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181-176
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, July 14, 2025 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 11-17 KENAI UNIT 11-17 Jim Regg InspectorSrc: 11-17 N SPT 3958 1811760 1500 1580 1570 1570 1570 0 0 0 0 Other (describe in notes)Pass 2 yr cycle per DIO 9.001. 30 MinPretestInitial15 Min Type Test Notes: Interval P/F Well Type Inj TVD PTD Test psi Tubing OA Packer Depth 447 2120 2114 2112IA 45 Min 60 Min 50-133-20349-00-00 181-176-0 Sully Sullivan 4/21/2025 Well Name Permit Number: API Well Number Inspector Name:KENAI UNIT 11-17 Inspection Date:Insp Num: Rel Insp Num: mitSTS250428090728 MITOP000010898 BBL Pumped:1.2 BBL Returned:1.3 Monday, July 14, 2025 Page 1 of 1 9 9 9 9 9 99 9 99 99 99 9 9 9 &KDQJHGLQWHUYDOWR2WKHUDQGDGGHG1RWHV 5(9,6(' James B. Regg Digitally signed by James B. Regg Date: 2025.07.16 13:40:01 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, May 22, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 11-17 KENAI UNIT 11-17 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/22/2023 11-17 50-133-20349-00-00 181-176-0 W SPT 3958 1811760 1500 1720 1720 1720 1720 0 0 0 0 OTHER P Adam Earl 4/6/2023 MIT-IA tested as per DIO 9.001. 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:KENAI UNIT 11-17 Inspection Date: Tubing OA Packer Depth 405 2352 2345 2342IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE230412114251 BBL Pumped:2 BBL Returned:2 Monday, May 22, 2023 Page 1 of 1 MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Jeff Jones Petroleum Inspector Well Name KENAI UMT 11-17 Insp Num: mitJJ210422084807 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Cas Conservation Commission DATE: Tuesday, April 27, 2021 SUBJECT: Mechanical Integrity Tests lfilcorp Alaska, LLC 11-17 KENAI UNIT 11-17 Sre: Inspector Reviewed By:9z P.I. Supry ZBR--- Co.. API Well Number 50-133-20349-00-00 Inspector Name: Jeff Jones Permit Number: 181-176-0 Inspection Date: 4/16/2021 Packer Depth Well a -n TypeInj N -TVD s9sa _ PTD Is1 n6o pe Test SN Test psi Isoo BBL Pumped: zs "BBL Returned: zs Interval oTfMR P� p Notes: 2 year test cycle. One well inspected, no exceptions noted. Pretest Initial 15 Min 30 Min 45 Min 60 Min ubing 1760 1760 - 1760 - - 760 IA 44 2372 - 2370 - 2:71 • OA o o 0 0 Tuesday, April 27, 2021 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg �p� / p / DATE: Monday, April 29, 2019 P.I. Supervisor I``*fyf L {1 f�j SUBJECT: Mechanical Integrity Tests [ 11 I HILCORP ALASKA LLC II -17 FROM: Guy Cook KENAI UNIT 11-17 Petroleum Inspector Ste: Inspector Reviewed By: P.I. Sup" JY -- NON -CONFIDENTIAL Comm Well Name KENAI UNIT 11-17 API Well Number 50-133-20349-00-00 Inspector Name: Guy cook Permit Number: 181-176-0 Inspection Date: 4/15/2019 Insp Num: mitGDC190423170809 Rel Insp Num: Packer Depth Pretest Initial I5 Min 30 Min 45 Min 60 Min Well 11-17 -Type Inj I N -TVD 3958 - Tubing 1715 171 nos ' 1700 �_—.1- — - PTD 1811760 T e Test spr Test SI 1500 IA «4 2334 ' 2330 1314 YP_ P I_— BBL Pumped: 11 .1 "BBL Returned: f� OA j 2 2 2 _ - Interval OTHER P/F P Notes: 2 year cycle for SI disposal. Testing performed with a triplex pump and calibrated gauges. Monday, April 29, 2019 Page I of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg �7 11th DATE: Tuesday,May 02,2017 P.I.Supervisor SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC 11-17 FROM: Guy Cook KENAI UNIT 11-17 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv,}ge— NON-CONFIDENTIAL Comm Well Name KENAI UNIT 11-17 API Well Number 50-133-20349-00-00 Inspector Name: Guy Cook Permit Number: 181-176-0 Inspection Date: 4/24/2017 Insp Num: mitGDC170427095941 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 11-17 1Type Inj N_ TVD 3958 - Tubing 1530 1500 1480 - 1470 - PTD 1811760 ' FType Test SPT Test psi 1500 IA 530 1720 1720 - 1710 - BBL Pumped: I BBL Returned: I - OA o 0 0 0 Interval OTHER P/F P v Notes: 2 year testing. SCANNED AUG 2 4 2017 Tuesday,May 02,2017 Page 1 of 1 STATE OF ALASKA ALlikA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon J Plug Perforations Li Fracture Stimulate J Pull Tubing A Operations shutdown _A Performed: Suspend ❑ Perforate ❑ Other Stimulate [] Alter Casing❑ Change Approved Program Plug for Redrill ❑ srforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Xylene/Acid E 2.Operator 4.Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska,LLC Development ❑ Exploratory ❑ 181-176 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service [] 6.API Number: Anchorage,AK 99503 50-133-20349-00 7.Property Designation(Lease Number): 8.Well Name and Number: FEE-CIRI Kenai Unit 11-17 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Kenai Gas Field/Sterling 5.1 Gas-Sterling 6 Gas-Undefined WDSP 11. Present Well Condition Summary: Total Depth measured 5,400 feet Plugs measured N/A RECEIVED true vertical 4,856 feet Junk measured 5,270 feet PR 082016 Effective Depth measured 5,276 feet Packer measured (see below) feet true vertical 4,758 feet true vertical (see below) feet AOGCC ,sC Casing Length Size MD TVD Burst Collapse Structural Conductor 174' 20" 192' 192' Surface 1,976' 13-3/8" 1,994' 1,889' 3,090psi 1,540psi Intermediate Production 5,353' 9-5/8" 5,371' 4,840' 6,870psi 4,750psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic SS 3-1/2" N-80 4,522'MD 4,107'TVD Tubing(size,grade,measured and true vertical depth) LS 3-1/2" N-80 5,049'MD 4,558'TVD Baker A-5&AL-5 Dual Pkrs, 4,347'&4,508'MD 3,949'&4,097'TVD Packers and SSSV(type,measured and true vertical depth) 2 Model D Pkrs; N/A: SSSV-N/A 4,620'&4,999'MD 4,193'&4,519'TVD 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A APR 2 0 2016 Treatment descriptions including volumes used and final pressure: N/A i`A�HGD 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 535 105 1815 Subsequent to operation: 0 0 460 115 1490 14.Attachments(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development❑ Service El Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL2❑✓ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ Li SUSP❑ SPLUG Li 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 316-107 Contact Taylor Nasse-777-8354 Email tnasse@hilcorp.com Printed NameChad Helgeson Title Operations Manager Signature 6,// /--/;�i Phone 907-777-8405 Date >/i// XV-/:3—l6 Form 10-404 Revised 5/2015 RBDMS [ry OR 1 1 2016 Submit Original Only 111 Hilcorp Alaska, LLC Weekly Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date KU 11-17 N/A 50-133-20349-00 181-176 2/21/16 2/21/16 Daily Operations: 02/21/2016-Sunday 1030hrs met with Bobby Aguillard with X-Chem, pumped 30 gals of WC-11 into day tank and staged 1 drum of Xylene, 1 drum of Oil safe AR(acid replacement). 1045hrs pumped 1 drum of Xylene down well down stream of injection pump. 1100hrs pumped 1 drum of Oil safe AR. 1115hrs pumped 40bbls of produced water down well, using the injection pumps to totally displace the tubing string. Shut in well for 4hrs. 1730hrs started WC-11. I • fl KU 11 -17 SCHEMATIC Tbg Hgr @ 18.5' KU 11-17 Kenai AK 13 3/8",61 ppf, K-55 Csg @ 1,994' • • F 3 1/2"Otis XA Sly @ 4,337' ' 3 1/2"Otis XA Sleeve @ 4,343' Baker Model A-5 Dual Packer @ 4,347' '91! II Tagged metal 1-3/4"DD Bailer 4,477' B-3(2/82): :...* • 5/31/11 4,468'-4,483' I Blast Jts 4456'-4505' 3 1/2"Otis XA Sly @ 4,430' q i • ' Baker AL-5 Dual Packer @ 4,508' 3 1/2"Otis XN Nipple @4,520' - , Blast Jts 4,519'-4,597' Plug installed B-4(2/82): • 4,528'-4,587' [._, 3 1/2"Otis XA Sleeve @ 4,607' - Baker Locator @ 4,620' - Baker Mod D Pkr w/Seal assy @4,621' Lower B-4 Sd (2/82): 4,641'-4,661' $_'. ', Baker Locator @ 4,999' Baker Mod D Pkr w/seal assy @4,999' Sqzd Isolationi _ ' (2/82): C-1 (3/82): Baker bull nose entry 5,103'-5,105' 5,106'-5,152' 11 guide @ 5,048' 5,160'-5,162' , Last Tagged Fill 9 5/8", 47 ppf, N-80 @ 5,371' 5,136' (5/95) Well Name&Number: KU 11-17 Lease: County or Parish: Kenai Peninsula Borough StatelProv. Alaska (Country: USA Perforations(MD) (TVD) Angle/Perfs Angle @ KOP and Depth BHP: BHT: Completion Fluid: Dated Completed Mike Sulley 6/1/2011 III • ,,,'ICo „OF D eg'\�\�jy.�• THE STATE Alaska Oil and Gas 1.3,,,..-' og � i�, of e T S Conservation Commission •a-=_ =- 333 West Seventh Avenue ^ti GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 OMain: 907.279.1433 ALAS ---•-- Fax: 907.276.7542 www.aogcc.alaska.gov Chad Helgeson Operations Manager Hilcorp Alaska, LLC scAtmEr riai 14 ,..,i.!),J 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: Kenai Field, Sterling 5.1 and Sterling 6 Gas Pools,Undefined WDSP, KU 11-17 Permit to Drill Number: 181-176 Sundry Number: 316-107 Dear Mr. Helgeson: 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 AOGCC grants for good cause shown, a person affected by it may file with the AOGCC 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, Cathy . Foerster Chair DATED this /0 day of February,2016. RBDMS LL FEB 1 6 2016 • • RECEIVED STATE OF ALASKA FEB 0 5 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION 1 .fl a/c,,, APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑✓ • Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. Xylene/Acid D. 2.Operator Name: Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number: Exploratory ❑ Development ❑ 181-176 • 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service 6.API Number. Anchorage,Alaska 99503 50-133-20349-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 510A Kenai Unit 11-17 , Will planned perforations require a spacing exception? Yes ❑ No 0 9.Property Designation(Lease Number): 10.Field/Pool(s): FEE-CIRI - Kenai Gas Field/Sterling 5.1 GasSteriing 6 Gas-Undefined WDSP 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 5,400' 4,856' • 5,276' 4,758' 2,100psi N/A 5,270' Casing Length Size MD TVD Burst Collapse Structural Conductor 174' 20" 192' 192' Surface 1,976' 13-3/8" 1,994' 1,889' 3,090psi 1,540psi Intermediate Production 5,353' 9-5/8" 5,371' 4,840' 6,870psi 4,750psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size:SS 3-1/2" Tubing Grade: N-80 Tubing MD(It): 4,522' See Attached Schematic See Attached Schematic LS 3-1/2" N-80 5,049' Packers and SSSV Type: Baker A-5&AL-5 Dual Pkrs, Packers and SSSV MD(ft)and ND(ft): 4,347'&4,508"MD!3,949'&4,097'ND 2 Model D Pkrs;N/A: 4,620'&4,999'MD/4,193'&4,519'ND;N/A,N/A 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development❑ Service ❑✓ • 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Feburary 19,2016 OIL ❑ WINJ 0 WDSPL2 ❑Q , Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Taylor Nasse-777-8354 Email tnasseehilcorp.com Printed Name Chad Helgeson Title Operations Manager Signature .�'l",,° / Phone 907-777-8405 Date ?_/c•—/(tom COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 3\Lt - k 07 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No E Subsequent Form Required: 10-404 RBDMS LL FEB 1 6 1016 APPROVED BY / Approved by: (0146, /9 ' _ __ f COMMISSIONER THE COMMISSION Date: Z-�G_(h 0 R p� A .%NM Z11��Aitt Submit nForm and Form 10-403 Revised 11/2015 p r a�i valid for 12 months from the date of approval. ��! `ttac�is in Duplicate ' r' P z-.v.�� - Well Prognosis Well: KU 11-17 Hilcory Alaska,LL Date:2/5/2016 Well Name: KU 11-17 API Number: 50-133-20349-00 Current Status: Shut In Disposal Well • Leg: N/A Estimated Start Date: Feb. 19, 2016 Rig: Reg.Approval Req'd? Yes Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 181-176 First Call Engineer: Taylor Nasse (907)777-8354 (0) (907)903-0341 (C) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907)229-4824(C) AFE Number: Maximum Expected BHP: —4,113psi 4,646' ND (Based on MPSP and water p @ column to surface) Max. Potential Surface Pressure: —2,100 psi (Pressure Safety Valve relief setpoint) Brief Well Summary KU 11-17 in the Kenai Gas Field is a Class II injection well that was originally drilled in 1982.The well consists of 9-5/8" production casing with dual 3-1/2" tubing and multiple packers. The well has been starting to pressure up and was shut-in in January 2016. • The purpose of this work/sundry is to pump a well treatment of xylene and acid to improve injectibility. • Notes Regarding Wellbore Condition • Expected pumping rate for procedure is 37 bbl/hr(26 GPM) at 2,100 psig. • Prior to well plugging up,average injection rate was 600 BWPD at 1,800 psig. • Pumping Procedure 1. Pump 55 gallons of Xylene into the well (downstream of water injection pump). 2. Immediately following the Xylene, pump 55 gallons of acid (downstream of water injection pump). 3. Pump produced water into the well to completely displace the tubing string to ensure xylene/acid has made it to the formation and is out of the tubing string. 4. Shut the well in for 4 hours. 5. Begin normal water injection with WC11 at a rate of 100 ppm for 24 hours. 6. Reduce WC11 injection rate to 30 ppm for continuous injection. Attachments: 1. Actual Schematic ! S 11 KU 11 -17 SCHEMATIC Tbg Hgr @ 18.5' i ::, .' [ KU 11-17 Kenai AK 13 3/8", 61 ppf, K-55 Csg @ 1,994' r 4 ilii V 3 1/2"Otis XA Sly @ 4,337' "' : 3 1/2"Otis XA Sleeve @ 4,343' I • ' Baker Model A-5 Dual Packer @ 4,347' u i 11 Tagged metal 1-3/4"DD Bailer 4,477' B-3(2/82): 5/31/11 4,468'-4,483' Blast Jts 4456'-4505' 3 1/2"Otis XA Sly @ 4,430' I tri,------.1i Baker AL-5 Dual Packer @ 4,508' 3 1/2"Otis XN Nipple @4,520' Blast Jts 4,519'-4,597' Plug installed B-4(2/82): [: 4,528'-4,587' . 3 1/2"Otis XA Sleeve @ 4,607' Baker Locator @ 4,620' Baker Mod D Pkr w/Seal assy @4,621' x Lower B-4 Sd(2/82): '<. 4,641'-4,661' ?` a .c ' Baker Locator @ 4,999' i' A Baker Mod D Pkr w/seal assy @4,999' Sqzd Isolation " (2/82): C-1 (3/82): Baker bull nose entry 5,103'-5,105' 5,106'-5,152' ;. guide @ 5,048' 5,160'-5,162' Last Tagged Fill 9 5/8", 47 ppf, N-80 @ 5,371' 5,136'(5/95) Well Name&Number: KU 11-17 Lease: County or Parish: Kenai Peninsula Borough State/Prov. Alaska Country: USA Perforations(MD) (TVD) Angle/Perfs Angle @ KOP and Depth BHP: BHT: I Completion Fluid: Dated Completed: Mike Sulley 6/1/2011 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday,May 04,2015 TO: Jim Regg SI a1 is P.I.Supervisor l e74 SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC 11-17 FROM: Jeff Jones KENAI UNIT 11-17 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry...leg-- NON-CONFIDENTIAL Comm Well Name KENAI UNIT 11-17API Well Number 50-133-20349-00-00 Inspector Name: Jeff Jones Permit Number: 181-176-0 Inspection Date: 4/21/2015 Insp Num: mitJJ150501075405 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 11-17 1TYpe Inj W "TVD 3958 Tubing) 1250 1300 - 1300 - 1300 PTD Type Test 1811760 �+--_----SPT Test psi 1500 ' IA 260 2000 1980 - 1980 Interval FOTHER P/F P OA o 0 0 - o Notes: 2 year MIT < 1 BBL methanol pumped 1 well!inspected,no exceptions noted SCANNED MAY 2 2 2 9 Li Monday,May 04,2015 Page 1 of 1 Ima, ect Well History File Cover XHVZE This page identifies those items that were not scanned during the initial production scanning phase, They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Organizingj~o.~) ~items: Well Hist~ory File Identifier DIGITAL DATA [] Diskettes, No. [] Grayscale items: [] Other, No/Type [] Poor Quality Originals: [] Other: NOTES: BY: BEVERLY ROBIN VINCENT SHERYL (~ WINDY OVERSIZED (Scannable) [] Maps: Other items scannable by large scanner OVERSIZED (Non:Scannable) [] Logs of various kinds [] Other Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL MARIA WIN~ DATE:, J7"4¢. /'" = TOTALPAGES Scanning Preparation BY: BEVERLY ROBH~~HERYL MARIA WINDY Production Scanning Stage '1 PAGE COUNT FROM SCANNED FILE: ~ PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: / YES BEVER.'dE ,NCEN'. S.E.Y. MAR,A W,.D¥ BY: Stage 2 BY; (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE SASI$ DUE TO QUALITY, GRAY$CALE OR COLOR IMAGES) NO IF NO IN STAGE t ~ PAGE(S) DISCREPANCIES WERE FOUND: YES NO ReScanned (individual page [,special at~et~t~pn] scetming comptet, ed) RESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARI,~ WINDY DATE: Is~ General Notes or Comments about this file: Quality Checked 12110102Rev3NOTScanned.wpd MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday,May 03,2013 TO: Jim Regg , 5 JIDlt-3 P.I.Supervisor SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC 11-17 FROM: Bob Noble KENAI UNIT 11-17 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KENAI UNIT 11-17 API Well Number 50-133-20349-00-00 Inspector Name: Bob Noble Permit Number: 181-176-0 Inspection Date: 5/1/2013 Insp Num: mitRCN130502105446 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well H-17 Type Inj W `TVD 3958 IA 7 431 1809 1799 1798 ' _. . 1811760 � SPT PTD Type Test�� Test psi l 1500 " '�I OA o I o I o Interval j0THER P/F P Tubing! 1180 . 1180 1180 1180 - — Notes: 2 yr MIT 41.11./ 1 ArCi-o— SCANNED FEB 2 0 2014 • Friday,May 03,2013 Page 1 of 1 • • AOGCC Docket 10 -12 MIT Test Anniversary Dates Marathon Oil Company Request Dated May 26, 2010 Background Marathon requested changing the anniversary dates of eight Kenai Peninsula injection wells to allow the mechanical integrity test (MIT) required by regulation/order to be performed during summer months. Marathon proposed the wells be adjusted to show a September 1 anniversary date. Action Marathon's email request dated May 26, 2010 followed several telephone discussions between Kevin Skiba (Marathon; 907 - 283 -1371) and Jim Regg (AOGCC; 907 - 793 - 1236). Subsequent to the email request, telephone discussions were held on June 1, 2010, February 7, 2011 and February 8, 2011. Mr. Skiba was told that the following during discussions: - MIT due date can be changed by simply scheduling the test during the summer months; - Tests must be completed in advance of the next due date; - Make sure to give AOGCC Inspectors the required advance notice to allow for opportunity to witness; AOGCC witness is required to adjust the anniversary date; - Industry Guidance Bulletin 10 -002 provides details about testing injectors for mechanical integrity. Marathon was told the proposed September 1 anniversary date would not work for all wells since some MITs would be performed later than the currently required anniversary date. Resulting from the guidance provided to Marathon, the anniversary date for each of the eight injection wells has been changed based on successful, witnessed MITs as shown below: Well PTD MIT Completed Next MIT Due Beaver Creek Unit 2 1670260 5/4/2011 5/4/2015 Kenai Beluga Unit 23x -6 1841090 5/25/2011 5/25/2015 Kenai Unit 11-17 1811760 5/3/2011 5/3/2013 Kenai Unit 12 -17 2080890 5/3/2011 5/3/2013 Kenai Unit 24 -07RD 2050990 5/3/2011 5/3/2015 Kenai Unit 31 -7X 2001480 5/25/2011 5/25/2015 Kenai Unit WD -1 1811070 5/3/2011 5/3/2015 Sterling Unit 43 -09 1630110 5/4/2011 5/4/2015 With MITs completed on these wells during May 2011, Docket 10 -12 can be closed. James B. Regg / 1 October 6, 2011 • . . Colombie, Jody J (DOA) From: Regg, James B (DOA) Sent: Wednesday, May 26, 2010 11:25 AM To: Colombie, Jody J (DOA) Subject: FW: MIT tests anniversary date setup Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Skiba, Kevin J. [mailto:kskiba @marathonoil.com] Sent: Wednesday, May 26, 2010 11:10 AM To: Regg, James B (DOA) Subject: MIT tests anniversary date setup Jim, Below is a list of Marathon Alaska's injection well MIT dates. Well Last test Frequency Next test BC -2 1/15/08 4 -year 1/15/12 KBU 23x -6 6/4/07 4 -year 6/4/11 KU 11 -17 5/12/10 1 -year 5/12/11 KU12 -17 8/27/09 2 -year 8/27/11 KU 24 -7RD 2/12/10 2 -year 2/12/12 KU 31 -7x 8/8/07 4 -year 8/8/11 SU 43 -9 5/13/09 2 -year 5/13/11 WD -1 5/12/10 4 -years 5/12/14 As per our telephone conversation, we would like to set up an anniversary date for the MIT tests on these wells. As stated, the anniversary date would allow us to complete the MIT tests in the summer months without having the forward movement affect on the test dates. With that said, we are interested in a September 1 date as the anniversary date. Please let me know if you need any additional information concerning this request. Thanks again, Kevin Skiba Regulatory Compliance Representative Marathon Alaska Production LLC 1 Office (907) 283 -1371 • Cell (907) 394 -1880 Fax (907) 283 -1350 2 • • co � O L P a a SEAN PARNELL, GOVERNOR 0 .) ALASKA. OIL AND GAS 333 W. 7th AVENUE. SUITE 100 CONSERVATION CO1rII1'I<ISSION ANCHORAGE. ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 ADMINISTRATIVE APPROVAL NO. DIO 9.001 Mr. Kevin Skiba Regulatory Compliance Representative Marathon Alaska Production LLC " AU z t i r P.O. Box 1949 Kenai, AK 99611 Re: Mechanical Integrity Test Time Interval Revision DIO 9 — Kenai Unit 11- 1'708117611) Dear Mr. Skiba: Marathon submitted an Application for Sundry Approvals (Form 10 -403) dated April 04, 2011 requesting the 1 -year Mechanical Integrity Test (MIT) interval currently in place for the subject well be changed to the standard 4 -year test interval contained in 20 AAC 25.252 (d). The standard 4 -year test interval is specified in Rule 2 of DIO 9; however a 1 -year test interval has been in place since tubing by inner annulus communication (TxIA) was suspected in 1998. Since the MIT interval is set forth in a Commission order, Marathon's request cannot be granted via Sundry Approval. The Commission will treat the request as an application for administrative approval under Rule 7 of DIO 9. Marathon's request to change the MIT interval is GRANTED in part, however the specified test interval will be 2 years. The request is granted based upon the MIT records for this well; a 2 -year interval is specified so that the well may be a readily available back -up for slurry injector KU 12 -17 (2080890) located on the same pad. In addition, the Commission has revised the text of Rules 2 and 3 to conform to the Commission's current integrity requirements. Now therefore, as provided by Rule 4 of DIO 9, Rules 2 and 3 are hereby revised as follows: RULE 2: Demonstration of Mechanical Integrity The mechanical integrity of an injection well must be demonstrated before injection begins, and before returning a well to service following a workover affecting mechanical integrity. After injection is commenced for the first time in a well, when injection conditions (temperature, pressure, rate, etc.) have stabilized, a Commission - witnessed MIT must be performed. Subsequent tests must be performed at least once every two years. The Commission must be notified at least 24 hours in advance to enable a representative to witness mechanical integrity tests. Unless an alternate means is approved by the Commission, mechanical integrity must be demonstrated by a tubing/casing annulus pressure test using a surface pressure of 1,500 psi or 0.25 psi/ft multiplied by the vertical depth of the packer, whichever is greater, that shows • • DIO 9.001 July 7, 2011 Page 2 of 2 stabilizing pressure and does not change more than 10 percent during a 30 minute period. Results of mechanical integrity tests must be readily available for Commission inspection. RULE 3: Well Integrity Failure and Confinement Whenever any pressure communication, leakage or lack of injection zone isolation is indicated by the injection rate, an operating pressure observation, a test, a survey, a log, or any other evidence, the operator shall immediately notify the Commission, obtain Commission approval to continue injection and submit a plan of corrective action on Form 10-403 for Commission approval. A monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating any well integrity failure or lack of injection zone isolation. Except as otherwise specifically modified herein, the statutes and regulations of the Commission as well as the provisions of DIO 9, remain in full force and effect. tiUstw o 4 DONE at Anchorage, Alaska and dated July 201J I j t , M . .. , • drI1,/ r amel T. Se: ' ount, Jr. irrs ' . Norman athy ' . Foerster Chair Co ' . ioner Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10-days is a denial of reconsideration. lithe Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[tlhe questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday. II MEMORANDUM Stat NDUM of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Friday, May 27, 2011 Jim Regg P.I. Superv ( 5 1 0- 71/1 SUBJECT: Mechanical Integrity Tests MARATHON OIL CO 11 -17 FROM: John Crisp KENAI UNIT 11 -17 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Well Name: KENAI UNIT 11 - 17 API Well Number: 50 133 - 20349 - 00 - 00 Inspector Name: John Crisp Insp Num: mitJCr110505133635 Permit Number: 181 - 176 - Inspection Date: 5/3/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well i 11-17 Type Inj. W TVD 3958 IA 400 1590 1580 1580 P.T.D! 1811760 + TypeTest I SPT Test psi 1500 _ OA 3 3 3 3 ■ Interval OTHER p /F P . - Tubing' 1500 1540 I 1600 1660 J Notes: 44 gal. 80/20 methanol pumped for pressure test. Produced water injection started 15 minutes prior to MIT. Injection pressure rising during MIT. I was concerned with the tubing pressure being very close to MIT test pressure. Talked with Senior Petroleum Engineer Tom Maunder about test pressure. Torn indicated that test pressure was all that was required by AOGCC. Well is on 1 year test cycle & Marathon has request in to AOGCC to return this well to 4 year cycle. Thermal stabilization due to short amount of time injecting cold water would be very difficult to obtain. Jim Regg will make pass /fail determination. Jim Regg determined test was a pass. Wellbore schematic & injection graph attached to report. TP-- � N b 2011 Friday, May 27, 2011 Page 1 of 1 . 0 0 KU 11 -17 Pth 191- (7(e '5) rd MARATNO) Tbg Hgr @ 18.5' t- t- 1 f I f li KU 11 -17 ,, `" ! Kenai AK � RT -GL =0' I �' b* 20 -Apri1-2006 13 3/8 ", 61 ppf, K -55 Csg @ 1994' ', �' _1 :f Notes: 1 k 1 I Short string injection i. r appears to be through damaged plug in XN at IA A. 4520' RKB into B4 .t„,. '3 Long string injection t ; • appears to be through : a hole in blast joint at S 1 4490' RKB into B -3 ot r f r .; 3 1/2" Otis XA Slv @ 4337' ± I 3 1/2" Otis XA Sleeve @ 4343' 4 . q Baker Model A -5 Dual Packer @ 4347' B -3 (2/82): ?" - "; Blast Jts Hole at 4490' ?? 4468' -4483' ", 4456-4505' 3 1/2" Otis XA Slv © 4430' d� Tag 4490' 20- Apr -06 ,' e- ' ` Baker AL -5 Dual Packer @ 4508' 3 1/2" Otis XN 'r Nipple @4520' ''+ Blast Jts 4519' 4597' Plug installed B -4 2/82 /,' Plug Leaks ?? 4528'4587' 3 1/2" Otis XA Sleeve @ 4607' Baker Locator @ 4620' i Baker Mod D Pkr w/ Seal assy @4621' Lower B -4 Sd (2/82): 4641' -4661' : Baker Locator @ 4999' fr-t 4 Baker Mod D Pkr w/ seal assy @4999' Sqzd Isolation I f Baker bull nose entry (2/82): C 1 (3/82) r . , 5103' -5105' 5106- 5152' ,, c' ° guide @ 5048' 5160' -5162' Last Tagged Fill 9 5/8 ", 47 ppf, N -80 © 5371' 5136' (5/95) Well Name & Number: KU 1 1 -1 7 Lease: County or Parish: Kenai Peninsula Borough State: Alaska I Country:1 USA Perforations (MD) (TVD) Angle © KOP and Depth: AnglelPerfs: Dated Completed: . IN. v 11 _ / 1 ° v r /1 ;!2r1! it:51.73 "'4, 1St p, • __ _ _ _ • (4/19/2011 12:12:23 AM) 367 psi 111 psi (62 days, 23:18:00) 20 1.0120 2000 1000 • r d 0 ° II ��a" ° +° N•es. J a. o• • • . N. ° I `a . °• • • r • ` s• • 4 •• a .. ° .• • ° � • •. . ° °° °i •� w�• - ' fe / 114 w+ "o • e• diwrlort a •w .411 • ° 016 ► • ,Matte• • b4 ••••"* • V* e . ° e: � e a • o • . •. • elk,. a • ' ° • a . o • M 4a • . • n ...moo • i.N•• e° • •! • • e .• • •H • •niN ewee•. o n• ea or M ® m owe • •M NM • !• eere rrl •® •a*i v • • e Q •p+ • 0 NUMONIMilinforil 0 2/1/2011 2/19/2011 • • 3/9/2011 • 3 /27/2011 4/14/2011 5/2/2011 12:03:23 PM 11:51:23 AM 11:39:23 AM 12:27:23 PM 12:15:23 PM 12:03:23 PM Tag Name I Des - 1.server Cabr tints I > m I 1I0Adana - i lime Offset I © U: A4118 KGF ProdWater_Inj_FT 41 -18 KGF W.W. Injection Fbwrate KGFR5969 BPD 0 20 1lkgfrs960lVIEWITegN... 0:0000.... la A4118 PLC KGF_Inj_Ttotal 41 -18 KGF W.W. Inj. Today's Total KGFR5969 Barrels 0 10 ilkgfrs9601VIEWITagN... 0:00:00..,. ®L A4118 Web 11 17 Outer Cas 41-18 WeN 11-17 Outer Casing Psi C:a KGFR5969 psi 0 1000 11kgfrs9601VIEWjTagN... 0:00:00.... ❑ IL A4118 Well_11 17 Tempp 41-18 WeN 11 -17 Temp KGFR5969 Deg F 50 100 l\kgfrs9601V1EWITag 1.., 000:00.... . El LL A4118_We 11 17A_INFSi 41 -18 Well 11 -17A Inj. Psi .rA KGFR5969 - psi 0 1000 1lkgfrs960\VIEW ITagN... 0:00:00.... ® { , A4116 WeN_11 17L InjPsi 41 -18 Well 11 -171 Inj, Psi 11.s KGFR5969 psi 0 2000 11krs9601V1EWjTagN,.. 0:00:00.... ' 0 Cii.1 A4118_WeN_11 17S_Infsi 41 -18 Wel 11- 1751nj, Psi T KGFR5969 psi 0 1000 ilkgfrs9601VIEWITagN,.. 0:00:00.... Prb i ( b l 1-1(!'' Page 1 of 2 • • Maunder, Thomas E (DOA) From: Dammeyer, Michael D. [mddammeyer@marathonoil.com] Sent: Thursday, April 14, 2011 10 :49 AM To: Maunder, Thomas E (DOA); Skiba, Kevin J. Cc: Ibele, Lyndon; Ellis, Michael Subject: RE: KU 11 -17 (181 -176) Tom, Marathon Alaska has six Class II injection wells, but currently injects slurry into only one, KU 12 - 17 (208 -089). As a backup for slurry injection, two other wells are configured so they can take slurry from our G &I plant; they are KU 24 - 7RD (205 -099) and KU 11 - 17 (181 -176). However, G &I hasn't injected slurry into these wells for some time, and doesn't intend to unless something goes wrong with 12 -17. Please email or call with any further questions, Michael Dammeyer Marathon Alaska Production LLC Production Engineer 907- 283 -1333 (office) 907 - 394 -8270 (cell) } From Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, April 13, 2011 4:17 PM To: Skiba, Kevin 3. Cc: Dammeyer, Michael D. Subject: RE: KU 11 -17 (181 -176) Kevin and Michael, Thanks for the information. As I have been researching the files, another question has come up. Regarding 24 -7RD, is it a slurry injector'? If not, what wells do you have that are slurry injectors' Thanks in advance. Tom Maunder, PE AOGCC From: Skiba, Kevin J. [mailto:kskiba @marathonoll.com] Sent: Monday, April 11, 2011 3:12 PM To: Maunder, Thomas E (DOA) Cc: Dammeyer, Michael D. Subject: FW: KU 11 -17 (181 -176) Tom, Below are answers that Michael Dammeyer supplied to me. Let me know if you need anything else. Thanks again, Kevin Skiba Regulatory Compliance Representative Marathon Alaska Production LL,C Office (907) 283-1371 Cell (907) 394 -1880 Fax (907) 283 -1350 From: Dammeyer, Michael D. Sent: Monday, April 11, 2011 2:59 PM To: Skiba, Kevin 3. Cc: Ellis, Michael; Ibele, Lyndon Subject: RE: KU 11 -17 (181 -176) Kevin, Here's the answers to Tom's questions. 1. Is a positive pressure maintained on the annulus while injecting? Yes, around 330 psig. See trend below for the last 30 days; orange trend is annulus pressure. 2. Is there a pressure response in the annulus while the well is on injection? Yes, the annulus pressure responds to injection. See trend below for the last 30 days; orange trend is annulus pressure. 3. What other disposal wells are located on the same pad? KU 12 -17 KU 24 -7RD 5/26/2011 Page 2 of 2 Ill • (3/12/2011 12:03:30 AM) 332 psi (4/2/20115:0930 PM) 327 psi -5 psi (21 d 20 it 1000 2000 1000 t , iillk PO( N, q,,i,,,,, • „,,,„,„, ., ,,. \ 4 1 . . , ..\ . • • \ : • .- �•�: • • • • •a • • . •••• • • • • • •s •. • • . ' •••.M•••.•W ,....:w..... ..,•.••••.••.•Y•.•.r.4✓.�rs••.•. w•:..•..o►.• • ....... � ..... .a....s.�.y..._:...�.... ..� ... •• ••.•.•_0••••••• . . ; «:..: .a.•. ••••• • •••r• •••� 6 g • • : • ; • • • ; ■ 0 1 1 1 3/7/2011 • 3/13/2 3/19/7 3/25/ 4/1/2011 8:36:30 AM 2:12:30 PM 6:48:30 PM 11:24:30 PM 4:00:30 AM Ten Name .., . , , Server Craw Units J_M'rrmun I Maximum 1 10 Address 1 Time Offset 1 ❑� ill A4118 K(F_PradWater_Inj FT 41 -18 KGF W.W. Injection Flowrate KGFR5969 BPD 0 20 ((kgfrs96O\vIEWITagN... 0:00:00.... © Ill A4818_PLC KGF_Inl_Ttotal 41 -18 KGF W,W. Inj. Today's Total KGFR5969 Barrels 0 10 (lkgfrs9601VIEWITa9N... 0:00:00.... © I A4IIB_Wei_11_17 Outer_Cas 41 -18 Wel 11 -17 Outer Casing Psi KGFR5969 psi 0 1000 ttkgfrs960WIEWITagN... 0:00:00.... ❑ LLI A4118 We8_11 17_Temp 41 -18 Wel 11 -17 Temp KGFR5969 Deg F 50 100 \\kgfrs960WIEW ITagN... 0:00:00.... 41 -18 Wel 11-17A Inj. Psi KGFR5969 psi 0 1000 \/ frs960\ VIEW ITagN... 0:00:00.... ❑� - A4118_WeI_11_17L_Innsi 41 -18 Wel 11 -17L Inj. Psi KGFR5969 psi 0 2000 0kgfrs960\VIEW ITagN... 0:00:00.... i 21 A4118_Wel_11_175 Inpsi 41-18 Wel 11 -175 Inj. Psi KGFR5969 . psi 0 1000 ■(kgFrs960\VIEWITagN... 0:00:00.... From: Skiba, Kevin 3. Sent: Monday, April 11, 2011 2:47 PM To: Dammeyer, Michael D. Subject: FW: KU 11 -17 (181 -176) Mike, Can you help answer these questions? Kevin Skiba Regulatory Compliance Representative Marathon Alaska Production LLC Office (907) 283 -1371 Cell (907) 394 -1880 I Fax (907) 283 -1350 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, April 11, 2011 8:19 AM To: Skiba, Kevin J. Subject: KU 11 -17 (181 -176) Hi Kevin, I am looking at the sundry request to change the MIT cycle from 1 year to 4 year. I am not sure these questions are for you, but I bet you know who has the answers. According to the well history, a 1 way leak from tubing or pacer to annulus was reported 11/6/98 and the MIT schedule has been annually since. Most of the reports 1 read note that the annulus is already pressured up when the Inspectors arrive due to "pre- testing ". 1 Is a positive pressure maintained on the annulus while injecting? 2. Is there a pressure response in the annulus while the well is on injection? 3. What other disposal wells are located on the same pad? Thanks in advance, Tom Maunder, PE AOGCC 5/26/2011 • Marat. Alaska Production LLC Alaska Asset Team Marathon P.O. Box 1949 MARATHON Alaska Production LLC Kenai, AK 99611 Telephone 907/283 -1371 Fax 907/283 -1350 April 4, 2011 RECEIVED Mr. Winton Aubert C 1�' L APR tI i Alaska Oil & Gas Conservation Commission 333 W 7 Ave Ativka Oil & £as Cons. Commission Anchorage, Alaska 99501 Arivornc Reference: 10 -403 Application for Sundry Approvals Field: Kenai Gas Field Well: Kenai Unit 11 -17 AMMED AUG 1 : 2011 Dear Mr. Aubert: Submitted for your approval is the10 -403 Application for Sundry Approvals for KU 11 -17 well. Marathon request that the MIT test schedule, for KU 11 -17, be converted to a 4 -years cycle from its present 1 -year cycle. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, Kevin J. Skiba Regulatory Compliance Representative Enclosures: 10 -403 Application for Sundry Approvals cc: AOGCC Current Well Schematic Houston Well File Detailed Operations Program Kenai Well File KJS eA STATE OF ALASKA ' %0". • ALASKA•AND GAS CONSERVATION COMMISSIO• // • i 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 ❑ Perforate ❑ Pull Tubing ❑ Specify: Time Extension ❑ Operational shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter casing ❑ Other: Change MIT Schedule to 4 yrs - El 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Marathon Alaska Production LLC Development ❑ Exploratory ❑ 181 -176 _ 3. Address: PO Box ' 949 Stratigraphic ❑ Service El , 6. API Number: Kenai Ala- a, 99611 -1949 50- 133 - 20349 -00 -00 - 7. If perforating, closest approach in . •ol(s) opene this operation to nearest 8. Well Name and Number: property line where ownership or Ian.. wnership anges: Spacing Exception Required? Y No el Kenai Unit 11 -17 9. Property Designation (Lease Number): 10. Field /Pool(s): _ ADL 22330, FEE - CIRI Kenai Gas Field / Sterling Pool 5.1 & 6, Undefined WDSP 11. PRE ENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): E - ctive D MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 5,400' - 4,856' ..-- 5,2 4,758' NA 5,270' Casing Length "°'-/ ize MD TVD Burst Collapse Structural Conductor 176' ` 20" 192' 192' Surface 1,978' tt3&318" 1,994' 1,889' 3,090 psi 1,540 psi Intermediate Production 5,355' 9 - 5/8" 371"‘"`N..,j 4,840' 6,870 psi 4,750 psi Liner L"" Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): B -3 4,468'- 4,483' 4,062'- 4,075' Short ---- 3 /2" N -80 4,522' B -4 4,528'- 4,587' 4,114' - 4,164' Long c..3`-k1/ -" N -80 5,049' C -1 5,106'- 5,152' 4,611' - 4,651' �-^ "----. J\ Packers and SSSV Type: Baker Models A -5 & AL -5 Dual Packers Packerg and SS V MDD.(ft� and TVD (ft): 4,347' & 4,508' 3,959' & 4,097' Two Baker Model D Packers C1 4,621' & 4,999' 4,193' & 4,519' 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after pr osed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ De opment ❑ Service El - 14. Estimated Date for 15. Well Status after propos work: Commencing Operations: Oil ❑ Gas ❑ \ WDSPL 0- Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ \ WAG El Abandoned ❑ Commission Representative: G GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283 - 1371 Printed Name Kevin J. Skiba Title Regulatory Compliance Representative Signature ` G Pilo (907) 283 -1371 Date April 4, 2011 i ) COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ( I 1 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ RECEIVED Other: APR 0 6 tf!�iw� At ska Ctrl & Gas CaIls. Commission Subsequent Form Required: An toI'a APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Form 10 -403 Revised 1/2010 ORIGINAL Submit in Duplicate • • April 4, 2011 M MARATHON Marathon Oil Corporation Field: Kenai Gas Field KU 11 -17 Convert to 4 -year MIT Test Schedule Well Status: Class -2 Injection Well Objective: Convert MIT test schedule from 1 -year to 4 -year test cycle History: KU 11 -17 was placed on a 1 -year MIT test cycle based on a suspected tubing/casing leak. The well has been passing yearly MIT tests verifying that there are no down -hole mechanical issues. Request: Marathon request that the MIT test schedule, for KU 11 -17, be converted to a 4 -years cycle from its present 1 -year cycle. Successful completion of past MIT tests has confirmed that there is no tubing/casing leakage. KU 11 -17 is not used for slurry injection. It is only used for produced water injection well. The last MIT test was performed on May 12, 2010. Conversion to a 4 -years schedule would place the next test date as May 12, 2014. . • • KU 11 -1 7 i 11 ( :M ) MARATHON Tbg Hgr © 18.5' KU 11 -17 Kenai AK RT -GL =O' 20 -April -2006 13 3/8 ", 61 ppf, K -55 Csg @ 1994' Notes: Short string injection appears to be through damaged plug in XN at 4520' RKB into B -4 Long string injection appears to be through hole in blast joint at 4490' RKB into B -3 3 1/2" Otis XA Sly © 4337' 3 1/2" Otis XA Sleeve © 4343' • r Baker Model A -5 Dual Packer @ 4347' lo ii 4 B-3 (2/82): III Blast Jts Hole at 4490' ?? 4468' -4483' +1 1 4456' -4505' 3 1/2" Otis XA Slv @ 4430' . �_) r Tag 4490' 20 - Apr - iv,,, Baker AL -5 Dual Packer @ 4508' 3 1/2" Otis XN Nipple ©4520' IL Blast Jts 4519' -4597' Plug installed B-4 (2/82): Leaks ?? Plug 4528' -4587' 11. 3 1/2" Otis XA Sleeve @ 4607' Baker Locator @ 4620' Baker Mod D Pkr w/ Seal assy @4621' Lower B -4 Sd (2/82): l 4641' -4661' Baker Locator @ 4999' ' Baker Mod D Pkr w/ seal assy @4999' Sgzd Isolation C - (3/82): }� i 182): Baker bull nose entry 5103.-5105' 5106' -5152' g uide @ 5048' 5160' -5162' J Last Tagged Fill 9 5/8 ", 47 pP , N -80 @ f 5371' 5136' (5/95) Well Name & Number: KU 1 1-1 7 Lease: County or Parish: Kenai Peninsula Borough State: Alaska 1 Country:) USA Perforations (MD) (TVD) Angle @ KOP and Depth: Angle /Perfs: Dated Completed: MEMORANDUM • State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 26, 2010 To: Jim Regg ~ ~ E~f ~ ~ l;, P.I. Supervisor ~ SUBJECT: Mechanical Integrity Tests MARATHON OIL CO 11-17 FROM: Jeff Jones KENA] tJNTT 11x7 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed B~ P.I. SuprvJ Comm Well Name: KENAILINIT 11-t7 API Well Number: 50-133-20349-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ10052016s633 Permit Number: 181-176-0 Inspection Date: s/12/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Wel~ n-v ''Type Inj. P.T.D tsu76o~'TypeTest --- ~'~ sPT ~ -~ TVD 9s3 s Test psi ]soo i - IA pA sso ]sso ~' ' o ]o I -~ ]gso ]o ]sso ]o -- Interval oT~R p/F P Tubing ~ 12so it ]zzo ]z6o ]zso Notes: < 1 BBL 50/50 methanol pumped. 1 year MIT cycle. 1 well inspected; no exceptions noted. 1~^ ^ ". Wednesday, May 26, 2010 Page 1 of 1 MIT results -Marathon Alaska Prod~on LLC -Wells WD O1 & KU 11-1712-10 Page 1 of 1 Regg, James B (DOA) ~ l~ ~- (~(~ From: Dammeyer, Michael D. [mddammeyer@marathonoil.com] Sent: Thursday, May 13, 2010 2:23 PM ,~~~~ ~ I l 1 ~ i u To: Regg, James B (DOA) Cc: Mullin, Mickey; Dammeyer, Michael D.; Laughlin, Gary A. Subject: MIT results -Marathon Alaska Production LLC -Wells WD 01 & KU 11-17 - 5-12-10 Attachments: MIT - WD 01.x1s; MIT - KU 11-17.ZIP Jim Regg, Attached are Mechanical Integrity Test results from two CII wells, WD 01 & KU 11-17, which were performed yesterday (5/12/10). The results are provided on the "MIT Report Form". Multiple sheets on each well's form provide both current and previous MITs, with corresponding graph showing the SCADA pressure trends during each MIT (note that for well WD 01 the SCADA annulus pressure sensor maxes out at 518 psi, however, the calibrated gauge used for the MIT was reading correctly and this pressure is provided on the form). Sincerely, Michael Dammeyer Marathon Alaska Production LLC Production Engineer 907-283-1333 (office) 907-394-8270 (cell) E' F~ {[` Kra ,~ ~ ~~ u, «MIT - WD 01.x1s» «MIT - KU 11-17.ZIP» 5/19/2010 Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: Marathon Oil Company ~'~ ~~ 1tJ FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Kenai Gas Field /Pad 41-18 05/12/09 Mickey Mullin Jeff Jones • Packer Depth Pretest 2:25 2:40 2:55 Well KU 11-17 Type Inj. W TVD ~ 3,958' Tubing 1,250 1,220 1,260 1,280 Interval 1 P.T.D. 1811760 Type test P Test psi 1500 Casing 850 1,850 1,850 1,850 P/F P Notes: There was 1050 psi on IA to begin test because apre-te OA 0 0 0 0 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P~F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G =Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) ~U~~~~ ~~ ~~~ <<-~7 SliZ~i~ 200 4000 ~9n 2000 0 1:50:00 PM sllz/zolo 5112,J2010 5/12/2010 silzlzolo KGFR5969:A4118 Wdl 11_174_InjPSi [Cyclic-0000:00:09.712) s; lvzola ^ %y A4118_KGF_RodWater_Inj_FT 41-18 KGF W.W. Injection Flowrate KGFR5969 BPD 0 20 ~~kgfrs960~VIEW~TagN... Oam:00..,. ^ ~' A4118_PLC_KGF_Inj_Ttotal 41-18 KGF W.W. Inj. Today's Total KGFRS%9 Barrels 0 ]0 titikgFrs960~VIEW~TagN... 0:00:00.... ^~ i~A4118_Well_I I_17_Outer_Cas 41-I8 We811-17 OUter Casing Psi KGFR5969 psi D 200 titikgFrs960~VIEW~TagN... 0:00:00.... ® ®A4318_WeR_li_17A In1PSi 41-IB Well 11-17A Inj. Psi KGFR5969 psi 0 4000 ti,~kgFr5960~VIEW~TagN.,. 0:00:00.... Q ~ A4118_Well_II_I7L_InjPsi 41-IB Well 11-17L Inj. Psi KGFR5969 psi 0 2000 >,tikgfr5960ti,VIEW ~TagN... 0:00:00.... i~ A4118_Well_11_375_InjPsi 41-18 Wefl i1-175 Inj. Psi KGFRS%9 Dsi 0 20~ titikgfrs960~VIEW~TagN.,. 0:00:00.... _ _ : ~:~_ FI.i X52 c= i5~ LN2~riC :30:51 PM) 1850 Psi 998 psi (0 days, 00:3z:48j Tv~,~.Y; L~ / Z 7~ L x•08.00 PM x'26.00 PM ~•aa•nn oM 107:00 PM 3:20:00 PM s(12J2010 • From: Dammeyer, Michael D. [mailto:mddammeyer@marathonoil.com] Sent: Thursday, April 15, 2010 12:44 PM To: Maunder, Thomas E (DOA) Cc: Ibele, Lyndon; Ostroot, James G. Subject: RE: Marathon Alaska Production LLC - Injection ~I KU 11-17 (181-176) Potential Communication Notification Tom, •.~ • v ~ Thanks for the reply; I understand you guys are busy and this is not the only thing on your plate. We will make sure we watch the pressures when we try our first injection cycle, and shut everything down if we see anything amiss. Regarding the volume that was required to pressure up: that's an excellent question and I don't know the answer. The engineer who was observing the MIT is currently in the field; let me regroup with him and I'll let you know. Thanks again, ~~+x ~~~9~~aaii ~F~ ~ ~:~ 20i~~ Michael From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Thursday, April 15, 2010 12:24 PM To: Dammeyer, Michael D. Cc: Ibele, Lyndon Subject: RE: Marathon Alaska Production LLC -Injection Well KU 11-17 (181-176) -Potential Communication Notification Michael, Sorry I have been delayed getting back to you. It appears that it was operator's error that allowed the communication. Marathon's response to the potential communication was appropriate. It does appear appropriate for Marathon to return the well to operation. I only have one question, it is stated that 50 gallons of fluid was pumped into the annulus to achieve the test pressure. Do you have any information as to the volume split between what it might have taken to fill the annulus (fluid pack) and the volume actually employed to pressure up? I have not done the fluid compression calculation myself. Tom Maunder, PE AOGCC From: Dammeyer, Michael D. [mailto:mddammeyer@marathonoil.com] Sent: Thursday, April 15, 2010 11:48 AM To: Maunder, Thomas E (DOA) Cc: Ibele, Lyndon Subject: FW: Marathon Alaska Production LLC -Injection Well KU 11-17 -Potential Communication Notification Mr. Maunder, • I left another message on your voice mail earlier today (4/15/10) regarding the shut-in status of well KU 11-17; this email is a follow-up to that message. As discussed below, since we observed no pressure loss during our MIT on 4/9/10, and believe the original pressure loss from 4/2/10 was merely an operation error and not a mechanical failure, Marathon would like to run a single injection cycle to verify all is well, and if so to continue to use the well. Again, note that we are scheduled to have an AOGCC witnessed MIT in about a month on this well, and this will verify the MIT from the 9th. Your response is appreciated; note that Commission approval is required to continue injection after any irregular pressure observation on this well (KU 11-17 DIO Rule 3). Thank you, Michael From: Dammeyer, Michael D. Sent: Friday, April 09, 2010 4:00 PM To: 'tom.maunder@alaska.gov' Cc: Ibele, Lyndon Subject: FW: Marathon Alaska Production LLC -Injection Well KU 11-17 -Potential Communication Notification Mr. Maunder, This email is a follow up to the phone message I left for you this afternoon. We believe we have found the problem on KU 11-17, which was a slightly open valve on the pressure transducer manifold. We performed performed an MIT on the annulus today after closing the valve, and it tested fine. The trend and notes from the test are below. We would like to run an injection cycle to verify everything is normal. If the pressures check out to your satisfaction, we would then like to return the well to injection (monitoring the pressures as normal).In the meantime, the well is SI and will remain so until we receive your reply. Note that we are scheduled to have an AOGCC witnessed MIT in about a month on this well, and this will verify the test we performed today as well. Thank you, Michael Michael Dammeyer Production Engineer II Marathon Alaska Production LLC 907-283-1333 (office) 907-394-8270 (cell) Test Notes: Upon arrival: outer annulus = 0 psi inner annulus = 300 psi long string = 0 psi raror~nin ~,azia crv~l 3 nti 0 psi (0 days, 02,8:00) L9 PM ~„~ 2010 Ta Name Descri ion Server ! ~= olor Units Minimum Maximum !O Address Time Offset ^~ ®~~~ 41-18Weli I1-17 Outer Casing Psi kgFrs969 psi 0 2000 ~ti,kgfrs960~VIEWITagN.,, 0:00;00.,.. InjPsi Well l l 17A Q~ A4118 41-18 Well 11-17A Inj, Psi kgFrs969 _ psi 0 2000 ti,tikgfrs960ti,VIEW~TagN.., 0:00;00.... _ _ _ _ 17L InjPsi Well l l 0 ~l A4118 41-18 Well 11-17L Inj. Psi kgfrs969 psi 0 2000 ti,~kgfrs960~VIEWITagN... 0:00;00.... _ _ _ ^~ (~; A4118_Well 11_175_InjPsi 41-18 Well i1-175 Inj, Psi kgfrs969 ~ psi 0 2000 ~~kgfrs960ti,VIEW~TagN... 0:00:00.... • u 4f 4/2010 4f9?'2010 4f9fZ010 4l9~2UlU Yry/cuiu ~J It took 50 gals of liquid to fill inner annulus and the pressure test went as follows: initial = 1490 psi 15 min=1485 psi 30 min = 1482 psi The outer annulus and long string remained at 0 psi throughout the test. Pressure on the inner annulus was bled to 790 psi upon completion. Good test! i'Q; 2D10 li 5? :? ~?•'_ ps (4i9~2010 2;47:19 PMj 3 psi 2000 ~.., L__ Q 11:23:1 r~-~ 4.19i2D10 `~59^6:A~11~_W'el~_li_1? O~te+_Css jBts'~t- ®E 941a~i Tag Name 0 Description ~ Server Culc~r Units J Minimun ~~ 41-18 Well 11-17 Outer Casing Psi kgFrs969 psi [ ^~ Lf A4118_Well_i l_17A InjPsi 41-18 Well 11-17A Inj. Psi kgFrs969 ~ psi [ Q (~ A4118_Well_i l_17L_InjPsi 41-18 Well 11-17L Inj. Psi kgfrs969 psi [ ^~ (~!.~ A4118_Well_1l_175_InjPsi 41-18 Well 11-175 Inj, Psi kgFrs969 psi [ 14,19,I'ZO10 4f 9 jZ010 4f 9,rZ010 From: Dammeyer, Michael D. Sent: Monday, April 05, 2010 2:44 PM To: Maunder, Thomas E (DOA) Cc: Ibele, Lyndon; Skiba, Kevin J.; Walsh, Ken Subject: RE: Marathon Alaska Production LLC -Injection Well KU 11-17 -Potential Communication Notification Mr. Maunder, Your rapid response is appreciated. Below is the 90 day trend; we have four pressure monitoring points on this well (short string injection, long string injection, annulus, and outer casing). What we've found so far: - the current annulus/tubing pressures have been verified with physical gauges -the short string sudden drop in pressure from 70 to 40 psi on 4/2/10 was most likely merely a meter blowdown (it was blown down that day) I will keep you updated of anything else we find. In the meantime, the well will remain shut in. Please don't hesitate to call or email with any further questions. oM~,sz ~ ~ -F59 Dsl {IZ days, 15:22:: 2 000 , . r I i~ i i i 1 ~, i~~ ~ I ,! ~ ~ ~ ~ i r. ~ ~, vr, ~j '~~~` i~Y~~,~(~ ~ ~~!~~ ~I~!~y,u~i h>tl~~l~ii~~l>li i .~~I N,lAji' 1~~~ ~I~i ~I~ ~ ~ ~ , 'r `~, ~ 'sit I ! ,, ----- .-- --'- \ ~_ _. __. _._ '~ ~M.., 0 Ii5/2010 ,23jZ010 2J10iZ010 2f28/2010 3/18~20~OA 3 i20 .. ~~-~ 1.15~~7 1:15:37 PM 1:03:37 PM ^ ~, A4118_KGF_ProdWater_InJ_FT 41-16 KGF W.W. Injection Flowratt ^ ;~ A4118_PLC_KGF_Inj_Ttotal 41-18 KGF W.W. Inj. Today's Total © ~ A4118_Well_l l_17_Outer_Cas 41-18 Well 1 Y V Outer Cas!ng Psi ® ~ A4118_Wetl_11_17A_InjPsi 41-t8 Well 11-17A Inj. Psi ^~ ,'!d A4118_We~_1l_17L_InjPsi 41-18 Well 11-17L Inj, Psi ^~ 41j A4118_Well_11 175_InjPsi 41-18 Well ti-I75 Inj. Psi Server Calor LmRs Mkdmum Maximum 7... Time Offse KGFR5969 BPD 0 1000 ~,,. 0:00:00.... KGFR5969 Barrels 0 1000 ti,... 0:00:00.... KGFR5969 psi 0 2000 ~... 0:00:00.... KGFR5969 psi 0 2000 >,... 0:00:00.... KGFR5969 psi 0 2000 ~... 0:00:00.... KGFR5969 p<i 0 2000 ~... O:OD:00.... 10 PM • • From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, April 05, 2010 1:04 PM To: Dammeyer, Michael D. Cc: Ibele, Lyndon Subject: RE: Marathon Alaska Production LLC -Injection Well KU 11-17 -Potential Communication Notification Thanks Michael. Was there any active injection occurring when the annulus pressure loss was noted? Would you please provide a pressure plot that includes the pressures (injection tubing, 9- 5/8" annulus, others?) monitored on the well for the last 90 days? This is the standard request made when an operator reports a suspected pressure integrity loss. Shutting in the well is the appropriate response. I look forward to your reply. Call or message with any questions. Tom Maunder, PE AOGCC From: Dammeyer, Michael D. [mailto:mddammeyer@marathonoil.com] Sent: Monday, April 05, 2010 12:52 PM To: Maunder, Thomas E (DOA) Cc: Ibele, Lyndon Subject: Marathon Alaska Production LLC -Injection Well KU 1i-17 -Potential Communication Notification Mr. Maunder, I called Jim Regg today regarding a potential communication to the annulus on injection well KU 11-17 (the pressure change was noticed on 4/2/10; the DIO for this well requires Commission notification on the first working day following the observation). Mr. Regg requested I send the details to you. KU 11-17 has dual 3.5" strings with a 9-5/8" annulus; we inject through the long-string 3-1 /2" tubing. The annulus has been pressured to around 800 psi for monitoring, and has held steady in the past. Below is the annulus pressure trend (0 - 1000 psi scale) which fell rapidly to -320 psi. This well will remain shut in while we investigate. The long string tubing pressure is currently 160 psi and falling. We have not yet investigated for measurement error, but will do so. Please email or call with any questions, Michael Dammeyer Production Engineer II Marathon Alaska Production LLC 907-283-1333 (office) 907-394-8270 (cell) 4~v pp.ct~ .Marathon & commercial disposal~ough G&I facility ! K Maunder, Thomas E (DOA) From: Stebbins, Tiffany A. [tastebbins@marathonoil.com] Sent: Tuesday, March 09, 2010 9:27 AM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA) Subject: RE: Marathon & commercial disposal through G&I facility Tom, • Page 1 of 2 ~~o ~ Thanks for responding to the subject. If we do begin third party disposal, I will add a line item to capture the volumes on our annual DIO reporting. c'Jti~~,~, ~~,~,,,~ Regulatory Compliance Representative Marathon Oil Corporation Phone 907-565-3043 Ce11907-529-0522 Fax 907-565-3076 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, March 08, 2010 2:03 PM To: Stebbins, Tiffany A. Cc: Regg, James B (DOA) Subject: RE: Marathon & commercial disposal through G&I facility Tiffany, Commission Disposal Injection Orders (DIOs) authorize the Operator to dispose of Class II waste. We have not made any distinction regarding whether the injected waste is solely produced by the Operator or results from some third party's well operations. If third party waste is accepted, it is incumbent on Marathon to be satisfied that the waste is indeed Class II and meets the requirements of the DIO. In your annual report it may be appropriate to have a third party line item where such volumes can be listed. Call or message with any questions. Tom Maunder, PE AOGCC From: Regg, James B (DOA) Sent: Monday, March 08, 2010 11:45 AM To: Maunder, Thomas E (DOA) Subject: FW: Marathon & commercial disposal through G&I facility Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 3/9/2010 Marathon & commercial disposal~ough G&I facility • Page 2 of 2 907-793-1236 From: Stebbins, Tiffany A. [mailto:tastebbins@marathonoil.com] Sent: Monday, March 08, 2010 11:00 AM To: Regg, James B (DOA) Subject: Marathon & commercial disposal through G&I facility Hi Jim, We are considering commercial disposal. Would we need to convert our current disposal permit to a commercial disposal permit even if we intend to only dispose of approved Class II exempt wastes. Thanks, C'Jti~~nu~, ~ ~i~fii.rv~ Regulatory Compliance Representative Marathon Oil Corporation Phone 907-565-3043 Ce11907-529-0522 Fax 907-565-3076 3/9/2010 From: Miranda, Kyle [kmiranda@marathonoil.com] Sent: Friday, June 12, 2009 10:08 AM ~~',~ IZ,e~~1 To: Regg, James B (DOA) ~~~'`~ Cc: Grimaldi, Louis R (DOA) Subject: RE: MIT results KU 11-17, SU 43-9 Attachments: HPIM0481.jpg; HPIM0482.jpg; HPIM0483.jpg; HPIM0486.jpg; HPIM0488.jpg; HPIM0489.jpg; +~ HPIM0490.jpg; HPIM0491.jpg Jim, Here is the follow up for well KU 11-17. Just to clarify, we were unable to visually verify that the OA and IA casing valve positions were open. In addition, Mr. Grimaldi also wanted to make certain that two grease cap fittings were put in place properly; this has been taken care of and is now verified by the pictures attached. The cellar was drained and the valves were manually checked to make sure they were open. All valves were ~ indeed open. Please see attached photos at your convenience. A follow upon well SU 43-09 is soon to follow. Thank you, Kyle Miranda Production Engineer I Marathon Oil Company-Alaska Asset Team 907-283-1370 (office) 907-394-8271 (cell) ,T 1y From: Regg, James B (DOA) [mailto:jim.regg@alaska.govj Sent: Friday, May 29, 2009 5:07 PM To: Miranda, Kyle Subject: RE: MIT results KU 11-17, SU 43-9 Thank you for the info. Couple observations from Inspector's reports that need to be addressed: KU 11-17 -surface casinghead was under water; unable to verify OA casing valve position SU 4Z-09 -surface casinghead was buried with mud/gravel; unable to verify OA casing valve position Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Miranda, Kyle [mailto:kmiranda@marathonoil.comJ Sent: Thursday, May 28, 2009 3:39 PM To: Regg, James B (DOA); Skiba, Kevin J. Cc: Fleckenstein, Robert J (DOA); Aubert, Winton G (DOA) 6/ 12/2009 MIT results KU 11-17, SU 43-9• • Page 2 of 3 Subject: RE: MIT results KU 11-17, SU 43-9 Jim, Sorry about that I had the PTD's ready and accidentally cleared the cell before !sent. I have re-attached the MIT files. There was 1050 psi on the IA of KU 11-17 at the beginning of the test because apre-test was performed the day prior at 1000+ psi was left on the IA, it was not bled off. This 1000 psi was left on the well overnight merely for convenience and time saving for the witnessed test the following day. Also attached is a 90 day plot of tubing, IA, and OA pressures for KU 11-17 prior to the MIT. Please let me know if you need anything else. Likewise, have you found the "MIT guidelines" as described in the attached email message? I am preparing a roles and responsibilities worksheet for Marathon employees regarding MIT's and will finalize it when I receive ail the information from the Commission. Thank you, Kyle Miranda Production Engineer I Marathon Oil Company-Alaska Asset Team 907-283-1370 (office) 907-394-8271 (cell) From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, May 28, 2009 2:40 PM To: Miranda, Kyle; Skiba, Kevin J. Cc: Fleckenstein, Robert J (DOA); Aubert, Winton G (DOA) Subject: RE: MIT results KU 11-17, SU 43-9 Kyle - Please make sure to include required info on forms, namely the PTD. We cannot import the incomplete form into our inspection database. KU 11-17 PTD 1811760 SU 43-09 PTD 1630110 What was the reason for high pre-test IA pressure (>1000psi) in KU 11-17? Please provide for Commission review a plot of tubing, inner annulus and outer annulus pressures for the 90 days prior to MIT . Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Miranda, Kyle [mailto:kmiranda@marathonoil.com] Sent: Thursday, May 28, 2009 11:53 AM To: Regg, James B (DOA) Cc: Skiba, Kevin J. Subject: MTT results KU 11-17, SU 43-9 6/12/2009 MIT results KU 11-17, SU 43-: • Page 3 of 3 Mr. Regg, Please find attached the MIT results for wells KU 11-17 and SU 43-9. Thanks, Kyle Miranda Production Engineer I Marathon Oil Company-Alaska Asset Team 907-283-1370 (office) 907-394-8271 (cell) «KU 11-17 MIT 05-13-09.x1s» «SU 43-9 MIT 05-13-09.x1s» 6/12/2009 • ~ ~ 6 ~ ~~1~ ~~~ Kenai Unit 11-17 (PTD 181-176) Follow-up to Wellhead Issues Identified 5-13-2009 Photos Courtesy of Marathon Refer to email from Marathon (Kyle Miranda, 6-12-09); follow-up to issues identified during AOGCC witness of MIT on Kenai Unit 11-17 1) Casing valves under water; unable to verify IA and OA casing valves positions; 2) Grease cap fillings (2) on wellhead missing IA (right) and OA (left) pressure gauges moved to visible location on KU 11-17 wellhead Stainless steel tubing for new IA and OA pressure gauges • a KU 1 1-17 Inspection Follow-up 6/12/2009 Water in well cellar drained; rust on wellhead indicative of water level in well cellar IA valve and pressure gauge (below grade); gauge block valve position open lA and OA valve positions 2 • KU 11-17 Inspection Follow-up 6/12/2009 IA and OA pressure gauges (below grade; covered w/water in well cellar during 5/13/2009 inspection) Grease cap fitting properly installed Grease cap fitting properly installed • MEMORANDUM TO: Jim Regg ~P.~~ 5~2'`1~U`~ P.I. Supervisor C ~ ~~ FROM: LOU Grimaldi Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, May 14, 2009 SUBJECT: Mechanical Integrity Tests MARATHON OIL CO 11-17 KENAI iJNIT ] 1-17 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~- Comm Well Name: KENAI UNIT 11-17 API Well Number: 50-133-20349-00-00 Inspector Name: Lou Grimaldi Insp Num: mitLG090514064134 permit Number: 181-176-0 Inspection Date: 5/13/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 11.17 Type Inj. D TVD 3958 ~ IA 900 1620 1620 1620 P.T.D 1s1176o TypeTest SPT Test psi 162o OA o 0 0 0 Interval OTHER per, P ./ Tubing 1370 1370 1370 1370 Notes: Yeazly test. IA was at 1050 when I arrived, bled to 900 psi (all fluid) and observed for thiiy minutes with no change. Raised IA pressure to r, could not verify OA casing valve nd er Ovate test of IA. Surface casin~ea d u change. Go solid od 1620 and observed for thirty minutes with no 4Q // '' ~~ ~~ ~~ ~~ ~~ / ~~i cU~~~, ~ 5 ~~~~; position. ~C4fGf-I'~`Cr~ QCJr~`~'&' ~ ~ ~~,,'ec~ l ::y t: Thursday, May 14, 2009 Page 1 of I MIT results KU 11-17, SU 43-. • Page 1 of 2 Regg, James B (DOA) r From: Miranda, Kyle [kmiranda@marathonoil.com] Sent: Thursday, May 28, 2009 3:39 PM ~ S,Z~,~vS ~~ C To: Regg, James B (DOA); Skiba, Kevin J. C Cc: Fleckenstein, Robert J (DOA); Aubert, Winton G (DOA) Subject: RE: MIT results KU 11-17, SU 43-9 ~ ~~I - ~ 7 ~ Attachments: KU 11-17 MIT 05-13-09.x1s; SU 43-9 MIT 05-13-09.x1s; KU 11-17 MIT 2-12-09 to 5-12-09 Pressure Plot.xls; RE: upcoming MITs Jim, Sorry about that I had the PTD's ready and accidentally cleared the cell before I sent. I have re-attached the MIT files. There was 1050 psi on the IA of KU 11-17 at the beginning of the test because apre-test was performed the day prior at 1000+ psi was left on the IA, it was not bled off. This 1000 psi was left on the well overnight merely for convenience and time saving for the witnessed test the following day. Also attached is a 90 day plot of tubing, IA, and OA pressures for KU 11-17 prior to the MIT. Please let me know if you need anything else. Likewise, have you found the "MIT guidelines" as described in the attached email message? I am preparing a roles and responsibilities worksheet for Marathon employees regarding MIT's and will finalize it when I receive all the information from the Commission. Thank you, Kyle Miranda Production Engineer) $'~`°~)'~~, 1~U~~` 'y =' LOCH' a~c.y Marathon Oil Company-Alaska Asset Team 907-283-1370 (office) 907-394-8271 {cell) From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Thursday, May 28, 2009 2:40 PM To: Miranda, Kyle; Skiba, Kevin J. Cc: Fleckenstein, Robert J (DOA); Aubert, Winton G (DOA) Subject: RE: MIT results KU 11-17, SU 43-9 Kyle - Please make sure to include required info on forms, namely the PTD. We cannot import the incomplete form into our inspection database. KU 11-17 PTD 1811760 SU 43-09 PTD 1630110 What was the reason for high pre-test IA pressure (>1000psi) in KU 11-17? Please provide for Commission review a plot of tubing, inner annulus and outer annulus pressures for the 90 days prior to MIT . Jim Regg AOGCC 5/29/2009 MIT results KU 11-17, SU 43-. • Page 2 of 2 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Miranda, Kyle [mailto:kmiranda@marathonoil.com] Sent: Thursday, May 28, 2009 11:53 AM To: Regg, James B (DOA) Cc: Skiba, Kevin J. Subject: MIT results KU 11-17, SU 43-9 Mr. Regg, Please find attached the MIT results for wells KU 11-17 and SU 43-9. Thanks, Kyle Miranda Production Engineer I Marathon Dil Company-Alaska Asset Team 907-283-1370 (office) 907-394-8271 (cell) «KU 11-17 MIT 05-13-09.x1s» «SU 43-9 MIT 05-13-09.x1s» 5/29/2009 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: Marathon Oil Company Kenai Gas Field Pad 41-18 05/13/09 Kyle Miranda Louis Grimaldi Packer Depth Pretest Initial 15 Min. 30 Min. Well KU 11-17 Type In'. N TVD /3,958' Tubing 1,370 1,370 1,370 1,370 Interval 1 P.T.D. 1811760 Type test P Test psi =/1500 Casing 1,050 900 900 900 P/F P Notes: There was 1050 psi on IA to begin test because OA 0 0 0 0 a pre-test was performed the day prior at 1000+ psi was left on the IA, it was not bled off. Well KU 11-17 Type Inj. N TVD 3,958' Tubing 1,370 1,370 1,370 1,370 Interval 1 P.T.D. 1811760 Type test P Test psi 1500 Casing 900 /(,620 1,620 1,620 P/F P Notes: OA 0 0 0 0 Well Type Inj. TVD Tubing Interval P.T.D. T pe test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubin Interval P.T.D. Type test Test psi Casin P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 2009-0513_MIT_KU_11-17_Ig.xls KU 11-17 Pressure Plot 90-day 1800 1600 1400 1200 1000 a 800 600 400 200 0 -200 ~ ~\ `L ~L`L `~ ~\ ~\ \ \ ~ ~, ~ \ -Tubing Pressure [psi] -IA Pressure [psi] OA Pressure [psi] Date MEMORANDUM To: Jim Regg ~~ ~~~~ 5~Z?lcwp P.I. Supervisor FROM: Bob Noble Petroleum Inspector n State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, May 22, 2008 SUBJECT: Mechanical Integrity Tests MARATHON OIL CO 11-17 KENAI LTIIT 1 I-17 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. SuprK".~ Comm Well Name: ICENAI UNIT 1 t-t7 API Well Number: 50-1 3 3-20349-00-00 Inspector Name' Bob Noble Insp Num: mitRCN0805 1 5 1 70945 Permit Number: 181-176-0 ~ Inspection Date: Si15/2008 Rel Insp Num: Packer Depth Pretest Initial.. , 15 Min. 30 Min. 45 Nlin. 60 Min. Well 1117 ''Type Inj. N ; TVD ~ 39a9 ';' IA Isoo j zzso ~ zzso z>>o ~ -- - -- `- J! ---- -- ---- ~ --- - ---- -- YP P ~ --- p T IsI v6o ,T eTest SPT j Test si_ -zzso ~ OA '~ to , Io to to - Tubin ---- -- -- - _.-- ~ ----------- Interval oTI~R p/F P ~ g ; 6zs ~ 6zs 6zs 6v Notes' Well on 2 year cycle. This well is a duel compleation. The second stings pressure was 4s0 throught the test. ~,~;,$~~~ MAY ~; ~ 200 Thursday, May 22, 2008 Page l of 1 MEMORANDUM . State of Alaska Alaska Oil and Gas Conservation com. DATE: Wednesday, June 20, 2007 SUBJECT: Mechanical Integrity Tests MARATHON OIL CO 1I-17 TO: Jim Regg P I( P.I. Supervisor 'f\~(1' bU(ù ? FROM: JeffJones Petroleum Inspector KENAI UNIT 11- 17 ./ \\ ~ \~\ Reviewed By: P.I. Suprv.,Jße.- Comm Src: Inspector NON-CONFIDENTIAL Well Name: KENAI UNIT Il-I7 API Well Number: 50-133-20349-00-00 Inspector Name: Jeff Jones Insp Num: mitlJ070608I00308 Permit Number: 181-176-0 Inspection Date: 6/4/2007 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well , 11-17 Type Inj. I TVD 4505 I IA 820 2250 I 2250 2250 P.T.DI 1811760 TypeTest SPT Test psi 1500 lOA 20 20 I 20 20 Interval OTHER PIF P Tubing I 1640 1540 I 1520 1520 I Notes: 1 year cycle MIT. Dual string well injecting into tubing long string, short string is out of service. There is known communication between both tubing strings. 1 BBL water pumped. . J\j~ ~ '11fJtJ1 S~EO Wednesday, June 20,2007 Page 1 of 1 Tbg Hgr @ 18.5' 13 3/8", 61 ppf, K-55 Csg @ 1994' 3 1/2" Otis XA Slv @ 4337' 3 1/2" Otis XA verified open 6/93 3 1/2" Otis XN Nipple @4520' Plug installed Plug Leaks?? B-4 (2/82): 4528'-4587' Lower B-4 Sd (2/82): 4641 '-4661' Sqzd Isolation (2182): 5103'-5105' 5160'-5162' C-1 (3/82): 5106'-5152' e\-RI-t11e KU 11-17 ~::::: .;.:-~ ~1~ '.;.:.; t~ -~~: tl r 1'1 :". ~ e :~~ ,:.:;;; :~~:? ~~~ ;=;:-;.-. ~~~ ;:;=;:: ::~::: :)~ KU 11-17 Kenai AK -?J ,,,:.: K:::" ~:;:::-: ~~; .~~~~ i! $;::: {;;.;: ~;::: ~}~ '¡it} ~:~;~ it; ::::;::: ;:~~: ;:-::;;: I ~~~: Notes: Short string injection appears to be through damaged plug in XN at 4520' RKB into B-4 Long string injection appears to be through hole in blast joint at 4490' RKB into B-3 3 1/2" otis XA Sleeve @ 4343' Baker Model A-5 Dual Packer @ 4347' Blast Jts Hole at 4490'?? 4456'-4505' Tag 4490' 20-Apr-06 1/2" otis XA Sleeve @ 4607' 95/8",47 ppf, N-80 @ 5371' 8::;;: *:~ :::~:' ':;)¡~: ~~¡;* 5136' (5/95) ". e e l~ l ~-( (¡; ........""".. If ................ ...""'y""........... ....vJ. ..."............ u Subject: Re: Final reports tÖr ;VUTS From: James Rcgg <jim_regg@admin.statc.ak.us> Date: Wed, 25 Jan 2006 14:21 :57 -0900 To: "Cissell, 'Wayne E." <wecissell@marathonoil.com> CC: Louis R Grimaldi <Iou_._grimaldi@admin.state.ak.us> \ -" \0~ \ '2'"' '\<ltt MIT for Kenai Unit 11-17 is attached as witnessed by Jeff Jones. (f'ï1) ü. IVI-17"') re: Kenai Unit 24-7RD, I checked the Operations Summary Report provided with the Well Completion Report - it says Lou witnessed a passing MIT (TxIA) at 0400 hrs 6/30/2005. I do not have a copy of that test from Marathon or Lou. I spoke with Lou this afternoon - he did witness an unsuccessful test done around 11 :00 pm 6/29/2005 but was not available for the test reported as passing - Lou was in the Anchorage office all day 6/30/2005 for inspection meetings. D--.. .. .:it ¡ II) Zfy;-cr('¡ Since your passing test was not witnessed and prior to perforating the well; we would like to do a witnessed MIT with stable well conditions. Please coordinate scheduling with me. Thank you. Jim Regg AOGCC r G, ( (, 1 Cissell, Wayne E. wrote: On 247RD the MIT was done on June 29th, 2005 at 1700 hours. It was pressured up to 1500 psig. On well 11-17 I believe that Jeff Jones witnessed the MIT around the 2nd week in June. Wayne Cissell From: James Regg [mailto:iim reqq@admin.state.ak.us) Sent: Wednesday, January 25, 2006 8:34 AM To: Cissell, Wayne E. Subject: Re: Final reports for MITS Dates for MITs? Cissell, Wayne E. wrote: Jim, I was reviewing our well files and could not find a copy of the MITS for 11-17 or 24-7RD. I found the report when the Rig did the MIT and Lou Grimaldi witnessed but I cannot put my hands on a formal report. Is there a web site we can access to obtain a copy? Wayne E. Cissell Marathon Oil Company Northern Business Unit AAT Advanced Engineering Technician 10f2 1/25/20062:22 PM 1.'-'-'. t HUH l.....pVl L.:J l.Vl .lV..LJ. J. oJ .. e e W ecissel1(ä~Marathonoi 1. com 907-283-1308.394-1324 20f2 2005-0525_MIT_KU_1l-17 --ij.pdf Content-Type: applicationlpdf Content-Encoding: base64 1/25/2006 2:22 PM IVl.ElVl U KAN U U lVl TO: Jim Regg ~/ P.I. Supervisor ~ ~l /:;1 J t lú,; FROM: Jeff Jones Petroleum Inspector Well Name: KENAI UNIT 11-17 Insp Num: mitJJ050603125848 ReI Insp Num: Packer Well I 11-17 [Type Inj. I N I TVD _. P.T. 11811760 ITypeTest fAM~ Test psi Int~rval OTHER P/F P State 01" Alaska Alaska Oil and Gas Conservation Commt, 'ì ) DATE: Monday, June 06, 2005 SUBJECT: Mechanical Integrity Tests MARATHON OfL CO 11-17 KENAI UNIT 11-17 Src: Inspector NON-CONFIDENTIAL API Well Number: 50-133-20349-00-00 Permit Number: 181-176-0 Depth 4505 1126.25 Pretest Initial 2050 J1500 I I 15 Min. 1500 575 \Cö\>t10 Reviewed By: r-:- f! t- P.I. Suprv "..10. Comm Inspector Name: Jeff Jones Inspection Date: 5/25/2005 30 Min. 45 Min. 1500 I I '1-- 575 I 60 Min. I IA I lOA iUbing I 575 575 Notes: Well 11-17 IA was already pressured up to 2050 PSI on my arrival. I verified pressures and monitored for 30 minutes with no change. The IA was then bled to 1500 PSI and monitored for 30 minutes with no change. This well is on a 2 year test cycle. The OA pressure was not accessible due to water and and depth of cellar. I instructed Wayne Cissel (Marathon) to install equipment to enable OA pressure monitoring. Monday, June 06,2005 SCJ\NNED JUN ~!, ~7 2005 ,,,,/ Page I of 1 ( MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Reog --;)" / I P.I. Sup:rv;,., t't'fl '0Tz.IC4- DATE: Monday, June 21, 2004 SUBJECT: Mechanical Integrity Tests MARATHON OIL CO FROM: Lou Grimaldi Petroleum Inspector II-I? KENAI UNIT II-I? \~\~ n h Src: Inspector Reviewed By: ..-.-; P.I. Suprv '- JRt-- Comm NON-CONFIDENTIAL Well Name: KENAI UNIT 11-17 Insp Num: mitLG040618080107 ReI Insp Num: API Well Number: 50-133-20349-00-00 Permit Number: 181-176-0 Inspector Name: Lou Grimaldi Inspection Date: 6/17/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 11-17 Type Inj. N TVD 4861 IA 1950 2080 2080 2080 1600 1600 P.T. 1811760 TypeTest SPT Test psi 1126.25 OA -- Interval REQV AR P/F p Tubing 1000 1050 1020 1000 920 920 Notes: Test req. by variance. Outer annulus could not be observed. IA pressure was decreased 480 psi after 30 min's and observed for additional 30 mins "OK". Monday, June 21, 2004 Page] of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Reudrich Commissioner THRU: Jim Regg "'~1£i P.I. Supervisor FROM: Jeff Jones Petroleum Inspector NON- CONFIDENTIAL DATE: August 15, 2003 SUBJECT: Mechanical Integrity Tests Marathon 41-18 / 34-31 pads WD-1 /KU 11-17 Kenai Unit Kenai Gas Field 1 Packer Depth Pretest Initial 15 Min. 30 Min. | We,,I WD-I IType,nj.I F I T.V.D. 12174 I Tubingl 1000 I~000 I~000 I~000 I,nterva, I 1'/ P.T.D.I 181-107ITypetest] P ITestpsil 544 I Casingl 50 I 17001 17001 17001 P/F I --P / Notes: Tubing leak repaired last year. WellI KU 11-17 I Type Inj. P.T.D.I 181-176 Type test Notes: Packer Depth Pretest Initial 15 Min. 30 Min. Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N -- NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey Interval I- Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover D= Differential Temperature Test O= Other (describe in notes) Test's Details Angust 15, 2003: I traveled to Marathon Oil Co.'s Kenai Gas Field to witness annual MIT's on injection wells WD-1 andKU 11-17. Wayne Cissel was the Marathon representative for the tests today, which were accomplished in a safe an~l proficient manner. The pre-test pressures were observed to be stable and the standard annulus pressure test was then performed. Both wells passed the MIT and are suitable for continued injection. An MIT was also attempted on well KU 24-7 but the annulus would not build pressure. Mr. Cissel indicated he would investigate the cause and report his findings to the AOGCC. Summarty: I witnessed successful MIT's on Marathon's injection wells WD-1 and KU 11-17 in the Kenai Gas Field. M.I.T.'s performed: 2 Number of Failures: 0 Attachments: none Total Time during tests: 7 cc: Don Irwin (KGF Foreman MIT report form 5/12/00 L.G. MIT KGF WD-1, KU 11-17 8-15-03 JJ.xls 8/19/2003 CANNED, AUG 20 3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille O. Taylor Chair THRU: Tom Maunder f-C'dTw/~ P.I. Supervisor FROM: John Crisp Petroleum Inspector DATE: June 27, 2002 SUBJECT: Mechanical Integrity Tests Marathon Oil Co. KU 24-7 , KU 11-17 Kenai Unit Kenai Gas Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. WellI KU24-7 I Typelnj.I N ~ I Tubingl 0 I 0 I 0 I 0 I lntervall O P.T.D.I 1820160 ITypetestl S ITestpsil 1500 I Casingl 1550I 2075 I 20601 20501 P/F I:P~ Notes: Annual MIT. WelllKUa1-171Type,nj.I N ~,o~ ITubingl o I oIo I o I,nterva, I O P.T.D.I 1811760 ITypetestl S ITestpsil 1126 I CasingI 1000I 1700I 1700I 1700I P/F I Notes: Annual MIT. Well P.T.D. Notes: P.I.D. Notes: P.T.D. Notes: Type Inj. Type test IType Inj. Type test IType Inj. Type test Type INJ. Fluid Codes F = FRESH WATER IN J. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4-- Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to Marathon's Kenai Gas Field to witness MIT's on diSposal wellS 24-7 & 11-17. A circular chart recorder was to be used to read pressures for tests on 11-17. I requested Marathon Rep. Wayne Cissell to a!so use ,a pressure :gauge on each well. Zero pressure on tubing for each well was confirmed by opening each well to atmosphere during tests. No failures witnessed. Testing was conducted in a safe & efficient manner. M.I.T,'s performed: 2 Attachments: Number of Failures: 0 Total Time during tests: 3 hrs. cc: MIT report form 5/12/00 L.G. MIT Kenai Gas Field 06-27-02jc.xls 7/8/2002 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser ~ ~\q/' DATE: July 25, 2001 Commissioner SUBJECT: Mechanical Integrity Tests P.I. Supervisor 41-18 / 34-31 Pad Kenai Unit FROM: Jeff Jones Kenai Gas Field Petroleum Inspector ..... Packer ~ Pr~test 'Initial 15 Min.' 3~) Min. P.T.D.I, 1811070 ITyPe't~tl M ITestp~l S44' ,Casingl o' 1550 1,5o0, "14801,P,/F ~-_ Well h_~s_ known tubin( le~_k; tubing tail plug set for test. One year interval MIT Well[ '~2'7:" ITyPe Inj. N .,, I T.v.D. 4313 Tubing 600 600 600 600~;~1 p.T:D;I '1820!'60 ITyPete~{~ M'" IT~tpsi 1078 Casi"~ 1100 2120 2120 2!20. P/F ~: One ye~-_-r interval MIT_, pm~-sum _obse__wed for 30 min. then lowered .500.psi and observed 30 min. WellI Type InI. I N [. T.V.D,' i, I Tubing I "0 I 0 I. ~ o I~.te~a~! . . . ...... "1700 I p~F p.T.D,I' ~S,?~0 IT~t~'l i~' ITe. t.p~ ~2S I casing'I '"1700'I 1700 i ,~?~ Notes: One. Year interval. MIT, p _re~_SUre observed for 30 min. then lowered 500 psi and ob .s~____e~_,, 30 min. Type INJ. Fluid Codes Type Test Interval F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey' A= Temperature Anomaly Survey D= Differential Temperature Test I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details Wednesday, Ju!~'_ . ~ 200..!.;. I traveled to Marathon Oil Co.'s Kenai Gas Field to witness one year MIT's on waste disposal injection wells WD-1, KU 24-7 and KU 11,17. Wayne Cissel was the.Marathon Oil representative in charge of testing today and he performed the tests in accordance with AOGCC regulations. Wells KU 24-7 and KU 11-17 were already pressured up on my arrival and the pressures were observed for 30 minutes with no changes noted. The pressure was then decreased 500 psi on each well and monitored for an additional 30 minutes with no changes noted. Well WD-1 has the test. Once:pressured up;:~ the :tubing .and casing psi. AIl three wells passed the pressure tests and are suitable for continued injection. Summary: I witnessed successful MIT's on Marathon Oil Co.'s Kenai' Gas Field waste disosal injection wells WD-1, KU 24-7 and KU 11-17. 3 wellhouse inspections; 0 failures. M.I.T.'s performed: 3 Number of Failures: 0_. Total Time during tests: 5.hou~ Attachments: 0 ¢c..;, DLon E ,rwin. (. KGF. Foreman) MIT KGF WD-1,KU 24-7, KU 11-17 7-25-01 JJl.xls 8/10/01 MEMORANDUM, I I State of Alaska I Alaska Oil and Gas conservation Commission .......... I .. TO: Dan Seamount i;~ ~-~ DATE: July 5, 2000 Chairman 7, ~12/0"' I SUBJECT: Mechanical IntegritY TeSts THRU': Blair Wondzell ~.t,~ Marathon P.I. Supervisor 7('!~/o(.) Kenai Gas Field I 'l ,, ,,~ WD-1, 11-17, 24-17 FROM: Lou Gdmald~'d)~,~J.- Kenai Gas Field Petroleum Inspector ... Non-confidential packer D.e. pth Pretest Initial 15 Min. 30 Min. Well WD-1 Type Inj. F T.V.D. 2174 Tubing 250 1850 1850 1850 InterVal O P.T.D. '181-107: Type test P Test psi 544 Casing 200 ' 1500 1500 1500 P/F P Notes:~ Lease water injector. Yearly.test Well 24-7 I Type Inj. I O I T.V.D. 4313 Tubing 390 440 440 '440 InterVal O P.T.D. ~182~016i:,lType'tesil P I Test psi 1078 Casing 1900 1775 1765' 1760 P/F P Notes:~ Mud slurry injector. Yearly.test Well ;11-17 I T~,l:)9,_[nj. I N IT.V.D, 4505 Tubing 0 0 0 802 Interval O , p.T.,D.1 P ITestpsi 1126 Casing 2120 1820 1820 I 0 p/F p_ Notes: Mud slurry injector, Shut in. Yearly test. . . ' Well Type !.nj. .... T.V:D. Tubing ~ Interval ...P.T.D.1 ~Type test Test, pSi 0 Casing P/F Notes: Well Type Inj. T'V.D. Tubing Interval ' P.T.D. 'Type test Test psi 0" Casing. ... P/F Notes: Type INJ. Fluid Codes Type Test Interval F '- FRESH WATER INJ. M= Annulus Monitoring I= Initial Test "G"'= bAS INJ. P= Standard Pressure Test 4= Four Year Cycle S = SALT WATER INJ. R= Internal Radioactive Tracer SurVey V= Required by Variance N = NOT INJECTING A= Temperature Anomaly Survey W= Test during Workover O=OTHER (see notes) D= Differential Temperature Test 0=, Other (describe in notes) ...... ~'"ansCed at the WD-1 well on the main pad of the Kenai Gas Field to find a wireline unit'rigged up on"WD-1. A "PX" wireline Plug had been set in the landing nipple below the packer. The Annulus was pressured up to 1600 psi in my presence. Tubing pressure was 350 psi. The casing pressure slowly bled off with onlY a slight rise in tubing pressure which indicated the plug was possibly not holding. A "W" circulating device was set on top of the plug. The tubing pressure was Pumped up to 1850 psi and the annulus was pressured to 1500 psi. The test went well with both Tubing and Annulus remaining at these Pressures for thirty minutes. Well's 24-7 and 11-17 were already pressured up and had been'ill this state for approximately 48 hours. I had Wayne Cissel (Marathon rep.) reduce the pressures and I observed the, wells in this state for thirty minutes with negligable change. All wells exhibited casing integrity and should be "OK" for continued injection. The drilling rig that is in Operation ha the field at this pOint cOuld do a workover on WD-1 which would bring this well into full compliance without variance and greatly shorten the test time experienced annually. ,. .._ ..!.T.,s performed:.. _3 .Number'of Failures: Non.__.~e Total Time during tests:I 6 hours Attatchments: None I I . . cc:.l:Don.ErWin (:Marathon) MEMORANDUM STATE OF ALASKA DATE: TO: FROM: RE: October 8, 1999 Commissioners Christenson, Johnston & Oechsli Wendy Mahan Kenai Unit Well 11-17 Inspection ~1- I3G I traveled to the Kenai Gas Field on August 24th, 1999 to observe me Class II 11-17 grind & inject project. I met Chick Underwood at the Anchorage airport and we flew to Kenai on the 8:15 am flight. When we arrived in Kenai, he picked up a rental car and we drove to the Kenai gas field. After signing in, we discussed the foaming problem in well KU 11-17 met with Marathon personnel. I asked Sherry Petty, Bob Barlow and Don Erwin about the types and frequency of environmental training provided by Marathon. According to Sherry Petty, training is provided 2-3 times/yr. We then toured the main facility pad, where the disposal well KU WD-1 is located. Well KU WD-1 is limited to clear liquid waste. The well is equipped with a Barton flowmeter. Next to the well are two storage tanks where produced water is stored prior to injection in the WD-1 well. In addition to the KU WD-1 well, the main facilities pad houses the central offices with Scada system and processing equipment, as well as hazardous and empty drum storage areas. According to Chick Underwood, early in 1996, Phillips Environmental removed all of the hazardous waste located on the pad at that time. Three wells were drilled at the pad edge and the reserve pit was thermally remediated in September 1998. All areas were clean and well maintained. We then travelled to Pad 14-6. In the summer of 1995, sheening was observed on this pad when it rained. The source of the sheening was determined to be condensate, from past production practices oon this pad. Marathon requested and received permission from the Commission to reinject condensate recovered from groundwater. There are 7 4" heat traced shallow (20') groundwater monitoring wells. The wells have adjustable PVC stingers and a probe is used to measure product and groundwater. Four of the wells are in operation at one time and a pump is page 2 located inside a building where storage tanks are also housed. The main waste plume appears to be located on the pad. At Pad 41-17 we stopped to look at a new alarm panel that was being installed. The SCADA system is housed in the main office. Pad 41-18 is the site of well 11-17 the associated Grind & Inject facilities, the main focus of my trip to the Kenai Gas Field. We met Larry Drusto, the Veco facility manager and he gave us a tour of the site. Solids go through belts to a Jaw Crusher, then through classifiers and the Ball Mill prior to injection. Unfortunately, the ball mill wasn't in operation when we visited because crews were waiting on parts. Injection proceeds Monday through Friday, 12 hours per day. Solids are injected June through October, because equipment is outside and it has proved too difficult to process frozen material. The majority of injection occurs in the summer, with a few short 3-7 day injection periods during the winter. At the generating location, solid and liquid wastes are separated and the solid wastes stored until they can be transported to the Grind & Inject facility. Liquids are removed with Vac trucks or Super Suckers and put in waste storage tanks. The waste is screened to down to 50 mesh for injection. The plant is run by an 800 Kw turbine. The injection pump can achieve a rate of 9 bpm, although the maximum operating rate is 5 bpm. There is also a backup pump with an operating limit of 3 1/2 bpm. The 11-17 well operates at an average of 1500 psi. Tanks are strapped before and after wastes are injected into the 11-17 well. Daily logs are maintained of tank volumes, wastes accepted, additivies, and the 11-17 tubing/casing pressures. These logs are faxed to Marathon's office. Marathon uses an inter-company manifest. Staff in the main office at the Kenai Gas Field review manifests before sending trucks on to the Grind & Inject facility. The information is entered into a database and also periodically reviewed by Marathon's environmental staff. I asked Mr. Drusto who furninshed environmental training to Veco staff at the Grind & Inject site and he stated that Veco supplied his training. When Chick Underwood heard this he said that he'd like to get him into Marathon's next training event. I was satisfied that Marathon intended to take proactive measures to train personnel manning their facilities. X-.274,B97.62 5/8' · ~EBAR W/ 2' · ALU. CAP/i $1/¢' · ~'~ $ 8917'13' £ '~ 2641.51' rI~C'IR~ SWn'CH ~ox w/2.~'x2.:~' Gu~o ~ Y-~'75~7 ~ e" Ca~Ng 1~ ~' P~ m~ ~7.~ Y-2.35e.727.37 I~ll OLO/I)LM monument found this ~JrVey. 0 Re¢oced 1/2' rebar as noted ,1~ Found survey monument as de~cn'oed. Power P~e light Pole · ~xisting wall christmas tree Monitor Weft Valve .-o Piping underground ~ectrical switch box Septic Vent O.H.E. O%~:RH~ ELECTRIC O.H. P/W O91~H~AD PIPE: WAY EM. ELECTRIC METER NOTE~; 1) E3evettons at the top of pipe for monitoring weil~ we taken with ¢ov~r off ar open. 2) Refm'once datum is mean sea Isvetz 0.00' for detect, one shown. 3) All bearings are grid unlm noted othm.~as. 4*) Basis of CoQrdinatas is U.S.C. & G.S. TH Statlan AUORY In A.S.P. Zone 4.. Average conv~cjence of points shown: -01'04.'58' $) T.B.M. dev.-, 67.90' SW comm' top wall cellar KU 11-17 $) AUORY location: Lat.: 60'30'50.559'N Long.: 151'16'37.445'W X-269.866.75 Y- 2,382,0~5.42 McLANI CONSULTING NO.: g51~4118 ().Marathon Oil Company KENAI GAS FIELD PAD AS-BUILT SURVEY KENAI GAS FIELD PAD 41-18 MOV 06 '~8 15:~? M~R~THOM KGF Marathon Oil Company P.1 Kenai Gas Field P.O. Box 1949 Kenai, AK 99611-1949 Telephone (907) 283-6205 Fax (907) 283-6175 Fax Cover Sheet TIME: TO: FROM: PHONE: NAME: COMPANY: PHONE: PAGES SENT (Including Cover Sheet) [ ] Response Requested [ ]Immediate [ ]Information Only REMARKS: ~_/~-,,'ri~ ,,fi>t- //-/7, // ~0v 0 6 ;998 STATE OF ALASKA B AI.,6~KA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Typo gl Request: Ab.3n~on ,~ Su~end ~ O~er~ ~n~ __ Re,e~ ~~ ~ ~ ~ ~ ~ 2.-~otOp~rator ; - 5. ~pe~Well: ....... ~ ~ O~um~evaaon(OForK'a} ' :~-' ~ I Address- ' / 8ua~ra~n~c J Z Unit or Pr~p~y n~e_ ' - .- .. ,, ,., ...... , - __, _ --... ToI~ depth: re;ea~reo reel Plags(muaaured) Iruc vortical fee{ measl./red Pachers aha SSSV (type a. nd rnea.'~ured depth) L~.jth Size Cornenle~ Measured de~31h ~"F£Je verl~cal depLh ORIGINAL . ~ ~- . ' ' ..- 14. E~timaled date (or c~mmen~ng oper~0rl j l& Status ~f ! Name of appr~r Data s~pro~d ~ Sar~c~ 1Z i here~ c~dY ~ ~ne'lomgo~-is'~rd~ an0 corr,[ to ~ne oest o~ my kn~ledg~ !~.~~.''. ..... '""-,~ .: - '" .., · _. _. :.:- ~ogC'o~SS~ON us~ Plug Jnlegri~y __ 80P Tes{ __ ~/ion ~earance __ _ . t ~.~ M~nan~ Integnty Teal __ $u~aquent ~[m rcquieea 10.~~[ ~ [ ~ -:: "- - ...... Al~prevsd ~! order ot the C~mmte,'~on Original 8igned By Oavid W. Johnston - 43 - t 1998 MOV 06 '98 11:10 MARATHON K~F Marathon Oil Company Kenai Gas Field P.O. Box 1949 Kenai, AK 99611-1949 Telephone (907) 283-6205 Fax (907) 283-6175 DATE: //~//~ ~-~ TIME: Fax Cover, Sheet TO: NAME: j'Y)r COMPANY: ,,~ PHONE: FROM: /'~¢z t/' / PHONE: ",', ',- ~ ~/.,_~ .., FAX: PAGES SENT (Including Cover Sheet) ~ [ ~esponse Requested [ ]Immediate [ ]Information Only REMARKS' MO¥ 06 '98 11:09 MARATHON KGF Company P 1 Domestic Production Kenai Gas Field P.O. Box1949 Kenaj, AK 99611-1949 Telephony (907)283-6205 Fax (907) 283-6175 November 6, 1998 State ot Alaska Alaska Oil and Gas Commission Mr. Blair Wonzell 3001 Porcupine Drive Anchorage, Alaska 99501-31 Re; Marathon Oil Company's Kenai Gas Field KU 11-17 Class Ii Disposal Well Dear: Mr. Wonzeli Based on the phone conversations with your office yesterday, Marathon hopes to clarify a few issues pertaining to KU 11-17 as a class I1 disposal well since the summer of 1995. The well has and continues to support our Exploration and Production Operations, The disposal operations are periodic and are usually confined to the summer months, however, periodic winter support of drilling programs have beer] and wJlf continue to be required. The last MIT was performed on June 14, 1998. The well was used for the first time Jn 1998 during a two-day window in October (10/25 & 10/26), Prior to that, KU 11-17 has been idle since September of 1997, As part of our well monitoring philosophy, Marathon has employed real time pressure monitoring equipment at the site. This information is used in the well modeling program at our research center. The equipment was installed soon after Marathon succeeded as operator ol~ the Kenai Gas Field, just prior to ~he 1995 grind and injection program. It is Maralhon's belief that a one way hydraulic Peak has developed downhole, causing the 9 5/8" casing to pressure up. It should be noted that the observed pressure does not threaten the mechanical integrity of the casing. As previously noted, the last' injection period was completed on October 26, 1998. Maximum pressures observed during the two days were 1496 psig on the short string, 1420 psig on the long string and 1600 psig on the 9 5/8" annulus. To date, ten days later, the 9 5/8" is still holding at 1600 psig, while the LS is recording 87 psig and the SS 0 psig respectively. Marathon feels that a basic MIT is performed at the end of each injection day and well KU 11-17 is fit for service. Marathon will continue to monitor tubing and casing pressures for casing integrity and will investigate the possibility of the one way tubing leak being located at the tubing hanger. Marathon feels that the one way hydraulic leak is minor and poses no threat to the mechanical integrity of the well. We would like verification that our injection operati6ns may continue. If you have any questions, please feel free to call me at (907) 283-6215. We look forward to working witt~ your department or] this issue. Yours truly, Ray Schemanski Production Supervisor RLS:sJp [$1p]m:\docs\corresp\KU.11.,17.wpd 3P.~ 1 ~¥:~ara~non Oil Company ; 7-2§-~5 ; §:37AM ; Anchorag~ Alaska Region Dornastie Production 907 276 7542;# 1/ 4 (Marathon OilCompany July 20, 1995 P.O. Box 198168 Anchorage, AK 9951 g-6188 Telephone 907/661-5511 Mr. David lolmi Alaska Oil and ¢ 3001 Porcupine' Anchorage, Alas Re: Request for Clarification of Acceptable Wastes Pursuant Dear Mr. John, ton: ,IUL 2 Marathon Oil Company ("Marathon")would like to provide the Co~ervalion Commission ("AOGCC') with information on its plans as the new operator o£ an injection well, and obtain concurrence that the wastes that are antidpated to be disposed in the injection well may be legally disposed the]:e. The wastes will come, directly or indirectly, from Cook Inlet .offshore oil and gas production platforms as well as from onshore production facilities owned or operated by Marathon and/or other companies. The waste will be wastes generated from operations prior to the I. ACT meter where transfer of legal custody of the product occurs and transportation begins. As you know, the AOGCC issued Disposal Injection Order No. 9 for Kenai Unit No. 11-17 well, Kenai Unit, to Union Oil of California (UNOCAL) on November 16, 1994 ("Permit"). Unocal and Marathon notified the AOGCC on November 8, 1994 that Marathon would be the Designated Operator of the Kenal Unit Area, which includes that well, 'as o£ December 1, 1994. The AOGCC transferred this permit to Marathon on December 5, 1994. Marathon and UNOCAL are currently negotiating their SERVICE AGREEMENT FOR WASrl/ DISPOSAL BY INIECTION WELLS AT KENAI GAS FiEI~, and~ as noted above, we both want to confirm with the AOGCC our understanding of what wastes may be properly injected into this Well. Section 13 of that Permit provides as follows: 13. Disposal fluids will consist exclusively of fluids brought to the surface as a result of drillin~ production, and workover operations. Typical fluids will include produced water, drilling and completion fluids, equipment wash water, drilUug mud and cuttings, and pipe scale, A subsidiary of USX Corporation Environmentally aware for the long mn. $1~T BY:~lara~hon 011 Company ; 7-26-05 ; 8:37A~1 ; Anchorage~ Letter to Alaska Oil and Gas Conservation Commi..~si0n ,Iuly 10, 1995 Page 2 of 4 907 276 7§42;# 2/ 4 The Permit does not expressly state that Exploration attd Production Exempt Waste ("It & P Exempt Waste') or NORM Wastes may be disposed ia a Class H/njection well. However, based on permits and approvals granted by the AOGCC and EPA documents, Marathon believes the AOGCC and EPA traditionally and correctly have included as waste acceptable for injection into a Class II wells wastes that are assodated with the exploration, development, or production of crude oil or natural gas, that is, E & P Exempt Waste. An example of an 1~ & P Exem t Waste is ri wash, which ~ . . P g _ this Alasl~ injection permit expressly allows ng wash to be rejected in this Class II well. List of Wastes for Injection in Class H Injection Wells We would like written clarification that the following antidpated wastes are approved for injection in our Class Ii injection well. 1. One is pipe scale. The pipe scale will likely come from'the tubulars and pipes once used in oil or gas production, and possibly exploration operations. That is, the tubulars and pipes had been located at the production or exploration sites prior to the LACT meter transfer of legal custody of the product occurs and transportation begins. The pipe scale, some of which may contain naturally occurring radioactive materials ("NORM") as noted in Unocal's application, has been "brought to the surface" in conjunction with conventional oil and gas production. As you know, NORM waste occurs as scale or se0!ment in production tubing and fittings. The AOGCC has written to oil companies that it considers NORM waste to be a Class H substance and eligible for injection into a Class II disposal well. Given the space limitations on the offshore platforms, those tubulars and pipes (as well as from onshore facilities) will most likely be taken to locations off. site of the production fac'Flit/es to have the/r pipe scale removed and temporarily stored in drums prior to disposal in the injection welL (Hence, the wastes came indh'ectly from E & P fadlities.) We anfidpate the pipe scale coming from three types of storage locations: One existing storage location is Marathon's Nikiski warehouse where pipe scale is stored in drums awaiting disposal in this injection well. A second source will be new pipe scale and sludges with NORM. The sources of the sludges with NORM will consist primar/ly of treatment vessels for produced water "brought to the surface" in which the NORM sludges settle out. These treatment vessels will be located on the offshore production platforms and at the onshore production facilities prior to the LACT meter where ownership and change of custody of the product occurs. A third source providing pipe scale that orig/nally had been "brought to the surface" are the aery/ce facilities that store tubulars and pipes, such as Arctic Pipe Inspections near Kenai. The tubulars and pipes are stored on storage racks. The pipe scale (as SENT BY:Mars:hen Oil Company ; 7-26-9§ ; 8:38A~1 ; Anchorage~ 907 276 7542;# 3/ 4 Letter to Alaska Oil and Gas Conservation Commission Suly 10, 1995 Page3 of 4 well as old, non-hazardous, pipe dope used to seal pipe joints) may fall out of the ends and fall to the soil and gravel; other pipe scale from these locations result from pipe cleanings. This pipe scale and pipe dope, some mixed w/th soil, would be put in drums and disposed in this injection well. Of course, dry pipe scale (and other dr/E & P Exempt Waste such as soil), in order to be injected downhole, must have water added to the waste to create a slurry. The sources of this water will include produced water, ~rcsh water from local wells, and/or rain water found within containment dikes at production facilities, such as Trading Bay Production Facility. The rainwater would be considered an E & P Exempt Waste. 2. Besides pipe scale, other wastes to be disposed in the injection well includes rin~ate from rins/ng drnm$ used to store E & P Wastes, such as crude oil condensate rags, tank sludges, glycol from contactors, etc. 3. Another waste would be gas separation wastes, including wastes which may have come into contact with glycol-based dehydration compounds, arising from operations necessary in the oil and gas production process. Dehydration vessels, such as contactor towers, have a potential for glycol carryover. 4. The equipment wash water specifically mentioned in the Injection Permit will be fresh wash water from local wells since produced water would have salt that would obviously cause corrosion problems on the equipment. 5. Other wastes to be disposed in the injection well are mixtures of B &: P Exempt Waste and non-hazardous solid waste or media, such as soil and organic materials which have been contaminated by spills of produced fluids, production waste, pipe scale with NORM or solvent used to clean pipe dope from the threads, or contsrnlnated rainwater from secondary containment sites used for temporary storage of such E & P Exempt Wastes. These mixtures of B & P Exempt Waste and solid wastes which are not RCRA Subtitle C hazardous wastes would be allowed to be injectcd since they are equivalent to ~ydrocarbon- bearing soil" which EPA specifically listed as an E &: P Exempt Waste in its July 6, 1988 Regulatory Determination. 6. Stormwater in contact with secondary containment areas for I/& P F. xempt Waste storage areas and production equipment, onshore reserve pits, and production pads. The above list of anticipated wastes to be disposed of in the injection well is not all- inclusive, Marathon may inject other wastes determined by U.S. EPA to be RCRA E & P Exempt Wastes. RECEIVED SENT BY:Marazhon 0il Company ; 7-26-9~ ; 8:39AM ; Anchor age-~ Letter to Alaslm OU and Gas Comervation Com_u2ission July 10, 199;5 Page 4 of 4 907 276 7§42;# 4/ 4 Request for AOGCC Concurrence It is our view that the above described proposed waste disposals are all legally permitted under the above referenced AOGCC permit. Marathon would appreciate a letter from AOGCC concurring that the above described waste may be legally disposed in the injection well. Marathon would appreciate a response as soon as poss~le so that it may use the /njection well for all of the above described E & P Wastes quickly and productively before thc s-turner/fall season is over. Our plans are to begin injecting current waste on and after Suly 24, 1995, be~nning with the waste that is expressly permitted under the Permit. Obviously, we would like to max/raizc our use of it this season since injection wells are among the most environmentally protective d/sposal methods available. If you have any questions, please feel free to call me at 907/564-6372. Marathon would appreciate your prompt review of this matter, preferably before Suly 24, 1995. Sincerely, Stephanie S. Olson ~O:WLW.'ww Doc, 4868~.0~ cc Mr. John Betia, Union Oil of Califorrda, Anchorage EECEIVED IUL 26 t995 ~[~a.Oii .& Gas Cons, CommiSsiOn' ' ~chorage Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 March 30, 1995 Mr. Steve McMains Statistical Technician Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Reference: Kenai Unit 11-17 --- ~"1--/? ~ Dear Mr. McMains: Attached is the completed Form 10-404 for the Kenai Unit Well 11-17. Sincerely, T. J. Kbv~cevich Operations Superintendent H:\WP\OPNS95\TJK3302 Attachment xc: Well KU 11-17 RECEIVED APR -6 1995 Alaska Oil & Gas Cons, Commission Anch0ra,? A subsidiary of USX Corporation Environmentally aware for the long run. STATE OF ALASKA [ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS · Operations Performed: Operations Shutdown ~ Stimulatem Plugging ~ Perforate__ Pull Tubing __ Alter Casing __ Repair Well ~ Other X Convert to Class II Disposal 2. Name of Operator UNOCAL 3. Address P.O. Box 196247 Achorage, AK 4. Location of well at surface 768' S, 631'W on NE[ comer, Sec. 18-4N-11W-SM At top of productive interval (Class II Disposal Well) 5. Type of Well: Development Exploratory Stratigraphic Service ~" -- 6. Datum elevation (DF or KB) KB 85' MSL feet 7. Unit or Property name Kenai Unit 8. Well number KU 11-17 9. Permit number/approval number 81-176 10. APl number 50- 133-20349 At effective depth At total depth 31' N, 1385' E of SW comer, Sec 8-4N-IIW-SM 12. Present well condition summary Total Depth: measured 0 feet true vertical 0 feet 11. Field/Pool Kenai Gas Field Plugs (meaSured) Effective depth: measured 0 feet true vertical 0 feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length Junk (measured) Size Cemented (See eriginal Sundr;~ App.,'~;val) Measured depth True vertical depth 13. true vertical Tubing (size, grade, and measured depth) 0 Packers and SSSV (type and measured depth) 0 *Gfimuiation or Cemer;~ squeeze summary Intervals treated (measured) APR -6 1995 Alaska 0ii & Gas Cons. C0mmL~_qe... Anchora,2~ 14. Treatment d ~e~lp~t~ '~ ~n~l~.ing~~,~sed and final pressure Representative Daily Average Production or Injection Data Oil-Bbl. Gas-Mcf Water-Bbl. Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments J 16. Status of well classification as: I Copies of Log and Surveys run __ Daily Report of Well Operations m Oil w Gas w 17. I hereby certify that the foregoing is true and correct to the best of my knowledge S,ened [ ~ ~ ~ Form 10-404 Rev 06/1~/8~8 Suspended Service Convert to Class II Disposal TEle Date SUBMIT 1N DUPLICATE LlaU ALAS~ OIL ~ GA~ , CONSERYA~FION COYI~ISSION / TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE~ ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 March 15, 1995 Lyndon Ibele Marathon Oil Company P 0 Box 190168 Anchorage, Alaska 99519 RE: 81-0176 Kenai Unit 11-17- Noncompliance Dear Mr. Ibele, A review conducted on our well files after Novej'nber reported oil production indicates the reference well, Kenai Unit 11-1/~,'/as a Gas producer in our data base. This well was converted to a disposai'well without a Report Of Sundry Well Operations (10-404), and daily well operations being forwarded to the commission to date. The Application for Sundry Approval (10-403) was received January 20, 1995. I called Mr. Gary Laughlin January 20, 1995 concerning these materials required under 20 AAC 25.080(d). Our regulations require that the oper. ator provide these items within thirty (30) days after the well is converted. The Commission request action on this matter. I hope this situation can be corrected quickly to update our well files. Sin. Cere!y, Steve McMains Statistical Technician 51zl~'l' t~Y:t~laraxhon Oil Company ., AP CATION FOR 8UNDI:IY APPROVALS ~ ReQuo~: At)ac, den .__. gtmaend .._... Alta'ea~ng __ ~ Reoairwei.._ Cl~ange approvee program _.. PuN tubing __ Variance ---- Petiole ._. Devmecment ._ ) Exmorax~' __ )6247, ~chora ~ 99519-624~ .~liorf~ltatm~ace 768'$ ~ O3i'~ of NE corner, Sec. ~O~ Of,~"~ I~' ORIGINAL ~ectr~ lntald~'h 31'N & 1385t£ of SW eorncr, S,,c. 8, T4N~ RIlW, $,M. ,. - imll . i f~,~! Plugs (measurea} FROI~t AOOCC;~ 3/ 4 tffecm/e tiepin: mea~ursd true vertical feet J~nk (men,ore,J) Surface Prnd~ ~Cl~on ~Lmor ir;oration cleO~lq: mea,surecl gm 8~' MSL ?. U~I or Propeny name Kenai Unit B. ~ n~r mmm. m ........ 9. ~mit ~m~ - ~0. AP~ ~ ~n- ~3-Z034~ .. m Kenat Gas Cemented Mee~ureO depth True vertical Gel)th RECEIVE tr~rtical ~,ng (size, ora{Jet anO measureO Del)tn) and $88V (Woe anti ~urecl ae~n] JAN £0 !995 .Alaska 0ii & Gas ~;o~)s. L;~[~ Anchorage (See ori$inal g.ndry Approval) ...... Illl . IIIll I II .llml I lachrtlents Description RLm'U'nary of proDo$~l ~ ~mled operations pr~ram__ ~OP sketuh __ ' -' __onvert,,, to a Claes 1[, ,d~sposal veil. Jmat~ ant° ~r ~menmng o~rai~ [ I~, ~t Of well ~lh~bon as: ~Ov, L, tg94 I ~m ~ ~r~iy aoo~ ............. I I ~e~ ap~r Oama~~[ " .~':~cc? ,.. ~ 1~ Envtronmental Scientist O~e 10/4194 ~. , .... "- ~. ~aw~ ~S~ onLY .................. ': Plug int~rity BOPPer ~ati~ cl~ran~ ,. _ I ~- ~pproved Copy ' Returned i Original Signee dy ~~r~meC~m~er .................... David W. Johnston SUBMIT IN TRIPU~ ,~-~__ .................... -.... . . Marathon Oil Company L. R. Dar~ · Production. ~ .~ager Alaska Regi~,;~i Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 December 14, 1994 Blair Wondzell State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Blair: ~~ Per your request of Dec~e find attached a copy of the cement bond log for ,Were K enai Gas Field (date of log, 2/15/82). If l can be of additional asSistance, please advise. ~C. ibe~lesincirely' ../¢ Production Coordinator LCl:kgh Attachment H:\WP\LRI94\1214 RECEIVED DEC 1 6 1994 Alaska 0il & Gas Cons. Commission Anchorage A subsidiary of USX Corporation Environmentally aware for the long run. SCALE !" = 300' LEGEND AND NOTES' Found GLO brass cap monument Set 1/2" x 24" rebar K U 11-17 Center of Well ~ Cella Lat. 60°26'34.819,' Lonq; 151°14'41~606,, X: 275,173~84 Y: 2,355,971.17 NE Cor. Sec 18' 17 Lat. 60°26'42.383'' Long. 151°14'29.027', X = 275,819.31 Y - 2,356,727.16 ./ 631.' Top of We,ll Cellar elevation is 79.0 feet above HLLW of Cook Inlet or 67.9 feet above Mean Sea Level. Basis of coordinates and bearings is USC&GS Tri Station AUDRY in ASP Zone 4, and..related Azimuth Mark. Lat. 60°30'50.559 N Long. 151°16'37.445W X = 269,866.75 Y: 2,382,045.45 K- U 11-17 i i PREPARED FOR UNION OIL COMPANY OF CALIF. OPERATOR i .... SURFACE LOCATION: 768 Ft, South and 631 Ft. .... West from the NE corner of Section 18, T4N, RllW, S.M., Alaska Surveyed by: McLane and Associates, Inc. Date of Survey, Jan. 25, 1982 APR F.Bk. 81-37, 81-31 .... ~ Alaska' Oil & (~as STATE oF ALASKA .i" ALASKA OI'L AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501 (907) 279-1433 TO: RE' Receipt of the following material e .. - / QUANT I TY which was transmitted via is hereby acknowledged: DESCRIPTION RECEIVED: Copy sent YES to sender NO _~ WELL COMPLETION OR RECOMPLETION REPORT AND LO 1. Status of Well Classification of Service Well .. OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator '7. Permit Number UNION OIL ~ANY OF CALIFORNIA 81-176 3. Address 8. APl Number P. O. Box 6247, ANCHORAGE, ALASKA. 99502 50- 133-20349 4' L°cati°n °f well at surface 768 ' S & 631'W of ~ Cor, Sec 18, T4N, RllW, 9. Unit or Lease Name S.M. Kenai Unit AtT°pPr°ducinglntervalll2'S & 958'E of h-W Cor, Sec 17, T4N, ~LI~, 10. WellNumber S.M. KU 11-17 . At T°tal Depth 31'N,& 1385'E of SW Cor, Sec 8, T4N, RllW, S.M. 11. Field and Pool . -5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No.'' Ke~ai Gas Field KB 85'MSLI ADL-22330 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 16. No. of Completions 1-29-82 2-09-82 3-05-82J feet MSL 2 22. Type Electric or Other Logs Run : DIL-Sonic-GR, VDL-GR, FDC-CNL-GR, CBL-VDL-GR" 23. CASING, LINER AND CEMENTING RECORD .SETTING DEPTH MD CASING SIZE WT. PER F.T. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94# Plain Surface 176, "Driven Driven' - .. 13 3/8" 68~ K-55 Surface 1994' 17 1/2" 1180' sxs Cl "G" 9 5/8" '47# .. N_80 Surface ,$37.1',...,~' - 112.-.1/4,, ..... 1900,.- sxs Cl' ,,G, - 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. ' TUBING RECORD interval, size and'number) .... .. . SIZE' DEPTH SET (MD) PACKER SET (MD) ,' 3 1/2" 5005' MD TVD HPF ...... ! ,..3 .1/2" 4622' -. . . 4528'-4587' 4112'-4163' 8 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. - ! 4.468. -4498 · . 40.61.!~4086' . 8 .~ :,.... DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 5'106'-5i54 F' 4607"4648 ''~ 8 "51~0'~-~162' 2~'0 S:~s' C1 "G" 5103'-5105 ' " 250 SXs Cl "G" 4641'-4661' 400 sxs C1 "G" · "~ ! '" .~ '.. ~ . : · : ;. 27. , ' " ' PRoDUCTi'ONTEST .... "' '' Date.~irst Ecoduction .... ,' ] Method of Operation (Flowing,,q, as lift, etc.) .', : , ';. -.,. . . .. j , .. , , '.. ..~",' .:, '~ ~ , . .'. I Date of Test Hours Tested PRODUCTION FORi~ OIL-BBL GiA,,S-~F~ ~ WATER:BBL cHOKE SIZEI' GAS'OIL RATIO' 3-11t-82 . 24 .... TEST PER,OD.-, .... !. --: :.. 0 Flow ..,Tubing., Casing Pressure .. CALCULAT.Ep.~ OI.L-BBL ' .. GAS-McF ' WATER'BBL elL'GRAVITY-APl (corr) '. . 24;HOUR RATE I~ · ,.'-'... . .,.L .' , ... 965 28. CORE DAfA :' "'" .... Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None " ', '. -.-.-".-"" : '-": ' " MAYI · A,j~ska 0it & Gas C~. ,. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Sterling Gas 4033' 3686' B-4 f/ 4641-4661', too wet to produce to Sands to surface- squeezed. B-3 f/ 4528-4587', surface pressure 920 psi, 8.6 MMCFPD w/ 115 BWPD, 16 hr test - open. Beluga FormatiOn 5~'~2' 4793' ... No tests. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge / ' / - -- ~ . .,//,-, ~-/ -/ INSTRUCTIONS General: This form is designed for submitti,ng a complete and correct well completion report and log o.n all types of lands and leases in Alaska. I'tem I' 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 i~:~.completed for"'separate production from more than one in;~.erval (multiple completion), so state in item 16, and in item 24 show th~,~produc.ing interv, als for only the interval reported in item 27. S~ubmit a separate form for each additional interval to be s~parately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attad. hed supplemental records for this well should show the detai~i;s of any multiple stage cement- lng 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". PAG[: t"l O. ,, ;, Kenai Unit ,,,,AS.] ;'fEI,l) Kenai Gas Field ,OCAT1ON 76_8' S & 631' W of NE corner, Sec. 18 T4N, .R!.i.W, S.M. ?Ei-{MIT NO... 81-176 ,. .SERIAL NO.~ADL 22330 F.D.. 5400' T.V.D. 4861 SPUD DA'ri,: 1-29-82 COMP. DATE CONTIb%CTOit Brinkerhoff TYPE UNIT. Wilson 120 3-9-82 RIG NO 58 , - ,~,, 4 1/2" "E" DtxlI.,L Pi~ r~ DZSCtlIPTION. . EL!;iVATIONS: \V,.VI'Elt 1)EPTiI ll.T. TO OCEAN FLOOR I1. T. TO },ILLW 16' RT to Gnd Level 95' 20" Drive Pi'~' 13 3/8" 61# Butt K-55 9 5/8" 47# Butt N-80 3 1/2" 3 1'~~ 9.2# 9.2# Butt Butt -- N-80 N-80 176' 1994' Cmt'dw/llS0 sxs "G" 5371' Cmt'dw/ 1900 sxs "G" 5049' 4522 Pkrs set @ 5005' & 4622' Pkrs set @ 4351" & 4505" PERFORATING RECORD ~. ~ ~. -UmEY, f~AL ......... E,T_.D_. ,_ ~EA_~Olt___] ..... Pa_E_ S E itfL_Q O_/I I2LT_~ O I I ...... "G" w/ 2-.16-82 5160-5162 5265 (FC) isolation! Sqz' d w/ 250 sxs . ,additives 2-17,82! 5103-5105 . . .5142.. (RET). ..i.SOlation S~_d w/ 225. sxs "G"." ~' 2-20-82 ...4.641-4661 5265 iFC) production Lower B-4 sqz'd w/.. 400. sXS".' "G" Sqz '_ fe'_~l away, isolated behind pkrs. 2-23-82 4528-87' 4630 (BP) --production. B-4 open for 'production iS.S) sho%"'W/ 2 1/16" rigid'jets @ ~t{PF,'" 0° & '120° phasing 2-25-82~ 44~8'83 .- . 4630, (BP). produ6tio~ B-3 open for p~od. iS.S) .... 3-5,..8..2.. '5i~6-'5i5~-' ' ..52...85. (RET~ production.... C-.i"'snd open for product.ion - shot w/ D.A. 2 1/16". rigid-jets '~ 6o &' 12'0°- , 'phasing, 8 HPF total. . ..... . · ,. · DATE · IIITERVAL NET OIL TYPE:' CIW INITIAL PRODUCTIO_N CASING HEAD: CASING HANGER: · Shaffer 9 5/8" CASING SPOOL: TUBING HEAD: TUBING HANGER: 20" 2000 psi X 12" 2000 psi Cameron ~-12" 300'0 psi'x 10"' 5000 psi. CIW dual 3 1/2" TUBING IIEAD .TOP' MASTER VALVES: 3 .1/2"EUE CHRISTMAS 'FREE TOP CONN.: 3 1/2"m-$ JUN t 6 1 82 Anchorafls ~SE DATE 4521.22 4519.57 4507.50 4507.27 4497.19 4433.79 4429.93 4366.60 4365.60 4361.57 4351.25 4351.00 4340.00 4336.60 20.00 18.50 SHEET D · PAGE UNIOH OIL CC~,~?A~N OF CALIFO~.IIA UNIT FIELD ~T 4519.57 4507.50 4507.27 4497.19:' 4433.79 4429.93 4366.60 4365.60 4361.57 4351.25 4351.00 4340.00 ~.3~6.60 20.00 18.50 DETAILS OF OPEPATIONS, DESCRIPTIOitS & RESULTS T,K~G~F~-I SS TEIBING~ILo.~ 1.65 12.07 .23 10.08 1 ': .... 63.40 3.86 63.33 2 1.00 1 4.03 10.3'2 .25 11.00 1 3.40 4316.60 1.50 137 LANDED BELOW R.T. DESCRIPTION Otis XN Nipple Baker mod AL-5 Dual pkr Left hand safety sub 3 1/2" 9.2# N-80 Butt pup "3 1/2" 9.2# N-80 Butt Otis XA Sleeve 3 1/2" 9.2# N-80 Butt 3 1/2" 9.2# N-80 Butt pup Baker telescoping swivel sub Baker model A-5 Dual pkr Left hand safety sub 3 1/2" 9.2# N-80 Butt pup Otis XA sleeve -" 3 1/2" 9.2# N-80 Butt c~ tbg hngr SHEET D PAGF NO, UNION OIL COFPANY OF CALIFORNIA LEASE DATE 5048.47 5047.79 5016.69 5015.19 4999.39 4998.59 4631.16 4620.59 4619.79 4609.79 4606.70 4596.70 4519.13 4504.57 4455.62 4362.52 4346.70 4343.05 4337.05 45.30 20.00 18.50 KENAI UNIT ~'i~L I~ECORD. · .. ltELL NO, ~u ~_~. . . L.S. Tbg detail .~ TOP 5047.79 5016.69 5015.19 4999.39 4998.59 4631.16 4620.59 4619.79 4609.79 4606.70 4596.70 4519.13 4504.57 4455.62 4362.52 4359.65 4346.90 4343.05 4337.05 45.30 20.00 FIELD .. DETAILS OF OPERATIONS,' DESCRIPTIOHS & RESULTS 18.50 0 .68 31.10 1 1.50 15.80 .80 367.43 11 10.57 .80 10.00 1 3.09 10.00 1 77.57 4 14.56 48.95 3 93.10 3 2.87 1 12.75 3.85 6.00 1 4291.75 138 25.30 2 1.50 KGF DESCRIPTION Baker bull nose entry guide 3 1/2" 9.2# N-80 Butt Otis x nipple *Bkr mod D pkr & seal assy Locator 3 1/2" 9.2# N-80 Butt *Bkr mod D pkr & seal assy Locator 3 1/2" 9.2# N-80 Butt pup Otis XA sleeve 3 1/2" 9.2# N-80 Butt pup 3 1/2" BKR blast jts-~-<~ Bkr model ALLS dual pkr 3 1/2" Bkr bl~st jts. 3 1/2" 9.2# N-80 Butt 3 1/2" 9.2# N-80 Butt pup Bkr mod A-5 dual pkr. Otis XA sleeve 3 1/2" 9.2# N-80 Butt pup 3 1/2" 9.2# N-80 Butt 3 1/2" 9.2# N-80 Butt pup Landed below R.T *Model D pkrs set w/ W.L. @ 4620' & 5003' CBL. U~SE UNIO~ OIL CQ'~PANY OF CALIFORUIA ¥~£LL RECO~ ~ U~IT ¥~[LL NO, ~-~7 FIELD SHEET D PAGE I"b, Kenai Gas Field DATE 1994.00 1992.17 1958.46 1956.31 20.40 BOTIOM 5371.42 5369.74 5277.16 5275.73 20.40 TOP 1992.17 1958.46 1956.31 20.40 TOP 5369.74 5277.16 5275.73 20.40 DETAILS OF OPERATIONS,' DESCRIPTIOHS ~, RESULTS T A-~qGTH 1.83 33.71 2.15 1935.91 49 13 3/8" CsgDetail JTS LANDED BELOW R.T. DESCRIPTION B & W float shoe K-55 61# Butt B & W Float collar K-55 61# Butt 1.68 9 5/8" Csg Detail JTS 92.58 2 1.43 5255.33 123' LANDED BELOW R.T. DESCRIPTION B & W Float shoe 47# N-80 Butt B & W ~l.at collar - 9 5/8" 47# N-80 * Ran 123 full jts and two pups 17.70' & 15.10' I ECEIVED JUN 1 6 ]982 Alaska Oil & Gas Cons. Commission Anchorage KU 11-17 0' 18.51 , i , ~ ~ 13 3/8" K-55 61# C. 1994' · · I, 4437 ' ' XA' Sleeve Otis XA Sleeve 4343 ' · ~ -- X' X ~ 4351' 'A-5' Dual pkr. ~ 4362' Telescoping swivel sub ~ 4430' 'XA' Sleeve ~. ~ i~ 4508' 'AL-5' Dual pkr .~ ~ 4520 Otis XN nipple I Blast jts 4519'-4596' ' I I0 Otis ' X~' sleeve 4607' .. Mod 'D' pkr 4620' · · oo3' C£1V l Otis 'X' nipple 5015 '~ ~ -- JUN161982 Bkr special bull nose ~ . entry guide 5048' Alaska 0/I & 8as C0ns_.~ommf · ~ · _ I~ 9 5/8" 47 # N-~c.~a~3 i-L- T.D. 5400' KU 11-17 ^,,'o. ,,, Kenai Gas Field s~ ,. completed 3/82 o^~ .. .. .. I , UNION OIL COMpANy OF CALIFORNIA ,,, , ,, ,, UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE KENAI UNIT WELL NO. '11-17 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS A 1/22/82 DAILY COST: $ 19,734 ACC COST: $ 19,734 AFE AMT: $2,190,000 B 1/23/82 DAILY COST: $ 21,225 ACC COST: $ 40,959 AFE AMT: $2,190,000 C 1/24/82 DAILY COST: $ 20,345 ACC COST: $ 61,304 AFE AMT: $2,190,000 D 1/25/82 DAILY COST: $ 73,961 ACC COST: $ 135,265 AFE ANT: $2,190,000 E 1/26/82 DAILY COST: $ 21,748 ACC COST: $ 157,013 AFE AMT: $2,190,000 Commenced operations on KU #11-17 00:01 hrs 1/22/82. Continued general rig up. Located solids pkg. Continue RU Brinkerhoff Rig #58. Raised derrick & worked on solids pkg. Continued general RU over KU #11-17. Installed lights & steam to FPS unit. Laid out diverter lines. Continued general RU. Worked on frozen generator. Installed pump in water well. RU drive hammer. Broke off cush plates on hammer - repaired same. F 1/27/82 20" D. 176' DAILY COST: $ 25,521 ACC COST: $ 182,534 · AFE AMT: $2,190,000 Drove 20" 94# drive pipe to refusal $ 176' w/ 250 BPF (153' of soil penetration). RD drive hammer. Cut off 20" csg & began welding on 20" 2000 psi SOW csg head. Head cracked during welding - damage was too ex- tensive to repair. Removed head. Wait on new head to arrive. RECIEIVEI) JUN 1 ]982 SHEET D UNION OIL COMPANY OF CALIFORNIA WELL RECORD PAGE NO. 2 LEASE KENAI UNIT WELL NO. 11-17 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 6 1/28/82 20" D. 176' 65 PCF 200 SEC DAILY COST: $ 49,066 ACC COST: $ 231,600 AFE AMT: $2,190,000 1 1/29/82 493'/493' 20" D. 176' 69 PCF 200 SEC DAILY COST: $ 54,906 ACC COST: $ 286,506 AFE AMT: $2,190,000 2 1/30/82 1134'/641' 20" D. 176' 68 PCF 140 SEC DAILY COST: $ 75,325 ACC COST: $ 361,831 AFE AMT: $2,190,000 3 1/31/82 2003'/869' 20" C. 176' 69 PCF 150 SEC DAILY COST: $ 53,793 ACC COST: $ 415,624 AFE AMT: $2,190,000 4 2/1/82 2003'/0' 20" D. 176' 68 PCF 100 SEC DAILY COST: $ 26,533 ACC COST: $ 442,157 AFE AMT: $2,190,000 Installed & tested 20" SOW flange & 20" diverter assy. Drl rat hole & mouse hole w/ dyna-drl. Spud $ 03:00 hrs 1/29/82. Drld 17 1/2" vertical hole to 493' w/ BHA #1 & blt #1. POOH. RIH w/ blt #2 on BHA #2. Oriented dyna-drl w/ SDC. Oriented dyna-drl. Oyna-drld 17 1/2 hole f/ 493' to 940' POOH. RIH w/ bit #3 on BHA #3. D~r drld 17 1/2" hole f/ 940' to 1134'. Dir drld 17 1/2" hole f/ 1134' to to 1546'. POOH. RIH w/ bit #1PR1 on BHA #4. Dir drld 17 1/2" hole f/ 1546' to 2003'. Cond mud & hole for 13 3/8" csg. POOH. Wait I hr on bank. RIH & check for fill. Tag fill @ 1997' (6' fill). Circ clean. POOH. LD 17 1/2" stabilizers & re- lated equip. RU & ran 13 3/8" 68# K-55 butt csg to 1994'. E C l V E I) JUN 1 6 .982 ~ska Oil & Gas Cons, Cor~j.~i,o~ UNION OIL COMPANY OF CALIFORNIA WELL RECORD PAGE NO. 3 LEASE KENAI UNIT WELL NO. 11-17 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 5 2/2/82 2003'/0' 20" D. 176' 13 3/8" C. 1994' 68 PCF 52 SEC DAILY COST: $ 141,922 ACC COST: $ 584,079 AFE AMT: $2,190,000 6 2/3/82 DAILY COST: ACC COST: AFE AMT: 7 2/4/82 2003'/0' 20" D. 176' 13 3/8" C. 1994' 68 PCF 45 SEC $ 23,370 $ 607,449 $2,190,000 2003'/0' 20" D. 176' 13 3/8" C. 1994' 68 PCF 52 SEC DAILY COST: $ 30,532 ACC COST: $ 637,981 AFE AMT: $2,190,000 8 2/5/82 DAILY COST: ACC COST: AFE AMT: 2013'/10' 20" D. 176' 13 3/8" C. 1994' 67 PCF 45 SEC $ 37,300 $ 675,281 $2,190,000 Could not stab into FC. Trip DP for centralizers. Engauged FC ~ 1956' & &circ clean. Cmt'd 13 3/8" csg thru DR w/ FS ~ 1994' & FC ~ 1956' w/ 930 sxs "G" w/ 2 1/2% pre-hyd gel & 2% CaCL2 followed by 250 sxs "G" w/ 2% CaCL2. POOH w/ DR. WOC 4 hrs. Removed 20" diverter assy. Installed 13 3/8" SOW csg head. NU BOPE. Installed & tested BOPE. RIH w/ bit #4 on BHA #5. Tagged green cmt stringer e 1450'. C&C mud prior to drlg out cmt. Lost pump press - POOH. Had cmt in bit ~ets. RIH. CO cmt to FC ~ 1956'. Tested 13 3/8" csg to 2_50.Q ~_s~i - ok. Drld FC ~F-~t to 1984' & r'et~ted csg to 2500 psi. Drld FS ~ 1994' & new~013' Tested 13 3/8" csg seat to leak ~ff ¢ 91 PCF equiv. POOH to chg BHA. ~ NOW: POOH. JUN 1 6 982 Alaska Oil & Gas Cons. Commission Anchorage SHEET D UNION OIL COMPANY OF CALIFORNIA WELL RECORD PAGE NO. LEASE KENAI UNIT WELL NO. 11-17 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 9 2/6/82 3536'/1523' 20" D. 176' 13 3/8" C. 1994' 70 PCF 55 SEC DAILY COST: $ 60,148 ACC COST: $ 735,429 AFE AMT: $2,190,000 10 2/7/82 DAILY COST: ACC COST: AFE AMT: 11 2/8/82 3536'/0' 20" D. 176' 13 3/8" C. 1994' 70 PCF 53 SEC $ 23,528 $ 758,957 $2,190,000 4553'/215' 20" D. 176' 13 3/8" C. 1994' 70 PCF 63 SEC DAILY COST: $ 31,452 ACC COST: $ 790,409 AFE AMT: $2,190,000 12 2/9/82 DAILY COST: ACC COST: AFE AMT: 5400'/847' 20" D. 176' 13 3/8" C. 1994' 71 PCF 64 SEC 77,338 867,747 $2,190,000 RIH w/ BHA #6 & bit #5. Dir drld 12 1/4" hole f/ 2013' to 3536'. POOH. Work on #3 DW clutch. RIH to bridge ~ 3475' Unable to break circ. POOH. ~it plugged w/ cmt. RIH rabbiting pipe. Break circ ~ shoe. Bit plugged. POOH LD DP. RIH & PU new DP. CO bridge 8 3435' & washed to btm. Oir drld 12 1/4" hole f/ 3536' to 4553'. Dir drl 12 1/4" hole f/ 4553' to 4594'. POOH. RIH w/ bit #7 on BHA #9 to bridge ~ 2438'. C0 bridge ~ 2438' & RIH. Had tight hole on trip in @ 3926', 4114', & 4177'. Dir drl 12 1/4" hole f/ 4594' to 5400'. RECEIVEI) JUN 1 6 i982 A!~ska Oil & Gas, Cons. Commission Anchorage UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE KENAI UNIT WELL NO. 11-17 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 13 2/10/82 5400' TD 20" D. 176' 13 3/8" C. 1994' 70 PCF 61 SEC DAILY COST: $ 24,327 ACC COST: $ 892,074 AFE AMT: $2,190,000 14 2/11/82 5400' TD 20" O. 176' 13 3/8" C. 1994' 70 PCF 56 SEC DAILY COST: $ 83,050 ACC COST: $ 975,124 AFE AMT: $2,190,000 15 2/12/82 DAILY COST: ACC COST: AFE AMT: 16 2/13/82 DAILY COST: ACC COST: AFE AMT: 5400' TD 5276' ETD (FC) 13 3/8" C. 1994' 9 5/8" C. 5371' 71 PCF 61 SEC $ 319,293 $1,294,417 $2,190,000 5400' TD 5276' ETD (FC) 13 3/8" C. 1994' 9 5/8" C. 5371' 71 PCF 60 SEC $ 77,563 $1,371,980 $2,190,000 C&C hole for logs· Pulled to shoe & wait 1 hr. RIH - worked thru bridge ~ 4427'. RIH & tagged fill ~ 5365' (35' of fill)· Washed & reamed to 5400'. C&C hole - getting some coal & shale up. Strapped DR out of hole. RU Schlum & ran DIL-Sonic-GR & YDL- GR logs. Ran VDL-GR & FDC-CNL-GR logs f/ 5390 to 13 3/8" shoe. RD Schlum. RIH w/ bit #SRR on BHA #10. CO 15' fill. Bit plugged while circ. Trip to un- plug bit. Found no fill. C&C mud for csg. POOH. RU to run 9 5/8" csg. Changed pipe rams. Ran 9 5/8" 47# N-80 butt csg to 5371'. Stuck csg ~ 5371' while,,PU ldg jt &cmtg head. Cmtd 9 5/8 csg w/ 1900 sxs "g" w/ 3% KCL, 1.2% D-19 · 2% gel, .1% A-2, .1% R-5 & .2% D-6. Pumped 50 bbls water ahead of 50 bbls of 85 pcf mud sweep. Followed sweep w/ cmt. Displaced cmt w/ 10 bbls water & 376 bbls of mud. Bumped plug w/ 2600 psi. Received some cmt contaminated mud ~ surf & had only partial returns during last 40 bbls of displacement. CIP ~ 23:30 hrs 2/12/82. Attempted to drop slips thru BOPE. Slips hung up in hydril. Removed BOPE. Installed slips - hung 225,000#. RECEIVED JUN 1 6 i982 Al3ska Oil & Gas Cons. commis~ioo Anchorago SHEET D UNION OIL COMPANY OF CALIFORNIA WELL RECORD PAGE NO. 6 LEASE KENAI UNIT WELL NO. 11-17 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 17 2/14/82 5400' TD 5265' ETD (FC) 13 3/8" C. 1994' 9 5/8" C. 5371' 71 PCF 52 SEC DAILY COST: $ 25,193 ACC COST: $1,397,173 AFE AMT: $2,190,000 18 2/15/82 5400' TD 5265' ETD (FC) 13 3/8" C. 1994' 9 5/8" C. 5371' 70 PCF 40 SEC DAILY COST: $ 42,959 ACC COST: $1,440,132 AFE AMT: $2,190,000 19 2/16/82 DAILY COST: ACC COST: AFE AMT: 2O 2/17/82 DAILY COST: ACC COST: AFE AMT: 5400' TD 5140' ETD (RET) 13 3/8" C. 1994' 9 5/8" C. 5371' 70 PCF 40 SEC $ 60,779 $1,500,911 $2,190,000 5400' TD 5053' ETD (RET) 13 3/8" C. 1994' 9 5/8" C. 5371' 68 PCF 32 SEC $ 30,782 $1,531,693 $2,190,000 Cut off 9 5/8" csg. Installed & tested CIW "DCB" spool. NU & tested BOPE. LD 4 1/2" DP. RIH w/ 8 1/2" blt & 9 5/8" csg scrpr. 0 to~ 5265' DPM (5276' csg meas). Circ clean. POOH. Ran SDC gyro survey on Dresser Atlas WL. Ran Dresser Atlas CBL-VDL-GR. PreSs tested 9 5/8" csg to 3000 psi. Perfed 4 HPF for sqz below Sterling C-1 f/ 5160' to 5162'. Ran GR & OB to 5150'. Set cmt ret on WL ~ 5140. Sqz'd perfs for isolation w/ 250 sxs "G" w/ 5% KCL, .75% D-31, .7% D-19, .2% A-2 & .2% A-6. Initial rate 3 1/2 BPM ~ 1500 psi, final rate 2 BPM ~ 2275 psi. Form held 750 psi prior to sqz & 1850 psi after. Rev olean & POOH. Parred 4 HPF f/ 5103' to 5105'. RIH & set cmt ret $ 5053'. Sqz'd perfs above Sterling C-1 sand f/ 5103' to 5105' for isolation w/ 250 sxs "G" w/ 5% KCL, .75% D-31, .7% D-19, .2% A-2 & .2% D-6. Initial' rate 4 BPM ~ 1000 psi, final rate 4 BPM ~ 1000 psi. Formation held 300 psi prior to sqz & 650 psi after. Rulled out o~ ret &circ clean (could not rev - kill line frozen). POOH. RECElVEI7 UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE KENAI UNIT WELL NO. 11-17 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 21 2/18/82 5400' TD 5265' ETD (FC) 13 3/8" C. 1994' 9 5/8" C. 5371' 67 PCF 36 SEC DAILY COST: $ 21,891 ACC COST: $1,553,584 AFE AMT: $2,190,000 22 2/19/82 5400' TD 5265' ETD (FC) 13 3/8" C. 1994' 9 5/8" C. 5371' 64 PCF 3O SEC DAILY COST: $ 39,025 ACC COST: $1,592,609 AFE AMT: $2,190,000 23 2/20/82 DAILY COST: ACC COST: AFE AMT: 24 2/21/82 DAILY COST: ACC COST: AFE AMT: 5400' TD 5265' ETD (FC) 13 3/8" C. 1994' 9 5/8" C. 5371' 64 PCF 30 SEC $ 54,968 $1,647,577 $2,190,000 5400' TD 4263' ETD (RET) 13 3/8" C. 1994' 9 5/8" C. 5371' 64 PCF 30 SEC $ 57,740 $1,705,317 $2,190,000 WOC. CO ret ~ 5053'. Cmt still soft. WOC. CO cmt f/ 5053' to 5107'. RIH to ret @ 5142'. C0 ret ~ 5142' & cmt to 5265' ETD. Circ clean. POOH. RU & ran DA CBL-VDL-GR f/ 3000' to 5265' ETD. RD DA. RIH w/ 8 1/2" bit & 9 5/8" scrpr. X-over to KCL comp fluid. X-over to 4% KCL comp fluid. POOH. RIH w/ test tools. Displ DP w/ N2 & set RTTS ~ 4532'. Bleed off N2 to 800 psi. Inflow perfed B-4 w/ 4 HPF~ w~ 2 1/16" guns f/ 4641' to 4661'. Put well on test. Well died. Re- displaced DP w/ N2. Put well on test. Well died - too much water to produce to surface. Ran static BHP survey. Ran BHP survey. BHP stabilized ~ 1178 psi ~ 4316' VD. RD DA. Killed well. POOH w/ test tools. RU DA. Ran GR & OB to +4700'. Set cmt ret on WL ~ 4263'. RIH w/ DP. Broke down parrs f/ 4~641' to 4661' w/ 1250 psi. Pumped in~6~-r~s~ '4BPM w/ 1300 psi. Sqz'd parrs w/ 400 sxs "G" w/ 10% silica sand, 5% KCL, .75% D-31, .7% D-19, .2% D-6 & .2% A-2. Final rate 2 1/2 BPM ® 1250 psi. Held 1200 psi w/ pumps off after sqz (held only 200 psi prior to sqz). Rev clean. UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. LEASE KENAI UNIT WELL NO. 11-17 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 25 2/22/82 5400' TD 5265' ETD (FC) 13 3/8" C. 1994' 9 5/8" C. 5371' 64 PCF 30 SEC DAILY COST: $ 24,802 ACC COST: $1,729,319 AFE AMT: $2,190,000 26 2/23/82 DAILY COST: ACC COST: AFE AMT: 27 2/24/82 DAILY COST: ACC COST: AFE AMT: 28 2/25/82 DAILY COST: ACC COST: AFE AMT: 5400' TD 4607' ETD (SAND) 13 3/8" C. 1994' 9 5/8" C. 5371' 64 RCF 28 SEC $ 38,119 $1,764,798 $2,190,000 5400' TD 4607' ETD (SD) 13 3/8" C. 1994' 9 5/8" C. 5371' 64 PCF 28 SEC $ 28,025 $1,792,793 $2,190,000 5400 ' TD 4607' ETD (FC) 13 3/8" C. 1994' 9 5/8" C. 5371' 64 PCF 28 SEC $ 25,130 $1,817,923 $2,190,000 POOH. WOC. RIH w/ 8 1/2" bit. Drld out cmt ret ~ 4623'. CO hard cmt to 4646'. CO cmt stringers to FC @ 5265'. CO to FC $ 5265'. Circ well clean. POOH. RIH w/ RTTS & RBP. Set RBP ~ · 4627' & sanded out to 4607'. Set RTTS ~ 4406'. Displ DR w/ N2. Tested surf equip to 2000 psi. Bled off N2 to 750 psi. Rerfed 4 HRF w/ 2 1/16" link jet guns f/ 4567' to 4587'. Rut well to flare. Developed leak in surf test mani- fold. Shut well in. Changed out bad connection. Perfed remainder of B-4 sd f/ 4547' to 4567' DIL & 4528' to 4547' DIL (total perfs f/ 4528' to 4587' DIL). Opened well to test - had stab rate after 16 hfs of 8.60 MMCFD ~ 920 psi w/ ll5 BWRD (total water produced = ll2 bbls). SHut well in. Rerfed B-3 sd f/ 4483' to 4498' DIL. Perfed B-3 sd f/ 4468' to 4483' DIL (total shots f/ 4468' to 4498' DIL). Released RTTS &circ to kill well. RIH to 4593'. Displ DR w/ N2 & set RTTS. Opened to flare - made small amt of gas then dead for 2 hrs. Re- leased RTTS & rev circ- estimated 40 bbls of fluid entry (unsure whether RTTS actually set below upper B-4 perfs). POOH. RU DA & tested lub. While testing lub, DA pulled out of rope socket & dropped 4" perf gun down hole. , UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. 9 LEASE KENAI UNIT WELL NO. 11-17 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 29 2/26/82 DAILY COST: ACC COST: AFE AMT: 5400 ' TD 4512' ETD (RBP) 13 3/8" C. 1994' 9 5/8" C. 5371' 64 RCF 32 SEC $ 59,844 $1,877,767 $2,190,000 RIH w/ OS & latched onto fish - POOH & rec fish. RU DA & perfed B-4 sd f/ 4468' to 4498' DIL & B-3 sd f/ 4528' to 4587' DIL w/ 4 1/2" HRF. RD DA. RIH w/ retrieving tool & latched onto RBR ~ 4630'. Pulled up to 4512' & stick RBR. Circ visc sweep around & POOH - did not rec RBR. 3O 2/27/82 5400' TD 5340' ETD (CMT) 13 3/8" C. 1994' 9 5/8" C. 5371' 64 PCF 32 SEC DAILY COST: ACC COST: AFE AMT: $ 27,596 $1,905,363 $2,190,000 RIH w/ OS & tagged RBP ~ +1210'. POOH - rec RBP. RIH w/ bit & csg scrpr to 5340'. Circ clean & POOH. RIH w/ GR & OB to 5050'. Ran & set Baker model "D" prod pkr ~ 5010' DIL. RIH w/ stinger on DP & tested pkr - would not test. POOH. 4990'. Tested to 600 Psi 31 2/28/82 DALLY COST: ACC COST: AFE AMT: 32 3/1/82 DAILY COST: ACC COST: AFE AMT: 5400' ID 5337' ETD (OUNK) 13 3/8" C. 1994' 9 5/8" C. 5371' 64 PCF 33 SEC $ 22,267 $1,927,630 $2,190,000 5400' ID 5337' ETD (OUNK) 13 3/8" C. 1994' 9 5/8" C. 5371' 64 PCF 33 SEC $ 24,878 $1,952,508 $2,190,000 POOH W/ retrievamatic pkr. RIH w/ BO shoe & pkr picker. Milled over pkr & pushed junk to btm. POOH. Rec small pce of mandril. RIH w/ bit & csg scrpr - tagged junk ~ 5337'. Circ btms up & POOH. RIH w/ cmt ret & set ~ 5285'. POOH w/ DP. RU DA & set 9 5/8" model "D" pkr ~ 5005' DIL. RIH w/ 2' of seals on DP & test pkr to 500 psi - ok. POOH. RIH w/ 9 5/8" model "D" pkr on WL & set ~ 4622' DIL. RI~H~LZ_2! of seals on DP & test pkr to 500 psi - ok. ~ ~OOH LD DP & DC's. Changed rams. JUN 1 6 i982 & 6ores. Oommt F UNION OIL COMPANY OF CALIFORNIA WELL RECORD PAGE NO. 10 LEASE KENAI UNIT WELL NO. 11-17 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 33 3/2/82 DAILY COST: ACC COST: AFE AMT: 34 3/3/82 DAILY COST: ACC COST: AFE AMT: 35 3/4/82 DALLY COST: ACC COST: AFE AMT: 36 3/5/82 DAILY COST: ACC COST: AFE AMT: 5400' TD 5285' ETD (RET) 13 3/8" C. 1994' 9 5/8" C. 5371' 64 PCF 30 SEC $ 24,878 $1,952,508 $2,190,000 5400 ' TD 5285' ETD (RET) 13 3/8" C. 1994' 9 5/8" C. 5371' 64 PCF 30 SEC $ 222,487 $2,181,864 $2,190,000 5400' TD 5285' ETD (RET) 13 3/8" C. 1994' 9 5/8" C. 5371' PKR FLUID $ 128,454 $2,301,318 $2,190,000 5400' TD 5285' ETD (RET) 13 3/8" C. 1994' 9 5/8" C. 5371' $ 49,038 $2,359,356 $2,190,000 Ran dual 3 1/2" comp assy. un dual 3 1/2" comp assy. Spaced ~n'~e~ ~g] A-5 pkr¢ 4605'. Se~ o~ned "XA"-~431' &tested pkr. Closed "XA" $ 4431'. Removed BOPE. Installed & tested tree. Opened "XA" sleeve ~ 4337'. Displ annulus w/ pkr fluid. Closed XA ~ 4337'., Opened XA ~ 4431'. Latched on 70 XN plug in XN nipple ~ 4519'. Could not pull plug. Opened XA in LS ~ 4598'. Pulled XN plug f/ SS ~ 4519'. Displ N2 down LS taking . returns on SS until B-3 & B-4 perfs came on. Flowed B-3 & B-4 up SS until clean. Shut in SS. Flowed -'~-~B-3 & B-4 up LS thru sleeve ~ 4598' until clean. Closed XA ~ 4598'. Tested lub. Inflow perfed C-1 w/ 8 HPF f/ 5106' to 5154' w/ 2 1/16" ridgit jet guns. Installed BPV's. Released rig to moving rate ~ 24:00 hrs. A~s~30~t & 6~s Co.s. Commission UNION OIL COMPANY OF CALIFORNIA WELL RECORD SHEET D PAGE NO. ll LEASE KENAI UNIT WELL NO. 11-17 FIELD KENAI GAS FIELD DATE ETD DETAILS OF OPERATIONS, DESCRIPTIONS & RESULTS 37 3/6/82 5400' TD Moving rig. 5285' ETD (RET) 13 3/8" C. 1994' 9 5/8" C. 5371' DAILY COST: $ 18,306 ACC COST: $2,377,662 AFE AMT: $2,190,000 38 3/7/82 5400' TD Moving rig. 5285' ETD (RET) 13 3/8" C. 1994' 9 5/8" C. 5371' DAILY COST: $ 30,109 ACC COST: $2,407,771 AFE AMT:. $2,190,000 39 3/8/82 5400' TD 5285' ETD (RET) 13 3/8" C. 1994' 9 5/8" C. 5371' DAILY COST: $ 20,000 ACC COST: $2,407,771 AFE AMT: $2,190,000 4O 319182 5400' TD 5285' ETD (RET) 13 3/8" C. 1994' 9 5/8" C. 5371' DAILY COST: $ 29,653 ACC COST: $2,437,424 AFE AMT: $2,190,000 41 3/10/82 DAILY COST: ACC COST: AFE AMT: 5400 ' TD 5285' ETD (RET) 13 3/8" C. 1994' 9 5/8" C. 5371' 10,670 466,631 $2,190,000 Moving rig. Moving rig. Moved rig to Kenai Yard. Released rig 3/10/82. RECEIVED JUN 1 6 1982 Alaska Oil & Gas Cons. Commission Anchorage AMF° JOB NUMBER: WEI...L NAHE: I..[)CAT I ON: oURVEY DATE: SCIENTIF"IC DRILI_ING INTERNATIONAL 1111 E 80TH ANCHORAGE GYROSCOPIC DIRECTIONAL SURVEY FOR ******************************* *UNION OIL OF CALIFORNIA* *************************** 5301 KU-11-17 K~N~I PENINSULA 02115/82 SURVEY ENGINEI.ER: B,CHAPPELL M A G N Ii..". T I C D E C L I N A T I 0 N: A T ,00 E GYRO REFERIEN[;E BEARING: S 15.- 6 E METHOD OF CALCUI..ATION: VERT]~CAI.. SEC'rION: 'qMMENI'S THE I'ANGENTIAI_ METHOD CALCULATED THANK YOU USING PROPOSAl_ OF N 85-25 E THIS SURVEY IS GORREGT TO THIE BEoT OF MY * COHP ANV~ EP R ESENTAT I VE .X..X..X..X..X..X..X..~ .X..X..X..X. ~..X..~ .X..~ ~..~ .~ ~ ~ ~ .X..X..X..X..X..X..X..X..X..~..X..X..X..X..X..X..X..X..X..X..X..X..X..X..X' AMF SCIENTIFIC DRILL. lNG INTERNATIONAL 1111 E 80TH ANCHORAGE PAGE JOB NUMBER: 5301 MEAS, ViER T, VER T, DEP TH DEPTH SECT, 100,00 100.00 200 . O0 199.99 300 , O0 299,98 400 , O0 399.98 500 . O0 499.95 600 . O0 599.60 700 . O0 898,75 800 . O0 796,65 ?00 . O0 893,25 000 . O0 988,88 1100,00 1083,98 12(ILO , O0 1177,49 1300 . O0 1289,55 1400 . O0 1359 , 81 1500, O0 1447,84 INRUN SURVEY BY THE TANGENTIAL METHOD COURSE INC BEARING DEV, D M D M .17 .87 0-30 N 13-10 W ,75 .87 0-30 N 18-57 E 1,34 1,75 1- 0 N 4-55 W 3,05 1,75 1- 0 N 77-11 E 4,75 1.75 1- 0 N 77.-25 E 13,02 8,28 4-45 N 81-32 E 28,07 13,05 7--30 N 64-12 E 46,43 20,36 11-45 N 65-13 E 72,31 2).5,88 15- 0 N 64-17 E 101,50 ;~9,24 17- 0 N 82-85 E DATE: 08115/82 COORDINATES LATITUDE DEPARTURE D-LEG PER 100 ,85 N ,20 W ,50 1.88 N ,08 E ,28 3,42 N ,09 W ,57 3,81 N 1,61 E 1,31 4,19 N 3,31 IE ,00 8,14 N 13,82 N 22,38 N 33,59 N 47.13 N 10,59 E 3,80 22,34 E 2,76 40,83 I:'[ 4,25 64,15 E 3,28 90,06 E 2,06 117,48 E 1,00 149,44 E 8,82 184,42 E 2,27 223,30 El 2,75 268,29 E 8,59 132,37 30,90 18- 0 N 62-31 E 81,39 N 187,79 35,43 20-45 N 64.-27 E 78,67 N 206,84 39,07 23- O N 83-33 E 94,07 N 250,28 43,44 25-45 N 83.-29 E 113,48 N 297,34 47.08 28- 5 N 65--58 E 132,65 N AMF SCIENTIFIC DRILLING INTERNATIONAL Illl E 80TH ANCHORAGE PAGE 2 JOB NUMBER: MEAS , VER l' , I)EP TH DEP TH 1600,00 1536,00 1700,00 1623,60 1800,00 1711,06 1900,00 1799,22 2000,00 1887.38 2100 , O0 1974,91 2200. O(.l 2062,65 2500 . O0 2150 2400 , O0 22~6,93 2500,00 2325, 5301 VERT, SECT, 1NRUN SURVEY BY THE TANGENTIAl_ METHOD [;OURSE INC BEARING DEV, D M D M 544,54 47,20 28-'10 N 65.- 8 E 392,77 48,25 28-50 N 65-47 E 441,24 48,48 29- 0 N 64-49 E 488,45 47,20 28-.10 N 65-41E 535.65 47,20 28-10 N 65-57 E 584,00 48.35 28-55 N 65-29 E 651.97 47,97 28-40 N 65-58 E 680.07 48.10 28-45 N 65-55 E 730,06 5(3,0(3 50- 0 N 66.-56 E 780.05 50.(30 5{3'- 0 N 67-24 E 2600.00 2412,05 826,58 46,56 27-45 N 66'-'59 E 2700,00 2500,55 875,52 46,95 28- O N 66-33 IE 2800,00 2588.82 ~20,07 46.56 27'-45 N 66-30 E 2900,00 2676,98 967.25 47,20 28-10 N 67-18 E 3000.00 2765,48 1013.76 46.56 27-45 N 68-13 E DATE: 02/15/82 COOR D I NATES LATITUDE DEPARI'UR D-.-LEG E PER 100 152,59 N 509,07 E 172,58 N 555,(36 E 195,(30 N 596,95 E 212,44 N 459.95 E 251,95 N 482,94 E 251,99 N. 526.93 E 271,53 N 570.75 E 291,18 N 614.65 IE 511,04 N 660.54 E 550,25 N 706,70 lie 548,71N 749,44 E 567,59 N 792.51 E 585,96 N 855.21 E 4(34,17 N 878,76 E 421,45 N 922,00 E ., 46 ,76 .4?' ,75 ,54 1 ,30 ,40 2,28 ,25 .25 ,56 AMF SCIENTIFIC I)RILL. 1NG INTERNATIONAL llll E 801'H ANCHORAGE PAGE.'". 3 JOB NUMBER: 5301 MEAS, VERT, VERI'. DEPTH I)EP'¥H SECT . INRUN SURVEY BY THE TANGENTIAL METHOI) COURSE INC BEARING I)EV. I) M D M 3100,00 2853, ?8 1060,26 46,56 27-45 N 68-1I E ~200.00 2743,08 1105,66 45,40 27- 0 N 65-~2 E 3300,00 3032,05 1151,23 45,66 27-10 N 6~- 5 E 3400,00 3120,75 1197,31 46,17 27-30 N 6?- 1. E 3500,00 3807,65 1243,01 45,7? 27-15 N 67-- 1 E 3600,00 37 (! 0,00 ;'~800, O0 35~ 00.00 4000,00 41 O0.01) 4200. It 0 4300, O0 440 I). I) 0 4500.00 32?8,6? 1288,45 3387,3? 1334,47 3475,68 1381,31 3563,28 1427,36 3650,75 1477.72 3737.57 1527,111 3823,73 1577,61 3909,45 1628,80 3995,16 1680,00 4080,88 1731,10 45,53.3 27- 5 N 6?- 8 E 46,17 27-30 N 6?-42 E 46,95 28-' O N 69-37 E 48,23 28-50 N 70-23 E 48,48 2?-' O N 6?-27 E 49,62 2?-'45 N 71'- 6 E 50,75 3(~-30 N 70-58 E 51,50 31- 0 N 71'"45 E 51,50 31-' 0 N 71-43 E 5'1,50 31'- 0 N 72-34 E DATE: 02/15/82 COORI)INATES I_ATITUI)E I)EPARI'UR 438,76 N 965,23 E 457,56 N 1006,55 E 473,86 N 1047,20 E 4?0.3? N 1092,31 E 506,7? N 1135.06 E 523,10 N 1177,57 E 539,12 N 1220,88 E 555,47 N 1264,1-38 E 571.66 N 1310,31 E 588,68 N 1355,70 E 604,76 N 1402,65 E 621,31 N 1450,63 E 637,44 N 1499.54 E 653,59 N 1548,45 E 669,02 N 1597,59 E I).--LEG E PER 100 ,01 1,43 1,62 ,25 ,17 ,52 ,50 ,48 1,10 ,75 ,64 , O1 ,44 AMF ~'"' ,.~t.,IENTIr=IC DRILLING INTERNATIONAL 1111 E 8ilTH ANCHOR AGE PAGE JOB NUMBER: 53(;1 DATE: MEAS, VER l) E P T H l) E P 4600. OO 4166 47 (; 0 . 0 O 4851 480 (;, 00 4:336 4900 , O0 4482 5000 , Oil 4508 51 O0 , O0 4594 ~,= il 0, I1 il4680 ,.~::.~, 00 47~-.:J INRUN SURVEY BY THE TANGENTIAl_ METHOI) COURSIE INC BEAR lNG I)EV, l) M l) M COOR D I NATES LATITUDE l)EP AR TUI;{IE ,45 1782,,35 51,75 31-10 N 73..-84 E 683,81 N 1647,18 E ,71 1834,21 52,25 ;~1.-30 N 72.-26 IE 699,57 N 1697,00 E ,¢?7 1886,il7 52,25 31--~50 N 72-25 E 715,36 N 1746,81 E ,69 1937,18 51,50 31-. 0 N 72'-28 E 7;~0,87 N 1795,~2 E ,41 1988,;~il 51,50 31-. O N 72.-26 E 746,41 N 1845,il2 E ,35 2il38,94 51,1,3 3(3-45 N 7.3.-20 E 761,08 N 1894,00 E ,51 2089,1~~. 5il,75 30-~.0 N 74- 6 E 774,98 N 1942,81 E ,Ti; 2114,01 25.19 3il-15 N 74.- 7 E 781,88 N 1~67,04 E THE HORIZONTAl.. DISPLACEMENT AT THE l)EPTH OF · X..X, {(..X..X- .X..X. -X. ~:: .... 0 O0 I=IEET IEQUAL. S 2'116 74 FEET AT N 68-17 E · X- -X, ,X- -X' -X, -X. ,X' -X, 02/1 5/8'~,,.. I)"-L..EG PER 100 ,46 ,60 ,01 ,50 ,01 .46 ,SI; Suggested form to 1~ inserted in each "Active" well folder to check for tin~21y compliance wi~n. our rogulations. Ol~arator, Well Name and Number Reports and Materials to bc received by: ,~ '-~ Date Rax]ui red Date Received Remarks · Cc~pl~tion Report .. Yes ...:.. i.~ ,~./ ........... "'~ ":~' ........... :"~ ....... t~ . ~ ~ Wel 1 H.ist~ "~'"~'(~> S~les : PI Mud L~ .. , ~, ,.~ Core ~scription .... .Inclination Su~ey ~.~ Dire~ional su~ey . Drill St~ Test Re~s Pr~uction Test Re~rts ~ ~'~ ~ ,1~ Digitiz~ ~ta ' / STATE OF ALASKA . ~-~~ ALASK~ .L AND GAS CONSERVATION C( ,MISSION MONTHLY REPORT OF DRILLING AND WORKOVER OpERA'rl · Drilling well ~] Workover operation [] 2. Name of operator 7. Permit No. UNION OIL COMPANY OF CALIFORNIA 81-176 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 50- 133-20349 9. Unit or Lease Name KENAI UNIT 4. Location of Well at surface 768'S & 631'W of NE corner, Sec. 18, T4N, RllW, SH. 5. Elevation in feet (indicate KB, DF, etc.) [\1,.) T.J. lq./',./ i - i,,,.,~ i.-- 6. Lease Designation and Serial No. ADL 22330 10. Well No. KU #11-17 11. Field and Pool KENAI GAS FIELD For the Month of MAR£H ,19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Released rig 3/10/82. TMD 5400 ' 13. Casing or liner run and quantities of cement, results of pressur9 tests None 14. Coring resume and brief description None 15. Logs run and depth where run None 16. DST data, perforating data, shows of H2S, miscellaneous data Perfed 5106-5154' 17. I hereby/~)tify that the foregoing is true and correct to the best of my knowledge. o~-~ /.,~ hi)..,/ DIST DRLG SUPT 4/15/82 o u,~E~~/ ~ , ~~/~~ITLE DATE NO~eport on this form is required for each cale~ar month, regardless of the status of operations, and must be filed in duplicate with the Al'~ska Oil ~d Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 i/,~i6*;~~!~¼?i,,~;~!~- Document Transmittal :'*'~.i:-~:~:~,i~i-'~!~i~:.~iii~i~i-,:.i'~i-',':i', ..' ~*~*' ~ Union Oil Company of Ca~ifornia DATE SUBMITTED ACCOUNTIN'G MONTH 04/02/82 'roAictskct u~ t, ommissiun ATTN- Harry Kugler Robert C. Warthen ~3001 Porcupine Drive ~ UNION OIL COMPANY Anchorage, AK 99504 Anchorage " ' TELEPHONE NO. TRANSMITTING THE FOLLOWING: 276- 7600 KU 11-17 1 )ach Blueline & Sepia of the ]~o.llowi g- 5" DIL 2" DIL 5" CNL FDC 5" BHC Soni(, 2" BHC ~nn~c .... ' , 5" VDL (0H) 5" FDC ,, 2" CVL '1 Tangential Directional S~rvey 1 Rad. of Curv. Directiona Survey, 1 Ave. Angel Dir~ctin~a! 1 Magnetic Tape , .. ~ Ee~se ac~owledge receipt by si~ing and A,~W fill & G ~s Cons. Com~ss[o~ ~ } ~ ~ ~-.~,', .:.-'-~:? - .:.:. · . · FORM 1-2M02 (REV. 11-72) PRINTED IN U.S.A. ' ~, t, J''~' ¢,~~0tJ'tJr~b~i0~' · .. - '.,~'..~:'.').r.~? f MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. UNION OIL COHPANY OF CALIFORNIA 81-176 3. Address 8. APl Number P0 BOX 6247 ANCHORAGE AK 99502 50- 133-20349 4. Location of Well at surface 768'S & 631'W of NE corner, Sec. 18, T4N, RllW, SM. 5. Elevation in feet (indicate KB, DF, etc.) KB +!00' HSL 6. Lease Designation and Serial No. 9. Unit or Lease Name KENAI UNIT 10. Well No. KU ~11-17 11. Field and Pool KENA! GAS FIELD For the Month of FEBRUARY , 19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks TMD 5371' ~ 2/28/82. 13. Casing or liner run and quantities of cement, results of pressure tests Ran 13 3/8" 68~ K-55 butt csg to 1994' - cmt w/ 1180 sxs cl "G" - tested to 2500 Psi Ran 9 5/8". 47~t N-80 butt csg to 5371' - cmt w/ l~O0 sxs cl "G" - tested to 3000 psi - 14. Coring resume and brief description None 15. Logs run and depth where run DIL-Sonic-GR, VDL-GR, FDC-CNL-GR f/ 53~0-19~4' CBL-VDL-GR f/ 5371' CBL-VDL-GR f/ 3000-5265' 1 6. DST data, perforating data, shows of H2S, miscellaneous data Perfed & sqz'd 5160-5162' 5103-5105' 4641-4661' ' Perfed 4468-4498' 4528-4587' 17. I hereby~'l~ify that the foregoing is true and correct to the best of my knowledge. . DAT~ 3/15/82 N?E-~,~eport on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oif~A'nd Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate L AND GAS CONSERVATION C0~ MONTHLY REPORT OF DRILLING AND wORKOVER OPERATIONS · Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. UNION OIL CONPANY OF CALIFORNIA 81-176 3. Address 8. APl Number PO BOX 6247 ANCHORAGE AK 99502 50- 13~-20349 4. Location of Well 9, Unit or Lease Name at surface KENAI UNIT 768'S & 631'W of NE corner, Sec. 18, T4N, RllW, SM. 5. Elevation in feet (indicate KB, DF, etc.) KR +100' NLSL 6. Lease Designation and Serial No. ADL 223~0 10. Well No. KU ¢t11-17 11. Field and Pool KENAI GAS FIELD For the Month of 3ANUARY ,19 82 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Commenced operations ~ 00:01 hrs 1/22/82 Spudded ~ 03:00 hrs 1/29/82 TMD ~ 2003' on 1/~1/82 13. Casing or liner run and quantities of cement, results of pressure tests None 14. Coring resume and brief description None 15. Logs run and depth where run None 1 6. DST data, perforating data, shows of H2S, miscellaneous data Gas Cons,, C0~rnJssiai-~ 17. I hereby~cer~ify that the foregoing is true and correct to the best of my knowledge. DIST DRLG SUPT SNIGNE~D E. DATE. NO~--~ort on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska ~Gas Conservation Commission by the 15th of the succeeding month unless otherwise directed. Form 10-404 Submit in duplicate Rev. 7-1-80 THRU ALASKA OIL AND GAS CONSERVATION COMMISSION Cha~~a~terton Commissioner Petroleum Inspector February 23, 1982 Witness BOPE Test on Union Oil's KGU-11-17 Well Sec. 18, T4N, RllW, S.M. Permit No. 81-176 ~hursday, F.ebruary 4,~. 198.2 - The BOPE test commenced at 1:00 p.m. and was concluded at-7:30 p.m. There were no failures and I filled out an A.O.G.C.C. BOPE test report which is attached. In summary I witnessed the successful BOPE test on Union Oil Company's KGU 11-17 well on Brinkerhoff Rig No. 58. I filled out an A.O.G.C.C. BOPE test report which is attached. O&G # 4 4/80 STATE OF AX,ASKA '~' ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. InsPe. ction Report Inspector Operator Well Location: Sec T R [! Drilling ~C~ntra-ct~ r ~,/)'*~!'~/~ ,~-.-/~ Date ~- - ~- Well ,~/-'(C..? ~-! Representative Permit # Rig # ~ , Location 7~ General .~ Well Sign General Housekeeping , ,,'~/<f, ' Reserve pit Rig ACCUMULATOR SYSTEr.1 '- Full Charge ~ressure .~OO(~ ps ig , , Pressure After Closure l~ ~..?f->c. psig 200 psig Above PreCharge Attained: Full Charge Pressure Attained: N2 !~OO. 1 ~ 50 ~,.Tz,..~r3. ~/~,0~ ..0 ps i~ . 1.' . / - Controls: Master O/<' Remote ~' ~Iinds switch cover · T~est Pr.es.s~re- K~lt-¥ a.n'~ Floor. Sa..fety Va. lves,,~-.,,,~,:,,,.,,:,~,.,~,~~. .............................. ,~.~ ..... ~; ,~ ~ ~ . . , ~ ~., ~'~i;~, ...., ,,~,,~r~par. Kal ly ' ' " · ' Ball Type ~ Test Pressure ~' Inside BOP -' Test Pressure -" .Blind' R~ams Choke Line Valves H.C.R. Valve ~ /' · Kil~ Line Valves~( Check V'al '~ Test Pressure Choke ManifOld :. ,No. Valves No.' flanges : Adjustable Choke~ Hydrauically operated choke_, Test Results.: Failures "~ Test Time ~. hrs. ,~"0 Repair or Repl'acement of failed equipment to be made within , .,., days and Inspector/Commission office notifiqd. Remarks: rain ~q sec min ('3_.~ sec /,//I Distribution orig .' - AO&GCC cc - Operator cc - Supervisor Inspector ALASKA AND GAS CONSERVATION CO ~,vllSSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. UNZON 0ZL COMPANY OF CALZFORNZA 3. Address 8. APl Number LA'--~. ~' PO BOX 6247 ANCHORAGE AK ~9502 5o- -~- 9. Unit or Lease Name 4. Location of Well +750'S & 650'W of NE corner, Sec. 18, T4N, R11W SN. OTHER 81'¢~-~ /7~' Number ~, .- or Lease Name KENAZ UNiT ~FN~T ~ FTFI 5. Elevation in feet (indicate KB, DF, etc.) VII J_ 1 I"ICI I MC::I -- I 6. Lease Designation and Serial No. 10. Well Number 11. Field and Pool ADL 223_~0 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 [] [] Other ~] Pulling Tubing [] Pull 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). The bottom hole location needs to be changed to +90'S & 1240'E of NW corner, Sec. 17, T4N, R11W, SH. This location provides a better location upstructure for better recovery. Because of this change, the name should be changed to KU #11-17. The surface location needs to be changed to +770'5 & +625'W of the NE corner, Sec. 18, T4N, Rl1~, SN. This location provides b~tter utilization of the pad area. The new well course does not cross any other well courses. Surface and bottomhole locations revision verbally approved by Russ Douglass on 12/10/81. E£E VED' DEC? 3 198] Abska 0il & Gas Cons. Commission Anchorage ~ertify that/t~ f~oir Signe~ ThVp/e below for Commission use Co itions of Approval, if any: tomg is true and correct to the best of my knowledge. Title DTST DRLG SUPT Date 12/18/81 Approved by ApproYed :~o~3y By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in.Duplicate WATER WELL RESERVE ,.Prr ~b/ ~ ,2/- 17 December 1, 1981 Mr. Robert T. Anderson District Land Manager P. O. Box 6247 Anchorage, Alaska 99502 Kenai Unit KU 21-17 Union Oil Company of California Permit No. 81-176 Sur. Loc. z 750'S, 650'W of NE cr Sec 18, T4N, RllW, SM. Botto~'ole Loc.l 200~S, 1800'E of NW cr Sec 17, T4N, RllW, SM. Dear Mr, Andersonz Enclosed is the approved application for permit to drill the above referenced well. well samples and. a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). available, a tape containing t~he digitized log information shall be submitted, on 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 migration of anadromous fish. operation~ in these areas are subject to AS i6.50.870 and the regulations promulgated thereunder (Title Alaska Administrative Code). Prior to commencing operations you may be contacted by the ~abitat Coordinator's o~ftce, Department' of Fish and Ga~e. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 an4 the regulations promulgated thereunder (Title 18, Alaska Admi~istrative Code,. Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to Mr. Robert T. Anderson Kenai Unit KU 21-17 ¸--2-- December 1, 1981 commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified .so that a repre- sentative of the Commission may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment, please give this office adequate advance notification so that we may have a witness present.. Ve~. truly yours, H. Hamilton Chair-man, of BY ORDER OF THE CO~;SSlON ~ ' Alaska Oil & Gas Conservation Corn iss~on Enclosure cc= Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o/encl. Union Oil and Gas~;vison: Western Region Union Oil Compans~ of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 union Robert T. Anderson District Land Manager November 24, 1981 Mr. Hoyle Hamilton Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99504 KENAI SOLDOTNAAREA State of Alaska Kenai Gas Field Kenai Unit, KU #21-17, ADL-22330 (8-86-71-5390-600956) Dear Mr. Hamilton: Enclosed for your approval are three (3) copies of the Permit to Drill the above captioned well. Also enclosed is our check number 19171 in the amount of $100.00 to cover the required filing fees. Upon approval, we would appreciate a copy so that we may complete our files. Very truly yours, bde Enclosures (4) NOV 5 lSS! Oil & ~as COns. STATE OF ALASKA ALASKA L AND GAS CONSERVATION C vlMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL [~ lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL [] DEVELOPMENT OIL[] SINGLE ZONE [~ DEEPEN [] DEVELOPMENT GAS [~ MULTIPLE ZONE [] 2. Name of operator UNION OIL COMPANY OF CALIFORNIA 3. Address PO BOX 6247, ANCHORAGE, ALASKA 99502 4. Location of well at surface 9. Unit or lease name +750'S & +650'W of the NE Corner, Sec. 18, T4N, RllW, SM. Kenai Unit At top of proposed producing interval 10. Well number +380'S & +ll00'E of NW Corner, Sec. 17, T4N, RllW, SM. Kg #21-17 At total depth 11. Field and pool +200'S + +1800'E of NW corner, Sec. 17, T4N, RllW, SM. 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. KB +100' MSLI ADL 22330 Kenai Gas Field 12. Bond information (see~O AAC 25.025) National Fire Insurance Company of Type Statewide Surety and/or number Hartford (B5534278) Amount ~200~000·00 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed South +5 i/2 miles +200 feet well+1300 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 6300' MD & 5500' TVD feet 2270.6 December 1, 1981 KICK OFF POINT feet. MAXIMUM HOLE ANGLE 29 o (see 20AAC25.035(c) (2) 1800 ..psig@5000 ft. TD(TVD) 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND LINER SET]lNG DEPTH QUANTITY OF CEMENT Hole Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOM TVD (include stage data) _ Z0,. 94# Plain End 100 Surf I +100~ 100 Driven lY 1/2 13 3/8' 61¢; K55 Butt 2000 Surf I +2--000I · I I 1750 To surface_+1100 sxs 12 1/4 9 5/8 47¢! N80 Butt. 6300 Surf , +6300 I 5500 Mininum of 500' in- . Ii I side surf csg, .based I I on caliper log. 22. Describe proposed program: 1. Rig up Brinkerhoff Rig #58. 2. Drive 20" to refusal @ +100'. 3. Install 20" 2000 psi Hyd--ril & diverter assembly. RECE ~VED 4. Drill 17 1/2" directional hole to +2000' MD. ' 5. Run and cement 13 3/8" casing. 6. Remove 20" diverter assembly.NOV2 51,981 ~7. Install and test 13 5/8" 5000 psi BOPE. 8 Directionally drill 12 1/4" hole to +5800' MD Alaska0il&GasC0ns. C0mmissi0n · _ · Anchorage 9. Run logs· 10. Run and cement 9 5/8" casing, and test and complete well as justified by logs. .......... to the best of my knowledge 23. I hereby certify that the foregoing is true and corre~t~ The space below for Commission use Robert T. Ande~Mson CONDITIONS OF APPROVAL Samples required I Mud log required Directional Survey required I APl number I--lYES j~NOI i--lYES ~NO ~L.YES UNOI 50-/J~-%- ~ O ~'~/~ Permit number Approval date ~/-/'7(.,, 12/01/81 [ SEE COVER LETTER FOR OTHER REQUIREMENTS APPROVED BY ,COMMISSIONER DATE Dec_~n__h~__r 1_; 1_9R1 by order of the Commission Form 10-401 Submit in triplicate Rev. 7-1-80 1'578" 3.00o ps, III ka Oil & Gas Cons. Commission .Anchorage ~ 13"~'' ~"ooo 4-0 /:z · ,t /;~" 3000 Alaska Oil & Gas Con- Anchora~ uommis~ioo ~ ~ NOV2 5 198y NOV' 18 ~981 ~l~s,ka Oil ~ Oas Cons ' UNION OIL CO~Y OF C~I~RNIA I I FORkll Z47 (NEW DESIGN BY - ,-'/.-I,~, mD. OR. n J. R. UNDERHILL NOV 18 1981 --' psi/ft, M.S.P. , INTERVAL LENGTH. DESCRiPTION WEIGHT TENSION }2hq~R4 TDF W/ BF -top of STRENGgK Bottom Top Wt. Grade Thread W/O B,.~ section TESBION lbs lbs 1000 lbs COLLAPSE COLLAPSE PRESS. ~ P~SIST. bottom tension psi psi CDF 0 ,~ ~ensi~Load/Plpe Yield Strength Forr~ulae: Collapse resistance in tension = X (Collapse pressure ratify) Calculations: ~urst Pressure = ~m? + ~e~th ( ~a. or. zz -.~) BF (BouyanCy Fac'tot) = z.oo - (o. oz~ x ~u~ wt. z) BUP~T IIiTE~i'L~L PRESSURE I.ff ,.'~!.~x. Y~ELD psi psi BDF PP~CE PER PT. Totai Cost ,, I000 ~000 3OOO -~ .... i: !':i',Ur 3N OIL, .COMPANY OF C~ .... ~ '' ' ' .., -~ ..... !KENAI UNIT 21-17 ,' ! ' : --' ~ DRILL PAD · 41-18 ' :.~, '- ........ : ' : :- !";-' SCALE 'i"=1000I ' '..~_L ...................................... :-~--;--~--i--NOV. 16, ..1981. i-':-: ...... . i ...... i" BY . ~ '' '"' ' ~': ~" : ' ' 'i .............. ; .... '-' .... ~' '' BES E, EPP'S ~ POTTS : - '= .... ~ i · : ,. ! · ' FOR ,. ' ''::':' GREAT 1:'AND DIRECTIONAL"'DRILLING ": [ ' . : · . '~' ' ~-:' . 0 .............. ' SURFACE -~-' .... ~ ....... '" .... ' ............................ I000 ..... i ;:. - 718 : - KOP TVD:TMD= 50~500 ' : ! i . . . : 'o= ; ~_ i 'llOO' ~ TD 5° DEP= 0 ' . i '. . ' r41 - ' I-~~-"~"~~ TARGET A ............... ' 'tl' 8~ ...... ~ 0 BUILD 2 V2e PER I00'! , ,', I u · · o , T 4 N, R II W, SM - ' TVD= 1839 0 I000 . 2000 :~000 TMD= 19.30 : .. , DEP= 432 .-.:- . ~ ~ ....i-~ ..................... i ......... ' ............ [ . ; : ' 24o AVERAGE ANGLE 35°44'' , ........... ;~ .......... ,~ ...... ~ ....... , ,, .... · . TARGET A TVD=3725 TMD:4254'DEP=I789 : EOG TVD: 3957 TMD = 4528 ...... :" ': 'f ..... ' DEP= 1936 ' : ' ' . .. . 5000' ~. ' .... AVERAGE ANGLE 28°o . . ... TVD: 5000 ' ! TMD: 5720 ..................... i' ;' - DEP = 251 I ' - 25° 5000' _ . ' DROP 2 I/'2°i PER I00' · . . -j I000 2000 i ' U-M KDU-4RD {13-7} ~ 'VID 10,810 T N U-M KDU-2 (21-8) 1 M D 10,620 0 500 1000 FEET 18 17 Alaska District PROPOSED W~LL LOCATION KU-~I-17 ! ! II ! ! ! ! u-u S/T~ 3 n~ 8,TU/~v b,,,-snu \. -F I I I I I i I I I I I I I I I I I I I I I t I I I ..,,d~KU-14'4 1.5 mZ BTU/hr. Mt -F I I NOV ' I Oil & Gas r, I RIIW I I I I I t ! ! EXHIBiToC Fig. C-2 unt , n AI4Jkl OiJefk! KENAI GAS FIELD PRODUCTION FACILITIES CHECK LIST FOR NEW WELL PERMITS Company ,, ~x_~, Lease & Well No. , ~'~ /'? ITEM APPROVE DATE (2) Loc ~'%-1' ~/ 2. ~ thru 8) 3. / 4. 5. 6. 7. 8. (3> Admin:~/~ f!''l'?$1 9. thru 11) 10. 11. (12 thru 20) 12. 13. 14. 15. 16. 17. 18. 19. 20. YES NO Is the permit fee attached .............. , ........................ Is well to be located in a defined pool ............... Is well located proper distance from property line .... Is well located proper d±stance from other wells ................. Is sufficient undedicated acreage available in this pool . Is well t° be deviated and is well b°re plat'~ncl~d~d '[' i' ........... .......... Is operator the only affected party ..... , ......... .......... Can permit be approved before ten-day wait ....................... Does operator have a bond in force ................. Is a conservation order needed .... Is administrative approval needed ................................... Is conduct string provided or eeeeeeeeeeeeeeeeeeeeee®eee®®eeeeeeeeeeee Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings Will all kn wn pr d ti hori cement cover o o uc ve zons ..................... Will surface casing protect fresh water zones ....................... Wiil all casing give adequate safety in collapse, tension and burst..~ Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 .. ......... Is adequate well bore separation proposed ........................... REMARKS (5> BOPE ~, ~,/~71~! (21 thru 24) (6) Add: ~.. 21. 22. 23, °_4, ¸25. Is a diverter system required : ~ eeeeeeeeeee .eeeeeeeeeeeeeeeeeeeeee.eee e Are necessary diagrams of diverter and BOP' equipment attached ...... ~. ~f~ Does BOPE have sufficient pressure rating.- Test to ~O~o psig .. ~~' _ Does the choke manifold Comply W/AP1 RP-53 (Feb.78) .................. ~ ,.. Additional requirements Additional Remarks: Geology: Engi_ne~ering: ,cs rev~ 0~1~01~ INITIAL i GEO. UNIT ioN/oFF POOL CLASS STATUS AREA NO, · S.HORE · 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. hi5 TAPE VERIFICATION LISTIN'~ APR .0 5 1982 5VP 009.H05 VERIFICATION 5ISTING PAGE *~ RS£L HEADER SERVICE N~N~ :$ERVIC DATE :$2/02/25 O~iGi~ : R~L :~&ME :RE~L ID CONTI~JATION # PREVIOOS REEL SE, RVI~' u~ NA~E :SHRVIC DAT~ :~2/02/2~ ORIG!~ :1070 TAPE ~-~ME :62554 CO~'fi~tATION ~ :(;i CO~STS :TAP~ COMMENTS *~ FI[~E HEADER ~ FILE qA~E :SERVIC.O0i SERVICE NA~E : VERSIOq # DAT~ : MAXi~JM L~:NGTH : 1024 FIL~: TYPE : PREVIOUS ~IGE : *~ ImFORMATIOt! RECORDS Ci,~ : U~,ION OIL COMPANY ~;m : KU 11-17 F~,~ : KENAI GAS SECT: CO~JN: K~]NAI STAT: ALASKA CTR~: USA MNE~ CONTENTS PRtS: NEDiT4F ** R£CORO TYPE 047 UNIT TYP~ CAT~ SIZE CODE 000 000 01~ O65 000 000 008 065 000 000 010 065 000 000 003 065 000 000 002 065 000 000 002 065 000 000 006 065 000 000 006 065 000 000 004 065 UNIT TYPE CATE SIZE CODE 000 000 007 065 5VP 00q. H05 VERiFICATiON 5I'$~ING RECORD fYPE 047 *~ RECORD 'fYPE 047 ~ CO~qP~Y = UNION 0i5 COMPANY' DF ~ALTFORNIA WELL U i1 I7 FIELD = KENAI GAS COUN~'~ = KENAI STATE = ALASKA JUS ~ 10707,62554 DID ~ ~i, LOGGED 09'FE0'$2 BOTTO,q LOG INTERVAb TOP {~OG INTERVA~ CASi~,~~ ..... TYP~ ~OLE F~UiD VISCOSITY PH 5384 FT. =i983 13.38 IN. ~ 1983 FT. 1~,:25 ~N. DUDVIS/RESI~E~ 71 64 9,0 PAGE LVP oog.H05 VERIFICATION LISTING PAGE 3 FLUI5 bOSS RM ~ :~EAS. TEMP. R~F ~ ~EAS. TEMP. R~C ~ ,lEAS. TEMP. R~ ~ ~HT = 7.2 ML = .407 l.~ 61 F = .426 (4 60 m = .329 @ 67 F = .253 .~ ~02 F MATRI~ ** DaTA FORMAT RECORD ** ENTRY BLOCKS TYPE SIZ~ REPR CODE ENTRY ~ ! 66 8 4 73 60 9 ~ 65 .tin 0 I 66 0 DATUM SPECIFICATION BLOCKS MNE~ o~VICE SERVICE UNIT API AP1 AP1 API FILE SIZE PROCESS SAMPLE REPR ID OROER ~ LQG TYPE CLASS MOD NO, bEVEL CODE DEPf FT 0 0 ILM OIL OHMM 7 0 ILO O1b OmMM 7 12 SP ~)IL MV 7 GR OIL GAPI 7 31 DT BHC US/F 60 52 SP ~HC MV 60 GR ~hC GAPI 60 3i NPi~I ?ON PO 42 68 RMOB FDN G/C3 42 35 D~MO FD~ G/C3 42 44 CALI FDN IN 42 GR FDN GAPI 42 3I NRA~r FON 42 42 NCNL FON 42 34 FC~L FDN 42 0 0 0 4 0 0 0 4 0 0 0 4 46 0 0 4 0 0 0 4 32 0 0 4 32 0 0 4 0 0 0 4 32 0 0 4 2 0 0 4 I 0 0 4 0 0 0 4 3 0 0 4 32 0 0 4 1 0 0 4 92 0 0 4 93 0 0 4 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 68 DE PT SP 5423.000 SFLO -999.250 GR -999.250 IbM -999.250 DT -999.250 ILO -999.250 -999.250 -999.250 LV'P GR CALl FC~i, D£PT SP GR CALl FCmL DEPI SP GR CALl FCML DEPT GR CALl FCML DEP? SP GR CAbi FCNL DEPT SP GR CALl FCN b SP CALl FC~L DfPf SP G~ CALl FCSL DEPT SP GF CALl FCNL D~: PT SP 009.H05 VERIFICATION LISTING -9 -320 99 250 NPMI , 4,883 12:250 GR · 3652.000 80.000 NRAT 5400,000 SFLU 31,078 IL~ '36.2'19 GP 57,563 DT 57,563 NPHi 34.082 RHOB 7.2!97 GR '3652.000 NRAT 737.000 5300.000 SFLU 7.906 -26.453GR 55.3~2 55,312 NPMI 30.566 RMO8 12,211 GR 57,531 NRAT ~24,000 5200.000 SFLU -30.406 GR 49:000- ST 49.000 NPHI 33.691 12.195 GR 56.063 NRAT 59!,000 5.535 63.750 DX 33 154 64:I88 NRAT 5100.000 SFDU -16,484 GR 63.750 NPMI I2.305 GR b22.000 11.656 IbM 49,406 DT 35.645 5~,500 5000.000 SFbU -31,438 'GR 49,406 NPHI 12,I56 GR 571.500 6.734 58,655 DT 35,010 RHO~ 57.906 4900.000 SFbU -31,234 GR 58,656 NPH1 12.i72 GR 565.000 7 23~ Ib~ 47~938 D~ ~1,260 RH08 ~9.469 NRA'I ~800.000 SFbU -37,281 GR 47,938 NPHI 12.234 GR 520,000 ~ 000 52,295 RHOB 71.500 NRAT loo.ooo 20.250 aR 71.188 .NP~I 12.547 Gi~ 367.500 3.645 IbM 66.500 DT 4600.000 SFLO -t2.914GR -16384.000 0,961 3~.563 112,375 2.090 2.891 5.902 115.000 2.184 2.998 8,406 109 188 2:215 3.174 6,504 11i,750 2.264 3.172 I1.000 101.000 2.340 3.281 7,680 100.553 2.238 3,248 7.816 110.188 2.131 3.596 6.895 112.000 2,141 4.219 4,039 114,750 DRHO NCNb DRHO NCNb IbD SP DRHO NCNb IbD SP DRHO NCNb ILD SP DRHO NCNb IbD DR~O NCNb ILD SP DRNO NCNb ILD SP DRHO NCNb I bP SP DRHO NCNb ILD SP PAGE -16384.000 -16384.000 26.281 -36.219 0.062 2210.000 5.848 -26.453 0.042 207~.000 9.305 -30.406 0.033 1975.000 6.715 -16,484 0,031 2012.000 10.898 -31,438 0 018 oo9:ooo 7.496 -31,234 0.010 2164,000 7.535 -37.281 0.003 2000.000 7.352 -20.250 0.032 1830.000 4.160 -12.914 LVP 009.H05 VERIFICATION LISTING PAGE 5 GR CALl FC~i~ G~ CALl FC~b CALI FC~OL DEP~ SP G~ CALI FC~L SP GR CA'~I FCi'~ DEPT CALI FCi~L DEPT $P CALl FCNL DEPT SP GR CALl FCiqL DEPf SP GR CALl FC~gL SP 60.500 NPHI 12.595 GR 613.000 4500.000 SFbU -20.953 GR 52.938 NPMI 13.547 GR 451.250 4400.000 SFLU -37.969 GR 46.469 NPMI 12.281 GR 738.000 4300.000 SFLU -15.539 GR 61.094 NPHI i2.914 GR 440.25U 4200,U00 SFLU -18.000 GR 52.250 NPHI 13.547 GR 488.250 4100.000 SFLO -28.453 GR 49.813 NPHI 12.352 GR 442,250 4000.000 SF5U -18.922 GR 54.031 NPHI 12.836 GR 505.500 3900,000 SFLU -44.719 GR ~5.28i NPMI 12.203 Ga 560.500 3800.u00 SFbU -28,922 GR 52.688 NPHI 12.813 GR g53.750 3700.000 SFLU -27.688 GR 35.107 67.875 4.883 52.938 42.432 52.875 17.594 46,469 28.857 48.938 4.535 61.094 48.779 65.063 8.406 52.250 45.264 49.250 8.227 49.813 41.553 51.719 6.918 54,031 35.107 54.312 15.969 45.281 42.871 ~9.375 5.i84 52.688 44.629 56.281 7.535 61.000 DT NRAT IL~ DT RHOB DT RHOB NRAT IL~ DT RHOB NRAT I~ DT RMOB NRAT IL~ DT RHOB ~RAT IbM DT RHOB NRAT DT NRAT Ib~~, DT 2.240 3.268 4.914 111.i88 2.213 3.697 21.797 139.000 2.031 2.885 5.734 116.375 2.117 4.031 7.402 i15.563 2.203 3.854 7,953 130.750 2.094 3.617 5.938 114.750 2.28t 3.271 i8.641 136.125 2.117 3.686 5.133 12t.750 2.152 3.799 7.422 125.000 DRHO NCNb ILL SP DRMO SP DRMO ILD SP DRHO NCNb SP DRHO IbD BP DRHO NCNb ILL DRHO NCNb ILD SP DRHO NCNb SP ORHO NCNb ILL 0,013 2082.000 4.980 -20.953 o :O2 ooo 21.422 -37.969 -0.003 2376.000 6.156 -15.539 ° ooo 7.242 -18.000 0,056 1720.000 7 527 -28:453 0.O54 1739.000 6 055 -:i, 8:922 0.063 I873.000 17.703 -44.719 0.007 2168.000 5.242 -28.922 0.016 1786.000 7.496 -27.688 LVP GR CALX FCNL DEPT CALl FC~L DEPT SP GR CAbI FCNL D£PT SP CAbI FCN~ DEP~ SP GR CALi FCNb DEPT SP GR CAbi FC~L DEPY SP CALl FC~b SP CALl FCNL DE:PT SF CALI FC~L SP 009.M05 VERIFICATION LISTING 61.000 NPMI 12.~52 GR 434,250 3600,000 SFLO -30,3'59 GR 54,063 NPMI 12,6'41 GR 338,750 350u.000 -29.281 GR 54.000 NPMI 14.391 3~6,500 3i00.000 SFLU -29,453 GR 62,5.31 NPMI I5,344 GR 328,500 3300,000 SFbU -30,984 GR 63.219 NPM1 12.594 GR 381,500 3200.000 SFbU -42.750 GR 5g.031 NPHI 12,250 GR 473,500 3100,000 SFLU -44,563 GR 59,719 NPMI 12,453 GR 506.250 30o0.000 SFLU -37,03! G~ 49,875 NPMI 12,758 GR 386.250 2900,000 SFLU -53.719 GR 49,531 NPHI i2.297 GR 501,750 2800.000 SFBU .. -39.7t9 GR 46.826 55,031 ~,~9~ 56,063 55,078 48,844 6.0~6 6~.000 45.605 60,938 62.531 52,979 61,406 7,875 63'219 46.338 55.344 i2,758 54,031 42,920 47,375 8.29'7 59.719 46.289 54.312 9,i09 49.~75 47,754 43,469 13.094 49,53i )9,893 30.469 10.266 63.063 ~RAT DT DT RHOB DT NRAT DT NRAT DT NRAT IbM DT NRAT DT RHOB NRAT IbM D~ NRAT IL~ DT 2,096 3,908 7.703 125.563 2.1!7 4.375 6,969 128,375 2,096 3,896 132'750 2,063 4,328 8,i17 119,375 2,061 3,887 1i,906 129,000 2.078 3,68g 10,~45 129,500 2,082 3.883 9.234 135.000 1,979 3,973 15.758 136,i25 2,06b 3.521 10.672 i27.188 DRHO NCNb SP DKHO NCNb ILD DRHO NCNb IbP SP DRHO NCNb IbD SP DRHO NCNb ILD SP DRHO NCNb ILO SP DRHO NCNb iLD DRNO NCNb ILD BP DRHO NCNb I bD SP PAGE 0,029 1790,000 7,797 -30.359 0.045 1642.000 7.301 -29,28! 0.058 1468,000 7,156 -29,453 0.086 1508,000 8,~6! -30,984 0.031 1572,000 11,914 -42.750 0,006 1910.000 10.070 -44,563 0.021 1962.000 9.773 -37,031 0,023 1615.000 15.109 -53,719 0,001 1945,000 10.508 -39,719 bY? 009.H05 VERiFICATiON LISTING PAGE 7 GR 63,063 NPHI CALI 12,867 GR FC~L q17.750 DEPT 2700,000 SFbd SP -41,563 GR CALl 12.734 GR FC~L 3~7.500 DEPT 2bO0,O00 S~'bU S? -56,719 GR GR 41,000 NPHI CALl 12,430 GR FC~L 454,500 DEF'£ 2500,000 SFbU SP -58,500 GR GR 41,781 NPHI CALl 12.273 G~ FCi~ 51~,500 DEPT 2400,000 SFLO Ga 41,312 MPai CALl 12,398 GR FCNL ~41,50u DEP'£ 2300,000 SFbU SP -69,250 GR GR 41,938 NPHi CALl 12.250 GR FC:~L 515.000 DEPf 2200,000 SFbO SP -66,438 GR GR 43,50o NPMI CA%I 12,281 GR FC~b 426,750 DEPT 2i00,000 SFLU SP -69.688 GR GR 38,688 NPHI CA~i 12.305 GR FC~L g84.000 DEPT 2000,000 SFLU SP -51,406 GR GR 49,781 NPHi CALl ]4,484 GR FC~L 438,250 DEPT 1959.000 SFL[~ SP -68.250 GR 47,903 62.1~S 11.133 4B.46g 48.975 52.03i 11,875 41.000 t4.043 34,969 41,781 40,332 40.500 10.14i 41.312 42.236 44.188 11.656 41.935 ]7.5i9 4~.156 10,508 43,500 45,068 42.000 38.68~ 43.60i 43,156 11.2!I 49,781 45,068 45,844 2000.000 30.297 RHOB NRAT IbM .DT NEAT IbM D? RHOB NEAT IbM D~ RHOB NEAT IbM DT RH05 NEAT IbM DT RHOB NEAT IbM DT NEAT IbM DT RHOB NEAT IbM DT RHOB NEAT IbM OT 2.055 3,979 10.188 12S.000 2.105 4.039 13,227 147.000 2,064 3,758 19.391 145,375 2.109 3,547 10.516 143.000 2.076 3.656 i2,500 147,000 2,i31 3.391 iI.43~ i45,375 2,07~ 3,809 12,938 138.000 2.105 3.729 1!.383 149,500 2.078 3,~67 2000.000 5b.781 DEMO NCNb ILD SP DRHO NCNb ILD SP DEMO NCNb IbP SP DEMO NCNb lbo SP DRHO NCNb SP DRHO NCNb SP DRHO NCNb DRHO NC~)b ILD SP DRHO NCNb ILD SP 167~ '063 ,000 10,547 -41,563 000 i2.648 -56.719 0.022 1803.000 18,984 -58,500 -0,003 2098,000 10.266 -63.781 -~ 002 : ooo 12.i56 -69.250 0,§03 i959, O0 1i.~52 -66. 38 -0.000 1826.000 12.711 -69.688 0,013 1888.000 11.602 -51.406 0.019 1753.000 2000,000 -68,250 LISTING GR 30.297 NPHI CALl -999,250 GR FC~!L -999.250 -999.250 -999.250 R~iO8 NRAT ** FIibM TRAILER Fibs f,~ A ~-~ E :$ERV!C.00! S~,VIC~ NAME DATE : MAXI~{O~4 LENGT~ : ~024 FIb~ TYPE NEXT FihE NAME : -999.250 -999.250 ORHO NCNb PAGE -999.250 -999.250 ** T~PM TRAILER ** SERVICE MANE :SERVIC DATE ;~2/02/25 ORIGI~q :1070 TAPE ~A~E :62~.54 CO,TItiVATION # :01 NEXT '~PE NAME : COi~E~TS ~TAPE COMMENTS ** REEL TRAILER ** SE~ViCE NaME :SERVIC DATE ;82/02/25 ORIGI~ : REE6 ~AME ;REEh iD CONTI~0ATION $ ;01 NEXt' EOF EOF
