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Home My WebLink About190-084 TT RR AA NN SS MM II TT TT AA LL FROM::Sandra D. Lemke, ATO-704 TO:: Meredith Guhl ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 330 W. 7 th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage, Alaska 99501 RE: Schlumberger Wireline Backlog – Kuparuk River Unit DATE: 12/19/2023 Transmitted: North Slope, Kuparuk River Unit Via hard drive data drop 3G-10 50-103-20134-00 190084_3G-10_IPROF_08Jan2023 3G-13 50-103-20137-00 190116_3G-13_Puncher_03Oct2022 3G-20 50-103-20141-00 190123_3G-20_IPROF_28Apr2022 3H-35 50-103-20805-00 219064_3H-35_IPROF_03Aug2023 3I-11A 50-029-21932-01 210074_3I-11A_SBHPS-PLUG_25Jul2023 3M-05 50-029-21706-00 187025_3M-05_TBG_09Jan2022 3O-04 50-029-21826-00 188062_3O-04_CBL Post BiSN_24Aug2023 188062_3O-04_LDL_04Jan2022 3O-06 50-029-21824-00 188060_3O-06_CBL Pre-BiSN_24Aug23 3R-18 50-029-22249-00 192017_3R-18_LDL_21Feb2022 192017_3R-18_PressTemp_22Mar2022 3S-03 50-103-20458-00 203091_3S-03_IBC-CBL_04Sep2023 203091_3S-03_MechCut_14Jul2023 9of 12 Transmittall instructions: please promptly sign, scan, and e-mail to Sandra.D.Lemke@conocophillips.com Receipt: Date: Alaska/IT-Support Services GGRE |ConocoPhillips Alaska |Office: 907.265.6947; Mobile 907.440.4512 T38395 T38396 T38397 T38398 T38399 T38400 T38401 T38402 T38403 T38404 2/29/2024 3G-10 50-103-20134-00 190084_3G-10_IPROF_08Jan2023 Kayla Junke Digitally signed by Kayla Junke Date: 2024.02.29 12:12:37 -09'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, September 20, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3G-10 KUPARUK RIV UNIT 3G-10 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/20/2023 3G-10 50-103-20134-00-00 190-084-0 W SPT 5789 1900840 1500 2829 2829 2829 2829 64 237 225 222 4YRTST P Adam Earl 8/1/2023 MIT IA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3G-10 Inspection Date: Tubing OA Packer Depth 560 1830 1790 1790IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230802192552 BBL Pumped:0.5 BBL Returned:0.5 Wednesday, September 20, 2023 Page 1 of 1          Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Sunday, November 24, 2019 7:27 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 3G-10 (PTD 190-084) End of Monitor Update Attachments: KRU 3G-10 (PTD 190-084) TIO plot 90 -day 11-24-19.JPG Chris, KRU 3G-10 (PTD 190-084) is nearing the end of its extended monitor period during gas injection. Pressure changes appear thermally induced, so CPAI plans to continue normal WAG injection operations. If future suspect behavior is observed, then the well will be reported at that time. Attached is a 90 -day TIO plot. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Sara Carlisle Well Integrity, ConocoPhillips Alaska lnc. Office: 907-659-7126 Cell: 816-868-2420 Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Friday, October 25, 2019 3:32 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: RE: KRU 3G-10 PTD#190-084 Suspect IA Pressurization on Gas Injection Chris, 3G-10 (PTD 190-084) is nearing the end of the 30 -day gas injection monitor period to investigate suspect IA pressurization. The IA pressure has increased some over the 30 -days, however, so has the well's temperature. At this time, we are considering the trend inconclusive. CPAI intends to monitor the well during gas injection for an additional 30 days. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Sara Carlisle Well Integrity, ConocoPhillips Alaska Inc. Office; 907-659-7126 Cell: 816-868-2420 From: Well Integrity Compliance Specialist WNS & CPF3 Sent: Thursday, September 26, 2019 8:23 AM To: 'chris.waIlace @alaska.gov' <chris.wallace@alaska.gov> Cc: CPA Wells Supt <n103O@conocophillips.com> Subject: RE: KRU 3G-10 PTD#190-084 Suspect IA Pressurization on Gas Injection Good morning Chris, This is an update on the KRU 3G-10 (PTD 190-084) gas injection monitor. The injector was put on gas injection after the plant maintenance ended to start the gas monitor period, however, it was only injecting for about 4 days before the well was shut-in due to a surface valving issue. CPAI plans to restart the 30 -day gas injection monitor period following the surface valving repair. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Sara Carlisle Well Integrity, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 From: Wel ntegrity Compliance Specialist WNS & CPF3 Sent: Saturday, t 17, 2019 3:43 PM To: chris.wallacera alaska_ Cc: CPA Wells Supt <n1030 cono-C hi!' s.com> Subject: KRU 3G-10 PTD#190-084 Suspect LIA"Press4rization on Gas Injection Dear Chris, Gas injector KRU 3G-10 PTD#190-084 is exhibiting suspect IA pressurizationWhikon gas injection. This well passed a witnessed MIT -IA to 1810 psi 8/3/19. CPAI intends to perform initial diagnostic inclu ' tubing packoff tests. We i Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Thursday, September 26, 2019 8:23 AM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: RE: KRU 3G-10 PTD#190-084 Suspect IA Pressurization on Gas Injection Good morning Chris, This is an update on the KRU 3G-10 (PTD 190-084) gas injection monitor. The injector was put on gas injection after the plant maintenance ended to start the gas monitor period, however, it was only injecting for about 4 days before the well was shut-in due to a surface valving issue. CPAI plans to restart the 30 -day gas injection monitor period following the surface valving repair. Please let us know if you have any questions or disagree with this plan. Regards, Rachel Kautz/Sara Carlisle Well Integrity, ConocoPhillips Alaska Inc. Office: 907-659-7126 Cell: 816-868-2420 From: Well Integrity Compliance Specialist WNS & CPF3 Sent: Saturday, August 17, 2019 3:43 PM To: chris.wallace@alaska.gov Cc: CPA Wells Supt <n1030@conocophillips.com> Subject: KRU 3G-10 PTD#190-084 Suspect IA Pressurization on Gas Injection Dear Chris, Gas injector KRU 3G-10 PTD#190-084 is exhibiting suspect IA pressurization while on gas injection. This well passed a witnessed MIT -IA to 1810 psi 8/3/19. CPAI intends to perform initial diagnostic including tubing packoff tests. We suspect the IA pressure rise is contributed to thermal fluctuations because of rate changes. After the well can return to service post plant maintenance, CPAI intends to bleed down the IA and monitor the well for 30 days while on gas injection to confirm the integrity of the well. Please let us know if you disagree with this plan forward or have any questions. Attached is a 90 -day TIO plot and a well schematic. Sincerely, Sa,ra,CarUsl i ofPibktvO / IZa-cl P ,Kaurk Well Integrity & Compliance Specialist, WNS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n2549Pcop.com Cell: 907-331-7514 1 sara.e.carlisleCa)cop.com Wallace, Chris D (CED) From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Sent: Saturday, August 17, 2019 3:43 PM To: Wallace, Chris D (CED) Cc: CPA Wells Supt Subject: KRU 3G-10 PTD#190-084 Suspect IA Pressurization on Gas Injection Attachments: 3G-10 Schematic.pdf, 3G-10 TIO 8.17.19.pdf Dear Chris, Gas injector KRU 3G-10 PTD#190-084 is exhibiting suspect IA pressurization while on gas injection. This well passed a witnessed MIT -IA to 1810 psi 8/3/19. CPAI intends to perform initial diagnostic including tubing packoff tests. We suspect the IA pressure rise is contributed to thermal fluctuations because of rate changes. After the well can return to service post plant maintenance, CPAI intends to bleed down the IA and monitor the well for 30 days while on gas injection to confirm the integrity of the well. Please let us know if you disagree with this plan forward or have any questions. Attached is a 90 -day TIO plot and a well schematic. Sincerely, Sara.Ca,rU%7.ei (ifesUw) /Ra.c]tieV Ka.utk Well Integrity & Compliance Specialist, WINS & CPF3 KOC F-218, ConocoPhillips Alaska Office: 907-659-7126 1 n2S49@co .com Cell: 907-331-7514 1 sara.e.carlisleCu)co .com MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Re DATE: Tuesday, August 6, 2019 P.I. Supervisor `l ��l LI ('Irr SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3G-10 FROM: Adam Earl KUPARUKRIV UNIT3G-10 Petroleum Inspector Sre: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3G -I0 API Well Number 50-103-20134-00-00 Inspector Name: Adam Earl Permit Number: 190-084-0 Inspection Date: 8/3/2019 ' Insp Num: mi[AGE190805I0I106 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1 30-10 IType Inj G TVD 1 5789 Tubing 2840 2840 - 2840 2840 - PTD 1 1900840 Type Testj sPT Test psi I500 IA iso 1810 • 1780 - 1780 BBL Pumped: 0.7 BBL Returned: 0.6 OA 14 20 20 20 Interval 4vRTST P/F P _ Notes: MIT IA /The well has an OOA that read zero psi for the test Tuesday, August 6, 2019 Page I of 1 - - • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Friday,August 21,2015 P.I.Supervisor I'e11 .31 /5 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3G-10 FROM: John Crisp KUPARUK RIV UNIT 3G-10 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J ' NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3G-10 API Well Number 50-103-20134-00-00 Inspector Name: John Crisp Permit Number: 190-084-0 Inspection Date: 8/15/2015 Insp Num: mitJCr150821100526 Rel Insp Num: � Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3G-10 r Type Inj w TVD 5789 Tubing I 2678 2678 • r 2679 • 2680 • i PTD I 1900840 IType Testi SPT Test psi' 1500 IA 460 2010 -1 1960 - 1950 - Interval I4YRTST f P/F P `/ OA 1 147 533 - { 515 - 511 Notes: 3 bbls pumped for test. - SCANNED Friday,August 21,2015 Page 1 of 1 Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. Num,,er we,, H,s,o ,',,e PAGES TO DELETE Complete RESCAN [] Color items - Pages: [] Grayscale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other Scanned by: Bevedy~incent TO RE-SCAN Nathan Lowell Notes: Re-Scanned by: Beverly Bren Vincent Nathan Lowell Date: /si NOTScanned.wpd " • • Page 1 of 2 Regg, James B (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] k u Sent: Thursday, September 08, 2011 7:08 PM 7 1111/1 � 1q005,40 To: Regg, James B (DOA); NSK Problem Well Supv t Cc: Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Subject: RE: Witnessed MITIA's on 3G pad, 1B-02, and 1E-08A Jim, I was not aware of the 8 -20 -11 due date. Unfortunately, I was under the impression that the pad MIT testing was always due by the end of the anniversary month (and not the anniversary date); therefore no extension was requested. There was a CPF3 shutdown on Aug 17 which lasted for 5 days. Then, pumping resources were tight which didn't allow us to schedule the testing till August 30. I realize ignorance is no excuse. I will do my best to ensure that this does not happen again. Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Tuesday, September 06, 2011 10:36 AM To: NSK Problem Well Supv Cc: Maunder, Thomas E (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Subject: RE: Witnessed MITIA's on 3G pad, 1B -02, and 1E -08A t/ MIT due date for KRU 3G injectors was 8- 20 -11; reminder that Industry Guidance Document 10 -002 clarified test dates (at request of the industry) for MITs; tests are required on or before anniversary date unless a specific due date is established (e.g., admin approval). If delay was communicated to Commission, include who granted extension. 3G -10: Packer TVD does not match our database; should be 5687 ft based on past efforts to make sure CPAI and AOGCC packer TVDs match; actual test pressure ok 16-02: Packer TVD is 6102 ft according to our data; actual test pressure ok Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: NSK Problem Well Supv [ mailto :n1617 @conocophillips.com] Sent: Saturday, September 03, 2011 2:06 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Brooks, Phoebe L (DOA); DOA AOGCC Prudhoe Bay Subject: Witnessed MITIA's on 3G pad, 1B -02, and 1E -08A All, 9/9/2011 Page 2 of 2 Attached are the test forms for the witnessed MITIA's that were performed on 08 -30. 1 B -02 is scheduled to be retested on 09/06/11 due to a plant upset and the injection temperature has been varying about 20 degrees up and down. Please let me know if you have any questions. Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 9/9/2011 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, September 07, 2011 TO: Jim Regg C/ P.I. Supervisor ` 4 fr {I SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3G -10 FROM: Jeff Jones KUPARUK RIV UNIT 3G -10 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry ,'1 C-- NON- CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 3G -10 API Well Number: 50- 103 - 20134 -00 -00 Inspector Name: Jeff Jones Insp Num: mitJJ110906080439 Permit Number: 190 -084 -0 Inspection Date: 8/30/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well T 3G -10 - I - Type Inj. G "I TVD { I 5698 IA 1375 2320 ' 2290 2290 ' P.T.D 19008ao TypeTest SPT Test psi 150o OA 738 924 917 914 — Interval 4YRTST - P/F P - Tubing 2892 2900 1 2900 2899 Notes: 0.5 BBLS diesel pumped. 1 well inspected; no exceptions noted. - Wednesday, September 07, 2011 Page 1 of 1 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, March 23, 2011 TO: Jim Regg '� P.I. Supervisor 7 1 / it SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3G -10 FROM: Chuck Scheve KUPARUK RIV UNIT 3G -10 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv_-JR NON- CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 3G - 10 • API Well Number: 50 103 - 20134 - 00 - 00 Inspector Name: Chuck Scheve Insp Num: mitCS110322164356 Permit Number: 190 - 084 - Inspection Date: 3/22/2011 Rd Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1 3G-10, Type Inj. ' W ` '' TVD 5698 7 IA 500 2210 - I 2180 2180 - P. T.D 1900840 'T ypeTest SPT Test psi , 1500 - OA I 180 600 600 600 Interval INITAL _ P/F P Tu 1 1465 1465 1465 I 1465 Notes: Operator paper work indicates post workover packer TVD at 5698'. Wednesday, March 23, 2011 Page 1 of 1 STATE OF ALASKA y ALASKA . AND GAS CONSERVATION COMMIS ` REPORT OF SUNDRY WELL OPERAT NS 1. Operations Performed: Abandon r Repair well F Plug Frrrforations r Stimulate r Other r Alter Casing Rill Tubing Perforate New Pool r" Waiver r Time Extension Change Approved Program [ Operat. Shutdow n r Perforate r Re -enter Suspended Well r- 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 190 - 084 3. Address: 6. API Number: Stratigraphic r Service P. O. Box 100360, Anchorage, Alaska 99510 w 50 - 103 20134 - 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25547 -•• 3G - 1 9. Field /Pool(s): M Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 8250 feet Plugs (measured) 7872 true vertical 6118 feet Junk (measured) None Effective Depth measured 8156' feet Packer (measured) 7633', 7728', 7860' true vertical 6060 feet (true vertucal) 5726', 5789', 5875' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 115 115 SURFACE 3748 9 -5/8" 3783 3035 PRODUCTION 8208 7" 8241 6112 LINER 7688' 5.5" 7724' 5786' Perforation depth: Measured depth: 7776'- 7834', 7888'- 7904', 7926' -7946' ' r (; 1 !UP True Vertical Depth: 5820'- 5858', 5892'- 5903', 5917' -5929' egg ,? P flit& t ' a*" Tubing (size, grade, MD, and TVD) 3.5, L -80, 7609 MD, 5710 TVD VI"I6l "wage Packers & SSSV (type, MD, and TVD) PACKER - CAMCO'HRP -I -SP' RETRIEVABLE PAC @ 7728 MD and 5789 TVD PACKER - TIW 'SS' PERMANENT PACKE 860 M nd 5875 TVD PACKER - BAKER PREMIER PRODUCTIO PACKER @ 7633 MD and 5726 TVD CAMCO 'DS' NIPPLE @ 521' MD and 521' TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable FEB 0 3 ZU1 Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 2090 Subsequent to operation si 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory E Development r Service Stratigraphic r 15. Well Status after work: Oil r Gas r WDSPL Daily Report of Well Operations XXX ` GSTOR r WIND ' WAG 1 GINJ r SUSP r SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310 -411 Contact Erik Nelson @ 263 -4693 Printed Name ik Nel Title Wells Engineer / Signature Phone: 263 -4693 Date ` DMS FEB G � 2011 V I ate wi Form 10-404 Revised 10/2010 /� Submit Original Only .? —/- // 2/4 v . �� KUP 3G -10 i _ ConacoPhil i Well Attributes 1Max Angle & MD TD Alaska 1 Wellborn APUUWI Field Name Well Status Incl (°) MD (ftKB) Act Btm (ftKB) /' . 501032013400 II INJ 51 81 - Comment ent �(UP;RU YSIVEH UN Date Annotation of ton End Date KB -Grd 9J 8 260 0 rd (ft) (ft) RigRl e Date _WOIII Cgnfig, 39'14,100/2011 ,38.36 PM C NIPPLE WO: l/162611 36 _ 8/8/1990 _ . 8604.30050 g12ua1 Annotation De _ � h HKB End Date Annotation IL M t d. -. End Date Last Tag: SLM 8,090.0 12/11/2010 I Rev Reason NEW WELL Imosbor l 1/26/2011 Casing Strin.s li 1 „ • _ Casing Description String 0... String ID . Top (866) Set Depth (f... Set Depth (ND) .. String Wt... String String Top Thrd HANGER, 36 ' CONDUCTO 16 15 062 36.0 115.0 115.0 62.50 H-40 WELDED ,. Casing Description String 0... String ID _ Top (H1(8) Set Depth (T.. Set Depth (ND) ... String Wt... String ... String Top Thrd j SURFACE 9 5/8 8.921 35.0 3,7810 3,034.6 36.00 J BTC j Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND)... String Wt... String... String Top Thrd PRODUCTION . Tom 7 6151 330 1,8313 1,662.1 26.00 J -55 BTC -MOD -_ _- f - ...._.- Casing Description String 0... String ID . . . Top (ftY(B) Set Depth (L.. Sat Depth (ND) ... String Wt... String ... String Top Thrd ,. PRODUCTION Btm 7 6.151 1,831.3 8,241.1 6,112.2 26.00 J - 55 BTC Casing Descnption String 0... String ID ... Top (HKB) Set Depth (8... Set Depth (ND) ... String WI... String String Top Thrd LINER 51/2 4.950 36.0 7,724 -0 5,786.4 15.50 L -80 BTC -M Liner Details CONDUCTOR, Top Depth 36 -115 (ND) Top Inc! Nomi... To. HKBJ (HKB) ( °) It Descript Comment ID (in) NIPPLE, 521 A 7,592.1 5,698.8 47 59 XO BUSHING I CROSSOVER BUSHING _ 4 -490 " 7,593 -7 5,699.5 47.60 SBE iBaker 80-40 Seal Bore Extension 4.000 7,612.5 5,712.5 48.33 XO BUSHING CROSSOVER BUSHING 2.980 ,I 7,633.1 5,726.4 48.48 PACKER BAKER PREMIER PRODUCTION PACKER 589 -287 2.980 PRODUCTION . I ':1 7,6 ' . 91.1 5,764.8 4887 NIPPLE HES 'X' NIPPLE 2.812 Top,33 - 1,831 ' 7,7 10.9 5,777 8 49 00 LOCATOR LOCATOR SUB 3.000 r iI 77 12.2 5,778.7 49.01 SEAL ASSY ,CAMCO SEAL ASSEMBLY WITH NO SEALS 3.000 i SURFACE, Tubing Strings 353,783 4 Tubing Description String 0 String ID .. Top (ftKB) Set Depth (f.. -'Set Depth (ND) ... IStr ng Wt... !String (String Top Thrd I TUBING 3 1,2 2.992 36 0 7,609 4 5,710.4 9 30 L 1 IBT wJECnoN._ _ 1s - Completion Details k. Top Depth Inc; . -_. ..... NIPPLE, 7,567 , ' ND N inn Top F To• 8) (HKB) c) Item Description Comment ID (i -- � S ; ` 36 D 36.0 0.23 HANGER McEvoy Gen 4 Tubing Hanger Type: DP- 1 -DS -3 2.950 :.' 521.31 521.0 6.65 NIPPLE 3 1/2" Camco "DS" Nipple 2.875" 2.875 iF 7,566.7 :1,681.6 47.41 NIPPLE 31 /2 "HES 2.812"X Nipple 2.812 { 7,586.3 5,694.9 47.55 LOCATOR Locator Sub ( +3 ft Stick -up) 2.850 LOCATOR, -° 7,590.1 5,697.5 47 58 SEAL ASSY Baker 80 -40 GHB -22 LTSA IBTN w /SCC 2.980 7,586 ( t completion DQt I Str O.. !Strn ID... T HKB) Se t De th f... Set De th .6 Strm Wt... S StAn To Thrd T bin Des ri 9 9 oP ( P ( P ( ) 9 9 9 P `✓ - / / TUBING Original 3 V2 2 992 ( 7 714 6 I 78789 I 5886 6 9.30 I l 80 �- AB MOD IPC sEALASSV,- ails 7.590 - - p Top Depth (ND) Top Inc! Nami... Top (ftKB) (668) (°) Item Description Comment ID (in) 7314.6 5,780.2 49.03 PBR CAMCO 10' STROKE PBR 2.937 7,728.0 5,789.0 49.12 PACKER CAMCO HRP -1 -SP RETRIEVABLE PACKER 2.867 a: -- ' ,: 7,850.9 5,868.7 50.42 NIPPLE AVA BPL NIPPLE 2.750 IP . 7,857.7 5,873.0 50.47 XO Reducing CROSSOVER 3.5 x 2.875 2.875 7,858.3 5,873.4 50.47 SEAL ASSY TIW LOCATOR SEAL ASSEMBLY 2.589 7,860.1 5,874.6 50.48 PACKER TIW SS PERMANENT PACKER 3.210 lit t. 7,863.3 5,876.6 50.51 SBE SEAL BORE EXTENSION 3.270 is 7,872.4 5,882.4 50.57 NIPPLE CAMCO D NIPPLE NO GO 2.250 SOS CAMCO SHEAR OUT SUB 2.441 PBR,7,735- i q Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) LINER, 4 I Top Depth I 36 -7,724 I (TVD) Top Intl i PACKER, 7,728 -- '; Top (HKB) (668) ( °) Description Comment Run Date ID (in) - ' 7,850.9 5,868.7 50.42 SLEEVE - O 2.75" AVA TPC (OAL =29") - FULL OPEN 12/20/2010 12/20/2010 2.310 4 INJECTION, L Vi i_. 7,871A 5,881.8 50.56 CATCHER CATCHER SET ABOVE PLUG 12/20/2010 0.000 7,744 7,872.4 5,882.4 50.57 PLUG CA -2 PLUG 12/20/2010 0.000 IPERF, + Perfor ns $. Slots _._._ n« 7,776.7.834 s._... Top (TM) Btm (TVD) Dens Top (ftKB) Ben (6103) (RIGB) (NKB) Zone Date (ah-. Type Comment 7,776.0 7,834.0 5,820.3 5,857.8 C -4, C -3, C -2, 2/3/1991 10.0 IPERF 4.5" Csg Gun; 60 deg ph C -1, 3G -10 7,888.0 7,904.0 5,892.4 5,902.7 A -3, 3G -10 2/3/1991 4.0 IPERF 4.5" Csg Gun; 180 deg ph - 7,926 -. NIPPLE, 7,651 = . 0 7,946.0 5,916.5 5,929.0 A - 2, 3G - 10 2/3/1991 4.0 0 IPERF 4.5" Csg Gun; 180 deg ph SLEEVE -O, N 7,851 Notes: General & Safety End Date Annotation 2/21/1991 NOTE Walvered well for water Injection only SEAL ASSY, 7,858 - - -1 2/22/1991 NOTE Possible hole In 9 -5/8" surface CSG between surface & 1800' . . 8/30/201'0 NOTE: View Schematic w/ Alaska Schematic9.0 PACKER. 7,860 SBE, 7,863 "' Mandrel Details Top Depth Top Port I NIPPLE, 7,872 Ste' )TVDI Inc! OD Valve Latch I Sae TRO Run CATCHER, 7,871 To•(ftKB) (ftK6) ( Make Model G ^) Sery Type tYPe ON (PM) Run Date Com... PLUG,7,872 , --- __ .... _ 7 5.G4 8.1 47.05 CAMCO KBG 2 -9 INJ SOV DCK 0.000 0.0 1/16/2011 2 7,744. s. /99.6 49.23 CAMCO MMG -W INJ DMY RKP 0.000 0.0 2/6/1991 SOS, 7,878 ' 7.688 -7.904 _ IPERF, -, 7,928 -7,946 PRODUCTION at, 1,831 -8,241 \ TD, 6,250 3G -10 Pre -Rig Work DATE SUMMARY ,11/11/10 PRE RWO T -POT ( PASSED ), T- OT ( PASSED ), IC -POT ( PASSED ), I POT ( PASSED) FT -LDS ALL NORMAL. 12/11/10 TAGGED @ 8090' RKB, EST. 144' RATHOLE. SET 2.25 CA -2 WITH PANEX GAUGES @ 7872' RKB. RETURN IN 3 DAYS FOR BHP. 12/18/10 PERFORM 30 MIN SBHP @ 7860' RKB =3579 PSI, 128 DEG F. 15 MIN GRADIENT © 7707' = 3535 PSI. JOB IN PROGRESS 12/19/10 PULL CA -2 PLUG & GAUGES @ 7872', PULL 2.75" AVA TPC @ 7851', BRUSH & FLUSH SSSV @ 1791'. JOB IN PROGRESS 12/20/10 SET 2.75" NEW STYLE AVA TPI @ 7851'. ATTEMPT TO FUNCTION TEST SSSV, LOCKOUT SSSV © 1791'. SET 2.25" CA -2 PLUG @ 7872'. P/T TBG TO 2500 PSI, BLEED TBG TO 0 PSI FOR 15 MIN (GOOD TEST). SET 2.73" X 88" CATCHER @ 7851' RKB, PULL DV @ 7658' RKB. JOB COMPLETE 12/31/10 CUT 3.5" TUBING IN THE MIDDLE OF FIRST FULL JOINT(7692') ABOVE PBR(7715') RCT CUT DEPTH =7692' CCL -MID CUTTER HEAD =9.4' OFFSET, CCL STOP DEPTH =7682' • • ConocoPhillips Time Log & Summary We/N/ew Web Reporting Report Well Name: 3G - 10 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 1/6/2011 9:30:00 AM Rig Release: 1/16/2011 9:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01/05/2011 24 hr Summary PJSM on rig move from 3A Pad to 3G Pad. Road rig from 3A towards 3B. 22:00 00:00 2.00 MIRU MOVE MOB P Held PJSM and road rig from 3A pad to 1/2 mile short of 3B pad. 01/06/2011 Continue to road past 3B pad to 3G Pad. Load tree in cellar and spot well head equip behind well. MIRU, Kill well, ND Tree, adapter and studs. 00:00 06:00 6.00 MIRU MOVE MOB P Continue to move rig from 3 A pad access road to 3F pad. 06:00 07:00 1.00 MIRU MOVE MOB P Grease plantaries. 07:00 09:00 2.00 MIRU MOVE MOB P Move rig from 3F -pad to 3G -pad 09:00 10:00 1.00 MIRU MOVE MOB P PJSM. Hang new tree in rig cellar, spot additional wellhead equipment behind wellhead. Accept rig at 09:30 on 01- 06 -11. 10:00 11:30 1.50 MIRU MOVE MOB P PJSM. Move rig over wellhead, spot additional equipment. 11:30 13:30 2.00 COMPZ WHDBO KLWL P PJSM. Pick -up BPV lubricator and lubricate out BPV, lay down equipment. 13:30 16:30 3.00 COMPZ WHDBO KLWL P Rig -up circulating lines, load pits, rig -up hardline to return tank. 16:30 19:30 3.00 COMPZ WHDBO KLWL P PJSM. PT lines to 4,000 psi, bleed tbg /casing SIWHP 1,100 psi and casing 250 psi, both bled to 0 psi. Displace well with 10.8 KWF to surface. approximately 250 bbls Ca 4 BPM, good returns. Monitor well 30 mins, well static. ? 19:30 20:30 1.00 COMPZ WHDBO KLWL P Rig down circulating equipment, set <pit BPV. 20:30 00:00 3.50 COMPZ WHDBO NUND P PJSM. ND tree, adapter, and studs.. 01/07/2011 Perform initial BOPE function test. Unland tubing hanger, circulate 1.5 well volumes 540 bbls KWF, pull 3.5" completion to 4,600 -ft. Set storm packer and test, ND BOP stack. 00:00 05:00 5.00 COMPZ WHDBO NUND P NU BOPE 05:00 09:30 4.50 COMPZ WHDBO BOPE P Perform initial BOPE test. Function and PT BOP rams and choke manifold to 250/4,000 psi, PT annular to 250/3,500 psi. AOGCC waived test (Jeff Jones) at 06:35 on 01- 06 -11. 09:30 10:00 0.50 COMPZ WHDBO MPSP P Pull Test plug and lay down dry rod. Page 1 of 8 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:00 11:00 1.00 COMPZ RPCOM PULD P PU and MU 3 1/2 Landing pup jts. BOLDS, Pull hanger to rig floor. Un landed at 50k Pulled,,50k - cut parted UP wt @ 100k while pulling TBG hanger to floor. 11:00 13:00 2.00 COMPZ RPCOM CIRC P Circulate 540 bbls at 4 bpm @ 300 psi. while RU and blowing down OA to kill tank. RU control line spooler. 13:00 21:30 8.50 COMPZ RPCOM PULD P POOH laying down 3 1/2" TBG spooling control line for the first 1,791 -ft. control line was dragging and had missing bands. Pull to SSSV and lay down. Had recovered 23 of 32 SS Bands. Continue to POOH laying to 4,600 -ft. left in hole. PU Baker storm packer and RIH to 50 -ft from surface and set. Up weight 72K Down weight 65K. 21:30 23:00 1.50 COMPZ RPCOM PRTS P Test Baker storm packer to 1,500 psi, good test. Bleed packer to 0 psi, test good. 23:00 00:00 1.00 COMPZ RPCOM NUND P ND BOPE, recovered two stainless steal C/L bands from drip pan, seven still missing downhole. 01/08/2011 ND tubing head, 7" casing growing, cut 13" from casing stub. NU casing head and test to 3,000 psi. NU BOP stack and shell test break to 3,000 psi. Release and retrieve 7" Baker storm packer. TOH w/ 3.5" completion from 4,618' to 3,295. 00:00 01:30 1.50 COMPZ RPCOM NUND P ND BOP stack. 01:30 02:00 0.50 COMPZ RPCOM SFTY P Held PJSM with rig crew on removing 7 1/16" 5m x 11" 3m TBG Head 02:00 09:00 7.00 COMPZ RPCOM NUND P Begin ND tubing head, found 7" CSG string to be growing. Call out PESIAK for Hydrotight. RU unit and allow CSG to grow 3.875 ". Initial pressure was 5,000 psi., Final pressure was 150 psi. in 8 cycles. RD Hydrotight. 