount December 2, 2002 $200,000 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 14536' MD / 6789' TVD 17. Anticipated pressur1(see 20 AAC 25.035 (e)(2)) Maximum surface 2632 psig At total depth (TVD) 3355 psig Setting Depth Kuparuk River Field Kuparuk Oil Pool Maximum hole angle 67° Hole Casing Weight 42" 30" x 16" 62.5# 12.25" 9.625" 40# 8.5" 7" 26# Specifications Grade Coupling H-40 Weld L-80 BTC L -80 BTCM Length 80' 9424' 14508' Top Bottom Quantity of Cement MD TVD MD TVD (include stage data) 28' 28' 108' 108' 9 cu yds High Early 28' 28' 9452' 4522' 1 030 sx AS Lite & 615 sx LiteCrete 28' 28' 14536' 6789' 230 sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured true vertical feet feet Plugs (measured) Effective Depth: measured true vertical feet feet Junk (measured) Casing Conductor Surface o Length Size Cemented Measured depth True Vertical depth RECEIVED Perforation depth: measured true vertical NOV 1 5 2002 AJ!:\91(9 nil,~ G::1!o1 Cons. Commission 20. Attachments Filing fee 0 Property Plat 0 BOP Sketch 0 Diverter Sketch - U DrillirAnohol'aai] Drilling fluid program 0Time vs depth plot Qefraction analysis DSeabed report 020 AAC 25.050 requirements 0 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Call Shane Cloninger 265-6829 . ~~~---=- ltll5"lo~ Signed ' _. ) Title: Kuparuk Team Leader Date Randy Thomas PfAnArAd hv ShAmn AII.c;lln-nrAkA Commission Use Only Permit Number I API number I Approval date 11/'11/0 ."1 :z. 0..2.. - <.- z.. 2.- 50- ð 2. 9 - 2. 3 /2.. 7 I' rJ', Conditions of approval Samples required 0 Yes ~ No Mud log required Hydrogen sulfide measures 0 Yes ~ No Directional survey required ~ Yes Required working pressure for BOPE D2M; 0 3M; 0 5M; 0 10M; 0 0 Other: T-e.)t ~o PE to S"ooo pÇ.~. M I: \) tM..A.- f b~i1 to, rt?~~~d. by order of ORIGINAL SIGNED BY M L. IjJß Isee cover letter for other requirements U Yes ~ No o No Approved by Commissioner the commission Date II .;\ \ n~ Form 10-401 Rev. 12/1/85· CRr:!"', ~..~ ~ ".': ¡' U ~. J J j'~l ~ Submit in triplicate ) "~cation for Permit to Drill, Well 1 C-22 , Revision No.O , Saved: 15-Nov-02 Permit It - Kuparuk Well 1 C-22 Application for Permit to Drill Document Mo)ximizE We-II VQIII,J~ Table of Contents 1. Well Name................................................................................................................. 2 Requirements of 20 AAC 25.005 (f)............... ............ .......... .............. ................ ...... ...... ......................... 2 2. Location Su m mary ................................................................................................... 2 Requirements of 20 AAC 25. 005( e)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b).................. .... ......... ............ ........ ...................... .................... ....... ....2 3. Blowout Prevention Equipment Information .........................................................3 Requirements of 20 AAC 25. 005( e)(3) ................................................................................................... 3 4. Dri II i ng Hazards I nformati on ................................................................................... 3 Requirements of 20 AAC 25.005 (e)( 4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ...........................................3 Requirements of 20 AAC 25.005 (e)(5) .................................................................................................. 3 6. Casing and Cementi ng Program... ... ......... ..... ...... ....... ....... ...... .... ...... ......... ........ .... 4 Requirements of 20 AAC 25. 005( e)(6) ................................................................................................... 4 7. Diverter System Information. ...... ................ ...... ............ ..... ...... ....... ............ ..... ....... 4 Requirements of 20 AAC 25. 005( e)(?) ................................................................................................... 4 8. Dri II i ng FI u id Program ............................................................................................. 4 Requirements of 20 AAC 25. 005( e)(8) ................................................................................................... 4 9. Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (e)(9) .................................................................................................. 5 1 O. Seism ic Analys is...................................................................................................... 5 Requirements of 20 AAC 25.005 (e)(1 0) ................................................................................................ 5 11. Seabed Condition Analysis .....................................................................................6 Requirements of 20 AAC 25.005 (e)(11) ................................................................................................6 12. Evi dence of Bond i ng ............................................................................................... 6 Requirements of 20 AAC 25.005 (e)(12) ................................................................................................ 6 1 C-22 PERMIT IT. DOC Page 1 of 7 _', """,, , ','", ,",' " ~ ,,", [rinted: 15-Nov-02 0, 'il ¡" . , } "1 j 'i i ~,~ ~ !I .¡ t'; . ) '\ication for Permit to Drill, Well 1 C-22 J Revision No.O Saved: 15-Nov-02 13. Proposed Drilling Program .....................................................................................6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 7 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................7 15. Attachments............................................................................................................. 7 Attachment 1 Directional Plan ........ ................ .......... ....... .... ....... ...... .... ....... ....... ................ ....... ............ 7 Attachment 2 Drilling Hazards............................................................................................. 7 Attachment 3 Well Schematic.............................................................................................. 7 1. Well Name Requirements of 20 AAC 25.005 (f) Ear:.1ì well mu.~1: be Identified by a unique name designated by the operator and a unique API number assigned bV the comml53jon uflder 20 AAC 25.040(b). For a vv'ell wittl multiple well braf1cl]e5~ each brand} must sÍlmï¿1J1v be IdentifIed by a unique name and API number by adding a suffix to the name de5~ql7ated fÓr the vlell by the operator and to the number as:'ifqned to the well by the comml'ision The well for which this application is submitted will be designated as lC-22. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Dr/II must be aa'C}mpaméd by each of the têïllowinq t!ems~ except t(](' an item already on file with the cOlmni5:~;jon ,~:¡fìd Identitìed In the applk,:¡tkm: (2) a plat identifying the property and the property's owners and showing (A}the cvordlÍ7ates or the proposed location of'the well at t!ie 5'Urf~7cç~ at the tor.) of' each objective (ármatkJn¡ and at total dt.':.'l.ìth referenced to governmental ::'ì.:?ctlon line.'). (B) the mordinates of the proposed location olthe well at the surfáæ¡ reférenced to the state plane coordJi7ate sy..<;tem f'or this state as maintained by tile NatkJnal c;e()detk~ Survey Iii the National Oceanic and Atmosphenc AdministratkJn/ (q the proposed depth ol t17f.! ¡'Fell at the top ol each objective tbrmat/on and at total dt'!}th/ Location at Suñace NGS Coordinates Northings: 5,968,647 11593' FNL, 1327' FWL, Sec 12, TllN, Rl0E, UM RKB Elevation Eastings: 562,335 Pad Elevation 28.0' AMSL 60.0' AMSL Location at Top of Productive Interval (Kuparuk "C" Sand) NGS Coordinates Northings: 5,973,504 2116' FNL, 2270' FWL, Sec 05, TllN, RllE, UM Eastings: 573,407 Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 14,239' 6,579' 6,491' Location at Total Depth 12032' FNL, 2463' FWL, NGS Coordinates Northings: 5,973,589 Eastings: 573,599 Sec 05, TllN, RllE, UM Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: 14,536' 6,789' 6,701' and (D) other InfÒrmation required by 20 AAC 25,05(}(b)/ Requirements of 20 AAC 25. 050 (b) Ila well is to be intentionally deviated, the applIcation for a Permit to Dnll (Form 10-401) must (1) include a plat, drawn to a suitable scale, showing the path of" the proposed wellbore, Including a/I adß¡cent wel/bores vIlthln 200 féet of any portion of the proposed vvell,' Please see Attachment 1: Directional Plan 1C-22 PERMIT IT. DOC Page 2 of 7 Printed: 15-Nov-02 O iI""': .~ .....~. I' .. ~ I' I ¡~j' i ~i ¡ iJ /'1 ~ ) '~cation for Permit to Drill, Well 1 C-22 J Revision No.O " Saved: 15-Nov-02 and (2) for all well'i witt1li7 200 feet of the proposed wellbore (í1) list the names of the operators of those well'i¡. to the extent that t¡lOse names are known or dlsì.,,;overable in pub!k- record~ and show that each named operator has been fum/s1/ed a copy or the application by certilled mal/,' or (8) state that the applicant is the only atT-ected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be acY"vmpimied by each of the fÒllov,¡/Íìlj Item5.~ exæpt {or an item already on file with the (vmmission and identified in the applk.;zition: (3) a diagram and description olthe blowout prevention equipment (BOPE) as requin;d by 20 AAC ZI),03_'Ï¡ 20 AAC 25.03tÝ¡ or 20 AAC 25. 037/ as applicable/ Please reference BOP schematics on file for Doyon rig 141./ 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An applic,::;tion fvr a Permit tv Drill must be acrx;mpanied by eaäï of the tolloflv'l/7g ìtem5~ exæpt /br an item already on file with the (;ommission and identified in the applìcation: (4) infÒlmaliofl 0/7 dilling hazards¡ including (A) the maxlinum downhole pressure that may be encountere(t cnteria USi:yj to determ¡lìe it and maxlinum potentJ/:l! surtàce pressure based on a methane gladìent; Based on reservoir modeling and history match of production/injection data, the estimated pressure is to be 3050 psi at 6434' TVD 55 with an accur~of (+/- 200 psi). Therefore, the highest expected pressure is 3250 psi at 6434' TVD 55, 0.51 psi/ft orC21. ppg EMW (equivalent mud weight). .' I 0.:;-- The maximum potential surface pressure (MPSP) while drilling lC-22 is calculated using above maximum reservoir pressure, a gas gradient of 0.11 psi/ft, and the Kuparuk C sand target at 6579' tvd: MPSP =(6579 ft)*(0.51 - 0.11 psi/ft) = 2632 psi (8) data on potent/~ll gas zOl7e!>~' The well bore is not expected to penetrate any gas zones. and (C) dF¡ta cr.mceming potenÖ;;¡/ D.'luses or hole problems such as abnormally geo"pre.ssured strata, lost ärcu!,wÒn z()nes~ and zones that have a propelï5ity for differential stiding/ Please see Attachment 2 - Drilling Hazards Summary 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a P(;f7mt to Drill must be accompanied by each of the fÒ//m-lJÍ79 ¡tem~ except fÒr an Item already on file with the commission and identifìed in the applìcatìon: (5) a descnj7tiofì of Ihe procedure f..0r conducting formation ¡illegrity testS,. as required under ,zO AAC 25: 030(f/, A procedure is on file with the commission for performing LOT's. 1 C-22 PERMIT IT. DOC Page 3 of 7 Ii, " Printed: 15-70V-02 V D . J ~i I ~ ';I r~ L ) ì\ication for Permit to Drill, Well 1 C-22 J Revision No.O Saved: 15-Nov-02 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An applicðtion for a Permit to Drill must be accompanied by each of the Ivllow/of! Item5~ except IÒr an item already on (¡Ie with the (,Vmmi5-sion and Identil?ed in the applk.'ation: (6) a complete propos-ed c:-¿lsing and cementing program as required by 20 AAC 25.03~ and a desaiption o('any slotted liner~ pre- pt?