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182-163
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, June 20, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Austin McLeod P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1E-27 KUPARUK RIV UNIT 1E-27 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/20/2022 1E-27 50-029-20837-00-00 182-163-0 W SPT 5888 1821630 1500 2525 2525 2525 2525 230 300 310 310 4YRTST P Austin McLeod 6/4/2022 MITIA 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1E-27 Inspection Date: Tubing OA Packer Depth 490 2010 1960 1960IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSAM220605184545 BBL Pumped:1.1 BBL Returned:1.1 Monday, June 20, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.06.20 15:28:15 -08'00' • S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Tuesday,June 12,2018 Jim Regg l v P.I.Supervisor &lLi (15 )(l7 SUBJECT: Mechanical Integrity Tests &l CONOCOPHILLIPS ALASKA,INC. 1E-27 FROM: Adam Earl KUPARUK RIV UNIT 1E-27 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv: NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1E-27 API Well Number 50-029-20837-00-00 Inspector Name: Adam Earl Permit Number: 182-163-0 Inspection Date: 6/9/2018 Insp Num: mitAGE180611084939 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1E-27 - Type Inj W' TVD 5888 Tubing 2660 2650 2650 2650 '� _-__..— --- -- �---- -;- . PTD 1821630 - Type Testi SPT Test psil 1soo IA 620 1800 1765 - 1760 - BBL p axRTST lP/F P Interval j 0.7 OA 170 220 210 - 210,� Pumped: I BBL Returned: Notes: MIT-IA SEAMED JUN 22Lu1 Tuesday,June 12,2018 Page 1 of 1 , , • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Plug Ibrforations r Ftrforate r Other I ProD => Inj H2O After Casing r Rill Tubing r j Stimulate - Frac r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ,: Exploratory r 182 -163 3. Address: 6. API Number. Stratigraphic r Service r P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 20837 - 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL -25651 1E-27 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): 4 None Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 6800 feet Plugs (measured) None true vertical 6639 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 5966, 6220 true vertical 0 feet (true vertucal) 5888, 6120 Casing Length Size MD TVD Burst Collapse CONDUCTOR 53 16 85 85 SURFACE 2186 10 3/4 2218 2218 PRODUCTION 6685 7 6715 6564 RECEIVED titNED MAY 2 a 2012 MAY 15 2012 Perforation depth: Measured depth: 6122 - 6167,6177 -6185, 6330 -6340, 6357 -6382, 6390 -6394 AOGCC True Vertical Depth: 6031 -6072, 6081 -6088, 62195 -6228, 6244-6266, 6274 -6277 Tubing (size, grade, MD, and TVD) 3.5, J - 55, 6245 MD, 6142 TVD Packers & SSSV (type, MD, and TVD) PACKER - OTIS RRH RETRIEVABLE PACKER © 5966 MD and 5888 TVD PACKER - OTIS WD PERMANENT PACKER © 6220 MD and 6120 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A �, Treatment descriptions including volumes used and final pressure: Aeroatti A 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water Casing Pressure Tubing Pressure Prior to well operation 356 988 1366 1350 204 Subsequent to operation 0 0 2344 1453 913 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r i Development r Service � Stratigraphic r 16. Well Status after work: O il r Gas r VVDSPL r Daily Report of Well Operations GSTOR r VVINJ p WAG r GINJ r SUSP r SPLUG r 17.1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt 312 -063 Contact Darrell Humphrey / Bob Christensen Printed Name Darrell Humphrey Title Production Engineering Specialist Signature ` t Phone: 659 - 7535 Date Submi Original Only RL3 QNIS MAY 15 �1� ` Form 10-404 Revised 11/2011 2 g v • • 1E-27 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summa 04/151121Injection commenced 05/06/12 Initial State Witnessed (John Crisp) MITIA (Passed), Initial T/I/O= 275/633/180. Pressured up IA to 3000 psi with 2.0 bbls of diesel. Start MITIA, TA /O= 275/3020/200, 15 min reading T/1/O= 275/2968/210, 30 min reading T /1 /O= 275/2953/210. Bleed IA down, (5 min bleed, all fluid). Final T/I/O= 275/500/180. I I 1 1 1 I r : KUP • 1E-27 ConocoPhillips 0- Well Attributes Max An & MD TD Alaska. Inc. Wel!bore APW WI Field Name Well Status Inc! (1 MD (RKB) Act Btm (RKB) coma:hops 500292083700 KUPARUK RIVER UNIT PROD 27.20 6,550.00 6,800.0 Comment H2S (ppm) Date Annotation End Date KB63rd (R) Rig Release Date ••• Wall COnfq: DEVIATED -tE -Z7 V10/$0122:0652 PM SSSV:TRDP Last WO: 12/30/1984 39.00 10/19/1982 Sc5matb -Mal Annotation Depth (ttKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 6,362.0 7/30/2011 Rev Reason: WELL REVIEW osborl 4/10/2012 HANGER, 27- " ( Casing Strings Casing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd J 1; / r CONDUCTOR 16 15.060 32.0 85.0 85.0 65.00 H-40 WELDED Casing Description String 0... String ID ... Top (ttKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd / SURFACE 103/4 9.950 31.6 2,217.6 2,217.5 45.50 K - 55 BTC Casing Description String 0... String ID ... Top (ttKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 30.5 6,715.1 6,563.7 26.00 K - 55 BTC CONDUCTOR, - Tubing Strings 32 -85 Tubing Description String 0... String ID ... Top (RKB) Set Depth (t.. Set Depth (TVD) ... String Wt.. String ... String Top Thrd SAFETY VLV, TUBING 31/2 2.992 27.3 6,245.4 6,143.0 9.20 J -55 BTC -MOD 1,874 �1 Completion Details Top Depth fi (TVD) Top Inc! Nomi... Top (RKB) MB) (1 Item Description Comment ID (in) 27.3 27.3 -0.43 HANGER FMC GEN III HANGER 3.500 SURFACE, A L 1,874.3 1,874.2 1.06 SAFETY VLV CAMCO TRDP- 1A -ENC NON- EQUALIZING SAFETY VALVE 2.813 32 - 2216 5,940.0 5,863.8 23.05 SBR OTIS SBR 2.970 GAS LIFT. } 5,966.1 5,887.9 23.03 PACKER OTIS RRH RETRIEVABLE PACKER 2.813 5.898 6,120.3 6,029.3 23.90 BLAST JTS CAMCO 10' STEEL BLAST JOINTS (8) 2.992 6,219.2 6,119.2 24.83 LOCATOR OTIS STRAIGHT SLOT LOCATOR 4.000 SBR, 5,940 5 6,220.5 6,120.4 24.82 PACKER OTIS WD PERMANENT PACKER 4.000 I 1 6,223.9 6,1214 24.80 ADAPTER OTIS PACKER ADAPTER 4.000 PACKER, 5,988 I - -_!I 6,224.4 6,123.9 24.79 SBE ' OTIS SEAL BORE EXTENSION 2.970 IR 6,238.7 6,136.9 24.69 NIPPLE CAMCO D NIPPLE NO GO, MILLED TO 2.80" 2.800 INJECTION, 6.244 7 6,142.4 24.64 SOS OTIS SHEAR OUT SUB 3.950 6,005 - -.. - --/ Other In Hole ireline retrievable plugs, valves, pumps, fish, etc.) lit Top Depth (TVD) Top lncl Top (RKB) MKS/ ( °) Description Comment Run Date ID (in) INJECT 6,235.0 6,235.0 6,133.6 24.71 PUNCHES TUBING PUNCHES, PRE -CTD LATERALS 8/2/2011 2.992 s oaa 6,288.0 6,181.6 25.29 WHIPSTOCK NON- RETRIEVABLE 8/31 /2011 Perforations & Slots Shot IPERF. Top (TVD) Btm (TVD) Dens 612246,167 1 Top (MB) Btm (RK8) (RKB) (121(8) Zorn Date (Phi- Type Comment 6,122.0 6,167,0 6,030.9 6,071.9 C C - 3, 1E - 27 10/18/1982 4.0 IPERF IPERF, E 72 6,177 6,177.0 6,185.0 6,081.0 6,088.2 C -2, C -1, 1E -27 10/18/1982 4.0 IPERF 6,330.0 6,340.0 6,219.5 6,228.5 A -5, 1E -27 10/18/1982 4.0 IPERF 6,357.0 6,382.0 6,244.0' 6,266.5 A-4, 1E -27 10/18/1982 4.0 IPERF INJECTION. 6,390.0 6,394.0 6,273.7 6,277.3 A-4, 1E -27 10/18/1982 4.0 IPERF 6,204 Notes: General & Safety End Date Annotation 9/7/2010 NOTE: View Schematic w/ Alaska Schematic9.0 Cement 9/2/2011 NOTE: ADD LATERALS L1, L1 -01, L1-02 Squeeze, 6,215 LOCATOR. 6,219 II I J t PACKER, 6,220 ' - r ADAPTER, _1: - 6,E __ SBE, 6,224 TIRE MIR IN PUNCHES, �: 6.235 PI NIPPLE. 6,239 *nr, I i® 505.6,245 sal. WHIPSTOCK, � 6,288 IPERF, 6 ill 1 ,330-6,340 IPERF, 8.35 II IPERF, PR, . II 6,390 -6E,'394 PRODUCTION, 316.275 TD 80), • Mandrel Details 6,800 Top Depth Top Port WHIPSTOCK, (TVD) Intl OD VaNe Latch 512e TRO Run 8.900 SLOTS, Stn Top (RKB) (RKB) ( Make Model (in) Sery TYP. Type (in) (Psi) Run Date Corn... 6,7 SLOTS 1 5,897.9 5,825.0 22.31 OTIS LBX 1 1/2 GAS LIFT DMY RM 0.188 0.0 3/12/2012 SOTS ,601 _ 2 6,005.1 5,923.6 22.55 OTIS LBX 1 1/2 INJ DMY RM 0.000 0.0 7/31/2011 LINER L1 L1 - 01, 6,215 1 R s -6.3o6 3 6,080.1 5,992.5 23.55 OTIS LBX 1 1/2 INJ DMY RM 0.000 0.0 8/5/1997 4 6,203.8 6,105.3 24.95 OTIS LBX 1 1/2 INJ DMY RM 0.000 0.0 8/5/1997 ■ LINER L1 -02, El 6,901 -9,601 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday,May 07,2012 TO: Jim Regg Raiv. S/ P.I.Supervisor (I 1/�f I zi SUBJECT:Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1E-27 FROM: John Crisp KUPARUK RIV UNIT 1E-27 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 1E-27 API Well Number 50-029-20837-00-00 Inspector Name: John Crisp Permit Number: 182-163-0 Inspection Date: 5/6/2012 Insp Num: mitJCr120507110648 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1E-27 Type lnj j W 'TVD 5888 - IA 633 3020 - 2968 2953 - - PTD 1821630 - Type Test SPT Test psi 1500 - OA 180 200 210 210 . — - Interval IINITAL 1P/F P ' I Tubing 275 275 275 275 Notes: 2 bbls pumped for test.Initial post WO. - SCANNED MAR 1 3 2014 Monday,May 07,2012 Page 1 of 1 • • L� Regg, James B (DOA) P r ( B Z 4.3 o From: Regg, James B (DOA) Sent: Monday, April 16, 2012 8:49 AM / To: 'CPF1 Prod Engr' Subject: RE: LPP /SSV Defeated for 1E-27 on 04/15/2012 Just to be clear — 1E27 is PTD 1821630; other PTDs you list (partial list) are laterals and spokes (missing PTD 2111200) and are not necessary to list since all production and safety valve system are tied to main wellbore (1E -27) Jim Regg AOGCC 333 W. 7th Ave, Suite 100 r 907-793-1236 - K 99501 SCAB* App From: CPF1 Prod Engr [ mailto :n1269(aconocophillips.com] Sent: Monday, April 16, 2012 6:36 AM To: Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; NSK Prod Engr & Optimization Supv; Seitz, Brian; CPF1 &2 Ops Supt; NSK Prod Engr Specialist; Gauer, Jenn L; CPF1 Prod Engr; Seitz, Brian Subject: LPP /SSV Defeated for 1E -27 on 04/15/2012 Tom: The low pressure pilot (LPP) on dual Kuparuk injector 1E -27 (PTD# 211 -095 and 211 -096) was defeated on 04/15/2012 when well was brought online and the injection pressure was below 500 PSI while on injection. This low pressure is most likely because this injector was pre - produced for some time after the CTD laterals were completed. As of 0630 hrs on 04/16/2012 , wellhead injection pressure is 316 psi; injection rate is 2180 bwpd. The LPP and SSV have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The AOGCC will be notified when the injection pressure on either well has increased to above 500 psi and the LPP /SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. ConocoPhillips Alaska, Inc. West Sak Production Engineer Work - 907.659.3910 Mobile - 303.489.8833 1 '2-1217 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. March 9, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Plug Setting Record: 1E-27 Run Date: 3/8/2012 The technical data listed below is being submitted herewith. Please address any p roblems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1E -27 Digital Data (LAS), Digital Log file 1 CD Rom 50- 029 - 20837 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: 7-2 2 Signed: /24,41.a..--- 1 � � i • • Q,LN f 1_ F , i, C'� ; SEAN PARNELL, GOVERNOR 0L . Lai ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COIN ISSIOIQ ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Robert D. Christensen NSK Production Engineering Specialist , iF i, 1'. 10‘5 ConocoPhillips Alaska, Inc. bk: .. P.O. Box 100360 kq:"-- Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1E-27 Sundry Number: 312 -063 Dear Mr. Christensen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM , on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, , ,( . Daniel T. Seamount, Jr. Chair DATED this 22-day of February, 2012. Encl. • • • Robert Christensen/Darrell Humphrey Production Engineering Specialists. Greater Kuparuk Unit , NSK -69 PO Box 196105 ConocoPhillips Anchorage, AK 99519 -6105 Phone: (907) 659-7535 Fax: 659 -7314 February 14, 2012 RECEIVED Dan Seamount AOGCC Commissioner FEB 1 6 2012 State of Alaska, Oil & Gas Conservation Commission 33 W. 7 Ave. Ste. 100 ` Alaska Oil & Gas Cons. Commission Anchorage, AK 99501 Anchorage Dear Mr. Seamount, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk River Unit wells 1E- 27, 1E-27L1, 1 E -27L 1 -01, and 1 E27L 1 -02 from oil production to WAG injection v service.. Enclosed you will find 10 -403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. regarding 1E-27 (PTD 182 -163), 1E-27L1 (PTD 211- 095 -0), 1E-27L1-01 (PTD 211- 096 -0), and 1E-27L1-02 (PTD 211 - 120 -0). If you have any questions regarding this matter, please contact myself or Darrell Humphrey at 659 -7535. Sincerely, tgr Robert D. Christensen Attachments Sundry application Well schematic r STATE OF ALASKA • ALAS•IL AND GAS CONSERVATION COMMISS• a ,I Y � ti �� APPLICATION FOR SUNDRY APPROVALS . - ,�, , 20 AAC 25.280 1. Type of Request: Abandon r Plug for Redrill r Perforate New Pool r Repair well r Change Approved Program r Suspend r Plug Perforations r Perforate r Pull Tubing r lime Extension r Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing r Other:Convert to Injector 17 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development n Exploratory r 182 -163 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 20837 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property Tine 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No 0 1E-27 , 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25651 • Kuparuk River Field / Kuparuk River Oil Pool " 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6800 • 6639 - 6624' 6483' Casing Length Size MD TVD Bun- Collapse CONDUCTOR 80 16 112' 112' I® !/ ♦E® SURFACE 2186 10.75 2218' 2218' PRODUCTION 6685 7 6715' 6564' 1CD 1 ; 2012 a" rs > ns. CommiXiCin Perforation Depth MD (6122 - 6167, 6177 - 6185, Perforation Depth TVD (ft): 6031 -6072 Tubing Size: ' Tubing 6235 - 6237, 6330 - 6340, 6357 - 6382, 6390 - 6394 6081 - 6088, 6134 - 6135, 6220 - 6229, 6244 - 6267, 6274 - 6277 3.5 J -55 6245 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - OTIS RRH RETRIEVABLE PACKER MD= 5966 TVD= 5888 PACKER - OTIS WD PERMANENT PACKER MD= 6220 TVD= 6120 SSSV - CAMCO TRDP- IA -ENC MD =1874 TVD =1874 12. Attachments: Description Summary of Proposal 17, 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 2/20/2012 Oil r Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG J Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob Christensen / Darrell Humphrey Printed Name A R � t - rt D Chri tensen Title: NSK Production Engineering Specialist >f/ Signature / ♦ 5 (' / . _ Phone: 659 -7535 Date - 1 Commission Use Only Sundry Number:5 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test re Location Clearance r Other: Subsequent Form Required: /0 •. 4 /0 I f APPROVED BY 2 ZZ / j l Z Approved by: COMMISSIONER THE COMMISSION Date: / 1 I�8DMS F E B 2 21012 submit in u Ilcate y�� iv GINAL Form 10 -403 Revised 1/2010 p i -0441......0R • 1E-27 • DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert Kuparuk Well 1 E -27 from Oil Production service to WAG Injection service as the well has completed its pre - production period, post CTD operations which added multi - laterals L1, L1 -01, and L1 -02.. Well 1E-27 was completed as a Kuparuk Oil Pool A & C sand Water Injector on October 19, 1982. Oil production rates and bottom hole pressures have declined and warrant converting this well to a service injector. Conversion of well 1 E -27 to WAG Injection service will provide pressure support to offset producers 1 E -29, 1 E -05 and 1 E -06. The 16" Conductor was cemented with 272 sx AS II. The 10 -3/4" Surface casing (2218' and / 2218' tvd) was cemented with 1500 sx AS III, 250 sx AS I. The 7" Production casing (6715' and / 6564' tvd) was cemented with 635 sx Class 'G" & 250 sx AS I.. A State Witnessed MIT -IA was last performed on 06/24/10; MITIA 2720 psi, 30 minutes, Passed The injection tubing /casing annulus is isolated via OTIS Retrievable Packer located @ 5966' and / 5888' tvd. The injection tubing /casing annulus is isolated via OTIS Permanent Packer located @ 6221' and / 6120' tvd. The Top of the Kuparuk "C" Sand is 6122' and / 6032' tvd The Top of the Kuparuk "A" Sand is 6317' and / 6208' tvd 1 KUP 1E-27 ConocoPhillips o glen Attributes ax Angle & MD TD �, .. Wellbore APIAJWI Field Name Well Status Inol r) MD (517(13) Act Btm (RKB) lonomftellIps 500292083700 KUPARUK RIVER UNIT PROD 27.20 6,550.00 6,800.0 Comment 925 (ppm) Date Annotation End Date KB (R) Rig Release Date SSSV: TRDP Last WO: 12/30/1984 39.00 10/19/1982 Well Conap. DEVIATED - 1E -27 125201211'. 4009 AM Schematic - Actual Annotation Depth (R68) End Date Annotation Last Mod ... End Date Last Tag: SLM 6,362.0 7/30/2011 Rev Reason: PULL VALVE ninam 1/25/2012 HANGER 27 Casing Strings Casing Description String 0... String ID ... Top (lt(B) Set Depth (5... Set Depth (TVD) ... String Wt.. String ... String Top Thrd 7 r CONDUCTOR 16 15.060 32.0 85.0 85.0 65.00 H WELDED Casing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd l SURFACE 10 3/4 9.794 31.6 2,217.6 2,217.5 45.50 K - 55 BTC Casing Description String 0... String ID ... Top (RKB) Set Depth (5... Set Depth (TVD) ... String Wt... String ... String Top Thrd /� ' PRODUCTION 7 6.276 30.5 6,715.1 6,563.7 26.00 K -55 BTC Tubing Strings CONDUCTOR. Tubing Description String 0... String ID ... Top (BNB) Set Depth (5... Set Depth (TVD)... String Wt.. String ... String Top Thrd 32 - 85 TUBING 31/2 2.992 27.3 6,245.4 6,143.0 9.20 J -55 BTC -MOD C. SAFETY VLV o 1 Completion Details 1.674 C- Top Depth (TVD) Top Inc' Nom'... Top (RKB) (RKB) (1 Item Description Comment ID (01) 27.3 27.3 -0.43 HANGER FMC GEN III HANGER 3.500 SURFACE, ■ 1,874.3 1,874.2 1.06 SAFETY VLV CAMCO TRDP- 1A -ENC SAFETY VALVE 2.813 32 5,940.0 5,863.8 23.05 SBR OTIS SBR 2.813 :it 5,966.1 5,887.9 23.03 PACKER OTIS RRH RETRIEVABLE PACKER 2.970 GAS LIFT, 5,898 6,120.3 6,029.3 23.90 BLAST JTS CAMCO STEEL BLAST JOINTS 2.992 6,219.2 6,119.2 24.83 LOCATOR OTIS STRAIGHT SLOT LOCATOR 2.992 6,220.5 6,120.4 24.82 PACKER OTIS WD PERMANENT PACKER 4.000 SBR, 5,940 6, 223.9 6,123.4 24.80 ADAPTER OTIS PACKER ADAPTER 4.000 6,224.4 6,123.9 24.79 SBE OTIS SEAL BORE EXTENSION 2.970 PACKER, 5,966 ��. 6,238.7 6,136.9 24.69 NIPPLE CAMCO D NIPPLE NO GO, MILLED TO 2.80" 2.800 6,244.7 6,142.4 24.64 SOS OTIS SHEAR OUT SUB 3.950 INJECTION. # Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) 60 ' Top Depth (TVD) Top Inc' Top (1868) (R ( ") Description Comment Run Data ID (In) 6,288 6,181.6 25.29 WHIPSTOCK NON - RETRIEVABLE 8/31/2011 INJECTION L Perforations & Slots Shot Top (TVD) 8M (TVD) Dens Top (RKB) 8411 (RKB) (RKB) (RKB) Zone Dots (ah... Type Comment 6,122 6,167 6,030.9 6,071.9 C-4, C-3, 1E -27 10/18/1982 4.0 IPERF IPERF. 6,177 6,185 6,081.0 6,088.2 C-2, C-1, 1E -27 10/18/1982 4.0 IPERF 6.122 I IPERF, II 6,235 6,237 6,133.6 6,135.4 8/2/2011 6.0 IPERF 2" BH PERF GUN, 60 DEG .5185 6,1770.185 l 11 6,330 6,340 6,219.5 6,228.5 AS, 1E -27 10/18/1982 4.0 IPERF J 6,357 6,382 6,244.0 6,266.5 A -4, 1E -27 10/18/1982 4.0 IPERF IIIII 6,390 6,394 6,273.7 6,277.3 A -4, 1E -27 10/18/1982 4.0 IPERF INJECT 05 _ { Notes: General & Safety . 6 204 End Date Annotation 9/7/2010 NOTE: View Schematic w/ Alaska Schematic9.0 Cement Squsso, 6.215 LOCATOR, 8.219 il C PACKER, 8,220 ' _ r ADAPTER, 6,224 S8E.6,224 • U = � PE 237 8,256237 E NIPPLE, 6,239 1 ■ ■ SOS, 6245 e Ems WHIPSTOCK. 8,205 i IPERF. III 8,3308,310 340 IPERF, , 6,35 82 1PERF, -8 394 , 63908,391 P II RODUCTION, 308,715 \ TD(IE -27), ` Mandrel Details 6 Top Depth ' Top Port WHIPSTOCK, (TVD) Inc' OD Valve Latch Size TRO Run STS, _ Stn Top (RKB) ( si) ) (1 Make Model (In) Se Type Type (in) (p Run Oats Cont.. 8'7 SL 1 5,897.9 5,825.0 22.31 OTIS LBX 1 12 GAS LIFT OV RM 0.188 0.0 9/25/2011 LINER L1 -0 SLOTS. 6E L1- , 2 6,005.1 5,923.6 22.55 OTIS LBX 1 12 INJ DMY RM 0.000 0.0 7/312011 e 3 6,080.1 5,992.5 23.55 OTIS LBX 1 12 INJ ' DMY RM 0.000 0.0 8/5/1997 4 6,203.8 6,105.3 24.95 OTIS LBX 1 1/2 INJ DMY RM 0.000 0.0 8/5/1997 LINER L1-02, 8.901-9,601 /gl - 1E -27L1, L1 -02, and L1 -01 CTD ConocoPhillips SIDETRACK 3 Yz" Camco TRDP- 1A -ENC SSSV / � /J J� // sssv at 1,874' MDrkb l GLM # Type MD -RKB TVD -RKB Valve Type 1 Otis LBX 5,898 5,825 Dummy 2 Otis LBX 6,005 5,924 Dummy 3 Otis LBX 6,080 5,993 Dummy 4 Otis LBX 6,204 6,105 Dummy All 6 10 -3/4" 45.5# K -55 BTC casing Set @ 2,218' MD / 2,217' TVD Otis RRH Packer Set 5966' MD / 5,888' TVD U �� - C Sand Perfs: — 1 — yt OCT 7 n Isolated - e,726' 0� /ti N 1. ! 0 / 201 - � � Isolated between C packers Otis WD Packer Set 6,221' MD / 6,120' TVD ■ r, M/ 2-3/8" 4.7# L -80 liner top 6,215' MD / 6,115' TVD /j ° ' 3' /2" 9.3# L -80 IBTM SC tubing tail at 6,237 MD ' � r � 5 1E- 27L1 -02 l ' i 1E- 27L1 -01 iy�a� b s � ,� TD: 8,528' MD / 6,278' TVD TD: 9,603' MD / 6,253 TVD Top of window �A, g 6,288' MD / , 6,182' TVD j£' ,zi:.*wL t h. imii y ll.IIIIIIIIIIIIIII. .4 1 E -27L1 � i, TD: 9,310' MD / 6,324' TVD rs A Sand Perfs: C ` �� m %�- 7,704' - 7,726' C r ;......_ Anchored Billet Anchored Billet e ,n s - w.