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200-063
Originated: Delivered to:9-Aug-24 Alaska Oil & Gas Conservation Commiss 09Aug24-NR ATTN: Meredith Guhl 333 W. 7th Ave., Suite 100 600 E 57th Place Anchorage, Alaska 99501-3539 Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax WELL NAME API # SERVICE ORDER #FIELD NAME SERVICE DESCRIPTION DELIVERABLE DESCRIPTION DATA TYPE DATE LOGGED 3T-621 50-103-20882-00-00 224-022 Kuparuk River WL RST FINAL FIELD 4-Jun-24 3T-621 50-103-20882-00-00 224-022 Kuparuk River WL RBP FINAL FIELD 26-Jun-24 2N-347 50-103-20337-00-00 200-063 Kuparuk River WL LDL-WFL FINAL FIELD 19-Jul-24 Transmittal Receipt ________________________________ X_________________________________ Print Name Signature Date Please return via courier or sign/scan and email a copy to Schlumberger. Nraasch@slb.com SLB Auditor - TRANSMITTAL DATE TRANSMITTAL # A Delivery Receipt signature confirms that a package (box, envelope, etc.) has been received. The package will be handled/delivered per standard company reception procedures. The package's contents have not been verified but should be assumed to contain the above noted media. # Schlumberger-Private T39395 T39395 T393962N-347 50-103-20337-00-00 200-063 Kuparuk River WL LDL-WFL FINAL FIELD 19-Jul-24 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.08.09 10:31:44 -08'00' Originated: `§1 600 E 57th Place Anchorage, AK 99518 (907) 273-1700 main (907)273-4760 fax Delivered to: TRANSMITTAL DATE31-Ju424 Alaska Oil & Gas Conservation Commis 37JUITA-NR ATTN: Meredith Guhl 333 W. 7th Ave., Suite 100 Anchorage, Alaska 99501-3539 ��Wr MT7-93 50-103-20866-00.00 ORDEJ If 223-099 "FIELD NAME Greater Mooses Tooth SERVICE WL r DELIVERABLE DESCRIPTIONCE TTiX PPROF FINAL FIELD r 11-Jun-24 r MT7-05 50-103-20833-00.00 221-087 Greater Mooses Tooth WL TTiX PPROF FINAL FIELD 18-Jun-24 MT7-96 50-103-20834-00-00 221-100 Greater Mooses Tooth WL TTiX PPROF FINAL FIELD 21-Jun-24 2N-347 50-103-20337-00.00 200-063 Kupamk River WL LDL FINAL FIELD 17-Jul-24 T3935O T39351 T39352 T39353 mittal Receipt Digitally signed by Gavin p Gavin Gluyas Gl"y" A Delivery Receipt signature confirms that a package (box, envelope, Dzte:3024A8.020833,16 etc.) has been received. The package will be handled/delivered per X -va W standard company reception procedures. The package's contents hai Name Signature Date not been verified but should be assumed to contain the above noted media. e return via courier or sign/scan and email a copy to Schlumberger. 50lu mberger-Private Originated: Delivered to:1-Jul-21Halliburton Alaska Oil and Gas Conservation Comm.Wireline & Perforating Attn.: Natural Resource TechnicianAttn: Fanny Haroun 333 West 7th Avenue, Suite 1006900 Arctic Blvd. Anchorage, Alaska 99501Anchorage, Alaska 99518Office: 907-275-2605FRS_ANC@halliburton.comThe technical data listed below is being submitted herewith. Please address any problems orconcerns to the attention of the sender aboveWELL NAME API # SERVICE ORDER # FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS # DIGITAL #1 1A-24 50-029-22984-00 907203651 Kuparuk River Packer Setting Record Field- Final 11-Jun-21 0 12 1E-34 50-029-22805-00 n/a Kuparuk River Leak Detect Log Field- Final 27-Jun-21 0 13 1E-34 50-029-22805-00 n/a Kuparuk River Plug Setting Record Field- Final 27-Jun-21 0 14 1J-168 50-029-23260-00 907188201 Kuparuk River Packer Setting Record Field- Final 3-Jun-21 0 15 2M-33 50-103-20240-00 907209681 Kuparuk River Packer Setting Record Field- Final 17-Jun-21 0 16 2N-347 50-103-20337-00 906961909 Kuparuk River Plug Setting Record Field- Final 14-Jun-21 0 17 2T-207 50-103-20287-00 907201320 Kuparuk River Leak Detect Log Field- Final 9-Jun-21 0 18 2T-207 50-103-20287-00 907199652 Kuparuk River Multi Finger Caliper Field & Processed 9-Jun-21 0 19 2V-03 50-029-21040-00 907177252 Kuparuk River Plug Setting Record Field- Final 27-May-21 0 110 3F-08 50-029-21464-00 907196137 Kuparuk River Plug Setting Record Field- Final 10-Jun-21 0 1PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF:Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518FRS_ANC@halliburton.comDate:Signed:Transmittal Date:07/01/2021Wd͗ϮϬϬϬϲϯϬ Ͳ^Ğƚ͗ϯϱϯϮϮBy Abby Bell at 3:53 pm, Jul 01, 2021 Originated: Schlumberger PTS - PRINT CENTER 6411 A Street Anchorage, AK 99518 (907)273-1700 main (907)273-4760fax 1 A-22 1 B-04 2N-347 1 B-04 1A-17 L 1A-15 1 50-029-20711 nsmittal 23 Delivered to: AOGCC -•. \ ATTN: Natural Resources Technician II (- Alaska Oil & Gas Conservation Commision 333 W. 7th Ave, Suite 100 -y Anchorage, AK 99501 RIVER I WL KUPARUK RIVER �-4— KUPARUK RIVER KUPARUK RIVER WL FINAL FIELD FINAL FINAL FINAL 200063 3 195 7 TRANSMITTALDATE-,-Jan-20 24Jan20.JW01 9 1 1 — -- --•-- wL LDL FINAL FIELD 31 -Dec -19 1 EOSH-00128 KUPARUK RIVER WL LDL FINAL FIELD 1 -Jan -20 7 return via courier or sign/scan and email a copy to and OPAL Schlumberger -Private 7 A Transmittal Receipt signature confirms that a package (box, envelope, etc.) has been received and the contents of the package have been verified to match the media noted above. The specific content of the CDs and/or hardcopy prints may or may not have been verified for correctness or quality level at this point. SLR Auditor • • OU_ ConocoPhillips Alaska P.O. BOX 100360 fi E IVED ANCHORAGE,ALASKA 99510-0360 AUG 29 2016 August 25, 2016 AOGCC Commissioner Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 " P 3 0 201 Anchorage,AK 99501 SCM41" Commissioner Cathy Foerster: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The attached spread sheet presents the well name,top of cement depth prior to filling and volumes used on each conductor. Please call Roger Winter at 907-659-7006 or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, Roger Winter ConocoPhillips Well Integrity Field Supervisor • • A ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Kuparuk Field Date 8/25/2016 1 D,2A,2L,2N&2W PAD Corrosion Initial top of Vol.of cement Final top of Cement top off Corrosion inhibitor/ Well Name API# PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 1D-09 50029228750000 1980650 14" NA 14" NA 7 8/24/2016 2A-19A 50103201970100 2010830 11" NA 11" NA 4.25 8/24/2016 2L-306 50103206300000 2101820 12" NA 12" NA 2.55 8/24/2016 2N-341 50103202630000 1981030 14" NA 14" NA 6.8 8/24/2016 2N-347 50103203370000 2000630 13" NA 13" NA 10.2 8/24/2016 2W-10 50029212390000 1842230 10" NA 10" NA 6 8/24/2016 • STATE OF ALASKA III ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter Casing Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other: Conductor Extension fi 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 200-063 3.Address: 6.API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-103-20337-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0375108 KRU Tarn 2N-347 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 12735 feet Plugs(measured) None true vertical 5268 feet Junk(measured) None Effective Depth measured 12604 feet Packer(measured) 11893 true vertical 5196 feet (true vertical) 4792 Casing Length Size MD TVD Burst Collapse CONDUCTOR 97 16 136 136' SURFACE 4172 7 5/8 4211 2300' PRODUCTION 12692 51/2 12725 5262' RECEIVED MAY 3 J 2016 Perforation depth: Measured depth: 12195-12205, 12352-12382 True Vertical Depth: 5052-5070'4969,4963-4969 AOGCC Tubing(size,grade,MD,and TVD) 3.5, L-80, 11910 MD,4802 TVD Packers&SSSV(type,MD,and TVD) No SSSV -CAMCO DS NIPPLE @ 387 MD and 387 TVD BAKER 80-40 CSG SEAL ASSEMBLY @ 11893 MD and 4792 TVD 12.Stimulation or cement squeeze summary: NA Intervals treated(measured): p�p� Treatment descriptions including volumes used and final pressure: SCANNED J1`N 2 r7 2017 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations r Exploratory r Development F Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-208 Contact MJ Loveland Email: n1878(C�conocophillips.com Printed Name MJ Loveland Title: NSK Well Integrity Project Supervisor Signature Phone:659-7043 Date - -71:17( 1Z-2-67 /(:----------- ----- CH). 6 .--& v-ri, / /Sl/f-, Form 10-404 Revised 5/2015 44046RBDMS j,✓JUN 0 2 2016 Submit Original Only • • Iv' . . RECEIVED ConocoPhillips MAY 31 20161 Alaska / P.O. BOX 100360 O GCC ANCHORAGE,ALASKA 99510-0360 May 26, 2016 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West '7thAvenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well 2N-347, PTD 200-063 conductor extension. Please contact me at 659-7043 if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • • 2N-347 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 05/22/16 Vac'd out cellar and attached an air mover to wellhead near conductor. 2N Operator's 2nd reading= 02=20.9% C0=0 H2S=0 LEL's=0% Welded a 13"conductor extension onto conductor with 2N pad operator's approval. Final T/I/O= 300/1100/280 -`f s ' {i1 \'tom*1 11 ° 4 ,^ , ' k\ " I ,a ' � ftp #a • , trr' y LJ /CD 1,14 k sus +} • '� ! :' k. ,e Ur' (^I)` 4 W }' +� k 44: „1,4,A.S.' \ ci. .� OWiL, ',‘"...„ 'kt \\' Villi,8'..r; i. r-Q � � � G % ON .,cz s cA L • CD O Q_ Q p_ C6 o_ C) ''' kr'''"".46. * e. ., Y f 1 . w i P F • . i t..., ,..,.*,..,.. 10 4pi*op e• * alirig.tose tifralto,„,41,. , Atio III. ' .4. - C it. . ... . , .. .. . , . .,......... • .. . ..... am......,4, ,,,,..., .. _ ........ _ ‘ . 01.414, , _ ililloir • ,filrilft"Itr...._ 'Cir .taliiraiir 411.IW irr alp i illarimilwarwar ,,, .. ,. Jar Aram ., Ai***4144.4.0 Mr spy wit ' allir 3111 at ,,,. Air 111."is*at' 0\- liftrlift"fitoirara • ..,.. v._ 4111,a0, Nv , Ar it Mr amp ‘ iNtram, 0-0 0 11'41 St AltiN , ''''. iroPTD 20. air , • • 2 , " ( opyrighttNitykil Ig , r , I S . hts r- .k -.- (4 ed . .. . . ", • • raph is pro • , m 4,o the AO , ith „..„ Permis' 0 • cop for its4lovirniusve• ,. , ' -; ing for ariff ( 1pr purpose or kty 'i.- ny. • r .' ,__s pruhi others rte .,„ 'b. MIKva' ithout the oft15- _ q Alatiticip, ) c ...., . consent. 4-11s 11( re itoPhillip 4xDre' s, _r_ , , of r„, • • s� THE STATE Alaska Oil and Gas of® L AcKA Conservation Commission t ==' ' 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 o „,. e„ Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov MJ Loveland NSK Well Integrity Project Supervisor y 1 ( 7 2r) ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU Tarn 2N-347 Permit to Drill Number: 200-063 Sundry Number: 316-208 Dear Ms. Loveland: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, a4 Cathy . Foerster Chair DATED this Aay of April, 2016. RBDMS i.'-APR 0 5 2016 • RECEIVED STATE OF ALASKA MAR 2 9 2016 • ALASKA OIL AND GAS CONSERVATION COMMISSION as 1 h APPLICATION FOR SUNDRY APPROVALS AOGGG 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Repair Well Operations shutdown r Suspend r Perforate r Other Stimulate r Pull Tubing r Change Approved Program 1-- Rug for Redrill r Perforate New Pool r Re-enter Susp Well r Alter Casing r Other Conductor Extension J 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r 200-063 ' 3.Address: Stratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-103-20337-00 • 7. If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No (� KRU Tarn 2N-347 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0375108 Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth Mp:: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 12735 5268 '4)042,4' r'N6 5196' 2000 None None Casing Length Size MD TVD Burst Collapse CONDUCTOR 96 16 135' 135' SURFACE 4172 7 5/8 4211' 2300' PRODUCTION 12692 51/2 12725' 5262' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 12195-12205, 12352-12382 ' 5052-5070'4969,4963-4969 3.5 L-80 11910 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) Non SSSV-CAMCO DS NIPPLE t MD=387 TVD=387 BAKER 80-40 CSG SEAL ASSEMBLY - MD=11893 TVD=4792 12.Attachments: Proposal Summary Fro WellBore Schematic r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development • p Service r 14. Estimated Date for 15. Well Status after proposed work: 04/15/16 OIL r • WINJ r vvosRL r Suspended r Commencing Operations: 16.Verbal Approval: Date: GAS r WAG r GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact: MJ Loveland Printed Name MJ Loveland , Phone:659-7043 Email: n18781a�conocophillips.com Title: NSK Well Integrity Project Supervisor Signature ,/r l G ! Date: 3/02///‘ /‘ Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3\LIZ — 20cd Rug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: RBDMS LI- APR 0 5 2016 Post Initial Injection MIT Req'd? Yes r No Spacing Exception Required? Yes r No 17 Subsequent Form Required: / — �e'1-1-- ,,// APPROVED BY Approved by: H((..— COMMISSIONERlTHE COMMISSION Date: 1¢/4 V T L 4/406, ( f 3/3o/iS. Q /! �lr Submit Form and Form 10-403 Revised 11/2015 for 12 months from the ate of approve. Attachments in Duplicate • • ConocoPhillips RECEIVED Alaska MAR 2 9 2016 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC March 26, 2016 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foerster: Enclosed please find the 10-403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 2N-347, PTD 200-063 conductor extension. Please contact me at 659-7043 if you have any questions. Sincerely, MJ Loveland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska,Inc. Kuparuk Well 2N-347 (PTD 200-063) SUNDRY NOTICE 10-403 APPROVAL REQUEST 03-26-16 This application for Sundry approval for Kuparuk well 2N-347 is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to the surface casing. At some point during normal operations the conductor subsided about 13". With approval, the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Examine surface casing for any corrosion damage if it is exposed. 3. Extend the conductor to starter head. 4. File 10-404 with the AOGCC post repair. NSK Well Integrity Projects Supervisor KUP PROD 2N-347 Conoc Phillips ; Well Attributes Max Angle&MD TD Alaska,Inc. ' '' Wellbore API/UW Field Name Wellbore Status ncl(') MD(ftKB) Act Btm(ftKB) CmocrR.lfip, 'r 501032033700 TARN PARTICIPATING AREA PROD 74.45 10,596.00 12,735.0 •.. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2N-347,11/8/20144.0140 PM SSSV:NIPPLE 82 12/21/1931 Last WO: 43.381 6/9/2000 Vertical schematic(actual) Annotation Depth(MB) End Date Annotation Last Mod By End Date Last Tag:SLM 12,398.0 11/7/2014 Rev Reason:TAG lehallf 11/8/2014 HANGER;32.0 3 f -IF Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 39.0 135.0 135.0 62.58 14-40 WELDED II Casing Description OD(in) ID(in) Top(ftKB) Set Depth(kKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread - SURFACE 75/8 6.875 39.0 4,210.8 2,300.2 29.70 L-80 BTC-MOD Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread "•"•"•^'^••^^"••"'�'•'"^••"^"'� - •PRODUCTION 5.5'x3.5" 51/2 4.950 32.2 12,724.6 5,262.0 15.50 L-80 BTC-MOD @ 11916' Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth IND)(...Wt(lb/ft) Grade Top Connection TUBING 3 29921 32.0 11,910.21 4,801.61 9.30 L-80 EUE8RDMOD M/CONDUCTOR;39.a135.o „ Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(") Item Des Com (in) NIPPLE;386.9 I i 32.0- 32.0 0.08 HANGER FMC GEN V 5M TUBING HANGER 3.500 386.9 386.8 2.17 NIPPLE CAMCO DS NIPPLE 2.875 11,620.8 4,641.6 57.92 SLEEVE BAKER CMU SLIDING SLEEVE 2.813 11,885.6 4,788.0 56.41 NIPPLE CAMCO D NIPPLE NO GO 2.750 Iii.. 11,892.7 4,792.0 56.47 LOCATOR BAKER LOCATOR 2.985 11,893.5 4,792.4 56.48 SEAL ASSY BAKER 80-40 CASING SEAL ASSEMBLY 2.985 GAS LIFT;3,713.3 , � Perforations&Slots I Shot Dens Top(TVD) Btm(ND) (shots/f Top(ftKB) Btm(kKB) (ftKB) (ftKB) Zone Date t) Type Com 12,195.0 12,205.0 4,962.8 4,968.5 T-3;S-8,2N- 11/15/2008 6.0 APERF 2.5"HSD HyperJET 347 2506 RDX,60 deg pH 12,352.0 12,382.0 5,052.4 5,069.7 T-3:S-5,S-3, 6/16/2000 4.0 (PERF Big Hole GUNS 2N-347 SURFACE;39.0-4,210.8-- 4 Stimulations&Treatments Min Top Max stem Depth Depth Top(NS) Btm(ND) (ftKB) (ftKB) (ftKB) (065) Type Date Com 12,352.0 12,382.0 5,052.4 5,069.7 FRAC 6/22/2000 PLACED 144M#OF 16/20 PROPPANT BEHIND GAS LIFT;7,549.4 PIPE,9.2 PPA ON PERFS.70%OF DESIGN ii...._33 12,195.0 12,205.0 4,962.8 4,968.5 FRAC 11/17/200 FRAC w/YF125ST gel. Placed 8ppa 124965#16/20 8 Carbolite on formation Mandrel Inserts St ati (� on Top(ND) Valve Latch Port Slze TRO Run 555 LIFT,10,259.9 ■ N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (In) (psi) Run Date Com l-! '1 3,713.3 2,151.5 CAMCO KBG-2- 1 GAS LIFT DMY INT 0.000 0.0 6/9/2000 9 2 7,549.4 3,322.2 CAMCO KBG-2- 1 GAS LIFT DMY INT 0.000 0.0 6/9/2000 9 3 10,259.9 4,162.0 CAMCO KBG-2- 1 GAS LIFT DMY INT 0.000 0.0 6/9/2000 • 9 SI I-SHE,11,620a 4 11,676.8 4,671.6 CAMCO KBG-2- 1 GAS LIFT OV INT 0.313 0.0 11/25/2008 9 Notes:General&Safety End Date Annotation 11/24/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT;11,676.8 • • NIPPLE;11,885.6 LOCATOR;11,892.7 I-1 l APERF;12,195.0-12,205.0 FRAC;12,195.01 �y FRAC;12,352.0 1 _ IPERF;12,352 .0-12.382.0- - Casing 3;11,916.0-12,724.0 PRODUCTION 5.553.61 11916`;32.2-12.724.6 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. ~_- _~,,.~ Well History File Identifier RESCAN/ DIGITAL DATA OVERSIZED (Scannable) o/ Color items:/ ~'"'"Diskettes, No~ [3 Maps: Grayscale items: [] Other. No/Type [] Other items scannable by large scanner Poor Quality Originals: OVERSIZED (Non-Scannable) Other: [3 Logs of various kinds TOTAL PAGES:/~' NOTES: ORGANIZED BY: BEVERLY BRE~SHERYL MARIA LOWELL [] Other Project Proofing PROOFED BY: BEVERLY BRE~ SHERYL MARIA Scanned (done) [] Staff Proof By: Date: PAGES: (at the time of scanning) SCANNED BY; BEVERLY BREN VINCEN~ARIA LOWELL f V DATE: /SI RESCANNED BY: BEVERLY BRE~SHERYL MARIA LOWELL General Notes or Comments about this file: PAGES: /~--- Quality Checked {done) ~ J • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate Q Other Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate Q Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConOCOPhillipS Alaska, InC. Development ~ Exploratory ^ 200-063 / ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20337-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 35', Pad 120' 2N-347 ` 8. Property Designation: 10. Field/Pool(s): ADL 375108 Kuparuk River Field / Tarn Oil Pool 11. Present Well Condition Summary: Total Depth measured 12735' . feet true vertical 5268' feet Plugs (measured) Effective Depth measured 12604' feet Junk (measured) true vertical 5196' feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 100' 16" 135' 135' SURFACE 4175' 7-5/8" 4210' 2300' PRODUCTION 11881' 5-1/2" 11916' 4805' LINER 808' 3-1/2" 12724' 5262' Perforation depth: Measured depth: 12195'-12205', 12352'-12382' ,. ~~ t ~ ~i ~ ~ ~~ ~~~~ true vertical depth: 4963'-4969', 5053'-5070' Tubing (size, grade, and measured depth) 3.5", L-80, 11916' MD. Packers & SSSV (type & measured depth) no packer Camco DS nipple @ 386' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 12195'-12205' 124965# 16/20 carbolite on formation 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 455 ~ 1334 3003 -- 256 Subsequent to operation 1506 ' 1389 2827 -- 352 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil^~ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Guy Schwartz @ 265-6958 Printed Name Guy Sch rtz Title Wells Group Engineer Signature <r-' Phone: 265-6958 d Date /~ -~l - O p Pre b Sh r n Alls Drake 263-4612 ` `~ ~ / ~ /L •/S• ~ Form 10- 4 Revised 04/2006 4°a~ ~" `~'" ~ ~ ~~~~ Subm t Ori ' al Only /a/is/~ DATE SUMMARY 2N-347 Well Work Summary 11/3/08 RAN 2.64" X 10' DMY DRIFT. BLE TO GET PAST 10406' SLM. GAU TBG TO 2.79" WITH PUMP ASSTS ROM 9500' TO 10886' SLM. UNABLE T~T DEEPER. FLOW WELL OVERNIGHT. IN PROGRESS. 11/4/08 WORKED /PUMPED 2.5" x 5' BAILER TO 12357' SLM. GAUGED TBG TO 2.79" TO 11885' SLM. R/D FOR CTU TBG WASH. 11/5/08 COIL TUBING UNIT 8. PERFORMED HOT-DIESEL TUBING WASH, PUMPING 130-135-DEG F DIESEL USING 1.96" JSN WITH CONCENTRATED JETTING THROUGH ALL GLM's AND OTHER JEWELRY TO 12,300'. 11/6/08 RAN 10' x 2.64" DRIFT AND TAGGED FILL @ 12366' SLM REQUIRING PUMP ASSIST. DRIFTED WITH 2.5 DUMMY GUN & 3' ROLLER STEM ABOVE AND BELOW GUN (20' OAL). TAGGED @ 12366' SLM; NO PUMP ASSIST BUT DIFFICULT WORKING PAST ~ 9300' SL.M. PULLED OV @ 11676' RKB; GLM LEFT OPEN. READY FOR CTU. 11/8/08 COIL TUBING UNIT 8. PERFORMED SAND PLACEMENT JOB. LAID-IN 6.3-BBL OF B# SLURRY (975# 0/40 M H SAND) FROM TAG DEPTH AT 12.419' TO 12,,95' CTMD (124' AND PL ~ CONFIRMED SAND TOP AFTER ONE HOUR_ AND AGAIN AFTER 30-MINUTES, AT 12,295' CTMD. FREEZE PROTECTED WELL. READY FOR SLICKLINE. 11!9/08 TAGGED @ 12380' SLM / 12397' RKB; WINDOW TARGET: 12225' -12260'. DRIFTED TBG WITH 10' x 2.5" DUMMY; TAGGED @ SAME. READY FOR CTU. 11/12/08 PERFORM WEEKLY BOP TEST AFTER SEVERAL HOURS DOWN TIME DUE TO BROKEN TRACTOR. RESTART IN A.M. 11/13/08 PERFORM SAND PLUG, 1ST RUN TAGGED D-NIPPLE @ 11867 FOR DEPTH CORRECTION, 2ND RUN PUMPED 1000# OF 20/40 SAND FROM TAG DEPTH OF 12409 RKB. LAST SAND TOP TAG WAS 12235 CORRECTED. WELL IS FREEZE PROTECTED, READY FOR S/L. 11/14/08 TAGGED @ 12223' SLM EST. 12240' RKB. DESIRED TARGET: 12225' - 12260'. READY FOR E/L. 11/15/08 PFRFC~RATF RI 11F I nRF (7F TH T-~ FROM 12195-12205' WITH 2.5" HSD , HYPERJET LOADED 6 SPF, 60 DEGREE PHASING. TUBING PRESSURE INCREASED FROM 750# TO 800# AFTER PERFORATING. TAGGED AT PBTD AT 12228'. 11/16/08 SET CAT SV @ 11885' RKB. PUMP 200 BBL DSL DOWN TBG, TAKING RETURNS OFF IA TO PRODUCTION. SET DV @ 11676' RKB. TEST IA 3500 PSI, GOOD. BLEED IA TO 1500 PSI. PULLED CAT SV. READY FOR FRAC. 11/17/08 Pumped Frac in Tarn T3 layer, with YF125ST gel. Pumped a total of 164392# of 16/20 Carbolite 39436# left in WB 124956# and 8 PPA on formation. Frac Screened out when 10 ppa hit formation NWB width problem,. (NO FREEZE PROTECTION PUMPED). Used 2790 BBL of SW, with an average pressure of 6239 psi. (EST BHP=2750 psi) Problems with POD computers during job caused us to pump 60+ bbls with out proppant during the 7 ppa stage. 11/18/08 FCO DOWN TO HARD TAG 12611' CTMD ESTIMATED 230' OF RAT HOLE. WELL LEFT SHUT IN AND FREEZE PROTECTED FROM 3000' TVD TO SURFACE. TURN DSO, READY FOR POST FCO DRIFT AND TAG. 11/20/08 BRUSHED FLUSHED WITH BLB AND 2.77" GAUGERING TO 11854' SLM; TOOLS PACKED W/ FRAC SAND. JOB ONGOING. 11/21/08 ATTEMPT TO SET CATCHER. ATTEMPT TO PULL STA #3 OR #2 SAND, UNABLE TO REACH NOW DUE TO SAND IN TBG. WELL NOW NOT TAKING FLUID SO PUMP ASSIST IS UNAVAILABLE. RDMO FOR COIL CLEANOUT. 11/23/08 PERFORM FCO TO 12578' CTMD WITH HARD TAG. ESTIMATED 196' RAT HOLE. FREEZE PROTECT WELL 3000' TVD. WELL LEFT SHUT IN, READY FOR S/L. 11/25/08 SET CATCHER @ 11,885' RKB. PULLED DV FROM 11,676' RKB, SET 5/16" OV @ SAME. PULLED CATCHER. JOB COMPLETE. KUP • 2N-347 .nt. t COtIOCOPfIi~~IpS ~` Well Attribut es Max A ° ' ngle 8 MD ~TD ~,~,„' I I Wellbore APVU WI Well Status Prod/l Field Name nj Type Incl ( ) MD (flK8) Act Btm (flK8) i 507032033700 TARN PAR IICIPATING AREA (PROD 74.45 j 10,596.00 12,735.0 C ment ) Date A notation (p End Date Ke-Grtl (ft) Rig Release Dah °° w c r zr + so oe s:ao : w ~ O 7/1/2008 (Last WO_: I I 43.38 I 6/9/2000 ell o g:S`.c A c ~_` ~ . w n ' p ( J notation De E End Data Last Taa CTMD 1123/2008 R ' 12.6780 v Reason: TAG GLV C/O 12/5/2008 TUBING LIF7 ICAMCO/KBG-2-9/1/DMYIINT!//Comment: STA 1 LIFT '~CAMCO/KBG-2-9/1/DMY/INTO/Comment: STA2 LIFT ~CAMCO/KBG-2-9/1/DMY/INTO/ Comment: STA 3 80-0O SEAL ASSY etm deg pH 2000 i 4.OiIPERF Big Hol Min TOp Max Btrn TOp Depth Depth '~ Depth Depth (ND) (Tt/DI (flK8) (flK8( (flK8) (flK8) Type Date I 12, 195.OI 12,205.0 i1 4962.8 4.968.5 FRAC 11/17/2008 FRAC wNF126ST gel. Carbolite on formation ~l~r~~~~~~~~i~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ,, ,. ~ ~ t. ~~} ;, ;~ °~ ~~~ N0~ ~ ~ 2007 Log Description NO.4520 ~.J Company: Alaska Oil & Gas Cons Comm ~ ~ ~~ Attn: Christine Mahnken 333 West 7th Ave Suite 100 ~~4 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 2N-347 11632726 CH EDIT RST ~' 06/28/07 1 1 11 /27/07 • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 4, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission ©~~ 333 West 7th Avenue, Suite 100 ~Cd b `' Anchorage, AK 99501 ~ N~~ ~ ~ 200? Dear Mr. Maunder: Enclosed please find a (revised 10/3/07)spreadsheet with a list of wells from the Kuparuk field (KRU}. Each of these wells was found to have a void in the conductor. These voids were filled with a corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top jobs were pumped on September 9, 2007 and the corrosion inhibitor/sealant was pumped on September 16-27, 2407. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. This spreadsheet is a revised format for the original submitted on 9/28/07 Please call myself at 907-659-7506, or M.J. Loveland at 659-7043 if you have any questions. Sincerely, ~--_~ on Arend ConocoPhillips Well Integrity Field Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 9128/2007 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2L-303 201-239 7' 7" 1.2 18" 9/9/2007 7.5 9/16/2007 2L-309 205-210 13' 3" 2 18" 9/9/2007 7.5 9/16/2007 2N-302 201-115 5' 11" na 5" 11" na 39.5 9/16/2007 2N-313 198-091 5' 0.75 18" 9/9/2007 2N-335 198-204 20" na 20" na 13 9/16/2007 2N-347 200-063 21' 4 18" 9!9/2007 6 9/16/2007 2N-348 201-142 4' 8" 1.5 12" 9/9/2007 4.5 9/16/2007 2N-303 200-169 5" n/a 5" n/a 1 9/27/2007 2N-304 201-130 10" n/a 10" n/a 4.5 9/27!2007 2N-305 200-135 12" n/a 12" n/a 7.5 9/27/2007 2N-307 199-017 14" n/a 14" n/a 4.5 9!27/2007 2N-308 199-010 5" n/a 5" n/a 1 9/27/2007 2N-309 199-021 9" n/a 9" n/a 2 9/27/2007 2N-311 206-179 12" n/a 12" n/a 10 9/27/2007 2N-313 198-091 18" n/a 18" n/a 2 9/27/2007 2N-314 200-193 26" n/a 26" n/a 7 9/27/2007 2N-315 198-190 6" n/a 6" n/a 3 9/27/2007 2N-317 198-143 5" n/a 5" n/a 1 9/27/2007 2N-318 200-100 10" n/a 10" n/a 1 9/2712007 2N-319 198-197 5" n/a 5" n/a 9.5 9/27/2007 • ConocoPhillips aas~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 28, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~` Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~~ NC1~ ~ 200 ~~~Fi ocr © VFl) A/eska Di/~ 6a 2 ~~0~ ane~° a9~ C~fifssi Oq aoo~a~3 Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRin. Each of these wells was found to have a void in the conductor. These voids were filled with a corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement top jobs were pumped on September 9, 2007 and the corrosion inhibitor/sealant was pumped on September 16-27, 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call myself at 907-659-7043, if you have any questions. Sincerely, ,, M.J. vel d ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Date Kuparuk Field 9/28/2007 Well Name PTD # Initial top of cement Vol. of cement um d Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 2L-~03 201-239 7' 7" 1.2 18" 9/9/2007 7.5 9/16/2007 2L-309 205-210 13' 3" 2 18" 9/9/2007 7.5 9/16/2007 2N-302 201-115 5' 11" na 5" 11" na 39.5 9/16!2007 2N-313 198-091 5' 0.75 18" 9/9/2007 2N-335 198-204 9" na 20" na 13 9/16/2007 2N-347 200-063 21 ` 4 18" 9/9/2007 6 9/16/2007 2N-348 201-142 4' 8" 1.5 12" 9/9/2007 4.5 9!16!2007 2N-303 200-169 5" n/a 5" n/a 1 9/27/2007 2N-304 201-130 10" n/a 10" n/a 4.5 9/27/2007 2N-305 200-135 12" n/a 12" n/a 7.5 9/27!2007 2N-307 199-017 14" Na 14" n/a 4.5 9/27/2007 2N-308 199-010 5" n/a 5" n/a 1 9/27/2007 2N-309 199-021 9" n/a 9" n/a 2 9/27/2007 2N-311 206-179 12" n/a 12" n/a 10 9/27/2007 2N-313 198-091 5" n/a 5" n/a 2 9/27/2007 2N-314 200-193 26" n/a 26" n/a 7 9/27/2007 2N-315 198-190 6" n!a 6" n/a 3 9/27!2007 2N-317 198-143 5" Na 5" n/a 1 9/27/2007 2N-318 200-100 10" n/a 10" n/a 1 9/27/2007 2N-319 198-197 5" n/a 5" n/a 9.5 9/27/2007 MICROFILMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc Permit to Drill 2000630 M D 12735 TVD DATA SUBMITTAL COMPLIANCE REPORT 9/6/2002 Well Name/No. KUPARUK RIV U TARN 2N-347 Operator PHILLIPS ALASKA INC. 5268 Completion Dat 6/16/2000 "'""~' Completion Statu 1-OIL APl No. 50-103-20337-00-00 Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log N._9o Sample N__9o Directional Survey N~~j~'~'- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital ~Digital Typo_~Modi~ Fmt Log Log Run Name Scale Media No Interval Start Stop (data taken from Logs Portion of Master Well Data Maint) OH I Dataset CH Received Number Comments D 9834 FINAL LIS Verification FINAL SCMT 5 FINAL SRVY RPT ROP/GR/Res MD - 2/5 FINAL GR/Res TVD . 2/5 FINAL GR/Neu/Den MD 2/5 FINAL GR/Neu/Den TVD 2/5 FINAL LDWG LIS LDWG LIS Directional Survey FINAL IIFR Survey FINAL Directional Survey FINAL 4167 12680 Case 9800 12600 CH 0 12735 OH 4167 12735 CH 2287 5267 CH 4167 12735 CH 2287 5267 CH 4167 12680 CH CH OH 2/22/2001 098~r~'~4167-12680 2/22/2001 98;~¢"'~'LIS Verification Digital Data 2/22/2001 LIS~.V.e~ation Paper Copy 7/19/2000 BL--~tC)-.~.~/00- 12600 6/21/2000 SPERRY 0-12735. 1/9/2001 4167-12735 BL, Sepia 1/9/2001 2287-5267 BL, Sepia 1/9/2001 4167-12735 BL, Sepia 1/9/2001 2287-5267 BL, Sepia 1/9/2001 4167-12680 Digital Data 1/9/2001 Lis Verification 6/14/2001 Directional Survey, Paper Copy 6/14/2001 I IFR Survey, Digital' Data 6/14/2001 Directional Survey, Paper Copy Well Cores/Samples Information: Name Interval Start Stop Sent Received Dataset Number Comments ADDITIONAL INFORMATION Permit to Drill 2000630 DATA SUBMITTAL COMPLIANCE REPORT 9/612002 Well Name/No. KUPARUK RIV U TARN 2N-347 Operator PHILLIPS ALASKA INC. APl No. 50-103-20337-00-00 MD 12735 TVD Well Cored? Y/N~ Chips Received? ~ Analysis ---Y-/-N-'- R ~.c~.iv~d ~ 5268 Completion Dat 6/16/2000 Completion Statu 1-OIL Current Status Daily History Received? (~ / N Formation Tops ~'/N 1-OIL UIC N Comments: Compliance Reviewed By: Date: PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 October 13, 2000 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, Third Quarter, 2000 Dear Ms. Mahan: Please find reported below the volumes injected into surface casing by production casing annuli during the third quarter of 2000, as well as total volumes injected into annuli for which injection authorization expired during the third quarter of 2000. Annular Injection during the third quarter of 2000: h(1) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total CD1-45 5036 100 0 5136 365 5501 c~ CD1-03 33505 100 0 33605 385 33990 ? 1D-14 33916 100 0 34016 1487.5 35503.6 ~CD1-25 24860 100 0 24960 8627. 33587 2N-341 13544 100 0 13644 20506 34150 2N-335 25395 100 0 25495 0 25495 2N-347 14666 100 0 14766 340 15106 1D-38 33907 100 0 34007 0 34007 1D-30 30492 100 0 30592 0 30592 2N-318 220 100 0 320 0 320 2N-316 240 100 0 340 0 340 CD1-43 285 100 0 385 0 385 Ant far Dis ~,,,,~u, t.,~,~?c~.u~ aurtng the tntra ~'uarter of h(1) h(2) h(3) Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date 1C-27 28133 100 0 28233 3633 31866 June 2001 July2001 1C-127, 1C-117, lC-111, 1C-123 CD2-42 13465 100 0 13565 18134 31699 May2001 July2001 CD2-24, CD2-33 CD2-24 . 30443 100 0 30543 375 30918 June 2001 Sept2001 CD2-33, CD2-39, CD2-14 2N-318 520 100 0 620 16978 17598 Dec 2000 July 2001 2N-314, 2N-302, 2N-332' 31453 100 0 31553 325 31878 Aug 2001 Sept 2001 2N-348, 2N-350 1C-16 19579 100 0 19679 0 19679 Sept 2001 Sept 2001 1C-102, 1C-131 ..... 1C-26 34160 100 0 34260 0 34260 Aug2001 Sept2001 1C-123, 1C-119, 1C-102 -- CD2-39 279 100 0 379 0 379 Sept 2001 Sept 2001 Freeze protect volume from CD2-39 CD2-14 276 100 0 376 0 376 Sept 2001 Sept 2001 Freeze protect volume from CD2-14 Total Volumes into AnnuIi for which Disposal Authorization Ex ~ired durin the third ruarter 2001' Total Volume Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume Status of Annulus CD1-43 30937 100 0 31037 Open, Freeze Protected Jan 2001 Feb 2001 CD1-NQ1, CD1-21 2N-332' 225 100 0 325 Open, Freeze Protected July 2000 July 2000 Freeze protect 2N-332 only .... 2N-347 31540 100 0 31640 Open, Freeze Protected Sept 2000 Sept 2001 2N-349, 2N-305 1D-38 33907 100 0 34007 Open, Freeze Protected July 2000 Sept 2000 1D-30, 1D-40, 1D-141, 1D-36 1D-30 31622 100 0 31722 Open, Freeze Protected Sept 2000 Oct 2000 1D-36, 1D-34 2N-318 · 17498 100 0 17598 Open, Freeze Protected Dec 2000 July 2001 2N-314, 2N-302 ~ 2N-316 240 100 0 340 Open, Freeze Protected Aug 2000 Aug 2000 Freeze protect 2N-316 '2N-332 was permitted for annular disposal the first time in July 2000 (300-187) and re-permitted (301-219) in August 2001. The volumes for the expired permit applies just to that permit. PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 January 23, 2001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kuparuk Area Annular Disposal, Fourth Quarter, 2000 (Revision 1) Dear Ms. Mahan: Please find the revised report below with the volumes disposed into surface casing by production casing annuli during the fourth quarter of 2000, as well as total volumes disposed into annuli for which disposal authorization expired during the fourth quarter of 2000. The revision is for the annulus of Well 1D-42. An annular disposal report for 12/26/00 of 2437 barrels was not counted in the total for the Quarter. The revised total for Well 1D-42 is 15,118 from 12,681 barrels as noted in the table below. Annular Disposal during th~; fourth quarter of 2000: h(1)' h(2)' h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total 2N-343 13713 100 0 13813 17995 31808 2L-313 9017 100 0 9117 17273 26390 CD1-45 26735 100 0 26835 5501 32336 CD1-42 26447 100 0 26547 4807 31354 CD1-44 22410 100 0 22510 0 22510 2N-347 16434 100 ~ 16534 15106 31640 1D-30 1030 100 0 1130 30592 31722 2N-318 1199 100 0 1299 320 1619 1D-36 30104 100 b 30204 0 30204 2N-305 280 100 0 380 0 380 1D-34 32133 100 0 32233 0 32233 1D-42 15018 100 0 15118 0 15118 _. 13-Jun-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2N-347 MWD Dear Dear Sir/Madam' Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 'MD 12,735.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED · JUN 1 A ?.001 PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 January 19, 2001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kuparuk Area Annular Disposal, Fourth Quarter, 2000 Dear Ms. Mahan: Please find reported below the volumes injected into surface casing by production casing annuli during the fourth quarter of 2000, as well as total volumes injected into annuli for which disposal authorization expired during the fourth quarter of 2000. Annular Disposal-during thefourth quarter of 2000: h(1) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total 2N-343 13713 100 0 13813 17995 31808 2L-313 9017 100 0 9117 17273 26390 CD1-45 26735 100 0 26835 5501 32336 CD1-42 26447 100 0 26547 4807 31354 CD1-44 22410 100 0 22510 0 22510 2N-347 16434 100 0 16534 15106 31640 1D-30 1030 100 0 1130 30592 31722 2N-318 1199 100 0 1299 320 1619 1D-36 30104 100 0 30204 0 30204 2N-305 280 100 0 380 0 380 1D-34 32133 100 0 32233 0 32233 1D-42 12581 100 0 12681 0 12681 IO4- Ms. Wendy Mahan AOGCC Fourth Quarter 2000 Annular Disposal Report Page Two Total Volumes into Annuli for which Disposal Authorization Expired during the fourth quarter 2000: Total Total h(1) Total h(2) Total h(3) Volume Well Name Volume Volume Volume Injected Status of Annulus CDI-16 28950 100 0 29050 Open, Freeze Protected CD1-45 32236 100 0 32336 Open, Freeze Protected CD 1-32 33413 100 0 33513 Open, Freeze Protected CD1-42 31234 100 0 31334 Open, Freeze Protected CD1-36 33567 100 0 33667 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader CC' Marty Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kupamk Environmental: Engel / Snodgrass B. Morrison and M. Winfree Sharon Allsup-Drake Well Files WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 January 04, 2001 RE: MWD Formation Evaluation Logs 2N-347, AK-MM-00049 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 2N-347: ,/2" x 5" MD Resistivity & Gamma Ray Logs: 50-103-20337-00 72" x 5" TVD Resistivity & Gamma Ray Logs: 50-103-20337-00 ~2" x 5" MD Neutron & Density Logs: 50-103-20337-00 ~2" x 5" TVD Neutron & Density Logs: 50-103-20337-00 Blueline Folded Sepia ='1 Blueline vl Folded Sepia ~,1 Blueline -~1 Folded Sepia Blueline Folded Sepia To~ WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 December 15, 2000 MWD Formation Evaluation Logs 2N-347, AK-MM-00049 1 LDWG formatted Disc with verification listing. API#: 50-103-20337-00 PLEASE ACKNOWLEDGE RECEIFr BY SIGNING AND RETURNING THE ATTACHED COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: Annular Injection- 2N 347 ...... 2 00 -0 3 Subject: Annular Injection- 2N 347 Date: Thu, 7 Sep 2000 17:18:09-0900 From: "Tom J Brassfield" <TBRASS~ppco.com> To: Blair Wondzell <blair_wondzell~admin.state.ak.us> CC: "Randy L. Thomas" <RLTHOMAS~ppco.com>, "Nabors 19E Company Man" <NABORSCM~ppco.com>, "Brian D Noel" <BNOEL~ppco.com> Blair, we will be moving the Tarn annular injection program to the 2N 347 annulus while drilling production hole on 2N 349. As agreed we wanted to notify the AOGCC of this change. The 2N 347 annular injection approval no. is 300-186 dated 7/21/00. The 2N 347 API# is 50-103-20337-00 and the permit number is 200-063 Thanks, Tom 1 ofl 9/11/00 8:15 AM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil J~J Gas E] Suspended r-J Abandoned r-J Service J-"i 2. Name of Operator 7. Permit Number Phillips Alaska, Ino. 200-063 / iS. Address.. _ 8. APl Number P, O. Box 100360, Anchorage, AK 99510-0360 t ~ 50-103-20337-00 151' FNL, 1143' FEL, Sec. 3, T9N, R7E, UM (ASP: 460450, 5911859) ''~" ,~',: ~: .... '~ ! Kuparuk River Unit At Top Produoing Interval ~_L~__ ;_..~).._~..' i 10. Well Number 230' FSL, 1076' FEL, Sec. 32, T10N, R7E, UM (ASP:449958, 5912802) i ',.f~i-~[~i~.L~ ' ! 2N-347 At Total Depth i ..... } 11. Field and Pool 124' FSL, 1466' FEL, Sec. 32, T10N, R7E, UM (ASP: 449568, 5912198)'~ .................. Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) J6. Lease Designation and Serial No. Tarn Pool RKB 35', Pad 120 feetJ ADL 375108 ALK 4309 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. J 15. Water Depth, if offshore 16. No. of Completions I May 18, 2000 June 3, 2000 June,~, 2~0~0 ~J) N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Suwey J20. Depth where SSSV set 21. Thickness of Permafrost 12735' MD/5268' TVD 12604' MD/5196' TVD YES ~ No ~J N/A feetMD 1267' 22. Type Electric or Other Logs Run G~Re~Den/Neu, SCMT, CCL 23. eASING, LINER AND CEMENTING RECORD S~ING DEPTH MD J CASING SIZE ~. PER ~. GRADE TOP BO~OM HOLE SIZE CEME~ING RECORDJ AMOUNT PULLED 16" 62.5~ H-40 Sudace 135' 24" 9 cu yds High Early 7.625" 29.7~ L-80 Sudace 4210' 9.875" 410 sx AS III LW, 240 sx Class G 5.5" x 15.5~ L-80 Sudace 11916' 6.75" lO5 sx Class G 3.5" 9.3~ L-80 11916' 12724' 6.75" 248 sx Class G 24. Perforations open to Production (MD + TVD of Top and BoHom and 25. TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 11910' WA 12352'-12382' MD 5052'-5070' TVD 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12352'-12382' 144M~ of 16/20 proppant behind pipe, 9.2 ppa on per~, lee 35M~ in wellbore 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) July 4, 2000 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MOF WATER-BBL CHOKE SIZE J GAS-OIL RATIO 7/24/2000 6 h rs Test Period > 673 1357 0 100J 2017 Flow Tubing O~ing Pr~sure Calculated OIL-BBL GAS-MOF WATER-BBL OIL GRAVITY - APl (corr) 470 psi not available 24-Hour Rate > 2691 5427 0 not available 28. CORE DATA 'Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECEIVED N/A 000 ORIGINAL aske & ns. Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. T-3 T-2 NAME GEOLOGIC MARKERS MEAS. DEPTH 12066' 12426' 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey TRUE VERT. DEPTH 4889' 5095' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. Annulus left open - freeze protected with diesel. 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Tom Brassfield 265-6377 Randy ThomaS, INSTRUCTIONS Prepared by Sharon AIIsup-Drake General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1' Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Shut-in, Other-explain. Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, RECEIVED Item 28: If no cores taken, indicate "none". Form 10-407 AU6 16 ; 000 Alaska Oit & Gas Cons. Commission Anchorage Date: 08/08/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:2N-347 STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: TARN PARTICIPATING AREA SPUD:05/18/00 START COMP: RIG:NABORS 19E BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20337-00 05/17/00 (D1) TD/TVD: 105/0 SUPV:R.W. SPRINGER MW: 10.0 VISC: 100 PV/YP: 24/41 (105) PICKING UP MWD & ORIENTING APIWL: 8.0 Move rig on location and rig up. Accept rig ~ 0900 hrs. 5/17/00. PJSM. NU diverter. Hold pre-spud meeting. Function test diverter system. 05/18/00 (D2) TD/TVD: 1018/0 SUPV:R.W. SPRINGER MW: 10.0 VISC: 60 PV/YP: 28/29 APIWL: 6.0 ( 913) DRILLING 9-7/8" SURFACE HOLE ~ 1270', GAS 10-100 UNITS Drilled ice from 28'-103' Drilled ice from 103'-115' drilled from 115' to 231'. Large quantities of lignite coal below conductor from -100'. Repair mud mixing hopper. Drilled from 231' to 1018'. Spud meeting. 05/19/00 (D3) TD/TVD: 2088/0 SUPV:R.W. SPRINGER MW: 10.3 VISC: 51 PV/YP: 27/24 (1070) DRILLING ~ 2398' APIWL: 6.0 Drilled from 1018' to 2088' Circ hole clean with weighted sweep. Monitor hole. Wiper trip to 700', tight spot ~ 800', worked pipe. 05/20/00 (D4) TD/TVD: 3225/0 SUPV:R.W. SPRINGER MW: 10.2 VISC: 54 PV/YP: 27/23 (1137) RIH FROM WIPER TRIP. APIWL: 6.0 RIH to 2048' from wiper trip. Wash and ream from 2048' to 2087' Circ high vis sweep, heavy cuttings over shakers. Drilled from 2087' to 3225'. Pump sweep, circ hole clean, monitor hole. Wiper trip, cuttings dragging to 1575', hole swabbing. 05/21/00 (D5) TD/TVD: 4078/0 SUPV:R.W. SPRINGER MW: 10.2 VISC: 52 PV/YP: 26/22 (853) POH TO RUN CASING APIWL: 5.0 Work tight hole w/kelly and circulate hole clean @ 1475' POH to D/CLRS @ 157', work tight hole from 1575' to 1060'. RIH, no hole problems. Circ bttms up, pump low and high vis sweep and circ clean. Drilled from 3225' to 4078' 05/22/00 (D6) MW: 10.2 VISC: 46 PV/YP: 25/15 APIWL: 6.0 TD/TVD: 4220/2302 ( 142) R/D DIVERTER SYSTEM. SUPV:R.W. SPRINGER Drilled from 4078' to 4220'. Pump high and low sweeps, circ hole clean. P0H to 3023'/ no hole problems . _RJl/. ,2 ir, c,am~h~ RECEIVED AUG 1 6 2000 Alaska Oit & Gas Co~s. Commission Date: 08/08/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 condition hole, drop single shot survey. PJSM. Run casing. Circulate hole condition mud reciprocate pipe. Pump cement. Did not bump plugs, floats held. 05/23/00 (D7) MW: 9.6 VISC: 38 PV/YP: 14/ 6 APIWL: 0.0 TD/TVD: 4220/2302 ( 0) DRILLING CEMENT SUPV:R.W. SPRINGER Did not bump plugs. Floats held. R/D diverter system. NU speed head. N/U BOPs. Test BOPs to 250/3000 psi. RIH to 3155', trip drill. PJSM. Conducted stripping exercise. 05/24/00 (D8) MW: 9.6 VISC: 44 PV/YP: 16/12 APIWL: 4.4 TD/TVD: 4220/2302 ( 0) DRIL SUPV:R. SPRINGER/D. GLADDEN Perform stripping exercise. Test casing to 2000 psi. Tag cement ~ 3913' Drill cement, float collar and float shoe from 3913' to 4220' Drill new hole from 4220' to 4240' MD. Change out mud to LSND. Perform FIT, EMW - 16.2. PJSM. Drill from 4240' to 4700' 05/25/00 (D9) MW: 9.8 VISC: 44 PV/YP: 17/15 APIWL: 4.4 TD/TVD: 5365/2647 (1145) DRLG 6 3/4" HOLE ~ 5773' SUPV:DEARL W. GLADDEN Directional drilling from 4700' to 5271'. Pump sweep, circu clean. TOH to shoe. Monitor well, static. Working to put rig on hi line power. PJSM. Directional drilling from 5271' to 5365' 05/26/00 (D10) MW: 9.6 VISC: 43 PV/YP: 15/15 APIWL: 4.2 TD/TVD: 6629/3036 (1264) TIH -ON RIG GENERATORS - COULD NOT GET HI LINE EQUIP T SUPV:DEARL W. GLADDEN Direct. drilling from 5365' to 6502' Pump sweep, circu hole clean. Dir drilling from 6502' to 6629'. CBU, survey, monitor well. TOH. Hole not taking proper fill, well breathing slightly, trip back to bottom. CBU. Monitor well. TOH to shoe (4210') 05/27/00 (Dll) MW: 9.6 VISC: 45 PV/YP: 17/16 APIWL: 4.0 TD/TVD: 7734/3378 (1105) DIR DRLR 6.75" HOLE ~ 8139' SUPV:DEARL W. GLADDEN Continue to monitor well, work to complete hi line hook-up for rig. TIH to 6589', no hole problems. Wash and ream to bottom, no fill. Direct. drilling 6629' to 7323' Pump sweep w/drilling, circu until clean. Dir drilling 7323' to 7734' 05/28/00 (D12) MW: 9.6 VISC: 44 PV/YP: 13/14 APIWL: 4.0 TD/TVD: 8808/3713 (1074) DIR DRLG 8 9260' SUPV:DEARL W. GLADDEN Dir drilling from 7734' to 8150' On connection well RECEIVED appeared to be flowing. Well was shut in. Shut down annular injection. Continue to drill from 8150' to 8334' Pump AUG 16 2000 Alaska Oil & Gas Cons. Commission Anchorage Date: 08/08/00 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 sweep, CBU. Wiper trip to 6034', no hole problems. Pull and swab minimal. Wash & ream 8294' to 8334' Dir drilling 8334' to 8808' 05/29/00 (D13) MW: 9.7 VISC: 45 PV/YP: 16/12 APIWL: 3.8 TD/TVD:10300/4175 (1492) TOH SUPV:DEARL W. GLADDEN Dir drilling from 8808' to 9946'. SCR system, C/O bad UBS. Dir drilling 9946' to 10300'. Pump sweep, circ clean for short trip. 05/30/00 (D14) MW: 9.7 VISC: 44 PV/YP: 16/12 APIWL: 3.9 TD/TVD:10300/4175 ( 0) PREFORM LOT #2 SUPV:DEARL W. GLADDEN Continue circu hole clean, shut down, monitor well. Wiper trip 20 stds, trip slowly. Pump wt sweep, circ until clean. TOH. Monitor hole ~ 10 stds, no swab. PJSM. Test BOPE to 250/3000 psi. 05/31/00 (D15) MW: 9.7 VISC: 45 PV/YP: 15/15 APIWL: 3.5 TD/TVD:10300/4175 ( 0) DIR DRLG ~ 10,980' SUPV:DEARL W. GLADDEN PJSM. TIH to shoe. Perform LOT, EMW 12.8 TIH from shoe. Wash and ream 10253' to 10300'. Dir drilling 10300'-10799' Held safety meeting. 06/01/00 (D16) MW: 9.7 VISC: 46 PV/YP: 15/17 APIWL: 3.0 TD/TVD:l1528/4593 (1228) DIR DRLG 6 3/4" HOLE ~11720' SUPV:DEARL W. GLADDEN Dir drilling from 10799' to 10957' Finish circ sweep to surface, clean hole. Dir drilling 10957' to 11496'. Pump sweep and circu hole clean to lower ECDs. Dir drilling from 11496' to 11528' 06/02/00 (D17) MW: 9.7 VISC: 46 PV/YP: 18/21 APIWL: 2.8 TD/TVD:12177/4953 ( 649) DIR DRLG 6 3/4" HOLE ~12,388' SUPV:DEARL W. GLADDEN Dir drilling from 11528' to 11815' Finish circ sweep to surface, circu hole clean. Monitor well, wiper trip to 9925'. Dir drilling from 11815' to 12071' Finish circ sweep to surface. Dir drilling from 12071' to 12177' Monitor well, well static. 06/03/00 (D18) MW: 9.7 VISC: 45 PV/YP: 14/17 TD/TVD:12735/5268 ( 558) TOH TO RUN CSG SUPV:DEARL W. GLADDEN RECEIVED AUG 16 2000 APIWL: 2.8 Circu and monitor well for gas. Dir drilling 12198' to 12295'. Finish circu sweep to surface. Dir drilling from 12295' to 12725'. Circ and condition mud. BOP drill. Wiper trip to 9878', no hole problems, no swab or excess drag, monitor well, static. Circ and condition. Oil & Gas Cons. Commission Anchorage Date: 08/08/00 ARCO ALASKA INC. WELL SIIMMARY REPORT Page: 4 06/04/00 (D19) MW: 10.0 VISC: 48 PV/YP: 16/18 APIWL: 2.8 TD/TVD:12735/5268 ( 0) RUNNING 5 1/2" CSG SUPV:DEARL W. GLADDEN Continue pump sweep out, clean hole. Spot Lube pill on bottom. Monitor well, static. TOH. PJSM. Test BOPs to 250/3000 psi. R/U 3.5" tubing equipment. Tbg tongs broke down (lost hydro drive motor) C/O tongs. 06/05/00 (D20) MW: 10.0 VISC: 42 PV/YP: 15/13 APIWL: 3.0 TD/TVD:12735/5268 ( 0) ATTEMPT TO WASH 5.5" CSG TO BTTM SUPV:DEARL W. GLADDEN PJSM. Run 5.5" casing. Circulate and condition and continue to run 5.5" casing. Tight hole ~ 9107' Circulate, good returns, no fluid loss. 06/06/00 (D21) MW: 8.6 VISC: 28 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:12735/5268 ( 0) LOADING PIPE SHED, W.O.C. SUPV:DEARL W. GLADDEN Continue circulating and working casing down. Circ and condition mud. PJSM.Pump cement. Bumped plug. Floats held. Install packoff and test to 5000 psi. 06/07/00 (D22) MW: 8.6 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:12735/5268 ( 0) RIGGING UP TO RUN COMPLETION SUPV:R.W. SPRINGER Set test plug, test BOPE to 250/3000 psi. PJSM. Run CMTB-cement mapping tool. 06/08/00 (D23) TD/TVD:12735/5268 SUPV:R.W. SPRINGER MW: 8.5 VISC: 0) ND BOPE/NU TREE 0 PV/YP: 0/ 0 APIWL: 0.0 Continue running cement bond log. PJSM. Run 3.5" completion. 06/09/00 (D24) MW: 8.5 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD:12735/5268 ( 0) RIG RELEASED MOVED OVER 2N-332 SUPV:R.W. SPRINGER Test 5.5" casing to 3500 psi for 30 min, OK. Freeze protect well. N/D BOPE. N/U tree and test. Clean BOPE and cellar area. Rig released ~ 1400 hrs. 6/9/00. Move to 2N-332. RECEIVED AU(; 1 6 ; 000 Alaska ~ A Gas Cons. Commission Anchorage PHILLIPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(2N-347(W4-6)) WELL 2N-347 JOB SCOPE DRILLING SUPPORT-CAPITAL JOB NUMBER 0611001852.6 DATE DALLY WORK UNIT NUMBER 06/16/00 2 1/5" HSD, 4 SPF, BH PERFORATE SWS 2128 OPERATION COMPLETE SUCCESSFUL NO NO InitialTbgPress IFinalTbgPress[0PSI 0PSI Initial Inner Ann 0 PSI KEY PERSON SWS-JOHNSON Final Inner Ann I 0 PSI I DAY 1 SUPERVISOR JOHNS Initial Outer Ann J Final Outer Ann 0 PSII 0 PSI DALLY SUMMARY PERFORATED: 12352' - 12382', 4 SPF BIG HOLE J TIME LOG ENTRY 09:00 ARRIVE WELL SWS UNIT 2128, ENG JOHNSON 10:00 HOLD SAFTEY MEETING 10:15 PRESSURE TEST BOP/RISER TO 3000# 10:30 RIH W/HEAD/SWlVEL/ROLLER/CCL/ESIC/20' GUN/ROLLER 12:30 TIE IN TO SCMT DATED 6/7/00 12:45 BLEED WHP TO 200 PSI 13:18 SHOOT 12362 - 112382 13:22 POOH 14:50 RIH W HEAD/SWIVEL/ROLLERS/VVT BAR/CCL/ESIC/10' GUN/ROLLERS 16:32 SHOOT 12352 - 12362 16:40 POOH 18:00 AT SURFACE, ALL SHOTS FIRED, RIG DOWN 18:30 LEAVE LOCATION RECEIVED AUG 16 2000 ,~aska 0it & Gas Cons. Commi~iorl Anchorage PHILLIPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(2N-347(W4-6)) ...... WELL JOB SCOPE JOB NUMBER 2N-347 DRILLING SUPPORT-CAPITAL 0611001852.6 DATE DAILY WORK UNIT NUMBER 06/22/00 INITIAL FRAC DAY 3 OPERATION COMPLETE SUCCESSFUL YES YES Initial Tbg Press 0 PSI KEY PERSON DS-YOAKUM SUPERVISOR ODELL DALLY SUMMARY 0 PSI 500 PSI 500 PSI 510 PSI 550 PSI PUMPED INITIAL FRAC. PLACED 144M# OF 16/20 PROPPANT BEHIND PIPE, 9.2 PPA ON PERFS. 70% OF DESIGN PLACED. LEFT 35M# IN WELLBORE. ALL TREESAVER RUBBERS LEFT IN WELL. [Frac-Refrac] TIME LOG ENTRY 08:00 MIRU DS EQUIPMENT, LRS TO BACKSIDE. INSTALL TREESAVER. 12:15 SAFETY MEETING. 13 DS, 1 PAl, 2 LRS, 1 APC, 1 NABORS. JOB REVIEW, MUSTER AREA, RIG CONCERNS. WATCH FOR CONTRUCTION WORK ON BACKSIDE OF PAD. 12:30 PRIME UP PUMPS, PT LINES TO 9300 PSI. PUMP DOWNHOLE TO SET TREESAVER. FOUND LEAKS ON TREATING LINE, BLEED DOWN AND CHANGE OUT RUBBERS. SWAP OUT POPOFFS ON PRV SKID. PT LINES TO 9300 PSI. GOOD TEST. 13:45 START BREAKDOWN STAGE. PUMPED 200 BBLS SLICK WATER AT UP TO 30 BPM, SAW GOOD BREAK BACK FROM 8400 TO 6200 PSI, THEN PRESSURE BUILT WHEN WATER HIT PERFS. BUILT BACK TO 7000 PSI, PERFORMED SDT, XS FRIC = 3295 PSI, ISlP = 664 PSI, FG = .57. SDT QUESTIONABLE DUE TO INCREASING PRESSURE. 14:05 START SCOUR STAGE. 100 BBL XL PAD, 50 BBL 1 PPA SCOUR, 160 BBL FLUSH. SDT SHOWED XS FRIC OF 1090 PSI. ISIP -- 803 PSI, FG - .60. MAKE GEL FOR DATAFRAC. 14:45 START DATAFRAC. 300 BBLS XL GEL, FLUSHED WITH 109 BBL 20# LINEAR GEL AT 20 BPM. ISIP = 989, FG = .64. TC = 13.5 MINUTES, PC = 728 PSI. ADJUST PAD VOLUME TO 380 BBLS. 16:00 START SAND STAGES. SAW TSO -55 MINUTES INTO JOB, HAD NWBSO WITH 9.2 PPA ON PERFS, 144M# BEHIND PIPE. 70% OF DESIGN PLACED. 35M# IN WELLBORE. ESTIMATED SAND TOP - 6150'. 17:15 FLUSH OUT DS EQUIPMENT, RIG DOWN DS. HAVING DIFFICULTY PULLING TREESAVER. TREESAVER FREED UP. MASTER CLOSED. 19:15 DS RIGGED OFF OF WELL, ALL TREESAVER RUBBERS LEFT IN HOLE. WELL SECURED. RECEIVED AUG 1 6 2000 Alaska 0it & Gas Cons. Commission Anchora§s PP,' .LIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM C©MPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 R. Thomas Phone (907) 265-6830 Fax: (907) 265-6224 August 14, 2000 Mr. Daniel T. Seamount Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Well Completion Report for 2N-347 (200-063) Dear Mr. Commissioner: Phillips Alaska, Inc. submits the attached Well Completion Report for the drilling operations on 2N-347. If there are any questions, please contact me at 265-6830 or Tom Brassfield at 265-6377. Sincerely, R. Thomas Kuparuk Drilling Team Leader Phillips Drilling RT/TJB/skad RECEIVED AUG 16 D00 Alaska 0it & Gas Cons. Commission An~or~e Kuparuk River Unit North Slope, Alaska Kuparuk 2N, Slot 2N-347 2N-347 MWD Job No. AKMMO0049, Surveyed: 3 June, 2000 SURVEY REPORT June, 200~ Your Ref: API-501032033700 Surface Coordinates: 5911858.83 N, 460450.23 E (70° lO' 12.4759" N, 150° 19' 05.8686" W) Kelly Bushing: 155.58ft above Mean Sea Level DRiLLiNG SEll'Vii:ES Survey Ref: svy9252 A Halliburton Company Sperry-Sun Drilling Services Survey Report for 2N-347 MVVD Your Ref: API-501032033700 Job No. AKMMO0049, Surveyed: 3 June, 2000 Kuparuk River Unit Measured Depth (ft) Sub-Sea Depth (ft) 0.00 0.000 0.000 -155.58 115.00 0.000 0.000 -40.58 150.88 0390 140.710 -4.70 246.86 0.260 204.640 91.28 329.21 0.730 267.870 173.63 35970 1.200 277.140 388.49 2.230 276.780 419.64 3.250 275.820 44860 4.170 275.530 478.33 5.340 279.960 509.19 6470 282.900 539.84 7.820 285.890 569.43 9.140 285.220 599.52 10.710 286.800 691.29 15.590 290.330 783.52 21.730 289.550 874.66 24.130 285.730 964.65 24.240 278.860 1058.37 28.970 276.550 1153.88 32.700 274.960 204.11 232.89 264.00 292.90 322.53 353.22 383.64 412.90 442.54 531.88 619.22 703.15 785.26 869.04 951.03 Vertical Depth (ft) 0.00 115.00 150.88 246.86 329.21 359.69 388.47 419.58 448.48 478.11 508.80 539.22 568.48 598.12 687.46 774.80 858.73 940.84 1024.62 1106.61 1247.65 38.230 273.390 1027.38 1182.96 1343.06 42.760 274.850 1099.92 1255.50 1437.71 46.230 274.190 1167.42 1323.00 1532.23 50.550 275.360 1230.18 1385.76 1628.03 54.940 275.820 1288.16 1443.74 1722.02 58.990 274.840 1339.38 1494.96 1818.11 63.100 274.070 1385.89 1541.47 1910.97 67.070 273.830 1425.01 1580.59 2005.94 70.520 271.270 1459.36 1614.94 2101.05 72.000 271.040 1489.91 1645.49 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 0.00 N 0.00 E 5911858.83 N 460450.23 0.00 N 0.00 E 5911858.83 N 460450.23 0.09 S 0.08 E 5911858.74 N 460450.31 0.55 S 0.19 E 5911858.28 N 460450.42 0.73 S 0.41W 5911858.10 N 460449.82 0.70 S 0.92W 5911858.13 N 460449.31 0.60 S 1.77W 5911858.24 N 460448.45 0.44 S 3.26W 5911858.41N 460446.97 0.25 S 5.12W 5911858.60 N 460445,11 0.09 N 7.56W 5911858.96 N 460442.67 0.73 N 10.67W 5911859.61N 460439.57 1.68 N 14,36W 5911860.59 N 460435,88 2.85 N 18.56W 5911861.78 N 460431.68 4.29 N 23.54W 5911863.24 N 460426.71 11.04 N 43.28W 5911870.10 N 460407.01 21.07 N 71.02W 5911880.27 N 460379.32 31,77 N 104.86W 5911891.15 N 460345.54 39.60 N 140.82W 5911899.17 N 460309.62 45.16 N 182.41W 5911904.94 N 460268.06 50.03 N 231.11W 5911910.06 N 460219,39 53.94 N 285.35W 5911914.26 N 460165.17 58.42 N 347.12W 5911919.07 N 460103.42 63.64 N 413.24W 5911924.63 N 460037.33 69.54 N 483.64W 5911930.90 N 459966.96 76.98 N 559.51W 5911938.73 N 459891.13 84.28 N 637.95W 5911946.44 N 459812.73 90.80 N 721.76W 5911953.40 N 459728.96 96.60N 805.76W 5911959.64 N 459644.99 100.51N 894.19W 5911964.01N 459556.58 102.33 N 984.24W 5911966.30 N 459466.54 Dogleg Rate (°/100ft) 0.000 1.087 0.376 0.796 1.619 3.578 3.278 3.177 4.122 3.789 4.567 4.473 5.295 5.387 6.663 3.097 3.128 5.165 3.997 5.976 4.851 3.699 4.663 4.598 4.397 4.334 4.282 4.417 1.573 North Slope, Alaska Kuparuk 2N Vertical Section Comment 0.00 0.00 -0.08 -0.22 0.38 0.89 1.75 3.23 5.10 7.56 10.69 14.41 18.66 23.7O 43.71 71.84 106.10 142.36 184.14 233.00 287.35 349.26 415.54 486.13 562.25 640.92 724.93 809.10 897.61 987.66 MWD Magnetic 13 June, 2001 - 14:05 Page 2 of 7 DrillQuest 2.00.08.005 'Sperry-Sun Drilling Services Survey Report for 2N-347 MWD Your Ref: API-50f 032033700 Job No. AKMMO0049, Surveyed: 3 June, 2000 Kuparuk River Unit Measured Depth (ft) Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 2194.99 71.870 271.170 1519.04 1674.62 2290.47 71.880 271.200 1548.75 1704.33 2384.91 72.110 273.220 1577.94 1733.52 2479.07 71.960 272.930 1606.98 1762.56 2574.30 71.390 272.540 1636.92 1792.50 2669.26 71.810 274.510 1666.90 1822.48 2763.63 71.880 275.680 1696.31 1851.89 2859.07 71.400 275.740 1726.37 1881.95 2954.58 70.680 276.040 1757.40 1912.98 3048.13 69.960 274.750 1788.90 1944.48 3146.00 71.740 273.870 1821.01 1976.59 3238.52 72.030 274.620 1849.78 2005.36 3332.65 71.940 274.240 1878.89 2034.47 3427.07 71.460 275.210 1908.54 2064.12 3522.17 71.760 274.730 1938.54 2094.12 3617.64 72.960 273.280 1967.47 2123.05 3712.62 72.400 274.060 1995.75 2151.33 3806.79 72.320 274.370 2024.28 2179.86 3901.37 72.880 273.600 2052.57 2208.15 3996.81 73.150 271.990 2080.45 2236.03 4090.79 72.670 272.320 2108.07 2263.65 4145.94 72.460 272.980 2124.59 2280.17 4278.16 70.780 271.620 2166.28 2321.86 4372.81 72.000 270.570 2196.49 2352.07 4468.04 72.570 270840 2225.47 2381.05 4569.98 72.830 271.270 2255.78 2411.36 4663.78 73.420 276.470 2283.03 2438.61 4751.80 73.850 277.120 2307.83 2463.41 4853.99 72.480 274.620 2337.43 2493.01 4942.49 72.820 274.810 2363.82 2519.40 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 104.05 N 1073.53W 5911968.49 N 459377.26 E 105.92 N 1164.25W 5911970.84 N 459286.55 E 109.39 N 1254.00W 5911974.77 N 459196.82 E 114.19 N 1343.44W 5911980.04 N 459107.41 E 118.51N 1433.73W 5911984.83 N 459017.14 E 124.05 N 1523.66W 5911990.84 N 458927.24 E 132.01 N 1612.98W 5911999.27 N 458837.96 E 141.03 N 1703.11W 5912008.75 N 458747.88 E 150.29 N 1792.96W 5912018.49 N 458658.08 E 158.58 N 1880.65W 5912027.23 N 458570.43 E 165.52 N 1972.84W 5912034.66 N 458478.28 E 172.03 N 2060.53W 5912041.63 N 458390.62 E 178.95 N 2149.78W 5912049,01N 458301.41E 186.33 N 2239.12W 5912056.86 N 458212.12 E 194.15 N 2329.02W 5912065.15 N 458122.25 E 200.50 N 2419.78W 5912071.97 N 458031.53 E 206.30 N 2510.26W 5912078.25 N 457941.08 E 212.90 N 2599.76W 5912085.31N 457851.62 E 219.17 N 2689.80W 5912092.05 N 457761,62 E 223.62 N 2780.96W 5912096.98 N 457670.48 E 226.99 N 2870.73W 5912100.82 N 457580.73 E 229.43 N 2923.29W 5912103.53 N 457528.18 E 234.47 N 3048.65W 5912109.23 N 457402.85 E 236.18 N 3138.33W 5912111.41N 457313.17 E 237.30 N 3229.04W 5912113.00 N 457222.47 E 239.09 N 3326.35W 5912115.30 N 457125.17 E 245.15 N 3415.87W 5912121.83 N 457035.69 E 255.14 N 3499.73W 5912132.26 N 456951.88 E 265.15 N 3597.02W 5912142.78 N 456854.65 E 272.10 N 3681.20W 5912150.16 N 456770.50 E Dogleg Rate (°/100ft) 0.191 0.032 2.049 0.333 0.714 2.018 1.180 0.506 0.810 1.509 2.007 0.832 0.396 1.100 0.574 1.917 0.981 0.325 0.977 1.638 0.611 1.204 1.602 1.663 0.657 0.477 5.342 0.861 2.698 0.435 North Slope, Alaska Kuparuk 2N Vertical Section Comment 1076.95 1167.67 1257.48 1347.04 1437.44 1527.52 1617.09 1707.52 1797.68 1885.64 1978.04 2065.93 2155.39 2244.96 2335.11 2426.O5 2516.70 2606.40 2696.61 2787.89 2877.71 293O.33 3055.80 3145.47 3236.14 3333.45 3423.14 3507.35 3604.97 3689.37 13 June, 2001- 14:05 Page 3 of 7 DrillOuest 2.00. 