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196-204
MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, July 21, 2020 TO: Jim Regg I/ n /,, P.L Supervisor 6 ! I vl I2'� SUBJECT: Mechanical Integrity Tests 6 ConocoPhillips Alaska, Inc. 2F-17 FROM: Matt Herrera KUPARUK RN 11NiT 2F-17 Petroleum Inspector Ste: Inspector Reviewed B: I�� ,y P.L Supry . NON -CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2F-17 API Well Number 50-029-22731-00-00 Inspector Name: Matt Herrera Permit Number: 196-204-0 Inspection Date: 7/12/2020 ✓ Inap Num: mi[MFH2O0714161957 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Miu 45 Min 60 Min Well 217-17 --T Type Inj III W TVD 5631 TLLbing 2730 2730 2720. 2720 PTD 1962040 Type Test SPT Test psi 1500 IA 400 1720 1670 1 1660 BBL Pumped: 0.6 ' BBL Returned: 0.6 OA 45o aso Oso aso Interval 4YRTST Notes: Tuesday, July 21, 2020 Page I of I • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO Jim Regg }� JGi '"I/�, DATE: Monday,August 29,2016 P.I.Supervisor 1 e (511(.0 SUBJECT: Mechanical Integrity Tests l ( CONOCOPHILLIPS ALASKA INC 2F-17 FROM: Johnnie Hill KUPARUK RIV UNIT 2F-17 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry T/e-- NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2F-17 API Well Number 50-029-22731-00-00 Inspector Name: Johnnie Hill Permit Number: 196-204-0 Inspection Date: 7/8/2016 Insp Num: mitJWH160826174017 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2F-17 . Type Inj I1 W-iTVD 5631 - Tubing 2760 , 2700 2675 2690 PTD 1962040 - Type Test SPT Test psi 1500 - IA 850 2015 - 2000 - 1995 • Interval 4YRTST P/F P ✓� OA 190 190 190 190 Notes: SCANNEV JUN 2 3201! Monday,August 29,2016 Page 1 of 1 • ConocoPhiliips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 December 19, 2015 [ 996- 02/°4' af- 17 Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage,AK 99501 SCANNED SEP 2 0 2016 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 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 spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call MJ Loveland or Roger Winter at 907-659-7043 or 943-1055,if you have any questions. Sincere , ,✓ 7 Roger Winter ConocoPhillips Well Integrity Field Supervisor • 0 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations(10-404) Kuparuk Field Date 12/19/2015 1H-17,2F-17&2L-311 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 1H-17 50029223140000 1921300 8" N/A 8" N/A 5.8 12/6/2015 2F-17 50029227310000 1962040 9" NA 9" NA 5.5 12/6/2015 2L-311 50103204690000 2031550 10" NA 10" NA 3.4 12/6/2015 STATE OF ALASKA • r ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate IT Pull Tubing r Operations shutdown r Performed: Perforate Other Stimulate Alter Casing 9 Change Approved Program Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Conductor Extension 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 196-204 l• 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic ( Service ' 50-029-22731-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0035666 • KRU 2F-17 4 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 9561 ' feet Plugs(measured) None true vertical 6396 • feet Junk(measured) None Effective Depth measured 9461 feet Packer(measured) 8703 true vertical 6263 feet (true vertical) 5727 Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 121 121 0 0 SURFACE 3977 10 4019 3136 0 0 PRODUCTION 8937 5.5 8975 5929 0 0 WINDOW L1-02 10 4 9092 6015 0 0 LINER 843 4.563 9561 6396 0 0 Perforation depth: Measured depth: 9038-9048, 9126-9181 , h It . (4,Ci% e:� .;,� True Vertical Depth: 5975-5983,6042-6084 �y���f j.,t ,, `1 r"-~' n �v ,t.,g' !� N.Y ' 1 3 ,/O Tubing(size,grade,MD,and TVD) 3.5, L-80, 8704 MD, 5728 TVD Packers&SSSV(type,MD,and ND) PBR-BAKER W/10'STROKE @ 8703 MD and 5727 TVD No SSSV 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 p Exploratory r Development r Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: . Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG p 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: 315-666 Contact MJ Loveland Email n1878conocophillips.com Printed Name MJ Loveland Title. WI Project Supervisor Signature one:659-7043 Date 11/11/2015 %-�' ‘- 7.;-"7 VTL— i/to/no RBDMSAI,NOV 16 2015 Form 10-404 Revised 5/2015 ,fi /,47 6' Submit Original Only • • ConocoPhillips Alaska Nov 1 3 20!: P.O. BOX 100360 4,„Ar ANCHORAGE,ALASKA 99510-0360 November 11, 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 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well 2F-17, PTD 196-204, Sundry 315-666, conductor extension. Please contact me at 659-7043 if you have any questions. Sincerely, zr'W,/' e_____.------ -- 7 MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • 2F-17 DESCRIPTION OF WORK COMPLETED SUMMARY Date11/11/15 Event Summary 11/10/15 Welded a 9" conductor extension onto conductor due to rising wellhead. 2F-17 DESCRIPTION OF WORK COMPLETED SUMMARY • • F T�ir0 �����j%s� THE STATE Alaska it anal Gas � ®f Conservation Commission '113 :_ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 `Th' Main: 907.279.1433 OFALAS�'� Fax: 907.276.7542 www.aogcc.alaska.gov iCAHOSI NOV 1 7 2015 MJ Loveland 6....,2 0 WI Project Supervisor j ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2F-17 Sundry Number: 315-666 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, e /- I Ps. ck_. Cathy '. Foerster , -- Chair DATED this GO day of October, 2015 Encl. RBDMSN+^0 2 2015 4` 3TM rh V eft STATE OF ALASKA 1PASKA OIL AND GAS CONSERVATION COMMIION 0 r V 2 3 ?5 i=. APPLICATION FOR SUNDRY APPROVALS h s o 4C 20 AAC 25.280 ' 1.Type of Request: Abandon r Plug Perforations E Fracture Stimulate r Pull Tubing r Operations shutdown E Suspend E Perforate r Other Stimulate r Alter Casing r Change Approved r Plug 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 E 196-204' 3.Address: 6.API Number: Stratigraphic r Service F • P.O. Box 100360,Anchorage,Alaska 99510 50-029-22731-00 • 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 F KRU 2F-17 9.Property Designation(Lease Number): �i 10.Field/Pool(s): ADL09358C 2S 66 4 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): 9561 - 6396 " 9461' 6263' • None None Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 121' 121' SURFACE 3977 7.625 4019' 3136' PRODUCTION 8937 5.5 8975' 5929' WINDOW L1-02 10 4 9092' 6015' LINER 843 3.5 9561' 6396' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9038-9048,9126-9181 • 5975-5983,6042-6084 3.5 L-80 8704 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) BAKER FA-1 PRODUCTION PACKER MD=8568 TVD=5631 • BAKER SABL-3 w/LINER HANGER(PACKER) MD=8718 TVD=5738 NO SSSV 12.Attachments: Description Summary of Proposal F 13. Weil Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory E Stratigraphic r Development r Service 14.Estimated Date for Commencing Operation: 11/5/2015 15. Well Status after proposed work: OIL r WINJ r WDSPL E Suspended r 16.Verbal Approval: Date: GAS E WAG F - 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 Email: n1878( conocophillips.com Printed Name MJ Loveland Title: WI Project Supervisor Signature Phone:659-7043 Date 10/20/15 Commission Use Only Sundry Number: (5-(6, Conditions of approval: Notify Commission so that a representative may witness JJJ Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance [— Other:Other: Spacing Exception Required? Yes 0 No II' Subsequent Form Required: J c% ____4_ 4_ APPROVED BY Approved by: t 29..e.,,,,4----- COMMISSIONER THE COMMISSION Date: /0- 2,— p�■�c ((J� ?? Approved application is valid for 12 months from the date of a]h'nproval. Submit Form and Rl11� �ed S/2 190 �� �'s`Attachments in Duplicate ORIGINAL . (K�%— . • • . IIIPV • • ConocoPhillips RECEIVED Alaska OC1 2 31 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC October 20, 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 2F-17, PTD 196-204 conductor extension. Please contact MJ Loveland at 659-7043 if you have any questions. Sincerely, 7 MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 ConocoPhillips Alaska,Inc. Kuparuk Well 2F-17 (PTD 196-204) SUNDRY NOTICE 10-403 APPROVAL REQUEST October 20, 2015 This application for Sundry approval for Kuparuk well 2F-17 is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to the surface. At some point during normal operations the conductor subsided about 9". 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. 4. File 10-404 with the AOGCC post repair. NSK Well Integrity Projects Supervisor �[�1. KUP INJ 2F-17 ~ Conoc PhiIIips Well Attributes Max Angle&MD TD •. Alaska Inc Wellbore APIIUWI Field Name Wellbore Status ncl I°) MD(ftKB) Act Btm(ftKB) Lon6in,,,,� 500292273100 KUPARUK RIVER UNIT INJ 60.13 7,900.00 9,561.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date DEVIATED-2F-17,4/24/2014 3:37:08 PM SSSV:NIPPLE Last WO: 5/152013 2/5/1997 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ,,,,, ....... ., _.. Last Tag:SLM 9,075.0 3/1012014 Rev Reason:to correct icon lehallf 4/242014 HANGER 27.8-IL e • Casing Strings Casing Description OD lin) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread 11 IT CONDUCTOR 16 15.062 43.0 121.0 121.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I..Grade Top Thread SURFACE 75/8 6.750 41.3 4,018.5 3,136.0 29.70 L-80 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ..A/CONDUCTOR;43x121.0- !. A....n.PRODUCTION 512 4.767 38.6 8,975.4 5,929.4 15.50 L-80 LTC-MOD Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread WINDOW L1-02 4 3.000 9,082.0 9,092.0 6,015.8 NIPPLE;492.5 -, Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread LINER 31/2 2.867 8,718.0 9,560.5 6,396.0 9.20 L-80 BTC Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl I') Item Des Com (in) 8,718.0 5,738.4 40.70 PACKER BAKER SABL-3 w/LINER HANGER 2.867 Tubing Strings Tubing Description !String Ma...)ID(in) !Top(ftKB) I Set Depth(ft..J Set Depth(ND)(...I Wt(Ib/ft) (Grade )Top Connection TUBING WO 31/2 2.992 27.8 8,56301 5,6282 930 L-80 IBT GAS LIFT;3,004.6 Completion Details Nominal ID C- Top(ftKB) Top(ND)(ftKB) Top Incl(3 Item Des Com (in) ), ' 27.8 27.8 0.00 HANGER FMC TC-1A-EN,6 x 3-1/2" 2.992 F, 492.5 492.5 0.49 NIPPLE CAMCO 2.875"DS NIPPLE 2.812 8,550.2 5,619.9 49.39 SEAL ASSY BAKER GBH-22 LOCATOR/804-0 SEAL ASSEMBLY 3.000 # Tubing Description l String Ma...l ID(in) "Top(RKB) (Set Depth(ft..l Set Depth(ND)(...I Wt(Ib/ft) !Grade )Top Connection PACKER/PBR ASSY 4 3.000 8,554.01 8,56801 5,631.6 SURFACE;41.3-4,018 5 • ' Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (n) GAS LIFT;5,403.5 8,554.0 5,622.3 49.20 PBR BAKER w/10'Stroke 3.000 Tubing Description String Me...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection STACKER PACKER 3 1/2 2.992 8,567.7 8,715.0 5,736.1 9.30 L-80 EUE 8rd � Completion Details GAS LIFT;6.844.4 1/..-.. Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (m) 8,567.7 5,631.4 48.48 PACKER BAKER FA-1 PRODUCTION PACKER 3.630 8,651.9 5,689.5 44.18 NIPPLE CAMCO 2.813'X'NIPPLE 2.812 GAS LIFT;7,796.1 8,703.9 5,727.7 41.22 SEAL ASSY BAKER GBH-22 TOP BONDED SEAL ASSEMBLY 2.990 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.), Top(TVD) Top Incl Top(ftKB) (ftKB) (3 Des Com Run Date ID(in) GAS LIFT;8,498.7 ( 9,082.0 6,0082 41.12 WHIPSTOCK WHIPSTOCK FOR L1-02 THAT COMES OFF THE 5/5/2013 MAIN WELLBORE 1 - Perforations&Slots I Shot Dens SEAL ASSY;8,550.2, Top(ND) Btm(ND) (shots/f PER;8,554.0 'me Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 9,038.0 9,048.0 5,975.3 5,982.8 C-4,UNIT B, 82/1997 6.0 )PERF 60 deg.Phasing;2.5" 2F-17 HSD DP PACKER;8.567.7 9,126.0 9,136.0 6,041.7 6,049.3 A-5,2F-17 8/2/1997 6.0 )PERF 60 deg.Phasing;2.5" IX HSD DP 9,164.0 9,181.0 6,071.0 6,084.3 A-4,2F-17 5/6/1997 4.0 IPERF 180 deg.Phasing;2.5" HSD BH NIPPLE,8,651.9 Mandrel Inserts t 1 at ti on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com SEAL ASSY;8,703.9, _ 1 3,004.6 2,594.2 Camco KBG-2- 1 GAS LIFT DMY BTM 0.000 0.0 4/12/2014 PBR;8,704.0 9 2 5,403.5' 3,892.5 Camco KBG-2- 1 GAS LIFT DMY BTM 0.000 0.0 4/12/2014 ANCHOR;8,717.4 'i Irl[(. _ 9 3 6,844.4 4,681.2 Camco KBG-2- 1 GAS LIFT DMY BTM 0.000 0.0 4/12/2014 �• 9 4 7,796.1 5,184.3 Camco KBG-2- 1 GAS LIFT DMY BTM 0.000 0.0 4/15/2014 9 5 8,498.7 5,586.3 Camco KBG-2- 1 GAS LIFT DMY INT 0.000 0.0 5/12/2013 9 Notes:General&Safety PRODUCTION;38.6-8,975.4 End Date Annotation 10/14/2010 NOTE:View Schematic w/Alaska Schematic9.0 !PERF;9,038.0-9,048.0 6/13/2013 NOTE:ADD LATERALS L1,L1-01,L1-02(off main wellbore) % LINER L1-02 (off wellbWH;WHIPSTOCK.;9,082.0- WINDOW L1-02;,082.0, WINDOW L7-02;9,082.0- 9,092.0 I IPERF;9,126.0-9,136.0 IPERF;9.164.0-9,181.0 LINER;8,718.0-9,560.5 • • 2cQ2sq WELL LOG TRANSMITTAL DATA LOGGED q/Z2 2015 k.BENDER To: Alaska Oil and Gas Conservation Comm. August 19, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Injection Profile : 2F-17 , ^ Run Date: 8/3/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2F-17 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-22731-00 Injection Profile 1 Color Log 50-029-22731-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. SCONE, Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: m.,442.4",..04/7) 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. File Number of Well History File PAGES TO DELETE RESCAN n Color items - Pages: [] GraYScale, halftones, pictures, graphs, charts. Pages: [] Poor Quality Original- Pages: [] Other - Pages: DIGITAL DATA [] Diskettes, No. Other, No/Type -OVERSIZED .Logs of various kinds [] Other COMMENT~: Complete TO RE-SCAN Notes: m... ¢' .. .-, ,,., ,.,, ,~, ,.i htr- ,-,..,...,.~ ua,~,.~ n=mth~ Nnlt~n Lowell ' Date: „,,(4.&\1//7,,' ts` THE STATE .fitz2.1.a C _t, au'. � Ca . �� .. "•ir _ ----,e43. 2 ��.1 a r. J'J \_„j;;. !U :_ i 333 West Seventh Avenue u ”" Ji ()OV ERNOR SI.AN PARNELI Anchorage, Alaska 9950! 3572 ' '' Main: 907 2'79 1433 ods ' -4zAs,' ,,ox. 907.276.7 42 Darrell R. Humphrey SCANNED JUL 3 U 2014: NSK Production Engineering Specialist ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2F-17 6 -czo V. Sundry Number: 314-148 Dear Mr. Humphrey: 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, - P:751// -- Cathy P. oerster Chair LL DATED this 4' day of April, 2014. Encl. STATE OF ALASKA RECEIVED • AL .A OIL AND GAS CONSERVATION COMMIS_ APPLICATION FOR SUNDRY APPROVALS MAR 1 1 2014 20 AAC 25.280 OTs S 4-1.4-1 a 3 1.Type of Request Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Approvecg AWC Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r Other: Prod to WINJ Fit 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development G✓. 196-204 ' 3.Address: Stratigraphic r Service 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-029-22731-00 - 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 WI • t 2F-17 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25666 . 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 ND(ft): Plugs(measured): Junk(measured): 9561 • 6396 • 9461' + 6263' ' None None Casing Length Size MD ND Burst Collapse CONDUCTOR 78 16 • 121' 121' SURFACE 3977 104Q19'i. 3136' !�' . PRODUCTION 8937 5.5 8975' 5929' LINER 843 4.563 9561' 6396' Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9038-9048,9126-9136,9164-9181 5975-5983,6042-6049,6071-6084 • 3.5 L-80 8704 Packers and SSSV Type:SSSV=None Packers and SSSV MD(ft)and ND(ft) SEAL ASSY-BAKER GBH-22 LOCATOR/804-0 SEAL ASSEMBLY• MD=8550 TVD=5620 PBR-BAKER W/10'STROKE • MD=8554 ND=5622 PACKER-BAKER FA-1 PRODUCTION PACKER , MD=8568 TVD=5631 NIPPLE-CAMCO 2.813'X'NIPPLE ' MD=8652 TVD=5689 PBR-BAKER W/10'STROKE ' MD=8703 ND=5727 NIPPLE-CAMCO 2.875"DS NIPPLE . MD=493 TVD=493 12.Attachments: Description Summary of Proposal • p-; 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r- Exploratory r Stratigraphic r Development r Service g—,- 14. - 14.Estimated Date for Commencing Operations: 15. Well Status•after proposed work: 3/20/2014 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ (i!. GINJ r WAG r Abandoned r Commission Representative: .-,•• GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob Christensen/Darrell Humphrey Email: n1139Aconocophillips.com Printed Name Darrell R. Humphrey Title: NSK Production Engineering Specialist Signature Phone:659-7535 Date 3.g. Commission Use Only RBDMS MAY 10 2014 Sundry Number: \�� Conditions of approval: Notify Commission so that a representative may witness 1\q"1--(51 Plug Integrity r BOP Test r Mechanical Integrity Test VLocation Clearance r Other. f-� ,tt tv► f n7 5 5 2- d /1/1 1 T- JA c'�lc�viiltd 0t, {f 5 t4 bf it 3-1-of lktf CTL� Spacing Exception Required? Yes 0 No 2( Subsequent Form Required: /Q — ,) L� d✓ ae APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 1--1--/3 Approved application is valid for 12 months from the date of approval. Form 10-403(Revised 10/2012) ORIGINAL ,7/4 3/II'rf Submit Form and Attachments in Duplicate ki-rx-/311 LI- 2F-17 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert Kuparuk Well 2F-17 and its associated laterals from Oil Production service to Water Injection service. The CTD Permit to Drill (which added multi-laterals L1, L1- 01, L1-02)was completed with the well as an injection well, but the completion report was filed as an oil producer to allow for extended pre-production. The pre-production period following CTD operations has now been completed and the well is being prepared for initial water injection. w RECEIVED Robert Christensen/Darrell Humphrey MAR I 1 2014 Production Engineering Specialists. Greater Kuparuk Unit,NSK-69 PO Box 196105 ConocoPhu l l i PS AOGCC Anchorage,AK 99519-6105 Phone:(907)659-7535 Fax:659-7314 March 8, 2014 Dan Seamount AOGCC Commissioner State of Alaska, Oil & Gas Conservation Commission 33 W. 7th Ave. Ste. 100 Anchorage, AK 99501 Dear Mr. Seamount, ConocoPhillips Alaska, Inc. requests approval to convert Kuparuk River Unit wells 2F-17, 2F-17L1, 2F-17L1-01 and 2F-17L1-02 from Oil Production to Water Injection service. Enclosed you will find 10-403 Application for Sundry Approval for Co coPhilli s Alaska, Inc. regarding 2F-17, 2F-17L1, 2F-17L1-01 and 2F-17L1-02 (PTD 196-204) 213-058, 213-059, 213-060). If you have any questions regarding this matter, please contact myself or Bob Christensen at 659-7535. Sincerely, Darrell Humphrey Attachments Sundry application Well schematic •. • KUP 2F-17 V,---.--' ConocoPhillips F" Well Attributes Max Angle&MD TD AfaSka k1e Wellbore API/UWI Field Name Well Status Incl(°) MD(EKE) Act BM,(RKB) ... . _ 500292273100 KUPARUK RIVER UNIT SVC . 60.13 7,900.00 9,561.0 cmomFmwpt Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date •• Well Conk; 2f47.713/201395409AM SSSV:NIPPLE Last WO: _5/152013 2/5/1997 Schematic-Actual Annotation Depth(RKB) End Date Annotation Last Mod...End Date Last Tag:SLM 9,175.0 5/18/2013 Rev Reason:GLV C/O,PULL CATCHER haggea 7/3/2013 HANGER,28---- [ . :I Casing Strings Casing Description String 0... String ID...Top(EKE) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR 16 15.062 43.0 121.0 121.0 62.50 H-40 WELDED Casing Description String 0... String ID...Top(EKE) Set Depth(f...Set Depth(ND)...String Wt..String...String Top Thrd SURFACE 75/8 6.750 41.3 4,018.5 3,136.0 29.70 L-80 BTC Cuing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...S41ng Wt..String...String Top Thrd PRODUCTION 512 4.767 38.6 8,975.4 5,929.5 15.50 L-80 LTC-MOD CONDUCTOR, Casing Description String 0... String ID...Top(ftK8) Set Depth(f...Set Depth(TVD).. String Wt..String...String Top Thrd 43 121 .WINDOW 11-02 4 3.000 9,082.0 9,092.0 6,015.8 Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top Thrd NIPPLE,493 I LINER 31/2 2.867 8,718.0 9,560.5 6,396.0 9.20 L-80 BTC Liner Details . Top Depth (ND) Top Incl Komi... Top(EKE) (RKB) (°) Item Description Comment ID(In) 8,718.0 5,738.5 40.70 PACKER BAKER SABL-3 w/LINER HANGER 2.867 ' Tubing Strings Tubing Description String 0... String ID...Top(MB) Set Depth(I...Set Depth(TVD)...String Wt...String...String Top Thrd GAS LIFT. - TUBING WO 31/2 2.992 27.8 8,563.0 5,628.7 9.30 L-80 IBT 3,005 Completion Details • Top Depth (TVD) Top Incl Noml... Top(RKB) (RKB) (°) Item Description Comment ID(In) 27.8 27.8 -0.04 HANGER FMC TC-IA-EN,6 x 3-1/2' 2.992 492.5 492.5 0.36 NIPPLE CAMCO 2.875"DS NIPPLE 2.812 8,550.2 5,620.7 49.34 SEAL ASSY BAKER GBH-22LOCATOR/804-0 SEAL ASSEMBLY 3.000 SURFACE, Tubing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd 4t-4,018 -'� PACKER/PBR ASSY 4 3.000 8,554.0 8,568.0 5,631.9 Completion Details GAS LIFT,_ I Top Depth 5,40:1 (TVD) Top Incl Nomi... Top(R103) (RKB) (°) Item Description Comment ID(in) 8,554.0 5,623.0 49.15 PBR BAKER w/l0'Stroke 3.000 GAS LIFT_ E Tubing Description String 0... String ID...Top(MB) Set Depth(I...Set Depth(TVD)...String Wt...String...String Top Thrd 6,844 -- STACKER PACKER 3 1/2 2.992 8,567.7 8,715.0 5,736.1 9.30 L-80 EUE 8rd Completion Details Top Depth (TVD) Top Incl Nomi... GAS LIFT,_ _ Top(ftKB) (ftK8) 1") Item Description Comment ID(in) 7'796 8,567.7 5,631.7 48.45 PACKER BAKER FA-1 PRODUCTION PACKER 3.630 8,651.9 5,689.7 43.11 NIPPLE CAMCO2.813'X'NIPPLE 2.812 { 8,703.9 5,727.7 41.22 SEAL ASSY BAKER GBH-22 TOP BONDED SEAL ASSEMBLY 2.990 GAS LIFT,_ _ [. 