¡fÒrtlted líner~ or screen to be installed; Casing and Cementinq PrOqram Hole / / Top Btm CsgíTbg Size Weight Length MDíTVD MDíTVD OD (in) (in) (Iblft) Grade Connection (ft) (ft) (ft) Cement Program 30 X 16 42 62.5 H-40 Welded 80 28/28 108 / 108 9 cy High Early Insulated Lead: ~ 9-5/8 12-1/4 40 L-80 BTC 9,424 28/28 9,452/4,522 lo.7ir III Lite Tail: r 1~ x 12.0 ppg 'Lite E'. / (Yield=2.24 cuft/sk) ~d TOC=Surface 7 8-1/2 26 L-80 BTC-Mod 14,508 28/28 14,536/6,789 ~d. x 15.8 ppg 'G' wI Planned TOC= 13,400' An open-hole leak-off test will be performed on the 8 '12" open hole interval after reaching the contingent casing point. If the leak-off test indicates insufficient formation integrity, 7" casing will be top-set above the Kuparuk C sand. In this case, 6 1/8" hole would be drilled to total depth and a 3 V2" 9.3 ppf L-80 SLHT production liner will be cemented across the productive interval. 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An applk:ë1tíon lor a Perm!!' to Drill must be actvmpanied by each of the fNlowing Itê:!m5~ exa;pt' /Ór an Item already on flle with the cvmmiS5ion and Identi/ied in tfle applk.'(}tiol7: (7) a diagram and desalptiol7 ot'the dlllerter system as required by 20 AAC 25, 03~ unless tNs requirement Is waived by the commlssiol7 under 20 AAC 25,035(17)(2); Please reference diverter schematic on file for Doyon rig 141. ./ 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An applicatio/ï Ivr a PermIt to Dn/I must be accompðnied by each of the following items, except for an item already on lìIe wtlfì the commission and identified t/¡ the appliG'itJÒn: (8) a drillt/7g flUldprogram/ il7äuding a diagram and description oftfle dnlling fluid system/ as required by 20 MC 25:033/' Drilling will be done using mud systems having the following properties: 1 C-22 PERMIT IT. DOC Page 4 of 7 Printed: 15-Nov-02 Or:" ,~ ~ ~', ; :~ ¡ I'~ì Î ~J j 4 \J ¡~, ;.. ) 't,' ¡cation for Permit to Drill, Well 1 C-22 , Revision No.O Saved: 15-Nov-02 Suface Hole (extended bentonite) Spud to Base of Permafrost Initial Value Final Value 8.5 ~9.4 150-200 150-200 Base of Permafrost to Total Depth Initial Value Final Value ~9.4* 9.4* /' 150 65-75 Density (ppg) Funnel Viscosity (seconds) Yield Point (cP) Plastic Viscostiy (lb1100 sf) 10 second Gel Strength (lb1100 sf) 10 minute Gel Strength (lb1100 sf) pH 8-9 API Filtrate(cc) 8-15 Solids (%) 5-8 *9.8 ppg if hydrates are encountered 30-60 8-15 10-30 25-55 30-60 20-40 18-30 11- 22 15-30 15-30 10-25 10- 25 10-25 25-55 20-40 20-40 8-9 8-9 8-9 6 5-6 5-6 5-8 5-8 6-11 Production Hole (LSND) Density (ppg) Funnel Viscosity (seconds) Yield Point (cP) Plastic Viscostiy (lb1100 sf) 10 second gel 10 minute gel pH API filtrate HTHP filtrate Solids % Initial Value 9.3 40-55 5-8 6-13 3-7 6-13 9-10 <6 NC 4-10 Final Value 10.2 /" 40-55 18-26 14- 25 4-7 6-14 9-10 <6 <10 6-12 Diagram of Doyon rig 141 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 MC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) A/7 applicatlo/7 for a Permit to Dnll must be accompamed by each ol the fol/owli79 Item.", except for a/7 Item already on file with the commission and identified Ii] the application: (9) tÒr an exploratory or stratigrapflic test we/~ a tatJulatio/7 setting out the depths of predicted abnormallv geo-pressïlred strata as requ¡{-ed by 20 AAC 25.0JJ(f),· NjA - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application lor a Pe/lnlt to Dnl! must be accompanied by eacl7 ol the lollowli7g Item.", eXCI.:?pt lor an Item already on file with the comml'isiol7 and identified iii the application: (lOj for an exploratory or stratigraphic test v¡tel¿ a seisl77k: refraction or reflection anafySì:'i as reqUIred by 20 MC 25.061(3); Nj A - Application is not for an exploratory or stratigraphic test well. LHc 1C-22 PERMIT IT. DOC Page 5 of 7 Printed,; 15-Nov-02 ! \..,:). ~ ~' ~¡ :~3 \, } ")'cation for Permit to Drill, Well 1 C-22 Revision No.O Saved: 15-Nov-02 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An applic,'<",Jtion for a Permit to Drill must be accompanied by each of the following items" except f'or an item already on (¡Ie 1111th the commi.':;:';;ion and identified in the applicF;t!on: (1.1) for a well drilled from an offs1ìOre pJatf'Orrn mobile !JottOm-f¿ìU!ìded structurel jack"'up r~9" or floating df/lling vessel, an analY5i.5 of seabed conditions as reqwi-ed by 20AAC 25',061(b): N/ A - Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application fÒr a Permit to Dnll must be accompaméd by each of the following item0 eXCë;,'pt for an item already on tile with the commis"!:;iof) and identified i/7 the application: (12) eVIdence showing that the requin.·?ments of 20 MC 2.5.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a PermIt to Drill mu.5t be accompanied by each of the followliìg /Ï-em.fi¡ e:.;'cept ('Or an item already on file with the commission and identified in the applicabÒn: The proposed drilling program is listed below. Please refer as well to Attachment 3, Well Schematic. 1. MIRJ..tDeyd"ñ 1. / 2. ..A·rístall di",e r system. 3.(..D.r.uJ.<:~·- 4" hole to 9-5/S" surface casing point according to directional plan. Run LWD logging equipment with GR and resistivity. 4. Run and cement 9-5/S" 40#,/L-SO BTC casing string to surface. Employ lightweight permafrost cement lead slurry and LiteCRETE tail slurry. Pump adequate excess to ensure cement reaches the surfacz: If cement does not circulate to surface, perform top job. Install and test BOPE to 5000 psi. Test casing to 2500 psi. 5. Drill out cement and 20' of new hole. Perform LOT. 6. Drill S-1/2" hole to contingent top-set casing point according to directional plan. Run LWD logging equipmen),rwith GR, resistivity, and neutron density. Perform second LOT to evaluate /"' long string option. Drill well to total depth according to directional plan, and run 7" 26# L-SO BTCM casing to surface and cement. Note: If significant hydrocarbon zones are present above the Kuparuk C sand, sufficient cement will be pumped f9F isolation in accordance with 20 AAC 25.030( d)(3)(C). 7. Run 3-1/2" 9.3#, L-SO Srd EUE Srd-Mod completio~?embly w/ SAB-3 permanent packer and PBR. Set packer, shear out of PBR, P/U tUb~·ng ngerJ and land tubing. Pressure test tubing to 3500 psi. Pressure test 3 V2" x 7" annulus t 500~. Burst shear valve for freeze protect. S. Set TWC and ND BOPE. Install and pressur "production tree. 9. Freeze protect. Secure well. Rig down and move out. 10. Handover well to Operations Personnel. Note: If the deep LOT indicates insufficient formation integrity to continue drilling, 7" 26# L -SO BTCM casing will be run and cemented above the Kuparuk C sand. 6 l/S" hole will be drilled to total depth /' according to the directional plan and a 3 '12" 9.3# L -SO SLHT liner will be ran and cemented across the productive interval. 1C-22 PERMIT IT,DOC C R "G ~ .'\ .. ,rA,; Page 6 of 7 ·1 ¡ , , J r~ jf{~ 15-Nov-02 ). '.)'cation for Permit to Drill, Well 1 C-22 Revision No.O Saved: 15-Nov-02 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill must'c be accompanied by eadï of the f'ollowing item5~ except t'or an item a/ready on tìle with the commission and Identified in the application: (14) a general de;;;-crlption of!7ow the operator plans to dispose oldrillJ/79 mud dnd CULtïiï[!S and a sÜ;ltement of whether the operator intends to request authorization under 20 AAC 2S.0/JO for an annular di!:·;posal oper,'1tion in the well.; Waste fluids generated during the drilling process will be disposed of down a permitted annulus on 1C pad or hauled to a KRU Class II disposal well. All cuttings will be disposed of either down a permitted annulus on 1C pad or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. /' At the end of drilling operations, an application may be submitted to permit 1C-22 for annular pumping of fluids occurring as a result of future drilling operations on 1C pad. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic. 1C-22 PERMIT IT. DOC Page 7 of 7 J f"~ :7 "~,","~ ,~ " r:p~nrd: 15-Nov-02 j ~'.L/ i:: :" ,t, r ;, ~,i", '~ I Q I \.:J'~ J ;¡ ',~ ConocoPhillips Alaska. Inc. Pad 1C 22 slot #22 Kuparuk River Unit North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref Our ref License 1C-22 Version #1 prop5318 Date printed Date created Last revised 14-Nov-2002 31-0ct·2002 14-Nov-2002 Field is centred on n70 16 18.576.w150 5 56.536 Structure is centred on n70 19 45.173.w149 30 19.124 Slot location is n70 19 29.509.w149 29 40.351 Slot Grid coordinates are N 5968646.500. E 562334.800 Slot local coordinates are 1592.63 S 1328.39 E Projection type: alaska - Zone 4. Spheroid: Clarke - 1866 Reference North is True North , ) OrJ~/~r' .! , i"~ ìl t.:¡',j' ~,.'." " ,I ) ConocoPhillips Alaska, Inc. PROPOSAL LI STI NG Page 1 Pad 1C,22 Your ref : 1C-22 Version #1 Kuparuk River Unit.North Slope, Alaska Last revised : 14-Nov-2002 Measured Inclin. Azimuth True Vert R E C TAN G U L A R Dogleg Vert Depth Degrees Degrees Depth COO R DIN ATE S Deg/lOOft Sect 0.00 0.00 73.00 0.00 0.00 N 0.00 E 0.00 0.00 250.00 0.00 73.00 250.00 0.00 N 0.00 E 0.00 0.00 KOP 350.00 4.00 73.00 349.92 1.02 N 3.34 E 4.00 3.47 450.00 8.00 73.00 449.35 4.08 N 13.33 E 4.00 13.86 550.00 12.00 73.00 547.81 9.15 N 29.93 E 4.00 31.12 650.00 16.00 73.00 644.82 16.22 N 53.06 E 4.00 55.16 750.00 20.00 73.00 739.91 25.26 N 82.61 E 4.00 85.88 850.00 24.00 73.00 832.61 36.21 N 118.43 E 4.00 123 . 11 950.00 28.00 73.00 922.47 49.02 N 160.34 E 4.00 166.68 1000.00 30.00 73.00 966.20 56.11 N 183.52 E 4.00 190.77 1100.00 33.95 71.78 1051. 01 72 . 16 N 233.97 E 4.00 243.46 1200.00 37.90 70.78 1131. 97 91. 01 N 289.52 E 4.00 301. 95 1300.00 41.87 69.95 1208.69 112.57 N 349.89 E 4.00 365.93 1400.00 45.84 69.23 1280.79 136.74 N 414.81 E 4.00 435.12 1500.00 49.81 68.61 1347.91 163.40 N 483.94 E 4.00 509.16 1600.00 53.79 68.05 1409.74 192.42 N 556.95 E 4.00 587.70 1700.00 57.77 67.55 1465.97 223.66 N 633.49 E 4.00 670.36 1800.00 61.75 67.09 1516.33 256.96 N 713.18 E 4.00 756.72 1900.00 65.73 66.67 1560.57 292.17 N 795.64 E 4.00 846.38 1929.82 66.92 66.55 1572.55 303.01 N 820.71 E 4.00 873.69 EOC 2000.00 66.92 66.55 1600.06 328.71 N 879.93 E 0.00 938.25 2479.33 66.92 66.55 1788.00 504.20 N 1284.45 E 0.00 1379.19 Base Permafrost 2500.00 66.92 66.55 1796 . 11 511.77 N 1301. 90 E 0.00 1398.21 3000.00 66.92 66.55 1992.15 694.83 N 1723.87 E 0.00 1858.17 3500.00 66.92 66.55 2188.19 877.88 N 2145.84 E 0.00 2318.14 4000.00 66.92 66.55 2384.23 1060.94 N 2567.80 E 0.00 2778.10 4500.00 66.92 66.55 2580.27 1244.00 N 2989.77 E 0.00 3238.06 5000.00 66.92 66.55 2776.31 1427.06 N 3411.74 E 0.00 3698.02 5500.00 66.92 66.55 2972.36 1610.12 N 3833.71 E 0.00 4157.98 6000.00 66.92 66.55 3168.40 1793.18 N 4255.68 E 0.00 4617.94 6500.00 66.92 66.55 3364.44 1976.24 N 4677.65 E 0.00 5077.90 7000.00 66.92 66.55 3560.48 2159.30 N 5099.61 E 0.00 5537.86 7500.00 66.92 66.55 3756.52 2342.35 N 5521.58 E 0.00 5997.82 7901. 64 66.92 66.55 3914.00 2489.40 N 5860.54 E 0.00 6367.30 Top West Sak 8000.00 66.92 66.55 3952.56 2525.41 N 5943.55 E 0.00 6457.79 8500.00 66.92 66.55 4148.61 2708.47 N 6365.52 E 0.00 6917.75 8942.24 66.92 66.55 4322.00 2870.38 N 6738.74 E 0.00 7324.57 Base West Sak 9000.00 66.92 66.55 4344.65 2891. 53 N 6787.49 E 0.00 7377.71 9452.33 66.92 66.55 4522.00 3057.14 N 7169.23 E 0.00 7793.82 9 5/8" Casing 9500.00 66.92 66.55 4540.69 3074.59 N 7209.45 E 0.00 7837.67 10000.00 66.92 66.55 4736.73 3257.65 N 7631.42 E 0.00 8297.63 10500.00 66.92 66.55 4932.77 3440.71 N 8053.39 E 0.00 8757.59 11000.00 66.92 66.55 5128.81 3623.77 N 8475.36 E 0.00 9217.55 11500.00 66.92 66.55 5324.86 3806.82 N 8897.33 E 0.00 9677.51 12000.00 66.92 66.55 5520.90 3989.88 N 9319.30 E 0.00 10137.47 12500.00 66.92 66.55 5716.94 4172.94 N 9741.26 E 0.00 10597.44 13000.00 66.92 66.55 5912.98 4356.00 N 10163.23 E 0.00 11057.40 13143.66 66.92 66.55 5969.31 4408.60 N 10284.47 E 0.00 11189.55 Begin Drop 13200.00 65.79 66.55 5991.91 4429.14 N 10331. 