`t ; 6,26' / 6,293' / 6,2611 TVD TVD TVD 6,293' TVD Original Wellbore 7.0" 26.0# K -55 @ 6,715 MD / 6,563' TVD • STATE OF ALASKA ALASKA •AND GAS CONSERVATION COMMISS• REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Plug Perforations Stimulate I Other Cora "• t° 13°I"er Alter Casing r Pull Tubing r" Perforate New Pool r Waiver r Time Extension E < F1°wl34J Change Approved Program r- Operat. Shutdow n C'" Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: — ConocoPhillips Alaska, Inc. Development r Exploratory r _ , 182 - 163 3. Address: 6. API Number: Stratigraphic j Service 17/ P. O. Box 100360, Anchorage, Alaska 99510 , 50 - 029 - 20837 - • 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25651 ' , 1 E - 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 6800 feet Plugs (measured) None true vertical 6639 feet Junk (measured) None Effective Depth measured 6624 feet Packer (measured) 5966, 6220 true vertical 6483 feet (true vertucal) 5888, 6120 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 112 112 SURFACE 2186 10.75 2218 2218 RECEIVED' PRODUCTION 6685 7 6715 6564 OM 042011 Alaska Oil & Gas Cons. Commissior Perforation depth: Measured depth: 6122' - 6167', 6177'- 6185', 6235'- 6237', 6330'- 6340', 6357'- 6382', 6390' -6394' Anchorage True Vertical Depth: 6031'- 6072', 6081'- 6088', 6134'- 6135', 6220'- 6229', 6244'- 6267', 6274' -6277' Tubing (size, grade, MD, and TVD) 3.5, J - 55, 6245 MD, 6142 TVD Packers & SSSV (type, MD, and TVD) PACKER - OTIS RRH RETRIEVABLE PACKER @ 5966 MD and 5888 TVD PACKER - OTIS WD PERMANENT PACKER @ 6220 MD and 6120 TVD SSSV - CAMCO TRDP- 1A -ENC @ 1874 MD and 1874 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: see attached summary 12. 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 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development • - Service r Stratigraphic r 15. Well Status after work: - OiI p Gas r WDSPL r Daily Report of Well Operations XXX GSTOR (` WINJ r WAG r GINJ SUSP r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -228 Contact Mike Winfree Cad 265 -6820 Printed Name Mi e Wi free Title CTD Engineer Signature ."*"----___,_ Phone: 265 - 6820 Date /0/3 /a Form 10 -404 Revised 10/2010 RSDMS OCT 04 2011 ;' /C 1 /" // Submit Original Only '; (9/,1;7, l�; ,„ KU 1 E -27 Dil '? Well Attributes Max Angle & MD TD _ Aka ja me 'z 7 We1lDore APUUWI Fold Name Well Status Inc! ( °) IND (ftKS) Act Btm (HKB) csxr , np , Xt 500292083700 KUPARUK RIVER UNIT INJ 27 20 6,550 00 6,800.0 -- 'Comment 1612S (ppm) (Date Annotation I End Date KB - Grd (ft) Rig Release Date • SSSV. WOE I _ Last WO: 1 12/30/1984 39.00 10/19/1982 - _YP5l. 0008 0- t ,,, l e1(2411 : 433 .EMT - . _ 'Depth De th ' - S A�eHI_ p (ftK8) End Date 'Annotation Last Mod ...]End Date Last Tag: SLM 6,362.0 7/30/2011 Rev Reason Tag, GLV C /O, Perfs Mill Nip, Cmt Sqz nmam 8/11/2011 Casing Strings ' HANGER, 27 -- Vii' Casing Description String 0... String ID ... Top (kKB) Set Depth (I... Set Depth (TVD) . String Wt... !String ... String Top Thrd 2. CONDUCTOR 16 15.060 32.0 85.0 85.0 65.00 /1 WELDED " Casing Description String 0.. String ID ... Top (ftKB) Sat Depth (E.. Set Depth (TVD) ... String wl... String _. Siring Top Thrd ' SURFACE 10 3/4 9.794 31.6 _ 2,217 6 2,217.5 45.50 K 55 BTC _ C asing Description String 0... String ID .. Top (kKB) Set Depth (I... Set Depth (TVD) ... String WI... String ... [ String Top Thrd ' PRODUCTION _ 7 6.276 30 5 _ 6,715. 6 O 563.7 26.00 K -55 IC Tubing Description String 0... String ID ... Top (kKB) I Set Depth (1... I Set Depth (TVD) . String Wt... String ... String Top Thrd Tubing Strin s 4 z TUBING 31/2 2 - 992 27.3 6,245.4 6,143.0 9.20 J - 55 BTC - MOD CONDUCTOR. Completion Details 32 -85 Top Depth (TVD) Top tool Need... SAFETY VLV, Tep(NCB) (flKB) f) !lean Description _�.. __. _.._ Comment ID (in) 1.674 27.3 27.3 -0.43 HANGER FMC GEN III HANGER 3.500 II 1,874.3 1,874.2 1.06 SAFETY VLV CAMCO TRDP- 1A -ENC SAFETY VALVE 2.813 5,940.0 5,863.8 23.05 SBR OTIS SBR 2.813 5,966.1 5,887.9 23.03 PACKER OTIS RRH RETRIEVABLE PACKER 2.970 6,120.3 6,029.3 23.90 BLAST JTS CAMCO STEEL BLAST JOINTS - 2.992 SURFACE,____ 32 -2.218 6,2192 6,119.2 24.83 LOCATOR OTIS STRAIGHT SLOT LOCATOR 2.992 _ 6,220 5 6,120.4 24 82 PACKER OTIS WD PERMANENT PACKER 4.000 GAS LIFT. 6,223.9 6,123.4 24 80 ADAPTER OTIS PACKER ADAPTER 4.000 illt 5 . 89 e 6,224.4 6,123.9 24.79 SBE OTIS SEAL BORE EXTENSION 2.970 6,238.7 6,136.9 24.69 NIPPLE CAMCO D NIPPLE NO GO, MILLED TO 2.80•' 2.800 11 B244 6,142.4 24.64 SOS OTIS SHEAR OUT SUB 3.950 SBR, 5,940 - I Hl (reline retrievable plugs, a - othe r n oe - � etrievable PI 3 , vlves - .._Pumps fish, et Top Depth _ (TVD) Top Intl PACKER, 5, 968 - -- Tn_Q(fKB) (ftK8) (°) Inscription 1 Comment Run Date ID (in) -- = 6,239 6,136.9 24.69 VALVE SAFETY VALVE 7/30/2011 Perforations & Slots Shot INJECTION,_.._. Top (TVD) Btm (TVD) Dens 8.085 Top (kKB) Btrm (111(B) (flKB) (ftK8) Zone Date Intl- - - yp .. ... .. Comment 6,122 6,167 6,030.9 6,071.9 C-4, C -3, 1E -27 10/18/1982 4.0 IPERF 6,177 6,185 6,081.0 6,088.2 C -2, C -1, 1E -27 10/18/1982 4.0 IPERF - -- _ 6,235 6,237 6,133.6 6,135.4 8/2/2011 6.0 IPERF 2" BH PERF GUN, 60 DEG INJECTION, _ - 6,330 6,340 6,219.5 6,228.5 A - 5, 1E - 27 10/18/1982 4.0 IPERF 6.060 l . 6,357 6,382 6,244.0 6,266.5 A-4, 1E-27 10/18/1982 4.0 IPERF 6,390 6,394 6,273.7 6,277.3 A-4, 1E -27 10/18/1982 4.0 IPERF Notes: General & Safety''..,';-=',:-',: End Date I Annotatio IPERF . . -- 9/7/2010 I NOTE: View Schematic w/ Alaska SchemaUC9 0 I 6,122 -6,167 ail: LLL .. !PERF. V 8.177 -6.185 „_ INJECTION, 6,200 It i Cement Squeeze, 6,215 LOCATOR, 6,219 PACKER, 6,220 Yv ADAPTER 4 8,224 SBE, 6,224 - -- ( I O IPERF, li I _ 6,235. 6,237 - gg - NIPPLE,6,239� - . i ' VALVE, 6,239 -- T e I Mandrel Details Top Depth Top .t __.. Port sf (TVD) Inc! OD Valve Latch Size TRO Run Stn Top (,KBj_ (flKB) (') Make Model (in) Sery Type TIM. Ps) (Psi) Run Date Can... SOS, 6,245 G 131 �etD 1 5,897.9 5,825.0 22.31 OTIS LBX 1 12 GAS LIFT DMY RM 0.000 0.0 8/5/1997 . 2 6,005.1 5,923.6 22.55 OTIS LBX 1 12 INJ DMY RM 0.000 0.0 7/31/2011 3 6,080.1 5,992.5 23.55 OTIS LBX 1 12 INJ DMY RM 0.000 0.0 8/5/1997 li !PERF. .. - . __ - 8,330 - 6,340 - 4 6,203.8 6,105.3 24.95 OTIS LBX 1 12 INJ DMY RM 0.000 0.0 8/5/1997 ten .._., •A ( IPERF, - -.. ' - rn` n - j . / \ Set Q 'PM- -- r "- 6, 'P 39 - 6,394 PRODUCTION, - 30.6,715 N TD, 6,800 /0- CT0 S I 1��� y. K 1E-27 Pre and Post Rig Work Summary DATE SUMMARY 7130/11 DRIFT TBG W/ 5' X 2.5" BLR TO AP@ 6362' SLM, SET 2.75" SV IN D -NIP 39' RKB, PULL HFCV @ 6005' RKB, IN PROGRESS. 7/31/11 SET DV IN CSM @ 6005' RKB, ATTEMPT MITT, PULL 2.75" SV @ 6239' RKB, SET 2.75" CA -2 PLUG, PERFORM PASSING 2500 PSI MITT, PULL 2.75" CA -2 PLUG. * *C -SAND ISOLATED * *, IN PROGRESS. 8/1/11 MEASURE BHP @ 6354' RKB, GRADIENT @ 6243' RKB. READY FOR E -LINE. 8/2/11 RIG IN HOLE WITH 2" OD PERF GUN LOADED 6 SPF 60 DEG PHASE. LOADED 2' WITH 6.8 GM BH HMX CHARGES AND PERFORATE FROM DEPTH OF 6235' - 6237'. SHOTS IN THE MIDDLE OF THE 6' PUP JOINT ABOVE THE D NIPPLE AT 6239'. 8/5/11 RIH, MILL NIPPLE @ 6239' CTMD USING USED MILL THAT GAUGE'NOGO 2.79 ", MILLED FOR 9HRS DID NOT GET THROUGH NIPPLE, IN PROGRESS 8/6/11 RIH, MILL OUT D NIPPLE @ 6,239' RKB TO 2.80 ", RAN NEW MILL 5HRS, IN PROGRESS 8/7/11 RIH, SQUEEZE CEMENT, COULD NOT OBTIAN SQUEEZE PRESSURE, PUMPED AWAY, IN PROGRESS 8/8/11 RIH, PUMP 15BBL 17PPG NEAT CEMENT, SQUEEZE TO 500,600,750,1000 PSI, CLEAN OUT TO 6215' CTMD, POOH, READY FOR WIRE LINE 8/11/11 TAGGED CEMENT TOP @ 6231' SLM, EST. 6242' RKB. PRESSURE TEST TBG 2000 PSI, PASSED. COMPLETE. 8/13/11 PRE -CTD T -POT ( PASSED ), T -PPPOT ( PASSED), IC -POT ( PASSED ), IC -PPPOT ( PASSED ), , 0C- POT ( FAILED ), OC -PPPOT ( PASSED ), MIT - IA(PASSED), MIT -OA ( PASSED), PT- MV & WV PASSED), DD- MV & WV (PASSED ), PT- SSV ( PASSED), DD- SV (PASSED ), PT -SV ( PASSED), DD -SV ( PASSED ). • • ConocoPhillips Time Log & Summary We /View Web Reporting Report Well Name: 1E-27 Rig Name: NABORS CDR2 -AC Job Type: DRILLING SIDETRACK Rig Accept: 8/29/2011 12:00:00 PM Rig Release: 9/23/2011 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 38/28/2011 24 hr Summary Move rig from 3H to 1 E 06:00 00:00 18.00 MIRU MOVE MOB P Mob rig from 3H pad 08/29/2011 MIRU on 1E-27, rig accepted at 12:00 change skates on injector, pump slack, start testing BOP, State witnessing waived by Jeff Jones 00:00 06:00 6.00 MIRU MOVE MOB P Move rig from 3H to 1E 06:00 09:00 3.00 MIRU MOVE MOB P On location spot rig 09:00 12:00 3.00 MIRU WHDBO NUND P Nipple up and prepare for BOPE test 12:00 19:30 7.50 MIRU WHDBO RGRP P Injector maintenace ** *Nabors on Non - Billable time *** 19:30 23:00 3.50 MIRU WHDBO SLPC P Pump slack, cut 70' of pipe (57' to find wire) 23:00 00:00 1.00 MIRU WHDBO BOPE P Test BOP to 4000 PSI, state witness waived by Jeff Jones 38/30/2011 Complete BOP Test, Head up E -Coil, Run Cement pilot hole BHA, Tie in for +4', Tag TOC @6236'. Mill Cement 00:00 10:00 10.00 0 0 MIRU WHDBO BOPE P Continue testing BOP 250 low 4000 high. Lower Blind /Shear failed Replaced both upper & lower blind rams. Re- tested - passed. C -9 & C -10 failed - re- tested. 10:00 12:00 2.00 0 0 SURPRI WELLPF SLPC P MU CTC, Pull test 35K, M/U Quick connect.Pressure test TT line. 12:00 14:00 2.00 0 0 SURPRI WELLPF MPSP P Rig Up FMC & pressure test to 2000 psi. Pull BPV. 150 psi on well. Bled down to zero. Shut in a static test for 10 minutes, zero PSI on well. 14:00 14:30 0.50 0 0 PROD1 WHPST SLPC P Pressure test CTC to 4000 psi. 14:30 15:30 1.00 0 0 PROD1 WHPST SFTY P Pre -spud meeting with Maddy Crew. 15:30 16:30 1.00 0 0 PROD1 WHPST PULD P PJSM - P/U cement milling BHA for Run #1 with 2.81 go, 2.80" no go D331 bit with 0.6 AKO motor assembly. 16:30 18:36 2.10 0 6,045 PROD1 WHPST TRIP P IA = 300 / OA = 29. Check SSSV - RIH with EDC closed pumping SW .5 bpm taking returns to the tiger tank. 18:36 18:48 0.20 6,045 6,082 PROD1 WHPST DLOG P Log Gamma tie in for a +4' correction, Start swap to Biozan 18:48 19:12 0.40 6,082 6,236 PROD1 WHPST TRIP P RIH to mill cement i Page 1 of 20 • • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:12 19:54 0.70 6,236 6,245 PROD1 WHPST MILL P Tag TOC @ .25 BBIs /Min, Pick up and bring rate to 1.44 BPM@ 2330 PSI FS, TF= 20ROHS 19:54 20:06 0.20 6,245 6,246 PROD1 WHPST MILL P Bleed IA from 1000 psi to 350 PSI, OA from 620psi to 300psi Milling ahead 10 -15 FPH 20:06 00:00 3.90 6,246 6,304 PROD1 WHPST MILL P Mill Cement pilot hole, TF= 20ROHS, 1.44 BPM @ 2330 PSI FS Midnight depth 6304, ROP =--15 FPH D8/31/2011 Complete Cement pilot hole to 6315', Run Dummy to 6300', set whipstock 6285 TOWS, P/U Window mill and start milling window 00:00 00:45 0.75 6,304 6,315 PROD1 WHPST MILL P Milling Cement pilot hole 00:45 01:15 0.50 6,315 6,230 PROD1 WHPST REAM P P/U and ream pilot hole before drift, PUW=41K, 1.32 BPM @ 2336 PSI 01:15 01:30 0.25 6,230 6,315 PROD1 WHPST REAM P Dry Drift hole, saw light stacking in transition area, clean below that area to TD 01:30 02:30 1.00 6,315 6,220 PROD1 WHPST REAM P PUH and Ream Transition area 6220 to 6265 02:30 03:30 1.00 6,220 6,220 PROD1 WHPST REAM P Dry drift after 2 up and 1 down pass, still seeing a bobble on DHWOB. Rotate TF to 180 03:30 04:15 0.75 6,220 6,220 PROD1 WHPST REAM P Ream 2 down and 2 up passes @ 180 degree TF 6620 to 6680 1.37 BPM @ 2320 PSI FS. No Motor work at this TF 04:15 04:30 0.25 6,220 6,280 PROD1 WHPST REAM P Dry drift 6210 to 6285, Looks good still have bobble @ 6250' 700 lbs on DHWOB, PUH for no flow 04:30 04:45 0.25 6,280 6,280 PROD1 WHPST CIRC P 6217', Perform no flow test, good test, Open EDC and trip out PUW =40K 04:45 06:45 2.00 6,280 71 PROD1 WHPST TRIP P POOH 06:45 08:15 1.50 71 71 PROD1 WHPST PULD P PJSM - no flow check. Lay down BHA & P/U Dummy WS BHA 08:15 08:45 0.50 71 71 PROD1 WHPST COND P Take on old flo -pro fluid & remove Bio -zan 08:45 10:45 2.00 71 6,072 PROD1 RPEQP1TRIP P RIH with Dummy WS - EDC closed pumping flo -pro @ .3 bpm. Started seeing weight swings from 4000' down.P /U weight check 33 - 39K weight swings. RIH 10:45 11:15 0.50 6,072 6,300 PROD1 RPEQP1 DISP P Tie in & increase pump rate to 1.4 bpm to circ out Bio fluid. +3 ft correction. RIH to 6300'. Clean drift. Circ out Bio -zan. 11:15 13:15 2.00 6,300 71 PROD1 RPEQPITRIP P POOH - P/U weight 40K. Weight swings not as noticable with flo -pro. 13:15 14:15 1.00 71 71 PROD1 RPEQPI PULD P PJSM - Lay down Dummy WS & P/U WS with 2 pip tags. 14:15 16:15 2.00 71 6,295 PROD1 WHPST TRIP P RIH pumping .3 bpm through EDC. kp4/ 6050' - Tie in +3ft correction. RIH �IUt slowly to 6300' - P/U weight 34K to setting depth of TOWS 6285', BOWS 6294.84'. High side. Page 2 of 20 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:15 16:30 0.25 6,285 6,285 PROD1 WHPST WPST P Stop pumping , WOB zero - close EDC. Bring up pump, WS set @ 3600psi. WOB increase to 2K. Set down 3K. - good indication of set. P/U weight 38K dry - 33K wet. 16:30 18:06 1.60 6,285 79 PROD1 WHPST TRIP P POOH for milling BHA 18:06 19:21 1.25 79 0 PROD1 WHPST PULD P Lay down BHA #3 Whipstock setting run 19:21 20:00 0.65 0 0 PROD1 WHPST PRTS P Rig up PDL to Pressure test 3K 20:00 20:30 0.50 0 73 PROD1 WHPST PULD P P/U BHA #4, Window milling BHA with .6 degree motor, Dimond string mill and window mill 20:30 21:06 0.60 73 73 PROD1 WHPST SFTY P Pre spud meeting with Corder's crew 21:06 22:48 1.70 73 6,070 PROD1 WHPST TRIP P Tag up, set counters, trip in well with BHA #4, EDC shut 22:48 22:54 0.10 6,070 6,092 PROD1 WHPST DLOG P Log Gamma tie in for a +3' correction 22:54 23:36 0.70 6,092 6,288 PROD1 WHPST TRIP P Trip in well, stacked out @ 6240, Pick up and inspect injector. PUW= 45K Everything looks good. RIH and dry tag TOWS @ 6288, 23:36 00:00 0.40 6,288 6,288 PROD1 WHPST MILL P Pick up and bring pumps online, 1.5 BPM @ 3700 PSI FS, wash down to whipstock, call pinch point 6287.6. Start time milling per procedure, Midnight 6288.1 39/01/2011 ` Complete window and rat hole, Trip out. Cut 1400' for fatigue mgmt. Investigate injector noise. Head up E -Line ti/ 00:00 04:00 4.00 6,288 6,291 PROD1 WHPST MILL P Continue time milling window, 1.5 .,- BPM @ 3700 PSI FS, stalled @ 5'k` 6288.6, PUW =37K Q 04:00 06:30 2.50 6,291 6,293 PROD1 WHPST MILL P Milled 3.2' go to auto drill 1 FPH, 1.5 r✓` BPM © 3600 FS, Bleed down IA and OA LI- 06:30 10:30 4.00 6,293 6,308 PROD1 WHPST MILL P Increase ROP to 2 fph - both mill & string mill exit out the window. Increase to 5 fph from 6296'.Keeping WOB below 2K. 10:30 11:30 1.00 6,308 6,308 PROD1 WHPST REAM P Backreaming passes. P/U weight off bottom 37K. Make two passes - clean no motor work detected. Dry drift with WH trapped, no leak off. Clean drift at 8 fpm. P/U weight 40K. Clean up pass. TOW = 6287.5 BOW = 6293.5 11:30 13:30 2.00 6,308 200 PROD1 WHPST TRIP P POOH following MPD. Open EDC. Jet across SSSV a couple of times. 13:30 14:00 0.50 200 71 PROD1 WHPST RGRP T Injector making new vibration noises close to surface. Stop and inspect and troubleshoot. POOH to surface. 14:00 15:30 1.50 71 0 PROD1 WHPST PULD P PJSM - undeploy BHA. Mechanic inspected both drive shafts with no indications of fatigue. Page 3 of 20 Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) i V30 Sent: Tuesday, September 27, 2011 8:10 AM To: 'CPF1 Prod Engr' a t l - O c \. Co Cc: NSK Prod Engr & Optimization Supv; Schwartz, Guy L (DOA); Davies, Stephen F (DOA) Subject: RE: 1E-27 (PTD 182 -163) Daniel, checked our records and 1 E -27 is still listed as a service well, lwinj and I do not find that any completion reports (Form 407) for the new laterals have been filed. A 404 should be submitted changing 1E-27 to development, 1 -oil and 407s should be submitted for the new laterals also showing development, 1 -oil. When was drilling completed on the new laterals? For a production well or well + laterals, I am not aware that the paperwork needs to be submitted prior to placing the well(s) in operation although new completion reports are due within 30 days of well completion which in this case would be likely when CDR2AC was released. You are correct that when the well is changed from production (pre - produced) to injection that the 403s (4 of them in this case) must be filed. Those documents need to be approved PRIOR to initiating injection into the well(s). Call or message with any questions. Please reply all with any messages. Tom Maunder, PE AOGCC From: CPF1 Prod Engr [mailto:n1269 @conocophillips.com] Sent: Tuesday, September 27, 2011 6:24 AM To Schwartz, Guy L (DOA) , _ ? . # £ Z O Cc: Maunder, Thomas E (DOA); NSK Prod Engr & Optimization Supv Subject: 1E -27 (PTD 182 -163) Guy, ConocoPhillips requests confirmation that all required documentation is in place to bring newly CTD sidetracked well 1E -27 (PTD 182 -163) on production as a pre - produced injector. The well will be pre produced for 1 -3 months then swapped over to an injection well after the appropriate 10 -403 documentation has been filed. Please advise, thanks. Daniel Bearden /David Lagerlef CPF1 Production Engineers n1269@conocophillips.com 907 -659 -7493 pager 907 -659 -7000 #765 9/27/2011 • IOC/ WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 22, 2011 Attn.: Howard Okland .. 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 5LA4 E MAC .1 ,4 L J12 RE: Perforation Record: 1E -27 Run Date: 8/2/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1E -27 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 20837 -00 I I PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: 12 �` Signed: 441/4, oar • • • STATE SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Mike A. Winfree CTD Engineer pp� ConocoPhillips Alaska, Inc. q �'- 1 123 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1E-27 Sundry Number: 311 -228 Dear Mr. Winfree: .1,H_ j ; ., ., .JUL 2 9 2O1 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. Si, cerely, l ilt Da Seamount, . . p Cha DATED this i ( day of July, 2011. Encl. • • Conoco Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 I? ° „ ; 1 .,r. , : July 21, 2011 Commissioner - State of Alaska a . , Alaska Oil & Gas Conservation Commission { "' "`` " ° 333 West 7th Avenue Suite 100 Alit:OtitagG Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an application for sundry approval to plug Kuparuk A sand perforations in preparation for two coiled tubing drilling (CTD) laterals out of Kuparuk well 1 E- 27 182 -163) using the Nabors CDR2 -AC coiled tubing drilling rig. Pre -rig work is expected to begin August 1 . Attached to this application are the following documents that explain the proposed pre -rig operations: - Form 10-403 Application for Sundry Approvals - Current 1 E -27 Wellbore Schematic - Summary of Operations If you have any questions or require additional information please contact me at my office 907 - 265 -6820. Sincere , Mike A. Win ee ConocoPhillips Alaska Coiled Tubing Drilling Engineer err Pie tlf.*A 'fee SJO r ,. Or* CO. T� �vv i Tit w� r' iloc Q./ cross o tilt(' A'0 f �(x /l- f e b."? fV 9 Wr 1 p� %mil c�c f rr� s ov�q ( bt agseod ! �a;r ' "1,04 N o 4 a P t 0/94.-/... .-4 . - c ' s.4 No i i3P /e- - Ltn - s ca. e . � j3 A 74/JD Pet f • • KRU 1 E -27 Application for Sundry Approval Summary of Operations: ¶ C SAND > secrier Well 1E -27 is a Kuparuk A- sand well equipped with 3 tubi and production casing. Two proposed A -sand CTD laterals will increase reservoir exposure and support future CTD producers 1E -05 and 1E -24A. Prior to drilling, the existing A -Sand perfs in 1E -27 will be squeezed with cement to provide a means to kick out of the 7" casing. 'e ' sA o r3E LOP T cWit!. ?do 7.21 .if After plugging off the existing perfs with cement, a pilot hole will be drilled through the cement to 6,285' MD and a mechanical whipstock will be placed in the pilot hole at the planned kickoff point. The 1E -27L1 sidetrack will exit the 7" casing at 6,285' MD and will target the A4 sand east of the existing well with a 3,315' lateral. The hole will be completed with a 2%" slotted liner from the TD of 9,600' MD with an anchored aluminum billet at 7,100' MD. The 1E-27L1-01 lateral will kick off from the aluminum billet at 7,100' MD and will target the A5 sand east of the existing well with a 2,350' lateral. The hole will be completed with a 2W slotted liner from the TD of 9,450' MD with the final liner top located just inside the 31/2" tubing at 6,240' MD. CTD Drill and Complete 1E -27 Laterals: Sedtember 2011 Pre -CTD Work 1. Positive pressure and drawdown tests on master valve & swab valve 2. RU slickline. Obtain updated static BHP on A -sand. Dummy off all GLMs. RD slickline. ✓ 3. RU e -line. Perf holes in 3 '/2" tubing tail at 6,230' MD. RD e-line. ✓ 4. RU coil. Mill out XN- nipple in tubing tail to 2.80" ID. Plug the A -sand perfs with cement up to 6,230' MD. RD coil. 5. RU slickline. Tag top of cement. RD slickline. 6. Prep site for Nabors CDR2 -AC, including setting BPV Rig Work 1. MIRU Nabors CDR2 -AC rig using 2" coil tubing. NU 7- 1/16" BOPE, test. 2. 1E -27L1 Sidetrack (A4 sand, east) Pk) ,a. Drill 2.80" high -side, pilot hole through cement to 6,315' MD. Frl, 1 ,b. Drift pilot hole with whipstock dummy ✓c. Set whipstock at 6,285' MD with high -side orientation. d. Mill 2.80" window with high -side orientation at 6,285' MD. r s The following operations will be covered in the new PTD. The operations are only listed here for convenience. e. Drill 2.70" x 3" bi- center lateral to TD of 9,600' MD f. Run 2%" slotted liner with an aluminum billet from TD up to 7,100' MD 3. 1E-27L1-01 Lateral (A5 sand, east) a. Kick off of the aluminum billet at 7,100' MD b. Drill 2.70" x 3" bi- center lateral to TD of 9,450' MD c. Run 2 slotted liner from TD up to 6,240' MD, up inside the 3 tubing tail 4. Freeze protect. Set BPV, ND BOPE. RDMO Nabors CRD2 -AC. Post -Rig Work 1. Pull BPV 2. Obtain static BHP 3. Put well on production Page 2 of 2 July 21., 2011 • Opl- STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION il? ; i - ; ! r ,., . ti. ' ' r id iiffillSS1Q(t APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ; ° " 1. Type of Request: Abandon ❑ Plug for Redrill ' Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations In 1 .3- Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc Development ❑ Exploratory ❑ 182 -163 • 3. Address: Stratigraphic ❑ Service Q 6. API Number: P.O. Box 100360, Anchorage, Alaska 99510 50 -029- 20837 -00 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No in 1E -27 , 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25651 ALK 469 Kuparuk River Field / Kuparuk River Oil Pool 11 PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 6800 • 6639 • Casing Length Size MD TVD Burst Collapse Structural Conductor 85 16 112 85 Surface 2186 10-3/4 2218 2218 3580 psi 2090 psi Intermediate Production 6685 7 6715 6564 4980 psi 4320 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): ( 6122 - 6167)(6177- 6185)(6330 - 6340)(6357- 6382)(6390 -6394) (6031- 6072)( 6081 - 6089)( 6220 - 6229)(6244 - 6267)(6274 -6277) 3 -1/2 J-55 6245 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Otis RRH PKR, Otis WD PKR, Camco TRDP -1AE RRH (5,956' MD 1 5,888' TVD), WD (6220' MD,6120' TVD), SSSV (1874' MD, 1874' TVD) 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service 0 14. Estimated Date for 15. Well Status after proposed work: 74 7t.8.4 8/1/2011 Commencing Operations: Oil Gas ❑ WDSPL ❑ Suspended L 16. Verbal Approval: Date: WINJ rE GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mike A. Winfree Printed Name ke A. Winfree Title CTD Engineer Signature --,......_ Phone 265 -6820 Date 7/21/2011 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ✓ z ' - .9a% Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: / U — 0 � 7/ / APPROVED BY Approved by: 'j COMMI +NER THE COMMISSION Date: 7- z7 --f/ ....„., 'p -:kk s : ['mS JUL '' 0 . GIN AL -7' S in Du lcate. v Form 10 -403 Revised 1/2010 . P i KUP 1E-27 Conoco Phillips f , Attributes Max Angle & MD TD +.. Alaska. `W. Wellbore API /UWI Field Name Well Status Inc! ( °) MD (ttKB) Act Btm (RKB) cn,Yx,, �Y 500292083700 KUPARUK RIVER UNIT INJ 27.20 6,550.00 6,800.0 Comment H2S (ppm) Data Annotation End Date KB -Grd (ft) Rig Release Date ... Well cann9: - E - 27, 4/202011 1.21'07 PM SSSV: TRDP Last WO: 12/30/1984 39.00 10/19/1982 Schematic - Actual Annotation Depth (RKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 6,362.0 12/9/2010 Rev Reason: Pull Plug/Gauges, GLV C/O Imosbor 4/20/2011 Casing Strings HANGER, 27 Casin Description strip 0... String ID ... Top ftK6 Set Depth Set Depth ND String Wt... String String Top . i 9 P 9 9 P( 1 M f (..- pt (TVD) 9 g.- 9 Thrd CONDUCTOR 16 15.060 32.0 85.0 85.0 65.00 H - 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd / 'f ' SURFACE 103/4 9.794 31.6 2,217.6 2,217.5 45.50 K - 55 BTC Casing Description String 0... String ID ._ Top (RKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd ' PRODUCTION 7 6.151 30.5 6,715.1 6,563.8 26.00 K -55 BTC Tubing Strings i III Tubing Description String 0... String ID ... Top (RKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd TUBING I 31/2 I 2.992 I 27.3 I 6,245.4 I 6,143.2 I 9.20 I J -55 I BTC -MOD Completion Details CONDUCTOR, Top Depth 32-85 (TVD) Top Incl Noml... Top (ttKB) (RKB) ( °) Rem Description Comment ID (In) SAFETY VLV. ! 27.3 27.3 0.09 HANGER FMC GEN III HANGER 3.500 1.074 - 1,874.3 1,874.2 0.66 SAFETY VLV CAMCO TRDP- 1A -ENC SAFETY VALVE 2.813 5,940.0 5,864.2 23.06 SBR OTIS SBR 2.813 5,966.1 5,888.2 23.11 PACKER OTIS RRH RETRIEVABLE PACKER 2.970 6,120.3 6,029.6 24.03 BLAST JTS CAMCO STEEL BLAST JOINTS 2.992 6,219.2 6,119.4 24.99 LOCATOR OTIS STRAIGHT SLOT LOCATOR 2.992 SURFACE, 6,220.5 6,120.6 25.00 PACKER OTIS WD PERMANENT PACKER 4.000 32 - 2,218 ( 6,223.9 6,.6 4.000 6,224.4 6,124 25.02 25.02 ADAPTER SBE OTIS PACKER ADAPTER OTIS SEAL BORE EXTENSION CAMCO D NIPPLE NO GO 2.970 2.750 GAS LIFT, 6,238.7 6,137.1 25.09 NIPPLE 5,898 6,244.7 6,142.6 25.13 SOS OTIS SHEAR OUT SUB 3.950 Perforations & Slots Shot SBR ,594G Li Top Bt(f(ND) Dens Top (RKB) Btm (RKB) (RKB) (RKB) Zone Date (sh -. Type Comment 6,122.0 6,167.0 6,031.2 6,072.2 C-4, C -3, 1E -27 10/18/1982 4.0 IPERF .. PACKER, 5,966 6,177.0 6,185.0 6,081.3 6,088.6 C-2, C-1, 1E-27 10/18/1982 4.0 IPERF ` 6,330.0 6,340.0 6,219.7 6,228.7'A -5, 1E -27 10/18/1982 4.0 IPERF 6,357.0 6,382.0 6,244.0 6,266.6 A-4, 1E -27 10/18/1982 4.0 IPERF U 6,390.0 6,394.0 6,273.8 6,277.4 A-4, 1E -27 10/18/1982 4.0 IPERF INJECTION, _ ! Bo os Notes: General & Safety End Date Annotation I I I 9/7/2010 1 NOTE: View Schematic w/ Alaska Schematic9.0 INJECTION, M O 6,080 .9_ c, sA A.)0 IPERF, 6.122 -6.167 1 -- IPERF. 8,1776,185 INJECTION, I C 6,204 -- LOCATOR. 8,219 PACKER. 6.220 - ADAPTER, 6,224 SBE. 8,224 - _ NIPPLE. 8,239 - -- 1_ Mandrel Details Top Depth Top Port (ND) Inc, OD Valve Latch Size TRO Run 1 Stn Top (RKB) (RKB) (1 Make Model (in) Sery Type Type (in) (psi) Run Date Com... 305. 6,24s 71 Stn 5,897.9 5,825.4 22.98 OTIS LBX 1 1/2 GAS LIFT DMY RM 0.000 0.0 8/5/1997 2 6,005.1 5,923.5 22.62 OTIS LBX 1 12 INJ HFCV RM 0.000 0.0 4/19/2001 IPERF, 3 6,080.1 5,992.9 23.54 OTIS LBX 1 12 INJ DMY RM 0.000 0.0 8/5/1997 8,3306,340 4 6,203.8 6,105.4 24.91 OTIS LBX 1 12 INJ DMY RM 0.000 0.0 8/5/1997 IPERF, 6,3576,382 1 - S Jtu o PERF, _ L 8.3906,394 � \ PRODUCTION. O, 0 ,715 TD. 0,600 Page l of l Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. if the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. file: //F: \Daily_Document Record \Procedures_Instructions \FW INTENT PLUG for RE -D... 6/29/2011 • WELL LOG r TRANSMITTAL PROAcriVE DiACINOSTIC SERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659 -5102 RE : Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 4 Y 2011 use 059 -163 3 0 .13 6 1) Caliper Report 26- Mar-11 1 E -27 1 Report / EDE 50-029 - 20837 -00 2) RECEW Signed : , Date : APR 1 9 2011 Print Name: & c .; Cons. C'>rnrrtis on PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAX: (907)245 -88952 C:\Documents and Settings\Diane Williams \Desktop \CPAI_Transmitdocx 1 • • 1 3 Memory Multi- Finger Caliper Log Results Summary 1 C ompany: ConocoPhillips Alaska, Inc. Well: 1E -27 Log Date: March 26, 2011 Field: Kuparuk I Log No.: Run No.: 10258426 ZX70 State: Alaska 1 API No.: 50- 029 - 20837 -00 Pipet Desc.: 3.5" 9.2 Ib. J -55 BTC-MOD Top Log Intvll.: Surface Pipet Use: Tubing Bot. Log Intvll.: 6,245 Ft. (MD) 1 Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS : 1 This caliper data is correlated to Tubing Tally Record This log was run to assess the condition of the tubing with respect to corrosive and mechanical damage. I The caliper recordings indicate the 3.5" tubing logged appears to be in good to fair condition, with a maximum wall penetration of 37% in a line corrosion pup joint 198.1 (6,244'). Wall penetrations ranging from 1 20% to 40% are recorded in 27 joints of 211 joints analyzed. Recorded damage appears as shallow line of pits, line of pits and line corrosion. Cross - sectional wall loss of 15% is recorded in area of line corrosion pup joint 197.2 (6,215'). No significant restrictions are recorded throughout the tubing. 1 This summary report is an interpretation of data provided by Halliburton Well Services. MAXIMUM RECORDED WALL PENETRATIONS: I Line Corrosion ( 37 %) Jt. 198.1 @ 6,245 Ft. (MD) Line Corrosion ( 34 %) Jt. 154 @ 4,755 Ft. (MD) I Line Corrosion ( 33%) Jt. 197.2 @ 6,215 Ft. (MD) Line of Pits ( 32%) Jt. 196 @ 6,093 Ft. (MD) Line Corrosion (30 %} Jt. 175 @ 5,400 Ft. (MD) I MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS: Line Corrosion ( 15 %) Jt. 197.2 @ 6,215 Ft. (MD) I No other significant cross - sectional wall loss are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS: 1 No significant I.D. restrictions are recorded throughout the tubing logged. 1 1 Field Engineer: D. Schwarzenberger Analyst: C. Lucasan Witness: B. Boehme I ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (231) 565 -1369 E -mail: PDS @memorylog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 1 1 v - "C ( - 20930 I • • Correlation of Recorded Damage to Borehole Profile I • Pipe 1 3.5 in (32.3' - 6244.7') Well: 1 E -27 Field: Kuparuk I Company: Country: ConocoPhillips Alaska, Inc. USA Survey Date: March 26, 2011 I I . Approx. Tool Deviation ■ Approx. Borehole Profile 1 36 1 25 -1 1 50 1548 I 75 2327 I I 100 3097 IT s I c 125 — 3858 a I 150 _ 4615 _N.. 175 -..` 5372 I GCNT 3 _ 1 M GLM 4 MINI I 198.2 6245 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) i I Bottom of Survey = 198.2 I I • • I PDS Report Overview ti s . Body Region Analysis I Well: 1E-27 Survey Date: March 26, 2011 Field: Kuparuk Tool Type: UW MFC 24 No. (HAL) Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 I Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.2 ppf J -55 BTC -MOD Analyst: C. Lucasan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. I 3.5 ins 9.2 ppf J -55 BTC -MOD 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration(% wall) Damage Profile (% wall) 200 ∎ Penetration body w Metal loss body 0 0 50 100 ' 150 = wiz 100 - 50 0 50 1 0 to 20 to 40 to over 20% 40% 85% 85% Number of joints analysed (total = 211) I 184 27 0 0 100 I Damage Configuration ( body )= 150 = 1 100 = 150 =M 50 _ � O ' Isolated General Line Other Hole/ _= Pitting Corrosion Corrosion Damage Pos. Hole ��� _ii 196 Ai GEM 4 I Number of joints damaged (total = 112) 103 0 9 0 0 Bottom of Survey = 198.2 1 I I I i • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.2 ppf J -55 BTC -MOD Well: 1 E -27 Body Wall: 0.254 in Field: Kuparuk U Upset Wall: 0.254 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in USA Survey Date: March 26, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 0.1 32 0 0.02 8 1 2.97 Pup 1 36 0 0.03 11 3 2.92 Lt. Deposits. C 2 67 0 0.03 13 2 2.94 Shallow Pitting. • 3 97 0 0.03 11 2 2.96 • 4 129 0 0.04 16 3 2.91 Shallow Line of Pits. Lt. Deposits. r I 5 158 0 0.02 9 2 2.93 • 6 187 0 0.03 13 2 2.95 Shallow Pitting. • • 7 218 0 0.03 12 3 2.95 Shallow Pitting. 8 249 0.03 0.04 16 3 2.91 Shallow Pitting. Lt. Deposits. C I 9 278 0 0.02 8 3 2.94 10 310 0 0.02 9 2 2.94 • 11 341 0 0.03 11 2 2.94 • 12 371 0 0.04 16 3 2.97 Shallow Pitting. 13 401 0 0.03 13 3 2.94 Shallow Line of Pits. C 14 433 0 0.03 11 3 2.91 Lt. Deposits. 15 464 0 0.03 13 3 2.96 Shallow Pitting. Au 16 495 0 0.03 10 2 2.96 1. 17 527 0 0.03 11 2 2.96 • 18 558 0 0.02 9 2 2.94 • U 19 589 0 0.02 7 2 2.96 20 619 0 0.02 8 2 2.95 • 21 650 0 0.02 9 2 2.95 • I 22 681 0 0.02 8 2 2.94 23 712 0 0.03 10 3 2.94 • 24 743 0 0.02 7 2 2.95 25 775 0.03 0.03 13 2 2.96 Shallow Pitting. iti 26 807 0 0.02 9 2 2.97 • 27 837 0 0.02 8 2 2.95 • U 28 868 0 0.02 9 2 2.95 • 29 899 0 0.02 8 2 2.96 • I 30 928 0 0.03 10 2 2.95 31 960 0 0.03 10 ; 2.94 C 32 991 0 0.03 10 2 2.94 • 33 1023 0.03 0.03 13 3 2.90 Shallow Pitting. Lt. Deposits. C 34 1053 0 0.03 10 2 2.95 I 35 1083 36 1114 0 0.03 13 2 2.98 Shallow Pitting. VI 0 0.03 10 2 2.95 • 37 1145 0 0.03 13 2 2.94 Shallow Line of Pits. MI 38 1177 0 0.03 12 2 2.94 • I 39 1209 0.04 0.04 14 2 2.96 Shallow Pitting. 40 1238 0.05 0.05 19 2 2.95 Shallow Line of Pits. I 41 1268 0 0.02 6 2 2.96 42 1299 0 0.03 12 3 2.96 C I 43 1330 0 0.03 10 2 2.95 44 1362 0 0.04 14 2 2.96 Shallow Pitting. MI 45 1393 0 0.02 9 2 2.96 • 46 1422 0 0.02 8 3 2.97 • 47 1454 0 0.04 15 2 2.95 Shallow Line of Pits. IIII I 48 1485 0 0.03 12 2 2.97 U 49 1516 0.04 0.04 17 3 2.95 Shallow Pitting. rat I Metal Loss ion Body I Page 1 Penet I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.2 ppf J -55 BTC -MOD Well: 1 E -27 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in USA Survey Date: March 26, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % I oss I.D. Comments (% wall) (Ins.) (Ins.) °,0 (Ins.) 0 50 100 I 50 1548 0 0.02 9 2 2.96 • 51 1577 0.01 0.04 15 3 2.96 Shallow Pitting. • ■ 52 1608 0.01 0.03 12 3 2.94 Shallow Pitting. • 53 1639 0 0.03 12 3 2.95 Shallow Line of Pits. 54 1670 0 0.02 8 2 2.94 I 55 1701 0 0.03 10 2 2.94 • 56 1732 0 0.03 11 2 2.95 ■ 57 1763 0 0.03 13 2 2.96 Shallow Pitting. • 58 1795 0 0.03 12 2 2.96 Shallow Pitting. • I 59 1825 0 0.03 10 2 2.95 60 1856 0 0.02 7 2 2.94 60.1 1885 0 0 0 0 2.81 Camco TRDP -1 A -ENC SSV 61 1898 0 0.03 11 2 2.96 • I 62 1929 0 0.03 10 3 2.93 Lt. Deposits. • 63 1959 0 0.02 9 3 2.92 Lt. Deposits. • ■ 64 1989 0 0.03 10 2 2.95 • 65 2020 0 0.02 9 2 2.89 Lt. Deposits. ■ I 66 2051 () 0.03 13 2 2.96 Shallow Pitting. • 67 2083 0 0.03 11 2 2.94 68 2112 () 0.02 8 2 2.96 7 69 2143 O 0.02 9 2 2.92 Lt. Deposits. • 70 2174 0 0.03 12 2 2.91 Lt. Deposits. ■ I 71 2204 0 0.03 12 2 2.95 • 72 2234 0 0.02 9 3 2.96 ■ 73 2265 0 0.03 10 2 2.94 ■ 74 2296 0 0.02 9 2 2.95 ■ 75 2327 0 0.03 13 3 2.95 Shallow Pitting. • I' 76 2358 0 0.03 10 2 2.94 • 77 2389 0 0.03 10 2 2.94 • 78 2420 0 0.03 11 1 2.94 • I 79 2449 0.04 0.04 15 2 2.94 Shallow Line of Pits. • 80 2479 0.03 0.04 15 2 2.94 Shallow Line of Pits. ■ 81 2510 0 0.04 17 3 2.95 Shallow Line of Pits. ■ 82 2540 0 0.03 11 2 2.95 w 83 2571 0 0.02 8 2 2.94 J I 84 2602 0 0.02 9 2 2.91 Lt. Deposits. • 85 2632 0 0.04 17 4 2.92 Shallow Line of Pits. Lt. Deposits. ■ 86 2663 0 0.03 11 3 2.94 • 87 2694 0 0.04 15 1 2.98 Shallow Line of Pits. • I 88 2726 0 0.03 12 2 2.91 Shallow Pitting. Lt. Deposits. • 89 2756 0 0.03 11 2 2.93 Lt. Deposits. ■ 90 2787 0 0.04 15 3 2.93 Shallow Line of Pits. Lt. Deposits. • 91 2818 0 0.03 11 1 2.94 ■ I 92 2849 0 0.04 15 2 2.93 Shallow Line of Pits. Lt. Deposits. • 93 2879 0 0.03 12 2 2.94 94 2910 0 0.02 9 2 2.93 Lt. Deposits. 95 2940 0 0.04 17 4 2.94 Shallow Line of Pits. • I 96 2972 0 0.03 10 2 2.95 • 97 3004 0 0.04 16 3 2.93 Shallow Line of Pits. Lt. Deposits. • ■ 98 3035 0 0.03 10 2 2.93 Lt. Deposits. Prat Body I Meta enet l Loss ion Body Page 2 I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.2 ppf J -55 BTC -MOD Well: 1 E -27 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in USA Survey Date: March 26, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 99 3066 0 0.03 13 3 2.93 Shallow Pitting. Lt. Deposits. • 100 3097 0 0.04 15 3 2.96 Shallow Line of Pits. • ■ 101 3129 0 0.03 12 3 2.94 102 3161 0 0.03 11 3 2.91 Lt. Deposits. • 103 3191 0 0.03 13 3 2.93 Shallow Pitting. Lt. Deposits. I 104 3223 0 0.02 9 2 2.94 105 3253 0 0.04 14 2 2.94 Shallow Line of Pits. 106 3284 0 0.02 6 3 2.92 Lt. Deposits. 107 3315 0 0.03 10 2 2.94 108 3346 0 0.03 13 3 2.93 Shallow Pitting. Lt. Deposits. • 109 3375 0 0.03 12 3 2.92 Lt. Deposits. ■ 110 3406 0 0.03 10 2 2.93 111 3436 0 0.03 11 2 2.91 Lt. Deposits. 112 3466 0 0.03 13 2 2.93 Shallow Line of Pits. Lt. Deposits. 113 3495 0 0.02 9 3 2.90 Lt. Deposits. • 114 3525 0 0.04 17 2 2.92 Shallow Line of Pits. Lt. Deposits. 115 3555 0 0.04 15 3 2.91 Shallow Line of Pits. Lt. Deposits. • Iii 6 3586 0 0.04 15 2 2.93 Shallow Line of Pits. Lt. Deposits. • 117 3616 0 0.03 10 2 2.92 Lt. Deposits. • ■ 118 3647 0 0.03 13 5 2.88 Shallow Line of Pits. Lt. Deposits. ■ 119 3677 0 0.06 25 3 2.93 Line of Pits. Lt. Deposits. 120 3708 0 0.04 17 2 2.93 Shallow Line of Pits. Lt. Deposits. 121 3739 0 0.02 8 2 2.93 Lt. Deposits. • 122 3767 0 0.04 16 3 2.89 Shallow Line of Pits. Lt. Deposits. • 123 3797 0 0.03 10 2 2.92 Lt. Deposits. 124 3828 0 0.05 19 I 2.94 Shallow Line of Pits. I 125 3858 0,04 0.04 16 3 2.92 Shallow Line of Pits. Lt. Deposits. • 126 3889 0 0.03 10 2 2.94 127 3919 0.07 0.07 28 2 2.93 Line of Pits. Lt. Deposits. 128 3950 0 0.03 13 2 2.91 Shallow Pitting. Lt. Deposits. I 129 3980 0.03 0.04 17 2 2.94 Shallow Line of Pits. 130 4011 0 0.03 12 3 2.93 Shallow Pitting. Lt. Deposits. 131 4041 0 0.04 16 3 2.96 Shallow Line of Pits. 132 4071 0 0.02 8 2 2.93 Lt. Deposits. I 133 4102 0 0.03 12 2 2.94 Shallow Pitting. ■ 134 4133 0 0.04 17 2 2.93 Shallow Line of Pits. Lt. Deposits. . 135 4162 0 0.03 12 3 2.92 Shallow Pitting. Lt. Deposits. ■ 136 4193 0 0.04 14 2 2.93 Shallow Line of Pits. Lt. Deposits. 137 4223 0 0.04 15 2 2.94 Shallow Line of Pits. I 138 4254 0 0.04 16 2 2.96 Shallow Line of Pits. • 139 4283 0 0.06 22 2 2.93 Line of Pits. Lt. Deposits. ■ 140 4314 0 0.05 18 3 2.92 Shallow Line of Pits. Lt. Deposits. • 141 4342 0 0.04 18 2 2.91 Shallow Line of Pits. Lt. Deposits. I 142 4372 0 0.03 12 2 2.95 143 4401 0 0.05 19 3 2.90 Shallow Line of Pits. Lt. Deposits. • 144 4431 0 0.05 20 3 2.92 Line of Pits. Lt. Deposits. ■ 145 4461 0 0.04 17 3 2.95 Shallow Line of Pits. • I 146 4493 (1 0.04 16 2 2.90 Shallow Line of Pits. Lt. Deposits. ■ 147 4523 0 0.05 20 2 2.94 Shallow Line of Pits. • 148 4552 0 0.03 10 2 2.95 Penetration Body I I Metal Loss Body Page 3 I • 0 PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.2 ppf J -55 BTC -MOD Well: 1 E -27 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: March 26, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % I cuss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 149 4584 0 0.03 13 3 2.94 Shallow Pitting. • 150 4615 0.04 0.05 20 2 2.94 Shallow Line of Pits. • 151 4644 0 0.03 13 2 2.93 Shallow Line of Pits. Lt. Deposits. ■ 152 4673 0 0.04 17 2 2.95 Shallow Line of Pits. • 153 4703 0 0.04 17 2 2.93 Shallow Line of Pits. Lt. Deposits. ■ 154 4734 0 0.09 34 4 2.96 Line Corrosion. ■■ 155 4763 0 0.05 19 2 2.90 Shallow Line of Pits. Lt. Deposits. ■ 156 4793 0 0.03 11 2 2.94 ■ 157 4825 0 0.05 18 2 2.93 Shallow Line of Pits. Lt. Deposits. ■ I 158 4856 0 0.04 16 2 2.93 Shallow Line of Pits. Lt. Deposits. • 159 4885 0.04 0.05 21 4 2.92 Line Corrosion. Lt. Deposits. • 160 4915 0 0.03 11 2 2.91 Lt. Deposits. ■ 161 4946 0.04 0.05 18 4 2.93 Shallow Line of Pits. Lt. Deposits. • I 162 4976 0.03 0.04 16 2 2.94 Shallow Line of Pits. ■ 163 5007 0 0.03 12 3 2.93 Shallow Pitting. Lt. Deposits. ■ 164 5038 0 0.04 15 3 2.90 Shallow Line of Pits. Lt. Deposits. IN 165 5068 0.03 0.04 15 2 2.91 Shallow Line of Pits. Lt. Deposits. • I166 5098 0 0.03 13 2 2.92 Shallow Line of Pits. Lt. Deposits. ■ 167 5130 0 0.03 11 3 2.93 • 168 5159 0 0.05 20 4 2.94 Shallow Line of Pits. ■■ 169 5190 0 0.05 20 4 2.92 Line Corrosion. Lt. Deposits. •• 170 5222 0 0.05 19 2 2.93 Shallow Line Corrosion. Lt. Deposits. I 171 5251 U 0.02 9 2 2.94 ■ ■1 172 5281 0 0.07 26 3 2.92 Line of Pits. Lt. Deposits. ■ 173 5310 0 0.03 11 2 2.92 Lt. Deposits. • 174 5341 0 0.05 19 3 2.91 Shallow Line of Pits. Lt. Deposits. ■ I 175 5372 0.05 0.08 30 3 2.94 Line Corrosion. ■■ 176 5404 0.04 0.06 25 4 2.93 Line of Pits. ■ 177 5434 0 0.03 11 3 2.91 Lt. Deposits. • 178 5466 0.04 0.04 15 3 2.93 Shallow Line of Pits. Lt. Deposits. • 179 5497 0 0.03 13 3 2.94 Shallow Pitting. ■ 180 5529 0.04 0.06 23 5 2.90 Isolated Pitting. Lt. Deposits. ■■ 181 5560 0 0.05 20 4 2.94 Line of Pits. ■■ 182 5590 0.04 0.06 24 3 2.96 Line Corrosion. ■■ 183 5619 0 0.05 20 3 2.93 Shallow Line of Pits. ■ I 184 5649 0 0.04 14 4 2.96 Shallow Pitting. 185 5681 0 0.02 9 2 2.93 Lt. Deposits. 186 5713 0.04 0.04 14 3 2.93 Shallow Pitting. Lt. Deposits. • 187 5744 0.05 0.07 28 4 2.94 Line Corrosion. ■■ I 188 5775 0.04 0.06 23 3 2.93 Line of Pits. Lt. Deposits. ■ 189 5805 0 0.02 9 2 2.94 190 5837 0 0.02 8 2 2.95 191 5868 (1 0.02 , 9 2 2.93 Lt. Deposits. I 191.1 5899 0 0 0 0 2.86 GLM 1 (Latch @ 11:00) 192 5912 0 0.07 26 7 2.90 Isolated Pitting. Lt. Deposits. il 192.1 5943 0 0 0 0 2.81 OTIS SBR 192.2 5967 0 0 0 0 2.97 OTIS RRH Retrievable Packer 192.3 5970 0.05 0.05 20 3 2.96 Pup Shallow Line of Pits. ■ 193 5976 0 0.03 10 3 2.96 193.1 6006 0 0 0 0 2.87 GLM 2 (Latch @ 2:00) I Penetration Body I Metal Loss Body Page 4 I I I • ! PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.2 ppf J -55 BTC -MOD Well: 1 E -27 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in USA Survey Date: March 26, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 194 6018 0.04 0.03 13 3 2.94 Shallow Pitting. 195 6049 0.03 0.06 22 3 2.92 Line of Pits. Lt. Deposits. 195.1 6079 0 0 0 0 2.86 GLM 3 (Latch @ 9:00) 196 6091 0 0.08 31 5 2.96 Line of Pits. I 196.1 6121 0 0.04 17 6 2.92 Pup Shallow Pitting. Lt. Deposits. 196.2 6140 0 0.02 9 2.93 Pup Lt. Deposits. 196.3 6150 0 0.02 8 2 2.91 Pup Lt. Deposits. 196.4 6169 0 0.02 8 3 2.93 Pup Lt. Deposits. IN 196.5 6178 0 0.02 7 i 2.93 Pup Lt. Deposits. II I 196.6 6188 0 0.02 9 2 2.92 Pup Lt. Deposits. 196.7 6198 0.07 0.06 24 7 2.97 Pup Line of Pits. 196.8 6204 0 0.02 9 8 2.90 Pup Lt. Deposits. 196.9 6206 0.03 0.04 15 2 4.11 Pup Shallow Line of Pits. 197.1 6208 0 0 0 0 2.93 GLM 4 (Latch @ 4:00) 197.2 6213 0 0.08 33 15 2.94 , Pup Line Corrosion. 197.3 6218 0 0 0 0 2.99 OTIS Straight Slot Locator 197.4 6220 0 0 0 0 4.00 OTIS WD Permanent Packer 197.5 6223 0 0 0 0 4.00 OTIS Packer Adapter 197.6 6225 0 0 0 0 2.97 Seal Bore Extension 197.7 6232 0 0.02 7 4 2.92 Pup Lt. Deposits. 197.9 6238 0 0 0 0 2.75 Camco D Nipple No Go 197.9 6239 0.07 0.07 26 2 2.92 Pup Line of Pits. Lt. Deposits. I 198.1 6243 0.09 0.09 37 4 2.95 Pup Line Corrosion. 198.2 6245 0 0 0 0 3.95 OTIS SOS Penetration Body I I I Metal Loss Body I I I I Page 5 I I I • • I PDS Report Cross Sections I Well: 1E -27 Kuparuk Survey Date: March 26, 2011 Field: Tool Type: UW MFC 24 No. (HAL) Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 ' Tubing: 3.5 ins 9.2 ppf J -55 BTC -MOD Analyst: C. Lucasan I I Cross Section for Joint 198.1 at depth 6243.604 ft Tool speed = 57 Nominal ID = 2.992 I Nominal OD = 3.5 Remaining wall area = 96% Tool deviation = 25° 1 L I I \_ I \ \ / I Finger = 19 Penetration = 0.093 ins Line Corrosion 0.09 ins = 37% Wall Penetration 7 HIGH SIDE = UP I 1 I I I I • • PDS Report Cross Sections ti JI ., p I Well: 1E -27 Survey Date: March 26, 2011 Field: Kuparuk Tool Type: UW MFC 24 No. (HAL) Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 I Tubing: 3.5 ins 9.2 ppf J -55 BTC -MOD Analyst: C. Lucasan I I Cross Section for Joint 154 at depth 4755.083 ft Tool speed = 59 Nominal ID = 2.992 I Nominal OD = 3.5 Remaining wall area = 96% / Tool deviation = 10° I I / 1 1 I +: i - I I 1 , \ I Finger = 19 Penetration = 0.086 ins Line Corrosion 0.09 ins = 34% Wall Penetration HIGH SIDE = UP 1 I I I I I S • 1 PDS Report Cross Sections Well: 1E-27 Survey Date: March 26, 2011 Field: Kuparuk Tool Type: UW MFC 24 No. (HAL) Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 I Tubing: 3.5 ins 9.2 ppf J -55 BTC -MOD Analyst: C. Lucasan 1 I Cross Section for Joint 197.2 at depth 6215.200 ft Tool speed = 57 Nominal ID = 2.992 _ I Nominal OD = 3.5 0...-----; Remaining wall area = 85% Tool deviation = 25° / � / 1 I t \I I i N \ if/ 1 I Finger = 21 Penetration = 0.083 ins Line Corrosion 15% Cross - sectional Wall Loss HIGH SIDL = UP I I I KU ConocoPhillips S Attributes ogle &MD TD 1 E -27 I,iak� lil ; Wellbore APIA/WI Field Name Well Status Ind P) MD (11KB) Act Btu (1 B) conocciPhillips 500292083700 KUPARUK RIVER UNIT INJ 27.20 6,550.00 6,800.0 Comment 1125 (ppm) Date Amotatlon End Date KB[kd (II) Rig Release Date Wei confi9 - 7E 17 SSSV: TRDP Last WO: 12/30/1984 39.00 10/19/1982 Schematic - 27 31 Annotation Depth (fll(B) End Date Amotation Last Mod ... End Date Last Tag: SLM 6,362.0 12/9/2010 Rev Reason: UPDATE GLV C/O DATE Imosbor 3/8/2011 Casing Strings HANGER 27 ` MO Casing Description String 0... String ID ... Top (NCB) Set Depth (L.. Set Depth (ND) ... String Wt... String ... String Top Thrd i CONDUCTOR 16 15.060 32.0 85.0 85.0 65.00 H-40 WELDED • Casing Description String 0... Stang ID ... Top (NCB) Set Depth (L.. Set Depth (WD)... String Wt... String ... String Top Thrd SURFACE 103/4 9.794 31.6 2,217.6 2,217.5 45.50 K - 55 BTC Casing Description String 0... String ID ... Top (LLKB) Set Depth (r... Set Depth (WD)... Wring Wt... String ... String Top Thrd ' PRODUCTION 7 6.151 30.5 6,715.1 6,563.8 26.00 K -55 BTC Tubing Strings Tubing Description String 0... String ID ... Top (11i(B) Set Depth (f... Set Depth (WD)... String Wt... String ... Wring Top Thrd I TUBING 31/2 2992 27.3 6,245.4 6,143.2 9.20 J-55 BTC -MOD Compl Details CONDUCTOR, Top Depth 32-85 (ND) Top Ind NomL.. 1, _____/ Top Top (NCB) MB) 11 Item Description Commea ID @1 5AFETV vLV, .c=s 27.3 27.3 0.09 HANGER FMC GEN III HANGER 3.500 I 1.874 1,874.3 1,8742 0.66 SAFETY VLV CAMCO TRDP- 1A -ENC SAFETY VALVE 2.813 l 5,940.0 5,864.2 23.06 SBR OTIS SBR 2.813 5,966.1 5,888.2 23.11 PACKER OTIS RRH RETRIEVABLE PACKER 2.970 6,120.3 6,029.6 2403 BLAST JTS CAMCO STEEL BLAST JOINTS 2.992 I SURFACE. 6,219.2 6,119.4 24.99 LOCATOR OTIS STRAIGHT SLOT LOCATOR 2.992 6,220.5 6,120.6 25.00 PACKER OTIS WD PERMANENT PACKER 4.000 32 - 2,218 6,223.9 6,123.6 25.02 ADAPTER OTIS PACKER ADAPTER 4.000 6,224.4 6,124.1 25.02 SBE OTIS SEAL BORE EXTENSION 2.970 GAS LIFT, 6,238.7 6,137.1 25.09 NIPPLE CAMCO D NIPPLE NO GO 2.750 I 5.898 6,244.7 6,142.6 25.13 SOS OTIS SHEAR OUT SUB 1 3.950 Perforations & Slots Shot SBR, 5940 Top(TVD( Btm(TVD) Dens Top (11KB) Mtn (M(13) (MB) (MB) Zone Date (oh- Type eminent i PACKER, 5,966 6,122.0 6,167.0 6,031.2 6,072.2 C -4, C -3, 1E -27 10/18/1982 4.0 IPERF 6,177.0 6,185.0 6,081.3 6,088.6 C -2, C -1, 1E -27 10/18/1982 4.0 IPERF ` 6,330.0 6,340.0 6,219.7 6,228.7 A-5, 1E -27 10/18/1982 4.0 IPERF 6,357.0 6,382.0 6,244.0 ' 6,266.6 A -4, 1E -27 10/18/1982 4.0 IPERF 6,390.0 6,394.0 6,273.8 6,277.4 A -4, 1E -27 10/18/1982 4.0 IPERF "E e j Notes: General & Safety iil End Date Amotatlon 9/7/2010 NOTE: View Schematic w/ Alaska Schematic9.0 ill I w,FcnoN. 6,086 IPERF. 8,1228167 91778185 - . i I INJECTION, 6,204 I 204 R I LOCATOR, 6,219 J PACKER, 6,220 ADAPTER, 6.224 SEE, 6,224 ) I i 1 NIPPL F 6239 KO IN Mandrel Details To Top Port (ND) Ind OD Valve Latch Size TRO Run SOS, 6,245 tan Top (NCB) (MB) P) Make Nadel (In) Sery Type Type (in) (psi) Run Date Corn... 1 5,897.9 5,825.4 22.98 OTIS LBX 1 1/2 GAS LIFT DMY RM 0.000 0.0 8/5/1997 2 6,005.1 5,923.5 22.62 OTIS LBX 1 1/2 INJ DMY RM 0.000 0.0 12/10/2010 IPERF, 3 6,080.1 5,992.9 23.54 OTIS LBX 1 1/2 INJ DMY RM 0.000 0.0 8/5/1997 6,331 4 6,203.8 6,105.4 24.91 OTIS LBX 1 1/2 INJ DMY RM 0.000 0.0 8/5/1997 IPERF, 6,3578,382 PE 8 39 08, PRODUCTION, 308, TD, 6,800 1 • MEMORANDUM TO: Jim Re gg ~~ 7 y3~io P.I. Supervisor ( t FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 14, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IE-27 KUPARUK RIV iJNIT 1E-27 Src: Inspector NnN-('nNFiDENTiAL ~~ Reviewed By: P.I. Suprv .,~~ Comm Well Name: KUPARUK RIV UNIT 1E-27 API Well Number: so-029-20837-00-00 Inspector Name: Bob Noble Insp Num: mitRCN100628064226 Permit Number: 182-163-0 Inspection Date: 6/24/2010 Rel Insp Num: Packer Deptb Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. We11 y ~1E-z pe In ~'~' T TVD 5888 ' IA 6so 27ao ~ zrzo j z72o ~ - P.T.D 1821630 TypeTCSt SPT I Test psi 2740 ~ QA 75 90 90 90 -~~ Interval a~TST p/F P ~ Tubing 22so 22so 2zso z2so Notes: ~ ~ ~,~ ~ ,(e~).._ t'~Up~ Wednesday, July 14, 2010 Page 1 of 1 • • Brooks, Phoebe L (DOA) From: Regg, James B (DOA) Sent: Tuesday, July 13, 2010 2:57 PM To: Brooks, Phoebe L (DOA) Subject: RE: KRU 1 E pad MITIA 062410 Info provided by CPAI on 8/12/2008 as part of Packer TVD project confirmed the following: KRU 1 E-1 - -- acker TVD = 6020 ft ~ RU 1 E-27 (PTD 182-163) -- Packer TVD = 5 r Please adjust RBDMS to reflect these revisions. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Brooks, Phoebe L (DOA) Sent: Tuesday, June 29, 2010 8:48 AM To: Regg, James B (DOA) Subject: FW: KRU 1E pad MITIA 062410 Hi Jim, I emailed Conoco about the differing Packer TVD's and it sounds like they are firm on the figures reported. I checked the well history and didn't see any reports that could have changed the figures. I looked at the last MIT report (prior to this one) in RBDMS and both the operator and inspector reported the same numbers below (not what is currently in RBDMS) so I'm wondering if I should change our figures to match the operator's? Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Tuesday, June 29, 2010 8:41 AM To: Brooks, Phoebe L (DOA) Subject: RE: KRU 1E pad MITIA 062410 Phoebe, The packer depths are as CoP reported I re checked them myself this morning. I unintentionally left the P's of the report for 1 E-112 and 1 E-119. I'm covering 3 jobs this week and clearly not very well. Thanks • • MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 From: Brooks, Phoebe L (DOA) [mailto:phoebe.brooks@alaska.gov] Sent: Monday, June 28, 2010 10:23 AM To: NSK Problem Well Supv Subject: RE: KRU 1E pad MITIA 062410 MJ, Will you please verify the Packer TVD for the following wells: • 1E-11 PTD #1820510 - 6020' reported, 6008' in our database 1E-23 PTD #1821840 -- 5907' reported, 6124' in our database 1E-27 PTD #1821630 - 5888' reported, 5858' in our database Also, wells 1E-112 through 1E-119 were missing the test type, I'm assuming Standard Pressure Test "P"? Thank you, Phoebe Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Friday, June 25, 2010 2:12 PM To: Regg, James B (DOA); Brooks, Phoebe L (DOA); Maunder, Thomas E (DOA); DOA AOGCC Prudhoe Bay Cc: NSK Problem Well Supv Subject: KRU 1E pad MITIA 062410 Attached please find the 4 year MITIA's completed at KRU DS1 E yesterday and witnessed by Bob Noble. Let me know if you have any questions. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 • ~ Page 1 of 3 Regg, James B (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Tuesday, August 12, 2008 12:05 PM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: RE: Packer TVD Attachments: Copy of pkr_depth_edits_CPAI_data COP edit 8-12-08.x1s; AOGCC 1 of 5.zip Jim, Enclosed are the results of our investigation into the few wells with remaining discrepancies over top packer depth. I have found errors in COPs data in roughly half of the wells you submitted. Those wells are marked in a column that I have added to your original spreadsheet with OK. I will make the required changes to our database to fix those depths. The information confirming the packer depths is contained in the attached folder for your convenience. COPs recorded top packer depth on roughly half the wells does not agree with the States data. I have added supporting documentation for these wells to the attached folder. Please see the returned modifed spreadsheet, the attachments, and the comments below. Due to the size of the attachments and the restrictions of our system I'll have to break it into segments and send in subsequent a-mails to follow. Let me know if you have any questions Perry Klein Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7043 Cell Phone (907} 943-1244 Wells in question: 30-16 -COP agrees with the States PKR MD and TVD of 7648' and 6325' respectively. 1J-180 -COP agrees with the States PKR MD and TVD of 9996' and 3291' respectively. 3M-12 -COP contends the top packer MD and TVD to be 9994' and 6122' respectively. I've enclosed a PDF scan of the 8-19-87 tubing tally,completion report, and schematic which I believe to be the most current. The tally indicates the Camco HRP-1-SP packer was set at 9993.69 MD. 1A-05 - - I'm unaware of a pending workover on 1A-05 at this time. The well currently has PKR MD and TVD of 6745' and 5922' respectively. Most recent schematic, tubing tally and completion report are in the attachments. There has been some recent tubing patch work completed on the well but no tubing has been pulled and replaced. I've a call in to the drill site engineer in town to confirm future plans for this well. If it is worked over in the near future any new packer depths should be covered in the sundry process. 1 R-13 -I've researched the packer depth and our schematic does not agree with the workover performed. Our schematic lists the packer at 7880'. The tubing tally and 10-404 from the workover correctly identify the packer at 7878' MD. I've submitted our schematic internally to be updated to reflect the correct packer depth. 2L-329 -COP agrees with the States PKR MD and TVD of 5467' and 4898' respectively. 7/13/2010 Page 2 of 3 2X-04 -COP contends the top packer M • d TVD to be 6919' and 5306' respectivel•'ve included the tubing tally, schematic, and 10-404 report of sundry operations from the latest workover. 1 B-09 -COP agrees with the States PKR MD and ND of 7745' and 6241' respectively. 1Y-05 -COP contends the top packer MD and TVD to be 6250' and 5853' respectively. I've included the tubing tally, schematic, and 10-404 report of sundry operations from the latest workover. I've also included a 10-403 sundry request that we submitted with and incorrectly identified packer MD. I'm assuming the error was initiated in the sundry and propagated forward. 3F-04 -COP agrees with the States PKR MD and TVD of 6167' and 5729' respectively. 1 E-11 -COP contends the top packer MD and TVD to be 7491' and 6020' respectively. I've included a daily report of rig activities, tubing tally, notice of troubled welt, and schematic. It appears as if the well was worked over, added a stacker packer, in order to fracture stimulate the well. I found a state witnessed BOP test during the time of the work over but I can not find any supporting well completion report or 10-404 sundry report to support the tally information. 1 E-114 - COP agrees with the States PKR MD and TVD of 7414' and 3479' respectively. 1 L-21 DPN -COP contends the top packer MD and TVD to be 11275' and 5769' respectively. Included are the well schematic, tubing tally, well completion report and the 10-404 WINJ to WAG. 2A-01 -COP contends the top packer MD and TVD to be 7122' and 5796' respectively. Included are the well schematic, tubing tally and well completion report. 1 H-19 -COP contends the top packer MD and TVD to be 8242' and 6370' respectively. Included are the well schematic, tubing tally and well completion report. 2B-09 -COP contends the top packer MD and TVD to be 6904' and 5805' respectively. Included are the well schematic, tubing tally and well completion report. 1 C-117 - COP agrees with the States PKR MD and TVD of 4460' and 3685' respectively. 2C-03 - COP agrees with the States PKR MD and TVD of 7020' and 5608' respectively. 1 R-04 - COP agrees with the States PKR MD and TVD of 7706' and 6303' respectively. 1 E-104 - COP agrees with the States PKR MD and TVD of 5564' and 3351' respectively. 1A-14 - COP agrees with the States PKR MD and TVD of 7113' and 6013' respectively. 1C-133 -COP contends the top packer MD and TVD to be 3951' and 3669' respectively. Included are the well schematic, tubing & casing tally and well completion report. 1 E-27 -COP contends the top packer MD and TVD to be 5966' and 5888' respectively. Included are the well schematic, tubing tally and well completion report. 2P-434 -COP contends the top packer MD and TVD to be 5525' and 5129' respectively. Included are the well schematic, tubing tally, survey and well completion report. 1 E-117 -COP agrees with the States PKR MD and TVD of 9369' and 3338' respectively. 2T-217A -Apparently the only issue with this well was it's status. The 10-404 sundry of conversion to injection was mailed 7/30/08. I don't believe there were any questions regarding packer depth. 7/13/2010 • • Page 3 of 3 From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Tuesday, July 22, 2008 2:27 PM To: NSK Well Integrity Proj Cc: Fleckenstein, Robert J (DOA) Subject: Packer TVD Perry -Thank you for all the work you/others have done to help us close this project out. We are getting real close. Attached is the list of wells that we still are reviewing and could use another look by you. I've added a column of remarks that hopefully helps. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 7/13/2010 _ ~ • Cc~nacoPhillips Alaska, ln+. KRU 1 E-27 1 E-27 API: 500292083700 Well T e: INJ An le TS: 24 de 6121 SSSV Type: TRDP Orig 10/19/1982 Angle @ TD: 27 deg @ 6800 sssv Com letion: (1a7a-1a75, ~ -, ~ Annular Fluid: Last W/O: 12/30/1984 Rev Reason: TAG FILL OD:3.500) - 'J Reference Lo Ref Lo Date: Last U date: 8/31/2006 Last Ta : 6388' RKB TD: 6800 ftK6 Last Ta Date: 8/30/2006 Max Hole An le: 27 de 6800 Casin Strin -ALL. STRINGS Gas Lift - D@SCrI lion Size To Bottom TVD Wt Grade Thread andrel/Dummy _ ~ CONDUCTOR 16.000 0 85 85 65.00 H-40 valve 1 ' SUR. CASING 10.750 0 2218 2218 45.50 K-55 (5as7-5asa, OD:5.800) PROD. CASING 7.000 0 6715 6564 26.00 K-55 Tubin Strin' =TUBING Size To Bottom TVD Wt Grade Thread sBR 3.500 0 6245 6143 9.20 J-55 BTC MOD (5saossal, .Perforations Summa oD:3.5o0) Interval TVD Zone Status Ft SPF Date T e Comment 6122 - 6167 6031 - 6072 C-4,C-3 45 4 10/18/1982 IPERF 6177 - 6185 6081 - 6089 C-2,C-1 8 4 10/18/1982 IPERF 6330 - 6340 6220 - 6229 A-5 10 4 10/18/1982 IPERF PKR 6357 - 6382 6244 - 6267 A-4 25 4 10/18/1982 IPERF (5sss-5ss7, 6390 - 6394 6274 - 6277 A-4 4 4 10/18/1982 IPERF oDS.15s> Gas Lift Mandrels/Valves St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date Vlv Mfr Run Cmnt 1 5897 5825 Otis LBX DMY 1.5 RM 0.000 0 8/5/1997 Injection ~ ~ In'ection Mandrel s/Valves andrel/Dummy ~ St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date Vlv Valve 2 (soo5-coos Mfr Run Cmnt , oD:S.eoo) 2 6005 5924 Otis LBX DMY 1.5 RM 0.000 0 8/5/1997 3 6080 5993 Otis LBX DMY 1.5 RM 0.000 0 8/5/1997 4 6203 6105 Otis LBX DMY 1.5 RM 0.000 0 8/5/1997 Injection ~ Other lu s e ui . BtC. - JEWELRY andrel/Dummy Val e 3 "` ~ '.,:~ De th TVD T e Descri lion ID v (soso-sos1, - 1874 1874 SSSV Camco TRDP-1AE 2.813 OD:5.800) 5940 5864 SBR Otis 2.813 Pert 5966 5888 PKR Otis'RRH' RETR. 2.970 (s122-x167) - - 6220 6120 PKR Otis'WD' PERM. 4.000 6238 6137 NIP Camco 'D' Ni le NO GO 2.750 ___ _ 6245 6143 SOS Otis 2.992 Pert -- - -- 6246 6144 TTL 2.992 (6177E195) ---- Injection andrel/Dummy - - Valve 4 ~ (6203204, I OD:5.900) PKR - (6220~221, OD:6.156) NIP (623aFi239, OD:3.500) TUBING ', (0-6245, OD:3.500, ID:2.992) SOS (6245-6246, -~ OD:3.500) Perf _.......-- - - ..._.__. (6330-6340) -- - -- Perf (6357382) Pert - (6390~394) - ., • STATE OF ALASKA ALASKA tJiL AND GAS CONSERVATION CI.~yIMISSiON WELL COMPLETION OR RECOMPLETIOH REPORT AND LOG 1. Status of Well OIL DfX GAS ^ SUSPENDED ^ ABANDONED ^ SERVICE ^ Classification of Service Well 2. Name of Operator ARCO Aiaska, Inc. 7. Permit Number 82-163 3. Address P. 0. Box 100360, Anchorage, AK 99510 B. API Number 50- 029-20837 4. Location of well at surface 307' FNL, 641' FEL, Sec.21, T11N, R10E, UM 9. Unit or Lease Name Kuparuk River Unit At Top Producing Interval 99' FNL, 1038' FEL, Sec.21, T11N, R10E, UM 10. Well Number 1E-27 At Total Depth 119' FSL, 1243' FEL, Sec.16, T11N, R10E, UM 11. Field and Pool Kuparuk River Field 5. Elevation in feet (indicate KB, OF, etc.) 106' RKB 6. Lease Designation and Serial Nc. ADL 25651 ALK 469 Kuparuk River Oi 1 Pool 12. Date Spudded 10/07/82 13. Date T,D. Reached 10/14/82 14. Date Comp., Susp. or Aband. 10/19/82 15. Water Depth, if offshore N/A feetMSL 76. No. of Completions 1 17. Total Depth (MD+TV D) 6800'MD,6639'TVD 18. Plug Back Depth (MD+ND) 6624'MD,6483'TVD 19. Directional Survey YES C.1 NO ^ 20. Depth where SSSV set 1874 feet MD 21. Thickness of Permafrost 1450' A rox 22. Type Electric or Other Logs Run DIL/SFL/GR/Cal/FDC/CNL BGT RFT CBL 23. CASING, LINER AND CEMENTING RECORD CASING SIZE WT, PER FT. 'GRADE SETTING DEPTH MD TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 S rf ' " 10-3/4" 45.5# K-55 Surf ' " 7" 26.0# K-55 S rf ' " 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET IMD) 6390' - 6394' 6177' - 6167' " ' ' ' 6330' - 6340' 6132' - 6147' 6177' - 6185' 6122' - 6132' w)~5,~[' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC, 6367' - 6382' t'~ DEPTH INTERVAL IMD) AMOUNT & KIND OF MATERIAL USED 6357' - 6367' 6147' - 6157' 27. N/A PRODUCTION TEST .Date First Production Method of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Press. Casing Pressure CALCULATED 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (corn) . 28: CORE DATA Brief :description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips: NONE . Form 10-407 GRU3/WC56 Submit in duplicate Rev. 7-1.80 CONTINUED ON REVERSE SIDE ._ ~ - _ _ 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity , MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 6123' 6032' N/A Base Upper Sand 6184' 6088' Top Lower Sand 6317' 6208' Base Lower Sand 6435' 6314' 31. LIST OF ATTACHMENTS 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ Title Associate Engineer Date f'0'~4'~ v INSTRUCTIONS General: This form is designed for submitting a complete and. correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ,Item 16 and 24: Ff this well is completed for separate production from more than one interval (multiple completion), so'. state in item T6, and in item 24 show the producing intervals for only. the. interval reported ~ . - .:. ~.in. item 27:: Submit ~a 'separate-form for each additional interval to~'be separately. produced, showing the. . ` ~ ; dada pertinent to such interval. . Item 21: lnd~cate whether from ground level (G L) or other elevation (DF, KB; etc.): ,, Item 23: Attached upplemental records for this well shou d show the details of. a.ny multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, bVater In- jection,'Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ;'; :Form 10-407 i q ... ... .._.y:..:..~ ::.._. _.__._ : _ :. SING !TUBING /LINER DETAIL DRILL SITE ~~~cwu K I != - Z7 ARCO Alaska, Inc. ~j DATE fZ-a -27~` Subsidlery of AlIan11cR1chHeldCompany Page ~ of f pages NITEMS COMPLETE DISCRIPTION OF EQUIPMENT RUN LENGTH DEPTH ~ ~ ~ ~' z AMC ® i ,. .8~ z~, ' " ~ - -' ~- TC N o 00 ~I i ~~ ~ C `~ z.3 ~ y,` ~ ~~. 2 - s~ ~~ ~ ~ ~ f, l ~ 5 ~ ~ " ~ ~ ~.~~ - r e ~TG ~ r ,~ r ~ 2, f (70Z. '~} l ~ n ~ - C z Z' ~' _ - M T~ l9 ~ ~ ~ . ~,~„ ^ ., . ~ o ~ D` ~ i - Nl C~ z ~ uti.`~ to ~' y ~ Eal; - " \ ` ~ZL ~~ 5, 0, ` ~ r ~~ '-~~ 7 .~ ~rj 1 l l ' 1j ` Z ~ ~~~ - TL r~ , ~l .~ B ' ., s~- n BOTTOM OFTUBING TAIL ~ ~I~~. ~12.8~3 ~2 ~7 ~z.~?~3 F7 ~7 ,~~ ~~ y„ y ~, 2,~7 ,~5~ z,~i7 3,~[y AacosFne R. Supervisor C, -- :„,,,,,,„,„,„„„„~„, MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg :\(-/ ", (,I(l f'e,.>" P.I. Supervisor ,'- r9 - DATE: Wednesday, June 07,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILUPS ALASKA mc IE·27 KUPARUK RIV UNIT lE-27 Src: Inspector .. \b3 \~~ Reviewed By: P.I. Suprv ~\Bf?:'- Comm FROM: Chuck Scheve Petroleum Inspector NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT IE-27 API Well Number 50-029-20837-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS0606051 0 1804 Permit Number: 182-163-0 Inspection Date: 6/4/2006 ReI Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well i IE-27 ,Type Inj. i ~ TVD 5888 i IA 175 2350 2300 I 2300 i __----1- I - I 1821630 ! I I P.T. ¡TypeTest ! SPT I Test psi 1500 i OA 0 0 0 I 0 ! , -t Tubing 500 í 500 500 i 500 Interval 4YRTST P/F P I I ------------ Notes Well temporarily shut in for common line repair. ,"I~:~ N N t: r, ~"', ,. " _<!.a~ Wednesday, June 07, 2006 Page 1 of 1 ARCO Alaska, Inc. Post Office BO... ,)0360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 November 9, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton' Attached in duplicate are multiple Reports of Sundry Well Operations on the following Kuparuk wells. Conversions 3N-11, 3N-10, 3N-05, 3N-04, 3F-12, 3F-03, 3F-08, 3N-03, 13, 1E-21, 1E-19, 1E-23, 1E-lA, 1E-04, 1E-16 and1E-27 .Fracture~ and Stimulations · 3K-14, 3C-16, 3K-17, 1E-14, 3N-17, 3F-16 and 2V-12 Perforations 3N-11, 3F-11 and 3N-8A 1E-30 Failed MIT If you have any questions, please call me at 265-6840. Sincerely, Senior Operations Engineer Attachments cc: J. Gruber M. L. Hagood S. P. Twiggs KOE1.4-9 ATO 1478 ATO 1120 ATO 1130 3N-12, 3N- RECEIVED NOV ! 5 1988 ARCO AlasKa. Inc. is a Subsidiary of AtlanticRichfieidCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS , _ /ype of Request: Operation Shutdown Stimulate Plugging Perforate Pull tubing Alter casing Repair well Pull tubing Other X Conversion 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development .ARCO Alaska. Inc. Exploratory _ 106 RKB feet 3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service _ Kuparuk River Unit 4. Location of well at surface 8. Well number 307' FNL, 641' FEL, Sec. 21, T11N, R10E, UM 1E-27 //~ At top of productive interval 9. Permit number/approval number 99' FNL, 1038' FEL, Sec. 21, T11N, R10E, UM 7-167 At effective depth 10. APl number 119' FSL, 1243' FEL, Sec. 16, T11N, R10E, UM 5o- 029-20837 At total depth 11. Field/Pool 119' FSL, 1243' FEL~ Sec. 16~ T11N~ R10E, UM Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured 6800' MD feet Plugs(measured) NONE ;\L~l.;I ¥.~,~J~l:':~J~. true vertical 6639' MD feet ,~ ' Effective depth: measured 6624' MD feet Junk(measured) NONE ~',~. true vertical 6467' MD feet ~,~ '~'~o ~. ~.& I~as Cons. [;mmmis~i0~ Casing Length Size Cemented Measured Structural Conductor 85' 1 6" 272 Sx ASIi 85' 85' Surface 2218' 1 0-3/4" 1500 Sx ASIII & 2218' 2217' Intermediate 250 SX ASI Production 6 71 5' 7" 635 Sx Class G & 6715' 6556' Liner 250 SX ASl Perforation depth: measured 6122'-6167', 6177'-6185', 6330°-6340', 6357°-6382', 6390'-6394' true vertical 5988'-6032', 6042'-6050°, 6192'-6201', 6218'-6242', 6250'-6254' Tubing (size, grade, and measured depth) 3.5" J-55 @ 6239' Packers and S$SV (type and measured depth) Camco TRDP-1AE @ 1868', Otis RRH Packer @ 5934', Otis WD Packer @ 6214 13. Stimulation or cement squeeze summary Well 1 E-27 was returned to water injection service from Intervals treated (measured) production service on 4/16/87. It passed a MIT on 4/11/87 (see attached). No wireline work was required. Treatment description includin$ volumes used and final pressure 14. Representative Daily Averaee Production or Iniection Data - OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut In Since 4/85 ......... Subsequent to operation (W.l.) ...... 4455 1 2 8 0 2 0 4 0 15. Attachments MIT Test 16. Status of well classification as: Copies of Logs and Surveys run ~ Daily Report of Well Operations . Oil ~ Gas ~ Suspended ~ Service Water Iniection 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Jvt~/ .Sic~ned 10.~404~~R v ~ ~JTitle Sr. Operations Engineer Date 11/01/88 Form ' 06/15/88 SUBMIT IN DUPLICATE OIL AND. Gl ~NSERVATION ~SSION MECHANIC~ ~TY TEST Field: ii i i ii iii i mll i ii i llll ii I iiii .o *p *I TYPE OF PKR ' CAS~ TBG REQ . -,TBG ..... TiME: TiME TIME ' WELL *S _._ ANNIrUJS ~ SIZE/Wr/~E SIZE .TEAT CSG TBG TBG TBG *M *N FLUID MD PRESS PRESS CSG CSG CSG PRESS PRESS PRESS · ?~- t - ~*2e ................ z,~o' zoo ..... zo~ z~:>_ ............. '~: ,( ? ,/ ~ / . ~ '/z 2 ~ ,~ ' ~ .... . .... . .. . ;:',,.~s ~ ~ ..... ....... ~ ~ _7' ,, ;,,0 .~ /ao ~.. r'..~ /ooo /mac> ....... ~,,t4z 7/zr,. ,,. , , , , ,, ,.,, :z.,,~,p . z/.,a~ z/6o z~,e~ /:,,e~,.~,.. " 7t9'~ /~'~ 5 N ,, o~ 7"/ z~*/~-f5 .~'/~" z,7~ ~oa 7~o ~ ~'~ iii iii ii iii II i I II I I I I ii I__ *TUBING IK3FLTION HMID: P = PRD[XX~ WATER IN3 S - SALT WATER INJ M - MISCIBI~ ~ON I - INjF_L'rINo N-NOT ~ DIESEL "' · ~$ ~5 GLY(X)L ..... SALT WATER DRILLIJqG ~ L ' D.EWS.06 ARCO Alaska. Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: January 28, 1988 Transmittal #: 7067 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. '~ 3C-4 ~" 3C-16 ~ 2U-15 ~ 1L-7 PBU Bottom-Hole Pressure Survey Kuparuk Well Pressure Report(Otis) Kuparuk Well Pressure Report(Otis) KOE Falloff Analysis KOE Falloff Analysis 12-10-87 8-26-87 7-3-87 12-21-87 12-31-87 50-029-21416 FBHP 'A' Sand Static 'C' Sand Both Sands Both Sands Anchorage Receipt Adknowledged: DISTRIBUTION: Date: D &M State of Alaska Chevron 'Mobil SAPC Unocal ARCO Alaska. Inc :s a Subs~la~ ol AtlantlCRichheldCompany ATTACIIMENT 1 PAGE I KUPARUK RIVER FIELD CONSERVATION ORDER 198 RULE h - 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 :' ~'~IE-01Aj 20h6401 "~'~lE-Oh 05/08/83 0h/17/83 '"'~1E-16j 20777 02/11/83 '""~1E-27 ~ 20837 02/11/83 '~"~1C-06"'"~20890 07/28/8h 1R-08t''~ 21333 08/29/85 1Y-01 ~ 20933 10/15/85 1Y-02'~- 20941 03/30/85 '"'~'1Y-07j 20950 11/01/85 "'"'1Y-08''''''~ 20944 03/30/85 ""'Z2B-06,-/ 21078 11/07/85 '~2B-07j 21080 07/12/86 "~2B-10'~ 2108h 11/09/86 05/31/87 SPINNER REINITIATED INJECTION 06/03/87 SPINNER REINITIATED INJECTION 06/01/87 SPINNER REINITIATEB INJECTION 06/02/87 SPINNER REINITIATEB INJECTION 06/23/87 SPINNER FOLLOWUP 06/11/87 SPINNER FOLLOWUP 06/09/87 SPINNER FOLLOWUP 06/21/87 SPINNER FOLLOWUP 03/16/87 SPINNER FOLLOWUP 06/10/87 SPINNER FOLLOWUP 06/14/87 SPINNER FOLLOWUP 06/17/87 SPINNER FOLLOWUP 06/15/87 SPINNER FOLLOWUP WELL COMPLETION A~C SS A&C SS A&C SS A&C SS A&C SS AEC SS A&C SS A&C SS A&C SS A&C S A~C S A&C S A&C S ZONES TAKING WATER A&C A&C A&C A&C A&C A&C A&C A&C A&C A&C A&C A&C A&C I NJ ECT I ON BWPD RECEIVED .AUG - Alaska Oil & Gas Cons. Anchorage STATE OF ALASKA ALAS. ~ OIL AND GAS CONSERVATION COMI~SSION 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 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc ' RKB 99 feet 3. Address PO Box 100360. Anchorage, AK 4. Location of well at surface 99510 307' FNL. 641' FEL. Sec.21 T11N RIOE UM At top of productive interval ' ' ' 99' FNL, 1038' FEL, Sec.21, T11N, R10E, UM At effective depth 92' FNL, 1097' FEL, Sec.21, T11N, RIOE, UN At total depth 119' FSL, 1245' FEL. Sec.16: TllN_. RI~IE: IlM 11. Present well condition summary Total depth: measured 6800' MD feet true vertical 6639' TVD feet · Effective depth: measured 6624' MD feet true vertical feet 6467' TVD 6. Unit or Property name KunartJk River Ilnit 7. Well number 1E-27 8. Permit number Permit #82-163 9. APl number 50-- 029-20837-00 10. Pool I~t~,nart~k I~'iv~r 13il Pool Plugs (measured)None Junk (measured) None Casing Length Size Cemented Measured depth True Vertical depth Structural 85' 16" 272 SX AS II 85' MD 85' TVD Conductor Surface 2218' 10.75'" 1500 SX ASIII 2218' MD 2217' TVD xxx~r~t~mX~te & 250 SX AS I Production 6715' 7" 635 SX Class G 6715' MD 6556' TVI~ xxxJ~xxxx 250 SX AS I Perforation depth: measured 6122'-6167' MD, 6177'-6185' MD, 6330'-6340' MD, 6357'-6382' MD 6390' -6394' MD true vertica15988'-6032' TVD, 6042'-6050' TVD, 6192'-6201' TV.D, 6218'r--624,2' 6250'-6254' TVD ;~ L. ~i. i:..iTM ~' ~-~ ii ?, Tubing (size, grade and measured depth) 3.5", J-55, 9.2# w/Tail @~6239' Packers and SSSV (type and measured depth) ~lt. is RRH PI<R @ ~qqzt,/ Camco TRDP-I.a.E, SS~v ra ~, un ~ef~.!~ 12.'Attachments --I~esc'ription summary of proposa'~'l~" I~e"t~i~ed'~'~erations program [] BOP s ~"~? Convert well from oroductinn ~ervice ~_n A ~nrl £ Sand water injection. 13. Estimated date for commencing operation March 25, 1987 14. If proposal was verbally approved Name of approver -,..~ /0- 5/¢_~_ ~;:~.~:~ t/,.' / / Date approved 15. I hereby certify that the foregoing is true and ~orrect to the best of my knowledge Signed .~7~ ,~ ,~,,~,,~~.,¢/' Title Sr. Operations Engineer Commission Use Only Dat2/10/87 Conditions of approval [] Plug integrity [] BOP Test Mec~n~.cat Approved by Notify commission so representative[] Locationmay witneSSclearance Approval No. ..~ .~/~, ¢ ..... by order of Commissioner the commission Date rD Form 10-403 Rev 12-1-85 Submit in triplicate Mr. C..V. Cha+~orton May 27, 1986 Page 2 KUPARUK ~,~.I NITIAL · ATTACHMENT (~r ,.: .-.v ~ C, !o8[ ~" RIVER UNIT INJECTI~N'LOGS C ~" INJECTION PROFILES ....... -~ Well Number Date of Initial Injection Date of Injection Profile 1A-7 3/21/83 3/25/83 1A-9 3/1/83 3/22/83 1A-11 3/7/83 3/21/83 1A-12 3/1/83 3/6/83 lA- 13 2/4/83 10/17/83 lA- 14 2/22/83 4/11/83 1A-15 3/1/83 3/18/83 1A-16 3/1/83 3/24/83 I Number Date of Initial Injection Date of Injection Profile 1E-lA 1E-4 1E-9 1E-13 1E-14 1E-16 1E-19 1E-21 '1E-23 1E-27 . 1E-30 1 Number 1F-10 1F-11 1F-13 1F-15 1 Number 5/8/83 5/17/83 4/17/83 5/19/83 2/16/83 10/4/83 2/8/83 3/7/83 2/10/83 8/2/83 2/11/83 3/15/83 4/29/83 5/11/83 5/2/83 10/4/83 5/3/83 4/5/84 2/11/83 10/7/83 2/14/83 10/7/83 Wel Wel Wel Date of Initial Injection Date of Injection Profile Date 8/13/84 10/30/84 8/12/84 9/24/84 8/16/84 9/25/84 8/16/84 9/26/84 of Initial Injection Date of In,iec. tion Profile 1G-3 10/25/85 12/20/85 1G-6 7/28/84 9/23/84 1G-9 9/15/84 9/23/84 IG-i4 8/24/84 9/22/84 1G- 16 8/24/84 9/22/84 Attachment I I Page 2 Drill Site 1H Well No. ~IH-4 ~1H-7 ~1H-8 Log Date 8/16/82 8/13/82 6/21/82 7/20/82 7/22/82 Drill Site Well No. Log Date 1E 1E-lA "~/lg/81 1E-2 "8/17/81~-7 _'"1/17/84/ 1E-3 ~"'10/18/81~, ~11/7/81/ '~8/4/80'\ _~ 1E-5 ~10/27/81. 1E-6 ~10/21/81~ ~1/12/82/ ~1E-7 ~/28/81~ ~11/1/81/ 1E-12 ~11/28/84 1E-15 ~/26/82 1E-16 ~/29/82 1E-17 ~9/1/82 1E-20 ~5/7/83 .1E-24 ~/17/83 1E-25 ~1/17/83 1E-26 ~1/13/83 1E-27 ~0/31/82 1E-28 ~10/27/82 ] ~E-2g ~0/~/~ ~7/~/~ / 1E-30 ~0/16/82 Drill Site 1G Well No. '"'IG-1 "%1G-2 '"~1G-3 "~1G-4 "-,16-5 '~ 1G-8 Log Date 9/7/82 ' 9/25/82%~ 9/28/82 12/8/84/ 10/13/82 11/12/82 3/12/83 1/22/83 Drill Site Well No. Log Date 1F IF-1 2/19/83 1F-2 2/3/83 %1F-3 1/31/83 '"1F-4 5/29/83 %1F-5 . 10/25/82 '~1F-6 10/28/82' '~ 1F-7 11/1g/82~ ~ ~/7/83/~ RECEiVi FEB 2 1 1986 Alaska 011 & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 17, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Attached are our notices of intention field well 2X-5 and to convert the injectors- to perforate Kuparuk following wells to 1E-lA; 1E-4; 1E-16; 1E-19; 1E-21; 1E-23; 1E-27 If you have any questions, please call me at 263-4212. T. Mark Drumm Kuparuk Operations Coordinator TMD / kmc Attachment (in Triplicate) I ECEIVED JUL l ,~ 1985 Alaska .Oil & Bas Cons. Commission '-' ,. Anchorage "'-" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2, Nan~el~)pe~tl~_~S KA, INC. 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 4. Location of Well SURFACE LOCATION. 307' FNL, 6q1' FEL, SEC. 21, T11N, R10E, UM 5. Elevation in feet (indicate KB, DF, etc.) 106' 12. 7. Permit No. 82-163 8. APl Number 5o- 029-20837 9. Unit or Lease Name KUP^RUK RIVER UN I T 10. Well Number 1E-27 1 1. Field and Pool KUPARUK RIVER F I ELD 6. Lease Designation and Serial No. KUPARUK R ! VER O I L (RKB) ADL 25651, ALK 469 POOl_ Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment r-I Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other ~] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that Kuparuk well 1E-27 be converted from a to a water injection well. The well was converted from an to a producer March 27, 1985. Injection will be into the sands. producer injector "A" and "C" ANT I C ! PATED START DATE: SEPTEMBER 1 , 1 985 RECEIVED J U L l 8 19 5 Naska 0ii & Gas Cons. Commission Anchorage KUPARUK 14.1 hereby certify that the foregoing is true and correct to the best of my(~:$(~l~iiON~) COORDINATOR Signed The space below for Commission use Title 7/16/85 Date Conditions of Approval, if any: Approved by Approved Copy Ret rn By Order of COMMISSIONER the Commission Date Form 10~103 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office Be .10360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 17, 1985 Mr. C. V. Chatter Alaska Oil and Ga 3001 Porcupine Dr Anchorage, AK 9 ton, Chairman s Conservation Commission ive 9501 Dear Mr. Chatterton' Attached in duplicate are subsequent notices following wells at the Kuparuk River Field' Well Action 1B-2 Fracture 1B-4 Fracture 1E-lA Cancel lation (Reperf) 1E-lA Cancel lation (Frac) 1E-27 Cancellation (Frac) 1E-30 Polymer Project 1F-6 Cancel lation (Frac) 1F-13 Cancel lation (Frac) 1G-1 Cancel lation (Stressfrac) 1Q-5 Acidize 1Q-6 Acidize 1Q-7 Fracture 1Q-11 Cancellation (Frac) 1Q-1 3 Fracture lQ- 1 4 Fracture 1Q-15 Fracture 1Q-16 Fracture 1Y-2 Conversion 1Y-8 Conversion 1Y-12 Conversion 2A-2 Conversion 2C-8 Cancellation (Perf) 2C-14 Acidize 2H-15 Stimulation 2V-2 Conversion Date Performed 6/14/85 6/1~/85 1/5/85 6/23/85 6/24/85 6/25/85 7/2/85 7/1/85 7/2/85 7/2/85 3/3O/85 3/30/85 3/30/85 3/31/85 7/2/85 6/3O/85 5/16/85 on the If you have any questions, please · T. M. Drumm Kuparuk Operations Coordinator TMD/kmc Attachment (Duplicate) call me a t 263-4212. ARCO Alaska, Inc. is a Subsidiary o! AllanlicRichfieldCompany ~ STATE OF ALASKA "~", ALASKA OIL AND GAS CONSERVATION COr,,MISSION $1_IN_nRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL I--I COMPLETED WELL E~ OTHER [] 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O, BOX 100360, ANCHORACE, ALASKA 99510 4. Location of Well SURFACE LOC. ATION' 307' FNL, 641' FEL, SEC. 21, T11N, R10E. UM Elevation in feet (indicate KB, DF, etc.) 12. 7. Permit No. 82-163 8. APl Number 5o- 029-20837 --~. Unit or Lease Name KUPARUK RIVER UN I T 10. Well Number 1E-27 11. Field and Pool KUPARUK RIVER F I ELD 6. Lease Designation and Serial No. KUPARUK R I VER O ! L 106' (RKB) ADL 25651, ALK 469 POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' Perforate Stimulate Repair Well (Submit in Triplicate) (Submit in Duplicate) [] Alter Casing [] Perforations [] Altering Casing [] Abandon [] Stimulation F-] Abandonment [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Due to suspected communication between the Kuparuk well 1E-27, the "A" sand will not at this time. "A" and "C" sand in be fracture stimulated 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. KUPARUK . DTa~e1 6 / 8 5 Signed ~, ~-,~ ~),~-<.~--'~--- Tit,e OPERATION:'3 COORDiNAi-OR .~~ 4" 0' ~'I '~ g 5"' The space below for Commission use , ~ / .~ --- Conditions of Approval, if any: Approved by_ By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate Form 10-403 and "Subsequent Reports" in Duplicate RETURN TO: ARCO Alaska, inc. ~s! Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ARCO ALASKA, INC. KUPARUK OPERATIONS RECORDS CLERK ATO-1115B P.O. ~BOX 100360 ANCHORAGE, AK 99510 TRANSMITTAL NO:5230 PAGE 1 OF 2 ENGINEERING TRANSMITTED HER~¥qITH ARE THE RECEIPT AND RETURN ONE SIGNED COPY OF SEQUENCE OF EVENTS FROM WELL SERVICE PRESSURE, FLUID,. AND ACI FOLLOWING ITF~S. PLEASE ACKNOWLEDGE NUED ON THE 'FOLLOWING ACKNOWLEDGE D: D DATA lB-! SBHP 05-30-8 lB-2 SBHP' 05-30-8 lB-4 SBHP 05-16-8 lB-4 PRE-WORKOVER 05-24-8 ID-8 SBHP 04-29-8 1E-iA TUBI~]G LEAK 05-03-8 1E-5 COMP PBU ETC. 04-28-8 1E-11 LEUTERT Blt SMPL 06-02-8 !E-23 SBHP 05-22-8 1E-23 SBIIP 05 -23 -8 1E-27 TEMP/SPIN-LEAK 05-0 3-8 1E-27 TUBING LEA!f 05-04-8 1G-6 PRESSURE FALL- 05-07-8 OFF !H-6 SBHP 04-29-85 1L-5 PBU W/E-LINE 04-27-85 iL-5 PBU 04-29-85 !Q-1 ISIP ~ 05-30-85 .!Q-1 SBHP 'A'SDS 05-26-85 lQ-3 TAG FILL BHP 05-18-85 lQ-4 SBHP 'C' SD ETC 05-10-85 lQ-4 SBHP ETC 05-14-85 lQ-4 ACID JOB 05-17-85 lQ-5 ISIP TEST 04-29-85 iQ-7 ACID JOB 05-26-85 iQ-9 'C' SD PBU 05-12-85 lQ-9 PBU 'C'SD ETC 05-13-85 1Y-12 FALL-OFF TEST 05-05-85 2A-2 BHP 05-27-85 2A-4 'A'SD BlIP 05-10-85 2A-4 'A'SD BHP 05-09-85 2A-4 'A'SD BHP 05-11-85 2A-5 SBHP 05-05-85 * * * COY£ I PA RECEIPT THIS TRANSMITTAL. REPORTS (ONE COPY OF EACH) 5 CAMCO 5 CAMCO 5 CAMCO 5 CAMCO 5 CAMCO 5 CAMCO 5 CAMCO 5 OTIS 5 CAMCO 5 CAMCO 5 CAMCO 5 CAMCO 5 CAMCO CAMCO CAMCO CAMCO B. J. HUGHES CAMCO CAMCO CA~CO CAMCO NOWSCO/B.J.HUGHES B.J.HUGHES NOWSCO/DOWELL CAMCO CAMCO CAMCO OTIS CAMCO CAMCO CAMCO CAMCO GE*** T,'{ iBU~£I ON: W. PASI{ER EXXON PUILLIPS OIL* J. FATHMELL,~ BPAE* DRILLI~TC B. CURRIER L. JOHNSTON CHEVRON* ~OBIL* D & M.b' NSK CLE2K DATE: ~'STATE OF ALASKA..~' SOHIO* · U NIO,~* K. TULIN/VAULT ARCO Alaska, Inc. Post Office Bo,, 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 19, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1E-27 Dear Mr. Chatterton: Enclosed is a Well Completion Report for the subject well. you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU9/L85 Enclosure If ARCO Alaska, Inc, is a Subsidiary of AtlanticRichfieldCompany " ~ STATE OF ALASKA · ALASKA ~. AND GAS CONSERVATION CC~ISSION 'WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~X GAS [] SUSPENDED [] ABANDONED [] SERVICE [] · 2. Name of operator .... 7. Permit Number ' ARCO Alaska, Inc. 82-163 ,, 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20837 4. Location of well at surface 9. Unit or Lease Name . 307' FNL, 641' FEL, Sec.21, T11N, RIOE, UN Kuparuk River Unit At Top Producing Interval 10. Well Number 99' FNL, 1038' FEL, Sec,21, T11N, RIOE, UN 1E-27 At Total Depth 11. Field and Pool 119' FSL, 1243' FEL, Sec.16, TllN, RIOE, UN Kuparuk River Field §. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool 106' RKBI ADL 25651 ALK 469 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 10/07/82 10/14/82 10/19/82I IN/A feet MSL 1 '~7. '~otal Depth (MD+TVD) 18. Plug Back I~epth (MD+'rVD) 19. Directional Survey 20. Depth where SSSV set J 21. Thickness of Permafrost 6800'MD,6639'TVD 6624'MD,6483'TVD YES [~ NO F1 1874 feet MDI 1450' (Approx) 22. Type Electric or Other Logs Run DIL/SFL/GR/Cal/FDC/CNL, BGT~ RFT~ CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H'40 Surf 78' 24" 272 sx AS II ~10-3/4" 45.5# K-55 Surf 2218' 13-1/2" 1500 sx AS III & 250 s:' /~S I 7" 26.0# K-55 Surf 6715, 8-3/4" 635 sx Class C & 250 s: A~ I . ,, 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD , interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 6390' - 6394' 6177' - 6167' ., 3-1/2" 6245' ~220' & _~9~' 6330' - 6340' 6132' 6147' 6177' - 6185' 6122' 6132' W),~ ~r~ 26. ACID, FRACTURE' CEMENT'~QUEEZE, ETC. 6367' - 6382'~'J DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6357' . 6367' - N/A ,, 6147' - 6157' ..... · 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) . Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-'OIL RATIO TEST PERIOD I~ I Flow TUbing Casing Pressure CALCULATED. ~lb OI L-BBL ' GAS-MCF WATER-BBL el L GRAVITY-APl (c°rr)" Press. 24-HOUR RATE '~ '"~8. CORE DATA ' ,, Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE ".~'~° Con~ C°rnn~issior~ /~;?"-;/?"~r.,~.., ' Form 10-407 GRU3/WC56 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. .. 3O. . ' GEOLOG'IC.M/~'RKER~S' :' '~i .-. " FORMATION TESTS NAME Include interval tested, pressure data, ali fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Upper Sand 6123' 6032' N/A Base Upper Sand 6184' 6088' Top Lower Sand 6317' 6208' Base Lower Sand 6435' 6314' 31. LIST OF ATTACHMENTS Wnrk~n~,~r W~=ll Fli~t-nrv 32, ~ hereby certify that the foregoing is true and correct to the best of my knowledge Signed t/f~~ .Y,_~-~-'~-' Title Associate Engineer Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". ARco:oil and Gas Company Well History - Initial Report- Dally Insinuations: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are started. Dally work prior to s~udding should be summarized on the form giving inclusive dates only. Distriot Alaska Field Kuparuk River I County. parish or borough I -- North Slope Borough ~ Le~ee or Unit ADL 25651 Recompletion IStets Alaska Well no. 1E-27 W/O Auth. or W.O. no. A~E Cap 403083/Exp 403075 Operator WWS #l API 50-029-20837 ARCO Alaska, Inc. Spudded or W.O. begun I ARCO W.I. · 56 24% ]Date IH°ur1930 hfs ]Prior status If a w.o. Workover Date and depth as of 8:00 a.m. 12/26/84 12/27/84 12/28/84 12/21/84 Complete record for each day reposed 7" @ 6715' 6624' PBTD, Fsh'g f/Pkr @ 5940' 10.3 NaCl/NaBr Accept rig @ 1930 hrs, 12/21/84. Pull BPV, tat BOPE. RIH & retrv GLM @ 5928'. Spot 35 bbls BridgeSal pill & sqz to parrs. Displ ann w/10.4 ppg brine. Displ ann w/10/4 ppg brine. Set BPV. ND tree, NU & tat BOPE. Att to shear SBR w/o success. RIH w/2.75" tbg cutter, cut tbg @ 5944'. Pull tbg hgr. POOH, chg all colrs to modified BTC. POOH w/compl string. PU fsh'g tls, TIH to TOF @ 5944' (Otis perm pkr). Mill over top of 3½", 9.2# stub, latch onto fsh & jar SBR loose. Spot 35 bbl BridgeSal pill & sqz pill to perfs. POOH w/SBR. LD tbg stub & OS. Redress SBR w/retrv'g tl, TIH to 5955', wsh over slick jr. PU mill's assy& TIH to pkr @ 5980' WWS RKB. Mill pkr~ made approx 20", circ, POOH. Chg shoes, TIH, mill perm pkr. Circ & spot 25 bbl BridgeSal pill, POOH, LD mill'g assy. PU Tri-State spear, TIH to pkr, spear pkr & wrk loose, POOH; no fsh. Dress spear & TIH, tag pkr @ 5940', fsh f/pkr. 7" @ 6715' 6624' PBTD, Chg out tbg head 10.3 NaC1/NaBr Fsh f/pkr, POOH w/fsh. PU bit/JB/csg scrpr, RIH, tag fill @ 6492', wsh & rm to 6618', POOH, LD tls. PU Bkr Model "C" retrv BP, RIH & set @~ 6095'. Tst plug to 2500 psi; OK. ND stack, chg out tbg head to FMC 5000# Gan III. 7" @ 6715' 6622' PBTD, LD 3½" DP 10.3 NaC1/NaBr NU 5000# tbg head, NU &tst BOPE to 250/5000 psi. Tst csg to 3500 psi. RIH w/retrv'g tl, rel BP, CBU, POOH w/BP. RU DA, rn JB & 6.125" gage ring, set dn @ 6122'. Rn JB & 6" gage ring to 6622'. RIH w/WD Pkr, set @ 6224', POOH, RD DA. RIH w/DP & start LD DP. The above is correct 81gnature /I For form preparation a~ di~ributlon, ~ee ProoedUr~a Manual, Section 10. Drilling, Page8 86 end 87, IDate 1/09/85 ITM Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be use(] for reporting the entire operation if space is available. I Accounting cost center code District County or Parish ~ State I Alaska North Slope Borough I Alaska Field Kuparuk River Auth. or W.O. no. AFE Cap 403083/Exp 403075 Lease or Unit Title J Well no. ~DL 25651 I 1E-27 W/O Recompletion WWS #1 API 50-029-20837 Operator J A.R.Co. W.I. Irotal number of wells (active or inactive) on this cost center prior to plugging and I ARCO Alaska, Inc. I 56.24% /aband°nment of this well I Spudded or W.O. begun I Date Hour I Prtor status if a W,O, I I Workover 12/21/84 1930 hfs Date and depth as of 8:00 a.m. 12/29/84 thru 12/30/84 Complete record for each day reported 7" @ 6715' 6591' PBTD, RR Diesel RIH w/3½" prod string, tst contrl in & SSSV to 5000 psi; OK. Tag pkr @ ±6230' w/3000#, psh dnhole to ±6615' (btm of fsh top @ 6591'). POOH w/prod string. RIH w/6.125" gauge ring to 6112', set dn. RIH w/6" gauge ring to 6591', rec'd pkr debris. Made CO rn w/GR/JB. RIH w/Otis WD Pkr, set @ 6214'. RIH w/compl string, hook contrl in to SSSV &tst to 5000 psi; OK. Lnd tbg. Set top pkr, shear pins on SBR. Set BPV. ND BOPE, NU tree &tst pack-off to 5000 psi. Tst tree to 250/5000 psi. Star[ to press ann, sheared out @ 2400 psi. Displ dn ann w/50 bbls diesel & crude. RU Otis S/L, RIH, set std'g vlv. Press ann to 2500 psi. Close SSSV & monitor f/15 min. Open SSSV, press tbg to 2000 psi. RIH w/S/L, pull std'g vlv. Set BPV. RR @ 0600 hrs, 12/30/84. SSSV @ 1874.34' - Otis 7" Retry Pkr @ 5966.14' WD Perm Pkr @ 6220.47' - Tbg Tail @ 6245.36' Old TD New TD Released rig Date 0600 hrs Classifications (oil, gas, etc.) Oil Producing method Flowing Potential test data I PB Depth IKind of rig 12/30/84 I rType completion (single, dual, etc.) Single Official reservoir name(s) Kuparuk Sands 6591' PBTD Rotary Well no. Date Reservoir Producing interval Oil or gas Test time Production i~E~o ~e ~ate '~ump size, SPM X length Choke size T.P. C.P. Water % GOR correctedGravity Allowable The above ia correct For form preparation ar~ distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drillin~ Superintendent ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 05-t 5-85 'I'i:;:AN.':~iglTTAL N0'5to.-*""~' i~E'f'UF(N TO: I'I:::ANS'MITTED HEREHII'H ARE ]'HE FOi...L. OHING I l'lii. H ,.9 ,~A C I< N OWLED E; E i:(ECEIF'T AHD RF'/URN ONE $'[(;NED COI:'Y OF THIS 'FI.',:ANSMIT'I'AL, W$1:;:/5'I:':.:qUENC, IF. OF EVE. i",IT,S' (ONE COPY 01:' EACI'I) t A-t i::'BU 04-2t -85 t A-t F'BU 04-'"~"~-'~':'~,~.-' ~.,.., tA-2 RUN LYNES' i:( Ei C (] i:;: I) E I;: 3 04-2t-'8.5 t A'-2 IEEND F'i"~LJ/F(UN WRDF' 04-'2~-8'"~ t A- 3 ~"" " - ?-'~:J-> ~ I:,I-IF 04 t r ,. r... I A-4 ~'Ii~l--IP '04-t 9-85 i A-9; F:'Ii':U 04-;2 t -'85 t A-5 F'ULL F'BU (~4-'22-85 t A-6 I::'BU 04-21 -85 I A-6 I'-IAN(.; (.]Fi: I')[]HB,S' FE)R F'BU F I N I S I"1 F' l:.~lJ RUN LYNE.S' I:;:ECOF~:Dr'ER.S~ F'LILL LYNES' I:(ECOF,:DE:F($ F'BU F' I;.~ t.! ,.'9 D H F:' $ B I"1F' RUN LYNES I:;;ECOI:::DEF~:,.Y RETRIFVF~ LYNE,~ i'",:ii"'C,(.]F;:DFi",:,2' R UN ,2'r:' I NN[."R/T EHF:'[.i:F(ATURE ,~'LJI~VEY--i_IEAK I)ET[-"C]' T ON i'-;:LJN I::'BU 5'LII:i:Vii.'Y I N,JI.'..'.CT I V I TY TF3'I' INJECTIVITY TEST IN,JECTION 'T'I:-':,.'gT/'A ' SAND T Ei-IF'ERATLJR[E/,.'gP ]: NNER--. LEAl( DETECTI[)N RUN LYNr-.'$ TANDEH l:'i:::E.'~',~'tJl:;:r--' BOHD$ F'OR PBU R E." T I:;: I EVE L Y N E,.'9 I:;: E C t] I:,,' D E R $ RUN LYNES' I-~:EC[.)i:(DI.'.].i:;:$ .... 'C' ,S'AND ONLY RETRIEVE i_YNIi[S I':,'F'C(]F;:DEF;;~ ACI(NOWLED[;ED: tA-6 t A-i 0 t A-t 6' i B-3 tB-3 t tC-4 tC-6 tC-6 tE"'4 1::-.5 E:-t6 I.:.':-t 6 E-27 t E-2'7 t I:-3 IF-5 t 1:"'- 9; F;:ECE ]' F'T BF'AE~' B, CUI:;~RIEF::'x' L., JOHNSTON C I"1E V I:;; 0 N .x. ~(- i'i 0 Ii-'. :i: !... D & H~ N..91( CI_EI:;:I( CAMCO CAMCO CAMCO CAMCO CAMCO . CAMCO CAHC[) CAHCO OTIS (.)4-2t -85: [)T I..~' 04-22-85 [)TIS (.)4 ,.t-85 CAHC[) "" "' "~ '~ ' '" ~ - Ill 5 ~-,- ~,.~ ,.~ CAMCO 0'1-2t -85 CAHCO 04-22-8"7 CAMCO 04-2~-'8.5 CA~4CO 04 -25-85 CAMCO 04-2t -'85 OTIS' (~4-'23-85 OTIS' .., _"~'"' o5 O t ,:,.,2 -,:, C A i't C ,34 -' 26 - 8 --:'~ C A M C 04-t 9-85 04-20-8"7 ARCO O 4-'"":- 8"i;,-.,:.. ARCO 04-2'7-85 OTI~S' 04-2t -85 0'¥ I .S' 84-23-85 0]" I $' ~) 4 -' 21 - S 5 0 T 15' 04 '",.~.- '~ ''~ 85 0'[ I $ DF;: ]: 1...I.. I NJ; W. PASi"IER EXXON · ~':' F:' I"11 L. I.. ]: I:"' 5' 0:11L · x-J. 1-';,:,':'.', T H H F L L ARCO Alaska, Inc. ' ~' Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Apri ! 4, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Attached are our notices of intention to reperforate Kuparuk field wel Is 1E-lA, 1E-4, 1F-16 and fracture 1E-lA, 1E-4, 1E-8, 1E-16, and 1E-27. If you have any questions, please call me at 263-4253. · ke L. Laue ~ ~ Kuparuk Operations Coordinator MLL/kmc Attachment (In Triplicate) RECEIVED Alaska 0ii & Gas Cons. commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany · "~' STATE OF ALASKA ALASKA'OlL AND GAS CONSERVATION CO,vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL E~ 2. Name of Operator ARCO ALASKA, INC. 3. Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 OTHER [] 4. Location of Well SURFACE LOCAT ! ON: 307 ' T11N, RIOE, UM FNL, 641' FEL, SEC. 21, 5. Elevation in feet (indicate KB, DF, etc.) 106 ' (RKB) 12. 7. Permit No. 82-163 8. APl Number 50- 029-20837 9. Unit or Lease Name KUPARUK R I VER UN I T 10. Well Number 1E-27 11. Field and Pool KUPARUK RIVER FIELD 6. Lease Designation and Serial No. KU PARUK R ! VER O I L ADL 25651, ALK 469 POOL Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [~ Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed that the "A" sand in Kuparuk well 1E-27 be hydraulically fractured and propped to improve production. The treatment uses gelled water as the pad and carrying fluid and sand as the proppant. Gelled diesel will be used as a flush. 20/40 Lines and equipment will be pressure tested to 5000 psi prior to starting the job. Pre-post frac logs are included in the treatment program. Fluid' Gel.led water 247 BBLS Gelled diesel 65 LBS Proppant: 20/40 sand 13,902 LBS ANTICIPATED START DATE: APRIL 11, 1985 o. o./o-q-o3 Dated _~_//_~/..~ff" RECEIVED APR 4 985 Alaska 0ii & Gas C~,~s ~;.,..,~.ss,ur, Ancho~;~j,~ 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sig ~ ~'~~~Title OPERATIONS COORDINATOR The spa/ce/belo~v ~or Comgission u~ 4/4/85 Date Conditions of Approval, if any: Approved by Approvea Copy Returned j By Order of COMMISSIONER the Commission Date ... f Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, In~ Post Office oox 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 January 29, 1985 Mr. C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Dear Mr. Subsequent Sundry Reports - Various Wells Chatterton- Enclosed are Subsequent Sundry Reports for the following wells: 1E-3 1E-6 1E-27 If you have any questions, please call me at 263-4944. Si ncerely, Gruber Associate Engineer JG/tw GRU3/L83 Encl osures RECEIVED F E B 0 1 1985 Alaska Oil & Gas Cons. Commission Anchorage ,kRe('l Al=gbJ~ Ine I_q ;J ~lJbsldiarv of AtlanlicRIchfleldCompany L , STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL OTHER [] 2. Nar~)l~ Operator Alaska, Inc. 3'Ad~r. es~b. Box 100360, Anchorage, AK 99510 4. LoCation of Well Surface: 307' FNL, 641' FEL, Sec.21, T11N, RIOE, UN 5. Elevation in feet (indicate KB, DF, etc.) 106' RKB 12. 7. Permit No. 82-163 8. APl Number 50-- 029-20837 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 1E-27 11. Field and Pool Kuparuk River Field I 6. Lease Designation and Serial No. Kuparuk River 0il Pool ADL 25651 ALK 469 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing '~ (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Accepted rig ~ 1930 hrs, 12/21/84. Killed well. ND tree. NU BOPE & tstd to 3000 psi - ok. Unable to shear SBR. RIH and cut tubing ~ 5944' (left 21' stub on top of SBR). POH and LD tbg hanger. Pulled compl, assy. Milled over stub. Jarred SBR loose. Spotted 35 bbls Bridge Sal pill to pkr - squeezed pill into perfs. POH w/SBR & tbg stub. Redress SBR w/retrieving tool and TIH to top of slick jt @ 5955'. POH & LD SBR & slick jr. Milled pkr ~ 5980'. Speared pkr & worked loose. Fished for pkr & recovered. Tstd csg to 3500 psi - ok. Set WD pkr @ 6214'. Ran 3-1/2" completion assy. Dropped ball & set pkr. ND BOPE. NU tree & tstd to 5000 psi - ok. Disp well w/diesel & crude oil. Tstd tbg to 2000 psi - ok. Set BPV. Secured well & released rig ~ 060C hrs, 12/30/84. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~w ~[J'P~/~L/ ~5~~ Title Associate Enqineer The space be for Commission use Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date__ Form 10-403 Rev. 7-1-80 UJ(U~/~N1 ~) Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Post Offi~ !ox 360 Anchorage, Alaska 9951 Telephone 907 277 5637 RET~ TO: Date: 12 / 12/84 Transmittal No: 4909 ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 ~/~chorage, AK 99510 . ' '~ransmitted herewith are the following-" items. Please acknowledge receipt and return one signed copy cf this transmittal. PB~ SURVEYS - Torque Turn ~'/2X-1 / ~/ 1F-1 v' 2Z-7 11/30- 12/02/84 6/08 - 6/09/84 12/02- 12/04/8A #64009 #63140 #63138 Otis ~ 2z-5 11/29/84 2C-8 11/26/84 z/~ 2X-5 11/27/84' Cm~nco /1E-19 11/10/84 1E-21 11/10/84 ~/1E-23 11/11/84 /1E-27 11/11/84 /cat Receipt Acknowledged: Date: DISTRIBUTION B. Currier Drilling W. Pasher State of AK BPAE Geolog-y G. Phillips Sohio Chevron Mobil Phillips Oil Union D & M NSK Op.s. J. Rathmell Well Files STATE Of ALASKA ALASKA 0IL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well COMPLETED WE LLxI~ 7. Permit No. 82-163 8. APl Number 50- 029-20{]~7 9. Unit or Lease Name OTHER [] Surface: 307' FNL, 641' FEL, Sec.21, TllN, RIOE, UM Kuparuk River IIn{~ 10. Well Number 1 E-27 11. Field and Pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool RKB 106' I ADL 25651 ALK 12. Check Appropriate BOx To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate ~ Abandon [] Stimulation [] Abandonment' [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing ~ Other ~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonmentsee20 AAC 25.105-170). ARCO Alaska, Inc., proposes to convert well 1E-27 to a selective single completion. follows: The procedure will be as 1. Well will be killed with brine. Weight to be determined after running pressure bomb. 2. Current completion assembly will be pulled. 3. The well will be completed as a selective single and 5000# wellhead equipment will be installed. 4. After the rig is released, an acid and/or frac job will be done. A 13-5/8", 5000 psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost intb~val. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated Start: December 27, 1984 RECEIVED DEC 0 5 1984 Alaska 0il & Gas Cons. O0mmissJ0n Anchorage Date 14. I hereby cer/~ that the foregoing is true and correct t° the best of my knowledge. // Signed J/~,~,'/"~ -( '~" ~~/~ Title, Area Dri l ]ing Engineer The space fo sion use Approv~a t - Conditio~of Appr~f any: E~tur~ /' . ~ . , ~. Approved by Form 10~,03 BY iI&ItRY W, i(IIGLER By Order of COMMISSIONER the Commission Submit "Intentions" in Triplicate Rev. 7-1-80 SN/001 and "Subsequent Reports" in Duplicate ARCO Alaska, I~-''''~ Post Offic,. Jbx 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 9, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: 1E-27 Dear Mr. Chatterton: Enclosed convert 1 Si nce we earliest questions is a Sundry Notice for the subject well. We propose to E-27 to a selective single completion. expect to start this work on October 15, 1984, your approval will be appreciated. If you have any , please call me at 263-4970. Sincerely, J. B. Kew in Area Dril ling Engineer JBK/JG/tw GRU1/L79 Enclosures RECEIVED OCT O ]984 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany '"'":-" STATE OF ALASKA '-"'"~"~ ALASKA OIL AND GAS CONSERVATION L;OMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of Well Surface: 307' FNL, 641' FEL, 5ec.21, T11N, R10E, UN 5. Elevation in feet (indicate KB, DF, etc.) RKB 106' OTHER [] COMPLETED WELLx~ 7. Permit No. 82-163 8. APl Number 50-- 029-20R_~7 9. Unit or Lease Name Kupa,':,k R~,:er Un,."t 10. Well Number !F-_77 11. Field and Pool Kuparuk River Field 6. Lease Designation and Serial No. Kuparuk River 0i 1 Pool AD~ ~5_~! ALK 469 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate ~ Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] 12. Other ~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any .proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc., proposes to convert well 1E-27 to a selective single completion. fol 1 ows: The procedure will be as 1. Well will be killed with brine. Weight to be determined after running pressure bomb. 2. Current completion assembly will be pulled. 3. A retrievable packer will be run to test for zone isolation between the A and C sand, and to test casing integrity. 4. The well will be completed as a selective single and 5000# wellhead equipment will be installed. 5. After the rig is released, an acid and/or frac job will be done. A 13-5/8", 5000~psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uneemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated Start: October 15, 1984 14. I hereby certify that/}the foregoing is true and correct to the best of my knowledge. Signed ~, Z,~.~__,~~/I' ~.~ ~r'~ Title Area Drilling Engineer The space below for Commission use Conditions of Approval, if any: 6~il~l#tL Stgtl£g LON~tl[ C. SBITI! · Approved by Approved Copy Returr~, By Order of COMMISSIONER the Commission RECEIVED OCT1 o 1984 Alaska 0il & Gas Cons. commission Date /~/~ /~Y ! · Submit "Intentions" in Triplicate Form 10-403 Rev. 7-1-80 GRU1/SN69 and "Subsequent Reports" in Duplicate KUPARUK ENGIHEERING TRANSHITTAL # ~ ~3 TO' ~ FROM: / · D~TE' / / ~ WELL NANE' / - Transmitted herewith are the following' D. Fay Allison see below PLEASE NOTE' BL - BLUELINE, S - SEPIA, F - FILM, T - TAPE, PC - PHOTOCOPY Well Description Date Run · ' / tm P,~PT ACKNOWLEDGED' PLEASERETURN RECEIPT TO' ARCO ALASKA, INC. DATE' ATTN' D. FAY ALLISON - ATO/1115-B P. O. BOX 100360 ANCHORAGE, AK. 99510 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COiv,,vllSSlON SUNDRY NOTI'CES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. ARCO ALASKA, INC. 82-163 3. Address 8. APl Number P. O. BOX 360, ANCHORAGE, ALASKA 99[;10 50-029-20837 OTHER [] 4. Location of Well SURFACE LOCATION' 307' T11N, R10E, UM FSL, 641' FEL, SEC. 21, BOTTOM HOLE LOCATION' 119' FSL, 1243' FEL, SEC. 16, T11N, R10E, UM (PRELIMINARY]) 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 106' (KB) I ADI 25651 12. 9. Unit or Lease Name KUPARUK RIVER UNIT 10, Well Number 1E-27 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOl Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation ~ Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On January 4, 1983, Kuparuk River Unit Well 1E-27 was stimulated with 86 bbls of 15% HC1 through coiled tubing. All surface lines and BOP's were pressure tested to 4000 psig. The maximum coiled tubing pressure observed was 900 psig and the maximum tubing pressure was 1600 psig. 82 MCF of nitrogen were injected via the coiled tubing to aid in cleanup. Following the cleanup period the well was switched to the CPF. The post-acid well test showed this well producing 1600 BOPD as compared to the pre-acid rate of 900 BOPD. MAY 0 ,5 1983 Alaska 0ii ,2 Gas Cons. CommJs~,lo~ Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed _ ~"- Title OPERATIONS The space below for Commission use COORDINATOR Date Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate KUPARUK ENGINEERING TRANSMITTAL =~__~ TO: Wi'lliam Van Allen 'FROM: D. W. Bose/Shelby J. Matthews Transmitted. herewith are the following- . , PLEASE NOTE' BL - BLUELINE, S - SEPIA, F - FILM, T -.'TAPE,(~ DATE' . . ;'. ARCO ALASKA, INC. ATTN' SHELBY J. MATTHEWS - AFA/311 · P O. BOX 360 ANCHORAGE, AK. 99510 FARCO'Alaska, I nc.~,..~.: Post Office:~ 360 Anchorage, A~as~ka 99510 Telephone 907 277 5637 November 23, 1982 Mr.' C. V. Chatterton Commi s s i one r State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Dear Mr. Enclosed following wells' 1E-26 1E-27 1F-8 If you have any Sincerely, p. ^. Yah Dusen D~strict Drillin§ P^¥/dG'sm Inclosures ~RU2/L45 Well Completion Reports Chatterton- are completion reports and questions,· please Engineer gyroscopic surveys for the call JoAnn Gruber at 263-4944. RECEIVED DEC 0 9 I982 Alaska 0il & Gas Cons. COmmlssior) Anchorage ARCO Alaska, Inc. is a subsidiary of AllanticRichfteldCompany ~ .. STATE OF ALASKA ALASKA ~'~.~ AND GAS CONSERVATION CG ~ MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG __ 1. Status of Well Classification of Service Well OILX~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 82-163 3. Address 8. APl Number P. 0. Box 360, Anchorage, AK 99510 50- 029-20837 4. Location of well at surface 9. Unit or Lease Name 307' FNL, 641' FEL, Sec. 21, TllN, R10E, UM Kuparuk River Unit At Top Producing Interval LOCATIONS; 10. Well Number 99' FNL, 1038' FEL, Sec. 21, TllN, R10E, UN VERIFIED 1E-27 At Total Depth Surf. .F-. i 11. Field and Pool 119' FSL, 1243' FEL, Sec. 16, TllN, R10E, UM B.H. ~-- -I Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Seri'al No. Kuparuk River 0i 1 Pool I 106' RKBIADL 25651, ALK 469 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 10/07/82 10/14/82 10/19/82 N/A feet MSLI 1 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurvey I 20. Depth where SSSV set I 21. Thickness of Permafr°st 6800'MD,6639'TVD ~624'MD,6483'TVD YES ~[] NO [] 1907' feet MD 1450' (approx) 22. Type Electric or Other Logs Run D IL/SFL/GR/Cal/FDC/CNL, BGT, RFT, CBL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 - Surf 78' 24" 272 sx AS II 10-3/4" 45.5# K-55 Surf 2218' 13-1/2" 1500 sx AS Ill & 250 sx AlS I 7" 26.0# K-55 Surf 6715' 8-3/4" 635 sx Class G & 250 sx IS I 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 6390'-6394' 6177'-6167' 3-1/2" 6047' 5989' 6330'-6340' 6132'-6147' 6177'-6185' 6122'-6132' 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. 6367'-6382' DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 6357 ' -6367' 6147 ' -6157 ' N/A , . ., 27. N/A PRODUCTION TEST Date First Producti°n ~' I Method of Operation (FloWing, gas lift; etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER~BBL CHOKE SIZE IGAS'OILRATIO ' · - -TEST PERIOD ~ I Flow Tubing Casing Pressure . CALCUEATED I~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ .- * ' 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None - .. R CEIVED DEC 0 9 ]982 Alaska 0il & Gas Cons. Commission Anchorage Form 10-407 Rev. 7-1-80 GRU1/WC20 CONTINUED ON REVERSE SIDE Submit in duplicate GEOLOGIC MARKERS NAME MEAS. DEPTH TRUE VERT. DEPTH Top Upper Sand 6123' 6032' Base Upper Sand 6184' 6088' Top Lower Sand 6317' 6208' Base Lower Sand 6435' 6314' 30. N/A FORMATION TESTS nclude interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 3t LIST OF ATTACHMENTS Drilling Hi_story, Gyroscopic Survey (2 copies) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Title Sr. Drilling Engineer Date INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. .. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none" 1E-27 DRILLING HISTORY NU Hydril & diverter. Spudded well @ 1930 hrs, 10/07/82. Drld 13-1/2" hole to 2238'. Ran 55 jts 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe @ 2218'. Cmtd 10-3/4" csg w/1500 sx AS III & 250 sx AS I. ND Hydril & diverter. Instd 10-3/4" packoff & tstd to 2000 psi - ok. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC, cmt, FS & 10' new form. Tstd form. to 12.5 ppg EMW. Drld 8-3/4" hole to 6800' TD (10/14/82). Ran DIL/SFL/SP/GR/Cal/FDC/CNL. Ran BGT & RFT. Ran 169 jts 7", 26#/ft, K-55, BTC csg w/shoe @ 6715'. Cmtd .7" csg w/635 sx Class G. Instld 7" packoff & tstd to 3000 psi - ok. Ran Gyro. Ran CBL - good bond. Perf'd 6390'-6394'; 6330'-6340'; 6177'-6185'; 6367'-6382'; 6357'-6367'; 6147'-6157'; 6177'-6167'; 6132'-6147' & 6122'-6132'. Ran 3-1/2" completion assy w/tail @ 6047' & pkr @ 5989'. Tstd tbg hanger & packoff to 3000 psi - ok. ND BOPE. NU tree & tstd to 2000 psi. Disp well w/diesel. Dropped ball. Closed SSSV @ 1907'. Set BPV. Secured well & released rig @ 0600 hrs, 10/19/82. JG'llm 11/15/82 GRU2/DH29 DEC 0 9 ]982 Alaska Oil & Gas Cons. Commission Anchorage COMPLETION REPORT 18 . ARCO ALASKA, INC KUPARUK GYROSCOPIC SURVEY KB ELEV. RADIUS OF CURVATURE METHOD OF COMPUTATION COMPUTED FOR SDI BY OCEANTECH(FM LINDSEY & ASSOC,) dOB NO. RECORD OF SURVEY TRUE MEAS. DRIFT VERTICAL SUB DRIFT DEPTH ANGLE DEPTH SEA DIREC D M DEG. TOTAL COORDINATES 82 !-E-27 ~ 104;.00 FT, C L 0 S U R E S SEVERITY STANCE ANGLE DEG/1 08FT 0 0 0 100 0 5 200 0 4 30,0 O 6 4 0:0 0 5 500 0 8 600 0 22 200 0 27 8 O0 0 39 900 0 33 ! O'O'O O 39 1100 0 46 12'00 0 52 1300 1 5 1400 I 7 1500 0 41 1.600 O. 20 1 ?00 0 2t 1800 0 26 1900 0 40 2000 0 43 21 O0 0 48 2200 0 47 2300 O. 37 24:00 0 47 ,00 100,00 200,00 300,00 400 O0 500 O0 600 O0 700 O0 799 99 ~99 99 999.98 1 099,97 1199.96 1299.95 1399,93 1499.92 1599,91 S699.91 1799.91 1899.90 }999.98 2099.89 2199,88 2299.87 2399.86 -106,00 N ,OOE -6,00 N48,68E 94,00 829,48E 194,00 S24.13E 294,00 817,48E :394,00 S 7,67W 494,00 594,00 S61;80W 693.99 HS2,i2id .793.99. N76,60W · 893.98 Ne2, ' 993,97 S74 $ 893,96 S7 1193.95 961.72id 1293,93 S72.S7id 1393,92 S53.42~ 1493,91 $44.33W 1593.91 SS7,75W 1693.91 S53,63W 1793.90 S56,60W 1893,90 S38,15W 1993.89 S21,08B 2093,88 S 9,33~ 2193.~7 S18.88E 2293.'86 S38.35E ,00 S , O0 W .00 .06 N .03 E .07 ,05 N .14 E ,08 S .21 E .22 ,23 8 ,26 E .35 5 1 1,07 $ 4,72 ~ 4,84 1.49 8. 6.08 W 6.26 2,16 S 7,64 W 7,94 2.9~ S 9.40 W 9.84 3,62 S 10.80 W 11,39 4,20 S 11.46 U 12.21 4.58 8 I1 ,93 g 12.78 4.96 S 12.49 ~ 13.44 5.51 S 13,2~ W 14.3S 6.32 8 14.16 Id 15.51 7.47 S 14.82 ~ 16.59 8.80 S 15,18 U 17,54 1-O,Oi S 15,08 ~ 18,10 11,07 S 14,49 U 18.24 S 90 0 0 W ,00'0 N 24 20 29 E ,083 N 72 19 0 E ,017 S 67 49 11 E ,033 S 48 27 56 E ,017 S 33 39 23 E .050 S 5 3,~ 9 E .233 S 22 47 17 W ,083 8 46 i9 55 Id ,200 S 64 28 38 W .100 $ 74 16 57 Id .100 $ 77 .14 20 Iii .117 S 76 13 44 W ,100 $ 74 10 36 W ,217 S 72 48 36 W ,034 S 71 28 7 W ,433 S 69 52 14 W ,350 S 69 0 34 W ,017 S 68 20 18 W ,083 S 67 27 48 W ,233 S 65 56 18 W .050 S 63 14 25 U ,083 S 59 53 22 W ;017 S 56 25 34 W .167 S 52 37 7 Id .167 SECTION DISTANCE .00 01 - 09 - 22 - 35 - 47 - 52. - 1.33 2 3.23 4.10 4.99 6,00 6,72 6.93 7,09 7.33 7.66 7.91 7,78 7,31 6.53 5.44 ARCO KUPARUK GYROSCOPIC SURVEY NO. 28'13' lB'NOV. 82 RECORD OF SURVEY HEAS, DRIFT DEPTH'ANGLE D H 2500 26 O0 I ? 270:0 I 23 280'0 J 28 2900 30 O0 I 32 3100 I 32 3200 1 39 3300 3400 .3500 I 38 3600 37'00 1 33 3800 1 29 39O0 I 20 4000 1 22 4100 1 25 4200 4300 I 15 4400 1 15 4500 I 4600 4 47 47O0 8 22 4800 11 32 4900 14 11 500O 17 32 5100 19 58 5200 21 10 5300 21 20 TRUE VERTICAL &EPTN 2499,85 2599,83 2699,8i 2799,78 2899,74 2999. ? 0 3099,66 3199,62 3299,58 3399,55 3499,51 3599,47 3699.44 3799,40 3899,37 3999.34 4099,31 4199,29 4299,26 4399,24 4499,22 4599,07 4698.40 4796.88 4894,37 4990.55 5085.23 5178.86 5272,06 SUB SEA 2393,$5 2493,83 2593.8i 2693;79 2793.'74 2893.70 2993,66 3093,62 3193,58 3293.55 3393.51 3493,47 3593,44 3693,40 3793,37 3093.34 3993.31 4093,29 4193,26 4293,24 4393,22 4493,07 4592,48 4690.88 4788,37 4884,55 4979.23 5072,86 5166.06 DRIFT DIREC DEG. S61.27E 867.43E 864.70E' S65.95E 868.45E S63.28E S62.00E S58,30E S56,62E S52,67E SSO.OOE SS6.OTE S47,45E S48,20E S46,57E S46,7?E S39,25E 838,55E S41,43E 838.68E 863.28W 880,07W 881,05W N88,97W N75,85W N68,47W NS6,80W NS3,4JW NS?,83W TOTAL COORDINATES CLOSURES D I STANCE ANGLE D H DOG LEG SEVERITY DEG?IOOFT 12,15 S 13,00 S 14,92 S 15.98 S 17.13 S le.~6 s 22,83'~: 24,54 26, les 27.82 S 29.60 S 31,26 S 32.88 S 34.65 S 36.47 S 38,16 S 39,83 S 41,51 S 43. lO S 44,98 8 46.17 8 43,23 S 34.87 S 20.12 S ,03 S 20,42 H 13,23 W 17,96 S 47 26 4 W 11,46 W 17,32 S 41 23 4S W 9,46 W 16,80 S 34 t6 54 W 7,20 W .16,57 8 25 46 13 W 4,67 W '16,65 S 16 16 59 W 2.11 W 17.26 S 7 0 59 W .27 E i8,36 S 0 50 li E 2.68 E 19.92 S 7 43 16 E 26,28 S 20 58 13 E 28,64 S 23 55 16 E 31.02 S 2~; 15 27 E 15.68 E 33,50 S 27 55 20 E 17,49 E 35.82 S 29 13 55 E 19.21 E 38.00 S 30 17 39 E 20.86 E 40.45 S 31 3 3 E 22,33 E 42,77 S 31 25 45 E 23.74 E 44,94 S 31 53 37 E 25,15 E 47,10 S .32 16 14 E 24.78 E 48.35 $ 30 50 2 E 20,00 E 47.51 S 24 53 21 E 8,70 E 45.81 $ 10 57 1 E 8.51 W 46,94 S 10 26 46 W 30.52 W 52.92 S 35 13 12 W 56.51 W 66,40 S 58 19 29 W 85,01 W 87,35 S 76 41 4 W 113,82 W 113.82 S 89 59 4 W 143.73 W t45.17 N 81 54 45 bi ,350 ,017 ,267 ,083 ,217 ,150 ,034 ,117 ,067 ,067 .117 ,,117 ,034 ,067 ,150 · 033 · 050 ,150 .017 ,060 .236 3,768 3,583 3,192 2.765 3.416 2.788 I .278 ,606 SECTZON DISTANCE 3,78 1 -,29 -2.74 -5 -8.i7 -10,82 -13,59 -16 ..40 -19,11 -21 .85 -24,68 -27,27 -29.90 -32.33 -34.67 -37,04 -39.30 -41 ,42 -43,53 -44.20 -41 ,21 -33,08 -19,71 -. 05 26. O0 92.90 129.13 1 GYROSCOPIC SURVEY 0 JO8 NO, 2813 · 18 NOV. S2 RECORD Of SURVEY TRUE NEAS. DRIFT VERTICAL SUB .DEPTH ANGLE DEPTH SEA D M DRIFT DIREC DEG, 54'00 21 42 5,365,09 5259.09 N55 55-00 22 29 5457.75 5351.75 N54 5600 22 30 5550.14 5444,14 N54 5700 22 19 5642,59 5536.59 N53 5800 22 29 5735,04 5629,04 N54 590'0 22 59 5827,27 5721,27 N52 6000 23 10 5919,27 5813127 NS1 6100 2.3 47 6011.00 5905~00 N48 6200 25 0 61 02.07 5996,07 N47 6300 25 25 6192.54 6086,54 N45 64'00 25 57 6282.66 6176.66 H45 6500 26 49 6372.25 6266.25 N41 6550 27 12 6416.79 6310,79 N40 ,98W · 58W ,2.OW ,73W ,07W .55W · 58W ,22W ,37W ,98W .23W .75W ,12W THE FOLLOWING IS EXTRAPOLATED TO TD 6800 27 12 6639,!5 65.33,15 H40.12W TOTAL COORDINATES CLOSURES DISTANCE ANGLE D M DOG LEG SEVERITY DEG/IOOFT 40,45 N 174.45 61,87 N 205,37 84,14 N 236,47 106.56 N 267.30 129.02 H 298.09 152,11 N 329,07 176.20 N 359.99 201,95 N 390,45 179.08 N 76 56 47 W 214.48 N 73 1'4 7 W 250,99 N 70 24 49 W 287.76 N 68 15 51 W 324,81 N 66 35 46 W 362.53 H 65 11 32 W 400,.79 N 63 55 11 W 439,54 N 62 :39 43 W 479,57 N 61 23 44 W 52.o.ee N u 605'83 N 57 57 47 W ,445 ,SlO ,859 ,195 ,174 ,551 .237 1,226 .488 ,552 1,120 1.026 425,91 N 602,08 W 737.50 N 54 4.3 27 W .000 SECTIOH DISTANCE 165.7~ 203.39 241,64 279.76 317,86 356.49 395.64 435,33 476.32 , 518.50 561 .29 604.87 626.92 737.50 BOTTOM HOLE CLOSURE 737,50 FEET AT N 54 43 27 W ARCO KUPARUK 1-E-27' GYROSCOPIC SURVEY OB NO, 2813 MEASURED DEPTH A)4D OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, 82 TRUE MEASURED VERTICAL ~UB HD-TVD. VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 0 206 306 406 506 606 7 06 ,806 906 · 1 ~:006 1106 1206 1306 1406 1506 1606 1706 1806 1906 2'006 21 06 2206 2306 2406 2506 2606 2706 2806 2906 3.006 31 06 3206 3306 3406 3506 0 2O6 306 4 06 606 706 8O6 906 1006 1106, 1206, 1306, 1406, 1506, 1606, 1706. 1806, 1906, 2006, 2106, 2206, 2306. 2406. 2506. 2606, 2706. 2006. 2906, 3006. 320~. 3306, 3406, 3506, -'t 06 0 100 0 200 0 300 0 400 0 500 0 600 0 700 0 800 0 900 0 1000 0 1100 0 1200 0 1300 0 1400 0 1500 0 1600 0 1700 0 1800 0 1900 0 2000 0 2100 0 2200 0 2300 0 2400 0 2500 0 2600 '0 2700 0 2800 0 2900 0 3000 0 3100 0 3200 0 3300 0 3400 0 .00 .04 ,09 ,24 ,44 1.22 1.36 1.16 ,97 1.09 52 22 95 23 60 0 5,55 0 6.38 0 7,55 0 8,88 0 10.07 0 1'1.14 0 12,20 0 13.04 0 13,94 0 14,98 0 1~,. 05 0 17.21 0 18.44 0 19,84 0 21,36 0 22.93 0 24 ,00 W .15 E .21 E .27 E .28 E ,05 E ,55 W I, 50 W 2,52 W 3.56 W 4,79 W 6.17 W 7,74 W 9.52 W 10,85 W 11,49 W 11.96 W 12.53 W 13.34 W 14.21 W 14~85 G! 15.19 W 15,05 W 14,44 W 13.12 W 11.34 W 9,:33 W 7.06 W 4,50 W 1.96 U .42 E 2.83 E 5,20 E 7.40 E 9.55 E ~RCO KUPRRUK 1-E-27 GYROSCOPIC SURVEY JOB NO. 2813 IIEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, NOV. 82 TRUE MEASURED VERTICAL SUB HD-TYD VERTICAL DEPTH DEPTH SER DIFFERENCE CORRECTION TOTAL COORDINATES 3607 3707 3807 3907' 4007 41 07 42 07 4307 4407 4507 4607 4.7 08 4809 4912 5016 5122 5229 5336 5444 5552 5660 5769 5877 5986 6095 6204 6315 6426 6538 6650 6763 6800 3606, 3706, 3806, 3906, 4006. 4 ! 06. 4206, 4306, 4406, 4506, 4706 4806 4906 5006 51 O6 5206 5306, 5406. 5506. 5606. 5706, 5806, 5906, 6006. 61 06. 6206. 6506, 6406. 6.506. 6606. 6639. 3500 0 3600 0 3700 0 3800 0 3900 0 400O 0 4100 0 4200 0 4300 0 4400 0 4500 0 4600 1 4700 3 4800 4900 10 5000 16 5100 23 5200 30 5300 38 5400 46 5500 54 5600 62 5700 70 5800 79 5900 88 6000 98 6100 108 6200 119 6300 131. 6400 144 6500 156 6533 160 8 49,71 8 73.47 8 97.68 8 121.97 8 146,66 9 172.68 9 200,39 I0 230,84 I0 263.28 11 297,24 12 334.31 13 373.58 12 412,89 4 425,91 $ S S S S $ $ S S S S S ..S S N N N N N N N N N N N N N N N N 1i.76 E 13,95 E 1.5,81 E 17,61 E 19,,7,2 E 20,97 E 22,43 E · 23.84 E 25,23 E 24,66 E 19,41 E 7;58 E 10,40 W 33.41 W 61.08 W 91,34 W 122,34 W 154.96 W 188.02 W 221,63 W 255.15 W 288,38 W 321 . 92 W 355.54 W 388.81 W 422.39 W 456.63 W 491 , 03 ld 524.87 W 557.99 W 591.10 W 602.08 W ARCO KUPARUK 1-E-27 6YRO$COPIC SURVEY JOB NO. NOV, 82 IN?ERPOLATED YALUES FOR EVEN 1000 FEET OF MEASURED DEPTH', TRUE MEASURED VERTICAL SUB DEPTH DEPTH SEA TOTAL COORDIHATES 0 O, -'106. tO00 1000. 894. 200'0 2000, 1894, 3000 3000, 2894, 4000 3999, 3893, 5000 4991, 48@5, 6000 5919. 5813. 6800 6639. 6533, ,'O0 6.32 17.13 32.88 34,87 176.20 425,9'1 ,00 W 3.49 W 14,16 W 2.il W 19.21 E 56.51 W 359.99 W 6 02.08 W ~RCO KUPARUK ~YROSCOPIC SURVEY O JOB NO, 2813 NOV. 82 INTERPOLATED TRUE VERTICAL DEPTHS, COORDINATES AND CLOSURES FOR GIVEN DEPTHS · TRUE CODE MEASURED VERTICAL NAME DEPTH DEPTH TOTAL COORDINATES C L 0 S U R E SUB D I STANCE ANGLE SEA D M S TP UP SAND 6123 6032.02 208.08 N 397.40 W BS UP SAND 6184 r6087.56 225.04 N 416,'08 W TP LO SAND 6317 -6207.89 263.90 N 457.27 W BS LO SAND 6435 6314,10 3:00.1.0 N 493.81 W PBTD 6624 6482.61 364.39 N ~50,24 W' T,D, 6800 6639,15 425.91 N 602.08 W 448.58 N 62 2.1 46 W 5926,02 473.04 N 61 35 33 W 5981.56 527.96 H 60 0 34 W 6101.89 577.85 N 58 42 43 W 6208,10 659.96 H 56 29 9 W 6376,61 737.50 N 54 43 27 W 6533.15 ........................................................................................................................................ VERTICAL SECTION· .~' .... ARCO ALASKA, INC. : KUPARUK I- E - 27 .......................................................... RADIUS OF CURVATURE ...... ..... GYROSCOPIC'SURVEY SCALE: I" = *1000' : .___$.URFAC.E._LOCATION lS ._. NO,¥.: .. 18 , .I 982 ............................... $07r SNL~ 641~ WELi-SEC; 21 . . 8~ ....... -. . . , _ - ~ "I '~ ' ' HOR[ZONTtA E'-' VI EW ..................................' .............. ' - ..... ARCO !ALASKA i INC: KUPARUK I- E RADIUS-'- OF- CURVATURE ............. GYROSCOPIC :SURVEY .. ._ ' SCALE-= I. ~,----IOOO'-- - · ............... . : . .. _ . .., _.., -~ ........................ .: ...... ....... - . . :: ..... :. :.. _ :, .... = -: ......................... ' ... . : . . . . .. ........... ~ -:--; ....... . ....... ~-_,_. ............... : ._: ................... . .... : · .... · .... .. . .. ,, ~ o,?.,:, ...... : .... ' '! .":: :- ' ' ..... :: ,. ~ "J ..... :"-: '!'.":';~ :'"-:"} ';':--::c1:. -i--~-')-~:'~- ...... - ......... '-'-: · : :-- --: ...... ',, ........... T.-tkN:,'R I0 E'J,U.M. '~ ........ . _ .. _ : .:_~- ..... : ~. :. ' "- -'-!-- :-:~-'i" .... ~- ' :-!- -TV~-:=:66-$9'i- ::-:'- -:'::--i ....... :: " ; " . ~ ...................... :-~: ........... ~ ...... ± ..... :'--TMD"=i6SOO'_'-~ .... i' ........ ~ .......... :--' is ..... .... :~'!-",- ' "" : · ..--:.-:~ :: :--} ::: ' i -:-' ':. i.'-- ~:' f '" ' '"-! .... "-' ......... '":? ..... '--~ ' ...... ; ..... "::~-~i!" "' " ~ : ' ,..~ :. ..... ' ..... :';_:_-: :L/:' 2::~::::_:::~-~ :, - . , : ........ : ............ · ,. .... ; _~. ..... - ·:... :... - . ..,. ..... ..._ _~ ~ .... . ~._.:.:- : -- :::'-..! :.:-: -- ~ ::.'-:--!. i-':- -: '--: : ::~:'::. . - .. - . . . . . _ '._ ._. - ................. ; . - :: ...... . -. _ ,.. ......... ....... : . . .,- . . . - _ __ . - . ' ~ . - - i' - - - ........... :-. . · ~.... , ...... .. . ............... . · . - ' t ALL -DEPTHS "SHowN' - ........ ... ~'.ARE'~"-T,~''-~-~'_~ ..... :'i_~:'..-i ~ ..-. -, .~ . ... .:-.._ . .- _ ...... ;:-- ,- ..... ; ; -_-:. .,- . .: . · _ - , . : .... . . _! . _. .... : ...... .. . . : ....... · Suggested form to be inserted in each "Active· well folder to check for timoly compliance w'J_~ our regulations. f '' 'Operato~, ~-i ~ame and Number !e ~ -~ Reports and Materials to be received by:. / / ~t -- Required Date Received Remarks ~ ,, Ccmpletion Report Yes /~- · - .. · _Samples :/LJ'3 --~'.~t _ , , / Registered Survey Plat Y~ ~ - - ' '" i ' ' Incl±nat2.on Survey -- - , ,, Directional Survey 'Ye3 --P [ --- , , Drill Stem Test Reports ,~,X.?.~.~ .,,/.,~ . , , , '~ .... ~ ~'~' _ _ ~,9~[~,~ ..... Prod~c~iOn Test Reports X/.~_~ I~-:?-F~ : ' ' ,, Digitized Data , . ~/q~"-~ tt---:~[-- ~7-. :' !~' , · , , TO: William VanAlen ., Transmitted herewith are the following: D. W. Bose/Lorie L. Johnson PT.WASE NOTE: BL_ BLUELINE, S - SEPIA, F- FTTM, T- TAPE _ IF-t,, PLFASE RETtS~ RSEEIPT TO: ARCO ALASKA, INC. ATIN: LORIE L. JOHNSON P. O. BOX 360 ANCHORAGE, AK. 99510 ARCO Alaska, Inc. Post Office Be,.. 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Landon B. Kelly Kuparuk Operations Manager November 29, 1982 Mr. Chat Chatterton State of Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Chat' Attached are notices of our intent wells 1E-27, 1E-28, 1E-29 and 1E-30. If you have any questions, please call R. L. St ramp Kuparuk Operations Coordinator RLS/b Attachments xc' L. M. Sellers - ANO 332 E. A. Simonsen - AFA 331 H. C. Vickers - AFA 326 to acidize Kuparuk Unit me at 263-4528. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~-~ ALASKA ~,,L AND GAS CONSERVATION CO,wMISSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL~ OTHER [] 7. Permit No. 2' N~m~bOP/~S KA, INC. 82-163 3. Address 8. APl Number P. O. BOX 360, ANCHORAGE, ALASKA 99510 50_029-20837 9. Unit or Lease Name 641' SEC. KUPARUK RIVER UNIT 4. Location of Well SURFACE LOCATION' 307' FSL, FEL, 21, T11N, R10E, UM BOTTOM HOLE LOCATION' 119' FSL, 1243' FEL, SEC. 16, T11N, R10E, UM (PRELIMINARY) 5. Elevation in feet (indicate KB, DF, etc.) 106' (KB) 6. Lease Designation and Serial No. ADL 25651 10. Well Number 1E-27 11. Field and Pool KUPARUK RIVER FIELD KUPARUK RIVER OIL POOL 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [~ Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). ARCO Alaska, Inc. proposes to acidize Kuparuk River Unit Well 1E-27 through coiled tubing to improve the well's productivity. The initial production test on this well indicated a high skin factor and a corresponding low flow efficiency. Other Kuparuk wells with similar characteristics have ~hown marked improvements following acid treatments. The treatment will consist of 4032 gals of 12% HC1 with mud and silt remover additives. The coiled tubing unit BOP's will be pressure tested to 4000 psig. The end of the coiled tubing will be positioned initially just below the lowermost perforations and then pulled up across the perforations as the acid is pumped. Pump pressure will be limited to 4000 psig and the tubing pressure will be limited to 1500 psig. Following the acid treatment, nitrogen will be injected through the coiled tubing and aid the cleanup. During cleanup the well will be produced to tanks on location. Following the cleanup the well will be produced to CPF1. RECEIVED Expected start date' December 2, 1982.NOV29 ]982 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Alaska 0il & Gas Cons. C01~missi0n ~"'-"~ / ~~.L~ OPERATIoNsKUPARUK Anchorage Signed ~,v~ ~ ~.'~" ' "--'--J-- Title COORDINATOR Date The space Iow for Commission use :e ¢1_c Conditions of Approval, if any: Approved i~iop¥ Subsequent Work Iteportecl Returned ORIGINAL SIGNED / . By Order of Approved by BY LON~{~E C.SMITH COMMISSIONER the Commission Date .......... ~ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. ~' ' ~(~$t Office ~360 Anchorage,~ ~ka 99510 Telephone 9u~,277 5637 November 12. 1982 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commission 3001 pOrcupine Drive Anchorage, Alaska 99501 Subject: State Reports. Dear Mr. ChattertOn· Enclosed are monthly reports for October on these drill sites' 1-21 18-7 1-22 18-10 6L23' 1E-26 6-24 1E-27 7~15 1F-7. 13-14 1F-8 13-15 1G-4 WSW-4 WSW-5 WSW-6 Also enclosed are well completion reports for: 1-20 1G-2 6-22 1G-3 13-16 WSW-3 1E-30 The surVey for 2-22 needs to be reran; a completion report for this well will De submitted when an approved survey is received. We also are including subsequent Sundry Reports for 1-20 and 13-16. P. A. VanDusen. District Drilling Engineer PAV'JGOI'ltc Attachments ARCO Alaska, Inc. is a subsidiary of AttanticRichfieldCompeny i EEF ' VED NOV1 81982 /I/aska Oil & Gas Cons. Commission Anch0raga ~~., STATE OF ALASKA CO'-'~/IlSSiON ALASKA ( ~ AND GAS CONSERVATION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling wellX~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 82-163 3. Address 8. APl Number P. O. Box 360, Anchorage, AK 99510 50- 029-20837 9. Unit or Lease Name FEL~ 307~ FNL~ Sec. 21~ TllN~ R10E~ UM Kuparuk R~ver Unit 4. Location of Well 641 ' at surface 5. Elevation in feet (indicate KB, DF, etc.) 106' RKB 6. Lease Designation and Serial No. ADL 25651 ALK /+69 10. Well No. 1E-27 11. Field and Pool Kuparuk River Field Kuparuk River Oil Pool October 82 For the Month of. ,19__ 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks ' Spudded well ~ 1930 hfs, 10/07/82, Drld 13-1/2" hole to 2238'; ran, cmtd & tstd 10-3//+" csg, Drld 8-3//+" hole to 6800'; ran logs; ran, cmt, d & tstd 7" csg, Ran Cyro/CBL, Perf'd well, Ran 3-1/2" completion assy, Secured well & released rig (~ 0600 hfs, 10/19/82 SEE DRILLING HISTORY 13. Casing or liner run and quantities of cement, results of pressure tests 10-3/4" 45 5#/ft, K-55, BTC csg w/shoe ~ 2218' Cmtd w/1500 sx AS 7" 26 O#/ft, K-55, BTC csg w/shoe @ 6715' Cmtd w/635 sx Class G III & 250 sx AS I. SEE DRILLING HISTORY :14. Coringresumeandbriefdescription None 15. Logs run and depth where run DIL/SFL/GR/Cal/FDC/CNL BGT RFT CBL 16. DST data, perforating data, shows of HzS, miscellaneous data N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--R~port d for each calendar month, regardless of the status of opera~'ions, and must be filed in duplicate with the Alaska Oil and Gas Conservation Comm,~qon by the 15th of the succeeding month, unless otherwise directed. Form 10-404 ~ GRU2/MR26 Submit in dupticate 1E-27 DRILLING HISTORY NU Hydril & diverter. Spudded well @ 1930 hrs, 10/07/82. Drld 13-1/2" hole to 2238'. Ran 55 jts 10-3/4", 45.5#/ft, K-55, BTC csg w/shoe @ 2218'. Cmtd 10-3/4" csg w/1500 sx AS III & 250 sx AS I. ND Hydril & diverter. Instd 10-3/4" packoff & tstd to 2000 psi - ok.. NU BOPE & tstd to 3000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC, cmt, FS & 10' new form. Tstd form. to 12.5 ppg EMW. Drld 8-3/4" hole to 6800' TD (10/14/82). Ran DIL/SFL/SP/GR/Cal/FDC/CNL. Ran BGT & RFT. Ran 169 jts 7", 26#/ft, K-55, BTC csg w/shoe @ 6715'. Cmtd 7" csg w/635 sx Class G. Instld 7" packoff & tstd to 3000 psi - ok. Ran Gyro. Ran CBL - good bond. Perf'd 6390'-6394'; 6330'-6340'; 6177'-6185'; 6367'-6382'.; 6357'-6367'; 6147'-6157'; 6177'-6167'; 6132'-6147' & 6122'-6132'. Ran 3-1/2" completion assy w/tail @ 6047' & pkr @ 5989'. Tstd tbg hanger & packoff to 3000 psi - ok. ND BOPE. NU tree & tstd to 2000 psi. Disp well w/diesel. Dropped ball. Closed SSSV @ 1907'. Set BPV. Secured well & released rig @ 0600 hrs, 10/19/82. JG'llm 11/15/82 GRU2/DH29 TO:' William VanAlen , .D.W...,Bose/Lorie L. Johnson Transmitted herewith are ~he following: · . · · NOV 1 o ]982 R~CEI~ A~RrK~ED: , ~;~-'' DATE: ATTN: LORIE L. JOHNSON - AFA/311 P, O. BOX 360 ANCHO:~r::~GE, AK.. 99~10 · · . Alaska Oil & ~s Cons. Commission Anchorage TO:' William VanAlen FROM: D. W. Bose/Lorie L. Johnson Transmitted herewith are the following: PT.FASE NOTE: BL- BLUELINE, S- SEPIA, F- FIIM, ~PC- PHOTOCOPY / ~IPT A~,RDGED: - e VED' NO¥ 0 2 1§~ ARCO ALASKA, INC. ATIN: LORIE L. JOHNSON - AFA/311 P. O..,BOX 360 ANCHORAGE, AK. 99510 Anchorage M E M O R^~N D U M TO: TNRU: Stale of Alaska C. ~.~-'tt~,erton DATE: October 19 1982 Chai~n-%....- - . Lonnie C. Smith /~~"-~ FILE NO: 108A/C TELEPHONE NO: Commissioner SUBJECT: FROM: Edgar We Sipple, Jr. Petroleum Inspector · Witness BOPE Test on ARCO's Kuparuk 1E-27 Sec. 21, TllN, R10E, UM Permit No. 82-163 Rowan Rig 34 Saturday,_October 9, 1982 - I traveled this date from hhC=h6'r-age ~=~laSk~~ A~ines to Prudhoe Bay' to ARCO' s IE-27, Rowan Rig 34 to do a BOPE test. The test commenced at 10:45 a.m. and was concluded at 12:45 p.m., there' was one failure. The remote blind ram light, in the closed position would not light. An electrician checked out the problem and fixed the light. I filled out the A.O.G.C.C. BOPE report which is attached to this report. In summary, I did a BOPE test on ARCO's Kuparuk 1E-27, 'Rowan Drilling Rig 34. There was one failure, the remote blind ram light in the closed position would not light, it ~as fixed immediately. . ~ ' . Well /~:--' ~Y~ ~t ~ ~tion: Sec..~/ T/;~R/o~' MU~ ~~Casing Set'~. ~/~ ft. ~il linq ~n~a~or~~-~ R~_ ~ 3 ~ Repre~ntative ~ ~tion, ~neral ~.~ _ ~CCb~UIA~R SYS~ Well Si~ ~ /( ~11 Olarge ~es~rq ~ Ceneral }{o~(e~ing O_ {~ _ ~essure After Closure /~. 3~ psig Pese~e pit o ~ ~p ~cr. clos. pres. 200 psig__ / ~nl~ sec. ~g O ~, ~11 Cha~ Pressure Atta~: ~ ~n. /7.sec. -- ~ Sta~ Test ~es~e ~elly and Flor Safe~ Valves - ~u~., ~ven~ ~ 3.~ ~~ ~por ~<~ ~y~ ~ ~ ~t ~u~ ~lind ~s ~k .__~0oo' ~11 ~pe ~t% Test ~es~re H.C.R. Val~ _, ~ ~O~O Choke ~nifold Test ~essure ~0~ Kill ~e Val~s ~ _ Che~ Val~~~ _~_ ~Q.~ No. flanges ~ ~ Test Re~lts: Fail~es. ' ~ Test Ti~' ~. ~s.., f~epair or Replac~en~ off ffail~ ~uip~n~ [o ~ ~de wi~in-~ ~ys and j. - . I~~or/C~sion office notifi~. Di s~ut ion ~rig. - AO~C - CC- ~rator ~~/~ ~/ cc - su~sor hs~cto ..-. ~ ~_ October 1, 1982 Mr. J. B. Kew~n Senior Drilling ~ngineer ARCO Alaska, Ine. p.O. Box 360 Anchorage, Alask~ 99510 .Re= Kuparuk River Unit iE-27 ARCO Alaska, Inc. ~emit No. 82-165 Sure Loc. 641' FEL, 307' FNL~ Sec. 21, TllN, R10E, UM Btmhole ~o 1486' FEL, 75' FSL, Sec. 16, Tlln,' RIOE, UM Dear Mr. Kewin ~ Enclosed is the approved application for permit to drill the above referenced well. Well samples and a mud lo9 are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape coataining the digitized log information shall ~ submitted oa all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or m~gration of anadron~us fish. Operations in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title '5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's Office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by ~he Federal Water Pollution Control Aot, as amended. Prior to commencing o~rations you may be contacted by a representative of the Departmant of Environmental Conservation. To aid us in scheduling field ~ork, please notify this office 24 hours prior to commencing installation of the blowout preven- tion equi~ment so that a representative of the Commission ~y ~r. J. B. Kewtn ~upa ruk 1E-27 -2- October 1, 1982 be present to witness testing of the equipment before the surface casing shoe ie drilledo h~ere a diverter system is required, please also notify this office 24 hours 'prior to commencing eT~ipment installation so that the Cc~mission may witness test/ng before drilling below the shoe of the conductor In the event of suspension or abandonment, please gave this office ade~ate..advance notification so that we may have a wi the-ss present. Very truly yours, C. V. Chatterton Chairman of Alas~ Oil and ~s Conse~ton C~ssion Enclosure cc~ Department of Fi.sh & Game, ~abitat Section w/o encl. Department of Ena~_ronmental Conservation w/o eno1. CV¢/~ lh ARCO Alaska, Inc./'"~ Post Office 360 Anchorage, Alaska 99510 Telephone 907 277 5637 September 27, 1982 Mr. C. V. Chatterton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Kuparuk 1E-27 Dear Mr. Chatterton' Enclosed are- 0 If Sincerely, o An application for Permit to Drill Kuparuk 1E-27, along with a $100 application fee. o A diagram showing the proposed horizontal and vertical projections of the wellbore. o A proximity map indicating the relative location of Kuparuk wells 1E-lA, 1E-4, 1E-17, 1E-28, 1E-29, and 1E-30. o A discussion of wellbore crossings. o A diagram and description of the surface hole diverter system. o A diagram and description of the BOP equipment. A map showing the location of the well, as built. you have any questions, please call me at 263-4970. Senior Drilling Engineer JBK/JG:sm Enclosures GRU2/L1 RECEIVED SEP 0 1982 Alaska 011 & Gas Cons. Commission Anchorage ARCO Alaska, Inc. is a subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ~ ALASKA ~IL AND GAS CONSERVATION C,..,IMISSION RERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL ~]( DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC I-~ SINGLE ZONE [] MULTIPLE ZONE [] 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 360, Anchorage, Alaska 99510 4. Location of well at surface 641' FEL, 307' FNL, Sec. 21, TllN, R10E, UN At top of proposed producing interval 1246' FEL, 33' FNL, Sec. 21, TllN, RIOE,UM At total depth 1486' FEL, 75' FSL, Sec. 16, T11N, RIOE, UM 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. 72' PAD, 106' RKB ADL 25651 ALK 469 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 9. Unit or lease name Kuparuk River Unit 10. Well number 1E-27 11. Field and pool Kuparuk River Field Kuparuk River 0il Pool Amount $500,000 13. Distanceand directionfrom nearesttown 30 Miles NW Deadhorse miles 14. Distance to nearest property or lease line at total depth, 3794 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 6835'MD, 6609'TVD feet 2560 15. Distance to nearest drilling or completed E-lA well74 @ 2358' MD feet 18. Approximate spud date 10/06/82 2588 19. If deviated (see 20 AAC 25.050) 20. Anticipated pressures KICK OFF POINT4500 feet. MAXIMUM HOLE ANGLE 30° o (see 20 AAC 25.035 (c) (2) 2945 21 Proposed Casing, Liner and Cementing Program SETTING DEPTH QUANTITY OF CEMENT psig@_~_0° F Surface .. psig@ _6156 ft. TD (TVD) SIZE Hole Casing Weight 74" 16" 65# 13-1/2" 10-3/4" 45.5# 8-3/4" 7" 26# 22. Describe proposed program CASING AND LINER Length Grade Coupling H-40 We1 dad 80' K-55 IBTC I 2167' K-55 IBTC I 6804'_ MD TOP 35' I 33' I 31' TVD 35' 115' I 33' 2200' I1 31' MD BOTTOM TVD 115' 2200' 6835' 16609' I I (include stage data) 250 cf, 1100sx AS III + 2505x AS II 6205x Class "G" ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approx. 6835' MD, (6609'TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. A 13-5/8", 5000 psi, RSRRA BOPE stack will be installed on the 10-3/4" surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig (1800 psi for annular). Maximum expected surface pressure is 2588 psig. Pressure calculations are based on current reservoir pressure. Surface pressure calculated with unexpanded gas bubble at surface including temperature effects. The well will be completed with 3-1/2", 9.2#, J-55 buttress tbg. Non-freezing fluids will be left in uncemented annuli through the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safl ECa ,f¥ 'Obe installed and tested upon completion of the job. · 23 I hereby certify that the foregoing is true and correct to the best of my knowledge ~,J~.l SIGNED TITLE Sen~ or Dr~ ]-~q~ -~ngl n~b~ . The space bTw fr~o~ission u~ .......... CONDITIONS OF APPROVAL Samples required [] YES Permit number APPROVED BY Form 10~,01 Mud log required [-]YES ,~NO ~ ] Approv~¥~date GRU2/PD1 Directional Survey required [ APl number ~_ES []NO I 50- o'/. ~-~.~ ~.T? SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSl ONER DATE /O~~ by order of the Commission Submit in triplicate SEP ~ o 1982 · Alaska 0il & (~as Cons. CcmmJssion Anchorage ANALYSIS OF 1E-27/1E-28, 1E-27/1E-29 AND 1E-27/1E-1A WELL CROSSINGS NOTE: Refer to the attached Proximity'Map 1E-27/1E-28 The proposed Well 1E-27 will cross the proposed Well 1E-28 by a dis- tance of 75' at a measured depth of 1590'. This distance was calculat- ed using the proposed well-path data for 1E-28 and assuming that Well 1E-27 will be drilled vertically to its kick-off depth of 4500'. Well 1E-28 will have an ellipse of uncertainty of 44' across its major axis at the depth at which the crossing occurs. Well 1E-27 will have a cone of uncertainty of 12' in diameter at the depth of interest. The areas of uncertainty for the two wells will therefore not intersect. 1E-27/1E-29 The proposed Well 1E-27 will cross the existing Well 1E-29 by a dis- tance of 87' at .a measured depth of 2~1~24~' This distance was calculat- ed using the single-shot surveys on.-6- 9' and assuming that Well 1E-27 will be drilled vertically to its kick-off depth of 4500'. Well 1E-29 has an ellipse of uncertainty of 82' across its major axis at the depth at which the crossing occurs. Well 1E-27 will have a cone of uncertainty 16' in diameter at the depth of interest. The areas of uncertainty for the two wells will therefore not intersect. 1E-27/1E-1A The proposed Well 1E-27 will cross the existing Well 1E-lA by a dis- tance of 74' at a measured depth of 2358'. This distance was calculat- ed using the gyro multi-shot survey on 1E-lA and assuming that Well 1E-27 will be drilled vertically to its kick-off depth of 4500'. Well 1E-lA has an ellipse of uncertainty of 120' across its major axis at the depth at which the crossing occurs. Well 1E-27 will have a cone of uncertainty 16' in diameter at the depth of interest. The areas of uncertainty for the two wells will therefore not intersect. ARCO proposes that the following procedures be used to drill 1E-27 safely past the above crossings. . The 13-1/2" surface hole will be surveyed to its total depth (2200'). The 8-3/4" straight hole will be surveyed to at least 2400'. . The following will be done if calculations show that intersections of 28', 49', and 68' or less are to occur with Wells 1E-28, 1E-29, and 1E-lA, respectively. These distances correspond to the intersections of the areas of uncertainty. Ae A jetting assembly will be run approximately 300' above the crossing depth to impart a small angle (3°+) in the appropri- ate direction. Be The well to be crossed will be shut-in, and casing and tubing pressures will be monitored until a safe crossing is made. In addition to the above precautions, the on-site rig personnel and supervi- sors will continuously monitor all parameters as the intervals of interest are drilled. With respect to Wells 1E-4. 1E-17, and 1E-30, the distances between these wells and Well 1E-27 are a minimum of 300'. RECEIVED SEP o 1982 Alaska 011 & Sas Cons, Commission Anchorage Surface Div:rter Ssstem 1. 16" Bradenhead. 2. 16" x 20"' 2000 psi double studded adapter. $. 20', 2000 psi drilling spool w/lO" side outlets. 4.' 10" ball valves, hyraulically actuated, w/lO" lines to reserve pit. Valves to open auto~a~tT~ cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. 20" bell ~ipple. Maintenance & Operation 1. Upon initial installation close annular preventer and verify that ball valves have opened properly. 2. Close annular preventer and blow air through diverter lines every 12 hours. 3. Close annular preventer in the event that gas or fluid flow to surface is detected. If necessary, manually over- ride and close ball valve to upwind diverter line. Do not shut in well under an_y_ circumstances. 16" Conductor RECEIVED SEP 0 1982 Alaska Oil & Gas Cons, C~mmission Anchorage 13-5/8" 5000:PSI RSRRA BOP 'STACK RNNULR.q PREVENTOR . 1. 16" Bradenhead 2. 16" 2000"PSI x 10" 3000 PSI casing head 3. 10" 3000 PSI tubing head 4. 10" "3000 PSI x 13-5/8" 5000 PSI adapter spool 5. 13-5/8" 5000 PSI 6. 13-5/8" .$000 PSI · and ki 11. 1 i nes 7. 13-5/8" 5000 PSI 8. 13-5/8" 5000 PSI 9. 13-5/8" 5000 PSI pi pe r~ms drilling spool w/choke pipe rams blind rams annul a r BLI ND RRHS 8 ACI~.IULATOR CAPACITY TEST PIPE RRtt$ 7 ILLING SPOOL 6 PIPE RRHS 5 TBG HD 3 CSG HO 2 RECE VEO f -SEP) 0 1982 ' Alaska 0il & Gas Cons. Commission L.A la Anchorage ® * . 5. 6. 7. 8. CHEOC ANO FILL AOCUNULATOR RESERVOIR TO PROPER LLrVEL WITI4 HYDRAULIC FLUID. ASSURE ll'~T ACCLI. ItlLATOR PRESSUR/ IS 3000 PSI 14IT)l 1500 PSI DI~GTREAM OF TIlE REGULATOR. 08SERVE TIRE TI.IEN CLOSE ALL UNITS SIRULTA~IE- 0USL¥ AND P/CORD l'14E TIRE ,A.ND PRESSURE REMAIN- ING AFTER ALL U~IITS ARE CLOSED Will4 C)iARGZNG PURP OFF. 4. RECORD ON IADC REPORT. ~ ACCEPTABLE LO'dER LZRIT IS 45 SECO:iDS CLOSII~ TIttE AgO 1200 REMAINING PRESSI~. · .' 13-S/8' BOP ,STACX 'r~ 1.' FILL SOP STAcX NiO RANIFOLD WI'T14 ARCTIC DIESEL. 2. ~EC)C TI.IAT ALL I4OI.D DOWN SCREWS AJ~E FULLY RE- TRACTED. PRED~INE ~ l'14AT 'rT..qT Pt. UG WILL SEAT AND SEAT IN WELUtEA~. RUg DOWN SCRE"~ Z N )lEAD. CLOSE ANNULAR PREYEI4T~ A/ID ~OK~$ AND BYPASS VALVES ON MA~I ! FOLD. TEST ALL C~)4PONE~ITS TO Z.~43 PSI AND HOLD FOR 10 HINUTES, INCREASE PRESSURE TO 18OO PS! AND )4OLD FOR 10 XINUTES. BLEZD TO ~ PSI. OPEN ANNUI.AJ~ PREYEt~I'ER A~ ¢~.OSE ~ SET OF PIPE P. ARS. INCREASE PRESSURE TO I AND gOLD FOR lO HZr~l'ES. CLOSE VALVES. DIREClq.¥ ~ OF 81.[ED DOWNSTP. EA~ PRESSURE TO ZERO PSI TO TEST VALVES. TEST i~_.IAINING UIITESTED MANIFOLD VALVES, IF ANY, WIl')4 3000 PSI UPS~ OF VALVE ANO ZERO PSI D~t~. SI. ZED SYSTEM TO ZERO PSI. g. OPEN TOP SET OF PIPE RJI,'4S ,q~lO CLI~SE BOTTI~',~ SET OF PIPE ~. 10. INCREASE PI~ESSUR~ TO 30OO PSI AND ~IOLD FOR l0 MINUTES. BL£ED TO ZERO PSI. 11. OPEN BOTTOM SET OF PIPE RAI~S. 8AC)C OFF RUN- NING JOINT ANO PULL OUT OF HOLE. CLOSE BLIN0 RAMS AND TEST TO 3000 PSI FOR l0 MINUTES. BLEED TO ZERO PSI. 12. OPEN BL/I(O RAHS AND RECOVER TEST PLUG. MAKE SURE HNIIFOLD N(O LINES ARE FULL OF ARCTIC 0IESE]. AND ALL VALVES ARE SET IN DRILL/);G POSITION. 13. TEST STA~iOPIPE VALVES TO 3000 PSI. 14. TEST KELLY COOCS AZID INSIDE BOP TO 3000 PSI WITH KO(~Y PL~. lS. RECOR0 TEST INF0~4ATION 0g 8LOWOUT PREVE~iTER TEST FORM SIGN A;ID SE)iD TO DRILLII(G SUPER- VISOR. 16. PERFOR/-1 CC~iPLLrl~E BOPE TT. ST 0gICE A WE~)~ FUNCTI0gIALLY OPERATE 8OPE DAILY. ~o .. 8SSOG, lll~lllll iM kill , , , . .ARCO Alaska, Inc. Ku iruk Pro ect · ~llzJ'~Z. scale: i,,=4o,~, drawn by ' ~.uc~-t dwg. no. · 1~$t<9.tc~.~ ,1, £ e£~ ., L~'T.:. "To°'"l' ~ -'n-T-ti L~.-T = --fo~ ( E~.' o, EE~ ~.~ II ARCO Alaska. Inc. Kuparuk Prolect scale' drawn by ' ~],.~..,:_~ dw9. no. ',N'~K-) to5.~'~, , I [ i I I I iii I I I I _111 CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. /~ ~-~-~ 2~'~') ITEM (1) Fee (2) Loc ,,, (3) Admin APPROVE DATE ~ thru 8) 3. 4. 5. 6. 7. 8. (9~ thru 11) 10. 11. (4) Casg (~ - th-ru 20) 13. 14. 15. 16. 17. 18. 19. 20. (21 thru 24) 21. 22. 23. 24. (6) Add: f-?,a.~'>-- 25. Is the permit fee attached .......................................... Is well to be located in a defined pool ............................. pe ty Is well located pro r distance from proper line ................. Is well located proper distance from other wells .................... Is sufficient undedicated acreage available in this pool Is well to be deviated and is well bore plat included ...~]~'~.~.~ ~ Is operator the only affected party Can p rmit be appr ved before day ait e o ten- w .......................... Does operator have a bond in force Is a conserva on order needed ........ . , Is administrative approval needed ........ Is conductor string provided .. . Is enough cement .used t° circul;;~'~ Will cement tie in surface and intermediate or production .s]r.~n.g.~ Will cement cover all known productive horizons .... Will surface casing protect' fresh water zones "']']']']]];~'~g~g;]i~ Will all casing give adequate safety in collapse, tension Is this well to be kicked off from an existing wellbore .............. Is old wellbore abandonment procedure included on 10-403 ........... Is adequate well bore separation proposed .......................... Is a diverter system required ...................................... Are necessary diagrams of diverter and BOP equipment attached Does BOPE have sufficient pressure rating - Test to '~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. Additional requirements ............................................. Additional Remarks: o ~-t. ~ o Geology: Eng J~er ing: HWK~ LCS~ BEW / WVA ~7_~ JK~RAD rev: 08/19/82 INIT IAL GEO. UNIT ON/OF F~ 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. bVP 0tO,HO! VERIFICATION bISTING PAGE ** REEL HEADER SERVICE NAME :SERVIC DATE {82/10/21 ORIGIN : REEb NAME CONTINUATION # 101 PREVIOUS REEb COMMENTS ILIBRARY TAPE ** TAPE HEADER SERVICE NAME :SERVIC DATE :82/10/2,1 ORIGIN 16573 TAPE NAME CONTINUATION # 101 PREVIOUS TAPE COMMENT8 :bIBRARY TAPE ********** EOF ** FI,L.E PREVIOUS FIbE : ** ] FN : TOWN: N COUNI NOR~ LVP OIO,HO1 VERIFICATION~LISTING PAGE 2 RECORD TYPE 047 RECORD TYPE 047 ** ** COMMENTS ** SCHLUMBERGER AbAMKA COMPUTING CENTER COMPANY : ATLANTIC RICHFIELD COMPANY WE6b = 1E'27 FIELD = KUPARU~ COUNTY = NORTH SLOPE BOROUGH STATE = ALASKA JOB NUMBER .AT ACC; 65736 RUN #i, DATE bOGGED~< I5'OCT-B2 TOP DEPTH = 22'19 bVP 010,HO1 VERIFICATION LISTING PAGE DENSITY ! lO,O LB/G VISCOSITY = 42,0 S PH = 9,5 FLUID LOSS = 5 8 C3 RM I 3,20 ~ 63,0 DF R~F m ], 70 M 63,0 DF R~C ~ 2,860 ~ 63 0 DF R~ AT BHT = 1,62! ~ 14~' DF MRTR]X SANDSTONE DATA FORMAT RECORD ** TYPE SIZE REPR CODE ENTRY 0 0 DATUM SPECIFICATION BLOCKS SFLU Dlb I bD D I b '~')~ ~ 'M ? ........ J. 2 46 0 {3 4 O 1 ORHO FDN CALl FDN RNR NCN[~ FDN LVP OlO,HOl VERIFICATION LISTING PAGE 4 ** DATA DEPT 6~15.5000 SELU 2 Sp 27.5958 GR 115 RHOB 1,7227 CALl 8 NRAT 3.6309 NCNb 1813 DEPT 68.00.0000 SFbU 2 Sp 27,~938 GR RHOB 1, 227 CA{~I , NRAT 3,6309 NCNL 1813. DEPT 6700,0000 SFLU 2, $p '26,6406 GR 113, RHOB 2.4160 CALI 9. NRAT 3,3320 NCNb 1968, .oo.oooo SP 24,8906 GR 9~.' RHOB ], 4434 CAbI 9 ' NRAT ,2422 NCNb 2200~ DEPT 6500, Sp:: -2 4, AAOB 2 ' NRA:T 0000 SFLU ~32'0 C~I ~DpBP.T DEPT ~:RAT 7754 IbM 0000 FCNb 7734 IbM 5625 NPH! 4648 GR 0000 FCNb 0586 Ib~ 500 NPHI 109 GR 0000 FCNb 4355 .Ib~ 1250 NPHI .140,6 GR 0000 FCNL 2 6;~$4 ILN 2,3926 ILD 50,4883 DRHO 115 5625 RNRA 458:2500 4883 DRHO 115,5625 RNRA 458.2500 : 8994 IbD 3 4043 ORMO 111,2500 RNR. A 562,5000 3~, 1914 IbD .8906 DRHO .0000 2.2402 IbP 3 "66'4I I LD 3'5 ,,595:,:7:': DRHo 5::~ ~ 0000. DEPT 6t00' ::1::.:,i8682 :: :: 4:7';1680 DRHO 2.1836 0,0439 3.9564 2,2871 0,0439 3,9564 :8525 0371 3,6594 2,1426 0,0366 3,5243 2.2441 ,02:25 .8349 60 ,: 2969 ,03<8:1 ], ! 003 3.6'230 ,4 8'1'4 , 1,6006 EVP 010,H01 VERIFICATION LISTING PAGE 5 DEPT 5900,0000 SFLU SP -18'7656 GR RHOB 2~5215 CALl NRAT 3;3223 NCNb DEPT 5800.0000 SFbU SP -28,0469 GR RHOB -999'2500 CAb! NRAT -999,2500 NCNb DEPT 5700 0000 SFLU SP -24 3438 GR RHOB -999 2500 CAb! NRAT -999 2500 NC'Nb OEPT 5~00 SP 20 RHOB "99:9 NRAT -999 DEPT SP RHOB NRAT O00.SFbU 813 GR 3.1016 230,0000 NPHI 9;4063 GR 1974,0000 FCNL 3,~363 147, 000 NPH! 10,4219 GR -999,2500 FCNL 6,1445 I~.6875 ,0938 GR -999.2500 :Nb U 2500 CAb! 2,2871 38 9648 230i0000 532 5000 .99~ '7070 .2500 147 ,~000 -999~ 500 3,9355 -999,2500 112.6875 '999'2500 ,0.703 IbM . 4 ,750'0 NPH! 999 '4219,2500 GR:FcNL -~9929 4 2305 Iht4 2 ?:500 N~PH:I ":999 60i6 C;R I'/8 ',: ,,9:99 ILD 2,4219 DRHO 0,001~ R'NRA 3.703 I~D 2,6816 DRHO -999,2500 RNRA -999,2500 lbD 4,03t3 DRHO :~99.2500 RNRA 99.2500 5 47 ILD 4,8828 500 DRHO -999,2500 7.500 RNRA -999,2500 2500 ,6777 ILD . 2,9375 ,2500 DRHO ~999,2500 ,7500 RNRA 999~,2500 ':2500 ,'2500 DRHO 7'4411 2500 2~ DEPT RHOB SP RAT bVP 010,H01 VERIFICATION LISTING PAGE 6 DEPT SP RHOB NRAT 4800,0000 SFLU 02'04697 IbM -28,5938 GR I ,7500 NPHI -999,2500 CAb! 9,4375 GR -999,2500 NCNb -999,2500 f~CNL 4700,0000 SFLU 2,0488 IL~ -30,5781 GR I03,1250 NPH! -999,2500 CALl 10'4844 OR -999.2500 NCNb -999.2500 f'CNL DEPT RHOB NRAT DEPT SP RHOB NRAT 4600. 0000 SFi, U ~, 3730 IL~4 31,1094 GR 9~ 0 I - 250 NPH '999,2500 CALI lO 4453 GR '999,2500 NCNB '999,2500 FCNL DEPT RHOB NRAT 4.500 0000 SFLU 2,8984 ~32:0625 GR: 90,4375 NPHI -999,2500 CALl 'I0~1953 GR ,,999,2500 f~CNL -,99:9,2500 F'CNb E PT 4400 P -34 HOB .999 ~']::RAT "999 DEPT 4300 :N:'RA:~'~': :: N~ 00:00 6250 GR 2500 .CAb:i .'2500 4375 NPHI 0 O00 S'FLLi 3 .99~,1250 ILD 2,1426 ,2500 DRHO -999,2500 107,7500 RNRA '999,2500 -999,2500 2,1270 IbD 2,1855 -999,2500 DRHO -999,2500 103,1250 RNRA -999,2500 -999,2500 2656 IbP 2,~125 -99 ;2500 DRHO -999, 500 95,2500 RNRA -999.2500 99~ 2500 . 2,8477 ILD 2,8184 999,2500 DRHO -999~2500 90,4175 RNRA -999,2500 -999'2500 NRAT Di LVP OIO,H01 VgRI~ICATIDN bI~?ING PAGg NRAT 3.2754 NCNL 2084 DEPT 3700,0000 SFLU 6 SP ' 85 ,0313 GR 67 RHOB 2,1953 CALI 9 NRAT 3,2871 NCNb 2152 DEPT 36000000 SFbU 5 SP -46:2500 GR 8! RHOB 2,2520 CAL! 10 NRAT 3,5313 NCNb 18.10 DEPT 3500,0000 SFLU 7 SP -60, 313 GR 90 RHOB 2, 930 CALI 10 NRAT 3,3887 NCNb 1822 8 83 D£PT 3400 SP -55 RHOB ~ NRAT DEPT 3300 RHOB NRA? 3~ NRAT 0000 SFLU 25 2 168 CAL! .oooo FCNL 555,5000 ,890b IbM 4,5078 ILD 4 ~375 ,0000 NPHI 37,7441 DRHO O:v068 .7969 GR 67,0000 RNRA 3,5839 ;0000 FCNL 574,0000 ,2422 IbM 4,8398 IbD 5,~383 ,0625 NPHI 41,6992 DRHO O,0449 ,0938 GR 81.0625 RNRA 3,7319 ,0000 FCNL 486'5000 ,6172 Ibm 7,0391 ILD 7,3867 ,62'50 NPH! 38,4277 DRHO 0,0454 ~5703 GR 90'6250 RNRA 3,6205 ,000,0 FCNb 503,2500 t6,7:2 IbM 8,4375 !' bD 9,031:3 ,875 NPH! 40,6738 DRHO 0,0117 5~43:1'8750000 RNRA 3,9677 812'5 21,1406 IbD FCNI, DEPT 0000 SFb'U 1:2 RHOB 1875 008; 2~'580 DEPT RHOB SP hVP 010.HO1 VERIFICATION LISTING PAGE 8 RHOB 2.1133 CALI 13 NRAT 3.8574 NCNL 1548 DEPT 600. 0000 SFI,.U 3, SP DEPT 2500,0000 SFLU 12 SP -60.4688 GR 5! RHOB 2,0547 CALl 15 NRAT 3,6523 NCNb 1,838 DEPT 2.400;0000 SFLU SP 55 5625 GR RHOB 2~, 0762 CRL, I 1901~ NRAT 3.8516 NCNL DEPT 2300 SP ,,,74 RHOB 1 NRAT 2 0000 SFLU 69 8584 CAL! 61.7'2: ,:' .: :, NCN b: ;:,:' .:, 236:4: DEP? SP NRAT DEPT 2195 RHOB 2'500 GR 4 1 ** F IbL TRAIi.,ER ** 8359 GR 57,0000 RNRA 4.2745 0000 FCNh 373.5000 4902 IbM 5,9687 IbD 8,4766 2189 NPHI 51.5137 DRHO -0,0059 52{4 GR 62,2187 RNRA 4.6626 0000 FCNL 425~5000 1797 GE 5 ,2500 RNRA 4,1581 0000 FCNb 45 .7500 ,85i6 IbM 9,0,469 IbD 9,5313 ,8750 NPH! 45,3125 DRHO O,OOlO '3750 OR 61,8750 RNRA 4,0257 .0000 FCNL 472.7500 ,7344 GR ~8750 RNRA ,0000: FCNb 8~5,0000 200.,0: 1 72 ,1250 62 i~ N R A 5.125:8 43'7'5 .... IbM 200'0 O000ILD 132, LVP OlO,HOl VERIFICATION bISTING PAGE 9 **RgEt TRAILER SERVICE NAME :SERVIC DATE :82/10/21 ORIGIN : REEb NAME CONTINUATION ~ :01 NEXT REEL NAME COMMENTS IbIBRARY TAPE EOF bVP 010,H01 VERIFICATION LISTING PAGE DATE :99/t0/14 ORIGIN :CSU REEL NAME : CONTINUATION # : PREVIOUS REEL ~ COMMENTS ISCNLUMBERGER WELL SERVICES FIELD TAPE ** TAPE HEADER ** SERVICE NAME :PROC DATE :99/10/14 ORIGIN :CSU TAPE NA~E I CONTINUATION # : PREVIOUS TAPE : COMMENTS :SCHLUMBERGER ~ELL SERVICES FIELD TAPE EOF FILE NANE ,PRu 101 S,ER!.vERSiON:IiCE ! N-A,~E:# : 20 2~¥::BA :'1'024 BVP OlO,HOl VERIFICATION LfSTING PAGE 2 TVTD UNAb ,lin 0 MTD UNAb ,~IN 0 MCT ~D~C UNAb DEG 0 PVU~ ALLO ---' 1 0000 CD AI~LO ,lin 26628~ FCD AbbO IN 7,0000 ICVD ALLO .... BOT~ B$ UNAL IN 8,7500 KPDU UNAb FE DRDU UNAb FEET MMDU UNAb FEET PF dNAL bONG YEAR UNA~ 1982 MONT UNAB DAY R1 UNAL R2 R3 UNAL R 4 'U NAb HIDE UNAL WN ~N LUL WITN STAT DMF 0=~4 OS6 TN bVP 010 MO! VERIfICATIOn, LISTING PAGE TN8 UNAL TN9 UNAL TNIO UNAL TN1 UNAL PD UNAb SON UNAL SECT UNAb TOWN UNAb RRNG UNAb TABLE TYPE ICONS MNEM STAT UNIT VAbU NATI UNAL CQNT UNAb MSS UNAL MFSS U.N ~CSS STATE CLAB COUNTY BS3 UN RUN BL! TD~ LVP OlO,M01 VERIFICATION LISTING PAGE 4 CBb3 UNAb ,lIN STEN UNAL DEGF MRT UNAL DEGE DFD UNAL LB/G DFV UNAL S DFPH UNA5 DFL UNAL C3 RMF8 UNAb OHMM RMS UNAb OMMM RMC$ UNAb OMMM MST UNAL DEGF MFST UNAL DEGF MCST UNAL DEGF ** FILE TRAILER ** FILE NAME :PROC .10! S~R:VICE NAME {:PbAYBA VERSION # : 20,2 DATE z81/O0/O0 MAXIMUM LENGTH :1024 NEXT FIbE NAME 0 0, 0, O, 0, 0, O, O, O, O, 0, O, 0, 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 0000 FILE NAM. E VERSION :PROC ILE : LVP OI'O,H01 VERIFICATION LISTING PAGE 5 SD UNAb FNUN UNAb FEXP []NAb FPHI UNA6 TVTO UNA6 MTD UNA6 MET UNA6 MDEC UNAb PVU~ ALLO CD A~60 TD Ah~O FCD ICVD RW UNAD KPDU ORDU UNA~ ~DU UNA~ PF UNAL YBAR UNA.~ ~OHT DAY UN:A~ R1 UNAB R2 R3 UNAB UNAb ,lin ,liN DEG D~G ,lin OHMM 8192 0000 1 0000 2 0000 PHi; 0 0 36 816000 7 0000 ,7500 °°°° FEET FEET bONO 1982 10 A N 0S2 0,94 LVP 010,HOI VERIFICATION LISTING PAGE 6 TN4 UNAL TN5 UNAL TN6 UNAL TN? UNAL TN8 UNAL TN9 UNA~ TN10 UNAL TNt1 UNAL TN12 UNAL PD UNAL SON UNAb SECT UNAL TOWN UNAD RANG UNAU TABLE TYP~ ~CON$ MNEM STAT UNIT VALU NATI UNAL CONT UN-~5 MCSS UNAL C$2 EPD , bVP 010,HOl VERIFICATION LISTING PAGE CBL2 UNAL ,lIN CW] UNAL 5B/F 0SD3 UNAL ,lIN CBb3 UNAb IN STEM UNAL DEGF MAT UNAb DEGF DFD UNAb bB/G DFV UNAL DFPH UNAb DFL UNAL C3 RMF$ UNAb OHMM R~$ UNAL OHMM RMC$ UNA6 OHMM MST UNAb DEGF MFST UN,Ab D~GF ~CST IJNAb DEGF 0 o6oooo 0 0 0 ~000 0 000 0 0000 0 0000 0 0000 0 0000 0 0000 0 0000 0 0000 0 0000 0,0000 0o0000 $* DATA FORMAT RECORD ** ENTRY BLOCKS ENTRoY 0 INCH bVP OIO,H01 VERIFICATION bIST'ING PAGE 6 4 73 0 7 4 65 INCH 9 4 65 ,lin 1! 1 66 !26 14 4 65 ,lin 16 ! 66 1 0 I 66 0 DATUM EPE¢IFICA?ION MNE~ SERVICE SERVICE UNIT AP1 AP1 AP1 AP1 FILE SIZE SPL REPR PROCESS ID ORDER # ,OG TYPE Cb,SS ,OD NO. CODE (OCTAb) TENS PROC LB 85 635 21 0 2 2 t 49 OOO00000000000 2 I O0200000000000 ,, ~ ~ ~ oo~ooooooooooo ~s~..oc ~. ~o,~.~ o~o ~ = ~ ~ oo=ooooooooooo ** DATA ** 8,75O0 LVP OIO,HOI VERIFICATION LISTING PAGE 9 SERVICE NAME ~LAYBA VER6ION # ~ 20, DATE 581/00/00 MAXIMUM L~NGT~! :1024 FI~E TYPE :PL NEXT FILE NAME ~ EOF EOF