5,4ss Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top Depth (TVD) Top not Top(MKS) (RKB) C) Description Comment Run Date ID(in) SEAL ASSY, 9,082.0 6,008.3 41.26 WHIPSTOCK WHIPSTOCK FOR L1-02 THAT COMES OFF THE MAIN 5/52013 PSR.8,5554� ( WELLBORE Perforations&Slots PACKER,8,568 Dens Top(ND) Btm(TVD), Dens Top(ftK8)Stm(RKB) (ftK8) (RKB) Zona Date (ah••. Type Comment 9,038.0 9,048.0 5,975.4 5,982.8 C-4,UNIT B, 82/1997 6.0IPERF 60 deg.Phasing;2.5"HSD DP 2F-17 NIPPLE,8,652----- 9,126.0 9,136.0 6,041.7 6,049.4 A-5,2F-17 82/1997 6.0 IPERF 60 deg.Phasing;2.5"HSD DP 9,164.0 9,181.0 6,071.4 6,084.4 A-4,2F-17 5/6/1997 4.0 IPERF 180 deg.Phasing;2.5"HSD BH Notes:General&Safety SEAL ASSY. End Date Annotation PER.s:ia\ - 10/14/2010 NOTE:View Schematic w/Alaska Schematic9.0 - 6/132013 NOTE:ADD LATERALS L1,L1-01,11-02(off main wellbore) - ANCHOR, 8.717 PRODU39-8,97CTION5, IPERF, 0,1, i tf 9038-9,048 rte' WHIPSTOCK 9,082 NANDOW Mandrel Details 9,0829 l B-02, 111 Top Depth Top Port S... (TVD) Incl OD Valve Latch SW TRO Run IPERF, - I N...Top(RKB) (EKE) (") Make Model (in) Seen Type Type PM (psi) Run Date Com... 9,126-9,1361 I 1 3,004.6 2,594.2 58.68 Camco KBG-2-9 1 GAS LIFT GLV BTM 0.156 1,299.0 6/26/2013 IPERF, 9,16441,181\ 2 5,403.5 3,892.8 54.83 Camco KBG-2-9 1 GAS LIFT GLV BTM 0.313 1,328.0 6/26/2013 8,718855661 3 6,844.4 4,681.2 56.64 Camco KBG-2-9 1 GAS LIFT GLV 'BTM 0.188 1,316.0 6/26/2013 TD(9, , 4 7,796.1 5,184.3 58.89 Comm KBG-2-9 1 GAS LIFT OV BTM 0.250 0.0 6252013 9,174.1077884 5 8,498.7 5,586.3 49.43 Camco KBG-2-9 1 GAS LIFT DMY INT 0.000 0.0 5/12/2013 SLOTS, 9,559-11,494 LINER L1.02 (off main 1 wellbore), 9,076-10,784 LINER L1.01 4111 , (of L1.02), 9,550.12,981 Kuparuk Well 2F-17 Conversion from Production to Water Injection Area of Review Well Summary Kuparuk well 2F-17 was drilled in 1997, approximately 13 years after initial drillsite 2F Kuparuk, to exploit A4 and A5 sand targets on the southern flank of the Kuparuk field. The well was completed as a Kuparuk AC sand producer over the interval of 9,038' MD to 9,181' MD. It was initially produced fora period of six months, during which time it produced a total of 31 MBO, before being converted to injection in order to support the neighbouring well 2F-18, which was drilled in the same time period. Well 2F-17 was a water injector from December 1997 to June 2012. In June 2013, three laterals were drilled from well 2F-17 in the A4 and A5 sands with coiled tubing from a whipstock located at 9,082' MD. All three laterals were completed with slotted liners. The well was pre- produced before being shut in February 22, 2014, having produced 80 MBO, for a well lifetime total production of 111 MBO. Converting well 2F-17 to injection will provide water injection support to the offset Kuparuk producers 2G- 11 and 2F-18. Below, the Area of Review includes a description of the following: • Map with 1/4 mile radius shown around the target injection zone; • 2F-17, 2F-17L1, 2F-17L1-01, 2F-17L1-02 wellbore schematics; • The mechanical condition of the proposed injection well; and • 2F-17 CBL and interpretation of the cement quality of the subject well Area Map with 1/4 mile radius around target injection zone Kuparuk well 2F-17 is located in the Southwest quadrant of the drillsite 2F Kuparuk development. The map attached shows that there are no other wells located within a 1/4 mile radius of the 2F-17 penetration of the Kuparuk A and C sands. Kuparuk well 2F-17 Wellbore Schematic Kuparuk well 2F-17 was completed with a single completion having a 3-1/2" 9.2Ib/ft L-80 liner by 5-1/2" 15.5lb/ft L-80 production casing. The surface hole was completed with 7-5/8"29.7lb/ft L-80 casing. 2F-17 was originally perforated over the AC sand interval of 9,038' MD to 9,181' MD. The three coiled tubing laterals drilled in June 2013 were completed with 2-3/8"4.7lb/ft L-80 slotted liner. The top of the Kuparuk C-sand was encountered at 9,038' MD, and the top of the Kuparuk A sand was encountered at 9,105' MD. The schematics for 2F-17, 2F-17L1, 2F-17L1-01, and 2F-17L1-02 are attached. Mechanical Condition of Well to be Converted to Injection and MIT History (2F-17) The mechanical condition of Kuparuk well 2F-17 is good. The well is classified as a"Normal Well", meaning that the historical MIT-T and MIT-IA tests have passed. The most recent MIT-T was tested to 3500psi on May 9, 2013. The most recent MIT-IA was tested to 2500psi on May 12, 2013. A State-witnessed MIT-IA will be performed once well 2F-17 is converted to water injection, online, and stabilized. 2F-17 CBL and interpretation of the cement quality of the subject well (no other wells are located within 1/4 mile radius) Well 2F-17 is located in an injector row in the drillsite 2F development. Although the well was pre- produced after initially being drilled, and again after the three laterals 2F-17L1, 2F-17L1-01, 2F-17L1-02 were drilled, it has been an injector for the majority of its life. 2F-17 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert Kuparuk Well 2F-17 and its associated laterals from Oil Production service to Water Injection service. The CTD Permit to Drill (which added multi-laterals L1, L1- 01, L1-02)was completed with the well as an injection well, but the completion report was filed as an oil producer to allow for extended pre-production. The pre-production period following CTD operations has now been completed and the well is being prepared for initial water injection. ti + • c.i... -• 2F-01 0 2F-02 . •�2B-04 &..... 2F,08 • .. .. ! / . 2 4110 2F-20 ..... •2G-06 ,2F=16 •' . 09 �2F-15 .2F • .....r•2G-08 2F-13 • 2F-14 0 •'F-12 • 2 2G • .. •2F-17 : +F-18PB1 2G-09 2F-18 • FF}• ;:2 12F- •PB1 12F-17L1-02 �2F-18L1-01 2F-19AL2 • • «2F-19AL3 IG 2G-11 \ ? N• •2F-18L1-02 2F-19AL1 2F-17L1-01 • 2F-17L1 ••A 2G-11AL2PB1 42F-18L1 Legend 2G-11 APB1 Well Types A ACTIVE,INJ,SW / A ACTIVE,INJ,GAS ACTIVE,INJ,MG \\ A ACTIVE,INJ,PW • ACTIVE,PROD,OIL/GAS 2G-11AL1-01 A ACTIVE,INJ,DG G-11 Q ACTIVE INJ,MWAG G-11AL1 ' ACTIVE INJ,IWAG 2G-14•NL2 • ACTIVE,DISP/SERVICE pteit•2G-1fLl-01����� + OPSH/SUSP ▪ P+A p 1/4 Mile Radius 2G-17 ConocoPhillips 0 Alaska,Inc. 2F-17 Convert to Injection 111111111111111111111111111111111111111111 1/4 Mile Radius Evaluation N Ao o.,a oa os l 2F-17MWAG-swap.mod CSR 3/11/2014 2F-17i Final CTD Laterals Last Updated:6/12/13 i ,. , 16"62#H-40 shoe 3-1/2"Camco D nipple @506' MD @121'MD ) i -- -— - 3-1/2"9.3#L-80 EUE 8rd Tubing to surface 3-1/2"Camco MMG gas lift mandrels @ 3018',5417',6858',7810'&8512' 7-5/8"29.7#L-80 J 3-1/2"x 5-1/2"FA packer(3.0"ID)@ 8568' RKB shoe @ 4019'MD I — 3-1/2"Camco X landing nipple @ 8652' RKB(2.813"min ID) -,,,.,,� Baker 3-1/2"PBR @ 8703'RKB(3"ID) Baker KBH-22 Anchor-seal nipple(3.0"ID)@ 8717'RKB .1,, 10.911.:2) 1.� Baker SABL-3 liner top packer/hanger @ 8718'RKB 5-1/2"15.5#L-80I (min ID 2.78") shoe @ 8975'MD — ..— 1 I C-sand perfs 9038' 3-1/2"monobore -9048'MD - - whipstock 2F-17L1-02 TD=10784'MD 2F-17L1-01 TD=12981'MD Liner:9075'-10784'MD Liner 9550'-12981'MD KOP @ 9082'MD 0�I f \\ Liner top @ 9075'MD Liner billet @ 9550'MD C 3. 0"OH 9082'- 10784'MD 3.25"OH 9082'- 11005'MD \\ 3.00"OH 11005'- 12981'MD A-sand perfs 9126' _ - \\ — ./..:Z------ _ --_- 9181'MD .. -- 2F-17L1 TD=13375'MD 3-1/2"9.3#L-80 Liner:1096T-13028'MD shoe @ 9560'MD _�� Anchor billet @ 10697'MD 3.25"OH 9082'- 12744'MD The cement job on the 5-1/2"casing was completed on February 4, 1997. No cement bond log was run. Per the cementing details report, 120 sacks of G-class cement at a yield of 1.15ft3/sack was pumped at 3.3bpm. Calculated top of cement(assuming 30%excess factor)is 8,418' MD,which provides more than 500'of isolating cement between the top of cement and the casing shoe at 8,932' MD. (These measured depths reference the original 1997 schematic depths,which has the 5-1/2"casing shoe at 8,932' MD.) From the drilling report of February 4, 1997: Flush lines w/5 bbl water. Test to 3500 psi. Pump 10 bbl preflush, 50 bbl 11.0#spacer, drop plug, 24 bbl(120 sx) 15.8 slurry, drop plug. Displace w/5 bbl water, 48 bbl diesel and 156 bbl water. Did not bump plug. Hole started packing off when slurry went around shoe. CIP @ 2014 hrs. Calculated top of cement as follows: • Total displacement of cement=5 bbl (water)+48 bbl(diesel)+ 156 bbl(water)=209 bbls • Shoe depth= 8,932' MD • Casing capacity of 5-1/2" 15.51b/ft casing to shoe=8,932'*0.022075 bbl/ft= 197.2 bbls • Cement displaced into annulus=209 bbls— 197.2 bbls= 11.8 bbls • Height of 11.8 bbls of cement in the annular space between 6.75"hole and 5-1/2" 15.51b/ft casing assuming 35%excess factor (11.8bbl*1 0.651 6��ft l_514 ft • Calculated top of cement=8,932' MD—514'of cement=8,418' MD In addition to the 5-1/2"casing cement job,the 3-1/2"liner was cemented on March 24, 1997.A cement bond log of the 3-1/2"liner cement job was performed on May 1, 1997.The cement bond log shows good cement from the bottom of the log at 9,445' MD up to 8,720' MD, including the overlap between the 3-1/2" liner and 5-1/2"casing from 8,932' MD to 8,720' MD. 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' JH• 1 i 'I' I ' HMI Ilill I I ill i ' HI 1111111U II I I 1 .: _,_ ._... .• J 1 ( 1 i II I ihr in 1 , ii ! iltHilill ill Hii 1 im—liwiwou II 1 i 7 . 1- 1 i 1 i i Iii Ji _LA Hr , 1 - , ..cf: . F_ , • . . _ ,, - _ _ ._. . ,_ . ....__ ,. -,_- .,,.... .., .______ __._-_, ,___ ______ _____. . . . . -, - STATE OF ALASKA • • , ALA.OIL AND GAS CONSERVATION COMMIOON REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r Rug Perforations r Perforate r Other Inj to Prod>30 days Alter Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extension r Change Approved Program rOperat.Shutdow n r Stimulate-Other Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 196-204 3.Address: 6.API Number: Stratigraphic r Service 50-029-22731-00 P.O. Box 100360,Anchorage,Alaska 99510 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25666 2F-17 - 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 9561 feet Plugs(measured) none true vertical 6396 feet Junk(measured) none Effective Depth measured 9461 feet Packer(measured) 8550, 8554,8568, 8652, 8703 true vertical 6263 feet (true•vertical) 5620, 5622,5631, 5689, 5727 Casing Length Size MD ND Burst Collapse CONDUCTOR 78 16 121 121 0 0 SURFACE 3977 10 4019 3136 0 0 PRODUCTION 8937 5.5 8975 5929 0 0 LINER 843 4.563 9561 6396 0 0 0 0 0 0 0 0 Perforation depth: Measured depth: 9038-9048,9126-9136,9164-9181 True Vertical Depth: 5975-5983,6042-6049,6071-6084 P 2 4 201'i Tubing(size,grade,MD,and TVD) 3.5, L-80,8704 MD,5728 TVD 0 "^C",.." Packers&SSSV(type,MD,and TVD) SEAL ASSY-BAKER GBH-22 LOCATOR/804-0 SEAL ASSEMBLY @ 8550 MD and 5620 ND PBR-BAKER W/10' STROKE @ 8554 MD and 5622 TVD PACKER-BAKER FA-1 PRODUCTION PACKER @ 8568 MD and 5631 TVD NIPPLE-CAMCO 2.813'X NIPPLE @ 8652 MD and 5689 TVD PBR-BAKER W/10'STROKE @ 8703 MD and 5727 ND 12.Stimulation or cement squeeze summary: r �1 c NOV Intervals treated(measured): SCANNED NO 18 2013 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 0 0 1235 400 1190 Subsequent to operation 534 288 2951 1368 195 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development F,7 Service r Stratigraphic r 16.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations X GSTOR r WIND r 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 N/A Contact Bob Christensen/Darrell Humphrey Email n1139(aconocophillips.com Printed Name Darrell R. H mphrey Title NSK Production Engineering Specialist Signature ^_��. Phone:659-7535 Date "f 2,O ` l� 3 '� w � d%* Submit Original Only Form 10-404 Revised 10/2012 1/71--� ! ��� RB[�i1A� OCT �1 4 ./ //3-1/3 • • , 2F-17 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 08/23/13 Convert to Producer(pre-produced water injector> 30 days) e KUP 2F-17 ConocoPhillips "41 Well Attributes Max Angle&MD TD (IX' Wellbore API/UWI Field Name Well Status Inc!(°) I MD(ftKB) Act Btm(ftKB) canoao 500292273100 KUPARUK RIVER UNIT ISVC 60.13 7,900.00 9,561.0 '"' Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date •-- SSSV:NIPPLE Last WO: 5/15/2013 2/5/1997 Well Config_-2F-17.7/3/20139.54 09 AM Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag:SLM 9,175.0 5/18/2013 Rev Reason:GLV C/O,PULL CATCHER haggea 7/3/2013 HANGER,28 i ' Casing Strinn_gs Casing Description String 0... String ID Top(ftKB) Set Depth(f...Set Depth(TVD) String Wt...String... String Top Thrd 1 CONDUCTOR 16 15.062 43.0 121.0 121.0 62.50 H-40 WELDED als Casing Description String 0... String ID...Top(ftKB) Set Depth(L..Set Depth(ND)...String Wt...String...String Top Thrd II 75/7 SURFACE 1117 CONDUCTOR, 8 6.750 41.3 4,018.5 3,136.0 29 70 L-80 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd PRODUCTION 51/2 4.767 38.6 8,975.4 5,929.5 15.50 L-80 LTC-MOD Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd 43"121 WINDOW L1-02 4 3.000 9,082.0 9,092.0 6,015.8 it Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd NIPPLE,493 BE LINER 1 31/2 2.867 8,718.0 9,560.5 6,396.0 9.20 L-80 BTC alr, OW Details ___ Top Depth € (ND) Top Intl Nomi...i Top(ftKB) (MB) (0 Item Description Comment ID(in) 8,718.0 5,738.5 40.70 PACKER BAKER SABL-3 w/LINER HANGER 2.867 Tubing Strings Tubing Description String 0... String ID...Top(960) Set Depth(f...Set Depth(TVD)...String Wt...I String... String Top Thrd GAS LIFT, TUBING WO 31/2 2.992 27.8 8,563.0 5,628,7 9.30 1, L-80 IBT nos ------ .: alt Completion Details 4t> •c1 Top Depth (TVD) Top Intl Nomi... Top(ftKB) (ftKB) (°) Item Description Comment 10(in) 27.8 27.8 -0.04 HANGER FMC TC-1A-EN,6 x 3-12" 2.992 492.5 492.5 0.36 NIPPLE CAMCO 2.875"DS NIPPLE 2.812 8,550.2 5,620.7 49.34 SEAL ASSY BAKER GBH-22 LOCATOR/804-0 SEAL ASSEMBLY 3.000 SURFACE, ■ Tubing Description String 0... String ID...Top(968) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd 41-4,018 PACKER/PBR ASSY 4 3 000 8,554.0 8,568.0 5,631.9 1111 Completion Details _ GAS LIFT, ' Top Depth Nomi... 5,403 (ND) Top Inc' Top(ftKB) (ftKB) (°) Item Description Comment ID(In) 8,554.0 5,623.0 49.15 PBR BAKER w/10'Stroke 3.000 IIII GAS LIFT Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd 6,844 + STACKER PACKER 3 1/2 2.992 8,567.7 8,715.0 5,736.1 9.30 L-80 EUE 8rd R( ) Details 19 Completion Det Top I I Nomi... Top Depth GAS LIFT, _ Top ftKB (ftKB) () Item Description Comment ID(in) 7,796 8,567.7 5,631.7 48.45 PACKER BAKER FA-1 PRODUCTION PACKER 3.630 ri 8,651.9 5,689.7 43.11 NIPPLE CAMCO 2.813'X'NIPPLE 2.812 8.703.9 5,727.7 41.221SEAL ASSY BAKER GBH-22 TOP BONDED SEAL ASSEMBLY 2.990 GAS LIFT, 8,499 Other In Hole(Wireline retrievable plugs,valves, rah" s,fis l�;'etC.) ---Top Depth (TVD) Top Intl ■ Top(ftKB) (ftKB) (0 Description Comment Run Date ID(in) SEAL ASSY. 9,082.0 6,008.3 41.26 WHIPSTOCK WHIPSTOCK FOR L1-02 THAT COMES OFF THE MAIN 5/52013 8,5501 _ PIM WELLBORE PBR,8,554 Perforations 8,Slots -w Shot PACKER,8,566 Top(ND) Btm(TVD) Dens ar Top(ftKB)Btm(ftKB) (ftKB) (ftKB) Zone Date (oh... Type Comment Mt 9,038.0 9,048.0 5,975.4 5,982.8 C-4,UNIT B, 82/1997 6.0 IPERF 60 deg.Phasing;2.5"HSD DP 2F-17 NIPPLE,8,652 - OR 9,126.0 9,136.0 6,041.7 6,049.4 A-5,2F-17 8/2/1997 6.0 IPERF 60 deg.Phasing;2.5"HSD DP MI MI 9,164.01` 9,181.0 6,071.4 6,084.4 A-4,2F-17 5/6/1997 4.0 IPERF 180 deg,Phasing:2.5"HSD BH Notes:General&Safety SEAL ASSY, End Date 1 Annotation 6704_-__ 10/14/2010 NOTE:View Schematic w/Alaska Schematic9.0 PBR,8,704 -- 6/13/2013 NOTE:ADD LATERALS L1,L1-01,L1-02(off main wellbore) ANCHOR, 8,717 PRODUCTION, 39.8,975 IPERF, HEE STATE OF ALASKA` ± a, ALIA OIL AND GAS CONSERVATION COM•ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon F ` Repair w ell f- Plug Perforations f Perforate 3 Other r 4i. ,-, ( E Alter Casing I - Rill Tubing f✓ Stimulate - Frac ( - - Waiver F Time Extension ` f - , 0 f `' - - -I Change Approved Program f Operat. Shutdow n r Stimulate - Other im Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. • Development r Exploratory E _ 196 -204 - 3. Address: 6. API Number: Stratigraphic jµ" Service IW 50 - 029 - 22731 - P. O. Box 100360, Anchorage, Alaska 99510 • 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25666 2F -17 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): none Kuparuk River Field / Kuparuk River Oil Pool • 11. Present Well Condition Summary: Total Depth measured 9561 ' feet Plugs (measured) 8739 true vertical 6336 feet Junk (measured) none Effective Depth measured 9461 feet Packer (measured) 8568, 8715, 8718 true vertical 6263 feet (true vertical) 5632, 5736, 5738 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 121 121 SURFACE 3977 7.625 4018 3136 PRODUCTION 8937 5.5 8975 5930 LINER 842 3.5 9561 6396 Perforation depth: Measured depth: 9038 - 9048, 9126' - 9136, 9164 - 9181 `� i 13 True Vertical Depth: 5975 - 5983, 6042 - 6049, 6071 - 6084 SCANNED Tubing (size, grade, MD, and TVD) 3.5, L - 80, 8563 MD, 5629 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER FA -1 PRODUCTION PACKER @ 8568 MD and 5632 TVD PACKER - STACKER PACKER @ 8715 MD and 5736 TVD PACKER - BAKER SABL -3 PACKER @ 8718 MD and 5738 TVD NIPPLE - CAMCO DS NIPPLE @ 493 MD and 493 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable 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 shut - Subsequent to operation shut - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory E Development d — Service 5:0 • Stratigraphic I- 16. Well Status after work: Oil r Gas E WDSPL F Daily Report of Well Operations xxX GSTOR E VVINJ IW • WAG r GINJ I SUSP V 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: 313 -171 Contact Monty Myers @ 265 -6318 Email Montt/ .M.Mverseconocophillips.com Printed Name Monty M. Myers Title Wells Engineer Signature •-� _ Phone: 265 -6318 Date V1- z RBDMS JUN -7 201& Form 10 -404 Revised 10/2012 iD / ! 'i4 13 Submit Original Only 114 KUP • 2F -17 Conoc Well Attributes M ax Angle & MD. TD Alaska, Inc Wellbore API/UWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) 500292273100 KUPARUK RIVER UNIT INJ 9,561.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date "' SSSV: NIPPLE Last WO: 5/15/2013 2/5/1997 Well Confie - 2F -17, 5117/2013 9'52'.21 AV scnema[ic- ac[ual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 9,399.0 2/25/2012 Rev Reason: WORKOVER osborl 5/17/2013 HANGER,28 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) _. String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 43.0 121.0 121.0 62.50 H - 40 WELDED "SI VP Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE 75/8 6.750 41.3 4,018.5 3,136.5 29.70 L -80 BTC I Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 51/2 4.767 38.6 8,975.4 5,929.5 15.50 L -80 LTC -MOD Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 43 -121 CONDUCTOR, LINER 3 1/2 2.867 8,718.0 9,560.5 6,396.0 9.20 L - 80 BTC III 1111 1 Liner Details Top Depth NIPPLE, 493 `, (TVD) Top Inc! Nomi... Top (ftKB) MICE) (1 hem Description Comment ID (in) ti 8,718.0 5,738.1 39.42 PACKER BAKER SABL -3 w/LINER HANGER 2.867 Tubing Strings ". Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String _. String Top Thrd ®k ' TUBING WO 3 1/2 2.992 27.8 8,563.0 5,628.7 9.30 L -80 IBT d ? Completion Details i. Top Depth i (TVD) Top loci Nomi... GAS LIFT, Top (ftKB (ftKB) (1 Item Description Comment ID (in) 3,00s ( 27 27.8 0.00 HANGER FMC TC- IA- EN,6x3 -1/2" 2.992 -- -- 492.5 492.5 0.49 NIPPLE CAMCO 2.875" DS NIPPLE 2.812 8,550.2 5,620.7 49.34 SEAL ASSY BAKER GBH -22 LOCATOR/804-0 SEAL ASSEMBLY 3.000 Tubing Description String 0... String ID ... Top (ftKB) Set Depth (8... Set Depth (TVD) ... String Wt... String ... String Top Thrd PACKER /PBR ASSY 4 3.000 8,554.0 8,568.0 5,631.9 ri Completion Details Top Depth (TVD) Top Inc! Nomi... SURFAC , m E, � Top(ftKB) (ftKB) (°) Item Description Comment ID (in) a1 °'ote 8,554.0 5,623.0 49.15 PBR BAKER w /10' Stroke 3.000 cos LIFT, -I � Tubing Description String 0... String ID ... Top (ftKB) Set Depth (L.. Set Depth (ND) ... String Wt... String ... String Top Thrd __. STACKER PACKER 3 1/2 2.992 8,567.7 8,715.0 5,735.8 9.30 L - 80 EUE 8rd 5.403 r a ,_ Completion Details Top Depth "-® (TVD) Top Inc! Nomi... GAS LIFT, Top (ftKB) (ftKB) 11 item Description Comment ID 0n) 6,844 - 8,567.7 5,631.7 48.45 PACKER BAKER FA -1 PRODUCTION PACKER 3.630 8,651.9 5,689.5 44.18 NIPPLE CAMCO 2.813 'X' NIPPLE w/XX PLUG INSTALLED 2.812 8,703.9 5,727.2 39.37 SEAL ASSY BAKER GBH -22 TOP BONDED SEAL ASSEMBLY 2.990 GAS LIFT, - __- - Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc.) 7,796 Top Depth (TVD) Top Intl Top (ftKB) (ftKB) (3 Description Comment Run Date ID (in) 8,739.0 5,754.3 39.50 PLUG 1.688" WEATHERFORD INFLATABLE BRIDGE PLUG 5/1/2013 0.000 GAS LIFT, _ a 8499 Perforations & Slots Shot Top (ND) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (eh ... Type Comment 9,038.0 9,048.0 5,975.4 5,982.8 C-4, UNIT B, 8/2/1997 6.0 IPERF 60 deg. Phasing 2.5" HSD DP SEAL ASSY, 2F - 8,550 PBR, 8,554 9,126.0 9,136.0 6,041.7 6,049.4 A -5, 2F -17 8/2/1997 6.0 IPERF 60 deg. Phasing; 2.5" HSD DP 9,164.0 9,181.0 6,071.4 6,084.4 A-4, 2F -17 5/6/1997 4.0 IPERF 180 deg. Phasing; 2.5" HSD BH PACKER,8,568 - -- Notes: General & Safety End Date Annotation SI 10/14/2010 NOTE: View Schematic w/ Alaska Schematic9.0 NIPPLE, 8,652 SEAL ASSY, 8,704 - N PBR, 8,704 ANCHOR, 8,717 PLUG, 8,739 PRODUCTION, 39-8.975 - Mandrel Details Top Depth Top Port IPERF, g (TVD) Intl OD Valve Latch Size TRO Run 9,038 -9,048 N... (ftKB) (ftKB) (1 Make Model (in) Sery Type (in Run D ate Con,... 1 3 2,594.3 o K -9 1 GAS LIFT DMY INT 0.000 0.0 5/9/2013 2 5,403.5 3,892.8 583 Camco KBG 1 GAS LIFT DMY INT 0.000 0.0 5/9/2013 1 GAS LIFT DMY INT 0.000 0.0 5/9/2013 IPERF, 3 Top 6 4 CaCamc mco KBG2 -9 1 GAS LIFT DMY INT Type 0 .00 0 (psi) 0.0 5/9!20 9.126-9,136 4 7,796.1 5,184.3 5900 Camco KB G2 -9 IPERF, 5 8 5 , 58 6. 3 4 55: 9. 7 5 643 1 Camco KBG2 -9 1 GAS LIFT SOV INT 0.000 0.0 5/9/2013 9.1848,181 LINER, 8,718-9,581 TD (2F -17), 9,561 2F -17 Pre Rig Well Work DATE SUMMARY • • 1/8/2013 (PRE RWO) RIG WORK, T POT (PASSED), T PPPOT (PASSED), IC POT (PASSED), IC PPPOT (PASSED), FUNCTION TEST T LDS (ALL FUNCTIONED PROPERLY). 1/10/2013 MEASURED BHP © 9000' RKB ( 4193 psi) . COMPLETE. 3/11/2013 (PRE RWO) MITIA (PASSED) 4/2/2013 (PRE CTD) PT & DD TEST; MV- PASSED; SSV- PASSED; SV- PASSED 4/14/2013 DELAYED START DUE TO HEAD CATCHER NOT FUNCTIONING. DRIFT TO NIPPLE REDUCER @ 8694' RKB AND TOOLS TEMPORARILY DETAINED ( BLEED TBG. BRIEFLY THROUGH BLEED HOSE TO GET FREE ). SWITCH TO 1.25 TOOL STRING AND DRIFT TO 9000' SLM W/ 1.67 ". MEASURE BHP ( 3968 psi ) @ 9000' RKB. PROCEDURE NEEDS REVISED FOR SECURE WELL. 4/26/2013 PULLED DV @ 8642' RKB. READY FOR E /L. 5/1/2013 COMPLETED SETTING WEATHERFORD 1.688" IBP. CORRELATED TO TUBING TALLY AND SET IBP MID - ELEMENT @ 8740' PERFORMED MIT OF IBP AND THE PLUG PASSED MIT • • Conoco Time Log & Summary WeiMew Web Reporting Report Well Name: 2F - 17 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 5/2/2013 5:30:00 PM Rig Release: 5/10/2013 3:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/01/2013 24 hr Summary Standby for CPAI field changeout, Road rig to 1A access road 16:30 19:30 3.00 MIRU MOVE MOB X Waiting on CPAI field change out 19:30 00:00 4.50 MIRU MOVE MOB P Road rig from 1D Pad to 1A Access road (4.1 Miles) 05/02/2013 Continue to road rig to 2F. Stand by for well prep, MIRU. Lubricate out BPV, Spot and begin RU of slick line. 00:00 01:30 1.50 MIRU MOVE MOB P Continue to Road rig from 1A access to Oliktok Y 01:30 04:30 3.00 MIRU MOVE MOB P Continue to Road rig from Oliktok Y to 2C Access road 04:30 06:30 2.00 MIRU MOVE MOB X Set down for CPAI field change out. 06:30 09:00 2.50 MIRU MOVE MOB P Continue to 2F -Pad 09:00 15:30 6.50 MIRU MOVE MOB T Remove Lines from Back of Well, Set BPV, Remove Well Platform. (Move Rig Camp from 1D to 2F Pad - 09:00 to 11:30) 15:30 17:30 2.00 MIRU MOVE MOB P Set mats and spot rig, set down Accept Nordic rig 3 @ 17:30 hrs 17:30 21:00 3.50 MIRU MOVE RURD P Berm Up, Spot anxcillary equipment, Load lubricators for BPV and Slick line in pipe shed. Load pits w/ 10.9 ppg NaCI / NaBr kwf. Install 1502 Integral Companion Flange on IA. KDTH Building Dike for Kill Tank, load kill tank and run Hard Iron to rig. 21:00 23:30 2.50 MIRU WELCTI MPSP P PJSM, RU lubricator to tree and PT @ 2,500 psi. Lub out BPV. Secure well. RD Lubricator. Open up well and obtain pressures - 1,250 psi SITP, 1,200 psi SIICP and 100 psi SIOCP. 