82 E ./ 2.00 11241.16 13300.00 63.79 66.55 6034.50 4465.14 N 10414.81 E 2.00 11331.63 All data is in feet unless otherwise stated. Coordinates from slot #22 and TVD from Est RKB (D-141) (88.00 Ft above mean sea level). Bottom hole distance is 12301.73 on azimuth 66.77 degrees from wellhead. Total Dogleg for well path is 89.11 degrees. Vertical section is from wellhead on azimuth 66.78 degrees. , .' ,1 , Calculation uses the minimum curvature method. or" " Presented by Baker Hughes INTEQ I: ,\ 1 ¡,.tt",' ~ ~ t.. ~'~, .:) \ i ~ ~ !~ ~/ .,1 ~ '~ ConocoPhillips Alaska, Inc. PROPOSAL LISTING Page 2 Pad lC,22 Your ref : lC-22 Version #1 Kuparuk River Unit,North Slope. Alaska Last revised : 14-Nov-2002 Measured Inclin. Azimuth True Vert R E C TAN G U L A R Dogleg Vert Depth Degrees Degrees Depth COO R DIN ATE S Deg/lOOft Sect 13400.00 61.79 66.55 6080.22 4500.54 N 10496.40 E 2.00 11420.56 13500.00 59.79 66.55 6129.02 4535.27 N 10576.46 E 2.00 11507.83 13575.75 58.27 66.55 6168.00 4561.12 N 10636.05 E 2.00 11572.78 Top HRZ 13600.00 57.79 66.55 6180.84 4569.31 N 10654.92 E 2.00 11593 .36 13700.00 55.79 66.55 6235.61 4602.61 N 10731. 67 E 2.00 11677 . 02 13800.00 53.79 66.55 6293.27 4635.12 N 10806.62 E 2.00 11758.72 13900.00 51.79 66.55 6353.74 4666.82 N 10879.68 E 2.00 11838.35 13929.33 51. 20 66.55 6372.00 4675.95 N 10900.74 E 2.00 11861.31 Base HRZ 14000.00 49.79 66.55 6416.95 4697.65 N 10950.76 E 2.00 11915.83 14100.00 47.79 66.55 6482.83 4727.59 N 11019. n E 2.00 11991.05 14186.63 46.06 66.55 6542.00 4752.78 N 110n .81 E 2.00 12054.33 Top Kuparuk 14200.00 45.79 66.55 6551.30 4756.60 N 11086.62 E 2.00 12063.93 14239.43 45.00 66.55 6578.99 4767.77 N 11112.38 E 2.00 12092.01 Target - EOD 14239.45 45.00 66.55 6579.00 4767.78 N 11112.39 E 2.00 12092.02 lC-A C4 TGT RVSD 13 NOV 02 14297.43 45.00 66.55 6620.00 4784.10 N 11150.00 E 0.00 12133.02 C-3 14332.79 45.00 66.55 6645.00 4794.05 N 11172.94 E 0.00 12158.02 C-2 14400.67 45.00 66.55 6693.00 4813.15 N 11216.97 E 0.00 12206.02 C-l 14436.02 45.00 66.55 6718.00 4823.10 N 11239.91 E 0.00 12231. 02 Top B 14500.00 45.00 66.55 6763.24 4841.11 N 11281.41 E 0.00 12276.26 14536.02 45.00 66.55 6788.71 4851.25 N 11304. n E 0.00 12301.73 TD, 7" CSG Pt. All data is in feet unless otherwise stated. Coordinates from slot #22 and TVD from Est RKB (D-141) (88.00 Ft above mean sea level). Bottom hole distance is 12301.73 on azimuth 66.77 degrees from wellhead. Total Dogleg for wellpath is 89.11 degrees. Vertical section is from wellhead on azimuth 66.78 degrees. Calculation uses the minimum curvature method.-' 1 Presented by Baker Hughes INTEQ û ~ J '<.., ~ ,j ,; L ConocoPhillips Alaska, Inc. Pad 1C.22 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : lC-22 Version #1 Last revised : 14-Nov-2002 Comments in wellpath -------- ---------- MD TVD Rectangular Coords. Comment --........-----........---...............----...........--------......----............---............-----...........----..............-....-..........--.............----.. 250.00 250.00 0.00 N 0.00 E KOP 1929.82 1572.55 303.01 N 820.71 E EOC 2479.33 1788.00 504.20 N 1284.45 E Base Permafrost 7901.64 3914.00 2489.40 N 5860.54 E Top West Sak 8942.24 4322.00 2870.38 N 6738.74 E Base West Sak 9452.33 4522.00 3057.14 N 7169.23 E 9 5/8" Casing 13143.66 5969.31 4408.60 N 10284.47 E Begin Drop 13575.75 6168.00 4561.12 N 10636.05 E Top HRZ 13929.33 6372.00 4675.95 N 10900.74 E Base HRZ 14186.63 6542.00 4752.78 N 11077.81 E Top Kuparuk 14239.43 6578.99 4767.77 N 11112.38 E Target - EOD 14239.45 6579.00 4767.78 N 11112.39 E 1C-A C4 TGT RVSD 13 NOV 02 14297.43 6620.00 4784.10 N 11150.00 E C-3 14332.79 6645.00 4794.05 N 11172.94 E C-2 14400.67 6693.00 4813.15 N 11216.97 E C-l 14436.02 6718.00 4823.10 N 11239.91 E Top B 14536.02 6788.71 4851. 25 N 11304.77 E TD. 7" CSG Pt. Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ..........----....--....------.........--..---............------..........-......--.........------......---..--................--........-------..-....-------...... 0.00 0.00 0.00 0.00 O.OON O.OON O.OOE 14536.00 6788.69 O.OOE 9452.33 4522.00 4851.24N 11304.76E 7 CSG 3057.14N 7169.23E 9 5/8 SURFACE Targets associated with this wellpath -------------- ------------ Target name Geographic Location T.V.D. Rectangular Coordinates Revised ....-............----..............---............-----........---..------....---..........-------....--.......--.....--..........----......-----..........-..---.... lC-A C4 TGT RVSD 13 573407.000,5973504.000,0.0000 6579.00 lC-A Hardline Pt#l 2 573325.000,5974150.000,0.0000 6500.00 lC-A Hardline Pt#2 2 573624.000.5973916.000.0.0000 6500.00 1C-A Hardline Pt#3 2 574137.000.5973550.000,0.0000 6500.00 lC-A Hardline Pt#4 2 574460.000.5973440.000,0.0000 6500.00 lC-A Hardline Pt#5 2 574480.000,5973124.000.0.0000 6500.00 4767.78N 5414.49N 5178.04N 4807.85N 4695.21N 4379.03N 11112.39E 17-Sep-2002 11035.64E 31-0ct-2002 11332.75E 31-0ct-2002 11842.81E 31-0ct-2002 12164.94E 31-0ct-2002 12182.37E 31-0ct-2002 l(f,: . I~ \,(.i' \;,.' ' .: "ÌI1Ø ) ConocoPhillips Alaska. Inc. Pad lC 22 slot #22 Kuparuk River Unit North Slope. Alaska PRO P 0 S ALL 1ST I N G by Baker Hughes INTEQ Your ref : lC-22 Version #1 Our ref : prop5318 License Date printed Date created Last revised 14-Nov-2002 31-0ct·2002 14-Nov-2002 Field is centred on n70 16 18.576.wI50 5 56.536 Structure is centred on n70 19 45.173,wI49 30 19.124 Slot location is n70 19 29.509.wI49 29 40.351 Slot Grid coordinates are N 5968646.500. E 562334.800 Slot local coordinates are 1592.63 S 1328.39 E Projection type: alaska· Zone 4. Spheroid: Clarke· 1866 Reference North is True North ! '<" ~ ,J :J 1 ~J ) ) ConocoPhillips Alaska, Inc. PROPOSAL LISTING Page 1 Pad 1C.22 Your ref : 1C-22 Version #1 Kuparuk River Unit,North Slope, Alaska Last revised: 14-Nov-2002 Measured Inclin Azimuth True Vert R E C TAN G U L A R G RID COO R 0 S G E 0 G RAP H I C Depth Degrees Degrees Depth COO R 0 I N ATE S Easting Northing COO R 0 I N ATE S 0.00 0.00 73.00 0.00 O.OON O.OOE 562334.80 5968646.50 n70 19 29.51 w149 29 40.35 250.00 0.00 73.00 250.00 O.OON O.OOE 562334.80 5968646.50 n70 19 29.51 w149 29 40.35 350.00 4.00 73.00 349.92 1.02N 3.34E 562338.13 5968647.55 n70 19 29.52 w149 29 40.25 450.00 8.00 73.00 449.35 4.08N 13.33E 562348.10 5968650.68 n70 19 29.55 w149 29 39.96 550.00 12.00 73.00 547.81 9.15N 29.93E 562364.66 5968655.89 n70 19 29.60 w149 29 39.48 650.00 16.00 73.00 644.82 16.22N 53.06E 562387.73 5968663.15 n70 19 29.67 w149 29 38.80 750.00 20.00 73.00 739.91 25.26N 82.61E 562417.19 5968672 .42 n70 19 29.76 w149 29 37.94 850.00 24.00 73.00 832.61 36.21N 118.43E 562452.92 5968683.66 n70 19 29.86 w149 29 36.89 950.00 28.00 73.00 922.47 49.02N 160.34E 562494.72 5968696.82 n70 19 29.99 w149 29 35.67 1000.00 30.00 73.00 966.20 56.11N 183.52E 562517.84 5968704.09 n70 19 30.06 w149 29 34.99 1100.00 33.95 71.78 1051.01 72.16N 233.97E 562568.15 5968720.55 n70 19 30.22 w149 29 33.52 1200.00 37.90 70.78 1131.97 91. 01N 289.52E 562623.54 5968739.85 n70 19 30.40 w149 29 31.90 1300.00 41.87 69.95 1208.69 112.57N 349.89E 562683.73 5968761.90 n70 19 30.61 w149 29 30.14 1400.00 45.84 69.23 1280.79 136.74N 414.81E 562748.44 5968786.60 n70 19 30.85 w149 29 28.24 1500.00 49.81 68.61 1347.91 163.40N 483.94E 562817.35 5968813.82 n70 19 31.11 w149 29 26.22 1600.00 53.79 68.05 1409.74 192.42N 556.95E 562890.12 5968843.43 n70 19 31.40 w149 29 24.09 1700.00 57.77 67.55 1465.97 223.66N 633.49E 562966.39 5968875.28 n70 19 31.71 w149 29 21.86 1800.00 61.75 67.09 1516.33 256.96N 713.18E 563045.80 5968909.23 n70 19 32.03 w149 29 19.53 1900.00 65.73 66.67 1560.57 292.17N 795.64E 563127.96 5968945.10 n70 19 32.38 w149 29 17.12 1929.82 66.92 66.55 1572.55 303.01N 820.71E 563152.94 5968956.15 n70 19 32.49 w149 29 16.39 2000.00 66.92 66.55 1600.06 328.71N 879.93E 563211.95 5968982.32 n70 19 32.74 w149 29 14.66 2479.33 66.92 66.55 1788.00 504.20N 1284.45E 563614.99 5969161.07 n70 19 34.46 w149 29 02.85 2500.00 66.92 66.55 1796.11 511.77N 1301. 90E 563632.37 5969168.78 n70 19 34.54 w149 29 02.35 3000.00 66.92 66.55 1992.15 694.83N 1723.87E 564052.80 5969355.25 n70 19 36.34 w149 28 50.03 3500.00 66.92 66.55 2188.19 877.88N 2145.84E 564473.22 5969541.72 n70 19 38.14 w149 28 37.71 4000.00 66.92 66.55 2384.23 1060.94N 2567.80E 564893.65 5969728.18 n70 19 39.93 w149 28 25.38 4500.00 66.92 66.55 2580.27 1244.00N 2989.77E 565314.08 5969914.65 n70 19 41.73 w149 28 13.06 5000.00 66.92 66.55 2776.31 1427.06N 3411.74E 565734.50 5970101.11 n70 19 43.53 w149 28 00.74 5500.00 66.92 66.55 2972.36 1610.12N 3833.71E 566154.93 5970287.58 n70 19 45.33 w149 27 48.42 6000.00 66.92 66.55 3168.40 1793.18N 4255.68E 566575.35 5970474.04 n70 19 47.12 w149 27 36.10 6500.00 66.92 66.55 3364.44 1976.24N 4677.65E 566995.78 5970660.51 n70 19 48.92 w149 27 23.77 7000.00 66.92 66.55 3560.48 2159.30N 5099.61E 567416.20 5970846.97 n70 19 50.72 w149 27 11.45 7500.00 66.92 66.55 3756.52 2342.35N 5521.58E 567836.63 5971033.44 n70 19 52.52 w149 26 59.12 7901. 64 66.92 66.55 3914.00 2489.40N 5860.54E 568174.35 5971183.22 n70 19 53.96 w149 26 49.22 8000.00 66.92 66.55 3952.56 2525.41N 5943.55E 568257.05 5971219.90 n70 19 54.31 w149 26 46.80 8500.00 66.92 66.55 4148.61 2708.4 7N 6365.52E 568677.48 5971406.37 n70 19 56.11 w149 26 34.47 8942.24 66.92 66.55 4322.00 2870.38N 6738.74E 569049.34 5971571.29 n70 19 57.70 w149 26 23.57 9000.00 66.92 66.55 4344.65 2891.53N 6787.49E 569097.91 5971592.84 n70 19 57.90 w149 26 22.14 9452.33 66.92 66.55 4522.00 3057.14N 7169.23E 569478.25 5971761.52 n70 19 59.53 w149 26 10.99 9500.00 66.92 66.55 4540.69 3074.59N 7209.45E 569518.33 5971779.30 n70 19 59.70 w149 26 09.82 10000.00 66.92 66.55 4736.73 3257.65N 7631.42E 569938.76 5971965.77 n70 20 01. 50 w149 25 57.49 10500.00 66.92 66.55 4932.77 3440.71N 8053.39E 570359.18 5972152.23 n70 20 03.29 w149 25 45.16 11000.00 66.92 66.55 5128.81 3623.77N 8475.36E 570779.61 5972338.70 n70 20 05.09 w149 25 32.83 11500.00 66.92 66.55 5324.86 3806.82N 8897.33E 571200.03 5972525.16 n70 20 06.88 w149 25 20.50 12000.00 66.92 66.55 5520.90 3989.88N 9319.30E 571620.46 5972711.63 n70 20 08.68 w149 25 08.17 12500.00 66.92 66.55 5716.94 4172.94N 9741. 26E 572040.89 5972898.09 n70 20 10.47 w149 24 55.84 13000.00 66.92 66.55 5912.98 4356.00N 10163.23E 572461. 31 5973084.56 n70 20 12.26 w149 24 43.51 13143.66 66.92 66.55 5969.31 4408.60N 10284.47E 572582. 11 5973138.13 n70 20 12.78 w149 24 39.97 13200.00 65.79 66.55 5991.91 4429.14N 10331. 82E 572629.28 5973159.06 n70 20 12.98 w149 24 38.58 13300.00 63.79 66.55 6034.50 4465.14N 10414.81E 572711.97 5973195.73 n70 20 13.33 w149 24 36.16 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #22 and TVD from Est RKB (0-141) (88.00 Ft above mean sea level). Bottom hole distance is 12301.73 on azimuth 66.77 degrees from wellhead. Total Dogleg for wellpath is 89.11 degrees. Vertical section is from wellhead on azimuth 66.78 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid L "' oj -{",v'li ,(¡. ./ } I Presented by Baker Hughes INTEQ ) ConocoPhillips Alaska, Inc. PROPOSAL LISTING Page 2 Pad 1C.22 Your ref : 1C-22 Version #1 Kuparuk River Unit,North Slope, Alaska Last revised: 14-Nov-2002 Measured Inclin Azimuth True Vert R E C TAN G U L A R G RID COO R D S G E 0 G RAP H I C Depth Degrees Degrees Depth COO R DIN ATE S Easting Northing COO R DIN ATE S 13400.00 61.79 66.55 6080.22 4500.54N 10496.40E 572793.26 5973231.78 n70 20 13.68 w149 24 33.77 13500.00 59.79 66.55 6129.02 4535.27N 10576.46E 572873.03 5973267.17 n70 20 14.02 w149 24 31.43 13575.75 58.27 66.55 6168.00 4561.12N 10636.05E 572932.40 5973293.49 n70 20 14.27 w149 24 29.69 13600.00 57.79 66.55 6180.84 4569.31N 10654.92E 572951.20 5973301.84 n70 20 14.35 w149 24 29.14 13700.00 55.79 66.55 6235.61 4602.61N 10731.67E 573027.67 5973335.75 n70 20 14.68 w149 24 26.90 13800.00 53.79 66.55 6293.27 4635.12N 10806.62E 573102.35 5973368.87 n70 20 15.00 w149 24 24.71 13900.00 51.79 66.55 6353.74 4666.82N 10879.68E 573175.14 5973401.16 n70 20 15.31 w149 24 22.57 13929.33 51. 