08.005 Sperry. Sun Drilling Services Survey Report for 2N-347 MWD Your Reft API-501032033700 Job No. AKMMO0049, Surveyed: 3 June, 2000 Kuparuk River Unit Measured Depth (ft) Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 503664 73.270 274.500 2391.27 2546.85 5132.09 71.800 273.000 2419.92 2575.50 5225.87 71.600 272.650 2449.37 2604.95 5323.28 72.300 272,090 2479.55 2635.13 5418.52 72.660 272.300 2508.22 2663.80 5510.05 71.060 271,480 2536.72 2692.30 5605.18 71,200 271.740 2567.48 2723.06 5706.40 71.780 271.320 2599.62 2755.20 5801,36 72.810 271.820 2628.50 2784.08 5896.13 72.090 271.800 2657.07 2812.65 5991.25 73.010 271,080 2685.60 2841.18 6085.71 72.380 273.300 2713.70 2869.28 6173.80 73.160 273,720 2739.79 2895.37 6275.71 72,000 273.890 2770.30 2925.88 6370.48 72,890 274.560 2798.88 2954.46 6465.08 72,550 273,590 2826.98 2982.56 6557.22 70.690 273.810 2856.04 3011.62 6654.12 71.030 272,160 2887.81 3043.39 6749.13 72.140 272.360 2917.82 3073.40 6836.70 72.950 272,220 2944.09 3099.67 6938.22 72.760 273.700 2974.02 3129.60 7027.18 70.900 273.080 3001.76 3157.34 7120.56 71.170 272.260 3032.11 3187.69 7215.52 71,920 272.450 3062.17 3217.75 7310.45 72.420 271.730 3091.23 3246.81 7405.37 71.380 273.420 3120.73 3276.31 7499.96 71.360 274.620 3150.94 3306.52 7594.22 72.020 274,210 3180.56 3336.14 7689.10 72.740 274,560 3209,28 3364.86 7783.67 73,200 273.480 3236.97 3392.55 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 279.41N 3770.96W 5912157.94 N 456680.78 E 285.37 N 3861.81W 5912164.37 N 456589.96 E 289.75 N 3950.74W 5912169.23 N 456501.06E 293.58 N 4043.28W 5912173.54 N 456408.54E 297.06 N 4134.03W 5912177.49 N 456317.81 E 299.93 N 4220.96W 5912180.82 N 456230.89 E 302.46 N 4310.94W 5912183.82 N 456140.93 E 305.02 N 4406.89W 5912186.88 N 456044.99 E 307.50 N 4497.32W 5912189.83 N 455954.58 E 310.36 N 4587.63W 5912193.16 N 455864.28 E 312.64 N 4678.35W 5912195.91N 455773.58 E 316.08 N 4768.46W 5912199.82 N 455683.49 E 321.23 N 4852.43W 5912205.42 N 455599.54 E 327.68 N 4949.45W 5912212.37 N 455502.56 E 334.34 N 5039.56W 5912219.50 N 455412.48 E 340.76 N 5129.66W 5912226.39 N 455322.42 E 346.40 N 5216.92W 5912232.49 N 455235.19 E 351.17 N 5308.33W 5912237.73 N 455143.80 E 354.72 N 5398.41W 5912241.76 N 455053.75 E 358.06 N 5481.88W 5912245.53 N 454970.30 E 363.07 N 5578.75W 5912251.05 N 454873.45 E 368.07 N 5663.12W 5912256.49 N 454789.11 E 372.18 N 5751.34W 5912261.06 N 454700.91E 375.89 N 5841.34W 5912265.24 N 454610.94 E 379.18 N 5931.65W 5912269.00 N 454520.64 E 383.23 N 6021.77W 5912273.52 N 454430.54 E 389.51 N 6111.19W 5912280.27 N 454341.16 E 396.40 N 6200.41W 5912287.63 N 454251.98 E 403.32 N 6290.57W 5912295.01 N 454161.85 E 409.65 N 6380.77W 5912301.82 N 454071.69 E Dogleg Rate (°ll00ft) 0.572 2.149 0.414 0.903 0.433 1.944 0.298 0.695 1,195 0.760 1.207 2.341 0.996 1.149 1.156 1,043 2,031 1.646 1.185 0.937 1.406 2.193 0.879 0.812 0.894 2.016 1.202 0.813 0.836 1.195 North Slope, Alaska Kuparuk 2N Vertical Section Comment 3779,36 3870.38 3959.41 4052.03 4142.85 4229.82 4319.83 4415.80 4506.25 4596.61 4687.33 4777.51 4861.63 4958.84 5049.14 5139.43 5226.85 5318,38 54O8.53 5492.O6 5589.06 5673.57 5761.88 5851,95 5942.32 6032.54 6122.14 6211.57 6301.94 6392.33 13 June, 2001.14:05 Page 4 of 7 DrillQ,est 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 2N-347 MWD Your Ref: API-501032033700 Job No. AKMMO0049, Surveyed: 3 June, 2000 Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 7878.23 72.300 273.440 3265.01 3420.59 7972.87 69,930 273.160 3295.64 3451.22 8068.07 69,620 272.120 3328.56 3484.14 8170.37 70.700 271,320 3363.28 3518.86 8258.75 71.800 271.530 3391.69 3547.27 8359.81 72.780 272.380 3422.43 3578.01 8447.09 73.710 272.120 3447.59 3603.17 8541.66 72.790 272.110 3474.84 3630.42 8636,23 72,620 271.690 3502,96 3658.54 8731.01 71.110 273.250 3532.46 3688.04 8826.13 70.810 273.110 3563.49 3719.07 8920.80 71.450 273.210 3594.11 3749.69 9015.90 72.410 273.880 3623.61 3779.19 9110.55 73.140 273.520 3651.63 3807.21 9212.34 74.140 273.300 3680.31 3835.89 9306,99 73.080 273.490 3707.01 3862.59 9401.78 73.810 272,590 3734.02 3889.60 9496.97 73.060 272.800 3761.16 3916.74 9592.05 73.360 273.610 3788.63 3944.21 9687.04 70.700 272.850 3817.93 3973.51 3849.42 3880.43 3909.45 3941.09 3972.55 9782.48 70.770 271,950 9877.00 70,930 272.280 9964.55 70,360 274.220 10059.05 70,510 273.900 10154.30 70.920 274.240 4005.00 4036.01 4065.03 4096.67 4128.13 10229.85 71.430 273.260 3996.93 4152.51 10318.55 72.090 273.530 4024.69 4180.27 10405.84 72.860 274.040 4050.98 4206.56 10501.31 73.650 273.420 4078.48 4234.06 10595.99 74.450 273.690 4104.50 4260.08 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 415.10 N 6470.91W 5912307.74 N 453981.58 E 420.26 N 6560.30W 5912313.37 N 453892.21 E 424.37 N 6649.53W 5912317.95 N 453803.00 E 427.26 N 6745.72W 5912321.34 N 453706.84E 429.34 N 6829.38W 5912323.86 N 453623.19 E 432.63 N 6925.59W 5912327.64 N 453526.99 E 435.91 N 7009.10W 5912331.36 N 453443.50 E 439.25 N 7099.60W 5912335,18 N 453353.03 E 442.24 N 7189.84W 5912338.64 N 453262.80 E 446.12 N 7279.82W 5912342.99 N 453172.84 E 451.11N 7369.60W 5912348.45 N 453083.09 E 456.05 N 7459.05W 5912353.85 N 452993.67 E 461.64 N 7549.28W 5912359.91 N 452903.47 E 467.47 N 7639.50W 5912366.22 N 452813.28 E 473.28 N 7736.99W 5912372.54 N 452715.82 E 478.66 N 7827.63W 5912378.39 N 452625.21 E 483.48 N 7918.36W 5912383.68 N 452534.50 E 487.76 N 8009.50W 5912388.45 N 452443.39 E 492.85 N 8100.39W 5912394.01N 452352.53 E 497.95 N 8190.59W 5912399.58 N 452262.36 E 501.72 N 8280.60W 5912403.82 N 452172.36 E 505.02 N 8369.83W 5912407.58 N 452083.15 E 509.70 N 8452.30W 5912412.69 N 452000.71 E 516.00 N 8541.12W 5912419.46 N 451911.93 E 522.38 N 8630.80W 5912426.31N 451822.28 E 527.06 N 8702.15W 5912431.36 N 451750.95 E 532.05 N 8786.24W 5912436.79 N 451666.89 E 537.54 N 8869.30W 5912442.72 N 451583.86 E 543.49 N 8960.53W 5912449.14 N 451492.67 E 549.14 N 9051.39W 5912455.26 N 451401.84 E Dogleg Rate (°/100ft) 0.953 2.520 1.076 1.287 1.265 1,258 1,103 0.973 0,461 2.233 0.345 0,683 1.211 0.853 1.004 1.136 1.192 0,816 0,875 2.902 0.893 0.371 2.190 0.356 0.547 1.401 0.798 1:043 1.035 0.888 North Slope, Alaska Kuparuk 2N Vertical Section Comment 6482.62 6572.15 6661.47 6757.69 6841.37 6937.63 7021.21 7111.76 7202.05 7292.12 7382.03 7471.60 7561.99 7652.37 7750.02 7840.81 7931.66 8022.90 8113.92 8204.26 8294.35 8383.64 8466.23 8555.23 8645.10 8716.59 8800.82 8884.03 8975.43 9066.44 13 June, 2001 - 14:05 Page 5 of 7 DrillQ,est 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 2N-347 MWO Your Reft API-501032033700 Job No. AKMMO0049, Surveyed: 3 June, 2000 Kuparuk River Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 10690.71 73.640 273.320 4130,54 4286.12 554.70 N 9142.29 W 5912461.30 N 451310.97 E 10785.55 72.240 272.400 4158.36 4313.94 559.23 N 9232.84 W 5912466.30 N 451220.44 E 10880.20 72.340 272.250 4187.15 4342.73 562.89 N 9322.93 W 5912470.43 N 451130.37 E 10975.05 72.850 271.240 4215.52 4371.10 565.64 N 9413.39 W 5912473.66 N 451039.92 E 11077.26 71.190 269.270 4247.08 4402.66 566.08 N 9510.60 W 5912474.61 N 450942.72 E 11165.26 68.800 268.840 4277.18 4432.76 564.72 N 9593.27W 5912473.68 N 450860.04 E 11259.84 66.860 268.020 4312.87 4468.45 562.33 N 9680.82W 5912471.74 N 450772.48 E 11354.64 63.760 265.910 4352.47 4508.05 557.79 N 9766.82W 5912467.65 N 450686.46 E 11450.52 60.310 264.030 4397.42 4553.00 550.39 N 9851.16W 5912460.69 N 450602.08 E 11546.57 58.040 260.320 4446.65 4602.23 539.19 N 9932.85W 5912449.92 N 450520.33 E 11642.83 57.890 257.330 4497.72 4653.30 523.38 N 10012.89W 5912434.53 N 450440.21E 11733.11 55.770 255.030 4547.12 4702.70 505.35 N 10086.27W 5912416.88 N 450366.74 E 11835,05 55.970 254.140 4604.31 4759.89 482.92 N 10167.61W 5912394.88 N 450285.28 E 11928.71 56.780 254.320 4656.18 4811.76 461.73 N 10242.66W 5912374.08 N 450210.12 E 12026.73 55.130 254.360 4711.05 4866.63 439.80 N 10320.86W 5912352.56 N 450131.80 E 12122.98 55.070 254.000 4766.12 4921.70 418.28 N 10396.81W 5912331.44 N 450055.74 E 12219.03 55.430 255.330 4820.87 4976.45 397.41 N 10472.92W 5912310.97 N 449979.53 E 12315.24 55.130 255.630 4875.67 5031.25 377.59 N 10549.47W 5912291.54 N 449902.87 E 12411.73 54.250 255.250 4931.44 5087.02 357.79 N 10625.68W 5912272.15 N 449826.56 E 12507.88 55.350 254.450 4986.86 5142.44 337.26 N 10701.52W 5912252.01 N 449750.62 E 12604.34 56.560 254.820 5040.86 5196.44 316.08 N 10778.59W 5912231.24 N 449673.44 E 12653.25 57.050 254.630 5067.64 5223.22 305.30 N 10818.07W 5912220.66 N 449633.90 E 12735.00 57.050 254.630 5112.11 5267.69 287.12 N 10884.22W 5912202.82 N 449567.66 E All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.074° (18-May-00) The Dogleg Severity is in Degrees per 100 feet (US). Vedical Section is from Well and calculated along an Azimuth of 272.400° (True). 13 June, 2001.14:05 Dogleg Rate (°/100rt) O.934 1.743 0.184 1.150 2.449 2.754 2.203 3.845 3.993 4.072 2.638 3.172 0.749 0.880 1.684 0.313 1.198 0.404 0.967 1.331 1.294 1.053 0.000 North Slope, Alaska Kuparuk 2N Vertical Section Comment 9157.50 9248.16 9338.32 9428.82 9525.96 9608.50 9695.88 9781.61 9865.57 9946.72 10026.03 10098.58 10178.91 10253.01 10330.23 10405.21 10480.38 10556.03 1O631.35 10706.26 10782.37 10821.37 1O886.69 Projected Survey Page 6 of 7 DrillQuest 2.00.08.005 Sperry. Sun Drilling Services Survey Report for 2N-347 MIA/D Your Ref: API-501032033700 Job No. AKMMO0049, Surveyed: 3 June, 2000 Kuparuk River Unit Based upon Minimum Curvature type calculations, at a Measured Depth of 12735.00ft., The Bottom Hole Displacement is 10888.00ft., in the Direction of 271.511° (True). North Slope, Alaska Kuparuk 2N Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 12735.00 5267.69 287.12 N 10884.22W Comment Projected Survey Survey tool program for 2N-347 MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 12735.00 5267.69 Survey Tool Description MWD Magnetic 13 June, 2001.14:05 Page 7 of 7. Dr#lQ,est 2.00.08.005 Kuparuk River Unit North Slope, Alaska Kuparuk 2N, Slot 2N-347 2N-347 Job No. AKZZ10170, Surveyed: 3 June, 2000 DEFINITIVE S UR VEY REPORT f3 June, 200f Your Ref: API-5016320337 Surface Coordinates: 59f1858.83 N, 460450.23 E (70° lO' 12.4759" N, Kelly Bushing: 155.58ft above Mean Sea Level 150°19'05.8686"W) DRiLLiNG SER:VIEES Survey Ref: sYy9562 A Halliburton Company Kuparuk River Unit Measured Depth (ft) Azim. 0.00 0.000 0.000 115.00 0.297 140.682 150.88 0.390 140.682 246.86 0.260 205.174 329.21 0.730 267.910 359.70 1.200 277.357 388.49 2.230 276.772 419.64 3.250 275.859 448.60 4.170 275.401 478.33 5.340 279.977 509.19 6.470 282.764 539.84 7.820 285.299 569.43 9.140 285.004 599.52 10.710 286.622 691.29 15.590 290.279 783.52 21.730 289.337 874.66 24.130 285.758 964.65 24.240 278.875 1058.37 28.970 276.592 1153.88 32.700 275.039 1247.65 38.230 274.065 1343.06 42.760 275.184 1437.71 46.230 274.583 1532.23 50.550 275.377 1628.03 54.940 275.485 Sub-Sea Vertical Depth Depth (ft) (ft) -155.58 0.00 -40.58 115.00 -4.70 150.88 91.28 246.86 173.62 329.20 204.11 359.69 232.89 388.47 264.00 419.58 292.90 448.48 322.53 478.11 353.22 508.80 383.63 539.21 412.90 568.48 442.54 598.12 531.88 687.46 619.22 774.80 703.15 858.73 785.26 940.84 869.04 1024.62 951.03 1106.61 1027.38 1182.96 1099.91 1255.49 1167.42 1323.00 1230.17 1385.75 1288.15 1443.73 1722.02 58.990 274.289 1339.38 1494.96 1818.11 63.100 273.616 1385.89 1541.47 1910.97 67.070 273.196 1425.00 1580.58 2005.94 70.520 269.989 1459.36 1614.94 2101.05 72.000 270.536 1489.91 1645.49 Sperry-Sun Drilling Services Survey Report for 2N-347 Your Ref: API-50f 6320337 Job No. AKZ. ZfO170, Surveyed: 3 June, 2000 North Slope, Alaska Kuparuk 2N Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 0.00 N 0.00 E 5911858.83 N 460450.23 E 0.23 S 0.19 E 5911858.60 N 460450.42 E 0.40 S 0.33 E 5911858.43 N 460450.55 E 0.85 S 0.44 E 5911857.98 N 460450.67 E 1.04 S 0.16W 5911857.80 N 460450,06 E Dogleg Vertical Rate Section (°ll00ft) 0.00 0.258 -0.20 0.258 -O.34 0.379 -O.47 O.793 0.13 Comment AK-6 BP IFR-AK -- 1.00 S 0.67W 5911857.83 N 460449.55 E 0.90 S 1.53W 5911857.94 N 460448.70 E 0.74 S 3.01W 5911858.11 N 460447.22 E 0.55 S 4.88W 5911858.30 N 460445.35 E 0.21S 7.31W 5911858.66 N 460442.92 E 1.622 0.64 3.578 1.50 3.277 2.98 3.178 4.85 4.134 7.30 0.42 N 10.42W 5911859.31N 460439.81E 1.35 N 14.12W 5911860.26 N 460436.12 E 2.49 N 18.33W 5911861,42 N 460431.91 E 3.91 N 23.32W 5911862.86 N 460426.93 E 10.63 N 43.07W 5911869.68 N 460407.22 E 3.777 10.43 4.522 14.16 4.463 18.41 5.299 23.45 5.392 43.43 20.59 N 70.83W 5911879.79 N 460379.51 E 31.24 N 104.69W 5911890.61 N 460345.71 E 39.08 N 140.65W 5911898.65 N 460309.79 E 44.66 N 182.23W 5911904.44 N 460268,24 E 49.58 N 230.92W 5911909.62 N 460219.57 E 6.665 71.54 3.044 105.76 3.134 141.99 5.163 183.74 3.993 232.59 53.87 N 285,14W 5911914.19 N 460165.38 E 58.89 N 346.87W 5911919.53 N 460103.67 E 64.53 N 412.96W 5911925.51 N 460037.61 E 70.67 N 483.34W 5911932.03 N 459967.26 E 77.89 N 559.23W 5911939.64 N 459891.41E 5.928 286.92 4.808 348.80 3.693 415.05 4.613 485.61 4.583 561.71 84.58 N 637.73W 5911946.75 N 459812.95 E 90.37 N 721.59W 5911952.97 N 459729.13 E 95.36 N 805.64W 5911958.40 N 459645.10 E 97.80 N 894.12W 5911961.30 N 459556.64 E 98.21 N 984.18W 5911962.18 N 459466.57 E 4.439 640.40 4.321 724.41 4.295 808.59 4.807 897.10 1.649 987.12 13 June, 2001 - 14:32 Page 2 of 7 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 2N-347 Your Ref: API-5016320337 Job No. AKZZ10170, Surveyed: 3 June, 2000 Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 2194.99 71.870 271.936 1519.04 1674.62 2290.47 71.880 271.329 1548.75 1704.33 2384.91 72.110 273.101 1577.94 1733.52 2479.07 71.960 272.945 1606.98 1762.56 2574.30 71.390 273.125 1636.92 1792.50 2669.26 71.810 275.562 1666.90 1822.48 2763.63 71.880 274.897 1696.31 1851.89 2859.07 71.400 274.670 1726.37 1881.95 2954.58 70,680 275.706 1757.40 1912.98 3048.13 69.960 274,013 1788.91 1944.49 1821.01 1849.78 1878.90 1908.54 1938.55 3146.00 71.740 273.228 3238.52 72.030 276.227 3332.65 71.940 275.931 3427.07 71.460 275.298 3522.17 71.760 274,099 1976.59 2005.36 2034.48 2064.12 2094.13 3617.64 72,960 273.476 1967.48 2123.06 3712.62 72.400 271.361 1995.76 2151.34 3806.79 72,320 273.234 2024.30 2179.88 3901.37 72.880 272.334 2052.58 2208.16 3996.81 73.150 270,728 2080.46 2236.04 2108.08 2124.61 2166.30 2196.50 2225.48 2255.79 2283.04 2307.84 2337.44 2363.83 4090.79 72.670 269.674 4145.94 72.460 271.658 4278.16 70.780 271.324 4372.81 72.000 270.248 4468.04 72.570 270.541 4569.98 72,830 270.990 4663.78 73.420 276.182 4751.80 73.850 276.833 4853.99 72.480 274.309 4942.49 72 820 274.498 2263.66 2280.19 2321.88 2352.08 2381.06 2411.37 2438.62 2463.42 2493.02 2519.41 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 100.14 N 1073.47W 5911964.58 N 459377.30 E 102.72 N 1164.17W 5911967.63 N 459286.61 E 106.19 N 1253.92W 5911971.58 N 459196.89 E 110.92 N 1343.36W 5911976.77 N 459107.47 E 115.70 N 1433.63W 5911982.03 N 459017.22 E 122.53 N 1523.47W 5911989.32 N 458927.42 E 130.70 N 1612.77W 5911997.96 N 458838.16 E 138.26 N 1703.04W 5912005.99 N 458747.94 E 146.43 N 1792.99W 5912014.62 N 458658.03 E 153.89 N 1880.76W 5912022.55 N 458570.30 E 159.72 N 1973.02W 5912028.86 N 458478.07 E 166.97 N 2060.64W 5912036,57 N 458390.49 E 176.45 N 2149.66W 5912046.51 N 458301.53 E 185.22 N 2238.87W 5912055.75 N 458212.36 E 192.61N 2328.81W 5912063.61 N 458122.46 E 198.62 N 2419.59W 5912070.09 N 458031.71E 202.45 N 2510.17W 5912074.40 N 457941.15 E 206.05 N 2599.84W 5912078.46 N 457851.50 E 210.43 N 2689.98W 5912083.32 N 457761.38 E 212.87 N 2781.22VV 5912086.23 N 457670.16 E 213.19 N 2871.05W 5912087.02 N 457580.33 E 213.80 N 2923.66W 5912087.90 N 457527,73 E 217.07 N 3049.09W 5912091.83 N 457402.32 E 218.29 N 3138.78W 5912093.52 N 457312.63 E 218.92 N 3229.49W 5912094.62 N 457221.93 E 220.22 N 3326,81W 5912096.43 N 457124,62 E 225.84 N 3416.36W 5912102.52 N 457035.10 E 235.41 N 3500.27W 5912112,53 N 456951.24 E 244.91 N 3597.60W 5912122.54 N 456853.95 E 251.40 N 3681.83VV 5912129.46 N 456769.77 E Dogleg Rate (°/'~OOft) 1.424 0.605 1.801 0.224 0.625 2.475 0.673 0.551 1.273 1.870 1.970 3.096 0.314 0.815 1.237 1.403 2.206 1.897 1.084 1.634 1.187 3.453 1.293 1.680 0.666 0.492 5.334 0.862 2,718 0.435 North Slope, Alaska Kuparuk 2N Vertical Section Comment 1076.42 1167.16 1256.97 1346.52 1436.91 1526.94 1616.48 1706.96 1797.16 1885.13 1977.55 2065.38 2154.68 2244.16 2334.3O 2425.24 2515.91 2605.65 2695.89 2787.16 2876.94 2929.53 3055.O0 3144.67 3235.35 3332.65 3422.34 3506.55 3604.16 3688.57 13 June, 2001 - 14:32 Page 3 of 7 DrillQuest 2.~0.08.005 Sperry-Sun Drilling Services Survey Report for 2N-347 Your Ref: API-5016320337 Job No. AKZZI0170, Surveyed: 3 June, 2000 Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Vertical Depth Depth (ft) (ft) 5036.64 73.270 274.221 2391.29 2546.87 5132.09 71.800 272.696 2419.93 2575.51 5225.87 7t.600 272.318 2449.38 2604.96 5323.28 72.300 271.793 2479.56 2635.14 5418.52 72.660 271.982 2508.23 2663.81 5510.05 71.060 271.171 2536.73 2692.31 5605.18 71.200 271.450 2567.50 2723.08 5706.40 71.780 271.034 2599.63 2755.21 5801.36 72.810 271.534 2628.51 2784.09 5896.13 72.090 271.512 2657.09 2812.67 5991.25 73.010 270.794 2685.61 2841.19 6085.71 72.380 273.025 2713.71 2869.29 6173.80 73.160 273.433 2739.80 2895.38 6275,71 72.000 273.584 2770.31 2925.89 6370.48 72,890 274.261 2798.90 2954.48 6465,08 72,550 273.286 2827.00 2982.58 6557.22 70.690 273,519 2856.05 3011.63 6654.12 71.030 271.863 2887.82 3043.40 6749.13 72.140 272,050 2917.84 3073.42 6836.70 72.950 271,938 2944.10 3099.68 6938.22 72,760 273.391 2974.03 3129.61 7027.18 70.900 272.768 3001.77 3157.35 7120,56 71.170 271,950 3032.12 3187.70 7215.52 71.920 272.133 3062.18 3217.76 7310.45 72,420 271.442 3091.25 3246.83 7405.37 71.380 273.118 7499.96 71,360 274.324 7594.22 72,020 273,896 7689.10 72.740 274.262 7783.67 73.200 273.183 3120.74 3276.32 3150.96 3306.54 3180.57 3336.15 3209.29 3364.87 3236.99 3392.57 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 258.24 N 3771.62W 5912136.78 N 456680.01 E 263.74 N 3862.50W 5912142.75 N 456589.16 E 267.63 N 3951.45W 5912147.11 N 456500.23 E 270.96 N 4044.01W 5912150.92 N 456407.69 E 273.95 N 4134.78W 5912154.38 N 456316.94 E 276.34 N 4221.73W 5912157.23 N 456230.01 E 278.40 N 4311.72W 5912159.76 N 456140.02 E 280.48 N 4407.68W 5912162.34 N 456044.08 E 282.51 N 4498.12W 5912164.84 N 455953.65 E 284.91 N 4588.44W 5912167.72 N 455863.34 E 286.73 N 4679.17W 5912170.01N 455772.62 E 289.74 N 4769.29W 5912173.49 N 455682.51 E 294.48 N 4853.30W 5912178.67 N 455598.54 E 300.43 N 4950.35W 5912185.12 N 455501.52 E 306.61N 5040.49W 5912191.78 N 455411.41 E 312.55 N 5130.62W 5912198.19 N 455321.31 E 317.74 N 5217.91W 5912203.84 N 455234.06E 322.04 N 5309.35W 5912208.61N 455142.64 E 325.12 N 5399.44W 5912212.16 N 455052.57 E 328.02 N 5482.92VV 5912215.50 N 454969.10 E 332.53 N 5579.82W 5912220.52 N 454872.22 E 337.07 N 5664.22W 5912225.50 N 454787.85 E 340.71N 5752.46W 5912229.59 N 454699.63 E 343.92 N 5842.47W 5912233.27 N 454609.63 E 346.73 N 5932.80W 5912236.56 N 454519.32 E 350,32 N 6022.95W 5912240.62 N 454429.20 E 356.14 N 6112.39W 5912246.90 N 454339.79 E 362.55 N 6201.65W 5912253.78 N 454250.56 E 368.98 N 6291.84W 5912260.69 N 454160.40 E 374.85 N 6382.08W 5912267.03 N 454070.20 E Dogleg Rate (°ll00ft) 0.555 2.166 O.438 0.883 0,422 1.940 0.314 0.693 1.195 0.760 1,206 2.352 0.990 1.147 1,160 1,047 2.033 1.652 1.183 0.933 1.380 2.194 0.878 0.811 0.870 2.004 1.208 0.822 0.843 1.194 North Slope, Alaska Kuparuk 2N Vertical Section Comment 3778.56 3869.58 3958.61 4051.22 4142.05 4229.02 4319.03 4415.00 4505.45 4595.81 4686.53 4776.71 4860.83 4958.03 5048.34 5138.63 522605 5317.58 5407.73 5491.26 5588.26 5672.77 576t.08 5851.16 5941.52 6031.74 612t.34 6210.77 6301.14 6391,53 13 June, 2001- 14:32 Page 4 of 7 Dr#lQ.est 2.~(~.08.005 Sperry-Sun Drilling Services Survey Report for 2N-347 Your Ref: API-5016320337 Job No. AKZZ10170, Surveyed: 3 June, 2000 Kuparuk River Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 7878.23 72.300 273.141 3265.03 3420.61 7972.87 69.930 272.869 3295.66 3451.24 806807 69.620 271.833 3328.57 3484.15 8170.37 70.700 271.018 3363.29 3518.87 8258.75 71.800 271.231 3391.70 3547.28 8359.81 72.780 272.090 3422.44 3578.02 8447.09 73.710 271.810 3447.60 3603.18 8541.66 72.790 271.820 3474.86 3630.44 8636.23 72.620 271.399 3502.97 3658.55 8731.01 71.110 272.949 3532.47 3688.05 8826.13 70.810 272.798 3563.50 3719.08 8920.80 71.450 272.918 3594.12 3749.70 9015.90 72.410 273.572 3623.62 3779.20 9110.55 73.140 273.213 3651.65 3807.23 9212.34 74.140 272.991 3680.32 3835.90 9306.99 73.080 273.182 3707.03 3862.61 9401.78 73.810 272.282 3734.04 3889.62 9496.97 73.060 272.498 3761.17 3916.75 9592.05 73.360 273.320 3788.64 3944.22 9687.04 70.700 272.550 3817.94 3973.52 9782.48 70.770 271.664 3849.43 4005.01 9877.00 70.930 271.991 3880.44 4036.02 9964.55 70.360 273.936 3909.46 4065.04 10059.05 70.510 273.614 3941.10 4096.68 10154.30 70.920 273.930 3972.56 4128.14 10229.85 71.430 272.963 3996.94 4152.52 10318.55 72.090 273.217 4024.70 4180.28 10405.84 72.860 273.172 4050.99 4206.57 10501.31 73.650 273.123 4078.49 4234.07 10595.99 74.450 273.391 4104.51 4260.09 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 379.83 N 6472.24W 5912272.48 N 453980.06 E 384.53 N 6561.66W 5912277.64 N 453890.67 E 388.20 N 6650.91W 5912281.78 N 453801.44 E 390.59 N 6747.11W 5912284.67 N 453705.25 E 392.23 N 6830.78W 5912286.75 N 453621.59 E 395.02 N 6927.01W 5912290.05 N 453525.38 E 397.86 N 7010.53W 5912293.33 N 453441.87 E 400.73 N 7101.05W 5912296.67 N 453351.38 E 403.27 N 7191.30W 5912299.67 N 453261.13 E 406.68 N 7281.30W 5912303.56 N 453171.15 E 411.19 N 7371.11W 5912308.53 N 453081.37 E 415.66 N 7460.58W 5912313.47 N 452991.93 E 420.77 N 7550.84W 5912319.06 N 452901.69 E 426.12 N 7641.09W 5912324.88 N 452811.47 E 431.41N 7738.61W 5912330.67 N 452713.98 E 436.30 N 7829.28W 5912336.03 N 452623.34 E 440.62 N 7920.04W 5912340.84 N 452532.60 E 444.43 N 8011.20W 5912345.12 N 452441.47 E 449.05 N 8102.10W 5912350.21 N 452350.58 E 453.68 N 8192.33W 5912355.32 N 452260.38 E 456.99 N 8282.37W 5912359.10 N 452170.36 E 459.84 N 8371.61W 5912362.41N 452081.14 E 464.11N 8454.10W 5912367.11N 451998.67 E 469.97 N 8542.95W 5912373.44 N 451909.85 E 475.89 N 8632.66W 5912379.82 N 451820.18 E 480.18 N 8704.04W 5912384.49 N 451748.82 E 484.72 N 8788.16W 5912389.47 N 451664.73 E 489.36 N 8871.26W 5912394.55 N 451581.64 E 494.38 N 8962.55VV 5912400.04 N 451490.39 E 499.55 N 9053.43W 5912405.69 N 451399.53 E Dogleg Rate (°/100ft) 0.953 2.519 1.072 1.295 1.265 1.264 1.109 0.973 0.461 2.226 0.350 0.687 1.203 0.852 1.004 1.137 1.192 0.817 0.886 2.904 0.880 0.369 2.195 0.358 0.532 1.387 0.792 0.883 0.829 0.888 North Slope, Alaska Kuparuk 2N Vertical Section Comment 6481.82 6571.35 6660.67 6756.89 684O.57 6936.83 7020.41 7110.96 7201.25 7291.32 7381.23 7470.80 7561.19 7651.57 7749.22 7840.01 7930.87 8022.10 8113.12 8203.46 8293.55 8382.84 8465.43 8554.43 8644.30 8715.79 8800.02 8883.24 8974.65 9065.66 13 June, 2001 - 14:32 Page 5 of 7 Dr#lQ,est 2.~0.08.005 Sperry-Sun Drilling Services Survey Report for 2N-347 Your Reft API-5016320337 Job No. AKZZ10170, Surveyed: 3 June, 2000 Kuparuk River Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 10690.71 73.640 273.020 4130.55 4286.13 504.65 N 9144.36 W 5912411.26 N 451308.63 E 10785.55 72.240 272.096 4158.37 4313.95 508.69 N 9234.94 W 5912415.78 N 451218.08 E 10880.20 72.340 271.941 4187.16 4342.74 511.87 N 9325.04 W 5912419.42 N 451127.99 E 10975.05 72.850 270.951 4215.54 4371.12 514.15 N 9415.52 W 5912422.18 N 451037.52 E 11077.26 71.190 268.970 4247.09 4402.67 514.09 N 9512.73 W 5912422.63 N 450940.32 E 11165.26 68.800 268.532 4277.19 4432.77 512.29 N 9595.39 W 5912421.26 N 450857.64 E 11259.84 66.860 267.721 4312.88 4468.46 509.44 N 9682.93 W 5912418.86 N 450770.09 E 11354.64 63.760 265.631 4352.48 4508.06 504.46 N 9768.90 VV 5912414.34 N 450684.10 E 11450.52 60.310 263.725 4397.44 4553.02 496.63 N 9853.21 W 5912406.95 N 450599.75 E 11546.57 58.040 260.013 4446.66 4602.24 485.00 N 9934.84 W 5912395.74 N 450518.06 E 11642.83 57.890 257.035 4497.73 4653.31 468.77 N 10014.79 W 5912379.93 N 450438.02 E 11733.11 55.770 254,714 4547.13 4702.71 450.35 N 10088.07 VV 5912361.89 N 450364.65 E 11835.05 55.970 253,857 4604,32 4759.90 427.49 N 10169.30 W 5912339.46 N 450283.31 E 11928.71 56.780 254.036 4656.19 4811.77 405.93 N 10244.24 W 5912318.29 N 450208.25 E 12026.73 55.130 254.073 4711.06 4866.64 383.61 N 10322.33 W 5912296.38 N 450130.04 E 12122.98 55.070 253.710 4766.13 4921.71 361.71 N 10398.17 W 5912274.88 N 450054.09 E 12219.03 55.430 255.019 4820.88 4976.46 340.44 N 10474.17 W 5912254.01 N 449977.98 E 12315.24 55.130 255.350 4875.68 5031.26 320,22 N 10550.62 W 5912234.19 N 449901.43 E 12411.73 54.250 254.943 4931.45 5087.03 300.04 N 10626.73 W 5912214.40 N 449825.21 E 12507,88 55.350 254.143 4986.87 5142.45 279.10 N 10702.45 W 5912193.85 N 449749.38 E 12604.34 56.560 254.519 5040.88 5196.46 257.51 N 10779.41 W 5912172,67 N 449672.32 E 12653.25 57.050 254.331 5067.65 5223.23 246.52 N 10818.83 W 5912161.89 N 449632.83 E 12735.00 57.050 254.331 5112.12 5267,70 228.00 N 10884.88 W 5912143.71 N 449566.69 E All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Magnetic Declination at Surface is 26.073° (18-May-00) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 272.101° (True). Dogleg Rate (°ll00ft) 0.934 1.746 0.188 1.132 2.456 2.756 2.200 3.835 4.004 4.074 2.626 3.185 0.723 0.879 1.684 0.315 1.181 0.421 0.975 1.331 1.295 1.053 0.000 North Slope, Alaska Kuparuk 2N Vertical Section Comment 9156.72 9247.38 9337.54 9428.04 9525.18 9607.73 9695.10 9780.83 9864.79 9945.94 10025.25 10O97.80 10178.13 10252.24 10329.46 10404.45 10479.61 10555.27 10630.59 10705.49 10781.60 10820.60 1O885.93 Projected survey 13 June, 2001 - 14:32 Page 6 of 7 DrillQuest 2.00.08,005 Sperry-Sun Drilling Services Survey Report for 2N-347 Your Ref: API-5016320337 Job No. AKZZlOf70, Surveyed: 3 June, 2000 Kuparuk River Unit Based upon Minimum Curvature type calculations, at a Measured Depth of 12735.00ft., The Bottom Hole Displacement is 10887.27fl., in the Direction of 271.200° (True). North Slope, Alaska Kuparuk 2N Comments Measured Station Coordinates Depth TVD Northings Eastings (rt) (ft) (ft) (ft) 12735.00 5267.70 228.00 N 10884.88W Comment Pr~ected suwey Survey tool program for 2N.347 From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 Survey Tool Description 12735.00 5267.70 AK-6 BP IFR-AK 13 June, 2001 - 14:32 Page 7 of 7 DriliQuest 2.00.08.005 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount, Commissioner THRU: Blair Wondzell, P. I. Supervisor DATE: July 20, 2000 FROM: John Crisp,' ~,~ C,, SUBJECT: Petroleum Irf~pector Safety Valve Tests Kuparuk River Unit Tarn Field 2N & 2L Pads July 20, 2000: I traveled to Phillips Alaska's Kuparuk River Unit Tarn Field to witness the semi-annual Safety Valve System tests on Pads 2N & 2L. Testing went well with only one failure on 2L Pad witnessed. No failures were witnessed on 2N Pad. The AOGCC test report is attached for reference. SUMMARY: I witnessed the semi-annual SVS tests on KRU's Tarn Pads 2N & 2L. 2N Pad, 9 wells, 18 components tested. No failures. 2L Pad, 6 wells, 12 components tested. 1 failure. 8% failure rate. Attachments: SVS Tarn KRU 2N & 2L 7-20-00jc cc; NON-CONFIDENTIAL SVS Tam KRU 2N & 2L 7-20-00jc.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Inc Submitted By: John Crisp Date: 7/20/00 Operator Rep: Emie Bamdt Field/Unit/Pad: Tarn, Kuparuk River, 2N AOGCC Rep: John Crisp Separator psi: LPS 94 HPS Well Permit Separ Set L/P Test Test Test Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code GAS or CYCLE 2N-307 1990170 2N-308 1990100 94 70 65 P P OIL 2N-309 1990210 2N-313 1980910 94 70 70 P P OIL 2N-315 1981900 2N-317 1981430 94 70 70 P P OIL 2N-319 1981970 2N-320 1990010, 94 70 65 P P OIL 2N-321A 1981730 2N-323 1980710! 94 70 70 P P OIL 2N-325 1981630i 2N-329 1980670 94 70 70 P P OIL ,2N-331 1981170 2N-335 1982040 94 70 70 P P OIL 2N-337A 1981220 2N-339 1981000 2N-341 1981030 94 70 65 P P OIL 2N-343 1980920 2N-345 1981130 ~~!~-~2000630 94 70 60 P P OIL Wells: 9 Components: 18 Failures: 0 Failure Rate: 0.0% [] 90 Day Remarks: 7/27/00 Page 1 of 1 SVS Tam KRU 2N 7-20-00jc.xls 7/18/00 Obi o~,% Schlumberger NO. 347 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk Color Well Job # Log Description Date BL Sepia Print 1Q-11 ~ ! ¢,... INJECTION PROFILE 000709 I 1 2V-09 PRODUCTION PROFILE 000708 I 1 2V-14 LEAK DETECTION LOG 000710 I 1 30-14 INJECTION PROFILE 000711 I 1 2N-347 20265 SCMT 000607 1 ..... ,,,, R['CF, trn · IVLL/ JUL 1 9 2000 SIGNE DATE: 'n Uin~ne~co~y Naska 0il & Gas C0ns. C0mmissi0n Anchorage Please sign a d ret of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Thank you. Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Inc Operator Rep: Emie Bamdt AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: Tam, Kuparuk River, 2L Separator psi: LPS 94 HPS 7/20/00 Well Permit Separ Set L/P Test Test Test Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code GAS or CYCLE 2L-305 1982400 94 70 60 P 4 OIL 2L-307 1982560 94 70 70 P P OIL 2L-313 1982190 94 70 65 P P OIL 2L-315 1982180 94 70 70 P P OIL 2L-321 1982620 2L-323 1982510 2L-325 1982090 94 70 65 P P OIL 2L-329A 1982250 800 700 700 P P GAS Wells: 6 Components: 12 Failures: 1 Failure Rate: 8.0% [D 90 Day Remarks: 7/27/00 Page 1 of 1 SVS Tarn KRU 2L 7-20-00jc.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Other _X Change approved program _ Pull tubing _ Variance _ Perforate _ Annular Injection 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 35 feet .. 3. Address Exploratory__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service Kuparuk River Unit 4. Location of well at surface 8. Well number 151' FNL, 1143' FEL, Sec. 3, T9N, R7E, UM (ASP: 460450, 5911859) 2N-347 .. At top of productive interval 9. Permit number / approval number 230' FSL, 1076' FEL, Sec. 32, T10N, R7E, UM (ASP:449958, 5912302) 200-063 At effective depth 10. APl number 50-103-20337-00 At total depth 11. Field / Pool 124' FSL, 1466' FEL, Sec. 32, T1 ON, R7E, UM (ASP: 449568, 5912203) Kuparuk River Field/Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 12735 feet Plugs (measured) true vertical 5268 feet Effective depth: measured 12604 feet Junk (measured) true vertical 5196 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 80' 16" 9 cu. Yds High Early 1 15' 1 15' Surface 4175' 7.625" 410 sx AS III LW, 240 sx Class G 4210' 2300' Intermediate 1 1881' 5.5" X 105 sx Class G & 1 1 916' 4805' Production 808' 3.5" 248 sx Class G 12724' 5262' Perforation depth: measured 12352'-12382' MD j~"t~, ~.~ ~.~,~, L, ~ ~ ~,,~ true vertical 5052'-5070' TVDORIGINAL Tubing (size, grade, and measured depth 3.5", 9.3#, L-80 @ 11910' Alaska0il & Gas Cons. Commission Anchor~je Packers & SSSV (type & measured depth) Casing Seal Receptacle @ 11896' MD / 4794' TVD, No SSSV 13. Attachments Description summary of proposal ~ Detailed operations program ~ BOP sketch __ LOT test, surface cement details and casing detail sheets, schematic ~X 14. Estimated date for commencing operation 15. Status of well classification as: July 26, 2000 16. If proposal was verbally approved Oil __X Gas__ Suspended __ Name of approver Date approved Service __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Tom Brassfield 265-6377 Signed Ok ,~,4,4-3~ _ ~-r,~,~-~~ Title: Drilling Engineering Supervisor Date t, ~ ~r,.,~ ~"~__*"1 James Trantharn Prepared b~/ Sharon AIIsup-Drake FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval no. Plug integrity __ BOP Test__ Location clearance_ Mechanical Integrity Test __ Subsequent form required 10- ...~iRiGINAL SIGNED BY i~-"'¢,,,~-~.~ ~ " -"/'~/)~,c,, r~ ,.~ammissioner Date Approved by order of the Commission ~r.~..,.,,. o Form 10 403 Rev 06/15/88 SUBMIT IN TRIPLICATE CASING TEST and FORMATION INTEGRITY TEST Well Name: 2N-347 Date: 5/24/00 Reasoms~ for test: Supervisor: R.W. SPRINGER [] nitial Casing Shoe Test [] Formation Adequacy for Annular Injechon [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 7-5/8% 29.7#, L-80 BTC MOD Casing Setting Depth: 4,210' TMD 2,303' TVD Mud Weight: 9.5 ppg Hole Depth: 4,240' TMD 2,309' TVD Length of Open Hole Section: 30' EMW = _eak-off Press. + Mud Weight 0.052 x TVD = 800 psi + 9.5 ppg 0.052 x 2 309' EMW for open hole section = 16.2 ppg Pumc output = 0.1010 bps Fluid Pumped = 0,8 bbl LEAK-OFF TEST I '"'~" CASING TEST I TiME LINE J STROKES NOTE: STROKES TURN TO M NUTES DURING "SHUT IN TIME":soe time line above LEAK-OFF DATA CASING TEST DATA 0 stks 0 psi i 0 stks ~ 0 ps~ i 6stks 520 psi i ................... .6___s.t .k.s' ...... .f~__p..s~ 8 stks 800 psi ~ 8 stks 750 psi 10 stks 900 psi¢~ ................................................... ': ,- ............... ................................................... SHUT IN TIME SHUT IN PRESSURE 0.0 rain 800 psi .................. .2_!__s_t._k.s___. _.2_:9. _O.O__.P_.S! _. SHUT IN TIME ~ SHUT IN PRESSURE 0.0 min ' ' I 2,000 ps~ 1.0 min ' I 2,000 ........................... 2.0 rain : 2,000 .... __4_..o__[?_ ................... ...4.z?..~!.n' ..................... _7_ _5. _0_ _e_s_ ] ...... _8:_0_ _ ~_i.n. .................... _ __5_ z.O_..m_ !_n' ...................... Z.5..O...p.s. j ....... _~:_0_ __m. _i.n_ ..................... .... _6_:_o___m_j?_ ...................... Z~.P~! ........ J_9:-°-_-mJ ?- ..................... ,__.~_o___m_?_ ..................... .7..2_s_e~] ..... .2.9:.o._?.~!n' ................. i___2_:_o_9_O_p?_!__ 9.0 rain 725 p.s.i 25.0 min i 2,000 psi NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: 2N-347 Ann LOT Date 6/9 Rev 6122 [] Initial Casing Shoe Test Reason(st for test: ~ Formation Adequacy for Annular Injection ~ Deep Test: Open Hole Adequacy for Higher Mud We~gm Casing Size and Description: 7-5/8 X 5-1/2" Casing Setting Depth: 4,210' TMD 2,303' TVD Mud Weigi~t: 9.5 ppg Sueervisor: R.W. SPRINGER Hole Depth: Length of Open Hole Section: 4,210' TMD ' D 2,303 TV 0~ EMW = Leak-off Press. + Mud Weight = 460 psi + 9.5 ppg 0.052 x TVD o.o52 x 2.303' EMW for open hole section = 13.3 ppg ~ump ou[put = 0.0580 bps =luid Pumped = 2.4 bbl STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time ine aoove LEAK-OFF DATA CASING TEST DATA MINUTES MINUTES FOR FOR LOT SMOKES PRESSURE CSG TEST STROKES PRESSURE ..................... .o_.s_t~ ......... .o.?! .......................... .o___s.t__~.s_ ......... .o__.p_?! 9 stks 190 psi 10 stks 200 psi 11 stks 210 psi 12 stkS 220 psi · 13 stks 230 psi 14 stks 250 psi 16 stks 275 psi .................... 22stks , 340 psi 24 stks 360 psi .................... .2_~_.s__t.k_.s___. ___.~_ Z E e?j .... .................... ~fLsj. k_.s___..__.4_.o_q. _p.s_! .... .................... .3_O_.s_t,k~__ __4_2_~___p.s_ j .... .................... ~2_.s__t.k_.s_...._.4.~9.,.P. sj .... 34 stks 450 psi ..................... ~e_.s__t.~_.s___,_ __.4_EO_. P?J .................... ~Es._t.~_.s___..__.4_.E?.sj , 42 stks 460 psi ..s_H.u_TJ~ ~?~ ............... .s_ _H.U_I_~.N_.P_ ?.E ~s.s. u_ .EE 0.0 min 460 psi .I:~_m!E ...................... .~_~O_.e. sJ .... ._2.:R .mj~- ...................... .3_4..o., .p.?! .... ___.3.:0. m!.n. ...................... .~_.4_0_..psj ___4_:0_ r0jn_ ...................... ~.~.o_.e.s_j .... ___ ~_:o_m.~. ....................... .~_~.o_. _psj .... 7.0 Illin 330 psi , 8.0 mln 325 psi ..................... ~..s.t..k.s. ....... ._5.2_.E_R_s_~ .... ..................... .8_._s_t._ks_ ....... 10 stks 900 Psi .................... ::::::::::::::::::::::::::::::::::::::::::::::: ..................... .!~.~s~t.~.E.. .................... .1.8_. _s~tk_s._ .................... .2_.o_ .s_t.k.,s._ .................... .2j_.¢.~.s__ _2_,~_o.o_.p_.s_L' 0 0 m n : ~ 2,000 DSI ' ...... ' ........... ! ............... ! ............... 1.0 nlin ~ 2 000 p~'~ 2.0 mm 2,000 3,0 min [ 2,000 psi 4.0 mln : 2 000 psi 5.0 min i 2,000 psi .... _e:o__mj~. ................... ?.:_o__o_o__p__S_L~ 8.0 min 2,000 psi .... ~:~_~ ................... ................. 2,000 psi 15.0 min : 2,000 ps~ 2,000 psi , .__°~_~Ln..:_%~:z ;:,:i ............... ' = 9.0min 325.a, ............... 10.0 mm 325 psi ~ 30.0 m~n , 2,000 ps~ , NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY Phillips Alaska Drilling Cementing Details Well Name: 2N-347 Report Date: 05/23/2000 Report Number: 7 Rig Name: Nabors 19E AFC No.: AK0054 Field: TARN Centralizers State type used, intervals covered and spacing Comments: BOW TYPE, JTS 1-12, EVERY 3RD JTTO SURFACE. 41 TOTAL Mud Weight: PV(prior cond): PV(after cond): YP(prior cond): YP(after cond): Comments: 10.2 25 15 VIS 47 AFTER CONDITIONING. Gels before: Gels after: Total Volume Circulated: 4/7 3+ HOLE VOLUMES i Wash 0 Type: Volume: Weight: Comments: ARCO Wash 20 8.34 Spacer 0 Type: Volume: Weight: Comments: ARCO Spacer 40 10.2 Lead Cement 0 Type: Mix wtr temp: No. of Sacks: Weight: Yield: Comments: AS III LW 75 410 10.7 4.44 Additives: G W/50%D124, 9%D44, .4%D46, 30%D53, 1.5%S1, 1.5%D79 Tail Cement 0 Type: ' Mixwtrtemp: ' No. ofSacks: ' Weight: Yield: Comments: GI I 175 240 15.8 1.17 Additives: G + 1%S1, .2%D46, .3%D65 Displacement 0 Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: Comments: 6-7 4 125 DISPLACED W/MUD W/RIG. Reciprocation length: Reciprocation speed: Str. Wt. Down: 15 1/MINUTE 55 Theoretical Displacement: Actual Displacement: Str, Wt. in mud: 189 BBL 191 BBL Calculated top of cement: CP: Bumped plug: Floats held: GOOD CEMENT TO SURFACE- 30 BBL EXCESS, Date:5/23/00 NO YES NO BROACHING. Time:0200 Remarks: Cement Company: Rig Contractor: I Approved By: Dowell NABORS I R.W. SPRINGER PHILLIPS Alaska, Inc. Casing Detail 7-5/8" surface casing WELL: 2N-347 DATE: 5/22/00 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Nabors 19E RT to GL = 34.50' TOPS Above RKB 4,54 !7 5/8" Landing Joint (38,97 total) 34.50 4.54 7 5/8" FMC GEN IV FLUTED MANDREL HANGER 2.45 39.04 jts.78-101 7 5/8", 29.7#, L-80 BTC-MOD 982.41 41.49 !Tam Port Collar 2.47 1023.90 jts 3-77 7 5/8", 29.7#, L-80 BTC-MOD 3096.50 1026.37 Gemeco Float Collar 1.34 4122.87 jts 1-2 7 5/8", 29.7#, L-80 BTC-MOD 85.05 4124.21 Gemeco Float Shoe 1.50 4209.26 BTM OF SHOE @ ..... >>>>> 4210,76 TD of 9 7/8" hole = 4220'MD 41 TOTAL, Gemeco Bow Spring Centralizers 3, Centralizers in center of jts. 2, 77 and 78 over stop collars 98 ,Centralizers over collars of jts. 1, 3-12, 15, 18, 21, 24, 27, 30, 33 36, 39, 42, 45, 48, 51,54, 57, 60, 63, 66, 69, 72, 75,81,84, 87, 90, 93 96 ~,. Ali:,~ RemarRs: String ~eig~ts ~it~ BlooRs: 125R Up, 55R Dn, 18R BIocRs. Ran 1~1 )oints of aasing. Dri~ed aa~ing xit~ 6.7~" plastic ra~it, gsed Best-o-LiFe 2~ t~read compound on all connections. T~ree joJnts surplus inoluding one jr t~at did not PHILLIPS ALASKA INC CASING TALLY PAGE' 1 of 2 WELL: 2N-347 Kuparuk Unit RIG: Nabors 19E TUBING DESCRIPTION: 7 5/8", 29,7#, L-80, BTC-M DATE: 5/22/00 Column 1 Column 2 Column 3 Column 4 Column 5 Column 6 Column 7 Column 8 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 1 41.77 26 42,57 51 40,12 76 43.53 101 42,18 126 151 176 2 43,28 27 40.64 52 42.58 77 42.07 102 ~iiiiiili~Ei~i~ii?~ii 127 152 177 3 42,65 28 4].27 53 42,6] 78 39.38 153 178 4 42,60 29 42.68 54 42.64 79 4].56 104 129 154 179 5 39.08 30 4].87 55 4].35 80 33.69 105 130 155 180 6 40.92 31 37.55 56 42.62 81 42,32 106 131 156 181 7 42,62 32 42.58 57 38.66 82 35,46 107 132 157 182 8 42.]4 33 37,72 58 40.48 83 40,78 108 133 158 183 9 40,36 34 42.39 59 39,78 84 42.62 109 134 159 184 10 40,24 35 38,43 60 41.60 85 41.42 110 135 160 185 11 41,60 36 42,45 61 34.82 86 42,14 111 136 161 186 12 42,57 37 42.56 62 37.97 87 41.47 112 137 162 187 13 40.48 38 42.32 63 42,53 88 41.56 113 138 163 188 14 41.24 39 40.77 64 42,09 89 41.49 114 139 164 189 15 41.62 40 42.64 65 42.57 90 42.48 115 140' 165 190 16 39.08 41 43.1] 66 40.38 91 4].27 116 141 166i 191 17 40.89 42 42.65 67 40.92 92 42,61 117 142 167 192 18 42.65 43 42.64 68 42.62 93 41.79 118 143 168 193 19 42.17 44 40.94 69 42,54 94 41.30 119 144 169 194 20 39.39 45 42.49 70 42,66 95 42.42 120 145 170 195 21 42,45 46 42.27 71 38,66 96 42.61 121 146 171 196 22 39.10 47 38.87 72 40.18 97 41.81 122 147 172 197 23 39,83 48 42.57 73 42.35 98 39,81 123: 148 173 198 24 41,49 49 42.63 74 42.55 99 39,57 124 149 174 199 25 42,64 50 41,77 75 39,43 100 40,67 125 150 175 200 Tot 1032.86 Tot 1038.38 Tot 1024.71 Tot 1025.83 Tot 121.01 Tot Tot Tot TOTAL LENGTH THIS PAGE = 4242.79 TOTAL JOINTS THIS PAGE = 103 !DIRECTIONS: Float Shoe = 1,50 Float Collar = 1.32 Stage Collar = 2,50 Fluted Hanger = 1.32 PHILLIPS ALASKA INC CASING TALLY PAGE: 2 of 2 WELL NUMBER: Kuparuk Unit RIG: Nabors 19E TUBING DESCRIPTION: 7 5/8", 29.7#, L-80, BTC-M DATE: 5/22/00 Column9 Column 10 Column 11 Column 12 Column 13 Column 14 Column 15 Column 16 No Feet No Feet No Feet No Feet No Feet No Feet No Feet No Feet 201 226 251 276 301~ 326 351 376 202 227 252 277 302 327 352 377 203 228 253 ~278 303 328 353 378' 204 229 254 279 304 329 354 379 205 230 255 280 305 330 355 380 206 23' 256 281 306 331 i356 38' 207 232 257 282 307 332 357 382 208 ~233 258 283 308 333 358 383 209: 234 259 284 ,309 334i 359 384 210 235 260 285 310 335~ 360 385 211 236 261 286 311 336 361 386 212 237 262 287 312 337 362 387 213 238 263 288 313 338 363 ~388 214 239 264 289 314 339 364 389 215 240 265 290 315 340 365 390 216 241 ~266 291 316 341 366 391 217 242 267 292 317 342 367 392 218 243 268 293 318 343 368 393 219 244 269 294 319 344 369 394 220 245 270 295 320 '345 370 395 221 246 271 296 321 346 371 396 222 247 272 297 322 347 372 397 223 248 273 298 323 348 373 398 224 249 274, 299 324 349 1374 399 225 !250 275 300 325 350 375 400 Tot Tot Tot Tot Tot Tot Tot Tot TOTAL LENGTH THIS PAGE = TOTAL LENGTH = 4242.79 TOTAL JOINTS THIS PAGE = TOTAL JOINTS -- 103 Average Jt = 41.19 DIRECTIONS: CASING TEST and FORMATION INTEGRITY TEST Well Name: 2N-347 Ann LOT Date: 6/9 Rev 6/22 [~] Initia] Casing Shoe Test Reason(s} for test: I~] Formation Adequacy for Annular Injection [] Deep Test: O13en Hole Adequacy for Higher Mud Weight Casing Siza a~d Oescdplion: 7-5/8 X ,.w. s,,,,G,, LEAK-OFF DATA LOT STROKE;~ ~ Oslks 0 psi Hole Oe~: 4,210' mO v~ X~~: 2,303' WD LenCh of Open H~e So,ion: ~-~ ti ..... ~, t2 st~ ..........22Oosi ;_.____.. -- - ...- ~q -- 13st~ 230psi : = 4~ p;i + 9.5 ~ ; ..... ........ 0.052 x 2.303' Casing Setting Depth: 4,210' TMD 2,303' TVD Mud Weight: 9.5 ppg EMW = Leak-off Press. + Mud We~ht 0.O52 x 'I'VD EMW for open hole section = 13.3 ppg Pump output = 0.051~ bps Fluid Pumped = 2.4 ~,-e.. LEAK-OFF lEST / ~ · . , J ',,'~-C~NG ESI ....... LOT SHUT IN TIME _ , t -- -~ CAGING TEST SHUT tN TIME -- ~ ~ME UNE 1 ·, [ ....... .~;..:~.: .:j.&?:: :~':::: ::: ::; -, -1-- - ~' ~ I~ME UNE --- -- ::. NOTE: STROKES TURN TO M1NUTES DURING "SHUT tN TIME":see time line above ~ 14 stks 250 psi : 15 stk$ [. 260 psi .] .[ ........... .... = ................. 1- ..... i 20 st~ 320 ps~ , ~ 22 st~ 340-~si = i : 24 ~ 36~ ~i .... L. ~---~ ............ ; 26 stks 375 ~i ; ........... ;~ - .......... CASING TEST OATA CSG TESf' ~TROKES PRESSURE 0 stks i ..... .O._~.s_~i 6 st~ 525 psi .... 12 stks 1,100 p~= 14 ~tks 1,250 ~ 16 stks 1,475 ~i ~ ..... ~ .......~... 18stks : 1,700~i : ~ 20~ks , 1,g4Opsi: ..................... ~ ........ i ....................... , ....... 32 stks 430 _p_s!...j ..... ----~---,,-~ 34 elks 450 psi .... ,.f-, .................. .% : 36 stks 45o P.?L-~ 40 stks 460 psi F-- ........ 42 stks ; 460 psi-- i I -- SHLi1'lN TIME ' SMUT IN PRESSURE 0.0rain ~ 460os~ , 1.0rain i ' 340 pst · , : ! .... :-"! 3.0 rain ; 340 psi _j -- .... ~,. ,,,..=..=...~ s.o ni, i [ 330 p,.i...! ~ O' rain f ; 330 psi 7.0 mm [ : .3_3o ~ ,"-~~'"~'-- ' "T .... ' ' ' 325 S~ a._._20 m,._ n__n .,, ......... ,___..p:'~._~ 9.0 rnin ; ;_ . 325P_~_.j 10.0 rain ' 325 psi 28 stks 400 psi , 30 sties 420 psi : I "-SHUT IN TIME SMUT IN PRE$SUR~ .......... -~. ........... ~ ............. -,--~ '"' 0 -,in ~ . 2,000 D, Sl ~, i i~ . ._:.:.;.__.~ ......... -_--£--?~ :;:-~, ~nmin I z,uuupsl: p ~3 mm ', 2,000 ps~ ...... ...---i. ..... -- ....... i 3.0 rain ' 2,000 4 0 min , 2,000 F- s.o mi, i .,? n rain ~ ~ 2,000 OSl ~,"" ................ ~ ........ .~-----.-I Z'{l',~'rnin ~ 2,000 psi r~r : 2,000 psi .~= n ""'i'" i : 2,000 osl _ .;~_c.. ~.. ' ,_,_.,; _.f. .................... ~.---~ 20.0 rain I o...2,_~_0 .p_s.i_ .~ -~60 mi, ~ ~2,0.__~ psi..i NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY PHILLIPS Alaska, Inc. A Subsidiary of PHIL.LIPS PETROl EUM COMPANY P.O. BOX 100~0 Anchora~, Ak g9510~)360 (S07) 26~224 Krl ! LL I l"~ AK 1 I~U'~' Fax or Review CC: [] Plo~se Comment [] Ploase Reply [] Please Recycle .Comments: 20-Jun-O0 AoGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 2N-347 Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on SurveY: Window / Kickoff Survey Proiected Survey: 0.00' MD 0.00' MD 12,735.00' MD (if applicable} please catI me at 273-3545 if you have any questions or concerns. Regards, RECEIVED Kenneth W. Allen Survey Manager Attachment(s) JUN 2 1 2000 Alaska Oil & Gas Cons. Commission Anchorage North Slope Alaska Alaska State Plane 4 Kuparuk 2N 2N-347 Surveyed: 3 June, 2000 ORIGINAL SURVEY REPORT 20 June, 2000 Your Ref: API-501032033700 Surface Coordinates: 5911858.83 N, 460450.23 E (70° 10' 12.4759" N, 150° 19' 05.8686" W) Kelly Bushing: 155.58ft above Mean Sea Level DRILLING SERVII::ES RECEIVED dUN 21 ~000 AJast<a OJJ & Gas Cons. Commission Anchorage Survey Ref: svy9252 A HALLIBURTON Sperry-Sun Drilling Services Survey Report for 2N-347 Your Ref: API-501032033700 Surveyed: 3 June, 2000 North Slope Alaska Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 0.00 0.000 0.000 -155.58 0.00 115.00 0.000 0.000 -40.58 115.00 150.88 0.390 140.710 -4.70 150.88 246.86 0.260 204.640 91.28 246.86 329.21 0.730 267.870 173.63 329.21 359.70 1.200 277.140 204.11 359.69 388.49 2.230 276.780 232.89 388.47 419.64 3.250 275.820 264.00 419.58 448.60 4.170 275.530 292.90 448.48 478.33 5.340 279.960 322.53 478.11 509.19 6.470 282.900 353.22 508.80 539.84 7.820 285.890 383.64 539.22 569.43 9.140 285.220 412.90 568.48 599.52 10.710 286.800 442.54 598.12 691.29 15.590 290.330 531.88 687.46 783.52 21.730 289.550 619.22 774.80 874.66 24.130 285.730 703.15 858.73 964.65 24.240 278.860 785.26 940.84 1058.37 28.970 276.550 869.04 1024.62 1153.88 32.700 274.960 951.03 1106.61 1247.65 38.230 273.390 1027.38 1182.96 1343.06 42.760 274.850 1099.92 1255.50 1437.71 46.230 274.190 1167.42 1323.00 1532.23 50.550 275.360 1230.18 1385.76 1628.03 54.940 275.820 1288.16 1443.74 Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) Alaska State Plane 4 Kuparuk 2N Dogleg Rate (°/100ft) 0.00 N 0.00 E 5911858.83 N 460450.23 E 0.00 N 0.00 E 5911858.83 N 460450.23 E 0.000 0.09 S 0.08 E 5911858.74 N 460450.31 E 1.087 0.55 S 0.19 E 5911858.28 N 460450.42 E 0.376 0.73 S 0.41W 5911858.10 N 460449.82 E 0.796 0.70 S 0.92W 5911858.13 N 460449.31 E 1.619 0.60 S 1.77W 5911858.24 N 460448.45 E 3.578 0.44 S 3.26W 5911858.41 N 460446.97 E 3.278 0.25 S 5.12W 5911858.60 N 460445.11 E 3.177 0.09 N 7.56W 5911858.96 N 460442.67 E 4.122 0.73 N 10.67W 5911859.61 N 460439.57 E 3.789 1.68 N 14.36W 5911860.59 N 460435.88 E 4.567 2.85 N 18.56W 5911861.78 N 460431.68 E 4.473 4.29 N 23.54W 5911863.24 N 460426.71 E 5.295 11.04 N 43.28W 5911870.10 N 460407.01 E 5.387 21.07 N 71.02W 5911880.27 N 460379.32 E 6.663 31.77 N 104.86W 5911891.15 N 460345.54 E 3.097 39.60 N 140.82W 5911899.17 N 460309.62 E 3.128 45.16 N 182.41W 5911904.94 N 460268.06 E 5.165 50.03 N 231.11W 5911910.06 N 460219.39 E 3.997 53.94 N 285.35W 5911914.26 N 460165.17 E 5.976 58.42 N 347.12W 5911919.07 N 460103.42 E 4.851 63.64 N 413.24W 5911924.63 N 460037.33 E 3.699 69.54 N 483.64W 5911930.90 N 459966.96 E 4.663 76.98 N 559.51W 5911938.73 N 459891.13 E 4.598 Vertical Section (ft) Comment 0.00 0.00 -0.08 -0.22 0.38 0.89 1.75 3.23 5.10 7.56 10.69 14.41 18.66 23.70 43.71 71.84 106.10 142.36 184.14 233.00 287.35 349.26 415.54 486.13 562.25 RECEIVED JUN 2 t 2000 Continued... 20 June, 2000-10:37 -2- Alaska 0il & Gas Cons. 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Jno~ ZfTE'NE ~oJ 7~odal~ ~faA~nS sao!A aS OU!llHO uns- O ads Sperry-Sun Drilling Services Survey Report for 2N-347 Your Ref: API-501032033700 Surveyed: 3 June, 2000 North Slope Alaska Alaska State Plane 4 Kuparuk 2N Comments Measured Depth (ft) 12735.00 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 5267.69 287.12 N 10884.22 W Comment Projected Survey Survey tool program From Measured Vertical Depth Depth (ft) (ft) 0.00 0.00 To Measured Vertical Depth Depth (ft) (ft) 12735.00 5267.69 Survey Tool Description MWD Magnetic RECEIVED JUN 2 t 2000 Alaska 0il & Gas Cons. Commission Anchorage 20 June, 2000 - 10:37 - 8 - DrillQuest 1.05.05 2N 34Y~ Subject: 2N 347 Date: Tue, 30 May 2000 11:58:46 -0900 From: "Tom J Brassfield" <TBRASS~ppco.com> To: Blair Wondzell <blair_wondzell@admin.state.ak.us> CC: "Chip Alvord" <CALVORD~ppco.com>, "Randy L. Thomas" <RLTHOMAS~ppco.com> Blair, per your conversation over the weekend with Chip Alvord we are forwarding the attached event description from the Nabors 19E 5/28/00 morning reports. The rig has subsequently drilled to 10,300' MD without further incident (currently tripping out of the hole for a BOPE test) and the wellbore has been very "static" since stopping the annular injection into the 2N 341 7-5/8" x 5-1/2" annulus. Thanks, Tom (See attached file: 2N 347 341 Communication.doc) i I Name: 2N 347 341 Communication.doc Type: Microsoft Word Document (application/msword) I~D2N 347 341 Communication.docI Encoding: base64 I t Description: Mac Word 3.0 1 of 1 5/30/00 !:59 PM 12:00 AM 06:00 AM 6.00 DRIL PROD Making Hole Dir Drlg 7734' to 8150' MD 06:00 AM 08:00 AM 2.00 PRB MISC PROD Other On Connection Well appeared to be flowing.Well was shut in . After 9 min build SIDPP 230 psi & CICP 230psi.Pressure stabilized at that point and did not increase.A volume of mud was bled out & pressure reducted to 100psi . The well built back to 230psi was slower by (1.5 min) .The second time we bled off to 100psi the volume was smaller. It was thought this indicated the well was breathing. The well was opened back up and it showed a slight flow that seem to be decreasing. At this time we CBU at a reduced rate to reduce the ballon pressure on well. Total BU stks were 2350 stks, @ 1290 stks into BU circu a slight gas increase (40 units) was seen( this would have been app 131bbl or 4564' down hole.The well was circu to total BU with no more show of influx or gas. After discussing with the CPM about their Annular injection(they had injected 300+ bbls stopping @ 6:20 into well 2N-341) All indications show this well is in cammunication with 2N-347. We also had a slight smell of Diesel in our mud,which would be another indicator. We started back drilling and on connections the well only shows a slight "Breathing" problem upon making a connection. I have shut down all annular injection. CPM will process cutting and we will Vac truck them to iR Pad for disposal. 08:00 AM 10:30 AM 2.50 DRIL PROD Making Hole Dir Drlg 8150' to 8334' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Robert Christenson Chairman THRU: FROM: /.~ j-- ~//,x~f,,/~,, DATE: May 23, 2000 Blair Wondzell P.I. Supervisor LOU Orimald~ Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Blowout Preventer Test Nabors 19E Phillips 2N-pad 2N-347 200-063 Kuparuk River Field Operator Rep.: Ray Springer Contractor Rep.: Jon West Op. phone: 263-3140 Rig phone: 263-3141 Op. E-Mail: Rig E-Mail: Test Pressures Rams: 250/3000 MISC. INSPECTIONS: P/F P/F Location Gen.: P Sign: P Housekeeping: P Rig cond: P PTD On Location P Hazard: P Standing Order: P Annular: 250/3000 Choke: 250/3000 TEST DATA FLOOR VALVES: MUD SYSTEM: Visual Alarm Quantity P/F Trip Tank P P Upper Kelly 1 P Pit Level Indicators P P Lower Kelly 1 P Flow Indicator P P Ball Type 1 P Meth Gas Detector P P Inside BOP 1 P H2S Gas Detector P P BOP STACK: Quantity Size P/F ACCUMULATOR SYSTEM: Annular Preventer 1 13 5/8 P CHOKE MANIFOLD: Time/Psi P/F Pipe Rams I 13 5/8 P Quantity P/F System Pressure 3100 P Lower Pipe Rams I 13 5/8 P No. Valves 16 F After Closure 2000 P Blind Rams 1 13 5/8 P Man. Chokes 1 P 200 psi Attained :40 P Choke Ln. Valves I 4" P Hyd. Chokes 1 P Full Pressure 3:07 P HCR Valves 2 3&4" P Blind Covers (All Stations): P Kill Line Valves 1 3" P N2 Bottles (avg): 4 @ 2000 Check Valve 0 Test's Details The rig was ready to test when Jeff Jones (Petroleum Inspector) and I arrived. The test went well with one failure observed, this being the stem seal on the inside bypass valve in the choke manifold. The stem was greased but still would not test. The rest of the BOP equipment tested "OK". The rig and the area surrounding it was clean and orderly. The rigs equipment showed signs of maintenance and upkeep. Jon West (ToolPusher) was on hand for the test and followed a established procedure. I received a call from Jon West the following day reporting that the Bonnet on the failed valve had been replaced and retested "OK". I allowed for the rig to drill out. Total Test Time: 4 Number of failures: cc: MorrisonlOverstreet Kuparuk Drillin(~ Attatchments: None BOP Nab 19E 5-23-00 LG 6/7/00 ALASKA OIL AND GAS CONSERVATION CO~L~ISSION Randy Thomas Drilling Team Leader ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 TONY KNOWLES, C~)VERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 9950 ! -3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Re~ Kuparuk River Unit 2N-347 ARCO Alaska, Inc. Permit No: 200-063 Sur Loc: 151'FNL, 1143'FEL, Sec. 3, T9N, R7E, UM Btmhole Loc. 167'FSL, 1344'FEL, Sec. 32, T10N, R7E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced well. ARCO is the operator of record for this field. Please provide the Commission with the appropriate forms regarding notice of ownership and designation of operator. Annular disposal has not been requested as part of the Permit to Drill application for Kupamk River Unit Well No. 2N-347. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on Drill Site 2N must comply with the requirements and limitations of 20 AAC 25.080. Approval of this permit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space ora single well or to use that well for disposal purposes for a period longer than one year. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. / / . Robert N. Christenson, P.E. Chair BY ORDER OF T}~[ COMMISSION DATED this ~ ~ day of May, 2000 dlf/Enclosurcs Department of Fish & Game. Habitat Section w/o encl. Dcpanmcnt of Environmental Consen'ation xv/o cnct. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type ofwork: Drill ~] Redril, D I ,b. Type ofwell. Exploratory D StratigraphicTest D Development Oil r~ Re-entry r-] Deepen DI Service D Development Gas D Single Zone F~l Multiple Zone 2. Name~~la~~of Operator /~¢",'-~-'a ,¢K¢/~,,¢,.~.~ , 5. DatumRKB35elevation (DF or KB)feet 10. Field and Pool 3. Address 6. Proper~ Designation Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL375108 ALK 4309 Tarn Pool 4. Location of well at surface 7. Unit or prope~ Name 11. Type Bond (see 2o AAC 25.0251) 151' FNL, 1143' FEL, Sec. 3, T9N, R7E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 275' FSL, 945' FEL, Sec. 32, T10N, R7E, UM 2N-347 ~U-630610 At total depth 9. Approximate spud date Amount 167' FSL, 1344' FEL, Sec. 32, T10N, R7E, UM May 11, 2000 $200,000 12. Distance to nearest proper~ line ~ 13. Distance to nearest well 14. Number of acres in proper~ 15. Proposed depth (MD and TVD) 167' G TD feet] 2N-345 29.8' G 261' feet 2560 12603 ' MD / 5211 ' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035 (e)(2)) Kickoff depth: 250' MD M~imum hole angle 72.19 M~imum surface 1908 psig At total depth (TVD) 1610 psig 18. Casing program Se~ing Depth size Specifi~tions Top BoSom Quanti~ of Cement Hole Casin~ Weight Grade Oouplin~ Length MD TVD MD TVD (include sta~e data) 24" 16" 62.5~ H-40 Weld 100' 35' 35' 135' 135' 9 cy High Early 9.875" 7.625" 29.7~ L-80 BTCM 3407' 35' 35' 3442' 2300' 310 sx AS III L & 240 sx Class G 6.75" 5.5"x 15.5~ L-80 LTC Mod 11698' 35' 35' 11733' 4712' 280 sx Cla~ G , 6,75" 3.5" 9.3~ L-80 8rd EUE 870' 11733' 4712' 12603' 5211' see above 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary TotalDepth: truemeas~redverti~l feetfeet Plugs(measured) ORIGINAL Effective Depth: measured feet Junk (measured) true verti~l feet Casing Length Size Cemented Me~ur~ depth True Ve~ical depth Conductor Sudace Intermediate RECEIVED ~roduction '-,,* 032000 Perforation depth: measured ~a~ka ~i & G~ C~s. true verti~l ~or~ 20. Attachments Filing fee ~ Property Plat ~ BOP Sketch ~ Diverter Sketch ~ Drilling program Drilling fluid program ~ Time vs depth plot ~ReffactJon ana~sis ~ Seabed report ~ 20 ~C 25.050 requiremen~ 21. I hereby cedi~ that the foregoing is true and correct to the b~t of my knowledge Questions? Carl Bill Lloyd 265-6531 Signed ~~- ~ ~ Title: Ddlling Team Leader Date Randy Thomas I Pregar~d hv .gh~rnn AIl.~uD-Drak¢ Commission Use Onl) Permit Number APl number ~ Approval ~te ISee cover leper ~ o~ -- ~3 50- /0~-- ~ ~ ~ ~7, ~, - ~¢~ Jfor other requirements Conditions of approval Samples required D Yes ~ No Mud logrequired D Yes ~ No H ydroge, s~lfidemeasures D Yes ~N~ D irectio~alsurveyrequired ~ Yes ~ No Required working pressure for BOPE D2M;~~ ~ SM; ~ 10M;~ Other: ORIGINAL SIGNED. By by order of Approved by Robe~ N. Chr/st~. Commi~ioner the commission Date Form 10-401 Rev. 12/1/85 · Submit in triplicate Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 May 1,2000, 1999 Robert Christenson, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill KRU 2N-347 Surface Location: 151' FNL 1143' FEL Sec 3 TgN RTE, tim Target Location: 275' FSL, 945' FEL Sec. 32, T10N, RTE, tim Bottom Hole Location: 167' FSL, 1344' FEL Sec. 32, T10N, RTE, UM Dear Commissioner Christenson, Phillips Alaska, Inc. hereby files this Application for Permit to Drill a development well in the Tarn area, KRU 2N-347, located approximately seven miles southwest of the Kuparuk River Unit's 2M Drillsite. The well is accessed via a new gravel road originating at 2M Pad. Nabors Rig 19e will drill the well. If commercial, the well will also completed with Nabors 19e. Attached is the information required by 20 AAC 25.005(c). There will be no reserve pit for this well. Waste drilling mud will be disposed of down the annulus of an existing well on Drillsite 2L (subject to AOGCC approval), or hauled to a KRU Class II disposal well. All cuttings generated will be preferentially ground at the on-site ball mill and injected down an approved, existing well annulus on 2N pad or stored temporarily onsite or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. The TD of this well will be in the Tarn formation. H2S has not been encountered in this region in any stratum shallower than the Lisburne Formation. Therefore, Phillips has not included an H2S contingency plan with this Application, and requests an exemption from the H2S requirements. However, all drilling mud, cores and produced fluids exiting the wellbore will be monitored for detectable levels of H2S. The following are Phillips' designated contacts for reporting responsibilities to the Commission: 1) Completion Report Sharon AIIsup-Drake, Drilling Technologist 263-4612 (20 AAC 25.070) 2) Geologic Data and Logs Doug Hastings, Geologist 265-6967 (20 AAC 25.071) If you have questions or require additional information, please contact Bill Lloyd at 265-6531 or me at 265-6120 in our Anchorage office. Sincerely, Drilling Engineering Supervisor RECEIVED Attachments cc: KRU 2N-347 Well File 05 2000 AJ~ka Oil & Gas Cons, Commi~ior~ Anchorage Phillips Alaska, Inc. is a Subsidiary of Phillips 66 Phillips Alaska, Inc. GENERAL DRILLING AND COMPLETION PROCEDURE KUPARUK RIVER FIELD - PRODUCER KRU 2N-347 1. Move in and rig up Nabors 19e. 2. Install diverter system. 3. Drill 9.875" hole to 7-5/8" surface casing point according to directional plan. . . . , Run and cement 7-5/8" 29.7#, L-80 BTC-Mod casing string to surface. Employ lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface. If cement does not circulate to surface, a Top Job will only be performed after consulting with the AOGCC. Install and test BOPE to 3,500 psi. Test casing to 2,000 psi. Drill out cement and 20' of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). Drill 6-3/4" hole to TD according to directional plan. Run LWD logging equipment with density and porosity tools. Note: If significant hydrocarbon zones are present above the Tarn, sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(C). Run and cement 5-1/2" L-80 LTC Csg X 3-1/2" L-80 8rd EUE-Mod tapered production casing string with Baker casing seal receptacle at crossover point. 9. Pressure test casing to 3,500 psi. 10. Run 3-1/2" L-80 8rd EUE-Mod completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3,500 psi. 11. Set TWC, ND BOPE and install production tree. 12. Secure well. Rig down and move out. 13. Hydrocarbon intervals will be tested after the rig move. RECEIVED ,, 0 ;5 2000 Alaska 0ii & Gas Cons. Co,;~missi0r:~ Anchorage Phillips Alaska, Inc. DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS We~l KRU 2N-347 Drilling Fluid Properties: Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to surface casing point 9.5-10.2 ppg 16-26 25-35 50-120' 10-20 15-40 7-15 9.5-10 +10% Drill out to TD 9.0 - 11.0 ppg 6-20 5-20 35-50 2-6 4-8 <6 through Tarn 9.0-10 <11% .... 03 2000 Gas Cor~s. Commission Drillinq Fluid System- ITriple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Degasser IPit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 100-120 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033, MaXimum Anticipated Surface Pressure: Maximum anticipated surface pressure (MASP) while drilling the production hole is calculated using a reservoir pressure of 2400 psi at a target mid-point of 4922' TVD. Gas gradient is anticipated to be 0.1 psi/ft. Using this data, the MASP is calculated to be: MASP=((2400/4922)-0.1)'4922 MASP=1908 psi ~ or,. ~..(t~ Therefore ARCO will test the BOP equipment to 3,000 psi after setting surface casing. Based on offset well data, reservoir pressures in the Tarn sands in the vicinity of 2N pad are expected to be -2,400 psi (0.49 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 10.0 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 4922'. Target (Midpoint T2 T3) (2400+150)/(0.052'4922)=10.0. :,CEIVED 2000 Phillips Alaska, Inc. Well Proximity Risks: The nearest well to 2N-347 is 2N-345. The wells are 29.8' from each other at a depth of 261' Drillinq Area Risks: The primary risk in the 2N~347 drilling area is shallow gas below the permafrost. Therefore the surface hole will need to be drilled with weighted mud (9.5 - 10.2 ppg) to avoid underbalancing the hole. Another observed problem in the area is possible lost circulation at approximately 3,300' TVD and in the Tarn formation. Analysis of pressure data from offset wells shows that a mud weight of 9.0-10.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement the well through the reservoir. The 9-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the casing. Recent information has indicated an the presence of gas migration from the reservoir to a shallower sand interval. Log, tracer, pump-in test, and offest BHPBU evaluations indicate any migration has occurred outside of the wellbore interval and is most likely isolated below the TOC and/or below the Iceberg interval. In the event gas migration has occurred into the Iceberg interval at 4304' TVD, the highest required MW would be 10.7 ppg. Annular Pumping Operations: Incidental fluids developed from drilling operations will be either injected into an approved annulus on the same pad or hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be iniected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2N-347 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. Following drilling operations, ARCO Alaska, Inc. will submit application for approval of 2N-347 for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 200' vertically below the base of the West Sak into the heart of the shales. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Phillips Alaska, Inc. Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) = (12.0 ppg) * (0.052) * (2,300') + Max Pressure = 2,935 psi + 1,500 psi 1,500 psi This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 7-5/8" 29.7 L-80 3 BTC 4,790 psi 4,072 psi 6,450 psi 5,483 psi 5½" 15.5 L-80 3 LTC-Mod 4,990 psi 4,242 psi 7,000 psi !5,950 psi 3Y2" 9.3 L-80 2 8rd EUE Mod 10,530 psi 8,951 psi 10,160 psi 8,636 psi Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). ..... (.,,Et ,,,ED , ,, 03 2000 0it & Gas CoIls. C0n]missi0n Anchorage Well Name: 2N-, AFC#: AK0054 ADL#: 380054 ALK 4602 APl #: 50-1- Permit #: Well Name: KRU 2N-347 AFC#: AK0054 ADL#: 380054 ALK 46O2 APl #: 50-1- Permit #: 0 Surface Location: 151' Target Location: 275' Bottom Hole Location: 167' FNL 1,143' FEL Sec3 FSL 945' FEL Sec 32 FSL 1,344' FEL Sec 32 T9N R7E T10N R7E T10N R7E Expected Formation Tops Sub Sea Base of Permafrost 1,050' West Sak 1,095' Base of West Sak 1,765' C80 (Tabasco/K-10) 2,312' Camp Sand 2,355' 050 (K-5) 3,460' C40 3,635' T 8.2 (Iceberg) 4,150' T3.1 Cairn 4,660' T3 (Top Bermuda) 4,673' Target (Midpoint T2 T3) 4,767' T2 (Base Bermuda) 4,860' C35 (K-3) 4,885' TD TVD MD 1,204' 1,267' 1,249' 1,325' 1,919' 2,930' 2,466' , 3,394' 2,509' ~ 4,891' 3,614' '~8,503' 3,789'.. 9,075' 4,304' 1.0,759' 4,814' 11,910' 4,827' 11,933' 4,920' 12,099' 5,014' 12,259' 5,039' 12,303' 5,211' 12,603' GL Sub 119' 35' 154' 1 267' MD / 1 325' MD / 2,93O' MD / 3,394' MD / 4,891' MD / 8,5O3' MD / 9,075' MD / 10,759' MD 11,910' MD 11,933' MD 12,099' MD 12,259' MD 12,303' MD 12,603' MD 1 204' TVD 1 249' TVD 1 919' TVD 2,466' TVD 2,509' TVD 3,614' TVD 3,789' TVD / 4,304' TVD / 4,814' TVD / 4,827' TVD / 4,920' TVD / 5,014' TVD / 5,039' TVD / 5,211' TVD 7-5/8" Csg Point 2,300' 3,442' 3,442' MD / 2,300' TVD KOP Begin Turn to Target EOC Begin Drop to Target EOD to Target PORT Collar Depth Cement top at Iceberg Interval 51/2'' 15.5 ppf L-80 LTC-M 3Y2" 9.3 ppf L-80 8rd EUE Baker Seal Receptacle Nearest Well: Initial Az: Build Rate Turn to Final Azimuth: Max Angle: Target Angle: Departure: 270-0 4-o/100' 272.2-0 255.0-0 72-0 55-0 10~767' 250' 250' 750' 750' 1,634' 2,029' 4,361' 10,946' 4,712' 11,733' 0' 0' 4,243' 10,559' 4,304' 10,759' 4,712' 11,733' 4,712' 11,733' 4,712' 11,733' R :CE!VED 03 2000 Alaska Oii& Cons, Commission 250' MD / 250' TVD 750' MD / 750' TVD 2,029' MD / 1,634' TVD 10,946' MD / 4,361' TVD 11,733' MD / 4,712' TVD 0' MD/0' TVD 0' MD / 0' TVD 10,559' MD /4,243' TVD 10,759' MD/4,304' TVD Surface to 11,733' MD 11,733' MD to 12,603' TD 11,733' MD / 4,712' TVD Initial Az: 270-o Build Rate: 4-o/100' Turn to 272.2-o Final Azimuth: 255.0° Max Angle: 72-o Target Angle: 55-° Departure: 10,767' 5/1/00 Drilling Plan Surface Location: 151' FNL, 1,143' FEL, Sec 3, T 9 N, R 7 E Well Name: KRU 2N-347 Target Location: 275' FSL, 945' FEL, Sec 32, T 10 N, R 7 F Pad Level: 1 19' Bottom Hole Location: 167' FSL, 1,344' FEL, Sec 32, T 10 N, R 7 E RKB: 154' AFC#: AK0054 ADL#: 380054 APl #: 50-1- Permit #: 0 Formation Tops Well Geometry Hydraulics Cement Logging Surface Hole 9-7~8" Hole 9-7/8" Hole 7-5/8" Casing 9-7/8" Hole Base of Permafrost KOP Steerable Motor Assembly 7-5/8" X 9-7/8" 1,267' MD / 1,204' TVD 250' MD / 250' TVD w/8" M1C Motor bow spring centralizers MWD West Sak Initial Az: 270.0 Pump Pressure: (1 per joint on bottom (Directional) 1,325' MD / 1,249' TVD Build Rate: 4-0/100' 2,200 - 3,000 psi 12 joints, then every Flow Rate: third joint to surface) Begin Turn to Target 450 - 600 GPM 750' MD / 750' TVD Bit Recommendation Base of West Sak HTC MX-1 2,930' MD / 1,919' TVD 3x16's jets Mud Weight: 20 bbl ARCO Wash .. 10.0 by 1100' TVD 40 bbl ARCO Spacer at 10.7 lb/gal i~.~,, ~% [% ~ - ~= WOB 10 -30 M Lead 310 sx AS3 ~,~ ~ + additives Tail 240 sx CIG cmt '~ ' V + additives 0;5 2000 Rotary 80 - 120 RPM il &Gas C0,qs, Commission Turn to 272.2-o Mud Motor 300- 352 No E-line Logs .~Of~8 Max Angle: 72°. Stabilize BHA Single shot at TD to avoid differential sticking EOC 10.2 by 1900' TVD 7-5/8" Csg Point 2,029' MD / 1,634' TVD 3,442' MD / 2,300' TVD Final Azimuth: 255.0.0 Production Hole 6-3~4" Hole 6-3/4" Hole 5-1/2" x 3-1/2" Casing 6-3~4" Hole I 5-1/2"x61/2" centering guid6 every fifth joint from 0' to KOP & 1 every third joint from KOP to 2000'TVD in csg. C80 (Tabasco/K-10) Steerable Motor BHA 51/2" x 63,4" Bow Spring MWD 3,394' MD / 2,466' TVD w/4-3/4" MlXL 1 per joint to 500' (Directional) Begin Drop to Target motor and PDC bit above crossover C50 (K-5) 10,946' MD / 4,361' TVD 31/2" x 61/2" LWD (GR/Resistivity) 8,503' MD / 3,614' TVD Hycalog DS68FGPV Weatherford GR/Res logs real time - Target Angle: 55.0 or HTC STR 554 Spirolizers Density(record mode) C40 EOD to Target TFA -- 0.4 - 0.5 run 1 per jt. Must be rotating for log, 9,075' MD / 3,789' TVD 11,733' MD / 4,712' TVD (4 X 12 = 0.442 TFA) 90 fph 2 data points/ft (4 X 13 = 0.520 TFA) 180 fph 1 data point/ft T3 (Top Bermuda) 11,933' MD / 4,827' TVD WOB 5-15 M Rotary 120 - 150 RPM Target (Midpoint T2 T3) Mud Motor 300 - 357 Cement top at 12,099' MD / 4,920' TVD 10,559' MD / 4,243' TVD Pump Pressure: T2 (Base Bermuda) 2,500- 3,500 psi 12,259' MD / 5,014' TVD 5½" 15.5 ppf L-80 LTC-M Flow Rate: 20 bbl ARCO Wash, C35 (K-3) Surface to 11,733' MD 300 - 350 GPM 40 bbl ARCO Spacer: 12,303' MD / 5,039' TVD @ 12 ppg TD 3-1~,, 9.3- ppf L-80 8rd EUE Mud Weight: 280 sx Class G 12,603' MD / 5,211' TVD 11,733' MD to 12,603' TD ~ 9.1 - 10.0 ppg + additives 5/1/00 Dri. and set Casing All Depths are RKB Nabors Rig 19e 2N-347 I FMC Gen V 9-5/8 x 51/5 x 31/2 7-5/8 ............................................ L Mandrel Hanger ''~ ................. Base of permafrost at 1,267' MD / 1,204' TVD .:.:.:' .,.,... ,.,.,,, : 9-7/8" Hole .' .' .' Top of West Sak at 1,325' MD / 1,249' TVD Base of West Sak 2,930' MD / 1,91 9' TVD 7-5/8" 29.7 ppf L-80 BTC Mod Surf. Csg. 3,442' MD / 2,300' TVD 6~" Hole · · . · , . 16" Conductor Mud Weight in Surface hole: 10.0 ppg by 1100' TVD 10.2 ppg by 1900' TVD Weatherford Gemoco 7-5/8" Float Collar and Float Shoe Mud Weight in Production hole 9.1 to 10.0 ppg X-Over 5Y2 LTC Box X 51/2 BTC 51/2" 15.5 L-80 LTC Mod Csg 11,733' MD / 4,712' TVD Weatherford Gemoco 3Y2" Float Collar and Float Shoe 3½" 9.3 L-80 8rd EUE Tbg 12,603' MD / 5,211' TVD Completed 2N-347 FMC Prudhoe Gen V 9-5/8 x 5Y2 x 31/2 Base of permafrost at 1,267' MD/1,204' TVD 9-7/8" Hole 3-1/2" Completion will have 2 non-conductive, 3-1/2" x 4- 11/16" centralizers/joint from base Permafrost to hanger 7-5/8" 29.7 ppf L~80 BTC Surf. 3,442' MD / 2,300' TVD 3¥2" 9.3 ppf L-80 8rd EUE tubing Baker CMU Sliding Sleeve, Size 2.813" w/3½" 8rd EUE Box x w/2.813" Camco DS profile 63~ ' 2.875" CAMCO DS nipple for SCSSV at 1300' + MD Baker 5Y2" Csg Seal Receptacle (CSR) Size 80-m 5Y2" 15.5 ppf Mod BTC box up X 3¥2" 9.3 ppf 8rd EUE pin down 11,733' MD / 4,712' TVD rb' Ol~ :::i::: r' C iiiiiii i:i:i:i si, 40::::::: .,..,.-.,.o... .............. :.:.2.:.:.:.:.: ;.:.:.:.:.:.;. Camco 3Y2" x 1" Camco 3½"x 1" pocket GLM CAMCO 2.75" D nipple pocket GLM 31/2'' 9.3 ppf L-80 EUE (tubing) Csg 12,603' MD / 5,211' TVD 2000 Gas Cons. Commission 3-1/2" Slimhole Monobore Completion 5/1/00 Phillips Alaska, Inc. Diverter Schematic Nabors 19e 21 lA" 2,000 psi WP DRILLING SPOOL w/16" Outlet Flowline 214¼" HYDRIL MSP 2,000 psi WP ANNULAR PREVENTER 16" 200 psi WP HYDRAULIC KNIFE VALVE 16-3/4" 2M SOW Starting Head 16-3/4" x 21-1/4" x 2M Psi DSA Flange 16" 62 ppf PEB CONDUCTOR PIPE set at 80' (GL) RECEIVED '~,.',: 03 2000 Alaska Oil & Gas Cons. Commission Anchorage Phillips Alaska, Inc. POOL #6 13-5/8" 5,000 PSI BOP COMPONENTS ¼ J I I 3" 5,000 psi WP OCT MANUAL GATE KILL LINE 3" 5,000 psi WP Shaffer GATE VALVE w/hydraulic actuator E~ / 1 / DSA 13-5/8" 5,000 psi WP x 11" 3,000 psi WP 11" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 11" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom b i 3" 5,000 psi WP Shaffer GATE VALVE _] ~raulic actuator ~.q~,~~ ~0 psi wCpHoOcKTE LINE 11" 5,000 psi WI::' w/two 3" 5M [:)si WP outlets J SINGLE 11" 5,000 psi WP, I HYDRIL MPL BOP w/pipe rams RECEIVED I":~'¢ 0,5 2000 Alaska 0ii & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Tarn Drill Site 2N 347 slot #347 Tarn Development Field North Slope, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : 347 Version #13 Our ref : prop3754 License : Date printed : 1-May-2000 Date created : 3-Dec-1999 Last revised : 1-May-2000 Field is centred on nT0 12 49.742,w150 18 33.414 Structure is centred on n70 10 13.955,w150 18 32.772 Slot location is n70 10 12.476,w150 19 5.869 Slot Grid coordinates are N 5911858.844, E 460450.215 Slot local coordinates are 150.29 S 1142.46 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North 'poq2om oln2~A~no mnm!u!~ o~2 SaSh uo!aelnOlPo · saa~6ap 09'gL5 ~2nm!z~ uo p~a~iiam mo~ s! uo!]oas I~O!~aA 'saa~6ap §I'96 s! q2PdIIam ~o~ DaIDO~ I~2OL '(Te^~I eas u~ ~^oq~ ~d 00'9~I) (~6I s~oqe~) ~HH ~o~ ~A~ pue g~£# ~oIs ~o~ s~u!p~ooo · p~s es!~o sseiun ~eg u~ s! e~ep II~ 8L'6£§6 00'£ M 08'£Z§6 M 99'6L§ 9L'5199 90'OLE L9'89 O0'OOIII I6'~996 00'£ M L6'6596 N 88'LL§ ~5'8L~9 II'SL$ §6'OL O0'O00II u~nL/do~G ~a~ ~6'96C6 00'0 M ~0'6L£6 N I~'~L~ ~5'I9£~ 05'£L~ 61'5L ~'9960I ~aqaoi 9L'91~6 00'0 M 5I'I056 N ~§'~9§ 00'90£P 0~'£L~ 6I'5L 80'6§LOI 0I'0L68 00'0 M 98'9~68 N 9L'I§§ §L'9~5~ 0~'£L5 6I'5L 00'00~0I II'9698 00'0 M §~'6L~8 N §I'VE§ IS'It0P 05'£L5 6I'5L 00'0000I ~I'8108 00'0 ~ 9~'9008 N 9§'869 98'816C 05'£L5 6I'lL 00'00§6 090 86'CI9L 00'0 M IL'009L N 96'§L9 00'68LC 0E'CL5 6I'lL 99'§L06 9I'~9§A 00'0 ~ 86'85§L N 56'IL9 ~6'§9L£ 0~'£t~ 61'5£ 00'0006 0~O ~£'690L 00'0 ~ 88'9§0L N 69'~9 00'919£ 05'£L~ 61'5£ 9['C0§8 §I'990£ 00'0 M 69'£§0£ M IE'599 L6'EI9£ 0~'£L5 61'5£ 00'00§8 9I'06~9 00'0 M 0~'8L~9 M 0L'8IP £0'09~£ 05'~L5 6I'5L 00'0008 8I'PII9 00'0 M II'f019 M 60'56~ 80'L0££ 05'£L5 6I'EL 00'00~L 6I'8C9§ 00'0 M 58'L~9§ M 89'§9£ PI'9~I£ 0~'£L5 6I'lL 00'000L 05'59I~ 00'0 M £§'5§I~ M L8'8££ 6I'I00£ 05'£LE 6I'Et 00'00~9 55'9899 00'0 M P~'LL99 M g$'5I£ §~'8985 0~'£L5 6I'5L 00'0009 £5'0I~9 00'0 M §6'I0~9 N 99'§85 I~'§695 05'~L5 6I'5L 00'00~§ 95'9£L£ 00'0 M 99'95L£ M £0'6§5 9~'5~5 OE'fL5 6I'lL 00'000§ SS d~eo 59'0£9E 00'0 M 66'559£ N ~'£~5 00'60§5 05'£L5 6I'5L 96'0689 080 09'969[ 00'0 M 9£'68~£ N 9L'§95 00'9995 05'£L5 6I'5L 9~'0§L9 9~'8§E£ 00'0 M L£'I§5£ N ~9'5£g 59'68£5 05'£L5 6I'5L 00'00~9 £5'~8£5 00'0 M 80'9££~ N I8'§05 L9'9£~5 0E'££E 6I'5£ 00'0009 85'90£E 00'0 M 6£'00£5 N 6I'6£I £§'£805 0~'££5 61'5£ 00'00g£ ~S M ase~ IL'9£8I 00'0 M 16'6581 M CS'~I 00'5£61 05'£L~ 6I'~£ £9'900C 0£'0£81 00'0 M I§'~58I N 8§'5§I 8~'0£6I 05'£LE 6I'5L 00'000£ I£'~£I 00'0 M 55'0§£I N L6'§5I 99'LLLI 05'£L~ 6I'5t 00'00§~ DOZ 99'506 0~'9 M £5'506 N 68'00I 89'CC9I 0~'£LE 6I'EL 5L'8505 ~9'8L8 0~'9 M E0'~L8 N 9£'66 6C'959I 6~'~g~ 06'0L 00'000~ ~£'~8L 0§'9 M 80'58L N gL'£6 00'88§I 09'CLg I9'99 00'006I L~'~69 0§'9 M 0£'~69 N §8'L8 59'99§I £6'£L5 56'I9 00'008I II'609 0§'9 M 5~'909 N 99'I8 96'£69I 65'9L~ £9'L~ O0'OOtI 60'L5§ 0~'9 M 09'9Z§ N 9~'~L 98'9£91 69'~L5 96'Z§ 00'0091 08'699 0§'P M E£'L99 N ~9'89 9§'£L£I 9I'~L5 ~9'89 00'00§I £L'LL£ 0§'9 M Lg'~L£ N 98'I9 9£'90£I 99'~L~ L6'CP 00'009I ~e$ ~ doA LP'LSf 0§'9 M 8£'§~£ N 69'95 00'69~I 0I'9L5 19'09 9I'~5£I I£'II£ 0~'9 M 85'60[ N §6'9§ 9L'65EI LS'9L5 69'6C 00'00C1 Jsox~Pmlad aseS 0L'065 0~'9 M §L'885 N §9'~§ 00'905I 69'9L5 I0'8£ 66'9951 L6'0~E 0~'9 M 8I'695 N L6'L9 9I'0§II 00'LL$ I0'§£ 00'005I 90'L6I 0~'9 M I§'§6I M L6'09 0I'990I E6'£L5 9§'0E 00'00II ~eiIOO ~o~ 98'09I 0~'9 M 89'6§I N 69'~£ 00'000I 08'8L~ LI'L~ g6'69I 05'9 M £9'89I N 86'£[ 80'8L6 5I'6L5 t0'9E 00'000I ~8'60I 0~'9 M I8'80I N §O'LE ~9'988 8L'08~ 59'I5 00'006 60'LL 0§'9 M I~'9£ N I~'OE 9£'56L 95'~85 05'ti 00'008 u~/pI~ b~ I§'£9 00'£ M 98'59 N 98'91 I~'~gL 00'58~ O0'§I O0'O~L £L'09 O0'C M IC'09 N 08'01 80'L99 00'§8~ 00'~I 00'0§9 ~6'5g 00'£ M IL'gg N 60'9 LA'BP§ 00'58Z 00'6 00'0§~ IS'0I 00'£ M II'0I N It'~ E9'69~ 00'585 00'9 00'0§9 5§'~ 00'£ M CS'E N 89'0 56'69C 00'§8~ 00'£ O0'OSC dOM 00'0 00'0 Z 00'0 N 00'0 00'055 00'585 00'0 00'055 00'0 00'0 g 00'0 N 00'0 00'0 00'~8~ 00'0 00'0 000~-XeN-i : pas!na~ fi# uo!s~aA APE : 3a~ ~noA I sDed ONI~$Iq 'ouI '~SelV ODHV · p~o~TTo~ ~o~ soo~op ~L'IL~ ~anm~z~ uo ££'LgLOI s~ oou~p oio~ 'p~eas ~s!~q~o ss~iun ~oo~ u! 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Tarn Drill Site 2N,347 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 347 Version I~13 Last revised : 1-May-2000 Comments in wellpath MD TVD Rectangular Coords. Comment 250 00 750 00 1024 52 1266 99 1325 16 2028 72 3004 63 4750 36 4890.94 8503.36 9075.46 10759.08 10946.25 11733.21 11910.55 11933.21 12098.84 12259.23 12302.82 12602.82 250 744 1000 1204 1249 1633 1932 2466 2509 3614 3789 4304 4361 4712 4814 4827 4922 5014 5039 5211 .00 0 .31 16 .00 35 .00 52 .00 56 48 100 00 152 00 245 00 253 00 445 00 475 00 565 25 575 28 512 00 474 00 469 00 434 00 400 00 391 07 327 .00 N 0.00 E KOP .84 N 62.86 W Beg Bld/Trn .69 N 159.48 W Port Collar .65 N 288.75 W Base Permafrost .69 N 325.38 W Top W Sak .89 N 902.23 W EOC .83 N 1829.91 W Base W Sak .74 N 3489.36 W C80 .22 N 3622.99 W Camp SS 49 N 7056.88 W C50 94 N 7600.71 W C40 55 N 9201.12 W Iceberg 51 N 9379.04 W Beg Drop/Turn 13 N 10074.27 W EOC 54 N 10214.59 W T3.1 73 N 10232.52 W T3 61 N 10363.57 W 2N-347 Rvsd 23-Feb-00 61 N 10490.49 W T2 37 N 10524.97 W C35 76 N 10762.34 W TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TV]D Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 4207.68 2300.00 216.86N 2973.50W 7 5/8'' Casing 0.00 0.00 0.00N 0.00E 12602.80 5211.06 327.77N 10762.33W 5 1/2'' Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 2N-347 Rvsd 23-Feb-0 450090.000,5912346.000,0.0000 4922.00 434.61N 10363.57W 3-Dec-1999 Created by finch For: B Lloyd Dote plotted: 1-May-2000 Plot Reference is 347 Version ~15. Coordlnotee ore in feet reference slot ~54.7. True Vertrcal Depths are reference RKg (Nabors I gE). INTEQ ARCO Alaska, Inc. Sfruofure: Tarn Drill $1fe 2N Well: 547 JFleld : Tarn Development Field Looatlon: North Slope, Alaska 5OO ooo 500 2000 2500 5000 5500 I V 4000 4500 500o 550O RKB ELEVATION: 154' KOP 5,00 DL$: .3.00 deg per 100 ft. 9.00 Beg BId/Trn 21.62 $0.54Port Collar DLS: 4.50 deg per 100 ft ~9.49 Base Permafrost 48.45 Top W $ok 57.43 70.90 EOC Bose W Sok MAXIMUM ANGLE 72.19 DEG 7 5/8" Casing C80 Camp SS 272.4 AZIMUTH 10373' (TO TARGET) ***Plane of Proposal*** 2000 C50 C40 Iceberg DLS: 3.00 deg per 100 ft TARGET ANGLE ~eg DropS/Turn 70.95 64.18 55 DEG E%., ~7.7~ T3 Torgei Mid Bermudo T2 C~5 TO - C~a;ng ~ I I I I I' I I I I I I I I I I I I I I I I I I I I I I I II I I i I I I I I I I I I I i' II 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 10500 11000 Vertical Section (feet) -> Azimufh 272.40 wifh reference 0.00 N, 0.00 E from sial #347 Cre~ted by f;nch For: B Llo~'d D~te ploti:ed: l-May-2000 Plot R~ferenc~ i~ ,}47 Version ~1~. Coord;notes ore in feet r~ference slot ~47. INT~Q IARC0 Alaska, Inc. Structure: Tarn Drill Site 2N Well: 547 IField: Tarn Development Field Looaflon : North Slope, Alaska 272.4 AZIMUTH 10373' (TO TARGET) ***Plone of Proposol*** 5500 2750 2200 1650 1100 550 0 550 1100 1650 2200 2750 <- West (feet) 11000 10450 9900 9550 8800 8250 7700 7150 6600 6050 5500 4950 4400 3850 5500 2750 2200 1630 11 O0 550 0 550 I I [ I I I I I I I I I I I I I I I I I I I I I I I I I i I I I I I I I I I I I I I I TARGET LOCATION: 275' FSL, 945' FEL SEC. 52, TION, R7E SURFACE LOCATION: 151' FNL, 1145' FEL SEC. 3, T9N, R7E TD LOCATION: 167' FSL, 1344' FEL SEC. 52, TION, R7E 873.2 Az I I I I I I I I I I ! I I I I I I I I ] I I I I II I I I I I I I I I I I [ I I I I I 11000 10450 9900 9350 8800 8250 7700 71 50 6600 6050 5500 4950 4400 3850 3300 2750 2200 1650 1100 550 0 550 <- West (feet) 3500 2750 22O0 1650 11oo Z 550 0 -i- 0 550 1100 1650 22O0 2750 Point KOP Beg BId/Trn Port Collar Base Permafrost Top W Sak EOC Bose W Sak C80 Camp SS C50 C40 Iceberg Beg Drop/Turn EOC T3.1 T5 Target Mid Bermuda T2 C55 TD - Cosinq Pt IARCO Alaska, Inc. Structure: Torn Drill $14e 2N Well: ~47 gleld: Tarn Development Field Looation: North Slope, Alaska PROFILE COMMENT DATA MD Inc Dir TVD North East V. Sect 250.00 0.00 285.00 250.00 0.00 0.00 0.00 750.00 1 5.00 285.00 744.51 1 6.84 -62.86 65.51 1024.52 27.1 7 278.80 1000.00 35.69 - 159.48 1 60.84 1266.99 58.01 276.49 1204.00 52.65 -288.75 290.70 1525.16 40.61 276.10 1249.00 56.69 -325.58 527.47 2028.72 72.19 275.20 1655.48 100.89 -902.25 905.66 5004.65 72.19 275.20 1952.00 152.85 -1829.91 1854.71 4750.56 72.19 275.20 2466.00 245.74 -5489.56 5496.60 4890.94 72.19 275.20 2509.00 255.22 -5622.99 5650.42 8505.36 72.19 273.20 3614.00 445.49 -7056.88 7069.55 9075..46 72.19 275.20 5789.00 475.94 -7600.71 7615.98 0759.08 72.19 275.20 4504.00 565.55 -9201.12 921 6.74 0946.25 72.19 275.20 4561.25 575.51 -9579.04 9594.92 1733.21 55.00 255.00 4712.28 512.15 -10074.27 10086.88 1910.55 55.00 255.00 4814.00 474.54 -10214.59 10225.50 1933.21 55.00 255.00 4827.00 469.73 - 10252.52 10245.22 2098.84 55.00 255.00 4922.00 454.61 -10365.57 10572.68 2259.25 55.00 255.00 5014.00 400.61 -10490.49 10498.06 2502.82 55.00 255.00 5039.00 591.37 - 10524.97 10532.13 2602.82 55.00 255.00 5211.07 527.76 -10762.54 10766.65 Deg/1 O0 0.00 3.00 4.50 4.50 4.50 4.50 0.00 0.00 0.00 0.00 0.00 0.00 0.00 3.00 0.00 0.00 0.00 0.00 0.00 0.00 c~.~ ~/~.<~ For: B Lloyd Do. plotted: "1 -Moy -,2.00G 33O 320 310 [ARCO Alaska, Inc. IStructure : Tarn Drill Site 2N Well : 547 IField : Tarn Development Field Location : North Slope, Alask 340 TRUE NORTH 350 0 10 20 30 40 50 3OO 60 290 280 270 I00 70 80 9O 26O 250 100 Eib 110 240 250 220 210 200 190 Normal Plane Travelling Cylinder - Feet 9OO 120 1300 3O 140 150 170 1300 ,60 1 3 1100 1100 All depths shown are Measured depths on Reference Well Crsot.~ ~ '~c~ For: B Lloyd Dot~ plotted: 1-May-2000 Plot Rst~erence {s 547 Version Coordinates are ;n fe~ r~erlnce slot ~7. True Ve~l ~pths ore r~erence RKB (Na~r~ IARCO Alaska, .............. IStructure : Torn Drill Site 2N Well: Field : Torn Development Field Loooflon : Nor'th Slope, Alaska 240 200 16o 120 80 D 40 120 160 2OO 240 <- West (feet) 720 680 640 600 560 520 480 440 400 560 520 280 240 200 160 120 80 40 0 40 80 I I I I I I I I I I I I I , I I I I I I I I I I I I I I I I I I I I I I I I I I 240 1600 1500 ~ ' "'--" 1~00 1500 ~ 160 ~ ..... 1500 ...... 1400 80 oz .... --, .... 1500 ~ ~--,~ ~ 120o .... ,,,- ~ ~ 1100 ~5~00 5500 5,mo 5500 5200 .... '"'-' ........................ ~_ ~:,500..~" .,/600 F 0 .. oo OO?oo o 160 _ 720 680 040 600 560 52.0 480 440 400 360 520 280 240 200 160 120 80 40 0 40 80 <- West (feet) Created by f;nch ~0~': ~1 Date platted: 1-May-2000 Plot Reference ie 347 Veraian Caordlnatee are in feet reference Blot True Vertical Depthe are referen;e RKB (Nabors 19E), ARCO Alaska, Inc. Structure: Tarn Drill Site 2N Well: 547 Field : Tarn Development Field Looatlon : North Slope, Alaska~ <- West (feet) 2500 2400 2500 2200 2100 2000 1900 1800 1700 1600 1500 1400 1500 1200 1100 1000 900 800 700 600 500 1~00700t~ I I I I I I I I I I I I I I I I I I I i I I I I ~[ ~... ~~1 I I I I t I~1 -~.I I I I I I I 700600 400 ~oo I 200 -I-. ,~_ 1 OD 1 OD 200 5oo 400 500 25O0 --'--- 2500 · ---- 21 O0 2500 ~ _ _ 2~ oo 2100 ,,---....-_....___.~ 1900 1700 19OO ............ 1~_700 r~-~_ 5700 5500 5500 51oo 4900 4700 4500 4300 41oo 5900 3700 5500 3300 400 300 200 1 OD o 1 OD 2500 ~ 200 25oq --'- 2900 500 3,00 I I I I I I I t I I I I I I 500 2500 2400 2500 2200 21 O0 2000 1900 1800 1700 1600 1500 1400 1300 1200 11 DO 1000 gDO BOO 700 600 500 <- West (feet) /k I Z 0 c.ot~ oy f~.ch For: B LioTd Dote plotted: 1-Moy-2000 Plot Reference [8 547 Vemion ~15. Coordinotes ore in fe~ r~erence slot ~7. True Ve~l ~pth~ ore reference ~B (N~ 19E). IARCO Alaska, Inc. .... IS~ruofure: Torn Drill ~lfe 2N Well: 547 }Field : Torn Development Field Looation : North Slope, Alas. k..o: 1200 1000 800 600 400 200 0 2oo 400 600 80O 1000 <- West (feet) 6000 5800 5600 5400 5200 5000 4800 4600 4400 4200 4000 5800 5600 3400 5200 5000 2800 2600 2400 2200 ~ I I I I I i I I l,, I ,, I I I ,,,I I [ , t I I I I I ,I , I ~ I ,, I I I I, I, , I ,I ,, I I I ,, I 4500 "-""~"~'~---.-.__.~.~ 4100 "~'--'-----_.__..~900 3700 5~00 5500 3100 5500 3100 -~ -- =''' ~ '~ " 29O0 3300 1 O0 2900 2700 2700- ....... 3300 3100 2900 5100 45o0 ~100 3900 ~00 ~ 2300 2500 2 700 ~ 29~ 3100 i i ~ i i i i i i i i i i i i i 'ti i 'T i i ~." i .... t .... t i i i t i ! i i i i i i 6000 5800 5600 5400 5200 5000 41500 4600 4400 4200 4000 5800 3600 5400 5200 5000 2800 2600 2400 2200 <- West (feet) 1200 lOOO 8oo 6oo 400 /X, I z 200 0 0 200 4OO 60O 80O lOOO oo~z ooo~ O09L OOZL I .c oo~ o · ' 0 OOl~ 0 OOB z (~ee~) lseM -> OOtt OOgt 00~ OW§ o00g ~tg ~99 OOZL OOgL o00g O0~g oogg 00~6 0096 O000L O0~OL OO90L O0~LL OOgL[ OOO~L O0~L I I I I I I I I I I I t I I i I I I I I I I I I I I I I i I I I I I I I I I I 00~ ~ ~ o~ oo ~ ~ OOZL ~ 00~ 00~ Ov~ O0 L ~ 00~ OOg~ OO6£ 00£~ ~ .... ~ 006~ ~ O0~G OOL~ 006~ 00~ 00~ OOG~ OOL~ ..... 00~ 00~ oo~ ~ 00~[~~ O09L'~~ 00~~ 009~ ~ °°~~ oooz ~rT~ ooo~ oo~ oo~ 0o~~ 00~ OOg~ OOZg oogg 0009 o0~g 0099 O0~Z oogL o00g O0~g oogg 00~6 0096 O000L O0~OL OOgOL O0~LL OOgLL O00~L O0~L oog 0 z o oo~ ~- oog --t- I OOZl, V D4SDIY 'edOlS HMON : UOll. Ooo9 pleI] ~ueLudOleAe~ UJDi : pleUI /..t~£: IlO~ N~ ells III JO uJ,',j.: eJrl~,OflJ~S ltlll 'Z~ 1.OIS O:2uli*JSJOJ ~llO]. u! aJO eOlou!p.~ooo Tl*l~ uo.tmOA L'~G' "'! o",uo.fo~o~ total O00~'-,/[OlN-I, : pollOld olo0 p,~orl ~ :JO.,]' 4ou.u Xq polomJD ARCO Alaska, Inc. Tarn Drill Site 2N 347 slot #347 Tarn Development Field North Slope, Alaska PROPOSAL LISTING INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : 347 Version #13 Our ref : prop3754 License : Date printed : 1-May-2000 Date created : 3-Dec-1999 Last revised : 1-May-2000 Field is centred on n70 12 49.742,w150 18 33.414 Structure is centred on n70 10 13.955,w150 18 32.772 Slot location is n70 10 12.476,w150 19 5.869 Slot Grid coordinates are N 5911858.844, E 460450.215 Slot local coordinates are 150.29 S 1142.46 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North o o 0 ............. , ....... , ....... , ......... , .., ....... ~ .................................................. ~ ~.~ .................................................. ~< ~z~ O~ ~ · ~N o.... ...., ,.... ~ ~ ~z ~ , , ~ ~o ooooo ooooo ~0 z oo oo oo oo ZZ~ZZZZZZ~ZZZZZZZZZZ ~ ~o~ o~oo~ ~o~o~ o~o~ ~o~oo ~oo~ ~~ ~~o o~~ ~~ 00~00 00~0~ 00000 000~ 000~0 0~000 0000~ 0~00~ 00000 00000 ..................... . · . · ~~ ~~ ~~ ~~ ~~ ~~ ~~ ~00~ 0~00 00000 ~. 0 ~ .................................................. ~ ~.~ O~ 0 O~ ~ .................................................. ~ ~ 0~ ~ O. 0 G~GNZ~ ~0~ D~ ~ ~ o ~.~ ....... · ........................................... .~ ~o~ .................................................. · ~ o ~ ................................................ z~ ~.o o o CDC) · ~0 ~'~ u~ ~O'-h ~0 "~-~ OZ~ ~'~0 · ~ ooo~ ooooo ooooo · . o , o o~ooo ~oooo 0000~ 0000~ ..... 0000~ 00000 ..... O0 ZZZZZZZZZZZZ~ZZZZZZZ O~Z~O~ ~ ~ ~ O0 ~ 0 ~ 0 , 0 -~. ~D O0 CO 00~0 00~00 00000 000~ 00000 0~000 0000~ 0~00~ 000~ ~~ 00~00 00~0~ 00000 000~ 000~0 0~000 0000~ 0~00~ 00000 00000 .................................................. ~ o ~ o ~ 0 ~ .................................................. ~ .... . ..... ..... ..... ... ..... .. ..... ..... ~ ~.~~. zzzzz zzzzz zzzzz zzzzz zzzzz zzzzz zzzzz zzzzz zzzzz zzzzz oo . o~ ~.~ .................................................. ~~ ~ ~ 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 ~. ~ ~ 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 O0 0~.~ ~ ~ ~ 0 0 Z~ 00000 00000 00000 00000 00000 00000 00000 00000 00000 00000 ... .......... . ...... . ..... .... .............. . ..... ..... ..... ooooo ooooo ..... ..... 00000 0000~ ...... .... ZZZZZ ZZZZZ ZZZZZ ~Z Z~ z ZZZZZZZZZZZZZZZZZZZZ ~ ooooooo~~~ 0 _.,i .--i ._1 _._l ..~ Z Z Z Z DO:~ Z Z DO ZZ Z Z Z Z o r--oo z I-- z 0 z z ~.~-~'D Z~D ZZ ~D ~Z~. ~- ~. ~ ~ ~ ~Z~Z ~ZZ ZZZ~ZZZ~ ZZ ~ ~ Z Z~ ~ ~ Z~ Z Z Z Z Z 0 0 Z , 0 · '~ N c'1- 0 ..,i. z "~ o o _1 ,,J. o rtl -ID 0 --4 z~ 0 ~ ::3"lCD (~) ~ ---~ '--' ~D 0 0 ....~ ct- Co "1=7 0 4::,, To[he order off 03-21-00 STATE OF ALASKA DaLe ALASKA OIL & GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE AK 99501 ***'**''''****100.00' Amount Void after 90 days Two ~gnatures required for amounu over $2S,000.00 ,"OO0O;OOqS~," ,:O65qOhS& O q qoooo"" WELL PERMIT CHECKLIST FIELD & POOL ~ ?(~) / ~..~' ADMINISTRATION 1. . 3. 4. 5. 6. 7. 8. 9. 10. 11. APPR D/yTE/ 12. ENGINEERING 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. I~ DATE 26. _ .¢[~. (:::~ 27. 28. 29. GEOLOGY 30. 31. 32. · 34. COMPANY .,,~.,,,"':'._.,:-.~ WELL NAM.~.~.Z~ INIT CLASS Permit fee attached ....................... Lease number appropriate ................... Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected pady ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... Conductor string provided ................... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg ........ CMT will cover all known productive horizons .......... Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. If a re-drill, has a 10-403 for abandonment been approved... Adequate wellbore separation proposed ............. If diverter required, does it meet regulations .......... ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N (B) will not contaminate freshwater; or cause drilling waste... Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N PROGRAM: exp ~ dev ~ redrll . serv~ GEOL AREA _,~? C__.) UNIT# ///_K'~ APPR DATE ~'N N N N N 'N !N ®U Y N wellbore seg ann. disposal para req ~ ON/OFF SHORE Drilling fluid program schematic & equip list adequate ..... BOPEs, do they meet regulation ................ (~ N BOPE press rating appropriate; test to _':J~3 _¢Y'~ psig. Choke manifold complies w/APl RP-53 (May 84) ........ Work will occur without operation shutdown ........... '.L~-~ Is presence of H2S gas probable ................. Permit can be issued w/o hydrogen sulfide measures ..... Y N Data presented on potential overpressure zones ....... Seismic analysis of shallow gas zones .............. Seabed condition survey (if off-shore) ............. Contact name/phone for weekly progress reports [exploratoryo/~Y N GEOLOGY: ENGINEERING: UIC/Annular TM TE M (--~....,---,,., COMMISSION: Comments/Instructions: '0 Z m z rn c:\msoffice\wordian\diana\checklist (rev. 02/17/00) 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 APPENDIXl ., No 'special'effort has been made to chronologically organize this category of information. o. Sperry-Sun Drilling Services LIS Scan utility SRevision: 3 $ LisLib SRevision: 4 $ Thu Nov 30 12:14:10 2000 Reel Header Service name ............. LISTPE Date ..................... 00/11/30 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 00/11/30 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA (Tarn Pool) JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: MWD RUN 2 AK-MM-00049 B. HENNINGSE R. SPRINGER 2N-347 501032033700 PHILLIPS Alaska, Sperry Sun 30-NOV-00 MWD RUN 3 AK-MM-00049 J. MARTIN D. GLADDEN 3 9N 7E 151 1143 155.58 Inc. DERRICK FLOOR: 154.25 GROUND LEVEL: 119.90 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 115.0 9.875 7.630 4210.0 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE STATED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 3. MWD RUNS 2 A_ND 3 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE 4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND STABILIZED LITH-DENSITY (SLD) . 4. GAMMA RAY LOGGED BEHIND CASING TO 4210' MD, 2300'TVD 5. DEPTH SHIFTING / CORRECTION OF MWD DATA IS WAIVED PER THE EMAIL MESSAGE FROM D. SCHWARTZ OF PHILLIPS ALASKA INC. OF 9/12/00. MWD DATA CONSIDERED PDC. 6. MWD RUNS 1 - 3 REPRESENT WELL 2N-347 WITH API 50-103-20337-00. THIS WELL REACHED A TOTAL DEPTH OF 12735'MD, 5268'TVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING ) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SHALLOW SPACING ) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING ) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING ) SFXE = SMOOTHED FORMATION EXPOSURE TIME SBD2 = SMOOTHED BULK DENSITY (LOW-COUNT BIN) SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE) CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE ENVIRONMENTAL PARJkMETERS USED IN PROCESSING THE NEUTRON LOG DATA: HOLE SIZE: 6.75" MUD WEIGHT: 9.60 - 10.0 PPG MUD FILTRATE SALINITY: 400 PPM CHLORIDES FORMATION WATER SALINITY: 19,149 PPM CHLORIDES FLUID DENSITY: 1.00 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/11/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPX RPS RPM RPD NPHI NCNT FCNT RHOB DRHO PEF FET ROP $ START DEPTH 4167 0 4200 0 4200 0 4200 0 4200 0 4200 0 4200 0 4200 0 4200 5 4200 5 4200 5 4221 0 4221 5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) STOP DEPTH 12680 0 12687 0 12687 0 12687 0 12687 0 12643 5 12643 5 12643 5 12658 5 12658 5 12658 5 12687 0 12734 5 LI69I L~OI£'E 88891 t'£890E 8889I ~0I'69E 8889I I9£5'S£ ££69I 6SL££'I S£69I L~EE'9 SL69I 9£L~'9 SL69I §£69I ~£918'~ AEOLI Z0'6II tE0£I 8L'6~I 9£ItI SL'0S~8 089I~ ~8'6S8I 9£'ES 98'6£ 000E 000E 0005 9£'I~ 90'I£E I9'~£9£ S'~CLEI £9'T HO/© GMN ~OHH 8'£68~I 0£dO 58'£51 0£dO 6~'8 S-Ad ~MN IHdN ££'0 E'0 II'I 8£'I 8£'I ~6'I H/i~ CMN dOH £9T~ ~I ES 89 ET 8~ 89 EI ~ 89 II 0~ 89 0I 9£ 89 6 E£ 89 8 8E 89 £ ~E 89 9 0E 89 ~ 9I 89 ~ EI 89 £ 8 89 E ~ 89 I 0 89 I~UU~q~ ~s~o ~poD d~H I ~ Z/S CMN ~ I ~ ND/© ~MN SOH~ I ~ 0£dD CMN ~NDN I 5 S-Ad ~MN IHdM I ~ NNHO CMN XdH I ~ Id~ GMN HO I ~ H/L~ CMN dOH mmSN oz~s s2Iufl ~op~o OOIA~OS omen 0'''~dXq-qns ZooI~ uoTqeOT~To~dS mnqec ....................... sqTufl SE'666-' ..................... ~nI~ qu~sq-lf psuT~pu~ ............. p~oo~ ~d s~m~:~ NII' 09 ..................... 6uTm~dS psuT~spu~ .............. quIod ~mu~H q~S ........... SqTUn qqd~p 5oI u~oQ ................. uoTqm~TC 5u!55oq 0 ..... ~clXL ~ooI~ UOTq~OT~T~d$ 0 .................. ~dX~ p~oo~H p~oo~H uoTq~oT~To~ds q~m~o~ S'~£LEI S'66EOI S'66EOI 0'tgI~ ZS~5 ZDHZN dOg ZQOD qOOL hsd HLdZG ZNIqZS~ DRHO MWD G/CM -0.648 0.856 PEF MWD B/E 1.21 13.94 0.0641201 16917 3.22096 16917 4200.5 4200.5 12658.5 12658.5 First Reading For Entire File .......... 4167 Last Reading For Entire File ........... 12734.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/11/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/11/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name. ...... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE GR RPD NCNT FCNT RPM RPS RPX NPHI PEF DRHO RHOB FET ROP $ LOG HEADER DATA DATE LOGGED: 2 .5000 START DEPTH 4167 0 4200 0 4200 0 4200 0 4200 0 4200 0 4200 0 4200 0 4200 5 4200 5 4200 5 4221 0 4221 5 STOP DEPTH 10245 0 10252 0 10208 5 10208 5 10252 0 10252 0 10252 0 10208 5 10223 5 10223 5 10223 5 10252 0 10299 5 29-NLAY- 00 0'0£ O'OL O' O'OL O0~'T O08'Y £L~' ' O~L ' 0'~ 0'6 0'5~ 09'6 0S£'9 ~%NM68~I08d I'lL 9'69 0'00£0I I~'0 E'S0'~ ~qTsuI §E'666-' ..................... anleA peu!gepu~ ............. p~o3e~ ~ed seme~g NII' 09 ..................... ~u7oed$ p~uI~epu~ .............. ~uIo6 e3u~ze~eH ~e~ ........... s~!un q~d~p BoI u~oG ................. 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STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/11/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NPHI 10209 0 12643 5 FCNT 10209 0 12643 5 NCNT 10209 0 12643 5 PEF 10224 0 12658 5 RHOB 10224 0 12658 5 DRHO 10224 0 12658 5 GR 10245 5 12680 0 RPM 10252 5 12687 0 RPS 10252 5 12687 0 RPD 10252 5 12687 0 FET 10252 5 12687 0 RPX 10252 5 12687 0 ROP 10300 0 12734 5 $ LOG HEADER DATA DATE LOGGED: 03-JUN-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite 4.05.2 DOWNHOLE SOFTWARE VERSION: 0.41 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 12735.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 54.3 MAXIMUM ANGLE: 74.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): TOOL NUMBER PB01520FGR4 PB01520FGR4 PB01428NL4 PB01428NL4 6.750 DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... 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UTBT~o o~/zz/oo .......... : .......... Zd~SI~ ............. ~meu ~OT~S ~iTe~L ~de£ ~00'SlTSLS ........... ~meN ~ITa ~x~N O~ ................ ~dXi ~I!S 0£/II/00 ....... uo!j~u@© ~o 0'0't ........... ~qmnN uo!s~A · ''~meN I~ qns £00'~I~SLS ............. ~meu ~OTA~S ~ITe~i ~IT~ S'~££gI ........... aITa ~xI2ua ~oa 6uTpe~a 60EOI .......... ~ITZ e~TquZ ~o~ 6uTpee~ qS~T~ S 8S9EI g 8S9EI fi £~9ET fi £~9EI £89~I L89EI L89EI t89EI L89EI 089~I S'~£LEI ~'~£g~I 6uTpeo~ 60g0I 60COI 60EOI S ESEOI S ESEOI S ESEOI S S~COI 00£0I 60EOI 5uTpee~ 0£8~ 0A85 0£8~ 0£8~ 0£85 0£8~ 068~ 068~ 068~ 068~ 068~ 0L8~ OL8~ ~OS mes~ ISI0'C 866~950'0 L9£0~'5 5'S69IC 5SE'60C 6SL9'EC L~6I'~ 98~£~'9 LI68E'9 L~I'9 68S9L'S 6sg'EEI SE£O'E6 8'IL~II ue@W 60'8 9S8'0 ~'~969£ 98'6£ E8'S~ S6'6~ 8L'IS 9£'1~ 99T EE'0I£ S'~£LCI IE'I 5~I'0- 58'I S'£9SLI 6'86I IE II 9~ 0 65 I I~ I 851 E'O£ ~6'I 60EOI MD/© 0£0QMM SOHN 0£dD 0£0~MM 0£dD 0£0~MM LND~ S-~d 0£0~MM IHdN ~H 0E0~MH MMHO 0£0~MM MMHO 0£0~MM MWHO O£O~MW IdV 0£0~MH H/L~ 0£0~MH dOH