23:30 00:00 0.50 MIRU WELCTISLKL P PJSM, Spot and Start RU slick line w/ first crew. J5/03/2013 Continue to RU slick line, Dump bail CaCO3 on IBP, RD Slick line. PT Kill and circulating lines. Kill well. NFT - Failed. Page 1 of 7 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 MIRU WELCTL SLKL P PJSM, Continue to RU slick line w /2nd crew. PT @ 2,250 psi - good test. Install fusible cap on SSV. RIH w/ 1.67" x 20 -ft x 1 -1/2" bailer for drift run to 8,720 -ft SLM (top of IBP). However the during this drift run we set down on the top of the patch and reducer nipple. POOH and reconfig tools string to 1.75" OD x 10 -ft for drift run #2. KDTH - Kill Tanks set and bermed, Hard line ran and tied in. TP and KDTH lead made 1C -16 route inspection. 06:00 17:30 11.50 MIRU WELCTLSLKL P Drift reconfigured and subsequently successful. Perform Dump Bailer runs dumping. Second attempt with Dump Bailer did not shear. Rerun and finish running dump bailer runs for a total of 4- staging 10' of CaCO3 on top of IBP. Tag CaCO3 plug @ 8,710 -ft SLM. Completion Tubing loaded, strapped, and tallied in Pipe Shed. 17:30 18:00 0.50 MIRU WELCTLSLKL P Rig down HES Slickline 18:00 19:00 1.00 MIRU WELCTL PRTS P PJSM, RU Kill lines in cellar, Test kill lines @ 250 / 3,500 psi - good test. Blow down lines. 19:00 00:00 5.00 MIRU WELCTLSFTY P Reviewed Nordic's revised Well kill procedure w/ crew. Held PJSM, review kill sheet, discuss operational positions filled to conduct well kill operations. Fill pump lines to choke and pressure up to 1,200 psi open up well SITP @ 1,570 psi, SICP @ 1,690 psi. Start well kill holding CP @ 1,690 psi while bring pump online to 2 bpm @ 1,670 psi for 75 bbls to fill TBG to circ. pt. Continue to circulate @ 2 bpm @ 1,700 psi while maintaining TBG pressure for the remaining 116 bbls with 1,130 FCP w/ 11.0 ppg KWF at surface. SWI and Blow down kill lines. Open up well and monitor SIWP for 1 hr. SIWP increased from 0 to 540 psi. Notified RWO Engr, called out 13.3 ppg WBM. 35/04/2013 W/O 13.3 ppg KWF, Kill well w/ 13.3 ppg WBM KWF. NFT, Install BPV and PT from below. ND Tree and NU BOPE. Page 2 of 7 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 13:00 13.00 MIRU WELCTL OTHR P Wait for 13.3 ppg WBM to be built at MI mud plant in Dead horse and ship to location and load in pits. While waiting for KWF, Build berm and install 2 400 bbl upright tanks for 11.0 ppg NaCI / NaBr brine storage on 2F pad, offload 11.0 KWF from rig pits. Prep pits for bringing on 13.3 ppg WBM. Drift & Tally Pup Joints, Clean and service Rig. 13:00 15:00 2.00 MIRU WELCTLOTHR P Load Pits with 13.3 ppg WBM. 15:00 18:15 3.25 MIRU WELCTL KLWL P PJSM, PT tubing to 500 psi, OK. Able to bleed pressure back to 10 psi. Pump 30 bbls Hi -Vis Sweep at 2 bpm- ICP 660 psi holding 200 psi Back Pressure. Circulate 13.3 ppg WBM at 2 bpm down tubing taking 11 ppg returns to Kill Tank. Circulate 180 bbls around and minitor pressure. Tubing and IA pressure 0 psi. 18:15 19:00 0.75 MIRU WELCTL OTHR P NFT - Good, Blow down top drive. 19:00 20:30 1.50 MIRU WHDBO MPSP P PJSM, install 3" ISA BPV, Pressure test from below to 500 psi w/ no surface leaks on BPV, however we lost 70 psi in 10 minutes. 20:30 22:00 1.50 MIRU WHDBO NUND P ND Tree, unflanged Tree from Adapter. (all studs and nuts installed on Adapter) Inspect 3 -1/2 EUE 8rd lift threads, Install blanking plug. 22:00 00:00 2.00 MIRU WHDBO NUND P NU 11" 5M BOPE, install choke and kill lines. Install riser. 35/05/2013 Continue NU BOPE. Conduct BOP Test. Unland hanger, pull seals from PBR, Rev. Circ 2 TBG vol. Spot 5 bbls of CI 13.3 WBM @ PBR. POOH laying down de- completion from 8,700 -ft to 6,840 -ft. Circulate surface to surface to condition mud. 00:00 00:30 0.50 MIRU WHDBO NUND P Continue to NU 11" 5M BOPE Page 3 of 7 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 06:00 5.50 MIRU WHDBO BOPE P PJSM, RU BOPE Test equipment. Conduct initial BOP test w/ 3 -1/2 test joint @ 250 / 3,500 psi. 24 hr Notice was given to AOGCC @ 04:39 hrs on 5 -2 -13, Right to witness test was waived by Chuck Scheve @ 19:21 hrs on 5 -3 -13. Test # 1, Blind rams, Manual kill valve, Manual TD valve, Choke Manifold 4,11,12. 3-1/2 Dart valve. Test #2, Blind rams, HCR kill valve, Hyd TD valve, Choke Manifold 3,7, 9 and 10, 3 -1/2 IF FOSV. HCR kill valve failed SN# 023554. Test #2 Re -test, Blind rams, Manual kill valve, Hyd TD valve, Choke Manifold 3,7, 9 and 10, 3 -1/2 IF FOSV. Test #3, Blind rams, Choke Manifold 2,5, and 8, 3 -1/2 8rd FOSV. Test #4, Annular, Choke Manifold 2,5, and 6. Test #5, Lower Pipe rams, Choke Manifold 1. 06:00 08:30 2.50 MIRU WHDBO BOPE T Change out Kill HCR and replace w/ SN# PV 3966 and Mud Manifold Kill line valve . 08:30 12:00 3.50 MIRU WHDBO BOPE P Test Upper Pipe rams and HCRs. Test Manual Choke. Test Mud Manifold Kill! Valve to 5000 psi. 2hrs over 12 hr contractual agreement. Draw down Test: System full pressure - 3,000 psi After closure - 1,850 psi 200 psi build - 17 seconds Full system build - 84 seconds 4 N2 bottles @ 2,000 psi. 12:00 12:30 0.50 MIRU WHDBO PULD P Rig Down BOP Test Equipment. BDHL, Drain Stack 12:30 13:30 1.00 0 8,703 COMPZ RPCOM MPSP P PJSM. Pull Blanking Plug and BPV. 13:30 14:30 1.00 8,703 8,670 COMPZ RPCOM PULL P PJSM. MU Landing Joint, BOLDS, Unseat Hanger 55k #. Pull out of PBR at 155k# including 35k# BW. 14:30 16:30 2.00 8,670 8,670 COMPZ RPCOM CIRC P Circulate 155 bbls of 13.3 ppg LSND down Tbg returns up IA at 3 bpm 2120 psi. Pump 5 bbl of 13.3 ppg LSND with 1% CRW CI followed by 80 bbls 13.3 ppg LSND Disp. lines includes surface lines. (calced 1 bbl CI LSND left in pipe). 16:30 17:00 0.50 8,670 8,670 COMPZ RPCOM OWFF P Shut down Pumps and perform no flow test. 17:00 00:00 7.00 8,700 6,796 COMPZ RPCOM PULD P PJSM, POOH w/ 60 jts from 8,700 -ft 95k up wt. to 6,810 -ft 87k up wt. Filling pipe on fill up line - Displacement irregular. 05/06/2013 PU, MU and RIH w/ 3 -1/2 IBT -M to Top of PBR, Circulate and condition hole volume while reciprocating. POOH w/ de completion to 2,200 -ft. Page 4 of 7 • S Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 6,796 6,796 COMPZ RPCOM CIRC P Circulate - Mud wt spotty, 13.1 ppg to 13.3+ ppg. Obtain SPR's at 6,840-ft. 01:00 06:00 5.00 6,796 8,645 COMPZ RPCOM PULD P Change over floor equipment and RIH, PU New 3 -1/2 IBT -M tubing from 6,796 -ft to 8,645 -ft to condition hole for running stacker packer completion (Packer w/ Positive plug in tail pipe) as we would not be able to wash ahead when RIH. 06:00 08:00 2.00 8,645 8,703 COMPZ RPCOM TRIP P RIH from 8640' to 8703'. Up 102k #, down 67k #. Condition Mud in Pits. 08:00 10:00 2.00 8,703 8,703 COMPZ RPCOM CIRC P Circulate 360 bbls at 3.5 bpm. ICP 2080 psi. Recipricate pipe 90'. FCP 1950 psi. BDTD. 10:00 10:30 0.50 8,703 8,703 COMPZ RPCOM OWFF P Monitor Well on Trip Tank. Static. 10:30 12:00 1.50 8,703 7,215 COMPZ RPCOM PULL P PJSM. POOH with 3 -1/2" IBTM from 8700', standing back Tbg and filling every 10 stands. Hole fill numbers actual —1 bbl over calculated. Change out Elevators. 12:00 00:00 12.00 7,215 2,200 COMPZ RPCOM PULL P Continue pulling decompletion out of the hole, laying down, strapping, and tally. At 4360', strap Pits and calculate displacement. Total of 1.8 bbls over for complete trip thus far. Returns consistent 13.3 ppg. Continure to POOH laying down 3 -1/2" de- completion to 2,200 -ft. X5/07/2013 Continue to POOH laying down 3 -1/2 De- completion. PU 3 -1/2 Stacker packer assy and RIH on 3 -1/2 Completion TBG. Locate PBR @ 8711' No -go 8721' Up /Dwn weight 110K/65K. Set down 5K, drop 1- 7/16" ball. Space out and set packer with 2500 psi and 6K overpull. 00:00 02:30 2.50 2,200 382 COMPZ RPCOM PULD P Continue to POOH from 2,200 -ft laying down 3 -1/2" De- completion to 382 -ft , Pull double and break out in mouse as Top jt had patch inside. 02:30 05:00 2.50 382 0 COMPZ RPCOM PULD P Contninue to POOH laying down 3 -1/2" De- completion from 382 -ft to seal assy. Strap and kick out de- completion, clean and clear work area. Bring casing scraper assy to rig floor. Measure and Caliper tools 05:00 07:30 2.50 0 0 COMPZ RPCOM PULD P PJSM to MU BHA, Crew changeout and discuss change of scope. Unload Casing Scaper. Prepare to run Upper 45 -FA -36 Packer. 07:30 09:15 1.75 0 150 COMPZ RPCOM PULD P PJSM. MU Packer and setting Assembly 09:15 11:45 2.50 150 2,110 COMPZ RPCOM RCST P RIH with Baker Packer Assembly on stands to 2110'. 11:45 20:45 9.00 2,110 8,695 COMPZ RPCOM RCST P PJSM, Continue RIH picking up Tubing singles from the Pipe Shed. Page 5 of 7 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:45 23:15 2.50 8,695 8,721 COMPZ RPCOM PACK P P/U weight 105 K, DN weight 65K. Locate top of seal assembly @ 8711' - continue down to no -go additional 11ft to 8721'. Set down 5K, mark pipe. P/U weight 110 K. Drop 1 7/16" ball. RIH to no -go - P/U and space out 1.5ft. Pressure up to 2500 psi on packer, P/U 6K overpull. 23:15 00:00 0.75 8,721 8,570 COMPZ RPCOM CIRC P P/U to 8570' and circ bottoms up prior to POOH. 2 bpm =1100 psi. X5/08/2013 Condition well, POOH and P/U 3.5" completion string. Sting into K anchor assembly and pressure up to 2000 psi, Release 30K overpull. P/U 20ft & circulate well over to inhibited SW. 00:00 02:00 2.00 8,570 8,570 COMPZ RPCOM CIRC P Circulate & condition well. Rig down surface lines, monitor well for 30 minutes. 02:00 09:00 7.00 8,570 0 COMPZ RPCOM TRIP P PJSM - POOH with Packer Running Tool from 8568' and LD Setting Tool. Pull and replace all Seal Rings at Breaks. 09:00 10:00 1.00 0 0 COMPZ RPCOM PULD P Clean Floor, Prep for 3 -1/2" Completion Run. 10:00 20:00 10.00 0 8,568 COMPZ RPCOM RCST P PJSM. MU and RIH with 3 -1/2" completion. Checking all Seal Rings at replacing at breaks. 20:00 21:30 1.50 8,568 8,568 COMPZ RPCOM RCST P Set down 10K into K latch, P/U 10K over to ensure latched. Rig up top drive and set up to pump and shear PBR.Bring pump up to 2000 psi, P/U and shear @ 130 K. P/U 16ft and circulate out 13.3# KWF. 21:30 00:00 2.50 8,523 8,523 COMPZ RPCOM CIRC P PJSM - Start pumping sweep, followed by SW to flush wellbore. Pumping 2 bpm © 1500 psi 35/09/2013 Complete pumping inhibited SW, sting into seals @ 8563'. Up weight 98K, down 73K. Space out 2ft above no -go, pressure test packer 2000 psi /30 minutes. Land hanger, PT tubing 3500psi/15 min, PT IA 3500 psi /30 minutes, SOV 2000 psi /monitor for 30 minutes. Pass. Set BPV, NDBOPE, NU tree, test 250/5000 psi, freeze protect with 85bbls of diesel. RDMO. Quarterly Safety Assessment with Wes Heinold, Chris Kennedj & Kevin Hite. 00:00 02:30 2.50 8,523 8,523 COMPZ RPCOM CIRC P Shut down pumping for 1.5 hrs to clean pits and make room for additional SW. 02:30 04:30 2.00 8,523 8,523 COMPZ RPCOM CIRC P Pump inhibited SW down backside. 3bpm @ 1000 PSI. 04:30 06:30 2.00 8,523 8,563 COMPZ RPCOM PRTS P Slowly roll pump and sting seals into PBR. Space out 2 ft above no -go, & 16.2' pups required for landing tubing hanger. Pressure test IA and packer for 30 minutes /2000psi. 06:30 09:00 2.50 8,563 8,563 COMPZ RPCOM HOSO P Continue spacing out. MU top Tbg Pups, Hanger, and Landing Joint. 09:00 10:00 1.00 8,563 8,563 COMPZ RPCOM SFTY P HSE Quaterly Assessment Meeting with crew in the dog house. 10:00 10:30 0.50 8,563 0 COMPZ RPCOM HOSO P Land Hanger. RILDS. Up 98k #, down 73k# 10:30 11:00 0.50 0 0 COMPZ RPCOM PULD P Lay down extra stand of Tbg from Derrick. Page 6 of 7 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 13:00 2.00 0 0 COMPZ RPCOM PRTS P PJSM. Pressure Test Tbg 3500 psi for 15 minutes and chart- Good. Bleed down Tbg to 3000 psi and PT IA to 3500 psi for 30 minutes and chart. Good Test. Shear SOV at 1330 psi 13:00 13:30 0.50 0 0 COMPZ RPCOM OWFF P Monitor Well. Static. 13:30 15:00 1.50 0 0 COMPZ RPCOM MPSP P Set BPV. Test 1000 psi from below. Good test. 15:00 16:30 1.50 0 0 COMPZ WHDBO NUND P ND BOPE 16:30 19:00 2.50 0 COMPZ WHDBO NUND P NU Tree 19:00 21:00 2.00 COMPZ WHDBO PRTS P Pressure test tree 250 /5000psi. Pull test plug. 21:00 23:30 2.50 COMPZ WHDBO FRZP P Reverse circ 85 bbls of diesel for freeze protecting well. Let well balance. 23:30 00:00 0.50 COMPZ WHDBO MPSP P Set BPV 35/10/2013 RDMO to 1C -16. ** *Rig Release @ 03:00 * ** 00:00 03:00 3.00 COMPZ MOVE RURD P Clean pits, offload fluid & RDMO. ** *Rig Release @ 03:00 * ** Page 7 of 7 2F -17 Post Rig Well Work 411 # DATE SUMMARY 5/12/2013 GAUGED TBG TO 2.85" TO 8504' SLM (UNABLE TO PASS), REPLACED SOV @ 8498' RKB WITH DV. MIT IA TO 2500 PSI (PASSED). ATTEMPTED TO EQUALIZE XX PLUG @ 8652' RKB WITH NO SUCCESS. IN PROGRESS. 5/13/2013 PULLED 2.81" XX PLUG @ 8652' RKB; BAILED MUD OFF IBP @ 8740' RKB. IN PROGRESS. 5/15/2013 BAILED MUD OFF IBP @ 8740' RKB. ATTEMPTED PULL IBP. IN PROGRESS. 5/16/2013 BAILED MUD/ CaCO3 OFF IBP @ 8740' RKB. ATTEMPTED PULL IBP, NO SUCCESS. RESUMED BAILING, LOST 16'. READY FOR CTU. 5/17/2013 RUN #1:PERFORM FCO TO 8722' CTMD, RUN #2: LATCHED INTO IBP FISHNECK AT 8722' CTMD, 5K OVERPULL AND THE IBP CAME FREE AND RECOVERED AT SURFACE, F/P TBG, JOB IN PROGRESS 5/18/2013 PERFORMED FCO WITH DIESEUGEL TO 9350' CTMD, MUD WITH LIGHT TRACES OF FORMATION SAND RETURNS, SWEPT THE HOLE WITH 20 BBLS GEL, READY FOR S/L DRIFT, JOB IN PROGRESS. 5/18/2013 TAGGED @ 9175' SLM. DRIFTED TBG w/ 2.63" DUMMY WHIPSTOCK TO 9175' SLM. READY FOR E /L. 5/19/2013 (PRE CTD): TREE TEST - MV, SSV, SV DDT PASSED, MV, SSV, SV PT PASSED. 5/19/2013 RAN 24 -ARM MIT FROM 9200' TO 8600' TO INSPECT PIPE INTEGRITY FOR WHIPSTOCK, 30 MIN STATIC PRESSURE READING @ 9100', PRESSURE & TEMPERATURE @ 9100': 3940 PSI & 125 DEG F, 15 MIN STATIC PRESSURE READING @ 8964', PRESSURE & TEMPERATURE @ 8964': 3885 PSI & 143 DEG F. ASSISTED VALVE CREW WITH SETTING BPV. JOB COMPLETED. MAY 10 2013 WELL LOG TRANSMITTAL A C To: Alaska Oil and Gas Conservation Comm. May 2, 2013 Attn.: Makana Bender `e‘G- 2-04 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 1_2542. RE: IBP Setting Record: 2F-17 Run Date: 5/1/2013 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Matthew Cook, Halliburton Wireline& Perforating, 6900 Arctic Blvd.,Anchorage, AK 99518 matthew.cook@halliburton.com 2F-:17 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-22731-00 SCANNED MAR 1 3 2014 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE 'TRANSMITTAL LEITER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Matthew Cook 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3572 Pax: 907-273-3535 uiatthew.cook@halliburton.com Date: 1, c kCo l 3 Signed: )V1 12 • • 1 oF i w ' I%% s THE STATE Alaska Oil and Gas k °fA LASKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Monty M. Myers SCANNED APR 12 2013 Wells Engineer a ConocoPhillips Alaska, Inc. /�j f P.O. Box 100360 � Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2F -17 Sundry Number: 313 -171 Dear Mr. Myers: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, / Cathy P oerster Chair DATED this it day of April, 2013. Encl. STATE OF ALASKA AL .A OIL AND GAS CONSERVATION COMAOION . APPLICATION FOR SUNDRY APPROVALS 41 1 20 AAC 25.280 � i 1. Type of Request: Abandon E Plug for Redrill 1 - Perforate New Pool )°" Repair w ell I" Change Approved frog ram E Suspend E Rug Perforations E Perforate r Pull Tubing p- Time Extension E Operational Shutdow n E Re -enter Susp. Well I-°- Stimulate r"" Alter casing r Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development [ Exploratory r 196 - 204• 3. Address: Stratigraphic i"" S ervice � 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 - 029 - 22731 - 00 7. If perforating, What 8. Well Name and Number: Regulation or Conservation Order govems well spacing in this pool? Will planned perforations require spacing exception? Yes r No I✓ 2F - 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25666 ' 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): '9561 6336 9461' 6263' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 121' 121' SURFACE 3977 7.625 4018' 3136' PRODUCTION 8937 5.5 8932' 5898' LINER 842 3.5 9561' 6396' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9038 - 9048, 9126 9164 - 9181 5975 - 5983, 6042 - 6049, 6071 - 6084 3.5 L - 80 8718 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER SABL -3 MD= 8718 TVD =5739 ' NIPPLE - CAMCO DS NIPPLE MD= 496 TVD =496 - 12. Attachments: Description Summary of Proposal . I 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch E Exploratory E Stratigraphic im Development E Service i� • 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 5/1/2013 Oil Ia Gas I - WDSPL I - Suspended `- 16. Verbal Approval: Date: WINJ I:: • GINJ 1 - WAG I Abandoned r Commission Representative: GSTOR E SPLUG E 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Monty Myers @ 265 -6318 Email: Monty .M.Mverseconocoohillips.com Printed Name Monty M. Myers Title: Wells Engineer Signature Phone: 265 -6318 Date Commission Use Only Sundry Number: 3-'f 7' Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 1 BOP Test F' Mechanical Integrity Test l - Location Clearance E ��r Other: 36 /) /--/ /- ;5 psi, R!3r �c APR 12 20� • Spacing Exception Required? Yes ❑ No 27 Subsequent Form Required: /Q _40 APPROVED BY Approved byr �� O OC ooR14 q application is vaRh tOr 9l nths from th l 30 oval. Date: 4 -i/ i 0 012) 11 Submit Form and Attachments in Duplicate 111./c— . 4 /0a /3 rArri, � -0 • • ConocoPhillips R EC Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 April 3, 2013 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to workover Kuparuk Well 2F -17 (PTD# 196 -204). 2F -17 was originally completed in March of 1997 as an A & C sand injector. It was used for preproduction for 8 months; however, it was producing 90% water and was then converted to an injector in November of 1997. This well has supported production for A4 and A5 sands on the southern part of 2F pad. In July of 2010, it was noted that from a caliper log that there was several areas of corrosion on the tubing. In April of 2011, a permanent patch assembly was set at 8,332'- 8,342'MD; however, the well was not able to inject afterwards due to fill on the A sands. In February of 2012, coil performed a fill clean out to 9,395' MD and in March of 2012, it was brought online for seawater injection. The injection in this well has been shut in since June of 2012 for pressure management for the upcoming RWO and CTD operations. Prior to being shut in, the A & C sand SBHP measured was 4668 psi combined at 9,000' RKB (above both A & C -sand Perfs) on 9/27/2012. Following the shut in, the current A & C -sand SBHP measured was 4194 psi combined at 9,000' RKB on 1/10/2013. The proposed workover will set this well up for an upcoming CTD sidetrack to support production from the proposed 2G -11 CTD well to the west. Plans are to pull the current 3 'h" upper completion, which has a restrictive tubing patch, and replace it with a new permanent packer stacked on top of the existing 3 -1/2" by 7 "packer and replace all 3 'h" upper completion equipment. Currently there is nothing wrong with the well, but this well was identified as a good candidate for a CTD sidetrack to target reserves at risk. If you have any questions or require any further information, please contact me at 265 -6318. Sincerely, ;1 Wells Engineer CPAI Drilling and Wells • • Kuparuk 2F -17 General Workover Procedure Pre Riq Work: 1. RU Slickline: RIH w/ dual Panex gauges, obtain SBHP. Pull DV from bottom mandrel. 2. RU E -Line. RIH w/ 1- 11/16" IBP and set in the 3 -1/2" liner at 8,740' MD. 3. CMIT TxIA to 2,500 psi against the IBP. 4. PT tbg & csg packoffs, FT LDS's. 5. Set BPV w/i 24 hrs of rig arrival. General Workover Procedure 1. MIRU. 2. Pull BPV. Reverse circulate KWF 9.6 ppg brine. Obtain SITP & SICP, if still seeing pressure at surface, calculate new KWF and repeat circulation as necessary. Verify well is dead. 3. Set BPV & blanking plug, ND tree, NU BOPE & test. 4. Pull blanking plug & BPV, screw in landing joint, BOLDS's, pull tubing hanger. 5. POOH laying down 3 -1/2" tubing. a. If tubing will not pull free, RU E -line: Fire a string shot and cut the tubing at XXXX' RKB (middle of the first full joint above the PBR). RDMO E -line. b. RIH w/ overshot dressed for 3 -1/2" tubing on 3 -1/2" IF drill pipe, latch onto tubing stub and jar seal assembly free. POOH laying down drill pipe. 6. Offload old tubing, rack & tally new tubing. 7. RIH w/ seal assembly and stack packer w/ packer setting tools on new 3 -1/2" tubing to the existing PBR (use drill pipe if used earlier to fish stub). 8. Spot corrosion inhibited brine in the IA below the stack packer. 9. Sting into existing PBR, PT IA to 500 psi to verify seals are engaged. Space out 1' off bottom, drop a ball, and pressure up to set the 'FA' packer. PT IA to 2,500 psi. Release from packer. 10. POOH standing back tubing. a. If packoffs need replaced: On TOH, set a storm packer at —100' w/ tubing hanging below. RU Hydratight equipment. NDBOP & Tbg head, replace tbg head & IC packoffs, NU BOP & test. Pull storm packer. 11. MU seal assembly, RIH w/ 3 -1/2" GL completion & SSSV. 12. Sting into new PBR, pressure up tubing to 500 psi to verify seals are engaged, space out 7' off bottom, mark the pipe and pull out of the PBR. 13. Space out w/ pups, MU hanger, feed control line through hanger port and secure w/ swage lock fittings. Pressure up control line to open SSSV. Spot corrosion inhibited brine in the IA below the bottom GLM. Land the hanger, RILDS. 14. Circulate well full of corrosion inhibited brine. II • • 15. Land the hanger, RILDS. PT the tubing to 2,500 psi, while holding 2,500 psi on the tubing, PT the IA to 3,500 psi for 30 min and record. Bleed the IA to zero, then the tubing. Ramp up the IA pressure quickly to shear the SOV. 16. Pull the landing joint, install BPV. 17. ND BOP, NU tree. Pull BPV, install tree test plug. Test tree to 250/5,000 psi. Pull tree test plug. 18. Freeze protect w/ diesel down to 2,000' TVD. 19. Set BPV. 20. RDMO. Post -Riq Work: 1. Reset well house(s) and flowlines of adjacent wells. 2. Pull BPV. 3. RU Slickline: Pull SOV, install DV. Pull IBP. 4. RU CTU: Mill out SAB -3 packer bore to 2.8" w/ diamond speed mills, FCO to PBTD. 5. Turn well over to operations. KUP . 2F -17 ConocoPhillips Well Attributes Max Angle& MD TD Alaska Inc, Wellbore APUUWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) 500292273100 KUPARUK RIVER UNIT INJ 60.13 7,900.00 9,561,0 Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date wrenconrxr.- 2F- n,7/920129ass7 AM SSSV: NIPPLE Last WO: 2/5/1997 Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag. SLM 9.399.0 2/25/2012 Rev Reason: WELL REVIEW osborl 7/9/2012 MANGER, 27 - gy p. _ - Casing St f- Casin Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ._ String Wt... String... String Top Thrd CONDUCTOR 16 15.062 43.0 121.0 121.0 62.50 H-40 WELDED • Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd SURFACE 75/8 6.750 41.3 4,018.5 3,136.0 29.70 L - 80 BTC Casing Description String 0... String ID... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt.. String ... String Top Thrd PRODUCTION 51/2 4.767 38.6 8,975.4 5,929.5 15.50 L - 80 LTC - MOD Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt.. String ... String Top Thrd CONDUCTOR, ' LINER 31/2 2.867 8,718.0 9,560.5 6,3960 920 L - 80 BTC 43121 Liner Details - -- Top Depth (ND) Top Intl Nomi... NIPPLE, 496 I " Top (ftKB) (ftKB) (°) Item Description Comment ID (in) -- - 8,718.0 5,738.5 40.70 PACKER BAKER SABL- 3w/LINER HANGER 2.867 --- Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (t... Set Depth (TVD) ... String Wt.. String ... String Top Thrd TUBING 31,2 2992 26.9 8,718.0 5,738.4 9.30 L -80 EUE -abm • Completion Details Top Depth (TVD) Top Inc! Nomi... Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) 26.9 26.9 0.42 HANGER FMC GEN IV TUBING HANGER 3.500 495.7 495.7 0.42 NIPPLE CAMCO DS NIPPLE 2.812 GAS LIFT, 8,694.5 5,720.7 41.56 NIPPLE CAMCO D NIPPLE 2.750 3,104 8,702.2 5,726.4 4128 LOCATOR BAKER LOCATOR 3.000 8,703.4 5,727.3 41.24' PBR BAKER w /10' Stroke 3.000 -- 8,717.4 5,737.9 40.73 ANCHOR BAKER KBH -22 ANCHOR 3.000 i. Other In Hole ireline retrievable plugs, valves, pumps, fish, etc.) i ' Top Depth i (TVD) Top Inc! Top (ftKB) (ftKB) (° ) Description Comment Run Date ID (in) 8,331.0 5,482.7 52.53 PATCH 2.71" X -SPAN TTS PATCH w /10' ELEMENT 4/21/2011 2.250 a 8,694.5 5,720.7 41.56 NIP Reducer 2.75" NIPPLE REDUCER 4/8/2011 1.810 Perforations & Slots SURFACE, $ Shot 41 -4,018 Top (TVD) Btm(TVD) Dens MIR Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date Oh- Type Comment 9,038.0 9,048.0 5,975.4 5,982.8 C-4, UNIT B, 8/2/1997 6.0 IPERF 60 deg. Phasing; 2.5" HSD DP 2F -17 GAS LIFT, 6,336 9,126.0 9,136.0 6,041.8 6,049.4 A -5, 2F -17 8/2/1997 6.0 IPERF 60 deg. Phasing; 2.5" HSD DP 9,164.0 9,181.0 6,071.4 6,084.4 A -4, 2F -17 5/6/1997 4.0 IPERF 180 deg. Phasing; 2.5" HSD BH Notes: General & Safety 1 End Date 10/1 Annotation PATCH, 8,331 4/2010 NOTE: View Schematic w/ Alaska Schematic9.0 GAS LIFT, , 8,643 NIP Reducer, 8,695 NIPPLE, 8,695 INK III LOCATOR, - - - -- 8,702 PBR, 8.703 J ANCHOR, 8.717 III PRODUCTION, 39-8.975 IPERF, 9,038 -9,048 Mandrel Details Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run IPERF, 9,126 -9,138 Stn Top (ftKB) (ftKB) ( °) Make Model (in) Sery Type Type On) (PM) Run Date Corn... 1 3,103.7 2,646.0 58.22 BST AXT 1 GAS LIFT DMY T1 0.000 0.0 4/1/1997 6:30 IPERF, 2 6,335.5 4,410.4 57.44 BST AXT 1 GAS LIFT DMY T1 0.000 0.0 4/1/1997 12:30 9,164-8,181 3 8,642.9 5,683.1 44.71 BST AXT 1 GAS LIFT DMY T1 0.000 0.0 5/7/1997 9:30 LINER, 8,718 -9,561 - T0, 9,561 • • • Ferguson, Victoria L (DOA) From: Myers, Monty M [ Monty .M.Myers @conocophillips.com] Sent: Wednesday, April 10, 2013 12:59 PM To: Ferguson, Victoria L (DOA) Subject: RE: Well 2F -17 Workover Sundry(PTD 196 -204, Sundry 313 -171) Good day Victoria! 1. What is the MPSP? What will the BOPs be tested to? MPSP is 2190 psi, BOPE will be tested to 3500 psi. 2. Is this well a potential CTD sidetrack? Yes this well will be set up for a CTD to sidetrack 3. Is the purpose of this WO to replace the permanent tubing patch? Yes, since there is a tubing patch in this well the ID is restricted enough that CTD cannot pass thru. So replacing the tubing is only necessary to accommodate that. If you have any more questions, please let me know. Thanks! Monty M Myers Drilling Engineer ConocoPhillips Alaska 907.265.6318 office 907.538.1168 cell From: Ferguson, Victoria L (DOA) [ mailto: victoria.ferguson@aalaska.govl Sent: Wednesday, April 10, 2013 10:02 AM To: Myers, Monty M Subject: [EXTERNAL]WeII 2F -17 Workover Sundry(PTD 196 -204, Sundry 313 -171) Monty, Please provide the following: 1. What is the MPSP? What will the BOPs be tested to? 2. Is this well a potential CTD sidetrack? 3. Is the purpose of this WO to replace the permanent tubing patch? Thanx in advance, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793 -1247 victoria.ferqusonaalaska.gov 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Wednesday, April 04, 2012 P.I. Supervisor " ( f (7 (1 t SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2F -17 FROM: Lou Grimaldi KUPARUK RIV iJNIT 2F -17 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry , NON- CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 2F - 17 API Well Number 50 - 029 - 22731 - 00 - 00 Inspector Name: Lou Grimaldi Permit Number: 196 - 204 - Inspection Date: 4/1/2012 Insp Num: mitLG120402094629 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 2F-17 • Type Inj W 'TVD 5727 • IA 750 3205 - 3156 x - PTD 1962040 ' Type Test I SPT Test psi 1500 - OA 320 330 330 330 Interval OTHER P/F P - Tubing 2600 2600 2600 2600 Notes: .8 Bbl's diesel pumped up and returned. Good solid test for post tubing patch. s JUN 1 . 2 `LU1% Wednesday, April 04, 2012 Page 1 of 1 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 16, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Patch Setting Record: 2F -17 Run Date: 4/21/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2F -17 Digital Data in LAS format, Digital Log Image file 0' 1 CD Rom 50- 029 - 22731 -00 I C-{ 0 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. *` .. 1; 14:W S' P ;? 1 Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: 1 3 4 Signed: la Oli„.4 STATE OF ALASKA ALASKA *AND GAS CONSERVATION COMMISSI• REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon Re air w ell Install Tubing �"" p r Plug F�rforati r Stimul r Other (;� Rill Tubing Ftrforate New Pool Waiver Patch Alter Casing r 9 � r r Time Extension � Change Approved Program l Operat. Shutdow n r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r ° 196 - 204 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service r " 50 029 - 22731 - 00 r' CEO 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25666 t 2F - 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 9561 feet Plugs (measured) None true vertical 6336 feet Junk (measured) None Effective Depth measured 9461 feet Packer (measured) no packer true vertical 6263 feet (true vertucal) Casing Length Size MD TVD Burst Collapse CONDUCTOR 121 16 121 121 SURFACE 4018 7.625" 4018 3136 PRODUCTION 8932 5.5 8932 5898 LINER 842 3.5 9561 6336 RECEIVED Perforation depth: Measured depth: 9038'- 9048', 9126- 9136', 9164' -9181' True Vertical Depth: 5975'- 5983', 6042'- 6049', 6071' -6084' ,\ 111 Alaska Oil & ffaSt CM*. CAtitinission Tubing (size, grade, MD, and TVD) 3.5, L -80, 8718 MD, 5838 TVD Antnetigje y 70 3 ` ii-ti) Packers & SSSV (type, MD, and TVD) no packer P G' NIPPLE - CAMCO DS NIPPLE @ 496 MD and 496 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation si Subsequent to operation si 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Servic 1' Stratigraphic r 15. Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ WAG r GINJ r SUSP r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 310 -282 Contact John Peirce (. 265 -6471 Printed Name John Peirce Title Wells Engineer Signature Phone: 265-6471 Date s /1 fi l ti / 572?-/( Form 10 -404 Revised 10/2010 RB DMB MAY 18 2011 1 , , 3 "( Submit Original Only 2F -17 Well Work Summary DATE SUMMARY 1/10/11 BRUSHED & BROACHED TBG TO' SLM. DRIFTED TBG WITH 10' 7" x 2. UMMY TO 8400' SLM. READY FOR NIPPLE REDUCER. 4/7/11 BAIL FILL FROM 8669' SLM TO 8674' SLM OFF CA -2 PLUG @ 8695' RKB, IN PROGRESS 4/8/11 PULLED 2.75" CA -2 PLUG FROM D NIPPLE @ 8695' RKB, BRUSHED D NIPPLE AND PATCH DEPTHS, FROM 8300' SLM TO 8700' SLM, SET 2.75" D X 1.81" D NIPPLE REDUCER @ 8695' RKB, COMPLETE 4/21/11 SET TTS 2.71" X -SPAN PATCH AT 8332'- 8342', LOG CORRELATED TO GLM AT 8643' ON LDL LEAK DETECT DATED 8JUL2010. a IKUP • 2F -17 �� g A mps ? Well Attributes -Max Angle & MD TD - B ? Wellbore API /UWI Field Name Well Status Intl ( °) IMD (ftKB) Act Btm (HKB) r „„i.N'+ ,� 500292273100 /.UPARUK RIVER UNIT INJ 6013 7,90000 9561.0 _. _.... C KB --_ omment H2S (ppm) Date Annotation End Date - Grd (ft) Rig Release Dab SSSV NIPPLE Last WO I _ 2/5/1997 ... _ CAtft... _S .17w QJ7, .i�17.A .-. --.. ft(91413) - _ _ - _ �. -.. 4=m:;__ad.p =Annotation notation I Depth (91413) End Date Mrbtation Last Mod ... End Date Last Tag. SLM 9 180 0 4/7/2010 JRev Reason: SET PATCH I Imosbor 4/21/2011 WINGER, 27 ` = • Casing Strings Casing Description String 0... String ID ... Top (ft66) Set Depth (t... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 45.0 121.0 121.0 62.50 H WELDED Casing Description String O... String ID ... Top (ftK6) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE 75/8 6.750 41.3 4,018.5 3,136.0 29.70 L-80 BTC r. casing Description String 0... String ID ... Top (ftK6) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd PRODUCTION 51/2 4.767 38.6 8,975.4 5,929.5 15.50 L -80 LTC -MOD �_- - _ Casing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (ND) . String Wf... String .. String Top Thrd LINER 31/2 2.867 6718.5 9,561.0 9.20 L -80 BTC CONDUCTOR, j 1 Liner Details 45-121 ..1. Top Depth (TVD) Top Intl N i...i I t Top (ftKe) (ftKB) f9 Ite.e Desuiption Comment ID (in) NIPPLE, 496 8,718.5 5,738 8 40 69 PACKER BAKER SABL -3 2.867 1 Tubing Strings Tubing Description String 0... String ID ... Top (ft06) Set Depth (f... Set Depth (ND) . String Wt... String ... String Top Thrd TUBING 3 1/2 2 992 I 26 9 I 8,718.0 5,738.4 I 9 30 L -80 EUE abm Completion Details Top Depth % : (TVD) Top Intl Nom,... Top (IIKB) (ftKB)__ -- e) Item Descption Comment ID (in) 26.9 26.9 0.42 HANGER FMC GEN IV TUBING HANGER 3.500 495.7 495.7 0.42 NIPPLE CAMCO DS NIPPLE 2.813 L i 8,694.5 5,720.7 41.56 NIPPLE CAMCO D NIPPLE 2.750 GAS LIFT, . 8,702.2 5,726.4 4128 LOCATOR BAKER LOCATOR 3.000 3,104 - 8,703.4 5,727.3 41.24 PBR BAKER w/10' Stroke ke 3.000 8,717.4 5,737.9 40.73 ANCHOR BAKER KBII -22 ANCHOR 3.000 O ther In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) € _, - Top Depth (TVD) Top Inol ,:J Top (RIM) _._...__ (9 ,...option Comment Run Date ID (in) 8,331.0 5,482.7 52.53 PATCH 2.71" X -SPAN TTS PATCH w /10' ELEMENT 4/21/2011 2.250 ( - 6,694 5,720.7 41.56 NIP Reducer 2.75' NIPPLE REDUCER 4/8/2011 1.810 Perforations & Slots Shot -.. Top (ND) Btm (TVD) Dens SURFACE, 61 4,018 Top (ftKB) Btm (ttKB) (ftK6) #003) Zone Date WI-. Type Comment 9,038.0 9,048.0 5,975.4 5,982.8 C-4, UNIT B, 8/2/1997 6.0 IPERF 60 deg. Phasing; 2.5" HSD DP 2F -17 GAS LIFT, r 9,126.0 9,136.0 6,041.8 6 049 4 A-5, 2F-17 8/2/1997 6.0 IPERF 60 deg. Phasing; 2.5" HSD DP 8,338 9,164.0 9,181.0 6 071 4 6,084.4 A-4, 2F-17 5/6/1997 4 0 ® deg Phasing 2.5" HSD BH te, , T ,v!st r .rc.' .aw 7? re " T.MM 3 -, :�a-< J. k ,x .. ... ........': ... �'-� e tam.. v ^. n``r,�.,x�- � End Data ° Annotation PATCH, 8,331 - 4/1/1997 NOTE: GLM #1 Oriented @ 6:30, GLM #2 @ 12:30, GLM #3 @ 9:30 10/14/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 GAS LIFT, 8,643 NIP Reducer, 8,695 NIPPLE, 8,695 - Y. LOCATOR _ / 8,702 V d/ P134,8,703 - - -- - • > ANCHOR, _�_ ... 8,717 .- PRODUCTION, 39 -8,975 IPERE, 9,038 -9,046 - Mandrel Details Top Depth Top ' Port (ND) Intl OD Valve Latch Size TRO Run 9026.9,136 -s,t3s IPERF, Stn Top (ftKe) (ftK6) ( °) Make yodel (in) s. TM. TYDe (in) (psi) Run Date Coin._ 1 3,103.7 2,646.0 58.22 BST AXT 1 GAS LIFT DMY Ti 0.000 0.0 4/1/1997 2 6,335.5 4,410.4 57.44 BST AXT 1 GAS LIFT DMY T1 0.000 0.0 4/1/1997 9,164 -51 3 8,642.9 5,683 144.71 BST AXT 1 GAS LIFT DMY T1 0.000 0.0 5/7/1997 9,561 8,119- 9,561 TD, 9,561 J L • • ~~Q~t~ 0~ aL~Q~~{Q /~..~.~~,~.,~ John Peirce Wells En meer - ConocoPhillips Alaska, Inc. ~ n (,~ P.O. Box 100360 6~ (~Y Anchorage, AK 99510 ,~ Re: Kuparuk River Field, Kuparuk River Oil Pool, 2F-17 Sundry Number: 310-282 Dear Mr. Peirce: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair i/~/ DATED this ~ day of September, 2010. Encl. STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMISS~ APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon Plug for Redrill ~ F~rforate New Pool Repair well ~ Change Approved Program Suspend ~"" Ru Ft?rforations ... Perforate 9 Pull Tubing ("' Terre Extension Operational Shutdow n ~ Re-enter Susp. Well Stimilate Alter casin g ~ Other: Install Tubing Patch 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ Exploratory ~"'~ 196-204 3. Address: Stratigraphic ~ Service ~" 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22731-00 ` 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes No ~" 2F-17 ' 9. Property Designation: 10. Field/Pool(s): ADL 25666. Kuparuk River Field /Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (n): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9561 6336 9461' 6263' 8695' Casing Length Size MD ND Burst Collapse CONDUCTOR 121 16 121' 121' SURFACE 4018 7.625 4018' 3136' PRODUCTION 8932 5.5 8932' 5898' LINER 843 3.5 9561' 6336' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9038'-9048', 9126'-9136', 9164'-9181' 5975'-5983', 6042'-6049', 6071'-6084' 3.5 L-80 8718 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER -BAKER SABL-3 PKR/ LINER HANGER MD= 8718 TVD= 5738 Camco'DS'nipple MD= 496 TVD=496 12. Attachments: Description Surmnry of Proposal 13. Well Class after proposed work: Detailed Operations Program BOP Sketch E~loratory ~ Development Service ~` 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 10/15/2010 Oil Gas ~ WDSPL ~! Suspended 16. Verbal Approval: Date: WINJ GINJ ~ WAG Abandoned ~I Commission Representative: GSTOR SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265-6471 Printed Name John Peirce Title: Wells Engineer Signature ~ ~ Phone: 265-6471 Date t O Sundry Number: 3 ~ ~ 'a~a Conditions of approval: Notify Commission so that a representative may witness Plug Integrity ~ BOP Test ~"`" Mechanical Integrity Test ~"" Location Cl earance t~ ' w~J ~ 9" R Other. • ~- , ~ ?~~~ Subsequent Form Required: `b . [~/V ~~ _ .,. ~ta~ ~ ~ ~ APPROVED BY ~ ~~ Approved by: COMMISSIONER THE COMMISSION Date: SEP 0 7 P•z-~= Form 40-403 Revise / Submit in Du licate ~~~~ Ofl • • 2F-17 Permanent Tubing Patch Installation 2F-17 is an A/C sand injector that has been shut-in since 6/1/10 due to a tubing leak causing annular communication. A 7/08/10 LDL found a leak at 8337' WLM at the middle of a full tubing joint. A permanent patch is proposed to isolate the leak to return 2F-17 to injection until a RWO can eventually replace the tubing. Per this procedure, a 10' long Permanent Tubing Patch will be set across the tubing leak at 8337' to eliminate annular communication and enable the return of 2F-17 to injection. Procedure: Slickline: 1. Brush & flush 3.5" tubing between 7600 - 8360' RKB with special attention on 8300 - 8360' RKB area where a tubing patch will be set. 2. RIH with 10' x 2.72" run OD dummy patch drift to 8360' RKB to verify the tubing drifts OK fora 1-trip permanent tubing patch installation. If 10' drift fails to reach 8360', run 5' x 2.72" run OD dummy drift to 8360' RKB. If shorter drift is successful, we will plan to run a 5' OAL permanent tubing patch. Perform the following work steps only if a successful drift is attained: 3. RIH & pull the plug from the D Nipple at 8695' RKB. Seta 2.25" Nipple Reducer in the D Nipple at 8695' RKB. The patch to be installed above this D Nipple will have 2.259" min ID. Retaining a functional nipple may provide some benefit even though the tubing is expected to be replaced by RWO sometime in the future. E-line: Install a 10` OAL or 5' OAL permanent tubing patch as follows: 4. RIH with a permanent tubing patch (2.715" special clearance run OD). Perform either option `a' or `b' below (depending on drift results): a) seta 10' OAL patch at 8332 - 8342' RKB (seal to seal) across the leak at 8337' RKB in a full joint of tubing. b) seta 5' OAL patch at 8334 - 8339' RKB (seal to seal) across the leak at 8337' RKB in a full joint of tubing. RD E-line. Determine if the annular communication issue has been corrected. Return 2F-17 to injection service if annular communication has been corrected. ____~ ! KUP ~ 2F-17 `. _ _- - ~~qqr ^ Y1 ~ ~ ~i ~~ ~ I 5 ~ ~~ We1 A b ~-~,MaXAngleBMD ~ ° TD B ft K ~- y ` X" • .. I~ ~ Wellbore APUUWI Field Name U ) IMD (ftKB) Incl ( Well Statu I Act fm ( B) `" ' - 3 00 'KUPARUKRIVERUNIT 002 922) I 60.13 7,900 00 INJ 9,561.0 r, a ,~~ _ _ _weu canng, 2,F t7 n2o r _ _ Sd1em@LF AcW., C ent IH25 (ppm) Date SSSV. NIPPLE ~ Annotation (Depth (ftKB) End Date Annotation Last Taa: SLM 9,190 0 4/7/2010 (Rev Reas An otation End Date KB-Grd (ft) Last WO:. I _ -.,_ _.__. _._ Last Motl By on: Add Mandrel Orientation Note ImosDOr (Rig Release Date 2/5/1997. Entl Date 8/712010 CONDUCTOR, 121 NIPPLE ass GAS LIFT, 3,106 SURFACE, 6.616 GAS LIFT, 6.336 GAS LIFT, 8.643 NIPPLE, 8,695 PLUG. 8,695 PBR. 8.]03 ANCHOR, 8,]1] TTL, 8,]16 Packer, 8.]16 PRODUCTION. 8.532 IPERF. 9,036-5, W8 IPERF, 9.1269.136 IPERF, 9.164~9.18t LINER, 9.561 TD, 9,561 Casing Description (CONDUCTOR String OD String ID (in) i. (in) 161 15.062 Top (ftKB) 0.0 Set Depth (ftKB) 121.0 Set Depth (ND) ~ (ftKB) 121.01 String Wt 1. String (Ibs/ft) Grade String TOp_Thrd 62.50 H~0 iSURFACE ~ 75/8 6.750 0.0 4,0180 3,135.8( 29.70 L-80 '. (PRODUCTION 51/2 4.767 0.0 8,932.0 5.898.3 15.50 L-80 LINER ~ 3112 2867 8,718.0 9,SGl.C1 9.20~L-80 ~i ~- Tubing Strings - _-_-_ -- String OD String ID __ Set Depth Set Depth (ND) Siring Wt Str g TubingD scription lint (in) Top (ftKB) (ftKB) (ftKB) (Ibs/ft) G de Str glop Thrd TUBING 3 1/2 2.992 `` 0.0 $718.0 5,738.41 111 ABM EUE 9.30 L 80 Other I n Hole All Jewel : Tub~in Run 8Retrievable, Fish etc. -._ _ - Top Depth ~ - - (T ! TO ncl P Tp Li1K6) (ftKB) (' Description 1 Comment Run Dat_e__ ID (in) 496 496.0(, 0.43 NIPPLE '~,Camco'DS'Nipple 4!1/1997 2813 3,104 2,646.1' 58.21 GAS LIFT BST/AXT/1/DMY77-1U/ Comment: STA 1 4/1!1997 2.900 6,336 4,410.6 57.44 GAS LIFT _ ~IBST/AXT/1JDMY/T-1/// Comment STA 2 ____ _ _. 4/1/1997 2 900 8,643 5683.1 4410 GAS LIFT BST/AXT/1/DMY/T-1l//Comment STA3 5/7/1997 '1 2.900 8,695 5,721.0 4L54 NIPPLE Camco'D' Nipple NO GO 4/1/1997 . 2.750 8 695 5,721.0 41.541 PLUG 2.75" CA-2 PLUG 7/1612010 ~ 0.000~~ 8,703 5,727.0 41.2S~ PBR Baker w/10'Stroke 4/1/1997 3.000 -- 8,717 5,737 7 40.74 ANCHOR Baker KBH-22 Anchor Seal Nipple 4/1/1997 3.000 ---8,718 5,738.4 40.70 TTL 3!31/1997 2.992 8,718 5,738.4 40.70 Packer Baker SABL-3 PKR/ Liner Hanger 4/1/1997 2.780 9 048 811 Q0714I 6,0844A-0, 2F-17 _. "61.8 Safety NOTE GLM #1 Oriemed ~~ 6:30, GLM deg. Phasing; 2.5" HSD DP~ deg. Phasing; 2.5" NSD UP ] tleq. Phasing; 25" HSD BH • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska. 99501 RE: Leak Detect Log: 2F-17 Run Date: 7/8/2010 July 16, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2F-17 Digital Data in LAS format, Digital Log Image file 50-029-22731-00 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barreto@h on.cc Date: 99 ~.3 Signed: ~ ~ WELL LOG S ~ TRANSM/7TAL PROACTIVE UTAfiNOSiIC SERVICES INC. To: AOGCC Christine -AAal~lee~• ~kvr ~Z.e/ 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road ~~,,gy~,,~ ~1 ~~. 1~ SUlte Ci x`•- '~ITr ~\.~ ~ 1~ t1 ~'' ~. U ~'`' Anchorage, AK 99518 Fax: (907) 245-8952 1) Caliper Report 16zlu1-10 2F-17 1 Report / EDE 50-029-22731-OQ 2) u~ C iai~ -ao~ ~°7~~~ Signed : Print Name: PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)24558952 E-MAIL : pdSaRClfarapP.LfiTer#wtlFloaCOm WEBSITE : tNWW:memyrlt~cor-1 C:\Docmnents and Settin~\Diane Williams\Deaktop\Transmit_Conoco.docx i ~ Memory Multi-Finger Caliper ~i LOg Results. Summary ;. Company: ConocoPhillips Alaska, Inc. Well: 2F-17 Log Date: July 16, 2010 Field: Kuparuk Log No.: 10651 State: Alaska Run No.: 1 API No.: 50-029-22731-00 Pipet Desc.: 3.5" 9.3 Ib. L-80 ABM-EUE Top Log Intvl1.: Surface Pipet Use: Tubing and Liner Bot. Log Intvl1.: 8,795 Ft. (MI?) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS This caliper data is tied into the 3.5" tubing tai! @ 8,718' (Driller's Depth). This log was run to assess the condition of the tubing and liner with respect to corrosive and mechanical damage prior to tubing patch operations. A 3-D log plot of the caliper recordings across the interval where an LDL (07-08-10) found a tubing leak (--8,337') is included in this report. The caliper recordings indicate the 3.5" tubing and liner logged appear to be in good to poor condition with respect to corrosive and mechanical damage, with wall penetrations ranging from 20% to 69% wall thickness recorded in 253 of the 288 joints logged. Recorded damage appears as general corrosion, line corrosion, and a line of pits. No significant areas of cross-sectional wall loss or I.D. restrictions are recorded throughout the tubing and liner logged. The caliper recordings indicate slight buckling throughout the tubing and liner logged. MAXIMUM RECORDED WALL PENETRATIONS: Line corrosion (69%) Jt. 201 @ 6,316 Ft. (MD) Line corrosion (67%) Jt. 247 @ 7,777 Ft. (MD) Line corrosion (67%) Jt. 223 @ 7,017 Ft. (MD) Line corrosion (67%) Jt. 260 @ 8,164 Ft. (MD) Line corrosion (66%) Jt. 275 @ 8,671 Ft. (MD) MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 10%) are recorded throughout the tubing and liner logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the tubing and liner logged. Field Engineer: G. Etherton Analyst: C. Waldrop Witness: C. Fitzpatrick Proactive Diagnostic Services, Inc. / P.O, Bc;~ 1369, Stafford, TX 77497 Phone: {281) or (888) 565-9085 s=ax; (281) 565-1359 E-mail: PDSamemorylog.com Prudhoe Bay Field Gffice Phone: {907) 659-2307 Fax: {907) 659-2314 u ~~- ~~~ aou ?9 ~~ i ~ PDS Multifinger Caliper 3D Log Plot Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2F-17 Date : July 16, 2010 Description : Detail of Caliper Recordings Across Area Where LDL Found Tubing Leak (8,337). Comments Depth Max. Pen. (%) Max. I.D. (ins.) 3-D Log Image Map 1ft:240ft'0 100 2.5 3.5 0° 0° 90° 180° 270° 0° Min. I.D. (ins.) 2.5 3.5 Nominal I.D. (ins.) 2.5 3.5 Joint 263 -~~ '"`~ - ~ -; 8290 - - __- Joint 264 8300 Line Corrosion 50% Wall i Penetration $310 ~--+- 8320 Joint 265 8330 ~ ~b ~ Line Corrosion Penetration 8340 ~ ` ,,,_ 8350 ~ ~ ° ~.~~ _ `"` _ - _ _ - ~' ~ -- d I J i 266 8360 ~ °"---'~ o nt ~ Line Corrosion i ~°. 53% W ll 70 ,. a $3 Penetration ~` ~ ~ _ -~- I 8380 ' ~ ~ _ -~... ~ _e ~ _. Joint 267 ~ -- Line Corrosion 8390 ~ 44% Wall -~ ' Penetration - Nominal I.D. (ins.) 2.5 3.5 Min. I.D. (ins.) 2.5 3.5 Comments Depth Max. Pen. (%) Max. I.D. (ins.) 3-D Log Image Map 1ft:240ft 0 100 2.5 ~ 3.5 0° 0° 90° 180° 270° 0° • Correlation of Recorded Damag Pipe 1 3.5 in (13.8' - 8763.7') Well: Field: Company: Country: Survey Date: ;e to Borehole Profile 2 F-17 Kuparuk ConocoPhillips Alaska, Inc. USA July 16, 2010 . A pprox. Tool De viation ^ A pprox. Borehol e Profil e 1 17 25 774 5+ ~ i 1557 75 2338 I GLM 1 1(30 3151 `° ~ 125 3928 ~ .~ z L ~ 150 4704 a '0 0 175 5485 GLM 2 } 6265 225 7077 250 7853 GLM 3 275 8668 277 8764 0 5 0 1 00 Dam age Pr ofile (% wall) / Tool D eviatio n (degr ees) Bottom of Survey = 277 C~ • PDS Report Overview -~,.- ~:,. Body Region Analysis Well: 2F-1 7 Survey Date: July 16, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. 218527 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Analyst: C. Waldrop Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f L-80 AMB-CUE 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (% wall) ~ penetration body - metal loss body 300 2 50 200 150 100 50 0 0 to 1 to 10 to 1 % 10% 20% 20 to 40 to over 40°/ 85°/ 85% Nurnber of ~oints anal sed total = 288 pene loss . 0 5 37 6 282 0 131 115 0 0 0 0 Damage Configuration (body ) 150 100 50 ~ isolated general line nng hole/poss pitting corrosion corrosion corrosion ible hole Number of ~oints damn ed total = 279 120 91 68 0 0 Damage Profile (% wall) i• penetration body Fir- metal loss body 0 50 100 n GLM 'I GLM 2 GLM 3 Bottom of Survev = 277 Analysis Overview page 2 • PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 AMB-EUE Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal LD.: 2.992 in Country: Survey Date: • -LATION SHEET 2 F-17 Kuparuk ConocoPhillips Alaska, Inc USA July 16, 2010 Joint No. Jt. Deplh (Ft.) I'cvi. Upset !his.) Pen. Body (Ins.) I'en. °% ~11e~tal loss °~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 14 i? 0.03 11 -1 2.93 PUP 1 17 t? 0.03 13 Z 2.94 Shallow corrosion. Sli ht Bucklin - 2 48 !) 0.04 1 F~ ~' 2.95 Shalhw ittin . 3 80 i? 0.11 44 2.94 Isolated ittin - 4 111 !? 0.07 ~? 2.95 Isolated ittin 5 142 U 0.08 31 2.95 Corrosion. 6 173 l) 0.07 28 2.95 Corrosion. Sli ht Bucklin . 7 204 t) 0.04 1.5 2.95 Shallow ittin . 8 236 t i 0.09 34 S 2.96 Isolated ittin . 9 264 Ii 0.03 11 2 2.96 10 294 (? 0.04 1 7 ~' 2.95 Shallow corrosion. 11 326 (1 0.03 13 4 2.95 Shallow ittin Sli ht Bucklin . 12 356 !? 0.04 15 y 2.94 Shallow corrosion. 13 388 ! i 0.04 I (i -t 2.96 Shallow corrosion. 14 417 i? 0.04 I4 I 2.95 Shallow ">ittin . 15 448 i? 0.04 1 5 2.94 Shallow corrosion. 15.1 479 !! 0.01 i, 2.96 PUP Sli ht Bucklin . 15.2 485 U 0 ~) t1 2.81 Camco DS-Ni le 15.3 487 t? 0.01 t) 2.92 PUP 16 492 O 0.03 13 ~ 2.95 Shallow corrosion. _ 17 523 (' 0.04 15 7 2.94 Shallow ittin . 18 555 U 0.03 11 2.96 Sli ht Bucklin . 19 586 t) 0.05 19 1 2.94 Shallow corrosion. 20 618 (? 0.05 Z I 1 2.94 Corrosion. i 21 649 !? O.US _>I) ~ 2.94 Shallow corrosion. 22 681 ~~ 0.04 17 ~ 2.93 Shallow corrosion. Lt De osits. 23 711 O 0.03 d ~' 2.96 Sli ht Bucklin . 24 743 i? 0.07 26 _' 2.94 Isolated ittin . 25 774 (? 0.04 17 2.95 Shallow ittin . 26 805 ! 0.06 24 ~' 2.96 Isolated ittin . 27 837 !) 0.07 2i _' 2.95 Corrosion. 28 868 U 0.08 31 4 2.95 Isolated ittin . 29 900 ~? 0.05 1 t3 5 2.94 Shallow ittin Sli ht Bucklin . 30 931 +? 0.04 1 % 2.95 Shallow ittin . 31 962 t? 0.06 ~4 -? 2.94 Corrosion. 32 993 t? 0.05 21 t 2.95 Isolated ittin . 33 1025 (• 0.05 ~'0 ? 2.93 Corrosion. 34 1056 U 0.07 ~8 2.96 Isolated ittin Sli ht Bucklin . 35 1087 i? 0.06 _'~ 2.95 Corrosion. 36 1119 t? 0.06 2 5 2.94 Corrosion. - 37 1150 U 0.07 Ztf ~ 2.95 Isolated ittin Lt De osits. 38 1182 1? 0.07 ZED ? 2.94 Corrosion. 39 1213 t, 0.06 2:3 2.94 Corrosion. 40 1245 t? 0.05 1 t9 ~ 2.93 Shallow corrosion. Sli ht Bucklin . 41 1276 U 0.07 Z8 ? 2.95 Corrosion. 42 1308 U 0.05 ;'t) 2.94 Shallovv~ corrosion. 43 1338 (? 0.06 2z 2.94 Corrosion. 44 1369 i? 0.06 ?5 ~ 2.92 Isolated ittin Sli ht Bucklin . 45 1401 0.07 '~9 ~ 2.94 Corrosion. Lt. De osits. 46 1432 0.06 ,: i 2 2.94 Isolated ~ittin . _ Penetration Body Metal Loss Body Page 'I PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 AMB-EUE Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • iLATION SHEET 2 F-17 Kuparuk ConocoPhillips Alaska, Inc USA July 16, 2010 Joint No. Jt. Depth (Ft.) I'c~n. Ul~sel (In,"i Pen. Body (Ins.) I'en. `% Metal Ic~ss %~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 47 1464 t~ 0.08 3(7 2.93 Corrosion. Lt. De osits. 48 1494 c) 0.06 ,!-1 a 2.95 Isolated ittin . 49 1526 U O.Oh .' i :1 293 Corrosion. 1 t. De. osits. 50 1557 ~~ 0.06 2.93 Corrosion. Sli ht&~cklin . 51 1588 {~ 0.05 'U 2.93 Isolated ittin~. 52 1618 Ci 0.05 I f9 2.96 Shallow ittin . 53 1 b50 i i 0.09 > 5 _' 2.95 Isolated ittin . 54 1681 i? 0.06 Z-1 ( 2.94 Isolated ittin 55 1713 i~ 0.06 22 2.93 Corrosion. Sli ht Bucklin . 56 1744 i~ 0.05 2li -1 2.92 Shallow corrosion. Lt. De osits. 57 1776 it 0.05 18 2.94 Shallow ittin - 58 1807 a 0.05 2t) 2.93 Shallow ittin - 59 1839 i) 0.09 3 ? 2.93 Corrosion. - 60 1871 O 0.08 3 I 2.93 Corrosion. Sli ht Bucklin - 61 1901 i ~ 0.09 37 S 2.94 Corrosion. 62 1933 c? 0.06 24 2.94 Isolated ittin . 63 1964 +~ 0.06 25 2.93 Isolated ittin . 64 1994 U 0.07 29 2.94 Corrosion. 65 2025 i~ 0.07 Zt3 2.94 Isolated ittin 66 2057 !~ 0.08 32 2.93 Corrosion. Sli ht Bucklin 67 2088 (~ 0.07 2(i i 2.94 Isolated ittin. 68 2120 t? 0.07 26 2.94 Isolated ittin . 69 2151 a 0.04 16 ~' 2.94 Shallow ittin . 70 2183 t~ 0.06 ~4 2.93 Corrosion. 71 2212 U 0.06 24 2.93 Isolated ittin . 72 2244 ii 0.05 2tl 2.94 Shallow ittin Sli hl Bucklin 73 2275 it 0.07 27 2.93 Corrosion. - 74 2306 ii 0.06 25 2.95 Isolated ittin - 75 2338 ~~ 0.07 28 ~ 2.94 Isolated ittin - 76 2369 U 0.07 28 3 2.94 Isolated ittin - 77 2401 t) 0.07 Z(/ _' 2.94 Isolated ittin Lt De osits. 78 2431 U 0.06 _'< -l 2.93 Corrosion. Sli ht Bucklin _ 79 2462 tt 0.05 19 ~~ 2.93 Shallow corrosion. 80 2493 O 0.06 ?5 ~' 2.87 Isolated ittin Lt. De osits. 81 2525 it 0.05 It3 2.93 Shallow ittin Lt. De osits. 82 2556 (i 0.05 19 293 Shallow corrosion. 83 2588 t~ 0.06 ?_5 295 Isolated ittin . 84 2618 U 0.08 Str a 2.93 Isolated ittin Sli ht Bucklin . 85 2650 n 0.07 27 2.91 Isolated ittin Lt. De osits. 86 2682 l1 0.09 a4 Z 2.93 Isolated ittin - 87 2712 0 0.08 32 a 2.94 Corrosion. Lt. De osits. - 88 2744 0 0.10 19 ~ 2.91 Corrosion. Lt De osits. - 89 2776 l) 0.07 2t) 1 2.94 Isolated ittin Lt. De osits. 90 2807 +.~ 0.09 ~i ~ 2.92 Corrosion. Lt De osits. Sli ht Bucklin . 91 2838 i~ 0.07 (1 2.93 Corrosion. Lt. De osits. 92 2869 ~? 0.08 >1 _' 2.90 Isolated ittin Lt. De osits. 93 2899 it 0.08 3> ~; 2.88 Corrosion. (.t. Deposits. 94 2930 ii 0.09 3~ ~ 2.91 Isolated ittin . Lt. De osits. 95 2961 i? 0.08 ~~) } 2.93 Corrosion. Lt. De osits. Sli ht Bucklin . 96 2993 i) 0.09 ~~ -1 2.92 Isolated illin LL Deposits. _ Penetration Body Metal Loss Body Page 2 • PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf 1-80 AMB-FUF Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal LU.: 2.992 in Country: Survey Date: ELATION SHEET 2 F-17 Kuparuk ConocoPhillips ,Alaska, Inc USA July 16, 2010 Joint No. Jt. Depth (Ft) I'cn. (lFsc•i (li~.j Pen. Body (Ins.) Pen. % Metal Loss `;'~~ Min. LD. (Ins.) Comments Damage Profile (%wall) 0 50 100 97 3023 n 0.08 32 ~' 2.93 Isolated ittin Lt. De osits. 98 3055 !? 0.10 39 ! 2.93 Corrosion. Lt. De osits. 98.1 308.5 ~! 0.06 24 ~' 2.94 PUP Isolated ittin . 98.2 3100 ti 0 O t? N A GLM 1 Latch @ 6:30 98.3 3106 t? 0.05 1~) 2.92 PUP Shallow itlin Lt. De osits. - 99 3121 U 0.08 i~' 2.90 Corrosion. Lt De osits. Sli ht Bucklin . 100 3151 U 0.12 4tS -t 2.89 Corrosion. Lt. De osits. 101 3182 U 0.09 5 -1 2.89 Corrosion. Lt. Deposits. 102 3213 i? 0.07 27 ? 2.89 Corrosion. Lt. De osits. 103 3245 U 0.07 28 2 2.93 Corrosion. 104 3276 t? 0.08 >1 3 2.90 Isolated ittin Lt De osits. - 105 3307 t? 0.08 >"I i 2.86 Corrosion. Lt. De osits. Sli ht Bucklin - 106 3338 (? 0.09 5 5 2.90 Corrosion. Lt De osits. 107 3368 t? 0.09 ;6 ~ 2.87 Corrosion. Lt. De osits. 108 3399 (? 0.09 35 4 2.87 Corrosion. Lt. De osits. 109 3429 (~ 0.09 34 -t 2.84 Corrosion. Lt. De osits. 110 3461 i? 0.09 ~5 > 2.86 Corrosion. Lt De osits. Sli ht Bucklin . 1 1 1 3493 (? 0.09 > ; 4 2.87 Corrosion. Lt. De osits. 112 3524 (? 0.09 ,5 4 2.84 Line corrosion. Lt. De osits. 113 3555 i? 0.10 37 ,! 2.83 Corrosion. Lt. De osits. 114 3587 a 0.10 ;~a 2.87 Corrosion. Lt De osits. 115 3619 ~? 0.11 4~ -1 2.83 Corrosion. Lt De osits. 116 3650 (1 0.10 ;t9 ~ 2.88 Corrosion. Lt. De osits. Sli ht Bucklin . 117 3680 tt 0.09 ~'> 2.82 Corrosion. Lt. De osits. ~ 118 3711 (~ 0.08 ;~> 2.87 Corrosion. Lt De osits. ~ ~ 1 19 3742 1 i? > 0.10 4t) -1 2.88 Line corrosion. Lt De ~ osits. I 120 3774 l~ 0.09 3:> 2.85 Corrosion. Lt. De osits. ~ 121 3806 a 0.10 -11 2.86 Corrosion. Lt. De osits. 122 3836 t~ 0.07 Z' ~ 2.88 Corrosion. Lt. De osits. 123 3865 t? 0.12 47 2.88 Corrosion. Lt. De osits. Sli ~ht Bucklin . 124 3897 (? 0.08 32 2.88 Corrosion. Lt. De osits. 125 3928 C~ 0.10 i7 a 2.87 Corrosion. Lt. De osits. 126 3960 (i 0.12 46 2.87 Corrosion. Lt. De osits. - 127 3990 (> 0.10 9 4 2.86 Line corrosion. Lt Ue osits. - 128 4021 i ~ 0.09 ; -1 2.87 Corrosion. Lt. De osits. - 129 4054 ~! 0.12 47 t1 2.85 Corrosion. Lt. Deposits. Sli ht Bucklin - 130 4084 t? 0.12 48 ~ 2.90 Corrosion. Lt. Deposits. - 131 4115 !? 0.09 ~6 -l 2.87 Corrosion. Lt De osits. - 132 4146 ~? 0.10 39 t> 2.87 Isolated ittin Lt. De osits. 133 4177 t) 0.08 31 ? 2.87 Corrosion. Lt De osits. 134 4209 U 0.10 t, S 2.87 Isolated ittin Lt. Dc osits. 135 4240 i? 0.10 ~8 i 2.88 Corrosion. Lt. De osits. 136 4271 (? 0.10 i9 ? 2.88 Corrosion. Lt. De osits. Sli ht Bucklin . 137 4302 t? 0.11 44 1 2.87 Corrosion. Lt. De osits. 138 4333 (? 0.08 i> 2.88 Corrosion. Lt. De osits. 139 4364 ii 0.07 ~~} 2.88 Corrosion. Lt. De osits. 140 4394 U 0.11 <7~1 2.88 Isolated ~ittin Lt. Deposits. 141 4426 t? 0.09 4 ~ 2.88 Corrosion. Lt. De osits. Sli ht Bucklin . 142 4458 U 0.11 4~ i 2.88 Isolated ittin Lt De osits. 143 4489 t) 0.09 37 ~' 2.89 Isolated ~ittin LL De osits. `~ ` ` _ Penetration Body Metal Loss Body Page 3 i PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 AMB-LUE Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: -LATION SHEET 2 F-17 Kuparuk ConocoPhillips ,Alaska, Inc USA July 16, 2010 Joint No. Jt. Depth (Ft) i'cn. t )Inet (Ins.) Pen. Body (Ins.) Pen. °io :Metal Loss 4°~~ Min. LD- (Ins.) Comments Damage Profile (% wall) 0 50 100 144 4520 O 0.09 37 -# 2.90 Isolated ~ittin Lt. De osits. - 145 4551 (1 0.12 46 '~ 2.81 Corrosion. Lt De osits. 146 4581 1? 0.11 44 ~' 2.89 Corrosion. I_t De osits. 147 4612 U 0.09 > ; _> 2.88 Corrosion. Lt. De osits. Sli ht Bucklin . 148 4643 C+ 0.08 sl ~ 2.84 Corrosion. Lt. De osils. - 149 4672 U 0.10 >~) 6 2.88 Corrosion. Lt. De osits. 150 4704 ~~ 0.08 3 -1 2.87 Corrosion. Lt. De osits. - 151 4735 t) Q11 45 3 2.90 Corrosion. Lt. Deposits. _ 152 4766 ~) 0.09 .36 3 2.92 Corrosion. Lt De osits. Sli ht Bucklin - 153 4797 t) 0.11 1 t~ 2.86 Corrosion. Lt. De osits. 154 4829 ti 0.12 -t6 2.92 Line of .its. Lt. De osits. - 155 4860 (~ 0.10 4i) I 2.92 Line of its. 156 4892 l) 0.09 34 - 2.91 Line corrosion. Lt De osits. 157 4923 it 0.08 3U _' 2.93 Line of its. Sli ht Bucklin . 158 4954 t~ 0.09 ~6 2.92 Line corrosion. 159 4985 t) 0.10 ~~) 2.92 Line corrosion. 160 501 7 U 0.15 58 5 2.93 Line of its. ~ , 161 5048 r) 0.11 43 4 2.92 Line of its. Lt. De osits. - 162 5080 t1 0.06 2"~ t3 2.93 Line of its. i 163 5111 li 0.11 44 2.93 Line corrosion. Sli ht Bucklin . ~ 164 5143 (1 0.07 Zt3 ~l 2.91 Line of its. I 165 5175 (~ 0.12 ~7 > 2.92 _ Line of its. - 166 5206 t) 0.11 44 ) 2.93 Line corrosion. - 167 5236 (~ 0.11 42 ~' 2.94 Line corrosion. - 168 5267 (1 0.09 35 ~ 2.94 Line of its. Sli ht Bucklin - 1G9 5297 ~) 0.10 ~t; ~ 2.91 Line of its. Lt De osits. - 170 5327 i) 0.09 3=f t 2.92 Line corrosion. 171 5359 a 0.09 ;; 2.93 Linc of its. 172 5390 ! ~ 0.14 5.1 2.93 Line of its. - 173 5422 ~? 0.08 2.93 Line corrosion. Sli ht Bucklin 174 5453 ~) 0.07 <<) 2.93 Line of its. - 175 5485 ~) 0.10 ~' } 2.91 Line corrosion. - 176 5516 t) 0.10 39 ~ 2.93 Line corrosion. - 177 5548 !) 0.08 S2 2.92 Line corrosion. _ 178 5579 ~ ~ 0.1 1 ~ 2.90 Line of its. - 179 5609 ~~ 0.08 3"I _' 2.93 Line of pits. Sli ht Bucklin - 180 5641 (1 0.09 3 ; 2.93 Line corrosion. - 181 5673 0 0.11 44 1 i i 2.92 Line of its. L t. De osits. 182 5704 U 0.11 X13 2.91 Line of its. 183 5735 ~) 0.10 ~ ? 2.92 Line of its. - 184 5766 (? 0.13 51 ~' 2.92 Line corrosion. Lt De osits. _ 185 5798 U 0.08 31 ? 2.93 Line corrosion. 186 5829 t' 0.11 4'. (, 2.92 Line corrosion. Sli ht Bucklin . 187 5861 i! 0.11 4~ -1 2.93 Line corrosion. ~ 188 5892 ~~ 0.16 64 - 2.93 Line corrosion. 189 5924 (~ 0.15 6U 2.92 Line corrosion. I I 190 5954 0.12 4;' ~ 2.92 Line of pits. 191 5986 ~ ~ 0.12 ~9 2.93 Line of its. 192 6017 0.11 44 4 2.93 Line of its. Sli ht Bucklin 193 6048 0.14 i7 i 2.91 Line of its. _ Penetration Body Metal Loss Body Page 4 • PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 AMB-FUF Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal LD.: 2.992 in Country: Survey Date: • iLATION SHEET 2 F-17 Kuparuk ConocoPhillips Alaska, Inc USA July 16, 2010 Joint No. Jt. Depth (Ft.) I'r~n. UI»~~1 Ilr~..? Pen. Body (Ins.) I'en. % ~1eta) I cuss %~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 194 6078 l~ 0.12 48 (~ 2.93 Line of pits. 195 6109 i) 0.14 55 2 2.93 Line of its. _ 196 6"140 ~i 0.12 46 2.93 Line of its. 197 6171 U 0.13 ~3 [, 2.92 Line of its. - 198 6203 (' 0.15 5~) ~ 2.91 Line corrosion. Sli ht Bucklin 199 6234 U 0.14 5 5 2.92 Line corrosion. - 200 6265 ~? 0.16 b4 -t 2.91 _ Line corrosion. Lt. De osits. - 201 6294 tl 0.17 69 2.91 Line corrosion. Lt. De osits. 201.1 6325 i) 0.04 14 1 2.93 PUP Shallow ittin . 201.2 6340 O 0 0 tl N A GLM 2 Latch ~ 12:30 201.3 6345 r7 0.10 38 ~' 2.93 PUP Line of its. Sli ht Bucklin . 202 6360 !~ 0.12 ~~? - 2.92 Line corrosion. Lt De osits. 203 6392 t~ 0.16 E,l -1 2.93 Line of its. Lt De osits. 204 6424 !% Q14 5-t -1 2.89 Line of its. 205 6454 a Q.14 57 5 2.91 Line of its. _ 206 6485 i~ 0.13 53 4 '293 Line corrosion. Sli ht Bucklin . 207 6517 (~ 0.15 61 6 2.93 Line corrosion. 208 6548 tr 0.16 63 4 2.93 Line corrosion. 209 6579 O 0.17 65 -l 2.92 Line of its. 210 6611 ~~ 0.10 ~9 2.93 Line of its. 211 6643 !` 0.14 55 ~ 291 Line of its. Sli ht Bucklin . 212 6674 !? 0.14 57 `~ 2.92 Line of its. Lt De osits. 213 6705 „ 0.12 47 ~ 2.91 Line of its. 214 6735 ~? 0.12 X1£5 -l 2.91 Line corrosion. 215 6765 ~~ 0.13 S_' -1 2.92 Line of its. 216 6796 i1 0.11 d3 S 2.91 Line corrosion. Sli ht Bucklin . 217 6828 i~ 0.16 (,l 5 2.93 Line of its. 218 6857 !? 0.12 4t3 2.93 I ine corrosion. Lt. De osits. - 219 6888 t~ 0.16 (,1 2.91 Line corrosion. - 220 6921 U 0.13 5t) 1 292 Line of its. - 221 6951 !~ 0.12 4£i _' 2.91 Line corrosion. Sli ht Bucklin 222 6982 ri 0.13 52 3 2.94 Line corrosion. 223 7014 ~' 0.17 (,7 i~ 2.93 Linc corrosion. 224 7046 ii 0.16 f~5 -1 '2.92 Line corrosion. - - 225 7077 r ~ 0.11 43 > 2.93 Line of its. 226 7109 i) 0.14 5(, -1 2.92 Line corrosion. - 227 7141 U.i~~) 0.14 ~3 ~ 292 Line corrosion. Sli ht Bucklin 228 7172 O 0.13 52 5 2.92 Line of its. Lt. De osits. 229 7203 U 0.14 5+ 2.93 Line corrosion. - 230 7235 ~! 0.13 =~4 + 2.91 Line corrosion. Lt. De osits. 231 7266 U 0.10 -11 ; 2.93 Line of its. 232 7295 ~? 0.12 -1') 2.92 Line of its. 233 7324 !? 0.12 4C> 2.93 Line of its. Sli ht Bucklin - 234 7357 t) 0.13 52 4 2.93 Line of its. 235 7387 U 0.13 50 4 2.94 Line corrosion. 236 7418 (1 0.13 52 4 2.94 Line of its. 237 7449 U 0.14 54 ', 2.93 Line corrosion. 238 7482 U.t)5 0.13 51 -1 2.93 Line corrosion. 239 7512 ! ~ 0.14 50 -1 2.93 Line of its. Sli ht Bucklin . 240 7544 i) 0.13 5t) 5 2.94 Line corrosion. Penetration Body Metal Loss Body Page 5 PDS REPORT JOINT TABUL ATION SHEET Pipe: 3.5 in 9.3 ppf L-80 AMB-EUE Well: 2F-17 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal LD.: 2.992 in Country: USA Survey Date: July 16, 2010 Joint No. Jt. Depth (Ft.) I'cn. t 1F~~e! (Ins.} Pen. Body (Ins.) I'cn. `% Metal I oss °h, Min. LD- (Ins.) Comments Damage Profile (% wall) 0 50 1 ~"~ ~'~i 241 7575 !' 0.14 55 4 2.91 Line corrosion. ~ I 242 7608 (? 0.13 51 ~ 2.92 Line corrosion. 243 7638 (? 0.10 41 _' 2.91 Line of _its. 244 7668 ~:?. I ~ 0.14 56 4 2.90 Line of its. Sli ht Bucklin . 245 7699 !) Q14 5:; 2.92 Line of its. 246 7730 0 0.14 54 -t 2.93 Line of its. 247 7759 U 0.17 67 i 2.90 Line corrosion. 248 7791 i) 0.14 54 ~> 2.90 Line corrosion. - 249 7822 ~?.t)5 0.13 49 2.92 Line corrosion. - 250 7853 U 0.11 4.; 2.92 Line of its. Sli ht Bucklin . 251 7882 t) 0.09 i4 a 2.91 I ine corrosion. - 252 7916 U 0.13 52 5 2.91 Line corrosion. Lt De osits. - 253 7947 l? 0.10 41 S 2.91 Line corrosion. - 254 7977 !) 0.15 57 4 2.92 Line corrosion. - 255 8009 !? 0.15 58 2 2.90 Line corrosion. - 256 8041 U 0.11 4:3 2 2.91 Line of its. Sli ht Bucklin 257 8071 O.UB 0.15 59 2.90 Line corrosion. - 258 8103 O 0.13 52 (i 2.90 Line corrosion. Lt. De osits. 259 8132 t? 0.13 51 5 2.90 Line of its. 260 8163 t? 0.17 67 5 2.91 Line corrosion. Lt. De osits. 261 8195 !) 0.13 51 4 2.92 Line corrosion. - 262 8226 !! 0.14 i4 i 2.91 Line of its. Sli ht Bucklin ~' 263 8257 !? 0.14 5 3 i 2.92 Line corrosion. Lt. De osits. _ _ 264 8288 U 0.13 5t) ~~ 2.92 Line corrosion. Lt. De osits. 265 8318 i? 0.12 48 (, 2.90 Line corrosion. Lt De osits. 266 8351 ~? 0.1 ~ 5 ; -1 2.91 Line corrosion. 267 8382 .) 0.11 a4 2.91 Line corrosion. - 268 8413 i? 0.16 G3 -i 2.90 Line corrosion. Sli ht Bucklin - 269 8445 tr 0.12 48 a 2.88 Line corrosion. - 270 8477 t? 0.09 ~7 2.92 Line corrosion. 271 8508 U 0.11 4 a 2.91 Line of its. 272 8539 !) 0.11 44 2.90 Line of its. Lt. De osits. 273 8571 ! i 0.09 b ~~ 2.89 Line corrosion. Sli ht Bucklin . 274 8602 i? 0.07 26 2.90 Line of its. 274.1 8632 (? 0.05 1'r3 2.91 PUN Shallow ittin . 274.2 8646 !) 0 0 !~ N A GLM 3 Latch @ 9:30 274.3 8653 t? 0.03 10 2.92 PUP 275 8668 (? 0.17 6b 4 2.92 Line of its. Sli ht Bucklin . 275.1 8698 [) 0 ~) a 2.75 Cameo D-Ni le No Go 275.2 8700 t? 0.03 lU ? 2.93 PUP 275.3 8705 !> 0 (? t) 3.00 Baker PBR w 10' Stroke 275.4 8718 u 0 U U 2.99 3.5" Tubin Tail 275.5 8720 U 0 U !) 2.78 Baker SABL-3 Packer Liner Han er 275.6 8728 t? 0.02 8 I 2.92 PUP To of 3.5" Liner. 276 8732 t? 0.12 46 _' 2.93 Line of its. 277 8764 !? 0.12 4~) ~' 2.93 Line of its. Penetration Body Metal Loss Body Page 6 • s PDS Report Cross Sections ~~~ ~.~ Well: 2F-1 7 Survey Date: July 16, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. 218527 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf L-80 AMf3-EUE Analyst: C. Waldrop Cross Section for Joint 201 at depth 6315.89 ft Tool speed = 43 Nominal ID = 2992 Nominal OD = 3.500 Remaining wall area = 97 °~° Tool deviation = 70 " Finger 22 Penetration = 0.1 74 ins Line corrosion 0.17 ins = 69% Wall Penetration HIGH SIDE = UP Cross Sections page 1 • • S PDS Report Cross Sections ,~ Well: 2F-1 7 Survey Date: July 16, 2010 Field: Kuparuk Tool Type: UW MFC 24 No. 218527 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 3.5 ins 9.3 f L-80 AM&EUE Anal st: C. Waldro Cross Section for Joint 247 at depth 7776.86 ft Tool speed = 43 Nominal ID = 2.992 Nominal OD = 3.500 i Remaining wall area = 97 °% Tool deviation = 60 " Finger 1 Penetration = 0.171 ins Line corrosion 0.17 ins = 67% Wall Penetration HIGH SIDE = UP Cross Sections page 2 ,,~'\~ KUP ~ 2F-17 ConoeoPhillips ( ~ II Attributes An le 8 MD TD Wellbore APIIUWI FlNtl Name Well Status Inc! (°) MD jmce) Act B[m jrt Ke) ' I / 500292273700 KUPARUK RIVER UNIT INJ 60.13 zsno.n6 9,561.0 Comment K251ppm) Date Arnotatlon Entl Date KB-Grtl jR) Rig Relea se Date -- SSSV: NIPPLE Last WO: 2/5!1997 Well Confi -2F-1 i 4/18f201G "<4 0 u6 PM Smamanc-Aaual Amotatlon DepNIRKB) End Date Amotatlon Last Morley End Date Last Tag: SLM 9.190.0 417/2010 Rev Reason: TAG FILL Imosbor 4/18/2010 Casin Strin s String O D S[dng ID Set Depth Set Depth (ND) String Wt S[dng Casing Descrlptlon pn) (n) ToP (~~ I~BI 1RK8) pbsrcp Grace String To p Thrd ~ ~ CONDUCTOR 1 6 15.062 0.0 121.0 127.0 62.50 H-00 J I SURFACE 75 /3 6.750 0.0 4,073.0 3,135.3 29.70 L-30 r~ND~~rTOR, PRODUCTION 51 /2 4 767 0 0 8 932 0 5 898 3 15 50 L-80 121 . . . . , . . LINER 31 /2 2.867 8,718.0 9,561.0 9.20 L50 Tubin Strin s Stnng l> D String ID Set Depth Set Depth jTVD) String Wt String Turing Descrfptlon Pn1 PM Top jmcB) p[I(B) jmc6) (IbsiR) Grade String To p Thrtl wPPLE, a3s TUBING 3 1/ 2 2.992 0.0 8,718.0 5,738.4 9.30 L-80 A8M-EUE Other In Hole A ll Jewe l :Tubin Run 8 Retrievabi Fish etc. Top Depm jrvo) Top Ind Top (RKB) (~8) (°) Descrlptlon Comment Run Date ID (In) 496 496.0 0.43 N IPPLE Camco'DS' Nipple 4/1/1997 2.813 3 104 2 646 1 58 27 G AS LIFT BST/AXT/1/DMYIT-1!//Comment: STA1 4/1/1997 2 900 SAS LIFE, , , . . . 310° f+.336 4,410.E 57.44 G AS LIFT BST/AXT/7/DMYff-i//! Comment STA 2 4/1/7997 2.900 S.G43 5.683.1 44.70 G AS LIFT BST/AXT/7/DMYIf-10/ Comment STA 3 5(](1997 2.900 8,695 5,721.0 41.54 N IPPLE Camco'D' Nipple NO GO 4/1/1997 2]50 SURFACE, 8,703 5.727.0 41.25 P BR Baker w/ 70' Svoke 4/1/1997 3.000 a,e16 8,717 5.737.7 40.74 A NCHOR Baker KBH-22 Anchor Seai Nipple 4/1/1997 3.000 8.778 5.7384 40.70 T TL 3/31/1997 2992 8,778 5.738.4 40.70 P acker Baker SABL-3 PKR! Liner Hanger 4/1/1997 2780 ~A; LIFT, Pertorations 8 Slots 6,336 Shat Top jrvD) Btm (TVD) Dens Top jmcB) Bfm jm®) (mcBl l~el Zone Date Ish... 7YPe ComnerR 9,038 9,048 5,975 4 5,982.8 C-0, UNIT B, 8/2!1997 6.0 IPERF 60 deg. Phasing: 2.5" HSD DP 2F-17 9.126 9.136 6.041.8 6.049.4 A-5. 2F-17 8/2/1997 6.0 IPERF 60 deg. Phasing; 2.5" HSD DP cAS uFr. 6 643 9,164 9,187 6,071.4 6,084.4 A-0, 2F-17 5!6/1997 4.0 IPERF 180 deg. Phasing; 2.5" HSD BH NIPPLE, 8695 PfiR, e i03 MICNUR. ~l II 8,711 ~~ 00 it L, 6,118 Pecker, 8,718 PRODUCTION, 8,932 IPERF, 9,038-9 W b IPFRF 9,126tia,136 IPERF, 9,164-9181 LINER. 9 561 TD, 9 561 ~::~;+~._-.~,6°.~,t'ili-'a1r'uC~.'1.44'a''ic„.3b'~'~.=~~.~~:" kl'~ 1, ~ rtf -!7 Ktlt! AR~O Aiss~t~~ IItG. 5~s~xY of 1-~ariuc FfE~t"Aa+c! ~r~jt ~- ITEMS C{}I~11a1 ~TI± 41x s~'~~P4 ~'~, i,; "~;* X25 i27~ a~ t 7821;1 Gi ~,~ ~r75-9 77 GL1~1 ~'2 p1MJ2/ y7~ iJ 1<(~ PA Jt Iit RT to Yt~sln.~' ~•i~.4~~. F1-~-~'~ar.~.~.~`~t~`~- -, •~.Y' ~~*.~ !G dirt 14', :~ t a1 ` 1 Ll~ks`+~t~3! ~+~~ e~~ ~~ ~ ~ ", ~ ~ ' ~ -~ 3".~ ~`_+~; 3.112`. ~.3Y. L-94. EiE~~~-~~±~ ~ `a~,~ r~ _ 3.1Pz" Fte{.~1"4' Gnll~~~t~~i ".~ 3.1 ~ 9.:3t-, ~-${~, ti~$\4 ~lf~ ~~r l~,`~~ ~ti,~.a±,~ ~` s,~ ~., ~,_ t~ :-: ~..~,~~ _~._ n _ 3.1+'2`, ~ ~lr 1M 3t~. r\13tit ~+ t_ \~~~ Ir`'~^'' ~c ..~,;'~` .~ ~`~`, ~~~~~~ -- f Sb t~ Y ~w«,~~] R .rr7 ~ ~,ptl,~ l ~~`Y~ ` q '~ `ilf~~s1~y~~'i ~: k~ >ti ~ ,-..`2 . ~ .. U~.1A~f~t i`~7p~~ iu~.~1t) n^a17'~.,~ k,~5 fi r.~~ _ .,_ , .+acY~nr...... ~aRR~ hc.iil4 \ti~ ~~+ Lsi R~ 4n~§7! ~t ,.- Atocl< t{t3~i C~ t\t~t+r.H•:••ae.#1 °~f' 4~ ~ :~ ~* ~, . 'y. # ^+~= a, ~„~ i #d1t~~rr.~.t to ~~ ._ _..~.. r...~.~..a~....'.... ~;~. .e. m ~;"~t~ .~~_,~. ... . f~~ ~*.1~1 ~4~~ ~Tl# :~~~ 1 d~fi ~i~~3 '#~,~_ ~,~~ _ '~~,~?$ 1'~~~~~ ~~~~ ~_~ ~~.~~ ,~~ ~ ~ .13#1 ~'~•~- _yy~. 6 ~ . ~'~ ~~>, . t .i!! 1 ~ ~~ .. 't .1.....~ .~~~ ~3~.~ {~.'~'~ t~ '~•!~ t'~~ , l ~ ~~~.~~ ,t ~ f};},, ~'d ~1 ~~.m~2 6"13'~.~2 ~~'~,~;~ 6356.~1•a ~~~_35 ~~~~.~_~ l1C~~.a` S1 52 L ~~ far 1S ~~~ ~.._ .- .~ . ~. .. # .. t F _m _ - _ ~. .,_ f~m~-xs• Strir'o~ ~ti"~6cthto wtti~ ,~~+~~'.~?.~~, ~~ ~~''.!;"'. ~ °~ :'~'~~ ~~, ~h ~,s~~ ~'~t !?. a .__ ~. _ - -- a~f ~'ta~~s ~'~tl~>r j,4{6ar„~,, rsk`p-~sct; ~,'+'`a~ ~"`~ '~ g GflR}¢bUttd ~ $ot rn+~+li(~E3C~x+ie~x ~4~~efl~lc'.,~M.~4.4.+~.'~1'~'`9T~y: ?~``,~`~;" '"~'+,"T``"°`„,y~tit a?a"~~.'4,`~"L''"k.*~..k1 ~"(~ ~i. o f ey t~ € f +. 1 .. x[}13 ~1 i`"$'t~ 1~i~~ aist~Cfr~i~ ! 1 ~, ~~1 {~+.h~~.x iF'lfv~~.~ a.. ~`.}~,~t ktl"...''r~'~` %~~""~~" -- _-~...~..._.~.._~xr_ . ,~._..a ~....~ ... .. _,. - , . r . r w „ ~ . - .~.~.,..-- ,i Regg, James B (DOA) Page 1 of 1 From: NSK Problem Well Supv [n1617@conocophillips.co; ] ~ QJ~~,'t~ Sent: Friday, June 04, 2010 2:25 PM ~ To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv Subject: 2F-17 (PTD 196-204) Report of failed MITIA Follow Up Flag: Follow up Flag Status: Blue Attachments: 2F-17 schematic.pdf Tom, Guy, Jim Kuparuk injector 2F-17 (PTD 196-204) failed a diagnostic MITIA on 06/03/10. The TIO prior to testing was 2400/1850/360 with the well SI upon arrival. The well will remain SI while dia nostics are performed. The proper paperwork will be submitted for repair or continue injection pending the outcome of the diagnostics. The well has been added to the monthly report. Attached is a schematic and a 90 day TIO plot. Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 ~~ _ ~ ~ ~ ~ ~ ~~ 8/20/2010 KRU 2F-17 PTD 1962040 6/4/2010 Tin Pressures Plot T11/0 Plot - 2F-17 2500 2000 N 1500 a 1000 500 0 ... ~ +r l _ ~,+ '~ -+ 01-Apr-10 01-May-10 200 150 ai E as 100 Y O t V 50 ~1- 0 01-Jun-10 C~ Date ---- --- ~OtlO~C1~~11~~1~35 ~ ell Attributes _ Nlellbore API/UYJI ~F {d N me W II Status w; i i 500292273100 KUPARUK RIVER UNIT INJ Comment H2S (ppm) Data Annot h n End [ weu ce~ea -zF-v alarzolo zaoo6 Pm --SSSV: NIPPLE LastWO. S~hemazK-n~wai - Annotation Depth (RKB) End Date Annotation Last Tag. SLM 9,190.0 4(72010 Rev Reason: TAG FILL CONDUCTOR, 121 NIPPLE, 4% GAS LIFT. 3,104 6URFACE, 4,018 GAS LIFT, 6,336 GAS ~ 2F-17 _ lax Angle & MD TD cl (J LID (ttKB) t Bt (RKB( ~ 60.13 I 7,900.00 h 9,561.0 KB-Grd (R) Rig Release Date 2/5/1997 Last Mod By End Date Imosbor 4/18/2010 /D) String Wt 3anng (Ibs/tt) Grade Str g T p Thrd g p ' P I ftK8 _ (RKB) (lbs/f[( Grade Str rig Top Thrd 0 112 2 99 -___ 1 _. ..__ __. .. .. __._. Other In Hole (All Jewelry: Tubing TRunK& Retrlevabl a s 30 ~ so ABM-FUE e, Flsh, etc. Top Depth I (ND) Top Incl Too (ftKBI I (RKB) l (°) Description Comment Run Date ID (inl f -~ I ~~I r t ~ LfFfF ,. Shoff Top (ND) Btm (ND) Den Top (RKB( Btm (ftK8) (RKB) (ftK8) Zone Date (sh... 9,038 9,048 5,975.4 5,982.8 C-4, UNIT B, 82/1997 6.0 2F-17 NIPPLE, B,fi95 ~ 1 tG PBR, 8,703 t' ANCHOR, I~ 8,717 TTL, 8,718 ~ Packer, 8,718 ~~ ( 1. PRODUCTION, 6,932 IPERF, ~ 9,038-9,046 ) IPERF, 9,126-9,136 ' I S t IPERF, } 9,164-9,181 , LINER, 9,561 TD, 9,561 ~~----ii DP • ,_~' ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Sept 14, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 ~~~~~~~ SF~" ~~ :~ 20~~ Dear Mr. Maunder: • ~~~+~~ ~` Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pum~ed August 20~' -Sept 11th, 2008. The corrosion inhibitor/sealant was pumped Sept 12 - 13t ,2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) ~~ Date • Kuparuk Field 9/14/2008 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1C-178 203-041 8' 1.50 8" 9/11/2008 4.68 9/12/2008 2F-17 196-204 12' 10" 2.25 8" 9/11/2008 7.65 9/12/2008 3R-20 192-022 9' 4" 1.50 16" 9/11!2008 1 Y-27 193-088 11' 9" 3.00 20" 8/24/2008 2.97 9/12/2008 1 Y-29 188-091 41' 6.00 5' 8/20/2008 10.20 9/12/2008 1 Y-32 188-093 27' 8" 4.40 32" 8/20/2008 6.80 9/12/2008 1 Y-34 193-091 8' 1.10 27" 8/20/2008 5.95 9/12/2008 1 E-33 197-151 9' 6" 2.10 20" 8/24/2008 7.23 9/12/2008 1 E-104 204-227 7' 1.40 9" 8/24/2008 1.70 9/12/2008 2X-01 183-084 10" NA 10" NA 3.40 9/13/2008 2X-02 183-103 23" NA 23" NA 3.40 9/13/2008 2X-03 183-109 6" NA 6" NA 1.28 9/13/2008 2X-05 183-107 8" NA 8" NA 5.10 9/13/2008 2X-06 183-110 6" NA 6" NA 1.70 9/13/2008 2X-07 183-113 6" NA 6" NA 1.28 9/13/2008 2X-08 183-114 6" NA 6" NA 1.28 9/13/2008 2X-17 195-171 6" NA 6" NA 1.70 9/13/2008 `'r F :~ ~ 'tii~^ l~El~®~le1D~.T1VI • TO: Jim Regg ~ j jt P.I. Supervisor '~~(j ff FROM: Bob Noble Petroleum Inspector State off Alaska • Alaska Oil and Gas Conservation Commission DATE: Tuesday, July 08, 2008 SliBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 2F-17 KUPAR[IK RIV UNIT 2F-17 Src: Inspector NON-CONFIDENTiAi. Reviewed By: P.I. Suprv ~',J a~= Comm Well Name: KUPARUK RN UNIT 2F-17 Insp Num: mitRCN080707143034 Rel Insp Num: API Well Number: 50-029-22731-00-00 Permit Number: 196-204-0 Inspector Name• Bob Noble Inspection Date: 7/5/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ 2F-17 ~TYpe III. W ~'~ 5738 IA ~ 800 ~ 2980 2950 ~ 2940 p T ~ I962oao TypeTest SPT .Test psi ! 2980 OA i a9o soo soo soo Interval 4YRTST per, P / Tubing ~ 2350 2350 ~ 2350 2350 Notes: ~o"~1N~~ Ate ~ ~ ~ 2D08 Tuesday, July 08, 2008 Page 1 of 1 c~ 04/20/07 Schlumbel'gel' 5~ MAY 0'7 2007 NO. 4239 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 D n~Y 0 4 2007 UTC- 10~ -dtlf f¡~~ Field: Kuparuk Well Color CD Job# Date BL Log Description 2F-17 11632699 INJECTION PROFILE 04/30/07 1 1G-17 11632696 PRODUCTION PROFILE 04/27/07 1 1J-170L 1 11661143 MEM INJECTION PROFILE 04/25/07 1 3H-04 11665424 PRODUCTION PROFILE 04/25/07 1 2N-309 11632693 INJECTION PROFILE 04/24/07 1 3A-01 11632691 PRODUCTION PROFILE 04/22/07 1 2H-17 11665423 INJECTION PROFILE 04/24/07 1 1J-180 11632690 PRODUCTION PROFILE 04/20/07 1 2X-11 11632700 PRODUCTION PROFILE 05/01/07 1 2X-13 11632701 PRODUCTION PROFILE 05/02/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. (0 . . MEMORL\NDUM State of Alaska Ala~ka Oil and Ga~ Conservation Commi~sion TO: Jim Regg P.I. Supervisor ---, I ~(:/,(, 7(: '5 04 {( DATE: \\'ednesda), July I"¡ ~OO"¡ SllBJECT: t-.le~hanl~allnlegnty Tests CONOCOPHILLlPS ALASIV; INC ~F-17 FROM: Lou Grimaldi Petroleum In~pector KUPARUK RI\' UNIT ~F-17 Src: Inspe~tor Re\'iewed B~ P.I. Supn j l3f'~ Comm NON-CONFIDENTIAL Permit Number: 196-~0"¡-0 Inspector Name: Lou Gnmaldl Inspection Date: 7/\3/2004 \Vell Name: KUPARUK RIV UNIT 2F-17 Insp Num: mltLGO..¡0713100535 Rellnsp Num: API \Vell Number: 50-029-22731-00-CI0 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. \Vell ~F-17 Type Inj. P TVD 6336 I 1:\ 1560 1560 1000 ]000 1000 P.T. 19620~0 TypeTest SPT Test psi 1~~9 ~5 0:\ 560 560 550 550 550 I Interval ~YRTST P/F P Tubing I ~ooo ~oûo ~oùo ~oüo ~ooo Notes: Observed pretest conditions for 30 minutes Ihen dropped 0:\ pres5ure 10 1000 psi and observed for thirty addilional minutes \Vednesday. July 14.2004 Page 1 of I MEMORANDUM state of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount Commissioner THRU: FROM: Blair Wondzell P.I. Supervisor ~O/:~ leo John Cd~p/ Petroleum Inspector DATE: September 28, 2000 SUBJECT: Mechanical Integrity Tests Phillips Alaska Inc. 2F Pad 15,16,17 Kuparuk River Unit Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. WellI 2F-15 I Typelnj. I G I' T.V.D. I 5872 ITubing 13850 ! 38~)0"'I 3800 I~00 ]IntervalI 4 P.T.D.I 1831720 Typetest] P ITestpsil 1468 I Casingl 1000 I' 1650 I 1640 I 1630 I P/FI P Notes: · WellI 2F-16 P.T.D.I 1831770 Notes: WellI 2F-16 P.T.D.I 1962040 IType,nj.I 'N I T.V.D. 15836 I Tubin'~l 2100 12100 I=~00 I~00 I'nte~a'l 4 Type testI P I TeStpsil 1459 ICa%gI 1025 I 1740 I 1720 I 1720I P/FI P- I I I I Tu ,n ll ,0 I,nter a,I4 I Type testI P I Testpsil 1429 leasingI 1775I 2500I 5200I 2490I PIE I P ' Notes: Notes: P.T.D.I Notes: I Type testI ITest psiI I Casing I I , I I I P/F I I TyPe Inj. I ! T.V.~. I I Tubing I I J I I lntervall I Typetesti ]TestpsiI } Casing J j ] I I P/F I Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test dudng Workover O= Other (describe in notes) Test's Details I traveled to Phillips KEU to witness 4 ),car MIT's on 2F Pad. All tests successful, no problems. .I.T.'s performed: 3_ Attachments: none Number of Failures: 0 Total Time during tests: 1.5 hrs. cc: MIT report form 5/12/00 L.G. MIT KRU 2Fb 9-28-00jC.xls 10/3/00 THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANU ,2001 M P L /It T W T H E IA L U N D E ~ IS M ARK E t~ C:LO~M.DOC PERMIT DATA AOGCC Individual Well Geological Materials Inventory T DATA PLUS Page: 1 Date: 05/24/99 RUN RECVD 96-204 7678 ~T-~CHL~ DITE W/PDC 96-204 MWD SRVY ~PERRY 0-8872 96-204 MWD SRVY u~SPERRY 0-8872.5 FINAL 05/07/97 FINAL 05/07/97 2 05/07/97 FINAL 05/09/97 1 05/09/97 05/14/97 07/07/97 10-407 /~OMPLETION DATE @37~/~ · ~ ~--~ ~/iq /~?'/ DAILY WELL OPS R @ / /~{,j/~ )/ TO _ Are dry ditch samples required? ~~ ~d received? Was the well cored? yes n~..~. ~alysis & description received? Are well tests required. ~S ._~ Received. yes'~-~~' Well is in compliance ~ Inftial CO~ENTS @?/ yes >.~... T D BOX ARCO Alaska, Inc. Post Office Box 100360~ ' Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 3, 1997 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2F-17 (Permit No. 96-204) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 2F-17. This well was originally permitted as an injector. We are pre-producing this well until later this year. We will submit the necessary forms at the time we convert to an injector. If there are any questions, please call 263-4622. Sincerely, W. S. Isaacson Drilling Engineer Kuparuk Drill Site Development WSI/skad .... STATE OF ALASKA ALAS; .., OIL AND GAS CONSERVATION £..MMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well '" clas~'ificaiion of Service Well ...... [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 96-204 3. Address ..... 8.' ~,'PI N'umber' P. O. Box 100360, Anchorage, Alaska, 99510 50-029-22731 4. Location of well at surface '~ ~,'~?:¥.'-~:' ';-~'~: I ~ 9. Unit or Lease Name 128' FNL, 1738' FEL, Sec. 33, T11N, R9E, UM ~ .......... '"' ~~ Kuparuk River Unit At top of productive interval i '~- ~,t..., r,~.' ~ 10. Well Number ! 2F-17 716' FNL, 1784' FWL, Sec. 4, T10N, R9E, UM ~ ' '-~'~.~: .s '.'- Attotal depth !__~~ ! 11. Field and Pool 1060' FNL, 1686' FWL, Sec. 4, T10N, PgE, UM i~. Ele-~tion in f-~et (indic-~.~-~--KB,-D-~:-~ et~:~-i ....... 16-~---~.-~.as~.---i~s-ig-r~ation--a-~d se-r-iai N-~i ........ Kuparuk River Rig RKB 32', Pad 97'I ADL 25666, ALK 2587 i12. Date Spudded i13. Date T.D. Reached 114. Date Comp., Susp., or Aband.115. Water depth, if offshore 116. No. of Completions 1/29/97 i 3/22/97 I 5/6/97 I N/A MSLI One 17. T°t'&l Depth (iVID+'I'V~)! 18J piug"l~ack 'D~l~th (Mb;¥VD)II~'i DirectiOnal 'Surveyi20. Depth Where SSSV set~l. ¥~iCkness of Permafrost 9561 6336 F~ ..... 9761 -.~ 6263 ..... FT~ I~Yes I-1No ~[ N/A MD/ 1650' (Approx.) 22. Type Electric or Other Logs Run GR/CCL/SLTJ 23. CASING, LINER AND CEMENTING RECORD CASING ...... sE~I-I-ING DEPTH ! HOLE ......... ....S_!ZE V~-_.. PER FT:__ GPA_DE .- ..... :~o1~--i---ii-~0--~(~-~iii]___ S!_Z__E . C_EMENTING RECORD _ _ AMOU__N~-._- PULLED 16" 62.5# H-40 Surf. 121' 24" 260 Sx AS I 7.625" 29.7# L-80 Surf. 4018' 9.875" 251 sx ASLW, 530 sx Class G, 65 sx AS I 5.5" 15.5# I--:-~0 Surf. 8932' ----~:-75"--- :l--2i:)-~-~--i2-[~.ss (~ .............................................................................. 3-:5,, -9.2# .... L:80 8718' 9-56i~ -i 4175- 114SxClassG ............ I 24. Perforations op~ to Production (MD+TVD 'oi Top and Botto'r~ '25. 'TUBING RECORD and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 871 8' 871 8' MD TVD MD TVD .......................................................................................................... 9161 '-9181' 6044'-6058 ............................ 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTFF~V,~ (MD) AMOUNT & KIND OF MATERIAL USED ....... 9161~918i'; 'Pumpes' 98868#'~rop(10094 ~ of 77906# of #12/18, 10868 # of #10/14). Inject- ed 97907# of prop in formation w/12# ppa of ......... #10114 @ perfs 27. ' ..... PRODucTI~ TEST ............. iDate First ProduCtio~' iMethod of Operation (FloWing, ga~' lift, etc.) ' 5/9/97 i Gas Lift !Date of Test iHours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-GEL CHOKE SIZE i GAS-OIL RATIO 6/15/97 i 5.9 TEST PERIOD ' 59 1 48 21 9 1 76 [ 2776 iF-i0w TuBi~-~ii3-~in~ I~-i,-~,-s-br~i2-~t~OE~5----; ...... -Oi-L:-Bi~i~ ................. ~-:~'~ .............. i-W-~:~Ei~':-I~-~-L .......... -OiE-C_.-,-~,-~i-i:~,:A'~-i -(-~5~-¢i) ........................ Pres.s.. 01 . ..24-HOUR RATE 221 612 ........ 888 . , 24° ........ 28. CORE DATA Bri~i description of lithology, porosit'~,, fractures, apparent dips and presence of oil, gas or water. Submit core chips. 0 :? 61NAL . Form 10-407 Rev. 07-01-80 ! 29. Geologic Mar'--' 30. ~ · Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. , Top Kuparuk C 9038' 5954' Bottom Kuparuk C 9046' 5960' Annulus left open - freeze protected well with diesel. Top Kuparuk A 9106' 6004' Bottom Kuparuk A 311 List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,~ ~,~. t ~ ........................ _..-- _ __' -,. -,~.,.- Title OI~L~.T~. [~,4F.~I;~ Date '-~r' ~ -~"1 Prepared By Name/Number: 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Date: 6/18/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:2F-17 RIG:NORDIC WELL ID: AK8577 TYPE: -- AFC: AK8577 AFC EST/UL:$ 1420M/ 1704M STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK' SPUD:01/29/97 START COMP: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22731-00 01/28/97 (D1) TD: 121' (121) SUPV:DCL DAILY:$ 01/29/97 (D2) TD: 3830' (3709) SUPV:DCL DAILY:$ 01/30/97 (D3) TD: 4028' (198) SUPV:DCL DAILY:$ 01/31/97 (D4) TD: 4028' ( 0) SUPV:DCL DAILY:$ 02/01/97 (D5) TD: 6395' (2367} SUPV:DCL DAILY:$ 02/02/97 (D6} TD: 8050' (1655) SUPV:DCL DAILY:$ 02/03/97 (D7) TD: 8932' (882) SUPV:DCL DAILY:$ 02/04/97 (D8) TD: 8932'( SUPV:GRW 0) DAILY:$ MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 DRILLING Move rig from 2F-19 to 2F-17. Accept rig @ 19:30 on 1/28/97. Function test diverter system. M/U BHA. 50,250 CUM:$ 50,250 ETD:$ 0 EFC:$ 1,470,250 MW: 9.4 VISC: 62 PV/YP: 22/20 APIWL: 7.8 CIRC AFTER WIPER TRIP Drilling from 121' to 3830'. 87,803 CUM:$ 138,053 ETD $ 311,760 EFC'$ 1,246,293 MW: 9.4 VISC: 47 PV/YP: 18/14 APIWL: 7.2 NU BOP Drilling from 3830' to 4028' Held pre-job safety meeting. Run in hole with 7-5/8" casing. Pump cement. 157,280 CUM:$ 295,333 ETD:$ 325,787 EFC:$ 1,389,546 MW: 8.4 VISC: 37 PV/YP: 5/ 7 APIWL: 15.8 DRILLING Test all BOPE to 300/3000 psi. Drill out ES cementer and plugs. Drill out cement, FE, and 20' new formation to 4048'. 83,090 CUM:$ 378,423 ETD:$ 325,787 EFC:$ 1,472,636 MW: 9.0 VISC: 52 PV/YP: 16/18 APIWL: 8.0 WIPER TRIP @ 6990' Perform LOT, 12.0 ppg EMW. Drilling from 4148' to 6395' 77,776 CUM:$ 456,199 ETD:$ 559,843 EFC:$ 1,316,356 MW- 9.5 VISC: 51 PV/YP: 18/18 APIWL: 6.8 DRILLING AT 8400' Drilling from 6395' to 6990' Had large amount of gas to surface. Circ out gas. Monitor well. Had small amount of gas. Drilling from 6990' to 8050' increase mud weight. 75,949 CUM'$ 532,148 ETD:$ %23,554 EFC:$ 1,228,594 MW: 9.5 VISC: 49 PV/YP: 17/20 APIWL: 6.4 RIH W/5.5" CASING Drilling from 8050' to 8932'. Made 20 stand wiper trip. No problems. CBU. No gas. Circ lo/hi vis sweep. POH. Monitor well at shoe. No problems. 83,262 CUM:$ 615,410 ETD:$ 810,800 EFC:$ 1,224,610 MW: 9.5 VISC: 46 PV/YP: 17/13 APIWL: 6.4 LAYING DOWN DP Held safety meeting. Run 5.5" casing. Pump cement. Hole started packing off. CIP @ 2014 hrs. 123,544 CUM:$ 738,954 ETD:$ 810,800 EFC:$ 1,348,154 Date: 6/18/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 02/05/97 (D9) TD: 8932' ( SUPV: GRW 0) DAILY:$ 03/18/97 (D10) TD: 8923' ( 0) SUPV: DLW DAILY: $ 03/19/97 (Dll) TD: 8923' ( 0) SUPV: DLW DAILY: $ 03/20/97 (D12) TD: 9221' (298) SUPV: DLW DAILY:$ 03/21/97 (D13) TD: 9466' (245) SUPV:DLW DAILY:$ 03/22/97 (D14) TD: 9561' ( 95) SUPV: DLW DAILY:$ 03/23/97' (D15) TD: 9561' ( 0) SUPV:DLW DAILY:$ 03/24/97 (D16) TD: 9561' ( 0) SUPV:DLW DAILY:$ MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED TO 2F-05X Install packoff, test to 3000 psi for 15 min. Freeze protect. Release rig at 10:30 hrs. 2/5/97. 85,267 CUM:$ 824,221 ETD:$ 810,800 EFC:$ 1,433,421 MW: 8.3 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 MU BHA RIH Turn key well to well rig move from 2F-05X to 2F-17. Accept rig @ 1200 hrs. 3/18/97. ND tree and set plugs. NU BOPs. Test BOPE to 250/3500 psi. RIH with open ended 2-7/8" DP to 2200' 32,191 CUM:$ 856,412 ETD:$ 809,910 EFC:$ 1,466,502 MW: 11.3 VISC: 60 PV/YP: 20/28 APIWL: 4.0 DRILLING AHEAD @ 9100' W/4.75" Test 5.5" casing to 3500 psi for 30 min. OK. Clean out cement from 8776' to 8905' 46,995 CUM:$ 903,407 ETD:$ 809,910 EFC:$ 1,513,497 MW: 12.6 VISC: 45 PV/YP: 23/11 APIWL: 4.2 DRILLING @ 9315' Continue to clean out cement from 8905' and shoe @ 8923'. Drill new 4.75" hole to 8943'. LOT @ 8943' MD. Continue drilling 4.75" hole from 8943' to 9070' well started to flow. Circulate out kick on choke @ 9075'. Continue to drill 4.75" hole from 9070' to 9221' Well started to flow after drilling into 'A' sand. Mud light gas and oil cut. Raise mud weight to 12.6 ppg. 46,008 CUM:$ 949,415 ETD:$ 0 EFC:$ 2,369,415 MW: 12.6 VISC: 50 PV/YP: 27/15 APIWL: 3.8 DRILLING AHEAD @ 9513' Raise weight to 12.6 ppg. Drill ahead w/4.75" from 9221' to 9466'. 59,110 CUM:$ 1,008,525 ETD:$ 0 EFC:$ 2,428,525 MW: 13.2 VISC: 50 PV/Y?: 27/15 APIWL: 4.0 POOH FOR E-LOGS Continue drilling 4.75" hole from 9466' to 9561'. Raise mud weight in pits to 13.2 ppg. 43,558 CUM:$ 1,052,083 ETD:$ 0 EFC:$ 2,472,083 MW: 13.2 VISC: 50 PV/YP: 27/15 APIWL: 4.0 3.5" LINER ON BTM @ 0600 HRS Continue to displace well bore w/ 13.2 ppg mud. Well taking extra mud. Well dead. Run 3-3/8" GR/SGT/DITE. Stopped at 9180' in the 'C' sand. POOH. Run 3.5" liner. 46,580 CUM:$ 1,098,663 ETD:$ 0 EFC:$ 2,518,663 MW: 8.5 vise: 28 PV/YP: 1/ 0 APIWL: 0.0 POOH TO RUN COMPLETION Continue to run 3.5" liner to 8923'. Run 3.5" casing from 5.5" casing shoe to 9550' Gas cut mud and air form filling pipe on way in hole. Pump cement. Test 5.5" casing and 3.5" liner to 3500 psi for 30 min., OK. 41,370 CUM:$ 1,140,033 ETD:$ 0 EFC:$ 2,560,033 Date: 6/18/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 03/25/97 (D17} TD: 9561' ( 0) SUPV:DLW DAILY:$ MW: 8.5 VISC: 28 PV/YP: N/U TREE AND TESTING Run 3.5" tubing and GLM's. 101,815 CUM:$ 1,241,848 ETD:$ 1/ 0 APIWL: 0.0 0 EFC:$ 2,661,848 03/26/97 (D18) TD: 9561' ( 0} SUPV: DLW DAILY:$ MW: 0.0 VlSC: 0 PV/YP: 0/ 0 APIWL: 0.0 RELEASE RIG Continue to 'U' tube diesel with annulus to tubing til balanced. Test 3.5" tubing to 3500 psi for 15 min. Test 5.5" x 3.5" annulus to 3500 psi for 15 min. N/D BOPE. N/U tree. Test packoff to 250/5000 psi, test tree to 250/5000 psi. Move off well. Release rig @ 1000 hrs. 3/26/97. 43,697 CUM:$ 1,285,545 ETD:$ 0 EFC:$ 2,705,545 End of WellSummary for Well:AK8577 ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT A Kl(2F-17(W4-6)) WELL JOB SCOPE JOB NUMBER 2F-17 PERFORATE, PERF SUPPORT 0425971550.3 DATE DAILY WORK UNIT NUMBER 05/06/97 PERFORATED/PRE FRAC SWS-WALSH 3 YES _ YES SWS-WALSH CHANEY Initial Tbg Press i Final Tbg Press I Initial Inner Ann I Final Inner Ann I Initial Outer Ann Final Outer Ann 200 PSI 1500 PSI 0 PSI 1100 PSI 700 PSI 700 PSI DAILY SUMMARY PERFORA'IED 9161'-9181' 4 SPF BIG HOLE CHARGES 180 PHASED, 6 DEG CC"vV FROM HIGH & LOW SIDE. WHTP INCREASED FROM 800 I PSI TO 1400 PSI INSTANq'LY WHEN SHOT. I TIME 09:00 10:00 LOG ENTRY MI-TGSM-RU RADIO SILENCE, RU GUN PT 30(30 PSI. 10:30 RIH W/HEAD/CCL/ORIENTING MAGNET/20' GUN, 26.3' 2.5" OD 11:40 SHOT GUN WITH WR[.I~ SLIGHTLY UNDERBALANCED. WHP = 800 PSI.IMMEDIATELY SAW 1400 PSI ON TUBING AND 700 PSI ON IA 13:00 AT SURFACE, PULLED TIGHT AT 86', ABLE TO GET OUT OF HOLE SAFELY. ALL SHOTS FIRED. 14:00 RDMO SPE ARCO ALASKA INC KUPARUK RIVER UNIT / 2F-17 500292273100 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/10/97 TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH · 00 .00 -138.00 281.82 281.82 143.82 467.94 467.94 329.94 555.07 555.05 417.05 645.53 645.38 507.38 736.97 736.43 598.43 827.84 826.60 688.60 921.18 918.97 780.97 1018.72 1015.36 877.36 1107.86 1103.18 965.18 COURS INCLN DG MN '-SUN DRILLING SERVICES ANCHOR_AGE ALASKA 0 0 0 14 0 15 1 40 4 3 6 26 7 58 8 30 9 6 10 43 1201.81 1195.07 1057.07 13 16 1294.55 1284.66 1146.66 16 38 1389.34 1374.61 1236.61 20 6 1483.35 1461.46 1323.46 24 51 1577.43 1545.56 1407.56 28 22 1670.45 1626.50 1488.50 30 38 1761.11 1703.85 1565.85 32 13 1853.90 1782.47 1644.47 31 57 1944.84 1859.10 1721.10 33 11 2037.97 1935.56 1797.56 36 24 PAGE DATE OF SURVEY: 020397 MWD SURVEY JOB NUMBER: AK-MM-70025 KELLY BUSHING ELEV. = 138.00 FT. OPERATOR: ARCO ALASKA INC 2128.43 2008.02 1870.02 37 2221.90 2082.17 1944.17 37 2313.06 2153.06 2015.06 40 2404.62 2222.14 2084.14 42 2498.10 2289.74 2151.74 45 COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 7 53 0 1 19 N .00 E .00 .00N .00E S 75.43 E .09 .15S .57E N 8.98 E .20 .15N 1.01E N 61.96 W 1.85 .94N .09W N 69.39 W 2.66 2.69N 4.25W .00 -.02 - .43 -.88 -1.39 2591.51 2352.94 2214.94 49 30 2682.95 2410.88 2272.88 51 49 2774.87 2465.58 2327.58 55 7 2867.38 2517.34 2379.34 56 49 3051.73 2615.57 2477.57 58 46 N 86.16 W 3.08 4.18N 12.41W S 71.37 W 3.49 2.51N 23.47W S 54.63 W 2.62 3.55S 35.23W S 41.30 W 2.17 13.52S 46.20W S 28.83 W 3.01 26.09S 54.86W -.51 4.21 13.34 25.99 40.49 S 21.97 W 3.11 43.76S 63.11W S 14.40 W 4.18 66.51S 70.40W S 14.47 W 3.65 95.44S 77.85W S 17.39 W 5.19 129.95S 87.80W S 21.44 W 4.22 169.64S 101.88W 59.78 83.66 113.51 149.42 191.48 S 22.04 W 2.45 212.19S 118.86W S 20.84 W 1.87 256.19S 136.13W S 20.64 W .31 302.28S 153.58W S 21.59 W 1.47 347.95S 171.22W S 21.79 W 3.46 397.33S 190.86W 237.09 284.17 333.31 382.10 435.01 3328.60 2758.52 2620.52 59 3 3605.82 2904.36 2766.36 57 27 3950.44 3086.05 2948.05 58 54 4211.23 3228.89 3090.89 54 40 4542.15 3412.85 3274.85 57 47 S 21.61 W .80 447.64S 210.89W S 22.05 W .86 500.47S 232.05W S 20.96 W 2.43 553.77S 253.04W S 18.27 W 2.94 610.37S 273.18W S 17.53 W 3.57 671.80S 293.01W 488.93 545.58 602.64 662.62 727. 14 S 18.44 W 4.52 737.19S 314.25W S 17.46 W 2.68 804.46S 336.04W S 17.19 W 3.60 874.97S 358.03W S 17.25 W 1.83 948.20S 380.72W S 16.72 W 1.09 1097.36S 426.28W 795.88 866.56 940.41 1017.06 1173.02 S 17.24 W .19 1324.13S 495.52W S 17.05 W .58 1549.38S 565.01W S 17.22 W .43 1829.18S 651.28W S 13.71 W 1.98 2039.34S 709.59W S 18.17 W 1.47 2303.67S 785.29W 1410.11 1645.81 1938.59 2156.66 2431.60 SPE f-SUN DRILLING SERVICES ANCHOR3AGE ALASKA PAGE RCO ALASKA INC KUPARUK RIVER UNIT / 2F-17 500292273100 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/10/97 DATE OF SURVEY: 020397 MWD SURVEY JOB NUMBER: AK-MM-70025 KELLY BUSHING ELEV. = 138.