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206-177
{i`fL 3/f/z-d g13DMSI4-(hEC 2 b 2019 Form 10-404 Revised 4/2017 Submit Original Only STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Rednll ❑ Perforate New Pool ❑ Repair -Well ❑ Re-enter Susp Well ❑ WINJ t0 WAG ❑r 2. Operator Well Class Before Work: 5. Permit to Drill Number: CPhilliAlkInc.. Name: onocops asa, nc. Development ❑ Stratigraphic ❑ Exploratory ❑ Service 0 206-177 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50029233376000 7. Property Designation (Lease Number): 8. Well Name and Number: KRU U-1181-1 ADL 25661, 25650 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): NA 10. Field/Pool(a) Ku aruk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 14,788 feet Plugs measured None feet true vertical 3,802 feet Junk measured None feet Effective Depth measured 14,754 feet Packer measured 7,146 feet true vertical 3,801 feet true vertical 3,595 feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 108' 108' Surface 3,327' 10.75" 3,358' 2,218' Production 8,922' 7.625" 8,949' 3,868' Liner 6,827' 4.5" 14,788' 3,802' Tubing (size, grade, measured and true vertical depth) 4.5 " L-80 7,190' MD 3,604' TVD Packers and SSSV (type, measured and true vertical depth) Packer: Baker SXP Liner Top Packer 7,146' MD 3,595' TVD SSSV TYPE: NA NA NA 12. Stimulation or cement squeeze summary: Intervals treated (measured): NA Treatment descriptions including volumes used and final pressure: NA 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 1900 psi 1300 psi 500 psi Subsequent to operation: 0 1000 Mscid 0 700 psi 1450 psi 14. Attachments (requinxi per 20 PAC 25.070, 25D71, 8 25.283) 15, Well Class after work: Daily Report of Well Operations ❑' Exploratory ❑ Development ❑ Service ❑� Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑� GINJ ❑ SUSP ❑ $PLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/Aif C.O. Exempt: 3f 9-429 Contact Name: Sydney Autry Authorized Name: Sydney Autry Contact Email: sydney.autry@cop.com Authorized Title: Senior Petroleum Engineer - - L� 2414 Contact Phone: 907-265-6813 Authorized Signature -''� Date: {i`fL 3/f/z-d g13DMSI4-(hEC 2 b 2019 Form 10-404 Revised 4/2017 Submit Original Only 1J-1181-1 DESCRIPTION OF WORK COMPLETED SUMMARY 11126119 A--\ KI1P INJ WELLNAME U-118 WELLBORE 1J-118 KUP INJ WELLNAME U-118 WELLBORE 1J -118L1 Well Attributes Max Angle & MD TD /�� ��' •''"'im� Alaska. Inc Fleltl Name WeI1Wre - PPVUWI WellEore status Icll°I MOIXNB %ciBM (XN91 272 13.302.13 14,795.0 Commen X3SIppm1 Oah /lnnolalbn SSSV.NIPFLE Last WO. End Dale N6GNHX R'q flea.[¢Dale 32.29 31202007 "."a" p/1.L.3721 FM I Last Tag .., xnmuti[I.) I Annotation Deena MKS) Ene wen vMa4ol. -Snood Dv - Last Tag iJ-111511 ImOSDO( RA"GER' 22.a Last Rev Reason Amlotaton EM Bate WpDen1e Leal Mod ev Rev Reason: SHOW PERF SECTIONS 5/162013 1J-11811 osbprl M CONOULTOR; Aa iva.0 NIFPLE sols Casing Strings WSLIFT', 3.tYa.1 I 4 Caslnp "lipOo 6n1 B-Santl S'Lned LINER 412 IB llnl Top 1X1(81 6e1 BepN1XRa) 348 ],9614 14,]8Z] .I.tM INB1... WULan 11... GrWe Top TMead 3,8024 11.60 Lb BTC Liner Details SURFACE:3 S-5Lsd a GAS LIFT; 6.007.6 Npmina110 SLEEVE. 11113a LO TOa,)1B2o Top MKBl TopIND11XXa1 Tepin[I (°I Ilan Oen Com Unl 7.9610 3.]06.3 8926 SLEEVE BAKER HR LINER SETTMG SLEEVE 5.010 ..ASS, .veL7 ],9]62 3,)06.6 8894 NIPPLE "RS"PackOH Seal Nippe.6 DT OD 14.8]"p 4.879 7.9776 3,]06.6 88.91 HANGER 5.5"%]63""FIA,.Lol, Liner H9O6.WODI4.8YID 4.850 Owlx. ?'x24)217. ),9813 3.]06 ] 88.83 SBE i90A7 Seal Bore ErL 629" OD I a ]5" ID 4]50 Perforations & Slots sent D na DLNERLEMI 714AS-7,WO rop028 elm tmcal ToplrvDl IXxal Blmlrv0l Olkal unkeemne Bele lalwum 1 T1.TS Goon 8,028.0 87]2.0 370]7 382.9 W58. 1J-11811 742007 320 SLOTS 'N WELLBOREI Unduutmg Alternating SoleYSINaed pipe - 0.125W.5" @ 4 D LINER Hn:?mT&7a O a rcurnfvernin.djacas 1 mops, 3' centers staggered 18 deg, 3' non-slaMd ends e Lm9a nn:95W.4?)az.) 7:1b.)-0.819.0 8.9]2.0 3.]34.0 WS B. 1J-11811 3M209 320 SLOTS IMERMEDIK a WINDOW: ].)�0].T)60 DOnERLEM,).9Q27eb2 9.681.0 19,138.0 T737.8 3.745.2 WS B. 1J-11811 74200) 320 SLOTS 10,394.0 10,85]0 3.]4].1 3.]59.6 WS e. 1J-118Li 3142007 32.0 SLOTS 1T1060 11564.0 3.]59.] 3,756.7 WSB, iJ-11811 3142007 MID SLOTS 178180 122790 3.79.9 3,763.3 WSB.iJ711811 741200] 32.0 BLOTS cors 12,5200 72.966.0 3.766.2 8]77.1 WS -8-1J-1 1811 3/42007 320 SLOTS - - 18202.0 13,654.0 3,7/9.5 3.7)].5 WS B. iJ-118111 Y4I2007 320 SLOTS 13,882.0 14,34].0 3.]85.5 3,]9].2 WS B, 1J-11811 3/4200] 320 SLOTS - 14-5880 14754.0 3.800.0 3,801.6 WS B. 1J -t 1811 7412097 32.0 SLOTS SLDTa,6.Tse37O-� - - Notes: General & Safety End Date I Annoblion 8121(ctl08 NOTE'. VIEW SCHEMATIC w/Alaska Sctlematic9.0 - 3202007 NOTE:MULTI-LATERAL WELL-1J-118(A-SAND),IJ-118L11&SAND), IJ -1181219 -SAND) SLOTS, RPH101d 1W. - FLATS. 1.,. 6Iaw a- 9LOTa:11106611.0l 61073: 11,8180.12290 ALOT6: 12.S x 013.78. 0----- SLOTS. 13. M.013.6 D0� SLOTS: 13,078$611.31] O� SLOTS. &Se ..1-INER; S614`J a) THE STATE ALASKA GOVERNOR MIKE DUNLEAVY Sydney Autry Senior Production Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1J -118L1 Permit to Drill Number: 206-177 Sundry Number: 319-429 Dear Ms. Autry: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the 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, Jeremy 4ice Chair DATED this ! day of October, 2019. RBDMS OCT 10 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 9n AAr` 0G oon SLP � C '21C19 1. Type of Request: Abandon LJ Plug Perforations 0 Fracture Stimulate Li Repair Well LJ Operations shutdown LJ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ WINJ to WAG Other: ❑� 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: . ConocoPhilli s Alaska Inc. Exploratory ❑ Development ❑ Stratigraphic ❑ Service Q 206-177 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50029233376000 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No ❑ 1 J -118L 1 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25661, 25650 Kuparuk River Field / West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 14,788' 3,802' 14,754' 3,801' 1897 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 108 108' Surface 3,327' 10.75" 3,358' 2,218' Intermediate x x x x Production 8,922' 7.625" 8,949' 3,868' Liner 6,827' 4.5" 14,788' 3,802' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Slotted liner: 8028' -14754' 3708'- 3801' 4.5" L-80 7,190' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): No SSSV, Baker SXP Liner Top Packer Packer: 7146 MD, 3,595' TVD 12. Attachments: Proposal Summary O Wellbore schematic O 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service ❑� 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1-01 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Sydney Autry Sydney Autry Contact Name: Authorized Title: Senior Production Engineer Contact Email: sydney.autry@cop.com Contact Phone: 907-265-6813 Authorized Signature: Date: 6/ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: n I J H 2— ^l /J ( Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance El Other: 4-7-0 Post Initial Injection MIT Req'd? Yes ❑ No m-� AB®MS1-'-1OCT 10 2019 Spacing Exception Required? Yes ❑ No Subsequent Form Required: 40L� APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: °1 of\1',VI ,� <, NAI. Form q"rae:ed a o I Approved application is valid for 12 months from the date of approval. Submit Form and Attachments in Duplicate rJ*'a 422/14 1J -118L1 Sundry Proposal ConocoPhillips Alaska Inc. requests approval to convert West Sak Well 1J-1181-1 (PTD# 206-177) from Water Injection service to Water Alternating Gas Injection service. Area of Review: West Sak well 1J -118L1 was completed as an injector on 3/19/2007 to provide injection support into the reservoir to increase the ultimate recovery of oil. This well supports existing producers 1J-115 and 1J-120. The top of the Ugnu C sand was found at 5,474' MD / 3,026' TVD The top of the Ugnu B sand was found at 5,908' MD / 3,191' TVD The top of the Ugnu A sand was found at 6,327' MD / 3,345' TVD The top of the West Sak D sand was found at 7,207' MD / 3,606' TVD Area Map with 1/< mile radius around target injection zone (see attached): The map attached shows that, in addition to the offset supported producers (1J-115 and 1J-120), there are two Kuparuk wells (1D-36 and 1J-03) and five West Sak wells (1D-102, 1D-138, 1D-141, 1D -141A, and 1J- 107) that have penetrations in the West Sak interval located within a 1/4 mile radius of the 1J-1181-1 penetrations of the West Sak interval. Mechanical Condition of Well to be Converted: The mechanical condition of West Sak injector 1J-1181-1 is good. The injection tubing/casing annulus is isolated via a Baker ZXP liner top packer located at 7,146' MD (3,595' TVD). The last state -witnessed MITIA was performed on May 9, 2018 to 2000 psi. CBL and interpretation of the cement quality: See attached AOR detail for 1J-118 (identical for U-1 & 1J-11812) and offset well condition. Conditions for approval (if applicable): ADL025651 ADLO25650 �f - ADL028243 a 0 0 o N ll� N r O 00 N N M J r � � r N r O r ADLO28248 Well Pad ADL025661 t�-03 — Well Trajectory 1J -118L1, Open Interval �, o Q1J-1181.1 01 Quartermile Buffer — West Sak Well 0 West Sak Well WS Interval G 'i- West Sak Base in non -West Sak Wells — Non -West Sak Well I West Sak PA 1 I— CPAI Leases - ConocoPhillips o r Alaska 0 1J -118L1 Injection Sundry N 0 0.2 0.4 0.6 ADL: 12/5/2017 Miles � - s P s_eog IET n`3mo 3u-.% V- e o'sa g 5 ywaap3 eao i:o5 a H Rq' is .a3 o$� y $Wo'$3�3 39v5y 0A3 �$eTc ip_n 3ooe �a3'S-$n73 -n# $^i� ^ 5 9Z:Bi �x�„.#eA �. '.43i^ •off R.3R $w m8 £m�� ^eC ^� nn - 3�SG ntn e g cRgsA l A83'24 -mg Pem 8$a �'J^A%a19 G C ldn SSM 3qC 5 'd J 3 g'd-'� '3 3 3 y sf 12 +ate oc U=aWWQ 'o cu �... �_ .�y1:5 i mm u cF Lu O0 J eqsi__ m- @off i yy Yy soe m �x X.2 oeot Y a c 5 ay mti 5 ._m egoo �m a Q W gs hm y�5 om m R Z in o =_9 d = �o sm 33H a � m� _„ # a rc l a_ Y n Qm r C H LL m e = - WJ m Y mm o w'a V) 0 C y v Ey v Um A t" O u •C co C c'a C j� _m s �.mi li U) r :.i?m p � , r f6 'a O Y N C f.. tem - on a m oo z 'a u C L 9 �9i mm asm 'a a" 3E 9 p y y J £en m� N S r o mn 06a s m: r�F U C f y .00 n m £ S E 4 u ca M1 Sg� m v N3 _ m � "• � �\ ma m � s e n 3 o m°; ®S• E N m m^ Ep d_ S y�Yyp aF xw � C._ u �a 3U o0 }` o wG O M1'¢ w pCo C Ea •p AN p Qi: W �a Em� rno �Jx —s J r Mpw tiN Loepp, Victoria T (CED) From: Autry, Sydney <Sydney.Autry@conocophillips.com> Sent: Thursday, October 3, 2019 3:16 PM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]West Sak wells: Conversion from WI to WAG 1J-118, 1J-176 Victoria, Regarding your note below, the AIO allowing WAG injection at West Sak is AIO 2B (Conservation Order 406). For well 1J-176, there are no offset Kuparuk wells are two Kuparuk wells in the AOR (1J-03 & 1D-36). • 1D-36 4 Surface casing is set at 7,047' MD below the top of the West Sak D sd) • 1J-03 4 Surface casing is set at 7,784' MD below the top of the West Sak D sd) in the AOR. For 1J-118 there (reaching 1,243'MD/618'TVD (reaching 1,612'MD/673'TVD Please let me know if you have any additional questions. Thanks, Sydney Autry West Sak 1E/1J Drillsite Engineer ConocoPhillips Alaska, Inc. Sydney.Autry@conocophillips.com W:907-265-6813 C:907-342-7606 + GKA RWO Coordinator From: Autry, Sydney Sent: Saturday, September 28, 2019 6:33 AM To: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Subject: RE: [EXTERNAL]West Sak wells: Conversion from WI to WAG 1J-118, 1J-176 Victoria, Sorry for the slow reply - I have been on the slope the last few days and will be up here until Wednesday. I am aiming to send you an updated AOR in the next couple days. Thank you, Sydney Autry From: Loepp, Victoria T (CED) <victoria.loepp@alaska.aov> Sent: Wednesday, September 25, 2019 10:55 AM To: Autry, Sydney <Svdnev.Autry@conocophi Ili ps.com> Subject: [EXTERNAL]West Sak wells: Conversion from WI to WAG 1J-118, 1J-176 Sydney, For any Kuparuk wells identified in the AOR of these wells, is the surface shoe above or below the WSak? I Please identify which AIO allows this WAG injection. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. LoeooCdralaska.g ov CONFIDENTIALITY NOTICE., This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). If may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria Loeoo@alaska gov Image Pject NVell I-list® t=ile r Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~ ~ - ~ ~ ~ Well History File Identifier Organizing (done) RES AN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: .~,„d iuuimuiiiuii DIG TAL DATA Diskettes, No. l ^ Other, No/Type: ^ Rescan Needed II I II II (I (I I I II I III OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: BYE ~Mafla ~ Date: ~-~' ~~,~ ~~~~ /s/ Project Proofing BY: Maria Date: ~ ~ /s/ 1 x 30 = + ~ =TOTAL PAGES Scanning Preparation _~ """ ~~, (Count does not include covers eet) n /~ BY: Maria Date: `U-~,~~ ~f !s/ ~/ (/ ~1 Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cov sheet) Page Count Matches Number in Scanning Prep ration: YES NO BY: Maria Date: ~~ ~~ (~ ~ /s/ Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scannin is complete at this point unless rescanning is required. II I II'I II I II II I I III 9 ReScanned III 111111 IIIII II III BY: Maria Date: /s/ Comments about this file: Quality Checked II I II ~I II III (I'I III 10!6/2005 Well History File Cover Page.doc .~~~ ,~:; ~ ~.p ~~ ~wry~,;" 4 MICROFILIViED 6/30/201.0 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Mazker.doc • t _ ~. -. ;'~~zoi~a~ierE ~e~c~s~ic ~~~ericrs, ~~vc_ ~ `~~,~. ~.~~~~ ~'~ ,` ~, ~~~ ~ To: ,~10GCC Christine iVlahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 995~1 (907) 659-5102 • RE : Cased Hole/Open Hole/Mechanical Logs and/orTubing Inspection(Caiiper/ MTT] . _... _ .... The technicat data listed below is being submitted herewith. Please acknour~edge receipt by returning a signed copy of this transmittal letter to the tollowing : ProActive Disgnostic Services, lnc. Attn: Robert A. Richey 130 West Irrternational Airport Road ~ ~~~~~~~~' ~ ~. ~ ~ zv~ ~Q ~~ Suite C Anchora~, AK 99518 Fa~c (907) 245-8952 1] Injection Profile 17-May-09 1 J-118 L1 2) J~ ~ ~~ ~ i~ Signed : Print Name: ~ D~ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT Rp SUITE C, ANCHORAGE, AOC 99518 PHONE: (90T)245-8951 Fax: (907)245~8952 E-MAIL ~:v ____-.~ _ _._ :_ _ ~~ :.._ .~;:: bNEBSITE::; <: _ Color Log / E~E 50-029-23337-60 C:1Documen6 and SeiRngsiOwr+er~Desktop'~Tiarrsrtut_Cortoco.docx ~~ ~~1_I~ lfl ~ ^ ~t `~ 0 Q ~p r i \ DATA SUBMITTAL COMPLIANCE REPORT 3126/2009 Permit to Drill 2061770 Well Name/No. KUPARUK RIV U WSAK 1J-118L1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23337-60-00 MD 14795 TVD 3803 Completion Date 3/19/2007 Completion Status 1-OIL Current Status 1WINJ UIC Y -. -_ _- --- - -- - -- __ REQUIRED INFORMATION ~~<<f ~ Mud Log IVo Samples IVo Directional Survey Ye DATA INFORMATION Types Electric or Other Logs Run: GR/Res, USIT Well Log Information: Log/ Electr Dada Digital Dataset Tj~fpe Med/Frmt Number /Name ED C Lis 15183 Induction/Resistivity p 15183 LIS Verification Q D Asc D~irectional Survey D C Lis 15238'~Induction/Resistivity pt 15238 LIS Verification ~Otog Induction/Resistivity i g I~nduction/Resistivity C 17567 "See Notes Well Cores/Samples Information: (data taken from Logs Portion of Master Well Data Maint ~- Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments 3318 14795 Open 6/12/2007 __ _ LIS Veri, GR, FET, ROP w/Graphics PDF & TXT ~ 3318 14795 Open 6/12/2007 LIS Veri, GR, FET, ROP ~ 7726 14795 Open 6/12/2007 3318 14795 Open 6/25/2007 LIV Veri, GR, FET, ROP w/Graphics txt and PDF 3318 14795 Open 6/25/2007 LIV Veri, GR, FET, ROP ~ ~ 25 Col 108 14795 ~a 2/4/2009 MD ROP, DGR, EWR 21- Feb-2007 25 Col 108 3802 a 2/4/2009 TVD DGR, EWR 21-Feb- 0 0 ~+ ~ 2/4/2009 2007 EWR logs in EMF, CGM and PDS graphics Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 3/26/2009 Permit to Drill 2061770 Well Name/No. KUPARUK RIV U WSAK 1J-118L1 Operator CONOCOPHILLIPS ALASKA INC MD 14795 TVD 3803 Completion Date 311.9/2007 Completion Status 1-OIL Current Status 1WINJ ADDITIONAL INFORMATION Well Cored? Y~ Daily History Received? Chips Received? Y71~ Formation Tops ~ N API No. 50-029-23337-60-00 UIC Y Analysis 1~!-I+J- Received? Comments: Compliance Reviewed By: - _. __ _ ___ - ~ '\ - -- - __ v~.~ ~~ Date: _ _ __ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1J-118+L1+L2+PB1+PB2 January 20, 2009 AK-MW-4884845 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Bryan Burinda, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1J-118+L 1+L2+PB 1+PB2 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 50-029-23337-00,60,61,70,71 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 50-029-23337-00,60,61,70,71 Digital Log Images 50-029-23337-00,70,71 50-029-23337-60 50-029-23337-61 1 Color Log 1 Color Log 3 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 Fax: 907-273 -3 53 5 BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Bryn.B~u~in~ia'~z~halli~aon.com UL~- ~p(o'1~~ L~S~~ Date: ~ _ 9 Signed ~----~ ~T J! '~---- Y ~ • ~ tl t~s Rref ~mn s :. STATE OF ALASKA -~~ ~ (3 ZOO7 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL ~~~' ' '`~ l~~s ions. C~mme~~ OP 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ ERATIO ~~ l t Ir Stimulate ^ Other /^ Prod to WINJ ~ Alter Casing. ^ Pull Tubing ^ Perforate New Pool ^ ^ Waiver ^ Time Extension Change Approved Program ^ Operat. Shutdown^ .Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. ~ Development ^ Exploratory ^ 206-177 3. Address: Stratigraphic ^ Service ^ 6. API Number: P, O. Box 100360, Anchorage Alaska 99510 , 50-029-23337-60 '' 7. KB Elevation (ft): 9. Well Nameand Number RKB 109' . 1J-118L1 ' 8. Property Designation: ~ 1D. Field/Pool(s): ADL 25661 &ADL 25650 Kuparuk River Field /West Sak Oil Pool - 11. Present Well Condition Summary: TotaLDepth measured 14795' feet true vertical 3803' ~ feet Plugs (measured) Effective. Depth measured 14787 .feet Junk (measured) true vertical 3802' feet 5-1/2" x 4-1/2" Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 20" 108' 108' SURFACE .3249' 10-3/4" 3358' 2221' INTERMEDIATE 8840° 7-5/8" 8949' '3729` WINDOW L2 1' 7-5/8" 7208'. 3606' WINDOW L1 1' 7-5/8" 7767 Perforation depth:. Measured depth: 8028' - 14753' true vertical depth: 3707 - 3802' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 7190' MD. Packers &SSSV (type & measured depth) PKRS = BAKER'ZXP' LINER TOP PACKERS PKRS = 71 46'; 7312'; 7851' SSSV=NIP SSSV= 503' 12. Stimulation or cement squeeze summary: Intervals treated (measured) ~~ S~~~ ~ 1007 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data P i t Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure r or o well operation 1396 1584 45 806 272 Subsequent to operation 14. Attachments 1503 526 229 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ^ i Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ ~ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the bes t of my knowled e g . Sundry Number or N/A if C.o. Exempt: Contact 307-148 Bob Christensen /Bob Buchholz Printed Name ~_ rt D. C istensen Title Production Engineering Technician Signature Phone 659-7535 Date. ~ ~,/ Form 10-404 Revised 04/2004 Rut,mit n~~l„~~ ~~~,, ~ • 1J-118L1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 08/31/07 Commenced Water Injection Service • WILL LOG TRANSMITTAL To: State of Alaska June 7, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`~' Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 1J-1 l8 L1 Redo AK-MW-4884845 1 LDWG formatted CD Rom with verification listing. APl#: 50-029-23337-60 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ~~~ ~)ll~1 ~ ~ 2007 Date: Signed: __--- ~~laska ail t~ (gas C;a~s. ~ornrnissiort Note: Thi3-~~~f~~upersedes any past information for well 1J-118 L1. ao~ - ~ ~~ ~~ ~ a3~$ U `'ELL I.®G ~TR~=~dS!~IIT`~'AL T®: Stag of Alaska June 1, X007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 Vest 7`i' Avenue, Suite 100 Anchorage, Alaska RE: M~VD Formation Evaluation Logs 1J-118 Ll AK-MW-4884845 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23337-60 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A:~TD RETURNING A COPY OF THE TRA='vSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 11-May-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-118 L1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 7,726.90' MD Window /Kickoff Survey 7,766.70' MD (if applicable) Projected Survey: 14,795.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 ~~ Date ~.-- 1 Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ConocoPhillips April 17, 2007 RECEIVED Commissioner APR 2 5 State of Alaska 2007 Alaska Oil & Gas Conservation Commission Alaska'Oil ~ Gas Cons. Commission 333 West 7th Avenue Suite 100 Anchorage Anchorage, Alaska 99501 Subject: Well Completion Reports for 1J-118, 1J-118L1 and 1J-118L2 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations on the West Sak wells 1 J-118, 1 J-118L1, 1 J-118L2. If you have any questions regarding this matter, please contact me at 265-6830 or Dennis Hartwig at 265-6862. Sincerely, R. Thomas Kuparuk Drilling Team Leader CPAI Drilling Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. p. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 RT/skad ~ ~- ~°EIVEL~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ('~ 2 5 2007 WELL COMPLETION OR RECOMPLETION REPORTRAI~~,~.,~~,~ 1a. WeII Status: Oil O Gas Plugged Abandoned Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. a lass: ~nir~i0rr8 p Development O - Ex~dratory ^ Service ^ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. ~ ,~, 5. Date Comp., Susp., orAband.: March. , 2007 . Permit to Drill Number: 206-177 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: ~ February , 2007 ~ •b7 13. API Number: 50-029-23337-60 4a. Location of Well (Governmental Section): Surface: 1914' FSL, 2366' FEL, Sec. 35, T11N, R10E, UM ~ 7. Date TD Reached: March 3, 2007` 14. Well Name and Number: 1J-118L1 Top of Productive Horizon: 1391' FNL, 2215' FWL, Sec. 36, T11 N, R10E, UM 8. KB (ft above MSL): ~jrj ~iyg Ground (ft MSL): 81' . 3b• 15. Field/Pool(s): 7 Kuparuk River Fieid Total Depth: 346' FSL, 2016' FWL, Sec. 24, T11 N, R10E, UM 9. Plug Back Depth (MD + TVD): 14787' MD / 3802' TVD West Sak Oil Pool ° 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558844 ' y- 5945727 '' Zone- 4 10. Total Depth (MD + TVD): ~ 14795' MD / 3803' TVD 16. Properly Designation: ADL 25661, 25650 ° TPI: x- 563407 y- 5947739 Zone- 4 Total Depth: x- 563146 ~ - 5954753 ~ Zone- 4 11. SSSV Depth (MD + TVD): nipple @ 503' 17. Land Use Permit: 471, 468 18. Directional Survey: Yes 0 No ^ ~ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (TVD): 3566' MD ! 2304' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): K~: ~?~.? ~~,Zj~ 2i g3 ~ ?jam GR/Res, USIT •~~+ ~,3p•Zl7 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE ING AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENT RECORD PULLED 20" x 34" 78.6# H-40 28' 108' 28' 108' 42" 360 sx AS 1 10.75" 45.5# L-80 28' 3358' 28' 2221' 13.5" 575 sx AS Lite, 180 sx LiteCRETE 7-5/8" 29.7# L-80 28' 8949' 28' 3867' 9-7/8" 525 sx DeepCRETE 5.5" X 4.5" 11.6# L-80 7508' 14788' 3657' 3802' 6.75" slotted liner 23. Open to production or injection? Yes ^/ No ^ If Yes, list each 24. TUBING RECORD Interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET tubing in main wellbore 7312' slotted liner from 8772'-8973', 9437'-9681', 10138'-10308', 10857'-10934', 11564'-11818', 12279'-12520', 12966'-13202', 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 13653'-13882', 14347'-14588' MD DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production April 7, 2007 Method of Operation (Flowing, gas lift, etc.) flowback Date of Test 4/7/2007 Hours Tested 6.5 hours Production for Test Period --> OIL-BBL 643 GAS-MCF 659 WATER-BBL 0 CHOKE SIZE 30 Bean GAS-OIL RATIO 85 Flow Tubing press. 526 psi Casing Pressure not available Calculated 24-Hour Rate -> OIL-BBL J 2273 GAS-MCF 2512 WATER-BBL 1 OIL GRAVITY -API (corr) not available 27. CORE DATA Conventional Core(s) Acquired? Yes ^ No ^/ Sidewall Cores Acquired? Yes ^ No Q If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. . r5~;~.a}y ~,y.~ •f77 ''- NONE ~~..~~ ~' t 3 ~p ..,... -e, -°I Form 10-407 Revised 2/2007 ORIGINAL CONTINUED ON REVERSE SIDE t~H t~ et ~ L~UI ~. y.3o.r~7 .~ 28. GEOLOGIC MARKERS (List all formations and ma rs encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ~ Yes / No If yes, list intervals and formations tested, Permafrost -Top 3566' 2304' briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 3566' 2304' needed, and submit detailed test information per 20 AAC 25.071. West Sak B Top 7763' 3693' West Sak B Bottom 14795' 3803' N/A ~ ~p7 ~ ~ Formation at total depth: I~ 14795' /' 3803' 30. LIST OFATTACHMENTS Summary of Daily Operations, Directional Surveyv slotted liner detail sheets 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Dennis Hartwig @ 265-6862 Printed Name Randv Thomas Title: Drilling Team Leader Signature --~ Phone "LL- ~ S Fr ~ S CJ Date INSTRUCTIONS Sharon Allsup-Drake 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 a i i Tirnc Logs Date - From _ To Dur S D pti~ E Depth Phase Code Subcode T COM 02/24/2007 00:00 00:45 0.75 0 0 COMPZ CASINC RURD P Remove all tools from rig floor and clean same. 00:45 02:00 1.25 0 0 COMPZ RIGMN SVRG P Slip & Cut Drill Line 72' cut, Service TD, Ck saver sub "OK" 02:00 03:00 1.00 0 0 COMPZ DRILL PULD P PU Baker tools from beaver slide. Sta eon ri floor. 03:00 06:30 3.50 0 90 PROD2 DRILL PULD P MU BHA #4 - MU Stop sub w1 finer seals, Unloader sub, 1 jt 3.5" Dp, 2 pup jts (14.62' + 9.78') Blank sub, Trip anchor, Safety disconnect, Drain sub, Debris cover sub, Whip stock, Window mill, Lower mill, Upper Full Guage mill,. 1 jt 3.5" HWDP, Flt sub, Su er Slim MWD 06:30 07:00. 0.50 90 90 PROD2 DRILL SRVY P Up Load MWD. 07:00 -07:45 0.75 90 370 PROD2 DRILL PULD. P Con't PU BHA #4 - PU Bamper sub, XO, 2 stds Hybrid Push Pipe -Shallow Test MWD 370"'OK" 07:45 12:00 4.25 370 6,504 PROD2 DRILL TRIP P RIH f/ 370' to 6504' MD - Up wt 124K, Dn wt 74K """NOTE"`' Using slick DP only. No WWT S5 because of steel cuttin could dams a sleeves. 12:00 12:30 0.50 6,504 6,720 PROD2 DRILL SFTY P PJSM & Con't Tripping in hole. Mad pass for K-13 tie in, 6680' to 6720' MD ~ 12:30 13:30 1.00. 6,720 7,857 PROD2 DRILL TRIP P Con't RIM to 7792' MD - MU std - Up ~ wt 140K, Dn wt 70K- Tag TOL @ 7857 ~~®~ w/ 15K -Set whipstock 16 deg Left & confirmed set w/ 10K over ull. 13:30 14:15 0.75. 7,857 7,765 PROD2 DRILL CIRC P Shear off Whipstock- Displace-hole over to drillin OBM. 8.4+ 14:15 16:30 2.25 7,765 7,779 PROD2 DRILL MILL P Mill "B" lat.. window from 7766' to 7779' - WOM 2-3K, RPM 100, PR 285 GPM, PP2400psi, Torq 6K -Pumped ~~ 30 bbl hi vis sweep (20% increase in cuttin TOW 7766' & BOW 7779' MD ~~~ 16:30 19:00 2.50 7,779 7,797 PROD2 DRILL MILL P Mi117779' to 779T MD (Leaves Ful! ' ' guage hole to 7784 ) 5 outside window. 19:00 19:45 0.75 . 7,797 7,797 PROD2 DRILL MILL P Pump sweep and circu around- Dress window area (Made 4 passes thru window with pump and the last pass without pump.) Pu wt 128K, Dn wt 85K, Rot wt 95K ,Torq 4K, Monitor well, Pum slu ,Blow down TD 19:45 22:00 2.25 7,797. 0 PROD2 DRILL TRIP P POOH w/Milling asst'-Std Bk Push Pi e & H brid DCs 22:00 00:00 2.00. 0 0 PROD2 DRILL PULD P VD Bumpersub, Dn Load MWD, UD Milling asst. Guaged upper milt "Full Gua e.. 02/25/2007 00:00 00:30 0.50 0 0 PROD2 DRILL PULD P Clean all tools from rig floor- BOLDS- Pull wearbushin - - - _ - Time Logs___ - Date From To__ D_ ur S Depth E. Depth Phase Code ---- Subcode_ T -_ _ COiN _ _ 02!25/2007 00:30 01:00 0.50 0 0 PROD2 DRILL CIRC P PU Flushing tool -Flush all BOPS components by circu thru tool and rotating, working up and down thru stack to remove metal milling cuttings. Function all Rams & Annular. 01:00 02:00 1.00 0 0 PROD2 WELCT BOPE P RU BOP Test Equipment 02:00 06:00 4.00 0 0 PROD2 WELCT BOPE P Test BOPs 250 psi Lo - 3000 psi High -Test witnessed by AOGCC rep Jeff Jones - Tested all BOP components and Choke manifold. Gas and H2s alarms tested "All OK" 06:00 06:30 0.50 0 0 PROD2 WELCT NUND P Set wear bushing - RILDS 06:30 07:45 1.25 0 94 PROD2 DRILL PULD P PJSM - MU BHA #5 per DD &MWD detail 07:45 08:30 0.75 94 94 PROD2 DRILL SRVY P Upload MWD 08:30 09:30 1.00 94 371 PROD2 DRILL PULD P Con't PU BHA #5 -Shallow test MWD 371' "OK" 09:30 12:00 2.50 371 5,149 PROD2 DRILL TRIP P RIH to 1512' - PU XO, Agitator & Shock sub, XO, Test same "OK". AG Tool @ 1600', 80 SPM, 284 GPM, 2240 psi - Blow do TD - Con't RIH to 5149' MD 12:00 13:00 1.00 5,149 7,797 PROD2 DRILL REAM P PJSM - RIH to 7668' MD break circu - Orient to Hi side and wash to 7759' Up wt 108K, Dn wt 69K) Slide clean without pump to 7785' (Top of full guage hole) & open ho-e to 7797' Bttm of pilot hole) Clean hole ECDs 9.40 13:00 00:00 11.00 7,797 8,297 PROD2 DRILL DDRL P Drlg & Slid 6 3/4" hole w/Motor 7797' to 8297' MD / 3711' TVD. *" Note** Drilled total of 125' of concretions this tour. 02/26/2007 00:00 12:00 12.00 8,297 8,786 PROD2 DRILL DDRL P Drlg & Slide w/ Motor f/ 8297' MD to 8786' MD / 3717' TVD. Up wt 119K, Dn wt 65K, Rot wt 83K, Torq on & off 7K, Max gas 83 units, Jar hrs 67.28. Drilled total of 89' of concretions. ART 8.88 hrs, AST .35 hrs =Total ADT 9.23 hrs, ECDs 9.68 12:00 12:15 0.25 8,786 8,786 PROD2 DRILL SFTY P PJSM -Drilling & Conections pinch oints -hazard reco nition. 12:15 00:00 11.75 8,786 9,786 PRODZ DRILL DDRL P Drlg & Slide w/ Motor f/ 8786' MD to 9786' MD ! 3740' TVD. Up wt 120K, Dn wt 60K, Rot wt 85K, Torq on 7K off 8K, Max gas 159 units, Jar hrs 75.05. Drilled total of 87.0' of concretions. ART 8.88 hrs, AST .35 hrs =Total ADT 9.23 hrs, ECDs 10.01 ~ ____._____.-. _s~ _ ~ -_~ P~~~ ~w raf ~~.... ~~ C Time Logs Date _ From To Dur_ S De th E. De th Vhase Code Subcode T COM _ _ 02l27/2007 ~00:00 __ 12:00 . 12.00 9,786 10,576 PROD2 DRILL DDRL P Directionally drilled 6 3/4" hole in "B" sand lateral with 1.5 deg mud motor from 9,786' to 10,576' MD/3,750' ND (790'} ART 5.55 hrs, AST 1.69 hrs, ADT 7.24 hrs, MW 8.45 ppg, ave ECD 10.0 ppg, ave BGG 45 units, max gas 95 units, drilled thru 4 concretions for 42'. 12:00 00:00 12.00 10,576 11,485 PROD2 DRILL DDRL P Directionally drilled 6 3/4" hole in "B" sand lateral with 1.5 deg mud motor from 10,576' to 11,485' MD/3,760' ND (909') ART 6.89 hrs, AST 1.14 hrs, ADT 8.03 hrs, MW 8.45 ppg, ave ECD 1.0.3 ppg, ave BGG 45 units, max gas 142 units, drilled thru 10 concretions for 97' 14 total last 24 hrs for 139' . 02/28/2007 00:00 10:45 10.75 11,485 12,240 PROD2 DRILL DDRL P Directionally drilled 6 3/4" hole in "B" sand lateral with 1.5 deg mud motor from 11,485' to 12,240' MD/3,762' ND (755') ART 8.13 hrs, AST .29 hrs, ADT 8.42 hrs, MW 8.45 ppg, ave ECD 10.35 ppg, ave BGG 50 units, max gas 193 units, drilled thru 5 concretions for 60'. Decision was made to POOH and PU Geo ilot. 10:45 12:00 1.25 12,240 12,240 PROD2 DRILL CIRC NP Pumped 30 bbl hi vis sweep and circ out of hole, had 5% increase in cuttings back from the sweep. Reset iron roughneck on track after repairing same. 12:00 16:00 4.00 12,240 7,760 PROD2 DRILL REAM NP Held PJSM then backreamed out of hole 10 stds from 12,240' to 11,400' then BROOH every other std to 7,948', then POOH thru the window to 7,760'. (TOW at 7,766') BROOH at 90 rpm's, 300 gpm, ICP 3,250 psi, FCP 2,800 si, no roblems BROOH. 16:00 16:30 0.50 7,760 7,760 PROD2 DRILL OWFF NP Monitored well-static, pumped dry job and blew down to drive. 16:30 19:30 3.00 7,760 91 PROD2 DRILL TRIP NP POOH from 7,760' to MWD at 91', LD shock tool and agitator then stood back HWDP, jars and NMFDC's on trip out. Hole took 4.5 bbls over calc hole fill. 19:30 21:00 1.50 91 0 PROD2 DRILL PULD NP Downloaded MWD then fin. LD BHA #5, LD MWD and motor 21:00 22:00 1.00 0 0 PROD2 DRILL OTHR NP Cleared and cleaned rig floor 22:00 22:30 0.50 0 0 PROD2 RIGMN SVRG NP Serviced top drive and drawworks 22:30 00:00 1.50 0 40 PROD2 DRILL PULD NP Began to MU BHA #6, MU bit on Geopilot, pony flex DC, smart stabilizer and DM HOC 03/01/2007 00:00 02:15 2.25 40 456 PROD2 DRILL PULD NP Fin MU geopilot BHA #6, MU MWD and uploaded same, RIH with BHA and 1 std of 4" DP to 456' and shallow tested MWD and eo ilot. ®® ®_ ~~ ~ j ~~t~L ~,s G'~ fit; ~ ~~ Time Lo~s__ _ -- __ _ Date From To Dur S. De th__E Depth Phase Code Subcode T__. COM 03/01/2007 02:15 07:00 4.75 456 11,849 PROD2 DRILL TRIP NP RIH from 456' to 11,849' and lost down wt., no problems RIH thru window at 7,766' 07:00 08:00 1.00 11,849 12,240 PROD2 DRILL REAM NP Washed and reamed from 11,849' to btm at 12,240' with no problems, washed down at 50 spm, 177 gpm at 1,280 si, 100 r m's 9K ft-Ibs for ue. 08:00 00:00 16.00 12,240 13,560 PROD2 DRILL DDRL P Directionally drilled 6 3/4" hole with geopilot in "B" sand lateral from 12,240' to 13,560' MD/3,774' TVD (1,320') ADT 11.2 hrs, 8.45 ppg MOBM, ave ECD 10.9 ppg, pumped hi vis sweep at 12,900' and had 5% increase in cuttings back from the sweep, ave BGG 50 units, max gas 125 units. Drilled thru 8 concretions for 106'. 03/02/2007 00:00 12:00 12.00 13,560 13,996 PROD2 DRILL DDRL P Directionally drilled 6 3/4" hole with geopilot in "B" sand lateral from 13,560' to 13,996' MD/3,787' TVD (436') ADT 9.68 hrs, 8.45 ppg MOBM, ave ECD 10.9 ppg, 10.5 ppg while on concretion, ave BGG 50 units, max gas 93 units. Drilled thru 5 concretions for 42'. 12:00 00:00 12.00 13,996 14,551 PROD2 DRILL DDRL P Directionally drilled 6 3/4" hole with geopilot in "B" sand lateral from 13,996' to 14,551' MD/3,800' TVD (555') ADT 9.12 hrs, 8.45 ppg MOBM, ave ECD 11.0 ppg, 10.5 ppg while on concretion, ave BGG 50 units, max gas 111 units. Drilled thru 9 concretions for 71'. (14 total for 113') No swee s 03/03/2007 00:00 02:30 2.50 14,551 14,795 PROD2 DRILL DDRL P Directionally drilled 6 3/4" hole with geopilot in "B" sand lateral from 14,551'to 14,795' MDl3,802' TVD (244') ADT 2.28 hrs, "B" lat T.D 02:30 02:45 0.25 14,795 14,795 PROD2 DRILL OWFF P Monitored well-static, took SPR's 02:45 12:00 9.25 14,795 7,756 PROD2 DRILL REAM P Backreamed out of hole from 14,795' to above TOW to 7,756', (TOW @ 7,766') BROOH at 130 rpm's, 320 gpm, ICP at 3,500 psi, FCP 2,600 psi, pulled thru window with 5-10K drag and had no other roblems BROOH. 12:00 13:15 1.25 7,756 7,756 PROD2 DRILL CIRC P Pumped 35 bbl wt'd hi vis sweep (2# over MV1n and circ hole clean, had 15% increase in cuttings back from the sweep, circ hole clean at 130 rpm's, 5k ft-Ibs torque, 320 gpm at 2,600 si. 13:15 15:45 2.50 7,756 12,409 PROD2 DRILL TRIP P RIH from 7,756' to 12,409' when we lost all down wt. a , ~~® _ ~ w~<~c~~ 1~ ~f ~3 Time Lis Date __ From To Dur S _C~e th E. ~eUth Phase Code_ Subcode T_ COM - -_ __ 03/03/2007 15:45 18:30 2.75 _ 12,409 14,795 PROD2 DRILL - REAM P Washed and reamed from 12,409' to btm at 14,795', washed down at 80 rpm's, 8K ft-Ibs torque, 185 gpm at 1,375 psi. No problems RIH or washin to btm. 18:30 20:45 2.25 14,795 14,795 PROD2 DRILL CIRC P Pumped 35 bbl, 9.1 ppg hi vis sweep and circ hole clean, had no increase in cuttings back from the sweep, circ hole at 320 gpm, 3,750 psi, 130 rpm's with 9K ft-Ibs for ue 20:45 22:15 1.50 14,795 14,795 PROD2 DRILL CIRC P Dislpaced hole over from 8.45 ppg MOBM to 8.45 ppg SFMOBM, 320 m at 3,750 psi. 22:15 22:30 0.25 14,795 14,795 PROD2 DRILL OWFF P Monitored well-static 22:30 00:00 1.50. 14,795 14,265 PROD2 DRILL TRIP P POOH on elevators from 14,795' to 14,265', POOH w/3 stds hybrid push pipe then dropped 1 7/8" rabbit on wire, cont. to POOH on elevators to 14,265' 03/04/2007 00:00 08:15 8.25 14,265 371 PROD2 DRILL TRIP P Cont to POOH on elevators from 14,265' to BHA at 371'. While pulling thru window made 3 attempts at pulling 15K over w/no success, rotated thru window then went down thru pulling back thru w/no rotation and had only 10K drag, cont. POOH to BHA, calc hole fil- 85 bbts, actual fill 104 bbls. 08:15 11:00 2.75 371 0 PROD2 DRILL PULD P POOH LD BHA #6, stood back HWDP, jars and NMFDC's, downloaded MWD then fin. LD BHA and cleared ri floor. 11:00 11:45 0.75 0 0 COMPZ CASIN( RURD P RU to run 4 1/2" liner 11:45 12:00 0.25 0 0 COMPZ CASINC SFTY P Held PJSM on running of 4 1/2" liner. 12:00 16:45 4.75 0 6,834 COMPZ CASINC RNCS P PU and RIH with 4 1/2", 11.6 ppf, L-80 liner to 3,822', RIH with 4 1/2"guide shoe, 47 jts of slotted BTC, 87 jts of blank BTC, XO to 15 jts of blank Hydril 521 and 15 jts of slotted, spaced out per well plan, used 80 torque rings, 163 stop rings with 163 Hydraform centralizers floating below stop rings. MU Baker liner setting sleeve and running tool RIH to 6,834', st wt up 88K, do wt 60K, rotated at 20 rpm's with 2K ft-Ibs for ue and 70K rot wt. 16:45 17:15 0.50 6,834 6,834 COMPZ CASIN RURD P RD liner running tools and cleared rig floor. l J Time Los __ __~I ~- --__ Date From To Dur S. De th E. De th Phase Code Subcode T COM 03/04/2007 17:15 19:45 2.50 6,834 11,700 COMPZ CASINC RUNL P RIH with 4 1/2" liner on 4" DP from 6,834' to 11,700' when we lost all down wt., no problems going thru the window, st wt up 130K, est rotation at 20 rpm's, 8K ft-Ibs torque and 75K rot wt. (Note: set torque limiter at 9K ft-Ibs 19:45 00:00 4.25 11,700 14,081 COMPZ CASINC RUNL P Rotated liner in the hole from 11,700' to 14,081', ave 15-20 rpm's with 9K ft-Ibs torque, at 14,081' PU wt 170K, rot wt 70K, rot do wt 55K, increased for ue limit to 11 K ft-Ibs. 03/05/2007 00:00 01:00 1.00 14,081 14,795 COMPZ CASIN( RUNL P Cont to rotate 4 1/2" liner in the hole, rotated from 14,081' and tagged btm at 14,795', ave 11 K ft-Ibs torque with 10-20 rpm's with torque limiter set at 13K st wt up 200K, rot do wt 50-55K , rot wt 95K. 01:00 01:45 0.75 14,795 14,788 COMPZ CASINC RUNL P Dropped 29/32" ball and set liner on depth with top of setting sleeve at 7,961' and shoe at 14,788', pumped ball down and with ball on seat pressured up to 2,500 to release running tool then pressured up to 4,500 psi and sheared ball seat, st up wt 150K after releasin liner. 01:45 02:15 0.50 7,961 7,779 COMPZ DRILL TRIP P POOH from 7,961' to 7,779' to btm of window 02:15 02:45 0.50 7,779 7,779 COMPZ DRILL CIRC P Circ a btms up across WS slide to clean slot, Circ at 326 gpm at 2,400 si. 02:45 03:30 0.75 7,779 7,030 COMPZ DRILL TRIP P POOH with hybrid push pipe from 7,779' to 7,030' 03:30 06:30 3.00 7,030 7,030 COMPZ RIGMN RGRP T Changed out O-ring on the top drives goose neck then changed out swivel ackin . 06:30 08:00 1.50 7,030 7,030 COMPZ RIGMN SVRG P Held PJSM then slip and cut 214' of drl line. 08:00 15:30 7.50 7,030 0 COMPZ DRILL TRIP P POOH from 7,030' with liner running tool and LD same, inspected WWT sliders on trip out and moved down 1' on DP, changed out 6 collars and 3 sleeves all others checked ok. (WWT re on loc.) cleared ri floor. 15:30 17:00 1.50 0 60 COMPZ FISH PULD P Mil whipstock retrieving hook on fishin BHA #7 RIH to 60'. 17:00 20:15 3.25 60 7,771 COMPZ FISH TRIP P RIH with BHA #7 from 60' to WS slot at 7,771', st wt u 140K, do 80K 20:15 00:00 3.75 7,771 7,771 COMPZ FISH FISH P Latched onto whipstock slot and jarred whipstock loose ,was able to hook slot and jar on WS, would come out of slot then would need to re-hook, jarred up to 130K over st wt when whipstock came free, (cycled jars 14X) monitored well and took 3 bbls to fill hole. PU and at wt up was 150K, Monitored well-static. ®~ ~ ® ~ _ ~~~ ~~ of ~~ r~ Time Logs _Date___ From To Dur S. De th,_E, Deoth Phase Code Subcod__e T COM _ 03/06/2007 00:00 03:45 3.75 7,771 60 COMPZ FISH TRIP P POOH with BHA #7 from 7,771' to BHA at 60' 03:45 06:00 2.25 60 0 COMPZ FISH PULD P POOH LD BHA #7, LD whipstock and seal assembly, cleared and cleaned ri floor. 06:00 07:00 1.00 0 0 COMPZ CASIN( RURD P RU to run hook hanger assembly 07:00 07:30 0.50 0 0 COMPZ CASIN< SFTY P Held PJSM on MU hook hanger assembl with slim hole MWD 07:30 09:30 2.00 0 262 COMPZ CASINC PUTB P MU "B" lat Hook Hanger assembly with ECP packer and slim hole MWD RIH to 262', oriented MWD and shallow tested same. 09:30 13:00 3.50 262 7,766 COMPZ CASINC RUNL P RIH with hook hanger assembly on 4" DP from 262' and tagged up on XO of "A" lat, PU to TOW at 7,766', st wt up 140K, do wt 85K 13:00 17:00 4.00 7,766 7,763 COMPZ CASINC OTHR P Rotated hook hanger, est circ and oriented hook and RIH hooking hanger at the btm of the window at 7,779', PU, rotated hook, RIH and tagged up on "B" lat XO at 8,023', PU and rehooked at btm of the window, dropped 1 3/4" ball and pumped down to seat, pressured up to 1,000 psi then to 4,000 psi, took .25 bbls to inflate ECP paker, set top of hook hanger at 7,762.69' and btm of mule shoe at 8,017'. PU and released from hook, st wt up 159K, took several attempts to release running tool, worked tool with and without 1,000 psi ressure then tool came free. 17:00 17:15 0.25 7,763 7,763 COMPZ CASIN OTHR P Monitored well-static, blew down top drive. 17:15 20:30 3.25 7,763 20 COMPZ CASIN( RUNL P POOH with liner running tool from 7,763' to tool at 20' 20:30 21:30 1.00 20 0 COMPZ CASINC OTHR P LD Baker running tool and slim hole MWD tool, cleared ri floor 21:30 22:15 0.75 0 0 COMPZ RPCOh RURD P RU to run LEM assembly 22:15 22:30 0.25 0 0 COMPZ RPCOh SFTY P Held PJSM on picking up and running of LEM 22:30 00:00 1.50 0 142 COMPZ RPCOh PULD P Began to MU "B" lat. LEM assembly RIH to 142' 03/07/2007 00:00 01:30 1.50 142 599 COMPZ RPCOh PULD P Fin MU "B" Lat. LEM assembly with ZXP pkr and slim hole MWD RIH to 599', st wt u 45K, do wt 45K 01:30 05:00 3.50 599 7,755 COMPZ RPCOA TRIP P RIH W/LEM from 599' to 7,755', shallow tested MWD at 690', st wt up 135K, do wt 83K ~~ m m ~ ~~....._~.~ _ ._... ______ ~~' 1 eat 2fi ~ ~~ Time Lois - --- - - ----- _~ Date -___ Frorn To -Dur S. De th E. Depth Phase Code__ Subcode T COM _ __ _ 03/07/2007 05:00 ____ 07:15 2.25 7,755 7,312 COMPZ RPCOh OTHR f P Cont to RIH with LEM from 7,755', tagged top of hook at 7,763', rotated off and cont. RIH and tagged TOL to "A" lat at 7,851', oriented LEM to 16 deg left of high side, cont. RIH and saw seals enter SBE, st up wt 140K, do wt 80K, cont to go dn, taking 10K do wt to push seals thru SBE, tagged up with LEM and staged wt do on hook up to 35K and saw AZ swing from 16L to 75R indicating LEM was in place, PU 15K over PU wt to make sure LEM was latched. Dropped 1 3/4" ball and pumped do to seat, press. up to 2,800 psi to set hanger then to 4,200 psi to release from LEM, PU 3' and was free, st wt up 130K. Set top of "B" lat ZXP pkr at 7,312' with btm of the seals at 7,896' (6.5' above "A" lat XO 07:15 07:45 0.50 7,312 7,312 COMPZ RPCOh DHEQ P RU and tested ZXP packer and csg to 2,500 si for 5 min, ood test. 07:45 10:30 2.75 7,312 20 COMPZ RPCOti TRIP P POOH from 7,312' to Baker running tool at 20' 10:30 12:00 1.50 20 0 COMPZ RPCOCV PULD P POOH LD running tool and slim hole MWD, cleared and cleaned rig floor. talc fill on trip out 49 bbls, actual fill 49 bbls. 12:00 12:15 0.25 0 0 PROD3 STK OTHR P Held PJSM on MU of whipstock assembl 12:15 16:00 3.75 0 206 PROD3 STK PULD P MU milling BHA #8, MU space out seal assembly, whipstock and mills then MU MWD and uploaded same RIH to 206' 16:00 17:00 1.00 206 396 PROD3 STK TRIP P RIH from 206' to 396' and shallow tested MWD, blew down to drive. 17:00 18:15 1.25 396 396 PROD3 RIGMN SVRG P Serviced top drive and changed out saver sub. 18:15 00:00 5.75 396 6,980 PROD3 STK TRIP P RIH with milling BHA #8 from 396' to 6,980', MADD passed K-13 to correlate MWD while RIH. *"*NOTE""`Attachment to file - Orentation of LEM & Hook Han er. 03/08/2007 00:00 00:30 0.50 6,980 7,206 PROD3 STK TRIP P Cont RIH with whipstock BHA #8 RIH from 6,980', RIH and oriented WS to 13L of high side, tagged "B" lat ZXP at 7,312', set WS and sheared off from same with top of WS at 7,206', st wt u 135K, do wt 80K 00:30 01:00 0.50 7,206 7,206 PROD3 STK CIRC P Began to displace hole over from 8.45 ppg SFMOBM to 8.45 ppg MOBM (to fin. u w/millin ~~..~i ~" ~ ~~ _a~ ~ ~-____ _e~~ m ~ _~ ~~~~~ ~~ ~6 ~a i f # ~ Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Date: 4/1 V2007 Time: 09:43:10 Page: t Field: Kuparuk River Unit Co -ordinate(NE) Reference:. Well: 1J-11$;Tru e North Site: Kuparuk 1J Pad Ve rtical(TVD)tic fcrence: 1J-118L1:'109.0 Welt: 1J-118 Section (VS)'Refer ence: Well (O.OON,O.OO E,O.OOAzi) Wellpath: 1 J-1 i $L1 .. _ Survey (:~Iculation Method: Minimum Curvature Db: Oracle __ __ __ _ __ I Field: Kuparuk River Unit _ North Slope Alaska i United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: 1 J-118 Slot Name: Well Position: +N/-S -192.83 ft Northing: 5945727.24 ft Latitude: 70 15 44.361 N I +E/-W 52.25 ft Easti ng : 558843.70 ft Longitude: 149 31 27.486 W ~, ~ Position Uncertainty: 0.00 ft ~ Wellpath: 1J-118L1 500292333760 Drilled From: Tie-on Depth: 1J-118PB1 7726.90 ft Current Datum: 1 J-118L1: Height 109.00 ft Above System Datum: Mean Sea Level Magnetic Data: 2/2/2007 Declination: 23.63 deg Field Strength: 57618 nT Mag Dip Angle: 80.81 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg ~ 28.00 0.00 0.00 0.00 ~ Survey Program for Definitive Wellpath ~ Date: 4/11/2007 Validated: No Version: 4 Actual From To Survey To olcode Tool Name ft ft 50.00 917.00 1J-118P61 gyro (50 .00-917.00) CB-GYRO-SS Camera based gyro single shot 952.48 7726.90 1J-118PB1 (952.48- 8930.79) (3) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7766.70 14757.01 1J-118L1 (7766.70-14757.01) L_ MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC _-._ - Survey _ _ __ _ NID Jnci ~iim TVll SvsTVil ti/S ElW Map[v MapE ~Innl ft deg deg ft ft' ft ft ft ft 28.00 0.00 0.00 28.00 81.00 0.00 0.00 5945727.24 558843.70 TIE LINE 50.00 0.26 178.55 50.00 -59.00 -0.05 0.00 5945727.19 558843.70 CB-GYRO-SS 100.00 0.35 185.44 100.00 -9.00 -0.32 -0.01 5945726.92 558843.69 CB-GYRO-SS ~ 172.00 0.41 204.37 172.00 63.00 -0.77 -0.14 5945726.47 558843.57 CB-GYRO-SS 264.00 0.53 206.73 263.99 154.99 -1.45 -0.46 5945725.79 558843.25 CB-GYRO-SS 356.00 1.13 107.26 355.99 246.99 -2.10 0.21 5945725.14 558843.93 CB-GYRO-SS 447.00 4.18 84.03 446.88 337.88 -2.02 4.37 5945725.26 558848.08 CB-GYRO-SS 535.00 7.32 80.59 534.43 425.43 -0.77 13.09 5945726.57 558856.79 CB-GYRO-SS 629.00 10.71 78.99 627.25 518.25 1.88 27.57 5945729.33 558871.26 CB-GYRO-SS 732.00 14.71 84.31 727.71 618.71 5.00 49.99 5945732.63 558893.65 CB-GYRO-SS 826.00 16.54 84.61 818.23 709.23 7.45 75.19 5945735.27 558918.82 CB-GYRO-SS i 917.00 18.07 85.00 905.11 796.11 9.89 102.15 . 5945737.93 558945.76 CB-GYRO-SS ~ 952.48 18.85 83.37 938.77 829.77 11.03 113.32 5945739.16 558956.92 MWD+IFR-AK-CAZ-SC 1043.68 21.78 85.65 1024.29 915.29 14.02 144.84 5945742.39 558988.41 MWD+IFR-AK-CAZ-SC 1143.62 25.49 86.25 1115.83 1006.83 16.83 184.80 5945745.51 559028.34 MWD+IFR-AK-CAZ-SC 1236.06 27.56 88.80 1198.54 1089.54 18.58 226.03 5945747.59 559069.56 MWD+IFR-AK-CAZ-SC 1285.00 28.16 89.95 1241.80 1132.80 18.83 248.90 5945748.01 559092.42 MWD+IFR-AK-CAZ-SC 1330.98 31.33 89.47 1281.72 1172.72 18.95 271.71 5945748.31 559115.23 MWD+IFR-AK-CAZ-SC 1374.40 35.57 89.81 1317.94 1208.94 19.10 295.64 5945748.64 559139.15 MWD+IFR-AK-CAZ-SC I 1427.82 37.21 89.42 1360.94 1251.94 19.31 327.33 5945749.11 559170.83 MWD+IFR-AK-CAZ-SC 1522.61 37.43 90.02 1436.32 1327.32 19.59 384.79 5945749.83 559228.29 MWD+IFR-AK-CAZ-SC 1616.90 41.63 90.66 1509.03 1400.03 19.22 444.79 5945749.93 559288.28 MWD+IFR-AK-CAZ-SC 1669.94 46.39 89.61 1547.17 1438.17 19.15 481.63 5945750.15 559325.12 MWD+IFR-AK-CAZ-SC 1710.91 50.31 89.47 1574.39 1465.39 19.39 512.24 5945750.63 559355.72 MWD+IFR-AK-CAZ-SC j 1755.08 51.00 89.71 1602.40 1493.40 19.64 546.40 5945751.14 559389.87 MWD+IFR-AK-CAZ-SC 1805.44 51.68 90.37 1633.86 1524.86 19.61 585.72 5945751.42 559429.19 MWD+IFR-AK-CAZ-SC 1853.81 54.16 90.34 1663.02 1554.02 19.37 624.30 5945751.49 559467.77 MWD+IFR-AK-CAZ-SC 1902.80 54.95 90.90 1691.43 1582.43 18.94 664.21 5945751.37 559507.68 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhilhps Alaska Inc. Date: 4/11/2007 Time: 09:43:10 Pa~ae: 2 Field: Kuparu k River Unit Co-or dinate(NE) Reference: Well: 1 J-11 8, Tru e North Site: Ku paru k 1 J Pad Vertical (TVD) Reference: 1 J-113L1: 109.0 Well: 1J -118 Section (VS) Reference: Well (0-OON,O.OO E,O.OOAzi} Wellpath: 1J -118L1 Survey Calc ulation Method: Minimum C urvature Uh: Oracle S u n'e}' N#D- Inc ! azim TVI) Sys 1YD hIS E/W MapN \]aph' Tool ft deg deg ft ft ft ft ft ft 1937.72 57. 64 90.44 1710. 80 1601. 80 18. 60 693. 26 5945751. 25 559536. 72 MWD+IFR-AK-CAZ-SC 1998.89 59. 84 91.39 1742. 54 1633. 54 17. 76 745. 54 5945750. 82 559589. 00 MWD+IFR-AK-CAZ-SC i 2030.52 62. 36 91.96 1757. 83 1648. 83 16. 95 773. 21 5945750. 23 559616. 68 MWD+IFR-AK-CAZ-SC 2092.99 64. 67 94.04 1785. 69 1676. 69 14. 01 829. 04 5945747. 73 559672. 53 MWD+IFR-AK-CAZ-SC 2189.09 70. 82 95.06 1822. 07 1713. 07 6. 94 917. 66 5945741. 35 559761. 19 MWD+IFR-AK-CAZ-SC 2286.70 73. 19 95.06 1852. 22 1743. 22 -1. 24 1010. 12 5945733. 89 559853. 71 MWD+IFR-AK-CAZ-SC 2382.12 71. 05 95.20 1881. 52 1772. 52 -9. 36 1100. 57 5945726. 48 559944. 20 MWD+IFR-AK-CAZ-SC 2476.11 71. 26 93.38 1911. 88 1802. 88 -16. 02 1189. 26 5945720. 52 560032. 94 MWD+IFR-AK-CAZ-SC 2568.26 70. 85 91.35 1941. 80 1832. 80 -19. 61 1276. 34 5945717. 60 560120. 03 MWD+IFR-AK-CAZ-SC 2664.04 71. 27 92.79 1972. 89 1863. 89 -22. 89 1366. 87 5945715. 04 560210. 58 MWD+IFR-AK-CAZ-SC 2756.26 69. 10 91.04 2004. 15 1895. 15 -25. 80 1453. 58 5945712. 81 560297. 29 MWD+IFR-AK-CAZ-SC j 2847.00 69. 97 92.62 2035. 88 1926. 88 -28. 51 1538. 54 5945710. 75 560382. 27 MWD+IFR-AK-CAZ-SC 2943.26 71. 58 91.70 2067. 57 1958. 57 -31. 94 1629. 37 5945708. 04 560473. 11 MWD+fFR-AK-CAZ-SC 3039.70 70. 63 92.26 2098. 80 1989. 80 -35. 09 1720. 55 5945705. 60 560564. 31 MWD+IFR-AK-CAZ-SC 3134.18 70 .26 92.17 2130. 43 2021. 43 -38. 53 1809. 52 5945702. 86 560653. 29 MWD+IFR-AK-CAZ-SC 3200.94 68. 25 91.59 2154. 07 2045. 07 -40. 58 1871. 91 5945701. 29 560715 .69 MWD+IFR-AK-CAZ-SC ~ 3229.87 66. 58 92.72 2165. 18 2056. 18 -41. 58 1898. 60 5945700. 50 560742. 39 MWD+IFR-AK-CAZ-SC 3295.41 64. 01 92.70 2192. 57 2083. 57 -44. 40 1958. 07 5945698. 15 560801. 87 MWD+IFR-AK-CAZ-SC 3313.70 63. 85 92.94 2200. 61 2091. 61 -45. 20 1974. 48 5945697. 47 560818. 28 MWD+IFR-AK-CAZ-SC 3453.41 65. 79 93.79 2260. 05 2151. 05 -52. 63 2100. 69 5945691. 03 560944. 53 MWD+IFR-AK-CAZ-SC 3547.91 67. 44 94.37 2297. 56 2188. 56 -58. 81 2187. 20 5945685. 53 561031. 09 MWD+IFR-AK-CAZ-SC 3641.45 67 .18 94.71 2333. 64 2224. 64 -65. 64 2273. 23 5945679. 37 561117 :16 MWD+IFR-AK-CAZ-SC 3737.18 66 .21 95.04 2371. 51 2262. 51 -73. 11 2360. 83 5945672. 59 561204 .81 MWD+IFR-AK-CAZ-SC 3834.00 67 .24 92.42 2409. 78 2300. 78 -78. 88 2449. 57 5945667. 51 561293 .58 MWD+IFR-AK-CAZ-SC 3930.20 66 .62 92.98 2447. 47 2338. 47 -83. 05 2537. 98 5945664 .03 561382 .01 MWD+IFR-AK-CAZ-SC 4025.99 67 .73 92.76 2484. 63 2375. 63 -87. 47 2626. 16 5945660 .30 561470 .21 MWD+IFR-AK-CAZ-SC 4120.47 67. 61 93.16 2520. 53 2411. 53 -91. 99 2713. 44 5945656. 47 561557. 51 MWD+IFR-AK-CAZ-SC I 4213.33 66. 69 93.72 2556. 59 2447. 59 -97. 12 2798. 85 5945652. 00 561642. 96 MWD+IFR-AK-CAZ-SC 4310.21 67. 42 92.38 2594. 36 2485. 36 -101. 86 2887. 94 5945647. 96 561732. 07 MWD+IFR-AK-CAZ-SC 4404.86 67. 62 92.21 2630. 55 2521. 55 -105. 37 2975. 33 5945645. 14 561819. 47 MWD+IFR-AK-CAZ-SC 4499.68 67 .33 92.60 2666. 87 2557. 87 -109. 04 3062. 84 5945642. 15 561907. 00 MWD+IFR-AK-CAZ-SC 4591.05 67 .62 92.95 2701. 87 2592. 87 -113. 13 3147. 14 5945638. 72 561991 .32 MWD+IFR-AK-CAZ-SC 4686.19 68 .23 92.11 2737. 63 2628. 63 -117. 02 3235. 21 5945635 .52 562079 .42 MWD+IFR-AK-CAZ-SC ~ 4780.87 68 .23 88.09 2772. 76 2663. 76 -117. 17 3323. 12 5945636 .05 562167 .31 MWD+IFR-AK-CAZ-SC 4874.94 67 .42 86.84 2808. 26 2699. 26 -113. 32 3410. 14 5945640 .58 562254 .30 MWD+IFR-AK-CAZ-SC 4968.89 67 .91 83.86 2843. 97 2734. 97 -106. 27 3496. 75 5945648 .30 562340 .83 MWD+IFR-AK-CAZ-SC 5064.95 67. 63 81.22 2880. 32 2771. 32 -94. 73 3584. 90 5945660. 53 562428 .89 MWD+IFR-AK-CAZ-SC 5160.91 69 .51 76.53 2915. 40 2806. 40 -77. 48 3672. 51 5945678. 47 562516. 35 MWD+IFR-AK-CAZ-SC 5253.70 69 .49 70.42 2947. 92 2838. 92 -52. 77 3755. 79 5945703. 82 562599 .42 MWD+IFR-AK-CAZ-SC , 5351.34 69 .70 66.02 2981. 98 2872. 98 -18. 83 3840. 74 5945738. 43 562684 .10 MWD+IFR-AK-CAZ-SC 5448.46 68 .60 62.73 3016. 55 2907. 55 20. 41 3922. 56 5945778 .30 562765 .61 MWD+IFR-AK-CAZ-SC 5544.21 67 .75 57.64 3052. 17 2943. 17 64. 58 3999. 66 5945823 .06 562842 .34 MWD+IFR-AK-CAZ-SC ~ 5638.68 67 .85 53.26 3087. 88 2978. 88 114. 17 4071. 67 5945873 .21 562913 .97 MWD+IFR-AK-CAZ-SC 5735.67 68 .05 48.42 3124. 31 3015. 31 170. 91 4141. 35 5945930 .49 562983 .19 MWD+IFR-AK-CAZ-SC 5830.70 66 .10 44.27 3161. 34 3052. 34 231. 30 4204. 67 5945991 .36 563046 .03 MWD+IFR-AK-CAZ-SC 5924.22 69 .30 39.64 3196. 84 3087. 84 295. 64 4262. 46 5946056 .15 563103 .31 MWD+IFR-AK-CAZ-SC 6015.21 68 .68 35.42 3229. 47 3120. 47 362. 98 4314. 19 5946123 .88 563154 .51 MWD+IFR-AK-CAZ-SC 6110.16 67 .87 32.60 3264. 62 3155. 62 436. 08 4363. 53 5946197 .36 563203 .27 MWD+IFR-AK-CAZ-SC 6205.26 68 .40 29.72 3300. 05 3191. 05 511. 60 4409. 18 5946273 .23 563248 .33 MWD+IFR-AK-CAZ-SC 6301.73 68 .32 27.60 3335. 63 3226. 63 590. 28 4452. 19 5946352 .23 563290 .71 MWD+IFR-AK-CAZ-SC 6397.50 66 .91 23.40 3372. 11 3263. 11 670. 17 4490. 31 5946432 .41 563328 .21 MWD+IFR-AK-CAZ-SC 6492.22 66 .44 20.99 3409. 62 3300. 62 750. 70 4523. 17 5946513 .19 563360 .43 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report __ Company: ConocoPhillips Alaska Lic Field: Kuparuk River Unit Site: Kuparuk 1J Pad ' Wetl: 1J-118 N'ellpath: 1J-118U ~i Sunny i - MD lucl ,azim ft deg deg --__ 6588.77 70.38 16.05 6681.74 72.83 12.14 6777.79 74.24 7.05 6869.50 73.93 2.38 6964.12 75.87 358.76 7058.97 7154.43 7251.26 7295.62 7344.66 7385.41 7439.36 7535.83 7580.51 7632.34 7726.90 /7766.70 7805.17 7898.93 7956.90 7992.59 8085.02 8179.48 8212.68 8270.56 8364.30 8457.87 8552.21 8645.19 8739.85 8833.81 8927.37 9020.43 9114.52 9207.19 9299.74 9393.27 9486.78 9577.91 9672.46 9763.91 9857.92 9951.68 9999.90 10045.71 10138.47 10232.66 10324.79 10418.85 10512.58 10607.32 10659.02 10699.98 75.11 358.72 79.30 358.11 79.79 357.34 79.62 357.13 80.29 355.45 79.89 355.14 80.09 357.91 82.47 0.07 82.58 1.02 82.24 1.50 81.59 1.19 81.57 1.15 85.05 0.63 87.03 359.30 89.35 357.60 88.59 357.43 89.60 355.47 89.29 352.45 89.15 352.37 89.11 353.01 88.22 354.59 89.03 355.19 87.87 354.74 89.54 353.46 88.06 352.27 87.24 352.28 88.98 350.97 89.40 352.61 90.09 352.76 89.66 353.51 89.15 353.34 88.78 352.97 89.78 352.86 88.97 354.18 88.36 355.75 87.98 357.16 89.09 358.83 89.40 357.80 89.84 358.92 89.52 357.87 89.85 1.05 90.16 0.92 89.11 0.31 88.72 359.76 88.79 359.15 88.35 356.61 88.06 356.57 88.28 356.67 Date: 4/11/2007 Time: 09:43:10 Pafie: ' 3 Co-ordiuate(NE)Reference: Well: 1J-118, Tcue Ncrth Vertieal(TVD)Refcrence`.' 1J-118L1:109A Section (VS)Reference: Well (O.OON,O,OOE,O.OOAziI Survey Calculation btethod: Minimum Curvature Db: Oracle -- - __ 'I'VD Sys TVD ?SIS ft ft ft --- 3445.16 3336.16 835.79 3474.50 3365.50 921.33 3501.74 3392.74 1012.12 3526.90 3417.90 1099.99 3551.56 3442.56 1191.31 3575.32 3466.32 1283.12 3596.46 3487.46 1376.15 3614.03 3505.03 1471.30 3621.96 3512.96 1514.89 3630.51 3521.51 1563.08 3637.53 3528.53 1603.08 3646.91 3537.91 1656.11 3661.53 3552.53 1751.44 3667.34 3558.34 1795.73 3674.19 3565.19 1847.10 3687.49 3578.49 1940.69 3693.32 - 3584.32 1980.05 3697.80 3588.80 2018.25 3704.27 3595.27 2111.78 3706.10 3597.10 2169.69 3706.75 3597.75 2205.34 3708.21 3599.21 2297.58 3709.12 3600.12 2391.50 3709.57 3600.57 2424.41 3710.45 3601.45 2481.81 3712.64 3603.64 2574.97 3714.88 3605.88 2668.14 3717.43 3608.43 2762.08 3719.53 3610.53 2854.54 3721.52 3612.52 2948.44 3725.37 3616.37 3041.47 3728.46 3619.46 3133.98 3729.77 3620.77 3226.07 3730.19 3621.19 3319.39 3730.39 3621.39 3411.40 3731.35 3622.35 3503.33 3733.04 3624.04 3596.18 3734.22 3625.22 3688.97 3735.21 3626.21 3779.51 3737.41 3628.41 3873.66 3740.33 3631.33 3964.89 3742.74 3633.74 4058.81 3743.97 3634.97 4152.52 3744.29 3635.29 4200.71 3744.55 3635.55 4246.51 3745.06 3636.06 4339.25 3745.05 3636.05 4433.42 3745.64 3636.64 4525.54 3747.42 3638.42 4619.59 3749.46 3640.46 4713.29 3751.82 3642.82 4807.93 3753.44 3644.44 4859.51 3754.75 3645.75 4900.38 l1Vi` - _MapN ft ft __ _____ 4551.62 5946598.49 4573.08 5946684.19 4588.41 5946775.09 4595.66 5946863.00 4596.55 5946954.32 4594.54 5947046.10 4591.96 5947139.10 4588.18 5947234.20 4586.07 5947277.77 4582.95 5947325.93 4579.65 5947365.90 4576.43 5947418.90 4574.76 5947514.20 4575.18 5947558.50 4576.31 5947609.86 4578.51 5947703.46 4579.31 5947742.82 4579.90 5947781.02 4579.85 5947874.54 4578.28 5947932.43 4576.73 5947968.07 4571.01 5948060.25 4561.07 5948154.08 4556.69 5948186.94 4549.32 5948244.28 4539.20 5948337.35 4530.87 5948430.45 4522.59 5948524.31 4513.04 5948616.68 4501.29 5948710.48 4488.67 5948803.40 4475.05 5948895.79 4461.76 5948987.77 4449.78 5949080.98 4438.70 5949172.89 4428.11 5949264.73 4416.96 5949357.48 4405.43 5949450.16 4395.14 5949540.61 4386.85 5949634.69 4381.20 5949725.86 4377.91 5949819.74 4375.15 5949913.42 4373.77 5949961.60 4372.49 5950007.37 4371.62 5950100.10 4373.23 5950194.28 4374.22 5950286.39 4374.28 5950380.42 4373.39 5950474.11 4369.89 5950568.71 4366.81 5950620.26 4364.40 5950661.10 11apF. Tool 563388.21 MWD+IFR-AK-CAZ-SC 563409.00 MWD+IFR-AK-CAZ-SC 563423.62 MWD+IFR-AK-CAZ-SC 563430.18 MWD+IFR-AK-CAZ-SC 563430.36 MWD+IFR-AK-CAZ-SC 563427.63 MWD+IFR-AK-CAZ-SC 563424.32 MWD+IFR-AK-CAZ-SC 563419.80 MWD+IFR-AK-CAZ-SC 563417.35 MWD+IFR-AK-CAZ-SC 563413.85 MWD+IFR-AK-CAZ-SC 563410.25 MWD+IFR-AK-CAZ-SC 563406.61 MWD+IFR-AK-CAZ-SC 563404.19 MWD+IFR-AK-CAZ-SC 563404.27 MWD+IFR-AK-CAZ-SC 563405.00 MWD+IFR-AK-CAZ-SC 563406.46 MWD+IFR-AK-CAZ-SC 563406.96 MWD+IFR-AK-CAZ-SC 563407.25 MWD+IFR-AK-CAZ-SC 563406.47 MWD+IFR-AK-CAZ-SC 563404.45 MWD+IFR-AK-CAZ-SC 563402.62 MWD+IFR-AK-CAZ-SC I 563396.18 MWD+IFR-AK-CAZ-SC ' 563385.51 MWD+IFR-AK-CAZ-SC 563380.87 MWD+IFR-AK-CAZ-SC 563373.05 MWD+IFR-AK-CAZ-SC 563362.21 MWD+IFR-AK-CAZ-SC 563353.15 MWD+IFR-AK-CAZ-SC 563344.14 MWD+IFR-AK-CAZ-SC 563333.86 MWD+IFR-AK-CAZ-SC 563321.38 MWD+IFR-AK-CAZ-SC 563308.03 MWD+IFR-AK-CAZ-SC 563293.69 MWD+IFR-AK-CAZ-SC 563279.69 MWD+IFR-AK-CAZ-SC 563266.98 MWD+IFR-AK-CAZ-SC 563255.18 MWD+IFR-AK-CAZ-SC 563243.87 MWD+IFR-AK-CAZ-SC 563232.00 MWD+IFR-AK-CAZ-SC I 563219.74 MWD+IFR-AK-CAZ-SC 563208.75 MWD+IFR-AK-CAZ-SC 563199.72 MWD+IFR-AK-CAZ-SC 563193.36 MWD+IFR-AK-CAZ-SC 563189.34 MWD+IFR-AK-CAZ-SC 563185.85 MWD+IFR-AK-CAZ-SC 563184.09 MWD+IFR-AK-CAZ-SC I 563182.45 MWD+IFR-AK-CAZ-SC 563180.85 MWD+IFR-AK-CAZ-SC 563181.74 MWD+IFR-AK-CAZ-SC 563182.01 MWD+IFR-AK-CAZ-SC 563181.33 MWD+IFR-AK-CAZ-SC 563179.71 MWD+IFR-AK-CAZ-SC 563175.46 MWD+IFR-AK-CAZ-SC 563171.99 MWD+IFR-AK-CAZ-SC 563169.25 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report " Company: ConocoPhillips Alaska Inc. Date: 4/11/2007 Time: 09:43:10 Page: d Field: Kuparuk River Unit Co-ordinate(NE} Reference: Well: 1J-118, True Notth Sitc KuparuklJPad ~'criical(TVp)Referencr. 1J-11$L1: 109.0 i ~~cll: 1J-118 SeciiunrVS)Reference: Well {O.OON,O.OOE,O.QOAzi) i ~~cll~inrh: 1J-11811 5ar~~c.talculationDlethod: Minimum Curvature D6: Oracle ~urvcv J1D' Intl Azim TVD Sys TVD N/S E/W iV1apN ~IapE: Tool ft deg deg ft ft ft ft ft ft 10747.26 88.22 358.77 3756.19 3647.19 4947.60 4362.52 5950708.30 563167.01 MWD+IFR-AK-CAZ-SC 10793.53 88.41 359.38 3757.55 3648.55 4993.84 4361.77 5950754.53 563165.90 MWD+IFR-AK-CAZ-SC lid 10841.98 88.12 359.98 3759.02 3650.02 5042.27 4361.50 5950802.95 563165.25 MWD+IFR-AK-CAZ-SC 10886.95 89.65 0.30 3759.89 3650.89 5087.23 4361.61 5950847.91 563165.01 MWD+IFR-AK-CAZ-SC 10979.65 90.14 359.43 3760.06 3651.06 5179.93 4361.39 5950940.59 563164.07 MWD+IFR-AK-CAZ-SC 11027.35 90.40 359.81 3759.84 3650.84 5227.62 4361.08 5950988.28 563163.38 MWD+IFR-AK-CAZ-SC 11073.45 90.14 1.78 3759.62 3650.62 5273.72 4361.72 5951034.37 563163.66 MWD+IFR-AK-CAZ-SC ~ 11165.64 90.01 3.43 3759.50 3650.50 5365.81 4365.91 5951126.48 563167.13 MWD+IFR-AK-CAZ-SC 11259.89 90.38 2.26 3759.18 3650.18 5459.94 4370.58 5951220.64 563171.07 MWD+IFR-AK-CAZ-SC 11353.48 89.83 1.80 3759.01 3650.01 5553.47 4373.90 5951314.19 563173.65 MWD+IFR-AK-CAZ-SC 11445.93 91.25 1.41 3758.14 3649.14 5645.88 4376.49 5951406.60 563175.52 MWD+IFR-AK-CAZ-SC 11539.67 90.51 2.51 3756.70 3647.70 5739.55 4379.69 5951500.29 563177.99 MWD+IFR-AK-CAZ-SC 11632.26 89.90 1.82 3756.37 3647.37 5832.07 4383.19 5951592.82 563180.77 MWD+IFR-AK-CAZ-SC 11726.16 89.48 1.37 3756.88 3647.88 5925.93 4385.81 5951686.69 563182.65 MWD+IFR-AK-CAZ-SC 11805.50 90.53 1.13 3756.87 3647.87 6005.25 4387.54 5951766.02 563183.76 MWD+IFR-AK-CAZ-SC 11911.15 88.37 1.10 3757.88 3648.88 6110.87 4389.59 5951871.64 563184.99 MWD+IFR-AK-CAZ-SC 12004.84 88.55 0.90 3760.40 3651.40 6204.51 4391.23 5951965.28 563185.89 MWD+IFR-AK-CAZ-SC i 12099.16 89.47 0.65 3762.03 3653.03 6298.81 4392.50 5952059.58 563186.43 MWD+IFR-AK-CAZ-SC 12193.24 90.08 0.31 3762.40 3653.40 6392.89 4393.29 5952153.65 563186.48 MWD+IFR-AK-CAZ-SC j 12227.14 89.69 0.51 3762.47 3653.47 6426.78 4393.53 5952187.54 563186.46 MWD+IFR-AK-CAZ-SC ', 12272.90 89.01 1.70 3762.99 3653.99 6472.53 4394.42 5952233.29 563186.98 MWD+IFR-AK-CAZ-SC 12367.96 90.00 1.31 3763.81 3654.81 6567.55 4396.91 5952328.32 563188.74 MWD+IFR-AK-CAZ-SC 12462.06 88.95 359.48 3764.67 3655.67 6661.64 4397.56 5952422.40 563188.65 MWD+IFR-AK-CAZ-SC 12555.37 88.03 358.17 3767.13 3658.13 6754.90 4395.65 5952515.63 563186.01 MWD+IFR-AK-CAZ-SC 12649.58 89.38 358.42 3769.26 3660.26 6849.04 4392.85 5952609.74 563182.47 MWD+IFR-AK-CAZ-SC 12742.74 88.09 357.00 3771.32 3662.32 6942.10 4389.13 5952702.76 563178.02 MWD+IFR-AK-CAZ-SC 12835.96 88.77 356.14 3773.87 3664.87 7035.12 4383.55 5952795.72 563171.72 MWD+IFR-AK-CAZ-SC 12929.57 88.52 357.16 3776.08 3667.08 7128.54 4378.08 5952889.09 563165.52 MWD+IFR-AK-CAZ-SC 13023.41 89.01 359.92 3778.11 3669.11 7222.32 4375.69 5952982.83 563162.40 MWD+IFR-AK-CAZ-SC 13114.53 89.75 0.18 3779.09 3670.09 7313.43 4375.77 5953073.94 563161.77 MWD+IFR-AK-CAZ-SC 13209.34 90.00 359.95 3779.30 3670.30 7408.24 4375.88 5953168.74 563161.14 MWD+IFR-AK-CAZ-SC 13302.13 92.72 1.66 3777.10 3668.10 7500.98 4377.18 5953261.48 563161.71 MWD+IFR-AK-CAZ-SC 13396.46 92.66 1.23 3772.67 3663.67 7595.18 4379.56 5953355.68 563163.35 MWD+IFR-AK-CAZ-SC i 13489.69 89.14 0.64 3771.21 3662.21 7688.37 4381.08 5953448.87 563164.15 MWD+IFR-AK-CAZ-SC i 13581.22 87.04 1.06 3774.26 3665.26 7779.83 4382.43 5953540.33 563164.79 MWD+IFR-AK-CAZ-SC ~i 13674.95 88.40 2.02 3777.98 3668.98 7873.45 4384.95 5953633.96 563166.57 MWD+IFR-AK-CAZ-SC II 13768.73 87.10 3.22 3781.67 3672.67 7967.06 4389.23 5953727.59 563170.12 MWD+IFR-AK-CAZ-SC i 13862.74 88.89 1.35 3784.96 3675.96 8060.93 4392.98 5953821.47 563173.13 MWD+IFR-AK-CAZ-SC 13951.72 89.14 358.48 3786.49 3677.49 8149.88 4392.85 5953910.42 563172.31 MWD+IFR-AK-CAZ-SC 14042.52 88.52 356.56 3788.34 3679.34 8240.58 4388.92 5954001.07 563167.67 MWD+IFR-AK-CAZ-SC 14132.77 87.47 354.59 3791.50 3682.50 8330.50 4381.96 5954090.92 563160.01 MWD+IFR-AK-CAZ-SC 14223.80 88.70 356.71 3794.54 3685.54 8421.21 4375.06 5954181.57 563152.40 MWD+IFR-AK-CAZ-SC 14314.10 88.89 359.26 3796.44 3687.44 8511.42 4371.89 5954271.75 563148.53 MWD+IFR-AK-CAZ-SC 14404.97 89.69 1.40 3797.57 3688.57 8602.28 4372.41 5954362.60 563148.34 MWD+IFR-AK-CAZ-SC 14495.87 88.89 358.97 3798.69 3689.69 8693.16 4372.71 5954453.47 563147.92 MWD+IFR-AK-CAZ-SC 14586.67 89.75 0.32 3799.77 3690.77 8783.95 4372.14 5954544.24 563146.65 MWD+IFR-AK-CAZ-SC 14676.98 89.57 0.42 3800.31 3691.31 8874.26 4372.73 5954634.54 563146.53 MWD+IFR-AK-CAZ-SC 14757.01 88.71 0.21 3801.51 3692.51 8954.28 4373.17 5954714.56 563146.34 MWD+IFR-AK-CAZ-SC i 14795.00 88.71 0.21 3802.36 3693.36 8992.26 4373.31 5954752.53 - 563146.19 ~ PROJECTED to TD r~ 1J-118'B' Sand Liner Detail well: 1J-118L2 4-1f2" Slotted and Blank Liner Date: 3/3/2003 ~~'~~~~~~~~~~~"~ PLOP & DROP AEdska: lric. DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 1 LENGTH TOPS 7961.00 _ 7961.00 7961.00 ~~ 7961.00 7961.00 7961.00 XO to DP 7961.00 Running Tool (Does not stay in hole) 7961.00 Baker "HR" Liner Setting Sleeve, 5 1/2" ID 5.01" 15.17 7961.00 Baker Liner Nipple, 5.55" OD x" 4.99" ID 1.40 7976.17 5 1/2" H521, 15.5 ppf, L-80 Pup Jt ID 4.89" 3.68 7977.57 5 1/2" Hydril 521, 15.5 ppf L-80 Receptacle Jt ID 4.97" 41.77 7981.25 5-1/2" H521 x 4-1/2" H521 Crossover Bushing ID 3.96" 1.40 8023.02 4-1/2", 11.6ppf, L-80 H521 Pup Joint ID 3.96" 3.79 8024.42 Jts 163 to 163 1 Jts 4-1/2" Hydril 521, 11.6 ppf, L-80 Slotted Casing 40.90 8028.21 Jts 162 to 162 1 Jts 4-1/2" Hydril 521, 11.6 ppf, L-80 Slotted Casing 42.20 8069.11 Jts 161 to 161 1 Jts 4-1/2" Hydril 521, 11.6 ppf, L-80 Blank Casing 40.63 .8111.31 Jts 160 to 160 1 Jts 4-1/2" Hydril 521, 11.6 ppf, L-80 Slotted Casing 41.95 8151.94 Jts 159 to 159 1 Jts 4-1/2" Hydril 521, 11.6 ppf, L-80 Blank Casing 41.91 8193.89 Jts 158 to 158 1 Jts 4-1 /2" Hydril 521, 11.6 ppf, L-80 Slotted Casing 40.97 8235.80 Jts 157 to 157 1 Jts 4-1/2" Hydril 521, 11.6 ppf, L-80 Blank Casing 41.12 8276.77 Jts 156 to 156 1 Jts 4-1/2" Hydril 521, 11.6 ppf, L-80 Slotted Casing 41.13 8317.89 Jts 155 to 155 1 Jts 4-1/2" Hydril 521, 11.6 ppf, L-80 Blank Casing 41.27 8359.02 Jts 154 to 154 1 Jts 4-1/2" Hydril 521, 11.6 ppf, L-80 Slotted Casing 42.04 8400.29 Jts 153 to 153 1 Jts 4-1 /2" Hydril 521, 11.6 ppf, L-80 Blank Casing 41.90 8442.33 Jts 152 to 152 1 Jts 4-1 /2" Hydril 521, 11.6 ppf, L-80 Slotted Casing 42.18 8484.23 Jts 151 to 151 1 Jts 4-1/2" Hydril 521, 11.6 ppf, L-80 Blank Casing 41.64 8526.41 Jts 150 to 150 1 Jts 4-1/2" Hydril 521, 11.6 ppf, L-80 Slotted Casing 36.82 8568.05 Jts 149 to 149 1 Jts 4-1/2" Hydril 521, 11.6 ppf, L-80 Blank Casing 41.69 8604.87 Jts 148 to 148 1 Jts 4-1/2" Hydril 521, 11.6 ppf, L-80 Slotted Casing 41.60 8646.56 Jts 147 to 147 1 Jts 4-1/2" Hydril 521, 11.6 ppf, L-80 Blank Casing 41.35 8688.16 Jts 146 to 146 1 Jts 4-1/2" Hydril 521, 11.6 ppf, L-80 Slotted Casing 42.05 8729.51 Jts 141 to 145 5 Jts 4-1/2" Hydril 521, 11.6 ppf, L-80 Blank Casing 201.79 8771.56 Jts 139 to 140 2 Jts 4-1/2" Hydril 521, 11.6 ppf, L-80 Slotted Casing 84.08 8973.35 Jts 138 to 138 1 Jts 4-1/2" Hydril 521, 11.6 ppf, L-80 Blank Casing 38.67 9057.43 Jts 136 to 137 2 Jts 4-1/2" Hydril 521, 11.6 ppf, L-80 Slotted Casing 84.00 9096.10 Jts 135 to 135 1 Jts 4-1 /2" Hydril 521, 11.6 ppf, L-80 Blank Casing 41.30 9180.10 Jts 134 to 134 1 Jts 4-1/2" Hydril 521, 11.6 ppf, L-80 Slotted Casing 42.14 9221.40 Ran total of 62 jts Blank = 2599.99' and 102 jts Blank= 4155.25' ,Slots are On Btm Up Wt 200K w/ (32) 2.5" long x .125" 4 Circumferential adjacent rows, 3" Centers Rotating Wt 95K staggered 18 deg., 3 ft. non-slotted ends Rot Dn Wt 55K 163 stop rings ~ Hydraform Cent's, middle of jt floating, 80 Torque rings on Block Wt 35K Jts #54 thru 133 Liner & running tool only, up wt 88K, do wt 60K ~ Used Run-N-Seal thread compound on all connections. All drifted w/ 3.875" rabbit. Supervisors: Guy Whitlock /Peter Wilson /Dan Lowe • 1 Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 2 LENGTH TOPS Crossover 4-1/2" Hydril 521 box x 4-1/2" BTC pin 1.65 9263.54 Jts 133 to 133 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Blank Casing 42.69 9265.19 Jts 132 to 132 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Slotted Casing 43.20 9307.88 Jts 131 to 131 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Blank Casing 42.32 9351.08 Jts 130 to 130 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Slotted Casing 43.29 9393.40 Jts 124 to 129 s Jts 4-1/2" 11.6 ppf, L-80 BTC Blank Casing 244.57 9436.69 Jts 123 to 123 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Slotted Casing 42.77 9681.26 Jts 122 to 122 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Blank Casing 40.38 9724.03 Jts 121 to 121 1 Jts 4-1 /2" 11.6 ppf, L-80 BTC Slotted Casing 43.04 9764.41 Jts 120 to 120 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Blank Casing 42.86 9807.45 Jts 119 to 119 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Slotted Casing 42.92 9850.31 Jts 118 to 118 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Blank Casing 40.35 9893.23 Jts 117 to 117 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Slotted Casing 36.87 9933.58 Jts 116 to 116 1 Jts 4-1 /2" 11.6 ppf, L-80 BTC Blank Casing 41.96 9970.45 Jts 115 to 115 1 Jts 4-1 /2" 11.6 ppf, L-80 BTC Slotted Casing 39.64 10012.41 Jts 114 to 114 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Blank Casing 42.87 10052.05 Jts 113 to 113 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Slotted Casing 42.86 10094.92 Jts 107 to 112 6 Jts 4-1/2" 11.6 ppf, L-80 BTC Blank .Casing 255.92 10137.78 Jts 106 to 106 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Slotted Casing 43.04 10393.70 Jts 105 to 105 1 Jts 4-1 /2" 11.6 ppf, L-80 BTC Blank Casing 40.30 10436.74 Jts 104 to 104 1 Jts 4-1 /2" 11.6 ppf, L-80 BTC Slotted Casing 42.86 10477.04 Jts 103 to 103 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Blank Casing 42.90 10519.90 Jts 102 to 102 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Slotted Casing 40.42 10562.80 Jts 101 to 101 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Blank Casing 42.82 10603.22 Jts 10o to 100 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Slotted Casing 43.40 10646.04 Jts 99 to 99 1 Jts 4-1 /2" 11.6 ppf, L-80 BTC Blank Casing 42.86 10689.44 Jts 98 to 98 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Slotted Casing 42.95 10732.30 Jts 97 to 97 1 Jts 4-1 /2" 11.6 ppf, L-80 BTC Blank Casing 38.39 10775.25 Jts 96 to 96 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Slotted Casing 43.28 10813.64 Jts 90 to 95 6 Jts 4-1 /2" 11.6 ppf, L-80 BTC Blank Casing 249.20 10856.92 Jts 89 to 89 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Slotted Casing 43.08 11106.12 Jts 88 to 88 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Blank Casing 42.81 11149.20 Jts 87 to 87 1 Jts 4-1 /2" 11.6 ppf, L-80 BTC Slotted Casing 42.85 11192.01 Jts 86 to 86 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Blank Casing 37.24 11234.86 Jts 85 to 85 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Slotted Casing 43.03 11272.10 Jts 84 to 84 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Blank Casing 43.20 11315.13 Jts 83 to 83 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Slotted Casing 41.64 11358.33 Jts 82 to 82 1 Jts 4-1 /2" 11.6 ppf, L-80 BTC Blank Casing 43.19 11399.97 Remarks: Joints # 54 through 133 (80 joints) will have torque-rings installed All joints will have a stopring install in the middle of the joint with aHydro-form centralizer below it. The first 7 slotted joints have the old style 2-blade hydroforms and the rest of the slotted and blankjoints have the new style 3-blade hydoform centralizers. • 1 Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 3 LENGTH TOPS Jts 81 to 81 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Slotted Casing 36.98 11443.16 Jts 8o to 80 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Blank Casing 42.91 11480.14 Jts 79 to 79 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Slotted Casing 40.89 11523.05 Jts 73 to 78 6 Jts 4-1 /2" 11.6 ppf, L-80 BTC Blank Casing 253.83 11563.94 Jts 72 to 72 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Slotted Casing 42.53 11817.77 Jts 71 to 71 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Blank Casing 42.10 11860.30 Jts 7o to 70 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Slotted Casing 43.07 11902.40 Jts 69 to 69 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Blank Casing 39.93 11945.47 Jts 68 to 68 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Slotted Casing 42.89 11985.40 Jts 67 to 67 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Blank Casing 40.17 12028.29 Jts 66 to 66 1 Jts 4-1 /2" 11.6 ppf, L-80 BTC Slotted Casing 43.02 12068.46 Jts 65 to 65 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Blank Casing 42.91 12111.48 Jts 64 to 64 1 Jts 4-1 /2" 11.6 ppf, L-80 BTC Slotted Casing 42.90 12154.39 Jts 63 to 63 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Blank Casing 39.47 12197.29 Jts 62 to 62 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Slotted Casing 42.65 12236.76 Jts 56 to 61 6 Jts 4-1/2" 11.6 ppf, L-80 BTC Blank Casing 240.14 12279.41 Jts 55 to 55 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Slotted Casing 43.06 12519.55 Jts 54 to 54 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Blank Casing 37.55 12562.61 Jts 53 to 53 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Slotted Casing 43.62 12600.16 Jts 52 to 52 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Blank Casing 38.25 12643.78 Jts 51 to 51 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Slotted Casing 43.07 12682.03 Jts 50 to 50 1 Jts 4-1 /2" 11.6 ppf, L-80 BTC Blank Casing 40.30 12725.10 Jts 49 to 49 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Slotted Casing 37.05 12765.40 Jts 48 to 48 1 Jts 4-1 /2" 11.6 ppf, L-80 BTC Blank Casing 40:21 12802.45 Jts 47 to 47 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Slotted Casing 43.04 12842.66 Jts 46 to 46 1 Jts 4-1 /2" 11.6 ppf, L-80 BTC Blank Casing 37.62 12885.70 Jts 45 to 45 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Slotted Casing 43.15 12923.32 Jts 39 to 44 6 Jts 4-1/2" 11.6 ppf, L-80 BTC Blank Casing 235.22 12966.47 Jts 38 to 38 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Slotted Casing 44.23 13201.69 Jts 37 to 37 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Blank Casing 40.10 13245.92 Jts 36 to 36 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Slotted Casing 41.69 13286.02 Jts 35 to 35 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Blank Casing 37.35 13327.71 Jts 34 to 34 1 Jts 4-1 /2" 11.6 ppf, L-80 BTC Slotted Casing 43.05 13365.06 Jts 33 to 33 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Blank Casing 39.82 13408.11 Jts 32 to 32 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Slotted Casing 39.23 13447.93 Jts 31 to 31 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Blank Casing 40.13 13487.16 Jts 3o to 30 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Slotted Casing 43.06 13527.29 Jts 29 to 29 1 Jts 4-1 /2" 11.6 ppf, L-80 BTC Blank Casing 40.12 13570.35 Remarks: • • Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 4 LENGTH TOPS Jts 28 to 28 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Slotted Casing 43.05 13610.47 Jts 22 to 27 6 Jts 4-1/2" 11.6 ppf, L-80 BTC Blank Casing 228.75 13653.52 Jts 21 to 21 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Slotted Casing 42.86 13882.27 Jts 20 to 20 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Blank Casing 41.76 13925.13 Jts 19 to 19 1 Jts 4-1/2" 11.6 ppf,- L-80 BTC Slotted Casing 43.30 13966.89 Jts 18 to 18 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Blank Casing 42.78 14010.19 Jts 17 to 17 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Slotted Casing 40.47 14052.97 Jts 16 to 16 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Blank Casing 40.07 14093.44 Jts 15 to 15 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Slotted Casing 43.63 14133.51 Jts 14 to 14 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Blank Casing 40.32 14177.14 Jts 13 to 13 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Slotted Casing 43.28 14217.46 Jts 12 to 12 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Blank Casing 42.93 14260.74 Jts 11 to 11 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Slotted Casing 43.39 14303.67 Jts 5 to 10 6 Jts 4-1/2" 11.6 ppf, L-80 BTC Blank Casing 240.71 14347.06 Jts 4 to 4 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Slotted Casing 42.67 14587.77 Jts 3 to 3 1 Jts 4-1/2" 11.6 ppf, L-80 BTC Blank Casing 37.73 14630.44 Jts 1 to 2 2 Jts 4-1/2" 11.6 ppf, L-80 BTC Slotted Casing 85.81 14668.17 Crossover 4-1/2" BTC box x 4-1 /2" IBT pin 2.05 14753.98 4-1/2" 12.6 ppf, L-80 IBT Blank Casing 30.05 14756.03 4 1/2" Float shoe 1.60 14786.08 14787.68 6-3/4" hole drilled to 14,795' M.D. (7.32' of rathole) COMPLETE DESCRIPTION OF EQUIPMENT RUN Remarks: ~~ ~®leTS~~t'QA7i`I®1dT C®M~II5SI®laT Robert D. Christensen Production Engineering Technician ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1J-118L1 Sundry Number: 307-148 Dear Mr. Christensen: 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~~ Dan T. Seamount Commissioner DATED this day of May, 2007 Encl. SARAH PALIAI, GOVERPIOR ~ti ~ ~s,z,~~ ~ I~E~EIVED ~/ STATE OF ALASKA ~ APR 3 ~ ZO07 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL Alaska Oil & Gas Cons. Commission 20 AAC 25.280 Anchorage 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^/ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Chan e a roved ro ram g pp p g ^ Pull Tubing ^ Perforate New Pool ^ Producer to -- Re-enter Suspended Well ^ Injector 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development^ ~- Exploratory ^ 206-177 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23337-60 "~ 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Y@S ^ NO Q 1J-118L1 9. Property Designation: it ~pL ZS7®~- ~ ~ ~~- Z~sU K k Ri U 10. KB Elevation (ft): 11. Field/Pool(s): ld /W k Oil P l k Ri Fi t S K uparu ver n RKB 109' uparu ver e es a oo 12. '` 07 PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD ): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14795' 3803' 14787' 3802' Casing Length Size MD ND Burst Collapse CONDUCTOR g0' 20" 108' 108' SURFACE 3249' 10-3/4" 3358' 2221' INTERMEDIATE 8840' 7-5/8" 8949' 3729' WINDOW L2 1' 7-5/8" 72p8' 3606' WINDOW L1 1' 7-5/8" 7767' 3694' Slotted Liner 7280' 5-1/2" x 4-1/2" 14788' 3802' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): $028' - 14753' 3707' -3802' 4-1 /2" L-80 7190' Packers and SSSV Type: Packers and SSSV MD (ft} PKRS = BAKER'ZXP' LINER TOP PACKERS PKRS = 7146'; 7312'; 7851' SSSV= NIP SSSV= 503' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service^ `° 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: May 7, 2007 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ~ - WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob Christensen /Bob Buchholz Printed Name o rt D. istense Title: Production En ineering Technician Signature Phone 659-7535 Date ~~(p Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness a~-" !~~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ Other: ~~C~~<~nS ~ "~. C~C~~ ~ r ~L~ ~- ` - ~ J t _ ~~~.. tn,~~ ~~ ~~ 2007 Subsequent Form Required: Ltvt~ APPROVED BY ~ '7 4' Approved by: OMMISSIONER THE COMMISSION Date: Form 10-403 I'~evised 06/2006 ~`4 ~ L1 ~ 1-~ ~ I\~ (,j i ~u_br}i~ ip Dup~e~~.D' / ~• 1J-118L1 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to begin Water Injection service in West Sak Tri- lateral Well 1 J-118L1. This well has been pre-produced for 30 days in order to recover Oil based drilling fluids prior to putting the well on injection. 1 J-118L1 will provide pressure support for the West Sak B sands. The 10-3/4" Surface casing (3358' and / 2221' tvd) was cemented with 575 sx AS Lite followed by 180 sx LiteCRETE. The 7-5/8" Intermediate casing (8949' and / 3867' tvd) was cemented with 525 sx DeepCRETE. The injection tubing/casing annulus is isolated via the following: Upper D sand ZXP 5-1/2" x 7- 5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 7146' and / 3595' tvd, Upper B sand ZXP 5-1/2" x 7-5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 7312' and / 3625' tvd, and an Upper A sand ZXP 5-1/2" x 7-5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 7851' and / 3706' tvd. The top of West Sak D sand was found at 7207' and / 3606' tvd. D sand Lateral window top is located @ 7207' and / 3606' tvd. The top of West Sak B sand was found at 7763' and / 3693' tvd. B sand Lateral window top is located @ 7766' and / 3693' tvd. The top of West Sak A sand was found at 8902' and / 3867' tvd. LOCATOR (7162-7164, OD:5.500) SEAL plea-71so, OD:4.740) Perf (8028-14753) TERMEDIATE (08949, OD:7.625, Wt:29.70) ConocoPhillips Alaska, Inc. KRU 1J-118L1 1J-118L1 API: 500292333760 Well Type_ SVC Angle TS: deg @ SSSV Type: __ NIPPLE Orig Com letion: 3/20/2007 _ __ _ Angle @ TD: .. _ _ .. 89 deg @ 14795 Annular Fluid: Last W/O: Rev Reason: NEW GLD DESIGN Reference L 28' RKB Ref Lo Date: Last U ate: 4!2/2007 Last Tag: TD: 14795 ft_KB Last Ta Date: Max Hole An le: 93 de 13302 Casing_Strin -ALL STRINGS De_ s_ cription Size To Bottom TVD Wt Grade Thread _ _ CONDUCTOR 20.000 0 80 80 94.00 K55 WELD I I SURFACE 10.750 0 3358 2219 45.50 L-80 BTC - -- INTERMEDIATE 7.625 0 8949 3729 29.70 L-80 BTC-M WINDOW L2 7.625 7207 7208 3606 0.00 WINDOW L1 7.625 7766 7767 3694 0.00 B-SAND LINER TOP 4.500 7779 7978 3707 11.60 L-80 BTC B-SAND LINER TOP 5.500 - 7978 8024 3707 15.50 L-80 H521 B-SAND LINER BOTTOM - 4.500 - 8024 - 14788 3802 11.60 L-80 BTC Tubin Strin -TUBING Size To Bottom TVD Wt Grade Thread 4.500 0 7180 3601 12.60 L-80 IBT Pertorations Summa Interval TVD Zone Status _ _ _Ft_ SPF Date Type Comment 8028 - 14753 3707 - 3802 WS B 6725 32 3/4/2007 SLOTS Alternatin solid/slotted i e Gas lift MandrelsNalves St MD TVD _ Man Mfr Man Type V Mfr V Type _ V OD ---- Latch --- Port TRO _ mate Run - Vlv Cmnt 1 _2173 1816 CAMCO KBMG _ GLV 1.0 BK-5 0.156 1430 3/31/2007 2 6008 3227 CAMCO KBMG DMY 1.0 BK-5 0.000 0 3/19/2007 Other - lu s, a ui ., etc -- .) -_COMPLETION - De th ND _Type- Description ID 23 _ 23 HANGER TUBING HANGER 4.500 503 503 NIP CAMCO'DB' NIPPLE 3.875 7110 3587 SLEEVE-O BAKER CMD SLIDING SLEEVE -RUN OPEN - 3.810 7162 j 3598 LOCATOR BAKER LOCATOR 3.880 ' 7164 13598 SEAL ___ BAKER GBH-22 LOCATING SEAL ASSEMBLY 3.880 Other_ l plugs, e__ u(LQ~c .~ - LIN_ ER DETAIL De th- ND I _ Type Description - - -- ID 7146 3595 PACKER -- D-SAND LEM LINER TOP PACKER 4.950 7165 3598 SBR D-SAND LEM 109-47 CASING SEAL BORE 4.750 7185 3602_ XO D-SAND LEM CROSSOVER BUSHING 3.910 7194__ 3604 HANGER D-SAND LEM ABOVE HOOK HANGER 3.980 7201 3605 HANGER D-SAND LEM INSIDE HOOK HANGER 3.688 7312 3625 PACKER B-SAND LEM ZXP LINER TOP PACKER 4.950 7331 3628 SBR B-SAND LEM 109-47 CASING SEAL BORE 4.750 7351 _3632 XO B-SAND LEM CROSSOVERBUSHING 3.940 7753 3691 HANGER B-SAND LEM ABOVE HOOK HANGER 3.940 7763 3693 HANGER _ B-SAND LEM INSIDE HOOK HANGER 3.688 7779__ 3695 HANGER B-SAND BAKER MODEL PZ H_O_OK HANGER OUTSIDE 3.970 7832 3700 PACKER B-SAND BAKER PAYZONE EXTERNAL CASING PACKER 3.920 7961 3706 SLEEVE B-SAND BAKER'HR' LINER SETTING SLEEVE 5.040 7976 3707 NIP B-SAND BAKER LINER NIPPLE 4.990 8023 3707 XO B-SAND CROSSOVER BUSHING 3.940 14786 3802 SHOE B-SAND FLOAT SHOE 3.958 General Notes Date Note 3/20/2007 NOTE: MULTI-LATERAL WELL- 1J-118 A-SAND , 1J-118L1 B-SAND , 1J-118L2 D-SAND I I t `~'CNF.hIC~L INTF,GRIT"=`.PORT s ~~~_ r ~-- ~~. ~~~ '~ ~~~ =._c ..~~~: ~~ . ;.ALL N~~R 1 ~~-\~.~ - L~ - ~~- "~~LL DST T~. 1`'I~~~S?~ ~~t~`S TVD; =BTD: 1~1~~~ ?ID 3~5~ TVD '`145 Shoe:Y'a~_t-II) ~~~,1 Tti~ ; li V : N ~- ?~ ~ ~~ T~r~i Casi^g ~.~ ~_-:e=. Shoe: '~ TyL; .CP : ~'i~ ~ ~~ i' _ ~o~,v ~r ~~ PaCKer 1i4~ :~ T'nj, CeC cL e _ e G11Q ~ oT~~ :~,Cra1~=~~~ IZITEGRET`~ - ?a,RT #z Comments : ~ ~ t ~ ~ ~ ~ -4~s~~ ~~ ~ tS ~ ~h~y~ v °~ ~® ~-~ ~ DSf ~ ~nr_uius Press Test: _? ~5 min ~0 min '~'CHANICr' ~, INTEGRIT'*' _ PART #Z ~---~C:~~~j -~a~h`o~S Cement Volumes :" ~~t. Liner Cs~5545.,t DV 1~8"~ C~.t -JOi to cover oers ~.~OZc ~S ~~~~k. h~~~ ~ c©~cc L ~- ~+v~~c~~ iJS ~~~~ ~ f __ eoretical TCC ~ ~Z~ ~~ T~ C. = `-~ S~C~ Cement Bond Log (Yes or No) ~~~ In AOGCC File ~~5 C3L evaluation, gone above perks Production 'Log: Type CONCLJS ~ Ot1S Part #l: 7 ` 12 dl f ~ ~ ~.c~ Evalu~ti on ~~~'(S/a-~o'l RE: tJ-1 l8 Intermediate Casing Bond Log Subject: AE: 1J-118. Intermediate using Bond Log From: "Hartwig, Dennis D"Dennis.D.Hartwig@conocophillips.com> Date: Mori, 05 NIar 2007 12:12:23 -090® To: Thomas Maunder <tom..maunder@admin.stateak.us> Tom, ~Q fQ ` \~ 1 1 sat down with Robin Smyth (schlumberger} this morning and revisited the USIT log from the 1J-118 Intermediate. Robin's interpretation is as follows; Excellent zonal isolation between the West-Sak Production intervals ie...A2, B, & D O A2 top at Aproximately 8899'md O B top @ approximately 7763'md O D top at approximately 7201'md Further, O Cement bond across the B window (7766-7779'md) was goad, but not excellent and same for the D-window (7201-7214'md) O Zonal isolation Between the Upper West Sak (West Sak D - 7201'md) production interval and the Ugnu sands (Ugnu A - 6445'md} is excellent. O Zonal Isolation between the Ugnu Intervals including the upper most hydrocarbon contact (Ugnu C- 5485'md) is also excellent. o Ugnu Atop - 6445'md o Ugnu Btop - 6364'md o Ugnu Ctop - 5485'md O In excess of 500' of excellent cement bond above the Ugnu C. Your other question related to reciprocating the drill-string during cementation. It is my understanding that once the cement turned the corner no reciprocation was possible. Please contact me if I may provide further information. Regards... Dennis Dennis Hartwig Drilling Engineer ConocoPhillips Alaska, Inc. Office :907-265-6862 Cell :907-980-1433 Fax :907-265-1535 -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Friday, March 02, 2007 7:55 AM To: Hartwig, Dennis D Subject: Re: 1J-118 Intermediate Casing Bond Log 1 oft 5/1/2007 11:20 AM RE: IJ-I 18 Intermediate Casing Bond Log Dennis, Thanks for the information. One item I am curious about is was the pipe reciprocated during cementing It says it was during the circulations I will look forward to the Schlumberger interpretation you mentiono Tom Maunder, PE AOGCC Hartwig, Dennis D wrote, On 3/1/2007 5:01 PM: «1 J-118 Ops Report. pdf» «1 J-118 Geo Morning Report.xls» «USIT MAXTRAC_1 J-118_23-FE8-2007.zip» Tom, Attached is the Schlumberger USIT log for the 1 J-118 as well as the operations summary for 7 5/8" casing and cementation interval. West Sak B-sand window is from 7766' - 7779' md. West Sak D-sand window will be from approximately 7201'- 7214' and I have also attached the latest Geologic summary which lists formation tops of the Ugnu Sands, (Top of Ugnu C at 5485'MD). 1 have a verbal interpretation of the log from Schlumberger, a formal interpretation is forthcoming. Regards...Dennis Dennis Hartwig Drilling engineer ConocoPhillips Alaska, Inc. Office :907-265-6862 Cell :907-980-1433 Fax :907-265-1535 2 of 2 5/1/2007 11:20 AM ~ ~ 12:30 14 00 1.50 INTRM1 CASING CIRC P Perform Injectivit est pumping down OA, with chart picking MWE @ 11.5 PPG. Flush annulus with 40 BBLs of water, continuing to pump freeze protect diesel @ 2.75 BPM - 800 PSI when shut in. All pumping recorded on chart. SIMOPS: Rig up short bales on Top Drive, install mousehole, and ri u to la down 5" DP. 14:00 14:15 0.25 INTRM1 DRILL PULD P Install Wear bushing. RILDS. 14:15 17:00 2.75 INTRM1 DRILL PULD P Breakout & lay down 5" DP from the derrick. 17:00 17:45 0.75 INTRM1 DRILL PULD P Pull thread protectors and tools to rig floor. 17:45 23:30 5.75 INTRM1 DRILL PULD P Continue breakout & lay down 5" DP from the derrick.la ed down 90 stands total. SIMOPS: Level ri . 23:30 00:00 0.50 INTRM1 DRILL OTHR P Change elevators, pick up 3 1/2" IF handling tools to rig floor. Crew Chan e > C.~t~c~S Ti-ne TWpe S.owrce D~pth Densi z~hl F V~~. PV YP Ge{s ' NfiHP M~T FL Tsxnp 16:00 Oil Base Pit 8,950 8.5 0.0 45.4 13 1.OOI 8.00 18.00 18.0 4.40 0.00. 23'GO 'Oil Base Pit 8,950 8.5 0.0 45.4 13 1.00 8.00 18.00 18.0 4.40 0.00. ,---- ~_ _--___ . ___ - ----- - --- --~ _ .~.. ___ ___ _ _..___ -, ---- ---~_ . ___ --__ ---- ---- -- '~~sc~~ 2 c~~ 2 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk, West Sak Oil Pool 1J-118L1 ConocoPhillips (Alaska), Inc. Permit No: 206-177 Surface Location: 1914' FSL, 2366' FEL, Sec. 35, T11N, RlOE, UM Bottomhole Location: 345' FSL, 2021' FWL, Sec. 24, T11N, R10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. The permit is for a new wellbore segment of existing well KRU 1J-118, Permit No 206- 176, API 50-029-23337-00. Production should continue to be reported as a function of the original API number stated above. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the rev tion or suspension of the permit. When providing notice for a representative of tl>L Co mission to witness any required test, contact the Commission's petroleu 'spec or at (907) 659-3607 (pager). 1 DATED this day of December, 2006 cc: Department of Fish 8v Game, Habitat Section w/ o encl. Department of Environmental Conservation w/ o encl. STATE OF ALASKA ALASKA OlL AND GAS CONSERVATION COMMISSION `~ t I,j ~ ~ ~ 3 ZOO6 PERMIT TO DRILL ~,~;i{, ;;, ~ Cas Cons. Commission 20 AAC 25.005 •_-~ -- 1a. Type of Work: Drill Q ~ Re-drill ^ Re-entry ^ 1b. Current Well Class: Exploratory Development Oil ^ Stratigraphic Test ^ Service ^/ Development Gas ^ Multiple Zone ^ Single Zone ^/ 1c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: 1J-118L1 ' 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 14666' ND: 3774' ' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surtace: 1914' FSL, 2366' FEL, Sec. 35, T11N, R10E, UM 7. Property Designation: ADL 25661 & 25650 West Sak Oil Pool Top of Productive Horizon: 1706' FNL, 2242' FWL, Sec. 36, T11 N, R10E, UM ~ 8. Land Use Permit: ALK 471 & 468 13. Approximate Spud Date: 1/22/2007 Total Depth: 345' FSL, 2021' FWL, Sec. 24, T11 N, R10E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: < 1 mile 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558844 ' y- 5945727 ~ Zone- 4 10. KB Elevation (Height above GL): 28' RKB feet 15. Distance to Nearest Welt within Pool: 1 D-138 ,961' 16. Deviated wells: Kickoff depth: 7323 ' ft. Maximum Hole Angle: 90° deg 17. Maximum Anticipated Pressures in psig (see zo AAC 25.035) Downhole: 1698 psig r Surface: 1283 psig 18. Casing Program S e if ti n Setting Depth Quantity of Cement Size p ica c O S Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 42" 20" x 34" 94# K-55 Welded 80' 28' 28' 108' 108' 260 cf ArcticCRETE 13.5" 10.75" 45.5# L-80 BTC 3222' 28' 28' 3222' 2200' 560 sx AS Lite, 180 sx DeepCRETE 9-7/8" 7-5/8" 29.7# L-80 BTCM 8338' 28' 28' 8338' 3848' 450 sx DeepCRETE 6.75" 4.5" 11.6# L-80 BTC 7343' 7323' 3677' 14666' ~ 3774' - slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be com pleted for Redrill and Re-Entry Operations) Tota! Depth MD (ft): Total Depth ND (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/S t ru ct u ra I Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth ND (ft): 20. Attachments: Filing Fee O BOP Sketch Drilling Program ~ Time v. Depth Plot Shallow Hazard Analysis ~ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program ^/ 20 AAC 25.050 requirements ^/ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Nugent @ 265-6862 Printed Name .Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ~ ~ ~~~ `- ~ ~~~_-~~ Phone C~ S_ ~ ~' >c~ Date t z / r o/Y~6 n All k Commission Use Only Permit to Drill~ /'~/ / Number: ~ ~ I ~~ API Number: 50- ~ Zi~~ 13 ' ~ ~ ~ Permit Approval Date: Z l See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce Coalbed methane, gas hydrates, or gas contained in shales: '~ ~ ` ~~'~~5~ ~~ ~~G 1~'(~~ Samples req'd: Yes ^ No ~ d g req'd: Yes ^ No [~ Other: c ~ H2S easures: Yes ^ No D' io al y req'd: Yes ~ No ^ ROVED BY THE COMMISSION DATE: ~ ~~ ~Q ,COMMISSIONER Form 10-401 Revised 12/2005 14 ~ ,. 5,~~ I ~ 2 PI~eCXo 1-~ (~ Applica~r Perrnit to Drill, Well 1J-118 L1 Revision No.O Saved: 4-Dec-O6 Permit It -West Sak Welt #1J-118 L1 •~°~ Application for Permit to Drill Documen r.~ ~~i t, I~'I~'II MpxirYiiaB well ~ralue Table of Contents 1. Well Name ................................................... ............. 2 Re uirements of 20 AAC 25:005 ...........: ............................................ 2 q (fl ............................................... 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ..............................................................:.................................... 2 Requirements of 20 AAC 25.050(b) ....................:............................................~--..............................:.... 3 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(c)(3) ................................................................................................... 3 4. Drilling Hazards Information ................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) ..........................................................................:....................... 3 5. Procedure for Conducting Formation Integrity Tests.., ........................................ 3 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 3 6. Casing and Cementing Program ............................................................................ 3 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information ..............................................:.................................... 4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Drilling Fluid Program .........: ................................................................:.................. 4 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 4 Lateral Mud Program (MI VersaPro Mineral Oil Base) ........................................................................... 4 9. Abnormally Pressured Formation Information ......................................,.............. 5 Requirements of 20 AAC 25.005 (c)(9)......---~ .............................................................:............:............. 5 10. Seismic Anaiysis .................................................................................:................... 5 Requirements of 20 AAC 25.005 (c)(10) ............................................................................:................... 5 11.Seabed Condition...Analysis ...................................................:................................. 5 Requirements of 20 AAC 25.005 (c)(11) ....................................:........................................................... 5 12. Evidence of Bonding ....................:.......................................................................... 5 Requirements of 20 AAC 25.005 (c)(12) ..............................................................................................:. 5 1J-118L1 PERMIT IT Page 1 of 6 Printed: 4-Dec-O6 ~RIGIN.AL • Applic~r Permit to Drill, Well 1J-118 L1 Revision No.O Saved: 4-Dec-06 13. Proposed Drilling Program ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(13) ............................................:................................................... 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 6 15.Attachments ............................................................................................................. 6 Attachment 1 Directional Plan ................................................................................................................ 6 Attachment 2 Drilling Hazards Summary ............................................:.................................................. 6 Attachment 3 Well Schematic ...._ ........................................................................................................... 6 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25. C1411(b). For a well with multiple weI/ branches, each branch must similar{y be identified by a unique name and API number by adding a suffix to the name designated for the we/! by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as iJ-118 Li. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the app/icatian.• (2J a p/at identifyr"ng the property and the property`s owners and showing (A)che coordinates of the proposed location of the wet/ at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines (B} the coordinates of the proposed location of the weI/ at the surface, referenced to the state plane coordinate system for this state as maintained by the Nationa/Geodetic Survey in the Nationa/Oceanic and Atmospheric Aa'ministration,• (C) the proposed depth of the weI/ at the top of each objective formation and at total depth; Location at Surface 1,914' FSL, 2,366' FEL, Section 35, T11N, R10E ASPZone 4 NADZ7Coordinates RKB Elevation 109.0' AMSL Northings: 5,945,727 °Eastings; 558,844 ~ Pad Elevation 81.0' AMSL Location at Top of Productive Interval West Sak "B" Sand 1,706' FNL, 2,242' FWL, Section 36, T11N, R10E ASP Zone 4 NAD 27 Coordinates MeaSU/"ed De th, RKB; -7,323 Northings 5,947,424 Eastings 563,437 Total Vertica/De th, RKB.• 3,677 Total l/ertica/De th, SS.' 3,568 Location at Total De th 345' FSL 2,021' FWL, Section 24, T11N, R10E ASP Zone 4 NAD 27 Coordinates MeaSU/ed De th, RKB: 14;666 Northings 5,954,752 Eastings: 563,151 Total ~erticalDe th, RKB: 3,774 Total t/ertical De th, SS.• 3,665 and (D) other information required by .20 AAC 25.05(J(bJ, 1J-118L1 PERMIT IT Page 2 of 6 ~ij ~~.~p'yy Printed:4-Dec-O6 Applic~r Permit to Drill, Well 1J-118 L1 Revision No.O Saved: 4-Dec-06 Requirements of 20 AAC 25.050(b) Ifa well is to tae intentionally deviated, the application for a Permit to Dri!/ (Form 10-401) must (1) include a ptat, drawn to a suitable scale, showing the path of the proposed weUbore, including all adjacent we/fbores within 200 feet of any portion of the proposed we/% Please see Attachment 1: Directional Plan and (2) for all weI/s within 200 feet of the propased we/bbore (A) list the names of the operators of these wells, to the extent that these names are known or discoverabfe in public records, and show that each named operator has been furnished a copy of the app/r"catian by certified mail; ar (B) state that the applicant is the anfy affected owner. The Applicant is the only affected owner. 3. Blowou# Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application far a Permit to £1ri11 must be accompanied by each of the fo/lowing items, except for an item a/ready on file with the commission and identified in the application,• (3) a diagram and description of the blowout prevention equipment (BORE) as required by 20 AAC 25.035, 20 AAC 25.036, ar 20 AAC25.037, as app/icable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1J-118 Li. Please see information on Doyon 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An app/ication for a Permit to Dri/1 must be acc~ampanied by each of the fa/lowing items, except for an item a/ready on fr/e with the commission and identified in the application: (4) information on dill/ing hazards, me/uding (A) the maximum downhate pressure that maybe encountered, criteria used to determr`ne it, and maximum potentia/surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the 1J area are 0.45 psi/ft, or 8.7 ppg EMW (equivalent mud weight). Pressures are predicted based on the undisturbed West Sak pressure gradient. The maximum potential surtace pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak °B" sand formation is 1,283 psi, calculated thusly: MPSP =(3,774 ft TVD)(0.45 - 0.11 psi/ft) = 1,283 psi (B) data an potentia/gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole Arab/ems such as abnarma//y gee pressured strata, Post circu/atian zanes, and zones that have a propensr`ty far differentia/sticking; Please see Attachment 2: 1J-118 L1 Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An app/ication for a Permit to tJri/l must be accompanied by each of the fo/%wing items, except for an item already on fle with the commission and identified in the app/icatianr (5) a description of the procedure for conducting farmatian integrity tests, as required under 20 AAC 25.030(t); The parent wellbore, 1J-118, will be completed with 7-5/8" intermediate casing landed in the. West Sak A- Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance with the °Formation Integrity Test Procedure" that ConocoPhillips Alaska. placed on file with-the. Commission. 1J-118L1 PERMIT /T .Page 3 of 6 Printed: 4-Dec-O6 ORIGINAL Applic~or Permit to Drill, well 1J-118 L1 Revision No.O Saved: 4-Dec-O6 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An app/ication for a Permit to Dri/l must be accompanied by each of the fo/lowing items, except for an item already on file with the commission and identified in the app/ication: j6) a complete proposed casr`ng and cementing program as required by ZO AAC 25.030, and a description of any slotted liner, pre- perforated //ner, or screen to be instal/ed; Casing and Cementing Program Hole Top etm Csg/Tbg Size Weigh Length MD/TVD MD/TVD OD in in t Ib/ft Grade Connection ft ft ft Cement Pro ram 4-1/2 6-3/4" A Sand 11.6 L-80 BTC 7,148 7,423 / 3,694 14,571 / 3,920 Slotted- no cement La r - 4-1/2 Slotted 6-3/4" B Sand Lateral (1J-118 Ll) 11.6 L-80 BTC 7,343 7,323 / 3,677 14,666 / 3,774 - Slotted- no cement D Sand 11.6 L-80 BTC 7,717 6,961 / 3,597 14;678 / 3,713 Slotte - no cement slotted Lateral (1J-118 Lz) 7. Diverter System Information .Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Dril/ must be accompanied by each of the fc~l/owing items, except for an item a/ready on file with the commission and identfied in the application: (7) a diagram and description of the diverter system as required by ZO AAC 25.035, unless this requr"cement is waived by the commission under 20 AAC 2s 035jh) j2); No diverter system will be utilized during operations on 1J-118 L1. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Dri// must be accompanied by each of the fol%wing items, except for an item a/ready on d/e with the commission and identified in the application: js) a drilling fluid program, including a diagram and description of the drilling fluid system, as required 6y ZO AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (MI VersaPro, Mineral Oil Base) Value Densif pp 8.6 Plastic Viscostiy lb/100 s 15 - 25 Yield Point cP 18 - 28 HTHP Fluid loss (ml/30 min @ 200psi & 150° <4.0 Oil /Water Ratio 70 / 30 Electrical Stabilit 650-900 `~ p r CxS CAE t: ~~"~~ r' ~ Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon Rig 141. 1J-118L1 PERMIT IT Page 4 of 6 Printed.• 4-Dec-06 ~~ Applic~or Permit to Drill, Well 1J-118 L1 Revision No.O Saved: 4-Dec-06 9. Abnormally Pressured Formation information Requirements of 20 AAC 25.005 (c)(9) An appGcatian for a Permit to Drill must be accompanied by each of the fo/%wing items, except for an item a/ready on ~/e with the commission and identified in the app/ication: (9) for an exploratory or stratigraphic test a~rell, a tabulation setting aut the depths of predicted abnormal/y geo pressured strata as required by Z0 AACZ5.033(f); Not applicable: Application is not for an exploratory or stratigraphic test well 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An appfication for a Permit to Dri// must be accompanied by each of the fo/lowing items, except for an /tam a/ready on frle with. the commission and identified in the application; (10) for an exp/oratory or stratigraphic test wel% a seismic refraction or reflection analysis as required by 2tI AAC 25, ®61(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Colndition Analysis Requirements of20 AAC 25.005 (c)(11) An appl/cation for a Permit to Drill must be accoriapanied by each of the follow/ng items, except for an item a/ready on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floafing drilling Vess% an analysis afseabed conditions as required by 20 AAC 25.06I(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An app/ication for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identifred in the appfication: (12) eV/dance showing that the requirements of20 AAC 25.025 {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005. (c)(13) An application for a Permit to Drill must be accompanied by each of the fo/%wing items, except for arz item a/ready on file with the comet/scion and identifred in the application: The proposed drilling program is listed below. Please refer also to Attachment 3, Well Schematic. Note: Previous operations are covered under the 1J-118 Application for Permit to Drill. 1. Run and set Baker WindowMaster whipstock system, at window point of +/- 7,323' MD / 3,677` TVD, the top of the B sand. 2. Mill 6-3/4" window. POOH. 3. Pickup 6-3/4".drilling assembly with LWD and MWD and PWD. RIH. 4. Drill to TD of 8 sand lateral at +/- 14,666' MD / 3,774' TVD, as per directional plan. 5. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. PU and run 4-1/2"slotted liner. 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool. POOH. 1J-118L1 PERMITlT Page 5 of 6 Printed: 4-Dec-O6 ORIGINAL Applic~or Permit to Drill, Well 1J-118 L1, Revision No.O Saved:4-Dec-06 10. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. 11. POOH and prepare to drill the ~~D" sand lateral iJ-118 L2. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An app/ication for a Permit to Dri/! mustc be accompanied by each of the fol/owing items, except far an item a/ready on frle with the commission and identified in the application: (14) a general description of how the operatorp/ans to dispose of dri//mg mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.4~'ll for an annular disposal operation m the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1J Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on iJ Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic ORIGINAL 1J-118L1 PERMIT IT Page 6 of 6 Printed: 4-Dec-O6 ConocoPhillips Alaska • Plan: 1J-118 L1 (wp05) rry Drilling rvic Proposal Report -Geographic 02 November, 2006 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J"Pad .Plan 1J-118 1J-118 L1 Local Coordinate Origin: Viewing Datum: TVDs to System: North Reference: Unit System: Centered on Well Plan 1J-118 Doyon 141 (28+81) @ 109.OOft (Doyon 141 (28+81)) N True ' API - US Survey Feet Sperry Drilling Services ORIGINAL • • pr Halliburton Energy Services ~~t~r~r Co1~1CiC01""hl~~lp$ Planning Report -Geographic °''""^s a"a F°''"'at'°^ Alaska e~at~,®t6°" Database: _EDM_2003.11_b48 Local Co-ordinate Reference: \Nell Plan 1J-118 Company: ConocoPhillips Alaska, Inc. TVD Reference: Cayon 141 (28+81) @ 109.OOft (Doyon 141 (28+81)) Project: Kuparuk River Unit MD Reference: Rayon 141 (28+81) @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: true Well: Plan 1J-118 Survey Calculation Method: Minimum Curvature Wellbore: 1J-118 L1 Design: 1J-118 L1 (wp05) Project Kuparuk River Unit, North Mope Ala .i a, Uni ted States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Poinf Map Zone: Alaska Zone 04 Using geodetic scale factor Well flan 1J-118 Well Position +N/-S 0.00 ft Northing: +E/-W 0.00 ft Fasting: Position Uncertainty 0.00 ft Wellhead Elevation: 5,945,728.90 ft Latitude: 70° 15' 44.358" N 558,844.00 ft Longitude: 149° 31' 27.477" W ft Ground Level: O.OOft Wellhore 1J-118 L1 -- Magnetics Model Name Sample Date Declination Dip Angle Field Strength bggm2005 6/25/2006 24.05 80.77 57,564 Design 1J-118 L1 (wp05) Audit Notes: Version: 12 Phase: PLAN Tie On Depth: 7,323.21 Vertical Section: Depth From (TVD) +NI-S +E!-W Direction (ft) (ft) (ftj (°} 28.00 0.00 0.00 0.00 11/2/2006 9:31:06AM Page 2 of 7 COMPASS 2003.11 Build 50 ~r~~~~~,~ , + r C Ph ~' Halliburton Energy Services ®~1~C 1 ~ I$ Planning Report -Geographic Alaska ~~ I Database: _EDM_2003.11 b48 Local Go-ordinate Reference: Company: ConocoPhillips Alaska, Inc. TVD Reference: 'I Project: Kuparuk River Unit MD Reference: Site: Kuparuk 1J Pad North Reference: Well: Plan 1J-118 Survey Calculation Method: Wellbore: 1J-118 L1 Design: 1J-118 L1 (wp05) _____ _ Plan Summary Measured Vertical Depth Inclination Azimuth Depth +N/-s +E/-W (ft) ~`) O (n) (ft) (ft) 7,323.21 80.00 2.00 3,676.90 1,660.85 4,606.40 7,335.21 81.91 2.00 3,678.78 1,672.69 4,606.82 7,53T.83 89.83 355.66 3,693.39 1,874.48 4,602.64 7,592.20 89.83 355.66 3,693.55 1,928.69 4,598.53 7,636.21 89.00 357.70 3,694.00 1,972.62 4,595.98 7,797.94 89.48 352.87 3,696.15 2,133.74 4,582.69 8,438.44 89.48. 352.87 3,702.00 2,769.26 4,503.21 .8,492.40 89.28 354.48 3,702.59 2,822.89 4,497.26 9,239.00 89.28 354.48 3,712.00 3,565.97 4,425.43 9,395.66 88.69 359.14 3,714.79 3,722.32 4,416.71 10,539.11 88.69 359.14 3,741.00 4,865.34 4,399.58 10,556.10 89.05 359.50 3,741.34 4,882.33 4,399.37 11,139.33 89.05 359.50 3,751.00 5,465.45 4,394.26 11,158:71 89.59 359.72 3,751.23 5,484.83 4,394.13 12,238.56 89.59 359.72 3,759.00 6,564.64 4,388.85 12,252.42 90.00 359.73 3,759.05 6,578.50 4,388.79 13,038.70 90.00 359.73 3,759.00 7,364.77 4,385.10 13,056.28 89.48 359.76 3,759.08 7,382.35 4,385.03 13,704.84 89.48 .359.76 3,765.00 8,030.87 4,382.31 13,714.01 89.22 359.67 3,765.10 8,040.05 4,382.26 14,439.04 89.22 359.67 3,775.00 8,765.00 4,378.04 14,478.09 90.35 359.97 3,775.15 8,804.04 4,377.92 14,666.08. 90.35 359.97 3,774.00 8,992.03 ~~~ 4,377.82 • ~>a~rt >I Drilling end Formation Evatuatiran 'iJell Plan 1J-118 Doyon 141 (28+81) @ 109AOft (Doyon 141 (28+81 )) Doyon 141 (28+81) @ 109.OOft (Doyon 141 (28+81)) True P;linimum Curvature Dogleg Build Turn Rate Rate Rate TFO (°/100ft) (°I100ft) (°I100ft) ~~) 0.00 0.00 0.00 0.00 15.90 15.90 0.00 0.00 5.00 3.91 -3.13 -38.88 0.00 0.00 0.00 0.00 5.00 -1,88 4.63 112.11 3.00 0.29 -2.99 -84.40 0.00 0.00 0.00 0.00 3.00 -0.37 2,98 97.08 0.00 0.00 0.00 0.00 3.00 -0.38 2.98 97.26. 0.00 0.00 0.00 0.00 3.00 2.14 2.10 44.41 0.00 0.00 0.00 0.00 3.00 2,7T 1.15 22.44 0.00 0.00 0.00 0.00 3.00 3.00 0.09 1.63 0.00 0.00 0.00 0.00 3.00 -3.00 0.16 176.93 0.00 0.00 0.00 0.00 3.00 -2.82 -1.02 -160.19 0.00 0.00 0.00 0.00 3.00 2.90 0.77 14.96 0.00 0.00 0.00 0.00 11/2/2006 9:31:06AM Page 3 of 7 COMPASS 2003.11 Build 50 ~~~~i? • • ConoCOPhillips Alaska Database Company Project: Site: Well: '~ Wellbore: I Design: _ED M_2003.11 _b48 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-118 1J-118 L1 1J-118 L1 (wp05) Halliburton Energy Services Planning Report -Geographic Local Go-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Well Plan 1J-118 Doyon 141 (28+81) @ 109.OOft (Doyon 141 (28+81 )) Doyon 141 (28+81) @ 109.OOft (Doyon 141 (28+81)) True i:linimum Curvature Planned Survey 1 J-1111 L1 iv:;~~J~) MD Inclination Azimuth ND SSTVD +NI-S (ft) (~) (`) (ft) (tt) (ft) 7,323.21 80.00 2.00 3,676.90 3,567.90 1,660.85 L1 - 7 5/8" TOW 7323' MD, 3677' TVD: 1 706' FNL, 2242' FWL - Sec36-T11N-R10E 7,324.21 80.16 2.00 3,677.07 3,568.07 1,661.84 7 5/8" TOW 7,324.97 80.28 2.00 .3,677.20 3,568.20 1,662.58 7,335.21 81.91 2.00 3,678.78 3,569.78 1,672.69 L1 - 7 5/8" BOW 7335' MD , 3679' TVD 7,399.97 84.43 359.96 3,686.48 3,577.48 1,736.98 7,499.97 88.34 356.84 3,692.78 3,583.78 1,836.71 7,537.83 89.83 355.66 3,693.39 3,584.39 1,874.48 7,592.20 89.83 355.66 3,693.55. 3,584.55 1,928.69 7,599.97 89.68 356.02 3,693.58 3,584.58 1,936.44 7,636.21 89.00 357.70 3,694.00 3,585.00 1,972.62 7,699.97 89.19 355.80 3,695.01 3,586.01 2,036.27 7,797.94 89.48 352.87 3,696.15 3,587.15 2,133.74 7,799.97 89.48 352.87 3,696.17 3,587.17 2,135.76 7,899.97 89.48 352.87 3,697.08 3,588.08 2,234.98 7,999.97 89.48 352.87 3,698.00 3,589.00 2,334.20 8,099.97 89.48 352.87 3,698.91 3,589.91 2,433.42 8,199.97 89.48 352.87 3,699.82 3,590.82 2,532.65 8,299.97 89.48 352.87 3,700.74 3,591.74 2,631.87 8,399.97 89.48 352.87 3,701.65 3,592.65 2,731.09 8,438.44 89.48 352.87 3,702.00 3,593.00 2,769.26 1J-118 6 CP2 8/1106 8,492.40 89.28 354.48 3,702.59 3,593.59 2,822.89 8,499.97 89.28 354.48 3,702.68 3,593.68 2,830.42 8,599.97 89.28 354.48 3,703.94 3,594.94 2,929.95 8,699.97 89.28 354.48 3,705.20 3,596.20 3,029.48 8,799.96 89.28 354.48 3,706.46 3,597.46 3,129.01 8,899.96 89.28 354.48 3,707.73 3,598.73 3;228.53 8,999.96 89.28 354.48 3,708.99 3,599.99 3,328.06 9,099.96 89.28 354.48 3,710.25 3,601.25 3,427.59 9,199.96 89.28 354.48 3,711.51 3,602.51 3,527.12 9,239.00 89.28 354.48 3,712.00 3,603.00 3,565.97 1J-118 B_CP3 (8/1/06 9,299.96 89.05 356.29 3,712.89 3,603.89 3,626.73 9,395.66 88.69 359.14 3,714.79 3,605.79 3,722.32 9,399.96 88.69 359.14 3,714.88 3,605.88 3,726.62 9,499.96 88.69. 359.14 3,717.18 3,608.18 .3,826.58 9,599.96 88.69 359.14 3,719.47 3,610.47 3,926.54 9,699.96 88.69 359.14 3,721.76 3,612.76 4,026.51 9,799.96 88.69 359.14 3,724.05 3,615.05 4,126.47 9,899.96 88.69 359.14 3,726.35 3,617.35 4,226.43 9,999.96 88.69 359.14 3,728.64 3,619.64 4,326.39 10,099.96 88.69 359.14 3,730.93 3,621.93 4,426.35 10,199.96 88.69 359.14 3,733.22 3,624.22 4.526.32 Map +E!-W Northing (ft) (ft) 4,606.40 5,947,423.54 4,606.44 5,947,424.52 Map Fasting DLSEV Vert Section (ft) ('I100ft) (ft) 563,436.84 0.00 1,660.85 563,436.87 15.90 1,661.84 4,606.46 5,947,425.27 563,436.89 15.90 1,662.58 4,606.82 5,947,435.38 563,437.16 15.90 1,672.69 4,607.91 5,947,499.66 563,437,76 5.00 1,736.98 4,605.12 5,947,599.36 563,434.18 5.00 1;836.71 4,602.64 5,947,637.11 563,431.41 5.00 1,874.48 4,598.53. 5,947,691.28 563,426.87 0.00 1.,928.69 4,597.96 5,947,699.03 563,426.25 5.00 1,936.44 4,595.98 5,947,735.19 563,423.98 5.00 1,972.62 4,592.36 5,947,798.80 563,419.87 3.00 2,036.27 4,582.69 5,947,896.18 563,409.44 3.00 2,133.74 4,582.44 5,947,898.19 563,409.17 0.00 2,135.76 4,570.03 5,947,997.31 563,395.99 0.00 2,234.98 4,557.62 5,948,096.42 563,382.80 0.00. 2,334.20 4,545.21 5,948,195.53. 563,369.62 0.00 2,433.42 4,532.80 5,948,294.65 563,356.44 0.00 2,532.65 4,520.39 5,948,393.76 563,343.25 0.00 2,631.87 4,507.98 5,948,492.87 563,330.07 0.00 2,731.09 4,503.21 5,948,531.00 563,325.00 0.00 2,769.26 4,497.26 5,948,584.58 563,318.64 3.00 2,822.89 4,496.54 5,948,592.10 563,317.85 0.00 2,830.42 4,486.91 5,948,691.54 563,307.45 0.00 2,929.95 4,477.29 5,948,790.98 563,297.05 0.00 3,029.48 4,467.67 5,948,890.42 .563,286.65 0.00 3,129.01. 4,458.05 5,948,989.86 563,276.26 0.00 3,228:53 4,448.43 5,949,089.30 563,265.86. 0.00 3,328.06 4,438.80 5,949,188.74 563,255.46 0.00 3,427.59 4,429.18 5,949,288.18 563,245.06 0.00 3,527.12 4,425.43 5,949,327.00 563,241.00 0.00 3,565.97 4,420.52 5,949,387.71 563,235.62 3.00 3,626.73 4,416.71 5,949,483.26 563,231.06. 3.00 3,722.32 4,416.64 5,949,487.56 563,230.97 0.00 3,726.62 4,415.15 5,949,587.50 563,228.69 0.00 3,826.58 4,413.65 5,949,687.43 563,226.41 0.00 3,926.54 4,412.15 5,949,787.37 563,224.13 0.00 4,026.51 4,410.65 5,949,887.31 563,221.85 0.00 4,126.47 4,409.15. 5,949,987.25 563,219.57 0.00 4,226,43 4,407.65- 5,950,087.19 563,217.29 0.00 4,326,39 4,406.16 5,950,187.12 563,215.01 0.00 4,426,35 4,404.66 5.950,287.06 563,212.73 0.00 4,526.32 11/2/2006 9:31:O6AM Page 4 of 7 COMPASS 2003.11 Build 50 i~~~s°~e Drilling and Formation Evaluation ~~!G{~~AL p ~ Halliburton Energy Services ~ax>L~° CUll~e ®1-l lps Alaska Planning Repo rt -Geographic o~~tu~,g ®~a ~o~~,et~o~ e~~tu~tt~n Database: _EDM_2003.11_b48 Local Co-ordinate Reference: Well Plan 1J-118 Company: ConocoPhillips Alaska, Inc. ND Reference: Doyon 141 (28+g1) @ 109.OOft (Doyon 1 41 (28+81)) Project: Kupamk River Unit MD Reference: C!oyon 141 (28+81) @ 109.OOft (Doyon 1 41 (28+81 )) Site: Kuparuk 1J Pad North Referenc e: True Well: Plan 1J-118 Survey Calculation Method: h.1 nimu m Curvature Wellbore: 1J-1 18 L1 Design: 1J-1 18 L1 (wp05) Planned Survey 1J-118 L1 (w p05) Map Map MD Inclination Azimuth TVD SSND +N/-S +EI-W Northing Fasting DLSEV Vert Section (ftl (~) (°) lft) (fU (ft) (tt) (ft) Iftl (,~/100ft) (ft) 10,299.96 88.69 359.14 3;735.52 3,626.52 4,626.28 4,403.16 5,950,387.00 563,210.45 0.00 .4,626.28 10,399.96 88.69 359.14 3,737.81 3,628.81 4,726.24 4,401.66 5,950,486.94 563,208.17. 0.00 4,726.24 10,499.96 88.69 359.14 3,740.10 3,631.10 4,826.20 4,400.16 5,950,586.87 .563,205.89 0.00 4,826.20 10,539.11 88.69 359.14 3,741.00 3,632.00- 4,865.34 4,399.58 5,950,626.00 563,205.00 0.00. 4,865.34 1J-118 B CP48/1/O6 10,556.10 89.05 359.50 3,741.34 3,632.34 4,882.33 4,399.37 5,950,642.99 563,204.67 3.00 4,882.33 10,599.96 89.05 359.50 3,742.06 .3,633.06 4,926.17 4,398.99 5,950,686.82 563,203.94 0.00 4,926.17 10,699.96 89.05 359.50 3,743.72 3,634.72 5,026.16 4,398.11 5,950,786.79 563,202.28 0.00 5,026.16 10,799.96 89.05 359.50 3,745.38 3,636.38 5,126.14 4,397.24 5,950,886.75 563,200.62 0.00 5,126.14 10,899.96 89.05 359.50 3,747.03 3,638.03 5,226.12 4,396.36 5,950,986:71 563,198.97 0.00 5,226.12 10,999.96 89.05 359.50' 3,748.69 3,639.69 5,326.10 4,395.48 5,951,086.67 563,197.31 0.00 5,326.10 11,099.96 89.05 359.50 3,750.35 3,641.35 5,426.08 4,394.61 5,951,186.64 563,195.65 0.00 5,426.08 11,139.33 89.05 359.50 3,751.00 3,642.00 5,465.45 4,394.26 5,951,226.00 563,195.00 0.00 5,465.45 1J-178 B CP5 8/1/06 11,158.71 89.59 359.72 3,751.23 3,642.23 5,484.83 4,394.13 5,951,245.37 563,194.72 3.00 5,484.83 11,199.96 89.59 359.72 3,751.53 3,642.53 5,526.07 4,393.93 5,951,286.61 563,194.19 0.00 5,526.07 11,299.95 89.59 359.72 3,752.25 3,643.25 5,626.07 4,393.44 5,951,386:59 563,192.92 0.00 5,626.07 11,399.95 89.59 359.72 3,752.97 3,643.97 5,726.07 4,392.95 5,951,486.57 563,191.65 0.00 5,726.07 11,499.95 89.59 359.72 3,753.69 3,644.69 5,826.06 4,392.46 5,951,586.55 563,190.38 .0.00 5,826.06 11,599.95 89.59 359.72 3,754.41 3,645.41 5,926.06 4,391.97 5,951,686.53 563,189.11 0.00 5,926.06 11,699.95 89.59 359.72 3,755.12 3,646.12 6,026.05 4,391.49 5,951,786.51 563,187.84 0.00 6,026.05 .11,799.95 89.59 359.72 3,755.84 3,646.84 6,126.05 4,391.00 5,951,886.48 563,186.57 0.00 6,126.05. 11,899.95 89.59 359.72 3,756.56 3,647.56 6,226.04 4,390.51 5,951,986.46 563,185.30 0.00 6,226.04 11,999.95 89.59 359.72 3,757.28 3,648.28 6,326.04 4,390.02 5,952,086.44 563,184.03 0.00. 6,326.04 12,099.95 89.59 359.72 3,758.00 3,649.00 6,426.04 4,389.53 5,952,186.42 563,182.76 0.00 6,426.04 12,199.95 89.59 359.72 3,758.72 3,649.72 6,526.03 4,389.04 5,952,286.40 563,181.49. 0.00 6,526.03 12,238.56 89.59 359.72 3,759.00 3,650.00 6,564.64 4,388.85 5,952,325.00 563,181.00 0.00. 6,564.64 1J-118 6 CP6 8/1/06 12,252.42 90.00 359.73 3,759.05 3,650.05 6,578.50 4,388.79 5,952,338.87 . 563,180.83 3.00 6,578.50 12,299.95 90.00 359.73 3,759.05 3,650.05 6,626.03 4,388.56 5,952,386.38 563;180.23 0.00 6,626.03 12,399.95 90.00 359.73 3,759.04 3,650.04 6,726.03 4,388.10 5,952,486.37 563,178.98 0.00 6,726.03 12,499.95 90.00 359.73 3,759.03 3,650.03 6,826.03 4,387.63 5,952,586.35 563,177.73 0.00 6,826.03 12,599.95 90.00 359.73 3,759.03 3,650.03 6,926.02 4,387.16 5,952,686.33 563,176.48 0.00 6,926.02 12,699.95 90.00 359.73 3,759.02 3,650.02 7,026.02 4,386.69 5,952,786.31 563,175.23 0:00 7,026.02 12,799.95 90.00 359.73 3,759.02 3,650.02 7,126.02 4,386.22 5,952,886.29 563,173.98 0.00 7,126.02 12,899.95 90.00 359.73 3,759.01 3,650.01 7,226.02 4,385.75 5,952,986.28 563,172.73 0.00 7,226.02 12,999.95 90.00 359.73 3,759.00 3,650.00 7,326.02 4,385.29. 5,953,086.26 563,171.48 0.00 7,326.02 13,038.70 90.00 359.73 3,759.00 3,650.00 7,364.77 4,385.10 5,953,125.00 563,171.00 0.00 7,364.77 1J-118 B CP7 8/1/06 13,056.28 89.48 359.76 3,759.08 3,650.08 7,382.35 4,385.03 5,953,142.58 563,170.78 3.00 .7,382.35 13,099.95 89.48 359.76 3,759.48 3,650.48 7,426.02 4,384.84 5,953,186.24 563,170.26 0.00 7,426.02 13,199.95 89.48 359.76 3,760.39 3,651.39 7,526.01 4,384.42 5,953,286.22 563,169.06 0.00 .7,526.01 13,299.95 89.48 359.76 3,761.30 3,652.30 7,626.00 4,384.01 5,953,386.20 563,167.86 0.00 7,626.00 13,399.95 89.48 359.76 3,762.22 3,653.22 7,726.00 4,383.59 5,953,486.17 563,166.66 0.00 7,726.00 13,499.95 89.48 359.76 3,763.13 3,654.13 7,825.99 4,383.17 5,953,586.15 563,165.46. 0.00 7,825.99 13,599.95 89.48 359.76 3,764.04 3,655.04 7,925.99 4,382.75 5,953,686.13 563,164.26 0.00 7,925.99 11/2/2006 9:31:O6AM Page 5 of 7 COMPASS 2003.11 Build 50 ~'~!ClNAL ConocoPhillips Alaska ~~' Dal tabase: EDM_2003.11_b48 Company: ConocoPhillips Alaska, Inc. Project: I<uparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-118 Wellbore: 1J-118 L1 Design: 1J-118 L1 (wp05) Planned Survey Ll-1 l ?~ L1 i;wLiO`,I Halliburton Energy Services LI~~r Planning Report -Geographic or•ining ana Formation Evaluation Local Co-ordinate Reference: Well Plan 1J-118 TVD Reference: Doyon 141 (28+81) @ 109.OOft (Doyon 141 (28+81 )) MD Reference: Doyon 141 (28+81) @ 109.OOft (Doyon 141 (28+81)) North Reference: . True Survey Calculation Method: 'Minimum Curvature __...._ Map Map MD Inclination Azimuth TVD SSND +Ni-S +Ei-W Northing Fasting DLSEV Vert Section (ft) (°) O ~ftl (ft) (ft) (tt) lft) (ft) (`I100ft) (ft) 13,704.84 89.48 359.76 3,765.00 3,656.00 8,030.87 4,382.31 5,953,791.00 563,163.00 0.00 8,030.87 1J-118 8 CP8 8/1/06 13,714.01 89.22 359.67 3,765.10 3,656.10 8,040.05 4,382.26 5;953,800.17 563,162.88 3.00 8,040.05 13,799.94 89.22 359.67 3,766.28 3,657.28 8,125.97 4,381.76 5,953,886.08 563,161.71 0.00 8,125.97 13,899.94 89.22 359,67 3,767.64 3,658.64 8,225.96 4,381.18 5,953,986.05 563,160.35 0.00 8,225.96 13,999.94 89.22 359.67 3,769.01 3,660.01 8,325.95 4,380.60 5,954,086.03 563,158.99. 0.00 8,325.95 14,099.94 89.22 359.67 3,770.37 3,661.37 8,425.94 4,380.02 .5,954,186.00 563,157.62 0.00 8,425.94 14,199.94 89.22 359.67 3,771.74 3,662.74 8,525.93 4,379.44 5,954,285.97 563,156.26 0.00. .8,525.93 14,299..94 89.22 359.67 3,773.10 3,664.10 8,625.91 4,378.85 5,954,385.94 563,154.90 0.00 8,625.91 14,399.94 89.22 359.67. 3,774.47 3,665.47 8,725.90 4,378.27 5,954,485.91 563,153.53 0.00 8,725.90 14,439.04 89.22 359.67 3,775.00 3,666.00 8,765.00 4,378.04 5,954,525.00 563,153.00 0.00 8,765.00 1J-118 B CP9 8/1/06 14,478.09 90.35 359.97 3,775.15 3,666.15 8,804.04 4,377.92 5,954,564.04 563,152.57 3.00 8,804.04 14,499.94 .90.35 359.97 3,775.01 3,666.01 8,825.90 4,377.91 5,954,585.89 563,152.39 0.00 8,825.90 14,599.94 90.35 359.97 3,774.40 3,665.40 8,925.89 4,377.85 5,954,685.87 563,151.55 0.00 8,925.89 14,666.08 90.35 359.97 3,774.00 3,665.00 8,992.03 4,377.82 5,954,752.00 563,151.00 0.00 8,992.03 L1 - BHL 14666' MD, 3774' ND; 345' F SL, 2021' FWL - Sec24-T11 N-R10E - 4 1/2" -1J-118 B_Toe (FEL2) 11/2/2006 9:31:O6AM Page 6 of 7 COMPASS 2003.11. Build 50 C] COYIOCOP~'t1IIp5 Alaska ~'~~ ( Dal tabase: EDM_2003.11 b48 Company: ConocoPhillips Alaska, Inc. Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-118 Wellbore: 1J-118 L1 Design: 1J-118 L1 (wp05) Geologic Targets 1 J-118 L1 Halliburton Energy Services Planning Report -Geographic Lit Drilling snd Formation Evx~iuetion Local Co-ordinate Reference: `i:'ell Plan 1J-118 TVD Reference: Doyon 141 (28+g1) @ 109.OOft (Doyon 141 (23+81)) MD Reference: Doyon 141 (28+81) @ 109.OOft (Doyon 141 (28+81 )) North Reference: True Survey Calculation Method: Minimum Curvature I TVD Lu-n~~t Nanis• (ft) zl,~i~=:: 3,751.00 1J-198 i3__GP5 8!1!06 - Point 3,759.00 1J-118 B_CP7 8!1106 - Point 3,702.00 1J-118 B_GP2 811f06 - Point 3,741.00 1J-118 B CP4 8/1(06 - Point 3,765.00 1J-118 B_GP8 8/1108 - Point 3,775.00 1J-118 B CP9 811(06 - Point 3,759.00 1J-118 B_CP6 811106 - Point 3,712.00 1J-118 B_CP3 (811106 - Point 3,774.00 1J-118 8_Toe (FEL2} - Point • +NI-S +EI-W Northing Easting ft ft (ft) (fti 5,465.45 4,394.26 5,951,226.00 563,195.00 7,364.77 4,385.10 5,953,125.00 563,171.00 2,769.26 4,503.21 5,948,531.00 563,325.00 4,865.34 4,399.58 5,950,626.00 563,205.00 8,030.87 4,382.31 5,953,791.00 563,163.00 8,765.00 4,378.04 5,954,525.00 563,153.00 6,564.64 4,388.85 5,952;325.00 563,181.00 3,565.97 4,425.43 5,949,327.00 563,241.00 8,992.03 4,377.82 5,954,752.00 563,151.00 Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter lft1 (ft) C') (") ~~ 3, 221.71 2,200.00 10-3/4 13-112 7,324.21 3,677.07 7-5/8 9-5/8 14,666.07 3,774.00 4-1/2 6-3/4 ' Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +EI-W Comment (ft) (ff) (ft) (ft) 7,323.22 3,676.90 1,660.86 4,606.40 L1 - 7 5/8" TOW 7323' MD, 3677' TVD: 1706' FNL, 2242'. FWL - Sec36-T11 N-R10E 7,335.21 3,678.78 1,672.69 4,606.82 L1 - 7 5/8" BOW 7335' MD, 3679' TVD 14,666.07 3,774.00 8,992.02 4,377.82 L1 - BHL 14666' MD, 3774' TVD: 345' FSL, 2021' FWL - Sec24-T11 N-R10E 11/2/2006 9:31:O6AM Page 7 of 7 COMPASS 2003.11 Build 50 ~~~~~.~, 1~T-118Ll~rillin Hazards S~mmar (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 6-3/4" Ogen Hole / 4-1/2" Liner Interval Hazard Risk Level Miti ation Strate . Abnormal Reservoir Pressure Low Stripping drills, shut-in drills, increased mud weight. Stuck Pipe Low Good hole cleaning, PWD tools, hole opener runs, decreased mud weight Lost Circulation Low Reduced pump rates, mud rheology, LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets),pumping out, backreaming f~ 1J-998L1 Drilling Hazards Summary ~ ° 1 ~ ~ ~ ~ prepared by David A. Nugent °' s ~' "'' 12/4/2006 2:33 PM 20" 94.0# x 34" Insulated Conductor, K-55, set at +/. 80' 10.3/4" x 4.1/2" Wellhead, 5,000 psi Shoe set @ 3222'' M~ 2200' TVD Tubing String 4-1 /2" 12.8#, L-80, IBTM 3.958" ID, 3.833" Drift 5-112" X 7-S18" ZXP Liner Top Packer wl Hold Seal Assembly Downs 4.75" Seal OD Tubing, 4-1/2", 12.8#, IBTM, Special Drift to +/. 500' 3.875" DB Nipple, for Possible SSSV, +/- 500' GLM, Camco KBG-2, 4-1/2" X 1" GLM, Camco KBG-2, 4-1 /2" X 1 ", 70 deg, +/. 1 jt above sliding sleeve CMD Sliding Sleeve, w/ 3.81" DBNipple, 72 deg, +/. 1 jt above. seals ~ Casing Sealbore Receptacle, 20' Length Lateral Entry Module(LEM) D-sand Window t 6960' MD, 3597' ND ,< ~ Payzone ECP 4112" 11.0# L-80 Slotted ~\ !.. _ Liner Every Other Joint ~ ~ ~ 1 4-1/2" X 7-5/8" Seal Bores Model'B' HOOK Hanger 3.68" ID 5-1/2" X 7-518" ZXP Liner Top Packer wl Hold Downs Lateral Entry Module (LEMI Assembly ~ ~ .~ 5-112" X 7.5/8" ZJ(P Liner Top Packer with Hold Downs Casing Sealbore Receptacle 4.75" ID Orienting Profile Automatic Alignment of LEM Positive Latching Collet ~~ Indicates Correct Location Seal Bore for Lateral .Isolation - 3.68" ID. Access Window Positive Lateral Access Via Thru-Tubing Diverter Seal Bore for Lateral Isolation - 3.68" ID ~\ Isolation Seal Asembly 4.75" Seal OD 3.875" Seal ID Casing ~OC1t'~CCU~'11~1~5 West Sak 7-5/8" Injector 1J-118 Tri-Lateral Completion 'D' Sand Lateral 4.1/2" Guide Shoe _ _ ~ - ~-" -~---~ ~ 4.1/2" Liner Shoe, 11.8#, L-80 BTC \5-1/2"Tieback Sleeve Set @ 14678' MD, 3713' TVD \4112" bent muleshoe Seal Assembly 4.75" Seal OD I,yFal Entry Module(``LEM) ` C•` - \J ~ `~~ `~--..... B-sand Window at 7323' MD, 3677 TVD 'B' Sand Lateral 4 V2" 11 6# G80 Slotted ~~i~ NIIQXiS Baker Oil Tools Lateral Entry Module (LEMl With Diverters and Isolation Lateral Access D iverter lateral Isolation Diverter GS Running Tool String Installetl Installed (3.00" Lateral Drill) (2.50" ID Mainbore Drift) 'GS' Profile for Coil Connector / RunninglRetrieving ~ i I I (1.00' Length) 77 Snap In/Snap Out ! 4reack Pressure Valve / Positive LocaOngti yy..~ (1.60'Length) Collet Lateral isolation ~~ .~ Flow-Thm Swivel ( Seals (1.25' Length) '-" ~ / lateral Diverter _ Hydraulic / Ramp ~ Disconnect (1 50' Length) ~ Isolatlonl Mainbore . Diverter Sleeve ~~ GS Spear i _ _ ~ (1.50' Length) I Lateral Isolaton ~ ~ Seals 6.85 a Approx. OAL" 'Jars may be required in highly deviated 78.5' D iverter Length 18.5' Sleeve Length ~r- or tleep applications (6' approx length). T ""' Payzone ECP ~ Liner Every Other Joint '~ 4-112" X 7.518" _~ ~ , ~ _ ,,, 4.1/2" Guide Shoe , ,~ wB ~"., ., ~'' ;I'B' HOOK Hanger - `-, ) ~ ~ . . ,.. _.. ~~/-- a.', 4-1 /2" Liner Shoe, 11.E#, C-80 BTC Seal Bores ~ \ Set @ 14666 MD, ~r774' TVD ' 3.68" ID 5-1/2" Tieback Sleeve ti 4-112" bent muleshoe _-_~ -- 4.1/2" 12.6# Tubin - SG^" DB Nlnnlo---- _ -- 3.633" Drin 3.958" ID .~ 5-1/2" X 7.5/S" ZXP `' ~ Liner Top Packer with Hold Downs 5-112" X 7-518" Flex Lock Liner Hanger/Packer Assembly at Liner Hanger +/- 7423' MD, 3694' ND Casing Sealbore Receptacle, 20'Length 0 Baker Hughes 2005. Thla document may not be reproduced or distributed, In whale ar In part, In any form or by any means electronle or mechanical, Ineludirg photoeopying, reeortling, or by any informadon storage and remevai system now known or hereafter Invented, without written permission hom Baker Hughes Inc. Seal Assembly 4.75" Seal OD 'A' Sand Undulating Lateral 4-1/2" 11.6# L-80 Slotted L~ er E ~ ry Other Joint 4-1/2" Eccentric Guide Shoe ~~ .~l •~ Eauipment Specifications 4-1/2" X 7-5/8" HOOK Hanger Mainbore Drift: 5.32" Mainbore Drift, with diverter: 4.63" Lateral Drift, no diverter or LEM: 3.88" Lateral Drift, w/ diverter, no LEM: 3.88" Lateral/Mainbore Diverter OD: 6.75" 4-1 /2" Lateral Entry Module ' Mainbore Drift: 3.85" Mainbore Drift, w/ isolation sleeve: 2.50" Lateral Drik, w/ coil diverter. 3.00" OD of Diverter and Sleeve: +/- 3.89" Diverter and Sleeve Length: +1.18.5' "" -~~~ ~ 4-1 /2" Casing Shoe, 11.8#, L-80 BTC ~~u°'` °.. ~ ;" Set @ 14571' MD, 3920' TVD 7-5/8" 40# Casing, L-S0, BTCM, Set at @ 8338' MD, 3848' TVD owg Tm.: (85 deg) weatsak7s/a-Td-laearalcomplanon-mlacwr me.: onwa ay: i November t, 2006 Mare D. Kuck RE: [Fwd: 7-5/8" Cement Record--1J-115] • • Subject: RE: [Fwd: 7-5/8" Cement Record--1J-115.] From:"Greener, Mike R." <Mike.R.Greeneraconocophillips.com> Date: Wed, 20 Dec 2006 13:31:57 -0900 To: Thomas ~~laundcr 'tom maunder(cl-'aclmin.statc.~~k.us==~, "Rcillti-, Patrick J" ~~_Patrick..1.Rci]ly(~iconocoPhillips.con~-> CC': "Thomas, LZandv L" ~<Randv.L,"l~homas~u:conocophilli7~s.com=~ -here is the daily reports. I am still trying to get the cement report in a format to send to you., It uTill be coming. -----Origlna! Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.usj Sent: Wednesday, December 20, 2006 1:24 PM To: Greener, Mike R.; Reilly, Patrick J Cc: Thomas, Randy L Subject: [Fwd: 7-5/8" Cement Record--i)-115] All, I am taking the shotgun approach here. I haven't heard back from David so I wanted to make sure someone was checking on this information. Thanks, Tom Maunder, PE AOGCC ------- Original Message -------- Subjeet:7-5/8" Cement Record--1J-115 Date:Tue, 19 Dec 2006 16:25:04 -0900 From:Thomas Maunder atom maunder(u~admin.state.ak.us> Organization:State of Alaska To:David Nugent <David.A.Nugent(aconocophillips.cam> David, I am reviewing the application for 1J-118. Since this is an injector, I need to review the wells within 1/4 mile that penetrate the WS. I have been able to do all wells except iJ-115. I don't believe the 407 has been filed yet, at least it is not in our file. I was wondering if you could send some sort of summary regarding that cement job. Essentially I like to see the last bit of drilling and then the operations up through the next LOT. Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC Content-Description: 1J-115 intermediate.pdf 1J-115 intermediate.pdf :Content-Type: application/octet-stream'' 'Content-Encoding: base64 1 of 1 12/21 /2006 1:04 PM • TRANSMITTAL LETTER C~IECKLIST WELL NAME ,~l2l~C ~ ~~/l~ ~-l Development Service Exploratory Stratigraphic Test Non-Conventional Welt Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK i ADD-ONS ! T'EXT' FOR APPROL'AL LETTER ,' Vb'HAT ! (OPTIONS) I APPLIES I I I , I MliLTI LATERAL ~ The permit is for a new wellbore segment of existing If f t t di it ~ weI l ~~LL. ~•~-- ~ ~ i as wo ( g s ~j~/// i API b n Permit No. - ( , API No. ~0-D2q - Za~337 -~. er num between 60-69) are Production should continue to be reported as a function of the original API number stated above. PILOT HOLE ! ~ In accordance with 20 AAC 25.005(f), all records, data and logs ;acquired for the pilot hole must be clearly differentiated in both ~ ;well name ( PH) and API number (50- - -_~ from records, data and logs ~ ~ acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION ~ 25.0». Approval to perforate and produce /inject is contingent I upon issuance of a conservation order approving a spacing j j I exception. assumes the ~ liability of any protest to the spacing exception that may occur. ! DRY D[TCH j All dry ditch sample sets submitted to the Commission must be in SA!~IPLE I no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals ;' ;through target zones. ;Please note the following special condition of this permit: Non-Conventional i production or production testing of coal bed methane is not allowed Well ~ for (name of well) until after (Companv Name) has designed and ~ implemented a water well testing program to provide baseline data on water quality and quantity. !Company Name) must contact the !Commission to obtain advance approval of such water well testing I 'program. Rev: 12~i06 C:`jody~transmittal_checkl ist ~ ~ ~^ ~ ~ , N O- W N ~ ~ , ~ °, 3 a a ~, ~ 3 >, ~ ~ ~ ~, ~ ~ ~ ~ f0, ~ N. ~ ~ , C. ~ I O ~ N. O' ~ N' ~ O, ~ ~ ~ ~ ~ ~ w ~ ' ~ ~ c6 7. h' ~ ' ~ N N O ~ ~ 0 ~ ~ d ~ ~ ~ O G r ~ N ~ ~~ ~ N, 'T O O: ~ W m ~ a, v, ~ ~ ~ a ~ c ~ ..~ '~~ °5 ~ N . ~ E O °o. ~ ~~ ~ a~, ~~ E'. ~~ MO. 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N a ~ _ ~ O N M V ~ (O I~ M O O N M I LL) O r O O O N M C ~ M ~ W O ~ ° ~ __ N M _~ _LL) .._ ____ CO f~ 00 O -__ ~ r ~ ~ N N N N N N N N N N M M M M M M M M M M U __ _~_ _ _ 2 c O ++ N .+ O N O .. N N v c W O • ~ ^ ~ ~ ^ N ^ ~ O N I .~ v n r O ~ r r O. ' ) " J p N vi ° I `m I ~` O E 1+~ ~ a ^ ~ ~ a ~ ~ I ~ a ^ U ~ a ¢ a ~ w a ~ ~ ~ acn n Well History File APPENDIX • Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. 1j-11811.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri May 18 15:53:58 2007 Reel Header Service name .............LISTPE Date . ...................07/05/18 Ori9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date . ...................07/05/18 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library Physical EOF Comment Record TAPE HEADER west sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER OPERATOR WITNESS JOB NUMBER: LOGGING ENGINEER OPERATOR WITNESS SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: scientific Technical services scientific Technical services 1]-118 L1 500292333760 ConocoPhillips Alaska, Inc Sperry Drilling Services 18-MAY-07 MWD RUN 2 MWD RUN 6 w-0004884845 w-0004884845 R. REPLOGLE S. GREENE D. GLADDEN G. WHITLOCK MWD RUN 8 w-0004884845 S. GREENE G. WHITLOCK 35 11N l0E 1914 2366 Page 1 MWD RUN 7 w-0004884845 5. GREENE aocA-~ ~~- ~* ~ sr ~ 3 ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1j-11811.tapx 109.00 81.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 9.875 10.750 3358.0 6.750 7.625 7766.0 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 7766' MD/3693'TVD, WITHIN THE RUN 2 INTERVAL OF THE 1J-118 PBl WELLBORE. THE WHIPSTOCK WAS POSITIONED, THE WINDOW WAS MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING MWD RUN 6. ONLY SROP DATA ARE PRESENTED FOR THIS RUN. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,7,8 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD). MWD RUN 7 ALSO INCLUDED AT-BIT INCLINATION (ABI). MWD RUN 8 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP). 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1,2,6-8 REPRESENT WELL 1J-118 L1 WITH API#: 50-029-23337-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14795'MD/3802'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 (DEEP SPACING). Page 2 1j-11811.tapx SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR FET RPM RPS RPD RPX ROP 1 clipped curves; all bit runs merged. .5000 START DEPTH 3318.0 3340.0 3340.0 3340.0 3340.0 3340.0 3366.5 STOP DEPTH 14738.0 14745.0 14745.0 14745.0 14745.0 14745.0 14795.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP 2 3318.0 6 7766.5 7 7797.0 8 12240.0 REMARKS: MERGED MAIN PASS. MERGE BASE 7766.0 7797.0 12240.0 14795.0 Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name service order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 Page 3 1j-11811.tapx RPX MWD OHMM 4 1 68 16 5 FET MWD OHMM 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3318 14795 9056.5 22955 3318 14795 RPD MWD OHMM 1.98 2000 47.4491 22811 3340 14745 RPM MWD OHMM 2.9 2000 44.8702 22811 3340 14745 RPS MWD OHMM 1.08 2000 43.361 22811 3340 14745 RPX MWD OHMM 0.99 2000 41.3947 22811 3340 14745 FET MWD OHMM 0.17 289.36 1.15555 22811 3340 14745 GR MWD API 20.82 156.11 62.0908 22841 3318 14738 ROP MWD FT/H 0.16 519.58 182.563 22858 3366.5 14795 First Reading For Entire File..........3318 Last Reading For Entire File...........14795 File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1,0.0 Date of Generation.......07/05/18 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Phy5lCa1 EOF File Header Service name... .......STSLIB.002 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3318.0 7766.0 RPD 3340.0 7766.0 RPX 3340.0 7766.0 RPM 3340.0 7766.0 FET 3340.0 7766.0 RPS 3340.0 7766.0 RoP 3366.5 7766.0 Page 4 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: 1j-11811.tapx TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth units. .. .. .. ..... Datum specification Block sub-type...0 14-FEB-07 Ins~te 74.11 Memory 7766.0 3365.0 7766.0 64.1 89.5 TOOL NUMBER 124724 228272 9.875 3358.0 Polymer 9.00 70.0 8.8 200 4.6 7.000 63.0 93.200 89.6 6.500 63.0 2.800 63.0 Name service order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 Page 5 1j-11811.tapx RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MwD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MwD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3318 7766 5542 8897 3318 7766 RPD MwD020 OHMM 1.98 2000 '20.4276 8853 3340 7766 RPM MwD020 OHMM 2.9 1107.46 13.1863 8853 3340 7766 RPS MWD020 OHMM 1.08 73.15 12.9291 8853 3340 7766 RPX MWD020 OHMM 0.99 62.5 12.188 8853 3340 7766 FET MwD020 HOUR 0.17 62.12 0.998713 8853 3340 7766 GR MwD020 API 20.82 156.11 70.5828 8897 3318 7766 ROP MWD020 FT/H 9.09 417.03 203.298 8800 3366.5 7766 First Reading For Entire File..........3318 Last Reading For Entire File...........7766 File Trailer Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/18 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EoF File Header Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 7766.5 7797.0 LOG HEADER DATA DATE LOGGED: Page 6 24-FEB-07 ~: 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 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 1j-11811.tapx BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) 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 Ins~te 72.13 Memory 7797.0 7766.0 7797.0 81.6 81.6 TOOL NUMBER 6.750 7766.0 Mineral Oil Base 8.50 60.0 .0 35500 .000 .000 .000 .000 .0 .0 .0 .0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 First Last Page 7 1j-11811.tapx Name Service Unit Min Max Mean Nsam DEPT FT 7766.5 7797 7781.75 62 ROP MWD060 FT/H 0.16 14.78 7.79419 62 First Reading For Entire File ..........7766.5 Last Reading For Entire File. ..........7797 File Trailer Service name... .......STSLIB.003 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/18 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/18 Maximum Physical Record..65535 File Type. ............Lo Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 7766.5 FET 7766.5 RPx 7766.5 RPM 7766.5 RPD 7766.5 RP5 7766.5 ROP 7797.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: Reading Reading 7766.5 7797 7766.5 7797 header data for each bit run in separate files. 7 .5000 STOP DEPTH 12174.5 12181.5 12181.5 12181.5 12181.5 12181.5 12240.0 28-FEB-07 Incite 72.13 Memory 12240.0 7797.0 12240.0 85.1 91.3 Page 8 1j-11811.tapx TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) 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 Loging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .liN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. .. ..... Datum specification Block sub-type...0 Name Service Order DEPT RPD MWD070 RPM MWD070 RPS MWD070 RPX MWD070 FET MWD070 GR MWD070 ROP MWD070 Name Service Unit DEPT FT RPD MWD070 OHMM TOOL NUMBER 153879 48783 6.750 7766.0 Mineral oil Base 8.50 66.0 .0 33500 3.8 .000 .0 .000 111.0 .000 .0 .000 .0 units size Nsam Rep Code offset Channel FT 4 1 68 0 1 OHMM 4 1 68 4 2 OHMM 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 HOUR 4 1 68 20 6 API 4 1 68 24 7 FTjH 4 1 68 28 8 Min Max Mean Nsam 7766.5 12240 10003.3 8948 7.44 1339.42 60.92 8831 Page 9 First Reading 7766.5 7766.5 Last Reading 12240 12181.5 1j-11811.tapx RPM MWD070 OHMM 11.48 2000 62.6773 8831 7766.5 12181.5 RPS MWD070 OHMM 15.09 2000 62.7552 8831 7766.5 12181.5 RPX MWD070 OHMM 15.65 2000 58.8747 8831 7766.5 12181.5 FET MwD070 HOUR 0.21 289.36 1.20254 8831 7766.5 12181.5 GR MwD070 API 34.57 95.33 57.2059 8817 7766.5 12174.5 ROP MWD070 FT/H 0.65 519.58 166.401 8886 7797.5 12240 First Reading For Entire File..........7766.5 Last Reading For Entire File...........12240 File Trailer Service name... .......STSLIB.004 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/18 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name... .......STSLIB.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/18 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12175.0 14738.0 RPX 12182.0 14745.0 RPD 12182.0 14745.0 FET 12182.0 14745.0 RPM 12182.0 14745.0 RPS 12182.0 14745.0 ROP 12240.5 14795.0 LOG HEADER DATA DATE LOGGED: 03-MAR-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 14795.0 TOP LOG INTERVAL (FT): 12240.0 BOTTOM LOG INTERVAL (FT): 14795.0 BIT ROTATING SPEED (RPM): Page 10 HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 1j-11811.tapx TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Di rection .................DOwn Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing ...... ............60 lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units. .. .. .. ..... Datum Specification Block sub-type...0 Name Service order DEPT RPD MWD080 RPM MWD080 RPS MWD080 RPX MWD080 FET MWD080 GR MWD080 ROP MWD080 87.0 92.7 TOOL NUMBER 153879 48783 6.750 7766.0 Mineral oil Base 8.50 64.0 .0 35000 11.6 .000 .0 .000 118.0 .000 .0 .000 .0 units size Nsam Rep Code offset Channel FT 4 1 68 0 1 OHMM 4 1 68 4 2 oHMM 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 HOUR 4 1 68 20 6 API 4 1 68 24 7 FT/H 4 1 68 28 8 First Last Page 11 ~ i 1j-11811.tapx Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12175 14795 13485 5241 12175 14795 RPD MWD080 OHMM 33.77 2000 70.9051 5127 12182 14745 RPM MwD080 OHMM 30.28 2000 68.9082 5127 12182 14745 RPS MWD080 OHMM 26.54 213.74 62.5035 5127 12182 14745 RPX MWD080 OHMM 24.75 292.35 61.7187 5127 12182 14745 FET MwD080 HOUR 0.18 21.92 1.34544 5127 12182 14745 GR MWDO80 API 34.4 81.95 55.7551 5127 12175 14738 ROP MWD080 FT/H 1.69 384.51 177.082 5110 12240.5 14795 First Reading For Entire Fil e..........12175 Last Reading For Entire File ...........14795 File Trailer service name... ....... sTSLI6.005 Service sub Level Name... version Number. ........ 1.0.0 Date of Generation....... 07/05/18 Maximum Physical Record.. 65535 File Type ................ L0 Next File Name........... STSLIB.006 Physical EOF Tape Trailer Service name ............. LISTPE Date . ................... 07/05/18 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 . ................... 07/05/18 Ori9in ................... 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 Page 12 • i 1]118L1o03032007s5N.txt Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ wed Jun 06 09:13:39 2007 Reel Header Service name .............LISTPE Date . ...................07/06/06 Ori 9in ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name ............. LISTPE Date . ................... 07/06/06 Origin ................... STS Tape Name. .... ........ .. UNKNOWN Continuation Number...... 01 Previous Tape Name....... UNKNOWN Comments ................. STS LIS Physical EOF Comment Record TAPE HEADER west Sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA scientific Technical services Scientific Technical Services 1J-118 L1 500292333760 ConocoPhillips Alaska, Inc Sperry Drilling Services 18-MAY-07 MWD RUN 2 MWD RUN 6 JOB NUMBER: W-0004884845 W-0004884845 LOGGING ENGINEER: R. REPLOGLE S. GREENE OPERATOR WITNESS: D. GLADDEN G. WHITLOCK MWD RUN 8 JOB NUMBER: w-0004884845 LOGGING ENGINEER: S. GREENE OPERATOR WITNESS: G. WHITLOCK SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: l0E FNL: FSL: 1914 FEL: 2366 FWL: Writing Library. Page 1 MWD RUN 7 W-0004884845 S. GREENE arm-t'~-~ ~isa3~ ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1J118L1o0303200755N.txt 109.00 81.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 3358.0 2ND STRING 6.750 7.625 7766.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 7766' MD/3693'TVD, WITHIN THE RUN 2 INTERVAL OF THE 1J-118 PB1 WELLBORE. THE WHIPSTOCK WAS POSITIONED, THE WINDOW WAS MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING MWD RUN 6. ONLY SROP DATA ARE PRESENTED FOR THIS RUN. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,7,8 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD). MWD RUN 7 ALSO INCLUDED AT-BIT INCLINATION (ABI). MWD RUN 8 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (G P). 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1,2,6-8 REPRESENT WELL 1J-118 Ll WITH API#: 50-029-23337-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14795'MD/3802'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 (DEEP SPACING). Page 2 17118L1o03032007SSN.txt SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name... .......STSLIB.001 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/06 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 3318.0 FET 3340.0 RPM 3340.0 RPS 3340.0 RPD 3340.0 RPx 3340.0 ROP 3366.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD all bit runs merged. STOP DEPTH 14738.0 14745.0 14745.0 14745.0 14745.0 14745.0 14795.0 BIT RUN NO MERGE TOP 2 3318.0 6 7766.5 7 7797.0 8 12240.0 REMARKS: MERGED MAIN PASS. MERGE BASE 7766.0 7797.0 12240.0 14795.0 Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep code offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 Page 3 17118L100303 2007SSN.tx t RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 3318 14795 9056.5 22955 3318 14795 RPD MWD OHMM 1.98 2000 47.4491 22811 3340 14745 RPM MWD OHMM 2.9 2000 44.8702 22811 3340 14745 RPS MWD OHMM 1.08 2000 43.361 22811 3340 14745 RPX MWD OHMM 0.99 2000 41.3947 22811 3340 14745 FET MWD HOUR 0.17 289.36 1.15555 22811 3340 14745 GR MWD API 20.82 156.11 62.0908 22841 3318 14738 ROP MWD FT/H 0.16 519.58 182.563 22858 3366.5 14795 First Reading For Entire File..........3318 Last Reading For Entire File...........14795 File Trailer Service name... .......STSLIB.001 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/06 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLI6.002 Physical EOF File Header Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/06 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY header data for each bit run in separate files. 2 .5000 VENDOR TOOL CODE START DEPTH GR 3318.0 RPD 3340.0 RPx 3340.0 RPM 3340.0 FET 3340.0 RPS 3340.0 ROP 3366.5 STOP DEPTH 7766.0 7766.0 7766.0 7766.0 7766.0 7766.0 7766.0 Page 4 C~ • 17118L1O03032007ssN.txt LOG HEADER DATA DATE LOGGED: 14-FEB-07 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 7766.0 TOP LOG INTERVAL (FT): 3365.0 BOTTOM LOG INTERVAL (FT): 7766.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 64.1 MAXIMUM ANGLE: 89.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 124724 EWR4 ELECTROMAG. RESIS. 4 228272 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 9.875 DRILLER'S CASING DEPTH (FT): 3358.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (5): 70.0 MUD PH: 8.8 MUD CHLORIDES (PPM): 200 FLUID LOSS (C3): 4.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 7.000 63.0 MUD AT MAX CIRCULATING TERMPERATURE: 93.200 89.6 MUD FILTRATE AT MT: 6.500 63.0 MUD CAKE AT MT: 2.800 63.0 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 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 Page 5 • • 17118L1o03032007SSN.tx t RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MwD020 FT/H 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 3318 7766 5542 8897 3318 7766 RPD MWD020 OHMM 1.98 2000 20.4276 8853 3340 7766 RPM MWD020 OHMM 2.9 1107.46 13.1863 8853 3340 7766 RPS MWD020 OHMM 1.08 73.15 12.9291 8853 3340 7766 RPX MWD020 OHMM 0.99 62.5 12.188 8853 3340 7766 FET MwD020 HOUR 0.17 62.12 0.998713 8853 3340 7766 GR MWD020 API 20.82 156.11 70.5828 8897 3318 7766 ROP MWD020 FT/H 9.09 417.03 203.298 8800 3366.5 7766 First Reading For Entire File..........3318 Last Reading For Entire File...........7766 File Trailer Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/06 Maximum Physical Record..65535 File Type ................L0 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.......07/06/06 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 7766.5 7797.0 LOG HEADER DATA DATE LOGGED: 24-FEB-07 Page 6 • 1.7118L1003032007SSN.txt 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 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS 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 (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing....... ............60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Insite 72.13 Memory 7797.0 7766.0 7797.0 81.6 81.6 TOOL NUMBER 6.750 7766.0 Mineral oil Base 8.50 60.0 .0 35500 .000 .000 .000 .000 .0 .0 .0 .0 Name Service order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RoP MWD060 FT/H 4 1 68 4 2 First Last Page 7 • 17118L1003032007SSN.txt Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 7766.5 7797 7781.75 62 7766.5 7797 ROP MWD060 FT/H 0.16 14.78 7.79419 62 7766.5 7797 First Reading For Entire File..........7766.5 Last Reading For Entire File...........7797 File Trailer Service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/06 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/06 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 7766.5 12174.5 FET 7766.5 12181.5 RPX 7766.5 12181.5 RPM 7766.5 12181.5 RPD 7766.5 12181.5 RPS 7766.5 12181.5 RoP 7797.5 12240.0 LOG HEADER DATA DATE LOGGED: 28-FEB-07 SOFTWARE SURFACE SOFTWA RE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12240.0 TOP LOG INTERVAL (FT): 7797.0 BOTTOM LOG INTERVAL (FT): 12240.0 BIT ROTATING SPEE D (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.1 MAXIMUM ANGLE: 91.3 Page 8 • 1.7118L1003032007SSN.txt TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: TOOL NUMBER 153879 48783 6.750 7766.0 Mineral oil Base 8.50 66.0 .0 33500 3.8 .000 .0 .000 111.0 .000 .0 .000 .0 Data Format Specification Record Data Record Type... ..... .....0 Data Specification Bloc k 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 sto ck sub -type...0 Name Service order Units size N sam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD070 OHMM 4 1 68 4 2 RPM MWD070 OHMM 4 1 68 8 3 RPS MWD070 OHMM 4 1 68 12 4 RPX MWD070 OHMM 4 1 68 16 5 FET MWD070 HOUR 4 1 68 20 6 GR MWD070 API 4 1 68 24 7 ROP MwD070 FT/H 4 1 68 28 8 First Name Service Unit Min Max Mean Nsam Reading DEPT FT 7766.5 12240 10003.3 8948 7766.5 RPD MWD070 OHMM 7.44 1339.42 60.92 8831 7766.5 Page 9 Last Reading 12240 12181.5 • • 17118L1003032007SSN.txt RPM MWD070 OHMM 11.48 2000 62.6773 8831 7766.5 12181.5 RPS MWD070 OHMM 15.09 2000 62.7552 8831 7766.5 12181.5 RPX MWD070 OHMM 15.65 2000 58.8747 8831 7766.5 12181.5 FET MWD070 HOUR 0.21 289.36 1.20254 8831 7766.5 12181.5 GR MwD070 API 34.57 95.33 57.2059 8817 7766.5 12174.5 ROP MWD070 FT/H 0.65 519.58 166.401 8886 7797.5 12240 First Reading For Entire File..........7766.5 Last Reading For Entire File...........12240 File Trailer Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/06 Maximum Physical Record..65535 File Ty e ................LO Next F~~e Name...........STSLIB.005 Physical EOF File Header Service name... .......STSLIB.005 Service Sub Level Name... Version Number. ........1.0.0 Date of Generation.......07/06/06 Maximum Physical Record..65535 File Type. ............Lo Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12175.0 14738.0 RPX 12182.0 14745.0 RPD 12182.0 14745.0 FET 12182.0 14745.0 RPM 12182.0 14745.0 RPS 12182.0 14745.0 ROP 12240.5 14795.0 LOG HEADER DATA DATE LOGGED: 03-MAR-07 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 14795.0 TOP LOG INTERVAL (FT): 12240.0 BOTTOM LOG INTERVAL (FT): 14795.0 BIT ROTATING SPEED (RPM): Page 10 • HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 17118L1o03032007SSN.txt TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 Electromag Resis. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) 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 Name Service order DEPT RPD MWD080 RPM MWD080 RPS MWD080 RPX MWD080 FET MWD080 GR MWD080 ROP MWD080 87.0 92.7 • TOOL NUMBER 153879 48783 6.750 7766.0 Mineral oil Base 8.50 64.0 .0 35000 11.6 .000 .0 .000 118.0 .000 .0 .000 .0 units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 OHMM 4 1 68 4 2 OHMM 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 HOUR 4 1 68 20 6 API 4 1 68 24 7 FT/H 4 1 68 28 8 First Last Page 11 17118L1o03032007SSN.txt Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12175 14795 13485 5241 12175 14795 RPD MWD080 OHMM 33.77 2000 70.9051 5127 12182 14745 RPM MWD080 oHMM 30.28 2000 68.9082 5127 12182 14745 RPS MWD080 OHMM 26.54 213.74 62.5035 5127 12182 14745 RPX MWD080 OHMM 24.75 292.35 61.7187 5127 12182 14745 FET MWD080 HOUR 0.18 21.92 1.34544 5127 12182 14745 GR MWD080 API 34.4 81.95 55.7551 5127 12175 14738 ROP MWD080 FT/H 1.69 384.51 177.082 5110 12240.5 14795 First Reading For Entire File..........12175 Last Reading For Entire File...........14795 File Trailer Service name... .......STSLIB.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/06/06 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................07/06/06 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Reel Trailer Service name .............LISTPE Date . ...................07/06/06 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................5T5 LIS Physical EOF Physical EOF End Of LIS File writing Library. writing Library. 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