The URL can be used to link to this page

Home My WebLink About200-075 ) Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. ~-(}25 Well History File Identifier Organization (done) 0 Two-Sided Rescan Needed RESCAN DIGITAL DATA OVERSIZED (Scannable) o CtJlor items: o Diskettes, No. o Maps: Grayscale items: o Other. NofType o Other items scannable by large scanner o Poor Quality Originals: o Other: OVERSIZED (Non-Scannable) o Logs of various kinds TOTAL PAGES:' rß o Other NOTES: ORGANIZED BY: BEVERLY BRE~INCE~HERYL MARIA LOWELL DATE '1-/5 ,s,/!$ Project Proofing o Staff Proof PROOFED BY: BEVERLY BREN~INCENl...AHERYL MARIA LOWELL DATE: 9:13 BYl~ Scanned (done) PAGES: (at the time of scanning) SCANNED BY: BEVERLY BREN VINCENT~ARIA LOWELL DATE: Isl ReScanned (done) RESCANNEDBY: BEVERLY BW SHERYL MARIA LOWELL DATE:!()-Y ls' 1//J General Notes or Comments about this file: Quality Checked (done) PAGES: IJ~ Rev1 NOTScanned.wpd or riti, THE STATE hlasic r:_ c C, as } — 333 WesT Seventh Avenue k' : (3OV'FAVOR S1 A'' PAR\ELI, Anchorage, Aiasi<a 99501-3572 1 ..,gci, 907.279.1,133 swap JUL 2 9 2114 Jacob Voss Wells Engineer n -- Q 7S ConocoPhillips Alaska, Inc. au, P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1D-102 Sundry Number: 314-014 Dear Mr. Voss: 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, 13 „(„__ Cathy P. Foerster Chair DATED this day of January, 2014. Encl. . STATE OF ALASKA r ' AL A OIL AND GAS CONSERVATION COMM DN K` ^ APPLICATION FOR SUNDRY APPROVALS ti`s �' 0 ` '`} 20 AAC 25.280 N' D S 2 4�/r4- 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r` - Change 0� r Suspend r Rug Perforations r Perforate r" Pull Tubing IY , Time Extension r Operational Shutdown r Re-enter Susp.Well r StimulateAlter casing ,7 r -Other: (-' 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development p,• 200-075' 3.Address: Stratigraphic r Service 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-22960-00 ' 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No 1 D-102 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25650. Kuparuk River Field/West Sak Oil Pool. 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 7378 • 3721 7357' • 3720' 4125' 4363' • Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 13.375 110' 110' SURFACE 4899 7.625 4930' 3752' INNER CASING 4044 5.5"x 3.5" 4074' 3375' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 4925-7257 • 3752-3722 2.875 L-80 3961 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER PREMIER PACKER • MD=4105 TVD=3395 PACKER-BAKER PREMIER PACKER , MD=4250 TVD=3485 NO SSSV • 12.Attachments: Description Summary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r,i, Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 2/7/2014 Oil r• Gas 1- WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jake Voss @ 265-6935 Email: Jake.Vossaconocophillips.com Printed Name J Co Vo Title: Wells Engineer Signature %�' e. .._ Phone:265-6935 Date 11711 4 Commission Use Only fJ Sundry Number: 31�l-b1 y Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test 1VMechanical Integrity Test r Location Clearance r RBDMS MAY 1 0 Other: Sop 7,..e5-f- 1--a 3 0 0 0 1'S 1- . fl 2014 Spacing Exception Required? Yes ❑ No [ Subsequent Form Required: /d ^4 �( APPROVED BY Approved by: t1� 2(47 COMMISSIONER THE COMMISSION Date: I- l"/ Approved application is valid tor 11 monthssttrrom the date of approval. Form 10-403(Revised � ! � ORIGINAL...e"/„ FII Submit Form and Attachments in Duplicate V ` Nov ConocoPhillips o 8 21,11-', AOGCC January 7, 2014 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Producing well 1D-102 was drilled and completed in June 2000. It was first brought online in July 2000 as a West Sak dual lateral A/B/D sand ESP producer. This well has had a fair share of problems due to heavy sand and gravel production from a matrix bypass event with injector 1D-139, failed RMLS junction in the upper lateral and also ESP failures. The most recent workover was in August 2011, which converted the well to a jet pump producer with the installation of a 5-1/2" inner casing string. The most recent failure on 1D-102 occurred in April of 2013 when tubing by inner annulus communication was discovered. A follow up leak detect log showed a tubing leak at 3,877' MD. In August of 2013, the ESP motor grounded out as well. A caliper log showed internal corrosion in the tubing as well as the tapered 5-1/2" casing string. a The proposed workover will pull the 2-7/8" Jet Pump completion, pull and replace the inner string of 5-1/2" casing and re-complete the well with a 2'/8" jet-pump/gas-lift completion with internal coated tubing. This Sundry is intended to document the proposed change to the casing structure as well as request approval to workover the well. The current SBHP from the downhole gauge is 1610 psi at 3,259' TVD, which equates to an EMW of 9.50 ppg. Attached is a proposed schematic along with a general workover procedure. If you have any questions or require any further information, please contact me at 265- 6935 or Jake.Voss@conocophillips.com. Sincerely, Jacob Voss Wells Engineer CPAI Drilling and Wells KUP PROD 1D-102 Drt._ Con ocoPhillips .w , ,Well Attributes Max Angle&role TO Alaska,Inc Wellbore API/UWI Field Name Wellbore Status ncl(") MD(ftKB) Act Btm(ftKB) ,..,,a1 ,, 500292296000 WEST SAK PROD 93.76 6,304.31 7,378.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1D-102,10/30120134:14.49 PM SSSV. NIPPLE 20 8/142012 Last WO: 8/21/2011 39.60 6/22/2000 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:PULL JET PUMP,CLOSE CMU, hipshkf 70/30/2013 ......HANGER;27.9 SET IBP 1- '. Casing Strings CHANGER;24.1 ' Casing Description OD(in) ID(in) Top(CAB) Set Depth(ftKB) Set Depth(TVD)...VW/Len(I...Grade Top Thread ppa:1 ll CONDUCTOR 133/8 12415 39.6 110.0 110.0 68.00 L-80 WELDED ✓°J CONDUCTORS,30.8.110.0• II• Casing Description OD fin) ID(in) Top(CAB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade 'Top Thread NIPPLE;517.9 SURFACE 7.875x7 7 5/8 6.875 30.6 4,929.7 3,752.4 29.70 L-80 BTCM Mir Casing Description OD(in) ID(In) Top(CAB) Set Depth(CAB) Set Depth)T/D)... Wt/Len(I...Grade Top Thread WINDOW D 6 6.000 4,368.0 4,383.0 3,568.1 Casing Description OD(in) ID(in) Top MB) Set Depth(ftKB) •Set Depth(TVD)... Wt/Len(I...Grade Top Thread I AB SAND SCREENED 4 3.548 4,778.1 7,357.0 3,7204 9.50 L-80 HSLHT GAS LIFT,2,670.9 I LINER ILiner Details GAS LIFT,3,771.1 I' Nominal ID Top(CAB) Top(ND)(CAB) Top Incl)") Item Des Com (in) WIREGUIDE,3.1730.2 4,778.1 3,733.0 78.50 PACKER BAKER MODEL SC-1R LINER TOP PACKER 70B- 4.000 SLEEVE-C;3.631.4 I II 40 WIREGUIDE:3,635.4is 4,822.8 3,741.6 79.74 SLEEVE BAKER MODEL CMD SLIDING SLEEVE 3.430 1 AR=GAUGE;3,868.5 Tubing Strings Tubing Description 'String Ma...I ID(in) 'Top(ftKB) I Set Depth)ft..1 Set Depth(ND)(...I Wt(lb/ft) I Grade 'Top Connection M TUBING 27/8 2.441 24.4 3,960.51 3,303.8 6.50 L-80 EUE Completion Details SEAL ASSY.3.942.0 '- Nominal ID SBE;3.950.7 Top(CAB) Top(ND)(CAB) Top Incl(") Item Des Corn (in) I24.4 24.4 0.06 HANGER VETCO GRAY 10.75 x 2.875 TUBING HANGER 2.875 517.9 517.7 6.26 NIPPLE CAMCO DS LANDING NIPPLE 2.312 CIRC MANDREL,4.017.6 3,830.2 3,223.9 51.94 WIREGUIDE TEC WIRE GUIDE 2.500 111 3,831.4 3,224.7 51.96 SLEEVE-C BAKER CMU SLIDING SLEEVE w/2.25"D PROFILE 2.250 (CLOSED 4/15/13) SEAL ASSY; 4 PBR;4,08174 4 . 4,074. 3,835.4 3,227.1 52.04'WIREGUIDE TEC WIRE GUIDE 2.500 - PACKER,4,105.4 - 3,888.5 3,259.6 5228 GAUGE GUARDIAN SIDEMOUNT GAUGE CARRIER 2.500 3,942.0 3,292.5 51.98 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 3.000 PLUG,4,125.0 t - Tubing Description I String Ma...ID ID(in) Top(ftKB) 'Set Depth(ft..'Set Depth(TVD)(...I Wt(IdN) I Grade 'Top Connection INNER CASING 512 4.950 27.9 4296.1 3,514.0 15.50 L-80 BTCM Completion Details Nominal ID Top(ftKB) Top(ND)(CAB) Top Incl(°) Item Des Corn (in) PACKER;4.250.2 - 27.9 27.9 0.06 HANGER VETCO GRAY CSG HANGER 5.500 III3,950.8 3,297.8 51.93 SBE BAKER 80-40 SEAL BORE EXTENSION 4000 SOS;4,295.3 II) 3,970.1 3,309.8 51.59 XO Reducing 5.5"x3.5" 3.500 ( f1 3,975.0 3,312.9 51.50 XO Reducing 3.5"x2.875" 2.875 WINDOW D;4,366 0-4,383.0 ' 4,066.7 3,370.9 50.39 XO Enlarging 2.875"x3.5" 2.875 JUNK;4,363.0 _ _ 4,074.4 3,375.8 50.49 SEAL ASSY BAKER LOCATOR SEAL ASSEMBLY 3.000 4,081.7 3,3805 50.59 PBR BAKER 80-40 PBR 4.000 ' , 4,105.4 3,3955 50.92 PACKER BAKER PREMIER PACKER 2.875 Itr 4,250.2 3,485.4 51.83 PACKER BAKER PREMIER PACKER 2.875 ` 4,2620 3,4927 51.55 XO Reducing 3.5"x2.875" 2.875 SURFACE 787527;30.6- f. 4.295.3 3,513.5 51.35 SOS WLEG ALUMINUM BALL SEAT SHEAR SUB 2.441 4.929.7- Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) mm Top(ND) Top Incl MI Top(CAB) (CAB) I") Des Corn Run Date ID(in) i 4,1250' 3,407.8 51.19 PLUG 2.125"IBP @ 4125(OAL=46.5') 10/29/2013 0.000 Mb 4,363.0 3,555.7 51.51 JUNK 5 1/4"HALF MOON LIB INDICATES TOP OF JOINT 4/27/2008 0.000 i 4/30/2008 ilk Perforations&Slots Shot - i Dens Top(TVD) Btm(TVD) (shotslf In Top(ftKB) Btm(CAB) (ftKB) (ftKB) Zone Date t) Type Com 4,925.0 7,256.7 3,752.2 3,722.1 WS B,AS A4, 6222000 50.0 SLOTS Perfs thru screens WS A3,WS 11111 A2,WSA1,1D Mil -102 MI i Mandrel Inserts Mb St ' Mk ati C on Top(TVD) Valve Latch Port Size TRO Run MN No Top(CAB) (CAB) Make Model OD(in) Sery Type Type (in) (psi) Run Date m SLOTS,4,9250-7,2567- i 1 2,670.9 2,507.5 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 10/18/2011 2 3,771.1 3,187.0 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 8/20/2011 ilew 3 4,017.6 3,339.6 CAMCO KBMG 1 CHEM DMY BK-5 0.000 0.0 10/22/2011 Notes:General&Safety End Date Annotation 3/5/2001 NOTE:MULTI-LATERAL WELL NB-Sand(1D-102),D-Sand(1D-102L1) Mil 11/8/2003 NOTE:ESP WORKOVER 9/17/2005 NOTE:ESP WORKOVER 12/28/2005 NOTE:ESP WORKOVER MIMI 5/6/2008 NOTE:ESP WORKOVER 6/17/2008 NOTE:VIEW WITH Alaska Schematic9.0 5/3/2009 NOTE:ESP WORKOVER 8/21/2011 NOTE:WELL CONVERTED FROM ESP TO GAS LIFT w/JET PUMP IIM ENE NB SAND SCREENED LINER; 4,778.1-7,3570 1D-102 Rig Workover Pull and Replace 2-7/8" JP Completion and 5-1/2" Inner Casing (PTD #: 200-075) Current Status: West Sak Jet Pump producer 1D-102 was SI April 2013.The well is shut in due to a tubing leak at 3,889' MD, located by a leak detect log on 5/24/2013.The well passed a MITOA to 1800 psi in September 2013. In October 2013, a plug was set in the tubing tail and the well passed a CMIT. Scope of Work: Pull the existing 277/8"EUE Jet Pump completion,pull and rjace the 5-1/2"BTCM casing string, install new 2-7/8"EUE Jet Pump Completion. General Well info: MASP: 1,284 psi(using 0.1 psi/ft gas gradient and SBHP listed below) Reservoir pressure/TVD: West Sak-Sands— 1,610 psi/3,259'TVD(9.50 ppg EMW)measured 10/27/2013 with downhole gauge. Wellhead type/pressure rating: Vetco Gray Horizontal, 11"5M psi top flange Nordic 3 BOP Config: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Ram MIT results: CMIT TxIA—Passed 10/29/2013 MIT-OA—Passed 9/20/2013 Well Type: Producer Estimated Start Date: February 7,2014 Production Engineers: Amanda Patterson Workover Engineer: Jacob Voss(265-6935/Jake.Voss@conocophillips.com) Proposed Pre-Rig Work: 1. RU Slickline: a. RIH and set catcher b. RIH and pull DV in GLM#3 at 4,018' MD c. RIH and pull catcher sub d. RIH and open CMU at 3,831' MD e. RIH, lightly tag top of IBP. f. Dump bail—20 ft of CaCO3(or sand)on top of IBP. Allow enough time to settle. g. Tag top of sand in tubing. h. RDMO. 2. Bleed gas from Tbg and IA, fluid pack annulus with diesel 3. Set BPV w/i 24 hrs of rig arrival. Proposed Procedure: 1. MIRU 2. Pull BPV. Load well with 9.6 ppg NaCl brine.Ensure well is dead. 3. Install BPV. ND tree. 4. NU BOPE. Install the blanking plug. Test BOPE to 250/3,000 psi. .L 5. Pull the blanking plug. Pull the BPV. 6. BOLDS,un-land tubing hanger and pull to the floor. 7. POOH laying down tubing and spooling Tec Wire. 8. Circulate to condition KWF around 5-1/2"annulus. n , 9. BOLDS,un-land casing hanger, and pull to the floor. 10. POOH laying down casing. 11. RIH with new 5-1/2"BTCM casing and seal assembly to PBR at 4,082' MD,bullhead diesel down the annulus. 12. Land 5-1/2"casing hanger,RILDS. Pressure test annulus to 2500 psi. 13. Run new 2-7/8"Fusion Bonded Epoxy Tubing and Jet Pump completion w/downhole gauge and seal assembly. Proposed Procedure Continued: 14. Sting into SBE. Space out,mark the pipe,pull seals from SBE,circulate well full of CI brine,space out seals. 15. MU tubing hanger. Splice TEC wire to penetrator.Land the hanger and RILDS. 16. PT tubing to 3,500 psi. Pressure test the IA to 3,500 psi for 30 minutes and record casing pressure test on chart recorder. 17. Bleed T and IA. Shear the SOV. Bleed tubing and IA pressures to zero. Monitor for flow. 18. Pull landing joint. Drain stack,remove side-port isolation sleeve. Set two-way check. 19. ND BOP stack,NU tree and test,pull two-way check. 20. Freeze protect w/diesel. Set BPV. 21. RDMO Nordic 3. Proposed Post-Rig Work: 1. Pull BPV. 2. RU Slickline. a. Replace SOV w/DV. b. RIH and open CMU c. Install Jet Pump 3. RD Slickline 4. Reset well house(s)and flowlines of adjacent wells. 5. Handoff to operations. • J ConocoPhillips West Sak Well: 1D-102 2014 RWO PROPOSED COMPLETION API: 500292296000L Conductor: PTD: 200-075 / 13.375", 68#, L-80 at 110' Wellhead: Gray Horiz (`os X-mas Tree: 3-1/8", 5K psi J Surface Casing: Lift Threads: 3.725" MCA 7.625", 29.7#, L-80 to 4175' BPV: 3"'H' 7", 26#, L-80 from 4175'to 4929' RMLS Junction at 4,369' MD Proposed 2'/8" Completion •Fusion Bonded Epoxy(FBE)Tubing *2%",6.5#, L-80,8rd EUE •2.313"DS-nipple at 500' •2'/8"KBMG-1"GLV J •2%8"KBMG-1"GLV c"^" ♦ CMU Sliding Sleeve at 3830'RKB •2%8"CMU Sliding Sleeve w/2.25"D profile. •Guardian Pressure Gauge. 4 Guardian Sidemount Gauge Carrier •XO from 2%8"EUE to3'/:"EUE. 9 •80-40 GBH-22 LTSA Seal Assy.for 20'SBE. 410.0. 4 80-40 Seal Assy/SBE @-3942 `I Proposed 5'/2" Inner Csg. String J 4 2-7/8"GLM(circ.mandrel) •Casing=5W,15.5#, L-80,BTCM-SCC. -v' •XO from 5'/z'BTCM-SCC to 5"BTCM. 46.0. -4- Seal Assy/PBR @ •20'SBE,5"BTCM. 111--3-1/2"x 7-5/8"Premier Packer @ 4105'RKB •XO from 5"BTCM to 2W EUE. ' ><�� 3-1/2"x 7"Premier Packer @ 4250'RKB •2'/e'EUE Tubing w/Circ.Mandrel. 2-7/8"EUE Tbg Tail w/SOS&WLEG •XO from 2'/d'EUE to 3W EUE. / 5°s •Baker locator w/seal assy. RMLS Jxn @ 4369'RKB Bakerweld Pre-pack screens: 4'x 4.5",Alt. screen/blank liners Last Updated: 6-Jan-13 Updated by: Jake Voss Zoo- o75 • • 21)4o\ WELL LOG TRANSMITTAL DATA LOGGED O/0/2013 M K BENDER To: Alaska Oil and Gas Conservation Comm. September 30, 2013 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RECETVED OCT 10 RE: Multi Finger Caliper(MFC): 1D-102 OOC f` Run Date: 9/25/2013 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Matthew Cook, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage,AK 99518 matthew.cook@halliburton.com 1D-102 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-22960-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Matthew Cook WOOD DEC `1 6900 Arctic Blvd. ��, `+, Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook@halliburton.com Date: V91\0 LA'S Signed: STATE OF ALASKA ALASKA (SAND GAS CONSERVATION COMMISSI• REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Plug F rforations f Stimulate r Other ry ESP to Jet Pump Alter Casing p- Rill Tubing 17 Perforate New Pool r Waiver r Time Extension r Change Approved Program j"•" Operat. Shutdown r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r i 200 -075 3. Address: 6. API Number: Stratigraphic - Service f P. O. Box 100360, Anchorage, Alaska 99510 • 50 - 029 - 22960 - 00"' 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25650 r _1D 9. Field /Pool(s): r Kuparuk River Field / West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 7378 feet Plugs (measured) None true vertical 3721 feet Junk (measured) 4363 Effective Depth measured 7357 feet Packer (measured) 4105, 4250, 4778 true vertical 3720 feet (true vertucal) 3395, 3485, 3733 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 13.375 110 110 SURFACE 4145 7.625 4175 3439' SURFACE 754 7 4929 3752' LINER 2579 4.5" / 4" 7357 3720' RECEIV Perforation depth: Measured depth: 4778' - 7357' } t rg "ir, t" +4,,,,j ' r .` '? [�'E SEP 2011 f.. True Vertical Depth: 3733' -3721' ' .. Alaska Oil & Gas Ca ns. Comrrris Ancnorag© Tubing (size, grade, MD, and TVD) 2.875, L -80, 3961 MD, 3302 TVD Packers & SSSV (type, MD, and TVD) 2 BAKER PREMIER PKRS @ 4105' MD and 4250' MD, BAKER LINER TOP PKR @ 4778' MD CAMCO 'DS' LANDING NIPPLE @ 518' MD I 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut - Subsequent to operation shut - 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development (;r` , Service E Stratigraphic r 15. Well Status after work: Oil,r 7 Gas r WDSPL E Daily Report of Well Operations _XXX GSTOR r WINJ E WAG r GINJ r SUSP r SPLUG E 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -234 Contact Brett Packer ( 265 -6845 Printed Name Brett Packer Title Wells Engineer Signature -1 Phone: 265 -6845 Date l'/ ?BGMS SEP 0 9 20— 9'22'11 Form 10-404 Revised 10/2010 " � �I Submit Original Only �Q tr� a. KU 1 D - 102 C �Pb1�N� Wei Attributes Max Angle & MD TD } Wellbore APUUWI Field Name (Well Status Inc!(°) IMD (ftKB) Act Btm Afal'IL h'iC' 500292296000 'WEST SAK 1 1 PROD 9336 6,304 31 7,378.0 Ciro,R9,10 Comment �H2S (ppm) [Date Annotation 'End Date 17 OD Ri g Release Date SSSV: NIPPLE 0 L 8/7/2009 ( Last WO 1 5/3/2009 39.60 6/22/2000 ._Well Cenfg - twiQ 0l1 a 35:59 PM ... - - -- $n .,..44 l Annotation I Depth (ftKB) !End Date [Annotation TL st Mod .. End Date Casing 5, o Last Tag: I- Rev Reason WORKOVER (Imam 9/7/2011 HANGER I Casing Strings y Casing Description String 0... String ID ._ Top (ftKB) Set Depth (f..- Set Depth (TVD) String Wt... Str g Sting Top Thrd CONDUCTOR 133/8 12.415 39.6 110.0 110.0 68.00 L80 WELDED HANGER 2s -- : - -.M Casing Description Siting 0... String ID... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd colvdua0 - CTOR. P- _ 6 SURFACE 7.875x7 7 5/8 6.875 30.6 4,929.7 3,752.8 29.70 L BTCM 110 Casing Description String 0... String ID... Top (BKB) Set Depth (E.. Set Depth (IVO) ... String Wt... String ... String Top Thrd NIPPLE, 518 WINDOW 6 6.000 4,368.0 4,383.0 3,568.1 ._ C asing Description String 0... String ID ... Top (ftKB) Set Depth (L.. Set Depth MAD) ... String Wt... String ... String Top Thrd A/B SAND LINER 4 3.548 4,778.1 7,357.0 3,720S 9.50 L HSLHT GAS LIFT, 45x4 :MOM- 2,671 � 'Liner Details . • To Depth' GAS LIFT � z (TVD) Top Intl Nomi... WIREGUIDE, 1 Top(0KB) MKS) r) Item Description Comment ID (in) 3 4,778.1 3,733.0 78.50 PACKER BAKER MODEL SC - 1R LINER TOP PACKER 709 4.000 SLEEVE - C, 3.831 NM 4,822.8 3,741.6 79.74 SLEEVE BAKER MODEL CMD SLIDING SLEEVE 3.430 WIREGUIDE, w Ems 3,835 sfel Tubing Strings Tubing Description (String 0... iString ID Top (ftKB) Set Depth (1.. 'Set Depth (ND) .. String Wt._ [Str g ... Sting Top Thrd GAUGE, 3,669 - JET PUMP 27/8 ( 2.441 _ 24.4 39605 3,301.5 6.50 1 L80 EUE MOPE SW IV Completion Details Top Depth SEAL ASSY,"'' (ND) Top Intl 3,942 Top (ftKB) (ftKB) (1 Item Description Comment ID (!n) SBE, 3,942 --- 24.4 24.4 -0.02 HANGER VETCO GRAY 10.75 x 2.875 TUBING HANGER 2.875 517.9 517.7 6.26 NIPPLE CAMCO DS LANDING NIPPLE 2.312 505 LIFT 3,830.2 3,224.1 52.62 WIREGUIDE TEC WIRE GUIDE 2.500 a,018 3,831.4 3,224.8 52.61 SLEEVE -C BAKER CMU SLIDING SLEEVE w/ 2.25" D PROFILE (CLOSED) 2250 SEAL ASSY, __, 3,835.4 3,227.2 52.59 WIREGUIDE TEC WIRE GUIDE 2.500 4,082 '_ -- PBR, d,082 - - 3 3,259.6 52.28 GAUGE GUARDIAN SIDEMOUNT GAUGE CARRIER 2.500 - PACKER, 4,105 3,942.0 3,292.5 51.98 SEAL ASSY BAKER 80-40 SEAL ASSEMBLY 3.000 II I Tubing Description String 0... String ID ... ITOp (ftKB) Set Depth (f... Set Depth (TVD) ... Sting Wt... Sting ... String Top Thrd INNER CASING 5 1/2 4 . 950 27.9 4,296.0 3,514.0 15.50 L -80 BTC -M 5x3 5x2.875 Completion Details Top Depth PACKER, 4,250 - -' - - (1/0) Top Inc! Nomi... Top (fIKB) OMB) (°) Item Description Comm ent ID (in) 27.9 27.9 - 0.01 HANGER VETCO GRAY CASING HANGER 4.950 SOS, 4,295 3,95117 3,297.8 51.93 SBE BAKER 80-40 SEAL BORE EXTENSION 4.000 WINDOW, :;. 3,970.0 3,307.8 49.06 XO Reducing CROSSOVER SUB 5 x 3.5 3.000 -v 4,3684,383 -- .. JUNK, 4,363 - 3,974.9 3,311.1 49.12 XO Reducing CROSSOVER SUB 3.5 x 2.875 2.875 4,066.6 3,370.9 50.38 X0 Enlarging CROSSOVER SUB 2.875 x 3.5 3.500 4,074.3 3,375.7 50.49 SEAL ASSY BAKER 80-40 LOCATOR SEAL ASSEMBLY 3.000 4,081.6 3,380.3 50.59 PBR BAKER 80-40 PBR 4.000 4,105.4 3,3953 50.92 PACKER BAKER PREMIER PACKER 2.875 4,25111 3,4852 51.00 PACKER BAKER PREMIER PACKER 2.870 a. ,x. -- -- . - •.r ■ 9 '' 4,261.9 3,492.6 51.10 XO Reducing CROSSOVER SUB 3.5 x 2.875 2.875 SURFACE a ;� 4,295 .2 3,513.5 51.48 SOS WLEG ALUMINUM BALL SEAT SHEAR SUB 1/2 MULESHOE 2.440 31875X7. - .... -,. 314,930 1. > 6 �- Other In Hole reline retrievable plugs, valves, pumps, fish, etc.) Top Depth (ND) Top Intl . (ftKB) ( ") _ Description Comment Run Date ID (In) _ _.. 4,363 3,555.7 51.10 JUNK 5 1/4" HALF MOON LIB INDICATES TOP OF JOINT 4/27/2008 0.000 4/30'2008 Perforations & Slots j i Shot Top (TVD) Btm (TVD) Dens Top (fIKB) Ban (181(13) (ftKB) (ftKB) Zone Date (sh... Type Comment 4,925 7,357 3,752.8 3,7205 WS B, AS A4, 6/22/2000 50.0 SLOTS Pens thru screens .. WS A3, WS A2, W5A1, 1D -102 Notes: General &Safety EndDate Annotation 3/5/2001 NOTE Multilateral well. A/B -Sand (1D -102), D -Sand (1 D 102L1) 6/17/2008 NOTE: VIEW WITH Alaska Schematic9.0 SLOTS, 4,925 -7,357 I ■ Mandrel Details Top Depth Top Port ,. (TVD) Intl OD Valve Latch Size TRO Run ...K Stn Top (fIK8) (81U3) ( °) Make Model (in) Sere Type Type (lei (Ps) Run Date Cam... 1 2,670.9 2,507.6 51.11 CAMCO KBMG 1 GAS LIFT SOV BEK 0.000 0.0 8/20/2011 2 3,771.1 3,188.6 52.96 CAMCO KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 8/20/2011 3 4,017.5 3,339.3 49.71 CAMCO KBMG 1 GAS LIFT DMY BK -5 0.000 0.0 8/19/2011 _ A SAND .. A63 LINER4.5x4, 4,778 -7,357 MOD-102), 7,378 1D-102 Well Work Summary DATE , SUMMARY 8/7/11 PULLED 4 1/2 SLIP STOP @ 35880M, SET 4 1/2 D &D TEST TOOL W/ BAIT AS CATCHER, ATTEMPTED TO PULL 1" SOV @ 3509' RKB, SOV POSS. OUT OF POCKET, IMPRESSION BLOCK INDICATES SAME. DRIFT TBG TO BAIT SUB CATCHER W/ 3.69" IMPRESSION BLOCK TBG OPEN, SWEEP GLM'S W/ 2.62" IMPRESSION BLOCK UNABLE TO FIND MISSING VLV, ATTEMPT TO SET 1" BTM LATCH DMY @ 3509' RKB. IN PROGRESS. 8/8/11 RAN 1.22" LIB ON KOT LIB SHOWS 1/2 MOON OF POCKET, RAN KOT & RUNNING TOOL MARKS ON TOOL INDICATE VLV PARTLY OUT OF POCKET, WORKED 1" SOV BACK INTO POCKET. MIT TBG TO 1500 PSI GOOD TEST, PULLED 4 1/2 D &D TEST TOOL @ 3605' RKB, DRIFTED TBG OPEN TO 3.845" DOWN TO 3605' RKB, MADE SEVERAL ATTEMPTS TO PULL 4 1/2 PACKOFF ASSEMBLY @ 3605' RKB. IN PROGRESS. 8/9/11 MADE SEVERAL ATTEMPTS TO PULL 4 -1/2" PACKOFF © 3605' RKB, NO SUCCESS. PULLED SOV a 3509' RKB, LEFT GLM OPEN. CALLED FOR BPV. 8/10/11 PRE RWO, VIOD -PPPOT (PASSED), UPPER T -PPPOT (PASSED), LOWER -PPPOT (PASSED), GRAYLOC- PPPOT (PASSED) FT -LDS ALL NORMAL. • • Conoc ©Phillips Time Log & Summary We/Niew Web Reporting Report Well Name: 1D Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 8/12/2011 3:30:00 PM Rig Release: 8/21/2011 2:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08/10/2011 24 hr Summary Disconnect from Shore Power. Clean location and button up misc small projects. Prep and stage Rig at pad entrance in preparation for move to 1D-102 15:00 22:30 7.50 DEMOB MOVE DMOB P Prep for Move to 1D-102. Disconnect from Shore Power. Pick up plywood, secure tools, breakdown containment and button up misc small projects while waiting on Rig Mat delivery f/ Nabors in Prudhoe. 22:30 00:00 1.50 DEMOB MOVE DMOB P Rig Mats on location. Jack up Rig, Move off mats, clean area and spot Rig at pad entrance in preparation for Rig move. 08/11/2011 Continue Rig Move 1C pad to 1D-102 00:00 01:30 1.50 DEMOB MOVE SFTY P PJSM- Rig Move 1C pad to 1D-102. Continue laying down mats. Pre trip inspection of rig. 01:30 00:00 22.50 DEMOB MOVE TRNS P Security notified and announced. Move off 1C pad. Destination 1D-102. 08/12/2011 Continue Rig Move 1C pad to 1D-102. Build 11" 5M BOPE. Spot Rig over well. Accept Rig @ 15:30 hrs. MIRU all support equipment. Pull BPV. Pressure Test hard line, manifold and hoses 250/3500. 00:00 05:00 5.00 DEMOB MOVE TRNS P Continue Rig Move 1C pad to 1D -102 05:00 07:00 2.00 DEMOB MOVE TRNS P Standby at KIC for field wide change out. 07:00 08:00 1.00 DEMOB MOVE TRNS P Continue with Rig move towards 10-pad. 08:00 09:00 1.00 DEMOB MOVE TRNS P Shuffle Mats to Culvert and stage. 09:00 12:00 3.00 DEMOB MOVE TRNS P Continue with Rig move towards 1D-pad. 12:00 14:30 2.50 MIRU MOVE PULD P PJSM. Load 11" BOPE back inside Cellar. Hang Tree and Casing Head. Spot Rig. 14:30 15:30 1.00 MIRU MOVE OTHR P Move Rio over 10-102. spot and level Rig. Accept Rig at 15:30 P.M. 15:30 23:00 7.50 MIRU WELCTL RURD P Set up berm around cellar, Spot Cuttings Box, Boiler Blow Down Box, Used oil tank and Kill tank. RU hard line to Kill Tank and hoses in cellar. Bring in BPV lubricator and equipment and Test Joints. 23:00 23:30 0.50 MIRU WHDBO KLWL P Lubricate and pull BPV. 23:30 00:00 0.50 MIRU WELCTL KLWL P Pressure test hard line and manifold 250/3500. Page 1 of 9 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08/13/2011 24 hr Summary Circulate surface to surface 8.6 ppg 60° filtered Seawater with 3% KCI. Set BPV. ND Tree. NU BOPE and begin test. 00:00 00:30 0.50 COMPZ WELCTL SFTY P PJSM- Circulating out well. 00:30 02:00 1.50 COMPZ WELCTL KLWL P Start circulating 8.6 ppq- 160° filtered seawater A 3 bpm, clean, hot 8.43 ppg returns at 180 bbls. ICP 140 psi, FCP 120 psi with 1:1 returns. 02:00 02:30 0.50 COMPZ WELCTL KLWL P Shut in and monitor well, initial SITP 10 psi, slight pressure increase to 20 psi in 30 min. 02:30 04:00 1.50 COMPZ WELCTL KLWL P Circulate last 100 bbls hot filtered 8.6 ppg seawater. ICP 140 psi, FCP 180 psi. 1:1 returns. 04:00 05:00 1.00 COMPZ WELCTL KLWL P Shut in and Monitor well, SITP 0 psi, IA 0 psi, returns hot and clean. no pressure increase in 30 minutes but still have flow. off load 60° 8.6 ppg seawater to pits. 05:00 07:00 2.00 COMPZ WELCTL KLWL P Circulate 150 bbls 8.6 ppg 60° seawater, 1:1 returns to outside / tank. ICP 170 psi, FCP 140 psi.. Monitor well for 30 mins. 07:00 07:30 0.50 COMPZ WELCTL KLWL P Install Type "H" BPV. 07:30 09:30 2.00 COMPZ WELLPF NUND P PJSM. N/D Tree and remove from cellar. Inspect Lifting threads. All Good. 09:30 19:00 9.50 COMPZ WELLPF NUND P PJSM. N/U BOPE. Install 2 7/8" x 5" , VPR's in lower set and 3 1/2" Fixed in upper set. 19:00 21:30 2.50 COMPZ WELLPF BOPE T Attempt Shell test BOPE, found leak at kill line grayloc at mezzanine. replace seal in grayloc. 21:30 22:00 0.50 COMPZ WELLPF BOPE T Attempt Shell test failed, trace leak to block valve at manifold, change out block valve and get passing Shell test. 22:00 00:00 2.00 COMPZ WELLPF BOPE P Begin BOPE test 250/3500. Annular 250/3000. 08/14/2011 Continue BOPE test. Pull Blanking Plug and BPV. Pull Hanger to floor, LD same. POOH laying down 4.5" Tubing Spooling back ESP cable / TEC wire / Heat Trace. PU MU Clean Out and Casing Drift assembly. P{"k. 00:00 03:00 3.00 COMPZ WELLPF BOPE P BOPE test 250/3500. Annular 250/3000. 03:00 04:00 1.00 COMPZ WELLPF OTHR P Pull Blanking Plug and BPV. Install Side Isolation Sleeve. 04:00 05:30 1.50 COMPZ WELLPF OWFF P Monitor well for flow. Bring in small spooler and empty spool and Centalift equipment. Prep floors for 4 1/2 equipment. Well Static. 05:30 06:15 0.75 COMPZ RPCOM SFTY P PJSM w/ Centralift Reps. Pulling ESP Completion, Non Standard Procedure. 06:15 07:15 1.00 COMPZ RPCOM OTHR P Hang ESP and Heat Trace Sheave for Both. Check For Flow and Psi on Well. Check All Audio Alarms on Rig. Page 2of9 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:15 09:00 1.75 COMPZ RPCOM PULL P Un -seat Hanger at 210k, free weight at 98k. Continue up hole with hanger and measure distance from mark on rotary table to landing joint. ( 27'.4 "). Pull one full stand and rig up heat trace and ESP cable to spoolers. Remove Penetrator, L/D hanger and landing joint. 09:00 15:00 6.00 3,694 107 COMPZ RPCOM TRIP P PJSM. POOH standing bank 4 1/2" _ De- Completion while removing ESP clamps. Up Wt 98k 15:00 15:15 0.25 107 107 COMPZ RPCOM SFTY P PJSM. Discuss Hazard of Removing ESP from 4.5" Completion. 15:15 16:00 0.75 107 0 COMPZ RPCOM PULL P Able to remove 4 1/2" Completion. Pack -off assembly was stuck inside tubing. 16:00 21:30 5.50 0 0 COMPZ RPCOM PULL P Pulled and dis- assemble lower section of ESP. Take samples, Box ESP equipment and Kick out. No clamps or bands missing. 5 mid -joint dual - channel HT clamps= 454 4' mid -joint dual - channel HT clamps= 11 3' mid -joint dual - channel HT clamps= 10 2' mid joint dual - channel HT clamps= 7 Dual- channel cross - coupling clamps= 98 Single- channel cross - coupling clamps= 20 Stainless -steel flat bands= 22 Flat gaurds= 4 Protectolizers= 3 21:30 22:00 0.50 0 0 COMPZ WELLPF OTHR P Change over Floors 22:00 00:00 2.00 0 0 COMPZ WELLPF PULD P Bring in Baker Clean Out tools. Set Wear Ring. PU MU BHA #1 as per Baker Rep. X8/15/2011 RIH w/ Clean Out - Casing Drift assembly to 4,224 -ft, Clean out to 4,353 -ft. POOH standing back DP, LD & KO BHA #1. PU MU and RIH w/ Surface Casing Pressure Test assembly and set Top of RBP at 4,247 -ft. Test 7" RBP to Test Packer at 4,036 -ft to 1500 psi, failed, 60 psi loss in 15 minutes. Test Backside to Test Packer at 4,036 -ft to 1500 psi, failed, 60 psi loss in 15 minutes. Move Test Packer down to 4,046 -ft, test same. Release Test Packer and Test Casing to RBP. Appears to be surface leak. 00:00 01:30 1.50 0 0 COMPZ RPCOM PULD P PU MU BHA #1 as per Baker Rep 01:30 03:00 1.50 0 209 COMPZ RPCOM PULD P Bring in 4 3/4 Drill Collars, strap and continue PU MU of Clean Out assembly. 6" OD smooth body concave mill, 1 jt. DP, 6" OD string mill, magnet, oil jar, 4 ea. DC's, 7 5/8" casing scraper, dual boot baskets and pump out sub. 03:00 06:30 3.50 209 4,224 COMPZ RPCOM TRIP P RIH w/ BHA #1 on 3 1/2" Drill Pipe (Single In) Page 3 of 9 • S Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:30 08:30 2.00 4,224 4,261 COMPZ RPCOM CIRC P Set Down with Drift assembly at 4,224 -ft. Start Circulating and Rotating thru fill. Clean to 4,261 -ft. PUH 1 joint and CBU at 6 bpm, 760 psi,until return are clean and good 8.6 ppg fluid is seen at surface. 08:30 09:30 1.00 4,261 4,353 COMPZ RPCOM CIRC P Continue to Circulate down to 4,353 -ft at 6 bpm, 740 psi, 09:30 12:00 2.50 4,353 4,353 COMPZ RPCOM CIRC P Clean down to target depth at 4,353 -ft, circulate a 25 bbl High -Vis sweep and CBU until returns are clean. Pump rate 8 bpm, 950 psi. Return Not cleaning up very well. CBU again. Load Baker Testing Equipment to rig floor. 12:00 15:00 3.00 4,353 200 COMPZ RPCOM TRIP P Seen good clean 8.6 ppg fluid at surface. Start POOH standing back DP while keeping hole full. Up Wt 108k, Down Wt 72k. 15:00 16:30 1.50 200 0 COMPZ RPCOM PULD P BHA at surface. PJSM. Lay down Clean Out Assembly. 16:30 17:30 1.00 0 128 COMPZ RPCOM PULD P PJSM. PU MU Surface Casing Test Assembly. 7" Model 'G' RBP, Model 'L' Retrieving Head, 3 joints DP, 7 5/8" Retrievamatic Test Packer. BHA #2 17:30 22:00 4.50 128 4,247 COMPZ RPCOM TRIP P RIH with BHA #2 on DP and set Top of RBP at 4,247 -ft (Top of Test Packer at 4,132 -ft) Up wt 98k, Dn wt 70k. 22:00 00:00 2.00 4,247 4,161 COMPZ RPCOM PRTS P PUH 1 stand, Circulate down DP 31 bbls 3 bpm at 110 psi. Set Top of Test Packer at 4,036 -ft. Attempt test RBP 1500 pi, failed, lost 100 psi in 15 minutes, appears to be linier. Attempt Test Backside to 1500 psi, same results 100 psi in 15 minutes. Release Test Packer, RIH and Set @ 4,046 -ft, Attempt tests botn screw with samr results. Release test Packer and test Backside to RBP to 1500 psi. 08/16/2011 Reset RBP up hole at 4,237 -ft. Test Backside from Top of Test Packer at 4,107 -ft to 1500 psi, Ppssed. Unable to obtain Test from Test Packer @ 4,107 -ft to RBP at 4,237 -ft, Leak off rate 60 psi every 15 minutes. Dump Sand on RBP. POOH Standing back 10 joints DP, Single out remainder of DP. LD KO BHA #2. Run Micro - Vertilog from 4,180 -ft to surface. ND Riser. NU shooting Flange. Run Caliper /MTT /GR /CCL log from 4,228 -ft to surface. 00:00 00:30 0.50 4,161 4,161 COMPZ RPCOM PRTS P Release test Packer and test Backside to RBP to 1500 psi. steady leak off rate 120 psi in 30 min. Confer w/ Town Rep. Page 4 of 9 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 02:00 1.50 4,161 4,237 COMPZ RPCOM PRTS P RBIH to 4,247 -ft, release RBP and reset RBP Top at 4,237 -ft. PUH 15' with Test Packer 4,127 -ft to 4,107 -ft and set. Attempt test between plugs, failed, same leak off rate. Pressure test Backside 1,450 psi good, Flat line 25 minutes, All tests Charted. 02:00 04:00 2.00 4,237 4,219 COMPZ RPCOM PRTS P PUH and reset Test Packer na. 4,103 -ft, set in slips, Kelly down and hook up direct to DP. Attempt Pressure Test between Plugs, same 60 psi in 15 minutes, 120 psi in 30 minutes leak off rate. 04:00 04:30 0.50 4,219 4,193 COMPZ RPCOM OTHR P Unseat Test Packer PUH 1 Joint and dump 300 lb sand on RBP at _ 4, 237 -ft. 04:30 05:30 1.00 4,193 4,193 COMPZ RPCOM OTHR Allow sand to drop. BD Top Drive 05:30 06:00 0.50 4,193 4,228 COMPZ RPCOM TRIP P RIH and Tag Top of Sand at 4,228 -ft 06:00 10:00 4.00 4,231 0 COMPZ RPCOM TRIP P POOH standing back first 10 stands DP, Single out remainder of DP, LD and KO BHA #2 and DP. 10:00 12:00 2.00 0 0 COMPZ EVALWE SFTY P PJSM- Bring in Wireline tools and equipment. RU Wireline. 12:00 13:00 1.00 0 4,180 COMPZ EVALWE ELOG P RIH w/ Micro Vertilog / GR /CCL. Log up from 4,180 -ft to surface. 13:00 14:00 1.00 4,180 0 COMPZ EVALWE OTHR P LD and off load Micro Vertilog tools 14:00 17:00 3.00 0 0 COMPZ WELCTI NUND P PJSM- ND riser and NU Shooting Flange 17:00 18:00 1.00 0 0 COMPZ EVALWE NUND P Bring in and RU Wireline Lubricator and stripper head. 18:00 00:00 6.00 0 4,228 COMPZ EVALWE ELOG P MU and RIH with Caliper / MTTX / GR / CCL, Log up from 4,228 -ft to surface. Repeat MTTX Log from 270 -ft to surface. J8/17/2011 Run GYRO /GR /CCL log from 4,228 -ft to surface. Run HES CAST -M /GR /CCL from 4,180 -ft to surface. ND Shooting Flange. Run Storm Packer /RBP Retrieval Assembly and set at 100 -ft. Pressure Test 7 5/8" Casing to Storm Packer 3500 psi. 00:00 01:00 1.00 0 270 COMPZ EVALWE ELOG P Repeat MTTX Log from 270 -ft to surface. LD and push out PDS Caliper / HES MTTX / GR / CCL. 01:00 02:00 1.00 270 0 COMPZ EVALWE ELOG P PJSM- Bring in, MU GYRO / GR / CCL. 02:00 07:00 5.00 0 0 COMPZ EVALWE ELOG P RIH w/ GYRO / GR / C.CL and Log up from 4,225 -ft to surface. 07:00 10:30 3.50 0 0 COMPZ EVALWE ELOG P Rehead 5/16" Line through grease injector. Calibrate cast -m tool. 10:30 10:45 0.25 0 0 COMPZ EVALWE SFTY P Held PJSM with rig crew on on rigging up tool string and lubricator. 10:45 14:00 3.25 0 0 COMPZ EVALWE ELOG P Rig up tool string and lubricator. Pressure test lube to 1,000 psi standby for rig to change valve and tighten shooting flange. Pressure test lubricator to 1,000 psi. Page 5 of 9 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 18:00 4.00 0 0 COMPZ EVALWE ELOG P RIH w/ Cast -M tool to 4,207 -ft. Log Cast -M tool in pipe inspection mode to surface. 18:00 20:30 2.50 0 0 COMPZ EVALWE FLOG P Bleed off lubricator and and RD Tools, Lubricator, Sheaves and ND Shooting Flange. NU riser. 20:30 21:00 0.50 0 0 COMPZ WELLPF RURD P RU Floor to run 4 1/2" Tubing 21:00 23:00 2.00 0 948 COMPZ WHDBO TRIP P PU MU RBP retrieving head, 9 stands of 4 1/2 ", 12.6# L -80 IBTM Tubing (843 -ft= 10,620 Ibs) hang below 7 5/8" Model "EA" Retrievamatic Storm Packer assembly. RIH w/ BHA #3 on 1 std DP to set Storm Packer A 100 -ft, bottom of assembly @ 948 -ft. Up wt 48k, Dn wt 50k. POOH w/ Running tools. 23:00 00:00 1.00 0 0 COMPZ WHDBO PRTS P RU and Attempt Pressure test 7 5/8" Casing to Storm Packer to 3500 psi, , slow leak off rate. troubleshoot and attempt again w/ same results. X8/18/2011 Pressure Test Storm Packer. ND BOPE and Tubing Head. NU New 5.5" Casing Head and New Tubing Head. Test ODC connection. NU BOPE. Test Breaks to 250/3500 psi. POOH and LD Storm Packer. RBIH w/ RBP Retrieval head on 4 1/2" Tubing and DP. Circulate out sand. Release RBP and Stand back DP, Single out 4 1/2" Tubing. LD RBP. C/O Pipe Rams to 5 1/2 ". 00:00 01:00 1.00 0 0 COMPZ WHDBO PRTS P Pressure test 7 5/8" Casing to Storm Packer to 3500 psi, Charted and passed. 01:00 02:00 1.00 0 0 COMPZ WHDBO NUND P ND BOPE. 02:00 04:30 2.50 0 0 COMPZ WHDBO NUND P ND Tree head- NU New Casing Head, Tree Head. ODC Adapter tested to 5000 psi for 15 minutes, Passed. Tree orientation verified by DSO (Donna Collins at 04:00) Measure new RKB's. 04:30 08:00 3.50 0 0 COMPZ WHDBO NUND P NU BOPE 08:00 10:00 2.00 0 0 COMPZ WHDBO PRTS P RU and Pressure test New Tubing Spool to CSG head break at 3.500 psi for 20 minutes with no pressure loss. RD Test equipment. 10:00 10:15 0.25 0 0 COMPZ WHDBO SFTY P Held PJSM with Rig crew and Baker Service hand on engaging and releasing Storm packer. RIH and washing sand off RBP and Releasing RBP. 10:15 11:30 1.25 0 0 COMPZ WHDBO MPSP P RIH and Retrieve Storm packer at 100 -ft. and lay down same. 11:30 14:00 2.50 0 4,221 COMPZ WELLPF TRIP P Continue to RIH with 4 1/2 IBTM TBG to 3,442 -ft and Cross over to 3 1/2 DP. Continue to RIH w/ 3 1/2 DP to 4,221 -ft and tag top of sand. Page 6 of 9 • . Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 16:00 2.00 4,221 4,229 COMPZ WELLPF CIRC P MU Top drive and wash down to RBP and engage at 4,229 -ft. Release off RBP and PU 2 -ft, Pump 30 bbl hi visc sweep at 8 bpm at 800 psi taking returns to kill tank with 189 bbls of filtered 3% KCL.Release RBP and let elements relax. 16:00 17:00 1.00 4,229 3,442 COMPZ WELLPF TRIP P POOH standing back 3 1/2 DP to 3,442 -ft. 17:00 22:00 5.00 3,442 0 COMPZ WELLPF PULD P POOH laying down 4 1/2 IBTM TBG and Baker "G" Bridge plug 22:00 00:00 2.00 0 COMPZ WHDBO BOPE P Set Test Plug. Change out Rams to 2 7/8" Upper and 5.5" Lowers 08/19/2011 C/O Pipe Rams to 5 1/2" Lower, 2 7/8" Upper and Test 250/3500. MU PU and RIH w/ 5.5" Casing Completion. Load Annulus and Casing w/ 180 bbls 9.6 ppg inhibited brine. Position and Set Packers. Shear PBR, Space out and land Casing Hanger. Test Annulus 1500 psi. Test Casing Hanger. RD Casing Crew. Bring in 2 7/8" Jet Pump Completion equipment and Tubing, Rack and Tally. 00:00 00:30 0.50 0 0 COMPZ WHDBO BOPE P Continue changing out Rams to 2 7/8" Upper and 5.5" Lowers. 00:30 04:30 4.00 0 0 COMPZ WHDBO BOPE P RU and Test @ 2 7/8" Upper pipe rams 250/3500, Annular 250/3000. Test 5.5" Lower pipe rams 250/3500. 04:30 05:00 0.50 0 0 COMPZ RPCOM SFTY P PJSM- Running 5.5" Inner Casing Completion. Third party Casing crew. 05:00 05:30 0.50 0 0 COMPZ RPCOM OTHR P Change over floor to RIH w/ 2 7/8 and 3 1/2 Tail assy. 05:30 06:30 1.00 0 318 COMPZ RPCOM PUTB P PU MU and RIH w/ Lower Casing Completion as per run order to 318 -ft. 06:30 07:00 0.50 318 318 COMPZ RPCOM OTHR P Change over floor to RIH w/ 5 1/2 Casing 07:00 11:00 4.00 318 4,296 COMPZ RPCOM RNCS P RIH w/ Lower Casing assy from 318 -ft, picking up 5 1/2 Casing to 4,296 -ft. Up wt 110k, Dn wt 75k 11:00 11:15 0.25 4,296 4,296 COMPZ RPCOM SFTY P Held PJSM on spotting CI 9.6 ppg Brine 11:15 14:00 2.75 4,296 4,296 COMPZ RPCOM CIRC P Reverse circulate 80 bbls of CI 9.6 ppg Brine at 3 bpm at 80 psi. Switch to bullhead 100 bbls CI 9.6 ppg Brine down 5 1/2 Casing. ICP at .5 bpm at 950 psi for 2 bbls, then broke down and was able to increase rate to 3 bpm at 500 psi - seen increase to to 800 psi. FCP at 320 psi at 3 bpm. SWI and insert ball. Drop ball and wait for 30 minutes. Pressure up to 1,500 psi and set Premier Packers 7" at 4,250 -ft and 7 5/8" at 4,105 -ft. Slack off from 75k to 70k, pressure up to 3,000 psi and hold pressure for 10 minutes. Bleed off pressure. 14:00 14:30 0.50 4,296 4,296 COMPZ RPCOM PRTS P Pressure test 7 5/8" x 5 1/2" annulus at 1 500 psi for 15 minutes and chart. - Good test. 14:30 15:00 0.50 4,296 4,296 COMPZ RPCOM PACK P Pressure up to 1,500 psi and shear out of PBR at 127k. Page7of9 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 15:45 0.75 4,296 4,088 COMPZ RPCOM HOSO P POOH and lay down Tag joint. PU and MU 10 3/4" x 5 1/2" Casing hanger and landing joint. Land Hanger - seen seals engage PBR 4,074 -ft. RILDS. 15:45 16:00 0.25 4,088 4,088 COMPZ WHDBO PRTS P Pressure test Casing hanger void at 250/5,000 psi 16:00 17:30 1.50 4,088 4,088 COMPZ RPCOM PRTS P Pressure test 7 5/8" x 5 1/2" annulus at 1,500 psi for 15 minutes and chart. - Good test. 17:30 19:00 1.50 4,088 0 COMPZ RPCOM OTHR P LD Landing joint, RD Casing crew, send out tools. 19:00 20:00 1.00 0 0 COMPZ WHDBO BOPE P Change out Lowers to 2 7/8" - 5" VBR's 20:00 21:00 1.00 0 0 COMPZ WHDBO BOPE P Test Lower VBR's 250/3500. RD test equipment. 21:00 23:45 2.75 0 0 COMPZ RPCOM PULD P Bring in remainder of 2 7/8" Tubing and Completion Equipment. Rack and Tally 2 7/8" Tubing. bring in TEC wire spool and spooler. Set up and test Guardian Gauge for installation. 23:45 00:00 0.25 0 0 COMPZ RPCOM SFTY P PJSM- Running 2 7/8" Jet Pump completion. 08/20/2011 PU and RIH w/ 2 7/8" Jet Pump Completion. Space out and MU Tubing Hanger. Circulate well full. Land Tubing Hanger and RILDS. PIT Tubing Hanger Packoff. P/T Tubing and Tubing x Annulus. Shear SOV. ND BOPE. NU Tubing Head Adapter and Tree. Freeze Protect Tubing and IA. 00:00 07:30 7.50 0 3,974 COMPZ RPCOM TRIP P PU and RIH w/ 2 7/8" Jet Pump Completion as per run order. Test and install Guardian Gauge, TEC wire adding Single- channel cross - coupling clamps at each joint. stop just above SBE at Up wt 63k, Dn wt 53k. No -go out at 3,950 -ft with mule shoe at 3,974 -ft. 07:30 09:00 1.50 3,974 3,943 COMPZ RPCOM HOSO P Mark pipe and POOH laying down tag joints. PU 18 -ft of space out pups and TBG hanger with full joint below. MU landing joint. RU circ hose to circulate, lower hanger down to Rotary Table for Tec wire splice. 09:00 10:00 1.00 3,943 3,943 COMPZ RPCOM OTHR P Install Penetrators and and splice Tec wire. MU Tec wire to Penetrator and check installation. - working good. 10:00 11:00 1.00 3,943 3,943 COMPZ RPCOM CIRC P Pump 20 bbl spacer @ 2 bpm @ 320 psi and follow with 114 bbls of CI Sea water at 2 bpm @ 300 psi. 11:00 11:30 0.50 3,943 3,967 COMPZ RPCOM HOSO P Locate seals at SBE at 3,950 -ft, open bleeder and land hanger w/ Mule shoe at 3,967 -ft.. Dn wt 53k RILDS. 11:30 12:30 1.00 3,967 3,967 COMPZ RPCOM PRTS P Pressure test TBG hanger void at 250/5,000 psi for 15 minutes. Page 8 of 9 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:30 14:00 1.50 3,967 3,967 COMPZ RPCOM PRTS P RU Testing equipment to TBG and 2 7/8" x 5 1/2" IA. Pressure up to 2,500 psi on TBG and chart for 15 minutes. No Losses. Leave pressure on TBG and Pressure up on 2 7/8" x 5 1/2" IA to 3,500 psi for 30 minutes. Good test - no losses. Bleed off IA first then follow TBG pressure. Pressure up IA and Shear SOV at 2,000 psi. RD Test equipment. 14:00 14:15 0.25 3,967 3,967 COMPZ RPCOM SFTY P Held PJSM with Crane operator on loading Empty ESP spool. 14:15 14:45 0.50 3,967 3,967 COMPZ RPCOM OTHR P RU crane and load Empty ESP Spool. RD Crane. 14:45 15:15 0.50 3,967 24 COMPZ WHDBO OTHR P Back out Landing jt at 24.45 -ft and recover ISO sleeve. Drain stack and set 3" H - BPV. 15:15 15:30 0.25 24 24 COMPZ WHDBO SFTY P Held PJSM on ND BOPE 15:30 19:30 4.00 24 25 COMPZ WHDBO NUND P Change Upper Rams from 2 7/8 to 3 1/2 Solid Rams. Swap out HCR Valve on kill line. ND BOPE. 19:30 21:30 2.00 25 COMPZ WHDBO NUND P NU tree and accuator, Accuator orientation verified by Ricky Lawless DSO lead. Test Tubing Hanger Packoff 5000 psi, good. 21:30 22:30 1.00 COMPZ WHDBO PRTS P Pressure Test Tree 250/5000 psi, Chart and RD test equipment. 22:30 00:00 1.50 COMPZ WHDBO FRZP P MIRU Little Red Services. Pressure Test Lines and equipment 3500 psi. Pump 70 bbls Diesel Dn IA taking returns to Kill tank. ICP 1850 psi, FCP 2150 psi @ 2 bpm. 08/21/2011 Continue Freeze Protect TBG & IA. Set BPV. Dress Tree. Clean Cellar. RDMO. 00:00 00:30 0.50 0 0 COMPZ WHDBO FRZP P Continur pumping Diesel Freeze Protect Diesel Dn IA taking returns to Kill tank. ICP 1850 psi, FCP 2150 psi @ 2 bpm. Bleed TBG and IA to 0 psi. 00:30 01:30 1.00 0 0 COMPZ WHDBO SEQP P Set BPV. Dress Tree. Clean cellar. 01:30 01:45 0.25 0 0 COMPZ MOVE SFTY P PJSM- Moving on pad well to well. 01:45 02:00 0.25 0 0 COMPZ MOVE MOB P Jack up Rig. Move off mats. Rig Released @ 02:00. Page 9 of 9 • • WELL LOG TRANSMITTAL PROActivE DiA SERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659 -5102 RE : Cased Hole /Open Hole /Mechanical Logs and/or Tubing Inspection(Caliper / MTT) The technical data, listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 . :!t; S,4_ u! Fax: (907) 245 -8952 w } 9 g 3 8 1) Caliper Report 16- Aug -11 1D-102 1 Report / CD 50- 029 - 22960 -00 2) Signed : Date : 1 J c Print Name: \A-0 War k∎- PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)2454951 FAX: (907)245 -8952 E -MAIL : PDSANCHORAGEOMEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:\ Archives\ Distribution\ TransmittalSheets \ConocoPhillips Transmit.docx 0 2 0 0 . OAS II • • I Pi ilio Multi-Finger Caliper Log Results Summary 1 Company: ConocoPhillips Alaska, Inc. Well: 1D -102 Log Date: August 16, 2011 Field: Kuparuk (West Sak) I Log No.: 6869 State: Alaska Run No.: 2 (1 x MTT, 1 x MIT) API No.: 50- 029 - 22960 -00 Pipet Desc.: 7.625" 29.7 Ib. L-80 BTCM Top Log Intvll.: Surface Pipet Use: Surface Casing Bot. Log Intvll.: 4,185 Ft. (MD) I Pipe2 Desc.: 7" 26 Ib. L -80 BTCM Pipe2 Use: Surface Casing Top Log Intv12.: 4,185 Ft. (MD) Bot. Log Intv12.: 4,221 Ft. (MD) Inspection Type : Corrosive and Mechanical Damage Inspection 1 COMMENTS : This log is correlated to the Casing Detail dated June 5, 2000. 111 This log was run to assess the condition of the surface casing with respect to corrosive and mechanical damage, as well as to identify areas of buckling or ID restriction due to subsidence. I The caliper recordings indicate the 7.625" surface casing logged appears to be in good to fair condition with respect to corrosive and mechanical damage. A maximum recorded wall penetration of 20% is recorded in a line of pits in joint 90 (3,703') and joint 93 (3,816') respectively. No other significant wall penetrations or areas of cross - sectional wall loss are recorded throughout the 7.625" surface casing logged. I Although no significant I.D. restrictions are recorded, the caliper recordings indicate mild buckling with slight areas of ovality from —230' to —280', —900' to —940', — 1,110' to — 1,130', and — 1,310' to — 1,350'. An overlay of the centered and off - center caliper recordings highlighting the areas of mildly buckled 7.625" surface I casing is included in this report. The caliper recordings indicate the interval of 7" surface casing logged appears to be in good condition with respect to corrosive and mechanical damage, with no significant wall penetrations, areas of cross - sectional I wall loss or I.D. restrictions recorded. The body region analysis and joint tabulation data for the 7.625" and 7" surface casing are combined. I Although PDS has run a Magnetic Thickness Tool (MTT) once in this well, this is the first time a PDS caliper has been run. I MAXIMUM RECORDED WALL PENETRATIONS: Line of Pits ( 20 %) Jt. 90 @ 3,703 Ft. (MD) Line of Pits ( 20 %) Jt. 93 @ 3,816 Ft. (MD) 1 No other significant wall penetrations (> 19 %) are recorded throughout the surface casing logged. MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS: 1 No significant areas of cross - sectional wall loss (> 5 %) are recorded throughout the surface casing logged. MAXIMUM RECORDED ID RESTRICTIONS: 1 No significant I.D. restrictions are recorded throughout the surface casing logged. I I Field Engineer: N. Kesseru Analyst: C. Waldrop Witness: R. Dolcator ProActive Diagnostic Services. Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E-mail: PDS;g:memorylog.com 1 Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 1 �.ba— o ?s` I • • PDS Multifinger Caliper 3D Log Plot I Company : ConocoPhillips Alaska, Inc. Field : Kuparuk (West Sak) Well : 1D -102 Date : August 16, 2011 I Description : Overlay of Centered and Off - Center Caliper Recordings Across Buckled 7.625" Casing. Maximum I.D. Depth 3 -D Log (Off -Center) Image Map (Off - Center) 3-0 Log (Centered) Image Map (Centered) I 6 inches 8 1ft:700ft 0° 0° 90° 180° 270° 0° 0° 0° 90° 180° 270° 0° Minimum I.D. —t 6 inches 8 U 6 Nominal I.D. inches 8 , I f ■ i1 50 E . — 100 } ■ 150 Mt ■ 200 de ' - - -- 250 _ . I MINI .- 1111111 300 ■ 4.,..14 I -- 350 - 400 ! _ . ■ I . - -- 450 -*, ■ MENNOIMIIIIIIMMIMEMMINIMIIIIIMIIIII•11•111■111111■11111111111111111111=■11■111111=111111111111111•1111M1111111111111111MMINIIIIIIN • r 1 ir , ii ,o it 01 1 H 01 ii q10.11h 1 h41 ii 'Hi tf illiiiiill 1 1 /11,1 n1.41110111+ .; lir, if I II hi I t 1 ii. I 1 : ! I 4 , 1 , 4 i 1 . - i , til ! il I i li PO I 011114 . 11 il Nil IF A i itio i 1441 i . iff iiii i $ • 4 li 0 0 g g g 8 8 8 la 2 w ww) r, 1,`" w co' co m Ine .9 rallaill ••••••••••• ••••••• • •••••••••••• ••••••• ••••••• •• •••••••••••••• • • •••••••••••••• ••••• HI IMIlmi mmonmonsum • • summummum Immo um mml ow El 1 1 mosImmum mon . 1 mum MEM 1111 pool EN =.1.Efiii t..-• , g fitEr.....,— I oiri ••mmummo•mammom•ummailimmi mmumiemmeittim ••••a••••••••••••••••••••••••••• Nommmummommomilms Immommsommosmoimmommmum umommamommummum •••• •••••••••••••••••••••••• .. mumm...........ma .......................................... I • • 1 1050 n f i ..,- i 1, , 1100 I - _ i '� w - 1150 ...= �, - - 1200 r 1250 s Ai t I I 1300 F E I s It 1350 I • j 1400 -- i NEM SC 1450 amais- All. 1500 I L I Nominal I.D. 6 inches 8 I 6 Minimum I.D. inches 8 Maximum I.D. Depth 3 -D Log (Off -Center) Image Map (Off - Center) 3-0 Log (Centered) Image Map (Centered) 6 inches 8 1ft:700ft 0° 0° 90 180° 270° 0° 0° 0° 90° 180° 270° or I • . Correlation of Recorded Damage to Borehole Profile I k Pipe 1 7.625 in. (35.2' - 4185.2') Well: 1 D -102 Pipe 2 7 in. (4185.2' - 4190.2') Field: Kuparuk (West Sak) I Company: Country: ConocoPhifips Alaska, Inc USA Survey Date: August 16, 2011 I I Approx. Tool Deviation ■ Approx. Borehole Profile III 1 38 I 10 407 I 20 823 I 30 1228 1 40 1633 E E 50 �,, 2046 `� c Z s a 60 2455 8' I 70 2866 I 80 3264 N N . 90 3677 100 4090 A i IL. , . I N 102 4190 0 50 100 I Damage Profile (% wall) / Tool Deviation (degrees) Bottom of Survey = 102 1 I I • • I ___ PDS Report Overview `� Y � . Body Region Analysis I Well: 1D -102 Survey Date: August 16, 2011 Field: Kuparuk (West Sak) Tool Type: UW MFC XR 40 No. 217958 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 I Country: USA No. of Fingers: 40 Analyst: C. Waldrop Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 7.625 in. 29.7 ppf L -80 BTCM 6.875 in. 7.625 in. 6.0 in. 6.0 in. I 7 in. 26 ppf L -80 BTCM 6.276 in. 7 in. 6.0 in. 6.0 in. I Penetration(% wall) Damage Profile (% wall) 1 50 Penetratio body Metal loss body 0 50 100 0 — 100 I 50 0 I 0 to 20 to 40 to over 20% 40% 85% 85% Number of joints analysed (total = 105) 1 103 2 0 0 50 1 Damage Configuration ( body ) 20 I 15 10 I 0 I Is olated General Line Other Hole / Pitting Corrosion Corr°sion Damage Pos. Hole 100. Number of joints damaged (total = 12) 12 0 0 0 0 Bottom of Survey = 102 I I 1 I . • PDS REPORT JOINT TABULATION SHEET I Pipe: 7.625 in. 29.7 ppf L-80 BTCM Well: 1 D -102 Body Wall: 0.375 in. Field: Kuparuk (West Sak) I Upset Wall: 0.375 in. Company: Country: ConocoPhiNips Alaska, Inc. Nominal I.D.: 6.875 in. USA .Survey Date: August 16, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I. D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 0.1 35 0 0.02 5 1 6.84 Pur 1 38 0 0.03 7 1 6.83 2 74 0 0.03 7 2 6.82 3 117 0 0.02 6 2 6.79 I 4 157 0 0.03 7 2 6.83 5 198 0 0.03 9 3 6.84 Slight Oval due to Mild Buckling. • 6 240 0 0.04 10 3 6.82 Slight Oval due to Mild Buckling. 7 283 0 0.03 8 3 6.84 8 325 0 0.03 9 3 6.82 I 9 365 0 0.03 7 2 6.82 10 407 0 0.03 8 3 6.79 11 447 0 0.04 9 4 6.80 12 489 0 0.03 7 2 6.83 I 13 532 0 0.03 8 3 6.80 14 572 0 0.03 8 2 6.80 15 615 0 0.04 10 4 6.78 16 656 0 0.03 9 2 6.80 17 697 0 0.03 7 1 6.82 18 739 0 0.03 9 2 6.80 19 780 0 0.03 8 3 6.83 20 823 0 0.03 9 4 6.81 21 861 0 0.04 11 4 6.80 I 22 900 0 0.03 8 4 6.81 Slight Oval due to Mild Buckling. 23 941 0 0.03 9 5 6.83 24 984 0 0.04 9 3 6.80 24.1 1020 0 0 0 0 6.75 7.625" Tam Port Collar I 25 1023 0 0.04 9 2 6.79 26 1063 0 0.03 7 2 6.78 27 1106 0 0.03 8 2 6.79 Slight Oval due to Mild Buckling. 28 1147 0 0.03 7 2 6.79 i] I 29 1190 0 0.03 9 2 6.80 30 1228 0 0.03 8 2 6.82 31 1267 0 0.04 11 2 6.75 ■ 32 1308 0 0.04 10 2 6.79 Slight Oval due to Mild Buckling. I 33 1350 0 0.03 0 2 6.79 34 1393 0 0.03 2 6.78 35 1435 0 0.03 2 6.79 36 1470 0 0.03 2 6.82 37 1511 0 0.03 8 2 6.80 I 38 1554 0 0.02 6 1 6.81 39 1593 0 0.03 7 2 6.82 40 1633 0.12 0.03 7 2 6.80 41 1676 0 0.03 7 2 6.79 0 I 42 1718 0 0.02 6 2 6.80 43 1756 0 0.02 5 2 6.80 M 44 179 7 0 0.02 5 2 6.79 45 1839 0 0.02 5 2 6.84 I 46 1880 0.05 0.02 5 2 6.83 47 1921 0.06 0.02 ( 6.83 48 1963 0 0.03 2 6.81 Penetration Body 1 Metal Loss Body Page 1 I I I . • PDS REPORT JOINT TABULATION SHEET I Pipe: 7.625 in. 29.7 ppf L-80 BTCM Well: 1D-102 Body Wall: 0.375 in. Field: Kuparuk (Wewst Sak) I Upset Wall: 0.375 in. Company: Country: ConocoPhillips Alaska, Inc Nominal I.D.: 6.875 in. USA .Survey Date: August 16, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 49 2006 0 0.03 9 2 6.78 50 2046 0.14 0.03 9 2 6.80 51 2085 0 0.03 8 2 6.81 52 2128 0 0.03 7 2 6.82 I 53 2170 0 0.02 5 2 6.79 54 2210 0 0.02 5 1 6.80 55 2252 0 0.02 6 2 6.79 56 2291 0 0.04 10 2 6.80 57 2331 0.13 0.04 10 2 6.82 IL I 58 2373 0 0.02 6 2 6.79 59 2416 0 0.03 7 2 6.84 60 2455 0 0.02 5 1 6.81 61 2495 0 0.03 7 6.80 I 62 2537 0 0.02 5 2 6.76 63 2577 0 0.02 5 1 6.82 64 2619 0 0.03 7 1 6.81 65 2658 0 0.02 6 2 6.80 I 66 2699 0.15 0.02 5 2 6.83 67 2741 0.08 0.02 5 2 6.81 68 2783 0 0.02 5 2 6.79 69 2824 0.12 0.02 5 2 6.78 70 2866 0 0.02 6 1 6.79 I 71 2908 0.12 0.02 6 1 6.78 72 2951 0 0.03 7 1 6.81 73 2990 0 0.02 6 1 6.80 74 3029 0 0.02 6 1 6.81 I 75 3069 0 0.04 10 2 6.78 76 3112 0 0.03 7 2 6.80 77 3150 0 0.02 5 2 6.81 78 3185 0.24 0.03 8 2 6.78 I 79 3224 0 0.02 5 2 6.79 80 3264 0 0.02 6 1 6.78 81 3307 0 0.03 8 2 6.78 82 3348 0 0.02 5 2 6.80 I 83 3387 0 0.02 6 1 6.79 84 3429 0 0.03 8 1 6.82 85 3471 1.15 0.03 7 2 6.82 86 3513 ).08 0.03 7 2 6.77 87 3553 ?.08 0.02 5 2 6.80 I 88 3596 114 0.03 7 2 6.78 89 3635 0 0.04 12 2 6.79 Shallow Pitting. 90 3677 0 0.07 20 2 6.79 Line of Pits. 91 3720 0.06 0.06 17 2 6.79 Shallow Line of Pits. I 92 3760 0 0.07 17 2 6.82 Shallow Line of Pits. 93 3802 0.05 0.07 20 2 6.83 Line of Pits. 94 3844 0 0.07 18 2 6.79 Shallow Line of Pits. 95 3887 0 0.05 14 2 6.81 Shallow Pitting. I 96 3922 0 0.04 12 2 6.82 97 3964 0.25 0.05 13 2 6.82 Shallow Pitting. 98 4007 0 0.06 15 2 6.79 Shallow Pitting. II Penetration Body Metal Loss Body Page 2 I • • PDS REPORT JOINT TABULATION SHEET ' Pipe: 7.625 in. 29.7 ppf L -80 BTCM Well: 1 D -102 Body Wall: 0.375 in. Field: Kuparuk (West Sak) ' Upset Wall: 0.375 in. Company: Country: ConocoPhillips Alaska, Inc Nominal I.D.: 6.875 in. USA Survey Date: August 16, 2011 ' Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss LD. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 ' 99 4049 0 0.06 15 2 6.81 Shallow Pitting. 100 4090 0.13 0.06 15 2 6.78 Shallow Pitting. 101 4133 0.06 0.07 18 2 6.79 Shallow Line of Pits. 101.1 4175 0 0.02 6 1 6.77 Pu ' 101.2 4179 0 0 0 0 5.98 7.625" x 7" Crossover 101.3 4185 0 0.03 7 1 6.21 7 Pup 102 4190 0 0.04 10 1 6.18 Top of 7" Casing • Penetration Body Metal Loss Body 1 1 1 Page 3 1 I 0 • I PDS Report Cross Sections iri I Well: 1D-102 Survey Date: August 16, 2011 Field: Kuparuk (West Sak) Tool Type: UW MFC XR 40 No. 217958 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 I Tubing: 7.625 in. 29.7 ppf L -80 BTCM Analyst: C. Waldrop I I Cross Section for Joint 90 at depth 3702.940 ft Tool speed = 20 I Nominal ID = 6.875 Nominal OD = 7.625 Remaining wall area = 99% Tool deviation = 46° -� I 1 I 1 I Finger = 29 Penetration = 0.075 in. Line of Pits 0.08 ins = 20% Wall Penetration HIGH SIDE = UP I 1 I I 1 • • 1 PDS Report Cross Sections I Well: 1D -102 Survey Date: August 16, 2011 Field: Kuparuk (West Sak) Tool Type: UW MFC XR 40 No. 217958 Company: ConocoPhillips Alaska, Inc. Tool Size: 2.75 Country: USA No. of Fingers: 40 I Tubing: 7.625 in. 29.7 ppf L -80 BTCM Analyst: C. Waldrop 1 1 Cross Section for Joint 93 at depth 3816.310 ft Tool speed = 20 Nominal ID = 6.875 I Nominal OD = 7.625 Remaining wall area = 98% Tool deviation = 48° \ \ \ I I 1 1 1 1 / 1 I t 1 Finger = 28 Penetration = 0.075 in. Line of Pits 0.08 ins = 20% Wall Penetration HIGH SIDE = UP 1 1 1 1 1 € KUP 1 D -102 Conoco Phillips Attributes gle a MD T Wedbore APN1WI Field Name Well Status Ind ( °) AD (BKB) Act Btrn (AKB) carxxxin>obs 500292296000 WEST SAK PROD 93.76 6,304.31 7,378.0 "'" Comment H2S (ppm) Date Annotation End Date 6B -0M (ft) Rig Release Date i wet c«xw: tD m2.3252011 2:0927 PM SSSV: NONE 0 8/7/2009 Last WO: 573/2009 39.60 6/22/2000 Sdieme10 -Atlual Annotation Depth (ftK8) End Data Annotation Last Mod -_'End Data caahg 3, o Last Tag: Rev Reason: FORMAT UPDATE Imosbor 3/25/2011 HANGER, 31 Casing Strings Casing Description String 0... String ID... Top (MB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd t CONDUCTOR 13 3/8 12.415 39.6 110.0 110.0 6800 L WELDED Casing Description String 0._ String ID - _ Top (MB) Set Depth (f... Set Depth (TVD) ... String Wt. String ... String Top Tbrd CONDUCTOR. 1 SURFACE 7.875 "x7" 75/8 6.875 / 3 y 0.6 4,929.7 3,752.8 2930 L BTCM 40 Casing Description Siring 0_. Strig ID__ Top MKS) Set Depth (f... Set Depth (TVO) _ String Wt.. String ... String Top Turd 1 WINDOW 6 6.000 4,368.0 4,383.0 3,568.1 ESP Casing Description Siring 0... Siring ID ... Top (MB) Set Depth (f... Set Depth (TVD) - -- String Wt.. String ... String Top Thrd MANDREL, NB SAND LINER 4 3.548 4,778.1 7,357.0 3,720.5 9.50 1-80 HSLHT 2,501 45x4" ESP Liner Details MANDREL, - _ Top Depth 3 ' (TVO) Top Intl Nomi... Top MKS) (B) (°) hem Description Comment ID (in) 'tad,algn, C 4,778.1 3,7330 7850 PACKER BAKER MODEL SC - 1 R LINER TOP PACKER 70B 4.000 3,598 I PACK 4,822.8 3,741.6 79.74 SLEEVE BAKER MODEL CMD SLIDING SLEEVE 3.430 A any PUMP 3944 '►'. . Tubing Strings INTAKE, 3,658 J �� Tubing Description String O._ String D ... Top (M(B) Set Depth (f... Set Depth (TVD) ... Siring Wt -. Siring _. String Top ThN SEAL, 3.689 I - TUBING 4 1/2 3.958 30.6 3,697.3 3,139.7 12.60 L IBTM ESP M030R, : 3,682 � Completion Details I 3,693 SENSOR, Top Depth Centralizer, r' "�"' (TVD) Top Intl None_ 3� 05 Top (MCB) (MLB) (1 hem Description Comment ID (in) 306 30.6 0.00 HANGER 103/4' x 4 1/2" Vetco Gray Tubing Hanger 3.992 3,585.7 3,066.2 48.45 Discharge Phoenix Discharge Pressure Sub MI pup below 3.833 3,658.1 3,114.3 49.30 INTAKE TTC "Bullet Proof w /Crossover Coupling inside 0.000 I 3,668.5 3,121.1 49.42 SEAL Tandem Seal Section 0.000 { 3,662.3 3,130.0 49.58 ESP MOTOR 190 hp ESP Motor 0.000 W'.NLIGW, 43694,383 3,693.4 3,137.2 49.71 SENSOR Phoenix MDT -XT Gauge 0.000 .; 4,363 3,595.4 3,138.4 49.74 Centralizer Motor Centralizer 4.500 Other In Hole (YMireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (TVO) Top Ind Top (0IKB) (Mt (% Description Comment Run Date ID (in) I , 3,605.0 3,079.2 48.67 PACKOFF 4 1/2" PACKOFF ASSY OAL= 101" 5/8 /2009 2.125 ASSY i SOREACE 3,644.0 3,105.1 4913 PUMP SET TTC ESP OAL= 37.5' 5/7/2009 0.000 0 0 4,363.0 3,555.7 51.10 JUNK 5 1/4" HALF MOON LIB INDICATES TOP OF JOINT 4/272008 0.000 4/30/2008 731-4,930 0 Perforations & slots . • Shot U i Top (WD) Btfi (TVD) Dens Top (M(8) Btm MOH ( IMrO) Zone Dam HA.— Type ment No - 4,925.0 7,357.0 3,752.8 3,720.5 WS B, AS A4, 6/22/2000 50. Screen Perfs thnl screens WS A3, WS A2, se q WSA1,1D -102 i ■ ■ Notes: General & Safety ' mil End Date Annotation It ii OM 3/5/2001 NOTE: Multilateral well. NB-Sand (1D-102), D -Sand (1 D- 102L1) 11/18/2003 NOTE: WORKOVER s-s 4/17/2005 NOTE ESP WORKOVER 12/28/2005 NOTE: WORKOVER i I 1 5/9/2008 1 II NM 6/17/2008 NOTE: KNOWN TBG X IA COMMUNICATION = NO PACKER NOTE VIEW WITH Alaska Schematic-9.0 NS i 1 I I IM 1 III MO i i 1 WO I Screen. NE 4,925 -],3A s ■ OM i 5 II i sIII i I ■r MI i II II Mandrel Details i Top Depth Top Port si (1110) Mel OD Valve Latch Sire IRO Run Stn Top (M(B) (MB) (7 Mate Model III) Sere Type TYPn (in) (Pei) Run Date Com... 1 2 2,390.6 43.41 Camco KBG-2 -1R 1 ESP DMY BK -5 0.000 0.0 5/2/2009 2 3,509.3 3,017.6 50.18 Camco KBG -2 -1R 1 ESP SOV BK -5 0.000 2,000.0 1/4/2010 1 I I Ell IM II II II NO Mill I NB SAN' LINER 47.34", 1 3 (10-102). 1,357 TT) ,378 7,378 Brett Packer Page 15 of 33 8/9/2011 1 • If [E [EF Z SEAN PARNELL, GOVERNOR �T ALASKA OIL AND GAS T 333 W. 7th AVENUE, SUITE 100 COl`SERVAjIO1` COMMISSIOl` ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Brett Packer Wells Engineer ConocoPhillips Alaska, Inc. i P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1D -102 Sundry Number: 311 -234 'FS'W j 014" M•' U L Dear Mr. Packer: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday o weekend. Sincerely, 4i D. eamoun', . Cha DATED this lit day of July, 2011. Encl. e • • Conoco Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 - 0360 � July 22, 2011 , "' ' \ I E Commissioner State of Alaska ; ,s t , , ;Cif IS. :9iorntSSion Alaska Oil & Gas Conservation Commissionr� 333 West 7 Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover West Sak Well 1D- 102 (PTD# 200 -075). Producing well 1D -102 was drilled and completed in June 2000. It was first brought online in July 2000 as a West Sak dual lateral A/B/D sand ESP producer. This well has had a fair share of problems due to heavy sand and gravel production from a matrix bypass event with injector 1D -139, and also due to the failed RMLS junction in the upper lateral. We have worked this well over five times in the past, and this will be the sixth. The most recent failure occurred in December 2009, when the ESP went down unexpectedly. Subsequent attempts to restart the pump were unsuccessful, and during an attempt to freeze protect the IA, the well pressured up to 3500 psi indicating a sand plug below the ESP. Due to the heavy sand production from this well, and the numerous ESP failures, we have decided that an ESP is not the desired artificial lift mechanism we want to pursue in the future for this well. This time, we plan to install a surface powered jet pump, similar to what has been done on four of our West Sak 1 C single casing wells. This completion will allow CTD access below the tubing tail for cleanouts and such. ConocoPhillips has initiated a new two- barrier policy from any energized fluid (i.e. reservoir fluids, power fluid, lift gas), consequently, in order to install a surface powered jet pump, this well requires another string of casing to provide that 2 barrier. The proposed workover will pull the 4 ' /2" ESP completion, install an inner string of 5'/2" casing and re- complete the well with a 2 %" jet -pump /gas -lift completion. This Sundry is intended to document the proposed change to the casing structure as well as request approval to workover the well. The current SBHP is 1650 psi at the mid -perf depth of 3,708' TVD, which equates to an EMW of 8.6 ppg. Current SITP is 150 psi. Attached is a proposed schematic along with a general workover procedure. If you have any questions or require any further information, please contact me at 265 -6845. Sincerely, ee Brett Packer Wells Engineer CPAI Drilling and Wells ga. a $ �*^ ,j. • t t • STATE OF ALASKA �yy s A:. _ ° " �P 4$,.. p ALASKA` AND GAS CONSERVATION COMMISSI tit °' I n ti..':... 4 .,,tr' t APPLICATION FOR SUNDRY APPROVA�S . `. i' 20 AAC 25.280 Type Request: Rug r Repair r r 4 � "' ,.f� . I` tl 1. T e of Re uest: Abandon R u for Redr Perforate New Pool �" ' Re air we �.:�1i&' �,�� rd�vectl=T arri ot sio Suspend r Plug Perforations r Perforate r Pull Tubing IV ' ThleiBttellion r Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing P , Other: g T-f P irr 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development g7 ' Exploratory r 200 - 075 • 3. Address: Stratgraphic r Service r 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 22960 - 00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No iv 1D -102 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 25650 Kuparuk River Field / West Sak Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7378 • 3721 - 7357' 3720' 4363' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 13.375 110' 110' SURFACE 4145' 7.625" 4175' 3439' SURFACE 754' 7 4929' 3752' LINER 2579 4.5" / 4" 7357' 3720' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4778' -7357' 3733' -3721' 4.5 L -80 3697 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER SC-1R LINER TOP PACKER MD= 4778 TVD= 3733 no SSSV 12. Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch Exploratory Development Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 8/8/2011 Oil 17 Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brett Packer @ 265 -6845 Printed Name Brett Packer Title: Wells Engineer Signature '7.72—/, ? Phone: 265 -6845 Date 312 2 (i( Commission Use Only Sundry Number `'a3 q Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test fIC Mechanical Integrity Test r Location Clearance r .t- 3Soo psi. j3d1 �"- Other: A 2,S p s i, ,4 e s f `''.' -� ) I Subsequent Form Required: /6 _'/ , r i APPrc APPROVED BY `� B DMQ AIL I � � ' �' � • MMISSIONER THE COMMISSION Date: 1,7,1.ff ; . �? It Form 10 -403 Revised 1/2010 + /' _2 /•ff ORIGINAL Submit in Duplicate 7 , ,� O(1/ • • 1D-102 Rig Workover Install 5 casing and 2'/8" JP Completion (PTD #: 200 -075) Current Status: West Sak ESP producer was SI January 2010. The ESP cannot be re- started due to a sand bridge below the ESP. Scope of Work: Pull the 4 '/z" ESP completion, cleanout down to the RMLS junction, pressure test the casing, run a suite of diagnostic e-line logs in the 7 5 /g" casing, install a 5 %z" inner casing string, install a 2'/8" Jet Pump completion. General Well info: Well Type: Producer MPSP: 1,279 psi Reservoir pressure/TVD: 1,650 psi / 3708' TVD (8.6 ppg) Wellhead type /pressure rating: Vetco Gray Horizontal, 11" 5M psi top flange BOP configuration: Annular / Pipe Rams / Blind Rams / Mud Cross / Pipe Rams MIT results: MIT -IA /OA not possible due to single casing packerless ESP completion. Earliest Estimated Start Date: August 8, 2011 Production Engineer: Jenn Gauer Workover Engineer: Brett Packer (265 - 6845 / j.brett.packer @conocophillips.com) Pre - Rig Work: 1. RU Slickline: a. Pull slipstop, packoff, and pump. b. Swap out SOV for DV in GLM #2 at 3,509' RKB. 2. PT tubing & casing packoffs. 3. Set BPV. Proposed Procedure: 1. MIRU Nordic 3. Pull BPV. Reverse circulate hot filtered seawater w/ 3% KCL to clean the ESP & tubing. Stop circulating and bullhead another 25 bbls down the IA to the formation. Obtain SITP & SICP, and verify needed KWF. Repeat circulation using filtered KWF if necessary. Verify well is dead. 2. Set BPV & blanking plug, ND tree, NU BOPE & test. 3. Pull blanking plug & BPV, install side isolation sleeve in hanger, screw in landing joint, BOLDS's and pull to the floor. 4. POOH w/ ESP completion, standing back tbg, spooling up ESP cable & heat trace. Lay down ESP equipment. 5. RIH w/ 7 %" scraper assembly on old 4 ' /z" tubing, cleanout down to RMLS junction at 4,369' MD. POOH standing back tubing. 6. MU 7" RBP and 7 5 /" test packer, RIH on old 4 ' /z" tubing to 4,275' MD. Set RBP and release from RBP. Pull up into the 7 %" casing and set the test packer. PT the RBP to 1500 psi. PT back side to 1500 psi. a. If pressure tests OK: Release test packer & RBP, POOH laying down tubing, and proceed with running E -line logs • • 7. RU E -line: RIH w/ Microvertilog, 40 -Arm Caliper, and Gyro; log from 4150' back to surface. 8. Unload old tubing and rack & tally new casing and tubing in pipe shed. 9. PU and RIH w/ 5 '' /z ", 15.5 #, L -80 BTCM -SCC casing, SBE, PBR Seal Assy, 3 ' /z" x 7" Premier Packer, solid seat SOS, and WLEG. 10. Install storm packer at —100' MD w/ casing hanging below. NDBOP. 11. Remove old wellhead and install new wellhead to accommodate the 5 ' /z" casing. 12. NUBOP & test. 13. Release storm packer and POOH laying down storm packer. 14. Continue RIH w/ 5 ' /z" casing to packer setting depth of 4,275' MD. Land the 5 %z" casing hanger, RILDS. 15. Bullhead gelled diesel down the 5 '/z" x 7 5 /8" annulus to below the packer. Pressure up on casing to set the packer. PT the annulus w/ diesel to 1500 psi. BOLDS, pull up on 5 '/z" casing to shear the PBR. 16. Space out 7' off bottom and land 5 'h" casing hanger. RILDS. Pressure test 5 '/z" x 7 5 /g" annulus to 1500 psi. 17. PU and RIH w/ 2 7 /8" jet pump completion w/ downhole gauge and seal assy. 18. Sting seals into SBE, mark pipe, pull seals from SBE, circulate well full of CI brine, space out 7' off bottom, make up hanger and splice TEC wire to penetrator, land the hanger. RILDS. 19. PT tbg to 3000 psi, monitor annulus, bleed tbg to 2750 psi. PT IA to 3500 psi for 30 min. Record casing test on chart recorder. Bleed IA to zero, bleed tbg to zero. Ramp up IA pressure to shear SOV. 20. Pull landing joint, drain stack, remove side -port isolation sleeve, set two -way check, NDBOP. 21. NU and test tree. Pull two -way check, freeze protect through the SOV, set BPV. 22. RDMO Nordic 3. Post - Ria Work: 1. Reset well house(s) and flowlines of adjacent wells. 2. Make necessary S -riser mods 3. Re- attach flowline. Connect new Guardian gauge. 4. Pull BPV. 5. RU slickline, replace SOV w/ DV. 6. Turn well over to production. w ' � • • CANIOCOPhilliPS West Sak Well: 1 D -102 2011 RWO PROPOSED COMPLETION API: 500292296000 Conductor: PTD: 200 -075 13.375 ", 68 #, L -80 at 110' Wellhead: Gray Horiz DS X -mas Tree: 4- 1/16 ", 5K psi J Surface Casing: Lift Threads: 4.909" MCA 7.625 ", 29.7 #, L -80 to 4175' BPV: 4" 'H' 7 ", 26 #, L -80 from 4175' to 4929' RMLS Junction at 4,369' MD Proposed 2'/e" Completion IA • Tubing = 2 % ", 6.5 #, L -80, 8rd EUE. Oft New Inner Casinq: • 2.313" DS- nipple at 500' I 5.5 ", 15.5 #, L -80 BTCM • CMU Sliding Sleeve w/ 2.25" D J profile. Bakerweld Pre -pack screens: • Guardian Pressure Gauge. 4' x 4.5 ", Alt. screen /blank liners • Baker locator w/ 17' seal assy. l CMU Sliding Sleeve j 4- � c�A. y o / LsI V " J Proposed 5' /z" Inner Csq. String Guardian Sidemount Gauge Carrier • Casing = 5'/",15.5 #, L -80, BTCM -SCC. • XO from 5 %" BTCM -SCC to 5" BTCM. F- 5" SBE (20' long) IAA • 20' SBE. 3 -1/2" EUE Tbg • XO from 5" BTCM to 3' /z' EUE. Iftwor4 / • 3' /s" EUE Tubing. 1s 4 PBR (20' long) • Baker locator w/ 17' seal assy. / X/ 4 Premier Packer to be set @ 4275' RKB • 20' PBR /� • Baker 3' /i' x 7" Premier Packer ` 4 2-7/8" EUE Tbg Tail w/ SOS & WLEG • XO from 3 %" EUE to 2 %" EUE. 4 RMLS Jxn @ 4369' RKB • 2 %" EUE tubing tail • Shear out Sub A • WLEG ' o , Last Updated: 22- Jul -11 Updated by: JBP WELL LOG TRANSMITTAL PROACTIVE DIACINOSTIC SERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659 -5102 RE: Cased Hole /Open Hole /Mechanical Logs and /or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following: ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 MTT Report 30 -0ct -10 1 D-102 1 Report 50-029- 22960-00 2) Caliper Report 03- Nov-10 2Z -15 1 Report/ EDE 50 -029- 21362 -00 r Signed: Date Print Name: Awlarska Oil PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)2454951 FAX: (907)24548952 E-MAIL: iodsanchoraQe0memorylOC Corn WEBSITE : www.memorylog.com C:\Documents and Settings \Diane Williams \Desktop \Tcansmit_Conoco.doc Memory Magnetic Thickness Tool Lo Results Summary S g Company: ConocoPhillips Alaska, Inc. Well: 1D -102 Log Date: October 30, 2010 Field: Kuparuk Log No.: 10675 State: Alaska ' Run No.: 1 API No.: 50- 029 - 22960 -00 Pipet Desc.: 4.5 in 12.6 lb L -80 IBT Top Log Intvl.: Surface Pipet Use: Tubing Bot. Log Intvl.: 175 Ft. (MD) Pipe2 Desc.: 7.625 in 29.7 lb L -80 BTC -MOD Top Log Intvl.: Surface Pipe2 Use: Surface Casing Bot. Log Intvl.: 175 Ft. (MD) Pipe3 Desc.: 13.375 in 68 lb. L-80 Welded Top Log Intvl.: Surface Pipe3 Use: Conductor Pipe Bot. Log Intvl.: 110 Ft. (MD) Inspection Type: Corrosive & Mechanical Damage Inspection COMMENTS: ' This MTT data is tied into the Mandrel Hanger @ 0 ft. Depth. This is the first time this well has been logged with the 12 Arm Magnetic Thickness Tool (MTT). The MTT ' responds to the total metal thickness of the 4.5 in. tubing, 7.625 in. surface casing, with some influence from the 13.375 in. conductor pipe. Passes at 5Hz, 8Hz and 10Hz were made at 20 fpm. INTERPRETATION OF MTT LOG RESULTS The MTT log results cover the interval from surface to 175 ft. Changes in metal volume are relative to the calibration points at 10 ft. and 101 ft., where the readings are assumed to represent undamaged pipe. All ' other readings are relative to these reference points, which include influences from the 4.5 in. tubing, 7.625 in. casing and 13.375 in. conductor pipe. The MTT recordings indicate no significant areas of metal loss. A log plot overlay of the filtered average overall metal thickness recorded by the 5Hz, 8Hz and 10Hz passes is included in this report. Since the lower frequency magnetic signals are more capable of permeating metal further from the tool than the higher frequency signals, the response from the 5Hz pass is considered to be more representative of the relative overall metal loss over this interval. Log plots of the entire 5Hz pass and an expanded log plot of -- top 30 ft. ' of the 5Hz pass are included in this report. A fairly consistent spread of the tool response at different recording frequencies is indicated over the interval 42 ft. — 76 ft., near the bottom of the conductor. The correlation of this interval to the 2" joint of 7 5/8 in. casing points to a possibility that this casing joint has slightly different metal properties or wall thickness than the top joint of 7 5/8 in. casing. ' The percent circumferential metal loss expressed in this summary is a percentage of the total metal that the tool is responding to, which may include influences from the 4.5 in., 7.625 in. and 13.375 in. pipe. If all of the metal loss is specific to the 7.625 in. surface casing, the percent metal loss from that pipe alone is probably ' higher than the numbers expressed. Some of the metal loss indicated could be from either the 4.5 in. tubing or 13.375 in. conductor. Field Engineer: G. Etherton Analyst: HY. Yang & J. Burton Witness: B. Boehme ProActive Diaonostic Services, Inc, / P.O. Box 1369, Stafford, T)( 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDS @memorylog.com ' Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 Database File, dAwarnorWata\test\3rd cal\overlay.db Dataset - athname: overlay Preseoverlay -.. Depth -. Delta Metal Thickness 2010 (101-14 50 Delta Metal - 0 Delta Metal t i!!!ililii i!!!!ii!lliE�- �li!!i! iliiiiilii iliiiil��■■��liiili KN!!!lii�iiC•� imom No M 0 0 NEOMMI momm No 0 M i No ON NIMMIMMOM M M ON 0 OiMON1000 M MOOMM WNW WOMIMMIM100 w MOMMIM Now MONO !MONO S1i!!!!iMONO iO IN0100 M ommo =0010 am momm WMIMIMMMIN w ON.moMMOMM ommom ON MMIMOM IMMOI MMMOMMOMMIR M NIMMOM No !ii!!!!!! !!!!!!!!!0" !!!!!!!!! 00 IMMMM Mi MOMIiWIMMO10511000 IMMOMOM WMIMMMIMOMMIM =001IMMOMMMlUMMMOMMIMM�� ililiiilii iiiili001=0 000iiilii MiMIMMIMOM ■ WOMI MOM M MM NONNI MW 1001MO ■■■ W00001100 MW ili! MONO !i MWOM IMMIMM OMMIMMI M OWN ■i MONO � MMOINWIM00111111MOM INNON�� NIMMiMIMMMO SIONO ommo m� WIMMIMMO ■■■MMEOMM MMOMOM MMiIMMiMMiN MOMOMM■1 Mrlil , mom = !i!!!!!!!i i!!!!!!!l� IMM 0 10 0 0 iiiliiilii .. Wkimmliii!!i i!illiiili iliilililii:_''iiliilii SIC.. wommomw 100 ff 120 140 ' 160 514z Delta Metal Thickness ' 180 8Hz Delta Metal Thickness ' ==lOHz Delta Metal Thickness ' -50 Delta Metal Thickness 2010 (10Hz) ( %) 50 -50 Delta Metal Thickness 2010 (8Hz) ( %) 50 ' -50 Delta Metal Thickness 2010 (5Hz) ( %) 50 i Q % Reirded Magnetic Thickness L Data - 5Hz Pass 1 • 02 Oct ober 3 2010 Database File: d:\warrior\data\test\3rd cal\5hzpass.db .. Presentati • / Chart Dataset Creation: Mon Nov 01 12:14-40 2010 • Depth in Feet - • 1 -50 Delta Metal Thickness 2 MTTP01 (rad) 12 1 - • --• 11 • •• MINE Tree 0 WIN 1111111 mom 111" e� m shir2ft No MIMNINMMIMIMR MI IS IM IN IN IN W! w M IN 10111"Mm .... - �i■�aaa aaar�r�ar�aaar■r�aaf�aaa� a WIa11M■aM . - . - ■��r�r�l��as�l��a�aa�la��i� No Mon aammmaaaaa a� ►aa�■��ls��r�alslar�a�a��ta�1 aa�■�aaa��a ■ ��a��a�a��a ■r;a��aEa��a�a�Elr� i!!!!!!!!i • ' wommommimiow mrillas!![olIN aaaa■aMM =M r IMEA !!!!!!!!!! t1111ro Ilt11 MINIM 0111 lIL�E�llsllt��IN IMr /Ml!llt��1 !!!!!!!!!! !lr�t��l�1li�tlt�ll� \�!i!�lti ! ti!!!m wommmmmommmammmmmmLai l IN . .. Fmimmmaa MINIM rr WI»INNIaPNI MIaa aaIMAaia■ir r i!!!!!!!!! aaaMa1NaaN1I1a . , a�Eaar� lr�■i�a�a�lr�i�■rarl�r�s� aaamaaamma a�:��r�lr�rria�lraaraa�l�ia IN a�■a as aar�r�aa�■ir�■aa��lra��a�■�� MINIM rai�aaaaa� aa■��aaaaaa aaE�r��la:�■raaa��lra��r�aaa�� itlUit Mom. lLGL i!!!!!!!!! il1�t�li!!1�l�t1ll��!!l�1 !!!!!!!!!i !lfai�la!!1�li�1lla��i'!lii� aai■�aaaaaa 60 ala��ailaai■ aasair�la�a�aialraararraf�afar �!�■��!!!!! .. a�aaaa�la��E�alraa►afa��la�aEa aa��a�a��a a�ia�a�la�lraalaaari�aarl�al�r� aa��a�aaaaa aaa��r�la��aairaaaraa�la�aLAI aaa�a�aaaaa aslrarils�aaal��►ara��ar�ara ■�la��!la�a ■ir��s�ls�a�a�ar�l�ra�la�ia�a aaa�a�aa��a a` +�a�a�aa�a ►aaar�a►aEaa�a��a�a !!!!!L'111 1�%■!��! a��■ralr�r��ar�araaar��ar�1■r�! aami■waamoa ��araa�r ■�a��araa�i■raa�a■��iaa aaama,mmmoa aaa�aaaaaa �1�� la��r�■��a�a��r�aia��a Tub in Jt.3 ' 1 ' 45" Collar ��■ 120 7.625" Collar ' Tubing A 4 ' 140 4.5" Collar ' Tubing A 5 160 ' 7.625" Collar ' Delta Metal Thickness 5" Collar ' Line Speed— 180 I I I I 1 -50 Delta Metal Thickness ( %) 50 2 MTTP01 (rad) 12 ' 0 Line Speed (ft /min) -200 -6.8 MTTP12 (rad) 3.2 " Q om N Exnanded Magnetic Thickness L Data - 5Hz Pass- 1 D -102 October 30, 2010 ' PmALrivcDinymsricSuviccs Database File: d:lwarriorldataltestl3rd callexpanded 5hzpass.db Dataset Pathname: 5HzPass ' Presentation Format: 20 Dataset Creation: Mon Nov 01 12:14:40 2010 Charted by: Depth in Feet scaled 1:60 -50 Delta Metal Thickness ( %) 50 2 MTTP01 (rad) 12 0 Line Speed (ft/min) -200 -6.8 MTTP12 (rad) 3.2 Tree Line Speed Hanger L �T r - F== 7.625' Collar ' Delta Metal Thickness Tubing A 1 20 -50 Delta Metal Thickness ( %) 50 2 MTTP01 (rad) 12 0 Line Speed (ft/min) -200 -6 MTTP12 (rad) 3. 2 r 0 *KRU ID-102 GonocoPhilllps Alaska, Inc. r 1D-102 API: 500292296000 Well T •PROD Angle @ TS: Heat Trace SSSVT •None Ori Com letion: ed22/2000 Angle @ TD: 89 73 8 (0 -2958, Annular Fluid: Last W /O: 12(29/2005 Rev Reason: PULL ESP PUMP 013:1.000) ASSEMBLY, C/O SOV r TUBING Reference '30.58' RKB Ref L Date: Last U •5/19/2007 (0.4131, Lai Tag 3997 TD: 7378 ttK6 Last T Date: 12/1112001 Max Hole An le: 94 6304 013:4.500, :3.958) Casing String - B -SAND LINER ternating blank pipe & Baker Dual Screens 4 "x4.5 Description Slze I Top I Bottom TVD Wt I Grade I Thread B -SAND LINER 4.500 4778 4925 3751 12.60 L -80 HSL SCREENS 4.500 4925 7 '57 3722 1 12.60 1 L-80 HSLHT Casino String - COMMON STRINGS Description Size Top Bottom TVD Wt Grade Thread CONDUCTOR 13.375 0 110 110 1 68.00 1 L -80 WELDED r SURFACE 7.625 0 4175 3439 1 29.70 1 L -80 BTC -MOD SURFACE 7.000 4175 4929 3752 26.00 L-80 BTC -MO CSG WINDOW 6.000 4368 4383 3568 0.00 L -80 to 1D -1021-1 Tubing String - TUBING Size I Top I Bottom I TVD Wt I Grade Thread r _ 4.500 0 4131 3411 1260 L -80 SURFACE P IBT erforations Summa (0 -4175, Interval I TVD I Zone Status Ft SPF Date TvDe Comment OD:7 625, 4925 - 7257 3751 - 3722 WS B,WS 2332 50 6122/2000 Screens Perfs thru screens r wt29.711) A4,WS A3,WS A2,WS All Gas Lift MandrelsNalves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv r - CmM 1 2512 2398 CAMCO KBG -2 DMY 1.0 K 5 B 0.000 0 12!28/2005 2 3963 3306 CAMCO KBG -2 SOV 1.0 BK 5 0.000 2000 4/29/2007 Other lu s equip., etc. COMPLETION Depth TVD Type Description ID 0 0 Heat Trace HEAT TRACE 0•000 r X 31 31 HANGER VETCO GRAY TUBING HANGER 3.958 (4090- 4101, 4014 3338 SUB PHOENIX DISCHARGE PRESSURE SUB 3.958 OD:5.130) 4090 3386 XO TCC CROSSOVER/COUPLING SET 3.956 4101 3392 SEAL Centralift ESP TANDEM SEAL 0 SEAL 4115 3401 MOTOR Centralift ESP MOTOR SET 0.000 r (4101 -4115, 4131 3411 C- 0alizer Centralift Centralizer SET 0.000 OD:5.130) 4133 3413 SENSOR PHOENIX PRESSURE SENSOR 0.000 Other lu s equip., etc. - B-SAND DETAIL jj TVD T Descrl onID MOTaR 3733 PACKER BAKER SG7R PACKER w/MILLOUT EXTENSION 4.000 (4115-4131, SLEEVE R CMD SLIDING SLEEVE 3.430 3733 TUBING 3.958 013:5.620) 3742 3721 SHOE IPAWER 5" MODEL GPV SHOE 5•000 Centralizer General Notes (4131 -4133, Date Note ' OD:6.000) 3/5f2001 NOTE: Multilateral well. B -Sand 1D-1 D-Sand 113 -1021-1 SENSOR (4133.4134, OD:6.250) r SURFACE (4175 -4929, OD:7.000, Wt26.00) r TUBING (4779 -4925, 013:4.500) &SAND LINER (4778 -4925, OD:4.500, _ Wt 12.60) Pert (4925 -7257) r r Casing OR Tubing OR rilling Detail well: 1D -102 41/2" IBT ESP Completion Date: 5/2/2009 G W _ _ ftilli Rig: Nordic 3 Awka, Inc. Depth rt Number .joints Well Equipment Description and Comments Length Tops Page 1 ORKB Nordic 3 30.58 10 3/4 x 41/2 Vetco Gray Tubing Hanger .94 30.58 4 1/2 ", 12.6#, L -80 IBTM Hanger Joint NSCT x IBT 32.00 31.52 4 1/2" 12.6# L -80 IBTM Pup Joint 9.61 63.52 4 1/2" 12.6# L -80 IBTM Pu2 Joint 9.61 73.13 Jts 37 to 114 78 As 41/2" 12.6# L -80 IBTM Tubing 2413.12 82.74 4 1/2" 12.6# L -80 IBTM Pup Joint 5.36 2495.86 Cameo KBG -2 -1 R 41/2" x 1" GLM, w/ DV, BK-5 Latch 6.88 2501.22 4 1/2" 12.6# L -80 IBTM Pup Joint 5.56 2508.10 Jts 5 to 36 32 As 4 1/2" 12.6# L -80 IBTM Tubing 990.07 2513.66 4 1/2" 12.6# L -80 IBTM Pup Joint 5.56 3503.73 Camco KBG -2 -1 R, 41/2" x 1" GLM, w/ DV, BK -5 Latch 6.88 3509.29 - 41/2",12. 6# L -80 IBTM Pu Joint 5.55 3516.17 As 3 to 4 2 As 4 1/2" 12.6# L-80 IBTM Tubing 60.85 3521.72 4 1/2" 12.6# L -80 IBTM Pup Joint 3.13 3582.57 Phoenix Discharge Pressure Sub w/1 pup below 4.17 3585.70 As 1 to 2 2 As 41/2" 12.6# L -80 IBTM Tubing 62.17 3589.87 4 112-" L -80 IBTM Pup Joint 6.02 3652.04 TTC "Bullet Proof'w/Crossover Coupling inside 10.46 3658.06 Tandem Seal Section 13.78 3668.52 190 hp ESP Motor 11.08 3682.30 Phoenix MDT -XT Gauge 1.97 3693.38 Motor Centralizer 2.00 3695.35 3697.35 3697.35 ma 3697.35 20 - Single Channel X -couplings 3697.35 102 - Dual Channel X -couplings 3697.35 446 - 5' Mid t Dual Channel 3697.35 4'- Mid it Dual Channel 3697.35 3' - Mid t Dual Channel 3697.35 2'- Mid it Dual Channel 3697.35 4 - Flat Guards 3697.35 3 - Protectorlizers 3697.35 22 - SS Bands 3697.35 Remarks: Heat trace starts at +/- 3,009' Up Wt 87K Dn Wt 70K Block Wt 35 K Supervisors: Overstreet / Pederson • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ^ Repair Well ^~ , Plug Pertorations ~ Stimulate ^ Other ^ Alter Casing ^ Pull Tubing ^~ ` Perforate New Pooi ~ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Pertorate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConoCOPhillips Alaska, InC. Development 0' Exploratory ~ 200-075 /' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22960-00 • 7. KB Elevation (ft): 9. Well Name and Number: RKB 30' • 1 D-102 • 8. Property Designation: 10. Field/Pool(s): ADL 25650 • Kuparuk River Field / West Sak Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 7378' ~ feet true vertical 3719' • feet Plugs (measured) Effective Depth measured 7357' feet Junk (measured) 4363' true vertical 3720' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 13-3/8" 110' 110' SURFACE 4145' 7-5/8" 4175' 3439' SURFACE 754' 7" 4929' 3752' LINER 2579' 4.5" / 4" 7357' 3720' ~~~C~VG~ PerForation depth: Measured depth: 4778'-7357' ~ p ,. ,_ r „;. ~~~~~ ~ ~ ~~~ ~~ true vertical depth: 3733'-3721' :~ ~.J N~~ 2 ~ 0 9 A(aska Oi6 ~:;~ ;;~~ Con,. Commission ' " Tubing (size, grade, and measured depth) 4.5 , L-80, 3697 MD. n y, Hd'3 ~; i t~ Y"i`,'~'~~~, Packers & SSSV (type & measured depth) eaker SC-~ R liner top pkr @ a77s~ no SSSV 12. Stimulation or cement squeeze summary: ~~\~ S ~ ~ ~~.,~ Q I ntervals treated (measured) not app/icable ~~ ~ 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 364 ~ 8 399 -- 191 Subsequent to operation 304 ' 15 368 -- 174 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: OilO • 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 Brett Packer @ 265-6845 Printed Name B Packer -~-'-~\ rit~e Wells Engineer ~~ ~ Signature ~ ~ Phone: 265-6845 Date g P a b Sha n ll u Orake 263-4612 ~~ -7 ~. v~j Form 10-404 Revised 04/2006 ~'~~~~~ ~~_ .iUL k.~ ~ Zl~~~ ~~'7Submit Original I~~~~ . ~ ConacoPhiilips ;' ~ ! ... :~,.;, , ;~, ~~~~ '_'__'- WtlC 1 102,5[~O/1GG9'.0:53~SlAM _..___. . sp,emar~o-.anwi .... MANGER,31 - r.:~i;V~;~ ~ ~ I ~ CqNDUCTOR, ao-i i o ESP MANDREI, 2.501 ESP MANDREL. 3,509 orsa~arye. '~ ~ 3,506 PACKOFf x ~ ASSY, 3,605 --" PUMP. 3.64d ~ IMAKE.3.656 -~~~ ~ SEAL. 3.669 ESP MOTOR, \ 3,682 SENSOR, 3.693 cemra~zer. '~ ~ .. ~ ~ ; . 3,695 SURFACE,~ 2]d.i]51 - .... t SURFACE,__ 6.175-6.9P9 ~~ G> . ~~ KU P ~ 1 D-102 Wallbore APVUWI Fie1C Name WeIlStatus Incl (°) MD (flK6) jAtt Btrn (ftKB) 500292296000 IWEST SAK IPRODUCING I 93J6 6,304.31 ~~ 7,378.0 IComment ',H25~ppn) ~'.Date Mnotation ~'EnODate IKB-GrA~k) !RigReleaseDate ~SSSV: NONE 0 1 1/1/2009 ~ LastWO: ~ 5/32009 i 39.60 ' 6/22/2000 ~AnnoGtion ~i Depth (RKB) End Date Mnotation ~ Last Mod By I ~;End Data ~~Last Tag: '~ I Rev Reason: Workover, GW C/O, set Pump l Imosbor '~ S114/2009 ' Casing Strin_ s ~Casing Description ~String 0... String ID .. . Top (ttK6J Sat Depth ((... Sat Dapt~ (ND) ... String Wt... String ... Shing Top ThN ~CONDUCTOR 133/8 12.415 39.6 110.0 110.0 6800 l80 WELDED .Gasing Descnption String O.. String ID ._ Top (ftKB~ Set Depth (f... Se[ Depth (ND) ... String NM... String String Top Thrd iSURFACE 7 5/8 6J50 27.1 4.175.0 3,440.5 I 29J0 L 80 BTC-MOD iGasing Description String 0... String ID ._ Top (HKB) Se~ Dapth (f... Set Dep~~ (ND) ... I String VW... String ... Stnng Top Thrd SURFACE ~ 7 I 6.059 4.175.0 4,929.0 ~ 3.752.8 26-00 L-80 BTC-MOD I Casing Oescription String ID ... Top (NKB) ,String 0... I Se~ Dapt~ (t... Set Depth (ND) ...'String VW...'I String ... ~String Top ThN IWINDOW I '~~ 6 ~ 6.000 4,368.0 4.383.0 3,568.1 Casing Description String 0... i5tring ID . _ Top (ftKB) Sat Dapth (f... Sel Depth (ND) ... String Wt... String ... String Top Thrd IA/B SAND LINER 4 ~. 3.548 4.778.1 7,357.0 3,720.5 9.50 L-80 HSLHT 4.Sx4" . ~ ..._. ._...__ ._ _. . .. . . _'_. ___ _. ._ __.__'__ Liner Details Top Depih I _ . I _------- _. __ _. .. . ----._ . _.- ----- - - (ND) ~ Top Incl ~ Top (ttNe) (NKB) . (°) Ifem Dascripti on Commant ~ ID (in~ ~ 4,778.1 ~ 3,733 0'~ 78.SOIPACKER BAKER MODEL SC-1R LWER TOP PACKER 708-00 4.000 I 4,822.8~ 3,741.6I 79J4ISLEEVE BAKER MODEL CMD SLIDING SIEEVE ~ 3.430 r~~inol an~~vya~~~~... ae~vey~~~t~.~l... u..~~~~ 30.6 3,6973 3.139J I 72 CommeM 0 3/4" x 4 12" Vetco Gray Tubing Hanger ~hceniz Discharge Pressure Sub w/1 pup below TC "BWlet Proof' wlCrossover Coupling inside andem Seal Sedion 90 hp ESP Motor 'hcenix MDT-XT Gauge 1obr Cenirallzer ~lugs, vatves, pumps, fish, etc.)__ Com ent 1/2" PACKOFF ASSY OAL=701" ET TTC ESP OAL=3J.5" 1/4" HALF MOON LIB INDICATES TOP OF JO 1OI15 E~ SIOtS __.- - _-____.._ -_ _. __.___.__ _ . _________ S~ot ~ Top (TVD) Btm (TVD) Dens I Btrn (itKB) (flK8) (itKB) Zone Date (s~~~~ Typa CommaM 7,357 3,~52.8 3,72Q5 WS B, AS A4, 6/22/2000 50.0 Screen PeAs ihru screens ~i WS A3. WS A2, ', W SA 7, 1 D-102 VIEW WITH Saeen. 4.925-7.357 a1~S __ >POeP~h Top .. _..___.... _ ___ _.. .. . PoA I I (TVD) Incl OD Valve Latc~ Sae ~TRO Run (fiK8) (°) Maka~ Model (~~) Sarv Typa li Type (~^I . (psi) Run Date ~ Com... 2.390.6~43.41ICamco ~KBG2-1R ~ 1~ESP ~DMV IBK-5 ~O.OOOI 0.0~5/2/2009 3.017.6I50.18ICamco IKBG-2-1R I 1IESP ISOV IBK-5 IO.OOOI O.OISr/2009 wa snwo L INER {.Sz~', •.]]8.].35] - - To~ro-~oz~. - -. 7.378 • ~~~~~~~~~~~~~ Time Log & Summary tNetNiew Wab ReAOrting Re p o rt Well Name: 1 D-102 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 4/30/2009 10:30:00 PM Rig Release: 5/3/2009 6:00:00 PM 4/30/2009 24 hr Summarv Moved rig from 2K-22 to 1 D-102, spotted rig over well, bermed up, RU hardlines to kill tank and MI filter van, heatin 9.6 brine with LRS. 08:30 15:30 7.00 COMPZ MOVE TRNS P Move rig from 2K pad to 1 R turn off. Pull off to side road and let Doyon 15 Cam ass. 15:30 17:00 1.50 COMPZ MOVE TRNS P Continue to move rig from 1 R turn off to KOC CPF 1. 17:00 19:00 2.00 COMPZ MOVE OTHR P Stand by with crews at KOC for field wide chan e out. 19:00 21:30 2.50 COMPZ MOVE TRNS P Cont moving rig from KOC to 1 D Pad. 21:30 22:30 1.00 COMPZ MOVE PSIT P Spot rig overwell, level up, install Handy Berm. Accepted Nordic Rig 3 at 22:30 hrs on 4/30/2009 22:30 00:00 1.50 COMPZ RPCOM RURD P Spot tanks and mudshack, start RU hardline from rig to kill tank and filter van, spot LRS and start heating 9.6 brine for we~l kill. 5/01 /2009 Tested hardline to kili tank, RU circ lines in cellar, pulled BPV, reverse circ 200 bbls hot 9.6 brine down IA, shut in IA and bullheaded 100 bbls down tbg, installed BPV, ND tree, NU BOP, tested all BOPE at 250/3,000 psi, pulled blanking plug and BPV, MU landing jnt, pulled hange rto floor and LD, POOH stand back 4 1/2", s oolin u ESP cable. 00:00 01:00 1.00 COMPZ RPCOM RURD P Cont RU hardline to kill tank and filter van, heat brine, RU circ lines in cellar. 01:00 02:00 1.00 COMPZ RPCOM KLWL P RU lubricator and pull BPV. 280 asi on tb and annulus. 02:00 02:30 0.50 COMPZ RPCOM KLWL P Pressure tested hardline to kill tank at 250/3,000 si, ood test. 02:30 03:30 1.00 COMPZ WELCTI KLWL P Notified security and DSO of possible venting gas, pumped 160 degree 9.6 ppg brine down IA at 4 bpm, holding 280 psi backpressure on choke untii ftuid started up the tbg, had good fluid returns while pumping a total of 200 bbls, shut down and shut in well, monitored for pressure, 0 psi on gauge, slight gas ca on bleeder. 03:30 05:00 1.50 COMPZ WELCTI KLWL P Off loaded remaining 80 bbls into pits, strapped kill tank (196 bbls), RU next vac truck, shut in IA and bullheaded 100 bbls down tbg, staging pump rate up to 3.5 bpm - FCP 560 psi. 05:00 06:30 1.50 COMPZ WELCTI OWFF P Shut down and shut in well, monitored for pressure, 0 psi on gauges but still a slight gas cap, opened tree, well dead, installed BPV. 06:30 07:30 1.00 COMPZ WELCTL NUND P ND and inspect tree, install blanking lu . 07:30 09:30 2.00 COMPZ RPCOM OTHR P Spot crane and remove ESP cable spooi and replace with empty spool for ullin com letion. 09:30 14:00 4.50 COMPZ WELCTL RURD P NU 13 5/8" BOPE w/11" DSA and w/ 2 7/8" x 5 1/2" variable rams in both u er & lower i e rams. 14:00 17:00 3.00 COMPZ WELCTI BOPE P RU test e ui ment function and PT BOP rams, choke manifold and annular to 250/3000 psi. Witnessing of test waived by AOGCC (Bob Noble 15:30 hrs on 4-30-2009. 17:00 18:00 1.00 COMPZ RPCOM PULL P Pull BPV set isolation sl v. MU landin 't in han er. BOLDS. 18:00 1830 0.50 3,701 3,671 COMPZ RPCOM PULL P Heat wellhead w/steam. Unland tubing hanger w/150k, pulled hanger to floor u wt 90K. Break out penetrators, LD hanger and landing 18:30 ~ 00:00 ~ 5.50 ~ 3,671 ~ 1,660 ~COMPZ~ RPCOM P spooling up ESP cable and heat trace from 3,701' to 1,660' 5/02/2009 Cont POOH stand back 4 1/2" tbg, RIH with test packer to 4,150' and test 7 5/8" csg, POOH LD packer and DP, stand back tb , MU new ESP um assembl , RIH with 4 1/2" IBTM ESP com letion to 1,380'. 00:00 03:30 3.50 1,660 54 COMPZ RPCOM PULL P Cont POOH with 4 1/2" ESP completion from 1,660' to pump assembly, hole taking 10 to 11 bph, had dama ed cable at MLE. 03:30 06:30 3.00 54 0 COMPZ RPCOM PULD P Cut cable, test motor (bad test indicating grounded), obtain oil samples, break down pump assembly, bottom of motor had oily water, top section had burnt oil, cross over on coupling is good, clean and box up for shipping, clean rig floor, all SS bands and cannon clamps accounted for, wrap used ESP cable for shipping. Set wear 06:30 08:30 2.00 0 1,624 COMPZ RPCOM TRIP P RU tools for runnina RBP & oacker.,, PU, MU RBP & Retrievamatic packer, 18 jts of 3 1/2' drillpipe and RIH on 4 1/2" IBT tubing from derrick to 1624'. 08:30 09:30 1.00 1,624 1,624 COMPZ RPCOM OTHR P Shut down, RU crane and swap out ESP cable s ools. 09:30 12:00 2.50 1,624 4,147 COMPZ RPCOM TRIP P Contine to RIH w/ w/ RBP & packer to 4147'. Set retrievamatic packer. Hole still taking ap roximatel 10 bbls per hour. 12:00 13:00 1.00 4,147 4,147 COMPZ RPCOM PRTS P Pressure test IA to 2500 psi and chart for 30 min. ood test. 13:00 16:30 3.50 4,147 0 COMPZ RPCOM TRIP P Release Retrievamatic Packer (a~ 4147'. POOH standing back 4 1/2' IBT tubing and laying down 3 1/2" drill i e. 16:30 19:00 2.50 0 45 COMPZ RPCOM RCST P Pull wear ring. RU tools and rig floor for running ESP completion. PU motor and seals and service both. 19:00 00:00 5.00 45 1,380 COMPZ RPCOM RCST P PJSM, RIH with 4 1/2" IBTM ESP completion, to 688', MU heat trace, cont RIH testing ESP cable every 1,000', to 1,380'. 5/03/2009 Cont RIH w 4 1/2" IBTM ESP completion, MU hanger and landing joint, splice ESP and heat trace, landed hanger, RILD's, tested void, LD landing jnt and installed 2 way check, ND BOPE, NU and tested tree, pulled 2 wa check, freeze rotected well, set BPV, ulled ri off well, cleaned well site. 00:00 06:00 6.00 1,380 3,665 COMPZ RPCOM RCST P Cont RIH with 4 1/2" IBTM ESP completion checking integrity every 1,000', to 3,633' MU hanger and landin 'nt. 06:00 09:00 3.00 3,665 COMPZ RPCOM HOSO P Splice ESP cable and heat trace to enetrators. 09:00 09:30 0.50 COMPZ RPCOM HOSO P Drain stack, Land hanger. RILDS. Test ackoff /void 5000 si. 09:30 11:30 2.00 COMPZ RPCOM NUND P Pull isolation sleeve. Set Two-way check. ND BOPE. 11:30 12:00 0.50 COMPZ RPCOM OTHR P Checked the ESP cable/motor electrical integrity and megger the Heat Trace and record same. RD both cable s oolers. 12:00 13:00 1.00 COMPZ RPCOM NUND P NU tubing head and adapter and tree. Test tree to 5000 psi. Test hanger void/packoff to 5000 psi. Pull two-wa check. 13:00 15:30 2.50 COMPZ RPCOM FRZP P Freeze rotect the well by pumping 40 bbls diesel down the tubing and 70 bbls down the IA. 15:30 16:30 1.00 COMPZ RPCOM OTHR P RU lubricator and set Vetco-Gray 4" H-BPV in tubing hanger profile, SITP = 400 si, IA = 400 si. 1630 18:00 1.50 COMPZ RPCOM RURD P Pull rig off the well, remove mat boards, clean cellar box and tree. Re~eased Nordic Rig 3 at 18:00 hrs on 5/3/2009 1D-102 PTD(200-075) Reporl~failed ESP # Page 1 of 1 Regg, James B (DOA) . From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Saturday, March 21, 2009 12:27 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv Subject: 1 D-102 PTD(200-075) Report of failed ESP Tom, Jim ~/ 1 D-102 PTD(200-075) ESP failed down hole on 3/20/2009 due to a down hole electrical short (balanced phase to phase, imbalanced phase to ground). The last welltest was on 3/14/2009; the well produced 364 bopd at 52% watercut and 15 mscf/d formation gas at 522 psi pump intake pressure. This well has a single casing string and will not be gas lifted. A rig workover will be needed to return the well to production. This ESP completion was installed on 5/8/2008 by Nordic 3. The well was placed on production on 5/23/2008 and ran for 301 days before failure. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 ~.w~,_. 3/23/2009 • STATE OF ALASKA ~Jtrj~ ~ ~ 1~~i~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERAAT=°~1~. ~~~~ 1. Operations Performed: Abandon ^ Repair Well ^~ Plug Pertorations ^ Stimulate ^ Qt(~r ^ Alter Casing ^ Pull Tubing ^~ •Pertorate 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: ConocoPhillips Alaska, InC. Development ~ Exploratory ^ 200-075 / 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22960-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 30.5' 1 D-102 8. Property Designation: 10. Field/Pool(s): ADL 25650 Kuparuk River Field /West Sak Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 7378' feet true vertical 3719' ~ feet Plugs (measured) Effective Depth measured 4363' feet Junk (measured) 4363' true vertical 3556' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 80' 13=3/8" 110' 110' SURFACE 4145' 7-518" 4175' 3439' SURFACE 754' 7" 4929' 3752' LINER 2579' 5-1/2" 7357' 3720' Perforation depth: Measured depth: screens 4778'-7357' pp++,,y~~~yy ~~yy r~fntee JUL ~ ~t1vD ~ true vertical depth: 3733'-3721' ~af~19f~ Tubing (size, grade, and measured depth) 4-1/2", L-80, 3702.6' MD. Packers &SSSV (type & measured depth} no packer no SSSV 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 SI Subsequent to operation 348 ~ 17 280 -- 188 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 N/A if C.O. Exempt: none contact Brett Packer @ 265-6845 Printed Name Brett Packer Title Wells Group Engineer 6 /~~/ Signature "'"' ~~~ Phone: 265-6845 Date ~(~`l~ D Pre a b Sharo All 263-4612 ((''''~~ /- # S ~~~. ~tJk~ ~ ~ 20DB .~ ~. 8'.a8 Form 10-404 Revised 04/2006 ~ tr•(~ ~ ~ ~! A L Submit Original my 11~~ 'V ~~~~•~ 1 D-102 Post Workover • DATE SUMMARY 5/17/08 ATTEMPTED TO SET 46' TTC ESP PUMP . UNABLE TO GET PUMP PAST 3640' SLM. REMOVED PUMP FROM WELL AND NOTICE VISIBLE SCRAPE MARKS THE LENGTH OF THE PUMP. IN PROGRESS. 5/18/08 SET 4 1/2 TTC ESP PUMP (46' OAL )@ 3649' RKB. SET 4 1/2 D&D PACKOFF ASSEMBLY W/ KOBE AND CHECK VALVE (100.5" OAL) IN TOP OF PUMP @ 3603' RKB. PULLED DGLV AND SET 2000 PSI TBG. SHEAR VALVE @ 3506' RKB. TESTED PACKOFF AND SOV TO 1000 PSI (GOOD TEST ). (( DID NOT INSTALL SLIP STOP )). JOB COMPLETE. ~._ __ ~ ~KUP 1 D-102 I I ~ ~fl~ll~{If~ API/DWI s i ,..,, ~ '~, FIe~~Nam {Ij e ~ a : _ W II S[atua Maximum Inclination (") I otal Depth (hKB) ' "' 5002922960 _ WEST SAK PROD 93.76 7407.0 Comment H2S (ppm) Date Annotati... End Date KB-Grountl Distance (ft) IRig Release Date „zo co„ny 1o uis. r~l ull200e 1n ea.1a nr.~ SSSV: NONE Last WO: 5/9/2008 39.60 6/2212000 s,.hPm.~ii~.. Actual..... -F.nnotation Depth (HKB) End Date Annotation - End Date Il Last TaD~ 4,363.0 5!4/2008 Rev Reason: FORMAT UPDATE 6/18/2008 _ _ + Casing Description ~ OD (In) ID (In) Top (ftKB) Set Depth (hKB) Set Depth (ND) (ftKB) .. Wt (Ibsrh) Grade 1 op G nnection CONDUCTOR 13 3/8 12 415 0.0 110.0 110.0 68.00 L-80 WELDED ~ Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (ND) (ftKB) Wt (Ibslft) Grade Top Connection E SURFACE 75/8 6.750 0.0 4,175.0 3,440.5 29.70 L-80 BTC-MOD HANGER 28 Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (ND) (ftKB) Wt (Ibslk) Gratle Top Connection - SURFACE 7 6.059 4,175.0 4,929.0 3,752.8 26.00 L-80 BTC-MOD _ Casing Description _ OD (In) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (ND) (ftKB) Wt (Ibs/k) Gmtle Top Connection I WINDOW 6 6.000 4,368.0 4,383.0 3,568.1 ( __ Casing Description ' OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Deptb (ND) (ftKB) Wt (ibsttt) Gratle Top Connection ''(PRODUCTION ~ 41/2 4.000 4,778.0 7.357.0 3.720.5 12.60 L-80 ~ HSLHT ~_...... Imc. Tub 1. ~~I,:~.V rcl....... ., n l~. i., ~~.I ~il,,.C Iv ;, t'. a r.~..... I« ~ I.~ ~ii.~„ . TLI I l l CONDUCTOR, 0-110 ~ ~ - `... w _. I 1 op (TthB) Item Descdphon ent _ I lu pn1 MANDREL, ESP PACKOFF ASSV, 3,595 PUMP, 3,603 XO W/INTAKE, 3,fi49 ESP SEAL, 3,668 ESP MOTOR, 3,682 ESP GAUGE, 3,699 CENTRALIZER, 3,701 SURFACE, =: i t »~ ~:. € «' E -.: a ~ WINDOW, 4,368-0,363 a~ WINDOW, 4,388-0,383 JUNK, 4,363 d SURFACE, 4,1]5-0,929- PRODUCTION, J I 4,778-7,357 TD (1D-102),7,3]8 I 3.668.31 ESP SEAL ICentralift ESP Tandem Seal section G563DB I I f - e - e _ -~ Top (ftKB) Description ~ommen[ Kun Uate w (m( 3,594.6 PAC KOFF ASSY jSET D&D PACKOFF ASSY W/ KOBE AND CHECK VLV 100.5" OAL set 5/18/2008 1.610 15/18/2008 4,363.0 JUNK S 1/4" HALF MOON LIB INDICATES TOP OF JOINT 4/30/2008 4/27!?nn8 j 0.0001, " '. _. 'I SI,~[ Galcul... I ~ etm Top (ND) Btm (ND) Dens Shot (Top (ftKB) (ftKB) (ftKB) (ftKB) Type Zone (sho... Total Date Comment 4,778.0 7,357.0 3,733.0 3,720.5 SCREEN WS B, 50.0 6/222000 Perfs thru screens 1D-102 End Date Annotation ~~ pth Valve latch Port iRU /tun I tKB) Make Model OD fin/ Type Type (Size (in) (Psi) Run Date Comment Cor~ocoP~i~ips Time Log Summary Welrv7ew Y/eb Reporting Well Name: 1 D-102 Job Type: RECOMPLETION _ -- - Time Logs - -- -- - --- - ---- Date ____ From To Dur S__De th E. Dapth Phase Code Subcode T CO_M_____ __ _ 04/27/2008 08:00 09:30 1.50 MIRU MOVE OTHR NP Standby w/ crews while waiting on hi hline ower to ri down. 09:30 14:00 4.50 MIRU MOVE MOB P Move rig from 1J-174 to 1 D-102. 4 miles, derrick down. 14:00 15:00 1.00 . MIRU MOVE RURD P MIRU, spot & level rig over 1 D-102. ACCEPT NORDIC RIG 3 THIS DATE 15:00 17:00 2.00 COMPZ RPCO RURD P Spot misc. rig equipment. 17:00 18:30 1.50 COMPZ RPC06 NUND P R/U lubricator and pull BPV. 350 psi on Tb & IA. 18:30 00:00 5.50 COMPZ RPCOb OTHR P Flush lines & clean pits w/ filtered seawater in re for filtered brine. 04/28/2008 00:00 01:00 1.00 COMPZ RPCOti CIRC P Take on 255 bbls hot filtered seawater w/ 6% KCL to rig pits. RU tree lines for well kill. Plumb to kill tank /all related a ui . 01:00 03:00 2.00 COMPZ RPCOh CIRC P PT hard lines to 2500 psi. Vent gas off tbg & IA. Reverse circ. 255 bbls hot filtered seawater w/ 6% KCL down annulus taking returns out the tubing. Good returns. Shutdown w/ 140 psi on tbg & IA. Calc'd KWF to be 9.5 03:00 04:00 1.00 COMPZ RPCO CIRC P Load pits w/ filtered 9.6 ppg brine w/ 6% KCL. 04:00 06:30 2.50 COMPZ RPCOh CIRC P Reverse in 9.6 ppg filtered brine w/ 6% KCL at 3 bpm. ICP = 220 psi, FCP = 160 psi. Still seeing some diesel/crude in returns. Cont circ clean 4 b m / 260 si. 06:30 07:30 1.00 COMPZ WELC OWFF P Monitor well pressures, confirm well dead. "O" psi tbg /annulus. Well on vac. 07:30 09:30 2.00 COMPZ RPCOh NUND P PJSM, Set BPV, ND prod tree. 09:30 10:30 1.00 COMPZ RPCOh PULD P PJSM, Place ESP spools / equip to ri floor. 10:30 14:30 4.00 COMPZ RPCOh NUND P PJSM, NU BOPE, all related equip. C!O lower pipe rams to 4-1/2" because no test joint on hand yet for 2-3/8". 14:30 21:30 7.00 COMPZ WELCT BOPE P PJSM test BOPE to 250/2500, afl components, all floor safety valves. BOP test witnessed by Chuck Sheve-AOGCC. Perform time / volume / ress test to accumulator. i ~;~~,, ? cr 1:~ • • Time Logs J _ __ _ Date Frorr7 To Dur S De th E De th Phase Code S bcode T COM 04/28/2008 21:30 22:30 1.00 COMPZ RPCOh PULD P _ Pull blanking olua. null BPV & install side isolation sleeve. 22:30 23:00 0.50 COMPZ RPC06 PULD P PU landing jt. &-attach pup,. BOLDS. Pull hanger free w/ 180K Ibs (35K block wt . 23:00 00:00 1.00 COMPZ RPCO PULD P Pull han er to riq floor, 95K UP wt• Test ESP & heat trace penetrators and lower connectors. Cut connector & s lice. La down han er 04/29/2008 00:00 01:00 1.00 COMPZ RPCO CIRC P RU to tubing and circ bottoms up @ 5 b m, 160 si. 01:00 02:00 1.00 COMPZ RPC06 PULD P Attach ESP cable and Heat trace to s ools. RU to ull com letion. 02:00 12:00 10.00 COMPZ RPCO PULD P Pullin ESP com letion standin back - / " jpg, spooling up ESP cable and heat trace, removing clamps , and bands. 12:00 13:30 1.50 COMPZ RPCO PULD P L/D ESP Seals & Motor. 13;30 15:00 1.50 COMPZ RPC06 PULD P Clean and clear rig floor. RU to run BHA #1 and drill i e. 15:00 15:30 0.50 COMPZ RPCO TRIP P Set wear ring. 15:30 17:00 1.50 0 294. COMPZ FISH TRIP P PU BHA #1, 5 3/4" Washpipe w/ 6.125" Shoe & VACS Tool., on 31/2" IF Drill Pipe. Total BHA Length = 294.35' 17:00 21:00 4.00 294 4,000 COMPZ FISH TRIP P Trip in hole with BHA#1 picking 31/2" drill i e sin les. RIH to 4000' MD. 21:00 22:00 1.00 4,000 4,000 COMPZ RIGMN' SVRG P Service Top Drive. Change out saver sub. Set torque values for milling arameters. 22:00 22:30 0.50 4,000 4,177 COMPZ FISH TRIP P Continue TIH picking up DP singles from 4000', to tag on'junk" at 4177 DPM. UP WT = 90K, SO WT = 73K. 22:30 00:00 1.50 4,177 4,177 COMPZ FISH MILL P Make up Top Drive. Obtain milling parameters. ROT WT - 80K. Pumps at 208 GPM's - 1080 PSI. Tag & mill on Munk" at 4177, with 1-2K WOB, milling torque from 2-6K ft/Ibs, and 80 RPM's. Observed little or no success in gaining hole, with string stalling. Utilize MI Swaco filtration unit to filter returns pits at 2.5 - 5 BPM. Brine weight - 9.4 PPG. Total fluid losses for the da = 397 bbls. 04/30/2008 00:00 00:30 0.50 4,177 4,177 COMPZ FISH MILL P Continue mill on'junk". @ 4177 MD. ROT WT - 80K. Pumps at 208 GPM's - 1080 PSI, with 1-2K WOB, milling torque from 2-6K ft/Ibs, and 80 RPM's. Observed little or no success in ainin hole, with string stalling. Utilize MI Swaco filtration unit to filter retums pits at 2.5 - 5 BPM. Brine wei ht - 9.4 PPG. Decision to POOH. • Time Logs __ _ _ ~ .Date ___From To Dur 5 Depth E. De th Phase Code_ Subcode _ T COM _ _ 04/30/2008 00:30 02:00 .1.50 4,177 4,177 COMPZ .FISH CIRC P Circulate.bottoms up at 4 BPM -1100 PSI. No gas, minimal fluid loss. Blow down To drive. Monitor well -static. 02:00 04:00 2.00 4,177 294. COMPZ FISH TRIP P POOH with BHA #1 from 417T - 294'. Observed displacement 12 BBLS more than calculated. 04:00 05:00 1.00 294 0 COMPZ FISH PULD P Break out & lay down BHA #1. Inspect and guage shoe to8.125". Make up BHA #2 with 6" milling shoe on wash i e. Total BHA len th = 293.0'. 05:00 08:00 3.00 0 4,292 COMPZ FISH TRIP P Trip in hole with BHA #2 on 31/2' DP from derrick to 4292'. 08:00 09:30 1.50 4,292 4,292 COMPZ RPCO OTHR P Change out ESP cable spool while crane available. 09:30 10:00 0.50 4,292: 4,353 COMPZ FISH TRIP P Continued to RIH tagged Cad 4353'6 Up wt 95K Dwn 75K. 10:00 11:00 1.00 4,353 4,353 COMPZ FISH MILL P Attempt to circulate down, unsuccessful. PU est. rotation, _ attem t to work ast tag_deoth 4353'.., ROT 80 RPM Up wt 95K Dwn wt 75K, ROT wt 82K. Stopped rotation, attempt to push down by putting 10K on obstruction, unseccessful. 11:00 11:30 0.50 4,353 4,353 COMPZ FISH CIRC P Circulate hole clean. 11:30 13:00 1.50 4,353 0 COMPZ FISH TRIP P POH with BHA #2. 13:00 15:00 2.00 0 0 COMPZ RPCOh TRIP P UD BHA #2. Cuttin ed a of 6"shoe worn down smooth. 15:00 18:00 3.00 0 4,359 COMPZ FISH TRIP P PU 2 3/8" mule shoe, 2jts 2 3/8" tubing, bumper sub and jars. on 3 1/2" drill pipe, RIH. Tagged solid @ 4359'. Rotate mule shoe 1/2 turn attempting to work buy bad spot with no success. PU 6', kicked pump on and tried to wash down with no success. 18:00 21:00 3.00 4,359 336 COMPZ FISH TRIP P Breakout & blowdown TD. Monitor well - static. POOH from 4359' - 336'. 21 `00 22:00 1.00 336 0 COMPZ FISH PULD P Lay down BHA. Inspect mule shoe: Obtain pictures. No damage observed. SIMOPS: RU Halliburton Slickline unit. 22:00 00:00 2.00 0 0 COMPZ FISH SLKL P Held PJSM. Discuss safety & hazard issues. make up Halliburton Slickline sheaves. MU 5.9" Lead Impression block assembly. WLIH to tag @ 4359' WLM. Tap LIB with s an s one time. WLOH. Ins ect LIB obtain pictures.L16 indicated setting down on i e. Total Fluid loss for the da = 187 BBLS. 05/01/2008 00:00 01:00 1.00 0 0 COMPZ FISH SLKL P Rig down Slickline sheaves & unit. Clean & clear floor area. 01:00 02:30 1.50 0 0 COMPZ EVALV~ WOEQ P Loadpipe shed with ESP completion equipment, while wait on Halliburton E-line Video unit & e ui ment. ~'.~ge 3 of '0 • C~ Time Logs T COM _ Date From To Dur S De th E. D th Phase Code Subcode 05/01/2008 02:30 04:30 2.00 0 .4,359 COMPZ EVAL _ TRIP P _ Decision to TIH with mule shoe assembly to circulate and attempt to clean wellbore fluid for video run. Utilize MI filtration unit on location. TIH to to at 4359' 04:30 06:30 2.00 4,359 4,359 COMPZ EVALV~ CIRC P Circulate at 84 GPM's - 100 PSI. Stage pump rate up to 296 GPM @ 820 psi. Run returns through filtration unit, and pump cleaner fluid into well bore. Well bore fluids clean for running Haliburton down hole video. 06:30 08:30 2.00 4,359 0 COMPZ EVAL11~ TRIP P POOH from 4359' standing back drill pipe, laying down bumper sub, jars and muleshoe. 08:30 12:00 3.50 0 0 COMPZ EVAL ELOG ND riser from to of BOP stack. NU shootin flan a for wireline lubricator. 12:00 18:30 6,50 0 0 COMPZ EVALW ELOG P PJSM ; RU Haliburton Wireline unit for running video. Ran video to top of obstruction @ 4353 wireline measurements. Results not conclusive enou h t~ o~ determination on what is in hole 4353'. WLOH, lay down. camera assembl . 18:30 00:00 5.50 0 0 COMPZ EVAL ELOG P Rehead, and change out spools on Eline unit. Make up Gyro data assembly. Troubleshoot communication issues. There was a voltage issue, suspecting trouble with the 30,000 ft of line on spool. Total . fluid loss for the - 05/02/2008 00:00 02:30 2.50 0 0 COMPZ EVAL ELOG T Continue trouble shoot issues with communication to Gyro data assembly. No success. Decision to get Sperry Sun Gyro unit. Standby for unit to arrive. RD Eline truck to make room for next unit. 02:30 04:00 1.50 0 0 COMPZ EVALIPo ELOG T Spot & RU Gyro.unit. MU Gyro Data assembl . 04:00 07:00 3.00 0 0 COMPZ EVAL ELOG P WLIH with Gyro Data assemby to 4350' WLM. Obtain data surveys. WLOH, la down assembl . 07:00 08:00 1.00 0 0 COMPZ EVALW FLOG P ND shooting flange. NU riser. 08:00 09:00 1.00 0 0 COMPZ EVAL TRIP P MU Baker 7 5!8" Retrievamatic. Move drill collars to off drillers side of derrick to et out of the wa . 09:00 11:30 2.50 0 4,083 COMPZ EVALVb TRIP P RIH and set 7 5/8".Retrievamatic 4083°. UP WT = 85K, SO WT = 70K 11:30 18:00 6.50 4,083 4,083 COMPZ EVAL RURD P RU safety valves xovers etc to et to _ Eline BOP and lubricator. RU Schlumberger (Nitrogen) pumper and ardlme. l I Time Logs _ Date., From To Dur S. De~th._E..De th-: Phase CodeSubcode T COM__ _ 05/02/2008 18:00 19:30 1.50 4,083 4,083 COMPZ EVALVI~ FLOG P WLIH with 1 11/16" camera to 2400' WLM @ 10-100 fUmin. Observed camera lens became covered with grease. Pump down drill string with SWS nitrogen, and observe 1250 PSI surface ressure. 19:30 20:00 0.50 4,083 4,083 COMPZ EVAL FLOG P WLOH. Shut in drill string. Bleed lubricator. Break off lubricator, and re lace camera lens. 20:00 22:00 2.00 4,083 4,083. COMPZ EVALVI~ -FLOG P Make up Lubricator, Pressure to equalize at 135D PSI. WLIH to 3000' and observe camera lens once again blacked out covered in rease. 22:00 22:30 0.50 4,083 4,083 COMPZ EVAL FLOG P WLOH. Shut in drill string. Bleed lubricator. Break off lubricator, and clean camera lens. 22:30 00:00 1.50 4,083 4,083 COMPZ EVAL FLOG P Make up Lubricator, Pressure to equalize at 1380 PSI. WLIH to 3100' observin camera lens-clear with no issues. Running speed from 10100 ft/min. Surface pressure observed. _ 1420 PSI. 05/03/2008 00:00 03:00 3.00 4,083 4,083, COMPZ EVALW FLOG P Continue WLIH with 1 11/16" Video camera assembly from 3100' - 4351 WLM. Observed clean lens, and nitrogen pressure at surface = 1680 PSI. Observed with camera that there is a 3" "rin "from the 6" it hun in the 7" casin collar at 43 ' WLM. We could not see ve f the rin ,and did not observe an colla sed casin or fu h obstruction. Repeat attempts to get camera beyond the ring, with no success. Pull back up hole and obtain ood video of the transition from 7 5/8" casing to 7" casin . WLOH with camera. 03:00 03:30 0.50 4,083 4,083 COMPZ EVAL FLOG P Shut in the drill string with camera in the lubricator. Bleed lubricator pressure. Breakout & lay down assembly. Breakout and rig down Schlumber er nitro en crew. 03:30 04:30 .1.00 4,083 .4,083 COMPZ EVAL RURD P Breakout crossover above pump in sub. Held PJSM. Discuss safety & hazard recognition issues. Discuss procedure to bleed pressure, and release packer. Rig up and make up Top drive to drill string. Pump down drill string 40 BBLS to kill well. Pick up drill string to observe packer valve equalized and open. Immediate returns in the annulus. _Time Los - 9---- - ---- --- ---- : Date From To Dur _ S Depth E. De th Phase . Code=., Subcode T COM _ _ 05/03/2008 04:30 07:00 2.50 4,083 4,083 COMPZ EVALIPo CIRC P Begin circulation a 3 BPM observing flow increasing. Shut down pumps, and line up through choke manifold. Bring pumps up to 1.5 BPM with 20 PSI drill string pressure, and 700 on the choke. Circulate toallow well to unload nitrogen, and balance well with 9.4 ppg brine. Pumped 3 hole volumes, monitor well, small trickle of flow. 07:00 10:30 3.50 4,083 4,083 COMPZ EVALVb CIRC P ND pump in sub.-Circulate another BU 3 BPM 150 psi. Monitor well. Well dead. Discussed with AOGCC (John Krisp) Annular shutin as a recautiona messure no need to ret t Annular. 10:30. 14:00 3.50 4,083 0 COMPZ EVALW TRIP P POH with Retrievamatic Packer and standing back drill pipe, monitoring hole fill LD acker. 14:00 14:30 0.50 0 0 COMPZ FISH CIRC P MU BHA (saearl for fishing 3" end of. 14:30 16:00. 1.50 0 4,361 COMPZ FISH TRIP P RIH on drill pipe.. Tagged fish @ 4352'. Up wt 95 down wt 74K. PU free, lowered back down past 4352' and to ed u 4361. 16:00 19:00 3.00 4,361 0 COMPZ FISH FISH P POOH with fish, standing back drill pipe. Hung up @ 4177, (Sperry Allignment Tool). Pulled 30 over string wt. working up and down, rotated to left 2 turns and bumped with jars with 25K over. Dragged for approx. 2-3 ft., until we were inside the 7 5/8" casing. Continued to POOH free, no drag. Breakout & lay down fish & fishing assembly. Recovered "3" ringed" end of mill shoe and a flat uard band in the s ear ra le. 19:00 20:30. 1.50 0 338 COMPZ FISH PULD P Held PJSM. Make up BHA #5, 2.3/8" mule shoe & 2 joints for dummy run through window area. Total BHA len th = 338'. 20:30 22:30 2.00. 338 4,363 COMPZ FISH TRIP P Trip in hole with BHA @5. Observed . proper displacrement. Tag "junk" at 4363' DPM re eat attemptsto get throu h 'unk settin down 10K. No succes . UP WT = 93K, SO WT = 74K Pum sat 3 BPM - 180 PSI. 22:30 00:0.0. 1.50 4,363 4,363 COMPZ .FISH CIRC P Circulate bottoms up @ 3 BPM - 180 PSI. Total fluid for the day = 128 BBLS. 05/04/2008 00:00 00:30 0.50 4,363 4,363 COMPZ FISH CIRC P Continue circulate bottoms up at 3 BPM - 180 PSI. Observed minimal gas at surface. Moriitor well -dead 00:30 03:15 2.75 4,363 0 COMPZ FISH TRIP P Trip out of hole with BHA #5. Breakout. & lay dowh BHA. Observed proper hole fill. I ~a3c~bot i0 1 Time Lo s -- g ---- - -- - --- - - --- -- ~ Date__ From To Dur S Depthh_ E. Depth Phase Code_ Subcode T _C~M _ _._ 05/04/2008 03:15 03:45. 0.50 0 0 COMPZ FISH PULD P Clean & clear floor area. PuA. tools to rig floor. Held PJSM with crew & fishin too! re . 03:45 04:45 1.00 COMPZ FISH PULD P Make u BHA #6 6" Millin shoe with 1 joint of 5 3/4" washpipe & boot baskets. 04:45 07:15 2.50 0 4,177 COMPZ FISH TRIP P Trip in hole with BHA #6. Observed ro er dis lacement. 07:15 08:00 0.75 4,352 4,352 COMPZ FISH TRIP P Ta ed u on S er Ali nmentTool 4177, worked thru with 20K overwt. continued on and tagged up @ 4351.5'. 08:00 10:00 2.00 4,352 4,353 COMPZ FISH MILL P . Milled on obstruction from 4351.5' to '. Up wt 90K Dwn wt 74K Rot wt 83K Free Torque 2K, ROT Torque 3K to 5K max. Returns showing signs of cement scale and ossibl formation. 10:00 11:00 1.00 4,353 4,353 COMPZ FISH CIRC P PU to 4345' circulated hole clean. 11:00 14:00 3.00 4,353 0 COMPZ FISH TRIP P POOH standing back drill pipe and drill collars. LD BHA. 14:00 15:00 1.00 0 0 COMPZ FISH OTHR P Load out fishing tools for shipping back to sho . 15:00 17:00 2.00 0 0 COMPZ RPCOh RURD P Clean rig floor and prep tools for running ESP completion. Hang Sheave. 17:00 00:00 7.00 0 0 COMPZ RPCOh RCST P Held PJSM. Discuss safety & hazard recognition issues. Pick up Motor , Phoenix gauge, Tandem Seal section. Fill motor with oil, ensure good rotation of motor. Continue MU ESP assembly attaching control line to discharge sub. Megger test line, continue RIH with completion on 4 1/2" tbg string in derrick. Total fluid loss for the da = 3 BBLS. 05/05/2008 00:00 04:30 4.50 0 1,063 COMPZ RPCO RCST P Continue run ESP completion on 4 1/2" tb strip in derrick. Inistall GLM's as er detail. 04:30 10:00 5.50 . .1,063 1,063 ' COMPZ RPCOh RCST T Observed ESP cable hung up in slips, and damaged the armor and wires. Pick u ,ins ect. Make news lice. 10:00 12:00 2.00 1,063 1,886 COMPZ RPCO RCST P After splice, check electrical on cable, heat trace, and Phoenix Guage. Continue in hole with ESP on 4 1/2" tb strip from derrick.to 1886'. 12:00 19:30 7.50 1,886 3,655 COMPZ RPCOh RCST P Continue RIH with ESP completion to 3655'. UP WT = 95K, SO WT = 72K Observed ro er dis lacement on TIH. 19:30 20:30 - 1.00 3,655 3,655 COMPZ RPCOh RCST P Make up landing joint & hanger. Ru to s lice ESP cable. • • .Time Loas Date From To Dur S. Depth E. De th_ Phase Code Subcode T COM _ ~ 05/05/2008 20:30 00:00 3.50 3,655 3,655 COMPZ RPC06 RCST P Perform splicing operation on ESP cable as per Centrilift rep. Monitor well -static. Ran a total of 87 dual channel cannon clamps, 18 single channel, 2 - 4' Dual Channel, 3 - 3' Dual channel, 5 - 2' Dual channel, 3 protectolizers, 443 - 5' Dual channel & 26 ss bands. 05/06/2008 00:00 01:00 1.00 3,655 3,688 COMPZ RPCO RCST P Complete ESP. cable splice to penetrator. Install to hanger. Splice Heat trace. MU to han er. 01:00 01:30 0.50 3,688 3,688 COMPZ RPCO RCST P UP WT = 95K, SO WT = 72K. RIH land tbg hanger. RILDS. Tbg string with centralizer located at 3688' MD. Perform megger test on ESP cable, test good. Transfer fluid in pits to u ri ht tanks for next well. 01:30 05:00 3.50 0 0 COMPZ RPCOh NUND P Install H-BPV. Nipple down BOP , stack. SIMOP: RU Little Red hot oil heat KCL water for next well, prep for freeze rotect. 05:00 07:00 2.00 0 0 COMPZ RPCOh NUND T Before ni le u of tree re-test ESP cable/motor electrical integrity. Test showing high voltage leak off (sign of insulation breakdown). Checked several times with digital meter and analo meter, same results. 07:00 12:00 5.00 0 COMPZ RPCO NUND T Re-Set blanking plug. Nipple back up BOP 12:00 17:00 5.00 COMPZ WELC BOPE T Function and PT ROPE rams and choke manifold t 250/2500psi, Pt annular to 250/2500 psi. Witnessing of test waived b AOGCC Bob Noble . 17:00 18:30 1.50 COMPZ RPCO PULD T Pull test dart, set isolation sleeve. BOLDS. Pall han er to floor. 18:30 20:00 1.50 COMPZ RPCO DHEQ T Check penetrator, cut splice and found high voltage leak off still in system downhole. 20:00 21:00 1.00 COMPZ RPCOI~ OTHR T Lay down hanger and landing joint. Strin u heat trace sheave. 21:00 00:00 3.00 3,655 2,265 COMPZ RPCO TRIP T . Pooh f/ 3,655' to 2,265' inspecting ESP Cable for damage -found none. 93k u wt., 71kdo wt. 05/07/2008 00:00 08:00 8.00 2,265 40 COMPZ RPCOf1 TRIP T Continue to Pooh f/ 2,265' to ESP Motor, take out Pothead to determine if bad Pothead or bad Motor., Water was found in the Pot head. Put Pothead back in. 08:00 11:00 3.00 40 0 COMPZ RPCOI~ RURD T Lay down Motor and seals, box up and move out of pipe shed. Clean & organize rig for re-run. Making up s lice on new Motor Lead. 11:00 13:00 2.00 0 COMPZ RPCO DHEQ T New Motor and seal section arrived, load in pipe shed and prep for running. Continue with s lice on Motor Lead. 13:00 17:00 4.00 0 122 COMPZ RPCOti DHEQ T PJSM. MU & Service Motor ,.Seal Section, & Phoenix Gua e. • • Time Logs -- Date ___ From To Dur S De th E_(7e~th _Phase _Code Subcode T COM_ 05/07/2008 17:00 20:00 3.00 122 1,063 COMPZ RPCO RCST T Rih w/ 4 1/2 ESP Completion f/ 122' to 815'. Start heat;trace, bottom of heat trace will be @ 2899' when landed. Continue to Rih to 1,063' 20:00 00:00 4.00 1,063 1,063 COMPZ RPCOti OTHR T Splice ESP Cable 05/08/2008 00:00 00:30 0.50 1,063 1,063 COMPZ RPCO OTHR T Test Electronics for continuity 00:30 09:00 8.50 1,063 3,655 COMPZ RPCO RCST T Continue to Rih from 1,063' w/ 41/2 ESP Com letion to 3655'. 09:00 10:00 1.00 3,655 3,655 COMPZ RPCOh HOSO T PU hanger and MU landingjt. RIH,get measurements on ESP cable, 5' short from cuttin while RIH. 10:00 12:30 2.50 3,655 3,655 COMPZ RPCOa HOSO T Laydown landingjt, hanger & pup. Remove top jt 31' jt, replace with 2 - 10' - 4 1/2" IBT pups jts. PU hanger and landin 't. Lower into well 12:30 16:00 3.50 3,655 3,677 COMPZ RPCOh HOSO T Install Penetrators. in hanger. Perform splicing operation on ESP cable and heat trace to pig tails. Re-test ESP cable and heat trace. Monitor well - static. Land hanger. Up wt 90K Dwn wt 70K Ran a total of Protectorlizers -3, Stainless Steel Bands - 19, Single Channel Xcoup.- 20, 5' Dual Channel Mid jtcoup -446, Dual. Channel Xcoup - 92, 2' Dual Channel Mid jt coup - 3, 3' Dual Channel Mid jt coup - 2, and 4' Dual Channel Mid 't cou . 2. 16:00 17:00 1.00 COMPZ RPCOh HOSO T RILDS, test hanger to 5000 psi. ND landin 't. Set TWC. 17:00 19:00 2.00 COMPZ RPGO NUND T ND ROPE. Set back 13 5/8 BOP out of the way and secure. 24 hr Notice was given to AOGCC for 1 D-134 18:45 hrs on 5-8-08 19:00 20:00 1.00 COMPZ RPCOh DHEQ P Test ESP cable, Heat Trace and Downhole Gauges through the Penetrators. All tested ood. 20:00 21:30 1.50 COMPZ RPCOh NUND P Set 13 5/8 BOP back on well and _ break stack. Remove Choke side and Rack back 13 5/8 BOP. 21:30 22:30 .1.00 COMPZ RPCO DHEQ P Test through Penetrators again -test ood. 22:30 23:30 1.00 COMPZ RPCOh NUND P Set and NU Tree. 23:30 00:00. 0.50 COMPZ RPCOh SFEQ P Test tree 250/5,000 si 05/09/2008 00:00 01:00 1.00 COMPZ RPCO SFEQ P Continue to`Test Void and Tree @ 250/5,000 si. 01:00 01:30 0.50 COMPZ RPCOh DHEQ P Test ESP Cable, heat trace and down hole au es -test ood 01:30 03:30 2.00 COMPZ RPCOh OTHR P RU Lubricator and-Pull TWC. Lay down Lubricator 03:30 05:30 2.00 COMPZ RPCOi1 FRZP P RU Little Red Services. Held PJSM. PT lines @ 2,500 psi. Pump 85 bbls diesel for Freeze protect. RD LRS. Allow well to U tube. - - - ?~[~~• 4 ~ a ~ Time Lo s 9 ---- - - --- - - Date From To_ Dur S De th E. De~th__F'h e Code Subcode T _ COM _ 05/09/2008 05:30 08:30 3.00 COMPZ RPCOh NUND P Set Vetco Gray H-BPV. Clean cellar area and wellhead. RDMO. Release Nordic 3 ri 08:30 hrs 5-6-08 Fa~:, 1U r.~ :) KRU 1 D-102 . ~~,®,~,g,~~ Page 1 of 1 ,~ ~'~~~~' Regg, James B (DOA) From: Crisp, John H (DOA) [john crisp@alaska.gov] ~ ~ ~-. „ Sent: Sunday, May 04, 2008 1:14 PM ` \~ l ~, To: Nordic 3 Company Man; aogcc_prudhoe_bay@admin.state.ak.us Subject: RE: KRU 1 D-102 Your request is granted. If for any reasan your plans change please call AOGCC Inspectors for a chance to witness BOP test. Thanks. From: Nordic 3 Company Man [mailto:n1433@conocophillips.com] Sent: Sunday, May 04, 2008 12:09 PM To: aogcc_prudhoe_bay@admin.state.ak.us Subject: KRU iD-102 As per our conversation. We are due a weekly BOP test on Monday May 5,2008. We will start our completion this afternoon approximately 3:OOpm and be landing completion sometime Monday afternoon. We would like to ask for a variance since we will be completing the well and nippling down the BOPE and moving to the next workover. Thanks, Rick Overstreet ConocoPhillips Nordic 3 Rig Supervisor 659-7446 ~~~~~ JUL ~ ~ 2008 5/5/2008 1D-102 (PTD#200-075) Video Log Page 1 of 2 Regg, James B (DOA) • • From: Regg, James B (DOA) ~ ~ ~~~ 0~ Sent: Friday, May 02, 2008 1:18 PM ~q To: 'Gober, Howard'; Maunder, Thomas E (DOA) (( Cc: Ennis, J J; Nordic 3 Company Man; Cawvey, Von; CPA Wells Supt; Eggemeyer, Jerome C.; Allsup-Drake, Sharon K; Packer, J.Brett; Gauer, Cody Subject: RE: 1 D-102 (PTD#200-075) Video Log Thank you for providing the email summary of status and plans. You have accurately captured our discussion. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 s~~~@~ MAY ~ ~ 2008 From: Gober, Howard [mailto:Howard.Gober@conocophillips.com] Sent: Friday, May 02, 2008 11:24 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: Ennis, J J; Nordic 3 Company Man; Cawvey, Von; CPA Wells Supt; Eggemeyer, Jerome C.; Allsup-Drake, Sharon K; Packer, J.Brett; Gauer, Cody Subject: 1D-102 (PTD#200-075) Video Log Jim, I just wanted to document our discussion this morning about the workover on 1 D-102. Nordic 3 is currently on the well doing the workover. The purpose of the job is to pull the failed ESP, make a cleanout run, and run a new ESP. This work does not require a 10-403. We have pulled the ESP without issue. A cleanout run was made with a 6" shoe, but we could not get past the Sperry R.1V~LS junction. We tried to get past the obstruction with 2-3/8" pipe to no avail. We circulated the hole with 2 micron filtered fluid and pulled out with the pipe. An attempt was made to video the obstruction, but there were too many solids in the fluid. As soon as the camera was pulled out of the fluid, the picture cleared up perfectly. Our plan is as follows: o RIH with a 7-5/8" test packer on the 3-1/2" workstring o Set the packer just above the crossover to 7" casing. o RU Halliburton video camera. Displace the fluid in the drillpipe and in the casing below the packer with ~ nitrogen. o Video the obstruction and make plans for fishing or completion o POOH with video. o Bleed of N2. RD video equipment. o Release packer and circulate hole to ensure the hole is full of consistent kill weight fluid o POOH with drill pipe and packer o Move forward with fishing operations or completion as determined by the video log As per our discussion, there are no special reporting requirements (other than the normal 10-404), nor AOGCC approval needed to proceed with this operation. Please confirm that this accurately captures our conversation. 5/2/2008 1D-102 (PTD#200-075) Video Log Page 2 of 2 Thank you for you help. Please call~u have any questions. Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907-263-4220 Office 907-240-5515 Cell Howard.Gober@conocophillips.com 5/2/2008 1D-102 (PTD 200-075) 2-3/$" ram test Maunder, Th©mas E (DOA) Page 1 of ~ • From: Maunder, Thomas E (DOA) Sent: Monday, Apri128, 2008 1:33 PM To: 'Gober, Howard' Cc: Nordic 3 Company Man; Packer, J.Brett; Ennis, J J; Gauer, Cody Subject: RE: 1 D-102 (PTD 200-075) 2-318" ram test Howard, You have captured our conversation. 1 will place a copy of this message in the file. A copy should be available on the rig. Tom Maunder, PE AOGCC From: Gober, Howard [mailto:Howard.Ober@conocophillips.com] Sent: Monday, Apri128, 2008 1:32 PM To: Maunder, Thomas E (DOA) Cc: Nordic 3 Company Man; Packer, J.Brett; Ennis, J J; Gauer, Cody ~~}~ APR ~ $ ~~~5 Subject: 1D-102 (PTD 200-075) 2-3/8" ram test Tom, This is to document our recent conversation regarding 1 D-102 (PTD 200-075}. Nordic 3 is rigged up on the well with a 13-5/8" 5K stack consisting of: Annular Pipes 2-7/8"x5-112" VBR`s Blinds Flow Cross Pipes 2-318" The welt was killed with seawater containing &°to KCL. The tubing string currently in the well is 4-1/2". We can test the upper VBR's with 3-1/2" and 4-1/2" prior to pulling the well. 3-1/2" is our workstring diameter. Due to the offset ESP hanger, we cannot get a test on the lower ram (2-3/8") without making a donut for the test joint. There is no 2-3/8" pipe currently in the hole. As we discussed, we will have a body test on the lower rams during the initial BOP test. After pulling the completion, we will set a test plug and test the 2-3l8" rams to 250!2500 psi. Upon a successful test, we wilt be able to run the 2-318" drill pipe for a Geanout in the lower B sand lateral. Please calf or a-mail back ifi you have any questions. Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907-263-4220 Office 907-240-5515 Cell 4/28/2008 1 D-102 PTD # 200-075, notice of packerless failed ESP . • Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Monday, July 30, 2007 2:00 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK West Sak Prod Engr Subject: RE: 1 D-102 PTD # 200-075, notice of packerless failed ES~~~ ~U~. ~ ~ ZDd~ Tom, There is no current plan to attempt gas lift on this well. Page 1 of ~ The pump is down and the shaft is rounded. We have areal-time read out of BHP on the inlet side of the ESP. It was 1660psi at S/l and has leveled off at 1700 psi over the last week. Surface pressures are T/1=4701440 psi. Freeze protect fluid is at surface on both the tubing and the IA. Let me know if you have any other questions. Perry From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, July 30, 2007 8:21 AM To: NSK Problem Wetl Supv; Regg, James B (DOA) Cc: NSK West Sak Prod Engr Subject: RE: 1D-102 PTD # 200-075, notice of packerless failed ESP Perry, Is there any plan to gas lift? With the ESP down/off, what sort of surface pressures develop? I presume there is some sort of gas head on top of fluid. Thanks in advance. Tom Maunder, PE AOGCC From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Monday, July 30, 2007 8:05 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK West Sak Prod Engr Subject: 1D-102 PTD # 200-075, notice of packerless failed ESP Tom, 1 D-102, PTD # 200-075, ESP producers pump has failed. The well will require a rig work over to repair the failed pump. Enclosed is a schematic. Let me know if you have any questions. r±~N~~ ~CL:~ <~ 7/9/2008 ~~ ~~~~~~ r Heat Trace (0-2958, OD 1000) TUBING (0-0131. OD 4500. ID:3.958) SURFACE (0-4175, OD:7,625, Wt:29.70) XO (409011101, OD:5.130) SEAL (4101-4115, OD 5 130) MOTOR (4115-0131, OD:S 620) Centralizer (4131-0133. OD:6 000) SENSOR (4133-0134 OD 6 2501 SURFACE (41754929, OD 7000, Wt:26.00; TUBING (47794925 OD:4.500', B-SANG LINEF (4778-0925 OD:4.500 Wt:12.60 Per (4925-7257 KRU 1 D-102 ConocoPfiillips Alaska, Inc. . . ConocJPhillips 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 toO Anchorage, AK 99501 5 d.(tJ - 01 8~~ JUL 11 2007 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). 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 form 10-404, Report of Sundry Operations. Please M.J. Loveland at 907-659-7043, if you have any questions. _.,- 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 PTO# cement pumped cement date inhibitor sealant date ft bbls ft aal 1 0-09 198-065 23" na 5 6/912007 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 6/912007 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 6/9/2007 10-114 198-159 2" na 1 6/912007 10-115 197-232 2" na 1 6/9/2007 10-116 198-172 2" na 1 6/9/2007 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 6/912007 10-122 198-149 2" na 1 6/9/2007 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 6/912007 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 ) ) Jim Ennis Wells Group Engineer Drilling & Wells ConocóP'hillips P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-1544 !)DO,- D 75 January 16, 2006 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 REceIVED JAN 1 8 2006 Alaska 0;' & Gas Cons CRI"iI"MMI' . . \#111111188100 Anchorage Subject: Reports of Sundry Well Operations for 1 D-1 02 /1 D-1 02L 1 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Reports of Sundry Well Operations for the recent 'workover on the West Sak well 1 D-1 02 /10-1 02L 1. If you have any questions regarding this matter, please contact me at 265-1544. Sin ce re Iy '...........-? ~%- J. ~nniS\ Wells Group Engineer CPAI Drilling and Wells $CANNED JJAN 1 ~~ 2005 J E/skad 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 30.5' ') ') "'C:L,I::IVt:U JAN I 8 2006 Alaska Oil & Gas Cons. Commiss Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Repair Well 0 Pull Tubing 0 Operat. ShutdownD Stimulate 0 Waiver 0 Other o o o Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development 0 Stratigraphic 0 Time Extension Re-enter Suspended Well Exploratory 0 Service 0 5. Permit to Drill Number: 200-0751 6. API Number: 50-029-22960-00 9. Well Name and Number: 1 0-1 02 8. Property Designation: ADL 25650, ALK 468 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURF CASING PROD CASING B-SAND LINER Perforation depth: 10. Field/Pool(s): Kuparuk River Field 1 West Sak Oil Pool measured 7378' feet true vertical 3719' feet measured 7357' feet true vertical 3720' feet Length Size MD 80' 13-3/8" 110' 4145' 7-5/8" 4175' 754' 7" 4929' 2579' 4" 7357' Plugs (measured) Junk (measured) TVD Burst Collapse 110' 3439' 3752' 3720' Measured depth: screens 4925'-7257' true vertical depth: 3751 '-3722' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 4063' MD. Packers & SSSV (type & measured depth) Baker SC-1 R pkr @ 4778' no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable RBDMS 8Ft. JAN 1 8 Z006 13. Treatment descriptions including volumes used and final pressure: Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ Oil-Bbl 286 326 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casinç¡ Pressure 774 329 27 518 15. Well Class after proposed work: Exploratory 0 Development 0 Service 0 Tubinç¡ Pressure 549 192 Daily Report of Well Operations _X 16. Well Status after proposed work: Oil0 GasD WAG 0 GINJD WINJ 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: Contact Printed Name Signature WDSPL 0 Jim Ennis @ 265-1544 , Ji~~_iS "ý'~ Title Phone Wells Engineer (îo ~ì)2~'- IÇ~P'I Date i ~ 7 ) ð Co Prepared ~!sh~ronLISUP-Drake 263-4612 ORIGINAL Form 10-404 Revised 04/2004 Submit Original Only Legal Well Name: 1 D-1 02 Common Well Name: 1 D-1 02 Event Name: WORKOVER/RECOMP Contractor Name: Nabors Alaska Drilling Rig Name: Nabors 38 .:..:' bate': ·Frorn~. To'· .Hö~·r~::·'6-6~·è;"~.·¿~~e.:·· Pha~é·· ::, P 9/11/2005 00:00 - 06:45 06:45 - 07:30 07:30 - 08:30 08:30 - 09:00 09:00 - 12:00 12:00 - 20:30 20:30 - 22:30 22:30 - 00:00 9/12/2005 00:00 - 02:00 02:00 - 06:00 06:00 - 11 :00 ) ) . '," . '.. .. .. . ... .. ·.·;.9ono~oPhiU~p~A1a~ka/--· . .'. :;·9þe.r~~iø·ris::SÜm~äry: .RØPQ~,: . . . . Page f of} I·n . ' ~' . . Start: 9/10/2005 Rig Release: 9/17/2005 Rig Number: 3S Spud Date: 6/1/2000 End: 9/17/2005 Group: . ".. .', .,',' . Description 9f Operations.. . . 6.75 MOVE RURD RIGUP Move camp from 1C pad to 1D and reconnect to generator and telecom. Layout Herculite for containment under rig. Continue to spot rig, pipe shed and pit module. 0.75 MOVE OTHR RIGUP Derrick sub spotted. While lowering sub stabilizers, rear stabilizer has pressed mat upwards into wellhead front casing valve, breaking ring gasket seal. Approx 1100 psi on annulus venting gas to atmosphere. Pull sub off well row out of hazardous area. Wind direction blowing away from equipment. Evacuate area, notify DSO, DSL T, Wells Coordinator, and Nordic 2 (further down pad) of situation. 1.00 WAlTON OTHR RIGUP Nipple up and bleed off annulus to production header. Note: reading once gauge was re-installed = 420 psi after approx 10 mins of bleeding, 185 psi header pressure). Rig up Hot Oil pump to tubing and jumper to tiger tank off rear casing valve. 0.50 WAlTON OTHR RIGUP Annulus pressure 220 psi- well still flowing (WHTP not appearing to fall any further). Hearlsee gas leak swapping to fluid, tighten up flange with hand tools. Leak stopped, few teaspoons of fluid spilled on ground. Call valve shop to VR install plug. 3.00 WELLSR OTHR RIGUP Plug installed; well secure. Conduct pre-job safety meeting. Replace rig mats and resume spotting rig. Security on site due to reports on bear on pad; suspend work until bear is located (off pad). Resume work. 8.50 MOVE RURD RIGUP Call PEAK back out. Get derrick sub spotted. Spot up pipe shed and pits. Tight fit (6"- 1 ') to adjacent wellheads. Build berms for kill tanks. Rig ready to raise derrick and scope up. 2.00 WAlTON WOW RIGUP Winds blowing @ 29 MPH gusting to 40 MPH. Waiting on wind to die down to raise derrick. 1.50 MOVE RURD RIGUP Winds calmed down to 24 MPH just below the limit. Raised derrik, scoped up and secured. Raise windwalls, tighten stablizer lines. Hook up flowlines, choke and killllines and stand pipe maifold. NU hard line and flowback tanks. Rig up LRS for pumping. Accept rig @ 2400 hrs 9/11/2005. 2.00 WELLSR PLGM DECOMP Accept rig @ 2400 hrs 9/11/2005. PU lubricator, pulled BPV 4.00 WELCTL KILL DECOMP Pre-job safety meeting on well kill. Well press @ 450 psi. Start pumping seawater @ 125 deg 2.35 BPM 450 psi. Pumped 200 bbls seawater shut down had 100 psi on well. Switched to 9.6 ppg 3% KCL filtered brine. 125 deg 2.3 BPM 200 psi shut down monitor well 30 psi. Pumped another 50 bbls 5.00 WELCTL CIRC DECOMP Pump 50 bbls, SI to check press = 20 psi. Rig down Hot Oil Svcs pump and rig up to pump with the rig pump taking return to the pits. Come online circulating brine down tubing taking rtns up IA at 4 bpm, 510 psi circ pressure. 200 bbls away, shut down and monitor well. Bleed off residual pressure. 0 psi tbg IIA. Install back pressure valve. ND tree. Install plug off tool in lift threads. NU 11" BOPE State witness of BOP test waived by John Spaulding. Function test and PT BOP rams and choke manifold to 250 1 3000 psi, annular to 250 12500 psi. Dig and install mousehole. RU camera for spooler. NU TIW valve. Pull test plug. Retrieve BPV. Check well for press. static. Install side port isolation sleeve in hanger. MU landing jt and mark the pipe at the rotary table. Prejob safety meeting BOLDS. Unland tubing hanger, pulled loose at 90K. Up wt =65K. Pull hanger to rig floor. Cable connection on bottom of penetrator blown copper wire exposed. Filled hole, took 5 bbls to fill. Measured and recorded 11 :00 - 12:00 1.00 WELLSR PLGM DECOMP 12:00 - 14:30 2.50 WELCTL NUND DECOMP 14:30 - 22:30 8.00 WELCTL NUND DECOMP 22:30 - 00:00 1.50 WELLSR PLGM DECOMP 9/13/2005 00:00 - 01 :00 1.00 WELCTL OBSV DECOMP 01 :00 - 03:15 2.25 FISH PULL DECOMP Printed: 11/14/2005 2:28:32 PM ) , . ) '". !". . . " ., ::.C:qn,ocbPhillips ~Ia:s.kcr.···.:;:: Ope"rations' summary:·~ø:pørt.:· ::. .'.' . . t· .'. -. . PULL DECOMP distance from the hanger to the mark on the landing jt. Lay down hanger. RU cable spooler. Start pulling out of hole standing back 4.5" tubing in derrick and spooling ESP cable. Start pulling out of hole standing back 4.5" tubing in derrick removing clamps and spooling ESP cable. Tranformer for hydraulic pump blown on rig; power pack/electrician on way to to fix. NOTE: 3 HOURS OF DOWNTIME Continue pulling out of hole, racking back. Continuing to pull out of the hole with 4-1/2 completion. Hole stable/static. Pump equipment at surface; begin breaking pump equipment down laying it down. Inspection of pump shows partial collapse of housing at intake screens; screens collapsed as well). TCC x-over full of sand & what appears to be gravel. Lrg. (3/4"x1") rocks found in string - apears to be cement. Wait on clean-out shoe from Baker and cossover form 4.5" NSCT to 3.5" IF Trouble locating crossovers ( BP tool services sent wrong x-over and Baker Fishing sent shoe that won't mate up to their x-over sub). Prep rig for clean-out run, install wear ring. Make up tools for cleanout run. Run in hole with 6" burn shoe on 4-1/2" NSCT production string I PH-6 drill pipe. Soft tag at 4353' orig RKB, set down 5k#. Pick up off tag approx 20'. Tested rotation, able to rotate freely at 1900#. Note: Removed front annulus valve (valve hit previously with rig mat) and replaced studs (slightly bent), ring gasket, inspect seal areas-good. Re-installed valve and tested against VR plug to 5k#-good. Rig up to rev-circulate. Begin pumping at 4.0 bpm taking rtns across shaker. Circulate 120 bbls around; watching for solids, none seen. Shut down. Begin POOH, rack back 4 stand of PH-6, lay dawn remainder. Rack back NSCT. Make up BHA retrievable bridge plug and test packer RIH wI BHA and 4.5" NSCT tubing Continue in hole with test packer and RBP Continue in hole with test packer and RBP. Up weight 52K Down weight 38K. Set RBP (turn freely to set at 2200# of torque). Release from RBP. Lay down one joint of tubing. Rig-up head pin and prep to pt casing to 25boPSI Pressure up on annulus to 2500 psi. Bleeding off slowly. Locate slight leak on kill line, break apart and replace brass. Casing valve stem packing leaking, energize packing with grease gun. Pressure up again to 2500 psi; holdlchart for 30 mins- good test. Bleed off and prep to pull out of hole standing back. Begin pulling RBPltest packer standing pipe back in the derrick. Hole stable, cont to pump across the top while pulling out of hole. At surface; lay down RBP/packer assembly and begin prepping to run new ESP completion. Make up running tool and pull wear ring. Rig up to run ESP motor assembly. Pick up motor centralizer/phoenix sensor/esp motorldual seal sectionfTCC crossover. Finish making ESP BHA as per procedure RIH wI 4.5" ESP completion string , :" .. . , , . ... Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 D-1 02 1 D-1 02 WORKOVER/RECOMP Nabors Alaska Drilling Nabors 3S ..pat~ . FrÓm ~ To. ..Hours:'· ·C.od~ ,.: ·ðud1)'. '··Pha$e· .oe, 9/13/2005 01:00 - 03:15 2.25 FISH 03:15 - 05:00 1.75 FISH PULL DECOMP 05:00 - 08:00 3.00 WAlTON EQIP DECOMP 08:00 - 12:00 4.00 FISH PULL DECOMP 12:00 - 16:00 4.00 FISH PULL DECOMP 16:00 - 20:00 4.00, FISH PULL DECOMP 20:00 - 00:00 4.00 WAlTON EQIP DECOMP 9/14/2005 00:00 - 06:00 6.00 WAlTON EQIP DEMOB 06:00 - 14:00 8.00 WELLSR TRIP WRKOVR 14:00 - 16:00 2.00 WELLSR CIRC WRKOVR 16:00 - 21 :00 5.00 WELLSR TRIP WRKOVR 21 :00 - 22:30 1.50 WELLSR RURD WRKOVR 22:30 - 00:00 1.50 WELLSR TRIP WRKOVR 9/15/2005 00:00 - 03:00 3.00 WELLSR TRIP WRKOVR 03:00 - 04:30 1.50 WELLSR TRIP WRKOVR 04:30 - 05:30 1.00 WELLSR PLGM WRKOVR 05:30 - 07:00 1.50 WELLSR DEQT WRKOVR 07:00 - 10:00 3.00 WELLSR TRIP WRKOVR 10:00 - 17:00 7.00 WELLSR TRIP WRKOVR 17:00 - 18:00 1.00 CMPL TN RURD CMPL TN 18:00 - 19:00 1.00 CMPL TN RURD CMPL TN 19:00 - 22:00 3.00 CMPL TN PULD CMPL TN 22:00 - 00:00 2.00 CMPL TN PULD CMPL TN 9/16/2005 00:00 - 05:00 5.00 CMPL TN PULD CMPL TN 05:00 - 08:00 3.00 CMPL TN RUNT CMPL TN Start: 9/10/2005 Rig Release: 9/17/2005 Rig Number: 38 Spud Date: 6/1/2000 End: 9/17/2005 Group: - .' '~', . . . ..: ' :. ',", . Description of c>perations ;. . Printed: 11/14/2005 2:28:32 PM ) ) . . . - . , " . , . ".. . .":" '. . --. . " . .. ',,~" .;:,Conb60ÞhiUiþàAla~ka . , " . ~ , c· ;¿·:øp:er.ations SúmlTu~ry:Re:po~t.. .", . 1.00 CMPL TN RUNT CMPL TN Stop running completion in order to rig up to run heat trace. Begin heat trace 35' down on stand #17 placing bottom of heat trace at 2995' orig RKB. 2.00 WAlTON ORDR CMPL TN Shut down to address clamp issue. All 2" cross clamps of on locationand in stock are "back- wards" meaning they would have to be flipped over and pinned from underneath if run. Attempt to locate correct clamps. Confer with WIO Engineer I Centrilift on options. Continue RIH with completion. Note: Clamps being run as per program, however, 2' cross clamps being run upside-down. Well stable. Seal area dinged on bottom of stand #31, remove from string. Continue running in the hole. Continue in hole with 4.5" ESP completion string with heat trace to 4121. Make up hanger assembly. Perform final test on ESP and heat trace line. Set penetrators. Make final splice of ESP cable and heat trace to penetrators. Heat trace splice complete. Centrilift having difficulties making their splice. Centrilift has figured out how connector works; complete splice. Wash out stack and pump out through annulus valve. Land hanger with ¡so sleeve installed and RLDS. Test upper and lower hanger seals to 5k#- good. Remove iso sleeve and install 2-way check. Begin Nippling down BOP stack Bop stack layed down; perform heat trace and power cable conductivity test. Nipple up tree. Test heat trace and ESP cable Test well head void and tree to 5000psi Pull two way check. Install BPV. Secure well. Release rig @ 22:00 on 9/17/05 (1 D-1 02) Prep rig to lay down derrick - ;,r.