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205-186
STATE OF ALASKA • ISKA OIL AND GAS CONSERVATION COMMI SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations LJ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate E Alter Casing❑ Change Approved Program ,❑J Plug for Redrill Elerforate New Pool ❑ Repair Well E Re-enter Susp Well 0Other: and m If d 3f� 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development❑ Exploratory❑ 205-186 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic Service❑ 6.API Number: 99510 50-029-21248-60 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 1 Q-02BL1 ADL 25634 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NONE Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 12,050 feet Plugs measured None feet true vertical 6,758 feet Junk measured None feet Effective Depth measured 12,050 feet Packer measured 0 feet true vertical 6,758 feet true vertical 0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 64 feet 16 " 100'MD 100 SURFACE 3,794 feet 9 5/8" 3,829'MD 3517 PRODUCTION 8,086 feet 7 " 8,119'MD 6247 LINER BL1 3,554 feet 2 7/8" 12,050'MD 6758 RECEIVED Perforation depth Measured depth 9623-11499 feet lYltt!{M AV 1 6 2017 017 True Vertical depth 6686-6715 feet A 3C C Tubing(size,grade,measured and true vertical depth) 4.5" L-80 6,079' MD 5,072'TVD Packers and SSSV(type,measured and true vertical depth) Packer=Weatherford PB Packer 5,991' MD 5,011'TVD Packer=Weatherford ER Packer 6,024'MD 5,034'ND Packer=Baker HYFLO III Liner Top 6,119'MD 5,100'TVD SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A SCANNED UN .G 4 13 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 1100 1000 717 3800 Subsequent to operation: 0 1000 1200 413 3800 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 2 Exploratory Development❑ Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil ❑ Gas El WDSPL ❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ ❑ WAG 0 GINJ 0 SUSF❑ SPLUG ❑ 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: 317-128 Contact Name: Jason Burke Authorized Name: Jason Burke ' Contact Email:jason.burke@cop.com Authorized Title: Wells Engineer r/ Contact Phone: (907)265-6097 Authorized Signature: Datc.51,57 Form 10-404 Revised 4/2417 O, 7"� 7- RBDMS P u M v 1 7 2017 Submit Original Only �/G/ ZV`TL fir/ 1 RBDMS V !' L • • 1 Q-O2BLI ACID STIMULATION DTTMSTAI JOBTYP SUMMARYOPS 4/17/17 ACID Spot Dynamic Acid Dispresion treatment with CT from 12,024 ft to 8,500 ft. POOH, unstab and secure well, ***Job Complete'`** 5/1/17 PUMPING PUMPED 105 BBLS OF DIESEL DOWN THE TUBING TO BRING THE TUBING PRESSURE DOWN. JOB COMPLETE. TRACKING ONLY KUP1 Q-02B Con0e0Phi111p5 n Well Attribt Max Angle MD TD AI1,16ka.,816. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) coracoahllhps 500292124802 KUPARUK RIVER UNIT INJ 95.09 9,976.94 11,501.0 -.° A.,.. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) .-Rig Release Date ' 1Q-02B,5/15/20172:24:55 PM SSSV:NIPPLE 5 6/182006 Last WO: 30.10 4/11/1985 vortral echamatw(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:ACID TREATMENT(DAD)SEE pproven 5/152017 NOTES HANGER;21.3 ' j'ff '�-�1 asmg rings . - Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 36.0 100.0 100.0 62.58 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread c SURFACE 9 5/8 8.921 35.1 3,829.5 3,516.9 36.00 J-55 BTC I, 1 lc Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread 1f PRODUCTION 7 6.276 33.3 8,118.7 6,246.8 26.00 J-55 BTC Casing Description OD(in) ID(in) Top(OKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread CONDUCTOR,36.0-100.0 LINER 1Q-02A 41/2 3.958 6,112.8 9,010.0 6,638.6 12.60 L-80 NSCT Liner Details �.,'', _ Nominal ID NIPPLE;500.0 Top(ftKB) Top(ND)(ftKB) Top Indy) Item Des Corn (in) e� 6,112.8 5,095.8 45.63 SLEEVE BAKER LINER PACKER SETTING SLEEVE 5.500 Iti 6,119.0 5,100.1 45.62 PACKER BAKER HYFLO III LINER TOP PACKER 5.063 • 6,121.3 5,101.7 45.61 SBE BAKER 80-47 SEAL BORE EXTENSION 4.750 6,135.8 5,111.9 45.57 HANGER BAKER CMC MECHANICAL LINER HANGER 4.125 6,145.0 5,118.4 45.55 XO Reducing CROSSOVER 5 x 4.5,ID 3.958,#12.60,L-80,NSCT ' 4.500 SURFACE;35.1-3,829.5 7,974.5 6,153.3 50.66 NIPPLE OTIS X LANDING NIPPLE 3.812 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread PACKER;5,991.0111'.'1'-z;--,:i:j1.1 WINDOW 4 3.958 8,539.0 8,540.0 6,516.9 6.16 L-80 =- Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)..."WtlLen(I...Grade Top Thread UPPER L1 TOP 3 3/16 2.810 8,496.0 8,705.0 6,606.9 6.16 L-80 TCII PATCH;6,004.8- ('J , SLEEVE-C;6,008.0 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...'Wt/Len(1...Grade Top Thread LOWER s TOP 2 7/8 2.441 8,705.0 9,609.0 6,684.0_ 6.16 L-80 STL �k� Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) 'Set Depth(ND)... WELen(I...Grade Top Thread PACKER;6,024.0 - LINER B 27/8 2.441 9,608.9 11,501.0 6.16 L-80 STL Liner Details Nominal ID 1 71H Top(ftKB) Top(ND)(ORB) Top Incl(°) Item Des Com (In) • 9,608.9 6,683.9 81.59 BILLET WEATHERFORD LINER BILLET w/GS PROFILE 8 2.441 LOCATOR;8,061.4 3.5'PUP SEAL ASSY;8,081.8 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING 41/2 3.795 21.3 6,078.7 5,072.0 12.75 L-80 ABM-EUE - Completion Details ' ,' 'Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) El 21.3 21.3 0.00 HANGER FMC GEN IV TUBING HANGER 4.500 500.0 500.0 0.29 NIPPLE CAMCO DB LANDING NIPPLE 3.875 6,008.8 5,023.4 46.04 SLEEVE-C BAKER CMU SLIDING SLEEVE-CLOSED 6/24/2011 3.812 6,061.4 5,059.9 45.81 LOCATOR BAKER LOCATOR 3.880 6,061.8 5,060.2 45.81 SEAL ASSY BAKER SEAL ASSEMBLY 3.875 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) Cl Des Corn Run Date ID(in) 5,991.0' 5,011.0 46.12 PACKER 'WEATHERFORD PB PACKER 10/1212011 ' 2.375 5,994.0 5,013.1 46.10 PATCH 'SPACER PIPE 8 SNAP LATCH ASSEMBLY 10/12'2011 2.250 E. 6,024.0 5,033.9 45.98 PACKER WEATHERFORD ER PACKER 10/5/2011 2.375 I Perforations&Slots Shot Den Top(TVD) Btm(ND) (shots/ PRODUCTION;33.3-8,118.7 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Corn Squeeze Pads;8,203.0 ftKB 9,623.0 11,499.0 6,685.9 A-3,A-4,A-5, 11/18/2005 99.0 SLOTS STL SLOTTED LINER (PERF;8,203.0-8,205.0• A # 1Q-02B RPERF;8,389.0-8,384.0 RPERF;8,369.08,354.0.k Notes:General&Safety RPERF;8,3 .0-8,384.0` End Date Annotation APERF;8,140.0.8,4420 11/27/2005 NOTE:MULTI-LATERAL WELL w/SIDETRACK 10-028,LATERAL LEG 1Q-02BL1 Shot sq:Peas;8,440.0 ftKB •° 46/4/2011 NOTE:CONFIRMED ISO-SLEEVE LEAK @ 6009'RKB 4/17/2017 NOTE:Spot Dynamic Acid Dispresion treatment with CT from 12,024 ft to 8,500 ft WINDOW;8,539.0-8,540.0 UPPER L1 TOP;8,4980- 8,705.0 ,498-8,705.0 I 1 I. i1 1' 11 It I1 1' LINER 1Q-02A;8,112.8-9,010.0 1 1 SLOTS;8,720.0-12,038.0 LINER BL1;8,498.1-12,050.0 LOWER L1 TOP;8,705.0 X 9,809-8 SLOTS;9,623.0-11,499.0 _J i I LINER B;9,808.9-11,501.0 ilk KUP 1Q-02BL1 ConoCoP"Ud ips A Well Attribu Max Angle at D TD AI/IMka,IncWellbore APVUWI Field Name Wellbore Statusncl(°) MD(kKB) ACo500292124860 KUPARUK RIVER UNIT INJ I 93.77 9,970.21 12,050.0 °.. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1D-02BL1,5/15/20172:25:30 PM SSSV:NIPPLE 5 6/18/2006 Last WO: 30.10 4/11/1985 Vertraal,schwnaac{aoNaO Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag' Rev Reason:ACID TREATMENT(DAD)SEE pproven 5/15/2017 NOTES HANGER;21.3 31 '®11® asing rings Casing Description OD(in) ID(10) Top(ftKB) Set Depth(73) Set Depth(TVDI... WtlLen(I...Grade Top Thread LINER BL1 1 27181 24411 8,496.11 12,050.01 6.757.6 6.161 L-80 ISTL 1Liner Details F i Nominal ID F ' Top(ftKB) Top(TVD)(kKB) Top Incl(°) Item Des Com (in) Jllllil 8,496.1 6,488.7 49.97 DEPLOY L1 LINER BTT DEPLOYMENT SLEEVE 3.000 8,511.5 6,498.6 49.99 XO Reducing CROSSOVER 3.5 x 3.1875,ID 2.812,#6.2,L-80, 2.780 CONDUCTOR;38.0-100.0 TCII IL 8,700.8 6,605.1 65.14 XO Reducing CROSSOVER 3.1875 x 2.875,ID 2.441,#6.16,L-80, 2.810 NIPPLE;500.0MI STL 12,037.8 6,756.8 86.36 0-RING BTT 0-RING PACK OFF 1.250 Perforations&Slots Shot Dens Top(TVD) Btm(TVD) (shots/ Top(ftKB) Eitel(ftKB) (RKB) (ftKB) Zone Date ft) Type Corn SURFACE;35.1-3,829.5 8,720.0 12,038.0 6,612.9 6,756.8 A-3,10- 11/25/2005 99.0 SLOTS 1Q-02BL1 SLOTTED 02BL1 LINER PACKER;5,991 0 Notes:General&Safety End Date Annotation II11/27/2005 NOTE:MULTI-LATERAL SIDETRACK:1Q-02B,1Q-02BL1 PATCH;5,994.0— ' 1, 1/13/2011 NOTE'View Schematic w/Alaska Schematic9.0 SLEEVE-C;6,008.8 ii 6/4/2011 NOTE:CONFIRMED ISO-SLEEVE LEAK @ 6009'RKB � 9 4/17/2017 NOTE Spot Dynamic Acid Dispresion treatment with CT from 12,024 ft to 8,500 h PACKER;6,024.0 111!,: LOCATOR;6,061.4 SEAL ASSY;6,061.8 Isi.-=-. Ilillik ' k PRODUCTION,33.3-8,118 7 Squeeze Pers;8,203.0 MO IPERF;8,203.0-8,205.0 4N RPERF;8,389.0-8,384.0 RPERF;8,3E9.0-8,384.0 RPERF;8,369.0-8,384.0 Shot Sqz Parts,8,440.0 MO APERF;8,400.0-8,442.0 r '. 16. WINDOW;8,539.0-8,540.0 UPPER L1 TOP;8,496.0- 8,705.0 I JI11 , IlI �l LINER 10-02A;6,112.8-9,010.0 LOWER L1 TOP;8,705.0- 9,609.0 SLOTS;8,720.0-12,038.0 LINER 81.1;8,496.1-12,050.0 i i 0*/.'� I�j, THE STATE Alaska Oil and Gas it, ofALASKA Conservation Commission 333 West Seventh Avenue " 1. GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 *ti` Main: 907.279.1433 �F " m`e/'Q' Fax: 907.276.7542 AiAs www.aogcc.alaska.gov Jason Burke Wells Engineer NNE APR 1 9 2017 ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool,KRU 1 Q-02BL 1 Permit to Drill Number: 205-186 Sundry Number: 317-128 Dear Mr. Burke: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy 16. Foerster Chair DATED this day of April,2017. RBDMS - 4 2017 RECEIVED • • STATE OF ALASKA MAR 2 8 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION 4/41) 7 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑., . Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: a G is 517`kv irr 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory ❑ Development ❑ 205-186 3.Address: Stratigraphic ❑ Service 2_ 6.API Number: PO Box 100360,Anchorage AK 99510 50-029-21248-60 , 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? ©. �� KRU 1Q-026L1 Will planned perforations require a spacing exception? Yes 111 No 9.Property Designation(Lease Number): 10.Field/Pool(s): Kuparuk River Unit/ Kuparuk River Pool ADL 025634 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 12050' 6O 12050' 6J? Ilk 1464 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 64' 16" 100' 100' Surface 3794' 9-5/8" 3829' 3529' Intermediate Production 8086' 7" 8119' 6259' Liner 3554' 2-7/8" 12050' 6769' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8720'-12038' v 6625'-6769' 4.5" L-80 6078' Packers and SSSV Type: Baker HYFLO III Liner Top Packer Packers and SSSV MD(ft)and TVD(ft): '6119'MD&5112'ND Weatherford PB Packer . 5991'MD&5023'ND Weatherford ER Packer •6024'MD&5046'ND 12.Attachments: Proposal Summary 0 Wellbore schematic U 13.Well Class after proposed work: Detailed Operations Program ❑., BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service ❑., - 14.Estimated Date for 15.Well Status after proposed work: 4/3/2017 Commencing Operations: OIL LI WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑✓ • GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Jason Burke Email jason.burke@cop.com Printed Name Jason Burke Title Wells Engineer Signature Phone 907-265-6097 Date 3/27/2017 :141(4111 Or" e:r21//7 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 317— 12S5" Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ 1--kCS t: L-( I'-t I I' Other: RBDMS IL AP - 4 2017 Post Initial Injection MIT Req'd? Yes ❑ No Er Spacing Exception Required? Yes ❑ No L2 Subsequent Form Required: / —4 0 T In APPROVED BY A Approved by: i ! 7 '.`.- COMMISSIONER THE COMMISSION Date:4 - `t" 'r j 4- 4 firtelNi Submn Fbrm and Form 10-403 R vised 11/201 0r sIralid for 12 months fro e d e of approval. Attachments in Duplicate N 3/30// �� 0 • ConocoPhillips Alaska,Inc. Drilling& Wells ConocoPhillips Well Intervention Alaska 1Q-02B DAD Treatment (General Well Work) Engineer: Jason Burke Wells Engineer 907-231-4568 DAD, dynamic acid dispersion, is an acid outside-phase emulsion prepared and stabilized with dispersing agent F103. The purpose of the dispersion is to simultaneously dissolve acid-soluble minerals and remove oil paraffinic deposits. Target areas can be tubulars, perforations or the critical matrix. Objectives: Spot Dynamic Acid Dispersion (DAD) treatment with CT into perforations to fry to restore injectivity 1 • Coiled Tubing: Spot 200 bbl of DAD into formation 1. MIRU CT, MU 5 port wash nozzle BHA 2. Begin RIH, enter slotted liner completion at 8496' MD. 3. Continue RIH until TD 12050' MD is reached or until CT locks up 4. When CT has reached ultimate depth begin pumping DAD treatment. When treatment is exiting the CT (depending on CT volume) shut in the choke and begin POOH at a rate that will allow treatment to be spotted from final depth to 8750' MD (At 12050' MD 200 bbl/1 BPM=200 min & 3300 ft / 200 min=16.5 fpm). Chase the DAD treatment out of the CT with produced water or diesel. a. Do not exceed 4500 psi surface pressure 5. After an additional 5 bbl of fluid has been injected behind the treatment POOH 6. RDMO CT. Return well to injection. Function SLB Code Concentration Quantity Acid corrosion inhibitor A264 4 gpt 34 gal HCl H036 221.4 gpt 1865 gal Emulsifier F103 15 gpt 126 gal Iron Control L058 20 ppt 168 lbs Non-emulsifier W054 2 gpt 17 gal Xylene A026 100 gpt 840 gal February 14,2017 1Q-02B Well Work Procedure Page 1 of 1 KUP 1Q-02BL1 ConocoPhillips - Well Attributes Max Angle&MD TD Alaska 111, Wellbore APUUWI Field Name Well Status Ind(*) MD(ftKB) Act Btm(ftKB) o.rcn.�;rr.laps 500292124860 KUPARUK RIVER UNIT INJ 93.77 9,970.21 12,050.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date ••• Well Con(g:-1Q-030L1,111820124x08:53 PM SSSV:NIPPLE Last WO: 30.10 4/11/1985 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:WELL REVIEW osborl 1/10/2012 Casing Strings HANGER.21----91111 :.. Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String WL..String... String Top Thrd LINER BLI 27/8 2.441 8,496.6 12,050.0 6,769.6 6.16 L-80 STL Liner Details Top Depth IND) Top Incl Nomi... Top(ftKB) (ftKB) �) Item Description Comment ID(in) I 8,496.6 6,500.3 48.71 DEPLOY Li LINER BTT DEPLOYMENT SLEEVE 3.000 8,512.0 667:50:800))..73 ,510.7 49.18X0 Reducing CROSSOVER 3.5 x 3.1875,ID 2.812,#6.2,L-80,TCII 2.780 CONDUCTOR, 3a1oo 8,701.3 6,617.3 65.21 XO Reducing CROSSOVER 3.1875 x 2.875,ID 2.441,#6.16,L-80,STL 2.810 12,037.8 6,768.8 86.36 0-RING BTT O-RING PACK OFF 1.250 NIPPLE,000 Perforations&Slots Shot Top(ND) Btrn(TVD) Dens Top(ftKB)Blm(ftKB) (ftKB) ( ) Zone Date (sh... Type Comment 8,720.0 12,038.0 6,624.8 6,768.8 A-3,1Q-02BL1 11/25/2005 99.0 SLOTS 1Q-02BL1 SLOTTED LINER Ell" Notes:General&Safety SURFACE. End Date Annotation 35-3,830 11/27/2005 NOTE:MULTI-LATERAL SIDETRACK:1Q-02B,1Q-02BL1 1/13/2011 NOTE:View Schematic w/Alaska Schematic9.0 PACKER,5,981 • 6/4/2011 NOTE:CONFIRMED ISO-SLEEVE LEAK @ 6009'RKB IISMIL. PATCH,5,994- SLEEVE-C. 6.009 NO PACKER.6,024 - -I LOCATOR, , 8,061"- SEAL ASSY, 6,082 ii di PRODUCTION, 338,119 N 8.2038,205 + . Squeeze Pada. 8.213 RPERF, 8,389$,384 RPERF, 8,369-8,384 RPERF, 8,389-8,384 8,440-0,442 Sha Sq.Perk, 8,440 II WINDOW. 8.539-0.540 UPPER LI TOP, 8,496-8,705 a LINER 10-02A. ' n 8,1134,010 LOWER LI TOP, _ l 8.706-0.609 SLOTS. 8720-12038 ilk LINER BLI, 8,497-12,050 J L TD(I0-020L11, 12,050 KUP IQ-026 • ConocoPhillips ONWell Attributes • Max Angle&MD TD �>,I,iti,,:in: Wellbore APIIUWI Plaid Name Well Status Ind I.) MD(RKB) Act Btm(RKB) 500292124802 KUPARUK RIVER UNIT INJ 95.09 9,976.94 11,501.0 ' ' Comment H2S(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Date ••• Well Conte,-10-028,1/10/20124:06.09 PM SSSV:NIPPLE Last WO: 30.10 4/11/1985 Schematic-Actual Annotation Depth(RKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:WELL REVIEW osborl 1/10/2012 Casing Strings HANGER,21 Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR 16 15.062 36.0 100.0 100.0 62.58 H-40 WELDED Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String VOL.String...String Top Thrd SURFACE 95/8 8.921 35.3 3,829.5 3,528.9 36.00 J-55 BTC I Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd PRODUCTION 7 6.276 33.1 8,118.7 6,258.8 26.00 J-55 BTC Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd LINER 10-02A 4 1/2 3.958 6,112.9 9,010.0 6,650.6 12.60 L-80 NSCT Liner Details _ CONDUCTOR, I I Top Depth 36-100 (ND) Top Incl Nonni... Top(RKB) (RKB) 11 Item Description Comment ID(In) 6,112.9 5,108.0 45.66 SLEEVE BAKER LINER PACKER SETTING SLEEVE 5.500 NIPPLE,500 Fr 6,119.0 5,112.3 45.64 PACKER BAKER HYFLO III LINER TOP PACKER 5.063 6,121.4 5,113.9 45.64 SBE BAKER 80-47 SEAL BORE EXTENSION 4.750 MN. 6,135.9 5,124.0 45.59 HANGER BAKER CMC MECHANICAL LINER HANGER 4.125 6,145.1 5,130.5 45.56 XO Reducing CROSSOVER 5 x 4.5,ID 3.958,#12.60,L-80,NSCT 4.500 7,974.6 6,165.5 50.66 NIPPLE OTIS X LANDING NIPPLE 3.812 SURFACE, A I 8,451.8 6,469.1 47.31 MARKER Jr 3.958 35-3'630 Casing Description String 0... StringID...Top(RKB) Set Depth(f...Set Depth(ND)...String WL,.String ng...String Top Thrd WINDOW 4 3.958 8,539.0 8,540.0 6,528.9 6.16 L-80 PACKER.5.991 -- Casing Description String 0... String ID...Top(RKB) Set Depth(1...Set Depth(ND)...String WL..String...String Top Thrd UPPER L1 TOP 3 3/16 2.810 8,496.0 8,705.0 6,618.9 6.16 L-80 TCII igi MP Cuing Description String 0... String ID...Top(RKB) Sat Depth(f...Sat Depth(TVD)...String Wt...String...String Top Thrd �+;; LOWER Li TOP 27/8 2.441 8,705.0 9,609.0 6,696.2 6.16 L-80 STL PATCH,5,991 Casing Description String 0... String ID...Top(RWt...String...(RKB) Set Depth(f...Set Depth(TVD)...String StringTo Thrd SLEEVE-C, P 6.009 LINER B 2 7/8 2.441 9,609.2 11,501.0 6.16 L-80 STL ti Liner Details PACKER.6.024 - Top Depth 1111 (ND) Top Incl Nonni... Top(RKB) (RKB) ('I Item Description Comment ID(in) 9,609.2 6,696.2 82.83 BILLET WEATHERFORD LINER BILLET w/GS PROFILE&3.5'PUP 2.441 Tubing Strings. LOCATOR, Tubing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd Q061 TUBING 4 1/2 3.795 21.5 6,078.7 5,084.0 12.75 L-80 ABM-EUE SEAL ASSY, __ 6,062 l Completion Details Top Depth (ND) Top Incl Nonni... .r: i Top(RKB) (RKB) (°) Hem Description Comment ID(in) 421.5 21.5 -2.54 HANGER FMC GEN IV TUBING HANGER 4.500 500.2 500.2 0.60 NIPPLE CAMCO DB LANDING NIPPLE 3.875 6,008.8 5,035.4 46.04 SLEEVE-C 'BAKER CMU SLIDING SLEEVE-CLOSED 6/24/2011 3.812 6,061.4 5,071.9 45.81 LOCATOR BAKER LOCATOR 3.880 6,061.8 5,072.2 45.81 SEAL ASSY BAKER SEAL ASSEMBLY 3.875 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top Depth (TVD) Top Incl Top(RKB) (RKB) PI Description Comment Run Date 10(In) 5,991.0 5,023.0 46.12 PACKER WEATHERFORD PB PACKER 10/12/2011 2.375 5,994.0 5,025.1 46.10 PATCH SPACER PIPE&SNAP LATCH ASSEMBLY 10/122011 2.250 6,024.0 5,045.9 45.98 PACKER WEATHERFORD ER PACKER 10/5/2011 ' 2.375 MO Perforations&Slots Shot Top(ND) Btm(TVD) Dens Top(RKB)Btm(RKB) (RKB) (RKB) Zone Date (sh•- Type Comment 9,623.0 11,499.0 6,697.9 A-3,A-4,A-5, 11/18/2005 99.0 SLOTS STL SLOTTED LINER 1Q-02B PRODUCTION. 6.2m :11 9 N • • Notes:General&Safety Squeeze Perls, End Date Annotation RPERRF, 11/27/2005 NOTE:MULTI-LATERAL WELL w/SIDETRACK 1Q-02B,LATERAL LEG 1Q-02BL1 8,369-8,384 RPERF, 6/4/2011 NOTE:CONFIRMED ISO-SLEEVE LEAK @ 6009'RKB 8,369-8,381 RPERF. 8,369-8,3844 8,44040-8,4 V 8,440 Shot SPella 440 WINDOW, I 8.539-8,540- UPPER Lt TOP, 8,496-8,705 IJI U LINER 10-026. 6,113.9,010 LOWER L1 TOP, 8,7059,608 VI SLOTS, 9,62311,499 1 I 9,809-11,50 LINER B, 1 TD(10-02B), 11,501 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~Q~ - ~ ~ ~ Well History File Identifier Organizing (done) ~wo-sided ~{I II'II~ l~ I~I II ~I~ ^ Rescan Needed III IIIIII II II III III R CAN DIGITAL DATA OVERSIZED (Scannable) Color Items: ^ Diskettes, No. ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: ^ Other: OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: ^ Other:: BY: ~ Maria) Date: ~~ ~ (.J ~ (~ ~j /s/ y ~~ Project Proofing III IIIIII VIII II Ill BY: Maria Date: ' ~ /s/ 1 Scanning Preparation ~~, x 30 = ~~ + ~ =TOTAL PAGES (Count does not include cover sheet) BY: Maria Date: Q /s/ Production Scanning III II II II II III V III Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ES NO BY: Maria Date: a~' q~0~ /s/ Y~/I 1 YYY~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III II'II) III II I I III ReScanned III II'lI) VIII II III BY: Maria Date: /s/ Comments about this file: Quality Checked III II'lll1ll Ilil III 10/6/2005 Well History File Cover Page.doc ~. ~ DATA SUBMITTAL COMPLIANCE REPORT 1 /29/2008 Permit to Drill 2051860 Well NamelNo. KUPARUK RIV UNIT 1Q-026L1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-21248-60-00 MD 12050 TVD 6758 Completion Date 11/27/2005 Completion Status 1-OIL Current Status WAGIN UIC Y REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: MWD GR / RES Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ~'j,@D D Asc Directional Survey ''~ Rpt Rpt Directional Survey Directional Survey ~v~pt 15271 LIS Verification tS 1r~.7r ~ G t ~'~~~`~,`r.. `~ . -~og 15271 ~ InductionJResist vity ~-COg 15271 Induction/Resistivity Well Cores/Samples Inform ation: Name Interval Start Stop {data taken from Logs Portion of Master Well Data Maint Log Scale Log Run Media No Interval Start Stop OH ! CH Received Comments 0 12050 Open 10-026, 1Q-026 P61, 10- 026 L1 on diskette 0 12050 Open 10-026 L1 8548 12050 Open 7/6/2007 LIS Veri, GR, ROP w/Graphics PDF And Meta 25 Blu 8548 12050 Open 7/6/2007 MD Multi Prop Res GR 26- Nov-2005 25 Blu 8548 12050 Open 7/6/2007 TVD Multi Prop Res GR 26- Nov-2005 Sent Received Sample Set Number Comments ADDITIONAL INFORMATION Well Cored? Y~ / Chips Received? ~L.LA}~ Analysis -~/ /7~ Received? Daily History Received? Formation Tops ~-N Y/N Comments: Samples No Directional Su - -- - ---- - _ - -_ Compliance Reviewed By: ___ _ ____ _ - __ __ Date: _~~_~~ Transmittal Form ~~~~ men me~uax nmrwu BAKER NuGNES ~' INTEQ tzltaa.uva aka.. vr.v.~a•aa.u..a. a..a.uw. Lam,.,... «.«~,. ~~ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska °-IT,x 99501 Attention: Christine Mahnken •~•°~- ~ Reference: 1Q-02B, 1Q-02BL1, 1Q-02BPB1 ~ --•~ Contains the following: 3 LDWG Compact Disc (Includes Graphic Image files) 3 LDWG lister summary 1 3 bluelines - MPR-DIR_md Log 3 bluelines - MPR-DIR tvd Log 1 LAC Job#: 1011834 Sent By: Cosetta Todirica D 0 ~~',;~ ,,~•` ~? Date: !~~~- ~ ~d 2007 Received By• ~_~. ~ ,~,~;t E C~ Cons. Comr~iss~cn Anc~~e PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY _ FAX: (907) 267-6623 ~ ~~ ~~~ _ ~~ ~ Baker Hughes INTEQ _ 7260 Homer Drive ~ ~~~~ Anchorage, Alaska _ 99518 ~ l ~ ~~% Direct: (907) 267-6612 _ FAX: (907) 267-6623 =::. _ ;; ~- , ... ______ ~ ! ~ E i, ~ - K . ~_ = ~..._ ~ ~, a : 1 ~ ~'~ 1 ~ RECEIVED STATE OF ALASKA NOV 2 O ~0~6 ALASKA OiL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONSst3s~a oa ~ Gas cons. commission 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other. A ~to WAG Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConoCOPhillipsAlaska, InC. Development ^ Exploratory ^ 205-1867 3. Address: Strati ra hic g p ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21248-60 7. KB Elevation (ft): 9. Well Name and Number:. RKB 78' 1Q-026L1 8. Property Designation: 10. Field/Pool(s): ADL 025634 Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 12050' feet true vertical 6758' feet Plugs (measured) Effective Depth measured 12050' feet Junk (measured) true vertical 6758' feet Casing Length Size MD ND Burst Collapse' Structural CONDUCTOR 100' 16" 100' 100' SURFACE 3752' 9-5/8" 3830' 351 T PRODUCTION 6190' 7" 6268' 5205' LINER 10-02A 2955' 4-1/2" 9010' 6639' wwDOw 1' 3-1/2" 8540' Perforation depth: Measured depth: 8369' - 8384', slotted liner 8720' - 12038' true vertical depth: 6407 - 641 T, 6613' - 6757 Tubing (size, grade, and measured depth) 4-1/2" , L-80, 6061' MD : Packers &SSSV (type & measured depth) no packer SSSV= NIP SSSV= 500' 12. Stimulation or cement squeeze summary: - - Intervals treated (measured) 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 51 451 9 200. 173 Subsequent to operation 4134 1100 1714 14. Attachments 15. Well Class after proposed"work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service^ Daily Report of Weli Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG Q 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: 306-318 contact Bob Christensen /Bob Buchholz Printed Name ert ristense Title Production Engineering Technician Signature Phone 659-7535 Date jl /~ ~ R~,~." ~9 ~,. Uzi ~~ `~ ~ 2Q06 Form 10-404 Revised 04/2004 G l ~) ~ 1 N A L Submit Original Only 1 Q-02BL1 DESCRIPTION OF WORK COMPLETED SUMMARY Date. Event Summary 10/19/06 Commenced Injection Service • _. ; ~; ~ - ? a v . ~-~ - ' - = FRANK H. MURKOWSKI, GOVERNOR ~1 t~iac-l~-t7~~ O~ ~ _ ~-7 333 W. 7TM AVENUE, SUITE 100 CO~SsIRQAiiO~ CODII-iIS~O~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 " FAX (907) 276-7542 Robert Buchholz Production Engineering Technician ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1 Q-02BL 1 Sundry Number: 306-318 Dear Mr. Buchholz: 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. When providing 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. Sincerely, i~-_ Cathy P. Foerster Commissioner DATED this ~~ day of October, 2006 Encl. • • Conoc~hillips September 11, 2006 To: Tom Maunder, P.E. Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission 33 W. 7`h Ave. Ste. 100 Anchorage, AK 99501 Subject: Sundry Applications for Proposed Change of Well Class Robert Buchholz J Robert Christensen Production Engineering Tech. Greater Kuparuk Unit , NSK-69 PO Box 196105 Anchorage, AK 99519-6105 Phone: (907) 659-7535 Fax: 659-7314 i ~ ~° ~~° "_~,ti j ,e ~ -r -:~ - -_~ r _,J . ConocoPhillips Alaska, Inc. submits the attached sundry applications for proposed change of well class on Kuparuk well 1Q-02B and ,,I~-62L2 8~ ~ ~ ~.~3 ~~ ConocoPhillips Alaska, Inc. submits the attached sundry applications for proposed change of well class on West Sak wells 1J-127, 1J-127L1, 1J-127L2, 1J-184, 1J-184L1. If you have any questions regarding this matter, please contact myself or Robert Christensen at 659-7535. Robert W. Buchholz Attachments: 10-403 Forms DECEIVED STATE OF ALASKA ~ , `~~ S E P 1 2 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVA~~aska oil & Gas Cons. Commission 20 AAC 25.280 Anchorage 1. Type of Request: Abandon ~ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ~ Other Q Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ ~'~ w~./l~~ • Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ ~~ 9,~3•Q~ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q Exploratory ^ 205-186 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-21248-60 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? YeS NO ~ 10-026L1 9. Property Designation: 10. KB Elevation (ft): 11. FieldlPool(s): ADL 025634 " RKB 78' Kuparuk River Field /Kuparuk Oil Pool 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured}: 12050' 6758' 12050' • 6758' ' Casing Length Size MD TVD Burst Collapse CONDUCTOR 100' 16" 100' 100' SURFACE 3752' 9-5/8" 3830' 3517' PRODUCTION 6190' 7" 6268' 5205' LINER 1Q-02A 2955' 4-112" 9010' 6639' WINDOW 1 ~ 3-112" 8540' 6517' Pertoration Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8369' - 8384', slotted liner 8720' - 12038' 6407' - 6417', 6613' - 6757 4-1 /2" L-80 6061' Packers and SSSV Type: Packers and SSSV MD (ft) no packer SSSV= NIP SSSV= 500' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: October 7, 2006 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG 0 GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob Christensen I Bob Buchholz Printed Name Robert W. Buchholz ®~ Title: Production Engineering Technician Signature l ~ / ~/.s~y~ ~~f~i~ Phone 659-7535 Date ~~~/~ 6 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representat ive may witness 3 L Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ Other: . , ~ ~~I~. ~ C1 1 ~ 1006 Subsequent Form Required: ~ L~ (,,,\ APPROVED BY / ~" Approved MISSIONER THE COMMISSION Datq! Form 10-403 Rev' ed O6/20 Submit in Duplicate 1 Q-02BL1 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to begin Water Alternating Gas (WAG) Injection service in Kuparuk Dual-lateral Well 1Q-02BL1. This well was pre-produced since January 15, 2006. Lateral 1Q-02BL1 will provide pressure support to offset producers. "'' The 9-5/8" Surface casing (3830' and / 3517' tvd) was cemented with 1000 sx Coldset III followed by 420 sx Coldset I. The 7" Intermediate casing (8119' and / 6247') was cemented with 550 sx Class G followed by 250 sx Coldset I. The injection tubing/casing annulus is isolated via Baker 5-1/2" X 7" HyFlo III Liner Top Packer with Baker Sealbore Extension located @ 6061' and 15060' tvd. Following a liner setting sleeve, this well also contains a Baker 5-1/2" X 7" HyFlo III Liner Top Packer with Baker 80-47 Sealbore Extension located @ 6119' and / 5100' tvd. ~~~' ~~l~~~c~~~t~ltip~ A~~sk~l ~~~: 1Q-02BL1 TUBING j (asosl, P '';~ OD:4.500, ID:3.958) TTL '- - (sosasosl, ~ OD.4.500) i LINER 14-02A (so5s-solo, OD:4.500, Wt:12.60) LINER 14-02BL1 (8496-8705, OD.3.188, Wt6.16) i''' ' Perf (8720-12038) RETAINER (8883-8884, - OD:4.500) 3 • KRU 1 Q-02BL1 API: 500292124860 Well T : PROD An le TS: d SSSV T e: NIPPLE Orig Com letion: 11/27/2005 Angle TD: 86 deg 12050 i Annular Fluid: Last W/O: Rev Reason: Show TVDs Reference Lo Ref Lo Date: Last U date: 7/25/2006 Last Ta TD: 12050 ftKB Last Tag Date - - - - - - Max Hole An~le_ 94 deg @ 9970 - -- Casin~ Stringy - COMM_ON_S_TRINGS _ _ __ _ _ _ __ _ _ _ Descri lion Size To Bottom ~ ND V11t _ -- -- Grade _ _ _ - Thread SURFACE 9.625 0 3830 3517 36.00 J-55 PRODUCTION 7.000 0 6268 5205 26.00 J-55 CONDUCTOR 16.000 0 100 100 62.50 H-40 WELDED LINER 1 Q-02A 4.500 6055 9010 6639 12.60 L-80 LINER 1Q-02BL1 3.188 8496 8705 6607 6.16 L-80 TCII WINDOW 4.000 8539 8540 6517 6.16 L-80 STL LINER IQ-02BL1 2.875 8705 12050 12050 6.16_ Tubing String= TUBING _ - _ -- Size ~ To ~ Bottom TVD Wt i Grade ~ 4 500 _ _ 0 _ 6_061_ _ - 5_060. 12.75 i L 80 _ i _ P_erfvratio_ns S_um_m_ary_ _ _ _ _ _ _ _ _ _ _ _ __ Interval ND Zone Status ` Ft SPF Date T e _L_-80 _ ___STL - -- _ Thread_ ABM E_U E _ _ - Comment 8369 - 8384 6407 - 6417 15 4 10/19/1998 RPERF 1Q-02A PERFS 8720 - 12038 Other (plugs, De th TVD 6613 - 6757 3318 99 11/25/2005 Slots 1Q-026L1 SLOTTED LINER equip., etc.) -COMMON_J_EW_EL_RY _ _ __ - - __-_____ _ _ I T e Descri lion ~ ID 500 500 NIP CAMCO'DB' LANDING NIPPLE 3.875 6009 5024 SLEEVE-C BAKER CMU SLIDING SLEEVE -CLOSE 2/16/2006 3.812 6009 5024 PUMP 4112" CAMCO D-6 LOCK ON JET PUMP (SN# PH-1135) 67" OVER ALL 10C-RATIO, 10 NOZZLE , #12 THROAT set 1/8/2006 0.000 6055 5056 TIEBACK BAKER 5.500 6060 5059 TTL TUBING TAIL 3.958 6061 5060 PACKER BAKER'HYFLOW III' PACKER 5.063 6113 5096 Setting SLEEVE BAKER LINER SETTING SLEEVE 5.500 6119 5100 PACKER BAKER 'HYFLO III' PACKER 5.063 7975 6154 NIP OTIS'X' LANDING NIPPLE 3.812 8705 6607 XO 2.875 88_83 Other ( De th 6635 plugs, ND RETAINER equip., etc T e BAKER CEMENT RETAINER _ _ _ _ _ _ __ .) - 1Q-02B LATERAL JEWELRY Descri lion _ _ _ _ _ _0.000 _ i ID 8496 6489 Deploy SLEEVE BTT DEPLOYMENT SLEEVE 3.000 12048 ~Gener Date 6757 _SHOE UN{O_UE I_NDEXING_G_UIDE SHOE _ _ alNotes----- ----------------- Note --__-- 2.411 ----~ 1!27/200 MULTI-LATERAL SIDETRACK: 10-026,14-026L1 l~,'C:~iANICAI, INTEGRITY .PORT ~'~~~~ `~ OPER ~ FZELD ~~ R ~ 1LJ pc~.~J 1~-. n ~ LL J AT: _ TD : ?~.. 'I'V~D ; ? BTD : ? ID ='VD 1,:~,~;-~'- ~:~s ~^-~ _ i.~ t (.~ „ Shoe : '~4 ~ ~~ t~ID TVD ; °T'aP ~ : ~3©.~ 5 ?~ =~~i -==~e_ : ~~~~- Shoe: ladS~C '~ T`J?J ; =CP . '•~ ~',"D ~ ,~ ~o~- ~ ~ ~~ PaCK~= ~o~~p, ~ TVD; ~ ~ Set et mole 5_ce ~o ~~~ ena ~~'~~ Perfs S~~ ~ \.~~r t-ti~c~ `o ~ '"`=.~:.ct~?~=C~'. TNTEGR?'TY - PA~.T # -?nrulus Press Test: _~ 15 nin ~0 min Comments: i CH.F N 1 C~i INTE GRTT'*' _ PART # 2 \., 4 ~~.~o Cement Volumes : Amt . Liner L1'Ia`` Cs ~ DV ~~ Cr,t -col to cover oers _ eore tical TOC Cement Bond Log (Yes or No) L" In AOGCC File ~ C3L Evaluation, Y gone above perfs C,.k~' ~-~ uh~~~ vJ~.~~~ cX: ~-~ ~'~`a5` 1~ 5 ic.~c-~~ ,o S~wS`~v~ f~ `~O4"~.` Production Log: '?'yve Evaluation CONCLJSIOIZS Part #l: ~- , ?art 12 : (`'~ ~ i S `~~ ~Cc~: ~L'= J ~ ~1~ f a 3 ~ ~ DECEIVED STATE OF ALASKA DEB 4 2 X006 ALASK {LAND GAS CONSERVATION COMSION WELL COMPLETION OR RECOMPLETION REPORT ANDA Oil & Gas Cons. Commission AgOduced Injector 1a. Weil Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG zoAAC zs.,os zoAAC zs.,,o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other ib. Well Class: ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: Conoco Phillips Alaska Inc. 5. Date Comp., Susp., or Aband. 11/2712005 ~ 12. Permit to Drill Number 205-186 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 11/20/2005 ' 13. API Number 50-029-21248-60-00 4a. Location of Well (Governmental Section): Surtace: ' ' 7. Date T.D. Reached 11/25/2005 14. Well Name and Number: Kuparuk 1Q-02BL1 1206 FNL, 1175 FEL, SEC. 26, Ti2N, R09E, UM Top of Productive Horizon: 560' FSL, 2264' FEL, SEC. 24, T12N, R09E, UM 8. KB Elevation (ft): 78' 15. Field /Pool(s): Kuparuk River Unit /Kuparuk River Pool Total Depth: 3680' FSL, 3211' FWL, SEC. 24, T12N, R09E, UM 9. Plug Back Depth (MD+TVD) 12050 + 6758 Ft 4b. Location of Welt (State Base Plane Coordinates): Surface: x- 528448' y- 5984667 'Zone- ASP4 10. Total Depth (MD+TVD) 12050 + 6758 ~ Ft 16. Property Designation: ADL 025634 TPI: x- 532631 y- 5986450 Zone- ASP4 Total Depth: x- 532811 Y- 5989571 Zone- ASP4 11 • Depth where SSSV set 500' MD 17. Land Use Permit: --"------"----"---- ~----~----------~--- -"---"- -~-"--~--- i f f 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL Perma rost 20. Th ckness o 1380' (Approx.) 21. Logs Run: ~' !~J o~w c2 ' ~h D ' '7--/D MWD GR / RES 5'G ~ ~-~ ~• 3 • ~G 2. ASING, LINER AND EMENTING RECORD .CASING INO PTH MD EITINQ EPiH TVD ..HOLE MOUNT SIZE WT. PER FT. GRADE OP TTOM OP TTOM SIZE. CEMENTING REGARD PULLED 16" 62.5# H-40 Surtace 100' Surtace 100' 24" 40 sx Coldset II 9-518" 36# J-55 Surface 3830' Surface 3517' 12-1/4" 1000 sx Coldset III, 420 sx CS I 7" 26# J-55 Surtace 6268' Surface 5205' 8-1/2" 550 sx Class 'G', 250 sx CS I 4-1/2" 12.6# L-80 6055' 8539' 5055' 6516' 6-1/8" 113 sx class'G' 3-,/2° x 3-3/16" x 2-7/B" 92# / 6.a# / 6.,6iF L-80 8497' 12050' 6489' 6758' a-,ra• x 3-3ra• Uncemented Slotted Liner 23. Perforations open to Produc tion (MD + TV D of Top and " " 24. TUBING RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Slotted Section Note: 4-1/2", 12.75#, L-80 6061' 6061' MD TVD MD TVD 87201' - 12038' 6613' - 675T Only Welf Branch 1 Q-02BL1 15 25. ACID, FRACTURE,: CEMENT SQUEEZE, ETC. Directly ibl A DEPTH INTERVAL MD AMOUNT $c KIND OF MATERIAL USED ccess e Freeze Protect with 20 Bbls of McOH 26. PRODUCTION TEST Date First Production: January 21, 2006 Method of Operation (Flowing, Gas Lift, etc.): Water Jet Lift Oil Date of Test 1/2112006 Hours Tested 14 PRODUCTION FOR TEST PERIOD OIL-BBL 380 GAS-MCF 622 WATER-BBL 193 CHOKE SIZE 209 Bean GAS-OIL RATIO 1639 Flow Tubing Press. 22 Casing Pressure 2130 CALCULATED 24-HOUR RATE OIL-BBL 651 GAS-MCF 1067 WATER-BBL 331 OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". t ... _~ t S ~~~ ~=E~ ~~ ~a 2DOfi ~ ~ ~= None ` x`27 ~ b Form 10-407 Revised 12/2003 ~ ~gy z ~~ ~ ~ $ ~<~j TI~IUED UN REVERSE SIDE 28. GEOLOGIC MARKER 29' -OFiMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". (From 1 Q-02B) None Kuparuk A3 8702' 6606' 30. List of Attachments: Summary of Daily Drilling Reports, Wetl Schematic Diagram, Surveys 31. I hereby certify that the foregoi g is true and correct to the best of my knowledge. Signed Terris Hubble Title Technical Assistant Date ~~Dr~ Kuparuk 1 Q-02BL1 205-186 Prepared By NamelNumber. Terris Hubble, 564-4628 Well Number Drilling Engineer: Aras Worthington, 440-7692 Permit No. / A royal No. INSTRUCTIONS GeNeRAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: True vertical thickness. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: if this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: If no cores taken, indicate "None". IreM 29: list all test information. if none, state "None". Form 10-407 Revised 12/2003 Submit Original Oniy BP EXPLORATION Page 1 of 16 Operations Summary Report Legal Well Name: 1 Q-02 Common W ell Name: 1 Q-02 Event Nam e: DRILL+C OMPLE TE Contractor Name: NORDIC CALIST A Rig Name: NORDIC 2 Date II From - To I -~ Hours ~~ Task j ~ Code I NPT -- 11/6/2005 ---- 00:00 - 01:30 _--- 1.50 -_ MOB . _ P 01:30 - 01:45 0.25 MOB P 01:45 - 02:00 0.25 MOB P 02:00 - 02:45 0.75 MOB P 02:45 - 03:30 0.75 MOB P 03:30 - 03:45 0.25 MOB P 03:45 - 04:15 0.50 MOB P 04:15 - 05:00 0.75 RIGU P 05:00 - 05:45 0.75 BOPSU P 05:45 - 06:15 0.50 BOPSU P 06:15 - 06:30 0.25 BOPSU P 06:30 - 12:00 5.50 BOPSU P 12:00 - 13:30 1.50 BOPSU P 13:30 - 17:30 4.00 BOPSU P 17:30 - 18:00 0.50 RIGU P 18:00 - 18:20 0.33 RIGU P 18:20 - 18:45 0.42 RIGU P 18:45 - 19:45 1.00 RIGU P Spud Date: 11{512005 Start: 11/5/2005 End: 11/27/2005 Rig Release: 11/27/2005 Rig Number: Phase I Description of Operations PRE ND BOPE and secure in cellar for move. NU tree cap. Pressure test to 500 psi and 4000 psi with diesel. Passed ok. PRE Prepare to move rig off of 10-04 and onto 10-02. Spin tires to warm moving system. Move cuttings box, and other equipment out of the way. Break hardline to tiger tank. PRE Hold PJSM Re: Moving from 10-04 to 10-02. Discuss job assignments. Place block between rig and wellhead. Note -Due to time adjustment, Accept rig at 02:00. PRE Move rig from iQ-04 and stage in front of 10-02. PRE Place Herculite around wellhead. Move rig mats from 10-04 to 1 Q-02. Shut in well on driller side of 10-02 (Pad Operator). PRE PJSM prior to moving over well. Attended by all rig hands, MWD hand, TL, TP, WSL, DSO. PRE Move rig over well 10-02. PRE Set rig down over well. Begin rigging up. PRE Begin NU BOPE. PRE Hold Safety Standdown with day crews in conjuction with Tech Limit meeting. Discussed recent field accidents, increased safety awareness with the cold/dark winter weather conditions. Reviewed our commentment to safety on the rig and present working tasks and conditions. Also reviewed hazards we will need to deal with on this particular well concerning pressure deployment of tools. PRE After crew changeout held PJSM and reviewed "SIMOPS Plan" guide to swapping rig over to 2-3/8" coil and NU BOP's. Gave out job assignments to individual crew members and or teams. PRE Install XO flange to BOP stack for this well. Lift reel into reel house and secure. (Will need to allow it to warm-up). Take on 480 bbls of 8.9ppg used Flo-Pro that was in storage at MI. NU BOP stack. Start working on injector changing out gripper blocks from 2" to 2-3/8°. PRE Nordic crew change day. Oncoming crews briefed about present work and reviewed SIMOPS Plan. Continue NU BOP chokelkill lines. Continue with injector gripper block swp. Grease choke manifold valves. Prep to test BOP's. Empty 2 upright Flo-Pro tanks in Tank Farm and prep to move tanks to new Tank Farm location which will be out of the way of Nordic #3 operations. PRE Test BOPE. AOGCC witnessing waived by Chuck Sheive. Test 250flow 40001high. Suspend working on injector until all rams were tested then resumed changing gripper blocks. Finished Tank Farm move. Instal{ internal grapple & pull cable into end of coil. Drawdown test accumulator. Finished installing gripper blocks. PRE Start on gooseneck change over. PRE Pre spud meeting with oncoming night tour and Aras Worthington from Anchorage office. PRE Crew change. PRE Hold Safety Stand down with night tour. Discuss recent inicidents in the rotary world that could have resulted in serious injuries. Discussed complacency, and how safety is a journey, Printed: 11/28/2005 12:59:04 PM BP EXPLORATION Operations Summary Report Legal Well Name: 1Q-02 Common Well Name: 1 Q-02 Event Name: DRILL+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To i Hours Task Code'I NPT ~~ 11/6!2005 18:45 - 19:45 1.00 RIGU P 19:45 - 22:30 2.75 RIGU P 22:30 - 0.00 RIGU P Start: 11 /5/2005 Rig Release: 11 /27/2005 Rig Number: Phase PRE PRE PRE 1117/2005 00:00 - 00:20 0.33 RIGU P PRE 00:20 - 01:00 0.67 RIGU P PRE 01:00 - 02:30 1.50 RIGU P PRE 02:30 - 04:05 1.58 RIGU P PRE 04:05 - 06:00 I 1.921 RIGU I P I I PRE 06:00 - 06:30 0.50 RIGU P PRE 06:30 - 08:45 2.25 RIGU P PRE 08:45 - 09:00 0.25 RIGU P PRE 09:00 - 09:15 0.25 RIGU P PRE 09:15 - 11:00 I 1.751 RIGU I P I I PRE 11:00 - 14:00 I 3.001 RIGU I P I I PRE 14:00 - 14:15 0.25 RIGU P PRE 14:15 - 16:30 2.25 RIGU P PRE 16:30 - 18:00 1.50 RIGU P PRE 18:00 - 18:30 0.50 CLEAN P W EXIT 18:30 - 19:35 I 1.08 I CLEAN I P I I W EXIT 19:35 - 21:00 I 1.42 I CLEAN I P I I W EXIT 21:00 - 21:20 I 0.331 CLEAN I P I I W EXIT 21:20 - 21:55 ~ 0.58 ~ CLEAN ~ P ~ ~ W EXIT Page 2 of 16 Spud Date: 1115!2005 End: 11 /27/2005 Description of Operations and not a destination. Asked hands to have a renewed commitment to safety. Each hand was asked to make a rig walkaround in an area he does not normally work in and write 2 stop cards. Good participation from all hands on rig. Slip and cut 50' of drilling line. PU injector. Attach packoff. Attach gooseneck. Change packoff elements and brass inserts. PJSM prior to stabbing coil. Pull coil off reel and stab into injector. Make up hose to reverse circulate. Stab injector onto well. Reverse circulate 25 bbls of methanol, followed by water spacer then mud to perform slack management. Good audible indication of slack eline moving in the coil, SD pumps. Blow back end of coil with rig air to FP. Rig up hardline in reelhouse, and Jupiter cable. Held TL meeting and Pre-Spud meeting with .daylight crews. Continue MU inner reel hardline and a-line junction box. PJSM review coil cutting procedures and hazards. Attempt to check well pressures before unstabbing injector: Master vavle is pressure locked. Call valve shop. Slowdown kill line to prevent freezing. Unstab injector. Seen 11' of a-line beyond end of coil. Trim back 8' of coil. Install Kendal CTC. Pull test to 40K MU Baker UOC. Cut/slip 60' of .125" slickline then rehead. PU BHA to mousehole and motor/mill to well. Check WHP...slight but enough to flow 1"stream. PSJM review "Pressure Deployment" procedures. Pressure deploy BHA #1 following guideline steps.Shut-in well and pop off lubricator seen we've mismeasured spaceout of double ball valves. Too high. Stab lubricator open well and slackoff to lower set depth. Shut-in well again. Remove lubricator and standback. PT UOC assembly to 3500psi. MEG test tools. Stab injector. Open BOP's. Tag-up set depth. RIH w/ BHA #1 Continue RIH with mill and motor. Clean thru 7370' where eline had trouble with whipstock. Clean to dry tag up at 8612' CTM. Kick on pumps. Start displacement of well to mud. Log tie in pass down over RA charecter at 8200'. Make -14.5' correction. RIH at 25 fpm and pumps at 2 bpm. Found hard bottom at 8688'. Pick up off bottom. Kick on pumps to full rate. 4300 psi at 2.5 bpm. Seems high. SD pumps, open EDC. Kick on pumps circ press at 2.5 bpm is 3200 psi. Mud appears to be vis'ed up a bit. SD pumps, shut EDC. Come on line with pumps, POOH pumping at 2.3 bpm, 4000 psi. Got a fair amount of pipe scale/cement chunks while POH. Good call to run the cleanout run. Tag up at surface. Start to flow check well. Hold PJSM. Discuss 2 options. Well is dead, Well is not dead and we need to undeploy. Review undeployment proceedure in detail. Assign individuals to tasks on undeployment proceedure. Flow check of well confirms that well is dead. Break injector. Printed: 11/28/2005 12:59:04 PM BP EXPLORATION Operations Summary Report Legal Well Name: 10-02 Common Well Name: iQ-02 Event Name: DRILL+COMPLETE Start: 11/5!2005 Contractor Name: NORDIC CALISTA Rig Release: 11/27/2005 Rig Name: NORDIC 2 Rig Number: Date ~I From - To ~ Hours ~~ Task I Code ~ NPT I Phase 1 i/7f2005 21:20 - 21:55 21:55 - 22:50 0.58 CLEAN P 0.92 STWHIP P 22:50 - 00:00 ! 1.171 STWHIPI P 11/8/2005 00:00 - 01:00 01:00 - 01:20 01:20 - 01:55 01:55 - 02:05 1.00 STWHIP P 0.33 STWHIP P 0.58 STWHIP P 0.17 STWHIP P 02:05 - 03:30 03:30 - 04:45 04:45 - 06:30 06:30 - 13:30 1.42 STWHIP P 1.25 STWHIP P 1.75 STWHIP P 7.00 STWHIP P 13:30-13:10 ~ 23.67~STWHIP~P WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT 13:10 - 13:40 0.50 STWHIP P WEXIT 13:40 - 14:15 0.58 STWHIP P WEXIT 14:15 - 15:40 I 1.421 STWHIPI P I I WEXIT 15:40 - 16:00 0.33 STWHIP P WEXIT 16:00 - 17:30 1.50 STWHIP P WEXIT 17;30 - 20:15 ~ 2.75 ~ DRILL ~ P ~ ~ PROD1 20:15 - 22:30 2.25 DRILL P PROD1 22:30 - 23:00 0.50 DRILL P PROD1 23:00 - 23:15 0.25 DRILL P PROD1 23:15 - 00:00 0.75 DRILL P PROD1 11/9/2005 00:00 - 03:00 3.00 DRILL P PROD1 03:00 - 05:00 I 2.001 DRILL I P I I PROD1 -~ _ ~ _ Page 3 of 16 Spud Date: 11/5/2005 End: 11 /27/2005 Description of Operations Lay down BHA #1, clean out mill and motor. MU BHA #2, WF WS setting BHA. WS tray face scribed to orienter. RIH with BHA #2 to set WF whipstock. Pumping at 0.5 bpm thru an open EDC. RIH at 70 fpm. Continue RIH with BHA #2. Log tie in pass down from 8220'. Make -i 1' correction. Log CCL pass down from 8260'-8540'. Confirmed on depth. Move set depth up to put WS top at 8540' to avoid casing collar deeper. Check PU weight, and found at 32500 lbs. Bring pumps up. Pressure up on setting tool. Saw indication of set. Set 5000 {bs on whipstock. Good inciation of set. PU at 31000 lbs. Confirmed set whipstock. WS tray oriented to 30 deg left of high side. Top of whipstock at 8540' Bot of whipstock at 8553'. Open EDC. Pump at full rate while POOH. Pumping at 3076 psi at 2.3 bpm. Lay down BHA #2, whipstock setting BHA. PU BHA #3, window milling BHA. Running WF 0 deg motor, HCC string reamer, WF window mill. RIH with BHA #3 to mill window. Tagged at 8540.3' Mill window f/ 8540.3' to 8547'. 2.70!2.70 free-spin 3950psi 100-150psi mototwork following time milling schedule. Max wob 6k most time 2-3k. Milied to 8547'. Shut-in well trapping 1000psi. Held for 5min. No leak-off. Called town to confirm pressures and wait times. Drill open hole from 8547' to 8558'. Make 2 up and down reaming passes thru the window. No motor work or problems observed. Dry drift window up and down. No problems observed. POOH to pick up build section BHA. Hold PJSM and review undeployment proceedure. Trap 550 psi on wellhead. Pressure undeploy window milling BHA. Mills recovered in good shape. WF whipstock mill recovered at 3.79" Go, 3.78" No-Go, and had the proper swirl pattern on the face. HCC string reamer recovered at 3.80" Go, 3.79" No-Go. Make up BHI MWD tool for build section. (2.3 deg mtr w HTC bi-center) /Electrically test same. Pressure deploy BHA. Found 305 psi on well. Had trouble getting bit past tbg hanger. Get off well and turn bit 180 deg. Get through tbg hanger ok. Stab coil. Test mwd. Get on well. Run in hole following WHP schedule. Log gr tie in from 8210 to 8250'. Subtract 16' correction. Continue to RIH. Orient to 40L to pass through window. Drill ahead from 8558'. 3535 psi fs Q 2.6 bpm. Drill build from 8570'. 3550 psi fs at 2.6 in/out. DSPI:i00-200. DHWOB: 1.0-1.5 k#. WHP/BHP/ECD: 66/3651/10.9 ppg. IA/OA/PVT: 260/146/320 bbls. Several stalls just outside window. ROP averaging 25-30 fph. Continue to drill build section from 8700'. Printed: 11/28/2005 12:59:04 PM BP EXPLORATION Page 4 of 16 Operations Summary Report Legal Well Name: 1 Q-02 Common Well Name: 1Q-02 Spud Date: 11/5/2005 Event Name: DRILL+COMPLETE Start: 11/5/2005 End: 11/27/2005 Contractor Name: NORDIC CALISTA Rig Release: 11/27/2005 Rig Name: NORDIC 2 Rig Number: Date I From - To ~~ Hours !~ Task Code ~'~ NPT Phase ! Description ofOperations i 11!912005 05:00 - 05:15 0.25 DRILL P PROD1 Wiper trip to window. 05:15 - 06:00 0.75 DRILL P PRODi Drill. 06:00 - 10:00 4,00 DRILL P PROD1 Continue drilling build section. Free spin pressure 3480 psi at 10:00 - 12:35 12:35 - 14:00 14:00 - 14:15 14:15 - 14:30 14:30 - 16:30 16:30 - 18:00 18:00 - 18:30 18:30 - 21:00 21:00 - 22:30 22:30 - 23:00 23:00 - 00:00 1111012005 00:00 - 06:00 06:00 - 08:45 08:45 - 09:25 09:25 - 10:05 10:05 - 13:00 2.6 bpm. Drilling ahead in Ankorite at 2.61/2.64/3776 psi. ROP=5 fph. PVT=320 bbls. IAP=515 psi, OAP=396 psi. BHP=3690 psi. ECD=10.91 ppg. WOB=7000 lbs. String wt = 6200 lbs. 2.58 DRILL P PROD1 Broke thru Ankorite finally! Geo reports 5-6' TVD of Ankorite. Continue drilling to land build and turn. 1.42 DRILL P PROD1 Build section of well landed. POOH to pick up lateral section BHA. No problems in open hole on wiper trip to window. Pull thru window with pumps down, and holding WHP. Open EDC. Pump at full rate while POOH. Note -Mud is a used system from a previous well and contains 14 ppb Kla-Gard. 0.25 DRILL P PROD1 PJSM Re: Undeployment of build section BHA. 0.25 DRILL N RREP PROD1 Found leaking swab on pump #2. Take a few minutes to isolate and clean up mud in pump room. 2.00 DRILL P PROD1 Undeploy BHA #4. Left 400 psi on well at start of undeployment. Bit recovered graded 1,2, with 1 chipped cutter on the wing. Sit is rerunable. 1.50 DRILL P PROD1 Hold Safety stand down with Nordic crew #3. Topic of stand down was recent spate of injuries that we have had in the past 3 weeks. Discussed the dangers of getting complacent, and the need to stay focused on the job. 0.50 DRILL P PROD1 MU lateral BHA with reistivity mwd tool. Hold PJSM with night crew to discuss. Discuss positions, assignments, hazards. Evaluate if slickline carrhandle BHA weight (yes, it can). 2.50 DRILL P PROD1 MU lateral assembly with UPR tool. (1.0 deg xtreme mtr w/ new HTC bi-cent) Slow going due to tool length. Found 200 psi trapped on well. Stab coil. Test mwd. Get on well. 1.50 DRILL P PROD1 Run in hole. Maintain BHP following pressure schedule. 0.50 DRILL P PROD1 Log gr tie in from 8220'. Subtract 16.5' correction. 1.00 DRILL P PROD1 Log build section with resistivity tool. 5 fpm. 3450 psi fs at 2.42 in/2.7 out. 6.00 DRILL P PROD1 Drill lateral from 8900'. 3510 psi fs @ 2.43 in/2.66 out. DPSI: 100-200. DHW06:1.5-2.5k#. WHP/BHP/ECD:84/3770/11.1 ppg. IA/OA/PVT: 378/254/316 bbls. I NC/AZM/TF: 88.1/16.4/95L. ROP averaging 25 fph. Slow drilling. 2.75 DRILL P PROD1 Continue drilling lateral section. Free spin 3690 psi at 2.5 bpm. Drilling at 2.56/2.62/3750 psi. PVT=313 bbls. IAP=760 psi, OAP=626 psi. BHP=3804 psi. ECD=11.2 ppg. 0.67 DRILL P PROD1 Wiper trip to window. Slight overpull on pickup. PU weight 30 klbs. Clean to window. Clean back in hole. 0.67 DRILL N RREP PROD1 Back on bottom. Nordic hands need to do maintenance on pump #2. Can't drill with 1 pump. Make slow wiper trip toward window while they sort it out. 2.92 DRILL P PROD1 Resume drilling. Start swap to new mud. Free spin with new mud 3527 psi at 2.6 bpm. Drilling at 2.67/2.72/3710 psi. New mud made a big improvement in drilling. We went from 35 fph to 60 fph. Printed: 11/28/2005 12:59:04 PM BP EXPLORATION Operations Summary Report Page 5 of 16 Legal Well Name: 1 Q-02 Common W ell Name: 1 Q-02 Spud Date: 11/5/2005 Event Nam e: DRILL+C OMPLE TE Start : 11/5/2005 End: 11/27/2005 Contractor Name: NORDIC CALIS TA Rig Release: 11/27/2005 Rig Name: NORDIC 2 Rig Number: Date ~i From - To ~ Hours ~ Task j Code ~ NPT ~~ ~ Phase j Description of Operations 11/10/2005 13:00 - 17:00 4.00 DRILL P PROD1 Drilled into the Ankorite. Point tool face straight down. Geo thinks we faulted into it. ROP 5 fph. Gnawing away at it. 17:00 - 19:15 2.25 DRILL P PROD1 Made 18' in 4 hours, 4.5 fph. Geo says at minimum we have 75' more measured depth of Ankorite to cut. POOH to pick up tricone to get back down thru it. 19:15 - 21:30 2.25 DRILL P PROD1 Hold PJSM to discuss un-deployment. At surface. Shut in well with 500 psi WHP. Undeploy BHA. HTC bi-center graded 3-3, with several broken and/or worn nose cutters. MU HTC tricone STXM20DX2 3.75" bit. Deploy BHA. Found 150 psi on well head, Perform inspection of blocks before picking up injector. Stab coil. Get on well. 21:30 - 23:30 2.00 DRILL P PROD1 Run in hole following BHP pressure schedule. 23:30 - 00:00 0.50 DRILL P PROD1 Log gr tie in from 8535'. Subtract 17' correction. Continue in hole. 11!1112005 00:00 - 03:00 3.00 DRILL P PROD1 Drill ahead from 9183'. 3500 psi fs Q 2.66 in/out. DPSI: 150. DHWOB: 5-6k#. WHP/BHP/ECD: 66/3676/10.8 ppg. IA/OA/PVT: 7/0/388 bbls. INC/AZM/TF: 86.6/354.7/180 deg. Start out with 500 # WOB to break in bearings. Slowly increase to 5-6k#. Could not get any more than this for DHWOB. Made 5' in three hours. 03:00 - 03:20 0.33 DRILL P PROD1 Wiper trip to window. Hole smooth. 03:20 - 06:00 2.67 DRILL P PRODi Circulate out of hole. Jog in hole near surface to try and clean out cuttings. By pass micro motion to avoid plugging. 06:00 - 06:15 0.25 DRILL P PRODi SD operations for crew change. 06:15 - 06:30 0.25 DRILL P PRODi Hold PJSM with day tour crew to discuss Undeploy and redeploy of BHA. 06:30 - 08:15 1.75 DRILL P PROD1 Undeploy BHA #6. Change out tricone bit for Hycolog concentric reamer bit (CRXE1005). Redeploy BHA. 08:15 - 10:00 1.75 DRILL P PROD1 RIH with BHA #7 to continue drilling Ankorite. 10:00 - 10:20 0.33 DRILL P PROD1 Log tie in pass over RA tag in whipstock. Make -18.5' correction. 10:20 - 10:40 0.33 DRILL P PROD1 Run to bottom. Pumping at full rate in open hole. 10:40 - 11:40 1.00 DRILL P PROD1 Free spin 3280 psi at 2.56 bpm. Tag bottom at 8188.1'. Begin drilling. PVT=337 bbls. IAP=O, OAP=O, BHP=3677 psi. ECD=10.8 ppg. Initial ROP=15 fph. Yee haw. Drilling great in Ankorite. Best we've ever done. 11:40 - 14:00 2.33 DRILL P PROD1 Made 14' in the last hour. ROP seems to be slowing down slightly. 14:00 - 15:15 1.25 DRILL P PROD1 Bit is hanging in at 10 fph. Good ROP compared to 2-5 fph with the bicenter. Continue chugging away. Making some hole anyway. 15:15 - 16:30 1.25 DRILL P PROD1 Drilling break. Got down out of the Ankorite finally. Drilling ahead at 80 fph in good A3 sand. Holding 83 deg INC for the time being to get down below the Ankorite. This bit drills sand good too! 16:30 - 17:10 0.67 DRILL P PROD1 Wiper trip to window. Clean PU off bottom. Clean in open hole up. Pump 15 bbls of 100 klsrv mud to help hole cleaning. Continue trip up to window. Clean back down to bottom. 17:10 - 19:00 1.83 DRILL P PROD1 Drill ahead in ankorite to 9380'. Appear to out of ankorite and into sand. 19:00 - 22:00 3.00 DRILL P PROD1 Drill to 9500'. 3250 psi fs @ 2.47 in/out. DSPI: 200-300 DHWOB: 2-3k#. WHP/BHP/ECD: 60/3700/10.9 ppg. Printed: 11/28/2005 12:59:04 PM BP EXPLORATION Operations Summary Report Legal Well Name: 10-02 Common Well Name: 1Q-02 Event Name: DRILL+COMPLETE Start: 11/5/2005 Contractor Name: NORDIC CALISTA Rig Release: 11/27/2005 Rig Name: NORDIC 2 Rig Number: Date ~ From - To ~ Hours ~ Task ~ Code ~~ NPT i _ _ ----`19:00-22:00 II 3.00`.- - -I - -~ -' 11/11!2005 I DRILL I P 11 /12/2005 11/13/2005 22:00 - 23:00 1.00 DRILL P 23:00 - 00:00 1.00 DRILL P 00:00 - 00:30 0.50 DRILL. P 00:30 - 03:30 I 3.001 DRILL I N I DFAL 03:30 - 04:30 ~ 1.00 ~ DRILL ~ N ~ DFAL 04:30 - 06:30 I 2.001 DRILL I N I DFAL 06:30 - 06:50 0.33 WHSUR P 06:50 - 07:05 0.25 DRILL N DFAL 07:05 - 08:15 1.17 DRILL N DFAL 08:15 - 09:35 1.33 DRILL N DFAL 09:35 - 09:55 0.33 DRILL N DFAL 09:55 - 10:25 0.50 DRILL N DFAL 10:25 - 10:45 0.33 DRILL P 10:45 - 13:15 2.50 DRILL P 13:15 - 14:25 1.17 DRILL P 14:25 - 16:30 16:30 - 19:00 19:00 - 22:00 22:00 - 23:30 23:30 - 00:00 00:00 - 06:00 Phase Page 6 of 16 Spud Date: 11/5/2005 End: 11/27/2005 Description of Operations PROD1 IA/OA/PVT: 200/103/346 bbls. INC/AZMlTF: 85.6/312.5/908. ROP avg 10 fph in ankorite, 40-60 fph in sand. PRODi Wiper trip to window. Hole smooth. PROD1 Drill ahead from 9500'. PROD1 Drill lateral to 9564'. Lost ability to read tool face and near bit inc. Trouble shoot tools & re boot computers etc. Unable to re-establish TF or inc. PROD1 Wiper trip to window. Circulate out of hole at max pump rate, following BHP schedule. PROD1 PJSM. At surface. Shut in well on BHA. Get off well. Unstab from coil. Undeploy BHA. Lay down mwd tools. WHP has bled to zero psi. PROD1 Test mwd tools on rig floor /catwalk. Found bad HOT. Replace same. PROD1 Function test BOPE. All passed ok. PROD1 PJSM Re: Deployment of BHA #8. Rerunning same Hycalog CRX bit as used on last run. Bit examined for micro dulling, and found to be in great shape. Graded 0,0 when recovered from last run. Heck of a good bit we have here. PROD1 Pressure deploy BHA #8 following SOP. PRODi RIH with BHA #8. Shallow hole test ok. Continue RIH. PROD1 Log tie in pass over RA tag. Make -19' correction. PROD1 Run to bottom. Free spin 3480 psi at 2.57 bpm. PROD1 Tag bottom and resume drilling. Trying to drill down out of Ankorite as per Geo. PVT=370 bbls. IAP=O, OAP=O, BHP=3810 psi, ECD=11.12 ppg. WOB=6800 lbs. String wt = 3200 psi. ROP=10-15 fph. PROD1 Drilling break. Drilling 90 fph. Pump 15 bbl high vis sweep. Seem to be getting a lot of cuttings back now, although it is too soon for bottoms up from the high ROP stuff. PRODi Wiper trip to window. Clean PU off bottom. Clean in open hole. Clean back to bottom. Still pumping sweeps 1 per hour. 2.08 DRILL P PROD1 Free spin 3570 psi at 2.57 bpm. Tag bottom. Resume drilling. TF = highside. Going to invert and drill back up thru the Ankorite to land the invert section in the A4 sand. Current NB INC=87 deg. 2.50 DRILL C PROD1 Hit the Ankorite again. Intentionally this time. ROP 9-12 fph. INC=54 deg. Going to drill up thru it and roll it over in the A4 sand. Note -Time code change from "P" to "C" at this point due to decision to drill the 2nd lateral. (As per Aras Worthington) 3.00 DRILL C PROD1 Drill ahead form 9820'. 3500 psi fs at 2.55 in/2.55 out. 200-300 DPSI. DHWOB: 5-6k#. WHP/BHP/ECD: 70/3821/11.14 ppg. IA/OA/PVT: 327/186/363 bbls. ICN/AZM/TF: 94.8/347.3/408. ROP averaging 8-10 fph in ankorite. Continue climb up through A3 ankorite zone. i.50 DRILL C PROD1 Wiper trip to window. Hole smooth. 0.50 DRILL G PROD1 Drill ahead from 9850'. 6.00 DRILL C PROD1 Drill ahead from 9855'. 3600 psi fs at 2.65 in/out. 200-300 DPSI. DHWOB: 5-6k#. WHP/BHP/ECD: 70!3837!11.20 ppg IA/OA/PVT: 487/336!352 bbls. INC/AZM/TF: 94.2/350.4/908 Printed: 11/28/2005 12:59:04 PM BP EXPLORATION Operations Summary Report Page 7 of 16 Legal Well Name: 1Q-02 Common Well Name: 1Q-02 Spud Date: 11/5/2005 Event Name: DRILL+COMPLETE Start: 11/5/2005 End: 11/27/2005 Contractor Name: NORDIC CALISTA Rig Release: 11!27/2005 Rig Name: NORDIC 2 Rig Number: Date ~ From - To ~ Hours I Task j Code ~ NPT ~ Phase ~ Description of Operations _1-------~ ~-~--- ~ --- - --------- ------- 11113/2005 00:00 - 06:00 6.00 DRILL C PROD1 Continue to drill at 8-12 fph while climbing up through A3 ankorite. 06:00 - 06:20 0.33 DRILL C PROD1 Continue drilling up in Ankorite. We have cut 9' TVD so far. The Ankorite thickness in the parent well was 5' TVD. We have either crossed a fault, or found thicker Ankorite here. 06:20 - 07:25 I 1.081 DRILL I C 07:25 - 08:10 0.75 DRILL C 08:10 - 08:25 0.25 DRILL C 08:25 - 09:05 0.67 DRILL C 09:05 - 11:30 2.42 DRILL C 11:30 - 13:10 I 1.671 DRILL IC 13:10 - 15:35 2.42 DRILL C 15:35 - 17:30 1.92 DRILL C 17:30 - 20:00 ~ 2.50 ~ DRILL ~ C 20:00 - 22:00 2.00 DRILL C 22:00 - 00:00 2.00 DRILL C 11/14/2005 00:00 - 00:45 0.75 DRILL C 00:45 - 01:30 0.75 DRILL C 01:30 - 03:15 1.75 DRILL C 03:15 - 03:40 0.42 DRILL C 03:40 - 06:00 I 2.331 DRILL I C 06:00 - 06:45 0.75 STKOH C 06:45 - 07:00 0.25 STKOH C 07:00 - 08:20 i.33 STKOH C 08:20 - 10:30 2.17 STKOH C 10:30 - 10:45 ~ 0.25 ~ STKOH ~ C 10:45 - 12:15 I 1.501 STKOH I C Drilling at 2.6512.65/3820 psi. PVT=348 bbls. IAP=536 psi, OAP=377 psi. BHP=3838 psi. ECD=11.2 ppg. WOB=5550 lbs. String wt=2400 lbs. ROP=8-10 fph. PROD1 Drilling break. Popped up thru the Ankorite. Now drilling 80 fph in the A4 sand. Rolling TF over to land it. Resume pumping 15 bbl high vis sweep 1 time per hour to help in hole cleaning. PROD1 Wiper trip to window. Clean PU off bottom at 32 klbs. PROD1 Log tie in pass accross RA tag in whipstock. Make +4' correction. PROD1 Continue back in the hole on wiper trip. Smooth while RIH. PROD1 Resume drilling lateral section in the A4 Free spin 3470 psi at 2.44 bpm. Drilling at 2.44/2.41/3713psi. WOB=4000 lbs. String wt = 6600 lbs. ROP=60 fph. PROD1 Wiper trip to window. Clean PU off bottom at 33 klbs. Clean to window and back in the hole. PROD1 Continue drilling. Holding 90 deg {NC. ROP=60 fph. WOB=2400 lbs. String wt = 8000 lbs. Mud driN solids are up to 1.0%. Call for trucks for a mud swap. PROD1 Wiper trip to the window. Clean PU off bottom at 32 klbs. Clean in open hole. PROD1 Drill ahead from 10,300'. 3650 psi fs at 2.46 in/2.47 out. DPSI: 200-300. DHWOB: 2.5 - 3.5k#. WHP/BHP/ECD: 62/3951/11.56 ppg. IA/OA/PVT: 532/380/328 bbls. ROP averaging 50-60 fph in A4/A3 zone. Not sure if we are in A4 or not. Sand quality mediocre at best. PROD1 Wiper trip to window. Hole very smooth. PROD1 Drill ahead from 10535'. Increase angle to 94-95 deg climb up through section. PROD1 Drill ahead from 10535'. Discover we have drilled across a fault into A6. PROD1 Wiper trip to window. Discuss sidetrack plan with town. PROD1 Circulate out of hole to pick up side track assembly. PROD/ Stop at 1000'. Circulate at max rate to clean hole. Getting lots of shale across shaker. PROD1 At surface. PJSM. Get off well. Unstab coil. Undeploy BHA assembly. LD resistivity tool. MU replacement 1.8 deg mtr with R-60 ST bit w/ brass nose. Deploy BHA. PROD1 Continue reconfiguring BHA for sidetrack run. PROD1 PJSM prior to deploying sidetrack BHA. PROD1 Deploy BHA #9, sidetrack BHA. PROD1 RIH with BHA #9. Repair powerpack on way in the hole. Stop and tighten drive plates on way in the hole. PROD1 Log tie in pass over RA tag in whipstock. Make -19' correction. PROD1 Run to bottom pumping 0.25 fpm thru the bit. Set down slightly Printed: 11/28/2005 12:59:04 PM BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 10-02 10-02 DRILL+COMPLETE NORDIC CALISTA NORDIC 2 Start: 11 /5/2005 Rig Release: 11/27/2005 Rig Number: Page 8 of 16 Spud Date: 11/5/2005 End: 11/27/2005 Date 1 From - To j Hours ~, Task i Code ~, NPT ~ 11114!2005 ~ 10:45 - 12:15 ~ 1.50 I STKOH I C 12:15 - 14:30 I 2.25 I STKOH I C 14:30 - 15:00 0.50 STKOH C 15:00 - 15:40 0.67 STKOH C 15:40 - 16:00 0.33 STKOH C 16:00 - 16:15 0.25 STKOH C 16:15 - 16:30 0.25 STKOH C 16:30 - 17:15 0.75 STKOH C 17:15 - 21:00 I 3.75 I STKOH I X I STUC 21:00 - 00:00 { 3.001 STKOH ~ X (STUC 11!15!2005 100:00 - 00:30 { 0.501 STKOH I X STUC 00:30 - 03:00 I 2.501 STKOH I X 1 STUC 03:00 - 04:15 I 1.25 I STKOH I X I STUC Phase Description of Operations PROD1 at 8666', but bounced thru. Set downs at 9885', but bounced thru. Kicked on pumps at 10450', and had ratty weight the rest of the way to bottom. Tag up hard with pumps on at 10476'. Pull up hole to start sidetracking. PRODi Trough hole from 9980'-9995'. Make 3 troughing passes down. Tool face = lowside. Trough while RIH at 15 fph. PROD1 Stationary drill at 9995'. PROD1 Time drill at 3'lhr. Started seeing WOB after i.0' of coil movement at surface. PROD1 Time drill at 6'1hr. WOB constant at 500 lbs. PROD1 Control drill at 10 fph. WOB constant at 1000 lbs. PROD1 Drill at 35 fph. WOB = 1250 Ibs, 150 psi motor work. PROD1 Confirmed sidetracked from directional information. Backream window area at 90 deg, 0 deg, 270 deg. PROD1 Wlper trip to window. Reduce pump to min rate to go through window. Shut down pump at 8505' to close open EDC. Unable to re-establish circulation afer opening EDC. Unable to move pipe either. Able to circulate down coil. BHP approx 4400 psi before injecting into formation. Stop pumps and allow BHP to bleed off to 3850 psi. Push down on pipe and/or leave in neutral weight. Do this several times. Eventually pipe began to move down. Able to RIH at 14k# do wt, which is normal RIH weight. Pressure still trapped below BHA. Circulate across wellhead to verify nothing is plugged at surface. RIH to below build to 8875'. Able to move up and down hole freely. 37k# up, 14k# do weight. But pressure is still trapped below BHA !!!! Plan is to cycle up and down 10' to try and loosen what ever is packing off coil. POOH to try and reduce bore hole pressure below BHA by removing coil volume from well below pack off. Draw BHP down to 8.8 ppg . PROD1 Pressure wellhead to 200 psi with BHP reduce to 2980 psi while RIH. Bleed WHP. Repeat this several times while RIH and POH, with up to 500 psi WHP. Continue to be able to run in and out of hole. 14k# do wt, 38k# up wt, which varies a little depending on BHP or WHP. None. of this seems to have any effect. Begin to cycle pipe from 8800' to 9200' while maintaining a constant BHP using to pump to try and minimize pressure fluctuations on open hole. PRODi Continue to run in and out of hole from 8800' to 9200' to try and loosen material packed off around coil. PROD1 Pipe became stuck at 9078'. Pull to 42k#, slack off to -4k#. Continue to work pipe, mostly from neutral to do wt. Came free. Continue to work pipe up and down. from 8800' to 9200'. Pressure wellhead to 300 psi. Bleed off quickly several times. PROD1 Continue to move pipe between 8800' and 9200'. Put 500 psi on well head, and dump pressure. Maintain 11.0 to 12.2 ppg pressure on open hole to help kep shales stable. Do this while moving pipe up and down. Plpe continues to move freely. 14k# do wt, 35k# up wt. Pipe moving freely most of the time. Have pulled as much as 50k# up wt to keep pipe moving. May Printed: 1 t(28l2005 12:59.04 PM BP EXPLORATION Page 9 of 16 Operations Summary Report Legal Well Name: 10-02 Common Well Name: 1Q-02 Event Name: DRILL+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date I' From - To ~ Hours j Task ~I Code NPT j 11115/2005 04:105 - 05:00 0.75 STKOH ~C STUC 05:00 - 06:30 I 1.501 STKOH I C 06:30 - 07:15 I 0.751 STKOH I C 07:15 - 09:00 I 1.75 I STKOH I C 09:00 - 09:20 I 0.331 STKOH I C 09:20 - 11:00 1.67 STKOH C 11:00 - 13:30 2.50 DRILL C 13:30 - 13:40 I 0.171 WHSUR I C 13:40 - 15:30 I 1.831 DRILL IC 15:30 - 18:45 I 3.251 DRILL I C 18:45 - 19:00 0.25 DRILL C 19:00 - 19:50 0.83 DRILL C 19:50 - 20:45 I 0.921 DRILL I C 20:45 - 21:20 I 0.581 DRILL I C 21:20 - 22:15 ( 0.921 DRILL I C 22:15 - 23:15 1.00 DRILL C 23:15 - 00:00 0.75 DRILL C Spud Date: 11/5/2005 Start: 11/5/2005 End: 11/27/2005 Rig Release: 11/27/2005 Rig Number: Phase I Description of Operations ---L---- PROD1 be starting to break up pack off. PRODi Began to get a small trickle of returns. Stopped, then started again a few times. Slowly increasing pump rate, starting to get 1:1 rtns. Pump pressure coming down. Yahoo !!!! PRODi Continue to circulate while POH slowly. Getting large amount of cuttings & shale across shakers. Having to bypass choke and micro motion. Through window ok at 1 bpm. Continue to POH circing at 2.76 bpm. PROD1 2675', while POOH returns went to 0, we plugged off the choke or micromotion with cuttings. Bypass same to get returns back. Pump a high vis sweep to help clean the hole. Pump bottoms up prior to continuing to POH. PRODi Got lots of rocks out while circulating bottoms up. Returns clean now. Continue POH. PROD1 PJSM prior to undeploying BHA. Discuss clearing choke, micromotion, and bypass lines also. Make job assignments. Review tasks to ensure that there would be no interference between operations. PROD1 Undeploy sidetrack BHA. PROD1 Reconfigure BHI BHA to add resistivity to it. Rig crew blowing down all lines, checking choke, micromotion and bypass lines as well as BOP stack to ensure that all rocks and cuttings are cleared out. Found rocks in cavity of lower set of TOT's. PROD1 Pressure test BOP stack and hardline in choke room to 250 psi and 4000 psi. Passed ok, no leaks. PROD1 Pressure deploy BHA #10. Lateral BHA with RES. BHA has a 1.0 deg motor and CRXE concentric reamer bit. Stab coil and get on well. PROD1 Run in hole circulating at 2.42 bpm. Maintain BHP as per schedule. Perform weight checks every 2000'. Monitor shakers for excess cuttings. PROD1 Log gr tie in across RA tag at 8547'. Subtract 19' correction. PROD1 Circulate in hole. Choke open. Monitor weight and circulating pressure closely due to concerns regarding pssible cuttings bed and hole condition. 3430 psi fs at 2.56 in. 1:1 rtns. PVT: 288 bbls. PROD1 Hole was clean to set down at 9668' w/ TF 180 out. Essentially clean up hole from 9666' to 9704' as follows-PUH from 9668' for 50' w/ high MW. RBIH and set down at 9666'. Try to drill it, but got MW instead. PUH 8k over and sli packing off. Drill it at 458 2.58/2.52/3500 w/ 250 psi MW, 3k wob w/ 11.2 ECD at 3840 psi DHP PVT 292. Get to 9681' and stacking. Wiper back up hole w/ 10k over and MW. Ream back down to 9704'. Wiper back to 9630' and had MW and 5k overpull at 9650' PROD1 Wiper back to 9704' was clean. Wiper slowly to TD tagged at 10017', clean. Drill 3' just to be sure on bottom PROD1 Wiper to window to test the waters, clean. PUH thru window at 1.0 bpm at midway point of hi vis pill exiting bit, clean. Wiper to 8400' at 2.6 bpm, clean. No rocks, but excessive small pieces of shale in returns PROD1 Wiper back to TD was clean, PVT 288 PROD1 Drill from 10020' 2.69/2.63/3600/908 w/ 200-500 psi dill, 3-5k wob w/ 11.3 ECD at 60-90'/hr in A4 Printed: 11/28/2005 12:59:04 PM BP EXPLORATION Operations Summary Report Legal Well Name: 1 Q-02 Common Well Name: 1Q-02 Event Name: DRILL+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date j 1=rom - To ~ Hours 'I Task ~ Code i 11116/2005 _-_. 00:00 - 01:25 - 1.42 _ _ DRILL - -_ C 01:25 - 03:20 1.92 DRILL C 03:20 - 06:00 I 2.671 DRILL I C 06:00 - 07:15 1.25 DRILL C 07:15 - 07;30 0.25 DRILL C 07:30 - 08:00 0.50 DRILL C 08:00 - 11:30 3.50 DRILL C 11:30 - 13:30 2.00 DRILL C 13:30 - 16:30 3.00 DRILL C 16:30 - 19:30 3.00 DRILL C 19:30 - 22:10 2.67 DRILL C 22:10 - 23:30 1.33 DRILL C 23:30 - 23:45 0.25 DRILL C 23:45 - 00:00 0.25 DRILL C 11117!2005 00:00 - 00:55 0.92 DRILL C 00:55 - 04:05 I 3.171 DRILL IC 04:05 - 05:25 1.33 DRILL C 05:25 - 06:45 1.33 DRILL C 06:45 - 08:45 2.00 DRILL C 08:45 - 12:00 3.25 DRILL C 12:00 - 16:45 4.75 DRILL C 16:45 - 18:10 1.42 DRILL C 18:10 - 20:10 2.00 DRILL C 20:10 - 21:30 I 1.33.1 DRILL I C 21:30 - 21:55 I 0.421 DRILL I C 21:55 - 22:10 0.25 DRILL C 22:10 - 23:40 1.50 DRILL C 23:40 - 00:00 I 0.331 DRILL I C Page 10 of 16 Spud Date: 11!5/2005 Start: 11 f5f2005 End: 11 f27f2005 Rig Release: 11/27/2005 Rig Number: NPT i Phase I Description of Operations PRODi Drill from 10060-170' at 50-80'/hr PROD1 Wiper to window was clean both directions w/ no excessive cuttings or shales in returns PVT 282 PROD1 Drill from 10170' 2.66(2.61/3600/75-1008 w/ 300-500 psi diff, 2.5-4.5k wob w/ 11.48 ECD holding 89 deg at 6606' TVD PVT 281 PROD1 Wiper to window. Hole smooth on the way out. PRODi Log gr tie in. Add 6' correction. PROD1 Wiper trip back to btm. Hole smooth and apparently clean. PROD1 Drill ahead from 10,320'. 3770 psi fs at 2.65 in/2.6 out. DSPI: 200-350. DHWOB:2.0-3.Ok#. WHP/BHP/ECD: 29/3944/11.52 ppg. IA/OA/PVT: 398/242/270 bbls. Avg ROP: 50 fph. Mostly in sand. A4 is only about 1' thick. PROD1 Wiper trip to window. Hole smooth. PROD1 Drill ahead from 10,470'. 3750 psi fs at 2.66 infout. PVT: 256 bbls. Inc: 89-91 deg PROD1 Wiper trip to window was clean. Wiper to TD had wt loss, MW at 8700' and rest of hole was clean PVT 248 PROD1 Drill from 10620' 2.6/2.54/3600/90L w/ 200-500 psi diff, 2-3k wob w! 11.7 ECD at 88 deg at 6614' TVD. Adding brine to thin 80k LSRV back to 65k and lower ECD's PROD1 Wiper to window PROD1 Log tie-in down from 8570', add 6' PROD1 Wiper back to TD PROD1 Continue wiper back to TD. Hole was clean both ways PVT 316 PROD1 Drill from 10770' 2.63/2.56l3600l85L w/ 100-300 psi diff, 2-3k wob w/ 11.34 ECD at 90 deg at 6614' TVD PVT 308 PROD1 Wiper to window was clean PROD1 Wiper to TD. Hole smooth. PROD1 Drili ahead from 10920'. 3550 psi fs at 2.45 in/2.38 out. DPSI: 150-300 DHW06:2.0-2.5k# WHP1BHPiECD:26/ 3973/11.58 ppg lA(OA(PVT: 5241367/303 bbls INC/AZM/TF: 88.5/4.2/100L. Drilling ahead smoothly at 50-70 fph. PROD1 Wiper trip. Hole smooth in both directions. Log gr tie in. PRODi Drill ahead from 11,070'. 3850 psi fs at 2.60 in/2.54 out. 2-3k# DHWOB PVT: 289 bbls. PROD1 Wiper trip to window was clean PROD1 Wiper to TD was clean except for numerous setdowns 10970-11000'. Spent 20 min cleaning up this area PVT 265 PROD1 Drill from 11220' 2.6/2.51/3760/908 w/ 100-300 psi diff, 2-3k wob w/ 12.1 ECD at 87 deg at 6625' TVD. Roll TF to 1308 at 11250' to begin drop to find the A3 ankerite and penetration rate 100'/hr PROD1 Wiper to 11200' after cutting fast hole and while swap to fresh mud. Also, repairing pump #1 swab PROD1 Drill from 11335-350' and pump #2 cap started leaking .. . PROD1 Wiper to window (early) due to pump probs and while continuing to displace to fresh mud. Fresh mud from outside tanks was 55 deg and cooled off IA from 600 psi to -17 psi vac, and OA dropped from 350 to zero psi .. Wiper was clean PROD1 Log tie-in down from 8570' after swapping to repaired pump #1. Printed: 11(28(2005 12:59:04 PM BP EXPLORATION Page 11 of 16 Operations Summary Report Legal Well Name: 1 Q-02 Common W elt Name: 1 Q-02 Spud Date: 11/5/2005 Event Nam e: DRILL+C OMPLE TE Start : 11/5/2005 End: 11/27/2005 Contractor Name: NORDIC CALIST A Rig Release: 11/27/2005 Rig Name: NORDIC 2 Rig Number: Date ~~ -- -- From - To ! ~ Hours it Task ! ~ Code ' ! NPT '! l Phase I Description of Operations ~ 11/17/2005 ---- 23:40 - 00:00 _ 0.33 DRILL _ _ C -- -- - - - PROD1 _ - -- - Corr+5.5' 11/18/2005 00:00 - 01:55 1.92 DRfLL C PROD1 Wiper back to TD was clean until set down at 11250'. Ream to 11260' for 20 min w/ 10k overpulls. Slow ream to TD tagged at 11352' Swap to repaired pump #2 PVT 250 01:55 - 04:05 2.17 DR{LL C PROD1 Drill from 11352' 2.57/2.50/3530/1408 w/ 200-300 psi dill, 2-3k wob w/ 11.3 ECD and continue drop to find A3 ankerite. Drill to 11500' and noseeum PVT 246 04:05 - 05:40 1.58 DRILL C PROD1 Wiper to window, 33k while geo confirms this is deep enough 05:40 - 06:30 0.83 DRILL C PROD1 Pu{I thru window and wiper to 7000' 2.7/3600 06:30 - 08:30 2.00 DRILL C PROD1 Run back in hole. Wipe hole to TD. Log gr tie in from 8575'. Add 5' correction. Continue wiper trip to TD tagged at 11501'. 08:30 - 10:15 1.75 DRILL C PROD1 Displace hole to 9.9 ppg KWF with 3 ppb coarse beads. 10:15 - 12:30 2.25 DRILL C PROD1 Continue to POH. Displace tbg to 9.9 ppg kwf. Get a moderate amount of cuttings back as BHA neared surface. Slow coil speed to allow hole to clean up. 12:30 - 13:00 0.50 DRILL C PROD1 Monitor flow while holding PJSM to discuss BHA handling and running liner. Well appears to be stable. 13:00 - 14:15 1.25 DRILL C PROD1 Get off well. Unstab coil. Purge BHA tools. LD MWD components and re-configure for liner running assembly. Rig up floor to run liner. 14:15 - 18:40 4.42 CASE C RUNPRD Make up 57 jts 2-7/8" 6.16# L80 STL slotted liner w/indexing guide shoe and Weatherford 3.25" aluminum billet liner top. Found several jts with bad box threads. Replace with additional pipe on location. MU GS and BHI MWD assy PVT 17 18:40 - 19:55 1.25 CASE C RUNPRD RIH w( liner on CT w/o pump 19:55 - 21:00 1.08 CASE C RUNPRD 34k Q 8500', PVT 50. RIH thru window, clean. RfH 50-70'/min in OH w/ one minor wt loss at 8800' to TD tagged at 11852' CTD?? (CT counter was also off on prior POH). EOP counter for this run was close to planned TOL depth. PUH 45.4k, clean. Set liner back at TD. Pump 2.0/4000 and GS released from liner at 31 k. Left bottom of liner at 11501' and top of aluminum billet at 9609' PVT 64 21:00 - 21:30 0.50 CASE C RUNPRD POH w/ setting assy thru OH at 0.56/0.3 21:30 - 23:00 1.50 CASE C RUNPRD Open EDC above window. POH circ 1.4/1970 PVT 10 23:00 - 23:30 0.50 CASE C RUNPRD Flowcheck while conduct safety mtg re: LD BHA & ELSM LD W S setting BHA. Close master/swab 23:30 - 00:00 0.50 DRILL C PROD2 Cut off CTC and remove lower lub from injector 11/19/2005 00:00 - 02:15 2.25 DRILL P PROD2 RU cutter and cut 800' of CT/eline. RD cutter, dispose of CT 02:15 - 04:00 1.75 DRILL P PROD2 Replace nearly empty slickline drum w/ new O.i25" wire and PT 04:00 - 05:00 1.00 DRILL P PROD2 Install Kendal CTC. Meg test, PT's 05:00 - 06:15 1.25 DRILL P PROD2 Pump slack forward while changing out CT footage counter wheel 06:15 - 06:30 0.25 STWHIP P PROD2 PJSM to discuss making up BHA. 06:30 - 07:00 0.50 STWHIP P PROD2 MU sidetrack assembly. 1.5 deg mtr w! 3.75 HTC SPR335 bit 07:00 - 08:15 1.25 STWHIP P PROD2 Run in hole. Circ at min rate. 08:15 - 08:30 0.25 STWHIP P PROD2 Log gr tie in from 8575'. Subtract 3' correction, 08:30 - 09:15 0.75 STWHIP P PROD2 Continue to run in hole. Circ at 1 bpm in/1.07 out. Tag TOL at 9609' 09:15 - 12:15 3.00 STWHIP P PROD2 Begin time milling on billet at 9609'. 0.1' per 6 minutes. Displace 9.9 KWF to 9.0 flo pro. 3540 psi fs at 2.56 in/2.49 out. TF: 608 NB Inc: 80.53 deg Printed: 11!2812005 12:59:04 PM BP EXPLORATION Page 12 of 16 Operations Summary Report Legal Well Name: 1 Q-02 Common W ell Name: 1 Q-02 Spud Date: 11/5/2005 Event Nam e: DRILL+C OMPLE TE Start : 11/5/2005 End: 11/27/2005 Contractor Name: NORDIC CALIST A Rig Release: 11/27/2005 Rig Name: NORDIC 2 Rig Number: Date ! i From - To i Hours Task ~ Code I NPT i Phase ~ Description of Operations 11/19/2005 09:15 - 12:15 3.00 STWHIP P PROD2 WHP/BHP/ECD: 70/3880/11.34 ppg. IA/OA/PVT: 0!01115 bbls. Drill to 9635'. 12:15 - 13:00 0.75 STWHIP P PROD2 Back ream at 65R, 15R and 160R. Dry drift. Hole/billet smooth. 13:00 - 15:00 2.00 STWHIP P PROD2 Wiper trip to window. Circulate out of hole. Lots of aluminum in returns while POOH, near 1500'. Plugged of choke and by pass lines. Eventually cleaned up. 15:00 - 17:30 2.50 STWHIP P PROD2 At surface. Hold PJSM. Get off well. Unstab coil. Un-deploy BHA. LD BHA tools. 17:30 - 21:30 4.00 STWHIP N MISC PROD2 Clean out surface choke lines. Clean out micro motion. Clean out bypass lines. Also, cleanout aluminum in Baker choke 21:30 - 00:00 2.50 BOPSU P PROD2 Biweekly BOPE test. The right to witness was waived by AOGCC 11/20/2005 00:00 - 02:00 2.00 BOPSU P PROD2 Fin BOPE test 02:00 - 03:00 1:00 DRILL P PROD2 Check well for pressure and on sli vac. Fill hole w/ < 1 bbl Open-hole MU lateral drilling assy w/ res tool 03:00 - 05:10 2.17 DRILL P PROD2 Prep to RIH w/ BHA #13, but return line in cellar was frozen (-44F amb). Circ CT thru Baker choke while thaw line. RIH after 20 min and Circ thru bit 0.411300. Out MM plugged off from more aluminum pieces. Open EDC and circ 2.0/2450 wl 'out' MM bypassed while RIH. Cleaned up good by 5000' 05:10 - 05:35 0.42 DRILL P PROD2 Park at 8500'. Close EDC, route returns thru 'out' MM Log tie-in down from 8570', corr -10' 05:35 - 06:15 0.67 DRILL P PROD2 W iper to TD. Hole smooth. 06:15 - 08:45 2.50 DRILL P PROD2 Drill ahead from 9635'. 3600 psi fs at 2.67 in/2.68 out. DPSI: 200-300. DHWOB: 2-3k#. WHP/BHP/ECD: 62/3829/11.2 ppg. IA/OA/PVT: 0/0!372 bbls. INC/AZM/TF: 82.2(-l70R. ROP avg: 55 fph. 08:45 - 10:15 1.50 DRILL P PROD2 Wiper trip to window. 28.5 k# up wt off btm. 3550 psi fs at 2.67 in. PVT: 371 bbls. Hole smooth in both directions. 10:15 - 13:15 3.00 DRILL P PROD2 Drill ahead from 9785'. 3560 psi fs at 2.65 in/out. PVT: 367 bbls. 13:15 - 14:45 1.50 DRILL P PROD2 Wiper trip to window. Hole smooth. 3500 psi fs at 2.63 in/out. PVT: 365 bbls. 14:45 - 17:45 3.00 DRILL P PROD2 Drill ahead from 9935'. Finally found sand around 9960'. 17:45 - 18:30 0.75 DRILL P PROD2 Wiper trip to 7500' 18:30 - 18:55 0.42 DRILL P PROD2 Log tie-in down from 8570', corr +4.5' 18:55 - 19:40 0.75 DRILL P PROD2 Wiper to TD was clean except for wt loss and MW at 8663' PVT 356 19:40 - 23:35 3.92 DRILL P PROD2 Drill from 10085' 2.6i/2.57/3550l80-100R w/ i00-300 psi diff, 1-5k wob at 89 deg at 6631' TVD in mostly sand wf minor ankerite streaks. Swap to left at 10200'. Drill to 10245' and stacking PVT 354 23:35 - 00:00 0.42 DRILL P PROD2 Wiper to window 11121/2005 00:00 - 01:25 1.42 DRILL P PROD2 Finish wiper to window, clean both directions PVT 352 01:25 - 03:15 1.83 DRILL P PROD2 Drill from 10245' 2.6/2.57/3580/55-100L w/ 100-350 psi diff, 1-3.5k wob w! 11.4 ECD at 90 deg at 6632' TVD PVT 347 03:15 - 05:15 2.00 DRILL P PROD2 Wiper to window, clean both directions PVT 34i 05:15 - 08:00 2.75 DRILL P PROD2 Drill from 10400' 2.60/2.56/3600/85-110L w/ 100-350 psi diff, 1-3.5k w/ 11.46 ECD at 91 deg at 6631' TVD 08:00 - 10:15 2.25 DRILL P PROD2 Wiper trip to window. Log GR tie in. Add 3' correction. 3644 Printed: 11(28(2005 12:59:04 PM BP EXPLORATION Operations Summary Report Legal Well Name: 10-02 Common Well Name: 1Q-02 Event Name: DRILL+COMPLETE Start: 1115/2005 Contractor Name: NORDIC CALISTA Rig Release: 11!27/2005 Rig Name: NORDIC 2 Rig Number: Date 1112112005 11 /22/2005 From - To ~'I Hours ~ Task i Code i NPT ! Phase 08:00 - 10:15 2.25 DRILL P PROD2 10:15 - 15:00 4.75 ~ DRILL ~ P PROD2 15:00 - 17:15 2.25 DRILL P PROD2 17:15 - 21:00 3.75 DRILL P PROD2 21:00 - 21:50 0.83 DRILL P PROD2 21:50 - 22:55 i,08 DRILL P PROD2 22:55 - 00:00 1.08 DRILL P PROD2 00:00 - 01:25 1.42 DRILL P PROD2 01:25 - 03:20 1.92 DRILL P PROD2 03:20 - 05:15 I 1.921 DRILL I P I I PROD2 05:15 - 05:30 0.25 DRILL P PROD2 05:30 - 06:45 1.25 DRILL P PROD2 06:45 - 10:45 4.00 DRILL P PROD2 10:45 - 13:45 3.00 DRILL P PROD2 13:45 - 17:25 3.67 DRILL P PROD2 17:25 - 19;35 I 2.171 DRILL J P PROD2 19:35 - 22:05 2.501 DRILL ~ P PROD2 22:05 - 22:15 0.17 DRILL P PROD2 22:15 - 00:00 1.75 DRILL P PROD2 i1/23J2005 00:00 - 04:10 4.17 DRILL PROD2 04:10 - 05:15 1.08 DRILL PROD2 05:15 - 07:20 I 2.08 {DRILL I I I PROD2 07:20 - 07:35 0.25 DRILL PROD2 07:35 - 09:00 1.42 DRILL PROD2 09:00 - 13:05 4.08 DRILL PROD2 13:05 - 16:20 3.25 DRILL PROD2 16:20 - 19:00 2.67 DRILL PROD2 Page 13 of 16 Spud Date: 11/5/2005 End: 11 /27/2005 Description of Operations psi fs at 2.65 bpm. PVT: 335 bbls. Drill ahead from 10,550'. 3700 psi fs at 2.68 in/2.64 out. PVT: 326 bbls. 90.5 deg at 6628' TVD. Hit a few slow spots. Possibly ankorite. Wiper trip to window. 3730 psi fs at 2.67 bpm. Load trucks for mud swap. Thaw upright valves. Drill ahead from 10700'. Get into ankerite at 10738' and point TF down Start new mud at 10757' 2.6/2.57/3630/165L w/ 200 psi dill and 5.4k wob w/ 11.46 ECD and still drilling ankerite Break out of ankerite at 10762' and drill 2.6/2.58/3400/85L w/ 100-400 psi dill and 1.5-2.5k wob w/ 11.0 ppg ECD after hole displaced Wiper to window was clean Wiper back to TD was clean Drill from 10850' 2.6/2.56/3500/90L w/ 100-300 psi dill, 1.5-2.5k wob wl 11.2 ECD at 88 deg at 6641' TVD Wiper to window, clean. Puli thru window and wiper to 8000', clean. Wiper back in hole Log tie-in down from 8570', Corr +4.5' Wiper back to TD. Hole smooth. Drill ahead from 11,000'. 3410 psi fs at 2.57 in/out. 200-300 DPSI DHWOB: 2k-3k#. WHPIBHPlECD: 6613854111.19 ppg. IA(OA/PVT: 143/44/390 bbls. INC/AZMJTF: 89.il4.5/105L. ROP: 30-50 fph. Some short hard spots, mostly good looking sand. Wiper to window Drill from 11150' 2.6/2.57/35000/70-90L w/ 1-3.5k wob, 100-300 psi dill w/ 11.32 ECD at 90 deg at 6642' TVD. Swap to right at 11220' Wiper to window. Setdown at 9624' pick-up once and went through. Okay to bottom. Drill ahead f/ 11300' to 11305' then hit Ankorite stringer 2.66/2.60 3450 fs 2-300 mw 4-5k wob 10'/hr Short wiper trip to 11200' Drill Ankorite f/ 11319' to 11330' 4k wob. Drilling ahead t/ 11330'. Came out of Ankorite at `I~1336' then back in at 11341'. Adjust TF to 1258 to aggressively drop below Ankorite. Still in Ankorite at 11356'. Set TF to 180. 2.65/2.60 3500fs 2-300 mw 5k wob 11.4ppg ECD Drilling ahead in good sand. 3k wob 90'/hr positive 6-7k coil wt. Bring TF to 508 Wiper trip to window was clean. Pull thru window and wiper to 8000', clean. Wiper back in hole Log tie-in down from 8570', corr +6.5' Wiper back to TD was clean PVT 319 Drill from i 1452' 2.63/2.58/3490/1658 w/ 200-400 psi dill, 2-3k wob wl 11.56 ECD at 6641' TVD at 92 deg. Find ankerite at 11472' and 11565', but otherwise drill at 60'/hr w/ 6.8k str wt w/ 2.8k wob. Swap to left at 11550' PVT 311 Wiper to window, clean both directions Drill from 11598' 2.612.5413530J60L wJ 200-400 psi dill, 2-3k wob w14k str wt wJ 11.59 ECD at 89 deg at 6638' TVD Printed: 11/28/2005 12:59:04 PM BP EXPLORATION Operations Summary Report Legal Well Name: iQ-02 Common Well Name: 1Q-02 Event Name: DRILL+COMPLETE Start: 11/5/2005 Contractor Name: NORDIC CALISTA Rig Release: 11!2712005 Rig Name: NORDIC 2 Rig Number: Date From - To ! Hours j Task j Code i NPT I; Phase ----~ _-1__- _ __' 11/23/2005 22:45 - 00:00 1.25 DRILL ~ PROD2 PROD2 11/24/2005 ~ 00:00 - 03:30 3.50 ~ DRILL ~ P ~ ~ PROD2 03:30 - 04:00 0.50 DRILL P PROD2 04:00 - 06:00 2.00 DRILL P PROD2 06:00 - 07:45 I 1.751 DRILL I P I I PROD2 07:45 - 09:10 1.42 DRILL P PROD2 09:10 - 09:25 0.25 DRILL P PROD2 09:25 - 10:50 1.42 DRILL P PROD2 10:50 - i 1:05 0.25 DRILL P PROD2 11:05 - 13:00 1.92 DRILL P PROD2 13:00 - 14:20 { 1.331 DRILL 1 P f I PROD2 14:20 - 14:35 0.25 DRILL P PROD2 14:35 - 16:00 1.42 DRILL P PROD2 16:00 - 16:30 0.50 DRILL P PROD2 16:30 - 17:45 I 1.251 DRILL I P I I PROD2 17:45 - 18:35 ~ 0.83 ~ DRILL ~ P ~ ~ PROD2 18:35 - 00:00 5.421 DRILL P PROD2 11/25/2005 ~ 00:00 - 01:50 ~ 1.83 ~ DRILL ~ P ~ ~ PROD2 Page 14 of 16 Spud Date: 11/5/2005 End: 11 /27/2005 Description of Operations Wiper trip to window. Hole in good condition. Directionally drill ahead f/ 11738' 2.62/2.57 3820fs 200-300 mw, 2-3k wob 80'/hr 4k CT wt. ECD 11.7ppg Presently at 6644' tvd plan is to drop to 6660' tvd by 11900'. Ran into Ankorite at 11780'. Drill f/ 11783' to 11808' in Ankorite w/ 180 TF. Swapped to new 9.2ppg FloPro mud system. 2.60/2.63 3550fs <50psi mw 11.6ECD 4.5k wob Short wiper trip to 11200'. Drill ahead on Ankorite section. Same parameters. ECD dropping with new mud system 11.42ppg Seeing small pieces of motor's stator rubber occasionally coming across shaker since midnight. Final check of parameters while attempting to drill at 11811' 2.64/2.6(3560/179L w150-100 psi diff, 4k wob w! -13k surface wt at 11.41 ECD at 89 deg w/o progress (assume motor and bit are shot). PVT 250 Wiper to window w/minor overpull and MW at 9637' POH, circ thru bit 2.8513500 following pressure schedule Safety mtg while flowcheck PVT 180 LD drilling assy. Reconfigure for tractor run w/o resistivity. Bit was rung out on nose (had first two cutter visible) and motor was loose Safety mtg re: MU/test tractor assy RU to use standpipe line for surface test of tractor. MU motor w/o bit and attach tractor. Close bag. Bring rate up in stages and find that wheels turn at 1.5 bpm and open at 2.0 bpm. RD test setup/MU used CRXE bit. MU MWD on tractor assy RIH w/ BHA #14 (1.2 deg motor, used CRXE bit w/ Weltec tractor tool) circ 0.311200 thru bit following pressure schedule Log tie-in down from 8570', corr +10' Wiper in hole at 1.5/2490 was clean Start motor/tractor at 11700' 2.47/2.47/3988 and ream while zeroing wob sensor while RIH 11'/min. Tag TD @ 11810'? at 1.0 bpm. PUH 36k. Start motor, ease in hole looking for TD. Seem to find it at 11811', but have 1 i .4k pos string wt, zero dill PVT 317 Drill ahead from 11813' while learning how to drill w/ tool 2.44/2.43/3900/110L w/ 2.5k wob, 0-150 psi dill w/ 11.5 ECD at 88 deg at 6646'. In and out of ankerite Drilled to i 1830' motor started to stall and SLB trips shutdown pump at 4600psi. May be out of Ankerite. Stabilizer pressures at 1000psi. PU string to 11800'. Slowly RIH pum at 2.47 stop and check Tractor function/pull test 9201bs -good. Slowly RIH tag bottom. Resume drilling at 55'/hr 2k wob 9600# CTW 2.47/2.44 3900fs 200mw 11.45ppg ECD Back into Ankerite at 11840' 150psi mw 4k wob -5000# CTW. TF 180 Have been drilling on Ankerite last 6 hrs. No progress last 1-1/2 hrs. (bit maybe) Slowdown pump to relax Tractor wheels. PU off btm 36.2k. Open EDC. Pump at 2.55bpm short trip to 11000'. RIH to 11650' and close EDC. BHi surface equipment indicates the EDC has a "position missed error". The EDC is Printed: 11/28/2005 12:59:04 PM BP EXPLORATION Page 15 of 16 Operations Summary Report Legal Well Name: 1 Q-02 Common W ell Name: 1 Q-02 Spud Date: 11 /5/2005 Event Nam e: DRILL+C OMPLE TE Start : 11/5/2005 End: 11/27/2005 Contractor Name: NORDIC CALIST A Rig Release: 11/27/2005 Rig Name: NORDIC 2 Rig Number: Date I From - To j Hours ~ Task I Code it NPT ~ Phase Description of Operations I 11/25/2005 00:00 - 01:50 1.83 DRILL P PROD2 closed but no attempt to open it again should be made or it could go into the "disconnect" mode. Only option is to TOH. This EDC has 340hrs on it. 01:50 - 04:45 2.92 DRILL N PROD2 TOH. EDC is closed. Having the Tractor in the string we can only pump at 1.5bpm maximum. 04:45 - 05:00 0.25 DRILL N PROD2 PJSM for changing out BHA componets and monitor well. 05:00 - 06:00 1.00 DRILL N PROD2 LD BHA. Bit was rung out on nose w/one cutter visible on nose. Tractor wheels were worn, tool was full of cuttings and profusely leaking hydraulic fluid. Weltec elected not to run backup tool due to hole conditions 06:00 - 08:00 2.00 DRILL P PROD2 Discuss w1 Asset and will drill to planned TD of around 12050' while looking for A3 marker wJ GR. Scribe motor, load out tractor tools while wo new CHXE bit (to keep test conditions similar). MU BHA 08:00 - 09:30 1.50 DRILL P PROD2 RIH w/ BHA #15 (1.2 deg motor, used 1-1-I CHXE bit from L5-17) circ thru bit 0.3/1190 following pressure schedule 09:30 - 09:50 0.33 DRILL P PROD2 Log tie-in down from 8570', corr +12' 09:50 - 11:45 1.92 DRILL P PROD2 Wiper back to TD and normal rates 2.4/3300 @ 35'/min. Had several setdowns between 11450-550'. Tag TD at 11846' 11:45 - 15:30 3.75 DRILL P PROD2 Resume drilling ankerite 2.54!2.51/3585190-170L w! 3.5-4.Ok wob, 250 psi diff at 11.5 ECD at 80 deg. Get out of ankerite at 11855' and back to 50'/hr. Drill to 12000' (6665' TVD) 15:30 - 17:25 1.92 DRILL P PROD2 Wiper to window 17:25 - 18:00 0.58 DRILL P PROD2 Log tie-in down from 8570' +2.5' 18:00 - 19:35 1.58 DRILL P PROD2 Wiper back to bottom. No problems 19:35 - 21:00 i.42 DRILL P PROD2 Drill ahead f/ 12000'. 2.63/2.62 3740fs 350mw ECD 11.7ppg, 2k wob +3500 CTW 50'/hr Drilled to 12050' TD 21:00 - 00:00 3.00 DRILL P PROD2 Wiper to window. Clean pu off bottm 33.6k. Clean to window. RIH 11/26/2005 00:00 - 01:00 1.00 DRILL PROD2 Finish wiper trip to bottom 12050'. No problems. 01:00 - 04:10 3.17 DRILL PROD2 TOH for liner. Spot new 9.2ppg Flo-Pro pill with 3ppb Alpine Beads in openhole. Stop at 100' flow-check well. Hold PJSM for UD BHA same time. Well dead. 04:10 - 04:45 0.58 DRILL PROD2 Tag-up. Unstab injector. UD BHA #15 04:45 - 05:00 0.25 CASE RUNPRD PJSM review liner running procedures, and potential hazards. Review liner running order and liner jewelry. 05:00 - 05:15 0.25 CASE RUNPRD RU tongs and 2-7/8" elevators. MU TIW to solid jt 2-718". 05:15 - 12:10 6.92 CASE RUNPRD MU 103 jts 2-7/8" 6.16# L-80 8TL R2 slotted liner, plus 6 jts 3-3/16" 6.2# L-80 TCII R2 solid liner w/guide shoe, o-ring sub, LSL sub and 3-1/2" BTT Deployment sub (3553.44' OA). MU BHI MWD assy 12:10 - 13:00 0.83 CASE RUNPRD RIH w/ BHA #16 (liner on CT). Initial CT surface wt 11k. Circ thru GS 0.3511500 following pressure schedule 13:00 - 14:00 1.00 CASE RUNPRD Wt chk Q 8500'=37k. RIH thru window clean. RIH in OH w/ {finer at 70'fmin and tag TD at 12034'. PUH 55k for 40', clean. RBIH and set liner at TD 14:00 - 14:10 0.17 CASE RUNPRD Incr pump and bleed off WHP 1.7/4200. PUH 30.5k and released GS from liner leaving TOL at 8496.56' w! shoe at 12050'. Open EDC 14:10 - 15:45 1.58 CASE RUNPRD POH circ 1.5/2150 following pressure schedule 15:45 - 16:30 0.75 CASE RUNPRD Check well for flow. LD BTT GS and MWD tools 16:30 - 17:00 0.50 WHSUR POST MU nozzle assy w/ stinger Printed: 11/28/2005 12:59:04 PM BP EXPLORATION Page 16 of 16 Operations Summary Report Legal Well Name: 1 Q-02 Common Well Name: 1Q-02 Event Name: DRILL+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To I Hours I Task ~i Code ~ NPT - _ - - 1- - ~- _~ 11 /26/2005 ~ 17:00 - 20:00 3.00 ~ W HS U R 20:00 - 20:45 0.75 WHSUR 20:45 - 21:00 0.25 WHSUR 21:00 - 23:20 2.33 WHSUR 23:20 - 00:00 { 0.671 WHSUR 11/27/2005 ~ 00:00 - 01:30 i 1.50 ~ RIGD i P 01:30 - 01:45 0.25 RIGD P 01:45 - 02:15 0.50 RIGD P 02:15 - 07:30 5.25 RIGD P Spud Date: 1 il5/2005 Start: 11/5/2005 End: 11/27/2005 Rig Release: 11/27/2005 Rig Number: Phase ~~ Description of Operations +_ --- __ - POST RIH following pressure schedule while circ 30 bbls rig water followed by 160 bbls diesel to 8400'. TOH displacing tbg with diesel. Shut MV/SV trapping 950psi on well. POST RU N2 equipment. POST PJSM review blowdown procedures and hazards. POST PT N2 lines to 4000psi. load coil with 20 bbls methanol. Seeing higher than normal pump pressures at low pump rate. Unstab injector. Find both BHI check valves trash. Lower check valve's baffle worn off stem that holds it in place. Upperllower valve both had high errosion wear. Stab back on well. Pump remaining meth and blow down reel with N2. Bleed off pressures. POST LD nozzle BHA and BHI upper/lower quick connect. Cut-off Kendle connector. POST Install internal grapple to end of 2-3/8" coil. Prep to unstab from injector and secure end to reel. POST PJSM review procedures and hazards for unstabbing coil. POST Pull back coil to reel and secure. Prep to lower reel. POST Lower reel. Remove pack-off from injector and secure to rig floor. Change out BOP rams to 2". NDBOP stack and install tree cap. Clean rig pits. Empty cuttings and Tiger tank. RREL @ 0730 hrs Additional comments found on 1 L-25 report of same date Printed: 11/2812005 12:59:pA PM BP Alaska Baker Hughes INTEQ Survey Report BAKER HUGHES INTEQ Company: ConocoPhillips Alaska, Inc. ~ Field: Kuparuk River Unit llate: 1/12/2006 Time 05:39:56 Page: t Co-ordinatc(NE) Reference: Well: 2, True North Site: KRU 1Q Pad Vertical (TVD) Re ference: Datum 2 78.0 ~ Weil: 2 Section (VS) Refer ence: Well (O.OON,O.OOE,41.91Azi) j 4Veltpath_ 1 Q-02BL1 _ _ _ _ _ _ Survey Calculatio n Method: _ Minimum Curva ture __ Db: Sybase Field: Kuparuk River Unit- - - _ - - _ - ~- - - -~- - - ------ North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Sy stem: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2004 Site: KRU 1Q Pad UNITED STATES: North Slope Site Position: Northing: 5985877.04 ft Latitude: 70 22 20.956 N From: Map Easting: 529617.73 ft Longitude: 149 45 33.406 W Position Uncertainty: 0.00 ft North Referen ce: True Ground Level: 0.00 ft Grid Convergence: 0.23 deg Well: 2 Slot Name: We{l Position: +N!-S -1206.00 ft Northing: 5984666.52 ft ' Latitude: 70 22 9.094 N +E/-W -1175.00 ft Easting : 528447.63 ft ~ Longitude: 149 46 7.777 W Position Uncertainty: 0.00 ft Wellpath: 1 Q-02BL1 Drilled From: 1 Q-02BPB1 Tie-on Depth: 9625.00 ft Current Datum: Datum 2 Height 78.00 ft Above System Datum: Mean Sea Level Magnetic Data: 11/18/2005 Declination: 24.02 deg Field Strength: 57614 nT Mag Dip Angl e: 80.78 deg Vertical Section: Depth From (TVD) +N/-S +E!-W Direction ft ft ft deg 78.00 0.00 0.00 41.91 Survey Program for Definitive Wellpath Date: 11/18!2005 Validated: No Version: 3 Actual From To Survey Toolcode Tool Name ft ft 88.00 6300.00 GMS (88.00-8564.00) (0) Good_gyro Good Gyro 6392.91 7625.15 MWD (6392.91-8345.00) (1) MWD MWD -Standard 7677.06 8418.17 MWD (7677.06-9017.00) (2) MWD MWD -Standard 8539.00 9589.64 MWD (8539.00-10552.00) (3) MWD MWD -Standard 9602.00 12050.00 MWD (9602.00-12050.00) MWD MWD -Standard Annotation ~ MD fVD ~ ft ft 9589.64 6680.94 TIP 9602.00 6682.91 KOP 12050.00 6757.59 TD Survey: MWD Start Date: 11/21/2005 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path Survey MD Inc! Azim 1'Vll Sys TVD N/S E/W D1apN Mapk~ VS DLS Tool I ft deg deg ft ft ft ft ft ft ft deg/100ft i ----------------- 9589.64 80.48 333.37 6680.94 6602.94 -_-.--_- 2573.79 4090.54 -_ _. __. --- 5987255.58 532527.95 --.-_-. -. 4647.65 0.00 MWD 9602.00 81.18 335.13 6682.91 - 6604.91 2584.78 4085.24 5987266.55 532522.61 4652.29 15.16 MWD 9635.79 82.04 342.00 6687.85 6609.85 2615.88 4073.03 5987297.60 532510.29 4667.28 20.27 MWD 9665.06 83.81 346.00 6691.45 6613.45 2643.80 4065.03 5987325.48 532502.18 4682.71 14.85 MWD 9695.08 83.15 349.85 6694.86 6616.86 2672.96 4058.79 5987354.61 532495.83 4700.24 12.93 MWD 9725.56 82.56 353.61 6698.66 6620.66 .2702.88 4054.44 5987384.52 532491.37 4719.61 12.39 MWD 9755.29 82.62 357.08 6702.49 6624.49 2732.26 4052.05 5987413.88 532488.86 4739.87 11.58 MWD 9790.95 83.83 1.33 6706.70 6628.70 2767.66 4051.56 5987449.28 532488.24 4765.89 12.31 MWD 9820.31 83.99 4.91 6709.82 6631.82 2796.80 4053.15 5987478.43 532489.72 4788.64 12.14 MWD 9850.14 85.93 8.01 6712.44 6634.44 2826.32 4056.49 5987507.96 532492.95 4812.85 12.22 MWD 9880.03 88.45 10.94 6713.90 6635.90 2855.77 4061.40 5987537.41 532497.75 4838.04 12.92 MWD 9911.54 91.80 12.46 6713.83 6635.83 2886.62 4067.79 5987568.28 532504.02 4865.27 11.67 MWD 9940.73 92.57 16.39 6712.72 6634.72 2914.86 4075.06 5987596.55 532511.18 4891.14 13.71 MWD ' ~ BP Alaska ~ ~G~s Baker Hughes INTEQ Survey Report INTEQ ~ Compan~~: ConocoPhillips Alaska, Inc. Date: 1/12/2006 Time: 05:39:56 Page: 2 I, li Field: Kuparuk River Unit Co-ordinate(VH:) Reference: V'Jelf: 2, True North Site: KRU 1 Q Pad Vertical (1 VD) Reference: Datum 2 78.0 Wcll: 2 Section (VS) Reference: Well (O.OON,O.OOE,41.91Azi) Wcllpath: 14-026L1 Survey Calculation J'icthod: Minimum Curvature Ub: Sybase --___-- - _ _- _ _. --____ -_- - ------- __--- __--J Survcv N1D Incl Azim 'I'VD S~,S TVU N/S 1'J1V D~fapN NIapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft 9970.21 93.77 19.28 6711.09 6633.09 2942.88 4084.07 5987624.60 532520.08 4918.01 10.60 MWD 10000.94 92.04 22.65 6709.53 6631.53 2971.53 4095.05 5987653.29 532530.95 4946.67 .12.31 MWD 10029.98 90.57 26.54 6708.87 6630.87 2997.92 4107.13 5987679.73 532542.93 4974.38 14.32 MWD 10059.79 89.65 28.54 6708.81 6630.81 3024.35 4120.91 5987706.21 532556.61 5003.26 7.38 MWD 10088.93 88.35 32.59 6709.32 6631.32 3049.43 4135.73 5987731.34 532571.33 5031.82 14.59 MWD 10118.64 88.61 39.01 6710.11 6632.11 3073.51 4153.09 5987755.48 532588.60 5061.33 21.62 MWD 10147.92 90.57 41.49 6710.32 6632.32 3095.85 4172.01 5987777.90 532607.43 5090.60 10.80 MWD 10178.05 89.83 46.35 671022 6632.22 3117.55 4192.90 5987799.67 532628.24 5120.70 16.32 MWD 10208.98 90.60 46.98 6710.10 6632.10 3138.77 4215.40 5987820.98 532650.65 5151.52 3.22 MWD 10238.25 89.98 43.33 6709.95 6631.95 3159.41 4236.14 5987841.69 532671.32 5180.74 12.65 MWD 10268.53 89.43 39.33 6710.11 6632.11 3182.14 4256.14 5987864.50 532691.22 5211.01 13.33 MWD 10298.27 90.08 35.64 6710.23 6632.23 3205.74 4274.23 5987888.16 532709.22 5240.66 12.60 MWD 10328.35 90.84 30.20 6709.99 6631.99 3230.98 4290.57 5987913.46 532725.47 5270.36 18.26 MWD 10358.26 91.80 26.35 6709.30 6631.30 3257.31 4304.74 5987939.84 532739.53 5299.41 13.26 MWD 10388.31 92.44 21.84 6708.19 6630.19 3284.71 4316.99 5987967.29 532751.68 5327.99 15.15 MWD 10423.46 91.37 17.92 6707.02 6629.02 3317.74 4328.94 5988000.36 532763.50 5360.55 11.55 MWD 10451.33 90.45 14.10 6706.58 6628.58 3344.52 4336.62 5988027.17 532771.08 5385.61 14.10 MWD 10486.46 90.44 8.80 6706.31 6628.31 3378.94 4343.59 5988061.61 532777.92 5415.89 15.09 MWD 10515.55 91.73 9.97 6705.76 6627.76 3407.64 4348.33 5988090.32 532782.55 5440.41 5.99 MWD 10545.08 91.40 15.67 6704.95 6626.95 3436.41 4354.88 5988119.11 532788.99 5466.19 19.33 MWD 10575.24 89.68 21.13 6704.66 6626.66 3465.01 4364.40 5988147.75 532798.39 5493.84 18.98 MWD 10604.54 91.98 23.77 6704.24 6626.24 3492.08 4375.58 5988174.86 532809.48 5521.46 11.95 MWD 10636.60 90.51 26.49 6703.54 6625.54 3521.10 4389.19 5988203.92 532822.97 5552.14 9.64 MWD 10665.68 89.49 29.61 6703.54 6625.54 3546.76 4402.86 5988229.63 532836.55 5580.37 11.29 MWD 10701.90 86.97 31.30 6704.66 6626.66 3577.96 4421.21 5988260.90 532854.77 5615.85 8.38 MWD 10730.13 85.99 29.92 6706.40 6628.40 3602.21 4435.56 5988285.20 532869.03 5643.48 5.99 MWD 10760.21 82.35 29.01 6709.45 6631.45 3628.26 4450.28 5988311.31 532883.64 5672.70 12.47 MWD 10790.22 83.00 25.20 6713.28 6635.28 3654.75 4463.84 5988337.85 532897.10 5701.47 12.78 MWD 10820.52 86.27 21.71 6716.11 6638.11 3682.42 4475.84 5988365.56 532909.00 5730.08 15.75 MWD 10849.96 87.62 19.01 6717.68 6639.68 3709.98 4486.06 5988393.15 532919.12 5757.42 10.24 MWD 10879.94 88.88 14.51 6718.60 6640.60 3738.67 4494.70 5988421.87 532927.65 5784.53 15.58 MWD 10910.37 88.94 12.28 6719.18 6641.18 3768.26 4501.75 5988451.48 532934.58 5811.27 7.33 MWD 10940.42 89.13 8.63 6719.68 6641.68 3797.80 4507.20 5988481.04 532939.92 5836.89 12.16 MWD 10970.66 89.68 4.46 6720.00 6642.00 3827.84 4510.65 5988511.09 532943.25 5861.55 13.91 MWD 11000.48 90.17 0.50 6720.04 6642.04 3857.62 4511.94 5988540.88 532944.43 5884.58 13.38 MWD 11030.83 88.33 357.93 6720.43 6642.43 3887.96 4511.52 5988571.21 532943.90 5906.88 10.41 MWD 11060.37 89.16 354.76 6721.08 6643.08 3917.43 4509.64 5988600.67 532941.90 5927.56 11.09 MWD 11089.84 89.13 352.09 6721.52 6643.52 3946.70 4506.26 5988629.92 532938.42 5947.09 9.06 MWD 11119.73 89.86 348.60 6721.78 6643.78 3976.16 4501.25 5988659.36 532933.29 5965.67 11.93 MWD 11149.87 91.30 346.13 6721.48 6643.48 4005.57 4494.66 5988688.74 532926.59 5983.15 9.49 MWD 11180.00 92.16 343.09 6720.57 6642.57 4034.60 4486.67 5988717.74 532918.49 5999.42 10.48 MWD 11210.07 92.13 340.70 6719.44 6641.44 4063.16 4477.33 5988746.26 532909.04 6014.43 7.94 MWD 11240.18 91.30 343.75 6718.54 6640.54 4091.82 4468.15 5988774.88 532899.75 6029.63 10.49 MWD 11269.74 90.45 343.96 6718.09 6640.09 4120.21 4459.93 5988803.23 532891.42 6045.27 2.96 MWD 11299.96 89.92 349.47 6717.99 6639.99 4149.61 4452.99 5988832.60 532884.37 6062.51 18.32 MWD 11330.97 89.86 352.53 6718.05 6640.05 4180.23 4448.14 5988863.21 532879.41 6082.06 9.87 MWD 11361.49 87.87 355.04 6718.66 6640.66 4210.56 4444.83 5988893.52 532875.99 6102.43 10.49 MWD 11391.19 90.26 356.75 6719.14 6641.14 4240.18 4442.71 5988923.13 532873.75 6123.05 9.89 MWD 11420.36 92.16 359.69 6718.52 6640.52 4269.32 4441.80 5988952.27 532872.73 6144.14 12.00 MWD 11451.81 93.30 3.07 6717.03 6639.03 4300.72 4442.56 5988983.67 532873.37 6168.01 11.33 MWD 11485.00 90.69 4.69 6715.87 6637.87 4333.81 4444.80 5989016.76 532875.49 6194.14 9.25 MWD 11514.84 89.71 7.34 6715.77 6637.77 4363.49 4447.93 5989046.44 532878.50 6218.31 9.47 MWD 11545.56 89.46 9.22 6715.99 6637.99 4393.88 4452.35 5989076.85 532882.81 6243.89 6.17 MWD 11577.48 86.36 6.31 6717.15 6639.15 4425.48 4456.66 5989108.47 532887.00 6270.28 13.32 MWD 11616.91 86.88 3.37 6719.48 6641.48 4464.70 4459.98 5989147.69 532890.17 6301.69 7.56 MWD 11645.13 88.39 0.97 6720.64 6642.64 4492.87 4461.05 5989175.86 532891.13 6323.37 10.04 MWD 11675.32 86.98 357.73 6721.86 6643.86 4523.03 4460.71 5989206.02 532890.67 6345.58 11.70 MWD ' ~ BP Alaska Baker Hughes INTEQ Survey Report BAKER Wu~we±~ Company: ConocoPhillips Alaska, Inc. Date: 1/12/2006 Time 0539:56 Page: 3 Field: Kuparuk River Unit Co-ordinatc(NE) Reference: Well: 2, True North Site: ~ KRU 1Q Pad Vertical ("CVll) Reference: Datum 2 78.0 ~ Well: 2 Section (VS) Reference: Well (O.OON,O.OOE,41.91Azi) yVel)path: 1Q-02BL1 Survey Calculation Method: Minimum Curvature Db: Sybase D1D -ncl Azim FVD SysT~~D N/S EIW MapN i~1apE VS DLS Tool ft I __ _ deg _ deg -- --- ft - _ ft ft ft ft ft ft _ deg(100ft 11705.15 87.28 353.66 6723.36 -- 6645.36 4552. _ 73 4458.47 __ - 5989235.71 - - - 532885.32 _ - 6366.19 - 13.66 - MWD 11735.29 89.74 352.11 6724.14 6646.14 4582. 63 4454.74 5989265.59 532884.48 6385.95 9.65 MWD 11765.09 88.91 348.12 6724.49 6646.49 4611. 98 4449.62 5989294.91 532879.25 6404.38 13.67 MWD 11815.36 83.68 344.60 6727.74 6649.74 4660. 70 4437.81 5989343.59 532867.25 6432.75 12.53 MWD 11845.12 82.56 340.36 6731.31 6653.31 4688. 87 4428.91 5989371.72 532858.25 6447.77 14.64 MWD 11875.43 80.49 341.09 6735.77 6657.77 4717. 17 4419.02 5989399.98 532848.25 6462.22 7.23 MWD 11905.46 79.72 342.95 6740.93 6662.93 4745. 31 4409.89 5989428.08 532839.01 6477.06 6.62 MWD 11944.69 80.50 346.89 6747.68 6669.68 4782. 61 4399.84 5989465.34 532828.82 6498.12 10.09 MWD 11974.27 83.59 349.63 6751.77 6673.77 4811. 29 4393.88 5989493.99 532822.76 6515.48 13.90 MWD 12006.16 85.72 353.26 6754.74 6676.74 4842. 68 4389.16 5989525.36 532817.92 6535.69 13.15 MWD 12018.07 86.36 355.00 6755.56 6677.56 4854. 50 4387.94 5989537.18 532816.66 6543.67 15.53 MWD ,~ 12050.00 86.36 355.00 6757.59 6679.59 4886. 25 4385.17 5989568.91 532813.76 6565.44 0.00 MWD KRU 1 Q-02B Injector Proposed CTD Completion E. 4-1/2" Camco DS nipple, 3.875" min ID at 500' MD 9-5/8" 36# J55 ~ 3830' D. 4-1/2" Baker CMU sliding sleeve @ 6009' MD w/ 3.812" min ID 7" 26# J-55 6268 MD' 2-3/8" liner top @ +/-8400' MD Window in 4-1/2" KOP at 8550' MD Squeezed A3/® A4-sand perfs -"~ 8662' - 8808' and 4-1/2" 12.8# L-80 ~ 9010 MD' Fill B. Baker "Hyflo III" liner top packer/SBE/seal assembly at 6119' MD ~`'' ~ , t~r'~C)~t~~'1! ~ ~ ~5- Alaska, Inc. 1Q-02BPB1 A4 Lateral, TD @ 10,552' MD/6596' TVD A. 3-°/2" Otis "X" nipple, 3.812" min ID at 7975' MD Sgz'd C-sand perfs ° ° 4 1 /8" / 3 3/a" Openhole ® 8369'-8384' and ° ° ° ° °° i r~ ° ° 1 Q-02B A4 Lateral, TD @ 11,500' MD/6674' TVD; 6, ~~a KOP @ 9975' MD/6605' TVD; P/N: 205-142 `~ 3 3 \\,~et ° o ° ° o o ° ° o 0 0 0 ° ° ° o 0 0 0 0 0 0 0 ° o o ° ° o o ° ° ° ° o 0 0 0 0 0 0 0 0 0 0 0 1Q-02BL1 A3 Lateral, TD @ 12,050' MD/6680' TVD; KOP @ 9609' MD/6605' TVD; P/N: 205-186 2-7/8" slotted liner, 4 holes/ft, 3/8" hole size xE:1Q-ozBiJl • Subject: RE: 1Q-02BL1 From: "Hubble,. Terrie L" <HubbleTL zr BP.com> Date: Mon, 21 Nov 2005 09;~t2:04-0900 'To: Thomas ~~laun~i~r =-tom_maund eaYuaclmin.st~ite.akus: C'C': "~Vortbington, ;1ras J" ~ wortaj~ci BP.corn=~° "Gann, Lamar L" <-GanttLL(«~~BP.conl- Hi Tom, Yes, these wells (legs) will all be injectors. Sorry for the confusion. Thanks! ._^ Terrie -----Original Message----- From: Thomas Maunder [mailta:tam maunder«?admi.rz.state.ak.us] Sent: Monday, November 21, 2005 7:53 AM To: Worthington, Aras (ConocoPhillips) Cc: Hubble, Terrie L Subject: 1Q-02BL1 Aras, Left a message on your cell phone on Friday. Regarding the permit for this well. Are 1Q-02B and -02BL1 going to be injectors? 1Q-02A was a service (WAG) well and 1Q-02B was permitted as a service well but -02BL1 is "checked" as a development well. Sorry to be bureaucratic but... If it is a service well, just let me know. It should not be necessary to resubmit any paperwork. I can make the corrections on the copy already submitted. Thanks, Tom Maunder, PE AOGCC 1 of 1 11!21!2005 9:45 AM Re: 1Q-02B Diagram • Subject: Re: 1Q-02B Diagram From: Thc~~nas Maunder ~ _to~T~ maundcr~cz~~idrninatate.ak.iis= Dater Thu, 10 Nov 2005 ] 1:02:25 -O90U L_J To: "~~~orthin~ion, Aral ,f" ~ =.bras.J.~~'orthin~ton~ri%conocophillips.com= CC: Step e Day ics ~ stc~ e davicsra!a~lir~in.statc.ak.us Aras, Jpg works just fine. Steve Davies and I looked at your drawing. Thanks, that makes the determination much easier. Based on prior "naming", Steve and I believe that the name for the upper hole section should be 1Q-02BL1. Thanks for checking. We will look forward to the paperwork. Please note, it is acceptable to continue you operations pending receipt of the approved permit. The change in well path(s) is due to geological reasons. Call or message with any questions. Tom Maunder, PE AOGCC Worthington, Aras J wrote, On 11/10/2005 10:46 AM: Tom, How about Jpg? Let me know if this works! Thx, Aras -----Original Message----- From: Thomas Maunder f mailtoaom_ maunder@admin.state.ak.us] Sent: Thursday, November 10, 2005 10:32 AM To: Worthington, Aras ) Subject: Re: iQ-02B Diagram Hi Aras, I can't open visio. Could you resend in .pdf, word or powerpoint?? Thanks, Tom Worthington, Aras J wrote, On 11/10/2005 10:27 AM: Tom, Here is the schematic of the proposed additional lateral. I propose we call the added A4 (upper) lateral 1 Q-02B-01 and the A3 lateral (essentially the original plan minus the A4 exposure) 1 Q-02B. Please call 440-7692 so we can discuss wellbore names. Thanks, Aras 1 oft 11/18/2005 1:33 PM 1Q-02B CTD proposed completion.jpg (JPEG Image, 1014x791 pixels) • • ~RU ~t~~0B 1~1JQCtL3C Prc~posed~ CTD Compl~tian E. daSi2' f;~xt3pp G~ ni~ipl4s, ~,&75° rt3in [© at SPt~' R4D 9.518" 36# J55 ~ 3E70' ~_ ~-'!+2" Heker CMU stirfir~g s}?~e~e c~7r 809' k!D w13.8tZ" min IA B: 8ak~r "Hyfto D(° li~'~er tt~p ptacker7SS~s~a1 ~ss~rnbty ei 6119' Wib CQn~c~Ph~li~s ~lasE~.~, lric. T 2fi~t'J SSA __... -- --- 6zssa~~ ~. ~ ~° oes .~» oivtNe. a.ai z° min teat ~sts~ rib A~ Latar~l, Tb a{e'~ ~1 t3,3{la' and Sqz°d C-sanc3 perfs /,/-~''''" ~~ 83b9'-8384' and ~ e '~9-~__~~~~ 2 a1s° Iin~r 4av ~ ~~a~ ,~ /~,~~ ~ 4 118" 13 ;e" O~ienhole °,~-~as79' nrttt ~.~C~ ~ j / ,~ ~ ,rte ~~ ti~Y'~ ~.' / / ~ ~.3 Lateral, ~D~ 92,05U'rttd = ,~ _ KOF at ~'iSSiJ` hAQ ~~ ~" ~ q a o e a o o n o P n e z~ n ~ a n a e~ n o o 0 Squeeaed A31~l4-sand ~'`~ 2-7rs° s3~n~d a~n~r 13nef, a r,oPes,Yt; si&' h~lesrz~ perfs 8662' -8808' and 4.if2"12.61t~.-8U Fill ~s9loRSn' DEV9r23?45 1 Of 1 11/18/2005 1:33 PM ALASK~f. OIL ~DI~S CO1~T5ERQA7'IO1Q COIrII-'II5SIOrT Aras Worthington CT Drilling Engineer Conoco Phillips Alaska Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: KRU 1 Q-02BL 1 Conoco Phillips Alaska Inc. Permit No: 205-186 ~y FRANK H- MURKOWSKI, GOVERNOR i a r r~ ~ 333 W. 7'" AVENUE, SUITE 100 f' ANCHORAGE, ALASKA 99501-3539 ~' PHONE (907) 279-1433 FAX (907) 276-7542 Surface Location: 1206' FNL, 1175' FEL, SEC. 26, T12N, R09E, UM Bottomhole Location: 3739' FSL, 3287' FWL, SEC. 24, T12N, R09E, UM Dear Mr. Worthington: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. The permit is for a new wellbore segment of existing well KRU 1Q-02B, Permit No 205-142, API 50-029-21248-02. Production should continue to be reported as a function of the original API number stated above. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness required test. Contact the Commission's petroleum field inspector at (907 59 3607 (pager). K. DATED this ~ day of November, 2005 cc: Department of Fish 8v Game,. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA NQV 1 ~ ZOO ALASK~IL AND GAS CONSERVATION C ISSION PERMIT TO DRILL ;r al.:ka nll ~+~~~ Gons. 20 AAC 25.005 /~tt~ Z~" ~ Anchorage 1 a. Type Of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^~ ~xploratory ! 'Development Oil ^ Multiple Zone ^ Stratigraphic Test p'Service [~ Development Gas ^ Single Zone 2. Operator Name: Conoco Phillips Alaska Inc. 5. Bond: ®Blanket ^ Singte Well Bond No. 59-52-180 ~' 11. Well Name and Number: Kuparuk 1Q-02BL1 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: ~ MD 12050 ` TVD 6664ss 12. Field f Pool(s): Kuparuk River Unit /Kuparuk 4a. Location of Well (Governmental Section): Surface: 1206' FNL 1175' FEL SEC T12N 26 R09E UM 7. Property Designation: ADL 025634 ° River Pool , , . , , , Top of Productive Horizon: 503' FSL, 2632' FEL, SEC. 24, T12N, R09E, UM 8. Land Use Permit: 13. Approximate Spud Date: November 19, 2005 Total Depth: 37`3 7 ~ /~c • r (• r;~' 3739' FSL,~,xxif` FWL, SEC. 24, T12N, R09E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 22,675' "" 4b. Location of Well (State Base Plane Coordinates): Surface: x- 528448 - 5984667 Zone- ASP4 10. KB Elevation (Height above GL): 78' feet 15. Distance to Nearest Well Within Pool 1 Q-22 is offset by 265' 16. Deviated Wells: Kickoff Depth: 8550 Maximum Hole Angle: 90 feet de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3500 Surface: 2870 r 113. asing rogram: Size Specifications Setting Depth To Bottom uantrty o ement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data a-va• X s-ara° s-a~~s° x 2-7~9° 6.4# / 6.16# L-80 STL 3510' 8540' 6434' 12050' 6664' Uncemented Slotted Liner 19. PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations) Total Depth MD (ft): 9017 Total Depth TVD (ft): 6830 Plugs (measured): 8883 Effective Depth MD (ft): 8720 Effective Depth TVD (ft): 6633 Junk (measured): None Casin Len th Size Cement Volume MD TVD r 100' 16" 40 sx Coldset II 100' 100' 3830' 9-518" 1000 sx Coldset 111, 420 sx Coldset 1 3830' 3517' 6268' 7" 550 sx Class 'G', 250 sx CS { 6268' 5205' r n 2955' 4-1/2" 113 sx Class 'G' 6055' - 9010' 5056' - 6822' Perforation Depth MD (ft): None Perforation Depth TVD (ft): None 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true an corr Printed Name Aras rthingto Si nature t to the best of my knowledge. Contact Aras Worthington, 440-7692 Title CT Drilling Engineer Preparetl By Name/Number: Phone Cell: 440-7692 Date // 3' ;' 7errie Hubble, 564-4628 Commission Use Only Permit To Drill -, Number: ?~°~~ ^ 1~~~_~ API Number: 50- 029-21248-60-00 Permit Appro I ~ Date: ~ ~ See cover letter for other requirements Conditions of Approval: Samples Required Hydro Ifide Measures Other: A rove ^ Yes ~ No Mud Log Required ^ Yes o ~'S'es ^ No Directional Survey Required Yes ~~ No APPROVED BY ~r ~ d THE COMMISSION Date Form 10-401 Revise oo ( ~~ ; ~~ ~ ~ ,~ ~ ubm In Duplicate ~i ~, ..,, KR~Q-02B & 1 Q-026L1 Sidetracks -Coiled Tubin Drillin 9 9 5ummarv of Operations: Coiled tubing planned to drill 1 lateral in injector KRU 1Q-02A using Dynamically Overbalanced pressure ` drilling technique (DOBCTD, see description below). The horizontal lateral will target Kuparuk A sand for injection. The existing Kuparuk A & C Sand perforations in the existing well 1Q-02A, will be cement squeezed and abandoned for injection control into the new lateral. A second lateral (1Q-02BL1) has been planned after drilling the build section of 1 Q-02B and finding ~5' TVD of ankerite. ~ CTD Drill and Complete 10-02B program: Planned for Nov 10, 2005 1. Pre CTD MIT-IA, MITT 2. Pre CTD test MV & SV 3. Pre CTD CT cement squeeze of A & C sand perforations 4. Pre CTD CT Mill out cement 5. Pre CTD drift tubing/liner with dummy whipstock 6. MIRU Nordic 2. NU 7-1l16" BOPE, test 7. Set 4'/z" whipstock at 8550' and 8. Mi113.80" window at -8550' and and 10' of openhole 9. Dri114 1/8" bicenter hole h~ntal lateral from window to --11,300' and targeting Kuparuk A3/A4 sands ~. -'~--r---^~ --•-~------____ 10. Kill well with Brine (~llppg). ~Q5'° ~~SCo 11. Complete with 2 718" slotted liner from TD to 9500' with an Aluminum kick-off billet. 12. Recover brine '~"~ ~ c, ~ ~-=~` ~ 13. Kick-off of Aluminu and drill 4 1/8" / 3 3/4" hole orizontal lateral to TD @ --12,050' i well wi nne (--1 lppg) 15. Complete with 3 3/16" x 2 7/8" slotted liner from TD, up into the 4 1/2" liner to ~ 540' 16. Recover Brine. 17. ND BOPE. RDMO Nordic 2. 18. Post CTD rig. BOL. Mud Program: • Step 8,9, & 13: 9.5 ppg Chloride based Flo-Pro mud • Step 10,11, 14, & 15: Chloride based Flo-Pro mud (~ 11 ppg) Disposal: • No annular injection on this well ' • Class II liquids to KRU 1R Pad Class II disposal well • Class II drill solids to Grind & Inject at PBU Drillsite 4 • Class I wastes will go to Pad 3 for disposal Casing Program: • 1Q-02B: 2 7/8", 6.16#, L-80, STL slotted liner from 9500' and to -11,300' md. • 1Q-02BL1: 3 3/16" x 2 7/8", 6.16#, L-80, STL slotted liner from 8540' and to 12,050' md. ` Well Control: • Two wellbore volumes 0370 bbls) of KWF will be location during drilling operations. • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4000 psi. • The annular preventer will be tested to 400 psi and 2500 psi. Directional • See attached directional plans for 1 Q-02B & 1 Q-02BL 1. ' • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. ' • The nearest well to 1Q-02B is 1Q-22, which is offset by 265': KRU boundary is 22675' away. KR~GI-02B & 1 Q-02BL1 Sidetracks -Coiled Tubin Drillin 9 9 Logging _ • MWD Gamma Ray & Resistivity will be run. Hazards • 1Q is an H2S pad, the highest H2S measurement on the pad is 220 ppm. All H2S monitoring equipment will be operational. Reservoir Pressure • The expected reservoir pressure of 1Q-02B &l Q-02BL1 is 3500 psi at 6300' TVD, 10.7 ppg EMW. Max. surface pressure with gas (0.1 psilft) to surface is 2870 psi. - DOBCTD Pressure Drilling Dynamically overbalanced pressure drilling (DOBCTD) techniques will be employed to provide constant bottom hole pressure by using 9.5 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be used to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allows use of less expensive drilling fluid and minimizes fluid losses and/or fracturing at the end of the long wellbores. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifolding and the mud pits and will be independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the BHA will be accomplished utilizing the BOP pipelslips (3" rams, see attached BOP configuration). The annular preventer will act as a secondary containment during deployment and not as a stripper. Estimated max reservoir pressure: 3500 psi at 6300' TVD, 10.7 ppg EMW. ~ Expected annular friction losses while circulating: 500 psi. Planned mud density: 9.5 ppg equates to 3110 psi hydrostatic bottom hole pressure. While circulating 9.5 ppg fluid, bottom hole circulating pressure is estimated to be 3600 psi or 11 ppg ECD. When circulation is stopped, a minimum of 500 psi surface pressure will be applied to maintain constant BHP. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements and shale behavior while drilling. • • Page 1 of 1 K RU 14028 Injector Y Proposed CTD Completion ~Ot'tOCO~Ij~IjJJrS Akaska,tnC. _ E. 4112" Camco DS nipple, 3.875" min ID st 888r YD 9-ara" ssr Jss ~ SSSO' D. 41l7'BakerCMU sliding sleeve ®BD68' W rd&812'min ID B. Baker "Hypo III° linertop paakedSBElseal assembly at 6178' ILl 7"90RJ-0a ~ .% s2sa altr A. 3-'h" Otis °k' nipple, o.s1 z~ min lD sa ~• Mlo 1 Q-02B Lateral, TD @ ~1 , 30D' and Sgz'd C-sand parts 8368'-8384' and 2-~!s"Gnertopd0 ~~p1t'f- 41!13"13'f." Operlhole ~!-aaoar~l0 ~~~6~~ 1 Q-02BL1 Lateral, TD @ 12,050' and ~ +AMdowin 411'2" KOP Oa 5550' M1AO • ' • • • ; • Squeezed A31a4-Sa19d p.7lg" slotEOd liner Fner, 4 holesxt. 3/8' hok: size parts 8662' - 88D8' and avr•tasrl.~o R~ Q9070 1A0 DE4921AD6 file:/IC:\Documents and Settings\wortaj\Local Settings\Temporary Internet Files\OLK10... 11/11/2005 Conoco hillips ~ Baker Hughes INTEQ Baker Hughes INTEQ Planning Report [NT~q- Company: ConocoPhillips Alaska, Inc. Date:. 10/31/2005 Time: 15:16:18 Page: t Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 2, True North Sites KRU 1Q Pad` Vertical (TVD) Reference: Datum 2 78.0 Well: 2 Wellpath: `Plan 6, 1Q-026 ~ { Section (VS) Reference: ` Well (O.OON,O.OOE,5.OOAzi) Snrvey Calculation Method: Minimum Curvature - Db: Oraele Field: Kuparuk River Unit North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2004 Site: KRU 1 Q Pad UNITED STATES: North Slope Site Position: Northing: 5985877. 04 ft Latitude: 70 22 20.956 N From: Map Easting: 529617.73 ft Longitude: 149 45 33.406 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.23 deg Well: 2 Slot Name: Well Position: +N/-S -1206.00 ft Northing: 5984666. 52 ft r Latitude: 70 22 9.094 N +E/-W -1175.00 ft Easting : 528447. 63 ft •~ Longitude: 149 46 7.777 W Position Uncertainty: 0.00 ft Wellpath: Plan 6, 1 Q-026 Drilled From: 1 Q-02A Tie-on Depth: 8546.11 ft Current Datum: Datum 2 Height 78. 00 ft Above System Datum: Mean Sea Level Magnetic Data: 9/14/2005 Declination: 24.10 deg Field Strength: 57607 nT Mag Dip Angle: 80.78 deg Vertical Section: Depth From (TVD) +N/-S +E!-W Direction ft ft ft deg 78.00 0.00 0.00 5.00 Plan: Plan #6 Date Composed: 9!14/2005 Copy Lamar's Plan 6 Version: 10 Principal: Yes Tied-to: From: Definitive Path Targets Map Map <---- `Latitude -> <-_ Longitude -> Name Description TVD +N/-S +E/-W Northing Eastiug Deg Min Sec Deg Min Sec ~ Dip. Dir. ft ft $ ft ft ~ 1Q-026 Polygon 78.00 1663.98 4128.13 5986346.00 532569.00 70 22 25.448 N 149 44 6.995 W -Polygon 1 78.00 1663.98 4128.13 5986346.00 532569.00 70 22 25.448 N 149 44 6.995 W -Polygon 2 78.00 1824.09 4365.77 5986507.00 532806.00 70 22 27.021 N 149 44 0.040 W -Polygon 3 78.00 2146.18 4350.99 5986829.00 532790.00 70 22 30.189 N 149 44 0.467 W -Polygon 4 78.00 2949.92 4178.02 5987632.00 532614.00 70 22 38.095 N 149 44 5.515 W -Polygon 5 78.00 3486.05 4423.09 5988169.00 532857.00 70 22 43.366 N 149 43 58.334 W -Polygon 6 78.00 4057.38 4614.28 5988741.00 533046.00 70 22 48.984 N 149 43 52.728 W -Polygon 7 78.00 4447.58 4573.76 5989131.00 533004.00 70 22 52.822 N 149 43 53.907 W -Polygon 8 78.00 4850.62 4573.29 5989534.00 533002.00 70 22 56.786 N 149 43 53.914 W -Polygon 9 78.00 5191.04 4472.57 5989874.00 532900.00 70 23 0.134 N 149 43 56.856 W -Polygon 10 78.00 5046.87 4251.00 5989729.00 532679.00 70 22 58.718 N 149 44 3.344 W -Polygon 11 78.00 4733.58 4317.82 5989416.00 532747.00 70 22 55.636 N 149 44 1.394 W -Polygon 12 78.00 4412.65 4291.59 5989095.00 532722.00 70 22 52.480 N 149 44 2.167 W -Polygon 13 78.00 4010.43 4338.07 5988693.00 532770.00 70 22 48.524 N 149 44 0.813 W -Polygon 14 78.00 3460.17 4125.96 5988142.00 532560.00 70 22 43.113 N 149 44 7.030 W -Polygon 15 78.00 2981.18 3849.11 5987662.00 532285.00 70 22 38.404 N 149 44 15.139 W -Polygon 16 78.00 1858.09 4103.87 5986540.00 532544.00 70 22 27.357 N 149 44 7.702 W -Polygon 17 78.00 1748.27 4052.44 5986430.00 532493.00 70 22 26.277 N 149 44 9.209 W 1Q-026 Target 1 6641.00 1995.00 4131.39 5986677.00 532571.00 70 22 28.704 N 149 44 6.895 W 1 Q-02B Target 2 6641.00 2712.35 4058.11 5987394.00 532495.00 70 22 35.759 N 149 44 9.028 W 1Q-026 Target 3 6703.00 3466.76 4235.99 5988149.00 532670.00 70 22 43.178 N 149 44 3.810 W 1Q-026 Target 4 6703.00 3817.15 4406.34 5988500.00 532839.00 70 22 46.623 N 149 43 58.818 W 1Q-02B Target 5 6741.00 4975.23 4416.74 5989658.00 532845.00 70 22 58.012 N 149 43 58.494 W Conoco/Phitlips ~ Baker Hughes INTEQ i Baker Hughes INTEQ Planning Report ENTEt~ Company: ConocoPhillips Alaska, Inc.: Date: 10!31!2005 Time: 15:16:18 Page: 2 Field: Kuperuk River Unit Co-ordinate(NE) Refereoee: Well: 2, True North "Site: KRU 1Q Pad Vertical ('I'VD)`Reference: Datum 2 78.0 "Well: 2 Section (VS) Reference; Well (O.OON,O.OOE,S.OOAzi) Wellpath: Plan 6, 1Q-02B t-~ Survey Calculation Method: Minimum`Curvature Db: Oracle Targets -- -- Map .....Map ~---' Latitude ---> <--- Longitude --> ; Name: Description TVD +N/-S +E/-W Northing Eastiag Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft Annotation - - MD TVD - '. ft ft '. ~_- - 8546.11 6520.84 TIP 8550.00 6523.34 KOP 8570.00 6535.98 End of 9°(100' DLS 8847.04 6641.20 End of 30°/100' DLS 9222.04 6641.20 5 9722.04 6641.20 6 9872.04 6649.77 7 10097.04 6674.32 8 10322.04 6696.19 9 10492.57 6703.94 10 10617.57 6703.94 11 10892.57 6703.94 12 11042.57 6707.27 13 11292.57 6717.79 14 17542.57 6726.91 15 11792.57 6734.80 16 12050.00 6741.82 TD Plan Section Information MD Inc! Azim TVD +N/-S +E!-W DLS - Build Turn. TFO .. Target I ft deg deg... fC ft ft deg/100ft degN00ft deg/100ft deg 8546.11 50.04 87.68 6520.84 1714.26 4075.25 0.00 0.00 0.00 0.00 8550.00 50.01 87.78 6523.34 1714.38 4078.23 2.12 -0.77 2.57 111.41 8570.00 51.57 86.63 6535.98 1715.14 4093.71 9.00 7.82 -5.74 330.00 8847.04 90.00 5.44 6641.20 1891.47 4242.15 30.00 13.87 -29.31 275.50 9222.04 90.00 320.44 6641.20 2240.82 4134.93 12.00 0.00 -12.00 270.00 9722.04 90.00 20.44 6641.20 2711.65 4055.62 12.00 0.00 12.00 90.00 9872.04 83.50 3.62 6649.77 2857.50 4086.77 12.00 -4.34 -11.21 248.50 10097.04 84.21 30.77 6674.32 3069.16 4152.30 12.00 0.32 12.07 90.00 10322.04 84.84 3.65 6696.19 3261.09 4217.90 12.00 0.28 -12.05 270.00 10492.57 90.00 23.48 6703.94 3445.80 4257.70 12.00 3.02 11.63 76.00 10617.57 90.00 38.48 6703.94 3552.66 4321.86 12.00 0.00 12.00 90.00 10892.57 90.00 5.48 6703.94 3804.17 4423.36 12.00 0.00 -12.00 270.00 11042.57 87.47 347.65 6707.27 3953.24 4414.43 12.00 -1.68 -11.89 261.80 11292.57 87.81 17.68 6717.79 4199.91 4425.91 12.00 0.14 12.01 90.00 11542.57 88.11 347.66 6726.91 4446.63 4437.39 12.00 0.12 -12.01 270.00 11792.57 88.36 17.67 6734.80 4693.39 4448.88 12.00 0.10 12.01 90.00 12050.00 88.59 346.77 6741.82 4947.42 4458.72 12.00 0.09 -12.00 270.00 Survey MD Intl Azim SS TVD N/S EiW MapN MapE DLS VS TFO Tool I ft deg deg ft ff ft ft ft deg/100ft ft deg 8546.11 50.04 87.68 6442.84 1714.26 4075.25 5986396.08 532515.93 0.00 2062.92 0.00 MWD l° 8550.00 50.01 87.78 6445.34 1714.38 4078.23 5986396.21 532518.91 2.12 2063.30 111.41 MWD 8570.00 51.57 86.63 6457.98 1715.14 4093.71 5986397.03 532534.38 9.00 2065.40 330.00 MWD 8575.00 51.73 84.73 6461.08 1715.43 4097.62 5986397.34 532538.29 30.00 2066.04 275.50 MWD 8600.00 52.98 75.38 6476.37 1718.86 4117,07 5986400.84 532557.73 30.00 2071.14 276.68 MWD 8625.00 54.93 66.42 6491.10 1725.48 4136.13 5986407.53 532576.77 30.00 2079.40 282.40 MWD 8650.00 57.51 57.94 6505.02 1735.18 4154.47 5986417.30 532595.07 30.00 2090.66 287.68 MWD 8675.00 60.61 49.98 6517.89 1747.80 4171.78 5986429.98 532612.32 30.00 2104.74 292.40 MWD 8700.00 64.17 42.53 6529.48 1763.11 4187.74 5986445.36 532628.23 30.00 2121.39 296.50 MWD 8725.00 68.08 35.53 6539.61 1780.87 4202.11 5986463.16 532642.52 30.00 2140.33 299.96 MWD 8750.00 72,27 28.91 6548.10 1800.76 4214.62 5986483.10 532654.96 30.00 2161.23 302.80 MWD " ~onoc Phillips ~ Baker Hughes INTEQ i Baker Hughes INTEQ Planning Report tN~rsEq- Company: ConocoPhillips Alaska, Inn. Date: 10/31/2005 Time: 15:1.:6:18 Page: 3 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 2, True North I :Site: KRU 1 Q Pad Vertical (TVD) Reference: 'patum 2 78. 0 Well: 2 - Section (VS) Reference: Well (O.OON, O.ODE,5.OOAzi) Wellpaths Pl an 6, 1Q-02 B ~- ~ Survey Calcniation Method: Minimum Curvature Db: Oracle ~ Survey MD Incl Azim SSTVD N/S -E/W MapN MapE DLS VS TFO Tool I ft deg deg ft tt ft ft ft deg/1DOft ft deg I 8775.00 76.67 22.61 6554.80 1822.44 4225.07 5986504.82 532665.32 30.00 2183.74 305.04 MWD 8800.00 81.22 16.53 6559.59 1845.54 4233.27 5986527.95 532673.43 30.00 2207.47 306.74 MWD 8825.00 85.87 10.60 6562.41 1869.68 4239.08 5986552.10 532679.16 30.00 2232.02 307.90 MWD 8847.04 90.00 5.44 6563.20 1891.47 4242.15 5986573.91 532682.14 30.00 2254.00 308.57 MWD 8850.00 90.00 5.08 6563.20 1894.42 4242.43 5986576.86 532682.40 12.00 2256.96 270.00 MWD 8875.00 90.00 2.08 6563.20 1919.37 4243.99 5986601.81 532683.87 12.00 2281.95 270.00 MWD 8900.00 90.00 359.08 6563.20 1944.36 4244.24 5986626.80 532684.03 12.00 2306.88 270.00 MWD 8925.00 90.00 356.08 6563.20 1969.34 4243.19 5986651.77 532682.88 12.00 2331.66 270.00 MWD 8950.00 90.00 353.08 6563.20 1994.23 4240.83 5986676.65 532680.43 12.00 2356.25 270.00 MWD 8975.00 90.00 350.08 6563.20 2018.95 4237.17 5986701.36 532676.67 12.00 2380.56 270.00 MWD 9000.00 90.00 347.08 6563.20 2043.46 4232.22 5986725.84 532671.63 12.00 2404.54 270.00 MWD 9025.00 90.00 344.08 6563.20 2067.67 4226.00 5986750.02 532665.32 12.00 2428.12 270.00 MWD 9050.00 90.00 341.08 6563.20 2091.52 4218.51 5986773.84 532657.75 12.00 2451.23 270.00 MWD 9075.00 90.00 338.08 6563.20 2114.94 4209.79 5986797.23 532648.94 12.00 2473.80 270.00 MWD 9100.00 90.00 335.08 6563.20 2137.88 4199.86 5986820.13 532638.92 12.00 2495.79 270.00 MWD 9125.00 90.00 332.08 6563.20 2160.27 4188.74 5986842.47 532627.71 12.00 2517.12 270.00 MWD 9150.00 90.00 329.08 6563.20 2182.04 4176.46 5986864.20 532615.35 12.00 2537.74 270.00 MWD 9175.00 90.00 326.08 6563.20 2203.14 4163.06 5986885.25 532601.87 12.00 2557.60 270.00 MWD 9200.00 90.00 323.08 6563.20 2223.52 4148.57 5986905.56 532587.31 12.00 2576.63 270.00 MWD 9222.04 90.00 320.44 6563.20 2240.82 4134.93 5986922.81 532573.61 12.00 2592.68 270.00 MWD 9225.00 90.00 320.79 6563.20 2243.11 4133.05 5986925.10 532571.72 12.00 2594.80 90.00 MWD 9250.00 90.00 323.79 6563.20 2262.89 4117.77 5986944.81 532556.36 12.00 2613.17 90.00 MWD 9275.00 90.00 326.79 6563.20 2283.44 4103.53 5986965.31 532542.05 12.00 2632.40 90.00 MWD 9300.00 90.00 329.79 6563.20 2304.71 4090.40 5986986.52 532528.83 12.00 2652.44 90.00 MWD 9325.00 90.00 332.79 6563.20 2326.63 4078.39 5987008.40 532516.74 12.00 2673.23 90.00 MWD 9350.00 90.00 335.79 6563.20 2349.15 4067.55 5987030.88 532505.82 12.00 2694.72 90.00 MWD 9375.00 90.00 338.79 6563.20 2372.21 4057.90 5987053.90 532496.08 12.00 2716.86 90.00 MWD 9400.00 90.00 341.79 6563.20 2395.75 4049.47 5987077.40 532487.56 12.00 2739.56 90.00 MWO 9425.00 90.00 344.79 6563.20 2419.69 4042.28 5987101.31 532480.29 12.00 2762.79 90.00 MWD 9450.00 90.00 347.79 6563.20 2443.97 4036.36 5987125.57 532474.27 12.00 2786.47 90.00 MWD 9475.00 90.00 350.79 6563.20 2468.54 4031.72 5987150.11 532469.53 12.00 2810.53 90.00 MWD 9500.00 90.00 353.79 6563.2D 2493.31 4028.36 5987174.87 532466.09 12.00 2834.91 90.00 MWD 9525.00 90.00 356.79 6563.20 2518.22 4026.31 5987199.77 532463.94 12.00 2859.55 90.00 MWD 9550.00 90.00 359.79 6563.20 2543.21 4025.57 5987224.75 532463.10 12.00 2884.38 90.00 MWD 9575.00 90.00 2.79 6563.20 2568.20 4026.13 5987249.74 532463.57 12.00 2909.32 90.00 MWD 9600.00 90.00 5.79 6563.20 2593.12 4028.00 5987274.67 532465.35 12.00 2934.32 90.00 MWD 9625.00 90.00 8.79 6563.20 2617.92 4031.18 5987299.48 532468.43 12.00 2959.30 90.00 MWD 9650.00 90.00 11.79 6563.20 2642.51 4035.64 5987324.09 532472.80 12.00 2984.19 90.D0 MWD 9675.00 90.00 14.79 6563.20 2666.84 4041.39 5987348.43 532478.46 12.00 3008.92 90.00 MWD 9700.00 90.00 17.79 6563.20 2690.83 4048.41 5987372.45 532485.38 12.00 3033.44 90.00 MWD 9722.04 90.00 20.44 6563.20 2711.65 4055.62 5987393.29 532492.51 12.00 3054.81 90.00 MWD 9725.00 89.87 20.11 6563.21 2714.43 4056.65 5987396.08 532493.53 12.00 3057.66 248.50 MWD 9750.00 88.77 17.32 6563.50 2738.11 4064.67 5987419.78 532501.46 12.00 3081.95 248.50 MWD 9775.00 87.67 14.52 6564.28 2762.13 4071.52 5987443.83 532508.22 12.00 3106.48 248.53 MWD 9800.00 86.58 11.72 6565.53 2786.45 4077.19 5987468.16 532513.79 12.00 3131.20 248.62 MWD 9825.00 85.50 8.92 6567.25 287 0.98 4081.66 5987492.71 532518.17 12.00 3156.03 248.76 M W D 9850.00 84.43 6.11 6569.45 2835.67 4084.91 5987517.41 532521.33 12.00 3180.90 248.95 MWD 9872.04 83.50 3.62 6571.77 2857.50 4086.77 5987539.25 532523.11 12.00 3202.82 249.20 MWD 9875.00 63.50 3.98 6572.10 2860.44 4086.96 5987542.18 532523.29 12.00 3205.76 90.00 MWD 9900.00 83.51 6.99 6574.93 2885.16 4089.34 5987566.91 532525.57 12.00 3230.59 89.96 MWD 9925.00 83.54 10.01 6577.75 2909.73 4093.01 5987591.49 532529.15 12.00 3255.39 89.62 MWD 9950.00 83.58 13.03 6580.56 2934.07 4097.97 5987615.84 532534.02 12.00 3280.06 89.28 MWD 9975.00 83.65 16.05 6583.34 2958.11 4104.21 5987639.91 532540.16 12.00 3304.56 88.94 MWD ConocoPhiltips ,Baker Hughes INTEQ Baker Hughes INTEQ Planning Report ><cvT~C~ Company: ConocoPhillips Alaska, Inc. Date: 10131/2005 7hme: 15:16:18 ' Page: 4 ~ Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 2, Ttue North Site: KRU 1Q Pad Vertical (TVD) Reference: Datum 2 78. 0 Well: 2 Wellpatha Plan 6, 1Q-02B L 1 Section (VS) Reference: Well (O.OON,O.OOE,5.OOAzi) Snrvey Calculation Method: Minimum Curvature Db Oracle Survey MD Intl Azim SS TVD N/S E/W MapN MapE DLS VS `' TFO Tool i ft deg deg ft ft. ft ft ft deg/100ft, 'ft deg 10000.00 83.73 19.07 6586.09 2981.80 4111.71 5987663.63 532547.57 12.00 3328.81 88.60 MWD 10025.00 83.83 22.08 6588.80 3005.07 4120.44 5987686.92 532556.21 12.00 3352.75 88.27 MWD 10050.00 83.95 25.10 6591.46 3027.84 4130.39 5987709.73 532566.07 12.00 3376.31 87.94 MWD 10075.00 84.08 28.11 6594.07 3050.07 4141.52 5987732.00 532577.12 12.00 3399.42 87.62 MWD 10097.04 84.21 30.77 6596.32 3069.16 4152.30 5987751.13 532587.82 12.00 3419.38 87.31 MWD 10100.00 84.21 30.41 6596.62 3071.70 4153.80 5987753.67 532589.31 12.00 3422.04 270.00 MWD 10125.00 84.22 27.39 6599.14 3093.47 4165.82 5987775.49 532601.25 12.00 3444.77 270.04 M W D 10150.00 84.24 24.38 6601,65 3115.85 4176.67 5987797.90 532612.02 12.00 3468.01 270.34 MWD 10175.00 84.29 21.36 6604.15 3138.76 4186.34 5987820.85 532621.60 12.00 3491.68 270.64 MWD 10200.00 84.34 18.35 6606.63 3162.16 4194.79 5987844.28 532629.96 12.00 3515.72 270.94 MWD 10225.00 84.42 15.34 6609.07 3185.97 4202.00 5987868.11 532637.07 12.00 3540.07 271.24 M W D 10250.00 84.50 12.32 6611.49 3210.13 4207.95 5987892.29 532642.93 12.00 3564.66 271.54 MWD 10275.00 84.61 9.31 6613.86 3234.57 4212.62 5987916.75 532647.51 12.00 3589.41 271.83 MWD 10300.00 84.73 6.30 6616.19 3259.23 4216.00 5987941.42 532650.79 12.00 3614.27 272.12 M W D 10322.04 84.84 3.65 6618.19 3281.09 4217.90 5987963.28 532652.61 12.00 3636.22 272.40 MWD 10325.00 84.93 3.99 6618.45 3284.03 4218.10 5987966.23 532652.80 12.00 3639.17 76.00 MWD 10350.00 85.66 6.91 6620.51 3308.83 4220.47 5987991.03 532655.07 12.00 3664.08 75.97 MWD 10375.00 86.41 9.83 6622.24 3333.50 4224.10 5988015.72 532658.61 12.00 3688.97 75.73 MWD 10400.00 87.16 12.74 6623.64 3357.98 4228.98 5988040.21 532663.40 12.00 3713.78 75.53 MWD 10425.00 87.92 15.64 6624.71 3382.19 4235.10 5988064.44 532669.43 12.00 3738.43 75.36 MWD 10450.00 88.69 18.54 6625.45 3406.07 4242.44 5988088.35 532676.68 12.00 3762.87 75.24 MWD 10475.00 89.46 21.44 6625.86 3429.56 4250.99 5988111.87 532685.13 12.00 3787.01 75.15 MWD 10492.57 90.00 23.48 6625.94 3445.80 4257.70 5988128.13 532691.78 12.00 3803.77 75.11 MWD 10500.00 90.00 24.37 6625.94 3452.59 4260.71 5988134.93 532694.77 12.00 3810.80 90.00 MWD 10525.00 90.00 27.37 6625.94 3475.08 4271.62 5988157.46 532705.59 12.00 3834.15 90.00 MWD 10550.00 90.00 30.37 6625.94 3496.97 4283.69 5988179.40 532717.57 12.00 3857.01 90.00 MWD 10575.00 90.00 33.37 6625.94 3518.20 4296.89 5988200.67 532730.69 12.00 3879.31 90.00 MWD 10600.00 90.00 36.37 6625.94 3538.71 4311.18 5988221.23 532744.90 12.00 3900.99 90.00 MWD 10617.57 90.00 38.48 6625.94 3552.66 4321.86 5988235.22 532755.53 12.00 3915.82 90.00 MWD 10625.00 90.00 37.59 6625.94 3558.51 4326.43 5988241.09 532760.08 12.00 3922.05 270.00 MWD 10650.00 90.00 34.59 6625.94 3578.71 4341.16 5988261.35 532774.73 12.00 3943.45 270.00 MWD 10675.00 90.00 31.59 6625.94 3599.66 4354.80 5988282.34 532788.29 12.00 3965.51 270.00 MWD 10700.00 90.00 28.59 6625.94 3621.29 4367.34 5988304.02 532800.74 12.00 3988.14 270.00 MWD 10725.00 90.00 25.59 6625.94 3643.54 4378.72 5988326.31 532812.04 12.00 4011.31 270.00 MWD 10750.00 90.00 22.59 6625.94 3666.36 4388.92 5988349.17 532822.15 12.00 4034.93 270.00 MWD 10775.00 90.00 19.59 6625.94 3689.69 4397.91 5988372.52 532831.05 12.00 4058.95 270.00 MWD 10800.00 90.00 16.59 6625.94 3713.45 4405.67 5988396.31 532838.72 12.00 4083.30 270.00 MWD 10825.00 90.00 13.59 6625.94 3737.58 4412.18 5988420.47 532845.14 12.00 4107.91 270.00 MWD 10850.00 90.00 10.59 6625.94 3762.03 4417.42 5988444.93 532850.28 12.00 4132.71 270.00 MWD 10875.00 90.00 7.59 6625.94 3786.71 4421.36 5988469.63 532854.13 12.00 4157.65 270.00 MWD 10892.57 90.00 5.48 6625.94 3804.17 4423.36 5988487.09 532856.07 12.00 4175.21 270.00 MWD 10900.00 89.87 4.60 6625.95 3811.57 4424.02 5988494.49 532856.69 12.00 4182.64 261.80 MWD 10925.00 89.45 1.63 6626.10 3836.53 4425.37 5988519.45 532857.95 12.00 4207.62 261.80 MWD 10950.00 89.02 358.66 6626.43 3861.52 4425.43 5988544.44 532857.92 12.00 4232.53 261.82 MWD 10975.00 88.60 355.69 6626.95 3886.48 4424.20 5988569.40 532856.59 12.00 4257.29 261.86 MWD 11000.00 88.18 352.71 6627.66 3911.34 4421.68 5988594.24 532853.97 12.00 4281.83 261.92 MWD 11025.00 87.76 349.74 6628.54 3936.03 4417.87 5988618.92 532850.07 12.00 4306.09 262.00 MWD 11042.57 87.47 347.65 6629.27 3953.24 4414.43 5988636.12 532846.56 12.00 4322.94 262.11 MWD 11050.00 87.47 348.54 6629.60 3960.51 4412.90 5988643.37 532845.00 12.00 4330.04 90.00 MWD 11075.00 87.48 351.55 6630.70 3985.10 4408.58 5988667.95 532840.59 12.00 4354.17 89.96 MWD 11100.00 87.49 354.55 6831.80 4009.89 4405.56 5988692.73 532837.48 12.00 4378.60 89.83 MWD 11125.00 87.51 357.55 6632.89 4034.81 4403.84 5988717.63 532835.66 12.00 4403.27 89.70 MWD Conato~illips ~ Baker Hughes INTEQ Baker Hughes INTEQ Planning Report INTSfrQ Company:. ConocoPhillips Alaska, Inc.., Date: 10/31/2005 Time: 15:16118 - _ __ Page: _` -- 5 Field: Kuparuk River Unit Co-ordinate{NE) Reference: Well: 2, True North ~ Site: KRU 1 Q Pad Vertieal(TVB) Reference: Datum 2 78. 