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Home My WebLink About200-169 1m. Project Well History File cov.age XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. :1 00- 1 bo/- Well History File Identifier Organizing (done) RES CAN D Two-Sided III 111111111I111111 Scanning Preparation á x 30 = l:iD-- D Rescan Needed III 1111111111111111 OVERSIZED (Scannable) 0 Maps: 0 Other items scannable by large scanner OVERSIZED (Non-Scannable) 0 Logs of various kinds 0 Other . DATeS 7 Jel Y11 1111111111I 11111111 VVlP 0 Color items: 0 Grayscale items: 0 Poor Quality Originals: 0 Other: DIGIT~ ~ Diskettes, No. .~ o Other, NolType NOTES: BY: BEVERLY ROBIN VINCENT SHERYL .EJ;INDY Project Proofing BY: BEVERLY ROBIN VINCENT SHERe WINDY BY: BEVERLY ROBIN VINCENT SHERYLelNDY VV1 Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: lo,!} PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: -+ YES _ NO BY: BEVERL1~~~~.'0NCENT SHERYL MARIA WINDY DATE: /f-I5:t';!3/~~ Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPA~~ERE FOUND: YES NO 'v: BEVE" v RO'," ""CEN, SHER'" MAR" ,W D^,"'.LJ -15-~ (~~:~~'~~~~'~~~~~C~L~~~ ~~~'~~~:SS)ECIAL ATTENTION IS REQUIRED ON AN I AGE BASIS 1111111111111111111 ReScan ned (ìmJívídl1ô/ p"ge ¡special ,~ttontionJ .scanning camp/clod) III II 11111111111111 RESCANNED BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: ISI General Notes or Comments about this file: Quality Checked (done) 1111111111111111111 12/1 O/02Rev3NOTScanned. wpd • • 6,I' \\V/7--; HESTATE 6 Gac AV'} ' f - - -- 333 West Seventh Avenue GOVERNOR SEAN '.AR�FIAnchorage Alaska 99501 3572 r✓roin: 907.279 1 433 ALA-El 90/ 273, 754/ SC.P►NV1 Tyson Wiese © � tbq Workover Engineer `1 Q ConocoPhillips Alaska, Inc. V� P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Tarn Oil Pool, 2N-303 Sundry Number: 314-052 Dear Mr. Wiese: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P Foerster Chair DATED this *lay of January, 2014. Encl. EU CEIV STATE OF ALASKA 0.0" I'1E V AL :A OIL AND GAS CONSERVATION COMM. ON %.•1' JAN 2 2014 • APPLICATION FOR SUNDRY APPROVALS C 20 AAC 25.280 G '``� 1.Type of Request: Abandon r Rug for Redrill r < Perforate New Pool r Repair w ell r Change Ap r Qd Program r Suspend r Rug Perforations r . Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r Other: r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development 174 200-169 - 3.Address: Stratigraphic r Service r 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-103-20352-00 • 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will plapned perforations require spacing exception? Yes r No FY • 2N-303 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 380053,380054• Kuparuk River Field/Tarn Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 7057 • 5744 - 6920' • 5641' * 6250' none Casing Length Size MD TVD Burst Collapse CONDUCTOR 105 16 140' 140' SURFACE 2598 7.625 2632' 2298' PRODUCTION 7017 5.5 x 3.5 7049' 5739' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6562-6576 • 5366-5377 3.5 L-80 6270 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft) no packer NIPPLE-CAMCO'DS'NIPPLE TD=504 TVD=504 12.Attachments: Description Summary of Proposal • p 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development 17. Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/1/2014 Oil r Gas r WDSPL r Suspended r• 16.Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tyson Wiese @ 263-4250 Email: Tyson.M.Wiese(a.conocophillips.com Printed Name Tyson Wiese Title: Workover Engineer 1-1t 'Signature Phone:263-4250 Date _^t—f Commission Use Only Sundry Number: SZPluConditions of approval: Notify Commission so that a representative may witness --2- ‘4(-- 061- Plug g Integrity ' BOP Test Mechanical Integrity Test r Location Clearance r Other: ,t3 6 p ¢•e 5 - -to 3 50 O p s . RBDMSNAY v V 2014 Spacing Exception Required? Yes ❑ No u Subsequent Form Required: 1© —4 co APPROVED BY /- q / ,L Approved by: COMMISSIONER THE COMMISSION Date: / 2_ ppro�ORIGINAL IIr nths trom the d to of approval. Form 10-403(Revised 10/2012) 9Fk1 II z'2'-,r 1 Submit Form and Attachments in Duplicate VL l/28AgJ/7 • 2N-303 Plug for Redrill Permit to Drill #: 200-169 2N-303 Tarn Producer has been shut in since May2010 due to a tubingleak, as well as a failing C-MIT, which is believed to have been caused by casing corrosion (operated as a surface powered jet pump well). The objective of the proposed 2N-303 RST is to restore well integrity, allowing the shut-in well to a returned to production, improving Bermuda oil recovery and sweep efficiency. ri*faced U-e// •fCfrlq f e .a T i, Of 74-40 �' �}�ifry oQ e. T4er.11P /JO v�v i1 � /IC st/v�f � Procedure Summary: A'Cts00. i Z Slick Line/LRS: (Well Prep) 1. RIH and pull DMY from GLM #4 @ 6,206' KB. Load well with 130 bbls of diesel. 2. Pull CA-2 plug from nipple @ 6,250' KB. RIH and obtain updated SBHP. 3. B&F planned retainer set depth, and DMY drift for retainer assembly. 4. Pump 10 bbl injectivity test with diesel to ensure adequate rates for cementing. RDMO. Coil Tubing: Isolation Cement Plug) (500' 9) 1. Ensure the 10-403 Sundryhas been approved bythe AOGCC. PP 2. RIH and set cement retainer @ approx. 6,234' KB. 3. Pump 24 bbls of 15.8#Class G cement, squeezing off the Bermuda perfs, and bringing TOC in Tubing and IA to 5,759' KB (500' plug above seal assembly). F.P. RDMO. Digital Slick Line/ LRS: (Tag/Test plug) 1. WOC at least 24 hours prior to tag and test. 2. Notify the AOGCC (AOGCC.Inspectors@alaska.gov) of the timing of the cement plug tag and PT. Provide at least 24 hour notice. 3. Tag TOC @ approx. 5,759' KB. Perform C-MIT to 2,000 psi. Record Results. ✓" 4. Perform CBL from tubing tag to surface, locate TOC in IA if any. 5. Punch tubing holes approx. 50' above TOC in IA (mid joint). 6. Circ. 10 bbls of diesel to ensure adequate rates/pressure for cementing ops. 7. If C-MIT passed, utilize Digital Slickline to complete Option 1.) below. 8. If C-MIT failed, E-line will be required to perform the Ultrasonic LDL in Option 2.) below. TW • Option 1: (C-MIT Passed) Digital Slick Line/LRS: 1. Circulate 78 bbls of Corr. Inh. 8.6#SW and 42 bbls of diesel F.P. U-Tube at Surface. 2. RIH and Jet Cut 3 1/2"tubing at approx. 3,100' KB (mid joint). RDMO. Ready for BPV. Option 2: (C-MIT failed) E-Line/ LRS: 1. Perform Ultrasonic LDL to attempt to find 5 'h" casing leak above TOC. 2. If casing leak is found shallow in first 2,800' of casing (rig will cut/pull), pump 78 bbls of KWF and 42 bbls of F.P., cut 3 '/"tubing at approx. 3,100' KB. RDMO. If Ultrasonic LDL is unable to locate any casing leaks Coil Tubing: (2nd Cement Plug) 1. RIH and tag TOC @ approx. 5,759' KB. 2. Lay in 45 bbls of 15.8#Class G Cement, to bring TOC in Tubing and IA to 3,600' KB. 3. RDMO. Digital Slick Line/ Little Red: 1. WOC at least 24 hours prior to tag and test. 2. Tag TOC @ approx. 3,600' KB. Perform MIT-IA and MIT-T to 2,000 psi. Record Results. Note: If MIT-IA still fails after 2nd plug test, a shallow casing leak still exists, and the rig will be cutting/pulling that section of 5 W'casing. 3. Jet Cut 3 %2" Tubing @ approx. 3,100' KB (mid joint). Document TxIA communication. 4. If no TxIA communication is seen, run CBL, locate TOC in IA, and reattempt tubing cut. 5. Circulate 29 bbls of Corr. Inh. 8.6# KWF and 42 bbls of diesel F.P. U-tube at Surface. 6. RDMO. Ready for BPV. TW Rig Proposed Plan: The proposed scope of work for the forthcoming sundry application includes: 1. MIRU Nabors 9ES onto 2N-303A. 2. Test 5 '/" casing, 5 %2" casing pack off and BPV through inner annulus to 2,000 psi for 10 minutes, chart PT. 3. Test tree adaptor to 5,000 psi. 4. Pull BPV. 5. Circulate diesel freeze protect out through the tubing cut at-3,000' MD, swapping over to seawater through tree, taking returns to tiger tank. 6. Set BPV and test through inner annulus to 2,000 psi. 7. Set blanking plug. 8. Nipple down tree. 9. Notify AOGCC field inspector 24 hours prior to BOPE test. 10. Nipple up BOPE and test to 250/3500 psi with 3 'A", 4" and 5 '/2' test joints. �- 11. Remove blanking plug and BPV. 12. Stand back 3-1/2"tubing (pre-cut at-3,000 MD). 13. Run 5 %2"casing scraper on 3 '/2" tubing to -2,950' MD, circulate clean, POOH, LD 3 /" tubing 14. Run 5 %2" Baker CIBP on wireline and set at-2,900' MD. PT to 2,500 psi 17 15. Run in hole with wireline mechanical casing cutter and cut casing at 2,800'MD. 16. Flush 5 '/2"x 7%" annulus with seawater taking returns to tiger tank. 17. Pull 5 '/2" casing to surface and lay down same. a. If casing is stuck and will not come free b. RIH with wireline casing cutter again and cut 5 'A"casing @ 2550'MD c. POOH with upper portion of 5 '/z" casing d. PU 4", XT-40 drill pipe, RIH with spear and fishing jars, retrieve lower portion of 5 %2" casing 18. RIH with 3 'A"tubing or(4"drill pipe with 3 '/" stinger) and set cement plug from the top of bridge plug @ 2,900'MD to 200 ft inside the the 7%" surface shoe. POOH and lay down 3 %" tubing or stand back the 4" drill pipe) 19. P/U directional drilling BHA and RIH on the 4", XT-40 drill pipe. Tag TOC and pressure test surface casing and kick off plug to 2,500 psi. 20. Displace seawater to 9.0 ppg LSND mud system 21. Dress off cement kickoff plug and control drill to below surface casing shoe. 22. Drill out 20' of new formation and perform FIT/LOT. 23. Ready to move into drilling phase under new PTD. 24. Begin new PTD. Begin two-week BOPE testing cycle. TW • Current Well Schematic: KUP PROD 2N-303 s ConocoPhillips Well Attributes Max Angle&MD TD Alaska Ince Waltham,APF01) Pie./lame WellhDre statue n I I"-1 MD IhOBI Act Bun(81451 c,waeinweps 501U320352(Hi IARN PART ICIPAT INC AREA PROD c 41.40 1,689.7'3 7.057,0 .-. HIS(ppm) Date Annotation End Date K8-Ptd(8) Rip Release Date era-3036"510'1619'.Yt AM. SSSV'NIPPLE 35 1/14/2010 Last WO: 12/29/2000 43.12 11`18/2000 vanesl Nnamabc WARP Annotation Depth 16x8) End Date Annotation Lae,Mod By End Date Last Tag.SLM 6.548.0 9/11:2013 Rev Reason TAG.RESET PLUG haggea 9/23/2013 Casing Strings • t I Casing Description OD tin, m fell Tee(80191 set Dep.(80111 let Depth(TVDI...Wtlen K...Crede Top Thread Il CONDUCTOR 30- 16 15.062 350 140.0 140.0 62.50 H-40 WELDED a: ed -� • 1� Caning Dee<nplien OD(to) ID Iml Top(Rest Set Dep.MKS, Set Dep.(TVDI...Wt:len p...Grade Top Thread -t SURFACE 756.875 34.5 2.632.1 2,298.4 29-70 L-80 BTCM Casing Deecripuon + !8 OD nnl ID Inl Top IIKBI Sat Dap.hail) Sat Dope,(TVDI...w"-.1"5"O ,Len It-..Grade Top Thread ��y PRODUCTION 5 1.2 4.950 32.4 7,049.2 5.738.5 15 50 L-80 BTC MOD Li ._7I t i, 5.5"z3.5"(gr.6275' V ii Tubing Strings Tuning Description String Me...ID DM TOP(814M) SM Dap.(h.. Set Depth(TVD)(...Wt 110011 Grade Top Connection Completion Details 2 30.5 6.270.3 5.1400 9.30 L-80 EUE8rdMO0 TUBING 1122 � p �.C''''''''")'$'3'r.70-='''''''-'`-"-' Nominal ID 350.1aou I Top 111051 Top ITVDI(8051 Top Incl(°) kern Dee Corn tint 30.5 30.5 0.05 HANGER FMC GEN V TUBING HANGER 3 500 NIPPLE.SO4 t I toe 1 504.4 503.9 7,09 NIPPLE CAMCO DS'NIPPLE 2.875 6 165.6 5.057.5 37.19.SLEEVE-C BAKER CMU SLIDING SLEEVE-CLOSED 4/6/2010 2.813 • 6.250.1 5.124.3 38.42 NIPPLE CAMCO D'NIPPLE NO GO 2.750 6,257.1 5.129.8 38.54 LOCATOR BAKER LOCATOR 2.985 6.2591 5 131.3 38.57 SEAL ASSY BAKER SEAL ASSEMBLY 2.985 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top ITVDI Top toot ;W_ ,,rT_.120 a Top 181451 1.0,11'I Dee Con, MM Run Date ID I 6,250.0 5.124.2 38.42 PLUG 2.75"CA-2 PLUG 9:11/2013 0.000 Perforations&Slots Shot Dane Top(TVO) rim(TVDI leholsif Top(8141) Bun MK.) 181411 180161 Zone Date tl Type Com 6,5620' 6.576.0 6,366.4 5,377.2 S-3,2N-303 122001 4.0 (PERT 2.5"HOD;180 deg phase...1-90 deg from high sIde -�"`-=E------='- Stimulations&Treatments Min Top Max ttm Dep. Dep. Top(TVDI Bim(TVDI 180131 18061 (hKBI 1805) Type Date I 6,562.0 6,5/60 5.3664 5.377.2 FRAC 1.11,2001 INITIAL FRAC TREATMENT B Mandrel Details - ad C '- on Top(TVOI Valve Latch Port Size TRO Run o Ito Top(8081 111088 Make Model OD IIM Sery Type Type (Int Weil Run Date in - I 2,420.3 2.134.6 CAMCO 0130-2-9 1 GAS LIFT DMY DIM 0.000 0.0 4:17/2006 Gee^' y Lta7.64620 0 2 4.285 1 3.579.4 CAMCO KBG-2-9 1 GAS LIFT LIMY -DTM 0.000 U.0 4'17,2006 ti 3 5.462 0 4,495 7 CAMCO 500-2-9 1 GAS UFT DMV DIM 0.000 0.0 4/1772006 ~ 4 6.205.1 5.089.6 CAMCO KBG-2-9 1 GAS LIFT OW BTM 0.000 0.0 4,18/2006 p_65.5-C.616561 Notes:General&Safety P0,10a1a Annotation • �--i 4;212006 NOTE:TUBING LEAK DETECTED yfp 5020' • 6.17:2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9,0 GAS LIFT:6206 trce ce PLUG:8.2500-.--.. /.: NIPRE:B�^50 E LOCATOR:8257 1- SEAL ASS v:6250 t rRAC:fi 562 D WERr,666'04576.g PRODUCTION .. I PRODUCTION 5.r.1.6'8t __ 8275:32!-7.0402-- _ TW Proposed Schematics: TW 1-15-2014 2N-303 Option 1 - Plug for Redrill (Passing C-MIT) PTD #: 200-169 Notes: C-MIT(TxlA)failed on 5/8/10 @ LLR of 4.7 GPM. Ultrasonic LDL ran on 5131/10,no leak found planned Plua Back Leak @ Seal Assembly or Prod.Casing All16"62.50#H-40 Conductor @ 140'KB Ihkin Summary: S.L: 2 875'DS Nipple @ 504'KB 0 1.)RIH and pull DMY from GLM#4 @ 6,206'. KWF to 2.000'KB with Diesel F.P to surface 2.)Load well with 130 bbls Diesel. 3.)Pull CA-2 plug from nipple @ 6.250'. 4.)Obtain updated SBHP 5.)DMY drift for cement retainer and B&F planned set depth. 7.58"29 7#L-80 Surface Casing @ 2,632'KB AI 6.)Pump injection test with 10 bbls diesel to insure rates for cementing GLM's: CTU: Dr>ly(a?2,420'KB DMY l/4,285'KB 1.)RIH and set retainer @ approx.6.234'. DMY @ 5,462'KB — 2.)Pump 24 bbls of 15.8#Class G cement OPEN @ 6,206'KB to squeeze the pelts and bring TOC in TxIA to approx.5,759'. Est.Ongmal5'i'x't 1'3'Casing TOC (13#Lead)@ approx 4,890'KBa ' j Digital Slickllne: Known Tubing Leak @ 5,020'KB a ...... f _3 1.)WOC 24 hours, Notify AOGCC 24 hrs in advance for witness. V,</;; '--- 2.)Tag TOC C'approx.5,759' TOC @ 6.759'KB ,,, jj ff/ , / //,r 3.)C-MIT(TxIA)to 2,000 psi . 4.)Run CBL Log to locate TOC in IA(if any) '' / �%-1 6.)Punch holes in Tubing mid-joint above TOC. Baker CMU Sliding Sleeve 6.)Circ.78 bbls of Corr.Inh.8.6#KWF and 42 g ' , O bbls of Diesel F.P. U-Tube at Surface. (CLOSED)@ 6.166'KB 7.)RIH with Jet Cutter and cut 3's"Tubing @ approx 3.100'B(mid joint), RDMO P,. //; 3/ / Weatherford Cement Retainer @ approx / 6.234'KB /r/�A/• �//• 2.75"Camco D Nipple 0 6,250'KB / _' /,rf ,�,�/� Baker 80-40 Casing Seal Receptacle //:, / /f (5 n x 3 12")(a?6,259'KB • +� /''!"??.'''''?;'%,/ 3 I'Tubing to 6.270'KB ff9``' 5 i'Prod Casing from Surface-6,275'KB Peri Interval 6.562'-6,576'KB(Bermuda S-3) Estimated KWF=6.5# Fill fag: rdG548': 3',a,Prod.Casing from 6,275'KB-7,049'KB • • . . .• TW TW 1-15-2014 2N-303 Option 2 - Plug for Redrill (Failing C-MIT) PTD #: 200-169 Notes: C-MIT(TxIA)failed on 5/8/10 @ LLR of 4.7 GPM. Ultrasonic LDL ran on 5/31/10,no leak found Planned Piva Back Leak i Seal Assembly or Prod.Casing 16"62.50#H-40 Conductor i 140'KB A Summary: S.L: 2875"DS Nipple C(504'KB L. l '.1.)R11-I and pull DMY from GLM#4 Cr,6,206'. KWF to 2.000'KB with Diesel F.P to surface 2.))Load weth 13Di 3. Pull CA-2ll plug from0 nipple Ld 6 '. 4.)Obtain updated 5BHPbbis 5.)DMY drift for cement retainer and Be, 7 518"29.7*L-80 Surface Casing a 2,637 KB planned set depth. 6.)Pump injectiowin test with 1Desel.bbls diesel Tubing Cut @ 3,100'KB 411 to insure rates for cementing. TOC 2i0 Plug @,3,600'KB CTU: GLM's DMY ell 2,420'KB 1.)RIH and set retainer i I,approx.6,234'. DMY(a?4.285'KB �/� 2.)Pump 24 bbls of 15.8#Class G cement DMY ll 5,462'KB 4(1' to squeeze the perfs and bring TOC in OPEN @ 6,206'KB k TxIA to approx.5.759'. Est Original 5 W x 3 W Casing TOC(13#Lead)a 4,890'KB Digital Slickline: rio, - 1.)WOC 24 hours. Notify AOGCC 24 hrs in Known Tubing Leak @ 5,020'KB advance for witness. 1:0;;SaY,, . 2.)Tag TOC approx.5,759' TOC 1"Plug ct 5,759'KB / A 3.)C-MIT(TxIA)to 2,000 psi.(FAILED) 4.)Run CBL Log to locate TOC in IA(if any) 5.)Punch holes in Tubing mid-joint above TOC. 6.)Circ.10 bbls of diesel to confirm circ.to IA. Baker CMU Sliding Sleeve (CLOSED)0_,6,166 KB ' , ', E-Line: .7 1.)Run Archer Ultrasonic LDL to try to locate casing leak depth. 2,)If leak depth is found shallow(in casing that /, /r rig will cut/pull,pump 78 bbls KWF and 42 bbls of �! � diesel F.P,and cut 3':"Tubing at approx.3.100' Weatherford Cement Retainer @ approx. KB. RDMO 6231'KE i 2.75"Camco D Nipple ED 6.250'KB „ / If No Leak is Found during LDL: CTU: 1.)RIH and tag TOC(,§approx.5,759'. 7 / 2.)Lay in 45 bbls of 15.8#Class G cement into Baker 80-40 Casing Seal Receptacle / TxIA.bringing TOC to approx.3.600'KB. RDMO (5'z'x 3'-.')@ 6,25. KB 6/. / :I. nr/ Digital Slickline: 3''a'Tubing to 6,270'KB iy / /l 1.)WOC 24 hours. Notify AOGCC 24 hrs in 5 I,'Prod Casing from Surface-6,275'KB // advance for witness of 2°'plug test. A 2)Tag TOC e.approx.3,600'.MIT-T and MIT-IA to 2.000 psi. Perf Interval Note:Rig plans to cut/puff casing,repairing any c 6.562'-Estimated KB(Bermuda S-3) . . . . . shallow casing teaks that might have caused EimateKWF=6.9# failing pressure tests. iji?19 4 6,b48' 3.)RD-land Jet Cut 3':"Tubing Cr/approx.3,100' 4.)Circ.33 bbls of Corr.Inh.8.6#KWF and 42 3'2':Prod.Casing from 6.275 KB-7.040'KB ' ': bbls of diesel F.P. U-Tube at Surface. RDMO. TW Roby, David S (DOA) From: Manoppo, Elan Rizaldi <Elan.R.Manoppo@conocophillips.com> Sent: Thursday,January 23, 2014 10:26 AM To: Roby, David S (DOA) Cc: Lewis,Adam M (Alaska);Wiese, Tyson M Subject: RE: Sundry Application for KRU 2N-303 Well David, I confirm Tyson's answer below. We could pretty much say it's a twin since 2N-303A bottom hole location locationklocated slightly less than 500 ft to the east of the existing 2N-303. 2N-303A will target the same reserve as 2N-303 did which is the oil pool in Bermuda formation. In addition, it is also Planned to target the underlying Purple formation to test its potential. Thank you for your kind attention and just let me know if you need more clarification. Regards, Elan Rizaldi Manoppo Greater Tarn Development Coordinator ConocoPhillips Alaska 0+1(907) 263-4323 M +1 (907) 280-9726 From: Wiese,Tyson M Sent: Thursday,January 23, 2014 7:57 AM To: Roby, David S (DOA) Cc: Manoppo, Elan Rizaldi Subject: RE: Sundry Application for KRU 2N-303 Well David, The well integrity repair is related to the 5'/z" Casing that the rig will pull/replace during the RST. The rig will cut/pull the corroded 5'/z"casing and potential the leak point(we have a failing C-MIT). The rig will then place a KOP and RST out of the plugged back mother bore,to access the Bermuda formation. I believe the RST is designed to drill/complete across the same Bermuda Pool as the original 2N-303 well, but to confirm, I will pass that question onto the Drillsite Engineer as his team is more familiar with the RST objectives. Thanks, Tyson Wiese ConocoPhillips Wells Engineer Office:1-907-263-4250 Ce11:1-907-230-5388 From: Roby, David S(DOA) [mailto:dave.roby( alaska.gov] Sent: Wednesday,January 22, 2014 5:54 PM To: Wiese,Tyson M Subject: [EXTERNAL]Sundry Application for KRU 2N-303 Well 1 Tyson, I am reviewing your application to plug the subject well in preparation of a rotary side track and have a question. In the application it states that the objective is to restore well integrity to allow the well to be returned to service. Is the 2N- 303 RST planned as a twin of the existing wellbore,or will it be targeting reserves not currently being accessed in the pool? Thanks in advance, Dave Roby Sr. Reservoir Engineer Alaska Oil and Gas Conservation Commission (907) 793-1232 2 • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 April 13, 2011 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 1 v - 303 Anchorage, AK 99501 Commissioner Dan Seamount: �r k° � !� 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 cement was pumped November 11, 2001. The corrosion inhibitor /sealant was pumped February 17 and 18, 2011. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907 - 659 -7043, if you have any questions. Sincerely, Perry Klein ConocoPhillips Well Integrity Projects Supervisor • 0 ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Kuparuk Field Date 4113111 2M & 2N 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 2M -05 50103201680000 1920470 Surface NA 16" NA 2.5 2/17/2011 2M -06 50103201760000 1920770 Surface NA 19" NA 2.5 2/18/2011 2M -30 50103201800000 1920840 Surface NA 16" NA 4.25 2/17/2011 2N -303 50103203520000 2001690 26' 5.00 20" 11/8/2001 4.4 2/17/2011 2N -306 50103204900000 2040620 SF NA 24" NA 2 2/17/2011 2N -310 50103205490000 2070900 SF NA 28" NA 5.1 2/17/2011 2N -342 50103205470000 2070680 24" NA 24" , NA 7 2/17/2011 2N-303 10-404 Resubmit New Summary 082608.x1s • Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com) Sent: Tuesday, August 26, 2008 2:29 PM To: Maunder, Thomas E (DOA) Subject: 2N-303 10-404 Resubmit New Summary 082608.x1s Attachments: 2N-303 10-404 Resbmit New Summary 082608.x1s ..~~ - «2N-303 10-404 Resbmit New Summary 082608.x1s» Tom, As per your request, attached is the updated summary for the patch in the 2N-303 well. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 Cell 907-943-1720 / 1999 Pager 907-659-7000 #909 ~~~~~~ BUG ~ ~ 20~~ Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, August 20, 2008 12:24 PM To: NSK Problem Well Supv Cc: 'NSK Well Integrity Proj;'NSK Well Integrity Field Supv' Subject: 200-169_KRU_2N-303. pdf ,~ Attachments: 200-169_KRU_2N-303.pdf Martin, In early June you submitted a 404 (received 6/9) documenting the setting of tubing patch in this well. You followed up the original 404 with another (received 6/10). So far as I can see, the 404s were the same although you attached a note saying you had been notified from AOGCC that you had sent in the wrong form. I am a little confused here, however in conducting the review I have noted a few omissions from the 404 and have attached a marked up copy of the 404. Some of this ties into the "packer information" message I sent out yesterday. The long string in this well is a tapered 5-1/2" x 3-112". As such, there is a seal bore slightly below the XO that functions as a packer. Where seal bores are so employed, it should be noted on the 404. It is also appropriate to note the patch depth as well since the patch is a restriction in the tubing. The 404 reports the setting of a new patch in late May 2008. When was the patch that would have been in the well pulled? Call or message with any questions. Tom Maunder, PE AOGCC - ®® ii • • .JUN 1 ~ 2008 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska (71I & GaS Cons. Comtni$Sion REPORT OF SUNDRY WELL OPERATIONS Anchorage 1. operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other Q Patch ' Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ .Time Extension ^ ~~~~ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number. ConocoPhlllips Alaska, InC. Development ~ Exploratory ^ 200-169 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20352-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 156' 2N-303 8. Property Designation: [~ 10_ Field/Pool(s): .~ („ 3~(~jJ? !' L,/` . Q$ Kuparuk River Field / Tarn Oil Pool 11. Present Well Condition Summary: ~'v~\ n~e~~~ Total Depth measured 7057 feet ~~ ~ _ ~-~'~~ ~.~~ true vertical 5744' feet Plugs (measured) ~~ Effective Depth measured feet Junk {measured) ~, ~~ true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 140' 16" 140' SURFACE 2481' 7-5/8" 2637 PRODUCTION 6119' 5-1/2" 6275' PRODUCTION 774' 3- 1 /2" 7048' ` ` ~~-C~cS'e~ ~.G,S`c n.S s~tc~i ~~ i ~~°T G ~a r~r ) Perforation depth: Measured depth: 6562 - 6576 true vertical depth: 5366 - 5377 Tubing (size, grade, and measured depth) . 3-1/2" , L-80, 6270' MD. r ~~ Packers & SSSV (type & measured depth) no packer 5Q ~~ ~ W c+'lp~ ~~~ SSSV_MD = 504 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/q 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 313 ~ 617 253 2397 257 Subsequent to operation 442 ~ 915 175. 2422 259 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: OIIQ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NiA if C.O. Exempt NIA contact Martin Walters / Brent Rogers Printed Name M in W Iters Title Problem Wells Supervisor Signature Phone: 907-659-7224 Date 06/04/08 Pre red b Mafin Wafters 659-7224 ~ ~ I ~ AL ~~~ ~~uU ~ ~ ~o ~ ~~ Form 10-404 Revised 04/2006 '!submit Q~' '~ ~Ci1~ • • 2N-303 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 5/13/2008 5/21/2008 ~U E-line equipment, check tools, pressure test wellhead to 3000 psi. RIH w/ head, 2 weight gars, GR/CCL, safe head, Baker 10, and Weatherford ER packer (32'x2.75" max OD). RIH, :orrelate, set packer with mid-element at 5036'. (CCL stop depth = 5025 ; CCL to mid-element MIRU Slickline Unit. Make up .125" wire, 5' OF 2-1/8" stem, KJ ,OJ, KJ, and LSS. RIH w/ 2.78" centralizer, 3' stem, and 2.79" impression block. Tag top of lower ER packer @ 5012' SLM / 5035' RKB. POOH w/tools. Had impression of top of ER packer. Pressure test lubricator and RIH W/ ETD tools and Weatherford tubing patch. Stung into lower packer @ 5015' SLM / 5035' RKB. Wait for ETD tools to fire. POOH w/tools (lost 125#). RIH w/ 3-1/2" GRAND 3-1/2" ER test tool. Sting into upper packer Cad 4982' SLM / 5004' RKB. Initial T/1= 450/0: Pressure up tubing to 2500 psi and slowly bleeding back (monitor for 15 minutes and (came down to 2075 psi due to gas in tubing). Retest to 2500 psi and held solid for 20 minutes w/IA remaining @ 0 psi). Bleed back to 450 psi and POOH w/test tool. t 2N-303 DESCRIPTION OF WORK COMPLETED ' SUMMARY Date Event Summary 315108 PULLED K-3 /ECLIPSE STRADDLE PATCH ASS'Y @ 4980' RKB. IN PROGRESS. 316/08 3/7108 4!10108 511 /08 5!13/08 5/21 /08 BAILED FILL OFF SLIP STOP @ 6165' RKB 8~ PULLED SAME. ATTEMPTED PULL JET PUMP. IN PROGRESS. ATTEMPTED PULL JET PUMP @ 6165' RKB, NO SUCCESS. LEFT 3" JDC, X/O, 2.70 x 2.31 G BAIT SUB ON 2.81 CS LOCK @ 6165' RKB. READY FOR CTU. PULLED 3" RC JET PUMP #PH-1108 FROM 6147 CTMD, WELL IS FREEZE PROTECTED, TURNED OVER TO S/L. SET 2.$1"JET PUMP (OAL=62", 106 RATIO, SER# PH-1021) @ 6165' RKB. WELL READY ',FOR TBG PATCH RU E-line equipment, check tools, pressure test wellhead to 3000 psi. RIM w/ head, 2 weight bars, GR/CCL, safe head, Baker 10, and Weatherford ER packer (32'x2.75" max OD). RIH, correlate, set packer with mid-element at 5036'. (CCL stop depth = 5025'; CCL to mid-element = 11') MIRU Slickline Unit. Make up .125" wire, 5' OF 2-1/8" stem, KJ ,OJ, KJ, and LSS. RIH w/ 2.78" centralizer, 3' stem, and 2.79" impression block. Tag top of lower ER packer @ 5012' SLM / 5035' RKB. POOH w/tools. Had impression of top of ER packer. Pressure test lubricator and RIH W/ ETD tools and Weatherford tubing patch. Stung into lower packer @ 5015' SLM / 5035' RKB. Wait for ETD tools to fire. POOH w/tools (lost 125#). RIH w/ 3-1/2" GR AND 3-1/2" ER test tool. Sting into upper packer @ 4982' SLM / 5004' RKB. Initial T/1= 450/0. Pressure up tubing to 2500 psi and slowly bleeding back (monitor for 15 minutes and ',came down to 2075 psi due to gas in tubing). Retest to 2500 psi and held solid for 20 '~, minutes w/IA remaining @ 0 psi). Bleed back to 450 psi and POOH w/test tool. s~ ~/ . ,~ /~ ~t~~-~. ~Y~~~~~fs~~ifi~ NO. 4775 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # i ~'+. ;~~i~N~~ JUL ~ 2 2008 Log Description Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 07/10/08 2W-04 12061711 INJECTION PROFILE ja 06/24/08 1 1 1 L-20A 10215099 PRODUCTION PROFILE ~QU ~ 06/26/08 1 1 1 G-05 12080389 LDL 06/27/08 1 1 3B-10 12081714 INJECTION PROFILE °-' ~ t / '- 06/27/08 1 1 2L-327 12061715 SBHP SURVEY '-' (~ 06/28/08 1 1 1J-109 12080390 SBHP SURVEY / / 06/28/08 1 1 2N-323 12061716 SBHP SURVEY '~-- ~ 06/28/08 1 1 2X-15 12080392 SBHP SURVEY ~ - 06/29/08 1 1 2N-303 12061717 SBHP SURVEY 06/29/08 1 1 2L-309 12061718 SBHP SURVEY - j 06/29/08 1 1 2X-14 12080391 SBHP SURVEY / 06/29/08 1 1 2X-11 12080393 SBHP SURVEY Cf_ S 06/29!08 1 1 iG-09 12080401 INJECTION PROFILE V -- ( /~`j 07/05/08 1 1 2H-05 12080396 SBHP SURVEY L°~.-- 06/30/08 1 1 2H-12 12080395 SBHP SURVEY _ ~ 06/30/08 1 1 2H-11 12080394 SBHP SURVEY '- f 06/30/08 1 1 1D-07 12080398 SBHP SURVEY -~( 07/02/08 1 1 2N-341 12061720 SBHP SURVEY ~ O 06/30/08 1 1 3C-15 11982441 USIT - ~ / (p 07/04/08 1 1 2W-1U 11982445 INJECTION PROFILE `6 -- (p 07/08/08 1 1 1L-19 12061724 PRODUCTION PROFILE J O -6 07/10/08 1 1 2W-02 11982446 INJECTION PROFILE - ~ 07/09/08 1 1 • Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. :!', ,r-~ ~ ~... • STATE OF ALASKA • ~~~~~ i! D ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF S NDRY WELL OPERATION~~N 0 9 2008 -+vb,~~ 1. Operations Pertormed: Abandon ^ Repair Well Plug Perforations ^ ~ t0~ Stimulate~8~~ ~~~ ~ G~~~Ofl~ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ . Waiver ^ Tir~~~~y~~ ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConoCOPhillips Alaska, InC. Development ^~ Exploratory ^ 200-169 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20352-00 ' 7. KB Elevation (ft): 9. Well Name and Number: RKB 156' 2N-303 8. Property Designation: ~~ L 3~~~~3 ~ a: ~~~~~g 10. Field/Pool(s): Fi ld / T Oil P l K k Ri ver arn oo uparu e 11. Present Well Condition Summary: Total Depth measured 7057' feet true vertical 5744' ~ feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 140' 16" 140' SURFACE 2481' 7-5/8" 2637' PRODUCTION 6119' 5-1/2" 6275' PRODUCTION 774' 3-1/2" 7048' Perforation depth: Measured depth: 6562 - 6576 JUN ~ ~ 2008 ~~rP~I~NF~ true vertical depth: 5366 - 5377 Tubing (size, grade, and measured depth) 3-1/2" , L-80, 6270' MD. Packers & SSSV (type & measured depth) no packer SSSV_MD = 504 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/q 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 313 617 253 2397 257 Subsequent to operation 442 ~ 915 175 2422 259 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. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Martin Walters / Brent Rogers Printed Name M in W Iters Title P oblem Wells Supervisor Signature Ph;>n : ~ ~ -6 - ~ ~ Date 06/04/08 Pre ared b Martin Wafters 659- 224 Form 10-404 Revised 04/2006 Submit igi a O ~~~.~ ~~ 2N-303 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 5/13/2008 5/21 /2008 RU E-line equipment, check tools, pressure test wellhead to 3000 psi. RIH w/ head, 2 weight bars, GR/CCL, safe head, Baker 10, and Weatherford ER packer (32'x2.75" max OD). RIH, correlate, set packer with mid-element at 5036'. (CCL stop depth = 5025'; CCL to mid-element = 11') MIRU Slickline Unit. Make up .125" wire, 5' OF 2-1/8" stem, KJ ,OJ, KJ, and LSS. RIH w/ 2.78" centralizer, 3' stem, and 2.79" impression block. Tag top of lower ER packer @ 5012' SLM / 5035' RKB. POOH w/tools. Had impression of top of ER packer. Pressure test lubricator and RIH W/ ETD tools and Weatherford tubing patch. Stung into lower packer @ 5015' SLM / 5035' RKB. Wait for ETD tools to fire. POOH w/tools (lost 125#). RIH w/ 3-1/2" GRAND 3-1/2" ER test tool. Sting into upper packer (a~ 4982' SLM / 5004' RKB. Initial T/1= 450/0. Pressure up tubing to 2500 psi and slowly bleeding back (monitor for 15 minutes and came down to 2075 psi due to gas in tubing). Retest to 2500 psi and held solid for 20 minutes w/IA remaining @ 0 psi). Bleed back to 450 psi and POOH w/test tool. • • ~~~L ~~.di.~ ~R.4/U~fi~f/l ~l.4L ~# _ ~~_ ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTTJ 1) 2) Signed The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road suite C ~~~~®MAY ~ ~ 200& Anchorage, AK 99518 Fax (907] 245-8952 Caliper Report/ MfT 25•Apr-08 2N-3O3 1 Report/ E~ 50-103-20352-00 Print Name: PROACTNE DIAGNOSTIC SERVICES, INC., 13o W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)246-88952 E-MAIL: ~dSs~f:~h~~~tS®!~9?3?~i35`.t?~~',.~~f53 WEBSITE:`~f!'r~IV,9?'Se~'a?Cg'1ll~i„.~;~~'tl C:~Documents and Settings\Owner~Desktop\Tcansmit_Conoco.doc • ~ Memory Multi-Finger Caliper & MTl' Log Results summary Company: ConocoPhillips Alaska, Inc. Well: 2N-303 Log Date: Apri125, 2008 Pietd: Kuparuk Log No.: 9542 State: Alaska Run No.: 2 API No.: 50-103-20352-00 Pipet Desc.: 3.5" 9.3 Ib. L-80 EUE 8RD Top Log Intvl.: Surface Pipet Use: Tubing Bot. Log Intvl.; 6,270 Ft. (MD) Pipet Desc.: 5.5" 15.5 Ib. L-80 LTC MOD Top Log Intvl.: Surtace Pipet Use: Production Casing Bot. Log Intvl.: 6,275 Ft. (MD) Pipe3 Desc.: 7.625" 29.7 Ib. L-80 BTCM Top Log Intvl.: Surface Pipe3 Use: Surtace Casing Bot. Log Intvl.: 2,637 Ft. (MD) Pipe4 Desc.: 16" 62.5 Ib. H-40 Welded Top Log Intvl.: Surface Pipe4 Use: Conductor Bot. Log Intvl.: 140 Ft. (MD) Pipes Desc.: 3.5" 9.3 Ib. L-80 EUE 8RD Top Log Intvl.: 6,275Ft. (MD) Pipes Use: Liner Bo#. Log Intvt.: 6,312Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS i"his caliper and MTT data is tied into the top of the 3.5"liner @ 6,275' (Driller's Depth). INTERPRETATION OF CALIPER LOG RESULTS: This log was run to assess the condition of the 3.5"tubing and liner logged with respect to corrosive and mechanical damages. The 3.5" tubing and liner logged appears to be in good to fair condition, with a maximum wall penetrations of 30% in joint 163 (5,152'). The damage appears in the forms of Shallow Corrosion and Isolated Pitting. No significant areas of cross-sectional wall loss (> 6°k) ar I.D. restrictions are recorded throughout the 3.5" tubing and liner logged. 3.5" TUBING & LINER -MAXIMUM RECORDED WALL PENETRATIONS: tsolated Pitting (30%) Jt. 163 @ 5,152 Ft. (MD} Shallow Pitting (20°~) Jt. 158 @ 5,005 Ft. (MD) No other significant wall penetrations (> 19%) are recorded throughout the tubing and liner logged. 3.5" TUBING 8< LINER -MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS No significant areas ofcross-sectional wall loss (> 6%) are recorded throughout the tubing and liner logged. 3.5" TUBING 8< LINER -MAXIMUM RECORDED ID RESTRICTIONS No significant I,D. restrictions are recorded throughout the tubing and liner logged. ~~~~~ MAY (~ ~ ADO ' RroActive Diagnostic Services, Inc J P.O. Box 1369, Stafford, TX 77497 Phone: (281) or {888) 565-9085 Fax: (~81) 565-1369 E-mail: PDS~c~i memorylog.com Prudhoe Bay Field Office Phene: (907} 559-2307 Fax: (9fl7) 559-2314 1 ~GU- Il~°~ ~ l~l~D • • This is the second time a PDS caliper has been run in this well and the 3.5" tubing and liner have been logged. A comparison between this log and the previous log (April 29, 2006) indicates no increase in corrosive damage in the 3.5" tubing and liner logged. Comparison graphs illustrating the difference in maximum recorded wall penetrations between logs have been included in this report. The apparent decrease in recorded damage between logs is due to the previous report identifying manufactured features at the pin ends of the tubing as damage. The current log classifies these recordings as part of the makeup rather than the analyzed body of the joint. INTERPRETATION OF MTT LOG RESULTS A plot of average metal thickness as recorded by the MTT on a joint-by joint basis is included in this report, as well as detailed plots of the MTT recordings at 10Nz from surface to 200', across the bottom of the surface casing and across the bottom of the production casing is included in this report. The Delta Metal Thickness (%) curve in these plots refers to total metal surrounding the MTT tool, which includes both the tubing and casing strings. A maximum of 3% circumferential metal loss is recorded in the interval logged. The low frequency characteristic of this metal loss indication points to the probability that this is representative of damage or a manufactured feature in the casing in this well, rather than the tubing. ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS@memorylog.corr Prudhoe Bav Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 • • The percent circumferential metal loss expressed in this report is a percentage of the total metal that the tool is responding to, which includes influences from the 3.5", 5.5", 7.625" and 16" pipe. If all of the metal foss is specific to the 5.5" production casing, the percent metal loss from that pipe alone is probably higher than the numbers expressed. Some of the metal foss indicated could be from either the outside of the 2.875" tubing, the 5.5" production casing or the 20" conductor. Due to the concentric pipe strings in the log interval, the MTT response is qualitative -indicating an overall increase or decrease in metal surrounding the tool, but not distinguishing in which pipe string the change in metal thickness occurs. In this log, the MTT was calibrated down hole (273'), where the readings are assumed to represent undamaged tubing and casing. All other readings are relative to this reference point, which include influences from the 2.875" tubing, 5.5" production casing, and 20" conductor pipe. ' Field Engineer: S. Carpenter Analyst: HY. Yang & M. Lawrence Witness: C_ Fitzpatrick ProActive Diagnostic Services, Inc. / P.Q. Box 1369, Stafford, TX 77497 Phone: (281} or (888) 565-9085 Fax: (281) 565-1369 E-mail: PDS~memorylog.com Prudhoe Bay Field Office Phone; (907J 659-2307 Fax: (907; 659-2314 • • Maximum Recorded Penetration ~, `~.,. Comparison To Previous Well: 2N-303 Survey Date: April 25, 2008 Field: Kuparuk Prev. Date: April 29, 2006 Company: ConocoPhillips Alaska, Inc. Tool: UW MFC 24 No. 214320 Country: USA Tubing: 3.5" 9.3 Ib L-80 EUE SRD Overlay Max. R ec. Pen . (mils) 0 5 0 1 00 15 0 2 00 25 0 0.1 9 18 28 38 48 58 68 76.2 85 E 95 Z 105 e 115 125 135 142 152 162 172 179 189 195 il! April 25, 2 008 ^ April 2 9, 2006 1 1 1 1 1 1 I 1 1 1 1 i ^ • Correlation of Recorded Damage to Borehole Profile Pipet 3.5 in (15.9'-6285.6') Well: 2N-303 Field: Kuparuk Company: ConocoPhilips Alaska, Inc. Country: USA Survey Date: April 25, 2008 ^ Approx. Tool Deviation . Approx. Borehole Profile 19 775 1560 2342 GLM 1 O 3148 ~ ~ . s 3931 v GLM 2 4727 GI_M 3 5532 GLM 4 197 6286 0 50 100 Damage Profile (% wall) /Tool Deviation (degrees) Bottom of Survey = 197 1 25 50 ~ 100 E Z ~ 125 ~ o 150 175 I • .7 PDS Report Overview ~~ ~. Body Region Analysis Well: 2N-303 Survey Date: April 25, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Anal st: HY. Yan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom. Upset Upper len. Lower len. 3.5 ins 9.3 f L-80 EUE 8RD 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration and Metal Loss (°~ wall) ~ penetration body ,;:,~ metal loss body 200 150 100 50 0 0 to 1 to 10 to 20 to 40 to over 1% 10% 20% 40% 85% 85% Number of ~oints anal sed total = 210 pene. 0 38 171 1 0 0 loss 146 64 0 0 0 0 Damage Configuration (body ) 20 10 0 isolated general line ring hole/poss pitting corrosion corrosion corrosion ihle hole Number of'oints dama ed total = 22 6 16 0 0 0 Damage Profile (°~ wall) ~ penetration body ;; metal loss body 0 50 100 0 49 GLM 1 97 GLM 2 145 GLM 3 193 GLM 4 Bottom of Survey= 197 Analysis Overview page 2 • PDS REPORT JOINT TABI Pipe: 3.5 in 9.3 ppf L-80 EUE SRD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company: Nominal I.D.: 2.992 in Country: Survey Date: • 1lATION SHEET 2 N-303 Kuparuk ConocoPhilips Alaska, Inc. USA April 25, 2008 Joint No. )t. Depth (Ft) I'c~n. lJlse~) Ilm.) Pen. Body (Ins.) Pcv~. °/~ ~1~~t;~l I uss ",4. Min. LD. (Ins.) Comments Damage Profile (%wall) 0 50 100 .1 16 i.) 0.01 2 t) 2.95 PUP 1 19 t) 0.03 1 1 ? 2.94 1.1 50 U 0.03 1 Z I 2.95 PUP 2 54 0 0.03 11 1 .95 3 86 t) 0.03 1 U I 2.93 4 117 l1 0.03 1 1 1 2.95 5 148 a 0.03 11 I 2.95 6 179 (1 0.03 1 U ~ 2.94 7 210 (1 0.03 I 1 I 2.94 8 24 t) 0.03 ltl I 2.95 9 273 l) .03 12 I 2.95 10 305 U 0.03 1 Z 1 2.95 11 335 t) 0.03 11 I 2.95 12 366 c) 0.03 11 I 2.94 13 398 U 0.03 II I 2.95 14 429 U 0.03 11 I 2.95 1 460 l1 0.04 I i 2.93 Sallow corrosion. 15.1 492 l) 0 l) t) 2.88 Camco'DS Ni le 16 493 O 0.03 1 Z I 2.95 17 525 U 0.03 11 I 2.94 18 556 tt 0.03 11 i 2.95 19 587 U 0.03 Il I 2.94 20 61 t) 0.02 9 I 2.96 21 650 t) 0.03 11 1 2.95 22 682 U 0.03 12 1 2.94 23 712 l) 0.03 11 1 2.93 24 743 t ~ 0.03 1 1 1 2.94 25 775 c) 0.03 11 I 2.95 26 806 U 0.03 ll) I 2.94 27 838 a 0.03 11 1 2.95 28 869 U 0.03 1I I 2.94 29 900 t) 0.03 11 a 2.93 30 932 O 0.03 11 I 2.95 31 963 t) 0.03 1 1 I 2.93 32 995 t) 0.03 11 I .94 33 1026 l) 0.02 ~) 2.93 34 1058 t) 0.03 11 1 2.94 35 1089 O 0.03 I1 1 2.95 36 1120 t) 0.03 I1 I 2.95 37 1152 a 0.03 1 U I 2.94 3 1183 a 0.03 1 1 t) 2.93 39 1215 t) 0.03 11 1 2.95 40 1246 l) 0.03 111 1 2. 5 41 1278 U 0.03 1 t) 2.93 42 1309 t ~ 0.03 1 1 I 2.94 43 1340 a 0.03 1 t_) I 2.93 44 1372 i) 0.03 I I I 2.94 45 1403 ~) 0.03 I 1 I 2.95 46 1435 t~ 0. 3 1I 2.93 47 1466 i ~ 0.03 I I ~ ~ 2.93 Penetration Body Metal Loss Body Page 1 PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE 8RD Well: 2N-303 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhilips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: April 25, 2008 Joint No. Jt. Depth (Ft.) I'~~n. Ul~sc~t (Ins.) Pen. Body (Ins.) Nen. %, Metal Ivss `,~~~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 48 1497 t> 0.03 11 1 2.93 49 15 9 t t 0.03 1 1 I 2.9 50 1560 a 0.03 1 U I 2.94 51 1591 (t 0.03 1 1 I 2.95 52 1623 O 0.03 11 1 2.93 53 1654 l1 0.03 1 ~1 I 2.94 54 1683 U 0.03 11 U 2.95 55 1715 t) 0.03 1 1 1 2.95 56 1746 t t 0.03 1 1 1 2.93 57 1777 a 0.03 11 I 2.94 58 1809 U 0.03 II 1 2.93 59 1838 a 0.03 11 ~' 2.94 6 1870 U 0.03 1I _' 294 61 190 t t 0.03 I U _' 2.95 62 1933 U 0.03 11 I 2.95 63 1965 U 0.03 11 _> 2.93 64 1996 a 0.03 11 I 2. 3 65 2027 t t 0.03 11 ? 2.93 66 2059 a 0.03 11 I 2.94 67 2090 O 0.03 1O I 2.96 68 2121 t t 0.03 l U I 2.95 69 2153 (t 0.03 11 _' 2.96 70 2185 O 0.03 10 v 2.96 71 2216 t) 0.03 11 1 2.94 72 2248 t) 0.03 12 1 2.94 73 2279 t t 0.03 10 1 2.95 74 2310 i t 0.03 12 6 2.96 75 2342 a 0.03 11 d 2.96 76 2374 a 0.0 11 1 .93 76.1 2405 U 0.03 11 _' 2.97 PUP 76.2 412 (t 0 0 U N A GLM 1 Latch ~ 8:30 76.3 2418 U 0.03 11 Z 2.94 PUP 77 424 U 0.03 10 ~ 2.96 78 2455 U 0.03 Li 5 2.96 9 2487 U 0.03 I (? I 2.94 80 2518 U 0.03 1I !, 2.96 81 2550 O 0.03 11 I 2.94 82 2581 i1 0.03 11 I 2.93 83 2613 t t 0.03 1 1 2.95 84 2644 l) 0.03 11 i 2.97 85 2676 a 0.03 11 1 2.95 86 2707 a 0.03 11 5 2.96 87 273 O 0.03 12 ~? 2.93 88 2771 t i 0.03 1 1 ~ 2.96 89 2802 ct 0.03 12 1 2.95 90 2833 (t 0.03 13 6 2.97 91 2865 O 0.03 11 I 2.94 92 2896 (1 0.03 11 1 2.94 93 928 O 0.03 10 1 2.95 94 2959 tt 0.03 1O 1 .93 ' Penetration Body Mehal Loss Body Page 2 • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.3 ppf L-80 EUE SRD Well: 2N-303 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhiNips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: April 25, 2008 Joint No. Jt. Depth (Ft.) I'F~n. I )l~~c~t (Im.j Pen. Body (Ins.) P~~n. "/~ Mc~~.il I us, `;~~ Min. LD• (Ins.) Comments Damage Profile (% wall) 0 50 100 95 2991 a 0.04 I i 2.93 Shall w corrosion. 96 3022 U 0.03 I 1 i ~ 2.94 97 3053 t) 0.03 I ' I 2.93 98 308 i ~ 0.03 I I I 2.93 99 3116 i ~ 0.03 1 I 2.93 100 3148 t I 0.03 1 I 2.94 101 3179 I) 0.0 I 1 I 2.95 102 3210 U 0.03 11 1 2.94 10 3242 tl 0.03 lI I 2.94 104 3273 ~) 0.03 11 1 2.93 105 3305 O 0.03 11 1 2.94 106 3336 t) 0.03 11 I 2.95 107 3367 n 0.03 l U I 2 9 108 3397 U 0.03 11 I 2.94 109 3429 t~ 003 11 U 2.93 110 3461 C) 0.03 1l) li 2. 4 111 3492 ~ I 0.03 1 1 I .94 112 35 3 ! ~ 0.03 1 I I 2.94 113 3555 U 0.03 I1 1 2.94 114 3585 tl 0.03 11 I 2.95 115 3617 U .03 II I 2.95 116 3648 U 0.03 1l) 5 2.97 17 3680 O 0.03 11 1 2.95 1 18 3710 l) 0.04 1 5 5 2.96 Shallow corrosion. 1 3742 U .03 11 ' .93 120 3773 U 0.03 II -1 2.96 121 3805 t) 0.03 1 ? I 2.92 122 3836 t) 0.03 11 -1 2.95 1 3 3868 U .03 11 -i 2.97 124 3900 t) 0.03 11 ~1 2.96 25 3931 t) 0.03 11 1 2.95 126 3963 i) 0.03 12 1 2.94 27 3993 t~ 0.03 1 ~ 1 2.95 128 4024 t~ 0.03 i ~ I 2.93 129 4056 U .03 11 I 2.93 130 4087 tt 0.03 I? I 2.94 131 4117 t) 0.03 1 1 I 2.94 132 4149 O 0.03 1 ' I 2.94 133 4180 U 0.03 I z I .95 134 4210 t1 0.03 11 Z 2.92 135 4 42 t 1 0.03 11 1 2.94 135.1 4273 tl 0.03 1 ' 2.94 PUP 135.2 4278 i) 0 (~ i ~ N A GLM 2 Latch ~ 5:00 135.3 4285 U 0.03 1 Z ~ 2.95 PUP 136 4291 U 0.03 1 1 2 2.92 Lt. De its. 137 4322 t1 0.02 ~~ 1 2.93 138 435 t~ 0.03 II I 2.95 139 4383 t ~ 0.03 11 1 2.93 140 4415 {? 0.03 1O I .93 141 4446 ! ~ 0.03 1 ? I 2.92 _ Penetration Body Metal Loss Body Page 3 PDS REPORT JOINT TABI, Pipe: 3.5 in 9.3 ppf L-80 EUE SRD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company. Nominal I.D.: 2.992 in Country: Survey Date: • NATION SHEET 2 N-303 Kupa ru k ConocoPhilips Alaska, Inc USA April 25, 2008 Joint No. Jt. Depth (Ft) I'~~n. Ul~ti~~t li i,. i Pen. Body (Ins.) Pen. °r'~~ Metal lu,ti Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 142 4477 ~) 0.03 I I i 2.94 143 4509 ~~ 0.02 `~ I 2.94 144 4540 ~ ~ 0.03 1 1 U 2.93 145 4572 ~) 0.03 1 U I 2.94 146 4601 t ~ 0.03 I 1 i ~ 2.94 147 4632 c ~ 0.03 13 I 2.9 148 4664 t ~ 0.02 ~ < < ~ 2.94 149 4695 ~ ~ 0.03 I ~> I 2.94 150 4727 U 0.03 11 I 2.93 151 4758 U 0.03 l i t 4 2.96 152 4790 t) 0.03 II 1 .95 153 4821 0 0.03 1 Z 1 2.96 154 4853 O 0.03 11 1 2.94 155 4885 c~ 0.03 I1 3 2.97 156 4916 U 0.03 11 1 2.93 1 7 4948 ~~ 0.04 14 _' 2.96 Shallow corm ion. 58 4979 ~~ 0.05 .'U ~ 2.95 Shallow ittin . 159 5011 ~~ 0.04 I' 1 2.93 Shallow ittin . 160 504 I ~ 0.03 12 ~ 2.96 161 5074 I) 0.03 13 t) 2.94 162 5105 ~I 0.05 19 -l 2.94 Shallow itti 163 5137 l1 0.07 3U 2.96 Isolated ittin 164 5168 tl 0.03 13 ~t 2.95 165 5201 ~ ~ 0.02 ~> 1 2.93 1 6 ~ 3 a 0.03 1 3 I 2. 167 5262 ~ ~ 0.03 I 1 2.95 168 5294 i ~ 0.03 12 1 .95 169 5325 ~~ 0.03 11 1 2.93 170 5357 U 0.02 ? 1 .96 171 5388 II 0.04 Li 2.94 Shallow corrosion. 172 5420 cl 0.02 (> > 2.94 172.1 5452 It 0.03 11 I 2.94 PUP 172.2 5457 I~ 0 U l) N A GLM 3 Latch@ 10:30 172.3 5462 0 0.02 6 I 2.94 PUP 173 5469 0 0.03 13 ~' 2.95 174 5501 t) 0.04 16 1 2.93 Shallow corrosion. 175 5532 U 0.03 1 Z 1 .96 176 5564 ~ I 0.03 12 1 2.93 177 5595 ~ ~ 0.03 13 1 2.95 178 5 27 U 0.02 ~) 2.92 179 5658 I~ 0.04 1 5 ' 2.95 Shallow corrosion. 180 5690 ~ ~ 0.03 1 1 1 2.94 181 5721 ~ ? 0. 1 1 U 2.93 182 5753 a 0.03 11 I 2.94 183 5784 i) 0.04 16 ? 2.95 Sha low corrosion. 184 5815 a 0.03 13 ~ ~ 2.93 185 5847 ~ ~ 0.03 10 2.93 186 5878 n 0.04 1 ~> - 2.93 Shallow corrosion. 187 5910 !? 0.04 I i, 2.93 Shallow corrosion. 188 5941 ~ ~ 0.04 I -G 2.95 Shallow corrosion. Penetration Body Metal Loss Body Page 4 • PDS REPORT JOINT TABI. Pipe: 3.5 in 9.3 ppf L-80 EUE SRD Well: Body Wall: 0.254 in Field: Upset Wall: 0.254 in Company. Nominal I.D.: 2.992 in Country: Survey Date: • iLATION SHEET 2 N-303 Kupa ruk ConocoPhilips Alaska, Inc. USA Apri125, 2008 Joint No. Jt. Depth (Ft.) I'~•n. Ul~s~•1 Un,.) Pen. Body (Ins.) Nc~n. % ~1c•i,il L~»s ,~ Min. LD• (Ins.) Comments Damage Profile (%wall) 0 50 100 189 5972 U 0.04 14 2.95 Shallow cor onion. 190 6004 O 0.03 1 1 ~) 2.94 191 6035 U 0.04 15 -t 2.92 Shallow corrosion. 192 6067 U 0.04 I ,' _' 2.93 hallow itUn . 193 6098 I) 0.04 14 t1 .93 Shallow orrosion. 194 6129 t) 0.03 l a 1 .96 194.1 6160 ~) 0.01 ~ U 2.81 Baker CMU Slidin Sleeve O ned 2 26 06 195 6165 U 0.04 I ~ I 2.96 Shallow corrosion. 195.1 6197 ~) 0.04 17 1 2.95 PUP Shallow ittin . 195.2 6203 It 0 U u N A G M 4 Latch ~ 10:30 195.3 6208 t) 0.03 12 I 2.98 PUP 196 6214 U 0.04 15 ~' 2.96 Shallow corrosion. 196.1 6247 I) 0 ~) U 2.75 C mco ' ' Ni e 196.2 6254 O 0.04 14 1 2.97 PUP 196.3 627 O 0 0 ~.i N A Packer 196.4 6275 t) 0.03 13 2.9 PUP Liner 197 6286 ~ ~ 0.03 I I I 2.95 _ Penetration Body Metal Loss Body Page 5 PDS Report Cross Sections ~~ ~~ ,~ u Well: 2N-303 Survey Date: April 25, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.3 ppf L-80 EUE 8RD Analyst: HY. Yang Cross Section for Joint 163 at depth 5152.457 ft Tool speed = 44 Nominal ID = 2.992 Nominal OD = 3.500 Remaining wall area = 99 Tool deviation = 39 ° Finger 3 Penetration = 0.075 ins Isolated pitting 0.08 ins = 30% Wall Penetration HIGH SIDE = UP • Cross Sections page 1 ~ ~ '~ ~ ~ ~ ~ ~ ~ ~ r ~ ~ ~ ~ ~ ~ ~ ~ ~~~ _ ~+~ PDS Report Cross Sections Well: 2N-303 Survey Date: April 25, 2008 Field: Kuparuk Tool Type: UW MFC 24 No. 214320 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 Tubin 3.5 ins 9.3 f L-80 EUE 8RD Anal st: HY. Yan Cross Section for Joint 158 at depth 5005.49 ft Tool speed = 43 Nominal tD = 2.992 Nominal OD = 3.500 Remaining wall area = 98 Tool deviation = 45 ° Finger 13 Penetration = 0.05 ins Shallow pitting 0.05 ins = 20% Wall Penetration HIGH SIDE = UP • Cross Sections page 2 • s Average Recorded Metal Thickness Relative to Calibration Point Pipe 1 3.5 in (15.9' - 6271.2') Well: 2N-303 Pipe 1 5.5 in (6271.2' - 6275.0') Field: Kuparuk Pipe 1 3.5 in (6275.0' - 6285.6') Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: April 25, 2008 ^ D ecrease ^ In crease 1 19 25 775 50 1560 GLM 1 2342 100 v 3148 ~ E ~ ~ •- Z s 0 125 3931 0 GLM 2 150 472 7 GLM 3 175 5532 GLM 4 197 6286 - 50% 0 5 0% C hange in Meta l Thick ness (% ) Bottom of Survey = 197 Magnetic Thicknes~g (10 Hz) April 25, 2008 Recordings Tied Into Casing Hanger at 0' Database File: 2n-303.db Dataset Pathname: 10hz.1 Presentation Format: 4 scale Dataset Creation: Tue Apr 2913:10:07 2008 by Calc Sondex Warrior V7.0 Charted by: Depth in Feet scaled 1:150 0 MTT Frequency (Hz) 20 4 MTTP01 (rad) 14 -50 Delta Metal Thickness (%) 50 -4.8 MTTP12 (rad) 5.2 0 Line Speed (ft/min) -200 Tree _~__~-Casing Hanc 5" Collar ~~ Pup Jt. 0.1 5" Collar Joint 1 20 ~' Collate ~~ Pup Jt. 1.1 5" Collar i i ~ ~~ 5.5" Production Casing ~1 .62a" Surface Casing C Joint 60 5" h-}--~ Joint 3 n of 16" Conductor 80 Production Casing 625" Surface Casing Collar Magnetic Thicknes~g (10 Hz) April 25, 2008 Recordings Across End of Surface Casing PnosAern,e Dlwgwoerfe 5ew,ncs, Inc. (2,610' - 2,980'} Database File: 2n-303.db Dataset Pathname: 10hz.1 Presentation Format: 2.2 scale Dataset Creation: Tue Apr 2913:10:07 2008 by Calc Sondex Warrior V7.0 Charted by: Depth in Feet scaled 1:150 0 LSPD (ftlmin) -100 22 MTTP01 (rad) 12.2 -50 Delta Metal Thickness (%} 50 -6.6 MTTP12 (rad) 3.4 5" Collar ~~ 2620 .Bottom of 7.625" Surfacke I = 5.5" Production Casing C Joint 83 2640 3.5" Colla ~ K 2650 2660 2670 5.5" Production Casi 3.5" Collar ~ 2680 2690 Joint 85 2700 3.5" Colla ~~ 2710 Joint 84 " 5.5 Pro J .5" Collar J I 5.5" Prod ucti .5" Colla r Y J " 5.5 Productic 3.5" Collar J .5" Collar . ,, _. ~ 5.5" Prod uctic r? Y I C ~ Colla _ :. r 3 Collar < ' -- ~- _- -~ _ -}- :(.~~ -y s.. " ;~ Colla i . _ ~ _ 5 r 4 ~ ~. I Collar In asmg 2720 pint 86 2730 2750 pint 87 m Casi <<~~ 2780 pint 88 2790 ~n Casing 280D 2810 pint 89 2820 2830 ~~ ~~ n Casing ~Rtin -- oint 90 2860 5" Collar 2870 5" Production Casing Colla Joint 91 ?890 ~' Collar ~ 2900 2910 Joint 92 -~-t-1 2920 5.5" Production Casing X3.5" Collate --~--}-~ 2930 2940 Joirrt 93 X950 5" Collar•••~~ 5" Production Casing 2970 Joint 94 0 LSPD (ft/min) -100 2.2 MTTP01 (rad) 12.2 -50 Delta Metal Thickness (%} 50 -6.6 MTTP12 (rad} 3.4 5" 5" s11o Joint 193 :ion Casin 6120 6140 Joint 194 6150 5" Production Sliding Sleeve ~' Collars 6170 6180 Joint 195 6190 5" Collar. Pup Jt. 195.' ____3..1111.~~~~~5" ..__al1IIlCollar~ -1 GLM 4 ' Collar 6210 -Pup Jt. 195. olla~ ~ 6220 Joint 196 6230 a~an ConocoPhillips Alaska, Inc. • KRU 2N303 2N-30 --_ - API: 501032035200 Well T : PROD An le TS: de SSSV Type: NIPPLE Orig 12/28/2000 Angle ~ TD: 41 deg ~ 7057 Com eti n: N1P (soa-sos, Annular Fluid: Last W/O: 12/29/2000 Rev Reason: Set Pump, Open OD:3.500) S. LV TUBING (08270 Referen L Ref L Da te: t U te: 3/42 06 , oD:3.5o0, Last T : 6581 TD: 7057 ftKB ID:2.992) Last Tap Date: 2/82008 Max H An ole le: 41 deg ~ 1690 C sin Strin -ALL Descri lion Size To Bottom TVD Wt Grade Thread CONDUCTOR 18.000 0 140 140 62.50 H-40 WELDED SURF CASING 7.625 0 2837 2302 29.70 L-80 BTCM Gas Lln '~ PROD CASING 5.500 0 8275 5144 15.50 L-SO TC MOD '"~~D`""`"y Valve 1 ^ LINER 3.500 8275 7048 5738 9.30 L-80 EUE 8RD (242o-2az1, Tubin Strin -TUBING oD:a.7zs) ` Size To Bottom TVD Wt G rede Thread 3.500 0 8270 5140 9.30 L -80 EUE SRD Perforations Summ Interval TVD Zone Status Ft SPF Date T Comment 8562 - 6576 5368 - 5377 14 4 122001 IPERF 2.5' HSD; 180 deg ph; +/- 90 from h' h side Gas LiR Stimulations Treatments '"~"aw"'""'y V lv 2 Interval Date T Comment a e (azas-aza6 6562 - 6578 1/11/2001 F C INITIAL FRAC TREATME NT , oD:a.7zs) Ges Lift Ma ndrelsNahres St MD ND Man Man Type V Mfr V Type V OD Latch Port TRO Dete Vlv Mfr Run Cmnt 1 2420 134 CAMCO KBG 2-9 Camco DMY .0 DC 0.000 0 0/15200 2 4285 3579 CAMCO KBG 2-9 Camco DMY 1.0 BTM 0.000 0 /102006 1 3 5462 4496 CAMCO KBG 2-9 CAMCO DMY 1.0 BTM 0.000 0 228200 C~2s Lift 4 6206 5089 CAMCO KBG 2-9 Camco DMY 1.0 BTM 0.313 0 0/15200 ~rWref/DUmmy 1. Overs¢ed PKG valve3 5462-5463 Other lu s ui ems. - JEWELRY , ( OD:4.725) ~ ' - De ih TVD T e Descri lion ID 504 50 NIP Camco'D ' N' le 2.875 6165 50 7 SLEEVE-O Baker CMU Slidin S leeve OPEN D 226200 6 2.813 6165 5057 PUMP RIH W/ 3.0' D-RT,2.81' CS LOCK 8 3' RC JET PUMP #PH-1056 (#10 0.000 N ZZLE #10 THRO AT & #10A RATIO 226/20 06 6250 51 4 NIP Cam o'D' Ni le .750 PUMP enera l No (s1s5-s1ss, Dete Note OD300°) 0/17200 ORIGINAL COM PLETION WAS 11/18/0 0 not 1128/00. WORKOVER DONE 12290. SLEEVE-0 (61658166, OD:3.500) Gas Lit[ ~_ i narelNUmmy Valve 4 6206 6207 ! - , , ( OD:4.725) __ ~ NIP (625D-6251, OD:3.500) PROD CASING (08275, OD:5.500, VJt 15.50) FRAC - (65628576) - Perf (6562-6576) LINER - (6275-7048, '~~ - OD:3.500, j - Page 1 of 2 Maunder, Thomas E (DOA) From: Peirce, John W [John.W.Peirce@conocophillips.com] Sent: Friday, April 25, 2008 8:10 AM To: Maunder, Thomas E (DOA) Subject: RE: 2N-303 jet pump job aoo-~~~ Tom, We have not been filing 404's for jet pump sets or pulls. We do a lot of pump swaps on a regular basis for resizing or for maintenance, so there would be a lot of Sundries to do if we need to do them. Regards, John Peirce From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, April 23, 2008 4:33 PM To: Peirce, John W Subject: RE: 2N-303 jet pump job John, I believe that this work should not need a sundry but that a 404 may be of value if it contains production information. Have you been submitting any 404s for this work? Tom From: Peirce, John W [mailto:John.W.Peirce@conocophillips.com] Sent: Wednesday, April 23, 2008 11:54 AM ~~~~~~~ ~~~ ~ ~ 2~~$ To: Maunder, Thomas E (DOA) Subject: RE: 2N-303 jet pump job Tom, slickline normally does most of the work, but sometimes E-line or coil tubing must be used to run or pull jet pumps. If we're doing a straddle jet pump construction from scratch, it's pretty critical for us to get our pump assembly constructed accurately 'on depth'. Due to this concern we have to use E-line for depth contra) to insure we set our lower straddle packer on depth. After that, we'll normally run the rest of our pump straddle assembly runs via slickline. When we come back later to pull these pumps for maintenance, we normally get all the work done with slickline and we can leave our lower packer set in place. S Sometimes pulling a jet pump with slickline doesn't get it free, and we end up having to go in with coil to jar them out. We have had quite a few stuck pumps where use of CT was needed to get them pulled. Hole angle we're working in is also sometimes a factor on if we can get by with slickline, or are we better off using CT. Regards, John Peirce From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, April 23, 2008 11:34 AM To: Peirce, John W Cc: Allsup-Drake, Sharon K Subject: RE: 2N-303 jet pump job John, As I understand, that is all done with slickline correct? If that is the case, then at least the no sundry applies. 5 ~' ~ ~ ~~ 6/5/2008 Page 2 of 2 • • Probably the no 404 either. Look forward to your reply. Tom Maunder, PE AOGCC From: Peirce, John W [mailto:John.W.Peirce@conocophillips.com] Sent: Wednesday, Aprit 23, 2008 11:32 AM To: Maunder, Thomas E (DOA) Cc: Allsup-Drake, Sharon K Subject: FW: 2N-303 jet pump job Tom, Your Sundry guidelines matrix sheets do not specifically discuss Sundry requirements for pulling and running Jet Pumps, so I'm seeking some clarification on this issue. The matrix lists no sundries required for'Pump Changes', but I'm guessing this may be intended to refer to electrically powered (ESP's, PCP's, etc.). I'm not positive that Jet Pumps are also intended under this classification. If we want to run or pull a surface powered jet pump or formation powered jet pump in a well, what Sundries would be appropriate? Do we need sundries for pulling and rerunning jet pumps? We do a lot of regular maintenance work to swap out jet pumps for new nozzle and throat sizings, or to replace worn pump components. Regards, John Peirce Wells Engineer CPAI Drilling & Wells (907)-265-6471 office (907)-240-5533 cell From: Allsup-Drake, Sharon K Sent: Wednesday, April 23, 2008 11:05 AM To: Peirce, John W Subject: 2N-303 jet pump job John - Theway 1 read the regulations, we don't need to report the pulling of the jet pump assembly on 3/5/08. Would you agree? Thank you, Sharon 263-4612 6/5/2008 • 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 Anchorage, AK 99501 Dear Mr. Maunder: a~~~~q 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, 2007. 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 9128/07 Please call myself at 907-659-7506, or M.J. Loveland at 659-7043 if you have any questions. Sincerely, i~ _~,_ 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 9/28/2007 Well Name PTD # Initial top of cement Vol. of cement um ed Finat 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" nla 2 9127/2007 2N-311 206-179 12" nla 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" nla 1 9/27/2007 2N-319 198-197 5" n/a 5" n/a 9.5 9/27/2007 • ~ RFC /V COr~OCOPhit~1~S Ai$s . °cr © ~L) Alaska ka 0,t ~ 2 ?pOT P.o. eox ioos6o has Cons ANCHORAGE, ALASKA 99510-0360 anehora8'e Cnrnnission September 28, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission d 1 333 West 7~` Avenue, Suite 140 ~,~ Anchorage, AK 99501 ,~~~ ~~~ E~' ~ Z00~ Dear Mr. Maunder: 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 inhibitorlsealant 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 S/28/2007 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 bbts 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-335 188-204 9" na 20" na 13 9/16/2007 2N-347 200-063 21` 4 18" 919!2007 6 9116/2007 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" nia 12" n/a 10 9!27/2007 2N-313 198-091 5" nla 5" nla 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" nia 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 . . ConocriPhillips Robert Buchholz / Robert Christensen Production Engineering Tech. Greater Kuparuk Unit, NSK-69 PO Box 196105 llnchorage,AJC 99519-6105 Phone: (907) 659-7535 Fax: 659-7314 August 26,2006 RECEIVED AUG 2 9 2006 To: Tom Maunder, P.E. Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission 33 W. 7th Ave. Ste. 100 Anchorage,AJe 99501 Alaskã Oil & Gas Cons. Commission Anchorage Re: Enclosed is a 10-404 for 2N-303. On 4/21/2006, this Surface Powered Jet Pump well was found to have a tubing leak. After multiple attempts, the leak has been successfully patched and the well was returned to production 08/10/06. y(~dur- Robert D. Christensen Attachments: 10-404 Form SCANNED AUG 3 .1 2006 900-( 0Cj · t'<f=l';t:IVED . ¡'ìlr::, ') n '10 STATE OF ALASKA'" / 11 / 06 REP¿~~KA;; ;~~~~;S~~~~N ~;~::';Ictka ',Ii "A~:~:,f,~/i" ê,OI1íuíon 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 156' 8. Property Designation: ADL 380053/& 380054 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURF CASING PROD CASING LINER Perforation depth: 5. Permit to Drill Number: 200-1691 . 6. API Number: 50-103-20352-00 . 9. Well Name and Number: 2N-303 . 10. Field/Pool(s): Kuparuk River Field 1 Tarn Oil Pool . measured 7057' feet true vertical 5744' feet measured 6920' feet true vertical 5641' feet Length Size MD 140' 16" 140' 2481' 7-5/8" 2637' 6119' 5-1/2" 6275' 773' 3-1/2" 7048' Plugs (measured) Junk (measured) TVD Burst Collapse 140' 2302' 5174' 5738' Measured depth: 6562'-6576' true vertical depth: 5366'-5377' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 6270' MD. Packers & SSSV (type & measured depth) no packer SSSV= NIP SSSV= 504' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Revised 04/2004 OR\G\t~AL ;-. - ¡-S.ss- \~;BOMS BFl AUG 3 1. 2006b .~ $'t/.c:>k. /'0 Submit Original Only · 2N-303 . DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 04/21/06 LEAK DETECT LOG. PUMP DOWN IA TAKING RETURNS TO FORMATION INDICATES LEAK IN TUBING AT 5020'. NO OTHER LEAKS OBSERVED. 04/29/06 PULLED CMU ISO SLEEVE FROM 6165' RKB. LOGGED PDS CALIPER FROM 6325' RKB TO SURFACE. OPENED CMU @ 6165' RKB. IN PROGRESS. 04/30/06ISET 2.81" JET PUMP IN CMU @ 6165' RKB. WELL READY FOR TBG PATCH. 05/13/06 INCOMPLETE OPERATION. SET LOWER PACKER AT 5034' AS REQUIRED. SECOND RUN- STAB UPPER PATCH ASSEMBLY INTO SNAP LATCH- PULL UP TO VERIFY LATCH AND UNINTENSIONALL Y PULL OUT OF WEAKPOINT AT 75% WP RATING. WEAK POINT FAILURE FOUND TO BE IN DRILLED OUT SECTION IN SPIDER ROPE SOCKET. DID NOT ATTEMPT TO SET UPPER ELEMENT AND UPPER PATCH SECTION SHOULD SHEAR OUT OF SNAP LATCH AT 7000# WHEN FISHED. OVERALL FISH LENGTH = 43.8' MAX OD = 2.75'. 05/15/06PULLED E-LlNE TOOLSTRING W/ PATCH @ 4961' SLM. JOB COMPLETE. 05/16/06 WEATHERFORD ECLIPSE TOP 3-1/2" PATCH PB PACKER ELEMENT SET AT 5014 FT. PATCH SET FROM 5014' - 5034' - ELEMENT TO ELEMENT. OS/21/06 PULLED ECLlPCE PATCH (BOTH UPPER & LOWER) @ 5014' RKB. PULLED JET PUMP @ 6165' RKB. TAG @ 6580' RKB. ESTIMATE 4' BELOW BTM PERF. IN PROGRESS. OS/26/06 SET 20' PATCH ACROSS TUBING LEAK IN TWO RUNS. SET LOWER PACKER ELEMENT AT 5034'. STING UPPER ASSEMBLY INTO LOWER AND SET UPPER PACKER AT 5014'. USED WEATHERFORD 3.5" ER PACKERS. MINIMUM ID OF PATCH IS 1.71". WELL RETURNED TO PRODUCTION. 06/15/06 PULLED UPPER & LOWER ECLIPSE PACKER & SPACER PIPE ASSY @ 5014' ELM. PULLED JET PUMP 6165' RKB. IN PROGRESS. 06/16/06 TAGGED FILL @ 6577' RKB. EST. l' RATHOLE. SET 10B RATIO JET PUMP ON 2.81" CS LOCK IN CMU @6165' RKB. SET SLIP STOP ON TOP OF PUMP. JOB COMPLETE. 07/08/06 SET WEATHERFORD ECLIPSE 3.5" LOWER PACKER ELEMENT AT 5037'. UPPER ELEMENT READY TO BE SET WITH SLlCKLlNE. 08/05/06 RAN UPPER ECLIPSE PKR PATCH ASSEMBLY WI EDT TOOL. HAD GOOD INDICATION OF A GOOD SET. RAN ECLIPSE TEST TOOL BUT PT TEST FAILED, IA WAS TRACKING THE TBG. PULLED TEST TOOL AND KICKED ON PUMP, IA WAS STILL TRACKING. IN PROGRESS. · 2N-303 . DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 08/06/06 SET D&D HOLE FINDER ON TOP OF ECLIPSE PKR @ 4981' SLM. GET GOOD PT TEST CONFIRMING UPPER ECLIPSE PKR IS NOT HOLDING. PULLED BOTH SECTIONS OF THE PATCH @ 4981' SLM (THE 19.78' SECTION & ECLIPSE 13.49' SECTION). JOB SUSPENDED UNITIL A NEW PATCH IS READY. 08/09/06 SET WEATHERFORD PATCH CONSISTING OF G BAIT SUB, "SO" TIE BACK, SPACER PIPE, & SNAP LATCH. (19.78' LONG) IN ECLIPSE PKR @ 5037' RKB. PULLED 800# OVER PICK UP WEIGHT TO ENSURE SNAP LATCH WAS SET. IN PROGRESS. 08/10/06 SET K-3 PACK OFF, SPACER PIPE & "SO" STINGER (11' 8" LONG) @ 4994' SLM. TEST K- 3 PACK OFF TO 2500 PSI, GOOD TEST. SET SLIP STOP ON TOP OF K-3 @ 4980' SLM. WELL IS READY FOR PRODUCTION. 05/09/06 Scblumberger NO. 3792 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TIN: Beth Company: Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~ KUpaN. ~ÐD -I ~3 d-~'~ "'1\1 i ''"ìfîìÇ: ~CANNEI) ..nJ¡¡l {.d!,l Field: Well Job # Log Description Date BL Color CD 1Y-29 11213739 PRODUCTION PROFILE WID EFT ~ 'ifi(' - r..C\ I 04/28/06 1 3M-25A N/A SHUT IN 8HP 1C\'--aG<O 04/23/06 1 2N-303 N/A LDL Ç'I' 0 - 11....c.. 04/21/06 1 1 R-21 11213737 PRODUCTION PROFILE W/DEFT \~1-t\3 04/25/06 1 3F-07 N/A INJECTION PROFILE 'Í(-';- ~ 94f..,- 04/23/06 1 18-16 11235353 PRODUCTION PROFILE W/DEFT ,e; I...I-(\~-:} 04/04/06 1 38-15 11213741 INJECTION PROFILE ¡~ç - ¡¡ ~.:..- 04/30/06 1 1 G-07 N/A PRODUCTION LOG W/DEFT I 'ÍÍ g. - rll', \ 04/19/06 1 1A-20 11235356 PRODUCTION LOG W/DEFT Ir,O - 1tr.:J 04/26/06 1 1 H-18 N/A INJECTION PROFILE C1'~ - ()~b . 04/24/06 1 1 R-12 11213738 . PRODUCTION LOG W/DEFT I ~'S ~o':1?1 04/27/06 1 1 Y -13 11213740 INJECTION PROFILE 1-<6~ - C' Ie.:; 04/29/06 1 2N-318 11213742 LDL dDC -IOD 05/01/06 1 1 Q-08A 11213743 INJECTION PROFILE ~ '1- -i~C, -':2, 05/02/06 1 1G-01 11213744 INJECTION PROFILE IYd-- l;;t;{) 05/03/06 1 3J-17 11258704 PRODUCTION LOG W/DEFT íC, (,0 - I '-¡-1- 05/04/06 1 1 R-26 11258705 INJECTION PROFILE 'I C11 - (':~ ';:}. 05/05/06 1 2A-04 11249902 INJECTION PROFILE ì ~~/ - (')<~ 05/06/06 1 1 G-06 11249903 INJECTION PROFILE 15? - ~;::).t-- 05/07/06 1 1 E-18 11216193 MEMORY PRODUCTION PROFILE I "[2, - ,~I (" 05/07/06 1 1G-14 11249904 INJECTION PROFILE 1~3'- ~/I 05/08/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. e e I I I I I I I I I I I I I I I I I I I e e Memory Multi-Finger Caliper Log Results Summary Company: Log Date: Log No. : Run No.: Pipe1 Desc.: Pipe1 Use: ConocoPhillips Alaska, Inc. April 29, 2006 7565 1 3.5" 9.3 lb. L-80 EUE 8rd Tubing Well: 2N-303 Field: Kuparuk(Tam) State: Alaska API No.: 50-103-20352-00 Top Log Intvl1.: Suñace Bot. Log Intvl1.: 6,322Ft. (MD) Inspection Type : Co"osive & Mechanical Damage Inspection COMMENTS: This caliper data is tied into top of GLM 4 @ 6,206' (Driller's Depth). This log was run to assess the condition of the 3.5" tubing with respect to corrosive and mechanical damages. The 3.5" tubing logged appears to be in good condition, with the exceptions of 24% and 22% wall penetrations in joints 195.1 (6,201') and 45 (1,445'). The damage appears in the forms of general corrosion and isolated pitting. No significant areas of cross-sectional wall loss or I.D. restrictions are recorded throughout the 3.5" tubing interval logged. Cross-sectional drawings of the most significant events recorded are included in this report. The distribution of maximum recorded penetrations is illustrated in the Body Region Analysis Page of this report. A graph illustrating the correlation of recorded damage to borehole profile is included in this report. MAXIMUM RECORDED WAll PENETRATIONS: Isolated Pitting Corrosion ( 24%) ( 22%) 195.1 @ 45 @ 6,201 Ft. (MD) 1,445 Ft. (MD) Jt. Jt. No other significant wall penetrations (> 20%) are recorded throughout the tubing logged. MAXIMUM RECORDED CROSS-SECTIONAL METAL lOSS: No significant areas of cross-sectional wall loss (> 9%) are recorded throughout the tubing logged. MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the tubing logged. , tr ~± I Field Engineer: J. Halvorsen Analyst: M. Tahtouh Witness: C. Fitzpatrick I Pro.L,ctive Diagnostic Services, Inc. Plione: or 565-9085 Faic Prudhoe Field Office Phone: P,O, Box Stafford, T>( 77497 565-1369 E-mail: 659-2307 Faic .; ~O i ~ C( I I I I Well: Field: Company: Country: 2N-303 Kuparuk(T am) ConocoPhillips Alaska, Inc. USA Survey Date: Tool Type: Tool Size: No. of Fingers: IT Report Overview Body Regia Analysis April 29, 2006 MFC 24 No. 040665 1.69 24 M. I Penetration and Metal Loss «'/0 wall) I penetration body 250 I 200 150 100 50 0 o to 1% pen. loss 2 208 0 I I I I I 150 I I I 100' I 50 I Damage Profile (% wall) metal loss body penetration body o o metal loss body 50 100 20 to 40 to over 40% 85% 85% 0 0 0 GLM 1 GLM 2 o isolated general line ring hole I poss pitting corrosion corrosion corrosion ible hole GLM 3 I I GLM4 I I I I Bottom of Survey = 198 Analysis Overview page 2 -l I I I I I I II I I I I I I II I I I I [ I ' I I I I , . I I IUI I I I I I I I I I I I I I Pipe 1 I I I I I I 3.5 in (281' - 6320.0') Borehole Well: Field: Company: Country: Survey Date: Approx. Tool Deviation of Recorded Damage 31 787 1571 GLM 1 ~~~ . . __...I;ï 2352 ,,-.., 0 .... 100 3156 6 () .c ..... E tL :::¡ ¡:: Z J:::. - 15.. ¡:: 125 'õ 3938 () -, 0 GLM2 150 4733 GLM 3 GLM4 Bottom of Survey = 198 25 50 175 198 o 2N-303 Kuparuk(Tarn) ConocoPhillips Alaska, Inc. USA April 29, 2006 Approx. Borehole Profile Damage Profile (% wall) I Tool Deviation (degrees) 50 5537 6320 100 I I I I I I I I I I I I I I I I I I I PORT JOINT TABULATION H Pipe: Body Wall: Upset Wall: NominaII.D.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field: Company: Country: Survey Date: 2N-303 Kuparuk(Tarn) ConocoPhillips Alaska, Inc. USA April 29, 2006 Joint Jtl2epth t~~~~t Pen. Pen. Metal Min .~ Profile No. Body Loss r wall) ) (Ins.) 0 50 100 .1 i 2.91 , PUP II 1 2.90 Shallow corrosion. 111II 1.1 2.87 PUP pittinq. . 2.92 99 I 2.91 I Shallow corrosion. III 30 I 2.90 Shallow corrosion. -------- ^^^^ -^-~ III 60 I 2.91 I Shallow corrosion. -------- ^ -~-~----~-,-- .~ _.~~ III i 92 2.92 Shallow corrosion. -- -- - "" ------ 7 0.04 Shallow corrosion. ...- 0.04 --.....- 2.87 hi I 2.91 hi I =jt-=t-= pittino. , I , , I pp e I o. )3 0 0,04 J. J J J. pittino J.' J¡ , I U~ m=1 2.90 I I i I I I I [ 0.05 , I Shallow corrosion. Shallow corrosion. '"'v,'v II. , '"'v, 'v II. I I I .v II. I , I '"'v, 'v II. I 3 0 Shallow corrosion. 39 Shallow corrosion. 1257 Shallow 289 Shallow 320 I :3~?t I I II I=R JJhj 1 0 1477 0 netration Body Metal Loss Body Page 1 I I I I I I I I I I I I I I I I I I I PORT JOI Pipe: Body Wall: Upset Wall: Nominal 1.0.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well: Field Company: Country: Survey Date: 2N-303 Kuparuk(Tarn) ConocoPhiilips Alaska, Inc. USA April 29, 2006 Joint i Jt Depth Pen I Pen. Pen Metal Min. _~ Profile No. (Ft) Body Comments wall) ) (Ins.) (Ins.) 0 50 100 I 48_f---1508 2.92 I 49... ...1540 ( 2.91 I 50 1571 2.90 I- IIU. I 51r 1602 2.90 ~f 1634 2.89 I 53· ········1665 2.91 I ~+ ·1694 I I 2.90 I Shallow I I I 55 1726 I 2.91 0.05 0.05 I I 2.89 01 FFf90 l I " I I I 31 "" IVVV I 2100 I 0.04 I I I I I , 74 I 2320 0.03 I ~... 2352 0.03 76 2384 0.04 ( I 76.1 2415 0,03 PUP 71 .2 2421 0 I '4, GLM (Latch ãJ 8:00\ I 71 .3 PUP I 3 I I I i I . ......-...- .1 ¡ , I' I ') II r--91 5 '" 92 2905 2.90 93 2937 0.04 I ;} 2.90 I 94 2968 I] 0.04 17 ( 2.90 Shallow corrosion. LLL ~ - ~~,.~~ _..^.,~..~~._~ Body Loss Body 2 I I I I I I I I I I I I I I I I I I I PORT Pipe: Body Wall: Upset Wall: Nominal 1.0.: 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well Field: Company: Country: Survey Date: 2N-303 Kuparuk(Tarn) ConocoPhillips Alaska, Inc. USA April 29, 2006 Joint Jt Depth Pen Pen. Pen l'v1eta I Min. .'" Profile No. Upset W. Comments wall) ! (Ins.) 0 50 100 95 3000 ~ I , 96 3031 I· 97 3062 ~. 98 I 3694 Ii::! JW 99 3125 1 100 3156 nOr 318'( I I H02 3219 ". 103 3251 0, 2,91 I 0 2.91 Qi 0.04 1 0.03 i I I 116 3687 :" , [ I 0.03 , 005 E I I 1 I J ... 2.88 VI 31 2.90 Shallow corrosion. .... I 2.89 I - 2.89 Shallow oittino. I"" ¿ 5 L1 31 I V , i·..· i . 0.03 I I,,· 3 I 3 ¡ I j II I ~ I I ¡ ~ 1 285 1 N/A 2 (Latch IÕ) 4:00) II 1135.3 I 4291 0.03 ¡ 2.82 ::> Lt. I ~ I 136 I 4297 I 0 0.03 2.88 I II i 137 I 4329 0.03 2.89 138 4360 I -º.:.04 2.91 I. I Illlli 139 4390 0.03 2,90 I. 140 4421 0.05 2.89 'VI ". 141 4453 0.05 2.88 ". Ir Body Loss Body 3 I I I I I I I I I I I I I I I I I I I PDS JOINT TABULATION Pipe: Body Wall: Upset Wall: Nominal LD.: Well: Field: Company: Country: Survey Date: 2N-303 Kuparuk(Tarn) ConocoPhillips Alaska, Inc. USA April 29, 2006 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Joint Jt [)epth I~~~~'t Pen. Pen. r~~~~1 Min. Profile No. Body LD. Comments wall) I (Ins.) (Ins.) 0 50 100 142 4484 0.04 ( 2.91 Shallow corrosion. ~~~.~_..- --I I 143 4516 0.05 2.89 Shallow corrosion. I 144 4547 0.03 i 2.88 ShallowQittin9· I 145 4578 , 0.03 2.87 ShallowpittlD9· I --.-- L 8 2.90 Shallow corrosion. ~. .. _.~~..m._ L 9 2.90 Shallow pittíniL 2.90 Shallow corrosion. _.~~mm.._ 2.89 .. . shallow-corrosion. - .~ 2.89 Shallow pitting. ~~._~ I [ 151 4mB' 2.92 -~ I 152 =Hl?:::~: ~~;~;,i()Q.___=~__ -_..~ I , 153 48 ' I M__'_ 48 ~[ 'pitting. Lt. 48 , O.C ' pittino. c.c C:h",llmAl <;VIIU<:>IU' I. ( <;UIIU;:>IUII · pittíno. 5174 ' pittino. 0 2.88 2.85 +- -- i , 2.88 1_ --~_....,'~ : 0.03 ( 2.84 I : 0. )3 ) 8 1 O. )2 8 PUP 1 :> r GLM 3 (Latch @ 12:00) 1 3 PUP : pittinQ. : · pitlinQ. [) J · pittinQ. 1 Shallow corrosion. 179 0,04 2.89 Shallow pittinQ. 180 J. 2.86 Shallow J. Shallow pittinQ. ----- J. Shallow pitting. ..__._~.. J. Shallow corrosion - -r I J, .m._.'"" Shallow corrosion. .-- - ... .. m 0.04 Shallow corrosion. 1 0.04 i 2.89 0.04 2.86 0.04 2.87 I I I L. Body Loss Body Page 4 I I I I I I I I I I I I I I I I I I I JOINT TABULATION PDS 3.5 in 9.3 ppf L-80 0.254 in 0.254 in 2.992 in Well Field: Company: Country: Survey Date: 2N-303 Kuparuk(Tarn) ConocoPhillips Alaska, Inc. USA April 29, 2006 Pipe: Body Wall: Upset Wall: NominaII.D.: Comments 0.00 I 2 0 0 I 0 I û I Û 0.04 I 16 I 4 I 0 0.03 IW I " I .j 10 0.02 ~ I 2 I ~} 5 o Body Loss Body ------ ------------- MI Report Cross Secti s Well: Field: Company: Country: 2N-303 Kuparu k(T arn) ConocoPhillips USA Inc. Survey Date: Tool Type: Tool Size: No. of Fingers: April 2006 MFC No, 040665 1.69 24 ft Tool speed = 48 NominallD = 2,992 Nominal aD = 3.500 Remaining wall area 95 % Tool deviation = 390 2 Penetration 0.062 ins Isolated Pitting 0,06 ins = 24% Wall Penetration HIGH SIDE = UP Cross Sections page 1 ..........-..............-.......... M IT Report ross Sections Well: Field: Company: Country: 2N-303 Kuparuk(Tarn) ConocoPhillips Alaska, Inc. USA Survey Date: Tool Type: Tool Size: No. of Fingers: April 29, 2006 MFC 24 No. 040665 1.69 24 ft Tool = 49 NominallO 2,992 Nominal 00 3.500 Remaining wall area = 93 % Tool deviation = 430 3 Penetration = 0.056 ins Corrosion 0.06 ins = 22% Wall Penetration HIGH SIDE = UP Cross Sections page 2 I I I (504-505, 00:3.500) TUBING (0-6270, 00:3,500. 10:2.992) I I Gas Lift mdrellOummy 'oAo~~I:~,1 004725) I I Gas Lift ~ndre!lDummy Valve 2 (4285-4286, 004,725) I I Gas Lift _.~~-~ mdrellDummy Valve 3 (5462-6463, 00:4,725) I I PUMP (6165-6166, 00:3,000) SLEEVE-O I I Gas Lift ~ndre!lDummy Valve 4 I I NIP (6250-6251, 00:3500) PROO CASING I I FRAC """"""" (6562-6576) """"""""'" I___ Perf """""""'" 1-' (6562-6576) __ 1m.., LINER I""""""""", (6275-7048, ""'" I""", 00:3,500, Wt9,30) ",-, -" I-m-, I I KRU 2N-303 17N.303 ___Well Type: IPROD Orig AnGie (aJ I::>: Idea @ Angle (gJ I U: 41 deg @ 7057 API: 501032035200 SSSV Type: NIPPLE "I II Iwal lUlU. I <ld IAII( '" """:5V". Set Pump, 0 SLY 41 /I ¿uuo AN' Last Tao: 16574 ~14/ILILUUO IJ]~m~Ií;LL Ref Loa n",tA' ILJ III!'> 1 ftKR dEJa @""i690 Rc om TVO 140 2302 í:¡--:¡¿j,4 S7:'ìR ( Grade H-40 L-80 L-80 L-80 Size 16.00 '.62: 5.50( 3.50( Tin IUK URF SING LINE 6; 75 2 6 7 Size 3,500 UI'JII\lt:> I Ton I Bottom 1 TVD~---L Wt I Grade 1 I 0 I 6270 I 514~ 9.30 I L-80 I TVO i Zone I Status I Ft ISPF I Date TVDe I 5366 - 5377 1141 4 11/2/2001 IPERF I' 2.5" HSD: 180 deg ph: +1- 90 dea from hioh side Thread EUE 8RD Interval 6562 - 6576 ¡ntenal 6562 - 3576 r::.... I St ME N[ ate Type ¡LVV' I FRAC i TfNfnJ\i':15i\? I K!::A I M!::N I ,Ian Man I ype V Mfr VT ~rE VI:U D ,1 n EUE 8RD FmlCO ameo ( \MCO ameo V ÖD latch Port ITRO Date ~V¡v. Run lJmm 1() DCK () 0/15/2001 10 BTM 0.000 I 0 2/10/2006-(1) 1.0 I BTM , 0.000 I 0 2/29/2000 --=ro _ B~13 I 0 0/15/2001 1 2420 2134 _L¡~ _3579 ++- ~i~~ -,~~ / ~~~,l"camco 'OS' Nipple I 6165 5057 SLE VE-O Baker CMU ! 6165 5057 P MP RIH W/3'~'1~-~~~ó8;; ~~~~2~:T¡~)R21~7~~tvU" tr n- IV::>" (#10 "6250 ;124 NIP Cameo LJ mrJP,e Date Note IVI I ¡LUU' l¿õlVVI. f)()NF 12/29/00. ('r'\UDI t".TION WAS 1 2 '5 23 O. )0 2.750 2N-303 (PTD 2001690) report oftbg leak. e e ~öa - \\0 ~ Tom & Jim, Producer 2N-303 has a tbg leak at 5020'. The leak was logged by Eline on 4/21/06. The well is lifted by a surface powered jet pump set in a CMU at 6165'. The leak was found during diagnostics to troubleshoot the jet pump after the pump appeared to be circulating power fluid water around and no longer lifting the well properly. The IA and packer both have integrity as a CMIT with a plug in the tbg tail at 6250' passed on 4/12/06. A retrievable tbg patch is planned to repair the tbg leak to return the well to jet pump production. The jet pump will be installed, then the tbg patch. Attached is a schematic and 90 day T/I/O plot. I have added this well to the SCP report while waiting on the tbg patch repair. Please let me know if there are any questions. Marie McConnell Problem Well Supervisor 659-7224 §Ç¿:\NNEfJ: .2 8 2006 «2N-303 90 day TIO plot 4-24-06.gif» «2N-303.pdf» Content-Description: 2N-303 90 day no plot 90 day TIO plot 4-24-06.gif Content-Type: image/gif Content-Encoding: base64 Content-Description: 2N-303.pdf Content- Type: application/octet-stream Content-Encoding: base64 1 of I 4/26/20067:20 AM -303 NIP (504-505. ------ 00:3.500) TUBING (0-6270. 00:3.500. 10:2.992) Gas Lift mdral/Oummy Valve 1 (2420-2421. 00:4.725) Gas Lift mdrellOummy Valve 2 (4285-4286. 00:4725) Gas Lift 'ndral/Oummy Valve 3 (5462"5463. 00:4725) PUMP --- (6165-6166. 00:3.000) SLEEVE-O (6165-6185. 00:3.500) Gas Lift Jndral/Oummy Valve 4 (6206-6207, 00:4.725) NIP (6250-6251 . 00:3.500) PROO CASING (0-6275. 00:5.500. Wt15.50) FRAC (6562-6576) Parf (6562-6576) liNER (6275-7046, 00:3.500, Wt:9.30) KRU Date I Note 110/17/2001 ORIGINAL 2N-303 (PTD 200-169) e e dOO-lCo~ Producer 2N-303 (PTD 200-169) is a surface powered jet pump well that exhibited TxlA communication during it's bi annual MITIA and Jet pump PM cycle. The leak location has been narrowed down to around the 2 GLM, however extended packing dummies have not been able to repair the leak. Currently the Jet pump has been pulled and the sliding sleeve in the tubing is closed. Our next step is to get an LDL to pin point the leak for patching options. A schematic is attached. Let me know if you have any questions MJ Loveland «2N-303.pdf» Content-Description: 2N-303.pdf Content-Type: application/octet-stream Content-Encoding: base64 lof! 4/26/20067:19 AM F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker. doc MICROFilMED 04/01/05 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE :~~"'" Re: Jel Pumped \VeIls Subject: Re: Jet Pumped \VelIs From: "NSK Problem Well Supv" <n 1617@eonoeophillips.eonl> Date: Sat, 7 Dee 2002 14:07:01 -0900 To: Tonll\1aunder <tom _ nlaunder@~admin.state.ak.us> CC: "n 1617" <n 1617@eonocophillips.conl> Tom: 1 requested a list of surface powered jet pump wells from our PEls. The following should be the current total for the Kuparuk area: West Sak wells: 1C-123 (PTD 2010840) was recently 81 for high watercut 1C-135 (PTD 2012200) is a huff and puff well and was recently put on water injection cycle CPF 2 are as follows: 2L-307 (PTD 1982560) 2L-313 (PTD 1982190) 2L-315 (PTD 1982180) 2L-321 (PTD 1982620) 2L-325 (PTD 1982090) ~2N-303 (PTD 2001690) 2N-304 (PTD 2011300) 2N-305 (PTD 2001350) 2N-318 (PTD 2001000) 2N-319 (PTD 1981970) 2N-332 (PTD 2000790) 2N-337 (PTD 1981220) 2N-339 (PTD 1981000) 2P-415 (PTD 2012260) There are no surface powered jet pump wells at CPF3. 1 hope this answers your question. Let me know if you need more information. Jerry Dethlefs ConocoPhillips Problem Well Supervisor Tom Maunder <torn maunderr'·i'admin.state.i:tk.1J.s> 12/06/2002 09:00 AM To: NSK Problem Well Supv/PPCO@Phillips cc: Subject: Jet Pumped Wells Pete and or Jerry, 1 have some emails fro h'l b k maw 1 e ac. regarding the wells out there on jet pumps. WC"uld you Please Provide a-n d . 1 up ated listing of the wells present y on Jet pumps in greater KRU?? Thanks in advance. To Permit to Drill 200t 690 MD 7057 ~' TVD DATA SUBMITTAL COMPLIANCE REPORT 1116~2003 Well Name/No. KUPARUK RIV U TARN 2N-303 Operator CONOCOPHILLIPS ALASKA INC 5744 ,-/ Completion Dat 1/2/2001 -/ Completion Statu 1-OIL Current Status 1-OIL APl No. 50-103-20352-00-00 UIC N _ REQUIRED INFORMATION Mud Log No Sample N._~o Directional Survey No DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Media Fret 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 L L R R D D R R D D R R D D R R C C ~.,e~SBHP 5 FINAL Survey Report Directional Survey FINAL Directional Survey FINAL Directional Survey FINAL Directional Survey FINAL 'fl3~50 ~-"'"'"'~- FINAL LIS Verification FINAL t.,1~356 ~ FINAL 2593 6100 2593 2556 7002 6650 7002 6964 Open 10/10/2001 10350 2593-7002 CH 2/2312001 6100-6650 BL, Sepia 1/9/2001 Survey Report Paper Copy OH 6/1412001 Dir Survey, Digital Data OH 6/1412001 Dir Survey, Paper Copy OH 6/14/2001 Dir Survey, Digital Data OH 6/14/2001 Dir Survey, Paper Copy OH 10/10/2001 10350 ~.2593-7002 Digital Data OH 10110/2001 LIS Verification Paper Copy oh 10/1112001 10356 ~Z5"~-6964 Digital Data ~, Well Cores/Samples Information: Name Interval Start Stop Sent Received Dataset Number Comments . ADDITIONAL INFORMATION Well Cored? Y / ~) Chips Received? ~ Analysis ~ R ~.c.~.ivP. d ? Daily History Received? Formation Tops (~/N Comments: Permit to Drill 2001690 DATA SUBMITTAL COMPLIANCE REPORT 1 I16~2O03 Well Name/No. KUPARUK RIV U TARN 2N-303 Operator CONOCOPHILLIPS ALASKA INC APl No. 50-t03-20352-00-00 MD 7057 TVD 5744 Completion Dat 1/2/2001 Completion Statu 1-OIL Current Status 1-OIL UIC N Compliance Reviewed By: (' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other _X 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1' FSL, 500' FEL, Sec. 34, T10N, R7E, UM At top of productive interval 1970' FNL, 673' FWL, Sec. 35, T10N, R7E, UM At effective depth At total depth 1637' FNL, 4484' FEL, Sec. 35, T10N, R7E, UM 5. Type of Well: Development _X Exploratory _ Stratigraphic _ Service__ (asp's 461093, 5912007) (asp's 462279, 5915311) (asp's 462400, 5915640) 6. Datum elevation (DF or KB feet) RKB 35 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2N-303 9. Permit number / approval number 200-169 / 10. APl number 50-103-20352 11. Field / Pool Kuparuk River Field / Tarn Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size CONDUCTOR 140' 16" SURF CASING 2602' 7-5/8" PROD CASING 6240' 5-1/2" LINER 773' 3-1/2" LINER 7O57 5744 6893 5621 feet Plugs (measured) feet feet Junk (measured) feet Cemented 9 cu yds High Early 448 sx AS III Lite, 240 sx Class G, 80 sx Class G 320 sx Class G Measured Depth True vertical Depth 140' 140' 2637' 2302' 6275' 5144' 7048' 5738' Perforation depth: measured 6562' - 6576' true vertical 5366' - 5377' Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 3-1/2", 9.3#, L-80 Tbg O 6270' MD. No packer CAMCO 'DS' O 504' MD. Oil & Gas Co~s. Commissior~ 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl Representative Daily Average Production or Injection Data Gas-Md Water-Bbl Casing Pressure Tubing Pressure . 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _X Oil__ X Gas__ Suspended_ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,,,,:,_ T.,.. w.... Form 10-404 Rev 06/15/88 · ORIG'INAL Questions? Call Peter Nezaticky 659-7224 Date 11/12/01 Prepared by Sharon AIIsup-Drake 2634612 SUBMIT IN DUPLICATE PHILLIPS Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(2N(W4-6)) WELL JOB SCOPE JOB NUMBEI~ ' " 2N ANN-COMM 1107011721.4 DATE DAILY WORK UNIT NUMBER 11/08/01 OOA CEMENT TOP JOB 2N-303, 317, 343, 349 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR I YESI YES APC-AREND NEZATICKY FIELD AFC# CC# DAILY COST ACCUM COST Signed ESTIMATE K85329 35TN2N1 NG Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 0 PSI 0 PSI 0 PSI 0 PSII 0 PSII 0 PSI DAILY SUMMARY CEMENT TOP JOBS ON THE SURF X COND (OOA). 2N-303, 317, 343, 349.[VVH Maintenance] TIME LOG ENTRY 11:00 ON LOC. MIRU 12:00 PRE-JOB SAFETY MEETING. START MIXING CEMENT. 12:30 12:45 CEMENT MIXED, 6 BBL OF 15.7 PPG ARTIC SET. START PUMPING CEMENT DOWN 2N-303 SURF X CONDUCTOR ANNULUS (OOA) THROUGH 1" HOSE TAKING RETURNS TO VAC TRUCK, PUMPED 5 BBL. START MIXING 4 BBL OF CEMENT. 13:00 CEMENT MIXED MOVED TO 2N-343. PUMPED 2 BBL INTO A 6 Fl' VOID. 13:25 MOVED TO WELL 2N-349. PUMPED 1 BBL INTO A 7.5 FT VOID. 14:00 DUMPED 5 GAL OF CEMENT INTO 2N-317. SMALL 8 INCH VOID, BUT' PREVIOUSLY REPORTED SOFT MATERIAL WHEN TAGGED. 14:30 RDMO SUNDRY NOTICE 10-404 Phillips Kuparuk Well 2N-303 Annular Cement "Top-Job" November 08, 2001 Phillips Alaska, Inc., Kuparuk well 2N-303 top of cement between the surface pipe conductor (7 5/8" x 16") was measured at 26 feet below grade. Arctic Set I cement (15.7 ppg) was pumped into the annular void (5 bbls) via a hose, filling from the bottom-up. The cement top was brought to the surface of the conductor casing. The State Inspector was notified of the cement job and waived attendance, but will inspeC:t the wellhead post cementing. The field Well Service Report is attached. Oil & Gss Cons. (;olmission .~,nchorage (' WELL LOG TRANSMITTAL To: State of Alaska October 9, 2001 Alaska Oil and Gas Conservation Comm. Atm.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 2N-303, AK-MM-00247 oPoo- ~,~ . 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-303: Digital Log Images 1 CD Rom RECEIVED OCT 1"~ 2001 Oil & (;as Cons. To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 October 4, 2001 MWD Formation Evaluation Logs 2N-303, AK-MM-00247 1 LDWG formatted Disc with verification listing. APl#: 50-103-20352-00 PLEASE ACKNOWLEDGE RECEIPT 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: ocr 3-Aug-01 AOGCC 333W 7th Ave Suite 100 Anchorage, AK, 99501 To whom it may concern, Included in this package are disks for the following final surveys as requested. · 2N-303, IFR and MWD 7.¢X)--tl~ · 2N-305, IFR and MWD · 2N-349, IFR and MWD ?.~- It t · 2N-349A, IFR and MWD ZeD't~ If you have any questions or concerns please do not hesitate to call. Regards, -Vic Eppler SSDS IFR/SMS (907) 273-3564 RECEIVED ALIG 0,7 201~ PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 J. Trantham Phone (907) 265-6434 Fax: (907) 265-6224 February 26, 2001 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for 2N-303 (200-169) Dear Mr. Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Tam well 2N-303. If you have any questions regarding this matter, please contact me at 265-6434 or Brian Noel at 265- 6979. J. Trantham Drilling Engineering Supervisor PAI Drilling JT/skad RECEIVED FEB ?~ 7 ~.001 Alaska Oil 8, Gas Cons. Commission Anchorage ORIG, INAL STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification o! Service Well Oil [~ Gas ~] Suspended D Abandoned r-] Sen/ice 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. 200-169 / 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-103-20352-00 ,4. Location of well at surface ~,.,..__ _ 9. Unit or Lease Name 1' FSL, 500' FEL, Sec. 34, T10N, R7E, UM (ASP: 461093, 5912007) ~' ~'"':i'i'?'''i '. :" ~~T~: Kuparuk River Unit At Top Producing intewal ~. .- . '=-.-. ' [ V~:~ li 10. Well Number At1970' FNL, 673' FWL, Soo. 35, T10N, R7E, UM (ASP: 462279, 5915311)[ Total Depth ~ .... ~'""' ~~ ~"/-'- '} :i~ 11. Field 2N-303 and Pool 1644' FNL, 805' FWL, Sec. 35, T10N, R7E, UM (ASP: 462412, 5915636) Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Tam Pool RKB 35 feet'1 ADL 380053 :& 380054 ALK 4601 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, If offshore 16. No. of Completions November 4, 2000 November 15, 2000 Decerj~00~'~,,~. z/z~.tI N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 7057' MD / 5744' TVD 6920' MD / 5641' TVD YES [~ No r-~I N/A feet MD 1242' 22. Type Electric or Other Logs Run GR/Res, Res/Neu, CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'I-rOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.5# H-40 Surface 115' 24" 9 cu yds High Early 7.625' 29.7# L-80 Surface 2636' 9.875" 448 sx AS III Lite, 240 sx Class G & 60 sx AS I 5.5" X 15.5# L-80 Surface 6275' 6.75" 80 sx Class G 3.5" 9.3# L-80 6275' 7049' 6.75" 320 sx Class G 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD intewal, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 6270' 6260' (CSR) 6562'-6576' MD 5366'-5377' TVD 4 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 6562'-6576' M D 170M# 20/40 and 12/18 proppant behind pipe with 8.3 ppg on peris. 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) February 20, 2001 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF .WATER-BBL CHOKE SIZE IGAS-OIL RATIO I 2/22/2001 3.5 Test Period > 378 155 29 100 ~ choke open I 694 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) press. 391 psi 1254 psi 24-Hour Rate > 2676 1100 207 not available 28. CORE DATA Brief description of Iithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECEIVED N/^ lIB Z 7 2001 ^laska Oil & Gas Cons. Commission ^nchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ORIGINAL Submit in duplicate ,r GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. T-3 6447' 5277' T-2 6576' 5377' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Brian Noel 265-6979 Signed %..~ ~ Title Ddllina E nalneerln.q Supen/lsor Date ~:~ <~ ~--~'~ t James Trantham Prepared by Sharon AIIsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water .injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for 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: Shut-in, Other-explain. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, RECEIVED Item 28: If no cores taken, indicate 'none". Form 10-407 FEB 2 7 2001 Alaska Oil & Gas Cons. Commission Anchorage Date: 02/09/01 ARCO ALASKA INC. WELL SUMMARY REPORT .... RECEIVED FEB Z ? 2001 Alaska Oil & Gas Cons. Co~s~o,n : 1 Anchorage ,, WELL:2N-303 STATE:ALASKA COUNTY: NORTH SLOPE WEST FIELD: TARN PARTICIPATING AREA SPUD:il/04/00 START COMP: RIG:NABORS 19E BLOCK: FINAL: WI: 0% SECURITY:0 API NUMBER: 50-103-20352-00 11/03/00 (D1) TD/TVD: 115/0 SUPV:R.W. SPRINGER MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 ( 115) FUNCTION TEST DIVERTER, PREPARING TO P/U BHA. (RIG ON Move modules to 2N-303. Rig accepted @ 2200 hrs. 11/3/00. Nipple up diverter system. 11/04/00 (D2) TD/TVD:. 463/0 SUPV:R.W. SPRINGER MW: 9.6 VISC: 85 PV/YP: 26/44 APIWL: 8.4 (348) DRILLING SURFACE ~ 622' (24 HR HI-LINE) Nipple up diverter stack. Function test diverter system. Diverter valves leaked, attempt to tighten packing on valve, still leaking. Change gasket on diverter line knife valve and nipple back up. Drilled from 115' to 463'. 11/05/00 (D3) TD/TVD: 1538/0 SUPV:R.W. SPRINGER MW: 10.0 VISC: 58 PV/YP: 25/19 APIWL: 6.0 (1075) DRILLING SURFACE @1768' (24 HR HI-LINE POWER) Drilled from 463'-1538'. 11/06/00 (D4) MW: 10.1 VISC: 56 PV/YP: 22/24 APIWL: 4.4 TD/TVD: 2645/2308 (1107) POH TO RUN CASING SUPV:R.W. SPRINGER Drilled from 1538'-1760'. Circulate and condition for trip, pump sweep. Wiper trip to 1057', hole slick, no problems, RIH. Drilled from 1760'-2645'. Circulate and condition mud. 11/07/00 (D5) MW: 10.1 VISC: 47 PV/YP: 18/16 APIWL: TD/TVD: 2645/2308 ( 0) N/D DIVERTER SYSTEM (RIG ON HI LINE POWER LAST 24 HRS SUPV:DEARL W. GLADDEN Circ and condition for wiper trip. Wiper trip to 1562' Circ and condition to run casing. PJSM. Run 7-5/8" casing. PJSM. Cement casing. Plug bumped, floats held. 11/08/00 (D6) MW: 9.6 VISC: 43 PV/YP: 12/12 APIWL: 6.0 TD/TVD: 2645/2308 ( 0) PREFORM STRIPPING DRILL SUPV:DEARL W. GLADDEN PJSM to N/D diverter. Unable to break out landing joint. N/D diverter. Install casing head and test packoff to 1000 psi. OK. PJSM. N/U BOPs and test to 250/3500 psi. PJSM. 11/09/00 (D7) MW: 9.6 VISC: 44 PV/YP: 13/11 APIWL: 5.8 TD/TVD: 3029/2604 (384) DRLG 6 3/4" HOLE @ 3290' (RIG ON HI LINE POWER LAST 24 SUPV:DEARL W. GLADDEN PJSM. Perform stripping drill and well kill drill. RIH. Date: 02/09/01 ARCO ALASKA INC. WELL SUMMARY REPORT i RECE Vi::D, ,,- FEB g ? ZOO1 Page: 2 Alaska Oil & Gas Cons. Commission Anchorage Circ slowly down to tag cement, tag cement ~ 2516' Drilling cement, FC & FS and drilling 2645' to 2675', 30' new hole LOT point. Circ and C/O mud to new LSND system. Perform LOT, 15.9 EMW. Drilling from 2675' to 3029'. TOH. C/O kelly swivel packing. 11/10/00 (D8) MW: 9.6 VISC: 45 PV/YP: 14/ 9 APIWL: 4.4 TD/TVD: 3788/3194 (759) L/D MWD - ATTEMPT REPAIRS - NO SPARE ON LOCATION (RIG SUPV:DEARL W. GLADDEN Drilling 3029' to 3788'. Rig on weather hold. Phase 3 conditions. PJSM. WOW. PJSM. TOH slowly. 11/11/00 (D9) MW: 9.6 VISC: 45 PV/YP: 12/ 9 APIWL: 4.0 TD/TVD: 3788/3194 ( 0) TIH W/BHA 94 ( RIG ON HI LINE POWER LAST 24 HRS - NO P SUPV:DEARL W. GLADDEN TOH. Attempt to repair MWD, problems with sub bus. Cannot get tool from Deadhorse, Phase 3 weather conditions. TIH to shoe w/circulating assembly. WOW. Circ slowly @ shoe. Attempt to convoy tools from Deadhorse. TOH. 11/12/00 (D10) MW: 9.6 VISC: 48 PV/YP: 15/15 APIWL: 4.0 TD/TVD: 4609/3835 ( 821) DRLG 6 3/4" HOLE @ 4950' ( RIG ON HI LINE POWER LAST 2 SUPV:DEARL W. GLADDEN PJSM. MAD pass from 3612' to 3787'. Drilling from 3788' to 4609' 11/13/00 (Dll) MW: 9.6 VISC: 46 PV/YP: 15/14 APIWL: 4.4 TD/TVD: 5653/4649 (1044) DRLG 6 3/4" HOLE @ 6006' ( RIG ON HI LINE POWER LAST 2 SUPV:DEARL W. GLADDEN Drilling from 4609' to 5400'. Circ hole clean. Wiper trip to 3794', no swab. Drilling from 5400' to 5653' 11/14/00 (D12) MW: 9.6 VISC: 44 PV/YP: 14/16 APIWL: 3.8 TD/TVD: 7057/5745 (1404) WELL TD'ED@ 7057'- CIRCU HOLE CLEAN FOR WIPER TRIP (RI SUPV:DEARL W. GLADDEN Drilling from 5653' to 6791'. 11/15/00 (D13) MW: 9.6 VISC: 44 PV/YP: 14/16 APIWL: 3.8 TD/TVD: 7057/5745 ( 0) RUN 5.5" X 3.5'' CSG (RIG ON HI LINE POWER LAST 24 HR SUPV:DEARL W. GLADDEN Drilling from 6791' to 7057'. Circ hole clean. Wiper trip to 5140', tight hole ~ 5850', 5225'. Work thru, clean. Circ & condition mud to run casing. Pump hi vis pill. Spot lube pill. TOH. PJSM. 11/16/00 (D14) MW: 8.6 VISC: 28 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7057/5745 ( 0) RUN 3 1/2" TBG COMPLETION ( RIG ON HI LINE POWER LAST SUPV:-DEARL W. GLADDEN PJSM. Run 5.5" x 3.5" casing. CBU @ shoe. Run 5.5" x 3.5" casing to 7049'. Circ and condition hole to cement. Pump Date: 02/09/01 ARCO ALASKA INC. WELL SUMMARY REPORT RECEIVED FEB 3 ? 001 Page: 3 Alaska Oil & Gas Cons. Commission Anchorage cement. Bump plug, floats held. 11/17/00 (D15) MW: 8.6 VISC: 28 PV/YP: 1/ 0 APIWL: 0.0 TD/TVD: 7057/5745 ( 0) L/D DP OUT OF DERRICK ( RIG OFF HI LINE POWER ll:00AM SUPV:DEARL W. GLADDEN Hold PJSM. Run 3.5" tubing completion assembly. Test casinH to 3500 psi. Circ to clean 8.6 ppg sea water. PJSM. Freeze protect well. PJSM. 11/18/00 (D16) MW: 0.0 VISC: 28 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 7057/5745 ( 0) MOVE RIG TO 2L - 317 ( 3 MILE MOVE ) SUPV:DEARL W. GLADDEN Perform LOt 7-5/8" x 5.5" annulus, EMW 15.4 ppg. N/D BOP. N/U & test tree to 5000 psi, OK. Rig released 1730 hrs. 11/18/00. 12/24/00 (D17) MW: 0.0 VISC: 28 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 0/5745 ( 0) NU BOPE AT 6AM 12/25 SUPV:RICK OVERSTREET Move rig to 2N pad. Accepted rig @ 12:00 am 12/24/00. 12/25/00 (D18) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 0/5745 ( 0) R/U RUN 1-1/4" HYDRILL PIPE TO CIRC. HOT SEAWATER. SUPV:RICK OVERSTREET N/D wellhead, N/U BOPE. Test equipment. Run in hole with 2.73" kick over tool for pulling 1" dummy valve from GLM. Hit obstruction at 43'. Could not work thru obstruction, possibly ice. Run in hole with slick line with 2" sample catcher, hit ice at 61'. 12/26/00 (D19) MW: 8.6 VISC: 28 PV/YP: 1/ 0 APIWL: 0.0 TD/TVD: 0/5745 ( 0) PULLING OUT OF HOLE WITH COMPLETION SUPV:RICK OVERSTREET RIH w/1.25" hydrill w/muleshoe tagged ice plug @ 59', plugged melted. RIH w/retrieving tool, pulled 1" dummy valve from GLM @ 5461' PJSM. POH w/3.5" completion assembly. 12/27/00 (D20) MW: 8.6 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 0/5745 ( 0) NIPPLING DOWN BOPE SUPV:R.W. SPRINGER POH w/3.5" tubing. PJSM. Rib w/3.5" tubing. Reverse circ. Displace well with clean seawater. 12/28/00 (D21) MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 TD/TVD: 0/5745 ( 0) WELL RECOMPLETED, RIG MOVED TO 2N-314 SUPV:R.W. SPRINGER Test tubing, test annulus. Freeze protect well. Test tubinH and annulus to 3500 psi, OK. N/D BOPE. N/U tree. Release rig @ 4:00 pm 12/28/00. Well Service Report FEB g ? 2001 Alaska Oil & Gas Cons. Commission Anchorage Well 2N-303 Date 01/02/2001 ][Job Scope IlJ°b Number I II~24°°~27'1 I l[Unit Number [ IIDR~LL~NG SUPPORT-CAPITAL [IDaily Work II~m'-~ su~,~,o.T-c^~,xT~: PERFORATrNO & ss.:el12145 I IDaY IlOpera.on Complete Ilsucce,sfui II~ey Person IlSu~.~,o, 0 True False SWS- GOBER STEPHENSON !lInit Tbg Press IlFin~ Tbg Press IIInit Inner Ann Ilvin~l Inner Ann [lI~it Outer Ann IlFin~ Outer Ann I 0 II 0 Il 1450 II 1450 Il 0 II 0 Daily COULD NOT GET PAST 6229' WITH GUN-GAMMA TOOL - RUN PSP TOOL Summary FOR CORRELATION LOG - PBTD TAGGED @ 6816' - JEWELRY LOGGED FROM PBTD TO 6100' - PERFORATED FROM 6562'-6576' WITH 2.5" HSD/BH/4 SPF/180 DEG PHASING ORIENTED +/- 90 DEG FROM HIGH SIDE USING 35 B UP CHARGES (EHD = 0.62" & TTP = 10.2") [Perf, Pressure Data] Time IlLo~ l~ntry 07:00 II~'EPART ~:CC FOR mC 07:30 II~EPART fac FOR 2N-303 o8:45 II~l~VE o1~ rOCATIO~-SPOT VEaICr~S 09:~5 IIHOLD S~TY MEET~G I o9:25 IISTART ~G UP I ~0:20 I[~ TO 30~ 10:25 II~ TO 3~ 10:35 II~ wx~ G~-CC~-M~D-S~-14' =.5" ~SD G~ I 11:30 IIs~ DO~ ~ G~M ~ ~=9' I ~:35 r~OO~ ~U~m~ ~I~S ~ ~9' [CC~-~-~OO~ S~. GLM ~ 6206'] ]1:45 [Igoo Tm m enss ~OM 6:0:' TO 5450' ~:x5 II~oo~ x=:4s II~GDOW~G~N ~=:55 II~~ ~OW~ ~OS~ ~OZ~ 13:~5 IIco~~~o~ 13:45 II~ ~e ~se ~0~ mw~y ~0~ Page 2 of 3 14:35 GET THROUGH GLM #4 - TENSION BOUNCED A BIT BUT NO INDICATION OF A TAG OR OBSTRUCTION [ 14:40 IITAG PBTD @ 6816', LOG PASS FROM PBTD TO 6000' -I 114:55 IIPooi-i I I {.5:40 Ilux~ r, OWN PSP I 16:10 limo uP Gtm 16:30 {{RIH WITH CCL- MPD-SAFE 14' 2.5" HSD 17:20 {IAT 6600' - GUN SLOW~G DOWN - PUTT~G SLACK ~ THE HOLE 15:25 II~oo xm ~ ~nss FROM ~5o' xo ~oo' 15:35 I{LOO INTO SHOOTING POS~ION, PUMP ~P TO 3500 PSI US~G T~PLEX 15:50 PERORATE FROM 6562' - 6576' - WHP DROPPED ~OM 35~ PSI TO 3000 PSI 15:55 linGO. ~8:~0 ling DOWN GUN- ~g SHOTS FX~D ~:35 II~GUP~S~ I1~:45 II~H WXT~ 2 WGT BAR-CEE-GR- ~S- TEM~ I19:20 }{LOG TIE IN STRIP I19::s 'llsr~rs~v e ~9.0' ~19:30 ]IBHP HAS NOT STABIL~ED ~T 20:30 ~LL IS RELAT~ELY ST~LE - ~START SBHP LOG - ~ER 20 M~, w~ssu~ ~s sm~ w~~ I::::~ II~sr~rs~avno~ I 22:55 20 M~ STATION, P~SSU~ VAR~D BY LESS TH~ 1 PSI, SBHP = 2702 PSI ~ 6569' MD I 23:00 IISTART SECOND SBHP LOG-P~SSU~ NOT ST~LE I I :3:as II~sr~rs~vno~ I 00:10 20 M~ STATION, P~SSU~ VAR~D BY LESS TH~ 1 PSI, SBHP = 2659 PSI ~ 6~0' MD I23:56 {100:12 POOH I I:3:57 1100:45 srn~r~vo~ I I23:58 Il02:00 ~G DOWN COMPLETE-LEAVE LOCATION I I:3:59 1103:00~ru~ronc I RECEIVED FEB Z 7 2001 Alaska Oil & Gas Cons. Commission h~p://www~ak.ppc~.c~m/we~s/wsr.../atdbw~rk~g.asp?~D=2N3~3~022001~94329&~c~h~a~ 2/9/01 Page 1 of 2 Well Service Report IIWell 12N-303 Date 10Ul 1/2001 liJob Scope IIJob Number [IDRILLING SUPPORT-CAPITAL 124001527.1 IIDany Work Ilunit Number [[DRILLING SUPPORT-CAPITAL: INITITAL FRAC TREATMENT I [Day [[Operation Complete [[Successful []Key Person [[Supervisor 700 II o II 1100 II ' 500 II · 300 II 350 Daily Summary PUMPED INITIAL FRACTURE TREATMENT. JOB INCLUDED BRACKETFRAC STAGE. PLACED 170M# 20~40 AND 12/18 PROPPANT BEHIND PIPE WITH 8.3 PPA ON PERFS, 98% OF DESIGN. HAD TSO 65 MINUTES INTO JOB, HAD NWBSO 31 BBLS INTO FLUSH. LEFT 5870~ PROPPANT IN WELLBORE. [Frac-Refrac] I'nm'' IlI'°g~:n~ I 11:45 ' IlcoN'rINu~. RIG-UP. RIGGING UP LITrLE RED FOR BACKSIDE PRESSURE CONTROL. I ~2:oo IIP~- uP Props, Fotn, r~ xc~. XN ON~ LXN~. ~AW LI~, ALL ProPS mM~D uP. [ 12:35 IlwAm uP LIraS, SET ~EE SAVER. PT L~S TO 1~ PSI. GOOD ~ST. 13:~ START B~A~OWN STAa~. 1~ BB~S XmO STAa~, HAD ~A~ ~ C.IC~SAN, sam DOm. OBS~WD ~ m ~m~ ~aI~ COmmAndaNT. ~X~N~UIS.~D ~, ~O~D ~Aa ON ~AUST. SWAP O~ CmC~S~. ~-~~ ~O~CT B~D DOW~ LI~. 13:25 CO~N~ B~A~O~ STAGE. 150 BBLS 2~ LI~AR GEL PE~ORMED SDT, XS ~IC = 18~ PSI, ISIP = 230 PSI, FG = 0.49 PS~. SUSPECT POSSIBLE PRESS~E GAUGE PROBLEM. 13:35 IIMA~ GEL FOR SCO~ STAGE, WORK ON P~SSU~ ~NSDUCER. FO~D PROBL~ [l~ ~NSDUCERS, PREVIOUS P~SS~S A~ ~ACCU~. 13:55 START SCO~ STAGE. 100 BBLS ~ PAD, 50 BBLS 1 PPA SCO~, 132 BBLS 2~ LI~ ~USH. PE~O~ED SDT, XS ~C = 1440 PSI, ALL PE~. MA~ MO~ GEL FOR DATA,AC. 14:25 START DATA~C. 3ffi BBL 4~ ~ GEL, 35 BPM. 59 BBL LI~AR GEL FLUSH. SH~ DO~ FOR DECL~ ANALYSIS, NO CLOSU~ OBSERVED ~ 30 MIN~S, ~DO DAT~AC. MA~ MORE GEL. 15:30 START SECOND DATA~C. 300 BBLS 4~ ~ GEL. 59 BBL LI~AR G~ ~USH. SD FOR DECL~ ANALYSIS. ~H~ = 4~1 PSI, ISIP = 965 PSI, FG = .62 PS~, ~ = 849, TC = 14.6 M~, E~C = 53%. PLAN JOB FOR DESIG~D PAD OF 800 BBLS. MA~ MO~ GEL BATCH UP B~C~~C MA~~S. 'l 16:3o Ilmow~ums DO~HOL~TOWAm ~LX~S. /~laska 0il & Gas Cons. Commissioo ^nchorage' Page 2 of 2 35 BPM, 780 BBLS 20~ LINEAR GEL FLUSH AT 22 AND 18 BPM. 18:15 SWITCH TO PROPPED FRAC JOB, 800 BBL 40~ XL GEL PAD, 35 BPM. CUT RATE TO 25 BPM FOR SLURRY STAGES. 200 BBL 1 PPA STAGE, 300 BBL 1-4 PPA. IN 4 PPA FLAT STAGE, HAVING TROUBLE KEEPING UP AT 25 BPM WITH THE PCM. WATER FROM TANKS IS FOAMING UP EXCESSIVELY. CUT RATE TO 22 BPM. ABLE TO KEEP UP WITH PUMPS AT 22 BPM. PUMP 400 BBL 4 PPA FLAT STAGE. SAW PROBABLE TSO -65 MINUTES INTO JOB. 400 BBL 4-8 PPA RAMP AT 22 BPM. HAD NWBSO 31 BBLS INTO FLUSH. PLACED 170,0004~ BEHIND PIPE, HAD 8.3 PPA 12/18 ON PERFS. LEFT 5870~ SAND IN WELLBORE. I 19:35 [ISHUT DOWN' FLUSH OUT DS EQUIP AND RIG DOWN DS' ALLTREESAVER RUBBERSIii~COW~D' 21:30 lids I RF_.CF_.. VE-D FEB ~ 7 ~.001 Alaska Oil & Gas Cons. Commission Anchorage 13-Jun-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definative Survey Re: Distribution of Survey Data for Well 2N-303 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 7,057.00' MD (if applicable Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 00000 0~~ 0~~ 0~0~ ~0~0 ~~ ~0~0 ~0 ZZZZZ ZZZZZ ZZZZZ ZZZZZ ZZZZZ ZZ~Z ZZZZZ ZZZZZ ZZZZZ ~~ ~0000 ZZZZZ ZZZZZ ~~0 mmmmm 00000 ~0000 ZZZZZ mmmmm mmmmm mmmmm mmmmm mmmmm 00000 0000~ 00~ m= o z 0 ..... ..... ~0~ 0~~ ..... ~0~ 00000 ~0~ ..... zzzzz ~0~ ~00 ~~0 ZZZZZ 0~0~ ~0~0 ~0~ 00000 ~0~ 0~~ ZZZZZ mmmmm ZZZZZ ~~0 m~~ ~0~ ..... ~0~ ZZZZZ ..... ~00~ ~0~ z o ::3' -- e 00000 00000 ~ ~' Z ZZZZZ ZZZZZ 0 ~ ~ ~ 0~~ < m mmmmm o Z o ~~ ~ 0 ~0~ ~ Z ZZZZZ 00~ ~0~ ~0~0 ZZZZZ 000~ m~~ ~00~ ~~ ZZZZZ ZZZZZ ~0~ ~0~ o~o~ ~~ Z o Z o o z Zo o "~ Z 00000 00000 00000 00000 ~00~ ..... ~0~ ..... ~0~ 00000 .......... ~0~ ~~0 ~~ ~00~ ~~0 00000 00000 00000 00000 00000 ..... ~00 ~00 ~0000 0~00 0~00 00000 ~00 ~00 00000 ZZZZZ ZZZZZ ZZZZZ ZZZZZ ZZZZZ Z~ZZ ~~ ~~ 0~0~ ~00~ ~0~ mmmmm mmmmm mmmmm mmmmm mmmmm 00000 ~00 00~ ~~ ~~ ~~ 00000 00000 ~0~ 0~~ ~0~0 ~~ ~~ 00000 .............................. ZZZZZ ZZZZZ ZZZZZ ZZZZZ ZZZZZ ZZZZZ mmmmm mmmmm mmmmm mmmmm ~~0 00000 ~00~ ~~ o o Z o Z 0 .................... ~0~ ~0~ 000~ 0~~ 00000 00000 00000 00000 00000 00000 00000 00000 .....~~ ~~ ~ ~0~ 00~0~ 00000 00000 .......... ZZZZZ ZZZZZ ZZZZZ ZZZZZ 0~~ ZZZZZ ZZZZZ ~0~0~ ~0~ mmmmm mmmmm mmmmm mmmmm ZZZZZ ZZZZZ ZZZZZ ZZZZZ ZZZZZ ZZZZZ Z o Z 0 . < ~' O0 00000 00000 00000 ~ .. ZZ ZZZZZ ZZZZZ ZZZZZ ~ ~~ ~00 000~ ~ ~0~ ~~ ~0~ mm mmmmm mmmmm mmmmm zz zzzzz zzzzz zzzzz ~~ ~00 ~~ 0~00~ .o~ ooooo oo-,o~o .o.o.o.o.o .......... 003 0300,300 '-,,l(Ol'O.,b, 01 .-..~3.,b, o~o Z o "~ 1:3 Z 0 ~ mO~ z Z 0 0 ~ O0 0~00 ~ 0 ~ ~ 0000 ~§8~~ §~o ~°~ Re: 2N-303 workover Subject: Re: 2N-303 workover Date: Wed, 20 Dec 2000 11:35:02 -0900 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: Brian D Noel <BNOEL@ppco.com> CC: AOGCC North Sope Office <aogcc_prudhoe_bay@admin.state.ak. us> Brian, ~Ol~ --I, ~-~ Thanks for the notification. I am not aware of any further information we would need for the workover. As indicated in our earlier conversations, once the rig left it has not been possible to any further work due to the obstruction in the tubing. Although there are no perforations in the well, the 3500 psi BOP test pressure will still apply. Tom Maunder Brian D Noel wrote: > Tom- > Well 2N-303 was drilled, cased and tubing run in November 2000 by Nabors 19E > (Permit #200-169). But an obstruction in the tubing has prevented the > perforation and fracture stimulation of the Bermuda interval. As discussed a > few weeks ago, Nabors 19E will be moving back onto 2N-303 to pull~rerun the > tubing after operations are complete on 2L-317. The estimated start date for > the 2N-303 workover is December 24. As agreed, this work is covered under the > existing permit and by this email we are notif~ng AOGCC of our plans Form 407 > (completion report) mil be filed afterwards. Please let me know if additional > information is needed. Thanks- Brian 265-6979 ~eer Alaska Oil and Gas Conservation Commission 1 of 1 12/20/00 11:37 AM ALASIIA OIL AND GAS CONSERVATION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 James Trantham Drilling Engineering Supervisor Phillips Alaska, Inc. P O Box 1966i! 2 Anchorage, AK 99510-0360 Re; Kuparuk River Unit 2N-303 Phillips Alaska, Inc. Permit No: 200-169 Sur Loc: I'FSL, 500'FEL, Sec. 34, T10N, R7E, UM Btmhole Loc. 1616'FNL, 782'FWL, Sec. 35, T10N, R7E, UM Dear Mr. Trantham: Enclosed is the approved application for permit to drill the above referenced well. 'i 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. Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this 2_. ~' ''~ day of October, 2000 dlf/Enclosures 'cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~,' ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work: Drill r~ Redrill D I lb. Type of well. Exploratory r~ Stratigraphic Test E] Development OIl [_~] Re-entry r'~ Deepen DI Service [~ Development Gas D single Zone r~ Multiple Zone D 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. RKB 35 feet 3. Address 6. Property Designation ..~.5-z//Z¢ Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 380053 ALK 4601 ~) Tarn Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) 1' FSL, 500' FEL, Sec. 34, T10N, R7E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 1903' FNL, 681' FWL, Sec. 35, T10N, R7E, UM 2N-303 #U-630610 At total depth 9. Approximate spud date Amount 1616' FNL, 782' FWL, Sec. 35, T10N, R7E, UM October 26, 2000 $200,000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 681' @ Target feetI 2N-305 27.5' O 422' feet 2560 7080' MD / 5756' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) iKickoff depth: 300 MD Maximum hole angle 39° Maximum surface 1862 psig At total depth (TVD) 2400 psig 18. Casing program Setting Depth size specifications Top Bottom Quantity of Cement Hole Casin~l Wel~lht Grade CoupIIn~l LunCh MD TVD MD TVD (include sta~le data) 24' 16" 62.5# H-40 Weld 83' 35' 35' 118' 118' 9 cu yds. High Early 9.875' 7.625" 29.6# L-80 BTCM 2593' 35' 35' 2628' 2300' 290 sx AS III L & 240 sx Class G 6.75' 5.5" x 15.5# L-80 LTC-Mod 6259' 35' .35' 6294' 5146' 50 sx Class G 6.75" 3.5" 9.3# L-80 8rd EUE 786' 6294' 7080' 7080' 5756' 320 sx Class G 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total Depth: measured feet Plugs (measured) true vertical feet Effective Depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Conductor Surface Production #REF! ...... ' Perforation depth:measuredORIGINAL .ooo 20. Attachments Filing fee [~ Property Plat D soP Sketch [~] Dive,er Sketch r'~ Drilling program r~ Drilling fluid program r~ Time vs depth plot DRefraction analysis D Seabed report D 20 AAC 25.050 requirements D 21. i hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Call Brian Noel 265-697; Signed ["'~-~~ Title: Drilling Engineering Supervisor Date , o · ~-"James Trantharn Pret~ared bv Sharon AIIsuD-Dral(~ Commission Use Onl) Permit Number I ^p,n~mb~r I Approval~ate ISee oover letter ,~__,.~) ._//~4:~ 50-/~),~_.~ "- -.,~-~,....~'.2~- O (~ //~f~ -' C~ ~.~' ~ Ifor other requirements Condit,o.sof~oproval samples ro.u,red I--I Ye. [] .o Mud~ogre.uired I--I Ye. El .o Hydrogen suit,de measures !--I Yes [] .o D,roc~,onalsurvey ro.u,red I~ Yes I--I .o by order of ORIGINAL $1Gr,~,L.. ~ ;, Approved by r3 T=,~,.,.. o .... Commissioner the commission Date ..................... IUUII[ Form 10-401 Rev. 12/1/85 · Submit in triplicate ( Phillips Alaska, Inc. GENERAL DRILLING AND COMPLETION PROCEDURE KUPARUK RIVER FIELD -- PRODUCER/Injector KRU 2N-303 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" or 6-1/2"x7-1/2" 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 BTC-Mod Csg X 3-1/2" L-80 8rd EUE-Mod tapered production casing string with Baker casing seal receptacle at crossover point. 8. Pressure test casing to 3,500 psi. . 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. 10. Set TWC, ND BOPE and install production tree. 11. Secure well. Rig down and move out. 12. Handover well to Operations Personnel. ( Phillips Alaska, Inc. (' DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU 2N-303 Drillinq 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% Drilling Fluid System: 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% Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Degasser 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 5381' TVD. Gas gradient is anticipated to be 0.1 psi/ft. Using this data, the MASP is calculated to be: MASP=((2400/5381)-0.1)'5381 MASP=1862 psi Therefore PAl will test the BOP equipment to 3500 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 (0.45 psi/fi). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 9.11 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 5381'. Target (Midpoint T2 T3) (2400+150)/(0.052'5381)=9.11. Phillips Alaska, Inc. (" Well Proximity Risks: The nearest well to 2N-303 is 2N-305. The wells are 27.5' from each other at a depth of 422' MD. This well does meet with the Phillips ellipse separation criteria. Drillinq Area Risks: One identified risk in the Tarn 2N-303 drilling area is the shallow gas hydrates below the permafrost. To date the hydrates encountered while drilling the Tarn Phase 3 wells 2N-347, 2N- 332, 2N-316, 2N-318, 2N-349 & 2N-305 have been minimal. Standard SOP's have been developed to minimize the hydrate impacts i.e. maintaining Iow mud viscosity, pre-treating with Driltreat (Lecithin) and DriI-N-Slide, using cold make-up water for the mud, control drilling, and optimized flow rates. The surface hole will 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 7-5/8" 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 the possibility of gas migration from the reservoir to a ~" shallower sand interval. However, NO overpressured zones were encountered while drilling 2N-347, 2N-332, 2N-316, 2N-318, 2N-349 or 2N-305 wellbores. Log, tracer, pump-in test, and offset BHPBU evaluations indicate migration has not 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 4270' TVD, the highest required MW would be 10.8 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 injected down the dedicated disposal well but will be recycled or held for an open annulus). The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2N-303 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, Phillips Alaska, Inc. will submit application for approval of 2N-303 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 a~.e., kno.,W.n,,.:~to....pro¥ide vertical ;,~ ,~ ~ . ~ . ~ ., ,~ '~ ~ .,,.~.~ , ; Phillips Alaska, Inc. (' 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: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2,300') + 1,500 psi Max Pressure = 2,935 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 BTC-Mod 4,990 psi 4,242 psi 7,000 psi ~5,950 psi 3W' 9.3 L-80 2 8rd EUE Mod 10,530 psi8,951 psi 10,160 psi8,636 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). c,o~,~ ~ ..~h For: B Noel Dole pl~lted: 16-0ct-2000 Coor~not~ ore ~ V~t ~ference I~t ~3. True VeHicol Doptha oro reference RKB (~ leE). Phillips Alaska, Inc. Structure: Tern Drill Site 2N Well : 30;5 [Field : Tern Development Field Location : North Slope, Alaska TD LOCATION: 1616' FNL, 782' FWL SEC. 55, TION, R7E TARGET LOCATION: 1903' FNL, 681' FWL SEC. 35, TIO, R7E Easf (feel) -> 300 0 300 600 900 1200 1500 I I I I I I I I I [ I I I TD - Casing Pt¢ ~/c35 Target Mid- Bermuda )~- T3.1 400 800 1200 1600 2000 2400 2800 3200 3600. 4000 4400 4800 5200 5600 6000 T7 t Iceberg RKB ELEVATION: 154' o 19.22 AZIMUTHc4o ~.oOooK°P 3575' (TO TARGET) ~.00 DLS: 3.00 deg per 100 ft 12.00 · 15.00 18.00 21.00 Port Collar 24.00 Base Permafrost 0 Top W Sak EOC TRUE SS X,,x~Bose W Sok 7 5/8 Casing ~ 7 5/8 Casing ~X C80 ~lase W Sak EOC Top W Sak Permafrost Collar AVERAGE ANGLE N, c~o 39.07 DEG k c4o SU.ACE LOC~T~ON: 1' FSL, 500' FEL '~C37 SEC. 34, TION, E7E Iceberg ,~T7 T3.1 Target Mid- Bermuda T2 ~ C55 TD - Casing Pt i i i f i , i i i i i i i i i i i i i i i i s 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 Verficol Section (feet) -> Azimuth 19.22 with reference 0.00 N, 0.00 E from slot #$03 39oo - 3600 3300 3000 2700 240O 21oo I Z 0 1800 ~ 1500 (~ .-I- 1200 900 6OO 300 300. 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ~ 0 ~ ~'0 r'O r,o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C~ r~ 0 0 0 0 ',d'- 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 'd- ~ ~ m 0 i"O m O0 0 ~'0 I'0 ~ UO ,-- ,-- C',I r'o 0 0 0 'd~ 0 ,--- 0 0 0 ~ O~ O0 O0 O0 0,,1 0 CO CD C~I I" ! o o o ~0 0~ r-,. r--. ~ r',. r,-. r-,. b. r-.. r-.. r,,. r,,. ~ r~ r,.. ~ r--. ~ o ~0 ~ r'-- o o o o o o o o o o o o o o o o 0 r'~ 0 0 0 r,D O0 CD i'O ~ d' ,-- r~) CO ,-- 0 r'-, I'-- o,,I ~0 r,o [ ,Phi_Iii_p_?. A_laska, Inc. Structure: Tarn Drill Site 2N Well: 305 [Field : Tarn Development Field Location : North Slope, Alaska 310 320 2500 33O 340 TRUE NORTH 350 0 10 20 30 4O 5O 3OO 6O 29O 70 28O 8O 270 <~ 260 9O 100 250 110 240 120 23O 1300 210 200 190 Normal Rlone Trovelling Cylinder - Feet 130 140 150 160 180 170 All depths shown are Measured depths on Reference Well Phillips Alaska, Inc. c,.,,,.e ~ f~.c. For: B Noel ] Sfrucfure: Tarn Drill sire 2N Well : 503 Dele pletlea: 16-0¢t-2000 P,~, ..,.,~.. ~. ~o.~ vm',~,~ I". I Field : Tarn Developmenf Field Location: North Slope, Alaska Ceem;nelll ore Jn lee! tolerance ilo! ~303. I Tr~ Vii~gl Deplhl ara rlfl~'ln¢l RKB (NiP,era t"r).I East (feet) -> 1 O0 200 500 400 500 600 700 800 900 1000 1100 1200 1500 1400 1500 1600 1700 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 3900 1500 3900 5800 3800 3700 5700 ~/5700 3800 / 3600 3300 3500 / 3500 ~ 5500 ii 3400 / 3400 - / 3300 - //5300 3300 - / 3200 - / 3200 3100 //51 O0 I iI I ? 490O I // / I ~ 4700 / 900 I 2700 ~ 4500 2700 I I /I 2600 t // 2800 / ~ 4300 2500 / ///// 2500 ~. 2700 / 100 2400 [ /e 4 2400 2300 // //// 2300 ,' ~oo 2200 /// 2200 2000 2000 O0 200 500 400 500 600 700 800 900 1000 11 O0 1200 1300 1400 1500 1600 1700 East (feet) -> A 3100- I . 3000- - 2900- ,4--, g - ~' 28oo- 3too A I 3000 2900 2800 IPhillips Alaska, Inc.I c,.,.. ,, ..=h For: S Noel 1 I Structure : Tarn Drill Site 2N Well: 303 ~ ..,e~.~. ~ ~v.~ Is. JField : Tarn Development Field Location : Nodh Slope. Alaska ~rO;notel ore ;n I~t relem~e slot i~. ~ I East (feet) -) 300 200 1 O0 0 100 200 ~00 400 500 600 700 800 900 1000 11 O0 1200 1 ~0 2200 ' ~ , , , , ~ ~ i ~ i i i ~ i i ~ i i I ~ , i ~ I I i i i I I L 2200 2100 I . 2000 500 - 2000 1900 1900 1800' 1700 1600 1500 1400, 1300 ,~- 1200 "~ 1100 0 Z 2700 2500 1000 2300 90O 800 700 2100 800 500 4OO 1900 300 iI iI ~ 3500 /I I ii /~ 3300 180o I iI / 1700 /31 O0 2300 // I 6oo I ii ~ 2900' 1500 I i! ii ~./2700 I 2100 ~/2500 / // i/ / // 1000 //I / 900 1900 ;2100 ~. ~ ~.%~..% //! // 800 ~ 1900 // 700 / 1700 // ~/1700 600 iI // 500 / 1500 ~ 1500 i 400 // i0(~//1300 300 2OO 300 200 100 0 100 200 300 400 . 500 . 600 East (feet) -> 200 700 800 900 1000 1100 1200 1300 1400 13oo I Z 0 12oo ~ 11oo ~ ,-I- ( ~;.c. For: B Noel DQte pto~ecl: ore ;n ~t telerate ~t ~, INIZ~ 340 320 300 280 - 260 - 240 - 220 - 200 - 180 A I . 140 - . '~ ~2o- 0 Z lOO Phillips Alaska, Inc. Structure : Torn Drill S;fe 2N Well : ;305 Field : Tern Development Field Locotion : North Slope, Alosko Easf (feel) -> 100 80 60 40 20 0 20 40 60 80 100 120 140 160 180 200 ,,,, iI 1700 IIll iI 1500 // /I 600 1200 /~ 1200 iI 1200 iI iI iI 1100 ~/1100 iI 1100 / i/ / 1000 / 1400 // / 900 ~/900 iI O0 / 80 300 /~ 800 60 1500 /I 700 / j~ 700 40 / ~ 600 20 I 500 ~ 500 400 ~ 400 0 300 ~00 0 20 40 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 60 100 80 60 40 20 0 20 40 60 80 100 120 140 160 180 200 East (feet) -> 340 320 300 280 260 240 220 2OO 180 ~6o I Z 0 14o ~ 120 · 100 Phillips Alaska, Inc. Tarn Drill Site 2N 303 slot #303 Tarn Development Field North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 303 Version #6 Our ref : prop2828 License : Date printed : 16-0ct-2000 Date created : 23-Feb-1998 Last revised : 16-0ct-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 13.970,w150 18 47.265 Slot Grid coordinates are N 5912007.404, E 461093.110 Slot local coordinates are 1.54 N 500.27 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath · PMSS IFR <6234-12026'>,,332,Tarn Drill Site 2N PMSS IFR <0-8684'>,,332PB1,Tarn Drill Site 2N PMSS <10920 - 11225'>,,331,Tarn Drill Site 2N PMSS <0-6043'>,,349,Tarn Drill Site 2N PMSS <2520-6498'>,,349A,Tarn Drill Site 2N PMSS <0-12735'>,,347,Tarn Drill Site 2N PMSS <7387 - 8182'>,,325,Tarn Drill Site 2N PMSS <0-8500'>,,317,Tarn Drill Site 2N PMSS <0-12077'>,,335,Tarn Drill Site 2N PMSS <0-9553'>,,323,Tarn Drill Site 2N PMSS <0-7039'>,,319,Tarn Drill Site 2N PMSS <5303 - 11526'>,,321,Tarn Drill Site 2N PMSS <9235 - 10028'>,,32iA,Tarn Drill Site 2N PMSS <8085-8239'>,,339,Tarn Drill Site 2N PMSS <0-10520'>,,308,Tarn Drill Site 2N PMSS <0-8960'>,,307,Tarn Drill Site 2N PMSS <288-8750'>,,309,Tarn Drill Site 2N PMSS <0-12339'>,,341,Tarn Drill Site 2N PMSS <9483 - 9631'>,,343,Tarn Drill Site 2N PMSS <0-7431'>,,345,Tarn Drill Site 2N PMSS <0-9690'>,,329,Tarn Drill Site 2N PMSS <0-10655'>,,337PB1,Tarn Drill Site 2N PMSS <7090-10245'>,,337,Tarn Drill Site 2N PMSS <0-11456'>,,318,Tarn Drill Site 2N PMSS <266'-l1061'>,,320,Tarn Drill Site 2N PMSS <0-9134'>,,313,Tarn Drill Site 2N PMSS <0-13692'>,,316,Tarn Drill Site 2N PMSS <0-11197'>,,315,Tarn Drill Site 2N ~--~PMSS <0-10334'>,,305,Tarn Drill Site 2N MSS IFR <421-??>,,326,Tarn Drill Site 2N Closest approach with 3-D Minimum Distance method Last revised Distance 3-0ct-2000 435.1 435.1 419.9 689.9 689.9 659.8 330.0 209.9 478.9 300.1 240.0 270 3 270 3 537 0 73 1 59 9 90 0 570 4 599 3 629 9 389 2 509 3 509 3 224 5 253 0 149 9 194 7 179 9 27 5 345 1 3-0ct-2000 10-May-2000 19-Sep-2000 19-Sep-2000 7-Jun-2000 21-Dec-1998 14-Aug-1998 27-0ct-1998 15-Aug-2000 9-0ct-1998 29-Feb-2000 21-Dec-1998 9-0ct-1998 24-Feb-1999 8-Mar-1999 30-Mar-1999 30-Sep-1998 28-Feb-2000 21-Ju1-1998 10-May-2000 27-Jun-2000 27-Jun-2000 1-Sep-2000 9-Feb-1999 4-Aug-1998 10-Aug-2000 18-Jul-2000 9-0ct-2000 15-0ct-2000 M.D. 0.0 0 0.0 0 20.0 20 220.0 220 220.0 220 200.0 200 20.0 20 180.0 180 322.2 322 20.0 20 100.0 100 20.0 20 20.0 20 322.2 322 400.0 400 0.0 0 0.0 0 100.0 100 300.0 300 100.0 100 311.1 311 280.0 280 280.0 280 220.0 220 344.4 344 100.0 100 300.0 300 100.0 100 422.2 6701 100.0 100 Diverging from M.D. 0 0 0 0 0 0 0 0 2 0 0 0 0 2 0 0 0 0 0 0 1 0 0 0 4 0 0 0 0 Phillips Alaska, Inc. Tarn Drill Site 2N 303 slot #303 Tarn Development Field North Slope, Alaska 3-D MINIMUM DISTANCE C LEARANC'E REPORT INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : 303 Version Our ref : prop2828 License : Date printed : 16-0ct-2000 Date created : 23-Feb-1998 Last revised : 16-0ct-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 nT0 10 13.970,w150 18 47.265 Slot Grid coordinates are N 5912007.404, E 461093.110 Slot local coordinates are 1.54 N 500.27 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet Proximities will incorporate ellipses - when survey tools are defined for both wells. Ellipse separation in reverse brackets, e.g. )10.2(, where available. DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* Object wellpath Closest approach with 3-D Minimum Distance method Last revised Distance PMSS IFR <6234-12026'>,,332,Tarn Drill Site 2N PMSS IFR <0-8684'>,,332PB1,Tarn Drill Site 2N FMSS <10920 - 11225'>,,331,Tarn Drill Site 2N PMSS <0-6043'>,,349,Tarn Drill Site 2N PMSS <2520-6498'>,,349A,Tarn Drill Site 2N PMSS <0-12735'>,,347,Tarn Drill Site 2N PMSS <7387 - 8182'>,,325,Tarn Drill Site 2N PMSS <0-8500'>,,317,Tarn Drill Site 2N PMSS <0-12077'>,,335,Tarn Drill Site 2N PMSS <0-9553'>,,323,Tarn Drill Site 2N PMSS <0-7039'>,,3~9,Tarn Drill Site 2N PMSS <5303 - 11526'>,,321,Tarn Drill Site 2N PMSS <9235 - 10028'>,,32iA,Tarn Drill Site 2N PMSS <8085-8239'>,,339,Tarn Drill Site 2N PMSS <0-10520'>,,308,Tarn Drill Site 2N PMSS <0-8960'>,,307,Tarn Drill Site 2N PMSS <288-8750'>,,309,Tarn Drill Site 2N PMSS <0-12339'>,,341,Tarn Drill Site 2N PMSS <9483 - 9631'>,,343,Tarn Drill Site 2N PMSS <0-7431'>,,345,Tarn Drill Site 2N PMSS <0-9690'>,,329,Tarn Drill Site 2N PMSS <0-10655'>,,337PB1,Tarn Drill Site 2N PMSS <7090-10245'>,,337,Tarn Drill Site 2N PMSS <0-11456'>,,318,Tarn Drill Site 2N PMSS <266'-11061'>,,320,Tarn Drill Site 2N PMSS <0-9134'>,,313,Tarn Drill Site 2N PMSS <0-13692'>,,316,Tarn Drill Site 2N PMSS <0-11197'>,,315,Tarn Drill Site 2N 314 v7.c,,314,Tarn Drill Site 2N 322 Version %37,,322,Tarn Drill Site 2N PMSS <0-10334'>,,305,Tarn Drill Site 2N 326 Version %4,,326,Tarn Drill Site 2N PMSS IFR <421-??>,,326,Tarn Drill Site 2N 3-0ct-2000 3-0ct-2000 10-May-2000 19-Sep-2000 19-Sep-2000 7-Jun-2000 21-Dec-1998 14-Aug-1998 27-0ct-1998 15-Aug-2000 9-0ct-1998 29-Feb-2000 21-Dec-1998 9-0ct-1998 24-Feb-1999 8-Mar-1999 30-Mar-1999 30-Sep-1998 28-Feb-2000 21-Ju1-1998 10-May-2000 27-Jun-2000 27-Jun-2000 1-Sep-2000 9-Feb-1999 4-Aug-1998 10-Aug-2000 18-Jul-2000 4-0ct-2000 12-0ct-2000 9-0ct-2000 2-0ct-2000 15-0ct-2000 .)434.8 )434.8 )419.0 )688.6 )688.6 )658.5 )329.8 )208.6 )477.2 )299.6 )239.1 )269.9 )269.9 )534.7 )70.8 )59.3 )89.1 569.7 597.2 628.7 387.5 507.8 507.8 222.7 )250.6 )148.9 )193.2 )179.1 )163.2 )283.7 )25.1 )343.2 )344.0 M.D. 8O 0 80 0 220 0 280 0 280 0 280 0 5O 0 311 1 333 3 180 0 240 0 100 0 100 0 333 3 422 2 220 0 311 1 140 0 322 2 311 1 333 3 311 1 311 1 260 0 355 6 220 0 300 0 220 0 280 0 160 0 450 0 260 0 240 0 Diverging from M.D. 80.0 80.0 220.0 280.0 280.0 7040.0 50.0 311.1 333.3 180.0 300.0 100.0 100.0 333.3 422.2 220.0 311.1 300.0 322.2 311.1 6100.0 311.1 311.1 260.0 7060.0 220.0 300.0 220.0 280.0 160.0 450.0 260.0 240.0 Phillips Alaska, Inc. Tarn Drill Site 2N 303 slot #303 Tarn Development Field North Slope, Alaska PROPOSAL LISTING Baker Hughes INTEQ Your ref : 303 Version #6 Our ref : prop2828 License : Date printed : 16-0ct-2000 Date created : 23-Feb-1998 Last revised : 16-0ct-2000 Field is centred on n70 12 49.742,w150 18 33.414 Structure is centred on nT0 10 13.955,w150 18 32.772 Slot location is n70 10 13.970,w150 18 47.265 Slot Grid coordinates are N 5912007.404, E 461093.110 Slot local coordinates are 1.54 N 500.27 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Phillips Alaska, Inc. Tarn Drill Site 2N,303 Tarn Development Field,North Slope, Ala~'~ Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth 0.00 0.00 19.22 0.00 0.00 300.00 0.00 19.22 300.00 0.00 400.00 3.00 19.22 399.95 2.47 500.00 6.00 19.22 499.63 9.88 600.00 9.00 19.22 598.77 22.20 700.00 12.00 19.22 697.08 39.41 800.00 15.00 19.22 794.31 61.45 900.00 18.00 19.22 890.18 88.27 1000.00 21.00 19.22 984.43 119.78 1016.70 21.50 19.22 1000.00 125.50 1100.00 24.00 19.22 1076.81 155.91 1200.00 27.00 19.22 1167.06 196.56 1241.70 28.25 19.22 1204.00 214.82 1293.16 29.79 19.22 1249.00 238.39 1300.00 30.00 19.22 1254.93 241.61 1400.00 33.00 19.22 1340.18 290.94 1500.00 36.00 19.22 1422.59 344.42 1600.00 39.00 19.22 1501.91 401.90 1602.48 39.07 19.22 1503.84 403.38 2000.00 39.07 19.22 1812.45 639.98 2137.26 39.07 19.22 1919.00 721.67 2500.00 39.07 19.22 2200.61 937.58 2628.03 39.07 19.22 2300.00 1013.78 2889.52 39.07 19.22 2503.00 1169.42 2897.24 39.07 19.22 2509.00 1174.02 3000.00 39.07 19.22 2588.77 1235.18 3500.00 39.07 19.22 2976.94 1532.78 4000.00 39.07 19.22 3365.10 1830.38 4500.00 39.07 19.22 3753.26 2127.98 4634.91 39.07 19.22 3858.00 2208.28 4933.76 39.07 19.22 4090.00 2386.15 5000.00 39.07 19.22 4141.43 2425.58 5182.36 39.07 19.22 4283.00 2534.12 5500.00 39.07 19.22 4529.59 2723.18 5697.61 39.07 19.22 4683.00 2840.80 5959.10 39.07 19.22 4886.00 2996.43 6000.00 39.07 19.22 4917.75 3020.78 6395.77 39.07 19.22 5225.00 3256.34 6493.67 39.07 19.22 5301.00 3314.61 6500.00 39.07 19.22 5305.92 3318.38 6596.72 39.07 19.22 5381.00 3375.94 6701.05 39.07 19.22 5462.00 3438.04 6779.63 39.07 19.22 5523.00 3484.81 7000.00 39.07 19.22 5694.08 3615.98 7079.63 39.07 19.22 5755.90 3663.37 RECTANGULAR COORDINATES PROPOSAL LISTING Page 1 Your ref : 303 Version #6 · Last revised : 16-0c~ %0 Dogleg Vert Deg/100ft Sect 0.00 E 0.00 0.00 0.00 E 0.00 0.00 KOP 0.86 E 3.00 2.62 3.44 E 3.00 10.46 7.74 E 3.00 23.51 13.74 E 21.42 E 30.77 E 41.76 E 43.75 E 54.35 E 68.52 E 74.89 E 83.11 E 84.23 E 101.43 E 120.07 E 140.11 E 140.62 E 223.10 E 58 E 85 E 41 E 67 E 27 E 251. 326. 353. 407. 409. 430.60 E 534.34 E 638.09 E 741.84 E 769.83 E .84 E .58 E .42 E .33 E .33 E 831 845 883 949 990 .59 E .08 E .19 E .51 E .82 E 1044 1053 1135 1155 1156 .89 E .54 E .84 E .57 E .09 E 1176 1198 1214 1260 1277 3.00 41.74 3.00 65.08 3.00 93.48 3.00 126.85 3.00 132.91 Port Collar 3.00 165.12 3.00 208.16 3.00 227.50 Base Permafrost 3.00 252.46 Top W Sak 3.00 255.87 3.00 308.12 3.00 364.75 3.00 425.62 3.00 427.18 EOC 0.00 677.75 0.00 764.27 Base W Sak 0.00 992.92 0.00 1073.62 7 5/8 Casing 0.00 1238.44 C80 0.00 1243.31 Camp SS 0.00 1308.08 0.00 1623.25 0.00 1938.41 0.00 2253.58 0.00 2338.62 C50 0.00 2526.99 C40 0.00 2568.74 0.00 2683.69 C37 0.00 2883.91 0.00 3008.47 Iceberg 0.00 3173.29 T7 0.00 3199.07 0.00 3448.54 T3.1 0.00 3510.25 T3 0.00 3514.24 0.00 3575.20 Old 305 Rvsd 24-Aug-00 0.00 3640.97 T2 0.00 3690.50 C35 0.00 3829.40 0.00 3879.60 TD - Casing Pt '; '~. l:] 9 ,',;i".' t',~.,'i ,',,. 0 U.~.,' .... · '.i.#'..':~'i.i~.:,!~.....,... ,,., ...,.....,... .............. "~:':" :'" '~'"?""" :' ':,'. '4', ............ ~" ''':!;1:7'f''~'''1:~' .... '~: '%. Ail data is in feet unless otherwise stated. Coordinates from slot 9303 and TVD from RKB (Nabors 19E) (154.00 Ft above mean sea level). Bottom hole distance is 3879.60 on azimuth 19.22 degrees from wellhead. Total Dogleg for wellpath is 39.07 degrees. Vertical section is from wellhead on azimuth 19.22 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. PROPOSAL LISTING Page 2 Tarn Drill Site 2N,303 Your ref : 303 Version #6 . Tarn Development Field,North Slope, Ala~ Last revised : 16-0c~ '0 · Comments in wellpath MD TVD Rectangular Coords. Comment 300.00 1016.70 1241.70 1293.16 1602.48 2137.26 2628.03 2889.52 2897.24 4634.91 4933.76 5182.36 5697.61 5959 10 6395 77 6493 67 6596 72 6701 05 6779 63 7079 63 300.00 1000.00 1204.00 1249.00 1503.84 1919.00 2300.00 2503.00 2509.00 3858.00 4090.00 4283.00 4683.00 4886.00 5225.00 5301.00 5381.00 5462.00 5523.00 5755.90 0.00 125.50 214.82 238.39 403.38 721.67 1013.78 1169.42 1174 02 2208 28 2386 15 2534 12 2840 80 2996 43 3256 34 3314 61 3375 94 3438 04 3484.81 3663.37 N 0.00 E KOP N 43.75 E Port Collar N 74.89 E Base Permafrost N 83.11 E Top W Sak N 140.62 EEOC N 251.58 B Base W Sak N 353.41 E 7 5/8 Casing N 407.67 E C80 N 409.27 E Camp SS N 769.83 E C50 N 831.84 E C40 N 883.42 E C37 N 990.33 E Iceberg N 1044.59 E T7 N 1135.19 E T3.1 N 1155.51 E T3 N 1176.89 E Old 305 Rvsd 24-Aug-00 N 1198.54 E T2 N 1214.84 E C35 N 1277.09 E TD - Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 2628.03 2300.00 1013.78N 353.41E 7 5/8 Casing 0.00 0.00 0.00N 0.00E 7079.63 5755.90 3663.37N 1277.09E 5 1/2 Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised Old 305 Rvsd 24-Aug- 462287.000,5915377.000,0.0000 5381.00 3375.94N 1176.89E 25-Feb-2000 Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 October 18, 2000 Daniel T. Seamount, Jr., Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill KRU 2N-303 Surface Location: 1' FSL 500' FEL Sec. 34, T10N RTE, UM or ASP4, NAD 27 coordinates of X=461,093 & Y=5,912,007 Target Location: 1903' FNL, 681' FWL'Sec. 35, T10N, R7E, UM Bottom Hole Location: 1616' FNL, 782' FWL Sec. 35, T10N, R7E, UM Dear Commissioner Seamount, Phillips Alaska, Inc. hereby files this Application for Permit to Drill the development well KRU 2N-303. Nabors Rig 19e will drill the well. Please utilize documents on file for this rig. Subject to AOGCC approval, fluids and cuttings generated from drilling the well will be pumped down an approved and existing annulus on Drillsite 2N, or hauled to an approved Prudhoe or GKA Class II disposal well. This well will be a producer in the Tarn formation. Though all operations will be monitored for H2S, there has not been any H2S encountered on this pad. Phillips Alaska, Inc. requests an exemption from the H2S requirements. 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 Bill Morris, Geologist 263-4588 (20 AAC 25.071) If you have questions or require additional information, please contact Brian Noel at 265- 6979 or me at 265-6434 in our Anchorage office. Sincerely, James Trantham Drilling Engineering Supervisor Attachments: Information as required cc: KRU 2N-303 Well File Phillips Alaska, Inc. is a Subsidiary of Phillips 66 Tarn Area Information Subject: Tarn Area Information Date: Tue, 24 Oct 2000 12:29:13 -0800 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: Brian Noel <bnoel@ppco.com> CC: Bob Crandall <bob_crandall@admin.state.ak. us> Brian, Good to talk with you. As I indicated in the call, our Sr. Geologist Bob Crandall is interested in additional information regarding the possible gas migration comments made in the Drilling Area Risks section of the permit attachments. We have seen this statement in other plans and are interested in the results of the investigation program. You mention that the logs, tracer-surveys, pump-in tests and offset BHPBUs do not indicate any migration outside the wellbore interval. You indicated that a reservoir presentation on the subject has been made, however you do not know if a formal report has been prepared. Please get back to either myself or Bob with regard to this request. Please note, I will be out of town all next week. Thanks. Tom Maunder Petroleum Engineer. ITom Maunder <tom maunder~,admin.state.ak, us> P---~rol~oel' ..... ~,as.ka..0`' .and.. G.aS...C0.n.servat!0.n...C0mmis, ,~,iOn 10/24/0012:52 PM 1 of 1 WELL PERMIT CHECKLIST FIELD & POOL y'~O/~,:5'- ADMINISTRATION IIAPP_R DATE .~ io , z ~J,~ . . COMPANY"~'~'"~/(/,~ WELL NAME ,Z,,%/'-.,~ PROGRAM: exp CLASS ENGINEERING 1. Permit fee attached .......... ,, .............. 2. Lease number appropriatelY..5~-. ~: .~.'~. / .'~." .{~./.'.. 3. Unique well name and.number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellborn plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... 14. Conductor string provided ............ ' ....... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long' string to surf csg .... ; . . . 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ ann. disposal para req dev v/ redrll serv wellbore seg GEOL AREA ,~~ UNIT#. C) ///~, E) -- ON/OFF SHORE N DATE /o,~,?, ,~o 26. BOPE press rating appropriate; test to ~.~---'-~(~3 Dsig. 27. Choke manifold complies w/APl RP-53 (May 84).... ..... 28. Work will occur without operation shutdown ........... 29. Is presence of H2S gas probable ................. Permit can be issued wlo hydrogen sulfide measures ..... (~)~ 30.31. Data presented on potential overpressure zones ....... ,,~ ~ 32. Seismic analysis of shallow gas zones .......... '. '.. ~ Y N , ' ' ~ ~': ' ~' '" v~. ~ ..... re P Y N 33. Seabed ~ndition su~ey (if off-sho ) ....... ' .... / ' · 34. Conta~ name/phone for weekly progress repo~s [~p~o~ only] Y N ' ' ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; ....... Y N APPR DATE Y N GEOLOGY: (B) will not contaminate freshwater; or cause drilling waste... to surface; .(C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. ENGINEERING: UICIAnnular COMMISSION: Y N Y N Y N Comments/instructions: m z c:~soffice\wordian~iana~checklist (rev. 02117100) ,. 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 {he roadability of the Well History file and to simp!ify finding information, informati~)n of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Wed Oct 03 14:38:31 2001 Reel Header Service name ............. LISTPE Date ..................... 01/10/03 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 01/10/03 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Unit (Tarn Pool) MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 2 AK-MM-00247 B. HENNINGSE D. GLADDEN 2N-303 501032035200 Phillips Alaska Inc. Sperry-Sun Drilling Services 03-OCT-01 MWD RUN 3 AK-MM-00247 B. HENNINGSE D. GLADDEN 34 i0N 7E 1 500 156.11 154.78 120.20 IST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 16.000 115.0 6.750 7.625 2637.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY AND IS NOT PRESENTED. 4. MWD RUNS 2 & 3 WERE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND STABILIZED LITHO-DENSITY (SLD). 5. DATA FROM 3661'MD/3097'TVD TO 3783'MD/3194'TVD (BIT DEPTHS) WERE ACQUIRED WHILE RIH FOR RUN 3. 6. MWD DATA ARE CONSIDERED PDC PER E-MAIL FROM D. SCHWARTZ, PHILLIPS ALASKA, DATED 1/30/01. 7. MWD RUNS 2 & 3 REPRESENT WELL 2N-303 WITH API~:50-103-20352-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 7057'MD / 5744.34'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: MUD WEIGHT: MUD FILTRATE SALINITY: 6.75" 9.6 ppg 350-500 ppm chlorides FORMATION WATER SALINITY: FLUID DENSITY: MATRIX DENSITY: LITHOLOGY: $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/03 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 19,149 ppm chlorides 1.0 g/cm3 2.65 g/cm3 SANDSTONE 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 START DEPTH STOP DEPTH NCNT 2556.5 6964.5 NPHI 2557.5 6964.5 FCNT 2557.5 6965.0 PEF 2572.5 6980.5 GR 2593.0 7002.0 RPX 2599.0 7009.0 RPS 2599.0 7009.0 RPM 2599.0 7009.0 RPD 2599.0 7009.0 FET 2599.0 7009.0 RHOB 2634.5 6980.5 DRHO 2634.5 6980.5 ROP 2645.5 7056.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD $ REMARKS: EQUIVALENT UNSHIFTED DEPTH Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined MERGED MAIN PASS. $ BIT RUN NO MERGE TOP MERGE BASE 2 2556.5 3787.0 3 3787.0 7056.5 Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type,,,0 Name DEPT ROP GR RPX RPS RPM RPD FET NPHI FCNT NCNT RHOB DRHO PEF Service Order Units Size Nsam Rep FT 4 1 68 MWD FT/H 4 1 68 MWD API 4 1 68 MWD OHMM 4 1 68 MWD OHMM 4 1 68 MWD OHMM 4 1 68 MWD OHMM 4 1 68 MWD HOUR 4 1 68 MWD PU-S 4 1 68 MWD CNTS 4 1 68 MWD CNTS 4 1 68 MWD G/CM 4 1 68 MWD G/CM 4 1 68 MWD BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Service Unit Min Max DEPT FT 2556,5 7056,5 ROP MWD FT/H 0 222,26 GR MWD API 42,27 222,88 RPX MWD OHMM 1,05 2000 RPS MWD OHMM 1,07 1.625,78 RPM MWD OHMM 1,08 2000 RPD MWD OHMM 1,2 2000 FET MWD HOUR 0,4698 209,065 NPHI MWD PU-S 8,38 67,03 FCNT MWD CNTS 89,6 1308.5 NCNT MWD CNTS 12816,9 35974.8 RHOB MWD G/CM 1,902 3,132 DRHO MWD G/CM -0,085 0,746 PEF MWD BARN 1,79 13,94 Mean 4806,5 94,8268 125,522 4,50204 4,48294 12,9889 16.1575 4,94224 35,4435 264,262 19794,1 2,33149 0,0633439 3,64369 Nsam 9001 8823 8819 8821 8821 8821 8821 8821 8815 8816 8817 8693 8693 8817 First Reading 2556,5 2645,5 2593 2599 2599 2599 2599 2599 2557.5 2557.5 2556,5 2634,5 2634,5 2572,5 Last Reading 7056,5 7056,5 7002 7009 7009 7009 7009 7009 6964,5 6965 6964.5 6980.5 6980,5 6980,5 First Reading For Entire File .......... 2556,5 Last Reading For Entire File ........... 7056,5 File Trailer Service name ............. STSLIB,001 Service Sub Level Name,,, Version Number ........... 1,0,0 Date of Generation ....... 01/10/03 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 ....... 01/10/03 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NCNT 2556.5 3696.5 FCNT 2557.5 3696.5 NPHI 2557.5 3696.5 PEF 2572.5 3712.5 GR 2593.0 3733.0 RPD 2599.0 3741.0 FET 2599.0 3741.0 RPM 2599.0 3741.0 RPS 2599.0 3741.0 RPX 2599.0 3741.0 DRHO 2634.5 3712.5 RHOB 2634.5 3712.5 ROP 2645.5 3787.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 SLD STABILIZED LITHO DEN CTN COMP THERMAL NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: 10-NOV-00 Insite 4.15 Memory 3787.0 2645.0 3787.0 37.6 39.1 TOOL NUMBER PB01686WNL4 PB01686WNL4 PB01686WNL4 PB01686WNL4 6.750 LSND 9.60 44.0 9.5 MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 400 5.8 2.630 1.880 2.510 1. 980 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 N?HI MWD020 ?U-S 4 1 68 32 9 FCNT MWD020 CNTS 4 1 68 36 10 NCNT MWD020 CNTS 4 1 68 40 11 RHOB MWD020 G/CM 4 1 68 44 12 DRHO MWD020 G/CM 4 1 68 48 13 PEF MWD020 BARN 4 1 68 52 14 68.0 97.9 68.0 68.0 Name Service Unit DEPT FT ROP MWD020 FT/H GR MWD020 API RPX MWD020 OHMM RPS MWD020 OHMM RPM MWD020 OHMM RPD MWD020 OHMM FET MWD020 HOUR NpHI MWD020 PU-S FCNT MWD020 CNTS Min Max Mean Nsam 2556.5 3787 3171.75 2462 0 222.26 108.611 2284 58.4 184.52 119.035 2281 1.92 2000 6.33692 2285 2.04 1625.78 6.24677 2285 1.94 2000 39.156 2285 2.02 2000 50.9288 2285 0.4698 209.065 14.4692 2285 14.91 67.03 40.8658 2279 89.6 583.3 189.889 2279 First Reading 2556.5 2645.5 2593 2599 2599 2599 2599 2599 2557.5 2557.5 Last Reading 3787 3787 3733 3741 3741 3741 3741 3741 3696.5 3696.5 NCNT MWD020 CNTS RHOB MWD020 G/CM DRHO MWD020 G/CM PEF MWD020 BARN 12816.9 26400.5 1.902 2.48 -0.085 0.202 2.64 13.94 17246.4 2281 2.17753 2157 0.0517251 2157 4.90926 2281 2556.5 2634.5 2634.5 2572.5 3696.5 3712.5 3712.5 3712.5 First Reading For Entire File .......... 2556.5 Last Reading For Entire File ........... 3787 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/03 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/03 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 NPHI FCNT NCNT PEF RHOB DRHO RPM RPS RPD FET RPX ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 3697.0 3697.0 3697.0 3713.0 3713.0 3713.0 3733.5 3741.5 3741.5 3741.5 3741.5 3741.5 3787.5 SURFACE SOFTWARE VERSION: STOP DEPTH 6964.5 6965.0 6964.5 6980.5 6980.5 6980.5 7002.0 7009.0 7009.0 7009.0 7009.0 7009.0 7056.5 15-NOV-00 Insite DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 SLD STABILIZED LITHO DEN CTN COMP THERMAL NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): RE~ARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 4.15 Memory 7057.0 3787.0 7057.0 36.3 41.4 TOOL NUMBER PB01725WNL4 PB01725WNL4 PB01725WNL4 PB01725WNL4 6.750 LSND 9.60 44.0 9.0 35O 3.8 2.800 1.450 3.000 2.800 67.0 135.3 67.0 67.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 '0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 RPX MWD030 RPS MWD030 RPM MWD030 RPD MWD030 FET MWD030 N?HI MWD030 FCNT MWD030 NCNT MWD030 RHOB MWD030 DRHO MWD030 PEF MWD030 API 4 1 68 OHMM 4 1 68 OHMM 4 1 68 OHMM 4 1 68 OHMM 4 1 68 HOUR 4 1 68 PU-S 4 1 68 CNTS 4 1 68 CNTS 4 1 68 G/CM 4 1 68 G/CM 4 1 68 BARN 4 1 68 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Service Unit DEPT FT ROP MWD030 FT/H GR MWD030 API RPX MWD030 OHMM RPS MWD030 OHMM RPM MWD030 OHMM RPD MWD030 OHMM FET MWD030 HOUR N?HI MWD030 PU-S FCNT MWD030 CNTS NCNT MWD030 CNTS RHOB MWD030 G/CM DRHO MWD030 G/CM PEF MWD030 BARN Min Max 3697 7056.5 0 176.54 42.27 222.88 1.05 59.61 1.07 54.88 1.08 46.25 1.2 40.93 0.5704 43.0968 8.38 53.66 142.5 1308.5 16377.5 35974.8 2.006 3.132 -0.045 0.746 1.79 7.45 Mean Nsam 5376.75 6720 90.0122 6539 127.785 6538 3.86056 6536 3.8663 6536 3.84088 6536 4.00146 6536 1.61161 6536 33.5528 6536 290.19 6537 20683.2 6536 2.3823 6536 0.0671784 6536 3.20201 6536 First Reading 3697 3787.5 3733.5 3741.5 3741.5 3741.5 3741.5 3741.5 3697 3697 3697 3713 3713 3713 Last Reading 7056.5 7056.5 7002 7009 7009 7009 7009 7009 6964.5 6965 6964.5 6980.5 6980.5 6980.5 First Reading For Entire File .......... 3697 Last Reading For Entire File ........... 7056.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/10/03 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 01/10/03 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 01/10/03 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File