20 66.55 6372.00 4675.95N 10900.74E 573196.12 5973410.46 n70 20 15.40 w149 24 21.95 14000.00 49.79 66.55 6416.95 4697.65N 10950.76E 573245.96 5973432.57 n70 20 15.61 w149 24 20.49 14100.00 47.79 66.55 6482.83 4727.59N 11019.77E 573314.71 5973463.07 n70 20 15.91 w149 24 18.48 14186.63 46.06 66.55 6542.00 4752.78N 11077 .81E 573372.55 5973488.72 n70 20 16.15 w149 24 16.78 14200.00 45.79 66.55 6551.30 4756.60N 11086.62E 573381.33 5973492.61 n70 20 16.19 w149 24 16.52 14239.43 45.00 66.55 6578.99 4767.77N 11112.38E 573406.99 5973503.99 n70 20 16.30 w149 24 15.77 14239.45 45.00 66.55 6579.00 4767.78N 11112.39E 573407.00 5973504.00 n70 20 16.30 w149 24 15.77 14297.43 45.00 66.55 6620.00 4784. ION 11150.00E 573444.4 7 5973520.62 n70 20 16.46 w149 24 14.67 14332.79 45.00 66.55 6645.00 4794.05N 11172.94E 573467.33 5973530.76 n70 20 16.56 w149 24 14.00 14400.67 45.00 66.55 6693.00 4813.15N 11216.97E 573511.20 5973550.22 n70 20 16.74 w149 24 12.71 14436.02 45.00 66.55 6718.00 4823.10N 11239.91E 573534.05 5973560.35 n70 20 16.84 w149 24 12.04 14500.00 45.00 66.55 6763.24 4841.11N 11281.41E 573575.40 5973578.69 n70 20 17.02 w149 24 10.83 14536.02 45.00 66.55 6788.71 4851. 25N 11304.77E 573598.68 5973589.02 n70 20 17.12 w149 24 10.15 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #22 and TVD from Est RKB (D-141) (88.00 Ft above mean sea level). Bottom hole distance is 12301.73 on azimuth 66.77 degrees from wellhead. Total Dogleg for well path is 89.11 degrees. Vertical section is from wellhead on azimuth 66.78 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid L ',.\,;,~"" ,1 I ; '}, ) Presented by Baker Hughes INTEQ ) ConocoPhillips Alaska, Inc. Pad 1C,22 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 1C-22 Version #1 Last revised: 14-Nov-2002 MD TVD Rectangular Coords. Comments in wellpath Comment --------...........-----..-----------......----...----........--------..............--...-...............------.......-------........----...........----- 250.00 250.00 O.OON O.OOE KOP 1929.82 1572.55 303.01N 820.71E EOC 2479.33 1788.00 504.20N 1284.45E Base Permafrost 7901. 64 3914.00 2489.40N 5860.54E Top West Sak 8942.24 4322.00 2870.38N 6738.74E Base West Sak 9452.33 4522.00 3057.14N 7169.23E 9 5/8" Casing 13143.66 5969.31 4408.60N 10284.47E Begin Drop 13575.75 6168.00 4561.12N 10636.05E Top HRZ 13929.33 6372.00 4675.95N 10900.74E Base HRZ 14186.63 6542.00 4752.78N 110n .81E Top Kuparuk 14239.43 6578.99 4767.nN 11112.38E Target - EGD 14239.45 6579.00 4767.78N 11112.39E 1C-A C4 TGT RVSD 13 NOV 02 14297.43 6620.00 4784. ION 11150.00E C-3 14332.79 6645.00 4794.05N 11172.94E C-2 14400.67 6693.00 4813.15N 11216.97E C-1 14436.02 6718.00 4823.10N 11239.91E Top B 14536.02 6788.71 4851. 25N 11304. nE TD, 7" CSG Pt. Casing positions in string 'A' ------------------------------ -------- Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing --....-.................---.....................-......--....--...-------.........----------........-----......---.....-----......-..--...--........-------........... 0.00 0.00 0.00 0.00 O.OON O.OON O.OOE 14536.00 6788.69 O.OOE 9452.33 4522.00 4851.24N 11304.76E 7 CSG 3057.14N 7169.23E 9 5/8 SURFACE Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised .....------............-----..............--------............----------...........----.........-........---...................--...................---...........---..----- 1C-A C4 TGT RVSD 13 573407.000,5973504.000,0.0000 6579.00 1C-A Hardline Pt#l 2 573325.000,5974150.000,0.0000 6500.00 1C-A Hardline Pt#2 2 573624.000,5973916.000,0.0000 6500.00 1C·A Hardline Pt#3 2 574137.000,5973550.000,0.0000 6500.00 1C-A Hardline Pt#4 2 574460.000,5973440.000,0.0000 6500.00 1C-A Hardline Pt#5 2 574480.000,5973124.000.0.0000 6500.00 4767.78N 5414.49N 5178.04N 4807.85N 4695.21N 4379.03N 11112.39E 17-Sep-2002 11035.64E 31-0ct-2002 11332.75E 31-0ct-2002 11842.81E 31-0ct-2002 12164.94E 31-0ct-2002 12182.37E 31-0ct-2002 O ~, ~I ' ~ (:'. /,,1 'I:; ,,·l ~., ~ \.' ~ L } Baker Hughes INTEQ Anticollision Report Company: ConocoPhillips Alaska, Inc. Field: Kuparuk River Unit Reference Site: Pad 1c Reference Well: 22 Reference Wellpat~C-22 Vers# 1 NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation MethodMD Interval: 100.00 ft Depth Range: 0.00 to 14536.02 ft Maximum Radius6000.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 9252.33 4443.58 9.625 12.250 9 5/8" 14536.02 6788.71 7.000 8.500 7" Plan: 1C-22 Vers# 1 Principal: Yes Summary <---------------------- Offset Well pa th ----------------------> Site Well Well path Pad 1 C Pad 1C Pad 1 C Pad 1C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1C Pad 1C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1c Pad 1C Pad 1 C Pad 1 C Pad 1 C Pad 1C Pad 1C Pad 1C Pad 1 C Pad 1C Pad 1c Pad 1C Pad 1 C Pad 1 C Pad 1 C Pad 1C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1C Pad 1 C 01 02 03 04 05 06 07 08 09 10 102 102 104 104 104 109 109 111 11 117 119 121 12 123 125 127 131 13 133 135 14 15 16 17 18 23 23 24 25 26 27 b (PB) c (B) d (19) e (129) F (IB) g 1 C-01 V2 1 C-02 VO 1 C-03 VO 1 C-04 VO 1 C-05 VO 1 C-06 VO 1 C-07 VO 1 C-08 VO 1 C-09 VO 1C-10 VO 1C-102 VO 1C-102L 1 VO 1 C-1 04 VO 1C-104L 1 V1 1C-104PB1 VO 1C-109 VO 1C-109L 1 VO 1 C-111 VO 1C-11 VO 1C-117 VO 1C-119 VO 1C-121 VO 1C-12 VO 1C-123 VO 1C-125 VO 1C-127 VO 1 C-1 31 VO 1C-13 VO 1C-133 VO 1C-135 VO 1C-14 VO 1C-15 VO 1C-16 VO 1C-17 VO 1C-18 VO 1 C-23A V2 1 C-23PB 1 VO 1 C-24 VO 1 C-25 VO 1 C-26 VO 1 C-27 V1 1 C-PB Vers#O.a VO Plan 1 C-B Vers#1 VO Plan: 1 1C-D(19) Vers#O.a VO P 1C-e (Y14-129) Vers#5 1C-IB Vers#1 VO Plan: 1C-g (WestSk) VersO.a Date: 11/14/2002 Time: 14:47:16 Page: Co-ordinate(NE) Reference: Well: 22, True North Vertical (TVD) Reference: Wellhead(88') 88.0 Reference: Error Model: Scan Method: Error Surface: Db: Oracle Plan: 1 C-22 Vers# 1 & NOT PLANNED PROGRA ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Date Composed: Version: Tied-to: 11/7/2002 18 From Surface Reference Offset Ctr-Ctr No-Go Allowable MD MD DistanceArea Deviation war~ ft ft ft ft ft 399.28 400.00 129.86 5.74 124.13 Pass: Major Risk 297.43 300.00 85.71 4.43 81.28 Pass: Major Risk 295.19 300.00 163.22 4.40 158.82 Pass: Major Risk 293.16 300.00 272.65 4.38 268.27 Pass: Major Risk 291.28 300.00 388.77 4.36 384.41 Pass: Major Risk 289.54 300.00 507.61 4.34 503.27 Pass: Major Risk 287.96 300.00 626.04 4.32 621.72 Pass: Major Risk 286.48 300.00 747.46 4.30 743.16 Pass: Major Risk 283.76 300.00 813.72 5.92 807.80 Pass: Major Risk 285.37 300.00 665.59 4.29 661.30 Pass: Major Risk 199.99 200.00 748.14 3.32 744.81 Pass: Major Risk 199.99 200.00 748.14 3.32 744.81 Pass: Major Risk 284.78 300.00 720.45 4.27 716.18 Pass: Major Risk 284.78 300.00 720.45 4.27 716.18 Pass: Major Risk 284.78 300.00 720.45 4.27 716.18 Pass: Major Risk 100.00 100.00 637.39 1.75 635.64 Pass: Major Risk 100.00 100.00 637.39 1.75 635.64 Pass: Major Risk 200.00 200.00 609.93 3.25 606.68 Pass: Major Risk 286.09 300.00 781.83 4.39 777.44 Pass: Major Risk 287.17 300.00 530.49 4.50 525.99 Pass: Major Risk 287.54 300.00 504.25 4.28 499.98 Pass: Major Risk 287.91 300.00 479.00 4.40 474.61 Pass: Major Risk 358.73 400.00 768.15 5.60 762.57 Pass: Major Risk 288.27 300.00 455.02 4.44 450.58 Pass: Major Risk 288.65 300.00 430.42 4.49 425.93 Pass: Major Risk 200.00 200.00 407.56 3.13 404.43 Pass: Major Risk 199.99 200.00 364.07 3.11 360.97 Pass: Major Risk 289.89 300.00 482.69 4.33 478.37 Pass: Major Risk 290,31 300.00 344.26 4.44 339.83 Pass: Major Risk 100.00 100.00 326.26 1.74 324.52 Pass: Major Risk 2111.02 2200.00 122.96 109.99 15.36 Pass: Major Risk 390.57 400.00 96.80 5.98 90.88 Pass: Major Risk 290.29 300.00 455.82 4.57 451.25 Pass: Major Risk 200.00 200.00 790.21 3.20 787.01 Pass: Major Risk 292.02 300.00 339.23 4.37 334.87 Pass: Major Risk 393.18 400.00 84.14 5.97 78.20 Pass: Major Risk 393.18 400.00 84.14 5.97 78.20 Pass: Major Risk 298.07 300.00 84.12 5.48 78.64 Pass: Major Risk 298.93 300.00 99.37 4.47 94.93 Pass: Major Risk 299.31 300.00 108.58 4.49 104.12 Pass: Major Risk 692.49 700.00 118.86 12.50 106.58 Pass: Major Risk 298.30 300.00 80.63 4.94 75.69 Pass: Major Risk 297.44 300.00 120.72 4.93 115.79 Pass: Major Risk 602.41 600.00 31.81 10.14 21.67 Pass: Major Risk 710.52 700.00 71.75 13.03 58.90 Pass: Major Risk 299.09 300.00 40.27 4.94 35.33 Pass: Major Risk 296.60 300.00 160.19 4.93 155.27 Pass: Major Risk n r: "" ~~ ! \~} ~'r,:...1,:t1~ ) ) Baker Hughes INTEQ Anticollision Report Company: ConocoPhillips Alaska, Inc. Field: Kuparuk River Unit Reference Site: Pad 1C Reference Well: 22 Reference Wellpat":C-22 Vers# 1 Summary <---------------------- Offset Wellpath ----------------------> Site Well Wellpath Pad 1C Pad 1C Pad 1C h WS-1 WS-24 1 C-h (WestSk) VersOJ WS 1 VO WS-24 VO Date: 11/14/2002 Time: 14:47:16 Page: 2 Co-ordinate(NE) Reference: Well: 22, True North Vertical (TVD) Reference: Wellhead(88') 88.0 Db: Oracle Reference Offset Ctr-Ctr No-Go Allowable MD MD Distance Area Deviation Warning ft ft ft ft ft 295.04 300.00 240.22 4.91 235.31 Pass: Major Risk Out of range 11670.83 5900.00 138.95 30.81 138.95 Pass: Minor 1/200 n, Cì :~ l: if;~? f~ .f /. ,.,$ k ~ .if ~!,¡ i ,I! :,,,' ",.jl'~1 " ~.~~t:;~· M ii. M \.~., ~ I ,IJ :' 'I "l~/,\,,:, } Baker Hughes INTEQ Error Ellipse Survey Report Company: ConocoPhillips Alaska, Inc. Fie]d: Kuparuk River Unit Site: Pad 1C Well: 22 Wellpath: 1C-22 Vers# 1 Field: Kuparuk River Unit North Slope, Alaska USA Map SystenUS State Plane Coordinate System 1927 Geo DatumNAD27 (Clarke 1866) Sys Datum:Mean Sea Level Date: 11/14/2002 Time: 14:51 :46 Page: Co-ordinate(NE) Reference: Well: 22, True North Vertical (TVD) Reference: Wellhead(88') 88.0 Section (VS) Reference: Well (0.00N,O.00E,66.78Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 Site: Pad 1C North Slope, Alaska Site Position: Northing: 5970228.13 ft Latitude: 70 19 45.173 N From: Map Easting: 560993.64 ft Longitude: 149 30 19.124 W Position Uncertainty: 0.00 ft North Reference: True Ground Leve]: 60.50 ft Grid Convergence: 0.24 deg Well: 22 Slot Name: Well Position: +N/-S -1592.63 ft Northing: 5968646.50 ft Latitude: 70 19 29.508 N +E/-W 1328.39 ft Easting : 562334.80 ft Longitude: 149 29 40.351 W Position Uncertainty: 0.00 ft Wellpath: 1C-22 Vers# 1 Drilled From: Surface Tie-on Depth: 0.00 ft Current Datum: Wellhead(88') Height 88.00 ft Above System Datum: Mean Sea Level Magnetic Data: 11 /7/2002 Declination: 25.63 deg Fie]d Strength: 57496 nT Mag Dip Angle: 80.74 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 66.78 Plan: 1C-22 Vers# 1 Date Composed: 11/7/2002 Version: 18 Pri ncipa]: Yes Tied-to: From Surface Position uncertainty and bias at survey station All uncertainties 31.6 standard deviatioßighside-----> Latera]-------> Vertical------> Magn. Semi-majoSemi-minor MD Incl Azim TVD Unc. Bias Unc. Bias Unc. Bias of Bias Unc. Unc. Azimutli'oo] ft deg deg ft ft ft ft ft ft ft ft ft ft deg 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE UNE 100.00 0.00 0.00 100.00 0.11 0.00 0.11 0.00 2.96 0.00 0.00 0.11 0.11 0.00 MWD 200.00 0.00 0.00 200.00 0.40 0.00 0.40 0.00 2.96 0.00 0.00 0.40 0.40 0.00 MWD 300.00 2.00 73.00 299.99 0.64 0.00 0.64 0.00 2.97 0.01 0.01 0.64 0.64 135.00 MWD 400.00 6.00 73.00 399.73 0.82 0.00 0.85 0.00 2.96 0.02 0.02 0.86 0.84 103.40 MWD 500.00 10.00 73.00 498.73 1.07 0.00 1.30 0.01 2.95 0.03 0.03 1.30 1.14 80.22 MWD 600.00 14.00 73.00 596.53 1.35 -0.01 2.03 0.03 2.92 0.04 0.05 2.03 1.49 76.55 MWD 700.00 18.00 73.00 692.63 1.67 -0.01 3.04 0.06 2.89 0.06 0.09 3.04 1.86 75.31 MWD 800.00 22.00 73.00 786.58 2.03 -0.01 4.33 0.11 2.85 0.08 0.14 4.33 2.27 74.71 MWD 900.00 26.00 73.00 877.92 2.43 -0.02 5.89 0.18 2.82 0.10 0.21 5.89 2.70 74.36 MWD 1000.00 30.00 73.00 966.20 2.86 -0.03 7.72 0.28 2.80 0.12 0.30 7.72 3.16 74.12 MWD 1100.00 33.95 71.78 1051.01 3.35 -0.04 9.81 0.40 2.82 0.14 0.42 9.81 3.63 73.83 MWD 1200.00 37.90 70.78 1131.97 3.87 -0.06 12.13 0.54 2.90 0.16 0.56 12.14 4.12 73.40 MWD 1300.00 41.87 69.95 1208.69 4.41 -0.08 14.69 0.71 3.04 0.18 0.73 14.71 4.61 72.90 MWD 1400.00 45.84 69.24 1280.79 4.98 -0.10 17.48 0.90 3.28 0.20 0.92 17.50 5.10 72.39 MWD 1500.00 49.81 68.62 1347.91 5.57 -0.12 20.47 1.12 3.61 0.22 1.14 20.50 5.58 71.90 MWD 1600.00 53.79 68.06 1409.74 6.16 -0.14 23.66 1.36 4.04 0.24 1.38 23.69 6.05 71.42 MWD 1700.00 57.77 67.56 1465.97 6.77 -0.16 27.01 1.62 4.57 0.26 1.65 27.05 6.49 70.97 MWD 1800.00 61.75 67.11 1516.33 7.37 -0.18 30.51 1.91 5.18 0.27 1.93 30.56 6.90 70.55 MWD 1900.00 65.73 66.68 1560.57 7.96 -0.21 34.13 2.22 5.87 0.29 2.24 34.19 7.28 70.15 MWD 2000.00 66.92 66.56 1600.06 8.74 -0.21 37.85 2.53 6.61 0.30 2.56 37.90 7.61 69.79 MWD 2100.00 66.92 66.56 1639.27 9.60 -0.21 41.60 2.85 7.40 0.31 2.88 41.65 7.93 69.49 MWD 2200.00 66.92 66.56 1678.47 10.46 -0.21 45.36 3.17 8.19 0.32 3.20 45.40 8.24 69.24 MWD 2300.00 66.92 66.56 1717.68 11.32 -0.21 49.12 3.49 8.99 0.34 3.52 49.16 8.56 69.03 MWD 2400.00 66.92 66.56 1756.89 12.19 -0.21 52.89 3.81 9.78 0.35 3.84 52.93 8.88 68.86 MWD C') ~.