0 .Well: 2 Wellpath; Plan 6, 1Q-026 ~ ~ Section (VS) Reference;" Well (O.OON,O.OOE,5.OOAzi) Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim SS TVD N/S ' E/W MapN ' MapE DLS VS TFO Tool ft deg deg ft , ft` -ft ft ft deg/100ft ft deg 11150.00 87.54 0.55 6633.97 4059.78 4403.42 5988742.60 532835.16 12.00 4428.11 89.57 M W D 11175.00 87.57 3.56 6635.03 4084.74 4404.32 5988767.56 532835.96 12.00 4453.05 89.44 MWD 11200.00 87.61 6.56 6636.09 4109.61 4406.52 5988792.44 532838.06 12.00 4478.03 89.31 MWD 11225.00 87.66 9.56 6637.12 4134.34 4410.02 5988817.18 532841.47 12.00 4502.97 89.18 MWD 11250.00 87.71 12.56 6638.13 4158.85 4414.82 5988841.71 532846.17 12.00 4527.81 89.06 MWD 11275.00 87.77 15.57 6639.12 4183.08 4420.89 5988865.96 532852.15 12.00 4552.47 88.94 MWD 11292.57 87.81 17.68 6639.79 4199.91 4425.91 5988882.80 532857.11 12.00 4569.67 88.82 MWD 11300.00 87.81 16.78 6640.08 4207.00 4428.11 5988889.89 532859.28 12.00 4576.92 270.00 MWD 11325.00 87.82 13.78 6641.03 4231.09 4434.69 5988914.01 532865.77 12.00 4601.50 270.03 MWD 11350.00 87.83 10.78 6641.98 4255.50 4440.00 5988938.44 532870.99 12.00 4626.28 270.15 MWD 11375.00 87.85 7.78 6642.93 4280.15 4444.03 5988963.10 532874.92 12.00 4651.19 270.26 MWD 11400.00 87.87 4.77 6643.86 4304.98 4446.76 5988987.94 532877.56 12.00 4676.16 270.38 MWD 11425.00 87.90 1.77 6644.78 4329.92 4448.19 5989012.88 532878.89 12.00 4701.13 270.49 MWD 11450.00 87.93 358.77 6645.70 4354.90 4448.31 5989037.86 532878.91 12.00 4726.03 270.60 MWD 11475.00 87.97 355.77 6646.59 4379.86 4447.12 5989062.81 532877.63 12.00 4750.78 270.71 MWD 11500.00 88.02 352.77 6647.47 4404.71 4444.62 5989087.65 532875.04 12.00 4775.33 270.82 M W D 11525.00 88.07 349.77 6648.32 4429.41 4440.83 5989112.33 532871.15 12.00 4799.59 270.92 MWD 11542.57 88.11 347.66 6648.91 4446.63 4437.39 5989129.53 532867.65 12.00 4816.45 271.02 MWD 11550.00 88.11 348.55 6649.15 4453.89 4435.86 5989136.79 532866.09 12.00 4823.55 90.00 MWD 11575.00 88.11 351.55 6649.98 4478.50 4431.54 5989161.38 532861.68 12.00 4847.69 89.97 M W D 11600.00 88.12 354.55 6650.80 4503.30 4428.52 5989186.17 532858.57 12.00 4872.13 89.87 MWD 11625.00 88.13 357.55 6651.62 4528.22 4426.80 5989211.08 532856.75 12.00 4896.81 89.77 MWD 11650.00 88.15 0.56 6652.43 4553.20 4426.39 5989236.06 532856.25 12.00 4921.66 89.67 MWD 11675.00 88.18 3.56 6653.23 4578.17 4427.29 5989261.03 532857.05 12.00 4946.61 89.58 MWD 11700.00 88.21 6.56 6654.02 4603.06 4429.49 5989285.92 532859.16 12.00 4971.60 89.48 M W D 11725.00 88.24 9.56 6654.79 4627.80 4432.99 5989310.67 532862.56 12.00 4996.55 89.39 MWD 11750.00 88.28 12.56 6655.55 4652.32 4437.79 5989335.21 532867.26 12.00 5021.39 89.29 MWD 11775.00 88.33 15.56 6656.29 4676.56 4443.86 5989359.46 532873.24 12.00 5046.07 89.20 MWD 11792.57 88.36 17.67 6656.80 4693.39 4448.88 5989376.31 532878.20 12.00 5063.27 89.11 MWD 11800.00 88.36 16.78 6657.01 4700.48 4451.08 5989383.41 532880.37 12.00 5070.53 270.00 MWD 11825.00 88.36 13.78 6657.73 4724.58 4457.66 5989407.54 532886.86 12.00 5095.12 270.03 MWD 11850.00 88.37 10.78 6658.44 4749.00 4462.97 5989431.97 532892.08 12.00 5119.90 270.11 MWD 11875.00 88.38 7.78 6659.15 4773.66 4467.00 5989456.64 532896.02 12.00 5144.82 270.20 MWD 11900.00 88.40 4.77 6659.85 4798.50 4469.73 5989481.49 532898.65 12.00. 5169.80 270.28 MWD 11925.00 88.42 1.77 6660.54 4823.44 4471.16 5989506.44 532899.98 12.00 5194.78 270.37 MWD 11950.00 88.45 358.77 6661.22 4848.43 4471.28 5989531.42 532900.01 12.00 5219.68 270.45 MWD 11975.00 88.48 355.77 6661.89 4873.39 4470.09 5989556.38 532898.72 12.00 5244.44 270.53 M W D 12000.00 88.51 352.77 6662.55 4898.25 4467.60 5989581.23 532896.14 12.00 5268.99 270.61 MWD 12025.00 88.55 349.77 6663.19 4922.95 4463.80 5989605.91 532892.25 12.00 5293.27 270.69 MWD 12050.00 88.59 346.77 6663.82 ~ 4947.42 4458.72 5989630.36 532887.08 12.00 5317.20 270.77 MWD LEGEND T Plan: Plan A•6 (2/Plan 6, 10-028) Bf A~O^O --- 21a-02) Azimuths to True North /y y BAK R~~ - z 1°-0~ M Magnetic North: 24.10° Crealad By: all Miaraelson Date: ,a3,noos 2~1o-0zA~B,> -- Plan 6, 1D-0ze Magnetic Field , .,n;aa lntorma~ion wcu.AiM O[rAU HUGHES - ~~ - Plan p6 ~t..aloox~61 Strength: 57607nT Ern Michaelson Dip Angle: 80.78° Direct. (907) 267-662a •....1 w.eawer 1osxA ~~'~1~L~ Date: 9/14/2005 Cell (907)301-73570 TM as MD+ aaN.11 Model: bggm2004 E-maiP. bill.michaelsonah,!eq com nyr n-.ek: ^r. ow-n.r o.m. x noon v.a«aoa o la to Mare A.pM r -rv net. °t~ro 5000 i .. ~ . . a.ao• o.oo o.oo raoo - - 10-028 Te t 5 TD ~ ~, ~ I I ' ' ~'~ REFERENCE INFORMATION 4800 ~ I t~l ~ ~ ~ ~ t } I r t f '~ ~ • ~ ~ i I l t I t I I ,~ 'j . Coordinate (N/E) Reference' Well Centre: 2, True North j I ~ , ~ I ~ . • I 16 ~ I ' I l ~ I I Vertical (TVD) Reference. Syysstem Mean Sea Level l ~ 1 I I 1 ~ ` , , Sedan (VS) Reference. Sbl - (O.OON,O.OOE) 4600 ~, t - -F ! '+'- + + '; - +~ - 1- -~ ~- - + • • - ~ + - Measured Depth Reference: Datum 2 76.00 I i l . ~ ( ~ ' ~ ~ : I ~ I ' Calculatron Method. Mn'mum Curvature 4400 - ` 1-j-~ ~ ~ + -++l ~ , I i 15 ~ ~ I ~ I l - i ' I ~.I { ' ' .« o x- .n m ..,a .uar ...x w r-x., i t f l i ~ ~ I I I -: + ~ i f _... ~~ I I t * '- i 7 , ~ - ~ I.. j I I I' tt ~ t ~ .~ 4200 ~ '. I ;-~ a ~ i 1` + ~ '~!- + .-+ -+-~--~-_ ~ + X4000 ~ ~ l ~ ] t. ,.I ~ + •I +~ I + i, ,ar w.a. ~~ xae ...,.. ~ I I .1 ~ i ~ ,3 ~ { t I I 10-028 T 14 1 I I { t 3600 + t 1 +.~_-;.~ 1z I I+ i li ~ ; t r. -_ M -~ ..a N 3600 I ~ I ~ ' + ~ 1 ; T , , , I , , ~ , ' .° .,.,,r.aM _ I I _ It I r. I. i~ ,cot ~ ~ _ t I ~ ~ ~ I .....,..~„ ,,. oa>ar.,~a ~- 3400 I' ~ ~ l _._..--~_ l wm w~ warnorw ,o~~ :'q°~.,s e'°eea-oo ars:aa «,e:r• vie.-n v -. ' I I-I f '~ ~O-028 Tm t3 9 70 i I i -++j ~ I F I t _ ;, rarnorw + I : l- ~-~-. +: :nn:n~ r I ~ l ,~ 1~ ~ f _~ ~:f :.i:u io°0°iu'aa. w ~+ 3200 ~ ~.: ~.: ~ { -. i ;-{ .. ~ ~- + - + r r •_:.~ ~ -t t t r l~ : I 6 I I 1 ..~a...,a.x„ ,x t 4 Z 3000 I ~ I I ~ I:' - ~ ! L +i i i t ~,~ 2600 7 1ao2Br tz , f ' I F ~ 1' ' ssoo Mo zsoo ~ r"f- - z ,0-02 --~. _ ~._.,~ + .~, + Ir ~~ 5700 -~ +: 2400 t ~ .I ~_• ;:.~10~ +~:~~ ~ i1:' _L:' _ ; } I 2200 I , ~ s I , 1.~i ~..~. ~ ~ II + I 5800 - -f - : . ~ ' . t+1 t 1 . ^5900 2000 I t [o-0-2e r_ t 1 i i{ 4 I`~ _. C ' z 10-02APB1 End-of 30°/100 DL ( ~ ( l I I .: 6000 -,_ 1800 ~ ', ~ ~ . ~' l -+ _~ + ~ j +;. 0 6100 1600 ~ TIP KOP End o/ 9°/100 Dl - r = 6200 ` 20002200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 4800 5000 5200 5400 5600 5800 6000 6200 6400 6600 6800 7000 7200 d s3oo West(-)/East(+) [200ft/in] IOQ z io-0uwB, 41~ 6400 nP KOP ~t+ 6500 Era or 9°nar DL ,o-0zB tar a 1o-02B T t z : 10-028 T l3 10-028 T I4 5 8 6600 is~aorsti°iiarDL 7 B 9 1e 1a ie rD] ' 11 12 13 15 - 6700 io-ozB rar~et~ F 2j10-02~ ' 6800 z ,ao2 ~l I j; i T ,. I ~ I I I I ~ I II,I l i i I 6900 + r l r ' + l : ; ~.~ + I ~ I I ' .. I I I I i I I I ~ I I ,i ~ Il + t i i i ,. +, ,_~ I I+~~I, I ~ : I it .. i i+~ ... 7000 ~- ~ ~~ ~ i ,~ i I.,I,~, ii i ~ li .~~ t {! I -i~; + ,I I i it ~'i~ L.~ ~_ I 1.~ II IL~ l,i l II ,~ ', . ,. 7100 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 5000 5100 5200 5300 5400 5500 5600 Vertical Section at 5.00° (100ft/in] • Operator: Conoco Phillips Alaska, Ine. Grid Correction: 0.23 Job No: Field: Kuparuk Magnetic Declination: 24.10 AFE No: Well: 1Q-02B Dip: 80.78 API No: Rig: Nordic 2 Dogleg per: 100 ft MWD Com Surface Location Original VS Plane: 5.011 Parent Wel X: 528447.63 ft View VS Plane: 5.00 RKB Heigh Y: 598466652 ft Start Date: 1008/05 TD Date: Meas. Incl. TRUE Subsea Coords. -T rue North Coords. -ASP or Grid Dogleg Original View Toal Build DepW (ft) Angle (de) Azi. (deb) TVD (ft) N(+)/S(-) (ft) E(+)/W(-) (ft) N(+)/S(-) Lat. (Y) E(+)/W(-) De . (X) Severity (°1100 ft) VS (5°) (ft) VS (5°) (ft) Face (deg) (°1100 ft) 8418.17 49.87 $9.98 6360.52 1712.26 3977.34 5986394.74 532418.06 1.t2 2052.40 2052.40 135 -0.78 8539.00 50.03 87.81 6438.27 1714.05 4069.81 5986396.89 532510.52 1.38 2062.23 2062.24 -85 0.13 8560.53 50.70 87.30 6452.00 1714.76 4086.37 5486397.67 532527.08 3.61 2064.38 2064.39 -31 3.11 8589.96 53.01 77.30 6470.21 1717.88 4109.25 5986400.88 532549.95 27.83 2069.49 2069.49 -77 7.85 8620.69 56.88 67.30 6487.89 1725.56 4133.14 5986408.66 532573.81 29.44 2079?2 2079.23 fib 12.59 8650.19 59.31 58.30 6503.50 1737.01 4155.37 5986420.20 532595.99 27.17 2092.57 2092.57 -75 8.24 8678.41 62.59 50.29 6517.46 ]751.67 4175.71 5986434.94 532616.28 26.91 2108.94 2108.95 -07 11.42 8710.67 66.28 41.67 6531.18 1771.57 4196.26 5986454.92 532636.75 27.04 21.30.56 2130.56 -67 11.62 8740.83 69.73 31.31 6542.50 1794.03 4212.84 5986477.45 532653.23 33.83 2154.38 2154.38 -72 11.44 8772.70 77.15 30.30 6551.58 1820.25 4228.46 5986503.73 532668.75 23.48 2181.86 2181.87 -8 23.28 8801.76 84.39 27.45 6556.24 1845.36 4242.30 .5986528.89 532682.44 26.73 2208.07 2208.08 -21 24.91 8830.11 90.20 23.97 6557.58 1870.86 4254.58 5986554.44 532694.66 23.88 2234.55 2234.55 -31 20.49 8858.80 91.73 16.43 6557.10 L897,76 4264.47 5986581.38 532704.45 26.81 2262.2] 2262.21 -78 5.33 8890.35 88.60 15.50 6557.00 1928.09 4273.15 5986611.74 532713.01 10.35 2293.18 2293.18 -163 -9.92 8921.11 88.88 11.68 6557.68 1957.97 4280.37 5986641.66 532720.11 12.45 2323.58 2323.59 -86 0.91 8950.70 88.51 9.17 6.558.36 1987.06 4285.73 5986670.77 532725.35 8.57 2353.03 2353.03 -98 -1.25 8981.47 87.92 4.57 6559.31 201.7.59 4289.41 5986701.31 532728.90 15.06 2383.76 2383.76 -97 -1.92 9016.14 86.78 2.57 6560.92 20.52.15 4291.56 5986735.88 532730.92 6.63 24]8.38 2418.38 -120 -3.29 9046.43 87.59 358.02 6562.41 2082.40 429].72 5986766.13 532730.9,5 15.24 2448.52 2448.53 -80 2.67 9075.31 85.21 356.61 6564.22 2111.19 4290.37 5986794.91 532729.49 9.57 2477.08 2477.09 -149 -8.24 9106.68 87.62 354.71 6566.18 2142.40 4288.00 5986826.12 532726.99 9.78 2507.97 2507.98 -38 7.68 9136.55 88.71 351.50 6567.14 2172.04 4284.41 5986855.74 532723.29 11.34 2537.18 2537.19 -71 3.65 9166.75 87.10 349.38 6568.24 2201.79 4279.40 5986885.48 532718.16 8.81 2566.39 2566.39 -127 -5.33 9195.13 85.03 347.51 6570.19 2229.53 4273.73 5986913.19 .532712.38 9.82 2593.53 2593.53 -138 -7.29 9226.49 83.28 344.30 6573.38 2259.78 4266.14 5986943.41 532704.66 11.63 2623.00 2623.01 -1 t9 -5.58 9255.68 82.94 340.75 6576.89 2287.42 4257.44 5986971.01 532695.85 12.]3 2649.78 2649.78 -96 -1.16 9286.31 84.88 337.36 6580.14 2315.86 4246.55 5986999.41 532684.85 12.70 2677.16 2677.16 -60 6.33 9315.28 85.93 335.62 6582.46 2342.34 4235.03 5987025.84 532673.22 7.00 2702.53 2702.54 -59 3.62 9345.11 86.48 332.12 6584.43 2369.06 4221.92 5987052.51 53266(1.01 11.85 2728.01 2728.0] -81 1.84 9375.67 85.10 329.91 6586.68 2395.71 4207.16 5987079.10 532645.14 8.51 2753.28 27.53.28 -122 -4.52 9404.99 85.43 325.75 6588.97 2420.45 4191.60 5987]03.78 532629.48 14.43 2776.56 2776.57 -79 2.83 9436.86 86.85 321.84 6590.98 2446.11 4172.81 5987129.36 532610.59 12.58 28(10.49 2800.49 -77 2.89 9466.44 86.39 32].87 6592.72 2469.33 4154.57 5987152.51 532592.26 1.56 2822.03 2822.04 176 -1.56 9499.46 86.94 326.74 6594.64 2496.]0 4]35.35 5987179.20 532572.92 14.82 2847.02 2847.02 84 1.67 9530.65 85.84 328.56 6596.61 2522.39 4118.69 5987205.42 532556.16 6.81 2871.76 2871.76 12 t -3.53 9560.40 84.49 331.65 6599.12 2548.09 4103.92 5987231.06 53254].29 11.30 2896.07 2896,08 li4 -4.54 9589.64 80.48 333.37 6602.94 2573.80 4090.54 5987256.72 532527.80 14.90 2920.52 2920.52 1-57 -13.71 9627.01 82.63 338.66 6608.43 2607.56 4075.52 5987290.42 532512.65 15.14 2952.84 2952.84 68 .5.75 9663.12 82.23 340.37 6613.19 2641.09 40(13.00 5987323.89 532499.99 4.82 2985.15 2985.15 103 -1.11 97(10.10 85.63 343.97 6617.10 2676.08 4051.74 5987358.85 532488.60 13.35 3019.03 3019.04 47 9.f9 9730.65 87.71 345.27 6618.87 2705.49 4043.66 5987388.22 532480.39 8.03 3Ck17.62 3047.b2 32 6.81 9760.07 91.67 347.28 6619.03 2734.06 4036.68 ,5987416.76 53247330 15.09 3075.48 3075.48 27 13.46 9790.41 94.02 350.45 6617.53 2763.79 4030.83 5957446.46 532467.33 13.00 3104.58 3104.58 53 7.75 9821.97 94.87 351,29 6615.08 2794.85 4025.83 5987477.51 532462.21 3.78 3135.09 3135.09 45 2.69 9850.23 93.09 35533 6613.12 2822.,34 4022.55 5987505.49 532458.82 15.59 3162.69 3162.70 114 -6.30 9880.58 92.63 356.16 661 L60 2853.07 4020.30 5987.53.5.71 532456.45 3.12 3192.61 3192.61 119 -1.52 9913.50 93.30 359.16 6609.40 2885')2 4018.96 5987568.55 532454.97 933 3225.2] 3225.22 77 2.04 9946.00 94.35 2.24 6607.73 2918.34 4019.36 _59876(10.97 532455.24 9.99 3257.54 3257.55 71 3.23 9976.94 95.09 5.42 6605.19 2949.1.0 4021.41 598763 L74 532457.17 10.52 3288.37 3288.37 77 2.39 9995.00 94.93 6.77 6603.61 2966 ~~4 4023.32 5987649.64 532459.01 7.50 3306.35 3306.36 97 -0.89 10005.00 92.70 6.77 6602.94 2976.90 4024.50 5987659.55 532460.15 22.30 3316.33 3316.33 180 -22.30 10010.00 91.6!1 6.77 6602.76 298L86 4025.09 5987664.51 532460.72 22.(10 3321..32 3321.33 180 -22.00 10025.00 88.00 6.77 6602.81 2996.75 4026.86 5987679.41. 532462.43 24.(10 3336.31 3336.32 180 -24.00 10050.00 87.00 9.00 6603.90 3021.49 4430.28 5987704.16 53246,5.75 9.77 3361.25 3361.2b 114 -4.00 87.Q0 13.00 6606.52 3070.49 4039.81 5987753.21 532475.08 7.99 3410.40 3410.91 90 0.00 10150.00 89.00 16.00 6608.26 3118.86 405232 5987801.62 532487.40 7.21 3460.18 3460.18 56 4.00 10200.00 89.00 20.00 6609.13 3166.40 4067.76 5987849.22 532502.65 8.00 3508.88 3508.88 90 0.00 10250.00 89.0(1 24.00 6610.01 3212.74 4086.49 5987895.64 532521.19 8.00 3556.68 3556.68 90 0.00 10300.00 89.00 28.00 6610.88 3257.67 4108.40 5987940.65 532542.92 8.(10 3603.34 3603.34 90 0.00 10350.00 89.00 32.00 6611.75 3300.95 4133.39 5987984.04 532567.74 8.00 3648.64 3648.64 90 0.00 10400.00 89.00 36.00 6612.63 3342.39 4161.34 5988025.54 532.595.52 8.00 3692.35 3692.36 90 0.00 10450.00 89.00 40.00 6613.50 338 L77 4192.11 5988065,10 532626.13 8.00 3734.27 3734.28 90 0.00 10500.00 89.011 44.Q0 6614.37 3418.92 4225.56 5988102,37 532659.43 8.00 3774.19 3774.19 90 0.00 10550.00 89.00 48.00 6615.25 3453.64 4261.51 5988137.24 532695.24 8.00 3811.91 3811.92 90 0,(10 Current Survey Page 1 of 4 (1Q-02BPIan9 Surveys.xls) 11/14/2005 11:12 AM Meas. Incl. TRUE Subsea Coords. -True North Coords. -ASP or Grid Dogleg Original View Tool Build „ Depth (ft) Angle (de) Azi. (de) TVD (ft) N(+)/S(-) (ft) E(+)/W(-) (ft) N(+)/S(-) Lat. (Y} E(+)/W(-) Dep. (X) Severity (°1]00 ft) VS (5°) (fl) VS (5°) (ft) Face (de (°/100 ft) 10600.00 89.00 44.0(1 6b16.12 3488.36 4297.46 59$8172.10 532731.06 S.W 3849.63 3849.64 -90 4.00 10650.00 89.00 40.00 6616.99 3525.50 4330.91 5988209.38 532764.35 8.00 3889.55 3889.56 -90 0.00 10700.00 89.00 36.00 6617.86 3564.89 436L68 5988248.89 532794.97 8.00 3931.47 3931.47 -90 0.00 10750.00 89.00 32.00 6618.74 3606.33 4389.63 5988290.44 532822.75 8.00 3975. ] 9 3975.19 -90 0.00 10800.011 $9.00 28.00 6619.61 3649.61 4414.62 5988333.83 532847.57 8.00 4020.49 4020.49 -90 0.00 10850.00 89.00 24.00 6620.48 3694.54 4436.53 5988378.84 532869.30 8.0(1 4067.15 4067.15 -90 0.00 10900.00 89.00 20.00 6621.36 3740.88 4455.26 5988425.25 532887.83 8.00 4114.95 4114.95 -90 0.00 10950.00 89.00 16.00 6622.23 3788.42 4470.70 5988472.85 532903.09 8.00 4163.65 4163.65 -90 0.00 11000.00 89.110 12.00 6623.10 3836.91 4482.79 5988521.40 532914.99 8.00 4213.01 4213.02 -90 O.fl0 11050.00 89.00 12.0(1 6623.97 3885.81 4493.19 5988570.34 532925.18 0.02 4262.63 4262.64 90 0.00 11100.00 89.00 8.00 6624.85 3935,04 4501.87 5988619.60 532933.b6 8.00 4312.43 4312.43 -90 0.00 11150.00 89.00 4.00 6625.72 3984.74 4507.09 5988669.33 532938.69 8.00 4362.40 4362.40 -90 0.00 11200.00 89.00 0.00 6626.59 4034,70 4508.84 5988719.28 532940.23 8.00 4412.31 4412.32 -90 O.UO 11250.00 89.00 356.011 6627.47 4-084.65 4507.09 5988769.23 532938.29 8.00 4461.92 4461.93 -90 0.00 11300.00 89.00 352.00 6628.34 4134.36 4.501.87 598881.8.92 532932.86 8.00 4510.99 4510.99 -90 0.00 #N/A #N/A #N!A #N/A #N/A #N/A #N/A #N!A #N/A #N/A #N/A #N/A #N/A #N/A #N/A #N/A #N/A #N/A #N/A #N/A #N/A #N/A #N/A #N!A #N/A #N/A #NA #N/A #N/A #N/A ;- Current Survey Page 2 of 4 (1~-02BPIan9 Surveys.xis) 11/14/2005 11:12 AM ., Kuparuk OOBCTD BOP configuration 2-3f8" Coil Well 1Q-0213 ~ ~~ Floor I Lubricator ID = 6.375" with 6" Oli; - 71!16" 5000 psi BtJP's. ID = 7.06" KB Elevation _~ HCR ~. HCR Choke Line Kill Line 1 ~~ 2 1/16' 5000 psi . Rx-24 ~~ " 7 1/16 5000 psi (RX-46) or ~ - 4 1116" 5000 psi (RX-39) -- ~~ Swab Valve Tree Size ~~ 71!16" 5000 psi. RX~t6 D ((~~ 1/4 Tum LT Valve L~~ 3" 5000 psi {~ 7 1/16" 5000 si RX-46 ~_ ssv H~ r Master Valve ~~ r Base Flan e Page 1 • PERMIT T~ DRILIL 20 AAC 25.005 • (e) If a well has multiple well branches, each branch requires a separate Permit to Drill. 1f multiple well branches are proposed from a single conductor, surface, or production casing, the applicant shall designate one branch as the primary wellbore and include all information required under (c) of this section with the application for a Permit to Drill for that branch. For each subsequent well branch, the application for a Permit to Drill need only include information under (c) of th'ss section that is unique to that branch and need not include the $100 fee. • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER ~ ,~ WELL NAME ~~`~' ~`~~~'~~- ~- PTD# ~~ ~ '^l ~~' CHECK WHAT I ADD-ONS ti "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of ~ I LATERAL existing well t~~~, tr~~'~~~ Permit No,~~~ ~~4~~API No. S~ `~ ~~`~ Z~ ~ ~ (If API number Production should continue to be reported as , ~ last two (2) digits I a function of .the original API number stated ~ are between 60-69) 4 above. ~ i ,PILOT HOLE In accordance with 20 AAC 25.005(f), all (p)er i, records, data and togs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) ' and API number (SO 'i ~ ~ 70/80) from records, data and logs acquired ~ ~ I for well (name on permit). I ~ i ,SPACING 'The permit is approved subject to full ~ ~ .EXCEPTION ~ compliance with 20 AAC 25.055. Approval to ~ ~ perforate and roduce/in'ect is contingent ~ ~ ~ upon issuance of a conservation order approving a spacing exception. ~ ~ (Comnanv Name) assumes ~ ~ !the liability of any protest to the spacing 'exception that may occur. ~ DRY DITCH All dry ditch sample sets submitted to the !. SAMPLE ~ Commission must be in no greater than 30' ~ sample intervals from below the permafrost j ' or from where samples are first caught and { i 10' sample intervals through target zones. I I ( ~ 22 ~`, G L Rev: 04/01/OS C\jody\transm ittal_checklist WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, KUPARUK RVOIL - 490100 Well Name: KUPARUK RIV UNIT 1Q-02BL1 -Program SER _ Well bore seg 0 PTD#:2051860 Company CONOCOPHILLIPS ALASKA INC Initial ClassRype SER I PEND GeoArea 890 Unit 11160 On/Oif Shore On Annular Disposal ^ Administration 1 Pe[mitfeeattached__-______-_--___-_____-__-___- -_-_-___NA_- ____-_Multilateral_wellbo[e; feewaiyed_per20AAC25_.005(e)__________________________-_-.-_ 2 tease number appropriate - - - Yes - 3 Uniquewelf-nameandnumber-___,-____-_ __. .__-_-,__Yes_ ____________________ 4 Well located in a_defined_pool- _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ - _ _ - _ _ - - _ Yes _ _ - _ - - Kuparuk River OiI Pool, gove[ned by Conservation Order No. 4320 _ _ _ - _ _ _ - _ - - - - _ - _ _ _ _ - _ 5 Well located proper distance from drilling unit_boundary- - . - Yes - Conservation Order No. 4320 contains no spacing restrictions with respecito drilling unit boundaries. _ 6 Well located proper distance from other wells- Yes _ Conservation Order No. 4320 has no interwell_spaeing-restrictions, - - - _ - _ . _ - _ _ 7 Sufficient acreage available in-drilling unit- - _ - . _ - - . - - - Yes . _ - - Conseryation Order No. 4320 has no interwell_spacing_rest(ictions, Wellbore will be. more than 500' from . - 8 If deviated, is_wehbore plat_included - _ - _ - _ _ Yes , - _ - an external property line_where-ownership or..landownership changes. - - _ _ 9 Operator onlyaff_ectedparty_, ___._ --_Yes_ ________ ______ --- -------------- 10 Operatorhas-appropriate_bondinforce--- - -- -- -- --- - - ---- -- -Yes- ---- ---- - --------~ ------ - -- -- -- -- ----- - - --- -- -- --- 11 Pe[mitcanbeissuedwithutconserYatignorder-___-_ __-__ _____-_Yes_ -______-___ _____-_._____________________________________________ ___ Appr Date 12 Permit_canbeissued___outadministrative-approva_I________ _______ ____-_.-Yes_ -__--_--..__----_- SFD 11/21!2005 13 Can permit be appro d before 15-day wait Yes 14 Nlell located within _rea and strata authorized by-Injection Order # (put_Ip# in-comments)-(For- Yes - - AIO.2B_ _ . _ - _ - - _ _ _ - . _ _ - _ _ _ _ . _ - 15 All wells within 1l -mile area of review identified (For service well only) . . . . . . . . . . . . . .. Yes . _ _ _ _ _ - KRU 1 Q-22,.KRU.1_Q-Q4L1, KRU 1Q-04L1,01. - _ _ _ . _ . _ _ . _ _ - _ _ _ - . _ - _ - _ . - - . _ _ . _ _ _ - . , 16 Pre-produced in _ ctor, duration_of pre production Less than 3 months-(For service well only) - -Yes - - _ - -Well will be re- roduced be and normal clean-u - o eraiions: _ - _ - P p Y - p P 17 ACMP-Findin of Consisteney_hasbeenissued_for-this project-__-___,__ _-____-_-NA-_ __.____-_,__-_-_______________________--___ --- Engineering 16 Conductorstring_provid_ed___-.___-____-_--_-_.__-__.--_ _-___-. NA-_ -_,__-Can_ductorset-in mot_herbore_well,-1Q-02(184-232).____-_______-___.____________ ___ 19 Surface casingprotectsall_know4U$DWs_.___---_.---- ___ _-.-- -_ NA-_ __-__Allaquifers exempted, 40CFR_147.102_(b)_(3).__-__-_____________________._--___ 20 CMT vol adequate-to circulate_on conducto[& surf_csg _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ - - _ _ _ Surface casin set in motherbore. - g- - - - 21 CMTv_otadequ_ate-to tie-in long string to surfcsg--__-____-_- __-_ _-;_-___-NA-_ _-__-Pr_oduction_casingset in.motherbore________________________,_-__.____-_,-_-__-___ 22 CMT_will coyer_allknown-productive horizons- . _ _ No- _ - _ . -Slotted liner completion planned, - - - - - _ 23 Casing designs adequate for C, T, B &-permafrost- _ . _ _ - - - - _ NA_ _ - - - 9riginal well_tubulars_met deli n_r_ uirements. -NA for slotted liner.. _ _ ... - - - g ~ - - 24 Adequate tankage_o_r reserve pit . _ - _ - _ - _ - - _ _ . _ - _ -Yes _ _ Rig is.e_quippedwith steel_pitS. -No-reserve-pitplanned, All waste to approved disposal wells.- _ - _ _ _ - - . , - 25 Ifa_re-dr-ill,has_a-10-403 for abandonment been approved__.______ __-_-_-__ Yes_ ____-30.5,287____________________ - - - 26 Adequate wellbore separation_proposed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ _ _ - - Proximit anarysisperf_ormed. -Nea[est.branch is"B"section.- Paths diverge, _ , _ _ _ _ - ---------------- 27 If diverter required, does it meet regulations- . _ _ _ - - - _ _ _ _ - _ _ . _ _ - - _ _ _ _ NA- _ _ _ _ BOP stackwill ai[eady_be inplace, - - - _ _ - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Appr Date 28 Drilling fluid_prograro schematic.& equip listadequate_ - - _ _ - _ .Yes - _ - - _ -Maximum expected formation pressure 1Q.7 EMW._ Dynamic overbalance with 9.5 ppgfluid and trapped pressure, TEM 1112112005 29 BOPEs,dotheymeetregulation____________________________ _________Yes- _--_._-_2wellboreyolums of~11.Qppgfluidwillbe_onlocatio_nforcontingency.___--___.-_-_______-_--_ Q~ 30 BOPS-press rating appropriate; test to_(put prig in comments)- - - - - - - - - - - - - - -Yes _ - - . - MASP calculated at 2870 psi. 4000.psi_BCfP testplanned, _ - _ _ - - - - - - - _ _ - - - - _ - _ , _ ' PX~j "~"" 31 Choke-manifold complieswlAPI_RP-5$(May84)___-__-._-_______ _________Yes_ ___-_-__- ,__-_,_-_ YYY ti~, 32 Work will occur withoutoperationshutdown-------------------- -----.---Yes- -----.---,.-------- ------------------.--------. ----------------_ ~~ 33 Is presence of H2S gas probable _ - - _ . _ . - _ - - - _ _ . - -Yes . _ - H2$ is repo[ted_on_1Q-pad.- Mud should preclude H2$ on-rig, Rig_has sensors and alarms.- . - - _ . - - - . 34 Mechanical condition of wells within AOR yerifed (For service well only) _ - _ _ - _ _ -Yes . - - - -Proximate wells-encountered breathing and hig res.-Pressure, but no AOR issues identifed-- - - - - - - - - - - - Geology 35 Pe[mitcanbeissuedwlo_hydrogen_sulfidemeasures-_-_._-_______ _________No__ _-__-_1Q-PadisadesinatedH2S ad.__.__--__--_-_,_-____-- ---__- 9 p 36 Data.presented on potential overpressure zones, _ - _ _ - - - . _ - _ Yes . - - _ -Expected pressure is 10.7 ppg EMW; wiltbe drilled with 9,5-ppg mud and-overbalanced pressure_using _ _ - Appr Date 37 Seismic anal sis. of shallow gas-zones- - - _ - _ - y - NA_ _ - - - coiled tubin a uivalentcirculatin densit -will be 11:0 g (q 9 - Y - RPgI• . - - - SFD 1111612005 38 Seabedcondjtionsunrey_(ifoff-sh_ore)-__-_-.-_--__________ --_____-_N_A-- -____-___-_-___ 39 _ Contact name/phone_for weekly progress reports jexploratory only]- , _ _ _ _ , - _ - - _ NA_ - Geologic Engineering Public Date Date: Date Lateral bein drilled to accommodate 5' TVD of ankerite encountered while drillin 1Q-026. SFD 9 9 Commissioner: Co Commissioner: • • • Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. **** REEL HEADER **** LDWG 07/06/15 AWS 01 **** TAPE HEADER **** LDWG 07/06/14 O1 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: LISTAPE.HED TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: 1Q-02BL1 API NUMBER: 50029212486000 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: BAKER HUGHES INTEQ TAPE CREATION DATE: 13-JUN-07 JOB DATA MWD RUN 4 MWD RUN 5 MWD RUN 7 JOB NUMBER: 4 5 7 LOGGING ENGINEER: T. STURDIVANT D. BARBA D. BARBA OPERATOR WITNESS: G. BARBER G. BARBER G. BARBER MWD RUN 8 MWD RUN 13 MWD RUN 14 JOB NUMBER: 8 13 14 LOGGING ENGINEER: T. STURDIVANT E. AGUIRRE D. LABRECQUE OPERATOR WITNESS: G. GOODRICH C. SEVCIK G. GOODRICH MWD RUN 15 JOB NUMBER: 15 LOGGING ENGINEER: E. AGUIRRE OPERATOR WITNESS: C. SEVCIK SURFACE LOCATION SECTION: 26 TOWNSHIP: 12N RANGE: 09E FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: 78.00 DERRICK FLOOR: 00.00 GROUND LEVEL: 00.00 # WELL CASING RECORD _ OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE {IN) DEPTH (FT) 1ST STRING 9.625 3830.0 2ND STRING 7.000 6268.0 3RD STRING 4.500 9010.0 PRODUCTION STRING 3.75 12050.0 REMARKS: PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. A5 SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR TO DELIVERY FROM THE WELL SITE. SURFACE LOCATION: LAT: N 70 DEG 22' 9.094" LONG: W149 DEG 46' 7.777" LOG MEASURED FROM K.B. AT 78 FT. ABOVE PERM. DATUM (M.S.L.). COMMENTS: (1) All depths are Measured Depths (MD) unless otherwise noted. (2) All depths are Bit Depths unless otherwise noted. (3) All Gamma Ray data are realtime data. (4) Baker Hughes INTEQ utilized Coiltrak downhole tools and the Advantage surface system to log this well. (5) Tools ran in the string included Casing Collar Locator, a Electrical Disconnect and Circulating Sub, a Drilling Performance Sub (inner and outer downhole pressure, downhole weight on bit, and vibration stick-slip), a Gamma and Directional Sub, and Hydraulic Orienting Sub with a near bit inclination sensor. (6) Data presented here is final and was not depth adjusted to a PDC (Primary Depth Control) log. The INTEQ Gamma Ray is the PDC for well 1Q-02BL1. (7) The 1Q-02BL1 wellbore was drilled from 1Q-02 through a milled window in 4.5" liner. Top of window 8541.1 ft. MD (6439.5 ft. SSTVD) Bottom of window 8548.4 ft. MD (6444.0 ft. SSTVD) (8) The interval from 12021 ft. to 12050 ft. MD (6677.7 ft. to 6679.5 ft. SSTVD) was not logged due to bit to sensor offset. (9) The 1Q-02BL1 wellbore was tied to 1Q-02 at 8190 ft. MD (6214.2 ft. SSTVD). (10) The interval from 8518 ft. to 8868 ft. MD (6424.8 ft. to 6556.9 ft. SSTVD) was recorded in a MAD PASS. (11) We11 1Q-02BL1 was sidetracked from 1Q-02BPB1 at 9608 ft. MD (6605.8 ft. SSTVD). Time drilled to 9635 ft. MD (6609.7 ft. SSTVD). (12) Ultra Slim Resistivity Sub was layed down at 11780 ft. MD (6646.9 ft. SSTVD) per customer request. • Tape 5ubfile: 1 93 records... Minimum record length: 8 bytes Maximum record length: 132 bytes **** FILE HEADER **** LDWG .001 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE001.HED 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 MWD 8548.0 12050.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 4 8548.0 8871.0 MWD 5 8871.0 9156.0 MWD 7 9156.0 9532.0 MWD 8 9532.0 9603.0 MWD 13 9603.0 11771.0 MWD 14 11771.0 11818.0 MWD 15 11818.0 12050.0 REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN 1Q-02BL1 5.xtf LCC 150 CN ConocoPhillips Alaska, Inc. WN 1Q-02BL1 FN Kuparuk River COUN North Slope Borough STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAX 0.0 RPD RPD RPCL 0.0 RP5 RPS RPCH 0.0 RAD RAD RACL 0.0 RAS RAS RACH 0.0 ROP ROP ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAPI 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPS MWD 68 1 OHMM 4 4 4 RAD MWD 68 1 OHMM 4 4 5 RAS MWD 68 1 OHMM 4 4 6 ROP MWD 68 1 FPHR 4 4 24 Total Data Records: 195 Tape File Start Depth = 8548.000000 Tape File End Depth = 12050.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 241 records... Minimum record length: 8 bytes Maximum record length: 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE011.HED FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 4 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 8548.0 8871.0 LOG HEADER DATA DATE LOGGED: 09-NOV-05 SOFTWARE SURFACE SOFTWARE VERSION: ADVANTAGE DOWNHOLE SOFTWARE VERSION: 3 CTK DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 8900.0 TOP LOG INTERVAL (FT): 8548.0 BOTTOM LOG INTERVAL (FT): 8871.0 BIT ROTATING SPEED (RPM): 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: 50.7 MAXIMUM ANGLE: 91.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER MPR MULT. PROP. RESIST. 10080984 GRAM GAMMA RAY 10098458 DIR DIRECTIONAL 10079128 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.75 DRILLER'S CASING DEPTH (FT): 8548.0 BOREHOLE CONDITIONS MUD TYPE: SFFP MUD DENSITY (LB/G): 8.90 MUD VISCOSITY (S): .0 MUD PH: .0 MUD CHLORIDES (PPM): 68000 FLUID LO5S (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 115.0 MUD AT MAX CIRCULATING TEMPERATURE: .000 .0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX:. MATRIX DENSITY: .00 HOLE CORRECTION (IN): .000 TOOL STANDOFF (IN): .0 EWR FREQUENCY (HZ): 0 REMARKS: BIT RUN 4 {MWD Run 4). GR/MPR. CURVE GLOSSARY: ~J GRAM - GAMMA RAY APPARENT (MSnTD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RACL - DEEP ATTENUATION RESISTIVITY (OHMM} RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1Q-02BLl.xtf LCC 150 CN ConocoPhillips Alaska, I WN 1Q-02BL1 FN Kuparuk River COUN North Slope Boro STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT - CNAM - - ---- - ODEP ---------------- - ----- GRAX --------------- -- GRAX -- - - GRAX - 0.0 RPCL RPCL RPCL 0.0 RPCH RPCH RPCH 0.0 RACL RACL RACL 0.0 RACH RACH RACH 0.0 ROPA ROPA ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units 1 GRAX MWD 68 1 GAPI 2 RPCL MWD 68 1 OHMM 3 RPCH MWD 68 1 OHMM 4 RACL MWD 68 1 OHMM 5 RACH MWD 68 1 OHMM 6 ROPA MWD 68 1 FPHR 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Total Data Records: 36 • • Tape File Start Depth = 8548.000000 Tape File End Depth = 8871.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 3 118 records... Minimum record length: 8 bytes Maximum record length: 4124 bytes **** FILE HEADER **** LDWG .003 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE012.HED FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 5 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 8871.0 9156.0 LOG HEADER DATA DATE LOGGED: 10-NOV-05 SOFTWARE SURFACE SOFTWARE VERSION: ADVANTAGE DOWNHOLE SOFTWARE VERSION: 3 CTK DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 9188.0 TOP LOG INTERVAL (FT): 8871.0 BOTTOM LOG INTERVAL (FT): 9156.0 BIT ROTATING SPEED (RPM): 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: 85.2 MAXIMUM ANGLE: 88.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER MPR MULT. PROP. RESIST. 10080984 GRAM GAMMA RAY 10098458 DIR DIRECTIONAL 10079128 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.75 DRILLER'S CASING DEPTH (FT): 8548.0 BOREHOLE CONDITIONS MUD TYPE: SFFP MUD DENSITY (LB/G): 8.9 MUD VISCOSITY (S): .0 MUD PH: .0 MUD CHLORIDES (PPM): 66000 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 117.0 MUD AT MAX CIRCULATING TEMPERATURE: .000 .0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: .00 HOLE CORRECTION (IN): .000 TOOL STANDOFF (IN): .0 EWR FREQUENCY (HZ): 0 REMARKS: BIT RUN 5 (MGTD Run 5). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1Q-02BL1.xtf LCC 150 CN ConocoPhillips Alaska, I WN 1Q-02BL1 FN Kuparuk River COUN North Slope Boro STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------- -- ----- GRAX ------------------ GRAX ----------- GRAX ----- - 0.0 RPCL RPCL RPCL 0.0 RPCH RPCH RPCH 0.0 RACL RACL RACL 0.0 RACH RACH RACH 0.0 ROPA ROPA ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curv es: Name Tool Code Samples Units 1 GRAX MWD 68 1 GAPI 2 RPCL MWD 68 1 OHMM 3 RPCH MWD 68 1 OHMM 4 RACL MWD 68 1 OHMM 5 RACH MWD 68 1 OHMM 6 ROPA MWD 68 1 FPHR Total Data Records: 32 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Tape File Start Depth = 8871.000000 Tape File End Depth = 9156.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 4 114 records... Minimum record length: 8 bytes Maximum record length: 4124 bytes **** FILE HEADER **** LDWG .004 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !r!!!!!!!!!!!r!!!!! Extract File: FILE013.HED FILE HEADER FILE NUMBER: 4 RAw MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 7 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 9156.0 9532.0 LOG HEADER DATA DATE LOGGED: 12-NOV-05 SOFTWARE SURFACE SOFTWARE VERSION: ADVANTAGE DOWNHOLE SOFTWARE VERSION: 3 CTK • DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 9564.0 TOP LOG INTERVAL (FT}; 9156.0 BOTTOM LOG INTERVAL (FT): 9532.0 BIT ROTATING SPEED (RPM): 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: 84.9 MAXIMUM ANGLE: 85.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER MPR MULT. PROP. RESIST. 10080984 GRAM GAMMA RAY 10098458 AIR DIRECTIONAL 10079128 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN}: 3.75 DRILLER'S CASING DEPTH (FT): 8548.0 BOREHOLE CONDITIONS MUD TYPE: SFFP MUD DENSITY (LBJG): 8.9 MUD VISCOSITY (S): .0 MUD PH: .0 MUD CHLORIDES (PPM): 69000 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 123.0 MUD AT MAX CIRCULATING TEMPERATURE: .000 .0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: .00 HOLE CORRECTION (IN): .000 TOOL STANDOFF (IN): .0 EWR FREQUENCY (HZ) 0 REMARKS: BIT RUN 7 (MWD Run 7). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1Q-02BL1.xtf LCC 150 CN ConocoPhillips Alaska, I WN 1Q-02BL1 FN Kuparuk River COUN North Slope Boro STAT Alaska • • *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 RPCL RPCL RPCL 0.0 RPCH RPCH RPCH 0.0 RACL RACL RACL 0.0 RACH RACH RACH 0.0 ROPA ROPA ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units Size Length 1 GRAX MWD 68 1 GAPI 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 ROPA MWD 68 1 FPHR 4 4 24 Total Data Records: 42 Tape File Start Depth = 9156.000000 Tape File End Depth = 9532.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 5 124 records... Minimum record length: 8 bytes Maximum record length: 4124 bytes **** FILE HEADER **** LDWG .005 1024 *** LIS COMMENT RECORD *** LDWG File Version 1.000 Extract File: FILE014.HED FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 8 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 9532.0 9603.0 LOG HEADER DATA DATE LOGGED: 14-NOV-05 SOFTWARE SURFACE SOFTWARE VERSION: ADVANTAGE DOWNHOLE SOFTWARE VERSION: 3 CTK DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 9635.0 TOP LOG INTERVAL (FT): 9532.0 BOTTOM LOG INTERVAL (FT): 9603.0 BIT ROTATING SPEED (RPM): 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: 80.5 MAXIMUM ANGLE: 95.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER MPR MULT. PROP. RESIST. 10080984 GRAM GAMMA RAY 10098458 DIR DIRECTIONAL 10079128 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.75 DRILLER'S CASING DEPTH (FT): 8548.0 BOREHOLE CONDITIONS MUD TYPE: SFFP MUD DENSITY (LB/G): 8.9 MUD VISCOSITY (S): .0 MUD PH: .0 MUD CHLORIDES (PPM): 76000 FLUID LOSS (C3) .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 133.0 MUD AT MAX CIRCULATING TEMPERATURE: .000 .0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: .00 HOLE CORRECTION (IN): .000 TOOL STANDOFF (IN): .0 EWR FREQUENCY (HZ): 0 REMARKS: BIT RUN 8 (MWD Run 8). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) • i RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1Q-02BL1.xtf LCC 150 CN ConocoPhillips Alaska, I WN 1Q-02BL1 FN Kuparuk River COUN North Slope Boro STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP - ----- GRAX ------------------ GRAX ----------- GRAX ----------------- 0.0 RPCL RPCL RPCL 0.0 RPCH RPCH RPCH 0.0 RACL RACL RACL 0.0 RACH RACH RACH 0.0 ROPA ROPA ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F } Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units 1 GRAX MWD 68 1 GAPI 2 RPCL MWD 68 1 OHMM 3 RPCH MWD 68 1 OHMM 4 RACL MPTD 68 1 OHMM 5 RACH MWD 68 1 OHMM 6 ROPA MWD 68 1 FPHR 1 Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Total Data Records: 8 • i • Tape File Start Depth = 9532.000000 Tape File End Depth = 9603.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 6 90 records... Minimum record length: 8 bytes Maximum record length: 4124 bytes **** FILE HEADER **** LDWG .006 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE015.HED FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 13 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 9603.0 11771.0 LOG HEADER DATA DATE LOGGED: 24-NOV-05 SOFTWARE SURFACE SOFTWARE VERSION: ADVANTAGE DOWNHOLE SOFTWARE VERSION: 3 CTK DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 11812.0 TOP LOG INTERVAL (FT): 9603.0 BOTTOM LOG INTERVAL (FT): 11771.0 BIT ROTATING SPEED (RPM): 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: 82.6 MAXIMUM ANGLE: 93.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER MPR MULT. PROP. RESIST. 10080984 GRAM GAMMA RAY 10098458 DIR DIRECTIONAL 10079128 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.75 DRILLER'S CASING DEPTH (FT): 8548.0 BOREHOLE CONDITIONS MUD TYPE: SFFP MUD DENSITY (LB/G): 9.0 • • MUD VISCOSITY (S): .0 MUD PH: .0 MUD CHLORIDES (PPM): 66000 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 139.0 MUD AT MAX CIRCULATING TEMPERATURE: .000 .0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: .00 HOLE CORRECTION (IN): .000 TOOL STANDOFF (IN): .0 EWR FREQUENCY (HZ): 0 REMARKS: BIT RUN 13 (MWD Run 13). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MGJD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY ( OHMM) ROPS - RATE OF PENETRATION (FPHR} RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIV ITY (OHMM) *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1Q-OZBL1.xtf LCC 150 CN ConocoPhillips Alaska, I WN 1Q-02BL1 FN Kuparuk River COUN North Slope Boro STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX GRAX GRAX 0.0 RPCL RPCL RPCL 0.0 RPCH RPCH RPCH 0.0 RACL RACL RACL 0.0 RACH RACH RACH 0.0 ROPA ROPA ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 • FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curv es: Name Tool Code Samples Units 1 GRAX MWD 68 1 GAPI 2 RPCL MWD 68 1 OHMM 3 RPCH MWD 68 1 OHMM 4 RACL MWD 68 1 OHMM 5 RACH MWD 68 1 OHMM 6 ROPA MWD 68 1 FPHR Total Data Records: 241 C~ Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 Tape File Start Depth = 9603.000000 Tape File End Depth - 11771.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 7 323 records... Minimum record length: 8 bytes Maximum record length: 4124 bytes **** FILE HEADER **** LDWG .007 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE016.HED FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 14 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 11771.0 11818.0 LOG HEADER DATA DATE LOGGED: 25-NOV-05 SOFTWARE SURFACE SOFTWARE VERSION: ADVANTAGE DOWNHOLE SOFTWARE VERSION: 3 CTK DATA TYPE (MEMORY OR REAL-TIME): MEMORY • TD DRILLER (FT): 11847.0 TOP LOG INTERVAL (FT): 11771.0 BOTTOM LOG INTERVAL (FT): 11818.0 BIT ROTATING SPEED (RPM): 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: N/A MAXIMUM ANGLE: N/A TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER MPR MULT. PROP. RESIST. 10080984 GRAM GAMMA RAY 10098458 DIR DIRECTIONAL 10079128 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.75 DRILLER'S CASING DEPTH (FT): 8548.0 BOREHOLE CONDITIONS MUD TYPE: SFFP MUD DENSITY (LB/G): 9.2 MUD VISCOSITY (S): .0 MUD PH: .0 MUD CHLORIDES .(PPM): 90000 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 143.0 MUD AT MAX CIRCULATING TEMPERATURE: .000 .0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: .00 HOLE CORRECTION (IN): .000 TOOL STANDOFF (IN): .0 EWR FREQUENCY (HZ): 0 REMARKS: BIT RUN 14 (MWD Run 14). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1Q-02BL1.xtf LCC 150 CN ConocoPhillips Alaska, I WN 1Q-02BL1 FN Kuparuk River COUN North .Slope Boro STAT Alaska • *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM - - - - ODEP -------------- - ----- GRAX ------------------ GRAX -- -- - -- GRAX -- - 0.0 RPCL RPCL RPCL 0.0 RPCH RPCH RPCH 0.0 RACE RACE RACE 0.0 RACH RACH RACH 0.0 ROPA ROPA ROPA 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F j Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units 1 GRAX MWD 68 1 GAPI 2 RPCL MWD 68 1 OHMM 3 RPCH MWD 68 1 OHMM 4 .RACE MWD 68 1 OHMM 5 RACH MWD 68 1 OHMM 6 ROPA MWD 68 1 FPHR Total Data Records: 6 Tape File Start Depth = 11771.000000 Tape File End Depth = 11818.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 8 88 records... Minimum record length: 8 bytes Maximum record length: 4124 bytes **** FILE HEADER **** LDWG .008 1 ~~ Size Length 4 4 4 4 4 4 4 4 4 4 4 4 24 1024 • *** LIS COMMENT RECORD *** LDWG File Version 1.000 Extract File: FILE017.HED FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 15 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH MWD 11818.0 12050.0 LOG HEADER DATA DATE LOGGED: 26-NOV-05 SOFTWARE SURFACE SOFTWARE VERSION: ADVANTAGE DOWNHOLE SOFTWARE VERSION: 3 CTK DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 12050.0 TOP LOG INTERVAL (FT) 11818.0 BOTTOM LOG INTERVAL (FT): 12050.0 BIT ROTATING SPEED (RPM): 0 HOLE INCLINATION (DEG) MINIMUM ANGLE: 79.7 MAXIMUM ANGLE: 86.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER MPR MULT. PROP. RESIST. 10080984 GRAM GAMMA RAY 10098458 DIR DIRECTIONAL 10079128 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 3.75 DRILLER'5 CASING DEPTH (FT): 8548.0 BOREHOLE CONDITIONS MUD TYPE: SFFP MUD DENSITY (LB/G): 9.2 MUD VISCOSITY (S): .0 MUD PH: .0 MUD CHLORIDES (PPM): 95000 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 141.0 MUD AT MAX CIRCULATING TEMPERATURE: .000 .0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: .00 HOLE CORRECTION (IN): .000 TOOL STANDOFF (IN): .0 EWR FREQUENCY (HZ): 0 REMARKS: BIT RUN 15 (MWD Run 15). GR/MPR. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1Q-02BLl.xtf LCC 150 CN ConocoPhillips Alaska, I WN 1Q-02BL1 FN Kuparuk River COUN North Slope Boro STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM - -- ODEP ------------- --- ----- GRAX ------------------ GRAX --- -- --- GRAX - - 0.0 RPCL RPCL RPCL 0.0 RPCH RPCH RPCH 0.0 RACL RACL RACL 0.0 RACH RACH RACH 0.0 ROPA ROPA ROPA 0.0 * FORMAT-RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 36 One depth per frame (value= 0) Datum Specification Block Sub-type is: FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 6 Curves: Name Tool Code Samples Units 1 GRAX MWD 68 1 GAPI 2 RPCL MWD 68 1 OHMM 3 RPCH MVTD 68 1 OHMM 4 RACL MWD 68 1 OHMM 5 RACH MWD 68 1 OHMM 6 ROPA MWD 68 1 FPHR Total Data Records: 26 1 Size Length 4 4 4 4 4 9 4 4 4 4 4 4 24 Tape File Start Depth = 11818.000000 ~ ~ Tape File End Depth = 12050.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 9 108 records... Minimum record length: 8 bytes Maximum record length: 4124 bytes **** TAPE TRAILER **** LDWG 07/06/14 01 **** REEL TRAILER **** LDWG 07/06/15 AWS Ol Tape Subfile: 10 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes
