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Home My WebLink About198-065MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Friday, July 22, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Guy Cook P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1D-09 KUPARUK RIV UNIT 1D-09 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 07/22/2022 1D-09 50-029-22875-00-00 198-065-0 G SPT 6150 1980650 1538 2910 2910 2910 2911 35 50 50 50 4YRTST P Guy Cook 7/10/2022 Testing completed with a Little Red Services pump truck and calibrated gauges. 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1D-09 Inspection Date: Tubing OA Packer Depth 1070 2010 1975 1970IA 45 Min 60 Min Rel Insp Num: Insp Num:mitGDC220709074222 BBL Pumped:0.6 BBL Returned:0.8 Friday, July 22, 2022 Page 1 of 1 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.07.22 16:21:34 -08'00' c ii —a' Regg, James B (DOA) From: CPF1 Prod Engr <n1269@conocophillips.com> Sent: Thursday,January 18, 2018 4:10 PM To: Regg,James B (DOA) ° ` ' i( 11/(3 Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Well Integrity Supv CPF1 and 2; Lewis, Brian M; McKee, Garrett L; NSK Prod Engr Specialist;Targac, Gary; CPF1 DS Operators; Carlisle, William B Subject: Defeated LPP/SSV on CPAI well 1 D-07 & 1 D-09 Jim, The low pressure pilot(LPP) on well 1D-07 (PTD#179-112) & 1D-09 (PTD#198-065)was defeated today, 1/18/18, after the C-WIX was swapped from Seawater Injection to Produced Water Injection service due to a mechanical failure on one of our larger turbine driven Produced Water injection pumps. This has reduced the injection capacity of our Seawater system and caused a decrease in our injection header pressure. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the"Facility Defeated Safety Device Log." 1 D-07 is currently injecting 1200 BWPD at a wellhead injection pressure of 500 psig . 1 D-09 is currently injecting 2500 BWPD at a wellhead injection pressure of 630 psig . The AOGCC will be notified when the injection pressure has increased to above 700 psig and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO No. 432D." Please let me know if you have any questions. Kind Regards, Courtney Gallo/Will Carlisle CPF-1 Production Engineer N1269 ,conocophillips.com Office: (907) 659-7493 Cell: (720) 318-5762 SCANNEV From: NSK West Sak Prod Engr Sent:Saturday, October 22, 2016 5:48 PM To: Regg,James B (DOA)<jim.regg@alaska.gov> Cc: CPF1 DS Lead Techs<n1140@conocophillips.com>; CPF1 Ops Supv<n2067@conocophillips.com>; NSK Problem Well Supv<n1617@conocophillips.com>; Sullivan, Michael<Michael.Sullivan@conocophillips.com>; NSK Prod Engr Specialist <n1139@conocophillips.com>; CPF1 Prod Engr<n1269@conocophillips.com>; Targac, Gary <Gary.Targac@conocophillips.com>; NSK Optimization Engr<n2046@conocophillips.com>; CPF1 DS Operators <n1275@conocophillips.com>; Effiong, Michael <Michael.Effiong@conocophillips.com> Subject: Defeated LPP/SSV on CPAI well 1J-102 Jim, The low pressure pilot(LPP) on well 1J•2 (PTD#206-110, 206-111, 206-112)was tfeated today, 10/22/16, after the well was returned to water injection service. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The well is currently injecting 470 BWPD at a wellhead injection pressure of 2 psig. The AOGCC will be notified when the injection pressure has increased to above 100 psig and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 406B.001." Please let me know if you have any questions. Kind Regards, Scott Stanley /David Haakinson West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 n1638@conocophillips.com • 2 RECEIVED ConocoPhillips AUG 2 9 2015 Alaska �'°►pp��/� P.O. BOX 100360 AOGCC ANCHORAGE,ALASKA 99510-0360 August 25, 2016 Commissioner Cathy Foerster Alaska Oil & Gas Commission SCANNED SEP 3 0 2016 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field(KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name, top of cement depth prior to filling and volumes used on each conductor. Please call Roger Winter at 907-659-7006 or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, �� Roger Winter ConocoPhillips Well Integrity Field Supervisor • • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Kuparuk Field Date 8/25/2016 1 D,2A,2L,2N&2W PAD Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 1D-09 50029228750000 1980650 14" NA 14" NA 7 8/24/2016 2A-19A 50103201970100 2010830 11" NA 11" NA 4.25 8/24/2016 2L-306 50103206300000 2101820 12" NA 12" NA 2.55 8/24/2016 2N-341 50103202630000 1981030 14" NA 14" NA 6.8 8/24/2016 2N-347 50103203370000 2000630 13" NA 13" NA 10.2 8/24/2016 2W-10 50029212390000 1842230 10" NA 10" NA 6 8/24/2016 • STATE OF ALASKA• • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend r Perforate r Other Stimulate Alter Casing(- F7 Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: conductor extend 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 198-065 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service ( 50-029-22875-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025650 KRU 1 D-09 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 7024 feet Plugs(measured) None true vertical 6651 feet Junk(measured) none Effective Depth measured 6928 feet Packer(measured) 6489 true vertical 6557 feet (true vertical) 6126 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 122 122' SURFACE 4504 9 5/8 4546 4322' PRODUCTION 6634 7 6673 6305' LINER 526 4 1/2 7024 6651' RECEIVED JUN 2 3 2016 Perforation depth: Measured depth: 6790-6810, 6835-6843,6846-6843,6857-6856, 6877-6882, 6887-6892 True Vertical Depth: 6412-6416,6421-6441, 6466-6473,6476-6482, 6487-6495,6507-6512, 6417-65 9 Tubing(size,grade,MD,and TVD) 4.5, L-80, 6489 MD, 6126 TVD Packers&SSSV(type,MD,and TVD) NIPPLE-CAMCO DB-6 NIPPLE NO GO @ 512 MD and 512 TVD Packer BAKER ZXP MD@6513 and TVD@ 6149 12.Stimulation or cement squeeze summary: Intervals treated(measured): NA Treatment descriptions including volumes used and final pressure: NA 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 F Exploratory r Development r Service F. 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 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: 316-204 Contact MJ Loveland 7 Email: n1878conocophillips.com Printed Name MJ Loveland Title: NSK Well Integrity Project Supervisor �� Signature /%� _Phone:659-7043 •Date ��aC///‘ VTC— //2 /lG 7 Form 10-404 Revised 5/2015 A q1 // � Submit Original Only JUN 2 3 2016 g • 0 RECEIVED ConocoPhillips JUN 2 3 2016 Alaska AOGCC P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 June 20, 2016 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 Operations for ConocoPhillips Alaska, Inc. well 1D-09, PTD 198-065 conductor extension. Please contact me at 659-7043 if you have any questions. Sincerely, 4 ere/ MJ Lo eland ConocoPhillips Well Integrity Projects Supervisor 1D-09 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 06/17/16 Weld 14" extension on to conductor kqg -Dcv. 5 RECEIVED21124,Cp MAY 10 2011) WELL LOG TRANSMITTAL#903214222 To: Alaska Oil and Gas Conservation Comm. May 5, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA ii oG ED Anchorage, Alaska 99501 M K BENDER RE: Injection Profile : 1D-09 Run Date: 3/28/2016 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 1D-09 Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-029-22875-00 Injection Profile Log SCANNED y 1 Color Log 50-029-22875-00 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. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: / vQd2�4147.4 ,, / �EAktt • • ti OF Tit 0+1. �1/7;4., THE STATE Alaska Oil and Gas ti "? Of LASKA Conservation Commission - 333 West Seventh Avenue 1"41-.17111*-- r. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 4:;) ALAs11"P' Fax: 907.276.7542 www.aogcc.alaska.gov MJ Loveland NSK Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. SCANIEV T P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1D-09 Permit to Drill Number: 198-065 Sundry Number: 316-204 Dear Ms. Loveland: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this OLday of April, 2016. RBDMS Lk/ APR 0 5 2016 ii .CEIVED . • III STATE OF ALASKA MAR 2 9 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION (XS 4/4-1 APPLICATION FOR SUNDRY APPROVALS AOGCG` 20 AAC 25.280 1.Type of Request: Abandon r Flug Perforations r Fracture Stimulate r Repair Well Operations shutdown r Suspend r Perforate r Other Stimulate r Pull Tubing r Change Approved Program r Rug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing r • Other: conductor extend +r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r 198-065 3.Address: Stratigraphic r Service r 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-22875-00 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Alf Will planned perforations require spacing exception? Yes r No r / KRU 1 D-09 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025650 ‘ Kuparuk River Field/Kuparuk River Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 7024 ' 6651 - 6928' - 6557' • 3400' none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 16 121' 121' SURFACE 4504 9 5/8 4546' 4322' PRODUCTION 6634 7 6673' 6305' LINER 526 4 1/2 7024' 6651' Perforation Depth MD(ft):6780-8784, Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6790-6810,6835-6843,6846-6843, 6412-6416,6421-6441,6466-6473,6476- 6857-6856,6877-6882,6887-6892 ' 6482,6487-6495,6507-6512,6417-6522 4.5 L-80 6489 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) No SSSV-CAMCO DB-6 NIPPLE NO GO • MD=512 TVD=512 Packer BAKER ZXP • MD=6513 TVD=6149 12.Attachments: Proposal Summary r WellBore Schematic r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service r , 14.Estimated Date for 15. Well Status after proposed work: 04/16/16 Commencing Operations: OIL r VVINJ r WDSPL r Suspended r 16.Verbal Approval: Date: GAS r WAG r • GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdow n r Abandoned r 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact: MJ Loveland Printed Name MJ Loveland Phone:659-7043 Email: n1878(a�conocophillips.com Title: NSK Well Integrity Project Supervisor Signature e��/�y 71. Date: /� 3/.2 6://‘ Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3\l.,,e- 20y Rug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Post Initial Injection MIT Req'd? Yes r No I/ Spacing Exception Required? Yes r No r✓ Subsequent Form Required: /0 —40}- APPROVED BY Approved by: P 1Gom `7"`. -- COMMISSIONER THE COMMISSION Date:T / 1/TL /4//10 Y 3/30//L � /� Form 10-403 Revised 11/2015 O pbcatinn s alid for 12 months from the date of approval. Attachments in Duplicate ��//////77 RBDMS 1,k- t' ? 0 5 2016 Submit Form and • • ConocoPhillips RECEIVED Alaska MAR 2 9 2016 P.O. BOX 100360 . ANCHORAGE,ALASKA 99510-0360 March 26, 2016 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 1D-09, PTD 198-065 conductor extension. Please contact me at 659-7043 if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska,Inc. Kuparuk Well 1D-09 (PTD 198-065) SUNDRY NOTICE 10-403 APPROVAL REQUEST 03-26-16 This application for Sundry approval for Kuparuk well 1D-09 is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to the surface casing. At some point during normal operations the conductor subsided about 12". With approval, the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Examine surface casing for any corrosion damage if it is exposed. 3. Extend the conductor to starter head. 4. File 10-404 with the AOGCC post repair. NSK Well Integrity Projects Supervisor 5 KUP INJ • 1D-09 ConoCoPhillips 01 Well Attributes Max Angle&MD TD Alaska.Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(1166) Act Btm(ftKB) c,,,, ,pr 500292287500 KUPARUK RIVER UNIT INJ 26.99 3,250.36 7,024.0 o ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 10-09,3/1420164:39:10 PM SSSV:NIPPLE Last WO: 4/22/1998 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 6,841.0 3/11/2016 Rev Reason:TAG ppmven 3/14/2016 y HANGER',364 -f I _lik-� Casing Strings r1'; t■ Casing Description OD(in) ID(in) Tap(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread lig�. !� CONDUCTOR 16 15.062 42.0 121.0 121.0 62.58 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.835 41.2 4,545.6 4,321.1 40.00 L-80 BTC ICasing Descnptian OD(in) ID(in) Top(ftKB) Set Depth(ftKB) -Set Depth(TVD)...Wt/Len(I.. Grade Top Thread I PRODUCTION 7 6.276 38.6 6,672.5 6,305.8 26.00 L-80 BTC MOD 4 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD) Wt/Len(I...Grade Top Thread LINER 4 1/2 3.958 6,497.8 7,024.0 6,651.3 12.60 L-80 NSCT Liner Details Nominal ID I Top(ftKB) Top(TVD)(ftKB) Top Incl(") Item Des Com (In) 1 6,497.8 6,134.9 13.59 PBR BAKER PBR SEAL BORE 4.750 ,Ant.CwwwCwTOww1w1w � 6,512.7 6,149.4 13.35 PACKER BAKER ZXP LINER PACKER w/HOLDDOWNS 3.875 6,519.9 6,156.5 13.20 HANGER BAKER HMC LINER HANGER 3.937 6,680.2 6,313.4 10.62 NIPPLE CAMCO DB-6 NIPPLE 3.750 NIPPLE;511.8 _ Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING 41/2 3.958 36.3 6,502.0 6,139.0 12.60 L-80 NSCT Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) ac 36.3 36.3 0.00 HANGER FMC GEN 5 TUBING HANGER 4.500 i , 511.8 511.7 2.00 NIPPLE CAMCO DB-6 NIPPLE NO GO 3.812 6,446.2 6,084.6 14.27 NIPPLE OTIS X NIPPLE 3.813 3.880 6,488.7 6,126.1 13.71 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 6,502.0 6,139.0 13.54 SHOE BOTTOM OF MULESHOE ON SEAL ASSEMBLY 4.000 Perforations&Slots _' .; c__',7::„..'",',5,7 SURFACE;41.2-4,545.6 Shot Den Top(IVO) Bun(TVD) (shots/f Top(ftKB) etm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com GAS LIFT;s,396 4 6,780.0 6,784.0 6,411.5 6,415.5 C-4,10-09 9/29/2008 6.0 APERF 2 7/8°HSD 2906 PJ Omega Guns,60 Deg pH 6,790.0 6,810.0 6,421.4 6,441.0 C-4,10-09 5/21/1998 4.0 (PERF 2 7/8 HC,DP;60-120 deg ph,no orient 6,835.0 6,843.0 6,465.6 6,473.5 C-3,1D-09 9/29/2008 6.0 APERF 2 7/8"HSD 2906 PJ Omega Guns,60 Deg NIPPLE;8,448.2 pH J 6,846.0 6,852.0 6,476.4 6,482.3 C-3,1D-09 9/29/2008 6.0 APERF 2 7/8"HSD 2906 PJ Omega Guns,60 Deg pH 6,857.0 6,865.0 6,487.2 6,495.1 C-2,1D-09 9/29/2008 6.0 APERF 2 7/8"HSD 2906 PJ Omega Guns,60 Deg SEAL ASST 6,488.7 pH 6,877.0 6,882.0 6,506.9 6,511.8 C-2,10-09 10/20/2008 6.0 APERF 2 7/8"HSD 2906 PJ `� Omega Guns,60 Deg pH 6,887.0 6,892.0 6,516.7 6,521.7 C-1,1D-09 10/20/2008 6.0 APERF 27/8"HSD 2906 PJ ` Omega Guns,60 Deg [ pH Mandrel Inserts St ati on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) _ (RKB) _ Make Model OD(in) Sere Type Type (in) (psi) Run Date Com PRODUCTION;38.6-6,672 5- 1 6,398.4 6,038.5 CAMCO KBG-2- 0.0 GAS LIFT DMY 0.000 0.0 4/24/1998 LS In Notes:General&Safety End Dale Annotation 8/17/2010 NOTE:View Schematic w/Alaska Schematic9.0 APERF;6,780.0-6,784.0 IPERF;6,790.0-6,810.0 ._APERF;6,835.0-6,843.0 APERF;6,848.0-6,852.0 APERF;6,857.0-6,865.0 ^ ` APERF;8,877.0-6,882.0 - r J ._APERF;6,887.0-6,892.0 LINER;8,497.8-7,024.0 - XHVZE Pages NOT Scanned in this Well History File 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 Complete [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts-, Pages: Poor Quality Original'- Pages: , [] Other -Pages: DIGITAL DATA n, Diskettes, No. [] Other, No/Type 'OVERSIZED Logs of vadous kinds Other COMMENTS: Scanned by: Beverly Mildred Dareth~~owell TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: Isl MEMORANDUM To: Jim Regg ~ P.I. Supervisor ~(~ ~ ~(rL7 I ( ~ FROM: Bob Noble Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Thursday, July 22, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1D-09 KUPARUK RIV UNIT 1D-09 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv Comm Well Name: KUPARUK RIV UNIT 1D-09 API Well Number: 50-029-22875-00-00 Inspector Name: Bob Noble Insp Num: mitRCN1007181s295s Permit Number: 198-Obs-O Inspection Date: 7/16/2010 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well i 1D-o9 Type Inj. ~ w TVD ~ 61so ~ IA 609 z3za A I zzso zz6z P.T.DI ]9806s0 ~iTYpeTCSt SPT Test psi z3zs - OA 86 ! 290 276 ~ 26s ~ IriterVal 4YRTST p~F, P ' Tubing 1603 1604 1601 1603 Notes: ~v'~.. re~~d ~~- is37~s; ~ ~ r, s.~;. .. s am z3 ._ Thursday, July 22, 2010 Page 1 of 1 • • RECEtVE® STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION DEC 2 3 2008 REPORT OF SUNDRY WELL OPERATION. _ ~ „ __ „___:~~;~..,, 1. operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate gthey ~ [QKClece/~t.e h Alter Casing ^ Pull Tubing ^ Pertorate New Pool ^ Of~ ^ HftC Waiver ^ Time Extension ~J~ Change Approved Program ^ Operat. Shutdown^ Pertorate ^ Re-enter Suspended Well ^ 3. 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 198-065 3. Address: Stratigraphic ^ Service ^~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22875-00' 7. KB Elevation (ft): 9. Well Name and Number: RKB 112' 1 D-09 ' 8. Property Designation: 10. Field/Pool(s): ADL 25650 PARUK RIVER FIELD / KUPARUK OIL POC 11. Present Well Condition Summary: Total Depth measured 7024' feet ~ '? (~ ~ ; 4 , ' ~i~JLr Nrm •r ` , ~ C t ~ " ` true vertical 6651' feet ~ Plugs (measured) Effective Depth measured 6928 feet Junk (measured) true vertical 6557 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 121' 16" 121' 121' SURFACE 4666' 9-5/8" 4778' 4531' PRODUCTION 6561' 7" 6673' 6306' LINER 526' 4-1/2" 7024' 6651' Perforation depth: Measured depth: 6780-6784, 6790-6810, 6835-6843, 6846-68 52, 6857-6865, 6877-6882, 6887-6892 true vertical depth: 6411-6415,6421-6441, 6465-6473, 6476-6482, 6487-6495, 6506-6511, 6516-6521 Tubing (size, grade, and measured depth) 4.5", L-80, 6499' MD. Packers & SSSV (type & measured depth) BAKER ZXP @ 6513 ~~ t ~ ~ ` ~ CAMCO DB-6 NIPPLE @ 512 ~ wcr ~) ~~. - \ ~ 12. Stimulation or cement squeeze summary: ~~ ~~ ~`~ ~~~~ ~~ Intervals treated (measured) ~Sn t~ ~c~ /~- ~3 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 4711 555 1963 Subsequent to operation 5453 1204 3029 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ^~ Daily Report of Well Operations X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A contact Bob Christensen/D. HUMPHREY Printed Name DARRELL R. HU PHREY Title Production Engineering Technician Signature ~ Phone: 659-7535 Date /z" 20- Form 10-404 Revised 04/2004 ~ Submit Original Only • 1 D-09 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/28/08 Commenced EORX WAG Injection i ~~ KUP ~ 1D-09 COt'IOCOPI1ill~p s well Attributes Alatitia ln :. Wellbore API/UWI Fleltl Name Well Statue Prod/In) Wall Type Incl (°) MD (RKB) TD (max) (ft... . 500292287500 KUPARUK RIVER UNIT INJ 26.99 3,250.36 7,024.0 Comment N23 (pPm) D ate Annolatlon End Dala KB~Grtl (fl) Rlg Raleaaa Data • SSSV: NIPPLE 0 7112008 Last WO: 42217998 Well ~1DJ18 1022 20061t1 9. TAM SUwmelk-A ctual Annolatlon Depth (RKB) E nd Date Annoatlon End Da[a Last Tag: ELM 6,925.0 10202008 Rev Reason: TAG FILL ELMD, ADD PERF 10/21/2008 Casio Strin s Casing Descrlpllan string OD (In) Shing ID (In) Top (RKB) Sat DepM (RKB) sat Depth (TVD) (RKB) String wt (Ibalfl) String Grade String Top Thrd coNDUCroR. CONDUCTOR 1 6 15.06 3 0.0 121.0 121.0 62.58 H-40 WELDED 121 SURFACE 95/ 8 8.70 3 0.0 4,7717.0 4,531.4 40.00 L-80 BTC PRODUCTION 7 6.06 3 0.0 6,673.0 6,306.3 26.00 L-80 Mod BTC NIPPLE. 512 LINER 41/ 2 3.95 3 6,498.0 7,024.0 6,651.3 12.60 L-80 NSCT Tubin Strin s string oo smog ID set Davtn set Depm (rvD) slring we stung Tubing Daacrlptlon (In) (In) Top (RKB) (RKB) (RKB) (Iba/R) Grade String Top Thrd suRFAGE. ~ ne TUBING 411 2 3.95 3 0.0 6.499.0 6,136.1 12.60 L-80 NSCT . Other In Hole All Jewel :Tubin Run 8l Retrievable Fish etc. rov oavtn (TVD) Top GAS LIFT. Top (RKB) (RKB) I ncl I°) Description Comment Run Date ID (In) 8.398 512.0 512.0 1.76 NIPPLE CAMCO DB-6 Nipple NO GO 42411998 3.813 6,398.0 6,038.2 14.89 GAS LIFT CAMCO/KBG-2-LS//DMVII// Comment: STA 1 42417998 3.650 6,489.0 6,126.4 13.86 SEAL BAKER SEAL ASSEMBLY 424/1998 4.500 SEAL, 9.1e9 6,513.0 6,149.7 13.35 PACKER LINER Baker ZXP PACKER 424/1998 3.875 6,516.0 6,152.6 13.29 HANGER LINER Baker HMC HANGER 4/2417998 3.953 6,680.0 6,313.2 10.46 NIPPLE LINER Camco 4 12' DB-6 Nipple NO GO 424/1998 3.750 6,821.0 6,451.7 10.17 PBR LINER Baker PBR 4 3/4" Seal Bore 4/24/1998 4.250 7,024.0 6,651.3 10.85 SHOE LINER GUIDE SHOE 424/1998 4.250 Perforations snot To RKB) elm (RKB Top (TVD) (RKB) Btm (TVD) (RKB) Z D t Dane (sh... T e Comment P C p ( 6 780 0 ) 6 784 0 411 8 5 6 415 5 ona C-4 1D-09 a e 9292008 0 6 yp APERF 2 7/8' HSD 2906 PJ Omega Guns 60 A KER. 8.513 , . , . . , , . , . , Deg pH 6,790.0 6,810.0 8,421.4 8,441.0 C-4, 1D-09 52117998 4.0 (PERF 2 7/8 HC, DP; 60.120 deg ph, no orient 6,835.0 6,843.0 8,465.5 8,473.4 C-3, 1D-09 9292008 6.0 APERF 2 7/8' HSD 2908 PJ Omega Guns, 80 HANGER. es19 Deg PH 6,846.0 8,852.0 8,476.4 8,482.3 C-3, 1D-09 9292008 6.0 APERF 2 718' HSD 2908 PJ Omega Guns, 60 Deg pH PRODUCTION. 6,857.0 8,865.0 6,487.2 8,495.1 C-2, 1 D-09 9292008 6.0 APERF 2 7/8' HSD 2906 PJ Omega Guns, 60 6 fi13 Deg pH 6,877.0 8,882.0 8.506.9 8,511.8 C-2, 1 D-09 10202008 6.0 APERF 2 7/8' HSD 2906 PJ Omege Guns, 60 Deg pH NIPPLE, 8,580 6,867.0 8,892.0 8.516.7 6,521.6 C-1, 1D-09 10202008 6.0 APERF 2 7/8' HSD 2906 PJ Omega Guns, 60 Deg pH APERF, IPERF, 6.790-6.910 PBN. 6.821 APERF, 9,935A.913 APERF, 6,619-0,652 APERF, 8957E.865 APERF. 9,6]1-0,882 APERF. B,BB7-8,892 LINER, ],024 rD, ] oz1 SHOE, ],020 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATI(~~~'S 1. Operations Performed: Abandon ^ Repair Well ^ Plug Pertorations ^ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhllllps Alaska, InC. Development ^ Exploratory ^ 198-065 / 3. Address: Stratigraphic ^ Service ^~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22875-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 41', Pad 71' 1 D-09 • 8. Property Designation: 10. Field/Pool(s): ADL 25650 ~ Kuparuk River Field !Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 7024'' feet true vertical 6651' feet Plugs (measured) Effective Depth measured 6928' feet Junk (measured) true vertical 6557' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' SURFACE 4505' 9-5/8" 4546' 4322' PRODUCTION 6632' 7" 6673' 6305' LINER 526' 4-1/2" 7024' 6651' ~ ~ Perforation depth: Measured depth: 6780'-6784', 6790'-6810', 6835'-6843', 6846'-6852', 6857'-6865', 6877'-6882', 6887'-6892' true vertical depth: 6412'-6416', 6421'-6441', 6482', 64 87'-6495', 6507'-6512', 6517'-6522' 6466'-6473', 6476' - ~~ ~~ p ~~:'~dl~~ ~ L, ~~ ~ ~ ~~~~ Tubing (size, grade, and measured depth) 4-1/2" , L-80, 6499' MD. Packers & SSSV (type & measured depth) Baker ZXP pkr @ 6513' Camco DB-6 nipple @ 512' 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 Casin Pressure Tubin Pressure Prior to well operation 5204 Subsequent to operation SI ~ -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service 0 Daily Report of Well Operations _X 16. Well Status after work: Oil^ Gas ^ WAG ^~ GINJ ^ WINJ ^ WDSPL ^ 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: none Contact John Peirce @ 265-6471 Printed Name John Peirce '' Title Wells Engineer ,/ { '"~~ ~8 Signature ~ { J' Phone: 265-6471 Date 1 i tN Pre a b Sharon Allsu Drake 263-4612 Form 10-404 Revised 04/2006 ~ "~~~.,f~~+'~4~ ~~ ~ ~!}' ~' ~ ~ ~ j ~ ~'~"~ Submit Qr~ginal Only t((l5~ ConocoPhiifips Ai°;^;;. 1' '. KUP ~ Well Attributes { Wellbore APl/UWI Field Name i 5002987500 KUPARUK COmment I • 1 D-09 WeIIC fi-1D-091012 ^.]merneCy- OOB 11: AcpW 19:02 AM ~VV-. ..... •..."""' `..". ..". .._.___ Annotation 'Depth (RKB) .End Date Annotation End Date Last Tag: ELM ~ 6,925.0 10i:=C!2008 Rev Reason: TAG FILL ELMD. ADD PFRF 10@1/2008 - __. -- I Casing-Strings __ Set Dep[h (TVD) String Wt St ing '~ String OD Sl ing ID Set Depth p (ttKB) I (nKB) (ftKB) (Ibs/ft) G ode ~~ St Ing Top Thrtl Casing Descr pt on I (in) (in) To - _ 0 121 58 H 40 j WELDED CONDUCTOR I 16 15 063 0 0 ~ 62 coNDUCroR, . , . . . t2t SURFACE 95/8 8.703 0.0 4,778.0 4,531.4 40.00 L-80 BTC PRODUCTION 7 6.063 0.0 6,673.0 6,306.3 26.00 L-80 Mod BTC NIPPLE. 51z- 1 1-~ LINER 4 1/2 3.953 6,498.0 7,024.0 6,651.31 12.60 L-80 NSCT _ I Tubin Strin s _ _ ___ String OD ', String ID Set Depth Set Depth (TVD) String Wt String I ~ (Ibsttt) Grade St ing Tap Thrd To ftK Descn hon (x 9 P ) p ( ) ) ( ) (x ( SURF4 n I 12.60 L-80 i NSCT 412 6,499.0 6,136.1 TUBING 3.953 0.0 9 1 _ ___--_-_ Othe In Hol (All J T bi & Relrie able Fsh l R v , etc. r e ewe ry;- u ng_ _u_n ,_ Top Depth ~ _.. _... _.__ (ND) I. Top GAS LIFT, Top (ftKB)! (ftKB) 'i Inc! (_) Description Comment Run Date ID (in) 6,398 512.0 512.Oi 1.76 NIPPLE ~CAMCO DB-6 Nipple NO GO 424/1998 3.813, 6,398.0 6,038.21 14.89IGAS LIFT ~CAMCOMBG-2-LS//DMY////Comment: STA 1 424/1998 13.650 6,489.0 ~, 6,126.4', 13.861SEAL BAKER SEAL ASSEMBLY 424/1998 4.500 SEAL. 6,489- _ _ T- 6,513.0 6,149.7 13.35IPACKER LINER Baker ZXP PACKER 424/1998 3.875 _ _ --_- 6,516.0 6,152.6 13.29IHANGER LINER Baker HMC HANGER 424/1998 13.953 -' 6,680.01 6,313.2 10.461 NIPPLE LINER Camco 4 1/2' DB-6 Nipple NO GO 424/1998 .i 3.750 6,821.0 6,451.7 ~' 10.17~PBR LINER Baker PBR 43/4' Seal Bore 4/24/1998 ~ 4.250 7,024.0 6 651.3 10.85 SHOE LINER GUIDE SHOE 424/1998 '. 4.250 ....... -..,,-.-._.__.. _ 1 Perforations snot Top (TVD) Bim (ND) Dens _ Top (itKB) Btm (ftKB)~ (hKB) (ftKB) Zone Date (sn-~ Type Comment PACKER. 6,513 6,780.0 6,784.0 6,411.5 6,415.5 C-4, 1 D-09 9/29/2008 6.0 APERF 2 7/8' HSD 2906 PJ Omega Guns, 60 _,g , Deg pH 6,J90.0 6,810.0 6,421.4 6,441.0 C-4, 1 D-09 5!21/1998 4.0 IPERF 2 7/8 HC, DP; 60-120 deg ph, no orient 6,835.0 6,843.0 6,465.5 6,473.4 C-3, 1 D-09 9/29/2008 6.0 APERF 2 7/8' HSD 2906 PJ Omega Guns, 60 HANGER. ~ pH x,516 _ _ _ 6,846-0 6,852.0 6.476.4 6,482.3 C-3, 1 D-09 929/2008 6.0 APERF 2 7/8' HSD 2906 PJ Omega Guns, 60 Deg pH PRODUCTION, 6,857.0 6,865.0 6,487.2 6,495.1 G2, 1 D-09 929/2008 6.0 APERF 2 7/8' HSD 2906 PJ Omega Guns, 60 6.6]3 Deg pH u 6,877.0 6,882.0 6,506.9 6,511.8 C-2, 1 D-09 10/202008 6.0 APERF 2 7/8' HSD 2906 PJ Omega Guns, 60 Deg pH NIPPLE. 6.680 - - r, - _. - - - - - - 6,887.0 6,892.0 6,516.7 6,521.6 Gi, 1 D-09 10/202008 6.0 APERF 2 7/8' HSD 2906 PJ Omega Guns, 60 IDeg pH --- _... _____ __- __ - I - APERF. 6, ]BO-6,]84 IPERF, 6,]90-6,810 PBR, 6.821 I -~ APERF. 6,835~6.BQ3 APERF, 6,846-6,852 APERF. 6.85]-6.965 APERF, 6,6]]-6,882 APERF, 6.88]-6,892 LINER. ],024 ~ TD. ],024 - SHOE, ],024 1 D-09 Well Work Summary DATE SUMMARY 10/20/08 WELL INJECTING UPON A AL, SI WELL. PERFORATE INTERVALS 6877-6882 AND 6887-6892 FT. TAGGED BOTTOM AT6925 FT. ALL SHOTS FIRED. API DATA 0.34" ENTRANCE HOLE, 36" PENETRETION, 60 DEG PHASING, 6 SPF, 2 7/8" HSD POWERJET OMEGA 2906 STATE OF ALASKA • ~ `~-~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS OCT 2 0 2008 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Pertorations ^ Stimulate ^ Alaska A~h~ Gas ®ns. COI~r~i~~10 Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extet,~i81~~~t~6 Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConoCOPhillips Alaska, InC. Development ^ Exploratory ^ 198-065 / - 3. Address: Stratigraphic ^ .Service Q - 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-22875-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 41', Pad 71' 1 D-09 8. Property Designation: 10. Field/Pool(s): ADL 25650. Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 7024' feet true vertical 6651' feet Plugs (measured} Effective Depth measured 6928' feet Junk (measured) true vertical 6557' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' SURFACE 4505' 9-5/8" 4546' 4322' PRODUCTION 6632' 7" 6673' 6305' LINER 526' 4-1/2" 7024' 6651' ' ~ ~ ~~ Perforation depth: Measured depth: 6780'-6784', 6790'-6810', 6835'-6843', 6848'-6852', 6857 68t?3' ' ' ''~ ``` true vertical depth: 6412'-6416', 6421'-6441', 6466'-6473', 6476'-6482', 6487'-6495' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 6499' MD. Packers & SSSV (type & measured depth) Baker 2XP pkr @ 6513' Camco DB-6 nipple @ 512' 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 Casin Pressure Tubin Pressure Prior to well operation 5193 Subsequent to operation 5545 -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ~ • Daily Report of Well Operations _X 16. Well Status after work: Oil^ Gas^ WAG^ GINJ^ WINJ ~ • WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: none Contact John Peirce @ 26 5-6471 Printed Name John Peirce Title Wells Engineer Signature ~ _„ Phone: 265-6471 r7 Date ~ C> "~ ~'Q$ Pre aced b Sharon Allsu Drak 263-4612 `--~~' g~ ~ ~ ~;~ ~~. 1, ~, ~, _ 2004 ~,~i~ (•a~i ~ i°• y°• `S Form 10-404 Revised 04/2006 /'~^ Submit Original Only 1 D-09 Well Work Summary DATE SUMMARY 9/11/08 DRIFTED TBG WITH 10' x 2-~UMMY PERF GUN TO 6840' WL, EST.~6' RKB. BOTTOM OF PROPOSED PERFS: 6892' RKB. 9/24/08 PERFORATE ADDITIONAL C SAND INTERVALS FROM 6780' - 6784', 6835' - 684.3', 6846' - 6852', 6857' - 6865' USING 2-7/8" HSD 2906 PJ OMEGA GUNS, 6 SPF, 60 DEG PHASING. TD TAGGED AT 6876' ELM. WELL PUT BACK ON INJECTION. ~__ . ~,,, ~ KUP 1 D-09 1 Well Attributes Cc-noco~illi ps ~ ~ - !, waillwra APINWI Field Nama YIaO Sla+us FmWln)Wall Ty 1nalO MD(ICh6) Iu(+»ax)(k... ~ ~ 500292287500 ~KUPARUK RIVER UNIT INJ 26.99 j 3,250.36 7,024.0 -- ___-- _ _ " ~ Comment MYS (ppm) Date Mnotatbn End Date KB-Grd (ft) Rig Release Date ~~ "~~ ..~i ----.. SSSV: NIPPLE 0 7(1(2008 Last WO: j 4Y22N 998 ~..~ ~~ n 4nnotatlon Depth (ftKB) End Data IMnotation (End Date ~LastTag: ELMD 6,876.0 9/24/2008 Rev Reason: TAG FILL ELMD, AD DPERF I 9/29/2008 Casing Strings Casing Descdption Siang OD ~ Strng 10 IIn1 j Iln) `-I UaPth ToP (ftKB) (ftKB) Sal DzPih (TVD) Striny Wl (ftKB) (Iludft) ~ String Grode SMng Top ThM ' ~ CONDUCTOR I 16 15.063 0.0 121.0 121 0~ 62.58 H-00 WELDED coNDUCroR. 121 iSURFACE 95/8 8.703 0.0 4,778.0 4,5314' 40.00 L-80 BTC I PRODUCTION 7 6.063 0.0 6,673.0 6,306.3 26.00 L-80 Mod BTC LINER 41/2 3.953 6,498.01 7,024.0 6,651.3 12.60 L-80 NSCT i NIPPLE, 512 Tubing Strings smoy oo str~ne io ~ sat oaPm sat Daum t I vo) sa+ng wt stn,ta Tubing Descdpdon (in) (b) Top (ftKB) I'~ (ftKB) (ftKB) (IbsNt) Grade ~ String Top Thrd - (TUBING 41/2 3.953 0.0 6,499.0 6,136.1 12.60 L-80 NSCT j SURFACE, % Other In Hole (All Jewelry: Tubing Run & Retriev_8ble, Fish, etc.} 4,778 ~z' ~a GAS LIFT, 8,398 ... SEAL, fi,489 r F -ter 'ACKER, 6,513 PRODUCTION, 6,673 NIPPLE, 6,680 APERF, 6,760-6,781 --- IPERF, fi,790-fi,610 PBR, 6,82' APERF, fi,835-6,843 APERF, 6,846-6,652 APERF, 6,657-6865 LINER, 7024 TD. 7.024 I Top IrvDI i Bnn (TyDI snot Dens j '~ Top (ftKB) Btm (ftKB) (RI(B) 1 (ftKB) Zorre Date Ish-~ Type Comment '~, 6,780.0 6,784.0 6,411.5 6,415.5 C-0, 1D-09 9/2912008 6.0 APERF 7/8" HSD 2906 PJ Omega Guns, 60 ( " DEG pH 6,790.0 6,810.0 6,421.4 6,441.0 C-0, 1D-09 5/21/1998 4.0 IPERF 2 7/8 HC, DP; 60-120 deg ph, no ~ orient 6,835.0' 6,843.0 6,465.5 6,473.4 G3, 1D-09 1 9/29/2008 6.0 APERF 7/8' HSD 2906 PJ Omega Guns, 60 i DEG pH 6,846.Oj 6,852.0 6,476.4 6,482.3 C-3, 1D-09 1 9129/2008 i 6.0 APERF H HD 2906 PJ Omega Guns, 60 I I DEG P 6,857.Oj 6,865.01 6,487.2 6,495.1 C-2, 1D-09 9/29/2008 6.0 APERF 7/8" HSD 2906 PJ Omega Guns, 60 DEG pH SHOE, 7,024 Perforations . . Conoc~illips Alaska RECEIVED .JUL 1 0 Z007 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Alaska Oil & Gas Cons. Commission Anchorage July 6, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK. 99501 5~ JUL 1 '1 2007 \ f\ C(, - O(Pç' Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from theKuparuk field (KRD). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter 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 fonn 10-404, Report of Sundry Operations. Please M.J. Loveland at 907-659-7043, if you have any questions. .$/Ä M.~l~ ConocoPhillips Well Integrity Project Supervisor - . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name prD# cement pumped cement date inhibitor sealant date ft bbls ft gal 1 D-09 198-065 23" na 5 6/9/2007 10-101 200-183 2" na 3.2 6/9/2007 10-102 200-075 2" na 3.2 6/9/2007 10-103 202-096 5" na 8 6/912007 1O-105a 201-202 25" na 38 6/9/2007 10-106 197-240 2" na 3.2 6/9/2007 10-107 200-177 2" na 3.2 6/9/2007 10-108 198-187 8" na 12.8 6/912007 10-113 198-178 2" na 1 6/912007 10-114 198-159 2" na 1 6/9/2007 10-115 197-232 2" na 1 6/9/2007 10-116 198-172 2" na 1 6/912007 10-117 197-237 2" na 1 6/912007 10-118 197-229 2" na 1 6/9/2007 10-119 197-222 2" na 1 6/9/2007 10-122 198-149 2" na 1 6/912007 10-123 198-170 2" na 1 6/9/2007 1O-125a 200-044 2" na 1 6/9/2007 10-126 198-108 2" na 1 6/9/2007 10-127 198-109 8" na 2.5 6/912007 10-128 198-133 2" na 1 619/2007 10-129 197-213 2" na 1 6/9/2007 10-130 197-183 23" na 5 6/9/2007 Kuparuk Field June 9,2007 12/06106 Scblumbepger NO. 4061 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth ('.r- " !I 1;; ',,.~ . f' r~' . ,"'1""" ~,.i~_¡r, . ¡... í' I,' , J....,. .",.\O<;.o....y J'-I..;' \..' () Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 U.I~ .- /01)- aCes Field: Kuparuk . Well Job# Log Description Date BL Color CD 1G-16 11486083 INJECTION PROFILE 11/26/06 1 1C-133 11486084 INJECTION PROFILE 11/27/06 1 1 R-20 11486085 LDL 11/28/06 1 1 D-05 11486086 INJECTION PROFILE 11/29/06 1 1D-03 N/A SBHP 11/25/06 1 1 D-09 N/A SBHP 11/25/06 1 2T-18 11477636 INJECTION PROFILE 12/01/06 1 1 R-03A 11483497 INJECTION PROFILE 11/30/06 1 2X-03 11483499 INJECTION PROFILE 12/02/06 1 1 E-04 11477639 INJECTION PROFILE 12/04/06 1 . I . Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8311. Thank you. MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: ~~~ s~:~r~isor ~t17({:,>l(i.tJ DATE: Wednesday, July 12,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHll..LIPS ALASKA INC 10-09 KUPARUK RIV UNIT 1D-09 tq~~D~ FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv.JP:::>i2-- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT lD-09 API Well Number 50-029-22875-00-00 Inspector Name: Jeff Jones Insp Num: mitlJ060711182211 Permit Number: 198-065-0 Inspection Date: 7/10/2006 ReI Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ¡ 10-09 IType Inj. ! W ! TVD 6150 I IA i 200 I 2520 i 2500 ! 2490 i ! P. T. ¡ 1980650 ITypeTest ] SPT ! Test psi 1537.5 lOA ! 640 940 I 940 I 930 i ! ; 1_, I I ¡ V T b' I TU40 i Interval 4YRTST P/F P U mg, 1740 1745 i 1745 I -----'- I Notes 1.5 bbls diesel pumped. I well house inspected; no exceptions noted. \jCt\ti\'Jf:,J ,....J ",. ., Wednesday, July 12,2006 Page lofl .'_. e lJ·tli:!i!ii~tìti':::. .. . , Gf" "::'\i::g:i::::j!:! ConocoPhdUps Alaska, Inc. . .......'" . NIP (512-513, 00:4.500) TUBING (0-6499, 00:4.500, 10:3953) Gas lift 1drel/Oummy Valve 1 (6398-6399, 00:5.800) SEAL (6489-6490. 00:5.000) ROOUCTION (0-6673, 00:7.000. Wt:26.00) PKR (6513-6514, 00:4.500) LINER (6498-7024, 00:4.500, Wt:12.60) HGR (6516-6517, 00:4.500) NIP (6680-6681, 00:4.500) WI din _ m:f- AJI.. ..' Wl. t !--I U - - Pelf (6790-6810) - - .-- i- - '-- - - - - - - - - PBR =] (6821-6822, 00:5.813) ..J ~ 1D~9 API: 500292287500 SSSV Tvpe: Nipple Annular Fluid: Reference Log: Last Tag: 6926 Last Tag Date: 7/26/2004 CasinaStrina - ALL STRINGS Description CONDUCTOR SURFACE PRODUCTION LINER Tubind :Strind: -TUBING Size I Top I 4.500 I 0 I Perforations: SUmmar,,: Interval 1 TVD I 6790 - 6810 6421 - 6441 I Size 16.000 9.625 7.000 4.500 Zone C-4 Gas Lift . MandrelsNalves St I MD I TVD I ~~; Man Type I 1 1 63981 60381 Cameo I KBG-2-LS I Other( luaseJuip..ekt-JEWELRY Depth TVD Type 512 512 NIP 6489 6126 SEAL 6513 6150 PKR 6516 6153 HGR 6680 6313 NIP 6821 6452 PBR 7024 7024 SHOE .. Bottom 6499 e Well Type: INJ Oria Completion: 4/22/1998 Last W/O: Ref Log Date: TO: 7024 ftKB Max Hole Angle: 27 deg @ 3250 ... ... Top Bottom o 121 o 4778 o 6673 6498 7024 I I KRU 1D-09 Anale @ TS: 11 dea @ 6772 Angle @ TD: 11 deg @ 7024 Rev Reason: DRIFT & TAG Last Update: 8/1/2004 .. .... .. ... TVD Wt Grade Thread 121 62.58 H-40 WELDED 4531 40.00 L-80 BTC 6306 26.00 L-80 Mod BTC 7024 12.60 L-80 NSCT . .... .... Thread NSCT .... ... Comment 27/8 HC, DP; 60-120 deg ph, no orient TVD 6136 I Wt I Grade I 1 12.60 I L-80 I ... .. ". ... I Status 1 Ft I /20 SPF Date Type 4 5/21/1998 IPERF I .. ... . .... V OD ¡Latch I Port ITRO I Date I Vlv Run Cmnt 0.0 I I 0.000 I 0 14/24/19981 ... ... Description .. .. .... V Mfr V Type DMY CAMCO DB-6 Nipple NO GO BAKER SEAL ASSEMBLY Baker ZXP Baker HMC Cameo 4 1/2" DB-6 Nipple NO GO Baker PBR 4 3/4" Seal Bore ID 3.813 4.500 3.875 3.953 3.750 4.750 4.750 MEMORANDUM TO: Randy Ruedrich Chair THRU: Jim Regg FROM' State of Alaska Alaska Oil and Gas Conservation Commission DATE: June 20, 2003 SUBJECT: Mechanical Integrity Tests ConocoPhillips Alaska Inc. P.I. Supervisor , ' ) 06, 09, 106, 109, 111 John H. Spaulding / Kuparuk River Unit Petroleum Inspector Kuparuk River Field NON- CONFIDENTIAL Welll 1D-06 I P.T.D. I 1790960 Notes: WellI P.T.D.I Notes: WellI P.T.D.I Notes: WellI P.T.D.I Notes: Well I 1D-111 I P.T.D. I 1981660 Notes: Packer Depth Pretest Initial 15 Min. 30 Min. I Typelnj. I S I T.V.[). I 6265 I Tubing I 1795 I 1790 I 1790 I 1790 I Interval[ 4 TypetestI P ITest[,sil 1566 I Casingl 1360I 25OOI 2500I 2490I P/F I P 1980650 ITypetestl P ITestpsil 1538 ICasingI 390 I 25351 25201 251O1 P/F I P 1972400 ITypetestl P ITestpsil 908 I Casingl 460 I 26201 26201 26101 P/F I P 1972350ITypetestl P I Testpsil 888 I Casingl POS. I 255°1 255°1 255°1 P/F I P IType Inj. Type test Type INJ. Fluid Codes F = FRESH WATER INJ. G -- GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) .l~had a positive pressure (basically 0 psi) when checked prior to rig up of the pump. The IA was pressured up to 2500 psi as noted and immediately started to bleed down. After 15 min. pressure was at 400 psi. Ultimately the IA went clear to 0 psi on the guage. As I was checking the IA the last time I noticed that diesel was coming up through the the hanger flutes. Approxiamtely 5 gals. over flowed into the cellar area. This was cleaned up. I contacted Tom Maunder and he suggested that the well be shut-in until CPAI offered a repair program to the AOGCC. Jerry Dethlefs Dethlefs CPAI rep. concurred with the shut-in advice. M.I.T.'s performed: _5 Number of Failures: 1_ Attachments: Total Time during tests: 3 hours cc: MIT report form 5/12/00 L.G. SCAN EEi: 0 2003 mit kru ld 6-20-03 jsl.xls 7/17/2003 ARCO Alaska, Inc. ' Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 9fl-,6 ~ - qg- 80 October 15, 1999 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, Third Quarter, 1999 Dear Ms. Mahan' Please find reported below volumes injected into surface casing by production casing annuli during the third quarter of 1999. as well as total volumes injected into annuli for which injection authorization expired during the third quarter of 1999. Annular Injection during the third quarter of 1999: Well Name 1C-25 CD1-40 CDI-O1 1C-23 CD1-23 CD1-37 h(1) h(2) h(3) Volume 520 20079 4905 24865 16079 17173 Volume 100 100 100 100 100 100 Volume Total for Quarter 620 20179 5005 24965 16179 17273 Previous Total 34316 12171 9605 New Total 34936 32350 5005 34570 16719 17273 CD1-39 3917 100 0 4017 0 4017 1D-12 4305 ~ 100 0 4405 0 4405 Total Vohm~esintoAnnuli.for;vl~icl~h~ectionAuthorization Expired during the quarter q%- ~ z.z. "' qB- I'i5 - Well Name Total h(1) Volume Total h(2) Volume Total h(3) Volume Total Volume Injected 32640 Status of Annulus Open, Freeze Protected 1D-09 32540 100 0 ~ 2N-337A 30539 100 0 i 30639 Open, Freeze Protected 2N-313 32758 i 100 0 ~ 32858 , Open, Freeze Protected 2N-321A 27507 i00 0 ! 27607 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader i-r'{ ,_.,, ;.,... 4nch0ra~e CC: Mike Zanghi Paul Mazzolini Randy Thomas Kuparuk Environmental: Engel / Snodgrass Morrison and Winfree Sharon Allsup-Drake Well Files Ms. Wendy Mahan AOGCC Third Quarter 1999 Annular Injection Report Page Two ARCO Alaska, Inc. To: Blair Wondzell From: Tom Brockway Fax: 276-7542 Pages: 3 (including this page) Phone:, 793-1226 Date: 07/07/98 Re: 1D-09 Surface Shoe LOT CC: [] Urgent [] For Review [] Please Comment [] Please Reply [] Please Recycle, Dear Mr. Wondzell, Sorry for the confusion over the LOT data for 1D-09. I reviewed my working files from this well and found that there was a typo on the LOT data sheet sent in from the dg. The correct depth of the surface shoe test is 4581' MD. I have attached a copy of the corrected LOT data sheet as well as a copy of the morning drilling report from the rig which also documents the testing depth and LOT results at the surface shoe. If you have any other questions concerning this data, please don't hesitate to contact me at 263-4135 of Tom McKay at 265-6890. Thanks, Tom 1. Type of Request: Abandon - .. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Suspend Operation Shutdown Re-enter suspended Alter casing _ Repair well _ Change approved program __ Plugging __ Pull tubing _ Time extension_ Stimulate_ Variance__ Perforate__ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 136' FNL, 598' FEL, Sec. 23, T11N, R10E, UM At top of productive interval 1544' FSL, 1043' FEL, Sec. 14, T11N, R10E, UM At effective depth At total depth 1589' FSL, 1056' FEL, Sec. 14, T11 N, R10E, UM 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service X Other X Annular Iniection 6. Datum elevation (DF or KB) 41' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 1D-09 9. Permitnumber 98-065 10. APInumber 50-029-22875 feet 12. Present well condition summary Total Depth: measured (approx) true vertical Effective depth: measured (approx) true vertical Casing Length Structural Conductor 80' Surface 4505' Intermediate Production 6631' Liner 526' 7O24 6651 6928 6557 Size 16" 9.625" 7" 4.5" feet feet feet feet Plugs (measured) None Junk (measured) 11. Field/Pool Kuparuk River Cemented Measured depth True vertical depth Perforation depth: measured 6790'-6810' true vertical 6421 '-6441' Tubing (size, grade, and measured depth) 4.5", 12.6#, L-80 @ 6502' Packers and SSSV (type and measured depth) Baker 'ZXP' Liner Pkr @ 6513' MD 9 cubic yards 121' 121' 1016 sxAS III & 4546' 4322' 515 sx Class G & 60 sx AS I 170 sx Class G 6672' 6305' 89 sx Class G 7024' 6651' ORIfiCIAL 13. Attachments Description summary of proposal __ Detailed operation program ~ BOP sketch Contact Chip Alvord at 265-6120 with any questions. LOT test, surface cement details and casing detail sheets X 14. Estimated date for commencing operation July 1998 Date approved 15. Status of well classification as: Oil ~ Gas __ Suspended __ Service X 16. If proposal was verbally approved Name of approver FOR COMMISSION USE ONLY 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. '7~,'~. plc[(~ Signed //~.¢',.,~-- ~ (~ Title Kuparuk Team Leader Date Conditions of approval: Notify Commission so representative may witness ,Approval No~,'~"~ .../72 Plug integrity BOP Test Lo~e.~--..~ . _ I. Mechanical ln~'egrityT~_e.c_t_ S~irel~i~'~.-./4.-~-~ /,a-,~' ~'.~¢~,,~.c/f ~,, _. 0 I:! I I_1_ I I~ G S E FI~./I I~ E~ S 02-Jun-98 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1D-09 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD n/a' MD 7,024.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Division of Dresser Industries, Inc, Kuparuk Unit Kuparuk 1D 1D-09 SURVEY REPORT May, ~998 Your Reft API-500292287500 Last survey 21-April-98 Job# AKMMS0191 KBE - 111.60' sp~~-sun DRILLING C;ERVICE5 ORiGiNAL Survey Reft svy6 Sperry-Sun Drilling Services Survey Report for ID-09 Your Ref: API-500292287500 Kuparuk Unit Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Depth (ft) 0.00 0.000 0.000 -111.60 0.00 121.00 0.000 0.000 9.40 121.00 170.00 0.750 271.000 58.40 170.00 356.00 0.250 306.000 244.39 355.99 446.00 0.750 13.000 334.39 445.99 555.86 2.840 53.950 444.19 555.79 643.78 5.010 70.930 531.90 643.50 737.47 7.140 50.280 625.07 736.67 828.48 8.340 74.230 .715.27 826.87 1008.61 11.290 72.650 892.75 1004.35 1192.56 11.330 74.680 1073.13 1184.73 1472.80 10.630 75.600 1348.24 1459.84 1658.31 9.310 70.330 1530.94 1642.54 1752.09 9.200 70.290 1623.50 1735.10 1845.46 9.300 62.580 1715.66 1827.26 1941.92 9.930 42.720 1810.79 1922.39 2035.92 11.440 27.480 1903.18 2014.78 2129.25 13.380 16.380 1994.34 2105.94 2221.64 14.870 6.400 2083.94 2195.54 2314.24 16.330 358.950 2173.14 2284.74 2406.69 17.400 355.650 2261.61 2373.21 2500.27 18.130 349.540 2350.74 2462.34 2593.77 19.420 338.380 2439.29 2550.89 2686.77 20.950 333.030 2526.58 2638.18 2779.69 22.290 334.430 2612.97 2724.57 2967.62 24.560 336.120 2785.40 2897.00 3250.35 26.990 335.050 3039.98 3151.58 3524.39 26.200 335.320 3285.02 3396.62 3803.12 25.380 334.580 3535.99 3647.59 4083.85 24.390 333.790 3790.65 3902.25 Local Coordinates Global Coordinates Dogleg Vertical. Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (o/100ft) (ft) 0.00 N 0.00 E 5959528.99 N 560490.59 E 0.00 0.00 N 0.00 E 5959528.99 N 560490.59 E 0.000 0.00 0.01N 0.32W 5959528.99 N 560490.27 E 1.531 0.12 0.27 N 1.87W 5959529.24 N 560488.72 E 0.303 0.94 0.95 N 1.89W 5959529.93 N 560488.69 E 0.769 1.59 3.26 N 0.47 E 5959532.25 N 560491.03 E 2.117 2.85 5.79 N 5.86 E 5959534.83 N 560496.40 E 2.774 3.18 10.85 N 14.21E 5959539.96 N 560504.71E 3.223 4.76 16.26 N 24.91 E 5959545.45 N 560515.37 E 3.748 5.78 25.07 N 54.32 E 5959554.50 N 560544.71 E 1.644 2.96 35.22 N 88.94 E 5959564.92 N 560579.24 E 0.218 -0.56 48.92 N 140.52 E 5959579.04 N 560630.71 E 0.257 -7.13 58.22 N 171.23 E 5959588.59 N 560661.34 E 0.864 -9.97 63.31N 185.43 E 5959593.79 N 560675.50 E 0.117 -10.56 69.30 N 199.15 E 5959599.89 N 560689.18 E 1.331 -10.13 79.00 N 211.72 E 5959609.69 N 560701.66 E 3.482 -5.83 93.23 N 221.52 E 5959624.00 N 560711.35 E 3.394 3.71 111.80 N 228.84 E 5959642.63 N 560718.52 E 3.286 18.21 133.85 N 233.17 E 5959664.71 N 560722.68 E 3.085 37.03 158.67 N 234.26 E 5959689.54 N 560723.56 E 2.674 59.65 185.45 N 232.97 E 5959716.31N 560722.06 E 1.553 84.98 213.73 N 229.27 E 5959744.55 N 560718.13 E 2.138 112.58 242.49 N 220.90 E 5959773.25 N 560709.53 E 4.075 142.40 271.69 N 207.66 E 5959802.34 N 560696.05 E 2.577 174.42 302.39 N 192.52 E 5959832.92 N 560680.67 E 1.545 208.56 370.26 N 161.32 E 5959900.54 N 560648.92 E 1.260 283.17 482.18 N 110.46 E 5960012.04 N 560597.17 E 0.875 405.98 593.53 N 58.97 E 5960122.98 N 560544.78 E 0.292 528.51 703.39 N 7.64 E 5960232.42 N 560492.56 E 0.316 649.60 809.74 N 43.79W 5960338.35 N 560440.28 E 0.372 767.46 Comment Kuparuk 1 D Continued... May, 1998 - 9:46 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for 1D-09 Your Ref: API-500292287500 Kuparuk Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (~) (ft) (ft) Local Coordinates Global Coordinates Dogleg Vertical- Northings Eastings Northings Eastings Rate Section (ft) (ft) (ft) (ft) (°/100ft) (ft) 4269.40 24.420 335.840 3959.63 4071.23 4477.28 25.760 334.920 4147.89 4259.49 4826.56 24.720 333.190 4463.82 4575.42 5108.60 24.460 336.680 4720.30 4831.90 5390.00 23,170 337.010 4977.73 5089.33 5668.16 21.990 337.720 5234.56 5346.16 5855.92 19.920 335.120 5409.90 5521.50 6042.18 18.340 333.270 5585.87 5697.47 6229.96 16.690 332.650 5764.94 5876.54 6322.15 15.820 332.380 5853.44 5965.04 6415.84 14.660 334.340 5943.84 6055.44 6507.28 13.470 334.040 6032.53 6144.13 6633.46 10.800 338.990 6155.89 6267.49 6717.40 10.480 342.210 6238.38 6349.98 6812.93 10.530 346.140 6332.31 6443.91 6905.92 10.560 344.790 6423.73 6535.33 6969.33 10.850 345.070 6486.04 6597.64 7024.00 10.850 345.070 6539.73 6651.33 879.11N 76.41W 5960407.45 N 560407.11E 0.457 843.99 959.23 N 113.15W 5960487.28 N '560369.72 E 0.671 932.04 1093.16 N 178.26W 5960620.68 N 560303.53 E 0.365 1080.60 1199.42 N 227.98VV 5960726.54 N 560252.96 E 0.523 1197.73 1303.89 N 272.66W 5960830.64 N 560207.44 E 0.461 1311,33 1402.46 N 313.78W 5960928.88 N 560165.53 E 0.435 1418.13 1464.01 N 340.57W 5960990.21 N 560138.24 E 1.208 1485.23 1518.97 N 367.10VV 5961044.96 N 560111.27 E 0.908 1546.12 1569.31 N 392.78W 5961095.09 N 560085.19 E 0.884 1602.41 1592.20 N 404.69W 5961117.89 N 560073.10 E 0.947 1628.10 1614.21 N 415.74W 5961139.80 N 560061.86 E 1.355 1652.64 1634.21 N 425.42VV 5961159.73 N 560052.03 E 1.304 1674.81 1658.47 N 436.09W 5961183.89 N 560041.16 E 2.269 1701,29 1673.08 N 441.24W 5961198.46 N 560035.89 E 0.804 1716.77 1689.83 N 445.99W 5961215.17 N 560031.01E 0,752 1734.08 1706.30 N 450.26W 5961231,61 N 560026.61 E 0,268 1750.95 1717.67 N 453.32VV 5961242.96 N 560023.46 E 0.465 1762.65 1727.61N 455.97W 5961252.88 N 560020.72 E 0.000 1772.86 All data is in feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well and calculated along an Azimuth of 338.060° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 7024.00ft., The Bottom Hole Displacement is 1786.77ft., in the Direction of 345.215° (True). Comment Projected Survey Kuparuk 1 D May, 1998 - 9:46 - 3 - DrillQuest ARCO Alaska, Inc. ' Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 2,1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1D-09 (Permit No. 98-65) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 1D-09. If there are any questions, please call 265-6120. Sincerely, G. C. Alvord Team Leader Kuparuk Drill Site Development GCA/skad STATE OF ALASKA '- --" ~.. ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL [~ GAS E~ SUSPENDED [~ ABANDONED ~SERVICE [~ Injector 2 Name of Operator i7 Permit Number ARCO Alaska, Inc 98-65 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-22875 4 Location of well at surface 9 Unit or Lease Name i~ . :~ ,'7' ~ · ~: ........ i t~,_,,.,, ~ .. ~ ~,-.~ .~ ~ Kuparuk River Unit 136' FNL, 598' FEL, Sec. 23, T11 N, R10E, UM 'i At Top Producing Interval t ~i.'-i'}:' .~'~i 10 Well Number 1544' FSL, 1043' FEL, Sec. 14, TllN, R10E, UM '~ ~'" 1D-09 At Total Depth ! ~~ii-' L. '~ ~;'~ iii~ i ' 11 Field and Pool 1589' FSL, 1056' FEL, Sec. 14, T11 N, R10E, UM ........ -~-~'--~_,,~--._-~_' - KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and SenEFRo. Kuparuk River Oil Pool RKB 41', Pad 71' ADL 25650 ALK 468 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Depth, if offshore 16 No. of Completions 13-Apr-98 21-Apr-98 22-Apr-98I NA feet MSL 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 7024' MD & 6651' TVD 6928' MD & 6557' TVD YES M NO U N/A feet MD 1700' APPROX 22 Type Electdc or Other Logs Run Dipole Sonic/GR, CBT 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE VV'I' GRADE TOP BTM HOLE SIZE CEMENT ~ECO~D 16' 62.5# H-40 SURF. 121' 24' 9 cubic yards High Eady 9.625' 40# L-80 SURF. 4546' 12.25' 1016 sx ASIII, 515 sx Class G, 60 sx AS I 7' 26.0# L-80 SURF. 6672' 8.5' 170 sx Class G 4.5' 12.6# L-80 6498' 7024' 6.125' 89 sx Class G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5' 6502' 6513' 6790'-6810' MD 6421'-6441' TVD 4 spf 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 27 PRODUCTION TEST i Gii,,,iAL,, Date First Production Method of Operation (Flowing, gas lift, etc.) _~.' Injector ,~'~K3, Date of Test Hours Tested PRODUCTION FOI OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE'1 GAS-OIL RATIO I TEST PERIOI: Flow Tl~bing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBI.J OIL GRAVITY-APl (corr) Press. 24-HOUR RATE: 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A Form 10-407 Submit in duplicate Rev, 7-1-80 CONTINUED ON REVERSE SIDE . .. 29. 30. ~- ': GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top of Kuparuk C 6772' 6403' Base of Kuparuk C 6904' 6533' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Drillin~ Reports, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. s, ed O-ZL ' '-- · "' 7 Prepared by Nar0___/~/Number Sharon AIIsup-Drake/263-4612 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water in- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT Kl(1D-09(W4-6)) WELL JOB SCOPE JOB NUMBER 1D-09 RESV DATA GATHERING 0505980714.3 DATE DAILY WORK UNIT NUMBER 05/21/98 PRFORATE "C3" SAND DAY OPERATION COMPLETE I SUCCESSFUL 1 YES I YES Initial Tbg Press [-Final Tbg Press I Initial InnerAnn 0 PSI! 1000 PSII 50 PSI DAILY SUMMARY PRFORATE "C3" SAND F/6790' TO 6810' KEY PERSON SWS-JOHNSON SUPERVISOR SCHWENDERMAN Final Inner Ann J Initial Outer Ann J Final Outer Ann 50 PSIJ 250 PSIJ 250 PSI TIME LOG ENTRY 13:00 MIRU TGSM WORKING IN WINDY CONDITIONS. COMMENCE RADIO SILENCE. MU PERF GUN ASSEM 2-7/8" HC, DP, 4 SPF, 180 DEG PHASING. (20' GUN/CCL) TL 24'. PT 3500 PSI 14:30 RIH CORRALATE W/SPERRY SUN LWD LOG DATED 4/21/98 AND CBT LOG. TAGGED DOWN AT 6915' RKB. PERFORATE FROM 6790' TO 6810' RKB. HAD GOOD SURFACE INDICATIONS. TUBING PRESS AT 1000 PSI. POH 15:30 AT SURFACE RD LAID DOWN LUBRICATOR ALL SHOTS FIRED. 17:00 RELEASED WELL BACK TO PRODUCTION. WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 1D-09, AK-MM-80191 May 20, 1998 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Ali Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1D-09: 2" x 5" MD Resistivi~ & Gamma Ray Logs: 50-029-22875-00 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-22875-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Division of Dresser Industries, Inc. Date: 5/14/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:iD-09 WELL_ID: AK9125 TYPE: AFC: AK9125 STATE:ALASKA 22875-00 AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT SPUD:04/13/98 START COMP: RIG:PARKER 245 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029- 04/13/98 (D1) TD: 1272' (1272) SUPV:DEB 04/14/98 (D2) TD: 4216'(2944) SUPV:GRW 04/15/98 (D3) TD: 4561'(345) SUPV:GRW 04/16/98 (D4) TD: 4561'( SUPV:GRW 0) 04/17/98 (D5) TD: 5300'(739) SUPV:GRW 04/18/98 (D6) TD: 6689' (1389) SUPV:GRW 04/19/98 (D7) TD: 6689'( SUPV:GRW o) MW: 9.5 VISC: 375 PV/YP: 46/76 DRILLING AT 2150' MD APIWL: 6.2 Move 424' from iD-10 to 1D-09. Accept rig @ 0700 hrs. 4/13/98. NU and function test diverter. Spud in at 121' and drill to 1272' MD. MW: 9.8 VISC: 270 PV/YP: 37/ 0 CIRC FOR SHORT TRIP. APIWL: 6.0 Drill from 1271' to 4216' mud gas cut to 8.9 ppg. Had oil at shakes @ 4000' and MW: 10.0 VISC: 330 PV/YP: 46/72 CEMENTING APIWL: 5.8 Drill from 4216' to 4561'. POOH. tight 3180' to 3133', 2899' to 2853', 2760'-2666' Run 9-5/8" casing. MW: 8.9 VISC: 40 PV/YP: 7/11 CLEANING OUT CEMENT APIWL: 16.2 Finish running 9-5/8" casing to 4545'. Pump 1st and 2nd stage cement. NU BOPE and test to 300/3000 psi. Drill closing plug and stage tool. MW: 8.5 VISC: 47 PV/YP: 11/19 DRILLING @ 6000' APIWL: 13.2 DRILL F/ 5581' TO, 5300' REPAIR RIG FILL UP LINE. MW: 9.2 VISC: 50 PV/YP: 16/18 RUNNING CASING. APIWL: 5.8 DRILL F/5300 T/6689' 6375 FIT = 12.9 EMW. TVD=6322', ADT 8.01. PULL OUT TO MW: 9.6 VISC: 49 PV/YP: 17/17 P/U DRILL PIPE. APIWL: 5.4 PULL WEAR BUSHING. SAFETY MTG W/TOOL PUSHER & CO MAN ON CSG PROCEDURE. TEST BOPE & CHOKE 300 TO 5000. Date: 5/14/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 04/20/98 (D8) TD: 6761'( 72) SUPV:GRW MW: 12.0 VISC: 62 PV/YP: 31/28 CONTINUE DRILLING 6.125" HOLE APIWL: 4.2 Test casing to 3500 psi. Clean out cement and float equipment from 6565 to 6615' Drill cement, shoe, and 20' of new hole to 6709' Perform FIT, 16.2 EMW. Drill 20' new hole from 6709'-6729' Perform LOT EMW = 15.6. Drill from 6729'-6761' 04/21/98 (D9) TD: 7024' (263) SUPV:GRW/PR MW: 12.0 VISC: 60 PV/YP: 29/32 RUNNING 4.5" LINER APIWL: 4.0 Drill from 6761' to 7024'. Flow check - CBU. Prepare to run 4.5" liner. 04/22/98 (D10) TD: 7024' ( 0) SUPV:GRW/PR MW: 12.0 VISC: 64 PV/YP: 34/30 CHANGING PIPE RAMS APIWL: 4.2 Run 4.5" liner on 3.5" DP. Cement 4.5" liner. Run 4.5" tubing. Test casing to 3500 psi. 04/23/98 (Dll) TD: 7024' ( 0) SUPV:GRW MW: 0.0 VISC: RIG RELEASED TO 3K-34 0 PV/YP: 0/ 0 APIWL: 0.0 Test tubing to 3500 psi and annulus to 3500 psi. N/D BOPE. N/U tree and test packoff to 5000 psi. Freeze protect 9-5/8" x 7" annulus. Rig released @ 1800 hrs. 4/24/98. End of WellSummary for Well:AK9125 Prepared by: S. ALLSUP-DRAKE WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs May 13, 1998 1 {J-09, AK-MM-80191 1 LDWG formatted Disc with verification listing. API#: 50-029-22875-00 PLEASE ACKNOWLEDGE RECElPT BY SIGNING AND RETURNING THE ATTACHED COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 Date: 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 ° Fax (907) 563-7252 A Division of Dresser Industries, Inc. Well Compliance Report File on Left side of folder MD 07024 ./ TVD 06651 {.~:~mpletion Date: 4/22/98 Completed Status: 1WINJ Current: T Name Interval D 8427 ~ SPERRY MPT/GR/EWR4 Sent Received T/C/D OH 5/13/98 5/13/98 L CBL ~L 6350-6908 ~/l~/~ CH 5 7/9/98 7/13/98 L DGR/EWR4-MD q*l~L 4561-7024 OH 5/20/98 5/21/98 L DGR/EWR4-TVD c~AL 4334-6651 OH 5/20/98 5/21/98 R SRVY R?T ~P~ERRY 0-7024. OH 6/2/98 6/19/98 Daily Well Ops ~.Jl~ .... ~/~///~t~ Are Dry Ditch Samples Required? yes ~ An~d Receive&-?~t~--~'0'-- Was the ~vell cored? yes ~ Analysis Description Rece' . no ample Set-'~'~~''''~'''-~ Comments: Monday, May 01,2000 Page 1 of 1 ARCO Alaska, Inc. KRU 1D-09 CONDUCTOR (0-121, 0D:16.000, Wt:62.58) NO GO (512-513, 0D:4.500) TUBING (0-6499, 0D:4.500, ID:3.953) SURFACE (0-4778, OD:9.625, Wt:40.00) PRODUCTION (0-6673, OD:7.000, Wt:26.00) Gas Lift andrel/Dummy Valve 1 (6398-6399, 0D:4.500) LSA (6489-6490, OD:5.000) 1D--09 AP1:1500292287500 ! WellType: INJ Angle@TS: 11deg@6772 SSSV Type: Orig Compltn: 4/22/98 Angle @ TD: 11 deg @ 7024 Annular Fluid: Last W/O: Rev Reason: New Schem Reference Lo(l: Ref Log Date: Last Update: 5/24/98 Last Tag: 6920 TD: 7024 ftKB Last Tag Date: 5/14/98 I Max Hole Angle: 27 deg @ 3250 CasingString-conductor:PiPe: :i: : : ::: ::: :: :: ::: : Size I Top I Bottom I TVD Wt Grade Thread 16.000 0 I 121 121 62.58 H-40 WELDED Casing String - Surface CaSing :: :: : : ::::. i : : : : ::: . Size Top I Bottom TVD Wt GradeI Thread 9.625 0 t 4778 4531 40.00 L-80 BTC Casing String -production casing : ;:: ~ : :;: :: ;: :~;:: : : ~ :: :i:: :: :~:ii :: Size Top I Bottom I 'rVD Wt Grade Thread 7.000 0 I {6673 6306 26.00 L-80 Mod BTC Casing String , Liner : :i : :i: :::: : ~:::~ :i: : :::: :: ::: Size I Top Bottom TVD Wt I Grade Thread 4.500 I 6498 7024 7024 12.60 L-80 NSCT Tubing String , TUBING : :: :: ::i::i:: ::: :::: :::: :::::: ; :::: :::::~ Size I Top Bottom TVD Wt Grade Thread 4.500 I 0 6499 6136 12.60 L-80 NSCT Perforations Summary : :::::: :~ : :: : : : :::~ ; : : i:::' :::: ::: Interval TVD Zone IStatuslFeetSPFiDate TypeI Comment 6790 - 6810 6421 - 6441 I C-4 I I 2°1 415/21/9812 7/8 160-120 deg phasing, no orientation Hollow CD~rder, GasLiffMandrelsNaives :: : :~ : : :: :: : :: : ::: :::i:: :: : Stn MD TVD Man I Man V Mfr VType VOD Latch Port TRO Date Vlv I I Mfr Type t I Run IComment 1 6398 6038 Camco 4 1/2"X 1" I DV 0.0 0.000 0 4/24/98 KBG-2-LS Other (plugs, equip.,etc;)-JEWELRY ::: i::: . :: : :::: Depth I TVDt Type 5121 512t NO GO 64891 61261 LSA 6513 61501 PER 6516J 61531 HGR 66801 63131 NO GO 6821 6452 t PBR 7024 7024 SHOE CAMCO DB~6 Nipple BAKER LSA Baker ZXP Baker HMC Camco 4 1/2" DB-6 Nipple Baker PBR 4 3/4 Seal Bore Description ID 3.813 4.500 3.875 3.953 3.750 4.750 4.750 CASING AND LEAK-OFF FRACTURE TESTS Well Name: KRU 1D-09 Date: 4/20/98 Supervisor: G.R. Whitlock/Pat Reilly Casing Size and Descril: 9-5/8", 40#, L-80, BTC Casing Setting Depth: ,/~2~ TMD ,; 6305 TVD Mud Weight: 9.5 ppg EMW- Leak-off Pressure (Pl.+ MW 0.052 x TVD LOT -- 2000 psi / (0.052 x 6305 ft) + 9~5~5~p~-.= 15 Hole Depth (md)= 6729 Fluid Pumped = 2.63 bbls. ,'/ /'~ '~'/ Pump output = .101 bps 3700 3000 2000 i 1900 17oo I N. ,.. I 1600 , 14oo' I Ii 13oo .,/,~ 12oo I 11°° _ _ I ooo ii 6O0 -r~ I 4oo --e-- LEAK-OFF TEST - 3oo ~/]/ I I ---I~--CASING TEST 0 2 4 6 8 10121416182022242628303234363840424446485052545658606264666870 STROKES CASING AND LEAK-OFF FRACTURE TESTS Well Name: KRU 1D-09 Date: 4118198 Supervisor: G.R. Whitlock/Pat Reili~, Casing Size and Descrip 9.5/8", 40#, L-80, BTC Casing Setting Depth: Mud Weight: 9.2 TMD 4321' 2 'I'VD ppg EMW --' Leak-off Pressure (PL + MW 0.052 x TVD LOT = 835~si I (0.052 x 4321 ft) + 9.2 ppg = 12.9 Fluid Pumped = 2..02 bbls. Pump output =. 101 bps 33O0 3200 3100 3000 2BO0 2800 2700 2600 2500 2400 23O0 22O0 2100 2O00 1900 1800 1700 1600 1500 1400 1300 1200 1100 1000 9O0 8O0 700 600 5OO 4OO 3O0 100 l' / / · _ Ii ~/ ~t~r ~ ~t'~' ~ +L~K-OFF TEST ' ~r ~CASING TEST ~' ' . .... illillllllll 0 2 4 6 8 1012141818202224262830323436384042444648~052545658606264666870 STROKES :907 Z65 1300 ¢ 3' 3 CASING AND LEAK-OFF FRACTURE TESTS Well Name: KRU 1D-09 Date: 4/17/98 Supervisor:. G.R. Whitfock/Pat Reill¥ Casing Size and Descdl: 9-5/8", 40#, L-80, BTC Casing Setting Depth? 4546' / TMD 4321' TVD Mud Weight:. 8.6 ppg EMW = Leak-off Pressure (,PL + MW 0.052 x TVD LOT = 1490 psiJ-(O~_~2 x 4321 ft) + 8.6 ppg = 15,2 ppg Hole Depth (md~-~-581~ Fluid Pumped = 2~"3-bbls. Pump output = .101 bps 33O0 32O0 3100 3OO0 28013 2700 26OO 25OO 24OO 23OO 2200 2100 1413O 12~ 7113 1121O 0 2 4 6 8 I(3121416 182022242628303234363a4042,4¢14648505254565860626466~70 STROKES Il,L[. ~lk Daily Drilling Report --P' ARCO Alaska, Inc. ~FC No. 1 Date Rpt No JRig Acc~m - hfsD~"~ ~;~c~ A~s~ 4.71 f 2 R~ Re~a~ - h~ Wel: 1~ K~k ~ ~D) ~ pr~ M~ 4~1 P~ 739 C~ PA~ER .. Dal~ C~ $1~9 ~ ~s~4~ ~l Co~ T~ ~m $ ..... ~g Name: ~G I ~S L~ C~ 9 ~8' ff~' N~C~ 7' ~ 4~5' Sh~ Te~: I~ ...... .. ... M~.., -':~~~ ' . ~-. ......... -. .... '~is ... ' . ~, ~:OA~A. _ : ~flDMUD ~E ~O~ 3~IT NO. ~BIT NO. yI~ID~T T~T B~VERT ~GHT ROT ~ SI~ SI~ - '~MPLOYER ~TH2S b~ '" ~ FI~ ORI~ LS~ 180i 8.5 8.~ : P~r ..... 0~1 ~1~ i VISCOSI~ ~ ~ ~MA~ ~K~ SPILL ~ C~FINED ~T D~LL 47s~ 210 I ~C ~C : N SPA~ GELS ...... AVG D~G ~AL NO S~IAL ~ '~L~ME ~EL USED , ....... ~ ~ M~ ~AG ~ ~T OEP~ ~ ~ST S~ MTG ~ WA~R USED - 13.2 4~1 I~ 0~7~ ~P ~ ~Q ~ ~ IN ,DE~ !N_.~;~.,.~, .:~ .._ .~ , -: -" ..... ';: :'" ' ...... ': ~A~E WATER 1~= HOLE VOLUME PU~ ~ES ADT/AST ~T/AST SOUR~ ~ ~P 'F MBT ~P' NO ~ 2 ~B 2 RA~ ~m)' ~ S~ED 4 7.s 112131 s-~2 s-~2 3 ~. ......... ph LIN~ SZ R~ 1 RPM I ~E~URE t~i) ~ND 0]~ g-~ e I e I ~s I 70- 70 - ~ ~ I ~A ' ~ ' DIESEL V~ ~) ~LL FAVOR '~ 17.93% 76i II o .5~ 9o DAILY ~ ,$PS 1 ~ C~T BIT C~T WAT~ VOL (bb~) ~A~ ~ef 301 ~ J I 0 0 S~ ~SO~L TOT~ ~' ' ~P 1 DU~ D~ ~ VOL ~l) ~$C ~SON~L C0~A~ "' MUD ~ G~DE G~ TOT ~ ~ (~) ~Rvtc~ 8ARO~ ~o.ol I I EIIIn=I~a III ... ' ~SONNEL TOT~ IN.CAD: H~ ON J~S: ~0S.~S .... t ~ AM 12:~0 ~ 0~0 ~_CSG ~ ~ T~I CSG ~1 Fl 10 ~n 1~ AM 01:30 AM 1.00 ~ _~ ~ H~ ~ ~g ~ ~4~ 01:~ AM 0~00 AM 0.~0 ~N_O~ M~ ~ ~ O~ AM 04:~ AM Z~ ~_CSG M~g ~ ~c B~ ~. Te~ ~G 3~I. o~ ~ ~n. 04:~ AM 0e:~ AM 4.00 ~ O~ ~g ~ ~ C~ ~ ~ & sh~ ~17~61 08~ ~ 0~ AM 1.00 ~L Ming ~ DrlN .~M.~g ~4~t~ A~ 1.~ ~ ~ ~, I ~:~AM I~AM 1.00 TE~ ~~ Cl~l~t.l~~15.~ ~- ~ i' 1 ~ ~ I~30 PM 0~0 ~ER Ma~ ~ ~fl~ H~ ~ d~e. 12:30 PM 0~:30 ~ I.~ ~ ~g ~ CendM~ ~d end 01:3g ~ 03:~ PM 2.00 ~P_O~ ~ ~ ~H 03:30 ~ 04:~ ~ 0.50 g~ ~g ~ ~ B~. 04:~ PM 04:30 PM 0.50 BHA M~ ~ O~ ~ ~ogmm S~ 04:30 PM 07:00 PM 2.50 ~_~ MaN~ ~ ~H RII ~ ~ HW ~ M~ds & b~om. 07:~ PM 10:00 ~ 3.00 ~ M~ H~e D~ ~ 558t' 1o ~ - A~ 1.~. 10:~ PM 1O:~O ~ 0.~ ~HER M~ H~ Re,ir rig f~ up I~ Daily Drilling Report: 1 D-09 Kuparuk 04/17/98 Page I ARCO Alaska Inc. Cementing Details Well//: Casing Size 9-5/8" Centralizers Mud Spacer Stage 1/Stage 2 Lead Cement Stage 1/Stage 2 Tail Cement Stage 1/Stage 2 Displacement Stage 1/Stage 2 D-09 Hole Diameter 12-1/4" Field: KuparukRiver Unit Angle @ shoe J Shoe Depth 25.76J 4545 Date: 4/16/98 Float Depth 4,467 State type used, intervals covered and spacing % washout 49 bowspring centralizersplaced 1/jt on first 13 jts and every third jt plus one on eacl" Baklerlocked joint on each side' of the stage collar. Weight 10.2 Gels before 28/60 Type Water PV(prior cond) 45 Gels after 12/18 Type J Mix water temp ASIII/ASIII J 75 Additives PV(after cond) JYP(prior cond) 38J 70 Total Volume Circulated 1200 bbls Volume 50/30 No. of sacks 532/484 Weight 10.5 YP(after cond) 45 Weight 8.33 Yield 4.41 50%-D 124, 3.5%-D44,0.4%-D46, 30%-D53,1..5%-S001,1.5%-D79 Class G/Class G 75 515/60 15.8 1.15 Additives 1%-S001,0.2%-D46, 0.3%-D65 Rate(before tail at shoe) 7.4/8.3 Reciprocation length 20'/O' Theoretical Displacement 335.5/152.7 Calculated top of cement J ClP Surface J 06:31/09:02 Rate(tail around shoe) 7.4/8.3 Reciprocation speed 40 fpm Actual Displacement 335.5/152.7 Bumped plug JFioats held yes/yes J Yes/Yes Str. Wt. Up 260 Str. Wt. Down 200 Str. Wt. in mud 154 Remarks: Include whether full returns were obtained, reciprocation throughout operation and any other pertinent information. Had full returns throughout both stages. Reciprocated pipe until all of lead and 50 bbls of tail through on first stage. Opened stage collar w/3100 psi. Had 70 bbls contaminated cmt and mud in returns. Pumped second stage and closed stage collar with 1300 psi. Cement Company Dowell J Rig Contractor Parker #245 JSignature G.R. Whitlock CASING / TUBING / LINER DETAIL 9-5/8" Surface Casing ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company WELL: 1D-09 KRU DATE: 4/14/98 1 OF 1 PAGES # ITEMS 51Jts Joint 'B' Joint 'A' 62 Jts 1 Jt 2 Jfs COMPLETE DESCRIPTION OF EQUIPMENT RUN RKB to Landing Ring - Parker Rig #245 FMC Fluted Mandrel Casing Hanger & 471I, NT-80SS, NSCC x BTC pc 9-5/8", 4C~, L-80, BTC Casing 9-5/8", 40#, L-80, BTC Casing - Baker Locked Gemoco '754' Stage Cementing Tool 9-5/8", 40#, L-80, BTC Casing - Baker Locked 9-5/8", 40#, L-80, BTC Casing Gemoco Insert Shut-Off Baffle 9-5/8", 40/1, L-80, BTC Casing Gemoco Float Collar 9-5/8", 40#, L-80, BTC Casing Gemoco Float Shoe LENGTH 41.20 1.94 1934.61 37.72 2.82 39.09 2369.62 39.50 1.50 75.88 1.70 Bottom of Shoe ==>> TD = 4561'MD (- 15' Rathole) Baker Lock thru Insert Shut-Off Baffle, plus Stage Collar to Joints 'A' & 'B' Install Insert Shut-Off Baffle in Connection on Top of Jt #3 Run Stage Collar & Baker Locked Jts 'A' & 'B' on Top of Jt #6~, Run FMC Hanger on Top of Joint # 116 49 Bow Spring Centralizers: One on each of first 13 joints (first two on stop rings), Then one on every 3rd joint to surface, Plus one on a stop ring on Baker Locked Jts 'A' & 'B Leave OUT 9Joints: #117 thru #125. Remarks: String Weights with Blocks: 250K11 Up, 180K# Dn, 76K11 Blocks. Ran DEPTH TOPS 41.20 43.14 1977.75 2015.47 2018.29 2057.38 4427.00 4427.00 4466.50 4468.00 4543.88 4545.58 23 joints of casing. Drifted casing with 8.679" plastic rabbit. Calipered pup on hanger to be sure it passed an 8-1/2" bi Arctic Grade APl Modified No Lead thread compound on all connections (National = BOL 2000). Torqued to the base of the triangle stamp. Parker Rig #245 Drilling Supervisor: G.R. Whitlock ARCO ALASKA, INC. KUPARUK RIVER UNIT PARKER 245 DS 1D-09 50-029-22875-00 AK-MM-80191 SPERRY-SUN DRILLING SERVICES 14-APRIL-1998 MAGUTM VALUES: DECLINATION = 27.68 DIP ANGLE = 80.62 TOTAL FIELD STRENGTH = 57,279 DATE OF MAGNECTIC DATA = 13-APRIL-1998 ORIGINAL MEASURED ANGLE DIRECTION DEPTH DEG DEG VERTICAL LATITUDE DEPTH FEET DEPARTURE VERTICAL DOG FEET SECTION LEG O.00 0.00 0.00 121.00 0.00 0.00 170.00 0.75 271.00 356.00 0.25 306.00 446.00 0.75 13.00 0.00 121.00 170.00 355.99 445.99 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.01 N 0.32 W 0.12 1.53 0.27 N 1.87 W 0.94 0.30 0.95 N 1.89 W 1.59 0.77 555.86 2.84 53.95 643.78 5.01 70.93 737.47 7.14 50.28 828.48 8.34 74.23 1008.61 11.29 72.65 555.79 643.50 736.67 826.87 1004.35 3 5 10 16 25 .26 N 0.47 E 2.85 2.12 .79 N 5.86 E 3.18 2.77 .85 N 14.21 E 4.76 3.22 .26 N 24.91 E 5.78 3.75 .07 N 54.32 E 2.96 1.64 1192.56 11.33 74.68 1472.80 10.63 75.60 1658.31 9.31 70.33 1752.09 9.20 70.29 1845.46 9.30 62.58 1184.73 1459.84 1642.54 1735.10 18.27.26 35 48 58 63 69 .22 N 88.94 E -0.56 0.22 .92 N 140.52 E -7.13 0.26 .22 N 171.23 E -9.97 0.86 .31 N 185.43 E -10.56 0.12 .30 N 199.15 E -10.13 1.33 1941.92 9.93 42.72 2035.92 11.44 27.48 2129.25 13.38 16.38 2221.64 14.87 6.40 2314.24 16.33 358.95 1922.39 2014.78 2105.94 2195.54 2284.74 79 93 111 133 158 .00 N 211.72 E -5.82 3.48 .23 N 221.52 E 3.71 3.39 .80 N 228.84 E 18.21 3.29 .85 N 233.17 E 37.03 3.08 .67 N 234.26 E 59.66 2.67 2406.69 17.40 355.65 2500.27 18.13 349.54 2593.77 19.42 338.38 2686.77 20.95 333.03 2779.69 22.29 334.43 2373.21 2462.34 2550.89 2638.18 2724.57 185.45 213.73 242.49 271.69 302.39 N 232.97 E 84.98 1.55 N 229.27 E 112.59 2.14 N 220.90 E 142.39 4.07 N 207.66 E 174.43 2.58 N 192.52 E 208.56 1.55 2967.62 24.56 336.12 3250.35 26.99 335.05 3524.39 26.20 335.32 3803.12 25.38 334.58 4083.85 24.39 333.79 2897.00 3151.58 3396.62 3647.59 3902.25 370 482 593 703 8O9 .26 .18 .53 .39 .74 N 161.32 E 283.17 1.26 N 110.46 E 405.98 0.88 N 58.97 E 528.51 0.29 N 7.64 E 649.60 0.32 N 43.79 W 767.46 0.37 4269.40 24.42 335.84 4477.28 25.76 .334.92 4826.56 24.72 333.19 5108.60 24.46 336.68 5390.00 23.17 337.01 4071.23 4259.49 4575.42 4831.90 5089.33 879 959 1093 1199 1303 .11 .23 .16 .42 .89 N 76.41 W 843.99 0.46 N 113.15 W 932.03 0.67 N 178.26 W 1080.60 0.37 N 227.98 W 1197.73 0.52 · N 272.66 W 1311.33 0.46 ARCO ALASKA, INC. KUPARUK RIVER UNIT PARKER 245 DS 1D-09 50-029-22875-00 AK-MM-80191 SPERRY-SUN DRiLLiNG SERVICES Page 2 14-APRIL-1998 MAGUTM VALUES: DECLINATION = 27.68 DIP ANGLE = 80.62 TOTAL FIELD STRENGTH = 57,279 DATE OF MAGNECTIC DATA = 13-APRIL-1998 MEASURED ANGLE DIRECTION DEPTH DEG DEG 5668.16 21.99 5855.92 19.92 6042.18 18.34 6229.96 16.69 6322.15 15.82 VERTICAL DEPTH 6415.84 14.66 6507.28 13.47 6633.46 10.80 6717.40 10.48 6812.93 10.53 LATITUDE FEET 6905.92 10.56 6969.33 10.85 7024.00 10.85 337.72 5346.16 1402.46 N 335.12 5521.50 1464.01 N 333.27 5697.47 1518.97 N 332.65 5876.54 1569.31 N 332.38 5965.04 1592.20 N 334.34 6055.44 1614.21 N 334.04 6144.13 1634.21 N 338.99 6267.49 1658.47 N 342.21 6349.98 1673.08 N 346.14 6443.91 1689.83 N 344.79 6535.33 1706.30 N 345.07 6597.64 1717.67 N 345.07 6651.33 1727.61 N DEPARTURE VERTICAL DOG FEET SECTION LEG 313.78 W 1418.13 0.44 340.57 W 1485.23 1.21 367.10 W 1546.13 0.91 392.78 W 1602.41 0.88 404.69 W 1628.10 0.95 415.74 W 1652.6~ 1.35 425.42 W 1674.81 1.30 436.09 W 1701.29 2.27 441.24 W 1716.77 0.80 445.99 W 1734.08 0.75 450.26 W 1750.95 0.27 453.32 W 1762.65 0.46 455.97 W 1772.86 0.00 THE DOGLEG SEVERITY IS IN DEGREES PER 100.00 FEET THE VERTICAL SECTION WAS COMPUTED ALONG 338.065 (TRUE) BASED UPON MINIMUM CURVATURE TYPE CALCULATIONS. THE BOTTOM HOLE DISPLACEMENT IS 1786.77 FEET, IN THE DIRECTION OF 345.222 (TRUE) TO/VY KIVOWLE$, GOVERNOFt Al,ASK& OIL AND GAS CONSERVATION COMMISSION April 7. 1998 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Mike Zanghi Drilling Superintendent ARCO Alaska. Inc. PO Box 100360 Anchorage. AK 99510-0360 ae~ Kuparuk River Unit l D-09 ARCO Alaska. Inc. Permit No. 98-65 Sur. Loc 138'FNL. 601'FEL. SEC. 23, T11N. R10E. UM Btmhole Loc. 1631'FSL. 1039'FEL. SEC. 14. TI IN. R10E. UM Dcar Mr. Zanghi: Enclosed is thc approvcd application for permit to drill thc abovc rcfcrcnccd v,'cll. This approval includes annular disposal of drilling xvastcs and is contingent on obtaining a well ccmcntcd surfacc casing confirmcd bra valid Formation Integrity Tcst (FIT) - cementing rccords. FIT data. and any CQLs arc to bc submitted to thc Commission prior to thc start of disposal operations· Thc pcrmit to drill docs not cxcmpt you from obtaining additional permits rcquircd by lax',' from other govcrnmcntal agencies, and docs not authorize conducting drilling operations until all other required pcrmitting dctcrminations arc made. Thc blowout prcvcntion equipment (BOPE) must bc tcstcd in accordancc with 20 AAC 25.035: and thc mechanical integrity (MI) of thc injection wells must bc demonstrated under 20 AAC 25.412 and 20 25.030(g)(3). Sufficient notice (approximately 24 hours) of thc MI tcst before operation, and of thc BOPE tcst pcrformcd before drilling below thc surface casing shoe. must be given so that a rcprcscntative of thc Commission may witncss thc tests. Notice mavbc given bv n thc North Slopc pagcr at 659-3607· · · David W:,J~hnston } -~ Chairman BY ORDER OF THE COMMISSION dlf/Enclosurc CC; Department of Fish &Gamc. Habitat Section ~v/o cncl. Dcpartmcnt of Environmcntal Conservation xv/o cncl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill F' I lb Type of Well Exploratory F~ Stratigraphic Test E Development Oil Re-Entry [~ Deepen F'[ service X Development Gas [~ SingleZone X Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 71' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25650, ALK 468 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 138' FNL, 601' FEL, Sec. 23, T11 N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1594' FSL, 1024' FEL, Sec. 14, T11N, R10E, UM 1D-09 #U-630610 At total depth 9. Approximate spud date Amount 1631' FSL, 1039' FEL, Sec. 14, T11 N, R10E, UM 4/8/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1D-119 7006' MD 1632' @ TD feet 13.0' @ 400' feet 2560 6632' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 300' feet Maximum hole angle 24.5° Maximum surface 3768 psig At total depth ('I'VD) 4471 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' +_200 CF 12.25" 9.625" 40.0# L-80 LTC 4494' 41' 41' 4535' 4325' 673 Sx Arcticset III & HF-ERW 484 Sx Class G & 60 SX AS I 8.5" 7" 26.0# L-80 BTC MOD 6717' 41' 41' 6707' 6337' 116 Sx Class G 6.125" 4.5" 12.6# L-80 NSCT 448' 6507' 6144' 7006' 6632' 80 sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: trrnueea$~t~cdal ffee~l Plugs (measured) 0 RI C IN A L Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured ~tlF~ C ~ ~TV ~ert"~ depth Structural Conductor Surface ' 1 Intermediate [¥'i/,~. i'~, P reduction Liner Perforation depth: measuredAlaska 0i~ & Gas Cons. (;0mmissi0r~ true vertical Anchorage 20. Attachments Filing fee X Property plat F' BOP Sketch X Diverter Sketch X Drilling program X Ddlling fluid program X Time vs depth plot [~ Refraction analysis E Seabed report [~ 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed'~.,~) ',~~ f"o~¢,, /~//~' Z~,~/~JG ~'/.Z~ Title Drilling Superintendent Date ~',/~-,7/~ For questions, please call Denise Petrash Commission Use Only Permit NumberK_ I APl number I Appr°val date long/~u~ii re~C'} L__~) ISee c°ver letter f°r ~ . ~'~.~'- .~"'~.,. 50- ~.,2_ ~'- ~ ~.~ ~' ~',..~ other requirements L, onoiti~ns of approval Samples required [~ Yes J~ No Mud Yes J~ No Hydrogen sulfidemeasures ~ Yes E~ No Directional surveyrequired ,[~ Yes Ir- No Required working pressure for BOPE [~ 2M F' 3M ,~ 5M [~ 10M ~ 15M Other: Approved by ~-~._.'_:__~ c,: .... ~ ~.. Commissioner the commission Date __. Form 10-401 Rev. 7-24-89 Original Signed By David W. Johnston tin triplicate GENERAL DRILL AND COMPLETE PROCEDURE KUPARUK RIVER FIELD - INJECTOR KRU 1D-09 1. Move in and rig up Parker #245. 2. Install diverter system. 3. Drill 12.25" hole to 9-5/8" surface casing point (+/4535') according to directional plan. 4. Run and cement 9-5/8" casing, using stage collar placed at least 200' TVD below the base of the permafrost, and light weight lead cement. 5. Install and test BOPE to 3000 psi. Test casing to 2000 psi. 6. Drill out cement and 20' of new hole. Perform formation integrity test, taken to leak off if possible, maximum pressure allowed 14.0 ppg EMW. 7. Drill 8.5" hole to intermediate TD (+/- 6707') according to directional plan. 8. Run and cement 7" intermediate casing string. Note: If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. 9. NU and test BOPE to 5000 psi. Test casing to 3500 psi. 10. Drill out cement and 20' of new hole. Perform formation integrity test, taken to leak off if possible, maximum pressure allowed 16.0 ppg EMW. 11. Drill 6.125" hole to well total depth (+/- 7006') according to directional plan, running LWD logging equipment as needed. 12. Run and cement 4-1/2" NSCT liner with Baker liner-top packer and hanger. Hydraulically set packer +200' inside intermediate casing shoe to provide appropriate liner lap. 13. Pressure test liner to 3500 psi. 14. Run completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus. 15. ND BOPE and install production tree. 16. Shut in and secure well. 17. Clean location and RDMO in preparation for coiled tubing cleanout and perforating. Note: 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. 1D-09 TAB,03/26/98, v.1 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, & DRILLING AREA RISKS Well KRU 1D-09 Drillinq Fluid Properties: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 8.8-10.0 35-70 25-50 150-250* 10-25 10-30 8-15 8-10 4-6% Drill out to 7" interm, casing 8.8-9.0 4-8 5-8 35-40 2-4 4-8 8-15 9.5-10 4-7% Drill out to TD 12.0-13.0 15-25 5-8 50-65 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drillinq 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 *Spud mud should be adjusted to a FV between 200-250 sec/qt to drill gravel beds Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW (0.70 psi/ft) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 2,560 psi. MASP = (4325 ft)(0.70 - 0.11) = 2551 psi Maximum anticipated surface pressure is calculated using an intermediate casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 3,753 psi. Therefore, ARCO Alaska, Inc. will do a one-time test of the BOP equipment to 5000 psi, retesting only broken flanges or after 7 day limit. MASP = (6387 ft)(0.70- 0.11) = 3768 psi Based on offset well data, reservoir pressures in the Kuparuk sands in the vicinity of 1D pad are expected to be 3900 psi (0.61 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 12.2 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 6407'. Well Proximity Risks: The nearest existing well to 1D-09 is 1D-119. As designed, the minimum distance between the two wells would be 13' at 400' MD. Drillinq Area Risks: Risks in the 1D-09 drilling area include running gravels, lost circulation and high pressures in the Kuparuk formation. These are addressed by using a high viscosity spud mud and by setting intermediate casing above the Kuparuk. Careful analysis of pressure data from offset wells shows that a mud weight of 12.2 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 9-5/8" and 7" casing shoes will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the casing. Annular Pumping Operations: Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of well 1D-10 or another permitted existing well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 1D-09 surface/production casing annulus will be filled with diesel after setting the production casing and prior to the drilling rig moving off of the well. If isolation is required perregulations on significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover the formation. It is requested that 1D-09 be permitted for annular pumping occurring as a result of drilling operations, per proposed regulations 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Please reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoes will be set _+200' vertical below the base of the West Sak into the heart of the shales. The maximum volume of fluids pumped down the annulus of this well will not exceed 35,000 bbls without the specified permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.5 ppg for drilling wastes. Using 12.5 ppg fluid and the rig's specified maximum pumping pressure of 1500 psi, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.5 ppg) * (0.052) * (Surf. Shoe TVD) + 1500 psi Max Pressure = 4312 psi The pressure is very conservative as frictional losses while pumping are not accounted for. The surface and production casing strings exposed to the annular pumping operations are determined to have sufficient strength by using the 85% collapse and burst ratings listed below. OD Wt Conx Collapse 85% of Burst 85% of (in) (Ib/ft) Grade Range Type (psi) Collapse (psi) Burst 9.625 40 L-80 3 BTC 3090 2627 5750 4888 7.000 26 L-80 3 BTC-M 5410 4599 7240 6154 Fluids to be disposed of in subject annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.254 ~//~ (1). 1 D-09 TAB, 3/25/1998, v. 1 I v 4OO ~00 i200 i 600 2000 24O0 28O0 3200 3600 4OOO 4400 4800 5200 5600 6000 6400 6800 c~¢~ ~,~¢~ For: T BROCKWAY o~t~ plotted : 26-J~n-§8 P~ot Reference ;$ 9 Vers;~n ~5. T~e Vertical Oept~s ere re~erence Est. RKB(Porker EST. RKB ELEVATION: 112' KOP TVI}:300 TMD=300 DEP=0 3.00 DIS 3.00 cleo per ~00 ft 6.00 END INITIAL BUILD TVD=566 TMD=567 DEP=2 ARCO Alaska, Structure : Pad 10 Well: 9 Field : Kuporuk River Unit Location : North Slope, Alaska TO LOCATION: I 1631' FSL, 10.39' FEL SEC. 14, T11N, RIOE 800 600 I I I 4 1/2 Liner 7 Casing TARGET LOCATION: 1594' FSL, 1024' FEL SEC. 14, T11N, RIOE TARGET TVD=6407 TMD=6778 DEP= 1783 NORTH 1752 WEST 423 9 5/8 Casing Pt <- West (feet) 400 200 0 TD C50 C55 Begin Angle Drop C50 Tfl C4 (EOD) 200 400 i 2000 1800 1600 1400 1200 C80 Companion SS / - 9 5/8 Casfng 1000 lEND HOLD - BEG TURN TO TARGET TVD=1787 TMD=1800 DEP=21 \ ~7.59 B/ PERMAFROST TVD=1812 TMD=1825 DEP=21 ~ 800 t'~.~ Top West Sak : rids 1~.08 DLS: 3.00 deg per 100 ft ~ / ~11 4'53 ~ F 600 11~' 18~ q]2'~ 6y ' 346,27 AZIMUTH ~-' aoc ~o:~; TUO:2~s oa~=~os 1783' (TO TARGET) k ~oo ~ ***Plane of Proposal*** ~EOC ANCLS _1 ~ws~o ~=4~2~ T~:4;~ c~oo ~% }~ 9 5/8" CSG PT ~D=4325 TMD=4535 DEP=976 C80 ~CAMP SS 1VD=4506 TMB=4734 DEP=1058 .... ~BEG ANGLE DROP WD=5486 TMD=5811 DEP=1500 __ _ C35 18.67~ DLS 1 50 de9 per 100 ft 17 17 ,: 1~0 ~g ~r ~O ft C3011~1J7~ B/ HRZ ~D=6217 TMD=6584 DEP=1745 c~u15.67 ~ K-1 MARKER ~D=6507 TMD=6676 DEP=1764 C2014.17~ 7" CSG PT ~D=6557 TMD=6707 DEP=1770 --- 12.67~T/ D WD=6587 TMD=6758 DEP=1779 ~[~ T/ C2 WD=6487 1MD=6859 DEP=1797 T/ C1 ~D=6533 DEP=6906 DEP=1805 TD - CSG PT ~D=6632 TMD=?O08 DEP=1822 ............ TARGET ANGLE o ~oo ~oo ~2oo ~6oo ~ooo 10 DEG Vertical Section (feet) -> Azimuth 346.27 with reference 0.00 N, 0,00 E from slot #9 Z 0 2' c ..... ~y, .... For; T BROCKWAY '[ ANCOAlaska, Oate ,¢~3tted : 2~-don-~8 Ptot Reference rs 9 Vets;on ~5. CoordMates are in ~eet re~e~¢nce slat ~§. last (feet) -> 280 240 200 160 120 8C 40 0 40 80 120 Inc. Structure: Pad 1D Well: 9 Field : Kuparuk River Unit Location : North Slope, Alaska 6o 200 240 280 320 720 680 640 6OO 56O 520 480 440 400 560 320 2400 2500 \~°° '"' %, ',,,,,j, °~",,,,,,,,,,.,(~ o o~~ 6 i\o lOOO '~,,1000 '..~ 10 "\ , ',,,,,~,,000 '"",,,,,,,,,,,,,,"'",,,,,,,,,,,, ~ 2~,, 600;, 600/ '~ 800 ~" ". l~,~o '"" / / / , / / ,, / / / ! / 5500 ~, 13oo ~3oo / I ' / I ! / '\ I / 1100/ \¢4ooi / / ',\ 112oo / / 330(~'"~ ];"¢' 1200 /'"" i\, ; 11 O0 ~ t 2200] ,, 100o¢ 210,~1000/ 1400 ' 900/' · 260O go0 :00 2800~, 30 ' 1000 ", 2700 ,, '""~ 900 ", 700 1300 280 ~,, '"' '"' "" '% 1700 260~'i "-..10~6, ",, '-,, ,. 240 '"',-.~1 O0 ".. "-~ 900 '-, ',, -~ '"-.. "-.. '% soo ""- .,., , 0~'-.. ;~ ".. "... '.. ~600 2~00'\ 2oo I~""'- '"- goo ~ ~,...~o..-.....'.,.~oo '.......e 1~oo km~29°° ~oo .... %'"'-a~%'"~oo "9 ~oo lOO 160~ ~ .. ~70( ~000 ~ 2~00 1~00 ~o ~ '~':'::'~--~'~:'~ ,oo ~:oo .... ~-~% ........ ~ '--.,.'~ ~2~oo 80 4O 4O 8O O0 600 720 68O 640 6OO 560 520 480 44O 4-00 360 320 2100 280 1500 240 2OO i20 500 ./' 1900 ~ ....... ~ ....... ~%o 23~ (~ 400 ........ 1500 ~~ ~ooe,~oo ..-~i-g~°° ~o 2100 200 ...... ~0 21 O0 ~ 500 -~ ........ 700 ~,.r~'h 1800 ~ 6;~-~ 500 ~00 '-:'-'-' 0 15O0 50O 5ooe~ 13oo ~ .......... 1_.2_0_.0_ 2 1__00 1000 900 500 X-. ~ 40 ..................................... 800 ~1400 .............. ~500 [ 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 [~0 280 240 200 160 120 80 40 0 40 80 120 1 60 200 240 280 520 Easf (feel) -> Z 0 Creot,~ ~ ~.~ For: T BROCkqYAY Dote ~otted : 2f-Jan-fl8 Plot Reference [s 9 Vers;on ~15. Caardinc~[es are ~n feet reference s~ot T~ Vertical Depths ore reter~nce EsLRKB(Porker ~245). 1820 1750 1680 1610 1540 1470 1400 1330 1260 1i90 ii20 1050 630 560 490 420 2700 370( \ , ',, , 1500 '~ ALPC0 Alaska, Inc, "~ 1 500 · Structure : Pad 10 Well : 9 Field : Kuparuk River Unit Location : North Slope, Alaska <- West (feet) 350 280 210 6500 '~ 6300 '~ 61 O0 '~ 5900 '~, \ 5700"~ 3500 5500 2100 2500 2300 980 910 "'""'"'. 840 ',,.,,. 1300 ',, 1300'~ 770 7OO 630 ', 420 5300 ,, 5100"' 4900 '~, , \ 4700\h, · 1300 3100 4500 140 70 i 630 560 490 420 2100 500 4300 4100 ~ ,39OO ', 5700 70 140 210 900 ~ 1 700 3500 , 33001 31001 2900i 1500 1900 ', " ,, 270CJ ' 1100 ', 1,3oo ',, , , 17aa',, 1100'~., ". ' ' ' oo.% % I I i i ,350 280 210 140 70 0 70 <- West (feet) /~ 1300 ! / l ! / ! ! ! / ! ! / 33oo/ /~10~" 140 280 350 ! ! ] , ! ¢ 1700 [ , / ! ! / / ! / ~ / ~ / I / / 15oo / / / / , ! , · i500 I I i i I 210 280 ,350 420 : k 175o ; , ; ! I i 680 ,, 1610 900 I ~ 540 I1470 140O i 330 i 260 ,' i 190 / ,, / / / 1~2o ,, / 1050 980 91o 840 77o 70o 65O k 560 P 490 ~ [ 420 420 A Z O ARCO Alaska, Inc. Pad 1D 9 slot #9 Kuparuk River Unit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE by Baker Hughes INTEQ REPORT Your ref : 9 Version #5 Our ref : prop2523 License : Date printed : 26-Jan-98 Date created : 18-Nov-97 Last revised : 26-Jan-98 Field is centred on nT0 16 18.576,w150 5 56.536 Structure is centred on nT0 18 1.316,w149 30 18.908 Slot location is nT0 17 59.959,w149 30 36.429 Slot Grid coordinates are N 5959526.663, E 560487.083 Slot local coordinates are 138.00 S 601.00 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less tha~ 500 feet DECREASING CL~CES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath TOTCO Survey,,WS-8,Pad 1D PGMS <0-8610'>,,6,Pad 1D PGMS <0-8930'>,,5,Pad 1D PGMS <0-7502'>,,4,Pad 1D PGMS <O-8070'>,,3,Pad 1D PGMS <O-9783'>,,2,Pad iD PGMS <0-8365'>,,1,Pad 1D MSS <3311-8200'>,,7,Pad 1D PMSS <O-4778'>,,H4,Pad 1D PMSS <0-5015'>,,GT,Pad 1D PMSS <1957-5265'>,,JS,Pad 1D PMSS <0-5462 >,,J3,Pad 1D PMSS <0-4414 >,,GS,Pad 1D PMSS <0-4530 >,,F6,Pad 1D PMSS <0-4515 >,,F4,Pad 1D PMSS <0-4590 >,,E5,Pad 1D PMSS <0-5142 >,,E3,Pad 1D PMSS <O-5205.'>,,ET,Pad 1D PMSS <0-5047'>,,G3,Pad 1D PMSS <0-4850'>,,D4,Pad 1D PMSS <381-6092'>,,CT,Pad 1D PMSS <0-5126'>,,D6,Pad 1D WS 1D-126/J1 Vets. #3,,J1,Pad 1D WS 1D-125/H2 Vers, #3,,H2,Pad 1D WS 1D-123/G1 Vers. #3,,Gl,Pad 1D Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 11-Nov-97 13-Nov-97 13-Nov-97 4-Aug-92 4-Aug-92 4-~ug-92 10-Dec-97 6-Nov-97 9-Nov-97 13-Nov-97 24-Nov-97 1-Dec-97 8-Dec-97 19-Dec-97 16-Dec-97 22-Dec-97 30-Dec-97 7-Jan-98 6-Jan-98 12-Jan-98 23-Jan-98 19-Jan-98 26-Jan-98 26-Jan-98 26-Jan-98 465.0 225.1 105.1 13.4 126 8 25O 3 353 4 345 0 267 9 388 0 310 2 252.3 42.3 27.7 13.0 28.2 77.1 47.2 131.2 197.1 271.6 228.7 165.0 150.0 75.0 100.0 100.0 100.0 450.0 820.0 620.0 1120.0 300.0 300 0 100 0 325 0 300 0 350 0 325 0 400 0 522 2 100 0 100 0 400 0 100 0 300.0 960.0 300.0 300.0 200.0 100.0 100.0 1580.0 6777.9 820.0 620.0 2680.0 3OO.O 300.0 100.0 325.0 300.0 350 0 1712 0 400 0 4680 0 4880 0 100 0 400.0 5000.0 300.0 960.0 300.0 300.0 200.0 ws 1D- 122 WS 1D- 116 W8 1D- 114 WS iD- 113 WS 1D-112 WS 1D- lll WS 1D- 110 WS iD- 108 WS 1D- 104 WS 1D-103 WS 1D- 102 WS 1D-101 /F2 Vets. #3 .... .2,Pad 1D /El Vets. #3,,El,Pad 1D /D2 Vets. #3,,D2,Pad 1D ~C1 Vets. #3,,C1,Pad 1D ~A1 Vets. #3,,Al,Pad 1D ~B2 Vets. #3,,B2,Pad 1D ~C3 Vers. #3,,C3,Pad 1D ~A3 Vets. #3,,A3,Pad 1D ~A7 Vets. #3,,A?,Pad 1D 'B6 Vets. #3,,B6,Pad 1D ~A5 Vets. #3,,AS,Pad 1D 'C5 Vets. #3,,CS,Pad 1D 26-Jan-98 26-Jan-98 26-Jan- 98 22-Jan-98 22-Jan-98 22-Jan-98. 22-Jan-98 22-Jan-98 21-Jan-98 21-Jan- 98 21-Jan-98 21-Jan298 60.0 58.7 90.0 105.0 120.0 165.0 180.0 -210.0 284.5 300.0 315.0 330.0 450 0 200 0. 200 0 325 0 325 0 300 0 300 0 425.0 200.0 300.0 300.0 300.0 450.0 200.0 200.0 325.0 325.0 5685 7 300 0 425 0 200 0 300 0 5520 0 1 13/11/98 MRT MJH AS~UILT PER I~ ~,~D.S.1B Rood ~ x-r- C P F1 D.S. ~-D ,o,~ ~ ~ 5-TM SUR~Y ~~.J ~ 14.15 : ~ 6 ~s ~ ~ClNITY MAP ~ ~ 4~7 ~ SCALE: 1" = I MILE ~ 118~ 4 i320 1~1 12o I ~ ~ e ~o LEGEND SEE SHEET ~ 2 FOR NOTES AND LOCATION INFORMATION o rX/S~¢NC CONOUCrO~S ~ ~OUNSBURY · NEW CONOUCTOR LOCAnON~'~'~/j~ · ASS0CIA~BS, INC. AREA' 1D MODULE XX UNIT' D1 ~ DRILL SI~ 1-D LK6104D13 3/11/98 CEA-D1DX-6104D13 1 0r 2 1 ~ 13/~/9al MRT MJH AS-BUILT PER KSB# K98017ACS '~'~[ NOTES l- ~-.D.S.,B ~ /, ~ ~ CPF1 ' SEA LEAL. ALL DISTANCES SHO~ ARE TRUE, ~e ~RE Y S X , ~ ~ i )~ Z BASIS OF LOCATIONS AND ELEVATIONS ARE D.S. 1-D MONUMENTS PER LHD AND ASSOCIATES. 3. CONDUCTORS ARE LOCATED ~IN PRO~AC~D SECTION 2~, TO,SHIP 11 NORTH, RANGE 10 EAS~ U.M. 4. DATE OF SUR~' 5/8/98, FIELD BK 98-18 PG'S 70-75. 5. DRILL SITE 1-D GRID NORTH IS ROTA~D 00' 01' 05" ~ ~S T FROM A.S.P. ZONE 4 GRID NOR TH. 6. SEE DRA~NG NSK-5.5-1 FOR AS-BUlL T LOCATIONS OF CONDUCTORS ~1 THROUGH ~8 AND CEA-DIDX-6104D10 FOR ~LL CONDUCTORS 105,106, 109, 115,117-121,124,129, 1~0,1~ ~ 1~5, ~CINI TY MAP SCALE: 1" = I MILE Sec. 25, T. 11 N., R. IO E. We~ A.S.P.s LA TITUDE LONGITUDE SEC.,,,~SEC.,,,~ PA D O.G. No. 'Y' 'J' L~ L~ ELE~ ELE~ F.N.L.F.E.L. 9 5,959,528.99 560,490.59 70' 17' 59.981" 149' ~0' 56.~26" 1~6' 598' 70.6' 66.0' 10 5,959,108.97 560,490.70 70' 17' 55,850" 149' ~0' ~6.422" 556' 601' 70.6' 69.4' OF 47~%- SURVEYOR'S CERTIFICATE ............. REG I S TERED ~ND L I CENSED TO PRA C T I CE " ~' ............................... ~ ..... ALASKA ~ND THAT TH I S PL~ T REPRESENTS ',,, A SURVEY DONE BY ME OR UNDER MY ~ ~ BRIAN G, MANGOLD ~ ~ DIRECT SUPEPVISION AND THAT ALL ~, ~A % LS-8626 ? ~ DIMENSIONS AND OTHE~ DET~ILS ARE assoa , s. ~ENGINEERS P~NNERS SURVEYORS ~k DRILL SI~ 1-D ARCO Alaska, Inc. ~LL CONDUCTORS 9 · 10 AS-BUILT LOCAqONS CADDF, LE NO. J IDRA~NO NO: I SHEET: IREV: LKblO4D13 3/11/98 CEA-D1DX-6104D1~ 2 o~ 2 ~ KUPARUK RIVER_.,? ,IT' 20" DIVERTER SCHEMA'TIC 6 4 3 [ - DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FiLL PREVENTER WITH WATER TC ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. . CLOSE ANNULAR PREVENTER IN THE EVENT~T AN INFLUX OF WF! I RORE 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) .~horage 1. 16' CONDUCTOR. 2. SLIP~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 LINF- THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WINO CONDITIONS. 6. 20" - 2000 PSI ANNULAR PREVENTER. DKP 1 , 6 5 i2 1. 16' - 2000 PSI STARTING HEAD 11' - 3000 PSI CASING HEAD 3. 11' - 3000 PSI X 13-5/8' - 5000 PSI SPACER SPOOL 4. 13-5/8' - 5000 PSI VARIABLE 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~'- 5000 PSI ANNULAR 13 5/8" 5000 PSi BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC 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 UMIT IS 45 SECONDS CLOSING TIME AND 1200 PS! REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND 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 5000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. TEST ANNULAR PREVENTOR TO 31:X)O PSI ONLY. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE UNE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. 7. TESTTO 250 PSI AND 5000 PS! AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 5000 PS! 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 Bo3-rOM PIPE RAMS, TEST BO~-FOM RAMS TO 250 PS! AND 5000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 5000 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 DRILUNG POSITION. 11. TEST STANDPIPE VALVES TO 5000 PSI FOR 3 MINUTES. 17_ TEST KELLY COCKS AND INSIDE BOP TO 5000 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. NOTE: PRIOR TO DRILUNG OUT OF THE INTERMEDIATE CASING SHOE ALL FLANGES AND SEALS BROKEN BETWEEN THIS TEST AND THE PRIOR ONE WILL BE TESTED TO 250 PSI LOW AND 5000 PSI HIGH · WELL PERMIT CHECKLIST COMPANY FIELD & POOL ~/' ~/('~O INIT CLASS WELL NAME/~'~. / ~) -4:~ ~ . GEOL AREA ~' ? ('2 PROGRAM: exp [] dev [] redrll [] servk'~wellbore seg t2 ann. disposal para req~ UNIT# ////,/~'"E~ ON/OFF SHORE ADMINISTRATION 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. Permit fee attached ....................... Lease number appropriate ................... Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... N N N N N N N N N iN N N N _.= ENGINEERING 14. Conductor string provided ................... ~ N 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... N 22. Adequate wellbore separation proposed ............. N 23. If diverter required, does it meet regulations .......... N,,,~ 24. Drilling fluid program schematic & equip list adequate ..... N 25. BOPEs, do they meet regulation ................ N 26. BOPE press rating appropriate; test to .~--(.)~::>'~;:) psig. N 27. Choke manifold complies w/APl RP-53 (May 84) ........ N 28. Work will occur without operation shutdown ........... N 29. Is presence of U2S gas probable ................. N GEOLOGY A~P~RR DATE 30. Permit can be issued w/o hydrogen sulfide measures ..... Y ~N/" ,~), 31. Data presented on potential overpressure zones ....... Y .,~ /-~/~ ~l, 32. Seismic analysis of shallow gas zones ............. .~. N ' -33. Seabed condition survey (if off-shore) ............. JY N 34. Contact name/phone for weekly progress repo, rts ...... / Y N lexp~ora~ory on~yj ' REMARKS GEOLO, C~Y:., ENGINEERING: COMMISSION: RNC ~_~~ co Comments/Instructions: HOW/Ijt - A:\FORMS\cheklist rev 09/97 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. Sperry-Sun Drilling Services LIS Scan Utility Tue May 12 09:57:52 1998 Reel Header Service name ............. LISTPE Date ..................... 98/05/12 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services Tape Header Service name ............. LISTPE Date ..................... 98/05/12' Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Services odx 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: MWD RUN 2 AK-MM-80191 P. SMITH G. WHITLOCK ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 1D-09 500292287500 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 12-MAY-98 MWD RUN 3 AK-MM-80191 P. SMITH G. WHITLOCK 23 liN 10E 138 601 .00 111.60 70.60 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 9.625 4545.0 8.500 7.000 6672.0 6.125 7024.0 1. ALL DEPTHS ARE MEASURE DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY, AND IS NOT PRESENTED. 3. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 4. MWD RUN 3 IS DIRECTIONAL, DGR, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 5. DEPTH SHIFT/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN M KREMER OF A~CO, ALASKA, INC. AND A TURKER OF SPERRY-SUN DRILLING SERVICES ON 05/11/98. THIS DATA IS CONSIDERED PDC. 6. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7024'MD, 6651'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE-SHIFT DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/05/12 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 GR 4542.5 ROP 4562.0 FET 6658.0 RPD 6658.0 RPM 6658.0 STOP DEPTH 6985.0 7024.0 6992.0 6992.0 6992.0 RPS 6658.0 6992.0 RPX 6658.0 6992.0 $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 2 4561.0 6689.0 3 6689.0 7024.0 MERGED MAIN PASS. $ 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 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHM~ 4 1 68 RPS MWD OHM~ 4 1 68 RPM MWD OHMS4 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 4542.5 7024 5783.25 4964 ROP 2.8237 2543.55 229.477 4925 GR 29.0345 520.297 132.192 4886 RPX 0.5349 2000 9.04939 669 R?S 0.543 47.6194 5.99196 669 RPM 0.2811 2000 104.086 669 RPD 0.3849 2000 25.6718 669 FET 0.5349 55.1767 6.92277 669 First Reading 4542.5 4562 4542.5 6658 6658 6658 6658 6658 Last Reading 7024 7024 6985 6992 6992 6992 6992 6992 First Reading For Entire File .......... 4542.5 Last Reading For Entire File ........... 7024 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/05/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/05/12 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 SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 4542.5 6646.5 ROP 4562.0 6689.0 $ LOG HEADER DATA DATE LOGGED: 18-APR-98 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.06 DOWNHOLE SOFTWARE VERSION: CIM 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 6689.0 TOP LOG INTERVAL (FT): 4561.0 BOTTOM LOG INTERVAL (FT): 6689.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 10.8 MAXIMUM ANGLE: 24.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS TOOL NUMBER P0999CG6 P0999CG6 8.500 8.5 MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) 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 LSND 163.50 47.0 9.5 450 13.2 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 2 API 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 44.2 First Name Min Max Mean Nsam Reading DEPT 4542.5 6689 5615.75 4294 4542.5 GR 42.7849 520.297 139.657 4209 4542.5 ROP 6.3711 2543.55 256.767 4255 4562 Last Reading 6689 6646.5 6689 First Reading For Entire File .......... 4542.5 Last Reading For Entire File ........... 6689 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/05/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/05/12 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 6651.0 6985.0 FET 6658.0 6992.0 RPD 6658.0 6992.0 RPM 6658.0 6992.0 RPS 6658.0 6992.0 RPX 6658.0 6992.0 ROP 6691.0 7024.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: 21-APR-98 ISC 5.06 CIM 5.46 MEMORY 7024.0 6689.0 7024.0 10.5 10.9 TOOL NUMBER P0921SP4 P0921SP4 6.130 6.1 LSND MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMS4) 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...0 230.80 53.0 8.5 5O0 4.6 2.700 1.260 2.350 3.400 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 API 4 1 68 4 2 RPX MWD 3 OHF~4 4 1 68 8 3 RPS MWD 3 OHN~4 4 1 68 12 4 RPM MWD 3 OH/~4 4 1 68 16 5 RPD MWD 3 OHMM 4 1 68 20 6 FET MWD 3 HOUR 4 1 68 24 7 ROP MWD 3 FT/H 4 1 68 28 8 51.6 First Name Min Max Mean Nsam Reading DEPT 6651 7024 6837.5 747 6651 GR 29.0345 159.663 85.5656 669 6651 RPX 0.5349 2000 9.04939 669 6658 RPS 0.543 47.6194 5.99196 669 6658 RPM 0.2811 2000 104.086 669 6658 RPD 0.3849 2000 25.6718 669 6658 FET 0.5349 55.1767 6.92277 669 6658 ROP 2.8237 898.826 54.187 667 6691 Last Reading 7024 6985 6992 6992 6992 6992 6992 7024 First Reading For Entire File .......... 6651 Last Reading For Entire File ........... 7024 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/05/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/05/12 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Services Reel Trailer Service name ............. LISTPE Date ..................... 98/05/12 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Services Library. Library. Scientific Scientific Technical Technical Physical EOF Physical EOF End Of LIS File