~. J .,.., .'",:" .1 4 ø~\~'J I( Ñ' ";~ ') ) Baker Hughes INTEQ Error Ellipse Survey Report Company: ConocoPhillips Alaska, Inc. Date: 11/14/2002 Time: 14:51 :46 Page: 2 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 22, True North Site: Pad 1C Vertical (TVD) Reference: Wellhead(88') 88.0 Well: 22 Section (VS) Reference: Well (0.00N,O.00E,66.78Azi) Wellpath: 1C-22 Vers# 1 Survey Calculation Method: Minimum Curvature Db: Oracle Position uncertainty and bias at survey station All uncertainties 31.6 standard deviatioilighside-----> Lateral----..:--> Vertical------> Magn. Semi-majo8emi-minor MD Incl Azim TVD Unc. Bias Unc. Bias Unc. Bias of Bias Unc. Unc. Azimutli'ool ft deg deg ft ft ft ft ft ft ft ft ft ft deg 2500.00 66.92 66.56 1796.10 13.06 -0.21 56.66 4.13 10.58 0.37 4.16 56.70 9.20 68.70 MWD 2600.00 66.92 66.56 1835.31 13.93 -0.21 60.43 4.45 11.38 0.38 4.48 60.46 9.52 68.57 MWD 2700.00 66.92 66.56 1874.52 14.80 -0.21 64.20 4.77 12.18 0.40 4.80 64.24 9.85 68.45 MWD 2800.00 66.92 66.56 1913.72 15.68 -0.21 67.98 5.09 12.99 0.41 5.12 68.01 10.17 68.35 MWD 2900.00 66.92 66.56 1952.93 16.55 -0.21 71.76 5.41 13.79 0.43 5.44 71.79 10.50 68.26 MWD 3000.00 66.92 66.56 1992.14 17.42 -0.21 75.53 5.73 14.60 0.44 5.77 75.56 10.83 68.18 MWD 3100.00 66.92 66.56 2031.35 18.30 -0.21 79.31 6.05 15.40 0.46 6.09 79.34 11.16 68.10 MWD 3200.00 66.92 66.56 2070.56 19.17 -0.21 83.09 6.37 16.21 0.48 6.41 83.12 11 .49 68.03 MWD 3300.00 66.92 66.56 2109.77 20.05 -0.21 86.88 6.69 17.01 0.49 6.73 86.90 11.83 67.97 MWD 3400.00 66.92 66.56 2148.97 20.92 -0.21 90.66 7.01 17.82 0.51 7.05 90.68 12.16 67.92 MWD 3500.00 66.92 66.56 2188.18 21.80 -0.21 94.44 7.32 18.62 0.53 7.38 94.46 12.50 67.86 MWD 3600.00 66.92 66.56 2227.39 22.68 -0.21 98.22 7.64 19.43 0.55 7.70 98.25 12.83 67.82 MWD 3700.00 66.92 66.56 2266.60 23.55 -0.21 102.01 7.96 20.24 0.57 8.02 102.03 13.17 67.77 MWD 3800.00 66.92 66.56 2305.81 24.43 -0.21 105.79 8.28 21.05 0.59 8.34 105.81 13.50 67.73 MWD 3900.00 66.92 66.56 2345.02 25.31 -0.21 109.58 8.60 21.85 0.61 8.67 109.60 13.84 67.69 MWD 4000.00 66.92 66.56 2384.23 26.19 -0.21 113.36 8.92 22.66 0.63 8.99 113.38 14.18 67.66 MWD 4100.00 66.92 66.56 2423.43 27.06 -0.21 117.15 9.24 23.47 0.65 9.31 117.16 14.52 67.62 MWD 4200.00 66.92 66.56 2462.64 27.94 -0.21 120.93 9.56 24.28 0.67 9.64 120.95 14.86 67.59 MWD 4300.00 66.92 66.56 2501.85 28.82 -0.21 124.72 9.88 25.09 0.69 9.96 124.73 15.20 67.56 MWD 4400.00 66.92 66.56 2541.06 29.70 -0.21 128.50 10.20 25.89 0.71 10.29 128.52 15.54 67.54 MWD 4500.00 66.92 66.56 2580.27 30.58 -0.21 132.29 10.52 26.70 0.74 10.61 132.31 15.88 67.51 MWD 4600.00 66.92 66.56 2619.48 31 .45 -0.21 136.07 10.84 27.51 0.76 10.93 136.09 16.22 67.49 MWD 4700.00 66.92 66.56 2658.68 32.33 -0.21 139.86 11.16 28.32 0.78 11.26 139.88 16.56 67.46 MWD 4800.00 66.92 66.56 2697.89 33.21 -0.21 143.65 11 .48 29.13 0.81 11.58 143.66 16.90 67.44 MWD 4900.00 66.92 66.56 2737.10 34.09 -0.21 147.43 11.80 29.94 0.83 11.91 147.45 17.24 67.42 MWD 5000.00 66.92 66.56 2776.31 34.97 -0.21 151.22 12.11 30.75 0.85 12.23 151.24 17.58 67.40 MWD 5100.00 66.92 66.56 2815.52 35.85 -0.21 155.01 12.43 31.56 0.88 12.56 155.02 17.93 67.38 MWD 5200.00 66.92 66.56 2854.73 36.73 -0.21 158.79 12.75 32.36 0.90 12.88 158.81 18.27 67.37 MWD 5300.00 66.92 66.56 2893.94 37.61 -0.21 162.58 13.07 33.17 0.93 13.21 162.60 18.61 67.35 MWD 5400.00 66.92 66.56 2933.14 38.48 -0.21 166.37 13.39 33.98 0.96 13.53 166.38 18.96 67.33 MWD 5500.00 66.92 66.56 2972.35 39.36 -0.21 170.16 13.71 34.79 0.98 13.86 170.17 19.30 67.32 MWD 5600.00 66.92 66.56 3011.56 40.24 -0.21 173.94 14.03 35.60 1.01 14.18 173.96 19.64 67.30 MWD 5700.00 66.92 66.56 3050.77 41.12 -0.21 177.73 14.35 36.41 1.04 14.51 177.74 19.99 67.29 MWD 5800.00 66.92 66.56 3089.98 42.00 -0.21 181.52 14.67 37.22 1.07 14.84 181.53 20.33 67.27 MWD 5900.00 66.92 66.56 3129.19 42.88 -0.21 185.31 14.99 38.03 1.09 15.16 185.32 20.68 67.26 MWD 6000.00 66.92 66.56 3168.39 43.76 -0.21 189.09 15.31 38.84 1.12 15.49 189.11 21.02 67.25 MWD 6100.00 66.92 66.56 3207.60 44.64 -0.21 192.88 15.63 39.65 1.15 15.82 192.89 21.36 67.24 MWD 6200.00 66.92 66.56 3246.81 45.52 -0.21 196.67 15.95 40.46 1.18 16.14 196.68 21.71 67.23 MWD 6300.00 66.92 66.56 3286.02 46.40 -0.21 200.46 16.27 41.27 1.21 16.47 200.47 22.05 67.21 MWD 6400.00 66.92 66.56 3325.23 47.28 -0.21 204.24 16.59 42.08 1.24 16.80 204.26 22.40 67.20 MWD 6500.00 66.92 66.56 3364.44 48.16 -0.21 208.03 16.90 42.88 1.27 17.13 208.04 22.74 67.19 MWD 6600.00 66,92 66.56 3403.64 49.04 -0.21 211.82 17.22 43.69 1.30 17.45 211.83 23.09 67.18 MWD 6700.00 66.92 66.56 3442.85 49.92 -0.21 215.61 17.54 44.50 1.33 17.78 215.62 23.44 67.17 MWD 6800.00 66.92 66.56 3482.06 50.80 -0.21 219.40 17.86 45.31 1.37 18.11 219.41 23.78 67.17 MWD 6900.00 66.92 66.56 3521.27 51.67 -0.21 223.18 18.18 46.12 1.40 18.44 223.20 24.13 67.16 MWD 7000.00 66.92 66.56 3560.48 52.55 -0.21 226.97 18.50 46.93 1.43 18.77 226.98 24.47 67.15 MWD 7100.00 66.92 66.56 3599.69 53.43 -0.21 230,76 18.82 47.74 1.46 19.10 230.77 24.82 67.14 MWD 7200.00 66.92 66.56 3638.90 54.31 -0.21 234.55 19.14 48.55 1.50 19.43 234.56 25.16 67.13 MWD 7300.00 66.92 66.56 3678.10 55.19 -0.21 238.34 19.46 49.36 1.53 19.76 238.35 25.51 67.12 MWD 7400.00 66.92 66.56 3717.31 56.07 -0.21 242.13 19.78 50.17 1.57 20.09 242.14 25.86 67.12 MWD 7500.00 66.92 66.56 3756.52 56.95 -0.21 245.91 20.10 50.98 1.60 20.42 245.93 26.20 67.11 MWD 7600.00 66.92 66.56 3795.73 57.83 -0.21 249.70 20.42 51.79 1.64 20.75 249.71 26.55 67.10 MWD Or"" ,J t;;;'" " If ~ 'I~~ " r i "l I ä}/c; L ') ) Baker Hughes INTEQ Error Ellipse Survey Report Company: ConocoPhillips Alaska, Inc. Date: 11/14/2002 Time: 14:51 :46 Page: 3 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 22, True North Site: Pad 1C Vertical (TVD) Reference: Wellhead(88') 88.0 Well: 22 Section (VS) Reference: Well (0.00N,O.00E,66.78Azi) Wellpath: 1C-22 Vers# 1 Survey Calculation Method: Minimum Curvature Db: Oracle Position uncertainty and bias at survey station All uncertainties &1.6 standard deviatioJllighside-----> Lateral-------> Vertical------> Magn. Semi-majo8emi-minor MD Ine] Azim TVD Unc. Bias Unc. Bias Unc. Bias of Bias Unc. Unc. Azimutl'i'ool ft . deg deg ft ft ft ft ft ft ft ft ft ft deg 7700.00 66.92 66.56 3834.94 58.71 -0.21 253.49 20.74 52.60 1.67 21.08 253.50 26.90 67.10 MWD 7800.00 66.92 66.56 3874.15 59.59 -0.21 257.28 21.06 53.41 1.71 21.41 257.29 27.24 67.09 MWD 7900.00 66.92 66.56 3913.35 60.4 7 -0.21 261.07 21.38 54.22 1.74 21.74 261.08 27.59 67.08 MWD 8000.00 66.92 66.56 3952.56 61.35 -0.21 264.86 21.69 55.03 1.78 22.07 264.87 27.94 67.08 MWD 8100.00 66.92 66.56 3991 .77 62.23 -0.21 268.65 22.01 55.84 1.82 22.40 268.66 28.28 67.07 MWD 8200.00 66.92 66.56 4030.98 63.11 -0.21 272.43 22.33 56.65 1.86 22.73 272.44 28.63 67.06 MWD 8300.00 66.92 66.56 4070.19 63.99 -0.21 276.22 22.65 57.46 1.89 23.06 276.23 28.98 67.06 MWD 8400.00 66.92 66.56 4109.40 64.87 -0.21 280.01 22.97 58.27 1.93 23.40 280.02 29.32 67.05 MWD 8500.00 66.92 66.56 4148.60 65.75 -0.21 283.80 23.29 59.08 1.97 23.73 283.81 29.67 67.05 MWD 8600.00 66.92 66.56 4187.81 66.63 -0.21 287.59 23.61 59.89 2.01 24.06 287.60 30.02 67.04 MWD 8700.00 66.92 66.56 4227.02 67.51 -0.21 291.38 23.93 60.70 2.05 24.39 291.39 30.37 67.04 MWD 8800.00 66.92 66.56 4266.23 68.39 -0.21 295.17 24.25 61.51 2.09 24.73 295.18 30.71 67.03 MWD 8900.00 66.92 66.56 4305.44 69.27 -0.21 298.95 24.57 62.32 2.13 25.06 298.96 31.06 67.03 MWD 9000.00 66.92 66.56 4344.65 70.15 -0.21 302.74 24.89 63.13 2.17 25.39 302.75 31.41 67.02 MWD 9100.00 66.92 66.56 4383.86 71.03 -0.21 306.53 25.21 63.94 2.21 25.73 306.54 31.76 67.02 MWD 9200.00 66.92 66.56 4423.06 71.91 -0.21 310.32 25.53 64.75 2.26 26.06 310.33 32.10 67.01 MWD 9300.00 66.92 66.56 4462.27 72.79 -0.21 314.11 25.85 65.56 2.30 26.40 314.12 32.45 67.01 MWD 9400.00 66.92 66.56 4501.48 73.67 -0.21 317.90 26.17 66.37 2.34 26.73 317.91 32.80 67.00 MWD 9500.00 66.92 66.56 4540.69 74.55 -0.21 321.69 26.48 67.18 2.38 27.07 321.70 33.15 67.00 MWD 9600.00 66.92 66.56 4579.90 75.43 -0.21 325.48 26.80 67.99 2.43 27.40 325.49 33.49 67.00 MWD 9700.00 66.92 66.56 4619.11 76.31 -0.21 329.26 27.12 68.80 2.47 27.74 329.27 33.84 66.99 MWD 9800.00 66.92 66.56 4658.31 77.19 -0.21 333.05 27.44 69.61 2.52 28.07 333.06 34.19 66.99 MWD 9900.00 66.92 66.56 4697.52 78.07 -0.21 336.84 27.76 70.42 2.56 28.41 336.85 34.54 66.98 MWD 10000.00 66.92 66.56 4736.73 78.95 -0.21 340.63 28.08 71.23 2.61 28.75 340.64 34.88 66.98 MWD 10100.00 66.92 66.56 4775.94 79.83 -0.21 344.42 28.40 72.03 2.65 29.08 344.43 35.23 66.98 MWD 10200.00 66.92 66.56 4815.15 80.71 -0.21 348.21 28.72 72.84 2.70 29.42 348.22 35.58 66.97 MWD 10300.00 66.92 66.56 4854.36 81.59 -0.21 352.00 29.04 73.65 2.74 29.76 352.01 35.93 66.97 MWD 10400.00 66.92 66.56 4893.57 82.47 -0.21 355.79 29.36 74.46 2.79 30.09 355.80 36.28 66.97 MWD 10500.00 66.92 66.56 4932.77 83.35 -0.21 359.58 29.68 75.27 2.84 30.43 359.58 36.62 66.96 MWD 10600.00 66.92 66.56 4971.98 84.23 -0.21 363.36 30.00 76.08 2.88 30.77 363.37 36.97 66.96 MWD 10700.00 66.92 66.56 5011.19 85.11 -0.21 367.15 30.32 76.89 2.93 31.11 367.16 37.32 66.96 MWD 10800.00 66.92 66.56 5050.40 85.99 -0.21 370.94 30.64 77.70 2.98 31 .45 370.95 37.67 66.95 MWD 10900.00 66.92 66.56 5089.61 86.87 -0.21 374.73 30.96 78.51 3.03 31.79 374.74 38.02 66.95 MWD 11000.00 66.92 66.56 5128.82 87.75 -0.21 378.52 31.27 79.32 3.08 32.13 378.53 38.36 66.95 MWD 11100.00 66.92 66.56 5168.02 88.63 -0.21 382.31 31.59 80.13 3.13 32.47 382.32 38.71 66.94 MWD 11200.00 66.92 66.56 5207.23 89.51 -0.21 386.10 31.91 80.94 3.18 32.81 386.11 39.06 66.94 MWD 11300.00 66.92 66.56 5246.44 90.39 -0.21 389.89 32.23 81.75 3.23 33.15 389.90 39.41 66.94 MWD 11400.00 66.92 66.56 5285.65 91.27 -0.21 393.68 32.55 82.56 3.28 33.49 393.68 39.76 66.94 MWD 11500.00 66.92 66.56 5324.86 92.15 -0.21 397.47 32.87 83.37 3.33 33.83 397.47 40.11 66.93 MWD 11600.00 66.92 66.56 5364.07 93.03 -0.21 401.25 33.19 84.18 3.38 34.17 401.26 40.45 66.93 MWD 11700.00 66.92 66.56 5403.27 93.91 -0.21 405.04 33.51 84.99 3.44 34.51 405.05 40.80 66.93 MWD 11800.00 66.92 66.56 5442.48 94.79 -0.21 408.83 33.83 85.80 3.49 34.86 408.84 41.15 66.92 MWD 11900.00 66.92 66.56 5481.69 95.67 -0.21 412.62 34.15 86.61 3.54 35.20 412.63 41.50 66.92 MWD 12000.00 66.92 66.56 5520.90 96.55 -0.21 416.41 34.47 87.42 3.59 35.54 416.42 41.85 66.92 MWD 12100.00 66.92 66.56 5560.11 97.43 -0.21 420.20 34.79 88.23 3.65 35.88 420.21 42.20 66.92 MWD 12200.00 66.92 66.56 5599.32 98.31 -0.21 423.99 35.11 89.04 3.70 36.23 424.00 42.54 66.91 MWD 12300.00 66.92 66.56 5638.53 99.19 -0.21 427.78 35.43 89.85 3.76 36.57 427.79 42.89 66.91 MWD 12400.00 66.92 66.56 5677.73 100.07 -0.21 431.57 35.75 90.66 3.81 36.92 431.57 43.24 66.91 MWD 12500.00 66.92 66.56 5716.94 100.95 -0.21 435.36 36.06 91.47 3.87 37.26 435.36 43.59 66.91 MWD 12600.00 66.92 66.56 5756.15 101.83 -0.21 439.14 36.38 92.28 3.92 37.60 439.15 43.94 66.91 MWD 12700.00 66.92 66.56 5795.36 102.71 -0.21 442.93 36.70 93.09 3.98 37.95 442.94 44.29 66.90 MWD 12800.00 66.92 66.56 5834.57 103.59 -0.21 446.72 37.02 93.90 4.04 38.30 446.73 44.64 66.90 MWD 12900.00 66.92 66.56 5873.78 1 04.4 7 -0.21 450.51 37.34 94.71 4.09 38.64 450.52 44.98 66.90 MWD O ¡;"'T'¡ ~ .,:: "'\ f ~ \' , ~ :' f'''t·1 ~\J1 J hi 1~~ '1 ) ) Baker Hughes INTEQ Error Ellipse Survey Report Company: ConocoPhillips Alaska, Inc. Date: 11/14/2002 Time: 14:51 :46 Page: 4 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 22, True North Site: Pad 1C Vertical (TVD) Reference: Wellhead(88') 88.0 Well: 22 Section (VS) Reference: Well (0.00N,O.00E,66.78Azi) Wellpath: 1C-22 Vers# 1 Survey Calculation Method: Minimum Curvature Db: Oracle Position uncertainty and bias at survey station All uncertainties a1.6 standard deviatioiHighside-----> Lateral-------> Vertical------> Magn. Semi-majoSemi-minor MD Incl Azim TVD Unc. Bias Unc. Bias Unc. Bias of Bias Unc. Unc. Azimutli'ool ft deg deg ft ft ft ft ft ft ft ft ft ft deg 13000.00 66.92 66.56 5912.98 105.35 -0.21 454.30 37.66 95.52 4.15 38.99 454.31 45.33 66.90 MWD 13100.00 66.92 66.56 5952.19 106.23 -0.21 458.09 37.98 96.33 4.21 39.33 458.10 45.68 66.90 MWD 13200.00 65.79 66.56 5991.91 107.11 -0.01 461.53 38.30 97.10 4.27 39.68 461.53 46.01 66.89 MWD 13300.00 63.79 66.56 6034.50 107.79 0.35 464.05 38.61 97.73 4.33 40.02 464.05 46.30 66.89 MWD 13400.00 61.79 66.56 6080.23 108.33 0.72 466.53 38.91 98.34 4.41 40.35 466.54 46.61 66.89 MWD 13500.00 59.79 66.55 6129.03 108.73 1.10 468.98 39.19 98.93 4.49 40.67 468.99 46.93 66.89 MWD 13600.00 57.79 66.55 6180.84 108.99 1.48 471.38 39.47 99.49 4.58 40.98 471.39 47.26 66.89 MWD 13700.00 55.79 66.55 6235.61 109.09 1.86 473.73 39.73 100.04 4.68 41.29 473.74 47.61 66.89 MWD 13800.00 53.79 66.55 6293.27 109.06 2.25 476.02 39.99 100.56 4.79 41.58 476.03 47.96 66.89 MWD 13900.00 51.79 66.55 6353.74 108.87 2.64 478.25 40.23 101.05 4.91 41.86 478.26 48.33 66.89 MWD 14000.00 49.79 66.55 6416.96 108.53 3.03 480.42 40.45 101.52 5.04 42.14 480.43 48.70 66.88 MWD 14100.00 47.79 66.54 6482.84 108.05 3.43 482.52 40.67 101.96 5.18 42.40 482.53 49.07 66.88 MWD 14200.00 45.79 66.54 6551.30 107.41 3.83 484.55 40.87 102.37 5.33 42.65 484.55 49.45 66.88 MWD 14300.00 45.00 66.54 6621.82 107.50 3.99 486.78 41.06 102.79 5.48 42.89 486.79 49.86 66.88 MWD 14400.00 45.00 66.54 6692.53 108.20 3.99 489.63 41.25 103.29 5.64 43.13 489.64 50.36 66.88 MWD 14500.00 45.00 66.54 6763.24 108.89 3.99 492.48 41 .43 103.78 5.80 43.38 492.49 50.85 66.88 MWD 14536.02 45.00 66.54 6788.71 109.15 3.99 493.51 41.50 103.96 5.86 43.46 493.52 51.03 66.88 MWD OJ, ê ; tI ".,,/ I I ~ :1.' : I ,) ~ ~ Ij ) '\ " " t:.~~~1 , " ~ " , ¡-c- 600 -'""" +- Q.) Q.) '+- '--" 0 - J 600 - 1200 - 1800 - 2400 - 3000 - 3600 - ..c +- 0... Q.) o o ü +- ~ Q.) > Q.) :J ~ .- I V 4200 - 4800 - 5400 - 6000 - 6600 - 7200 - Created by bmichoel For: S. Cloninger Dote plotted: 14-Nov-2D02 Pial Rer.rence i. IC-22 Version HI. Coordinates ore in feet reference slot 622. True Vertical Oeplhs ore reference EsI RKB (0-141), lID. ..... INTEQ Estimated RKB Elevation: 88' KOP 4.00 12.00 20.00 DLS: 4.00 deg per 100 ft 28.00 33.95 41.87 49.81 61.75 EOC Base Permafrost ConocoPhillips Alaska, Inc. Structure : Pad 1 C Well : 22 Field : Kuparuk River Unit Location: North Slope, Alaska 66.78 AZIMUTH 12092' (TO TARGET) ***Plane af Propasal*** TANGENT ANGLE 66.92 DEG o 600 2400 1200 1800 Base West Sak .::: 9 5/8 Casing 3000 6600 8400 3600 4200 4800 5400 6000 7200 7800 Vertical Section (feet) -> Azimuth 66.78 with reference 0.00 N, 0.00 E from slot #22 DLS: 2.00 deg 9000 ~ ConocoPhillips --" -'~ Begi65?fgP 59.79 Top HRZ 53.79 47.79 per 100 ft ~~sT<~P~~uk Target - EODC_3 C-2 C-1 Tap B TO, 7 CSG pt. 9600 10200 10800 11400 12000 12600 a ::~~~~~ ~ _--3 ~# c:~ e.-J.L! 1&--.0:...,.-.._ (~ . ~=-'- ------_.~~,. r--.. Created by bmichael For: S. Cloninger Dote plotted: 14-Nav-2D02 Pial Reference ;s 1C-22 Version 61. Coordinates ore in feet reference slot 622. True Vertical Depths ore reference Est RKB (0-141). R.. ..... 6600 - 6000 - 5400 - 4800 - 4200 - ^ I 3600 - "........, -+- (]) (]) '+- '-/ 3000 - ..c -+- L o Z 2400 - 1800 - 1200 - 600 - o 600 1200 INTEQ ESTIMATED SURFACE LOCATION: 1593' FNL, 1327' FWL SEC. 12, Tl1N, R10E 1200 600 1800 600 o 1200 ConocoPhillips Alaska, Inc. ....... ConocoPhillips Structure : Pad 1 C Well : 22 Field : Kuparuk River Unit Location North Slope, Alaska 66.78 AZIMUTH 12092' (TO TARGET) TO LOCATION: 2032' FNL, 2463' FWL SEC. 5, T11N. R11E /' ~ .> HARDLlNE QP@t'''C'J'aK <"0 ~ G) /' &0 o U'@ 6ð,,9. _ ;() 'Ý~ 'Ý~~ /-:> ?" <?..... % -~ ***Plone of Proposal*** TARGET LOCATION: 2115' FNL, 2270' FWL SEC. 5, T11N, Rl1 E cr TRUE "- 2400 3600 9600 10200 10800 11400 12000 12600 4200 4800 5400 6000 6600 7200 7800 8400 9000 3000 East (feet) -> ConocoPhillips Alaska, Inc. ....... ConocoPhillips Creoled by bmichael For: S. Cloninger Structure : Pad 1 C Well : 22 Dole plotted: 14-Nav-2D02 Pial Reference is 1C-22 Version 1/1. Field: Kuparuk River Unit Location : North Slope, Alaska Coordinales ore in feel reference 5101 622. True Vertical Deplhs ore reference Esl RKB (0-141). _il. .... INTEQ c:::::== c:::::== c::::== c:::::== PROF~LE COMMENT DATA ==== -. ----- Point ----- MD Inc Dir TVD North East V. Sect Deg/100 KOP 250.00 0.00 73.00 250.00 0.00 0.00 0.00 0.00 EOC 1929.82 66.92 66.55 1572.55 303.01 820.71 873.69 4.00 Bose Permafrost 2479.33 66.92 66.55 1788.00 504.20 1284.45 1379.19 0.00 Top West Sak 7901.64 66.92 66.55 3914.00 2489.40 5860.54 6367.30 0.00 Base West Sa k 8942.24 66.92 66.55 4322.00 2870.38 6738.74 7324.57 0.00 9 5/8 Casing 9452.33 66.92 66.55 4522.00 3057.14 7169.23 7793.82 0.00 Begin Drop 13143.66 66.92 66.55 5969.31 4408.60 10284.47 11189.55 0.00 Top HRZ 13575.75 58.27 66.55 6168.00 4561.12 10636.05 11572.78 2.00 Bose HRZ 13929.33 51.20 66.55 6372.00 4675.95 10900.74 11861.31 2.00 Top Kuparuk 14186.63 46.06 66.55 6542.00 4752.78 11077.81 12054.33 2.00 Target - EOD 14239.43 45.00 66.55 6578.99 4767.77 11112.38 12092.01 2.00 CJ C-3 14297.43 45.00 66.55 6620.00 4784.10 11150.00 12133.02 0.00 ::7~, C-2 14332.79 45.00 66.55 6645.00 4794.05 11172.94 12158.02 0.00 ~...-~-- ,4 !:; j C-1 14400.67 45.00 66.55 6693.00 4813.15 11216.97 12206.02 0.00 ~-'- ;0 Top B 14436.02 45.00 66.55 6718.00 4823.10 11239.91 1 2231 .02 0.00 :1' ::: r-- TD, 7 CSG pt. 14536.02 45.00 66.55 6788.71 4851 .25 11304.77 12301.73 0.00 ) ) ConocoPhillips Alaska, Inc. Created by bmichael For: S. Cloninger Date platted: 14-Nov-2002 Plot Roference is 1 C-22 Version N 1. Coordinates ore in feet reterence slot 122. True Vertical Depths are reference Est RKB (D-141). Structu re : Pad 1 C Well: 22 ~ ConocoPhillips Field: Kuparuk River Unit Location: North Slope. Alaska RiiW .,.. INTEQ 31 Ò\ \ \ 3~--a 300 \ \ \ ~ \ \ \ ~ \ \ "\ 1300 \330 \ 320 \ \ TRUE NORTH <=::r c:::J 350 0 10 340 20 210 30 40 50 60 290Œ} -,-a· 70 280 80 270 90 260 100 250 1 1 0 120 130 140 2'0 150 160 180 170 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well ; j \:~~, ~I J .) J .1 ""'~~ ~ ''-~~ --. r ~ ;=-;-:-- ~~ ~ <- ~ ,":-_-,-","F-;:' "-- '~ Crealed by bmlchael For: S. Cloninger Dote plotled : 14-Nay-2002 Plol Reference is 1C-22 Version 61. Coordinales ore in feet reference slot 622. True Vertical Depths ore reference Esl RK8 (0-1-41). W:iI. .... INTEQ 5600 - 5400 - 5200 - 5000 - 4800 - ^ I 4600 - ~ +- Q) Q) '+- '---" 4400 - ..r::: +- L- a z 4200 - 4000 - 3800 - 3600 - .... / 5000 3400 - @/ 3200 - 3000 7800 8200 8400 8000 I WS#24 8600 ConocoPhillips Alaska, Inc. Field: Kuparuk River Unit Structure : Pad 1 C Well : 22 Location North Slope, Alaska 6200// ,.-0 /....~oo .r / 5300 8800 9000 9200 9400 9600 6500/ / ..... ~ ConocoPhillips ',-- [W / -' 9800 10000 10200 10400 10600 10800 11000 11200 11400 11600 11800 12000 12200 East (feet) -> :r---.... ~Qk~~ i~~_ L- ~? '= ~....--~ Created by bmlchoel For: S. Cloninger Dote plotted: 14-Nav-2D02 Plot Reference is 1C-22 Version #1. Coordinates ore in feet reference slot #22. True Verlical Depths ore reference Est RKB (0- 141). ... .... INTEQ 4500 - f) J' "5300 4200 - I / 3900 - /5000 I / 3600 - , '4700 / ^ I / 3300 - / 3500/ / -0) / / / 3000 - ,........., +- Q.) Q.) '+- .........,. . / . /2900 ,~ 3?ÓO 2700 - <f)/ / / -0/ 2400 - ...c +- f.- a z 2100 - 900 600 2100 2400 2700 3000 Structure : Pad 1 C Well : 22 ConocoPhillips Alaska, Inc. Field : Kuparuk River Unit Location North Slope, Alaska ~100 Fill / 6500t I 6200j I 5900/ I 56009 15 6800 3300 3600 3900 4500 4800 5400 5700 440r# f) / / 3800 / / / / 41 00 / / .' / / '3500 / ? / / 38<y/ / / / / / / / .13200 5100 4200 East (feet) - > 6000 6300 6600 6900 ...... ConocoPhillips "- s§J ..... 5000 .....<Y" 470~ ..... ..... ....-:::....-:: 14 6500 -" 4700 7200 7500 7800 8100 8400 8700 Created by bmlchoel For: S. Cloninger Dote plotted: 14-Nov-2002 Plot Reference is IC-22 Version HI. Coordinates ore in feet reference slot H22. T rue Vertical Depths ore reference Est RKB (0- 141). ... ..... Structure: Pad 1 C Well: 22 ...... ConocoPhillips ConocoPhillips Alaska, Inc. Field: Kuparuk River Unit Location North Slope, Alaska INTEQ 400 ~€f <9 1300 - / / 1200 - 1100 - 1000 - 900 - ^ I 800 - '" +- Q) 700 Q) '+- '--'" ..c 600 - +- ~ 0 Z 500 - / -@ '7 / / / / " 1900 / 100/ / / / / / / / / /1 700 / /" / / / / / / /1700 / /" / / / / / / / / / / / / / " 2700 / / / / / --- / / / /,@ /' ""-2300 / / / / /1500 / / /1 500, / / / / / 5100 . 49g0· 5500 5900 ~ _/ / 2300 300 - 200 100 o 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 East (feet) -> Crea!ed by bmlchael For: S. Cloninger Dote plotled : 14-Nov-2D02 Plo! Reference is 1C-22 Version *1. Coordina!es ore in feet reference slot *22. True Vertical Depths ore reference Es! RKB (0-141). .... .... 220 c::-, L~::"'-'_. _,,-_-:- ,i j 200 - 180 - 160 - 140 - 120 - ^ I .......... 100 - +- Q) Q) / - I "-./ 80 - !B ..r:: +- L 0 60 Z 40 - 20 - 0 - 20 ..-c ~,;: Lj ConocoPhillips Alaska, Inc. ........ ConocoPhillips Struc1ure : Pad 1 C Well : 22 Field: Kuparuk River Unit Location North Slope, Alaska INTEQ (& Ii) / / / / / / / / / / / ""-' / I I / /900 I / / I I --@ / / / / / / /700 / / / __ --- 11 00 ----§ / / I ¡500 -- .....9ÔO ..-4' 1-300 _0 I -ø 300 __ --°700 ..-4 .-} 1DO~ -" OOCJ 0--700 ~3ÓÓ j..~~--.... :L.~ r-- 40 - e I I I I I I I I I I I I I I I I 60 40 20 0 20 40 60 80 100 120 140 160 180 200 220 240 260 280 300 320 340 360 380 400 East (feet) -> ~--~-~1 ~ ) ) ,lC-22 Drillina Hazards Summary 12-1/4" Hole / 9-5/8" Casina Interval Event Broach of Conductor Risk Level Moderate Gas Hydrates Moderate Gravel/Sand Sloughing to 500' Moderate Hole Swabbing/Tight Hole on Trips Moderate Possible thaw bulb Low Lost Circulation Moderate M itiqa~ion St~ateqy Monitor cellar continuously during interval. If observed - control drill, reduce pump rates, and reduce drilling fluid temperatures. Additions of Drilltreat. Increase mud weight / viscosity, High viscosity sweeps. Monitor fill on connections. Circulate hole clean prior to trip. Proper hole fill (use of trip sheets), Pumping out of hole as needed. Watch return viscosity for signs of thinning. Increased mud weight/viscosity as needed. Prevent by keeping hole clean. If losses occur - reduce pump rates and mud rheology, use LCM. 8-1/2" Hole / 7" Casina Interval Risk Level I M itiqation Strateqy Low Control with higher MW and proper drilling practices. Event Shale stability in HRZ, K-l, and Miluveach High ECD and swabbing with higher MW's required Moderate Barite Sag Low Differential Sticking Moderate Abnormal Reservoir Pressure Moderate Lost Circulation Moderate Condition mud prior to trips. Monitor ECD's while drilling across pay interval. Pump and rotate out on trips as a last resort. Good drilling practices as documented in well plan. Periodic wiper trips. Do not leave pipe static for extended period of time. Follow mud weight schedule and do not fall behind. Stripping Drills, Shut-in Drills, and Increase mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree. 1C-22 Drilling Hazards Summary. doc prepared by Shane Cloninger 11/14/02 On;) ~al~,1, l' ' ~,\I (i' ,", " {~f U I,' ., - KRU - 1 C-22 111. .btor Proposed Completion Schematic Single Completion Cono~óPhi ~ips 16"x30" insulated conductor @ +1- 110' MD r :f ~ ~ ~ ~ ~ I ~ ~ ~ i TAM 9-5/8" Pori d Collar Stnd fã Grade BTC ~ Threads (+/- ~ 1000' MD/TVD) I ~ ~ ~ ..