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206-178
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Plug Perforations❑ Fracture StimulatcE Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Pedorate ❑ Other Stimulate=] Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Wei= Re-enter Susp Well ❑ WI NJ t0 WAG ❑ 2.Operator CODOcoPhilllpS Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill NumberName : Development ❑ Explorator❑ Stratigraphic ❑ ServicED 206-178 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50029233376100 7. Property Designation (Lease Number): e. Well Name and Number: KRU 1J -118L2 ADL 25661, 25650 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): NA 10. Field/Pool(s): Kuparuk River Field ( West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 14,815 feet Plugs measured None feet true vertical 3,742 feet Junk measured None feet Effective Depth measured 14,783 feet Packer measured 7,146 feet true vertical 3,740 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 7,436' 4.5" 14,815' 3,742' 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 Ga!:Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 1900 psi 1300 psi 500 psi Subsequent to operation: 1 0 1000 Mscfd 0 700 psi 1450 psi 14. Attachments (required per 20 PAC 25.070, 25.071, 8 25.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Developmen[j Service 21 Stretigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas❑❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑Q GINJ ❑ SUSFfl❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIAif C. 0. Exempt: 319-428 Contact Name: Sydney Autry Authorized Name: Sydney Autry Contact Email: Sydney.autry@cop.com Authorized Title: Senior Petroleum Engineer L -.l Authorized Signature:= Contact Phone: 907-265-6813 Date: V7Z 3/4/2-c, 3/r/) -O2,' RBDMS &bEC 2 4 2019 Farm 10-404 Revised 4/2017 Submit Original Only 1J-1181-2 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11/26/191 Pump 5 bbls Methanol down Tbg for WAG, 25 bbls Methanol down flowline for F/P 11/27/19 WAG 1J-1181-2 from Seawater Inj to MI KUP INJ WELLNAME 1J-118 WELLBORE 1J-118 ConocoPhillips Waskn. il, r -11B PbW41912 M 1111. Perforations d Slots mauc Lactwn Top OVa) Use RVD) Tot,1.8) elm lnrce) (Me) RISE) LMkM zone Del. sMl Lens rerobM I Teo. cum HnNOER. 21,8 .T 8958.0 9,209.0 3.8690 3.8721 WS A2.1J-118 2123200) 32.0 SLOTS ALL PERFS IN WELLBORE'. Undulating COrvWCiOR, ffibiC8.0 Nwx.:sm.s ws U1.21Ta.1 A)ternaling solidlalOeC(1 oioe-0.25"x2.5•@4 circumferential adjacent rows, 3 centers staggered 18 or,, 3 non -W. ted ends suRRACE:30.sa,0ss.0 ons uPr'��ma 9.4160 10,0390 3,8]).0 3,8903 WS A2. 1J-118 2232007 324 SLOTS 10,2330 10,8480 3,8907 3,9033 WS A21 1J-118 WM007 320 SLOTS SLEEVE -07,+10s. LOf M. 7.161.0 11147.0 11])701 .910,6I S A2, - I223200] 620 SLOTS SEAL nssr: 7,107 12,0740 12,544.0 3,909.01 3,9134 WS A2. 1J-118 223200] 320 SLOTS 12,954.0 13A24.03,9269 WS A2, 1J -t18 223200] 320 SLOTS 137920 14.178.0 3,9385 1 3,9445 WS Al. W-118 lffd3zuul 320 SLOTS DWINDCAN.7=0. 7.2170 14,515.0 14,645.0 1 3,953.51 3,95)3 JWS A2, IJ -118 IMM007 320 ISLOTS Mandrel Inserts at ai NTap Topimm) )lVD)V.Ive (Win ALke MOOeI 009n) 8ery Tyce L.CN P.R 1YPo en) TRO Run (Pall Run Done Com 1 2,1)3.1 1,816] CAMCO KBMG 1 GAS LIFT DMV BKS 0.000 0.0 8/)200] DLMERLEM. 7,1NS.D7dee0 2 fi007fi 3.226] CAMCO KBMG t GASLIFT DMY BK -5 0.000 0.0 3119200) Notes: General & Safety End Dat Ann...n 9 LINER HH. 7.AI s-7KM0 8212006 NOTE-. VIEW SCHEMATIC wIAIasIrRSctRRRec9.0 320200) NOTE'. MULL I{ ILHAL WELL- 1J418(ASANO)1J-11811(B-SAND), IJ -1181'2 O -SAND) 3 LINER HX, ),50a3].]62> BWINCAV,7 0-7.>la.e B LWER LEM: 7.3122-] M} m1ERMEDIFTE 2E7-AW .LOT.:BSS0.63NB,0—� ..T.. IabL.®0� .1018, 10,M RI. Me _ ELOT., 11.7 111. SLOTS: 12m40 -Is M.O� ..R: 1249x0-I.A.13— SLOT.'. 13.133.0619,1730 .IOT.:lI,S1.6110050� MSntl SIOnOd LINER, 7.M 148930 KUP INJ WELLNAME 1J-110 WELL13UKL 1J-118L2 ConoeoPhillips lWell Attributes Max Angled MD TD j AI25kc. Iraq_ Field Name wellEore apvuWl wevbore sla+ue d(• Mo lnrcel A[I61m nn(e) .62 10,21968 14,822.0 Comment H351ppm1 Da& annobllon Da@ rtBGM(m Np Release Date SSSV: NIPPLE Last WO: Janet 32.29 3202007 u-ne¢.+als'mle lzsx9e pM Last Tag ve'4[/zMrmGc(e.) AnnDla4on celb(MO) End Dae, weuEore Last Moe By - ---- - --'Last Tag: 1J418L2 pointed., NANGER, ve Last Rev Reason AnneMNOn az End tale Wellpore LIMrMBy Rev Reason'. SHOW PERF SECTIONS 9162013 1,411812 osbotl CONOIICTOpRtE: :.Ei m25 �.5 NI s g Casin Strings GF611FT: 21T3.1 Lasing Beacriplion OD1in1 ID 1in1 TDp 1%KB1 SN DepIF (flKB1 set DeplM1 (IVO)... WIILen 9... Grata TOp TFeead D-Santl SlDttetl UNER 412 348 ],3]8.6 14,815.0 3,7419 11.60 L_8' BTC suREADE:3o.s9,areo—� Lint Details NDmIreI ID W6LE-0;7.WLB top (flNB) Top nV011XRB) Top Incl fl Ikm Oes Com (int sLEEVE4:zu6s ],3]6.6 3,6230 86.61 SLEEVE BAKER MR LINER SETTING SLEEVE 5.500 WCATOR;7162D 7,3913 3,623.8 1 88.14 NIPPLE IUML. RS NIPPLE 48]0 6EUANSY:7.uM7 Perforations d slots Sheet O LINER NN: 7."'.5-7,40 01 Sens INTERMEDIATE:Z 74NB0 Top BINote) (sho41H OLINER LEM,] 1.111 ilF Top443.NINEBlm%1N KB) 13.62 3,K3 W, DW 1 Type Com ],443.0 ],981.0 0 3,6264 1J- 3,639.4 WS D, 1J- X16200] 32.0 SLOTS ALL PFRFSIN 11812 WELLBORE: Undulating Alpe e011tl160n pipe-0.122 5'12.5" D4 4 adjcent rows, centers staggered ones,l inside ssagge 18 tl¢g, 3' nonrtlGnetl ends , 0.232.0 8,762.0 3,6459 3,6524 WNT1J- 3/162007 32.0 SLOTS SLOTS; T,N3D],991A� 11BU 9,049.0 9,340.0 3.654.4 3,6713 WE 0, IJ- 31162007 32.0 SLOTS 11BU 9,631.0 9,6730 3.6786 3,6])4 WS-D, IJ- SLOTS 11812 9,]18.0 10,259.0 3,616.2 3.6]3.0 W ,1J- 32.0 SLOTS 11812 10,6]3.0 11.144.0 3,680.] 3,6926 WE D, U- 32.0 SLOTS 118U 11,385.0 11,930.0 3,698.6 3,]032 WS D, 1J. 32A SLOTS 118U r1::732.0 12,183.0 12.63].0 3]09.5 3.]16.0 WE D, 1J- 320 SLOTS 1BU 12,803.0 13,433.0 3,]19.1 3,]150 WS D, 1J- 32A SLOTS SLDT6awaeaseo— 118U 136896 14,158.0 3,]23.4 3.]33.] WE D, 1J- 32A SLOTS 1180 SLOTS: 9,E3t 6B613A� 14,405.0 14,783.0 3,738.5 3,740.1 INS D. 1J- X162007 32.0 SLOTS 11812 Notes: General 6 Safety End Dale Annobllon SLOTS: 9718010odo X212008 I NOTE: VIEW SCHEMATIC wnnette uenemvend, XMO07 NOTE: MULTI-L ILRALWELL-1J-118(A-SAND),lb110LI(B-SAND),1J-118U(D-SAND) SLG76', loon MMA-- $LOTS, It affi Pll W20� ROTS 12169.61261].0—� SLOTS; 12ab.G13.a33o� SLOTS; la.0-1a IgO— SLOTS: 1l...4.761G— a9aW 6Io]m IJNER: T.3R6 a.euB-- THE STATE °fALASKA 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 -118L2 Permit to Drill Number: 206-178 Sundry Number: 319-428 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.00gcc.claska.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'1GI. Price Chair DATED this I day of October, 2019. -IBDMS ` O -CT 10 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon Plug Perforations L1 Fracture Stimulate Li Repair Well LJ Operations shutdown Li Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Reddll ❑ 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: ConocoPhllll S Alaska Inc. Exploratory ❑ Development ❑ Stratigraphic El Service ❑� 206-178 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 41 50029233376100 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 ❑ JVP1 1 J-1 18L2 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 2566125650 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 ND: MPSP (psi): Plugs (MD): Junk (MD): 14,815' 3,742 14,783' 3,740' 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' I Liner 17,436' 4.5" 14,815' 3,742' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Slotted liner: 7443'-14783' 3626'-3740' 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: 1 -Oct -19 Commencing Operations: OIL L] WINJ ElWDSPL ❑ 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 Contact Name: Sydney Autry Authorized Title: Senior Production Engineer Contact Email: sydney.autry@cop.com 2_d Contact Phone: 907-265-6813 Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No LvJ Spacing Exception Required? Yes ❑ No Subsequent Form Required: �G.-=�-0 �- �pMSCT 1 0 2019 APPROVED BY /� I I Approved by: ' ' 1 1 - COMMISSIONER THE COMMISSION 10 Date: 'Le /`� vgll Tl- 1"I" ORIGINAL 4 C -Q3 Revi�ed (r/zd6X Gi Approved application is valid for 12 months from the date of approval. Submit Form and Attachments in replicate 1J-1181-2 Sundry Proposal ConocoPhillips Alaska Inc. requests approval to convert West Sak Well 1J-1181-2 (PTD# 206-178) from Water Injection service to Water Alternating Gas Injection service. Area of Review: West Sak well 1J-1181-2 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, 1 D-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-1181-2 penetrations of the West Sak interval. Mechanical Condition of Well to be Converted: The mechanical condition of West Sak injector 1J-11812 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 1J-1181-1 & 1J -118L2) and offset well condition. Conditions for approval (if applicable): ADL0256511 ADL025650 t t \1 o4 / ( ADL028243 Well Pad — Well Trajectory 1J-11812, Open Interval C31,1-1181_2 01 Quartermile Buffer — West Sak Well West Sak Well WS Interval West Sak Base in non -West Sak Wells — Non -West Sak Well j_-__-1 West Sak PA = CPAI Leases ConocoPhillips Alaska U-1181-2 Injection Sundry N J N 00 N � � T O T O r 1 0 0.2 0.4 0.6 Miles I ADL028248 N ADL: A 17 I ADL028248 N ADL: A e % F - £ a P 4e' ' sn s a =�Nx„ a=," ;s €a 5.3a -'o3#s Woo 3 :'3 a5 aas Yg sc 4^'a i""=s o�=6 a.o m " =0 �cR 6 5 Halted_ La..' a P:3 Y^ c .^99vR S$�5o a&peso �C yoa;n INN Yw.`T `o$R0� S= oa°-'� -'x"a vis Yi .83 allHit 3�c suPb� aY8'3 lc� n nnYN3F vo SK e3 xiaasSi _n P5 3oyz puC 'e '^ qUNp' 3dns g&3'Rm 9aq 3'_fl§..: n$ �c8"pp .�p _�Z^w4 w&Z ®o! Syn m y':^o sao Kex avis xp'o R-,qU°=e Nyo iP 3"-x 'ay ; N g'e�� vC^ e: ::.: Y:G �' y.5q a -2'G:> A"•aNs�m F�� �q e y`' a3&^� :. 9u5 YIN � N5`mF $dx antt� 3%zF S 883I auElk 0 R aRR a �j3 <C H C eBs ash s �c na gga: Z x_98 A%.� 8 9 y�s o S y�v C ya i8gEA y� xe�S �:&4-& x 2 a KUP ConoeoPhillips Weu Attributes --'Max Angle&MD1 JTD18LI Wellbore gPVUWI Fieltl Name Alaska ITS: Well Stat- Incl (•) MO IRKBI A. IN IflK I 500292333]6Y WEST SAK INJ 9262 10,219.68 14,822.0 Comment H2S(PPM) Date gnnMation Entl pale Re Gra IN) Rig Release pate Cava 11 6/16©131 1 SSSV: NIPPLE Last WO: 32.29 32012007 dead. ec- HANGER.M Annotation OepIM1 IflKB) Entl Date Annotau- tast mod By End Dele Last Tag: Rev Reason: SHOW PERF SECTIONS osborl 51162013 _ cash Strin s _ CONDVOTOa, n V .Cooing pes¢rina n ._San SloI EN LINER _ String e... 412 So"'lD _. 3.4]6 Top NINE) Set ],3]8.6 DepthH..smDephRVD),.. 14,815.0 3]41.9 stung Wt. 11.60 String. -T61 L-80 -1710—T-1, m BTC Gs. GMILFT,. Liner Details- doo SIJEEVEo. ],11100 LOCATOR. FAL 6y, Tap Depth INOI iaP Incl To IfIKB) (tIKB) (°) Ihm Oeacri is nBAKERHRLINERSETTM Nomi... Comment land. 7,3]8.8 3,622.4 85.8]SLEEVE UIEEVE 5.500 ]tH o uNEa eu, ].1!&],319 ],391.3 3,623.5 86.24NIPPLE BAKER RS NIPPLE 4,g]0 Perforations & slots o LINEa HH, ],W4]s81 - SLOTS 9,1-4$]62 NrERMEoarE. VS. ToPIND) Sun (TVD) Top111KB) Bdn M1KB) IRKB) IttKB) Zon¢ Oen. pate IzM1,- T ,Pe comment 1,443.0 7,981.0 3,626.2 3,639.4 WS D, 1J-1181-2 3/16200] 32.0 SLOTS ALL PERFS IN WELLBORE: Und.laung Altemating dolid/slaRetl pipe -0.1taggered 1�4 circumferential a did Gant rows, T' Censers staggered 18 deg, 3' non -slotted ends 8,232.0 6,]82.0 3,645.9 3,6512 WS IJ. U-1181-2 31161200] LOTS 9,049.0 9,340.0 3,854.4 3,8]1.fi WS D, 1J-11812 3/16200) LOTS 9,63Y.0 9,6]3.0 36]8.6 3,6]].9 WS D, 1J-1181-2 3/1fi1200] LOTS 9,718.0 10,259.0 3676.4 3,674.8 WS D, 1J-1181-2 311612007 LOTS 1 10,673.0 11,144.0 3680.] 3,692.6 WE D. 1J-11812 31162007 OTS 11,385.0 11,930.0 3,698.2 3,703.7 WS D, IJ -1 18123/162007 LOTS U3ZOSLOTS 12,183.0 12,637.0 3,709.8 3,716.0 WS D. 1J-1181-2 311612007 LOTS is ':. 12,883.0 13,433.0 3,]19.1 3.]15.2 WS D, 1J-11812 3116/2007 OTS 13,6890 14,158.0 3]233 $]34.O WS D, -1J1 1812 3/Yfi2007 OTS 14,405.0 147830 3 ]379 3,740.1 WS D, 1J-1181-2 3116/200] OTS Notes: General & Safety_ 1 1 Ene pate Annmatmn 3201200) NOTE:MULTI-LATERAL WELL -1J -116(A -SAND), YJ -1181-1 (BSANO), 1J-1181-2 (D -SAND) sears, ? Boaga.sw � •' 8212008 l.UTE'. VIEW SCHEMATIC w/Alaska Scbematic9.0 stprs, -_ g.Gi188i3 art d —1' y"1 $LOT. tpa]3M1aa E i sr'm - 113asl1 GLors 121841263] 6LOi$ —A SLOTS, 13.68914,1Y Mandrel Details " SLOTd, 1d,46S14, AG p od sim.a IL ]3MIeels� TO pY1I.Ea le'. s... N._ Top IRKBI Top Depth IND) NVKB) rop Incl 1°) Make Model pD lin) Sery - Pou VaNe Lath Size Type Type (In) TRO Run (Psi) Run Date Com... 1 2,173.1 1,816) ]0.43 CAMCO KBMG 1 GAS LIFT' DMV BKS 0.000 0.0 8!112007 2 6,00) fi 3,226) 68)4 CAMCO KBMG 1 GAS LIFT DMV BK -5 0.000 0.0 31191200] F •eo / �� J OO Na oc$ r N-"„iyu sm £ m K i�f :Oaf h�,£ a Aa9”" E , so, - a �m -"x CL m p � L - $- " - ui ha=�mI aZ o0 C "- '' ,m CO Q .-cis Rc C zm E nen U pm m Eco ho fm W 1 `.ems y E m O a an v a u yx F E - S=e p m 9 ax i � IjSO hj•� p'§ W 3 mE0 X2 my om E `mo` W O K �Fm jm r m nN 0 -"pp, p, 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. Svdnev.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 <Svdney.Autry@conocophillips.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? 1 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 V ictoria. LoeopCoDa las ka. gov 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). It 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 Victo(ia.Loer)o@alaska.gov Image P1ect ell History File 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) r 6=a~, iiumiimuuii R„~~~~~a uuuuuiuum RESCAN ~olor Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: DIGITAL DATA Diskettes, No. ^ Other, No/Type: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: ^ Other:: -° /s/ 1 BY: Maria Date: ~,~~ Pro'ect Prooiin III II~III IIIII ~~ III J g ~(~ 6Y: Maria Date: ~~ ~j ~' /s/ ~" nnin Pre aration x 30 = ~, + ~ =TOTAL PAGES Sca g p (Count does not include cover sheet) BY: Maria Daie: ~-f- /c~~ ~ /~ ~ /s/ ~/ Stage 1 If NO in stage 1, page(s) discrepancie were found: YES NO BY: Maria Date: /s/ Scannin is complete at this point unless rescanning is required. II I II II II I II II I I III 9 ReScanned III II'III IIIII II III Stage 1 Page Count from Scanned File: (count does include cover beet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: ~~1~ ~ /s/ ~~ ~~ Production Scanning BY: Maria Date: /s/ Comments about this file: Quality Checked III IIIIII III II'I III 10/6/2005 Well History File Cover Page.doc 1a ~-*, DATA SUBMITTAL COMPLIANCE REPORT 3/26/2009 Permit to Drill 2061780 .Well Name/No. KUPARUK RIV U WSAK 1J-118L2 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23337-61-00 MD 14822 TVD 3742 Completion Date 3/19/2007 REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: GR/Res, USIT Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name - ___ D C Lis 15184 Induction/Resistivity 15184 LIS Verification t,t~ D Directional Survey Induction/Resistivity 1~6g I~nduction/Resistivity rED C 17568" See Notes Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y Chips Received? v i w Analysis -~/~V Received? Completion Status 1-OIL Current Status 1WINJ UIC Y -- - - -- G f ~~~ Samples No Directional Survey Yes (data taken from Logs Portion of Master Well Data Maint Interval Start Stop Log Log Run Scale Media No 2 Col 2 Col Sent Received Interval OH / Start Stop CH Received Comments 3318 14822 - Open 6/12/2007 - - - -- LIS Veri, GR, FET, ROP w/Graphics 3318 14822 Open 6/12/2007 LIS Veri, GR, FET, ROP 7154 14822 Open 6/12/2007 108 3742 use- 2/4/2009 TVD, DGR, EWR 21-Feb- ~rw . 2007 108 14822 / ~as~ 2/4/2009 MD ROP, DGR, EWR 21- o p~.~- Feb-2007 0 0 p ~t,~ 2/4/2009 C~ EWR logs in PDS, EMF and CGm graphics Sample Set Number Comments Daily History Received? ~ N Formation Tops ~ N DATA SUBMITTAL COMPLIANCE REPORT 312612009 Permit to Drill 2061780 Well Name/No. KUPARUK RIV U WSAK 1J-118L2 Operator CONOCOPHILLIPS ALASKA INC MD 14822 TVD 3742 Completion Date 3/19/2007 Completion Status 1-OIL Current Status 1WINJ Comments: API No. 50-029-23337-61-00 UIC Y __ -- - _. Compliance Reviewed By _ ___ Date: WELL L®G 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+L1+L2+PB1+PB2 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23337-00,60,61,70,71 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 1 Color Log 50-029-23337-00,60,61,70,71 Digital Log Images 3 CD Rom 50-029-23337-00,70,71 50-029-23337-60 50-029-23337-61 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Bryan Burinda Petrotechnical Data Center, MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 Office: 907-273-3536 ~,~~ ~~ ~~ ~OL~ Fax: 907-273-3535 ~ ~ ~-~ Bry~riBu1-n~l~-]iaYlibuz~on.com ; UL~ ~p(o - ~~~ C~SC~~ Date• ~. `m' u.~ ~ eta - ~-~ t ~ ~~~ Signed ~----~ 5~ I V ~~ STATE OF ALASKA 5EP `~ ~ ~~o~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATION~~~s~~ ~'~ & has ions. Commission v 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ 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 Welf Status: 5. Permit to Drill Number. .Conoco Phillips Alaska, lnc. Development 0 Exploratory ^ 206-178 / 3. Address: Stratigraphic ^ Service ^ 6. API Number. P. O. Box 100360, Anchorage, Alaska 99510. 50-029-23337-61 7. KB Elevation (ft): 9. Well Name and Number: RKB 109' ~ 1J-118L2 ' 8. Property Designatign: 10. Field/Pool(s}: ADL 25661 &ADL 25650 ' Kuparuk River Field /West Sak Oil Pool ~ 11. Present Well Condition Summary:. .Total Depth measured 14822' ~ feet true vertical 3742' ~ feet plugs (measured) Effective Depth measured 14815 feet Junk (measured) true vertical 3741 feet 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' Slotted Liner 7613' 5-1/2" x 4-1/2" 14815' Perforation depth: Measured depth: 7443' - 14783' true vertical depth: 3626'- 3740' Tubing (size, grade, and measured depth) 4-1l2" , L-80, 7190' MD. Packers &SSSV (type & measured depth) PKRS. = BAKER'ZXP' LINER TOP PACKERS PKRS = 7146'_; 7312'; 7851' SSSV= NIP SSSV= 503' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 4~° ~~, S~~ ~ ~, ~~~~ Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 1396 1584 45 806 272. Subsequent to operation 1503 526 229 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run - ,, ' Exploratory ^ Development ^ Service ^ Daily Report of Well Operations X 16. Well Status after proposed work: Oit^ Gas^ WAG[] GINJ^ WINJ Q WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or NIA if C.O. Exempt: 307-149 contact Bob Christens .Bob Buchholz Printed Namefi. ` obe ~`Chr to sen Title Production Engineering Technician Signature ~ Phone 659-7535 Date '' /,j ~~ 7T' ( ~' ~ 9' ZG - a'7 G R1 0 Form 1 0-404 Revi sed 4/ 0 2004 Submit Ori in al Onl 9 Y 1J-118L2 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 08/31/07 Commenced Water Injection Service ! ~ T'o: State of Alaska June 1, 2007 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`" Avenue, Suite 100 Anchorage, Alaska RE: MVVD Formation Evaluation Logs 1 J-118 L2 AK-MW-4884845 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23337-61 PLEASE ACKNOWLEDGE RECEIPT BY SIGIVZNG AND RETURNING A COPY OF THE TRANS4IITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ~~ ~ :~ ~_~ ,.may Date: ,t: ; Signed: ~O(D - 1 ~ ~ ~` ill ~~( • 11-May-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-118 L2 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 7,154.43' MD Window /Kickoff Survey 7,206.00' MD (if applicable) Projected Survey: 14,822.00' 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,~~,,,~._~.1~~-v'1 Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~d~~~?~ ConocoPhillips April 17, 2007 RECEIVED Commissioner APR 2 5 2007 State of Alaska 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 1J-118, 1J-118L1, 1J-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. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 RT/skad STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION °~ E~,EIVED ~; ~ ~ 2 5 2007 WELL COMPLETION OR RECOMPLETION REPOR~~;;~~f[~ ~SQ~, Commission 1a. WeII Status: Oil Q Gas Plugged ^ Abandoned ^ Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. well Class: r~flC~i0f896 Development ^/ ~ Exploratory ^ Service ^ StratigraphicTest^ 2. Operator Name: ConocoPhillipsAlaska, Inc. 5. Date Comp., Susp., p ~ p1 11 ~(•~ orAband.: March~A`2007 12. Permit to Drill Number: 206-178 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: ~~~ $~ ~7 February 6, 2007 ~•~D' 13. API Number: ~ 50-029-23337-61 ' 4a. Location of Well (Governmental Section): Surface: 1914' FSL, 2366' FEL, Sec. 35, T11N, R10E, UM ' 7. Date TD Reached: March 15, 2007 ~ 14. Well Name and Number: 1J-118L2 Top of Productive Horizon: 1939' FNL, 2226' FWL, Sec. 36, T11N, R10E, UM 8. KB (ft above MSL): ~~ ~ Ground (ft MSL): 81' y(,ja~ 15. Field/Pool(s): '7 Kuparuk River Field Total Depth: 368' FSL, 2024' FWL, Sec. 24, T11 N, R10E, UM 9. Plug Back Depth (MD + TVD): 14815' MD / 3741' 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): ~ 14822' MD / 3742' ND ~ 16. Property Designation: ADL 25661, 25650 TPI: x- 563423 y- 5947190 Zone- 4 Total Depth: x- 563154 ~ - 5954775 ~ Zone- 4 11. SSSV Depth (MD + TVD): nipple @ 503' 17. Land Use Permit: 471, 468 18. Directional Survey: Yes ^/ 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): If(~p : 72j~ 'IY.-~~ ~("~/ ' ?VD GR/Res, USIT .3p.07 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 34" 78.6# H-40 28' 108' 28' 108' 42" 36o 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 Class G 5.5" X 4.5" 11.6# L-80 7202' 14815' 3605' 3741' 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; Pertoration Size and Number): SIZE DEPTH SET (MD) PACKER SET tubing in main wellbore 7146' slotted liner from 7953'-8196', 8734'-9021', 9307'-9593', 10225'-10632', 11101'-11245', 11887'-12141', 12595'-12843', 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 13350'-13608', 14075'-14326' MD DEPTH INTERVAL (MD) AMOUNTAND 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 653 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 i 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 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. .. .. ) 1 NONE _ ..~'-~ ~'b 9 t j 4_.1'`1° ..a Form 10-407 Revised 2/2007 Q R ~ G ~ N A L CONTINUED O ,; ~ ~AY 9 ~ 2~Q7 ti/ ~ ~ ~ ./ ,~~,. ~,7 U! ~`1 ~ ~ ~T~~~ r ~ 28. GEOLOGIC MARKERS (List all formations and mar 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 D Top 7207' 3606' West Sak D Bottom 14822' 3742' N/A 1 pv rA.,1, Formation at total depth: Y _~ 4 8 22' 3742' 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Surveyfslotted liner detail sheets 31. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Dennis Hartwig @ 265-6862 Printed Nam. Rand omas , Title: Drillino Team Leader - - Signature ~ ~ 5O Date p_gg~g -Z C-, ~ 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 Time Lo gs Date Frorn To Dur 5- DrFth _ E Depth f'ha~e Code Subco+~ T COM _ _ ~~ 03/07/2007 05:00 07:15 2.25 7,755 7,312 COMPZ RPCOti OTHR P Contto 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 RPCOti DHEO 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 RPCOh TRIP P POOH from 7,312' to Baker running tool at 20' 10:30 12:00 1.50 20 0 COMPZ RPCOti PULD P POOH. LD running fool and slim hole MWD, cleared and cleaned rig floor. calc 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 RtH with milling 8HA #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 ~j 13L of high side, tagged "B" lat ZXP at ~~~ 7,312', set WS and sheared off from- ' samewith top of WS at 7,206 , st wt up 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 BFMOBM to 8.45 ppg MOBM (to fin. u w/millin ) -- _~_~ - ~~~e ~D of 28 -a--c ~~-~ ~~ ~~ Il J Time Logs _ _ Date From To Dur S. Depth E. De th _ Phase Code Subcode T COM --- -- 03/08/2007 01:00 08:45 7.75 7,206 7,248 PROD3 STK WPST P Milled window in "D" lateral from 7,206' to 7,218' then milled to 7,248' MD/ 3,612' TVD with gauge hole to 7,238', milted at 2-10K WOM, 100 rpm's, 4-8K ft-Ibs torque, 283 gpm at 2,280 si. ~'~ 08:45 09:45 1.00 7,248 7,248 PROD3 STK CIRC P Pumped wt'd hi vis sweep (2# over MW) and polished window while circ out sweep, went thru window several times with no pump and had no problems, st wt up no pump 126K, do wt 95K 09:45 10:00 0.25 7,248 7,248 PROD3 STK OTHR P Monitored well-static, pumped dry job and blew down to drive. 10:00 12:45 2.75 7,248 180 PROD3 STK TRIP P POOH with milling assembly from 7,248' to BHA at 180'. 12:45 15:00 2.25 180 0 PROD3 STK PULD P POOH LD BHA #8, LD mills and MWD, upper mill was in gauge, cleared ri floor 15:00 15:30 0.50 0 0 PROD3 STK OTHR P RU and flushed out BOP stack after millin window. 15:30 15:45 0.25 0 0 PROD3 DRILL PULD P Pulled wear bushing and installed test lu . 15:45 21:00 5.25 0 0 PROD3 WELCT BOPE P RU and tested BOPE, tested valves, manifold and rams including annular to 250 psi low and 3,000 psi high, tested with 4" and 4 1/2" test jts. Tested rig alarms and koomey, initial press. 3,000 psi, after closing rams, 1,900 psi, took 42 sec. to gain 200 psi and 3:00 min for full recovery, have 5-nitrogen bottles ave 2,150 psi. NOTE: Chuck Scheve with AOGCC waived witnessin of the test. 21:00 21:30 0.50 0 0 PROD3 DRILL PULD P Installed wear bushing 21:30 22:30 1.00 0 0 PROD3 RIGMN SVRG P Held PJSM then slip and cut 78' of drl line. 22:30 22:45 0.25 0 0 PROD3 DRILL SFTY P Held PJSM with rig crew and Sperry Sun reps on PU and MU of Geopilot BHA. 22:45 00:00 1.25 0 60 PROD3 DRILL PULD P Began MU 6 3/4" BHA #9 with Geo ilot and MWD RIH to 60' 03/09/2007 00:00 02:15 2.25 60 370 PROD3 DRILL PULD P Fin MU Geopilot BHA #9 RIH to 370', MU MWD and uploaded same then RIH with NMFDC's, HWDP and ~ars. 02:15 03:15 1.00 370 370 PROD3 DRILL OTHR T Trouble shoot problem with Geospan, found to be froze u in a valve. 03:15 03:30 0.25 370 370 PROD3 DRILL DHEO P Shallow tested MWD and broke in eo ilot. 03:30 06:30 3.00 370 7,248 PROD3 DRILL TRIP P RIH from 370' to 7,180' (TOW 7,206') RIH thru window with no problems then RIH washing down from 7,235' to 7,248'. l r ~~ Time Logs Date From To Dur S. D~th E. Depth Phase Code Subcode T COM -- _ _ ____ - 03/09/2007 06:30 12:00 5.50 _ 7,248 _ 7,925 _ PROD3 DRILL - - DDRL P Directionally drilled 6 3/4" hole in "D" sand lateral with geopilot from 7,248' to 7,925' MD/3,638' TVD (677') ADT 3.16 hrs. ave 8.5 ppg MOBM MW and ave 9.95 ppg ECD, ave 60 units BGG, max as 117 units. 12:00 00:00 12.00 7,925 9,186 PROD3 DRILL DDRL P Directionally drilled 6 3/4" hole in "D" sand lateral with geopilot from 7,925' to 9,186' MD/3,662' TVD (1,261') ADT 6.34 hrs. ave 8.5 ppg MOBM MW, ECD ave 10.2 ppg, ave 60 units BGG, max as 224 units. 03/10/2007 00:00 09:15 9.25 9,186 9,720 PROD3 DRILL DDRL P Directionally drilled 6 3/4" hole in "D" sand lateral with geopilot from 9,186' to 9,720' MD/3,675' TVD (534') ADT 6.45 hrs. ave 8.45 ppg MOBM MW, ECD ave 10.0 ppg, ave 50 units BGG, max gas 160 units. Drilled thru 3 concretions for 40'. 09:15 10:00 0.75 9,720 9,720 PROD3 RIGMN RGRP T Re-aligned torque tube for top drive. 10:00 00:00 14.00 9,720 10,631 PROD3 DRILL DDRL P Directionally drilled 6 3/4" hole in "D" sand lateral with geopilot from 9,720' to 10,631' MD/3,681' TVD (911') ADT 9.25 hrs. ave 8.40 ppg MOBM MW, ECD ave 10.2 ppg, ave 50 units BGG, max gas 100 units. drilled thru 10 concretions for 90'. 03/11/2007 00:00 12:00 12.00 10,631 11,566 PROD3 DRILL DDRL P Directionally drilled 6 3/4" hole in "D" sand lateral with geopilot from 10,631' to 11,566' MD/3,701' TVD (935') ADT 7.7 hrs. ave 8.45 ppg MOBM MW, ECD ave 10.5 ppg, max ECD 10.75 ppg ave 60 units BGG, max gas 107 units. drilled thru 5 concretions for 59'. 12:00 00:00 12.00 11,566 12,126 PROD3 DRILL DDRL P Directionally drilled 6 3/4" hole in "D" sand lateral with geopilot from 11,566' to 12,126' MD/3,706' TVD (560') ADT 8.4 hrs. ave 8.45 ppg MOBM MW, ECD ave 10.45 ppg, max ECD 10.60 ppg ave 60 units BGG, max gas 93 units. drilled thru 8 concretions for 81'. 03/12/2007 00:00 01:15 1.25 12,126 12,174 PROD3 DRILL DDRL P Drilled from 12,126'to 12,174' MD/3,709' TVD 48' ADT 1.3 hrs 01:15 01:45 0.50 12,174 12,174 PROD3 DRILL DHEO T Trouble shoot weak MWD signal, cleaned screens, swapped mud pumps and checked pulsation dam Hers. ~~ ~ ma _._ _® ~~ m_ F~ge 22 of 23 ~~ Time Logs - - _- Date From To Dur S De th E De th Phase Code -- Subcode _ T _ COM 03/12/2007 01:45 03:15 1.50 12,174 12,217 PR©D3 DRILL _ DDRL P Drilled from 12,174' to 12,217' MD/3,711' TVD (43') ADT .80 hrs, cont. to trouble shoot MWD while drilling on concretion, on last conn. had picked up 1st std of HWDP and saw a increase of 200 psi on the standpipe press., stood back std HWDP and PU 1 std of slick DP and had no change in pressure or signal. drilled thru 2 concretions for 21'. 03:15 05:45 2.50 12,217 12,217 PROD3 DRILL DHEO T Cont. to trouble shoot MWD with no success in getting a good signal. Decision was made to POOH. 05:45 09:45 4.00 12,217 9,328 PROD3 DRILL REAM T Backreamed out of hole 5 stds from 12,217' to 11,750', then cont to POOH 2 stds and backreaming 1 to 9,328', pulled tight at 10,575' and backreamed thru w/no problems, hole took 1.5 bbls over talc hole fill BROOH, BROOH at 300 gpm, 2,40 psi and 120 pm's, st wt u 130K, do wt 55K. 09:45 11:00 1.25 9,328 7,180 PROD3 DRILL TRIP T POOH on elevators from 9,328' to above TOW to 7,180' (TOW @ 7,206') hole took 1 bbl over talc fill. 11:00 12:30 1.50 7,180 7,180 PROD3 DRILL CIRC T Pumped 30 bbl wt'd (2# over mw) hi vis sweep and circ out of hole, had 5% increase in cuttings (mostly wt material), circ at 300 gpm, 2,400 psi, rot at 100 rpm's with 5K ft-Ibs torque, while circ sweep MWD began to work and decision was made to RIH. 12:30 14:00 1.50 7,180 9,888 PROD3 DRILL TRIP T RIH from 7,180' to 9,888' and lost all do wt, filled pipe while RIH and MWD ck'd ok. 14:00 14:30 0.50 9,888 10,075 PROD3 DRILL REAM T Began washing down from 9,888' and at 10,075' MWD tool lost it's si nal. 14:30 14:45 0.25 10,075 10,075 PROD3 DRILL OWFF T Monitored well-static, blew down top drive 14:45 19:00 4.25 10,075 370 PROD3 DRILL TRIP T POOH on elevators from 10,075' to BHA at 370'. 19:00 22:00 3.00 370 0 PROD3 DRILL PULD T Stood back HWDP, jars and NMFDC's, downloaded MWD then LD MWD and bit, inspected BHA and found no obstructions or visible signs of MWD failure. 22:00 22:30 0.50 0 0 PROD3 DRILL OTHR T Serviced geopilot and inspected NM on flex DC and all ck'd ok. 22:30 00:00 1.50 0 85 PROD3 DRILL PULD T Began MU BHA #10 RIH to 85', MU bit #6 on geopilot and MU BHA to MWD tool. 03/13/2007 00:00 00:15 0.25 85 85 PROD3 DRILL PULD T Continue to MU BHA #10 00:15 01:15 1.00 85 85 PROD3 DRILL PULD T Upload MWD 01:15 02:00 0.75 85 370 PROD3 DRILL TRIP T RIH, Shallow test MWD, downlink eo- ilot w _~ ~ _~® ~ P~~> .'~.;s of • Time Logs --- --- Date From__ To___ __ Dur S Depth_ E,_Depth_Phase Code Subcode T__ COM 03/13/2007 02:00 06:30 4.50 370 10,169 PROD3 DRILL TRIP T RIH to window, slide thru window with no problems. Continue to RIH until run out of S/O wei ht. 06:30 09:00 2.50 10,169 12,217 PROD3 DRILL REAM T Ream in hole, pumping 180gpm, 1150 si, rotatin 100 m 09:00 12:00 3.00 12,217 12,390 PROD3 DRILL DDRL P Drill ahead until crew change. Drilled 4 concretions, total 10'. ART 1.8hrs, max as 93 units, ECDs 10.74 12:00 00:00 12.00 12,390 13,124 PROD3 DRILL DDRL P Drill ahead, 8 concretions totaling 49'. ART 7.5hrs, max gas 97 units, ECDs 10.82 03/14/2007 00:00 12:00 12.00 13,124 14,013 PROD3 DRILL DDRL P Drill ahead. ART 7.7 hrs, max gas 127 units, ECDs 10.8. 6 concretions for total of 42'. 12:00 00:00 12.00 14,013 14,684 PROD3 DRILL DDRL P Drill ahead. ART 7.5 hrs, max gas 131 units, ECDs 11.18. 6concretions - total of 35'. 03/15/2007 00:00 01:30 1.50 14,684 14,822 PROD3 DRILL DDRL P Drtlg to TD - 14,822' MD / 3742' TVD, ART 1.2 hrs, Max as 55 units 01:30 02:00 0.50 14,822 14,822 PROD3 DRILL SRVY P Circu 10 min -Survey TD -Record SPR's -Monitor Well 02:00 06:30 4.50 14,822 12,200 PROD3 DRILL REAM P BROOH at drilling rates to last trip point. PR 315 gpm, 130 RPMs. Pull last 2 stds slow to let hole clean up. Max as 85 units 06:30 09:45 3.25 12,200 14,822 PROD3 DRILL REAM P Monitor well "Static" -Wash and Ream bk to bttm. PR 180 gpm, RPM's 100 09:45 12:00 2.25 14,822 14,822 PROD3 DRILL CIRC P Pump wt/hi vis sweep, PR 300 gpm, 135 RPMs, Recip string full 94', Saw 30% cutting increase on BU- Con't Circu at iven rates. Crew Chan e 12:00 15:45 3.75 14,822 14,822 PROD3 DRILL CIRC P Circu total 4 BU -Shakers clean - PR 300 m, 135 RPMs, Reci strin 94' 15:45 17:15 1.50 14,822 14,822 PROD3 DRILL CIRC P Disp well over to SFMOBM - PR 300 gpm, 135 RPMs, Recip drill string 94' - Pum ed total 620 bb-s. 17:15 17:30 0.25 14,822 14,822 PROD3 DRILL TRIP P PJSM tripping hazards -Observe well "Static" 17:30 00:00 6.50 14,822 4,755 PROD3 DRILL TRIP P POOH on elevators -Dropped 1-13/16" drift w/wire tail. Up wt 220k, Dn wt 42k 03/16/2007 00:00 02:00 2.00 4,755 370 PROD3 DRILL TRIP P Continue to POOH 02:00 03:00 1.00 370 75 PROD3 DRILL TRIP P UD BHA, HWDP, JARS and Drill collars 03:00 04:00 1.00 75 75 PROD3 DRILL TRIP P Download BHA 04:00 05:00 1.00 75 0 PROD3 DRILL TRIP P Continue to UD BHA 05:00 05:30 0.50 0 0 COMPZ RIGMN SVRG P Clear and clean rig floor 05:30 07:00 1.50 0 0 COMPZ RIGMN SVRG P Slip and cut 80' drilling line. Inspect saver sub. 07:00 07:30 0.50 0 0 COMPZ CASIN RURD P RU casing equipment ~ ~ - ~ ®~ ~ .. ~«~ Z~ cry Zf# C~ Time Logs Date From 7o Dur__ S Depth E. De th Phase _, Code Subco~e T COM 03/1612007 07:30 07:45 0.25 0 0 COMPZ CASIN SFTY P PJSM-Haxxard recognition 07:45 12:00 4.25 0 4,968 COMPZ CASIN( RUNL P Run 4 1/2" liner. Calculated displacement 20.16 BBLS, actual dis lacement 16.2 BBLS. 12:00 12:15 0.25 4,968 4,698 COMPZ CASIN( SFTY P Crew change, PJSM 12:15 14:00 1.75 4,698 7,372 COMPZ CASINC RUNL P Continue running liner 14:00 14:45 0.75 7,372 7,446 COMPZ CASINC RUNL P PU and RIH with tieback assembly 14:45 21:30 6.75 7,446 14,815 COMPZ CASINC RUNL P RIH with liner on DP. Lost S/O weight at 10,900. Started rotating. Rotate IH, one small tight spot @ 14,636' MD, Work thru and tag bttm. Pick up to 7379' MD TOL (Bttm @ 14,815' MD. Up wt 245K, Rot wt down 80K, Torq 10-11 K. 21:30 22:15 0.75 14,815 7,379 COMPZ CASIN RUNL P Drop ball and pump down. Ball on seat, pressure up to 3000 PSI and release liner, Up wt 145K. Top of tie back @ 7379' MD. Shear ball seat @ 4250 si -Monitor well "Static" 22:15 00:00 1.75 7,379 4,150 COMPZ DRILL TRIP P POOH @ 4150' MD 03/17/2007 00:00 02:00 2.00 4,949 0 COMPZ DRILL TRIP P PJSM on Tripping -POOH 4949' to Surface -Make all service breaks on runnin tools. UD same. 02:00 02:30 0.50 0 0 COMPZ CASINC RUNL P Clean & Clear rig floor 02:30 03:00 0.50 0 271 COMPZ DRILL PULD P MU Whipstock retreiving tool,1 jt 3 1/2" HWDP, Bumper Sub, Oil Jars, Flt sub, XO, 2 stds Push i e 03:00 06:15 3.25 271 7,211 COMPZ DRILL TRIP P TIH w/ Whipstock Retv tool t/ 7193' MD - Up wt 140k, Dn wt 82k, PU 1 single & wash to 7211' MD -Hook set on first attem t. 06:15 06:45 0.50 7,211 7,211 COMPZ DRILL OTHR P Hook Whipstock and fired jars 5 times staging up to 65K overpull. Pulled free Pu wt 120K -Hole took 2 bbls fluid. 06:45 07:30 0.75 7,211 7,193 COMPZ DRILL CIRC P Pull to 7193' MD - CBU - PR 255 gpm- Max as 41 units 07:30 12:00 4.50 7,193 60 COMPZ DRILL TRIP P Monitor Well -Blow Down Top Drive - UD single -POOH t/ 60.0' MD """'* Crew Chan e 12:00 13:00 1.00 60 0 COMPZ DRILL PULD P PJSM - UD Oil Jars -Bumper sub- Whi stock and tale ass . 13:00 13:45 0.75 0 0 COMPZ CASIN RUNL P Clean & Clear Rig floor 13:45 14:00 0.25 0 0 COMPZ CASINC RUNL P PJSM -Hazard Recognition picking up Hook Han er 14:00 16:00 2.00 0 236 COMPZ CASIN PUTB P PU Hook Hanger assy. per detail - PU and orient MWD 16:00 16:30 0.50 236 329 COMPZ CASIN RURD P TIH @ 329' Shallow test MWD - "OK" -Blow down To Drive. __ ~..~ ~__ ~ r~~a ?~ t~f 7Ya J Time Logs Date From To Dur S. De th E. De th .Phase Code Subcode T COM 03/17/2007 16:30 20:00 3.50 329 7,351 COMPZ CASINC PUTB P TIH w! Hook Hanger assy. First attempt tag mother bore @ 7351' MD - PU above window and apply 3 3/4 right hand raps. When out window on third attem t. U wt 145K, Dn wt 90K 20:00 20:30 0.50 7,351 7,430 COMPZ CASINC RUNL P Orient & hook 16R at 7430'. PU 15' orient 180 deg. and tag at 7438' -liner nogo. PU 25' reorient and rehook at 7430'. 20:30 21:00 0.50 7,430 7,430 COMPZ CASINC RUNL P Drop ball. Seated at 702 strokes. Pressure up to 2000psi. Monitor then increase to 2600psi. ESP inflated. Bleed down and stabilized at 950psi. Pressure back up to 2600psi. Pressure held. Increased pressure to 3000psi then bleed off pressure. PU to 160k, 15k over ull, did not release. 21:00 21:30 0.50 7,430 7,430 COMPZ CASINC RUNL T SO to 30k and attempt to shear ball seat, pressured up to 4500psi. Did not shear. Bleed off pressure and PU to 160k. Made several attempts to release working pipe up to 155k and SO at 45k. Would not release. 21:30 22:45 1.25 7,430 7,430 COMPZ CASINC RUNL T Attempt safety release. 1 1/4 turns 5000# lefthand torque. Recip pipe attempting to work torque down to tools. Unable to work torque down to tools. 22:45 00:00 1.25 7,430 7,430 COMPZ CASINC RUNL T PJSM-LD single, blowdown top drive. RU test pump manifold and cement line on 10' pup joint. SO to 40k. Pressure up to 3500psi with rig pump, isolate from mud line and pressure up to 5000psi with test pump. Ball seat would not shear. Continue working i e. 03/18/2007 00:00 02:00 2.00 7,430 7,427 COMPZ CASIN RUNL T Continue attempts to release from hook hanger. Called town for recommendations. Advised to pull to 175k. Tools released. PU 3' and circulate to confirm release. 02:00 05:30 3.50 7,427 0 COMPZ CASIN RUNL P Monitor well. Slowdown topdrive. POOH. 05:30 06:00 0.50 0 0 COMPZ CASIN( RUNL P Service brake, lay down running tools and MWD. An examination of the running tool found the ball seat had sheared and the lefthand safety release had released. There were metal shavin sin the tools. 06:00 06:30 0.50 0 0 COMPZ CASINC RUNL P Clear and clean rig floor. 06:30 07:00 0.50 0 0 COMPZ CASIN RUNL P RU 4 112" casing tools 07:00 07:15 0.25 0 0 COMPZ CASINC RUNL P PJSM-running LEM 07:15 09:00 1.75 0 50 COMPZ CASINC RUNL P PU and orient LEM assembly 5 ~a~ 2~i ~f ~ ~ C~ l J Time Logs __ _ _ --- Date From To Dur S. De th E. De th_ Phase Code Subcode T_ COM 03/18/2007 09:00 09:15 0.25 50 225 COMPZ CASIN( RUNL P RIH and shallow test MWD at 225', 40s m, 650 si. 09:15 12:00 2.75 225 3,989 COMPZ CASIN( RUNL P RIH with LEM 12:00 12:15 0.25 3,989 3,989 COMPZ CASIN( RUNL P Crew change. PJSM-running in hole, hazard reco nition. 12:15 14:00 1.75 3,989 7,346 COMPZ CASIN( RUNL P Tag 10k at 7200'. PU 145k - SO 85k. Pickup, rotate 1.5 turns and entered sealbore to 7332'. Stacked 15k. Twice PU @ 160k. Break circulation @ 3bpm, 80psi. Wash down clean to 7346. Latch and stack 30k, 31degrees right. PU and came free at 170k: SO to 7346' and stack 30k, 28degrees ri ht. 14:00 15:00 1.00 7,346 7,346 COMPZ CASIN RUNL P Drop and pump ball. 592 strokes to seat. Pressure up to 2300psi, pause and continue up to 4000psi. Bleed off and test back side of packer with 2500psi for 10 minutes. bleed off and pickup. Pulled free at 140k. (T.O.L. @ 7146' MD). Monitor well-static. Slowdown to drive 15:00 17:45 2.75 7,346 50 COMPZ CASINC RUNL P POOH 17:45 18:30 0.75 50 0 COMPZ CASINC RUNL P LD MWD. break out and lay down runnin tools. 18:30 19:00 0.50 0 0 COMPZ CASINC RUNL P Pull wear ring. 19:00 20:30 1.50 0 0 COMPZ CASINC RUNL P RU to run 4 1/2" tubing. 20:30 20:45 0.25 0 0 COMPZ RPCOh RCST P PJSM-running tubing 20:45 00:00 3.25 0 3,083 COMPZ RPCO RCST P RIH with 4 1/2" completion 03/19/2007 00:00 03:30 3.50 3,083 7,193 COMPZ RPCOh RCST P PJSM running Tbg - Con't to run 4.5 12.6# L80 I BT Tb f/ ~ts 100 - 229 03:30 05:00 1.50 7,185 7,185 COMPZ RPCOh CIRC P PU above seals and circu 2 BU to clean up tbg and hole. PR 320 gpm, PP 860 PSI, Loss 3.3 bbls) 05:00 05:30 0.50 7,193 7,193 COMPZ RPCOb RCST P Tag No Go w/ 10k @ 7193.33' - Up wt 85K, Dn wt 55k 05:30 06:00 0.50 7,185 7,185 COMPZ RPCOh HOSO P PU tubing hanger, space out w/9.82' u 06:00 08:00 2.00 7,185 7,190 COMPZ RPCOti RCST P Land tubing @ 7190.3 / RILDS. Test hanger seals to 5000 psi for 10 minutes. 08:00 08:15 0.25 0 0 COMPZ RPCO SFTY P PJSM - ND BOP 08:15 09:30 1.25 0 0 COMPZ RPCO NUND P ND BOP 09:30 12:00 2.50 0 0 COMPZ RPCOA NUND P NU tree and RU to test 12:00 12:15 0.25 0 0 COMPZ RPCOh SFTY P Crew change. PJSM 12:15 13:00 0.75 0 0 COMPZ RPCOh SFEQ P Test tree w/5000 psi for 10 minutes. Pull 2-wa check valve. l~____ m~ ~_ - .ea ..~ mO ~~~~~o~~ Time Logs - -- _- - .Date From To Dur S. De th E. De th Phase Code Subcode T COM 03/19/200713:00 16:00 3.00 0 0 COMPZ RPCOh FRZP P Pressure test lines w/3000 psi. Pump 315 bbls diesel @ 2 bpm. Full returns. Shut in and blowdown lines. 16:00 18:45 2.75 0 0 COMPZ RPCOh RURD P RU scaffolding and PU lubricator. Install back pressure valve. RD ~ scaffoldin and set mouse hole. 18:45 19:00 0.25 0 0 COMPZ RPCOh SFTY P PJSM -pinch point recognition. 19:00 22:00 3.00 0 0 COMPZ RPCO PULD P LD 135 joints of drillpipe with sliders. Remove sliders in the pipe shed. LD 24 'oints of slick drill i e. 22:00 00:00 2.00 0 0 COMPZ RPCOh PULD P LD 25 WXDP and 8 DCs 03/20/2007 00:00 08:30 8.50 0 0 COMPZ RPCOh PULD P Continue LD hybrid DC and 276 joints of stick drill i e. Clear ri floor. 08:30 10:00 1.50 0 0 COMPZ RPCO PULD P Change out geo-span, due to hours. Finish cleaning pits. RELEASE RIG 10:00 3/20. ~___..__ ~ u. ~.__ ~ _ _v t'z~r~~~ ~~3 ~~f 2~ Halliburton Company Survey Report Companyi ConocoPhillips Alaska Inc. Date: 4/1 1 12 0 0 7 Time: 10:01:10 Page: 1 Field: Kuparuk River Unit Co-ordinate(NE)Reference: `'Wet11J-118, Tru e North 5itc Kuparuk 1J Pad Vertical (TVD)Re fercnce: 1J-118L2: 109.0 ~~ ell: 1 J-1 ~ c: Section (VS) Reference: Well (O.OON,O.OO E,O.OOAzi) ~~ellh~th: 1 J-1 18L2 Survey Calculation Mcthod: Minimum Curvature Db: Oracle Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Sy stem: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: 1 J-118 Slot Name: i Well Position: +N/-S -192.83 ft Northing: 5945727.24 ft Latitude: 70 15 44.361 N +E/-W 52.25 ft Easti ng : 558843.70 ft Longitude: 149 31 27.486 W Position Uncertainty: 0.00 ft Survey __ MD lncl Azim TVll SvsTVD N/S E/1~' iYtapiV 1iapE' Tuui 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 i 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 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 i 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 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 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 Wellpath: 1J-118L2 Drilled From: 1J-118P61 ~, 500292333760 Tie-on Depth: 7154.43 ft ~I Current Datum: 1 J-118L2: 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 1 Date: 4/11/2007 Validated: No Version: 2 Actual From To Survey Toolcode 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 7154.43 1J-118PB1 (952.48-8930.79) (3) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7206.00 14784.65 1J-118L2 (7206.00-14784.65) i MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Halliburton Company Survey Report __ ___ ', Company: ConocoPhillips Alaska Inc. _ llate: 4/11/2007. . -_ Time: 10:01:10 Page: 2 Field: Ku paru k River Unit Co-or dinate (NE) Reference: Well: 1J-11 8, Tru e Nerth Site: Ku paru k 1J Pad Vertical ('1'V D)Reference:' 1J-118L2: 109.0 Nell: 1J- 11.8. Section (VS) Reference: Well (O:OON,O.OO E,O.OOAzi) Wcl]path: 1J- ~ 18L2 Surve y l~;ilc alatio nMethod: INiniil~um C urvature Db: Oracle __ Survey MD Inc l Azim TVD Sy~llD N/5 Elyl ~Iap1V' JIapE 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 2030. 52 62. 36 91. 96 1757. 83 1648. 83 16. 95 773. 21 5945750. 23 559616. 68 MWD+IFR-AK-CAZ-SC I 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 i 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 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+tFR-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 i 3295. 41 64 .01 92. 70 2192. 57 2083. 57 -44. 40 1958. 07 5945698. 15 560801. 87 MWD+IFR-AK-CAZ-SC t 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. i 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 4213. 33 66 .69 93. 72 2556. 59 2447. 59 -97. 12 2798. 85 5945652. 00 561642 .96 MWD+fFR-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 j 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 ~~ I i • • Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. llate: 4/11/2007 Time: 10:01:10 Page: 3 Field: Kuparuk River Unit Co-ordinate(NE) Reference: 'Weil: 1J-118, True North Sitc: Kuparuk 1J Pad Vertical (TVD) Reference: 1J-118L.2: 109.0 Well: 1J-118 Section(VS)Reference: Well'(O.OON,O.OOE,O.OOAzi) ~'ellpath: 1J-118L2 Survey Calculationllethod: MinimuniCurvalure Db: Oracle __ __ Suncv -_ -- - MD Incl Azim TVD Sys TVD N/S E/1V A1apIV ~taph: Tool ft deg deg ft ft ft ft ft fl 6588.77 70.38 16.05 3445.16 3336.16 835.79 4551.62 5946598.49 563388.21 MWD+IFR-AK-CAZ-SC 6681.74 72.83 12.14 3474.50 3365.50 921.33 4573.08 5946684.19 563409.00 MWD+IFR-AK-CAZ-SC 6777.79 74.24 7.05 3501.74 3392.74 1012.12 4588.41 5946775.09 563423.62 MWD+IFR-AK-CAZ-SC 6869.50 73.93 2.38 3526.90 3417.90 1099.99 4595.66 5946863.00 563430.18 MWD+IFR-AK-CAZ-SC 6964.12 75.87 358.76 3551.56 3442.56 1191.31 4596.55 5946954.32 563430.36 MWD+IFR-AK-CAZ-SC 7058.97 75.11 358.72 3575.32 3466.32 1283.12 4594.54 5947046.10 563427.63 MWD+IFR-AK-CAZ-SC 7154.43 79.30 358.11 3596.46 3487.46 1376.15 4591.96 5947139.10 563424.32 MWD+IFR-AK-CAZ-SC .~ 7206.00 79.56 357.71 3605.92 - 3496.92 1426.81 4590.11 5947189.74 563422.08 MWD+IFR-AK-CAZ-SC 7229.88 81.97 357.89 3609.75 3500.75 1450.36 4589.20 5947213.28 563420.99 MWD+IFR-AK-CAZ-SC 7324.15 86.07 358.56 3619.57 3510.57 1544.05 4586.30 5947306.94 563417.36 MWD+IFR-AK-CAZ-SC 7417.61 87.00 359.22 3625.22 3516.22 1637.32 4584.50 5947400.18 563414.82 MWD+IFR-AK-CAZ-SC i I 7511.68 89.72 0.57 3627.91 3518.91 1731.34 4584.32 5947494.19 563413.91 MWD+IFR-AK-CAZ-SC 7604.98 87.56 357.76 3630.13 3521.13 1824.59 4582.97 5947587.41 563411.83 MWD+IFR-AK-CAZ-SC 7698.75 88.73 357.53 3633.16 3524.16 1918.23 4579.11 5947681.01 563407.25 MWD+IFR-AK-CAZ-SC 7791.69 89.22 357.06 3634.82 3525.82 2011.05 4574.73 5947773.79 563402.14 MWD+IFR-AK-CAZ-SC i j 7885.12 88.36 355.57 3636.80 3527.80 2104.27 4568.73 5947866.94 563395.41 MWD+IFR-AK-CAZ-SC ~ 7980.37 88.48 356.38 3639.42 3530.42 2199.24 4562.04 5947961.85 563387.98 MWD+IFR-AK-CAZ-SC 8074.75 88.54 357.97 3641.88 3532.88 2293.47 4557.39 5948056.04 563382.60 MWD+IFR-AK-CAZ-SC 8166.48 88.48 357.88 3644.26 3535.26 2385.11 4554.07 5948147.64 563378.56 MWD+IFR-AK-CAZ-SC 8258.90 88.67 357.17 3646.56 3537.56 2477.42 4550.08 5948239.90 563373.85 MWD+IFR-AK-CAZ-SC 8351.36 88.97 353.90 3648.47 3539.47 2569.57 4542.89 5948331.98 563365.93 MWD+IFR-AK-CAZ-SC 8445.46 88.97 355.54 3650.16 3541.16 2663.25 4534.23 5948425.58 563356.55 MWD+IFR-AK-CAZ-SC 8540.26 88.73 357.73 3652.06 3543.06 2757.86 4528.67 5948520.14 563350.24 MWD+IFR-AK-CAZ-SC 8634.64 89.59 356.17 3653.44 3544.44 2852.09 4523.65 5948614.32 563344.49 MWD+IFR-AK-CAZ-SC 8724.65 91.13 351.26 3652.88 3543.88 2941.53 4513.80 5948703.67 563333.94 MWD+IFR-AK-CAZ-SC 8819.63 89.22 344.30 3652.59 3543.59 3034.30 4493.71 5948796.27 563313.13 MWD+IFR-AK-CAZ-SC 8870.45 89.71 341.69 3653.06 3544.06 3082.89 4478.84 5948844.73 563297.89 MWD+IFR-AK-CAZ-SC 8913.19 90.27 340.50 3653.07 3544.07 3123.32 4465.00 5948885.05 563283.73 MWD+IFR-AK-CAZ-SC I 8958.46 90.27 342.87 3652.86 3543.86 3166.29 4450.77 5948927.91 563269.17 MWD+IFR-AK-CAZ-SC 9006.93 88.91 344.57 3653.20 3544.20 3212.82 4437.19 5948974.32 563255.22 MWD+IFR-AK-CAZ-SC 9055.85 87.68 346.97 3654.66 3545.66 3260.21 4425.17 5949021.62 563242.83 MWD+IFR-AK-CAZ-SC 9099.05 87.06 348.05 3656.64 3547.64 3302.34 4415.83 5949063.67 563233.17 MWD+IFR-AK-CAZ-SC 9145.54 86.69 350.37 3659.18 3550.18 3347.94 4407.14 5949109.19 563224.12 MWD+IFR-AK-CAZ-SC 9192.68 87.12 352.28 3661.72 3552.72 3394.47 4400.04 5949155.66 563216.66 MWD+IFR-AK-CAZ-SC 9287.47 86.13 354.66 3667.30 3558.30 3488.47 4389.28 5949249.57 563205.17 MWD+IFR-AK-CAZ-SC j 9379.09 84.34 353.65 3674.91 3565.91 3579.30 4379.99 5949340.31 563195.16 MWD+IFR-AK-CAZ-SC 9429.86 86.26 356.23 3679.07 3570.07 3629.69 4375.53 5949390.66 563190.31 MWD+IFR-AK-CAZ-SC 9472.60 88.85 358.16 3680.90 3571.90 3672.34 4373.44 5949433.29 563187.89 MWD+IFR-AK-CAZ-SC 9518.71 90.83 2.07 3681.03 3572.03 3718.44 4373.53 5949479.38 563187.62 MWD+IFR-AK-CAZ-SC I, 9566.23 91.07 4.23 3680.24 3571.24 3765.87 4376.14 5949526.83 563189.86 MWD+IFR-AK-CAZ-SC 9618.78 91.69 4.34 3678.97 3569.97 3818.26 4380.07 5949579.24 563193.38 MWD+IFR-AK-CAZ-SC 9659.16 91.75 3.17 3677.76 3568.76 3858.54 4382.71 5949619.53 563195.70 MWD+IFR-AK-CAZ-SC 9714.14 91.32 1.00 3676.29 3567.29 3913.46 4384.71 5949674.46 563197.27 MWD+IFR-AK-CAZ-SC 9752.34 90.52 359.33 3675.67 3566.67 3951.65 4384.82 5949712.65 563197.08 MWD+IFR-AK-CAZ-SC 9846.70 88.61 356.22 3676.39 3567.39 4045.92 4381.16 5949806.88 563192.69 MWD+IFR-AK-CAZ-SC 9940.89 86.63 356.79 3680.30 3571.30 4139.85 4375.42 5949900.75 563186.22 MWD+IFR-AK-CAZ-SC 10033.18 91.69 359.81 3681.65 3572.65 4232.05 4372.68 5949992.92 563182.76 MWD+IFR-AK-CAZ-SC 10127.20 92.12 3.16 3678.53 3569.53 4325.97 4375.12 5950086.85 563184.46 MWD+IFR-AK-CAZ-SC 10219.68 92.62 3.36 3674.70 3565.70 4418.22 4380.37 5950179.13 563188.99 MWD+IFR-AK-CAZ-SC 10313.75 92.12 1.67 3670.81 3561.81 4512.12 4384.50 5950273.05 563192.38 MWD+IFR-AK-CAZ-SC 10406.09 88.61 359.66 3670.23 3561.23 4604.43 4385.57 5950365.36 563192.73 MWD+IFR-AK-CAZ-SC 10499.72 87.43 1.45 3673.46 3564.46 4697.99 4386.47 5950458.92 563192.91 MWD+IFR-AK-CAZ-SC 10594.15 87.68 1.26 3677.49 3568.49 4792.31 4388.71 5950553.24 563194.40 MWD+IFR-AK-CAZ-SC • Halliburton Company Survey Report • __ ___ _ __ Company: ConocoPhillips Alaska lnc. Date: 4/11/2007 Time: 10:01:10 Page= 4 E'ield: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1J-118, True North Site: KuparuklJPad Vertieal(TVD)Refercnce: 1J-118L2:109A R'elt: 1 J-118 Section (VS) Reference:. Well (O.OON,O.OOE,O.OOAzi) bY'ellpath: 1J-118L2 Survey Calculation ;Method: Minimum Curvature llb: Oracle Smti~cv VID Incl Azim TVD sys TVD N/S Eli' D1ap:V MapE Tool ft deg deg ft ft ft ft ft ft 10682.41 87.68 359.31 3681.06 3572.06 4880.49 4389.14 5950641.41 563194.15 MWD+IFR-AK-CAZ-SC 10774.84 88.79 359.94 3683.91 3574.91 4972.88 4388.54 5950733.78 563192.83 MWD+IFR-AK-CAZ-SC 10873.31 88.48 2.48 3686.26 3577.26 5071.29 4390.62 5950832.19 563194.13 MWD+IFR-AK-CAZ-SC 10967.34 90.15 4.32 3687.38 3578.38 5165.14 4396.19 5950926.08 5631.98.98 MWD+IFR-AK-CAZ-SC ! 11059.01 87.99 2.05 3688.87 3579.87 5256.64 4401.29 5951017.61 563203.35 MWD+IFR-AK-CAZ-SC ~i 11153.61 86.82 3.28 3693.15 3584.15 5351.04 4405.68 5951112.03 563207.01 MWD+IFR-AK-CAZ-SC !! 11246.54 88.66 1.99 3696.82 3587.82 5443.79 4409.95 5951204.80 563210.55 MWD+IFR-AK-CAZ-SC 11339.68 89.65 359.46 3698.19 3589.19 5536.91 4411.13 5951297.92 563211.00 MWD+IFR-AK-CAZ-SC ~ 11434.79 89.16 357.43 3699.18 3590.18 5631.97 4408.55 5951392.95 563207.68 MWD+IFR-AK-CAZ-SC 11527.31 89.72 357.52 3700.08 3591.08 5724.40 4404.47 5951485.33 563202.88 MWD+IFR-AK-CAZ-SC 11620.61 89.10 357.29 3701.04 3592.04 5817.60 4400.25 5951578.48 563197.93 MWD+IFR-AK-CAZ-SC 11714.25 89.84 0.96 3701.91 3592.91 5911.21 4398.82 5951672.07 563195.77 MWD+IFR-AK-CAZ-SC 11807.83 90.09 0.17 3701.97 3592.97 6004.78 4399.74 5951765.64 563195.96 MWD+IFR-AK-CAZ-SC 11901.53 88.98 356.99 3702.73 3593.73 6098.43 4397.42 5951859.26 563192.91 MWD+IFR-AK-CAZ-SC 11994.71 89.04 357.91 3704.34 3595.34 6191.51 4393.27 5951952.29 563188.04 MWD+IFR-AK-CAZ-SC 12090.10 88.40 356.66 3706.47 3597.47 6286.76 4388.76 5952047.50 563182.77 MWD+IFR-AK-CAZ-SC 12179.96 87.91 357.75 3709.36 3600.36 6376.47 4384.38 5952137.16 563177.69 MWD+IFR-AK-CAZ-SC 12268.42 88.90 357.62 3711.82 3602.82 6464.82 4380.80 5952225.47 563173.43 MWD+IFR-AK-CAZ-SC 12359.60 .89.21 0.65 3713.33 3604.33 6555.97 4379.43 5952316.60 563171.34 MWD+IFR-AK-CAZ-SC 12450.94 89.16 0.40 3714.63 3605.63 6647.29 4380.26 5952407.92 563171.47 MWD+IFR-AK-CAZ-SC 12541.85 90.08 358.92 3715.23 3606.23 6738.20 4379.73 5952498.81 563170.22 MWD+IFR-AK-CAZ-SC ~ 12630.09 89.09 351.20 3715.87 3606.87 6826.04 4372.13 5952586.58 563161.94 MWD+IFR-AK-CAZ-SC 12725.11 89.03 353.44 3717.43 3608.43 6920.19 4359.44 5952680.62 563148.51 MWD+IFR-AK-CAZ-SC 12771.26 89.59 355.51 3717.98 3608.98 6966.12 4354.99 5952726.51 563143.71 MWD+IFR-AK-CAZ-SC 12819.54 89.46 359.44 3718.38 3609.38 7014.34 4352.87 5952774.71 563141.21 MWD+IFR-AK-CAZ-SC 12902.87 89.16 358.49 3719.39 3610.39 7097.65 4351.36 5952857.99 563139.05 MWD+IFR-AK-CAZ-SC 12994.57 89.59 357.84 3720.39 3611.39 7189.30 4348.43 5952949.61 563135.40 MWD+IFR-AK-CAZ-SC j 13086.80 90.82 0.40 3720.06 3611.06 7281.51 4347.01 5953041.79 563133.26 MWD+IFR-AK-CAZ-SC 13176.60 90.02 3.04 3719.40 3610.40 7371.25 4349.71 5953131.55 563135.26 MWD+IFR-AK-CAZ-SC ICI 13265.79 92.30 3.60 3717.59 3608.59 7460.27 4354.87 5953220.59 563139.72 MWD+IFR-AK-CAZ-SC 13359.88 90.33 3.71 3715.44 3606.44 7554.14 4360.86 5953314.50 563144.98 MWD+IFR-AK-CAZ-SC ~ 13449.15 90.27 4.05 3714.97 3605.97 7643.20 4366.91 5953403.60 563150.33 MWD+IFR-AK-CAZ-SC ! 13539.25 87.18 3.24 3716.97 3607.97 7733.09 4372.63 5953493.52 563155.35 MWD+IFR-AK-CAZ-SC 13629.27 87.55 359.81 3721.11 3612.11 7822.97 4375.02 5953583.40 563157.04 MWD+IFR-AK-CAZ-SC 13720.54 88.35 358.70 3724.38 3615.38 7914.17 4373.84 5953674.58 563155.14 MWD+IFR-AK-CAZ-SC 13810.40 88.60 359.10 3726.77 3617.77 8003.98 4372.11 5953764.37 563152.72 MWD+IFR-AK-CAZ-SC 13900.87 88.54 358.92 3729.03 3620.03 8094.41 4370.55 5953854.77 563150.45 MWD+IFR-AK-CAZ-SC 13991.37 89.83 359.51 3730.31 3621.31 8184.89 4369.31 5953945.23 563148.50 MWD+IFR-AK-CAZ-SC 14085.30 88.11 359.13 3732.00 3623.00 8278.79 4368.20 5954039.12 563146.65 MWD+IFR-AK-CAZ-SC 14177.21 89.46 3.91 3733.95 3624.95 8370.62 4370.63 5954130.95 563148.37 MWD+IFR-AK-CAZ-SC 14225.49 87.43 4.23 3735.26 3626.26 8418.76 4374.06 5954179.11 563151.42 MWD+IFR-AK-CAZ-SC 14271.43 88.97 4.41 3736.70 3627.70 8464.54 4377.52 5954224.92 563154.52 MWD+IFR-AK-CAZ-SC 14364.49 89.40 3.67 3738.03 3629.03 8557.36 4384.07 5954317.78 563160.35 MWD+IFR-AK-CAZ-SC 14458.86 89.34 0.07 3739.07 3630.07 8651.66 4387.15 5954412.09 563162.69 MWD+IFR-AK-CAZ-SC 14552.24 90.33 357.92 3739.34 3630.34 8745.02 4385.51 5954505.42 563160.33 MWD+IFR-AK-CAZ-SC 14645.64 91.75 358.99 3737.64 3628.64 8838.37 4383.00 5954598.74 563157.08 MWD+IFR-AK-CAZ-SC 14737.66 87.86 359.16 3737.95 3628.95 8930.36 4381.51 5954690.70 563154.87 MWD+IFR-AK-CAZ-SC 14784.65 86.69 359.37 3740.19 3631.19 8977.29 4380.91 5954737.62 5631.53.91 MWD+IFR-AK-CAZ-SC ', i 14822.00 86.69 359.37 3742.34 ~ 3633.34 9014.57 4380.50 5954774.90 ~ 563153.20 ~ PROJECTED to TD 1J-118 'D' Sand Liner Detail Well: 1J-11812 4-7/2" Slotted and Blank. Liner Date:. 3/1 s/2oo7 Ct31'liQCtJP~''tl~1j3-S Plop and Drop Assy. Rig: boyon 141 Afasi:a.1»c. DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 1 LENGTH TOPS :. _;~: .. .;. .. ~~ ~~ ` x 7369.24 7369.24 7369.24 7369.24 4" DP to Surface =_> Y 7369.24 XO 3 1/2 IF x 4" HT 39 Z.00 7369'.24 Baker Liner setting tool w/pup jt (Does not stay in hole) ;, 7.45 7371.24 Baker "HR" Liner setting sleeve w/ 10' TBR 12.67 7378.69 Liner Nipple, 5.55" OD / 4.99" ID 1.03 7391.36 5.5" Liner Pup Joint 15.5# L80 5.53" OD X 4.91" ID 3.66 73:92.39 5.5" 15,5# L80 521 Hyd 5.53" OD X 4.87"1D 42.08 7396.05 XO Sub 5.5"Hyd 521 X 4.5" Hyd 521 - 5.72"OD X 3.91" ID 1.42 7438.13 4 1/2" Pup Jt, 12.6 ppf,. L-80 Hyd 521 B X P 3.66 7439.55 7443.21 _ 7443.21 7443.21 7443.21 7443.21 Jts 176 to 17 1 Jts 4-1/2" Hyd 521 11.6 ppf, L-80 Slotted Casing 42.06 7443.21 Jts 175 to 17 1 Jts 4-1/2° Hyd 521 11.6 ppf, L-80 Casing *(Blanks) - 41.15 7485.27 Jts 174 to 17 1 Jts 4-1/2" Hyd 521 11.6 ppf, L-80 Slotted Casing 41.02 7526.45 Jts 173 to 17 1 Jts 4-1/2" Hyd 521 11.6 ppf, L-80 Casing *(Blanks) 42.00 7567.47 Jts 172 to 17 1 Jts 4-1/2" Hyd 521 11.6 ppf, L-80 Slotted Casing 42.22 7609.47 Jts 171 to 171 1 Jts 4-1 /2" Hyd 521 11.6 ppf, L-80 Casing *(Blanks) 41.16 7651.69 Jts 170 to 17 1 Jts 4-1/2" Hyd 521 11.6 ppf, L-80 Slotted Casing 39.58 7692.85 Jts 169 to 16 1 Jts 4-1/2" Hyd 521 11.6 ppf, L-80 Casing *(Blanks) 41.01 7732.43 Jts 168 to 16 1 Jts 4-1/2" Hyd 521 11.6 ppf, L-80 Slotted Casing 41.62 ' 7773.44 Jts 167 to 16 1 Jts 4-1/2° Hyd 521 11.6 ppf, L-80 Casing *(Blanks) 41.84 7815.06 Jts 166 to 16 1 Jts 4-1 /2" Hyd 521 11.6 ppf, L-80 Slotted Casing 42.10 7856.90 Jts 165 to 16 1 Jts 4-1/2" Hyd 521 11.6 ppf, L-80 Casing *(Blanks) 41.75 7899.00 Jts 164 to 16 1 Jts 4-1/2" Hyd 521 11.6 ppf, L-80 Slotted Casing 40..97 7940.75 Jts 158 to 16 6 Jts 4-1/2" Hyd 521 11.6 ppf, L-80 Casing *(Blanks) 250.19 7981.72 Jts 157 to 15 1 Jts 4-1/2" Hyd 521 11.6 ppf, L-80 Slotted Casing 41.92 8231.91 Jts 156 to 15 1 Jts 4-1/2" Hyd 521 11.6 ppf, L-80 Casing *(Blanks) 38.67 8273.83 Jts 155 to 15 1 Jts 4-1/2" Hyd 521 11.6 ppf, L-80 Slotted Casing 38.78. 8312.50 Jts 154 to 15 1 Jts 4-1/2" Hyd 521 11.6 ppf, L-80 Casing *(Blanks) 41.45 8351.28 Jts 153 to 15 1 Jts 4-1/2" Hyd 521 11.6 ppf, L-80 Slotted Casing 41.98 8392.73 Jts 152 to 15 1 Jts 4-1 /2" Hyd 521 11.6 ppf, L-80 Casing *(Blanks) 41.39 8434.71 Remarks: Ran total of 1 13 jts Blank( 35 Hyd 521 & 78 BTC) and 63 jts slotted (19 jts Hyd 521 & 44 jts BTC) up Wt 240K Slots are 0.125" wide x 2.5" long x 32 slo/ft.w/ (32) 2.5" long x .125" @ 4 Circumferenti Rot Dn Wt 85K staggered 18 deg., 3 ft. non-slotted ends. Block Wt 35K Ran shoe joint slick. Torqued liner w/o torque rings to 3800 ft-Ibs, w/ torque rings to 5800 ft/Ibs Used Run-N-Seal thread compound on all connections. All drifted w/ 3.875". Run 1 Hydroform /joint below a stop ring in the middle of the joint. Used - 176 centrilizers and 176 stop rings Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 2 LENGTH TOPS Jts 151 to 151 1 Jts 4-1/2" Hyd 521 11.6 ppf, L-80 Slotted Casing 37.s4 8476.10 Jts 150 to 15 1 Jts 4-1 /2" Hyd 521 11.6 ppf, L-80 Casing *(Blanks) 41.87 8513.94 Jts 149 to 14 1 Jts 4-1 /2" Hyd. 521 11.6 ppf, L-80 Slotted Casing 40.05 8555.81 Jts 148 to 14 1 Jts 4-1/2" Hyd 521 11.fi ppf, L-80 Casing *(Blanks) 40.76 8595.86 Jts 147 to 14 1 Jts 4-1/2" Hyd 521 11:6 ppf, L-80 Slotted Casing 42.20 8636.62 Jts 146 to 14 1 Jts 4-1/2" Hyd 521 11.6 ppf, L-80 Casing *(Blanks) 41.75 8678.82 Jfs 145 to 145 1 Jts' 4-1 /2" Hyd 521 11.6 ppf, L-80 Slotted Casing 41.66 8720.57 Jts 138 to 14 7 Jts 4-1/2° Hyd 521 11.6 ppf, L-80 Casing *(Blanks) 287.02 8762.23 Jts 137 to 13 1 Jts 4-1/2" Hyd 521 11.6 ppf, L-80 Slotted Casing 41.46 9049.25 Jts 136 to 13 1 Jts 4-1 /2" Hyd 521 11.6 ppf, L-80 Casing *(Blanks) 41:45 . 9090.71 Jts 1.35 to 13 1 Jts 4-1/2" Hyd 521 11.6 ppf, L-80 Slotted Casing 41.24 9132.16 Jts 134 to 13 1 Jts 4-1 /2" Hyd 521 11.6 ppf, L-80 Casing *(Blanks) 41.75 9173.4Q Jts 133 to 13 1 Jts 4-1 /2" Hyd 521 11.6 ppf, L-80 Slotted Casing 41.93 9215.15 Jts 132 to 13 1 Jts 4-1 /2" Hyd 521 11.6 ppf, L-80 Casing *(Blanks) 41.27 9257.08 Jts 131 to 131 1 Jts 4-1/2" Hyd 521 11.6 ppf, L-80 Slotted Casing 41.94 9298.35 Jts 124 to 13 7 Jts 4-1 /2" Hyd 521 11.6 ppf, L-80 Casing *(Blanks) 291.12 9340.29 Jts 123 to 12 1 Jts 4-1/2" Hyd' 521 11.6 ppf, L-80 Slotted Casing. 41.95 9631.41 ~~~,3 ~ ~`t`~~fE~ 52~ ~ ~~~~~ BT~11t7C ~~: ,. 2.50 9673.36 9675.86 Jts 122 to 12 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Casing *(Blanks) + TR 42.79 9675.86 Jts 121 to 121 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing + TR 43.62 9718.65 Jts 120 to 12 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) + TR 41.10 9762.27 Jts 119 to 11 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Slotted Casing + TR 42.44 9803.37 Jts 11s to 11 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Casing *(Blanks) + TR 38.74 9845.81 Jts 117 to 11 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing + TR 43.04 9884.55 Jts 116 to 11 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) + TR 43.40 9927.59 Jts 115 to 11 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing + TR 43.27 . .9970.99 Jts 114 to 11 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Casing *(Blanks) + TR 43.08 10014.26 Jts 113 to 11 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing + TR 43.63 10057.34 Jts 112 to 11 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) + TR 42.88 10100.97 Jts 111 to 111 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Slotted Casing + TR 37.55 10143.83 Jts 11 o to 11 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) + TR 43.40 10181.38 Jts 109 to 10 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing + TR 34.54 . 10224.78 Jts 99 to 1os 10 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) + TR 413.99 10259.32 Jts 98 to 98 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Slotted Casing + TR 42.ss 10673.31 Jts 97 to 97 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) + TR 43.35 1.0716.19 Jts 96 to 96 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing + TR 43.15 10759.54 Jts 95 to 95 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) + TR 42.90 10802.69 Remarks: • Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 3 LENGTH TOPS Jts 94 to 94 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing + TR 43.34 10845.59 Jts 93 to 93 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) + TR 41.sa 10888.93 Jts 92 to 92 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing + TR 43.03 10930.81 Jts 91 to 91 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) + TR 41.81 10973.84 Jts 9o to 90 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing + TR 41.80 11015.65 Jts s9 to 89 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Bfanks) + TR 42:89 11057.45 Jts 88 to 88 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing + TR 43.41 11100.34 Jts s2 to s7 6 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) + TR 241.27. 11143.75 Jts 81 to 81 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing + TR 39.78 11385.02 Jts so to so 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) + TR 40.00 11424.80 Jts 79 to 79 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Slotted Casing + TR 43.08 11464.80 Jts 7s to 7s 1 Jts 4-4/2" BTC 11.6 ppf, L-80 Casing *(Blanks) + TR 40.21 11507.88 Jts 77 to 77 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing + TR 43.39 11548.09 Jts 76 to 76 1 Jts 4-1/2'" BTC 11.6 ppf, L-80 Casing *(Blanks) + TR 38.86 11591.48 Jts 75 to 75 1 Jts 4-1 /2" BTC 11.6 ppf, L-8U Slotted Casing + TR 43.41 . 11630.34 Jts 74 to 74 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) + TR 40.05 11673.75 ,Jts 73.to 73 1 Jts 4-1/2" BTC 11.6 ppf,. L-80 Slotted.Casing + TR _ _' 43.52 11713.80 Jts 72 to 72 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) + TR 43.36 11757.32 Jts 71 to 71 1 Jts 4-1/2" -BTC 11.6 ppf, L-80 Slotted Casing + TR 43.32 . 11800.68 Jts 7o to 70 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Casing *(Blanks) + TR 42.84 11844.00 Jts 69 to 69 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Slotted Casing + TR 42.82 11886.84 Jts 63 to 68 6 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) + TR 253.39 11929.66 Jts 62 to 62 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing + TR 43.44 12183.05 Jts 61 to 61 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Casing *(Blanks) + TR 40.24 12226.49 Jts 6o to so 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing + TR 42.21 12266.73 Jts 59 to 59 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Casing *(Blanks) + TR 43.40 12308.94 Jts 58 to 58 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Slotted Casing + TR 43.49 12352.34 Jts 57 to 57 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) + TR 39.41 12395.83 Jts 56 to 56 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing + TR 40.45 12435.24 Jts 55 to 55 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Casing *(Blanks) + TR 35.39 12475.69 Jts 54 to 54 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing + TR 43.25 . 12511.08 Jts 53 to 53 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Casing *(Blanks) + TR 40.35 12554.33 Jts 52 to 52 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing + TR 42.60 12594.68 Jts 46 to 51 6 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 245.53 12637.28 Jts 45 to 45 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.04 12882.81 Jts 44 to 44 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 39.20 12925.85 Jts 43 to 43 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.34 12965.05 Jts 42 to 42 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 43.19 13008.39 Remarks: Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Page 4 LENGTH TOPS. Jts 41 to 41 1 Jts 4-1 /2" BTG 11.6 ppf, L-80 Slotted Casing 43.40 13051.58 Jts 4o to 40 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Casing *(Blanks) 39.96 13094.98 Jts 39 to 39 1 Jts 4,1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.03 13134.94 Jts 3s to 38 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 40.83 13177.97 Jts 37 to 37 1 Jts 4-1/2" BTG 11.6 ppf, L-80 Slotted Casing 42.77 13218.80 Jts 36 to 36 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing "(Blanks) 42.88 13261.57. Jts 35 to 35 1 Jts 4-1 /2" BTC 41.6 ppf, L-80 Slotted Casing 43.01 13304.45 Jts 34 to 34 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing '(Blariks) 42.53 13347.46 Jts 33 to 33 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Slotted Casing 43.40 13389.99 Jts 27 to 32 6 Jts 4-1 /2" BTC 11.6 ppf, L$0 Casing *(Blanks) 255.73 13433.39 Jts 26 to 26 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 41.66 1.3689.12 Jts 25 to 25 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 43.35 13730.78 Jts 24 to 24 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.15 13774.13 Jts 23 to 23 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Casing "(Blanks) 43.12 13817.28 Jts 22 to 22 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Slotted Casing 43.29 13860.40 Jts 21 to 21 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) ' 41.x2 13903.69 Jts 20 to 20 1 Jts _ 4-1 /2" BTC 11.6 ppf, L-80 Slotted Casing 43:00 ' .13945.31 Jts 19 to 19 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Casing *(Blanks) 42.65 13988.31 Jts 18 to 18 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 40.62 14030.96 Jts 17 to 17 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 43.64 14071.58 Jts 16 to 16 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Slotted Casing 43.28 14115.22 Jts 10 to 15 6 Jts 4-1 /2" BTC 11.6 ppf, L-80 Casing *(Blanks) 246.41. . .14158.50 Jts 9 to 9 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 42.90 14404.91 Jts s to s 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Casing "(Blanks) 40.08 14447.81 Jts 7 to 7 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.20 14487.89 Jts 6 to 6 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 43.28 14531.09 Jts 5 to 5 1 Jts 4-112" BTC 11.6 ppf, L-80 Slotted Casing 43.36 14574.37 Jts 4 to 4 1 Jts 4-1 /2" BTC 11.6 ppf, L-80 Gasing'`(Blanks) 40.24 14617.73 Jts 3 to 3 1 Jts 4-1/2'' BTC 11.6 ppf, L-80 Slotted Casing 39.03 14657.97 Jts 2 to 2 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Casing *(Blanks) 42.61 14697.00 Jts 1 to 1 1 Jts 4-1/2" BTC 11.6 ppf, L-80 Slotted Casing 43.30 1..4739.61 XO sub - 4.5" BTC X 3.5" BTC 1.44 14782.91 3-1/2" BTC 11.6 ppf, L-80 Casing *(Blank Bent Joint) 2x.15 14784.35. 3-1/2" Silver Bullet Shoe 1.50 14813.50 BOTTOM OF SHOE __> 14815.00 14815.00 14815.00. 14815.00 Remarks: ~®~T~ERVA~'1[®lY C® S5I®16T Robert D. Christensen Production Engineering Technician ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1J-118L2 Sundry Number: 307-149 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. Sea_mount Commissioner DATED this Z day of May, 2007 Encl. SARAH P.4LIIV, G01/ERM®R c~~`" ~ . •... c,~a- ~. z -o~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~C~IV~[ ~~( ~'~ 3 0 2007 a APPLICATION FOR SUNDRY APPROVAL~~saska G~i ~ Gas Cons. Commission 20 AAC 25.280 Anchofage 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other Q 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 ^ 206-178 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23337-61 7. If perforating, Gosest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes NO ^~ 1J-118L2 9. Property Designation: tr'( (ol p` ~L ZS'~~ p~~ 10. KB Elevation (ft): 11. Field/Pool(s): ~ uparuk River Unit - ~•3D• ~~ RKB 109' Kuparuk River Field !West Sak Oil Pool 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ff): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 14822' 3742' 14815' 3741' Casing Length Size MD TVD 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" 7208' 3606' Slotted Liner 7613' 5-1/2" x 4-1/2" 14815' 3742' Perforation Depth MD {ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7443' -14783' 3626' - 3740' 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 Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: 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 1'~O D. Chr' tensen Title: Production Engineering Technician Signature Phone 659-7535 Date ~ 6 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness -- Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ Other: ~~E~~~o°T`,ai 1`~ C.>,C:.~ ~ W ~ ~~~~ ~~~ ~pu ~ ~ 2007 Subsequent Form Required: ~© /"1 ['~ ~ ^ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Z Date: Form 10-403 Revised 06/2006 Submit in Duplicate ~` 'y/~o1~~ ~tD Y-30 ~7 ~ ~ • 1J-118L2 DESCRIPTION SUMMARY OF PROPOSAL I~ L ConocoPhillips Alaska Inc. requests approval to begin Water Injection service in West Sak Tri- lateral Well 1J-118L2. 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-118L2 will provide pressure support for the West Sak D 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. TUBING (0-7180, OD:4.500, ID:3.958) LOCATOR (7162-7164, OD:5.500) SEAL (7164-7190, oD:a.7ao> Perf (7443-14783) • • KRU 1J-118L2 ConocoPhillips Alaska, Inc. 1J-118L2 API: 500292333761 Well T SVC Ankle TS: de SSSV Type: NIPPLE -- Orig Com letion: 3/2 012 0 0 7 - Angle @ TD: 87 deg @ 14822 Annular Fluid: Last W/O: Rev Reason: NEW GLV DESIGN Reference L 28' RKB Ref Lo Date: Last U ate: 4/2/2007 Last Tag: TD: 14822 ftK6 Last Ta Date: _ Max Hole An le: 93 de 10220 Casing String -ALL STRINGS - - Descr~on Size To Bottom TVD Wt Grade Thread _ CONDUCTOR _ 20.000 0 80 80 94.00 K55 WELDED SURFACE 10.750 0 3358 2219 45.50 L-80 BTC INTERMEDIATE 7.625 0 8949 3653 29.70 L-80 BTC-M WINDOW L2 7.625 7207 7208 3606 0.00 D-SAND LINER TOP 4.500 7218 9673 3677 11.60 L-80 HYDRIL521 5.5"x4.5" D-SAND LINER BOTTOM 5.5"x4.5" 4.500 9673 14815 _ _ 3742 11.60 L-80 BTC Tubin Strin -TUBING Size Top 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 7443 - 14783 3626 - 3740 WS D 7340 32 3/16/2007 SLOTS Alternatin solid/slotted i e Gas LiR Man drelsNalv e s _ St MD _ TVD _ Man Mrr _ _ __ Man Type V Mrr V Type V OD _ Latch Port TRO Date Run Vlv 1 2173 1816 CAMCO KBMG GLV 0.2 BK-5 430.00 0 3/19/2007 2 6008 3227 CAMCO KBMG DMY 1.0 BK-5 0.000 0 3/19/2007 Other LETION lu s, a ui~ etc.) - COM P De th TVD T e _ _ Description ID 23 23 HANGER TUBING HANGER 4.500 4 503 503 NIP CAMCO'DB' NIPPLE 3.875 _ 7110 3587 SLEEVE-O BAKER CMD SLIDING SLEEVE -RUN OPEN 3.810 __ 7162 3598 LOCATOR _ BAKER LOCATOR 3.88_0 7164 1 3598 SEAL BAKER GBH-22 LOCATING SEAL ASSEMBLY 3.880 Other plugs, equip., etc) _- LINER_ DETAILS } De th TVD T e _ Description T ID _ 7146 _ 3595 I_ 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 7341 3621 SEAL D-SAND LEM BAKER SEAL ASSEMBLY 3.880 7379 3623 SLEEVE D-SAND LINER BAKER'HR' LINER SETTING SLEEVE 5.750 7391 3624 NIP -__ . D-SAND LINER NIPPLE 4.990 7438 3626 XO D-SAND LINER CROSSOVER SUB 3.910 14813 3742 SHOE D-SAND LINER SILVER BULLET SHOE 2.992 General Notes Date Note 3/20/2007 NOTE: MULTI-LATERAL WELL - iJ-118 A-SAND , 1J-118L1 B-SAND , 1J-118L2 D-SAND ~ ~ `~ ~•C?~r"~'~?C~.L _~'E tZ1T" R EPOR~ ~ _ ~~~: ~_ ~ _ ,~ ~~S ~, a s i n ~ : ~ ~f 4~" Shoe : ~i5~_~ ~~5~~ T~r~J ; li V : ~ ~- ?~ ~ ~ T~~i ..::e.: Shoe : '^~ -,;o'- _ Tom, e at ~, ~"`~~~', P acicer 1r~C~ `,~ C r o ~ e S ~ ~ e ~, (~ and P e r ~ s ~.. ~ i-.~n+~t`~~- o ~'2 c~C`~ ~ ~'~=,Cra?1=~~_. ~NTEGRETY - ??~~ZT #I ~nrulus Press Test: .P 15 min SO min C o~ e n t s : ' / ~ ~ -~~ ~-~S~C> ~~ ~ <S ~ ~ahti~~~ v ~ ~® 3-~ C~ DS ~ wh~~ ~~~ ~~ ~cAe~c~~ ~ -- -- '~' CH? N ~ C?y INTEGRITY - PART # 2 ~---~C ~ ~a~ =~a 1 ~h~ S Cement Volt~es :- A.mt. miner Cs°~S©S~ ; DV ~I~ C.~t -rol to~~`` cove_ oe_ L ~- ~i ~ c~CJQvJ ~~JS ~~ o _ :eoretical TOC ~ ~~~ XS T~ L = W 5V~ t n Cement Bond Log (Yes or No) ~~S In AOGCC File ~~5 C3L Evaluation, cone above perfs •';;:, ~~~ ~.-- L©v~c~ c- s ~-~C.~4~ 5 C ~~c' ~CS~- Production Log: Tyve CONC--LJS~ONS: Part #l: • T 2 : ~ ~S~ ~ ar ~ j C Evaluati on RE: 1J-118 Intermediate Casing Bond Log Subject: RE: 1J-118. Intermediate Casing Bond Log From: "Hartwig, Dennis D" <Dennis.D.Hartwig@conocophillips.com> , Date: Mon, OS Mar 2007 12:12:23 -0900 To: Thomas Maunder <tom_maunder@admin.state.ak.us> Tom, `~-~~~~~ ~Q~ - ~Z~ I 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 ~ 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 good, but not excellent and same for the D-window (7201-7214'md) 0 Zonal isolation Between the Upper West Sak (West Sak D - 7201'md) production interval and the Ugnu sands (Ugnu A - 6445'md) is excellent. ~ 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 of 2 5/1/2007 11:20 AM RE: 1J-118 Intermediate Casing Bond Log 1.~ Dennis, Thanks for the information. One item I am curious about is was the pipe reciprocated during cementing. It says it was during the circulation. I will look forward to the Schlumberger interpretation you mention. Tom Maunder, PE AOGCC Hartwig, Dennis D wrote, On 3/1/2007 5:01 PM: «1J-118 Ops Report.pdf» «1J-118 Geo Morning Report.xls» «USIT_MAXTRAC_1 J-118_23-FEB-2007.zip» Tom, Attached is the Schlumberger USIT log for the 1J-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). I have a verbal interpretation of the log from Schlumberger, a formal interpretation is forthcoming. Regards...Dennis Dennis Hartwig Drilling Engineer ConocoPhillips tllaska, Inc. Office :907-265-6862 Cell :907-980-1433 Fax :907-265-1535 2 of 2 5/1/2007 11:20 AM ~ ~ ~,.-~ Cc~nac~~~~~ips Daily Drilling ~ ,^ , ;; x Report Printed:3/1l2007 ; . Vketlrretir Web Repo~ting~ i E € Re csrt Heat ~er Well: Report Date: Job Tvpe: Network: Report # Daily Cost: C~~r+, ~~~t~ 1J-118 02/15/2007 DRILLING 10163824 11 OR~GI NAL Field: Riq Name: Riq Supervisor: Riq Accept: Riq Release: WEST SAK DOYON 141 Steve 2/6/200 7 6:00:00 Shultz/Dearl AM 24 hr Summarv: Continue BROOH to shoe. Pump Hi Visc weighted sweep, POOH lay down BHA. Rig up & run 7 5/8" casing. Summarv (a~ Rpt Time: Circulating & conditioning mud for cement job . 24 hr Forecast: Continue run 7 5/8" casing. Circulate & condition mud. Perform Cement job. Set casing in slips. Time t,o Frorra To [~uFation Phase Cviie Su~code T' .e A iv~t 00:00 04:15 4.25 INTRM1 DRILL REAM P Continue BROOH from 7575' - 3350'. Observed hole looked ood, and unloadin hole while back reamin . 04:15 05:00 0.75 INTRM1 DRI~L CIRC P Pump Hi Visc weighfed sweep at the shoe. Circulate until swee returned and well bore clean. 05:00 06:30 1.50 INTRM1 DRILL TRIP P Pump dry job, Blow down lines & top drive. Continue POOH from 3350' - 350'. 06:3G 07:15 0.75 INTRM1 DRILL PULD P Rig up. Lay down 5" HWDP, Drilling jars and NMDCs. Q7:15 08:00 0.75 INl-RM1 DRIL~ OTHR P Plug in and download MWD assembly.' 08:OQ 08:45 0.75 IRTRM1 DRILL PULD P Continue breakout & lay down BHA. Inspec# & grade bit to 3/6/WT/A/E/4/RG/TD 08:45 09:15 0.50 INTRM1 DRILL OTHR P Clean & clear rig floor area. Send tools outside. 09:15 09:30 0.25 INTRM1 CASING OTHR P Rig up, BOLDS and pull wear bushing. 09:30 11:00 1.50 INTRM1 CASING RURD P Rig up to run 7 5/8" casing. 11:00 12;00 1.00 INTRM1 CASING RNCS P Held PJSM with crew. Discuss safety 7 hazard recognition issues. Make up shoe joint & threadlock 'oint. Make up torque 8000 ft/Ibs. Crew Chan e 12:00 14:00 2.00 INTRM1 CASING RNCS P Continue make up shoe track assembly. Fill casing & check floats, floats held. Continue run casing to 1722'. make u tor ue - 8000 ft/Ibs. 14:00 14:45 0.75 INTRM1 CASING RNCS NP POOH from 1722' - 1640'. Install 7 5/8" pup joint. 14:45 17:00 2.25 INTRM1 CASING RNCS P Continue run 7 5/8" casing from 1640' - 3350'. 17:00 1830 1.50 INTRM1 CASING CIRC P Circulate & condition mud at the shoe. pumps @ 4 BPM - 370 PSI. 18:30 00:00 5.50 INTRM1 CASING RNCS P Continue run 7 5/8" casing from 3350' - 7044'. Run 10 joints, circulate 1 joint down slow.Observe fair hole conditions working through a couple of spots 6620' and 6850'. Crew Chan e . _.~__~__. _ ~ _ ..._ __ _~_ _ _____.__~ _.. .__ _ __ ..._.. . __ ._._. ~. _ . __. ..~ . __ ___. _ . _ _ _ _. ~._.~. ~._. __ __. _.... _~ _ .._~. . . __~_ ___.~_ . .. ~. _~ . ~ _ ~ ~ zz~ ~~~~f - - ~ „~.____~__..__._,_._.....,_._...~ _. _.., _....._ __ _ .._ _~~__ . ..__._._..~ 1~p+^'~ E ~, o>> ~ °`.sx !; ` . ~~~~~~~'~~~`~ ~ Da i I D ri i I i n ~ ~ Printed 3/1/2007 Re ~ 1 l ~ ~ ~ {~it'I~V!@fY ~2b~ Ofi%flQ~ ~ F~e cart He~ der Well: Report Date: Job Tvpe: Network: Report # Daily Cost: Cum Cost: 1J-118 02/16/2007 DRILLING 10163824 12 ORIGINAL Field: Riq Name: Rig Supervisor: Rict Accept: Riq Release: WEST SAK DOYON 141 Dearl 2/6/2007 6:00:00 Gladden/Scott AM 24 hr Summarv: Continue run 7 5/8" casing. Circulate & condit ion mud. Perform 2 20 BBL Ce ment job. Set casing in slips with 70K. Perform Injectivity test. flush ann, and freeze protect. Lay down all 5" Dp from derrick. Summarv Ca~ Rpt Time: ~ Picking up 4 1/2" Drillpipe from pipe shed. 24 hr Forecast: Pick up 4" DP with Super Sliders, and all DP needed for next lateral. RAck i n derrick. MU BHA, TIH picking up DP. Time Lo Frort~ Ta Durat~~n f'hase O Cade Subco,ds Time Activi 00:00 02:30 2.50 INTRM1 CASING RNCS P Continue run 7 5/8" casing from 7044' to tag bottom @ 8958'. Verify bottom observing hard tag & pressure increase. Work through tight spots @ 8827' - 8830'. SIMOPS: Rig up Dowell cemeters & line up Vac trucks for OBM dis lacement. 02:30 03:45 1.25 INTRM1 CASING RNCS P Lay down joint # 210. Install 20' pup. Breakout & lay down Franks Fill up tool. Install 7 5/8" cement head & lines. 03:45 06:00 2.25 INTRM1 CEM~NT CIRC P Circulate & condition mud. Stage pumps to 6 BPM - 580 PSI. Reciprcate casing string in 20' increments.UP WT = 210K, SO WT = 65K. Pre cement mud = 9.0 PPG, YP-10, PV-12, Gels - 7/8/10. 06:00 07:30 1.50 INTRM1 CEMENT DISP P Turn rig over to Dowell. Pump 10 BBLS of CW100. Test lines to 3500 PSI. Pump 65 BBLS of CW100. Pump 75 BBLS of 11.0# Mud Push II, Drop Plug. Pump a total of 220.5 BBLS of 12.5 Tail Cement. Drop Plug, pump 2 BBLS water to flush lines to ri floor. 07:30 09:00 1.50 INTRM1 CEMENT DISP P Turn over to Rig pumps. Displace cement with 8.4 PPG MOBM @ 7 BPM, slowing pumps to 3 BPM, observe bumping plug with 4039 STKS (406 BBLS) with 1100 PSI. Pressure to 1600 PSI & hold for 5 minutes. Bleed pressure and check floats. Floats held. CIP @ 0840 H RS. 09:00 09:30 0.50 INTRM1 CEMENT RURD P Rig down Cement head & lines. Nipple down BOP stack & wellhead. 09:30 09:45 0.25 INTRM1 CASING RNCS P Set 7 5/8" Emergency slips as per Vteco Gray rep with 70K ulled on casin . 09:45 11:00 1.25 INTRM1 CASING RNCS P Rig up cutter & cut casing as per Vetco rep. Cut off 'oint = 11.67' as lanned in detail. Install ackoff. 11:00 12:00 1.00 INTRM1 CASING NUND P Nipple up wellhead & BOP stack. Crew Change 12:00 12:15 0.25 INTRM1 CASING DHEQ P Rig up lines to OA. Test packoff as per Vetco rep to 80% of burst 3850 PSI - 10 minutes. 12:15 12:30 0.25 INTRM1 CASING NUND P Install Turnbuckles on BOP stack. Air up riser boots. Clean cellar area. Ri u Little Red Services. ~ - _ ~ _ - - -- - --- ---- ~ ~g $- _ .._ .. ~ . -.,~ __ T"C~~~g' ~b :.e3 .i~ ~. .. ~ ~ 12:30 14:00 1.50 INTRM CASiNG CIRC P Perform Injectivi 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, instail mousehole, and ri up 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 DRILI 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 DRI~L PULD P Continue breakout & lay down 5" DP from the derrick.la ed down 90 stands totai. SIMOPS: Level ri . 23:30 00:00 0.50 INTRMI DRILL OTHR P Change elevators, pick up 3 1/2" IF handling tools to rig floor. Crew Chan e M1~r! Glt~c.lCs Time T~+q.e So.urce Depth D nsi# ~ F Vis. PV YP Geks NT#i~ MBl` ~L Texrt~ 16:00 Oil Base Pit 8,950 8.5 0.0 45.4 13 1.00 8.00 18.00 18.0 4.40 0.00. 23'.~0 Oil Base Pit 8,950 8.5 0.0 45.4 13 1.00 8.00 18.00 18.0 4.40 OAQ -- --- - _ ~ ._.__ _ ___ -_ _. _. _ ____ __ _- _ _ _ _ - - ; ___ _ _____ __ ___ __..___._ . _~__ , "~~~s~ 2 ~i ~ - - -- --, ,,~ -_. _u_ _ t. ~_ t_ .r .~, ~, _. . I ;~ SARAH PALIN, GOVERNOR L~is[J•-7~ OTIa ~ ~ 333 W. 7th AVENUE, SUITE 100 CO~SERQ~liO~` CO~TI-7SIO~ 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-118L2 ConocoPhillips (Alaska), Inc. Permit No: 206-178 Surface Location: 1914' FSL, 2366' FEL, Sec. 35, T11N, R10E, UM Bottomhole Location: 2061' FSL, 2238' FWL, Sec. 36, 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 revocation or suspension of the permit. When providing notice for a representative of the Com ssion to witness any required test, contact the Commission's petroleum fielcnspecto~at (907} 659-3607 (pager). Chairman DATED this day of December, 2006 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. FtE~EIVED STATE OF ALASKA DEC 1 3 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL Alaska Qil & Gas Cons. Commission 20 AAC 2s.oos Anchorage 1 a. Type of Work: Drill Q Re-drill ^ Re-entry ^ 1 b. Current Well Class: Exploratory ^ Development Oil ^ Stratigraphic Test ^ Service Q Development Gas ^ Multiple Zone^ Single Zone Q 1 c. 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-118L2 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 14678' ~ TVD: 3713' ~ 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 1914' FSL, 2366' FEL, Sec. 35, T11 N, R10E, UM 7. Property Designation: ADL 25661 & 25650 West Sak Oil Pool Top of Productive Horizon: 2061' FNL, 2238' FWL, Sec. 36, T11 N, R10E, UM 8. Land Use Permit: ALK 471 & 468 13. Approximate Spud Date: 1/29/2007 Total Depth: 367' 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 Well within Pool: 1 D-138 , 981' 18. Deviated wells: Kickoff depth: 6961 ft. Maximum Hole Angle: 90° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1671 psig Surface: 1262 psig 18. Casing Program cif ti ns S Setting Depth Quantity of Cement Size ica pe o Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD TVD (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 7717' 6961' 3597' 14678' • 3713' • slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth ND (tt): Plugs (measured) Effective Depth MD (tt): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD ND Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ^/ 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 LAS G2~~c~ Date t"2%ra/o~ h n All Commission Use Only Permit to Drill ~ ~/~ ~--7Q Number: ~-i-~(O~ ~ /C~ API Number: 50-D~9~ Z ~ 3'~ ~ ~/ Permit Approval Date: b 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 m thane, gas hydrates, or gas contained in shales: 3~~ ~~~ ~'1~-4~;-~ C~SF~`G~,~ . Samples req'd: Yes ^ No ~ Mud log req'd: Yes ^ No [~ Other: ~ r 2S measures: Yes ^ No [/f Directi svy req'd: Yes [a'' No ^ PPROVED BY THE COMMISSION DATE: ~~~ Z ~ "' ~ ~ COMMISSIONE Form 10-401 Revised 12/2005 Submit in Duplicate Applic~r Permit to Drill, Well 1J-118 L2 Revision No.O Saved: 4-Dec-06 Permit It -West Sak Well #1J-118 L2 Application for Permit to Drill Document klt~xiilhiag Well. value 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 Analysis ..................................................................................................... 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-118L2 PERMIT lT Page 1 of 6 Printed: 4-Dec-O6 C\~~~ Applic~r Permit to Drill, Well 1J-118 L2 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 Aftachment 1 Directional Plan ................................................................................................................ 6 Aftachment 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 coerrmission under 20 AAC 25.040(b). For a we// with mu/tip/e well branches, each branch must simi/ar/y be identified by a unique name and API number by adding a suffix to the name designated for the wet/ by the operator and to the number assigned to the we// by the commission. The well for which this Application is submitted will be designated as iJ-118 L2. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An app/ication for a Permit to Dr/1/ must be accompanied by each of the fo/%wr`ng /tams, except for an item atready on file with the commission and identified m the app/ication: (2) a p/at identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the we// at the surface, at the top of each objective formation, and at Iota/ depth, referenced to governmenta/section /mes (B) the coordinates of the proposed /ovation of the we// at the surface, referenced to the .state p/one coordinate system for this state as maintained by the Nationa/Geodetic Survey in the National Oeeanic and Atmospheric Administration; (C) the proposed depth of the well 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 NAD 27 Coord/Hates RKB Elevation 109.0' AMSL ' lVorthings; 5,945,727 •Eastings; 558,844. Pad Elevation 81.0' AMSL Location at Top of Productive Interval West Sak "D" Sand 2,061' FNL, 2,238' FWL, Section 36, T11N, R10E ' ASP Zone 4 NAD 27 Coord/Hates MeaSUred De th, RKB: 6,961 Northings: 5,947,070 Eastings: 563,436 Tota/ ~ertica/De th, RKB; 3,597 Tota/ l/ertical De th, SS.' 3,488 Location at Total De th 367' fSL, 2,021' FWL, Section 24, T11N, R10E .~ ASP Zone 4 NAD 27 Coord/Hates MeaSU/"ed De th, RKB.' 14, 678 ' Northings 5,954,774 Eastings; 563,.151 Tota/ t/ertica/De th, RKB.' 3,713 4 Tota/ t/ertica/De th, SS.' 3,604 and (D) other information required by 20 AAC25.050(b); 1J-118L2 PERMIT IT Page 2 of 6 Printed: 4-Dec-06 ~~ t Applic~r Permit to Drill, Well 1J-118 L2 Revision No.O Saved: 4-Dec-06 Requirements of 20 AAC 25,050(b) Ifa well is to be intentionally deviated, the application for a Permit to Driii (Faun I tl-4tI1J must (1) include a plat,. drawn to a suitable scale, showing the path of the proposed wellbore, including ali adjacent we//bores within 20~ feet afany partian of the prapased well; Please see Attachment 1: Directional Plan and (Z) for al/ wet/s within 20© feet of the proposed wellbore (A) list the names of the operators of those we/!s, to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the applicatian by certified mail; ar (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application far a Permit to Dri/! must be accompanied by each of the fallowing items, except far an -item a/ready an fi/e with the cammissian and identified in the applcatian: (3) a diagram and description of the blowout prevention equipment (BOPS) as required by ZO AACZS.035, ZO AAC25.036, ar 2tI AAC 25. t737, as applicab/e; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete the well. 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 application for a Permit to Dri/l must be accompanied by each of the fo!/owing items, except for an item already on fr/e with the cammr`ssion and identified in the application: (4) informatian an drilling hazards, including (A) the maximum downho% pressure that maybe encountered, criteria used to determine it, and maximum potential sun`ace pressure based an a methane gradient; ~: The expected reservoir pressures in the West Sak sands in the iJ 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 surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak "D" sand formation is 1,262 psi, calculated thusly: MPSP = (3,713 ft TVD)(0.45 - 0.11 psi/ft) = 1,262 psi (B) data an potentia! gas zones; The well bore is not expected to penetrate any gas zones. " and (C) data caneerning patentia/ causes of ho% prob/ems such as abnormally gea pressured strata, lost circulation zones, and zones that have a propensity for difi`erential sticking; Please see Attachment 2: iJ-118 Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An app/icatian for a Permit to Drill must be accompanied by each of the fo//awing items, except for an item already on fr/e wifh fhe commission and identified in the applicatian: (S) a description of the procedure for conducting farmatian integrity tests, as required under 20 AAC2s.030(17; 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-118L2 PERMIT IT Page 3 of 6 ~~ ~ ~ ~ ~ ~ r Printed: 4-Dec-O6 • Applic~r Permit to Drill, Well 1 J-118 L2 Revision No.O Saved: 4-Dec-06 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An app/ication for a Permit to Drill must be accompanied 6y each of the following items, except for an item already on file with the commission and identifred in the application: (6) a complete proposed casing and cementing program as required by 20 ARC 25. Q3(1, and a description of any slotted liner, pre- perfarated liner, ar screen to be installed; Casing and Cementing Program See also Attachment 3: Cement Summary Hole Top Btm 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 Slotted Lateral (1J-118) 4-1/2 6-3/4" B Sand .~ 11.6 L-80 BTC 7,343 7,323 77 .14,666 / 3,774 .Slotted- no cement -118 Ll) ___,_ 4-1/2 6-3/4" D Sand 11.6 L-80 BTC 7,717 6,961 / 3,597 14,678 / 3,713 Slotted- no cement Slotted Lateral (1J-118 L2) C 7. Diverter System Information -"~---- Requirements of 20 AAC 25.005(c)(7) An app/ication for a Permit to t7ril! must be accampanied by each of the following items, except for an item a/ready on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by ZO AAC 25.035, unless this requirement js waived by the commission under 20 AAC25.035(h)(2); No diverter system will be utilized during operations on iJ-118 L2. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to ©rill must he accompanied by each of the following items, except far an item already on fi/e witfr the commission and identifred in the app/icatian: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by Z©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 Densit 8.6 Plastic Viscostiy Ib/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 ~7/ Y" ~ l7-(? <` 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-118L2 PERMIT IT Page 4 of 6 Printed: 4-Dec-O6 !'~IGINAL • Applic~r Permit to Drill, Well 1J-118 L2 Revision No.O Saved:4-Dec-06 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An app/ication for a Permit to Drill must be accompanied by each of the fo/%wing items, except for an item already on fr/e with the commission and identified in the application; (9) for an exploratory ar stratigraphic test wel% a tabulation setting out the depths of predicted abnormally geo pressured strata as required by 20 AAC 25.033(1); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application fora Permit to Dri// must be accompanied by each of the fo//awing items, except for an item already an file with the commission and /dentifred in the application; (10J far an exploratory or stratigraphic test we/% a seismic refraction or reflection ana/ysis as required by 20 A.4C25, ®61(a); Not applicable: Application is not for an exploratory or stratigraphic test well 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An app//canon for a Permit to Drill must be accompanied by each of the fo/lowing items, except for an item already on file with the commis/on and identified in the application; (11) far a well drilled from an offshore p/ah`orm, mobile bottom-founded structure, jack-up rig, or t7oating dri/ling. Vess% an ana/ysis ofseabed conditions as required by 20 AAC 25.061(6); 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 Pern~ft to Dri// must be accompanied by each of the fo/%wing items, except for an item a/ready an file with the commission and identified in the application; (12) evidence shaving that the requirements of 20 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 app/ication for a Permit to Drill must be accompanied by each of the following items, except for an item a/ready on file with the commission and identified 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 iJ-118 Application for Permit to Drill. 1. Run and set Saker WindowMaster whipstock system, at window point of +/- 6,961' MD / 3,59T TVD the top of the D sand. 2. .Mill 6-3/4" window. POOH. 3. Pick up 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. 4. Drill to TD of D sand lateral at +/- 14,678' MD J 3,713' 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-118L2 PERMIT IT Page 5 of 6 Printed; 4-Dec-O6 • Applic~r Permit to Drill, Well 1 J-118 L2 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, laying down drill pipe as required. 12. PU completion as required and RIH to depth. Land tubing. Set BPV. 13. Nipple down BOPE, nipple up tree and test. Pull BPV. 14. Freeze protect well with diesel 15. Set BPV and move rig off. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill muste be accompanied by each of the fol%wing items, except for an item already on fr/e with the commission and identifred in the application: (I4) a general description of haw the operator p/ans to dispose of dri/ling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25. Q80 for an annular disposal operation in the wefl.; Waste flu-ids 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. ConocoPhiilips 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 1J-118L2 PERMIT IT Page 6 of 6 A ~ ~ ~ ~ Printed.• 4-Dec-06 .. ,~ Cono~oPhillips Alaska • Plan: 1 J-118 L2 (wp05) Sp rry Drilling Servic s Proposal Report -Geographic 02 November, 2006 ConocoPhillips Alaska, Inc. Kuparuk River Unit KuparuK 1J Pad Phan 1J-118 1J-118 L2 Local Coordinate Origin: Centered on Well Plan 1J-118 Viewing Datum: Doyon 141 (28+81) @ 109.OOft (Doyon 141 (28+81)) TVDs to System: N North Reference: True ' Unit System: API - US Survey Feet Sperry Drilling Services ORIGINAL ConocoPhillips ~ Alaska I Database: EDM_2003.11_b48 Company: ConocoPhillips Alaska, Inc. Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-118 Welibore: 1J-118 L2 Design: 1J-118 L2 (wp05) Project Kuparuk Eiver Unit, North Slope Ala;ha United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point. Map Zone: Alaska Zone 04 Using geodetic scale factor Well Plan 1J-118 Well Position +N/-S 0.00 ft Northing: 5,945,726.90 ft ~ Latitude: 70° 15' 44.358" N +E/-W 0.00 ft Easting: 558,844.00 ft Longitude: 149° 31' 27.477" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft Wellbore 1J-118 L2 ,.. Magnetics Model Name Sample Date Declination I Dip Angle Field Strength ' bggm2005 6/25!2006 24.05 80.77 57,564 Design 1J-11R L9 /wn05) Audit Notes: Version: 8 Phase: PLAN Tie On Depth: 6,959.60 Vertical Section: Depth From (TVD) +N(-5 +E!-W Direction (ft) (ft) (ft) (`) 28.00 0.00 0.00 0.00 11/2/2006 9:20:25AM Page 2 of 7 COMPASS 2003.11 Build 50 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: P:linimum Curvature - Halliburton Energy Services Planning Report -Geographic Drflling and Farmstion Evaluation • • ConocoPhillips Alaska [~ [ Database: _EDM_2003.11_b48 Company: ConocoPhillips Alaska, Inc. Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-118 Wellbore: 1J-118 L2 Design: 1J-118 L2 (wp05) Local Co-ordinat6 Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: 'o"Jell Plan 1J-118 Doyon 141 (28+81) @ 109.OOft (Doyon 141 (28+81)) Doyon 141 (28+81) @ 109.OOft (Doyon 141 (28+81)) T-ue h,inimum Curvature Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/-W Rate Ra[e Ra[e TFO (ft) (~) (") (fQ (ft) (ft) ("J100ft) (°I100ft) (°1100ft) l°) 6,959.60 77.00 357.70 3,597.00 1,306.29 4,602.79 0.00 0.00 0.00 0.00, 6,971.60 78.91 357.70 3,599.50 1,318.01 4,602.32 15.90 15.90 0.00 0.00 7,001.60. 78.91 357.70 3,605.27 1,347.43 4,601.14 0.00 0.00. 0.00 0.00 7,229.21 90.29 357.70 3,626.66 1,573.47 4,592.04 5.00 5.00 0.00 0.00 7,600.49 90.29 357.70 3,624.80 1,944.45 4,577.12 0.00 0.00- 0.00 0.00 7,628:66 88.88 357.70 3,625:00 1,972.59 4,575.99 5.00 -5.00 0.01 179.88 7,734.70 89.47 354.57 3,626.53 2,078.37 4,568.85 3.00 0.55 -2.95 -79:41 8,428.73 89.47 354.57 3,633.00 2,769.26 4,503.21 0.00 0.00 0.00 0.00 8,438.59 89.21 354.42 3,633.11 2,779.07 4,502.26 3.00 -2.59 -1.52 -149.53 9,229.31 89.21 354.42 3,644.00 3,565.97. 4,425.43 0.00 0.00 0.00 0.00 9,387.93 88.64 359.15 3,646.97 3,724.28 4,416.53 3.00 -0.36 2.98 96.89 10,529.44 88.64 359.15 3,674.00 4,865.34 4,399.58 0.00 0.00 0.00 0.00 10,545.02 88.95 359.50 3,674.33 4,880.91 4,399.39 3.00 2.00 2:24 48.31 11,129.68 88.95 359.50 3,685.00 5,465.45 4,394.26 0.00 0.00 0.00 0.00 11,152.13 89.59 359.72 3,685.29 5,487.90 4,394.11 3.00 .2.83 0:99 19.32 12,228.91 89.59 359.72 3,693.00 6,564.64 4,388.85 0.00 0.00 0.00 0.00 12,240.29 89.93 359.73 3,693.05 6,576.02 4,388.80 3.00 3.00 0.10 1.93 13,029.05 89.93 359.73 3,694.00 7,364.77 4,385.10 0.00 0.00 0.00 0.00 13,044.15 89.48 359.76 3,694.08 7,379.86 4,385.04 3.00 -2.99 0:19 176.43 13,695.19. 89.48 359.76 3,700.00 8,030.87 4,382.31 0.00 0.00 0.00 0.00 13,706.94 89.14 359.67 3,700.14 8,042.62 4,382.25 3.00 -2.89 -0.79 -164.64 14,429.41 89.14 359.67 3,711.00 .8,765.00 4,378.04 0.00 0.00 0.00 0.00 14,447.17 89.55 360.00 3,711.20 8,782.75 4,377.99 3.00 2.34 1.88 38.69 14,678.45 89.55 360.00 3,713.00 9,014.03 4,377.99 0.00 0.00 0.00 0.00 11/2/2006 9:20:25AM Page 3 of 7 COMPASS 2003.11 Build 50 Q~~~~~w Halliburton Energy Services Planning Report -Geographic LLE~I"r Drilling and Formation Evaluation ConocoPhillips Alaska Database: _EDM_2003.11_b48 Company: ConocoPhillips Alaska, Inc. Project Kuparuk River Unit Site: Kuparuk iJ Pad Well: Plan 1J-118 Wellbore; 1J-118 L2 Design: 1J-118 L2 (wp05) Halliburton Energy Services aL,~~°rlly Planning Report -Geographic o~ini~g a~a Formaoinn Evaluation Local Co-ordinate Reference: G;rell 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: Painimum Curvature Planned Survey 1J-1':~ L~ ir:;_~45j j~ Map Map MD Inclination Azimuth TVD SSTVD +N!-S +EI-W Northing Easting DLSEV Vert Section (ft) (~) (`) lftl lft) (ft) (ft) (ft) (ftl (°1100ft) (ft) 6,959.60 77.00 357.70 3,597.00 3,488.00 1,306.29 4,602.79 5,947,068.99 563,436.00 0.00 1,306.29 6,960.60 77.16 357.70 3,597.22 3,488.22 1,307.26 4,602.75 5,947,069.96 563,435.95. 15.90 1,307.26 L2 - 7 5/8" TOW - 6961' MD, 3597 TVD: 2061'FNL, 2238'FWL - Sec36-T11 N-R10E - 7 5/8" TOW 6,971.60 78.91 357.70 3,599.50 3,490.50 1,318.01 4,602.32 5,947,080.71 563,435.44 15.90. 1,318.01 L2 - 7 5/8" BOW - 6972' MD, 3600' TVD 7,001.60 78.91 357.70 3,605.27 3,496.27 1,347.43 4,601.14 5,947,110.11 563,434.02 0.00 1,347.43 7,099.97 83.83 357.70 3,620.03 3,511.03 1,444.58 4,597.23 5,947,207.22 563,429.36 5.00 1,444.58 7,199.97 88.83 357.70 3,626.44 3,517.44 1,544.26 4,593.22 5,947,306.86 563,424.57 5.00 .1,544.26 7,229.21 90.29 357.70 3,626.66 3,517.66 1,573.47 4;592.04 5,947,336.06 563,423.17 5.00. 1,573.47 7,299.97 90.29 357.70 3,626.31 3,517.31 1,644.18 4,589.20 5,947,406.73 563,419.77 0.00 1,644.18 7,399.97 90.29 357.70 3,625.81 3,516.81 1,744.09 4,585.18 5,947,506.60 563,414.97 0.00 1,744.09 7,499.97 90.29 357.70 3,625.30 3,516.30 1,844.01 4,581.16 5,947,606.47 563,410.17 0.00 1,844.01 7,600.49 90.29 357.70 3,624.80 3,515.80 1,944.45 4,577.12 5,947,706.87 563,405.35 0.00 1,944.45 7,628.66 88.88 357.70 3,625.00 3,516.00 1,972.59 4,575.99 5,947,735.00 563,404.00 5.00 1,972.59 1J-118 D CP1 8/1/06 7,699.97 89.27 355.60 3,626.15. 3,517.15 2,043.77 4,571.83 5,947,806.13 563,399.28 3.00 2,043.77 7,734.70 89.47 354.57 3,626.53 3,517.53 2,078.37 4,568.85 5,947,840.71 563,396.03 3.00 2,078.37 7,799.97 89.47 354.57 3,627.14 3,518.14 2,143.34 4,562.68 5,947,905.62 563,389.35 0.00 2,143.34 7,899.97 89.47 354.57 3,628.07 3,519.07 2,242.89 4,553.22 5,948,005.08 563,379.12 0.00 2,242.89 7,999.97 89.47 354.57 3,629.00 3,520.00 2,342.44 4,543.76 5,948,104.54 .563,368.88 0.00 2,342.44 8,099.97 89.47 354.57 3,629.94 3,520.94 2,441.98 4,534.30 5,948,204.01 563,358.65 0.00 2,441,98 8,199.97 89.47 354.57 3,630.87 3,521.87 2,541.53 4,524.85 5,948,303.47 563,348.41 0.00 2,541.53 8,299.97 89.47 354.57 3,631.80 3,522.80 2,641.08 4,515.39 5,948,402.93 563,338.18 0.00 2,641.08 8,399.97 89.47 354.57 3,632.73 3,523.73 2,740.62 4,505.93 5,948,502.39 563,327.94 0.00 2,740.62 8,428.73 89.47 354.57 3,633.00 3,524.00 2,769.26 4,503.21 5,948,531.00 563,325.00 0.00 2,769.26 1J-118 D CP2 8/1/O6 8,438.59 89.21 354.42 3,633.11 3,524.11 2,779.07 4,502.26 5,948,540.80 563,323.98 3.00 2,779.07 8,499.97 89.21 354.42 3,633:96 3,524.96 2,840.15 4,496.30. 5,948,601.83 563,317.54 0.00 2,840.15 8,599.97 89.21 354.42. 3,635.34 3,526.34 2,939.67 4,486.58 5,948,701.25 563,307.04 0.00 2,939.67 8,699.97 89.21 354.42 3,636.71 3,527.71 3,039.18 4,476.86 5,948,800.68 563,296.55 0.00 3,039.18 8,799.96 89.21 354.42 3,638.09 3,529.09 3,138.70 4,467.15 5,948,900.11 563,286.06 0.00 3,138.70 8,899.96 89.21 354.42 3,639.47 3,530.47 3,238.22 4,457.43 5,948,999.54 563,275.56. 0.00 3,238.22 8,999.96 89.21 354.42 3,640.84 3,531.84 3,337.73 4,447.71 5,949,098.97 563,265.07 0.00 3,337.73 9,099.96 89.21 354.42 .3,642.22 3,533.22 3,437.25 4,437.99 5,949,198.40 563,254.57 0.00 3,437.25 9,199.96 89.21 354.42 3,643.60 3,534.60 3,536.77 4,428.28 5,949,297.82 563,244.08 0.00 3,536.77 9,229.31 89.21 354.42 3,644.00 3,535.00 3,565.97 4,425.43 5,949,327.00 563,241.00 0.00 3,565.97 1J-118 D CP3 8/1/06 9,299.96 88.96 356.53 3,645.13 3,536.13 3,636.39 4,419.85 5,949,397.37 563,234.88 3.00. 3,636.39 9,387.93 88.64 359.15 . 3,646.97 3,537.97 3,724.28 4,416.53 5,949,485.21 563,230.87 3.00 3,724.28 9,399.96 88.64 359.15 3,647.26 3,538.26 3,736.30 4,416.36 5,949,497.23 563,230.60 0.00 3,736.30 9,499.96 88.64 359:15 3,649.62 3,540.62 3,836.26 4,414.87 5,949,597.17 563,228.33 0.00 3,836.26 9,599.96 88.64 359.15 3,651.99 3,542.99 3,936.22 4,413.38 5,949,697.11 563,226.07 0.00 3,936.22 9,699.96 88.64 359.15 3,654.36 3,545.36 4,036.18 4,411.90 5,949,797.04. 563,223.80 0.00 4,036.18 9,799.96 88.64 359.15 3,656.73 3,547.73 4,136.14 4,410.41 5,949,896.98 563,221.53 0.00 4,136.14 9,899.96 88.64 359.15 3,659.10 3,550.10 4,236.10 4,408.93 5,949,996.92 563,219.27 0.00 4,236.10 9,999.96 88.64 359.15 3,661.46 3,552.46 4,336.06 4,407.44 5,950,096.85 563,217.00 0.00 4,336.06 11/2/2006 9:20:25AM Page 4 of 7 COMPASS 2003.11 Build 50 O~ • • ' Halliburton Energy Services ~.~~-~~' COI IOC OPI11II1p5 Planning Report -Geographic Qrilling and Form®tion - -- Alaska Evacuation I Database: _EDM_2003.11_b48 Local Co-ordinate Reference: , . '^'ell Plan 1J-118 Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 141 (28+81) @ 109.OOft (Doyon 141 (28+81 )) Project: Kuparuk River Unit MD Reference: Doyon 141 (28+81) @ 109.OOft (Doyon 141 (28+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-118 Survey Calculation Method: P;linimum Curvature Wellbore: 1J-118 L2 Design: 1J-118 L2 (wp05) ' Planned Survey 1J-1 1 L2 (wp051 MD Inclination Azimuth 10,099.96 88.64 359.15 10,199.96 88.64 359.15 10,299.96 88.64 359.15 10,399.96 88.64 359.15 10,499.96 88.64 359.15 10,529.44 88.64 359.15 1J-118 D CP4 8/1/06 10,545.02 88.95 359.50 10,599.96 88.95 359.50 10,699:96 88.95 359.50 10,799.96 88.95 359.50 10,899.96 88.95 359.50 10,999.96 88.95 359.50 .11,099.96 88.95 359.50 11,129.68 88.95 359.50. 1J-11.8 D CPS 8/1/06 11,152.13 89.59 359.72 11,199.96 89.59 359.72 11,299.95 89.59 359.72 11,399.95 89:59 359.72 11,499.95 89.59 359.72 11,599.95 89:59 359.72 11,699.95 89.59 359.72 11,799.95 89.59 359.72 11,899.95 89.59 359.72 11,999.95 89.59 359.72 12,099.95 89.59 359.72 12,199.95 89.59 359.72 12,228.91 89.59 359.72 1J-118D CP68/1/06 12,240.29 89.93 359.73 12,299.95 89.93 359.73 12,399.95 89.93 359.73 12,499.95 89.93 359.73 12,599.95 89.93 359.73 12,699.95 89.93 359.73 12,799.95 89.93 359.73 12,899.95 89.93 359.73 12,999.95 89.93 359.73 13,029.05 89.93 359.73 iJ-118 D CP7 8/1/06 13,044.15 .89.48 359.76 13,099.95 89.48 359.76 13,199,95 89.48 359.76 13,299.95 89.48 359.76 13,399.95 89.48 359.76. Map Map TVD SSTVD +NI-S +EI-W Northing Easting DLSEV (ft) (ft) (ft) (ft) lft) (ft) (°I100ft) 3,663.83 3,554.83 4,436.02 4,405.96 5,950,196.79 563,214.73 0.00 3,666.20 3,557.20 4,535.98 4,404.47 5;950,296.73 563,212.47 0.00 3,668.57 3,559.57 4,635.94 4,402.98 5,950,396.66 563,210.20 0.00 3,670.93 3,561.93 4,735.90 4,401.50 5,950,496.60 563,207.93 0.00 3,673.30 3,564.30 4,835.86 4,400.01 5,950,596.53 563,205.67 0.00 3,674.00 3,565.00 4,865.34 4,399.58 5,950,626.00 563,205.00 0.00 Vert Section (ft) ~~ 4,436.02 4,535.98 4,635.94 4,735.90 4,835.86 4,865.34 3,674.33 3,565.33 4,880.91 4,399.39 5,950,641,56 563,204.69 3.00 4,880.91 3,675.33 3,566.33 4,935.84 4,398.91 5,950,696.48 563,203.78 0.00 4,935.84 3,677.16 3,568.16 5,035.82 4,398.03 5,950,796.44 563,202.13 0.00 5,035.82 3,678.98 3,569.98 5,135.79 4,397.16 5,950,896.40 563,200.47 0.00 5,135.79 3,680.81 3,571.81 5,235.77 4,396.28. 5,950,996.36 563,198.81 0.00 5,235.77 3,682.63 3,573.63 5,335.75 4,395.40 5,951,096.32 563,197.15 0.00 5,335.75 3,684.46 3,575.46 5,435.73 4,394.52 5,951,196.28 563,195.49 0.00 5,435.73 3,685.00 3,576.00 5,465.45 4,394.26 5,951,226.00 563,195.00 0.00 5,465.45 3,685.29 3,576.29 5,487.90 4,394.11 5,951,248.44 563,194.67 3.00 5,487.90 3,685.63 3,576.63 5,535.72 4,393.88 5,951,296.25 563,194.06 0.00 5,535.72 3,686.34 3,577.34 5,635.72 4,393.39 5,951,396.23 563,192.79 0.00 5,635.72 3,687.06 3,578.06 5,735.71 4,392.90 5,951,496.21 563,191.52 0.00 5,735.71 3,687.78 3,578.78 5,835.71 4,392.41 5,951,596.19 563,190.26 0.00 5,835.71 3,688.49 3,579.49 5,935.70 4,391.92 5,951,696.17 563,188.99 0.00 5,935.70 3,689.21 .3,580.21 6,035.70 4,391.44 5,951,796.15 563,187.72 0.00 6,035.70 3,689.93 3,580.93 6,135.70 4,390:95 5,951,896.13 563,186.45 0.00 6,135.70 3,690.64 3,581.64 6,235.69 4,390.46 5,951,996.11 563,185.18 0.00 6,235.69 3,691.36 3,582.36 6,335.69 4,389.97 5,952,096.09 563,183.91 0.00 6,335.69 3,692.08 3,583.08 6,435.68 4,389.48 5,952,196.07 563,182.64 0.00 6,435.68 3,692.79 3,583.79 6,535.68 4,388.99 5,952,296.05 563,181.37 0.00 6,535.68 3,693.00 3,584.00 6,564.64 4,388.85 5,952,325.00 563,181.00 0.00 6,564.64 3,693.05 3,584.05 6,576.02 4,388.80 5,952,336.38 563,180.86 3.00 .6,576.02 3,693.12 3,584.12 6,635.68 4,388.52 5,952,396.03 563;180.11 0.00 6,635.68 3,693.24 3,584.24 6,735.68 4,388.05 5,952,496.01 563,178.86 0.00 6,735.68 3,693.36 3,584.36 6,835.67 4,387.58 5,952,595.99 b63,177.61 0.00 6,835.67 3,693.48 3,584.48 6,935.67 4,387.11 5,952,695.98 563,176.36 0.00 6,935.67 3,693.60 3,584.60 7,035.67 4,386.65 5,952,795.96 563,175.11 0:00 7,035.67 3,693.72 3,584.72 7,135.67 4,386.18 5,952,895.94 563,173.86 0.00. 7,135.67 3,693.84 3,584.84 7,235.67 4,385.71 5,952,995.92 563,172.61 0.00 7,235.67 3,693.96 3,584.96 7,335.67 4,385.24 5,953,095.90 563,171.36 0.00 7,335.67 3,694.00 3,585.00 7,364.77 4,385.10 5,953,125.00 563,171.00. 0.00 7,364.77 3,694.08 3,585.08 7,379.86 4,385.04 5,953,140.09 563,170.82 3.00 7,379.86 3,694.59 3,585.59 7,435.66 .4,384.80 5,953,195.88 563,170.15 0.00 7,435.66 3,695.50 3,586.50 7,535.66 4,384.38 5,953,295.86 563,168.94 0.00 7,535.66 3,696.40 3,587.40 7,635.65 4,383.97 5,953,395.84 563,167.74 0.00 7,635.65 3,697.31 3,588.31 7,735.65 4,383.55 5,953,495.82 .563,166.54 0.00 7,735.65 11/2/2006 9:20:25AM Page 5 of 7 COMPASS 2003.11 Build 50 !l Halliburton Energy Services L,~f~r Conoc oPhi ips Planning Repo rt -Geographic °"mt^s a^a F°"macs°^ Alaska Evaw act°^ ~ ~ Dal tabase: _EDM_2003.11_b48 Local Co-ordinate Reference: Well Pl an 1J-118 Company: ConocoPhillips Alaska, Ina ND Reference: Doyon 141 (28+81) @ 109.OOft (Doyon 1 41 (28+81)) Project: Kuparuk River Unit MD Reference: Doyon 141 (28+81) @ 109.OOft (Doyon 1 41 (28+81 )) Site: Kuparuk 1J Pad Nortl~ Referenc e: True Well: Plan 1J-118 Survey Calculation Method: P~1inimu m Curvature Wellbore: iJ-118 L2 Design: 1J-118 L2 (wp05) Planned Survey 1J-11 ~ L2 Iwp05) ~I Map Map MD Inclination Azimuth TVD SSTVD +N/-S +E(-W Northing Easting DLSEV Vert Section (ft) (~) (`) (ft) (ft) (ft) (ft) (ft) (ft) f°1100ft) Iftl 13,499.95 89.48 359.76 3,698.22 3,589.22 7,835.64 4,383.13 5,953,595.80 563,165.34 0.00 7,835.64 13,599.95 89.48 359.76 3,699.13 3,590.13 7,935.63 4,382.71 5,953,695.78 563,164.14 0.00 7,935.63. 13,695.19 89.48 359.76 3,700.00 3,591.00 8,030.87 4,382.31 5,953,791.00 563,163.00 0.00 8,030.87 1J-118 D CP8 8/1106 13,706.94 89.14 359.67 3,700.14 3,591.14 8,042.62 4,382.25 5,953,802.75 563,162.85 3.00 8,042.62 13,799.94 89.14 359.67 3,701.54 3,592.54 8,135.62 4,381.71 5,953,895.73 563,161.58 0.00 8,135,62 13,899.94 89.14 359.67 3,703.04 3,594.04 8,235.60 4,381.13 5,953,995.69 563,160.22 ' 0.00 8,235.60 13,999.94 89.14 359.67 3,704.55 3,595.55 8,335.59 4,380.54 5,954,095.66 563,158.85 0.00 8,335.59 14,099.94 89.14 359.67 3,706.05 3,597.05 8,435.58 4,379.96 5,954,195.63 563,157.49 0.00 8,435.58 14,199.94 89.14 359.67 3,707.55 3,598.55 8,535.56 4,379.38 5,954,295.60 563,156.13 0.00 8,535.56 14,299.94 89.14 359.67 3,709.05 3,600.05 .8,635.55 4,378.80 5,954,395.57 563,154.77 0.00 8,635.55 14,399.94 89.14 359.67 3,710.56 3,601.56 8,735.54 4,378.22 5,954,495.54 563,153.40 0.00 8,735.54 14,429.41 89.14 359.67 3,711.00 3,602.00 8,765.00 4,378.04 5,954,525.00 563,153.00 0.00 8,765.00 1J-118 D CP9 8/1/06 14,447.17 89.55 360.00 3,711.20 3,602.20 8,782.75 4,377.99 5,954,542.75 563,152.81 3.00 8,782.75 14,499.94. 89.55 360.00 3,711.61 3,602.61 8,835.53 .4,377.99 5,954,595.52 563,152.40. 0.00 8,835.53 14,599.94 89.55 360.00 3,712.39 3,603.39 8,935.53 4,377.99 5,954,695.50 563,151.61 0.00 8,935.53 .14,678.45 89:55 360.00 3,713.00 ~ 3,604.00 9,014.03 4,377.99 5,954,774.00 563,151.00 0.00 9,014.03 L2 - BHL 14678' MD, 3713' TVD: 36T FSL, 2021' FWL - Sec24-T71N-R10E - 41/2" 11/2/2006 9:20:25AM Page 6 of 7 COMPASS 2003.11 Build 50 ~~ .., ~ • ConotoPhillips Alaska Database: EDM_2003.11_b48 Company: ConocoPhillips Alaska, Inc. Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-118 it Wellbore: 1J-118 L2 Design: 1J-118 L2 (wp05) Geologic Targets 1J-118 L2 TVD (ft) 3,625.00 1J -Point 3,700.00 1J -Point 3,685.00 1 J - Point 3,693.00 1J -Point 3,674.00 1J - Point 3,711.00 1 J -Point 3,694.00 1J - Point .3,633.00 1J -Point 3,713.00. iJ -Point 3,644.00 1J -Point Halliburton Energy Services Planning Report -Geographic Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: ~,~~tl~ Drilling end Formation Evaluation `Nell Plan 1J-118 Doyon 141 (28+81) @ 109.OOft (Doyon 141 (28+81)) Doyon 141 (28+81) @ 109.OOft (Doyon 141 (28+81)) True ~.linimum Curvature Target Namc +Nl-S +El-W Northing Easting 31iap^ ft ft (ft) (ft) 118 D._GP1 8/1(06 1,972.59 4,575.99 5,947,735.00 563,404.00 118 D_GP8 811106 8,030.87 4,382.31 5,953,791.00 563,163.00 118D_CP58I1106 5,465.45 4,394.26 .5,951,226.00 563,195.00 118 D_CP8 8/1106 6,564.64 4,388.85 5,952,325.00 563,181.00 118 D_CP4 8/1(06 4,865.34 4,399.58 5,950,626.00 563,205.00 118 D_CP9 8IV08 8,765.00 4,378.04 5,954,525.00 563,153.00 118D_CP78/1(O6 7,364.77 4,385.10 5,953,125.00 563,171.00 118 D_CP2 8!1(08 2,769.26 4,503.21 5,948,531.00 563,325.00 -118 D_Toe 8/1106 9,014.03 4,377.99 5,954,774.00 563,151.00 118 D_CP3 8/1!08 3,565.97 4,425.43 5,949,327.00 - - - - - - - - 563,241.00 - Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) (~~) (~~) 3,221.71 2,200.00 i0-3f4 13-112 6,960.60 3,597.22 7-5/8 9-5/8 14,678.40 3,713.00 4-112 63/4 Plan Annotations I Measured Vertical Local Coordinates I Depth Depth +Nl-S +FJ-W Comment fft) (ft) (ft) (ft) 6,960.60 3,597.22 1,307.26 4,602.75 L2 - 7 5/8" TOW - 6961' MD, 3597' TVD: 2061'FNL, 2238'FWL - Sec36-T11N-R10E 6,971.60 3,599.50 1,318.01 4,602.32 L2 - 7 5/8" BOW - 6972' MD, 3600' TVD 14,678.44 3,713.00 9,014.02 4,377.99 L2 - BHL 14678' MD, 3713' TVD: 36T FSL, 2021' FWL - Sec24-T11 N-R10E 11/2/2006 9:20:25AM Page 7 of 7 COMPASS 2003.11 Build 50 1J-118LZ~rillin Hazards S~mmar i. (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED 'DISCUSSION OF THESE RISKS) 6-3/4" Open Hole / 4-1/2" Liner Interval Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure ~ Low Stripping drills, shut-in drills, increased mud wei ht. 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 1J-118L2 Drilling Hazards Summary prepared by David A. Nugent 12/4/2006 2:33 PM 20" 94.11# x 34" Insulated Conductor, K-55, set at +/- 80' 10-3/4" x 4.1/2" Wellhead, 5,000 psi Tubing, 4-1/2", 12.6#, IBTM, Special Drift to+/. 500' Shoe set @ 3222' MD, 2200' TVD / Tubing String 4-1 /2" 12.6#, L-80, IBTM 3.958" ID, 3.833" Drift 5.1/2" X 7-518" ZXP Liner Top Packer cal Hold Seal Assembly Downs 4.75" Seal OD 3.875" DB Nipple, for Possible SSSV, +/. 500' GLM, Camco KBG2, 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" DB Nipple, 72 deg, +/- 1 jt above seals ~. Casing Sealbore Receptac '20' Length ~aC'~CO~'11~1~ West Sak 7-5/8" Injector 1J-118 Tri-Lateral Completion ral EntEM) 1 D-sand Window ~t 6960' MD, 3597' TVD 'D' Sand i Lateral Payzone ECP 4112" 11.6# L-80 Slotted Liner Every Other Joint `' I I ~ 4.112" Guide Shoe ,r i - ~ ' _ - - ---- 4-1 /2" Liner Shoe, 11.6#, L-80 BTfi ' ' ' \ i ~ :1~ 5.1/2" Tieback Sleeve Set @ 14678 MD, 3713 T~,D 4-112" X 7-818" Seal Bores jdgdel 'B' HOOK Hanger 3.68" ID 5-112" X 7-5/8" ZXP Liner Top Packer cal Hold Downs Lateral Entry Module (LEM1 A m '. k:: E .~ 5-112" X 7-SIB" ZXP Liner Top - -, Packer with Hold Downs Casing Sealbore Receptacle 4.75" ID OrienOng Profile Automatic Alignment of LEM Positive Latching Collet Indicates Correct Location ~ Seal Bore for Lateral IsolaOon - 3.66" ID Access Window Positive Lateral Access Via Thru-Tubing Diverter Seal Bore for Lateral Isolation - 3.68" ID Isoladon Seal Asembly 4.75" Seal OD 3.875" Seal ID Teal Assembly 4.75" Seal OD Lateral Entry Module(LEM) ~~~ B dW' d Casing Sealbore 4 Receptacle 20'Length 4-112" X 7.516" - " Model 'B' HOOK Hancer -san In ow at 7323• MD, 3677 TVD 'B' Sand Lateral 4.1/2" 11.6# L-80 Slotted Payzone ECP Liner Every Other Joint °.. ~ ... ~ I 41 l~+r~ N1~1611LS Baker Oil Tools With Div erters and Isolation Lateral Access Diverter Lateral Isolation Diverter GS Running Tool Stdng Installetl Installetl (3.00" Lateral Drin) (2.50" ID Mainbore DrKt) ' ' ^'-Coll Connector (1.00' Length) GS Profile for fRunninglRetrievingti l ~ Snap InlSnap Out r Back Pressure Valve /POSitive LOwtingti _" (1.60' Length) i ~ Collet l l l 6 ~~ L t I I f l r Flow-Thm Swivel ~ 'I , 1 era so a on a Seals ~ ( ,k ~ (1.25' Length) 1 I-J ~ f Lateral Diverter ~ 3 yi Hydraulic 3 ' Ramp ~ Disconnect ` /+' IsolatioN Mainbore i (1.50' Length) Diverter Sleeve ~~ GS Spear (1.50'Length) Lateral Isolation ~~ f ~ Seals ~ 6.65 a Approx. OAL' / ...~ ~ ~ . . E'I 'Jars may he required in highly deviated 78.5' Diverter Length 18.5' Sleeve Length a--' or deep applications (6' approx length). P Guide Shoe `~^'""^'~~~ . :.. 4-1 /2" Liner Shoe, 11.6#, L-80 BTC Seal Bores 5-1/2" Tieback Sleeve Set @ 14666' MD, 3774' TVD 3.68" ID 4-112" bent muleshoe 4.1/2" 12.6# Tubin 3.562" DB Nipple 3.833" Drin 3.958" ID r .~\', ti, / ~` 5-112" X 7-518" ZXP \ ~ ~:;• Liner Top Packer with Hold Downs .~~ 5-112" X 7.5/8" Flex Lock Liner Hanger I Packer Assembly at Liner Hanger +I- 7423' MD, 3694' TVD Casing Sealbore Receptacle, 20' Length Eauipment Specifications Seal Assembly Lateral Dnft, cal toll dwerter. 3.00" 4.75" Seal OD OD of Diverter and Sleeve: +l- 3.89" 'A' Sand Undulating Lateral Dlverter and Sleeve Length:+l-18.5' 4-1/2" 11.6# L-80 Slotted Liner Every Other Joint 4.112" Eccentric ~t,~ Guide Shoe ~., `~' ~"'""'~ + ~~ 4.1/2" Casing Shoe, 11.6#, L-80 BTC ' ' _ ~, f~,--- - Set @ 14571 TVD MD, 3920 7-5/8" 40# Casing, L-80, BTCM, ® Baker Hu hes 2005. This document may not be re reduced or tllatdbuted, In whole or In rt, in any form or Set at @ 8338' MD, 3848' TVD ows Tltl.: 9 P Pa (85 deg) Weat Sak 7-5/6" Trl-laterel Compledon - Infector by any means electronic or mechanical, Ineluding photocopying, retooling, or by any Iniormatlon storage antl retrieval system now known ar hereaner Invented, without written permission Rom Baker Hughes Inc. Date: Drawn ey: ReWelon N".: November'I, 2008 Marc D. Kuck 0 4-1/2" X 7-518" 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: 3.65" Mainbore Drift, cal isolation sleeve: 2.50" • • • ~'~ZANSIVIIT'I'AL LETTEIa CFIECKLIST iWELL NAIVIE K~~ ~''T ~lg ~' Z Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CF~CK ~ ADD-ONS ,' 1~b'HAT ~ (OPTIONS) aPPLIES TEXT FOR APPROVAL LETTER MliLTI LATERAL ~ The permit is for a new wellbore segment of existing I ~ welt ~~ ~S ~~g I (If last two digits in ,Permit No.2O~(o-/7~ , APt No. ~0-02 - Z.3~37 - ~ API number ;between 60-69) are ; ~ Production should continue to be reported as a function of the original AP[ number stated above. PILOT HOLE In accordance with 20 A.4C 25.005(f), all records; data and logs ;acquired for the pilot hole must be clearly differentiated in both ~ ' ~ tivell name ( PH) and API number i I (~0_ _ -__) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC 'EXCEPTION 12.0». Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing j I exception. assumes the ~ ~ i liability of any protest to the spacing exception that may occur. f i DRY D[TCH ; Al[ dry ditch sample sets submitted to the Commission must be in i i SA!~IPLE I no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals j ;through target zones. ;Please note the following special condition of this permit: Non-Conventional ~ production or production testing of coat bed methane is not allowed Well ~ for (name of well) until after (Company 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: l %Z~i06 C 'jody~transmitta!_checklist • • a^ „ : m a , Q t y G ~~ N, 'p N' ~: y: X , : ~ O a rn ~ O: ~~ ~ 4 ~ ~ ~ ~ C a, ~ v. N o C• w a ~ Q ~ , W ~ .q U~ ~, ~ ~ ~ ~ ~ ~ ~ ~ ~ , a ~ .. ., O' . a ~ ~ ~ ~ ~, ~~ m, ~- ~ O L ~ ~~ ~ ~ ~ , O ~ ~ ~ O, ~ ~, ~, O, ~ ~, ~ ~ ~~ a ~ t~ , ~ ~ ~ ~ , O p. O, iA N t N > m ~ ~ ~ ~ M, O ~ t0 O ~ G, ~ ~ 07 Z, O ~ ~, ~ , m N . , p m , ~ . ~ ~ p ~ ~ ~ ~ 4 , ~ N ~ , y . : ~ O, ~ _ 0~ ~ ~ 0, ~, ~ ~ ~ : ~ m O o: o. ~ C7. ~': 3. ~ ~, O, J N ~~ C ~ a •C fQ ~U~ a ~, z. ~ ~ ~ . ~ o. ~~ N, ~~ O, . O' ~ y~ N' O~ r, ~ ~~ .~ ~ M' ~, ~ M, ~ ~ p' 'Q ~ Q W' N, ~ ~ ~ ui - Yi v. o' 3. m, a ~~ a`i o, Z N, ~, m`' ~, o ~ ~, .. rn, o. ~, ~ ~ a~ 4 a '~ N o, ~ ~ a, ~ g, v, J. ~ ~ d' O w r ~ Y N m Q - a O '~ i ~~ a. a~ ~ ~ , , m' ~, a , ~ N, V, ao ~~ , y~ m u ~ °~ p., c' ~ ~ .~ Q ~ o . , ~ a : . , o o c+a ~, 4 , . a, , ° ' 0 ' ~ ~ ° o d ~ ~, Z. in c ~ o m ; a i c ~ a ~ u i, r. °, . a ~ o' ° Y ' ~ ~ ~ ~, o, ~ N ~ r, Z Y O uJ•>, ~ 'c, ~, m y o w a ~ ~ ~ ~ ~ a O 7 Y ~ `~ O N G U f0 G O N f6 Y U G ~~ t N CJ . . O: a ~ , Y m' O, . E, C ~, ~ : ~, ~~ N - , ' O w, V _O .C ~ a ~ O ~ ~ ~ 'O: Of a~ D '^' a N a c °, •Q N ~ - N N c m ,t a. ~, ~ R. a •X. ~ ~: ~ a> a' Z : O 7• O• ~~ : a ~ ~ . ~ . O' -~ >~ O. O, ~ 01 ~ O, O• f6• Q• N• ' X 3 ~ ~ ~ m ~ ~ p Vb Q, N, Z ~- N, t/D fM Nl~ N, N, N, N, } } ~ ~ f/1' tlh N~ N, N, N, } } } VA N~ N, N, N~ N, N N N~ N, N~ N, N, N, Q, Q, Q, Q, Q, t/} UA O, N, N, N~ Q, N, y~ Q, N, f/1: y, N~ N, N, N, N, O, N, ~ N: N, Q, Q, Q, ` _ , , , , , , , , , ~, } r } } } } z z, Z, Z Z Z ~, >-, Z ~, z ~, ~, } } ~, z ~-, >-, ~, Z Z Z w , , o ° ~ V ~ ~ ~ N. G O' ~ N x ~ a N ~ j ~ ~ ~ ~ ~ ~ N ~, t .O.S ~ ~ ~ ~ ~ ~ ~ G O. ~ ~ ~ i d' m. a~; ~; ~ .o 3. o, ~ Z, D ~° m Y ~ o. Z, ~ , T1' N' M' Q' ~ O• ~~ m. fA O, ~ ~ ~ ~ N. W ~ ~ N~ ~ ~ ~ ~ N. p. O, N~ ~ ~ ~ a s' 'a' D N : W Op `~i: •C O. ~ 3 ~, N, ~ M. U. N N: O: C O, N O. ~ 3 ~, a: N. y ~ ~ t, ~ ~, ~ ; , ~ ~, 3, ~ o ~ ~, ~ ~ ~ ~ ar ~ .~ o, ~ _ Q ~, w ~ ~ Y U z ~ ~ ~~ o: c. a ~ o~ °~ ~ •~, a m, a~, o< ~ ~ ~~ o: c. o~ m ~ o: o: rn d' ~ ~~ s. ~ c °~ c. ~, a .. Q ~ ~, . = v '' c ~ Q' o H o - V' i ~ ~~ °' ~ Y ~ ~'~ Q. i ~ ~ ~ O. 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' 0 o ~ ~ ' ' , ' ~ E o W o (n d a N N, N, a' c' 'v v 'm~ y a' 6 3. 3 ~ ~ ~, .. o: a, ~: 'v. ~ f0 N o' °, ~ ~ U o' un a 'a N ~, ~, 0 f6 d N 3 o t Z' ~ U -~ a, ° , , m~ ~ ~~ d o, 4 ~, ~ o m ~, a c' a m o o c' ~ o o N' a' ~' ~ , °' ~' _ °> o aai' °: ~' ~ ~ '3 u i °3 Z v, o, E, m' o: o. o> m' ~ q w, y, ~p «_~ ~ •~, w, of n: ca io m' ~ oS °~ ~ N' ~ ~~ o v , c~u ~~ c ~~ O: ~~ o ~~ v d ~_ ~, ~, ~, o. c. ~: N, x m. m. ° m 3. c, rn ~ c ar or ~ ~ ,~ N ~ ° ~ a~ m ° z ~ ~ :. ii U f0' o ~, m. ~, °? °3 c' m v' o m' c c c, a' o ~ u ~ ~ 'ar m ~o ~° ~ m' $ N , 3, m ~ o, N G v' o ~ m, c m c c a~ c, o E m ~ ~ Z ~~ c 3. ~, ~~ ~~ ~~ ~~ o . o ~~ ~. E ~~ ~, ~, ~~ o c~, f6. f0 ~ _ ~~ a;, , - =~ ~, v ~~ ~~ a a ~, _, c. ~. ~~ ~~ ° ~, c _ ,.~ ~ O • a~ °~~ -° ~ ~ ° a~ ° m ~ ~ o o, o, o a ~ ~ ~, ~ 3 o ~, , ~, a ~ ui ~ w w 3 N ~: Q ~, ~: ~ m ^/ i Y € , f6 , ~~ ~ ~ v. ~ ~ ~ ~ ~, . ~, a ~, 3, ~, o o ~ ~' c. ~ ~, a~ c, ' ' ~ . ' O O ° t, ' ' ~, `0 ~ _'•. ~, a~ a i a J °~ °~ ~ ~' ~' ~; 4 ~ ~; O 4 a; O a; ~ v z ~, . ~; , c> , ~ a ' ~ a, - v - o ' t , °= a ° ~ ~' ~'' a~~ m. 'm; a i; o o. p (~ U c , , , , , , , , d; a. , , N, O, O, U. U. ¢ , ¢, " _; ; m, m; U, ; , , , <n, tn, a, U W a '~ _ ~ O N M et ~ CO f~ OD 61 O N M V' to (O 1~ W O O N M V' M O h 00 d) O ~ N _M d' ~_p f~_OD O) -- _____ __ ~ T N N N N N N N N N N M M M M M M M M M M ~ U ~ _- - 0 C " O N d '-' p N d " N N U~ ~/~ W ~ y ~ ~ ~ O N ~~ p N"" I ~ a o ~ ~ c .~ ~ ~ ~ ~ -- J N Vl N ~ ~ t ~ ~ Q o E a ~ ~ a ~ ~ c a O U W ~ a s a m w a ~ ~ aai i Well History File APPENDIX Information of detailed nature that is not C~ 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 simplrfy 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 118L2O03122007SSN.txt Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon May 21 08:36:31 2007 Reel Header Service name .............LISTPE Date . ...................07/05/21 Ori 9in ...................STs Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date . ...................07/05/21 origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing scientific Technical services Library. scientific Technical services Physical EOF Comment Record TAPE HEADER west sak MWD/MAD LOGS WELL NAME: 1J-118 L2 API NUMBER: 500292333761 OPERATOR: ConocoPhillips Alaska, Inc LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 21-MAY-07 JOB DATA MWD RUN 2 MWD RUN 10 MWD RUN 11 JOB NUMBER: W-0004884845 w-0004884845 W-0004884845 LOGGING ENGINEER: R. REPLOGLE R. REPLOGLE R. REPLOGLE OPERATOR WITNESS: D. GLADDEN D. GLADDEN D. GLADDEN MWD RUN 12 JOB NUMBER: W-0004884845 LOGGING ENGINEER: R. REPLOGLE OPERATOR WITNESS: D. GLADDEN SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: l0E FNL: FSL: 1914 FEL: 2366 FWL: Page 1 c~CXo ' l ~ '~ ~ b~ I ~~~ ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1J 118L200312200755N.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 7206.0 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 7206' MD/3606'TVD, WITHIN THE RUN 2 INTERVAL OF THE 1]-118 PBl WELLBORE. THE WHIPSTOCK WAS POSITIONED, THE WINDOW WAS MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING MWD RUN 10. ONLY SROP DATA ARE PRESENTED FOR THIS RUN. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,11,12 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD). MWD RUNS 11,12 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 1,2,10-12 REPRESENT WELL 1J-118 L2 WITH API#: 50-029-23337-61. THIS WELL REACHED A TOTAL DEPTH (TD) OF 14822'MD/3742'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). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. Page 2 • 17118L200312200755N.txt File Header Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/21 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 RPS RPM FET 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 14764.0 14771.0 14771.0 14771.0 14771.0 14771.0 14822.0 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 10 7206.5 11 7248.0 12 12217.0 REMARKS: MERGED MAIN PASS. MERGE BASE 7206.0 7248.0 12217.0 14822.0 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 DEPT FT 4 1 68 0 RPD MWD OHMM 4 1 68 4 RPM MWD OHMM 4 1 68 8 RPS MWD OHMM 4 1 68 12 RPX MWD OHMM 4 1 68 16 Page 3 channel 2 4 5 • • 17118L2o0312 2007SSN.tx t 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 14822 9070 23009 3318 14822 RPD MWD OHMM 1.98 2000 40.6639 22863 3340 14771 RPM MWD OHMM 3.34 1107.46 37.4898 22863 3340 14771 RPS MWD OHMM 1.08 204.86 38.3605 22863 3340 14771 RPX MWD OHMM 0.98 567.78 40.8369 22863 3340 14771 FET MWD HOUR 0.17 577.23 1.12601 22863 3340 14771 GR MwD API 20.82 156.11 69.2309 22893 3318 14764 ROP MWD FT/H 0.23 509.72 202.409 22912 3366.5 14822 First Reading For Entire File..........3318 Last Reading For Entire File...........14822 File Trailer service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/21 Maximum Physical Record..65535 File Ty e ................LO Next F~~e Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/21 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 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 7206.0 RPM 3340.0 7206.0 RPD 3340.0 7206.0 RPx 3340.0 7206.0 FET 3340.0 7206.0 RPS 3340.0 7206.0 ROP 3366.5 7206.0 Page 4 17118L200312200755N.txt LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 14-FEB-07 Insite 74.11 Memory 7206.0 3365.0 7206.0 64.1 89.5 TOOL NUMBER 124724 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 (S): 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 RPD MWD020 OHMM 4 1 68 4 2 Page 5 17118L200312 2007SSN.txt 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 7206 5262 7777 3318 7206 RPD MwD020 OHMM 1.98 2000 19.584 7733 3340 7206 RPM MwD020 OHMM 3.34 1107.46 11.918 7733 3340 7206 RPS MWD020 OHMM 1.08 55.21 11.6532 7733 3340 7206 RPX MWD020 OHMM 0.99 50.17 11.1818 7733 3340 7206 FET MwD020 HOUR 0.17 62.12 1.04081 7733 3340 7206 GR MwD020 API 20.82 156.11 68.5059 7777 3318 7206 ROP MWD020 FT/H 9.09 417.03 208.992 7680 3366.5 7206 First Reading For Entire File..........3318 Last Reading For Entire File...........7206 File Trailer Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/21 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.......07/05/21 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: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 7206.5 7248.0 LOG HEADER DATA DATE LOGGED: 08-MAR-07 SOFTWARE Page 6 a • 17118L2o03122007SSN.txt SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 7248.0 TOP LOG INTERVAL (FT): 7206.0 BOTTOM LOG INTERVAL (FT): 7248.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 79.6 MAXIMUM ANGLE: 79.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE 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: TOOL NUMBER 6.750 7206.0 Mineral Oil Base 8.40 57.0 .0 66000 12.4 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 .000 .0 .000 58.0 .000 .0 .000 .0 Name service order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD100 FT/H 4 1 68 4 2 First Last Name service unit Min Max Mean Nsam Reading Reading Page 7 • • 17118L2o03122007S5N.txt DEPT FT 7206.5 7248 7227.25 84 7206.5 7248 ROP MWD100 FT/H 0.23 50.14 12.679 84 7206.5 7248 First Reading For Entire File..........7206.5 Last Reading For Entire File...........7248 File Trailer Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/21 Maximum Physical Record..65535 File Ty e ................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.......07/05/21 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: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 7193.5 12166.0 RPX 7193.5 12166.0 RPD 7193.5 12166.0 RPS 7193.5 12166.0 RPM 7193.5 12166.0 GR 7206.5 12159.0 ROP 7248.5 12217.0 LOG HEADER DATA DATE LOGGED: 12-MAR-07 SOFTWARE SURFACE SOFTWARE VERSION: insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12217.0 TOP LOG INTERVAL (FT): 7248.0 BOTTOM LOG INTERVAL (FT): 12217.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 82.0 MAXIMUM ANGLE: 92.6 Page 8 17118L2o03122007SSN.txt TOOL STRING (TOP TO 80TTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 153879 EWR4 Electromag Resis. 4 48783 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 7206.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.50 MUD VISCOSITY (S): 63.0 MUD PH: .O MUD CHLORIDES (PPM): 21500 FLUID LOSS (C3): 21.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 111.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O 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 o ffset Channel DEPT FT 4 1 68 0 1 RPD MWD110 OHMM 4 1 68 4 2 RPM MWD110 OHMM 4 1 68 8 3 RPS MWD110 OHMM 4 1 68 12 4 RPX MwD110 OHMM 4 1 68 16 5 FET MWD110 HOUR 4 1 68 20 6 GR MWD110 API 4 1 68 24 7 ROP MWD110 FT/H 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 7193.5 12217 9 705.25 10048 7193.5 12217 RPD MWD110 OHMM 1.01 2000 52.461 9946 7193.5 12166 RPM Mwo110 OHMM 2.81 2000 5 1.6865 9946 7193.5 12166 Page 9 17118L2o03122007SSN.txt RPS MWD110 OHMM 3.3 2000 52.8527 9946 7193.5 12166 RPX MWD110 OHMM 2.02 2000 54.3274 9946 7193.5 12166 FET MwD110 HOUR 0.17 577.55 2.53901 9946 7193.5 12166 GR MWD110 API 44.36 112.08 70.4175 9906 7206.5 12159 ROP MWD110 FT/H 1.13 412.63 205.208 9938 7248.5 12217 First Reading For Entire File..........7193.5 Last Reading For Entire File...........12217 File Trailer Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/21 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.......07/05/21 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: 12 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12159.5 14764.0 RPx 12166.5 14771.0 RPD 12166.5 14771.0 RPM 12166.5 14771.0 FET 12166.5 14771.0 RPS 12166.5 14771.0 ROP 12217.5 14822.0 LOG HEADER DATA DATE LOGGED: 12-MAR-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 14822.0 TOP LOG INTERVAL (FT): 12217.0 BOTTOM LOG INTERVAL (FT): 14822.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG Page 10 • 17118L200312200755N.txt MINIMUM ANGLE: 86.7 MAXIMUM ANGLE: 92.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 119578 EWR4 Electromag Resis. 4 156404 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 7206.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LO55 (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 MWD120 RPM MWD120 RPS MWD120 RPX MWD120 FET MWD120 GR MWD120 ROP MWD120 Name Service Unit Mineral oil Base 8.40 65.0 .0 25000 27.8 .000 .0 .000 111.4 .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 Min Max Mean Nsam Reading Reading Page 11 • i 17118L2o031220075SN.txt DEPT FT 12159.5 14822 13490.8 5326 12159.5 14822 RPD MWD120 OHMM 4.09 516.37 55.1501 5210 12166.5 14771 RPM MWD120 OHMM 6.04 568.14 52.8466 5210 12166.5 14771 RPS MWD120 OHMM 2.07 203.14 53.4283 5210 12166.5 14771 RPX MWD120 OHMM 0.98 567.78 62.0118 5210 12166.5 14771 FET MWD120 HOUR 0.19 33.07 1.43031 5210 12166.5 14771 GR MWD120 API 44.67 93.48 68.0572 5210 12159.5 14764 RoP MwD120 FT/H 0.82 509.72 190.426 5210 12217.5 14822 First Reading For Entire File..........12159.5 Last Reading For Entire File...........14822 File Trailer Service name... .......STSL2B.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/05/21 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................07/05/21 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Reel Trailer Service name .............LISTPE Date . ...................07/05/21 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................5T5 LI5 Writing Physical EOF Physical EOF End Of LIS File Library. scientific Technical services Library. scientific Technical services Page 12