09:00 09:30 0.50 COMPZ RPCOM FISH P Spear 7" CSG, pull 150k on wt. indicator - set Emergency slips and land csg in 115k tension. Release spear and lay down same. 09:30 11:00 1.50 COMPZ RPCOM CPBO P Cut 7" CSG stub with Wachs cutter, _ remove 13" of stub. Pulled original 7" pack off. MU "New" 7" pack off and set. Energize the same. Page 2 of 8 • Time Logs Date From To Dur S. Depth E. Depth Phase - Code Subcode T Comment 11:00 18:30 7.50 COMPZ RPCOM DHEQ P NU 11" 3m CSG spool, test pack off at 250/3,000 - lower seal failed. Pull and replace. Test at 250/3,000 - good test. Set adapter spool. NU 11" Class III BOP stack. 18:30 20:30 2.00 COMPZ RPCOM NUND P PJSM. Set test plug and shell test break to 250/3,000 psi. 20:30 22:00 1.50 COMPZ RPCOM PULD P PJSM. Release and retrieve Baker storm packer, lay down same. 22:00 00:00 2.00 4,618 3,295 COMPZ RPCOM TRIP P PJSM. TOH w/ 3.5" completion from 4,618' to 3,295' laying down sideways. Up weight 60K Down weight 55K. 01/09/2011 Pull remaining 3.5" completion. Load and tally 5.5" inner casing string in pipe shed. Change out upper /lower pipe rams from variable to 5 1/2" and test. Set down while RIH w/ 5.5" casing at 609', POOH and lay down same. Decision made to run PDS caliper survey on Slickline. Prep rig floor for S/L operations. 00:00 05:00 5.00 3,295 0 COMPZ RPCOM TRIP P Continue TOH w/ remaining 3.5" completion. On surface with seal assembly, tubing not cut, lay down assembly. 05:00 13:00 8.00 COMPZ RPCOM OTHR P Load pipe shed with Baker premier packer assembly, load and tally 5.5" casing. Sim ops - Change LPR's, UPR's From 3 1/2 to 5 1/2" 13:00 15:30 2.50 COMPZ RPCOM BOPE P Test LPR's, UPR's and Annular at V 250/3,000 psi. Had to field service Test plug. 15:30 16:00 0.50 COMPZ RPCOM SFTY P Held PJSM and reviewed run order. Discussed pinch points and hand -foot placement. 16:00 18:30 2.50 609 0 COMPZ RPCOM PULD P PU and RIH with 5 1/2 Inner string as per run order. Start in hole to 609', tagged up, work pipe up several times, stack out to 10K several times, unable to make hole. POOH and found indiratinns on the bottom of the packer - Packer depth in correlation to tail depth was 515 -ft ± 18:30 22:00 3.50 COMPZ RPCOM PULD P TOOH w/ 5.5" casing, lay down same, small medal mark on lower end on packer shoulder. Decision made to run PDS caliper on Slickline. 22:00 22:30 0.50 COMPZ RPCOM PULD P Install wear bushing. 22:30 00:00 1.50 COMPZ RPCOM PULD P Load shooting nipple in pipe shed, prep floor for Slickline operations. 01/10/2011 Run Caliper Survey f/ 7,707 -ft. to surface. Load pipe shed w/ 3 1/2" DP. Pull wear ring and set 11" test plug. Change out 5 1/2 rams to 3 1/2. Test BOP rams and annular at 250/3,000 psi. Annular failed - change out element. 00:00 02:00 2.00 COMPZ RPCOM SLKL P Continue prepping rig floor for S/L operations, MU 7" shooting flange. 02:00 04:30 2.50 COMPZ RPCOM SLKL P PJSM. MIRU Hes S/L unit and PDS memory logging tools. MU CCUGAMMA/ 40 Arm Caliper. Page 3 of 8 • 4 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 08:30 4.00 COMPZ RPCOM SLKL P Make caliper survey run to 7,700' to surface @ 50 fpm. 08:30 09:30 1.00 COMPZ RPCOM SLKL P Check Caliper to data, good data. RDMO HES Slickline and PDS equipment. 09:30 13:30 4.00 COMPZ RPCOM PULD P Load & Tally 3.5" drill pipe. Load BHA. Pull wear bushing. 13:30 16:30 3.00 COMPZ RPCOM PULD P Change out upper /lower pipe rams to 2 7/8" by 5" VBR's. ( � 16:30 21:00 4.50 COMPZ RPCOM RURD P RU to test pipe rams and annular, 'U� unable to get test on annular. Drain stack and test blind rams 250/3,000 psi. 21:00 00:00 3.00 COMPZ RPCOM RURD P Change out annular. 01/11/2011 Change out Annular Element and test same. Swedge out restriction in 7" Casing at 515 -ft. Make -up a Dummy Drift to simulate the Completion Packer configuration. Pass through restricted area with no problems. POOH and lay down Dummy Drift Assembly. 00:00 04:00 4.00 COMPZ RIGMNT EQRP T Continue to change out 11" 5m annular element. 04:00 05:00 1.00 COMPZ WELCTL BOPE P Test annular with 3 1/2 test joint to 250/3,000 psi. 05:00 06:00 1.00 0 209 COMPZ RPCOM PULD P Set wear ring, PU and RIH w/ 6 1/8" bit, 7" csg scraper assy to 209 -ft 06:00 07:00 1.00 209 515 COMPZ RPCOM PULD P RIH with BHA #1 from 209 -ft picking up 3 1/2 DP to 515 -ft. (15 -ft in on jt #10) 07:00 07:15 0.25 515 515 COMPZ RPCOM SFTY P Held PJSM on loading shed with next BHA components and POOH with BHA #1 07:15 07:45 0.50 515 0 COMPZ RPCOM TRIP P POOH with BHA #1 and lay down same Recovered 1 more SS Band fora total of 28 of 32 07:45 08:15 0.50 515 COMPZ RPCOM SFTY P Held PJSM on loading shed with next BHA components 08:15 08:45 0.50 515 515 COMPZ RPCOM OTHR P Load pipe shed with next BHA components 08:45 10:15 1.50 0 600 COMPZ RPCOM TRIP P MU BHA #2 5.63" casing swage and RIH to 600 -ft, no restriction @ 515' -ft. POOH and lat down same. 10:15 12:00 1.75 0 600 COMPZ RPCOM SWDG P MU BHA #3 5.75" casing swage and RIH to 600 -ft, only minimum restriction @ 515' -ft, work through several times, POOH with BHA and lay down same. 12:00 14:30 2.50 0 600 COMPZ RPCOM SWDG P MU RHA #4 6.00" casing swage and RIH to 600 -ft, took several jar licks down 5 -6 to work through restriction and 20 -25 to work back through, work swage through restriction several times @ 515' -ft, POOH with BHA and lay down same. Page 4 of 8 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:30 19:00 4.50 0 515 COMPZ RPCOM SWDG P MU BHA #5 6.125" casing swage, RIH to 515 -ft. Continue to work Casing Swedge through restricted section. Finally able to pass through. However, it takes 15K - 20K to pass through going down and —40 k to pull back up. Repeat 6 times with same results. Discuss results and plan forward with anchorage Engineer. 19:00 19:30 0.50 515 515 COMPZ RPCOM SVRG P Perform Derrick and Top Drive inspection. 19:30 21:30 2.00 515 0 COMPZ RPCOM TRIP P PJSM. Trip out with BHA #5 and lay down same. 21:30 23:00 1.50 0 600 COMPZ RPCOM TRIP P PJSM. Make up BHA #6 Drift Run as follows: 6" Swedge, 1 1.0 4 3/4" Drill, 5 3/4" Swedge. RIH to the restricted area at 515 -ft. Passed through with no problems. Continue down to 600 -ft. Repeat through restricted area, again with no problems. 23:00 00:00 1.00 600 0 COMPZ RPCOM TRIP P Single down the 3 1/2" Drill Pipe and Drill Collars. in Pipe Shed. 01/12/2011 Lay down Drill Pipe and Drill Collars. Lay down Dummy Drift Assembly. Change both Pipe Rams to 5 1/2" solids and test same. Pressure test the 7" Casing at 3,000 psi. Begin running the 5 1/2" Completion as designed. 00:00 00:30 0.50 0 0 COMPZ RPCOM TRIP P Finish lay down Dummy Drift Assembly. 00:30 02:00 1.50 0 0 COMPZ RPCOM PRTS P Test 7" Casing at 1,500 psi x 15 minutes. OA pressure 0 psi. Good test. Record on chart. 02:00 08:00 6.00 0 0 COMPZ RPCOM NUND P PJSM. Pull Wear Bushing. Install Test Plug. Pull both sets of 2 7/8" x 5" VB Pipe Rams and install 5 1/2" Pipe Rams in both gates. Test both sets of 5 1/2" Pipe Rams at 250/3,000 psi. Pull test plug. 08:00 09:00 1.00 0 0 COMPZ RPCOM DHEQ P PT 7" casing to 3,000 psi for 30 mins. Good test. Record on chart. 09:00 10:00 1.00 0 0 COMPZ RPCOM OTHR P Prep rig floor to run 5.5" IBT completion. Decision made to run seal assembly from old completion. 10:00 12:00 2.00 0 0 COMPZ RPCOM PULD T Wait on seal assembly recovery. Old seal assembly on location, remove seals. 12:00 13:00 1.00 0 COMPZ RPCOM PULD P MU lower 3.5" packer assembly/ X nipple/ seal assembly. 13:00 14:30 1.50 COMPZ RPCOM TRIP P TIH w/ packer assembly on 5.5" IBT to 515 -ft, set down on crossover bushing (6.07 ") in tight spot, rotate 1/2 turn and fell through restriction. 14:30 00:00 9.50 6,975 COMPZ RPCOM TRIP P Continue in hole with 5.5" completion to 6,975 -ft. Up Weight = 132K. Down Weight = 95K. Page 5 of 8 Time Logs S Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01/13/2011 24 hr Summary Finish running the 5 1/2" Casing. Tag the Camco PBR. Space out. RU S -Line to verify. Reverse in with Corr Inhib Brine, followed by Isotherm to freeze protect the Annulus. RU S -Line and set Plug. Set Packer. Test 7" x 5 1/2" Annulus. ND BOP Stack. Set 5 1/2" Slips. Cut -off 5 1/2" Casing. 00:00 01:30 1.50 6,975 7,714 COMPZ RPCOM TRIP P Finish running the 5 1/2" Completion from 6,795 -ft 01:30 05:00 3.50 7,714 COMPZ RPCOM HOSO P Tag the Camco PBR at 7,714 -ft the the Seal Assembly (No Seals) on Joint 181. Swallow down to No -Go on Dummy Seal Assembly. Pull back out of PBR. Bring pump on line at 2.0 bpm /390 psi. Enter the PBR again and No -Go at same place with the pressure increasing to 470 psi. Lay down Joint # 181 and #180. Add a 20.30 -ft Pup Joint Pick Joint 180 back up and space -out with the No -Go 2 -ft above the PBR. 05:00 09:00 4.00 COMPZ RPCOM SLKL P PJSM. Rig up S- (Line. RIH w/ 2.64" drift to 7,851 -ft, tag top of AVA BPL nipple, no issues.POOH. Stand back S /L. 09:00 10:30 1.50 COMPZ RPCOM CIRC P PJSM. RU circulating equipment. Close bag, circulate down annulus with 48 bbls 10.8 ppg CI brine followed by 22 bbls 7.0 ppg insulating packer fluid (Isotherm) ft 2 bpm 350 ICP. 10:30 13:00 2.50 COMPZ RPCOM SLKL P PJSM. RU Slickline, RIH w/ 2.813" X plug to 7,692 -ft, set plug. POOH. Test plug to 1,500 psi for 15 mins, good test. 13:00 15:00 2.00 COMPZ RPCOM SLKL P RIH w/ 3" GS and Catcher sub (52 ") to set above plug 7,692 -ft. POOH. RDMO S /L. 15 :00 16:00 1.00 COMPZ RPCOM DHEQ P Pressure up to 4,000 psi on 5.5" casing to set packer. PT,7" X 5 1/2" annulus to 1,500 psi, good test. 16:00 00:00 8.00 COMPZ RPCOM NUND P Pull 20 K over string weight. ND BOPE and pick -up BOP Stack. Cut off 5 1/2" Casing with Wacks Cutter. Lay down Cut -Off Joint (26.78 -ft). Set BOP Stack back on Stump. 01/14/2011 Install Pack -Off. NU Tbg Head. Test Pack -Off. NU BOP Stack. Install 2 7/8" x 5" VB Pipe Rams. Test Rams and body breaks. Load, tally, and drift the 3 1/2" Completion Tubing. Beging to single in with the 3 1/2" completion Section. 00:00 03:00 3.00 COMPZ RPCOM NUND P PJSM. Install 5 1/2" Pack -Off. Nipple up Type S -YB 11" 5,000 psi top x 11" 3,000 psi bottom Tubing Spool. Test Pack - Off /Hanger void at 3,000 psi. x 10 minutes. Good test. 03:00 09:00 6.00 COMPZ RPCOM NUND P PJSM. Nipple up BOP Stack. 09:00 15:00 6.00 COMPZ RPCOM BOPE P Change out upper /lower pipe rams to 2 7/8" X 5" VBR's and test 250/4,000 V / psi. Page 6 of 8 Time Logs Date From To Dur S. Depth E. Depth Phase Code - Subcode T Comment 15:00 21:00 6.00 COMPZ RPCOM PUTB P Finish loading pipe shed with 250 jts of tubing, drift and tally same. 21:00 00:00 3.00 0 2,675 COMPZ RPCOM PUTB P PJSM. Perform final Jewelry check. Make -up the 3 1/2" Completion Equipment as follows: Baker 80 -40 Seal Assembly, XO Pup Joint, 2.813" X- Nipple Assembly, 1 Joint of 3 1/2" 9.3 lb /ft L -80 IBT -M w /SCC Tubing, 3 1/2" x 1" GLM Assembly w /DCK Shear Valve. Begin to single in with 3 1/2" 9.3 lb /ft L -80 IBT -M w /SCC Tubing from Pipe Shed to 2,675 -ft. Up Weight = 52K. Down Weight = 52K. 01/15/2011 Continue to single in with the 3 1/2" Completion section. Space out. Make -up tubing Hanger. Displace Well over to Sea Water. Pump Corr Inhib Sea Water down annulus. Land Tubing Hanger. RILDS. ND BOPE. NU Tree and test same. 00:00 06:00 6.00 2,675 7,545 COMPZ RPCOM PUTB P Continue to single in the 3 1/2" Completion section from 2,675 -ft. Pick -up 2.875" DB- Nipple Assembly. continue to single in 3 1/2" Completion. Pick -up Joint 244. Make -up Head Pin on Joint 245. Tag 06:00 07:00 1.00 7,545 COMPZ RPCOM PUTB P Get up /down weights, 95K up 73K down. Locate seals with charge pump @ min. rate, shut down pump, engage locator. 07:00 08:00 1.00 COMPZ RPCOM PULD P Space -out, lay down joints 245,244,243, add two pups at 5.83' and joint 243, MU hanger and landing joint. 08:00 09:00 1.00 COMPZ RPCOM CIRC P Circulate out 10.8 ppg brine with seawater, pulled 160 bbls total. 09:00 13:00 4.00 COMPZ RPCOM CIRC T Wait on truck with CI seawater. Truck had mechanical issues. 13:00 14:00 1.00 COMPZ RPCOM CIRC P Pump 90 bbls Corrision inhibited seawater down annulus. 14:00 15:00 1.00 COMPZ RPCOM RCST P Locate seals, land hanger. RILDS. 15:00 16:00 1.00 COMPZ RPCOM DHEQ P PT tubing to 3,000 psi, monitor annulus for returns, no returns, good test, bleed tubing to 2,200 psi. RI, annulus to 3,500 psi for 30 minutes. •,� 1 ff chart test. Bleed tubing /casing to rv � zero, Pressure up annulus to 2,000 psi shear SOV. Monitor well, pull r j7 landing joint, set check relwe. VALVE tM 111 16:00 20:00 4.00 COMPZ RPCOM NUND P ND BOP Stack and set back on Stump. 20:00 22:30 2.50 COMPZ RPCOM NUND P PJSM. Nipple up Tree. (DSO witness Tree alignment). 22:30 00:00 1.50 COMPZ RPCOM PRTS P PJSM. Rig up test equipment. Test Tree at 250/5,000 psi. No leaks. Record on chart. Rig down test equipment. 01/16/2011 Freeze Protect Well. Install BPV. Secure Cellar Move of of 3G -10 Well Slot. Mob to 1J -Pad. Page 7 of 8 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 COMPZ RPCOM FRZP P PJSM. Pull BPV and lay down same. 01:00 04:00 3.00 COMPZ RPCOM FRZP P PJSM. Rig up Lil' Red Services. Pressure test lines. Freeze protest Well with 54 blls of Diesel at 1.1 bpm /1,500 psi. Rig down Lir Red. Hook up hoses and allow Diesel to U -Tube. 04:00 05:30 1.50 COMPZ RPCOM RURD P Set BPV. Dress Tree. Shut in Well and secure Cellar. Move Rig off of Well. 05:30 09:00 3.50 COMPZ MOVE MOB T Ready to move off Location. Wait on CPF -3 change -out. Wait on DSO to get by Rig. Released Rig at 09:00 hrs. Page 8 of 8 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. January 6, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Tubing Cut Record: 3G -10 Run Date: 12/31/2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 3G-10 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50 -103- 20134 -00 A FEB 61 2011 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 J3 n0-08q Office: 907 - 273 -3527 - Fax: 907 - 273 -3535 aU 03 klinton.wood @h14104n,,com Date: � `' ' � � - Signed: WELL LOG TRANSMITTAL PROAcrivE DiAgNoslic SERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659 -5102 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C og � 2. 11 Anchorage, AK 99518 "tl'It Fax: (907) 245 -8952 1) Cali er nrr 05-Jan-11 3C-17 1 Report / EDE 50 -029- 23389 -00 21 Caliper Report 10- Jan -11 3G-10 1 Report / EDE 50- 103- 20134-00 av ^ o 20c5 Signed : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 - 8951 FAX: (907)245 - 88952 E - MAIL : pdsanchoraae ca.memorvloq.com WEBSITE : www.memor'ioq.rorrt C:\Documents and Settings \Diane Williams \Desktop \Ttansmit_Conoco.docx ' • • ' Memory Multi - Finger Caliper Log Results Summary r! Company: ConocoPhillips Alaska, Inc. Well: 3G -10 Log Date: January 10, 2011 Field: Kuparuk ' Log No.: 7461 State: Alaska Run No.: 1 API No.: 50- 103 - 20134 -00 Pipet Desc.: 7 in. 26 Ib. J -55 BTC -MOD Top Log Intvll: Surface Pipet Use: Production Casing Bot. Log Intvll: 7,699 Ft. (MD) 1 Inspection Type : Buckling & Restriction Inspection COMMENTS : This caliper data is tied into the GR signature at 5,700 feet. This log was run to assess the condition of the 7 inch production casing with respect to buckling and minimum I.D. restrictions. ' The caliper recordings indicate severe buckling in joint 12 (518 ft.), restricting the I.D. to 5.60 inches. No other significant buckling or I.D. restrictions are recorded throughout the production casing logged. A graph ' illustrating minimum recorded diameters on a joint-by-joint basis and 3 -D log plots of the centered and off - center caliper recordings from surface to 1,000 ft. are included in this report. The caliper recordings indicate the 7 inch production casing logged appears to be in good condition with ' respect to corrosive and mechanical damage, with no significant wall penetrations or areas of cross- sectional wall loss recorded. ' MAXIMUM RECORDED WALL PENETRATIONS : No significant wall penetrations (> 19 %) are recorded throughout the casing logged. ' MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS : No significant areas of cross - sectional wall loss (> 12 %) are recorded throughout the casing logged. ' MAXIMUM RECORDED ID RESTRICTIONS : Severe Buckling Minimum I.D. = 5.60 in. Jt. 12 @ 518 Ft. (MD) 1 No other significant I.D. restrictions are recorded throughout the casing logged. 1 1 1 1 I Field Engineer: Wm. McCrossan Analyst: C. Waldrop Witness: M. Freeborn ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDS ©memorylog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 1 Igo —o' I • • PDS Multifinger Caliper 3D Log Plot I .1.4;3. Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 3G -10 Date : January 10, 2011 1 Description : Detail of Center Caliper Recordings Across Buckling Recorded in 7" Casing. Comments Depth Maximum I.D. 3 -D Log Image Map (Centered) 1ft:900ft 5 inches 7 0° 0° 90° 180° 270° 0° Mi I.D. 1 I 5 inches 7 Nominal I.D. I i i 5 inches 7 0 I !!!!!lMMISIE y . , IMi��lid a�Momi Joint 1 50 i' EMMEN 3a■•=Ell Joint 2 -----f ! ,-� I fii■.111iiifi,ififil , ififi 11 100 1.1!!!!!# M____I Joint 3 =====111 11111E,_-fiiE111- I 150 in= Joint 4 --f- ..MMM I 200 II 1 Joint 5 11.1.111111111111111 i I -----�[`i�� l Joint 6 25o i�i om= •i 11 I fii IMEE I EESIsIaENEM E Joint 7 300 ----i Joint 350 p___„,.._,... !MliIIl!!EI LEEMEES11 MEI fififil , fififi1fif 2,f.fM 1 M.��.JM. Joint 9 EllI•E1lil•_ 400 MEEKSI!!EI IIIIIIIIMIIIIIIIIIIIIMIIIIII �� =MM Joint 10 -.- NEMII 450 !MI!I♦l WIEI !1!!i■11,I=ill Joint 11 -111.== -i6 ■1111I1.1. /MEM I Joint 12 500 A! #i!!m i--_��E.7a1 -m- M n mum I.D. k5.60" EINEIM -IIIIII♦EMILIM i■- 1 1 1 1 1 ___1 "' 1 550 __ ___ - 1 • • Joint 13 I 600 Joint 14 Joint 15 6 -- 1 Joint 16 700 - 1 Joint 17 750 -- Joint 18 -- ili i 800 - Joint 19 . • I 850 Joint 20 • 1 900 Joint 21 Joint 22 950 1 Joint 23 Nominal I.D. 5 inches 7 Minimum I.D. f- -- I 5 inches 7 Comments Depth Maximum I.D. 3 -D Log Image Map (Centered) 1 1ft:900ft 5 inches 7 0° 0° 90° 180° 270° 0° 1 1 1 1 1 1 • • PDS Multifinger Caliper 3D Log Plot I VS Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 3G -10 Date : January 10, 2011 1 Description : Detail of Off - Center Caliper Recordings Across Buckling Recorded in 7" Casing. Comments Depth Maximum I.D. 3 -D Log Image Map (Off- Center) 1ft:900ft 5 inches 7 348° 0° 90° 180° 270° 0° 1 Minimum I.D. 1 5 inches 7 Nominal I.D. 1 ! 5 inches 7 �I�_�i.=••=miointo I MILE ICilliiiiiiiill..ii. .....ill... : r J oint, 50 � .....��... I ..•..fllIMI.MII .....[11... Joint 2 .....Eii... ' 100 MUM _ .. Joint 3 rimp111411111121 --111-- - ..111... I 150 ..f #��. .....111... Joint 4 -----11 1 �--- .....fuI... I .....111...E` 200 2t Joint 5 ! (..- .... ! II... I .....:r_ =mil » Joint 6 250 sll... .....III... Joint 7 300 .....11111... .....1 MI.. I .....i#al■a. .....E1II... Joint 8 350 .....11M... .....e i._.. ....VIII• :V.M I .....I.1... Joint 9 = =IMMII= I = == 400 _I•...rJI_i_ .....lII�I�W. Joint 10 MMIIIMMIIIIIIIIIIIMIII 450 ....IItIIIII.. .....iil... Joint„ .....iil... ..1I t... 500 ........ t,..„ I ..MMIMI Joint 12 -��■�E.111��- S evere Buckling ....�11�... Minimum I.D. = 5.60" ....1'i 550 - - - -s .'•__ 1 • • Joint 13 ----- Iii- -- 1 ----- i.1, - -- 600P -- IM--- Joint 14 -- I,1 - -- --III--- I 650 - - -rI - -- ----- ® - -- ••IEM-III--- ----- leiimm ---- 1111- -- Joint 16 700 -- -1 f 1' - -- .. -- -I f 1f--- ' - --�ti�_ =- 11•11111111111111111•111E.11111 - # Joint 17 ----- IIill- -- 4 750 - --- �f1 - -- 1 ---gh7--- Joint 18 ----- 1[i - -- 408 ----- 111 - -- 800 VI♦ - � initroj a Joint 19 ----- II1 - -- li ----- 111 - -- 850 -- -E!'_ M� 1 ----- ill - -- Joint 20 === -- - -- -..... -- .... 1 900 _____ ME- Joint 21 !! -- --- --1 * 1 --- 950 L Joint 22 1 Joint 23 -----I�� . . . r _ Nominal I.D. • 5 inches 7 1 Minimum I.D. 5 inches 7 Comments Depth Maximum I.D. 3 -D Log Image Map (Off - Center) 1 . 1ft:900ft 5 inches 7 348° 0° 9 9 180° 270° 0° 1 1 1 1 1 1 • • Minimum Diameter Profile 1 Well: 3G -10 Survey Date: January 10, 2011 Field: Kuparuk Tool: UW MFC 40 Ext No. 213120 I Company: Country ConocoPhillips Alaska, inc. Tool Size: Tubing I.D.: 2.75 inches USA 6.276 inches 1 Minimum Measured Diameters (In.) 2.75 3.25 3.75 425 4.75 5.25 5.75 625 1 9 I II i • 13 . I I 17 21 25 I 1 33 + 37 4T 44 1 48 52 56 60 1 64 68 72 76 80 7 88 Z 92 I w = 96 1 I 100 104 6 108 112 i I 116 120 124 6 T 128 I 132 136 ■ 140 144 I I 152 152 156 160. .. 1 164 168 172 176 1 180 1 1 1 • • Correlation of Recorded Damage to Borehole Profile 1 ■ Pipe 1 7. in (27.9' - 7664.4') Well: 3G -10 Field: Kuparuk I Company: Country: ConocoPhillips Alaska, Inc. USA Survey Date: January 10, 2011 1 . Approx. Tool Deviation ■ Approx. Borehole Profile 1 28 i 1 25 1068 1 50 2179 1 75 3286 0 E c Z 1 0 100 4369 op 1 125 5390 1 150 6413 1 1 175 7426 181 7664 I 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) i Bottom of Survey = 181 1 j • • 1 Report Overview ti S. Body Region Analysis 1 Well: 3G -10 Survey Date: January 10, 2011 Field: Kuparuk Tool Type: UW MFC 40 Ext. No. 213120 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 I Country: USA No. of Fingers: 40 Tubing: 7 ins 26 ppf J -55 BTC -MOD Analyst: C. Waldrop Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 7 ins 26 ppf J -55 BTC -MOD 6.276 ins 7 ins 6.0 ins 6.0 ins 1 Penetration(% wall) Damage Profile (% wall) 1 2 00 --- Penetration body Metal loss body 0 50 100 1 150 --- 100 --- 1 50 I 0 to 20% 20 to 40% 40 to 85% over 85% 51 Number of joints analysed (total = 181) 1 181 0 0 0 I Damage Configuration ( body ) 101 1 1 151 I Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos. Hole 1 Number of joints damaged (total = 0) 0 0 0 0 0 Bottom of Survey = 181 1 1 1 1 1 0 0 PDS REPORT JOINT TABULATION SHEET I Pipe: 7. in 26.0 ppf J -55 BTC -MOD Well: 3G-10 Body Wall: 0.362 in Field: Kuparuk I Upset Wall: 0.362 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 6.276 in USA Survey Date: January 10, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (` wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 1 28 0.06 0.06 16 8 6.24 i Il 1 2 64 0 0.05 13 6 6.25 3 108 0 0.05 14 6 6.25 , 4 150 0 0.04 12 7 6.23 1 5 192 0.05 0.05 14 6 6.27 1 I 6 235 0.05 0.05 13 7 6.27 i 7 279 0 0.05 14 7 6.28 1 8 323 0 0.04 12 5 6.21 1 9 367 0.06 0.06 17 8 6.24 1 I 10 410 0.05 0.06 17 9 6.28 i 11 455 0.07 0.07 19 10 6.26 12 , 499 0.06 0.05 14 10 5.60 Severe Buckling. 13 540 0.06 0.06 17 10 6.21 I 14 584 0.07 0.07 19 6 6.26 15 628 0.05 0.06 17 9 6.29 i 16 673 0 0.04 11 4 6.24 ■ 17 716 0.05 0.06 16 9 6.29 18 760 0.06 0.06 17 9 6.21 I 19 803 0 0.05 14 7 6.27 i 20 847 0.06 0.06 17 9 6.26 i 21 892 0.06 0.06 17 9 6.25 22 936 0.05 0.06 17 10 6.26 I 23 980 0.04 0.05 14 9 6.27 24 1025 0.05 0.06 16 8 6.28 i 1 25 1068 0.05 0.06 17 7 6.23 • 26 1112 0.05 0.06 18 11 6.28 I 27 1156 0.05 0.06 17 10 6.28 28 1198 0.05 0.06 16 9 6.27 i 29 1242 0.07 0.06 17 12 6.27 30 1287 0.06 0.06 17 10 6.28 I 32 31 1330 1374 0.06 0.07 19 10 6.29 0 0.04 12 8 6.25 33 1418 0.05 0.06 16 9 6.27 i 1 34 1463 0.06 0.07 18 10 6.28 I 35 1507 0.05 0.07 19 9 6.29 36 1551 0.05 0.06 16 9 6.29 37 1596 0.06 0.07 19 10 6.29 38 1641 0.06 0.06 17 10 6.29 39 1685 0.06 0.06 17 10 6.27 I 40 1730 0.05 0.05 14 10 6.26 41 17712 0.06 0.07 19 I2 6.24 41.1 1815 0 0 0 0 6.17 Baker (ECL) Open Hole Casing Packer 1 42 1825 0.06 0.06 17 11 6.31 I 43 1869 0.05 0.05 14 9 6.29 i 44 1913 0.05 0.05 14 10 6.30 45 1958 0.05 0.05 14 9 6.28 1 46 2003 0.06 0.06 17 10 6.27 47 2047 0.05 0.06 16 10 6.29 I 48 2091 0.07 0.06 17 12 6.29 49 2135 0.05 0.06 17 11 6.29 rat Body 1 I Metal Loss ion Body Page 1 Penet 1 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 7. in 6 p 2 .0 ppf J-55 BTC -MOD Well: 3G -10 Body Wall: 0.362 in Field: Kuparuk I Upset Wall: 0.362 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 6.276 in Country: USA Survey Date: January 10, 2011 J Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 50 2179 0.06 0.06 16 11 6.28 51 2223 0.05 0.06 16 10 6.27 52 2267 0.06 0.06 17 10 6.24 53 2312 0.04 0.06 16 10 6.26 54 2357 0.05 0.05 14 9 6.29 1 I 55 2401 0.06 0.06 15 10 6.27 56 2446 0.05 0.07 19 12 6.29 57 2490 0.06 0.07 , 19 12 6.27 58 2534 0.06 0.06 17 10 6.28 I 59 2578 0.05 0.07 19 11 , 6.29 60 2622 0 0.05 14 7 6.25 61 2666 0 0.05 13 9 6.27 i 62 2711 0.05 0.06 16 10 6.27 I 63 2754 0.06 0.06 17 10 6.29 64 2799 0.06 0.06 17 12 6.29 65 2841 0.05 0.06 16 12 6.27 66 2886 0.05 0.06 16 10 6.30 67 2931 0.05 0.06 16 11 6.31 I 68 2975 0.05 0.06 17 10 6.28 69 3019 0.05 0.06 17 10 6.28 70 3064 0.05 0.05 14 9 6.26 1 71 3109 0.05 0.06 17 12 6.31 I 72 3153 0.05 0.05 14 9 6.27 73 3198 0.04 0.05 14 10 6.30 74 3242 0.05 0.06 17 10 6.28 75 3286 0.05 0.06 16 9 6.27 76 3331 0.06 0.07 19 12 6.29 77 3376 0.04 0.06 16 10 6.28 78 3418 0.05 0.06 16 12 6.30 79 3462 0.05 0.06 16 10 6.29 I 80 3507 0.05 0.06 16 9 6.29 81 3551 0.05 0.07 19 11 6.30 82 3589 0.05 0.06 17 11 6.22 83 3634 0.05 0.06 17 11 6.31 84 3678 0.05 0.06 15 10 6.27 I 85 3723 0.06 0.06 17 10 6.29 86 3768 0.05 0.06 16 10 6.29 87 3813 0.05 0.06 16 9 6.27 88 3858 0.05 0.05 14 7 6.24 i I 89 3900 0.05 0.06 17 10 6.28 90 3944 0.05 0.07 18 10 6.24 91 3988 0.05 0.05 15 9 6.28 92 4032 0.06 0.06 17 10 6.28 I 93 4077 0.04 0.05 14 9 6.27 i 94 4121 0 0.04 10 5 6.25 ■ 95 4162 0 0.04 12 5 6.25 ■ 96 4203 0 0.06 17 7 6.24 1 97 4244 0.06 0.07 18 10 6.27 I 98 4286 0 0.04 10 3 6.24 ■ 99 4327 0.04 0.05 15 7 6.24 I Penetration Body I Metal Loss Body Page 2 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 7. in 26.0 ppf J -55 BTC -MOD Well: 3G -10 Body Wall: 0.362 in Field: Kuparuk Upset Wall: 0.362 in Company: ConocoPhillips Alaska, Inc. I I I 1 Nominal I.D.: 6.276 in Country: USA Survey Date: January 10, 2011 1 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 100 4369 101 4410 0 0.03 9 3 6.24 0 0.04 12 6 6.24 ■ 102 4451 0.04 0.05 14 7 6.27 1 103 4492 0.05 0.06 16 7 , 6.25 ■ 104 4533 0.05 0.06 16 4 6.23 • I 105 4574 0 0.04 11 4 6.23 • 106 4615 0 0.05 14 5 6.24 ■ 107 4654 0.05 0.05 14 6 6.25 ■ 108 4694 0.05 0.06 16 7 6.25 1 I 109 4734 0.05 0.05 14 5 6.25 ■ 110 4775 0.06 0.06 17 9 6.27 111 4817 0 0.04 11 5 6.23 ■ 112 4858 0.05 0.04 12 6 6.26 ■ I 113 4899 0 0.04 10 3 6.22 • 114 4940 0 0.05 13 6 6.24 115 4981 0 0.04 12 6 6.26 • 116 5023 0 0.04 12 4 6.21 ■ I 1 17 5064 0 0.04 12 4 6.21 • 118 5103 0.05 0.06 17 8 6.24 i 119 5144 0 0.04 11 4 6.24 • 120 5185 0.06 0.06 16 7 6.21 ■ 121 5226 0.05 0.05 14 6 6.24 ■ I 122 5267 0 0.05 13 5 6.25 ■ 123 5307 0 0.05 14 8 6.26 i 124 5348 0 0.06 18 9 6.25 125 5390 0 0.04 10 3 6.21 • I 126 5431 0.05 0.06 17 10 6.27 127 5472 0.05 0.06 16 7 6.25 128 5513 0 0.05 14 6 6.23 ■ 129 5553 0 0.05 13 6 6.21 ■ I 130 5593 0 0.04 12 4 6.24 ■ 131 5634 0 0.05 13 5 6.21 • ■ 132 5675 0 0.05 13 4 6.23 • 133 5716 0.06 0.06 17 9 6.26 i 134 5757 0 0.06 16 8 6.25 el I 135 5798 0 0.03 9 2 6.23 136 5838 0 0.05 13 5 6.21 ■ 137 5879 0 0.03 9 3 6.22 • 138 5919 0 0.04 10 3 6.23 • I 139 5960 0.04 0.05 14 6 6.26 • 140 6001 0 0.04 12 5 6.21 • 141 6041 0.05 0.05 14 6 6.24 ■ 142 6083 0 0.04 10 4 6.23 • I 143 6125 0 0.04 12 4 6.24 • 144 6165 0.06 0.06 15 8 6.26 i 145 6207 0 0.04 12 4 6.21 ■ 146 6248 0 0.06 16 7 6.24 ■ 147 6289 0 0.05 14 6 6.23 ■ I 148 6330 0 0.05 14 5 6.23 • 149 6372 0 0.04 12 6 6.22 I Penetration Body I Metal Loss Body Page 3 1 1 1 • 0 PDS REPORT JOINT TABULATION SHEET I Pipe: 7. in 26.0 ppf J -55 BTC -MOD Well: 3G -10 Body Wall: 0.362 in Field: Kuparuk Upset Wall: 0.362 in Company: ConocoPhillips Alaska, Inc. 1 Nominal LD.: 6.276 in Country: USA Survey Date: January 10, 2011 Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 150 6413 0.05 0.06 17 7 6.25 i 151 6455 0 0.05 13 5 6.22 152 6495 0 0.03 9 3 6.22 i 153 6533 0 0.03 9 2 6.23 154 , 6575 0 0.04 10 4 6.24 • I 155 6616 0 0.04 12 6 6.24 156 6657 0.05 0.05 14 6 6.25 1 157 6697 0.04 0.06 15 5 6.24 158 6739 0 0.03 9 2 6.24 I 159 6778 0 0.03 8 2 6.24 160 6816 0 0.04 12 5 6.23 161 6857 0 0.03 9 3 6.22 162 6898 0.05 0.06 16 7 6.23 1 I 163 6940 0 0.06 16 7 6.25 164 6981 0 0.05 14 6 6.26 165 7021 0 0.04 10 3 6.23 • 166 7062 0.0 .5 0.06 16 7 6.25 1 I 167 7102 0 0.04 10 3 6.21 • 168 7140 0 0.06 16 7 6.25 i 169 7182 0 0.04 11 3 6.21 ■ 170 7223 0.05 0.04 12 4 6.24 171 7264 0 0.06 16 7 6.25 1 I 172 7306 0 0.04 12 5 6.24 • 173 7347 0 0.04 11 2 6.21 • 174 7386 0 0.04 12 4 6.23 s 175 7426 0.06 0.07 19 9 6.24 i I 176 7467 0 0.04 12 3 . 