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 4722.71 3507.79 3369.79 58 45 S 16.06 W 1.12 2450.42S 830.47W 5093.33 3703.41 3565.41 57 31 S 15.30 W .37 2753.46S 915.55W 5462.51 3909.72 3771.72 54 30 S 15.51 W .82 3048.57S 996.85W 5831.95 4117.36 3979.36 57 5 S 15.96 W .71 3342.64S 1079.73W 6200.81 4317.34 4179.34 57 15 S 15.72 W .07 3640.82S 1164.33W '2585.14 2899.88 3205.93 3511.44 3821.38 6564.13 4511.29 4373.29 58 13 S 15.53 W .27 3936.67S 1247.07W 6931.85 4709.46 4571.46 56 32 S 13.93 W .58 4236.16S 1325.84W 7302.29 4910.50 4772.50 57 42 S 16.32 W .63 4536.42S 1407.05W 7580.64 5057.96 4919.96 58 18 S 13.50 W .89 4764.49S 1467.75W 7859.02 5202.02 5064.02 59 21 S 14.36 W .46 4995.67S 1525.10W 4128.56 4438.10 4749.08 4985.01 5222.98 8036.50 5295.92 5157.92 56 45 S 13.01 W 1.61 5141.97S 1560.75W 8221.45 5399.16 5261.16 55 22 S 11.36 W 1.05 5291.93S 1593.15W 8314.85 5453.92 5315.92 52 49 S 11.21 W 2.74 5366.12S 1607.96W 8408.16 5510.86 5372.86 51 58 S 13.93 W 2.48 5438.25S 1624.03W 8501.42 5569.36 5431.36 50 19 S 14.92 W 1.95 5508.58S 1642.11W 5373.40 5526.42 5601.77 5675.51 5748.08 8593.95 5629.60 5491.60 48 25 S 14.77 W 2.05 5576.45S 1660.10W 8687.86 5694.63 5556.63 43 54 S 16.32 W 4.97 5641.70S 1678.22W 8781.45 5764.51 5626.51 39 27 S 17.28 W 4.80 5701.27S 1696.18W 8872.50 5832.93 5694.93 43 6 S 15.80 W 4.16 5758.84S 1713.25W 5818.27 5885.98 5948.19 6008.25 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 6008.29 FEET AT SOUTH 16 DEG. 34 MIN. WEST AT MD = 8872 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 196.37 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD LAST SURVEY STATION AT 8,872.50' MD SP5 f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC KUPARUK RIVER UNIT / 2F-17 500292273100 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/10/97 DATE OF SURVEY: 020397 JOB NUMBER: AK-MM-70025 KELLY BUSHING ELEV. = 138.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION .00 .00 -138.00 .00 N .00 E .0 1000.00 996.88 858.88 11.30 S 44.25 W 3.1 2000.00 1904.75 1766.75 376.72 S 182.64 W 95.2 3000.00 2588.75 2450.75 1055.00 S 413.55 W 411.2 4000.00 3111.94 2973.94 1869.62 S 663.57 W 888.0 3.12 92.13 316.00 476.81 5000.00 3653.31 3515.31 2677.51 S 894.77 W 1346.6 6000.00 4208.67 4070.67 3478.28 S 1118.52 W 1791.3 7000.00 4747.03 4609.03 4291.35 S 1339.53 W 2252.9 8000.00 5276.05 5138.05 5112.15 S 1553.78 W 2723.9 8872.50 5832.93 5694.93 5758.84 S 1713.25 W 3039.5 458.64 444.64 461.64 470.98 315.62 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPE :-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE A~RCO ALASKA INC KUPARUK RIVER UNIT / 2F-17 500292273100 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/10/97 DATE OF SURVEY: 020397 JOB NUMBER: AK-MM-70025 KELLY BUSHING ELEV. = 138.00 OPERATOR: ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD DIFFERENCE VERTICAL CORRECTION .00 .00 -138.00 38.00 38.00 -100.00 138.00 138.00 .00 238.00 238.00 100.00 338.00 338.00 200.00 .00 N .00 E .00 .00 N .00 E .00 .00 .00 N .00 E .00 .00 .10 S .39 E .00 .00 .21 S .80 E .00 .00 438.00 438.00 300.00 538.02 538.00 400.00 638.14 638.00 500.00 738.55 738.00 600.00 839.36 838.00 700.00 .03 N .99 E .00 .00 .71 N .36 E .02 .01 2.51 N 3.76 W .14 .12 4.18 N 12.59 W .55 .42 1.99 N 24.99 W 1.36 .80 940.42 938.00 800.00 1041.66 1038.00 900.00 1143.36 1138.00 1000.00 1246.07 1238.00 1100.00 1350.54 1338.00 1200.00 5.20 S 37.55 W 2 16.39 S 48.55 W 3 32.23 S 58.02 W 5 53.90 S 66.75 W 8 82.99 S 74.64 W 12 .42 .66 .36 .07 .54 1.06 1.24 1.70 2.71 4.47 1457.64 1438.00 1300.00 1568.87 1538.00 1400.00 1683.82 1638.00 1500.00 1801.47 1738.00 1600.00 1919.63 1838.00 1700.00 119.89 S 84.71 W 19 165.89 S 100.44 W 30 218.50 S 121.41 W 45 276.30 S 143.78 W 63 335.11 S 166.14 W 81 .64 .87 .82 .47 .63 7.10 11.22 14.95 17.66 18.15 2041.00 1938.00 1800.00 2166.04 2038.00 1900.00 2293.41 2138.00 2000.00 2426.12 2238.00 2100.00 2568.79 2338.00 2200.00 398.99 S 191.53 W 103 468.76 S 219.26 W 128 541.98 S 248.52 W 155 624.16 S 277.70 W 188 720.94 S 308.87 W 230 .00 .04 .41 .12 .79 21.37 25.05 27.36 32.71 42.67 2727.67 2438.00 2300.00 2905.14 2538.00 2400.00 3094.99 2638.00 2500.00 3288.69 2738.00 2600.00 3482.48 2838.00 2700.00 838.39 S 346.66 W 289 978.38 S 390.09 W 367 1132.79 S 436.92 W 456 1291.44 S 485.38 W 550 1449.98 S 534.53 W 644 .67 .14 .99 .69 .48 58.88 77.47 89.85 93.70 93.79 3668.34 2938.00 2800.00 3857.39 3038.00 2900.00 4048.74 3138.00 3000.00 4227.03 3238.00 3100.00 4404.22 3338.00 3200.00 1599.76 S 580.47 W 730.34 1753.07 S 627.69 W 819.39 1909.16 S 675.09 W 910.74 2051.86 S 712.69 W 989.03 2193.04 S 750.91 W 1066.22 85.86 89.05 91.35 78.29 77.19 SPt f-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC KUPARUK RIVER UNIT / 2F-17 500292273100 NORTH SLOPE BOROUGH COMPUTATION DATE: 5/10/97 INTERPOLATED VALUES FOR EVEN 100 DATE OF SURVEY: 020397 JOB NUMBER: AK-MM-70025 KELLY BUSHING ELEV. = 138.00 FT. OPERATOR: ARCO ALASKA INC FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 4589.35 3438.00 3300.00 2341.61 S 797.75 W 1151.35 85.13 4780.94 3538.00 3400.00 2498.26 S 844.24 W 1242.94 91.59 4971.49 3638.00 3500.00 2654.31 S 888.42 W 1333.49 90.55 5157.30 3738.00 3600.00 2805.36 S 929.76 W 1419.30 85.81 5337.39 3838.00 3700.00 2949.76 S 969.50 W 1499.39 80.09 5511.43 3938.00 3800.00 3087.02 S 1007.55 W 1573.43 74.04 5687.84 4038.00 3900.00 3226.94 S 1046.82 W 1649.84 76.41 5869.93 4138.00 4000.00 3373.30 S 1088.49 W 1731.93 82.09 6054.15 4238.00 4100.00 3522.08 S 1130.91 W 1816.15 84.22 6239.00 4338.00 4200.00 3671.74 S 1173.03 W 1901.00 84.85 6424.98 4438.00 4300.00 3822.70 S 1215.39 W 1986.98 85.98 6614.86 4538.00 4400.00 3978.22 S 1258.61 W 2076.86 89.88 6802.20 4638.00 4500.00 4131.17 S 1299.80 W 2164.20 87.35 6983.62 4738.00 4600.00 4278.09 S 1336.24 W 2245.62 81.42 7166.57 4838.00 4700.00 4426.31 S 1374.81 W 2328.57 82.95 7353.76 4938.00 4800.00 4578.18 S 1419.27 W 2415.76 87.19 7542.64 5038.00 4900.00 4733.04 S 1460.20 W 2504.64 88.88 7733.41 5138.00 5000.00 4890.97 S 1498.30 W 2595.41 90.76 7928.55 5238.00 5100.00 5053.37 S 1539.59 W 2690.55 95.15 8113.25 5338.00 5200.00 5204.50 S 1575.20 W 2775.25 84.69 8288.25 5438.00 5300.00 5345.21 S 1603.80 W 2850.25 75.00 8452.10 5538.00 5400.00 5471.77 S 1632.39 W 2914.10 63.85 8606.49 5638.00 5500.00 5585.45 S 1662.50 W 2968.49 54.40 8746.66 5738.00 5600.00 5679.74 S 1689.57 W 3008.66 40.17 8872.50 5832.93 5694.93 5758.84 S 1713.25 W 3039.57 30.91 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X. Exploratory _ Stratigraphic _ Service 4. Location of well at surface 128' FNL, 1738' FEL, Sec. 33, T11N, R9E, UM At top of productive interval 775' FNL, 1780' FWL, Sec. 4, T10N, R9E, UM At effective depth 1000' FNL, 1716' FWL, Sec. 4, T10N, R9E, UM At total depth 1065' FNL, 1698' FWL, Sec. 4, T10N, R9E, UM 12. Present well condition summary Total Depth: measured 9561 feet true vertical 6336 feet 6. Datum elevation (DF or KB) RKB 39 7. Unit or Property name Kuparuk River Unit 8. Well number 2F-17 9. Permit number/approval number 96-204 10. APl number 5o-029-22731-00 11. Field/Pool Kuparuk River Field/Oil Pool Plugs (measured) None Effective depth' measured 9 4 61 feet Junk (measured) None true vertical 6 2 6 3 feet feet ORIGINAL Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 8 0' 1 6" 150 Sx (Approx) 1 21 ' 1 21 ' Surface 401 4' 7-5/8" 251 Sx ASLW & 401 8' 31 23' Intermediate 530 Sx Class G w/65 Sx AS I tail Production 8927' 5.5" 120 Sx Class G 8 9 3 2' 5 8 7 7' Liner 8 4 2' 3.5" 114 Sx Class G 95 61 ' 6 21 7' Perforation depth: measured 9161'-9181' true vertical 6044'-6058' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., L-80 @ 8718' Packers and SSSV (type and measured depth) Packer: Baker SABL-3 Liner Packer @ 8718'; SSSV: None, nipple @ 496' 13. Stimulation or cement squeeze summary Fracture stimulate 'A' Sands on 5/8/97 ¢¢~,~d~[~ Intervals treated (measured) ..... 9161'-9181' Treatment description including volumes used and final pressure Pumped 97.9 Mlbs of 20/40, 12/18, & 10/14 ceramic proppant into formation, fp was 8400 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 900 1240 Subsequent to operation 340 6 4 0 936 900 151 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I he~_~rti~ that the foregoing is true and correct to the best of my knowledge, Signed ~ /~~~.¢ Title Wells Superintendent Form .~~[::l~v/~67~5/8~- ' Date SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT ~ WELL SERVICE REPORT '~' K1(2F-17(W4-6)) WELL JOB SCOPE JOB NUMBER 2F-17 FRAC, FRAC SUPPORT 0506971525.10 DATE DAILY WORK UNIT NUMBER 05/08/97 "A" SAND FRAC DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 (~ Yes O NoI (~ Yes O No DS-GALLEGOS CHANEY FIELD AFC~ CCff DALLY COST AOOUM COST sj~nea O// ESTIMATE 998613 230DS28FL $86,882 $86,882,~,7/" P/~,/V-~, ~ Initial Tbcl Press Final Tb.cl Press Initial Inner Ann Final Inner Ann, Initial OLder Ann I Final Outer Ap¢i-' 1550 PSI 1700 PSI 1560 PSI 500 PSII I .~0700 PSI PSI DALLY SUMMARY I FREEZE PROTECTED DOWN TO 5100' RKB W/45 BBLS OF DIESEL. MAXIMUM PRESSURE 8400 PSI AND F.G. @ (.77) "A" SAND FRAC COMPLETED THRU FLUSH. INJECTED 97907 LBS OF PROP IN THE FORMATION W/12# PPA OF #10/14 @ PERF'S. TIME 07:00 09:00 09:40 10:40 11:50 LOG ENTRY MIRU DOWELL FRAC EQUIP, APC VAC TRK, AND LRS HOT OIL TRK. HELD SAFETY MEETING/15 ON LOCATION). PT'D BACKSIDE LINES TO 4000 PSI AND RAISED INNER CSG PRESSURE AS REQUIRED. SET TREESAVER AND PT'D HIGH PRESSURE LINES TO 9500 PSI. PUMP BREAKDOWN W/50# DELAYED XL GW @ 30 TO 15 BPM. VOLUME PUMPED 311 BBLS. MAXIMUM PRESSURE 8400 PSI AND ENDING PRESSURE 3300 PSI. S/D AND OBTAINED ISIP FOR 2000 PSI W/F.G. @ (.77). STOOD-BY AND MONITORED WHTP FOR CLOSURE. PUMP DATAFRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. VOLUME PUMPED 190 BBLS. MAXIMUM PRESSURE 5900 PSI AND ENDING PRESSURE 3600. S/D AND OBTAINED ISlP 2164 PSI W/F.G. @ (.80). STOOD-BY AND MONITORED WHTP FOR CLOSURE. PUMP FRAC W/50# DELAYED XL GW @ 5 TO 15 BPM. COMPLETED THRU FLUSH. S/D AND OBTAINED ISIP OF 2407 PSI. STOOD-BY AND MONITORED WHTP FOR 10 MINS. VOLUME PUMPED 760 BBLS. PUMPED 98868 LBS OF PROP ( 10094 LBS OF #20/40, 77906 LBS OF #12/18, 10868 BS OF #10/14). INJECTED 97907 LBS OF PROP IN THE FORMATION W/12# PPA OF #10/14 @ PERF'S. LEFT 961 LBS OF PROP IN THE WELLBORE. EST TOP OF FILL @ 9181' RKB. FREEZE PROTECTED DOWN TO 5100' RKB W/45 BBLS OF DIESEL. 13:10 STARTED R/D. DEPRESSURED THE INNER CSG TO 500 PSI AND R/D LRS HOT OIL TRK. 14:00 15:00 REMOVED TREESAVER (ALL CUPS RETURNED). CONTINUED R/D. R/D COMPLETE AND DOWELL LEAVING LOCATION. WELL SECURED AND NOTIFIED DSO OF STATUS. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL ,APC $5,200.00 $5,200.00 DIESEL $400.00 $400.00 DOWELL $77,542.00 $77,542.00 LII I LE RED $3,740.00 $3,740.00 TOTAL FIELD ESTIMATE $86,882.00 $86,882.00 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown__ Stimulate Plugging Pull tubing Alter casing Repair well Perforate X Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 9951O 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 128' FNL, 1738' FEL, Sec. 33, T11N, R9E, UM At top of productive interval 775' FNL, 1780' FWL, Sec. 4, T10N, R9E, UM At effective depth 1000' FNL, 1716' FWL, Sec. 4, T10N, R9E, UM At total depth 1065' FNL, 1698' FWL, Sec. 4, T10N, R9E, UM i12. Present well condition summary Total Depth: measured true vertical 9561 6336 feet feet 6. Datum elevation (DF or KB) RKB 39 7. Unit or Property name Kuparuk River Unit 8. Well number 2F-17 9. Permit number/approval number 96-204 10. APl number 5o-029-22731-00 11. Field/Pool feet Plugs (measured) Kuparuk River Field/Oil Pool None Effective depth: measured 9 4 61 true vertical 6263 feet feet Junk (measured) None Casing Length Size Structural Conductor 8 0' I 6" Surface 4 01 4' 7- 5 / 8" Intermediate Production 8927' 5.5" Liner 8 4 2' 3.5" Perforation depth: measured 9161'-9181' true vertical 6O44'-6058' Cemented Measured depth 150 Sx (Approx) 121' 251 Sx AS LW & 4 01 8' 530 Sx Class G w/65 Sx AS I tail 120 Sx Class G 8 9 3 2' 114 Sx Class G 9 5 61 ' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., L-80 @ 8718' Packers and SSSV (type and measured depth) Packer: Baker SABL-3 Liner Packer @ 8718'; SSSV: None, nipple @ 496' True vertical depth 121' 3123' 5877' 6217' 13. Stimulation or cement squeeze summary Perforated 'A' Sands on 5/6/97. Intervals treated (measured) 9161'-9181' Treatment description including volumes used and final pressure Perforated w/BH charges @ 4 SPF, fp was 1400 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 900 124O Subsequent to operation 340 640 936 900 151 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (~~. ~ /'~~,,,~ Title Wells Superintendent Form 10-4J~ / Date ~ -.-//,~--'.,~'~ SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT ~ ~ WELL SERVICE REPORT K1(2F-17(W4-6)) WELL JOB SCOPE JOB NUMBER 2F-17 PERFORATE, PERF SUPPORT 0425971 550.3 DATE DAILY WORK UNIT NUMBER 05/06/97 PERFORATED/PRE FRAC SWS-WALSH DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 3 (~ Yes O NoI (~) Yes O No SWS-WALSH CH, AMEY FIELD AFC_,ff CCC DAILY COST ACCUM COST S .... d ESTIMATE AK8577 230DS28FG $8,161 $42,686 eSr~.~n ~ ~,..-~ Initial Tb_q Press Final Tb_q Press Initial Inner Ann Final Inner Ann I Initial 200 PSI 1 500 PSI 0 PSI 1 100 PSII 700 PSII ~00 PSI DAILY SUMMARY I PERFORATED 9161"9181' 4 SPF BIG HOLE CHARGES 180 PHASED' 6 DEG CCW FROM HIGH & LOW SIDE' WHTP INCREASED IFROM 800 PSI TO 1400 PSI INSTANTLY WHEN SHOT. TIME LOG ENTRY 09:00 MI-TGSM-RU 10:00 RADIO SILENCE, RU GUN PT 3000 PSI. 10:30 RIH W/HEAD/CCL/ORIENTING MAGNET/20' GUN, 26.3' 2.5" OD 11:40 SHOT GUN WITH WELL SLIGHTLY UNDERBALANCED. WHP = 800 PSI. IMMEDIATELY SAW 1400 PSI ON TUBING AND 700 PSI ON IA 13:00 AT SURFACE, PULLED TIGHT AT 86', ABLE TO GET OUT OF HOLE SAFELY. ALL SHOTS FIRED. 14:00 RDMO SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $3.00 APC $250.00 $6,250.00 DIESEL $0.00 $325.00 DOWELL $0.00 $6,019.00 HALLIBURTON $0.00 $1,058.00 LI'I-I'LE RED $0.00 $3,400.00 SCHLUMBERGER $7,912.00 $25,632.00 I:OTAL FIELD ESTIMATE $8,162.00 $42,687.00 May 12, 1997 ARCO Alaska, Inc. AOGCC, Lori Taylor 700 G Street Anchorage, AK 99501 Re: MWD Survey 2F-17 Dear Sir/Madam, Enclosed is one hard copy of the above mentioned file(s). Well 2F-17 Tie in point 0.00', interpolated depth at 8,872.50'. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Operations Support Engineer Attaclunents. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company 5/6/97 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10994 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 · Field: Kuparuk (Open Hole) Well Job # Log Description Date BL RF Sepia LIS Tape 2F-5X ~(~-~O3 ZT---"/(e"/~ 97129 DITEW/PDCGR 970315 I I 1 2F-17 ~'~.,-~'-/ ~ "7(~"/~ 97163 DITEW/PDCGR 970323 I I 1 ,, S I G N E D' DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. 0 I:t I I--I-- I I~J G S ~::: I:t L/I C ~:: S WELL LOG TRANSMITrAL To: State of Alaska May 7, 1997 Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 ~,~ MWD Formation Evaluation Logs 2F-17, AK-MM-70025 The technical data listed below is being submitted herewith. Please address any problems or concems to the attention off Jina Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. API#: 50-029-22731-00 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 ° (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company spe -sur, WELL LOG TRANSMIIWAL To: State of Alaska May 7, 1997 Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 2F-17, AK-MM-70025 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention or2 Jun Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2F-17: 2" x 5" MD Gamma Ray Logs: 50-029-22731-00 2"x 5" TVD Gamma Ray Logs: 50-029-22731-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company ARCO Alaska, Inc. Post Office Bo× 100360 ~,,,aska 99510-0360 Anchorage, *'' Telephone 907 278 1215 January 14, 1997 Dave Johnston Commission Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Subject: Change to casing program on KRU Wells 2F-17 and 2F-19 STAT Dear Mr. Johnston: This letter is to inform the Commission that ARCO Alaska, Inc., is planning to alter the casing program approved in the Permits to Drill for 2F-17 (permit #96- 204) and 2F-19 (96-201). We have decided to topset the Kup~tik in both wells due to the unexpectedly high reservoir pressure seen in offset Well 2F-18. The new casing programs will be: Well Casing Length Top MD Top TVD Btm MD Btm TVD 2F-17 5-1/2" 8984' 41' 41' 9025' 5909' 3-1/2" 691' 8875' 5808' 9566' 6317' 2F-19 5-1/2" 10630' 41' 41' 10671' 5865' 3-1/2" 674' 10521' 5765' 11195' 6260' 5-1/2" casing is the standard 15.5# L-80 LTC Modified set in a 6-3/4" hole size. The 3-1/2" liners are 9.3# L-80 EUE 8rd Modified set in a 4-3/4" hole size. Both liners will be cemented with +75 sx of Class G to bring cement into the liner lap. If you have any questions on the information, please contact me at 263-4183. Sincerely, Denise Petrash Drilling Engineer jAN 1 4 1997 cc: Blair Wondzell AOGCC Alaska Oil & Gas Cons, Cornmis~n Anchorage AR3B-6003-93 242-2603 TONY KNOWLE$, GOVERNOR ALASi~ OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 JanuaD,' 8, 1997 Michael Zanghi Drill Site Develop Supv ARCO Alaska, Inc. P O box 100360 Anchorage, AK 99510-0360 Re~ Kuparuk River Unit 2F-17 ARCO Alaska, Inc. Permit No. 96-204 Sur. Loc 128'FNL, 1738'FEL, Sec. 33, T1 IN, R9E, UM Btmhole Loc. 1057'. 1721'FWL, Sec. 4, T10N, R9E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill thc above refercnccd well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and docs not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must bc tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstratcd under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of thc MI test before operation, and 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 tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman BY ORDER OF THE COMMISSION dlf/Enclosure CC; Department of Fish & Game, Habitat Section xv/o cncl. Dcpartmcnt of Environmental Conservation w/o encl. , STATE OF ALASKA · ALA~,,,A OIL AND GAS CONSERVATION COMMIS$,,.,N PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill [] lb Type of Well Exploratory [] Stratigraphic Test [] Development Oil Re-Entry E] Deepen [] Service X Development Gas E] Single Zone X Multiple Zone E] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. Rig RKB 41', Pad 97' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchora~]e, AK 99510-0360 ADL 25666, ALK 2587 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 20 AAC 25.025) 128' FNL, 1738' FEL, Sec. 33, T11N, R9E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 863' FNL, 1775' FWL, Sec. 4, T10N, R9E, UM 2F-17 #U-630610 At total depth 9. Approximate spud date Amount 1057' FNL, 1721' FWL, Sec. 4, T10N, RqE, UM 1/1 7/97 $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 2 F- 1 5 9566' MD 863 ~ Target feet 14' ~b 725' feet 2560 6317' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 70 0' feet Maximum hole angle 57.0° Maxirnumsurface 1846 psig At total depth (TVD) 3 1 75 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Wei~iht Grade Coupling Length MD TVD MD TVD linclude stac~e dataI 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' _+200 CF 9.875" 7.625" 29.7# L-80 LTC 3959' 41' 41' 4000' 3118' 1170 Sx Arcticset III & HF-ERW 490 Sx Class G 6.75" 4.5" 12.6# L-80 NSCT 9525' 41' 41' 9566' 6317' 240SxClassG Top 1000' 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 Measu red de_.pth_ __ i,, Ti'u~ J/~,ti(lI~depth Structural R .L /vtu Conductor Surface Intermediate Production DEC 3 1 1996 Liner Perforation depth: measured,l~as~(~ 011 & Gas Cons. commission true vertical Anchorage 20. Attachments Filing fee X Property plat [] BOPSketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot r'] Refraction analysis [--~ Seabed report D 20 AAC 25.050 requirements X 21. I hereby certifytl~t the foregoing )s true and correct to the best of my knowledge Signed /' l" ~...- ,_.~,,~ ~r'// / Title Drill Site Develop. Supv. Date ~' - //' / '~ Commission Use Only I Is. ?G ~ ~ ? ~o-c,.~ ? - z ;_. 7.s / - ~ - ¢7other requirements Conditions of approval Samples required I--! Yes I~] No Mud Icg required r'l Yes ~ No Hydrogen sulfide measures [] Yes D No Directional survey required ,i~ Yes r'l No nequired working pressure for BOPE ~ 2M [] 3M l-I SM D 1OM r'-I 15M Other: ,~-~gtn~.! Signed By David W. Johnston by order of /'"" ~)-- P 7 Approved by Commissioner the commission Date Fnrm ll3-AB1 Rnv 7-D,I-R~ .c;ifhmit in trinli~.ntn GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD KRU 2F-1 7 , . . . . . . . . Note: 10. 11. Note: 12. 14. Move in and rig up Parker #245. Install diverter system. Drill 9-7/8" hole to 7-5/8" surface casing point (4,000')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 or 16 ppg EMW formation integrity test, whichever is lower. Drill 6-3/4" hole to total depth (9,566') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 4-1/2" Iongstring. Space out as needed to land the hanger and place the external casing packer at the surface casing shoe. The cementing program is designed to reach 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. Set external casing packer at surface casing shoe. Pressure test to ensure seal. Freeze protect annulus through sliding sleeve above packer. 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. RECEIVED DEC 5 1 1996 Alaska 011 & Gas Cons. Commission /~ch0rage DRILLING FLUID PROGRAM Well KRU 2F-17 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 10.6 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/ft. This shows that formation breakdown would occur before a surface pressure of 1846 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 2F-17 is 2F-15. As designed, the minimum distance between the two wells would be 14' @ 725' MD. Drillin~l Area Risks' Risks in the 2F-17 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. 4-1/2" casing will be topset above the Kuparuk and either Nordic Rig #2 or a coiled tubing unit will drill out a 3-3/4" hole, and run a 3-1/2" FJ or 2-7/8" 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 10.6 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 7-5/8" casing shoe will be taken to leak-off or tested to a maximum of 16 ppg EMW 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 2F-17 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 2F-17 surface/production casing annulus will be filled with diesel after setting the 4-1/2" Iongstring and prior 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. 2F-17 will not be permitted for annular pumping as the annular isolation packer does not allow for this operation. ARCO ALASKA, Inc. Pad 2F 17 slot #17 Kuparuk River Unit North Slope, Alaska 3-D M [ N [ HUM D [ STANCE CLEARANCE by Baker Hughes [NTEQ REPORT Your ref : 17 Version #7 Our ref : prop399 License : Date printed : 10-Dec-96 Date created : 5-Feb-92 Last revised : 9-Dec-96 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 16 17.459,w149 50 40.077 Slot location is n70 16 16.198,w149 51 30.674 Slot Grid coordinates are N 5948754.438, E 517493.577 Slot local coordinates are 128.00 S 17'58.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances [ess than 500 feet DECREASING CLEARANCES of [ess than 1000 feet are indicated by an asterisk, e.g. 487.4' Object we[[path Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. PGMS <O-7820'>,,12,Pad 2F 4-Feb-92 309.1 460.0 460.0 PraMS <O-8452'>,,14,Pad 2F 4-Feb-92 75.0 20.0 400.0 PGMS <O-7837'>,,13,Pad 2F 4-Feb-92 134.8 20.0 3580.0 PGMS <O-7550'>,,15,Pad 2F 4-Feb-92 14.0 725.0 725.0 PGMS <O-7425'>,,16,Pad 2F 4-Feb-92 45.7 20.0 866.7 PGMS <O-6920'>,,1,Ped 2F 4-Feb-92 595.3 20.0 20.0 PGMS <O-7630'>,,2,Pad 2F 4-Feb-92 654.4 360.0 866.7 PGMS <O-8075'>,,3,Pad 2F 4-Feb-92 714.8 20.0 20.0 PGMS <O-8050'>,,4~Pad 2F 4-Feb-92 774.7 20.0 20.0 PGMS <O-9470'>,,6,Pad 2F 4-Feb-92 768.4 20.0 20.0 PGMS <O-9055'>,,7,Pad 2F 4-Feb-92 713.1 20.0 20.0 PGMS <O-637'5'>,,8,Pad 2F 4-Feb-92 658.1 240.0 700.0 PGMS <O-6560'>,,9,Pad 2F 4-Feb-92 281.9 640.0 640.0 PGMS <O-8725'>,,10,Pad 2F 4-Feb-92 279.1 360.0 360.0 PGMS <O-10160'>,,11,Pad 2F 4-Feb-92 289.3 20.0 20.0 PGMS <O-7380'>,,5,Pad 2F 4-Feb-92 821.3 725.0 725.0 18 (Gold Hills) Vers.#6,,18(GH),Pad 2F 6-Dec-96 149.1 280.0 280.0 19 Version #6,,19,Pad 2F 10-Dec-96 58.6 900.3 900.3 400 400 800 1200 1600- ~ 2000 240O Ch 280O 3200 3600 40aa I v 4400 4800 5200 56O0 6OOO 6400 ARCO ALASKA, Inc. <-Wes,(,ee}) 2400 2000 1600 1200 800 400 0 Structure : Pad 2F Well : 17 ~ ~ ~ ~ ' ~ ~ ~ ~ ~ ~ ~ ' 270.00 Az,~ 0 ..... , [ SURFACE LOCATION: ] // 400 :,~ ~,,,-~, FOR: D PET~SH[ I 128' FNL, 1738" FEL[ / ~t.,~: ~-~-g~ I [ SEC. 33, T11N, R9E / / 196.37 DEC Az 6269' (TO TARGET) ~ ~600 ***Plane of Proposal***~ 7 5/8 C~slng / 2000 [ ~KB EL~ATION: 138' J RECEIVED/ 9'.42 , · ~ ~,.~ Anchorage ~'/ 17.73 ~/~ % 23.55 =/ ;~00 % 26.49 ~ 29.44 ~ X 32.40 ~ ooov ~ /, T,~OST ,OCAT~O,: ~ ~5 22 ~ / I S~C. 4, T~O~ ~9~ I ~ ~ ' ~OC W0=2424 TMD=2727 DEP=875 ~ ~ ~ ~ 4400 ~ T/W SAK SNDS ~D=2435 TMD=2746 DEP=891 ~ ~ 4~oo ~ 7 5/8 Ceslng / ~D=6077 DEP 6269 T/ TBSCO (C80) ~D~378 TMD=~77 OEP=2543 ~ / u~=ezu~ ~ / so~=6o~5 ~ ~ WEST= 1767 5600 MAXIMUM ANGLE ~ ( / ) ~ooo 7.oo DSG - 8400 6800 K-5 (C40) WD=49~8 [M0=7305 DEP=4714 BLS: 2.00 deg per 100 ft 43.05 TA ~ ~ ~ TARGET - A4 (EOD) TVD=6077 .TMD=9252 DEP=6269 ~U ~ B/ KUP SNDS (MLVCH)WD=6164 TMD=9366 DE~6~4~_ TD ~ ~ 1/2" CSG PT ~D=6~17 TMD=g566 i i I i t i i i i i i i t i ii i i ii 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 3200 ~600 4000 4400 4800 5200 5600 6000 6400 6800 Verficol Secfion (feel) -> Azimuth 196.37 with reference 0.00 N, 0.00 E from slot #17 C,~d ~, ~.~. FOR: D PETRASH Oot~ plotted: 10-De:-95 P~o~ ~ere~e ;s 17 V~ ~7. ~r~nat~ ore in fed r~er~e ~t ~17. ARCO ALASKA, Inc. Structure : Pad 2F Well : 17 Field : Kuparuk River Unit Location : North Slope, Alaska 16o 120 80 40 120 ...I-- ~ 160 200 I 240 V 280 320 3~0 400 440 480 520 <- West (feet) 360 320 280 240 200 160 120 80 40 0 40 80 120 160 200 240 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I [ 160 120 3300 ~° '"~ 1100 ~?~e '..,.,~oo ,,oo/- ,oo '.. /' ~ "'.... ..... ,' 1900 ~ 13oo/ ",, 21oo // 1500~',,, ~ / ,oo ,,,,, 2100 360 320 280 240 200 160 120 80 40 0 40 80 120 160 200 240 ,/ '~ 1100 // ~700 xxx / /11oo i goo / i13oo 80 40 <- West (feet) 80 120 0 '",, 160 ' 240 I ',, 1900 V · 28O 32O 360 4OO 440 480 520 7 I 13 5/8" 5000 BOP STACK , 6 5 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. 16"- 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8"-5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8"- 5000 PSI ANNULAR 1. FILL BOP STACKAND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSi LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSi AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. VBRS WILL ACCOMODATE 3-1/2" TO 5-1/2" OR 5" TO 7" PIPE ODS AS APPROPRIATE. ACCUMULATOR CAPACITY TEST UPARUK RIVER UNI,' 20" DIVERTER SCHEMATIC 6 4 3 O , DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. I , . 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. SLIPK:)N 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 . w 'LL PERMIT CHECKLIST COMPANY FIELD&POOL ¢ ~./OO INIT CLASS / ADMIhlS'~ RATION -- GEOL AREA PROGRAM: exp 1:3 der [] redrll 0 sen/[] wellbore seg E] ann. disposal para req [] UNIT# /? )~',~ ON/OFF SHORE ENGINEERING 1. Permit fee a~ached ....................... N 2. Lease number appropriate ................... N 3. Unique well name and number ................. N 4. Wetl located in ~ de,ned pool .............. [.[. :[. 5. Well located proper distance from drlg unit boundary. 6, Well located proper distance from other wells ..... 7. Sufficient acreage avai~le in drilling unit. .......... N 8. If deviated, is wellborn pb.t included ............. N 9. Operator only a~fected party .................. N 10. Operator has appropriate bond in force ............. N 11. Permit can be issued wil~out conservation order ..... N 12. Permit can be issued wi~out administrative approva~ ..... 13. Can Permit be approved before 15-day wait. ....... REMARKS -GEoLoGY ...... APPR DATE_ _?: ,_ 14. Conductor string provided .................. 15. Surface ca.s~ng protects all known USDWs .......... 16. CMT vol adequate to circuiste on conductor & surf csg . . . 17. CMT vol adequate to tie-in long s~ng to surf csg ....... ,~ 18. CM'T' will cover all known productive horizons. ........ .Y~TN 19. Casing de..~gns adequate for C, T, B & permafrost. ..... ~ N 20. Adequate tankage or reserve pit. .............. .~ N 22. Adequate wellbore separation proposed ........... [ N 23. If diverter required, is it adequate ................ N 24. Ddlling fluid program scherr~dc & equip list adequate .... N 25. BOPEs adequate ........................ N 26. BOPE press rating adequate; test to -~C¢¢'Z;> psi 27. Choke manifold complies w/APl RP-53 (May 84) ....... .(,,.Y/N N ~J~ 28. Work will occur without operation shuh-lown ......... .(~N 2~. is presence of H2S gas probable .............. _ . ............... 30. Permit c, an be issued w/o hydrogen sulfide measures ..... .Y..N/~ 31. Dat~ presented on potential overpressure zones ....... 32. Seismic anaJysis of shallow gas zones ............. /~N ' . 33. Seabed condition survey (if off-shore) ........... //. Y N 34. Cor'~ name/phone forweekl~ progress repo~ ...../... Y N lexploratory only] GEOLOGY: ENGINEERING: COMMISSION: JDH ~ JDN TAB '~ Comme~ts/Insm~ctions: Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. * ALASKA COMPUTING CENTER * , . ****************************** * ............................ . ....... SCHLUMBERGER ....... * ............................ , ****************************** COMPANY NAME : ARCO ALASKA. INC. WELL NAME : 2F-17 FIELD NAME : KUPARUK BOROUGH : NORTH SLOPE STATE : AK API NUMBER : 500292273100 REFERENCE NO : 97163 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-MAY-1997 09:00 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 97/05/ 5 ORIGIN : FLIC REEL NAME : 97163 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC, 2F-17, KUPARUK, API #50-029-22731-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 97/05/ 5 ORIGIN : FLIC TAPE NAME '. 97163 CONTINUATION # : 1 PREVIOUS TAPE : COI~4ENT : ARCO ALASKA INC, 2F-17, KUPARUK, API #50-029-22731-00 TAPE HEADER KUPAR ~K OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL : FSL : FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD RUN 1 97163 E. BARTZ D. WESTER 1ST STRING 2ND STRING 2F-17 5002922731 O0 ARCO ALASKA, INC. SCHLU~i~ERGER WELL SERVICES 2-MAY-97 RUN 2 RUN 3 4 1 ON 9E 1057 1721 129.00 127.50 97.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 4.750 15.500 8923.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-MAY-1997 09:00 3RD STRING PRODUCTION STRING CONTAINED HEREIN IS THE DITE/GR DATA ACQUIRED ON ARCO ALASKA INC. WELL 2F-17. NO DEPTH SHIFTS WERE APPLIED TO THIS DATA AS IT IS THE PRIMARY DEPTH CONTROL (PDC). RIG = NORDIC #2. DEPTH CONTROL = OPEN HOLE MARKED LINE (USING NORDIC #2 RKB OF 129.0' ABOVE PERM. DATUM). PERM. DATUM = MEAN SEA LEVEL; ELEVATION 0.0'. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/05/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED OPEN HOLE MAIN PASS Ail tool strings; Depth shifted and clipped curves; all runs merged; no cased hole da£a. DEPTH INCREFiENT: 0.5000 FILE S~Y LDWG TOOL CODE .............. DTE $ BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 9174.0 8906.0 BASELINE DEPTH MERGED DATA SOURCE LDWG TOOL CODE R~4ARKS : THIS FILE CONTAINS THE CLIPPED AND EDITED MAIN PASS DATA FROM THE OPEN HOLE SECTION OF THE LOGGING RUN. NO DEPTH SHIFTS WERE APPLIED TO THIS DATA AS IT IS THE PRIMARY DEPTH CONTROL (PDC). $ .......... EQUIVALENT UNSHIFTED DEPTH .......... DTE ....... RUN NO. PASS NO. MERGE TOP MERGE BASE LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-MAY-1997 09:00 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE ~ 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 48 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 21 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE ~ CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER~ ~ LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 548885 O0 000 O0 0 1 1 1 4 68 0000000000 IDPH DTE OH~lM548885 O0 000 O0 0 1 1 1 4 68 0000000000 IMPH DTE OH~ff~548885 O0 000 O0 0 1 1 1 4 68 0000000000 ILD DTE OH~4M548885 O0 000 O0 0 1 1 1 4 68 0000000000 ILM DTE OH~4M548885 O0 000 O0 0 1 1 1 4 68 0000000000 SFL DTE OHMM548885 O0 000 O0 0 1 1 1 4 68 0000000000 GR DTE GAPI 548885 O0 000 O0 0 1 1 1 4 68 0000000000 TEND DTE LB 548885 O0 000 O0 0 1 1 1 4 68 0000000000 TENS DTE LB 548885 O0 000 O0 0 1 1 1 4 68 0000000000 MRES DTE OHMM548885 O0 000 O0 0 1 1 1 4 68 0000000000 MTEMDTE DEGF 548885 O0 000 O0 0 1 1 1 4 68 0000000000 SP DTE MV 548885 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 9174.000 IDPH.DTE -999.250 IMPH.DTE -999.250 ILD.DTE ILM. DTE -999.250 SFL.DTE -999.250 GR.DTE -999.250 TEND.DTE TENS.DTE 4458.000 MRES.DTE -999.250 MTEM. DTE -999.250 SP.DTE -999.250 369.452 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-MAY-1997 09:00 PAGE: DEPT. 8906.000 IDPH.DTE ILM. DTE 0.868 SFL.DTE TENS.DTE 3418.000 PiRES.DTE O . 338 IMPH . DTE 3. 413 GR.DTE O . 846 MTEM. DTE 1.528 77.685 143.684 ILD.DTE TEND.DTE SP.DTE 0.448 203.127 32. 000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 97/05/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE . FLIC VERSZON · 001C0~ DATE · 97/05/ 5 MAX REC SIZE : ! 024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUPIBER: 2 EDITED CASED HOLE MAIN PASS Depth shifted and clipped curves for open hole logs run into casing. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE S~Y LDWG TOOL CODE START DEPTH DTE 8906.0 $ BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (MEASURED DEPTH) STOP DEPTH .......... 8825.0 BASELINE DEPTH $ .......... EQUIVALENT UNSHIFTED DEPTH .......... DTE THIS FILE CONNTAINS THE CLIPPED AND EDITED MAIN PASS DATA FROM THE CASED HOLE SECTION OF THE LOGGING RUN. NO DEPTH SHIFTS WERE APPLIED TO THIS DATA AS IT IS THE PRIMARY DEPTH CONTROL (PDC). LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-MAY-1997 09:00 PAGE: $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 548885 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH DTE GAPI 548885 O0 000 O0 0 2 1 1 4 68 0000000000 TEND DTE LB 548885 O0 000 O0 0 2 1 1 4 68 0000000000 TENS DTE LB 548885 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 8906. 000 GRCH.DTE 77. 685 TEND.DTE 203 . 127 TENS.DTE DEPT. 8825. 000 GRCH.DTE 97.204 TEND.DTE 212. 882 TENS.DTE 3418.000 3444.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-MAY-1997 09:00 PAGE: **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : 001 CO1 DATE : 97/05/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE H~ER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE . 97/05/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 3 RAW OPEN HOLEMAIN PASS Curves and log header data for each run and tool string in separate files; Tool String #1 fo Sadlerochit run presented first (primary depth control string used to depth shift the Sadler interval) followed by files for other main pass tool strings per run. 1 1 1 0.5000 RUN NUM~ER: TOOL STRING NUMBER: PASS NUMBER: DEPTH INCREMENT: FILE SU~fiVARY VENDOR TOOL CODE START DEPTH STOP DEPTH DITE 9219.5 8906.0 $ LOG HEADER DATA DATE LOGGED: 23 -MAR- 97 SOFTWARE VERSION: 8C0 - 609 TIME CIRCULATION ENDED: 600 23-MAR-97 TIME LOGGER ON BOTTOM: 230 23-MAR-97 TD DRILLER (FT) : 9561.0 TD LOGGER (FT) : 9174.0 TOP LOG INTERVAL (FT) : 8905.0 BOTTOM LOG INTERVAL (FT) : 9174.0 LOGGING SPEED (FPHR) : TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... DITE DUAL INDUCTION CART. GR GAlV~VA RAY TOOL NUMBER ........... DIC-EB 262 SGC-SA LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-MAY-1997 09:00 PAGE: AMS AUX. MEAS. SONDE AMS - A BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 4.750 8923.0 8905.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMO?4 RECORDED TEMPERATURE (DEGF) : RESISTIVITY (OH~4) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT) : MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT) : WEIGHTED LSND 13.20 50.0 9.5 1. 035 65.0 O. 674 72.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): O. 25 REMARKS: TWO .25" STANDOFFS RUN ON PHASOR. 20 KHZ FREQUENCY USED FOR INDUCTION MEASUREMENT. BRIDGED AT 9180', LOGGED OUT FROM THERE DUE TO INCREASED STICKING. RIG: NORDIC #2. THIS FILE CONTAINS THE RAW DATA ACQUIRED OVER THE OPEN HOLE SECTION OF THE MAIN PASS LOGGING RUN. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 112 4 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-MAY-1997 09:00 PAGE TYPE REPR CODE VALUE 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 9 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 548885 O0 000 O0 0 3 1 1 4 68 0000000000 IDPH ROM 0H~548885 O0 000 O0 0 3 1 1 4 68 0000000000 IMPH ROM 0Pk4~548885 O0 000 O0 0 3 1 1 4 68 0000000000 ILD ROM 0H~I548885 O0 000 O0 0 3 1 1 4 68 0000000000 ILM ROM 0H~4548885 O0 000 O0 0 3 1 1 4 68 0000000000 SFLU ROM 0t~4~548885 O0 000 O0 0 3 1 1 4 68 0000000000 GR ROM GAPI 548885 O0 000 O0 0 3 1 1 4 68 0000000000 HTENROM LB 548885 O0 000 O0 0 3 1 1 4 68 0000000000 TENS ROM LB 548885 O0 000 O0 0 3 1 1 4 68 0000000000 MRES ROM 0H~I548885 O0 000 O0 0 3 1 1 4 68 0000000000 MTEMROM DEGF 548885 O0 000 O0 0 3 1 1 4 68 0000000000 SP ROM MV 548885 O0 000 O0 0 3 1 1 4 68 0000000000 CIDP ROM ~4HO 548885 O0 000 O0 0 3 1 1 4 68 0000000000 CIMP ROM I~IHO 548885 O0 000 O0 0 3 1 1 4 68 0000000000 CILD ROM MMHO 548885 O0 000 O0 0 3 1 1 4 68 0000000000 CILMROM ~IHO 548885 O0 000 O0 0 3 1 1 4 68 0000000000 IIRD ROM MMHO 548885 O0 000 O0 0 3 1 1 4 68 0000000000 IIXDROM Nk4HO 548885 O0 000 O0 0 3 1 1 4 68 0000000000 IIRMROM ~IHO 548885 O0 000 O0 0 3 1 1 4 68 0000000000 IIXMROM z~4HO 548885 O0 000 O0 0 3 1 1 4 68 0000000000 CDER ROM ~IHO 548885 O0 000 O0 0 3 1 1 4 68 0000000000 CDVR ROM Nk4HO 548885 O0 000 O0 0 3 1 1 4 68 0000000000 IDER ROM 0I~4~548885 O0 000 O0 0 3 1 1 4 68 0000000000 IDVR ROM 0H~548885 O0 000 O0 0 3 1 1 4 68 0000000000 CM~R ROM ~4~IHO548885 O0 000 O0 0 3 1 1 4 68 0000000000 CMVR ROM ~!HO 548885 O0 000 O0 0 3 1 1 4 68 0000000000 IMER ROM 0I~4 548885 O0 000 O0 0 3 1 1 4 68 0000000000 IMVR ROM 0HN~548885 O0 000 O0 0 3 1 1 4 68 0000000000 DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-MAY-1997 09:00 PAGE: DEPT. 9219.500 IDPH.ROM ILM. ROM 9. 882 SFLU. ROM TENS.ROM 850. 000 ~S.ROM CIDP.ROM 110. 807 CIMP.ROM IIRD.ROM 100.367 IIXD.ROM CDER.ROM 11 O. 671 CDVR.ROM CMER. ROM 99. 296 CMVR. ROM DEPT. 8906. 000 IDPH. ROM ILM. ROM O. 868 SFLU. ROM TENS. ROM 3418.0 O0 ~ES. ROM CIDP. ROM 2958.806 CIMP. ROM IIRD.ROM 1211.550 IIXD.ROM CDER.ROM 2380. 079 CDVR.ROM CMER . ROM 599. 624 CMVR . ROM 9.025 IMPH.ROM 13.824 GR.ROM 0.887 MTE~.ROM 99.275 CILD.ROM 8.956 IIRM. ROM 110.897 IDER.ROM 99.329 IMER.ROM 0.338 IMPH.ROM 3.413 GR.ROM 0.846 MTE~I. ROM 654.520 CILD.ROM -617.702 IIRM. ROM 2654.207 IDER.ROM 955.369 IMER.ROM 10 073 77 298 149 189 113 163 95 802 9 036 10 071 1.528 77.685 143.684 2230.919 1019.992 0.420 1.668 ILD. HTEN. SP. CILM. IIX~. IDVR . IMVR. ILD. HTEN. SP. CILM. I IXM. IDVR . IMVR. ROM ROM ROM ROM ROM ROM ROM ROM ROM ROM ROM ROM ROM ROM 8. 837 -57 460 0 000 101 197 18 097 9 017 10 068 0 448 203 127 32 000 1152 050 -932 356 0 377 i 047 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE ' FLIC VERSION · O01CO1 DATE : 97/05/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION · O01CO1 DATE : 97/05/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 4 RAW CASED HOLE MAIN PASS Curves and log header data for open hole logs run into casing. PASS NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE S~IARY VENDOR TOOL CODE START DEPTH STOP DEPTH DITE 8906.0 8823.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-MAY-1997 09:00 PAGE: 10 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME CIRCULATION ENDED: TI~E LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DITE DUAL INDUCTION CART. GR GA~VA RAY AMS AUX. MEAS. SONDE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: FLUID LOSS (C3): MAXIMUM RECORDED TE~IPERATURE (DEGF) : RESISTIVITY (OH~N) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): MUD AT BOTTOM HOLE TEMPERATURE (BHT): MUD FILTRATE AT (MT): MUD FILTRATE AT (BHT) : MUD CAKE AT (MT): MUD CAKE AT (BHT): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): REMARKS: 23-MAR-97 8C0 - 609 600 23 -MAR-97 230 23 -MAR-97 9561.0 9174.0 8905.0 9174.0 TOOL NUMBER DIC-EB 262 SGC-SA AMS-A 4.750 8923.0 8905.0 WEIGHTED LSND 13.20 50.0 9.5 1.035 65.0 0.674 72.0 0.25 TWO .25" STANDOFFS RUN ON PHASOR. 20 KHE FREQUENCY USED FOR INDUCTION MEASUREMENT. BRIDGED AT 9180', LOGGED OUT FROM THERE DUE TO INCREASED STICKING. RIG: NORDIC #2. THIS FILE CONTAINS THE RAW DATA ACQUIRED OVER THE CASED LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-MAY-1997 09:00 PAGE: 11 HOLE SECTION OF THE MAIN PASS LOGGING RUN. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 16 4 66 1 5 66 6 73 7 65 8 68 O. $ 9 65 FT 11 66 64 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 I ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 548885 O0 000 O0 0 4 1 1 4 68 0000000000 GR RCM GAPI 548885 O0 000 O0 0 4 1 1 4 68 0000000000 HTENRCM LB 548885 O0 000 O0 0 4 1 1 4 68 0000000000 TENS R~4 LB 548885 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 8906.000 GR.RCM 77.685 HTEN. RCM 203.127 TENS.RCM DEPT. 8823.500 GR.RCM 102.375 HTEN.RCM 206.161 TENS.RCM 3418.000 3486.000 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 5-MAY-1997 09:00 PAGE: 12 **** FILE TRAILER **** FILE NA~E : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 97/05/ 5 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 97/05/ 5 ORIGIN '. FLIC TAPE NAME : 97163 CONTINUATION # : 1 PREVIOUS TAPE : CO~fENT : ARCO ALASKA INC, 2F-17, KUPARUK, API #50-029-22731-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 97/05/ 5 ORIGIN : FLIC REEL NAME : 97163 CONTINUATION # : PREVIOUS REEL : COf~ENT : ARCO ALASKA INC, 2F-17, KUPARUK, API #50-029-22731-00 Sperry-Sun Drilling Services LIS Scan Utility Thu May 01 08:29:41 1997 Reel Header Service name ............. LISTPE Date ..................... 97/05/01 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Tape Header Service name ............. LISTPE Date ..................... 97/05/01 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Technical Scientific Technical Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING (FT FROM MSL 0) MWD RUN 2 AK-MM-70025 R. KRELL D. LUTRICK Date~ 2F-17 500292273100 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 01-MAY-97 33 lin 9E 128 1738 139.50 138.00 96.80 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 9.875 7.625 4016.0 6.750 8932.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND NOT PRESENTED. 3. MWD RUN 2 IS DIRECTIONAL WITH SCINTILLATION TYPE GAMMA RAY (NGP/SGRD) . 4. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8932'MD, 5876'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 3932.0 8832.5 ROP 3993.5 8897.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH ...... BASELINE DEPTH GR 3932.0 3967.5 8827.0 8862.5 8897.5 8933.0 $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MWD 2 4029.0 $ REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical=~og depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... MERGE BASE 8933.0 Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 3932 8897.5 6414.75 9932 3932 ROP 4.1216 1254.2 172.61 9809 3993.5 GR 39.4204 621.539 124.061 9802 3932 Last Reading 8897.5 8897.5 8832.5 First Reading For Entire File .......... 3932 Last Reading For Entire File ........... 8897.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Serve_ce Sub Level Name... Version. Number ........... 1.0.0 Date of Generation ....... 97/05/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SU~..<MARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3967.5 8875.5 ROP 4029.0 8933.0 $ LOG HEADER DATA DATE LOGGED: 03-FEB-97 SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG iNTERVAL (FT) : iSC 4.96/4.96 CIM 5.46/DEP2 2.042 MEMORY 8933.0 4029.0 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 NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHN[M) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 8933.0 39.4 59.4 TOOL NUMBER NGP 228 6.750 6.8 LSND 9.50 51.0 8.5 4OO 6.8 .000 .000 .000 .000 49.5 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 2 FT/H 4 1 68 4 2 GR MWD 2 AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 86.1027 8933 6444.61 9927 3967.5 ROP 4.1216 8875.5 177.116 9804 4029 GR 39.4204 8875 128.51 9812 3967.5 Last Reading 8933 8933 91.3805 First Reading For Entire File .......... 3967.5 Last Reading For Entire File ........... 8933 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/05/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/05/01 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Reel Trailer Service name ............. LISTPE Date ..................... 97/05/01 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Services Scientific Scientific Technical Technical Physical EOF Physical EOF End Of LIS File
