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Home My WebLink About195-193MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 16, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3Q-21 KUPARUK RIV UNIT 3Q-21 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/16/2024 3Q-21 50-029-22630-00-00 195-193-0 N SPT 3777 1951930 1500 2420 3120 3100 3100 REQVAR P Bob Noble 8/17/2024 MIT-T per 2B-005. Plug set at 7089'. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3Q-21 Inspection Date: Tubing OA Packer Depth 1 2 2 2IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN240818160824 BBL Pumped:0.3 BBL Returned:0.3 Wednesday, October 16, 2024 Page 1 of 1 9 9 9 9 9 9 9 99 9 9 9 9 9 MIT-T per 2B-005 James B. Regg Digitally signed by James B. Regg Date: 2024.10.16 12:33:49 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Wednesday, October 16, 2024 SUBJECT:Mechanical Integrity Tests TO: FROM:Bob Noble P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3Q-21 KUPARUK RIV UNIT 3Q-21 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 10/16/2024 3Q-21 50-029-22630-00-00 195-193-0 N SPT 3777 1951930 1500 2400 2600 2600 2600 REQVAR P Bob Noble 8/17/2024 MIT-IA per AIO 2B-005. Plug set at 7089'. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3Q-21 Inspection Date: Tubing OA Packer Depth 1 1810 1690 1675IA 45 Min 60 Min Rel Insp Num: Insp Num:mitRCN240818160057 BBL Pumped:1.3 BBL Returned:1.1 Wednesday, October 16, 2024 Page 1 of 1 9 9 9 9 99 999 99 9 9 9 MIT-IA per AIO 2B-005. James B. Regg Digitally signed by James B. Regg Date: 2024.10.16 12:35:53 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, September 2, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3Q-21 KUPARUK RIV UNIT 3Q-21 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/02/2022 3Q-21 50-029-22630-00-00 195-193-0 N SPT 3777 1951930 1500 2060 2820 2770 2760 REQVAR P Kam StJohn 8/10/2022 MIT-T every 2 years per AIO Against tubing plug per AIO 2B.005 Single casing well 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3Q-21 Inspection Date: Tubing OA Packer Depth 150 190 190 190IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS220810181625 BBL Pumped:0.3 BBL Returned:0.3 Friday, September 2, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 99 9 MIT-T every 2 years AIO 2B.005 James B. Regg Digitally signed by James B. Regg Date: 2022.09.02 12:15:41 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, September 2, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Kam StJohn P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 3Q-21 KUPARUK RIV UNIT 3Q-21 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 09/02/2022 3Q-21 50-029-22630-00-00 195-193-0 N SPT 3777 1951930 1500 2080 2390 2390 2390 REQVAR P Kam StJohn 8/10/2022 MIT- IA every 2 Years per AIO 2B.005 Single casing well 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 3Q-21 Inspection Date: Tubing OA Packer Depth 160 3300 3250 3240IA 45 Min 60 Min Rel Insp Num: Insp Num:mitKPS220810182030 BBL Pumped:1.9 BBL Returned:1.6 Friday, September 2, 2022 Page 1 of 1 9 9 9 9 9 9 9 9999 9 MIT- IA every 2 Years AIO 2B.005 James B. Regg Digitally signed by James B. Regg Date: 2022.09.02 12:18:12 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission To: Jim Regg DATE: Thursday, August 13, 2020 P.I. Supervisor � � � �Z� �L)Zt7 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3Q-21 FROM: Bob Noble KUPARUK RIV UNIT 3Q-21 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON -CONFIDENTIAL Comm I Well Name KUPARUK RIV UNIT 3Q-21 Insp Num: mitRCN200811144120 Rel Insp Num: API Well Number 50-029-22630-00-00 Inspector Name: Bob Noble Permit Number: 195-193-0 Inspection Date: 8/9/2020 Packer Depth Well 3Q-21 'Type Inj� N TVD I 3777 Tubing PTD 1951930 Type Testi SPT -Test psi 1500 IA BBL Pumped. 0.3 BBL Returned: 0.2 OA Interval REQVAR P/F — P Notes: MIT -T every 2 years as per AIO 2B.005 Pretest Initial 15 Min 30 Min 45 Min 60 Min 1070 - 1800 1760 - 1750 " 160 190 190 , 196 ' Thursday, August 13, 2020 Page 1 of 1 MEMORANDUM TO: Jim Regg P.I. Supervisor FROM: Bob Noble Petroleum Inspector Well Name KUPARUK RIV UNIT 3Q-21 Insp Num: mitRCN200811144553 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, August 13, 2020 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska, Inc. 3Q-21 KUPARUK RIV UNIT 3Q-21 Sre: Inspector Reviewed By: P.I. Supry Comm API Well Number 50-029-22630-00-00 Inspector Name: Bob Noble Permit Number: 195-193-0 Inspection Date: 8/9/2020 ' Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min --Tubin - Well 3Q-21 . �Type Inj �� N . D TV3777 , i g'11zo ]zzo i , •- 12ao • 1240 - — PTD 1951930 Type Test SPT- Test psi 1500 IA 150 1800 1680, 1650 - BBL Pumped: 0.9 - ;BBL Returned: 09 OA Interval REQVAR PIF P Notes: MIT -IA evert 2 years to 1500 psi as per AIO 213.005 Thursday, August 13, 2020 Page 1 of 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Monday,August 08,2016 P.I.Supervisor I SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3Q-21 FROM: Bob Noble KUPARUK RIV UNIT 3Q-21 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3Q-21 API Well Number 50-029-22630-00-00 Inspector Name: Bob Noble Permit Number: 195-193-0 Inspection Date: 8/2/2016 Insp Num: mitRCN160804112235 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3Q-21 Type Inj N TVD 3777 Tubing 530 690 690 690 PTD 1951930 ' Type Test SPT Test psi 1500 IA 170 1800 1780 • 1780 --------------- Interval REQVAR P/F P " OA Notes: MIT-IA per AIO 2B.005.Mono bore well. scAttiiiiED MAI 0 I n17- Monday, 1 '.Monday,August 08,2016 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Monday,August 08,2016 Jim Regg ', v P.I.Supervisor ��(� iJ�3(t .a SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3Q-21 FROM: Bob Noble KUPARUK RIV UNIT 3Q-21 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv,6s— NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3Q-21 API Well Number 50-029-22630-00-00 Inspector Name: Bob Noble Permit Number: 195-193-0 Inspection Date: 8/2/2016 Insp Num: mitRCN160804105825 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min --------- -- Well 3Q-2I (Type Inj N 'TVD 3727 ' Tubing 1010 1800- 1775 • 1770 PTD 1951930 Type Test SPT Test psi 1500 - IA 180 200 200 220 Interval REQVAR P/F P ✓ OA Notes: MIT-T per AIO 2B.005.Mono Bore well. Sakti ED Wil-SL, I2Q� Monday,August 08,2016 Page 1 of 1 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Tuesday,May 17,2016 Jim Re P.I.Supervisor �e �( 5(7'5(4° SUBJECT:Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3Q-21 FROM: Lou Grimaldi KUPARUK RIV UNIT 3Q-21 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry jet-- NON-CONFIDENTIAL etNON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3Q-21 API Well Number 50-029-22630-00-00 Inspector Name: Lou Grimaldi Permit Number: 195-193-0 Inspection Date: 5/12/2016 Insp Num: mitLG160512184343 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min � Well 3Q-21 JType Inj N TVD 3777 Tubing 1000 1160 1170 - 1170 - PTD 1951930 Type Testi SPT!Test psi 1500 IA 40 1765 - 1660 - 1640 - Interval REQVAR P/F P OA Notes: Casing MIT as required by AIO 2B.005.All required paperwork provided prior to test.See prior MITT(monobore well)for tubing test. Mit 1-Ci 1 l z i 5,3zt SCANNED SEP. 2 7 2016 Tuesday,May 17,2016 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Tuesday,May 17,2016 P.I.Supervisor �i I t"c' SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3Q-21 FROM: Lou Grimaldi KUPARUK RIV UNIT 3Q-21 Petroleum Inspector Sre: Inspector Reviewed By;._, P.I.Supry J lam! NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3Q-21 API Well Number 50-029-22630-00-00 Inspector Name: Lou Grimaldi Permit Number: 195-193-0 Inspection Date: 5/12/2016 Insp Num: mitLG160512183206 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3Q-2I Type Inj N TVD 3777 Tubing 1020 - 1810 , 1790 - 1785 PTD 1951930 Type Test SPT Test psi 1500 - IA 40 40 _40. 40 - Interval REQVAR P/F P ✓ OA Notes: MITT as required by AIO 2B.005.All required paperwork provided prior to test.See subsequent MIT IA(mono j re well)for casing test. � v SQc'r�k�7 e M+ LCablat 5-izt 4.-3`t3 wog) SEP 2 7 2016 Tuesday,May 17,2016 Page 1 of 1 • • RECE/VED OCT 232015 ConocoPhillips AQGGC Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 �� MAY 1 12016 October 20, 2015 /CIS' 193 Commissioner Cathy Foerster Alaska Oil& Gas Commission 3 Q — : I 333 West 7t'Avenue, Suite 100 Anchorage, AK 99501 Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field(KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC,this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spreadsheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call MJ Loveland at 907-659-7043, if you have any questions. Sincerely, 7/ c-_____",....-/r MJ Lo eland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 10/20/2015 3H,3J,3Q&3S Pad Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 3H-26 501032020800 1940290 9" NA 9" NA 4.3 10/9/2015 3J-18 500292270100 1961470 12" NA 12" NA 8 10/3/2015 3J-19 500292270200 1961480 11" NA 11" NA 4.25 10/5/2015 3Q 21 500292263000 1951930 12" NA 12" NA 5.5 10/9/2015 3S-6A 501032045401 2030880 11" NA 11" NA 9.1 10/3/2015 3S-23A 501032045301 2060430 16" NA 16" NA 6.2 10/3/2015 3S-24A 501032045601 2040610 18" NA 18" NA 6.3 10/3/2015 3S-26 501032036101 2010400 9" NA 9" NA 3.8 10/3/2015 STATE OF ALASKA ALL OIL AND GAS CONSERVATION CO SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter CasingChangeApprovedProgramr r Rug for Redrill r Perforate New Pool Repair Well r Re-enter Susp Well r Other:conductor Extension f 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 195-193 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-029-22630-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025512 KRU 3Q-21 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7617 feet Plugs(measured) None true vertical 6715 feet Junk(measured) 7140-7158' Effective Depth measured 7508 feet Packer(measured) 7140 true vertical 6276 feet (true vertical) 6340 Casing Length Size MD ND Burst Collapse CONDUCTOR 80 16 121 121 0 0 SURFACE 3983 7.625 4024 3910 0 0 LINER 3759 6.56 7616 6714 0 0 SC N EP DEC_, 1 2015 RECEIVED Perforation depth: Measured depth: 7304-7316',7332-7342', 7348-7388' True Vertical Depth: 6469-6479',6484-6499',6504-6536' OCT 1. 3 2015 Tubing(size,grade,MD,and TVD) 2.375, 0, 7154 MD, 6351 TVD AOCC Packers&SSSV(type,MD,and TVD) Baker ZXP packer @ 3857 MD&3777 TVD& BAKER MODEL'D' @ 7140 MD and 6340 TVD NIPPLE-4.5"Camco DB-6 Nipple @ 497 MD and 497 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): NA Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations r Exploratory r Development r Service J7 Stratigraphic r Copies of Logs and Surveys Run F 16.Well Status after work: Oil r Gas r WDSPL r Printed and Dectronic Fracture Stimulation Data r GSTOR r WINJ IT WAG r' GINJ r SUSP r SPLUG r 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: 315-532 Contact MJ Loveland/Martin Walt rs Email N1878@conocophillips.com Printed Name MJ Lovela d Title WI Project Supervisor Signature / hone:659-7043 Date 10/11/2015 zli L C v71.- (o/J4//5 � (00 Y.RBDMS 01;114 2015 Form 10-404 Revised 5/2015 Submit Original Only • 3Q-21 • DESCRIPTION OF WORK COMPLETED SUMMARY Date10/11/15 Event Summary 09/27/15 Welded 12.5"x16" .375 62# extension onto the existing conductor 10/09/15 Injected 5.5 gallons of RG2401 sealant into the conductor. • 3Q-21 • DESCRIPTION OF WORK COMPLETED SUMMARY • e(1!--;OF \�\V/7, sTHE STATE Alaska Oil and Gas #fr �, °I-ALASKA f Conservation Commission ._ ____�- ALASI�:.A 333 West Seventh Avenue ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279 1433 OFALAS1 Fax 907.276 7542 www aogcc.alaska.gov MJ Loveland ��, q j3 WI Project Supervisor l ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 3Q-21 Sundry Number: 315-532 Dear Ms. Loveland: 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 D- day of September, 2015 RBDM SEP 0 9 2015 Encl. ' STATE OF ALASKA AL_ _,JKA OIL AND GAS CONSERVATION COM,....)SION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1 Type of Request: Abandon r Plug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:conductor Extension 2.Operator Name 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. , Exploratory r Development r 195-193 - 3.Address: 6.API Number: Stratigraphic r Service r P. 0 Box 100360,Anchorage,Alaska 99510 50-029-22630-00 • 7.If perforating, What 8.Well Name and Number Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No r J KRU 3Q-21 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025512 , Kuparuk River Field/Kuparuk River Oil Pool- 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft) Effective Depth TVD(ft): Plugs(measured): Junk(measured): 7617 , 6715 • 7508' , 6276'. None 7140-7158' Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 121' 121' SURFACE 39833910' _ 7.625 4024' �y LINER 6714' fi x �.e� 3759 656 7616' E.C,�--� /705 `3 c )S AUG 2 g -G3 Perforation Depth MD(ft) Perforation Depth TVD(ft). Tubing Size: Tubing Grade Tubing MD(ft) 7304-7316', 7332-7342', 7348-7388' • 6469-6479', 6484-6499',6504-6536' 2.375 0 7154 Packers and SSSV Type' Packers and SSSV MD(ft)and TVD(ft) Baker ZXP packer MD=3857 TVD=3777 NIPPLE-4.5"Camco DB-6 Nipple MD=497 TVD=497 12.Attachments: Description Summary of Proposal F 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service F 14.Estimated Date for Commencing Operations 15. Well Status after proposed work: 9/15/2015 OIL r WINJ r WDSPL r Suspended r 16.Verbal Approval: Date: GAS r WAG • GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: MJ Loveland/Martin Walters Email: N1878(a�conocophillips.com Printed Name MJ Loveland ale: WI Project Supervisor / Signature Phone:659-7043 Date g o2S— /S-- Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3 k1 —G 3 2 Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other Spacing Exception Required? Yes ❑ No R Subsequent Form Required: /0 — 4G J/ �]�, APPROVED BY Approved by: / lq' ` proved application is vat& N meit /rroom thT��lS4 val. Date: 94-0-- `/ 1 SEP mit Form and Form 10-403 Revised 5/ ��` � BDMS t c sin Duplicate ORIGINAL ConocoPhillips Alaska AUG 2 8 2015 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 A O G C(`t August 25, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 3Q-21, PTD 195-193 conductor extension. Please contact Martin Walters or MJ Loveland at 659-7043 if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska, Inc. Kuparuk Well 3Q-21 (PTD 195-193) SUNDRY NOTICE 10-403 APPROVAL REQUEST August 25, 2015 This application for Sundry approval for Kuparuk well 3Q-21 is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to the surface casing. At some point during normal operations the conductor subsided about 12". With approval, the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Examine surface casing for any corrosion damage. 3. Extend the conductor to starter head and fill the void with cement and top off with sealant. 4. File 10-404 with the AOGCC post repair. NSK Well Integrity Projects Supervisor " i KUP INJ 3Q-21 Conoc Phillips 01 Well Attributes Max Angle&MD TD Alaska.Inc. Wellbore APIIUWI Field Name Wellbore Status Ind(°) MD(f1613) Act Btm(ftKB) cnrrsmrtun,pl 500292263000 KUPARUK RIVER UNIT INJ 40.60 6,526.84 7,616.0 --- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) 'Rig Release Date 30-21,4129(20144:16'41 PM SSSV:NIPPLE Last WO: 41.00 1/5/1996 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,428.0 4/21/2014 Rev Reason:TAG,PULLED PLUG lehallf 4/29/2014 ................................................................................................ HANGER;38.7-Ilk'I',±� Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread HANGER;39.3-I`'_ '...l CONDUCTOR 16 15.062 42.0 121.0 121.0 62.50 H-40 Casing Description OD(in) ID(in) Top(ftKB) 'Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 7 5/8 6.750 41.0 4,024.4 3,910.6 29.70 L-80 BTCMOD ... Casing Description OD(in) ID(in) Top(ftKB) -Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread LINER 41/2 3.958 3,857.4 7,616.0 6,713.8 12.60 L-80 NSCT l ` • Liner Details Nominal ID Top(ft68) Top(TVD)(R(B) Top Incl(") Item Des Com (in) s 3257.4 3,777.2 35.97 PACKER Baker ZXP Packer w/(6.80')C2 tieback sleeve and 5.750 CONDUCTOR;42.0-121.0 44 locator,5.75"ID 3,869.8 3,787.2 36.34 HANGER Baker HMC liner hanger 6.56"x 4.892" 4.892 3,876.4 3,792.5 36.54 PBR PBR,6.25 x4.75 4.750 I 3295.7 3,808.0 36.84 XO XO 5.5"BTC to 4.5"NSCT 3.958 NIPPLE,496.8 7,164.4 6,359.6 37.77 NIPPLE Camco DB-6(HLN 2013)nipple,4.5"NSCT x 3.750 3.750 - ID 4 7,516.4 6,636.2 38.81 COLLAR Baker landing collar 3.958 . 7,549.5 6,662.0 38.86 COLLAR Baker float collar 3.958 Tubing Strings SLEEVE-C;3,821.0 Tubing Description String M...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)I...Wt(Ib/1t) Grade Top Connection TUBING I 41/21 3.9581 38.71 3,896.61 3,808.71 12.601 L-80 I NSCT Completion Details Nominal ID Top(ftKB) Top(ND)(MB) Top Incl(°) Item Des Com (in) 11 38.7 I38.7 0.13 HANGER Tubing Hanger(above LDS) 3.958 39.3 39.3 0.13 HANGER Tubing Hanger(below LDS) 3.958 LOCATOR;3,863.8 496.8' 496.7 1.69 NIPPLE 4.5"Camco DB-6 Nipple 3.813 j 3,821.0 3,747.5 34.89 SLEEVE-C 'Baker sliding sleeve 5.5 x 3.812 w/CMU,Otis X selective 3.812 I t■ profile-CLOSED 4/28/2006 3,863.8 3,782.3 36.16 LOCATOR Baker locator and xo to NSCT 3.875 '- MI 3,866.0 3,784.1 36.23 SEAL ASSY Baker GBH 22S seal assembly and spacer tubes 3.875 SEAL ASSY;3,866.0 •i . 1 1IN a 3,896.1 3,808.3 36.85 SHOE mule shoe 3.833 lther In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) (*) Des Com Run Date ID(in) 7,140.0 6,340.3 37.73'PACKER BAKER MODEL'D'PACKER w 15'SEALBORE- '6/18/2001 2.093 SHOE;3,896.1 ABANDONED COIL JEWELRY 7,144.0 6,343.5 37.74 COIL 6/18/2001 2.004 7,157.0 6,353.8 37.76 PBR PBR-ABANDONED COIL JEWELRY 6/18/2001 1.781 7,158.0 6,354.6 37.76 NIPPLE PETROTECH 1.73"NO GO NIPPLE w/PUMP THRU 6/18/2001 1.730 SUB-ABANDONED COIL JEWELRY Perforations&Slots Shot Dens Top(ND) Btm(TVD) (shutoff Top(ftK8) Btm(ftKB) (ftKB) (ftKB( Zone Date t) Type Corn SURFACE;41.0.4,0244 . 7,304.0 7,316.0 6,469.8 6,479.3 A-3,3Q-21 2/13/1996 4.0 IPERF 180 deg.phasing; Oriented 170 deg.CCW &10 deg.,33/8"Csg Gun PACKER;7.140.0 ig 7,322.0 7,342.0 6,484.0 6,499.7 A-2,3Q-21 2/11/1996 4.0 IPERF 180 deg.phasing; COIL;7,1448 C Oriented 170 deg.CCW f/High Side,33/8"HC Csg Gun PBR;7,157.0 7,348.0 7,388.0 6,504.4 6,535.8 A-1,3Q-21 2/11/1996 4.0 IPERF 180 deg.phasing; ie NIPPLE;7,158.0 Oriented 170 deg.CCW F/High Side,3 3/8"HC Csg Gun Notes:General&Safety End Date Annotation 6/18/2001 NOTE:TOC SOS CBL 1/28/96 @ 6190' 7/21/2005 NOTE:External CSG Patch,welded @ bottom of CSG mandrel hgr 27"x8",X65 500 wall pipe WSR 7/21/05 5/9/2006 NOTE:WAIVERED WELL-MONOBORE INJECTOR-WATER ONLY!! - 11/29/2009 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 IPERF;7,304.0-7,316.0 4 IPERF;7.322.0-7342,0-i- _ .322.0-7,342,0 - IPERF;7,348.0.7,388,0 LINER;3,857 4.7,616 A I Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /¢.,-~'-,Z~ File Number of Well History File PAGES TO DELETE RESCAN Gr Oal~r items - Pages: scale, halftones, pictures, graphs, charts- Pages:~,t J~' [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other Complete COMMENTS: Scanned by: Bevedy Dianna~than Lowell Date: TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ K2tA 3Q -a • • Pm ici5 30 Regg, James B (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] K 4 /!3'(Z Sent: Friday, April 13, 2012 1:44 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv; CPF3 Prod Engrs; CPF3 DS Lead Techs Subject: 3Q -21 (PTD195 -193) AIO 2B.005 compliance testing Jim, Guy ✓. Kuparuk injector 3Q -21 (PTD 195 -193) is due for bi- annual compliance testing under AIO 2B.005 by 04/23/12. The well is currently SI while awaiting a new injection line and we are currently unable to rig Slickline up to the well to set the plug required for the MITT. The well will remain SI until we are able to set the plug and the required witnessed tests can be performed. The well is already on the monthly injector report as required by the AA. Please let me know if you have any questions or if this plan is unacceptable. Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 fitediNibigp APR 1 MEMORANDUM To: Jim Regg ~ S~Iz~io P.I. Supervisor~~~ FROM: Lou Grimaldi Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, April 28, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3Q-2 ] KIJPARUK RIV iINIT 3Q-21 Src: Inspector NON-CONFIDENTIAL • Reviewed By: P.I. SuprV Comm Well Name: KUPARUK RIV UNIT 3Q-21 Insp Num: mitLG100421091317 Rel Insp Num: API Well Number: 50-029-22630-00-00 Permit Number: 195-193-0 ~ Inspector Name: Lou Grimaldi Inspection Date: 4/21/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3Q-2I ~ Type Inj. N TVD 3777 ' IA 425 47s 480 480 p ~ 1961930 TypeTest ~ SPT Test psi Isoo ~ OA Interval REQVAR p/F' P '' Tubing 820 lsoo '' 176o vso Notes: MITT for A.A. 2B.005. Tubing plug reportedly set at 7125' (wlm). Successful test of tubing, bled pressure afterwards for test of annulus. r~1 ~/ ,~ ~~ ~ ~ Wednesday, April 28, 2010 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission ~~ DATE: Monday, April 26, 2010 To: Jim Regg ~, P.I. Supervisor ~~ ~ ~ Iz~'(G SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3Q-21 FROM: Lou Grimaldi KUPARUK RIV UNIT 3Q-21 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed B P.I. Suprv Comm Well Name: KUPARUK RIV UNIT 3Q-21 API Well Number: 50-029-22630-00-00 Inspector Name: Lou Grimaldi Insp Num: mi[LG1 0042 1 092940 Permit Number: 195-193-0 Inspection Date: 4/21/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Wel] i 3Q-21 ~~Type Inj. N TVD 3777 ~ IA 428 1830 /~ 1745 1725 _ _- P.T.D~ 1951930~TypeTest SPT Test psi lsoo pA Interval RsQvAR p/F P ~ Tubing soo 910 930 Sao Notes: Second part of MIT required by vaziance 2B.005, MIT IA of Monobore injector (see MITLGI00421091317). ~_ ___-- ~ ..4r ~,>.,~ ~ L - w ws:m Monday, April 26, 2010 Page 1 of 1 MEMORANDUM To: Jim Regg ~ P.I. Supervisor 1~~G IC~i ~~~ FROM: Bob Noble Petroleum Inspector State of Alaska • Alaska OiI and Gas Conservation Commission DATE: Wednesday, October O1, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3Q-21 KUPARUK RIV UNIT 3Q-21 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv J~ Comm Well Name: KUPARUK RIV UNIT 3Q-21 API Well Number: 50-029-22630-00-00 Inspector Name: Bob Noble Insp Num: mitRCN080927185057 Permit Number: 195-193-0 ~ Inspection Date: 9/25/2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well sQ-zl ,Type Inj. W ' TVD ~ 377 IA ~ 0 1800 1650 I 1640 p.T 119s193o TypeTest i SPT Test psi ]soo - ; OA i ! i ~ Interval 4YRTST p~F P ~ Tubing ! 2400 2400 2400 2400 NOteS: Mono Bore Well Wednesday, October Ol, 2008 Page I of i MEMORANDUM To: Jim Regg k,~~ ( ~ (Z~~~(~u P.I. Supervisor FROM: Bob Noble Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Thursday, April 24, 2008 SUBJECT: Mechanical Integrity Tests COtiOCOPHILLIPS ALASKA INC 3Q-21 KUPARUK RIV UNIT 3Q-21 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~. Comm Well Name: KUPARUK RN UNIT 3Q-21 Insp Num: mitRCN080423084219 Rel Insp Num: API Well Number: 50-029-22630-00-00 Permit Number: 195-193-0 Inspector Name: Bob Noble Inspection Date: 422%2008 Packer Well 3Q 2] !Type Inj. N ~ TVD Depth Pretest Initial ~ 3777 I~j 380 ~ 420 15 Min. 30 Min. 45 Min. 60 Min. 4 0 ~ 420 , ~ - 1951930 ~ SPT ~ P.T --' - - ---- ~TypeTest ~ ~ Test psi ~ i ] szo _-___ OA ' ------ - ! ~ - ~ - --- Interval REQvaR p~F P Tubing ~ sus ]szo j ta8o ~ la~o ', NOtes• MIT-T per AIO 28.005. Mono bore well ~~~1Vl~~ MAY ~ ~ 2D08 Thursday, April 24, 2003 Page i of l MEMORANDUM TO: Jim Regg ~' ~' ~~~9~~J P.I. Supervisor ~` ~ gip' ~ ~" FROM: Bob Noble Petroleum Inspector State of Alaska • Alaska OiI and Gas Conservation Commission DATE: Thursday, April 24, 2008 StiBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASIC4 11~'C 3 Q-21 KLPARUK RIV LMT 3Q-21 Src: Inspector NON-CONFIDENTIAL Reviewed Bv: P.I. Suprv ~~~~' Comm Well Name: KUPARUK RN iINIT 3Q-21 API Well Number: so-o2~-22630-00-0o Inspector Name' Bob Noble Insp Num: mitRCN080423084830 Permit Number: 195-193-0 Inspection Date: 422!2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. -- ~ - -_ _------ - - ---- -J -~-~- T- Well 3Q 21 ..Type Inj. I N j TVD s~~7 IA ~ 4~0 ~ i~zo laso ~ Iaso !- --- - -_ ---- P.T I9s I9so TypeTest sPr ~ Test psi I szo OA ' - _ _- __ ' '' '! - -- -- - -- --r-- Interval REQvaR p~F P Tubing soo 900 900 900 ~_ ', _ _ __ Notes' MIT-IA per AIO 2B.005. Mono bore well ~~ MAY ~ ~ 2D08 Thursday, April 24, 2008 Page I of I NON-CONFIDENTIAL State of Alaska Alaska ~d Gas Conservation Commission DATE: Monday, May 22, 2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3Q-2J KUPARUK RIV UNIT 3Q-2J Src: Inspector b ,/ f q 3 \;0( MEMORANDUM e TO: Jim Regg j) I 2./ P.I. Supervisor 'K/ftS{ 2-:y ¿} «-0 FROM: Lou Grimaldi Petroleum Inspector Permit Number 195-193-0 Inspector Name: Lou Grimaldi Inspection Date 4/25/2006 Well Name: KUPARUK RIV UNIT 3Q-2I Insp Num mitLG060425140800 Rei Insp Num MITOPOOOOOII03 API Well Number 50-029-22630-00-00 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. I I Well IType Inj. N I TVD 3777 IA 550 590 600 600 ! P.T. I TypeTest 8PT! Test psi 1500 : OA Interval Required by Variance P/F Pass Tubing ¡ 750 1540 1540 Notes Monobore completion. Tubing test portion of two part test required for variance compliance. ""; t) Monday, May 22, 2006 Page I of 1 MEMORANDUM e A State of Alaska Alaska _nd Gas Conservation Commission NON-CONFIDENTIAL DATE: Monday, May 22,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3Q-21 KUPARUK RIV UNIT 3Q-21 S,,, l"p""'" 6 ~ \ q3 \q TO: Jim Regg P.I. Supervisor ~q slZ 1~)(P FROM: Lou Grimaldi Petroleum Inspector Well Name: KUPARUK RIV UNIT 3Q-21 API Well Number 50-029-22630-00-00 Inspector Name: Lou Grimaldi Insp N um mitLG060425 I 45 141 Permit Number 195- 193-0 Inspection Date 4/25/2006 Rei Insp Num MITOPOOOOOl102 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well i IType Inj. i N .. ! 3Q-21 ¡TVD 3777 I IA I 540 ¡ 1610 1560 1550 I 1951930 !TypeTest ! SPT i Test psi lOA , I P.T. 1500 I I , Interval Required by Variance P/F Pass Tubing! 650 I 680 680 680 ! Notes Monobore completion. Casing (IA) portion of two part test required for variance compliance. Monday, May 22, 2006 Page I of 1 A~i~..~~~ ®~t A~~ ~7~A~ ~~-1~I;S~lt"~A~`IO~T CQr~~iSl®I`T 333 W. 7`" AVENUE, SUITE 100 ANCHORAGE, ALASKA 9950-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ADMINISTRATIVE APPR®VAL 2~e~05 Ms. Nlarie McConnell Problem tiL'ell Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 ~,/~~ ~A~ : ~ ~~(j RE: Kuparuk River Unit 3Q-21 (195- I93) Request for Administrative Approval Dear Ms. McConnell: _ , ~..... On April 27, 2006 ConocoPhillips Alaska, Inc ('`CPAI") requested an administrative approval under Rule 9 of Area Injection Order ("AIO") 2A to allow- continued water injection in service well Kuparuk River Unit ("KRU"} ;Q-21. The Alaska OiI and Gas Conservation Commission ("Commission") GRANTS your request for WATER ONL~c' service, as detailed below. As constructed, KRU 3Q-21 does not meet the requirements of 20 AAC 2.412 (b) for an injection well which is required to be equipped with a packer set not more than 200' measured depth above the top of the perforations. The purpose of this requirement is to ensure that the injection string can be monitored throughout its length for possible leakage. Some 3600' of this wellbore cannot be monitored. ~i~'here fresh water is not affected, 20 AAC 25.40 gives the Commission authority to approve less stringent well construction and integrity requirements. For wells similarly constructed, the Commission has exercised this discretionary- authority and approved injection operations with the fluid Limited to water only. CPAI has provided pressure test information, dated April 25, 2006, using water that demonstrates that the injection string (combination of tubing and liner) and the surface casing (the 7-5i 8" casing above the packer) do have integrity. Per Rule 9 of Area Injection Order 2B, the Commission hereby grants CPAI's April 27, 2006 request for administrative approval to allow the well to remain in service. The Commission's administrative approval allowing injection in KRU 3Q-21 is conditioned upon the following: 1. Injection is limited to MATER ONLY; FRANK H. INURKOWSKI, GOVERNOR • • ,~dministrat:ve Aporova AI0 28.005 ~Iay S, 2006 Page 2 of 2 2. CPAI shall monitor and record tubing, inner annulus pressures and injection rate daily; 3. CPAI shall submit to the Commission a monthly report of well pressures and injection rates; 3. CPAI shall perform a mechanical integrity test of the tubing ("N1IT-T"} every 2 years with a plug set in the nipple profile at 71 ~8' measured depth to demonstrate continued integrity of the injection string; 4. CPAI shall perform a mechanical integrity test of the inner annulus ("MIT-IA"j every 2 years to demonstrate continued integrity of production casing; ~. CPAI shall immediately shut in the well and notify the Commission if there is any change in the well's mechanical condition; and ~. After wel! shut in due to a change in the well's mechanical condition, Commission approval shall be required to restart injection. 6. For administrative purposes, the '~1IT anniversary date is April 23, 2006. As provided in AS 31.0.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this Letter, or the nett working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. _ DOl at ch ge, Alaska and dated May 8, 2006. ',~ = ~-~~ J hn o an Daniel T. Seamount, Jr. Cathy . Foerster Chairman Commissioner Commissioner e e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA TIONSh1;ÜŒ ^' ^'. Repair Well 0 Pull Tubing 0 Operat. ShutdownD Other '''''l:r Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: Stimulate D Waiver D Abandon D Alter Casing 0 , Change Approved Program D 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: 1. Operations Performed: Plug Perforations D Perforate New Pool D Perforate D 4. Current Well Status: Development D Stratigraphic D 195-1931 6. API Number: 50-029-22630-00 Exploratory D Service 0 P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 62' 9. Well Name and Number: 3Q-21 . 8. Property Designation: Kuparuk River Unit 11. Present Well Condition Summary: .A lH. 2. 561 z ~þ §'- ¡..cI&. 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool Total Depth Effective Depth Casing Structural CONDUCTOR SUR. CASING LINER Perforation depth: measured 7617' feet true vertical 6715' feet measured 7508 feet true vertical 6276 feet Length Size MD 121' 16" 121' 3962' 7-518" 4024' 3759' 4-1/2" 7616' Plugs (measured) Junk (measured) TVD Burst Collapse 121' 3910' 6714' Measured depth: 7304'-7316',7322'-7342',7348'-7388' . . <\Ì\\ ,-\~? ¡ '-¡¡v(!"'ta ..: ~C,_ o ~ true vertical depth: 6470'-6479',6484'-6499',6504'-6536' Tubing (size, grade, and measured depth) 4.5", L-80, 3897 Packers & SSSV (type & measured depth) pkr= BAKER 'ZXP' pkr= 3857' SSSV= NIP SSSV= 497' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. RBDMS BFl MAY (I 8 2006 Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mef Water-Bbl NIA NIA Tubina Pressure Casino Pressure Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ 15. Well Class after proposed work: Exploratory D Development D Service 0 16. Well Status after proposed work: OilD GasD WAGD GINJD WINJ 0 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: 305-025 . Daily Report of Well Operations _X WDSPL D Contact Marie McConnell / Perry Klein :~~~:~:am~~d#Þ~ ~, Title Phone Problem Well Supervisor 659-7224 Date 4/27/2006 Form 10-404 Revised 04/2004 ORIGINAL ~l. A s·~.o'- .Au~;Zinal Only e 3Q-21 DESCRIPTION OF WORK COMPLETED SUMMARY e Date Event Summary 7/8/2005 Cut top 2.7' off conductor. Removed cement and exposed 7-5/8" casing. Found externally corroded casing with a pin hole leak 10.5" below bottom of csg mandrel hanger as shown in Photo #1. John Crisp witnessed casino damaoe. 7/21/2005 Seal welded top casing threads to casing hanger mandrel bottom. Seal welded top collar to casing pup. Installed external surface casing sleeve patch over corroded casing from seal weld to seal weld. Patch was a 27" long section of 8", X65 pipe, split and welded to surface casing across corroded casing. See patch design drawing & Photo #2. 8/7/2005 Cut and removed an additional 1 0" of conductor for a total of 3.5' of conductor removed. Removed cement and exposed an addition 10" of casing for inspection to determine if additional patch length required. Inspection results showed adequate wall thickness at that depth. 8/11/2005IcMIT to 3000 psi passed. See attached MIT report. 8/12/2005 Installed denso corrosion resistant coating on the patch and exposed surface casino. 8/15/2005 Patched conductor 9/14/2005 Top off conductor with corrosion inhibitor/waterproofing sealants. Circulated 10 BBLS 124 deg F fresh water at 0.5 BPM down 3/4" hose inserted into conductor to cmt top. Conductor TOC @ -4ft from conductor top. Vac'd water from cellar to TOC. Pumped 12 gallons of 2401 film coating corrosion inhibitor at 108 deg F, switched products and pumped 13.9 gallons of ROYFILL 404-B corrosion inhibitor filler at 116 deg F. Removed 3/4" treatment hose from conductor. 3/15/2006 CUT 2-3/8" CT WITH 1-11/16" CHC /1-11/16"ANCHORS AND 1 x 1-11/16" x 48" BRFL3. TUBING CUT AT 7134 FT. 2 FT ABOVE D NIPPLE. 3/19/2006 SPOTTED CTU#4 UP TO WORK PLATFORM. COMPLETED RIG UP OF PLATFORM AND CTU#4. TESTED SURFACE LINES TO 4000 PSI. PERFORMED FUNCTION TEST OF BOPE; TESTED SAME 300/4000 PSI- GOOD. MADE UP TOOLS (CON, CHECKS, DISCONNECT W/ 5K RUPTURE, 4-1/2" G-SPEAR, ECLIPSE PKR RETRIEVAL TOOL). BEGAN RIH. ONGOING. 3/20/2006 PULLED 2.375" COIL TUBING ANNULUS EXTENSION (SCAB LINER) FROM WELL, FP WELL AND IA WITH 10 BBLS DIESEL, REMAINDER OF WELL HAS 10.7 BRINE. 3/26/2006 CLOSE CMU @ 3821' RKB, MITIA PASSED. TAG CUT COIL TBG W /2.75" LIB @ 7134' RKB. MAKE A COUPLE ATTEMPTS TO PULL PTN PLUG @ 7158' RKB, NO SUCCESS. IN PROGRESS. e 3Q-21 DESCRIPTION OF WORK COMPLETED SUMMARY e Date Event Summary 3/27/2006 DRIFT 3.785" GAUGE RING TO 7134' RKB. FIRST ATTEMPT TO PULL PTN PLUG W / 2.8" X .5" O.D. PRONG FAILED. ATTEMPT TO GET 1.75" PUMP BAILER INTO 2 3/8" COIL FAILED. FINALLY PULLED PTN PLUG FROM 7158' RKB. IN PROGRESS. 3/28/2006 TAGGED TOP OF CUT 2-3/8" COIL STUB WITH 3.765" LIB. PLANTED SHORTENED OVERSHOT (FLAT BTM, OAL=22.5") WITH BAIT SUB ON STUB @ 7132' RKB. ATTEMPTED PULL SAME. IN PROGRESS. 4/20/2006PULLED 20' COIL TBG. FISH FROM 7086' SLM. IN PROGRESS. 4/21/2006 SET (MODIFIED PETROTECH) 1.73 CAT STANDING VALVE (202/4" OAL W/ 7/8 FISH NECK) @ 7158' RKB. MIT TBG. TO 2500 PSI ( PASSED) MIT IA TO 2000 PSI ( PASSED ). 4/25/2006 State witnessed MIT-T passed (against a plug set at 7158') & MITIA passed. Witnessed by Lou Gramaldi. See Attached MIT report 2: 3Q-21 Cornpletedcasingpatch 07-21-05 e Subject " ~ (.( r t:i 0: File f.) S 3 ~ -21 · ?re -Heee t the J1!a,.,dr: / I ~ Collar f:D tile $~~ reg 1Jrl't t.$. t:l S La 5/',,3- lie 0 d h,r 5e~ / tve Ijù~ ¿';'k,u/¿), e Sheet number Calculations Chart ..I o,L 7: ..J7/¿JS' Date · 5eo/ We /J the tA~6ds 7úb¡"1/~~/'"J at the vt4ondr;/ i Lo/lor rv/o/1dri / (2 o»elJ pc.sses) A . ¡;'¡'i:; ~ /~ve b I:;e In ~ the i:oe of /:.;, e Sea I l.Ve I d .h,r BotÁ tltJe M4ndr// 4 Collar 5 1~e.IJe. úÆ)dS · GJrDo ve borh <þ lee ve. 5/ ee ve we Id at e"ds ð[ the t-v YI/14 t c h. t h,'c= "'" "'e~ s .S) " · Cc, ~/',fð IS 7/$ o.[) CÁ 5e 8" ApI SLX- X¿'S 1/ é), 3 7S ~ o. 5?n>" uH~I/ pl'pe fvr i::4e. sleeve- O.L. PRINTING (907) 563-4743 (Ä~¡~i OD~ : I I -t- - t I I I I s/ee ) e.. ,-/ -",,-,,271/ I .-J r I I • Maunder, Thomas E (DOA) From: Dethlefs, Jerry C [Jerry.C.Dethlefs@conocophillips.com] Sent: Friday, September 23, 2005 4:41 PM To: Maunder, Thomas E (DOA) Cc: 'NSK Problem Well Supv' Subject: RE: Monobore Injection Wells Tom: To my knowledge you are correct. Since we recently "discovered" 2M-09A, I cannot guarantee there are not other anomalous wells out there we do not know about. But your list looks complete for the wells we do know about. Should we come across another in this situation you will be the first to know. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska ;; ., ~'I~; 907-659-7043 ~~ ~ ~ ~ r,r -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Friday, September 23, 2005 9:22 AM To: NSK Problem Well Supv Cc: Jim Regg Subject: Monobore Injection Wells Jerry, et al: we are checking our records and wanted to confirm the wells that are monobores. There are various wells out there that have had the name "monobore" attached to them. For this message, monobore means a well. that does not have a separate production casing set proximate to the injection horizon and the packer is set a significant distance above the zone. The first 4 wells on the list have the packers set in the surface casing. The wells on our "list" 3K-22 30-19 3Q-21 1~~-i,y?~ and possibly 2M-09A 3H-lOB would also be on converted. are: the list, but it is a producer never having been Thanks in advance for your assistance. Tom. Maunder, PE AOGCC 1 MEC.NICAL INTEGRITY TEST (M~ FORM WELL NO.: 3Q-21 I DATE: 18-11-05 WELL TYPE: ISWI I i,e,: Prod, Prod AIL, MI, SWI, PWI MIT TEST TYPE: ¡MITIA I i.e., Tbg, IA /9-5/8", OA /13-3/8", T x IA combo, etc. REQUIRED TEST PRESSURE: 13000 I psi. Note: Please consult the PWS if there's any question @ 7224, pager 909. FLUID TYPE(S) USED TO PRESSURE TEST: I Diesel R d II W IIh d P b f d d . T t ecor a e ea ressures e ore an unnq es. START TIME: 116:10 PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE PASS T I PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI)* (PSI)** FAIL S TUBING 0 3000 2950 2950 T IA 0 3000 2950 2950 PASS OA 1 COMMENTS: START TIME: PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE PASS T I PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI)* (PSI)** FAIL S TUBING T IA / 9-5/S" OA /13-3/S" 2 COMMENTS: START TIME: I PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE PASS T I PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI) (PSI) FAIL S TUBING T IA / 9-5/S" OA /13-3/S" 3 COMMENTS: r'SC COMMENTS, I * Start the MIT over if press loss is = 5% @ 15 minutes. ** Repeat the MIT if press loss is = 10% @ 30 minutes. Note: Test must exhibit pressure stabilization - press loss second 15 min < 50% press loss first 15 min FINAL STEPS MUST BE COMPLETED AND CHECKED OFF!!! D -- FLAG THE CASING VALVE WITH LOAD AND TEST INFORMATION D -- FLAG THE WING VALVE IF SI AT TIME OF LOADING AND TESTING. D -- NOTIFY DSO OF TEST RESULTS, VOLUMES PUMPED AND STATUS OF WELL. Witness: I cc: PWS 6/3/00 · e e STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tcm_Maunder@admin.state.ak.us OPERA TOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk / KRU /3Q 04/25/06 Brent Rogers - ASRC Lou Gramaldi Packer Depth Pretest Initial 15 Min. 30 Min. We1l13Q-21 I Type Inj. I N TVD I 3,777' Tubin~ 650 680 680 680 Intervall V P.T.D.I 19519301 Type test I P Test psil 1500 Casing 540 1610 1560 1550 P/FI P Notes: Monobore MITIA - per sundry variance #305-025 OA Well3Q-21 I Type Inj. N I TVD I 3,777' Tubing 750 1610 1540 1530 Intervall V PTD.I 19519301 Type test I P I Test psil 1500 Casing 550 590 600 600 P/FI P Notes: Monobore MITT - per sundry variance #305-025 OA Plug set in tbg at 7158' on 4/21/06. Weill I Type Inj.1 TVD I Tubin~ Intervad P.T.D.I I Type tes~ I Test psil Casing P/FI Notes: OA Weill I Type Inj. TVD I Tubin~ Intervall P.T.DJ I Type tes~ I Test psil Casing P/FI Notes: OA Well! I Type Inj.! I TVD I Tubin~ Intervad P.T.D.I I Type tes~ Test psil Casing P/FI Notes: OA TYPE INJ Codes D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 9/1/05 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 KRU 3Q-21 04-25-06.xls .2&.... of 1 7/28/20059:35 AM ') '~7fÆ~Œ ])~ fÆ~fÆ~~fÆ ') AT,ASIiA. OIL AlQ) GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279.1433 FAX (907) 276.7542 Jerry. Dethlefs Problem Well Supervisor ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: 3Q-21 305-025 ag ~Cf8/" ~. '\' Dear Mr. Dethlefs: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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 liday or weekend. A person may not appeal a Commission decision to Superi Cou t unless rehearing has been requested. DATED this l'day of February 2005 Encl. SCANNED FES 1120D5 ') ConocJP'hillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 30, 2005 Mr. Tom Maunder Alaska Oil & Gas Çommission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 ) ij'jön) t1rI:Z "1 ~ < Irl::4!> tV iY . ~IV ^hy3!\;'~ f' (:1, Dear Mr. Maunder: Enclosed please find 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. wells 3F-09 (PTD 1852700) and 3Q-21 (PTD 1951930). Both approval requests regard repairs for casing leaks. Please call Brad Gathman or MJ Loveland at 659-7224 or me at 659-7043 if you have any questions. Sincerely, f~LO~ Jerry Dethlefs Problem Well Supervisor Attachments c..VPT-I "'-Ö-S ~R.~:::''\~~'" \<t~\S <0",--- ~~ ~~~ ~Q\\.S ö.+ \~(J~N\L, Rnt~-oç STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operation Shutdown D Plug Perforations D Perforate New Pool D ) 1. Type of Request: D 0 D Suspend D Repair well 0 Pull Tubing D Abandon Alter casing Change approved program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360 7. KB Elevation (ft): RKB 62' 8. Property Designation: Kuparuk River Unit 11. Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 7617' 6715' 7508 Casing Length Size CONDUCTOR SUR. CASING Waiver D Time Extension D Re-enter Suspended Well D 5. Permit to Drill Number: 50-029-22630-00 9. Well Name and Number: 30-21 10. Field/Pool(s): Kuparuk Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): 6630 MD ) Perforate D Stimulate D 4. Current Well Class: Development Stratigraphic D D Exploratory D Service 0 TVD 121' 3962' 16" 121' 121 7-5/8" 4024' 3910 4-1/2" 7616' 6714 Perforation Depth MD (ft): 7304'-7316',7322'-7342',7348'-7388' Packers and SSSV Type: pkr= ECLIPSE PACKER; BAKER 'ZXP'; BAKER 'ZXP' SSSV= NIP 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch D 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name drry Dethlefs nt:7>CJ Signature 7~~~ C~~p Commission Use Only Perforation Depth TVD (ft): 6470'-6479',6484'.6499',6504'-6536' Packers and SSSV MD (ft) pkr= 3194'; 3857'; 7140' SSSV= 497' 13. Well Class after proposed work: Exploratory D Development D 15. Well Status after proposed work: Oil D GasD WAG D GINJ D LINER 3759' 15-Mar-05 Date: Tubing Size: 4-1/2" / 2-3/8" Contact: Title: Phone 659-7043 Conditions of approval: Notify Commission so that a representative may Wit~ 't\Th'<-a \.::) L '\ Plug Integrity D BOP Test D Mechanical Integrity Test ~ Location Clearance D k :ì-13 OPj=' 2/ SZG Annular Disp. D Other D 195-193 6. API Number: Junk (measured): Burst Collapse Tubing Grade: L-80 / CT Tubing MD (ft): 7154' Service. 0 Plugged D WINJ 0 Abandoned D WDSPL D Gathman/Loveland 659-7224 Problem Well Supervisor Date ð~~a.r- Sundry Number: :3ðs-02~) Other: 3 5ðO 'i'~ '\ M:\ "'-'\. \I'-'\.'V~ \<;.~ \(s;\ ~ ~\ \ "'roo~ 1'--";, . "11.-., U \ - FEB U J 2G05 *~~~~\kL~~~-\-~ ~~~"~ r. "i"...¡":~2~1e RBDMS 8Ft FEB 082005 BY ORDER OF J...", ,~.~~ COMMISSIONER THE COMMISSION Date: ':1"/ o£ INSTRUCTIONS ON REVERSE C RIG I N A L Submit in Duplicate Form 10-403 Revised 12/2003 '-- ) ConocoPhillips Alaska, Inc. Kuparuk Well 3Q-21 (PTD 1951930) SUNDRY NOTICE 10-403 APPROVAL REQUEST 01/29/05 The purpose of this Sundry Notice request is for approval to repair a surface casing Jeak. The repair will include excavation (as needed) around the wellhead, removal of conductor casing, and mechanical patch of the surface casing. The well has been shut-in and plugged since November 17, 2004. We113Q-21 is a monobore injector, completed in January 1996. Due to the mechanical structure of the well the AOGCC requires increased monitoring and MIT tests; the terms and conditions of the monitoring are detailed in Sundry 301-174. In June 2001 a coiled tubing (CT) liner was installed in the well so that MI gas could be injected. The liner was installed in the lower portion of the tubing in order to provide an annulus from the perforations to the surface. The liner had gas-tight integrity until July 2002, at which time the well was swapped back to water injection service; the AOGCC was notified at the time. The well has been on water injection service until December 16, 2004, when fluid was observed around the wellhead. The well was immediately shut-in, the tubing was plugged and the AOGCC was notified. Diagnostics on the well have determined a leak rate through the surface casing into the conductor at 0.2 gpm @ 2000 psi. During the leak rate test the leaking fluids were observed approximately I-foot below the surface casing hanger. The cement top in the conductor is near the level of the casing leak. Localized corrosion is suspected to be the cause of the failed casing. The casing repairs are proposed to be performed prior to removal of the CT liner so that competent barriers are maintained in the wellbore at all times. CP AI proposes the following plan for repair and long-term operation of the well: REPAIR AND OPERATIONS PLAN 1. Verify the well has two barriers between the formation and surface prior to repair operations; 2. Excavate around the wellhead as needed to provide access to the top portion of the casing; 3. Cut and remove the conductor as needed to gain access to the surface casing; 4. Repair / patch the damaged casing as per CP AI Mechanical Engineers direction and the replace the conductor casing; 5. Perform an MIT to verify the repair integrity; 6. Pull the tubing plugs and CT liner from the well and close the sliding sleeve; 7. Perform an AOGCC witnessed MIT-IA and MIT-T to verify mechanical integrity of the well is competent; 8. Return well to water-only injection, gas injection is not allowed; 9. Perform an MIT-IA every 2-years subject to standard test criteria (0.25 x tvd @ packer or 1500 psi minimum, whichever is higher); 10. Perform an MIT-T every 2-years against a tubing plug set in the landing nipple @ 7164' MD subject to the standard test criteria listed above; 11. Submit monthly reports of daily tubing & IA pressures and injection volumes; 12. Shut-in the well and notify the AOGCC should MIT's or injection rates and pressures indicate further communication problems. FEB 0 :i Z005 NSK Problem Well Supervisor 01-29-05 ') ~ cOnOCOPhîlliPS3:~1aSka.'î)~. API: 500292263000 SSSV Type: Nipple Annular Fluid: Reference Log: Last Tag: 7503 Last Date: 4/4/2001 TUBING (0-3897, 00:4,500, 10:3.833) CTU TBG (3194-7154, 00:2.375, 10:1.995) .. ~ ~' ~ ~ ~ I I i ~ Ii ; ~ ~ I t I I Ie: I [ I I i f ! iI: I 1 I PKR (3857-3858, 00:6.151 ) HGR (3870-3871, 00:6,560) PBR (3876-3877, 00:6.250) TTL (3897-3898, 00:4.500) LINER (3857-7616, 00:4.500, Wt:12.60) PKR (7140-7157, 00:3.740) PBR (7157-7158, 00:2.500) NIP (7164-7165, 00:4.500) Perf (7304-7316) - -- - Perf - (7322-7342) - - ==t Perf (7348-7388) --+ ~ ) KRU 3Q-21 Well Type: Orig Completion: Last W 10: Ref Log Date: 1D: Angle ~ TS: 38 deg @ 7279 Angle ~ TD: 39 deg ~ 7617 Rev Reason: Set Plug Last Update: 12/4/2004 INJ 1/511996 Size 16.000 7.625 4.500 Max Hole Description CONDUCTOR SUR. CASING LINER TUbingSttirig :-TUBING Size I Top I Bottom I TVD 4.500 0 3897 3809 rubingStdng';COILEDrUBINGSCABIiINER.;;RUÍ'I:6I18/2001 . Size I Top I Bottom I TVD I 2.375 3194 7154 6351 Perforations Summary Interval TVD 7304 - 7316 6470 - 6479 7322 - 7342 7348 - 7388 Wt 62.50 29.70 12.60 Grade H-40 L-80 L-80 Thread Wt 4.45 Zone A-3 Status Ft SPF Date Type 12 4 2/13/1996 IPERF Comment 180 deg. phasing; Oriented 170 deg. CCW & 10 deg., 3 3/8" Csg Gun 180 deg. phasing; Oriented 170 deg. CCW f/ High Side, 3 3/8" HC Csg Gun 180 deg. phasing; Oriented 170 deg. CCW FI High Side, 3 3/8" HC Gun 6484 - 6499 20 4 2/11/1996 I~ERF A-2 6504 - 6536 A-1 40 4 2/11/1996 IPERF 3821 3747 3857 3777 3870 3787 3876 3792 3897 3809 7136 6337 7136 6337 7140 6340 7157 6354 7158 6355 7164 6359 GênêddNÔtê$ Date Note 6/18/2001 TOC SOS CBL 1/28/96 @ 6190' 12/9/2001 WAIVERED WELL - Monobore completion with CT liner. Depth TVD 497 497 3194 3183 Description ID 3.813 2.093 Type NIP PKR Cameo 'DB-6' NO GO ECLIPSE PACKER - Note: Special pulling tool needed, requires 4.5" Eclipse mdel SL adapter for GS; packer does not have GS fishing neck Baker Sliding Sleeve wI CMU Otis 'X' Selective Profile opened 6/14/01 Baker 'ZXP' Baker 'HMC' Liner Baker PBR wI muleshoe BAKER 'D' NIPPLE 1.812" CA-2 BLANKING PLUG set 11/17/2004 BAKER MODEL D PACKER WITH 15' SEALBORE 3.812 5.750 4.892 4.750 3.833 1.812 0.000 2.688 1.781 1.730 3.750 SLEEVE PKR HGR PBR TIL NIP PLUG PKR PBR NIP NIP PETROTECH 1.73" NO GO NIPPLE Cameo 'DB-6'. WAG injection allowed. :' [:'8. n",J! .7 0' n r. i!-. U ':IJ L.. luJ CRIGi~jj\L Re: Kuparuk we1l3Q-21 (PTD 1951930) Suspect Surface Casing Leak e e ~~{Cs lOIA I I ..-:- . .~ tw'\ Subject: Re: Kuparuk we1l3Q-21 (PTD 1951930) Suspect Surface Casing Leak From: Thomas Maunder <tom _ ma~nder@admin.state.ak. us> Date: Wed, 17 Nov 200408:08:28 -0900 To: NSK Problem Well Supv <n1617@conocophillips.com> CC: jimJegg@admin.state.ak.us, Jerry Dethlefs <Jerry.C.Dethlefs@conocophillips.com> Brad, Your notice is acknowledged. Regardless of the outcome of your diagnostic testing, that information should be communicated to us. Since you have indicated that you suspect a leak that results in fluids outside the confines of the wellbore, the well should not be placed back in service without the Commission's express approval. Please keep us informed. Call or message with any questions. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: SG!4~NEL f ( Tom, Yesterday we responded to a report of fluid in the cellar of Kuparuk well 3Q-21. The well is one of the monobore injectors that is currently under Sundry variance 301-174. We suspect there may be a leak in the surface casing which is leaking up the conductor to the surface. We have shut-in the well and are setting a tubing plug today. Our plan is to perform an MITIA ¡liquid leak rate to verify whether there is a leak or not. Depending on the outcome of our testing we will contact you for a plan forward. Brad Gathman ConocoPhillips Alaska Inc. Problem Well Supervisor 907-659-7224 1 of 1 11/23/2004 10:07 AM Re: 3Q-21 lof2 e e Subject: Re: 3Q-21 From: Thomas Maunder <tom _ maunder@admin.state.ak.us> Date: Mon, 09 Aug 200414:04:29 -0800 To: John Crisp <john_crisp@admin.state.ak.us> cc: Jim Regg <jim_regg@admin.state.ak.us> John, You are correct that the pressure should communicate via the sliding sleeve and test both CT packers. Tom John Crisp wrote: Hi Tom, I did have some questions for MJ in Kuparuk about MIT on 3Q-21. I assume the sliding sleeve being open in the tubing is the key for monitoring the CT x Tbg annulus. Is the assumption correct that by pressuring up on surface casing the top CT packer as well as the bottom CT packer will see test pressure? The surface casing has a sign installed on the annulus valve stating pressure must not exceed 2000 psi. Aside from being a poorly designed well, the Combo MIT passed wi bottom packer depth 6340' TVD. Thomas Maunder wrote: Jim and John, 3Q-21 is a monobore, however Phillips obtained a sundry in June 2001 (301-152) to install a CT string in the well stung into a deep set packer. The intention of installing the deep packer and CT string was to provide an annulus to near the perforations that could be monitored and tested. Having such an annulus would make this well nearly the same as other wells, although the OA is part of the monitored and tested space. Phillips' intention was to provide an annulus so that they could employ the well in WAG service. The CT packer was set at 6278' tvd which gives a minimum test pressure of 1570 psi which was satisfied by the test John witnessed. The MIT interval is 2 years, however CPAI was given an option to install a SD valve on the MI supply and seek to extend the test interval to 4 years. It would appear that they have not installed such a valve since they are testing at 2 years. One thing that bothers me with the information presented, is that it appears that the operators know that there is a CT string in the well however they don't know that the deep set packer setting depth is the important depth here. The packer near the base of the surface casing does provide sealing near the shoe, but with the sliding sleeve open that is all it provides. Let me know if you have any further questions. Tom NSK Problem Well Supv wrote: Attached are the 4 Year MIT results for DS 3R and DS 3Q. Also, John Crisp requested that we review the Sundry on 3Q-21 (PTD# 195-193, Sundry # 301-174) to ensure we are meeting UIC requirements, as it is different (has an inner string of coiled tubing) than the other 3 monobores that require tubing tail plugs and MITT's. I will ask Jerry Dethlefs to complete this review and follow up with you (Tom and Jim) after he returns from vacation 08/18/04. Please let me know if you have any questions. 11/23/2004 10:07 AM Re: 3Q-21 e e MJ Loveland ConocoPhillips Problem Well Supervisor 659-7224 «MIT KRU 3R OS-OS-04.xls» «MIT KRU 3Q OS-OS-04.xls» 2 of2 11/23/200410:07 AM Phillips Kuparuk we1l3Q-21 e e Subject: Phillips Kuparuk we1l3Q-21 From: "NSK Problem Well Supv" <n1617@ppco.com> Date: Thu, 18 Jul2002 09:21:59 -0800 To: tom_maunder@admin.state.ak.us CC: bob_fleckenstein@admin.state.ak.us, "NSK Problem Well Supv" <n1617@ppco.com> Tom: I received the signed Sundry for Kuparuk well 3Q-21. As we reported (See attached file: 3Q-21 MITIA 7-17-02.xls), it appears the coiled tubing liner is now leaking during MI injection. The well is back on water injection. An MIT was just performed to see if we could detect leaking from the surface, but it is jug-tight (form attached). Our Engineering staff will be reviewing the status of the well to see if it's worth pulling the liner and redressing the packers for continued WAG injection. I will keep you posted. Jerry Dethlefs Phillips Problem Well Content-Type: applicationlmsexcel MITIA 7-17-02.xls Content-Encoding: base64 1 of 1 11/23/200410:12 AM MECH.ICAL INTEGRITY TEST (MI",=ORM WELL NO.: 13Q-21 I DATE: 17-17-02 WELL TYPE: SWI I i,e,: Prod, Prod AIL, MI, SWI, PWI MIT TEST TYPE: IMITIA I i.e., Tbg, IA /9-5/8", OA /13-3/8", T x IA combo, etc. REQUIRED TEST PRESSURE: 13000 PSi. Note: Please consult the PWS if there's any question @ 7224, pager 909. FLUID TYPE{S) USED TO PRESSURE TEST: IDiesel R d II W IIh d P b f d d . T t ecor a e ea ressures e ore an unna es. START TIME: 108:00 PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE PASS T I PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI)* (PSI)** FAIL S TUBING 2600 2600 2600 2600 T IA / 9-5/8" 1250 3000 3000 3000 PASS OA /13-3/8" 1 COMMENTS: START TIME: PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE PASS T I PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI)* (PSI)** FAIL S TUBING T IA / 9-5/8" OA /13-3/8" 2 COMMENTS: START TIME: I PRE MIT INITIAL MIT 15 MINUTE 30 MINUTE PASS T I PRESSURES PRESSURES PRESSURES PRESSURES OR E (PSI) (PSI) (PSI) (PSI) FAIL S TUBING T IA / 9-5/8" OA /13-3/8" 3 COMMENTS: ¡MiSe COMMENTS, * Start the MIT over if press loss is = 5% @ 15 minutes. ** Repeat the MIT if press loss is = 10% @ 30 minutes. Note: Test must exhibit pressure stabilization - press loss second 15 min < 50% press loss first 15 min FINAL STEPS MUST BE COMPLETED AND CHECKED OFF!!! D -- FLAG THE CASING VALVE WITH LOAD AND TEST INFORMATION D -- FLAG THE WING VALVE IF SI AT TIME OF LOADING AND TESTING. D -- NOTIFY DSO OF TEST RESULTS, VOLUMES PUMPED AND STATUS OF WELL. Witness: I cc: PWS 6/3/00 Re: Phillips Kuparuk we1l3Q-21 e e Subject: Re: Phillips Kuparuk we1l3Q-21 From: "NSK Problem Well Supv" <n1617@ppco.com> Date: Fri, 5 Jul2002 16:49:38 -0800 To: Tom Maunder <tom_maunder@admin.state.ak.us> Tom: I think the economics are favorable for pulling the CT liner and replacing it. We just need to do a couple diagnostics first to justify it. How soon we get to it may be a different matter. Jerry Tom Maunder <tom maunder@admin.state.ak.us> 07/05/2002 04:45 PM To: NSK Problem Well Supv/PPCO@Phillips cc: Subject: Re: Phillips Kuparuk well 3Q-21 Thanks for the notice Jerry. Still dusting things off. Keep us appraised of the diagnostics and plan forward. Bummer that the leak developed. That little solution was working well. One of a number of the good things we have done. Take care. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: Tom: Phillips Kuparuk well 3Q-21 (PTD 1951930) is one of the monobores that we discussed last year. This is the well we ran the coiled tubing liner into for MI injection. It has operated trouble-free since last October, but developed T x IA communication last week while on MI. After several bleeds confirmed direct communication, the well was wagged to PWI on 6/29/02. We suspect the CT liner patch has sprung a leak at one of the patch packers. The well remains on water injection while diagnostics and leak repair work is planned. There does not appear to be a communication problem on water injection. We plan on performing an MIT and/or leak rate on the IA this week. Other than that our options are limited; we may be able to video the tubing or retrieve the coiled tubing in preparation for re-setting. In the interim we will continue to report pressures monthly. By the way, this is one of the lof2 11/23/200410:12 AM Re: Phillips Kuparuk we1l3Q-21 e Sundry's that is still in your shop. e Jerry Dethlefs Phillips Problem Well Supervisor (See attached file: tom_maunder.vcf) 2of2 Content-Type: application/octet-stream Content-Encoding: base64 11/23/2004 10:12 AM Kuparuk 3Q-21 MI injection and Sundry status e e Subject: Kuparuk 3Q-21 MI injection and Sundry status From: "NSKProblem Well Supv" <n1617@ppco.com> Date: Sat, 29 Sep 2001 13:53:19 -0800 To: tom_maunder@admin.state.akus CC: "NSK Problem Well Supv" <n1617@ppco.com> Tom: Today, Saturday September 29, Phillips Kuparuk well 3Q-21 has been put on MI injection. This is the monobore with the CT liner to provide an annulus. The Operators are going to watch closely to see how it behaves. They have instructions to WAG back to water if the IA pressure cannot be controlled within normal operating pressures. The MIT passed @ 2250 psi after the CT liner was installed on 7/6/01, witnessed by Jeff Jones. That brings up another issue; we still do not have the approved Sundry's for the monobores with the operating guidelines we agreed to. Here is a list of outstanding Sundry Notices: lA-09: Water injection with failed MIT (you IF-08: Water injection with failed MIT (you 3K-22: Monobore operating and MIT approval, 3R-25: Monobore operating and MIT approval, 3Q-21: Monobore operating and MIT approval, described above); 30-19: Monobore patch approval and operating and MIT approval, water-only injection. gave us verbal approval gave us verbal approval water-only injection; water-only injection; WAG service (CT liner as only) ; only) ; Still in diagnostic or repair mode by Phillips: 30-19: Has not yet been patched (shut-in); IF-II: Casing repair; cannot be welded, evaluating alternative repair options (shut-in). If you get a chance to get these approvals done I would really appreciate it! I will let you know how 3Q-21 behaves. Thanks! Jerry Dethlefs Phillips Problem Well Supervisor 1 of 1 11/23/2004 10:12 AM 3Q-21 "annulus" e e Subject: 3Q-21 "annulus" From: Tom Maunder <tom_maunder@admin.state.akus> Date: Fri, 08 Jun 2001 16:31:51 -0700 To: NSK Problem Well Supv <N1617@ppco.com> Jerry, I left a message for Mike Mooney and Aris with regard to the burst rating of the 7-5/S" casing and the expected injection pressures with water and MI. I also requested a sketch. I haven't heard from them so I though I would send you a message. Tom 1 of 1 11/23/200410:12 AM MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor ~q ~l 24 (Ov DATE: Wednesday, August 11,2004 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3Q-21 KUPARUK RIV UNIT 3Q-21 FROM: John Crisp Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv .::J&2- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 3Q-21 API Well Number: 50-029-22630..00..00 Inspector Name: John Crisp Insp Num: mitJCrO4081O184457 Permit Number: 195-193-0 Inspection Date: 8/8/2004 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3Q-21 Type Inj. S TVD 6714 IA 500 1700 1650 1640 P.T. 1951930 TypeTest SPT Test psi 1585 OA Interval REQVAR PIF P Tubing 2300 2300 2300 2300 Notes: Page 1 of 1 Wednesday, August 11, 2004 SENT BY :ARCO ALASKA ; ~- 1-98 ; 3:51PM ; KPS/IiF..II.S/CNST/PROJ-, ARCO Alaska, Inc. Kupamk Operafione Post Office Box 196105 Anchorage, Alaska 99519-6105 3Q-21 Monitoring-Report z ~ 0 T CHOKE N A OR DATE ~ T % 907 276 7542;# 2/ 8 SI DATA GAS WATER OAS 7" 10" LIFT INJ INJ H ANB CSG CSG VOL VOL VoL R FTP FTT T~P PSI PSI M$CF B~LS ~SCF S 04/01 B GI 100 4001 64 -21 700S 0 0. 0 1,491 0000 0 04102 ~ OI 100 4002 73 -13 7005 0 0 04/03 ~ G1 100 3999 69 -8 700S 0 0 04/04 B GI 100 3960 66 -11 700S 0 0 04/05 B GI 100 3807 36 -9 700S 0 0 04/06 B GI 100 3794 32 -4 1450S 0 0 0 3,305 0000 0 0 1.389 0000 0 0 0.508 0000 0 0 0.856 0000 O 0 2,690 0000 0 04/07 B GI 100 4010 78 2 1450S 0 0 04/08 B GI 100 4020 81 I 1450S 0 0 04/09 B GI 100 4021 72 -5 1450S 0 0 04/10 ~ G1 100 4039 64 -9 1450S 0 0 04/11 B GI i00 3965 69 -8 1450S 0 0 0 3.380 0000 0 0 3,037 0000 0 0 2,604 0000 0 0 3,276 0000 0 0 1.238 0000 0 04/12 B GI 100 4005 82 -10 1450S 0 0 04/13 B GI ],00 4007 80 -16 1450S 0 0 04/14 B GI 100 4023 84 -13 1450S 0 0 04/15 B GI 100 4010 76 -6 1450S O 0 04/16 B GI 100 3987 77 2 1450S O 0 0 2,518 0000 0 0 2.931 0000 0 0 2,893 0000 0 0 2-451 0000 0 0 2_462 0000 0 04/17 B Gl 100 4007 71 6 1450S 0 0 04/18 B OI 0 4020 77 11 1450S 0 0 04/19 B SI 0 3942 70 8 1450S 0 0 04/20 B SI 0 3843 46 8 1450S 0 0 04/21 B SI 30 3787 40 3 1450S 0 0 0 3.049 0000 0 0 3.222 0000 0 0 1.005 1540 68 0 0.000 2400 68 0 0.000 2400 68 04/23 B GI 48 3899 62 -6 1450S 0 0 04/23 B GI 100 3962 71 -4 1450S 0 0 04/24 B OI 100 3992 76 -7 1450S 0 04/25 B GI 100 401'I 77 -5 1450S 0 0 04/26 B OI 100 4035 79 -6 1450S 0 0 0 1.181 0454 68 0 4,089 0000 0 0 3.966 0000 0 0 3.976 0000 0 0 4.142 0000 0 04/27 B CI 100 4028 77 -4 1450S 0 0 0&/28 B GI 100 4015 71 0 1450S 0 0 04/29 B OI ]00 4019 72 3 1450S 0 0 04/30 B GI 100 3989 76 19 1450S 0 0 0 3.713 0000 0 0 3.536 0000 0 0 3.583 0000 o 0 2.636 0000 0 SHUT-iN CODE 68 = CPF PAC. EQUIP. MAINT, SCANNED DEC 1 9 2002 ,SENT BY:ARCO ALASKA ; 3- 9-99 ; 9:01AM ; KPS/WF. II.S/CNST/PROJ-' ARCO Alaska, Ino. Kuparuk Operations Post Office Box 196105 Anchorage, Alaska 99519-610~ 907 276 7542;# 6/ 7 3Q-21 Monitoring Report ~I DATA Z S GAS WATER GA~ C O T CHOKE 7" 10' LIFT INJ INJ H M 0 N A OR A~ CSG C,~G %rOT, VOI~ VOL R ! D DA'I'r,', ~. T % FTP FTT TEMP PSI PSI bISCF BBLS I~SCF ~n N E 02/01 B SW 100 2771 51 -38 350S 0 02/02 B SW 100 2907 51 .-33 350~ 0 02/03 B SW 100 2813 52 -23 350S 0 03/04 B SW. 100 2818 51 -30 350S 0 0 364:[ 0.000 0000 0 0 4208 0.000 0000 0 0 3425 0.000 0000 0 0 3289 O.O00 0000 0 02/05 B ~ 100 2805 52 -35 350S 0 02/06 B ~ ].00 27],5 51 -36 350S 0 02/07 B SW 100 28~7 51 .,-31 3505 0 02/08 B S~ 100 2821 50 -3R 350S 0 02/09 B Sw 100 2823 51 -45 350s 0 0 2995 0.000 0000 0 0 2454 0.000 0000 0 0 3229 0.000 0000 0 0 2943 O.OOO O00O O 0 2841 0,000 O00O 0 02/10 B $~ 100 2B04 50 -43 350S 0 02/:L1 B ~ 100 ~R~5 a9 -24 350S 0 02/12 B SW 100 2822 54 -10 350S 0 02/13 B ~ 100 2825 54 -1~ 3~0S 0 02/14 ~ SW 100 2823 53 .-15 350S 0 0 2667 0,000 0000 0 0 2694 0,000 0000 0 0 2604 0,000 O000 0 0 2553 0.000 0000 0 0 249:L 0,000 0000 0 02/15 B SW 100 2826 54 -19 350S 0 02/16 B ~ 100 2828 57 -15 350S 0 02/17 B SW 100 2828 55 -17 350S 0 02/18 B SN 100 2827 57 -~ 350$ 0 02/19 B SW 100 2832 57 -3 350S 0 0 2479 0.000 0000 0 0 2431 0.000 0000 0 0 2381 0,000 0000 0 0 2328 0.000 0000 0 0 2350 0.000 0000 0 02/20 B SW 100 2835 56 -7 350S 0 02121 B SW 1U0 2808 56 -10 350S 0 02/22 B SW 100 2833 54 -5 350S 0 02/23 B SW lO0 2837 52 -13 350S 0 02/24 B GI 100 2748 48 -14 350S 0 0 2328 0.000 0000 0 0 2230 0.000 0000 0 0 2271 0.000 0000 0 0 2237 0,000 0000 0 0 374 0,652 0533 71 02/2~ B ~i 100 405]. 42 -6 350S 0 0 02/26 B GI 10¢) 4044 37 -10 350g 0 0 02/27 B OI 100 4048 46 -10 350S 0 0 02/2§ B GI 100 4051 42 ,-16 3505 0 0 0 0.000 0000 0 0 0.000 0000 0 0 0.000 0000 0 0 0.000 0000 0 SI.IUT-~N CODE 71 = WAG WELL SWITCH OVER Al-lOO^laalm, lnc. leaSut)aldlacyofAIlanl, loRichfleldC mpany SCANNED oEc i 2oo STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Other _ Change approved program _ Pull tubing _ Variance _X Pedorate _ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__ RKB 62 feet 3. Address Exploratory_ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 service__x Kuparuk Unit 4. Location of well at surface 8. Well number 2306' FNL, 1942' FEL, Sec. 17, T13N, R9E, UM (asp's 516394, 6025765) 3Q-21 At top of productive interval 9. Permit number / approval number 195-193 At effective depth 10. APl number 50-029-22630 At total depth 11. Field / Pool 4989' FNL, 1549' FEL, Sec. 17, T13N, R9E, UM (asp's 516801, 6023084) Kuparuk Oil Pool 12. Present well condition summar Total depth: measured 7617 feet Plugs (measured) true vertical 6715 feet Effective depth: measured 7508 feet Junk (measured) true vertical 6630 feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 121' 16" 275 sxAS I 121' 121' SUR. CASING 3962' 7-5/8" 730 sx AS III, 260 sx Class G 4024' 3910' LINER 3759' 4-1/2" 280 sx C~ass G 7616' 6714' Perforation depth: measured 7304'-7316', 7322'-7342', 7348'-7388' true vertical 6470'-6479', 6484'-6499', 6504'-6536'RECEIVED Tubing (size, grade, and measured depth4-1/2", 12.6#, L-80 Tbg @ 3897' MD. JUN 2 7 2001 Packers & SSSV (type & measured depth) BAKER 'ZXP' @ 3857' MD. J~as~(a 0il & Gas cons. Commlssl0n CAMCO 'DB-6' NO GO @ 497' MD. Anchorage 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch __ 14. Estimated date for commencing operation 15. Status of well classification as: June 11,2001 16. If proposal was verbally approved Oil__ Gas __ Suspended __ Tom Maunde~ 6/11/01 Name of approver Date approved Service WAG 17. I hereby certily t~at the foregoing is true and correct to the best of my knowledge. Questions? Call Jerry Dethle~s 659-7224 Signed//'/Z~.....~.~.~ ~_~ O,~>~ Title: Problem Well Supervisor Date Jer~d C. Dethlefs Prepared b)z Sharon A//sup-Drake 263-4612 FOR COMMISSION USE ONLY Conditions of approval: PlugN°tify Commission so representative may witneSSintegdty__ BOP Test _ Location clearance __ I Appr°val n°,L/~ 0 Mechanical Integrity Test~J~ _ ~_ Subsequent form required 10-_ .... _A_p_prov_~d__by order of the Commission C~__m._m_.v Clm~i Ta_vt~ Commissioner Date Form 10-403 Rev 06/15/88 · 0 Relum ~o: Problem Well $~pe~visor, IxlSK-~ SU~T IN TRIPLICATE Phillips Alaska, Inc. Kuparuk Well 3Q-21 SUNDRY NOTICE 10-403 VARIANCE REQUEST 06/23/01 The purpose of this Sundry Notice variance request is to clarify Mechanical Integrity Test (MIT) requirements for the 3Q-21 monobore completion. The requirements were determined in a meeting between the AOGCC (Tom Maunder) and Phillips Alaska (Jerry Dethlefs) on June 11, 2001. These terms modify and supersede the conditions sent in a letter to ARCO Alaska, Inc., from the AOGCC (Blair Wondzell) dated May 2, 1997. Kupamk well 3Q-21 is a monobore injection well classified as a "failed MIT" due to the construction of the wellbore (i.e., the packer is not set within 200' of the perforations). Extensive portions of the casing/tubing cannot be monitored from the surface so communication or leak problems may go undetected. To provide for gas injection the AOGCC approved the installation of a coiled-tubing insert into the wellbore (installed 06/18/01). The top of the CT insert is tied-back above an open sliding- sleeve @ 3194' md; the bottom is anchored in a packer and seal bore @ 7140' md (top). The CT insert provides a new annulus to the surface that can be monitored for communication or leak problems. Successful MIT's of the ~completion will allow gas injection to commence into the well. Installation of a high-pressure pilot shut-down on the IA that will close the wellhead Safety System would provide additional protection for the well tubulars; the AOGCC suggested installation of such a system would drop the required frequency of 2-year MIT's to 4-year. This is not required but is an option for Phillips to consider. The well passed an AOGCC witnessed MITT / MITIA 04/10/01 against a wireline-set plug in the landing nipple @ 7164' md (prior to the CT insert installation). An MITIA of the new completion passed 06/18/01 @ 2000 psi. A post water injection MITIA has not yet been performed ACTION PLAN From this date forward 3Q-21 will be subject to the following requirements: 1. Perform an AOGCC witnessed MIT-IA after water injection commences to the new packer @ 7140' md (6278' tvd); 2. A passing MIT-IA and AOGCC approval will allow the well to be used for either water or gas injection; 3. Perform an MIT-IA every 2-years (4-year test with IA high-pressure shut-down) subject to standard test criteria ( 0.25 x tvd @ packer or 1500 psi minimum, whichever is higher); Submit monthly reports of daily tubing & IA pressures and injection volumes; Shut-in the well and notify the AOGCC should M1T's or injection rates and pressures indicate communication problems. . SCANNED JUL :8 1 2002 NSK Problem Well Supervisor 06/23/01 PHILLIPS Alaska, Inc. '~ - ..... ~i ~ Subsidiary of PHILLIPS PETROLEUM COMPANY NiP (497-498, -- OD:4.500) TUBING -- (0-3897, OD:4.500, ID:3.833) SLEEVE -- (3821-3822, OD:4.500) PKR -- (3857-3858, OD:6.151) HGR -- (3870-3871, OD:6.560) (3876-3877, OD:6.250) TTL-- (3897-3898, OD:4.500) TOC (6190-6191, OD:4.500) NIP (7164-7165, OD:4.500) Perf (7304-7316) Perf (7322-7342) Perf (7348-7388) Kkd 3Q-21 APl: 500292263000 WelIType: INJ SSSV Type: I Camco 'DB-6' Orig Compltn: 11/5/96 Annular Fluid: Last W/O: Reference Log: I Ref Log Date: Last Tag: 17508 TD: 17617 ftKB Last Tag Date: 17/25/00 Max Hole Angle: 41 deg (~ 6527 ~ih~ Sti~i~' ~ CONDUCTOR ~ ~ Angle @ TS: 138 deg @ 7279 Angle ~ TD: 13_9_d__e_g ~_~7617___ Rev Reason: I_'I'A_G_.B__Y VH Description Size I Top Bottom TVD Wt GradeI SUR. CASING 7.625 ] 0 4024 3910 29.70 L-e0 !CasingiiStdng:.:~ E!NER: , DescriptionI Size Top Bottom TVD I Wt I Grade I LINER I 4.500 3857 7616 6714 J 12.60 .__~_ L-80___[ :T~bi~f::string ::~ ~TU BiNG 4.500 0 3897 3809 12.60 L-80 J .Pe~arati~;Summ~: : Interval TVD 7304-7316 6470-6479 7322-7342 6484-6499 6504-6536 7348-7388 "Depth TVD" T~Pe ........... Description 4971 497] NIP Camco 'DB-6' NO GO 3821 3747 SLEEVE Baker Sliding Sleeve w/CMU Otis 'X' Selective Profile 3857 3777 PKR Baker 'ZXP' 3870 3787 HGR Baker'HMC' Liner 3876 3792 PBR Baker 38971 38091 TTL w/muleshoe 6190 56021 TOC SOS CBL 1/28/96 7164 6359 N P Camco DB-6. Thread Thread Thread Thread NSCT Zone ~Status~Feet SPF Date ] Type Comment A-3 ! ~ 12 4 2/13/96 IPERF 180 deg. phasing; Oriented 170 deg, ! r I I I CCW & 10 deg., 3 3/8" ~Cs~_ A-2 ! ~ 20 4 2/11/96 IPERF ~8~-i~ha~ir{.~i~:3~i~ted170~t~. J ~ J I J I J CCW f/High Side, 3 3/8" HC Csg / ! Gun A-1 ~ ~ 40 4 2/11/96 IPERF 180 deg. phasing; Oriented 170 deg. ~ ! CCW F/High Side, 3 3/8" HC Csg / / Gun 3.813 3.812 5.750 4.892 4.750 3.833 3.833 3.75O SCANNED JUL 3 ! 2002 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 25, 2001 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 RECEIVED JUN 27 2001 Alaska 011 & Gas Cons. Commission Anchorage Dear Mr. Maunder: Enclosed please find 10-403 Sundry Notices for Phillips Alaska, Inc., wells 1F-11, 3K-22, 3R-25, 3Q-21 and 30-19. The Sundry's regard the discussion we had on June 11, 2001, about the monobore injectors and the surface-casing leak on 1F-11. Please call Pete Nezaticky or me at 907-659-7224 if you have any questions. Sincerely, l~~~Dethlefs~ ~ Phillips Problem Well Supervisor Attachments SCANNED JUL 3 I 2002 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 June 6, 2001 Ms. Camille Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501 Subject: 3Q-21 Application for Sundry Approval Dear Ms. Commissioner: Phillips Alaska, Inc. submits the attached sundry for workover operations for the KRU 3Q-21 well. The plan is to run a 2 3/8" coiled-tubing liner packed-off above the open sliding sleeve and run to within 200' of the perforations, and packed-off there as well, effectively extending the monitorable annulus to within 200' of the perforations. This will allow for injecting MI into the well. If you have any questions regarding this matter, please contact me at 263-4574 or Aras Worthington at 265-6802. Sincerely, M. Mooney Staff Engineer PAl Drilling / Wells MM/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _X Repair well _X Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other_ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 2306' FNL, 1942' FEL, Sec. 17, T13N, R9E, UM At top of productive interval At effective depth At total depth 4989' FNL, 1549' FEL, Sec. 17, T13N, RgE, UM 5. Type of Well: Development __ Exploratory _ Stratigraphic __ Service__X (asp's 516394, 6025765) (asp's 516801, 6023084) 6. Datum elevation (DF or KB feet) RKB 41', Pad 21' feet 7. Unit or Property name Kuparuk Unit 8. Well number 3Q-21 9. Permit number / approval number 195-193 10. APl number 50-029-22630 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 7617 feet Plugs (measured) true vertical 6715 feet Effective depth: measured 7508 feet Junk (measured) true vertical 6630 feet Casing Length Size Cemented CONDUCTOR 121' 16" 275 sx AS I SUR. CASING 3962' 7-5/8" 730 sx AS III, 260 sx Class G LINER 3759' 4-1/2" 280 sx C~ass G Measured Depth 121' 4024' 7616' 6714' True vertical Depth 121' 3910' Perforation depth: measured 7304'-7316', 7322'-7342', 7348'-7388' " ' ~ - ' ~ ;: ' true vertical 6470'-6479', 6484'-6499', 6504'-6536' ; '!~:'! Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) 4-1/2", 12.6#, L-80 Tbg @ 3897' MD. BAKER 'ZXP' @ 3857' MD. CAMCO 'DB-6' NO GO @ 497' MD. 13. Attachments Description summary of proposal__ Detailed operations program __ BOP sketch _ 15. Status of well classification as: 14. Estimated date for commencing operation June 14, 2001 16. If proposal was verbally approved Name of approver Date approved 17.1 hereby certify that the foregoin.~.~s trj~and correct to the best of my knowledge. Michael Mooney Oil ~ Gas __ Suspended __ Service WAG Title: Staff Engineer FOR COMMISSION USE ONLY Questions? Call Aras Worthington 265-6802 Date Prepared by Sharon AIIsu~.Drake 263-4612 Conditions of approval:PlugN°tify Commission so representative may witneSSintegdty __ BOP Test'~ Location' ~ ~.~_.~ ~_¢ ~,, ~",t~ ~.~.-%.~.clearance __ Approval no~/ .... ,~ -~ Mechanical Integr~ Test ~ ~ Subsequent fo~ requir~ 10- ~~ Approved by order of the Commission D Taylor Seamount Commissioner Date Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE 3Q-21 CT Liner Procedure Charge Code: 999672; 230DS3QL Background 3Q-21 is a 4 W' monobore water injector that is a candidate for MI injection. A TTP was set @ 7164' 4/10/01 and the tbg/liner was MIT'ed to 2000 psi. The packer is set @ 3857', whereas MI injection requires a packer within 200' of the perforations. 1) 2) 3) 4) 5) This procedure is to run a 2 3/8 CT liner from above the sliding sleeve @ 3821' to within 200' of the perforations to essentially extend the monitorable annulus to within 200' of the perfs. 6) ! RU Slickline C7' ~/~ ~ ~ ?°-~ ,,~ 1. Open the sliding sleeve @ 3821' 2. Drift the tbg down to the 3.75 Camco nipple with a 3.75" x 15' drift to simulate the longest section of packer/sealbore to be run. RD Slickline. Kill well with corrosion inhibited brine: 1. Circulate 67 bbls diesel down the IA taking returns from the tbg. This will fill the IA dn to the sliding sleeve with diesel. 2. Shut-in the IA and bullhead 113 bbls of KW brine dn the tbg. 3. Pump 29 additional bbls of KW brine dn the tbg while taking returns from the IA. This will bring the diesel freeze protection in the IA up to 2200'. Note: a) Est. reservoir pressure is 3600 psi. Verify reservoir pressure from SlTP to calculate brine weight. b)The kill weight brine will remain in the annulus after the job and as such will need to be corrosion inhibited. RU E-Line and set 3.735" Eclipse Series III Model PB Packer with shearable Aluminum plug (1500 psi shear-out) in the middle of the first full joint of liner immediately above the Camco 3.75 nipple (approx. 7150' MD). Note: Contact Joe Simpson @ 333-7203 or cell #244-4151 for field-service with the Eclipse packers. RU work platform (w/BOPs: 2 3/8 slips/pipes, blind cutters, & annular preventer) & CTU with at least 7500' of 2 3/8" CT. MU bottomhole assembly CT to include: 1. 3.735" Anchor Seal Assy pinned to 10,000#s shear. 2. Seal assembly pinned to 2000#s shear-out with 6' of travel up and 4' of travel down. 3. Weatherford 1.73 no-go nipple with plug (check-valve type) in place 4. Weatherford Coiled tubing connector Run 3450' of CT taking displacement returns. Monitor returns closely to ensure that well is not flowing. Set slip-rams on CT. Slack-off on the CT to 0 surface weight to ensure that slips are holding. Double-check well status (killed!). Hot-tap the coiled tubing, Ensure there is no pressure inside of the CT. 7) Cut the Coil with the hydraulic shears. 8) Make a final cut on the CT with pipe cutters & install CT connector on the reel end of the CT. Pull-test & pressure-test the connector. 9) Install the following from top-down starting with the coil tubing connector: 1. Shear-out circ sub 2. hydraulic disconnect 3. Hydraulic Setting Tool, Model EH-CR 4. 3.74" Eclipse Series III Model PB Packer 5. Bottom Coil Tubing Connector Note: The upper CT connector will be installed on the CT from the reel, pull-tested & PT'ed. The upper CT connector will then be made-up w/the lower BHA including the lower CT connector and the lower connector installed on the CT stub from the well. Enough lubricator will need to be picked up prior to making the final connector to CT connection to cover the exposed BHA up to the upper CT connector to allow the CT injector to back-strip without the chains contacting the BHA. 10) PT the lubricator and RIH doing weight checks every 1000'. 11) About 100' above the packer, do a final PU weight. 12) Pressure up on the backside (CT x tbg annulus) and shear-out the plug in the bottom of the Eclipse packer. 13) RIH slowly and look for set dn weight from landing Anchor-Seal into the eclipse packer. Note: Do not set down more the 2000#s as the slip-stick/seal assy will shear @ 2000 #s. 14) PU to PU weight slowly. Continue PU to verify Anchor-seal is set in the Eclipse packer. Note weight & CT depth at which slip-stick shears (pinned to 2000#s). 15) Set down to close slip-stick. PU to PU weight +2' & drop ball (1/2") to set eclipse packer. 16) Continue pumping to shear-off of Eclipse packer. 17) Circulate out the KW brine above the upper Eclipse packer & replace with diesel. POOH & RD CTU & Work platform. 18) RU slickline & pull the plug from the tbg. Backflow the well to tanks for a full wellbore volume to flow out the KW brine. 19) Put the well back on injection. Comments/Questions on this procedure please call Aras Worthington @ 265-6802/Cell # 240- 5780. PHILLIPS Alaska, Inc. . A Subsidiary of PHILLIPS PETROLEUM COMPANY NIP (497-498, -- OD:4.500) (0-3897, OD:4.500, ID:3.833) (3821-3822, OD:4.500) PKR-- (3857-3858, OD:6.151) HGR -- (3870-3871, OD:6.560) PBR (3876-3877, OD:6.250) (3897-3898, 0D:4.500) TOC (6190-6191, OD:4.500) NIP (7164-7165, 0D:4.500) Per[ (7304-7316) Per[ (7322-7342) Perf (7346-7388) KRU 3Q-21 APl:J500292263000 SSSV Type: Annular Fluid: Reference Loq: Last Tag: Camco 'DB-6' 75O8 . Last Tag Date: 7/25/00 C~ing::stHng: ~ CONDUCTOR DescriptionI SizeI CONDUCTOR 16.000 C:~sin~ :stdng::~: SURFACE Description Size SUR. CASING 7.625 6esing!Strin~ Description LINER :;:LINER: ::: Size 4.500 TUbing:~ng:~ TUBING: Size I Top 4.500 I 0 perforations summary : Interval 730~4 - 7316 7322- 7342 7348-7388 TVD 6470 - 6479 6484 - 6499 6504 - 6536 Well Type: Orig Compltn: Last W/O: Ref Log Date: TD: INJ Angle @ TS: 138 deg @ 7279 1/5/96 I Angle L~ TD: 139 deg_@ 7617 Rev Reason: ITAG _B_Y VH 7617 ftKB Last Update: 8/15/00 41 deg (~ 6527 Max Hole Angle: T°P I B°tt°m [ TVD0 121 Top [ BottomI 0 4024 Top Bottom 3857 7616 Bottom TVD 3897 3809 NSCT Zone ~Status~FeetSPF Date Type l Comment A-3 ! ! 12 4 2/13/96 IPERF 180 deg. phasing; Oriented 170 deg. ! J CCW & 10 d~., 3 3/8" Csg Gun A-2 / / 20 4 2111/96 IPERF 180d(~g. phasi~g]~ri~d]70deg. I / / I I I /CCW f/High Side, 3 3/8" NC Csg Gun A-1 ~ [ 40 4 2/11/96 IPERF1180deg. phasing;Oriented170deg. ~ [ /CCW F/High Side, 3 3/8" HC Csg | I /Gun [ Wt [ GradeI Thread 121 TVD Wt Grade Thread 3910 29.70 L~80 TVD I Wt GradeI Thread 6714 L 1~2._6_0__l _L-80 Wt Grade Thread __ !2.60 _]__._L:8_0 _ J. :Other (plugS;: equip., etc,) - JEWELRY Depth I'rVDI Type I Description 497 ! 497 / NIP I Camco 'DB-6' NO GO 3821 ~3747 SLEEVE Baker Sliding Sleeve w/CMU Otis'X' Selective Profile 3857 ~3777 / PKR I Baker 'ZXP' 3870 J37871 HGR I Baker 'HMC' Liner 387613792 [ PBR ! Baker 3897 ~38091 TTL Iw/muleshoe 6190 J5602 / TOC I SOS CBL 1/28/96 716416359 [ NIP I Camco 'DB-6'. ID 3.813 3.812 5.750 4.892 4.750 3.833 3.833 3.750 OPERATOR: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test E-Mail to; Tom_Maunder@admin,state.ak.us and Bob_Fleckenstein@admin.state,ak.us Phillips Alaska, Inc. FIELD / UNIT / PAD: Kuparuk / GKA/3Q DATE: 4/10/01 PTD: 1951930 Well #: 3Q-21 COMMENTS: PTD: 1951930 Well #: 3Q-21 COMMENTS: PTD: Well #: COMMENTS: PTD: Well #: COMMENTS: PTD: Well #: COMMENTS: DSL 3, 777 7 5/8"/29.7#/L-80 3,857 MITIA to existing packer (monobore completion) 944 1,450 1,450 1,450 1,450 1500 0 2, 000 1,825 1,825 I N I P I DSL [ 3'777 I 4'5"/12'6#/L-80 I 4'5"13,857 3000944 I 1,4000 3'075 I 2'925 I 2'9000 0 0 I 9:30 lEI [I-I 2 Year MIT monobore injector - MIT tubing with plug set in the nipple at 7164' MD (6359' TVD). Continued test for 45 rain, final tubing pressure 2900 psL TBG. INJ. FLUID CODES F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Distribution: orig - Well File c - Operator c- Database c- Trip Rpt File c- Inspector TEST TYPE: M = ANNULUS MONITORING P = STD ANNULUS PRESSURE TEST R = INTERNAL RAD. TRACER SURVEY A = TEMPERATURE ANOMALY TEST D = DIFFERENTIAL TEMPERATURE TEST ANNULAR FLUID: DIESEL GLYCOL SALT WATER DRILLING MUD OTHER P.P.G. Grad. 0.00 WELL TEST: Initial 0.00 4- Year 0.00 Workover 0.00 Other X 0.00 OPERATOR REP SIGNATURE: Peter Nezaticky , AOGCC REP SIGNATURE: John Spauldin~l MIT KRU 3Q-21 04-10-01 .xls (Rev 9/23/99) PHILLIPS Alaska, Inc. -KUPARUK RIVER UNIT SERVICE REPORT 3Q-21(4-1)) WELL JOB SCOPE JOB NUMBER 3Q-21 STATE TESTING(240) 0130010552.4 DATE DAILY WORK UNIT NUMBER 04/04/01 SBHP, P/T TBG 70101 DAY SUPERVISOR I FITZPATRICK Signed FIELD ESTIMATE OPERATION COMPLETE SUCCESSFUL KEY PERSON O Yes ~ No ~ Yes O No HES-OBER AFC# CC# I DAILY COST ACCUM COST K85329 230DS36QL I $2,645 $2,645 I I°A IFinal OA ITTL Size Initial Tbg ]Final Tbg ]Initial IA Final IA Initial 2500PSlI 2500PSlI 0 PSI 0 PSI 0 PSI 0 PSl l 3.833 " IMin ID I Depth 3.750" 7164 FT DAILY SUMMARY TAGGED @ 7503' RKB' EST'115' RATHOLE' MEASURED BHP @ 7346, RKB: 3765 PSI' DRIFTED TBG TO 3.33'' TO 7400' RKB. JOB SUSPENDED, INCOMPLETE. [Pressure Data, Tag, PT Tbg-Csg] TIME LOG ENTRY 13:30 MIFFGSM- SLIPS, TRIPS & FALLS. COMMUNICATION. MUSTER AREA. BACK SAFETY, TOP FRONT HATCH DOOR STUCK, USE CRANE TO OPEN. 13:40 RU- HES. 1.875" TS: RS,QC,5',KJ,5',QC,KJ,LSS,QC. P/T EQUIP 1400 PSI LIFT GAS. 15:10 RIH W/2.76" TAG TOOL; TAG @ 7480' SLM (7503' RKB= 23' CF 02/01/00)- POOH. NOTE: SAT DOWN & FELL THRU @ 2900', 3580', 3800', 4020' & 6300' SLM, NO PROBLEM POOH, ASPHAULTINES ON SWG. 15:30 TOP PANEX #1037 & BTM PANEX #1039 STARTED. 16:39 15 MIN IN LUB, RIH W/DUAL PANEX ASS'Y (13' TL); 17:37 30 MIN @ 7346' RKB (7323' SLM) PUH; 18:07 30 MIN @ 7304' RKB (7281' SLM) PUH; 18:23 15 MIN @ 7100' RKB (7077' SLM) POOH; 18:58 15 MIN IN LUB W/DUAL PANEX ASS'Y; 19:30 RIH W/3.3" CENT- 2' STEM- 3.802" GAUGE RING; SAT DOWN @ 460' SLM (497' RKB= DB-6 NIP) TAP THRU EASY, WORK THRU TIGHT SPOTS 2870' TO 2876', 3054' TO 3094', 3583' TO 3587', SAT DOWN @ 3795' SLM (3821' RKB=SSD) WORK THRU SSD EASY TO 3800' SLM, SAT DOWN @ 3803' SLM, WORK TO 3816' SLM, UNABLE TO PASS, SUSPECT BALLING UP SCHMOO- POOH. 20:35 RIH W/2.75" CENT- 5' STEM- 3.33" GAUGE RING; WORK TOOLS 3810' TO 3824' & FELL THRU, RIH TO 7400' SLM- POOH, HEAVY PULL THRU PERF AREA, DRY HARD SCHMOO ON GAUGE RING. 22:30 LDFN- TURN WELL OVER TO DSO. 22:31 TANDEM PANEX GAUGES, TOP / BOTTOM: LUB: 2491 / 2482 PSI. 7346' RKB: 3765 / 3755 PSi. 7304' RKB: 3755/3744 PSI. 7100' RKB: 3731/3721 PSI. LUB: 2497 / 2484 PSI. Fluid Summary NO FLUIDS PUMPED. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $o.oo $o.oo APC $0.00 $0.00 HALLI BURTON $2,645.00 $2,645.00 LITTLE RED $0.00 / $0.00 TOTAL FIELD ESTIMATE $2,645.00 $2,645~'00~ PHILLIPS Alaska, Inc. .... KUPARUK RIVER UNIT ELL SERVICE REPORT 3Q-21(4-1)) WELL JOB SCOPE JOB NUMBER 3Q-21 STATE TESTING(240) 0130010552.4 DATE 04/07/01 DAY 1 FIELD ESTIMATE DALLY WORK GAUGE TBG, PT TBG OPERATION COMPLETE ISUCCESSFUL O Yes ~ No I ~ Yes O No AFC# ICC# I DAILY COST K85329 230DS36QL $8,655 Initial Tb9 I Final Tbg I Initial IA I 2500PSI] 1450PSII0 PSI I IKEY PERSON HES-OBER ACCUM COST $11,300 Final IA Initial OA IFinal OA ITTL Size I 0 PSI 0 PSI 0 PSII 3.833 " UNIT NUMBER 7O101 SUPERVISOR FITZPATRICK Signed IMin ID I Depth 3.750" 7164 FT DAILY SUMMARY ENCOUNTERED HEAVY ASPHALTENES; CLEANED UP W/HOT DIESEL. SET 3.750" DBPX PLUG (NO KEYS) @ 7161' RKB. IN PROGRESS. [PT Tbg-Csg] TIME LOG ENTRY 07:00 WEEKLY HES SAFTY MEETING @ KCC W/PHILLIPS REP. RDMO FROM 3H-03 TO 3Q-21. 10:00 MIFFGSM- SLIPS, TRIPS & FALLS. COMMUNICATION. MUSTER AREA. 10:20 RU- HES & LRS. 4.5" EQUIP. 1.875" TS: RS,QC,5',KJ,5',QC,KJ,LSS,QC. PfT LINES & EQUIP 3000 PSI. 11:20 RIH W/KJ-3.84" BLB- 3.33" GAUGE RING; BRUSH SSD 3795' TO 3800' SLM, WORKED AREA 3800' SLM TO 3900' SLM WHILE LRS PUMP MINIMUM RATE, RIH TAG DB NIPPLE @ 7148' SLM (7161' RKB) BRUSH NIPPLE GOOD- POOH. 12:20 RIH W/3.33" CENT- 2' STEM- 3.802" GAUGE RING; WORKED THRU SSD EASY @ 3795' SLM, TAG DB NIPPLE @ 7149' SLM (7161' RKB) POOH. 13:35 RIH W/3.75" DB LOCK- XO- PX SUB (28" TL) ON K J- 4.5" Z6 RNG TOOL; ATTEMPT TO SET @ 7149' SLM (7161' RKB) VERY POOR TOOL ACTION- POOH VERY HEAVY (1000#) W/DBPX PLUG, VERY TIGHT THRU SSD & UPPER DB NIPPLE, SPANGS & PLUG PACKED W/ASPHAULTINES (SCHMOO). SWOP TO 2.125" TS: RS,QC,5',KJ,5',QC,KJ,SSS,QC. CONFER W/CWG SUPV. 16:15 LRS PUMP 50 BBLS HOT DIESEL THEN RD TO RELOAD. 18:15 MIRU LRS. P/l' LINES & EQUIP 3000 PSI, DSPL TBG 60 BBLS HOT DIESEL, FINAL TBG PRESSURE 1450 PSI. 19:35 RIH W/3.750" DB LOCK (NO KEYS)- XO- PX SUB (28" TL) ON KJ- 4.5" PRS; SET @ 7143' SLM97161' RKB)- POOH. 20:50 RIH W/PX PRONG (89" TL, 1.375" FISHNECK) ON KJ- 2.75" CENT- 2.0" JDC; SET @ 7138' SLM (TBG PRESSURE 1450 PSI)- POOH. PRESSURE TBG TO 2500 PSI, HOLDING, LEAVE PRESURE ON TBG. 22:30 LDFN- TURN WELL OVER TO DSO. Fluid Summary I 120 BBLS DIESEL PUMPED. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $500.00 $500.00 APC $0.00 $0.00 HALLIBURTON $4,280.00 $6,925.00 LITTLE RED $3,875.00 $3,875.00 TOTAL FIELD ESTIMATE $8,655.00 $11,300.00 PHILLIPS Alaska, Inc. -~-KUPARUK RIVER UNIT ~. ~=LL SERVICE REPORT 3Q-21(4-1)) WELL JOB SCOPE JOB NUMBER 3Q-21 STATE TESTING (240) 0130010552.4 DATE DAILY WORK UNIT NUMBER 04/10/01 MITT & MITIA - STATE 2 YEAR TEST DAY 2 FIELD ESTIMATE OPERATION COMPLETE SUCCESSFUL I KEY PERSON ~ Yes O No ~ Yes O No I K85329 230DS36QL $700 $12,000 I I°A IFina'OA ITTL size Initial Tbg I Final Tbg I Initial IA Final IA Initial 1400PSII 0PSII 0PSI 0PSI 0PSI 0PSI 0.000 " SUPERVISOR NEZATICKY Signed IMin ID I Depth 0.000" 0 FT DALLY SUMMARY MITT TO 3000 PSI WITH TTP SET AT 7164'. MITIA TO 2000 PSI. BOTH TESTED PASSED, STATE WITNESSED. [MIT] TIME LOG ENTRY SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $o.oo $500.00 APC $700.00 $700.00 HALLI BURTON $0.00 $6,925.00 LITTLE RED $0.00 $3,875.00 TOTAL FIELD ESTIMATE $700.00 $12,000.00 PHILLIPS Alaska, Inc. .iKUPARUK RIVER UNIT SERVICE REPORT 3Q-21(4-1)) WELL JOB SCOPE JOB NUMBER 3Q-21 STATE TESTING(240) 0130010552.4 DATE 04/11/01 DAY 3 FIELD ESTIMATE DALLY WORK PULL PLUG OPERATION COMPLETE ISUCCESSFUL (¢~ Yes O No ] ~'~ Yes O No AFC# ICC# I DAILY COST K85329 230DS36QL $5,230 InitialTbg IFinalTbg IlnitiallA IFinallAI 1450 PSII 1450 PSII 90 PSI 90 PSI IKEY PERSON HES-FREEBORN ACCUM COST $17,230 Initial OA IFinal OA ITTL Size 0 PSll 0 PSII 3.830 " UNIT NUMBER 7O356 SUPERVISOR JOHNS Signed IMin ID I Depth 3.750" 7164 FT DALLY SUMMARY PULLED 3.75" DB LOCK WITH PX SUB FROM DB-6 NIPPLE @ 7164'RKB, JOB COMPLETE. [Open-Close A Sand] TIME LOG ENTRY 14:30 PICK-UP WELL FILE FROM CWG OFFICE, GATHER 4.5" EQUIPMENT FROM HES SHOP. 15:00 ARRIVE ON LOCATION AT 3Q PAD, TGSM- ABNORMAL RIG-UP, MIRU HES & LRS, PT LUB. 2500#, TS- 1.875" STANDARD TOOLSTRING 16:15 RIH W/3'X 1.5" STEM 2.80" CENT. 2" RB TO 7146'WLM LATCHED & PULLED PX PRONG PRESSURE DROPPED FROM 2000# TO 1450#, POOH W PRONG 18:30 RIH W/4.5" PRS TO 7150'WLM LATCHED & PULLED PLUG BODY FROM DB-6 NIPPLE @ 7164'RKB, POOH W/PLUG VERY SLOW GOING SUSPECT ROLLED PACKING 50 TO 100 FPM OOH 21:00 ARRIVE AT SURFACE WITH PLUG 21:30 RDMO, SECURE WELL, NOTIFIED DSO OF WELL STATUS. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $40.00 $540.00 APC $0.00 $700.00 HALLIBURTON $2,690.00 $9,615.00 LITTLE RED $2,500.00 $6,375.00 TOTAL FIELD ESTIMATE $5,230.00 $17,230.00 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser /? ~.~;~\~ DATE: April 10, 2001 Commissioner ~4~o~ , ' BJECT: Mechanical Integrity Tests THRU: TOmp.l. SupervisorMaunder"~'%~' [,,'5" t-~\ 3QPhillips Alaska Inc. 21 FROM: John H. Spaulding Kuparuk River Unit Petroleum Inspector Kuparuk NON- CONFIDE ,.NT,_ IAL, Packer Depth Pretest Initial 15 Min. 30 Min. W~I! 3Q-21" I Type"inj.1 SW~' 1 'i'.V.D'.'i 3777 l'Tb~g'j" ~46b i "3d75' i 2925 'P.T.D.'I 't95-1930 IType,t,~,tI' M. ]Te~t.p~ii ',944 ]..casing. j-positive, j p°sitiveJ'P0'S!tiVeJpositivej' p/F' [ _.p' Notes: MIT tubing with with plug set in the nipple ~ 7164' MD (6359'TVD) · We, I .... ~Q-21 i Type inj. I ' ~WII T.v.D. i 37'~7 I 'l:~bing I '1'45'0 I' 1500 I ~'SO0 I" ~5oo' I~terval[ '0" PiT,D.[ .~5_~930 ITypetestl. '.M.; 'l'Test ~! '9~ .J.Casi"nglp°Sitivel ..'20oo i ~2'5 I ~s25 '1 'P/F'"[ Notes: MITIA to exlSitn~l packer - weft) ! Typ& tnj. 1 ...... I :r.V.D. I ...... I'm~in~"J ' ' ' I"~ [' ' ' i " l~nterv~"~i' ' P.T.D;i. ITYpe'testl .~.'. "]'TestPsil ' [Casing'il. '.' I. 'I' . I'" Notes: ~ Weiil .... I¥~'~e"nJ'! ..... !T"V-D-i "' iT;jbing! ..... ! ' ' '1 ' I ......i"intervail: P:]"D-I.. ' ITy. Pete~;~I.'i. i l~rest'psil .'..'...1.'C.~"n.g'/' .... I..: '!. ".' i' ~ IF~/F ,i, Notes: w~il', ....... I'¥ypeinj.'l .... !'T.~/-D: 1 ..... I'T~Jbing !' ' ' i ' '1 "' i .... ll'~t;~Nail" ' P.T.D.I.. '. 'lTyP~'.testl' .' '_, 'J~'est PS[! .... 1' c%ing I .'-'..'.'....I ' I _' i i i . :.. ! P/F' I...".' Notes: Type INJ..Fluid Co~ ' 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 Intel ..... I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details This well is a monobore completion. The MIT of the tubing appeared to bleeding down quite a bit, pressure tested the robing for an additional 15 min. with no further bleed down. Final pressure of 2900 psi. The monobore wells currently are on a 2 year monitoring schedule. M.I.T.'s performed: 1 Affachments: n...~a Number of Failures: g Total Time during tests: ! .114 bm. Cc: MIT report form 5/12100 L.G. 010410-MIT KRU 3Q-21-js 4/13/01 W MEMORANDUM TO: Julie Huesser, Commissioner State of Alaska Alaska Oil and Gas Conservation Commission / "";~'~ DATE: December 1,2000 THRU:' Tom Maunder, P. I. SUpervisor FROM: SUBJECT: Chuck Scheve; 'Petroleum Inspector Safety Valve Tests Kuparuk River Unit 3Q Pad Friday, December 1, 2000: I traveled to 3Q Pad in the Kuparuk River Field and witnessed the safety valve system testing, on 4 miscellaneous WAG injectors. As the attached AOGCC Safety Valve SYstem Test Report indicates I witnessed the testing of 4 wells and 8 components with one failure observed. The pilot on well 3Q- 21, which had just been brought line and was not fully up to operating temp, tripped well below the required triP pressure. This pilot was retested upon completion of today's testing and operated properly. . Earnie Barndt conducted the testing today he demonstrated good test procedure and waS a pleasure to work with Summary: I witnessed the sVS testing of Kuparuk River Field. 4 WAG injectors at 3Q Pad in the KRU'3Q Pad, 4 Wells, 8 Components, 1 failure Attachment: SVS KRu 3Q Pad 12-1-00 CS X Unclassified Confidential (Unclassified if doc. Removed) SVS KRU.3Q Pad 12-1-00 CS.doc Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test Report OPerator: Phillips Operator Rep: Emie Bamdt AOGCC Rep: Chuck Scheve . Submitted By: Chuck Scheve Date: Field/Unit/Pad: Kupamlk/KRU / 3Q Pad Separator psi: LPS HPS 12/1/00 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 3Q-01 1911250 3Q-02 1870040 3700 2000 1750 P P WAG 3Q-03 1911260 3Q-04 1911240 3Q-06 1861950i 3Q-07 1861940 3Q-08A 1971930 3Q-09 1861860 3Q-lO 1861870 3Q-11 1861880 3Q-12 1861890 3700 2000 1900 P P WAG 3Q-14 1861770 3Q-22 1951860 3Q-16 1861790 3700 2000 2000: P P WAG 3Q-21 1951930 3700 2000 1200 3 P 12/1/00 WAG Wells: 4 Components: 8 Failures: 1 Failure Rate: [] 9o Day Remarks: Misc tests on Wag wells 12/4/00 Page 1 of 1 SVS KRU 3Q Pad 12-1-00 CS.xls PERMIT AOGCC Individual Well Geological Materials Inventory DATA T DATA PLUS Page: 1 Date: 02/25/98 RUN RECVD 95-193 CBL ~IfSEPIA )?ob- 7~'07 '1 02/27/96 95-193 ARC 5 - MD ~'~SEPIA )~ ~) - 2./~-7~ 1 04/10/96 95-193 ARC 5 - TVD 1 04/10/96 95-193 7204 04/10/96 10 -407 ~-R'" COMPLETION DATE ~//.~/.g~ / DAILY WELL OPS ~R' /~/3 ! /~3-'/ TO A/I) /q~ / Are dry ditch samples required? yes ~__.And received? Was the well cored? yes ~ Analysis & description received? Are well tests required? yes ~ Received? Well is in compliance /~ Initial COMMENTS ACO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 20, 1996 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 3Q-21 (Permit No. 95-193) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 3Q-21. If there are any questions, please call 263-4622. Sincerely, W. Isaacson Drilling Engineer Kuparuk Drill Site Development WSI/skad RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COb,,,.,!SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL F-~ GAS E~ SUSPENDED ~ ABANDONED [] SERVICE r~ Classification changed to water injector · 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 95-193 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 .... -~-~--~'-~--~.:' 50-029-22630 4 Location of well at surface ~&' '~'¢-~ ;;-~ ~. 9 Unit or Lease Name 2308'FNL, 1941'FEL, Sec. 17, T13N, R9E, UM ,, ............. ..._ . ,.~ ~~~ ,~ .~~ Kuparuk River Unit AtTop Producing Inte~al ~ ~,~,~;~ ~ 10 Well Numar 291' FSL, 1549 'FEL, Sec. 17, T13N, R9E, UM KUPARUK RIVER 5 Elevation in feet (indi~te KB, DF, etc.) 6 Lease Designation and Serial No. RKB 41', Pad 21' ADL25512 ALK2553 12 Date Spudded 13 Date T.D. Reached 14 Date ~mp., Susp. or A~nd. ~ 15 Water Depth, if offshore ~16 No. of Completions 12-30-95 ~/3/96 13-Feb-96 (peCd)~ NA feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Su~ey~ ~ ~20 Depth whore SSSV sot I 21 Thickness of ~rmafrost 7617'MD &6714'TVD 7516'MD &6636'~D YES ~ NO ~ NA feetMD ~ 1380'ss APPROX '~2 Ty~ Electric or Other Logs Run ARCE/GR, G~CCUCBT 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE ~ GRADE TOP BTM HOLE SIZE CEM~R~O~ 16" 62.58¢ H-40 SURF. 121' 24" 275 sx AS I 7.625" 29.7¢ L-80 SURF. 4024' 9.875" 730 sx AS III Lead, 260 sx Class G Tail 4.5" 12.6~ L-80 3857' 7616' 6.75" 280 sx Class G 24 Pedorations o~n to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD inte~al, size and numar) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5" 3897' 3857' 7304-7316'MD 4 spf 6470- 6479'TVD 7322-7342' MD 4spf 6484- 6499'TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 7348-7388' MD 4 spf 6504-6536' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST Date First Production ~Method of O~ration (Flowing, 9as liQ, etc.) I Injection well Date of Test Hours Tested PRODUCTION FOR OIUBBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD E FIowTubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE E 28 CORE DATA Brief description of lithology, ~rosity, fractures, apparent dips and presen~ of oil, 9as or water. Submit core chips. RE6EIVEB Alaska 011 & Oas Cons. Commis¢on Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7279' 6450' Bottom Kuparuk C 7295' 6463' Top Kuparuk A 7295' 6463' Bottom Kuparuk A 7420' 6561' 31. LIST OF A'FI-ACHMENTS Directional Survey, Daily Drilling History 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed L~ ~ J~. ('~ .... Title L,~T. Lt.T.~IL- ~',,,/~'~, DATE ~"' ~(..]' ~ ~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 5/16/96 ARCO ALASKA INCORPORATED WELL SUMMARY REPORT Page: 1 ELL:3Q-21 RIG:PARKER 245 WELL ID: AK8381 AFC: AK8381 TYPE: STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:12/30/95 START COMP: BLOCK' FINAL: WI: 55% SECURITY:0 AFC EST/UL:$ OM/ 1280M API NUMBER: 50-029-22630-00 12/31/95 (1) TD: 3100' (3100) SUPV' DL DAILY: MW: 9.9 PV/YP: 22/24 APIWL: 6.4 DRILLING Move rig from 3Q-22 to 3Q-21. Accept rig at 0900 hrs. 12/30/95. Drilling and MWD survey from 121' to 3100'. $107,390 CUM: $107,390 ETD: $0 EFC: $107,390 01/01/96 (2) TD: 4040' (940) SUPV:DL DAILY: MW: 9.8 PV/YP: 17/14 APIWL: 6.8 INSTALL FMC HEAD Drilling and MWD survey from 3100' to 4040'. RIH with 7-5/8" casing. Cement casing. $156,243 CUM: $263,633 ETD: $0 EFC: $263,633 01/02/96 (3) TD: 4863' (823) SUPV:DL DAILY: MW: 8.9 PV/YP: 7/ 4 APIWL: 17.5 DRILLING Test casing to 2000 psi . Drill out cement, plugs, FE and new formation to 4050' Perform FIT. Drilling and MWD survey from 4050' to 4863' $91,669 CUM: $355,302 ETD: $0 EFC: $355,302 01/03/96 ( 4) TD- 7261' (2398) SUPV:rLM DAILY: MW: 10.8 PV/YP: 21/ 9 DRILLING Directional drill from 4863' to 7261' $86,722 CUM: $442,024 ETD: $0 EFC: AP IWL' 5.2 $442,024 01/04/96 ( 5) TD: 7617' (356) SUPV: RLM DAILY: MW: 10.8 PV/YP: 24/14 APIWL: 4.5 RUN 4.5" LINER Directional drill from 7261' to 7617'. Held pre-job safety meeting. Run 4.5" liner. $122,678 CUM: $564,702 ETD: $0 EFC: $564,702 01/05/96 (6) TD: 7617' ( 0) SUPV:RLM DAILY' MW: 10.8 ?V/YP: 23/13 APIWL: 4.4 CHANGE OVER TO SEAWATER Run 4.5" liner. Cement casing. CIP @ 1745 hfs 1/4/96. Rig up to run 4.5" tubing. Held pre-job safety meeting. RIH on 4.5" tubing. Change over to sea water. $132,772 CUM: $697,474 ETD: $0 EFC: $697,474 01/06/96 ( 7) TD: 7617' ( 0) SUPV: RLM DAILY: MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED Freeze protect well. Test casing. Test annulus. Test tubing/casing. Release rig @ 2200 1/5/96. $160,543 CUM: $858,017 ETD: $0 EFC: $858,017 End of WellSummary for Well:AK8381 RECEIVED MAY 2 1 199G Alaska Oil & Gas Cons. Commission Anohor~ge Alaska, Inc. KUPARUK RIVER UNIT ,, WELL SERVICE REPORT '~ K1(3Q-21(W4-6)) .LL JOB SCOPE JOB NUMBER Q-21 PERFORATE, PERF SUPPORT 01 24961845.3 DATE DAILY WORK UNIT NUMBER 02/13/96 PERF "A" SAND DAY OPERATION COMPLETE ~ SUCCESSFUL KEY PERSON SUPERVISOR 2 YESI YES SWS-SCHWARTZ CHAN EY FIELD AFC# CC,# Signed ESTIMATE AK8381 230DS36QG Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSI 0 PSI 0 PSI 0 PSII 0 PSII 0 PSI DAILY SUMMARY PERFED "A" SAND 4 SPF @ 7304' - 7316'. I TIME LOG ENTRY 10:00 11:50 MIRU SWS, HELD SAFETY MEETING(4 ON LOCATION) PT'D TO 3000 PSI. RIH W/CCL, 20' OF 3-3/8" CSG GUN WITH ONLY BTM 12' LOADED WITH BIG HOLE CHGS ORIENTATED 2 SPF 170 DEGREES CCW FROM THE HIGH SIDE OF THE HOLE AND 2 SPF 10 DEGREES CW FROM THE HIGH SIDE OF THE HOLE, AND BOWSPRING ORIENTATION TOOL. TIED IN AND PERFED INTERVAL @ 7304' - 7316'. POOH 13:00 ON SURFACE ALL SHOTS FIRED 14:00 RDMO SWS, SECURED WELL AND NOTIFIED DSO OF STATUS. I Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT '~P~ K1(3Q-21(W4-6)) ,/ELL JOB SCOPE JOB NUMBER 3Q-21 PERFORATE, PERF SUPPORT 0124961845.3 UNIT NUMBER DATE 02/1 1/96 DAY 1 DAILY WORK PERF 'A' SAND OPERATION COMPLETE YES DALLY SUMMARY ISUCCESSFUL , _Y..E.S_ IKEY PERSON SCHWARTZ SUPERVISOR PAIGE PERFORATED INTERVALS 7322'-7342' & 7348'-7388' USING 3-3/8" HOLLOW CARRIER W/BIG HOLE CHARGES, 4 SPF, 180 DEG PH, AND ORIENTED 170 DEG CCW F/HIGH SIDE; WHP DID NOT INCR. UNABLE TO SHOOT UPPERMOST INTERVAL 7304'-7316' BECAUSE THE BOWSPRING WHICH IS USED TO INSURE THE ORIENTATION WAS BROKEN FOLLOWING THE THIRD RUN. TIME 10:00 11:30 12:30 ~ BLEED WHP TO 200#. FIRED GUN#l; POH. 13:00 I AT SURF W/GUN #1i ALL SHOTS FIRED. tLOG ENTRY MIRU SWS. HELD SAFETY MTG. PT LUB TO 3000#; TEST OK. RIH W/GUN #1 - CCL, 20' 3-3/8" HOLLO~,CARRIER W/BIG HOLE CHARGES, 4 SPF, 180 DEG PH, ORIENTED 170 DEG CCW F/HIGH SIDE TO SHOOT 7368-7388' 13:30 PT LUB TO'3000#; TEST OK. RIH W/GUN #2 - CCL, 20' 3-3/8" HOLLOW CARRIER W/BIG HOLE CHARGES, 4 SPF, 180 DEG PH, ORIENTED 170 DEG CCW F/HIGH SIDE TO SHOOT 7348'-7368' 14:00 WHP = 0#. FIRED GUN#2; POH. 14:20 AT SURF W/GUN #2; ALL SHOTS FIRED. 14:50 PT LUB TO 3000#; TEST OK. RIH W/GUN #3 - CCL, 20' 3-3/8" HOLLOW CARRIER W/BIG HOLE CHARGES, 4 SPF, 180 DEG PH, ORIENTED 170 DEG CCW F/HIGH SIDE TO SHOOT 7322'-7342' 15:30 WHP = 0#. FIRED GUN#3; POH. 16:00 AT SURF W/GUN #3; ALL SHOTS FIRED. THE BOW SPRING WHICH IS USED TO INSURE THE GUN IS PROPERLY ORIENTED IS BROKEN; NO REPLACEMENT IS ON LOC. 16:30 CURRENT TEMP IS -37 DEG; DECIDE TO RIG DOWN AND COMPLETE LAST RUN AT A LATER DATE. 17:30 RDMO. , RFCEI\!ED PAGE ********* SCHLUMBERGER ********** ********* ********** *********************************************************** *********** SURVEY PROGRAM *********** COMPAHY ARCO ALASgA~ IHCo WELL HAME 3Q-21 LOCATIOH 1 KUPARUg LOCATIOH 2 ALASgA MAGNETIC DECLIHATION 27.93 GRID CONVERGEHCE ANGLE 0.00 DATE: 03-JAH-96 WELL HUMBER 21 AFE Ag 8381 API WELL HO: 50-029-22630-00 WELL H£AD LOCATION: LA?(N/-S} 0,00 AZIMUTH FROM ROTARY TABLE TO TARGET IS TIE IH POIHT(TIP) : MEASURED DEPTH 121,00 TRUE VERT DEPTH 12!,00 IHCLIHATIOH AZIMUTH 0,00 LATITUDE(H/-S) 0,00 DEPARTURE(£/-W) 0.00 D£P(E/-W) 172,78 0.00 ~ NO, 2 3Q-21 ************* ANADRtLL SURVEY CALCULATIONS ************* CIRCULAR ARC M£THOD******** HEASURED INTERVAL VERTICAL DEPTH DEPTH ft ft f~ 121,00 0,0 121,00 375,96 255,0 375,94 561,46 185.5 561,39 836,93 275,5 836,73 1111,82 274,9 1111,48 TARGET STATIOH AZIMUTH LATITUDE S~CTIOH INCLH, H/-S ft deg deg f~ 0,00 0,00 0,00 0,00 -2,48 1,27 324,26 2,29 =5,39 1,91 61,82 5.42 -7,27 1,75 79,54 8,35 -7.91 1,89 77,63 10.08 DEPARTUR£ DISPLACEMENT ~t AZIMUTH ft f: deg 0,00 0,00 0,00 -1,65 2,83 324,26 -0,I3 5,42 358,64 8,04 11,59 43,92 16.58 19,41 58,71 DLS deg/ lOOft 0,00 0,50 1,31 0,21 0,06 1388,89 1665.72 1944,25 2221,25 2496.39 277,1 1388.38 276.8 1665,02 278.5 1943.38 277.0 2220,23 275,1 2495,24 -8.48 2.04 80.98 11.83 25,92 28,49 65,46 0,07 -8,26 2,22 86,80 12,90 36,15 38,38 70,35 0,10 -7.54 1,89 87,05 13.44 46,13 48.05 73,75 0,12 -6o85 1,79 87,35 13.88 55,02 56.74 75,84 0.04 -6.09 1.78 88,45 14.19 63,59 65.15 77.42 0.01 2588.13 2679,17 2773,20 2865.98 2958.87 91.7 2586,94 91,0 2677,93 94,0 2771,76 92,8 2863,91 92,9 2955,49 -5,79 1.68 89,57 14.24 66,36 67.87 77,89 0,12 -4,40 2.20 127,20 13.19 69.09 70,34 79,19 1.48 1,01 5.11 165,11 8.05 71,60 72,06 83.58 3.86 11,69 8,16 173.82 -2,49 73,38 73.42 91,94 3,45 27,15 II,10 179,85 -17.98 74,11 76,26 103,64 3,34 3048.31 3141.70 3235,54 3328.58 3420.30 89.4 3042,89 93.4 3133.25 93,8 3223.03 93.0 3310,88 91,7 3396,24 45,96 !3.42 181,36 -36,97 73.89 82,62 116,58 2.62 69,18 15,78 182,79 -60o48 73,01 94,81 129,64 2,55 96.16 18,05 180.48 -87,77 72,27 113,69 140,53 2,53 126,53 20,37 I79.41 -118o38 72,32 138,72 148,58 2,52 159,8I 22.57 180.83 -151.94 72,22 168,23 154,58 2.46 3513.61 3607.15 3698,80 3792,20 3884,80 93.3 3481,58 93.5 3565,18 91.7 3644.97 93.4 3723,80 92,6 3799,27 197,19 25.12 180,15 -189,66 71,91 202,83 159,24 2,75 238,74 28,13 180,42 -231,57 71,70 242,42 162,80 3,22 283,49 30,80 179,07 -276.65 71,92 285,84 165,43 3,00 333.32 34,04 177.68 -326.69 73,37 334,83 167,34 3.56 386,77 36.79 178,05 -380.31 75,36 387,71 168.79 2,98 3958,34 4133,54 4317,80 4504,42 4687,45 73.5 3858,02 175.2 3997.09 184.3 4142,31 186.6 4289,41 183,0 4434,51 430.82 37.15 177,52 -424,50 77.07 431,44 169.71 0,65 537,07 37,78 I76,78 -530,93 8Z, 38 537,28 171.18 0,44 650,29 38.20 175,60 -644.09 89,92 650,34 172,05 0.46 765°04 37,76 174,24 -758.48 100.08 765.05 172,48 0,51 876,55 37,35 174.69 -869.52 110,84 876,55 172.74 0.27 4870.09 5055,64 5237,01 5424,60 5608,91 182,6 4580.36 185.6 4726,00 181,4 4866.37 187,6 5011,51 I84,3 5153,58 986,47 36.67 172,23 -978o73 123,34 986,47 172,82 0.89 1101,40 39.89 172,25 -1092,61 138,86 1101.40 I72,76 1.74 1216,16 38.70 169,28 -1205.96 157,25 1216,17 172,57 1,23 1334,90 39.93 171,91 -1323,20 176,64 1334.93 172,40 1,I0 1452,31 39.21 173,21 -1439.61 191,85 1452.34 172.41 0.60 5790,86 5975.59 6161,79 6345.48 6526,85 181.9 5294,39 184,7 5437,53 186.2 5580,82 183.7 5720,88 181,4 5858,93 1567.19 39.48 164,85 -1552.63 1683,31 38,96 168,86 -1666.32 1801,83 40,41 167.66 -1782,72 1920,55 40.28 173,82 -I899,97 2038,19 40,60 171,90 -2016,69 213.78 1567,28 172,16 240,35 1683,56 171,79 264,56 1802,24 171,56 283,69 1921,03 I71,51 2,92 1,40 0,88 2,17 0.71 30-21 ************* ANADRILL ************** SURVEY CALCULATIONS ************* CIRCULAR ARC METHOD******** MEASURED INTERVAL VERTICAL TARGET DEPTH DEPTH SECTION ft ft ft ft 6712,21 I85.4 6001,32 2156.84 6897,32 185,1 6147.38 2270,54 7084,98 187,7 6296,83 2383.97 7269,14 184,2 6442,37 2496,61 7529,69 260.5 6646,60 2658,23 PROJECTED TO TO 7617.00 87,3 6714,58 2712,99 STATION AZIMUTH LATITUDE IHCLN. N/-S deg de9 ft 39.01 173,36 -2134.35 36.79 172.54 -2247,20 37.65 169.63 -2359.31 37.92 169.23 -2470.23 38.86 171,12 -2629,64 38.86 171.12 -2683,77 DEPARTURE DISPLACEMENT at AZIMUTH DLS E/-W de9/ ft ft deg lOOft 313.56 2157,26 171.64 0,99 327,50 2270,94 171,71 1,23 345,11 2384,41 171,68 1,04 365,81 2497,16 171,58 0.20 393,39 2658,91 171,49 0.58 401,85 2713,68 171,48 0,02 * ALASKA COMPUTING CENTER * * SCHLUMBERGER * COMPANY NAME : ARCO ALASKA, INC. WELL NAME : 3Q - 21 FIELD NAME : KUPARUK RIVER UNIT BOROUGH : NORTH SLOPE STATE : ALASKA APl NUMBER : 50-029-22630-00 REFERENCE NO : 96046 * ALASKA COMPUTING CENTER * SCHLUMBERGER * COMPANY NAME : ARCO ALASKA, INC. WELL NAME : 3Q - 21 FIELD NAME : KUPARUK RIVER UNIT BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 50-029-22630-00 REFERENCE NO : 96046 _o Tape Verification Listing Schlumberger Alaska Computing Center 28-FEB-1996 08:57 ~**~ REEL HEADER **** SERVICE NAME ·ED IT DATE ' 96/02/28 ORIGIN : FLIC REEL NAME : 96046 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., KUPARUK 3Q-21, API #50-029-22630-00 **** TAPE HEADER DATE ' 96 2/28 ORIGIN : FLIC ~APE NAME : 96046 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., KUPARUK 3Q-21, API #50-029-22630-00 TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA BIT RUN 1 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: ~URFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 96046 MILTON MORRISON 1ST STRING 2ND STRING - 21 0292263000 ARCO ALASKA, INC. SCHLUMBERGER ANADRILL 28-FEB-96 BIT RUN 2 BIT RUN 3 13N 9E 2308 1941 62.00 62.00 21.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.750 7.625 4024.0 PAGE: Tape Verification ]'Jisting ochlumoerger Alaska Computing Center 28-FEB-1996 08:57 3RD STRING PRODUCTION STRING REMARKS: Well drilled 02-JAN through 03-JAN-96 with ARC5 only. Ail data was collected in a single bit run. No MAD data was collected. **** FILE HEADER FILE NAME : EDIT 001 SERVICE : FLIC VERSION ' 001C~ DATE ' 96/0 28 lAX REC SIZE : 1024 z~ILE TYPE : LO LAST FILE PAGE: FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and ~li~d curves ; I CeEME T: FILE SUMMARY LDWG TOOL CODE START DEPTH MWD 3956.0 $ BASELINE CURVE FOR SHIFTS: GR CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH MWD all bit runs merged. STOP DEPTH -- 7616.5 EQUIVALENT UNSHIFTED DEPTH 88888.0 88888.5 7467.5 7468.0 7415.5 7417.5 7383.0 7385.0 7366.0 7367.0 7292.5 7293.0 7273.5 7273.5 7247.5 7247.0 7242.0 7240.5 7232.0 7231.5 7219.5 7219.5 7213.0 7212.5 7202.0 7202.5 7181 .5 7181 .5 7171 .0 7170.5 7127.5 7127.0 7108.5 7108.0 7102.0 7101.0 S Ta.~e Verification Listing S~hlum erger Alaska Computing Center 28-FEB--J996 08:57 7078 7067 7061 7024 7004 6936 6921 6866 6852 6834 6818 6794 6723 6655 6586 6496 6396 6260 6192 6145 5963 5898 5828 5748 5546 5352 5292 5187 5O97 4902 4648 4598 4469 4245 4184 100 $ .0 .5 .5 .5 0 5 0 5 5 5 5 0 5 5 5 5 5 0 .5 0 0 0 5 5 5 .5 .5 .0 .0 .5 .0 .5 .5 .5 .0 .0 MERGED DATA SOURCE LDWG TOOL CODE 7077.0 7068.5 706].5 7023.0 7003.5 6935.5 6920.0 6865.0 6852 0 6833 5 6817 0 6792 0 6721 0 6653 0 6584 0 6494 0 6394.0 6257.5 6190.0 6]43.0 5961 .0 5895.0 5825.0 5745.5 5542.5 5351.0 5287.5 5183.0 5093.5 4898.5 4647.5 4601.0 4473.0 4248.5 4187.5 103.5 BIT RUN NO. MERGE TOP MERGE BASE $ REMARKS' The depth adjustments shown above reflect the MWD GR to the CBT GR loqged by SWS. Ail other MWD curves were carried with the GR. # $ LIS FORMAT DATA PAGE: Taoe Verification Listing ochlumberger Alaska Computing Center 28-FEB-1996 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE ] 66 0 2 66 0 3 73 40 4 66 ] 5 66 6 73 7 65 8 68 O.5 9 65 FT 1] 66 25 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 08:57 PAGE ' ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE- API API API API FILE NUMB NUMB- SIZE REPR ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE PROCESS (HEX) DEPT FT 00 000 00 0 I 1 I 4 68 ROP MWD F/HR 00 000 00 0 1 1 1 4 68 FET HWD HR 00 000 00 0 I I 1 4 68 GR MWD GAPI 00 000 00 0 1 1 1 4 68 RPXX MWD OHMM O0 000 O0 0 1 1 1 4 68 RPX MWD OHMM 00 000 00 0 1 1 1 4 68 RPS MWD OHMM 00 000 00 0 1 1 1 4 68 RPM MWD OHMM 00 000 00 0 1 1 1 4 68 RPD MWD OHMM 00 000 00 0 1 1 1 4 68 GRCH CBT GAPI 00 000 00 0 I 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA DEPT. 7617.000 ROP.MWD 165.000 FET.MWD -999.250 RPXX.MWD -999.250 RPX.MWD -999.250 RPS.MWD -999.250 RPD.MWD -999.250 GRCH.CBT -999.250 DEPT. 7000.000 ROP.MWD 94.286 FET.MWD 1.078 RPXX.MWD 1.863 RPX.MWD 1.952 RPS.MWD 1.930 RPD.MWD 1.926 GRCH.CBT 80.438 GR.MWD RPM.MWD GR.MWD RPM.MWD -999.250 -999.250 112.688 1.887 Tape Verification Listing !umoerger Alaska Computing Center DEPT. 6000.000 ROP.MWD RPXX.MWD 2.114 RPX.MWD RPD.MWD 2.156 GRCH.CBT DEPT. 5000.000 ROP.MWD RPXX.MWD 3.483 RPX.MWD RPD.MWD 3.648 GRCH.CBT 28-FEB-1996 08:57 180.000 FET.MWD 2.178 RPS.MWD 76.875 104.211 FET.MWD 3.566 RPS.MWD 89.938 DEPT. 4000.000 ROP.MWD 180.000 FET.MWD RPXX.MWD -999.250 RPX.MWD -999.250 RPS.MWD RPD.MWD -999.250 GRCH.CBT 41.375 DEPT. 3950.000 ROP.MWD -999.250 FET.MWD RPXX.MWD -999.250 RPX.MWD -999.250 RPS.MWD RPD.MWD -999.250 GRCH.CBT 40.813 0.214 2.143 0.250 3.576 5.306 -999.250 -999.250 -999.250 GR.MWD RPM.MWD GR.MWD RPM.MWD GR.MWD RPM.MWD GR.MWD RPM.MWD PAGE: 116.194 2.106 95. 292 3.583 48.776 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION · 00}C01 DATE · 96 02/28 MAX REC SIZE :. 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION ' 00}~}2 DATE ' 96 8 '~AX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW MWD Curves and log header data for each bit run in separate BIT RUN NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 3956.0 761 6.5 $ files. .~S Tape Verification Listing Schlumberger Alaska Computing Center 28-FEB-J996 08:57 LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (PT): TOP LOG INTERVAL (FT/: BOTTOM LOG INTERVAL (FT)' BIT ROTATING SPEED (RPM) HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 03-JAN-96 4.0C 4.0C MEMORY 76]7.0 3960.0 76]7.0 8O 28.1 40.4 TOOL NUMBER LIS ARC5 RESISTIVITY ARC5-475 GR GAMMA RAY SLIM]-A $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN]' DRILLERS CASING DEPTH[~T)' 6.750 4024.0 BOREHOLE CONDITIONS MUD TYPE: LOW SAND MUD DENSITY (LB/G)' ]0.80 MUD VISCOSITY (S)' 52.0 MUD PH: ]0.0 MUD CHLORIDES (PPM)' FLUID LOSS (~3): . 6.5 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF)' MUD AT MEASURED TEMPERATURE (MT)' 2.960 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 2.480 MUD CAKE AT (MT): 2.440 (IN): NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION TOOL STANDOFF /IN/' EWR FREQUENCY HZ DISTANCE TO BIT:GR = 46.0,RES=41 .] $ REMARKS: FORMAT DATA 20000 POLYMER 74.0 68.0 70.0 PAGE: .~S TaDe Verification Listing Schlumberger Alaska Computing Center 28-FEB-1996 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE I 66 0 2 66 0 3 73 36 4 66 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 28 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 08:57 PAGE: ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API AP1 -API API FILE NUMB NUMB SIZE REPR ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE PROCESS (HEX) DEPT FT 00 000 00 0 2 I I 4 68 ROP LW1 F/HR 00 000 00 0 2 1 I 4 68 FET LWI HR 00 000 00 0 2 1 I 4 68 GR LWI GAPI 00 000 00 0 2 1 1 4 68 RPXX LW1 OHMM 00 000 00 0 2 I I 4 68 RPX LW1 OHMM 00 000 00 0 2 1 1 4 68 RPS LW1 OHMM 00 000 00 0 2 1 1 4 68 7PM LW1 OHMM 00 000 00 0 2 1 1 4 68 RPD LW1 OHMM 00 000 00 0 2 1 1 4 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 ** DATA ** DEPT. 7616.500 ROP.LW1 165.000 FET.LW1 0.244 RPXX.LW1 3.633 RPX.LW1 3.854 RPS.LW1 3.840 RPD.LW1 3.664 DEPT. 7000.000 ROP.LW1 116.471 FET.LW1 1.075 RPXX.LW1 1.921 RPX.LW1 1.999 RPS.LW1 2.013 RPD.LW1 2.038 DEPT. 6000.000 ROP.LW1 180.000 FET.LW1 0.211 RPXX.LW1 1.994 RPX.LW1 2.060 RPS.LW1 2.053 RPD.LW1 2.050 GR.LW1 RPM.LW1 GR.LW1 RPM.LW1 GR.LW1 RPM.LW1 80.389 3.710 114.467 2.006 111.355 2.027 kS Ta~e Verification Listing ~chlum erger Alaska Computing Center 28-FEB-1996 08:57 PAGE: DEPT. 5000.000 ROP.LW1 RPXX.LW1 3.377 RPX.LW1 RPD.LW] 2.976 DEPT. 4000.000 ROP.LW1 RPXX.LW1 ]000.000 RPX.LWl RPD.LW] ].155 DEPT. 3956.000 ROP.LWl RPXX.LW1 99.378 RPX.LW] RPD.LW] 1000.000 110.000 FET.LW] 0.~94 3.4]3 RPS.LW] 3.327 180. 000 FET. LW1 5 . 3] 4 24. 297 RPS. LW] 2.188 ~ 80 . 000 FET. LWl 0 . 000 436. 858 RPS.LW] 1000.000 GR. LW 1 RPM. LW 1 GR. LW ] RPM. LW ~ GR. LW 1 RPM. LW 1 91 .399 3.143 50.097 ] .324 8.397 1000.000 END OF DATA **** FILE TRAILER FILE NAME : EDIT .002 SERVICE : FLIC VERSION · 001C01 DATE ' 96~2/28 MAX REC SIZE · FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME 'ED IT DATE ' 96/02/28 ORIGIN : FLIC TAPE NAME : 96046 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., **** REEL TRAILER SERVICE NAME ' ED~ DATE ' 96 2/28 ORIGIN : FLIC REEL NAME : 96046 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., KUPARUK 3Q-21, KUPARUK 3Q-21, API #50-029-22630-00 API #50-029-22630-00 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10059 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 3/6/96 Field: Kuparuk (Open Hole) LIS Well Job # Log Description Date BL RF Sepia DIR MWD Tape ,.,i 3Q-21 96046 ARC 5 9601 03 I I 1 3Q-21 96046 ARC 5 TVD 9601 03 I 1 3R-25 95407 ARC 5 951 203 1 I I SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: ARCO Alaska, Inc. Date' February 5, 1996 Transmittal #' 9327 RETURN TO: ARCO Alaska, Inc. Attn.: Julie Nash Kuparuk Operations File Clerk ATO-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased Hole items. Please acknowledge receipt and return one signed copy of this transmittal. 3Q-21 (CBT) Cement Bond Log Receipt Acknowledge' 01/28/96 3700-7507 Date' DISTRIBUTION: Sharon AIIsup-Drake DS Development ATe-1205 Larry Grant (+sepia) AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Erickson/Zuspan NSK Central Files NSK-box 69 ALASI~A OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 December 18, 1995 Mike Zanghi, Drill Site Develop. Supv. ARCO Alaska Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Well # Company Permit # Surf Loc Btmhole Loc Kuparuk River 3Q-21 ARCO Alaska Inc. 95-193 2308'FNL, 1941 'FEL, Sec 17, T13N, R09E, UM 348'FSL, 1611'FEL, Sec 17, T13N, R09E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Si David W Chairman BY ORDER OF THE COMMISSION Ijb/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA "' ALASKA OIL AND GAS CONSERVATION COMMIS&.._,N PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill D lb Type of Well Exploratory D Stratigraphic Test [-] Development Oil X Re-Entry D Deepen D Service D Development Gas [~ Single Zone X Multiple Zone D 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 21' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25512, ALK 2553 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 20 AAC 25,025) 2308' FNL, 1941' FEL, Sec. 17, T13N, R9E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 556' FSL, 1635' FEL, Sec. 17, T13N, R9E, UM 3Q-21 #U-630610 At total depth 9. Approximate spud date Amount 348' FSL, 1611' FEL, Sec. 17, T13N, R9E, UM 12/23/95 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15, Proposed depth (MD and TVD) property line 3Q-16 7580' MD 348 ~ TD feet 21.7' ~ 720' MD feet 2544 6704' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 2721 ' feet Maximum holeangle 38.6° Maximum,surface 231 6 psig At total depth (TVD) 3600 psig 18. Casing program Setting Depth size Specifications Top Bottom Quanti~ of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include sta~le dataI 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' _+200 CF 9.875" 7.625" 29.7# L-80 LTC 3967' 41' 41' 4008' 3912' 730 Sx Arcticset III & 260 Sx Class G 6.75" 4.5" 12.6# L-80 NSCT 3730' 3850' 3783' 7580' 6704' 280 Sx ClassG Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor SurfaceRECEIVED Intermediate Production Liner .NOV ~0 '~995 Perforation depth: measured true vertical ~ O~ 20. Attachments Filing fee X Property plat g] BOPSketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot r'l Refraction analysis E] Seabed report E] 20 AAC 25.050 requirements X 21. I hereby certify that the foregoin, g is true and correct to the best of my knowledge Signed ~'~/! q ~CommissionTitle Drill Site DevoI°p' Supv' Date ]['"~"~'"~"~-Use Only Perm~Number '""ii.number ... I Approval date ... ~ ~ ~ See cover letter for <:::~'-~' "¢/~.. ;~ r'~o- ~3 ~-.<~' - .-~- ,2-- ~:::~ ,-,~ (::~ I /~:~- /~'~- '~ ~" I °thor requirements Conditions of approval Samples required E] Yes J~ No Mud Iog required E] Yes ~ No Hydrogen sulfide measures C~ Yes r'] No Directional survey required C~ Yes D No Required working pressure for BOPE E] 2M ~ 3M D 5M g] 1OM E] 15M Other:,.Jrlginal Signed By '~._~v[dW. Johnstonby order of Approved by Oommissioner the commission Date Form 10-401 Rev. 7-24-89 Submit, 3 triolicate GENERAL DRILUNG PROCEDURE KUPARUK RIVER FIELD KRU 3Q-21 , . . . . . . , . Note: Note: 10. 11. 12. Note: 13. 14. Move in and rig up Parker #245. Install diverter system. Drill 9-7/8" hole to 7-5/8" surface casing point (4,008')according to directional plan. Run and cement 7-5/8" casing. Install and test BOPE to 3000 psi. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 6-3/4" hole to total depth (7,580') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 4-1/2" liner on drillpipe, with 5-1/2" polished seal bore. Set liner hanger and liner-top packer with 150' of liner lap from the surface shoe. Release from liner. (See attached completion schematic.) Due to the long length of the liner, the cementing program is not designed to reach the liner lap but to extend 1000' above the top of the Kuparuk. If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Pressure test casing and liner-top packer to 3500 psi. Run 4-1/2" completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus. ND BOPE and install production tree. As a dedicated injector, cased hole cement bond logs (SLT-J or CBT) will be run to establish isolation after the cleanout is completed, but prior to perforating. Shut in and secure well. Clean location and RDMO in preparation for coiled tubing cleanout and perforating. RECEiVEL) NOV ;50 199,5 New Well Slimhole ~onobore Injector DS 30 & 3R Infill _ Need to change conductor cutoff / wellhead height, 1 6" Conductor Csg: ~100' Tubing Hanger w/BPV Profile Profile @ 500' CAMCO DB Nipple ID 3.81 2" Option of 4-1/2" on top with 4" below with AVA sleeve instead of a sliding sleeve? 4-1/2" Tieback NSCT L-80 from surface to top of Liner 4-1/2" Baker Sliding Sleeve (5.5" OD) with 3.81 2" X selective profile 7-5/8" ~2500-4000' TVD Top of Cement 4-1/2" Casing w/4-1/2" x 7-5/8" Liner Hanger and Liner Top Packer Profile for MIT Camco 3.75" DB 4-1/2" NSCT Gas Tight Connection L-80 from top of liner to TD A Sands RECEiVEL NOV 3 0 199,~ 6 3/4" hole Perforate A sand with 3-3/8" BH casing guns, oriented, 180° phasing. 9/95 jtz page #8 DRILLING FLUID PROGRAM Well KRU 3Q-21 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 15-25 15-35 50-80* 5-15 15-40 10-12 9.5-10 _+10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Weight up to TD 11.2 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur before a surface pressure of 2,316 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 3Q-21 is 3Q-16. As designed, the minimum distance between the two wells would be 21.7' @ 720' MD. Drilling Area Risks: Risks in the 3Q-21 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation material (LCM) and reduced circulating rates as needed. 5-1/2" casing will be topset above the Kuparuk and either Nordic Rig #1 or a coiled tubing unit will drill out a 4-3/4" hole, and run a 3-1/2" liner to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 11.2 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 7-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. ANNULAR PUMPING OPERATIONS WELL KRU 1Q-21 Incidental fluids developed from drilling operations will be pumped down the nearest permitted annulus, or hauled offsite to a permitted disposal well. The tubing will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 3Q-21 surface/production casing annulus will be filled with diesel after setting the 4-1/2" liner/tubing string and pdor to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons sufficient cement volume will be pumped during the production cement job to cover the formation. 3Q-21 will not be permitted for annular pumping as the annular isolation packer does not allow for this operation. ARCO ALASKA, Inc. Pad 3Q 21 slot #21 Kuparuk River Unit North Slope, Alaska CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 21 Version #5 Our ref : prop1396 License : Date printed : 16-Nov-95 Date created : 5-Sep-95 Last revised : 16-Nov-95 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on nTO 29 16.377,w149 51 0.781 Slot location is nTO 28 53.676,w149 51 57.872 Slot Grid coordinates are N 6025764.150, E 516389.856 Slot local coordinates are 2308.00 S 1941.00 N Reference North is True North Main calculation performed with 3-D Minimum Distance method ~Object wel[path PGMS <0-8020'>,,1,Pad 3Q PGMS <0-10620'>,,Oliktok #1,Pad 3Q PGMS <0-9993'>,,2,Pad 3Q PGMS <0-10145'>,,5,Pad 3Q PGMS <0-9747'>,,6,Pad 3Q PGMS <O-9298'>,,7,Pad 3Q PGMS <0-9400'>,,8,Pad 3Q PGMS <0-7990'>,,9,Pad 3Q PGMS <0-8390'>,,lO,Pad 3Q PGMS <0-7265'>,,11,Pad 3Q PGMS <0-7503'>,,12,Pad 3Q PGMS <0-8190'>,,13,Pad 3Q PGMS <0-8505'>,,14,Pad 3Q PGM$ <0-7480'>,,15,Pad 3Q PGMS <0-7300'>,,16,Pad 3Q PGMS <0 - 9640'>,,3,Pad 3Q PGMS <0-7720'>,,4,Pad 3Q 22 Version ~4,,22,Pad 3Q Closest approach with 3-D minimum distance method Last revised Distance M.D. Diverging from M.D. 8-Apr-92 449.4 0.0 0.0 26-Aug-91 674.3 100.0 200.0 26-Aug-91 423.8 100.0 200.0 26-Aug-91 349.5 200.0 200.0 26-Aug-91 323.8 100.0 200.0 26-Aug-91 299.1 100.0 200.0 26-Aug-91 272.7 433.3 433.3 26-Aug-91 199.1 100.0 100.0 26-Aug-91 173.6 433.3 433.3 26-Aug-91 148.4 433.3 2700.0 26-Aug-91 117.0 2796.1 2796.1 26-Aug-91 98.6 400.0 400.0 26-Aug-91 74.5 100.0 1300.0 26-Aug-91 49.5 400.0 2871.1 26-Aug-91 21.7 720.0 4420.0 3-Apr-92 399.0 0.0 0.0 1-Sep-92 373.9 200.0 200.0 13-Nov-95 87.6 300.0 4007.6 iCreoted by : jones For: D PETRASHi iDate plotted : 16-Nov-95 iPJot Reference ~s 21 Version t~5. !Coordinates ore in feet reference slot #21. iTrue Vertical Depths ore reference RKB (Porker ~245).i 400 400 _ -- 800 _ -- 1200_ _ 1600_ 2000_ - 2400_ - 2800_ 3200_ -- 3600_ -- 40O0_ _ 4400_ -- 4800_ -- 5200_ 5600_ 6000_ - 6400_ - 6800_ ARCO ALASKA, Inc. Structure : Pod ,30 Well : 21 Field : Kuparuk River Unit S 7.;32 DEG E a435' (TO TARGET) ***PLANE OF PROPOSAL*** RKB ELEVATION: 62' BEGIN NUDGE TVD=400 TMD=400 DE=O 1.5o BUILD 1.5 DEG / 100' END ANGLE BUILD TVD=600 TMD=600 DEP= -.25 BEGIN ANGLE DROP TYD=800 TMD=800 DE= -.76 2.00 1.00 DROP 1 DEG/ 100' END OF NUDGE TVD=1100 TMD=1100 DEP= -1.14 B/ PERMAFROST TVD=1612 TMD=1615 DEP= -1.14 Location : North Slope, Alaska , .oo East 400 2O0 0 200 KOP · . 400 -- _ 200 -- _ 0 -- _ 200 -- _ 400 -- _ 600 -- _ 8OO -- _1oo0 400 I 600 800 I I I I I SURFACE LOCATION: 2308' FNL, 1941' FEL SEC. 1 7, T13N, R9E Yap West Sok Sands Bose West Sok Sands EOC- 7 5/8 Casing Pt lOOO T/ UGNU SNDS TVD=2612 TMD=2613 DEP= -1.14 KOP TVD=2721 TMD=2721 DEP= -1.14 r ',EIVED 2i.00 T/WSAKSNDS TVD:340~TMD=3418 DEP:125 NO30 1; O0 V 1995 ~, .:~, 24.o0 \ 27.00 /'~,',~ 3600 ' " // "~'~-' EOC- 7 5/8" CSG PT 1VD:3912 TMD=4008 DEP=416 .~; ~.1~ ~. ~ TARGET-Top Un;t C( t )TL7 uUnni[A~ ~ TM0=7245 ~ ~../~V - 5 1/2 Coslng PI ~ ~oEt;H24~4S16 '~-~----~"- EAST 306 a8.6 ........... ~ B/ HRZ 1VD=6142 TMD=6861 DEP=2196 '~ K-1 1VD=6252 TMD=7002 DEP=2284 ~ T/ UNIT D TVD=6403 1MD=7195 DEP=2404 '~ TARGET - T/ UNIT C TVI)=6442 TMD=7245 DEP=~435 '%. T/ U, NIT A TVD=6455 1MD=7261 DEP=2446 x'x"~ B/ KUP SNDS TVD=6548 TMD=7380 DEP=2520 '~' TD -~ 1/2" ~ PT TVD=8704 TMD=7580 DEP=264§ I I I I I I I I I I I I I I I I I I 400 0 400 800 1200 1600 2000 2400 2800 4 uNe~L 1200 1400 1600 ~1800 _ _2000 -- _2200 -- _2400 _2600 -- _2800 _ Scale 1 : 200.00 Vertical Section on 172.78 azimuth with reference 0.00 N, 0.00 E from slot #21 I I V I / V' 240 28O 32O 560 400 440t 480~ 360 : 17~Nov~g~ Re~eren~ i~ 21 Ve~ion ~5. /COordino[~ ore in fee[ reference slot ~2L Vertical Dep~~~ RK~ (Parker ~245). CD 0 360 40 520 280 120 240 8O 120 760 200. 52O 520 280 240 200 /ARCO ALASKA Structure ; Pod 30 Field : KUparuk ~ ~Ner Unit Locoflon : Nodh Slope, Iosko/ A 200 160 ! 20 80 ! ooo 6O0 1 ooo ~200 /1400 RECEIVED NOV 30 1995 Anchorage 76O 120 80 40 0 West West 4O 0 40 80 120 160 3200 ~200 30O0 ,~3000 1400 1600 3200~~ %1200 3400 1800 ~4O0 3600 38O0 Scale i · 20.00 200 240 280 0 ¢ooo 40 120 200 240 280 SCale 1 ' 20.00 52O 600 8O 120 160 200 120 440 480 560 ,t20 40O tx) (D O © ,KjPARUK RIVER UNIT 20" DIVERTER SCHEMATIC I4 5 3 O---1 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. , MAINTENANCE ~, OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20" - 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PSI ANNULAR PREVENTER. DKP 11/9/94 O O O > z~ -~ [C I- .J~ LU 13. i:)n' o ~ om Ds-- 0C 13.. WIT, ~,~Z LU ~- W (/)( Z ~- ~ o~ .w.,,,zo~ -~ ~:~: zTO-- ~ 'Ji;)[IZw~ .~ ~o,~ -~w=_<~ ,UO~l-~l--Luo >- w ~ > c30 [::3 w i) ~LmOCnSWS~W LU I 0Z _~n' [3-1-- tti IJ_~_ ~O --W z .~w . . ~O~__LU '~ :~-- ~--W ,~ n .:.~z~ ,o,~) ;~ .~ ~z>~- <> ~;> · ,,~-- u. ~ Z~CC O w~:~. '"' z n -Onw w LU -~ wu- -_Z -- 03LU U_ )~: i_wnU~ ~w;~z ~a.~< ~ ~W~_z~ wu) ~7'qrr ~(~wo~:~n Z :C~ ~,, I-.- Z Z ,~ ~ .I--Z 3 ILl Z--r w_z cc w~.--w -~:~ O g<z,-, O a_ LU , ~;~ _'~w~-_ -JTn'_~ _1 U.I U.I[~-_ ~:U-LU 11" ~/)LLID- 133 ~.O[L--~O~l--zm(J>O OJ~OE NO<E31~--I~ [LO > WELL PERMIT CHECKLIST COMPANY /~-~o ~NIT CT,ASS,._~_../_.~ /-C)/~ WELL NAME GEOL AREA UNIT# PROGRAM: exp [] dev~ redrll [] serv [] ON/OFF snoRE ADM INI STRATI ON D/TE ; 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary.. 6. Well located proper distance from other wells ..... 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party .............. 10. Operator has appropriate bond in force ......... 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval.. 13. Can permit be approved before 15-day wait ....... Y N Y N Y N ?¥ N Y N Y N ENGINEERING 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg.. N 17. CMT vol adequate to tie-in long string to surf csg . . . Y 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved..~~ 22. Adequate wellbore separation proposed .......... ~_~ N 23. If diverter required, is it adequate .......... .~ N 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate ..................... ~Y/ N 26. BOPE press rating adequate; test to -~ psig.~ N 27. Choke manifold complies w/API RP-53 (May 84) ....... 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/~ 31. Data presented on potential overpressure zones ..... Y~ ~ ~ 32. Seismic analysis of shallow gas zones .......... ~/ N /~w/. 33. Seabed condition survey (if off-shore) ........ //Y N 34. Contact name/phone for weekly progress reports . . . ~/. Y N [exploratory only] REMARKS GEOLOGY: ENGINEERING: COMMI SS ION: Comments/Instructions: HOW/Ijb - A:\FORMSAcheklist rev 11195