6.22 • 177 7507 0.06 0.07 19 3 6.19 178 7546 0 0.03 9 2 6.23 179 7584 0 0.04 12 5 6.25 I 180 7624 0 0.03 9 3 6.24 181 7664 0 0.05 13 4 6.23 Penetration Body I Metal Loss Body 1 1 1 1 Page 4 1 1 1 • • 1 aF ; ,''S 1 '.' PDS Report Cross Sections I Well: 3G -10 Survey Date: Tool Type: January 10, 2011 Field: Kuparuk UW MFC 40 Ext. No. 213120 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 1 Tubing: 7 ins 26 ppf J -55 BTC -MOD Analyst: C. Waldrop 1 1 Cross Section for Joint 12 at depth 517.740 ft Tool speed = 51 Nominal ID = 6.276 I Nominal OD = 7 ffirilliiiiiir Remaining wall area = N/A Tool deviation = 3° 1 I I 1 1 i ■_ 4411 011111-' 1 Minimum I.D. = 5.596 ins Severe Buckling Minimum I.D. = 5.60 ins HIGH SIDE = UP 1 1 1 1 1 I ' : KUP 3G -10 C onocoPhill i ps / g Attributes ogle & MD TD - e AI<i� �1, It i.,. WeOUoee APWWI Field Name Well Status Ina ( °) ND (9K Act Bun (IIKB) conornnaap6 501032013400 KUPARUK RIVER UNIT INJ 51.81 8,129.99 8,250.0 "` Comment H2S (ppm) Date Annotation End Date KB- d (It) Rig Release Date t W011 0)030 -3G -10 11/27/20101 43:33 PM "" SSSV: TRDP Last WO: 36.00 8/8/1990 smemat0- Actual Amotatian Depth IRKS) End Die Annotation Last Mod By End Date Last Tag: SLM 8,063.0 8/28/2009 Rev Reason: SET TPC Imosbor 11/27/2010 Casing Strings Stang OD Stang ID Set Depth Set Depth (TVb) Stang Wt Stang Casing Description (In) (in) Top (MB) (8148) PDB) (limn Grade Stang Top cord i CONDUCTOR(QC) 16 15.062 35.0 115.0 115.0 62.50 H-40 WELDED SURFACE (QC) 95/8 8.921 35.0 3,783.0 3,034.6 36.00 J -55 BTC PRODUCTION (QC) 7 6.151 33.0 1,831.3 1,662.1 26.00 J-55 BTC -MOD PRODUCTION(QC) 7 6.151 1,831.3 8,241.1 6,112.2 26.00 J-55 BTC i Tubing Strings S[dng OD Stang ID Set DepM Set Depth (ND) Strang Wt Stang CONDUCTOR r Tubing Description MI Pn l Top OMB) ImtBl IKKB) P Oratle String Top Dud (OC), 115 TUBING 3 12 2.992 0.0 7,6 48.0 5,736.3 9.30 J - EUE & AB TUBING 31/2 2.992 7,648.0 7,788.0 5,828.1 9.30 L-80 EUE &AB TUBING 31/2 2.992 7,788.0 7,860.0 5,874.5 9.30 L-80 BTC I SAFETY t jai' I TUBING 27/8 2.441 7,860.0 7,879.0 5,886.6 6.50 J-55 EUE Other In Hole (All Jewelry: Tubing Run & Retrievable, Fish, etc.) Top Depth PACKER, 1,820 IND) Top Ind 1 Top MKB) MKB) 1 Description Comment Run Date ID (in) 1,791.0 1,633.8 41.95 SAFETY VLV Camco TRDP - 1A - SSA' 2/6/1991 2.812 I PRODUCTION 40.53 PACKER Baker 2 40 1 1,653.2 (ECL) Open Hole casing 0 (OC), 1,831 ( ) ce g packer 2/6/1991 7.000 7,658.0 5,742.9 48.64 GAS LIFT CAMCO/MMG- 2I1.5/DMV /RK/ // Comment: STA 1 3/10/1991 2.920 7,715.0 5,780.5 49.03 PBR Baker 10' stroke PBR 2/6/1991 2.937 SURFACE , 7,728.0 5,789.0 49.12 PACKER Camco'HRP- I- SP'RETREIVABLE PACKER 2/6 /1991 2.867 (OC),3,783 ` 7,744.0 5,799A 49.23 INJECTION CAMCO /MMG- W /1.5/DMY /RKP / // Comment ST A2 2/6/1991 2.920 7,851.0 5,868.7 50.42 NIPPLE AVA BPL nipple 2/6/1991 2.750 7,851.0 5,868.7 50.42 SLEEVE-0 2.75" AVA TPC (OAL =29 ") - FULL OPEN 11/9/2010 11/9/2010 2.310 7,860.0 5,874.5 50.48 PACKER TIW'SS' PERMANENT PACKER 2/6/1991 1270 GAS. , , 7,872.0 5,882.2 50.57 NIPPLE Camco'D' Nipple NO GO 2/6/1991 2.250 / ,',8 _ 7,878.0 5,886.0 50.61 SOS Cameo 2/6/1991 2.441 7,879.0 5,886.6 50.62 TTL 2/6/1991 2.441 Perforations & Slots snot i PBR, 7,715 Top ( Bl(6( Dens Top I BI BM OMB) IOW MR) Zone Date Rh- Type Comment 7,776.0 7,834.0 5,820.3 5,857.8 C-4, C-3, C-2, 2/3/1991 10.0 IPERF 4.5" Csg Gun; 60 deg ph _. C -1, 3G-10 PACKER, 7,728 7,888.0 7,904.0 5,892.4 5,902.7 A -3, 3G-10 2/3/1991 4.0 IPERF 4.5" Csg Gun; 180 deg ph 7,926.0 7,946.0 5,916.5 5,929.0 A -2, 3G -10 2/3/1991 4.0 IPERF 4.5" Csg Gun; 180 deg ph I Notes: General & Safety INJECTION, Date 7.74° 2/21/1991 NOTE: Waivered well for water injection only Amotatlan 2/22/1991 NOTE: Possible hole in 9-5/8" surface CSG between surface & 1800' 8/30/2010 NOTE: View Schematic w/ Alaska Schematic9.0 1 6 1 NIPPLE,7,851 SLEEVE -0,- \ 7,851 _ - - II I III 1 PACKH2 / ■ 1 NIPPLE, 7,872 ■ CI SOS, 7,878 r7 TTL, 7,879 1 IPERF, 7,888 -7,904 IPERF, il 7,926 -7,946 1 PRODUCTION (O, 8241 TD 8,250 1 • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 - 0360 Rff ` � 9 42 1 December 30 2010 t 1a I p c fAncri0 ate Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 I C) -� Anchorage, AK 99501 / 5tANEDJAN 242011. 3 e /a Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10 -404, Report of Sundry Operations. The corrosion inhibitor /sealant was pumped December 21 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907 - 659 -7043, if you have any questions. Sincerely, Perry Klein?" ConocoPhillips Well Integrity Projects Supervisor . • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) Kuparuk Field Date 12/30/2010 3G -10 & 3H-05 PAD Corrosion I Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor / Well Name API # PTD # cement pumped cement date inhibitor sealant date I ft bbls ft _ gal c ..--*>3G-10 50103201340000 1900840 SF n/a 25" n/a 2.8 12/21/2010 3H -05 50103200770000 1870770 16" n/a 16" n/a 4.7 12/21/2010 i A 71 r� SEAN PARNELL, GOVERNOR t�� G ALASKA OIL A ND GAS 333 W. 7th AVENUE, SUITE 100 CONSE RVATION COMUSSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Erik Nelson Wells Engineer ConocoPhillips Alaska, Inc. A Dad 2 P.O. Box 100360 Anchorage, AK 99510 00 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3G -10 Q ®� Sundry Number: 310 -411 Dear Mr. Nelson: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this l? day of December, 2010. Encl. RECEIVED ConocoPhilll p s DEC 1 3 2010 Alaska Maska Gib & Gas CDns. CAnmissiN P.O. BOX 100360 ANCHORAGE, ALA 99510-0360 AnGhOr gB SKA December 10, 2010 Commissioner Dan Seamount State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner Seamount: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 3G -10 (PTD 190 -084). During the development drilling of the 3G drill site in 1990, the surface casing to production casing annulus (9 -5/8" x 7 ") of well 3G -10 was used for disposal of drilling fluids. While injecting for disposal, the annulus plugged off and could not be freeze protected. It subsequently froze, collapsing the 7" production casing and bursting the 9-5/8" surface casing. The damaged portion of the 7" production casing was replaced with an external casing packer installed in order to further isolate the damage in the 9 -5/8" casing. This annulus communication problem has left the well without sufficient barriers for MI injection thus it has remained a water only injection well. The proposed workover would add a barrier to the well completion by installing a 5 -1/2" casing ,/ string within the 7" production casing from surface to the polished bore receptacle at 7700' MD. This added annulus provides the necessary second barrier to meet State and Internal requirements for a MI injection well. Passing MITIA tests consistently indicate that the production casing and tubing are competent, with the latest test occurring on August 10, 2009. If you have any questions or require any further information, please contact me at 263 -4693. Sincerely, r� Erik Q. Nelson Weiss Engineer CPAI Drilling and Well STATE OF ALASKA Ok 4Vj0 ALAS AND GAS CONSERVATION COMMISSI C ti 4 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon Rug for Redrill Perforate New Pool " Repair w ell Change Approved Program r Suspend r Rug Perforations r Perforate Pull Tubing ✓ Time Extension Operational Shutdown Re -enter Susp. Well Stimulate After casing g Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory ] 190 -084 - 3. Address: 6. API Number: Stratigraphic Service P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20134 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No Fv 3G -10 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25547 Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (fty Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8250 6118 _ 8156' 6060' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 115' 115' SURFACE 3748 9 -5/8" 3783' 3035' i PRODUCTION 8208 7" 8241' 6112' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7776'- 7834', 7888'- 7904', 7926' -7946' 5820'- 5858', 5892'- 5903', 5917' -5929' 3.5 x 2.875 L -80, J -55 7860', 7879' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - CAMCO 'HRP -1 -SP' RETREIVABLE PACKER MD= 7728 TVD= 5789 PACKER - TIW 'SS' PERMANENT PACKER MD= 7860 TVD= 5875 TRDP - CAMCO'TRDP -1A -SSA' MD= 1791 TVD= 1634 12. Attachments: Description Summary of Proposal 1v 13. Well Class after proposed work: Detailed Operatio s Program I BOP Sketch Exploratory Development Service Wo 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 12/22/2010 Oil Gas WDSPL� Suspended iW°'' 16. Verbal Approval: Date: WINJ i GINJ WAG Abandoned' Commission Representative: GSTOR SPLUG' 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ian Toomey @ 263 -4773 Printed Name E rik Nels Title: Wells Engineer Signatur Phone: 263-4693 Date ! Commission nl )) ,, Sundry Number: Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test Mech anical Inte Tes Location Clearance Other: 0'V DEC 1 3 2010 Subsequent Form Required: 'A 8ska Gii & Ices Cons. Coninis APPROVED BY Anchor* Approved by: COMMISSIONER THE COMMISSION Date: 4 / 71 Form 10 -403 Revised 1 E� OR N Submit in Duplicate • 3G -10 Capital Rig Workover (PTD #: 190 -084) Current Status 3G -10 is currently injecting water. 3G -10 had a passing MIT -IA on August 10, 2009. Scope of Work Run new 5 -1/2" casing in order to meet the 2 barrier requirement for MI injection. General Well info MASP: 3039 psi (utilizing 0.1 psi /ft gas gradient and SBHP listed below) Reservoir pressure/TVD: 3629 psi at 7897' MD (5898' TVD) SBHP taken on August 1, 2008 Wellhead type /pressure rating: WKM Gen IV, 11" 3K btm x 7- 1/16" 5K top flange BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams MITIA and MITOA results: MIT -IA - passed on August 10, 2009 MIT -OA - failed on March 28, 2003 Well Type: Injector Estimated Start Date: December 28, 2010 Production Engineer: Len Janson /John Tonello Workover Engineer: Ian Toomey (263 - 4773 / Ian. Toomey @contractor.conocophillips.com) Pre -Rig Work Request 1. RU HES slickline a. Lockout SCSSV at 1791' MD b. Pull ported sleeve and set iso sleeve in AVA nipple at 7851' MD 2. RDMO HES slickline. Shut in well for at least 3 days. 3. RU HES slickline a. Obtain A -sand SBHP b. Set plug in 2.25" nipple at 7872' MD. c. PT plug to 1500 psi and drawdown test to 0 psi. d. Set catcher sub on top of plug. e. Pull iso sleeve from AVA nipple at 7851'. l� f. Obtain C -sand SBHP. g. Set iso sleeve in AVA nipple at 7851'. —�� r - h. Pull DV from GLM #1 at 7658' MD, leave open. i. Pull catcher sub. 4. Displace IA and tbg w/ 9.6 # /gal brine 5. RU HES E -line a. Jet cut tbg just above PBR (7692' MD) 6. RDMO HES E -line 7. PT tubing and casing packoffs, FT LDS. / 8. Set BPV. '?� b O' . Proposed Procedure 1. MIRU Nordic 3. Pull BPV. Verify well is dead. Set BPV. ND tree. NU 11" 5K BOP and pressure test BOP to 250/3500 psi. 2. Pull blanking plug and BPV. MU landing jt and PU tbg hgr to rig floor. Circulate KWF down tbg taking returns from the IA at max rate in order to clean up any debris in the IA. 3. TOOH laying down tubing and spooling up control line. • --Proposed Procedure Continued-- 4. Set storm packer in 7" casing. 5. ND BOP. ND tubing head. NU,casing head for 5 -1/2" casing. NU BOP and test 6. Pull storm packer. 7. RIH with poor -boy overshot, 2.812 X nipple, Premier Packer, SBE and -7700'5-1/2", 15.5 #, L -80 BTC w /SCC casing. Swallow tubing stub with overshoot and circulate 9.6 ppg inhibited brine with diesel cap into OA. 8. RU HES slickline and set plug in 2.812 X nipple. PT plug to 1500 psi and drawdown test to 0 psi. Set catch sub on top of plug. 9. RDMO HES slickline. 10. Set Premier Packer and test annulus to 1500 psi. 11. ND BOP. Set slips and packoff for 5 -1/2" casing. NU tubing head. PT packoffs. NU BOP and test. 12. RIH with new 3 -1/2 ", 9.3 #, L -80 IBTM tbg, GLM #1 and seal assembly for SBE. Circulate well to corrosion inhibited brine. Locate SBE and space out positioning one full jt below tbg hgr. Space out should leave locator 3 ft above located position when the tbg hgr is landed. 13. Land tubing hanger and RILDS. 14. Pressure test tbg to 2500 psi for 15 mins. PT IA to 3500 psi for 30 mins and record on chart. 15. Bleed IA to 0 psi followed by tbg pressure to 0 psi. Ramp up IA pressure to 2000 psi to shear SOV. Bleed tbg and IA to 0 psi. 16. Set 2 -way check. ND BOP. NU tree and test. 17. Pull 2 -way check. Freeze protect well. Set BPV. 18. RDMO Nordic 3. Post -Ria Work reauest: 1. Pull BPV 2. RU HES Slickline: a. Pull SOV from GLM #1 b. Run DV in GLM #1 c. Pull catcher sub. -� d. Pull 2.25" plug. r✓+ -7 7 2 - n u e. Pull iso sleeve and installed ported sleeve in AVA nipple. 3. RDMO HES Slickline 4. Return well to injection. • - 3G -10 ConocoPh i I I i ps _ v� As- Planned 115' MD, 16" 62.5 #, H-40 of 3 -112" 9.3 #, L -80, IBTM w /SCC 1820' MD, Baker ECP 7480' MD, Camco KBG -2 -9 GLM 3783' MD, 9 -5/8" 36 #, J -55 7516' MD, 2.812" X Nipple 7543' MD, 5 -1/2" 15.5 #, L -80 7547' MD, Baker Seal Assembly 7544' MD, Baker SBE 7595' MD, Baker Premier Pacer 7631' MD, 2.812" X Nipple 7662' MD, Tubing Cut 7662' MD, Poor -Boy Overshot 7715' MD, Camco OEJ 7728' MD, Camco HRP -1 -SP Ret. Packer 7744' MD, Camco MMG -W Injection Mandrel 7776' - 7834' MD, C-4, C -3, C -2, C -1 Perforations 7851' MD, 2.75" AVA `BPL' Nipple • 3 -1/2" 9.3 #, L -80, EUE 8rd Mod 7858' MD, Top of Locator, 2 -7/8" 6.5 #, J -55 7860' MD, TIW `SS' Permanent Packer 7863' MD, `SS' SBE 7872' MD, 2.25" D Nipple 7878' MD, Shear Out Sub 7879' MD, 2 -7/8" 6.5 #, J -55 Tubing Tail 7888' - 7904' MD, A -3 Perforations 7926' - 7946' MD, A -2 Perforations 8241 MD, 7" 26 # , J-55 I Date: December 15", 2010 Drawn By: Ian Toomey fi ^ r ,, KUP 3G -1 0 ConocoPFlillips it,or A I/UWI KU dName RIVER UNIT 51 8,129.99 8,250.0 Alaska, hn ( 6 ) Wellbore APIIUWI Field Name Well Status Incl MD RKB Act Btm ftKB i e Attributes Max Angle Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date '.. 1Ne11 Config - 3G 10, 11/27/2010143:33 PM - SSSV: TRDP Last WO: 36.00 8/8/1990 - - Schematic - Actual _ Annotation Depth (RKB) End Date Annotation Last Mod By End Date Last Tag: SLM 8,063.0 1 8/28/2009 Rev Reason: SET TPC Imosbor 11/27/2010 Casing_Strings String OD String ID Set Depth Set Depth (TVD) String Wt String Casing Description _ (in) (in) Top (RKB) (RKB) (RKB) '. (lbs /ft) Grade String Top Thrill CONDUCTOR (QC) 16 15.062 35.0 115.0 115.0 62.50 H-40 WELDED n; SURFACE (QC) 95/8 8.921 35.01 3,783.0 3,034.6 36.00 J -55 BTC PRODUCTION (QC) 7 6.151 33.0 1,831.3 1,662.1 26.00 J -55 BTC -MOD PRODUCTION (QC) 7 6.151 1,831.3 8,241.1 6,112.2 26.00 J -55 BTC � Tubing Strings String OD String ID Set Depth Set Depth (TVD) String Wt String CONDUCTOR Tubing Description (in) pn) Top (RKB) (RKB) (RKB) (lbs+R) Grade String Top Third (QC), 115 TUBING 31/2 2.992 0.0 7,648.0 5,736.3 9.30 J -55 EUE & AB TUBING 31/2 2.992 7,648.0 7,788.0 5,828.1 9.30 L-80 EUE & AB [T TUBING 31/2 2.992 7,788.0 7,860.0 5,874.5 9.30 L-80 BTC SAFETY VLV, 1,791 TUBING 27/8 2.441 7,860.01 7,879.0 5,886.6 6.50 J -55 EUE Other In Hole (All Jewell ► Tubing Run & Retr Fish, etc. Top Depth '. - -_- PACKER, 1,820 _- - - -- (TVD) Top Incl Top (RKB) (RKB) (") Description Comment Run Date ID (in) 1,791.0 1,633.8 41.95 SAFETY VLV Camco'TRDP - 1A - SSA' 2/6/1991 2.812 toc >, 1,831 -- 1,820.0 1,653.2 40.53 PACKER Baker (ECL) Open Hole casing packer 2/611991 7.000 PRODUCTION 7,658.0 5,742.9 48.64 GAS LIFT CAMCO/MMG- 2/1.5 %DMY 1RK1// Comment: STA 1 3/10/1991 2.920 7,715.0 5,780.5 49.03 PBR Baker 10' stroke PBR 2/6/1991 2.937 SURFACE 7,728.0 5,789.0 49.12 PACKER Cam P-I co'HR-SP' RETREIVABLE PACKER 216 /1991 2.867 (OC), 3,783 7,744.0 5,799.4 49.23 INJECTION CAMCO %MMG -W/1.5 /DMY /RKP /// Comment: ST A2 21611991 2.920 7,851.0 5,868.7 50.42 NIPPLE AVA BPL nipple 216/1991 2.750 7,851.0 5,868.7 50.42 SLEEVE -O 2.75" AVA TPC (OAL =29 ") - FULL OPEN 11/9/2010 11/9/2010 2.310 7,860.0 5,874.5 50.48 PACKER TIW'SS' PERMANENT PACKER 2/6 /1991 3.270 GAS L FT, 7,872.0 5,882.2 50.57 NIPPLE Camco'D' Nipple NO GO 2/6/1991 2.250 7'858 7,878.0 5,886.0 50.61 SOS Camco 216 /1991 2.441 7,879.0, 5,886.6 50.62 TTL 216/1991 2.441 Perforations & Slots - -. -_ Snot Top (TVD) Btm (TVD) Dens Top (RKB)' Btm IRKS) (Ill (RKB) Zone pate (s h °. Type Co mment PBR 7,7i5 7,776.0. 7,834.0 5,820.3 5,857.8 C-4, C -3, C -2, 2/3/1991 10.0 IPERF 4.5" Csg Gun; 60 deg ph j C -1, 3G-10 PACKER, 7,728 7,888.0 7,904.0 5,892.4 5,902.7 A -3, 3G -10 2/3/1991 4.0 IPERF 4.5" Csg Gun; 180 deg ph _._ _ 7,926.0 7,946.0 5,916.5 5,929.0 A -2, 3G -10 2/3/1991 4.0 IPERF 4.5" Csg Gun; 180 deg ph Notes: General & Safety INJECTION, End Date A nnotatio n 7,744 _. - . - - - -- - - -- 2/21/1991 NOTE: Waivered well for water injection only 2/2211991 NOTE: Possible hole in 9 -5/8" surface CSG between surface & 1800' 8130/2010 NOTE: View Schematic w/ Alaska Schematic9.0 IPERF, 7,776 -7,834 NIPPLE, 7,851 - SLEEVE -O, 7,851 PACKER, 7,860 - -- -- - ~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Field: Kuparuk U Well Job # F.h-, c`~L~y~.~. ~t`~~. ._ ~u Log Description JUN ~ 9 2069 ~iask~ Cil ~ Cas Cons. Cor~misslAr~ NO. 5284 gOChOra~9 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Date BL Color CD 06/17/09 i B-19 ANHY-00091 PRODUCTION PROFILE L- < 05/27/09 1 1 3K-16 ANHY-00094 GLS j 05/29/09 1 1 3G-10 B04C-00058 INJECTION PROFILE ~ 05/31/09 1 1 iJ-160 62WY-00006 MEMORY INJECTION PROFILE ~ - - 05/31/09 1 1 iJ-164 62WY-00009 MEMORY INJECTION PROFILE - 06/01/09 1 1 iJ-160L2 AXBD-00028 MEMORY INJECTION PROFILE(] 06/07/09 1 1 1 A-04A B04C-00040 RST ~ C 05/05/09 1 1 3M-03A AZJZ-00011 CH EDIT SFRT 01/11/09 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. u r1 U MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: ~~;;;:r~isor ~n ß/~D7 DATE: Wednesday, August 22, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3G-10 KUPARUK RlV UNIT 3G-IO FROM: Chuck Scheve Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv~ Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 3G-1O API Well Number: 50-103-20134-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS070820 162142 Permit Number: 190-084-0 Inspection Date: 8/20/2007 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3G-IO Type Inj. w TVD 5789 IA 1200 2520 2520 2520 P.T. ' "vvo'"' TypeTest ;:,rl Test psi 1500 OA 5 5 5 5 Interval 4YRTST ./P/F P ../ Tubing 2600 2600 2600 2600 Notes: Pretest pressures observed for 30+ minutes and found stable. ./ SCANNED SEP 1 0 Z007 Wednesday, August 22, 2007 Page 1 of 1 Schlumbepgep NO. 3456 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Company: Field: Well Job # Log Description Date BL 1 E-18 Jj) j "è ì tø 11015713 LEAK DETECTION LOG 08/06/05 1 1 F-01 J S)... -,J. ¡'I 11047354 PRODUCTION PROFILE W/DEFT 07/31/05 1 1Y-06A 19T-i J '1 11015712 PRODUCTION PROFILE W/DEFT 08/05105 1 3J-06 ¡ SS'· - /...1 'i 11056679 PRODUCTION PROFILE W/DEFT 08/19/05 1 1Y-31 '<:13-0'10 11015708 PRODUCTION PROFILE W/DEFT 08/03/05 1 1B-10 l~í-)J>- 11056671 PRODUCTION PROFILE W/DEFT - 08/12/05 1 3G-10 ieft.·- C iJ~( 11056670 INJECTION PROFILE 08/11/05 1 2Z-23 } q f;-- () I Ù 11015717 INJECTION PROFILE 08/10/05 1 2X-06 8 ~ - j D 11015711 INJECTION PROFILE 08/04/05 1 2X-07 ¡In .../Jo3 11015710 INJECTION PROFILE 08/04/05 1 1 Y -04/ J J- ,(, \¡ 11047351 INJECTION PROFILE (REDO) 07/27/05 1 SIGNED: µoiLJ :SCANNED SEP 0 7 2005 DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 08/24/05 ttjo_oìt( Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Kuparuk Color -' CD r<) J/)l- ~~ S--- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Tom_Maunder@admin.state.ak. us and Bob_Fleckenstein@admin.state.ak.us OPERATOR: ConocoPhillips Alaska Inc. FIELD / UNIT / PAD: Kuparuk/KRU/3G DATE: 08/04/03 OPERATOR REP: Arend/Brake- APC AOGCC REP: Chuck Scheve Packer Depth Pretest Initial 15 Min. 30 Min. Welll3G-,0 I Typelnj I S I T.V.D. I 5789 I Tubingl 20001 20001 20001 20001 Interval P.T.D-I1900840IITypeTestP I TestpsiI 1500 I Casing I 13501 24601 24201 24201 P/F Notes: 2 Yr MIT required by internal Waiver Well 13G-12 P.T.D. 11900730 Notes: TypeTest Test psiI 1500 I Casing ] 12501 23501 23OOI 228OI P/F I P We11]36-13 I Type Inj P.T.D. I1901160 TypeTest Notes: Test psiI 1500 I Casing I 11401 24001 23801 23801 P/F P.T.D.11901210IITypeTestP I TestpsiI 1500 I Casing I 12401 24501 24251 24251 P/F Notes: A header pressure anonomile occurred right before the start of the test Well 13G-16 P.T.D. 11901040 Notes: Well 13G-24 P.T.D. I1901340 Notes: TypeTest Test psiI 1500 I Casing I 13001 2400[ 24001 24001 P/F Type Test Test psiI 1500 I Casing I 12001 21001 21001 21001 P/F Test Details: 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 Workover O = Other (describe in notes) MIT Report Form Revised: 05/19/02 MIT KRU 3G 08-04-03.xls 8/5/2OO3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU' FROM: Randy Ruedrich Commissioner Jim Regg /'~¢/[C[ P.I. Supervisor DATE: August 4, 2003 SUBJECT: Mechanical Integrity Test Conoco Phillips 3G Pad KRU Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. WellI [ Inj.I S I T.V.D. I 5789 I Tubing 12000 I~000 I~000 I~000 I,nterva, I 4 I 3G-10 Typetestl P ITestpsil 1447 I CasingI 1350I 2460I 2420I 2420I P/F IP I P.T.D.I 190-084IType Notes: I w~,,I 3G-12 I Type Inj.I S I T.V.D. I~ I Tubing 12350 12350 12350 12350 I lntervall 4 P.T.D.I 190-073ITypetestl P ITestpsil 1422 I CasingI 1250I 2350I 2300I 2280I P/F I P Notes: I I m.v.o. I 4 P.T.D.I 190-116 ITypetestl P ITestpsil 1445 I CasingI 1140I 2400I 2380I 2380I P/FI-P Notes: We,,I 3G-15 I~,~,,i.I ~ IT'¥'~' I~ I T"bing I4°°° I4°°° I4°°° I4°°° I'nterva'l 4 P.T.D.I 190-121 ITypetestl P ITestpsil 1432 I Casingl 1240I 2450I 2425I 2425I P/F I _P Notes: P.T.D.I Notes: Well P.T.D. Notes: 3G-16 I Type,~j.I G I T.V.D. 15764 I Tubing 13100 I 3100 13~00 13~00 I,nterva, I 4 190-104 ITypetestl P ITestpsil 1441 I Casingl 1300I 2400I 2400I 2400I P/F I --P 190-134ITypetestl P ITestpsil 1429 I CasingI 1200I 2100I 2100I 2100I P/F I P Type INJ. Fluid Codes F = FRESH WATER INJ. G: GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to Conoco Phillips 3G Pad in the Kupamk field and witnessed the routine 4 year MIT's on the above listed 6 wells. The pretest pressures were observed and found to be stable. The standard annulus pressure tests were then performed with all wells demonstrating good mechanical integrity. M.I.T.'s performed' _6 Number of Failures: 0 Attachments: Total Time during tests: 4 hours cc: MIT report form 5/12/00 L.G. 2003-0804_M IT_KRU_3G-24_cs.xls 8/15J2003 STATE OF ALASKA ~ OIL AND GAS CONSERVATION COMI~,,.,,51ON REPORT OF SUNDRY WELL OPERATIONS 1. Operation Performed: Operation Shutdown ~ Pull tubing , Alter casing Stimulate Plugging Perforate , Repair well Other ~ 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchora~le, AK 99510 4. Location of well at surface 5. Type of Well: Development Exploratory Stratigraphic Service 2538' FNL, 145' FWL, Sec. 24, T12N, R8E, UM At top of productive interval 1923' FSL, 2115' FWL, Sec. 13, T12N, R8E, UM At effective depth 2175' FSL, 2267' FWL, Sec. 13, T12N, R8E, UM At total depth 2238' FSL. 2305' FWL Sec. 1 IM 12. Present well condition summary Total Depth: 6. Datum elevation (DF or KB) 90' RKB 7. Unit or Property name Kul~aruk River Unit 8. Well number . 3G-10 9. Permit number/approval number 90-84/91-21 9 10. APl number 5o-103-20134 11. Field/Pool Kuparuk River Oil Pool feet measured 8 2 5 0' fe~t true vertical 61 18' feet Plugs (measured) Effective depth: measured 81 5 6' feet true vertical 6060' feet Junk (measured) Casing Length Size Structural Conductor 1 1 5' 1 6" Surface 3783' 9 5/8" Cemented 225 Sx AS I 760 Sx AS III & Measured depth 115' 3783' True vertical depth 115' 3035' Intermediate Production Liner Perforation depth: 8241' 7" measured 7776'-7834', true vertical 5820'-5858', Tubing (size, grade, and measured depth) 480 Sx Class G 485 Sx Class G & 200 Sx Class G Tail 7888'-7904', 7926'-7946' 5892'-5903', 5916'-5929' 3 1/2" 9.3#, EUE, ABMOD, IPC, w/tail @ 7873' and SSSV (type and measured depth) 7329' SSSV: Camco TRDP-1A-SSA ~ 1785'r Packer: TIW pkr. ~ 7855't Camco HRP-1-SP pkr. @ 7723' 13. Stimulation or cement squeeze summary Converted from Producing Well to Water Injection Well on ~ //z[./~t Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subse¢ ReDresentative Daily Averaae Production or 10!ectJon Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 803 371 1204 400 -0- 0- 7891 620 Tubing Pressure 160 2520 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Water Injector _~ Daily Report of Well Operations ~ Oil _ Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 09/12/90 Service SUBMIT IN DUPLICATE STATE OF At. N3KA ALASKA OIL AND GAS CONSERVATION COMMIS,'~ION REPORT OF SUNDRY WELL OPERATIONS 1. Operation Performed: Operation Shutdown Pull tubing Alter casing 2. Name of Operator ....A..RCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 2538' FNL, 145' FWL, Sec. 24, T12N, R8E, UM At top of productive interval 1923' FSL, 2115' FWL, Sec. 13, T12N, R8E, UM At effective depth 2175' FSL, 2267' FWL, Sec. 13, T12N, R8E, UM At total depth 2238' FSL~ 2305' FWL~ Sec. 13~ T12N~ R8E~ UM 12. Present well condition summary Total Depth: measured 8250' feet true vertical 6118' feet feet Stimulate ~ Plugging Perforate _ Repair well Other X 5. Type of Well: ~ 6. Datum elevation (DF or KB) Development _ I Exploratory -- i 90' RKB Stratigraphic m I 7. Unit or Property name Service x I Kuparuk River Unit I 8. Well number 3G-10 9. Permit number/approval number 90-84/91-21 9 10, APl number so-103-20134 11, Field/Pool Kuparuk River Oil Pool Effective depth: measured 8156' feet true vertical 6060' feet Plugs (measured) Casing Length Size Structural Conductor 1 1 5' 1 6" Surface 3 78 3' 9 5/8" Intermediate Production 8241 ' 7" Liner Perforation depth: measured 7776'-7834', true vertical 5820'-5858', Tubing (size, grade, and measured depth) Junk (measured) Cemented 225 Sx AS I 760 Sx AS III & 480 Sx Class G 485 Sx Class G & 200 Sx Class G Tail 7888'-7904', 7926'-7946' Measured depth 115' 3783' 7329' True vertical depth 115' 3035' 6539' RECEIVED 5892'-5903', 5916'-5929' 3 1/2" 9.3#, EUE, ABMOD, IPC, w/tail @ 7873' AJo~ka 0il & ~s C~)~s. C0~-~-~mission Packers and SSSV (type and measured depth) _ ~flCh9~{~ _ SSSV: Camco TRDP-1A-SSA @ 1785', Packer: TIW pkr. ~ 7855'~ Camco FIRP-1-SP pkr. ~ 7723' 13. Stimulation or cement squeeze summary Converted from Producing Well to Water Injection Well. Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or In!ection Data ' OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 803 371 1204 400 160 Prior to well operation 252O Service Date Subsequent to operation - 0 - - 0 - 78 91 6 2 0 15. Attachments ~ 16. Status of well classification as: Copies of Logs and Surveys run ~ I Water Injector ~ Daily Report of Well Operations X Oil_ Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE WELL SERVICE REPORT ARCO Alaska, Inc. ~-'~, SuDs~diary of Atlantic Rtchfield ComDany WELL ~ -/~ ~TRACTOR REMARKS ,,~T Rl~r' ~/A. TE DAYS DATE iPBDT t !FIELD - . OUt ~, ";" ........... Alaska Oil & 6¢t:".., Oo~,s. ,-- CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Temp. Chill Factor :Visibility Wind Vel. Repo~ Signed °F °F miles knots 1. Type of Request: STATE OF ALASKA ~ OIL AND GAS CONSERVATION COMMEx.'~ION APPLICATION FOR SUNDRY APPROVALS Abandon_ Suspend _ Operation Shutdown _ Re-enter suspended well Alter casing' _ Repair well _"' --' -~lugg~ng _ Time extension _ Stimulate _ 2. Name of Operator Change approved program ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Pull tubing _ Variance 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service _ 4. Location of well at surface 2538' FNL, 145' FWL, Sec. 24, T12N, R8E, UM At top of productive interval 1923' FSL, 2115' FWL, Sec. 13, T12N, R8E, UM At effective depth 2175' FSL, 2267' FWL, Sec. 13, T12N, R8E, UM At total depth 2238' FSL~ 2305' FWLr Sec. 13~ T12N~ 12. Present well condition summary Total Depth: measured true vertical measured true vertical Length 115' 3783' 8241' measured 7776'-7834', true vertical 5820'-5858', R8E~ UM 8250' feet Plugs (measured) 61 1 8' feet NOlle 81 56' feet Junk (measured) 6 0 6 0' feet NOne Size Cemented 1 6" 225 Sx AS I 9 5/8" 760 Sx AS III & 480 Sx Class G 7" 485 Sx Class G & 200 SX Class G Tail Perforate Other 6. Datum elevation (DF or KB) Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: RKB 90 7. Unit or Property name Kuparuk River Unit 8. Well number 3G-10 g. Permit number feet 10. APl number so-103-20134 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Measured depth True vertical depth 115' 115' 3783' 3035' 8241' 61 1 2' 7888'-7904', 7926'-7946' 5892'-5903', 5916'-5929' TVD Tubing (size, grade, and measured depth) 3-1/2" J-55 , 9.3#, AB Mod., IPC, W/Tail @ 7873' Packers and SSSV (type and measured depth) TIW Pkr. ~ 7855'~ Camco HRP-1-SP Pkr. @ 7723'~ Camco TRDP-1A-SSA SSSV ~ 1785' 13, Attachments Description summary of proposal _ Detailed operation program X BOP sketch Convert well from oil producer to water injector. 14. Estimated date for commencing operation AUGUST 1991 16. If proposal was verbally approved Name of approver Date approved Service 15. Status of well classification as: Oil ~ Gas __ Suspended _ 17. I her~j4~y ceRifl~that the foregoing is true and correct to the best of my knowledge. Signed '~/~'~. ~ Title ~v~l'/., FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance Mechanical Integrity Test .~ Subsequent form require 10- Approved by order of the Commission Commissioner Form 10-403 Rev 09/12/90 Date d~/~'"~ SUBMIT IN TRIPLICATE Original Signed By David W. Johnston Water Injection Conversion Well 3G-10 Procedure Procedure. I . SI well to perform surface equipment modifications. Install catalytic heater, rotate check valve and choke, install 2.0" meter runs, and calibrate instrumentation. 2. MIRU slick line unit. RIH and tag fill. 3. Conduct MIT. Note: The state should be notified a few days prior to performing the MIT so they can witness the test. . After well has been shut in for at least 72 hours, contact Operations Engineering (x7525) to record wellhead pressure and shoot tubing fluid level. This information will be used for waterflood surveillance. . Begin injection, eventually working up to a flow rate of approximately 5000 BWPD. ALA,aKA OIL AND GAS CONSERVATION CO,,..,ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Se~ice Well OIL ~l GAS [--'l SUSPENDED [~ ABANDONED [--'] SERVICE [~] 2 Name o~ Operator 7 Permit Number ARCO Alaska, IRc 90-84 3 Address -~ 8 APl Numb~ P.O. Box 100360~ Anchorage~ AK 99510-0360 50-103-20134 4 Location of well at surface ~-~=~ 9 Unit or Lease Name 2538' FNL, 145' FWL,'SEC 24, T12N, RSE, UM ~l~~D~,m ~ i 'L~"!~i']:].:'i{'~S?'~'i KUPARUK RIVER 1923' FSL, 2115' FWL, SEC 13, T12N, R8E, UM 3G-10 At Total DelXh ~ ~~ ! ~ H ~ :i 11 Fie~d and Pool 2238' FSL~ 2305' FWL, SEO 13~ T12N~ R8E~ UM KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease D~ignation and Serial No. KUPARUK RIVER OIL POOL RKB 90'I ADL 25547 ALK 2681 12 Date Spudded 13 Date T.D. R,ched 14 Date Comp., Suep. or Abend. 115 Water Depth, if offshore 116 No. of Completions 7/29/90. 8/04/90. 2/06/91.I NA feet MSLI 1 17TotalDepIh(MD+TVD) 18 Plug Back Dapth (MD+TVD) 19 DirectionslSurvey 20 Depth where SSSV sst 21 Thickness of permafrost 8250'MD, 6118'TVD 8156'MD, 6060'TVD YES ~ NO D 1790' feetMD 1600' APPROX 22 Type Electric or Other Logs Run EWR~ CN~ SFD~ CET~ DGR~ GYRO 23 CASING, LINER AND CEMENTING RECORD SETI'ING DEPTH MD CASING SIZE WT. PER FT. GRAEE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16' 62.5# H-40 SURF 115' 24' 225 SX AS I 9-5/8" 36~ J-55 SURF 3783' 12-1/4" 760 SX AS II1~ 480 SX CLASS G 7' 26# J-55 SURF 8241' 8-1/2" 485 SX CLASS G~ 200 SX CLASS G TRIAL 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD intewsi, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2' 7879' 7728'~7860' 17776'-7834' W/4-1/2" CSG GUN @4SPF MD 5820'-5858' TVD 7888'-7904' W/4-1/2" CSG GUN @4SPF MD 589Z-5903' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 7926'-7946' W/4-1/2" CSG GUN @4SPF MD 5916'-5929' TVD DEPTH INTERVAL (MD} AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD Flow Tubing Casing Pre, ute CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ,. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS FORMATION TESTS NNv~ Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. KUPARUK C TOP 7777 5821' NA KUPARUK C BOTTOM 7838' 5860' KUPARUK A TOP 7863' · 5876' KUPARUK A BO'FrOM 8053' '~ -- .... Egg6' , : 31. LIST OF ATTACHMENTS GYRO 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO O,, ,~nd Gas Company 4) Well History - Initial Report - Dai Instructiofle: Prepare and submit the "Initial Report" on the first Wedn~iday after a well is spudded or wor~over operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only, District Field Auth. or W.O. no. _~K4q74 JCounty, parish or borough Lease or Unit Title ~.~L'_ 2554? ~MP T,E~ T Q~ State AK Operator IARCO W i 55.2520'72 Prior status ~1 ;~ w,o, Spudd~ ~ ~V.O. begun SPUT~ Dsle and dapth as of 8:00 a.m. 01/16/91 (11) TD: 0 PR: 8158 SUPV:GB/SK 01/17/91 (12) TD: 0 PS: 8158 SUPV:GB/SK 01/18/91 (13) TD: 0 PR: 8158 SUPV:GB/SK IOate ~ 7_/9 0./qi3 IH°ur IComplete record for each day reported RU AND LAY DOWN 3 JTS CSG 7"@ 8241' MW:10.3 NaCl/Br MOVE RIG FROM 3G-04 TO 3G-10, ND TREE, REMOVE 7" BOPS FROM RIG, HEAT UP WELL HEAD, REMOVE LOWER SPOOL, PULL PRIMARY PACKOFF, RU AND WELD SLIP SEGEMENTS, MU 7" CASING SPEAR, RIH AND LATCH 7" CASING, WORK CSG TO RELEASE SLIPS, NO GO ON SLIPS, LD TRI-STATE SPEAR AND DP, NU ADAPTER FLANGE, NU 11" ROPE, FUNCTION TEST ROPE, MU 6-1/8" BIT ON 3-1/2" DP, RIH AND TAGGED OBSTRUCTION AT 106', CIRC WITH NO PROGRESS, POH, MU 1 JT 2-7/8" TBG AND 3-1/2" DP, TAG OBSTRUCTION AT 106', POH, MU 5-1/2" HYD CSG CUTTER ON 4-3/4" DC'S, RIH, CUT CSG AT 102', POH, MU 7" CSG SPEAR ON 3-1/2" DP, RIH AND LATCH 7" CSG STUB AND POH W/ SLIP SEGEMENTS ATTACHED TO CSG, BREAK OFF SLIPS AND LAY DOWN 7" CSG DAILY:S44,948 CUM:$1,159,460 ETD:S1,013,436 EFC:$1,616,024 UNPLUG PLUGGED FLOWLINE 7"@ 8241' MW:10.3 NaC1/Br FINISH LAYING DOWN 1 JTS 7" CASING, MU TRI-STATE MILL AND RIH, MILL ON 7" CSG FROM 102' TO 106', STOPPPED MAKING PROGRESS W/ MILL, POH, MILL OK, RIH WITH MILL, ATTEMPT TO MILL, UNABLE TO MAKE MILL CUT, BLOW DOWN AND KELLY AND SET BACK, PU 2 MORE 6-1/8" DC'S AND BEAT DOWN ON 7" CASING, LAY DOWN EXTRA DRILL COLLARS AND PU KELLY, ATTEMPT TO MILL 7" CSG, MILL WILL NOT CUT, BELIEVE 7" CSG COLLAR SPINNING UNDER MILL, BLOW DOWN AND SET BACK KELLY, JAR DOWN ON 7" CSG STUB, PU KELLY, MILL ON CSG FROM 106' TO 114', POH, INSPECT MILL (WORE ON OUTSIDE EDGE), MU 8" IMPRESSION BLOCK AND TIH, POH, BLOCK SHOWS CSG COLLAPSED (NOT CONFIRMATIVE TO EXTENT), MU NEW 8-1/2" MILL AND RIH, MILL ON CSG FROM 114' TO 126', UNPLUG STOPPED UP FLOW LINE DAILY:S28,147 CUM:$1,187,607 ETD:S1,092,396 EFC:$1,565,211 POH WITH PLUGGED BIT 7"@ 8241' MW:10.3 NaC1/Br FINISH UNPLUGGING FLOW LINE, MILL 7" CSG FROM 126'-130', FLOW LINE PLUGGED, UNPLUG FLOW LINE, MILL 7" CSG FROM 130'-135',CLEAN FLOW LINE, MILL 7" CSG FROM 135'-143', UNPLUG FLOW LINE, MILL 7" CSG FROM 143'-149', UNPLUG FLOW LINE, TAKE FLOW LINE APART AND REMOVE BUTTERFLY VALVE, MILL 7" CSG FROM 149'-157', CIRC 10 MINUTES, SET BACK KELLY AND POH, MU LEAD IMPRESSION BLOCK AND TIH, TAG UP AND POH, NO IMPLRESSION ON BLOCK, SET 6" DC'S AND TRI-STATE TOOLS IN DERRICK, MU 6-1/8" BIT AND RIH TO 7" CSG AT 157', ROTATE BIT INTO 7" CSG, RUN BIT TO 682' AND HIT OBSTRUCTION, PU KELLY AND BRF_J%K CIRC AT 68Z', BIT PLUGGED, WORK DP TO UNPLUG BIT, UNABLE TO UNPLUG, POH DAILY:S34,354 CUM:$1,221,961 ETD:S1,221,961 EFC:$1,470,000 The above is correct Drilling, Pages 86 and 87. AR3B-459-1-D · Number a I daily ~eli ARCO C ,d Gas Company Dally Well History--Inter I~letftlctiena: This form is used during drilling or workover operationS. If testing, cortng, or perforating, show formation name in descnbmg work performed. NumOer ail drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnlerlm" sheets until final comotetion. Rebort official or retoresentative test on "Final" form. I) SuOmlt "lnlerim" sheets when filled out but not Jess frequently than every ;30 days. or (2) On Wednesday of the week in which pti strillg is set. Submit weekly for workovers and followmg selt~ng of OH senn§ unlll complehon. District l County or Parish . , I State ARCO ALASKA INC. I NORTH SLOPE I AK ~Lease or Unit ' Wail no KUPARUK RIVER UNIT I ADL:25547 ALK:2661 3G-19 Complete record for each day while drilling or workover Jr1 progress NORDIC 1 Field Date and cleotll as of 8:00 a.m. 01/19/91 ( TD: 0 PB: 8158 SUPV:GB/SK 01/20/91 ( TD: 0 PB: 8158 SUPV:GB/SK 01/21/91 ( TD: 0 PS: 8158 SUPV:GB 01/22/91 ( TD: 0 PB: 8156 SUPV:GB :4) 6) The above is co,rect POH PU 6" FLAT BOOTOM MILL AND RIH TO 7", MILL TO 839' For ora l~rel~a bution ~ see Procedures Manual Sec~n 10, Drilling, Pages 86 and 87 CIRC TO CLEAN HOLE 7"@ 8241' MW:10.3 NaC1/Br WORK DP TRY TO UNPLUG BIT, UNABLE TO UNPLUG BIT, TRY TO REVERSE CIRC, BIT STILL PLUGGED, POH W/ SET STRING, UNPLUG BIT, TRIP BACK IN HOLE, WORK BIT THRU CASING TO 682', CSG COLLAPSED AT 682', POH W' BIT, PU JT OF 2-7/8" TBG, RIH AND TAG AT 682', POH, PU TRI-STATE CSG CUTTER AND TIH, CUT CSG AT 682', STUB, LAY DOWN CUTTER AND PU 7" SPEAR, RIH AND SPEAR 7", POH AND LAY DOWN 7" PU 8-11/16" MILL AND RIH, MILL FROM 682'-695', CLEAN CUTTINGS FROM HOLE DAILY:S29,667 CUM:$1,251,628 ETD:S1,251,628 EFC:$1,470,000 TRYING TO WORK INTO 7" 7"@ 8241' MW:10.3 NaC1/Br CeNT TO CIRC HOLE CLEAN, POH W/ MILL, PU 6-1/8" BIT AND T!H, TRY TO WORK BIT INTO 7" CSG, BIT WON'T GO, POH, PU MILL, MILL 7" CSG FROM 695'-710', POH, PU 6-1/8" AND RIH TO CSG, TRY TO WORK BIT INTO CSG, NO GO, POH, PU MILL AND RIH, MILL CSG FROM 710'-722', CIRC HOLE CLEAN AND POH, PU TRI-STATE 6-1/8" TAPERED MILL AND TIH, BRIDGE OF METLA CUTTINGS AT 424' CIRC AND CeNT RIH TO 709', TIGHT SPOST AT 709', CIRC HOLE CLEAN AND CeNT RIH TO 722', CIRC AND ROTATE MILL, WORK MILL INTO 7" CSG DAILY:S28,907 CUM:$1,280,535 ETD:S1,280,535 EFC:$1,470,0C0 RIH W/ HLS E-LINE STRING SHOT 7"@ 8241' MW:10.3 NaC1/Br WORK TAPERED MILL INTO 7" CSG, SET KELLY BACK, PU JT 3-1/2" DP, UNABLE TO GET THRU BACK INTO 7" SITH MILL, POH, PU NEW MM MILL AND RIH TO 722', MILL FROM 722'-725', CIRC HOLE CLEAN, POH, PU 6-1/8" BIT AND RIH TO 725', WORK BIT INTO CSG CSG HAS CUTTINGS PLUGGING IT UP, ROTATE AND PUSH PLUG DWON TO 825', METAL CUTTINGS AND JUNK FELL DOWN HOLE, SET KELLY BACK AND TIH TO 2218', CIRC AND COND BRINE, WARM WELL BORE, POH WITH BIT, PU TRI-STATE SPEAR AND RIH TO 725', RU HLS WIRELINE TO BACK OFF 7" CSG, RIH WITH STRING SHOT DAILY:S28,907 CUM:$1,309,442 ETD:S1,309,442 EFC:$1,470,007 MILL TOP OF 7" 7"@ 8241' MW:10.3 NaC1/Br FINISH IN HOLE WITH E-LINE AND STRING SHOT TO 1880', TORQUE CASING, FIRE STRING SHOT AND TORQUE RELEAED, POH W/ E-LINE, POH WITH DRILL PIPE AND 2 JTS OF 7" CSG, BACKED OFF CASING AT 810', PU 8-1/2" BIT AND 9-5/8 CSG SCRAPER, RIH TO 806', CIRC HOLE CLEAN, CLOSE ANNULAR AND INJECT INTO FORMATION, POH, PU RTTS AND RIH TO 810', COULD NOT GET INTO TOP OF 7" CSG, POH, LAY DOWN 7" RTTS, PU 9-5/8" RTTS AND RIH TO 801', CLOSE ANNULAR AND PUMP INTO FROMATION ABOVE RTTS, PUMP INeT FORMATION BELOW RTTS, RELEASE RTTS AND PU TO 673', SET RTT3 AND PUMP ABOVE AND BELOW RTTS, POH TO 313', UNABLE TO CLOSEBY PASS VALVE ON RTTS, POH, PU TRI-STATE 7" CSG CUTTES AND TIH TO 805', UNABLE TO GET INTO TOP OF 7" CSG, POH, LAY DOWN CSG CUTTERr PU 6-~./8" BIT AND RIH, CIRC. ROTATE INTO Title Odiiing SupL AR3B-459-2-8 Number all dally well h,slory forms consecuDvely as they are propared for each well ARCO C., _id Gas Company Daily Well History--Inter InstttlcfloIte: This form is used during drilling or workover operations. If testing, coring, Or perforaling, show formation name in describing work performed. Number all drill stem teats sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim'" sheets until f;nal completion Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frecluently than every 30 days, or on Wednesday of the week in which oil string is set. Submit weekly for workovera and following setting of oH string until completion. DiStrict ARCO ALASKA INC. Field KUPARUK RIVER UNIT ~County or Parish ISfate NORTH SLOPE Lease or Unit ADL:25547 ALK:2661 AK Date and depth as of 8:00 a,m. 01/23/91 ( TD: 0 PS: 8156 SUPV:GB 01/24/91 ( TD: 0 PB: 8156 SUPV:GB Complete record lot each day w~lile drdling or workover ~rl progress NORDIC I AND FOUND FREE HOLE DAILY:S40,153 CUM:$1,349,595 ETD:S1,24 EFC:$1,565,211 .8) MIX AS 1 CMT 7"@ 8241' MW:10.3 NaC1/Br FINISH TIH F/ 810' TO 2285', POH W/ MILL, WAIT ON STRING MILL, MU 6/125" FLAT BTM MILL, TIH TO TOP OF 7", DRESS TOP OF 7", POH AND LAY DOWN TOOLS, PU BAKER DBP, TIH TO 883', SET DBP, START MIX OF 16 PPG PILL TO SPOT IN 7" CSG UNABLE TO MIX PILL IN RIG PITS, WAIT ON DOWELL TO MIX PILL AND PUME CMT, PUMP POLL ON TOP OF DBP AND POH WITH DP,PU HOWCO RTTS AND RIH TO 786', SET AT 783' PUMP 220 BBLS H20 PREFLUSH DAILY:S47,908 CUM:$1,397,503 ETD:S1,397,503 EFC:$1,470,000 .9) 7"@ 8241' MW:10.1NaC1/Br CONT PUMPING 225 BBL H20 PREFLUSH, PUMP 46 BBLS OF ARCTIC SET 1 CMT, PUMP 52 BBL OF ARCTIC PACK, DROP PLUG, DISPLACE DP W/ 14 BBLS OF 10.4 BRINE, WOC, SEVICE RIG, OPEN DRILL PIPE TO REV FLOW, HEAVY FLOW, SI DRILL PIPE AND WOC, PUMP 14 BBLS VISCOUS BRINE DOWN DRILL PIPE, SHUT IN, MONITOR WELL AND CALL OUT DOWELL AND ARCTIC PACK FLUID, RU DOWELL AND ARCTIC PACK TANK, OPEN BYPASS ON RTTS, PREFLUSH WITH 210 BBLS DIESEL, BATCH MIX 335 SKS ARCTIC SET 1CMT, PUMP CMT - PUMP 1 BBLS H20 SPACER - PUMP 37.4 BBLS ARCTIC PACK - PUMP 17 BBLS BRINE TO DISPLACE OUT DRILL PIPE, SHUT IN AND WOC CONT PUMPING 225 BBL H20 PREFLUSH @ 5-1/2 BPM & 500 PSI, PUMP 278 SKS (46BBLS) 15.7 PPG ARCTIC SET I CMT @ 4 BPM & 450 PSI (BATCH MIXED), PUMP 52 BBL ARCTIC PACK (10.3 PPG) ~ 3BPM & 450 PSI, DROP PLUG, DISPLACE DP W/14 BBL, 10.4 BRINE @ 700 PSI, SIP-475 PSI, WOC, SERVICE RIG, SIP @ 1200=340 PSI OPEN DP TO REV LINE, HEAVY FLOW, SI, SIP-300PSI, WOC, PUMP 14 BBL VIS BRINE 10.4 PPG DOWN DP @ 3 BPM @ 650 PSI, SIP=475 PSI, MONITOR WELL, RU DOWELL, OPEN BY PASS ON RTTS PKR, PREFLUSH 14 BBL DIESEL, CLOSE BY PASS & CONTINUE PREFLUSH, 210 BBLS-3 BPM @ 700 PSI, BATCH MIX 335 SX ARCTIC SET I CMT 15.7 PPG, PUMP CMT @ 3BPM & 700 PSI, PUMP 1 BBL H20 SPACER FOLLOW W/37.4 BBL ARCTIC PACK 3 BPM @ 750 PSI, DISPLACE DP W/17 BBL 10.3 BRINE, 4 BPM @ 750 PSI, SHUT IN, WOC, SIP=450 PSI DAILY:S67,172 CUM:$1,464,675 ETD:S1,464,675 EFC:$1,470,007 01/25/91 ( !0) REV OUT DP, PREP TO REL PKR 7"@ 8241' MW:10.1 NaC1/Br TD: 0 WOC FOR 10 HRS, OPEN DRILL PIPE, BLEED 1 BBL BRINE, SHUT IN, PB: 8156 PRESS BUILDS TO 310 PSI, OPEN DP, BLEED 1/2 BBL BRINE, SHUT SUPV:GB/SK IN, PRESS BUILDS TO 310 PSI, PUMP 1 BBL BRINE DOWN DP, SHUT IN, PREPARE TO FLOW BACK WELL, OPEN DRILL PIPE, BLLED OFF FLUID SLOWLY, BLEED 11 BBLS, SHUT IN, BLEED 18 BBLS SHUT BLEED 12 BBLS SHUT IN, BLEED 5 BBLS, SHUT IN, BLEED 2 BBLS, SHUT IN, WELL STILI~ FLQWING SLQWLY, SHUT IN AND WELL BUILDS rheaboveiscorrec, / ~SURE SLOWLY WQ~, $IP'$~Q P~]~, PR~ ~ 15:30 - 320 PSI, mg.,tu,, ~~. ,D.,. / iT,,.. I ..... see Procedures Manuel Seclion I~ Drilling. Pages 86 and 87 ~Number all dally well h~slOry for~ecu.vel~ - las ihey are prepared for each well. AR3B-459-2-8 -- ARCO 0,. _.,d Gas Company Daily Well History--lnter~ tnatrucUelte: This form is used durmg drilling or workover ODerations. If testing, Coring, or perloraling, show formation name m dsscrlt, ling work performed. Number a;I drilJ stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "lnlerlm" sheets unhl hnal complehon. Report official or representative test on "Filial" form. f) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of Ihs week in which3 oil string it set. Submit weekly for workovers and foftowing sethng of oi) strin; until completion. District Field lCounty Or Parish IState ARCO ALASKA INC. I NORTH SLOPE AK ILease or Unit 3G-10 Date and c~eptll as of 8:00 a.m. KUPARUK RIVER UNIT Complete record for each daywhile drHting or workover in progress NORDIC i 01/26/91 ( TD: 0 PB: 8156 SUPV:GB/SK 01/27/91 ( TD: 0 PB: 8156 SUPV:GB/SK OPEN DP, BLEED OF 1 BBL BRINE, SIP - 220 PSI, BUILDS TO 310 PSI, BLEED OFF 1/2 BBL, SIP BUILDS TO 310 PSI, CONT REV OUT DP, @ 06:00 TOTAL BRINE/DIESEL/AP/CMT RETURNED=48 BBL SIP=80PSI, BLEED OFF LESS THAN 1 BBL. DAILY:S28,147 CUM:$1,492,822 ETD:S1,492,822 EFC:$1,470,000 CIRC & HEAT BRINE 7"@ 8241' MW:10.1NaCl/Br RELEASE BY PASS ON RTTS, REVERSE OUT DP, RELEASE RTTS, POH AND LAY DOWN RTTS, MU CSG SPEAR ON 5" DP, RIH TAG FILL IN CSG AT 810', CIRC AND ATTEMPT TO SPEAR 7" CSG, UNABLE TO SPEAR, POH W/ SPEAR AND 5" DP, LD SPEAR, MU 6-1/8" MILL AND 4-3/4" DC'S, TIH, TAG FILL AT 810', CIRC MILL THRU FILL, TAG BP AT 880', MILL OUT BRIDGE PLUG, CIRC BTMS UP, RIH W/ DP TO 2451', ATTEMPT TO CIRC, MILL PULUGGED, WORK PIPE TO UNPLUG MILL, MILL WON'T UNPLUG, POH (WET TRIP), MU 6-1/8" BIT - BIT SUB - BUMPER JARS - TEN 4-3/4" DC'S, RIH, BREAK CIRC AT 8 JTS IN, CIRC TO 2451, CIRC AND HEAT BRINE (TEMP IN AT 06:00 46 DEG, TEMP OUT 44 DEG REL BYPASS ON RTTS PKR, REV OUT DP, 21 EELS, RELEASE PKR, MONITOR WELL, POOH LD PKR, MU CSG SPEAR ON 5" DP, RIH, TAG FILL IN CSG @ 810', CIRC & ATTEMPT TO SPEAR 7" CSG, UNABLE TO SPEAR, POOH LD SPEAR, MU 6-1/8" MILL, TIH, TAG FILL @ 810', CIRC & MILL THRU FILL W/6K#, TAG BRIDGE PLUG @ 880' (38' OF FILL),MILL BRIDGE PLUG CBU, RIH W/DP TO 2451', MU CIRC HEAD, ATTEMPT TO CIRC, MILL PLUGGED, WORK PIPE, UNABLE TO UNPLUG MILL, POH WET TRIP MU 6-1/8" BIT, RIH MU CIRC HEAD @ 29 STDS IN, BREAK CIRC, CIRC 8 JTS TO 2451, CIRC & HEAT BRINE TEMP @ 06:00 46 DEG F IN, 44 DEG F OUT. DAILY:S28,147 CUM:$1,520,969 ETD:S1,520,969 EFC:$1,470,000 POOH W/7" CSG 7"@ 8241' MW:10.1NaC1/Br CONT TO CIRC AND HEAT BRINE, RU TO POH, POH W/ 3-1/2" DP, LD BHA, RU AND RIH W/ FREE POINT AND 7" CASING SPEAR, SPEAR CSG AT 812', RU FREE POINT TOOL TO 2000' CSG FREE AT 2000' RELEASE SPEAR, POH WITH SPEAR AND FREE POINT, PULL WAER BUSHING, INSTALL TEST PLUG IN 9-5/8", TEST BOPE, PULL TEST PLUG, MU 7" CSG CUTTER, RIH ON 3-1/2" DP, RIH, CUT 7" CSG AT 1800', POH W/ 3-1/2" DP AND CSG CUTTER, MU 7" CSG SPEAR, RIH LATCH ON 7" CSG, PULL CSG FREE (76K# TO PULL, 40K# OVERPULL) POH W/ 7" CSG CONT TO HEAT & CIRC BRINE DOWN DP, RETURN TEMP-45 DEG F, RD CIRC EQ, RU TO PUMP OUT OF HOLE, POOH W/3-1/2" DP, LD BHA, RU AK PIPE RECOVERY & RIH W/SPEAR & FREE POINT, SPEAR 7" @ 812', RUN FREE POINT TO 2000', FREE CSG TO 2000', RELEASE SPEAR, POH RD APR, PULL WEAR BUSHING, INSTALL TEST PLUG IN 9-5/8", TEST BOPE & CHOKE MANIFOLD, PULL TEST PLUG, MU 7" CSG CUTTER, RIH, CUT CSG @ 1800', POOH RIH W/7" CSG SPEAR, SPEAR CSG, PULL FREE, 76K# TO PULL FREE 40K# OVERPULL, POOH W/7" CSG IWeH no The aDove is correct DAILY Signature For form preparation and distripu'~ton see Procedures Menual Section",J~, Drilling, Pages 86 and 87 $47,977 CUM:$1,568,946 ETD:S1,568,946 gFC:$1~470,0:~. I Oate -- ITitle ..... A -- ~ AR38-459-2-B INumber alt dally well h,story terms consecubvely as (hey are plepared for each well. ARCo 011 Gas Company Daily Well History--lnterir Instrl~ct|eltl: This form is used during drilling Or workover operations. If testing, coring, or 0erforating, show formation name in describing work performed. Number ail dr~ll stem tests sequentially. Attach description of all cores. Work 0erformed by Producing Section will be reported on "lnlert~" sheets until final completion. Report official or representative test on "FIlial' form. 1) Submit "ll~lel'lm" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workoverS and following setting of Oil sirra§ unlil completion. District ~County or Parish ARCO ALASKA INC. { NORTH SLOPE Field ]Lease or Unit KUPARUK RIVER UNIT I ADL:25547 ALK:2661 Date and cleptn Complete record for each clay while drilling or workovar ~n progress as of S:00 a..~. NORDIC I 01/28/91 ( TD: 0 PB: 8156 SUPV:GB/SK 01/29/91 ( TD: 0 PB: 8156 SUPV:GB/SK 01/30/91 ( TD: 0 PB: 8156 SUPV:GB/SK 01/31/91 ( TD: 0 PB: 8156 SUPV:GB/SK 02/01/91 ( TD: 0 PB: 8156 SUPV:DB/LA IState 23) 26) AK TIH W/6-1/8" BIT 7"@ 8241' MW:10.8 NaC1/Br POOH W/7" CSG, RECOVERED 22.5 JTS, INSPECT 7" FOR DAMAGE, CH/t_NGE OUT SEAL RINGS, DRIFT, CLEAN & TALLY, 1.5 BAD JTS,MU & RIH W/8.5 BIT & 9-5/8" CSG SCRPR TAG CSG 7" @ 1798', CIRC, CLEAN MUD PITS WAIT ON BRINE, DIPLACE 9-5/8" F/1800' WITH 10.8 BRINE, DISPLACED FLUID APPEARS TO BE FRAC FLUID-GELLED DIESEL WATER, DISPLACE 160 BBL, PLUGGING FLOW LINE, TO THICK TO CIRC, POH W/ SCRP, MU 6-1/8" BIT & RIH TO PUSH BP TO BOTTOM. DAILY:S82,923 CUM:$1,651,869 ETD:SI,651,869 EFC:$1,470,000 RELEASE RTTS PKR 7"@ 8241' MW:10.7 NaC1/Br RIH W/6.125" BIT TO PUSH BP TO BOTTOM, TAGGED BP @ 2395', CBU, PU KELLY, TURN ON BP W/16K, SET KELLY BACK, PUSH DEBRIS DOWN SNAGGING INTERMITTENTLY, WORK PIPE AS NEEDED, TAG FILL @ 8120', CIRC HOLE CLEAN & HEAT UP, RETURN TEMP-40 F, POH, PU 9-5/8" RTTS PKR, RIH & SET PKR @ 1785', PRESS 9-5/8X7 TO 2000PSI, HOLD FOR 40 MIN, DOWN TO 75 PSI, BLEED OFF, OPEN BY PASS, CHECK OK, RELEASE PKR, POH DAILY:S28,835 CUM:$1,680,704 ETD:S1,680,704 EFC:$1,470,000 WAIT ON WEATHER 7"@ 8241' MW:10.7 NaC1/Br RELEASE RTTS PKR & POH, LD PKR, RIH W/TRISTATE BACK OFF TOOL STRAP IN HOLE, FILL W/DIESEL, PRESS DP & BACK OFF TOP CSG STUB @ 1822.54', POOH WET, RIH W/7" CSG SPEAR, CIRC & STAB FISH @ 1802', POOH W/22.48' CSG, TOP OF CSG 1822.5 LD SPEAR, RU TO RUN 7" CSG, MU TRISTATE SCREW IN CSG GUIDE & BAKER OPEN HOLE PKR ON BOTTOM OF 7" CSG, PULL WEAR BUSHING, RIH W/27 JTS CSG, 1197', INSTALL LOWER KELLY COCK & CIRC HEAD ON 7" CSG, BREAK CIRC, SECURE WELL, WOW FOR AP, ROAD DRIFTED IN DAILY:S31,809 CUM:$1,712,513 ETD:S1,712,513 EFC:$1,470,000 WAIT ON WEATHER 7"@ 8241' MW:10.7 NaC1/Br ROADS DRIFTED SHUT, MONITOR WELL, BREAK CIRC, RECIP PIPE, GENERAL RIG MAINT. DAILY:S31,809 CUM:$1,744,322 ETD:S1,744,322 EFC:$1,470,00~ RU TO CIRC ARCTIC PACK 7"@ 8241' MW:10.7 NaC1/Br RU TO RUN 7" CSG, RIH W/ 15 JTS TO 1822', 42 JTS TOTAL, CIRC DOWN 7" ONE COMPLETE CIRC @ 95 SPM @ 200 PSI, RU TO CIRC ARCTIC PACK. DAILY:S49,995 CUM:$1,794,317 ETD:S1,794,317 EFC:$1,470,00. 3G-!O The above is correct For form preparation and distriblaf~ii~l't ~ see Procedures Manual Section '1~, Drilling, Pages 86 and 8;' AR38-459-2-8 Number all dally well history forms consecullvely as {hey are prepared for each well. / ARCO 0,..,d Gas Company Daily Well History--lnter~ Inatl'tletielte: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in descrlbin,~ work performed. Number all drill stem tests SlCluentially. Attach deSCription of all cores. Work performed by Producing Section will be reported on "lnllrlnl' sheets untd final completion. Report official or ,eprex'ants,ire teat on "Final" form. 1) Submit "lnleglm" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in whict~ oil string ie ~t. Sul~mit weekly for workovers arid following Setting of oil st,in§ until completion. ICounty or Parish I State District ARCO ALASKA INC. I NORTH SLOPE I Field KUPARUK RIVER UNIT ILease or UnitAD:L 25547 ALK: 2661 Coral:lists record for 9~l.C..~.~h,l, drilling ..... kover in progress Date and de,th as of 8:00 a.m. 02/02/91 ( TD: 0 PB: 8156 SUPV:DB/LA 02/03/91 ( TD: 0 PB: 8156 SUPV:DB/LA 02/04/91 ( TD: 0 PB: 8156 SUPV:DB/LA 02/05/91 ( TD: 0 PB: 8156 SUPV:DB/LA AK 8) TIH W/6.125 BIT & 7" SCRP 7"@ 8241' MW:10.7 NaCl/Br SERVICE RIG, PUMP AP DOWN 7" CSG, RETURN TO PITS, UP WT 36K~ DWN WT 32K#, STRING WT 34K#, STAB CSG & SCREW INTO 7" CSG STUMP, PRESS TEST 7" CSG TO 1800, F/30 MIN, LOSS OF 60PSI ON TEST, BLEED OFF, DRAIN STACK, ND BOPE, RU PU SLINGS IN BLOCKS, PU STACK & HANG OFF SAME, RD PU SLINGS, RU CSG ELEV PU 7" TO ll0K#, RU 2" CIRC HOSE ON 7", SET 7" CSG SLIPS, SLACK OFF & SET PKR @ 2950PSI, PRESS TO 3500 PSI F/30 MIN, 70 PSI LOSS, BLEED OFF, PU STACK & CUT CSG W/PIPE CUTTER ND 9-5/8"X11" DSA, INSTALL PO, CUT CSG TO SPEC & DRESS, INSTALL PO & FI.J%NGE, TEST TO 3000PSI, SET ADAPTER FLANGE, SET TEST PLUG, NU BOPE, TEST BOPE, PULL TEST PLUG, SET WEAR RING, RIH W/3-1/2" DP TO 1847', CIRC OUT AP @ 1847' @ 95SPM, CONT TIH DAILY:S147,708 CUM:$1,942,025 ETD:S1,942,025 EFC:$1,470,000 TIH W/PERF GUNS 7"@ 8241' MW:10.8 NaC1/Br CONT RIH W/3-1/2" DP TO 8117', RU TO REV CIRC, WT UP CLEAN BRINE TO 10.BPPG WHILE CIRC, DISPLACE 170 BBLS, POOH, PULL WEAR RING, RD RISER & FLOWLINE, RU HLS, RIH W/PERF GUN, PERF 7946'-7926' W/4-1/2" CSG GUN @ 4 SPF 180 DEG PHASE. RIH W/PERF GUN #2 DAILY:S32,067 CUM:$1,974,092 ETD:S1,974,092 EFC:$1,470,000 MONITOR WELL, PREP TO RIH 7"@ 8241' MW:10.8 NaC1/Br RIH W/GUN#2 PERF 7888'-7904' @ 4 SPF 180 DEF PHASE, RIH W/GUN #3, PERF 7814'- 7834' @ 10 SPF, RIH W/GUN #4, PERF 7794'-7814' @ 5 SPF, WELL STARTED FLOWING, 3 BB; GAIN IN 25 MIN, SI @ 14:10 SIP-200PSI, SIP-215PSI IN 20 MIN, RD HLS, NU FLOW NIPPLE, DILUTE 10.BPPG SURFACE BRINE TO WT UP W/ NABR, MONITOR PRESS, 235PSI @ 1600 HRS, 260PSI @ 1700 HRS, 315PSI @ 1830 HRS, FRACMASTER CTU DOWN DUE TO COLD, CPANES DOWN' DUE TO COLD, BLEED OFF GAS HEAD THRU CHOKE, FILL HOLE W/2 BBL 12.0PPG BRINE & MONITOR WELL, NO FLOW INITIALLY THEN STARTED FLOWING SI WELL, 140PSI IN 15 MIN, 165PSI IN 35 MIN, BULLHEAD 150 BBL 12.0 PPG BRINE @ 1 BPM, MAX PRESS 2450PSI @ 25 BBLS INJECTED, FELL SLOWLY TO 1400PSI FINAL INJECTION PRESS, MONITOR WELL, 385 PSI @ 10 MIN, 305 PSI @ 1.5 HRS, 305 PSI @ 2 HRS, BLEED OF GAS HEAD & 3 BBL CRUDE THRU CHOKE, FILL HOLE W/6 BBL 12.0PPG BRINE, MONITOR. WELL, SOME GAS BUBBLING, NOT FLOWING, PREP TO RIH W/DC & DP, BIT & DC IN HOLE FILLING DP W/12.0PPG BRINE, DAILY:S177,950 CUM:$2,152,042 ETD:S2,152,042 EFC:$1,470,000 POH W/ 6" GR/JB 7"@ 8241' MW:ll.8 NaCl/Br MU BIT, RIH 5 STDS DP, CIRC 12.0 PPG BRINE, CONT RIH W/ DP AND TAG BOTTOM AT 8119', 3 BBL GAIN WHILE RIH, MONITOR WELL, BUBBLING BUT NOT FLOWING, CIRC 12.0 PPG BRINE, SLIP AND CUT 50' OF DRILLING LINE, POH, RD FLOW NIPPLE, RU HLS E-LINE, PU GUN #6 (RUN #7), FINISH PERFING 'C' SAND, MU 6" GR/JB ON Theal;oveisco,rect E-LINE AND RIH THRU 'C' AND 'A' PERFS, POH Ioate I jTitle m "7' I . AR3B-459-2-8 lNumber all dally well history forms Consecutively as they are prepared for each well. ARCO 0 d Gas Company Daily Well History--Inter: Inltllictioltl: This form ia used during drilling or workover oPerltionl. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem teltl se<luelwflllly. Attach delcription of all corel. Work performed by Producing Section will be reported on "InteriM" sheets untd final completion, Report official or reprelerttlllvl tell On "Filtel" form. 1) Submit "ll~tel, llW' sheets when filled out but not les,, frequently than avery 30 days, or (2) on Wednesclay of the week itl wllicl~ oil atrtl~ le Nt. Submit weekly for workovers and following setting Ot oil string until comDlation. County or Parish ARCO ALASKA INC. I NORTH SLOPE ! I Lease or Unit KUPARUK RIVER UNIT I ADL:25547 ALK:2661 )late record for each day while drilling or workover in progress NORDIC :]. District Fiejd bate aha' ~ as of 8:00 a.m. 02/06/91 ( ) TD: 0 PB: 8156 SUPV:DB/LA IState AK Welt no. 3G-10 DAILY:$28,147 CUM:$2,180,189 ETD:52,180,189 EFC:$1,470,000 SECURE WELL, CLEAN PITS 7"@ 8241' MW:ll.8 NaC1/Br POH W/ JUNK BASKET, MU TIW SS PERM PKR AND RIH AND SET AT 7855' WLM, TOH, RD HLS E-LINE, MU AND RUN 3-1/2" COMP ASSY TO SSSV, PU SSSV AND INSTALL 1/4" CONTROL LINE, CONT RIH W/ COMP ASSY, STAB INTO TIW PKR, MU TBG HNGR, TEST HNGR TO 5000 PSI, LAND TBG, SET PKR W/ 2500 PSI ON TBG, PU AND SHEAR PBR, RELAND TBG AND RILDS, CLOSE SSSV, TEST SSSV, ND BOPE, NU TREE, PULL BPV, SET TEST PLUG, TEST PACKOFF, TEST TREE, TREE LEAKED, TIGHTEN ALL FLANGES AND RETEST, PULL TEST PLUG, OPEN SSSV, TEST ANNULUS, PRESS TBG TO 3200 PSI AND SHEAR OUT SHEAR OUT SUB, DIPLACE ANN W/ 12 BBLS DIESEL, BULLHEAD 4 BBLS DIESEL DOWN TBG, SECURE WELL, INSTALL COMPANION FLANGE ON 7" ANN, CLEAN PITS DAILY:S317,333 CUM:$2,497,522 ETD:S2,497,522 EFC:$1,470,00~3 The a~ovl il , For ors preparation an see Procedures MlnUll ~tctJon Drilling, Pagel 88 and 87v JOate ]Title · Number all dally well history forms consecutively aa Ihey are prepared for each well. AR3B-459-2-B -- ARCO ,.,.i and Gas Company Daily Well History-Final Repo Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final ReRort" should be submitted also when operations ara suspended for an indefinite or apprscial~le length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided The "Final Report" form may be used for reporhng the entire operation if space is available. t Accounting cost center code District State ARCO ALASKA INC. AK Field County or Parish NORTH SLOPE Itease or Unit ADL:25547 ALK:2661 little COMPLETION IWell no. 3G~10 KUPARUK RIVER UNIT AK4974 Operator ~A.R.Co. W.I. ITotal number of wells (active or inactive) on this~ Icost center prior to plugging and ARCO [abandonment of this well 5 5 t 2 5 2 0 7 2 Spudded or W.O. begun I Date IHour J Prior status if a W.O. SPUD I 0*/29/90 / 23:00 Date and depth Complete record for each day reported as of 8:00 a.m. NORDIC 1 02/07/91 (33) TD: 0 PB: 8156 SUPV:DB/LA RELEASE 7"@ 8241' MW:ll.8 NaC1/Br INSTALL COMPANION FLANGE ON 7" ANN. CLEAN PITS DAILY:S3,775 CUM:$2,501,297 ETD:S2,501,297 EFC:$1,470,000 Old TD I New TO I PB Depth I I Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservoir name(s) Potential test data , , , Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on t~st Gas Der Pump size, SI~M X length Choke size T.P. C.P. Water % GOR Gravity AIl(~wable E~fec::.e Corrected The above is correct Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well history forms consecutively as they are prepared for each well. by GREAT LAND DIRECTIONAL DRILLING, INC. for Gyrodata Services, Inc. 08/31/90 Client .... : ARCO ALASKA, INC. Field ..... : KUPARUK RIVER Well ...... : KRU 3G-10 Section at: N,22.33,E Surveyor..: M. NAIRN Computation...: RADIUS OF CURVATURE Survey Date...: 08/12/90 RKB Elevation.: 90.00 ft API Number .... : 50-103-20134 Job Number .... : AK0890G239 INTERPOLATED MARKERS REPORT Surface Location: 2538 SNL 145 EWL S24 T12N RSE MARKER IDENTIFICATION KB 9-5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A BASE KUPARUK A 7" LINER TD MEAS INCLN DEPTH ANGLE 0 0.00 3783 44.43 7777 49.45 7838 50.05 7863 50.33 8053 51.55 8240 51.81 8250 51.81 VERT-DEPTHS SECT BKB SUB-S DIST DIRECTION REL-COORDINATES BEARING FROM-WELLHEAD 0 -90 3034 2944 5821 5731 5860 5770 5876 5786 0 N 0.00 E 1979 N 22.68 E 4837 N 28.68 E 4883 N 29.33 E 4902 N 29.50 E 0 N 0 E 1853 N 697 E 4461 N 1870 E 4502 N 1892 E 4518 N 1902 E 5996 5906 6111 6021 6118 6028 5049 N 31.43 E 5193 N 33.49 E 5201 N 33.49 E 4646 N 1976 E 4769 N 2056 E 4776 N 2060 E I( OFILMED GREAT LAND Client .... : Field ..... : Well ...... : Section at: Surveyor..: DIRECTIONAL DRILLING, ARCO ALASKA, INC. KUPARUK RIVER KRU 3G-10 N,22.33,E M. NAIRN INC. Computation...: Survey Date...: RKB Elevation.: API Number .... : Job Number .... : 08/30/90 RADIUS OF CURVATURE 08/12/90 90.00 ft 50-103-20134 AK0890G239 S MEAS INCLN C DEPTH ANGLE 7 100 0.31 7 200 0.44 7 300 0.28 7 400 0.68 7 500 6.10 VERTICAL-DEPTHS BKB SUB-SEA RECORD OF SURVEY SECTION DIRECTION RELATIVE-COORDINATES CLOSURE DL DISTNCE BEARING FROM-WELL-HEAD DISTNCE BEARING /100 100.0 10.0 0.1 S 28.52 E 0.0 N 0.2 E 0.2 N 75.74 E 0.31 200.0 110.0 -0.2 S 39.68 E 0.5 S 0.6 E 0.7 S 48.61 E 0.13 300.0 210.0 -0.6 S 25.50 E 1.0 S 0.9 E 1.4 S 41.29 E 0.16 400.0 310.0 -0.5 N 61.24 E 1.2 S 1.6 E 2.0 S 52.15 E 0.40 499.8 409.8 5.0 N 15.92 E 3.3 N 5.2 E 6.1 N 57.98 E 5.44 7 600 8.68 598.9 508.9 17.8 N 17.31 E 15.6 N 8.9 E 17.9 N 29.68 E 2.58 7 700 11.61 697.4 607.4 35.4 N 21.30 E 32.2 N 14.7 E 35.4 N 24.54 E 2.93 7 800 12.92 795.1 705.1 56.6 N 22.27 E 51.9 N 22.6 E 56.6 N 23.51 E 1.31 7 900 17.54 891.5 801.5 82.9 N 19.63 E 76.4 N 32.0 E 82.9 N 22.70 E 4.63 7 1000 23.69 985.1 895.1 118.0 N 17.63 E 109.8 N 43.2 E 118.0 N 21.48 E 6.16 7 1100 29.89 1074.3 984.3 162.8 N 16.90 E 152.8 N 56.6 E 162.9 N 20.32 E 6.20 7 1200 31.30 1160.4 1070.4 213.4 N 15.27 E 201.7 N 70.7 E 213.7 N 19.31 E 1.48 7 1300 30.75 1246.1 1156.1 264.6 N 15.94 E 251.4 N 84.5 E 265.2 N 18.59 E 0.58 7 1400 33.79 1330.6 1240.6 317.7 N 16.20 E 302.7 N 99.3 E 318.5 N 18.17 E 3.04 7 1500 37.67 1411.8 1321.8 375.8 N 17.35 E 358.6 N 116.2 E 376.9 N 17.95 E 3.90 7 1600 40.20 1489.6 1399.6 438.4 N 17.95 E 418.4 N 135.2 E 439.7 N 17.91 E 2.54 7 1700 40.90 1565.6 1475.6 503.3 N 19.34 E 480.0 N 156.0 E 504.7 N 18.00 E 0.92 7 1800 42.05 1640.5 1550.5 569.5 N 20.72 E 542.2 N 178.7 E 570.9 N 18.24 E 1.31 7 1900 43.27 1714.0 1624.0 637.2 N 21.93 E 605.4 N 203.3 E 638.6 N 18.57 E 1.35 7 2000 46.70 1784.7 1694.7 707.9 N 23.78 E 670.5 N 230.8 E 709.1 N 18.99 E 3.57 7 2100 46.65 1853.4 1763.4 780.6 N 24.54 E 736.9 N 260.6 E 781.6 N 19.47 E 0.40 ASurvey Codes: 7/GYRO (KRU3G10) KRU3G-10 S MEAS C DEPTH 7 2200 7 2300 7 2400 7 2500 7 2600 INCLN ANGLE 45 44 45 44 43 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE .64 1922.6 1832.6 852.7 .95 1993.0 1903.0 923.8 .62 2063.3 1973.3 994.8 .66 2133.9 2043.9 1065.7 .50 2205.7 2115.7 1135.2 7 2700 45.70 7 2800 46.12 7 2900 45.64 7 3000 45.28 7 3100 44.64 7 3200 45.84 7 3300 46.48 7 3400 45.92 7 3500 45.68 7 3600 45.66 7 3700 45.24 7 3800 44.27 7 3900 44.22 7 4000 44.25 7 4100 43.48 7 4200 43.23 7 4300 44.59 7 4400 45.74 7 4500 45.95 7 4600 45.88 2276.9 2186.9 1205.4 2346.5 2256.5 1277.2 2416.1 2326.1 1349.0 2486.2 2396.2 1420.2 2557.0 2467.0 1490.8 2627.4 2537.4 1561.8 2696.7 2606.7 1633.9 2765.9 2675.9 1706.1 2835.6 2745.6 1777.8 2905.5 2815.5 1849.3 2975.6 2885.6 1920.6 3046.7 2956.7 1991.0 3118.3 3028.3 2060.8 3189.9 3099.9 2130.5 3262.0 3172.0 2199.8 3334.7 3244.7 2268.4 3406.8 3316.8 2337.8 3477.3 3387.3 2408.7 3547.0 3457.0 2480.4 3616.5 3526.5 2552.2 3686.5 3596.5 2623.7 RECORD OF SURVEY 7 4700 45.35 DIRECTION BEARING RELATIVE-COORDINATES FROM-WELL-HEAD N 20.73 E 803.4 N 288.3 E N 21.64 E 869.7 N 314.0 E N 20.81 E 935.9 N 339.7 E N 20.99 E 1002.1 N 365.0 E N 20.99 E 1067.1 N 389.9 E N 21.63 E 1132.5 N 415.4 E N 20.07 E 1199.6 N 441.0 E N 20.31 E 1267.0 N 465.8 E N 20.60 E 1333.8 N 490.7 E N 20.91 E 1399.9 N 515.7 E N 21.42 E 1466.1 N 541.4 E N 21.81 E 1533.1 N 567.9 E N 21.51 E 1600.2 N 594.6 E N 21.98 E 1666.8 N 621.1 E N 21.94 E 1733.1 N 647.9 E N 22.06 E 1799.2 N 674.6 E N 22.81 E 1864.3 N 701.5 E N 22.61 E 1928.7 N 728.4 E N 23.27 E 1992.9 N 755.6 E N 23.61 E 2056.5 N 783.1 E N 24.02 E 2119.3 N 810.9 E N 23.85 E 2182.7 N 839.0 E N 22.65 E 2247.8 N 867.0 E N 21.69 E 2314.3 N 894.1 E N 20.87 E 2381.2 N 920.1 E N 22.09 E 2447.7 N 946.3 E Page 2 08/30/9© CLOSURE DISTNCE BEARING 853.6 N 19.74 E 924.6 N 19.85 E 995.7 N 19.95 E 1066.5 N 20.01 E 1136.1 N 20.07 E DL /lOO 2.19 0.83 0.79 0.96 1.16 1206.3 N 20.14 E 2.22 1278.1 N 20.18 E 0.91 1349.9 N 20.18 E 0.50 1421.2 N 20.20 E 0.39 1491.8 N 20.22 E 0.66 1562.8 N 20.27 E 1634.9 N 20.33 E 1707.1 N 20.38 E 1778.8 N 20.44 E 1850.3 N 20.50 E 1921.5 N 20.55 E 1991.9 N 20.62 E 2061.6 N 20.69 E 2131.3 N 20.76 E 2200.5 N 20.85 E 2269.1 N 20.94 E 2338.4 N 21.03 E 2409.2 N 21.09 E 2481.0 N 21.12 E 2552.8 N 21.13 E 2624.3 N 21.14 E 1.23 0.67 0.58 0.34 0.03 0.42 1.04 0.11 0.32 0.79 0.32 1.36 1.30 0.54 0.43 0.81 'Survey Codes: 7/GYRO KRU3G-IO S MEAS INCLN C DEPTH ANGLE 7 4800 45.52 7 4900 45.55 7 5000 45.52 7 5100 45.61 7 5200 45.86 7 5300 45.39 7 5400 45.50 7 5500 45.11 7 5600 44.40 7 5700 44.74 7 5800 44.42 7 5900 45.64 7 6000 45.26 7 6100 46.34 7 6200 46.30 7 6300 46.68 7 6400 46.97 7 6500 45.07 7 6600 45.41 7 6700 45.33 7 6800 45.62 7 6900 46.75 7 7000 47.41 7 7100 46.93 7 7200 46.88 7 7300 46.95 VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 3756.6 3666.6 2694.9 3826.7 3736.7 2766.2 3896.7 3806.7 2837.5 3966.7 3876.7 2908.9 4036.5 3946.5 2980.4 4106.5 4016.5 3051.9 4176.6 4086.6 3123.1 4247.0 4157.0 3194.2 4318.0 4228.0 3264.6 4389.2 4299.2 3334.7 RECORD OF SURVEY DIRECTION BEARING RELATIVE-COORDINATES FROM-WELL-HEAD Page 3 CLOSURE DISTNCE BEARING N 23.81 E 2513.3 N 974.1 E 2695.5 N 21.18 E N 25.22 E 2578.2 N 1003.7 E 2766.7 N 21.27 E N 24.97 E 2642.9 N 1034.0 E 2837.9 N 21.37 E N 24.50 E 2707.7 N 1063.8 E 2909.2 N 21.45 E N 24.47 E 2772.9 N 1093.5 E 2980.7 N 21.52 E N 23.14 E 2838.3 N 1122.4 E N 22.35 E 2904.0 N 1149.9 E N 22.21 E 2969.8 N 1176.9 E N 25.53 E 3034.2 N 1205.4 E N 25.22 E 3097.6 N 1235.4 E 08/30/90 DL /lOO 0.89 0.72 0.13 0.2~ 0.25 3052.1 N 21.58 E 0.82 3123.4 N 21.60 E 0.42 3194.5 N 21.62 E 0.40 3264.8 N 21.67 E 1.77 3334.8 N 21.74 E 0.37 4460.5 4370.5 3404.8 N 24.81 E 3161.2 N 1265.1 E 3404.9 N 21.81 E 4531.1 4441.1 3475.4 N 26'29 E 3225.0 N 1295.6 E 3475.5 N 21.89 E 4601.3 4511.3 3546.5 N 26.02 E 3289.0 N 1327.0 E 3546.6 N 21.97 E 4671.0 4581.0 3618.0 N 26.67 E 3353.2 N 1358.9 E 3618.1 N 22.06 E 4740.1 4650.1 3690.2 N 26.41 E 3417.9 N 1391.2 E 3690.2 N 22.15 E 4808.9 4718.9 3762.5 N 25.94 E 3483.0 N 1423.2 E 4877.3 4787.3 3835.3 N 25.49 E 3548.7 N 1454.8 E 4946.8 4856.8 3907.2 N 24.72 E 3613.9 N 1485.3 E 5017.2 4927.2 3978.2 N 23.55 E 3678.6 N 1514.4 E 5087.4 4997.4 4049.3 N 23.43 E 3743.9 N 1542.7 E N 23.36 E 3809.4 N 1571.0 E N 24.67 E 3875.3 N 1600.4 E N 24.13 E 3941.9 N 1630.7 E N 22.34 E 4009.3 N 1659.6 E N 22.40 E 4076.9 N 1687.4 E 4144.5 N 1714.9 E 5157.6 5067.6 4120.6 5226.8 5136.8 4192.7 5294.9 5204.9 4265.9 53'62.9 5272.9 4339,2 5431.2 5341.2 4412.2 3762.5 N 22.23 E 3835.3 N 22.29 E 3907.2 N 22.34 E 3978.2 N 22.38 E 4049.3 N 22.39 E 4120.6 N 22.41 E 4192.7 N 22.44 E 4265.9 N 22.47 E 4339.2 N 22.49 E 4412.3 N 22.48 E 4485.3 N 22.48 E N 21.93 E 5499.5 5409.5 4485.3 0.38 1.44 0.40 1.13 0.14 0.45 0.38 1.94 0.68 0.10 0.29 1.33 0.72 1.07 0.06 0.26 'Survey Codes: 7/GYRO KRU 3G- 10 S MEAS INCLN C DEPTH ANGLE 7 7400 46.81 7 7500 46.92 7 7600 47.65 7 7700 48.93 7 7800 49.61 7 7900 50.76 7 8000 51.45 7 8100 51.64 7 8130 51.81 X 8250 51.81 RECORD OF SURVEY VERTICAL-DEPTHS BKB SUB-SEA SECTION DISTNCE 5567.8 5477.8' 4558.2 5636.2 5546.2 4631.0 5704.1 5614.1 4704.4 5770.6 5680.6 4778.8 5835.8 5745.8 4854.2 5899.9 5809.9 4930.4 5962.7 5872.7 5007.5 6024.8 5934.8 5084.9 6043.4 5953.4 5108.0 6117.6 6027.6 5200.6 DIRECTION BEARING RELATIVE-COORDINATES FROM-WELL-HEAD Page 4 CLOSURE DISTNCE BEARING N 26.46 E 4211.1 N 1744.8 E 4558.2 N 22.51 E N 25.86 E 4276.6 N 1777.0 E 4631.1 N 22.56 E N 25.72 E 4342.7 N 1809.0 E 4704.4 N 22.61 E N 27.36 E 4409.5 N 1842.3 E 4778.9 N 22.68 E N 29.07 E 4476.3 N 1878.2 E 4854.3 N 22.76 E 08/30/90 N 29.75 E 4543.2 N 1915.9 E 4930.6 N 22.87 E N 30.26 E 4610.6 N 1954.8 E 5007.9 N 22.98 E N 32.47 E 4677.4 N 1995.6 E 5085.3 N 23.10 E N 33.49 E 4697.2 N 2008.4 E 5108.5 N 23.15 E N 33.49 E 4775.9 N 2060.4 E 5201.4 N 23.34 E DL /lOO 2.41 0.34 0 73 1.20 1.22 0.76 1.37 2.18 0.00 ASurvey Codes: 7/GYRO X/EXTRAPOLATED KRU3G-10 Page 5 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 08/30/90 SUBSEA MEAS INCLN DEPTH DEPTH ANGLE 0 90 0.28 100 190 0.43 200 290 0.30 300 390 0.64 400 490 5.57 500 591 8.45 600 692 11.39 700 795 12.85 800 898 17.47 900 1005 24.02 TVD BKB 90 190 290 390 490 59O 690 790 89O 990 1000 1118 30.15 1090 1100 1235 31.11 1190 1200 1352 32.32 1290 1300 1473 36.61 1390 1400 1601 40.20 1490 1500 1732 41.27 1590 1600 1867 42.87 1690 1700 2008 46.70 1790 1800 2153 46.11 1890 1900 2296 44.98 1990 2000 2438 45.26 2090 2100 2578 43.75 2190 2200 2719 45.78 2290 2300 2863 45.82 2390 2400 3005 45.25 2490 MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 0 0 S 28.52 E 0.04 N 0.16 E 0 0 S 38.56 E 0.43 S 0.51 E 0 0 S 26.92 E 0.97 S 0.88 E 0 0 S 34.59 W 1.71 S 0.84 E 0 0 N 20.38 E 2.39 N 4.75 E 1 1 N 17.18 E 14.29 N 8.48 E 2 2 N 21.00 E 30.79 N 14.16 E 5 2 N 22.22 E 50.84 N 22.14 E 8 4 N 19.67 E 75.99 N 31.81 E 15 7 N 17.59 E 111.86 N 43.87 E 28 13 N 16.60 E 161.49 N 59.19 E 45 17 N 15.50 E 219.00 N 75.44 E 62 17 N 16.07 E 277.25 N 91.98 E 83 21 N 17.04 E 342.78 N 111.30 E 111 28 N 17.96 E 418.77 N 135.34 E 142 32 N 19.79 E 500.11 N 163.15 E 177 35 N 21.53 E 584.51 N 195.03 E 218 41 N 23.84 E 675.61 N 233.04 E 263 45 N 22.52 E 772.14 N 275.92 E 306 43 N 21.60 E 866.92 N 312.90 E 348 42 N 20.88 E 961.23 N 349.35 E 388 40 N 20.99 E 1053.12 N 384.56 E 429 40 N 21.34 E 1145.01 N 420.36 E 473 44 N 20.22 E 1241.88 N 456.51 E 515 43 N 20.62 E 1337.33 N 492.03 E 2500 3147 45.20 2590 557 41 N 21.15 E 1430.57 N 527.54 E KRU3G-10 Page 6 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 08/30/90 SUBSEA MEAS INCLN DEPTH DEPTH ANGLE TVD BKB 2600 3290 46.42 2690 2700 3435 45.84 2790 2800 3578 45.66 2890 2900 3720 45.04 2990 3000 3861 44.24 3090 3100 4000 44.25 3190 3200 4139 43.38 3290 3300 4276 44.27 3390 3400 4418 45.78 3490 3500 4562 45.91 3590 3600 4705 45.36 3690 3700 4848 45.53 3790 3800 4990 45.52 3890 3900 5133 45.69 3990 4000 5277 45.50 4090 4100 5419 45.43 4190 4200 5561 44.68 4290 4300 5701 44.74 4390 4400 5842 44.93 4490 4500 5984 45.32 4590 4600 6128 46.33 4690 4700 6272 46.58 4790 4800 6419 46.62 4890 4900 6561 45.28 4990 5000 6704 45.34 5090 MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 600 44 N 21.77 E 1526.60 N 565.33 E 645 44 N 21.67 E 1623.32 N 603.72 E 688 43 N 21.95 E 1718.44 N 641.96 E 730 43 N 22.21 E 1812.58 N 680.02 E 771 40 N 22.69 E 1903.24 N 717.78 E 810 40 N 23.27 E 1992.95 N 755.60 E 849 38 N 23.77 E 2080.72 N 793.78 E 886 38 N 23.89 E 2167.62 N 832.34 E 928 42 N 22.48 E 2259.87 N 872.00 E 972 44 N 21.18 E 2355.65 N 910.32 E 1015 43 N 22.18 E 2451.00 N 947.65 E 1058 43 N 24.48 E 2544.30 N 987.98 E 1100 43 N 24.99 E 2636.64 N 1031.06 E 1143 43 N 24.49 E 2729.36 N 1073.70 E 1187 43 N 23.45 E 2822.91 N 1115.75 E 1229 43 N 22.32 E 2916.56 N 1155.08 E 1271 42 N 24.23 E 3009.17 N 1193.77 E 1311 40 N 25.22 E 3098.25 N 1235.76 E 1352 40 N 25.42 E 3187.62 N 1277.51 E 1394 42 N 26.06 E 3278.72 N 1322.04 E 1438 44 N 26.60 E 3371.00 N 1367.78 E 1482 45 N 26.07 E 3465.01 N 1414.38 E 1529 46 N 25.35 E 3560.88 N 1460.59 E 1571 43 N 24.00 E 3653.48 N 1503.27 E 1614 42 N 23.43 E 3746.30 N 1543.76 E 5100 6847 46.15 5190 1657 43 N 23.97 E 3840.00 N 1584.47 E KRU3G-10 Page 7 DATA INTERPOLATED FOR 100 FT SUBSEA INTERVAL 08/30/90 SUBSEA MEAS INCLN DEPTH DEPTH ANGLE TVD BKB 5200 6993 47.36 5290 5300 7140 46.91 5390 5400 7286 46.94 5490 5500 7432 46.85 5590 5600 7579 47.50 5690 5700 7730 49.13 5790 5800 7884 50.58 5890 5900 8044 51.53 5990 6000 8205 51.81 6090 MD-TVD VERT DIRECTION RELATIVE COORDINATES DIFF CRRT BEARING FROM WELL HEAD 1703 46 N 24.17 E 3937.11 N 1628.48 E 1750 47 N 22.36 E 4036.17 N 1670.62 E 1796 46 N 22.00 E 4135.08 N 1711.13 E 1842 46 N 26.27 E 4232.22 N 1755.32 E 1889 47 N 25.75 E 4328.87 N 1802.30 E 1940 50 N 27.87 E 4429.31 N 1852.69 E 1994 55 N 29.64 E 4532.72 N 1909.91 E 2054 59 N 31.23 E 4640.12 N 1972.36 E 2115 61 N 33.49 E 4746.57 N 2041.04 E KRU3G-10 Page 8 08/30/90 DATA INTERPOLATED FOR 1000 FT MEASURED DEPTH INTERVAL MEAS INCLN VERT-DEPTHS SECT DIRECTION REL-COORDINATES CLOSURE DEPTH ANGLE BKB SUB-S DIST BEARING FROM-WELLHEAD DIST BEARING DL/ 100 1000 23.69 985 895 118 N 17.63 E 110 N 2000 46.70 1785 1695 708 N 23.78 E 671 N 3000 45.28 2486 2396 1420 N 20.60 E 1334 N 4000 44.25 3190 3100 2131 N 23.27 E 1993 N 5000 45.52 3897 3807 2838 N 24.97 E 2643 N 43 E 118 N 21.48 E 6.2 231 E 709 N 18.99 E 3.6 491 E 1421 N 20.20 E 0.4 756 E 2131 N 20.76 E 0.3 1034 E 2838 N 21.37 E 0.1 6000 45.26 4601 4511 3547 N 26.02 E 3289 N 7000 47.41 5295 5205 4266 N 24.13 E 3942 N 8000 51.45 5963 5873 5008 N 30.26 E 4611 N 1327 E 3547 N 21.97 E 0.4 1631 E 4266 N 22.47 E 0.7 1955 E 5008 N 22.98 E 0.8 Speak Land Directional Drilling# Inc. VERTICAL SECTION VIEW <K8>O 500 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9OOO 5OO ARCO ALASKA, INC. KRU 36-~0 i Section at: N 22.33 E ! TVD Scale.' 1 inch = lO00 feet · Dep Scale.' i inch = ~000 feet {Drawn ..... · 08/30/90 1 Harker Identification A} ~8 B} 9-5/8" CASING ~ TOP KUPARUK C DJ BASE KUPARUK C ~ TOP KUPARUK A F} BASE RUPARUK A G} 7" LINER H} TD MD TVD SECTN INCLN 0 0 0 0.00 3783 3034 1979 44.43 7777 582t 4837 49.45 7838 5860 4883 50.05 7863 5876 4902 50.33 B053 5996 5049 5t.55 8240 8ti! 5i93 5t.8t 8250 6ttb 520t 51.8t 0 5OO ~000 i500 aooo asoo 30o0 3500 4o0o 4500 5000 Section Departure 48OO 4400 4000 3~00 3~00 2800 2400 2000 1600 t200 ! Great Land Dire£tlanaI Drilling. l-nc. Harker Identification ND NIS A) KB 0 0 N 0 B) 9-5/8" CASZNG 3783 t853 N 697 ~ TOP KUPARUK C 7777 446! N tB70 D) BASE KUPARUK C 7838 4502 N t892 ~ TOP KUPARUK A 7863 4518 N t902 F} BASE KUPARUK A 8053 4646 N 1976 ~ 7' L[NER 8240 4769 N 2056 ~ TD 8250 4776 N 2060 PLAN VIEW ARCO ALASKA, iNC. KRU 3G-10 CLOSURE ..... : 5201 ft N 23.34 E DECLINATION.: 0.00 E SCALE ....... : ! inch = BOO feet ~DRANN ....... : 08/30/90 800 ! 400 0 4O0 400 0 400 <- I~EST: EAST -> i 800 ~200 ~600 2000 e400 2800 3200 3600 4000 4400 AOGCC OPEN HOLE LOG INVENTORY Permit #: ¢~ ~ y .... Well Name: ~ ~ ~J ¢ ~ ~--/~) Completion Date: ~. LOG Date LOG Count RUN Received COMMENTS MUD LOG (CDM, E-Log) RESISTIVITY (DIL/SFL) DENSITY ~-~ / (CNFD, CNL) SONIC (BHC/SL, LSS SSS) CYBERLOOK DIPMETER (SHDT) GYROSCOPIC SURVEY ~ no Received Date: SAMPLES REQUIRED yes ~ Received Date : CORE INTERVALS RECOVERED COMMENTS D~K ~ ~¥£F~ ,, , * complete with form 407 PERMIT # WELL LOG INVENTORY WELL NAME OPEN HOLE LOG CNT RUN # ,, LOGS RECIEVED ON TIME MUD LOG (CDM,E-log) RESISTIVITY (DIL, DIL/SFL) DENSITY (CNFD, CFD) SONIC (BHC/SL,LSS) CYBERLOOK DIPMETER GYROSCOPIC SURVEY (GCT) SAMPLES: Required yes no Date Received: Intervals cored Core recovered COMMENTS LJG:4/91 AOGCC GEOLOGICAL MATERIALS iNVENTORY LIST · - check off or list data as it is rcceived.*list received date for 407. if not uired list as NR drillinu history survev tests core descri cored intervals core analysis I d ditch intervals d ital data ......... q~, o~/~,, , ...' ~'---,,s'-..,,, . .... LOG-r,,.,nc, ,r,_ ........ I:II~N I,~4TEFIVALS SCALE"" NO. [to...thc ncarcst footJ [inchll §0'] i ~] ¢%,, ~.... 3~qo -,qt~q ..... ii , , , ,,, ,~ ~ ARCO Alaska, Inc. Date: September 14, 1990 Transmittal #: 7888 RETURN TO: ARCO Alaska, Inc. ATTN: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 G- 1 1 Pulse Echo Cement Evaluation(PET) 9 - 7 - 9 0 2 9 4 0 - 6 7 8 4 3 G- 1 0 Pulse Echo Cement Evaluation(PET) 8 - 1 2 - 9 0 3 6 0 0 - 81 3 8 3G-07 Pulse Echo Cement Evaluation(PET) 8-1 I -90 3600-8408 3 G- 1 1 Acoustic Cement Bond Log 9 - 7 - 9 0 2 9 8 0 - 6 7 9 6 3 G- 1 0 Acoustic Cement Bond Log 8 - 1 2 - 9 0 3 6 0 0 - 81 4 0 3 G- 0 7 , Acoustic Cement Bond Log 8 - 1 I - 9 0 3 5 7 3 - 8 4 O 8 Receipt Acknowledged: DISTRIBUTION: RECEIVED Date: S E P 1 7 1990 Alaska 0il & Gas Cons. C0mmissi(~r- Anchorage Drilling NSK '3EP-£~t- ' '..;¢_ _ ..36: -'_,-.-' [ D: VICINITY i'~ ~ MI, biO. Y X L A T. LO $ $,$00,$$0.17 ' 450,$45.$$ ' ?O°ga'4?,gRR' ' ~ $,$88,$$0.40 49~,~4.?0 TO°iR'4~,~' I$0°0~0. e$$'' ~ $,~eo,$eo.$~ ~O,O?~.~O ~o*tt'~r.$te" 15o~o0'41.?t$' I0 $sOOOs ~0.40 4~0, $RO.?R PP POs op.~RO" I0~00'45. IOl " IR 0~00~ $60.~? 4 ~O, 4 ?4. ?8 ?Ootg' 4?.ORO" Ib~O0'~O. ~44 ~ 13 8~00~860.48 490,$04.86 ?OoPR' ~?.OR~" Ib~OO'op. 804" NO. ~ X L A ~ L O NO. m 8, ~O,$~0. sS 4ms, a$$.rt rooe~ ~r. gt$" /ooooo'ms, ot/" /m s, omm, meo.$/ 4$m, ss~.eff r~ee' q~.oeo" 1~ $~900~$~0.8~ 490~$0s. 04 ?O~RR' ~Y.ORO'' I~0°0~40.4 ?I' I0 5~900, 880. g~ 490~ ob9. Oo ?O°tR'op. ooO'' I0~'00. 030" PI ~~$~0.~ 4~ /O4. Ol ?~Pg'4?.OPO" I~'~./~0~ pg ~,900, 800.~ MOO,/~. ~ ?0~'4?~ OgO" /~'~8' /$ /0 b".N.L.,,, F.W.I.. 0.0. pAD P$$0' P$9' g§$O'~' PPO' ,10.4 $,$.0 t,ff$O'~' 195' 40. g P538'"' I?0' 4 ROSS'"' 145' 47.£ 83.4 PS,To'.," I gO" ~'~ /~' ~'~ I~0' 4~.~ ~NO $URV~YIN; IN r~ srArff OF AND ~Ar ?HIS PLAT ~EPR~$~N~ M~DE ~Y Mf ~ UN~R Mr O/~r ~m/&$ ~o~ coomer ~8 o¢ ~m~ t¢, moo. I I ..I o,,.I ¢r , ," ,, ~R¢O ALASKA,/NC. OW~. NO. ' NSDK, 3500. C~rA. 03 ;X. 650?0 O i,-- 'l~, I II III 7 1 4, ARCO...Alaska, Inc. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ Operation Shutdown ~ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other _ 6. Datum elevation (DF or KB) 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X.~ Exploratory _ Stratigraphic _ Service 4. Location of well at surface 2538' FNL, 145' FWL, Sec. 24, T12N, R8E, UM At top of productive interval 1950' FSL, 1950' FWL, Sec. 13, T12N, R8E, UM (approx) RKB 90' 7. Unit or Property name Kuparuk River Unit 8. Well Number 3G-1 0 9. Permit number 90-84 10. APl number 50-103-20134 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool At effective depth NA At total depth 2171' FSL, 2039' FWL, Sec. 13, T12N, RSE, UM 12. Present well condition summary Total Depth: measured 8 2 5 0' (approx) true vertical 6120' Effective depth: measured NA (approx) true vertical NA (approx) feet feet feet feet Plugs (measured) None Junk (measured) None Casing Length Size Structural Conductor 8 0' 1 6" Surface 3746' 9 5/8" Intermediate Production 8 2 0 5' 7" Liner Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth None Packers and SSSV (type and measured depth) None Cemented 760 Sx AS III & 480 Sx Class G 485 Sx Class G & 200 Sx Class G tail Measured depth True vertical depth (approx) 115' 115' 3783' 3032' 8240' 6114' 13. Attachments Description summary of proposal_ Detailed operation program X BOP sketch -- 14. Estimated date for commencing operation November, 1 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as:, Oil , Gas _ Service Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed , Title Area Drilling Engineer FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test _ Subsequent form require Approved by the order of the Commission Form 10-403 Rev 06/15/88 ORIGINAL SIGNED BY LONNIE C. SMITH Commissioner Approved Copy Retu. rned~ qllnlq IApproval No. / ~ SUBMIT IN TFilPLIOATE ARCO Oil and Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ICounty. parish or borough IState ARCO ALASKA INC. I NORTH SLOPE Field I Lease or Unit KUPARUK I,,t,eADL:. 25547 ALK: 2661 Auth· or W.O, no. AK4974 ~ DRILLING AK IWell no, 3~10 Operator ARCO W.I. ARCO I 55.2521 Spudded or W,O, begUnSPUD IDate 07/29/90 IH°ur 23: 00IPri°r status if a w'O' Date and depth as of 8:00 a.m. 07/30/90 ( 1) TD: 1119'(1119) SUPV:JMM 07/31/90 (2) TD: 3805'(2686) SUPV:JMM 08/01/90 ( 3) TD: 3805'( 0) SUPV:JMM 08/02/90 (4) TD: 4384' ( 579) SUPV:JMM 08/03/90 (5) TD: 6136'(1752) SUPV:JMM 08/04/90 (6) TD: 7685'(1549) SUPV:JMM 08/05/90 (7) TD: 8250'( 565) Complete record for each day reported DOYON 1 4 DRLG AT 1i19' MW: 9.1 VIS: 48 MOVE RIG FROM 3G-11 TO 3G-10. ACCEPT RIG AT 3G-10 AT 1900 HRS-7/29/90. NU DIVERTER, MU BHA, SRUD AT 2300 HRS ON 7/29/90. DRILL FROM 115' TO 1119'. DAILY:S60,679 CUM:$60,679 ETD:S60,679 EFC:$1,470,000 WIPER TRIP FOR 9-5/8" MW: 9.6 VIS: 46 DRLG WITH 12-1/4" AND NAVIDRILL FROM 1119' TO 3805', ADT=13.1. CIRC HOLE CLEAN AND DROP S.S. SURVEY. WIPER TRIP PRIOR TO RUNNING 9-5/8" CSG. DAILY:S62,089 CUM:$122,768 ETD:S122,768 EFC:$1,470,000 RUN WEAR BUSHING MW:10.7 VIS: 46 CONTINUE WIPER TRIP, CIRC HOLE CLEAN, DROP SS SURVEY, POOH. R/U AND RUN 9-5/8" CSG, SHOE AT 3783', FLOAT COLLAR AT 3704'. R/U AND CEMENT CSG, HAD FULL RETURNS THROUGHOUT CMT JOB. N/D DIVERTER, DO TOP JOB, N.U. BOP, RUN WEAR BUSHING. DAILY:S177,493 CUM:$300,261 ETD:S300,261 EFC:$1,470,000 RIH MW: 9.5 VIS: 38 M/U BHA ~ RIH, TAG FLOAT COLLAR AT 3704'. DRLG TO 3815' PERFORM EMW TEST TO 12.7 AT 3054' TVD. DRLG TO 4205' (BELOW COLVILLE). POOH TO GET TURBINE, MWD AND BIT. RIH, DRLG WITH TURBINE TO 4384'. MWD FAILURE, POOH. DAILY:S236,108 CUM:$536,369 ETD:S536,369 EFC:$1,470,000 RIH W/ NEW TURBINE MW: 9.5 VIS: 37 CONT. RIH, TURBODRLG 4384' TO 6136'. POOH, LOSS IN P/R INDICATES TURBO PROBLEM CHANGE OUT NEYRFOR TURBINE. RIH TO WITH NEW TURBINE. DAILY:S59,683 CUM:$596,052 ETD:S596,052 EFC:$1,470,000 ROTARY DRLG AT 7685' MW:10.8 VIS: 40 TURBOLRLG 8.5" HOLE 6136' TO 7628', CIRC/COND HOLE, DROP SS SURVEY. POOH TO 9-5/8" CSG SHOE, CIRC TO BALANCE MUD. PERFORM FORMATION TEST TO 11.3 EMW. POOH, CHANGE OUT BHA, RIH. ROTARY DRLG 7628' TO 7685'. NOTE: AT 7428' BEGAN TO P/U OIL TRACES IN M%TD. DAILY:S69,301 CUM:$665,353 ETD:S665,353 EFC:$1,470,000 LOGGING 8-1/2" W/ HLS MW:10.7 VIS: 39 ROTARY DRLG 7685'-8250'. CIRC A.ND COND HOLE, WIPER TRIP TO 4000', CiRC'ANu ~D HO~'- ~W-o~-~UKVE~'-PUOH. R/U HLS AND LOG 8-1/2" HOLE (RUN ~1 HRI-GR- SP-CAL). DAILY:S72,140 CUM:$737,493 ETD:S737,493 EFC:$1,470,000 The above is ~q,rrect Slgnat~m.~ ~ For form preparatiog,~and~dis~ribution · ~ see Procedures M~fl~al, Sechon 10, Drilling, Pages 86~,.m~d 87. Date -- -- [ Title -'-J AR3B-459-1-D Number all daily well history forms consecutively as they are prepared for each well. IPage no. ARCO Oilar, ,as Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number afl drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report officia~ or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field KUPABUK Date and depth as of 8:00 a,m, I County or Parish ARCO ALASKA INC. I NORTH SLOPE I Lease or Unit 3G-10 Complete record for each day while drilling or workover in progress 08/06/90 ( TD: 8250'( SUPV:JMM 08/07/90 ( TD: 8250'( SUPV:JCP 8) O) 9) ) DOYON 14 IState AK TIH MW:10.8 VIS: 39 LOGGING WITH HLS RUN#1 HRI/DSH/SDL/GR/CAL 8250-SURFACE; RUN#2 FWST-GR 8250 TO 9-5/8" CSG SHOE; RUN#3 ARCO SHEAR WAVE TOOL 8200'-7300'; RUN#4 SIDEWALL CORE TOTAL OF 48 SHOTS FROM 4071'-4036'. MU BHA AND TIH FOR CONDITION TRIP. DAILY:S51,918 CUM:$789,411 ETD:S789,411 EFC:$1,470,000 DISPLACE CMT W/ BRINE MW:10.9 VIS: 43 FIN TIH TO 8250'. ClRC AND COND MUD. POOH L/D DP. RU AND RUN 7", SHOE AT 8241' CIRC AND COND MUD, BATCH MIX CMT, PUMP CMT. FULL RETURNS AND RECIPROCATED PIPE ENTIRE JOB. DAILY:S253,538 CUM:$1,042,949 ETD:S1,042,949 EFC:$1,470,000 IWell no. The above is c~rect · ', , Slgnatur~ ~/~ For form prepara/tf~n/~nd distribution see Procedures ~Vl~,~al Section 10, Drilling, Pages 8'6"and 87 AR3B-459-2-B INumber all daily well hislory forms conseculively as they are prepared for each well. IPage no ARCO O,. und Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned. or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. fAccounting cost center code State AK District ~ County or Parish ARCO ALASKA TNC. t NORTH SLOPE Field Lease or Unit KUPARUK ADL: 25547 ALK: 2661 Auth. or W.O. no. lTitie AK4974 J DRILLING l Well no. 3~-10 Operator A.R.Co. W.I. ARCO 55. 2521 Spudded or W.O. begun Date SPUD 07/29/90 Date and depth as of 8:00 a.m. 08/08/90 (10) TD: 8250'( SUPV:JCP o) Complete re-cord for each day reported DOYON 14 I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well our23;00 Prior status if a W.O. N/D BOPE 7"@ 8241' MW:10.8 VIS: 0 INJECT 20 BBL MUD DOWN ANNULUS AND MONITOR FLOW BACK. N/D BOPE, CUT OFF 7" INSTALL TUBING HEAD, TEST TO 3000 PSI, OK. INJECT 140 BLS H20 AND 60 BBL DIESEL DOWN 3G-10, ALSO FREZE PROTECT 3G-8 WITH 60 BBL DIESEL. DAILY:S71,563 CUM:$1,114,512 ETD:Si,iI4,512 EFC:$1,470,000 Old TD J New TD I Released rig J Date Classifications (oil, gas, etc.) Producing method PB Depth I K nd of r g Type completion (single, dual, etc,) JOfficial reservo r name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T:P. C.P. Water % GOR Gravity Allowable Effective date corrected The above,~ correct ,' Date / JTi~,~ /~ Drilling, Pages 86 and 87. AR3B-459-3-C INumber all daily well history forms consecutively as they are prepared for each well, iPage no. DtvlMon of AtlantlcRIchflefdCompany KUPARLT< ENGINEERING TRANSMITTAL #1386 TO: John Bolye AOGCC DATE: August 20, 1990 FROM: K. W. Griffin/P. S. Baxter WELL NAME: 3G- 10 (Colville) CONFIDENTIAL TRANSMITTED HEREWITH ARE THE FOLLOWING' One each blueline and sepia: 3G-10 3G-10 ~-~ 3G-10 3G-10 Spectral Density DSN II Log Gamma Ray Tie-In For Sidewall Cores Microlog High ResolutiOn Induction DFL run 1 runl mn 1 run I 3G-11 3G-11 3G-11 Micro Log High Resolution Induction DFL Log Spectral Density DSN II Log mn 1 run 1 run 1 One each of tape and listing: 3G-10 3G-11 HRI; ML:SDL/DSN Top 3750.00 Bottom 4401.00 HRI, SDL/DSN, ML Top 3327.00 Bottom 3810.00 8/5/90 8/5/90 8/5/90 8/5/90 7/27/90 7/27/90 7/27/90 Date logged: 8/5/90 Date loged: 7/27/90 PLEASE RETURN RECEIFT TO: ARCO Alaska, Inc. ATTN: P. S. Baxter, ATO-1269 P. O. Box 100360 Anchorage, Alaska RECEIPT ACKNOWLEDGED:~ &~,fO0vX DATE: 99510R[ EIYED S EP - 4 1990 Alaska 0il & Gas Cons. Cotn~tssk ARCO Alaska, inc. Date: August 24, 1990 Transmittal #: 7866 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATe-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3G-10 Receipt LIS Tape and Listing 8 - 5 - 9 0 Full Wave Sonic REEEIVED Acknowledged: ................... Date' "-~[U'~'-? 7 1990 A/asa 011 & Gas Cons. Comml~On Anchorage DISTRIBUTION: Lynn Goettinger State of Alaska ARCO Alaska, Inc. Date: August 24, 1990 Transmittal #: 7864 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3 G- 1 0 Full Wave Sonic Delta-T Log 8 - 5 - 9 0 3 7 3 0 - 8 2 4 0 Receipt Acknowledged: ............................. Date: DISTRIBUTION: Ri ¢EIVED AU G 2 ? 1990 Alaska 0il & Gas Cons. uommiSsio[~ Anchorage D&M Drilling Franzen Vendor Package(Johnston) NSK State of Alaska(+Sepia) NAME : LOG · . w-~r.r. LOG INVENTORY LOG COUNT DATE REC RUN# CDM (mudlog) DIL/SFL (dual induction log) CNFD · (compensated neutron density) (compensated neutron formation/ litho-density) CFD (compensated formation density) BHC/SL "' (borehole compensated sonic) . LSS (long spaced sonic) ' · SSS (short spaced sonic) CYB (cyberlook) GCT (groscopic survey) DIPMETER .o SAMPLES: Require~ yes ~_~ Date Received: 'Comments: ~L ~v~'. c ~,. [ ) .~.~ ~ . (~, ~, o ~k ~ ,~ ~ ,,, . ~ ,' "~ , t3to~ ~ / ARCO Alaska, Inc. Date: August 17, 1990 Transmittal #: 7855 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3G-11 3G-10 3G-11 Receipt DISTRIBUTION: LIS Tape and Listing 7- 2 8 - 9 0 HRI,ML SDL/DSN LIS Tape and Listing 8 - 5 - 9 0 HRI,ML SDL/DSN LIS Tape and Listing , 8-16-90 AKRB900728 Acknowledged: Date: Lynn Goettinger State of Alaska ARCO Alaska, Inc. Date: August 17, 1990 Transmittal #: 7856 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 3G-10 High Resolution Induction DFL 5" 8-5-90 3790-8241 3G-10 High Resolution Induction DFL 2" 8-5-90 3790-8241 3G-10 Spectral Density DSN II Raw Data 8-5-90 3790-8214 3G-10 Spectral Density DSN II Porosity 8-5-90 200-8213 3G-10 High Resolution Induction Raw X & R 8-5-90 3790-8241 3G-10 Microlog 8-5-90 3790-8214 3G-11 Full Wave Sonic Delta-T Log 7-28-90 6300-6870 3 G - 1 1 Dual Gamma Ray Compensated 7 - 2 7 - 9 0 6 5 0 3 - 6 9 0 0 Neutron Porosity Simultaneous Formation Density 3 G - 1 1 Dual Gamma Ray Electrmagnetic 7 - 2 7 - 9 0 6 5 0 3 - 6 9 0 0 Wave Resistivity Receipt Acknowledged' ate' DISTRIBUTION: D&M Drilling Franzen Vendor Package(Johnston) NSK State of Alaska(+Sepia) July 1i, 1990 Telecopy~ (907)276-7542 P. J. Archey Area Drilling Engineer ARCO Alaska, thc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Kuparuk River Unit 3G- 10 ARCO Alaska, thC. Permit No. 90-84 Sur. Loc. 2538'F}~, 145'FWL, Sec. 24, T12N, RSE, UM. Btmhole Loc. 2171'FSL, 2039'FWL, Sec. 13, T12N, RSE, UM. Dear Mr. Archey: Enclosed is the approved application for pemit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional pemits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pe~itting dete~lnatlons are made. The Commission will advise you of those BOPE tests that it wishes to witness. Chair~n of Alaska Oil and Gas Conservation Commission BY O~ER OF THE COMMISSION d!f Enclosure Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALA,.. A OIL AND GAS ~SERVATION COMMI. 3N PERMIT TO DRILL 20 AAC 25.005 ! la. Type of Work Drill ;~ RedrJll --.- J lb. Type of Well Exploratory~ Stratigraphic Test -- Development Oil .~X Re-Entry _ Deepen --I Service _ Development Gas -- Single Zone ~ Multiple Zone _ 2. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, In~, RKB 90'. Pad 54' GL feet Kuparuk River Field 13. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25547 ALK 2661 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 2538' FNL, 145' FWL, Sec. 24, T12N, R8E, UM KuDaruk River Unit At top of productive interval (TARGET) 8. Well number Number 1950' FSL, 1950' FWL, Sec. 13 , T12N, R8E, UM 3G-10 #U630610 At total depth 9. Approximate spud date Amount 2171' FSL, 2039' FWL, Sec 13, T12N, R8E, UM 07-12-90 $200,000 .12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 3G-09 and 3G-11 8213' MD 3109' @ TD feet 25' at surface feet 2560 6162' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 400 feet Maximum hole angle 45° Maximum surface 1800 psi9 At total depth (TVD) 5900' 3200 psig 18. Casing program Setting Depth size Specification Top B~ttom ,, Quantity of cement Hole Casing Weight Grade Coupling Length IVD TVD' IVD TVD (include stage dataI 24 1 6" 62.5# H-40 Weld 80' 35' 35' 1 15' 1 15' :b?.00 Cu. Ft. 12.25 9.625 36.0# J-55 BTC 3667' 35' 35' 3702 3010 1400 Cu. Ft. AS ill & HF-ERW 600 Cu. Ft. Class G 8.5 7" 26.0# J-55 BTC 81 78' 35' 35' 821 3' 61 62 215Cu. Ft. ClassG HF-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor ISn~de raC;ediate RECEIVED Production Liner 'JUL 1 o 1990 Perforation depth: measured ~,, true vertical~.OW & ~ Ce~.'~malsslon 20. Attachments Filing fee__ Property plat -- BOP Sketch ~ Diverter Sketch ~ Drilling pr(~g~m~ll~r~ Drilling fluid program ~ Time vs depth plot __ Refraction analysis _ Seabed report _20 AAC 25.050 requirements 21. I hereby cert~hat the foregoing is true and correct to the best of my knowledge /)' Signed ~C~ ~ Title Area Drillincj En~]ineer Date Commission Use Only Permit Number APl number Approval dat~ See cover letter for em- 8q 50- 103 ' ~o1~1./ 7/11/90 other recluirements Conditions of aPl~roval Samples required __Yes ~ N o Mud log required __ Ye s ~ N o Hydrogen sulfide measures __ Yes ~ N o Directional survey required ~ Yes __ N o Required working{~,o~ __J~OM; __15M Other: by order of Approved by ~ ~ · ~ , ~ ' &"/'~9/'~,"~/'~" Commissioner the commission Date Form 10-401 Rev. 7-24-89 mit in triplicate DRILLING FLUID PROGRAM (3G-10) Spud to 9-5/8" Drill out to surface casino weioht uo Density 8.6-10.0 8.6-9.3 PV 15-35 5-15 YP 15-35 5-8 Viscosity 50-100' 30-40 Initial Gel 5-15 2-4 10 Minute Gel 15-40 4 - 8 APl Filtrate 10-1 2 8- 10 pH 9- 10 8.5-9 % Solids 10 +/- 4-7 Weight up to TD 11.0 10-18 8-12 35-50 2-4 4-8 4-5 9.0-9.5 10-12 Drilling Fluid System: - Triple Tandem Shale Shaker - (2) Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual and Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: - Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. - Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 1880 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 3G-10 is 3G-09. As designed, the minimum distance between the two wells would be 25' at 1040' MD. The wells would diverge from that point. Excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shut down in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. * Spud mud should be adjusted to a funnel viscosity between 100-120 to drill gravel beds. HORIZON kL SCALE I IN. PROJEOTION ' 1000 FEET ARCO ALASKA, !ne, Pad :~Q. Well No, 10 Proposed Kuperuk Field, North Slope, Alaska $000 4000 WEST-EAST 1 000 0 1 000 2000 I I TD LOCAT I ON' 2171' FSL, 2039' FWL b"EC. 13. TI2N. RBE z 5000 2000 TARGET GENTER TVD-5929 TMD-Z880 DEP-4837 NORTH 4488 EAST 181:75 TARGET L()CAT ION, 1950' FSL, I t~---~' FWL SEC. 13, TI2N, RSE 1 000 SURFACE: LO, AT [ ON, 2538' FNL, 145' FWL b"EO. 24. T! 2N. RSE 1 000 N 21 DEG 55 HIN E 4837' (TO TARGET) Pad ~0, Well No~ 10 Proposed Kuparuk F,eld. North Slope. Alaeka 0 . RI(lB ELEVATION' 90' 1000 _ 2000 - 3000_ 4000_ 5000 _ 6000 _ ZOO0 KOP TVD=400 TMD=400 DEP=O g BUILD 3 DEO 15 PER ti)OFT 21 a9 B/ PERMAFROST TVD=1605 T~D=I?04 DEP=428 45 EOC TVD=1766 T~D=1923 DEP=S75 T/ UGNU SNDS TVD=1800 T~D=197! DEP=610 T/ W SAK SNDS TVD=2360 TMD=2772 DEP=1183; B/ W SAK SNDS TVD=2810 TMD=3416 DEP=I644 g 5/8' CSO PT TVD=3010 TMD=3702 DEP=1849 K-lO TVD=3340 THD=41T5 DEP=2187 AVERAGE ANGLE 45 DE(; 41 HI N K-5 TVD=4910 TMD=6422 DEP=3794 T/ ZONE C TVD=5835 TMD=7746 DEP=4741 T/ ZONE A TVD=5926 TMD=T876 DEP=4834 TARGET ONTR TVD=5929 THD=TB80 DEP=48~7 B/ KUP SNDS TVD=6022 THD=8013 DEP=493~ TD (LOG PT) TVD=6162 THD=8213 DEP=5076 ! 000 2000 3000 4000 VERTICAL SECTION I 5000 I 6000 200 ~- 150 _ ( 100 - 5O 0 100 _ 1 O0 50 0 50 ~ i I I 100 ,I , / / 200 / , / ~ / / / '~ ~oo~ / / ~lBO0 / / / 400 ~' 400 ' ~00' 600 ~ oo / / / 150 I / / "2000 / / / / / / 400 / ! 200 uu '~200 60O '~400 800 1600 0 $0 200 I / / / / / / 1600 250 / *" 1800 / / / o00 200 ,00 ii i i m ii Il .J I ~ mj ~mmm m 300 I 1 O0 1 50 200 250 3;00 200 .150 .100 .50 .0 .50 100 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD 3G PAD . . . = Si . , SI . 10. 11. 12. 13. 14. 15. 16, 17. 18. 19. 20. Move in and rig up Doyon 14. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. Run and cement 9-5/8" casing. Install and test BOPE. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test. Drill 8-1/2" hole to logging point according to directional plan. Run open hole evaluation logs or RLL as needed. Run and cement 7" casing. (Isolation of the Colville sands will be performed if there is hydrocarbon presence.) Pressure test to 3500 psi. ND BOPE and install temporary production tree. Secure well and release rig. Run cased hole cement evaluation and gyro logs Move in and rig up Nordic #1. Install and test BOPE. Perforate and run completion assembly, set and test packer. ND BOPE and install production tree. Change over to diesel Shut in and secure well. Clean location and release rig. Fracture stimulate well. 21. Reperforate and add additional perfs. 7 , 6 5 4 I 13 5/8" 5000 F...i BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TESTALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTORAND MANUAL KILLAND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMSAND CLOSE BO'I-rOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JTAND PULL OUTOF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMSAND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR SRE 8/22/89 DOYON 14 KdPARUK RIVER UNI'~ 20" DIVERTER SCHEMATIC 5 HCR \ 6 4 3 DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES MAINTENAN(~E ~ OPERATION . . UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. ARCO ALASKA, INC., REQUEST S APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(B) 1. 16"CONDUCTOR 2. SLIP-ON WELD STARTING HEAD 3. FMC DIVERTER ASSEMBLY WITH TWO 2-1/16"- 2000 PSI BALL VALVES 4. 20" - 2000 PSI DRILLING SPOOL WITH TWO 10" OUTLETS. 5. 10" HCR BALL VALVES WITH 10" DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. VALVES CAN BE REMOTELY CONTROLLED TO ACHIEVE DOWNWIND DIVERSION 6. 20" - 2000 PSI ANNULAR PREVENTER SRE 2/6/90 (1) CHECK LIST FOR NEW WELL PEI~ITS Company ~ ~ /),~4~.~. Lease & Well No. IT~M APPROVE DATE YES NO .......................................... -- ~ ~/~o 1. Is the pe~ fee attached Fee (2) Loc_ (2 thru 8) (8) (3) Admin .... ~ T/cA o 9. (9 thru13)' 10. (10 and 13) 12. 13. (4) cass (14 thru 22) (23 thru 28) 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 2. Is well to' be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is well located proper distance from other wells .................... 5. Is sufficient undedicated acreage available in this pool 6. Is well. to be deviated and is we!lbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. ~. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... ~ Does the well have a unique name and number ......................... ~ Is c6nductor string provided ...................................... Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement =ie in surface and intermediate or production strings ... Will cement cover ail known productive horizons ..................... Will ail casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an ezisting wellbore ............. Is old wel!bore abandonment procedure included on 10-403 ............ Is adequate weilbore separation proposed ............................ Is a diverter system required ....................................... Is the drilling fluid program schematic and list of equipment adequate Are necessary diagrm~ and descriptions of dive:reT and BOPE attached. Does BOPE have sufficient pressure rating - Test to ~OO~ psig .. Does the choke manifold compiy w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ............................. ~... (6) OTHER ~ ~//=/Fa (29 thru' 31) (6) Add: Geology: Engi~eerin~: rev: 01/30/89 6.011. For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential ore:pressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. INITIAL GEO. UNIT I ON/OFF POOL CLASS STATUS AREA NO. SHORE , i Additional Remarks: ',GG - lO ~/ Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special 'effort has been made to chronologically organize this category of information. COMPUTER DIRECT DIGITAL LOGGING PR.OCESSED ANALYSIS MICROFILMED LLLLLLLLL I.L..LLLLLLL IIIIIIIIII iliIIIIilI ii II ii II ii I1 ii Ii iiiiiiiili IIIIIIIIII D[:DDDDDDD UU UU DDDDDDDDDD UU UU DD DD UU UU DD DD UU UU DD DD UU UU DD DD UU UU DD DD UU UU DD DD UU UU DD DD UU UU DD DD UU UU DDuDDDDDDD UUUUUUUUUUUU DDDDDDDDD UUUUUUUUUU I'11"1 I'1 I't H H H H H H l',i H H H H H H H HH HH HI"I NH J'1 J'l J"l H N J'J J"J I"i H 1'4 M M H H H H H hi H H H H H H H H H H H H HH HH H i',1 i"i H PPPPPPPPPPP PPPPPPPPPPP PP P PP P PP P PPPPPPPPPPP PPPPPPPPPPP PP PP PP PP PP ii iiii 11 1i ii ii li il ii iliiiiii 11i11111 O0 O0 O0 O0 O0 O0 O0 00 ii iii ilil ii ii ii ii ii ii ii iilllillii ilillliiil 00000000 0000000000 O0 O0 O0 O0 O0 O0 O0 O0 0000000000 00000000 AA AA AA AA AA AA AA AA AAAAAAAAAAAA AAAAAAAAAAAA AA AA AA AA AA AA AA AA 444 4444 44 44 44 44 44 44 44444444444 444444444444 44 44 44 44 44 UU UU UU UU UU UU UU UU UU UU UU UU UU UU UU UU UU ULi UU UU UUUUUUUUUUUU UUUUUUUUUU 88 88 88 88 88 88 88888~ 88 88 88 88 88 88 888888888888 8888888888 GGGGGGGGGG GGGGGGGGGGGG GG GG GG GG GG GG GGGGG GG GGGGG GG GG GGGGGGGGGGGG PPPPPPPPPPP PPPPPPPPPPPP PP PP PP PP PP PP PPPPPPPPPPP.P PPPPPPPPPPPP PP PP PP PP PP 9999999999 999999999999 99 99 99 99 99 99 999999999999 999999999999 99 99 99 99 999999999999 9999999999 NH M HHH NH HHHH HHH HH MM HH H HH HHHH H MN NH H MH H H H H 00000000 0000000000 O0 0 O0 0 O0 '0 O0 0 O0 0 O0 0 O0 0 O0 0 0000000000 00000000 '~crvice name_: &GSFOi Date: 90708710 Comments: HEADER Origin: RECORDS Reel name: 367708 Page Continuation #: Ol TAPE HEADER **** ger.',/ice name: &GSF01 Previous .tape: Date: 90208710 Comment=' Origin: Tape name: 367708 Continuation #: O1 :** FILE HEADER **** : :+: :+: .,~ :~. :+: :~. :{~ ~:~ .~* .~* ~:~ ~:~ ~ Film name: .001 Version #: Date: Haximum length: '1024 File type: LO Previous ~ile: I NFORMAT I ON 'RECORDS Page blt,t Ei'I CONTENTS UNIT TYPE CATG SIZE CODE ERROR t.IH FH C 0 U H :STAT AP iH L n T i l.. 0 H rs SECT T 0 l.d H P, AHG Et<B EDF E'3L PD L. HF D I'1F R Li H T I H E DATE LCC SON L I.j f,l Fl.. L. UL EHG i kl I T H DD CBD i C:Bl,. 1 TL.i I TL. AB BH T i"i I::~ 1' HT M '.3 S D F D H'"', i S DF'PH DFL RH P..HF F:H C: ARCO ALASKA INC. ~G-i 0 KtJPRRL I,, RIVER HORTH SLOF'E ALASKA USA 20i34,000 ....................... 0 Deg. 0 H in, 0 0 Sec. H 0 Drag. 0 Piin, 0 0 Sec, tJ 24. 12N ........... 08E ........... 90. OO'O ........ 89.0 O0 ....... 54,000 ....... MS ........... I<B .... . ........... KB ............. i · i i I i I i i I i · * 635,000 ......... 5/ 8/9 0 ......... ~67;?Uo"?' 51939 NORTH SLOPE NORTH SLOPE M c K A Y L 0 W E td 8250, OOO ............ u~50. 000 ........... 3783 000 ~ m I t * m m m I m i I 3790,000 ........ 3790. 000 ....... 8241 , 000 ........ ~ OOO b3,. 000 i58,000 ........ 158,000 ........ LSND CIRCULATED i 0,80'0 ........... 40,000 ........... R ~00 .. 6,200 I ,840 ............ i ,9i0 ............ 7'2 000 MEAS ...... 3,2(!0 ............ AP1 Ntlbl: 50-i0~-20i34 ................ DATE LOGGED: 08-0:,-~u ................ IlIl~lIIIIll;lIIIIIIlIlIIIIlllIIIIlI IIllllIIlllItlllll'IlIIIIlIIllll'~II IIl,lIIlIIllllllIIllllllIlIllIIII#lI ImllllmlImll m IllIllIlllll IIlIlIIl,,II I&llmIalll#lllI IfIIlamm tIllm lllllllI IlIII tlllll,l IlIlll tlllllI* el}ll Illlll IIIIIIlI itlllllllllllll iIIIill lliIIll IIlllll IIll III . I m m i , iiii , , · m , , · I I · m , m , , I i iii m m m m m · mm |Ilii,ii , mil i I I III I I III III Illl II1¢111 IIIlItI lllllll I , , m i , , , i · · 0 0 40 65 O O 40 65 0 O 4 O 65 0 0 20 65 O 0 20 65 0 O 20 65 O O 4 68 O '0 34 65 0 0 34 65 0 0 2 65 0 0 ~ 65 0 0 ~ 65 FT 0 J 4 68 FT .O 3 4 68 FT O 3 4 68 0 3 2 65 o 3 2 65 o 3 2 65 0 0 2 79 0 0 4 68 0 0 8 65 0 O 2 .79 0 0 i 0 65 0 o 10 65 0 0 2 0 65 0 O 20 65 0 0 20 65 0 0 20 65 FT 0 3 4 68 FT 0 ;3 4 68 FT 0 3 4 68 FT 0 3 4 68 FT O 3 4 68 FT 0 3 4 68 HR 0 2 4 68 HR 0 4 4 68 DEGF 0 I 4 68 DEGF 0 I 4 68 0 2 20 65 0 2 20 65 LB/G 0 2 4 68 CP 0 2 4 68 0 2 4 68 0 2 4 68 OHI'IM 0 2 4 68 OHHM 0 2 4 68 DEGF o 2 4 68 O 2 12 65 OHMH 0 2 4 68 i'i i'.i E t't i'iCST CS BS I NFORMAT I ON RECORDS CONTENTS UNIT 6~ 00:0 I IIIlIllIllIIIllIIIIllIlIIlIlIIlllIIlIIIlllllIIIlII MEAS ............................................. ,~0 ................................................... 8,500 ................................................... DEGF TYPE CATG SIZE 4 i2 4 CODE 68 65 68 ERROR i~mll Location Comment 1: Well Location Commmnt 2: &tmil Location Commmnt 3: i.~imll Location Commmnt himil File Comment 1: t~ell File Comment 2: i,lcll File Commmnt 3: tf~ll Film Comment 4: COMMENT RECORDS SURFACE: 2538' FNL & 145' FWL 4~ CHLORIDES = 1100 PPH. HRI,ML,SDL?DSN RUN IN COMBINATION. DATA PRESENTED USING CONDUCTIVITY X COMPONENT' OFFSET VALUES .OF: (-32.0 MMHOS FOR DEEP X) & (2.0 MHHOS FOR MEDIUM X) THIS TAPE CONTAINS KUPARUK DISTRIBUTION DATA ONLY. LIS tape written bp: ANCHORAGE COMPUTING CENTER All c,-~pve and tool mnemonics used are t.hozm which Halliburton curve and tool mnmmonicz. most closel~ match HALLIBURTON TO SCHLUMBERGER TOP BOTTOM MNEM SERVICE UNIT DEPTH MNEM SERVICE UNIT DEPTH DEPTH FT DEPT FT 180.00 GR SDL GAPI GR SD[. GAPI 3750,0'0 FDSN DSN2 CPS FDSN DSM2 CPS 3750.00 NDSN DSN2 CPS HDSN DSN2 CPS 3750, O0 ttPHI DSN2 DECP NPHI DSM2 DECP ~750, O0 NRAT DSN2 C/C NEAT DSN2 C/C 3750. O0 OPE SDL OPE SOL 3750.00 DPHI SOL DECP DPHI ~[L DECP 3750,00 DRHO SDL G?C3 DRHO SDL G,./C3 3750, O0 FSDL SDL CPS FSDL SDL CPS 3750,00 828 0.00 440'I 4401 O0 44 0 '1 ,00 44 01 O0 44'01 O0 4401 00 44'01 00 440'1 O0 4401 O0 Page N S D L PE ' PELC QL. -- - L:~ PE RHOB C:AL. ! M N 0 P,, HDR H D .X H t'I X HDRS HHRS H D C N HMCN DFL SP TENS SDL SDL SDL SDL SDL SDL SDL SDL ML ML HRI HRI HRI NRI HRI HRI HRI HRI NRI HRI SDL CPS 6/03 IN Oi-IMl'! OHMM OHMH OHMH HHHO MHHO OHHM MV LBS NSDL PE PELC QL QPE RHO8 CALl M I N V MNOR HDR HDX HMR HMX H[R~ HMRS HDCN HMCN DFL SP TENS SDL SDL SDL SDL S DL SDL SDL SDL ML ML HRI HRI HRI HRI HRI HRI HRI HRI HRI HRI SDL CPS G/C3 OHHH OHMM OHHH OHHH HHHO HHHO OHMH HV LBS 375 375 375 375 375 375 375 375 375 375 375 375 375 375 3?5 375 375 3?5 375 375 375 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0 O0 0,00 0..00 0,00 0,00 O, 0.0 0.00 O. O0 0,00 0,00 0,00 O. O0 0.00 O, .0'0 O, :0.0 440'1 . O0 4401, O0 44 O1. O0 4401 O0 4401 O0 4401 O0 44 01 O0 4401 4401 O0 4401 O0 4401. O0 4401. O0 4401 4401..00 4401 , O0 4401 , O0 4401. O0 4401 , '00 4401. O0 4401 , O0 4 4 0 '1 . 0 0 COMMEN T RECORDS P~g¢ DLOD SDL LBS DLOD SDL LBS ~750. O0 4401 ENTRY BLOCKS DATA EHTRY FORMA oPEC I F I CAT I TYPE SIZE [:ODE 16 1 66 0 1 66 P~g~ ::~:~ EHTRY 8LOCK LEGEND TYPE DESCRIPTION Datum zpeci{'ication block' sub-.t!~p~ Terminator <no- mopa ~ntpi~z ) ~ DATA FORMAT :** DATUH SPECIFICATION BLOCKS SPECIFICA TIONS Pag~ SERVICE SERVICE AP1 AF'I r,iHEM iD ORDER ~ UNIT LOg TYPE AP1 AP1 FILE CLASS MOD ~ PRC # ~iz~ LVL SMPL RC PROC~s~ iNDiCATORS £:'E PT 3677 08 FT 0 0 GR SDL 367708 t~At"' l 94 0 FDSH DSH2 3677 08 CPS .94 0 tlhSH DSN2 ~67708 CPS 94 0 HF'Hi DSN2 367708 DECP 94 0 NRAT DSN2 ~G77.08 C/'C 94 O DPE SDL ~67708 94 O [:,PHI SDL ~67708 DECP 94 0 [>RHO SD'L ~67708 C,,.~' C 394 0 FSDL SDL ~67708 CPS 94 ~ NSDL SDL ~67708 CPS 94 O PE SDL ~67708 94 0 t"'b LU SDL 367?08 94 0 t.~l. SDL ~67708 94 0 ~]S SDL ~G77.08 94 0 OPE SDL ~67708 94 0 RHOB SDL 367708 6?CJ 94 O CALi SDL 3677 08 iN 94 0 MiNV ML 367708 OHMM 94 0 HIqOR Ill. 3677 08 014 !'4~ 94 0 1'4D F~ HR i 3677 08 94 O H [:, "",-., HRI 367708 94 0 HHR HRI 367708 94 0 Hi'IX HRI 367708 94 0 HDRS HRI 367708 OHMM 94 0 I.-tM RS HR I 3677 08 OHMM 94 'O HD CN HR I 367708 MMHO 94 '0 HMCH HRI 367708 MMHO 94 0 [)FL. HR ! 367708 OHMbl '.:)4 8 SF' HR I 3677.08 MV 94 0 TEHS SDL 367708 LBS 94 0 Di..OD SDL 3677.08 LBS 94 O 0 0 1 0 ~ 0 0 ~ 0 0 $ 0 O ~ 0 0 1 0 0 1 0 0 1 0 0 ! 0 0 1 0 0 1 0 0 1 0 0 i 0 0 I 0 0 ! 0 0 1 0 0 i 0 0 ~ 0 0 1 0 0 '1 O' 0 i O 0 i 0 0 i 0 0 i 0 0 i 0 0 i 0 0 i 0 0 i 0 0 i 0 0 i 0 0 i 0 0 'l 0 4 O 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 0 4 4 4 4 0 4 0 4 0 4 0 4 0 4 0 4 O 4 0 4 0 4 4 0 68 68 68 68 68 68 68 6,8 6,8 68 68 68 68 68 6,8 68 68 68 68 68 68 68 68 68 68 68 68 68 ,68 ~8 68 000000 000000 000000 000000 O00000 O00OO0 000000 O000OO 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 O00OO0 000000 000000 OOOO00 000000 000000 000000 000000 000000 000000 000000 000000 OOOO00 000000 000000 OOOOOO OOOOOO 000000 000000 000000 000000 000000 000000 000000 O00OO0 000000 000000 000000 000000 0000.00 000000 000.000 000000 000000 000000 000000 000000 000000 000000 000000 O00OO0 000000 000000 0'00000 000000 000000 000.000 000000 000000 OOO000 OOOO00 O00OO0 OOOOO0000000 000000 000000 000000 000000 OOOO00 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 DEPT DRHO RH08 HDRS GR FSDL CALl HMRS FDSN NSDL HiNV NDCN DATA N D S N MNOR H H C N RECORDS NPHI PELC HDR DFL NRAT HDX SP DPE QS HMR TENS DPHI QPE HI'IX DLOD ,';40i. 000 .0i5 2. 373 4. 446 4400.000 .015 2.373 4.438 4300.008 .028 2.i95 3.2i7 4200.000 .034 2,184 5.083 4i00.000 .039 2.148 4,208 4 000.000 . 0,I8 2,205 6.011 3900.000 ,059 2.234 5,759 3800.000 ,059 2.i99 ~,aI5 111.651 7086,439 10.053 3.892 I 06,827 7086.439 10.050 3.897 102.430 9795,328 9,874 2.772 100.938 i0098.2i7 10.i59 4,343 97,873 10909.994 10,795 3,584 11 O, 073 9969,217 10,531 5.238 t 13. 534 9647,551 11,027 4,783 92.147 10269,328 13,277 1,586 1659.6,48 1 6 038. 064 3. 078 224.905 1659.648 16038.064 3,078 225.335 1442,409 17198.066 2.479 310,8i9 1491.899 17359.336 2.673 196.739 1318.447 17669,883 1.719 237,642 1681,622 17482,793 3,213 166,352 1:564,508 17520.15~ 2,563 173,640 1409.1 O0 17714,609 2.344 301 ,626 14315,744 3.493 2.395 256.952 14315.744 3.493 2,395 256.588 13661,920 2.752 2.096 360.757 · 13799,355 2,649 2.606 230.258 13335,432 2,640 1,675 279.809 14364,885 2,937 3,105 i90.92i 14046.516 3.401 2.706, 209. 072 · 13369. 572 3,3.03 2. 806 630.714 .409 3.682 190.369 3.463 .409 3. 682 189.344 3.505 .466 3. 093 227.919 2.426 .448 2,826 163.768 3.695 .494 2.660 201 .648 2. 925 ,404 3. 036 149.628 4,70~ ,425 3.613 150.33t 4,296 ,438 3.744 129.1i2 5,293 9.262 ,0i5 33,176 329.581 9.262 ,015 33.676 329.82i 10,170 -.0i6 44,652 336.045 9.931 -,046 22.340 354.880 10,860 -.036 36,459 357,535 9,172 ,.037 20,375 366,037 9,640 -,~313 23,435 362,230 '1 0,188 -,001 15.262 363,263 0.000 -,009 239,343 2954,876 0.000 -. 009 239.395 29i i. 208 O. 000 -, 008 305,259 2896.652 0,000 -,011 206.660 275i,091 O.O00 -,0'07 266,693 2765,647 O,OOO ,008 180,879 2634.643 0.000 -,04.0 189,585 2765,647 O, 000 ,009 161 ,362 2765,647 .168 -1 ,000 19.818 1 055,48 0 ,168 -1,000 19.458 1030.548 .276 -i,O00 3i,514 1130.278 ,282 -1,000 11,597 1101.190 ,304 -1.000 17,883 1'142.744 ,270 -1.000 10,324 1043,014 ,252 -1,00'0 24.057 1038.858 ,273 -1 ,000 6,962 I 121. 968 DEPT DRHO RHOB HDR$ GR FSDL CALl HNRS FDSN NSDL MINV HDCN DATA NDSN PE MHOR H bi C RECORDS HPH I PELC HDR DFL NRAT QL HD X SP DPE . -- HHR TENS DPHI QPE HMX DLOD Page ~ :~:~ FILE TRAILER Fil~ name: &GSFO! , OO1 M.a x i m u m 1 e r, g t h: 1 '8 ~ 4 TRAILER RECORDS Servic~ nam~I Vmrsion ~: File type: LO Na×t ~ile: Date: Page 10 S~rvice name: &G5F01 Next remi: TAPE TRAILER Smrvice name: &GSF01 N m >.'t tape Date: 90/08/I0 Comments: Date: 90708710 Comments: Origin: Origin: Tape name: 367708 Continuation Continuation #: 01 #: 01 [~IRECT IG.ITAL LO'GOING CO MPUTER PROCESSED ANALYSIS MICROFILMED Date . i? i_LLi_LLLLL L.L. 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Ii II II Ii ii II Ii . -- iiiiiiliii IIiiiiIIii SSSSSSSS SS'~"SSSSSSoo SS SSSSSSSSS oSS~SSS DDDDDDDDD UU UU DDDDDDDDDD UU ULi DD DD UU UU DD DD UU UU DD DD UU UU D D D D U U U U DO DD UU UU DD DD UU UU DD DD UU UU DD DD UU UU DDDDDDDDDD UUUUUUUUUUUU DD[~DD[~DDD UUUUUUUUUU MI'I MM iiHH MMM NMHH MMMM MM MH HM HH MH MMMM HH MM MM MH HM HH NH HM HH HH MM Mi'l MM HH MPI HH PPPPPPPPPPP PPPPPPPPPPP PP F' PP P PP PPPPPPPPPPP PPPP~FP~r PP PP PP PP PP ii itii ii ii ii ii ii ii ii ilil liil ii iii i$ii lI ii ii ii ii il iI iiil tiii iiii ilii illi iiii 22.22222222 222222222222 22 22 22 22 22 22 22 22 22 222222222222 222222222222 OOOOOOO0 0000000000 O0 O0 0.0 O0 O0 O0 O0 .00 O0 O0 O0 O0 O0 O0 O0 O0 0000000000 00000000 AA AAAA A'A AA AA AA AA AA AA AA AAAAAAAAAAAA AAAAAAAAAAAA AA AA AA AA AA AA AA AA 555555555555 555555555555 55 55 55 555555555 5555555555 55 55 55 555555555555 55555555555 tJU UU UIJ UU UU UU UU UU UU UU UU UU UU UU UU UU UU UU UU UU UUUUUUUUUUUU UUUUUUUUUU 9999999999 999999999999 99 99 99 99 99 99 999999999999 999999999999 99 99 99 99 999999999999 9999999999 GGGGGGGGGG GG GGGGG GG GGGGG GGGGGGGGGGGG GGGGGGGGGG I m · PPPPPPPPPPP PPPPPPPPPPPP PP PP PP PP PP PP PPPPPPPPPPP. P PPPPPPPPPPPP PP PP PP PP PP 9999999999 999999999999 99 99 99 99 99 99 999999999999 999999999999 99 99 99 99 999999999999 9999999999 MM I,i HMM NH HMMM HI'IH HM tin HH H NH HHMH M MM MM H NM H NH H HH H HH H HH H ~0000000 0000000000 O0 0 O0 0 O0 .0 O0 0 O0 0 O0 0 O0 0 O0 0 0000000000 00000000 REEL HEADER *-*:~* S~irvicm name: &GSF01 HEADER Date: 9 0/'08:' I 0 Origin: Commmnt~._.: RECORDS Re~i name: ~67708 Pag~ Continuation #: 01 Service r',amm: &GSFO1 Pr e;.,' i OLl~ t:.ap,D ,' Date: 90,-'08:'10 Origin Commentz: Tape name: ~677.08 Continuation #: Ol File name: , 001 Verzion #: Date: Haximum length: 1024 Film t~pe: LO Previous ¢ilm: I NFORMAT ! ON RECORDS Page iiIIEH CONTENTS UNIT TYPE CATG SIZE CODE ERROR CN {Ji-i Fi.i COUN STAT Ci'RY APiN LATi I..OHG SECT TObJN RANG EKB EDF EGL PD LHF D H F R U N T iHE DATE LCC SON LUN FL L, LIL W I l N DD DL CBDi CBL1 TLi ~i_I TCS TLAB BHT MR T HT HSS DFD i'i" iS DFPH D F L RH RI'IF HFST HFSS RMC ARCO ALASKA INC, ~G-iO APl NUM: KUPARUK RIVER [)ATE LOGGED NORTH SLOPE USA ......... 20i34.000 .................... 0 Deq, 0 Him, 0 0 Sec 0 DeG. 0 Hin. 0 0 Sec t2N ........... 0SE ........... 9,0. 000 ....... 89. 000 ....... 54,000 ....... MS .......... GS5,000 .... 52 8/90 .... ~67708 . 55939 .i NORTH SLOPE NORTH SLOPE HcKAY LOWEN 8250.000 ......... 8250.000 ......... 3?83.000 ......... 3790.000 ......... 3790.000 ......... 8241.000 ......... 5.000 ............ 635.000 .......... 158,000 .......... 158,000 .......... LSND CIRCULATED 10.800 ........ 40.00'0 ........ 8,500 ......... 6,200 ......... i.840 ......... 1,9i0 ......... 72.000 ........ HERS ....... 3,200 ............. III I elIi I , N 50-i 03-20i 34 ............... 08-05-'.-30 .............. . · Illl I , . . ' a I , I ma. Ii. ..m mai mill . . &Illllll 1 ,, . ,t I I I . ' m 0 0 40 65 0 0 40 65 0 0 40 65 0 0 20 65 0 0 20 65 0 0 20 65 0 0 4 68 0 0 34 65 0 O 34 65 0 '0 2 65 0 0 3 65 0 0 3 65 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 0 3 2 65 0 3 2 65 0 3 2 65 0 0 2 79 0 O 4 68 O 0 8 65 0 0 2 .79 0 0 10 65 0 0 iO 65 0 0 '~ ~0 65 0 0 20 65 0 .0 20 65 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 FT 0 3 4 68 HR 0 2 4 68 HR 0 4 4 68 DEGF 0 I 4 68 DEGF O i. 4 68 0 2 20 65 lO 2 20 65 LB,;G 0 2 4 68 CP 0 2 4 68 0 2 4 68 0 2 4 68 OHMM 0 2 4 68 OI-thlH 0 2 4 68 DEGF 0 2 4 68 O 2 12 65 OHMM 0 2 4 68 H i'-i E M INFORMATION RECORDS CONTENTS UNIT 63.000 .................................................. MEAS ............................................. 9,625 ................................................... 0.500 ................................................... DEGF TYPE CATG SIZE 4 12 4 4 CODE 68 65 Page ERROR COMMENT RECORDS iJcll Location Comment 1: SURFACE: ~,lcil Location Comment 2: (,i~il Location Comment 3: (,.Imll Location Comment 4: i~lmll File Comment i; CHLORIDES = i,t~ll File Commmnt 2: i.,~mll Film Comment 3: 2538' FNL & 145' FWL 1100 PPM. HRI,ML,SDL/DSN DATA PRESENTED USING CONDUCTIVITY X OF: (-32.0 MMHOS FOR DEEP X) & (2.0 RUN IN COMBINATION. COMPONENT OFFSET VALUES MMHOS FOR MEDIUM X) &;,~ll File Comment 4: THIS TAPE CONTAINS KUPARUK DISTRIBUTION DATA ONLY. LIS tape written by: ANCHORAGE COMPUTING CENTER ~:~ All curve and tool mnemonic~ u~ed are those which most closel~ match ~m Halliburton curve and tool mnmmonics, m:~ HALLIBURTON TO SCHLUMBERGER TOP BOTTOM MNEM SERVICE UNIT MNEM SERVICE UNIT DEPTH FT DEPT FT GE SDL GAPI GR SDL GAPI FDSN DSN2 CPS FDSN DSN2 CPS HDSN DSN2 CPS NDSN DSN2 CPS HPHI DSN2 DECP NPHI DSN2 DECP NRAT DSH2 C/C NEAT DSN2 C/C DPE SDL DPE SOL [)PHI SDL DECP DPHI SDL DECP DRHO SDL G/C3 DRHO SDL G?C3 FSDt. SDL CPS FSDL SDL CPS DEPTH 180,00 194 75 t94 75 t94 75 194 75 194 75 194 75 194 75 194 75 194 75 DEPTH 8280,00 8275.00 8275,00 8275.'00 8275.00 8275.80 8275,00 8275.00 8275,00 8275.00 Pagm N S D L PE PELC QL -- -- LJ ',_4 QP E RHOB CNL I M I NV M N 0 R HDR HD ~.( HMR HMX HDR~ HI'IRS H D C N H H C N DFL SP TEN~, SDL. SDL SDL SDL SDL '"o DL SDL SDL HL ML HRI HRI HRI HRI HRI HRI HRI HRI HRI HRI SDL CPS IN OHHM OHMM OHMM OHMH MHHO HHHO OHMH MV LBS NSDL PE PELC QL QS QPE RHOB CALl HINV HNOR HDR HDX HMR HMX HDRS HHRS HDCN HMCN DFL SP TENS SDL SDL SDL SOL SDL SDL SDL SDL ML ML HRI HRI HRI HRI HRI HRI HRI HRI HRI HRI SDL CPS G,-"C3 1 I''1 OHMM OHMM OHMM OHMM MMHO MMHO OHMM MY LBS 194 75 194 75 i94 75 194 75 194 75 194 75 194 75 194 75 194 75 194 75 194 75 194 75 194 75 194 75 194.75 194,75 i94,75 194,75 194,75 194,75 194.75 8275 O0 8275 O0 8275 O0 8275 00 8275 O0 8275 00 8275.00 8275,80 8275.88 8275.00 8275.8~ 8275.00 8275.00 8275,08 8275.00 8275,00 8275,08 8275,0~ 8275,00 8275,00 8275,80 COMMEN T RECORDS Page DI_OD SDL LBS DLOD SDL LBS 1~4.75 8~75.00 E ~-i T R Y DATA FORMA T._,°PEC I F I CA T IONS TYPE SIZE CODE Page 16 1 66 0 1 66 ~-::~::~: Ei-iTRY BLOCK LEGEND TYPE DESCRIPTION i6 Datum specification block sub-t~p~ 0 Terminator ( no more mntrims ) ATA FORMAT SPEC l F I C. AT IONS Pag~ SERVICE SERVICE iD ORDER # UNIT LOG API API API FILE TVPE CLASS blOD PRC # SIZE LVL SMPL RC PROCESS INDICATORS DEPT F[.,SN t.I [> S N HPH i DP E DPH i D P.'. H 0 F S [) L i'i S D L i:'E PEL. C t.';:!i... O. PE AH08 C~AI. i M ~ N V M H 0 R it D R H D ;4 H M R HMX I..tDRS H M R S I-.,i D C J,I H M [: t9 DEL SP TENS DLOD 367709 SDL 367708 DSN2 3677 08 DSN2 3677 08 DSN2 3677 08 DSN2 3677 08 ~L L 3677 08 SDL 3677 08 SDL ~G~7 O0 SDL 3677 08 oLL 36~708 DL ~o,, 08 SDL 367708 SDL SDL 367708 ~'DLo 3677 08 SDL 3677 08 SDL 367708 M L ~ ' '~ '~ d~,'., 08 ML ~677'08 HRi 367708 HRI 367708 HEI 367708 HEI 367708 HRi 367708 HRI 367708 HRi 36770~ HR I 3677 08 HR~ ~67788 HRI 367708 SDL 367708 SDL 367708 FT GAPi CPS CPS DECP CdC DECP G/CS CPS CPS IN OHMM OHMM OHMM OHMM MMHO MMHO OHMM MV LBS LBS 0 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 94 0 0 O ~ 0 0 1 0 0 0 1 0 0 0 1 0 0 0 1 0 0 0 1 0 0 0 ! 0 0 0 1 0 0 0 1 0 0 0 1 0 0 0 i 0 0 0 1 0 0 0 i 0 0 0 i 0 0 0 i 0 0 0 'i 0 0 0 i 0 0 0 'i 0 0 0 'I 0 0 0 1 0 0 0 i 0 0 0 i 0 0 0 '1 0 0 0 1 0 0 0 1 0 0 0 J 0 0 0 'i 0 0 0 I 0 0 0 i 0 0 0 : ! 0 0 0 i 0 0 0 I 0 4 0 I 68 4 0 i 6,8 4 0 1 68 4 0 1 68 4 0 I 68 4 0 I 68 4 0 I 68 4 0 1 6,8 4 0 I 68 4 0 1 6,8 4 0 1 68 4 0 i 68 4 0 I 68 4 0 1 68 4 0 1 68 4 O 1 68 4 0 1 68 4 0 1 68 4 0 i 6.8 4 0 1 68 4 0 1 G8 4 0 1 68 4 0 1 68 4 0 1 68 4 0 t 68 4 0 I 68 4 0 1 68 4 0 I 68 4 0 1 68 4 O I 68 4 0 1 68 4 0 1 68 000000 O0000O 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 00000'0 000000 0000.00 000000 000000 000000 000000 000000 000000 000000 .000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000.000 000000 000000 000000 000000 000000 000000'000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 DF. PT D P, H 0 RHOB H D R S GR FSDL CALI HHRS FDSN NSDL HINV HDCN D'A NDSN PE MNOR H H C N TA RECORDS NPH I PELC HDR DFI_ NRAT QL HDX SP DPE -- -- HMR TENS DPHI QPE HMX DLOD Page :3275.000 ,053 2,458 i2:345.000 C~200.000 .020 2,479 3,575 8iOO.OOO .029 2.438 J,b~6 SO00. '000 ,03i 2,38.3 7,982 7900,000 2,264 21.39i 7300. 000 ,030 2,505 i 34,070 7700,000 ,032 2.346 i,982 7600.000 ,040 2,398 2,589 115.i58 6495,217 8.500 -i2345,000 98,883 5899,558 8,484 3.379 i02,832 6440,550 8,622 3,460 88,204 7142,772 8,834 7,620 66,080 8857,217 8,,588 i9,93i 49,132 5806,217 8,946 i.82,358 123,750 764i,994 9,301 i,757 118,421 7095.2i7 $2,392 2,375 i982.424 i6i76.883 l,ii2 -i2345,000 2048,582 i5523,064 3.373 279.72i I994,814 i588i,246 3,i79 275,773 2505.444 i6202,520 7,003 i25,276 2743,367 16933,6'09 8,682 46,748 2656, i 82 156'04,70i 9,003 7,459 1386,792 i6449,973 i,652 504,659 1492,587 iG310,428 2,538 386,469 i5i38,201 3,333 i,464 -i2345,.000 15027,000 3,372 2.972 295.923 15206,764 3.062 2,573 288,982 165il,277 2,795 5,766 131,235 'i7296,555 2,449 i0.908 50.i74 i6836,820 4,347 i3.i62 5,484 13122.328 2,789 1 ,309 569. 184 13536.057 3,'i99 2,273 42i,i25 ,376 3,548 0,000 3. 765 ,360 3.915 225,952 3,392 ,372 3,390 222,996 3,362 ,314 3,ii2 113,i61 7,553 ,301 2,420 49,515 21,457 ,297 4,446 19.926 i82,506 ,470 2,952 356,082 i ,707 ,420 3,339 287,547 2.472 8,i99 -.048 O,OOO 123450000, 7,876 .0 04 43,040 343.476 8,185 ,005 43,114 351,469 7,076 -,040 lO,OSi 345.047 6,770 ,049 2,57i 299,584 6.806 ,835 -5,270 288,853 10,160 ,041 1 00,021 318.948 9,737 .010 69.627 325.t83 0,000 0,000 0,000 4788.937 0,000 -,OOi 272,0i9 5007,277 0,000 -.036 27i.052 4614.265 0,000 ,017 122,854 4323.144 0,000 -,054 43,540 4614,265 0.000 -,023 9,070 4497,8i6 0,00'0 ,025 468,457 4403,260 O, 000 ,008 366,625 4439,592 ,ii7 -i.O00 0,000 -20,778 ,103 -i,000 21,697 ii55.2ii ,i29 -i,O00 zu,oO5 I254,94i ,162 -I,000 5,889 1018.08i .234 -1 ,000 3.802 192.609 .088 -i ,000 -i ,700 i i 3 0,278 ,184 -1,000 52,i92 1259,097 ,153 -i,OOO 34.532 1i46,900 DEPT DRHO RHOB HDRS GR RSDL CALl HHRS FDSN NSDL MiNV HDCN DA N D S N MNOR H H C N TA RECORDS NPH I P E LC HDR DFL NRAT QL SP DPE -- -- HbiR DPHI QPE HHX DLOD Page 7'500. 000 · -, 005 4.265 7400. 000 ,022 ?300,000 -.999,250 -999,250 4.4i3 7200.000 --999,250 -999.250 5,124 7i00.000 -999,250 -999,250 2,757 7000.000 -.999,250 -999,250 4,556 6900,0.00 -999.250 -999,250 4,625 6800, 000 -999,250 -999,250 5. 020 257.685 6578,328 9.999 4,001 203. 0.732 7156,772 i0.270 4, 090 137,77 0 -999.250 i0,937 4, 037 '115,216 -999,250 '10.@~0 4,856 152,175 -999.250 10.536 2.390 i13,801 -999,250 10,152 4.i7i 1.06,687 -999,250 10,671 4,244 108.ii5 -999.250 i0.712 4.52i 1633.087 i554i,793 2,90i 234,461 1644,354 16139.609 3,179 227,390 -999,250 -999,250 3,078 226,618 -999,250 -999,250 ~, 070 i 95. i 78 -999,250 -999,250 3,078 362,674 -999,250 -999,250 3,078 2i9,5i3 -999,250 -999,250 3,078 216,23i -999,250 -999,250 3,078 i99,191 14077.95i 4.320 3,050 249. 937 i4039,885 3.345 2,806 244,488 -999,250 -99'9,250 2,395 247,714 -999,250 -999,250 2 ~ 205,933 -999,250 -999,250 2,395 418..465 -999,250 -999,250 2,395 239,757 -999,250 -999,250 2,395 235,629 -999,250 -.~9,250 2,395 2oj 204 ,414 4.460 202.260 4,234 .405 3.556 i87,264 ¢,276 -999,250 -999,250 i87,034 4,092 -999,250 -999,250 172.95i 5,296 -999,250 -999,250 239,522 2,i.65 -999,250 -999,25'0 i88,349 3,997 -999,25:0 -999,250 179,572 4,099 -999,250 -999,250 167,650 4,596 9.256 ,0i5 32.86i 32i.228 9.168 -,004 25.320 322,735 -999,250 -.~9 250 30,342 314,05~ -999,250 -999,250 26,982 305,764 -999,250 -999,250 44,479 298,206 -999,250 -999,250 35,'167 315,626 -999,250 -999.250 25,706 312,442 -999,25.0 -999,250 23,886 349,553 0,000 -. U.5~ 239.i77 4512,372 0,000 -,029 224,707 4381,368 -999,250 -999,250 227,707 4163,027 -999,250 -999,250 202.087 4133,9i5 -999,250 -999,250 327,047 4847,i61 -999,250 -999,25,0 228,661 4061,I35 -999,25,0 -999,250 220,399 4061,135 -999,250 -999,250 2.02,493 4148,471 ,i59 -i ,000 9,i39 1230, 009 ,168 -1 .000 6,121 1 084,568 -999,250 -999,250 14,400 1254,94i -999,250 -999,250 12,024 1296,496 -999,250 -999,250 23,534 105i,325 -999,250 -999,250 19,116 1026,393 -999,250 -999,250 12.561 1001,460 -999,250 -999,250 12,226 984,838 DEPT D R H 0 HPRS GR FSDL CALl HMRS FDSH HSDL MiNY HDCH DATA NDSN RE MNOR HMCH RECORDS HPH I PELC HDR DFL NRAT QL HDX SP DPE -- -- Hbi R TENS DPHI QPE Hbi% DLOD Pagm i0 o,'00,000 -¥ '~'~. ~. 50 -999,25 0 4.9~4 6600.000 .... }99,250 -999,250 5,699 ~.:500. 000 --999. ~'50 -999. 250 4.2i8 6400.000 -999.250 .... 999.250 4.429 6,300,000 · -999.25 0 · -999.25 0 · _'3.879 6200. 000 .... ~S'9 '-'~0 · -999,250 6i00.000 -999,250 6000,000 .-999,250 .--999,250 3,669 95.4i8 -999 ~= 10,282 4,515 97,340 -999,250 i0,488 5.444 125.28i -999,250 i0.908 3.843 i 07, i 93 -999,250 ii.J09 4. 057 i28,615 -999,250 ii ,309 3.564 I17,357 -999,250 10,903 3,459 119, 164 -999,250 ltl, 536 3,i2i ! 04,355 -999,250 10. 028 3,514 -999,25 0 -999.250 3, 078 2 OS. 07 i -999,250 -999,250 3,078 i75.458 -999,250 -999,250 3, 078 237,089 -999.250 -999,250 3,078 225.79i -999,250 -999,250 3,0?8 257.814 -999,250 -999,250 3,078 264,439 -999,250 -999,250 3,078 291,537 -999,250 -999,250 3,078 272.522 -999,250 -999.250 221 .478 -9'99,250 -999,250 z,$95 i83.679 -999.250 -999.250 2,395 260.2t7 -999,250 -999,250 2,395 246.5i~ -999,250 -999.250 2.395 280,589 -999,25'0 -999.250 2,395 289.i39 -999,250 -999,250 2.395 320,395 -999,250 -999,250 2,395 284.607 -- . . -999 17i -999 i6i 5 -999 -999 i98 -999 -999 189 -999 -999 2.11 3 -999 -999 3 -999 -999 233 2 -999 -999 225 3 ,250 ,250 . i59 .932 .250 ,250 ,409 ,56i .250 ,250 .i46 ,592 .250 .250 .876 ,907 ,250 .250 .655 .297 ,250 ,250 ,354 .295 ,250 ,250 ,282 .996 .250 .250 .79i .543 -999 -999 334 -999 -t'~ 'd '~ 24 324 -999 -999 33 3;30 -999 -999 335 -999 -999 340 -999 -999 39 335 -999 -999 50 329 -999 -999 47 ~43 ,250 ,250 .109 .580 ,250 .935 .443 ,250 .250 ,470 .431 ,250 .250 · i 64 ,i49 ,250 ,250 ,72i ,706 ,250 .250 ,584 .78..'3 ,250 ,250 ,396 ,768 ,250 ,250 ,200 .316 -999 -999 202 4206 -999 - L~ L-~ '--J 390i -999 -999 24i 3799 -999 -999 229 3799 -999 -999 256 3726 -999 -999 266 3886 -999 -999 294 3901 -999 -999 265 3624 .250 ,250 · 04,3 .695 .250 .250 .28i ,0i9 .250 .250 ,657 ,126 .250 ,250 .138 .126 . 250 ,250 ,364 ,346 ,250 .250 .176 ,462 ,250 · 250 ,7i2 .019 .250 .250 ,674 ,454 -999,250 -999,250 ii.108 100i.460 -999,250 -999,250 14,398 i009.77i -999.250 -999.250 i7,092 ~ .... i48 -999,250 -999.250 i6,741 955,750 -999,250 -999.250 19,853 984,838 -999,250 -999,250 i9,805 ii~ ~.609 -999,250 -999,250 23,478 993,~48 -999,250 -999,250 2i,683 i15i,056 DEPT DRHO RHO8 HDRS GR FSDL CALl HHRS FDSN NSDL MiNV HDCN DATA NDSN PE MNOR HMCN RECORDS NPHI PELC HDR DFL NRAT QL H D X DPE HHR TENS DPHi QPE DLOD Pagm li 5900, 000 --999,250 4,804 5800,000 -999,250 2,497 5700. 000 .... -~ :'~'~ . ~-50 .-999,~50 2,719 5600,0.00 --999,250 -999,250 3,154 5500,000 -999,250 .... 999,250 2,066 5400,000 -..999.250 -999,250 4,842 5300 ,.000 -999,250 -999,250 3,253 5200,000 -999,250 -999,250 i34,590 -999.25 0 10.7i0 4,460 147,774 -999,25 0 9,80! 2 ,~50 187. 098 -999.250 9. 944 2,547 155,044 -999,250 9.845 2,859 112.147 -999,250 9,772 1,810 172,792 -999.250 10,708 4,342 90,055 -999.250 10,497 2,946 i31,142 -999.250 10,190 2.959 -999,250 -999,250 3,078 208,153 -999.250 -999,250 3,078 400,509 -999,250 -999,250 3,078 367,795 -999,250 -999,250 3,078 317,084 -999,250 -999,250 3,078 484,005 -999,250 -999,250 3,078 206,534 -999,250 -999,250 3,078 307,444 -999,25 0 -999,250 3,078 309,982 -999,250 -999,250 2.395 224,234 -999.250 -999,250 2,395 425.536 -999,250 -999,250 2,395 392,579 -999,250 -999,250 2,395 349.744 -999,250 -999,250 2,395 552,5i7 -999,250 -999,250 2,395 23'0,309 -999,250 -999,250 2. 395 339,469 --999,250 -999.250 2,395 337,921 -~v~,250 -999,250 177,850 3.922 -999.250 -999.250 313.034 2,293 -999,250 -999,250 292.642 2,765 -999,250 -999,250 261.641 2.967 -999,250 --99'9,250 342,829 1,650 -999,250 -999,250 174,865 4,327 -999,250 -999,250 238,367 2,738 -999,250 -999,250 254,818 2,807 -999,250 -999.250 26.914 332.577 -999.250 -999,250 87,445 351,624 -999,250 -999,250 65,983 342.755 -999.250 -999,250 66,996 331,583 -999,250 -999,250 97,894 340,593 -999,250 -999,250 29,083 315,252 -999,250 -999,250 51,456 317,380 -999,250 -999,250 60.909 320.873 -~v~,250 -999.250 2i2.263 3668.i22 -999,250 -999,250 402.679 3566,229 -999,250 -999.250 378.927 3508,005 -99'9,25:0 '999,25.0 327,151 3580,786 -999,250 -999,25.0 476,635 3347,889 -999,250 -999,25:0 216,594 3493,45:0 -999,250 -999,250 306.389 3478,894 -999,250 -999,250 319,485 3406,113 -999,250 -999,250 li.93i luu~.~71 -999,250 -999,250 43,426 1200,92i -999,250 -999.250 29,736 1026,393 -999,250 -999.250 31,879 1092,879 -999,250 -999,250 53,647 1055,480 -999,250 -999,250 ! 2,077 1 051 . 325 -999,250 -999,250 26.619 1296,496 -999,250 -999,250 31,267 i097,035 DEPT RHO~ HDRS FSDL CALI FDSN NSDL HDON DATA NDSN PE HNOR HMCN RECORDS NPHI PELC HDR DFL NRAT QL HDX SP DPE HMR TENS DPHI QPE HHX DLOD Pmgm i2 ~-~100, 000 --':~':~ ':~. 250 -'.-)99,250 · 3. 0~0 5000, 000 .... )99 , 250 .--999. ~50 3, 046 4900. 000 ~99 . 250 .... 399.250 3.301 4800, 000 --999.250 -')99.250 3.2i2 4700.000 -999,250 -999.250 4600,000 -999,250 -999,250 3.974 4500,000 -999,250 --~¥,~U 4,372 4400.0.00 -999.250 -999,250 4,4J8 i24.2i4 -999,25 0 9. 927 2,719 129.224 -999.250 8,5ii 2.636 107.628 -999.250 9.543 2,934 114,390 -999,250 9,886 2.872 1 01 . 434 -999.250 10. 098 2.569 113,t00 -999,250 i0.302 3.399 125.503 -999.250 10,326 3,795 10G.827 -999,250 10.050 3.897 -999.250 -999.250 3.078 330.080 -999,250 -999,250 3.078 328.258 -999,250 -999,250 3.078 302.894 -999.250 -999.250 3.078 311.345 -999,25 0 -999.250 3,078 337. i 48 -999.25 0 -999,250 3,078 25i .GO6 -999.250 -999.250 3,078 228.740 -999,250 -999,250 3,078 225.335 -999,250 -999.250 2,395 367.783 -999.250 -999,250 2,395 379.384 -999,250 -999.250 Z.395 34'0.795 -999,250 -999.25.0 2.395 348.2:07 -999.250 -999,250 2.395 389.2i8 -999.250 -999,250 2.395 294.183 -999,250 -999.250 2,395 -999.250 -999.250 2.395 256.588 -999.250 -999,250 261 ,679 2,413 -999,250 -999.250 248.507 2.358 -999,250 -999,250 242,872 2,699 -999,250 -999.250 245.650 2.707 -999,250 -999,250 261 .406 2.334 -999,250 -999,250 2i 5.70'0 3.256 -999,250 -999.250 i9i.782 3.258 -999,250 -999,250 189.344 3,505 -999 -999 58 ,329 -999 -999 54 324 -999 -999 5i 319 -999 -999 55 -999 -999 330 -999 -999 42 332 -999 -999 32 324 -999 -999 33 329 .250 .250 ,608 .957 ,250 ,250 .886 .785 ,250 .250 ,438 ,032 .25O ,250 .42G .746 .250 .250 .669 ,672 ,250 ,250 ,706 ,450 ,250 ,250 .680 .724 .250 ,250 .82i -999,250 -999,250 332.240 3333.333 -999,250 -9'B9.25 0 334,5i9 3508,005 -999,250 -999,250 3i2,56i 3304.221 -999,250 -999,250 312,457 3144,104 -999,25'0 -999,250 343,830 3231,441 -999,250 -999,250 277,137 3173,2i7 -999,25'0 -999.250 241,828 291i.208 .-999,250 -999,250 239.395 29ii,208 -999 -999 30 1 097 -999 -999 29 ii?5 -999 -999 27 1084 -999 -999 29 1 059 -999 -999 32 i134 -999 -999 22 -999 -999 17 li30 -999 -999 19 1 030 .250 ,250 .827 035 .250 ,250 ,i32 .988 .250 .250 ,970 ,568 ,250 ,250 ,891 .636 ,250 ,250 ,114 ,434 ,250 ,250 ,510 .408 ,250 .250 ,873 .278 ,250 .250 .458 ,548 DEPT DR~O RHO~ HDRS FSDL CALl HMRS FDSN NSDL HiNV HDCN DATA NDSN PE MNOR HNCH RECORDS NPHI PELC HDR DFL NRAT QL HDX SP DPE HHR TEHS DPHI QPE H bi X DLOD Page 13 4.300,000 .... 999.250 -999.250 J.2i7 4200, 000 --999. 250 -999.250 5. 083 4i00.000 -999,250 -999.25 0 4,208 4000,000 -999.250 -999.250 6.0ii 3900,-000 -999.250 -999,250 5,759 3800,'000 -999,250 -999.250 3.315 3?00..000 -999.250 -999.250 -999.250 3600. 000 -999.250 -999.250 .... .~99.250 102.430 -999.250 9.874 2.772 lOO.93e -999.250 lo.159 4.343 97,873 -999,250 I0,795 3,584 lJO,O?~ -999,25.0 10.531 5,238 113,534 -999,250 II.i027 4.783 92,147 -999,250 13 ;277 i, 586 58.644' -999,250 8.965 -999.250. 51.898 -999.250 8,965 -999,250 -999.250 -999.250 2.479 3i0.819 -999.250 -999,250 2.673 196.739 -999.250 -999.250 1.719 237.642 -999,250 -999.250 3.213 166.352 -999.250 -999.250 2.563 173.640 -999,250 -999.250 2.344 301,626 -999,250 -999.250 -999.250 -999.250 -999,250 -999,250 -999.250 -999.250 -999 360 -999 -999 2 230 -999 -999 1 279 -999 -999 .'3 190 -999 -999 2 209 -999 -999 2 630 -999 -999 -999 -999 -999 -999 -999 -999 .zSO .250 · 096 ,757 .250 .250 .606 .258 ,250 .250 .675 · :009 ,250 .250 105 .921 .250 .250 .706 072 .250 .250 ,806 .714 .250 .250 .250 .250 .250 ,250 .250 .250 -999 - 999 227 -999 -999 16,3 3 -999 -999 201 2 -999 -999 149 4 -999 -99'9 150 4 -999 -999 129 5 -999 -999 -999 -999 -999 -999 -999 -999 .250 .250 .9i9 · 426 ,250 .250 .768 .695 .250 .250 .648 .925 .250 ,250 .628 .706 .250 .250 .331 .296 ,250 .250 .Ii2 ,293 ,250 .250 ,250 .250 .250 .250 .250 -999 -999 44 336 -999 -999 22 354 -999 -999 36 ,357 -999 -999 20 366 -999 -999 23 362 -999 -999 15 363 -999 -999 -999 -999 -999 -999 -999 -999 ,250 .250 ,652 .045 .250 ,250 .340 ,880 ,250 .250 · 459 .535 .250 .250 .375 ,0;37 ,250 ,250 ,436 .230 ,250 .250 .262 .263 ,25.0 ,250 ,250 ,250 ,250 .250 ,250 ,250 -9'99,250 -9'99. 250 305.259 2896.652 -999,250 -999.250 2-06,660 275i,091 -999.250 -999.250 266,693 2765,647 -999.250 -999,250 180.879 2634.643 -999.25'0 -999,250 189.585 2765.647 -999,250 -999,250 161.362 2765,647 -999,25.0 -999,250 -999.250 2~49.199 -999,25.0 -999,250 -999. 250 2678.312 -999.250 -999,250 3i,5i4 1130,278 -999.250 -999,250 11,597 iiOl.190 -999.250 -999,250 17.883 1142.744 -999.250 -999.250 10,324 i'043,014 -999,250 -999.250 24.057 1038.858 -999,250 -999,250 6,962 ti21.968 -999,250 -999.250 ,-999.250 1055.480 -999,250 -999,250 -999,250 1013.926 DEPT DRHO RHOB HDRS GR FSDL CALi HHRS FDSH N~DL MINV HDCH DATA NDSN PE MNOR H H C N RECORDS NPH I PELC HDR DFL NRAT QL HDX SP DPE QS HMR TENS DPHI QPE HMX DLOD Page 14 ;.';500, OOO -999,250 · .-999,250 -999,250 3400. 000 .... 39'B. 250 .... 799,250 -999,250 3300. 000 -999,250 .... -~9'-3 --999,250 S200.000 --999,250 ---999,250 --999,250 :_~i 00,000 -999,250 -999,250 -999,250 3000,000 -999,250 -999,250 -999,250 2900,000 -.999,250 -999 ~: -..999,250 2800,000 - 999,250 -. 99 250 --999,25 O 48.118 -999.250 8.965 -999.250 41,912 -999.250 8.965 -999.250 -999,250 '8,965 -999.250 50.651 -999,250 8.965 -99'9.25.0 48.485 -999,250 8.965 -999,250 50,896 -999,250 8,965 -999,250 69,892 -999,250 8.965 -999.250 48,963 -999;250 -999,250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999,250 -999,250 -999.250 -999.250 -999.250 -999.250 -999,250 -999,250 -999.250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999.250 -999.250 -999.250 -999,250 -- -- . -999 -999 -999 -99'9 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 -999 ,250 ,250 ,ZDU .250 ,250 ,250 ,250 .250 ,250 ,250 .250 ,250 ,250 ,250 .250 ,250 ,250 ,25'0 ,250 ,250 ,250 .250 ,250 ,250 ,250 ,250 ,250 ,250 .250 ,250 ,250 -999,250 -999.250 -999,250 -999.250 -999,250 -999,250 -999,250 -999,250 -999,250 -999.250 -999,250 -999.250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999.250 -999,250 -999.250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999.250 -999,250 -999.250 -999.250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,250 -999,25,0 -999,250 -999,250 -999.250 -999,25'0 -999,250 -999,250 -999,250 -999 -999 -999 2561 -999 -999 -999 2547 -999 -999 -999 2547 -999 -999 -999 2430 -999 -999 -999 2387 -999 -999 -999 2372 -999 -999 -999 2314 -999 -999 -999 2285 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'061 -999.250 -999.250 -999.250 1877.729 -999.250 -99'9.25.0 -999.250 1746.725 -999.25.0 -999.250 -999.250 1673.944 -999,250 -999.250 -999.250 1067.946 -999.250 -999.250 -999.250 i092.879 -999.250 -999.250 -999.250 1084.568 -999.250 -999.250 -999.250 1092.879 -999,250 -999.250 -999.250 I092,S79 -999.250 -999.250 -999.250 1142.744 .-999.250 -999.250 -999.250 li04.299 -999.250 -999.258 -999.250 t 130.27,9 DEPT DRHO RHOE~ HDRS GR FSDL CALI HHRS FDSN NSDL HiNV HDCN D.ATA NDSN PE MNOR HHCN RECORDS NPH I PELC HDR [)FL NRAT QL HDX SP OPE QS HMR TENS DPHI QPE HMX DLOD Page 17 i i 00, 000 .... 399, :-'5 0 -- 999 , 250 --999.2.5 0 t000,000 -999.250 -999,25 0 .... ~.99,250 900.000 ..... 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I"l~xi~,um length: !024 TRAILER RECORDS Service name: File type: LO Next Version ¢ile: Date: Pag~ 19 Film name: .002 Maximum length: · 1.024 Service name: Version #: Film type: LO Previous ?ile: Date: H t-I E H Ct4 Id H FH C: 0 U H STAT CTRY APtt,t I_AT I LOHG SECT TOWN P,, A N Q Ei<8 EDF EGL PD LHF D H F RUN ]' IHE DATE LCC SON L Li N FL LUL EHG i W I T H D D DL C B D i C.:BL 1 BI_i ! TLAB BHT NRT HT HS.S DFD NV IS: DFPH [)FL RH R bi F MFST HFSS F:. bi C INFORMATION RECORDS CONTENTS UNIT ARCO ALASKA INC. KUPARUK RIVER DATE LOGGED: NORTH SLOPE ............ ALASKA ............ USA ............ 20i34.000 ....................... 0 Deg. 0 Min, O. 0 Sec 0 Deg, O Min, O, 0 Sec 1 ~N ........... 08E ........... 90, OOO ........ 89. 000 ........ 54 000 K8 · KB ............ 6~5.000 ........ 52 8290 ........ 367708 ..... ,,1939 .......... NORTH SLOP~ HORTH SLOPE . McKAY . LOWEN , 8250.000 ............. 8250.000 ............. 3783 OOO . I I·l·llIItlitl· 3790 00'0 3?90.000 ............ 8241.000 ............ 5.000 ............... ~35.000 ............. 158,000 ............. 158.0.00 ............. L. SND , CIRCULATED . 10,8:00 ............... 40.000 ............... 8.500 ................ 6 20'0 I 840 i.910 ...................... -- 000 ~t , t , , , , ,, , , , , ,, , , t , , , , HEAS ................ 3 200 I|.|itl·lllt tmmlIamitt Itmlllitmtl ItitlIIIIII I IIIlIIlII · lIlIIIIll IlII · . · I It m ~ · .mit IlII titm. mmtt IImI.i API NUM: 50-103-20134. , 08-05-90 ...... Illlla.lmlmm. iilIliiliilll i111111 i m I · m · · t · iillm i·lllll Itmlaitll 1111111 I i · ll*·lll lllllllll [ltl. Will Itlillllit lllllllll tl.llllll ttllt N .itlII wit. ,III tItlt tlIl ,emil II11 t1111 Iltlllllll Illliitlit IIIIIIII IIIIIIII II IlIII II II lllitl It 11111 I III · I II1 I I Itl · t II1 I IIi I III i · Ill I IlIIl tlllmll.i l·llmll.I I · . . · t m · . t It It . I l I It a · · · II . . I I t le . It . t It ii · ti ti mi Il 11 Itt limit laIII Itllli lilts Itllll Ilitll Itlititl IIIit IIIit IIIIt iiiiiii lltllll ·lllllt IIIIIII IIIllitlllll IIIIIIIIIII t I I111111111 I I I I · i IIIIIIII I · IIIlitlll i I i11111 I · I t I I .illll ! I Illlll I I Iiilii I I Iilitll I IIII1111 · It II tt mlllitl I|1111 tliii ii · I| tm i. ii l· i Il ii ii i itll iiit 1111 IIIi iiii iiii iiii IlIi Iii ii Ii I · . I !I ii II II It TYPE CATG 0 0 :0 0 0 0 0 0 0 I0 0 0 0 0 0 0 0 o 0 0 0 0 0 0 FT l0 FT 0 3 FT 0 3 '0 3 0 3 0 3 · 0 0 0 0 0 0 0 0 0 0 0 0 o 0 o 0 0 0 o FT 0 3 FT 0 3 FT 0 3 FT ~0 FT 0 3 FT 0 3 HR 0 2 HR 0 4 DEGF 0 I DEGF 0 '0 2 0 2 LB,;G 0 2 CP 0 2 0 2 0 2 OHHM 0 2 OHHH o 2 DEGF 0 2 0 0 H bi H 0 2 SIZE 40 40 40 20 20 20 4 34 34 2 3 3 4 4 4 2 2 2 2 4 8 2 lO 10 20 20 20 20 4 4 4 4 4 4 4 4 4 4 20 20 4 4 4 4 4 4 4 ~2 4 CODE 65 65 65 65 65 68 65 65 65 65 65 65 65 '79 65 65 65 ~5 68 68 65 68 65 Page ERROR 2O H H E H I',1 C: $ T ~'i C: S S I NFORMAT I ON RECORDS COHTEHTS UNIT 63. 000 .................................................. HE~S ............................................. .15;/.,5 ................................................... '~ .500 ................................................... DEGF TYPE CATG SIZE 4 i2 4 4 CODE Pa,_Zl~ ERROR 2i COMME.NT RECIDRDS h~ell Location Comment l: SURFACE: i.~iell Location Comment 2: ~,iell Location Comment 3: ~.,.~eil Location Comment 4: h~ell File Comment 1: CHLORIDES = !,~all Film Comment 2: i.,Imll File Comment 3: 2538' fHl & 145' FWL 1100 PPM. HRI,ML,SDL?DSN RUN IN COMBINATION. DATA PRESENTED USING CONDUCTIVITY X COMPONENT OFFSET VALUES OF: (-32.0 MMHOS FOR DEEP X) & (2.0 MMHOS FOR MEDIUM X) Well File Comment 4: THIS TAPE CONTAINS KUPARUK DISTRIBUTION DATA ONLY, ~:~ LIS t. ap¢ written by: ANCHORAGE COMPUTING CENTER ~=~ All curve and tool mnemonics used are those which most closel~ match ~ Halliburton curve and tool mnemonics. HALLIBURTON TO SCHLUMBERGER TOP BOTTOM MNEM SERVICE UNIT MNEM SERVICE UNIT DEPTH DEPTH III --III --II~ DEPTH FT DEPT FT 180,00 8280,00 GRt SDL GAPI GR SDL GAPI 754~.75 8275.00 FDSNI DSN~ CPS FDSN DSN~ CPS ?546,?5 8275,O~ NDSNI DSH~ CPS NDSN DSN~ CPS ?546,?5 8275,~0 NPHI! DSN~ DECP NPHI DSN~ DECP ?546.?5 8275.~0 NRAT1 DSN~ C/C NRAT DSM2 C/C ?546.?5 8275.~0 DPE1 SDL DPE SDL 7546,75 DPHIi SDL DECP DPHI SQL DECP 754~075 8275.~0 DRHO1 BDL G/C3 DRHO SDL G?C3 7546,75 8275,00 FSDL1 SDL CPS FSDL SD[. CPS 7546,75 8275.00 Page 22 NSDL 1 PE1 PELCl OiL1 ~$1 QPE1 RHOBI CRL]I I'IHOR 1 HDRI HDXl HMRI HMX1 HDRSi Ht'IRS 1 HDCN I HMCH1 DFLi SPI TENS 1 SDL SDL SDL SDL SDL SDL SDL SDL HL HL HRI HRI HRI HRI HRI. HRI HRI HRI HRI HRI SDL CPS G/C3 IH OHNM OHMM ONMM OHMM MMHO MMHO OHMM MY NSDL PE PELC QL QS QPE RHOB CALI MINV MNOR HDR HDX HMR HHX HDRS HNRS HDCN HMCN DFL SP TENS SDL SDL SDL SDL SDL SDL SDL SDL ML ML HRI HRI HRI HRI HRI HRI HRI HRI HRI HRI SDL CPS G?C3 IH OHNN OHHN OHNN ONNN NNHO NNHO LBB 7546 ?546 7546 7546 7546 7546 7546 7546 7546 7546 .7546 7546 7546 7546 7546 7546 7546 7546 7546 7546 7546 .75 ,75 .75 ,75 75 75 75 75 75 75 .75 ,75 ,75 .75 .75 .75 .75 ,75 .75 ,75 e275 8275 8275 8275 8275 S275 8275 8275 8275 e275 8275 8275 82?5 82.75 8275 8275 e275 8275 e275 8275 8275 ,0'0 .00 , 'O 0 .O0 ,00 .00 ,00 . O0 .00 ,00 O0 O0 "00 O0 · 00 O0 ,00 . O0 ,00 .O0 COM'MENT RECORDS Pmgm [)LOD~ SDL LBS DLOD SDL LS~ 7546.75 8275.00 DATA : :~:~: EHTRY BLOCKS EHTRY FORMAT TYPE 16 SIZE SP~EC I F I CAT I OHS CODE 66 Page ENTRY BLOCK LEGEND TYPE DESCRIPTION Datum zpeci¢ication block sub-type T~rmina~or ,,~ no more ~n~ri DATA FORMAT :** DATUH SPECIFICATION BLOCKS SPECIFICATIONS Page 25 SERVICE SERVICE APl AP1 Hi-.IEM iD ORDER ~ UNIT LOG TYPE AP1 APl FILE CLASS HOD # PRC ~ SIZE LVL SMPL RC PROCESS INDICATORS DEPT 367708 FT 0 0 gR SDL 367708 GAPI 94 0 F[;SN DSN2 3677.08 CPS 94 0 tIDSH DSN2 367708 CPS 94 0 t,iF'H ~ DSN~ 3~708 DECP 94 i,IR~T DSN2 3G7708 C/C 94 0 DPE SDL 3G7708 94 0 DPHI SDL 36?708 DECP 94 0 DRHO SDL 367708 G/C3 94 0 FSDL SDL ~G~708 CP~ 94 0 NSDI_ SDL 367708 CPS 94 O PE SDL 367708 94 0 PELC SDL 367768 94 QL SDL 3G7708 94 0 QS SDL 367?08 94 0 OPE SDL ~7708 94 0 RHO8 SDL 367708 G/C3 94 0 CALl SDL ~G7708 IN 94 0 N i NV Mi. 3677 08 OHMM 94 0 HNOR HL 3677 08 OHHH g4 0 HDR HRI 36~708 94 0 HDX HRI 36~708 94 0 Hi'iR HR i 3677 08 94 0 HHX HR I ~77.08 94 0 HDRS HR I 3677.08 OHMM 94 0 HMRS HR I ~G77 08 OHMM 94 0 HbCN HR I 36~708 HHHO g4 0 HMCN HR I 367708 HMHO g4 0 DFL HRi 36~708 OHHH 94 0 SP HRI 367708 HV 94 0 TENS oDL ~G~.O8 LBS g4 0 DLOD SDL 3G77.08 LBS 94 0 0 0 2 4 0 0 3 i 4 0 i 0 3 i 4 0 i 0 3 i 4 0 0 3 i 4 0 0 3 i 4 0 i 0 3 i 4 0 0 3 1 4 0 i 0 3 i 4 0 i 0 3 I 4 0 0 3 i 4 0 0 3 1 4 0 0 3 i 4 0 0 3 i 4 0 0 3 1 4 0 i 0 3 i 4 0 0 3 ! 4 0 0 3 1 4 0 1 · 0 3 i 4 0 i 0 3 1 4 0 t O 3 i 4 0 1 O :3 1 4 0 1' 0 3 1 4 0 1 o 3 i 4 o 0 3 1 4 0 1' 0 3 1 4 0 0 3 1 4 0 t 0 3 1 4 0 t. O 3 1 4 0 0 3 i 4 0 0 3 1 4 0 1 0 ;3 1 4 0 G8 68 68 68 G8 68 G8 68 G8 68 68 68 G8 68 68 G8 68 68 68 G8 G8 G8 G8 68 G8 G8 G8 G8 68 68 000000 000000 000000 000000 000000 000000 000000 000000 000000 · 000000 000000 000000 000000 000000 000000. 000000 000000 000000 000000 000000 000000 000000 800000 000000 000000 000000 000000 000000 000000 000000 00000'0 000000 000000 000000 000000 000000 000000 O00000 000000 000000 000000 000000 O00OO0 O00OO0 000000 000000 0000'00 000000 000000 0000'00 000000 000000 O00000 000000 00000.0 000000 000000 000000 000000 000000 000000 800000 000000 0.00000 0000'00 000000 OOOO00 00.00'00 000000 0'00000 00~0000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 ~00000.0 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 DEPT DRHO RHOB GR FSDL CALI HMR~ FDSN NSDL MINV ~DCN DATA NDSN PE HNOR RECORDS NPHI PELC HDR DFL NRAT QL H D X SP DPE QS HMR TENS DPHI QPE HHX DLOD Page 26 E;275,000 ,036 2,477 -i2345.000 .027 2.479 3.458 8100.000 .039 2,448 '3,504 8000.:000 .028 2.3@6 7,.352 7900.,OOO ,028 2,273 2.0.904 7800.000 ,028 2,475 180,520 7700.000 ,038 2,351 1,912 7600,000 ,035 2,392 2.604 107.846 6106.217 8,50.0 -12345.000 105,421 5967.661 8.486 3.415 109,480 6437.883 '8.607 3,464 86.233 7061,772 8.832 7.657 64.293 8612.668 8,590 23,660 40,693 6084,550 8,92i 223,000 124,0.03 7627,550 9,298 t.668 119.340 7126,772 I2.013 2.394 2310.737 15802,883 1.06i -12345.000 2032.353 15632.883 3.213 289,162 2012.189 15979.883 3,382 285.352 2470.112 16144,246 7,754 136,017 2747.130 16767.246 8.581 47.838 2698,932 15711,883 10,252 5.548 1394,685 16495.066 1,643 523,07? 1481,470 16275,701 2,251 384,'052 15844.020 3.315 i.331 -12345.808 15071.078 3.354 2,883 292.828 15285,541 3,096 2.66'1' 288.679 16505.297 2,705 6,276 130,6.01 17542.941 2.519 1'0,933 42.265 16958.582 4.399 14,478 4.484 13231,635 2.836 '1,342 599,541 13536.965 3,153 2.229 417,763 .332 3.857 0,000 3.024 3 225 3 3 223 3 3 114 7 2 47 29 4 19 180 2 359 ! 3 287 2 ,364 .825 .945 ,392 ,372 .378 .335 ,388 .318 · 065 .106 .965 ,305 ,607 ,511 .891 ,295 ,516 .2:04 .107 ,475 ,975 .985 ,704 ,425 ,475 .2Bl ,479 7.362 ,047 0,000 123450000, 7,962 .005 50,765 289,270 8,157 .017 51.400 293.390 7. '175 -.003 18,772 289, I 06 6,857 ,019 9,038 259,493 6,747 -,'017 -4,955 272,436 10.187 ,023 100,499 296.244 9,811 . .007 69,066 292,559 0.000 0,000 4047.161 0.000 -.016 272.023 4672.488 0.000 .002 272,015 4628.820 0.000 -.0'04 124,660 4206,695 0,000 .015 41,935 46i4.265 0,000 -,008 9,225 4439,592 0,000 -.008 479,073 4468,7O4 O, 0.00 -, 0.02 366,697 44.39,592 .105 -1 .000 0.000 -20,778 ,104 -1 .000 19, t83 1 i 5 i , 056 ,122 -1 ,000 18,476 '1230. 009 .160 -i .000 4,514 1 03 O. 548 ,229 -1, OOO -1 ,358 1205. 076 ,106 -1,000 -2,528 1 092,879 .181 -l.OOO 54,991 1300.~51 .156 -I ,000 34,226 11 05, .346 DEPT DRHO RHOB HDRS GR F~DL CALI HMRS FDSN MINV HDCN DATA NDSN PE HNOR HHCN RECORDS NPHI PELC HDR DFL NRAT QL HDX SP DP£ Q~ HHR DPHI QPE DLOD Page ;27 FiLE TRAILER name: ~]5F0 Maximum length: 1024 TRAILER RECORDS File type: LO Version #: Next ~ile: Date: Page 28 REEL TRAILER Service name: &~;SFO1 Next reel: Date: 90/08/10 Commentz: Origin: Reel name: 367708 Continuation #: 01 ~::~ TAPE'TRAILER Service name: ~C~5F.0'1 N¢:.,',t t. mpe: Date.: 90/'08/10 Commentz: Origin: Tape name: Continuation #: 01 DIRECT DIGITAL LOOGING LLLLLLLLL L. LLLLLLLL IIIIIIIIII SSSSSSSS IIIIlIIIZI SSSSSSSSSS II SS SS II SS II SS II SS~SSSSSS II ~SSSSSSSS II ~ II SS ii SS SS IilIIIIIiI SSSSSSSSSS IIIIIIIIII SSSSSSSS DDDDDDDDD UU UU DDDDDDDDDD UU UU DD DD UU UU DD DD UU UU DD DD UU UU DD DD UU UU DD DD UU UU DD DD UU UU DD DD UU UU DD DD UU UU DDDDDDDDDD UUUUUUUUUUUU DDDDDDDDD UUUUUUUUUU NH NH PPPPPPPPPPF HHH MMM PPPPPPPPPPF MHHH MHMH PP F MH MM HH MM PP F HH HHHH HH PP F MH HH HH PPPPPPPPPPF HH HH PPPPPPPPPPF MM MM PP MH HH PP MM HH PP MH NH PP MM NH PP 22222222 222222222 22 22 22 22 22 22 22 222222222 222222222 444 4444 44 44 44 44 44 44 44444444444 444444444444 li Ill 1111 11 11 11 11 1 1 I liill 11111 44 44 44 44 44 1 I 1 11111 11111 III AA AAAA AA AA AA AA AA AA AAAAAAAAAAAA AAAAAAAAAAAA AA AA AA AA AA AA AA AA 2222222222 O00OOOO0 222222222222 O00000OO00 22 22 O0 O0 22 O0 O0 22 :00 O0 22 O0 O0 22 O0 O'O 22 00 00 22 .O0 O0 22 O0 O0 222222222222 O000OO000O 222222222222 00000000 UU. UU GGGGGGGGGG UU UU GGGGGGGGGGGG UU UU GG GQ UU UU GG UU UU GG UU UU GG UU UU GG UU UU GG GGGGG UU UU GG GGGGG UU UU GG GG UUUUUUUUUUUU GGGGGGGGGGGG UUUUUUUUUU GGGGGGGGGG PPPPPPPPPPP NM PPPPPPPPPPPP HHM PP PP HHMH PP PP NM MM MM PP PP NH HHHM PPPPPPPPPPPP NH NH PPPPPPPPPPPP MM PP MM PP MM PP NH PP MM PP HM 9999999999 OOOO00OO 999999999999 000000000( 99 99 O0 99 99 O0 99 99 O0 999999999999 ,00 999999999999 O0 99 O0 99 O0 99 99 O~ C 999999999999 000000000£ 9999999999 00000000 REEL HEADER Set. vice name: HLS Pravious reel Date: 90/0B/15 Comments: HEADER'RECORDS Origin: PLS Reel name: H904173 Continuation #: HL$ FORHATIOH EVALUATION SYSTEHS -- HEADQUARTERS Page TAPE HEADER **** :Sarvice name: HLS IIIIII Date: Previous tape: 90/08/05 Comments: Origin: PLS Tape name: H904173 Continuation #: File name.: Service name: Version #: SFMG Date: 89/01 ? O4 l"lsximum length: 974. File type: LO Previous ?lie: t,1H E bi CN b.I N FN C 0 U N STAT E; 0 H RUN [)ATE AP itl LUN LUL EN G I ~d i T N HR T RH HST ' Ri'iF I'IFST RNC: MCST EK B EDF EC~L LHF BSD1 BS2 BSD2 BS3 BSD3 CSi CSD1 CSD2 CS3 CSD3 BLI INFORMATION RECORDS CONTENTS ARCO ALASKA, INC ................ 3G-10 ............. KUPARUK RIVER UNIT ............. N, SLOPE ............................. L36770 ................................ ONE ................................ oe,,o ) 6 ............................ 501032013400 ........................ 51939 ................................ N. SL06~ ........ D. HCKAY , A., LO,EH . ................................. · III II III II It IIIIIIlIII I151 1 i i a · i i · 1 .91 ...... 3.2 ...... 90 ..... e9 ..... 54 ..... K~ ?~ ..... ~ I .... ~250 .... immmmmwmlmlmIlmmmmlmmlsmlIllIllI I~m~mam~m mmmmmmmlm Imm/llllI lllJlllll IIIiiiiiii Ii11115111 iiiiiiiiili1 iiiiIiIIlIll iiIiIillllll iiiiIiiIiIl* Illlmmllmmmlmllmlmlllllllmlmmllmllmlmlmlllmll iiiIitllltllllltllllIlIIIttllllllllllllllllll llllillllllllllIiIiIIlllllllltlllltllltllltll lliIillllltlllllllllllllllllllllllllllltlllll Illlllll!lllllllillllllllllllllllllIIIIIIllll iiii1111111111t1111111111111t1111111t111111tl Illmmmmmtm.lmlm m II I mmmltlI lmm lmmmlllllmllmlIIllllll 3783 ................................... ~240 3730 UNIT DEGF OHHH DEGF OHMM DEGF OHHM DEGF FT FT FT IN FT IN FT IN FT IH FT IH FT IH FT FT FT TYPE C~TG 0 0 o o 0 0 0 0 0 O 0 0 0 0 .0 0 O 0 0 '0 0 0 0 0 0 1. 0 2 0 2 0 2 0 0 2 0 2 0 0 3 0 3 0 3 0 3 0 3 0 3 0 3 0 3 O 3 0 3 0 3 0 3 0 3 O 3 0 3 0 3 .0 3 SIZE 28 28 12 2 8 4 32 40 40 4 4 4 4 4 4 4 4 4 4 CODE 65 65 65 65 65 Page ERROR COMMENT RECORDS Page THIS IS THE MAIN SECTION FOR FULL WAVE SONIC LOG. DATA ENTRY ~LOCKS ENTRY · |I~ ............... , .............. FORMAT TYPE 1 2 3 4 5 9 11 SIZE 1 1 2 1 4 4 I SPECIFICATIONS CODE 66 79 73 Page ENTRY BLOCK LEGEND **** TYPE DESCRIPTION Data record type ( logical record ~ype number ) Datum speci~iEationbiock type Data Creme size .( bytes ) Up ? Down .~lag ( I = up, 255 = d°wn~ :~ = neither Optical log depth scale ( 1 =?eet, 255 = meters Frame spaczng ~ depth di~?erence between ?tames Units o? Creme spacing Maxi:mum Cremes per record · Datum speci?ication block sub-type Terminator ( no more entries ) ) 0 = time DATA FORMAT SPEC I F I CAT IONS *:~ DATUH SPECIFICATION BLOOKS HNEM SERVICE SERVICE API API API API FILE iD ORDER # UNIT LOG TYPE CLASS' MOD # DEPT FWS CALl FWS GR FWS G4G$ FWS SCAE FWS TbiC FWS ALT FWS SCFI FWS SCF~ FWS SDC:S FWS G1 FWS L36770 FT 62 '0 0 1 L36770 iN 62 280 L36770 ~API 62 310 L36770 DB 62 980 21 '1 L36770 US/F 62 970 ?0 1 L36770 US 62 52 4 L36770, 62 980 L36770 US/F 62 50 3 L36770 US/F 62 50 3 1 1 L36770 62 S.O 3 i 1 L36770 DB ,62 988 22 PRC # SIZE LVL SMPL RC 4 0 1 68 4 O 1 68 4 0 I 68 4 0 1 68 4 0 1 68 4 0 I 68 4 0 1 68 4 O 't 68 4 0 1 68 4 O t 68 4 0 t 68 PROCESS INDICATORS 000000 O00OO0 000000 000000 000000 O000OO 000000 000000 000000 000000 OOOO00 O000OO O000OO O000OO 000000 . 000000 OOOO00 000000 00000'0 OOO000 000000 000000 OOO000 000000 000000 000000 000000 O0000O O00000 OOOO00 000000 00000~0 000000 Page DEPT $CF3 8240.000 0,000 8200.000 89,479 8i00,000 -999,250 8000.000 85.646 7900.000 93,996 780'0.000 125.074 7700.000 1 04. 326 7600, OOO i 07. 685 7500. 000 12 O. 341 7400,00'0 113.220 7300.000 1 04. 335 7200..000 92.06 0 CALI SE)CS GR 8. 500 0.000 8.486 .465 8.615 -999.250 8.832 i .893 8.598 .062 e.96o '20. 021 9.306 .267 12.411 I, 083 10. 043 3,505 10.277 .389 1"I , 002 -999.250 1'0. 857 3,.035 115.158 0.000 98.189 49.500 103.925 49.000 88.973 49.50.0 65.933 46.667 49.404 60.0'00 121. 525 53.167 1'16.397 50.00.0 265,624 51.333 205.241 55.833 136.663 56.833 115.193 59.333 DRTR RECORDS G4G'I SCAE TDIC ALT SCF1 O, 000 -.500 -.333 ,667 I . '167 · 667 3. O'O0 -4.66? .-4. ~)O:O -7.167 -3, -S. '000 O. '000 O. 000 89.002 91 ,173 89,673 94,828 117.440 I 03,447 1 05. 744 116,490 113.315 I 04.061 99.371 O.OOO 0 ..000 0. '-000 O. 00'0 O..000 O, 000 . 0...00 O 0 ,~OOO O, :.80 O 0, ~00'0 0..~00 Pag~ 0.000 0.000 -.012 88.166 .021 90.806 ,039 91.000 .009 94. 1 61 -.078 181.702 -, 026 1 03. 568 -.034 104.622 -,056 110,426 -,0'10 112.120 -. 067 -999,250 ,045 100,645 DEPT CALI GR SCF3 SDCS 01 7100.000 10.55:3 144.874 95.299 2.158 57,000 7000.000 10.17:3 117.24:3 82.219 5.:301 50.:3:3:3 6900 . 000 10. 674 1 09. 669 1 04.581 2.203 49. 000 6',900,000 10. 674 106. 057 1 O1 , 483 1 . 315 47,50.0 00, OOO 1'0. 256 95. 484 93,2'05 1 .296 47. 500 6600. 000 10.512 97.627 1 0,~. 294 2. 721 50.500 6500.000 I0.898 '123,312 105,267 .574 51.000 6400.,000 11.104 104.248 101,017 ,256 51.167 6300.000 11,285 128.895 103.400 ,295 52.333 6200. 000 10.903 116,168 -999. 250 -999. ;250 51 . 000 6,100,-000 10. 531 119. 350 112. 837 . 978 48,500 .' 6000 . OOO 10. 038 102. 999 116. 955 , 070 56.500 DATA RECORDS 04011 SCAE TDIC ALT SCFI Page 8 1 . 33:3 100. 880 O.OOO .020 101.403 -. 167 95.987 O.O00 , 114 97.213 -1 . 333 1 01 . 270 0.-:800 -. 054 98. 350 -4.167 100.528 0,900 -.031. 97.764 -,833 91 ,506 0.'000 -,045 89.539 -3.167 99.362 0.000 -,063 98.597 -, 500 1 04. 701 -1 .500 1 01 . 184 -4, O00 1 03. 041 :0.'000 -, 023 1 03,645 0.000 -. 01 I 1 00,298 .0..000 -. 006 1 02,566 -1 . 167 1 05,482 -1 ,667 11t .713 -4,667 116.76'1 0.0'00 -. 046 1 05.01 0 0.000 -. 022 11 O, 069 O.:OOO . 0.01 116 . 761 DEPT SCF3 5900,000 1 08. 762 5S00. OOO 1t7.416 5700. OOO -'9'99.25.0 5~00. OOO i i7. 036 5500. OOO -999.250 540'0. 000 1 i 7. 028 53.00. · 00 1 06. 874 5200. O00 I 12. 768 51 00. 000 I 1'6. 044 5000, .000 -999. 250 4900.000 -999.250 4800.:0:00 i i 7. 036 CALI SDCS 10.705 -999.250 9.8.01 I . 199 9.939 -999.250 9.840 .062 9.772 -999.250 1 O. 722 ,088 10. 449 2.415 1'0.214 I' .478 9.927 2.554 8.49 t -999.250 9. 547 -999.25O 9.866 :1 , 033 GR G1 132. 665 48. 167 148.844 48.500 184. 037 51 . 000 151 . 1t8 48.00'0 114.601 54. i 67 170.944 47. 333 91 . 035 50,000 132.737 50.333 'I 24.01 8 52.5.00 127,134 51 . OOO 109,'173 52,333 115.916 51.167 DRTR RECORDS G4G1 SCAR TDIC -1.167 -7.167 -4.500 -2.833 -4.333 -4.833 -.833 -7.333 -4,667 -2,667 -3,'167 ·-6,833 109.112 118.971 1 22,038 116,661 113.973 116,475 99.970 110.877 110.445 112.746 107.723 115.522 0,000 1,000 0.000 1 ,~)00 0 ,~)00 0,000 '0,000 . 0.000 1 .~'00 O. 000 ~0,800 O, :0'00 ALT ,000 .817 .019 ,0.04 -. 1 05 ,007 -. 07,0 -,038 -. 063 -, 058 -. o2s -, 028 SCFI 1 08. 737 120.808 121 .620 117,197 111.000 117.270 100,042 1 O8. 588 1 08.818 113.323 109,448 114.114 Page DEPT SCF3 CALl GR 4700.000 10,108 104 i32,687 6,755 52 4600,000 10.302 110 120.394 2.i27 51 4500,000 1-0,326 125 110,113 -999.250 53 4400.000 10.050 109 i14.836 1,968 52 4300..000 9.854 101 122.003 4.281 51 4200.000 10.156 102 112.951 .872 57 4100,000 10.773 99 118.063 .1~5 53 4000.000 10.531 '1'11 1i7,572 1.947 55 3900.000 11.027 113 121,881 ,503 51 3800.000 13,214 92 120,150 3.129 55 ,797 .333 .192 .833 .787 .500 ,976 ,639 ,833 .353 .667 ,559 ,833 ,162 ,833 ,535 .667 ,321 .167 D'ATA RECORDS G4GI SCAE TDIC ALT SCF1 2.000 ..... ,. , _ .............. _ ...... , i , , _. - _ - - 113,5~0 0.:000 -. 087 -6,167 119.358 O.OOO -1 ,833 1 09,651 0.000 -6,167 111,001 0,000 -. 056 -. 023 -. 051 Page 113. 579 114.379 -999.250 1 09.271 , 167 115.367 0..000 -, 059 1 09.895 -7,833 111 ,842 0.000 -, 016 110,484 -9,:000 118,432 ~0,000. -.008 118,530 114. 464 !0, ;000 -, 033 121.005 0.90'0 -. 017 -8,667 -4,833 112.064 12: O. 46,2 -,500 118,999 0,.000 -.'068 111 .301 t0 ** FILE TRAILER File name: HLS.O01 Maximum length: 974, TRAILER RECORDS Service name: Version #:SFMG File type: LO Next ?Jla: HLS. 0 02 89?01 ?04 Page 11 FILE HEADER **** File name: HLS.O02 Haximum length.:. 9?4. Service name: File type: LO Version #: SFMG Previou~ '¢ile: HLS,O01 Date: 89/01/04 M H E M CN FN COUN STAT SOH DATE AP LUH LUL EHG I [~I TN MRT RM MST RMF HFST RMC MCST EK8 EQF EGL LMF 8S~ BSQI BS2 BSD2 BS~ BSD~ CS~ CSDI CS2 CSD2 CS~ CSO~ BLi TLI I NFOR'MAT I ON RECORDS CONTENTS ARCO ALASKA, ~G-10 ...... KUPARUK RIVER UNIT ...... N. SLOPE ...................... L3~??O .......................... o~ ....................... oe/~6 6; .... ;; .................. 5810320!340~ .................. iiaiiiliiiIiliIliIiiiiiiii N. 'LO .. D, HCKA¥ IlIIIlItIllllIIlllIII IIleIIIiIlIlIllIlIllI IIIIlIIIIIIIlIIIiiIII IIIIlIIlIIlIlIllIIlII IllllIlIIIIIlIlIIlIlI IIlIIIIIIIIIIllIIlIlI IIIlIIIlIlIlllIIIlIII IIilliIlIIIlllIIlIllI lllIItIlIlIIlIIIIIIII IIlIIlIlIIIIIlIllllII IIIIIIlIllJIIIII A. LOWEN ~4' ;'' ;' ;'; .... ;"; ...... ; .... ;' ;' ': ...... ;' ;'" ;; ;';' ! - I II I I tIII II IIllII IlII I II IIlII I lit I 71 i 9! ' I III IIIlI It III IIIIII lllllllI t I IIIIII II 2 12 IlIIIIIItllllllIllIIlIIIIlIIIlIIIllIIIIIIIIlIIlIIIlI 3 IIiIIIIlIllIlIIIlIIIlIIIIIII~IIIIIIIIIIIlIIlliIllliiI 90 4 illiiIlIliIliIllllllIiIliliIiiliiilllilIiIlllIl, iill KB ...... i":":'"::":"":i':: ....... :':'"i']': ..... 0 172 ....... , ........ , ................... 8250 .................................................. IIIlllIIlIlIllllIllIIIIIIIlIItlIIlIIIlIlIIIIlIIlllIIIIii iIIIItlIlItll;lllIIlIelIIIIIllIIlIlIIlIIJIlIlIIIIlIIIIll IS IlililllIllII! 'II llIll lIII t IlIll II III Illlll 9 625 I. lllllllPtllllllltlllllIIIIl$11tlllllIIIIIllllillll 3783 ........................................ IIIIIllIIII I1'Sll I~111111 !1 II 11 I IIIIIII IIIlllI · I lllllllllllllllll 7640 000 I 1lllllIllIIlll41llltllllIIl'IIIlIIlIlllllllliltli UNIT DEGF OHMH DEGF OHHH DEGF OHMN DEGF FT FT FT IN FT IN FT tN FT iN FT IN FT IN FT FT FT TYPE CATG SIZE 0 0 26, 0 '0 28 0 O 28 0 0 12 0 0 2 0 0 0 0 0 4 0 0 8 0 0 16 0 0 0 0 32 0 0 40 0 :0 40 0 1 4 0 2 4 0 2 4 0 2 4 0 2 4 0 2' 4 El 2 4 O 3 0 3 6 O .3 6 0 3 0 3 6 0 3 0 3 0 3 0 3 0 3 0 3 0 ;3 4 0 3 4 CODE 65 65 65 65 65 65 65 65 65 65 65 65 65 65 65 65 65 65 65 65 65; 65 65 65 65 65 65 65 65 65 65 65 65 68 Page ERROR 12 COMMENT RECORDS Pag~ THIS IS THE REPEAT SECTION FOR FULL WAVE SONIC LOG. DATA FORMAT ~** ENTRY BLOCKS ENTRY . · TYPE 1 2 4 9 1'1 16 0 SIZE SPECIFICATIONS CODE 66 66 79 66 66 65 66 66 66 Page ~** ENTRY'BLOCK LEGEND TYPE DESCRIPTION I Data record type (.1 i 1 r og c.a ecord type number ) 2 Datum sgeci?ication bl ock type 3 Data ?tame size ( b~tes ) 4 Up / Down ~lag ( 1 = up, 255'= down, 0 = neither 5 Optical log depth scale ( 1 = ~eet, 255 = meters 8 Frame spacing .( depth difference b~tween ~rames 9 Units o~ ?tame spacing '1 Maximum ~ramez per record 6 Datum specification block sub-t~pe 0 Terminator ~ no more entries ) ' ) 0 = time DATA FORI'IAT SPEC I F I CAT IONS DATUM SPEC~IFICATION BLOCKS MNEM SERVICE SERVICE API API AP1 APl FILE ID ORDER # UNIT LOQ TYPE CLASS MOD 8 DEPT FWS L36770 CALl FWS L36770 QR FWS L36770 G4Gt FWS L36770 SCAE FWS L36770 TDIC FWS L36770 ALT FWS L367?O- SCF! FWS~ L36770 SCF3 FWS L36770 SDCS FWS~ L36770 ~$ FWS L36770 FT 62 O 0 2 2 IN 62 280 1 2 2 GAPI 62 310 1 2 2 DB 62 980 2t 2 2 US/F 62 970 70 2 2 US 62 52 4 2 2 62 980 1 2 2 US?F 62 50 3 2 2 US?F 62 50 3 2 2 62 50 3 2 2 DB 62 980 22 2 2 PRO # SIZE LVL SMPL RC 4 0 I 68 4 0 1 68 4 0 1 68 4 0 I 68 4 0 4 68 4 0 t 68 4 0 { 68 4 0 t 68 4 0 I 68 4 0 1 68 4 0 1 68 PROCESS INDICATORS ~000000 OOO000 000000 000000 OOOO00 000000 000000 O0000O 000000 000000 000000 000000 00000'0 000000 000000 . 000000 000000 000000 000000 800~000 000000 000000 000000 000000 000000 8OOO00 OOOO00 O00000 O000-O0 000000 O00000 O00000 000000 Page 1S DATA DEPT CALI GR G4G1 SCF3 SDCS 8230,000 :8,138 115,158 -2.5~00 92. 251 ,874 O,OOO 8200,.000 8.4e6 98,189 -2.000 -999,250 -999,2.50 49. 833 81 00,000 8,615 1 03,925 O,OOO 96, .073 ,983 49, OOO 8.000,000 e,832 88,973 1 ,5~00 93,253 1 , 598 50,50.0 7900,000 8. 598 65. 933 4 95,5t 7 . 147 46,667 7'80'0, .000 8,96~0 49.404 -, 66:7 ;86,245 -999,250 60, ~000 7700. 000 9,306 12'1,525 5,167 -999,250 -999.250 54,0.00 RECORDS SCAE TDIC ALT SCF1 91 . 126 '0.'00.0 90.415 0.900 Page 'I6 -.029 89,777 ..0'05 89,485 93,850 0,'000 -.040 93.292 91 . 387 0.~000 -, 00'1- 88. 733 95.265 :0.i0'00 97,620 O, ~00'0 -.017 95,922 · 301 -999. 250 98,646 '0,000 · -. 0!8 1'08.985 iTRAILER RECORDS ********************** ** FILE TRAILER File name~ HLS,~92 Version Haximum length: 9?4. ' File type~ LO Next ~ile~ Date= 89/0!/04 Page ************************ :** TAPE TRAILER .,*.,* Service name: HLS Next tape~ *********************** ~** R~EL TRAILER ***$ *********************** Service name.t HLS Next reel~.: Date: 90/08/05 Origin: PLS Tape name.I H9.04't73 Continuation Commen%s~ Date: 90/i08/15 Origin: PL'S Reel name: H9~41.73 Continuation #: Comments: HL$'FORHATZON EVALUATION SYGTEH$ -- HEADQUARTERS