&J. Surface csg. 9-5/8"40# L-80 STC @ +1- 9,452' MD I 4,522' TVD (Casing point 200' TVD below the base of the West Sak) Kuparuk C Sand Peñs (to be done post rig) Production csg. 7" 26# L-80 STCM @ +1- 14,536' MD I 6,789' TVD I ~ I ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ .1~1¡:!¡I:ml ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ -- -- ~ ~ '~"'''';¡¡'''¡I!'''',''¡!.¡' ~ ~ . ~~~~"þ) ~ ~ ~\<!r~~~ ~ / ~- "" ,\,/, " " ~ rg1 ~ ~ ~ ~ ~ ^ "" ,,=" ~ .1 ~::;~ J' r ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ I I ~ ~ ~ .~ !Í.i. ..~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ Gemëri~ I _ r-- ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ 2tI.... 3-1/2" FMC Gen V tubing hanger, 3-1/2" L-80 EUE8RD pin down. Special Drift 2.91" 3-1/2", L-80, 9.3# EUE8RD Spaceout Pups as Required. Special Drift 2.91" 3-1/2" 9.3# L-80 EUE8RD Tubing to Surface Special Drift 2.91" 3-1/2" Camco DS Landing Nipple with 2.875" ID No-Go profile set @ +1- 500' MD. Use of port collar at the discretion of the drilling team. 9-5/8" @ +1- 9,452' MD I 4,522' TVD 3-1/2" x 1-1/2" 'MMG' GLM wI DCR Dump Kill Valve (3000 psi casing to tubing shear). 6' L-80 handling pups installed on top and bottom of mandrel. 1 Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 3-1/2" Camco 'DS' nipple wI 2.813" No-Go profile 1 Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 6' Handling Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. Baker '80-40' PBR. Baker 7" x 3-1/2" 'SAB-3' Permanent Packer set +1- 100' MD above top planned perf. Minimum ID through the packer 3.00". 6' Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 3-1/2" Cameo 'D' nipple wI 2.75" No-Go profile. 6' Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. Baker 3-1/2" WL Re-entry Guide wI shear out sub. Tubing tail 50' above top planned perforation. TD @ 14,536' MD 16,789' TVD SDC 11/14/02 /\ " .~ ~ I,....~:.e· h t ~2~/~ ~ , f J -~ i1'1 ~f RECE\V£D NO'J 1 52002 _1)\\& GaSQoßS. GOmllÌ\SSIOI1 Ancboraue . r?;OOllars Chase Manhaltan Bank USA, N.A. Valid Up 0 _, ~ ..... CHASE 20DWhiIeCJayCenterDr..New.r!r.DE19111 f)/ 4#~Þ J ) L u ~., -{/Y"-. , . ^-- ( "",'",".. ....,._M"_'''O I, 2 7 2 5 711" 1.008 -:0 ~ ~ .00 . ~ 1.,.: 2 .8000 -- <;....,"::{i':[ S7ltlG DF ,/1 u4-SUt I AoGtc(" · 100. 00 .::'" r;::¡:~LL¡z;:''!::J--.. r"~:--m\;:¡;hS Ô , V0?-.... ..~_ .._,_,~___._~._,~_~~~~~.._~~__..~,_~_~~i-..~~,~,~,~".... .... 1008 OATEJ~lpv~~ (s Zfi;OL .. '-.-...--/ 62-14/311 S. K. ALLSUP-DRAKE PHILLIPS PETROLEUM COMPANY 711 G ST. ANCHORAGE AK 99501 ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME tf£q / C -- Z- Z- PTD# Zc:>¿ - z...z Z- CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function' of the original API number stated above. HOLE In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). paOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing , exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST COMPANVG:w,..,..... ð.h'I,*WELL NAME kRc.,( It':- 2-7 PROGRAM: Exp _ Dev _ Redrll_ Re-Enter _ Se~ Wellbore seg_ FIELD & POOL '7' '7 ó / b~~ INIT CLASS I ~ ..II ~ ~¡ GEOL AREA r7 ~ UNIT# // I ~ ~ ON/OFF SHORE 0-0 ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . Ç'... N 2. Lease number appropriate. . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . \ Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . \Y N (Service Well Only) 13. Well located w/in area & strata authorized by injection order#~ (fj N (Service Well Only) 14. All wells wlin ~ mile area of review identified. . . . . . . . .. ® N -"'-"ð~ 'Ie... ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . ~N 16. Surface casing protects all known USDWs. . . . . . . N 17. CMT vol adequate to circulate on conductor & surf csg. ' N ,- ,,- ~, A- 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . Y j1{ i-1It- ~ "-<- D Y'l6 ld<;' t .. 19. CMT will cover all known productive horizons. . . . . . . . . ~ N 20. Casing designs adequate for C, T, B & permafrost. . . . . . .' N 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N D "V¡ ~ t 4/ . 22. If a re-drill, has a 10-403 for abandonment been approved. . . .-¥-N Ai IN 23. Adequate wellbore separation proposed.. . . . . . . . . . . . N 24. If diverter required, does it meet regulations. . . . . . . . . . N /)/lL I 25, Drilling fluid program schematic & equip list adequate. . . . . N ¡t1ßvv I' tv-" 0 t P pc¡ 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N APPR DATE 27. BOPE press rating appropriate; test to S" 000 psig. N All <; P Z-~ $ 2.. f5 / . i. iCjk H lilt (' ø 'Z.,.. 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N "" 29. Work will occur without operation shutdown. . . . . . . . . . . N 30. Is Presence of H2S gas Probable.. . . . . . . . . . . . . . . . y Á.J 31. Mechanical condition of wells within AOR verified. . . . . . . . ~ I"tl A- 32. Permit can be issued wlo hydrogen sulfide measures. .'. . . ®N 33. Data presented on potential overpressure zones. . . . . . . . fi 34. Seismic analysis of shallow gas zones. . . . . . . .: .: .: .: .: .: ~ ~ f/lJ. 4, 35. Seabed condition survey (if off-shore). . . . . . . II 36. Contact namelphone for weekly progress reports. GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING RPL APPR DATE UL ~" (Service Well Only) GEOLOGY APPR DATE ~/~ ¿þ- (Explora(ory Only) Rev: 10/15/02 Ulc ENGINEER COMMISS!O}ER: COT /~.z/Az- DTS J ,/ e.ol0 ( MLB /1/z..f/<tPZ-. TEM JDH JBR SFD_ WGA / MJW G:\geology\perm its\checklist.doc ( Comments/Instructions: ) ') Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. . To improve the readability of the Well History file and to sinl,plify finding information, information of this nature is accumulated at the end of the file under APPEN,DIX. No special effort has been made to chronologically organize this category of information. ) **** REEL HEADER **** LDWG 03/01/09 AWS 01 **** TAPE HEADER **** LDWG 03/01/09 01 *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! LDWG File Version 1.000 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: LISTAPE.HED TAPE HEADER KUPARUK RIVER UNIT MWD /MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 1 C. WONG F. HERBERT MWD RUN 4 4 STURDIVANT D. WESTER # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING ) 1C-22 500292312700 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 09-JAN-03 MWD RUN 2 2 F. WENDLER M. HElM MWD RUN 5 5 C. WONG D. GLADDEN 12 11N 10E 87.10 59.10 MWD RUN 3 3 T. DURING D. GLADDEN MWD RUN 6 F. WENDLER M. HElM OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 30.000 138.0 aOd.-ò?~ J ¡tl7e¡ ) ) 9.625 9473.0 14620.0 # REMARKS: 3RD STRING 12.250 PRODUCTION STRING 8.500 PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR TO DELIVERY FROM THE WELL SITE. SURFACE LOCATION: LAT: N 70 DEG 19' 45. 173" LONG: W149 DEG 30' 19.124" LOG MEASURED FROM D.F. AT 87.1 FT. ABOVE PERM. DATUM (M. S. L.) . COMMENTS: (1) Baker Hughes INTEQ runs 1 and 2 utilized a Multiple Propagation Resistivity (MPR) and Gamma Ray with Near Bit Inclination services from 138-2756 feet MD (138 - 1882' TVD). (2) Baker Hughes INTEQ runs 3 and 4 utilized an AutoTrak RCLS (Rotary Closed Loop System) along with RNT (Reservoir Navigation Tool) Resistivity services from 2756 - 9481 feet MD (1882 - 4513' TVD). (3) Baker Hughes INTEQ runs 5 and 6 utilized the Advantage Porosity Logging Service (APLS) which includes the Optimized Rotational Density (ORD), Caliper Corrected Neutron (CCN), along with MAP (Modular Annular Pressure) and MPR Resistivity services from 9481 - 14620 feet MD (4513-6823' TVD). REMARKS: (1) Depth of 30 Inch Conductor Shoe - Logger: 138 feet MD (138' TVD) Depth of 30 Inch Conductor Shoe - Driller: 138 feet MD (138' TVD) (2) The interval from 254 to 307 feet MD (254 - 307' TVD) was logged up to 3.3 hours after being drilled due to a trip out of the hole. The trip was required to clear LCM from the MWD pulser. (3) The interval from 2703 to 2756 feet MD (1862 - 1882' TVD) was logged up to 12.3 hours after being drilled due to a trip out of the hole to pick up the AutoTrak tool string. Please note that due to the change in Resistivity tools, from MPR to RNT, that the presentation goes from 4 resistivity curves to 2 resistivity curves at 2703' MD ( 18 62' TVD). (4) The interval from 4803 to 4820 feet MD (2684 - 2691' TVD) was logged up to 23.4 hours after being drilled due to a trip out of the hole for AutoTrak. (5) The interval from 6693 to 6711 feet MD (3426 - 3433' TVD) was logged up to 8.5 hours after being drilled due to a short trip. (6) The interval from 9462 to 9473 feet MD (4506 - 4510' TVD) was not logged due to sensor-bit offset at the 9 5/8" casing point. Please note that due to the change in Resistivity tools from RNT to MPR, that the presentation goes from 2 resistivity curves to 4 resistivity curves at -9390' MD ( 4 4 7 8' TVD). (7) Depth of 9 5/8" Casing Shoe - Logger: 9473 feet MD (4510' TVD) Depth of 9 5/8" Casing Shoe - Driller: 9473 feet MD (4510' TVD) (8) The interval from 9944 to 12659 feet MD (4691 - 5761' TVD) was not logged due to an LWD tool malfunction. (9) The interval from 14579 to 14620 feet MD (6794 - ------------------------------------ *** INFORMATION TABLE: CONS MNEM VALU # $ MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. MERGE BASE 307.0 2757.0 4821. 0 9481. 0 12708.0 14620.0 MERGE TOP 138.0 307.0 2757.0 4821. 0 9481. 0 12708.0 BIT RUN NO 1 1 2 3 4 5 # REMARKS: BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- STOP DEPTH 254.0 2704.0 4804.0 9462.0 9944.0 14579.0 START DEPTH 138.0 254.0 2704.0 4804.0 9462.0 12647.0 clipped curves; all bit runs merged. .5000 LDWG File Version 1.000 Extract File: FILEOOl.HED 8 bytes 132 bytes 112 records... 1 ! ! ! ! !! ! ! ! !! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD MWD MWD MWD MWD MWD $ *** *** LIS COMMENT RECORD 1024 LDWG .001 **** FILE HEADER **** Minimum record length: Maximum record length: Tape Subfile: 1 6823' TVD) was not logged due to sensor-bit offset at TD. $ ) ) ) ) WDFN LCC CN WN FN COUN STAT lc-22 5.xtf 150 ConocoPhillips Alaska, Inc. 1C-22 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAM 0.0 RPD RPD RPD 0.0 RPM RPM RPM 0.0 RPS RPS RPS 0.0 RPX RPX RPX 0.0 RHOB RHOB BDCM 0.0 DRHO DRHO DRHM 0.0 PEF PEF DPEM 0.0 NPHI NPHI NPCKSM 0.0 ROP ROP ROPS 0.0 FET FET RPTH 0.0 MTEM MTEM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 52 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 19 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAP I 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPM MWD 68 1 OHMM 4 4 4 RPS MWD 68 1 OHMM 4 4 5 RPX MWD 68 1 OHMM 4 4 6 RHOB MWD 68 1 G/C3 4 4 7 DRHO MWD 68 1 G/C3 4 4 8 PEF MWD 68 1 BN/E 4 4 9 NPHI MWD 68 1 PU-S 4 4 10 ROP MWD 68 1 FPHR 4 4 11 FET MWD 68 1 HR 4 4 12 MTEM MWD 68 1 DEGF 4 4 ------- 48 Total Data Records: 1525 Tape File Start Depth 138.000000 Fresh Water 8.85 .0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): # 12.250 138.0 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # TOOL NUMBER MPR 35083 SRIG 8019 DAS 7050 BOTTOM) TOOL TYPE MULT. PROP. RESIST. GAMMA RAY DIRECTIONAL TOOL STRING (TOP TO VENDOR TOOL CODE MPR GRAM DIR $ # .0 .5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: MSB 18704 8.25 MPR MEMORY 307.0 124.0 254.0 o 08-DEC-02 STOP DEPTH 254.0 START DEPTH 124.0 FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ log header data for each bit run in separate files. 1 .2500 2 !! ! ! !!! !! !! ! !! !!! !! LDWG File Version 1.000 !! !!!! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: FILEOll.HED *** LIS COMMENT RECORD *** 1024 LDWG .002 **** FILE HEADER **** 8 bytes 4124 bytes Minimum record length: Maximum record length: 1582 records... Tape Subfile: 2 **** FILE TRAILER **** feet Tape File End Depth Tape File Level Spacing Tape File Depth Units 14620.000000 0.500000 ) \, ) ) MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: .0 2000 .0 .000 .000 .000 .000 64.0 .0 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 o # REMARKS: BIT RUN 1 (MWD Run 1) . GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT lc-22.xtf 150 conocoPhillips Alaska, I lC-22 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM RPCL RPSL RPCH RPSH RACL RASL RACH RASH ROPS GRAM RPCL RPSL RPCH RPSH RACL RASL RACH RASH ROPS GRAM RPD RPM RPS RPX RACLM RACSLM RACHM RACSHM ROPS 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 ) RPTH TCDM RPTH TCDM RPTHM TCDM 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 52 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 19 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 RACL MWD 68 1 OHMM 4 4 7 RASL MWD 68 1 OHMM 4 4 8 RACH MWD 68 1 OHMM 4 4 9 RASH MWD 68 1 OHMM 4 4 10 ROPS MWD 68 1 FPHR 4 4 11 RPTH MWD 68 1 MINS 4 4 12 TCDM MWD 68 1 DEGF 4 4 ------- 48 Total Data Records: 28 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 124.000000 254.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 127 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .003 1024 *** LIS COMMENT RECORD *** BIT RUN 1R (MWD Run 2) . GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWÐ-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) o .0 .00 .000 64.0 .0 .0 .0 .000 .000 .000 .000 Fresh Water 8.85 .0 .0 400 .0 12.250 138.0 TOOL NUMBER MPR 35083 SRIG 8019 DAS 34690 .5 70.2 MSB 18704 8.25 MPR MEMORY 2757.0 254.0 2704.0 o 09-DEC-02 REMARKS: # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOTTOM) TOOL TYPE MULT. PROP. RESIST. GAMMA RAY DIRECTIONAL TOOL STRING (TOP TO VENDOR TOOL CODE MPR GRAM DIR $ # # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 2704.0 FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ START DEPTH 254.0 log header data for each bit run in separate files. lR .2500 3 !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 ! !! ! !!! ! ! ! !! ! ! !!!!! Extract File: FILE012.HED ) ) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT lc-22.xtf 150 ConocoPhillips Alaska, I lC-22 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 RACL RACL RACLM 0.0 RASL RASL RACSLM 0.0 RACH RACH RACHM 0.0 RASH RASH RACSHM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE # 64) Data record type is: 0 Datum Frame Size is: 52 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 19 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 12 Curves: MSB 18704 8.25 RNT MEMORY 4821.0 2704.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): 10-DEC-02 STOP DEPTH 4804.0 START DEPTH 2704.0 FILE HEADER FILE NUMBER: AAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ log header data for each bit run in separate files. 2 .2500 4 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! LDWG File Version 1.000 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: FILE013. HED *** LIS COMMENT RECORD *** 1024 Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 AACL MWD 68 1 OHMM 4 4 7 AASL MWD 68 1 OHMM 4 4 8 AACH MWD 68 1 OHMM 4 4 9 AASH MWD 68 1 OHMM 4 4 10 ROPS MWD 68 1 FPHR 4 4 11 RPTH MWD 68 1 MINS 4 4 12 TCDM MWD 68 1 DEGF 4 4 ------- 48 Total Data Records: 516 Tape File Start Depth = 254.000000 Tape File End Depth = 2704.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TAAILER **** Tape Subfile: 4 615 records... Minimum record length: 8 bytes Maximum record length: 4124 bytes **** FILE HEADER **** LDWG .004 ) -) ) BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR RNT GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL RES. NAVIG. GAMMA RAY TOOL # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # ) 4804.0 o 66.7 70.2 TOOL NUMBER ASU 51312 RNT 20027 RNT 20027 12.250 138.0 Fresh Water 9.30 .0 .0 300 .0 .000 .000 .000 .000 71. 0 .0 .0 .0 .00 .000 .0 o BIT RUN 2 (MWD Run 3) . GR/RNT. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN lc-22.xtf 150 ConocoPhillips Alaska, I lC-22 Kuparuk River North Slope ') ) STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPCH RPCH RPS 0.0 RACL RACL RACLM 0.0 RACH RACH RACHM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 36 bytes Logging'direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 28 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 ROPS MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 8 TCDM MWD 68 1 DEGF 4 4 ------- 32 Total Data Records: 301 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 2704.000000 4804.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 5 391 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** .00 .000 120.0 .0 .0 .0 .000 .000 .000 .000 Water Fresh 9.70 .0 .0 250 .0 12.250 138.0 TOOL NUMBER ASU 37110 RNT 20034 RNT 20034 66.9 67.1 MSB 18704 8.25 RNT MEMORY 9481. 0 4804.0 9462.0 o 15-DEC-02 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOTTOM) TOOL TYPE DIRECTIONAL RES. NAVIG. TOOL GAMMA RAY TOOL STRING (TOP TO VENDOR TOOL CODE DIR RNT GRAM $ # # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9462.0 FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ START DEPTH 4804.0 log header data for each bit run in separate files. 3 .2500 5 !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !! !!!!!! ! !!!! ! ! ! ! !! Extract File: FILE014.HED *** LIS COMMENT RECORD *** 1024 LDWG .005 ) ) ') ) TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 o # REMARKS: BIT RUN 3 (MWD Run 4) . GR/RNT. CURVE GLOSSARY: GRAM - G.A11MA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT lc-22.xtf 150 ConocoPhillips Alaska, I lC-22 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPCH RPCH RPS 0.0 RACL RACL RACLM 0.0 RACH RACH RACHM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 36 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 28 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: MSB 18704 6.75 TC MEMORY 12708.0 9462.0 9944.0 o 21-DEC-02 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) STOP DEPTH 10015.0 FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ START DEPTH 9462.0 log header data for each bit run in separate files. 4 .2500 6 !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE015.HED *** LIS COMMENT RECORD *** 1024 LDWG .006 **** FILE HEADER **** 8 bytes 4124 bytes Minimum record length: Maximum record length: 756 records... Tape Subfile: 6 **** FILE TRAILER **** feet Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 4804.000000 9462.000000 0.250000 666 Total Data Records: Name Tool Code Samples Units Size Length 1 GRAM MW"D 68 1 GAP I 4 4 2 RPCL MW"D 68 1 OHMM 4 4 3 RPCH MW"D 68 1 OHMM 4 4 4 RACL MW"D 68 1 OHMM 4 4 5 RACH MW"D 68 1 OHMM 4 4 6 ROPS MW"D 68 1 FPHR 4 4 7 RPTH MW"D 68 1 MINS 4 4 8 TCDM MW"D 68 1 DEGF 4 4 ------- 32 0) # MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DIR CCN ORD MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL CAL. COR. NEUTRON OPT. ROT. DENSITY MULT. PROP. RES IS. G.AMJ:vIA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: # ) 65.8 67.7 TOOL NUMBER DAS 1234 CCN 4331 ORD 29293 MPR 22008 SRIG 31867 8.500 9473.0 LSND 9.50 .0 .0 300 .0 .000 .000 .000 .000 120.0 .0 .0 .0 SANDSTONE 2.65 .000 .0 o BIT RUN 4 (MWD Run 5) . GR/MPR/ORD/CCN. The interval from 9852 to 12659 feet MD (4656 - 5761' TVD) was not logged due to an LWD tool malfunction. CURVE GLOSSARY: GRAM - G.AMJ:vIA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) BDCM - BULK DENSITY COMPENSATED (G/C3) DRHM - DENSITY CORRECTION (G/C3) DPEM - PHOTOELECTRIC CROSS SECTION (BN/E) NPCK - NEUTRON POROSITY, CALIPER & SALINITY CORRECTED (SANDSTONE PU-S) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ ) ) *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT lc-22.xtf 150 ConocoPhillips Alaska, I lC-22 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 RACL RACL RACLM 0.0 RASL RASL RACSLM 0.0 RACH RACH RACHM 0.0 RASH RASH RACSHM 0.0 BDCM BDCM BDCM 0.0 DRHM DRHM DRHM 0.0 DPEM DPEM DPEM 0.0 NPCK NPCK NPCKSM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 68 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 14 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 RACL MWD 68 1 OHMM 4 4 7 RASL MWD 68 1 OHMM 4 4 8 RACH MWD 68 1 OHMM 4 4 9 RASH MWD 68 1 OHMM 4 4 10 BDCM MWD 68 1 G/C3 4 4 TOOL NUMBER 45.4 66.5 MSB 18704 6.75 TC MEMORY 14620.0 12556.0 14579.0 o 24-DEC-02 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE # # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 14620.0 START DEPTH 12556.0 FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ log header data for each bit run in separate files. 5 .2500 7 !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: FILE016.HED *** LIS COMMENT RECORD *** 1024 LDWG .007 **** FILE HEADER **** 8 bytes 4124 bytes Minimum record length: Maximum record length: 272 records... Tape Subfile: 7 **** FILE TRAILER **** feet Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 9462.000000 10015.000000 0.250000 159 Total Data Records: 11 DRHM MWD 68 1 G/C3 4 4 12 DPEM MWD 68 1 BN/E 4 4 13 NPCK MWD 68 1 PU-S 4 4 14 ROPS MWD 68 1 FPHR 4 4 15 RPTH MWD 68 1 MINS 4 4 16 TCDM MWD 68 1 DEGF 4 4 ------- 64 ) ) ) ) DIR CCN ORD MPR GRAM $ DIRECTIONAL CAL. COR. NEUTRON OPT. ROT. DENSITY MULT. PROP. RESIS. GAMMA RAY DAS 1474 CCN 4455 ORD 12613 MPR 6207 SRIG 5078 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 9473.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: LSND 10.20 .0 .0 300 .0 .000 .000 .000 .000 130.0 .0 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): SANDSTONE 2.65 .000 # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 o # REMARKS: BIT RUN 5 (MWD Run 6). GR/MPR/ORD/CCN. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) BDCM - BULK DENSITY COMPENSATED (G/C3) DRHM - DENSITY CORRECTION (G/C3) DPEM - PHOTOELECTRIC CROSS SECTION (BN/E) NPCK - NEUTRON POROSITY, CALIPER & SALINITY CORRECTED (SANDSTONE PU-S) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN lc-22.xtf 150 ConocoPhillips Alaska, I ) ) WN FN COUN STAT lC-22 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 RACL RACL RACLM 0.0 RASL RASL RACSLM 0.0 RACH RACH RACHM 0.0 RASH RASH RACSHM 0.0 BDCM BDCM BDCM 0.0 DRHM DRHM DRHM 0.0 DPEM DPEM DPEM 0.0 NPCK NPCK NPCKSM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 68 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 14 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 16 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 RACL MWD 68 1 OHMM 4 4 7 RASL MWD 68 1 OHMM 4 4 8 RACH MWD 68 1 OHMM 4 4 9 RASH MWD 68 1 OHMM 4 4 10 BDCM MWD 68 1 G/C3 4 4 11 DRHM MWD 68 1 G/C3 4 4 12 DPEM MWD 68 1 BN/E 4 4 13 NPCK MWD 68 1 PU-S 4 4 14 ROPS MWD 68 1 FPHR 4 4 15 RPTH MWD 68 1 MINS 4 4 16 TCDM MWD 68 1 DEGF 4 4 ------- 64 ) ) Total Data Records: 590 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 12556.000000 14620.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 8 700 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 03/01/09 01 **** REEL TRAILER **** LDWG 03/01/09 AWS 01 Tape Subfile: 9 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes