Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
185-282
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, September 15, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3A-14 KUPARUK RIV UNIT 3A-14 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/15/2025 3A-14 50-029-21490-00-00 185-282-0 W SPT 5998 1852820 3000 1850 1850 1800 1800 35 325 325 300 REQVAR P Austin McLeod 8/4/2025 Two year to MAIP. AIO 2C.084. 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 3A-14 Inspection Date: Tubing OA Packer Depth 380 3300 3150 3080IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM250804190717 BBL Pumped:2.5 BBL Returned:2.3 Monday, September 15, 2025 Page 1 of 1 9 9 9 9 9 9 9 999 999 9 9 9 9 9 Two year to MAIP AIO 2C.084 James B. Regg Digitally signed by James B. Regg Date: 2025.09.15 12:32:50 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, July 23, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3A-14 KUPARUK RIV UNIT 3A-14 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/23/2025 3A-14 50-029-21490-00-00 185-282-0 W SPT 5998 1852820 3000 1800 1800 1800 1800 100 200 200 200 REQVAR P Adam Earl 6/3/2025 MIT-IA tested as per AIO 2C.084 to max ant. Inj. PSI 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 3A-14 Inspection Date: Tubing OA Packer Depth 700 3330 3230 3200IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE250604091330 BBL Pumped:2.2 BBL Returned:2.1 Wednesday, July 23, 2025 Page 1 of 1 1 Regg, James B (OGC) From:NSK DHD Field Supervisor <n2238@conocophillips.com> Sent:Sunday, August 13, 2023 6:20 PM To:Regg, James B (OGC); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (OGC); Wallace, Chris D (OGC) Cc:Well Integrity Specialist CPF1 & CPF3 Subject:CPAI 10-426 form for Non-witnessed shut in test on 3A-14 on 8/13/23 Attachments:MIT KRU 3A-14 SI TEST 08-13-23.xlsx Please see the attached 10‐426 form for Non‐witnessed shut in MIT‐IA that was performed at 3A pad on 8/13/23. Please let me know if you have any questions or concerns. Thank you, Shelby Sumrall / Bruce Richwine DHD Field Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659‐7022 Cell phone: (907) 943‐0167 CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. KRU 3A-14PTD 1852820 Submit to: OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD 1852820 Type Inj N Tubing 1548 1560 1553 1552 Type Test P Packer TVD 5998 BBL Pump 2.1 IA 223 3300 3200 3185 Interval V Test psi 3000 BBL Return 1.9 OA 10 13 13 14 Result P Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result Well Pressures:Pretest Initial 15 Min.30 Min.45 Min.60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes)4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Notes:MITIA to maximum anticipated injection pressure per AIO 2C.084 Notes: 3A-14 Notes: Notes: Notes: ConocoPhillips Alaska Inc, Kuparuk / KRU / 3A Pad Beck / Casey 08/13/23 Form 10-426 (Revised 01/2017)2023-0813_MIT_KRU_3A-14 J. Regg; 10/12/2023 From:Wallace, Chris D (CED) To:AOGCC Records (CED sponsored) Subject:FW: KRU 3A-14 (PTD 185-282) Report of suspect IA pressure decrease Date:Thursday, November 18, 2021 10:53:36 AM Attachments:3A-14.pdf 3A-14 90 day TIO trend 11.10.21.pdf From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Wednesday, November 10, 2021 11:08 AM To: Wallace, Chris D (CED) <chris.wallace@alaska.gov> Cc: Earhart, Will C <William.C.Earhart@conocophillips.com> Subject: KRU 3A-14 (PTD 185-282) Report of suspect IA pressure decrease Chris, KRU 3A-14 (PTD 185-282) is exhibiting an unexplained very slow IA pressure decrease. The plan is for DHD to perform standard diagnostics including an MITIA and MITOA. After the diagnostic testing the annulus pressures will be manipulated and the well will be placed on a 90 day monitor period due to allow for the pressure decrease to be observed and allow for additional pressure manipulations if needed. The proper paperwork will be submitted upon conclusion of the monitor period and once a plan forward has been developed. A 90 day TIO trend and wellbore schematic are attached. Please let me know if you disagree or have any questions with the plan. Regards, Jan Byrne Well Integrity Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7224 Cell phone: (808) 345-6886 Casing Strings Casing Description CONDUCTOR String O... 16 String ID ... 15.062 Top (ftKB) 31.0 Set Depth (f... 107.0 Set Depth (TVD) ... 107.0 String Wt... 62.50 String ... H-40 String Top Thrd WELDED Casing Description SURFACE String O... 9 5/8 String ID ... 8.921 Top (ftKB) 30.7 Set Depth (f... 3,680.0 Set Depth (TVD) ... 3,180.2 String Wt... 36.00 String ... J-55 String Top Thrd BTC Casing Description PRODUCTION String O... 7 String ID ... 6.276 Top (ftKB) 30.0 Set Depth (f... 7,841.3 Set Depth (TVD) ... 6,429.4 String Wt... 26.00 String ... J-55 String Top Thrd BTC Tubing Strings Tubing Description TUBING WO String O... 2 7/8 String ID ... 2.441 Top (ftKB) 23.9 Set Depth (f... 7,221.8 Set Depth (TVD) ... 5,927.3 String Wt... 6.50 String ... L-80 String Top Thrd EUE-8rd Completion Details Top (ftKB) Top Depth (TVD) (ftKB) Top Incl (°)Item Description Comment Nomi... ID (in) 23.9 23.9 0.09 HANGER FMC TUBING HANGER 2.441 491.4 491.4 0.39 NIPPLE CAMCO 'DS' LANDING NIPPLE 2.312 7,199.1 5,909.9 36.79 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY, SPACED OUT 6.45' 2.410 Tubing Description STACK PACKER String O... 2 7/8 String ID ... 2.441 Top (ftKB) 7,206.1 Set Depth (f... 7,304.2 Set Depth (TVD) ... 5,994.3 String Wt... 6.50 String ... L-80 String Top Thrd EUE-8rd Completion Details Top (ftKB) Top Depth (TVD) (ftKB) Top Incl (°)Item Description Comment Nomi... ID (in) 7,206.1 5,914.3 35.26 PBR BAKER 80-32 20' PBR 3.250 7,231.4 5,935.1 35.53 PACKER BAKER FHL PACKER 2.450 7,249.7 5,950.1 35.72 NIPPLE HALLIBURTON 'X' NIPPLE 2.313 7,295.3 5,987.2 36.19 Mule Shoe Baker Mule shoe pup down to OD of 3.51", 3-1/2" EUE box 2.930 Tubing Description TUBING Original String O... 2 7/8 String ID ... 2.441 Top (ftKB) 7,297.3 Set Depth (f... 7,379.2 Set Depth (TVD) ... 6,054.5 String Wt... 2.87 String ... J-55 String Top Thrd EUE8rd Completion Details Top (ftKB) Top Depth (TVD) (ftKB) Top Incl (°)Item Description Comment Nomi... ID (in) 7,297.3 5,988.7 36.21 PBR BAKER SHEARED PBR 3.625 7,308.9 5,998.1 36.33 PACKER BAKER HB PACKER w/XO 2.890 7,346.2 6,028.0 36.72 NIPPLE CAMCO 'D' NIPPLE w/2.25" PROFILE 2.250 7,378.3 6,053.7 37.05 SOS BAKER SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top Depth (TVD) (ftKB) Top Incl (°)Description Comment Run Date ID (in) 7,734.0 6,340.4 34.06 FISH JUNK on Bottom BALL to Shear had 5' Aluminum Tail 12/9/1985 0.000 Perforations & Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB)Zone Date Shot Dens (sh...Type Comment 7,474.0 7,494.0 6,130.0 6,145.9 A-4, A-3, 3A-14 1/11/1986 4.0 IPERF 90 deg ph; 4" HJ II Csg Gun 7,506.0 7,550.0 6,157.3 6,191.0 A-2, 3A-14 1/11/1986 4.0 IPERF 90 deg ph; 4" HJ II Csg Gun 7,580.0 7,586.0 6,214.6 6,219.4 A-1, 3A-14 1/11/1986 4.0 IPERF 90 deg ph; 4" HJ II Csg Gun Notes: General & Safety End Date Annotation 3/22/2008 NOTE: WAIVERED WELL: T x IA COMMUNICATION, WI ONLY 2/19/2009 NOTE: View Schematic w/ Alaska Schematic9.0 Comment SSSV: NIPPLEWell Config: - 3A-14, 7/11/2013 1:27:40 PM Schematic - Actual TD, 7,855 PRODUCTION, 30-7,841 FISH, 7,734 IPERF, 7,580-7,586 IPERF, 7,506-7,550 IPERF, 7,474-7,494 SOS, 7,378 NIPPLE, 7,346 PACKER, 7,309 PBR, 7,297 Mule Shoe, 7,295 NIPPLE, 7,250 PACKER, 7,231 PBR, 7,206 SEAL ASSY, 7,199 GAS LIFT, 7,144 SURFACE, 31-3,680 NIPPLE, 491 CONDUCTOR, 31-107 HANGER, 24 Annotation Last Tag: SLM Depth (ftKB) 7,665.0 End Date 2/5/2012 Annotation Rev Reason: Pull Catcher/Plug/Ball/Rod, Glv c/o Last Mod ... haggea End Date 7/10/2013 KUP KB-Grd (ft) 36.21 Rig Release Date 12/11/1985 Annotation Last WO: End Date 6/20/2013 3A-14 H2S (ppm) Date Mandrel Details S... N...Top (ftKB) Top Depth (TVD) (ftKB) Top Incl (°)Make Model OD (in)Serv Valve Type Latch Type Port Size (in) TRO Run (psi)Run Date Com... 1 7,144.4 5,866.1 36.77 CAMCO KBMG-M-2 1 GAS LIFT DMY BK 0.000 0.0 7/2/2013 ... TD Act Btm (ftKB) 7,855.0 Well Attributes Wellbore API/UWI 500292149000 Field Name KUPARUK RIVER UNIT Well Status INJ Max Angle & MD Incl (°) 45.42 MD (ftKB) 4,400.00 MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Brian Bixby Petroleum Inspector Well Name KUPARUK RIV UNIT 3A-14 Insp Num: mitBDB210825103433 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, August 26, 2021 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3A-14 KUPARUK RIV UNIT 3A-14 Src: Inspector Reviewed By: P.I. Supry (jr-9— Comm API Well Number 50-029-21490-00-00 Inspector Name: Brian Bixby Permit Number: 185-282-0 Inspection Date: 8/24/2021 >, Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Tubing 98 D PTD I--- — 1852820 2890 " - Type Test SPT 'Test -- — si 1500 1500 BBL Pumped: 1.3 BBL - Returned: --------- 1.3 Interval F 4vRTST �p/F P - Notes: Pretest Initial 15 Min 30 Min 45 Min 60 Min Tubing 2890 2890 ' j- - 2890 2890 " IA 440 2000 1920 1900 ' --1 ! OA --- -- F-110 - . -- - --1 280- 280 _ 0 LN Thursday, August 26, 2021 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,December 07,2017 TO: Jim Regg Supervisor le-7 �)�I SUBJECT: Mechanical Integrity Tests P.I.Pci !JI n gy CONOCOPHILLIPS ALASKA,INC. 3A-14 FROM: Guy Cook KUPARUK RIV UNIT 3A-14 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry J�" NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3A-14 API Well Number 50-029-21490-00-00 Inspector Name: Guy Cook Permit Number: 185-282-0 Inspection Date: 12/5/2017 -• Insp Num: mitGDC171205172446 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3A-14 -TypeInj W TVD 5998 ' Tubingl 2850 2850 - 2850 - 2850 - F PTD 1852820 Type Test' SPT Test psi 1500 IA 940 2000 - 1950 - 1935 BBL Pumped: 0.7 BBL Returned: 0.5 - OA 250 360 - 360 360 Interval 4YRTST - P/F P Notes: Little Red Services pump truck used for testing. SCANNED i? 0 i; • Thursday,December 07,2017 Page 1 of 1 S • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday,August 29,2013 TO: Jim Regg P.I.Supervisor --Keic;q(?4 113 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3A-14 FROM: Bob Noble KUPARUK RIV UNIT 3A-14 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry:732_ NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3A-14 API Well Number 50-029-21490-00-00 Inspector Name: Bob Noble Permit Number: 185-282-0 Inspection Date: 8/25/2013 Insp Num: mitRCN130826140702 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min I 7 Weill 3A-I4 - -"Type Inj w 1TVD 1 35° 1 6003 lA 1 2134 - I- 2060 2046 .1 PTD 1852820 - Type Test SPT Test psi 1501 ' OA , 180 390 • 390 ----r — H— Interval IINITAL _ P/F P -/',Tubing 2850 . 2850 1. 2850 1 2850 - , i Notes: SCANNED DEC 1 ., Thursday,August 29,2013 Page 1 of 1 f ' STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon Repair w ell p- Rug Perforations r Perforate r Other Alter Casing `.`f Pull Tubing gro Stimulate-Frac r Waiver Time Extension r- Change Approved Program rOperat. Shutdown r Stimulate-Other c"- Re-enter Suspended Well 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r _ 185-282 • 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-21490-00 ' 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25631 3A-14 • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: • Total Depth measured 7855 feet Plugs(measured) none true vertical 6441 feet Junk(measured) 7734 Effective Depth measured 7746' feet Packer(measured) 7231, 7309 true vertical 6350' feet (true vertical) 5935,5998 Casing Length Size MD TVD Burst Collapse CONDUCTOR 76 16 107 107 SURFACE 3649 9.625 3680 3180 PRODUCTION 7811 7 7841 6429 I Perforation depth: Measured depth: 7474'-7494',7506-7550',7580'-7586 RECEIVED True Vertical Depth: 6130'-6146',6157'-6191',6215'-6219' JUL. 15 2013 Tubing(size,grade,MD,and TVD) 2.875, L-80, 7222 MD, 5927 ND 4Qc C Packers&SSSV(type,MD,and ND) PACKER-BAKER FHL PACKER @ 7231 MD and 5935 TVD �d iii PACKER-BAKER HB PACKER W/XO @ 7309 MD and 5998 TVD NIPPLE-CAMCO'DS' NIPPLE @ 491 MD and 491 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): not applicable SCANNED NOV' 0 6 2013 Treatment descriptions including volumes used and final pressure: ,rl�.Ai,l� 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development f Service Stratigraphic 16.Well Status after work: Oil r Gas r WDSPL Daily Report of Well Operations XXX GSTOR ( " WINJ R"' WAG E GINJ r SUSP r SPLUG ;!• 17.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: 313-183 Contact Jacob Voss @.265-6935 Email Jacob.Voss(c�conocophillips.com Printed Name ro,v7 Title Wells Engineer Signature Phone:265-6935 Date --- V I/P 3 RBDMS JUL 2 3 2013 Form 10-404 Revised 10/2012 -?-/3 4 "e ) Submit Original Only 41114 KUP • 3A-14 ConocoPhillips Well Attributes Max Angle&MD TO AL ask;.iih;;_ Wel!bore APUUWI Field Name Well Status Inc!(°) MD(ftKB) Act Btm(ftKB) 500292149000 KUPARUK RIVER UNIT INJ 45.42 4,400.00 7,855.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date "' SSSV:NIPPLE Last WO: 6/20/2013 36.21 12/11/1985 Well Confi g'-3A-14 7/1120131 21_40 PM Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM 7,665.0 2/5/2012 Rev Reason:Pull Catcher/Plug/Ball/Rod,Glv do haggea 7/10/2013 Strings trings HANGER,24 Casing Dg trion String 0... String ID...Top(ftKB) Set Depth(t...Set Depth(ND)...String Wt..String String Top Thrd I CONDUCTOR 16 15.062 31.0 107.0 107.0 62.50 H-40 WELDED Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String String Top Thrd - - SURFACE 95/8 8.921 30.7 3,680.0 3,180.2 36.00 J-55 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String... String Top Thrd PRODUCTION 7 6.276 30.0 7,841.3 6,429.4 26.00 J-55 BTC q Tubing Strings n i __ammo Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt..String... String Top Thrd TUBING WO 2 7/8 2.441 23.9 7,221.8 5,927.3 6.50 L-80 EUE-8rd --.1 Completion Details __ Top Depth Nomi... 1 (ND) Top Intl Top(ftKB) (ftKB) (°) Item Description Comment ID(in) 23.9 23.9 0.09 HANGER FMC TUBING HANGER 2.441 CONDUCTOR,_ 31-1n7 491.4 491.4 0.39 NIPPLE CAMCO'DS'LANDING NIPPLE 2.312 - 7,199.1 5,909.9 36.79 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY,SPACED OUT 6.45' 2.410 Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd NIPPLE,491 STACK PACKER 27/8 2.441 7,206.1 7,304.2 5,9943 6.50 L-80 EUE-8rd lir Completion Details Top Depth (ND) Top Intl Noml... Top(ftKB) (ftKB) (°) Item Description Comment ID(In) 7,206.1 5,914.3 35.26 PBR BAKER 80-32 20'PBR 3.250 1 7,231,4 5,935.1 35.53 PACKER BAKER FHL PACKER 2.450 7,249.7 5,950.1 35.72 NIPPLE HALLIBURTON'X'NIPPLE 2.313 SURFACE,_ ,4 I 7,295.3 5,987.2 36.19 Mule Shoe Baker Mule shoe pup down to OD of 3.51",3-1/2"EUE box 2.930 31-3,680 Tubing Description String 0... String ID...Top(ftKB) Set Depth(f.,,Set Depth(ND)...String Wt...String...String Top Thrd LA TUBING Original 2 7/8 2.441 7,2973 7,379.2 6,054.5 2.87 J-55 EUE8rd Completion Details - - .a GAS LIFT, Top Depth 7.144 (TVD) Top loci Nomi... a Top(11KB) (ftKB) (°l Item Description Comment ID(in) 7,297.3 5,988.7 36.21 PBR BAKER SHEARED PBR 3.625 7,308.9 5,998.1 36.33 PACKER BAKER HB PACKER w/XO 2.890 7,346.2 6,028.0 36.72 NIPPLE CAMCO'D'NIPPLE w/2.25"PROFILE 2.250 7,378.3 6,053.7 37.05 SOS BAKER SHEAR OUT SUB 2.441 SEAL ASSY, 7,199 - 'in Hole Wireiine retrievable plugs,valves,pumps,fish,etc.) PBR,7,206- Top Depth I (TVD) Top Intl Top(1KB) (ftKB) (°) Description Comment Run Date ID(in) __i- '11-: 7,734.0 6,340.4 34.06 FISH JUNK on Bottom BALL to Shear had 5'Aluminum Tail 12/9/1985 0.000 PACKER,7.231 Perforations&Slots Shot J Top(ND) Btm(ND) Dens Top(ftKB)Btm(ftKB) (ftKB) (ftKB) Zone Date (.h.° Type Comment 7,474.0 7,494.0 6,130.0 6,145.9 A-4,A-3,3A-14 1/11/1986 4.0 IPERF 90 deg ph;4"HJ II Csg Gun NIPPLE,7,250 ------- 1° 7,506.0 7,550.0 6,157.3 6,191.0 A-2,3A-14 1/11/1986 4.0 IPERF 90 deg ph;4"HJ II Csg Gun 7,580.0 7,586.0 6,214.6 6,219.4 A-1,3A-14 1/11/1986 4.0 IPERF 90 deg ph;4"HJ II Csg Gun Notes:General&Safety End Date Annotation _ 3/22/2008 NOTE:WAIVERED WELL:T x IA COMMUNICATION,WI ONLY L _A 2/19/2009 NOTE:View Schematic w/Alaska Schematic9.0 Mule Shoe, 7,295 PER.7.297 PACKER,7,309 1 NIPPLE.7,346 SOS.7,378 ...f L..`_ IPERF, 7,474-7,494 I Mandrel Details Top Depth Top Port IPERF, >-` g (ND) Intl OD Valve Latch Size TRO Run 7.50-7.590 N...Top(ftKB) (ftKB) (°) Make Model (in) Sery TYPe Type 6n) (Psi) Run Date Corn... 1 7,144.4 5,866.1 36.77 CAMCO KBMG-M-2 1 GAS LIFT DMY BK 0.000 0.0 7/2/2013 IPERF, 7,580.7686 _. FISH,7,734 • PRODUCTION, 30-7,841 • TD,7,855 • ConocoPhillips Time Log & Summary Wenview Web Reporting Report Well Name: 3A-14 Rig Name: DOYON 141 Job Type: RECOMPLETION Rig Accept: 6/17/2013 8:00:00 PM Rig Release: 6/20/2013 7:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T <Comment 06/17/2013 24 hr Summary Move rig, accept rig, R/U to kill well. 00:00 01:30 1.50 0 0 MIRU MOVE MOB P PJSM w/rig crew and PEAK truck drivers; Move pipeshed, stage on pad, load rockwasher, hook up to complexes. 01:30 05:00 3.50 0 0 MIRU MOVE MOB P Move Rockwasher and complexes to pad 3A and return to pad 1G. 05:00 06:00 1.00 0 0 MIRU MOVE MOB P Hook up pipesheds, move sub base off well 1G-10B. 06:00 10:00 4.00 0 0 MIRU MOVE MOB P Move Sub and pipeshed from 1G-10B to 3A-14. 10:00 12:00 2.00 0 0 MIRU MOVE MOB P Remove riding shacks, yolk and Spreader Beam, Spot Sub over well 3A-14. 12:00 15:00 3.00 0 0 MIRU MOVE MOB P PJSM, Lay Mats for power pack, spot same. 15:00 16:00 1.00 0 0 MIRU MOVE MOB P Lay Herculite and Mats for Rockwasher and pipesheds, spot same. 16:00 20:00 4.00 0 0 MIRU MOVE MOB P PJSM,Work on rig acceptance checklist, calibrate and test Gas Alarms. (RIG ACCEPTED 20:00) 20:00 00:00 4.00 0 0 MIRU MOVE RURD P PJSM, Hook up line to freeze protect, Install circulating flanges on tree&IA, clean after rig move,take on 290 bbls 9.8 Brine to be watered back to 9.6 ppg, R/U scaffold, prime both mud pumps. Tubing=1200 psi IA=800 psi, OA=230 psi. 06/18/2013 Kill well, N/D tree, N/U and test BOPE. R/U&pull tubing hanger. 00:00 00:30 0.50 0 0 MIRU MOVE PRTS P PJSM, Test Mud pumps and lines to 3500 psi. 00:30 01:00 0.50 0 0 MIRU MOVE RURD P R/U Lubricator,test to 2000 psi. 01:00 02:00 1.00 0 0 MIRU WHDBO RURD P Pull BPV. R/D Lubricator. 02:00 04:00 2.00 0 0 MIRU MOVE RURD P R/U Tiger Tank, Hard line and choke house. 04:00 06:00 2.00 0 0 MIRU WELCTL KLWL P Test CMT line and Hard line to tiger tank to 2500 psi, open tubing and IA to closed choke, bleed off trapped gas to 0 psi on both, R/U Circ out freeze protect, pump down tubing take return out IA to tiger tank. initial 1.5 bpm,400 psi, stage up to pump to 3 bpm,600 psi. Pumped 285 bbls of 9.6 brine. Pave 1 of 4 Time Logs •' Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 07:00 1.00 0 0 MIRU WELCT[OWFF P Monitor well for 30 min. (Static)R/D Circulating lines. 07:00 08:00 1.00 0 0 MIRU WHDBO RURD P Set BPV,test 1000 psi from below, R/D Circ lines and scaffolding. 08:00 09:00 1.00 0 0 MIRU WHDBO NUND P PJSM, N/D tree and adapter flange, dress tubing threads, install blanking plug. 09:00 12:00 3.00 0 0 MIRU WHDBO NUND P PJSM, N/U adapter flange,drilling spool, BOPE. 12:00 13:00 1.00 0 0 MIRU WHDBO NUND P PJSM, Continue N/U BOPE 13:00 14:45 1.75 0 0 MIRU WHDBO RURD P PJSM, C/O Upper VBR to 2.875"x 5" 14:45 16:15 1.50 0 0 MIRU WHDBO RURD P PJSM, R/U to test BOPE,verify lower ram clearance(Good). 16:15 21:30 5.25 0 0 MIRU WHDBO BOPE P PJSM,Test BOPE w/2 7/8"test joint. 250 psi low/4000 psi high for 5 minutes:#1 top pipe rams, valves 1,12,13,14 and manual kill;#2 upper IBOP, HCR kill,valves 9,11;#3 Lower IBOP,valves 5,8,10;#4 Dart valve,Valves 4,6,7;#5 Floor valve and valve 2;#6 HCR choke,4"kill line DEMCO valve;#7 Manual choke valve, HCR kill;#8 annular preventer; #9 Lower pipe rams;#10 Blind Rams,valve 3.Accumulator: system pressure 3000 psi,after clsed 1800 psi,200 psi attained 45 sec, full pressure attained 178 sec, nitrogen bottle average 2025 psi. Test witness waived by Bob Noble AOGCC. 21:30 22:00 0.50 0 0 MIRU WHDBO RURD P R/D BOPE test equipt, B/D Choke manifold, kill&choke lines. 22:00 23:30 1.50 0 0 COMPZ RPCOM RURD P PJSM, Pull blanking plug,drain out stack, pull BPV. 23:30 00:00 0.50 0 0 COMPZ RPCOM OWFF P Monitor well, 30 minutes dead. 36/19/2013 Pulled completion, L/D tubing. Bad tubing cut, came out with seal assembly from PBR at 7304'MD. P/U new completion and RIH t/jt#228. 00:00 01:00 1.00 0 7,304 COMPZ RPCOM THGR P PJSM, Screw into hanger w/landing joint, B.O.L.D.S. 01:00 02:00 1.00 7,304 7,276 COMPZ RPCOM THGR P PJSM, Pull Hanger to rig floor, P/U 69k, L/D Tubing Hanger and Landing Joint. R/U casing equipt and control line spooler. Monitor well on trip tank. 02:00 02:45 0.75 7,276 7,276 COMPZ RPCOM CIRC P PJSM, R/U Reverse circulate 2 tubing volumes @ 2 bpm,350 psi, R/D Circ. lines, Monitor well. 02:45 05:45 3.00 7,276 4,156 COMPZ RPCOM PULL P PJSM, POOH L/D 2 7/8"tubing. L/D SSV and control line spooler, 104 joints of tubing. 05:45 06:45 1.00 4,156 4,156 COMPZ RPCOM SVRG P Service drawworks and top drive. 1t?f4 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:45 09:30 2.75 4,156 0 COMPZ RPCOM PULL P Continue to POOH and L/D 2-7/8", L/D 234 joints, 1 GLM, 1 PBR w/ Bull nose. 30 SS bands. Fill actual 18.6 bbl, calculated 17.2 bbl. (Cut joint not cut all the way through, cut at 15.76'from top of joint&and 15.09'from bottom of joint) 09:30 10:45 1.25 0 0 COMPZ RPCOM PULD P Clear and clean rig floor, un-load pipeshed. 10:45 12:00 1.25 0 0 COMPZ WELLPF OWFF P PJSM, stage tree in cellar, Prep 2-7/8"tubing and pups in pipeshed. (Monitor well on TT, no gain- no loss) 12:00 15:00 3.00 0 0 COMPZ WELLPF OTHR X PJSM, Monitor well on tri p tank, Pressure wash rig floor, iron roughneck, pits, MP2, mobilize tools to rig floor, Generate adjusted completion running order, organize pipeshed for new running order per engineer. New tools mobilized to location and put into running order. 15:00 00:00 9.00 0 7,286 COMPZ WELLPF RCST P PJSM and RIH w/2-7/8"completion per detail t/jt#228. Make up circ head on jt#229 and prepare to locate. P/U 67k, S/O 60k, Calc disp=16.95 bbl,Actual disp=17.51 bbl. 36/20/2013 Land completion, circ, PT tbg&annulus, N/D BOPE, N/U tree, freeze protect. release rig. 00:00 01:15 1.25 7,286 7,299 COMPZ RPCOM RCST P M/U Jt 229 circ 1 bpm, 100 psi @ 7294' MD, Slack off,tag up @ 7306' MD, P/U 9', S/O w no pump,tag @ 7306'MD, P/U to 7290'MD, break circ @ 2 bpm, 300 psi, S/O observed psi increase,tag 7305.5'MD, bleed off pump, P/U to 7299' MD. 01:15 01:45 0.50 7,299 7,299 COMPZ RPCOM CRIH P Spot 10 bbls inhibited brine around packer,2 bpm,400 psi. 01:45 02:30 0.75 7,299 COMPZ RPCOM PACK P P/U to 7294' MD,drop 1.5"rod ball, S/O to 7304' MD, press up to 2500 psi,set packer, pick up, saw shear @ 76k, P/U 5', slack off and tag up on packer, confirm with 5k set down. 02:30 03:30 1.00 COMPZ RPCOM HOSO P Space out L/D 3 joints, pick up 6.06' &8.17'space out pup joints. P/U joint 227, RIH, M/U tubing hanger and landing joint. R/U Circ equipt. P/U=67k, S/O=60k. 03:30 05:00 1.50 COMPZ RPCOM CRIH P Reverse in 9.6 ppg inhibited brine (1%CRW 132)down 2 7/8"x 7" annulus @ 4 bpm, 780 psi. pump 200 bbls followed by 50 bbls 9.6 ppg brine. 05:00 05:30 0.50 0 COMPZ RPCOM HOSO P Land Hanger, RILDS. , ...T � ter .... 4 Time Logs S Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 05:30 08:15 2.75 0 0 COMPZ RPCOM PRTS P Test tubing to 3500 psi, record on chart for 15 min, bleed tbg to 2500 psi,test 2 7/8"x 7"annulus to 3500 psi for 30 min, record on chart, bleed IA to 0 psi, bleed tbg to 0 psi, ramp up IA,shear SOV @ 2800 psi, bleed off IA&tbg to 0 psi. 08:15 08:45 0.50 0 0 COMPZ RPCOM OWFF P Monitor well 30 min. 08:45 09:00 0.25 0 0 COMPZ RPCOM SEQP P Suck out stack,set BPV 09:00 09:30 0.50 0 0 COMPZ WHDBO PRTS P Test BPV from below to 1000 psi, record on chart. 09:30 11:00 1.50 0 0 COMPZ WHDBO NUND P PJSM, N/D BOPE&adapter flange. 11:00 12:00 1.00 0 0 COMPZ WHDBO SEQP P Dress well head, N/U adapter flange. 12:00 15:30 3.50 0 0 COMPZ WHDBO PRTS P PJSM, Continue N/U adapter and tree,test hanger void 250/5000 psi for 15 min, pull BPV, install TWC, fill tree w/diesel and test same 250/5000 psi for 15 min, pull TWC, record on chart. 15:30 17:00 1.50 0 0 COMPZ WHDBO FRZP P PJSM, R/U LRS to freeze protect, PT lines to 2500 psi, pump 85 bbls diesel freeze protect down IA, 1.25 bpm,450 psi. 17:00 18:15 1.25 0 0 COMPZ WHDBO FRZP P B/D lines, U-Tube well, install BPV, secure tree. 18:15 19:00 0.75 0 0 DEMOB MOVE DMOB P Offload rock washer&clean same. (Rig release @ 19:00 hrs)Break containments and RDMO. 3A-14 Pre and Post Rig Workover Well Work Summary DATE SUMMARY • • 4/18/2013 PRE RWO: T-POT (PASSED)T-PPPOT(PASSED) IC-POT(PASSED) IC-PPPOT(PASSED) MIT- OA(PASSED) FUNCTIONED LDS ALL NORMAL. 4/20/2013 LOCKED OUT SSSV @ 1797' RKB. PULLED CA-2 PLUG f/D NIPPLE. @ 7353' RKB. MEASURED BHP @ 7518' RKB: 3413 PSI. IN PROGRESS. 4/21/2013 SET CA-2 PLUG IN D NIPPLE @ 7353' RKB. SET 2.27" CATCHER @ SAME (OAL 83"). MIT TBG 3500 PSI, PASSED. PULLED DV @ 7260' RKB. READY FOR BPV. 6/14/2013 RIH WITH STRING SHOT, CCL TO MIDDLE OF STRING SHOT: 5', CCL STOP DEPTH 7280', STRING SHOT FIRED @ 7285', 5'STRING.SHOT WITH 80 GRAIN PRIMACORD, AFTER FIRING STRING SHOT TOOL BECAME STUCK @ GLM @ 7259', WAS ABLE TO GET FREE AND POOH 6/15/2013 RIH WITH RADIAL CUTTING TORCH TOOLSTRING, CCL TO CUTTER: 9.5', CCL STOP DEPTH @ 7275.5', CUT PIPE @ 7285', PULLED HEAVY TO GET OFF'AFTER FIRING TOOLSTRING, TOOL CAME FREE AND POOH WITH NO FURTHER ISSUES, JOB COMPLETED AND TURNED OVER TO DSO 7/1/2013 PULL BALL & ROD/PULL PLUG BODY @ 7250' RKB; PULL SOV @ 7144' RKB. JOB IN PROGRESS. 7/2/2013 SET DV @ 7144' RKB (MIT IA TO 2500- PASS); PULL CATCHER & PULL CA-2 @ 7346' RKB. JOB COMPLETE ((READY FOR STATE WITNESS MIT)) pr 411 ,P 3A-14 Rig Workover Pull and Replace Tubing _'3 (PIT) #: 185 -282) 6 /j 4-/f 3 sv ilj 31371g3 Current Status: This well is currently shut in awaiting a workover. r o C c&-t u r' ( - Scope of Work: Pull the 2 -7/8" 2.87# J -55 EUE 8rd tubing above the packer, run new -7/8" 6.5# L -80 EUE tubing string. General Well info: Well Type: Injector MPSP: 2,797 psi using 0.1 psi/ft gradient (Most recent SBHP = 3,413 psi on 4/20/13) Reservoir Pressure /TVD: 3,413 psi / 6,165' TVD (10.7 ppg) from Panex gauges on 4/20/13. Wellhead type /pressure rating: FMC Gen 3, 11" 5M psi top flange BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams MIT results: MIT -T passed on 2/3/13, MIT- IA passed on 2/3/13 Earliest Estimated Start Date: June 18, 2013 Production Engineer: Suzanne Short / Toon Changklungdee Workover Engineer: Jacob Voss (265 -6935 / jake.voss @conocophillips.com) Pre -Rig Work 1. RUE -Line a. RIH and fire string shot at 7,285' MD SCANNED JUN 14 2013 b. RIH with 1.688" RCT, cut tubing at 7,285' MD �•�+, c. RD E -Line 2. Set BPV w/i 24 hrs of rig arrival. Proposed Procedure 1. MIRU. 2. Pull BPV. Reverse circulate 9.6 ppg brine. Obtain SITP & SICP, if still seeing pressure at surface, calculate new KWF, weight up, and repeat circulation as necessary. Verify well is dead. 3. Set BPV & blanking plug, ND tree, NU BOPE & test to 250/4,000 psi. 4. Pull blanking plug & BPV, screw in landing joint, BOLDS's, unland tubing hanger. 5. POOH laying down 2 -7/8" tubing. 6. MU overshot/packer assembly and 2 -7/8" gas lift completion, RIH to tbg stub. 7. Spot 20 bbls of corrosion inhibited brine to fill tubing and IA below the GLM #1. 8. Engage tubing stub until shear pins on overshot shear. Lower onto tubing stub until fully engaged. Pick up 1'. Drop the ball and rod. Set the FHL packer. Pick up to shear out of PBR 9. Space out w/ pups, MU hanger. Load the IA w/ corrosion inhibited brine. Land the hanger, RILDS. 10. PT the tubing to 3,500 psi, bleed tubing to 3,000 psi, PT the IA to 3,500 psi for 30 min and record. Bleed the IA to zero, then the tubing. Ramp up the IA pressure quickly to shear the SOV. Bleed tbg to zero, then IA. 11. Pull the landing joint, install BPV. 12. ND BOPE, NU tree. Pull BPV, install tree test plug. Test tree. Pull tree test plug. 13. Freeze protect through the SOV, set BPV. 14. RDMO. • • 04-1f3 3A -14 Rig Workover Pull and Replace Tubing (PTD #: 185 -282) Post -Ri¢ Work 1. Pull BPV. 2. RU Slickline: a. Pull ball & rod b. Pull SOV, replace w/ DV. c. Remove RHC plug d. Remove Catcher e. Pull CA -2 plug. 3. Handoff to operations. • • W14 Rc visrd 5c I-to/46)4 L- 5v►-A 3 8 3 3A -14 ConocoPhillips Stack Packer Casing – 9 -5/8" 36 #, J -55 BTC @ 3,360' � — Tubing – 2 -7/8" 6.5#, L -80, EUE KBMG Mandrel @ 7,XXX' PBR @ 7,XXX' CUL ' 4 Baker FH Packer @ 7,225' 1 2.313" X- Nipple @ 7,240' 1 Overshot @ 7285' f PBR @ 7,304' 1 Baker HB Permanent Packer @ 7,316' ELL ■ a 1 2.25" D- Nipple @ 7,353' Q ; 1 2.441" Shear Out Sub @ 7,385' A -3, A -4 Perf @ 7,474'- 7,494' A -2 Pert @ 7,506'- 7,550' A -1 Perf @ 7,580'- 7,586' ---► ,�- 3 ■ Fish @ 7,734' G 1 Casing – 7" 26#, J -55 BTC @ 7,841' Date: June 13, 2013 !Drawn By: Jake Voss • • Ferguson, Victoria L (DOA) From: Ferguson, Victoria L (DOA) Sent: Friday, June 14, 2013 10:17 AM To: 'Voss, Jake' Subject: RE: 3A -14W0 (PTD 185 -282, Sundry 313 -183) Jake, Based on the cement evaluation log, you have approval to set the packer as outlined below. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793 -1247 victoria.ferquson a(�alaska.gov From: Voss, Jake [mailto:Jake.Voss @conocophillips.com] Sent: Thursday, June 13, 2013 5:06 PM To: Ferguson, Victoria L (DOA) Subject: RE: 3A -14W0 (PTD 185 -282, Sundry 313 -183) Victoria, Attached are the logs for 3A -14 showing our cement integrity. The TOC was recorded as 5,610'MD based on the attached addendum sent to the state back in 1985. The log shows TOC (5,610' MD), the TOC of good integrity (approximately 6,6O0'MD) and also the integrity of the cement where I plan to set the packer (7,225'MD). Please let me know if you need anything else. Thanks, Jake From: Ferguson, Victoria L (DOA) [mailto:victoria.ferguson @alaska.gov] Sent: Thursday, June 13, 2013 3:18 PM To: Voss, Jake Subject: [EXTERNAL]RE: 3A -14W0 (PTD 185 -282, Sundry 313 -183) Jake, I haven't been able to print the wellbore schematic. Could you please send it in a different form. From: Voss, Jake [ mailto :Jake.Voss©conocophillips.com] Sent: Thursday, June 13, 2013 2:38 PM 1 I To: Ferguson, Victoria L (DOA) Subject: RE: 3A -14W0 (PTD 185 -282, Sundry 313 -183) Victoria, Attached is the updated general procedures for 3A -14 Stacked Packer Completion as well as the updated schematic. Just to recap our conversation, due to material shortage we need to include the stacked packer completion for this workover. This will cause our top packer to be approximately 250' above the top perforation. I am asking for a variance to AOGCC Rule 20ACC 253412: Casing, Cementing and Tubing of Injection Wells for Enhanced Recovery, Disposal and Storage - Rule B for this well. Thanks, Jake Voss Wells Engineer ; C:onocoPhillips Alaska I Office: (907) 265 -6935 I Mobile: (832) - 499 -9085 2 aD wO As fl 0, - -r COUNTY NORTH SLOPE cn m • 33 T a =• to Z a s T Z ° 5 3 o Field or O = • :o I I p `-° o g, LOCATIpN r.ur.aRUx z m S g o O c= WELL 3A- 14 1 IUii 1J _ , ! n i!• Q ma o COMPANY A Co ATARKA. a_ 8 :r 3 '�' „ 3 r m 0 n m * CI I! ta a O > cn F- r rt z Lrl lft a T N la Q Ln ca 111 rm— z as rrl rrl a g2. a m u, v Z -� N N o 71 a N A p ry 3 T r o N 11111 IIII C- 4. I1 !;':; > m 3 o o n O a 3 rn < .. m t-^ �� O b >o G)o� n 3 x 111 i CD . FOLD HERE - The well nome, location and borehole reference data were furnished by the customer. PRIMARY CEMENTING DATA WERE W2FP AND W3FP DETERMINED BY CROSS PLOT: ® Actual 1:1 Estimated Hour -Date IF SO, DEPTH INTERVAL OF PLOT: STANDARD KUPARUK VAL ES: W •= - r� . _ . lIZEMEMEIMEMINTI Service Order Number Start Cement Bon• Lo. REM= _ • s_r ■ • s Finish Cement Bond Log 1 9 35 12/29 Preceding fluid 1T 9 O Volume 5 bbls. Pipe reciprocated during Pumping: Yea x No Cement pumped 7. 5 bbls. /minute Pipe reciprocated after plug down: Yea min, I SQUEEZE JOB DETAIL DOWNHOLE EQUIPMENT REMARKS: •ueeze num•er FILMILM 5568. • Date T EMMIEIZIMININIMMINNIEMMENIMMI CART. ELEM 2765 Volume of cement 1111.011.11.111.111111 . UrMlnIIIIIIIIMIOMMi/iMiMMMII. .. Retarder GR 294 Weig t o s urry LEarailLEMINEEMINIMINIII CART. 7 31 =rea •own •ressure MMMIIIIIIIIIIIIMI FLEX ax. pressure -stage r ,r rr 2 3 Final maximum •ressure am! entry Izer 'attern SONDE 819 /Joint rom to Started pum•in• cement /Joint from to Re ease• • ressure MM111111111.111111 ,Joint from to Start CBL IIIIIMIIIIIIIIIMMIIIII asine cratc er Pattern Finish CBL .Joint rom to AVERA E WELL DRIFT: --{ O.D. 4 " /Joint from, to ' •„ ° .a • - •int rom to All interpretations ore opinions based on infer nces from electrical or other measurements and we cannot, and do not guarantee the accuracy or correctness of an pretotions, and we shall not, except in the case of gross or willful negligence on ur part, be liable or responsible for any loss, costs, damages or expenses incu sustained by anyone sulting from any interpretation mode by any of our officers, agents or employees. These interpretations are also subject to our General Ten Conditions as set our in our current Price Schedule. CP 28.2 FILE 6 29- DEC -85 19:35 a aaa =aMI. -1.R. .. �E a MIm ::.._.. MIaa_Eaaa =aa.. ..a r. .waaE>a tit aaa =sa.. t Er __ ��. saMI iaC-= ..i . - - .. - aaa tl• i 5600 C���i„ �. ..aaaa =MIME.. MIaata a yam .Mar-- /!- ... aaa =aa.a IIIMMIMMIN ..aaa_El ? ---. a>laaaw.— ___.! MIME — .____.w . ,.....-- _, - �as.aMM M 1MIL l a.sy.� r. M M, : - -...� is 511.M t �MI .■ MI saasa 3■ iimsar t a ;:_., n'.m+.�.`_.'_•._ „, rrumom MISSarr. Lira u ■ asa ta. aaaa\ _ ,. tiriaMIMIAIMiII iiaa.■ as C'7■ a ' ”- _ , .'• , r r .aa.i MI .►a i - a�>t.aa - E. i aa. ■ _ __..1=== IL ,.�,.. « . « .., 112111111•=11=11111111111 .— =—MI. a MI sa.�.■ ___r -. �� - . : �,,. , - . ,. .,, �� --s �. P � EsT M =I ia AFAMI msa�s:cssawt ,_ -.: _: .a aria. Eiiu r err 'f"'' -'-' .- a� i.um alltr. 11•11111110111111 - =iMM • -. mss... - %a•aat =� 1 TOP h Nl ��M MI���� al MITTTY:TI as . 11� 111.4110.111111111•11•1•111 MI MINIMIMMI mM1111111=1 =aMIx sa�MIN a MI �a -aaa MA MM A a a �� MI r. - ` � ; — aaa.. saia—MI =sari r. a /. -i a aaaa =aa al i ■ al , ^4+;.R; ? r; .: . T. a.M.MI— waa.■ amat °�'.kx i_: • E>1ME .aaa =MIME... CIi�Ms� Mai #> ... i _: M�.iaaa waa.! aaatJEl aE�• i t i . / . __• a 1 MIaawaa� ..MIME a . .�sI :MEW r aaaa— waa. ti a sMa.aa• 1111111111111 aaMI.r OMa —a —MI =_.■ .aa>•aMIa =aMI.. I M_= w a awl ,---- .a ._aa Laa.■ aaa- _aaa ._ as w IIIIIIIIMMAM MICR= =` T- • 'r — a a a s SPLIC E asi37 'n summons . --.... "r L f�� M! ! aaaa" i .. MIaa —MI aaa I aa ___ a."•. aaaca - . E.MIaI.aaa .=aMr aaa... aaaa " ..- ' aaaaaa MIME. aaa... aaaa ►7aatasa =MIMEO' aaaw4o. aaa 5700 MIMI�ro� I� MMIm �.^'"`t•� 1MIaaaa .MIME! MI .. 'r_ _ .. - .: •. q -'• MI1=81/111/111=XXIMIMMAIMMI II •MIMIE 1 aaaa. MIMIatl\ 6 aaaaaa =aa. A. MIMIara. MIMIMI.I }_ s r f yo : aaaaaa =MIME ■ ___ • __altl► x. --MIaaa =Ma.: aaMIFa. MIME -- - aa,fwaaa =IMMMIa aaa.=» MI • aaMIMIaa .c_ ••■• a co aaMIP_ MIaMIa a—a—MIMI 1111111•11=E a o aar=r__ —MI—.r aaMIaaa =Maw e . aaaeIN.M aaa\. aaMIaaMI =MIMI.- 1 1 aMIMI►.la MIMIa. aaaaaMI =aaz il w MIMIMIMI., aMIar ' ' aMIaaaa =a�.�! 4, aaa.a.l MIaa . ' MIIIIIMMIMIN MN aaMIMIaa =MIM�a MImanmas aMIaE .,...,:«;"- N b w 111•1======1 =MIAMI I MIMIa=IN ___r a saaMIMI 111=1=1111 II MI•MI:>.• —MIa MIaMIaaa =MIaCi.! aMIMai• MIMIMI aMI>•MIaMI =MEMO 1 V, aaaca. aMIMIa. - ° -' saa—MI— M_.M i • - Maas. MIaaw► h-� - aaaaaa =sE>.. a aaMIa�a. aMIaa • e s In ,> a—MIaaMI =a..:a ■ N MIMIass+. MIMIaMI .y • •■•••• =a.►_.a a saMIMI. aMIa —MIaa —MI =MIMIC. . w1. __w!_. MIMIae � y. i s as aaa =awIla 3 MI MXIM saMI . . ,�. - 1•111•11141===111=1 Ma;�i.a aaMra.�m 111=1111111M. •aaaaa = —Mi 1 aaM Mall aMas aaMaaa .j sa.Raw aMIMI.• - aaawaaa a!% a \\ a.l mmur a aMI/ - -" t. ,., aaa—MIMI Numons ■ Maw 4 a MIaL 0 a =1=11111=1111111= =I Mara.■ aatarat! MIMIaa MI—MIasa Magi! m r au asa—aa wMI►a•i aaaca.= aaMIE. r "- mama ammohns a aaakaEl aaMIMIr .p MIa a =aM�! awMIr . aMIaa ;t - �4" , ^ ,,` ,,' a aa .-MIae II MIME ___• aaalr- "� MIAMI ■ aaMI:'we aMIav n MN MIME =a.La 1 MIMIMMIN 111111111== rt ' '` " g- I Mall as =aEr.l aaa __a► in aMI Mafia ■ aaMIa. MIw.Mr + as as MILIM! MMIE.MI. aMIai ' i . , 1 I miss ii a. aMIa mE EEI MI MENEN: � aaMIa► F r I MI a =MICE. ! 5800 MI■a. MIMIMI� � 4. =; v A -' a aaaa M__P .4 ___• aaMIw ^ t t s MI =Mall __ _Maw - -, ' aa a =aE'. ��� 5 uc � aaaaaa =M,M111 a aMIal - _ "'+nrr.- WW� ttir � , aaaa— =E1_ ® _ � �' ' =m E C G = 111 MIN f v - ,s ..N,,,� as MI a v. a MIEr w. iMIMI tar s C � Efs a ail.aa MIAs MIX MI �. '"- - -`. , .1 , • 0 ' ' , .! . . . < ',' . : . .. .:-, . , . 1 I :04.14 IL A a i ' . i _ 2_ , , :i ; , ( ' 1 jo � , O f iE ; . £ � . q � 1 "a , 1 :�, ' ' i `' "� } c 4 ,F 't � ; d- [ { N� :'.. gy p: + �� - �� t � r 1 ■ i( t , . if . ' ,i i i' . ,k 1 1 . :k4; ", -''. ., ''' •,0i.' t. ,,„_ , . .i t ,46 1 _,. i 1.. �� - ll � w ill ►... /lr lIl 1llll1111'4I e IY1 I Iililh 11ii. Alil►�NII IIfhIN11111111111 _ _,., i11 441► 1111u11 u 1 1 i In uu ' uIu. I.u,11 imn anhIu II iuu,uuIuuiiiiniau t- _ / nni► 1 lilHl iu rll 11ui11111p�i�lul 1111 ,uruuli! 1111IIl8 Illlllu111111l��11lmil lH01116_Ah. ei � li , � 111 � ' (n 1 ' 1� ,j iii � r�Mi II 1 I ' ' � ,'' ' ► ' MMI N1,.. X111 110011iul hI Miki �_ ... �u . . ��JiJrr rtY.d...�l'� �,.I.�. I!.r1Yi ���WY��t1111' ,��.,�.1 JI � 1 1111 u IW1 1811� 11111111111u11 11 RIIIIIIIIY1111�11111111111111 � X11 IY ++ 11111 Yli III iMI IIIN111u�MIII llllul111111IlIIIl 1 1111111uliuliuiiiilu111111 1 11 1�1IllllllHill 0 0 0 0 1 w F. ■rrrt urrrrrrrrrwmrrrrrrrr �rrrrrrrrrrrrrrrrrrrr� rrwrrrr�rrrrMrrwrrrr�i urrrrrrwrrrrrr.�rrrrrr urrrrr.UUj%Irrwrrr.U.a Hrrrrrrrrrrr r r iiiiiiiiiliiiiiiiiiiiiiiiiii ' lniiiiiiiiiiiiiiiiii�iiiiiiriiiidilii !�iiiii�iiiliii��iiiiiill iii�il ►Aiiiiii'iiiilllii �iiiiiii ..1 11; 11I► HIN/IIIN! 111111J111�11111E�1111111111 .11Grr 111111111► I:! IIlll► a�, 1il1��lIJ1►. 1, 11�. 1► lIt1I 111�.11JI►illli3►�11►111111111 �:1 la rinI���MINI EUIEG�a:��wiu►ulc� ll ally! alIM����M1123111E 1IIuIuh1IIIiIII111111 IIIlI��IUniuIIi1IIV iumri I1LIe iN1111111111111IIIM11111 IMIM111111111111u11111111111111MM11111111111111111M1111111ui1M1111 lliul111111i111 '111N 11 I1n l IlH l liiil l iil l l llii illllliliI i l llii i liilliiliill l l ll� ilu �iill i ii Ilil 11 . _ ; INNIIIIII IIIIIIU l WINMUIPPIIIIUIIIIIIIIII ! �l! s !III!! II IIIIIi!l IM F WHIM! !! !!__ ' 111 lunl� 111111111 ilillllllullllillllllllllnll 1111 um 11 I I1111111u11 lllui 11 11 Ilulii n11 11111111111111 11 nullll�I u i111111111111111111111®1l IIIIII Ill • • _ ; 1 :i. I,:1 00 41 ,i1 t # . , , , . . , . i , 1 r ' '' '' . :. .! . -:- ,• ' ■V ..: :•!I.i.' .. ! ,, 1/ I. ,:,:,.: Li , -, ' ! ,t!.'.1,!;„,,,i0.:?).1,i1;-in.„:„-,,,..,-r,,:;,i.,:,,..,::,,,;!::„,_:,,,::,,,0,,,, :,, ,,:,,,,, -,. :._, , . „ .-:. ;'Y.: ' .: .:',, i'.. ,: ' 4.1i!i:' .'i,.:;:A&,:: VI' ,, :l'iiii , .!A'.;-•yi , .'V - ' `"".;;.!.:: -!..:::, ,:1.1..i: i ,!:,.; ;,; !:."" v.jj'" ' '' "\J \ .!..+./ '."/ AIL A - %,/ ''-'-.;:.,ii.,i-i; . .'JrL. .,:,.../ •,,,,,::,-:.,,;-!, ::.-., v i --,- ' --;.,' .....ilanithipengpion,___...du, Ahmenbinni, - it - "'-'-- - ii.„.' • - A` it AMMULUMMummuljupaniiiiiinirmanol muimum g l ititettalirikir - ir . NOMMEMMI1111101110101111111MOMMIN 1111111111111111111 . PIIIMIMMINIMOOPUREVANOMMEIZIL mompmrimmimprompopmeounn mis AiiiiilatillitilifiliiifilthliiiiillinglillhildillltaillobirMINEM L Egulniedh.. "EREINNI deLi!. mmummumummoummoommmumm mmoomomoomillimibummlihmmum I hum ,c 0 0 ;; 0 ,-... c,., , . , _ pumumeme mumemorme, emu MIUIRPoinommillim sommumumpluimplumu guggion ,,,,, gimieemi imannemilmiumiumum weimmimmin: IiiiiiiiiMiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiiMiliiiiiiiiiiiiiiiiiiiiiiiiiiiiMENIMINIMMIliiiii INITIEWIIMICIARIMINIMINEMPUIEVENIIMIPOUP10111/1111 - MEMIMPLIIIIMMEINOMPICHOUGMENEVAININE JIMEMUCHLWAILLAINIKANDIUMMONYMEffilliinnelllilln . Emoonimiiiimenimiiiiiiiiiiiimnimmmommimumiumnimmommtimmummumutiom li ImommmonommommommumounopprommummulmommTummo 1111111 d 1111M110110110011111110011M 1' ; , MEW ill 11111011111111111111111111IN gloom mamma MON AIN MENIMMUIENUOMMIlle-- In UNCIROMMENIMMI MEMO ININIMPOI NUM" li N 1 IM IIMMIJON 191111MMI I MO 111111111111111111 IIIIIM 11011 011 Illmlibidlifi 1111 IMMO "11 ' ' ! OM 11111121111111110 11011110111M , , 11101M0111 NMI I EN . . _ .. el *e Li •••• INN 111m6 411 411 WELL: 3A-14 2/19/115 Arctic Pak well w/175 sx AS 1, tolloved by 62 bbls Arctic Pak. 12/30/85 Rn CET log f/7744' WLM co WO' TOC. Rn (CT gyro. FRACTURE STIMULATION SUMMARY 2/07/85 Begin Frac 'pork At: 1555 hrs. 2, AFE: AK0367 Frac'd Kuparuk "A" sand perfe 7474'-7494'. 75W-1550' & 758 in 7 sagos per :/3Lifk6 procedure using gelled dicsal v/Musol, 1000 mesh 4 20/40 sand, Pretis'd aril to 1610 psi widiesel. Tst lns to 7200 psi; OK. Stage 1: 35 bbl 5% U-66 Musol kl 5 BPM wifinal pressure of 2900 psi. Stage 2: 50 bblu gelled diesel pro-pad :5 bPM wiflmal pressure of 5400 psi. Stage 3: 19 13b15 gelled dirFel wil00 mrsh, 20.4 nY, woofinal pressure of 5050 psi. Stage 4: 64 bbls gelled diesel pad 0 '0 BP w/final pressure of 4670 psi. Stage 5: 23 bills gelled diesel w120/40 =esh 20 3?'! wifinal pressure of 4580 psi. Stage 6: 43 bbls gelleo diesel w/20/40 mesh 20 RPM w/final pressure of 5420 pmi. Stage 7: 44 bbls gelled dlcsrl flush 18 BPM wifinnl press of 5420 pgi. Pmp'd 80010 100 mesh * 2500v, 3 ppg 20/40 6. [COGSN 2O/40, ppg. leaving 492N 20/40 mesh sand. Job undertiushed by 1 bbls in Load to recover 249 bbl of dirs.el. Job complete (a 1712 Firs, 2/71b6. R.1E.C1 \I V 0,, 3 191 , • e ° • w��I % %S THE STATE ACitaska Gilt and Gas of (L nservati . n Commission GOVERNOR SEAN PARNE'L;E"`' • • 333 West Seventh Avenue ®ALAS *P' Anchorage, Alaska 99501 -3572 Main: 907.279.1433 Fax: 907.276.7542 Jacob Voss SCANNED SAY 2 Wells Engineer 2013 a,5� ConocoPhillips Alaska, Inc. U P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3A -14 Sundry Number: 313 -183 Dear Mr. Voss: 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, 7 Ca y P oerster Chair DATED this 1 f da y of May, 2013. Encl. II III • STATE OF ALASKA 11 AO<A OIL AND GAS CONSERVATION COMOSION 6 ' APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon i°"'" Plug for Redrill I. - Perforate New Pool ( - " Repair w ell (;i - Change Approved Program E Suspend r Plug Perforations r Perforate 1 Pull Tubing j• - Time Extension E Operational Shutdown ("` Re -enter Susp. Well E Stimulate I - Alter casing E Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development I- Exploratory F 185 - 282 ' 3. Address: Stratigraphic [ Service k' • 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 21490 - 00 • 7. If perforating, What 8. Well Name and Number: Regulation or Conservation Order govems well spacing in this pool? Will planned perforations require spacing exception? Yes f No Fil ` 3A - . 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25631 • Kuparuk River Field / Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 7855 6441 " 7353' 7734' Casing Length Size MD TVD Burst Collapse CONDUCTOR 76 16 107' 107' SURFACE 3649 9.625 3680' 3180' PRODUCTION 7811 7 7841' 6429' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7474' 7494', 7506 7550', 7580' - 7586 6130' 6146', 6157' 6191', 6215' - 6219' 2.875 J - 55 7386 Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft) PACKER - BAKER HB PACKER W /XO MD= 7316 ND= 6004 - SSSV - BAKER 'FVL' SSSV MD= 1797 TVD =1738 12. Attachments: Description Summary of Proposal • Iii 13. Well Class after proposed work: Detailed Operations Program I - BOP Sketch Exploratory I Stratigraphic I - Development I Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/18/2013 Oil E Gas IF WDSPL E Suspended E 16. Verbal Approval: Date: VVINJ r . GINJ r WAG I _ Abandoned r Commission Representative: GSTOR E SPLUG I - 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jacob Voss @ 265 -6935 Email: Jacob.Voss @conocophillips.con Printed Name Jacob Voss / V Title: Wells Engineer � f Signature / � Phone: 265 -6935 Date / i Commission Use Only Sundry Number: ZJ ?-'1 J1 Conditions of approval: Notify Commission so that a representative may witness f+ Plug Integrity r- on BOP Test I�'" Mechanical Integrity Test I` Location Clearance I Other. 50p fr5t to 46PU ) 5 / 44 l 77,9 rrg li 1 %G' F�"rV i- fg &111 11 i rC, l 14 /' 1 i n J c G t l '� Spacing Exception Required? Yes ❑ No [✓� Subsequent Form Required: I ( ) — !1- G RBDMS MAY 17 4 ' APPROVED BY _ Approved by: % p ro' vcd application is vaRf8VMrl1.T9grl the from A? ��t2IRORval. Date: SJ - / 7 -'/ i3 Form 10 -403 (Revised 10/2012) 1//1- Submit Form and Attachments in Duplicate R o \ ,, 1 0 X0/43 ORIGI ;, A\, . • S Conoco Phillips Alaska r P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 March 26, 2013 A ( _ c . Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to workover Kuparuk Well 3A -14 (PTD# 185 -282). Injecting well 3A -14 was originally drilled and completed in January of 1986. The well was put on injection for Kuparuk A -Sand only in April 1986. Throughout the well's life, it has required periodically bleeding pressure of the IA to keep the Inner Annulus pressure below 2,000 psi. From 2003 to 2004, the bleeding frequency grew from 2 to 4 times a week. On 3/22/2008, the well was waivered to only allow water injection. In July of 2011, the well failed a MIT IA and was shut in. A leak detection log was run in February of 2012, but no leak was found. A PDS noise and temperature survey was then run to locate the TxIA communication. A leak of 0.05 gal/min was detected; however no location was found. After passing a CMIT TxIA test and draw down test on February 3, 2013, it was determined that the TxIA communication was due to a mechanical failure in the tubing. The proposed workover plans are to pull and replace the 2 -7/8" tubing string with new 2 -7/8" 6.5# L -80 tubing string. This Sundry is intended to document the request for approval to workover the well. If you have any questions or require any further information, please contact me at 265 -6935. Sincerely, / Jacob V Wells Engineer CPAI Drilling and Wells • • 3A -14 Rig Workover Pull and Replace Tubing (PTD #: 185 -282) Current Status: This well is currently shut in awaiting a workover. Scope of Work: Pull the 2 -7/8" 2.87# J -55 EUE 8rd tubing above the packer, run new -7/8" 6.5# L -80 EUE tubing string. General Well info: Well Type: Injector MPSP: 2,797 psi using 0.1 psi/ft gradient (Most recent SBHP = 3,413 psi on 4/20/13) ✓� Reservoir Pressure/TVD: 3,413 psi / 6,165' TVD (10.7 ppg) from Panex gauges on 4/20/13. Wellhead type/pressure rating: FMC Gen 3, 11" 5M psi top flange BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams MIT results: MIT -T passed on 2/3/13, MIT- IA passed on 2/3/13 Earliest Estimated Start Date: June 18, 2013 Production Engineer: Suzanne Short / Toon Changklungdee Workover Engineer: Jacob Voss (265 -6935 / jake.voss @conocophillips.com) Pre -Rig Work 1. RU Slickline: a. Lockout Baker 'FVL' SSSV at 1,797' MD (2.312" ID) b. RIH and pull CA -2 plug c. RIH and get updated A -sand SBHP d. Pull DV in GLM #1 at 7,260'MD e. RIH with CA -2 Plug and set in `D'- Nipple (2.25" ID) at 7,353'MD f. RIH and set catcher on top of CA -2 Plug 2. OMIT TxIA 3. PT tubing and casing packoffs, FT LDS's. 4. Set BPV w/i 24 hrs of rig arrival. Proposed Procedure 1. MIRU. 2. Pull BPV. Reverse circulate 9.6 ppg brine. Obtain SITP & SICP, if still seeing pressure at surface, calculate new KWF, weight up, and repeat circulation as necessary. Verify well is dead. 3. Set BPV & blanking plug, ND tree, NU BOPE & test to 250/4,000 psi. 4. Pull blanking plug & BPV, screw in landing joint, BOLDS's, unland tubing hanger. 5. POOH laying down 2 -7/8" tubing. a. If tubing will not pull free, RU E -line: Fire a string shot and cut the tubing in the middle of the first full joint above the PBR. b. If tubing was cut, RIH w/ overshot & stacked packer. 6. MU seal assembly and 2 -7/8" gas lift completion, RIH to PBR until fully located, pull up to neutral weight plus 1', pull out of PBR. 7. Space out w/ pups, MU hanger. Load the IA w/ corrosion inhibited brine. Land the hanger, RILDS. 8. PT the tubing to 3,500 psi, bleed tubing to 3,000 psi, PT the IA to 3,500 psi for 30 min and record. Bleed the IA to zero, then the tubing. Ramp up the IA pressure quickly to shear the SOV. Bleed tbg to zero, then 1A. 9. Pull the landing joint, install BPV. 10. ND BOPE, NU tree. Pull BPV, install tree test plug. Test tree. Pull tree test plug. • • 3A -14 Rig Workover Pull and Replace Tubing (PTD #: 185 -282) 11. Freeze protect through the SOV, set BPV. 12. RDMO. Post -Rig Work 1. Pull BPV. 2. RU Slickline: a. Pull ball & rod (if needed) b. Pull SOV, replace w/ DV. c. Remove RHC plug (if needed) d. Remove Catcher e. Pull CA -2 plug. 3. Handoff to operations. r KUP • 3A -14 ' ConocoPhtlIips . :.ems Well Attributes Max Angle & MD TD , AlaSlta kK: Wellbore API/MI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) ......... . " c:rxiocoPoAkps ''j' 500292149000 KUPARUK RIVER UNIT INJ 45.42 4,400.00 7,855.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date "' SSSV: TROP Last WO: 36.21 12/11/1985 Well Confiq - 3A -14, 1 011 5/201 2 7 AM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag' SLM 7,665.0 2/5/2012 Rev Reason: WELL REVIEW osborl 10/15/2012 Casing Strings -- - "- - - - - -- cc() Description String 0... String ID ... Top ftKB Set Depth (5... Set Depth TVD String Wt... String ... Strn To Thrd 9 P 9 9 P( 1 P( P( 1��� 9 9 9 P HANGER, 24 NDUCTOR 16 15.062 31.0 107.0 107.0 62.50 H Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd ME SURFACE 95/8 8.921 30.7 3,680.0 3,180.2 36.00 J - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd PRODUCTION 7 6.276 30.0 7,841.3 6,429.4 26.00 J -55 BTC Tubing Strings r Tubing Description String 0... String ID ... Top (ft(B) Set Depth (5... Set Depth (TVD) ... String Wt... String ... String Top Thrd r , TUBING 27/8 2.441 24.0 7,386.1 6,060.0 2.87 J -55 EUEBrd Completion Details Top Depth (TVD) Top Incl Nomt... CONDUCTOR, Top (ftKB) MB) ( °) Item Description Comment ID (in) 31.107 24.0 24.0 0.09 HANGER FMC TUBING HANGER 2.875 1,797.4 1,737.5 32.13 SAFETY VLV BAKER 'FVL' SSSV 2.312 7,304.2 5,994.3 3628 PBR BAKER SHEARED PBR 2.500 7,315.8 6,003.7 36.40 PACKER BAKER HB PACKER w/XO 2.890 7,353.1 6,033.5 36.79 NIPPLE CAMCO'D' NIPPLE w /2.25" PROFILE 2.250 SAFETY VLV, 1.797 7,385.2 6,0592 37.13 SOS BAKER SHEAR OUT SUB 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVD) Top Inc! Top (ftKB) (ftKB) ( °) Description Comment Run Date ID (in) 7,353.1 6,033.5 36.79 PLUG CA -2 PLUG 2/6/2012 0.000 7,734.0 6,340.4 34.06 FISH JUNK on Bottom BALL to Shear had 5' Aluminum Tail 12/9/1985 0.000 Perforations & Slots Shot SURFACE, • ' Top (TVD) Btm (TVD) Dens 31 -3,680 Top(ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (.h... Type Comment 7,474.0 7,494.0 6,130.0 6,145.9 A -4, A -3, 3A -14 1/11/1986 4.0 IPERF 90 deg ph; 4" HJ II Csg Gun 7,506.0 7,550.0 6,157.3 6,191.0 A -2, 3A -14 1/11/1986 4.0 IPERF 90 deg ph; 4" HJ II Csg Gun GAS LIFT, 7,580.0 7,586.0 6,214.6 6,219.4 A -1, 3A -14 1/11/1986 4.0 IPERF 90 deg ph; 4" HJ II Csg Gun 7,259 Notes: General & Safety >.,- v, -, \ a \ \X\ ..wu? End Date Annotation 3/22/2008 NOTE: WAIVERED WELL: T x IA COMMUNICATION, WI ONLY 2/19/2009 NOTE: View Schematic w/ Alaska Schematic9.0 PBR. 7.304 . PACKER. 7,316 NIPPLE, 7,353 PLUG, 7,353 SOS, 7,385 —III Z IPERF, �.._ 7,474-7,494 IPER 1 r0 IPERF, 7,506 -7,550 IPERF, ! E 7,580-7,586 -- Mandrel Details Top Depth Top Port (TVD) Inc' OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) ( °) Make Model (in) Sery Type Typo (in) (psi) Run Date Com... Flsr+, 7,734 1 7,259.5 5,958.1 35.82 MERLA TGPD 1 1/2 GAS LIFT DMY RK 0.000 0.0 1/8/2006 PRODUCTION, 30-7.641 ■ TD, 7,055 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, August 11, 2011 TO: Jim Regg / P.I. Supervisor t l o f 1 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3A -14 FROM: Bob Noble KUPARUK RIV UNIT 3A -14 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry (16r-- NON-CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 3A -14 API Well Number: 50- 029 - 21490 -00 -00 Inspector Name: Bob Noble Ins P Num: mitRCN110802172602 Permit Number: 185 -282 -0 Inspection Date: 7/29/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3Aa4 " Type Inj. i W I TVD 6003 ' IA 2850 3330 , 3230 , 3173 3116 - P.T.D 1852820 " TypeTest SPT Test psi 2900 - OA 510 590 540 540 525 Interval REQVAR P/F F - Tubing 2740 2740 2740 2740 2740 Notes: Tubing x IA communication. Test pressure Oked by Tom Maunder. Test was held an extra 15 min. due to operator request; test looks like it paased in 30 min. but failed in 45 min. A50 zg ,a, I I Thursday, August 11, 2011 Page 1 of 1 • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 17, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: • APR ~~ ~ Eta; ,RC1FddCwd .~3~~ ~ ~ ~~~ ~~ ~~~ -, .,w ~~,~~ 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 cement if needed and 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 cement was pumped March 27th and 30th, 2009. The corrosion inhibitor/sealant was pumped April 6th and 15th, 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, Perry K~l~ein 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 4/17/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 3A-01 185-186 28" NA 28" NA 3.50 4/15/2009 3A-03B 207-131 11' 1.50 25" 3/27/2009 4.80 4/15/2009 3A-05 185-221 30' 4.10 26" 3/27/2009 7.70 4/15/2009 3A-06 185-222 12' 2.00 19" 3/27/2009 2.60 4/15/2009 3A-08 185-224 22" NA 22" NA 3.10 4/15/2009 3A-09 181-194 SF NA 13" NA 2.55 4/6/2009 3A-10 ~ 185-237 16' 2.50 25" 3/27/2009 5.95 4/6/2009 3A-11 185-238 SF NA 20" NA 2.55 4/6/2009 3A-12 185-239 SF NA 13" NA 1.00 4/6/2009 3A-13 185-281 18'8" 1.00 32" 3/30/2009 7.70 4/6/2009 3A-14 185-282 13' 3.00 20" 3/30/2009 9.35 4/6/2009 3A-15 185-283 NA NA 2.60 4/15/2009 3A-17 196-132 3'6" NA 3'6" NA 12.75 4/6/2009 3A-18 196-133 11'10" 2.00 9" 3/30/2009 2.55 4/6/2009 /,v -vj ki ire io- ri -)7v) oww vvitucaacu ivr►ivrx F%a rarc i vi Maunder, Thomas E (DOA) From: NSK Problem Well Supv [0617 @conocophillips.com] Sent: Tuesday, June 03, 2008 3:13 PM To: Regg, James B (DOA) Cc: NSK Well Integrity Proj; Maunder, Thomas E (DOA); Cawvey, Von; NSK Problem Well Supv Subject: RE: 2G -03 (PTD 1841390) State witnessed MITOA per AIO 26.014 Jim, I conducted a review of our waivered injectors and compiled the following list of wells with known TxIA communication that allow tubing and inner annulus pressure to equalize at greater than 2000 psi. Well Prod Casing Prod Casing IYP IA DNE MAOP MAOP %IYP AA # 2C -07 7" 26 ppf K -55 4980 3000 60% AIO 28.007 2G -03 7" 26 ppf J -55 4980 3000 60% AIO 28.014 3A -06 7" 26 ppf J -55 4980 3000 60% AIO 2B.008 3A -11 7" 26 ppf J -56 4980 3000 60% AIO 28.022 3A -14 7" 26 ppf J -56 4980 3000 60% AIO 2B.026 3H -09 7" 26 ppf J -66 4980 3000 60% AIO 28.009 3N -12 7" 26 ppf J -55 4980 3000 60% NA 3N -13 7" 26 ppf J -55 4980 3000 60% NA I also reviewed the history of 2G -03 and verified that in early December 2007 the IA pressure began increasing until ultimately equalizing with the tubing in mid - January 2008. This well has a known history of TxIA communication dating back to 1996 and it seems that this performance is consistent with the provisions in AIO 28.014 and the CPAI internal "Notice of Kuparuk Waivered Well" dated 08/13/06. As a result, CPAI has not performed any work to remediate the TxIA communication. The only wellwork done since the change in performance is an MITIA on 5/2/08 witnessed by John Crisp and an MITOA on 5/15/08 witnessed by Chuck Scheve. Please contact me at your convenience if you have any questions or comments. Martin Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office 907 - 659 -7224 NOV I Cell 907 - 943 -1720 Pager 907 - 659 -7000 #909 From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Friday, May 30, 2008 4 :41 PM To: NSK Problem Well Supv Cc: NSK Well Integrity Proj; Maunder, Thomas E (DOA) Subject: RE: 2G -03 (PTD 1841390) State witnessed MITOA per AIO 26.014 I went back and reviewed a fairly extensive history on KRU 2G -03, including the previous sundry approval 397- 046 that was the precursor to AIO 26.014. The justification provided with the sundry waiver request refers to not exceeding 70% of the production casing minimum yield strength. 11/9/2010 cv -v✓ ki iL io -r i ✓- 7v) oiaw vviLuwa%.0 lvui Y%.i cuv z.L.vi-T i ar vi ✓ • • The AIO 213.014 application (July 2006) makes reference to an approved MAOP without providing any specifics what the actual approved MAOP is. Can't tell from our files what we thought the approved MAOP was. Seems to me there may be some inconsistency in how annuli pressures are being handled, particularly in light of the additional restrictions /surveillance /safety devices imposed by the Commission on wells with relatively weak J55 production casing (published min yield strength is 4980 psi). The sundry waivers and admin approvals we have issued regarding injector integrity do not consistently specify a MAOP for the well - that may be something we need to adjust for future approvals to be clear about our expectations. CPAI's future applications for administrative approval should clearly identify the operating limits intended to be applied. You mention that there are other Kuparuk wells similar to 2G -03 where the tubing and IA are allowed to equalize up to the water header pressure with an upper bound - it would be helpful to have a list of the wells, and include what the annuli MAOP's are. Hopefully all are covered by existing admin approvals. KRU 2G -03 has an interesting pressure history (I have data only back to 2002). The significant pressure increase earlier this year is what surprises me the most after reviewing - has something changed in the well or has there been some decision by CPAI to manage the pressure differently? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 From: NSK Problem Well Supv [ mailto :n1617 @conocophillips.com] Sent: Tuesday, May 27, 2008 10:40 AM To: Regg, James B (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: RE: 2G -03 (PTD 1841390) State witnessed MITOA per AIO 26.014 Jim, CPAI was granted administrative approval to continue water injection in the 2G -03 well with know TxIA communication via AIO 213.014 on August 2, 2006. A subsequent CPAI internal Notice of Kuparuk Waivered Well was approved on August 18, 2006 that allows IA pressure to "equalize up to water header pressure, not to exceed 3000 psi ". The current water header pressure at DS2G is 2678 psi. I Please contact me at your convenience if you have questions or comments. I Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907 - 659 -7224 Cell 907- 943 -1720 / 1999 Pager 907 -659 -7000 #909 From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Wednesday, May 21, 2008 3:21 PM To: NSK Problem Well Supv Cc: Maunder, Thomas E (DOA) 11/9/2010 /-v -w kr i L i o-r i JYV) cotam wiLucbbcu ivii i vri yci ruv 1-t3.v i-r r agv J vi J • 0 Subject: RE: 2G -03 (PTD 1841390) State witnessed MITOA per AIO 26.014 IA pressure is 56% of MIYP for the well's 7" (J55, 26ppf) casing. I realize you just completed the MITIA earlier in May - curious why such a high pressure was left on the well. That certainly was not our intent in approving AIO 26.014. What is CPAI using for a MAASP in the annuli of 2G -03? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 From: NSK Problem Well Supv [ mailto :n1617 @conocophillips.com] Sent: Friday, May 16, 2008 11:00 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Fleckenstein, Robert J (DOA); DOA AOGCC Prudhoe Bay Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: 2G -03 (PTD 1841390) State witnessed MITOA per AID 26.014 Tom, Jim, and Bob, Attached is the MIT test form for a variance required MITOA on 2G -03. This test is in addition to the witnessed MITIA that was performed on 05/02/08 for the required testing per AIO 26.014. Please let me know if you have any questions. <<MIT KRU 2G -03 05- 15- 08.xis>> Brent Rogers /Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 11/9/2010 • STATE OF ALASKA ALASKA OlL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: ConocoPhillips Alaska 4nc. FIELD /UNIT /PAD: Kuparuk/ KRU/ 3A-14 ~;~~~ ~-~ j j ~~~ DATE: 01 /30/08 OPERATOR REP: Johnson /Bates / Greenwood - AES AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well 3A-14 Type Inj. W TVD -6,004' Tubin 2,950 2,950 2,950 2,950 Interval O P.T.D. 1852820 Type test P Test psi if501 Casin 2,800 /3,425 3,375 3,350 P/F P Notes: Non-witnessed test for AA aplication (MITIA) OA 0 0 0 0 Well 3A-14 Type Inj. W TVD X6,004' Tubin 2,950 2,950 2,950 2,950 Interval O P.T.D. 1852820 Type test P Test psi .1501 Casing 2,550 2,650 2,725 2,750 P/F P Notes: Non-witnessed test for AA aplication (MITOA) OA 0 ~t"800 1750 1740 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing PIF Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W = Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes t =initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) ~~~~ FEB ~ 0 2Q~~ MIT Report Form BFL 11!27/07 MIT KRU 3A-14 01-30-08.xis 3A-14 (PTD 185-282) TxIA com~ication Page 1 of 1 Re James B DOA 9J~ ~ ) From: NSK Weli Integrity Proj [N 1878@conocophillips.com] Sent: Friday, January 18, 2008 5:44 PM ,~ ~ - ~~~ ~~ To: Regg, James B (DOA); Maunder, Thomas E (DOA) ~~ Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: 3A-14 (PTD 185-282) TxIA communication Attachments: 3A-14.pdf; 3A-14 TIO.pdf Jim, 3A-14 (PTD 185-282) was reported to the Commission on 10/08/03 and again on 05/08/05 as showing signs of T x IA communication. All positive pressure diagnostics continue to pass integrity testing, as well as 30 minute drawdown tests, however the IA pressures up to tubing pressure within several days after being bled. There is no recordable leak rate so the exact location o the communication is not detectable but an intermittent packer leak is the suspected. The well passed a diagnostic MITIA to 30Q0 psi and an MITOA jo 1800 psi on 5/13/07. This well has been monitored internally by ConocoPhillips since the initial report to the Commission in 2003. At the time of the initial report the Commission did not require any additional reporting as the MIT's remain passing. However, since that time other wells with similar communication issues have required Administrative Approval (AA) to remain online. Therefore CP will be applying for an AA on this well too. It will also be added to the Monthly Injector report. Attached is a 3 month TIO and schematic. The AA application will be submitted after new MIT's are ~ completed later this month. ConocoPhillips requests approval to leave 3A-14 online with the intention of submitting the AA application within the next few weeks. ,,~ :/ «3A-14.pdf» «3A-14 TIO.pdf» Please let me know if you need anymore information before the AA application is submitted. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 1 /22/2008 p;~ -vs-z~-L 500 ~..E ......................................................................................................... 01-IV©v-07 01-Dec-07 01-Jan-08 Date •i • ,ta~'~~ ft,~ C©nocoPhil~ips ~t~aska, Inc. 3 1 - API:.... -. SSSV Type: i sssv Annular Fluid: (1797-nsa, j Reference Lo OD:2.875) ~ Last Ta (o Baas , Last Ta~Date: oD.z.a75, Casin~Strin~- A ID:2.347) ~, Descri lion I j Gas Lift andrel/Dummy Vale 1 (7259-7260, OD:5.460) PBR (7304-7305, OD:2.875) PROD. CASING {0-7835, OD:7.000, Wt:26.00) PKR (7316-7317, OD:6.151) NIP (7353-7354, OD:2.875) SOS (7385-7386, OD:2.875) TTL (7386-7387, OD:2.875) Perf (7474-7494) Perf (7506-7550) Perf (7580-7586) ^ I ~ I k I ~~ f ~~I I ~_~ l- 1 'I !. ___ KRU 3A-14 292149000 Well T INJ An le TS: 37 de c0 7361 1P Orig Com letion: 12/11/1985 Angle @ TD: 34 deg @ 7855 Last W/O: Rev Reason: PULL PLUG Ref Lo Date: Last U ate: 3/27/2006 2 TD: 7855 ftKB 2006_ Max Hole Angla• 45 dad n 4400 STRINGS _ Sic i Tnn i Rnttnm i T\/fl i Wt i (_r~Ac i Thro~A i CONDUCTOR 16.000 0 107 107 62.50 H-40 SUR. CASING 9.625 0 3680 3180 36.00 J-55 PROD. CASING 7.000 0 7835 6424 26.00 J-55 Tubing String TUBING_ - _ _ Size ~ Top I Bottom I TVD i VVt I Grade _ ~ Thread _ n 2 875 ~ 7386 ~ ~ii 6.50 J-55 UR,D FUE E R _ Perforations Summary ` _ ~ Interval TVD Zone Status ~ Ft SPF Date T e Comment _ _ 7474 - 7494 6130 - 6146 A-4,A-3 20 4 1/11/1986 IPERF 90 de h• 4' HJ II Cs Gun 7506 - 7550 6155 - 6191 A-2 44 4 1/11/1986 IPERF 90 de q ph; 4' HJ II Csg G_un . I /b2SU - /btS6 I 1i21b - 6219 I A-1 I I R I 4 I l/l 1/19?i6J IF'_tHF 19U Mari ph; 4' HJ II Cs!i Gun i Gas Lift Mandrels_ /Valves r St ~ MD ~ D ~ an Man Typ V Mfr V Tvpe V OD L,~ICh~Port ~'TRO Date Vlv Mfr Run Cmnt ~ 7259' S95~ Merla~ TGPD L r.1 . L', I- K _ I ~ ~ X00 _~ r~ 1 , ~nnr - - - Other (plus, a ui -, etc.) -JEWELRY __ _ I Depth TVD ~ Tvpe I Description I ID ! 17386 ~ 6060 TTL_ I I 2.44.1 - - - --- Flsh -FISH Depth i Description I Comment - - -- - - 7734 ~ JUNK on Bottom BALL to Shear had 5 Aluminum Tall -- - - - _ - - __ -. _ - - General Notes I Date (Note - - - _ - --_ -_ ~ !8/13/2003 WAIVERED WELL: T x IA COMMUNICATION. WI ONLY JUNK on Bottom (7734-7739, OD:2.875) MEMORANDUM TO: Julie ,eusser ,'~ ~',-" Commissioner THRU: FROM: State of Alaska Alaska Oil and Gas Conservation Commiasion DATE: July 21, 2001 SUBJECT: Mechanical Integrity Tests Tom Maunder ~.{~¢r~~ P.I. Supervisor ~\"~'~'~'~'~\ John Cdsp Petroleum Inspector Phillips Alaska 3A Pad 3A-11,14,15 GKA Kuparuk River Field NON- CONFIDENTIAL Wetll ~.-11 ! P.T.D.I 185_~380 wel~I 3.~.- 14 P.T.D.I 185~__~r~0 WellI 3A-15 P.'r.D.I 1852830 WalI P.I.D.I walI P.T.D.I Packer ~ Pretest Initial 15 Min. 30 Min. I T~e,nj.i sI T.V.D. I ~o~ ITu~.~I z~ol ~ol =~ol ~ I""~! 4. i Type t-'~--! P I T~I 147~ Icasingl 2c~00 I 3ooo1 30001 30001 P/F I P-- I Type'lni. I S I T.V.D. I aX-IT--ll 27~1 2~! 2~1 2~ I',~,.-,~! 4 T~p~t~l{P I T~p~l ~r~ l Ca~.~! ~ I 2425 ! 2,~1 24001 P/F I P I ,nj-I "! ~-v-~-i ~o~ IT"~",I ~00 I''001 '0~1 .0O I,.,.~! 4' Typet-'~t-I PIT,~I 1476 Ica~ngl 9so I 2~5°1 2~251 21~°! P/F I -P TypeIni. ! I T.V.D. I I Tubir~lI ! I [ I[r"'"~l · ~,e~l I~e~ ~! ! ~ ! I I ! I P~F ! Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N -- NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioacth~ Tracer Survey A= Temperature Armm~y Survey D= Differential Temperature Test Interval I= initial Test 4= Four Year Cycle V= Required by Variance W= Test during Worko~er O= Other (describe irt notes) Test's Details 3 MIT's performed, no failures. Annulus pressures were high on the injecting wells. The wells were bled down the day before State testing. Passed the Standard Annular Pressure tests. M.I.T.'s performed: 3 Attachments: Number of Failures: _.0 Total Time during tests: 2 HRS. CC: MIT report form 5/12/00 L.G. MIT KRU 3Ab 7-21-01jc.xls 7/23/01 STATE OF ALASKA ALASKA OIL AND GAS ~RVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown__ Stimulate B Plugging __ Perforate _ Pull tubing __ Alter casing __ Repair well B Pull tubing ~ Other X 2. Name of Operator ARCO Alaska. Inc 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic 4. Location of well at surface 841' FS, 832' FEL, Sec. 7, T12N, R9E, UM At top of productive interval 1308' FNL, 1368' FEL, Sec. 8, T12N, R9E, UM At effective depth 1231' FNL, 1435' FWL, Sec. 8, T12N, R9E,.UM At total depth 1094' FNL~ 1563' FWL~ Sec. 8r T12Nr R9E~ UM 12. Present well condition summary Total Depth: measured 7 8 5 5' feet true vertical 6440' feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 72 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3A-14 9. Permit number/approval ~qumber Permit #85-282 ,/.-7 -:z ~ 10. APl number 5o-029-21 490 11. Field/Pool Kul3aruk River Oil Pool Effective depth: measured 7556' feet true vertical 6196' feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 107' 16" 3680' 9-5/8" 7835 7" Cemented Measured depth True vertical depth 165 SX AS II 107' MD 107' TVD 1450SXAS III & 3680' MD 3181' TVD 310 Sx Class G 350 Sx Class G & 7835' MD 6424' TVD 175 SX AS I measured 7580'-7586', 7506'-7550' MD true vertical 6215'-6219', 6156'-6191' TVD Tubing (size, grade, and measured depth) 2-7/8", 6.5 #/ft, J-55, EUE, 8 round w/tail @ 7386' Packers and SSSV (type and measured depth) Brown HB Packer ~ 7316'; Baker FVL SSSV ~ 1797' 13. Stimulation or cement squeeze summary 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 Prior to well operation 445 575 0 500 130 Subsec~uent to operation 1400 80O 1380 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ 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 06/15/88 - ' ~' Service Water Injection Date ,,/ 6> '1' / q~ '3/ SUBMIT IN DUPLICATE RCOAlaska, inc. DRILLSITE STATUS REPORT DATE: TIME: WELL ST Z PRODUCTION WELL STATUS GAS LIFT STATUS NO. A O T N U E FTP TEMP CHOKE 7"CSG 10"CSG GAS INJ METER WELL S PSI F BEAN PSI PSI TEMP HCF TOTAL SI/HR REMARK ,, 5 T 6 [oo 3T' ~ ~o 8T~ .- LL NI ALLOVVABLE iNJECTION ',,','ELL S' ~ TL,'S CHART TOTAL TOTAL J ~N J~%1 WH TCMPICHOKE T'CSG 10 CSGi METER CALC ,,~,lJ ~l',lj .'.,¢: ' ~ . PSI -F BEAN PSi PSi ~ TOTAL MMSCF BBLS '.~MSCF GASCOnnr~CrOn = %~ ~- ~,T~ HEAOERPRESS = ] ~ ~ TOTAL FORDS DR~LL SiTE PROD TEST PROD J TEST BATH BLANKET RUN TIME ~EATER TEMP TEMP PSIJ PS' TEMP GAS J OuT,~*' I~' - CHEMICALS TYPE GAL DA ~ COMMENTS. OPERA,'ORS SIGNATURE. LI~ ~ ARCO Alaska, Inc. 1 WELL ST Z PRODUCTION WELL STATUS GAS LIFT STATUS NO. ' A O T N U E FTP ~TEMP CHOKE! 7"CSG 10"CSG GAS ~NJ METER WELL S PSI F BEAN PSI PSi TEMP HCF TOTAL SI~HR REMARK , MAX)MUM oZ ALLOWABLE INJECTION WELL ,~,~TUS . j ',1 ,,NJ '~' i ~r4J INJ WELL ' PSI F BEAN PSI PSI tOTAL I 1~~ , G~SCO~=~CTOR = ~EATE~[ ,EMP[ TEMP PSI PSI TEMP GAS PSI CHEMICALS TYPE GAL~DAY CO,MMENTS ATTACHMENT 1 PAGE 2 KUPARUK RIVER FIELD CONSERVATION ORDER 198 RULE 11 - INJECTIVITY PROFILES SECOND QUARTER 1987 SUBMITTAL WELL APl DATE OF DATE OF DATA TYPE REASON FOR NUMBER NUMBER INITIAL PROFILE/ PROFILE/ PROFILE/ 50-029 INJECTION SURVEY SURVEY SURVEY WELL ZONES COMPLETION TAKING WATER INJECTION BWPD 2B-11 21089 2H-O1 20033 2H-O. 20027 11/19/85 06/16/87 SPINNER FOLLOWUP 03/15/86 06/05/87 SPINNER FOLLOWUP 03/15/86 06/07/87 SPINNER FOLLOWUP A&C S A&C A&C S A&C A&C S a&c 50-103 2T-O. 20074 2T-09 20071 2T-11 20075 2T-15 20062 2T-16 20063 03/30/87 06/13/87 SPINNER INITIAL 03/30/87 06/16/87 SURVEY INITIAL 03/30/87 06/21/87 SPINNER INITIAL 03/30/87 06/16/87 SURVEY INITIAL 03/30/87 06/16/87 SURVEY INITIAL A&C SS A&C A S A 3485 A&C SS A&C A&C SS A 1833 A&C SS A 590 50-029 3A-02 21431 3A-Oq 21h33 3A-10 21457 3A- 14 21490 / 01/21/87 01/21/87 01/21/87 01/21/87 04/1./87 05/25/87 SPINNER INITIAL 05/81 SURVEY INITIAL 05/87 SURVEY INITIAL 05/27/87 ~'~ INITIAL 05/87 SURVEY INITIAL / · A&C SS A&C A&C SS A 2500 A S A 1200 A&C SS A&C A S A 1650 RECEIVED Al~ka Oil & Gas Cons, Commission Anchorage RECEIVED c,// STATE OF ALASKA ALASK,, OIL AND GAS CONSERVATION COMN, .SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon - Suspend - Operation Shutdown -- Re-enter suspended well Alter casing Time extension- Change approved program ~-- Plugging- Stimulate- Pull tubing - Amend order Perforate Other ,X 2. Name of Operator APCO Alaska, Inc 3. Address 6. PO Box 100360, Anchorage, AK 995]0 K~ 4. Location of well at surface 7. 841' FSL, 832' FEL, Sec. 7 T12N RgE, UH 3A At top of productive intervaF ' ' 1308' FNL, 1368' FEL, Sec. 8, T12N, R9E, UF. At effective depth 1231' FNL, 1435' FWL, Sec. 8, T12N, R9E, UM At total depth 1094' FNL_. 1563' FWL: S~c_ R: T1 ?N, RgF; tiM 11. Present well condition summary Total depth: measured 7855' MD feet true vertical 6440' ND feet 5. Datum elevation (DF or KB) RKB 72 Unit or Property name paruk RivPr IInit Well numbeF -14 8. PeFmit numbeF Permit #85-282 9. APl numbeF 5O-- 029-21490 10. Pool k:uparul~ Piver Oil Pool Plugs (measured) None feet Effective depth: measured 7556' MD feet true vertical feet 6 I96' MD Casing Conductor Surface X X ;4 ~ ~Xm'~! ke~te Production xx~e/xxxxx Perforation depth: Junk (measured) None Length Size Cemented Measured depth True Vertical depth 7835' measured 7835' MD 6424' TVD 107' 16" 165 SX ASII 107' MD 107' TVD 3680' 9-5/8" 1450 SX ASIII 3680' MD 3181' TV~ & 310 SX Class G 7" 350 SX Class G & 175 SX ASI 7580'-7586' MD, 7506'-7550' MD true vertical 6215'-6219' TVD, 6156'-6191' TVD Tubing (size. grade and measured depth) I-, '- ' '¢ [ ~ - .~-.. __ I 2-7/8", 26#/ft, J-55, EVE, 8 round w/Tail @ 7386' Packers and SSSV (type and measured depth) Rrnwn HR P~rl~er _~ 73!6'- Baker FVL SSSV .~ !797' "' 12.Attachments Description summary of proposal ~ Detailed operations program BOP sketch Convert well from oil producer tn wai'_~r i n..i~rfrlr 13. Estimated date for commencing operation April 12~ 1987 14. If proposal was verbally approved Name of approver L. Smith /0- ~Of'/ ,'O /~' ~ Date approved 4/10/87 15. t hereby certify that the foregoing is true and correct to the best of my knowledge /L} , t? ' L" Signed ,-. cLt..,(;¢ F),.-'~I:¥1...~ _ -¢ ,, '1- r -¢k/ Title Sr. Operations Engineer Commission Use Only Date 4/13/87 Conditions of approval Notify commission so representative may witness - Plug integrity - BOP Test - Location clearance !.~! J,,,e..=,.i y ,...S~. ,..--,~ '. Approved by ~mlss~o~r ' Form 10-403 Rev 12-1-85 Approval No. the commission Date Submit/4'n'~'r'glicate ARCO Alaska. In,. Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATe 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 09-15-86 T.~LkN SMiTTAL ~ 5761 Transmitted herewith are the following items. Please acknowledge return one signed copy of this transmittal. Final Prints: Schl: CET or CBL Logs: One * of each lA-7 12-03-85 Run #3 7585-8532 lA-14 .12-05-$5 Run #1 4550-4850 1H-4 12-26-85 Run ~2 6893-7466 1H-8 12-08-86 Run #3 7875-8368 1H-8 12-09-86 Run ~4 7850-8450 lQ-9 01-28-85 Run ~1 4898-6534 lQ-13 06-02-85 Run ~1 5300-7621 2C-16 02-19-85 Run ~1 7200-8294 2E-9 01-14-85 Run ~1 6780-8052 2E-15 01-12-85 Run ~1 3350-6874 2E-16 01-12-85 Run ~1 4840-7578 2H-lO 12-05-85 Run ~1 6500-7863 3A-7 11-04-85 Run ~1 5726-7164 3A-11 12-15-85 Run #1 5796-7206 3A-12 12-16-85 Run ~1 6426-7768 3A-13 12-29-85 Run ~2 5644-7482 3A-14 12-29-85 Run #2 5462-7744 3C-13 10-30-85 Run ~1 7075-9474 3F-5 11-13-85 Run #1 6947-8647 3F-6 11-13-85 Run #1 4600-7570 3F-9 12-19-85 Run ~1 6188-7490 3J-5 12-22-85 Run ~1 7000-8636 receipt and Receipt Acknowledged: Vault*films A]P..sI-m Oil & Gas C~ns. Date: ~:h0rage NSK Files*bi STATE OF ALASKA ALASKA O,L AND GAS CONSERVATION CO,v, MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG r ; 1. Status of Well Classification of Sera,c,' '.',e,~ :OIL ~XX GAS -- SUSPENDED -- ABANDONED -- SPR\/IC~ -- ' 2. Name of Operator ARCO Alaska, Inc, 3. Address P. 0. Box 100360, Anchorage, AK 99510 7. Permit Numi)e: 85-282 8 APl Number 029-21490 5O 4. Location of well at surface 841' FSL, 832' FEL, Sec.7, T12N, RgE, UN At Top Producing Interval 1308' FNL, 1368' FWL, Sec.8, T12N, RgE, UM At Total Depth 1094' FNL, 1563' FWL, Sec.8, T12N, RgE, UN 5 Elevation in feet lindicate KB, DF, etc.~ i 6. Lease Designation and Serial No. 72' RKB I ADL 25631 ALK 2565 12. Date Spudded 13. Date T.D. Reached i 14. Date Comp., Susp. o,- ADand. 02/02/85 1 2/09/85 I 2/11/85* 17. Total Depth (MD-TVDt 18. Plug Back Depth (MD-TVDi 19. Directional Survey 7855 'MD ,6440 'TVD 7746 'MD ,6350 'TVD ~. YES ~ NO _-- Kuparuk River Unit :0. Wel', Numt~e, 3A-14 ~ 1 P,eld an~] Pool Kuparuk River Fi eld Kuparuk River 0~] Pool N/A 'ee: LISL 1 20. Depth ','~he~e SSSV se:I 21 Th,c. ness -~i Pp,m :~' ~s' 1797 ~ee' MD i 1550' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/SP/GR, FDC/CNL, Ca1, CET~ GCT 23. CASING SIZE WT. PER FT. 16" 62.5# 9-5/8" 36.0# 7" i 26.0# GRADE H-40 CASING, LINER AND CEMENTING RECORD HOLE SIZE i CE',3ENTi:'iG RECORD 24" 165 sx AS II SETTING DEPTH MD TOP BOTTOM Surf 107' Surf 3680' Surf 7835' A".I© LJ ',~ T PULLED J -55 ' J-55 8-1/2" 350 sx Class C & 175 sm AS I 24. Perforations open to Production (MD-TVD of Top and Bottom and inte.val, size and numbert 7580' - 7586' w/~ spf 7506' - 7550' 27. N/A 12-1/4" 1450 sx AS III & 310 sx Class C SIZE 2-7/8" 25. TUBING RECORD i DEPT~ SET ~%~D~ P&CKE~, ~ET ~".~D~ 7386' ~ 731fi' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ' / A%1OUNT & KIND OF ~.IATERIAL '~q~D DEPTH iNTERVAL ~,MD~ See attached Addendum, dated 2/27/86. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.~ ! TEST PERIOD Flow Tubing i Casing Pressure 'CALCULATED Press. i '.:4-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core cn~ps. c0~s. Form 10-407 Rev. 7-1-80 * NOTE: Tubino was run and the well perforated 1/11/86. GRU1/WC12 CONTINUED ON REVERSE SIDE __ .~L~l!r~ i' fl 29. NAME Top Kuparuk ¢ Base Kuparuk £ Top Kuparuk A Base Kuparuk A GEOLOGIC MARKERS MEAS. DEPTH i, i: TRUE VERT. DEPTH FORMATION T ES-[ S Include interval tested, pressure data GOR, and time of each pi~ase 7359' 7370' 7462' 7609' 6038' 6047' 6120' 6237' N/A 31. LIST OF ATTACHMENTS Addendum (dated 2/27/86) 32. I hereby certify that the ,%regoiqg ,s trde and correct t.o the best of my kno~,,,ledge Associate Engineer Title r. INSTRUCTIONS General' This form is designed for submitting a complete and correct well com,,)iet~r)r, re;'..,r' ar',(J loft all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injectior~, ;:~' :nj(~.ction, su!T water disposal, water supply for 'niection, observation, injection for in-situ combust,r;n. Item 5' Indicate which elevation is used as reference (where not otherwiseshownl for ~tel)th ~,;asure~ents 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 on~.~ interval lmult~[)le completion), so state in item 16, and in item 24 show the producing intervals for only ti~e interval reported in item 27. Submit a separate form for each additional interval to be separately [~roduced, showinq the data pertinent to such interval. Item 21' Indicate wheti~er from ground level IGL) or other elevation (DF, KB, etc.). Item 23' AttaChed supplemental records for this wel should show the details of any' multipl~; s~aq~.~ cument lng and the location of the cementing too!. Item 27' Method of Operation' F owing Gas ~if*,_ ., Rod Pump, Hydraulic Purr,~). Su!}mersii)le, Water jection, Gas Injection, Shut in, Other explain. Item 28: If no cores taken, indicate "none". 10-407 ADDENDUM WELL: 12/19/85 12/30/85 2/07/85 3A-14 Arctic Pak well w/175 sx AS I, followed by 62 bbls Arctic Pak. Rn CET log f/7744' WLM to 5610' TOC. Rn GCT gyro. FRACTURE STIMULATION SUMMARY Begin Frac Work At: 1555 hrs, 2/7/86. AFE: AK0367 Frac'd Kuparuk "A" sand perfs 7474'-7494', 7506'-7550' & 7580'-7586' in 7 stages per 1/31/86 procedure using gelled diesel w/Musol, 100# mesh & 20/40 sand. Press'd ann to 1610 psi w/diesel. Tst ins to 7200 psi; OK. Stage 1: 35 bbls 5% U-66 Musol @ 5 BPM w/final pressure of 2900 psi. Stage 2: 50 bbls gelled diesel pre-pad @ 15 BPM w/final pressure of 5400 psi. Stage 3: 19 bbls gelled diesel w/lO0 mesh, 20.4 BPM w/final pressure of 5050 psi. Stage 4: 64 bbls gelled diesel pad @ 20 BPM w/final pressure of 4670 psi. Stage 5: 23 bbls gelled diesel w/20/40 mesh @ 20 BPM w/final pressure of 4580 psi. Stage 6: 43 bbls gelled diesel w/20/40 mesh @ 20 BPM w/final pressure of 5420 psi. Stage 7: 44 bbls gelled diesel flush @ 18 BPM w/final press of 5420 psi. Pmp'd 800# 100 mesh + 2500#, 3 ppg 20/40 & 10,008# 20/~0, 8 ppg, leaving 492# 20/40 mesh sand. Job underflushed by 2 bbls in 7". Load to recover 249 bbls of diesel. Job complete @ 1712 hrs, 2/7/86. Drilling Superintendent Z D~te ARCO Alaska. Inc. Post Office B,.^ 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 February 13, 1986 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- 3A-14 Dear Mr. Chatterton' Enclosed are the Well Completion Report and gyroscopic survey for the subject well. If you have any questions, please call me at 263 -4944. Sincerely, ~. Gruber Associate Engineer JG/tw GRU13/L122 Enclosure STATE OF ALASKA ALASKA O,L AND GAS CONSERVATION CO~.,,.llSSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification i OIL ~X GAS _ SUSPENDED _ ABANDONED __ SERVICE __ t 7. Permit Num!)e, 2. Name of Operator ARCO Alaska, Inc, ' 3. Address P. 0. Box 100360.. Anchorage.. AK 99510 ' 4. Location of well at surface 841' FSL, 832' FEL, Sec.7, T12N, RgE, UPI At Top Producing Interval 1308' FNL, 1368' FWL, Sec.8, T12N~ RgE, LIN At Total Depth ~ 85-282 i 8 APl Numbe, 5O 029-2149(3 9 Unit ,}' Lease N~m+, Kuparuk River Unit 10. Well Num,)e, ~A-14 1094' FNL~ 1563' FWL.. Sec.8; T12N~ R9E. UM Kuparuk River Fie~o 5. E!evation in feet (indicate KB, DF, etc.) 6.'Lease Designation and Serial No. Kuparuk River 0i 1 Pool 72 ' RKR , AD! ?=,¢,~1 Al K 12. Date Spudded 113. DateT.D. Reached , 14. Date Comp., Susp. or ADand. I 15 'Crater Dep:h,,'o~'shnre ,6 N) ..,f C ~ : s 02/02/85 12/09_/8.5 , 12/11/85- N/A ~ee; '..! S L 1 17. Total Depth (MD-TVD~ I18.PIugBackDepth(ME)-TVD' 19. Directiona'Survey. _ [20' Dep~h''~heresssVse: I 21 Tn'c ~'''~-p~'m;'''~s', 7855'ND_C,b,~,0'TVD 77~,R,MD;R.~,0,TVD YES ~¢X NO ~ 1797 fee: ;:ID i 1550' (Approx) ~2. Type Electric or Other Logs Run DIL/SFL/SP/GR, FDC/CNL, Cal, CET, GCT 23. CASING, LINER AND CEMENTING RECORD CASING S :,~ IZE WT. PER FT. 711 GRADE SETTING DEPTH MD TOP BOTTOM I ~'"/ ! ! 24. Perforations open to Production iMD-TVD of Top and Bottom and interval, size and numuer) 7580' 7586' w/6 spf 7506' - 7550' HOLE SIZE CE".'ENTING RECORD A",iO d N T PULLE[; _,_,,., sx ,.,aso ,. & 175 o-.,, AS t 25. TUBING RECORD SIZE DEPTH SET ,:~.ID~ PACKER SET 2-7/8" 7386' t 7316' 26. ACID, FRACTURE, CEMENT SQUEEZE ETC DEPTH INTERVAL t~.lD} I &MOUNT & KIND OF MATERIAL USED 27 , N/A PRODUCTION TEST Date First Production Date of Test Hours Tested Flow Tubing Press. Casing Pressure I Method of Operation (Flowing, gas lift, etc.t PRODUCTION FOR OIL-BBL TEST PERIOD II~ CALCULATED i OIL-BBL 24-HOUR RATE ~'i GAS-MCF VVATER-BBL I CHOKE SIZE ! GAS OIL RATIO i ! GAS-MCF i WATER-BBL OIL GRAVITY APl icor~, ~ I 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or ,.~ater. Sui3rnit core ch~ps. NONE Form 10-407 Rev. 7-1-80 * NOTE: Tubing was run and the well perforated i/ii/86. TEHP3/WC78 CONTINUED ON REVERSE SIDE 29¸ NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A I GEOLOGIC MARKERS FORMATION TESTS Include interval tested, pressure data, all fluids ~ .... ~,e(; _.qd d',,, .:~, GOR, and time of each phase MEAS. DEPTH TRUE VERT. DEPTH ~ 7359' 7370' 7462' 7609' 6038 ' 6047 ' 6120' 6237 ' N/A %1 L~ST OF ATTAC~ME'~TS We!l-q4istery, Gyroscopic Survey (2 c~>pies~-- -- 32 I hereby certify that the foregoing is true and correct :o the best o' rn¥ ~nov~,e~oe INSTRUCTIOtNS General' This form is designed for submitting a comp!ere and correct well completion rer,qrt and ,,:; o[-; al! types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection. t,~ater disposal, water supply for injection, observation, i~jectio~ for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measureme, r~ts 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 interva! (muitipi~ completion), so state in item 16, and in item 24 show the producing intervals for only the interval re~,nrted in item 27. Submit a separate form for each additional interval to be separately produced, showinq 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 staqu ~.-_ment ng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, V,.,'a~,ur tt~ jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Fo,m 10-407 ARCO Oil and Gas Company Daily Well History-Final Report Instructions: O,e=are a",c su,~,'~,: t~e "Final Report" cr' "Final Repo~" s~c~:c De su=--<~e~ aisc *ne- cce-a~,o~s a~e s~scerce~ ~ecu:rec ~ccn co--: et,or. 'eso~ com~e:;cn and ,epresentatve :est ca:a n ~,oc~s r,ov,ced T"e "Final Repo~" 'o,m -ay De usec for -erc,t n~ t~e e~hre oaerat~cn , state s a,a. az e Accou'~t,"g cost der, reT code Alaska North Slope Borough I Alaska F.ed Lease o- ~r~,t ,"~ mo Kuparuk River ADL 25631 3A-14 Auth. or WC mo ~Tite AFE AK0367 J Completion Nordic I API 50-029-21490 Oceratc' ~A m! Co W: ARCO Alaska, Inc. I 56.24% S~uCced or W C =,egun ~Date Complete I 1 / 11/86 Date and decth as of 8 00 a ~ 1/11/86 thru 1/13/86 Complete record for each day reported I otal number of Wells (acnve or ,nact*vel on cst center prior to plugging and bandonment of th~s well our I Pmor status 0000 hrs. 7" @ 7835' 7746' PBTD, RR Diesel in tbg ann Accept rig @ 0000 hrs, 1/11/86. NU BOPE &tst to 3000 psi. RU SOS, perf w/4" guns, 4 SPF, 90° phasing f/7580'-7586' & 7546'-7550', 7506'-7546' & 7474'-7494'. RU & rn 236 jts, 6.5#, J-55 EUE 8RD tbg w/SSSV @ 1797', PBR @ 7304'' HB Pkr @ 7316' . "D" Nipple @ 7353' & TT @ 7386'. Set &tst pkr, shear PBR, tst SSSV. NU &tst tree. Displ well to diesel. Secure well w/BPV. RR @ 1730 hfs, 1/11/86. Old TD New TD Re,eased .,`g Date 1730 hrs. C:ass;ficat,cns oi! gas e:c Oil Flowing mrocucmg method /11/86 Tyce :o--=~et on s ~g e Single C¢',c,a ,eser,,c,, Kuparuk Sands 7746' PBTD Rotary =oter':,a test :ara '¢'¢eli no 2a:e Rese%.o~r P-ccuc,ng ~r~:e~,a; C,, or .gasTest t --e m-ce.cT ,on C c~ test Gas 2e~ ~ay Pump s~ze. SPM X lePgth ChoKe sze T cor'ecte~ Signature Date tT~te For form preparation and ~tnbution. see Procedures Manual. Section 10. Dri hng Pages 86 and 87 Drilling Superintendent AtlanticRichfieldCompany '~' Daily Well History-Initial Report Inatm~etie~te: Prepare and submit the "Initial ReINed1" on the first Wednesday after a well is spudded or workover operations are started. Daily wort< prior to slxJclding should be summarized on the form giving inclusive dates only. District 1 County or Parish Alaska Field ILease or Unit Kuparuk River Auth. or W.O. no. ITitle I AFE AK0367 North Slope Borough ADL 25631 State Alaska IWIll no 3A-14 Drill Parker 141 AP1 50-029-21490 Operator ARCO Alaska, Inc. S~d~¢l or W.O. begun IDate Spudded I Date amt del~t ae of 8.-00 12103/85 12/o4/85 12/05/85 12/06/85 12/07/85 thru 12/09/85 Complete record for each day reported J Hour 12/2/85 2215 hrs. tA.R.Co'a W.I. Prior ItltUI if a W.O. 56.24% 16" @ 107' 523', (416'), DD Wt. 9.3, PV 5, YP 5, PR 9, WL 24.2, Sol 7.3 Accept rig @ 1800 hrs, 12/2/85. NU diverter sys. 2215 hfs, 12/2/85. Drl surf hole to 523'. Spud well @ 16" @ 107' 2250', (1727'), Drlg Wt. 9.5, PV 6, YP 18, PH 8.0, WL 31.4, Sol 8.0 RIH w/BHA, drl, DD & surv to 2250'. 928', 5.7°, N34.4E, 927.84 TVD, 6.36 VS, 5.25N, 3.59E 1238', 17.4°, N27.2E, 1230.64 TVD, 70.21VS, 58.75N, 38.46E 1616', 27.4°, N32.9E, 1579.24 TVD, 215.24 VS, 181.13N, 116.45E 2158', 39.2°, N33.4E, 2029.25 TVD, 515.59 VS, 435.39N, 276.81E 9-5/8" @ 3680' 3700', (1450'), Bleed press off 9-5/8" csg Wt. 10.1, PV 10, YP 5, PH 7.6, WL 24.6, Sol 13.3 Drl & surv 12¼" hole to 3700', CBU, TOH. RU & rn 93 Jts, 9-5/8", 36~, J-55 HF/ERW BTC csg w/FS @ 3680', FC @ 3598'. Cmt w/1450 sx AS III, followed by 310 sx C1 "G". Displ using rig pmps, bump plug. 2470', 40.8°, N33.7E, 2268.24 TVD, 716.11VS, 602.53N, 387.65E 2841', 41.4°, N35.3E, 2547.60 TVD, 960.00 VS, 803.52N, 525.79E 3215', 41.3°, N34.6E, 2828.36 TVD, 1207.08 VS, 1006.04N, 667.34E 3665', 39.5°, N37.2E, 3171.05 TVD, 1498.66 VS, 1242.29N, 838.36E 9-5/8" @ 3680' 3750', (50'0, TOH w/turbine Wt. 8.5, PV 1, YP 2, PH 11, WL NC, Sol 1.3 ND diverter sys. NU & tst BOPE. RIH, tag FC, tst csg to 2000 psi. DO FC, cmt, FS + 10' new hole. Conduct formation tst to 12.5 ppg EMW. TOH, PU turbine, TIH, drl to 3750', POH. 9-5/8" @ 3680' 7800' TD, (4050'), Circ Wt. 10, PV 14, YP 15, PH 9, WL 10.8, Sol 11 TIH, drl & surv 8½" hole to 7800', circ f/short trip. 4056', 42.7°, N36.6E, 3465.69 TVD, 1755.49 VS, 1447.84N, 992.69E 4682', 42.0°, N35.7E, 3917.96 TVD, 2188.16 VS, 1794.94N, 1251.24E 5023', 39.0°, N35.2E, 4177.26 TVD, 2409.60 VS, 1975.35N, 1379.69E 5635', 37.1°, N36.0E, 4662.82 TVD, 2781.96 VS, 2275.90N, 1599.75E 6636', 37.1°, N33.1E, 5462.78 TVD, 3383.45 VS, 2762.53N, 1953.58E 7512', 37.1°, N42.1E, 6162.85 TVD, 3909.64 VS, 3196.01N, 2251.61E The above is correct Signature For form 13reDaration and dislllibution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. lDate Title Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report t Inshuctiofls: Prepare and submit the *'Final Report" on the first Wednesday after a!lowaDle has been assigned or well ~s Plugged. Abandoned or Sold "Final Report" should be subm,tted also when operations are suspended for an indefinite or appreciable length of time. On wsrKovers ,*,'"e~ an official test ~s not reclulred ubon completion, report, completion and representative test data in blocks Crowded The "Final Report" form may be used for ,eoor!,ng the eh!rte operabon ~f space is avaHaPle. District Alaska County or Parish Field Lease or Umt Kuparuk River Auth. or w.o.A.FEnO. AK0367 T tie North Slope Borough Accounting cost center code State Alaska ADL 25631 IWe,, ~A- 14 Drill Parker 141 API 50-029-21490 Operator I A.R.Co. W I. ARCO Alaska, Inc. t 56.24% Spudded or W.O. begun Date Spudded 12/2/85 12/lO/85 12/11/85 12/18/85 Complete record for each day reported - Date and depth as of 8:00 a.m. Iotal number of wells (active or ~nachve) on th~s~ DSt center prior tO plugging and / bandonment of this well our 1 Prior status ~f a W.O. 2215 hrs. 9-5/8" @ 3680' 7855', (55'), LD 5" DP Wt. 10.3, PV 8, YP 6, PH 8.5, WL 8.6, Sol 10 15 std short trip, circ hi-vis sweep, POH. RU Schl, log DIL/GR/SP/SFL f/7800'-3679', cont w/GR f/3679'-145'. Rn FDC/CNL f/7800'-7250' & CAL f/7800'-6500', RD Schl. TIH, drl to 7855', 20 std short trip, C&C, POH, LD DP. 7760', 33.4°, N45.9E, 6365.38 TVD, 4050.85 VS, 3298.97N, 2351.04E 7" @ 7835' 7746' PBTD, RR 10.0 ppg NaCl/NaBr in 7" csg to 7746' Chg rams to 7", tst to 3500 psi. RU & rn 180 jts, 7", 26~ HF/ERW csg w/FS @ 7835', FC @ 7746'. Cmt w/100 sx Cl "G" w/50/50 Healey flyash, followed by 250 sx Cl "G". Bump plug. Instl pack-off & tree. Tst pack-off to 3000 psi. RR @ 0330 hfs, 12/11/85. Arctic packed well w/175 sx AS I. Old TD Released rig 0330 hrs. Classifications (oil, gas, etc.) Oil INew TD t PB Depth 7855' TD 7746' PBTD Date Kind of rig 12/11/85 Rotary Type completion (single, dual. etc.) Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Product'on 0,1 on test Gas Der day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Grav,ty AllowanCe Effect,ye da~e corrected The above is correct Signature J Date J Title I For form preparation anl~ distribution, see P~cedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent $UB-$URFACE DIRECTIONAL ~URVEY [~ UIDANCE [~ONTINUOUS [~OOL Company Well Name ,, Field/Location ARCO ALASKA INCORPORATED ! 3A-14 (841' FSL, 832' FEL, S7, T12N, R9E) KUPARUK , NORTH SLOPE, ALASKA · Job Reference No. 71182 Loaged By: S A_L_4~AR Date 27-JAN- 1986 Comput~ By: HALSTEAD ]CT Di~ CEI]~.~.4L %J~EY F3,:R 'RC" &L&SK&~ IN~. -J',/-¥ 3&f-: 12-30-{5 i - · _ v -,' '. .... Tr..., ~' ~ '.: _.. '',f. ,-.-:7:j 'ST '" 3xlT] ~ T&:,tG-f .',ZI'"IJT.'t 3F q]...kT~ 3- DE] 35 '~.["'1 ;'"&ST 'SAT=: Z6-J6N-R5 f~d' SJ3-SEA 'l'~5'dq;3 V'~TZ~&L V'~TICAL 3.;)2 O.J} -?Z.O0 120. }3 i,)r', ,},3 .:.].00 232.23 'JO. )'] 125.00 ~3.3.')3 ~J~. ).l ']]~.OO ~,] 3.3 ] ~ .~'~. 'T .:, ~ 2 'l. 73 1]]C.J ] 1130.33 109/.31 102q. ql 1338.3} 12J~.]~ i217.$: 1;bO.3] 13,~3. ]7 1311.07 1¢33.33 173~. 7 ~,"'~JRS'_, DEVI~TI3'~ AZI'4JT'~ 3EG '4Ih 3-3 ~ll", ~ '&. 51JR F_. 3130.3'3 '73~.'~ .~_~3;. 33 Z ~ 1 ,-,,. ,) 3330.32 Z- 5~.~.., 3533.33 .'.~1. 'l 3':3).33 1!7..:; 3727. ').;' ~Z 2';. .5 '/ J ,.~ · .' J , '~ . DATE 3F SJRVE?: 12-33-85 ,('LLY 5JSHING ELE~AT[]N: EN3INEER: S6LAZAR ] 3EPTH qESTANT, ULAR NDRTH/SOUTq FEET 0.00 3.13 0.17 '3.58 0. '~ 1 1 · 39 Z.13 3.29 5.01 10.55 72.00 F' ' 23.57 '.32 20. i 42.15 2.87 35. -, 55.12 5.27 54. _ )5.52 3.57 ,~1. ". 131.92 1.'~0 111. . 171.,33 1.67 144. - 2 i ?. 2,3 ~. 11 17'9. : ? 5']. ~6 Z. 7 ~ 21 ). ' ~11.:~0 2.76 253. z 355.95 Z.03 311. 424. ~6 1.72 360. %5'5.23 2.03 ~11. 54~.34 1.13 453. 513.15 0.23 517. ~7~.29 0.2~ 571. 743.65 0.25 52~. ~0).25 0.31 573. q7~.~l 3.25 732. ~0.55 3.5~ 786. 1005 ~I 0 2~ ~41 1073.32 3.1~ 113).90 3.25 ~50. llOo. ~3 O.~O 1004. 1272.40 1 ~7.q7 3.55 1112. 14,32.77 3.45 115~. i~7.]0 3.51 1217. 153'3.57 3.45 1263. 15~,.45 0.9~ 1329. 115~.41 1.15 1373. C33RDiN FzET O.O0 0.05 0.53 O.JZ 1.3~ 1.75 2.05 2.2~ 2.7~ 5.05 22 ~O ~0 73 56 51 05 12.37 22.8-~ 37.01 51.)5 70.11 91.39 115.:35 lg0.25 155.68 195.~5 41 04 22 11 91 90 ~,7 225.J2 255.57 293.81 333.D~ 355.5u 40'5.7w 441.03 47~.23 515.~ 553.27 35 53 75 55 37 35 7~ 32 591.25 557.~3 705.17 744.18 7~1.83 31~.24 855.27 893.47 931.55 ATE$ .N3R~,Z.., O.UO": 0.1~ 0.52 1.OB 1.62 2.23 2.99 3.~8 5.72 12.25 f 23.71 E 42.17 E 65.13 E 9,5.5~ E 132.04 E 171.17 E 213.32 = 250.52 E 312.05 E 367.30 ~25.37 485.56 543.75 513.55 579.57 575.23 }43.~3 i007.36 1373.55 1140.10 1205.51 1272.55 1333.10 1+32.q9 1~67.3) 1530.55 155~,46 OEO~RTURE AZIMUTH OEG 25 34 E 71 27 E 57 46 :: 55 4 ,~ 51 50 - 43 13 E 28 41 i 2'~ 35 E 31 27 E 32 52 E 34 1 E 32 33 E 32 4 E 32 15 E 3Z 38 E 32 33 E 32 17 E 32 7 E 32 4 = 32 10 32 22 E 32 32 - 32 a: 32 51 33 0 33 7 33 13 E 33 19 E 33 25 E 33 30 5 33 35 E 33 42 i 33 47 E 33 52 E 33 56 E 3~ 0 i 34 4 5 3~ 8 5 3~-1q. K JoAR,J<. ', 3 :,,' T d SLJ~A' C3 .IPJT&TID'~ ~-6- J ~, -35 DATE ]F SURVEY: 12-3)-85 <ELLY 5USHING ELECATION: ENGINEER: ,SALAZAR 72.00 FI ZNTZ4P3L~T ] VaLJSS '-34 -"l="l 130 FEET 5133.33 ~Z33.,3 ~.151.~3 5;'30.33 ,]12.57 ~242.~7 5~3J.33 ,~7!.~7 ~39~.57 ~530.33 ;~33.1a ~ 5:33. 33 ,7~3.77 ~7i7.77 ol30.23 ~ 33.3. 30 "'JJ?S' V:?TICAL 33GLEG 3Er 7. IT l"~ ;1Z I',! J T ~ S=CflDN SEV-RIT¥ OEG ql ~ 9-] ,',~IW FE~T DES/t00 42 15 '% ?~'::)ll ' 1725.T0 1.80 43 'q "4 3~ ~ : 179]..59 1.05 44 -) '.1 ~ ' ;';~ - 1)52.~1 3.9) ~5 1.1 ',l :.~ ~5 ' 1:~32.39 1.07 :.,.5_'4 -, 4 Z ~ -;3 1~ ,il 51 'q '~5 15 - 2211.67 3.77 ~0 51 q 35 21 J :L2'/'7.73 0.87 39 53 N ?5 21 ,f 23~2.56 1.2~ 3' ;': ;~ ~'~ '2~, - _>:,35.35 0.,¢5 3! :,¢ xl 35 31 5 2457.81 1.03 37 17 N 3~ 17 ~ ~528.52 3.3) ~7 33 ~ 35 17 _' 25~'9.3~ 9.30 ~7 33 ~ ~5 12 . !553.18 0.43 .,~ :2 '4 ~5, 1~ - 271I.i~ 0.22 q7 !7 '~ gE 31 : '772.01 3.4'¢ X7 2 '~ ~: '9 .--' ~¢2.~3 ,j77.7J :'23'~. 27 :..,7J 3~- .57 ' -,.j ~, . ~5 5<i".I~ )~7.~3 ~'~ J7 ',i 5~ ~ = 3312.45 ].13 3fi :~5 'J 3q 33 : $372.01 3.~7 3~ ~o 'q ~:, 5 _- 3131.51 0.42 ~ ~, '~ ~5 37 .. 3191.35 3.35 ~ ~5 '~ ~ ' : 3251.2~ 3.35 "q,. :,2 ',l ~ 53 - 3 ~11.1~ '~ 3.23 '~l 2 'J ~ 57 : 3371.15 ~.17 77 _ '~ ~' 33 - ~-~1.47 3.37 , . -- · '.22 37 ' ~ ~* ~ 3~1 77 u 37 1 N ~ ~3 : 5552.16 3.47 5.3 : 3512 ~5 3 37 · L · 51 : ~572.05 0.12 1 = 3732.00 3,8~ ,7 : ~791.43 3.00 35 : 3~53.,31 1.47 17 ~ ~911.22 0.63 15 '- 3~73.2~ 1.27 1 ~ ,~ ~,3~3.4~ O.OD 1~ ~1!3.73 3.03 MEASURED JEPTH RESTANDUL~R NDqTH/S,DUTH 1~25.79 1~81.50 1537.~2 1594.3~ 1552.10 1709.32 1F65.$2 1~20.14 1373.~0 1~25.52 1051.52 E 1862.$3 1092.74 E 1932.90 113~,.67 E 2001,.22 1175.35 E 237t,.82 1216.52 E 214r+.20 1256.41 E 2211.57 1295.5~ ~ 2277.73 1334.31 E 2342.55 DEP&RTURE AZIMUTfi DES MIN 1~75.51 2325.46 2075.31 2124.30 2173.~9 2222.72 2271.53 2320.10 2368.~1 2%15.95 1371.55 E 2~05.~5 1408.42 f 2~,57.83 1~46.50 E 252~.54 1480.42 c 2539.27 1515.~,~. fi 2550.22 1552.52 E 2711.23 158~.~5 ~ 2772.07 152:~.55 ~ 2332.33 1553.50 E 2592.51 1695.33 E 2~52.82 2512.50 2560.59 250'9.03 2557.~7 2706.92 2756.30 2~05.)2 2~55.71 2905.7d 1732.35 5 3012.55 1767.7~ f 3372.1~ 1803.12 E 3131.75 183~.11 E 3191.50 1871.79 E 3251.~0 1907.14 6 3311.29 1941.33 ~ 3371.3~ 1975.55 E 343!.52 200~.5~ E 34')1.~2 20~3.35 E 3552.30 2~55.59 3305.35 3355.15 3103.53 31~9.~4 3175.29 72~0.53 32~3.36 ~323.35 334~.36 2075.35 f 3512.~0 2113.18 : 3572.20 2143.5~ f 3732.12 217d.05 ~ 37)1.55 2215.09 ~ 3~50.~ 2255.01 E 3)11.%5 2295.52 E 3971.24 233~.57 : 4329.79 2373.55 E 43~3.9~ 2395.10 E 411~.35 3~ 13 E 3~ 18 E ~ 3~ 22 E 25 : ~ 3~ 31 c ~ 34 34 E ~ 3~ 39 fi ~ 3~ 42 E N 3~ 47 E N 3~ 50 5 ~ 3~ 52 f ~ 3~ 57 E Xl 35 0 .~ ~ 35 2 F xl 35 3 ~ N 35 5 ~ N 35 ~ E ~ 33 3 E ~ 35 3 5 ~ 35 7 ~ q 35 13 E q 35 18 E q 35 24 E N 35 32 : ~ 35 36 : 3~-14 KJP.~RJK. DATE DF SURVEY: 12-33-85 K:LLY BUSHING ELEVATIDN: ENGINEER: SALAZAR 72.00 TRUE V=RTI'-~L INTE~POL~Tcfl VaLJ:'5 SJS-SEA C3JRS' Vd~TICAL ~EVI~TI]~ ~ZI~UTH :VEN lOOO FEEl 3F ~MSASJREO 3EPT V-~TIS~L DOGLEG SECTION SEVeRiTY FE-T DE3/IO0 3.00 3.03 2. '5. "57 5.32 ~2~.. -)5 1.72 1'373. 32 3. 1725.70 ?.,35 .':~ ~ 0.35 ~012.~5 3.10 351£.2~ 3.37 ~113.73 0.00 RE'TAN~ULAR COOR NDRTH/SOUTH EAST :EET FEE 0.00 ~ O. 20,22 ~ 12, 350,ql N 225, 896.35 ~ 5'~1. 1~25.79 ~ 970. 1975.51 N 1371. 2~6~.~$ I 1732. 2955,5~ N 2075. 33~5.35 N 2395. DIqATES~DEP~RTURE /WEST 3, " ',~ZI~UTH f DE~ MIN O0 E 3 0 E 37 E 31 27 E ~2 E ~+25;~7'~ ~1 32 ~, E 25 E 1073,'5~ N 33 2~ 79 E 1725.73 N 3~ 13 ) 55 E 2~05,B6 ~ 3~ ~5 ~ 05 E 3912.56 q 35 5 ~ B5 E 3512.60 N 35 5 E 1~ E 411~.36 ~ 35 36 E :34~jT;i'i?'J 3;T':: 25-J~,N-45 ~AGE ~ DATE IF SJRVE¥: 12-33-55 K~LL¥ BUSHINg ELEVATZ]N: 7Z.O0 F1 ,..l S L! ':,: "...3 72.33 17~.33 Z 72 . '.] 3 372. )1 ? .... '., 1 772.jj 572.15 )72.0) lJ7~.ll 1,)5.53 1507. ] 1 I 72 I · ~ Z 2213.55 23~5.~5 2.77.3~ 27~'.35 ~175.51 3573.3) 379~.¢2 3~31.7; ~., 7. ~.. Tqd,: L)~PTt O. J3 72.3J 172 .3J ..? .:, f2. J ] 7 ?L. 3,) 57 '. JO 1072 . 03 I 17 Z. 30 1272.30 i~72.J3 1~72.00 1672.30 1772.30 1)72.3J ~072.00 2i72.0C ~7 .33 ~372. ]3 z 5 '? ] · ).3 ~O7'.)O ~27~.]] 3372. ) ) INT:qP3L;T'-2 'v'~LJ:S -3R ~"qTI'AL 53J25 ' ~ 3 ? J .-..., 35. 15 ~3 29 i7 21 55 5-; ~5 i5 - . i, _ 35 35 15 1 V = :< T i'2 AL ; ',- C T I .3 N F.F -T 3 -3.11 O. 28 3.,.32 1.35 1.94 2.60 3.69 9.~6 23.02 35.74 60.04 90.44 127.52 169.57 115.34 271.00 ~32.59 401.60 475.89 q57.06 542.47 72B,66 315.55 tOZ.45 ))0.33 1079.33 1165.53 1255.~2 1343.35 I-Z~.59 1511.51 15j4.40 1680.27 1770.95 1~55.~6 I~55.~3 2366.2'~ 21>2.2~ F~ET 2= 03G.EG SEV:RIT¥ DES/IOO 3.03 ! · ,33 3.13 3.15 3.03 ,3.25 3.0~ 1. 3.92 3.9'~ 4.51' 2.91t 1.80 1.75 ~.09 2.79 1.23 1.91 3.83 2.39 0.07 3.31 0.37 3.22 D.20 3.33 0.~ 3.52 3.45 0.41 3.9~ 1.40 0.60 1.00 0.41 0.90 1.67 SUB-SEA RE'T~N NDRTH/ FEE . O. O. O. O. 1. 1. 2. 4. ,9. 9EPTH 3UL~R S']iJf~ T 16 S Og N 82 N 21 q 90 q ~6 N 34 N 17.17 N 49.78 N 76.34 N 108.14 N 143.50 ~ 182.25 N 228.72 N 231.53 N 340.50 N 4O 3.24 ~,70.71 541.50 512.59 584.08 755.54 827.92 900. ~8 ~73.92 10~6.01 1110.87 11B5.a12 1 253.33 1320.54 1390.15 1463.31 1540.36 1520.~5 1702.~0 17,~0.23 C03RJI~TES EAST/WEST t~"~ FEET 9E~IIRTURE 0.00 E 0.03 E 0.33 E O .all E 1.22 E 1.55 E 1.97 E 2.1) E 2.49 E ~,.55 E AZIMUTH Dfi5 MIN O. O0 ,~ N 0 0 E 0.16 S 1Z 9 E 0.39 N 75 22 E O.9Z N 51 16 1.~7 N 55 f } 2.05 N 53 40 : 2.74 ~ 45 0 S 3.59 N 35 32 E 5.00 N 29 51 E :~.72 '~ 2~1 41 E 10.35 E l't. 70 E 33.5~1 E ~,?. 34 E 67. ,:11 E 90.53 E 115.79 E 1~5.69 E 177.45 E 213.50 E 20.06 ~ 31 6 E 35.75 ~ 32 23 E 50.05 ~ 3~ 0 S 90.~8 ~ 32 49 E 127.54 ~ 32 5 E 1.59.~1 ~ 32 15 E 216.~7 ~ 32 3~ E 271.18 ~ 32 29 E 332,~7 ~ 32 12 E G01,99 N 32 4 E 253.5~ Z9~.53 345.~7 395.21 493.90 543.:19 59~.70 646.0~ 697.21 ~7~.32 ~ 32 9 E 557.47 ~ 32 23 E 542.~5 ~ 32 36 E 729.31 ~ 32 49 ' 815.,~5 q 33 1 } ~02.74 ~ 33 10 c 990.59 N 33 18 E 137).55 ~ 3] 25 E 11~8.72 N 33 33 E 1257.38 ~ 33 41 E 7~7.59 795. ~8 845.22 893.44 943.8~ 997.55 1053.43 1111.t7 1171.05 1227.21 1343.98 ~ 33 ~7 E 1~28.70 N 33 54 E 1511.70 N 33 59 E 159~.~5 ~ 34 4 E 158'3.31 ~ 3~ 10 E 1770.98 N 3~ 16 i 1~65.88 q 34 22 E 1965.51 N 34 27 : 2355.20 N 34 31 ~ 2162.2~ N 3~ 34 E 3A-l~ C~4°JTATZ3'q CAr-: 25-J&N-~5 INTerPOLATE3 V~_:JE5 FOR :V~N 100 F~ET OF Tqd ' S J,.t- SEA M'-ASUqE3 V :RTI'-AL VE.~TI~AL ] - )Tq '] = P T-t 3EPrH 6327,T) +~72.J0 ~132.3~ 50?2.00 6275.)~ 5172.]J ~,31.~ ~272.33 5253.00 0526.73 5372.30 ~3OJ.OO o551.~2 ~72.OO o777.2, 5572.32 5)22,71 <5'/2.~J /327.7~ 577~.J'] 5[03.00 71 F2. 5~ ~.~72. }) ~523.00 C]JR$ ' DEVIATI']q &Z l'4j T-~ ]EG 4IN DF3 ~11'4 V~RTICAL 30$LEG N=CTION $EV:RITY F:ET 3EG/IO0 !252.10 1,22 !337.90 1.23 '2;~7.4) 3.64 2573.65 O.'~l !727. 50 3.21 Z379.04 3.25 J7 Z7 15 15 SUS-SEA RESTAN FEE 1352. 1)21. 1 gL-17. 2050. 2111. 173. 2235. 2297. 2357. 2~18. ]&T~ DF SUqVE¥: 12-33-35 KELLY 5USHI~S ELE~ATIJN: ENGINEER: S~LAZAR 5 72.00 3029.01 3.11 ~103.21 0.40 2537. 3177.53 3.45 2597. 3232.33 3. 35 2558. 3327.15 3.2~ 2720. 3402.43 3.13 2782. '.~473. O1 3.25 2~4~. 3553.73 3.45 2~07. 352,~.~7 0.15 2)69. J793.56 9.31 3331. ?~ 77 -3. '32 3.1~, 3392. 3551.~6 1.40 3150. {~ZT.B1 0.82 3207. *301.20 2.29 3253. .386.61 3.00 3312. ,113.73 3.03 3345. DEPTH r F E ~ T 59 N 1379 65 E 2~19.49 29 N 1425.07 ~ 15 N I471.1T ~ 7o q 1516.53 E 2550.55 ~6 N 1562.19 E 2727.55 17 N 1507,57 E 2503.a0 65 N 1652,53 E 2879.12 ~5 N 1697.~5 E 295~,70 12 N 1761.99 E 3329.13 5~ NI 1785.32 E 3103.35 83 N 1830.05 ~ 317'7.59 75 Xl 1873.~,2 E 3252.~9 08 N 1915.2'~ ~ 3327.32 07 q 195~,10 E 3~02.6~ 33 N 2001.85 E 3~73.16 13 N 204~.26 E 3353.93 ~8 N 2085.11 E 3529,30 51 N 2127.71 E 3703,5~ a7 N 24 N 2216.78 87 N 2255.)8 32 N 2315.~,5 59 N 2353.14 36 N 2395.13 377,~. 1~ 3~52.03 3)2,5.05 43b).11 4114.36 OEPqRTURE AZIMUTH DES MIN 3~ 38 E 34 42 E 36 4'9 3~ 5' i 34 54 34 56 ~ 3~ 59 E 35 1 E 35 3 E 35 6 E 35 8 E 35 9 E 35 10 E 35 9 f 35 9 E 35 B E 35 6 E 35 5 E 35 3 E 35 3 E 35 8 E 35 21 '- 3c i 35 36 : ~, J~i?J~, DATE 3F SdRVE¥: <ELLY BdSHING ELECATI3N: ENGINEER: SALAZAR :: a j .! ' d,3S:N H]RIZ]N% F R'3 ~1 K5 t346.5~ 6237.20 0349.56 6439o~5 TVD 5965.)0 5165.ZO $Z77.55 5357.)5 832 ' N 3130.65 N 2200.3? 3135.5g N 2204.35 3177.97 N 22~0.71 ~Z64.57 N ZZ99.05 3]01.75 'i 2352.5~ 33~5.35 N 23~5olJ ']7:.I~JT6T']q _3Xl'-:: Z6-J~N-R$ PAGE ? 3~-14 DATE 3F SJR~E¥: 12-33-85 KELLY BdSiINS ELECATE3N: =NGINEER: S6LAZ~R 72.00 Fl ~T~ T~ ~ ,-,, 1.,52.30 7T45.uO 7s55.30 ~T TJ: f-i J- SJ'>-S_:~ TVD =ROM KS 5JB-SEA 5037.)0 5965.~0 ~119.83 SJ~7.a3 5237.20 5165.20 53~9.56 5277.55 5439.95 5B67,~6 fl]R',' 3,'~T~L 3EP6RTURE 915[~'4CE &ZI~JTH ='4T bEG MI~ ~ 35 35 E 832' F REC NO .', SJRFA'E" '" i' iON EL~ SECtJZN, RgE, T~NGUL IN~TES ~fH/S~I T/WEST 130.55 N ZZ00.07 E 135,68 N ZZO~,35 E 117.97 N ZZ~O.?? E Z~4.$7 N 2Zgg,O5 E 331.75 N 235Z,5~ E 3~5.35 N 2395,lg E SCHLUMBERGER 0 [ RECT I ONAL SURVEY COMPANY ARCO ALASKA INC WELL 3A-14 FIELD KUPARUK COUNTRY USA RUN TWO DATE LOOOEO REFERENCE 0000"7 ! ! 82 WELL - 3A-14 (841' FSL, 832' FI:L, S7, TizN, R9E HORIZONTAL PROJECTION 4000 I~¢ILE = 1/lO00 IN/FT 2OO0 1000 -1000 ........... *-+ +.'t .... + ............ ~ .... t SOUTH -2000 -9000 I~EST ============================================================================================= 'i -2000 - 1000 0 1000 2000 3000 4000 $000 EPS' WELL - 3A-14 (841' FSL, 832' ~_., S7, T12N, R9E VERTICAL PROJECTION ~OTH -L~ - 1000 0 0 1 ~ 2~00 9000 4000 6000 6000 I : : . I ; . . : : ; I : - : ' ~ . : . I , : - ~ ', ~ ; ~ ! : : : : : ~ ; ~ I _ _ : _ ~ ; ~.~ ....... 1 ...... L ........ J ..... J ~ , ;; ~i~ :- ~i~ :' : ': ; '-'i~;~;'--l-', --~-%-' ,-7 ...... ::F'"':*::':-', L:;:'~: ~ :: ~'~ ;I',~ ;' ~'--':-'{_ ::_.~: .:. ;.~ ..... ~.+.:...~ .....~ .....: ...... : .............. ,. i :, . ,~1-, -- '~- ~ --' , :! - , , I ..... , , ~ ' , ~ ........ :"': ~'-" .... I';;;;'-- i,,.~-;'I'T%7~ i7 ~77, ,1 i4~-:,' ':,;-::,' ...... : .......... : ...... !":,,:-'-'~'~:';'- '~ ..... ~ ..... T ....... ; ..... ~ ...... : ...... /~'. :i:,''~.''-i - ~ 'I:'' : I ~ Ix ~'' ~' ' ~ ~ /~!~il. . .I I-, i ;, I ..... I - i I ' ' i ,.- -'t i -.4 +. ~-- ~% ..... ~.~ .............. ~ ~ ..... + ............................. ~ ............. + ...... ~ ..... --.; ~-- ~ : ~-~.- ~ I-- ........... ~ ...... L ...........' ................. ~ -.; --~ .......... ~ ..... + ............. ~ . . ' =. : I . · . . ;~ I ~ ' . ~ I . ' ' ~ t ..... ~ ........ ~ ...................... ~ ....... ~"'-~ .... ~ .... ~ .................. ~ .......... ~ .......... 1 ....... 7"-~': 'lDnnm'; ...... + ..................... T: ...... * ..... * ......................... ~ ........... :%~ :¢--~ ~ ' .i.:: :::~ :'i:l ............. .; .................. ~ ....... ~ ..... : ......... '. ........... ............ r ..... ~-~ ............................. ~ ......................................... .......... ~--* ......................... + ........... , ........... + ..................... + .................... t .......... .... F .......... z' ' 'I ~n~ .......... ; ................ ~ ........... : .............................. ............. ~ ....... ~ ........... ~ ........................ , .... ~ ~ ~ .................. ~ * ...... . ............... . .... . ..... ..... : ............. :::::::::::::::::::::::: .......':: :::::::::::::::::::::::-::::-:: ....... : ..... ,, ........................................... ,, :12:::..::.::~:.:::.:..:.::::~:::.:::::~..:..:.:::::2::.:..:...:...::::::.:::::::::..:: ' ::': :':::'':: PROdECTION ON VERTICAL PLANE NORTH - SOUTH SCALED IN vERTICAL OEPTHS ~OR!Z SCALE = 1/1300 WELL - 3A-14 (841' FSL, 832' EEL, S7, · 2N, R9E VERTICAL PROJECTION o o 1 _ _rj(~_ 2o00 ~)oo 4ooo sooo 60oo PROJECTION ON VERTICAL PLANE 34. - 214. S~LED IN vERTICAl.. DEPTHS ~DR1Z SCALE = l/lOOg IN/~T EXACT RAOIUS OF CURVATURE METHOD TIE-IN LOCATION MEASURED OEPTH O. 0 TRUE VERTICAL DEPTH 0,0 DISTANCE NORTH 0.0 DISTANCE EAST 0.0 BOTTOM HOLE COURSE LENOTH COURSE AZIHUTH MEASURED DEPTH TRUE VERTICAL DEPTH DISTANCE NORTH DISTANCE EAST LOCAT I ON 4118.0 95.6 78S5.0 6498.8 3347.7 2998.0 FT FT FT FT FT DEO FT FT FT FT REF 000071182 Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. ' · . . . Date · .. -- "~quized Date ReCeived Rem~zks '" _ .... ~ , , ~/~~ .. : If . ......... , Inclination Survey ' ,. Urtll Stem Test Report,, _ ,. ~/N . _ . , , , ARCO AlasKa. thc. most Off,ce Box 100360 Anchorage. AiasKa 99510-0360 Te~et~one 907 27~, 1215 RE~-~Jp~N TO: ARCO ~_LAS2<A, ~C. ATTN~: Kupa~ak Reccrds Clerk A.~O 1119 P. O. Box 130360 '" aa=~ n-0363 A_~.chc r age . -, Tr~nsritted herewith are tine fo!!c~'Lng items. return one si~_~n, ed copy of ~?.is tre_-.smistal. Final Prints/' Schl/ Open Hole/' One * cf each Please acknowledge receipt ./ 3A-!3 ~" DIL/SFL-GR 12-01-85 2" ~r./c~-co !2-0!-S5 5" Den/Neu (pcro) 12-01-85 2" Den/Neu (?ero) 12-01-85 5" Len/Neu (raw) !2-0i-85 2" Den/Neu {raw) 12-01-85 ~:De_~ook ~z-ul-85 o,.- _~. i-S00 R'~n .~I 5100-~,~ R'-_u =i 5!00-757! Run =! 5100-7571 ~ 3A-!4 5" DIL/SFL 12-09-85 = DiL/SFL 12-09-85 5" Den/Neu (poro) 12-09-85 2" Den/Neu (poro) 12-09-85 5"Den/ 'Ne~ ...... (raw) ~ ~-0~-~5 2" .Den/Neu (raw) 12-09-85 ~beriook 12-09-85 Rum #I 0'45-7795 Run #i 0145-7795 R'. '- n ~-1 7250-7770 Run #! 7250-7770 R'~ =! 7250-7770 R~n #1 7250-7770 Run #! 7300-7650 5" DiL/SFL-GR 12-17-85 2" DiL/SFL-GR ~ ~-~ 7-85 5" Den/Neu (poro) 12-17-85 2" Den/:{eu (poro) 12-17-85 5" Den/Xeu (raw) 12-17-85 2" ~_n/~,eu (raw) 12-~ 7-55 Cyberlook 12-17-~5 1800-7982 !800-79~2 4640-7956 ~0-~56 46~ ~ 4640-7956 4640-79~6 -450-7933 Re~=~ ~.+ Ad<nowiedced: State of ~v*~ /= _~a'aef ?" D & ...'bl ", a '--: :-= ARCO Alaska, Inc. Post Office Box 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 January 14, t986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Ccnservaticn Commission 3001 Porcupine Drive Anchorage, AK 9c~5CI SUBJECT' State Eeport$ Dear Mr. ~ ~ ' ~h~ ~teFton' Enclosed are the ~.eceF..~er ,monthly reports for the following wells- ,~f you have any ~ues~:~s, ~-ease call me at 263-494~. Sincerely, ,. Gruber Associate Engineer JG/tw GRU!3/L05 ~ncl osures RECEIVED JAN Oil & G~s Ar~"~rage - STATE OF ALASKA - ALASKA O,,_ AND GAS CONSERVATION CO, .,,llSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS Drilling we I~(X-~ Workover operation _ i2. Name of operator i 7. Permit No. I ARCO Alaska, Inc. 85-282 i 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50 029-21490 · Location of Well atsurface 841' FSL, 832' FEL, Sec.7, T12N, R9E, UN 5. Elevation in feet (indicate KB, DF, etc.) ! 6. Lease Designation and Serial No. 72' RKB ADL 25631 ALK 2565 , 9. Unit or Lease Name Kuparuk River Unit. 10. Well No. 3A-14 1 1. F~eld and Pool Kuparuk River Field Kuparuk River Oil Pool _ For the Month of December ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 2215 hrs, 12/02/85. Drld 12-1/4" hole to 3700'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 7800' Ran logs. Ccnt'd drlg 8-1/2" hole to 7855'TD (12/09/85). Ran, cmtd, & tstd 7" csg. PBTD = 7746'. Secured well & RR ~ 0330 hfs, 12/11/85. 13. Casing or liner run and quantities of cement, results of pressur? tests 16", 62.5#/ft, H-40, weld conductor set L~ 107'. Cmtd w/165 sx AS II. 9-5/8", 36.0~/ft, J-55, BTC csg w/shoe ~ 3680'. Cmtd w/1450 sx AS III & 310 sx Class "G". 7", 26.0#/ft, J-55, BTC csg w/shoe ~ 7835' Cmtd w/350 sx Class '%" & 175 sx AS I. 14. Coring resume and brief description None 15. Logs run and depth where run DIL/SFL/SP/GR f/7800~ - 3679~ GR to 185' FDC/CNL f/7800' - 7250' Cal f/7800' - 6500' 16. DST data, perforating data, shows of H2S, miscellaneous data None RECEIVED JAN ! 4 1986 17. I hereby certify that the foregoing is true and correct to the best o~ my kno~*.ledge. NOTE Report~n this form is requireo for each calendar month, regardless of the status of operations, and must De f~led in dupl cate ,~th the AlasKa Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10404 TEHP3/MR11 Subm,! ~n duplicate ARCO Alaska. Inc. -- Post Office B. ~0l~360 Anchorage, AlasKa 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC, ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DA~E12-!9-85. TRANSMITTAL # 5473 Transmitted herewith are the following items. Please acknowledge receipt ~nd return one signed copy of this transmittal. Open Hole LIS Tape plus listing/ schl/ One copy of each lQ-4/~ G3-18-85 Run ~ 71 4570.0-9471.0 re f# ' 70997 --£~ d.~f ~c~ ~2H-9H 12-02-85 Run #1 1800.0-8113.0 ref# 71048 ~2H-10~/ 11-23-85 Run #1 2856.0-7960.0 ref# 71002 '~2H-12 ~, 11-07-85 Run #1 2743.0-6829.0 ref# 70947 ~ 2U-7// 03-19-85 Run #1 3594.5-8179.5 ref# ~2V-16// 06-03-85 Run #1 2973.0-7168.0 ref# 70952-f~2~~f~ ~3A-10"! 11-09-85 Run #1 3179.0-7014.0 ref# 70960 ~3A-11', 11-16-85 Run #1 3208.0-7330.0 ref# 70989 ~ 3A-12// 11-23-85 Run #1 3797.0-8006.0 ref# 71003 ~3A-13;/ 12-01-85 Eun #1 1800.0-7597.0 ref# 71047 ~3A-14'/ 12-09-85 R'~n #1 0144.5-7818.0 ref# 71073 ~'3C-9~ 07-10-85 R'cus~1 3920.0-8332.5 ref# 70996 3F-8-! 11-09-85 Run #lA2 0115.0-7040.0 ref~ ~9994 ~3F-9/~ 11-17-85 Run #1 3410.0-7770.0 ref# 70990 ~3F-10;~ 11-27-85 Run #1 1800.0-6631.0 ref# 71037 '~3F-11~ 12-05-85 Run #1 0148.0-8618.5 ref# 71061 ~J3J-9-/ 11-24-85 R~n #lA2 0~9!.0-6789.0 ref# 71034 ~ 3J-10'~ 12-08-85 Run #'1 0096.5-7348.5 ref# 71074 Date: MEMORANr'JM TH RU' FROM' State of Alaska ALASY~A OIL AI-~u GAS CONSERVATION COI-R~ISSI~., f ;,.,..'? C. V/. ~atterton Lo~n±e Co Sm±t~ "' " Commis s ioner Bobby D. Foster~ / ' Petroleum Inspector DATE: December 10, 1985 FILE NO.: TELEPHONE NO.' D. BDF. 29 SUBJECT: BOP Test ARCO- K.R.U. 3A-14 Permit ~85-282 Kuparuk River Field Thursday~ December 5. 1985: The BOP test began at 11:00 Ab1 and was 6bncluded at 12:30PM. As the attached BOP test report shows, there were two failures, one of which was repaired. The choke manifold valve will be repaired and the inspector notified. In summary, I witnessed the BOP test ARCO's 3A-14. Attached O&& 5/84 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMiMISSION B.O.P.E. Inspection Report Inspector Operator Representative Drilling Contractor ~~//_~[.~ Rig ~/~/ Representative L - Location, General O~ Well Sign~ ACCUMULATOR SYSTEM General Housekeeping O~ Rig ~'~" Reserve Pit ~L Mud Systems Visual Audio Trip Tank ~-~ Pit Gauge Flow Monitor Gas Detectors BOPE Stack Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Pressure Test Results: Failures . Full Charge Pressure~C~P psig Pressure After Closure /,~r~ psig Pump incr. clos. pres. 200 psig -- min~ sec. Full Charge Pressure Attained: ~- mi~&sec. Controls: Master · Remote~ Blinds switch cover~~ Upper Kelly Lower Kelly Ball Type Inside BOP Kelly and Floor Safety Valves / / / Choke Manifold ~.~ Test Pressure No. Valves No. flanges Adjustable Chokes / Hydrautcally operated choke / Test Tl e hrs. Test Pressure Test Pressure Test Pressure Test Pressure Repair or Replacement of failed equipment to be made within ~ days and Inspector/ Commission office notified. Distribution orig. - AO&GCC cc - Operator cc - Supervisor Movember 25, 1985 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, !nc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk River Unit 3A-14 ARCO Alaska, Inc. Permit No. 85-282 Sur. Loc. 84!'FSL, 832'FEL, Sec. 7. T12N, RgE, IrM. Btmhole Loc. l178'F?-U~, 14!8'FI,U._~, Sec. 8, Dear Mr. Kewin: Enclosed is the approved application for pernit to drill the above referenced well. The pemit to drill does not indemnify, you from tha probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this o=~ice 24 hours prior to commencin~ installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled, l.There a diverter system is required, please also notify this office 74 hours prior to commencing equipment installation so that the Commission may witness testing before drilling be!mw the shoe of the conductor pipe. C. V. Chatterton Chai~an of Alaska Oil and Gas Conservation Co~issio~_ BY ORDER OF THE CO?R~ISSION be Enc lo sure cc: Department of Fish & Gam~, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lower>/ la. Type of work. - STATE OF ALASKA ALASKA t,,~ AND GAS CONSERVATION CO. PERMIT TO DRILL 20 AAC 25.005 DRILL ~X ! lb. Type of wetl EXPLORATORY ~ REDRILL -- DEVELOPblENT OIL ~l~X __ -- DEEPEN _ :1 DEVELOPMENT GAS _ .711SSION SERVICE _ STRATIGRA~,M1C SINGLE ZONE ~[~ ~ MULTIPLE ZONE'~ 2. Name of operator ARCO Alaska, Inc· 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 841' FSL, 832' FEL, $ec.7, T12N, RgE, UM At top of proposed producing interval 1359' FNL, 1293' FWL, Sec.8, T12N, R9E, UN At total depth 1178' FNL, 1418' FWL, Sec.8, TI2N, R9E, UM 9. Unit or lease name Kuparuk River Unit 10. Well number 3A-14 11. Field and pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF etc.) ] 6. Lease designation and serial no. Kuparuk Ri vet 0i ~ Pool RKB 72', PAD 41' ADL ~A1~,~65 1~. Bond information (see 20 AAC 25,0251 ~'~,4~-~ Fe~'e~'l Ih~u~hce Company Type Statewide Surety and or number ~8088-26-27 Amount $500,000 13. Distance and direction from nearest town ~ 14. Distance to nearest property or lease line 30 mi. NW of Deadhorse miles I 1178' ~ TD feet 16. Proposed depth (MD & TVD) ~ 17. Number of acres in lease 7757' MD, 6418' TVD feet 2560 15. D~stance to nearest dr~ll~n§ or completed 3A-1]well 25' ~ surface feet __ 18. Appro~'ratel 2 19. If deviated !see 20 AAC 25.0501 120. Anticipated pressures 2680 ps,g@ 80°F Surface KICK OFF POINT 800 feet. MAXIMUM HOLE ANGLE 39 : !!see 20 AAC 25.035 ~c~ 12~ 3081 __PS~g(:~ 60/4.6_ ft. TD ITVD) SIZE Hole Casing 24" 1 6" 12-1/4" 9-5/8" Proposed Casing, Liner and Cementing Program CASING AND LINER Weight Grade I Coupling Length 62.5# H-40 Weld 80' 36.0# J-55/HF-E~W BTC 3586' MD TOP 32' SETTING DEPTH TVD ~ MD BOTTOMTVD 32' ' 32' 3618! 3187' 31 31' 7757' 6418' 26.0# J-55/HF-ERW BTC 7726' 8-1/2" 7" QUANTITY OF CEMENT ~nclude stage data) ± 200 cf 1200 sx AS III & 310 sx Class G 400 sx Class G _ 22. Describeproposea program: ARCO Alaska~ tnc., proposes ~o drill a Kuparuk River Field development well ~o approximately 7757' FID (6~18' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on ~he 16" conductor wh~le drilling ~he surface hole. The 13-5/8", 5000 psi, RSRRA BOP s~ack will be installed on ~he 9-5/8" surface casing. The s~ack and rela~ed equipment will be tested to 3500 psig upon installation and weekly thereafter. Expected maximum surface pressure is 2680 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated wi~h an unexpanded gas bubble at surface, including temperature effects. Casing will be tested ~o 3500 psi prior to releasing the drilling rig. Non-freezing fluids will be left in uncemen~ed annuli through ~he permafrost interval. 3A-14 will be 25' away from 3A-13 at the surface. There are no closer wellbores anywhere downhole. Reserve pi~ fluids w~11 be disposed of by pumping them down the 7" x 9-5/8" annulus of ~his well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during an~ ~n~erruptions in ~he d~sposal process. (continued on at~ached sheet) 23. I hereby ~gr~g~ that the foregoing is true and correct to the best of my~n~wledge / / · ' TITLE Regional Drilling Engineer DATE SIGNED The space/~ow f[:~C~om/ission use .... CONDITIONS OF APPROVAL Samples required ~¢lud tog required D~rectional Survey requ,rea ~' APl numbe~ / _--YES ~YES %YES ~NO J s0 .: --~ - :"'- Permit number APPROVED BY Form 10q01 Approval date JFB) PD2/PD05 ~ / / SEE COVER LETTER FOR OTHER REQU REMENTS ,COMMISSIONER DATE_ tqovembe~: 25~ _ 1 gg5 Dy order of the Commission Subm,t ~n Triplicate PERMIT TO DRILL 3A-14 (cont'd) Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 175 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. ..... ~RCO 'ALASKA.- .... , A~A KUPARUK-FIELD~:--NORTH S_LLO_P_E___AL . _ _ .... _ K-5 TVD=4667 TMD=5514 DEP=2560 · --~'V~AGE- ANGLE 38 DEG 41 M:IN ......................... -r. ..... ; ..... 7'000 ............ ' ..... ~ ...... i 1 ............ ,3-;~;; ;:7; ' ! 000 .... 2000 - ---5000 V E R T tC~A+.~-~ t~ ......... ;. ........ ~. - _ ~,, ........ .,__ __ i --T/-ZONE g .TVD=6022 TI'ID=7..-250-DEP=36z ZONE C TVD-$046 TflD=7281 DEP,-3E / ZONE A TVDI6144 TtID'-7406 DEP=,~ TAROET CNTR TV[)-6203 TflD=?482 DE ~. TBASE--KUP---SNDS--TVD'6262 -TMD'-7557 · - TD CLOG PT) - - TVD-64t 8 -TMD=7757 · i I 4000 ...... ~.] -,. .... ~.--.....----.~.....I... I _ :'-~Sk8 .... ,-", ....... = ..... : -. o _ , . PAD 3'^, WELL"NO~ -1 -SLOPE.--^LASKA ..... ' -KUPARUK -F ~ ELD. ~ORTH EASTMAN WHIPSTOOK; -INC __ . 1000 ' - 0 - 1000 2000 2000 ..... 4000_ - ....... I - - - I .... I .... _ . _ _ ..... __ZBDDO'- .................. TARGET CENTER ......... TVD-6203 - - _ _~ -- _-_ ..................... TI"lD-?4.82 ............................. DEP-,.378g -- ................................... ................... NORTH ..................... EAST 2152 _ z .... 200.0_,_ - ........... - _. _ ::: ...... 1 DOD ._ . ......... D_L ...... - _ . ....... ...... . _ -- ..... 1 SI.,tf~AC~ LOCATION ~ .......... .... .~841' FSL. 832' FEI: ~ _ ___ SEC:. 7. TI2.N. RgE 4000 ' TD LOCAT'[ ON, 1175' F#L. ~I418'_-FI~IL-- ._ _ TARI3Lrl' LDOAT[ON, 1320' FNL. -1320' -F'I,~L .......... -- SEC. El. T I2N. RgE TARGET)-- ' ; - / ,;.~I~;~ i~ ~.:~- i~ ''l:-~i ;.~.' .... ~ . ,. I '?:' ~i?.l t ~ ' ........... ~,:,'~ f'i ;~;~:~ i ,~'',,.,,' ,- ~ ......... , .... ,.~i ;''~ '': : I - : '~' : ' . . : ' ' ' 'I [ ' ":- ~ : : , , ...: ~ ._~ : : ~ ; i~' : * ~ - ~9~ - -- ~-~- % ,.,,.' ; : ~ {,~ ~ '-- ~:- . -- i ' ~ ' ' -' ' ' ; / ' ....;:~~~~:~ ~ .. , .' ,;~- , ~_: ; ~ ' :1 -",.. , , . /_ . . ; . :: i- . , . , , · , ..i . ~, . ~ , ; ; .: . .... : ~' i I ' . _l ' - I , : ~ ~ , :4 ~ Z , 1 i _ : : ·/ ' . ~ _ ~ ~ ' '~. i---: ~ /~ 455 : , ~ ~ . i_. : / ..... ;'- , ~ (]Fi~- ~ ' -~ ~ ' ~i . '~ .... : · - ~ ~ . ~ ~ ~ . - : : :X . ~ ~ , :/ _~ -- , . '' : ] ' ;t :' :~ /' ~ : i' . .:,~ ,~ .-- : % - , · , , · ~ ' . : . ~ - . · : ' :1 ), : ' ' ~ ~ . li~ ~ ~ , , , , ~ ; , J ~ ~ I ~A~ ' - ;. - " - d .... '.z~%;~zF;~- ~ 7~D~_-'~~/J -. --- .-' .... ~_/~ .. ............. ~ ....... ~, --- '~ ............... ~ ~ --. ~ ~ , ~ .............._ ; ~:T96~ ~T~_~-:~_--_ _ ~ ; , ~ , -~~~ ~~ .... ~ - . ., I , , . i ;~ - . . ~ i , ~ .... , . :.. , ~ i : i- I :.. . - - - [ ~ , ' - Ii ~ : , ~ ~ i ' ' ' , , ; .. _ l' ', I '' ~ i~ ' ; ·I i ,. , .. :- ~ ~ · i ; i ., ~ * :'1 : . z' , ~ :' !. ~ , . ~ ~ . t -' I ~ - ; -~: - . . : , . - . ., ,.. ,.1. , . "' :' t , i ' ~ '' -~i ~L~ , 1 , . . ' . ~ ; ' ~ ' . - , . .~.. ~. .:.: ~ , .... I , -r ~ . ; .. ~ ' , : i . "?:~:~- : L ' ,.i i ' ' 1 .~' .~ , : ~ ~ l -' .,I :. I i · , ' , I : ~ , ' I ~'~ : ' ' - ' ' ' ~ i j I ·· · ' · ' ' -'; ' ' ' · ; , ] .... ~ , I ~ - , I · ~ : ' ~ ...... ? ..... , KUPAIRUK RIVEIR UNIT 20 DI VERTEtR SCHEMATIC DE S CR I P T I ON I. 16' 2. TAI~O STARTER HEAD. :5. TAI~O SAVER SUB. 4. TAI",iKO LOWER OUICK-C~CT ASSY. 5. TANIKO UPPER QUICK-C~CT ASSY. 6. 20' 20,00 PSI DRILLI~ SPOOL W/lO" OUTLETS. 7. I0" NCR BALL VALVES W/I O' DIVERTER LIFE. S, VALVES OPEN AUTOMATICALLY UPON CLOSURE Af',,l",Z~ AR PREVENTER. 8. 20' 2000 PSI AhI",iJLAR PREVENTER. ~]I NTENANCE & OPERAT ~I ON I. UPON INITIAL INSTALLATIO~ CLOSE PREVENTER AhlD VERIFY THAT VALVES HAVE OPENED PRC)F>ERLY. 2. CL~ AI~LAR PREVENq'ER Aha) EL. OW AIR THRCXJC.~ DIVERTER LINES EVERY 12 HOURS. CL(]SE ANNJLAR PREVENTER IN THE EVENT THAT AN Ih, FLUX C~' WELLBOR~E · FLUIDS OR GAS IS DETECTED, IF NECESSARY, MANIJALLY OVERRIDE AI'~ CLOSE APPRC)PE I ATE VALVE T 0 ACHIEVE ~IhlD DIVERSION. DO NOT SHUT IN I~ELL : UI',,E>ER ~A. NY CIRCUMSTAhX3ES. 7 6 13-5/{~" '00 PSI RSRRA BOP STA(;K I. 16' - 2000 PSI TAJ~I<CO STARTING I-EAD 2. I1' - 5000 PSI CASING I-EAD 5. I1' - 5000 PSI X 15-5/8' - 5000 PSI SPACE~ SP(I1. 4. 15-5/8" - 50(:X) PSI PIPE RAMS 5. 15-5/8' - 5000 PSI DRILLINS SP(33L W/O-ICI(~ ~ KILL LIltS 6. 15-5/8" - 5000 PSI DOJBLE ~ W/PIPE I;~ ~ TOP, ?, 15-5/'8' - 5000 PSI AN'4.1_AR ACC~ATOR CAPACITY TEST I. O-EC~ ~ FILL ~ATC~ RE~SERVOIR TO ~ ~TH ~IC FLUZD. 2. ~ T~T A~AT~ ~~ IS ~ ~I ~H I~ ~] ~T~ ~ T~ ~AT~. 5. ~~ TI~, T~N ~ ~L ~TS S~T~~_Y ~ ~TS ~ ~~ WITH ~I~ ~ ~F. 4. ~~ ~ ~ ~T, T~ A~T~ L~R LIMIT 5 L 13-5/8" BOP STACK TEST FILL BI:]P STACK ~ Cl-Od~ MANIFCLD WITH ARCTIC DIESEL. CIE(iX THAT ALL LOCX ~ SCREWS IN II'E_LLI,,EAD ARE FULLY RETRACTED. SEAT TEST PLUG IN ~'~LLI-E_AD WITH ~ING JT ~ ia. IN IN LOCKIX)~ SCREWS. LII~ VALVES ADJA~ TO BCP STACK. ALL OTi~R VALVES AhD CH~ SH~ BE OPEN. PRE~ UP TO 250 PS~I ~ HOLD FC~ I0 MIN. IN- CREASE PRESStl;~E TO ~ PSI AJ~D HOLD FOR I0 MIN. BLEED PEESS~ TO Oq:~. 03EN ,ae'~l,,lA~ PI:~'VENTE~ ~ ~ KILL Aha) L]I~[ VALVES. CLOSE TCP PIPE ~ ~ I-ICR VALVES CN KILL AM~ CHCI~ LIltS. TEST TO 250 PSI AMD 3,500 PSI AS IN STEP 4. CCNTIN. E TESTING ALL VALVES. LII~So AM2 CHiS W/TH A 250 PSI LO~ ~ 3500 PSI HIGH. TEST AS IN STEP 4. DO M3T Pt~5'SI_~ T~ST ANY CH~ THAT M3T A FLEL CLOSING POSITIVE SEAL CI-O<E. CN_Y FUNCTIC~ TF_.57 CI-~S 7HAT DO NO? FULLY CLOSE. ~N TOP PIPE ~ ~ CLOSE BO'rT{:~ PIPE TEST BOTTI:I~ PIPE I~ TO 250 PSI AI~ 5500 PSI. CPEN BOTTCM PIPE R.W~4S,. BACK ol/r RUI~ING JT PULL CUT OF HOLE. CLOSE BLII~ RAMS ~ TEST TO 250 PS] AMi) 3500 PSI. (3PEN BLII'4i) ~ Al'4) RETRIEVE TEST PLUG. MAKE MANIFI3.D ~ LII'~[S ARE FLL. L OF FLUID. ~ ALL VALVES IN DI~ILL]NG IM3~ITICN. TEST STAI',&iImIPE VALVES. KR~yo KELLY COCKS° D~ILL PIPE SAFETY VALVE. ~ II~IDE BCP TO 250 PSI AMD 3500 PSI. EECO~D TEST I I~:'O;~wlAT]ON CIN BLO~OJT PEE~R TEST FOI~ $IG~L ~ SENE) TO 12~ILLING PERFCI~ C(;~ETE BOPE TEST AFTER NIPPLINS UP WEEKLY THEREAFTER F~TICNALLY OPERATE BOPE CIAILY. KUPARUK 16 CONDUCTOR BOP STACK 5i 008400 ~ R6 ARCO Alaska. Inc. Post Office Bo.. ,00360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 November 18, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Kuparuk 3A-14 Dear Mr. Chatterton' Enclosed are' An application for Permit to Drill Kuparuk 3A-14, along with a S100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore ° A proximity plot Diagram and description of the surface hole diverter system c Diagram and description of the BOP equipment, ~1',~, We estimate spudding this well on December If you have any questions, please call me at ,'6~-4970. Sincerely, ~~~r 1 l~~.l~neer k , PD2/L05 Enclosures ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 August 28, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plats - 3A Pad Wells 1-16 Dear Mr. Chatterton' Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, ~'J. Gruber Associate Engineer JG/tw GRU11/L22 Enclosure If RECEIVED AUG 0 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska. Inc. is a Subsidiary ol AtlanticRichfieldCompany 6'.? AS BUILT CONDUCTORS I- 16 ? 8 17 NOTSS C_'CRD~'~ATES ,-,RE A.S.P,ZONE 4 2_. SEgTICN _,NE DISTANCES ARE TRUE. '5 HOR'ZONTAL POSITIONS BA3ED CN THE D.$.~3A WEST & 3AMID PER LHD ~ ASSOC. 4, VERTICAL POSITION BASED CN 3A EAST I~ 3A MID PER LHD [~ ASSOC. 5.0G ELEVATIONS INTERPOLATF. D FROM S/C D~/G, CED- RIXX- 3020 rev. ~ .-.&...'- ";*9, HEREBY CERTIFY THATI .a~MPROPERLYREG~ST£EED L,SCENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA, THAT TH~S PLAT REPRESENTS A SURVEY MA£E UNDER MY DIRECT SUPERV, SION AND THAT ALL DETAILS ARE CORRECT -~S OF AUGUST 14,1985 LOCATED IN PROTRACTED SEC.7,T. 12. N. R \ THIS SU! · ' AL Oil & 9 1- ¥=5,996,860.05 LAT= 70°2~'9~.520'' X= 507,712.0! LONG= ~78' ;SL, 736' :EL, 36.9 0}. ~').8 PAD 2- Y=5,~96,88a. 17 LAT= 70°7.,' ~. X= 5~7, 705.57 LONG: lg~':5' '~.29TM x= 507,6~.C6 ~3N] ~_ y:5,335,::)32. ~2 ~_AT 70~2~' 13.2j5'' ~= 5.37,5~Z.55 L~N3= 1~::~6' 1~.~ " 551' :GL, 756' :EL, 35.7 ~- ~:5,~6,~55.6t ~T_ ~3~2~' ;3..':'" ~= 507,696.2! ' 9N'5= 1~9~56' 1~. 575':SL, 752':EL, 35.5 9'%, ~O.~ PaD 6- Y=5,~96,980.B~ LAT= 70°2~' 10.709" X= 507,679.66 LONG= 1~9°56' 1~.~63" 599' :S[, 768 :EL, 36.5 7- Y:5, ~}7,00~.90 LA~- 70°2g' X: 507,673.25 623' :GL, VT~ 8- ~{~ 507,566.B ~7' ~SL, 781 9- ~:5,997, 101.2a X: 507,6~7. 70 720' ~SL, 800 10- Y=5,9~-, 125.66 ~= 5_ .fi~0.89 ~' : '_, 806 ~: 50~,53~.~a 768' FSi, 813 12- Y=5,997, 173.97 X= 507,627.96 792' FS[, 819 13- Y=5,997, 19~.0~ - = ~ , - ~ ~ . _ 5'~ ~ ; [EIVE, G 0 , . , , , Gas Cons. CommiSsar' ' mchorage CONDUCTOR AS- BUl LT LOCATIONS ,,~,,, ..... , ,..,~ Dr~f*id by :~ D-~. LONG= ~'EL, 36.5 ? ;. ,! . : :'" LA[= LONG= 1~,_~°5~;' 15. 3~'' ~L 36 LAT= 70o24' LONG= ~9o56' ~5.~96" LAT = 70°2~' LONG= 1"9°~6'; 15.2~:" FEL 36. 3 96, ~ I. 5 ~:- L T= ~0°2;' I2. 371'' LONG= FEL 36.20G, LAT= 70°2~' !2.5])" LONG= 1~9- 55' [5. , :EL 36. I SG, - I. ' '' LAT = 70°~' ' _ . ~; ' r[L 36.3 '~3, * I.: - ~:L 35.~ L T = 7092~' 13. ~:-" 35.5 7.3, ~I. ~ :' CHECK LIST FOR NEW WELL PERMITS Company ~7~ Lease & Well No. ITEM APPROVE DATE (1) Fee i/a-. (/- r?-,~' 1. Is / (2) i oc ffz_.. (~" thru 8) (3) Admin I~./_.~- 'f"f?-f,~" 9. (9 thru 12) 10. #,Z# . '(10 and '12) / 12. thru (22 thru/26) 13. 14. 15. 16. 17. 18. 19. 20. 21. YES NO ., 2. Is 3. Is 4. Is 5. Is sufficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included .......... 7. Is operator ,~he only affected party .................. '. 8. Can permit be approved before ten-day wait .......................... 22. 23. 24. 25'. 26. REMARKS 27. the permit fee attached ......................................... well to be located in a defined pool ............................. well located proper distance from property line .................. well located proper distance from other wells .................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings Will cement cover all known productive horizons ............... ' ''' Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... ~T~ Are necessary diagrams of diverter and BOP equipment attached..~..i~~;~ Does BOPE have sufficient pressure rating - Test to 3J'd-O pslg Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable .................................. N~T Geology: Eng$.~ee_ring: ,.cs WVA M~., HJH~ JAL rev: 03/13/85 ~~. INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE 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. ;,~ .... SC MLJMB ER GE R .... LIS TAPE ~E~IFIC~TIDN LISTING LVP OIO.HO2 VERIFICATION LISTIN3 PAGE 1 ::=:;~ REEL HEADER ~::: SEOVICE NAME :EDIT DATE :$5/12/16 ORIGIN : REEL NAME :149322 CONTINUATION ~ :01 PREVIOUS REEL : COMMENTS :LIBRARY TAPE :::$ TAPE HEAD=R $~ SERVICE NAME :EDIT gATE :35/12/16 ORIGIN :0000 TAPE NAME :1073 CONTINUATION m :01 PREVIOUS TAPE : COMMENTS :LIBRARY TAPE ~ILE NAME :EDIT SERVICE NAME : VERSION ~ 9~TE : HAXIMUM LENGTH :iLE TYPE : PREVIOUS FILE INFORMATION .001 : 1024 : RECORDS ~NEM CONTENTS CN : ~RCO ALASK~ WN : 3A-l~ :N : KUPARUK R~G: 9~ TOWN: 12N SECT: 7 COJN: N. SLOPE STAT: ~L~SK& CTRY: USA MNEM CONTENTS PRES: E ::::i: COMMENTS ~ INC UNIT UNIT TYPE O00 000 000 000 000 000 000 000 000 TYPE 000 C&TE 000 000 000 000 000 000 000 DO0 000 CaTE 000 SIZE 016 006 008 002 004 002 012 006 003 SIZE OOl CODE 065 065 065 065 O65 O65 065 055 O55 CODE 055 LVP OlD.H02 VERI:ICATiON LISTING PASE 2 SCHLUMB E R ALASKA COMPUTIN',~ CENTER COMPANY = ~RCD ~L~SK& INC WELL = FIELD : KUP~RUK COUNTY : NORTH SLOPE 50ROUGH ST&TE : ~L~SK& JOB NUMBER AT ACC: 71073 RUN N19 DATE LgGGE9: 9-DEC-~$ LOP: L. B. CUDNEY CASING = 9.625" TYmE FLUID = L.S.N.D. OENSITY : 10.1 LB/G VISCOSITY = 38.0 S PM : ;LLJIS LOSS : 10.8 C3 MATqIX SANDSTONE 3679' BIT SIZE RM RMF RMC RM AT TO 3.710 3.110 4.570 1.744 64.0 64.0 64.0 144. OF DF DF LV~ 010.H02 VERIFICATID!~ LISTIN,S PAgE NOLE CORRECTION=C~LIPER :',~:::..:,~c~: THIS DATA HAS NET ~EEN DEPTH SHIFTED - OVERLAYS :IELO PRINTS SCHLUMBERGER LOGS INCLUOEC, WITH THIS MAGNETiS TAPE: DgAL INDUCTION SPHERICALLY FOCdSED LOG (DIL) D~T~ ~V~ILABLE: 78~.0° TD FORMATION DENSITY COmPENSaTED LOG (FDN) COMPENSATED NEUTRON LOG (FDN) DATA ~VAILABLE: 7818.0' TO 7248.0' GAMMA RAY IN CASING (GR.CNL) DATA ~V~IL~BLE: 3709.0' TO 1~.5' ~::~ OAT4 FORMAT RECORD LVP OIO.HOZ VERIFICATISN LI$TIN3 PAGE ENTRY BLOCKS 3ATJM SPECIFICATION MNEM SERVICE SERVICE ID ORDER ~ DEPT SFLU DIL ILO OIL ILM DIL SP OIL 3R OIL GR ~ON CNLI FDN 2HOB FDN CRH] FON NR4T F3N RNR~ m[)N NPHI ~ON NC N L F ON FCNL FDN ,,SR C NL TYPE 2 16 0 SIZE 1 1 4 1 1 REPR DEPT SP NPHI SEPT SP NPHI OEPT SP R~3B NPHI DEPT SP NPHI DEPT SP CODE 86 66 73 65 66 66 BLOCKS UNIT ~PI 4PI 4PI API FILE LOG TYPE CLASS MOD NC. ~T O0 000 O0 0 0 OHMM O0 220 O1 0 0 OHMM O0 120 ~6 0 0 CHMM O0 120 44 0 0 MV O0 010 O1 0 0 S~PI O0 310 O1 0 O 3~PI O0 310 O1 0 0 IN O0 280 O1 0 0 G/C3 O0 350 02 0 0 G/C3 O0 356 O1 0 0 O0 ~20 01 0 O O0 000 O0 0 0 PU O0 890 O0 0 0 CPS O0 330 31 0 0 CPS O0 330 30 0 0 G~PI O0 310 O1 0 0 7818.5000 SFLU -41.2383 GR -999.2500 DRH3 -999.2500 NCNL 7500.0000 SFLJ -~4.~633 GR -1.95&3 ORH3 0.0977 NCNL 7700.0000 SFLU -43.3945 Se 2.4397 9RH3 42.575~ NCNL 200 -9~ -9~ 0.6875 0.0000 9.2500 9.2500 2.4651 0.0000 6.9250 0.0000 2 104 0 l'~6T 6 89 0 2075 9 76 0 .~7~9 .5898 .0~15 .6875 .9812 .5898 .0322 .5000 .1504 .2148 .0205 7500.0000 SFLO -43.9~83 GR 2.3948 36.8552 NCNL ILO 3R NR~T FCNL ILO OR NRAT FCNL ILO NRAT FCNL ILO GR NRAT FCNL ILD SR NR&T 7500.0000 SFLJ -55.0195 GR 2.4709 DRH] ENTRY 0 1 5O .lIN 1 0 SIZE SPL REPR CODE 4 I 68 ~ 1 58 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 ~ 1 68 ~ i 68 4 1 68 ~ 1 68 4 1 68 4 1 68 4 1 68 4 1 68 4 1 68 ~.2312 ILM -999.2500 CALI -999.2500 RNR~ -999.2500 GR 2.9153 ILM 0.0000 CALI 0.0000 RNRA 0.0000 OR 2.4377 ILM 10~.5898 CALI 3.5~52 RNRA ~96.8)06 GR 5.4109 ILM 89.5898 CALI 3.2053 RNRA 594.8125 GR 8.1815 ILM 76.2148 C&LI 2.8596 RNRA P ( 00000000 00000000 00000000 OOO00000 00000000 00000000 00000000 00000000 00000000 00000000 00000000 00000000 00000000 00000000 00000000 00000000 ROCESS OCTAL) 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 000000 80.9023 -999.2500 -999.2500 -9'99.2500 2.9612 0.0889 0.0000 -~99.2500 2.5527 9.4004 3.7581 -999.2500 5.9148 9.1348 3.~885 -999.2500 8.4473 9.0566 3.1213 tVp OiO.HOZ VERIFIC~TI3N LI$TIN3 PASE 5 DE~T SP RMgB NPHI DEPT SP NPHI DEPT SP RHOB NPHI DEPT SP NPHI DEPT NPHI DEPT SP NPHI DEPT SP NPHI DEmT SP RH3B NPMI 3EPT SP RH3B 9E~T SP NPHI OEPT SP 31.1035 NCNL 2317.5000 mCNL 7~00.0000 SFLJ -57.6~45 GR 2.4983 ORMO 30.6152 NCNL 10.3513 ILD 79.2148 GR 0.0137 NRAT 2255.5000 FCNL 7300.0000 S;LJ -56.9883 GR 2.2776 DRMO 45.8496 NCNL 1.8497 ILD 113.4648 GR 0.0259 NRaT 1714.6875 FCNL 7200.0000 SFL8 -66.0352 GR -999.2500 ORHO -999.2500 NCNL 3.3157 ILD 95.4023 GR -'999.2500 NRAT -999.2500 FCNL 7100.0000 SFLU -65.0977 GR -999.2500 DRHg -999.2500 NCNL Z.8459 ILO 124.2148 GR -9~9.2500 NR~T -999.2500 FCNL TO00.O000 SmLU -59.050B GR -999.2500 DRHD -999.2500 NCNL 1.??15 ILD 4Z0.1~06 GR -999.2500 NRAT -99'9.2500 FCNL 6900.0000 SFLU -70.9102 GR -999.2500 DRHO -999.2500 NCNL 3.9143 IL2 132.5625 GR -999.2500 NR~T -999.2500 mCNL 6800.0000 SFLU -75.2227 GR -999.2500 DRH] -999.2500 NCNL 4.4578 ILD 109.3398 GR -999.2500 NRAT -999.2500 FCNL 6700.0000 SFLg -75.7227 GR -999.2500 DRH3 -999.2500 NCNL 3.7229 ILO 106.0898 GR -999.2500 -999.2500 FCNL 6500.0000 SFLJ -70.1502 JR -999.2500 ORMO -999.2500 NCNu 3.5295 ILD 108.7773 GR -999.2500 NRAT -999.2500 FCNL 6500.0000 SFLJ -74.6602 GR -999.Z500 ORHO -999.2~00 NCNL ~.7507 ILD 112.2?73 GR -999.2500 NR~T -999.2500 FCNL 6~OO.O00O SmLJ -91.4102 GR 3.8030 ILO 95.7773 GR ?~Z.3125 GR 6.7468 ILM 79.2148 CALl 2.8~40 RNR~ 757.3125 GR 1.6241 ILM 113.4648 CALI 3.6975 RNRA 420.6406 GR 2.1370 ILM -999.2500 CALl -999.2500 RNRA -999.2500 GR 2.5515 ILM -999.2500 CALl -999.2500 RNR~ -999.2500 GR 1.5508 ILM -999.2500 CALi -999.2500 RNR4 -9~9.2500 GR 3.1956 ILM -999.2500 CALl -999.2500 RNRA -999.2500 GR 3.6780 ILM -999.2500 C~LI -999.2500 RNR~ -999.2500 GR 3.5334 ILM -999.2500 CALl -99'9.2500 RNR~ -999.2500 GR 3.3264 IL4 -999.250D CALl -999.2500 RNRA -999.2500 GR 4.9G21 ILM -9~9.2500 CALl -999.2500 RNRA -999.2500 SR 3.5~79 ILM -~99.2300 C~LI -999.2500 7.4148 9.2754 2.9768 -999.2500 1.7442 9.1270 4.0750 -999.2500 2.2502 -999.2500 -999.2500 -999.2500 2.6409 -999.2500 -999.2500 -999.2500 1.6964 -999.2500 -999.2500 -999.2500 3.3577 -999.2500 -999.Z500 -999.2500 3.8225 -999.2500 -999.2500 -999.2500 3.5686 -999.2500 -999.2500 -999.2500 3.3792 -999.2500 -999.2500 -9')9.2500 5.0437 -999.2500 -999.2500 -999.2500 3.72~8 -'999.2500 LVP OlO.H02 VE~!FICATION LISTIN3 PAGE 6 RHOB NPHI D~PT SP NPHI DEPT SP NPHI S~ ~HOB NPHI DEPT RHOB NPHI 2EPT SP RHOB NPHi DEPT SP RH'35 NPHI NPHI DEPT SP RHOB NPHI 3EmT SP RH3S NPMI DEPT SP NPHI -99 -99 630 -7 -99 - 99 620 -7 -99 -99 610 -7 -99 -99 60O -7 -99 -99 9.250 9.250 0.000 8.597 9.250 9.250 0.000 5.597 9.250 9.250 . 2. 9. 9. . 2. 9. 9. 5900. -72. -999. -999. . . . 3. 9. 9. 580 -9 -99 -99 570 -8 -99 -99 550 -7 -99 -99 5500. -73. -999. -999. . 6. 9. $~0 -7 -99 -99 530 . 000 535 250 250 000 (:,60 25O 250 000 660 250 250 000 785 250 250 000 472 25O 2.50 000 035 250 250 000 785 250 250 000 222 250 250 000 0 ORHO 0 NCNL 0 SFLU 7 GR 0 ORH9 0 NCNL 0 SFLU 7 GR 0 ORHO 0 NCNL 0 SFLJ GR 0 DRH3 0 NCNL 0 SFLO 2 GR 0 ORHD 0 NCNL 0 SF-LJ 2 GR 0 9RHO 0 NCNL 0 SFLU 0 DRY3 0 NCNL 0 SFLJ 7 GR 0 DRH3 9 NCNL 0 SFLU 2 5R 0 OReO 0 NCNL 0 S~LJ 2 GR 0 DRH3 0 NCNL 0 SFLJ 7 SR 0 DR'iD 0 NCNL C SFLU -999.2500 NRAT -999.2500 FCNL ~.5203 ILD 98.7773 GR -999.2500 NRAT -999,2500 ~CNL 3.7971 ILD 102.5898 GR -999.2500 NR~T -999.2500 FCNL 3.4338 ILO 98.9648 GR -999.2500 NRAT -999,2500 FCNL 2,9~17 ILD 110,9023 GR -999,2500 NRAT -999.2500 FCNL 3.4124 ILO 101.4648 GR -999.2500 NR~T -999.2500 FCNL 3.9202 ILD 130.3125 GR -999.2500 NRAT -999.2500 ~CNL 3.6194 ILD 132.6875 GR -9~9.2500 NRAT -999.2500 FCWL 2.4338 ILD 159.1875 GR -999.2500 NRAT -999.2500 FCNL 1.5899 ILD 117.9648 GR -999,2500 NR&T -999.2500 ~CNL 1.9229 IL9 107.0273 GR -999.2500 NR~T -999.2500 FCNL 1.~760 ILD -999.2500 RNRfi -999.2500 GR 4.2937 ILM -999.2500 CALI -999.2500 RNRA -99'9.2500 GR 3.7405 ILM -999.2500 CALl -999.2500 RNR~ -999.2500 GR 3.3147 ILM -999.2500 CALl -999.2500 RNR4 -999.2500 GR 2.8655 ILM -999.2500 CALl -999.2500 RNR~ -999.2500 GR 2.8303 ILM -999.2500 CALI -999.2500 RNRA -999.2500 GR 3.9338 ILM -999.2500 CALI -999.2500 RNRA -999.2500 GR 3.4573 ILM -999.2500 CALI -999.2500 RNRA -999.2500 GR 1.8546 ILM -999.2500 CALl -999.2500 RNRA -999.2500 GR 1.5~56 ILM -999.2500 CALl -999.2500 RNRA -999.2500 GR 2.0569 ILM -999.2500 CALl -999.2500 RNR& -999.2500 GR 2.0706 ILM -999.2500 -999.2500 4.3875 -999.2500 -999.2500 -999.2500 3.8362 -999.2500 -999.2500 -999.2500 3.3792 -999.2500 -999.2500 -999.2500 2.9221 -999.2500 -999.2500 -999.2500 2.9612 -999.2500 -999.2500 -999.2500 3.9729 -999.2500 -999.2500 -999.2500 3.5217 -999.2500 -999.2500 -999.2500 1.9297 -999.2500 -999.2500 -999.2500 1.6651 -999.2500 -999.2500 -999.2500 2.0745 -999.2500 -999.2500 -999.2500 2.0686 LVP OIO.HOZ VERIFICATION LISTINS PAGE 7 SP -73.5352 GR RH]B -999.2500 DRH2 NPHI -999.2500 NCNL 82.4648 GR -999.2500 NR~T -999.2500 mCNL 9EPT 5200.0000 SFLJ SP -76.0352 GR RHOB -999.2500 ORH3 NPHI -999.2500 NCNL 2.2971 72.2148 OR -939.2500 NR4T -999.2500 FCNL DEPT 5100.0000 SFLU SP -77.597? GR ~HOB -999.2500 DRH3 NP~I -999.2500 NCNL 2.4202 ILO 76.6523 -999.2500 NR&T -999.2500 FCNL OEPT 5000.0000 SFLJ SP -78.3477 GR 2H28 -999.2500 DRHO NPqI -99'3.2500 NCNL 2.0823 ILD 86.46~8 GR -999.2500 NRAT -999.2500 FCNL OEPT 4900.0000 S:LU SP -83.1602 GR ~HO~ -999.2500 OReS NPHI -999.2500 NCNL 3.6018 ILD 110.4023 GR -999.2500 NR&T -999.2500 FCNL DEPT 4800.0000 SELU SP -B2.1602 GR RHOB -999.2500 ORH2 NP~I -999.2500 NCNL 2.3713 IL3 93.5273 GR -999.2500 NR~T -999.2500 ~CNL DEPT GTO0.O000 S~Ld SP -83.0977 GR RH3S -9'99.2500 3RHO NPHI -999.2500 NCNL 2.9512 ILD )6.1523 GR -999.2500 NR4T -999.2500 FCNL DEPT 4600.0000 SFL~ SP -79.0352 GR RH35 -999.2500 DRHO NPHI -999.2500 NCNL 2.6155 ILD 91.5898 GR -999.2500 NR~T -9')9.2500 ~CNL ~EPT ~500.0000 SFLU SP -80.1502 GR RHGB -999.2500 ORHb NP~I -~99.2500 NCNL 3.2463 ILO 107.7148 GR -999.2500 NR~T -9)9.2500 ~CNL 2EPT 4400.0000 SFLJ SP -82.2852 GR q~35 -~99.2500 ORe3 NPHI -~99.2500 NCNL 8.4795 ILO 77.2773 OR -9)9.2500 NRaT -999.2500 ~CNL DEPT ~300.0000 SFLO SP -82.6502 GR QH]5 -999.2500 DRHG NP~I -999.2500 NCNL 3.0198 ILO ~4.589~ GR -999.2500 NR~T -9~9.2500 ECNL -999.2500 C4LI -999.2530 RNR~ -999.2~00 GR 2.5178 ILM -999.2500 C&LI -999.2500 RNR4 -999.2500 GR 2.5510 ILM -999.2500 CALI -999.2500 RNR~ -999.2500 GR 2.8538 ILM -999.2500 CALI -999.2500 RNRA -999.2500 GR 3.7542 ILM -999.2500 CALI -999.2500 RNR& -999.2500 GR 2.658~ ILM -999.2500 C~LI -999.2500 RNQ~ -999.2500 GR 3.2301 ILM -999.2500 C~LI -999.2500 RNR~ -999.2500 GR 2.8616 ILM -999.2500 C~Li -999.2500 RNR~ -999.2500 GR 3.5608 ILM -999.2500 C4LI -999.2300 RNR~ -999.2500 GR 4.2781 ILM -999.2500 C~LI -93~.2500 RNR~ -999.2500 GR 3.4334 ILM -999.2500 CALI -9)9.2500 RNRA -999.2500 GR -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 -999.2500 2.5393 -999.2500 -999.2500 -999.2500 2.6526 -999.2500 -999.2500 -999.2500 3.7815 -999.2500 -999.2500 -999.2500 2.5920 -999.2500 -999.2500 -999.2500 3.1682 -999.2500 -999.2500 -999.2500 2.7874 -999.2500 -999.2500 -999.2500 3.4709 -999.2500 -939.2500 -999.2500 4.5437 -999.2500 -999.250O -999.2500 3.3069 -999.2500 -999.2500 -999.2500 LVP OiO.HOZ VERIFICATIOq LI$TIN} PAgE 8 SEPT NPHI SP NPHI SP NPHI SEPT SP NPHI DE~T SP NPHi SEPT SP SEPT SP RHOB NPHI 9E~T SP RH]B NPHI 9E~T SP RH]5 NPqI SEPT SP '~PHI SEPT NPHI 4200.0000 SFLJ -~3.7552 G2 -999.2500 DRH3 -999.2500 NCNL 4100.0000 S:LU -86.5352 3R -999.2500 ORH3 -999.2500 NCNL 4000.0000 SFLU -86.2227 GR -999.2500 DRHO -999.2500 NCNL 3900.0000 SFLU -84.1502 GR -999.2500 ORH3 -999.2500 NCNC 3800.0000 SFLU -88.0352 GR -999.2500 ORHO -999.2500 NCNL 3700.0000 SFLU -89.0352 GR -999.2500 DRH] -999.2500 NCNL 3500.0000 SFLU -999.2500 GR -999.2500 DRH3 -999.2500 NCNL 3500.0000 SFLU -999.2500 GR -999.2500 DRH3 -999.2500 NCNL 3~00.0000 SFLJ -999.2500 3R -999.2500 ORM3 -999.2500 NCNL 3300.0000 SFLJ -999.2500 GR -999.2500 -999.2500 NCNL 3200.0000 S~LU -999.2500 GR -999.2500 9RH3 -9'99.2500 NCNL 3.3362 ILO 90.964B 3R -999.2500 NRAT -9~9.2500 FCNL 3.7131 ILO 95.4023 GR -999.2500 NRAT -999.2500 FCNL 4.2234 ILS 87.2148 GR -9~9.2500 NRAT -999.2500 FCNL 2.1780 ILO 98.2773 GR -999.2500 NR~T -999.2500 FCNL 4.7078 ILO 81.8398 GR -999.2500 NRAT -999.2500 FCNL 4.9226 ILS 84.589B GR -999.2500 NR~T -999.2500 FCNL -9~9.2500 ILO -999.2500 GR -999.2500 NR&T -999.2500 FCNL -999.2500 ILO -999.2500 GR -999.2500 NR&T -999.2500 FCNL -9g9.2500 ILD -9}9.Z500 GR -999.2500 NRAT -999.2500 FCNL -999.2500 ILO -999.2500 GR -999.2500 NRAT -999.2500 FCNL -999.2500 ILS -999.2500 3R -999.2500 NR~T -999.2500 FCNL 3.7581 ILM -999.2500 CALI -999.2500 RNR& -999.2500 GR ~.1765 ILM -999.2500 C6LZ -999.2500 RNR~ -999.2500 GR 4.7351 ILM -999.2500 CALI -999.2500 RNRA -999.2500 GR 2.8555 ILM -999.2500 CALI -999.2500 RNRA -999.2500 GR 6.250? ILM -999.2500 CALl -999.2~00 RNR~ -999.2500 GR 5.1453 ILM -999.2500 CALI -999.Z~00 RNRA -999.2500 GR -999.2500 ILM -999.2500 C4LI -999.2500 RNR~ -999.2500 GR -999.2500 ILM -999.2500 CALI -999.2500 RNR& -999.2500 GR -999.2500 ILM -999.2500 CALI -9'99.2500 RNR~ -999.2500 GR -999.2500 ILM -999.2500 C~LI -999.2500 RNR~ -999.2500 GR -999.2500 ILM -999.2500 C4LI -999.2500 RNR4 -999.2500 GR 3.6077 -9'99.Z500 -999.2500 -999.2500 ~.O125 -999.2500 -999.2500 -999.2500 4.5554 -999.2500 -999.2500 -999.2500 2.6877 -999.2500 -999.2500 -999.2500 5.&773 -999.2500 -999.2500 -999.2500 5.0437 -999.2500 -999.2500 66.0273 -999.2500 -999.2500 -999.2500 53.0117 -999.2500 -999.2500 -999.2500 57.8242 -999.2500 -999.2500 -999.2500 64.3398 -999.2500 -999.2500 -999.2500 44.7305 -999.2500 -999.2500 -999.2500 ~9.8555 , i LVm OlO.H02 VERImlCATIDN LISTIN$ PAGE 9 DEPT 3100.0000 SFLU SP -999.2500 GR RH3~ -999.2500 DRH2 NPHI -999.2500 NCNL 9EPT 3000.0000 SFL~ SP -999.2500 GR RHOB -999.2500 DRHO NPHI -99'~.2500 NCNL DEPT 2900.0000 SFLU SP -999.2500 GR RHgB -999.2500 DRH~ NPHZ -999.2500 NCNL DEmT 2800.0000 SFLU SP -999.2500 3R RHOB -999.2500 DRH3 NPHI -999.2500 NCNL 9EPT 2700.0000 SFLJ SP -999.2500 GR ~HD5 -99'9.2500 ORH3 NPHI -999.2500 NCN~ DEPT 2600.0000 SFLU SP -999,2500 3R RHDB -999.2500 DRH3 NP~I -999.2500 NCN~ ~EPT 2500.0000 SFL~ SP -999.2500 GR qH3B -999.2500 8RH3 NPflI -9~9.2500 NCNL 2EmT 2~00.0000 SFL~ SP -999.2500 RMV5 -999.2500 NPHI -999.2500 NCNL JEmT 2300.3000 S~LJ Sm -~99.2500 GR RMD6 -~99.2500 ORHO NPMI -999.2500 NCNL DEPT 2200.0000 SFLU Sp -999.2500 G2 RMDB -99~.2500 SRH3 NPHI -99~.2500 NCNL O~T 2100.0000 SFLJ SP -999.2500 GR 2H25 -999.2500 DRH] -999.250O ILD -999.2500 GR -9'99.2500 NR&T -999.2500 FCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 FCNL -99'9.2500 IL3 -999.2500 GR -'999,2500 NR~T -999.2500 FCNL -999.2~00 ILD -999.2500 GR -999.2500 NR~T -999.2500 FCNL -999.2500 ILD -999.2500 GR -9~9.2500 NR~T -9~9.2500 FCNL -999.2500 ILD -999.2500 GR -999.2500 NR~T -99'9.2500 FCNL -999.2500 ILD -999.2500 GR -999.2500 NR;T -999.2500 FCNL -9~9.2500 ILD -9~9.2500 GR -9}9.2500 NR~T -999.2J00 FCNL -999.2500 ILD -999.2500 GR -999.2500 NR~T -99'9.2500 FCNL -999.2500 IL9 -999.2500 GR -999.2500 NR&T -9~9.2500 mCNL -999.2500 -999.2500 GR -999.2500 -999.2500 C~LI -999.2500 RNR~ -999.2500 -9~9.2500 ILM -999.2500 C&LI -999.2500 RNR~ -9~.2500 GR -999.2500 ILM -999.2500 C~LI -999.2500 RNR~ -999.2500 GR -999.2500 ILM -999.2500 CALI -999.2500 RNR~ -999.2500 GR -999.2500 ILM -999.2500 C~LI -999.2500 RNR~ -999.2500 GR -999.2500 ILM -999.2500 CALI -999.2500 GR -999.2500 ILM -999.2500 C~LI -999.2500 RNRA -999.2500 GR -999.2500 ILM -999.2500 CALI -9'99.2500 RNRA -999.2500 GR -999.2500 ILM -999.2500 C~LI -99).2500 RNR~ -999.2500 GR -999.2500 ILM -9'~9.2500 CaLI -999.2500 RNRa -999.2500 SR -9'~9.2500 ILM -999.2500 C~kl -999.2500 RNR~ -999.2500 -999.2}00 -999.2500 47.7930 -999,2500 -999.2500 -999.2500 69.&648 -999.2500 -999.2500 -999.2500 ~1.511T -999.2500 -999.2500 -9'~9.2500 3~.T619 -9~9.2500 -999.2500 -999,2500 ~8.82~2 -999.2500 -999.2500 -999.2500 &2.~180 -999.2500 -9B9.2500 -999.2500 28.3330 -999.2500 -999.2500 51,7617 -999.2500 -999.2500 -999.2500 39.9~92 -999.2500 -999.2500 -999.2500 60.5555 -99'9.2500 -999.2500 -999.2500 LVP OlO,H02 VERIFICATI2~ LISTINS PAGE 10 NPHI OEPT SP RHO5 NPHi SP NPWI ~PHI OEPT SP NPMI 2EPT DEPT SP NPMI DEPT SP NPHI DE~T SP NPMI ,SEPT SP RMDB NPHI NPHI DEPT -999,2500 NCNL 2000.0000 SFLJ -999,2500 GR -999,2500 DRH3 -999.2500 NCNL 1900.0000 SFLd -999,2500 GR -999,2500 Dqdg -999,2500 NCNL 1800,0000 SFLJ -999,2500 GR -999,2500 DRH3 -999,2500 NCNL 1700.0000 SFLU -999,2500 GR -999.2500 DRH3 -999,2500 NCNL 1600,0000 SFLU -999,2500 GR -999,2500 DRH3 -999.2500 NCNc 1500,0000 SFLU -999,2500 GR -999,2500 DQHO -999,2500 NCNL 140D,O000 SFLU -999,2500 GR -999,2500 DRHO -99'~.2500 NCNL 1300.0000 SFLU -999,2500 GR -99'9.2500 DRH9 -999,2500 NCNL 1200,0000 SFLU -999,2503 SR -999,2~00 9Rq] -999.2500 NCNL 1100.0000 S~Ld -999,2500 GR -999.2500 DRH2 -999,2500 NCN~ 1000.0000 SFLJ -999.2500 SR -999.2500 FCNL -999,2500 ILD -999,2500 GR -999.2500 NR~T -999,2500 ~CNL -999,2500 IL9 -999,2500 GR -9~9.2500 NRAT -999,2500 ~CNL -999,2500 ILO -999,2500 GR -999,2500 NR~T -999,2500 FCNL -999,2500 ILD -999,2500 GR -9~99,2500 NRAT -999,2500 FCNL -999.2500 ILO -999.2500 GR -999.2500 NRAT -9~9.2500 FCNL -999.2500 IL9 -999,2500 GR -9J9,2500 NRAT -999,2500 FCNL -9~,2500 IL9 -999,2500 GR -999,2500 NRAT -999,2500 ~CNL -999,2500 lCD -999,2500 GR -999,2500 NRAT -999,2500 FCNL -999,2500 ILD -999.2500 SR -999,2500 NRAT -999.2500 FCNL -999,2500 ILD -999,2500 GR -999.2500 NRAT -999,2500 FCN~ -999.2500 ILD -999.2500 GR -999.2500 GR -999.2500 ILM -999.2500 C~LI -999.2500 RNRA -999.2500 GR -999,2500 ILM -999,2500 CALI -999,2500 RNRA -~99,2500 GR -999,2300 ILM -999,2500 CALI -999,2500 RNR~ -999,2500 GR -'9~9,2~00 ILM -ggg. ZSO0 CALI -999.2500 RNR.A -~99,2500 SR -999o2500 ILM -999.2500 CALI -999,2500 RNR4 -999,2500 GR -999,2500 ILM -999,2500 C~LI -999,2500 RNR4 -999,2500 GR -999.2500 ILM -999.2500 CALI -999,2500 RNR~ -999,2500 GR -999,2500 ILM -999,2500 CALI -999,2500 RNR~ -999,2500 GR -999,2500 ILM -999.2500 CALI -999,2500 RNRA -999.2500 GR -999,2500 ILM -9~9,Z500 CALI -999,2500 RNR~ -999,2500 GR -9~9.2500 ILM -999.2500 C~LI 30.1143 -999.2500 -999.2500 -999.2530 30.8174 -999.2500 -991~.~0 -999.2500 48.6055 -999.2500 -999.2500 -999.2500 34.5430 -99'},2500 -999.2500 -999.25O0 47.0117 -999.2500 -999.2500 -999.2500 47.0117 -9~9.2500 -999.2500 -999.Z500 34.7930 -999.2500 -999.2500 -999.2500 31.0361 -99'9.2500 -999,2500 -999.2500 17,8018 -999.2500 -999.2500 -999.2500 52.1992 -9~9.2500 -999.2500 -999.2500 50.7930 -999.2500 -999.2500 LV? OlO.HO2 VERIFIC&TION LISTIN~ PaGE 11 RHOB -999.Z500 DRH2 NPHI -999.2500 NCNL DEPT 900.0000 SFLU SP -999.2503 GR RH3B -999.2500 DRH3 NPMI -999.2500 NCNL DEmT 800.0000 SFLU SP -999.2500 gR RHgB -999.2500 DRHO NPHI -999.2500 NCNL 9EPT 700.0000 SFLU SP -999.2500 GR RH05 -999.2500 DRH3 NPHI -999.2500 NCNL DEPT 600.0000 SFLJ SP -999.2500 GR RHOB -999.2500 DRHO NPHI -999.2500 NCNL OEPT 500.0000 SFLU SP -999.2500 GR RH05 -999.2500 NPHI -999.2500 NCNL gEPT 600.0000 SFLJ SP -999.2500 GR RHOB -999.2500 DRHO NPHI -999.2500 NCN~ DEPT 300.0000 SFLJ SP -999.2500 GR RHD5 -999.2500 DRH] NPHI -999.2500 NCNL DEPT 200.0000 SFLJ SP -999.2500 GR RH3B -ggg.2$O0 DRH3 NP~I -999.2500 NCNL 2EOT 14~.$000 S~LJ SP -999.2500 GR RHSB -999.2500 DRH3 NPHI -999.2500 NCNL -999.2500 NR~T -999.2500 FCNL -999.2500 ILD -999.2500 GR -999.2500 NR~T -999.2500 mCNL -999.2500 ILD -999.2500 GR -999.2500 NR&T -9~9.2500 FCNL -999.2500 ILO -999.2500 GR -999.2500 NR~T -999.2500 FCNL -999.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 FCNL -9~9.2500 ILD -999.2500 GR -999.2500 NR~T -999.2500 FCNL -9~9.2500 ILD -999.2500 GR -999.2500 NRAT -999.2500 :CNL -999.2500 ILD -999.2500 GR -999.2500 NR~T -999.2500 ~CNL -9~9.2500 ILD -999.2500 GR -999.2500 NRAT -9~).2500 FCNL -9~9.2500 ILD -999.2500 GR -999.2500 NR~T -999.2500 FCNL -999.2500 RNR~ -999.2500 GR -999.2500 ILM -999.2500 C&LI -999.2500 RNR~ -999.2500 GR -999.2500 ILM -999.2500 CALI -999.2500 RNR~ -999.2500 GR -999.2500 ILM -9'99.2500 CALI -999.2500 RNRA -999.2500 GR -999.2500 ILM -999.2500 C~LI -999.2500 RNR~ -999.2500 GR -999.2500 ILM -999.2500 CALI -999.2500 RNRA -999.2500 GR -999.2500 ILM -999.2500 CALI -999.2500 RNR~ -999.2500 GR -999.2500 ILM -999.2500 CALI -999.2500 RNRA -999.2500 GR -999.2500 -999.2500 CALI -999.2500 RNR~ -999.2500 5R -999.2500 ILM -999.2500 CALI -999.2500 RNR& -999.2500 GR -999.2500 68.9180 -999.2500 -999.2500 -99'9.2500 22.8486 -999.2500 -999.2500 -999.25D0 46.293O -999.2500 -999.2500 -999.2500 53.8867 -999.2500 -999.2500 -999.2500 55.261T -999.2500 -999.2500 -999.2500 30.7393 -999.2500 -999.2500 -999.2500 41.3867 -999.2500 -999.2500 -999.2500 38.0117 -999.2500 -999.2500 -999.2500 63.4692 -9~9.2500 -999.2500 -9~9.2500 24.4893 FILE N&ME :EDIT SERVICE fl~ME : VERSION ~ : ]~T~ : .001 LVP OiO.HO2 VERIFICATIDN LISTING PAGE 12 MAXIMUM LENGTH : FILE TYPE : NEXT FILE NAME : 102~ :::~, TaPE TR~ILER SERVICE NAME :EDIT OATE :85/12/16 ORiSiN T~PE N~ME :107~ CDNTINU~TIgN m :01 NEXT T~PE N~ME : COMMENTS :LIBRARY T~PE =;~ REEL TRAILER ~::' SERVICE NA~E :EDIT 9/rTE :95/12/15 ORIGIN : REEL N~ME :149322 CONTINUATION ~ :01 NEXT REEL NAME : COMMENTS :LISR&RY T~PE EOF EOF