-,' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 D-1 02 1 D-1 02 WORKOVER/RECOMP Nabors Alaska Drilling Nabors 3S ".' ·.Ðc¡ite,,:: '. Fn:mi.- To. Hours' ':ê(jde Sub ··Phase :.. Code-. 9/16/2005 08:00 - 09:00 09:00 - 11 :00 11:00 -17:00 6.00 CMPL TN RUNT CMPL TN 17:00 - 00:00 7.00 CMPL TN RUNT CMPL TN 9/17/2005 00:00 - 03:00 3.00 CMPL TN RUNT CMPL TN 03:00 - 04:30 1.50 CMPL TN RURD CMPL TN 04:30 - 06:00 1.50 CMPL TN RURD CMPL TN 06:00 - 09:30 3.50 CMPL TN RURD CMPL TN 09:30 - 10:00 0.50 CMPL TN RURD CMPL TN 10:00 - 11 :45 1.75 CMPLTN RURD CMPL TN 11 :45 - 13:00 1.25 WELLSR PLGM CMPL TN 13:00 - 17:45 4.75 WELCTL NUND CMPL TN 17:45 -18:15 0.50 CMPL TN DEOT CMPL TN 18:15 -19:30 1.25 WELLSR NUND CMPL TN 19:30 - 21 :00 1.50 CMPL TN SEOT CMPL TN 21 :00 - 22:00 1.00 WELLSR PLGM CMPL TN 22:00 - 00:00 2.00 MOVE RURD MOVE . . .. . '~'på'gé3 'of3 . . Start: 9/10/2005 Rig Release: 9/17/2005 Rig Number: 3S Spud Date: 6/1/2000 End: 9/17/2005 Group: .. ". _n .. " , L 'þ~sçrjp~i~n of Operatl0l1S '. .. ., " Printed: 11/14/2005 2:28:32 PM ') ) ....¡,J ¡ ...~9~q9Rn¡lli~t~la~~ ...'...J ·'qp~~~ti~f"S·..,~.,~'mR1arY.,.·~ep()rt of2 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 10-102 10-102 WORKOVER/RECOMP Nabors Alaska Orillin g Nabors 3S 'pate> $up COde RURD MOVE MOVE MOVE RURD MOVE RURD MOVE RURD MOVE RURD MOVE Start: 12/24/2005 Rig Release: 12/29/2005 Rig Number: 3S Spud Date: 6/1/2000 End: Group: Frörn.1To Hall r$ 12/24/2005 13:30 - 20:30 20:30 - 22:30 22:30 - 00:00 00:00 - 06:00 06:00 - 09:00 09:00 - 10:00 7.00 MOVE 2.00 MOVE 1.50 MOVE 6.00 MOVE 3.00 MOVE 1.00 MOVE 12/25/2005 10:00 - 12:00 12:00 - 18:00 2.00 WELLSR PLGM DECOMP 6.00 WELLSR RURD DECOMP 18:00 - 00:00 6.00 WELCTL CIRC DECOMP 12/26/2005 00:00 - 06:00 6.00 WELCTL NUND DECOMP 06:00 - 10:30 4.50 WELCTL NUND DECOMP 11 :30 - 16:00 4.50 WELCTL BOPE DECOMP 16:00 - 18:00 2.00 WELCTL NUND DECOMP 18:00 - 00:00 6.00 FISH PULL DECOMP 12/27/2005 00:00 - 01 :30 1.50 FISH PULL DECOMP 01 :30 - 06:00 4.50 FISH PULL DECOMP 06:00 - 16:30 10.50 FISH PULL DECOMP 16:30 - 18:00 1.50 FISH PULL DECOMP 18:00 - 00:00 6.00 CMPL TN RUNT CMPL TN 12/28/2005 00:00 - 08:00 8.00 CMPL TN RUNT CMPL TN 08:00 - 15:30 7.50 CMPL TN RUNT CMPL TN 15:30 - 16:30 1.00 CMPLTN RUNT CMPL TN I 16:30 - 17:30 1.00 CMPL TNI RUNT i CMPL TN I i I ~ 17:30 - 20:30 3.00 CMPL TNI RUNT ! CMPL TN I : I I I 20:30 - 00:00 i 3.50 CMPL TN' RUNT ¡ CMPL TN i I I I I I I I . . '.:': ':'" : ":": ": ... .... . péscri ptiÖrt of ppêrátìO~$. · .. Rig released from 1 D-137 start to de-mob. Move rig from 1 D-137 to 1 D-1 02 Spot rig on 1 D-1 02 and begin to rig up Rig up over 1 D-1 02; raise mast. Crew change. Telescope out derrick and continue rig up. Begin nippling up kill line to tree, move lubricator to rig floor to pull BPV. Accept rig at 9:00 am, 12/25/05. Pull BPV. Having difficulties with lubricator. Waiting on brine from M-I (apparently having problems filtering). Rig up cable/heat trace sheaves, move tubing into pipe shed, repair rig heaters, etc. Circulate SW down tubing back up OA 290 bbls @ 3.25 BPM 610 psi. Holding 500 psi on OA. Continue circulating in Kill WT brine 9.6 ppg hole volume 170 bbls. Taking returns to tiger tank. Pumped 24 bbls bullheaded down tubing into formation. Monitor pressure well stable Set BPV and ND tree. NU BOP's; OA open, 0 psi on tubing. Tower meeting. Continue to NU BOP's; well is stable, 0 psi on OA. Begin testing BOPE, (25013000 psi). Witness of BOPE test waived by state rep John Crisp. Finish BOPE test. Pull test plug and BPV. Screw in landing joint, BOLDS, and pull hanger to the floor. Hanger would not pull free pulling 125K, no stretch visible from the floor, hung up in the well head. Steam well head and working pipe completion came free with 11 OK up wt. pulled hanger to the floor 65K up wt. Lay down hanger and pup and Rig up spoolers Continue to Rig up spoolers Pull old completion out of hole laying down sideways, spooling ESP cable and Heat trace. Well is losing approx. 2 bbls per Hr. Tower meeting. Continue out of hole with old completion. Out of hole with old ESP completion.Begin laying pump equipment down. SWS hand on location to redresslverify ESP equipment is working properly. Well still taking approx. 2 bblslhr fluid loss. Start running new completion. PU centrlilizer, Phoenix sensor and motor. Service motor. MU seal section and service same. Feed motor lead extension through sheave to floor and connect. Install Phoenix pressure tbg sub and connect cap. tbg. Install Cannon single-channel cross-coupling cable clamps on every connection until three full jts. and every other collar from there up. Picking up new 4.5" 12.6# IBT tubing drifted to 3.833". Total fluid losses for last 24 hrs = 43 bbls. Continue running ESP completion, picking up new tubing. Install heat trace 6' up from pin on jt #36 (2958'). Continue in hole with completion testing cablelheat trace every 1000'. Out of correct dual-channel cross-coupling clamps with none available at warehouse; discuss with WIO engineer. Begin running mis-manufactured clamps upside down on bottom of jt 81. Follow-thru at wharehouse shows additional clamps "correct" available in stock. Have delivered to location and begin running correct clamps in correct position from jt #86 (clamps run upside down from jt.#81-85). Continue in hole with completion testing cablelheat trace every 1000'. PU and MU hanger with full jt 4.5" IBT wI side port isolation sleeve and landing jt. Orient hanger, meg. both cables OK. Install penetrators. Make final splice of ESP cable and Heat Trace to penetrators. Megged cables again everything good. Lowered hanger down and landed on Printed: 1/17/2006 1:13:24 PM ) ) : .: . .::.. :-::" ...: .:.....:. . ".: '. .¡ ..~()~~Fd~!1iJliP:~~I~~k~i .¡... ;. ·QIJ~~_;ti;~I1I$<S'~rf1 m~!ryR~·p¡()rt· 3.50 CMPL TN RUNT CMPL TN mark. Up wt 62K Dwn wt 36K. Checked side port on hanger lined up good. Fluid for last 24 hrs = 18 bbls. 1.50 CMPL TN SOHO CMPL TN Run in lock down screws, Test hanger void/packoff to 5000 psi. Back out the landing joint, drain stack. Remove side port isolation sleeve from hanger. Install BPV. See remarks tab for band count. Change rams in BOP from 4.5" to 3.5". Nipple down BOPE. Checked the ESP cablelmotor electrical integrity. Meggar the Heat Trace. NU tree and test to 5000 psi. Pull 2-way check. Rig up Hot Oil. Circulate in diesel down lA, up tbg until diesel seen at pits (158 bbl total) for freeze protect. Begin cleaning pits. Install BPV. Finish cleaning pits. Telescope derrick down, lower derrick. Prep for move. Rig ready to move, waiting on CTU to finish on 1 D-113 in order to move down pad with rig to 1D-134. Released rig @ 1900 hrs on 12/29/2005. Pulled pipe shed forward, moved pit module out. Moved carrier unit out, moved crane in. Removed BOPE stack out from behind well. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 D-1 02 1 D-1 02 WORKOVER/RECOMP Nabors Alaska Drilling Nabors 3S ~ate .. . . .. .. .. . F. .. ro.·. ·.m. ... ,.~.. To.····.. .... H. Qu. rs Code < Siyp: pna$e· LÇOq~ 12/28/2005 20:30 - 00:00 12/29/2005 00:00 - 01 :30 01 :30 - 06:00 4.50 WELCTL NUND CMPL TN 06:00 - 08:00 2.00 WELCTL NUND CMPL TN 08:00 - 11 :00 3.00 WELLSR FRZP CMPL TN 11 :00 - 14:00 3.00 WELLSR PLGM CMPL TN 14:00 -17:00 3.00 MOVE MOVE MOVE 17:00 - 22:00 5.00 WAlTON OTHR MOVE 22:00 - 00:00 2.00 MOVE MOVE MOVE Start: 12/24/2005 Rig Release: 12/29/2005 Rig Number: 3S Spud Date: 6/1/2000 End: Group: .... .... ........... . ... ....... . .., .. ...... ........ . ... ... ".' ". .. .. . . . ,... . . .......... . . .. .... .. pésçrìPti~n¡þfqÞør~tìOr1S ... .;. Printed: 1/1712006 1: 13:24 PM Heat Trace (0-3023, 00:1.000) TUBING (161-4076, 00:4.500, 10:3.958) XO (4076-4086, 00:5.130) SEAL (4086-4100, 00:5.130) MOTOR (4100-4117, 00:5.620) GAUGE (4117-4119, 00:6.250) CSG WINOOW (4368-4383, 00:6.000) PROO CASING (4175-4929, 00:7.000, Wt:26.00) TUBING (4779-4925, 00:4.500) B-SANO LINER (4778-4925, 00:4.500, Wt:12.60) Perf (4925-7257) ConocoPhillips Alasll\.!' Inc. ] j: . I~---! lill I __ L.. ) KRU 1)-102 API: Well Type: SSSV Type: None Orig Completion: 6/22/2000 Annular Fluid: Last W/O: 9/17/2005 Reference Log: 31' RKB Ref Log Date: Last Tag: 3997 TD: 7378 ftKB Last Tag Date: 12/11/2001 Max Hole Angle: 94 deç¡ @ 6304 Casing String - COMMON STRINGS Description Size Top Bottom TVD Wt Grade Thread SURF CASING 7.625 0 4175 3439 29.70 L-80 BTC-MOD CONDUCTOR 13.375 0 110 110 68.00 L-80 WELDED PROD CASING 7.000 4175 4929 3752 26.00 L-80 BTC-MOD CSG WINDOW 6.000 4368 4383 3568 0.00 L-80 to 1 D-1 02L 1 Casing String - B-SAND LINER (Alternating blank pipe & Baker Dual Screens 4"x4.5"} Description Size Top Bottom TVD Wt Grade Thread B-SAND LINER 4.500 4778 4925 3751 12.60 L-80 HSLHT SCREENS 4.500 4925 7257 3722 12.60 L-80 HSLHT Tubing String - TUBING Size Top 4.500 0 4.500 161 Perforations Summary Interval I TVD 4925 - 7257 3751 - 3722 Gas tift Mandrels/Valves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Vlv Run Cmnt o 12/4/2005 (1) o 12/4/2005 deg @ TD: 89 deg @ 7378 Rev GLV C/O Last Update: 12/15/2005 Bottom 161 4076 TVD 161 3377 Wt 12.60 12.60 Grade L-80 L-80 Thread IBT NSCT Zone WSB Status 1Ft I SPF I Date I Type I Comment 2332 50 6/22/2000 Screens Perfs thru screens I I 1 2574 2442 CAMCO KBG-2 DMY 1.0 2 3955 3300 CAMCO KBG-2 DMY 1.0 1. Slickline found GLM ~ 2487' SLM, but tally shows 2574' RKB :Other 'plugs, equip., etc.) - JEWELRY Depth TVD Type o 0 HeatTrace HEAT TRACE 31 31 HANGER VETCO GRAY TUBING HANGER 3999 3328 SUB PHOENIX DISCHARGE PRESSURE SUB 4076 3377 XO TCC CROSSOVER/COUPLING SET 4086 3383 SEAL Centralift ESPTANDEM SEAL 4100 3392 MOTOR Centra lift ESP MOTOR SET 4117 3403 GAUGE PHOENIX GAUGE ASSEMBLY SET 4119 3404 Centralizer Centralift Centralizer SET Other ~plugs equip., etc.) - B-SAND JEWELRY Depth TVD Type Description 4778 3733 PACKER BAKER SC-1 R PACKER w/MILLOUT EXTENSION 4779 3733 TUBING 4823 3742 SLEEVE I BAKER CMD SLIDING SLEEVE 7355 3721 SHOE BAKER 5" MODEL GPV SHOE General Notes Date Note 3/5/2001 Multilateral well. B-Sand (10-102), D-Sand (1O-102L 1) 11/7/2003 TREE: VETCO GREY /4" / ESP / 5M TREE CAP CONNECTION: 7" OTIS ID 4.000 3.958 3.430 5.000 BK-5 BK-5 0.000 0.000 Description ID 0.000 3.958 0.000 3.958 0.000 0.000 4.500 0.000 ~", IF ¡¡rl? Œ" .. .. ~. a /;ð,\. ! I p , Ii· ''''-q iU" I l.i1 U ¡¡ e (ID~ L%~~~[[~ e AI.ASIiA OIL AlQ) GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR Brad Gathman Problem Wells Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99519 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: KRU 1D-102 Sundry Number: 305-336 ~NED DEC 1 ~ 2D05 Dear Mr. Gathman: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this-L day of November, 2005 Encl. ~ 10/31/2005 20:00 9076597314 e ,/ NSK WELLS GRO.Ø- ((- (-0 Jf"( r~J.ëd '\f¡rr:::: t. ....''', .~t:1 ,C ~ V 1 2005 l\( \ W!Jlver 0 Time Exœnsion 0 R:e-enler suspandad Well 0 Explortltory 0 5. Permit f.Q ~~I~~~~r: .. '" $I;!rvlce 0 6. API Number; 50·029-22960"00 9. Well Name and Number: 1D-102 1. Tyl'ê of Request STATE OF ALASKA ALl SKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25,280 Operational Shutdown 0 Plug PerfoTatlong 0 P~rfOrate New Pool 0 Abandon 0 o [2] " .ugpen(! 0 o o Perforate 0 o RE' air well Stimulaté Aller easing Ch!lnge approved program 2. Operator Name: ConocoPhilli s Alaska, Inc. 3, Address; Pur TIIblng 4. Current Well Class: Development [] stratigr~phic 0 P. O. Box 100360, Anchors e, Alaska 9951, ) 7. KB Elevation (ft); RKB 101' 8, Property Designation: Kuparuk River Unit 11_ Total depth MD (ft); 7378' Casing CONQUCrOR SURF CASING PROD CASING CSG WINDOW B~SAND LINER Other 0 10. FieldlPool(S): Kl.lparuk River Field / West Sale Oil Pool PRESENT WELL CONDITION SUMMARY erfedi 'Ð Depth MD (ft): Efkctive Depth TVD (fI); Plugs (measured): Jun~ (measured): Size MD TVD Bu!'!:!'t Collapse 13-318" 110' 7-5/8" 4175' 7" 4929' 6-1/2" 4383' 4-1/2" 4925' Meehl nic:allJitégrity Test 0 location Clearance 0 \ \ I \ - \) '\ ~ ""'-O-'i. \öcc. \Q. \~~C~ RBDMS 8Ft NOV (,) 2 Z005 Total Depth TVD (ft): 3721' Length 110' 4074' 754' 15' 147' Perforation Depth MD (fl.): Perfe, atlon Depth TVD (ft): Tubing 812:8: 4-1/2" No Perf$ - Pre ¡:Jack screens In horl;~(mæ ra1e~S Packers and SSSV Tyl'ê: no packer no SSSV 12. Attachments: Dee.cription Summary of Propos: I [2] Detailed Operations Program 0 BOP :ketcn 0 14. Estimated Date for Commencing Operations: NOli ~mber 1, 2005 15. Verbal Approval: Date: Commie.sion Representative: . 17. I I'Ierêby certify that the foregoing Is true and COt 1!!¢! to the best of my knowledge. Printed Name Brad Gathman Packèl'$ and $S$V MD (ft) nQ $SSV 13. Well Class after proposed wor\(: Exploratory 0 Development 0 15. Well Status aftér proposed work: 011 [2] Gas 0 WAG 0 GINJ 0 Contact: Title: Phone 659"7224 Signature Commission Use On 1 Conditions of approval: Notify Commi&$ion so thsl II representative may wltne$$ Plug Integrity 0 60P Test 0 Other: 1\ -:. \ '~Q~~'Lft: 4 f'O\\~ <.ct--..'-:>~~~ COMMISSIONER APPROVED BY THE COMMISSION A Form 10-403 ReviSéd 712005 vOR/G/NAL Tubing ~r8de: L-80 Tubing MO (ft); 4076' Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPl 0 Brad Gathmen Problem Wells Supervisor Date October 31, 2005 Date: Sub L~{~L{L~~8 L~;~~ ~tJ (b::J~ (,:H q e N~K W~LL~ ~~U~ PAGE 02 ConocnPhiIJips Alaska, Inc. West Sak In.iection Well 11)..1(1! (PTD 2000750) & 1Dkl02Ll (PTD 20007(0) SUN )RY NOTICE 10-403 V ARlANCE REQUEST 10/31/05 The purpose of this Sundry ~otice is for approval to produce multilateral West Sak producer lD- 102 via gaslift. The well is ;;ompleted as an ESP (electric submersible pump) producer and does not have a packer. ID-I02 was worked over itl September, 2005 to replace a failed ESP motor, Following the workover, the pump was urllble to be run downhole due to tigbt collars in the tubing. The collars were milled using a ;oiled tubing unit and it appears the spline shaft of the motor was damaged during the milling process. Because of the damaged spline, the pump cannot be run and it is requested that the ,; 'ell be produced by gas lifting the well. The tubing ís configured wih two gaslift mandrels at 2574' RKB (2442' TVD) and 3955' RKB (3300~ TVD)_ Gaslift will 1: e appJ.iedin the "standard" configuration; ie_, gas will be injected down the annulus and enter the tubing through the gaslift valves. The following is a summar) of the proposed plan: 1, The AOGCC approve t1: is request for a time period not to exceed 24 months from the approval date; 2. Should a workover not I; e completed within the approved time period the AOGCC will be contacted for a review a. td discussion of the plan forvvard. l~/~lIL~~~ L~:~~ 90"55914 NSK WELLS GRO_ PAGE 01 P.O. BOX 100360 ANCHORAGE, AlASKA 995 J 0-0:' ;0 Conoc~illip!¡ Alask~; :<'A..CSIMILE TRANSMITTAL SHEET 1b: Tom Maunder From: Brad Gathman Company: Cotnpany: Coo.ocoPbiUips Fax: 276-7542 Phooe; 659-7224 ~: KRU 10-102 h: :iuction Wel1 Pages: 3 Date: lO/31¡{)5 . Comments: Tom: Attached is the 10-4(1 J for West Sak production well 10-102 to produce via gasliflThiS well may be ready in a few days to br ng on production. Please notify me of your r:lecision. RE: ID-I02 (PTD 2000750) IA flange gas leak ) ) Subject: RE: ID-I02 (PTD'200075'O) IA flange gas leak From: NSK Env Proj <nl037@conocophillips.com> Date: Mon, 12 Sep 2005 09:04:55 -0800 To: James Regg <jim_regg@admin.state~ak.us> Cc: James Regg<jim.:-regg@admin.state.ak~us>, aogccj)rudhoe-bay@admin.state.ak~us,CPFlProd· Supy,<n 1132@conocophillips.com~, "Hunt, Hai t" <Hai.L.Hunt@conocophillips.com>,'NSK PrcpblemWell Supv <n1617@conocophillips.com>, Thomas Maunder ' . <tom _mamlder@admin.$tate.ak.us> . Jim: We will not be submitting a Venting Report to AOGCC for this incident. The estimated volume vented was 45 Mscf (de minimus) - significantly less than the 1 MM scf AOGCC threshold. Jeff Smith ConocoPhillips Alaska - Kuparuk Field Senior Environmental Coordinator (Phone) 907/659-7242 (Fax) 907/659-7712 (E-mail)n1037@conocophillips.com -----Original Message----- SC/\NNED SEP 1 2 2005 From: NSK Problem Well Supv Sent: Sunday, September 11, 2005 8:54 AM To: 'Thomas Maunder' Cc: James Regg; aogcc_prudhoe_bay@admin.state.ak.us Subject: lD-l02 (PTD 2000750) IA flange gas leak Tom, Just a heads up that we had a gas release on 10-102 that was reported to agencies this morning. Our environmental department notified the AOGCC slope inspector and left a phone message with their AOGCC spill contact in Anchorage. While placing rig mats around 10-102 for the workover rig to move onto the well today, the IA valve was bumped resulting in a gas leak at the flange connection to the wellhead. The leak was stopped by bleeding off the gas head to the production header and tightening the flange bolts. The well will be killed and a VR plug will be installed in the IA prior to moving the rig onto the well. 10-102 is a failed ESP packerless West Sak well that had been SI since 7/22/05. Please let me know if there are any questions. Marie McConnell Problem Well Supervisor 659-7224 1 of 1 9/12/2005 9:48 AM MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc r"' ~ Conoc6Philli ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 JOO- °7S September 24, 2004 RECEIVED SEP 2 8 2004 A/aska Oi/ & Gas Cons C '. . ommlSSlon Anchorage Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a 10-404 Sundry Notice for ConocoPhillips Alaska, Inc., West sat well1D- 102. The notice is for conversion to gaslift. Also attached is an event summary and well schematic. Please call MJ Loveland or me at 907-659-7224 if you have any questions. Sincerely, br-~:D Bradley Gathman ConocoPhillips Problem Well Supervisor Attachments ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D RepairWell D Plug Perforations D Stimulate D Other D Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program 0 Ope rat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development - 0 Exploratory D 200-075 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360 50-029-22960-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 101' 10-102 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 7378' feet true vertical 3721' feet Plugs (measured) Effective Depth measured 7357 feet Junk (measured) true vertical 6276' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 110' 13-3/8" 110' 110' 5020 psi 2260 psi SURF CASING 4074' 7-5/8" 4175' 3439' 6890 psi 4790 psi PROD CASING 754' 7" 4929' 3752' 7240 psi 5410 psi CSG WINDOW 15' 5-1/2" 4383' 3568' DUAL SCREEN L 2579' 4-1/2" 7357' 8431 psi 7500 psi Perforation depth: Measured depth: 4778-7357 true vertical depth: 3733-3721 Tubing (size, grade, and measured depth) 4-1/2' , L-80, 4122' MD. Packers & SSSV (type & measured depth) no packer no SSSV no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A RBDMS BFL SEP28. Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubino Pressure Prior to well operation 0 0 0 -- 0 Subsequent to operation 572 107 516 -- 356 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run - Exploratory D Development 0 Service D Daily Report of Well Operations _X 16. Well Status after proposed work: oil0 GasD WAGD GINJD WINJD WDSPLD 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: 304-346 Contact Loveland/Gathman Printed Name Bradley Gathman Title Problem Well Supervisor Signature 'ù.. -- "'. Phone 907-659-7224 Date' /2. ~o y ~ / J-../ . .. I ^ I PrRflarRrJ hv .<:harnn AII~un-nrak , II H \ \J \ \\1 1-\ L . . Form 10-404 Revised 04/2004 Submit Onglnal Only ~ ~ 1D-102 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 9/412004 Pulled OGL V from station #1 and SOV from Station #2. Set LGL V in station #1 and OGL V in station #2. Pulled catcher sub. 9/10/2004 Received verbal approval to bring 10-102 on-line with gaslift injection from Tom Maunder at AOGCC. 9/11/20O4Begin producing well with gaslift injection. r"' ~ .~II~ ~ me. KRU 1 D-102 1D-102 API: 500292296000 Well Type: PROD Anale (â) TS: dea (â) CONDUCTOR - SSSV Type: None Orig 6/22/2000 Angle @ TD: 89 deg @ 7378 (0-110, . Completion: OD:13.375, Annular Fluid: Last W/O: 11/3/2003 Rev Reason: GLV desian Wt68.00) Reference Loa: 31' RKB Ref Loa Date: Last UDdate: 9/5/2004 Last Taa: 3997 TD: 7378 ftKB TUBING Last Tag Date: 12/11/2001 Max Hole Angle: 94 dea (ã) 6304 (0-4122, OD:4.500. Casino Strine. ALL ID:3.958) DescrlDtion Size TOD Bottom TVD Wt Grade Thread CONDUCTOR 13.375 0 110 110 68.00 L-80 WELDED SURF CASING 7.625 0 4175 3439 29.70 L-80 BTC-MOD PROD CASING 7.000 4175 4929 3752 26.00 L-80 BTC-MOD CSG WINDOW 6.000 4368 4383 3568 0.00 L-80 to 1D-102L 1 DUAL SCREEN LNR 4.500 4778 7357 3721 12.60 L-80 HSLHT Tublno Strine. TUBING Size TOD I Bottom I TVD I Wt I Grade I Thread 4.500 0 I 4122 I 3406 I 12.60 I L-80 I NSCT ..i............ii .......... ii i ............................... ........................................ i.. Interval I TVD Zone Status Ft SPF Date Type I Comment 4778 - 7357 3733 - 3721 WS C,WS 2579 50 6/22/2000 screens Perfs thru screens B Gas LIft Mal1drelsNalves St MD TVD Man Man Type VMfr V Type VOD Latch Port TRO Date Vlv Mfr Run Cmnt 1 2598 2459 CAMCO KBG-2 GLV 1.0 BK-5 0.188 1503 9/4/2004 2 3975 3313 CAMCO KBG-2 OV 1.0 BK-5 0.250 0 9/4/2004 Other ( lu~s. IIJUID. etc.). JEWELRY .-- ..---. . - . DeDth TVD TvDe Del!c;;!!p~lon.... _n_. .. ID 31 31 HANGER . VETCO GRAY TUBING HANGER ' 4.000 3989 3322 SUB PHOENIX DISCHARGE PRESSURE SUB, set 11/7/2003 0.000 ..... 3995 3326 SUB PHOENIX DISCHARGE TEMPERATURE SUB SET 11/7/2003 0.000 ... 4075 3376 XO TCC CROSSOVER/COUPLING SET 11n/2003 3.958 it 4084 3382 SEAL Centra lift ESPTANDEM SEAL SET 11n/2003 0.000 4098 3391 MOTOR Centra lift ESP MOTOR SET 11n/2003 0.000 4114 3401 GAUGE PHOENIX GAUGE ASSEMBLY SET 11n/2003 4.500 4120 3404 Centralizer Centra lift Centralizer SET 11n/2003 0.000 Generel.NôtH Date Note 3/5/2001 NOTE: This is a West Sak multilateral well. This schematic represents the 'B' sand lower lateral. See the 1 D-1 02L 1 schematic for the 'D' sand UDDer lateral. 11/7/2003 TREE: VETCO GREY /4" / ESP / 5M TREE CAP CONNECTION: 7" OTIS SEAL (4084-4098. OD:5.130) MOTOR (40984114. OD:5.620) I J PROD CASING (4175-4929. OD:7.000, Wt26.00) Perf (4778-7357) ~ ~ ~1r~1rŒ lID~ ~~~~æ~ AI IASIiA. OIL AND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 September 13, 2004 Jerry Dethlefs Problem Well Supervisor ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage, AK 99510 Anchorage, AK 99519 leJò-O7) Re: West Sak lD-l02 304-346 Dear Mr. Dethlefs: Enclosed is the approved Application for Sundry Approval relating to the above- referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Enc!. Re: lD-I02 (200-075) ESP Failed and Conversion to GL ~ ~ Subject: Re: ID-I02 (200-075) ESP Failed and Conversion to GL From: Thomas Maunder <tom - maunder@admin.state.ak.us> Date: Fri, 10 Sep 2004 11 :05 :26 -0800 To: NSK Problem Well Supv <nI617@conocophillips.com> Sorry about that Jerry. You have answered my questions and you have approval to operate the well on GL. When I get the sundry copies you have mailed, we will process them and get them back to you. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: Tom: Both stations will be used for gaslift--the bottom station will be the operating valve and will pass all the gas once the well unloads. The top station will be a live valve that will close once the well unloads. The two station GLM design is an improvement in the system that was made during the workover since we had some difficulty doing this on the previous wells. It was not originally anticipated to be used this way, but has proven effective when needed. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7224 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Thursday, September 09, 2004 2:24 PM To: NSK Problem Well Supv Subject: lD-102 (200-075) ESP Failed and Conversion to GL Jerry, I did get your fax and I will look forward to receiving the hard copies you are mailing. What you propose is similar to the arrangement for several other wells that have/had ESP failures. You note that when this well was worked over that mandrels were installed to allow GL if the pump were to fail. What you propose mandrels be used just the deepest Please call with Tom Maunder, PE AOGCC is acceptable, however I do need a clarification. or one?? any questions. Will both 1 of 1 9/13/20049:34 AM ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 MC 25.280 ~ ~ ~~ Il"~ .J/~ 1. Type of Request: Abandon D Suspend D Operation Shutdown D Perforate D Waiver D Annular Disp. D Alter casing D Repair well D Plug Perforations D Stimulate D TIme Extension D Other D Change approved program 0 Pull Tubing D Perforate New Pool D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development - 0 Exploratory D 200-075 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360 50-029-22960-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 101' 1D-102 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7378' 3721' 7357 3720 Casing Length Size MD TVD Burst Collapse CONDUCTOR 110' 13-3/8" 110' 110 SURF CASING 4074' 7-5/8" 4175' 3439 PROD CASING 754' 7" 4929' 3752 CSG WINDOW 15' 5-1/2" 4383' 3568 DUAL SCREEN LNF 2579' 4-1/2" 7357' 3720 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4778-7357 3733-3721 4-1/2" L-80 4122' Packers and SSSV Type: Packers and SSSV MD (ft) no packer no SSSV no SSSV 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program D BOP Sketch D Exploratory D Development 0 Service D 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: I'" Þt Il-P " ".".. L. ~ Oil 0 Gas D Plugged D Abandoned D 16. Verbal Approval: Date:.L ~ IlrJ-o'i WAG D GINJ D WINJ D WDSPL D Commission Representative: ts:t~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Dethlefs/McConnell 659-7224 Printed Name d_erry Dethlefh Title: Problem Well Supervisor Signature /" <Cotll~J' C --- ~f' Phone~- 7Zz..'¡ Date ~/~P/ r e;;.-- Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry N~rtJI. ~ r¡ fp Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance D Other: ~\>ro~~\ ~ ~\Ý' ~ ~ ';/\S-rzJ$' ~~'ib~ tt:~ECEIVED S"bsoq"~~æd 't '\ ~~ ::"'~; 1 6 . SEP 1 32004 Alaska Oil & Ga. Co.s. ""';z Approved .../J ~~. COMMISSIONER BY ORDER OF Anchoraop '3/# / THE COMMISSION Date: V V '-- .~ I I Form 10-403 Revised 12/2003 INSTRUCTIONS ON REVERt:) R , GINA L Submit in Duplicate ~ ~ ConocoPhillips Alaska, Inc. West Sak WelllD-102 (PTD 2000750) SUNDRY NOTICE 10-403 VARIANCE REQUEST September 9, 2004 The purpose of this Sundry Notice is for approval to produce ConocoPhillips' West Sak welllD- 102 on gas lift. The well is completed as an ESP (electric submersible pump) producer and does not have a packer. ID-1O2 had previously been operating under Sundry #303-064 approval to produce with gaslift down the tubing and production fluids up the inner annulus (IA) due to a failed ESP motor. The well received a workover in November 2003 to replace the failed motor. The well produced via ESP until 8/26/04, at which time diagnostics confirmed the ESP motor had again failed. '" The tubing is configured with two gaslift mandrels that had been installed for gaslift as a backup lift system. Gaslift will be applied in the "standard" configuration; i.e., gas will be injected down the annulus and enter the tubing through the gaslift valves. All production from the well will be through the tubing to surface facilities. Since there will not be annular flow with this configuration, supplemental corrosion/erosion inspections will not be undertaken. The latest production test on 7/27/04 (ESP production) recorded 854 BOPD, 785 BWPD (48%WC), and 146 MSCF of gas. Attached is a wellbore diagram ofthe well. ConocoPhillips proposes that: 1. The AOGCC approve this request for a time period not to exceed 12 months from the approval date; 2. Should a workover not be completed within the approved time period the AOGCC will be contacted for a review and discussion of the plan forward. NSK Problem Well Supervisor ----, ~ KRU 1D-102 ConocoPhillips Alaska, Inc. 1D-102 ~~~OUCTOR ~- (0-110,- 00:13.375, Wt.68.00) lUBING --- -.--- (0-4122, 00:4.500, 10:3.958) SEAL (4084-4098, 00:5.130) MOTOR (4098-4114, 00:5.620) PROD CASING {4175-4929, 00:7.000, Wt:26.oo} Perf (4778-7357) I I' .,:,,'-- i 'I I Iii I. ,.:: '! -,- API: 5002~;1296000 SSSV Type: None I .___.ð!!9.!e- @ J~;- -~~..cã> I Angle @ TO: 89 deg @ 7378 I Rev Reason: GL\iëjëšiãñ-~ ---- -.. - - .l,.a_s.!--'dF<1-~!e: 9/5/2004 'I I Well Tvoe: PROD Orig 6122iiõoo---'---- Completion: ~nnular Fluid: ---____J_ast'!V/O: f1Ï3/2003 I Reference Loa: 31' RKB Ref Loa Date: ~: - - Last Tag: 3997 :~~-:::' - ___n- TO: 7378 ftKB ! Last Taa Date:: 12/1112001 Max Hole Angle: 94 deg (ã> 6304 - -- Casing String - ALL I ----- ...- D.,-scription ---- Size Top CONDUCTOR 13.375 0 SURF CASING--" -.. ----7.625 0 PROD CASIÑëf 7.000 4175 CSG wiÑoÕW 6.000 4368 -'-- -.. --- --1 Thread I WELDED I BTC-MOD ! BTC-MOD ' to I 1D-102L1 i HSLHT --.. - - . ...--- --- I Bottom TVD Wt Grade I 110 1J~- 68.00 : L-80 4175 3439 29.70 L-80 4929 -- ---'3752"'- -"26.00 ; L-80 ___n..- ---_._+--~--- - -,.. on. 4383 3568 O.OO! L-80 -- ..-.---.- -- .-- _n 12Ji..cLL.1.:.80 Thread ___n..- - -ÑSCT Gas Lift MandrelsNalves -'8\; MD TVD Man : Mfr , 1 2598 2459 CAMCO .. -KBG-=-2---:- GL V --1.r: BK-5 -- i. T 3975 3313 CAMCO KBG-2-r-- --.-. - --- OV -,.LO BK-5 Other lu s ulp~.L.!!ç,l: JEWELRY ------.... ,-.-------.-- '--..- DJlI th , TVD T I n_._--- . .. .. -- Description 31 : 31 HANGER VETCO GRAY TUBING HANGER . ~989- 3322 . -- :SUli___- P-!::IOENIXÞ.l~CB:ARGE PRE~~~~E SUB, set 11/7/2003 '3995 3326 SUB PHOENIX DISCHARGE TEMPERATURE SUB SET 11/7/2003 ~ --4'075 3376-- -. - XO TCC CROSSOVER/COUPLlÑG SET 11/7/2003 ; 4084 3382 --SEAL Central¡ft-ËSP'rÃNÖEM SEAL SET 11ni20Öj-_n____--_---- f"4Õ98 3391 MOTOR Centra lift ESP MOTÖR'ŠET 11n/2003 ~ 4114 3401 GAUGE PHOENIXGAUGEASSEMBLYSET1117äöÖ3--- 412Ö-- 34M Centralizer Centralift Centralizer SET-11n12003 General Notes ---.-..-..-.'..- - .- ---- --------..,..--.- Date' Note 3/5/2001 NOTE: This is a West Sak multilateral well. This schematic represents the 'B' sand lower lateral. See the 1D-102L 1 schematic for the 'D' sand u r lateral. 11n12003 TREE: VETCOGREY/4"/ESP/5M TREE CAP CONNECTION: 7" OTIS V OD Latch Port TRO 1 D-I 02 (200-075) ESP failure noti~~~~~~~//"'---- Subject: IDLI 2 (200-075) ESP fa. re notification From: NSK P blem Well Su <:::n1617@conocophillips.com> Date: Sun, 29 Aug :35:34 -0800 To: "Tom Maunder AOGCC (E-mail)" <tom_maunder@admin.state.ak.us> CC: NSK West Sak Prod Engr <n1638@conocophillips.com> Tom, The ESP in west sak well 1D-102 (PTD 200-750) has failed and will require a workover to repair. Diagnostics completed on 8/26/04 indicate the shaft is not turning while the motor is running, the shaft appears to be broken. The well has been SI since 8/10/04. Currently, gas lift is being considered as an alternative lift method. A 10-403 will be submitted prior to conversion to gas lift. Please let me know if you have any questions. Marie McConnell Problem Well Supervisor 659-7224 1 of 1 8/30/2004 11 :30 AM Mike Mooney Wells Group Team Leader Drilling & Wells y Cono coPh ill i ps P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 January 6, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 1 D-1 02/ 1 D-1 02L 1 (APD # 200-075/ 200-076) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent workover operations on the Kuparuk well 1 D-1 02 / 1 D-1 02L 1. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, M.¡.¡(~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad RECEIVED JAN 1 3 2004 Alaska Oil & Gas Cons. Commission Anchorage stA\M~EK~:1 J~~N 14 2.o0[~ OR\G\NAL 1. Operations Perfonned: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS D Suspend D Operation Shutdown D D Repair Well 0 Plug Perforations D D Pull Tubing 0 Perforate New Pool D Abandon Alter Casing Change Approved Program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: 4. Current Well Status: Development 0 Stratigraphic D P. O. Box 100360, Anchora e, Alaska 99510 7. KB Elevation (ft): RKB 101' 8. Property Designation: ADL 25650, ALK 468 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURF CASING PROD. CASING DUAL SCREEN L Perforation depth: measured 7378' / 7407' feet true vertical 3719' / 3647' feet measured 7357' feet true vertical 3720' feet Length Size MD 110' 13-318" 110' 4074' 7-5/8" 4175' 754' 7" 4929' 2579' 4" X 4.5" 7357' / 7393' Measured depth: no perfs: pre-pack screens in horizontal laterals true vertical depth: Tubing (size, grade, and measured depth) 4-1/2" , L-80, 4122' MD. Packers & SSSV (type & measured depth) no packer no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A 13. Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl 781 497 87 1693 15. Well Class after proposed work: Exploratory D Development 0 Service D 16. Well Status after proposed work: oil0 GasD WAGD GINJD WINJ 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Oil-Bbl 498 231 Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run - Daily Report of Well Operations_X Contact Printed Name Signature Guy Schwartz @ 265-6958 Mike ooney Title Phone: 263-4574 ORIGtN,ð\L Perforate D Variance 0 Annular Disp. D Stimulate D Time Extension 0 Other D Re-enter Suspended Well 0 5. Permit to Drill Nu~þV 200-0751 Y303-191 6. API Number: 50-029-22960-00 1 50-029-22960-60 9. Well Name and Number: 1 D-1 02 / 1 D-1 02L1 10. Field/Pool(s): Kuparuk River Field 1 West Sak Oil Pool Exploratory D Service D Plugs (measured) Junk (measured) TVD Burst Collapse 110' 3439' 3752' 3720' RECEIVED JAN 1 3 2004 ask a Oil & Gas Cons. Commiss,on Anchorage Casin Pressure Tubin Pressure 352 308 WDSPLD Wells Group Team Leader Date 1/1 t-/ó j Pre ared b Sharon Allsu -Drake 263.4612 SUBMIT IN DUPLICATE Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 11/3/2003 11/4/2003 06:30 - 09:00 09:00 - 14:00 14:00 - 16:00 16:00 -19:30 19:30 - 23:30 23:30 - 00:00 00:00 - 03:00 03:00 - 04:30 04:30 - 06:30 06:30 - 14:00 14:00 - 18:00 Page 1013 ConocoPhillips Alaska Operations Summary Report 10-102 1 D-1 02 WORKOVER/RECOMP Nabors 3S Sub Hours Code Code Phase 2.50 MOVE MOVE MOVE 5.00 MOVE MOVE MOVE 2.00 MOVE MOVE MOVE 3.50 MOVE MOVE MOVE 4.00 WELLS RURD WRKOVR 0.50 WELLS WRKOVR WRKOVR 1.50 WELCT NUND WRKOVR 2.00 WELCT KILL WRKOVR 7.50 WELCT KILL WRKOVR 4.00 WELCT OBSV WRKOVR 18:00 -19:00 1.00 WELCT SFTY WRKOVR 19:00 - 20:00 1.00 WELCT WRKOVR 20:00 - 22:00 2.00 WELCT WRKOVR 22:00 - 00:00 2.00 WELCT WRKOVR 11/5/2003 00:00 - 02:00 2.00 WELCT CIRC WRKOVR Start: 11/3/2003 Rig Release: Rig Number: Spud Date: 6/1/2000 End: 11/8/2003 Group: Description of Operations PJSM on rig move. Secure all service lines and loops. Prepare pad around wellhead. Prepare to scope derrick. Scope and lay down derrick on carrier unit. Blow down steam. Prepare pity moduele and move pits away and stage down pad. Move pipe shed away from rig. Move rig carrier of well 1 D-110A. Move Annular & Double gate BOP and set on mat behind well. Lay mats and herculite under back of carrier. Back rig carrier over well, center up, and jack up and level carrier. Move pipe shed into place, move pits into place. Raise derrick. Hang ESP cable sheave off derrick. Scope up top section 0 mast. Raise windwalls, tighten stablizer lines. Hook up flow line, choke and kill lines, reverse circulating line, and stand pipe manifold. Accepted rig for operations at 19:30 hrs. Stack up BOP in cellar. APC hands rigging up circulating lines and manifold outside from rig to tanks. RU Little Red Services for pumping. Lay berm and herculite for 2 open top tanks and tiger tank for well kill. RU & test choke manifold. APC rigging up tanks and lines for killing well. Test choke manifold to 250 psi & 3500 psi. APC rigging up hard lines, valve manifold, and choke. Finish laying Herculite and building berm. Move open top tank and spot another open top tank and a tiger tank for returns while killing well (also for well 1 D-140). Have 2, 290 Bbls loads of seawater with KCI on site and 290 Bblload of 10.2 ppg kill weight brine. RU lubricator. Pull BPV. RD lubricator. 1450 psi on tubing. Continue rigging up lines, tie into tubing and annulus wing valves, double valve same. Hook in Little Red pumper. Double check lines. Finish RU Little Red. Pressure test lines to 3000 psi with Little Red, OK. PJSM following crew change, with rig crew, Little Red, and APC hands. 1450 psi on Tubing, 1300 psi on Annulus. Bled down tbg & IA through choke to tiger tank. Pumped 40 bbls. heated diesel (105 deg F) down tbg @ 4 BPM taking returns into open top tank. Pumped 250 bbls filtered heated 3% KCL water down tbg. taking returns to open top @ 4 BPM holding 300 psi on IA to keep form. from flowing while circ. Bullheaded 330 bbls 3% KCL water dwn tbg. Shut down record tbg press @ 600 psi. Pumped 75 bbls KWB (10.2 ppg) down tbg taking returns to open top holding 300 psi back press on IA. Close IA and bullheaded 50 bbls 10.2 ppg brine down tbg. Resumed circulating 10.2 ppg brine bringing 10.2 ppg returns filling hole all the way around with KWF. Shut down. SI press = 125 psi. Monitor well. Held Pre-Spud and efficiency meeting at KOC with all contractors, engineer and all others involved with the project. Pre-Spud meeting with both crews. Continue to monitor well pressure status. Slowly bleeding off to 80 psi. Bled off 10 bbls from casing side and 5 bbls from tubing side. Pressure went from 80 psi to 40 psi. Load pits with 9.8# brine and build 10.3# Continue build brine to 10.3# per engineering. Bled off another 10 bbls from casing - pressure down from 38 psi to 33 psi after bleed. Observing well pressure - continue to build brine to 10.3# by adding NaBr sacks. Observe well while building 10.3# brine. 28 psi on well. Attempted to Printed: 12/15/2003 2:44:29 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 11/5/2003 00:00 - 02:00 02:00 - 03:00 03:00 - 04:30 04:30 - 07:00 07:00 - 07:30 07:30 - 08:30 08:30 - 12:00 12:00 - 14:30 Page 2 of 3 Conoco Phillips Alaska Operations Summary Report 1 D-1 02 10-102 WORKOVER/RECOMP Nabors 3S Sub Code Code Phase 2.00 WELCT CIRC WRKOVR 1.00 WELCT KILL WRKOVR Hours 1.50 WELCT WRKOVR 2.50 WELCT KILL WRKOVR 0.50 WELCT OBSV WRKOVR 1.00 WELCT COND WRKOVR 3.50 WELLS NUND WRKOVR 2.50 WELLS SEaT WRKOVR 14:30 - 15:30 SEQP WRKOVR 15:30 - 17:45 CIRC WRKOVR 17:45 - 20:00 2.25 WELLS PULD WRKOVR 20:00 - 00:00 4.00 WELLS PULD WRKOVR 11/6/2003 00:00 - 02:00 02:00 - 09:00 09:00 - 12:00 12:00 - 14:00 14:00 - 19:30 19:30 - 00:00 11/7/2003 00:00 - 02:30 2.00 WELCT COND WRKOVR 7.00 WELLS PULD WRKOVR 3.00 WELLS PULD WRKOVR 2.00 WELLS TRIP WRKOVR 5.50 WELLS TRIP WRKOVR 4.50 WELLS CIRC WRKOVR 2.50 WELCT KILL WRKOVR Start: 11/3/2003 Rig Release: Rig Number: Spud Date: 6/1/2000 End: 11/8/2003 Group: Description. of Operations bleed 10 more bbls. Well still charged up. Circulated 10.3# brine around 190 bbls @ 3 bpm - 80 psi backpressure on choke - lost 60 bbls to formation - 10.3# back to surface. Monitor well while bleeding off surface pressure to open top tank. Well flowing 18 bblslhour with 8 psi on surface. Got back all the losses during the circulation. Move fluid from open top back to pits to weight up another .2 to 10.5#. Begin second circulation using 10.5# NaBr brine - losing fluids to formation (avg. 2 bbls every 10 pumped) - slowed pump rate down to 1 bbllmin with a wide open choke. Still losing fluids to formation. Blow down return line to open top tank, monitor well. Transfer 10.2+ ppg brine from return tank back to pits. weight up to 10.5 ppg. RIU kill line to annulus to fill hole. Well dead. Tbg 0 IA O. Set BPV. ND tree and adaptor flange. NU BOP, riser and turnbuckles, choke line. PU 4.5" landing jt MU in hanger. Test BOP 250 psi and 3500 psi. Test annular to 3000 psi. Pull BPV install two-way check test blinds HCR choke, and inside manual. Pull two way check. Witnessing by State waived by Lou Gramaldi. BOLDS, Pull hanger up 3'. Heated 10.5 ppg brine in pits to 120 deg. and circulated one hole volume (165 bbls ) @ 3 BPM @ 170 psi. Pulled hanger to rig floor and ND penetrators and hanger Safety meeting and start pulling out of the hole with the completion. Several outer shield penetrations but cable seemed intact otherwise. No corrosion seen. Raychem cable was swollen and gasified. Continued out of hole with completion with spooling heat trace and ESP cable onto reels. Moved fluid from pit 1 to pit 2 and weighted up from 9.8# to 10.2# using NaBr. Moved fluid from the MI tanks to pit 2 to weight up to 10.2#. Fluid losses at this point 12-15 bbllhour with 10.5# in hole. Continued POOH. Continued pulling ESP completion to surface spooling ESP cable to Centrilift and Raychem heat trace to wooden spool. Total losses to formation during POOH @ 0600 - 123 bbls. 8.7 BPH aver. loss. LD pups, slotted nipple, and ESP Seal Section, gearbox, motor and centralizer. Unstring ESP cable from sheave and let cable down to ground and spool up. Clean up rig floor, and move clamps out of pipe shed. Load pipe shed with 6 jt. 4-1/2" NSCT tubing for running packer. Pick up 7-5/8" Baker Retrievamatic Packer. Tight getting packer thru wellhead. Losses to formation from 0600 hrs till 1200 hrs = 28 bbls. 4-5 BPH. Continue to RIH with packer to test 7-5/8" casing. Set Baker Retrievamatic Packer at 4110'. Press 7-5/8" casing to 2500 psi. on chart. Fluid losses 5 BPH. Tested casing for 30 min. Casing test good. Circ bottoms up per procedure w/1 0.2# + - well unbalanced - Circulated surface to surface w/1 0.2 heavy - well still unbalanced - influxed 9 bbls in 20 minutes - circulated around surface to surface again checking in and out weights continuously looking for heavy/light spots - prep to weight up brine again. Well still flowing. Weight up brine again to 10.4 heavy. Build up brine weight to 10.4# heavy. Inflluxed 8 bbls in 30 min while Printed: 12/15/2003 2:44:29 PM Page 3 of 3 ConocoPhillips Alaska Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 D-1 02 1 D-1 02 WORKOVER/RECOMP Nabors 3S Date Sub From.. To Hours Code Code Phase .. 1117/2003 2.50 WELCTL KILL WRKOVR 00:00 - 02:30 02:30 - 07:00 4.50 WELLSR PULD WRKOVR 07:00 - 11 :00 4.00 CMPL TN RUNT CMPL TN 11:00 -18:00 7.00 CMPLTN RUNT CMPLTN 18:00 - 20:00 2.00 CMPL TN DEOT CMPL TN 20:00 - 00:00 4.00 CMPL TN RUNT CMPL TN 11/8/2003 00:00 - 03:30 3.50 CMPL TN RUNT CMPL TN 03:30 - 06:00 2.50 CMPL TN RURD CMPL TN 06:00 - 07:00 1.00 CMPL TN RURD CMPL TN 07:00 - 15:00 8.00 CMPL TN NUND CMPL TN 15:00 -19:00 4.00 CMPL TN FRZP CMPL TN 19:00 - 00:00 5.00 WELLSR PLGM CMPL TN Start: 11/3/2003 Rig Release: Rig Number: Spud Date: 6/1/2000 End: 11/8/2003 Group: DescriptiÖn. of Operations monitoring well. Begin circulation surface to surface to re-kill well. Pumped 180 bbls of 10.4# heavy around - well appears to be dead - drinking about 4 bblslhour. Start to POOH wI packer - well still drinking 10.4# heavy at about 4-5 bph. Dropped 3.853" steel rabbit on 80' of slickline. Layed down 4 joints and begin standing back doubles in derrick. Found rabbit in mid stand #50. Drifts fine with 3.833". Put stand back together and continue to POOH. Layed packer down. Rigup cable sheave, and feed motor lead extension cable through to rig floor. Set up two spools of instrument lines for Phoenix Guage. Picked up motor centralizer, Phoenix Guage Assembly" ESP Motor, ESP Tandem Seal Section, TCC Crossover/coupling. Check and record breakaway & rotational shaft torque, and assemble seal section to motor section. Service the seal section and check and record shaft torque values of the entire assembly. Installed LaSalle Protectolizers to secure motor lead extention cable and Phoenix instrument lines alongside unit. Heat trace was not run back. Added two 4-1/2" Pin X Pin (IBT X NSCT) pups for lining up Phoenix Discharge Temp & Press. assembly. Lowered assembly into well while continuing to attach the MLE cable, as per procedure and tally. Continued to RIH with ESP, and power cable on 4-1/2" tubing installing Cannon cable clamps ever jt for 6 jts. every 2nd jt thereafter. Fluid losses 4-5 BPH. Tested all connections and feedback readings. Trouble reading the Phoenix Pressure gauge. Run in for laptop to help calibrate tools. New surface box from M.P. gave adequate readings. Discussed with engineering and Centrilift and decided to RIH. Started to RIH with completion adding clamps every other joint for ESP cable. Losing 2-3 bph fluid to formation. Continue to RIH with ESP completion string adding a clamp every other joint. Fluid losses about 2-3 bph. Picked up tubing hanger and landing joint. Cut power cable after checking megger. Begin splicing cable to tubing hanger. Splice complete - checked continuity again - power cable good. Landed tubing hanger - verified by looking in production valve to assure hanger was seated. RILDS. Back off landing joint. Begin NDNU process. Move tree out of pipe shed into cellar. Install BPV. ND stack. NU tubing adapter and 5K tree. Pull BPV Installed two-way check. Test tree to 250 psi and 5000 psi. Test the hanger voidlpackoff to 5000 psi. Pull test plug. Rigged up Liitle Red Pump truck, pumped 200 bbls sea water @ 450 psi 3.5 to 4 BPM. Shut in tbg. bullheaded 20 bbls to move NaBr away from Centrilift pump system. Switched to diesel and pumped 75 bbls diesel for freeze protect. Rigged up a line from tubing to casing to equalize the diesel Rig up BPV lubricator on rig floor and prep to set BPV after F.P. Set BPV. 500 psi on tubing and casing. Prep to clean pits and RDMO Nabors 3S to 1 D-129. Rig released @ 0000 hrs. on 11/9/03 (2400 hrs on 11/8/03). Printed: 12/15/2003 2:44:29 PM Date 11/24/03 11/25/03 1 D-102 Event History Comment TAGGED DRIVE @ 4046'WLM, JOB IN PROGRESS [ESP WORK] SET 4.5" TIC CENTRIFUGAL PUMP @ 4075'RKB, SET 4.5" PACK-OFF @ 4007'WLM, 4.5" SLIP STOP @ 3997'WLM, SET 1" SOV (2000#) @ 39751RKB, JOB COMPLETE [ESP WORK] Page 1 of 1 12/15/2003 )NOUCTOR (0-110, 00:13.375, Wt68.oo) TUBING (0-4122, 00:4.500, 10:3.958) SEAL (4084-4098, 00:5.130) PROD CASING (4175-4929, 00:7.000, Wt:26.00) ConocoPhillips Alaska, Inc. I I I 1D-102 API: 500292296000 SSSV T e: None Annular Fluid: KRU 10-102 PROD 6/22/2000 11/3/2003 Ref L Date: ID: Max Hole An Ie: Last U date: Size To Bottom TVD Wt Grade Thread 13.375 0 110 110 68.00 L-80 WELDED 7.625 0 4175 3439 29.70 L-80 BTC-MOD 7.000 4175 4929 3752 26.00 L-80 BTC-MOD 6.000 4368 4383 3568 0.00 L-80 to 1D-102L 1 4.500 4778 7357 3721 12.60 L-80 HSLHT Interval 4778 - 7357 St 1 2 MD TVD Man Man Type Mfr 2598 2459 CAMCO KBG-3 3975 3313 CAMCO KBG-2 0.000 0.000 De th 31 3989 3995 4075 4075 TVD 31 3322 3326 3376 3376 4084 4098 4114 4120 3382 SEAL 3391 MOTOR 3401 GAUGE 3404 Centralizer V Mfr VOD V Type Latch Port TRO Date Vlv Run Cmnt 0 11/7/2003 0 11/25/2003 2000# DMY SOV 1.0 1.0 BK-5 BK-5 Descri tion VETCO GRAY TUBING HANGER PHOENIX DISCHARGE PRESSURE SUB, set 11/7/2003 PHOENIX DISCHARGE TEMPERATURE SUB SET 11/7/2003 TCC CROSSOVER/COUPLING SET 11/7/2003 4.5" TCC CENTRIFICAL PUMP W/ 4.5" PACKOFF & SLiPSTOP SET ABOVE PUMP ON 11/25/2003 Centralift ESPTANDEM SEAL SET 11/7/2003 Centralift ESP MOTOR SET 11/7/2003 PHOENIX GAUGE ASSEMBLY SET 11/7/2003 Centralift Centralizer SET 11/7/2003 ID 4.000 0.000 0.000 3.958 0.000 0.000 0.000 4.500 0.000 Date Note 3/5/2001 NOTE: This is a West Sak multilateral well. This schematic represents the 'B' sand lower lateral. See the 1 D-1 02L 1 schematic for the 'D' sand u er lateral. 11/7/2003 TREE: VETCO GREY / 4" / ESP 1 5M TREE CAP CONNECTION: 7" OTIS ConocoPhillips Alaska, Inc. 1D-102L 1 PROD 7/12/2000 11/7/2003 TUBING (04122, 00:4.500, 10:3.958) KRU 1 D-1 02L 1 API: 500292296060 SSSV T e: NONE Annular Fluid: Ref L Last U date: Size To Bottom TVD Wt Grade Thread 13.375 0 110 110 68.00 L-80 WELDED 7.625 0 4175 3439 29.70 L-80 BTC-MOD 7.000 4175 4368 3558 26.00 L-80 BTC-MOD 4.500 4368 4999 3693 12.30 L-80 BTC-MOD 6.000 4368 4383 3567 0.00 to 1D-102 4.500 4999 7393 3648 9.50 L-80 HSLHT St MD TVD Man Man Type VMfr V Type VOD Latch Port TRO Date Vlv Mfr Run Cmnt 1 2598 2459 CAMCO DMY 1.0 BK-5 0.000 0 7/11/2003 2 3975 3313 CAMCO SOV 1.0 BK-5 0.000 0 11/23/2003 T e Descri tion ID HANGER VETCO GRAY TUBING HANGER SET 11/7/2003 4.500 SUB PHOENIX DISCHARGE PRESSURE SUB SET 11/7/2003 0.000 SUB PHOENIX DISCHARGE TEMPERATURE SUB SET 11/7/2003 0.000 SEAL XO TCC CROSSOVER/COUPLING SET 11/7/2003 4.500 (40854098, PUMP 4.5" TCC CENTRIFICAL PUMP WI 4.5" SLiPSTOP & PACKOFF SET 0.000 00:5.130) ABOVE PUMP SET 11/25/2003 4085 3382 SEAL Centralift Seal Section SET 11/712003 0.000 4098 3391 MOTOR Centralift PCESP Motor SET 11/7/2003 0.000 4114 3401 GAUGE PHOENIX GAUGE ASSEMBLY SET 11/7/2003 4.500 4120 3404 Centralizer Centralift Centralizer SET 11/7/2003 0.000 4646 3664 CMT Baker HMCV Cement Valve 3.844 VALVE ECP Baker 7' Isozone ECP 3.958 ECP Baker 20' Pa zone ECP 3.958 SLEEVE Baker CMD Slidin Sleeve 3.437 LINER (43684999, 00:4.500, Wt:12.30) I I I Note NOTE: This is a West Sak multilateral well. This schematic represents the 'D' sand upper lateral. See the 1D-102 schematic for the 'B' sand lower lateral. TREE: VETCO GREY I 4" I ESP I 5M TREE CONNECTION: 7" OTIS r~e: vvesT ,~aK vvorKovers Subject: Re: West Sak Workovers Date: Tue, 04 Nov 2003 07:11:50 -0900 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: "Schwartz, Guy L" <Guy. L.Schwartz@conocophillips.com> CC: "Mooney, M" <M.Mooney@conocophillips.com>, "Worthington, Aras J" <Aras.J.Worthington@conocophillips.com> Guy, et al: Thanks for bringing over the USIT log on 1D-140. I concur with your assessment of the log. It did not appear that there was any wall loss and a pattern suggestive of the original mill marks was evident. You also provided the report sheets for the boroscope inspections and the Schlumberger engineer's assessment of the log. You emailed me the log for 1D-110A. I agree with ConocoPhillips' proposal to eliminate the casing inspection logs in 1D-102 and 1D-129, subject to the assessment of the condition of the tubing and any other factors that would lead one to believe that conditions in one of these wellbores is different than the initial wells surveyed. Based on choosing what you believed were the worst case wells based on annular production time and the flow rates should have given ConocoPhillips the most conservative inspection. I will place a copy of this message in the respective well files. Please call me with any questions. Tom Maunder, PE AOGCC "Schwartz, Guy L" wrote: > Tom, > As per our conversation today regarding the ongoing West Sak ESP workovers I wanted formally state the results and discuss further diagnostic procedures. > The wells we have completed are first 1D-140 and 1D-110A. These two wells were chosen to be the first in our set of four workovers due to the longer duration of annular flow with these > wells. It was felt that if the casing and wellhead diagnostics looked favorable that further work on the following two wells (1D-lO2 and 1D-129) could be re-addressed and possibly reduced in scope. > > Results to date: > 1D-140: Borescope of the wellhead showed no wear or erosion. Inside of the wellhead and VR threads looked to be in "like new" condition. > The 7 5/8" casing was pressure tested to 2500 psi and held solid. > A USIT corrosion log was run over the entire 7 5/8" casing and showed that it was in very good condition. Milling marks were still very visible on the inside of the tubing and virtually no wall loss was seen. > > 1D-110A The borescope of the wellhead also showed the wellhead and 2" valve and VR to be in like new condition. > The 7 5/8" casing tested to 2500 psi. > USIT corrosion log showed the 7 5/8" casing to be in great shape. > > As a prudent operator we are proposing we continue to pressure test the 7 5/8" casing on the remaining workover wells but discontinue the borescope and USIT log. If conditions warrant change such as corroded tubing being pulled out the remaining two wells we would of course re-look at running the USIT log. > Thanks foryour consideration, > > Guy Schwartz > > Drilling and Wells Engineer > office: 907-265-6958 > AT0-1548 11/4/2003 7:12 AM Lauarterly llowline inspection reports Subject: Quarterly flowline inspection reports Date: Mon, 6 Oct 2003 13:02:53 -0800 From: "NSK Problem Well Supv" <n1617@conocophillips.com> To: tom_maunder@admin.state.ak.us, bob_fleckenstein@admin.state.ak.us CC: "n1617" <rtl 617@conocophillips.com> Tom, Here is a copy of the quarterly flowline inspection reports required to fulfill the Sundry requirements for the following wells. 1 D-102: PTD 2000750, Sundry #302-101 1D-105A: PTD 2012020, Sundry #302-294 1D-110A: PTD 2000390, Sundry #302-227 1 D-121: PTD 1971810, Sundry #302-304 1D-127: PTD 1981090, Sundry #353-057 1 D-129: PTD 1972130, Sundry #303-092 1D-140: PTD 2001360, Sundry #302-376 3H-05: PTD 1870770, Sundry #302-102 Please let me know if you have any questions. Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 (See attached file: 3H-05 Quarterly Inspection Log.xls)(See attached file: t D-102 Insp Log.xls)(See attached file: 1 D-105 Inspection Log.xls)(See attached file: 1D-110 Insp Log.xls)(See attached file: 1D-121 Inspection Log.xls)(See attached file: 1D-127 Inspection Log.xls)(See attached file: 1D-129 Inspection Log.xls)(See attached file: 1D-140 Inspection Log.xls) Name: 3H-05 Quarterly Inspection Log.xls Type: EXCEL File (application/msexcel) Type: EXCEL File (application/msexcel)l Encoding: base64 I ~1 Inspection Log.xls D-1 O5 Name: 1D-105 Inspection Log.xls ;t Type: EXCEL File (application/msexcel)iI Name: 1D-110 Insp Log.xls Type: EXCEL File (application/msexcel)l Encoding: base64 Type: EXCEL File (application/msexcel)'I Encoding: base64 .......... il B 1 D-127 Inspection Lo.q.xls Type: EXCEL File (application/msexcel)l Encoding: base64 j I of 2 101612003 3:17 PM q4uarterly llowline inspection reports ¢/1~'~ 1 D-129 Inspection Lo.q.xls Name: 1D-129 Inspection Log.xls t Type: EXCEL File (application/msexcel),I ,, Encoding: base64 ,¢~~--~ 1 D-140 Inspection Lo.q.xls Name: 1D-140 Inspection Log.xls Type: EXCEL File (application/msexcel) Encoding: base64 of 2 10/6/2003 3:17 PM 1 D-102 Special Inspection Request Log DS1D 1D-102 - Annulus flowback inspection - flow is still through the flowline - Inspect once every 2 weeks for 2 months - if no damage noted then inspect monthly B, I, N - (B - baseline inspection, I - Increase in % wall loss, N - No change from previous inspection) # of Worst Date of Inspection Inspection B, I, N CaseWall Damage Locations Loss % Grade Comments O4/04~O2 8 B O% A 04/05/02 2 N 0% A 04/18/02 6 N 0% A 05~04~02 6 N 0% A 05/19/02 0 0 0% n/a 06/19/02 2 N 0% A 06/24/02 6 N O% A 07/2O/02 6 N O% A 08/19/02 6 N 0% A 09/20/02 6 N 0% A 10/19/02 6 N 0% A 11/20/02 6 N 0% A 12/05/02 6 N 0% A o% ^ 07/27/03 6 Base line Inspection RT/UT No Changes No Changes No Changes No RT or UT inspection due to Drilling Rig No RT inspection due to Drilling Rig RT follow-up insp once drilling rig moved off. No changes noted No Changes No Changes No Changes No Changes No Changes .No Changes No Changes Quarterly Inspection Interval Quarterly Inspection Interval ConocOPhillips Guy Schwartz Senior Wells Engineer Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6958 July 17, 2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approval, West Sak 1 D-102 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the West Sak well 1 D-102. 1 D-102 was drilled in June 2000 as a multilateral West Sak producer. A Through Tubing Conveyed Progressive Cavity Pump (TTC PCP ) assembly was run in order to enable pump change-outs with Slickline in the event of pump failure. The motor coupling failed in December 2001 and attempts to restart the motor section failed until the well was put on gas lift in March 2002. The ESP pump section has been pulled and a packoff and'slipstop set in the tubing to allow gaslift through the GLM at 3984'. Gaslift has been ongoing by injection down the tubing with production up the 4 Y2" tubing by 7 5/8" casing annulus. The workover objective is to change out the existing TTC PCP pump/motor assembly and install a Through Tubing Conveyed Centrifical ESP pump assembly (TTC CESP). The actual pump section will be run on slickline after the rig has moved off location. Other goals included in the workover include a.,s_s_e~ of the 7 5/8" casing for corrosion/erosion and inte.~ty in regards to IQrLg_.te~Q_9_0~!ar flow. If the casing does not pressure test or the casing inspection log (USIT) shows significant wall loss the operation will be discontinued and the well secured. If you have any questions or require any further information, please contact me at 265-6958. Sincerely, Senior Wells Engineer CPAI Drilling and Wells GLS/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: Abandon Alter casing Change approved program Suspend D Operation Shutdown Repair well r'~'l ,¢ Plug Perforations Pull Tubing [~r~'' Perforate New Pool Perforate [~ Vadance Stimulate [~ Time Extension Re-enter Suspended Well Annular Disp. Other 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 4. Current Well Class: Development ~-~ Exploratory Stratigraphic [~ Service 5. Permit to Drill Number: 200-075 6. APl Number: 50-029-22960-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 101' 1D-102 8. Property Designation: 10. Field/Pool(s): ADL 25650, ALK 468 Kuparuk River Field / West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7378' 3721' 7357' 3720' Casing Length Size MD TVD Burst Collapse CONDUCTOR 110' 13-3/8" 110' 110' SURF CASING 4074' 7-5/8" 4175' 3439' SURF CASING 754' 7" 4929' 3752' DUAL SCREEN LNF 2579' 4" 7357' 3720' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): no parrs: pre-pack screens in horizontal latera 4-1/2" L-80 4129' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BAKER SC-1R PACKER pkr= 4778' no SSSV no SSSV 2. Attachments: Description Summary of Proposal [~] 13. Well Class after proposed work: Detailed Operations Program ~1 BOP Sketch [~ Exploratory ~ Development ~-~ Service r-I 14. Estimated Date for Commencing Operations: August 11, 2003 16. Verbal Approval: Date: 15. Well Status after proposed work: Oil r~ Gas r-'l Plugged r--1 Abandoned [] WAS Fl S NJ I--1 W NJ I--I WDSP, I--1 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Guy Schwartz Signature ~'7 '~'~ Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Contact: Title: Phone Guy Schwartz @ 265-6958 Senior Wells Engineer Date '?_/7-~ lSundry Number: Plug Integrity F-~ BOP Test ~ Mechanical Integrity Test F-~ Other: '~~) ~..~, ~,~,-~ ~,,~ ~,~.,,.3 ~,',.~,. '~)(~'i~ '-~'- ~EI~. ~ Subsequent Form Required: %~)~ JUL i ' 003 JUL Form 10-403 Revised 2/2003 · COMMISSIONER BY ORDER OF THE COMMISSION Date: 0 RIG IN ~R0~IBMIT IN DUPLICATE PRE-RIG WORK: West Sak 1D-102 GENERAL WORKOVER PROCEDURE 1. 5-7 days before RWO, RU Slick Line Unit. RIH and pull HFCV from GLM @ 3984' leaving an open pocket. 2. Kill well by pumping down tubing, taking returns up the annulus. 9.9 ppg KWF is expected. 3. Set BPV in tubing and VR plug in annulus valve. 4. Prepare Location for Nabors 3S: Remove well house(s), check tubing hanger LDS's, Test tubing and casing packoffs. GENERAL WORKOVER PROCEDURE: 1. MIRU Nabors 3S. Lay hard-line to tree. 2. Verify if well is dead. If not circulate well with appropriate KWF based on surface pressure. Install BPV. 3. ND tree/NU BOPE. Function test BOPE. Pull BPV. Install test plug. 4. Test BOPE to 4000 psi. Pull test plug. 5. Screw in landing joint ( 4.909 MCA thread connection ). POOH standing back 4-1/2" tubing and spooling up ESP Cable and Heat Trace (BOT gauge wire is embedded in the power cable). . Load, strap and drift 3-1/2" drill pipe. RIH with retrievable bridge plug, set at 4100 ft and release from plug. Cover with 10' of sand. Test casing to 2500 psi for 30 min. POOH standing back 3 ¥2 drill pipe. 7. RIH w/RBP latch, cleanout/casing scraper assembly. 8. Cleanout (reserving out) to 4100', relatch packer and release. POOH laying down 3-1/2" drill pipe. 9. PU and RIH w/Eline USIT casing inspection log. 10. RIH w/4-1/2" tubing and ESP Assembly. Space out heat trace and splice power cable. 11. Land tubing hanger. RILDS, install two-way check and test tubing hanger. 12. ND BOPE/NU Tree/Test. 13. Freeze protect with diesel to +/- 2000' TVD. Set BPV. RDMO workover rig. Lower Limit: 4.0 days Expected Case: 5.0 days Upper Limit: 7.0 days No problems encountered. Problems pulling ESP completion, Space out problems and control line issues. GLS 6/1/03 ConocoPhillips Alaska, Inc. (0-110, 0D:13.375, W~68.00) GasL~ t4andrelNalvE (3984-3985, OD:5.985) PUMP (4058-4059, 0D:4.500) NIP (4079-4080, 0D:4.500) SEAL (40854086, 0D:5.130) GEARBOX (4099-4100, 0D:5,620) TUBING (0-4129, 0D:4.500, ID:3,958) Centralize~ (4122-4129, OD:6.250) PKR (4778-4779, OD:6.000) Per[ (4778-7357) SLEEVE (4823-4824, 0D:5.500) SURF CASING (41754929, OD:7.000, Wt:26.00) KRU 1D-102 1D-102 APl:1500292296000 SSSV Type:I None Annular Fluid:I Reference Log:I Last Ta~l:13997 Last Tag Date:~ 12/11/2001 Casing String - ALL Description Well Type:IPROD Orig 16/22/2000 Completion:I Last W/O:I Ref Log Date:I TD:17378 ftKB Max Hole An~lle:194 deg (~ 6304 Size Angle (~ TS:I deg@ Angle @ TD: 89 deg@ 7378 Rev Reason:IGLV correction Last Update:Il/7/2003 Top 0 Boffom TVD CONDUCTOR 13.375 110 110 SURF CASING 7.625 0 4175 3439 SURF CASING 7.000 4175 4929 3752 CSG WINDOW 6.000 4368 4383 3568 DUAL SCREEN LNR 4.500 4778 7357 ~ 3721 Wt Grade 68.OOl L-8O 29.70 L-80 26.00 L-80 0.00 L-80 12.60 L-80 Thread WELDED BTC-MOD BTC-MOD to 1D-102L1 HSLHT TUbin9 Strin9 -TUBING Size I Top I Bottom TVD Wt GradeI Thread 4.500 I I 0 4129 3410 12.60 L-80 I NSCT i Perforations Summary Interval 4778 - 7357 TVD 3733 - 3721 Zone Status Ft SPF Date I Type Comment WS CB,WS 12579 50 6/22/2000 Screens Perfs thru screens stI MD I TVDI Ma. I Man I V Mfr IV Type Iv OD I Latchl Port IT.el Date I v~v Mfr Type Run I .0 I0. 0 1 0 1. wino check Other :(plugsi: equiP:i: :etciI Depth/TVD I Type 3023 127161 CAB'E 405813365I PUMP 4o79 I3379 1 NiP 4085 13382 I SEAL 4099 J3391 I GEARBOX 4100 /33921 MOTOR 4122 /3406 I Centralizer 4778 13733 J PER 4823 J3742 J SLEEVE Description ID Heat Trace Cable to 3023' 0,000 ESP PUMP reset 1/8/02 W/4.5" SLIPSTOP & PACKOFF @4008' reset 0.000 3/25/2002 0.000 Centralift Slotted Nipple Centralift Seal Section GST3 0.000 Centralift 9:1 Series 525 Gearbox 0,000 Centralift PCESP Motor 57 HP 1315/26 0.000 Centralift Centralizer w/Baker Sentry Gauge at 4128' Baker SC-1 R Packer Baker CMD Sliding Sleeve G~n::e~al~ N~teS:;: 0.000 4.000 3.437 Date I Note 3/5/2001 NOTE: This is a West Sak multilateral well. This schematic represents the 'B' sand lower lateral. See the 1D-102L1 schemat c for the 'D' sand upper lateral. ~' Q0~rt(~:ly Flowline line inspections Subject: Quarterly Flowline line inspections Date: Mon, 7 Jul 2003 16:08:20 -0800 From: "NSK Problem Well Supv" <n1617@conocophillips.com> To: tom_maunder@admin.state.ak.us CC: bob_fleckenstein@admin.state.ak.us, "rtl 617" <rtl 617@conocophillips.com> Tom, Here is a copy of the quarterly flowline inspection reports required to fulfill the Sundry requirements for the following wells. 1D-102: PTD 2000750, Sundry #302-101 1D-105A: PTD 2012020, Sundry #302-294 1D-110A: PTD 2000390, Sundry #302-227 1D-121: PTD 1971810, Sundry #302-304 1D-127: PTD 1981090, Sundry #353-057 1D-129: PTD 1972130, Sundry #303-092 1 D-140: PTD 2001360, Sundry #302-376 3H-05: PTD 1870770, Sundry #302-102 Please let me know if you have any questions. MJ Loveland Problem Well Supervisor ConocoPhillips Alaska Inc. (907) 659-7224, 659-7043 (See attached file: 3H-05 Quarterly Inspection Log.xls)(See attached file: 1 D-102 Insp Log.xls)(See attached file: 1D-105 Inspection Log.xls)(See attached file: 1D-110 Insp Log.xls)(See attached file: 1D-121 Inspection Log.xls)(See attached file: 1D-127 Inspection Log.xls)(See attached file: 1 D-129 Inspection Log.xls)(See attached file: 1 D-140 Inspection Log.xls) I_,, Name: 3H-05 Quarterly Inspection Log.xls 1 ~3H-05 Quarterly Inspection Log.xIs Type: EXCEL File (application/msexcel) L ...................................................................................................................... .E nco.d!,n.g_.!,??.se6~ ............................ .............................................................................. ~1D-102 Insp Lo,q.xls Name: 1D-102 Insp Log.xls I Type: EXCEL File (application/msexcel).1 . Encoding: base64 'I --,, Name: ~1D-105 Inspection Log.xls :t : ¢/LcL~ 1D-105 Inspection Lo.q..xls Type'. EXCEL File (application/msexcel) t ~I Encoding' base64 Name: 1D-110 Insp Log.xls . 1D-110 Insp Log.xls Type: (application/msexcel) EXCEL File Encoding: base64 ~1D-121 Inspection Log.xls Name: 1D-121 Inspection Log.xls t~ Type: EXCEL File (application/msexcel) Encoding: base64 lof2 8¢A NED JUL .!. 2 03 7/14/2003 10:39 AIV 1D-102 Special Inspection Request Log DS1D 1 D-102 - Annulus flowback inspection - flow is still through the flowline - Inspect once every 2 weeks for 2 months - if no damage noted then inspect monthly B, I, N - (B - baseline inspection, I - Increase in % wall loss, N - No change from previous inspection) # of Worst Date of Inspection B, I, N Case Wall Damage Inspection Locations Loss % Grade 04/04/02 8 B 0% A 04/05/02 2 N 0% A 04/18/02 6 N 0% A 05/04/02 6 N 0% A 05/19/02 0 0 0% n/a 06/19/02 2 N 0% A 06/24/02 6 N 0% A 07/20/02 6 N 0% A 08/19/02 6 N 0% A 09/20/02 6 N 0% A 10/19/02 6 N 0% A 11/20/02 6 N 0% A 12/05/02 6 N 0% A 01/29/03 6 N 0% A 05/02/03 6 N 0% A Comments Base line Inspection RT/UT No Changes No Changes No Changes No RT or UT inspection due to Drilling Rig No RT inspection due to Drilling Rig RT follow-up insp once drilling rig moved off. No changes noted No Changes No Changes No Changes No Changes No Changes No Changes No Changes Quarterly Inspection Interval Quarterly Inspection Interval 1. Type of request: ALASKA OIL AND GAS CONSERVATION COMMISSION ~-/kfl~t/ "~ i~[n'k)? APPLICATION FOR SUNDRY APPROVALS Suspend_ Operational shutdown _ Re-enter suspen, a~red ~_' Plugging _ Time extension .~/,P" Stimulate _ Pull tubing _ Variance _-~ " Perforate _ Abandon_ Altercasing _ Repairwell_ Change approved program_ Other_ 2. Name of Operator ConocoPhillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 STATE OF ALASKA 179' FSL, 595' FEL, SEC. 14, T11 N, R10E, UM At top of productive interval 1785' FNL, 823' FWL, SEC. 24, T11N, R10E, UM At effective depth 1070' FSL, 914' FWL, SEC. 24, T11N, R10E, UM At total depth 4206' FNL, 4364' FEL, Sec. 24, T11N, R10E, UM 5. Type of Well: Development Exploratory __ Stratigraphic __ Service_ (asp's 560491, 5959844) (asp's 562038, 5955470) 6. Datum elevation (DF or KB feet) RKB 101 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1 D-102 9. Permitnumber/approvalnumber 200-075 10. APInumber 50-029-22960 11. Field / Pool West Sak Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size CONDUCTOR 110" 13-3/8" SURF CASING 4074' 7-5/8" SURF CASING 754' 7" LINER 2579' 4 7378 3721 7357 3720 feet Plugs (measured) feet feet Junk (measured) feet Cemented 7 yds HE 520 sx AS IIIL, 410 sx Class G see above 111 sx Class G Measured Depth 110' 4175' 4929' 4778' True ve~icalDepth 110' 3439' 3752' 3721' Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) No perfs - Pre pack screens in horizontal laterals 4-1/2", 12.6#, L-80 Tbg @ 4129' MD. BAKER SC~IR PACKER @ 4778' MD. 13. Attachments Description summary of proposal _X Detailed operations program _ BOP sketch _ 15. Status of well classification as: 14. Estimated date for commencing operation March 27, 2003 16. If proposal was verbally approved Name of approver Date approved Oil __X Gas _ Suspended _ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title: Problem Well Supervisor Jeral FOR COMMISSION USE ONLY Questions? Call Jerry Dethlefs 659-7224 Date Conditions of approval: Notify Commission so representative may witness Plug integrity__ BOP Test__ Mechanica. I Integrity Test __ Approved by order of the Commission Form 10-403 Rev 06/15/88 · I Approval no~c~.~ (~/' Location clearance _ Subsequent form required 10- , ~ .... , ',.: ~ :- ~....., .... ?: Commissioner Date RBDHS BFL 6 Please return to: NSK Problem Well Supewisor, NSK-69 SUBMIT IN TRIPLICATE ConocoPhillips Alaska, Inc. West Sak Well 1D-102 (PTD 2000760) SUNDRY NOTICE 10-403 VARIANCE REQUEST March 3, 2003 / The purpose of this Sundry Notice is for an extension to produce ConocoPhillips' West Sak well 1D-102 that is completed as an ESP (electric submersible pump). // 1D-102 has been operating under Sundry//302-313 approval to produce with gaslift down the tubing and production fluids up the inner annulus (IA). The ESP f~/led on 12/11/01 with wellwork attempts to operate and fix ESP continuing until 3/15/02.' The initial 6-month Sundry #302-101 was approved by the AOGCC on 3/27/02, which allowed lift gas to be injected down the tubing and production up the annulus. After approval was granted, gaslifted production started on 04/04/02. / ConocoPhillips received approval from the AOGCC on 09/28/02 to ext~d the length of Sundry #302-101 for an additional 6-month period, which expires 03/30/2003. Inspections of the hardline have been scheduled monthly with the most recent performed 01/29/03. The results of these inspections have showed no erosion with 0% change in wall loss to date. Subsequent inspections will occur quarterly w~he next one scheduled for 04/29/03. · th -/~-~ ~/~ / The latest production test on February 14 recorde ~.:IsOPD, 372 BWPD (39%WC), and 639 MSCF of lift gas. Attached is a wellbore diagram of~he well. ConocoPhillips proposes that: 1. The AOGCC approve this extension request for a time period not to exceed 12 months from the approval date; 2. Perform quarterly flowline inspections and submit same to the AOGCC; /// 3. Should a workover not be completed within the approved time period the AOGCC will be contacted for a review and discussion of the plan forward. GConocoPhillips Alaska, Inc. ONDUCTOR ~ (0-110, O1~.13.375, ~68.00) Gas Uft ~landrelNalvE 1 (3984-3985, OD:5.985) PUMP (4058-4059, OD:4.500) NIP OD:4.500) SEAL (4085-4086, OD:5.130) GEARBOX (40994100, OD:5.620) TUBING (04129, 0D:4.500, ID:3.958) Centralizer (4122-4129, 0D:6.250) PKR (4778-4779, OD:6.000) Perf (4778.7357) SLEEVE (4823~824, OD:5.500) SURF --~~ CASING (41754929, OD:7.000, Wt:26.00) KRU 1D-102 1~102 APl:1500292296000 SSSV Type:I None Annular Fluid:I Reference Log:I Last Tag:13997 Last Tag Date:112/11/2001 Well Type:IPROD Orig 16/22/2000 Completion:I Last W/O:I Ref Log Date:I TD:17378 ftKB Max Hole Angle:194 deg (~ 6304 Angle (~ TS:I deg @ Last Update11/7/2003 CaSin9 Strin9 - ALL Description CONDUCTOR SURF CASING SURF CASING CSG WINDOW DUAL SCREEN LNR Size 13.375 7.625 7.000 6.000 4.500 Top 0 4175 4368 4778 Boffom 110 4175 4929 4383 7357 WD I Wt IGrade I 110 168.001 L-80 I 3439 129.701 L-80 I 3752 126.0Ol L-80 I 3721 I 12.60 I L-80 I Thread WELDED BTC-MOD BTC-MOD to 1D-102L1 HSLHT 4,500 0 4129 3410 112.601 L-80 I NSCT Perfo~ti'o:ns' summary 4778-7357 3733-3721 WS ,WS 2570 50 6122/2000 Screens Per[sthru screens 0~i~ L2ifl'Maddrels/V/ilYes.:. ::,..?:: ~:; ':..~i' ~.':~: i":~i: ::..':. !,'.:'~..., :: .:.. :'..; ":.. ". ".i: :: .. ~ ....'.i ..'i..! :.:':... ~/.:: i:' i' ..? i?. i::.' !'.:. ::... '::.: :::' .i: :...:i: '~.: :;':':' .:.:":::....:.". ::: stI MD I TVD I Man I Man I V Mfr I V Type I V OD I Latchl Port I TRO I Date I Vlv Mfr Type Run I, ov I .o Io. ,1 o 1. w/no check - JEWELRY Description I D Heat Trace Cable to 3023' 0.000 ESP PUMP reset 1/8/02 W/4.5" SLIPSTOP & PACKOFF @4008' reset 0.000 3/25/2002 0.000 Centralift Slotted Nipple Centralift Seal Section GST3 0.000 Centralift 9:1 Series 525 Gearbox 0,000 Centralift PCESP Motor 57 HP 1315/26 0,000 Centralift Centralizer w/Baker Sentry Gauge at 4128' Baker SC-IR Packer Baker CMD Sliding Sleeve 0.000 4.000 3,437 Date I Note 3/512001 I NOTE: IThis is a West Sak multilateral well. This schematic rePresents the 'B' sand lower lateral. ISee the 1D-102L1 schematic for the 'D° sand upper lateral. ConocoPhillips Alaska, Inc. CORROSION INSPECTION RESULTS West Sak Well Well 1D-102 (PTD 2000760) March 3, 2003 As of April 4, 2002, gas lift was initiated in the West Sak well, 1D-102 oil producer. Gas lift was hard lined from Kuparuk oil producer, 1D-12, and injected down the subj~ect well's production tubing string at approximately 900 PSIG and a rate of 400 ~yICFD.~ Wellbore fluid production is currently up the inner annulus at rates of 500-700 BOPD, and returned to the conventional, surf),ce flow line via a 2" annular flow line. Surface production flowing pressure is 300-350 PSIG: The following are corrosion report summaries: 12/05/02: On 01/29/03 we completed our follow-up inspection on the drillsite 1D-102 riser and flowline. This inspection was requested over concerns of possible erosion to the impingement areas of the riser and flowline (3"-PC-ID111-F4.4) due to production of this well through the annulus. The results are as follows:/. / Action Items: None Damage Summary: No changes were noted from our previous inspection performed on 12/05/02. ~'~' Ultrasonic inspection was performed on the 2 elbows located at the wellhead on the 3" production line. Radiographic inspection was performed on the divert tee to the test and production headers as well as the lower elbows to the headers. Please refer to the attached corrosion spreadsheet for inspection summary on 1 D-102. Future Inspection Plans: We will re-inspect these locations again on a quarterly basis (4/29/03). 1D-102 Special Inspection Request Log DS1 D 1 D-102 - Annulus flowback inspection - flow is still through the flowline - Inspect once every 2 weeks for 2 months - if no damage noted then inspect monthly B, I, N - (B - baseline inspection, I - Increase in % wall loss, N - No change from previous inspection) # of Worst Date of Inspection Inspection B, I, N Case Wall Damage Locations Loss % Grade Comments 04/04/02 8 B 0% A Base line Inspection RT/UT 04/05/02 2 N 0% A No Changes "~ 04/18/02 6 N 0% A No Changes 05/04/02 6 N 0% A No Changes 05/19/02 0 0 0% n/a No RT or UT inspection due to Drilling Rig 06/19/02 2 N 0% A No RT inspection due to Drilling Rig RT follow-up insp once drilling rig moved off. 06/24/02 6 N 0% A No changes noted 07/20/02 6 N 0% A No Changes 08/19/02 6 N 0% A No Changes 09/20/02 6 N 0% A No Changes // 10/19/02 6 N 0% A No Changes 11/20/02 6 N 0% A No Changes 12/05/02 6 N 0% A No Changes 01/29/03 6 N 0% A No Chanties West S~k Well 1 D-102 Monthly Inspection Subject: West Sak Well 1D-102 Monthly Inspection Date: Wed, 23 Oct 2002 16:49:55 -0800 From: "NSK Problem Well Supv" <n1617@ppco.com> To: tom_maunder@admin.state.ak, us Tom: Attached is a corrosion inspection for West Sak well 1D-102. The inspection shows no damage indicated. Please call if you have questions. Jerry Dethlefs ConocoPhillips Problem Well Supervisor ..... Forwarded by NSK Problem Well Supv/PPCO on 10/23/2002 04:47 PM ..... Jason A Brink 10/23/2002 09:43 AM To: NSK Problem Well Supv/PPCO@Phillips cc: Subject: 1D-102 Monthly Inspection Jason A. Brink Production Engineer Office:907-659-7061 Jabrink@ppco.com ..... Forwarded by Jason A Brink/PPCO on 10/23/2002 09:43 AM ..... NSK Corr DS Coord 10/20/2002 10:37 AM To: CPF1 Prod Supv/PPCO@Phillips cc: NSK Corr Insp Piping/PPCO@Phillips, NSK Corr Vessel Insp/PPCO@Phillips, NSK DS Fac Engr/PPCO@Phillips, NSK Full Field Prod Engr/PPCO@Phillips, CPF1 DS Lead Techs/PPCO@Phillips, NSK Engr&Corr Supv/PPCO@Phillips Subject: 1D-102 Monthly Inspection Carey/Warren, On 10/19/02 we completed our Ultrasonic and Radiographic inspection on well 1D-102. This inspection was originally requested by Ryan Dunn over concerns of erosion to the impingement areas of the line (elbows & tie-in tee) due to production of this well through the annulus. The results are as follows: Action Items: None Damage Summary: No changes were noted from our previous inspection performed on 9/20/02, Ultrasonic inspection was performed on the 2 1 of 2 $CANNEF tO 5 2002 10/24/2002 7:27 AM .West S{k Well 1 D-102 Monthly Inspection elbows located at the wellhead on the 3" production line (3" -PC-1 D111-F4.4). Radiographic inspection was performed on the divert tee to the test and production headers as well as the lower elbows to the headers. Please refer to the attached corrosion spreadsheet for inspection summary on 1 D-102. Future Inspection Plans: Our inspections will continue to be performed on a monthly basis per CPF-1 Supv email on 3/22/02 while the well is in production or until notified by operations. All UT/RT data is on file with corrosion and is available for your viewing. If you have any questions contact Chuck/George at ext. 7209 or Al Dahlquist at ext 7773. (See attached file: 1 D-102 Insp Log.xls) Thank you, George Foley/Chuck Froiland DS Inspection Coordinators NSK 39 n1016@ppco.com Office: (907) 659-7209 ~ 1 D-102 !nsp Lo..q.xls Name: 1D-102 Insp Log.xls Type: EXCEL File (application/msexcel) Encoding: base64 2 of 2 SCANNE NOV 0 5 2802 10/24/2002 7:27 AM ID-102 Special Inspection Request Log DS1 D 1D-102 - Annulus flowback inspection - flow is still through the flowline - Inspect once every 2 weeks for 2 months - if no damage noted then inspect monthly B, I, N - (B - baseline inspection, I - Increase in % wall loss, N - No change from previous inspection) # of Worst Date of Inspection B, I, N Case Wall Damage Comments Inspection Locations Loss % Grade 04/04/02 8 B 0% A 04~05~02 2 N 0% A 04/18/02 6 N 0% A 05/04/02 6 N 0% A 05/19~02 0 0 0% n/a 06/19~02 2 N 0% A 06/24/02 6 N 0% A 07/20102 6 N 0% A 08/19/02 6 N 0% A 09/20102 6 N 0% A 10/19/02 6 N 0% A Base line Inspection RT/UT No Changes No Changes No Changes No RT or UT inspection due to Drilling Rig No RT inspection due to Drilling Rig RT follow-up insp once drilling rig moved off. No changes noted No Changes No Changes No Changes No Changes STATE OF ALASKA /,,,,.~,,e /o/~/o ~- ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _X Perforate _ Other _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 STATE OF ALASKA 179' FSL, 595' FEL, SEC. 14, T11N, R10E, UM At top of productive interval 1785' FNL, 823' FWL, SEC. 24, T11N, R10E, UM At effective depth 1070' FSL, 914' FWL, SEC. 24, T11N, R10E, UM At total depth 4206' FNL, 4364' FEL, Sec. 24, T11N, R10E, UM 5. Type of Well: Development Exploratory __ Stratigraphic __ Service__ (asp's 560491, 5959844) (asp's 562038, 5955470) 6. Datum elevation (DF or KB feet) RKB 101 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1 D-102 9. Permitnumber/approvalnumber 200-075 10. APInumber 50-029-22960 11. Field / Pool West Sak Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size CONDUCTOR 110' 13-3/8" SURF CASING 4074' 7-5/8" SURF CASING 754' 7" LINER 2579' 4 7378 3721 7357 3720 feet Plugs (measured) feet feet Junk (measured) feet Cemented 7 yds HE 520 sx AS IIIL, 410 sx Class G see above 111 sx Class G Measured Depth 110' 4175' 4929' 4778' True vertical Depth 110' 3439' 3752' 3721' Perforation depth: measured true vertical Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) No perfs - Pre pack screens in horizontal laterals 4-1/2", 12.6#, L-80 Tbg @ 4129' MD. BAKER SC-IR PACKER @ 4778' MD. ECEIVED SEP o0" 2002 0il & ~as Cons. CoIilIIll~n Anchorage 13. Attachments Description summary of proposal _X Detailed operations program __ BOP sketch _ 15. Status of well classification as: 14. Estimated date for commencing operation October 1,2002 16. If proposal was verbally approved Name of approver Date approved Oil _X Gas __ Suspended _ Service 17. I hereby certify that the foregoing is true an~rrect to the best of my knowledge. SignedJerald ~"¢"¢'1~/ C v~Title: Problem well supervisor C/Dethlefsl~. FOR COMMISSION USE ONLY Questions? Call Jerry Dethlefs 659-7224 Date ~'.~~,~,,~-- Conditions of approval: Notify Commission so representative may witness I Approval no. Plug integrity_ BOP Test__ Location clearance -- I Mechanical Integrity Test_ Subsequent form required 10- , i~.~ ~x( ORIGINAL SIGNE[~¢~'''-' ~'I~° r~-~. ~¢ SJz~.~ ~ ,,~-. , Approved by order of the Commission D Taylor Seamounf Commissioner Date /~- SCANNED NOV 0 5 2002. Form 10-403 Rev 06/15/88 · Please return to: NSK Problem Well Supervisor, NSK-69 SUBMIT IN TRIPLICATE Phillips Alaska, Inc. Kuparuk Well 1D-102 (PTD 2000760) SUNDRY NOTICE 10-403 VARIANCE REQUEST 9/27/02 The purpose of this Sundry Notice is for approval to extend the length of Sundry #302-101 for a temporary 6-month period. West Sak well 1D-102 is an ESP completion that operates under Sundry (#302-101) approval to produce with gaslift down the tubing after the ESP failed. The original Sundry was approved for 6 months, which expires on 9/30/02. A baseline inspection was done on 4/4/02 with subsequent weekly inspections showing no erosion(. 'The latest production test on 9/19/02 recorded 523 bopd, 254 bwpd with 860 mscf of lift gas. The current sundry was approved on 3/27/02, which allowed lift gas to be injected down the /' tubing and production up the annulus. ConocoPhillips is asking for an extension through the first quarter of 2003, during which a workover ~s planned. ConocoPhillips proposes to maintain an inspection schedule that is identical to the original Sundry request. The proposed inspection schedule is: · If the well ceases continuous production, an ultrasonic inspection will be performed one day after stable production is re-established; × · Subsequent inspections will occur on bi-weekly basis; / · If no erosion is noted after two months, as currently anticipated, inspection frequency will continue on a monthly basis for the duration of the requested six-month period, j ConocoPhillips proposes that the AOGCC approve the above variance request for six months from the approval date. If a workover is not completed within that time period, the AOGCC will be contacted to review the status and discuss a plan forward. Attached is a wellbore diagram of the well. NOV 0 5 2002 West Sak 1D-102 Extension Subject: West Sakt D-102 Extension Date: Sat, 28 Sep 2002 16:08:22 -0800 From: "NSK Problem Well Supv" <n 1617@ppco.com > To: tom_maunder@admin.state.ak.us CC: "NSK Problem Well Supv" <n1617@ppco.com> Tom: i have placed in the mail a Sundry 10-403 for approval to extend temporary gaslift on West Sak well 1D-102. Attached is the request for your review. You should get the originals in a couple days. Please call if you have any questions. Jerry Dethlefs(See attached file: 1 D-102 Discussion Renew 09-28-02.doc) ConocoPhillips Problem Well Supervisor D1D-102 Discussion Renew 09-28-02.doc Name: 1D-102 Discussion Renew 09-28-02.doc Type: WINWORD File (application/msword) Encoding: base64 1 of 1 SCANNED IOV 0 5 2002. 9/30/2002 8:56 AM West Sak 1D-102 Monthly Inspection Subject: West Sak 1D-102 Monthly Inspection Date: Sat, 28 Sep 2002 16:50:43 -0800 From: "NSK Problem Well Supv" <n1617@ppco.com> To: tom_maunder@admin.state.ak.us Tom: Regarding the extension request I made for West Sak well 1D-102, the following email concerns the flowline inspection. I did not include this in the package I sent you. Please call if you have any questions. Jerry Dethlefs ConocoPhillips Problem Well Supervisor ..... Forwarded by NSK Problem Well Supv/PPCO on 0912812002 04:50 PM .... NSK Full Field Prod Engr 09/28/2002 04:39 PM To: NSK Problem Well Supv/PPCO@Phillips CC: Subject: DS1D 1D-102 Monthly Inspection ..... Forwarded by NSK Full Field Prod Engr/PPCO on 09/28/2002 04:38 PM NSK Corr DS Coord 09/21/2002 12:18 PM To: CPF1 Prod Supv/PPCO@Phillips cc: CPF1 DS Lead Techs/PPCO@Phillips, NSK Full Field Prod Engr/PPCO@Phillips, NSK DS Fac Engr/PPCO@Phillips, NSK Corr Insp Piping/PPCO@Phillips, CPF1 Prod Engr/PPCO@Phillips Subject: DSID 1D-102 Monthly Inspection Carey/Warren, On 9/20102 we completed our follow-up inspection on the drillsite 1D-102 riser and flowline. This inspection was requested by you over concerns of possible erosion to the impingement areas of the riser and flowline (3"-PC-ID111-F4.4) due to production of this well through the annulus. The results are as follows: Action Items: None Damage Summary: No changes were noted from our previous inspection performed on 8/19/02. Ultrasonic inspection was performed on the 2 elbows located at the wellhead on the 3" production line. Radiographic inspection was performed on the divert tee to the test and production headers as well as the lower elbows to the headers. Please refer to the attached corrosion spreadsheet for inspection summary on 1 D-102. 1 of 2 SC;ANNEI NOV 0 5 2002' 9/30/2002 8:55 AM West Sak 1 D-102 Monthly Inspection Future Inspection Plans: We will re-inspect these elbows again in 1 month (10/20/02) and continue a monthly inspection until notified by CPF-1 operations per your email dated 5121102. (See attached file: 1 D-102 Insp Log.xls) All UT data and f'~m is on file with corrosion and is available for your viewing. If you have any questions contact Chuck/George at ext. 7209 or Al Dahlquist at ext 7773. Thank you, George Foley/Chuck Froiland DS Inspection Coordinators NSK 39 n1016@ppco.com Office: (907) 659-7209 ~1D-102 Insp Log~xls Name: 1 D-102 Insp Log.xls Type: EXCEL File (application/m sexcel) Encoding: base64 2 of 2 9/30/2002 8:55 AN 2007.. D-102 Special Inspection Request Log DSID 1D-102 Annulus flowback inspection - flow is still through the flowline Inspect once every 2 weeks for 2 months - if no damage noted then inspect monthly B, I, N - (B - baseline inspection, I - Increase in % wall loss, N - No change from previous inspectio # of Worst Date of Inspection B, I, N Case Wall Damage Inspection Locations Loss % Grade 04/04/02 8 B 0% A 04105102 2 N 0% A 04/18102 6 N 0% A 05/04/02 6 N 0% A 05119102 0 0 0% n/a 06/19102 2 N 0% A 06/24/02 6 N 0% A 07/20/02 6 N 0% A 08/19/02 6 N 0% A 09120/02 6 N 0% A Comments Base line Inspection RT/UT No Changes No Changes No Changes No RT or UT inspection due to Drilling Rig No RT inspection due to Drilling Rig RT follow-up insp once drilling rig moved off. No changes noted No Changes No Changes No Changes .SCANNED NOV 0 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 28, 2002 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a 10-403 Sundry Notice variance request for ConocoPhillips Alaska, Inc., West Sak well 1D-102. The variance request is for a 6-month extension to temporarily use gaslift to produce the ESP-completed well. Also attached is a discussion and well schematic. Please call Pete Nezaticky or me at 907-659-7224, or Ryan Dunn / Jason Brink (PE's) at 659-7061 if you have any questions. Sincerely, ConocoPhillips Problem Well Supervisor Attachments NOV 0 5 2002 RECEIVED SEP 30" 2002 0B& Sas gons. ~~ Anchorage DATA SUBMITTAL COMPLIANCE REPORT 9~9~2002 Permit to Drill 2000750 Well Name/No. KUPARUK RIV U WSAK'ID-102 Operator PHILLIPS ALASKA INC. APl No. 50-029-22960-00-00 MD 7378 TVD 3719 Completion Dat 7/12/2000 J' Completion Statu 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log N._g_o Sample N._9o Directional Survey N.~o DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type _~ Fmt Name Log Log Scale Media Run No Interval Start Stop (data taken from Logs Portion of Master Well Data Maint) OH I Dataset CH Received Number Comments D ~ 9803 SRVY RPT SRVY RPT SRVY RPT SRVY RPT SCMT 9597 98O0 9802 b(,W~,,.,~,~ DGR/EWR-TVD FBHP/TEMP 2/5 5 1-8 FINAL 1&5 1-6 FINAL FINAL 76 76 76 76 5181 0 6143 6527 4119 100 18 7328 5311 6725 6411 6454 5354 6767 7378 4646 3753 4030 Open 9/8/2000 09803 c,,'76-7328 Open 8/30/2000 09597 -~-5311 Open 9/5/2000 09800 ~"~-6725 Open 9/5/2000 09802 ~7'~-6411 OH 9/8/2000 9803~//SPERRY MPT/GPJEWR OH 7/18/2000 SPERRY 5181.38-6454. PB2-~ OH 7/18/2000 SPERRY 0-5354 PB1 ~ OH 7/18/2000 SPERRY 6143.54-6767. PB3 ~- SPERRY 6527.44-7378 OH 7/18/2000 CH 8/18/2000 OH 8/30/2000 OH 9/5/2000 OH 9/5~2000 OH 10/19/2000 CH 6/15/2001 BL(C) 4119-4646 9597 ~S'PERRY MPT/GPJEWR4 PB1 9800 ~'~ERRY MPT/GPJEWR4 PB3 9802~"~ERRY MPT/GR/EWR4 PB2 100-3753 6/1/00 THRU 18-4030 BL, Sepia Well Cores/Samples Information: Name Interval Start Stop Sent Received Dataset Number Comments Permit to Drill 2000750 MD 7378 TVD DATA SUBMITTAL COMPLIANCE REPORT 9~9~2002 Well Name/No. KUPARUK RIV U WSAK 1D-102 Operator PHILLIPS ALASKA INC. 3719 Completion Dar 7/12/2000 Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-22960-00-00 UIC N ADDITIONAL INFORMATION Well Cored? Y/N~ Chips Received? ~ Analysis ~ Recc. ived? Daily History Received? ~ N Formation Tops ~/N Comments: Compliance Reviewed By: Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. IName of Operator I 5. Type of Well: 6. Datum elevation (DF or KB feet) Alaska, Inc. ! Development__X RKB 101 feet Exploratory ~ 7. Unit or Property name Stratigmphic ~ Service~ 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 5098' FNL, 595' FEL, Sec. 14, T11N, R10E, UM At top of productive interval (asp's 560491, 5959844) At effective depth At total depth 4206' FNL, 4364' FEL, Sec. 24, T11N, R10E, UM (asp's 562038, 5955470) 12. Present well condition summary Total depth: measured trUe vertical 7378 feet Plugs (measured) 3721 feet Kuparuk River Unit 8. Well number 1D-102 9. Pern~it number / appro'tml number 2O0-075 / 10. APl number 50-029-22960 11. Field / Pool West Sak Oil Pool Effective depth: measured feet Junk (measured) tree vertical feet C:asing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 110' 13-3/8" 7 cu yds High Early 110' 110' SURF CASING 4074' 7-5/8" 52O sx AS mL & 4~0 sx Cross G 4175' 3439' SURF CASING 754' 7" included above 4929' 3752' C:SG WINDOW 15' 5-1/2" 4383' 3568' CSG WINDOW 2579' 4-1/2" ~ ~ ~ sx C~ass G 7357' 3721' Perforation depth: measured ~~i~!~: .. ~. ~ ..'..~.~~~: ~ ~ : ~::::~:: :.~: ::::~: ~:.=:.~=~ ........... ~..~ ............. , .............. :=::~=~,~. ::::~=, ............ Packers & SSSV 13. S~ulation or cement squeeze su~ma~ Intew~s treat~ (measure) Trea~ent d~cripfion including volumes us~ and final pressure 14. Prior to well Operation Subsequent to operation 15. Attachments. Copies of Logs and Surveys run ~ Daily Report of Well Operations __X 17. I hereby certify that the foregoing is tree and correct to the best of my knowledge. Signed Title Production Engineering Supervisor Jeff A. Spencer Representative Daily Avemqe Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casin.q Pressure Tubinff Pressure Ouestio~? Call Jeff Spencer 659-7226 Pr~, red b~, Robert Christensen 65.~-7535 Form 10-404 Rev 06/15/88 o SUBMIT IN DUPLICATE 1D-102 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 4/4/20021Commenced Gaslifted Oil Production of faulty ESP completed well. PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 March 17, 2002 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a 10-403 Sundry Notice variance request for Phillips Alaska, Inc., West Sak well 1D-102. The variance request is for approval to temporarily use gaslift to produce the ESP-completed well. Also attached is a discussion and well schematic. Please call Pete Nezaticky or me at 907-659-7224, or Ryan Dunn / Jason Brink (PE's) at 659-7061 if you have any questions. Sincerely, Jerry Dethlefs Phillips Problem Well Supervisor Attachments ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request Abandon_ ~ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _'~': Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _X Pedorate _ Other_ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 STATE OF ALASKA 179' FSL, 595' FEL, SEC. 14, T11N, R10E, UM At top of productive interval 1785' FNL, 823' FWL, SEC. 24, T11 N, R10E, UM At effective depth 1070' FSL, 914' FWL, SEC. 24, T11 N, R10E, UM At total depth 4206' FNL, 4364' FEL, Sec. 24, T11 N, R10E, UM 5. Type of Well: Development __X Exploratory _ Stratigraphic __ Service__ (asp's 560491, 5959844) (asp's 562038, 5955470) 6. Datum elevation (DF or KB feet) RKB 101 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1D-102 9. Permitnumber/approvalnumber 200-075 10. APInumber 50-029-22960 11. Field / Pool West Sak Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size CONDUCTOR 110' 13-3/8" SURF CASING 4074' 7-5/8" SURF CASING 754' 7" LINER 2579' 4 7378 3721 7357 3720 feet Plugs (measured) feet feet Junk (measured) feet Cemented 7 yd$ HE 520 sxAS IIIL, 410 sx Class G see above 111 sx Class G Measured Depth 110' 4175' 4929' 4778' True verticalDepth 110' 3439' 3752' 3721' Perforation depth: measured true vertical Tubing (size, grade, and measured depth No perfs - Pre pack screens in horizontal laterals 4-1/2", 12.6#, L-80 Tbg @ 4129' MD. Packers & SSSV (type & measured depth) BAKER SC-1R PACKER @ 4778' MD. 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch__ 14. Estimated date for commencing operation March 25, 2002 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby certi~ that the foregoing is true and correct to the best of my knowledge. Signed ~ ~ ~ Title: Problem Well Supervisor Jera~C. Dethlefs Questions? Call Jerry Dethlefs 659-7224 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness I Approval no. Plug integrity __ BOP Test _ Location clearance __ I ~, ~.~O~ _ Mechanical Integrity Test_ Subsequer~form required lO- Approved by order of the Commission 01'i~i118~ Sl~lt0d By Commissioner Date Cam~. y 0~echsli Please return to: NSK Problem Well Supervisor, NSK-69 Form 10-403 Rev 06/15/88' SUBMIT IN TRIPLICATE Phillips Alaska, Inc. West Sak Well 1D-102 (PTD 2000760) SUNDRY NOTICE 10-403 VARIANCE REQUEST 3/16/02 The purpose of this Sundry Notice is for approval to temporarily gaslift West Sak producer 1 D- 102 that is completed as an ESP (electric submersible pump) well. The ESP has failed and a workover is required to pull and replace the ESP, and is expected to occur during 2002. The well makes approximately 750 bopd via ESP, a majority of which may be possible to produce on gaslift. Due to the configuration of the tubing production is to be up the annulus. Gaslift gas will be piped on the surface to flow down the tubing, exiting into the annulus via the existing mandrel. A 3/16" orifice valve will be installed in the mandrel for gaslift with the check valve removed allowing reverse-direction flow. The maximum anticipated gaslift rate will be 600-800 mcfd. The bottom of the tubing string will be sealed off with a modified packoff to seal the ESP pump intake. Since there is no packer, flow will move past the pump and up the annulus. Hydraulics are uncertain since the annular area is so large and the oil is viscous, but model predictions are for 500-700 BOPD. The basic gaslift and production facilities layout for 1 D-102 (under construction) will be identical to the current 1D-110A layout. Phillips has presently started fabrication and will install a new 3# annulus flowline on 1D-102 to replace the existing 2~' flowline prior to production. The above installation will decrease the fluid velocity and will minimize the elbows and impingement points to minimize erosion risk. (The same design is being implemented for 1 D-110A as a pro- active measure, even though there is no indication of active erosion in the 2' line on well 1D- 110A at the present time.) Velocity calculations have been done with maximum anticipated flow rates of 1000 BLPD and Total GLR of 600 scf/stb up the annulus and through the 3t' annular flow line. Production pressure is approximately 230 PSIG. The maximum velocity up the annulus will be 6 ft/s and velocity through the 3it, schedule 160, grade 6, A33 line will be 18 ft/s. There have been twelve (12) solids shakeouts on well 1D-102 since September 2001 and they range from 0.0% to 0.15% with a combined average of 0.04% solids by volume. Phillips intends to take production shakeouts both initially and periodically to monitor future performance. Below is a table of recent well test information. Well 1D-102 Oil Producer (Production rates with the ESP in operation) Formation Formation Choke Position FTP WHT Oil Rate Water Rate Gas Form Rate GOR GLR Esp Speed Well Name (% Open) Date Test (psig) (De[t F) (BOPD) (BWPD) Wc Pct {%) (MCFD) (SCF/STB/ (SCF/STB) (Hz) 1 D-102 100 7-Dec-01 277 70 743 131 15 82 11' 94 54 1 D-102 100 27-Nov-01 270 71 747 109 13 69 92 80 51 1D-102 100 14-Nov-01 257 70 739 114 13 84 113 98 51 1D-102 100 29-Oct-01 259 69 641 104 14 74 115 98 44 1 D-102 100 28-Oct-01 257 69 607! 97 14 61 100 86 42 1 D-102 100 20-Oct-01 268 69 610 95 13 62 102 88 42 1D-102 100 10-Oct-01 219 69 365 78 18 45 122 100 27 1 D-102 100 3-Oct-01 257 68 613 64 9 74 121 109 41 1D-102 100 18-Sep-01 217 68 575 62 10 72 12.~ 113 38 1D-102 100 11-Sep-01 219 68 576 57 9 73 126 114 38 Future Inspection Plans: A baseline ultrasonic inspection will be obtained prior to production. Recurring inspection schedule will be as follows: Inspect after 1 day of production or gas lift kickoff and bi-weekly once stable production is established. Inspections will be decreased to monthly intervals after two-months of inspections providing degradation is not detected. As an extra safety feature, a valve handle to the IA AP1 valve has been extended outside the wellhouse and a line from the WI header is connected to the gas injection line for killing the well in case of an emergency. Phillips proposes that the AOGCC approve this request for a time period not to exceed 6 months from the approval date. If a workover is not completed within that time period, the AOGCC will be contacted to review the status and discuss a plan forward. Attached is a wellbore diagram of down-hole information. PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY c( KRU ID-102 (0-110, OD:13.375, Wt:68.00) Gas Lift MandrelNalve 1 (3984-3985, OD:5.985) PUMP (4058-4O59, OD:4.500) NIP (4079.4080, OD:4.500) SEAL (4085-4O86, OD:5.130) GEARBOX (4099-4100, OD:5.620) TUBING (0-4129, OD:4.500, ID:3.958) APl: 500292296000 Well Type: PROD SSSVType: None OdD Completion: 6~22~2000 Annular Fluid: Last W/O: Reference Log: Ref Log Date: Last Tag: 3997 TD: 7378 ftKB Last Tag Date: 12/11/2001 Max Hole Angle: 94 deg @ 6304 ca~i~ St~ihD~E :: ::: Description size Top Bottom CONDUCTOR 13.375 0 110 SURF CASING 7.625 0 4175 SURF CASING 7.000 4175 4929 CSG WINDOW 6.000 4368 4383 DUAL SCREEN LNR 4.500 4778 7357 TVD 110 Angle @ TS:l deg @ Angle @ TD: 189 deg @ 7378 Rev Reason: Reset Pump, slipstop, packoff by ImO Last Update: 1/18/2002 3439 3752 3568 3721 Size Top Bottom TVD 4.500 0 4129 3410 Gas: Eiff: Mand reis/Valves Wt GradeI Thread 68.00 L-80 WELDED 29.70 L-80 BTC-MOD 26.00 L-80 BTC-MOD 0.00 L-80 to 1D-102L1 12.60 L-80 HSLHT Wt Grade 12.60 L-80 Thread NSCT TROi Date Vlv i Run Cmnt 0 i 12/9/2001 CABLE Heat Trace Cable to 3023' Description PUMP NIP ESP PUMP reset 1/8/02 W/SLIPSTOP & PACKOFF (~4008' reset 1/10/02 Centralift Slotted Nipple Centralift Seal Section GST3 ID 0.000 0.000 0.000 0.000 SEAL GEARBOX Centralift 9:1 Series 525 Gearbox 0.000 MOTOR Centralift PCESP Motor 57 HP 1315/26 0.000 0.000 Centralizer Centralift Centralizer w/Baker Sentry Gauge at 4128' PKR ;r SC-1R Packer Baker CMD Sliding Sleeve Date IN0te 3/5/2001 NOTE: This is a West Sak multilateral well. This schematic represents the 'B' sand lower lateral. See the 1D-102L1 schematic for the 'D' sand upper lateral. 4.000 3.437 Centralizer (4122-4129, OD:6.250) PKR (4778-4779, OD:6.000 SLEEVE (4823-4824, OD:5.500) SURF CASING (4175-4929, OD:7.000, Wt:26.00) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _X ESP Jet Pump 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 5. Type of Well: Development _X Exploratory __ Stratigraphic __ Service__ 4. Location of well at surface 5098' FNL, 595' FEL, Sec. 14, T11N, R10E, UM At top of productive interval At effective depth At total depth 4206' FNL, 4364' FEL, Sec. 24, T11 N, R10E, UM (asp's 560491, 5959844) (asp's 562038, 5955470) 6. Datum elevation (DF or KB feet) RKB 101 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1 D-102 9. Permit number / approval number 200-075 / 10. APl number 50-029-22960 11. Field / Pool West Sak Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size CONDUCTOR 110' 13-3/8" SURF CASING 4074' 7-5/8" SURF CASING 754' 7" CSG WINDOW 15' 6" CSG WINDOW 2579' 4-1/2" 7378 feet Plugs (measured) 3721 feet 7357 feet Junk (measured) 3720 feet Cemented 7 cu yds High Early 520 sxAS IIIL, 410 sx Class G included above 111 sx Class G Measured Depth 110' 4175' 4929' 4383' 7357' True vertical Depth 110' 3439' 3752' 3568' 3721' Perforation depth: measured No perfs true vertical No perfs Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80 Tbg @ 4129' MD. Packers & SSSV (type & measured depth) BAKER SC-1R PACKER @ 4778' MD. No SSSV RECEIVED JUN 2 0 2001 Alaska Oil & Gas Cons. Commission Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl N/A Representative Daily Average Production or Injection Data Gas-Md Water-Bbl 601 398 1 Casing Pressure Tubing Pressure 312 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X Gas __ Suspended Service _Water Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Michae/ Mooney Title Staff Engineer Form 10-404 Rev 06/15/88 · ORIGINAL Questions? Call Mike Mooney 263-4574 Prepared by'Sharon A//sup-Drake 263-4612 SUBMIT IN DUPLICATE Date Comment 1D-102 Event History 07/11/00 07/21/00 SET ESP PUMP, PACK-OFF & SLIP STOP. TEST PACK-OFF TO 1000#. [ESP WORK] SET 1" SOV @ 3984' RKB. COMPLETE [GLV] Page 1 of 1 6/15/01 PHILLIPS Alas ka, ol n ; A Subsidiary of PHI/lIPS PETROLEUM Post Office Box 100360 Anchorage, Alaska 99510-0360 M. Mooney Phone (907) 263-4574 Fax: (907) 265-6224 June 18,2001 Commissioner Camille Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations 1D-102 (200-075) Dear Ms. Commissioner: Phillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the ESP operations on the KRU well 1D-102. If there are any questions, please contact me at 263-4574. Sincerely, M. Mooney Staff Engineer Phillips Drilling MM/skad RECEIVED JUN 2, 0 ZOO1 Alaska Oil & Gas Cons. Commission Anchorage pm - -y-sun WEI~J~:LOG-~RANS~~ To: State of Alaska Attn.: Loft Taylor 3oo+ -Dr. Anchorage, Alaska 99501 October 19, 2000 The technical data listed below is being submitted herewith. Please address any problems or concerns torsion of.' Jim:~in;Sperry4u~:~~:~S~ado-Way,:gG; Anehoragc,: AK- 9-9518 1~102: 2" x 5" TVD Resistivity & Gamma Ray Logs: 50-029-2-2960-0¢- - l:Blueline l:Folde4 Sepia 1 Blueline t-.Folded-Sepia. RECEI 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 a Halliburton company To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 September 5, 2000 MWD Formation Evaluation Logs 1D-102, AK-MM-00058 1 LDWG formatted Disc with verification listing. API~: 50-029-22960-00 PLEASE ACKNOWLEDGE RECEIFF BY- SIGNI~,G AND-RE~G-A-COPY. OF-.nn:~s'~' ~AL · ' . t~]g~.~O~-_'I~, Spen'y-Sun Drilling Service-- Attrr._ _~_,v__ Gal~ 5631 Silverado Way, Suite G. Anchorage,_ Alaska 99518 RECEIVED Date: SEP 0 8 Alaska 0il & Gas Cons. Commission Anchorage 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 a Halliburton company 0 IR I LLI I~11~ WELL LOG TRANSM1TrAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs September 5, 2000 1D- 102 PB3, AK-MM-00058 1 LDWG formatted Disc with verification listing. APl#: 50-029-22960-72 PLEASE ACKNO~GE RECEll~ BY SIGNtNG~.~~G A COPY OF TilE TRA---------------------------------NSMII'YAL -I~irl~R TO: ~ .ATTENTION OF: Sperry-Sun Drilling.Service AUra: Jun Galvin 5631' Silverado Way, Suite G. Anchorage, Alaska 99518 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 a Halliburton company WELL LOG TRANSMI'ITAL To-' State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 1D-102 PB2, August 31, 2000 -MM-00058 1 LDWG formatted Disc with verification listing. API#: 50-029-22960-71 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING. AND RETURNING A COPY OF THE TRANSMITTAL UTTER TO ~ ATTENTION OF: Sperry-Sun Drilling Service Atto: Jim Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 ,.% Signed 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax' 907-273-3535 a Halliburton company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil I~l Gas F] Suspended BI Abandoned [~] Service r'] 2. Name of Operator ~~; 7. Permit Number Phillips Alaska, Inc.~"""~'"-~ 200-075 / 3. Address _.~~ 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360~ ~ 50-029-22960-00 4. Location of well at surface ~'::.:';::7'r::- :: -~ ~~ 9. Unit or Lease Name . &: Kuparuk River Unit 179' FSL, 595' FEL, Sec. 14, T11 N, R10E, UM (ASP:560490.6, 5959844) ~ j&; :.. i At Top Producing Interval ~ .... ~/~j~¢ 10. Well Number '-- ' 1D-102 1785' FNL, 823' FWL, Sec. 24, T11N, R10E, UM (ASP:561924.6, 5957893)~' ~R-' ~'~:~;i9 ~' At Total Depth ~___~ ........ ~ 11. Field and Pool 1070' FSL, 914' FWL, Sec. 24, T11N, R10E, UM (ASP: 562038, 5955470) Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. West Sak Oil Pool RKB 30 feet~ ADL 25650 ALK 468 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. ~15. Water Depth, if o~hore 16. No. of Completions June 1,2000 June 13, 2000 July 12, 2000~ ~A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Su~ey ~20. Depth where SSSV set 21. Thickness of Permafrost 7378' MD/3719'TVD 7357' MD/3720'TVD YES ~ No ~~ ~A feetMD 1642' 22. Type Electric or Other Logs Run G~ReCPWD 23. CASING, LINER AND CEMENTING RECORD S~ING DEPTH MD CASING SIZE ~. PER ~. GRADE TOP BOSOM HOLE SIZE CEME~ING RECORD AMOUNT PULLED 13.375" 68¢ L-80 Sudace 110' 20" 7 cu yds High Early 7.625" x 29.7¢ L-80 Sudace 4175' 9.875" 520 sx AS IIIL, 410 sx Class G 7" 26¢ L-80 4175' 4930' 9.875" see above 4" 9.5¢ L-80 4778' 7357' 6" 111 sx Class G 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5" 4129' 4778' No peals - Pre-pack screens in horizontal laterals 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED ~A 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas li~, etc.) July 22, 2000 Flowing Date of Test Hours Tested Production for OIL-EEL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO 8/4/2000 6 h rs Test Period > 250 49 0 100~ 194 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) press 234 psi not available 24-Hour Rate > 1004 195 1 not available 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dibs and ~ressence of oil, gas or water. Submit core chips. WA Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. NAME Top West Sak Sand West Sak A3 Base West Sak Sand GEOLOGIC MARKERS MEAS. DEPTH 4601' 4942' 4942' TRUE VERT. DEPTH 3679' 3753' 3753' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Mark Chambers 265-1319 Randy Thomas Title Kuparuk Drilling Team Leader Date INSTRUCTIONS Prepared by Sharon AIIsup-Drake General: This form is designed for submitting a complete and correct well completion report and Icg 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-sku 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 the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. ~'~',, ~'"~7% i~'T" ~,'~: ,¢~' ...... Item 28: If no cores taken, indicate "none". Form 10-407 Date: 08/15/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:iD-102 ML STATE:ALASKA COUNTY: NORTH SLOPE EAST FIELD: WEST SAK SPUD:06/01/00 START COMP: RIG:NORDIC 3 BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-029-22960-00 06/01/00 (D1) MW: 9.4 VISC: 251 PV/YP: 46/76 APIWL: 4.0 TD/TVD: 668/666 ( 668) DRILLING AT 1110' SUPV:DON WESTER & BRIAN NOEL Move from 1D-04 and accept rig at 00:30 hrs. NU diverter system and function test. PJSM, pre-spud meeting. Spud well at 110', drill to 286'. POOH w/hwdp. RIH, drill from 286' to 668' 06/02/00 (D2) MW: 9.1 VISC: 280 PV/YP: 51/68 APIWL: 4.2 TD/TVD: 0/666 ( 0) DRILLING AT 2567' SUPV:DON WESTER & BRIAN NOEL Drill from 668' to 2422' Using 250-300 vis to clean running rock & gravel from hole. 06/03/00 (D3) MW: 9.3 VISC: 252 PV/YP: 47/64 APIWL: 5.0 TD/TVD: 3645/3102 (3645) DRILLING AHEAD AT 4100' SUPV:DON WESTER & BRIAN NOEL Drill from 2422' to 2581' Gravel and rock from uphole continues to run. Pump high vis sweeps to clean hole. Flowline plugged w/mud over bell nipple but contained in cellar. Unplug flowline and clean gravel from possum belly. Drill from 2581' to 2650', flowline trying to plug. Circulate and move pipe while flushing flowline. Control drill from 2650' to 3645' Hole periodically unloading gravel and rock but frequency and volume decreasing. 06/04/00 (D4) MW: 10.0 VISC: 260 PV/YP: 52/59 APIWL: 4.0 TD/TVD: 4805/3733 (1160) TD FOR CASING AT 4942', CELLAR BROACHED AT 5:15 AM WHI SUPV:DON WESTER & BRIAN NOEL Drill from 3645' to 4805' Pump periodic sweeps for hole cleaning and add lubricants for slides. Small amount gravel in sweep returns. 06/05/00 (D5) MW: 10.0 VISC: 260 PV/YP: 52/59 APIWL: 4.0 TD/TVD: 4942/3751 ( 137) TAG CEMENT AT 107', WASH & REAM AT 250' SUPV:DON WESTER & BRIAN NOEL Drill from 4805' to 4942'. CBU and condition hole prior to POOH for hole opener. Cellar broached. Mud filled cellar and containment berm and spilled 5 bbls onto pad. POOH slow, clean up mud. POOH. Tight spots at 170' and 290'. RIH w/mule shoe joint. Lower mule shoe joint to 120', plugged. Pump water. Full returns. Pump 700 sx ASI. WOC. Hold spud meetings. ~i~..~.~'~_,~ ~ '~'~.~.~ ~'~ ~'~ ...... ~-_~:~?i[?l! Date: 08/15/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 06/06/00 (D6) TD/TVD: 4942/3751 ( SUPV:M.C. HEIM MW: 10.0 VISC: 292 PV/YP: 56/67 0) POH TO RUN CSG. APIWL: 4.2 WOC. Modify trip tank outlet line to 6", work on auger. Tag cement ~ 107' Drilling cement from 107' to 230' Pump away, lost returns. Torque ~ 6000#, up ream to 153' & wo water. Switch to mud and attempt to wash down, stalled top drive ~ 168'. Worked pipe to 153' Wash and ream from 200' to 340', circ out cement contaminated mud & heavy gravel, wash from 340' to 429' CBU. POH slow. RIH, ream tight spot ~ 250', RIH, wash & ream from 1610' to 3500' 06/07/00 (D7) MW: 9.6 VISC: 96 PV/YP: 36/34 APIWL: 5.4 TD/TVD: 4942/3751 ( 0) ORIENT WINDOW SUPV:M.C. HEIM RIH, washing and reaming from 3500' to 4942' TD. Circ and condition hole for casing, spot pill and pump dry job. POH. PJSM. Run 7" and 7-5/8" casing, work thru tight spots. 06/08/00 (D8) TD/TVD: 4942/3751 ( SUPV:M.C. HEIM MW: 9.6 VISC: 91 PV/YP: 32/32 0) SLIP & CUT DRLG. LINE. APIWL: 5.6 Reciprocate casing string, attempt to get circ, losing mud while circ going down. Circ, condition mud & hole for wl work, gained lost mud back. RIH w/gyro data. PJSM. Test cement lines. Pump cement. Bump plug. Floats held. ND diverter system. N/U BOPE. 06/09/00 (D9) TD/TVD: 4942/3751 SUPV:M.C. HEIM MW: 9.3 VISC: 43 PV/YP: 14/ 9 0) DISPLACE HOLE TO NEW MUD. APIWL: 8.0 Function test BOPs, set test plug, test BOPE. PJSM. RIH w/4" dp, wash to 4851' Drilling plug, motor not acting right. PJSM. POH, break bit, adjust mud motor to '0' and day down (appears the shaft is broke, can turn by hand). RIH with new mud motor. 06/10/00 (D10) MW: 9.1 VISC: 42 PV/YP: 12/22 TD/TVD: 5190/3748 ( 248) MAKING HOLE ~ 5560' SUPV:M.C. HEIM APIWL: 3.8 RIH to 4853' Break circ, tag ~ 4853'. Drilling FC, cement, shoe & 20' new hole to 4962'. CBU. Perform FIT 11.0#. Drilling and surveys from 4962' to 5354'. Circ and work pipe for sidetrack. Sidetrack & drilling from 5190' to 5200' 06/11/00 (Dll) MW: 9.1 VISC: 43 PV/YP: 11/23 APIWL: 3.8 TD/TVD: 6178/3745 ( 988) MAKING HOLE ~ 6545' SUPV:M.C. HEIM ~ .......~, ~ ....?~ Drilling and surveys from 5200' to 6454'. Circ, , ~f~'-,,~ ~,~ ~ work pipe ........... ~.~,,~,~ .~ ........... ~. · poh for sidetrack ~ 6170' Drilling sidetrack #2 from 6166' to 6178', Date: 08/15/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 06/12/00 (D12) MW: 9.2 VISC: 45 PV/YP: 11/25 APIWL: 3.6 TD/TVD: 6768/3705 ( 590) RUNNING IN HOLE-WENT IN OLD HOLE ~ 5354'-PULLED BACK-O SUPV:M.C. HEIM Drilling and surveys from 6178' to 6768' Sidetrack #2. Pump hi-vis hi wate pill sweep while drilling @ 6646'. POH 1 stand, pump hi-vis hi-wate sweep, circ around, recovered substantial amount of cuttings. POH. 06/13/00 (D13) MW: 9.1 VISC: 44 PV/YP: 12/22 APIWL: 3.8 TD/TVD: 7378/3719 (610) POOH SUPV:DON WESTER, G.R. WHITLOCK RIH w/reaming BHA and 1 std 3.5" dp. RIH to 6530'. Circ and cond mud. Start trench for sidetrack from 6530' to 6561' Drill from 6561' to 7378'. Circ and work pipe. Pump weighted sweep. POOH 9 stands. 06/14/00 (D14) MW: 9.1 VISC: 43 PV/YP: 12/21 APIWL: 3.8 TD/TVD: 7378/3719 ( 0) MIXING VISCOUS PILL SUPV:DON WESTER, G.R. WHITLOCK Work pipe past 3rd sidetrack from 6590' to 6520'. POOH to 5210' Trench from 5210' to 5160' POOH. RIH with hole opener assembly. Wash and ream from 4935' to 7377'. Circ and pump sweeps. RIH. Circ and work pipe. 06/15/00 (D15) MW: 9.1 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7378/3719 ( 0) CIRC AND FILTERING FLUID SUPV:DON WESTER, G.R. WHITLOCK Circ and build hi-vis sweep w/filtered brine. PJSM. Displaced well with brine. Spotted hi-vis pill. POOH slow. RIH w/scraper assembly. 06/16/00 (D16) MW: 9.1 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7378/3719 ( 0) POOH SUPV:DON WESTER, G.R. WHITLOCK Hold safety meeting. Pump caustic flush. Hold safety meeting. Pickle drillpipe with HC1 and reverse out. 06/17/00 (D17) MW: 9.1 VISC: TD/TVD: 7378/3719 ( 0) L/D SCREENS SUPV:DON WESTER, G.R. WHITLOCK 0 PV/YP: 0/ 0 APIWL: 0.0 Filter brine. POOH. Test BOPE to 250/3000 psi. PJSM. RIH w/screens. Safety meeting. RIH with 3.5" hwdp. RIH w/screens on 4" dp. Unable to get past 6760' 06/18/00 (D18) MW: 9.1 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7378/3719 ( 0) RUNNINING RETRIEVABLE BRIDGE PLUG SUPV:DON WESTER, G.R. WHITLOCK Attempt to work deeper than 6760' w/o success. POOH. RIH w/screens. Drop plug and pump down, set packer. Shear ball and circ brine. Spot acidize and displace through screens. Date: 08/15/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 4 06/19/00 (D19) MW: 9.1 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7378/3719 ( 0) RIH W/ WHIPSTOCK MILLS SUPV:DON WESTER, G.R. WHITLOCK POOH to 4672' Circ. RIH w/bridge plug and set at 4555.97' Pump 14' of sand on top of RBP. Circ and wash. POOH. RIH w/RMLS combo tool. Latch ~ 4387'. Shear out. POOH. RIH with whipstock to 4387' 06/20/00 (D20) MW: 9.2 VISC: 44 PV/YP: 12/25 APIWL: 4.2 TD/TVD: 4540/3637 ( 0) DRILLING ~ 4675' SUPV:DINK HEIM, G.R. WHITLOCK -- Set whipstock ~ 4387', survey. POOH. PJSM. Mill window from ~ 4368.5 to 4383.5. Circ sweep and bottoms up. POOH. RIH, slide thru window and make 20' of new hole. Circ and condition mud. Perform FIT to 11.25 ppg EMW. Drill from 4398' to 4540' 06/21/00 (D21) MW: 9.1 VISC: 47 PV/YP: 11/27 APIWL: 4.0 TD/TVD: 5082/3694 (542) TRIP OUT TO REPAIR LINK TILT SUPV:DINK HEIM, G.R. WHITLOCK Drill from 4540' to 5082'. Try to make bit drill, no success. Circ. POOH. M/U new motor. RIH. 06/22/00 (D22) MW: 9.1 VISC: 44 PV/YP: 11/26 APIWL: 3.9 TD/TVD: 5082/3694 ( 0) DRILLING ~ 6885' SUPV:M.C. HEIM, G.R. WHITLOCK RIH. Work through window. Wash 22' to bottom. Drill from 5498' to 6344' 06/23/00 (D23) MW: 9.1 VISC: 46 PV/YP: 12/25 APIWL: 3.9 TD/TVD: 7407/3648 (2325) CIRC PREPARING TO DISPLACE HOLE W/ BRINE SUPV:M.C. HEIM, G.R. WHITLOCK Drill from 6344' to 7397' Circ sweeps until hole clean. Drill from 7397' to 7407' POOH. Test BOPE 250/3000 psi. 06/24/00 (D24) MW: 9.1 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7407/3648 ( 0) POOH W/ HOLEOPENER SUPV:M.C. HEIM, G.R. WHITLOCK RIH w/hole opener BHA. Wash to bottom and circ. Circ hi-vis pill and clean brine. Spot hi-vis pill on bottom with brine. POOH to window. 06/25/00 (D25) MW: 9.1 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7407/3648 ( 0) PICKING UP SCREENS SUPV:M.C. HEIM, G.R. WHITLOCK POOH. Move 3.5" dp to other side of derrick. RIH to 4175' CBU. Wiper trip to upper scraper, RIH to 4175' PJSM. Pump caustic wash and circulate around. Pickle with acid and spot to bottom of dp. Reverse out pickle. Monitor well. PJSM. RIH w/screens, i"~' i .~ii{ii~' {!'/"/~!'i~' ./.,.i111[ Date: 08/15/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 5 06/26/00 (D26) MW: 9.1 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7407/3648 ( 0 LAYING DOWN 4" SCREEN LINER. SUPV:M.C. HEIM, G.R. WHITLOCK Continue running screens. Run 4.5" tubing. RIH with 2-7/8" tubing. RIH with screens. Unable to work screens past 4834' while circ. String stuck. Pump dry job. POOH. Recover wash string and left screen assembly in hole. 06/27/00 (D27) MW: 9.1 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7407/3648 ( 0) POOH THROUGH WINDOW INTO CASING, BUILDING BRINE VOLUME SUPV:DON L. WESTER, BRIAN NOEL RIH with fishing tools to 1808' Jar fish loose. POOH. RIH to 4372'. Work hole opener and fixed blade stabilizer out through window. Wash and ream from 4372' to 7271' 06/28/00 (D28) MW: 9.1 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7407/3648 ( 0) AT WINDOW RIH W/ SCREENS AND LINER SUPV:DON L. WESTER, BRIAN NOEL Finish reaming hole from 7271' to 7407'. Pump pill. PJSM. RIH w/ screens. 06/29/00 (D29) MW: 8.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7407/3648 ( 0) PICK UP CEMENTING CUP TOOL SUPV:DON L. WESTER, BRIAN NOEL Continue RIH w/screens, liner and 2-7/8" inner wash string. Ran 34 pre-pack screens, blanks and liner. Run liner and screens through window at 4368' and upper lateral to 6825' Increased drag last 60' differentially stuck work pipe. Pump brine and flo-pro pill and spot brine. Work pipe, slight movement slid liner to 6840' Pump second flo-pro pill and spot brine. Work pipe free. RIH, space out and land liner/screen assembly at 7393'. Set packer. POOH. 06/30/00 (D30) MW: 8.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7407/3648 ( 0) TAG TOP TRANSITION JOINT W/ 6" BIT & CIRCULATE OUT GRE SUPV:DON L. WESTER, BRIAN NOEL RIH on 2-7/8" tubing. Pump cement. Test BOP 250/3000 psi. 07/01/00 (D31) MW: 8.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7407/3648 ( 0) WAIT ON CEMENT BOND LOG TOOLS FROM ALPINE SUPV:DON L. WESTER, BRIAN NOEL Wash down and tag transition joint at 4370'. No indication of cement. POOH. RIH with 3.75" mill. Wash from top transition joint into 4.5" liner 4370'-4430'. No cement. POOH. RIH, wash 4.5" liner from 4417' to 4895' 07/02/00 (D32) MW: 8.7 VISC: 0 PV/YP: 0/ 0 TD/TVD: 7407/3648 ( 0) POOH AFTER CEMENT SQUEEZE (CIP AT 3:10 AM) SUPV:DON L. WESTER, BRIAN NOEL APIWL: 0.0 POOH. Wait on cement bond log tool. RIH w/SCMT to 4670' Log 4665'-4119'. PJSM. RIH w/4.5" Halliburton fast drill bridge plug and set at 4405' Date: 08/15/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 6 07/03/00 (D33) MW: 8.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7407/3648 ( 0) RIH W/ WASHPIPE SUPV:DON L. WESTER, BRIAN NOEL Complete breakdown test and circulate. PJSM. Perform cement squeeze. Tag TOC @ 4134'. Drill out cement to 4367' and CBU. RIH with 3.75" mill and 2-7/8" PAC. Tag at 4367' and drill out cement in 4.5" liner to 4384' 07/04/00 (D34) MW: 8.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7407/3648 0) WASHING OVER WHIPSTOCK SUPV:M.C. HEIM / S. GOLDBERG Continue drilling cement from 4384' to 4405' Drill bridge plug and clean out to 4415'. RIH to 4141'. Wash and ream down attempting to clean out. Wash down to 4287'. Torquing up and stacking out weight. Unable to get down. RIH with clean out BHA with mills. RIH to 4127' Wash and ream down to 4364'. Pump high viscosity sweep. POOH slowly due to drag. Lots of thin cement pieces in junk baskets. RIH to 4095'. Wash down and tag up on whipstock at 4365' Start rotating and slowly milling down. 07/05/00 (D35) MW: 8.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7407/3648 0) POOH WITH WHIPSTOCK RUNNING TOOL SUPV:M.C. HEIM / S. GOLDBERG Continue milling over the top of the liner and whipstock from 4363' to 4384'. Pump high viscosity sweeps to aid hole cleaning. Pull up into 7-5/8" casing with whipstock. Drop dart to open circulating sub. sub would not shear open. Continue to pull out of hole wet. Reverse out sand to top of bridge plug. POOH. RIH with completion whipstock. 07/06/00 (D36) MW: 8.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7407/3648 0) RIH WITH CUP TOOLS AND PERFORATED JOINTS SUPV:M.C. HEIM / S. GOLDBERG PJSM. Pump viscosified brine. Pump HC1. Displace with brine. RIH w/mill. Mill KOIV. Pump high viscosity sweep to clean hole. Continue running in hole to 7370'. POOH. 07/07/00 (D37) MW: 8.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7407/3648 0) RUNNING IN HOLE WITH ACIDIZING ASSEMBLY SUPV:M.C. HEIM / S. GOLDBERG Continue POOH with clean out assembly. RIH with sliding sleeve shifting tool and cup assembly. Tag up at 4817' Unable to work through. POOH with acidizing assembly. Cup assembly full of iron and cement mixture. RIH with mill. Tag and mill KOIV at 4908'. Work through and clean up. 07/08/00 (D38) MW: 8.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7407/3648 0) CIRCULATING CLEAN BRINE IN UPPER LATERAL SUPV:M.C. HEIM / S. GOLDBERG ?.~%.~ ½~i~?~ Pump high viscosity sweep. T00H. Small amount of cement and ~ ~'~ i~? steel RIH Work through KOIV. Tag up on sliding sleeve. Date: 08/15/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 7 Unable to work through. POOH with shifting tool. RIH with reverse circulating junk basket. Wash from 4368' to 4468' Tag up at 4942'. Pushed debris through sliding sleeve while circulating with reverse basket. RIH to 7342' POOH. Small amount of cement and steel in basket. 07/09/00 (D39) MW: 8.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7407/3648 ( 0) POOH WITH BRIDGE PLUG SUPV:M.C. HEIM / S. GOLDBERG RIH with sliding sleeve shifting tool. Tag up at 7349' Pump brine. PJSM. Perform acid treatment. POOH. RIH with retrieval tool. 07/10/00 (D40) MW: 8.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7407/3648 ( 0) RUNNING ESP COMPLETION. SUPV:M.C. HEIM / S. GOLDBERG Continue POH w/whipstock. RIH with bridge plug retrieving tool. Wash over bridge plug, latch and retrieve. Monitor well, losing 40 bph, slowed down to 20 bph. POH. Run in hole with 4.5" tubing. PJSM. 07/11/00 (D41) MW: 8.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7407/3648 ( 0) LAND HANGER SUPV:DON WESTER & BRIAN NOEL POOH. PJSM. RIH and set pump and packoff. RIH with 4.5" tubing. PJSM. RIH with 4.5" tubing and dual channel clamps. Start heat trace. PJSM. Megger heat trace and ESP cable. Run 4.5" tubing and dual clamps. 07/12/00 (D42) MW: 8.7 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7407/3648 ( 0) MOVE to 1D-118 WO. SUPV:DON WESTER & BRIAN NOEL Space out heat trace. Splice ESP power cable. Set BPV. ND BOP and test cables. NU tree and test to 250/5000 psi. Set BPV and RDM0. Rig release 3:00 PM on 7/12/00. DRILLING ~:; E R~./I r- E ~=; WELL LOG TRANSMITTAL To: State of Alaska August 25, 2000 Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 1D-102 PB 1 , '~~-~-00058 1 LDWG formatted Disc with verification listing. API#: 50-029-22960-70 'PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Atto: Jim. Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 R£C£1X/[D ' 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 a Halliburton company Schimberger NO. 429 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: KUparuk Color Well Job # Log Description Date BL Sepia Print 2W-02 t,J.t ~. MEM INJECTION PROFILE 000729 I 1 2X-07 V MEM INJECTION PROFILE 000731 I 1 1 D-102 L1 20310 SCMT 000702 1 f~ I L I ! T/ I L,~ 8/17/OO AUG 1 8 2000 SIGNED DATE: Alaska 0ii & Gas Cons. Commission Anchorage Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317, Thank you, 17-Jul-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re' Distribution of Survey Data for Well 1D-102 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 6,527.44' MD 6,558.00' MD 7,378.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Kenneth W. Allen Survey Manager Attachment(s) RECEiV JUL 1 8 ~00C. Alaska 0il & Gas Co~,s. G0m,.missi0n Anchorage 17-Jul-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1D-102 PB3 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 6,143.54' MD 6,170.00' MD 6,767.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Kenneth W. Allen Survey Manager Attachment(s) RECEIVED JUL. 1 8 ~OOL' Alaska Oil & Gas Co~',s. Com,~issi0n ~chorage 17-Jul-O0 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 S_o , Re: Distribution of Survey Data for Well 1D-102 PB2 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 5,181.38' MD 5,190.00' MD 6,454.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Kenneth W. Allen Survey Manager Attachment(s) JUL 18 2000 Alaska OJJ & Gas Cons. Commission Anchorage 17-Jul-00 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1D-102 PB1 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 0.00' MD 5,354.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, Kenneth W. Allen Survey Manager Attachment(s) RECEIVED JUL 1 8 2000 Alaska Oil & Gas Cons. Commission Anchorage North Slope Alaska Alaska State Plane 4 Kuparuk 1D 1D-102 SURVEY REPORT 17 July, 2000 Your Ref: API-500292296000 Surface Coordinates: 5959844.00 N, 560490.59 E (70° 18' 03.0795" N, 210° 29' 23.7478" E) Kelly Bushing: 101.60ft above Mean Sea Level A Halliburton Company RECEIVED JUL Anchorage Survey Ref: svy9260 Sperry-Sun Drilling Services Survey Report for 1D'102 Your Ref: API-500292296000 North Slope Alaska Measured Depth Incl. Azim. Sub-Sea Depth (ft) 6527.44 92.590 172.120 3631.18 6558.00 93.440 171.406 3629.57 6591.05 90.180 172.000 3628.53 6624.23 90.800 173.990 3628.24 6656.37 90.740 174.210 3627.81 6687.28 90.800 177.740 3627.40 6720.46 90.490 179.430 3627.02 6752.68 90.620 179.160 3626.71 6783.56 90.990 179.250 3626.28 6817.84 91.720 179.800 3625.47 6848.72 91.540 179.290 3624.59 6879.61 92.030 179.460 3623.63 6912.89 90.550 179.520 3622.88 6945.28 90.250 179.390 3622.65 6975.86 90.430 180.110 3622.47 7008.90 90.550 181.760 3622.19 7040.63 90.740 182.050 3621.83 7072.18 90.920 182.320 3621.37 7107.92 89.840 183.410 3621.14 7137.62 90.920 183.540 3620.94 7168.75 91.480 183.480 3620.29 7203.15 90.930 182.740 3619.56 7233.27 87.410 182.330 3620.00 7264.21 90.550 182.590 3620.55 7316.13 91.790 185.180 3619.49 Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 3732.78 3537.75 S 1511.92 E 3731.17· 3567.96 S 1516.29 E 3730.13 3600.64 S 1521.06 E 3729.84 3633.57 S 1525.11E 3729.41 3665.54 S 1528,41E 3729.00 3696.36 S 1530.58 E 3728.62 3729.53 S 1531.40 E 3728.31 3761.74 S 1531.79 E 3727.88 3792.62 S 1532.22 E 3727.07 3826.89 S 1532,51 E 3726.19 3857.75 S 1532.75 E 3725.23 3888.63 S 1533.09 E 3724.48 3921.90 S 1533.39 E 3724.25 3954.28 S 1533.69 E 3724.07 3984.86 S 1533.83 E 3723.79 4017,90 S 1533.29 E 3723.43 4049,61S 1532.23 E 3722.97 4081.13 S 1531.03 E 3722.74 4116.82 S 1529.24 E 3722.54 4146.47 S 1527.44 E 3721.89 4177.53 S 1525.54 E 3721.16 4211.87 S 1523.67 E 3721.60 4241.96 S 1522.34 E 3722.15 4272.86 S 1521.01 E 3721.09 4324.64S 1517,50 E Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/100ft) 5956318.87 N 562030.80 E 5956288.71 N 562035.41 E 3.63 5956256.07 N 562040.44 E 10.03 5956223.17'N 562044.75 E 6.28 5956191.24 N 562048.31 E 0.71 5956160.43 N 562050.73 E 11.42 5956127.28 N 562051.81 E 5.18 5956095.07 N 562052.47 E 0.93 5956064.20 N 562053.15 E 1.23 5956029.94 N 562053.71 E 2.67 5955999.08 N 562054,20 E 1.75 5955968.21 N 562054.78 E 1.68 5955934.95 N 562055.35 E 4.45 5955902.57 N 562055.92 E 1.01 5955871.99 N 562056.30 E 2.43 5955838.96 N 562056.02 E 5.01 5955807.25 N 562055.22 E 1.09 5955775.72 N 562054.28 E 1.03 5955740.01 N 562052.78 E 4.29 5955710.36 N 562051.22 E 3.66 5955679.28 N 562049.56 E 1.81 5955644.93 N 562047.97 E 2.68 5955614.84 N 562046.88 E 11.77 5955583.93 N 562045.80 E 10.18 5955532.13 N 562042.70 E 5.53 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 3837.20 Tie-on Survey 3867.18 Window Point 3899,63 3932,09 3963.39 3993.24 4024.87 4055.46 4084.80 4117.29 4146.56 4175.86 42O7.42 4238.14 4267.10 4298.16 4327.80 4357.22 4390.39 4417.83 4446.59 4478.45 4506.46 4535.25 4583.08 Continued... 17 July, 2000 - 12:00 - 2 - DrillQuest 2.00.02 Sperry-Sun Drilling Services Survey Report for 1D-102 Your Ref: API-500292296000 North Slope Alaska Measured Depth (ft) 7378.00 Sub-Sea Vertical Local Coordinates Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) 91.790 185.180 3617.56 3719.16 4386.23 S 1511.91 E Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°r~OOtt) 5955470.50 N 562037.62 E 0.00 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 100 feet. Vertical Section is from Well and calculated along an Azimuth of 161.010° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 7378.00ft., The Bottom Hole Displacement is 4639.49ft., in the Direction of 160.981 ° (True). * Grid Coordinate Scale Factors have been applied to all local coordinates. Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 4639.49 Projected Survey Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 6527.44 3732.78 3537.75 S 1511.92 E 6558.00 3731.17 3567.96 S 1516.29 E 7378.00 3719.16 4386.23 S 1511.91 E 17 July, 2000 - 12:00 Comment Tie-on Survey Window Point Projected Survey -3- RF..CF. IV £D JUL ! .3 :00£ Alaska Oi[ & Gas Co,~s. AnChorage Continued... DrillQuest 2.00.02 Sperry-Sun Drilling Services Survey Report for 1D-102 Your Ref: API.500292296000 North Slope Alaska Alaska State Plane 4 Kuparuk 1D Survey tool program From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) 0.00 0.00 7378.00 Vertical Depth (ft) 3719.16 Survey Tool Description MWD Magnetic 17 July, 2000 - 12:00 -4- DriilQuest 2.00. 02 North Slope Alaska Alaska State Plane 4 Kuparuk 1D 1D-102 PB3 ORIGINAL S UR VE Y REPORT 17 July, 2000 Your Ref: API-500292296072 Surface Coordinates: 5959844.00 N, 560490.59 E (70° 18' 03.0795" N, 210° 29' 23.7478" E) Kelly Bushing: 101.60ft above Mean Sea Level A Halliburton Company RECEIVED J~JL "t 8 ,tOO(, Alask~t Oii& G~.s C~-?,s. "' '"""° Anchorage Survey Ref: svy9259 Sperry-Sun Drilling Services Survey Report for 1D- 102 PB3 Your Ref: API-500292296072 North Slope Alaska Alaska State Plane 4 Kuparuk 1D Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate (fi) (ft) (fi) (fi) (fl) (fl) (fi) (°/lOOfl) 6143.54 92.030 180.130 3643.21 3744.81 3155.31 S 1491.00 E 5956701.10 N 562006.79 E 6170.00 91.720 181.000 3642.34 3743.94 3181.75 S 1490.74 E 5956674.66 N 562006.75 E 3.49 6176.64 91.790 181.560 3642.14 3743.74 3188.39 S 1490.59 E 5956668.02 N 562006.65 E 8.50 6208.12 90.990 180.910 3641.38 3742.98 3219.85 S 1489.91 E 5956636.56 N 562006.23 E 3.27 6240.29 90.800 180.090 3640.87 3742.47 3252.01 S 1489.63 E 5956604.39 N 562006.21 E 2.62 Vertical Section Comment 3468.75 Tie-on Su~ey 3493.68 Window Point 3499.90 3529.43 3559.75 6273.43 92.160 178.940 3640.02 3741.62 3285.14 S 1489.91 E 5956571.27 N 562006.75 E 5.37 3591.17 6304.31 93.760 177.850 3638.42 3740.02 3315.96 S 1490.77 E 5956540.46 N 562007.86 E 6.27 3620.60 6336.34 93.510 178.030 3636.39 3737.99 3347.91 S 1491.92 E 5956508.53 N 562009.27 E 0.96 3651.18 6369.63 93.020 175.740 3634.50 3736.10 3381.09 S 1493.73 E 5956475.36 N 562011.34 E 7.02 3683.14 6400.13 89.750 174.220 3633.76 3735.36 3411.46 S 1496.40 E 5956445.02 N 562014.25 E 11.82 3712.73 6433.38 89.690 174.100 3633.92 3735.52 3444.54 S 1499.78 E 5956411.97 N 562017.90 E 0.40 3745.11 6466.48 91.660 172.900 3633.53 3735.13 3477.42 S 1503.53 E 5956379.13 N 562021.91 E 6.97 3777.42 6495.66 92.280 171.660 3632.53 3734.13 3506.32 S 1507.44 E 5956350.26 N 562026.06 E 4.75 3806.02 6527.44 92.590 172.120 3631.18 3732.78 3537.75 S 1511.92 E 5956318.87 N 562030.80 E 1.74 3837.20 6560.41 93.510 171.350 3629.42 3731.02 3570.34 S 1516.65 E 5956286.33 N 562035.79 E 3.64 3869.55 6591.15 94.990 170.740 3627.15 3728.75 3600.62 S 1521.43 E 5956256.09 N 562040.80 E 5,21 3899.73 6624.66 93.140 169.400 3624.77 3726.37 3633.54 S 1527.19 E 5956223.22 N 562046.83 E 6.81 3932.74 6656.82 94.750 171.090 3622.56 3724.16 3665.16 S 1532.63 E 5956191.65 N 562052.52 E 7.25 3964.40 6687.02 95.670 173.210 3619.82 3721.42 3694.95 S 1536.73 E 5956161.90 N 562056.87 E 7.63 3993.91 6711.26 95.300 173.710 3617.50 3719.10 3718.92 S 1539.48 E 5956137.95 N 562059.81 E 2.56 4017.47 6767.00 95.300 173.710 3612.35 3713.95 3774.09 S 1545.56 E 5956082.84 N 562066.34 E 0.00 4071.62 Projected Su~ey 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 100 feet. Vertical Section is from Well and calculated along an Azimuth of 161.010° (True). R Based upon Minimum Curvature type calculations, at a Measured Depth of 6767.00ft., j~j1L.' The Bottom Hole Displacement is 4078.30ft., in the Direction of 157.730° (True). 17 July, 2000 - 11:36 - 2 - DrillQuest 2.00.02 Sperry-Sun Drilling Services Survey Report for 1D-102 PB3 Your Reft API-500292296072 North Slope Alaska * Grid Coordinate Scale Factors have been applied to all local coordinates. Alaska State Plane 4 Kuparuk 1D Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 6143.54 3744.81 3155.31 S 1491.00 E 6170.00 3743.94 3181.75 S 1490.74 E 6767.00 3713.95 3774.09 S 1545.56 E Comment Tie-on Survey Window Point Projected Survey Survey tool program From Measured Vertical Depth Depth (fi) (ft) 0.oo 0.00 To Measured Vertical Depth Depth (fi) (ft) 6767.00 3713.95 Survey Tool Description MWD Magnetic 17 July, 2000 - 11:36 -3- DrillQuest 2. 00. 02 North Slope Alaska Alaska State Plane 4 Kuparuk 1D 1D-102 PB2 ORIGINAL SURVEY REPORT RECEIVED 17 July, 2000 JUL 1 8 ~.000 ~Jaska Oil & Gas Cons. Commission Anchorage Your Ref: API-500292296071 Surface Coordinates: 5959844.00 N, 560490.59 E (70° 18' 03.0795" N, 210° 29' 23.7478" E) Kelly Bushing: 101.60ft above Mean Sea Level A Halliburton Company Survey Ref: svy9258 Sperry-Sun Drilling Services Survey Report for 1D- 102 PB2 Your Ref: API-500292296071 North Slope Alaska Measured Depth (ft) 5181.38 5190,00 5216.56 5245.35 5310.10 Incl. 90.250 89.760 88.210 88.520 88.580 Azim. 176.18o 176.430 176.680 175.750 175.910 Sub-Sea Depth (fi) 3654.25 3654.25 3654.72 3655.54 3657.18 Vertical Depth (fi) 3755.85 3755.85 3756.32 3757.14 3758.78 5340.45 91.110 176,280 3657.26 3758.86 5374.14 91.420 177.030 3656.52 3758.12 5405.56 91.660 175.980 3655.68 3757.28 5436.41 91.600 176.310 3654.80 3756.40 5469.44 91.850 176.920 3653.80 3755.40 5502.28 91.110 178.520 3652.96 3754.56 5532.35 90.310 179.130 3652.58 3754.18 5565.19 90.180 179.860 3652.44 3754.04 5597.16 89.260 179,580 3652.60 '3754.20 5628.14 88.890 179.230 3653.10 3754.70 5662.19 88.280 178.650 3653.94 3755,54 5694.31 89.080 179.540 3654.68 3756.28 5725.10 90.310 179.330 3654.84 3756.44 5757.77 90.430 178.800 3654.63 3756.23 5789.85 91.600 179.350 3654.06 3755.66 5820.57 91,780 180.600 3653.16 3754.76 5853.47 91.850 181.000 3652.12 3753.72 5885.68 92.280 180.410 3650.96 3752.56 5917.02 92.280 180.340 3649.71 3751.31 5949.91 91.480 181.420 3648.63 3750.23 Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 2194.17 S 1471.82 E 5957661.96 N 561979.88 2202.77 S 1472.37 E 5957653.36 N 561980.51 2229.28 S 1473.97 E 5957626.87 N 561982.32 2257,99 S 1475.87 E 5957598.18 N 561984.45 2322,55 S 1480.58 E 5957533.66 N 561989.67 2352.83 S 1482.64 E 5957503.41 N 561991.98 2386.45 S 1484,61 E 5957469.80 N 561994.22 2417.80 S 1486.52 E 5957438.47 N 561996.38 2448.57 S 1488.60 E 5957407.73 N 561998.71 2481.53 S 1490.55 E 5957374.79 N 562000.92 2514.33 S 1491,85 E 5957342.00 N 562002.49 2544.39 S 1492.47 E 5957311.95 N 562003.35 2577.23 S 1492.76 E 5957279.12 N 562003.90 2609.20 S 1492.91 E 5957247.15 N 562004.32 2640.17 S 1493.24 E 5957216.19 N 562004.89 2674,20 S 1493.87 E 5957182.16 N 562005.79 2706,31S 1494.37 E 5957150.06 N 562006.56 2737.10 S 1494,68 E 5957119.28 N 562007.11 2769.76 S 1495.21 E 5957086.63 N 562007.90 2801.83 S 1495.73 E 5957054.57 N 562008.68 2832.54 S 1495.74 E 5957023.86 N 562008.94 2865.42 S 1495.28 E 5956990.98 N 562008.74 2897.61 S 1494.88 E 5956958,80 N 562008.61 2928.92 S 1494.68 E 5956927.49 N 562008.65 2961.79 S 1494.18 E 5956894.62 N 562008.41 Dogleg Rate (°/lOOft) E E 6.38 E 5.91 E 3.4O E 0.26 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 2553.69 Tie-on Survey 2562.00 Window Point 2587.59 2615.36 2677.93 E 8.42 2707.23 E 2.41 2739.67 E 3.43 2769,93 E 1.09 2799.70 E 2.00 2831.50 E 5.37 2862.94 E 3.35 2891.57 E 2.26 2922.71 E 3.01 2952.99 E 1.64 2982.38 E 2.47 3014.77 E 3.73 3045.30 E 4.05 3074.51 E 1.66 3105.57 E 4.03 3136.06 E 4.11 3165.10 E 1.23 3196.04 E 2.27 3226.35 E 0.22 3255.89 E 4.08 3286.80 17 July, 2000 - 11:37 -2- RECEtVED JUL 1 8 P. O00 Alaska Oit & Gas C,o~s. uo,,H:~,v,, Anchorage Continued... DrillQuest 2.00. 02 Sperry-Sun Drilling Services Survey Report for 1D-102 PB2 Your Ref: API-500292296071 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (fi) (ft) (ft) (ft) (ft) 5982.64 91.290 181.740 3647.84 3749.44 2994.50 S 1493.27 E 6013.97 91.230 181.340 3647.15 3748.75 3025.81 S 1492.43 E 6047.67 91.660 180,930 3646.30 3747.90 3059.49 S 1491.76 E 6079.02 91.720 180.650 3645.38 3746.98 3090.82 S 1491.33 E 6110.62 91.970 180.210 3644.36 3745.96 3122.41 S 1491.09 E 6143.54 92.030 180.130 3643.21 3744.81 3155.31 S 1491.00 E 6176.64 91.790 181.560 3642.11 3743.71 3188.38 S 1490.51 E 6208.12 90.990 180.910 3641.34 3742.94 3219.85 S 1489.83 E 6240.29 90.800 180.090 3640.84 3742.44 3252.01 S 1489.55 E 6273.43 92.160 178.940 3639.98 3741.58 3285.14 S 1489.83 E 6304.31 93.760 177.850 3638.39 3739.99 3315.96 S 1490.69 E 6336.34 93.510 178.030 3636.36 3737.96 3347.91 S 1491.84 E 6369.63 93.020 175.740 3634.46 3736.06 3381.09 S 1493.65 E 6454.00 93.020 175.740 3630.02 3731.62 3465.11 S 1499.91 E Global Coordinates Dogleg Northings Eastings Rate (fi) (fi) (°/lOOft) 5956861.91N 562007.78 E 5956830.59 N 562007.19 E 5956796.91 N 562006.79 E 5956765.58 N 562006.61E 5956734.00 N 562006.63 E 5956701.10 N 562006.79 E 5956668.02 N 562006.57 E 5956636.56 N 562006.15 E 5956604.40 N 562006.13 E 5956571.28 N 562006.67 E 5956540.46 N 562007.79 E 5956508.53 N 562009.19 E 5956475,36 N 562011.26 E 5956391,41N 562018.20 E 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 100 feet. Vertical Section is from Well and calculated along an Azimuth of 161.010° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 6454.00ft., The Bottom Hole Displacement is 3775.81ft., in the Direction of 156.594° (True). * Grid Coordinate Scale Factors have been applied to all local coordinates, Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 1.14 3317.44 1.29 3346.77 1.76 3378.4O 0.91 34O7.89 1.60 3437.68 O.3O 3468.75 4.38 3499.87 3.27 3529.4O 2,62 3559.73 5.37 3591.14 6.27 362O.57 0.96 3651.15 7.O2 3683.12 0.00 3764.60 Projected Survey RECEIVED JUL 1 8 2000 Continued... 17 July, 2000 - 11:37 - 3 - Alaska Oil & Gas 6ons. Oomm. ission Anchorage DrillQuest 2.00.02 Sperry-Sun Drilling Services Survey Report for 1D- 102 PB2 Your Ref: API-500292296071 North Slope Alaska Alaska State Plane 4 Kuparuk 1D Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 5181.38 3755.85 2194.17 S 1471.82 E 5190.00 3755.85 2202.77 S 1472.37E 6454.00 3731.62 3465.11 S 1499.91 E Comment Tie-on Survey Window Point Projected Survey Survey tool program From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) o.oo o.oo 6454.00 Vertical Depth (ft) 3731.62 Survey Tool Description MWD Magnetic RECEIVED JUL ! 8 2.000 Anchorage 17 July, 2000 - 11:37 - 4 - DriliQuest ZOO. 02 North Slope Alaska Alaska State Plane 4 Kuparuk 1D 1D-102 PB1 ORIGINAL SURVEY REPORT 17 July, 2000 Your Reft API-500292296070 Surface Coordinates: 5959844.00 N, 560490.59 E (70° 18' 03.0795" N, 210° 29' 23.7478" E) Kelly Bushing: 101.60ft above Mean Sea Level I:l I:! I L I~ I N I:~ SERVICES A Halliburton Company RECEIVED JUL ! 8 Alaska 0il & G~s Cows. C.,ommissi(~n Anchorage Survey Ref: svy9257 Sperry-Sun Drilling Services Survey Report for 1D-102 PB1 Your Ref: AP1-$00292296070 North Slope Alaska Measured Depth (It) Incl. Azim. Sub-Sea Depth (ft) 0.00 0.000 0.000 -101.60 1 14.28 0.260 25.770 12.68 206.41 0.550 56.510 104.81 231.67 0.630 61.630 130.07 288.48 0.360 50.770 186.87 328.77 0.380 100.000 368.28 0.410 173.460 398.47 0.770 192.440 464.81 2.730 220.490 513.56 6.040 229.570 558.30 8.350 232.680 606.31 9.160 233.260 652.79 9.430 235.010 698.56 7.280 234.620 743.02 6.570 237.400 789.60 5.570 238.590 834.15 4.150 242.740 880.27 0.630 217.780 943.52 5.120 61.560 975.67 6.130 63.030 Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 0.00 0.00 N 0.00 E 114.28 0.23 N 0.11 E 206.41 0.67 N 0.57 E 231.67 0.80 N 0.80 E 288.47 1.06 N 1.21 E 227.16 328.76 1.12 N 1.44 E 266.67 368.27 0.95 N 1.58 E 296.86 398.46 0.65 N 1.55 E 363.17 464.77 0.99 S 0.43 E 411.77 513.37 3.54 S 2.28W 456,15 557.75 7.03 S 6.65W 503.60 605.20 11,43 S 12.49W 549.47 651.07 15.83 S 18.57W 594.75 696.35 19.66 S 24.01W 638.89 740.49 22.66 S 28.45W 685.21 786.81 25.27 S 32.62W 729.60 831.20 27.14 S 35.90W 775.67 877.27 28.10 S 37.54W 838.84 940.44 27.03 $ 35.27W 870.84 972.44 25.57 S 32.48W Global Coordinates Dogleg Northings Eastings Rate (fi) (fi) (°/lOOff) 1008.32 6.930 68.330 903.28 1038.23 7.240 74.110 932.96 1068.20 7.380 78.390 962.69 1102.29 7.490 88.020 996.49 1134.48 6.990 102.640 1028.43 5959844.00N 560490.59 E 5959844,23 N 560490.70 E 0.23 5959844.67 N 560491.16 E 0.38 5959844.80 N 560491.38 E 0.38 5959845.07N 560491.79 E 0.50 5959845.13 N 560492.02 E 0.77 5959844.97 N 560492.17 E 1.20 5959844.66 N 560492.14 E 1.34 5959843,01N 560491.03 E 3.14 5959840.45 N 560488.34 E 6.92 5959836.92 N 560483.99 E 5.23 5959832.47 N 560478.20 E 1.70 5959828.02 N 560472.15 E 0.84 5959824.15 N 560466.74 E 4.70 5959821.11N 560462.33 E 1.77 5959818.47 N 560458.18 E 2.16 5959816.58 N 560454.91 E 3.28 5959815.60 N 560453.28 E 7.78 5959816.69 N 560455.54 E 9.02 5959818.17 N 560458.32 E 3.17 1004.88 24.05 S 29.09W 1034.56 22.87 S 25.60W 1064.29 21.97 S 21.90W 1098.09 21.45 S 17.54W 1130.03 21.81S 13.53W 5959819.72 N 560461.69 E 3.07 5959820.93 N 560465.17 E 2.60 5959821.86 N 560468.87 E 1.88 5959822.41 N 560473.23 E 3.67 5959822.09 N 560477.24 E 5.91 JUL 8 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 0.00 -0.18 -0.44 -0.50 -0.61 -0.59 -0.39 -0.11 1.07 2.60 4.48 6.75 8.92 10.78 12.17 13.28 13.98 14.36 14.09 13.61 13.28 13.29 13.64 14.58 16.22 Continued... 17 July, 2000 - 11:38 - 2 - DrillQuest 2.00.02 Sperry-Sun Drilling Services Survey Report for 1D-102 PB1 Your Ref: API-500292296070 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) 1163.89 7.370 123.140 1057.61 1196.44 9.040 145.770 1089.84 1230.10 11.260 163.710 1122.97 1260.65 12.920 179.100 1152.85 1293.95 13.990 184.060 1185.24 1325.71 14.040 185.540 1216.05 1356,36 13.680 188.420 1245.81 1389.89 13.390 191.630 1278.41 1421,83 13.820 193.230 1309.46 1452.82 13.280 193.990 1339.58 1485.87 13.080 192.970 1371.76 1549.55 11.890 180.020 1433.95 1645.86 12.830 161.870 1528.06 1741.67 15.070 157.820 1621.04 1775.05 15.390 160.010 1653.25 1837.89 15.830 161.990 1713.77 1934.23 16.190 161.630 1806.37 2029.33 20.840 157.290 1896.53 2126.75 28.850 150.130 1984.88 2221.46 32.470 149,960 2066.34 2317.51 36.080 149.350 2145.70 2413.16 37.920 145.540 2222.09 2509.27 43.680 141.420 2294.83 2605.84 46.950 141.850 2362.73 2702.76 51.560 138.700 2425.98 Vertical Local Coordinates Depth Northings Eastings (ft) (ft) (ft) 1159.21 23.23 S 10.20W 1191.44 26.49 S 7.01W 1224.57 31.83 S 4.60W 1254.45 38.11S 3.71W 1286.84 45.85 S 3.94W 1317.65 53.51S 4.58W 1347.41 60.80 S 5.47W 1380.01 68.52 S 6.84W 1411.06 75.86 S 8.46W 1441.18 82.91 S 10.16W 1473.36 90.24 S 11.92W 1535.55 103.83 S 13.54W 1629.66 123.92 S 10.22W 1722.64 145.56 S 2.20W 1754.85 153.75 S 0.95 E 1815.37 169.73 S 6.45 E 1907.97 194.98 S 14.75 E 1998.13 223.18 S 25.46 E 2086.48 259.61S 43.89 E 2167.94 301.45 S 68.01 E 2247.30 348.12 S 95.34E 2323.69 396.59 S 126.34 E 2396.43 446.94 S 163.78 E 2464.33 500.77 S 206.39 E 2527.58 557.17 S 253.34 E Global Coordinates Dogleg Northings Eastings Rate (ft) (ft) (°/lOOft) 5959820.69 N 560480,58 E 8.76 5959817.46 N 560483.79 E 11.07 5959812.14 N 560486.24 E 11.40 5959805.87 N 560487.18 E 11.82 5959798.13 N 560487.02 E 4.72 5959790.46 N 560486.44 E 1.14 5959783.17 N 560485.61 E 2.54 5959775.43 N 560484.31 E 2.40 5959768.09 N 560482.75 E 1.79 5959761.02 N 560481.10 E 1.83 5959753.67 N 560479.40 E 0.93 5959740.08 N 560477.89 E 4.76 5959720.02 N 560481.37 E 4.13 5959698.44 N 560489.56 E 2.55 5959690.28 N 560492.78 E 1.97 5959674.34 N 560498.41 E 1.10 5959649.17 N 560506.90 E 0.39 5959621.05 N 560517.85 E 5.10 5959584.77 N 560536.57 E 8.77 5959543.14 N 560561.01E 3.82 5959496.70 N 560588.72 E 3.78 5959448.48 N 560620.10 E 3.07 5959398.44 N 560657.95 E 6.61 5959344.96 N 560700.98 E 3.40 5959288.94 N 560748.39 E 5.36 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 18.64 22.76 28.60 34.83 42.07 49.11 55.71 62.57 68.98 75.09 81.45 93.77 113.85 136.93 145.69 162.59 189.16 219.32 259.77 307.17 360.19 416.12 475.91 540.67 609.29 R[C£1V[D JUL 8 200C Continued... 17 July, 2000 - 11:38 -3- Alaska Oil 8, Gas Cons. Anchorage DrillQuest 2. 00.02 Sperry-Sun Drilling Services Survey Report for 1D-102 PB1 Your Ref: API-500292296070 North Slope Alaska Measured Depth (ft) 2799.28 2895.60 2991.79 3087.93 3184.50 Incl. 52.920 55.170 56.090 52.660 50.830 3279.39 3376.11 3471.91 3568.43 3664.14 50.950 51.620 50.880 49.060 49.370 3759.29 3856.17 3952.29 4048.09 4144.83 50.49O 52.470 51.920 50.130 51.460 4241.18 4276.73 4307.91 4337.54 4370.88 52.040 51.210 51.450 51.390 51.550 4404.87 4434.20 4468.70 4500.96 4529.55 53.490 55.700 58.250 61.580 63.110 Azim. 134.83o 135.71o 137.4oo 133.43o 133.930 135.920 136.030 138.850 137.94o 138.330 138.630 139.900 137.990 137.690 136.620 137.290 137.980 137.490 138.350 139.670 137.320 139.620 141.970 142.710 145.020 Sub-Sea Depth (fi) 2485.10 2541.65 2595.96 2651.96 2711.75 2771.61 2832.11 2892.08 2954.15 3016.67 3077.92 3138.26 3197.18 3257.43 3318.58 3378.23 3400.30 3419.79 3438.26 3459.03 3479.72 3496.71 3515.51 3531.68 3544.95 Ve~ical Depth (fi) 2586.70 2643.25 2697.56 2753.56 2813.35 2873.21 2933.71 2993.68 3055.75 3118.27 3179.52 3239.86 3298.78 3359.03 3420.18 3479.83 3501.90 3521.39 3539.86 3560.63 3581.32 3598.31 3617.11 3633.28 3646.55 Local Coordinates Northings Eastings (ft) (fi) 612.73 S 305.61 E 668.12 S 360.47 E 725.77 S 415.06 E 781.44 S 469.85 E 833.80 S 524.69 E 885.80 S 576.82 E 940.06 S 629.27 E 995.07 S 679.80 E 1050.34 S 728.86 E 1104.31 S 777.23 E 1158.82 S 825.49 E 1216.26 S 874.94 E 1273.53 S 924.81 E 1328.74 S 974.80 E 1383.69 S 1025.78 E 1438.99 S 1077.42 E 1459.58 S 1096.20 E 1477.60 S 1112.57 E 1494.79 S 1128.10 E 1514.47 S 1145.20 E 1534.67 S 1163.08 E 1552.56 S 1178.92 E 1574.98 S 1197.20 E 1597.07 S 1214.25 E 1617.53 S 1229.17 E Global Coordinates Northings Eastings (ft) (ft) 5959233.81N 560801.10 E 5959178.87 N 560856.40 E 5959121.67 N 560911.44 E 5959066.44 N 560966.67 E 5959014.53 N 561021.93 E 5958962.96 N 561074.47 E 5958909.13 N 561127.34 E 5958854.53 N 561178.31 E 5958799.66 N 561227.81E 5958746.09 N 561276.61 E 5958691.97 N 561325.30 E 5958634.94 N 561375.21 E 5958578.08 N 561425.53 E 5958523.28 N 561475.96 E 5958468.74 N 561527.37 E 5958413.87 N 561579.46 E 5958393.43 N 561598.40 E 5958375.55 N 561614.92 E 5958358.49 N 561630.57 E 5958338.94 N 561647.84 E Dogleg Rate (°/lOOft) 3.47 2.45 1.74 4.90 1.94 1.63 0.70 2.42 2.02 0.45 1.20 2.29 1.67 1.88 1.62 0.81 2.79 1.45 2.28 3.13 5958318.89 N 561665.87 E 7.92 5958301.13 N 561681.86 E 9.88 5958278.86 N 561700.31 E 9.34 5958256.90 N 561717.54 E 10.51 5958236.58 N 561732.63 E 8.94 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 678.83 749.06 821.33 891.80 959.16 1025.29 1 O93.66 1162.13 1230.35 1297.12 1364.37 1434.78 1505.15 1573.62 1642.17 1711.27 1736.85 1759.21 1780.52 1804.70 1829.61 1851.69 1878.83 1905.27 1929.47 RECEIVED JUL Continued... 17 July, 2000 - 11:38 -4- ~,laska 0i! & Gas Co'~s. Commission DrillQuest 2.00. 02 Sperry-Sun Drilling Services Survey Report for 1D-102 PB1 Your Ref: API-500292296070 North Slope Alaska Measured Depth (ft) 4565.14 4595.94 4625.32 4656.84 4688.90 Incl. 62.900 64,250 65,510 68.060 72.010 Azim. 145.690 146.960 148.080 147.310 148.410 Sub-Sea Depth (n) 3561,11 3574,81 3587.29 3599.71 3610,65 Vertical Depth (fi) 3662.71 3676.41 3688.89 3701.31 3712.25 4720.22 76.150 151.040 3619.24 3720.84 4754.67 78.580 153.520 3626.78 3728.38 4784.40 78.480 153.150 3632.69 3734.29 4818.05 79.280 153.350 3639.18 3740.78 4847.43 82,130 154.170 3643.93 3745.53 4877.52 84.410 156.470 3647.45 3749.05 4955.13 90.060 155.850 3651.20 3752.80 4989.41 90.120 160.410 3651.14 3752.74 5022.05 90.250 163.850 3651.04 3752.64 5051.93 89.200 167.300 3651.18 3752.78 5084.63 88.890 170.860 3651.73 3753.33 5117.35 88.090 172.010 3652.59 3754.19 5149.35 87.850 173.530 3653.72 3755.32 5181.38 90,250 176.180 3654.25 3755.85 5214.86 93.690 178.650 3653.10 3754.70 5244.73 94.930 178.780 3650.86 3752.46 5246.01 95.000 178.970 3650.75 3752.35 5279.45 96.170 178.920 3647.49 3749.09 5299.29 96.420 178.940 3645.32 3746.92 5354.00 96.420 178.940 3639.20 3740.80 Local Coordinates Global Coordinates Dogleg Northings Eastings Northings Eastings Rate (ft) (ft) (ft) (ft) (°llOOft) 1643.62 S 1247.20 E 1666.57 S 1262.49 E 1689.01 S 1276.78 E 1713.49 S 1292.26 E 1739.00 $ 1308.28 E 1765.01 S 1323.46 E 1794.76 S 1339.09 E 1820.80 S 1352,16 E 1850.28 S 1367.02 E 1876.29 S 1379.84 E 1903.44 S 1392.32 E 1974.31 S 1423.64 E 2006.12 S 1436.40 E 2037.18 S 1446.42 E 2066.11 S 1453.86 E 2098.21S 1460.05 E 2130.55 S 1464.92 E 2162.28 S 1468.95 E 2194.17 S 1471.82 E 2227,59 S 1473.33 E 2257.37 S 1474.00 E 2258.64S 1474.02 E 2291.92 $ 1474.63 E 2311.63 $ 1475.00E 2365.99 $ 1476.01 E 5958210.63 N 561750.86 5958187.81N 561766.34 5958165.48 N 561780.80 5958141,13 N 561796.48 5958115.75 N 561812.70 5958089.87 N 561828.08 5958060.25 N 561843.95 5958034.32 N 561857.24 5958004.96 N 561872.33 5957979.06 N 561885.36 5957952.01N 561898.05 5957881.40 N 561929.94 5957849.70 N 561942.96 5957818.73 N 561953.22 5957789.86 N 561960.89 5957757.81 N 561967.34 5957725.51N 561972.47 5957693.82 N 561976.75 5957661.96 N 561979.88 5957628.56 N 561981.66 5957598.79 N 561982.57 5957597.51 N 561982.60 5957564.25 N 561983.48 5957544.54 N 561984.01 5957490.19 N 561985.45 E 1.78 E 5.73 E 5.50 E 8.4O E 12.74 E 15.49 E 9.95 E 1.27 E 2.45 E 10.08 E 10.73 E 7.32 E 13.30 E 10.55 E 12.07 E 10.93 E 4.28 E 4.81 E 11.16 E 12.65 E 4.17 E 15.77 E 3.50 E 1.26 E 0.00 Alaska State Plane 4 Kuparuk 1D Vertical Section Comment 196o.01 1986.69 2o12.55 2040.74 2070.08 2099.61 2132.83 2161.70 2194.42 2223.18 2252.91 2330.12 2364.35 2396.97 2426.75 2459.12 2491.29 2522.60 2553.69 2585.78 2614.15 2615.37 2647.03 2665.79 2717.52 Projected Survey 17July, 2000- 11:38 RECEIVED JUL 1 8 -5- 'Alaska Oil & Gas Co?,s. Commission A~,horage Continued... DrillQuest 2.00. 02 Sperry-Sun Drilling Services Survey Report for 1D-102 PB1 Your Ref: API-500292296070 North Slope Alaska 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 100 feet. Vertical Section is from Well and calculated along an Azimuth of 161.010° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 5354.00ft., The Bottom Hole Displacement is 2788.64ft., in the Direction of 148.042° (True). * Grid Coordinate Scale Factors have been applied to all local coordinates. Alaska State Plane 4 Kuparuk 1D Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 5354.00 3740.80 2365.99 S 1476.01 E Comment Projected Survey RECEIVED JUL_ 8 00C' Alaska (.',il & Gss Co.~s. Com.q',.ission Continued... 17 July, 2000 - 11:38 - 6 - ARC~0f[tg(~ DrillQuest 2.00.02 Sperry-Sun Drilling Services Survey Report for 1D-102 PB1 Your Ref: API-500292296070 North Slope Alaska Alaska State Plane 4 Kuparuk 1D Survey tool program From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 To Measured Depth (ft) 5354.00 Vertical Depth (ft) 3740.80 Survey Tool Description MWD Magnetic RECEIVED JUL 'I 8 200f .¢"~ ~ I Ar~chorago 17 July, 2000 - 11:38 - 7 - DrillQuest 2.00.02 ALASILA OIL AND GAS CONSERVATION CO~I~ISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Chip Alvord Drilling Engineering Superv'isor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 1 D- 102 ARCO Alaska, Inc. Permit No: 200-075 Sur Loc: 179'FSL, 595'FEL, Sec. 14, T1 IN, R10E, UM Btmhole Loc. 1070'FSL, 912'FWL, Sec. 24, T1 IN, R10E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to redrill the above referenced well. Annular disposal has not been requested as part of the Permit to Drill application for Kuparuk River Unit Well No. 1D-102. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site 1D must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. 'Daniel T. Seamount. Commissioner BY ORDER OF THE CONJMISSION DATED this /~ 7'~ day of May, 2000 dl f/Enclosures cc: Dcpartmcnt of Fish & Game. Habitat Section '~v/o encl. Dcpamncnt of Environmcntal Conservation ,~x'/o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.0O5 la. Type ofwork: Drill ~] Redril, r-~ I ~. Type ofwel,. Exploratory r-1 Stratigraphic Test r"] Development Oil [~] Re-entry F1 Deepen [~I Service E] Development Gas ~! Single Zone r~ Multiple Zone r'] 2. Name of _Operator 5. Datum elevation (DF or KB) 10. Field and Pool ~ P~laska, Inc. ~../~ RKB 30 feet 3. Address 6. Property Designation Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25650 ALK 468 West Sak Oil Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 179' FSL, 595' FEL, Sec. 14, T11 N, R10E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 1729' FNL, 934' FWL, Sec. 24, T11N, R10E, UM 1D-102 #U-630610 At total depth 9. Approximate spud date Amount 1070' FSL, 912' FWL, Sec. 24 T11 N, R10E, UM May 23, 2000 $200,000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 1070' @ TD feetI 1 D-14 30.4' @ 304' feet 2560 7355 ' MD/3694 ' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 275' MD Maximum hole angle 92 o Maximum surface 1318 psig At total depth (TVD) 1732 psig 18. Casing program Settin~ Depth size Specifications Top Bottom Quantit~ of Cement Hole Casin~l Weight Grade Couplin~ Len~lth MD TVD MD TVD (include sta~le data) 20" 13.375" 68# L-80 BTC 80' 30' 30' 110' 110' 7 cu yds High Early 9.875" 7.625" x 7" 29.7# L-80 BTC Mod 4837' 30' 30' 4867' 3761' 468 sx Class G & 316 sx Class G 6" 4.5" x 4" 9.5# L-80 HSLHT 2488' 4867' 3761' 7355' 3694' Prepack screen 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) true vertical feet Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface Intermediate ~'~ -~(~~' ~ ~'~'~ r~ Production ~"~,, ..... Liner Perforation depth: measured 0RI GiN A L A~a~a 0ii & Gas Co~s. true vertical Anc~0fa~e 20. Attachments Filing fee r~ Property Plat D BOP Sketch [~] Diverter Sketch D Drilling program Drilling fluid program r'~ Time vs depth plot BRefraction analysis r"l Seabed report [-] 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Call Mark Chambers 265-131~. O ip Alvord Prepared bv ,~h,eron AIl.~un-Dr, ek~ Oommission Use Permit Numbe~_~)(~) 0 ~'~ ~"l APl number _ - ~ '"/~)--~ J for other requirements -- 50. O~_~-1~- .2. Z~:~ O&I Approvaldate....- - Isoecover,etter Conditions of approval Samples required r"l Yes ~ No Mud logrequired D Yes .[~ No Hydrogen sulfide measures O Yes ~N~ Directional survey required [~ Yes D No Required Working pressure forBOPE D2M; D 5M; D 10M;D E~] Other: · -~' by order of Approved bOy~.l~lNAl ,.,~ "~ ..... ': ~., Commissioner the commission Date ~-'y~-~ -,~r/O/jn~ Form 10-401 Rev. 12/1/85 Submit in triplicate Drilling Fluid Program, Pressure Calculations & Drilling Area Risks ~¥~AY 12 200el West Sak 1D-102 Multilateral Producer (Primary Well Bore) Well Plan Summary Surface Location: 179' FSL 595' FEL Sec 14 TllN R10E B-Sand Lateral - Target 1 1729' FNL 934' FWL Sec 24 T11N R10E B-Sand Lateral - TD 1070' FSL 912' FWL Sec 24 TllN R10E I AFE Number: I I I Rig: I Nordic 3 I Estimated Start Date: I 5/24/99 Operating days: I 37 I I I I I I I I KBE: I aO' I IType of Well Well Desiqn Formation Markers: (all depths adjusted for Nordic RKB) Producer Horizontal Multilateral - Pre-Packed Screen Formation Tops True Vertical True Vertical Measured Hole Angle Depth (SS) Depth (RKB) Depth (RKB) Degrees Primary Wellbore and B-Sand Lateral Base Permafrost 1533 1634 1642 15 Ugnu C-Sand 2943 3044 3575 52 U§nu B-Sand 3204 3305 4000 52 Ugnu A-Sand 3275 3376 4115 52 K-13 Shale 3417 3518 4346 52 West Sak D-Sand 3577 3677 4611 57 West Sak C-Shale 3616 3717 4694 65 West Sak B-Sand 3642 3743 4772 75 West Sak B-Sand Heel 3660 3761 4867 86 West Sak B-Sand Toe TD 3593 3694 7355 92 Casing/Tubing Program: (all depths adjusted for Nordic RKB) Hole Size Csg/Tbg Wt/Ft Grade Conn. Length Top Btm OD MD/TVD MD/TVD 9-7/8" 7-5/8" x 7" 29.7 / L-80 BTC - Mod 4,867' Surface 4,867' / 3,761' 26 6" Lower 4" Screen 9.5 L-80 HSLHT 4,867'/3,761' 7,355'/3,694' Lat. Logging/Formation Evaluation Program: IOpen Hole Cased Hole Logs: MWD/GR/RES/PWD (Pressure while Drilling) None Drilling Fluid Type 9-7/8" Surface Hole will be drilled with a standard Bentonite Slurry. 6" Production Hole will be drilled with a 6% KCL Drill'N Fluid. Drilling Fluid Properties: Spud - Base of Permafrost (+/- 1642): [nitial Final Density Viscosity YP PV 10 S Gel AP! Filtrate 8.5 250 25- 60 8- 15 10- 25 8-15 9.4- 9.6* 250 25- 60 11- 22 10- 25 6- 8 Base of Permafrost - TD of Surface Interval (+/- 4867): Density Viscosity YP Tnitial 9.4 - 9.6* 200 - 250 25 - 60 Final 9.4 - 9.6* 250 - 250 25 - 60 * 9.8 ppg if hydrates are found Production Interval (B-Sand Horizontal Lateral): Density 9.1 HTHP < 10 Viscosity YP PV 40- 55 22 - 27 8- 14 Chlorides LGS 27 - 32K 12 ppb (drilled LGS) P_gV 11 - 22 11 - 22 tau0 4- 7 10 S Gel 10 - 25 10 - 25 8.0 - 8.5 Drilling Fluid System: Tandem Geolograph / Swaco Shale Shakers Mud Cleaner Degassers Pit Volume Totalizer (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. APl Filtrate 6-8 5-7 APT Filtrate 4-6 12 200 MASP (Maximum Anticipated Surface Pressure): Only one string of surface casing is planned for the West Sak 1D-102 well. Therefore, the surface hole to be drilled from surface through the West Sak Reservoir will be drilled using a diverter system only for well control purposes. Based on actual well test data from the nearby WS1-01 well, expected reservoir pressures in the West Sak sands in the 1D pad area vary from 0.43 to 0.46 psi/ftc, or 8.2 to 8.8 ppg EHW (equivalent mud weight), depending on the TVD of the sand layer being evaluated. Assuming a 100 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.4 ppg can be predicted as a maximum mud weight required to safely drill this formation. Experience in the area has proven that these zones can be safely drilled using a diverter system only for well control purposes. The rig diverter system will be filled with water or mud and function tested prior to spudding the well. Calculating HASP based on the highest recorded reservoir pressure from the WS:[-01 well, and assuming a gas gradient of 0.1:[ psi/ft from maximum TVD in the B-Sand to surface, the following MASP can be computed' HASP = (3765 ft)(0.46 - 0.11 psi/ft) = :[3:[8 psi Based on this calculation for HASP, it will only be necessary to test the BOP equipment to a maximum of 3,000 psi. Following the cementing of the 7-5/8" x 7" surface casing in this well, the BOP stack will be installed and tested to 3,000 psi. The well will then be cleaned out and the casing will be pressure tested for 30 minutes at a pressure of :[,500 psi. The 7" 26" Sperry Preformed Window has a maximum burst rating of 2,500 psi; 70 % of this burst rating is :[,750 psi. Drillinq Area Risks: Drilling risks in the West Sak :[D-:[02 area are primarily limited to hydrates, lost circulation and potential borehole instability in and below the permafrost formation. Hydrate risks will be minimized by the use of sufficient mud weights to allow for tripping of the pipe, controlling drilling rates and optimum rheological properties to safely appropriate gas breakout. Lost circulation will be addressed with lost circulation material (LCH) and reduced circulating rates as needed. Based on previous Drill Site :[D drilling results, 9.8 ppg mud should be more than adequate to control both the Ugnu and West Sak formation pressures without resulting in lost circulation. ARCO has drilled through the West Sak formation many times in nearby wells. For this reason, AA][ requests that the requirements listed in 20 AAC 25.033 (e) and 20 AAC 25.061 (a) (pertaining to predicted overpressured strata and seismic refraction / reflection analysis, respectively) be waived for the drilling of West Sak :LD-:[38. Well Proximity Risks: The nearest existing well to 1D-102 is 1D-14. The wells are 30.37' from each other at a depth of 304' HD. Annular Pumpinq Activities: Incidental fluids generated from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface / production casing annulus of a permitted existing well on DS-:[D. That annulus will be left with a non- freezing fluid during any extended shut down (> 4 hr) in pumping operations. The West Sak 1D-:[02 surface casing / production tubing annulus will be filled with diesel and / or non-freezing brine after running the ESP completion and prior to the drilling rig moving off of the well. West Sak Procedure 1D-102 Horizontal Multilateral- Producer AFC # AK0074 i'll'lAY 12 2000 Cementing Program: Hole Category Casing Volume Type of Cement Properties Size/Depth Surface 7-5/8" x 7" 20 bbls Arco Pre-flush Density 8.40 ppg 50 bbls Mudpush XL Density 10.2 ppg 370 bbls Lead Slurry (ASLite) Density 10.7 ppg (468 sacks) Class 'G' Cement 50.00% D124 Yield 4.43 ft3/sk 9.000% D044 0.400% D046 30.00% D053 1.500% S001 1.S00% D079 66 bbls Tail Slurry Density 15.8 ppg (316 sacks) Class 'G' Cement 0.200% D046 Yield 1.17 ft3/sk 0.300% D065 0.400% D167 0.500% S001 Upper Lateral 4 1/2' 20 bbls Arco Pre-flush Density 8.40 ppg Bonzai 20 bbls Mudpush XL Density 13.0 ppg 15 bbls Class 'G' Cement Density 17.0 ppg 0.200% D046 1.000% D065 Yield 1.17 ft3/sk 0.100% D167 0.750% S001 Contacts: AAI Drilling Drilling Manager Kuparuk Drlg Team Leader Kuparuk Drlg Engr Supervisor Operations Drlg Engr West Sak Drlg Team Leader Kuparuk Asset Contacts O/A Engineer Geologist Drill Site Engineer Office Home Pager Mike Zanghi 265-6206 345-2679 275-7901 Randy Thomas 265-6830 243-4336 275-4773 Chip Alvord 265-6120 345-6407 275-4709 Mark Chambers 265-1319 345-8112 275-4726 Tom McKay 265-6890 522-9218 275-4704 Jordan Wiess 263-4370 Mike Werner 265-6191 Cliff Crabbtree 659-7493 Mark Chambers ver. 1 Page 5 05/12/00 Drill, Case and Completion Plan for West Sak 1D-102 Multilateral Producer General Procedure (Primary Well Bore): 1. Excavate cellar, install cellar box, set and cement 13-3/8" conductor to +/- 110' RKB. landing ring on conductor. Weld 2. Hove in / rig up Nordic 3. ]:nstall diverter & function test same. 3. Spud and directionally drill 9-7/8" hole to the casing point at 4,867' MD / 3,761' TVD as per directional plan. Run HWD, LWD and PWD tools as required for directional monitoring and formation data gathering. 4. Condition hole for casing. 5. Run, orient and cement 7-5/8", 29.7#, L-80, BTC Hod x 7", 26#, L-80, BTC Mod Casing String to surface. Displace cement with mud and perform stage job or top job if required. 7-5/8" Port Collar to be installed @ +/- 1,000' TVD. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface in a one stage job. Adequate excess cement will be pumped to ensure cement reaches the surface during the cement job. 6. Nipple down diverter, nipple up BOP's. Test BOP's. Notify AOGCC 24 hours before test 7. PU 6" PDC Bit and Directional BHA. R]:H to top of float equipment. 8. Pressure test casing to 3000 psi for 30 minutes. Record test results. 9. Drill out cement and approximately 20' of new hole. Perform F]:T not to exceed 11 ppg EIVlW and record results. This establishes a maximum allowable drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the F:[T or LOT EMW). 10. Directionally drill 6" hole to TD at +/- 7,355' MD / 3,694' TVD as per directional plan. 11. Circulate and condition hole to run liner. 12. Lay down MWD, LWD and PWD tools. 13. Displace mud with clean filtered brine and spot viscosified brine in open hole. 14. Perform casing clean-up including Caustic SL Wash and pickle. 15. Run 4-1/2" x 4" Liner with pre-packed screen (run liner with 2-7/8" inner wash string). 16. Land liner, set liner top packer and displace viscosified brine with clean filtered brine. Spot 8% Formic Acid through the screen while POOH. 17. Displace the well, above the liner top packer, with clean filtered brine. 1 D-102 West Sak Producer Multi Lateral w/Pre-Packed Screen Planned Completion - Phase 1 13-3/8" 68# L-80 BTC Conductor @ 80' Production Casing 7-5/8" 29.7# L-80 BTC Mod RMLS to surface KOP (~ 4469' ME) / 3593' TVD Production Casing 7" 26# L-80 BTC Mod TD to RMLS Casing Point @ 4.867' MD / 3761' TVD v'iAY '12 200G 7-5/8" 29.7# L-80 LTC Mod or BTC Mod Casing as required from TAM Port Collar to Surface. TAM 7-5/8" Port Collar BTC Mod Box x Pin set @ +/- 1000' TVD 7-5/8" 29.7# L-80 BTC Mod Casing as required from Orienting Crossover to TAM Port Collar. Sperry RMLS System Sperry Orienting Crossover 7-5/8" 29.7# BTC Box x 7" 29# BTC Pin w/Orienting Integral Profile. Sperry Casing Alignment Sub 7" 29# BTC Box x Pin 4 Joints 7# 26# L-80 BTC Mod Casing. Sperry RMLS Window Joint 7" 29# L-80 BTC w/Aluminum External Sleeve and Latch Coupling. 7" 26# L-80 BTC Mod Casing as required from Landing Collar to Latch Coupling. Sperry Float / Landing Collar 7" 29# L-80 BTC Box x Pin. 2 Joints 7# 26# L-80 BTC Mod Casing. Sperry Float Shoe 7" 29# L-80 BTC Box Up. MAC 05/10/00 1 D-102 West Sak Producer Multi Lateral w/Pre-Packed Screen Planned Completion - Phase 2 13-3/8" 68# L-80 BTC Conductor @ 80' TAM 7-5/8" Port Collar BTC Mod Box x Pin set @ +/- 1000' TVD Production Casing 7-5/8" 29.7# L-80 BTC Mod RMLS to surface K.OP @ 44.69' MD / 3593' TVD Production Casing 7" 26# L-80 BTC Mod TD to RMLS 7" Casing Point @ 4,867' MD / 3761' TVD Lower Lateral Completion (Run w/2-7/8" Hyd 511 Inner Wash Strinq) Baker SC-1R '70B-40' Single Bore - Rotationally Locked, Liner Top Packer (6.0" Max OD, 4" Min ID) w/5-1/2" HSLHT Box Down. Baker 6' Extension w/5-1/2" HSLHT Pin x Pin Crossover Sub w/5-1/2" HSLHT Box x 4-1/2" HSLHT Pin. 1 Joint 4-1/2" 12.6# L-80 Blank Pipe w/HSLHT Connections. Baker 4-1/2" Model 'CMD' Sliding Sleeve Assembly w/3.43" ID and 4-1/2" HSLHT Box x Pin. 1 Joint 4-1/2" 12.6# L-80 Blank Pipe w/HSLHT Connections. Crossover Sub w/4-1/2" HSLHT Box x 4" HSLHT Pin. 2 Joints 4" 9.5# L-80 Blank Pipe w/HSLHT Connections. 4" x 4-1/2" Bakerweld 140 Prepack Screens (20 Gauge Screen, 16-20 Resin Coated Gravel Prepack) w/HSLHT Connections as required from 'GPV' Set Shoe Assembly to Model 'CMD' Sliding Sleeve. 4" 9.5# L-80 Blank Pipe w/HSLHT Connections as required from 'GPV' Set Shoe Assembly to Model 'CMD' Sliding Sleeve. Plan to alternate Prepack Screen and Blank Pipe throu.qh production interval. 2 Joints 4" 9.5# L-80 Blank Pipe w/HSLHT Connections. Baker Model 'GPV' Set Shoe Assembly (5.560" Max OD). Assembly Includes Shoe, 5" Blank Pipe Above Shoe and Crossover Back to 4" Blank Pipe. TD B-Sand Lateral @ +/- 7,355' MAC 05/10/00 16" DI =.RTER SCHEMATIC- "ordic Rig 3 KUPARUK RIVER UNIT WEST SAK OPERATIONS 1 o" 15O ANSI Blanked L, J Open I Closed ~" '~ ~L _ Closed __.~ 3" Ball Valve Blanked ~- To Accumulator I ~_ .... From Accumulator Open Maintenance & Operation 1. Upon initial installation: Close valve and fill preventer with water to ensure no leaks Close preventer to verify operation and that the valve opens immediately . Close annular preventer in the event that an influx of wellbore fluids or gas is detected. Open valve to achieve diversion DO NOT SHUT-IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES 1. 13-3/8" Conductor 2. 13-3/8" x 16" 3000 psi Slip-on Weld Starting Head (Quick Connect) - Vetco Gray 3. 16" x 13-5/8" 3000 psi Quick Disconnect - Vetco Gray 4. 13-5/8" 3000 psi x 21-1/4" 2000 psi, Single-Studded Adapter Flange - DSR 5. Diverter Spool with APl 21-1/4" 2000 psi Flanges and 16" Outlet- Nordic 6. 21-1/4" 2000 psi x 13-5/8 5000 psi Double Studded Adapter Flange - Nordic 7. 13-5/8 Hydril GK 5000 psi Annular Preventer - Nordic 8. 16" Knife Valve. The valve opens automatically upon closure of annular preventer - Nordic 9. 16" Diverter Line - Nordic MAC 3/7/OO -"11" 5000 psi BOP Kuparuk River Unit West Sak Operations - Producer Wells 12 L, ~ 6 4 Accumulator Capacity Test 1. Check and fill accumulator reservoir to proper level with hydraulic fluid. 2. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. 3. Observe time, then close all units simultaneously and record the time and pressure remaining after all units are closed with the charging pump off. 4. Record on the IADC report. The acceptable lower limit is 45 seconds closing time and 1200 psi remaining pressure. BOP Stack Test 1. 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, chokes, and bypass valves on the manifold. All others open. 4. Test all components to 250 psi and hold for 3 minutes. Increase pressure to 3000 psi and hold for 3 minutes. Bleed back to zero psi. 5. Open annular preventer and manual kill and choke line valves. 6. Close top pipe rams and HCR valves on kill and choke lines 7. Test to 250 psi and 3000 psi as in step 4. Continue testing all valves, lines, and chokes with a 250 psi Iow and 3000 psi high. Test as in step 4. Do not pressure test any choke that is not a full closing positive seal choke. 8. Open top pipe rams and close bottom pipe rams. Test bottom rams to 250 psi and 3000 psi for 3 minutes. 9. Open pipe rams. Back off running joint and pull out of hole. Close blind rams and test to 3000 psi for 3 minutes. Bleed to zero psi. 10. Open blind rams and recover test plug. Make sure manifold and lines are full of arctic diesel and all valves are set in the drilling position. 11. Test standpipe valves to 3000 psi for 3 minutes. 12. Test kelly cocks and inside BOP to 3000 psi with Koomey pump. 13. Record test information on blowout preventer test form. Sign and send to drilling supervisor. 14. Perform BOPE test once per week and functionally operate BOPE daily. 1. 13-3/8" Landing Ring 2. 11" 5000 psi Horizontal Tubing Head 3. 11" 5000 psi Pipe Rams 4. 11" 5000 psi Drilling Spool with Choke and Kill Lines 5. 11" 5000 psi Double Ram with Pipe Rams on Top and Blind Rams on Bottom 6. 11" 5000 psi Annular Preventer MAC 3/15/00 Kuparuk River Unit Operations TAM Port Collar Utilization Decision Tree Cement / above Port / Collar / (1000' TVD)/ Perform Top Job as per requirements of AOGCC Nipple Up and Test BOP's Continue with Completion Begin Primary One Stage Cement Job I to Surface Cement below Port Collar (1000' TVD), If Top Job is ineffective or unacceptable to AOGCC Open Port Collar using drillpipe Circulate Cement to Surface and close Port Collar Cement to Surface Nipple Up and Test BOP's Continue with Completion Indicators of Cement Top 1. Observation of Tracers in Spacer ahead of lead cement 2. Calculated Displacement 3. Displacement Pressures during Primary Cement Job 4. Other indications that cement is near surface Nipple Up and Test BOP's Continue with Completion .,.';/,'.,Y '12 200 ,, Port Collar Cementinq Practices · · We will run a TAM Port Collar (see below for running details). · Circulate with casing on bottom at 10 bpm or greater if possible without losing returns. Equipment for the stage job consists of: · TAM Port collar · TAM Combo tool · TAM Choke Ensure that all connections are compatible or that there are appropriate crossovers available. If needed, TAM personnel can be available on site to check the equipment and confirm shear pin settings with prior notice. Run and cement with the Port Collar as follows: I. Check that all materials are at the rig site ·7 5/8" TAM Combo Tool, with 3-1/2" EUE Box by Pin and 7 5/8" 29.7 ppf Packer Cups · 7 5/8" TAM Port Collar with 7 5/8" BTCM Box x Pin Connections · Choke Sub with 3-1/2" EUE Box by Pin, pinned with 5 pins for 2225 psi shear. Uses 1.25 setting ball · All appropriate crossovers II. Ensure that all connections are compatible or there are appropriate crossovers available III. Pick up and run 7 5/8" 29.7 ppf casing with Port Collar placed at 1000' TVD. Note: If packing off problems were seen around this depth when drilling or tripping, consult with the Drilling Engineer. · Install centralizers in the center of the joints above and below the port collar. IV. Pump first stage of cement job (spacer, lead and tail) as specified in Drilling Plan. Pump until the plug bumps and pressure up to 500 psi above circulating pressure to insure the plug has landed. If floats do not hold, maintain 1500 psi on casing for a minimum of 4 hours before rechecking. V. If cement is not returned to surface, a top job or use of the pod collar will be required. The Arco company representative should review the attached decision tree is order to determine which method should be used. · Do top job using 1" tubing if good lead slurry cement did not circulate to surface. Run 1" tubing and tag top of previous cement job. If tubing does not tag, run it as deep as possible and contact the Arco drilling engineer or engineer on call to discuss options. Circulate while RIH to keep tubing from packing off. Flush annulus with water, then circulate annulus to cement. · AOGCC and Arco drilling engineer (or engineer on call) must be contacted prior to beginning top iob. Do not proceed with top iob without AOGCC approval. VI. If the Arco company representative determines that it is necessary to use the Pod Collar, run in the hole with the 4" drillpipe until the Combo Tool dogs engage the profile in the Port Collar. Workstring should be run in hole as quickly as possible to reduce chances of cement setting up. Port Collar Practices 1 TAB, 05/11/00, v.1 · In order to trip in with the 4" drillpipe and open the Port Collar, it is necessary to land the casing in the hanger as planned. Landing the casing above the hanger, and thus off the rig floor, would create a situation where the Port Collar could not be used. · Laying down the landing joint prior to using the Port Collar is preferred, as opposed to rigging up a false rotary table, which could take a couple of hours. In the meantime, cement could be setting up above or adjacent to the Port Collar. VII. Drop 1.25" setting ball and circulate to seat. Pressure up on workstring to 1000 psi to test Combo Tool. Bleed off workstring pressure VIII.Open Port Collar by bumping down on workstring with 10,000 to 15,000 lbs. IX. Establish circulation rate and pressure X. Cement casing as required to ensure visual confirmation that cement is at the surface · Slightly overdisplace the cement job so no cement remains in the workstring or casing Xl. While holding pressure on workstring, bump up with 10,000 to 15,000 lbs. to close Port Collar XlI. Pressure up on workstring to confirm collar is closed XIII.With workstring at neutral, slowly pick up while rotating to the right to release from the Port Collar XlV. Run in 1 joint of tubing. Pressure up on workstring to 2225 psi to expel the ball choke in Choke Sub XV. Reverse out excess cement as required XVI. Pull out of hole with tools Port Collar Practices 2 TAB, 05/11/00, v. 1 Greater Kuparuk Area Casing Pressure Test Standard Draft 4 The AOGCC requires a 30 minute casing pressure test prior to drilling out the float equipment. Current AOGCC regulations require surface casings to be tested to 1500 psi or 0.25 psi/fi, whichever is greater. This test needs to be charted for the AOGCC. Send the chart to the AAI Drilling Engineer assigned to the rig along with the other rig mail. Casing Test Procedure Pressure test the surface casing to the value specified in the well plan, above and below the stage collar, if one has been run. Hold each of these tests for 10 minutes to insure the stage collar is completely closed. The AOGCC does not require this test to be charted. Check the well plan for any site specific drill out details. 2. Run in hole to top of baffle plate or float collar, whichever occurs first. Establish circulation and insure well is stable for the 30 minute test. Pressure test surface casing to the value outlined in the well plan for 30 minutes. This test needs to be charted for the AOGCC. Pressure vs. volume needs to be plotted for AAI records and as a minimum volume line for the upcoming LOT/FIT. Run the rig pump at 0.5 BPM (maintain a steady pump rate). Record the pump pressure every two pump strokes until the pressure specified in the well plan is reached (this will insure enough data points on the LOT/FIT). Monitor shut in casing pressure for 30 minutes. Make sure test is being accurately recorded on a chart. Check surface equipment for leaks if pressure drops more than 10 percent in 30 minutes. If surface leaks are discovered repair them and do the casing test over. If no surface leaks are found and casing pressure continues to bleed off contact, the AAI Drilling Engineer assigned to the rig, prior to drilling out the casing float equipment. Contact the Drilling Team Leader if the Drilling Engineer can't be reached. 4. After achieving a successful casing test. Drill out remaining cement and all float equipment. Clean out any existing rat hole. Drill 20 feet of new hole. Perform a LOT/FITper the standard procedure that follows. RLM 7/31/98 Greater Kuparuk Area Leak-Off Test Standard Draft 4 '" There are several reasons for performing the Leak Off Test at the surface casing shoe, to determine maximum mud weights and maximum allowable shut in pressures are two of these reasons. In the Greater Kuparuk Area it has been decided that the LOT at the shoe would not exceed a 16 ppg EMW. This 16 ppg EMW ~low:, tt~nuu~L AGO, CC for aiini:lar ir. je~ exceeds any known required mud weights to control the reservoir pressure. n,~'m, cases the AOGCC--..m~ requir~an additional LOT that goes to break down. Check the well plan or with the AAI drilling engineer assigned to the rig to determine if a second test is required and if so, how much additional hole needs to be drilled prior to performing the test. If a second test is required to satisfy the AOGCC do not exceed the 16 ppg EMW at the shoe prior to consulting the AAI Drilling Engineer assigned to the rig. Contact the project Team Leader if the Engineer can't be reached. Previous tests above 16 ppg EMW at the shoe have damaged the casing cement job. Leak-Off Test Procedure Having completed a successful casing test and drilling 20 feet of new hole, proceed as follows. 1. The upper limit of the test will not exceed 16 ppg EMW at the casing shoe without prior consent fi'om the AAI Drilling Engineer assigned to the rig. Contact the Drilling Team Leader if the Drilling Engineer can't be reached. 2. Circulate and condition the well with the mud you plan to drill ahead with. Circulate until mud weights in and out are within 0.1 ppg of one another and viscosity's are within 2-3 seconds. 3. Pull bit into casing shoe and close the annular preventer or pipe rams. 4. Determine the surface pressure required to obtain 16 ppg EMW at the shoe with the weight of mud in use. 5. The AOGCC requires this test to be charted. Make sure chart recorder is working and ready. Send chart to the AAI Engineer assigned to the rig along with the other rig mail. Run the rig pump at 0.5 BPM (maintain a steady pump rate). Record pump pressure every two pump strokes until the formation breaks down or the 16 ppg EMW is reached. Do not exceed 16 ppg EMW. If the well breaks down prior to reaching the 16 ppg EMW continue pumping an additional three bbls of mud prior to shutting down the pumps, to satisfy AOGCC requirements. Record the breakdown pressure and record the bleed off pressures at one minute intervals for a minimum of 10 minutes. The AOGCC suggests that a good test will have a stabilized pressure for 10 minutes (this may be incorporated into the new regulations). If pressures have not stabilized after holding the test for 15 minutes total, check for surface leaks. If surface leaks are discovered repair them and do the test over. Bleed back mud from the well and compare with volume pumped on the test. Contact the AAI Drilling Engineer assigned to the rig if the LOT is below the minimum outlined in the well plan, prior to drilling ahead. Contact the Drilling Team Leader if the Drilling Engineer can't be reached. 9. Plot the casing and leak-off tests on the most current excel spreadsheet and forward to the office. RLM 7/31/98 Greater Kuparuk Area Formation Integrity Test Standard Draft 4 Some wells do not need to go to full leak-off. In those cases, a Formation Integrity Test will be performed. For instance, if it is known that the Kuparuk formation will be top set, a Formation Integrity Test is all that is necessary. Consult with the AAI Drilling Engineer assigned to the rig if it is unclear whether you need to do a Leak-Off Test or a Formation Integrity Test. Formation Integrity Test Procedure Having completed a successful casing test and drilling 20 feet of new hole, proceed as follows. 1. Circulate and condition the well with the mud you plan to drill ahead with. Circulate until mud weights in and out are within 0.1 ppg of one another and viscosity's are within 2-3 seconds. 2. Pull bit into casing shoe and close the annular preventer or pipe rams. 3. Determine the surface pressure required to obtain the desired EMW at the shoe. 4. This test needs to be charted. Make sure the chart recorder is working and ready. Send the chart to the AAI Drilling Engineer assigned to the rig along with the other rig mail. Run the rig pump at 0.5 BPM (maintain a steady pump rate). Record pump pressure every two pump strokes until the desired surface pressure is reached. Record the initial shut in pressure and record the pressure at one minute intervals for a minimum of 10 minutes. If pressure is bleeding off check for surface leaks. If surface leaks are discovered repair them and do the test over. 6. Bleed mud back from the well and compare with volume pumped on the test. 7. Contact the AAI Drilling Engineer assigned to the rig if the well breaks down before reaching the desired EMW, prior to drilling ahead. Contact the Drilling Team Leader if the Engineer can't be reached. 8. Plot the casing and formation integrity tests on the most current excel spreadsheet and forward to the office. RLM 7/31/98 Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone: 907-276-1215 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY May 12, 2000 Mr. Blair E. Wondzell, P.E. Senior Petroleum Engineer State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Permit(s) to drill first West Sak Multi-lateral well 1 D-102 Dear Blair, Attached please find the two permits to drill for the first West Sak multi-lateral well 1 D-102. The well will consist of two horizontal laterals, one each in the B and D sands of the West Sak sands. We have permitted the main trunk and initial (lower) horizontal lateral as the primary wellbore. The upper horizontal lateral has been separately permitted as sidetrack 1D-102a. At your convenience, we'd like to discuss the possibility of streamlining the permitting process of these multi-lateral wells. We'd like to suggest including an individual form 10-401 for each particular lateral accessing an individual sand and a single package describing the well in full (casing/completion design, drilling fluids, well control, drilling hazards, etc.) Please call me at 265-6120 if you have any questions regarding this request. Graham L. (Chip) Alvord Kuparuk Drilling Engineering Supervisor ARCO Alaska, Inc. Drilling Attachments: Permit to drill 1D-102 (main trunk wellbore and initial lateral) Permit to drill D-102a (upper lateral) MAY 12 200( , 0il & Gas Co~:~. C0mm~ssion ~P~~:.~ [ North Slope Alaska Alaska State Plane 4 __ 800 - 2400 - C~ II ~- 3200 - 0 Vertical Section jBegin Dir @ 2.000°/100ft· 275.00ft MD, 275.00ft TVD nd Dir' 57'5 4 ~egin Eiir @ '20.%f~b~ :'~5.~MD, 634.12ft TVD ~,~ ~en~inDi~ir9~5'2~.(~l~0/~b~t3:'~.~MD, 993.58ft TVD ~lncrease in Dir Rate @ 3.000°/100ft· 1295.00ft MD, 1293.03ft TVD n End Dir: 1595.00ft MD, 1587.70ft TVD ~ Dir @ 5.000°/100ft: 1802.06ft MD, 1787.70ft TVD .84ft TVD '%~,. /Top 37' Window Joint I I I 0 800 1600 Section Azimuth: 160.431° (True North) Kuparuk 1D DrillQuest .... 1 D-102 WPs ............ '~'~'~ ' 3600 - II ~ 4000 - ST Exit @ 12.000°/100ft, 0.000° TF: 4468.50ft MD, 3593.09fl TVD Increase in Dir Rate @ 14.000°/100ft: 4498.50ft MD, 3610.76ft TVD / End Dir: 4658.50ft MD~ 3673.42ft TVD / /. Begin Di, @E~c~reO~3a;e/li0n0D~i; ~7at0e5.&51f10M0%~)3o~1?J(~f148T¥0D. 96ft MD 3705.00ft TVD Begin [~irn2Di0r. 0 6OOi¢1.0201ffft:l~)7.~6250~6 1M8Dff,¢~C)7.72ft TVD // _ End Dir: 5055.36ft MD 3705.94ft TVD' -- ~ : ' ' ' ~Total Depth · 7358 80ft MD 3635 00ft TVD ..._ / / / / ' _Begin DiJ' @ 4.000°/100ft: 5547.92ft MD, 3686.22fl TVD / / ~ .... 1D-lO2 T3 ...~ ~ ~ 1D ~02 r~ ID-lO2 T2 ~ ~ ~ ~:~ ~ ] /-'"~'"--~-~-~ ,~.~ ._~ o~ ' ~ ~ Total Depth: 7354.86ft MD, 3694.00ft TVD I / ~'~ %- - ~ ~ .End~.Dir: 5636.78ft MD, 3741.98ft TVD ~x End Dir: 6624.12ft MD, 3715.80ft TVD / / ~ % EndDir'S05490ftMD 37640OftTVDc~eg ..... @4-000°/100ft:5605.16ftMD,3743.00ftTVD --Begin Dir @ 4.000°/lO0ft:6617.16ftMD, 3716.00ftTVD I \ ' Decrease in Dir Rate @ :10.0i)~°/100ft: ~866.~)9ft MD, 3761.00ft TVD [~ ~4'. ~l~n~r,,e, yzi? Dir Rate @ 12.503°/100ft: 4653.99ft MD, 3699.20ft TVD Bridge Plug Set Begin Dir @ 10.000°/100ft: 4509.09ft MD, 3618.03ft TVD Bottom 37' Window Joint Top 37' Window Joint I I I I I I I I 2000 2400 2800 3200 3600 4000 4400 4800 Scale: linch = 400ft Vertical Section Section Azimuth: 160.431 o (True North) DnllQue,..t North Slope Alaska Alaska State Plane 4~cale: linch = 600ft Kuparuk 1 D -6oo 0 1 D-102 WPs I O__ -600 -- -1200 - -1800 - -2400 -- -3000 -- -600 -3600 -- -4200 - Eastings 600 1200 I Begin Dir @ 2.000°/10011: 275.0011 MD, 275.00ft TVD End Dir: 575.00ft MD, 574.45ft TVD Begin Dir @ 2.000°/10011: 635.0011 MD, 634.12R TVD End Dir: 935.00ft MD, 933.58ft TVD Begin Dir @ 2.000°/10Oft: 995.00ft MD, 993.58ft TVD Increase in Dir Rate @ 3.000°/10011:1295.0011 MD, 1293.03ff TVD End Dir: 1595.0011 MD, 1587.7011 TVD Begin Dir @ 5.000°/10011:1802.06ft MD, 1787.7011 TVD Dir: 2599.8011 MD, 2444.8411 TVD Top 37' Window Joint Bottom 37' Window Joint Begin Dir @ 10.000°/100ft: 4509.0911 MD, 3618.0311 TVD Bridge Plug Set increase in Dir Rate @ 12.503°/10011: 4653.9911 MD, 3699.20ft TVD Decrease in Dir Rate @ 10.000°/10011: 4866.9911 MD, 3761.00ft TVD End Dir: 5054.9011 MD, 3764.0011 TVD Total Depth: 7354.86ft MD, 3694.00fl TVD I I 0 600 1800 I Scale: linch = 600ft Eastings ST Exit @ 12.000°110011, 0.000° TF: 4468.5( Increase in Dir Rate @ 14.0000/100ft: 44 4658.50ft MD, 3673.42ft TV[ /Begin Dir @ 12.003°/100ft: 4705.951 Decrease in Dir Rate @ 10.0( 1D-lO2 T1 End Dir: 5055.36ft MD, 3705.94 ID-lO2 T2 Begin Dir @ 4.00 End Dir: 5674.34 Dir @ 0.000°/10011: 61 1D-lO2 T3 End Dir: 6674.21ft MD, 36," ID-lO2 T4 Total Depth: 7358.80fl I I 1200 1800 Reference is True North --0 -- -600 - -1200 t MD, 3593.09ft TVD ~8.50ft MD, 3610.76ft TVD MD, 3683.36ft TVD - -1800 0°/100fl: 4870.96fl MD, 3705.001t TVD TVD f- O --2400 Z )°/100ft: 5547.92ft MD, 3686.22ft TVD MD, 3684.04ft TVD - -3000 ;72.2011 MD, 3657.72ft TVD - -3600 6.18ft TVD --4200 ~o II MD, 3635.00ff TVD~ Sperry-Sun Drilling Services Proposal Report for 1D- 102 WPs - 1D- 102 Wp3 Revised: 24 April, 2000 North Slope Alaska Measured Depth Incl. Azim. (fi) 0.00 0.000 0.000 101.00 0.000 0.000 200.00 0.000 0.000 275.00 0.000 0.000 Sub-Sea Vertical Depth Depth (ft) (ft) -101.00 0.00 0.00 101.00 99.00 200.00 174.00 275.00 300.00 0.500 230.000 199.00 300.00 400.00 2.500 230.000 298.96 399.96 500.00 4.500 230.000 398.77 499.77 575.00 6.000 230.000 473.45 574.45 600.00 6.000 635.00 6.000 700.00 4.700 800.00 2.700 900.00 0.700 935.00 0.000 995.00 0.000 1000.00 0.100 1100.00 2.100 1200.00 4.100 1295.00 6.000 1300.00 6.150 Local Coordinates Glob~ Northings Eastings Northin¢ (ft) (ft) (ft) 0.00 N 0.00 E 0.00 N 0.00 E .3.87 0.00 N 0.00 E 1.87 0.00 N 0.00 E 0.07 S 1.75 S 5.68 S L14 10.09 S 5959833.69 230.000 498.32 599.32 230.000 533.12 634.12 230.000 597.84 698.84 230.000 697.63 798.63 230.000 797.58 898.58~ 2~~ 0.000 832.58 9~;5~;~ 24.21 S 0.000 892.58 ¢~' ~;~ ..... 24.21 S 170.000 897.58 .~. 58%, 24.21 S 170.000 997.55 ~~~5 '~ 26.10 S ~f .... ~ .... .. ~. ~, 170.000 1097.40~,~** ~¢~ _ ~.~:~ 31.43 S 170.000 1192.~ ~'~'" '~? ~9~¢ 39.66 S 170.0~;~;~i~l~;~,,. 1298.00 40.18 S .99 5959829.62 21.47W 5959825.68 26.41W 5959821.50 28.68W 5959819.57 28.85W 5959819.43 28.85W 5959819.43 28.85W 5959819.43 28.51W 5959817.54 27.58W 5959812.22 26.12W 5959804.00 26.03W 5959803.48 1490.58 560490.58 560490.58 560490.58 560490.50 560488.51 560483.86 560478.64 560476.65 560473.87 560469.26 560464.35 560462.09 560461.93 560461.93 560461.93 560462.28 560463.26 560464.78 560464.87 Dogleg Rate (°/lOOft) 0.000 0.000 0.000 2.000 2.000 2.000 2.000 0.000 0.000 2.000 2.OOO 2.000 2.000 0.000 2.000 2.000 2.000 2.000 3.000 Alaska State Plane 4 Kuparuk 1D Vertical Section (ft) 0.00 0.00 0.00 0.00 0.04 0.98 3.17 5.63 6.56 7.88 10.05 12.36 13.43 13.50 13.50 13.51 15.40 20.75 29.00 29.53 Comment Begin Dir @ 2.000°/100ft: 275.00ft MD, 275.00ft TVD End Dir' 575.00ft MD, 574.45ft TVD BeQin Dir @ 2.000°/100ft: 635.00ft MD, 634.12ft TVD End Dir: 935.00ft MD, 933.58ft TVD Begin Dir @ 2.000°/100ft: 995.00ft MD, 993.58ft TVD Increase in Dir Rate @ 3.000°/100fl · 1295.00ft MD, 1293.03ft TVD Continued... 24 April, 2000- 13:58 - I - DrillQuest 1.05.053 Sperry-Sun Drilling Services Proposal Report for 1D- 102 WPs - 1D- 102 Wp3 Revised: 24 April, 2000 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 1400.00 9.150 170.000 1296.10 1397.10 1500.00 12.150 170.000 1394.36 1495.36 1595.00 15.000 170.000 1486.70 1587.70 1600.00 15.000 170.000 1491.53 1592.53 1800.00 15.000 170,000 1684.72 1785.72 1802.06 15.000 170.000 1686.70 1787,70 1900.00 18,997 160.246 1780.37 1881.37 2000.00 23.423 153.780 1873.58 1974.58 2100.00 28.034 149.307 1963.65 2064.65 2200.00 32.751 146.021 2049.89 2150,89 2300.00 37.535 143.487 2131.64 2232.64 2400.00 42,362 141.453 2208.29 2309.29 2500.00 47.218 139.764 2279.24 2380.24 2599.80 52.087 138.325 2343.84 2600.00 52.087 138.325 2343.96 2800.00 52.087 138.325 2466.85 3000.00 52.087 138.325 2589.74 3200.00 52.087 138.325 2712.64 3400.00 52.087 138.325 2835.53 3600.00 52.087 138.325 2958.! 3800.00 52.087 138.325 4000.00 52.087 138.32 4200.00 52.087 4390.24 52.087 4400.00 52.087 3305.21 3428.10 3545.00 3550.99 Local Coordinates Nothings Eastings (ft) (ft) (ft) 53.29S 23.72W 71.49 S 20.51W N 93.45 S 16.64W ).29 N 94.72 S 16.41 2 N 145.70 S N 146.22 S N 173.73 S ;70.15 N 206.90 S 959637.10 N 24~ N ~~ E 5959556.76 N ~.578 ~ 95.74E 5959510.08N ~38 ,~ 134.88E 5959459.54N 4~~¢'' 179.61E 5959405.50N 49~¢:~~~ 229.47 E 5959348.50 N 497.35 S 229.58 E 5959348,39 N S 334.49 E 5959231.38 N 733.06 S 439.41 E 5959114.37 N 850.92 S 544.32 E 5958997.36 N 968.78 S 649.23 E 5958880.35 N 1086.63 S 754.15 E 5958763.34 N 1204.49 S 859.06 E 5958646.34 N 1322.35 S 963.98 E 5958529.33 N 1440.20 S 1068.89 E 5958412.32 N 1552.31 S 1168.69 E 5958301.02 N 1558.06 S 1173.81 E 5958295.31 N ~gs E 560470.65 E 560474.69 E 560474.93 E 560484.33 E 560484.43 E 560492.24 E 560506.80 E 560527.89 E 560555.37 E 560589.01E 560628.56 E 560673.72 E 560724.05 E 560724.15 E 560830.01E 560935.87 E 561041.73 E 561147.59 E 561253.45 E 561359.31E 561465.17 E 561571.03 E 561671.73 E 561676.89 E Dogleg Rate (°/100ft) 3.000 3.000 3.000 0.000 0.000 0.000 5.000 5.000 5.000 5.000 5.O0O 5.000 5.000 5.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000 Alaska State Plane 4 Kuparuk 1D Vertical Section (ft) 42.67 60.93 82.95 84.23 135.36 135.88 164.36 200.37 243.13 292.30 347.51 408.35 474.34 544.84 544.98 690.56 836.14 981.72 1127.30 1272.88 1418.45 1564.03 1709.61 1848.09 1855.19 Comment End Dir: 1595.00ft MD, 1587.70ft TVD Beclin Dir @ 5.000°/100ft: 180'2.06ft MD, 1787.70ft TVD End Dir: 2599.80ft MD, 2444.84ft TVD K-13 Shale Continued... 24 April, 2000 - 13:58 - 2 - DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for 1D- 102 WPs - 1D- 102 Wp3 Revised: 24 April, 2000 North Slope Alaska Measured Sub-Sea Depth Incl. Azim. Depth (ft) ~t) 4450.00 52.087 138.325 3480.72 4487.00 52.087 138.325 3503.45 4509.09 52.087 138.325 3517.03 4600,00 56.852 147.850 3569.92 4647.00 59.581 152.352 3594.69 4653.99 60.000 153.000 3598.20 4700.00 65.598 154.491 4800.00 77.805 157.347 4866.99 86.000 159.100 4900.00 87.076 162.226 5000.00 90.374 171,670 5054.90 92.187 176.854 5200.00 92.187 176.854 5400.00 92.187 176.854 5600.00 92.187 176.854 5605.16 92.187 176.854 5636.78 91.518 177.929 5800.00 91.518 177.929 6000,00 91.518 177.92~ 6200.00 91.518 177, Vertical Local Coordinates Depth Northings Eastings (fi) Ct) (fi) 3581.72 1587.52 s 1200.03 E 3604.45 1609.33 S 1219.44 E 3618.03 1622.34 S 1231.03 E 3670.92 1681.48 S 1275.22 3695.69 1716.10 S 1295.1 3699.20 1721.47 S 1 3619.23 3720.23 1758.16 S 3650.57 3751.57 184~ 3660.00 3761.00 ~~. E ,..~ 3661.99 3762.99 ~z.33 S ~ 1390.03 E 3664.22 3765.22 2d~~¢¢' 1412.57 E 3663.00 2089.T~¢~' 1418.06 E 3657.46 2233.96 S 1426.01E 3649.83 t3,52 S 1436.98 E 3642.20 S 1447.95 E 3642.00 2638.22 S 1448.23 E 3640.! 2669.79 S 1449.67 E 2832.84 S 1455.57 E 3732.35 3032.64 S 1462.79 E 3727.05 3232.44 S 1470.02 E Glob~ Northin¢ (ft) N .49 N N N N 5958096.36 N N 5957948.79 N 5957917.80 N 5957820.71N 5957766.16 N 5957621.46 N 5957422.00 N 5957222.54 N 5957217.40 N 5957185.84 N 5957O22.84 N 5956823.10 N 5956623.37 N ~gs 703.36 E 561722.94 E .561734.63 E 561779.30 E 561799.46 E 561802.28 E 561820.65 E 561859.93 E 561885.00 E 561896.16 E 561919.49 E 561925.41E 561934.53 E 561947.11E 561959.68 E 561960.00 E 561961.70 E 561968.91E 561977.74 E 561986.57 E Dogleg Rate (°/100ft) 0.000 0.000 0.000 10.000 10.000 10.000 12.503 12.503 12.503 10.000 10.000 10.000 0.000 0.000 0.000 0.000 4.000 0.000 0.000 0.000 .~. Alaska State Plane 4 Kuparuk 1D Vertical Section Comment (ft) 1891.58 Top 37' Window Joint 1918.52 Bottom 37' Window Joint 1934.59 Beqin Dir @ 10.000°/100ft: 450'9.09ft MD, 3618.03ft TVD 2004.89 2044.10 Bridge Plug Set 2050.08 Increase in Dir Rate @ 12.503°/100ft: 4653.99ft MD, 3699.20ft TVD 2090.66 2185.04 2251.23 Decrease in Dir Rate @ 10.000°/100ft: 4866.99ft MD, 3761.00ft TVD 2284.17 2383.48 2436.89 End Dir: 5054.90ft MD, 3764.00ft TVD 2576.38 2768.64 2960.90 2965.86 Beclin Dir @ 4.000°/100ft: 560'5.16ft MD, 3743.00ft TVD 2996.18 End Dir: 5636.78ft MD, 3741.98ft TVD 3152.29 3343.57 3534.85 Continued... 24 April, 2000 - 13:58 -3- DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for 1D- 102 WPs - 1D- 102 Wp3 Revised: 24 April, 2000 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northin¢ (ft) (ft) (ft) (ft) (ft) (ft) 6400.00 91.518 177.929 3620.75 3721.75 3432.24 S 1477.24 E 595~23.63 N 6600.00 91.518 177.929 3615.45 3716.45 3632.04 S 1484.47 E 59~3.90 N 6617.16 91.518 177.929 3615.00 3716.00 3649.19 S 1485.09 E N 6624.12 91.710 178.131 3614.80 3715.80 3656.13 S 1485.33 N 6800.00 91.710 178.131 3609.56 3710.56 3831.84 S 1491 ~N 7000.00 91.710 178.131 3603.59 3704.59 4031.65 S 14~ N 7200.00 91.710 178.131 3597.62 3698.62 4231.45 S 955624.66 N 7354.86 91.710 178.131 3593.00 3694.00 4386.16 S 955470.00 N ire r~tive to True North. All data is in feet unless otherwise stated. Directions and coordi~¢s~ ~~_'~' Vertical depths are relative to 1D-102 WPs. Northings and Eas~,are re ~ive to 1D-102 WPs. The Dogleg Severity is in Degrees per 100ft. Vertical Section is from 1 D-102 WPs and of 161.01 3° (True). Based upon Minimum Curvature type The Bottom Hole Displacement is Depth of 7354.86ft., of 161.01 3° (True). ~gs E 562004.24 E 562005.00 E 562O05.30 E 562012.45 E 562020.58 E 562028.71E 562035.00 E Dogleg Rate (°/100ft) 0.000 0.000 0.000 4.000 0.000 0.000 0.000 0.000 Alaska State Plane 4 Kuparuk 1D Vertical Section (ft) 3726.13 3917.41 3933.82 394O.47 4108.49 4299.54 4490.60 4638.53 Comment Begin Dir @ 4.000°/100ft: 66fT.16ft MD, 3716.00ft TVD End Dir' 6624.12ft MD, 3715.80ft TVD Total Depth: 7354.86ft MD, 3694.00ft TVD Target - 1 D-102 B T4 Continued... 24 April, 2000- 13:58 -4 - DrillQuest 1.05.05a Sperry-Sun Drilling Services Proposal Report for 1D-102 WPs - 1D-102 Wp3 Revised: 24 April, 2000 North Slope Alaska Alaska State Plane 4 Kuparuk 1D Comments Measured Depth TVD Ct) (ft) 275.00 275.00 575.00 574.45 635.00 634.12 935.00 933.58 995.00 993.58 1295.00 1293.03 1595.00 1587.70 1802.06 1787.71 2599.80 2444.83 4450.00 3581.72 4487.00 3604.45 4509.09 3618.03 4647.00 3695.69 4653.99 3699.20 4866.99 3761.00 5054.90 3764.00 5605.16 3743.00 5636.78 3741.98 6617.16 3716.00 6624.12 3715.80 7354.86 3694.00 Station Coordinates Northings (ft) 0.00 N 10.09 S 14.12 S 24.21 S 24.21 S 39.66 S 93.45 S 146.22 S 497.23 S 1587.52 S 16O9.33 S 1622.34 S 1716.10 S 1721.47 S 1906.24 S 2089.19 S 2638.22 S 2669.79 Eastings Comment (ft) 0.00 E Begin Dir @ 2.000°/100ft: L00ft TVD 12.02 W End Dir: 575.00ft MD, 16.83 W Begin Dir @ 2.000°/10 2ft TVD 28.85 W End Dir: 935.00ft 28.85 W Begin Dir @ VID, 993.58ft TVD 26.12 W Increase in Di : 1295.00ft MD, 1293.03ft TVD 16.64 W Em 7.33 W 1802.06ft MD, 1787.70ft TVD 229.47 E 2444.84ft TVD 1200.03 E Joint 1219.44 E Joint 1231 Beg 10.000°/100ft: 4509.09ft MD, 3618.03ft TVD E 5.33 E 1509.16 E Bridge Plug Set Increase in Dir Rate @ 12.503°/100ft · 4653.99ft MD, 3699.20ft TVD in Dir Rate @ 10.000°/100ft· 4866.99ft MD, 3761.00ft TVD End Dir: 5054.90ft MD, 3764.00ft TVD Begin Dir @ 4.000°/100ft: 5605.16ft MD, 3743.00ft TVD End Dir: 5636.78fl MD, 3741.98ft TVD Begin Dir @ 4.000°/100ft: 6617.16ft MD, 3716.00ft 1-VD End Dir: 6624.12ft MD, 3715.80ft TVD Total Depth · 7354.86ft MD, 3694.00ft TVD Continued... 24 April, 2000 - 13:58 - 5 - DrillQuest 1.05.05a North Slope Alaska Sperry-Sun Drilling Services Proposal Report for 1D- 102 WPs - 1D- 102 Wp3 Revised: 24 April, 2000 Alaska State Plane 4 Kuparuk 1D Formation Tops Measured Vertical Sub-Sea Depth Depth Depth (ft) (ft) (ft) 4390.24 3545.00 3444.00 Northings (ft) 1552.31 S Eastings Formation Name (ft) 1168.69 E K- 13 Shale Targets associated with this wellpath Target Name 1D-102 B T1 1D-102 B T2 1D-102 B T3 1D-102 B T4 Mean S(~[evel/G Io~',;~oo rdinates: '~graphic~oordinates: ~n Sea Level/Global Coordinates: ~ Geograph ca Coord nates' ~t' ~, ' ~ean ~a Level/Global Coordinates: ~ Geographical Coordinates: Mean Sea keveVGIobal Coordinates: G~graphical Coordinates: arget Entry Coordinates TVD Northings (ft) (ft) 3761.00 1906.24 3660.00 5957950.00 70° 17' 44.3271" 3743.00 2638.22 3642.00 5957218.00 70° 17' 37.1275" 3716.00 3649.19 3615.00 5956207.00 70° 17' 27.1837" 3694.00 4386.16 3593.00 5955470.00 70° 17' 19.9349" Eastings Target (ft) Shape S 1529.12 E Point N 562O35.OO E N 149° 29' 51.6792" W S 1523.23 E Point N 562035.00 E N 149° 29' 51.8553" W S 1515.09 E Point N 562035.00 E N 149° 29' 52.0984" W S 1509.16 E Point N 562035.00 E N 149° 29' 52.2756" W Target Type 24 April, 2000- 13:58 -6- DrillQuest 1.05.05a Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone: 907-276-1215 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY May 12,2000 Mr. Blair E. Wondzell, P.E. Senior Petroleum Engineer State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Permit(s) to drill first West Sak Multi-lateral well 1 D-102 Dear Blair, Attached please find the two permits to drill for the first West Sak multi-lateral well 1 D-102. The well will consist of two horizontal laterals, one each in the B and D sands of the West Sak sands. We have permitted the main trunk and initial (lower) horizontal lateral as the primary wellbore. The upper horizontal lateral has been separately permitted as sidetrack 1D-102a. At your convenience, we'd like to discuss the possibility of streamlining the permitting process of these multi-lateral wells. We'd like to suggest including an individual form 10-401 for each particular lateral accessing an individual sand and a single package describing the well in full (casing/completion design, drilling fluids, well control, drilling hazards, etc.) Please call me at 265-6120 if you have any questions regarding this request. Graham L. (Chip) Alvord Kuparuk Drilling Engineering Supervisor ARCO Alaska, Inc. Drilling Attachments: Permit to drill 1D-102 (main trunk wellbore and initial lateral) Permit to drill D-102a (upper lateral) Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone: 907-276-1215 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY May 10, 2000 MAY 12 200 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill: West Sak 1 D-102 Surface Location: Target Location: Bottom Hole Location: 179' FSL, 595' FEL, Sec 14, T11 N, R10E 1729' FNL, 934' FWL, Sec. 24, T11 N, R10E 1070' FSL, 912' FWL, Sec. 24, T11N, R10E Dear Sirs: ARCO Alaska, Inc. hereby applies for a Permit to Drill an onshore development well to the West Sak interval from 1D Pad in the Kuparuk River Unit ("KRU"). The well is designed to penetrate and develop the production potential of the West Sak B-Sand in the vicinity of 1 D Pad. The well is designated as a horizontal producer using a 7-5/8" x 7" tapered casing string. A 4-1/2" x 4" Production Liner will be run and the well will be completed with 4-1/2" tubing and ESP. The well will be drilled and completed using Nordic Rig 3. Please find attached information as required by 20 AAC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1) Form 10-401 Application for Permit to Drill per 20 AAC 25.005 (a). 2) Fee of $100.00 payable to the State of Alaska per 20 AAC 25.005 (c) (1). 3) A directional plat showing the surface and bottom hole locations proposed for the well per 20 AAC 25.005 (c) (2). 4) Directional plots and proximity calculations in accordance with the requirements of 20 AAC 25.050. 5) Diagrams and descriptions of the BOP and Diverter equipment to be used as required by 20 AAC 25.035 (a) (1) and (b). 6) Complete proposed casing and cementing program is attached as per 20 AAC 25.030. A well bore schematic is also attached, visually depicting the proposed well and completion design. 7) The drilling fluid program, in addition to the requirements set forth in 20 AAC 25.033 are attached in this APD package. PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 8) 9) 10) 11) A copy of the proposed drilling program, including a request for approval of annular pumping operations is attached. A description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(f). Also note that ARCO does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S and combustible gas monitoring equipment functioning on the rig as is the standard operating procedure in the Kuparuk River Unit drilling operation. Please note that because of the large volume of regional information available in this area, ARCO considers this well to be a development well, and as such, no mudlogging operations such as type log generation and sample catching are planned. The following are ARCO's designated contacts for reporting responsibilities to the Commission: A) Completion Report (20 AAC 25.070) Sharon AIIsup-Drake, Drilling Technologist 263-4612 B) Geologic Data and Logs (20 AAC 25.071) Mike Werner, Geologist 265-6191 Please note that the anticipated spud date for this well is May 23, 2000. Should you have any questions or require further information, please contact Mark Chambers at 265-1319, Tom McKay at 265-6890 or Chip Alvord at 265-6120. Sincerely, Mark Chambers Operations Drilling Engineer Attachments: CC: KRU 1 D-102 Well File Chip Alvord Tom McKay ATO- 1 O30 ATO- 1060 To the order off STATE OF ALASKA ALAS~ OIL & GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE A_K 99501 05-12-00 ********** **** 100.00' Date Amount Void after 90 days T-w-o signatures required for amounts over SZS,O00.O0 ,'0000;00q55,' ':065q0L, 2&i~,: 0q q0000,,' WELL PERMIT CHECKLIST FIELD & POOL COMPANY ADMINISTRATION 1. , 3. 4. 5. 6. 7. 8. 9. 10. 11. DATE 12. _~'-,/~,., -C-~13. ENGINEERING DATE INIT CLASS ~../~'t,/ WELL NAME/Z~--/~ ~. PROGRAM: exp . /'~//--- GEOL AREA 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 ........... 14. Conductor string provided ................... 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... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to ~~ psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. dev ,, V/redrll serv UNIT# ~ wellbore seg ~ ann. disposal para req ~ ON/OFF SHORE ~,/7 GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures ..... ('~3 N ~ 31. Data presented on potential overpressure zones ....... A//~'-"Y N 32. Seismic analysis of shallow gas zones ............ .",,,~,,~ Y N AP.~R D,~AT~E. _ 33. Seabed condition survey (if off-shore) ............. ~/V~,,/-/ Y N ~ ,.~,/(., .GU 34. Contact name/phone for weekly progress reports [exploratory o~~ N I"- i------i---m--e-'i-- -----'~-i'~"- -'---g zone; . Cj..~~ O,_~5:ff~ U,~,~J-Z-~O0 ~O~.U$o~._ F~,~o~°'°~v,._%'TH l ~,~,.,j I,~--.5,~',~z'cb-. wJ )~O,~:~~ A ~) · APPR DATE (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular COMMISSION: Comments/Instructions: o Z O c:\msoffice\wordian\diana\checklist (rev. 02/17/00) Well Histo.ry File APPENDIX Information of detailed nature that is not padiculady 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 APPENDIXi ,. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Fri Aug 18 15:22:36 2000 Reel Header Service name ............. LISTPE Date ..................... 00/08/18 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 00/08/18 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientifi~ Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: MWD RUN 1 AK-MM-00058 J. FOLEY D. WESTER 1D-102 PB1 500292296070 PHILLIPS ALASKA INC. Sperry Sun 18-AUG-00 MWD RUN 5 AK-MM-00058 J. FOLEY D. HIEM 14 liN 10E 197 595 .00 RECEIVED AU6 2000 Alask~ Oil & ~as Cons. Commission Anchorage DERRICK FLOOR: 101.60 GROLrND LEVEL: 70.70 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 13.375 110.0 6.000 7.000 4935.0 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD)UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY °(DGR) UTIL- IZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 3. MWD RUNS 2-4 MADE NO FOOTAGE AND ARE NOT PRESENTED. 4. MWD RUN 5 IS DIRECTIONAL WITH DGR AND EWR4. THE EXTRA SHALLOW-SPACED PHASE RESISTIVITY DATA IS NOT PRESENTED DUE TO FAILURE OF THE RECEIVER PAST 4975'MD, 3753'TVD. 5. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN .R KALISH OF SPERRY-SUN DRILLING SERVICES AND M WERNER OF ARCO ALASKA, INC. ON o5/o5/oo. MWD DATA IS CONSIDERED PDC. 6. MWD RUNS 1 AND 5 REPRESENT WELL 1D-102 PB1 WITH API#: 50-029-22960-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 5354'MD, 3741'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 RESISTIVIT (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 ....... 00/08/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 76.5 5311.0 FET 100.0 5318.0 RPD 100.0 5318.0 RPM 100.0 5318.0 RPS 100.0 5318.0 RPX 100.0 4975.5 ROP 121.5 5354.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH 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 MERGED MAIN PASS. $ BIT RUlq NO MERGE TOP MERGE BASE 1 76.5 4941.5 5 4899.5 5354.0 Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 Nsam Rep Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 76.5 5354 ROP MWD FT/H 0 1115.01 GR MWD API 19.57 136.43 RPX MWD OHMM 0.37 980.44 RPS MWD OHMM 0.43 2000 RPM MWD OHMM 0.26 2000 RPD MWD OHMM 0.93 2000 FET MWD HOUR 0.21 126.92 Mean Nsam 2715.25 10556 111.139 10466 66.8217 10470 25.7957 9752 49.3372 10437 81.4914 10437 99.415 10437 1.58397 10437 First Reading 76.5 121.5 76.5 100 100 100 100 100 Last Reading 5354 5354 5311 4975.5 5318 5318 5318 5318 First Reading For Entire File .......... 76.5 Last Reading For Entire File ........... 5354 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/08/18 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 ....... 00/08/18 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: ~2 P~AWMWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 76.5 4899.0 RPX 100.0 4905.0 FET 100.0 4905.0 RPD 100.0 4905.0 RPS 100.0 4905.0 RPM 100.0 4905.0 ROP 121.5 4941.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE 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: 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): 05-JUN-00 Insite 4.05.2 65.41 MEMORY 4941.0 .0 84.4 TOOL NUMBER PB01531HWRGV6 PB01531HWRGV6 9.875 110.0 Water Based 9.60 255.0 9.3 5O0 4.2 3.200 2.160 3.200 2.900 68.0 104.0 68.0 68.0 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 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD010 FT/H 4 1 68 GR MWD010 API 4 1 68 RPX MWD010 OHMM 4 1 68 RPS MWD010 OHMM 4 1 68 RPM MWD010 OHMM 4 1 68 RPD MWD010 OHMM 4 1 68 FET MWD010 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Service Unit Min Max DEPT FT 76.5 4941.5 ROP MWD010 FT/H 0 1115.01 GR MWD010 API 19.57 136.43 RPX MWD010 OHMM 0.41 338.87 RPS MWD010 OHMM 0.6 1921.94 RPM MWD010 OHMM 0.63 2000 RPD MWD010 OHMM 0.93 2000 FET MWD010 HOUR 0.21 4.46 Mean 2509 110.977 67.5153 25.7222 47.0344 75.2089 97.1435 0.655961 Nsam 9731 9641 9646 9611 9611 9611 9611 9611 First Reading 76.5 121.5 76.5 100 100 100 100 100 Last Reading 4941.5 4941.5 4899 4905 4905 4905 4905 4905 First Reading For Entire File .......... 76.5 Last Reading For Entire File ........... 4941.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/08/18 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 ....... 00/08/18 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 NLTMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 4899.5 5311.0 RPD 4906.5 5318.0 RPM 4906.5 5318.0 RPS 4906.5 5318.0 RPX 4906.5 4975.5 FET 4906.5 5319.0 · ROP 4942 . 0 5354 . 0 $ LOG HEADER DATA DATE LOGGED: 10-JUN-00 SOFTWARE SLTRFACE SOFTWARE VERSION: Insite 4.05.2 DOWNHOLE SOFTWARE VERSION: 65.44 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT).: 5354.0 TOP LOG INTERVAL (FT):' BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 87.6 MAXIMUM ANGLE: 96.4 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: TOOL NUMBER PB1540WF4 PB1540WF4 6.000 4935.0 LSND 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 Depth Units ....................... Datum Specification Block sub-type...0 9.30 43.0 11.5 600 8.0 .O8O · 064 .120 .100 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 65.0 82.4 65.0 65.0 Name Service Unit DEPT FT ROP MWD050 FT/H GR MWD050 API RPX MWD050 OHMM RPS MWD050 OHMM RPM MWD050 OHMM RPD MWD050 OHMM FET MWD050 HOUR Min Max Mean Nsam 4899.5 5354 5126.75 910 0.07 255.22 113.034 825 29.5 108.74 58.702 824 0.37 980.44 30.946 139 0.43 2000 76.256 824 0.26 2000 153.319 824 0.97 2000 125.278 824 0.3 126.92 12.2546 826 First Reading 4899.5 4942 4899.5 4906.5 4906.5 4906.5 4906.5 4906.5 Last Reading 5354 5354 5311 4975.5 5318 5318 5318 5319 First Reading For Entire File .......... 4899.5 Last Reading For Entire File ........... 5354 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/08/18 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/08/18 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 00/08/18 Origin ................... STS Reel Name ................ UNElgOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Wed ~ ~ 03 q~ 2000 ~ug ~0 22: :~ Keel Header Service name ............. LISTPE Date ..................... 00/08/30 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 00/08/30 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services 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: 1D-102 PB3 0292296072 PHILLIPS ALASKA, INC. Sperry Sun 30-AUG-00 MWD RUN 1 MWD RUN 5 MWD RUN 6 AK-MM-00058 AK-MM-00058 AK-MM-00058 J. FOLEY J. FOLEY J. FOLEY D. WESTER D. HIEM D. HIEM JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: MWD RUN 7 AK-MM-00058 J. FOLEY D. HIEM 14 lin 10E 197 595 .00 101.00 GROUND LEVEL: ~{ELL CASING RECORD .00 OPEN HOLE CASING DRILLERS BIT SIZE {iN) S~ZE_ (~N 9. 875 13. 375 ii0. 6. 000 7. 625 4170.0 6.000 7.000 4935.0 !ST STRING 2ND STRING 3RD STRING PRODUCTION STRING RE~RKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD)UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTIL- IZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 3. MWD RUNS 2-4 MADE NO FOOTAGE AND ARE NOT PRESENTED. 4. MWD RUN 5 IS DIRECTIONAL WITH DGR AND EWR4. THE EXTRA SHALLOW-SPACED PHASE RESISTIVITY DATA IS NOT PRESENTED DUE TO FAILURE OF THE RECEIVER PAST 4975'MD, 3753'TVD. 5. MWD RUN 6 IS THE OPEN HOLE SIDETRACK FROM 1D-102 PB1 THAT OCCURRED DURING RUN 5. RUN 7 IS THE OPEN HOLE SIDE- TRACK THAT OCCURRED DURING RUN 6. 5. MWD DATA IS TIED IN TO 1D-102 PB2 WELLBORE AT THE KICKOFF POINT OF 6170'MD, 3744'TVD. MWD DATA IS CONSIDERED PDC. 6. MWD RUNS 1,5-7 REPRESENT WELL 1D-102 PB1 WITH API#: 50-029-22960-72. THIS WELL REACHED A TOTAL DEPTH (TD) OF 6767 'MD, 3714'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 RESISTIVIT (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.00! Service Sub Level Name... Version Number ........... i.0.0 Da~e of Generation ....... 00/08/30 Maximmv. Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Somment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 76.5 6725.0 FET t00.0 6732.0 RPD 100.0 6732.0 RPM 100.0 6732.0 RPS 100.0 6732.0 RPX 100.0 6560.0 ROP 121.5 6767.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 76.5 4941.5 5 4899.5 5190.0 6 5156.5 6170.0 7 6121.5 6767.5 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 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 ! 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 .EPM M~D OHMJE 4 I 68 ~,PD ,~D OHSflM 4 i 68 YET MWD HOUR 4 ! 68 20 24 28 lame Service Unit Min Max DEFT FT 76.5 6767 ROP MWD FT/H 0 1115.01 SR MWD API 19.57 136.43 RPX MWD OHMM 0.37 980.44 _EPS MWD OHMM 0.43 2000 RPM MWD OHMM 0.26 2000 RPD MWD OHFLM 0.93 2000 ?ET MWD HOUR 0.21 126.92 Mean Nsam 3421.75 13382 i14.337 13292 67.4377 13298 26.2424 12558 47.5384 13265 71,618 13265 85.9734 13265 1.40344 13265 First Reading 76.5 121.5 76.5 100 i00 100 100 100 Last Reading 6767 6767 6725 6560 6732 6732 6732 6732 First Reading For Entire File .......... 76.5 Last Reading For Entire File ........... 6767 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/08/30 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 ....... 00/08/30 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: 1 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 76.5 RPX 100.0 RPS 100.0 RPM 100.0 RPD 100.0 FET 100.0 ROP 121.5 $ LOG HEADER DATA STOP DEPTH 4899.0 4905.0 4905.0 4905.0 4905.0 4905.0 4941.5 DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TiME): TD DRILLER (FT): TOP LOG ~m~V~T '~ BOTTOH LOG iNTERVAL {FT): BIT ROTATING SPEED {RPM): HOLE iNCLINATION (DEG HIN!MUM ANGLE: MAXlMUH 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: 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 Depth Units ....................... Datum Specification Block sub-type...0 05-JUN-00 Insite 65.41 MEMORY 494!.0 .0 84.4 TOOL NUMBER PB01531HWRGV6 PB01531HWRGV6 9.875 110.0 Water Based 9.60 255.0 9.3 5O0 4.2 3.200 2.160 3.200 2.900 68.0 104.0 68.0 68.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 I 68 RPM MWD0!0 OHMM 4 1 68 RPD MWD0~0~ OH~LM 4 _l 68 FE? ~D0!0 HOUR 4 ! 68 i6 20 24 28 Xame Service Unit Min Max DEPT FT 76.5 4941.5 ROP ~D010 FT/H 0 1115.01 SR MWD010 API 19.57 136.43 RPX MWD010 OHMM 0.41 338.87 RPS MWD010 OHMM 0.6 1921.94 RPM MWD010 OHMM 0.63 2000 RPD MWD0!00HMM 0.93 2000 FET MWD010 HOUR 0.21 4.46 Mean Nsam 2509 9731 110.977 9641 67.5153 9646 25.7222 9611 47.0344 9611 75.2089 9611 97.1435 9611 0.655961 9611 First Reading 76.5 121.5 76.5 100 100 100 100 100 Last Reading 4941.5 4941.5 4899 4905 4905 4905 4905 4905 First Reading For Entire File .......... 76.5 Last Reading For Entire File ........... 4941.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/08/30 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 ....... 00/08/30 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: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 4899.5 5190.0 RPS 4906.5 5190.0 FET 4906.5 5190.0 RPD 4906.5 5190.0 RPX 4906.5 4975.5 RPM 4906.5 5190.0 ROP 4942.0 5190.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TiME): TD DRILLER (FI): TO? 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: 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 Depth Units ....................... Datum Specification Block sub-type...0 iO-JUN-O0 Insite 65.44 MEMORY 5354.0 87.6 96.4 TOOL NUMBER PB1540WF4 PB1540WF4 6.000 4170.0 LSND 9.30 43.0 11.5 600 8.0 .O80 .064 .120 .100 65.0 82.4 65.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 F, PX MWD050 OHMM 4 i 68 RPS MWD050 OHMM,, 4 i 68 RPM MWD050 OHMM 4 i 68 ~:~ MWD050 OHMM 4 i 68 FET !~{D050 HOUR 4 i 68 12 16 20 24 28 >(ame Service Unin Min Max ~ F? _~rT 4899.5 5190 ROP MWD050 FT/H 0.07 185.57 SR MWD050 API 29,5 74.68 R?X MWD050 OHMM 0.37 980.44 APS MWD050 OHMM 0.43 2000 RPM MWD050 OHMM 0.26 2000 RPD MWD050 OHMM 0.97 2000 FET MWD050 HOUR 0.33 126.92 Mean 5044.75 103.178 56.2842 30.946 85.4255 195.357 152.518 17.576 Nsam 582 497 582 139 568 568 568 568 First Reading 4899.5 4942 4899.5 4906.5 4906.5 4906.5 4906.5 4906.5 Last Reading 5190 5190 5190 4975.5 5190 5190 5190 5190 First Reading For Entire File .......... 4899.5 Last Reading For Entire File ........... 5190 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/08/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/08/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RPX 5156.5 FET 5190.5 ROP 5190.5 GR 5190.5 RPS 5190.5 RPD 5190.5 RPM 5190.5 $ STOP DEPTH 6170.0 6170.0 6170.0 6170.0 6170.0 6170.0 6170.0 LOG HEADER DATA DATE LOGGED: SOFTWARE SUR~.~ SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: ~,,,--~,, ~y~u (MEMORY OR Ru~.-T~M~): TD' DRILLER (FT): TOP LOG ~Tv, '~ BOTTOM LOG INTERVAL (FT): S~u (RPM): RO ~ =No :vvn HOLE iNCLiNATiON (DEG MINIMUM ANGLE: ~IMUM 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: 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 Depth Unins ....................... Datum Specification Block sub-type...0 !!-JUN-00 insite 65.44 MEMORY 6454.0 88.2 93.8 TOOL NUMBER PB1540WF4 PB1540WF4 6.000 4935.0 LSND 9.10 45.0 8.4 3000 4.0 .O80 .064 .120 .100 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 ROP MWD060 FT/H 4 1 68 4 2 65.0 82.4 65.0 65.0 8 12 16 20 24 28 i(ame Service Unit Min Max EEPT FT 5156.5 6170 ROP ~4D060 FT/H 1.45 380.72 SR MWD060 API 48.57 95.54 RPX MWD060 OHMM 10.03 458.98 RPS MWD060 OHMM 12.87 1610.5 RPM MWD060 OHMM 13.88 245.75 RPD MWD060 OHMM 15.06 148.5 FET MWD060 HOUR 0.24 6.46 Mean 5663.25 131.653 71.5901 26.8346 32. 6799 30. 9535 32.7773 0.593291 Nsam 2028 1960 1960 2028 1960 1960 1960 1960 First Reading 5156.5 5190.5 5190.5 5156.5 5190.5 5190.5 5190.5 5190.5 Last Reading 6170 6170 6170 6170 6170 6170 6170 6170 First Reading For Entire File .......... 5156.5 Last Reading For Entire File ........... 6170 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/08/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/08/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE GR RPM RPS RPX FET RPD ROP 7 .5000 START DEPTH 6121.5 6128 5 6128 5 6128 5 6128 5 6170 5 6170 5 STOP DEPTH 6725.0 6732.0 6732.0 6560.0 6732.0 6732.0 6767.5 $ LOG HEADER uA~.~ 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: ~AXIMUM 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: 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 Depth Units ....................... Datum Specification Block sub-type...0 !2-JUN-00 Insite 65.44 MEMORY 6767.0 89.7 95.7 TOOL NUMBER PB1540WF4 PB1540WF4 6.000 LSND 9.20 42.0 8.5 28000 3.6 .O8O .064 .120 .100 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 i 68 0 i 65.0 82.4 65.0 65.0 ROP MWD070 FT/H 4 ! 68 SR MWD070 API 4 i 68 RPX MWD070 OHMM 4 i 68 .,PS MWD070 OHMM 4 I 68 F, PM ,t<WD 070 OHMLM 4 i 68 ~,FD ~D070 OHMM 4 ! 68 ~-=~ !~D07 ~ HOUR 4 ~ 68 4 8 12 16 20 24 28 Xame Service Unit Min Max Mean DEPT FT 6121.5 6767.5 6444.5 ROP MWD070 FT/H 0.34 813.33 117.616 GR MWD070 API 43.88 110.99 65.8222 RPX MWD070 OHMM 8.66 79.37 30.0132 RPS MWD070 OHMM 6.86 1926.74 55.9547 RPM MWD070 OHMM 8.77 243.42 46.5634 RPD MWD070 OHMM 10.66 169.42 49.1086 FET MWD070 HOUR 0.27 9.04 1.47401 First Last Nsam Reading Reading 1293 6121.5 6767.5 1195 6170.5 6767.5 1208 6121.5 6725 792 6128.5 6560 1208 6128.5 6732 1208 6128.5 6732 1124 6170.5 6732 1208 6128.5 6732 First Reading For Entire File .......... 6121.5 Last Reading For Entire File ........... 6767.5 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/08/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/08/30 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 00/08/30 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Tue Aug 29 12:49:17 2000 Reel Header Service name ............. LISTPE Date ..................... 00/08/29 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 00/08/29 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1D-102 PB2 500292296071 PHILLIPS ALASKA, INC. Sperry Sun 29-AUG-00 1ST STRING MWD RUN 1 MWD RUN 5 MWD RUN 6 AK-MM-00058 AK-MM-00058 AK-MM-00058 J. FOLEY J. FOLEY J. FOLEY D. WESTER D. HIEM D. HIEM 10 lin 10E 179 595 .00 101.60 70.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 13.375 110.0 2ND STRING 6.000 7.625 4170.0 3RD STRING 6.000 7.000 4935.0 PRODUCTION STRING # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD)UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTIL- IZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 3. MWD RUNS 2-4 MADE NO FOOTAGE AND ARE NOT PRESENTED. 4. MWD RUN 5 IS DIRECTIONAL WITH DGR AND EWR4. THE EXTRA SHALLOW-SPACED PHASE RESISTIVITY DATA IS NOT PRESENTED DUE TO FAILURE OF THE RECEIVER PAST 4975'MD, 3753'TVD. 5. MWD RUN 6 IS THE OPEN HOLE SIDETRACK FROM 1D-102 PB1 THAT OCCURRED DURING RUN 5. 5. MWD DATA IS TIED IN TO 1D-102 PB1 WELLBORE AT THE KICKOFF POINT OF 5190'MD, 3756'TVD. MWD DATA IS CONSIDERED PDC. 6. MWD RUNS 1,5, & 6 REPRESENT WELL 1D-102 PB1 WITH API%: 50-029-22960-71. THIS WELL REACHED A TOTAL DEPTH (TD) OF 6454'MD, 3732'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 RESISTIVIT (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 ....... 00/08/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.O00 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPD FET RPM RPS RPX ROP $ START DEPTH STOP DEPTH 76.5 6411.5 85.5 6418.5 100.0 6418.5 100.0 6418.5 100.0 6418.5 100.0 6418.5 121.5 6454.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ # REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 76.5 4942.0 5 4942.0 5190.0 6 5190.0 6454.0 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 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 t 68 28 8 Name Service Unit Min Max Mean Nsam DEPT FT 76.5 6454 3265.25 12756 ROP MWD FT/H 0 1115.01 115.02 12666 First Reading 76.5 121.5 Last Reading 6454 6454 GR MWD API 19.57 136.43 RPX MWD OHMM 0.37 980.44 RPS MWD OHMM 0.43 2000 RPM MWD OHMM 0.26 2000 RPD MWD OHMM 0.93 2000 FET MWD HOUR 0.21 126.92 67.555 12671 26.5126 12264 46.5856 12638 72.8092 12638 89.3722 12667 1.41119 12638 76.5 100 100 100 85.5 100 6411 5 6418 5 6418 5 6418 5 6418 5 6418 5 First Reading For Entire File .......... 76.5 Last Reading For Entire File ........... 6454 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/08/29 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 ........... t.0.0 Date of Generation ....... 00/08/29 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: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 76.5 4899.0 RPD 100.0 4905.0 RPM 100.0 4905.0 RPS 100.0 4905.0 RPX 100.0 4905.0 FET 100.0 4905.0 ROP 121.5 4941.5 $ 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 05-JUN-00 Insite 65.41 MEMORY 4941.0 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: 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 Depth Units ....................... Datum Specification Block sub-type...0 .0 84.4 TOOL NUMBER PB01531HWRGV6 PB01531HWRGV6 9.875 110.0 Water Based 9.60 255.0 9.3 5OO 4.2 3.200 2.160 3.200 2.900 68.0 104.0 68.0 68.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 t 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 Name Service Unit Min Max Mean Nsam DEPT FT 76.5 4941.5 2509 9731 First Reading 76.5 Last Reading 4941.5 ROP MWD010 FT/H 0 GR MWD010 API 19.57 RPX MWD010 OHMM 0.41 RPS MWD010 OHMM 0.6 RPM MWD010 OHMM 0.63 RPD MWD010 OHMM 0.93 FET MWD010 HOUR 0.21 1115.01 136.43 338.87 1921.94 2000 2000 4.46 110.977 9641 67.5153 9646 25.7222 9611 47.0344 9611 75.2089 9611 97.1435 9611 0.655961 9611 121.5 76.5 100 100 100 100 100 4941.5 4899 4905 4905 4905 4905 4905 First Reading For Entire File .......... 76.5 Last Reading For Entire File ........... 4941.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/08/29 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 ....... 00/08/29 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: 5 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 4899.5 FET 4906.5 RPD 4906.5 RPM 4906.5 RPS 4906.5 RPX 4906.5 ROP 4942.0 $ 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) : STOP DEPTH 5190 0 5190 0 5190 0 5190 0 5190 0 4975 5 5190.0 10-JUN-00 Insite 65.44 MEMORY 5354.0 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: 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 Depth Units ....................... Datum Specification Block sub-type...0 87.6 96.4 TOOL NUMBER PB1540WF4 PB1540WF4 6.000 4170.0 LSND 9.30 43.0 11.5 600 8.0 .O80 .064 .120 .100 65.0 82.4 65.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 Name Service Unit Min Max Mean Nsam First Reading Last Reading DEPT FT ROP' MWD050 FT/H GR MWD050 API RPX MWD050 OHMM RPS MWD050 OHMM RPM MWD050 OHMM RPD MWD050 OHMM FET MWD050 HOUR 4899.5 5190 5044.75 0.07 185.57 103.192 29.5 74.68 56.2842 0.37 980.44 30.946 0.43 2000 85.4255 0.26 2000 195.357 0.97 2000 152.518 0.33 126.92 17.576 582 497 582 139 568 568 568 568 4899.5 4942 4899.5 4906.5 4906.5 4906.5 4906.5 4906.5 5190 5190 5190 4975.5 5190 5190 5190 5190 First Reading For Entire File .......... 4899.5 Last Reading For Entire File ........... 5190 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/08/29 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/08/29 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 5156.5 6418.5 RPD 5190.5 6418.5 RPM 5190.5 6418.5 RPS 5190.5 6418.5 GR 5190.5 6411.5 ROP 5190.5 6454.0 FET 5190.5 6418.5 $ 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) : ll-JUN-O0 Insite 65.44 MEMORY 6454.0 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: 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 Depth Units ....................... Datum Specification Block sub-type...0 88.2 93.8 TOOL NUMBER PB1540WF4 PB1540WF4 6.000 4935.0 LSND 9.10 45.0 8.4 3000 4.0 .08O .064 .120 .100 65.0 82.4 65.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 First Last Name Service Unit DEPT FT ROP MWD060 FT/H GR MWD060 API RPX MWD060 OHMM RPS MWD060 OHMM RPM MWD060 OHMM RPD MWD060 OHMM FET MWD060 HOUR Min 5156.5 1.23 40 03 10 03 12 87 13 88 15 06 0 24 Max 6454 380.72 95.54 458.98 1610.5 245.75 148.5 6.46 Mean Nsam 5805.25 2596 132.767 2528 70.3969 2443 29.2886 2525 35.8691 2457 34.5986 2457 36.5577 2457 0.586007 2457 Reading 5156 5 5190 5 5190 5 5156 5 5190 5 5190 5 5190 5 5190 5 Readinc 6454 6454 6411 5 6418 5 6418 5 6418 5 6418 5 6418 5 First Reading For Entire File .......... 5156.5 Last Reading For Entire File ........... 6454 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/08/29 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/08/29 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 00/08/29 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Fri Sep 01 13:28:09 2000 Reel Header Service name ............. LISTPE Date ..................... 00/09/01 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 00/09/01 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services 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: 1D-102 500292296000 Phillips Alaska, Inc. Sperry Sun 01-SEP-00 MWD RUN 1 MWD RUN 5 MWD RUN 6 AK-MM-00058 AK-MM-00058 AK-MM-00058 J. FOLEY J. FOLEY J. FOLEY D. WESTER D. HIEM D. HIEM RECEIVED SEP 0 8 ~ U L; U Alaska ,,~,~1 & 6as Cons. fomn-...~ssior~ Anchorage JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: MWD RUN 7 AK-MM-00058 J. FOLEY D. HIEM MWD RUN 8 AK-MM-00058 M. HANIK D. WESTER 14 lin 10E 179 595 .00 101.60 GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMUtRKS: 70.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.880 13.375 110.0 6.000 7.625 4170.0 6.000 7.000 4935.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD)UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTIL- IZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 {EWR4). 3. MWD RUNS 2-4 MADE NO FOOTAGE AND ARE NOT PRESENTED. 4. MWD RUN 5 IS DIRECTIONAL WITH DGR AND EWR4. THE EXTRA SHALLOW-SPACED PHASE RESISTIVITY DATA IS NOT PRESENTED DUE TO FAILURE OF THE RECEIVER PAST 4905'MD, 3753'TVD. 5. MWD RUN 6 IS THE OPEN HOLE SIDETRACK FROM 1D-102 PB1 THAT OCCURRED DURING RUN 5. RUN 7 IS THE OPEN HOLE SIDE- TRACK FROM 1D-102 PB2 THAT ocCURRED DURING RUN 6. 5. MWD DATA IS TIED INTO 1D-102 PB1 WELLBORE AT THE KICKOFF POINT OF 5190'MD, 3756'TVD; INTO 1D-102 PB2 WELLBORE AT THE KICKOFF POINT OF 6170'MD, 3744'TVD; AND INTO 1D-102 PB3 WELLBORE AT THE KICKOFF POINT OF 6558'MD, 3731'TVD. MWD DATA IS CONSIDERED PDC. 6. MWD RUNS 1,5-8 REPRESENT WELL 1D-102 WITH API#: 50-029-22960-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7378'MD, 3721'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 RESISTIVIT {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 ....... 00/09/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPS RPX SROP $ START DEPTH STOP DEPTH 76.5 7328.0 100.0 7335.0 100.0 7335.0 100.0 7335.0 100.0 7335.0 100.0 4905.0 121.5 7378.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 76.5 4941.5 5 4899.5 5190.0 6 5190.5 6170.0 7 6121.5 6558.0 8 6558.5 7378.0 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 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 0 4 8 12 16 20 24 28 Name Service Unit Min Max DEPT FT 76.5 7378 ROP MWD FT/H 0 1115.01 GR MWD API 19.57 136.43 RPX MWD OHMM 0.41 338.87 RPS MWD OHMM 0.43 2000 RPM MWD OHMM 0.26 2000 RPD MWD OHMM 0.93 2000 FET MWD HOUR 0.21 126.92 Mean Nsam 3727.25 14604 116.843 14441 67.2155 14504 25.7222 9611 47.3026 14471 69.7188 14471 83.0863 14471 1.32682 14471 First Reading 76.5 121.5 76.5 100 100 100 100 100 Last Reading 7378 7378 7328 4905 7335 7335 7335 7335 First Reading For Entire File .......... 76.5 Last Reading For Entire File ........... 7378 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/09/01 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 ....... 00/09/01 Maximum Physical Record..65535 File Type LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 76.5 4899.0 RPS 100.0 4905.0 RPX 100.0 4905.0 RPM 100.0 4905.0 RPD 100.0 4905.0 FET 100.0 ROP 121.5 $ 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) : 4905.0 4941.5 BOREHOLE CONDITIONS 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 Depth Units ....................... Datum Specification Block sub-type...0 05-JUN-O0 Insite 65.41 MEMORY 4941.0 .0 84.4 TOOL NUMBER PB01531HWRGV6 PB01531HWRGV6 9.880 110.0 Water Based 9.60 255.0 9.3 50O 4.2 3.200 2.160 3.200 2.900 68.0 104.0 68.0 68.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 RPX MWD010 OHMM 4 1 68 12 4 RPS MWD010 OHMM 4 1 68 16 5 RPM MWD010 OHMM 4 1 68 20 6 RPD MWD010 OHMM 4 1 68 24 7 FET MWD010 HOUR 4 1 68 28 8 Name Service Unit Min Max DEPT FT 76.5 4941.5 ROP MWD010 FT/H 0 1115.01 GR MWD010 API 19.57 136.43 RPX MWD010 OHMM 0.41 338.87 RPS MWD010 OHMM 0.6 1921.94 RPM MWD010 OHMM 0.63 2000 RPD MWD010 OHMM 0.93 2000 FET MWD010 HOUR 0.21 4.46 Mean Nsam 2509 9731 110.977 9641 67.5153 9646 25.7222 9611 47.0344 9611 75.2089 9611 97.1435 9611 0.655961 9611 First Reading 76.5 121.5 76.5 100 100 100 100 100 Last Reading 4941.5 4941.5 4899 4905 4905 4905 4905 4905 First Reading For Entire File .......... 76.5 Last Reading For Entire File ........... 4941.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/09/01 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 ....... 00/09/01 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: 5 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 4899.5 5190.0 RPM 4906.5 5190.0 RPS 4906.5 5190.0 FET 4906.5 5190.0 RPD 4 906.5 ROP 4942.0 $ 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: 5190.0 5190.0 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: 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 Depth Units ....................... Datum Specification Block sub-type...0 10-JUN-00 Insite 65.44 MEMORY 5354.0 87.6 96.4 TOOL NUMBER PB1540WF4 PB1540WF4 6.000 4170.0 LSND 9.30 43.0 11.5 600 8.0 .O8O .064 .120 .100 65.0 82.4 65.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPM MWD050 OHMM 4 t 68 16 5 RPD MWD050 OHMM 4 1 68 20 6 FET MWD050 HOUR 4 1 68 24 7 Name Service Unit DEPT FT ROP MWD050 FT/H GR MWD050 API RPS MWD050 OHMM RPM MWD050 OHMM RPD MWD050 OHMM FET MWD050 HOUR Min Max Mean Nsam 4899.5 5190 5044.75 582 0.07 185.57 103.178 497 29.5 74.68 56.2842 582 0.43 2000 85.4255 568 0.26 2000 195.357 568 0.97 2000 152.518 568 0.33 126.92 17.576 568 First Reading 4899.5 4942 4899.5 4906.5 4906.5 4906.5 4906.5 Last Reading 5190 5190 5190 5190 5190 5190 5190 First Reading For Entire File .......... 4899.5 Last Reading For Entire File ........... 5190 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/09/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/09/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH SFXE 5190.5 6170.0 RPD 5190.5 6170.0 RPM 5190.5 6170.0 RPS 5190.5 6170.0 GR 5190.5 6170.0 ROP 5190.5 6170.0 $ 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: 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 Depth Units ....................... Datum Specification Block sub-type...0 Il-JUN-00 Insite 65.44 MEMORY 6454.0 88.2 93.8 TOOL NUMBER PB1540WF4 PB1540WF4 6.000 4935.0 LSND 9.10 45.0 8.4 3000 4.0 .O8O .064 .120 .100 65.0 82.4 65.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 GR MWD060 RPS MWD060 RPM MWD060 RPD MWD060 FET MWD060 FT/H 4 t 68 API 4 1 68 OHMM 4 1 68 OHMM 4 1 68 OHMM 4 t 68 HOUR 4 1 68 4 8 12 16 20 24 Name Service Unit DEPT FT ROP MWD060 FT/H GR MWD060 API RPS MWD060 OHMM RPM MWD060 OHMM RPD MWD060 OHMM FET MWD060 HOUR Min Max 5190.5 6170 1.45 380.72 48.57 95.54 12.87 1610.5 13.88 245.75 15.06 148.5 0.24 6.46 Mean Nsam 5680.25 1960 131.653 1960 71.5901 1960 32.6799 1960 30.9535 1960 32.7773 1960 0.593291 1960 First Readinc 5190.5 5190 5 5190 5 5190 5 5190 5 5190 5 5190 5 Last Reading 6170 6170 6170 6170 6170 6170 6170 First Reading For Entire File .......... 5190.5 Last Reading For Entire File ........... 6170 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/09/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/09/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 6121.5 FET 6128.5 RPS 6170.5 ROP 6170.5 RPS 6170.5 RPD 6170.5 $ STOP DEPTH 6558 0 6558 0 6558 0 6558 0 6558 0 6558 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: 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 Depth Units ....................... Datum Specification Block sub-type...0 12-JUN-00 Insite 65.44 MEMORY 6767.0 89.7 95.7 TOOL NUMBER PB1540WF4 PB1540WF4 6.000 LSND 9.20 42.0 8.5 28000 3.6 .O8O .064 .120 .100 65.0 82.4 65.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 RPS MWD070 OHMM 4 1 68 RPM MWD070 OHMM 4 1 68 RPD MWD070 OHMM 4 1 68 FET. MWD070 HOUR 4 1 68 12 16 20 24 Name Service Unit Min Max DEPT FT 6121.5 6558 ROP MWD070 FT/H 5.35 813.33 GR MWD070 API 47.73 82.78 RPS MWD070 OHMM 12.21 185.29 RPM MWD070 OHMM 11.59 87.28 RPD MWD070 OHMM 13.81 80.2 FET MWD070 HOUR 0.27 9.04 Mean 6339.75 136.565 66.8148 35.9852 36.066 38.9402 1.47823 Nsam 874 776 874 776 776 776 860 First Reading 6121.5 6170.5 6121.5 6170.5 6170.5 6170.5 6128.5 Last Reading 6558 6558 6558 6558 6558 6558 6558 First Reading For Entire File .......... 6121.5 Last Reading For Entire File ....... .... 6558 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number...~ ....... 1.0.0 Date of Generation ....... 00/09/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/09/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RPD 6558.5 RPM 6558.5 RPS 6558.5 GR 6558.5 FET 6558.5 ROP 6595.0 $ LOG HEADER DATA DATE LOGGED: STOP DEPTH 7335.0 7335.0 7335.0 7328.0 7335.0 7378.0 13-JUN-00 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: 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 Depth Units ....................... Datum Specification Block sub-type...0 Insite 65.44 MEMORY 7378.0 87.4 91.5 TOOL NUMBER PB1540WF4 PB1540WF4 6.000 BARADRI L-N 9.20 45.0 8.3 30000 8.0 .200 .174 .200 .150 72.0 84.0 68.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD080 FT/H 4 1 68 4 2 GR MWD080 API 4 t 68 8 3 RPS MWD080 OHMM 4 1 68 12 4 RPM MWD080 OHMM 4 1 68 16 5 RPD MWD080 OHMM 4 1 68 FET MWD080 HOUR 4 1 68 2O 24 Name Service Unit Min Max DEPT FT 6558.5 7378 ROP MWD080 FT/H 3.25 303.23 GR MWD080 API 40.23 86.26 RPS MWD080 OHMM 20.89 1759.47 RPM MWD080 OHMM 21.84 338.05 RPD MWD080 OHMM 26.72 198.7 FET MWD080 HOUR 0.3 27.99 First Last Mean Nsam Reading Reading 6968.25 1640 6558.5 7378 128.979 1567 6595 7378 64.4314 1540 6558.5 7328 59.15 1554 6558.5 7335 54.7564 1554 6558.5 7335 55.9108 1554 6558.5 7335 0.703385 1554 6558.5 7335 First Reading For Entire File .......... 6558.5 Last Reading For Entire File ........... 7378 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/09/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/09/01 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 00/09/01 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name.. .......... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File