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Home My WebLink About205-028STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other. RPPG MBE TREATMENTD 2. Operator Name: ConocoPhillips Alaska, Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Development ❑ Exploratory ❑ Stratigraphic❑ Service 0 205-028 3. Address: P. 0. BOX 100360, Anchorage, 6. API Number: Alaska 99510 50-029-23251-61-00 7. Property Designation (Lease Number): e. Well Name and Number: ADL 25651, ADL 25660 KRU 1 E -117L2 9. Logs (List logs and submit electronic and pnnted data per 20AAC25.071): 10. Field/Pool(s): N/A Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 15,661 feet Plugs measured None feet true vertical 3,208 feet Junk measured None feet Effective Depth measured 15,661 feet Packer measured 10382, 9647 feet true vertical 3,208 feet true vertical 3486, 3392 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 feet 20 108' MD 108' TVD SURFACE 5,514 feet 133/8" 5,544'MD 2364'TVD RECEIVED 9,365 feet 9 5/8 " 9,391' MD 3509' TVD R D -SAND LINER 6,179 feet 5 1/2 " 15,661' MD 3208' TVD n OC 1p 1 7 2019 Perforation depth: Measured depth: 9580-15517 feet True Vertical depth: 3355-3209 feet �0�� Tubing (size, grade, measured and true vertical depth) 4,5 " L-80 9,348' MD 3,330' TVD Packers and SSSV (type, measured and true vertical depth) PACKER - HRD ZXP LINER TOP PKR 10,382' MD 3,486' TVD PACKER - ZXP LINER TOP PKR 9,647' MD 3,392' TVD SSSV - N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water-Bbi Casing Pressure Tubing Pressure Prior to well operation: SHUT-IN - _ _ -- Subsequent to operation: - - 511 - 557 14. Attachments(mquired per 20 AAC 25.070,25.071,825.283) 15. Well Class after work: Daily Report of Well Operations El Exploratory ❑ Development ❑ Service El Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG 71 GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-108 Contact Name: John Peirce Authorized Name: John Peirce Contact Authorized Title: Sr. Wells Engineer Email: John.W.Peirce@cop.com Authorized Signature: '41r9 Date: Le> (p /1 Contact Phone: (907) 265-6471 Form 10-404"Revised 4/2017 r (r%2.{�/y/Z n 4 '(111 RBDMS ��' OCT 2 12019 Submit Original Only 1E -117L2 RPPG MBE TREATMENT DTTM JOBTYP SUMMARYOPS START 4/20/19 MISC. RIH W/ DRIFT FREEZE PROTECT WELL W / 38 BBLS OF DIESEL RAN CAPACITY DRIFT TO 9529' JETTED TUBING AT SETTING DEPTH POOH. RBIH AND SUSTAINMENT SET ME BRIDGE PLUG AT 9496' POOH RDMO 4/20/19 PUMPING FREEZE PRTOECT TRACKING 65 BBLS DSL DOWN TUBING ONLY 2 BBLS METH DOWN FLOW LINE JOB COMPLETE 4/26/19 MISC. DRIFT TUBING COULD NOT FALL PAST 2220RKB DUE TO DEVIATION. CAPACITY SBHP JOB ABORTED, READY FOR SRIT. SUSTAINMENT 5/1/19 MISC. CONDUCT STEP RATE INJETION TEST CAPACITY SUSTAINMENT PUMP 10 BBLS SEAWATER AT 1 BPM PUMP 10 BBS SEAWATER AT 2 BPM PUMP 30 BBLS SEAWATER AT 3 BPM PUMP 200 BBLS SEAWATER AT 4 BPM PUMP 63 BBLS DIESEL FOR TUBING FREEZE PROTECT JOB COMPLETE 9/27/19 MISC. PUMPED FULLBORE RPPG TO TARGET D -SAND MBE, ESTIMATED CAPACITY TOE OF 1E-1171-2. PUMPED 599 -BBL TREATMENT INCLUDING 50 -BBL SUSTAINMENT 2% KCI PRE -FLUSH, FOLLOWED BY 333 -BBL SLURRY CONTAINING KCI PLUS 7040 -LB RPPG PRODUCT. DISPLACED SLURRY TO MBE WITH 154 -BBL KCI AND 62 -BBL DIESEL FP. GAINED APPROXIMATELY 700 - PSI NET PRESSURE DURING TREATMENT PUMPING 2.7-3.6 BPM, FINAL PUMP PRESSURE 1111 -PSI. NOTE: SUPPORTED PRODUCER 1J-168 WAS DIVERTED FROM FACILITY TO FLOWBACK TANK AT 12:35PM AT THE SAME TIME PUMPING TREATMENT INTO 1 E-117 STARTED. 1J-168 SI @ 15;40 WITH 129 -BBL FLOWBACK. KUP INJ WELLNAME 1E-117 WELLBORE 1E-117 ConocoPPhfllips tri !' ell Attributes Max Angie S MD TD Fieltl Nema Wer'._s'noI wellWnsAms Icll2l MD(nKBI pcl3lm (XKR) ` AI85Vld, SDC. IWFAT fiAK cn vavnnn o.. .. ._ IS 117. 1W1eaX82A. PM Last Tag votes rami mass) Annotation I Depth RUSSI I End Data .muI ren Last MW By .............................._........................................ HANGER; Al N\ -CONDUCTOR: 30.a1D0o NiaPLeso6.o ( SAS uRr; t ens SORPacB: as.9sst3.a sLEEVEG:93a.T mceTOR:5.3Rs SEAL: 5.33nz a6PHp LINER HH; 9,396,0. ssze3 X saxD LINER HH a/o6.B a. sari%o LINER LeM; 9,6as 1D,aze.e PRopwnoN:M6 IOMO SLOTS. 10,5]p0.f0,W70 1091 0-11.se D� L0,910.0 W4.D�jts 1 amts 1aID LO-14XSX� amts laeev.als,mzD- SLOTS; 1pA5a15%5.0 St so an X 1 .SO LINER', He X , ,751.] last Tag: 1E-11] ImosbOr Last Rev Reason Annam%on End Dnh wanes Lnst Moe ey Rev Reason: COIL CLEANOUT -SEE NOTES 72W016 1E-11] Pgroven 'Casing SVings Ca5in9 Description Do (in) In lint Top PUDD fiat DeplM1 1%KBI 6e[pepm lNDl... WtlLen 11... Gentle Top TM1reatl CONDUCTOR 20 19.12 30.0 108.0 108.0 94.00 KS5 WELDED casing Description Do (in) to (in) To Se[DapN (XKRI $el Death (TVpJ... WIILen (L.. Gmde Tap Threat SURFACE SURFACE 13318 1241 29.9 5,543.6 2,364.4 68.00 L-80 BTC C -Ing DesaripHon OD nnl 10 Sip Top(XKin Set Depth MB) set Depth TVD1... Wien p.-Gual Top Thad PRODUCTION 9518 8.83 26.3 10,5]20 3,509.5 40.00 L-80 BTCM caam9 DmrnlXmn DD (in) m (in) Tap Ig8e1 sat Depth IXBeI set pegn (rvol... wien (... Gmae mp Threae D -SAND LINER HH 5112 4.95 9,386.0 9,528.3 3,370.5 15.50 L$0 BTCM Liner Details Nominal ID Top plain Top (ND)IgKB) Top Incl l°) Ihm Des Com (in) 9,386.0 3,341.3 70.11 HANGER BAKER B-1 HOOK HANGER 4.950 9,413.3 3,347.0 ]808 XO BUSHING 4950 9,455.9 3,3558 ]8.16 ECP Baker Payzone External Packer 4.950 Cuing DescrlPllon OD(Inl ID pn) Top(XKB) BNDepthoma) Set Depth (rvD1... wgLan ll_. Gentle BSAND LINER HH 51/2 4.95 9,]06.6 9,8404 13,4192 1550 L-80 Top ihre9tl BTCM Liner Details Top MB) Top(Np)(flKBj Top lncq°) Hem Dea om Namine110 no) 9,]06.6 3,401.0 8149 HANGER BAKER B-1 LEM Hook Hanger]x9,625 5500 9,734.0 3,4049 81.76 XO BUSHING 4.950 9,7562 3,408.1 L.99 ECP TAKER PAYZONE External Casing Packer 4950 C7s1n90ucr1gion ODllnl ID llnl Top (NIB) set 0apth (XKRI sN DepM (Np)... waren (L.. Grade Top ThrW A -SAND LINER 512 4.95 10,382.2 15,751) 34153 15.50 L -0o BTCM Liner Details Top(%K31 TopINDI (XKaI Top Incl l°) Item pea Nominal lD Com (in) ,2 10,3822 3,486.2 83.11 PACKER ARD ZXP LINER TOP PACKER 7.000 10,400.8 30488.5 82.81 NIPPLE 0.S PACKOFF NIPPLE 4.g50 10,403.7 3,488.9 82.77 HANGER FLEX LOCK LINERHANGER ].000 10,415.3 3,4904 82.59 SBE 19647 SEAL BOREEXT -KB) 4.750 Oaring Describe ODin) ID(In) T Set Ce PUHMKIR Set pepM (Nin... Doi 11...Gw. BSAND LINER LEM 4112 396 9,64].5 10,429.9 3,4923 12.60 L-80 Top Thmed IBTM Liner Details I TORMOHIRS) TopinciE) (him Des eom Naming ID (in) 3 5 3,391.8 80.68 PACKER ZXP LINER TOP PACKER wIHRD profile 7.500 67.1 3,3949 80.95 SBR 19047 SEAL BORE RECEPTACLE 4.750 6.5 3,397.9 81.21 XOBUSHING CROSSOVER BUSHING 3940 80 3,398.2 8123 WIVEL 3.960 43 3,399.1 8132 HANGERI LEM Above Hook Hanger 3.980 NTub[na 67 3,401.0 81.49 HANGER LEM Inside Hook Hanger 3688 9.8 3,408.6 8202 NIPPLE CAMCO DB NIPPLE 3.563 6.6 3,491.8 82.41 SEAL BAKER SEALASSEMBLY 3870 tringsmemn Bering Ma...mon) Too lHKn)setapeh(X.relDepPTr )(..Vlt9W%) Dmae Toonneanon 412 3.96 2D.1 9,3426 3,333.5 12.fi0 L-80 IBTM Completion Details Top TrvD) ropmd xominm TOP ItMSI IRKS) (°I nem Des com Iron) 20.1 20.1 0.00 HANGER MB -2 TUBING HANGER 4500 506.0 505.5 7.18 NIPPLE CAMCO USNIPPLE 3.875 9,247.] 3,312.6 A.68 SLEEVE -C BAKER CMU SLIDING SLEEVE CLOSED 1012812005 3.812 9,3295 3,329) ]8.12 LOCATOR BAKER LOCATOR 3938 9,3302 3,329.9 78.12 SEAL BAKER SEAL ASSEMBLY 3.875 Perforations & Slots Top(RKBI Btmm.) Toofloh(TVID) ketl2on¢ Dah shot Deas ah'KMTYpe Com 105700 10,697.0 3509.3 A2, 7 ]/102005 1200 SLOTS IanNslonedSLOTS: jis 11545.0 3,511.9 2, 1E-117 #WS )I1 U2 5 20 SLOTS matingbhe alone11,0]80.18 118]9.0 128740 ),518.6 , tE-117 ]/102005 120.0 SLOTS ]AIternating nating blanklslDnejamts;taossala,T3aa� 13,055.0 13,734.0 3,483.2 , 1E-11] ]11012005 120.0 SLOTS nating blank/slowed jts 14,202.0 14,3690 3,4823 3,4]2.] WSA,1E-11] ]11012005 120.0 SLOTS Alternating"an'a onetl IH.TJIS 14,887.0 15,092.0 3,439.5 3,432.7 WS A2; 1E-117 7/102005 1 120.0 SLOTS Alternating blark(slonen inerts 15,265.0 15,685.0 3028.9 1 3,415.8 WS A2, 1E -it] ]11872005 120.0 SLOTS Altematingbank/sloned linerjts Mandrel Inserts room.) Toplrvpl (qKB) Make MWeI Op gn) Sery Valve Type La1cM1 Type PodS nnl TRORun Spon Serious t Com 1,8]5.5 1,SOOfi CAMCO KBU-2 I 'MY BK 0.000 0.0 1202006 600 KUP INJ WELLNAME 1E-117 WELLBORE 1E-117 CanocoPhillips`^'' Alaska, Im. 1 E::] 1`111,1¢ ESS 9SXW Pm 'Notes: General & Safety vvtinlcnematic txM9 Ena oma AnnoNFn ............................_..._................ ............_.......................... .8/1 312005 NOTE:MULTI-LATER AL WELL: t E-111(A-SAND(,1E-11]L1(B-SAND), 1E-11]L2(DSAND) HANGER: X.1 12/2812010 NOTE: VIEW SCHEMATIC W/Alaska Schema0c8.0 .N� CONDUCTOR; 30.61080 NIPPLE: EMO WSLIFT; I,B]55 SURFACE; WS -5.5438 SLEEV C; 9,,3<].] LOCATOR; I..5 SEAL '3M �j Q3 D LINER HH; e,3SB6 9,5X.3 BS DUNER HH; 8.1066 9BW.9 a8 D LINER LEM; 960].5 1.429. PROOUCTION', 2&910,5]$.0 1 SLOTS', IO,ETSMO,W]O- SLOTS;I0,G10611.O S L SLOT5;11A790.12W4.0�� SLOTS; 13.06&013,7340 SLOTS: 14,2I2OUMRS SLOTS; I4,X7 O1&W20� I SLOTS, I$X&O1&895,0 I� XSANOUNER;10,3022- t 15.]51 CmmoPhillips NasM, lnc- KUP INJ WELLNAME 1E-117 WELLBORE 1E -117L2 1E-117121W6Sm9Z. '07PM Last Tag ___ _ ..'c .—. (xpwp Annara5an Depth(XKBI End Oeb Wellbore lnsl Metl By WS ........................................................................................I.. Last TaA: tE-11 Imosbor Last Rev Reason Amtdion End DaW WoIIRev Reason: ADD FORMATION ZONES 10!23!2013 1E1 D12 ooped Casing Strings Casing Description SO(in) ID tlnl Top InKio Set OepM F;r Set DeplM1tND)WGten (LGrade TopTMead 7:1 D -SAND LINER 5112 4.95 94215,661. 15.50 L -BO BTCMLiner Details CONODCT Top mSe 1 TopLrvD)tnRa) iop lnm t•1 nem Des Com Nomin31 IS pn) 9,402.1 3,3554 85.69 JILILIVI JBAKILH HR SETTING SLEEVE6.151 NIPPLE:sm.o 9,535) 3,35]0 9091 XO WILL ng CROSSOVER]'x55' 5.51)0 Perforations & Slots G48 LIFT: 1.015.5 Sno, Den, Top nwo) I a" M, p000tsm TOPMB) BtmmR9) MKB) (nKB) Unke To Dah ) Type Com 9,580.0 9,9630 3,354.8 3,331.5 WS D. IE- 802005 400 SLOTS Alternating blanweJoudd 117U pipe 10,261.0 10,646.0 3,3227 3,313.9 WS D, 1E- 002005 40.0 SLUTS Alternating blandslotted 1172 pipe 10,772.0 10,938.0 3,3122 3,309.5 INS q1E- 80/2005 400 SLOTS Altemating blaWooned SURFACE; A.90.S 117U Pipe 11,0220 11,229.0 3,3072 3,3013 WS 0,1 - 8/72005 40.0 SLOTS Alternating blandalime SLEEVE C; 9,2477 11712 pipe 11,314.0 11,483.0 3,299.3 3,2955 NSD, 1E- &]2005 40.0 SLOTS Altemating blandslone 1172 pipe 11,7820 11,953.0 3,2882 3,285.6 WS 1 - WI2005 40.0 SLOTS owmaung eandelotted LOCAttIR19.3A.5 117&2 Pipe sBP1; 9.39Dz 12,03].0 12,246.0 3,284.8 3,281.2 WS" - 802005 40.0 SLOTS Altemating blends one 117L2 pipe RBODOCTION: 2SST0 RZO 12499.0 12,]090 3,278.4 3,275.8 W - 09/2005 40.0 SLOTS Alternating blan slobed O.SNm LINEK HH', 9,saso. F. 11712 pipe %Sx3 12,794.0 12,962.0 3,274.3 3,271.1 WS D. 1E- 802005 400 SLOTB Atermem, bled slotted 1172 pipe 13,261.0 13,4730 3,265.7 3,260.6 WITIT,1E- 80/2005 40.0 SLOTS Alternating blandsloned 117U pipe 13,5580 13,727.0 3,258.0 $252.9 WS D, 1E- 802005 40.0 SLOTS Altemating blar Veloned 172 pipe 14,0200 14,482.0 3244.6 3,2322 WS D, - 602005 40.0 SLOTS AlternatmAblandslone 17U pipe 14,]820 15,5120 3,224.4 3,208.] WS D,1 - 8012005 400 BLOTS Altemating blandslone sl.ora; esm.oe.9w.o— 117L2 pipe Notes: General & Safety SLOTS', f0,2a10_IS.o �Ena Date Annefaeon 8/1372005 NOTE:MULTI-LATERALWELL;1E-11](A-SAND),1E-117L1(B-SAND),1E-1172(D-SAND) 10152019 NOTE:927/19- FUllbom RPPG job pumped 70401bsof RPPGtoD MBE, 10162019 NOTE: VIEWS HEMATICw/Alaska SDSmaliD100 sLOTs:lnmo-l6eaen� SLOTS: t 1.022."1+, MS ------� sLDTs ++.9+a o4 um.D— KOTs; 11,Ta20.11,9530� 1 SLOTS; 1207r"12.24aO� SLOT0: 12.4tN 612,]16.0 3LOT3', 12.]84.613 A$.0------ SLOT5;13,A1O13.47313 SLOTS, I3SMI"13TPo SLOTS; 14025.614AZO2 SLOTs:la,Ma 15,5170 D -SP m LINER; 9.192.1 6 Io. o THE STATE Alaska Oil and Gas OIALASKA Conservation Commission GOVERNOR MIKE DUNLEAVY John Peirce Sr. Wells Engineer ConocoPhillips Alaska, Inc. P.O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, KRU IE -117L2 Permit to Drill Number: 205-028 Sundry Number: 319-108 Dear Mr. Peirce: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.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, Daniel T. eamount, Jr. Commissioner / B DATED this 7 day of March, 2019. OMS `Y / MPR % I I" 48 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS MAR 0 5 20ig 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operationsshutdo"El Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program[] Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: RPPG MBE ' 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: COnocoPhilli s Alaska Inc. Exploratory ❑ Development ❑ Stratigraphic ❑ Service 205-02$ 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23251-61-00 - 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 0 KRU 1E -117L2 9. Property Designation (Lease Number): 10. Field/Pool(s): f(nl zs�i f ADL 25660 Kuparuk River Field / West Sak Oil Pool ' 11. 3- & /'y PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 15,661' 3,208' 15661 3208 1450psi NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 78' 20" 108' 108' Surface 5,514' 133/8 5,544' 2,364' Production 9,365' 9 5/8 10,572' 3,509' Liner 5,370' S 1/2 15,661' 3,208' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9580 -15517 3355.3209 4.500" L-80 9,347' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): PACKER - HRD ZXP Liner Top Packer 10,382 MD and 3486 TVD PACKER - ZXP Liner Top Packer 9,647 MD and 3392 TVD SSSV - NONE 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stretigraphic❑ Development El Service [a ' 14. Estimated Date for 3/20/2019 15. Well Status after proposed work: Commencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG O • 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: John Peirce John Peirce Contact Name: Authorized Title: Sr. Wells Engineer Contact Email: John.W.Peirce@cop.com Contact Phone: (907) 265.6471 A,v' / /dC� Authorized Signature: /!O �Aw. ` .z - Date: (1 I COMMISSION USE ONLY Conditions of approval: Notify Commission an 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 f—� Spacing Exception Required? Yes ❑ No Ld/ Subsequent Form Required: APPROVEDBY3>007 / s� Approved by COMMISSIONER THE COMMISSION Date: ( l!/ 7 f ?� VT1. 1/Fq RBDMSI� MAR 0 71019 Submit Form and Form 10003 devised 4/201] Approved aPPII R A the date of approval. Attachmen in Duplicate ConocoPhillips Alaska, Inc. KUP INJ SAN NIPPLE WELLNAME 1E-117 WELLBORE 1E-117 lle417, 33'L++9]215 M1 Last Tag WNal wh-na lxEnq Annotation flUthall(e) End D. waspore Lal Mad By .Ye GEp. in t CONOVCiOR: 20611000 NIPPLE, 5060 un:+s GAs .an SURFACE a9.B5s1s6 sLEEVE{: 6,i4LT LOCATOR, 9,3i&5 bFAl epa02 DuxD urvEB wI: a.Sw.o- ¢5ze.a Issnxo un6a RN'. 9.JM& e.6ab.4 BSANO UNER LEM: 9,647& +O,4Ra pROCVCTtgV: 26.y+a.5'20 awrsl+a.Sro.DtG.BB70 �� Sims: m,a+guttSrsD- SLOTS, 1I.M.o-+2e SmTA Isles D+3.714 O- SLOTS.I.Lno.0+4.a9.0- ..is148RO-IS.- I SIAT6: 15.iCa.615,5.5A� L A41AND LINER +0a92'1- 1$151.] Last Tag' 1E-111 lani Last Rev Reason MnEnd Da* wxlLmo Lal Mod ey Rev Reason COIL CLEANOUT-SEENOTES 2)20)2016 1E4V pprgven Casing Strings ceemv Deacdpron and IO (in) roP MK8) Sat Depin MER Sin Retain Trial... WBLen ll.-Gnae TopTMcaa CONDUCTOR 20 19.12 30.0 108.0 1080 9400 K-55 WELDED cei, b-ijin" 006X) 109X1 T. 11X(8) Sed0eptn fnNel bet DijNa)... WBLen O... Geaae Top ThreM SURFACE 13318 12.41 29.9 5.5436 2364.4 6800 L-80 BTC Grin, Oe -",anon 0o (Int 110 IRS Top RIOR BN oepIn Ult) Set onsh nal Wvft.-(I... Grade TOP Threat PRODUCTION 9518 8.83 26.3 10.5720 3,509.5 40.00 LA0 BTCM Lansing 09aorlpai" oD(in) 1D (in)ToPrUIR 50 open WB) and Deal (rival inar n.,, G,Me Too Thread D -SAND LINER HH 5112 4.95 93860 9,5233 3.370.5 15.50 L-80 BTCM Liner Details Nomlrrelm Tap (X1(6) TOP Two) ghLel Tap lrrd l•1 Ihm Ms Com (Int 9,3860 33413 ]6.11 HANGER BAKER B-1HWKHANGER 4.950 9,413.3 334]0 ]806 XO BUSHING 4.950 9..559 )355.8 ]8.18 1c, Baker Payinnes Eatemal Packer 4.950 "an o serlPhon OO (in) 110(a) T PRUI) bat De a ntKla SN a M OV01... WBLen 11... GMe Tnp Thread B -SAND LINER HH 5112 4.95 9,706.6 9,8404 3.4192 15.50 LA0 BTCM Liner Details Top (nxel I Toptrivia HrcKBI Tap mol l'1 Item Des cam manna Ont 9,706.6 3,401.0 8149 HANGER BAKER &1 LEM Hook Hanger 2x9625 5.500 9,134.0 344) 81.]6 %O BASHING 4950 9,156.2 3,408.1 I II ECP BAKER PAYZONE External Casing Packer 4 950 coda, Oesnnpin' OOlinl ID lint Topol aNWetpolicl SDURRVId ItiaLen g... Grade Tap Thread A -SAND LINER 5112 495 10,3822 15.751) 3,415.3 15.50 L-80 BTCM Liner Details iop10,3 TapIND11RKB1 Top I=1 IIrvom1., Ihm Cez Cmm (Int 8311 10,382.2 3,486.2 83.11 PACKER HRD ZXP LINER TOP PACKER 7.000 10,400.8 3,4885 82.81 NIPPLE RS PACKOFF NIPPLE 4,950 10,4033 3,4889 82.)7 HANGER FLEXLOCK LINER HANGER 7.000 10,415.3 3,49 A 82.59 SBE 190-07 SEAL BORE EXT 4750 Caain00amlptian I.I. Tin) Ig (Int Top111KB1 Set Oe�MIt1KB) set D=Mh (NDS ., MLM(I...OrMe Top TnraM B -SAND LINER LEM 412 396 9,64]5 10,429.9 3,492.3 1260 LA0 187M Liner Details Noairul to Top(..) Top RVD)RIKIR Topmmrt Ihm Dea Lam aid 9642.5 3391.8 80.68 PACKER ZXP LINER TOP PACKER wIHRD profile ].500 9,667.1 3,3949 80.95 SBR 19047 SEAL BORE RECEPTACLE 4750 9,686.6 3,3979 8121 XO BUSHING CROSSOVER BUSHING 3.900 9,6880 3,398.2 8123 SWIVEL 3.960 9,694.3 3399.1 8132 HANGER1 LEM Above Hook Hanger 3980 9,2 J 3,4010 8149 HANGER LEM Inside Hook Hanger 3688 .759.8 3,408.6 82.02 NIPPLE CAMCO US NIPPLE 3.563 1..26.6 3.491.8 82.41 SEAL BAKER SEAL ASSEMBLY 3.870 Tubing Strings Tuhme ov 1.,1pnon suing Ma... m 1tn) Top (MR) set Depin In.. set DepthnVD) (-- wl OdXI G/Me Top Connection TUBING 4112 3.96 1201. 9,342.6 3,3335 12.60 L-60 IBTM Completion Details Top(MrvDl Top dna Nominal ioplhKBl )el fl Ihm Des cam ID Ona 201 201 000 HANGER I MB -2 TUBING HI 4.500 5060 505.5 718 NIPPLE CAMCO DB NIPPLE 3875 82477 3,3126 7].66 SLEEVEC BAKER MU SLIDING SLEEVE CLOSED 1012812005 3812 9,3295 33297 78.12 LOCATOR BAKERL AT R 1938 9,33. 3,3299 ]812 SEAL JISAKLH SEALASSEMBLY 3.875 Perforations & Slots Top(rcxbl elm(ItlUR TPoMB) 1 �We)D) Lmkes zone Dints snot Dees (sn;bM TIPS Com 10,5200 10670 3509.3 3,5167 W A,W A2, 1E-117 211& 09 100 BLOTS 6ernaa++9 re"Mood"! linerjls 10,91 0 11,505. 3,511.9 3,510.2 WS A2, 1E-111 ]l1&2005 120.0 SLOTS Alternating biank/slOrced inerjt. 11,829.0 1 , )4. ,5186 3,5042 WE A2, 1E-112 2/102005 120.0 SLOTS Alternating blanUsloaed erjin 13,055.0 13,734.0 ,4 2 ),488.6 WS A$1E-11] ]/1&2005 120.0 SLOTS hanartng blarkslotted linerjls 14.2)20 14,369.0 ],4 3.4727 WE A2,1E-117 )11012005 12OR SLOTS Abernaling Ian sort linerjls 14,8870 15,0920 3,4395 3.4327 WSA2,1E-it] 711012005 1 120.0 SLOTS ARern.a., plan .forted linerjts 15.265.0 15,6850 3,415.8 WSA2, 1E-117 niuvoi05 I 120.0 SLOTS Aremaling anaresiorent liner 115 Mandrel Inserts at N^I Top(KKB) Top (N01 (Me) make Mond �00(lm� So" Valve Type Lata Type Port sire 9n) TRO Run )rand Run 0i COT 1 1,8)5.5 1,500.6 CAMCO KBG-2 1 GAS LIFT DMY BK 0000 00 1202006 6:00 C KUP [NJ WELLNAME 1E-117 WELLBORE 1E-117 ConowPhUlips_ Alaska, Inc. re-1I7L""aSN'; Notes: General & Safety v.rdmvw�.zlc9 ) End Date I Ann.. ............ ............... .........____................. ..........,._._ &132005 NOTE: MULTI -LATERAL WEU: 1E-117(ASAND), 1E-1 171 -1(B -SAND), T -117 (D -SAND) 102UGIO NOTE: VIEW SCHEMATIC w/Alaska Ecbemau HANGER: M I .0 ^^ con'Duci�: mwlce.D NIPPLE',A80 PO&LIFi:18]BB SDRFACE:'A.9fi.S188 SLEEVE: 920.7 LOCATOR', 9.58.5 sEAL 98]0.2 DSM'D LINER HH: 8,3086 9,5ID`3 B -SAND LINER HN: 9,706.6 9.BIOa 684ND LINER LEM, 9.647 S 10, ai89 vRODDcnou: as.3-to.nzo J L SLOTS: msRSO-10Rnu— SLOTS, 10.910 0-1 1.NWS LLL SLOTS: 11.679prz.874 0�� SLDr8: 13 M5 1INK O0 slorS', 142O3.Du.3690� sLors: u.ee7.01s,w9.9—_ SLOT&: 18055615�S.O� MSAND LINER. 10.399.5 19,]511 ConocoPhillips Alaska, blc. KUP INJ SAS NIPPLE WELLNAME 1E•117 WELLBORE 1E -117L2 1E-11712,y9AI.IVIIAM Last Tag VelCal e[anvc(eceol) AnnodNon Depth MKS) End Dea Willson Last MW Sy Last T.g lansaws, Last Rev Reason HUNGER: M1 AnnoWlon End Dale wenWra Ia:i Moa By Rev Reason: ADD FORMATION ZONES IOI232013 1E-11 ]1-2 osbod Casing Strings CUI1q OescnpHon 00 (Int ID 4n1 Top nlKal set Oepm RVIS . wtl4n 11.. LMeae ToprnrtaE n-SANDLINER 5112 495 9J821 15IO 10IaKa) 15,6610 15.50 L-80 BTCM Liner Details No" IID CONDUCTION: SO.a1OLO Top(nKe) -R(nMp)(-a TOp IwIn IRm OH Com (IN 9,462.1 33557 85.69 SLEEVE BAKER HR SETTING SLEEVE 6.151 NIPPLE, RON0 9,535.] 3,35)0 90.91 XO Retleop' CROSSOVER]"x5.5" 5.500 Perforations & Slots Shd GIS LIFE: ya]55 Oen Top(TVD) BW MD) IsIwWK Top (nKB) Ban Oli (KKD) IRWIN) Lmked&ne N. ) Type Com b80.0 9,963.0 3,354.8 3,331.5 —WTD—,7r— 802005 40.0 SLOTS Anernaung anMslobed 1172 pipe 10.261.0 10.6160 3,322.4 3,313. - 802005 40.0 SLOTS wmakng anklslOned 11]1-2 pipe 10,7720 10,938.0 3,312..5 &72005 40.0 SLOTS Alternating blanwalafto SUNFACE.MIML9A3.9 1171-2 pipe 11,0220 11,229.0 3,30. ,03.] - 8012005 400 SLOTS Agemagng bIMPSloned SLEEV.:42a11 1171-2 Pipe 11,314.0 11,483.0 3,299.3 3.295.5 WS D, 1E- &72005 40.0 SLOTS Alwmaung blanklslone0 11712 pipe 11,782.0 11,953.0 3,288.2 3.285.8 WTD, 1 - 602005 Me SLOTS Allemating IT nUslOnad .T. e,3296 11712 Pipe .M.%3302 12,03].0 12,246.0 $284.8 32812 WTD RE - &72005 400 SLOTS A6emating blanWanfled 11]1-2 PIPE PRODUCTION; 263-105@.0 .D LINER H. 9386 61 12,499.0 12,709.0 3,278.4 3.2756 W qt - 1171-2 Bn 5 400 SLOTS AnemauNgblanWslone Pipe 127940 12,962.0 3,274.3 3,271.1 W D,1E- —w—U5— Wo SLOTS AI@mating blanklsloned 11]1-2 pipe 13,261.0 13,473.0 3,2657 3260.6 W D,1E- —8/7000-1— 40.0 SLOTS Alternating blanlsloned 1712 pipe 13,558.0 13,]2]0 3.2580 3,252.9 W ,i - 8012005 400 SLOTS Alfermlingblanklskned 117 2 pipe 14.U57 14,482.0 3244,6 3,232.2 W 8/12005 40.0 SLOTS ternalmg blanWoloned 17L2 Pipe 14,78 .0 15,517.0 3,1244 3,2067 WS D, 1E- 8012005 40.0 BLOTS Alternsfing bleawslonetl sLors, RsroDm.w3o—� 1 11]1-2 pipe Notea: General & Safety slmsa o.Rl alDdaO� t f End Deh An,.n 8/1312005 NOTE: MULTI-IATERAL WELL: IE -117(A -SAND), 1E -1I IL1(BSANO), 1E-117L2(DSAND) 12/292010 NOTE: VIEW SCHEMATIC.,aska o7eni u SLOTS; 14720-10.939.0—� t SLOTS; 11,022611 M0-1 rLr 1 aLOTa; 11,316611.tl9.0 �� SLOTS',I ..D-11,BSSO-- 3LOT5; 12W]612Na0—� r $LOTS; I2W 612]16.0 SURE. 12.781 612. G2 SLOTS; 13MIO—IN4MC0 I�L I SLOTS: 13,5580-13.7270—� 1 SLOTS; 14025.6142920� SLOTS', 14.782619.9110�� DSANOLINER;se ` i-� $891.0 Fullbore 1E-1171-2 to 1J-168 D MBE RPPG Treatment Proposal West Sak 1 E-117 Tri-Lat injector has 4.5", L-80, 12.6# tubing and horizontal A, B, and D laterals containing 5.5", 15.5#, L-80, slotted liners that extend to beyond 15000' RKB. 1E -117L2 D Lat is believed to contain an apparent 'toe' D MBE to 1J-168 D Lat 'heel'. Recent (PROF & PPROF data indicate a D MBE exists from 1E -117L2 toe to 1J -168L2 producer heel. The 1J-1681-2 PPROF of 4/3/18 showed warm fluid strongly flowed into 1J-1681-2 at 6800' RKB (likely from 1E-1171_2 D MBE), and then flowed downward in the D Lat on flowing & SI passes while 1 E-117 was on PWI to all 3 open Lats. This is evidence that an open 'toe' D MBE likely exists from 1E -117L2 'toe' to 1J-1681-2 'heel'. Production and injection data suggest the D MBE likely occurred in early 2016. Note, 1 E-1171_2 injector lateral 'toe' section of liner lies adjacent to the 1J -168L2 producer lateral 'heel' section of liner. 1E-117 D LEM installation is not properly aligned with the D Lat window. This was verified by May 2017 logging that ultrasonically imaged 1 E-1171_2 D LEM area. Thus, 1 E-1171_2 D Lat can't be entered for well work. However, fluid can still be pumped through the partly obstructed D Lat window. This procedure proposes that a Plug be set in main -bore tubing at 9496' RKB between the D & B Lats, to isolate the A & B Lats for a 1E-1 171_2 'D Lat Only' SRIT and RPPG D MBE treatment. After the Plug is set, a Step Rate Inj Test will verify adequate rate of -4 bpm can be pumped through the D LEM at acceptable treating pressures to enable performing a fullbore RPPG placement to the D MBE. Procedure: 1) Coil Tubing: RIH with a Plug and set it in 4.5 tubing at -9496' RKB between the D and B LEM's. 2) Slickline: RIH with gauges to obtain SBHP station stops at 9350' and 8904' RKB. 3) Pump SRIT: Perform SRIT with Seawater at 1, 2, 3, & 4 bpm to 1E -117L2. This will verify if adequate injection rate of -4 bpm can be attained at max WHIP'S below 1500 psi, which is needed to reasonably expect being able to perform a good fullbore RPPG treatment of toe D MBE at 15000' MD. 4) Pump RPPG: If the SRIT results showed good enough injectivity exists through the partly obstructed D LEM to pump a fullbore 1E -117L2 RPPG treatment, then plan to pump the RPPG slurry program proposed below. Otherwise, terminate plans for continued work to attempt D MBE treatment for now. At 12 - 24 hrs before RPPG treatment, put 1 E-1171_2 on PWI at 1000 BPD to warm up and liquid pack well, and to flush as much Diesel and Gas from well as possible to D MBE. Also, attempt simultaneous flow of 1J-168 to tanks at -6 hours just prior to RPPG job to help unload all hydrocarbons from 1E - 117L2 that may contaminate RPPG slurry, and to enhance drawdown on MBE. RU pumping unit at 1E-117. Hold PJSM & PT equipment. Line up warm 2% KCL Brine transport to pump van, then SI 1E-117 PWI and SI 1J-168 production to tanks. Next, immediately begin fullbore pumping -100 bbls Lead 2% KCL Brine at 4 bpm, then RPPG Slurry mixed on -the -fly at 0.50 - 0.75 ppg concentration at 4 bpm until 5000 to 10000 lbs of RPPG slurry enters tubing (total RPPG pumped will depend on observed treating pressure response), followed by -163 bbls 2% KCL Brine displacement at 4 bpm, followed by 63 bbls Diesel FP displacement at 4 bpm, followed by Shutdown. Note, RPPG slurry is intentionally under -displaced such that the lower third of 1E -117L2 lateral is left with RPPG Plug over D toe MBE inside 5.5" liner, since D MBE exists anywhere beyond 13000' RKB. Return 1J-168 to production and 1E-1171_2 to injection to evaluate the results of the D MBE treatment. JWP 3/5/2019 • S Carlisle, Samantha J (DOA) Do7 OS Dag b From: Loepp,Victoria T(DOA) 1 � 1 /7)-5— Sent: ` 7)-5— Sent: Friday,July 22, 2016 1:12 PM To: Carlisle, Samantha J (DOA) Subject: FW:Cancelation of 10-403 Approvals for 1E-117 Crystal Seal MBE Treatment Please handle. From: Peirce, John W [mailto:John.W.Peircec conocophillips.com] Sent: Thursday, June 09, 2016 1:37 PM To: Loepp, Victoria T(DOA) Subject: Re: Cancelation of 10-403 Approvals for 1E-117 Crystal Seal MBE Treatment Hi Victoria, The proposed 1E-117 Crystal Seal MBE treatment recently approved by AOGCC(per 10-403 approvals for: 1E-117, 1E- 117L2, 1J-168,and 1J-168L2) was attempted, but we had unexpected problems getting coil tubing through the D Diverter to enter the D lateral (1E-117L2)to pump the Crystal Seal job. After unsuccessful attempts to enter the D lateral we terminated plans to perform a Crystal Seal treatment and left 1E-117 configured with all 3 laterals open. The recent 1E-117 well events are summarized below. Future work options for 1E-117 will be evaluated. Since no Crystal Seal treatment will be pumped,there will be no Crystal Seal treatment to report on 10-404's. Thus, I request that the following 10-403 approvals be canceled: 1E-117 (316-272) 1E-117L2(316-273) 1J-168 (316-274) 1J-168L2 (316-275) Regards, John Peirce ScONED 2017 Sr Wells Engr CPAI Drilling&Wells (907)-265-6471 office Well Events History 1E-117 : 500292325100 : 6/9/2016 Date Event 05/27/2016 B&C CTU#1: RETRIEVE TYPE 1 ISO SLEEVE ACROSS B LEM AT 9706'. ALL SANDS LEFT IN OPEN POSITION. B&C CTU#1: PERFORM DOWNHOLE VIDEO OF D SAND LATERAL LEM 05/26/2016 AT 9706' WITH MEMORY EV VIDEO AND HES N2, TWO RUNS. VIDEO INDICATES DIVERTER KEY NOT ORIENTING CORRECTLY INTO SLOT ON LEM. IN PROGRESS. 05/24/2016 B&C CTU#1: REMOVE PLUG BODY FROM DB NIPPLE AT 9760' WITH BAKER G-FORCE JARS AND INSTALL TYPE 1 ISO SLEEVE ACROSS B 1 RBDMS \,\/ 3V'.- 2 6 2016 • • LEM AT 9706' WITH BAKER HIPP TRIPPER. WILL RETURN IN THE MORNING TO LOG VIDEO OF D LATERAL LEM. IN PROGRESS. B&C CTU #1: PERFORM WEEKLY BOP TEST ON BACK DECK. RETRIEVE 05/23/2016 TYPE 1 ISO SLEEVE ACROSS B LEM AT 9706' AND P PRONG FROM DB PLUG AT 9760' WITH BAKER G-FORCE JARS. WILL RETURN IN THE MORNING TO REMOVE PLUG BODY FROM DB NIPPLE. IN PROGRESS. B&C CTU#1: ATTEMPT TO GET THROUGH DIVERTER WITH SLIM FCO ASSEMBLY WITH 1.7" DJN AND NOTE METAL MARKS ON BOTTOM OF 05/22/2016 NOZZLE. ONE LAST ATTEMPT WITH LARGER 2.7"NOZZLE UNSUCCESSFUL. REMOVE TYPE 2 DIVERTER IN D LEM AT 9385' WITH BAKER G-FORCE JARS. IN PROGRESS. B&C CTU#1: INSTALL TYPE 2 DIVERTER IN D LEM AT 9385' WITH 05/21/2016 BAKER HIPP TRIPPER. MAKE TWO UNSUCCESSFUL ATTEMPTS TO GET THROUGH DIVERTER WITH DIFFERENT FCO ASSEMBLIES. IN PROGRESS. B&C CTU#1: ATTEMPT FCO OF D LATERAL WITH DJN. UNABLE TO MAKE IT PAST DIVERTER WITH 2 DIFFERENT BHA CONFIGURATIONS. 05/20/2016 REMOVE TYPE 2 DIVERTER IN D LEM AT 9385' WITH BAKER G-FORCE JARS. JET WASH LEM PROFILE WITH HES PULSONICS NOZZLE. WILL RETURN IN THE MORNING TO RESET DIVERTER AND REATTEMPT FCO. IN PROGRESS. B&C CTU #1: INSTALL TYPE 1 ISO SLEEVE ACROSS B LAT AT 9706'AND 05/19/2016 TYPE 2 DIVERTER IN D LEM AT 9385' WITH BAKER HIPP TRIPPER. IN PROGRESS. B&C CTU#1: REMOVE TYPE 2 ISO SLEEVE ACROSS D LEM AT 9365' 05/18/2016 AND TYPE 1 DIVERTER IN B LEM AT 9706" WITH BAKER G-FORCE JARS. IN PROGRESS 2 OF T • • �*c?, THE STATE Alaska Oil and Gas %�M Of T A Conservation C®ini111SS1®n 333 West Seventh Avenue z ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 U • ?` Main: 907.279.1433 ry ALAS Fax: 907.276.7542 www.aogcc.alaska.gov John W. Peirce SCP464. SEP 2 62,016 Sr. Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1E-117L2 Permit to Drill Number: 205-028 Sundry Number: 316-273 Dear Mr. Peirce: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this 60 day of May, 2016. RBDMS t,L' MAY 3 1 2016 RECEWED 0 STATE OF ALASKA • MAY 1 2 2016 • ALASKA OIL AND GAS CONSERVATION COMMISSION 5./45///, • APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon n Plug Perforations fl Fracture Stimulate E Repair Well E Operations Shutdown E Suspend E Perforate g . Other Stimulate f Pull Tubing E Change Approved Program Plug for Redrill E Perforate New Pool r Re-enter Susp Well fl Alter Casing f Other: Crystal Seal MBE Trmt F _ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Exploratory ...... Development f 205-028 r 3.Address: 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service 50-029-23251-61 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 1E-117L2 Will planned perforations require a spacing exception? Yes nNo 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25660 ' Kuparuk River Field/West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): Junk(MD): 15,661' 3,208' 15661 3208 1979 9759 N/A Casing Length Size MD ND Burst Collapse Structural Conductor 78' 20 108' 108' Surface 5,514' 13 3/8 5,544' 2,364' Intermediate Production 10,546' 9 5/8 10,572' 3,510' D-Sand Liner 6,179' 5 1/2 15,661' 3,208' Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9580-15517 3355-3209 4.500" L-80 9,348' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): PACKER-HRD ZXP Liner Top Packer 10382 MD=3486 ND PACKER-ZXP Liner Top Packer 9647 MD=3392 ND SSSV:NONE N/A 12.Attachments: Proposal Summary El Wellbore schematic 2 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory l Stratigraphic E Development r Service F 14.Estimated Date for 5/26/2016 15.Well Status after proposed work: Commencing Operations: OIL E WINJ F WDSPL E Suspended E 16.Verbal Approval: Date: GAS E WAG E GSTOR E SPLUG E Commission Representative: GINJ E Op Shutdown E Abandoned r- 17. 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact John Peirce @ 265-6471 Email John,W.Peirce@cop.com Printed Name John W.Peirce . Title Sr.Wells Engineer rt. -e - _ .S-71212414-6Signature Phone 265-6471 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3\Lk — 213 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No d Subsequent Form Required: / P - 4-G 4- RBDMS 1,i, MAY 3 1 2016 APPROVED BY �� // Approved by: 7 � C MMISSIONER THE COMMISSION Date:cS‘ -3dhrm and harm a-'U3 Nevi ed 11/L 15 a` a�n valla for 12 0 di om da o pprro al. Attachments in Duplicate • 1E-117L2 to 1J-168L2 'D' MBE Crystal Seal Treatment Proposal 1E-117 injector was shut-in after an MBE occurred to adjacent producer 1J-168. With 1E-117 SI, a decision was made to SI 1E-170 for reservoir and pattern protection. In order to return 1 E-170 (750 bopd) to service, 1E-117 must be returned to injection. Diagnostics have been done on the MBE between 1E-117 and 1J-168 as follows: 1. Mainbore (PROF completed in 1E-117 on 1/30/16. (PROF Identified injection splits as 30% D- sand, 60% B-sand, 10% A-sand. IPROF results show majority of injection into the B-sand led team to decide that a B lateral (PROF would determine location of MBE. 2. Set an A Sand Isolation Plug on 1/31/16 in DB Nipple at 9759' RKB. 3. B-sand lateral (PROF completed in 1E-117 on 3/15/16. IPROF got 2000' in lateral (3000' remaining). Logged interval showed no signs of an MBE. Team decided to perform a PPROF in 1J-168 to determine in which lateral the MBE existed. 4. Mainbore PPROF obtained in 1J-168 on 5/8/16. PPROF showed 98% of flow was entering the wellbore from D-sand. Team decided that MBE exists in D-sand lateral. Proposed Procedure - Coil Tubing will perform in 1E-117 & 1E-117L2: 1. RIH & pull the D Iso-Sleeve at 9385' RKB. 2. RIH & pull the B Lat Diverter at 9706' RKB. 3. RIH & set a B Lat Iso-Sleeve at 9706' RKB. 4. RIH & set a D Lat Diverter at 9385' RKB. 5. RIH with Nozzle and perform a D Lat Fluff& Stuff to deep as possible. 6. RIH with memory IPROF BHA and log D Lat IPROF to deep as possible to locate MBE. 7. If D MBE location can be determined from IPROF, RIH with 2" OD Perf Gun to perforate a 5' interval at 6 spf across the MBE location, using 'big hole' charges to provide large inflow area for Crystal Seal to exit slotted liner to the D MBE. If the MBE is not detected on the IPROF, it may be that the MBE exists at depth greater than can be attained with CT, in which case perforating will not be performed. 8. RIH with Down Port Nozzle and park nozzle above all slots at `safety' (9575' RKB), then pump 0.4 bpm Diesel down CT x Tbg (until Flush is called), and simultaneously start pumping 1,2,4 mm mesh Crystal Seal Slurry at 0.25 lbs Crystal Seal per gallon in 3% KCL Water, or Winter Seawater. Pump slurry down CT at steady rate between 2 - 3 bpm to MBE until target Wellhead Pressure on Tbg x CT annulus reaches 1000 - 1200 psi (near Frac pressure), then call Flush of 5 bbls 3% KCL Water (or Seawater) down CT, followed by 1 CT volume (-47 bbls) Diesel to FP CT, followed by POOH with CT replacing voidage with Diesel. Leave tubing FP to 2200' TVD (4889' RKB) = 75 bbls Diesel. 9. RIH with Down Jet Nozzle to Fluff & Stuff with Seawater through Crystal Seal to deep as possible while injecting all fluid to well. POOH. Return 1E-117L2 to PWI to and D Lateral to evaluate Crystal Seal treatment results at 1E-117 and 1J-168. JWP 5/12/2016 "'i'''', ; KUP 1E-117L2 COnoC6J "hips IIMIW Well Attribu Max Angle D TD Ian Inc Wellbore APUUWI Field Name Wellbore Status (°) MD(ftKB) Act Btm(ftKB) i3xocophiilips 500292325161 WEST SAK INJ Ind 94.84 9,872.28 15,661.0 .! Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1E-117L2,56220163:04:49 PM SSSV:NIPPLE Last WO: 10/16/2005 31.031 8/13/2005 Verna schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;20.1 ��eiS1a� Last Tag: Rev Reason:ADD FORMATION ZONES osborl 10/23/2013 �.1,'1 -Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ' Ill ' t�,:..,M,_D-SAND LINER 51/2 4.950 9,482.1 15,661.0 15.50 L-80 BTCM I Liner Details Nominal ID at Top(ftKB) Top(TVD)(ftKB) Top Incl Cl Item Des Com (in) 9,482.1 3,355.4 85.69 SLEEVE BAKER HR SETTING SLEEVE 6.151 CONDUCTOR,30 0-108.0 9,535.7 3,357.0 90.91 'XO Reducing CROSSOVER 7"x5.5" 5.500 NIPPLE;506.0 Perforations.&Slots it Shot Dens GAS LIFT,1,875.5 al_ Top(TVD) Btm(TVD) (shoal Top(111(B) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Coin 9,580.0 9,963.0 3,354.8 3,331.5 WS D,1E- 8/7/2005 40.0 SLOTS Alternating blank/slotted 117L2 pipe 10,261.0 10,646.0 3,322.4 3,313.9 WS D,1E- 8/7/2005 40.0 SLOTS Alternating blank/slotted 1171_2 pipe SURFACE;29.9-5,543.6-+ •• 10,772.0 10,938.0 3,312.2 3,309.5 WS D,1E- 8/7/2005 40.0 SLOTS Alternating blank/slotted 1171_2 pipe 11,022.0 11,229.0 3,307.2 3,301.7 WS D,1E- 8/7/2005 40.0 SLOTS Alternating blank/slotted SLEEVE-C,9,247.7 11712 pipe • 11,314.0 11,483.0 3,299.3 3,295.5 WS D,1E- 8/7/2005 40.0 SLOTS Alternating blank/slotted • 1171_2 pipe 11 11,782.0 11,953.0 3,288.2 3,285.8 WS D,1E- 8/7/2005 40.0 SLOTS Alternating blank/slotted LOCATOR;9,329.5 NIL 11712 pipe SEAL;9,330.2 12,037.0 12,246.0 3,284.8 3,281.2 WS D,1E- 8/7/2005 40.0 SLOTS Alternating blank/slotted 11712 pipe ISO SLEEVE,9,305.0 _. 12,499.0 12,709.0 3,278.4 3,275.6 WS D,1E- 8/7/2005 40.0 SLOTS Alternating blank/slotted D-SAND LINER HH,9,386.0 1171_2 pipe 9,5293 I 44'1 , 12,794.0 12,962.0 3,274.3 3,271.1 WS D,1E- 8/7/2005 40.0 SLOTS Alternatingblank/slotted PRODUCTION;26.3-10,572.0 11712 pipe 13,261.0 13,473.0 3,265.7 3,260.6 WS D,1E- 8/7/2005 40.0 SLOTS Alternating blank/slotted 11712 pipe 13,558.0 13,727.0 3,258.0 3,252.9 WS D,1E- 8/7/2005 40.0 SLOTS Alternating blank/slotted _..c' . 1171_2 pipe 14,025.0 14,482.0 3,244.6 3,232.2 WS D,1E- 8/7/2005 40.0 SLOTS Alternating blank/slotted i 11712 pipe 14,782.0 15,517.0 3,224.4 3,208.7 WS D,1E- 8/7/2005 40.0 SLOTS Alternating blank/slotted 1171_2 pipe SLOTS,9s80.09s63.0 Notes:General&Safety End Date Annotation SLOTS,10,261 0-10,646 8/13/2005 NOTE:MULTI-LATERAL WELL:1E-117(A-SAND),1E-117L1(B-SAND),1E-1171_2(D-SAND) 12/29/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 SLOTS,10,772.0-10,938.0 SLOTS 11 022.0-11,229.0 SLOTS;11,314 0-11,483 0 SLOTS;11,782 0-11,953 0 SLOTS;12,037.012,246.0 SLOTS,12,499.012,709.0 SLOTS;12,794.012,962.0 SLOTS,13,261.013,473.0 SLOTS,13,558.0-18727.0 SLOTS,14,025.0-14,482.0 SLOTS,14,782.0-15,517.0 0-SAND LINER,9,482.1- 15,661.0 4 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other 0 WINJ to WAG Aker Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator Name: 4. Current Well Status: Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 205 - 028 3. Address: Stratigraphic ❑ Service ❑✓ . API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 23251 - 61 B Elevation ft : p Well Name and Number: RKB s!R o 1 E - 1171_2 Property Designation: . Field /Pool(s): ADL 25660 Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured \- ',15661' feet true vertical ~` 3208' feet Plugs (measured) Effective Depth measured 15661' feet Junk (measured) true vertical 3208' feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 108' 20" 108' 108' SURFACE 5448' 13 -3/8" 5543' 2364' INTERMEDIATE 10477' 9 -5/8" 10572' 3510' LINER 6179' 5 -1/2" 15661' 3208' Perforation depth: Measured depth: 9580 - 15517' true vertical depth: 3355 -3209 9, 2005 Tubing (size, grade, and measured depth) 4 -1/2 ", L-80,9347 MD. Packers & SSSV (type & measured depth) Baker ECP 9456' SSSV =NIP 505' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casina Pressure Tubing Pressure Prior to well operation 788 1117 576 Subsequent to operation 1810 803 1783 14. Attachments Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ❑ Development ❑ Service ❑� Daily Report of Well Operations X Well Status after proposed work: Oil❑ Gas ❑ WAGE] GINJ❑ WINJ ❑ WDSPL❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt 309 -052 Contact B. Christensen/ D. Humphrey Printed Name obert D. Ch ristensen Title Production Engineering Specialist Signature Phone: 659 -7535 Date ` �'27 A %3r Form 10-404 Revised 04 /2004 1 �Z- 7 Submit Original Only r 1 E -1171-2 ' DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11123109 Commenced Viscous Recovery WAG Injection KRU 1 E-1 1712 ConocoPhilli p s Alaska, Inc. API: 5002923 Well Type: INJ Angle TS: I de TUBING — SSSV Type: NONE Orig Completion: 8/13/2005 Angle TD: 190 de 15661 (0-9347, Annular Fluid: Last W /O: 10/1612005 Rev Reason: FORMAT UPDATE ODA.500, Reference Log: 28' RKB Ref Lo Date: Last U date: 12/27/2007 ID:3.958) Last Tag: TD: 15661 ftKB Last Tag Date: Max Hole Angle: 95 qeg_ 9872 _. — Casin String - - Description Size To Bottom TVD Wt Grade Thread CONDUCTOR 20.000 0 108 108 94.00 K -55 WELDED SURFACE 13.375 0 5543 2364 68.00 L -80 BTC SURFACE INTERMEDIATE 9.625 0 10572 3315 40.00 L -80 BTCM — 6.500 9482 15661 I 15661 15.50 BTCM D -Sand Slotted Liner L -80 (0 -5543, Casing D -SAND SLOTTED LINER (Alternating is biank/slott 2.5"x .125 " 4 rove OD:13.375, Description Size To Bottom TVD __ Wt Grade _ Thread Wt:68.00) - Tubing String - ING _ — Bottom Thread 4. 500 0 9347 3333 12.60 L -80 IBTM TERMEDIATE - (0- 10572, PerforatiD Summ - OD:s.625, I Interval TVD Zone Status Ft SPF Date Type Comment Wt:40.00) 9580-9963 3355-3332 WS D 383 40 8/7/2005 Slots Alternating blank/slotted pipe 10261 - 10646 3322-3314 WS D 385 40 8/7/2005 Slots Alternatin blank/slotted pipe 10772 - 10938 3312-3310 WS D 166 40 8/7/2005 Slots Alternating blank/slotted pi 11022 - 11229 3307-3302 WS D M - 7 - 40 8/7/2005 Slots Alternating blank/slotted pi LOCATOR 11314 -11483 3299-3295 WS D 169 40 8/7/2005 Slots Alternating blank/slotted pi (9330 -9331, 11782 - 11953 3288-3286 WS D 171 40 8/7/2005 Slots Alternating blank/slotted pi ODA.750) 12037 - 12246 3285-3281 WS D 209 40 81712005 Slots Alternating blank/slotted pi 12499-12709 3278-3276 WS D 210 40 8/7/2005 Slots Alternating blank/slotted pi Blank Pipe 12794 - 12962 3274-3271 WS D 168 40 8/7/2005 Slots Alternating blank/slotted pi (9387 -9485, 13261 - 13473 3266-3261 WS D 212 40 817/2005 Slots Alternating blank/slotted pipe 00:5.500) 13558 - 13727 3258-3253 WS D 169 40 8/7/2005 Slots Alternating blank/slotted pipe D -Sand 14025 - 14482 3245-3232 WS D 457 40 8/7/2005 Slots Alternating blank/slotted pipe Window 14782 - 15517 3224 - 3209 WS D 735 40 8/7/2005 Slots Alternatin blank/slotted i e — ---.__..__..--- (9391 -9392, s Lift Mandrels/ OD:9.625) St MD TVD Man Mfr Man Type V Mfr V Type VOID Latch I Port TRO Date Run Vlv Cmnt 1 1 18761 15011 CAMCO I KBG -2 -1R DMY 1 1.0 1 BK 1 0.000 0 1 1/20/2006 Hook HNGR er lu s e ui .etc. - COMMON JEWELRY (9397-9398, 00:9.625) De th TVD Type Description ID 22 22 HANGER TUBING HANGER _ 3.900 506 505 NIP CAMCO'DB' NIPPLE 3.875 Bushing 9248 3313 SLEEVE -C BAKER CMU SLIDING SLEEVE - CLOSED 10/28/2005 3.812 (9413 -9414, 9330 3330 LOCATOR BAKER LOCATOR SEAL ASSEMBLY 3.875 OD:6.030) 9391 3342 D -Sand D -SAND WINDOW 7.000 Window or lu s equip. SAND J Depth TVD Type Description ID 9387 3342 Blank Pi D -SAND PIPE 4.950 9397 3343 Hook HNGR D -SAND BAKER MODEL B -1 HOOK HANGER 7.000 9413 3346 Bushin D -SAND CROSS OVER BUSHING 3.940 9456 3352 CSG D -SAND BAKER PAYZONE EXTERNAL CASING PACKER 5.500 PACKER 9482 3354 Setting D -SAND BAKER 'HR' LINER SETTING SLEEVE 6.151 Sleeve 9485 3354 Bent CSG D -SAND BTCM BENT BLANK CASING 4.950 9490 3355 Blank Pi D -SAND BLANK PIPE 6.151 9536 _ 3355 XO D -SAND CROSSOVER 4.940 9537 3355 Blank Pie D -SAND BLANK PIPE 4.950 Bent CSG 15660 3208 SHOE D -SAND SHOE 6.151 (9485 -9528, OD:5.500) Gener - Date I Note 8/13/2005 NOTE: MULTI - LATERAL WELL: 1E -117(A-SAND) 1E -117L1 (B -SAND), 1E -117L2 D -SAND Blank Pipe 10/15/2005 NOTE: WORKOVER RIG PULLED KILL STRING /D -SAND HOOK HANGER & REPLACED (9490 -9536, OD:7.000) i Blank Pipe (9537 -9581, OD:5.500) Perf (9580 -9963) DSand Slotted Liner (9482- 15661, OD:5.500, Wt:15.50) iL I - I - I I • • s;. ~ ~~ E [`~C,, ~ `~ ~ ~ u =. h p! ~ ~~ Fd" t ~` ikF ~ ~ ~ ~ ~~~ ~ f "3~ ~ ~~ E~e-~ ,t f' ~ ~ r ~.,~ ~ ~ , ~ r ~~- a ;: `p f ~ 7` ~ 4 J ~ eh 4 ~ ~ ~~~; ~ ~!r¢ ~ ~J ~ Bg ~ >~@ ~ y9 p F ~ E..~ k~ ~ i 0~ ~~ 4 ~~@' A ~ ~ ~ ~`~ F~ ~ ~ ' ~s ~ ~ ~ ~ SEAN PARNELL COVERNOR ~ ~ ~:~ ~ ~ ~ ~~ ~ ~ ~ , ~ ~ ~~ ~ ~~t ~ ~~ ~~ ~~ ~i ~~~ ~~'~ ,~, ~ ~ ` `~ 0, ~-7~ OI~ ~ ut~-.7 ~~ 333 W. 7th AVENUE, SUITE 100 r~ ANCHORAGE, ALASKA 99501-3539 COI~TSERQA'TIOrIT CO1~IIrIIS51O1~T ~ PHONE (907) 279-1433 ~ FAX (907) 276-7542 Mr. M.J. Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Unit, West Sak Pool, 1 E-117L2 Sundry Number: 309-052 ~~ANNE~ (~0`d ~ 3 200J Dear Mr. Loveland: ~5~~~ ~ 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, ~ Cathy P. Foerster Commissioner DATED this 1~~y of October, 2009 Encl. ~ `/ • • ConocoPhrll~ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 February 13, 2049 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~~ .~~~ ~-~ ~„°~ , 1«~ ~.~~~ s ~~~~~~ ~~ . ~ ~ ~. ~~.t~°~ ~"~~~~ ~ ~ ~` ~~" ~09 s~~ `'~ ;~ ~~°~"~~~ ~'r~ ~~SS~~'~ Enclosed please find the 10-403 Application for Sundry Approval for ConocoPhillips Alaska, Inc. Trilateral West Sak injection well 1E-117 (205-026), 1E-117L1 (205-027), 1E-117L2 (205-028) for viscosity reducing water alternating gas cycles (WRWAG). Please call Perry Klein or me at 659-7043 if you have any questions. Sincerely, , ,,,~,~~,~ ~iG~,; .~ r- MJ Loveland ConocoPhillips Well Integrity Projects Supervisor Enclosures • • ~~~~~~~ . ~~ STATE OF ALASKA ~` ~~ 1~ 2009 '~~p ALASKA OIL AND GAS CONSERVATION COMMISSI APPLICATION FOR SUNDRY APPR ~~ ~~~ ~~~~. ~~~m,ss;a~ ~° 20 AAC 25.280 ~~C~~~'~¢~ 1. Type Of Request: Abandon ~ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ~ Other Q Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ~ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ VR EOR WAG 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConoCOPhillips Alaska, Inc. Development ^ Exploratory ^ 205-028 • 3. Address: Stratigraphic ~ Service Q 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23251-61 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Y@S ~ NO ~^ 1E-117L2 ~ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25660~ RKB 95' Kuparuk River Field / West Sak Oil Pool • 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth ND (ft): Effective oepth Mo (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 15661' • 3208' • Casing Length Size MD ND Burst Collapse CONDUCTOR 108' 20" 108' 108' SURFACE 5448' 13-3/8" 5543' 2364' INTERMEDIATE 10477' 9-5/8" 10572' 3510' R 6179' 5-1 /2" 15661' ~ 3208 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Slotted Liner 9580-15517' 3355-3209' 4-1/2" L-80 9347' Packers and SSSV Type: Packers and SSSV MD (ft) Baker ECP 9456 no SSSV DB Nipple 505 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: U ~ ~ % ~ ~` Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: ate: WAG ~. GINJ ^ WINJ ^ WDSPL ~ Commission Representative: 18. I hereby certiy that the foregoing is true and correct to th , best of my knowledge. Contact: Perry Klein/MJ Loveland Printed Name MJ Loveland/Perry Klein ~... - Title: Well Integrity Project Supervisor ~ Signature • ~i" /' ~ ,~ ' ~ ~ ~~ .~.-- ~ ~~ ~ ~-°~ ~---~~ Phone 659-7043 Date ~,?~1 ~ j ~ 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: ~~~iM,.J~t o~.e~^a~'oh Iti 4cco~^~ c.u, Tw Z-6.~y7 Subsequent Form Required: r ~ ~ `~~ ~~ t APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: ~ ~ Form 10-403 R~iised 06/2006 ''t~ ~ ubmit in Duplicate ~ ! : ~ ~. ~~t'~~j ~~ a • t~.rft • • ConocoPhillips Alaska, Inc. 1 E-117 (PTD 205-026) & 1 E-117L1 (PTD 205-027) & 1 E-117L2 (PTD 205-028) Sundry Notice 10-403 Request Februray 12, 2009 Purpose: The purpose of this Sundry Notice is to notify the AOGCC of ConocoPhillips Alaska Inc., intent to inject viscosity reducing water alternating gas (VRWAG) cycles in ,, West Sak Injection Well 1 E-117 and gain approval to do so. This well is part of a 4 pattern field trial of the West Sak VRWAG process that will increase the oil recovery in each pattern and prove the incremental benefit of VRWAG to West Sak for a potential future project to expand EOR on a broader scale. See attached pattern map. Well History: 1 E-117 was drilled in July 2005, completed as a pre produced injector in October ~ 2005, and placed in water only injection service in February 2006. The well was drilled with a 20" conductor to 108'. The surFace hole was drilled with a 16" bit and cased with 13-3/8" casing to a TD of 5544'. The casing was cemented in place with 792 bbl of lead cement and 124 bbl of tail cement. Lost returns with 86 bbl left to pump. Bumped plug and saw mud push at surFace. Ran in annulus with 1'/4" Hydril to 264' and pumped 46 bbl cement with good returns to surface. The intermediate hole was drilled with a 12 1/4" bit and cased to 10572' with 9 5/8" casing. The casing was cemented in place with 324 bbl LiteCrete cement no returns were mentioned. The top of cement is confirmed at 5520' by a USIT log. The USIT log also shows good bond through and above the West Sak and Ugnu intervalw. See attached USIT excerpt. Proposed Plan: The proposed plan includes the following: 1. Inject VRWAG cycles into 1 E-117 2. Injection well 1 E-117 will be operated and maintained in compliance with 20 AAC 25 and Area Injection Order 2B. 3. All West Sak wells with in '/4 mile of 1 E-117 will be completed (or recompleted) with a tubing & packer completion (vs. ESP). 4. The VRWAG cycles will be closely monitored with frequent oil and gas samples from the offset West Sak producers. 5. All Kuparuk wells with in'/4 mile will have OA pressure indicating transmitters installed prior to VRWAG start up. 6. Prior to start up well integrity issues and corresponding mitigating VRWAG strategies will be clearly documented. ; ~ .._ .__.._. ..s_ ' ~ ~ , 1 ' F~ ~.a ~ . r f . ~ _ . . . ~ . .~~~ - .. - ~ e ~ , ~* + ~t ~ = ~ , ~. . - 1' ..~ ~ ~ + ' - ~ ~~ Y ~ . ~, ~ :.. ~ , _~ ~ r i .. .. .,_.... ~ i ti a ... ^ 1 --~- 1 E-102 -~~ i `TM' ~S m ' • :-,~'- . -.-.~. : _____ ~~- ~ ~ , ~. _ ___.____ _._ ~ / / f ~ ° '`~ ± ~ ~ ~ ~ _ ~ , ' . _., ____ _ ._~_~__._ ~.~ d ~ . ` J/~ / 1 1 r ~ . ~ ~.. _ - M ~.- . • ~' * ~ ~ ~ 2009 WSAK EOR ~ ~ ~ '~ _ ' ~'~ ~ . ~ ~ ~ ~ - - ' _ ' \ ri ~ ~ Pattern Targets ~ ~ ~ =: ~ ~ t .- ~ + . ~`.~~ ~ ~ ~ ~> ~'~' ~ _ __ . _ ~-;::. „. -. . • . . ~~ ~. ~ ~ . _ ~ . . ~ ~ ` ~ . i ~ ~..: ~ ~ -~ s ~ _ '~~ ~~~.~ • ~ 1 J-170 - ~ ~, f - _ ;, ~ `~; =~~'' ,.~ 1 J-122 - ~~ r I . } ;: ~~ > ~ ~ ~ ~ ~ p . ~ " ' - - ~: _ - ~ ,. ; ~ ~ ~ , ' ~ i ' ~ ~ ~ i 1. § ' ' _ ~. ~ ~ ~ •~ - ~ 1 +] ~ ~~^_ l 1 , i , ~ ~ ~ ~ ~ - ~ - 1 ' ~ ~.r _ ~ ~ ' ~ ; i ~ ~ ' ~ ~ _ S _~ - ~ ~ j ~ a ~ I ~ ~ ' ~ ~ _ r ~ L„v.~, EOR AAactsd V11bN 1 E-117 ~ ~ _ ~ ~ ~ ; - _ __ _- ,~ H~-r ~~ t1 D' d 115~'. - W:' ' ~~ '~` 6 1 ' vti9 s @ C '~~ . - 1 - ~ ~ - t~llaer KR~J W~e11 ~ ~ t . + . , ~ . ~. R , - YV'" h.~a~tx S~eakng Fautts wS Fs~w~s ~ • r ~ .. . , f ; k 9 ! r • C+~ PrGduC4~ j 1 ~ - 4~ ~~ ~ ~ 1 _ P.nd~caer ; - ~ S~ Pruducar ~ ~ i ~ ~ ~ ~ - P .9irW /4 ` ~ r ;.~ t. s Y ~ . • In1pC~c~r - ~ . ~ ~, ` . . . ': iE-t02 1M rn~ BufMe~ i ~ L ftvrv ifa m~ Bufrsr N ~ +~ ~ !~J Rosrv 11d rn~ 6uf'fV~r h ~~ ~ { ~' ln iS _B.', . . ~ 2 _.. C1 ROw 1f4 rrn 6uMOf 0~71131tif.* BDU~'Oa/y ~ _. . - W'= RA Baundary s--~ ~ ":~ ~M~Ms ' 1E-117 injector •Logged from 10,180 to 5,400' Tops UG C 7,077 •Top of cement labeled @-5,520' (above Ugnu) UG B 7,829 •Unable to determine cumulative footage of good bond UG A 7,933 K13 8,522 •Some channeling appears in CBL K13 8,820 D 9,391 Top interval 5,680'-5,500' 10,200-10,030 • MICROFILMED 03/0't/2008 DO NOT PLACE • .,,, ~~.. s '. , '_ . ANY- NEW MATERIAL UNDER THIS PAGE F:1LaserFiche\CvrPgs_InsertslMicmfitm MBxker.cbc f ~ ~ o ~ •2-C) ~ 7 DATA SUBMITTAL COMPLIANCE REPORT 11 /23/2007 Permit to Drill 2050280 Well Name/No. KUPARUK RIV U WSAK 1E-117L2 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23251-61-00 MD 15661 TVD 3208 Completion Date 10/16/2005 Completion Status 1-OIL Current Status 1WINJ Y ~ REQUIRED INFORMATION Mud Log No Samples No Directional DATA INFORMATION Types Electric or Other Log s Run: GR/Res, CCL Well Log Information: Log/ Electr Data Digital Dataset Tyge Med/Frmt Number Name ICE D Asc Directional5urvey ED D Asc Directional Survey r~ D Lis 13423 Induction/Resistivity i //////~~ t 13423 LIS Verification tpt 13424 LIS Verification F~D Lis 13424 InductionlResistivity ~EQ- C VV ~ 14456 Induction/Resistivity ~, i~ jE,~ C 1~s 14456 Induction/Resistivity wen coresisampies information; (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval Scale Media No Start Stop OH / CH Received Comments 10915 15661 Open 9/26/2005 IIFR 9337 11479 Open 9/26/2005 PB 1 IIFR 5524 15623 Open 1!31/2006 GR/EWR4lCNP/SLD/ROP! ' ACAL/PWD/GEOPILOT L2 5524 15623 1/31/2006 GR/EWR4/CNP/SLD/ROP/ ACAUPWDlGEOPILOT L2 5524 11441 1/31/2006 GR/EWR4/CNP/SLD/ROP/ ACAL/PWD/GEOPILOT L2 '' P61 5524 11441 Open 1/31/2006 GR/EWR4/CNP/SLD/ROP/ ACAUPWD/GEOPILOT L2 P61 5517 15661 Open 1/29/2007 LIS Veri, FET, GR, NCNT, NPHI, RHOB, DRHO w/Graphics 5517 11479 Open 1/29/2007 PB1 LIS Veri, FET, GR< ROP, NPHI, NCNT, DRHO, RHOB w/Graphics Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 11 /23/2007 Permit to Drill 2050280 Well Name/No. KUPARUK RIV U WSAK 1E-117L2 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23251-61-00 MD 15661 TVD 3208 Completion Date 10/16/2005 Completion Status 1-OIL Current Status 1WINJ UIC Y ADDITIONAL INFORM~N Well Cored? Y N Daily History Received? \:-J N Chips Received? ~"Tid~- Formation Tops ~,/ N Analysis ~~. Received? Comments: Compliance Reviewed By: Date: r • • WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 • November 13, 2006 RE: MWD Formation Evaluation Logs: 1E-117, PBl, L1, L1 PBl, L2 & L2 PB1, AK-MVV-3775114 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1E-117, PBl, L1, Ll PBl, L2 & L2 PBl: Digital Log Images: ~CD Rom 50-029-23251-00, 70, 60, 71, 61 & 72 i E -ltd + ~A ~ U=~ 2oS -~~~ ~ ~~L~~~ ~ ( ~ LJord boa ~a,~j ~~I Foy ~.~- I~~-~- i5 ~~ssr~~> i C - t i~ G--I ~ i~ V°~c aa~ - U~~ ~ r~cu~ 5 RECEIVED STAT ~ FEB 0 6 2006 E OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION g~ka Oil & Gas Cons. Cip111(nlSSlon REPORT OF SUNDRY WELL OPERATIONS Anchorage 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other ^/ Prod to WINJ Alter Casing ^ Pull Tubing ^ Pertorate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Pertorate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: COnoCOPhillips Alaska, InC. Development ^ Exploratory ^ 205-028 3. Address: Strati ra hic 9 P ^ Service ~ ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23251-61 7. KB Elevation (ft): 9. Well Name and Number: RKB 95' 1 E-117L2 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 15661' feet true vertical 3208' feet Plugs (measured) Effective Depth measured 15661' feet Junk (measured) true vertical 3208' feet Casing. Length Size MD TVD Burst Collapse Structural CONDUCTOR 108' 20" 108' 108' SURFACE 5448' 13-3/8" 5543' 2364' INTERMEDIATE 1047T 9-5/8" 10572' 3509' PROD. CASING 6179' S-1/2" 15661' 3208' Perforation depth: Measured depth: 9580' - 1551 T Slotted true vertical depth: 3260' - 3209' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 9347 MD . Packers &SSSV (type & measured depth) no packer SSSV= NIP SSSV= 506' 12. Stimulation or cement squeeze summary: Intervals treated (measured) /10/7e ~`~ ~;~~ ~ ~ 2D~~ 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 1901 526 33 900 328 Subsequent to operation 2795 943 -9 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service 0 Daily Report of Well Operations _X 16. Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ Q WDSPL^ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry. Number or N/A if C.O. Exempt Contact Robert W. Buchholz Printed Name Title Production Engineering Technician '~/ Signature (~~"~ ~ Phone 907-659-7535 Date Oz b ~ j~ / Form 10-404 Revised 04/2004 011 1 1 V 1 1 V A Submit Original Only 1 E-117L2 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 1/29/2006 Commenced Water Injection @+ S ~ .. °"- -~ ~-: ~~.~ ~ 5r~ ~ ~ , ~ t~T ~ ~ ~ ^ h FRANK H. MURKOWSKI, GOVERNOR ,' A~~TT ~T /~ tea 333 W. 7TM AVENUE, SUITE 100 ~~Ala~~ ~ ®i~ ~i~ ~~ ANCHORAGE, ALASKA 99501-3539 ,~ PHONE (907) 279-1433 Robert D. Christensen FAx (907) 276-7542 Production Engineering Technician ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: KRU 1 E-117L2 Sundry Number: 306-004 Dear Mr. Christensen: 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. Please provide at least twenty-four (24) hours 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- DATED this day of January, 2006 Encl. ~ ~ ~/~-~ STATE OF ALASKA t' / ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ~'3'a~ - ~ ~ ~ 1. Type of Request: Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ her 0 Waiver ^ , O t ~ ~ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ ~ , u . Time Extension ^ N'7r~n f h•~ ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: I ConocoPhillips Alaska, InC. Development ~ Exploratory ^ 205- 6/ /28 3. Address: Stratigraphic ^ Service ^ 6. API Number: ~Q ~3 P. O. Box 100360, Anchorage, Alaska 99510 50-029-23251- , 61 7. KB Elevation (ft): 9. Well Name and Number: RKB 95' 1 E-117, ~ L2 ~ ~ ~ ~r''zj 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unit Kuparuk River Field /West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 15774' 3415' 15751' 3625' Casing Length Size MD TVD Burst Collapse CONDUCTOR 108' 20" 108' 108 SURFACE 5448' 13-3/8" 5543' 2364 INTERMEDIATE 10477' 9-5/8" 10572' 3510 A-SAND SLOTTED LINER 5369' 5-1/2" 15751' 3415 Lt B-SAND SLOTTED LINER 588$' 5-1 /2" 15675' 3275 L2 D-SAND SLOTTED LINER 6179' 4-1/2" 15661' 3208 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): A: 10570-15685' Slotted; L1:9845-15631' Slotted; L2: 9580-15517' Slotted A: 3416-3415° L1:3412-3416'; L2: 3361-3416' 4-1/2" L-80 9347' Packers and SSSV Type: Packers and SSSV MD (ft) no packer SSSV= NIP SSSV= 506' 12. Attachments: Description Summary of Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service 14. Estimated Date for 15. Well Status after proposed work: 01/10/06 Commencing Operations: Oil ^ Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ~ WDSPL ^ Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Robert D. Christensen Printed Name Robert D. ristense Title: Production Engineering Technician Signature ~ Phone 659-7535 Date ~~ ~~ Commission Use Only witness Commission so that a re resentative ma l: Notif C diti f Sundry Number: ^~~/~ `W y p on ons o approva y Location Clearance ^ anical Integrity Test ~ h Plug Integrity ^ BOP Test ^ Mec \` __ lI '!'~~~ S~G~`~/ ~`r W`~ '~~~ ~ . Other: ~ v, F~47 ~ .~~~,r f# Subsequent For Re ' e ~ (~..~ (\ (.,..1 . APPROVED BY Approve CO I I N HE COMMISSION Date: ~ 0 For 1m 0-403 tl~Vlsed 07/20 ' ~ ~ Submi~ in [duplicate • • 1 E-117 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to begin Multi-Lateral Water Injection service in West Sak Well 1 E-117, L1, L2. This well was placed on production service on November 4, 2005. This multi-lateral wellbore will provide pressure support for the West Sak A, B, & D sands. The D sand lateral injection tubing/casing annulus is isolated via a Baker Payzone External Casing Packer" located @ 9456' and / 3352' tvd. The B sand lateral injection tubing/casing annulus is isolated via a lower ZXP 9-5/8" x 4-1/2" Liner Top Packer w/HRD located @ 9648' and / 3392' tvd. The A sand injection tubing/casing annulus is isolated via lower ZXP 9-5/8" x 4- 1/2" Liner Top Packer w/HRD located @ 10382' and / 3486' tvd. A MITIA was performed prior to placing the well on production service on 10/28/05; MITIA to 3000 psi for 30 minutes, Passed The following is a summary of the proposed plan: 1) Replace 1" x 3/16" GLV w/1" DV. 1) Close sliding sleeve with coil tubing unit and perform MITIA prior to injection. 2) Place well on Injection service. _ 3) Performed State witnessed MITIA shortly after injection is initiated and submit test results to the AOGCC. FW: Plans for 1E-117 ~ i Subject: FW: Plans for 1E-117 From: NSK Problem Well Supv <n1617@conocophillips:com> ~~ ~ , ~ ~~ Date: )~ri,'16 Dec 2005 08:58:19 -~)9O~i To: toiY~ maundercl:a~lil~in.state.ak.us. "Spenceley. Neil" ~-A'eiLK.Spenceley(~r?conoeophillips.com:= ('C: NSK Pruhlci7~ ~~"ell Sup~~ ~_r~l(il i~r~eonocopllillips.cc~m., Neil and Tom: After reviewing the approved 10-403 (#305-323) to produce 1 E-117, and from the note received from Tom Maunder about approval to extend the production period, the plan forward will be the following: 1. Produce the well until January 15, 2006; 2. Reconfigure the well for injection and perform and MIT; 3. Submit a 10-403 to covert the permit to injection service; 4. Place well on injection; 5. Notify AOGCC Inspector for witnessing the initial MIT. Tom: It appears I owe you a 10-404 and production report, I will get that in the mail. If you find I have missed anything please let me know. Thanks) Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska 907-659-7224 -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Thursday, December 15, 2005 4:31 PM To: Spenceley, Neil Cc: NSK West Sak Prod Engr; NSK Prod Engr Tech; Dethlefs, Jerry C; Paul, Jerome Subject: Re: Plans for 1E-117 Neil, et al, Extending the production period is not a problem. I need to check the paperwork, but prior to returning the well to injection, sundry requests should be filed requesting that change. Jerry is familiar with that process. Call or message with any questions. Tom Maunder, PE AOGCC Spenceley, Neil wrote, On 12/15/2005 3:59 PM: Tom, As we discussed we would like to continue producing the well to enable us to properly diagnose a potential production problem. To accomplish this I request to extend the pre-production period until January 15th, 2006. Please call me if you have any questions or concerns. Thanks. Neil Spenceley, P. Eng Drillsite Petroleum Engineer ConocoPhillips Alaska -Greater Kuparuk Area 1 of 2 1/3/2006 12:48 PM • • WELL LOG TRANSMITTAL To: State of Alaska November 18, 2005 Alaska Oil and Gas Conservation Co. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 ~ ~ t~~~ Anchorage, Alaska 99501 ~~ `D nQ RE: MWD Formation Evaluation Logs 1E-117 L2, AdKv-MW-3775114 1 LDWG formatted Disc with verification listing. API# : 50-029-23251-61 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RE'1'U12NING A COPY OF THE TRANSNIITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date:~'~~ Signe • WELL LOG TRANSMITTAL To: State of Alaska November 18, 2005 Alaska Oil and Gas Conservation Co. Attn.: Ceresa Tolley 333 West 7th Avenue, Suite 100 f Anchorage, Alaska 99501 _ ~~ ~-o~ o RE: MWD Formation Evaluation Logs 1E-117 L2 PB1, AK-MW-3775114 1 LDWG formatted Disc with verification listing. A PI# : 50-029-23251-72 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Dater a ~ ~ Signed• STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION R~NV~ N~ ~ 1 G X005 WELL COMPLETION OR RECOMPLETION REPOI~l~@a~,,,,,,,,, 1a. Well Status: Oil ^ Gas Plugged ^ Abandoned ^ Suspended ^ WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. of Completions _ Other_XXX Pre-Produced Injector ~ 1b. Well Class: QCh~fB @ ` Development ^ Exploratory ^ Service ~ Stratigraphic Test^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: October 16, 2005 12. Permit to Drill Number: 205-028 / 305-282 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date SpuddecL~~' ,~, ~~~- E,iup5 ~ ~T/~~ ` 13. API Number: 50-029-23251-61 4a. Location of Well (Governmental Section): Surface: 11' FSL, 228' FEL, Sec. 16, T11 N, R10E, UM 7. Date TD Reached: August 4, 2005 ~ 14. Well Name and Number: 1 E-117L2 At Top Productive Horizon: 2726' FSL, 1709' FWL, Sec. 27, T11 N, R10E, UM 8. KB Elevation (ft): 28' RKB / 95' AMSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 1742' FSL, 1732' FWL, Sec. 34, T11 N, R10E, UM 9. Plug Back Depth (MD + ND): 15661' MD / 3208' TVD West Sak Oil Poo) 4b. Location of Well (State Base Plane Coordinates): Surface: x- 550301 y- 5959601 ~ Zone- 4 10. Total Depth (MD + ND): 15661' MD / 3208' TVD 16. Property Designation: ADL 25660 TPI: x- 552306 y- 5951770 Zone- 4 Total Depth: x- 552385 - 5945506 ~ Zone- 4 11. Depth where SSSV set: none 17. Land Use Permit: ALK 470 1 S. Directional Survey: Yes 0 No 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 2052' MD 21. Lo s Run: ~~ /` / ~• GR/Res, CCL rG.~~ if" ~~ °«~ 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE G AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTIN RECORD PULLED 20" x 34" 62.5# H-40 Surf. 108' Surf. 108' 42" 390 sx AS I 13-3/8" 68# L-80 Surf. 5544' Surf. 2364' 16" 1047 sx AS Lite, 280 sx DeepCrete 9-5/8" 40# L-80 Surf. 10572' Surf. 3510' 12.25" 2ss bbls LiteCrete 5.5" 15.5# L-80 9482' 15661' 3355' 3208' 8.5" slotted liner 23. Pertorations open to Production (MD + ND of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET tbg run in main wellbore 1 E-117 only slotted liner from 9580' - 15517' MD 3355'-3209' ND 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production November 4, 2005 Method of Operation (Flowing, gas lift, etc.) Pre-Produced Injector -shares rate with 1 E-117 and 1 E-117L1 Date of Test 11/6/2005 Hours Tested 5 hours Production for Test Period --> OIL-BBL 335 GAS-MCF 163 WATER-BBL 27 CHOKE SIZE 60% GAS-OIL RATIO 531 Flow Tubing press. 411 psi Casing Pressure 1376 Calculated 24-Hour Rate -> OIL-BBL 1565 GAS-MCF 783 WATER-BBL 134 OIL GRAVITY -API (corr) not available 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". r°,,_._.' ~•-~~°, -,. Ilf'izi~ _.. i.. ~~ ~~I~IS ~~~,Y r~ ~U ~ ° 200 ~ .1~ ..~.~ ~t ~ ~. NONE '"~ Form 10-407 Revised 12/20Q$ rw., ~.~ CONTINUED ON REVERSE ~~-~ ~ ~4 ~ `~~~ L r~ 28. 29. GEOLOGIC MARKERS FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1E-117L2 Top West Sak D 9391' 3342' Base West Sak D 15661' 3208' N/A 1E-117L2PB1 TD 11479' 3288' 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve Mukavitr @ 263-4021 Printed Na Rand Thomas Title: Greater Kuoaruk Area Drilling Team Leader D t a e Signature Phone ~ ~ S` ~ ~ ~ ~ INSTRUCTIONS Prepared by 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. 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 elevation in feet abour mean low low water. 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: True vertical thickness. 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, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 • ConocoPhillips Alaska Page 1 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Spud Date: 6/20/2005 Event Name: ROT -DRILLING Start: 6/20/2005 End: 8/13/2005 Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date 'From - To Hours Code Code Phase __ __ 6/20/2005 101:30 - 03:00 I 1.50 MOVE DMOB I MOVE 03:00 - 04:00 1.00 MOVE MOVE MOVE 04:00 - 06:00 2.00 MOVE MOVE MOVE 06:00 - 10:00 4.00 MOVE RURD MOVE 10:00 - 12:00 2.00 WELCT NUND RIGUP 12:00 - 15:15 3.25 DRILL OTHR RIGUP 15:15 - 20:00 20:00 - 21:15 21:15 - 21:45 4.75 DRILL PULD RIGUP 1.25 DRILL PULD RIGUP 0.50. WELCT BOPE RIGUP 21:45 - 22:30 22:30 - 23:00 23:00 - 23:30 23:30 - 00:00 6/21 /2005 100:00 - 01:15 0.75 DRILL PULD RIGUP 0.50 DRILL PULD SURFAC 0.50 DRILL OTHR SURFAC 0.501 DRILL (TRIP (SURFAC 1.251 DRILL I DRLG I SURFAC 01:15 - 01:30 0.25 DRILL TRIP SURFAC 01:30 - 03:00 1.50 DRILL OTHR SURFAC 03:00 - 03:45 0.75 DRILL OTHR SURFAC 03:45 - 04:15 0.50 DRILL SFTY SURFAC 04:15 - 04:45 0.50 DRILL SURV SURFAC 04:45 - 06:00 1.25 DRILL DRLG SURFAC 06:00 - 06:30 0.50 DRILL SURV SURFAC 06:30 - 08:15 1.75 DRILL DRLG SURFAC 08:15 - 08:30 0.25 DRILL SURV SURFAC 08:30 - 09:45 1.25 DRILL DRLG SURFAC 09:45 - 10:00 0.25 DRILL SURV SURFAC 10:00 - 11:15 1.25 DRILL DRLG SURFAC 11:30 - 12:00 I 0.50 ~ DRILL DRLG I SURFAC 12:00 - 12:30 I 0.50 DRILL DRLG SURFAC Description of Operations Disconnected service loops between rig complex's, blow down lines and prep rig for move Moved rig complex's and staged on pad Moved sub base from 1 E-105 and spotted over well Spotted in rig complex's and rigged up, connected service loops and bermed around rig, completed rig acceptance check list and ACCEPTED RIG at 10:00 Hrs 6/20/2005 NU 21 1/4" 2M diverter and 16" line, loaded pipe shed with 5" DP and took on water in the mud pits Fin loading pipe shed with 5" DP and HWDP and strapped same, began mixing spud mud, rig went on highline at 13:00 hrs PU and stood back 150 jts (50 stds) of 5" DP PU and stood back 29 jts 5" HWDP and jars (10 stds) Function tested diverter, knife valve and accumulator,-good test. Note:- John Crisp with AOGCC waived witnessing of test, initial pressure 2900 psi, after closing 1800 psi. 200 psi buildup req 45 seconds, full charge 3 min 24 seconds, nitrogen bottles (5) avg 2275 psi. PU and stood back 1 std of 8" NM Flex dc's PU and MU 16" bit #1 on 8" motor with 1.83 deg bend RIH to 32' Flooded conductor with water and checked lines for leaks, pressure tested mudline to 3,500 psi Washed down from 32' and tagged cemept inside conductor at 107' and cleaned out to 108', washed down at 30 rpm's, 450 gpm, 325 psi, rot wt 46K, up wt 40K, do wt 44K Drilled 16" hole from 108' to 180' MD/ 180' TVD (72') ART 1.1 hrs, 5-7K wob, 30 rpm's, 448 gpm, 8.8 ppg mw, on btm pressure 450 psi, rot wt 40K, up wt 40K, do wt 40K. POOH f/ 108' to 32'. MU BHA. Plug in and upload Sperry Sun MWD. MU Float sub, UBHO, orient MWD and motor. RIH w. 1 stand NM flex collars to 162'. PJSM. RU Sperry Sun Gyro unit. Run Gyro @ 162'. Drilled 16" hole from 180' to 256' MD/ 256' TVD (76') ART .93 hrs, 10-12K wob, 30-40 rpm's, 440 gpm, 8.9 ppg mw, on btm pressure 1150 psi, rot wt 55K, up wt 55K, do wt 56K. Run Gyro @ 262'. Drilled 16" hole from 256' to 347' MD/ 347' TVD (91') ART .42 hrs, AST 1.22 hrs, 10-12K wob, 60 rpm's, 500 gpm, 8.9 ppg mw, on btm pressure 1325 psi, rot wt 59K, up wt 57K, do wt 59K. Run Gyro @ 34T. Drilled 16" hole from 347' to 439' MD/ 439' TVD (92') ART .23 hrs, AST 1.08 hrs, 10-15K wob, 60 rpm's, 500 gpm, 8.9 ppg mw, on btm pressure 1400 psi, rot wt 63K, up wt 60K, do wt 63K. Run Gyro @ 439' Drilled 16" hole from 439' to 530' MD/ 529' TVD (92') ART .23 hrs, AST .73 hrs, 10-15K wob, 60 rpm's, 500 gpm, 8.9 ppg mw, on btm pressure 1400 psi, rot wt 63K, up wt 60K, do wt 63K. Run Gyro @ 530'. Drilled 16" hole from 530' to 560' MD/ 559' TVD (30') AST .43 hrs, 15K wob, 60 rpm's, 500 gpm, 8,9 ppg mw, on btm pressure 1425 psi, rot wt 67K, up wt 66K, do wt 67K. Drilled 16" hole from 560' to 621' MD/ 619' TVD (61') ART .15 hrs, AST Printed: 10/28/2005 10:29:27 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date -From - To Hours Code Phase Code 6/21/2005 12:00 - 12:30 0.50 DRILL DRLG SURFAC 12:30 - 12:45 0.25 DRILL SURV SURFAC 12:45 - 00:00 11.25 DRILL DRLG SURFAC 16/22/2005 00:00 - 07:30 07:30 - 10:30 7.501 DRILL I DRLG I SURFAC 3.001 DRILL I REAM I SURFAC 10:30 - 12:00 1.50 DRILL TRIP SURFAC 12:00 - 12:30 0.50 DRILL OTHR SURFAC 12:30 - 13:00 0.50 DRILL TRIP SURFAC 13:00 - 13:30 0.50 DRILL TRIP SURFAC 13:30 - 14:00 0.50 DRILL REAM SURFAC 14:00 - 00:00 I 10.001 DRILL I DRLG I SURFAC 16/23/2005 100:00 - 12:00 I 12.001 DRILL I DRLG I SURFAC 12:00 - 13:00 13:00 - 20:15 20:15 - 20:30 20:30 - 00:00 6/24/2005 100:00 - 04:15 1.001 DRILL I OTHR ~ SURFAC 7.251 DRILL I DRLG I SURFAC 0.251 DRILL I OTHR I SURFAC 3.501 DRILL I DRLG I SURFAC 4.251 DRILL (DRLG (SURFAC Page 2 of 33 Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations .30 hrs, 15K wob, 60 rpm's, 500 gpm, 8.9 ppg mw, on bttm pressure 1425 psi, rot wt 67K, up wt 66K, do wt 67K. Run Gyro @ 621'. Drilled 16" hole from 621' to 1453' MD/ 1311' TVD (832') ART 1.44 hrs, AST 7.74 hrs, 15-30K wob, 60 rpm's, 508 gpm, 8.9-9.3 ppg mw, on btm pressure 1525-1825 psi, off bttm press 1400-1550 psi, on bttm torque 3-6k, off bttm torque 2-3k, rot wt 70-90K, up wt 69-92K, do wt 67-87K. Drilled 16" hole from 1453' to 1956' MD/ 1528' TVD (503') ART .65 hrs, AST 5.51 hrs, 30-33K wob, 60 rpm's, 508 gpm, 9.2-9.6 ppg mw, on btm pressure 1700-1825 psi, off bttm press 1550-1600 psi, on bttm torque 5k, off bttm torque 4k, rot wt 87-81 K, up wt 92K, do wt 82-73K. Backream out of hole f/ 1956' to 901' w/ 700-800 gpm, 2700 psi, 80 rpm. No problems. POOH f/ 901' to surface on elevators. No problems. Change bend on motor f/ 1.83 deg to 1.5 deg., remove UBHO sub. Trip in hole w/ BHA, HWDP and jars to 1082'. Continue trip in hole w/ 5" dp f/ 1082' to 1915'. Precautionary wash and ream f/ 1915' to 1956' w/ 80 rpm, 697 gpm, 3700 psi (plugged nozzle), torque 7k. Drilled 16" hole from 1956' to 2800' MD/ 1716' TVD (844') ART 2.24 hrs, AST 3.38 hrs, 10-30K wob, 80 rpm's, 508- 698 gpm, 9.6 ppg mw, on btm pressure 2250-3000 psi, off bttm press 1575-2750 psi, on bttm torque 7-10k, off bttm torque 6k, rot wt, 82-75K, up wt 88-90K, do wt 75-64K. Drilled 16" hole from 2800 to 3865' MD/ 1953' TVD (1065') ART 4.10 hrs, AST 3.36 hrs, 10-30K wob, 90-100 rpm's, 554-800 gpm, 9.6 ppg mw, on btm pressure 2050-3700 psi, off bttm press 1850-3700 psi, on bttm torque 7-10k, off bttm torque 7-8k, rot wt 75-78K, up wt 87-1001<, do wt 60-65K. Avg BG gas 35 units. Max gas 70 units while drilling @ 3675' Note: While drilling @ 3680'-3772' MD/ 1919'-1937' TVD, oil shows started appearing @ shakers. This would have been f/ approx 3605'-3630' MD/ 1904'-1910' TVD. CBU to clean hole. Lots of cuttings. Screen one shaker w 50's, other two have 140's. Drilled 16" hole from 3865 to 4439' MD/ 2090' TVD (574') ART 2.15 hrs, AST 2.0 hrs, 15-25K wob, 100 rpm's, 664-800 gpm, 9.6 ppg mw, on btm pressure 3100-3700 psi, off bttm press 2950-3700 psi, on bttm torque 10-12k, off bttm torque 7-11 k, rot wt 78-84K, up wt 100-120K, do wt 65-57K. Avg BG gas 50 units. Max gas 151 units while drilling @ 4290'. Change one shaker w 38's, other two have 50's. Lost 80 bbls fluid in 20 min to rockwasher prior to change. Drilled 16" hole from 4439' to 4658' MD/ 2133' TVD (219') ART 1.3 hrs, AST .44 hrs, 20-25K wob, 100 rpm's, 664-800 gpm, 9.6 ppg mw, on btm pressure 3100-3700 psi, off bttm press 2950-3600 psi, on bttm torque 11-12k, off bttm torque 10-11 k, rot wt 82K, up wt 122K, do wt 54-52K. Avg BG gas 60 units. Max gas 108 units while drilling @ 4540'. Note: Shaker screens @ midnight :one set of 84's, one set of 50's, one set of 110/110/84. Drilled 16" hole from 4658' to 4886' MD/ 2198' TVD (228') ART 1.83 hrs, AST 1.18 hrs, 0-25K wob, 100 rpm's, 700-800 gpm, 9.6 ppg mw, Printed: 10/28/2005 1029:27 AM • • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Start: 6/20/2005 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Code Code Phase 6/24/2005 ~ 00:00 - 04:15 04:15 - 06:15 06:15 - 06:45 06:45 - 12:00 12:00 - 16:45 16:45 - 00:00 6/25/2005 00:00 - 04:00 04:00 - 04:30 04:30 - 05:00 05:00 - 06:00 06:00 - 06:45 06:45 - 07:00 07:00 - 07:15 07:15 - 07:45 07:45 - 08:15 08:15 - 10:45 10:45 - 12:00 12:00 - 14:00 14:00 - 15:45 4.25 ~ DRILL ~ DRLG ~ SURFAC 2.001 DRILL (REAM (SURFAC 0.50 DRILL TRIP SURFAC 5.25 DRILL DRLG SURFAC 4.75 DRILL DRLG SURFAC 7.251 DRILL I REAM I SURFAC 4.00 DRILL REAM SURFAC 0.50 DRILL TRIP SURFAC 0.50 DRILL TRIP SURFAC 1.00 DRILL OTHR SURFAC 0.75 DRILL OTHR SURFAC 0.25 DRILL OTHR SURFAC 0.25 DRILL TRIP SURFAC 0.50 RIGMNT RSRV SURFAC 0.50 RIGMNT RGRP SURFAC 2.50 DRILL TRIP SURFAC 1.251 DRILL REAM I SURFAC 2.00 DRILL I DRLG SURFAC 1.751 DRILL I REAM I SURFAC 15:45 - 16:15 0.50 DRILL CIRC SURFAC 16:15 - 19:30 3.25 DRILL TRIP SURFAC 19:30 - 20:00 0.50 DRILL PULD SURFAC 20:00 - 20:45 0.75 DRILL OTHR SURFAC 20:45 - 21:45 1.00 DRILL PULD SURFAC 21:45 - 22:15 0.50 DRILL OTHR SURFAC 22:15 - 22:45 0.50 CASE OTHR SURFAC 22:45 - 00:00 1.251 CASE RURD SURFAC Page 3 of 33 Spud Date: 6/20/2005 End: 8/13/2005 Group: Description of Operations on btm pressure 2950-3700 psi, off bttm press 2750-3500 psi, on bttm torque 12k, off bttm torque 10-11 k, rot wt 82K, up wt 122-145K, do wt 52-44K. Avg BG gas 50 units. Max gas 68 units while drilling @ 4820'. Backream out of hole. Pull slow (2-40'/hr), pumping 800 gpm, rotate 100 rpm. Ream f/ 4886' to 4327', torque 12-14k. RIH on elevators f/ 4327' to 4793', orient to high side and RIH to 4886'. Drilled 16" hole from 4886' to 5164' MD/ 2273' TVD (278') ART 1.15 hrs, AST 1.8 hrs, 0-25K wob, 100 rpm's, 700-800 gpm, 9.6 ppg mw, on btm pressure 2950-3700 psi, off bttm press 2750-3500 psi, on bttm torque 12k, off bttm torque 10-11 k, rot wt 82K, up wt 122-145K, do wt 52-44K. Avg BG gas 50 units. Max gas 68 units while drilling @ 4820'. Backream @7' per min. Drilled 16" hole from 5164' to 5361' MD/ 2329.61' TVD (197') ART .4 hrs, AST 1.78 hrs, 15-20K wob, 100 rpm's, 710-800 gpm, 9.6-ppg mw, on btm pressure 3650-3750 psi, off bttm press 3550-3675 psi, on bttm torque 12-15k, off bttm torque 13-16k, rot wt 85K, up wt 155-175K, do Iwt 35K. Avg BG gas 160 units. Max gas 475 units while drilling @ 5260'. Backream @ 8' per min. Monitor well. Backream out of hole f/ 5361' to 2200' @ 700 to 800 gpm, 3100-3650 psi, 100 rpm. Pulling slow, 10'/min. Lots of sand returns. Backream out of hole f/ 5361' to 2200' @ 800-550 gpm, 3100-2300 psi, 100 rpm. Pulling slow, 10'/min.Torque 5-9k. Sand and clay and gravel in returns. Pull and stand back stand NM flex drill collar. Pull bit out of hole, clean a little, and grade bit. UD MWD. PU MWD. Remove restrictor to allow more flow w/ less pressure. Upload MWD. Orient MWD and motor. MU stand flex NMDC. Service top drive. Repair hydraulic fitting on top drive. RIH f/ 162' to 5109' with no problems, fill pipe @ HWDP and every 25 stands. Wash thru 5109' w/ no problems. Precautionary ream f/ 5258'- 5350', orient high side, wash f/ 5350' to 5361' Drilled 16" hole from 5361' to 5560' MD/ 2367' TVD (199') ART .51 hrs, AST .48 hrs, 10-20K wob, 100 rpm's, 795 gpm, 9.6-9.7 ppg mw, on btm pressure 3000 psi, off bttm press 2950 psi, on bttm torque 11-12k, off bttm torque 13k, rot wt 90-K, up wt 160-150K, do wt 60-63K. Avg BG gas 30units. Max gas 40 units while drilling. BU gas max 290 units Backream @ 8' per min. Monitor well. Backream out of hole f/ 5560' to 5074'. 100 rpm's, 867 gpm, 3300 psi, Pump dry job, blow down top drive. POOH on elevators. UD BHA. Download MWD UD MWD, bit and mtr. Calc displ 54.1 bbl, actual 56 bbls. Clean rig floor. Dummy run Vetco/Gray 13 3/8" landing joint and hanger. Load shoulder to rig floor 29.89'. Rig up to run 13 3/8", 68 ppf, L-80 BTC casing. Nnntea: iurluizuuo iu:za:zi vm • ConocoPhillips Alaska Page 4 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common W ell Name: 1 E-117 Spud Date: 6/20/2005 Event Nam e: ROT -D RILLING Start: 6/20/2005 End: 8/13/2005. Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Code Phase Description of Operations Code 6/26/2005 00:00 - 00:30 0.50 CASE SFTY SURFAC PJSM on running 13 3/8", 68 ppf, L-80, BTC. 00:30 - 04:15 3.75 CASE RUNC SURFAC Run 13 3/8": MU Weatherford model 303 Float Shoe, w/ stop ring 10' above and Weatherford bow centralizer over stop, also on box, MU jt # 2 with stop 10' below box and bow centralizer over stop, Weatherford model 402 Float collar on bottom of jt # 3 (all below joints baker locked to bottom of co-lar of jt #3. Jts # 3-15 have centralizers on box. Total of 16 centralizers. All casing 13 3/8", 68 ppf, L-80, BTC casing. Torque to 10,000 ft/Ib. Run to jt # 56 (2187) Record PU & SO wt's every 10 jts. 04:15 - 05:00 0.75 CASE CIRC SURFAC Break circ slow @ 2187', then bring up to 6 bpm w/ 325 psi, work jt 56 down slow, then the same with joint 57 to depth of 2265'. Circ total of 160 bbls. MW out 10 ppg, mw in 9.7 ppg. Final pressure 300 psi @ 6 bpm. PU wt 160k, SO wt 98K 05:00 - 07:00 2.00 CASE RUNC SURFAC Continue running casing f/ jt #58 to jt #88. (2265' to 3525'). Record PU 8 SO wt's every 10 jts. 07:00 - 07:30 0.50 CASE . OTHR SURFAC UD jt # 89(43.56'). Pin end bad. Replace jt. with spare joint # 141(37.54'). 07:30 - 07:45 0.25 CASE RUNC SURFAC Continue running casing to jt # 89 in hole (3525'-3574'). 07:45 - 08:15 0.50 CASE CIRC SURFAC Break circ @ 4 bpm w/ 290 psi while running jt # 90 and #91( 3574'-3661'). Circ total of 100 bbls. PU wt 245k, SO wt 85k. 08:15 - 09:15 1.00 CASE RUNC SURFAC Continue running casing to jt # jt 114 (3661' - 4600'). PU 295, SO wt 70k 09:15 - 10:15 1.00 CASE RUNC SURFAC Break circ @ 4 bpm w/ 300 psi while running jt # 115, then 5 bpm 350 psi w/ running jt # 116 (4601'- 4684'). Circ total of 120 bbls. 10:15 - 10:45 0.50 CASE RUNC SURFAC Continue running casing f/ 4684' to 5283' (jt #116-# 131). PU wt 350k, SO wt 70k 10:45 - 11:15 .0.50 CASE RUNC SURFAC Tagged up @ 5283' (jt # 131) in hole, work pipe and circ w/ Frank's fillup tool. PU wt 350, SO wt 70k. Pulled to 480k to free up, went down w! 70-80k. Ran jt # 132 f/ 5283' to 5320'. 11:15 - 11:30 0.25 CASE RUNC SURFAC Continue running casing f/ jt # 131 to jt # 137 (5320- 5510') 11:30 - 12:00 0.50 CASE RUNC SURFAC MU Vetco/Gray hanger and landing jt. Remove casing slips, RIH f/ 5510' to 5543.56' landed. PU wt 350k, So wt 75k, blocks 35k of this wt. 12:00 -16:15 4.25 CEMEN CIRC SURFAC Circ and condition mud prior to cement. Reciprocated 9 times w/only 4' of pipe movement @ surface then hanging up on base of conductor i Note; Had no pipe movment and worked pipe to btm after working pipe 9 times- Set pipe on hanger. Circ @ 7bpm w/ 475 psi. Circ total of 1785 bbls. Mud properties before: wt 9.7 ppg, vis 232, PV 43, YP 73. Mud properties after: wt 9.5 ppg, vis 49, PV 19, YP 14. 16:15 - 16:45 0.50 CEMEN SFTY SURFAC PJSM prior to cement job. 16:45 - 19:45 3.00 CEMEN PUMP SURFAC Dowell pump 10 bbls CW 100 (8.3 ppg) @ 4 bpm, test lines to 3500 psi, pump 40 more bbis CW100 (8.3 ppg) @ 4 bpm w/ 75 psi, pump 50 bbls mudpush w/ Red Dye (10.5 ppg) @ 5.8 bpm ,drop bottom plug, pump 792 bbls (990sx) lead Arctic set lite (10.7 ppg) (yield 4.49 cu ft/sx) @ 7 bpm w/ 73-121 psi, 124 bbls (280sx) tail DeepCrete (12.0 ppg) (yield 2.48 cu ft/sx) @ 7bpm w! 128-87 psi, drop top plug, pump 20 bbls water through tub. 19:45 - 21:45 2.00 CEMEN DISP SURFAC Rig displace cement w/ 9.5-9.6 ppg mud. Pump @ 7.5 bpm until last 82 bbls pumped pressure increasing f/ 400 psi to 820 psi. Lost returns @ 86 bbls left to bump, slowed to 5 bpm 650 psi, until last 10 bbls, then to 3 bpm @ 600 psi. Bump plug @ 7956 strokes (801 bbl) with 1100 psi. Note: Saw mud push @ 4300 strokes into displacement (433 bbls). Mud returns were 10.2+ ppg until losing returns @ 7100 strokes (715 bbls), Did not have any true signs of cement to surface. Unable to precirocate casing due to no movement. F'f1~t04: lU/LttlNUS IU:Ly:L/ HM • ConocoPhillips Alaska Page 5 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Spud Date: 6/20/2005 Event Name: ROT -DRILLING Start: 6/20/2005 End: 8/13/2005 Contractor Name: Rig Release: .Group: Rig Name: Rig Number: Date From - To Hours Code Code Phase 6/26/2005 21:45 - 00:00 2.25 CEMEN OTHR SURFAC 6/27/2005 00:00 - 02:00 2.00 CEMEN OTHR SURFAC 05:00 - 06:00 1.00 CEMENlf TRIPD SURFAC 06:00 - 06:30 0.501 CEMENT(OTHR ~ SURFAC 06:30 -11:30 5.00 CEMENl~OTHR SURFAC 11:30 - 12:00 0.50 CEMEN OTHR SURFAC 12:00 - 12:45 0.75 CASE RURD SURFAC 12:45 - 14:15 1.50 WELCT OTHR SURFAC 14:15 - 15:00 0.75 WELCT NUND SURFAC 15:00 - 20:45 5.75 WELCT OTHR SURFAC 20:45 - 21:00 0.25 VVELCT~ NUND SURFAC 21:00 - 22:45 1.75 WELCT NUND SURFAC 22:45 - 23:00 0.25 WELCT OTHR SURFAC 23:00 - 00:00 1.00 WELCT NUND SURFAC 6/28/2005 00:00 - 00:15 0.25 WELCT NUND SURFAC 00:15 - 02:00 1.75 WELCT NUND SURFAC 02:00 - 07:00 5.00 WELCT BOPE SURFAC 07:00 - 07:15 0.25 WELCT BOPE SURFAC 07:15 - 09:00 1.75 DRILL PULD SURFAC 09:00 - 10:00 1.00 DRILL PULD SURFAC 10:00 - 12:00 2.00 DRILL PULD SURFAC 12:00 - 15:00 3.00 DRILL PULD SURFAC 15:00 - 18:00 3.00 DRILL TRIP SURFAC 18:00 - 18:15 0.25 DRILL DEOT .SURFAC 18:15 - 19:45 1.50 DRILL TRIP SURFAC 19:45 - 20:00 0.25 DRILL TRIP SURFAC Description of Operations Cleaning out diverter stack, trying to catch sample @ Vetco Gray quick connect, thick fluid would not come out 2" valve. UD Dowell cement head. Prepare to UD landing joint. R/D casing equipment, UD landing joint, Flush thick mud f/ stack w/ water usnig 5" dp and rig pumps. N/D diverter line and diverter stack. RIH w/ 1.315" Hydril CS tubing (OD of connection 1.61"), 2.25 ppf. Run between Outs in hanger and landing ring (1.625" clearance). RIH to 53' RKB. Circ w/ rig water press (70 psi). Returns 10.2+ ppg. RIH 2 more joints to 112' RKB. Circ w/ Rig water pressure thick stuff 10.2+ ppg. POOH w! 1.315" Hydril CS tubing. Welder cut 4" wide x 4" hole in conductor to take returns to cellar. Rig & run 8 jts 1-1/4" Hydril tubing to 264' RKB, 80' below ground level in 13-3/8" x 20" annulus (Volume 14.6 bbls) i;< 156' in 13-3/8" x 16" (11.6 bbls), washing each joint dowrrwith fresh water and was unable to make any further progress. Flushed well with 58 bbls fresh water using Dowell. Mixed & pumped a total of 46.0 bbls (57 sacks) Lead cmt mixed @ 10.7 ppg. Had good 10.7 ppg cement returns to surface after pumping 26.1 bbls cement, C.I.P. @ 10:50 hrs 6/27/05. Pulled out of 'the hole w/ tubing and the fluid level dropped 4". Cleanup cellar box prep f/ welder. R/D casing equipment f/ rig floor. Crane removed diverter pieces and set in Vetco/Gray wellhead equip in the cellar area. NU Vetco gray multibowl wellhead. Test seal on graylock. Failed 4 different times. Test failed @ pressures of 4500 psi, 4800 psi, 5000 psi and again 5000 psi. Remove Vetco gray multibowl. Will install bowl assigned to 1J-154. NU Vetco/Gray multibowl (used the one assigned to 1J-154, set up as a producer). Test seal sub to 5000 psi f/ 15 min. OK. Change orientation of valves on Vetco/Gray multibowl. Change orientation of valves on VetcA/Gray multibowl f/ injector well. NU 13 5/8" BOPE. RU and test 13 5/8" BOPE. Witness of test waived by AOGCC inspector Chuck Scheve. Test using lower test plug. One test made @ 5000 psi high and 250 psi low to test all valves which were changed around. Only lower annulus valve of multibowl was NOT TESTED. This valve will be tested to 3000 psi when testing casing. Other tests were to 3000 psi. high and 250 psi low. Install wear bushing - RILDS P/U and single in hole 51 jts 5" DP from pipe shed Stand back these 17 stds in derrick -Clean rig floor M/U BHA #4 -w/ bit & 9.625 Geo -Pilot "` Note** Had to have Bit rep come over because the bit breaker would not fit the bit. He had the welder do a small modification to where it would fit after he confered with his engineers. Con't PU BHA #4 - Up Load MWD TIH picking up singles from pipe shed. install ghost reamers @ 824' and 1666' behind bit. Break in Geo Pilot Bearing Con't TIH PU singles from pipe shed TIH w/ DP from derrick - Dn wt 35K -Will need to circu and wash to FC rnntea: iu/zarzuuo IU:Z`.l:Z/ HM C. • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code Code Phase 6/28/2005 20:00 - 22:15 I 2.251 DRILL REAM SURFAC 22:15 - 23:45 1.50 DRILL DEOT SURFAC 23:45 - 00:00 0.25 RIGMNT RSRV SURFAC 00:00 - 01:30 1.50 RIGMNT RSRV SURFAC 01:30 - 02:30 1.00 RIGMNT RGRP SURFAC 02:30 - 05:00 2.50 CEMEN DSHO SURFAC 05:00 - 06:15 1.251 DRILL I CIRC I SURFAC 06:15 - 07:00 0.75 DRILL LOT SURFAC 07:00 - 12:00 5.00 DRILL DRLG INTRM1 12:00 - 00:00 12.00 DRILL DRLG INTRM1 16/30/2005 100:00 - 11:00 I 11.001 DRILL I DRLG INTRM1 11:00 - 12:00 I 1.001 DRILL I CIRC I INTRM1 12:00 - 17:15 I 5.251 DRILL DRLG INTRM1 17:15 - 18:30 1.25 ~ DRILL ~ DRLG ~ INTRM1 18:30 - 00:00 5.501 DRILL ~ DRLG ~ INTRMI Page 6 of 33 Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations __ Wash and Ream 4670' to 5450' MD - 500 gpm, PP 1100 psi, RPMs 50, Troq 13-15k -(Surface Float Collar @ 5461' MD) Circu 10 min - RU & Test Csg to 3000 psi on chart for 30 min - No loss Slip & Cut drill line. Con't Slip & Cut drill line (59' cut) -Service Top Drive & Draworks Repair fitting on top drive tube oil pump cooler Drlg shoe track + 20' new hole f/ 5560' to 5580' MD (2371' TVD) PP 12050, PR SPM 188, 735 gpm, WOB 10 -20k, RPMs 90- No problems 'noted on drill out. PU to shoe -Circu BU -Condition mud until uniform in and out. -Mud weight 9.1 ppg , Vis 60 RU for & Preform LOT - EMW 13.1 ppg Drlg 12.25" hole 5580' to 6117' MD (2467' TVD) ADT 3.6 hrs - PP 2050 psi, PR 188 SPM, 735 gpm, WOB 10-20k, RPMs 124 -Torg off Bttm 12 -18k, on Bttm 12-18k. Mud tubes 2.5% (1 % being CO)? - No problems noted - 9.625" Geo-Pilot appears to be hooking up better than the 8" tools of the past as we started drilling, we will see how it preforms as we drill.- Drilling Engineer (Pat Reilly) is on site to try and increase our daily ROP by changing some drilling parameters, WOB, Pump rate, RPMs ect,ect. to maximize footage drilled per tour. Drlg 12.25" hole 6117' to 7418' MD (2826' TVD) ADT 8.4 hrs- PP 2100 psi, PR 167 SPM, 700 gpm, WOB 10-20k, RPMs 130 -Torg off Bttm 14-18k, on Bttm 13-17k. Up wt 188k, Dn wt 56k, Rot wt 94k - ECD 9.68 Adding tubes to mud to help with torq. We will try to maintain 2.5-3 tubes (Not Including CO) and see if this helps with high Torgs? -High flow rates had to be reduced to about 700+ gpm to get good preformance from the geo-pilot. This 9.625" OD tool appears to work fairly well and stay hooked up. So far it has shown to give good response with 40 to 70% deflection if we do not pump faster than 720-730 gpm. The Sperry DD is keeping th FR and RPMs as HIGH as possible to maximize ROPs while still maintaining clean hole. Drlg 12.25" hole 7418' to 8718' MD (3188' TVD) ADT 8,18 hrs - PP 2300 psi, PR 155 SPM, 650 gpm, WOB 5-35k, RPMs 130 -Torg off Bttm 16 -17k, on Bttm 17-19k. Mud tubes 2.5% No problems noted - 9.625" Geo -Pilot continued to perform well- Observed max gpm's @ 730 before decrease in performance. PU wt = 192K SO wt = 68K ROT WT = 102K Circulate weighted sweep until clean @ 700 GPM's and 2480 PSI RPM's = 130 When sweep at surface, observed 10%- 15% increase in cuttings at shakers. Drlg 12.25" hole 8718' to 9274' MD ADT 7.95 hrs - PP 2100 psi, PR 150 SPM, 635 gpm, WOB 10-35k, RPMs 110 -Torg off Bttm 16 -17k, on Bttm 17-19k. Mud tubes 2.5% (1 % being CO)? - No problems noted - 9.625" Geo- pilot performing well. PU WT + 207K SO WT = 63K ROT WT = Control drill as per Geologist from 9274' - 9367' MD Geologist neede to evaluate correlated depths. Drlg 12.25" hole 9367' to 9758' MD tvd = 3408' ADT 7.95 hrs - PP 2100 psi, PR 150 SPM, 635 gpm, WOB 10-35k, RPMs 110 -Torg off Bttm 16 -17k, on Bttm 17-19k. Mud tubes 3.0% - No problems noted - 9.625" Geo- pilot performing well. PU WT + 207K SO WT = 63K ROT WT = 101 K rnncea: wr~oizuuo iuzy:zi r+m • • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To .Hours Code Code Phase 7/1/2005 00:00 - 03:30 3.50 DRILL DRLG INTRM1 03:30 - 05:00 1.50 DRILL CIRC INTRM1 05:00 - 06:45 I 1.751 DRILL I DRLG I INTRM1 06:45 - 07:15 0.501 DRILL REAM INTRM1 07:15 - 07:30 0.251 DRILL ~ DRLG ~ INTRM1 07:30 - 09:00 1.50 DRILL: REAM INTRM1 09:00 - 10:15 1.25 RIGMNT RGRP INTRM1 10:15 - 12:00 1.75 DRILL REAM INTRMI 12:00 -16:00 I 4.001 DRILL ~ REAM ~ INTRM1 16:00 - 16:30 0.501 DRILL CIRC INTRMI 16:30 - 19:00 2.501 DRILL (TRIP (INTRM1 19:00 - 22:15 3.251 DRILL CIRC I INTRM1 22:15 - 00:00 I 1.751 DRILL (TRIP INTRM1 17/2/2005 100:00 - 04:00 I 4.001 DRILL (TRIP INTRM1 04:00 - 05:00 I 1.001 DRILL I CIRC I INTRMI 05:00 - 05:15 0.25 DRILL TRIP 1NTRM1 05:15 - 07:45 2.50 DRILL TRIP INTRM1 07:45 - 08:30 0.75 DRILL PULD INTRM1 08:30 - 09:15 0.75 DRILL PULD INTRMI Page 7 of 33 !, Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group:. Rig Number: Description of Operations Continue Drilling From 9758'-.10388'. TVD =3486' Con't ciru Hi-Visc weighted sweep. 38 BBL, 11.1 PPG @ 750 GPM's , 2800 PSI. BU of sweep showed a moderate increase in cutting.. Continue drill from 10388'-10573 TVD = 3510' Obtain slow pump rates and surveys,. Monitor well, static. Back ream out of hole to 10390', at 600 GPM's - 2000 PSI Rotating torque = 14K RIH back to 10573'. Continmue drill from 10573' - 10580' MD TVD = 3511' PU wt = 152K Stack off wt = 75K Rot WT = 103K Torque on bottom = 15K torque off bottom = 13K RPM's = 100 Pumps at 600 GPM's w/ 2000 PSI ART = 3.31 HRS Back ream out of hole to 10384'. Stop and circulate @ 600 spm,2200- psi. Reciprocate drill string. Repair Top Drive. Change out SHot Pin Assembly on TD. Continue back ream out of hole, from 10384' - 9725' Pumps @ 600 GPM's 1975 PSI RPM's = 100, with 12-14k torque. Observed clean hole and no overpull issues. Continue back ream out of hole, from 10384' - 9725' Pumps @ 600 GPM's 1975 PSI RPM's = 100. with 12-14k torque. PU wt = 145k SO WT = 70K Continued to see no hole problems, or overpull. Circulate and condition hole and mud while reciprocating drill string, pumping at 600 GPM's 1600 PSI, 100 RPM's and 12K free torque. Had several shows of small batches of cutting to surface. Trip in hole from 7112'-10580', observed clean hole conditions. Change out 2 joints of drill pipe as a resuly of washouts. Circulate and condition. Pump a 30 BBL Hi-Visc weighted sweep @ 700 GPM's and 2675 PSI. 130 RPM's, and 14K free torque. Observe increase in cuttings on shakers when sweep came back, and observe hole cleaned up. Slowly TOH on elevators. Observed clean hole, and no issues until 9495' MD and work through tight spot. This is where we drilled a concretion earlier, and hole cleaned up by pumping 600 GPM's and 100 RPM's for one stand. We went back through tight spot with no pump or rotation and observed clean hole. Continue TOH "slowly" on elevators with no more overpull issues. Displacement was correct and no swabbing occured. Con't TOH on elevators to 9356' - 8720" MD -Tight spot, 40k over pull - M/U top drive and BR tight spot 8750' thru 8628' -Run back thru and wipe until clean - PR 600 gpm, 1500 PSI, 80 RPMs. - Con't TOH 8628' to 5560' MD - Spot tube across casing -Pump 60 bbls tube pill and displace back to 1500' in Ann. 57 bbls mud, 3 sx soda ash and 3 drums EMI 920. PR 600 gpm, PP 1500 psi, 100 RPMs. BDTD - FCW "OK" Con't TOH 5560' to 174' MD UD NM Flex Collars and float sub Down Load MWD Printed: 10/28/2005 10:29:27 AM ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name:. ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code Code Phase 7/2/2005 09:15 - 10:30 1.25 DRILL PULD INTRM1 10:30 - 11:00 0.50 CASE OTHR INTRM1 11:00 - 12:00 1.00 CASE RUNC INTRM1 12:00 - 12:45 0.75 CASE RUNC INTRMI 12:45 - 13:30 0.75 CASE SFTY INTRMI 13:30 - 17:30 I 4.001 CASE I RUNC I INTRMI 17:30 - 17:45 0.25 CASE CIRC INTRM1 17:45-20:15 2.50 CASE RUNC INTRM1 20:15 - 21:00 0.75 CASE CIRC INTRMI 21:00 - 23:30 I 2.501 CASE I RUNC I INTRMI 23:30 - 00:00 I 0.501 CASE I CIRC I INTRM1 17/3/2005 100:00 - 01:00 I 1.001 CASE I CIRC I INTRM1 01:00 - 11:30 10.501 CASE I RUNC INTRM1 11:30 - 12:00 0.50 CASE CIRC INTRM1 12:00 - 13:15 1.25 CASE CIRC INTRM1 13:15 - 13:45 0.50 CEMEN RURD INTRM1 13:45 - 17:00 3.25 CEMEN CIRC INTRM1 17:00 - 18:15 I 1.251 CEMENliPUMP INTRM1 18:15 - 20:15 2.00 CEMENI~ DISP I INTRM1 20:15 - 21:15 I 1.001 CEMEN~f RURD I INTRMI Start: 6/20/2005 Rig Release: Rig Number: Page 8 of 33 Spud Date: 6/20/2005 End: 8/13/2005 Group: Description of Operations BK and UD Bit, Geo Pilot, NM GP Flex, GR, Res, PWD and pulser tools. R/U and pull wear bushing -Clean tools from rig floor R/U to run 9 5/8", L80, BCTM Csg Continue to RU to run 9 5/8 csg. PJSM with crew. Discuss safety issues, running procedures and centralizer placement. Make up Shoe jnt and float collarjnt, continue run 9 5/8 casing installing tandem rise centralizers as per plan Circulate BTMS up @ 1933', at 4 BPM - 250 PSI, 6 BPM - 350 PSI, and 8 BPM - 500 PSI PU wt = 106 K So wt = 70 K Continue run 9 5/8 csg form 1933' - 3670', installing- tandem rise centralizers as per plan. Circulate BTMS up @ 3670', at 4 BPM - 350 PSI, 6 BPM - 450 PSI, 8 BPM - 600 PSI PUwt=125K SO wt=66K Continue run 9 5/8 csg form 3670' - 5530'. Shoe depth. Installing tandem rise centralizers as per plan. Circulate and condition mud at the shoe. Pumps at 4 bpm - 400 PSI, 10 BPM - 850 PSI PUwt=155K SO wt=70K Con't to circu and condition @ surface shoe (5530' MD w/ Csg) PR 400 gpm, 95 SPM, PP 850 psi, Up wt 155k, Dn wt 70k. Circu BU f/ 1800' & 3600' to maximize good mud properties of mud in hole while running casing. i Con't running csg 5,530' to 10,530 MD -Fill csg as ran. After every 10 to 12 joints were ran we would circu while coming down slowly with 2 to 3 joints. This kept fresh mud in the well bore so we could run pipe without stopping the job in open hole. PR 190 gpm, PP550. We had a good solid run without any problems. Circu & Condition with Franks tool 1 BUs+-Work pump rate up to 8 bpm slowly. @ 4.5 bpm, Continue Circu & Condition with Franks tool -Work pump rate up to 8 bpm slowly. @ 4.5 bpm, 8.0 BPM - 880 psi Reciprocate string from 10560' -10540' PU WT = 225K SO WT = 60K RD Franks Tool. RU Cement head & Lines. Con't to Circulate & Condition Mud for CMt Job. 80 SPM - 800 PSI. PU WT = 215K SO WT = 55K CMT 9 5/8" Csg -Pump 10 bbl CW100, Test lines to 3500 psi, pump remaining 30 bbls CW100, pump 40 bbls 10.5 ppg MudPush, drop bttm plug, pump 299.4 BBLS of DeepCrete 12.5 PPG tail cmt, Drop Top Plug, kick out plug w/ 3 BBLS of water. Rig displace cmt with 9.1 PPG OBM @ 8 BPM - 425 PSI, reciprocating pipe in 20' strokes. Up WT = 225K Dn WT = 68K. Allow mud push, and cement to turn corner, resume working string. Parked casing in place @ 6200 STKS( 122 bbls cmt around corner), Bump plug at 7976 STKS @ 20:15 HRS. Pressure = 780 PSI. Bring Press up to 1300 PSI, Hold for 5 min. Bleed Press. Final Up Wt = 240K DN WT = 40K, Check floats, OK RD Cement Head, ND and lift BOP stack. Printed: 10/28/2005 10:29:27 AM • • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Start: 6/20/2005 Contractor Name: Rig Release: Rig Name: Rig Number: Sub Date From - To Hours Code Phase Code 7/3/2005 21:15 - 23:30 2.25 WELCT NUND INTRM1 23:30 - 00:00 0.50 WELCT NUND INTRM1 7/4/2005 00:00 - 01:00 1.00 WELCT BOPE INTRM1 01:00 - 03:30 2.50 WELCT BOPE INTRM1 03:30 -.04:00 0.50 WELCT BOPE INTRMI 04:00 - 04:30 0.50 WELCT NUND INTRM1 04:30 - 05:30 1.00 DRILL PULD INTRM1 05:30 - 06:30 1.00 DRILL PULD INTRMI 06:30 - 08:30 2.00 DRILL TRIP INTRMI 08:30 - 12:00 3.50 DRILL TRIP INTRM1 12:00 - 15:30 3.50 DRILL TRIP INTRM1 15:30 - 16:30 1.00 DRILL TRIP INTRMI 16:30 - 16:45 0.25 DRILL OTHR INTRM1 16:45 - 18:15 1.50 RIGMNT RSRV INTRMI 18:15 - 19:00 0.75 RIGMNT RGRP INTRMI 19:00 - 22:30 3.50 DRILL TRIP INTRM1 22:30 - 00:00 1.50 DRILL TRIP INTRM1 7/5/2005 00:00 - 01:00 1.00 DRILL TRIP INTRMI 01:00 - 02:15 1.25 DRILL CIRC INTRMI 02:15 - 03:45 1.50 DRILL TRIP INTRM1 03:45 - 04:00 0.25 DRILL CIRC INTRM1 04:00 - 07:00 3.00 RIGMNT RGRP INTRM1 07:00 - 10:15 3.25 DRILL TRIP INTRM1 Page 9 of 33 Spud Date: 6/20/2005 End: 8/13/2005 Group: Description of Operations Set Emergency slips with 290K pulled on string. = 50K on slips. RU i WACHS pneunatic cutter & make final cut on 9 5/8 csg as per Vetco wellhead rep. POOH, lay down cut off joint. Length = 34.82'. Install 9 5/8 csg packoff. NU BOP stack, and Run in Lock down screws. RU to test packoff. RU & Test 9 5/8 csg packoff to 2400 PSI - 10 min. Test witnessed by Co. Rep RU to 13 3/8" X 9 5/8" Annulus, and press test line. Perform infectivity LOT, observe breakover @ 6.9 bbls and 800 psi (EMW 13.8 ppg). Pump 340 bbls of water annulus flush with a FCP of 775 psi. Recorded on chart. Changed BOP rams to 5" during injection. **"NOTE'"`* Hot Oil came out and pumped freeze protect. Pumped 140 bbls diesel 2413')... Install test plug. RU & test 5" rams and body test.BOP's. 250 psi low / - 3000 psi high Record on chart. Witnessed by Co. Rep & TP RD test equipment. Install W.B - RILDS PU 20 Lo-Tads from beaver slide, set on rig floor. C/O swivel packing on Top Drive Open and inspect Top Drive Saver Sud RIH w/ 60 stands of DP from Derrick., w/mule shoe to 5570' POOH, installing Lo-Tads on DP. 24 Total. Rack in Derrick Continue POOH, installing Lo-Tads on DP back to surface. Rack in derrick PU 18 jnts of 5" HWDP for push pipe, and POOH racking back in derricke Clean floor area of OBM Slip & cut 74' of drilling line. Service TD and draworks. Change out Hydraulic fitting, filter and "O" ring on TD HYD filter housing MU BHA #5. 8 1/2 BIT, Geo-Pilot assmy, GP pony, stabilizer, MWD, Stabilizer, HCIM, Neu/Den, TM, HOC, Float sub, INMFDC. Plug in and download. RIH to 160' and perform shallow hole pulse test. OK 5 BPM, 890 PSI, Hold PJSM, and load sources. PU 2 NMFDC's, 2 stnds of HWDP and jars. RIH picking up new drill pipe. make up, breakout clean and re-make every connection. picked up 24 jnts. Cont RIH from 1,146' with 8 1/2" BHA #5 PU new drill pipe, make up, breakout clean and re-make every connection, RIH to 2,384' Broke in bearings on Geo-pilot and shallow tested MWD, had no pulse on MWD, circ a DP cap and regained pulser Cont RIH from 2,384' with 8 1/2" BHA #5 PU new drill pipe, make up, breakout clean and re-make every connection, RIH to 4,010' (PU a total of 114 jts of Weatherfords 5" S-135 DP) Filled DP & re-checked MWD and ck ok Replaced pipe rotating assembly motor on top drive RIH with DP from derrick with BHA #5 from 4,010' and tagged cmt above FC at 10,483' (FC @ 10,490') 10:15 - 10:45 0.50. DRILL CIRC INTRMI Circ 50 bbls of mud to clear air from DP for csg test 10:45 - 11:30 0.75 CASE DEOT INTRMI RU and tested 9 5/8" csg to 3,000 psi for 30 min 11:30 - 14:45 3.25 CEMEN DSHO INTRM1 Drilled out plugs and Float collar at 10,490', shoe track and float shoe at 10,572' then cleaned out to btm at 10,580', drilled 25' of new hole to 10,605', ADT .26 hrs, drilled out with 5-8K wob, 100 rpm's, 500 gpm at rnncea iuizttrzuvo IU:Zy:Z/AM • ConocoPhillips Alaska Page 10 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common W ell Name: 1 E-117 Spud Date: 6/20/2005 Event Nam e: ROT -D RILLING Start: 6/20/2005 End: 8/13/2005 Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Code Phase Description of Operations Code 7/5/2005 11:30 - 14:45 3.25 CEMEN DSHO INTRM1 2,400 psi and 15-19K ft-Ibs torque, rot wt 105K, up wt 178K, do wt 66K 14:45 - 15:45 1.00 DRILL CIRC INTRMI Circ btms up for LOT, evened MW in and out at 9.1 ppg MOBM, circ hole at 550 gpm, 2,750 psi, 100 rpm's with 14-19K ft-Ibs torque 15:45 - 16:30 0.75 DRILL LOT INTRM1 RU and performed LOT to 14.4 ppg EMW with 964 psi, 9.1 ppg MOBM at 3,511' ND 16:30 - 17:15 0.75 BRILL DRLG PROD Drilled 8 1/2" hole in A2 sand from 10,605' to 10,699' (94') ADT .38 hrs 17:15 - 17:45 0.50 DRILL CIRC PROD Circ hole while geology evaluated logs, circ at 490 gpm, 2,350 psi, 100 rpms and 14-19K ft-Ibs torque 17:45 - 21:30 3.75 DRILL DRLG PROD Directionally drilled 8 1/2" hole in A2 sand lateral with Geo-pilot and Stratasteer tool from 10,699' to 11,143' MD/ 3,493' TVD, (444') ADT 2.16 hrs, 8-15K wob, 100-140 rpm's, 180 spm, 640 gpm, 3,700 psi, off btm torque 15-20K ft-Ibs, on btm 10-20K ft-Ibs, rot wt 104K, up wt 200K, do wt 61 K, 9.0 ppg MOBM, clean hole ECD is 10.7 ppg, ave ECD 11.3 ppg, ave BGG 450 units, max gas 856 units 21:30 - 23:00 .1..50 DRILL . CIRC PROD Circ hole while geology evaluated logs, circ at 550 gpm, 2,775 psi,-.100. rpms and 16K ft-Ibs torque, determined to have drilled out the top of A2 sand at 11,040' MD/3,501' TVD 23:00 - 00:00 1.00 DRILL DRLG PROD Directionally drilled 8 1/2" Hole in A2 sand from 11,143' to 11,189' MD/ 3,493' TVD (46') ADT .29 hrs 7/6/2005 00:00 - 04:00 _4.00 DRILL DRLG PROD Directionally drilled 8 1/2" hole in A2 sand lateral with Geo-pilot and Stratasteer tool from 11,186' to 11,593' MD/ 3,506' TVD, (407') ADT 2.71 hrs, 10-15K wob, 140 rpm's, 180 spm, 640 gpm, 3,700 psi, off btm torque 15-20K ft-Ibs, on btm 10-20K ft-Ibs, rot wt 105K, up wt 205K, do wt 55K, 9.0 ppg MOBM, clean hole ECD is 10.7 ppg, ave ECD 11.5 ppg, ave BGG 100 units, max gas 537 units, NOTE decision was made to sidetrack well since drilling out of zone from 11,040' MD/ 3,501' TVD to 11,400' MD/ 3,498' TVD (360' total) 04:00 - 05:00 1.00 DRILL REAM PROD Backreamed out at Drlg rate from 11,593' to 11,382' and cont to Pump out of hole to 10,820', pumped out at 160 gpm at 500 psi, st wt up 200K, do wt 60K 05:00 - 08:00 3.00 DRILL DRLG PROD Troughed well to preform OH sidetrack from 10,820' to 10,550' then time drilled from 10,850' to 10,860' and sidetracked well. 08:00 - 15:30 7.50 DRILL DRLG PROD Directionally drilled 8 1/2" hole in A2 sand lateral. with Geo-pilot and Stratasteer tool from 10,860' to 11,593' MD/ 3,513' TVD, (733') ADT 5.8 hrs, 10-15K wob, 140 rpm's, 180 spm, 640 gpm, 3,700 psi, off btm torque 14-20K ft-Ibs, on btm 9-14K ft-Ibs, rot wt 104K, up wt 221 K, do wt 54K, 9.0+ ppg MOBM, clean hole ECD is 10.7 ppg, ave ECD 11.8 ppg, ave BGG 120 units, max gas 581 units 15:30 - 00:00 8.50 DRILL DRLG PROD Directionally drilled 8 1/2" hole in A2 sand lateral with Geo-pilot and Stratasteer tool from 10,860' to 11,593' MD13,513' TVD, (99T) ADT 6.1 hrs, 10-15K wob, 140 rpm's, 180 spm, 640 gpm, 3,750 psi, off btm torque 15-20K ft-Ibs, on btm 8-14K ft-Ibs, rot wt 105K, up wt 220K, do wt 55K, 9.0 ppg MOBM, clean hole ECD is 10.8 ppg, ave ECD 11.7 ppg, ave BGG 140 units, max gas 600 units 7/7/2005 00:00 - 06:00 6.00 DRILL DRLG PROD Directionally drilled 8 1/2" hole in A2 sand lateral with Geo-pilot and Stratasteer tool from 12590' to 13245' MD/ 3,479' TVD, (655') ADT 4.52 hrs, 5-15K wob, 140 rpm's, 180 spm, 640 gpm, 3,800 psi, off btm torque 16-20K ft-Ibs, on btm 15-16K ft-Ibs, rot wt 104K, up wt 220K, do wt 50K, 9.0+ ppg MOBM, clean hole ECD is 10.7 ppg, ave ECD 12.0 ppg, ave BGG 54 units, max gas 675 units 06:00 - 06:45 0.75 DRILL CIRC PROD. Stop Drilling - PU and circu off bttm to evaluate logs. 06:45 - 10:15 3.50 DRILL DRLG PROD Directionally drilled 8.1/2" hole in A2 sand lateral with Geo-pilot and Stratasteer tool from 13245' to 13610' MD/ 3,485' TVD, (365') ADT 1.82 rnntea: ~wzarzuua 7U:Y`J:Z! HM • ConocoPhillips Alaska Page 11 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code Code Phase 7/7/2005 06:45 - 10:15 3.50 DRILL DRLG PROD 10:15 - 10:45 0.50 DRILL CIRC PROD 10:45 - 12:00 1.251 DRILL I DRLG PROD 12:00 - 13:45 1.75 DRILL DRLG PROD 13:45 - 14:15 0.501 DRILL I CIRC PROD 14:15 - 21:30 7.25 DRILL ~ DRLG PROD 21:30 - 00:00 2.501 RIGMNT RGRP PROD 7/8/2005 00:00 - 12:00 12.00 RIGMNT RGRP PROD 12:00 - 14:15 2.25 RIGMNT RGRP PROD 14:15 - 16:00 1.75 RIGMNT RGRP PROD 16:00 - 17:00 1.00 RIGMNT RGRP PROD 17:00 -00:00 ~ 7.00 ~ DRILL DRLG PROD 7/9/2005 00:00 - 06:00 6.00 ~ DRILL ~ DRLG ~ PROD Spud Date: 6/20/2005 Start: 6/20/2005 End: 8!13/2005 Rig Release: Group: Rig Number. Description of Operations hrs, 5-15K wob, 140 rpm's, 180 spm, 640 gpm, 3,800 psi, off btm torque 16-20K ft-Ibs, on btm 15-16K ft-Ibs, rot wt 104K, up wt 220K, do wt 50K, 9.0+ ppg MOBM, clean hole ECD is 10.7 ppg, ave ECD 12.0 ppg, ave BGG 54 units, max gas 675 units. While drilling do std pumped Wt! Hi Vis sweep. Circu weigthed sweep out of hole -Saw 35% increase in cutting when sweep came to surface Directionally drilled 8 1/2" hole in A2 sand lateral with Geo-pilot and Stratasteer tool from 13610' to 13703' MD/ 3,487' TVD, (93') ADT .59 hrs, 5-20K wob, 140 rpm's, 180 spm, 640 gpm, 3,850 psi, off btm torque 16-20K ft-Ibs, on btm 15-16K ft-Ibs, rot wt 104K, up wt 220K, do wt 50K, 9.0+ ppg MOBM, clean hole ECD is 10.7 ppg, ave ECD 12.0 ppg, ave BGG 70 units, max gas 470 units Directionally drilled 8 1/2" hole in AZ sand lateral with Geo-pilot and Stratasteer tool from 13703' to 13931' MD/ 3,490' TVD, (228') ADT 1.34 hrs, 5-20K wob, 140 rpm's, 172 spm, 610 gpm, 3,850 psi, off btm torque 20-22K ft-Ibs, orr btm 15-16K ft-fbs, rot wt 100K, up wt 245K, do wt 40K, 9.0+ ppg MOBM, clean hole ECD is 10.7 ppg, ave ECD 12.1 ppg, ave BGG 55 units, max gas 275 units Stop Drilling - PU and circu off bttm to evaluate Iogs.PR 173 SPM, 615 'GPM, PP 3700 psi, 130 RPMs Directionally drilled 8 1/2" hole in A2 sand lateral with Geo-pilot and Stratasteer tool from 13931' to 14660' MD/ 3,448' TVD, (729') ADT 4.67 hrs, 5-20K wob, 140 rpm's, 175 spm, 620 gpm, 3,850 psi, off btm torque 20-22K ft-Ibs, on btm 15-16K ft-Ibs, rot wt 100K, up wt 245K, do wt 40K, 9.0+ ppg MOBM, clean hole ECD is 10.7 ppg, ave ECD 12.1 ppg, ave BGG 55 units, max gas 275 units ** NOTE** @ 9:30 the #2 mud pump started leaking at the cyclinder head. Pump shut down for repairs. We cannot drill with 1 pump. While mud pump is repaired we will BROOH to shoe. TIH and be ready to drill when pump is repaired. BROOH PR 110 SPM, 130 RPMs, BR speed slow to allow hole to clean up Slowly BROOH 14,215'to 11,756' MD, PR 103 spm, 362 gpm, PP 1360. psi, RPMs 120, Troq 16-24k Moderate show of cutting at shakers - 10-15 % above drilling rate. Some slight pack off problems sceen if BR rate was to FAST. BGG 89 units Con't to slowly BROOH 11,756' to 11,510' MD, PR 105 spm, 374 gpm, PP 1400 psi, RPMs 120, Troq 15-19k. BGG 68 units TIH to 14,573' MD, Dn wt 60k, Up wt 185k - No problems TIH Wash & Ream 14,573 to 14,660' MD -Run in Pump #2 and ck for leaks - Re-Torq bolts after pressure run in: PR 168 spm, 597 GPM, PP 3700 psi, RPMs 120, Torq 18k Directionally drilled 8 1/2" hole in A2 sand lateral with Geo-pilot and Stratasteer tool from 14660' to 15303' MD/ 3,427' TVD, (643') ADT 4.63 hrs, 5-15K wob, 120 rpm's, 164 spm, 585 gpm, 3,850 psi, off btm torque 17-23K ft-Ibs, on btm 16K ft-Ibs, rot wt 112K, up wt 267K, do wt 49K, 9.0+ ppg MOBM, clean hole ECD is 10.7 ppg, ave ECD 11.8 ppg, ave BGG 75 units, max gas 310 units Directionally drilled 8 1/2" hole in A2 sand lateral with Geo-pilot and Stratasteer tool from 15,303' to 15,774' MD/ 3,415' TVD, (T. D.) (471') ADT 3.6 hrs, 5-12K wob, 120 rpm's, 163 spm, 580 gpm, 3,975 .psi, off btm torque 20-23K ft-Ibs, on btm 17-18K ft-Ibs, rot wt 125K, up wt 260K, rrinteo: ~urzor[uvo ~u:za:u rm • • ConocoPhillips Alaska Page 12 of 33 'I Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code Code Phase 7/9/2005 00:00 - 06:00 I 6.00 I DRILL ~DRLG PROD 06:00 - 06:15 0.25 DRILL OBSV PROD 06:15 - 09:30 3.25 DRILL WIPR PROD 17/10/2005 09:30 - 10:45 I 1.251 DRILL I WIPR I PROD 110:15 - 13:30 2.25 ~ DRIMNT C RCP I PROD 13:30 - 15:15 I 1.751 DRILL I CIRC I PROD 15:15 - 15:30 0.25 DRILL OBSV PROD 15:30 - 21:00 5.50 DRILL TRIP PROD 21:00 - 21:15 0.25 DRILL OBSV PROD 21:15 - 00:00 2.75 DRILL TRIP PROD 00:00 - 02:00 2.00 DRILL TRIP PROD 02:00 - 02:30 0.50 DRILL PULD PROD 02:30 - 05:30 3.00 DRILL PULD PROD 05:30 - 06:30 1.00 DRILL PULD PROD 06:30 - 07:00 0.50 CASE RURD CMPLTN 07:00 - 07:30 0.50 CASE SFTY CMPLTN 07:30 - 11:15 3.75 CASE PULR CMPLTN 11:15 - 12:30 I 1.25 I CASE I PULR I CMPLTN 12:30 - 16:00 I 3.501 CASE I RUNL I CMPLTN 16:00 - 16:30 I 0.501 CASE I CIRC I CMPLTN 16:30 - 17:30 I 1.001 CASE RUNL CMPLTN 17:30 - 20:00 2.50 CASE RUNL CMPLTN 20:00 - 22:15 2.25 CASE RUNL CMPLTN 22:15 - 23:30 1.25 CASE RUNL CMPLTN Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number. Description of Operations do wt 70K, 9.0-ppg MOBM, clean hole ECD is 10.7 ppg, ave ECD 12.0 ppg, ave BGG 50 units Monitored well-static Backreamed out of hole from 15,774' to 14,600' with no problems, BROOH to previous trip at 120 rpm's, 130 spm, 462 gpm at 2,500 psi, RIH from 14,600' to btm at 15,774' with no problems, pumped weighted hi vis weep and #2 mud pump went down Circu & Condition hole -Changed out valve and seat on #2 mud pump Cont to circ out weighted hi vis sweep and circ an additional btms up and was clean at shakers, circ hole clean at 560 gpm at 3,900 psi, 140 rpm's with 18K ft-Ibs torque Changed hole over from 9.0 ppg MOBM to 9.0 ppg SFMOBM, displaced hole out at 140 rpm's with 25K ft-Ibs torque and 547 gpm at 3,775- psi, rot wt 125K, up wt 295K, do wt 38K Monitored well-static, took SPR's POOH wet on elevators from 15,774' to 10,484' (Csg Shoe @ 10,572') with no problems Monitored well at shoe-static, dropped 2 3/8" rabbit on a wire Cont to POOH wet from 10,484' to 5,496' Con't POOH from 5,496 to BHA at 378', UD 2- 8.5" ghost reamers from string POOH from 378' to 150', LD 5 jts HWDP, Jars and 2 NM FDCs Held PJSM and remove radioactive sources then down Loaded MWD, talc fill on trip out of hole 141 bbls, actual fill 154 bbls of 9.0 ppg SFMOBM Fin POOH and LD BHA #5, cleaned rig floor RU Doyon's 5 1/2" liner running tools Held PJSM and reviewed liner detail and discuss know hazards, Stressed "Stay Focused" on task at hand. PU and RIH with 5 1/2", 15.5#, L-80, BTCM Liner per well program to 5,311' (125 Jts total), ran 5 1/2" ROT silver bullet guide shoe with no float, ran a total of 53 jts (2,262') of 5 1 /2" 15.5#, L-80, BTCM blank liner and ran 72 jts (3,027') of 5 1/2", 15.5# L-80 BTCM slotted liner per detail sheet, ran 124 - 5 1/2" x 8 1/2" spiralglide centralizers 1/jt, jts #2 thru # 125, ran 12 constrictor packers placed on blank liner to cover 'shale sections. Micro Slots on liner 120 - 1.5" long X .018" @ 4 rows per/ft. MU Baker 190-47 seal bore ext, 9 5/8" x 7" Flexlock liner hanger with, "RS" pack-off seal nipple and "HRD" ZXP liner top packer and RIH to 5,369", st wt up 60K, do wt 57K, RD liner running tools RIH with 5 1/2" liner on DP from 5,369' to 10,554', (csg shoe @ 10,572') RIH slow 30-45 fpm to minimize surge with large OD packer. Circ a DP volume at csg shoe, circ at 300 gpm at 500 psi, st wt up 163K, do wt 53K, set torque limiter on top drive at 8,500 ft-Ibs and attempted to rotate liner and would not rotate RIH with liner from 10,554' to 11,950' when liner began floating and down wt was running 45-35K (blk wt), up wt 175K Worked liner down from 11,950' to 13,366', having to work weight down by reciprocating liner. RIH with liner from 13,366' to 14,706', RIH with 14 stds of HWDP from derrick and MU 1-lo-tad per std while RIH RIH with liner from 14,706' to 15,266', RIH PU 2 additional stds of HWDP with Lo-Tads and 4 stds of 6 3/4" Dc's from pipe shed, st wt up Printed: 10!28/2005 10:29:27 AM • ConocoPhillips Alaska Page 13 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To 7/10/2005 22:15 - 23:30 23:30 - 00:00 7/11/2005 00:00 - 00:15 00:15 - 01:45 Hours Code Code Phase 1.251 CASE RUNL CMPLTN 0.50 CASE RUNL CMPLTN 0.25 CASE RUNL CMPLTN 1.50 CASE OTHR CMPLTN 01:45 - 02:00 02:00 - 02:15 02:15 - 03:30 03:30 - 03:45 03:45 - 10:00 10:00 - 11:00 0.25 ~ DRILL TDR PT I CMPLTN 1.251 DRILL ICIRC (CMPLTN 0.25 DRILL `OBSV CMPLTN 6.25 DRILL (TRIP CMPLTN 1.001 DRILL I PULD I CMPLTN 11:00 - 11:15 0.25 LOG SFTY CMPLTN 11:15 - 12:15 1.00 LOG RURD CMPLTN 12:15 - 20:00 7.75 LOG ELOG CMPLTN 20:00 - 22:00 I 2.00 I LOG I ELOG I CMPLTN 22:00 - 23:00 1.00 LOG RURD CMPLTN 23:00 - 23:30 0.50 WELCT OTHR CMPLTN 23:30 - 00:00 0.50 WELCT BOPE CMPLTN 7/12/2005 00:00 - 05:15 5.25 WELCT BOPE CMPLTN 05:15 - 07:00 1.75 RIGMNT RSRV CMPLTN 07:00 - 08:00 1.00 RIGMNT RSRV CMPLTN 08:00 - 08:30 0.50 RIGMNT RSRV CMPLTN 08:30 - 13:00 4.50 WINDO ULD PROD2 Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2Q05 Rig Release: Group: Rig Number: Description of Operations 270K, do wt 55K RIH from 15,266' to 15,742' with slick DP from derrick, st wt up 280K, do wt 40K, NOTE: Ran liner prior to running USIT bond log due to no tractor or personnel on slope Fin RIH with liner from 15,742' to 15,752' and placed A2 sand liner on depth with TOL at 10,382' and shoe at 15,752, st wt up 280K, do wt 40K Dropped 1 3/4" ball and pumped down to seat, initial rate of 4 1/2" bpm at 550 psi, slowed to 2 bpm at 200 psi and with ball on seat pressured up to 1,700 psi, slacked off on liner and hanger wasn't set, pressured up to 2,150 psi and slacked off and hanger hadn't set, pressured up to 2,200 psi and slacked off to blk wt and hanger was set. Pressured up to 3,000 psi and saw ZXP packer set then pressured up to 4,000 psi to release HR running tool. Set TOL at 10,382' MD/3,486' TVD with guide shoe at 15,752' Pressure tested ZXP pkr and annulus to 1,000 psi for 5 min, good test PU 245K and was released from running tool, LD 1-single POOH to 10,350' Circ btms up at 10,350' with no gas at btms up, circ at 295 gpm at 950 Psi Monitored well-static, took SPR's POOH with HR liner running tool from 10,350' to 50', while POOH LD 4 stds of 6 3/4" DC's and 2 stds of HWDP with Lo-Tads used to run liner, removed 4 Lo-Tads from HWDP leaving 10 stds of HWDP with Lo-Tads in the derrick Made service breaks on liner running tool and LD same, cleared and c{eaned rig f{oor, calc fill on trip out of hole 101 bbls, actual fill 111 bbls Held PJSM with rig crew and Schlumberger wireline (SWS) RU SWS wireline and scheaves, MU USIT logging tools with SWS 2 1/8" tractor tool RIH with USIT logging tools to 2,080' and tool stopped, powered up SWS tractor tool and cont RIH, tractor and tools stopped at 10,180' and was unable to go deeper, tool was RIH on .46" line and possibly stopped due to weight of line and tool string Ran USIT bond log from 10,180' to 5,400' then POOH with logging tools, had good cement bond from 10,180' to 5,670' with some cement shown up to 5,520' (13 3/8" Shoe @ 5,546') LD logging tools and RD SWS Pulled wear bushing RU to test BOP's Tested BOPE, tested rams, valves and manifold to 250 psi low and 3,000 psi high, tested annular to 250 psi then 2,800 psi, Lou Grimaldi with AOGCC witnessed testing, RD test equip. and installed wear bushing Changed out 4 1/2" IF saver sub on top drive Slip and cut 60' of drlg line Serviced top drive and greased drawworks PU & MU Whipstock milling assembly BHA #6 and RIH to 870', MU milling assembly and LD, MU seal assembly, locator sub, unloader sub, then PU 20 jts of 5" DP and 2-DP pup jts for spacing out and RIH with seal assembly, MU whipstock and milling assembly with MWD, oriented and uploaded MWD, RIH PU 3 -6 3/4" DC's, RIH to 870', st wt up 65K, do wt 60K Nflfltetl: 1U2tl/jUUb IV:Yy:L/ AM • • ConocoPhillips Alaska Page 14 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From-To Hours Code Code ' Phase 7/12/2005 13:00 - 15:00 2.00 WINDO RIP PROD2 15:00 - 15:15 0.25 WINDO IRC PROD2 15:15 - 17:00 1.75 WINDO RIP PROD2 17:00 - 17:45 0.751 WINDOV(IOTHR PROD2 17:45 - 20:15 2.50 WINDORIP PROD2 20:15 - 21:00 0.75 WINDO IRC PROD2 21:00 - 22:00 I 1.001 WINDOWTRIP I PROD2 22:00 - 23:30 1.50 WINDO~ETW PROD2 23:30 - 00:00 I 0.501 WINDOVj/CIRC PROD2 17/13/2005 100:00 - 00:45 0.751 WINDOVIfCIRC I PROD2 00:45 - 08:30 I 7.751 WINDOWSTWP I PROD2 08:30 - 09:30 I 1.00 WINDOV'i1CIRC PROD2 09:30 - 09:45 0.25 WINDO THR PROD2 09:45 - 13:45 4.00 WINDO RIP PROD2 13:45 - 14:45 1.00 WINDO ULD PROD2 14:45 - 16:00 I 1.251 WINDOWOTHR I PROD2 16:00 - 18:00 I 2.00 DRILL PULD PROD2 18:00 - 21:45 3.75 DRILL TRIP PROD2 21:45 - 22:00 I 0.251 DRILL REAM PROD2 22:00 - 00:00 I 2.001 DRILL I DRLG { PROD2 17/14/2005 100:00 - 02:30 I 2.501 DRILL I DRLG I PROD2 Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations RIH slow with whipstock assembly BHA #6 from 870' to 3,158' Shallow tested MWD at 3,158' at 460 gpm at 880 psi and tool ck ok RIH slow with whipstock assembly BHA #6 from 3,158' to 6,250' when highline power went down Highline power to 1 E pad went down at 17:00 hrs, began to bring rig motors on line when highline power was restored at 17:45 RIH slow with whipstock from 6,250' to 9,335' Made MADD pass from 9,335' to 9,241' (sensor depth 8,602' to 8,508') and correlated MWD to K-13, no corr. circ at 500 gpm at 2,050 psi, st wt up 193K, do wt 58K Cont to RIH with whipstock from 9,241' to 10,310', st wt up 220K, do wt 65K Oriented whipstock 13 deg left of high side, RIH from 10310' and tagged TOL at 10,382', set whipstock and sheared off from same, top of whipstock at 9,706' MD/3,401' TVD, RIH with whipstock milling assembly with 24 stds of slick 5" DP, 60 stds of 5" DP with Lo-tads, 14 stds of 5" HWDP (10 W/Lo-Tads), 1 std and a double of 5" DP Began to displace hole over from 9.0 ppg SFMOBM to re-conditioned 9.0 ppg MOBM, circ hole at 500 gpm at 2,550 psi Fin displacing hole over from 9.0 ppg SFMOBM to 9.0 ppg MOBM,circ at 465 gpm at 2,100 psi Milled 8 1/2" window in "B" sand lateral from 9,706' to 9,722', cont to mill to 9,738' MD/ 3,405' TVD, (32' total W/5' of gauge hole out of window) milled at 4-7K wob, 70-90 rpm's, 450 gpm at 1,950 psi, on btm torque 13-20K ft-Ibs, rot wt 120K, up wt 195K, do wt 95K Pumped 30 bbl weighted hi vis sweep and circ hole clean while working mills thru window, circ hole at 550 gpm, 2,800 psi and 100 rpm's, rot wt 120K, up wt 195K, do wt 95K Monitored well-static, pumped dry job POOH with BHA #6 from 9,738' to BHA at 190' POOH LD milling BHA #6, LD 3-6 3/4" dc's, bumper sub, MWD and mills, gauged mills and upper mill was in gauge, talc fill on trip out of hole 90 bbls, actual fill 102 bbls, cleared rig floor Pulled wear bushing and flushed out BOP stack after milling window, re-installed wear bushing MU 8 1/2" BHA #7 RIH to 346', MU RR 8 1/2" insert bit on 7" motor with 1.5 deg bend, float sub and MWD, uploaded MWD and RIH PU 3-NM Flex dc's, HWDP and jars from pipe shed while RIH to 346' RIH with BHA #7 from 346' to 9,597', shallow tested MWD at 2,726' ..while filling DP and tool ck ok Oriented motor at 9,597' and RIH thru window at 9,706' to 9,726' with no problems, washed down from 9,726' to btm at 9,738', washed down at 450 gpm, 2,100 psi, st wt up 144K, do wt 70K Directionally drilled 8 1/2" hole with motor from 9,738' to 9,769' MD/ 3,409' ND (31'), ART -0-, AST 1.33 hrs, 25 K wob, 126 spm, 450 gpm, 2,300 psi st wt up 144K, do wt 70K, drilling on concretion from 9,759' to 9, 769' Directionally drilled 8 1/2" hole with mud motor from 9,769' to 9,849' MD/ 3,409' TVD (80'), ART .30 hrs, AST 1.74 hrs, 25-28K wob, 60 rpm's, 128 spm, 455 gpm, 2,200 psi, rot wt 95K, up wt 175K, do wt 75K, drilled on concretions from 9,769' to 9,779' (10'), 9,788 to 9,790' (2'), 9,794' to 9,795' (1') and 9,848' to 9,849' (1'), drilled deep enough to line well up in middle of sand and to get Geo-Pilot out into open hole, did Printed: 10/28!2005 10:29:27 AM • ConocoPhillips Alaska Page 15 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common W ell Name: 1E-197 Spud Date: 6/20/2005 Event Nam e: ROT -D RILLING Start: 6/20/2005 End: 8/13/2005 Contractor Name: Rig Release: .Group: Rig Name: Rig Number: Date -From - To Hours Code Phase ' Description of Operations Code , 7/14/2005 00:00 - 02:30 2.50 DRILL DRLG PROD2 not drill out of zone. 02:30 - 02:45 0.25 DRILL TRIP PROD2 Pumped out of hole from 9,849' to 9,725' then POOH thru window to 9,694' to above top of whipstock, pumped out at 450 gpm at 2,150 psi, no problems pulling thru window 02:45 - 03:30 0.75 DRILL CIRC PROD2 Circ btms up at 9,694' and was clean at shakers, Circ at 600 gpm at 3,350 psi and 60 rpm's 03:30 - 03:45 0.25 DRILL OBSV PROD2 Monitored well-static, pumped dry job 03:45 - 07:15 3.50 DRILL TRIP PROD2 POOH with BHA #7 from 9,694' to BHA at 346' 07:15 - 08:30 1.25 DRILL PULD PROD2 LD BHA #7, stood back HWDP, jars and NM flex dc's, LD MWD, motor and bit, cleared rig floor, talc fill on trip out of hole 83 bbls, actual fill 92 bbls 08:30 - 12:00 3.50 DRILL PULD PROD2 PU 8~ MU 8 1/2" BHA #8 &RIH to 384', MU new 8 1/2 PDC bit, GEO-Pilot, MWD with Stratasteer, GR/Res/PWD//Neutron/density, uploaded MWD, held PJSM and loaded radioactive sources, cont RIH with NM flex dc's, HWDP and jars to 384' 12:00 - 16:00 4.00 DRILL PULD PROD2 RIH with BHA #8 from 384' to btm at 9,849', no problems going thru window or RIH to btm, PU 2 ghost reamers and placed 1-962' back from the bit and 2nd one 1,825' back from the bit 16:00 - 00:00 8.00 DRILL DRLG PROD2 Directionally drilled 8 1/2" hole in "B" sand lateral with Geo-pilot and Stratasteer tool from 9,849' to 10,110' MD/ 3,390' TVD, (261') ADT 3.72 hrs, 7-20K wob, 90-120 rpm's, 169 spm, 600 gpm at 3,100 psi, off btm torque 14-20K ft-Ibs, on btm torque 14-18K ft-Ibs, rot wt 102K, up wt 190K,dn wt 62K, 9.0 ppg MOBM, ave ECD 10.9 ppg, ave BGG 60 units, max gas 480 units. Drilled thru concretions from 9,849' to 9,862' (13'), 9,869' to 9,888' (19'), 9,966' to 9,979' (13') and 9,988' to to 10,009' (21') 7/15/2005 00:00 - 12:00 12.00 DRILL DRLG PROD2 Directionally drilled 8 1/2" hole in "B" sand lateral with Geo-pilot and Stratasteer tool from 10,110' to 10,494' MD/ 3,381' TVD, (384') ADT 10.21 hrs, 8-20K wob, 90-140 rpm's, 600 to 640 gpm at 3,100 to 3,300 psi, off btm torque 14-23K ft-Ibs, on btm torque 13-20K ft-Ibs, rot wt 104K, up wt 195K,dn wt 56K, 9.0 ppg MOBM, ave ECD 11.0 ppg, ave BGG 100 units, max gas 572 units. Drilled thru concretions from 10,128'-10,132' (4'), 10,158'-10,180' (22'), 10,182'-10,197' (15'), 10,271'-10,281' (10'), 10,295'-10,309' (14'), 10,350'-10,358' (8'), 10,389'-10,407' (18'), 10,425'-10,445', (20') 10,478'-10,490' (12') 12:00 - 00:00 12.00 DRILL DRLG PROD2 Directionally drilled 8 1/2" hole in "B" sand lateral with Geo-pilot and Stratasteer tool from 10,494' to 11,481' MD/ 3,356' TVD, (987') ADT 9.24 hrs, 5-20K wob, 90-140 rpm's, 660 gpm at 3,750 psi, off btm torque 15-20K ft-Ibs, on btm torque 12-20K ft-Ibs, rot wt 102K, up wt 205K,dn wt 52K, 9.1 ppg MOBM, ave ECD 11.8 ppg, ave BGG 90 units, max gas 330 units. Drilled thru concretions from 10,998'-11,018' (20'), 11,070'-11,076' (6'), 11,081'-11,089' (8'), 11,102'-11,109' (7'), 11,121'-11,126' (5'), 11,161'-11,163' (2'), 11,191'-11,193' (2') 7/16/2005 00:00 - 03:15 3.25 DRILL DRLG PROD2 Directionally drilled 8 1/2" hole in "B" sand lateral with Geo-pilot and Stratasteer tool from 11,481' to 11,853' MD/ 3,342' TVD, (372') ADT 1.82 hrs, 12-19K wob, 110-140 rpm's, 660 gpm at 3,700 psi, off btm torque 15-20K ft-Ibs, on btm torque 13-16K ft-Ibs, rot wt 100K, up wt 200K,dn wt 50K, 9.1 ppg MOBM, ave ECD 11.8 ppg, ave BGG 90 units, max gas 162 units. No concretions 03:15 - 04:30 1.25 DRILL CIRC PROD2 Circ hole and worked pipe while geologist evaluated logs, appears to i either have crossed fault orjust drilled out of zone at 11,766' MD/3,34T TVD, decision was made to sidetrack well 04:30 - 05:00 0.50 DRILL REAM PROD2 Backreamed out of hole from 11,853' to 11,650', backreamed out at 140 rpm's, 600 gpm at 3,200 psi Printed: 10/ZS2UUS 10292/ AM • • ConocoPhillips Alaska Page 16 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code Sub Phase Code 7/16/2005 05:00 - 07:45 2.75 DRILL DRLG PROD2 07:45 - 11:15 3.50 DRILL DRLG PROD2 11:15 - 00:00 12.75 DRILL DRLG PROD2 17/17/2005 00:00 - 12:00 12.00 DRILL DRLG PROD2 12:00 - 22:45 10.751 DRILL ~ DRLG ~ PROD2 22:45 - 00:00 17/18/2005 100:00 - 00:45 1.25 RIGMNTI RGRP ~ PROD2 0.751 RIGMNTI RGRP I PROD2 010:00-102:00 110.00 DRIMNTIDRLH PROD2 12:00 - 18:45 ~ 6.75 ~ DRILL ~ DRLH ~ PROD2 Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations Time drilled and sidetracked well from 11,650' to 11,666', ave 5'/hr with 135 rpm's, 610 gpm at 3,250', sidetracked well at 11,650' Directionally drilled 8 1/2" hole from 11,666' to 11,853' MD/ 3,354' TVD i ADT 1.31 hrs. Directionally drilled 8 1/2" hole in "B" sand lateral with Geo-pilot and Stratasteer tool from 11,853' to 12,769' MD/ 3,342' TVD, (916') ADT 9.74 hrs, 8-20K wob, 110-140 rpm's, 660 gpm at 3,825 psi, off btm torque 15-20K ft-Ibs, on btm torque 13-14K ft-Ibs, rot wt 98K, up wt 204K,dn wt 47K, 9.05 ppg MOBM, ave ECD 11.8 ppg, ave BGG 100 units, max gas 753 units. Drilled thru concretions at 11,233'-11,239' (6'), 11,830'-11,835' (4'), 11,956'-11,962' (6'), 11,969'-12,006' (37'), 12,046'-12,063' (17'), 12,130'-12,138' (8') Directionally drilled 8 1/2" hole in "B" sand lateral with Geo-pilot. and Stratasteer tool from 12,769' to 13,279' MD/ 3,328' TVD, (510') ADT 10.55 hrs, 10-21 K wob, 110-135 rpm's, 655 gpm at 3,825 psi, off btm torque 17-18K ft-Ibs, on btm torque 13-15K ft-Ibs, rot wt 99K, up wt 200K,dn wt 47K, 9.0 ppg MOBM, ave ECD 11.7 ppg, ave BGG 70 units, max gas 197 units. Drilled thru concretions at 12,768'-12,772' (4'), 12,837'-12843' (6'), 12,898'-121,913' (15'),.12,948'-12,962' (14'), 12,969'-12,980' (11'), 13,028'-13,034' (6'), 13,145'-13,150' (5') 13,176'-13,183' (7'), 13,201'-13,219' (18')13,241'-13,246' (5'), 13,258'-13,268' (10'), 13,277'-13,281' (4') Directionally drilled 8 1/2" hole from 13,279' to 14,085' MD/ 3,306' TVD, (806') ADT 8.4 hrs, 5-21 K wob, 90-135 rpm's, 647 gpm at 3,900 psi, off btm torque 17-20K ft-ibs, on btm torque 15-16K ft-Ibs, rot wt 97K, up wt 202K,dn wt 37K, 9.0 ppg MOBM, ave ECD 11.9 ppg, max 12.0 ppg, ave BGG 80 units, max gas 253 units. Drilled thru concretions at .13,394'-13,400' (6'), 13,485'-13,490' (5'), 13,510'-13,520' (10'), 13,687'-13,700' (13'), 13,790'-13,796' (6'), 13,804'-13,825' (21'), 13,831'-13,835' (4'), 13,844'-13,846' (2'), 13,923'-13,931' (8'), 13,981'-14,000' (19'). NOTE: 4" Demco valve on kill line failed causing a spill inside rigs secondary containment, spilled was approx 1/2 bbl with 1 gal leaking outside of rig onto side of the rig and matting board, notified security and spill was cleaned up Worked pipe out of hole slowly from 14,085' to 13,880' while changing out O-ring on 4" Demco valve on kill line, tested and still leaked, began to RU 2" line to circ hole while cont to repair valve. NOTE: Had a medical emergency with a Doyon employee after he had gone off tour, hand was sent to KOC medic then to Anchorage for further evaluation Changed out valve stem (bonnett) on 4" kill line valve and tested, ck ok, circ hole thru 2" line at 3 bpm at 270 psi while slowly working pipe at 13,880' while repairing valve RIH from 13,880' to btm at 14,085' Directionally drilled 8 1/2" hole in "B" sand lateral with Geo-pilot and Stratasteer tool from 14,085' to 14,336' MD/ 3,299' TVD, (251') ADT 9.3 hrs, 10-22K wob, 90-135 rpm's, 642 gpm at 3,800 psi, off btm torque 18-20K ft-Ibs, on btm torque 16-17K ft-Ibs, rot wt 95K, up wt 205K,dn wt 35-40K, 9.0 ppg MOBM, ave ECD 11.9 ppg, ave BGG 50 units, max gas 132 units. Drilled thru concretions at 14,118'-14,122' (4'), 14,193'-14,205' (12'), 14,201'-14,221' (20'), 14,246'-14,259' (13'), 14,268'-14,278' (10'), 14,292'-14,311' (19'), 14,313'-14,343' (30') Directionally drilled 8 1/2" hole in from 14,336' to 14,566' MD/ 3,294' Printed: 10/282005 10:29:27 AM ConocoPhillips Alaska Page 17 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common WeA Name: 1E-117 Spud Date: 6/20/2005 Event Name: ROT -DRILLING Start: 6/20/2005 End: 8/13/2005 Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date .From - To Hours Code Code Phase 7/18/2005 112:00 - 18:45 I 6.75 I DRILL I DRLH I PROD2 20:00 - 00:00 4.00 DRILL ITORIPV PROD2 17/19/2005 100:00 - 05:00 I 5.001 DRILL I TRIP I PROD2 05:00 - 06:00 1.00 DRILL TRIP PROD2 06:00 - 10:30 4.50 DRILL TRIP PROD2 10:30 - 11:00 0.50 DRILL PULD PROD2 11:00 - 12:00 1.00 DRILL PULD PROD2 12:00 - 14:15 2.25 DRILL PULD PROD2 14:15 - 17:15 3.00 DRILL PULD PROD2 17:15 - 21:30 4.25 DRILL TRIP PROD2 21:30 - 21:45 0.25 DRILL TRIP PROD2 21:45 - 23:15 1.50 RIGMNT RSRV PROD2 23:15 - 00:00 0.75 DRILL TRIP PROD2 7/20/2005 00:00 - 00:30 0.50 DRILL TRIP PROD2 00:30 - 02:30 I 2.00 I DRILL I OTHR I PROD2 02:30 - 03:00 0.50 DRILL TRIP PROD2 03:00 - 09:30 6.50 DRILL REAM PROD2 09:30 - 12:00 2.50 DRILL DRLH PROD2 Description of Operations TVD, (230') ADT 5.73 hrs, 10-22K wob, 90-135 rpm's, 642 gpm at 3,800 psi, off btm torque 18-20K ft-Ibs, on btm torque 16-17K ft-Ibs, rot wt 95K, up wt 205K,dn wt 35-40K, 9.0 ppg MOBM, ave ECD 11.9 ppg, ave BGG 50 units, max gas 132 units. Drilled thru concretions at 14,394'-14,402' (8'), 14,480'-14,496' (16'), 14,531'-14,539' (8'), 14,541'-14,552' (11'), last 3 concretions from ROP only no logs, penetration rate slowed thru concretions to 2-3'/hr down from 10', decision made to trip for bit Monitored well-static, took SPR`s POOH on elevators from 14,566' to 14,261' (3 stds) and hole wasn't taking proper fill, backreamed out of hole from 14,261' to 11,764', backreamed out at 622 gpm at 3,700 psi, 120 rpm's with 17K ft-Ibs torque, initial string speed was 20-25'/min due to torquing up but did not pack-off, increased speed to 25-30'/min, attempted to POOH on elevators at 13,433' and 12,505' and well was not taking any fill and had 30-40K add. drag BROOH from 11764 -10036' . Attempt to POOH on elevators from 10904' to 10518' and hole wasn't taking proper fill, backreamed out of hole from 10036' to 9746', backreamed out at 622 gpm at 3,700 psi, 120 rpm's with 17K ft-Ibs torque. POOH on elevators through window to 9649'. No issues through window. Monitor well. Static. POOH from 10036' - 8682', observed well taking proper fil. Shut down GEO- PILOT, pump dry job, Continue POOH from 8682' - 106' PJSM, remove radioactive sources from tool string. Plug in and download MWD Continue to download MWD, POOH -lay down HOC, MWD and bit. Grade bit to 0-0-NO-ALL-X-N-NO-ROP Make up BHA #9. Service GEO-PILOT and MU bit, MWD w/ NEU-DEN and HOC. Plug in -Upload MWD and perform shallow hole test. Hold PJSM, and load radiactive sources in tools. Continue MU 1- stnd of NM flex collars, 5 studs of HWDP and Jars. Trip in hole from 383' - 9615' (91' above TOW) Calibrate Caliper logging tool. 126 SPM, 448 GPM's at 1900 PSI. 30 RPM's with 14K free torque 202 K Up weight, 60k down weight 105k rotating weight Slip & Cut drilling line. Service Top drive & Drawworks. Continue trip in hole to 9914'. No issues going through window w/ driiling assembly. Continue TIH form 9914' - 10112', working pipe through a few tight spots. Perform caliper log coming up hole at 4-5 ft /min from 10112' - 9812'. Pumping at 144 spm, 2500 psi and 60 rpm's. TIH form 9812' - 10264', working pipe in hole at tight spots from 10140' Wash & Ream from 10264' -10683'. Attempt to RIH on elevators, NO-GO. Stacking out and run out of weight. Continue to wash & ream from 12217', and once again attempt to RIH on elevators to 12495'. Continue wash & ream to tag bottom @ 14482'. 206 k up weight, 47 K down, and 104K rot wt. Torque = 17K, Trip gas 90 units. Directionally drilled 8 1/2" hole w/ Geo-Pilot from 14,482' (Corrected depth 14,482) to 14,645' MD / 3,291' TVD, (163') ADT 1.64 hrs, 10-25K wob, 90-120 rpm's, 575 gpm at 3,900 psi, off btm torque 18-20K ft-Ibs, Printed: 10/28/2005 10:29:27 AM • • ConocoPhillips Alaska Page 18 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code Sub Phase .Code V2005 09:30 - 12:00 2.50 DRILL DRLH PROD2 12:00 - 00:00 I 12.001 DRILL I DRLH I PROD2 7/21 /2005 100:00 - 09:15 09:15 - 09:45 09:45 - 10:30 10:30 - 12:00 12:00 - 12:15 9.251 DRILL I DRLH I PROD2 0.50 DRILL CIRC PROD2 0.75 RIGMNT RGRP PROD2 1.501 DRILL I CIRC I PROD2 0.251 DRILL I CIRC I PROD2 12:15 - 13:00 13:00 - 13:15 13:15 - 22:15 22:15 - 23:30 23:30 - 00:00 7/22/2005 00:00 - 01:15 01:15 - 01:30 01:30 - 03:30 03:30 - 06:15 06:15 - 08:30 0.75 RIGMNT RGRP PROD2 0.25 WELCT OBSV PROD2 9.00 DRILL TRIP- PROD2 1.251 DRILL I CIRC I PROD2 0.50 RIGMNT RGRP PROD2 1.25 RIGMNT RGRP PROD2 0.251 DRILL I CIRC I PROD2 2.OOIDRILL (TRIP IPROD2 2.751 DRILL (TRIP IPROD2 2.251 DRILL I CIRC I PROD2 Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations on btm torque 16-18K ft-Ibs, rot wt 104K, up wt 206K,dn wt 47K, 9.0 ppg MOBM, ave ECD 11.9 ppg, ave BGG 50 units, max gas 132 units. Directionally drilled 8 1/2" hole w/ Geo-Pilot from 14,645' to 15268' MD / 3,277' TVD, (623') ADT 10.08 hrs, 10-25K wob, 90-120 rpm's, 575 gpm at 3,900 psi, off btm torque 18-20K ft-Ibs, on btm torque 19-21 K ft-Ibs, rot wt 116K, up wt 230K,dn wt 35K, 9.0 ppg MOBM, ave ECD 11.9 ppg, ave BGG 49 units, max gas 555 units. Continue Directional drill 8 1/2" hole with Geo -Pilot from 15268' -15667' TD. (399') TVD = 3275' Drilled through concretions from 15145 - 15159, 15165 -15183, 15190 -15192, 15216 - 15233, 15267 -15276, 15327 - 15344, 15426 - 15437, 15446 - 15482, 15114, and 15598. ART = 7.96 HRS - 570 GPM's at 3950 PSI. 140 RPM's, 230k up, 57K dn, 125K rot wt. ECD 11.8,and Tq off btm = 20K, on btm = 17-18K. WOB = 10-25K Jars = 220.15 HRS Obtain surveys, and Slow Pump rates. POOH rack back 1 stand. Remove and Repair Top Drive shot pin assembly, while circulate @ 71 spm, w/ 1100 PSI Pump Hi visc weighted sweep at 560 GPM's, 3950 PSI, and 140 RPM's while reciprocate drill string. 230k up, 57K dn, and 125K rot wt. Tq = 20k Continue pump Hi Visc weighted sweep at 560 GPM's, 3950 PSI, and 140 RPM's while reciprocate drill string. 230k up, 57K dn, and 125K rot wt. Tq = 20k Install repaired shot pin assembly on Top Drive. Monitor well, static Attempt to POOH on elevators from 15582' -15391' (191'). Observe improper hole fill. BROOH from 15391'-14451 (940') Attempt to POOH on elevators and observed hole swabbing. Continue BROOH to 9690'. (5701' Total) No issues pulling ghost reamer or BHA through window. TOW = 9706' 568 GPM's, 3950 PSI, 125 RPM's, TO = 18K Pump 30 BBL Hi Visc weighted sweep while reciprocate drill string from 9690' - 9624' 140 RPM's, TO = 12-23K, 180 SPM, 640 GPM's, w/ 3200 PSI. Pumped 3 btms up and observed 10 % increase in cuttings and casing clean. Swivel packing on Top Drive failed. Change out swivel packing Swivel packing on Top Drive failed. Change out swivel packing, Test ..same. Note: Rig Hand reported muscle sprain in back while hammering on Swivel packing. A PIR was generated and he was sent to medic, returned to work. Contimue Circulate while reciprocate drill string from 9690' - 9624' 140 RPM's, TO = 12-23K, 180 SPM, 640 GPM's, w/ 3200 PSI. Pumped 3 btms up and observed 10 % increase in cuttings and casing clean. TIH f/ 9690' - 13098'. (3408') No issues through window area with BHA. Tagged up at 13098' .Drill string would not go to bottom on elevators. Wash & ream from 13098' - 15667' TD. (2569') TVD 3275'. Pumps at 72 SPM, 250 GPM's at 1000 PSI. Rotating @ 70 RPM"S w/ 15-17K TQ. Attempt to RIH numerous times without wash & ream, and string would not go. 185K up, 67K down Rot wt = 125K Pump Hi Visc weighted sweep @ 575 Gpm's, 4250 PSI. 250K up, 55k dn, Rot wt = 120K TQ = 18-20K, 140 RPM's. Observed 20% increase in cuttings and shakers cleaned up. Reciprocate drill string while circulating. Printed: 10!28(2005 10:29:27 AM • ConocoPhillips Alaska Page 19 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Spud Date: 6/20/2005 Event Name: ROT -DRILLING Start: 6/20/2005 End: 8/13/2005 Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Code Phase . Code 7/22/2005 08:30 - 10:30 2.00 DRILL CIRC PROD2 10:30 - 12:00 1.50 DRILL TRIP PROD2 12:00 - 19:30 7.50 DRILL TRIP PROD2 19:30 - 20:15 0.75 DRILL TRIP PROD2 20:15 - 22:00 1.75 DRILL TRIP PROD2 22:00 - 23:00 1.00 DRILL TRIP PROD2 23:00 - 23:15 0.25 DRILL OTHR PROD2 23:15 - 00:00 0.75 CASE RURD CMPLT2 7/23/2005 00:00 - 00:30 0.50 CASE SFTY CMPLT2 00:30 - 04:00 3.50 CASE PULR CMPLT2 04:00 - 05:00 1.00 CASE PULR CMPLT2 05:00 - 07:30 2.50 CASE RUNL CMPLT2 07:30 - 09:45 2.25 CASE RUNL CMPLT2 Description of Operations Dispalce well with 9.0 PPG SFMOBM @ 121 SPM, 432 GPM"S, w/ 2500 PSI. Reciprocate drill string while displacing. After dispalcement 275K , 35K dn, rot wt = 124K, TQ = 23-25K with pumps off. Obtain slow pump rates. POOH on elevators from 15667' -14356' (1311') Observe hole clean, no swabbing. Continue POOH on elevators from 14356' - 90' (14266') Observe hole clean, no swabbing. Lay down Ghost Reamer. Breakout ~ lay down bad Lo-Tads off of stand # 92 , 90, 86, and 84. Serial #'s = 260856, 258285, 260862, and 260840. Held Pre- Job Safety Meeting with Crew. Removing radioactive sources form BHA .Pull sources from assembly, secure and lay down same. Stand back 1 stand NMDC's. Plug into MWD, and download. POOH lay down remaining BHA. Breakout Bit, inspect and gauge same. Bit gauge = 0/0/NO/A/X/I/NO/TD Clear & Clean floor area. Rig up to run 5 1/2 15.5#, L-80 slotted liner assembly with Baker "HR" liner setting sleeve. RU tongs, slips, and change out elevators. Held PJSM with entire crew. (Picking up 5 1/2 slotted liner assembly) Make up Guide shoe jnt, and Insert jnt. Continue RIH picking up 138 jnts of 5 1/2" blank -slotted liner assembly. Ran a total of 69 Blank jnts ( 2935.51') and a total of 69 Slotted jnts (2893.99') with (10) 2.5" long x 1 /8" wide,4 circumferential rows, 40 slots per foot. Ran total of 137 5-1/2" x 8" Centralizers, Liner was drifted to 4.825". Liner connections w/ torque rings, and a total of 14 constrictors @ depths of 14959', 14708', 14208', 13959',13459', 13208', 12709', 12461', 11959', 11561', 11108', 10859', 10408', and 10159', when landed. Make up 1 jnt 7" 26#, with 5 1/2" 15.5# XO jnt. Make up Baker "HR" setting sleeve with a 7" 26# pup and running tool, ball seat assembly crossed over to 4 1/2 IF for Drill pipe. Liner weight = 85 K up, 55K down TIH with 5 1/2 liner assembly to TOW @ 9700'. 140K up, 65K dn. Rot vut = 86K, w/ 20 RPM's 9K TQ, 40 Rpm's 8K TO Continue TIH with 5 1/2 Liner, obtaing torque and drag parameters. At 10297' -rot wt = 86K, 20 Rpm's -10K TO, 40 Rpm's - 10K TO. At 10784' -rot wt = 86K, 20 Rpm's - 11 K TO, 40 Rpm's - 13K TO. At 11169' -rot wt = 85K, 20 Rpm's -11 K TO, 40 Rpm's - 12K TO. At 12114', rot wt = 80K, 20 Rpm's - 13K TQ, 40 Rpm's 15K TO. Fill DP every 20 stands. Stopped at 12626'. No issues running through window. 09:45 - 12:00 2.25 CASE RUNL CMPLT2 Rotate 5 1/2" liner down from 12626' - 14054' (1428'). Rot Wt = 65K, 20 Rpm's 16K Average running speed = 20 ft per minute. 12:00 - 14:00 2.00 CASE RUNL CMPLT2 Continue Rotate 5 1/2" liner in hole from 14054' - 15675' (1621'). 250K up, 40K dn, and 115K rot wt. 19K TQ at 20 Rpm's. Landed 8.71' lower in well. 14:00 - 15:45 1.75 CASE CIRC CMPLT2 Drop ball in Dp, and allow to fall while pumping down DP @ 3 BPM, 250 PSI. 2 BPM @ 150 PSI. Ball landed. 15:45 - 16:30 0.75 CASE OTHR CMPLT2 Pressure up Dp to 1900 PSI to release from 5 1/2" Liner. Continue to pressure up to 3300 PSI to shear ball seat. POOH to 9700' (above TOW @ 9706') 5 1/2" Liner top at 9787.86'. 16:30 - 17:30 1.00 CASE CIRC CMPLT2 Circulate Bottoms up @ 8.3 BPM, 1000 PSI. 225K up, 80K dn, rot wt Printed: 10!28/2005 10:29:27 AM • • ConocoPhillips Alaska Page 20 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code Phase Code 7/23/2005 16:30 - 17:30 1.00 4 CASE CIRC CMPLT2 17:30 - 21:45 4.25 i CASE OTHR i CMPLT2 21:45 - 22:00 0..25 CASE ~URD CMPLT2 22:00 - 22:15 0.25 WINDO ULD CMPLT2 22:15 - 00:00 I 1.751 WINDOV'VPULD I CMPLT2 7/24/2005 00:00 - 04:00 4.00 WINDO RIP CMPLT2 04:00 - 05:30 1.50 RIGMNT~ RSRV CMPLT2 05:30 - 07:15 1.75 WINDO TRIP CMPLT2 07:15 - 08:15 1.00 WINDO IRC CMPLT2 08:15 - 08:30 0.25 WELCT OBSV CMPLT2 08:30 - 12:00 3.50 WINDO RIP CMPLT2 12:00 - 14:30 2.501 WINDOV'I/TRIP (CMPLT2 14:30 - 15:45 I 1.251 WINDOV'UPULD {CMPLT2 15:45 - 17:30 1.751 WINDOV'VPULD CMPLT2 17`30 - 18:30 1.00 CASE OTHR CMPLT2 18:30 - 20:45 2.25 CASE PUTS CMPLT2 20:45 - 00:00 3.251 CASE RUNL I CMPLT2 7/25/2005 00:00 - 02:45 I 2.751 CASE I RUNL I CMPLT2 02:45 - 03:15 I 0.501 CASE I RUNL I CMPLT2 Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations = 133K @ 20 Rpm's and 15K TQ Monitor well. Static. POOH from 9700' -surface. On TOH, breakout & lay do Bad Lo-Tads. Pins coming out, rollers flat. Stnd # 63, serial # 258260, Stnd # 49, serial # 258313, and Stnd # 38, serial # 258291. Lo-Tad lengths= 3.80' ea. Pin size on Lo-Tads = 3/8" x 2' long. We left 1 pin in hole. Total laved down = 11.40' from DP tally. Inspect remaing Lo-Tads on TOH. Breakout, lay down & inspect running tool. Small marks on running tool indicated set down on top of liner after released from liner. Clean floor area, and pull tools to floor. PJSM, with crew. (Picking up BHA) Make up Whipstock retrieving BHA as per BOT Rep. Make up Hook (8.30'), 1 -JNT HWDP(30.86'), Float sub(2.47'), 6 1/4" Bumper Jar(8.70'), 6 1/4" Oitjar(11.53'), Pump Out sub(2.02'), 3 x 6 1/4" Drill Collars(92.13'), and 1 - Stnd of 5" HWDP(92.42'). Total lenght of BHA = 248.43' TIH with Whipstock retrieving assembly From 248' - 9638' (9390') Fill pipe every 20 stands. Slip & cut Drilling Line. Service TD. replaced Hydaraulic fitting on TD. Continue RIH F/ 9638' - 9722' (84'} to position wash slots on Hook at slot in whipstock @ 9712'. Wash slot at 6-7 BPM, - 750 PSI. 210K up, 80K dn. Hook window and pull to 265K to allow jars to bleed open, and continue staright pull to 275K to observe BTA shear and pulling seals from lower liner top. Pull up to 9666', 225K new up weight. Circulate Bottoms up @ 96 SPM, 1100 PSI. No gas. 13 BBL loss. Monitor well, static. POOH with whipstock assembly, observe no swabbing. 118K upweight. Continue POOH with whipstock assembly to whipstock. Hang in clamp on rig flooor. Breakout and lay down whipstock retrieving assembly. Laved down Hook, 1 JNT of 5" HWDP, Float sub, 6 1/4" Bumper Jar & Oil Jar, Pump out sub, 3 - 6 1/4" drill collars, and 1 stand of 5" HWDP. Breakout and lay down whipstock assembly. Inspect whipstock. Laved down Whipstock Slide, Debris barrier cup and sub, drain sub, Shear disconnect, BTA, Blanking sub, 20 JNTS of 5" DP, 1-Flex joint, 1 JNT of 5" DP, Unloader Valve, Crossover sub, Locator sub, and seal assembly. Note: We recovered the lost Lo-Tad pin in the debris barrier cup. Clean & clear floor area. Pull tools to rig floor. PJSM with entire crew and BOT rep. Make up Hook hanger assembly. Picked up 1 JNT 5 1/2" L-80 BENT blank casing, (42.25'), 5 1/2" Pup (5.96'), 5 1/2" Pup (10.09'), Baker Payzone External Casing packer with pups (2.20',23.66' PKR, 6.60'), 5 12P' Pup (10.10'), Model B-1 Hook Hanger assembly with Crossover & pups (4.12',1.33', 27.38'). Make up Crossover to 4 112 IF for DP. and Baker running tool. RIH w/ Drill Pipe from derrick at a running speed of 90 ft /minute, as per BOT rep. Continue RIH w/ Hook assembly w/drill pipe from 5920' - 10420' 4500') at a running speed of 90 ft /minute, as per BOT rep. Tag Main Bore Crossover in seal bore at 10420'. We did not go into "B" lateral on first try. POOH back to 9680'. Printed: 10!28/2005 10:29:27 AM • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Start: 6/20/2005 Contractor Name: Rig. Release: Rig Name: Rig Number: Date .From - To Hours Code Code Phase 7/25/2005 03:15 - 04:45 1.50 CASE RUNL CMPLT2 04:45 - 06:00 I 1.25 CASE CIRC CMPLT2 06:00 - 06:30 1 0.501 CASE I SFTY CMPLT2 06:30 - 07:30 I 1.00 I CASE I MIT I CMPLT2 07:30 - 08:15 I 0.751 DRILL I TRIP I CMPLT2 08:15 - 08:30 0.25 WELCT OBSV CMPLT2 08:30 - 12:00 3.50 DRILL TRIP CMPLT2 12:00 - 12:30 0.50 DRILL TRIP CMPLT2 12:30 - 13:15 0.75 CASE RURD CMPLT2 13:15 -14:15 1.00 CASE RURD CMPLT2 14:15 - 14:45 0.50 RIGMNT RSRV CMPLT2 14:45 - 16:45 2.00 CASE PULR CMPLT2 16:45 - 17:15 I 0.501 CASE PULR CMPLT2 17:15 - 23:30 1 6.251 CASE I RUNL 1 CMPLT2 Page 21 of 33 Spud Date: 6/20/2005 End: 8/13/2005 Group:. Description of Operations Turn drill string 5 1/2 RH turns to orient bent joint to go through window. Slack off to to observe hooked hanger @ 9727.79'. (5.79' below original window cut) Pull up and un-hook hanger, rotate 1/4 RH turn increments to RIH and tag crossover in TOL @ 9845.88'.(1.98' low), and verify Hook depth. Hooked and Re-hooked a total of 4 times, to finally set @ 9727.79'. Set down 40K on Hook. 215 K up, 75K do Drop 29/32" ball, With Rig, pump to seat 800 stks @ 3 BPM - 325 PSI, 2 BPM -200 PSI. Total of 2311stks to seat ball. Pressure to 450 PSI. ,and line up to hold pressure on DP. Hold PJSM with entire crew and Schlumberger. Discuss pressure test and procedure of pumping. Line up Pump truck to DP. Pressure test lines to 3500 PSI. Good test. Pressure up to 1000 PSI, Hold 2 min. Check tank level. Pressure to 1500 PSI, Check tank level. Continue pressure up in 200 PSI increments to observe ECP inflate at 2695 PSI. Pressure bled back to 1700 PSI. Held Pressure 5 min. Bled pressure to 500 PSI. Check tank. level, observed .45 BBLS to inflate ECP. Bleed all pressure off. Job went very well. Pull up off of Hanger to 9700'. (27') CBU @ 180 SPM, 2900 PSI. 215K up, 80K do wt. Monitor well. Static. POOH from 9700' - 2167' (7533'). Inspect for failed Lo-Tads Continue to POOH from 2167' -surface. Lay down entire Hook Hanger running tool assembly, Visually inspect same. Clean and clear Rig Floor. Lay down all runnng tools. Service Top Drive, and inspect threads. PJSM with entire crew. Pull tools to floor, and RU to run LEM assembly. Make up 4 1/2" Baker Seal assembly (3.29') on 1 jnt of 4 1/2" IBT x STL 12.6# L-80 tubing, (43.67'}. Seals = 4.73" x 3.87" ID. Make up & RIH w/ 21 jnts of 4 1/2" IBTM 12.6# L-80 tbg, (615.72'). Collar OD = 5.21" x 3.958". Make up Camco "DB" nipple assmy. 4 1/2" IBT tbg pup (5.88'), DB Nipple (1.52') with an ID of 3.563" and profile of 5.21"., 1 jnt 4 1!2" IBT tbg (30.23) 21 jnts of tbg total ran. Make up LEM assembly. Pick up LEM Inside Hook Hanger (22.90') 7.69" x 3.688". MU LEM Above Hook Hanger (12.40') 8.49" x 3.98", 4 1/2" IBT tbg pup (3.80') 5.20" OD x 3.98" ID, 4 1/2 "Casing Swivel, 12.6# IBT (2.52') OD 5.75" x 3.96" ID. Crossover Bushing 5 1/2" Hydril 563 x 5 12/" IBT (1.40') OD 6.03" x 4.75" ID, 190-47 Casing Seal Bore Receptacle (19.45') OD 6.26" x 4.75" ID, Crossover 7" x 5 1/2" Hydril 563 (1.14') 7.67" OD x 4.94" ID, 2:XP Liner top PKR 7" x 9 5/8" w/ HRD profile (18.50') OD 8.49" x 7.5" ID, and Baker Hydraulic setting toot 5.10'), and Baker running tool (5.42'). Trip in hole Lem assembly from 792' - 10430' (9638'). Running speed of 60-80 Ft !Min as per BOT rep. Observe seals going into SBR @ 10420' and continue RIH to latch up to Hook Hanger @ 9706.69', Top of ZXP PKR @ 9647.48'. 220K up, 82K do wt. Pull 10K over to verify latch up. Layed down bad Lo-tads off of Stand # 37 (ser#258293), Stnd # 39 (ser#258289), Stnd # 43 (ser#258290), Stnd # 44 ser#258294), Stnd# 46 (ser#258262), Stnd# 48 (ser#258263), Stnd# 51 (ser#258266), Stnd# 52 (ser#258259), Stnd# 54 (ser#258372), Stnd# 55 (ser#258256), and Stnd# 57 (ser#258315). 11 Total layed down on trip. rnncea: ~urtaizuva iu:~a:u rim • ConocoPhillips Alaska Page 22 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code Code Phase 7/2512005 12 I 3:30 - 00:00 0.50 CASE RURD CMPLT2 17/26/2005 100:00-01:00 01:00 - 01:30 1.00 ~ CASE ~ DEOT ~ CMPLT2 0.50 I CASE I DEQT ~ CMPLT2 01:30 - 02:30 1.00 CASE CIRC CMPLT2 02:30 - 10:30 8.00 CASE OTHR CMPLT2 10:30 - 11:00 0.50 CASE OTHR CMPLT2 11:00 - 12:00 1.00 WELCT BOPE CMPLT2 12:00 - 12:30 .0.50 WELCT BOPE CMPLT2 12:30 - 16:30 4.00 WELCT BOPE CMPLT2 16:30 - 17:00 0.50 17:00 - 21:45 4.75 21:45 - 00:00 2.25 ']/27/2005 00:00 - 02:45 2.75 02:45 - 07:30 4.75 07:30 - 12:00 I 4.50 I W I 12:00 - 14:30 2.50 14:30 - 15:30 1.00 BOPE CMPLT2 PULD PROD3 LD PROD3 P PROD3 P PROD3 P PROD3 P I PROD3 P PROD3 Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations Rig up lines to pump down DP and utilize rig test pump if neccessary. Line up to record on chart. Continue to Rig up lines to pump down DP and utilize rig test pump if neccessary. Line up to record on chart. Drop 1 3/4". Using Rig pump, pump ball do to seat at 3 BPM- 300 PSI. Ball on seat @ 1550 STKS. Pressure to 3000 PSI, then stage pressure up to 4200 PSI to set ZXP Liner Top PKR @ 9647.48' DPM. Pull up 10' to release from PKR and verify set. PJSM, Discuss pressure test and procedure. Close annular and pressure test down annulus to test ZXP @ 1000 PSI. Record on chart and hold 10 minutes. Good test. Rig down test equipment. POOH, lay do 2 - 10; 5" DP pups, and screw into TD. 220K up, 82K do wt. CBU @ 180 SPM, 630 GPM's - 2900 PSI. Monitor well, Static. POOH, Breakout & lay down all Lo-Tads. We shipped out a total of 6t bad Lo-Tads. The 10 Lo-Tads on HWDP were kept on location for re-use as they are in good shape. Note: Bad Lo-Tads consisted of pins falling out, and rollers being "flat". Make service breaks on Running and Setting tools, and lay down same. BOLDS, Pull wear bushing. Install Test plug. RILDS. RU test pump. Continue RU test pump and equipment to test BOP's. Tested BOPE, tested rams, valves and manifold to 250 psi low and 3,000 psi high, tested annular to 250 psi then 2,800 psi. Test i Accumulator. Chuck Sheave with AOGCC waived witnessing testing, RD test equip. and installed wear bushing. RILDS RD test equipment, and pull tools to floor. Make up Whipstock Assembly with Space out drill pipe. MU BOT seals (3.43'), Locator sub (1.87'), Crossover 3 1/2 IF x 4 1/2 IF (1.57'), Unloader sub pinned for 60K Shear (6.47'), 7 - JNTS 5" Space out pipe. (216.78'), Blanking sub (1.57'), 9 5/8" Bottom Trip anchor (2.81'), Shear Disconnect sub 120k Shear (2.73'), Ported Drain sub (1.49'), Debris barrier sub w/Cup (1.59'), 9 5/8" Windowmaster Whipstock (18.98'), 8" Starting Mill (1.55'), 8" Lower Mill (5.67'), 8.510" Upper Mi{I (6.17'), 1 - JNT 5" HWDP (30.74'), Float Sub (2.47'), MWD Assmy (42.62'), 6 1 /4" Bumper Jar (8.70'), 6 - 6 114" Drill Collars (184.48'), 13 -stand 5" HWDP (1194.60'). Total BHA with Whipstock = 1732.85'. Total BHA withou Whipstock = 255.86'. Orient MWD to High side face of Slide. Pulse test MWD assmy, good. Shear Bolt = 45K Trip in hole w/ 9 5/8" Whipstock assembly from 1732'.- 2670'. (938'). 105K up, 65K do wt. Continue to TIH from 2670' - 6622' (3952') 90 seconds to 2 minutes per stand as per BOT rep. PU = 160K, SO WT = 53K POOH, after deciding we didn't have enough downweight to shear off- and mill window. POOH, from 6622' - 722' (5900') POOH 90 seconds per stand. Reposition HWDP in assembly. TIH with 9 5/8" Whipstock Assembly. from 722' - 4835' (4113'). 90 seconds to 2 minutes per stand as per BOT rep. PU = 110K, SO WT = 55K. Install Lo-Tads on stands # 10,13,16,19,22,25,28,31,34, and 37. Installed a total of 10 Lo-Tads. Continue to TIH from 4835' - 8790'. (3955'). 90 seconds to 2 minutes per stand as per BOT rep. Perform MADD PASS to K-13 for depth check. From 8790' - 8895' Printed: 10!28/2005 10:29:1/ AM • • ConocoPhillips Alaska Page 23 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code Code Phase Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number. Description of Operations 7/27/2005 14:30 - 15:30 1.00 WINDO RIP PROD3 (105'). 15:30 - 15:45 0.25 WINDO RIP PROD3 Continue T{H with Whipstock assembly from 8895' - 9644' (749'). PU = 215K SO WT = 68K. RIH to 80' above top of ZXP liner top. 15:45 - 16:15 0.50 WINDO ETW PROD3 Orient 9 5/8 Whipstock face to 12 Degrees left of High side As per Directional Driller and plan. PU = 215k, SO Wt = 68K 16:15 -19:15 3.00 WINDO ETW PROD3 Slack off to observe Seals going into top of ZXP liner top (3') and set down to 35K to Set BTA. Pull up to 10k over to verify BTA set. PU = 215K , SO WT = 68K. Slack off to 35K to Shear bolt, set for 45K shear. Repeat 3 times. Pull up to neutral position at 160K and attempt to rotate free. NOT free. Continue to work 5 Right Hand turns into drill string, and work torque down to bolt, by slacking off to 35k, and max pull to 215K. Repeat numerous times. No free rotation. Continue attempts to turn free with a max torque of 20,000 ft/lbs, and pumps at 450 GPM's, 1970 PSI. NOTE: MWD tool face readings indicated 155 degrees left of high side, and holding. We suspect starting mill pinched off in casing, not releasing torque back. 19:15 - 20:00 0.75 WINDO IRC PROD3 Dispalce well from SFMOBM to MOBM at 525 GPM's and 2500 PSI. The decision was made to displace at this time to have the added lubriciryin the MOBM possibly help in torque, up/down weights as well as transfer torque to bottom of assembly. This was a planned operation and trucks were ready. 20:00 - 21:45 1.75 WINDO ETW PROD3 Continue attempt to rotate free by working torque to bottom of hole. Observed Bumper Jar movement at 225K UP, and 75K down. Decision from town to MAX Pull to 70K over. We pulled to 285K. Repeat, numerous times. NOTE: The BTA is designed to release @ 60K overpull. The shear disconnect is designed to release with a 120K overpull. 21:45 - 22:15 0.50 WINDO ETW PROD3 We positioned the string in neutral position. Free rotation was obtained by rotaing to a max torque of 28K. Observed 100 RPM's 20K free torque, and we rotated only for 1/2 minute. Stopped Rotation. Discuss options with town, and it was decided to continue with planned operations, start milting. Circulate @ 500 GPM 'S, 2900 psi, no rotation or reciprocating string. String in neutral position, while wait on decision. 22:15 - 00:00 1.75 WINDO ETW PROD3 Attempt to re-establish free rotation. Repeat procedures as above, and could not gain rotation again. This procedure was repeated numerous times, changing variables such as pump speeds, and trying to find the neutral position again. PU WT = 215K SO WT = 68K. 7!28/2005 00:00 - 00:45 0.75 WINDO ETW PROD3 Continue Attempt to re-establish free rotation. Repeat procedures as above, and could not gain rotation again. This procedure was repeated numerous times, changing variables such as pump speeds, and trying to find the neutral position again. PU WT = 215K SO WT = 68K. Discuss options with town rig engineers. . 00:45 - 02:00 1.25 WINDO ULD PROD3 Decision to POOH with Whipstock assembly. Work drill string in increments of 25K, working up to a MAx pull of 425K. 75K Down. Assembly pulled free at 410K, and we pulled up hole 60'. Note: BTA designed to release with 60K overpull. Shear disconnect designed to release at 120K overpull 210K UP WT. , 75K DN WT. 02:00 - 02:45 0.75 WINDO ULD PROD3 POOH, with 1 stand HWDP, and lay down 1 single. Monitor well for swabbing. Hole taking fluid. Up WT = 215K. Pump Dry Job. 02:45 - 10:15 7.50 WINDO ULD PROD3 POOH from 9554' - 88' (9466'). Lay down 10 Lo-Tads to reposition them on next TIH. 10:15 - 11:00 -0.75 WINDO ULD PROD3 Lay down MWD assembly, Bumper Jar, Float Sub, and drain BOP stack. Clean & clear floor area. Printed: 10/28/2005 10:29:27 AM • • ConocoPhillips Alaska Page 24 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common W ell Name: 1 E-117 Spud Date: 6/20!2005 Event Nam e: ROT -D RILLING Start: 6/20/2005 End: 8113!2005 Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date From - To Hours Code Code Phase Description of Operations 7/28/2005 11:00 - 11:30 0.50 WINDO ULD PROD3 PJSM, with entire crew, and BOT reps. Discuss procedure to strip Whipstock assembly through BOP stack & rotary table considering it may be sheared. Discuss rigging up a 25' JNT of 9 5/8" 40# casing.'""` Special Note'"""' CPF 1 ask us to take the Rig off Hi Line @ 11:00 AM. May be off for 8 to 10 days ?? 11:30 - 12:00 0.50 WINDO ULD PROD3 Pick up 1 JNT of 9 5!8" 40# casing cut to a lenght of 25', with tugger, and strip it over 1 JNT of 5" HWDP hanging in blocks. MU HWDP to string hanging in slips. 12:00 - 12:15 0.25 WINDO ULD PROD3 Pull Milling Assembly to floor through 9 5/8" casing. We did not have the whipstock assembly. Clean & Inspect mills. Starting mill showed damage on OD. Indicatiions mill was pinched and pulled by brass pad on slide, and casing drag marks. Broken buttons and damged carbide. Pictures were taken and sent to town. 12:15 - 12:45 0.50 WINDO ULD PROD3 POOH, lay down 9 518" casing jnt. Lay down remaing Mill assembly. Layed down 8" Starting Mill (1.55'), 8" Lower mill (5.67), 8.510" Upper Mill (6.17'), and 1 -JNT 5" HWDP. 12:45 - 13:30 0.75 WINDO RIP PROD3 Pick up Whipstock retrieving assembly. Retrieving Hook (8.3'), 1 -JNT 5" HWDP (30.747, Float Sub (2.47'), MWD assembly (42.62'), 6 1/4" Bumper Jar (8.70'), 6 1/4" Oil Jar (11.53'), Pump Out Sub (2,02'), 3 - JNTS 6 1/4" Drill Collars (92.13'), 2 -Stands 5" HWDP (184.03'). Orient MWD to whipstock hook. 13:30 - 18:45 5.25 WINDO RIP PROD3 TIH from 416' - 9315' (8899'). Pulse test MWD, Inspect saver sub on Top Drive. Pick up 9 Lo-Tads on TIH. Lo-Tads on Stands #10 (ser#260830), #13 (ser#260851), #16 (ser#260854), #19 (ser#260832), #22 (ser#260852), #25 (ser#260833), #28 (ser#260837), #31 (ser#260861), #34 (ser#260813), and #37 (ser#260819). PU WT = 175K, SO WT = 78K. 18:45 - 20:45 2.00 WINDO ETW PROD3 Orient Hook to 12 Degrees left of High Side. Attempt to engage WHipstock slot @ 9396'. Could not get over top of Whipstock with Hook. Tag top of whipstock @ 9390'. Orient Hook to 180 Degrees opposite @ 177 Deg Right. Sfack off to below top of whipstock and re-orient Hook to 19 Deg left. Hook Slide and pull up to 205K (25K over) to verify catch. Pump up MWD surveys to verify whipstock still set, and oriented to 19 degrees left of high side. 530 GPM's 2840 PSI. Directional Driller confirmed orientation, and satisfied. Un-Hook from whipstock, and pull up to 60' over top of slide to verify free. 180K PU WT, 70K SO WT. 20:45 - 22:30 1.75 WINDO RIP PROD3 Monitor well, Static. Pump dry job. Obtain parameters. 195K PU WT, 83K SO WT, ROT WT = 120K, 80 RPM's, 13 -15K Free Torque. 530 GPM's, 2840 PSI. POOH from 9390' - 6910' (2480'). PU WT = 150K SO WT = 62K 22:30 - 00:00 1.50 RIGMNT RSRV PROD3 Slip & Cut Drilling Line. Service Top Drive. 7/29/2005 00:00 - 02:45 2.75 WINDO RIP PROD3 Continue POOH from 6910' - 198' (6712'). Observe proper hole fill. 02:45 - 03:45 1.00 WINDO RIP PROD3 Breakout & Lay down BHA. Layed down 3 - JNTS 6 1/4" Drill collars 92.13'), Pump out sub (2.02'), 6 1/4" Oil Jar (11.53'), 6 1/4" Bumper Jar (8.70'), MWD assembly (42.62'), Flaot Sub (2.47'), 1 -JNT 5" HWDP (30.74'), Retrieving Hook (8.3'). 03:45 - 04:30 0.75 WINDO RIP PROD3 Clean & clear Rig floor. Pull tools to floor. 04:30 - 05:30 1.00 WINDO RIP PROD3 MU Whipstock Milling BHA. MU GEN 2 window mill (1.24'), 8" Lower mill (5.67),8.510" Upper Mill (6.17), 1 -JNT 5" HWDP (30.74'), Float Sub (2.47); 6 1/4" Bumper Jar (8.70'), 3 - 6 1/4" Drill Co-lars (92.13'), and 3 -Stands 5" HWDP (275.59'). 05:30 - 12:00 6.50 WINDO RIP PROD3 TIH with Milling BHA, 38 Stands S-135 DP. Make Up Lo-Tads on Stand Printed: 1 o/28/2005 1029:27 AM • • ConocoPhillips Alaska Page 25 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code Code Phase 7/29/2005 I o ~ I 2~00 - 13:30 1.50 1 WINDO RIP PROD3 13:30 - 19:30 { 6.00 I WINDOV(/OTHR I PROD3 19:30 - 20:00 0.50 WINDO IRC PROD3 20:00 - 20:30 0.50 WINDO IRC PROD3 20:30 - 00:00 3.50 WINDO RIP PROD3 17/30/2005 00:00 - 00:15 0.25 WINDO~RIP PROD3 00:15 - 01:00 0.75 WINDO RIP PROD3 01:00 - 01:30 0.50 WINDOV~ITRIP PROD3 01:30 - 02:30 1.00 WINDO THR PROD3PROD3 02:30 - 03:30 I 1.00 I DRILL PULD I PROD3 03:30 - 03:45 0.25 DRILL DEOT PROD3 03:45 - 07:15 3.50 DRILL TRIP PROD3 07:15 - 08:00 0.75 DRILL TRIP PROD3 08:00 - 10:30 { 2.501 DRILL I DRLG I PROD3 10:30 - 11:45 I 1.25 I DRILL I TRIP I PROD3 11:45 - 12:00 I 0.251 DRILL OBSV PROD3 12:00 - 15:45 3.75 DRILL TRIP PROD3 15:45 - 17:30 I 1.75 I DRILL I PULD { PROD3 Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations #39. TIH from 422' - 7036'. (6614'). Continue TIH with Milling Assembly from 7036' - 9390' (2354') installing Lo-Tads. Installed a total of 42 Lo-Tads on Stands #39 - #80. PU WT = 168K, SO WT = 87K, Rot WT = 115K. Mill Wlndow from 9390' - 9422' (32'). Milled 16' window in 3.8 HRS. AVG ROP = 4.2 Ft per hour. Milled open hole in .63 HRS AVG ROP = 25.26 Feet per hour. Total milling time = 4.83 hrs. AVG Milling Time Total = 6.62 Feet per hour. Avg Torque in window area = 15K - 17K. 90 RPM's. Mud weight = 9.0 PPG MOBM. YP = 18 VISC = 83. PU WT = 168K SO WT = 87K. Pumps at 500 GPM's 2000 PSI. WOB = 2K - 10K. Milled to ensure 5' of 8 1/2" gauged hole beyond slide. Work drill string to dress window area until clean. Pumping Hi-Visc sweep. @ 500 GPM's - 2000 PSI. 168K PU WT, 87K SO WT, 90 RPM's l'O = 12-13K ~ Continue circulate sweep out of hole. 670 GPM's - 3300 PSI. Obtain Slow pump rates. 30 SPM - 280 PSI 40 SPM - 270 PSI. Pump #1. Monitor well. Static. Pump Dry Job. POOH from 9390' - 2422' 6968') PU WT = 182K SO WT = 92K TOH pipe displacement 1.1 bbls difference from calculated. Continue POOH with window milling assembly from 2422' - 422' (2000') Breakout & Lay down Whipstock Milling BHA. MU GEN 2 window mill 1.24'), 8" Lower mill (5.67'),8.510" Upper Mill (6.17'), 1 - JNT 5" HWDP ( 30.74'), Float Sub (2.47'), 6 1/4" Bumper Jar (8.70'), 3 - 6 1/4" Drill Collars (92.13'), and 3 -Stands 5" HWDP (275.59'). Gauge mill to full 8 1/2". Mills looked good. Clean & clear floor area, pull tools to floor. BOLDS, Pull wear bushing. Make up tools and flush stack. Install wear bushing. RILDS. Make up BHA #15, 8 1/2" Drilling assembly. PU 8 1/2" Roller cone Insert Bit (1.00') (TFA = .746), 7" Sperry drill lobe 7/8 - 6.0 stage motor (25.10'), Non-mag Float sub (2.50'), 6 314" MWD DM HOC (8.87'), 6 3/4" Gamma/Res (23.75), 6 314" TM HOC (10.0'), 3 - jnts Non Mag flex drill collars (91.54'), 1 -jnt 5" HWDP (30.76'), 6 1/4" Drilling Jar 30.38), and 4 - jnts 5" HWDP (123.28'). Pulse test MWD equipment at 450 GPM's, 1400 PSI. OK Trip in hole w/ Drilling assembly from 347' - 9377'. (9030'). Orient toolface to 12 degrees left of high side, to pass through window, down to 9422. Directional Drill 8 112" hole from 9422' - 9598'. (176'), to line up in "D" sand for Geo -Pilot Assmy. TVD = 3354'. AST = 1.49 HRS, ART = .3 HRS. ADT= 1.79 HRS. PU WT = 150K, SO WT = 95K, Rot WT = 95K: Torque on bottom = 13-14K, Off Bottom = 15-18K. Pumps @ 500 GPM's - 3000 PSI. Jars = 1.79 HRS POOH with drilling assembly from 9598' - 9377' (221'). Monitor welt, static. Note: Wlndow at 9391' - 9407'. Pump dry job, flow check. Continue POOH from 9377' - 347' (9030'). Hole fill 9.0 BBIs more than calculated. Down load MWD. Breakout & Lay do BHA #15, 8 1!2" Drilling assembly. 8 1/2" Roller cone Insert Bit (1.00') (TFA = .746), 7" Sperry drill lobe 7/8 - 6.0 stage motor (25.10'), Non-mag Float sub (2.50'), 6 3/4" MWD DM HOC (8.87'), 6 3/4" Gamma/Res (23.75), 6 3/4" TM HOC (10.0'), 3 - jnts Non Mag flex drill collars (91.54'), 1 - jnt 5" HWDP PfllltBtl: 1U/LYS/LUUS 7U:Ly:1/AM • • ConocoPhillips Alaska Page 26 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code Cade Phase 7/30/2005 ~ 15:45 - 17:30 ~ 1.75 i DRILL ~ PULD ~ PROD3 17:30 - 18:00 18:00 - 19:30 19:30 - 00:00 17/31 /2005 f 00:00 - 00:30 00:30 - 04:00 f 8/1/2005 04:00 - 04:30 04:30 - 12:00 0.50 DRILL TRIP PROD3 1.50 RIGMNT RGRP PROD3 4.50 DRILL f PULD I PROD3 0.501 DRILL I TRIP I PROD3 3.501 DRILL (TRIP IPROD3 0.501 DRILL I REAM I PROD3 7.50 {DRILL I DRLG I PROD3 12:00 - 00:00 I 12.00 {DRILL I DRLG PROD3 00:00 - 12:00 I 12.001 DRILL I DRLG I PROD3 Spud Date: 6/20/2005 Start: 6!20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations ( 30.76'), 6 1/4" Drilling Jar (30.38), and 4 -juts 5" HWDP (123.28'}. Bit Gauge=l/I/WT/A/E/I/NO/BHA Clean floor area, lay do tools, pull tools to rig floor. Change ou saver sub on Top Drive. Measure ID of Rotary table., = 27 1/2". ID of wear bushings = 10 3/4". Service Top Drive. MU 8 1/2" Geo -Pilot drilling assembly... PU 8 1/2" PDC FMF2643 w! 1.118 RP, Ser# 5012193RW (TFA = 1.666)(1.60'), 7600 GEO-Pilotw/ top motor stabilizer (23.22), Non MAg GP Flex pony collar (9.21'), Smart Stabilizer (2.20'), 6 3!4" MWD - GR/RES/PWD (21.01'), Smart stabilizer(1.96'), 6 3!4" MWD HCIM (6.94'), 6 314" MWD - NEU f DEN 29.92'), 6 3/4" TM HOC (10.0'), Non mag Float sub (2.50), 3 -Non mag Flex drill collars (91.54'), 1 - Jnt 5" HWDP (30.76'), Drilling Jars 30.38'), 4 -JNTS 5" HWDP (123.28'}, 16 - 5" Slick DP (508.02), 8 1/2" Ghost Reamer (6.9T), 48 -JNTS 5" SLick DP (1427.84'), and a 8 1/2" Ghost Reamer (6.95'). Pulse test MWD @ 525 Gpm's- 1050 PSI. , Upload, and break in GEO bearing. PJSM W! entire crew. Install radioactive sources in drilling assembly. Contininue to make up SHA to 385'. TIH w/ drilling assembly from 385' -9521' (9136'), picking up Ghost reamers in BHA @ 508' & 1428'. Fill drillstring @ 2779',5130',7491',and 9327'.. Continue TIH to 9521'. No issues passing asembly through window @ 9391'-9407, Wash & Ream down from 9521' -9598' (77'). Observe clean hole. Pumps @ 500 GPM's - 2500 PS1 PU WT = 150K, SO WT = 72K, ROT WT = 93K. TQ = 14-15K Directional Drill 8 112" hole in the "D" sand from 9598' - 9865' (267'). ~TVD = 3340'. Drill through Concretion @ 9531' - 9537' (6'). ADT = 5.52 i HRS. PU WT = 175K, SO WT = 60K, ROT WT = 90K. TO on BTM = 15-20K, TQ off BTM = 15-18K, @ 130 RPM"S. JAR HRS = 7.31, 630 GPM's - 3400 PSI ECD = 10.4 PPG. MW = 9.0 PPG YP = 23-25 MAX WOB = 5-15K Continue Directional Drill 8 1/2" hole in the "D" sand from 9865' - 10577' (267'). TVD = 3345'. Drill through 16 Concretions @ 9608' - 9615' (7'), 9645' -9654' (9'),9670' - 9678' (8'), 9688' -9700' (12'), 9708' - 9712' (4'), 9761' - 9765' (4'), 9795' - 9798' (3'), 9822' - 9826' (4'), 9860' -9872' (12'), 10041' - 10046' (5'), 10060' - 10072' (12'), 10282' - 10289' (7'), 10521' - 10524' (3'), 10540' - 10553' (13'), 10557' - 10563' (6'), 10558' - 10570' (12'). Total of 127' of concretions = 13% of drilled hole.. ADT = 7,86 HRS. PU WT = 200K, SO WT = 60K, ROT WT = 100K. TO on BTM = 15-17K, TQ off BTM = 18-20K, @ 135 RPM"S. JAR HRS = 15.1, 635 GPM's - 3550 PSI ECD = 11.5 PPG. MW = 9.0 PPG YP -23-25. MAX WOB = 10-25K Observed Higher Torque up to 23K when 1st Ghost Reamer going through window. Directional Drill 8 1/2" hole in the "D" sand from 10577' - 10979' (402'). TVD = 3308'. Drill through 10 Concretions @ 10586' - 10595' (9'), 10602' - 10610' (8'), 10655' - 10670' (15'),10680' - 10691' (11'), 10730' - 10745' (15'), 10790' - 10810' (20'), 10845' - 10862' (17'), 10890' - 10914 (24'), 10930' - 10950' (20'), 10968' - 10979' (11'). 150' Total Concretions = 38 % of drilled hole. ADT = 8.07 HRS. PU WT = 185K, SO WT = 50K, ROT WT = 85K. TQ on BTM = 15-22K, TQ off BTM = 17-18K, @ 130 RPM"S. Jars = 23..24 HRS Pumps at 622 GPM's - 3400 PSI ECD = 11.7 PPG. MW = 9.0 PPG YP = 23-25 MAX WOB = 10-30K Pfintetl: 1u/Zt52W~ 7U:Z9:Z/AM • • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 E-117. Common Well Name: 1 E-117 Event Name: ROT -DRILLING Start: 6/20/2005 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Code 8/1/2005 ~ 12:00 - 19:00 ~ 7.00 ~ DRILL 19:00 - 20:30 1.50 DRILL 20:30 - 00:00 3.50 DRILL 8!2/2005 00:00 - 07:45 7.75 DRILL 07:45 - 09:15 1.50 1 DRILL 09:15 - 09:45 0.50 DRILL 09:45 - 14:15 4.50 DRILL 14:15 - 17:15 3.00 DRILL 17:15 - 17:45 0.50 DRILL 17:45 - 19:45 2.00 DRILL Page 27 of 33 Spud Date: 6/20/2005 End: 8/13/2005 Group: Sub .Phase Description of Operations Code DRLG PRODS Continue Directional Drill 8 1/2" hole in the "D" sand from 10979" - 11479' (500'). TVD = 3287'. Drill through 2 Concretions @ 10990' - ~ 11005' (15'), 11086' -11095' (9'). Total of 24' of concretions = 5% of ~ drilled hole.. ADT = 4.91 HRS. PU WT = 185K, SO WT = 50K, ROT WT = 98K. TQ on BTM = 21-22K, TQ off BTM = 21 K, @ 130 RPM"S. JAR HRS = 29.14 HRS, Pumps @ 635 GPM's - 3500 PSI ECD = 11.62 PPG. MW = 9.0 PPG YP -23-25. MAX WOB = 10-25K Note: MWD Density tool stopped working at 9843' MD, and came back on @ 10663'. Lost - (820'). REAM PRODS BROOH from 11479' - 10980' (499'), at drilling rate. Decision with town to pull back and sidetrack as per Geologist. DRLG PRODS Work drill string from 10980' - 10997', troughing hole to start sidetrack. TVD = 3307'. 135 RPM's 48K TO, 635 GPM's 3500 PSI. ECD @ 11.6 PPG WOB = 0-2K ADT = .99 HRS *'* Note"`*"` Deprature point 10,980' MD DRLG PRODS Directionally Drill 8 1t2" hole in "D" Sand lateral with Geo-Pilot from 10,997' to 11,479', (482') ADT 5.09 hrs DRLG PRODS Drilled 8 112" Hole in "D" sand lateral from 11,479' to 11,609' MD/ 3,291' TVD, (130') ADT .73 hrs, 8-15K wob, 110-130 rpm's, 180 spm, 640 gpm, 3,700 psi, off btm torque 22K ft-Ibs, on btm 18K ft-Ibs, rot wt 95K, up wt 185K, do wt 35K, (Blk Wt), 9.05 mw, ave ECD 12.0 ppg, ave bgg 70 units, max gas 656 units CIRC PRODS Circ hole and evaluated logs for geology DRLG PRODS Drilled 8 1 /2" Hole in "D" sand lateral from 11,609' to 12,062' MD/ 3,284' TVD, (453') ADT 2.74 hrs, 5-12K wob, 130 rpm's, 178 spm, 630 gpm, 3,650 psi, off btm torque 22K ft-Ibs, on btm 19K ft-Ibs, rot wt 94K, up wt 205K, do wt 37K, 9.05 mw, ave ECD 12.0 ppg, ave bgg 175 units, max gas 807 units, (reed additional Lo-Tads) REAM PRODS Backreamed out of hole at drlg rate from 12,062' to 10,487' to install additional Lo-Tads PULD PRODS PU add. Lo-tads to rig floor TRIP PRODS RIH from 10,487' to 11,780' installing 1-Lo-tad per std, lost down wt at i 11,780' ~ 19:45 - 20:30 I 0.75 I DRILL I REAM 20:30 - 00:00 I 3.501 DRILL I DRLG I PRODS '18!3!2005 00:00 - 02:15 2.25 DRILL DRLG PRODS 02:15 - 03:00 0.75 RIGMNT RGRP PRODS 03:00 - 14:15 11.25 DRILL DRLG PRODS 'Washed and reamed down from 11,780' to btm at 12,062', installed a !total of 16 Lo-tads to 5" DP, (58 total in hole) having to rotate DP down to set slips Drilled 8 1/2" Hole in "D" sand lateral from 12,062' to 12,390' MD/ 3,280' TVD, (328') ADT 2.21 hrs, 5-10K wob, 130 rpm's, 176 spm, 625 gpm, 3,700 psi, off btm torque 20-22K ft-Ibs, on btm 18K ft-Ibs, rot wt 95K, up wt 200K, do wt 37K, having to rotate DP to set slips due to no slack off wt, 9.0 mw, ave ECD 12.1 ppg, ave bgg 70 units, max gas 135 units, Drilled a few small concretions after sidetracking well and no concretions since 11,200' Directionally drilled 8 1/2" hole in "D" sand lateral with Geo-Pilot from 12,390' to 12,665' MD/3,276' TVD (275') RDT 1.62 hrs Circ hole at a reduced rate while changing out valves and seats on #1 mud pump Drilled 8 1/2" Hole in "D" sand lateral from 12,665' to 13,561' MD/ 3,258' TVD, (896') ADT 7.28 hrs, 10-25K wob, 130 rpm's, 176 spm, 625 gpm, 3;825 psi, off btm torque 20-22K ft-Ibs, on btm 18K ft-Ibs, rot wt 98K, up wt 205K, do wt 35K, 9.05 mw, ave ECD 12.05 ppg, ave bgg 80 units, max gas 190 units, NOTE: A rubber boot on pump in rock washer failed Pflllfed: 10/Ztl20U5 70:Z9:Z/ AM • • ConocoPhillips Alaska Page 28 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date Frorn - To Hours Code Code Phase 8/3/2005 103:00 - 14:15 .. -- ~ 11.25 --- ~ DRILL I DRLG~ - PROD3 14:45 - 00:00 9.25 I DRI MNT DRLG I PROD3 8/4/2005 00:00 - 12:00 12.00 DRILL DRLG PROD3 12:00 - 17:00 5.00 DRILL DRLG PROD3 17:00- 17;30 0.50 RIGMNT RGRP PROD3 17:30 - 22:00 4.50 DRILL DRLG PROD3 22:00 - 00:00 2.00 DRILL WIPR PROD3 8/5/2005 00:00 - 11:00 11.00 DRILL WIPR PROD3 11:00 - 15:00 I 4.00 l LOG I DLOG PROD3 15:00-17:00 I 2.00 DRILL (WIPR PROD3 17:00 - 00:00 7.00 DRILL REAM PROD3 8/612005 00:00 - 01:00 1.00 DRILL REAM PROD3 01:00 - 03:15 2.25 DRILL CIRC PROD3 03:15 - 04:45 I 1.501 DRILL I CIRC I PROD3 Spud Date: 6/20!2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Descriptio+~ of Operations causing 3.6 bbls of MOBM to spill inside secondary containment inside rig, had 1 gal leak onto the secondary containment outside of rock washer. Changed out swab on #2 mud pump Drilled 8 1/2" Hole in "D" sand lateral from 13,561' to 14,340' MD/ 3,236' TVD, (779') ADT 5.6 hrs, 5-10K wob, 130 rpm's, 173 spm, 615 gpm, 4,100 psi, off btm torque 22-23K ft-Ibs, on btm 19-20K ft-Ibs, rot wt 112K, up wt 250K, do wt 35K, (blk wt), still having to rotate DP to set slips due to no down wt, began running 5" HWDP at 13, 422' with no change in do wt, 9.05 ppg mw, ave ECD 12.3 ppg, ave bgg 90 units, max gas 170 units, drilled thru a few concretions last 24 hrs Directionally drilled 8 112" Hole in "D" sand lateral with Geo-Pilot from 14,340 to 15,195' MD/ 3,214' TVD, (855') ADT 6.62 hrs, 5-15K wob, 130 rpm's, 169 spm, 600 gpm, 4-,100 psi, off btm torque 23-25K ft-Ibs, on btm 22K ft-Ibs, rot wt 100K, up wt with pumps on 205K, do wt 35K, (blk wt) 9.0 mw, ave ECD 12.3 ppg, ave bgg 70 units, max gas 160 units, Note: At 15,078' began taking torque readings with pumps on, still unable to get down wts without rotating Drilled 8 112" hole from 15,195' to 15,470' MD/ 3,208' TVD (275') ADT 2.67 hrs Circ hole with pump #2 while changing out swab on #1 mud pump Drilled 8 1/2" Hole in "D" sand lateral from 15,470' to 15,661' MD/ 3,208' TVD, (191') (T.D.) ADT 2.6 hrs, 5-15K wob, 120-130 rpm's, 162 spm, 575 gpm, 4,000 psi, off btm torque 26K ft-Ibs, on btm 25K ft-Ibs, with pumps on rot wt 95K, up wt 230K, do wt 35K, (blk wt) Drilled last 200' with directional only, no log data, ave bgg 50 units, surveyed at TD and monitored well-static. We were able to pump up a survey using 1 pump @ 360 gpm. Sperry said dropping the #2 pump lessoned the "pump noise" and a good siggnal was received to pump up survey. Began backreaming out of hole to window, BROOH from 15,661' to 15,360', BROOH at 110 rpm's 25K ft-Ibs torque, 580 gpm at 4,100 psi Backreamed out of hole from 15,360' to 9,617' MD/ 3,352' TVD, BROOH at 110 rpm's, 176 spm, 625 gpm at 4,000 psi, no problems BROOH or packing off MADD pass for caliper log from 9,617' to 9,476', logged at 80 rpm's, 15-24K ft-Ibs torque, 159 gpm, 565 gpm at 2,500 psi, circ hole clean while logging. RIH from 9,476' to 11,453' when we lost all down weight Washed and reamed from 11,453' to 14,946', washed down at 80 rpm's, 15-22K ft-Ibs torque, 113 spm, 400 gpm at 2,150 psi, MU an additional 11 stds DP with Lo-Tads while RIH, 69 total Lo-Tads in the hole, attempted several times to RIH with no pump and still had no down wt. Washed and reamed from 14,946' to btm at 15,661', washed down at 80 rpm's, 20-23K ft-Ibs torque, 113 spm, 400 gpm at 2,300 psi Pumped 35 bbl weighted hi vis sweep and circ hole clean at 15,661', had no increase in cuttings back from sweep and circ a total of 2X btms up and was clean at shakers, circ at 572 gpm at 4,100 psi, 140 rpm's with 20-23K ft-Ibs torque, after adding Lo-tads and moving HWDP up hole, torque was down 4-5K ft-Ibs and had good MWD signal. Initial ECD was 12.3 ppg, max during sweep was 12.7 ppg and after circ hole clean was down to 12.0 ppg and no gas Displaced hole over from 9.0 ppg MOBM to 9.0 ppg SFMOBM, circ at F'fffltB6: lUfG25/LUUb lU:ZB:Y/ AM • • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Start: 6120!2005 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Code Code Phase 8!6/2005 103:15 - 04:45 I 1.501 DRILL I CIRC 05:00 - 09:30 4.501 DRILL ITOR PV 09:30 -10:30 1.00 RIGMNT RSRV 10:30 - 11:00 0.50 RIGMNT RSRV 11:00 - 14:45 3.75 DRILL TRIP 14:45 - 16:00 I 1.251 DRILL I PULD 16:00 - 19:00 3.00 DRILL PULD 19:00 - 20:00 1.00 DRILL PULD 20:00 - 20:30 0.50 CASE RURD 20:30 - 20:45 0.25 CASE SFTY 18/7/2005 100:00 - 010:00 I 1.001 CASE PULR 01:00 - 01:30 I 0.501 CASE I PULR 01:30 - 01:45 01:45 - 08:30 08:30 - 09:45 09:45 - 10:15 10:15 - 14:15 Page 29 of 33 Spud Date: 6120!2005 End: 8/13/2005 Group: Description of Operations PROD3 572 gpm at 4,100 psi, 140 rpm's, rot wt 100K ,st wt up 280K, off btm torque 24-25K ft-Ibs PROD3 Monitored well-static PROD3 Dropped 1 15/16" rabbit and POOH on elevators from 15,661' to 9,230' with no problems, monitored well-static (TOW @ 9,391') PROD3 Slip and cut 74' of drlg line PROD3 Serviced top drive PROD3 POOH from 9,230' to BHA at 385', LD 2-8 1/2" ghost reamers, gauged same and were 1/8" undergauge PROD3 POOH from 385' to 111', stood back 1 std of HWDP, LD 2 jts HWDP, jars and 2 NMFDC's, held PJSM and removed radioactive sources, LD 1 more NMFDC PROD3 Downloaded MWD PROD3 Fin LD BHA #15, LD MWD and Geo-Pilot, cleared rig floor - CMPLT3 RU Doyons 5 1/2" liner running equipment CMPLT3 Held PJSM with rig crew and tong operator on liner running detail and - associated hazards CMPLT3 PU and RIH with 93 jts of 5 1/2" 15.5 ppf, L-80 slotted/blank liner per detail sheet to 4,000' CMPLT3 Cont to PU and. RIH with 5 1/2" liner from 4,000' to 6,080', PU a total of 145 jts of 5 112", 15.5#, L-80, BTCM Liner with torque rings per well program, RIH to 6,080', ran 5 1/2" ROT silver bullet guide shoe with no float, ran a total of 56 jts (2,384'} of 5 112" 15.5#, L-80, BTCM blank liner, ran 89 jts (3,738') of 5 1/2", 15.5# L-80 BTCM slotted liner, ran 128 - 5 1/2" x 8 1/4" spiralglide centralizers 1/jt #3 thru #144, ran 14 constrictor packers placed on blank liner to cover shale sections, did not run any centralizers on jts with constrictor packers. Accual Blank & Slot footage counting the 3' blank on each end of slotted joints= 2850' blank 46.8% and 3240' slotted 53.2°10. Total of 6090' CMPLT3 MU 7" tie-back assembly RlH to 6,191', MU 5 1/2" XO Jt to 7", 1-Jt of 7" csg and tie-back sleeve, st wt up 85K, do wt 52K 0.25 CASE RURD CMPLT3 RD Doyons liner running equipment and cleared rig floor 6.75 CASE RUNL CMPLT3 RIH with 5 1/2" liner on 5" DP from 6,191' to btm at 15,661', RIH to 12,476' and worked pipe down to btm, no problems thru whipstock, did not have to rotate liner to get to btm, took torque and drag readings while RIH, st up wt on btm 250K, do wt 45K, rot wt 112K, RIH with liner with 4 stds slick 5" DP, 69 stds DP with Lo-Tads, 11 stds slick and 15 stds of 5" HWDP. Took torque readings at: 6,285', st up wt 85K, do wt 52K, rot wt 65K, 20 rpm's = 3k ft-Ibs torque, 40 rpm's=2-4K ft Ibs 9,363', TOW, st wt up 135K, do wt 57K, rot wt 90K, 20 rpm's = 6,500 ft-Ibs torque, 40 rpm's = 6,500 ft-Ibs 10,534, st wt up 147K, do wt 53K, rot wt 90K, 20 rpm's = 9-11 K ft-Ibs torque, 40 rpm's = 9K ft-Ibs 15,661', st wt up 250K, do wt 45K, rot wt 112K, 40 rpm's = 20K ft-Ibs torque 1.25 CASE OTHR CMPLT3 Dropped 29/32" ball and pumped down to seat, pumped down at 4 bpm at 400 psi,slowed to 1 bpm, with ball on seat pressured up to 3,000 psi to release running tool, then pressured up to 3,720 psi and blew ball seat, PU and st wt up was 220K, top of 7" tie back sleeve at 9,483' 0.50 CASE CIRC CMPLT3 POOH from 9,482 to 9,394', est circ and washed top of whipstock face from 9,394' to 9,302', circ at 420 gpm at 1,400 psi 4.00 CASE RUNL CMPLT3 Monitored well-static, POOH wet from 9,302' to HR running tool at 20', Printed: 10/28/2005 10:29:27 AM • ConocoPhillips Alaska Page 30 of 33 Operations Summary Report Legal Well Name: 1E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code Phase Code 8/7/2005 10:15 - 14:15 4.00 CASE RUNL CMPLT3 14:15 - 15:00 0.75 DRILL PULD CMPLT3 15:00 - 16:15 1.25 FISH PULD CMPLT3 16:15 - 19:45 3.50 FISH TRIP CMPLT3 19:45 - 20:15 0.50 FISH FISH CMPLT3 20:15 - 21:15 I 1.001 FISH I CIRC I CMPLT3 121:18 - 00:00 I 2.751 FISH I TRIP I CMPLT3 00:00 - 04:00 I 4.00- FISH TRIP CMPLT3 04:00 - 05:30 1.50 FISH PULD CMPLT3 05:30 - 06:30 1.001 FISH ~ PULD ~ CMPLT3 06:30 - 07:30 I 1.00 I CASE I RURD {CMPLT3 07:30 - 07:45 f 0.251 CASE I SFTY I CMPLT3 07:45 - 08:45 I 1.001 CASE I PULR I CMPLT3 09:15 - 04:15 ~ 5.00 CASE RUNLD CMPLT3 14:15 - 17:30 I 3.251 CASE I OTHR I CMPLT3 17:30 - 20:00 I 2.501 CASE I OTHR I CMPLT3 20:00 - 20:45 I 0.751 CASE CIRC CMPLT3 20:45 - 21:30 I 0.751 CASE I OTHR I CMPLT3 21:30 - 22:30 I 1.001 CASE I CIRC I CMPLT3 Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations calc fill on trip out 87 bbls, actual fill 97 bbls LD Baker HR running tool and cleared rig floor MU whipstock retrieving BHA #16 and RIH to 337', MU retrieving hook, 1 jt HWDP, bumper sub, oil jars, pump out sub, 3-6.3/4" Dc's and 2 stds of 5" HWDP RIH with BHA #16 from 337' to 9,352', st wt up 218K, do wt 77K Hooked whipstock at 9,391' on 6th attempt. PU on whipstock and had 25K drag, did not see btm trip release, possibly due to over pull when pulling milling assembly loose, PU and stood back std, st wt up was 250K, after standing back std string wt dropped to 225K, set back down and tagged up 25' higher Stood back 1 std to 9,345' and circ btms up, circ at 420 gpm at 1,500 psi, max gas at btms up 20 units. Monitored well-static, POOH slow with whipstock assembly from 9,345' to 6,324' Cont to POOH with whipstock assembly from 6,324' to BHA #16 at 337' POOH and stood back 2 stds HWDP - LD 3-6 3/4" dc's, bumper sub, oil jars, pump out sub, 1 jt HWDP and retrieving hook and cleared rig floor of tools POOH and LD whipstock slide, 7 jts of 5" DP used for space out pipe and seals RU Doyon's 5 112" elevators and tongs, brough pup jts and XO subs to rig floor Held PJSM with rig crew and Baker Oil tool rep on MU hook hanger assembly and procedure to hook hanger and pressures required to set ECP packer MU "D" lateral hook hanger assembly with ECP Pkr RIH to 153', MU 5 1/2" bent jt, 1-5' pup j of 5 1/2" 15.5#, L-80 IBTM blank liner, ECP, 1-6',1-21' and 1-10' pupjts and hook hanger assembly RD Doyon's 5 1/2" elevators and tongs RIH with hook hanger assembly from 153' to above top of window to i 9,352', st wt up 200K, do wt 83K (TOW @ 9,391') i Worked bent jt thru window on 1st attempt setting down 40K at 9,407, ..did not see ECP Pkr go thru window, attempted to turn hook and go thru window, made approx 30- 1/2 round turns on DP and was unable to go deeper, stood back 1 std to 9,369' to above TOW Increased torque limiter on top drive and and rotated DP 20 turns and was able to work pipe down, worked pipe down to 9,555' well past no go, determined to be in main bore, PU to 9,375' and rotated pipe and after 12 1/4 turns worked hook hanger thru window and tagged no go at 9,535', PU to above TOW and after 8 attempts hooked hanger at BOW at 9,704', unhooked hanger and after several attempts re-hooked hanger setting 45K st wt down on hook, set top of hook hanger at 9,386' with bent jt spaced out 7' above 7" x 5 1/2" XO at 9,536' Dropped 29/32" ball and pumped down to seat, pumped at 3.5 bpm, 375 psi, with ball on seat pressured up to 850 psi and shut in RU Dowell and pressure test lines to 5,000 psi, bled down to 850 psi and opened Dowell to DP. Pressured up in 200 psi increments to observe ECP inflate at 2660 psi, pressure bled back to 1580 and stabilized for 5 min. Bled pressure to 850 psi. Check tank level and took .5 bbls to inflate ECP. Pressured up to 4,343 psi and sheared ball seat, bled off pressure. PU from top of hook hanger at 9,386' to 9,319', st wt up 225K, do wt Printed: 10/28/2005 102927 AM • ConocoPhillips Alaska ~ Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Start: 6/20/2005 Contractor Name: Rig Release: Rig Name: Rig Number: Date From - To Hours Code Phase Code 8/8/2005 21:30 - 22:30 1.00 CASE CIRC CMPLT3 22:30 - 00:00 1.50 CASE RUNL CMPLT3 8/9/2005 00:00 - 01:45 1.75 CASE RUNL CMPLT3 01:45 - 02:45 1.00 CASE PULR CMPLT3 02:45 - 03:15 0.50 CMPLTN RURD CMPLT3 03:15 - 03:30 0.25 CMPLTN SFTY CMPLT3 03:30 - 04:45 1.25 CMPLT PULD CMPLT3 04;45 - 10:15 I 5.501 CMPLTNI TRIP {CMPLT3 10:15 - 12:30 I 2.251 CMPLTNI TRIP I CMPLT3 12:30 - 16:45 ~ 4.25 ~ CMPLTNI TRIP ~ CMPLT3 16:45 - 17:15 0.50 CMPLTN RURD CMPLT3 17:15 - 19:00 1.75 CMPLTN PULD CMPLT3 19:00 - 19:15 0.25 WELCT OTHR CMPLT3 19:15 - 23:45 4.50 WELCT BOPS CMPLT3 23:45 - 00:00 0.25 WELCT OTHR CMPLT3 8/10/2005 00:00 - 01:00 1.00 RIGMNT RSRV CMPLT3 01:00 - 01:30 0.50 RIGMNT RSRV CMPLT3 01:30 - 05:45 4.25 DRILL PULD CMPLT3 05:45 - 06:30 0.75 CASE RURD CMPLT3 06:30 - 07:45 1.25 CASE PULR CMPLT3 07:45 - 08:00 0.25 CASE RURD CMPLT3 08:00 - 13:00 5.00 CASE RUNL CMPLT3 13:00 - 16:00 I 3.00 {CASE I RUNL {CMPLT3 16:00 - 17:45 I 1.75 {CASE {CIRC {CMPLT3 17:45 - 22:30 4.75 CASE ~ RUNL CMPLT3 22:30 - 22:45 0.25 CASE RURD CMPLT3 Page 31 of 33 Spud Date: 6/20/2005 End: 8/13/2005 Group: Description of Operations 77K, circ btms up from 9,319' at 180 spm, 640 gpm at 2,950 psi, monitored well-static POOH with hook hanger running tool from 9,319' to 6,771'. Cont to POOH with hook hanger running tool from 6,771' to running tool at 40' LD hook hanger running tool and cleared rig floor RU Doyon's 4 1/2" tbg handling tools Held PJSM wiith rig crew and tong operator on running of LEM MU "D" sand LEM assembly with SLZXP packer, hanger, CSR, LEM and 7 jts of 4 112" 12.6 ppf, L-80 IBT tubing and seals, RIH to 366' RIH with LEM assembly from 366' to top of hook hanger at 9,86', st wt up 210K, do wt 77K RIH with LEM from 9,386' and set down at 9,460', worked seal assembly approx 12 times trying to get to go thru hook with no success, 'worked pipe and rotated string at 15 rpm's with 15K ft-Ibs torque while attempting to go thru btm of hook at 9,407, st wt up 210K, do wt 77K rot wt 105K, appears collar above seals is setting down on XO bushing ,below hook on D lat Monitored well-static, POOH with LEM assembly from 9,460 to LEM at 366' RU Doyon's 4 1/2" tbg handling tools POOH LD LEM assembly with SLZXP packer, hanger, CSR, LEM and 7 jts of 4 1/2" 12.6 ppf, L-80 IBT tubing and seals, found collar above seals to show signs of where it was hitting on XO below hook, ZXP packer element had some scarring, sent packer to Baker to be re-dressed, talc fill on trip out of hole 85 bbls, actual 92 bbls Pulled wear bushing RU and tested valves, rams, annular and manifold to 250 psi low and 3,000 psi high, Note: Jeff Jones with AOGCC waived witnessing of test, RD test equipment Installed wear bushing Slip and cut 71' of drlg line Serviced top drive LD 38 stds of Weatherford 5" S-135 rental DP down from derrick while waiting on SLZXP packer to return from Baker Oil tools RU Doyon's 4 112" tbg handling equipment and held PJSM on running of LEM MU "D" sand LEM assembly #2 with SLZXP packer, hanger, CSR, LEM and 7 jts and 2-pup jts of 4 1 /2" 12.6 ppf, L-80 lBT tubing and seals, ~ RIH to 365' RD Doyon's 4 1/2" tbg handling equipment RIH with LEM assembly #2 from 365' to 9,343' (Top of Hook Hanger @ 9,386'), st wt up 205K, do wt 80K RIH from 9,343' and set down at 9,447', collar above seals tagging up at XO below hook at 9,413', rotated LEM and oriented seals thru hook after 4th attempt, cont to RIH and set down at 9,589', (87' F/Latching hook) attempted to work LEM down rotating string with no success, rotated at 10 rpm's with 15-17K ft-Ibs torque, st wt up 225K, do wt 75K, rot wt 110K Circ 1 complete circ from 9,589' while working LEM, would not go deeper, circ hole at 265 gpm at 750 psi, monitored well-static POOH with LEM assembly #2 from 9,589' to LEM at 365' RU Doyon's 4 1/2" tbg handling equipment and held PJSM on LO LEM rnnieo: wi~w~uuo -i u[ta:~i ruv~ • ConocoPhillips Alaska Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Event Name: ROT -DRILLING Contractor Name: Rig Name: Date From - To Hours Code Cade Phase 8/10/2005 ~ 22:45 - 00:00 ~ 1.25 ~ CASE ~ PULR ~ CMPLT3 8/11/2005 100:00 - 01:15 I 1.251 CASE !PULR !CMPLT3 01:15 - 02:30 I 1.251 FISH I PULD I CMPLT3 02:30 -06:00 3.50 FISH TRIP CMPLT3 06:00 - 07:30 1.50 FISH TRIP CMPLT3 07:30 - 09:30 I 2.00 FISH CIRC CMPLT3 09:30 - 10:30 If 1.00 FISH OTHR CMPLT3 811 212 0 0 5 10:30 - 12:30 I 2.001 FISH I TRIP I CMPLT3 12:30 - 12:45 0.25 FISH OTHR CMPLT3 12:45 - 16:00 3.25 FISH TRIP CMPLT3 16:00 - 18:00 2.00 FISH PULD CMPLT3 18:00 -19:00 1.00 I FISH f PULD CMPLT3 19:00 - 20:45 1.75 FISH I PULD CMPLT3 20:45 - 00:00 3.25 FISH TRIP CMPLT3 00:00 - 00:30 0.50 FISH TRIP CMPLT3 00:30 - 03:30 I 3.001 FISH I TRIP I CMPLT3 03:30 - 05:00 I 1.501 FISH CIRC I CMPLT3 05:00 - 05:15 0.251 DRILL I OBSV I CMPLT3 05:15 - 06:45 1.50 fI DRILL PULD CMPLT3 06:45 - 07:00 0.25 DRILL PULD CMPLT3 Page 32 of 33 Spud Date: 6/20/2005 Start: 6/20/2005 End: 8/13/2005 Rig Release: Group: Rig Number: Description of Operations POOH and LD 5LZXP packer, CSR and LEM, pkr, pkr element ck'd ok with only a couple of scratches, LEM had some scratches on upper OD of tool a{so, POOH to 4 1/2" tbg to 267', SLM out of hole, no correction Fin POOH from 267' LD remaining 4 1/2" tbg, POOH and checked seals, had 3-4 seals damaged leaving 8-9 good seals, changed out special clearance collar on seals to 5.2" IBT collar MU dummy run BHA #16 with seal assembly on bent jt, 10 jts 4 1/2" tbg with 7" OD boot basket and RIH to 353' RIH with BHA #16 from 353' and tagged top of hook hanger at 9,386', st wt up 220K, do wt 80K Oriented seal assembly and RIH below hook hanger and tagged up on XO below hook at 9,413', PU and re-oriented seal and on 2nd attempt went thru hook, cont RIH and tagged up at 9,589', same spot as last run, set down 10K uvt down, est circ at 6 bpm at 550 psi, est rotation at 15 rpm's with 15-16K ft-Ibs torque and set 10K wt down with no movement, st wt up 220K, do wt 78K, rot wt 115K Circ hole at 9,589' while working junk basket, circ at 150 spm, 533 gpm at 2,050 psi Attempted to work seals deeper, rotated on obstruction at 20 rpm's with 17-18K ft-Ibs torque with 1 OK wt down and circ hole at 50 spm, 178 ~ gpm at 700 psi was able to go down 3' to 9,592' Attempted to POOH, worked pipe from 9,592' to 9,385' pulling 25-35K over st wt, hole extremly tight possibly due to junk in hole, POOH to 9,331' to above top of hook at 9,386' Monitored well-static POOH from 9,331' to BHA #16 at 353' POOH and LD BHA #16, LD boot basket, 10 jts of 4 1/2" tbg, bent jt with seals, had 1 piece of brass with a few pieces of cement in junk basket, btm 3 collars where shined up with scrathes from iron, guide shoe on seals had 2 indentions on ID of seals PU tools for BHA #17 to rig floor MU reverse junk basket on BHA #17 and RIH to 362', MU 6 3/4" rev. junk basket, 2- 4 11/16" boot baskets,3-4 3/4" DC's, and 7 jts of 4" XT-39 DP{ and Rlh to 362' RIH with BHA #17 from 362' to 6,147 RIH with reverse circ junk basket on BHA #17 from 6,147' to 9,341', st wt up 210K, do wt 82K, est circ at 6 bpm at 750 psi, rotated string at 30 rpm's with 13-15K torque, rot wt 105K, do wt 105K, up wt 150K RIH from 9,341' began to see 10-15K drag at 9,398' (TOW @ 9,391'} circ hole and worked reverse junk basket down and tagged XO below hook at 9,413', attempted to go out of hook window with BHA #17 with no success, worked pipe approx 30 times and could not get to go thru window, tried numerous combinations trying to go thru window, with and without pumps, rotating pipe up different turns, rotating down etc. and wouldn't go thru. Decision was made to change hole over to brine, run 4 112" tbg and move rig off. POOH from 9,413' to above hook to 9,380', pumped 30 bbls sweep with 9.0 ppg brine and Safe Surf-O then displaced hole over from 9.0 ppg SFMOBM to 9.0 ppg Brine, circ hole at 8 bpm at 1,050 psi, 50 rpm's with 11-13K ft-Ibs torque, circ a total of 700 bbls of brine Monitored well-static, took SPR's POOH with BHA #17 from 9,380' to 8,424' LD 10 stds of 5" HWDP RIH with 5 stds of 5" HWDP to 8,885' Printed: 10!28/2005 1029:27 AM • CanocoPhillips Alaska Page 33 of 33 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Spud Date: 6/20/2005 Event Name: ROT -DRILLING Start: 6/20/2005 End: 811 312 0 0 5 Contractor Name: Rig Release: Group: Rig Name: Rig Number: Date .From - To Nours Code Code Phase 8/12/2005 107:00 - 16:30 I 9.501 DRILL I PULD I CMPLT3 16:30 - 19:15 I 2.751 DRILL I PULD I CMPLT3 19:15 - 21:00 I 1.751 FISH I PULL I CMPLT3 21:00 - 21:30 0.50 CMPLTN PULD CMPLT3 21:30 - 22:00 0.50 CMPLTN RURD CMPLT3- 22:00 - 22:15 0.25 CMPLTN SFTY CMPLT3 22:15 - 00:00 I 1.751 CMPLTNI RUNT I CMPLT3 18/13/2005 100:00 - 05:00 5.001 CMPLTNI RUNT I CMPLT3 05:00 - 05:45 I 0.751 CMPLTNI RUNT I CMPLT3 05:45 - 06:15 { 0.501 CMPLTNI SOHO I CMPLT3 06:15 - 07:00 I 0.751 CMPLTNI RURD I CMPLT3 07:00 - 11:00 I 4.001 CMPLTNI NUND I CMPLT3 11:00 - 12:00 1.00 CMPLTN RURD CMPLT3 12:00 - 13:00 1.00 RtGMNT RSRV CMPLT3 13:00 - 15:00 2.00 RIGMNT RSRV CMPLT3 15:00 - 16:30 I 1.501 CMPLTNI OTHR I CMPLT3 Description of Operations POOH with BHA #17 LD HWDP & DP from 8,885' to BHA at 362', tD 5 stds of 5" HWDP, 11 stds 5" stick DP, 69 stds of 5" DP with Lo-Tads and 4 stds of slick 5" DP to BHA (267 jts total) found many Lo-Tads to be worn and rollers flat spotted, cleaned rig floor RU mousehole and LD 37 stds of slick 5" DP out of derrick, LD a total of 408 jts of DP RU 4" handling equipment and POOH LD BHA #17 from 362', LD jars, 7 jts of 4" XT-39 DP, 2-boot baskets and 6 3/4" reverse circ junk basket, had no recovery in reverse circ junk basket or lower boot basket, in upper boot basket had 2 small pieces of metal and approx 1/2 cup of pieces of cement, talc fill on trip out of hole 83 bbls, actual fill 99 bbls Pulled wear bushing RU Doyon's 4 1/2" tbg.handling equipment Held PJSM with rig crew and tong operator on Winning order of 4 1/2" tubing and associated hazards PU seal assembly on 1 bent jt of 4 1!2" 12.6#, L-80 tbg, changed out used collar, then began PU and RIH with 4 1/2" 12.6#, L-80, IBT tubing to hang off in well, RlH with 55 jts of 4 1!2" tbg to 1,737' RIH with 4 1/2" kill string with bent jt and seal assembly from 1,737' to 9,362' (Top of Hook @ 9,386') st wt up 100K, do wt 55K, ran 247 jts of tbg (302 jts total) Cont to RIH and tagged XO below hook at 9,413' with end of seals at 9,446', PU rotating tbg to TOW at 9,391' and on 3rd attempt went thru 'hook, cont to RIH and tagged junk in hole at 9,592' PU and spaced out kill string with 2-4 1/2" pup jts (13.65'), MU full jt of tbg above pups and then MU hanger, landed hanger with no problems, landed tbg with end of seals at 9,590', st wt up 100K, do wt 53K (EOT ~2' above Junk) RIH with seals, 1-4 1/2" bentjt, 307 jts 4 1/2" 12.6 ppf, L-80 IBT tbg, 2-pup jts,1 jt tbg and hanger, total RIH 9,567.14 (RKB to ULDS 22.74') LD landing jt and RD Doyon's 4 1/2" handling equipment, Vetco Gray tested both upper and lower seals on hanger to 5,000 psi and tested each for 10 min, good test ND BOP's and set off stack, NU Vetco Gray 13 5/8" x 4 1/16" 5M Tree, tested tree and void to 5,000 psi each for 10 min, good test, pulled TWC and installed BPV and secured well Cleared rig floor, LD XO subs and cunt to clean mud pits and rock washer, cleaned out cellar box Slip and cut 62' of drlg line Changed out saver sub and serviced top drive while cont. to clean mud pits Fin cleaning mud pits and rock washer, Sim-Ops: moved camp, sewer plant and truck shop to 1 J pad, RELEASED RIG @ 16:30 hrs 8!13/05, Rig to move to 1J-168 Printed: 10!28!2005 10:29:27 AM • ConocoPhillips Alaska Page 1 of 9 Operations Summary Report Legal Wel{ Name: 1 E-117 Common Well Name: 1 E-117 Spud Date: 6/20/2005 Event Nam e: WORKO VER/R ECOM P Start: 9/24/2005 End: Contractor Name: Rig Release: Group: Rig Name: Nabors 3S Rig Number: Date From - To Hours Code Code Phase Description of Operations 9/24/2005 18:00 - 00:00 6.00 MOVE RURD DEMOB Rig down lower derrick and prepare to move to 1 E-117 9/25/2005 00:00 - 03;00 3.00 MOVE RURD DEMOB Rig down lower derrick and prepare to move to 1 E-117 03:00 - 09:00 6.00 MOVE MOVE DEMOB Move From 1 D to 1 E-117 Spot rig over well 09:00 -13:00 4.00 WAITON OTHR RIGUP Pre-job safety meeting. Prepare to spot rig. Call out BPV crew and install with scaffolding crew also. 13:00 -16:00 3.00 MOVE RURD DEMOB Spot rig and prep for rig up. 16:00 - 00:00 8.00 WAITON WOW RIGUP Except rig @ 16:00 hrs 9/25/200. Wind speed from 19 MPH to 34 MPH stand by for raising derrick. Chuck Scheavy AOGCC declined to witness BOP test tonight @ 07:OOPM 9!2612005 00:00 - 06:00 6.00 WELC NUND DECOMP ND tree and NU BOP's, 13 5/8 with variables 3.5"- 6" 06:00 - 13:00 7.00 WELC BOPS DECOMP Tower safety meeting continue to NU BOP's BOPE test waived by Chuck Sheavy @ 1900 hrs 9-25-2005. Perform BOPE test 250 PSI low, 3,000 PSI high. 13:00 - 14:00 1:00 WELCT NUND DECOMP Blow dwn all line and prepare to pull Two way check. 14:00 - 14:30 0.50 WELCT NUND DECOMP Pull Two way check. No pressure on well. 14:30 - 15:30 1.00 FISH SFTY DECOMP Pre-spud program. All hands for meeting. 15:30 - 17:30 2.00 FISH PULL DECOMP Prep rig floor for Pull. Pull hanger to floor. 67K up wt. no overpull while pulling out of hanger bowl. At 24' 15K over pull with normal fallback. Monitor wellbore for conditions. Clean and lay down hanger assym for inspection. Small mark onside. Vetco rep Erick says no problem. 17:30 - 18:00 0.50 FISH SFTY DECOMP Count 220 jts in pipe shed. All that will fit in our current configuration and still be able to lay down 4.5" kill string. BOPE drill. Shot fluid level @ 26' and holding 18:00 - 00:00 6.00 FISH SFTY DECOMP Night shift pre-spud program. Continue to POOH with 4.5" Kill string. Up WT. 72K 9/27!2005 00:00 - 06:00 6.00 FISH PULL DECOMP Continue to POOH with 4.5" kill string 06:00 - 12:00 6.00 FISH PULL DECOMP Pre Tower safety meeting, then continue pulling Kill string. Continue to work with fluid @ 26' below Kelly, DHD will shoot two fluid level shots per day 6:00 and 18:00. 41 bbl loss for the day. 12:00 - 15:00 3.00 FISH PULD DECOMP Out of the hole with the kill string. Strap remainder of pipe pulled, check OD of collars. All collars 5.17-5.20", pipe count /lengths matched run tally. Confer with workover engineer. 15:00 - 20:30 5.50 WAITON EOIP DECOMP Waiting on modifications to be made on mainbore diverter at Baker machine shop. Move remainder of PH-6 workstring into pipe shed and begin strapping. 20:30 - 23:30 3.00 WELLS EQRP DECOMP Ph-6 work-string loaded in pipe shed and strapped. BHA on location begin rigging up. 23:30 - 00:00 0.50 WELLS TRIP DECOMP BHA rigged up consisting of Diverter 5'long, with a 9.48' 4.51E pup, 3.5" X 4.5" IF XO 1.90' long, Sperry Sub 3.5" IF 2.89' long, with UBHO inside, a 3.5 IF pup 7.59' Tong and a XO 3.5" IF to PH-6 1.67' long. Followed by 300 joints of PH-6 work-string to surface UBHO is set to start 12 hours from 11:00 PM Tuesday. (or 11:00 AM) and will take samples for 16 hours @ 1 sample per min. until Thursday morning at 2:00 AM. Start tripping in the hole 9/28/2005 00:00 - 06:00 6.00 WELLS TRIP DECOMP Continue to trip Sperry's memory UBHO to verify orientation of Main bore Diverter ~ 06:00 - 11:40 5.67 WELLS TRIP DECOMP Pre tower safety meeting, high wind spead +_ 50 MPH Continue to trip Sperry's memory UBHO on 3.5 PH-6 tubing avg. about 26 joints per hour. Fluid level is aprox. 10' down from RKB. 43 bbl loss during for the day. 11:40 - 12:10 0.50 WELLS OTHR DECOMP Tag up at 9386'. PU wgt=75k, RIW=16k. Pick up off hook hanger...clean pickup, no overpull. RBIH and tag same, pick up to Printed: 10/28/2005 10:23:49 AM • ConocoPhillips Alaska Page 2 of 9 Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Spud Date: 6/20/2005 Event Name: WORKOVER/RECOMP Start: 9/24/2005 End: Contractor Name: Rig Release: Group: Rig Name: Nabors 3S Rig Number: Date From - To Hours Code Sub Code 9/28/2005 ~ 11:40 - 12:10 ~ 0.50 ~ WELLS OTHR Phase Description of Operations 12:10 - 12:35 { 0.421 WELLSF~ OTHR 12:35- 13:00 I 0.421 WELLSPoOTHR 13:00 -14:45 4 1.751 WELCTL OTHR 14:45 - 18:00 3.25 WELLS TRIP 18:00 - 00:00 6.00 WELLS TRIP 9/29/2005 00:00 - 01:30 1.50 WELLS EQRP 01:30 - 06:00 I 4.501 WELLSR TRIP 06:00 - 08:30 2.50 WELLS TRIP 08:30 - 09:30 1.00 WELLS PERF 09:30 - 11:00 I 1.50 I WELLSR PERF 11:00 -12:30 I 1.501 WELLSR PERF 12:30 - 18:00 { 5.50 { WELLSF~TRIP 23:00 - 00:00 I 1.00 ~ WELLS RURD 9/30/2005 f 00:30 - 02:30 I 1.00 WELLS TR PD 02:30 - 03:30 { 1.001 RIGMNTI RSRV DECOMP 103k, latched. Get 5 minute sample. Pick up, see tool unlatch at 100k. PUH 10' and rotate pipe w/ power tongs. 2 turns in (see turn at 4-5k torque), get 1-3/4 back. Get 5 minute sample. DECOMP Run back in hole and tag same; latch up. Get 5 minute sample. Pick up; see diverter unlatch again at 100k continue out 10'. Attempt to rotate, get 3/4 turn downhole. Get 5 minute sample. DECOMP Run back in hole and tag same; latch up. Get 5 minute sample. Attempt to pull free; 95k pulling out off hole dragging what appears to be the hook hanger. Pull up approx. 8'; dragging 95k. Attempt to run back in hole, stacking out. Shut down to confer and call W/O engineer. DECOMP Discuss options. Decide to attempt to "shuck" off hook hanger. Pull up hole a little quicker, 100-105k#...stifl just dragging. Run back in hole and re-attempt only pulling faster. At 120k pick up weight, see snap latch release leaving hook hanger at approx. 9374'.. DECOMP Begin puling out of hole racking back workstring, pumping hole fill. DECOMP Shoot fluid level; fluid approx. 175' down. Continue pulling out of hole. DECOMP Assembly BHA for Schlumberger gun run, consisting of 20.4' perf gun, 28.31' of CS HYD, 2.05' of XO, 14.02' space out pups, HR running tool 22.65', Bumper sub 7.86', XO to PH-6, and PH-6 work string to 9440' RKB to punch 9 holes in ECP. Fill hole with 15 bbls of 8.7 brine this brought the fluid level in the stack but it was dropping slowly. DECOMP BHA made up ready to start running stands of PH-6 work-string. Fluid level about 90' DECOMP Tower safety meeting Shoot fluid level to insure stable hole: Continue to RIH with PH-6 and perf gun Averaging 25 stands per HR. DECOMP Tag up in hook hanger at 5' down on jt. #30. RIW=17k, PUW=75k. Pull up hole to see if latched; slight wgt increase 5-6k# to 80K. Run back in hole, and set down in same spot, pull up hole of see if latched, same as previous attempt. Repeat with same results, not conclusive if latched. DECOMP Install headpin, rig to check for circulation. Establish ability to circulate, 1 bpm @ 200 psi. Drop ball and come online displacing at 1 bpm. Perf interval spaced out putting top shot at 9466`, cower shot at 9468'. Latched HR profile at 9419'. DECOMP 77 bbls away, see circulating pressure drop, rate increase. Good indication of gun firing. Attempt to run in hole, move freely 4'. Rig down headpin and begin pulling out of hole. No "bobbles" or drag seen through window, nothing definitive to show packer is on. Note: Sperry hand called to inform he was able to get info from UBHO tool. Sperry tool indicated diverter aligned 100 deg L of high side placing hanger oriented 180 deg R of high side. DECOMP Averaging about 18-20 stands/hr. Keeping hole full; losing approx 5 bbls/hr. Make crew changeout. DECOMP Continue to pull fishing string OOH DECOMP OOH with BHA Hook Hanger on HR running tool, and ECP packer al{ shots fired ECP deflated and on surface element intact. Rig up Clean out BHA consisting of a 4-5/8" junk basket, two 3-1/8" collars, 8-5/8" OD string milt, 4 joints 3-112" 13.3# HT38 drill pipe, and fishing jars on the 3-112" PH6 work string wash to the bottom of the "B" lateral LEM seal bore (4.75" ID; top at 9667' RKB and bottom at 9687'). DECOMP Continue to rig up Clean out BHA fluid level approximatety: 110' DECOMP RIH with cleanout BHA using 150 stands and 7 joints of 3.5" PH-6 tubing torque to 7000 psi DECOMP Rig maintenance slipping drill line. Fluid level 90' down, man rig floor Printed: 10/28/2005 10:23:49 AM • ConocoPhillips Alaska Page 3 of 9 Operations Summary Report Legal Weil Name: 1 E-117 Common Well Name: 1 E-117 Spud Date: 6/20/2005 Event Name: WORKOVER/RECOMP Start: 9/24/2005 End: Contractor Name: Rig Release: Group: Rig Name: Nabors 3S Rig Number: Date From - To Hours Code Sub Phase 9/30/2005 02:30 - 03:30 03:30 - 06:00 06:00 - 10:00 10:00 - 11:00 Code 1.00 I RIGMNTI RSRV 2.5011 WELLS HTRIP 4.001 WELLSI~TRIP 1.001 WELLSF~ M1LL 11:00 - 18:00 7.00 WELLS RURD 18:00 - 20:00 2:00 WELLS RURD 20:00 - 22:00 2.00 WELLS MILL 22:00 - 00:00 I 2.001 WELLSF~ RURD 110/1/2005 100:00 - 02:30 ~ 2.501 WELLSF~ RURD 02:30 - 06:00 I 3.501 WELLSR TRIP 06:00 - 18:00 I 12.001 WELLSt~ITRIP 18:00 - 21:00 I 3.00 I WELLS TRIP 21:00 - 00:00 3.00 WELLS RURD 110/2/2005 100:00 - 03:00 I 3.001 WELLSR RURD 03:00 - 06:00 I 3.00 I WELLSPo TRIP 06:00 - 07:30 I 1.501 WELLSF~ TRIP 07:30- 15:00 1 7.501 WELLSI~TRIP 15:00 - 18:00 I 3.001 WELLSR TRIP 18:00 - 00:00 I 6.001 WELLSPo TRIP ,10/3/2005 00:00 - 03:30 3.50 WELLS TRIP 03:30 - 05:00 1.50 WELLS TRIP Description of Operations DECOMP and monitor well DECOMP Continue to RIH with fishing string drill line slipped and ready to trip ' pipe. Hole stable, fluid level 90' from surface. ~ DECOMP Pre tower meeting continue RIH with cleanout string. Fluid loss to well= 73 bbl last 24 hrs, 193 bbls cummulative. Shoot fluid level, 54' from surface. DECOMP Tag up at 9470'. putting depth of string mill at 9400'. PUW = 87k. Pull up hole 10', attempt to rotate with power tongs while moving back in hole. Pipe rotating freely at 3800# of torque while moving. Rih to tag; pipe "torquing" at tag, 5500-6500#. Shut down and prep to rig up power swivel. DECOMP Conduct pre-job safety meeting on picking up 1 rigging up power swivel. Begin rig-up. DECOMP Crew change-out. Shoot fluid level=59' continue to rig up power swivel DECOMP Milling with string mill from 9390'-9396'. PUW = 85k. Pipe rotating at 6000# of torque about 36 RPM pump rate 3 BPM 1100 psi long way, RIH slowly, power swivel stalling out @ about 7000#. Work pipe free and attempt to mill down for two hours with same results making no hole. Concern over losing BHA below string mill (due to backlash from milling operation) resulted in Shut down milling with this BHA and rigging down power swivel. Circulating resulted in 50 of OBM returns to surface. DECOMP Rig down power swivel and prepare to come out of hole with PH-6 laying down ordered 290 bbls of 8.9 pps brine with 3% KCL. 4" XT-39 drill pipe from Doyon 141 on location load into pipe shed and strap. DECOMP Continue rigging down power swivel and prepare to come out of hole with PH-6 laying down ' DECOMP Power swivel laid down start pulling PH-6 laying. down sideways. Hole ' fill, pipe displacement plus 3 bbls per 10 JTS. Fluid down approximately 60'. Conduct BOP drill DECOMP Tower safety meeting continue to trip PH-06 OOH. Shoot fluid level =57'. Filling hole with pipe displacement, adding 2-3 bbls roughly every 5 stands. DECOMP Crew changeout. Continue out of hole with fishing string. DECOMP OOH with BHA, 8 5/8" string mill showed some scratches on smooth gauge of Mill. Clean floor, load 4" XT-39 drill pipe in shed and pick up Kelly. DECOMP Kelly picked up ready set floor up to rig up fishing BHA. Continue loading pipe shed and strapping XT-39 drill pipe. Drift 2.347" DECOMP Assemble Fishing BHA consisting of 8.5" Junk Basket, 8.625" String Mill, 6.25 Oil Jar, One 6" Drill Collar, and 4" XT-39 Dri11 pipe to surface. DECOMP Tower Safety meeting Ice conditions and safey use of spinner safety topics. Make up BHA and prep to begin RIH with 4"drill pipe, Mill and Junk Basket. Note: Lost 48bbls to formation in last 24 hrs. DECOMP Pipe skate broken; chain on skate has come apart. Begin hunting down parts, call out mechanic. Pull BHA back to surface. DECOMP Resume running back in hole with 4"drill pipe, milling string. Conduct spill drill DECOMP Crew changeout. Shoot fluid level= 120'. continue to RIH with 4" drill pipe average 25 jts. hour Rabiting Dri0 string 2.347" DECOMP Continue running back in hole with 4"drill pipe, milling string. DECOMP Pick up Kelly and tighten connections prepare to rotate through tight spot @ 9400' RKB Pf~nfetl: 10/28/2005 70:23:49 AM • • ConocoPhillips Alaska Page 4 of 9 Operations Summary Report Legal Well Name: 1 E-117 Common W ell Name: 1 E-117 Event Nam e: WORKO VER/R ECOM P Contractor Name: Rig Name: Nabors 3S Date From - To Hours Code Phase Code , 10/3/2005 05:00 - 07:00 2.00 WELLS MILL DECOMP 07:00 - 08:00 1.00 WELLS MILL DECOMP 08:00 - 09:00 1.00 WELLS MILL DECOMP 09:00 --11:00 2.00 WELLS MILL DECOMP I 11:00 - 12:30 1.50 WELLS CIRC DECOMP 12:30 - 14:30 2.00 WELLS CIRC DECOMP 14:30 - 18:00 3.50 WELLS TRIP DECOMP 18:00 - 00:00 6.00 WELLS TRIP DECOMP 10/4/2005 00:00 - 01:30 1.50 WELLS TRIP DECOMP 01:30 - 06:00 4.50 WELCT BOPE DECOMP 06:00 - 06:30 0.50 WELCT BOPE DECOMP 06:30 - 07:30 1.00 WELCT BOPE DECOMP 07:30 - 11:00 3.50 WELLS PULD DECOMP 11:00 - 17:30 6.50 WELLS TRIP DECOMP 17:30 -18:00 0.50 WELLS SFTY DECOMP 18:00 - 21:30 3.50 WELLS TRIP DECOMP 21:30 - 22:00 0.50 WELLS TRIP DECOMP 22:00 - 23:00 1.00 WELLS TRIP DECOMP 23:00 - 00:00 1.00 WELLS TRIP DECOMP 10/512005 00:00 - 06:00 6.00 WELLS TRIP DECOMP Spud Date: 6/20/2005 Start: 9/24/2005 End:, Rig Release: Group: Rig Number: Description of Operations Tagged obstruction @ 9392' RKB, rotating and working downfrom 9387' to dress up window. 60 RPM's pumping 2 BPM long way, torque gauge is not showing any torque, though off zero. 115K# up WT. 34K# down WT , 62K# down WT while rotating. Circulating at 2 bpm. 38 bbls lost in last 24 hrs, 287 bbls cumulative. Mill through to 9407'; see little to no "work" .Pull back through and make 2 more trips backreamming through. Down wgt. 30k, up wgt. 125k. Clean pickups through window. Make trip across window without rotating...clean pick-ups. Kelly buried; stop circulating pick up 10' of pups and work down to 9417'. Resume circulating at 2 bpm. Make 3 additional trips through window at 90 RPM. Trip again across window without rotating, 30k dn, 125k up, 70k rotating...clean pickups. Make 1 more trip back across window at 100 RPM. Stop circulating. Break out pups and pick up full jt. Resume circulating 2.0 bpm. Work through to Stop pumping. Begin picking up singles under Kelly and continue running in hole. Tag up 30' in on Kelly, jt #307 in hole (9646' orig RKB); come back online circulating bottoms up @ 3 bpm. Reciprocate with Kelly off bottom, make 3 trips to bottom while rotating, PUH after tag. 250 bbls around; break out Kelly and stand back. Begin pooh with 4" drillpipe, racking back. Begin filling hole across the top on the way out. 60 stands out of. Losing 3 bbls every 5 stands, swap back to filling pipe displacement, pumping extra every 5 stands. POOH with String Mill and Rev. Junk Basket. Junk Basket full of combination of Cement and Metal cuttings some of the cement pieces are 4" to 6" long metal cuttings some 2" to 3" long appear to be from window cutting operation. Rig up floor to start BOP testing. Cont to rig down BHA. Prepare for weekly BOP test. State witness of BOP test waived by John Crisp @ 3:00 pm 10/3. Function test BOP rams. Press test BOP and choke manifold to 250/3000 psi. Tower safety meeting currently BOP testing. Pressure test Kelly valves to 250 / 3000 psi. BOP Test completed at 07:30. Stand back Kelly and prep to pick up i drillpipe. i Pick up and run in hole with Bent jt of 5.5", Xovers and 4" Drill pipe. 'Tower safety meeting. Focus on pinch points and incident with floorhand getting finger pinched & fractured between 4" DP and DP Spinner Hawk. Cont RIH with 4" DP std's from derrick. Weights at 9360' 107 Klbs up/27 Klbs down. Tag up 6.5" OD x-over above 5.5" Bent joint on 6.25" ID X-over6 ft into 7" Tie-back, at 9506' RKB. Based on above, bottom of Bent joint at 9550'. Tie-back top is at 9500' and 7" x 5.5" X-over at 9553' RKB. L2 "D"-lateral liner is set 1 T deeper than reported. Pull back into main bore, rotate 6 turns, get 1.5 turns back. Trip in hole, take 4-5 Klbs weight from 9655' to hard tag. at 9660' RKB. Re-tag same depth and set down 8 Klbs. Estimate 5-6 ft of junk above seal bore below ZXP packer. POH racking 4" DP back stands in derrick Fill hole with displacement + 2-3 bbls everey 10 stands. 17 of 153 stands out at rpt time. Continue pooh with 4" DP and 5.5" bent joint assy. Depth at 06.00 hrs= Printed: 1l7l2B2005 1023:49 AM • • ConocoPhillips Alaska Page 5 of 9 I Operations Summary Report Legal Well Name: 1 E-117 Common W ell Name: 1 E-117 Spud Date: 6/20/2005 Event Nam e: WORKO VER/R ECOM P Start: 9/24/2005 End: Contractor Name: Rig Release: Group: Rig Name: Nabors 3S Rig Number: Date From - To Hours Code Phase Description of Operations Code 10/5/2005 00:00 - 06:00 6.00 WELLS TRIP DECOMP 1600 ft. 120 bbls 8.9 ppg brine 3% HCL lost to well last 24 hrs. 06:00 - 08:30 2.50 WELLS TRIP DECOMP Tower safety meeting. Cont pooh to surface. 08:30 - 09:30 1.00 WELLS PULD DECOMP Rig up to handle bent joint x-o's, break and lay down same. 09:30 - 11;30 2.00 WELLS PULD CMPLT3 Clear rig floor. Load pipe shed with Hook Hanger asst' and pup joints, bring same to rig floor. 11:30 - 12:00 0.50 RIGMNT RSRV CMPLT3 Lubricate and service rig. 12:00 - 16:00 4.00 WELLS PULD CMPLT3 Pick up and make up 5.5" bent jnt, 5.5" pup jnt's, ECP, 5.5" spacer pup jnt's, Model 'B' Hook Hanger and running tool. Details of Hook Hanger BHA under Pipe Tally, 16:00 - 17:00 1.00 WELLS OTHR CMPLT3 Clear and clean rig floor in preparation for tripping in hole. 17:00 - 18:00 1.00 WELLS TRIP CMPLT3 Rih with Hook Hanger BHA on 4" XT DP. Tower safety meeting. 18:00 - 00:00 6.00 WELLS TRIP CMPLT3 Continue rih wih HH BHA on 4" XT Drill Pipe. Depth at rpt time 6331 ft. 10/6!2005 00:00 - 03:00 3.00 WELLS TRIP CMPLT3 Cont rih to 9350'. Record up/down weights 1051-21 Klbs. 03:00 - 05:30 2.50 WELLS PLGM CMPLT3 Rih and slide to a stop at 9554'. Puh, increase speed dwn and tag 7" x 5,5" x-o in L2 "D" at 9556' rkb w/ full weight of string. Puh to 9550, rih ~ I confirm tag at 9556'. Puh w/ 10 Klbs o/pull to 9505', rotate 8 turns, get 5 back, rih set down at 9533'. Puh to 9520' w/ 20 Klbs o/pull. Increase i speed down and tag up 9554, puh & see 25 Klbs o/pull at 9549'. Rih tag 9556', puh hang up at 9539'. Rih 10', puh faster and slipped past restr w/ 45 Klbs o/pull, puh to 9520'. Rotate 12 turns, get 7 back. Rih tag 9556', puh hang up at 9543'. Free movement of pipe between 9543' and 9556', make +-30 attempts to pull past restriction av various speeds and and o/pull, max o/pull 75 Klbs (180 Klbs). 05:30 - 09:30 4.00 WELLS PLGM CMPLT3 Evaluate and discuss with town options to free and land hook hanger . 09:30 - 11:30 2.00 WELLS PLGM CMPLT3 Put 5 rounds torque in pipe, held with rig tongs. Worked up and down to work torque down to Hook for orienting Hook in window. Got 2 rounds back. Picked back up to 175K (50K overpull) still stuck but have 13' of travel. Worked up and down atempting to set Hook with no luck. Repeated procedure trying to work torque down to turn the Hook. On second attempt we got 5 1!2 turns back. Made third attempt putting 8 rounds in without holding torque with rig tongs. Released and got 3 turns back. Worked up and down 6 times, on down stroke of 6th attempt appeared to hook. Picked up to unhook and pulled over to 175K. Wt bled off to 150K, picked back up to 175K, original tight spot. Tried to go back down to where we hooked but could not-get all the way back down, 3' higher. Worked pipe up and down attempting to get loose, max pull was 225K. 11:30 - 14:30 3.00 WELLS PLGM CMPLT3 Evaluate and discuss options to free or shear HR. 14:30 -19:00 4.50 WELLS CMPLT3 RU head pin. Filled hole. Established circulation.2BPM @160 psi. Worked pipe while circulating still stuck no movement. Set weight down, dropped ball, ciruclated ball down at 3 BPM @ 220 psi for 60 bbls. Slowed pump down to 1.5 BPM @ 120 psi. Ball on seat at 85 bbls. Press up to 1400 psi, picked up was not released. Set wt back down press up to 1600 psi, bled off press. Picked up to 150K popped free, pulled free for 4' hung up again pulled up to 225K. Worked pipe up and down and rotating to work free. Pulled up to 235K and puNed free. Note: When released the Hook Hanger the top of hanger @ 9383', Hook @9404' and the mule shoe @ 9543'. 19:00 - 21:00 2.00 WELLS TRIP CMPLT3 Pooh to 8200' laying down 4" DP. ~, 21:00 - 00:00 3.00 WELLS TRIP CMPLT3 Tower safety meeting. Continue pooh laying down 4" DP. Depth at rpt time: 6100'. Lost 48 bbls brine to well last 24 hrs 10R/2005 00:00 - 02:30 2.50 WELLS TRIP CMPLT3 Continue pooh with Hook Hanger Running asst', laying down 4" XT39 Printed: 10/28!2005 10:23:49 AM • r ConocoPhillips Alaska Operations Summary Report Page G of 9 Legal Wefl Name: 1 E-117 Common Well Name: 1 E-117 Spud Date: 6/20!2005 Event Name: WORKOVER/RECOMP Start: 9/24/2005 End: Contractor Name: Rig Release: Group: Rig Name: Nabors 3S Rig Number: Date .From - To Hours Code Sub Phase __ _ Code 10/7/2005 00:00 - 02:30 2.50 WELLS~TRIP CMPLT3 02:30 - 03:30 1.00 WELLS OTHR CMPLT3 03:30 - 10:30 I 7.00 10:30 - 11:30 1.00 11:30 - 96:00 4.50 16:00 - 18:00 I 2.00 18:00 - 21:30 3.50 21:30 - 22:00 0.50 - 22:00 - 00:00 2.00 110/8/2005 100:00 - 05:30 I 5.50 05:30 - 06:30 I 1.00 06:30 - 11:00 4.50 11:00 -15:00 4.00 15:00 - 16:00 1.00 16:00 - 18:30 I 2.50 18:30 - 20:30 2.00 20:30 - 23:00 2.50 23:00 - 00:00 1.00 10/9/2005 00:00 - 07:30 7.50 07:30 - 09:00 1.50 09:00 - 13:00 4.00 13:00-14:00 1.00 14:00 - 20:00 6.00 I 20:00 - 20:30 0.50 20:30 - 00:00 3.50 10/10/2005 00:00 - 02:30 2.50 TRIP CMPLT3 TRIP CMPLT3 OTHR CMPLT3 OTHR CMPLT3 PULD CMPLT3 OTHR CMPLT3 TRIP CMPLT3 TRIP CMPLT3 TRIP CMPLT3 TRIP CMPLT3 TRIP CMPLT3 OTHR CMPLT3 OTHR CMPLT3 OTHR CMPLT3 PULD CMPLT3 TRIP CMPLT3 TRIP CMPLT3 TRIP CMPLT3 EQIP CMPLT3 PULD CMPLT3 TRIP CMPLT3 SFTY CMPLT3 TRIP CMPLT3 TRIP CMPLT3 Description of Operations DP. Swap 4" DP handling equipment, returning equipment belonging to Doyon 141. Cont pooh and laying down 4" XT39 DP. Lay down Baker HR running tool and associated jewelry. Unload pipe shed and rig floor of all and any Xt-39 drill pipe and handling tools and ship back to rig 141. Began loading pipe shed with 4" HT-38 drill pipe. Strapped all 4"-HT-38. Move BHA and handling equipment to rig floor. Pick up Main Bore Diverter, Sperry UBHO sub, bumper sub, and jars. Set UBHO to start recording at 05.10 hrs AM, 10/08(05, recording interval 1 min. Clear and clean rig floor in prep for tripping. Rih picking up 4" HT38 singles from pipe shed. Depth at rpt time 1381 ft. Lost 48 bbls 8.9 ppg brine to formation last 24 hrs. Cont trip in hole with Main Bore Diverter, Sperry UBHO, oil jar and .bumper sub, picking up 4" HT38 singles from pipe shed. Tower safety meeting. Focus on drop zones, lock-out procedures and handling DC's. Load remaining 4" HT38 DP into pipe shed and strap same. Cont rih with 4" HT38 DP from 6063' to 8670'. Picked up 15 - 6 1/8" Drill collars and 9 more jts of HT38 drill pipe. Up wt.= 111 K Dwn wt.=48K. Lowered diverted and latched up 9393.65',(top of hook hanger @ 9385' Hook @ 9406'). Set 15K down wait 10 min. PU pulling 115K dragging 10'. Wait 5 min. RIH set down 15K again at same depth, wait 10 min. PU pulling 115K again dragging, wait 5 min. RIH set 30K down at same depth. Wait 10 min. PU pulling 117K dragging. Pulled up 10' to connection, broke connection and set TIW valve. Discuss options with town. Tower safety meeting, focus on handling 6" i DC's ~ Rih from 9381', start to take wt @ 9393', set down all wt @ 9398' (18:54 hrs). Wait 10 min, DP slide to regain all down wt 40 Klbs (19:04 hrs). Cont rih with full wt 40 Klbs to 9402' (19:12 hrs, Hook @ 9414' RKB). Puh to 1st connection 9381' (19:54 hrs) with 90 - 95 Klbs. Reason for loss of up wt unknown. Cont puh to 9350', same up wt but indications of Hook Hanger assy being pulled through window. Pult 4 stands with 90-95 Klbs up wt. Pull and lay down 13 ea 6" XH DC's. Trip out of hole with 4" HT38 DP. Depth at report time 7800'. Lost 82 bbls brine to formation last 24 hrs. Cont pooh from 7800' racking back 4" HT38 DP stands in derrick. Tower safety meeting, focus on breaking and laying down BHA. Start laying down BHA. Did not recover Hook Hanger. LD Diverter. Discussed options with town Engineers. Wait on Baker HR running tool. PU and run in hole with Baker HR Tool (6.80" OD), bumper sub and jars on HT38 drill pipe to fish out Hook Hanger. Rih with 4" HT38 DP to 4800 ft. Kick / BOPE drill /audit, followed up by debrief and safety meeting. Cont trip in hole to 8200' with 4" HT38 DP stands from derrick. Lost 93 bbls brine to formation last 24 hrs. Cont rih stands from 8200' to 9345'. Check weights up 87 Klbs /down Printed: 10/28/2005 10:23:49 AM ~ • ConocoPhillips Alaska Page r of 9 Operations Summary Report Lega! Well Common Event Nam Contractor Rig Name: Date Name: Well Name: e: Name: From - To 1 E-117 1 E-117 WORKO Nabors Hours VER/R 3S Code ECOM Code P Phase 10/1012005 00:00 - 02:30 2.50 WELLS TRIP CMPLT3 02:30 - 04:00 1.50 WELLS TRIP CMPLT3 04:00 - 04:30 0.50 WELLS TRIP CMPLT3 04:30 - 12:30 8.00 WELLS TRIP CMPLT3 12:30 - 13:00 0.50 WELLS TRIP CMPLT3 13:00 - 14:00 1.00 WELLS TRIP CMPLT3 14:00 - 21:00 7.00 WELLS TRIP CMPLT3 21:00 - 22:30 1.50 WELLS WASH CMPLT3 i 22:30 - 00:00 1.50 WELLS TRIP CMPLT3 10/11!2005 00:00 - 05:00 5.00 WELLS TRIP CMPLT3 05:00 - 07:30 2.50 WELLS PULD CMPLT3 07:30 - 09:00 1.50 WELCT BOPE CMPLT3 09:00 - 11:30 2.50 WELCT ROPE CMPLT3 11:30 - 12:00 0.50 WELCT BOPE CMPLT3 12:00 -15:00 3.00 WELCT BOPE CMPLT3 15:00 - 18:00 3.00 WELCT BOPE CMPLT3 18:00 -19:00 1.00 WELCT BOPE CMPLT3 19:00 - 21:00 2.00 WELCT ROPE CMPLT3 21:00 - 22:30 1.50 WELLS OTHR CMPLT3 22:30 - 00:00 1.50 WELLS PULD CMPLT3 10/12/2005 00:00 - 04:00 4.00 WELLS TRIP CMPLT3 04:00 - 06:00 2.00 RIGMNT RSRV CMPLT3 06:00 - 08:DO 2.00 WELLS TRIP CMPLT3 08:00 - 09:15 1.25 FISH WASH CMPLT3 Spud Date: 6/20/2005 Start: 9/24!2005 End: Rig Release: Group: Rig Number: Description of Operations 27 Klbs. Cont rih to 9600' picking up singles, HR runninglpullingtoo! latch mechanism at 9590'. (Top of ZXP Packer at 9647' MD). No indications of weight fluctuations across window area. Weights up 95 /down 25 Klbs POOH past window to 9300' , no indications of weight fluctuations POOH with HR tool, standing back DP. Layed down BHA. Pick up and make up 8-1l2" Venturi Junk Basket, 8 jts 4" HT 38 drill pipe, bumper sub and oil jar. Tower safety meeting. RIH on 4" HT 38 drill pipe to 9375'. Check weights up 93 /down 30 Klbs. Cont rih tag up /set down 4 Klbs at 9397'. Pick up full wt at 9393', bumper sub open at 9391'. Rih set down 6000 Ibs at 9397. Set back stand, make up single and head pin. Pick up to 9350'. Rih while pumping at 4.6 BPM / 390 psi pump press. Tag up gently at 9397'. Repeat wash run same interval 3 times. See gradual incr in plu weigth, final p/u weight from tag was 110 Klbs, gradually dropping off until normal at +-75 ft above tag. Pooh racking back 4" HT38 DP stands in derrick. Depth at rpt time 6600'. Lost 91 bbls brine to formation last 24 hrs. Cont pooh from 6600' to 267' standing back4" HT38 DP in derrick. in Lay down 8.5" Venturi Jet Junk Basket BHA. Recover Minor cement 'rocks' and 3 pieces of steel, appr L 2" x W 0.4". Pictures of debris on NSK server. Make up running tool to test jnt, pull wear ring. Make up ported pump in sub, dart- & safety valves, test plug. Rih and land same in wellhead. Attempt to test Annular Preventer, leak at Choke Line HCR. Grease seals and re-test, still leaking. Blow down and ready to replace HCR. Replace leaking Choke Line HCR Perform weekly BOPE test to 250 psi ! 3000 psi. State witness of ROPE test waived by John Spaulding @ 12:00 pm 10/10/05. Pull test plug, set wear ring in wellhead, lay down test equipm. PJSM. Pick up Kelly, press test upper & lower Kelly valves to 250 psi ! 3000 psi. Break out test sub and stand back Kelly. Weekly BOPE test complete. PJSM. Remove BOP test equipm from rig floor- WOO- Clean and clear rig floor. Pick up BHA: 3.625" Venturi Jet Junk Basket w/ 4.625" Burning Shoe, Bit Sub, 62 ft of 2.875" PAC DC's, X-O's, 316 ft of 4" HT38 DP, Bumper Sub and Oil Jars. See DIMS Tally for details. Depth at rpt time 443 ft. i Lost 101 bbls of 8.9 ppg Brine to formations last 24 hrs. 'Trip in hole to 7670' with 4.625" Venturi Jet Junk Basket BHA on 4" HT38 DP std's from derrick. PJSM. Slip & Cut Drill Line. Continue trip in hole to 7670' with 4.625" Venturi Jet Junk Basket BHA on 4" HT38 DP std's from derrick. Record up and down wts just above Top of Hook hanger up wt = 98K dwn wt = 37K. Saw no movement of wt indicator when passing top of Hook hanger. Tagged top of ZXP @ 9647', set 5K on it an fell past. Tagged top of 5BE Xover @ 9664' set 5K down, no movement, set 10K down, fell thru. Lowered down and tagged bottom of of SBE @ 9687'. Printed: 10!28/2005 10:23:49 AM • ConocoPhillips Alaska Page 8 of g Operations Summary Report Legal Well Name: 1 E-117 Common W ell Name: 1 E-117 Spud Date: 6120!2005 Event Nam e: WORKO VER/R ECOM P Start: 9/24/2005 End: Contractor Name: Rig Release: Group: Rig Name: Nabors 3S Rig Number: Date From - To Hours Code Phase Description of Operations Code 10!12/2005 08:00 - 09:15 1.25 FISH WASH CMPLT3 NU headpin establish circulation 36PM @ 810 psi. Run down while pumping and tagged up at same 9687', made this same movement 3 times to clean out. 09:15 - 12:30 3.25 WELLS CIRC CMPLT3 Picked up to 9657' and circulated hole volume to balance well. 12:30 - 19:30 7.00 WELLS TRIP CMPLT3 Lay down 4 jts 4" HT 38 Drill Pipe and POOH standing back 150 stands. 19:30 - 21:00 1.50 WELLS PULD CMPLT3 Lay down BHA. Recover 1/6 gal cement lumps in Junk Basket barrel. See pictures on NSK server. 21:00 - 00:00 3.00 WELLS OTHR CMPLT3. Clear and clean rig floor, prep to run completion. Load completion assy's into pipe shed and strap same. 10/13!2005 00:00 - 02:00 2.00 WELLS PULD CMPLT3 Make final preparations to run completion. PJSM for completion. 02:00 - 09:00 7.00 WELLS PULD CMPLT3 Pick up & make up completion Sub Assy's: Seal Assy, 4.5" tbg Spacer Jot's, LEM, Premier Packer, Seal Bore Ext, Liner Setting Sleeve and Running Tool 09:00 - 16:00 7.00 WELLS TRIP CMPLT3 RIH 'D' Lateral LEM assy on 4" HT 38 drill pipe, on bottom at 16:00 16:00 -17:00 1.00 WELLS PLGM CMPLT3 Stopped to get up &dwn wts. UP=94K dwn=32K. Lowered LEM slowly past top of Hook @ 9397' clear, lowered past top of ZXP @ 9647' clear. Continued in hole to 9665' set 10k down, no movement. PU UP wt = 97K. Lowered back down tagged same @ 9665' set 10K down again no movement. PU UP wt 97K again. Lowered back down a little faster, tagged again @ 9665' put 10K down wt fell off. RIH to 9667' set 10k down no movement. PU UP wt= 103K. RIH tagged same spot @ 9667', set 15K down wt fell off. RIH steady down to 9675' set down 10K. PU UP 90K RIH set 15K down at same spot 9675'. Shut down activity, call Engineer. 17:00 - 18:30 1.50 WELLS PLGM CMPLT3 PU to UP wt 90K lowered at faster rate, set down at same spot 9675', put 20k wt fell off made 2' (9677'). Set all wt dwn (32K). PU to 110K to confirm Iatch.This put bottom seals in the middle of the "B" lateral LEM seal bore @ 9667'-9687' (9677'). 18:30 - 20:30 2.00 WELLS PLGM CMPLT3 Drop ball and circ same to seat with 80 bbls at 1.6 BPM / 150 psi. Press test surface lines to 4000 psi. Open headpin and pressure up to 4000 psi to set packer at 9369 ft (top of Premium Retrievable Packer). Clear indication of 2 sets of shear pins in packer shearing. Bled press off to 0 psi, PU to up wt 95K, free, pulled 2'. 20:30 - 21:00 0.50 WELLS DEQT CMPLT3 Close piperams, pressure up Drill Pipe x 9 5/8" csg annulus to 2500 psi / 30 min, good test, recorded on chart. Pump /bleed back 6.5 bbls. 21:00 - 22:00 1.00 WELLS RURD CMPLT3 RID Headpin, blow down kill&choke Tines and std pipe manifold. Clear and clean rig floor in prep for pooh. PJSM. 22:00 - 00:00 2.00 WELLS TRIP CMPLT3 Pooh with 4" HT38 laying down singles. 108 bbls brine lost to form last 24 hrs. Depth at report time 7900 ft. 10114!2005 00:00 - 15:00 15.00 WELLS TRIP CMPLT3 Continue tripping ooh laying down 4" HT38 DP and BHA. 15:00 - 19:00 4.00 WELLS TRIP CMPLT3 Lay down 2 stands from derrick pull wear ring. Rig down the kelly. PJSM 19:00 - 00:00 5.00 WELLS PULD CMPLT3 Load remainder of 4.5" tubing in pipe. shed and strap same. Replace seal rings and drift all joint's. Lost 108 bbls brine to formation last 24 hrs. 10!15/2005 00:00 - 01:00 1.00 WELLS RURD CMPLT3 Make final preparations to run completion 01:00 - 02:00 1.DO CMPLTN PULD CMPLT3 Pick up Seal Assy wl Muleshoe. Rih 2 ea 4.5" tbg jot's. Pick up and make up 'CMU' Sliding Sleeve Assy. 02:00 - 15:15 13.25 CMPLTN PULD CMPLT3 Rih with 4.5" 12.6# L-80 IBTM tubing joints. Weights UP 77 K /DOWN 27 K 15:15 - 17:30 2.25 CMPLTN SOHO CMPLT3 Tagged top of liner sleeve with muleshoe on depth @ 9321'. Pick up rotate to get into sleeve. Tagged bottom of crossover below the Liner Printed: 10l28I2005 10:23:49 ANf • • ConocoPhillips Alaska Page 9 of 9 ~ Operations Summary Report Legal Well Name: 1 E-117 Common Well Name: 1 E-117 Spud Date: 6/20/2005 Event Name: WORKOVER/RECOMP Start: 9/24/2005 End: Contractor Name: Rig Release: Group: Rig Name: Nabors 3S Rig Number. Date From - To Hours Code Phase Code 10!15/2005 15:15 - 17:30 2.25 CMPLTN SOHO CMPLT3 17:30 - 19:30 2.00 CMPLTN CIRG CMPLT3 19:30 - 20:00 0.50 CMPLTN SOHO CMPLT3 20:30 - 22:30 2.00 CMPLTN SOHO CMPLT3 22:30 - 00:00 1.50 WAITON EQIP CMPLT3 10/16/2005 00:00 - 01:00 1.00 CMPLTN SOHO CMPLT3 01:00 - 06:00 5.00 WAITON EQIP CMPLT3 06:00 - 07:30 1.50 CMPLTN SOHO CMPLT3 07:30 -12:00 4.50 WELLS NUND CMPLT3 12:00 - 12:30 0.50 WELLS PLGM CMPLT3 12:30 - 15:30 3.00 WELLS SEAT CMPLT3 15:30 - 16:00 0.50 WELLS PLGM CMPLT3 16:00 - 00:00 8.00 MOVE MOVE MOVE Description of Operations setting sleeve @ 9332' with locator, end of seats (muleshoe) @ 9349'. Set 10K down several times space out 2' off no-go. Layed down 3 jts. Installed space out pups, PU jt 306, make up hanger with head pin to pump corrosion inhibitor. Pumped 25 bbls 8.9 ppg brine with 2% by volume Petrolite CRW-132 (corrosion inhibitor) followed with 120 bbls 8.9 brine to spot. Close annular and bullhead 10 bbls @1:6 BPM ! 8Q psi. Open Annular Preventer. Drain BOP stack. Rih with Tubing Hanger, orient and land same. Make up Lock Down Bolts, back out & lay down landing joint. Press test between seals on Tubing hanger to 4000 psi. Found orientation of Tbg Hanger side outlet to be appr 180 deg oposite flow line outlet on Well Head. B/O Lockdown Bolts. Install landing jnt and pull Tbg Hanger to Rig Floor, confirm orienting slot to be incorrectly machined I no match to wellhead. Locate replacement Tubing Hanger at KCC, wait for same to arrive on location. Lost 95 bbls brine to formation last 24 hrs. Bring replacement Tubing Hanger to rig floor. Attempt to make up lift sub to 4.909" MCA Box top of hanger, no-go, 1 thread entered only. Attempt to m/u landing jnt to 4.909" MCA Box. No-go. Lay down tbg hanger. Hot shot replacement tubing Hanger to Baker Machine Shop, Deadhorse. Machine threads and return to location. MU new tubing hanger, RIH and orient and land same. Confirm side outlet lines up with flow line. RILDS. Set BPV. ND ROPE. NU tree. Set two way check. Test tree to 250 / 5000 psi. Tubing hanger void 1 packoff to 250 !5000 psi. Pull two way check and set BPV, secure well, clean cellar area, Release rig ~, @1600 hrs 1011612005. '.Prepare rig for move to 1 E-117, Lower derrick at 19.30 hrs - Puli pipe shed & pits away. Move rig from !E-117 to 1E-170. Printed; 10/28/2005 10:23:49 AM DEFI[y~~'4y~ Halliburton Sperry-Sun Western North Slope ConocoPhillips Kuparuk 1 E 1 E-117L2 Job No. AK-ZZ-0003775114, Surveyed: 4 August, 2005 Survey Report 1 September, 2005 Your Ref: AP1500292325161 Surface Coordinates: 5959600.86 N, 550300.51E (70° 18' 01.4269" N, 149° 35' 33.4054" V1~ Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 959600.86 N, 50300.51E (Grid) Surface Coordinates relative to Structure: 162.13 S, 409.92E (True) Kelly Bushing Elevation: 94.90ft above Mean Sea level Kelly Bushing Elevation: 94.90ft above Project V Reference Kelly Bushing Elevation: 94.90ft above Structure i'sl'e-51.~'f'1 GRILLING SERViCHS SurveyRef.•svy2200 A Nalliburton Company Ha/liburton Sperry-Sun Survey Report for Kuparuk 1 E - 1 E-117L2 Your Ref: API 500292325161 Job No. AK-ZZ-0003775114, Surveyed: 4 August, 2005 Western North Slope ConocoPhillips Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 10915.59 91.500 179.060 321523 3310.13 9364.94 S 2011.86E 5950249.59 N 552375.01E 9364.94 Tie-On Point 10980.00 91.630 179.360 3213.47 3308.37 9429.32 S 2012.74E 5950185.22 N 552376.33E 0.507 9429.32 Window Point 11007.71 91.650 177.530 3212.68 3307.58 9457.01 S 2013.50E 5950157.54 N 552377.27E 6.602 9457.01 11100.27 91.800 183.330 3209.89 3304.79 9549.49 S 2012.80E 5950065.06 N 552377.19E 6.265 9549.49 11194.26 91.060 181.750 3207.54 3302.44 9643.35 S 2008.64E 5949971.17 N 552373.66E 1.856 9643.35 11286.57 91.810 180.420 3205.23 3300.13 9735.61 S 2006.89E 5949878.90 N 552372.53E 1.654 9735.61 11380.06 91.240 181.010 3202.74 3297.64 9829.06 S 2005.72E 5949785.44 N 552371.99E 0.877 9829.06 11472.43 91.190 180.890 3200.78 3295.68 9921.40 S 2004.19E 5949693.10 N 552371.07E 0.141 9921.40 11564.66 91.870 180.660 3198.32 3293.22 10013.59 S 2002.95E 5949600.90 N 552370.44E 0.778 10013.59 11657.14 91.740 180.670 3195.41 3290.31 10106.02 S 2001.87E 5949508.47 N 552369.99E 0.141 10106.02 11751.00 90.440 179.710 3193.62 3288.52 10199.85 S 2001.56E 5949414.63 N 552370.31E 1.722 10199.85 11844.96 91.000 179.570 3192.44 3287.34 10293.80 S 2002.15E 5949320.69 N 552371.53E 0.614 10293.80 11939.21 90.630 179.550 3191.10 3286.00 10388.04 S 2002.88E 5949226.46 N 552372.88E 0.393 10388.04 12029.38 90.750 178.860 3190.02 3284.92 10478.20 S 2004.13E 5949136.31 N 552374.73E 0.777 10478.20 12091.77 91.190 178.100 3188.96 3283.86 10540.56 S 2005.78E 5949073.97 N 552376.81E 1.407 10540.56 12183.70 90.940 178.530 3187.25 3282.15 10632.43 S 2008.48E 5948982.11 N 552380.12E 0.541 10632.43 12275.99 90.630 178.620 3185.99 3280.89 10724.68 S 2010.78E 5948889.88 N 552383.04E 0.350 10724.68 12368.59 90.510 178.560 3185.07 3279.97 10817.25 S 2013.06E 5948797.33 N 552385.93E 0.145 10817.25 12462.58 90.760 178.850 3184.02 3278.92 10911.21 S 2015.18E 5948703.38 N 552388.69E 0.407 10911.21 12554.56 90.820 179.240 3182.76. 3277.66 11003.17 S 2016.71E 5948611.44 N 552390.84E 0.429 11003.17 12647.58 90.750 180.550 3181.48 3276.38 11096.18 S 2016.89E 5948518.43 N 552391.63E 1.410 11096.18 12739.91 90.750 182.000 3180.27 3275.17 11188.47 S 2014.83E 5948426.12 N 552390.19E 1.570 11188.47 12834.32 91.310 184.080 3178.58 3273.48 11282.73 S 2009.83E 5948331.84 N 552385.82E 2.281 11282.73 12926.62 90.880 184.520 3176.81 3271.71 11374.75 S 2002.91E 5948239.77 N 552379.51E 0.666 11374.75 13019.70 91.060 183.070 3175.24 3270.14 11467.61 S 1996.75E 5948146.87 N 552373.98E 1.570 11467.61 13111.30 90.750 182.240 3173.79 3268.69 11559.10 S 1992.50E 5948055.35 N 552370.35E 0.967 11559.10 13205.31 91.250 180.690 3172.15 3267.05 11653.06 S 1990.10E 5947961.38 N 552368.57E 1.732 11653.06 13298.28 91.560 180.420 3169.87 3264.77 11746.00 S 1989.20E 5947868.44 N 552368.29E 0.442 11746.00 13389.18 91.060 180.290 3167.79 3262.69 11836.88 S 1988.64E 5947777.56 N 552368.34E 0.568 11836.88 13480.35 91.930 178.860 3165.41 3260.31 11928.01 S 1989.31E 5947686.44 N 552369.63E 1.836 11928.01 13573.02 91.430 179.280 3162.70 3257.60 12020.63 S 1990.82E 5947593.83 N 552371.75E 0.705 12020.63 13667.00 91.930 180.810 3159.94 3254.84 12114.56 S 1990.74E 5947499.89 N 552372.30E 1.712 12114.56 13756.98 91.560 181.370 3157.20 3252.10 12204.48 S 1989.03E 5947409.96 N 552371.20E 0.746 12204.48 13850.75 91.430 180.700 3154.75 3249.65 12298.21 S 1987.34E 5947316.23 N 552370.13E 0.728 12298.21 13942.12 91.560 180.340 3152.37 3247.27 12389.54 S 1986.51E 5947224.89 N 552369.91E 0.419 12389.54 • • 1 September, 2005 - 16:00 Page 2 of 4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for Kuparuk 1E- 1E-117L2 Your Ref: AP1500292325161 Job No. AK-ZZ-0003775114, Surveyed: 4 August, 2005 ConocoPhillips Western North Slope Measured True Sub-Sea Vertical Local Coordinates Global Coo hi rdinates Eastings Dogleg Rate Vertical Section Comment Depth Incl. Azim. Depth Depth Northings Eastings ft ngs Nort (ft) (ft) (°/100ft) (ft) (ft) (ft) (ft) ) ( 63 14030 120 92 180.350 3149.53 3244.43 12478.00 S 1985.98E 5947136.43 N 552369.97E 04E 552370 0.633 742 0 12478.00 12570.95 . 14123.62 . 91.430 180.330 3146.65 3241.55 12570.95 S 1985.43E E 5947043.49 N 50 N 5946951 . 05E 552370 . 0.170 12662.93 14215.63 91.310 180.430 3144.45 3239.35 12662.93 S 1984.82 56E 4 . 74 N 5946858 . 552370.42E 0.752 12755.69 14308.43 91.740 179.880 3141.98 3236.88 12755.69 S . 198 75E 1984 . 36 N 5946768 552371.20E 0.343 12846.07 14398.84 91.430 179.890 3139.48 3234.38 12846.07 S . . 85 14490 620 91 179.190 3137.03 3231.93 12938.04 S 1985.48E 5946676.40 N 552372.56E 55E 552374 0.788 204 0 12938.04 13028.25 . 14581.11 . 91.740 179.050 3134.38 3229.28 13028.25 S 1986.87E 5946586.20 N 88 N 5946493 . 40E 552376 . 0.665 13120.58 14673.48 91.250 179.420 3131.97 3226.87 13120.58 S 1988.10E . . 8 7 39 S 13309 79E 1988 5946305.08 N 552378.35E 0.499 13309.39 14862.34 91.560 9.630 1 .40 312 3222.30 . . 46 14953 91 180 180.390 3125.22 3220.12 13400.48 S 1988.77E 5946213.99 N 552378.94E 39E 552379 0.932 830 0 13400.48 13495.82 . 15048.83 . 91.750 179.840 3122.78 3217.68 13495.82 S 1988.58E 5946118.66 N 40 N 5946027 . 552380.46E . 0.747 13587.08 15140.12 91.120 179.580 3120.50 3215.40 13587.08 S 1989.04E 72E 1989 . 87 N 5945932 552381.77E 0.067 13681.62 15234.68 91.060 179.600 3118.70 3213.60 13681.62 S S . 17E 1990 . 5945839.79 N 552382.84E 0.279 13774.70 15327.78 91.130 179.850 3116.92 3211.82 13774.70 . 82 15420 190 91 179.920 3115.04 3209.94 13867.72 S 1990.35E 5945746.77 N 8 N 552383.65E 08E 552384 0.099 088 1 13867.72 13960.41 . 15513.52 . 90.260 180.310 3113.86 3208.76 13960.41 S 1990.17E 8E 5945654.0 87 N 5945561 . 552384.22E . 0.207 14052.63 15605.74 90.450 180.290 3113.29 3208.19 14052.63 S 1989.6 68E 1989 . 36 N 5945537 552384.38E 2.407 14077.14 15630.25 90.450 179.700 3113.10 3208.00 14077.14 S . 85E . 61 N 5945506 552384.75E 0.000 14107.89 Projected Survey 15661.00 90.450 179.700 3112.86 3207.76 14107.89 S 1989. . All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 180.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 15661.OOft., The Bottom Hole Displacement is 14247.52ft., in the Direction of 171.972° (True). • C~ DrillQuest 3.03.06.008 1 September, 2005 - 15:00 Page 3 of 4 Western North Slope Comments Measured Depth (ft) 10915.59 10980.00 15661.00 Halliburton Sperry-Sun Survey Report for Kuparuk 1E - 1E-117L2 Your Ref.' AP1500292325161 Job No. AK-ZZ-0003775114, Surveyed: 4 August, 2005 Station Coordinates TVD Northings Eastings Comment (ft) (ft) (ft) 3310.13 9364.94 S 2011.86E Tie-On Point 3308.37 9429.32 S 2012.74E Window Point 3207.76 14107.89 S 1989.85E Projected Survey Survev tool program for 1 E-117L2 From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey 7001 Description (ft) (ft) (ft) (ft) 0.00 0.00 534.60 533.84 CB-SS-Gyro (1E-117P61) 534.60 533.84 15661.00 3207.76 MWD+IIFR+MS+SAG (1E-117PB1) ConocoPhillips • 1 September, 2005 - 16:00 Page 4 of 4 DrillQuest 3.03.06.008 DEFli~!?e~~ Halliburton Sperry-Sun Western North Slope ConocoPhillips Kuparuk 1 E 1 E-117L2PB1 • Job No. AK-ZZ-0003775114, Surveyed: 1 August 2005 Survey Report 1 September, 2005 Your Ref.• API 500292325172 Surface Coordinates: 5959600.86 N, 550300.51E (70° 18' 01.4269" N, 149° 35' 33.4054" Vl~ Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 959600.86 N, 50300.51E (Grid) Surface Coordinates relative fo Structure: 162.13 S, 409.92E (True) Kelly Bushing Elevation: 94.90ft above Mean Sea Level Kelly Bushing Elevation: 94.90ft above Project V Reference Kelly Bushing Elevation: 94.90ft above Structure She "~1'~y_SU't"l DRILLING SE~tytCi=s Survey Ref: svy2199 A Halliburton Gompa ny Ha(liburton Sperry-Sun Survey Report for Kuparuk 1E - 1E-117L2P61 Your Ref.• API 500292325172 JoB No. AK-ZZ-0003775114, Surveyed: 1 August, 2005 Western North Slope Measured True Sub-Sea Vertical Local Coordi nates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 9337.18 78.160 178.010 3236.42 3331.32 7791.64 S 1950.83E 5951822.46 N 552303.45 E -. 9391.00 78.100 178.080 3247.49 3342.39 - 7844.27 S 1952.63E 5951769.83 N 552305.60 E 9467.83 84.310 176.480 3259.23 3354.13 7920.07 S 1956.24E 5951694.06 N 552309.72 E 9564.22 93.680 174.510 3260.92 3355.82 8016.04 S 1963.80E 5951598.15 N 552317.93 E 9582.25 93.780 175.270 3259.75 3354.65 8033.96 S 1965.40E 5951580.24 N 552319.65 E 9677.67 92.600 176.960 3254.44 3349.34 8129.01 S 1971.86E 5951485.23 N 552326.74 E 9776.57 93.040 176.410 3249.57 3344.47 8227.62 S 1977.57E 5951386.66 N 552333.11 E 9872.27 94.840 179.640 3242.99 3337.89 8323.02 S 1980.86E 5951291.28 N 552337.04 E 9969.71 93.160 178.600 3236.20 3331.10 8420.21 S 1982.35E 5951194.11 N 552339.19 E 10067.06 92.480 175.070 3231.40 3326.30 8517.28 S 1987.72E 5951097.08 N 552345.20 E 10162.48 90.620 175.290 3228.82 3323.72 8612.32 S 1995.74E 5951002.09 N 552353.85 E 10260.62 90.880 177.030 3227.54 3322.44 8710.23 S 2002.31E 5950904.23 N 552361.08 E 10355.63 91.750 178.460 3225.36 3320.26 8805.14 S 2006.05E 5950809.35 N 552365.45 E 10453.61 91.310 179.230 3222.74 3317.64 8903.06 S 2008.02E 5950711.44 N 552368.08 E 10544.18 91.000 179.120 3220.92 3315.82 8993.60 S 2009.32E 5950620.91 N 552369.99 E 10636.97 91.130 180.650 3219.19 3314.09 9086.37 S 2009.51E 5950528.14 N 552370.80 E 10729.57 90.690 179.440 3217.72 3312.62 9178.96 S 2009.44E 5950435.56 N 552371.35 E 10822.58 90.440 179.260 3216.80 3311.70 9271.96 S 2010.49E 5950342.57 N 552373.02 E 10915.59 91.500 179.060 3215.23 3310.13 9364.94 S 2011.86E 5950249.59 N 552375.01 E 11010.97 94.540 179.510 3210.21 3305.11 9460.17 S 2013.05E 5950154.37 N 552376.84 E 11101.20 94.520 180.290 3203.08 3297.98 9550.12 S 2013.20E 5950064.43 N 552377.60 E 11194.21 92.040 178.400 3197.76 3292.66 9642.96 S 2014.27E 5949971.60 N 552379.28 E 11288.11 89.820 179.360 3196.23 3291.13 9736.82 S 2016.10E 5949877.75 N 552381.74 E 11380.17 91.070 181.030 3195.52 3290.42 9828.87 S 2015.79E 5949785.70 N 552382.05 E 11447.16 91.440 182.890 3194.05 3288.95 9895.81 S 2013.50E 5949718.75 N 552380.20 E 11479.00 91.440 182.890 3193.25 3288.15 9927.60 S 2011.89E 5949686.95 N 552378.81 E All data is in Feet (US Su rvey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relativ e to Well. Northings and Eastings are re lative to Well. Global Northin gs and Eastings are rel ative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees pe r 100 feet (US Survey). Vertical Section is from Well and calc ulated along an Azimuth of 1 80.000° (True). Based upon Minimum Cu rvature type calculations, at a Measured Depth of 11479.OOft., The Bottom H ole Displacement is 10129 41ft., in the Direction of 1 68.544° (True). ConocoPhillips Dogleg Vertical Rate Section Comment (°/100ft) 7791.64 Tie-On Point 0.169 7844.27 Window Point 8.340 7920.07 9.933 8016.04 4.243 8033.96 2.158 8129.01 0.712 8227.62 3.857 8323.02 2.026 8420.21 3.688 8517.28 • 1.963 8612.32 1.793 8710.23 1.761 8805.14 0.905 8903.06 0.363 8993.60 1.655 9086.37 1.390 9178.96 0.331 9271.96 1.160 9364.94 3.222 9460.17 0.862 3.350 2.576 2.266 2.830 0.000 9550.12 9642.96 9736.82 9828.87 9895.81 9927.60 Projected Survey • 1 September, 2005 - 15;56 Page 2 of 3 DriliQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for Kuparuk 1E- 1E-117L2P61 Your Ref.• API 500292325172 Job No. AK-ZZ-0003775114, Surveyed: 1 August, 2005 Western North Slope Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 9337.18 3331.32 7791.64 S 1950.83E Tie-On Point 9391.00 3342.39 7844.27 S 1952.63E Window Point 11479.00 3288.15 9927.60 S 2011.89E Projected Survey Survev tool program for 1E-117L2PB1 From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 534.60 533.84 CB-SS-Gyro (1E-117PB1) 534.60 533.84 11479.00 3288.15 MWD+IIFR+MS+SAG (1E-117P61) ConocoPhillips • • 1 September, 2005 - 15:56 Page 3 of 3 DrillQuest 3.03.06.008 • 23-Sep-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1 E-117 L2 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 10,915.59' MD Window /Kickoff Survey: 10,980.00' MD (if applicable) Projected Survey: 15,661.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date_ 1~ ~ 1 Signed - Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~o~ -~a~ • • 23-Sep-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1E-117 L2 PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 9,337.18' MD Window /Kickoff Survey: 9,391.00' MD (if applicable) Projected Survey: 11,479.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ~~~~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~~~~~~~ • ~ ~ , ~j ~ ,~ ~ ALASSA OIL A1~TD GAS COI~TSER~A7`I011T COMI-II55IO1Q Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99519 Re: 1 E-117 L2 Sundry Number: 305-325 Dear Mr. Dethlefs: FRANK H. MURKOWSKI, GOVERNOR 333 W. 7"' 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. Please provide at least twenty-four (24) hours 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. DATED this~~day of October, 2005 Encl. Sincerely, 1b111/2dt~5 17:57 } 907659 NSK WELLS GRO~ STATE dF ALASKA ALF, iKA QIL AND GAS CONSERVATION GQMMiSSION APPLII;ATIO~1 FOR SUNDRY AI~PROVAL 20 AAC 25.286 ~~ PAGE 03 1, Type'dPtO~st; Abantlon ^ :: spend ^ Operational 5nutdovm ^ Partorgte U Waiver Q Oth¢r [~ Alter casing © Rai: air w®u ^ Plug Pertoratlon4 ^ SUmutate ^ time Extenaan [~ Change approved program ^ Pull cubing ^ Perforate New Poot ^ Re•enxer Suspended Welt ^ 2. Operator Nam®~ 4. Current Well Ctass~ 5, Permit to Drilt Number: ConvcoPhilti s Alaska, Inc. Development ^ Exploratont ^ 205-028 ~~ 3, Address: Stratlgraphlc ^ 6. API Number. Service ^ P, d, Box 100360 Ancftora e, Alaska 9951' ~ 50-029`23251'61 7. KS Elevakion (ftj: 9. Well Name and Number: RKB 95' 1 E•117 L2 8. Property Designation: 10. Field/Pool(s): Kuparuk River Unik Kuparuk River Field /West Sak Oil Pool 11. PRESENT WEI,I_ CONDITI ON SUMMARY Total depth MD {ft}: Total Depth TVD (R)' EfreCfi ~e Deptn MD (R): Effective Depth ND (ft): Plugs {measured); Junk {measured): 15774' 3415' 15751 3625 Casing LengEh Size MD TVD Bur3t Collapse CONDUCTOR 108' ZO" 108' 108 SURFACE 544g~ 13-318" 5543' 2364 INl`ERMEQIATE 10477' 9-5l8" 1Q572' 3510 UNDULATING A- SAND SLOTTED 3415 LINER 5369' S-1 !2" 15751' Pertordtion Depth MD (ft)~ Parfr 'atlon depth TVD (ft). Tuf}ing Size: Tubing Grade: Tubing MD (ft}' L2: 9483-15661' 9totted L2:.s tBt-3416' 4-1x'2" L~B~ 9590' Packers and SSSr/ Typa: Packers and SS6V MD (ft} no packer no SSSV no SSSV 12, AttBChments: Description Summary pf Propos; it 0 73, Well Class after proposed work. Temporary Detailed Operations Program ^ BOP' Sketch ^ Expioratvry ^ Development 0 Setvic:e ^ 14. Estimated Date for 15. Well Statu9 after proposed work; Commencing Operations: 0~, ober 25, 2005 pit ~ C3as ^ Plugged ^ Abandoned ^ 16, Verbal Approval: Date: WAG ^ CaINJ ^ W1NJ ^ WDSPL ^ Commission Representative; 17, I hereby certify that the foregoing is true and cc •rect to the best aF my knowledge. Contact: HuntlNezaticky 659-7Dfi1 Printed Name .tef thlefs Title; Problem Welf Supervisor ~ ' Signpture Phone 659-7043 Date fd ~ / ~q" ornrnissiaf~ Use Onl Sundry Numb Conditions of approval Notify Commission so tP d a representative rrtay witness Plug integrity ^ BOP Test ^ Mecl apical Integrity Test ^ Location Clearance ^ L/e~ ~~~ () ~; ~ ~ ~ ~~~ Subsequent Form ~~ Aonrn COMMtSSlG7dkF,3~---- ~-._ _ Tf~tE COMNIl~S10N Date: .,--- Form 10- ..x2005 ~ ~ ~ ~ ~ ~ ~ Subm' in Dupli to 10/21/2005 17:57 907659 NSK WELLS GRO~ PAGE 04 ConacaPlwallips Alasks~, Ir~c. West Sak Injection Well X1t!~-117 (PTD 2050260) & L1 (PT:b 2050270) & 1:,2 (PTD 2050280) SUN'i iRY NOTICE 10-403 VARIANCE REQUEST 10!21. /OS Th.e purpose of this Sundry voti.ce is far approval to temporarily pre-produce multilateral west Sak injector 1E~117_ The to nparary production period is not to exceed 45 days fronr~ the time it is placed in service, The we+ 1 is n,ew and has not been in previous service, 1 E-117 is ahigh-angle inje~, lien well with a shallow gaslifl mandrel at 1876' MD and a sliding sleeve at 9248' MD. Deepe gaslift rna.ndrels were not run. due tv the inability to operate S1.ickHr,e tools at th.e .high ai .g1e. The shallow gasli.ft mandrel will not provide enough lift far production, 9v th.e open slid. ng aleeve will be used for lift gas Entry. With the sliding sleeve open there will be known tubing :Inner Annulus cammun.ieation during the production period. A variance from 20 AA.C ZS..! a0 PRODUCTION EQUIl~II~NT (d) is requested for the limited production period. The following is a summar,~ of the proposed plan: t , Sundry 10-403 approval equest for gaslift production. net to exceed 45 days with. known T x I.A. communication (open sliding sleeve to be used for gasli.fl); 2, Perform CMIT T x IA or MiTIA against a plug to demonstrate the production casing and packer have mechanical ntegrity; 3. Produce well, not to exc,: ~d 45 days; 4. Close sliding sleeve wit!'i coil tubing unit and perform'_~IITI,A prior to injection; 5. Place well orgy injection q~; rvice; 6. Perform State witnessed vtIT1A shortly after injection is initiated and submit test results to the AQGCC. After the temporary produc ion status tlae welt will be classi'xed as a Service well. A,ttacl~ed is a wellbore schematic from tk, :Well Ilan (actual depths may be different}. 3sssulaGed Crxs3rlot ~ Cb¢ge0`,9gA,iL55a 0 ~ 3~-,~.~~a• tvrc~ ~ rF fp MD ~~ ~ ~ ]3378', E83,i.f8q B13 ~] ~1- $537' tl0/~~~7i' ~~~~~I6 i f Q K ~~ >n ~ ~ ~. w ~ o o p a '^ B f+ pp R n _ P°1 :. `v 9-5~>P, 90sI,E-@Q STC.1~ R3 Csg ® i,~ 10,57Z' AiD 7],6?S TYD (aj 80 dggreer'lT] 1311;' hrte A2 4and Iinu, 5.,4`, 13.5, I,Bq BTCId, a13 6i sln~d and'n' hlaak, 00.RSfJdG20I3~[J11T07~COr L2 8-]13• Dsaadlataa) TD IS,E62' 1~! 3,399' TY6 LI: san_' "a^sandlrtua7 TD 15ti67S AiD 13,45P TYF3- 8.112,13 >asdl~r~l 3F] 15,75~'tSDl3,@25' TVI3 m N N N tS1 m cn ~n m ~„ z frl r r (n .-l~7 A m m Raker, tii16 seal bc[a assA ?~ W abeVL iEAf FS i'IC)Y INSTALLECI UNKPJO'NN OBSTRUCTION ^~~ (a~ -- 9,5J2' Ialzralknlsp i9orfula,l (I.E.'VI), Baia, wits sxal tiara and'LId.' ~acktr abase. ~"D"s~dtYudow ~ 4.706'-9,7ti' 75 ~]:~eas $.E3 P~'G BRINE FROi4S 7ue~N~ Ta~L To SURFACE- THE REST OF Ti1E f~t;OTH(~ BORE A~JD LATERALS CdNTAfN 9.0 ~'PG 5OLIi}S FREE dIL EASED MUD "lY° L;~s, 5-1lL",15.5~,! 9i0, Hi'[;2~f, X3 --~5slomedandYeila9.k, {0.125'x25'sgb, 32 par foot, SS9G v~eo nseaJ = - "B" I.;ss y, ~-]n•, 1SStl, isn. In~cu, R3 /~` Yi x4o16ed sod sh LlsaAr, (0.125'x1, 5' alma, J 33 par 6uot, 5.93(1 opw araa) Tu6ialr, 4S4' IB1'rl1, &em L~iim A2 Lice ,with seal seem ao6 C.4aiC0 3.~ff3"`DB'' aippla Sasl beta aodZlsl' pee%rEar.t2lieer +,'- 9a b+luw "B' win3aw u6i~ 3trirg #-1!l`, i2fi'a, I.-$Q IBTbi 4.5'TU$ING'I~ATH BENT JOINT AND 5E.4LS dN END SET 2` Asav~ urncNOwr~ OBSTRUCTION j ~ - 9,596` L2 "D" SandlYsodow ~ 9,39f' -9itQP 75 dtdserd ' ~ ~ ~ ~ ~ ~ a ~ S` i 33 '~ ' ~~ ~ 1 + ' ~ FRANK H. MURKOWSKI, GOVERNOR ~~~ Q , ~+~1 -~t~ 1~T ~1~~sj/ u~-7 ~ 333 W. 7'" AVENUE, SUITE 100 C~~-7i/RQ~iiO" C01•~i-uSSIO~ ANCHORAGE, ALASKA 99501-3539 ,~ PHONE (907) 279-1433 FAX (907)276-7542 Randy Thomas GKA Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: KRU West Sak 1 E-117L2 Sundry Number: 305-282 Dear Mr. Thomas: ~~p 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. Please provide at least twenty-four (24) hours 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, ~~~ ~~~~ John K. Norman Chairman DATED this ~ day of September, 2005 Encl. ' ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type Of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Pertorate ^ Waiver ^ Other Q Alter casing ^ Re air well p ^ Plu Perforations ^ g Stimulate ^ pre-produced ^ Time Extension injector Change approved program ^ Pull Tubing ^ Pertorate New Pool ^ Re-enter Suspended Well 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ ~8131~,»2~4 3. Address: Stratigraphic ^ Service Q 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23251-61 7. KB Elevation (ft): 9. Well Name and Number: RKB 28', 107' AMSL 1 E-117L2 8. Property Designation: 10. Field/Pool(s): ADL 25660, 25651 i ALK 470 Kuparuk River Field /West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured):. 15661' 3208' Casing Length Size MD TVD Burst Collapse CONDUCTOR g0' 20" 108' 108' SURFACE 5504' 13-3/8" 5544' 2364' INTERMEDIATE Production 10532' 9-5/8" 10572' 3510' Liner 6331' 5.5" 15661' 3208' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): none none 4.5" L-80 9590' Packers and SSSV Type: Packers and SSSV MD (ft) no packer no SSSV no SSSV 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: PRE-PRODUCED INJECTOR Detailed Operations Program ^ BOP Sketch ^ Exploratory [] Development ^ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: September 23, 2005 Oil ^ Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ~ WDSPL Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve Mukavitz @ 263-4021 Printed Name Randv Thomas Title: GKA Drilling Team Leader Signature ~ ~` ' ~ ~~,~• - ~= Phone 7~_S " ~~~ a Date `~ ~ZeS~S S Commission Use Onl Conditions of a roval: Notif Commission o th t a re ntative itn Sundry Number: ~~ y pp rep s a se may w ess Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ Other: (~~\~~ ~ ` ~~.~~ C~~`~®~~S ~`Qp`y ~ 1` I ~~~ ~~ ` ~~.~~'~'_' °1~~ ~~` ~ ~~~ ~ ~ ~~~~ Subsequent Form Required: ~~~ f APPROVED BY J ~ ~ "~ Approved by: 11 I ONER THE COMMISSION Date: - 7~ 5 o- c e p w~ ~ B V O 0 L.., Form 10-403 Re ised 7/2005 Submit in Duplicate Rig Workover Procedure Well 1 E-117 West Sak Injector Remove Obstruction and Complete Well Well History and Ria Workover Objectives: 1 E-117 was drilled and completed as a tri-lateral injector in the West Sak A2, B, and D sands by Doyon 141. Doyon 141 spudded the well June 21, 2005. 9-5/8" production casing was set and the two bottom laterals were drilled and slotted 5-1/2" liners run. After drilling the upper "D" sand lateral, running the 5- 1/2' liner, and installing the Baker Model B Hook Hanger junction at 9386', an attempt was made to install the "D" sand Lateral Entry Module (LEM) Assembly. The seal assembly would not pass through the hook hanger into the main wellbore, but instead went out into the "D" lateral. A second attempt was made to set the LEM, this time the seals were successfully oriented through the hook hanger into the main bore, however, the assembly set down at 9589' MD, approximately 78' above the top of the "B" lateral ZXP seal bore at 9667'. Attempts to rotate and work the seals down further were unsuccessful. A subsequent attempt to make a dummy run with a set of seals, junk basket and bent joint again tagged at 9589' MD and the seals were worked down 3' to 9592'. The assembly then pulled tight from 9592' to 9385' (to the top of the hook hanger) with 1 piece of brass and a few pieces of cement recovered form the junk basket when the assembly was pulled. A fourth run with a clean out assembly was unsuccessful in getting through the hook hanger into the main bore, at which time the decision was made to RDMO Doyon 141 and complete the well with Nabors 3S. The well was changed over from 9.0 ppg solids-free OBM to 8.9 ppg NaCI brine at 9380' MD and the clean out assembly was pulled, recovering 2 small pieces of metal and approximately %2 cup of cement. A 4-1/2" tubing/kill string with a be t joint on bottom was then run and was rotated through the "D" lateral hook hanger and landed at 9590' MD (2' above the final depth of the obstruction at 9592' MD). The 5K tree was nippled up and tested and Doyon 141 was released on August 13, 2005. The objectives of the rig Workover are as follows: ^ POOH with kill string. Install a Mainbore Diverter in the "D" lateral Hook Hanger with a memory MWD tool in the setting string to confirm the actual orientation of the "D" lateral Hook Hanger (the window was milled between 12 and 19 deg left of high-side) ^ If the Mainbore Diverter cannot be installed, try to install the LEM without the lower seal assembly to help orient the Hook Hanger if it is slightly out of line ^ Attempt to re-install the Mainbore Diverter after running the LEM to provide easier access to the main bore ar~d the obstruction at 9592' MD. ^ Clean out the obstruction at 9592' down to the bottom of the "B" lateral ZXP seal bore at 9687 P~1D using the 3-1/2" work string and clean out assembly. ^ Run the "D" lateral LEM assemk~ly and ZXP packer. If the LEM cannot be installed, run a 9-5/8" Premier packer on the ~vorkstring and set approximately 85' above the "D" lateral Nook Hanger. Test packer and casing to 2500 psi. ^ Run the 4-1/2" injection tubing and completion equipment and sting into the ZXP or Premier packer. Nipple up the tree. Page 3 9/20/2005 DRAFT ConocoPhillips September 20, 2005 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Randy Thomas GKA DriNing Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 Subject: Application for Sundry Approval for 1 E-117, 1 E-117L1, 1 E-117L2 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Application for Sundry Approval for the Kuparuk multilateral 1 E-117, 1 E-117L1 and 1 E-117L2. We are planning to re- enterthis well, clean out an obstruction, and run tubing. These wells have been permitted as injectors but we are planning to pre-produce them. We are requesting these sundries to be approved by Friday September 23, 2005. We apologize for the short notice. If this is a problem, please let us know. If you have any questions regarding this matter, please contact me at 265-6830. Sincerely, l t R. Thomas GKA Drilling Team Leader CPAI Drilling and Wells RT/skad °° ~ • ~ ~ `'~ ~ ~ ~~ ~ r ~~ ~~, ~ ; m ~~ " ~ '', FRANK H. MURKOWSK/, GOVERNOR ~~ ~~ OIL ~`~/ ~-7 333 W. T" AVENUE, SUITE 100 CO1~T5ERQATIOI~T COh'II~'II5SIOIQ ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchoragae, Alaska 99510 Re: Kuparuk 1 E-117L2 Sundry Number: 305-234 Dear Mr. Thomas: 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. Please provide at least twenty-four (24) hours 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 decisio o Superior Court unless rehearing has been requested. ~1 DATED this ~~day of August, 2005 Chairman Encl. ~ 8 /~-os/ STATE OF ALASKA ~~ ~'~~`6 /~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25 2fi0 ~~,~ 1. Type of Request: gbandon ^ Suspend ^ Operational shutdown ~ Perforate ^ ^ Waiver ^ Other Alter casing ^ Repair well ^ Plug Pertorations ^ Stimulate ^ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended WeILJ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 205-028 3. Address: Stratigraphic ^ Service Q 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23251-61 7. KB Elevation (ft): 9. Well Name and Number: 40' RKB, 107' AMSL 1 E-117L2 8. Property Designation: 10. Field/Pools(s): ADL 25660, 25651 / ALK 470 Ku aruk River Field /West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured) Junk (measured): 15661' 3208' Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 108' 108' Surface 5504' 13-3/8" 5544' 2364' Intermediate Production 10532' 9-5/8" 10572' 3510' Liner 6866' 5.5" 15660' 3208' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): None None None None None Packers and SSSV Type: Packers and SSSV MD (ft): None None 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 8/15/2005 Oil ^ Gas ^ Plugged ^ Abandoned ^ 16. Verbal Approval: Date: WAG Q GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact pat Reilly (a7 265-6048 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature ~ ` Phone 265-6830 Date ~ ~/1~ro S^ COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~D ~~~ Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ ~ Other: ~~ ~b M S ~`~'©'n. \ ~~ ~"J"lC..CJ ~ ~ C4..~3L0. \ t.SCq~"i'COt"~ ~ Q. C`M~ t[`C.f~~ Subsequen Re uir ` `SC'C~C7V\ O'er Cf3~ ~ APPROVED BY Approve COMMISSIONER THE COMMISSION Date: ~~ Form 10-403 Revised 11/2004 ~~S ~F~ ~~~ ~ ~ ~~QS ., r ,_„ /`~ L.» SUBMIT IN DUPLICATE • ConocoPhillips August 15, 2005 • Randy Thomas GKA Drilling Team Leader Drilling & Wells P_ O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 ~,~ ~~ Commissioner ~ ~. 2005 State of Alaska Alaska €~il ~ ~s Manse Con~l,~aissia~ Alaska Oil & Gas Conservation Commission ;~ch~ra~e 333 West 7t" Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approval for 1 E-117, 1 E-117L1, 1 E-117L2 Dear Commissioner: ConocoPhillips Alaska, {nc. submits the attached Application for Sundry Approval for the Kuparuk multilateral 1 E-117, 1 E-117L1 and 1 E-117L2. We are planning to shutdown temporarily operations on this well. Please see the attached diagram. There is an unknown obstruction in the mother bore between the top and middle laterals. Our plan forward is as follows: 1. Run video log (non-rig) to obstruction. 2. Evaluate log for rig 3S intervention. 3. MIRU 3S 4. Perform second video log to determine condition of top (D Lateral) liner hanger. 5. Evaluate second video log to determine final completion plan. If you have any questions regarding this matter, please contact me at 265-6830. Sincerely, ~-- R. Thomas GKA Drilling Team Leader CPAI Drilling and Wells RT/skad O 0 Insttlated Conductor n Casing, 20", 94#, K55 x ~( 34", 0.312" WT a +/- 80' MD • ~ . ~` m ~ fll 13.3/8", 68#, L-80, BTC, R3 a, +/- 4,53 T MD / 2,474' T VD -~ tT 69 degrees TD 16" bole ~ r. ~ ~,C W ~ o ~ C ~+ y ~' C r~ Baker, with seal bore and ZXP packer above. LEM 1S NOT INSTALLED UNKNOWN @ ~ 9, 592' Lateral Enky Module #1 (LEM), Baker, with seal bore and ZXP packer above. L2 "D"Sand Window tD 9,706' - 9,722' 75 degrees 8.9 PPG BRINE FROM TUBING TAIL TO SURFACE - THE REST OF THE MOTHER BORE AND LATERALS CONTAIN 9.0 PPG SOLIDS FREE OIL BASED MUD "D"Liner, 5-1/2", 15.5#, L80, BTCM, R3 %z slotted and % b1asIl:, (0.125" x 2.5" slots, 32 per foot, 5.9% open area) "B"Liner, 5.1/2", 15.5#, L80, BTCM, R3 /~ 'h slotted and %a blank, (0,125" x 2.5" slots, / 32 per foot, 5.9% open area) v b R' ~b o~ ~~~ ~~ o ' `~ r n~~- n~ro~ 5 4z; Tubhig, 4-''/i' IBTM, from LBM to A2 Liner, wills seal stem and CAMCO 3.562" "DB"nipple. Seal bore and ZXP packer for A2 liner +/- 90' below "B"window 4-5l8", 40#, L-80, BTCM, R3 Csg ~D +/- 10,572' MD / 3,675' TVD ~. 80 degrees TD 12-1 /4" hole A2 Sand Liner, 5?F~",15.5#,L80, BTCM, R3 % slotted and %z blank, constrictors for isolation L2: 8-1/2" D sand lateral TD 15,662' MD / 3,399' TVD L1: 8-1/2" "B" sand Lateral TD 15,675` MD 13,453` TVD 8-1/2 A2 sazid lateral TD 15,752' MD / 3,625' TVD Tubing String: 4-1(2", 12.6 #, L80, IBTM 4.5" TUBING WITH BENT JOINT AND SEALS ON END SET 2' ABOVE UNKNOWN OBSTRUCTION 1 @ ~ 9, 590' L2 "D" Sand Window r~ 9,391' - 9,407' 75 degrees ice: r w . in-i i i r~aii rurwaru - ~,n.-~iv~r, • Subject: Re: FW: 1E-117 Plan Forward -CHANGE From: Thomas Maunder <tom maunder@admin.state.ak.us> Date: Fri, 12 Aug 2005 11:07:19 -0800 y To: "Reilly, Patrick J" <Patrick.J.Reilly@conocophillips.com~ Pat, The total information here is a little sketchy, however based on the conversations with you and Steve yesterday I understand that there is some mechanical obstruction that is preventing the completion tubing from being run as planned. You all have determined to halt operations and set the well up so further evaluation can be done. You plan to run a tubing string deep in the well to facilitate the evaluations which will also provide a kill string for well control/circulating. After the work plan is determined, the 3S workover rig will move on the well to effect repairs. What you are planning is an "Operational SD" and a sundry will need to be filed. By copy of this email, you plan is acceptable. Please call or message with any questions. Tom Maunder, PE AOGCC Reilly, Patrick J wrote, On 8/12/2005 10:43 AM: Tom, Thanks for discussing 1 E-117 this morning. Please see the plan forward below. Sharon is out today. As per our conversation, we will prepare the sundry on Monday. Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907} 244-5558 CELLULAR (907) 265-1535 FAX Patrick.J.ReiIRVC~conocophillips.com «Patrick.J.Reilly _conocophillips.com.vcf» -----Original Message----- From: Reil{y, Patrick J Sent: Friday, August 12, 2005 10:34 AM To: Doyon 141 Company Man; Lowe, Dan E Cc: Thomas, Randy L; Spenceley, Neil; Gober, Jerome; McKeever, Steve; Greener, Mike R. Subject: 1E-117 Plan Forward -CHANGE Mike, Howard; Davis, Eric R.; Peterson, Erick Martin; Paul, We worked out a plan to get a video log on the obstruction before 3S moves in. When you leave, the Wells group will run a fiber optic video log down to the obstruction. Howard wiU have time to evaluate the video log and plan the 3S intervention. When 3S moves in, the rig will pick up fihe tubing to the hook hanger depth and get a second video 1 of 3 8/16!2005 10:20 AM xe: r w: i~-i i r Tian rorwara - LriHlvtJr, • • log of the hook hanger. 1. Continue POOH laying down DP. 2. Remove the burrs from the bottom of the seal assembly on the bent joint. 3. Run 4.5" lBT tubing (with bent joint and seat assembly on bottom) to just above the obstruction in the mother bore. 4. Space out tubing such that the seal assembly is at least 1-2' above the obstruction but not much higher than that. That should allow Wells to get a good video. 5. Land hanger. Howard is arranging the video iog with Mark Chaney. Mark can help at the rig site if you need more information on the space out. Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (907) 265-1535 FAX Patrick.J.ReiIlyC~conocophillips.com «Patrick.J.ReiNy(c~conocophillips.com.vcf» -----Original Message----- From: Reilly, Patrick J Sent: Thursday, August 11, 2005 5:26 PM To: Doyon 141 Company Man; Lowe, Dan E Cc: Thomas, Randy L; Spenceley, Neil; Gober, Howard; Davis, Eric R.; Peterson, Erick Martin Subject: 1E-117 Plan Forward Mike, I consulted with Howard Gober and Hal Martens. We came up with the following plan forward after you complete your junk basket run. 6. Displace to 8.9 ppg brine. (Hal is sending the recipe to his mud man on the rig) 7. POOH laying down DP. 8. Run 2,500' of 4.5 IBT tubing as a freeze protect string. (This might change to 3.5" PH6 if the torque required for the workover rig is low enough for PH6}. Dan Lowe is running some TAD calculations for Howard. 9. Land hanger. Pat Reilly ConocoPhillips Alaska Drilling & Wells (907) 265-6048 WORK (907) 244-5558 CELLULAR (907) 265-1535 FAX Patrick.J. Reiily[a7conocophillips.com 2 of 3 8/16/2005 10:20 AM • • ~ ~ ~~ 3 ~ ~ ~~ ('' , ~ FRANK H. MURKOWSKI GOVERNOR ~~ O~ ~ ~-7 ~ 333 W. T" AVENUE, SUITE 100 COI~TSERQA7`IO1~T CODIIrIISSIOI~T ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0364 Re: Kuparuk 1E-117L2 ConocoPhillips Alaska, Inc. Permit No: 205-028 Surface Location: 11' FSL, 228' FEL, SEC. 16, T11N, R10E, UM Bottomhole Location: 1742' FSL, 3548' FEL, SEC. 34, T11N, R10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or approvals 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. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to ' ness any required test. Contact the Commission's petroleum field inspector at (907) 659- 07 ager). DATED this ~i_'°day of February, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ConocoPhillips ~ Alaska Post OfFce Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907)265-6830 Email: Randy.L.Thomas@conocophillips.com February 16, 2005 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill, West Sak Injector, 1E-117L2 Dear Commissioners: .,, ~ ~~ ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill for an onshore injection wellbore, the upper lateral wellbore of a multilateral horizontal well, in the West Sak "D" sand. The main bore of this well will be designated 1E-117 and has been permitted under a separate application, submitted on February 16, 2005. This application is for the upper lateral of that well, to be designated 1E-117L2. The expected date that operations will begin on 1E-117L2 is 5/7/2005. Please find attached for the review of the Commission a Form 10-401 and the information required by 20 ACC 25.005 for each of this well bore. Please contact Steve Shultr at 263-4620 if more information is needed. Sincerely, Randy Thomas GKA Drilling Team Leader STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ; PERMIT TO DRILL ~'~ 20 AAC 25.005 1a. Type of Work: Drill ^ Redrill ^ 1b. Current Well Class: Exploratory Development Oil Multiple Zone ^ Re-entry Stratigraphic Test ^ Service ^/ Development Gas ^ Single Zone ^/ 2. Operator Name: 5. Bond: Blanket ^ Single Well ^ 11. Well Name and Number: ConocoPhillipsAlaska, Inc. Bond No. 59-52-180 1E-117L2 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 15639' TVD: 3193' * Kuparuk River Fieid 4a. Location of Well (Governmental Section): 7. Property Designation: ii Surface: 11' FSL, 228' FEL, Sec. 16, T11 N, R10E, UM ~ ADL 25660 ~ West Sak Oil Pool ~,~ Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: ~ cly 2696' FSL, 3535' FEL, Sec. 27, T11 N, R10E, UM ALK 470 5/7/2005 ~ Total Depth: 9. Acres in Property: 14. Distance to > ~+~,; /L„j 1742' FSL, 3548' FEL, Sec. 34, T11N, R10E, UM ~ 2560 Nearest Property: ,.3963'° ,6p z•Ly.vS 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well ~ re.-(12.~.~, rrcra Surtace: x- 550301 y- 5959601 Zone- 4 (Height above GL): 40' RKB / 10T AMSL Within Pool: ,,.ner+e ,,dl> ~,z> c 16. Deviated wells: Kickoff depth: ~ 9352 feet 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 93 deg. Downhole: 1516 psig Surface: 1161 psig 18. Casing Program: Specifications Setting Depth Quantity of Cement Size Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 40" 20" 94# K-55 Welded 80' 40' 40' 120' 120' 260 cf ArcticCrete 16" ~t5~3(8" L-80 utt 5347 40' 40' 5387 2379' 970 sx AS Lite, 260 sx DeepCrete 9- ~ 12.25' 40# -80 BT 10455' 40 , 1 3533' epCret 8.5" 5.5" 15.5# L-80 BTCM 6256' 9350' 3358' 15639' 3193' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Structural Conductor 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 Steve Shultz @ 263-4620 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature 1 ~ ~--- ~-~~_~~ Phone '` ~~ ~ ~ ?~ Date alt ~'!~c s Commission Use Only Permit to Drill API Number:~j ^ Permit Approval See cover letter for other Number: ~~ ~ ~ . ~ 7 50-Q~-1 " G~~~G-SJ^-~ / Date: ~/a ~ (7~ requirements Conditions of approval Sa s required Yes ^ No ~ Mud log required Yes ^ No dro en sulfide measures Yes ~ No ^ Directional survey required Yes ~ No ^ Other: ~ `t i~ cA-~~~~°~.S'.~..: ~.T A ^~ , c ,Q ~ ~OtiS ~;~ ~j~CCE?t'~ ~~ l~.~C) rJ-" APPROVED BY 8 D~ ~ Appr ved b . THE COMMISSION Date: ~ / v~ Form 10m -40/1 Revi\serd 06/2004 ORIGI^~A! Submit in Duplicate Application for Permit to Drill, Well 1 E-117L2 Revision No.O February 16, 2005 Permit- West Sak #1 E-117L2 Injector ("D" Sand) •~°d ~., Application for Permit to Drill Document, I~t~W~l1 M d x i m i z~ 'Well Value Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (t) ....................................................................................................... 2 2. Location Summary ................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ................................................................................................... 2 Requirements of 20 AAC 25.050(b) ....................................................................................................... 2 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 ............................................................................ 4 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 ............................................................................................. 5 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 5 Lateral Mud Program (M! FloPro NT) ..................................................................................................... 5 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 ............................................................................................... 6 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 6 Permit for 1 E-117L2 Injector Page 1 of 7 Printed: February 16, 2005 ORIGINAL Application for Permit to Drill, Well 1 E-117L2 Revision No.0 February 16, 2005 13. Proposed Drilling Program ..................................................................................... 6 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 6 15.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic 1. Well Name Requirements of 20 AAC 25.005 (t) Each we/I must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25,040(b). For a wel! with multiple well branches, each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1E-117L2. 2. Location Summary Requirements of 20 AAC 25.OO5(c)(2) An application for a Permit to Orill must be accompanied by each of the following items, except for an item a/ready on fi/e with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the we/f at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the /National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at tote! depth; Location at Surtace FSL 10.5' ,FEL 228', Sec.16, T11N/R10E ASPZone 4 NAD 27 Coordinates RKB Elevation 107' AMSL Northings; 5959600.8 Eastings; 550300 Pad Elevation 67' AMSL Location at Top of Productive Interval West Sak "A" Sand FSL 2696' FEL 3535', Sec. 27, T11NIR10E ASP Zone 4 NAD 27 Coordinates Measured De th RKB; 9350' Northings; 5951740 Eastings; 552342 Total 1/ertical De th, RKB; 3358' Total I/ertica/ De th, SS.• 3251' Location at Total Depth FSL 1742', FEL 3548', Sec 34, T11 N/R1OE ASPZone 4 NAD 27 Coordinates Measured De th, RKB; 15639' Northings; 5945407 Eastings; 552393 Total l/ertica/ De th, RKB; 3193' Total I/ertical De th, SS; 3086` and (D) other information required by 20 AAC 25.050(b); Requirements of 20 AAC 25.05O(b) If a well is to be intentionally deviated, the application for a Permit to Dri/l (Farm i0-401) must (1) include a plat, drawn to a suitable scale, showing the path of the proposed weffbore, including all adjacent wellbores within 200 feet of any portion of the proposed wel% ORIoINAL Permit for 1E-117L2 Injector Page 2 of 7 Printed: February 16, 2005 • Please see Attachment 1: Directional Plan Application for Permit to Drill, Well 1 E-117L2 Revision No.0 February 16, 2005 and (2) for all wells within 200 feet of the proposed we//bore (A) list the names of the operators of those webs, 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 application by certified mail; or (B) state that the app/icant 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 for a Permit to Drill must be accompanied by each of the following items, except far an item already on fi/e with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (ROPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; An API 13-5J8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1E-117L2. Due to the formation pressures being far less then the rating of the BOPS, CPAI would like to request that the stack be operated under the 3,000 psi BOP guidelines thereby allowing the use of one ram cavity far casing rams and negating an additional BOP test once the intermediate casing has been run. 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 Drill must be accompanied by each of the fo//owing items, except for an item already on fife with the commission and identified in the application: (4) information on drilling hazards, including (A) the maximum downhole pressure that maybe encountered, criteria used to determine it, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the 1E-117L2 area vary from 0.0.44 to 0.0.47 ~ psi/ft, or 8.6 to 9.0 ppg EMW (equivalent mud weight). These pressures are predicted based on actual bottom hole pressure data from the nearby West Sak wells. 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 A sand formation is 1161 psi, calculated thusly: MPSP =(3225 ft)(0.47 - 0.11 psi/ft) =1161 psi (B) data on potentiai gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potentia! causes of hole problems such as abnormally geo pressured strata, lost circuiation zones, and zones that have a propensity for differential sticking,• Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the fo/%wing items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC Z5.030(t); The parent wellbore,lE-117, will be completed with 9 5J8" 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 ~ ~ ~ r{ 3 Permit for 1 E-117L2 /njector Page 3 of 7 Printed: Febroary 16, 2005 Application for Permit to Drill, Well 1 E-117L2 Revision No.O February 16, 2005 ~r kL ~' ~. with the ~~Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 2s. 030, and a description of any slotted liner, pre- perforated liner, or screen to be instal/ed; Casing and Cementing Program See also Attachment 3, APD for 1E-117L2: Cement Summa Hole Top etm Csyl1"bg Size Weight Length MDlrVD MD/TVD OD in) in (Ib/ft) Grade Connection (ft (ft ft Cement Pro ram 20" 40" 94 K55 Welded 80' 40' / 40' 120` J 120' Cemented to surface with 260 cf ArcticCRETE 13 3/8" 16" 68# L-80 Butt 5347' 40'/40' 5387'/2379' Cemented to Surface with 970sx ASLite Lead, 260sx Dee CRETE Tail 12 1/4" 9 5/8" 40# L-80 BTCM 10455' 40'140' 10495'J3533' Cement Top planned @ 6100' MD/' TVD. Cemented w/ 810 sx Dee RETE 5 1/2" 8 1/2" ~~A" 15.5# L-80 BTCM 6052` 9700`/3422` 15752'/3411' Slotted- no cement slotted Lateral 5 1/2" 8 112" „B" 15.5# L-80 BTCM 6042' 9600'/3408' 15642'/3261' Slotted- no cement slotted Lateral ,~ 5 1/2 ~~ „ 8 1/2 D 15.5# L-80 BTCM 6289 9350/3358 . 9 J3193 Slotted-no cement slotted Lateral L2 4 2 NA L-80 IBTM 9160' 40'/40' 0'/3300' g tubin Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the fo/%wing items, except for an item a/ready on file with the commission and identified in the app/ication: (T) a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 2s.03s(h)(2); A 21-1/4", 2000 psi annular with a 16" diameter diverter line will be the diverter system used in the drilling of 1E-117L2. Please see diagrams of the Doyon 15 diverter system on file with the Commission. OR161NAL Permit for 1E-117L2 Injector Page 4 of 7 Printed: February 16, 2005 • Application for Permit to Drill, Well 1 E-117L2 Revision No.0 February 16, 2005 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (S) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with mud having the following properties over the listed intervals: Lateral Mud Program (VersaPro, Oil Base Mud) Pro erties Production Density (ppg) 9.0 Funnel Viscosity (seconds) 60 Yield Point (cP) 18-28 Electric Stability 650-900 Chlorides (m A NA H NA API filtrate (cc / 30 min) <4 "*HTHP filtrate (cc / 30 min) <10 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 15 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the fo/%wing items, except for an item already on file with the commission and identified in the application: f91 for an exploratory or stratigraphic test we//, a tabu{ation setting out the depths ofpredictedabnormally geo-pressured strata as required by 20 AAC 25. D33(~; Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An app/ication for a Permit to Dri!! must be accompanied by each of the following items, except for an item already on fr/e with the commission and identified in the app/ication: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.061(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 application 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: (11) for a well drilled from an offshore platform, mobi/e bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis ofseabed conditions as required by 20 AAC 25.061(6); Not applicable: Application is not for an offshore well. ~~1~~~ a Permit for 1E-117L2 Injector Page 5 of 7 Printed: February 76, 2005 .Application for Permit to Drill, Well 1 E-117L2 Revision No.0 February 16, 2005 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Driii must be accompanied by each of the fo/%wing items, except for an item a/ready on file with the commission and identified in the app/ication: (IZ) evidence showing that the requirements of20 AAC 25.025 {Bonding}have been met,• Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the fol%wing items, except for an item a/ready on fle with the commission and identified in the application: Once the "B" sand liner is in place, then the proposed drilling program for 1E-117L2 ("D" sand) listed below will be initiated. 1. Run and set Baker WindowMaster whipstock system, at window point of 9350' MD/3358' TVD, the top of the "D" sand. 2. Mill 8 1/2" window. POOH. 0 3. Pick up drilling assembly with LWD and MWD and PWD. RIH. 4. Drill to TD of "D" sand lateral at 15639' MD /3193' TVD, as per directional plan. 5. POOH, back reaming out of lateral. POOH. 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. PU and run 5 1/2" slotted liner. 8. RIH, until finer hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool. 10. POOH and lay down drill pipe 11. RU and run 4 1/2" injector completion with back up gas lift and a sliding sleeve 12. Space out tubing, stab seals into PBR above upper most lateral and land tubing in tubing head 13. Nipple down BOPE, nipple up tree and test, change over the hole to diesel 14. RDMO Doyon 15 15. Rig up wire line unit. Pull BPV 16. Circulate out well with diesel through sliding sleeve, then close same 17. Set gas lift valves in mandrels. Operate well on gas lift for +/- 30 days. 18. Replace gas lift valves with blank dummy valves. 19. Place well on injection 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Oril! mustc be accompanied by each of the fol%wing items, e,YCept for an item already on frfe with the commission and identified in the app/ication: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annu/ar disposa/ operatron in the wel/.; f~~~+~~ d ~ ~ ~ 1 Permit for 1E-117L2 /njector Page 6 of 7 Printed: February 16, 2005 Application for Permit to Drill, well 1 E-117L2 Revision No.O February 16, 2005 Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of by hauling 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. 15.Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic OR161NAL Permit for 1 E-117L2 Injector Page 7 of 7 Printed: February 16, 2005 Injector 1 E-117 Slimhole Design Note: the interemediate and all laterals are to be drilled with rotary steerabte 16" Hole (8.8 ppg Spud Mud) 13 3/8" Casing Hydraulics: KOP: 300' Surface: 900-1200 gpm Build at 3-5 Intermediate: 700-900 gpm degrees/ 100' 5387' MD • Laterals: 450-500 gpm Figure on a 50 YP for surface 2379' TVD Figure on a 35 YP for intermediate Pore Pressure 1450 psi Figure on a 28 YP for laterals TVDss 3130 ft ., 3225 ft - ~ MWE g , •' ~ ' .- Window C«~ 9352 M D ~ ~A~ .~~ Top of Ugnu 1 00' MD \y ~- - `" - "D" Sand (9.0 ppg Oil Base Mud} " H 1 -66 + 8 1/2 ole ,~~,~~ ~ i 5 1/2" Liner Top of Cement ' 15639' MD ' +/-6100 MD 3193 TVD ' nd (9.0 ppg Oi Base Mud) 9635'MD 8 1!2" Hole 5 1/2" Line Tangent Angle: 75 degrees 15642" MD 3261' 'TVD ' 12114" Hale (9.0 ppg LSND) 9 5I8" Casing 10,495' MD 3533' TVD (80 degrees "A-2" Sand (9.0 ppg Oil Base Mud} 8 1/2" Hole (Undulating) / 5 1/2" Liner j 15752' MD 3411' TVD • • ConocoPhillips Alaska ConocoPhillips Alaska Inc.(Kuparuk) Kuparuk River Unit Kuparuk 1 E Pad Plan 1 E-117 1 E-117 L2 Plan: 1 E-117 L2 (wp04) Proposal Report 09 February, 2005 QR1LLt G 5~R~1~~ A Halliburton Company li Project: Kuparuk River U Site: Kuparuk 1E Pad A~.<;-cr Well: Plan 1E-117 Wellbore: 1E-117 L2 Plan: 1E-117 L2 (wp04) 1 E-117_L2 (wp04)_~ LEGEND ~- Plan 1 E-117, 1 E-117 L1, 1 E-117 L1 (wp04) VO -~ Plan 1 E-117, 1 E-117, 1 E-117 (wp04) VO $ 1 E-117 L2 (wp04) 0 Top of Window - 2521'FSL 8 1746'FWL -Sect 27 - T11N - R10E :Drill out 8 112" Hole : 9335 tt MD, 3358 ft N i Botto Whim ps of ck :Assume 13.60°/100ft : 9352 ft MD, 3361 ft ND~ 500 ~ ~ B~ uild @4.00°/100ft_ 9382 ft MD, 3366 ft ND I i Begin Sail @ 96.95° Inc & 180.02° Azi, 9799 ft MD, 3376 ft ND '~T'""9 1000 ~ontinue Build @ 4.00°/100ft , 10140 ft MD, 3335 ft ND s~6~ - - ~ - 1500 ~ / c_ I ~ 2000 0 °o BHL :1742' FSL & 1732' FWL -Sect 34 - T11N - R10E :15639 ft r a 0 2500 r Begin Geosteering in D_Lateral : 10232 ft MD, 3327 ft ND y - > 5 1/2" ~ 3000 i 3500 6000 6500 7000 7500 8000 8500 9000 9500 10000 10500 11000 11500 12000 12500 13000 13500 14000 14500 15000 15500 Vertical Section at 180.00° (1000 fUin) ~ ' "~ ConocoPhill ips y West(-)!East(+) (1800 ft/in) - 900 0 900 1800 2700 3600 4500 5400 6300 7200 8100 9000 990 0 900 900 Project: Kuparuk River Unit Site: Kuparuk 1 E Pad o Well: Plan 1 E-117 o Wellbore: 1 E-117 L2 Plan: 1 E-117 L2 (wp04) -900 -900 Top of Wndoa - 2521'FSL 8 1745FWL -Sect 27 - T11 N - R 10E :Drill out 8 117' Hole : 9335 ft MD, 3358 ft TVD -1800 -1800 -2700 ~ i -2700 -3600 -3600 / -4500 Bottom Whipstock :Assume 13.60 /100ft : 9352 ft MD, 3361 ft ND ~ - _- - / - -- -4500 -5400 -5400 c ~ o c_ o -6300 -6300 ~ ~_ ''' Build @4.00°/100ft , 9382 ft MD, 336336 ft6~1VD + T - - - - - ~ ~ -7200 / ~ -7200 v o ~' Z r 3376 ft ND Begin Sail @ 96 95° Inc & 180 02° Azi 9799 ft MD o o ~ -8100 ~ . . , , - - - - - - - - - - - - - - - -8100 ~ o cn .-. Continue Build @ 4.00°/100ft , 10140 ft MD, 3335 ft ND j -9000 -9000 -9900 \ ~ -9900 Begin Geosteering in D-Lateral _10232 ft MD, 3327 ft ND -10800 -10800 -11700 -11700 1 E-117 L2 (wp04) _,2600 -,2600 -13500 -13500 -rBHL .1747 FSL 8 1737 FVVL -Seca 34 - T11 N - R 10E 15639 ft MD 3193 ft ND ~ -14400 _ - - __ - - - - - - -14400 - 900 0 900 1800 2700 3600 4500 5400 6300 7200 8100 9000 990 0 West(-)/East(+) (1800 ftJin) t._~ ti ~,. R .~ ,. • Ph ll C Halliburton Company ~~t~"1 ..C,~V~"~ onoco ~ ips Planning Report -Geographic AIISICS A HaUlburton Company Database: EDM 2003.11 Single User Db Local Co-ordinate Reference: Well Plan 1 E-1 t7 Company: ConocoPhillips Alaska Inc:(Kuparuk) TVD Reference: 66.9 GL + 40RF=106.9 ~ 106.90ft (Doyon 15 (66.9GL + 40R Project: Kuparuk River Unit MD Reference: 66.9 GL + 40RF=106:9 @ 106.90ft (Doyon 15 (66.9GL + 40R Site: Kuparuk`1E Pad North Reference: True Well: Plan 1 E-117 Survey Calculation Method: Minimum Curvature` Wellbore: 1 E-117 L2 Design; 1E-117 L2 (wp04) Project Kuparuk River Unit, North Slope Alaska, United States Map System: U5 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 1 E-117, Tri -Lateral Injector Well Position +NlS 0.00 ft Northing: 5,9b9,600.86 ft Latitude: +E/-W 0.00 ft Easting: 550,300.61 ft Longitude: Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 70° 18' 01.427" N 149° 35' 33.405" W 66.90 ft Wellbore 1 E-117 L2 j Magnetics I Model Name Sample Date Declination (°) - BGGM2004 12/1512004 24.49 i Design 1E-117 L2{wp04j Audit Notes: Version: Phase: PLAN Vertical Section: Depth From (TVD) +N/-S (ft) (ft) 40.00 0.00 Dip Angle Field Strength (°) (nT) 80.74 57,580 Tie On Depth: +E!-W (ft) 0.00 Direction (°) 180.00 9,335.04 i 2/3/2005 8:02:42PM Page 2 of 6 ~~ ~ ~ ~ ~ ~ COMPASS 2003.11 Build 50 ~ ~ h l Hailiburton Company ~ ~~f~"'i~~1"~. Ut"'~ Conoco P iips i Planning Report -Geographic Alaska A Halllburton Company Database: EDM 2003.11 Single User Db; Local Co-ordinate Reference: Well Plan 1E-177 Company: ConocoPhitlips Alaska tna(Kuparuk) ,, TVD Reference: 66.9 GL + 40RF=106.9 @ 106.90ft (Doyon 15 (66.9GL + 40R Project: Kuparuk River Unit - MD Reference: 66.9 GL + 40RF=106.9 @ 106.90ft (Doyon 15 (66.9GL + 40R Sit®: Kuparuk 1E Pad North Reference: True Well: Plan 1E-117 Survey Calculation Method: Minimum Curvature Wellbore: 1 E-117 L2 Design: 1 E-117 L2 (wp04) Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N!-S +Ef-W Rate Rate Rate TFO (ft) (°) (°) lit) (ft) (ft) (°/100ft) (°/100ft) (°/10Dft) (°) 9,335.04 78.00 180.03 3,357.90 -7,811.79 1,989.85 0.00 0.00 0.00 0.00 9,351.54 80.24 180.03 3,361.01 -7,827.99 1,989.84 13.60 13.60 0.00 0.00 9,381.54 8024 180.03 3,366.10 -7,857.55 1,989.82 0.00 0.00 0.00 0.00 9,707.44 93.28 180.03 3,384.47 -8,182.23 1,989.65 4.00 4.00 0.00 360.00 9,799.10 96.95 180.02 3,376.30 -8,273.51 1,989.62 4.00 4.00 -0.01 -0.19 10,140.03 96.95 180.02 3,335.07 -8,611.94 1,989.51 0.00 0.00 0.00 0.00 10,231.69 93.28 180.03 3,326.90 -8,703.22 1,989.47 4.00 -4.00 0.01 179.81 10,258.53 92.48 180.00 3,325.55 -8,730.02 1,989.47 3.00 -3.00 -0.12 -177.79 10,829.33 92.48 180.00 3,300.90 -9,300.29 1,989.48 0.00 0.00 0.00 0.00, 10,853.03 91,78 180.13 3,300.02 -9,323.98 1,989.45 3.00 -2.95 0.56 169.27 11,050.46 91.78 180.13 3,293.90 -9,521.31 1,989.00 0.00 0.00 0.00 0.00 11,062.20 91.46 179.97 3,293.57 -9,533.05 1,988.99 3.00 -2.68 -1.35 -153.19 12,028.90 91.46 179.97 3,268.90 -10,499.43 1,989.45 0.00 0.00 0.00 0.00 12,043.78 91.02 180.03 3,268.58 -10,514.31 1,989.45 3.00 -2.98 0.36 173.10 13,150.21 91.02 180.03 3,248.90 -11,620.56 1,988.95 0.00 0.00 0.00 0.00 13,208.37 92.76 180.01 3,246.98 -11,678,69 1,988.93 3.00 3.00 -0.02 -0.44 13,769.97 92.76 180.01 3,219.90 -12,239.64 1,988.80 0.00 0.00 0.00 0.00 13,835.68 90.79 179.98 3,217.86 -12,305.31 1,988.80 3.00 -3.00 -0.04 -179.18 15,639.40 90.79 179.98 3,192.90 -14,108.86 1,989.29 0.00 0.00 0.00 0.00 2/9/2005 8:02:42PM Page 3 of 6 +" ~ P"~ ;~ .~ °-. 3 { r F COMPASS 2003.11 Build 50 1-' ~ Ph N C Halliburton Company ~ ~~ry"~~..~n onoco i ips Plan ning Report -Geographic Alaska A HalllbuROn Company Database: EDM 2003 11 Single User Ob Loc al Co-ordinate Reference: Well Plan 1 E-117 Company: ConocoPhi)iips Alaska Inc.(Kuparuk) TVD Reference: 66.9 GL + 408E=106.9 @ 106.9 0ft (Doyon 1 5 (66.9GL + 408 Project: Kuparuk River Unit MD Reference: 66.9 GL + 408E=106.9 @ 106.9 0ft (Doyon 1 5 (66.9GL + 408 Site: Kuparuk 1 E Pad North Reference: True WeII: Plan 1 E-117 Survey Calcuiation Method: Minimum Curvature Wellbore: 1 E-117 L2 Design: 1 E-117 L2 (wp04) 'Planned Survey 1 E-117 L2 (wp04) - - - - - - - Map Map MD I nclination Azimuth ND SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft1 (ft) {ft) (ft) (ft) (ft) (°/100ft) (ft1 ~ I ~ 9,335.04 78.00 180.03 3,357.90 3,251.00 -7,811.79 1,989.85 5,951,803.33 552,342.41 0.00 7,811.79 Top of Window - 2521'FSL 81746'FWL - Sect 27 - T11N - 810E :Drill out 8 1/2" Hole :9335 8 MD, 3358 8 TVD -West Sak D - 95/8" Window Top 9,351.54 80.24 180.03 3,361.01 3,254.11 -7,827.99 1,989.84 5,951,787.13 552,342.51 13.60 7,827.99 Bottom Whipstock :Assume 13.50°71008:9352 8 MD, 3361 8 TVD I 9,381.54 80.24 180.03 3,366.10 3,259.20 -7,857.55 1,989.82 5,951,757.56 552,342.69 0.00 7,857.55 Build X4.00°/100ft , 9382 8 MD, 3355 8 TVD 9,400.00 80.98 180.03 3,369.11 3,262.21 -7,875.77 1,989.81 5,951,739.35 552,342.80 3.99 7,875.77 ~ 9,500.00 84.98 180.03 3,381.32 3,274.42 -7,975.00 1,989.76 5,951,640.13 552,343.42 4.00 7,975.00 9,600.00 88.98 180.03 3,386.59 3,279.69 -8,074.84 1,989.71 5,951,540.30 552,344.03 4.00 8,074.84 9,700.00 92.98 180.03 3,384.87 3,277.97 -8,174.80 1,989.66 5,951,440.35 552,344.65 4.00 8,174.80 ~ 9,707.44 93.28 180.03 3,384.47 3,277.57 -8,182.23 1,989.65 5,951,432.92 552,344.69 4.00 8,182.23 ~ 9,799.10 96.95 180,02 3,376.30 3,269.40 -8,273.51 1,989.62 5,951,341.66 552,345.27 4.00 8,273.51 j Begin Sail ~ 96.9b° Inc 8180.02° Azi, 9799 ft MD, 3376 8 TVD I ~ 9,800.00 96.95 180.02 3,376.19 3,269.29 -8,274.41 1,989.62 5,951,340.76 552,345.27 0.00 8,274.41 ~ 9,900.00 I 96.95 180.02 3,364.10 3,257.20 -8,373.67 1,989.58 5,951,241.51 552,345.91 0.00 8,373.67 10,000.00 96.95 180.02 3,352.00 3,245.10 -8,472.94 1,989.55 5,951,142.25 552,346.54 0.00 8,472.94 10,100.00 96.95 180.02 3,339.91 3,233.01 -8,572.20 1,989.52 5,951,043.00 552,347.17 0.00 8,572.20 ~ 10,140.03 96.95 180.02 3,335.07 3,228.17 -8,611.94 1,989.51 5,951,003.27 552,347.43 0.00 8,611.94 Continue Build ~ 4.00°I1008 ,10140 8 MD, 3335 8 TVD ~ 10,200.00 94.55 180.03 3,329.06 3,222.16 -8,671.60 1,989.49 5,950,943.61 552,347.80 4.00 8,671.60 ~ 10,231.69 93.28 180.03 3,326.90 3,220.00 -8,703.22 1,989.47 5,950,912.00 552,348.00 4.01 8,703.22 ~ Begin Geosteering in D-Lateral :10232 8 MD, 3327 8 TVD -1 E-117 L2-Ti (v3) 10,258.53 92.48 180.00 3,325.55 3,218.65 -8,730.02 1,989.47 5,950,885.20 552,348.17 3.00 8,730.02 ~ 10,300.00 92.48 180.00 3,323.76 3,216.86 -8,771.46 1,989.47 5,950,843.77 552,348.45 0.00 8,771.46 10,400.00 92.48 180.00 3,319.44 3,212.54 -8,871.36 1,989.47 5,950,743.87 552,349.12 0.00 8,871.36 ~ 10,500.00 92.48 180.00 3,315.12 3,208.22 -8,971.27 1,989.47 5,950,643.98 552,349.79 0.00 8,971.27 I 10,600.00 92.48 180.00 3,310.80 3,203.90 -9,071.18 1,989.47 5,950,544.08 552,350.46 0.00 9,071.18 10,700.00 l 92.48 180.00 3,306.49 3,199.59 -9,171.08 1,989.47 5,950,444.19 552,351.13 0.00 9,171.08 10,800.00 i 92.48 180.00 3,302.17 3,195.27 -9,270.99 1,989.48 5,950,344.29 552,351.80 0.00 9,270.99 ~ 10,829.33 ~ 92.48 180.00 3,300.90 3,194.00 -9,300.29 1,989.48 5,950,315.00 552,352.00 0.00 9,300.29 1E-117 L2-T2 (v3) ~ 10,853.03 91,78 180.13 3,300.02 3,193.12 -9,323.98 1,989.45 5,950,291.31 552,352.13 3.00 9,323.98 10,900.00 91.78 180.13 3,298.56 3,191.66 -9,370.92 1,989.34 5,950,244.37 552,352.34 0.00 9,370.92 ~ 11,000.00 91.78 180.13 3,295.46 3,188.56 -9,470.88 1,989.11 5,950,144.43 552,352.78 0.00 9,470.88 11,050.46 91.78 180.13 3,293.90 3,187.00 -9,521.31 1,989.00 5,950,094.00 552,353.00 D.00 9,521.31 1E-117 L2-T3 {v3) ~ 11,062.20 91.46 179.97 3,293.57 3,186.67 -9,533.05 1,988.99 5,950,082.27 552,353.07 3.00 9,533.05 ~ 11,100.00 91.46 179.97 3,292.60 3,185.70 -9,570.83 1,989.00 5,950,044.48 552,353.34 0.00 9,570.83 I ~ 11,200.00 91.46 179.97 3,290.05 3,183.15 -9,670.80 1,989.05 5,949,944.53 552,354.06 0.00 9,670.80 ~ 11,300.00 91.46 179.97 3,287.50 3,180.60 -9,770.77 1,989.10 5,949,844.57 552,354.77 0.00 9,770.77 11,400.00 91.46 179.97 3,284.95 3,178.05 -9,870.74 1,989.15 5,949,744.62 552,355.49 0.00 9,870.74 11,500.00 91,46 179.97 3,282.40 3,175.50 -9,970.70 1,989.20 5,949,644.66 552,356.21 0.00 9,970.70 ~ 11,600.00 91.46 179.97 3,279.84 3,172.94 -10,070.67 1,989.24 5,949,544.71 552,356.92 0.00 10,070.67 ~ 11,700.00 91.46 179.97 3,277.29 3,170.39 -10,170.64 1,989.29 5,949,444.75 552,357.64 0.00 10,170.64 11,800.00 91.46 179.97 3,274.74 3,167.84 -10,270.61 1,989.34 5,949,344.80 552,358.36 0.00 10,270.61 11,900.00 91.46 179.97 3,272.19 3,165.29 -10,370.57 1,989.39 5,949,244.84 552,359.08 0.00 10,370.57 2RJ/2005 8:02:42PM Page 4 of 6 COMPASS 2003.11 Build 50 /1~,. ~ P C I Hallibulrton Company • ~r'1 _y~-rV~" ~ !~ 011000 I 111 1 p5 Planning Report -Geographic Alaska A Ha1110uROn Company Database: EDM 2003.11 $ingie User Db Local Co-ordinate Reference: Well Plan 1 E-f17 Company: ConocoPhillips Alaska Ine.(Kuparuk) ND Reference: 66;9 GL + 40RF= 106:9 @ 106.9 0ft (Doyon t 5 (66 9GL + 40R Project: Kuparuk River Unit MD Reference: 66,9 GL + 40RF= 106.9 @ 106.9 0ft (Doyon 1 5 (6fi.9GL + 40R Site: Kuparuk 1 E Pad , No rth Reference: True Well: Plan 1 E-117 Su rvey Calculation Method: Minimum Curvatu re Wellbore: 1E-1 17 L2 Design: 1E-1 17 L2 (wp04) --- Planned Survey - - 1 E-117 L2 (wp04) - -- li I Map Map i I MD I nclination Azimuth ND SSND +N!-S +E!-W Northing Easting DLSEV I Vert Section (ft) (°) (°1 (ft- Iftl (ft) lft) (ft) (ft) (°/100ft) (ftl ~ 12,000.00 91.46 179.97 3,269.64 3,162.74 -10,470,54 1,989.44 5,949,144.89 552,359.79 0.00 10,470.54 ~ 12,028.90 91.46 179.97 3,268.90 3,162.00 -10,499.43 1,989.45 5,949,116.00 552,360.00 0.00 10,499.43 ~ 1E-117 L2-T4 (v3) I 12,043.78 91.02 180.03 3,268.58 3,161.68 -10,514.31 1,989.45 5,949,101.13 552,360.10 3.00 10,514.31 ~ 12,100.00 I 91.02 180.03 3,267.58 3,160.68 -10,570.52 1,989.42 5,949,044.92 552,360.45 0.00 10,570.52 I 12,200.00 91.02 180.03 3,265.80 3,158.90 -10,670.50 1,989.38 5,948,944.95 552,361.07 0.00 10,670.50 12,300.00 91.02 180.03 3,264.02 3,157.12 -10,770.49 1,989.33 5,948,844.98 552,361.70 0.00 10,770.49 ~ 12,400.00 91.02 180.03 3,262.24 3,155.34 -10,870.47 1,989.29 5,948,745.00 552,362.32 0.00 10,870.47 12,500.00 91.02 180.03 3,260.46 3,153.56 -10,970.46 1,989.24 5,948,645.03 552,362.94 0.00 10,970.46 ~ 12,600.00 91.02 180.03 3,258.69 3,151.79 -11,070.44 1,989.20 5,948,545.06 552,363.57 0.00 11,070.44 12,700.00 91.02 180.03 3,256.91 3,150.01 -11,170.42 1,989.15 5,948,445.09 552,364.19 0.00 11,170.42 ~ 12,800.00 91.02 180.03 3,255.13 3,148.23 -11,270.41 1,989.10 5,948,345.11 552,364.82 0.00 11,270.41 12,900.00 91.02 180.03 3,253.35 3,146.45 -11,370.39 1,989.06 5,948,245.14 552,365.44 0,00 11,370.39 ~ 13,000.00 91.02 180.03 3,251.57 3,144.67 -11,470.38 1,989.01 5,948,145.17 552,366.06 0.00 11,470.38 I 13,100.00 91.02 180.03 3,249.79 3,142.89 -11,570.36 1,988.97 5,948,045,20 552,366.69 0.00 11,570.36 j 13,150.21 91.02 180.03 3,248.90 3,142.00 -11,620.56 1,988.95 5,947,995.00 552,367.00 0.00 11,620.56 1E-117 L2-T6 (v3) 13,200.00 92.51 180.01 3,247.37 3,140.47 -11,670.33 1,988.93 5,947,945.24 552,367.32 3.00 11,670.33 ~ 13,208.37 92.76 180.01 3,246.98 3,140.08 -11,678.69 1,988.93 5,947,936.88 552,367.37 3.00 11,678.69 13,300.00 92.76 180.01 3,242.56 3,135.66 -11,770.21 1,988.91 5,947,845.37 552,367.96 0.00 11,770.21 ~ 13,400.00 92.76 180.01 3,237.74 3,130.84 -11,870.10 1,988.88 5,847,745.50 552,368.61 0.00 11,870.10 ~ 13,500.00 92.76 180.01 3,232.92 3,126.02 -11,969.98 1,988.86 5,947,645.62 552,369.25 0.00 11,969.98 13,600.00 92.76 180.01 3,228.10 3,121.20 -12,069.86 1,988.84 5,947,545.75 552,369.90 0.00 12,069.86 ~ 13,700.00 92.76 180.01 3,223.27 3,116.37 -12,169.75 1,988.82 5,947,445.88 552,370.55 0.00 12,169.75 13,769.97 92.76 180.01 3,219.90 3,113.00 -12,239.64 1,988.80 5,947,376.00 552,371.00 0.00 12,239.64 ~ 1E-117 L2-T6 )v3) I, j 13,800.00 91.86 180.00 3,218.69 3,111.79 -12,269.64 1,988.80 5,947,346.00 552,371.20 2.99 12,269.64 13,835.68 90.79 179.98 3,217.86 3,110.96 -12,305.31 1,988.80 5,947,310.34 552,371.44 3.00 12,305.31 ~ 13,900.00 90.79 179.98 3,216.97 3,110.07 -12,369.62 1,988.82 5,947,246.03 552,371.89 0.00 12,369.62 14,000.00 90.79 179.98 3,215.59 3,108.69 -12,469.62 1,988.85 5,947,146.05 552,372.59 0.00 12,469.62 14,100.00 90.79 179.98 3,214.20 3,107.30 -12,569.61 1,988.87 5,947,046.07 552,373.28 0.00 12,569.61 ~ 14,200.00 90.79 179.98 3,212.82 3,105.92 -12,669.60 1,988.90 5,946,946.09 552,373.98 0.00 12,669.60 14,300.00 90.79 179.98 3,211.44 3,104.54 -12,769.59 1,988.93 5,946,846.11 552,374.67 0.00 12,769.59 14,400.00 90.79 179.98 3,210.05 3,103.15 -12,869.58 1,988.96 5,946,746.13 552,375.37 0.00 12,869.58 ~ 14,500.00 I 90.79 179.98 3,208.67 3,101.77 -12,969.57 1,988.98 5,946,646.16 552,376.07 0.00 12,969.57 14,600.00 90.79 179.98 3,207.28 3,100.38 -13,069.56 1,989.01 5,946,546.18 552,376.76 0.00 13,069.56 14,700.00 90.79 179.98 3,205.90 3,099.00 -13,169.55 1,989.04 5,946,446.20 552,377.46 0.00 13,169.55 14,800.00 90.79 179.98 3,204.52 3,097.62 -13,269.54 1,989.06 5,946,346.22 552,378.16 0.00 13,269.54 14,900.00 90.79 179.98 3,203.13 3,096.23 -13,369.53 1,989.09 5,946,246.24 552,378.85 0.00 13,369.53 15,000.00 i 90.79 179.98 3,201.75 3,094.85 -13,469.52 1,989.12 5,946,146.26 552,379.55 0.00 13,469.52 15,100.00 90.79 179.98 3,200.36 3,093.46 -13,569.51 1,989.14 5,946,046.29 552,380.24 0.00 13,569.51 ~ 15,200.00 90.79 179.98 3,198.98 3,092.08 -13,669.50 1,989.17 5,945,946.31 552,380.94 0.00 13,669.50 15,300.00 90.79 179,98 3,197.60 3,090.70 -13,769.49 1,989.20 5,945,846.33 552,381.64 0.00 13,769.49 ~ 15,400.00 90.79 179.98 3,196.21 3,089.31 -13,869.48 1,989.22 5,945,746.35 552,382.33 0.00 13,869.48 i 15,500.00 90.79 179.98 3,194.83 3,087.93 -13,969.47 1,989.25 5,945,646.37 552,383.03 0.00 13,969.47 15,600.00 90.79 179.98 3,193.45 3,086.55 -14,069.46 1,989.28 5,945,546.40 552,383.73 0.00 14,069.46 / 15,639.40 90.79 179.98 3,192.90 3,086.00 -14,108.86 1,989.29 5,945,507.00 552,384.00 0.00 14,108.86 BHL :1742' FSL 8 1732' FWL -Sect 34 - T11N - R10E : 16639 ft MD, 3193 ft 1'VD - 6 112" -1E-117 L2-Toe (v3) 2/92005 8:02:42PM Page 5 of 6 COMPASS 2003.11 Build 50 eR!ciNa~ ' ~ • ~-' Ph ii C Halliburton Company h -SI.R'! onoco ~ ~ps Planning Report -Geographic A~BSICa A Hallibunon Company Database: EDM 2003,11 Single User Dp Locai Co-ordinate Reference: Well Plan 1 E-117 Company: ConocoPhiliips Alaska Ino.(Kuparuk) TVD Reference: 66,9 GL + 40RF=106. 9 ~ 106.90ft (Doyon 15 (66.9GL + 40R Project: Kuparuk River Unit MD Reference: 66,9 GL + 40RF=106. 9 @ 106.90ft (Doyon 15 (66.9GL + 40R Site: Kuparuk 1E Pad North Reference: True Welh Plan 1 E-117 Survey Calculation Method: Minimum Curvature Weiibore: 1 E-117 L2 Design: 1E-117 L2 (wp04) r- II Geologic Targets --- - 1 E-117 L2 --------------- -- - -- -- -- - -- - - - _-- - - - ~I I TVD Target Name +NI-S +E/-W Northing II Easting (ft) -Shape ft ft (ft) (ft) 3,248.90 1E-117 L2-T5 (v3) -11,620.56 1,988.95 5,947,995.00 552,367.00 - Point 3,326.90 1E-117 L2-T1 (v3} -8,703.22 1,989.47 5,950,912.00 552,348.00 - Point 3,192.90 1E-117 L2-Toe (v3) -14,108.86 1,989.29 5,945,507.00 552,384.00 - Point 3,219.90 1E-117 L2-Tfi )v3) -12,239.64 1,988.80 5,947,376.00 552,371.00 - Point 3,268,90 1E-1t7L2-T4(v3) -10,499.43 1,989.45 5,949,116.00 552,360.00 - Point I 3,300.90 tE-117 L2-T2 (v3} -9,300.29 1,989.48 5,950,315.00 552,352.00 I -Point I 3,293.90 1E-117 L2-T3 (v3) -9,521.31 1,989.00 5,950,094.00 552,353.00 II -Point i Prognosed Casing Points !i ~~ l I Measured Vertical Casing i Hoie !I Depth Depth Diameter Diameter (ft) Ift) (") (") 5,382.18 2,377.90 133/8 16 9,335.05 3,357.90 95/8 12-1l4 15,639.39 3,192.90 6-1/2 8-112 Prognosed Formation intersection Points Measured Vertical Depth Inclination Azimuth Depth +N/-E +E!-W (ftl (°) (°I (ft) (ft1 (ft) Name 2,051.72 73.00 160.00 1,528.90 -959.86 368.52 Base of Permafrost 2,876.10 75.44 166.31 1,747.90 -1,723.42 585.36 T3 3,910.36 75.44 166.31 2,007.90 -2,696.03 822.22 K16 5,382.18 75.44 166.31 2,377.90 -4,080.13 1,159.29 T3+676 6,607.37 75.44 166.31 2,685.90 -5,232.31 1,439.87 Ugnu C 7,605.82 75.44 166.31 2,936.90 -6,171.26 1,666.53 Ugnu B 7,776.87 75.44 166.31 2,979.90 -6,332.11 1,707.70 Ugnu A 8,492.90 75.44 166.31 3,159.90 -7,005.46 1,871.68 K13 9,335.04 78.00 180.03 3,357.90 -7,811.78 1,989.85 West Sak D 2/9/2005 8:02:42PM Page 6 of 6 COMPASS 2003.118ui1d 50 ~~ SURVEY PROGRAM Date: 21XK02-09TW:110:00 Validated: Ves Version: Dep[h Fmm Depth To Suner/Plan Tool JO.UO 8110.011 CB-GYRO-SSS 8W.IX1 9335,0.1 MWD 9335,0! 15439.30 IE-117 L2 (wpDQ MWD 0 270 TO /V ...~~ ~~ 180 avelling Cylinder Azimuth (TFO+AZI) I°I vs Centre to Centre Separation I50 ftdnl ANTI-COLLISION SETTINGS Interpolation Method: MD Interval: 25Stations Depth Range From: 9335.04 To 15747 Maximum Range:1800 Reference: Plan: 1E-117 L2 (wp04) REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Plan 1 E-117, True Nonh Venical (TVD) Reference: 66.9 GL + 40RF=106.9 (8~ 106.90ft (Doyon 15 (66.9GL + 40RK8)) Section (VS) Reference: Slot - (O.OON, O.OOE) Measured Depth Reference: 66.9 GL + 40RF=106.9 ~ 106.90ft (Doyon 15 (66.9GL + 40RK8)) Calculation Method. Minimum Curvature WELL DETAILS: PWn 1E-117 Ground Level: 66.90 +WS +E/-W Northing Eaatin9 Latinude Longitude Sbt 0.00 0.00 5959600.86 850300.51 70°[8'1.427N 149°35'33.405W ConocoPhillipsAWska Inc.(Kuparuk) Engineering West Sak Calculation Method: Minimum Curvature Error System: 1.9L1NSPL Scan Meftad: Trov. CyiirWer North Error Surface: Elliptical Conic Warning Method: Rules Based From Colour To MD 0 100 100 200 200 300 300 400 400 500 500 600 600 700 700 800 800 -- ~ ""~ 900 900 1000 1000 1500 1500 2000 2000 3000 3000 4000 4000 5000 5000 6000 6000 7000 7000 --- 8000 8000 9000 9000 10000 10000 ---- -"--- 11000 11000 12000 12000 13000 13000 -~----- 14000 14000 --- 15000 15000 17000 90 LEGErvG ~- 1E-112, 1E-112.1E-112 V1 ~- 1E-112.1E-112L1. 1E-112L1 VO -{_}-- tE-112. tE-112L2, tE-112L2 Vi -~-- 1E-112.1E-112PB1. 1E-112PB/V2 -~ 1E-114.1E-11 <. 1E-114 V1 $- tE-11d, 1E-114L1.1E-ltdll Vl ~-- tE-114,1E-1 /4L2.tE-114L2 V0 --&- 1E-119. tE-119.1E-1f9V1 -$- tE-188. tE-166,1E-166 V1 tE-166,1E-166L1, tE-16611 V1 ""4~-- tE-16fi, 1E-168L1P81. IE-186L1PB1 V2 ~- tE-166,1E-168L2.1E-18BL2 Vt -~- 1E-168,1E-168,1E-168 V1 ~- 1E-166.1E-186L1, tE-1BBL1 V3 ~-~-" tE-168.1E-18BL2, tE-166L2 V1 ~t- tE-168,1E-168L2PB1, 1E-168L2PB1 V3 -~- 1E-166,1E-16BPB1. tE-18BP81 V3 --~--~ 1E-23.1E-23.1E-23V1 -~ tE-24.1E-20. tE-24 V4 ~- tE-24.1E-2M.1E-2M V1 --~- 1E-25.1E-25. tE-25 V1 1E-Zfi. tE-26. tE-26 Vt -~ tE-33. tE-33.1E-33 V2 --e- 1E-33P81, tE-J3PB1.1E-33P81 V2 tE-35.1E-35. 1Ea5 V1 ~rr Pkn tE-1I0, PYn tE-1 ]0, tE-170 (wpD31 VO Plan tE-1]O, PMn fE-170 L1,tE-1]O L11wp03)VO Plan tE-i]O, PMn tE-1]0 L2. tE-1]0 L21wp03)VO "-~f-- u. m.111o. 111o v] --~--~ Pbn 11158,1)-M3ALe1xe1, 1J-M3A LabrYl Veni2A V' %an 11160,PYn 1J-M2 Let A. Plen 1J-M2 LetA VO -~~ Pkn 11162 (1.11), 11182, iJ-162 (wp03.1-NOM Hea6 VO --e-- Plan 11163 (M11, 1118211,11162 L11wp31) V0 -~- %en 111621M11, 11182 L2.11162 L2 (wp3.11 V0 -$- %en 1J-188.1)-166, 1J-166 (wp031 V0 -~- Plan 111E8.1J"168 L1, 1J-IBB Lt (wp03)VO -tJ %an 11166, iJ"I88 L2. 11166 L2 (wp031 V0 KOP34-11-1°1, 30"11-10.3411-10 V2 WSAK-0J. WEAK-03, WSAK-03 V0 --~- 1E-11]L3IWp011 180 Travelling Cylinder Azimuth (TFO+AZI) ~°~ vs Centre to Centre Separation X10 ft/in~ SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W OLeg TFace VSec Target 1 9335.04 78.00 180.03 3357.90 -7811.79 1989.85 0.00 0.00 7811.79 2 9351.54 80.24 180.03 3381.01 -7827.99 1989.84 13.80 0.00 7827.99 3 9381.54 80.24 180.03 3366.10 -7857.55 1989.82 0.00 0.00 7857.55 4 9707.44 93.28 180.03 3384.47 -8182.23 1989.65 4.00 360.00 8182.23 5 9799.10 96.95 180.02 3376.30 -8273.51 1989.82 4.00 -0.19 8273.51 6 10140.03 96.95 180.02 3335.07 -8611.94 1989.51 0.00 0.00 8611.94 7 10231.69 93.28 180.03 3326.90 -8703.22 1989.47 4.00 179.81 8703.22 1E-117 L2-T1 (v3) 8 10258.53 92.48 180.00 3325.55 -8730.02 1989.47 3.00 -177.79 8730.02 9 10829.33 92 48 180.00 3300.90 -9300 29 1989.48 0.00 0.00 9300.29 1 E-117 L2-T2 (v3) 1010853.03 91.78 180.13 3300.02 -9323.98 1989.45 3.00 169.27 9323.98 1111050.46 91.78 180.13 3293.90 -9521.31 1989.00 0.00 0.00 9521.31 1 E-117 L2-T3 (v3) 1211062.20 91.46 179.97 3293.57 -9533 OS 1988.99 3.00 -153.19 9533.05 1312028.90 91.46 179.97 3268.9x10499.43 1989.45 0.00 0.0010499 43 1 E-117 L2-T4 (v3) 1412043.78 91.02 180.03 3268.5&10514.31 1989.45 3.00 173.1010514.31 1513150.21 91.02 180.03 3248.9x11620.56 1988.95 0.00 0.00 11620.56 tE-117 L2-TS (J3) 1813208.37 92.76 180.01 3248.98-11678.69 1988.93 3.00 -0.4411678.69 1713769.97 92.76 180.01 3219.9x12239.64 1988.80 0.00 0.00 12239.64 1 E-117 LZ-T6 )v3) 1813835.68 90.79 179.98 3217.8612305.31 1988.80 3.00 -179.1812305.31 1915639.40 90.79 179.98 3192.9x14108.86 1989.29 0.00 0.0014108.86 1E-117 L2-Toe (v3) Halliburton Company Anticollision Report Company: ConocoPhillipsAlsskalnc. Date: '.2/9/2005 Time: 19:46:20 Page: 1 Field: Kuparuk River Unit . Reference Site: Kuparuk 1 E Pad Co-ordinate(NE) Reference: Weli: Plan 1 E-117, True North Reference Well: Plan 1 E-117 Vertical (TVD)Reference: Doyon 15 (40 +66.9) 106.9 Reference Wellpath: Plan 1 E-117 L2 Db: OraG2 NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Principal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.000 ft Error Model: ISCWSA Ellipse Depth Range: 9335.040 to 15639.400 ft Scan Method: Trav Cylinder North Maximum Radius:10000.000 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 12!15/2004 Validated: No Version: 2 Planned From To Survey Toolcode Tool Name ft ft 40.000 812.000 Planned: 1 E-117 (wp04) V2 (0) CB-GYRO-SS Camera based gyro single shot 812.000 9335.040 Planned: 1 E-117 (wp04) V2 (0) MWD MWD -Standard 9335.040 15639.400 Planned: 1 E-117 L2 (wp04) V1 MWD MWD -Standard Casing Points - AID T'VD Diameter Hole Size \ame ~ ft ft - in in __ -- 15639.400 3192.830 5.500 8.500 51/2" Summary <--------------------- Offset R'cilpath ------------------> Reference Offset Ctr-Cir No-Go Allowable Site Well Wellpath 'MD MD Distance Area Deviation Warning ft ft ft ft ft Kuparuk 1 E Pad 1 E-112 1 E-112 V1 Out of range Kuparuk 1 E Pad 1 E-112 1 E-112L1 VO Out of range Kuparuk 1 E Pad 1 E-112 1 E-11212 V1 Out of range Kuparuk 1 E Pad 1 E-166 1 E-166 V1 Out of range Kuparuk 1 E Pad 1 E-166 1 E-166L1 V1 Out of range Kuparuk 1 E Pad 1 E-166 1 E-166L2 V1 Out of range Kuparuk 1 E Pad Plan 1 E-170 Plan 1 E-170 L1 V1 Plan 15634.004 1 5075.000 1549.350 740.980 808.370 Pass: Major Risk Kuparuk 1E Pad Plan 1E-170 Plan 1E-170 L2 V1 Plan 15616.344 1 5050.000 1547.589 740.017 807.572 Pass: Major Risk Kuparuk 1 E Pad Plan 1 E-170 Plan 1 E-170 VO Plan: 1 15618.154 1 5075.000 1567.013 768.444 798.569 Pass: Major Risk Kuparuk 1J Pad 1J-10 1J-10 V7 12724.858 7625.000 1736.008 391.475 1344.533 Pass: Major Risk Kuparuk 1J Pad Plan 1J-158 Plan 1J-M3 Lat A VO 15636.262 5850.000 1810.114 535.370 1274.743 Pass: Major Risk Kuparuk 1J Pad Plan 1J-160 Plan 1J-M2 Lat A V0 15637.282 7100.000 509.646 422.044 87.603 Pass: Major Risk Kuparuk 1J Pad Plan 1J-162 1J-162 V3 Plan: 1J-162 15574.544 7800.000 776.078 413.432 362,646 Pass: Major Risk Kuparuk 1J Pad Plan 1J-168 1J-168 Li V2 Plan: 1J- 15372.615 6825.000 1551.322 543.738 1007.585 Pass: Major Risk Kuparuk 1J Pad Plan 1J-168 1J-168 L2 V1 Plan: 1J- 15372.615 6825.000 1551.322 543.738 1007,585 Pass: Major Risk Kuparuk 1J Pad Plan 1J-168 1J-168 V1 Plan: 1J-168 15372.615 6825.000 1551.322 543.738 1007.585 Pass: Major Risk Kuparuk River Unit N KUP 34-11-10-1 KUP 34-11-10-1 V1 15372.083 3350.000 1154.223 590.588 563.636 Pass: Major Risk Non-Pad WSAK-03 WSAK-03 VO 10238.279 3325.000 837.085 406.689 430.396 Pass: Major Risk Site: Kuparuk 1E Pad Well: Plan 1 E-170 Rule Assigned: Major Risk Wellpath: Plan 1E-170 L1 V1 Plan: 1E-170 L2 (wp03) V2 Iuter-Site Error: 0.000 ft Reference Offset -' Semi-Major Axis Ctr-Ctr No-Go Allowable NiD TVD MD TVD ~ Ref Offset TFO+AZITFO-HS Casing/HSflistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 9365.872 3363.373 8825.000 3183.134 118.967 43.776 263.206 83.176 6.750 1539.131 494.523 1044.608 Pass 9392.044 3367.770 8850.000 3189.645 119.175 43.840 263.287 83.257 6.750 1537.409 495.255 1042.154 Pass 9420.415 3372.095 8875.000 3196.149 119.397 43.904 263.384 83.354 6.750 1535.970 496.114 1039.856 Pass 9448.667 3375.849 8900.000 3202.643 119.620 43.969 263.500 83.470 6.750 1534.806 496.755 1038.051 Pass 9476.775 3379.035 8925.000 3209.126 119.842 44.033 263.636 83.606 6.750 1533.920 497.404 1036.515 Pass 9504.715 3381.658 8950.000 3215.599 120.065 44.113 263.790 83.760 6.750 1533.290 498.346 1034.944 Pass 9532.462 3383.726 8975.000 3222.069 120.300 44.216 263.963 83.933 6.750 1532.680 499.156 1033.524 Pass 9559.995 3385.248 9000.000 3228.540 120.533 44.319 264.153 84.123 6.750 1532.035 499.976 1032.059 Pass 9587.298 3386.235 9025.000 3235.010 120.764 44.448 264.361 84.331 6.750 1531.361 500.871 1030.490 Pass 9614.354 3386.700 9050.000 3241.481 121.001 44.590 264.586 84.556 6.750 1530.663 502.086 1028.577 Pass 9641.148 3386.656 9075.000 3247.951 121.242 44.732 264.828 84.798 6.750 1529.947 503.074 1026.873 Pass 9667.664 3386.120 9100.000 3254.422 121.480 44.874 265.087 85.057 6.750 1529.220 504.073 1025.148 Pass 9693.888 3385.107 9125.000 3260.892 121.716 45.016 265.363 85.333 6.750 1528.489 505.080 1023.409 Pass 9719.762 3383.638 9150.000 3267.363 121.955 45.159 265.654 85.626 6.750 1527.760 506.330 1021.430 Pass 9745.278 3381.732 9175.000 3273.817 122.197 45.302 265.958 85.933 6.750 1527.043 507.390 1019.653 Pass • 1 E-117L2 Drilling Hazards Summary_ 8 1/2" Open Hole / 5 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 0 ever, Decreased mud wei ht Lost Circulation Moderate Reduced um rates, Mud rheolo , LCM Hole Swabbing on Trips Low ~ Trip speeds, Proper hole filling (use of trip ~ sheets , Pum in out 1E-114 Drilling Hazards Summary prepared by Steve Shultz 2/1/2005 3:40 PM ~m ~ • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~~~f /~-// •i ~-- ~ Development Exploration Service Stratigraphic CHECK WI3AT ADD-OHS "CLUE"• APPLIES (OPTIONS • MUFTI The permit is for a new wellbore segment of LATERAL existing well !l/2~ ~~`~~~~ s~' •" `"~~ Z S a ~ API No. Permit No, Lc~-o (lf API number Production. should continue to be reported as . last two. (2) digits a funciion~of the original API number stated are between 60-69) above. • PILOT I]OLE In accordance with ~ 20 AAC 25.005(n, all CPS records, data and logs acquired. for ibe pilot . bole must be clearly differentiated ~in both • name (name on permit pins PIS and API number (50 - 70/80) from records, data and logs acquired • for well (name on permit). SPACING The permit is approved subject •to fug EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing ~ ezception. (Comaanv Hamel assumes the liability of any protest to the spacing .eiception that may occur. . DRY DITCH ~ All dry ditch sample sees submitted to the SAMPLE Commission must be in no greater than 30' . sample intervals from below the permafrost • or from where samples are first caught and ] 0' sample intervals through target zones. _~ WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAK OIL • 490150 __-- Well Name: KUPARUK RIV U WSAK 1E-117L2 Program SER Well bore seg ~ PTD#:2050280 Company CONOCOPHILLIPS ALASKA INC Initial Classlfype SER 1 PEND GeoArea 890 Unit 11160 OnlOff Shore On Annular Disposal ^ Administration 1 Permit-fee attached________________________________-_ ___-_-__-NA____ -- .Multilate[akwellsegmenk;feewaivedper20AAC25.OQ5(e)_-_--_-____.__--________.-_--_- 2 Lease number appropriate________________________--__--_ -- -__--Yes--__ _Wellbore segment-IocakedinADL-025660,_-__.__-----_- ------------------------- 3 Uniquewell_nameandnumbe[_______________ -_-_____- _---_-_-Yes_--._ --_- 4 Well located in.a_defnedpo4l- - - _ _ - - -- Yes - KRU West_Sak Oil Pool, overned.b Conservation-Order No, 4066_ _ - - - - - -- q y - - 5 Well located proper distance from drilling unit-boundary_ _ - - Yes WsU is more than-500 feet from an external property line, - _ _ - - - _ _ _ - 6 Weil located proper distance from other wells_ _ - - - Yes - - - - - No restrictions as_to well spacing in CO.406B _ . - ----------------------------- 7 Sufficient acreageayailablein-dril_linqunit--_-______ ___________ _________Yes_____-_ _--__-_____-__-__-- - - -- 8 Ifdeviated,is-wellboreplat-inc_luded_-___--__-__ -- - _- Yes------- ------------------ - -- 9 Operator only affected party___---__-_____-------- ---- ----Yes------- ----- --------------- - -- 10 Aperakorhas-appropriate-bond infRrce---------- - --- ------ ---------Yes..--- --... --------- --- -- ------- -------------- ------------ --- - ~11 Pe[mitean be issued without conservation order, - - - - Yes - - - - - - - Appr Date 12 Permit_canbeissuedwithoutadministrative_approval---------------- ---------Yes--._-__ __--__________--__ -- SFD 212312005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by Injection Order # (put_10# in comments)-(For Yes - - - - - Area Injection Order No.-2B. ~ -- - 15 All wells within 114_mile area of review ident[fied (Far service well only) _ _ _ _ _ _ _ _ _ __ _ _ _ _ Yes - - . - - - - Kup_34,11-1011,1E-166.± Iaterals,1E11$ ± Iaterals,1J-160, 1J-162,1J•10,1 E-36 - _ _ _ _ _ _ _ _ _ - _ _ _ _ - _ _ - 16 Pre-produced injector; duration of pre production Less than 3 months-(FOr_service well only) - - _N_o - - - - 17 ACMP-Finding of Consiskency_hasbeenissued_for-this project___________ _________NA-____--- --_-__-_____---_-_-.-.-___ - - - - Engineering 18 Conducto[ string.provided - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - NA_ _ - - _ _ - - _ Conductor_set-in motherbore,-1E-117 f20.5-026), _ _ - . - - . _ _ _ _ - _ - - _ _ -- 19 Surfacecasigg-prQtectsall_knpwnUSDWS--------- --- ----___ _-__----, NA--___-- Allaqurfersexempted, 40CFR.147.102_(b)(3).__-_-_-___ _-_-____- __----_ 20 CMT_v_ok adequate_to circulate_on conductor_& surf_ag _ . _ _ - - - NA- _ - _ Surface caskn set in_ 1 E-117, g - - 21 CMT_vol. adequate-to tie-in long string to surf csg_ - - - - - - _ . _ - - _ . _ _ - NA_ Produclion_easin set i_n_1 E-117, All h drocarbon-zones_ tanned-to be covered.. 9 y p 22 CMT_willcoverallknown_productivehorizons____________________ _________ No---_-_ - Slotted linercompletin_planned,_ .______ __--_.----_--------__ _____---- 23 Casing designs adequate forC,TB&permafrost_-_____ _ __- __--_----Yes_ _____ _____ _________ 24 Adequate tankage-or reserve pit - - - Yes - . - Rig is-equipped with steel_pits. -NO resen!e_pitplanned, All waste to_an approved annulus or Class_ II well. 25 Ifa-re-drill,hasa1.0-403 forabandonmenkbeenapproved----- ------- ---------NA__ ----_ ___-_--_- -- -- 26 Adequate wellbore separatjonproposed _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes . - - _ - - - Proximity. analysis performed, Traveling cylinder plot-plrovided.. Nearest wellbore_is B lateral below.. _ _ - - _ _ - 27 If divertertequired,doesitmeetregulations______________________ __-_---- NA_---__-- BQPstadc-willalready_be-in place,____-_--_-_____-__-__-- Appr Date 28 Drillingfiuid-program schematic & equip list adequate_ _ _ - - _ _ Yes - - _ _ - . Maximum expected formation pressure 8.6-- 9,0-EMW, Planned MW up to-9.0 Rp9• TEM 2/2812005 29 BOPEs,_dothe meet reulation_ _--_-.--- ---- y 9 -- -----Yes------ ----------------------------- -- ,~,//f ~~ lI~•/ 30 BOPE_press raiing appropriate; lest to-(put prig in comments)- . - - . - - . - - - Yes _ - . - - - --- MASP calculated at 1161 psi, 3000_psi-appropriate. _CP_AI normally tests_to 6000-psi. - - _ - 31 Choke_manrfold complies w/API_ RP-43 (May 84)- _ _ - ... _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - . _ _ _ _ - _ - -- - 32 Work will occurwhhoutoperationshutdown__________ ___________ ______ __Yes-_____- -__ 33 Is presence of H25 gas. probable _ _ _ . - - - _ _ - - - _ - - -Yes H2S has been seen in 1E WS wells, Mud should_preclude H2S on rig. Riq has sensors and alarms, 34 Mechanical condition of wells wi-thin AQR verified (For service well only) - _ _ - - _ _ Yes - - - - - - 33.11-10-1- (186-158) only penetration in AOR, File review indicates_weh is_prope[ly P&A. - _ - - Geology 35 Permit_can be issued wlo hydrogen_sulfidemeosures _ - . - _ _ _ _ _ - - No- - KRU 1E-Pad West Sak wells measured from 22 to 76 ppm H2S in 2044. 36 Data-presented on- potential overpressu[e zones- _ _ _ - - _ . -Yes _ Expected reservoirpressure rs 8:6 - 9,0_ppg EMW; will-be drilled with 9.4 ppg mud. - - - - Appr Date 37 Seismic analysis of shallow gas-zones- - - NA- - _ - _ - - - SFD 2/23/2005 38 Seabed conditoon survey-(if off-shore) _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ - - - - - - - - - - -- - - - -- 39 Contact namelphonefor weekly progress reports [exploratory only] - - - - - - - - - - - - - - - NA_ Geologic Commissioner: Engineering blic Date.^~~ Commissioner: Date Co ' n r Date ~ ~~ Slg~ ~ ~ • Well History File APPENDIX • Information of detailed nature that is not particularly germane 1o the Wei{ Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Nov 16 14:39:27 2005 Reel Header Service name .............LISTPE Date .....................05/11/16 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................05/11/16 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF ~p~~oa~ Scientific Technical Services Scientific Technical Services Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: 1E-117 L2 PBl API NUMBER: 500292325172 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 16-NOV-05 JOB DATA MWD RUN 4 MWD RUN 13 MWD RUN 14 JOB NUMBER: MW0003775114 MW0003775114 MW0003775114 LOGGING ENGINEER: P. ORTH P. ORTH P. ORTH OPERATOR WITNESS: D. GLADDEN D. GLADDEN D. GLADDEN MWD RUN 15 JOB NUMBER: MW0003775114 LOGGING ENGINEER: P. ORTH OPERATOR WITNESS: D. GLADDEN SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 16 11 10 11 228 94.90 66.90 ~ /344-- OPEN HOLE CASING DRILLERS ~~ BIT SIZE (IN) SIZE (IN) DEPTH (FT) • 1ST STRING 12.250 13.375 5543.0 2ND STRING 8.500 9.625 9391.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE EXITS 1E-117 PB1 AT 9391'MD/3342'TVD. 4. MWD RUNS 1-3,12,13 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED, EXCEPT FOR SROP DATA FOR RUN 13. 5. MWD RUNS 4,14,15 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) MWD RUNS 4,15 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP) AND PRESSURE-WHILE-DRILLING (PWD) MWD RUN 15 ALSO INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN), AZIMUTHAL LITHO-DENSITY (ALD), AND ACOUSTIC CALIPER (ACAL). NO ALD DATA ARE PRESENTED BETWEEN 9841'MD AND 10588'MD DUE TO AN INTERMITTENT TOOL FAILURE. 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 1-4,13-15 REPRESENT WELL 1E-117L2PB1 WITH API#: 50-029-23251-72. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11479'MD/3288'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). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, ACAL-DERIVED). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. ACAL = ACOUSTIC CALIPER. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: ACAL-DERIVED - 8.5" BIT MUD WEIGHT: 9.0 - 9.1 PPG MUD SALINITY: 41000 - 47000 PPM CHLORIDES FORMATION WATER SALINITY: 6000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/16 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH RPX 5517.0 11433.0 RPS 5517.0 11433.0 RPM 5517.0 11433.0 RPD 5517.0 11433.0 FET 5517.0 11433.0 GR 5524.5 11441.0 ROP 5560.5 11479.0 NPHI 9509.5 11386.5 FONT 9509.5 11386.5 NCNT 9509.5 11386.5 CALA 9511.5 11390.0 DRHO 9522.5 11400.5 RHOB 9522.5 11400.5 PEF 9522.5 11400.5 • # ' BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP MERGE BASE 4 5517.0 9391.0 13 9391.5 9421.0 14 9421.0 9599.0 15 9599.0 11479.0 REMARKS: MERGED MAIN PASS. 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 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 CALA MWD INCH 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5517 11479 8498 11925 5517 11479 ROP MWD FT/H 0.02 430.52 182.928 11838 5560.5 11479 GR MWD API 27.74 127.35 71.498 11834 5524.5 11441 RPX MWD OHMM 1.76 1701.52 21.5486 11833 5517 11433 RPS MWD OHMM 3.06 1234.97 23.8187 11833 5517 11433 RPM MWD OHMM 2.55 1835.59 26.394 11833 5517 11433 RPD MWD OHMM 4.28 2000 29.9642 11833 5517 11433 FET MWD HOUR 0.15 709.93 1.71968 11833 5517 11433 NPHI MWD PU-S 9.134 48.612 34.3881 3755 9509.5 11386.5 FCNT MWD CNTS 635 4348 1174.96 3755 9509.5 11386.5 NCNT MWD CNTS 120460 226835 153841 3755 9509.5 11386.5 RHOB MWD G/CM 2.032 4.198 2.27484 2263 9522.5 11400.5 DRHO MWD G/CM -0.056 0.547 0.0449717 2263 9522.5 11400.5 PEF MWD BARN 1.5 5.51 2.377 2263 9522.5 11400.5 CALA MWD INCH 8.84 11.06 9.26397 3758 9511.5 11390 First Reading For Entire File..........5517 Last Reading For Entire File...........11479 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/16 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/16 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 5517.0 9391.0 RPM 5517.0 9391.0 RPS 5517.0 9391.0 RPX 5517.0 9391.0 FET 5517.0 9391.0 GR 5524.5 9391.0 ROP 5560.5 9391.0 LOG HEADER DATA DATE LOGGED: O1-JLTL-OS SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9391.0 TOP LOG INTERVAL (FT) 5560.0 BOTTOM LOG INTERVAL (FT) 9391.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 70.6 MAXIMUM ANGLE: 83.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 120558 EWR4 ELECTROMAG. RESIS. 4 67981 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 12.250 5543.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Water Based 9.30 63.0 9.0 140 4.8 4.000 65.0 2.770 97.0 3.400 65.0 3.000 65.0 Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units.........,.Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel • DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5517 9391 7454 7749 5517 9391 ROP MWD040 FT/H 1.15 430.52 201.873 7662 5560.5 9391 GR MWD040 API 27.74 127.35 71.4979 7734 5524.5 9391 RPX MWD040 OHMM 1.76 1345.45 12.1738 7749 5517 9391 RPS MWD040 OHMM 3.06 1234.97 14.0717 7749 5517 9391 RPM MWD040 OHMM 6.41 1835.59 16.2879 7749 5517 9391 RPD MWD040 OHMM 4.99 2000 20.2857 7749 5517 9391 FET MWD040 HOUR 0.15 89.37 1.43885 7749 5517 9391 First Reading For Entire File..........5517 Last Reading For Entire File...........9391 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/16 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.......05/11/16 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 13 DEPTH INCREMENT: .5000 • • FIL E SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 9391.5 9421.0 LOG HEADER DATA DATE LOGGED: 29-JUL-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9421.0 TOP LOG INTERVAL (FT) 9391.0 BOTTOM LOG INTERVAL (FT) 9421.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASING DEPTH (FT) .0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) 9.00 MUD VISCOSITY (S) •0 MUD PH: •0 MUD CHLORIDES (PPM): 0 FLUID LOSS (C3) •0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 .0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .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 ROP MWD130 FT/H 4 1 68 4 2 • First Name Service Unit Min Max Mean Nsam Reading DEPT FT 9391.5 9421 9406.25 60 9391.5 ROP MWD130 FT/H 0.44 122.97 22.06 60 9391.5 First Reading For Entire File..........9391.5 Last Reading For Entire File...........9421 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/16 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/16 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.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: 14 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 9391.5 9549.5 RPD 9391.5 9549.5 RPM 9391.5 9549.5 RPS 9391.5 9549.5 RPX 9391.5 9549.5 GR 9391.5 9557.5 ROp 9421.5 9599.0 LOG HEADER DATA DATE LOGGED: 30-JUL-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9599.0 TOP LOG INTERVAL (FT) 9421.0 BOTTOM LOG INTERVAL (FT) 9599.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 78.1 MAXIMUM ANGLE: 93.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER Last Reading 9421 9421 DGR EWR4 DUAL GAMMA RAY ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN}; EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order DEPT ROP MWD140 GR MWD140 RPX MWD140 RPS MWD140 RPM MWD140 RPD MWD140 FET MWD140 132482 157645 8.500 9391.0 Oil Based 9.00 87.0 .0 47000 .0 .000 .0 .000 86.0 .000 .0 .000 .0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 OHMM 4 1 68 20 6 OHMM 4 1 68 24 7 HOUR 4 1 68 28 8 Name Service Unit Min Max Mean Nsam DEPT FT 9391.5 9599 9495.25 416 ROP MWD140 FT/H 2.08 249.02 134.473 356 GR MWD140 API 58.11 86.48 69.9102 333 RPX MWD140 OHMM 5.47 1701.52 50.5498 317 RPS MWD140 OHMM 7.46 79.9 37.3185 317 RPM MWD140 OHMM 2.55 93.44 35.782 317 RPD MWD140 OHMM 4.28 2000 77.9653 317 FET MWD140 HOUR 0.35 709.93 12.2099 317 First Reading 9391.5 9421.5 9391.5 9391.5 9391.5 9391.5 9391.5 9391.5 Last Reading 9599 9599 9557.5 9549.5 9549.5 9549.5 9549.5 9549.5 First Reading For Entire File..........9391.5 • Last Reading For Entire File...........9599 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/16 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.......05/11/16 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: 15 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NPHI 9509.5 11386.5 FCNT 9509.5 11386.5 NCNT 9509.5 11386.5 CALA 9511.5 11390.0 RHOB 9522.5 11400.5 DRHO 9522.5 11400.5 PEF 9522.5 11400.5 RPM 9550.0 11433.0 RPS 9550.0 11433.0 RPD 9550.0 11433.0 FET 9550.0 11433.0 RPX 9550.0 11433.0 GR 9558.0 11441.0 ROP 9599.5 11479.0 LOG HEADER DATA DATE LOGGED: O1-AUG-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 11479.0 TOP LOG INTERVAL (FT) 9599.0 BOTTOM LOG INTERVAL (FT) 11479.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 89.4 MAXIMUM ANGLE: 92.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER • • DGR DUAL GAMMA RAY 163686 EWR4 ELECTROMAG. RESIS. 4 134760 CTN COMP THERMAL NEUTRON 105918 ASLD Azimuthal Litho-Den 143795 ACAL Acoustic Caliper 143795 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASING DEPTH (FT) 9391.0 BOREHOLE CONDITIONS MUD TYPE: Oil Based MUD DENSITY (LB/G) 9.10 MUD VISCOSITY (S) 70.0 MUD PH: .0 MUD CHLORIDES (PPM): 43000 FLUID LOSS (C3) .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 138.2 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .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 ROP MWD150 FTfH 4 1 68 4 2 GR MWD150 API 4 1 68 8 3 RPX MWD150 OHMM 4 1 68 12 4 RPS MWD150 OHMM 4 1 68 16 5 RPM MWD150 OHMM 4 1 68 20 6 RPD MWD150 OHMM 4 1 68 24 7 FET MWD150 HOUR 4 1 68 28 8 NPHI MWD150 PU-S 4 1 68 32 9 FCNT MWD150 CNTS 4 1 68 36 10 NCNT MWD150 CNTS 4 1 68 40 11 RHOB MWD150 G/CM 4 1 68 44 12 DRHO MWD150 G/CM 4 1 68 48 13 PEF MWD150 G/CM 4 1 68 52 14 CALA MWD150 INCH 4 1 68 56 15 First Name Service Unit Min Max Mean Nsam Reading Last Reading DEPT FT 9509.5 11479 10494.3 3940 509.5 11479 ROP MWD150 FT/H 0.02 376.34 151.478 3760 9599.5 11479 GR MWD150 API 51.76 98.12 71.6386 3767 9558 11441 RPX MWD150 OHMM 16.64 70.61 38.3928 3767 9550 11433 RPS MWD150 OHMM 18.36 76.91 42.733 3767 9550 11433 RPM MWD150 OHMM 19.03 78.48 46.3929 3767 9550 11433 RPD MWD150 OHMM 19.79 76.7 45.8343 3767 9550 11433 FET MWD150 HOUR 0.21 20.42 1.4146 3767 9550 11433 NPHI MWD150 PU-S 9.134 48.612 34.3881 3755 9509.5 11386.5 FCNT MWD150 CNTS 635 4348 1174.96 3755 9509.5 11386.5 NCNT MWD150 CNTS 120460 226835 153841 3755 9509.5 11386.5 RHOB MWD150 G/CM 2.032 4.198 2.27484 2263 9522.5 11400.5 DRHO MWD150 G/CM -0.056 0.547 0.0449717 2263 9522.5 11400.5 PEF MWD150 G/CM 1.5 5.51 2.377 2263 9522.5 11400.5 CALA MWD150 INCH 8.84 11.06 9.26397 3758 9511.5 11390 First Reading For Entire File..........9509.5 Last Reading For Entire File...........11479 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/16 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date .....................05/11/16 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Reel Trailer Service name .............LISTPE Date .....................05/11/16 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Physical EOF Physical EOF Writing Library. Scientific Technical Services Writing Library. Scientific Technical Services End Of LIS File Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Nov 1613:38:30 2005 Reel Header Service name .............LISTPE Date .....................05/11/16 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................05/11/16 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library • / 3-~~3 ~©s-- D ~g Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER West Sak MWD/MAD LOGS WELL NAME: 1E-117 L2 API NUMBER: 500292325161 OPERATOR: ConocoPhillips Alaska, Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 16-NOV-05 JOB DATA MWD RUN 4 MWD RUN 13 MWD RUN 14 JOB NUMBER: MW0003775114 MW0003775114 MW0003775114 LOGGING ENGINEER: P. ORTH P. ORTH P. ORTH OPERATOR WITNESS: D. GLADDEN D. GLADDEN D. GLADDEN MWD RUN 15 MWD RUN 16 JOB NUMBER: MW0003775114 MW0003775114 LOGGING ENGINEER: P. ORTH P. ORTH OPERATOR WITNESS: D. GLADDEN D. GLADDEN SURFACE LOCATION SECTION: 16 TOWNSHIP: 11 RANGE: 10 FNL: FSL: 11 FEL: 228 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 94.90 GROUND LEVEL: 66.90 WELL CASING RECORD OPEN HOLE CASING DRILLERS • BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 13.375 5543.0 2ND STRING 8.500 9.625 9391.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELLBORE EXITS 1E-117 L2 PBl AT 10980'MD/3308'TVD BY MEANS OF AN OPENHOLE SIDETRACK. 4. MWD RUNS 1-3,12,13 WERE DIRECTIONAL ONLY - NO DATA ARE PRESENTED, EXCEPT FOR SROP DATA FOR RUN 13. 5. MWD RUNS 4,14-16 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) MWD RUNS 4,15,16 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP) AND PRESSURE-WHILE-DRILLING (PWD) MWD RUNS 15,16 ALSO INCLUDED COMPENSATED THERMAL NEUTRON POROSITY (CTN), AZIMUTHAL LITHO-DENSITY (ALD), AND ACOUSTIC CALIPER (ACAL). NO ALD DATA ARE PRESENTED BETWEEN 9841'MD AND 10588'MD DUE TO AN INTERMITTENT TOOL FAILURE. 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 1-4,13-16 REPRESENT WELL 1E-117L2 WITH API#: 50-029-23251-61. THIS WELL REACHED A TOTAL DEPTH (TD) OF 15661'MD/3208'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 RESISTIVITX (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). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, ACAL-DERIVED). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. ACAL = ACOUSTIC CALIPER. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZES: ACAL-DERIVED - 8.5" BIT MUD WEIGHT: 9.0 - 9.1 PPG MUD SALINITY: 41000 - 47000 PPM CHLORIDES FORMATION WATER SALINITY: 6000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/16 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH RPX 5517.0 15615.0 RPS 5517.0 15615.0 RPM 5517.0 15615.0 RPD 5517.0 15615.0 FET 5517.0 15615.0 GR 5524.5 15623.0 ROP 5560.5 15661.0 NCNT 9509.5 15569.0 FCNT 9509.5 15569.0 NPHI 9509.5 15568.5 CALA 9511.5 15572.0 RHOB 9522.5 15582.5 DRHO 9522.5 15582.5 PEF 9522.5 15582.5 • BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD BIT RUN NO MERGE TOP 4 5517.0 13 9391.5 14 9421.0 15 9599.0 16 10980.0 REMARKS: MERGED MAIN PASS. MERGE BASE 9391.0 9421.0 9599.0 10980.0 15661.0 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 Specifica tion Block sub -type...0 Name Service Order Units Size N sam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FONT MWD. CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 CALA MWD INCH 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5517 15661 10589 20289 5517 15661 ROP MWD FT/H 0.02 530.06 175.176 20202 5560.5 15661 GR MWD API 27.74 127.35 68.8548 20198 5524.5 15623 RPX MWD OHMM 1.76 1701.52 36.3442 20197 5517 15615 RPS MWD OHMM 3.06 1234.97 40.2158 20197 5517 15615 RPM MWD OHMM 2.55 1835.59 44.6059 20197 5517 15615 RPD MWD OHMM 4.28 2000 45.239 20197 5517 15615 FET MWD HOUR 0.15 709.93 1.29324 20197 5517 15615 NPHI MWD PU-S 9.134 48.612 38.6806 12119 9509.5 15568.5 FCNT MWD CNTS 635 4348 1080.07 12120 9509.5 15569 NCNT MWD CNTS 120460 226835 152561 12120 9509.5 15569 RHOB MWD G/CM 1.977 4.198 2.14999 10627 9522.5 15582.5 DRHO MWD G/CM -0.067 0.547 0 .0396477 10627 9522.5 15582.5 PEF MWD BARN 1 4.54 1.98354 10627 9522.5 15582.5 CALA MWD INCH 8.84 11.06 9.09755 12122 9511.5 15572 First Reading For Entire File..........5517 Last Reading For Entire File...........15661 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/16 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/16 Maximum Physical Record..65535 File Type ................LO • Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 5517.0 9391.0 RPS 5517.0 9391.0 RPD 5517.0 9391.0 FET 5517.0 9391.0 RPM 5517.0 9391.0 GR 5524.5 9391.0 ROP 5560.5 9391.0 LOG HEADER DATA DATE LOGGED: O1-JUL-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9391.0 TOP LOG INTERVAL (FT) 5560.0 BOTTOM LOG INTERVAL (FT) 9391.0 BIT ROTATING SPEED (RPM) HOLE INCLINATION (DEG MINIMUM ANGLE: 70.6 MAXIMUM ANGLE: 83.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 120558 EWR4 ELECTROMAG. RESIS. 4 67981 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 12.250 5543.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): Water Based 9.30 63.0 9.0 140 4.8 4.000 65.0 2.770 97.0 3.400 65.0 3.000 65.0 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 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5517 9391 7454 7749 5517 9391 ROP MWD040 FT/H 1.15 430.52 201.873 7662 5560.5 9391 GR MWD040 API 27.74 127.35 71.4979 7734 5524.5 9391 RPX MWD040 OHMM 1.76 1345.45 12.1738 7749 5517 9391 RPS MWD040 OHMM 3.06 1234.97 14.0717 7749 5517 9391 RPM MWD040 OHMM 6.41 1835.59 16.2879 7749 5517 9391 RPD MWD040 OHMM 4.99 2000 20.2857 7749 5517 9391 FET MWD040 HOUR 0.15 89.37 1.43885 7749 5517 9391 First Reading For Entire File..........5517 Last Reading For Entire File...........9391 File Trailer Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/16 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.......05/11/16 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 13 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 9391.5 9421.0 LOG HEADER DATA DATE LOGGED: 29-JUL-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9421.0 TOP LOG INTERVAL (FT) 9391.0 BOTTOM LOG INTERVAL (FT) 9421.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASING DEPTH (FT) .0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) .00 MUD VISCOSITY (S) •0 MUD PH: •0 MUD CHLORIDES (PPM): 0 FLUID LOSS (C3) •0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 .0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .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 . ~ • ROP MWD130 FT/H 4 1 68 4 2 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9391.5 9421 9406.25 60 9391.5 9421 ROP MWD130 FT/H 0.44 122.97 22.06 60 9391.5 9421 First Reading For Entire File..........9391.5 Last Reading For Entire File...........9421 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/16 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/16 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.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: 14 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 9391.5 9549.5 RPM 9391.5 9549.5 RPS 9391.5 9549.5 RPX 9391.5 9549.5 GR 9391.5 9557.5 FET 9391.5 9549.5 ROP 9421.5 9599.0 LOG HEADER DATA DATE LOGGED: 30-JUL-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9599.0 TOP LOG INTERVAL (FT) 9421.0 BOTTOM LOG INTERVAL (FT) 9599.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 78.1 MAXIMUM ANGLE: 93.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132482 EWR4 ELECTROMAG. RESIS. 4 157645 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order DEPT ROP MWD140 GR MWD140 RPX MWD140 RPS MWD140 RPM MWD140 RPD MWD140 FET MWD140 • 8.500 9391.0 Oil Based 9.00 87.0 .0 47000 .0 .000 .0 .000 86.0 .000 .0 .000 .0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 OHMM 4 1 68 20 6 OHMM 4 1 68 24 7 HOUR 4 1 68 28 8 Name Service Unit Min Max Mean Nsam DEPT FT 9391.5 9599 9495.25 416 ROP MWD140 FT/H 2.08 249.02 134.473 356 GR MWD140 API 58.11 86.48 69.9102 333 RPX MWD140 OHMM 5.47 1701.52 50.5498 317 RPS MWD140 OHMM 7.46 79.9 37.3185 317 RPM MWD140 OHMM 2.55 93.44 35.782 317 RPD MWD140 OHMM 4.28 2000 77.9653 317 First Reading 9391.5 9421.5 9391.5 9391.5 9391.5 9391.5 9391.5 Last Reading 9599 9599 9557.5 9549.5 9549.5 9549.5 9549.5 • FET MWD140 HOUR 0.35 709.93 12.2099 317 9391.5 9549.5 First Reading For Entire File..........9391.5 Last Reading For Entire File...........9599 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/16 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.......05/11/16 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: 15 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START. DEPTH STOP DEPTH NPHI 9509.5 10980.0 FCNT 9509.5 10980.0 NCNT 9509.5 10980.0 CALA 9511.5 10980.0 RHOB 9522.5 10980.0 DRHO 9522.5 10980.0 PEF 9522.5 10980.0 RPX 9550.0 10980.0 RPS 9550.0 10980.0 RPM 9550.0 10980.0 RPD 9550.0 10980.0 FET 9550.0 10980.0 GR 9558.0 10980.0 ROP 9599.5 10980.0 LOG HEADER DATA DATE LOGGED: 01-AUG-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 10980.0 TOP LOG INTERVAL (FT) 9599.0 BOTTOM LOG INTERVAL (FT) 10980.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 89.4 MAXIMUM ANGLE: 92.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 163686 EWR4 ELECTROMAG. RESIS. 4 134760 CTN COMP THERMAL NEUTRON 105918 ASLD Azimuthal Litho-Den 143795 ACAL Acoustic Caliper 143795 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 8.500 DRILLER'S CASING DEPTH (FT) 9391.0 BOREHOLE CONDITIONS MUD TYPE: Oil Based MUD DENSITY (LB/G) 9.10 MUD VISCOSITY (S): 70.0 MUD PH: .0 MUD CHLORIDES (PPM): 43000 FLUID LOSS (C3) .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 138.2 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .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 .1IN 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 ROP MWD150 FT/H 4 1 68 4 2 GR MWD150 API 4 1 68 8 3 RPX MWD150 OHMM 4 1 68 12 4 RPS MWD150 OHMM 4 1 68 16 5 RPM MWD150 OHMM 4 1 68 20 6 RPD MWD150 OHMM 4 1 68 24 7 FET MWD150 HOUR 4 1 68 28 8 NPHI MWD150 PU-S 4 1 68 32 9 FCNT MWD150 CNTS 4 1 68 36 10 NCNT MWD150 CNTS 4 1 68 40 11 RHOB MWD150 G/CM 4 1 68 44 12 DRHO MWD150 G/CM 4 1 68 48 13 PEF MWD150 G/CM 4 1 68 52 14 GALA MWD150 INCH 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9509.5 10980 10244.8 2942 9509.5 10980 ROP MWD150 FT/H 0.02 376.34 157.056 2762 9599.5 10980 GR MWD150 API 51.76 88.72 70.4487 2845 9558 10980 RPX MWD150 OHMM 21.86 70.61 41.8438 2861 9550 10980 RPS MWD150 OHMM 24.86 76.91 46.7506 2861 9550 10980 RPM MWD150 OHMM 29.84 78.48 50.7383 2861 9550 10980 RPD MWD150 OHMM 32.44 76.7 49.6881 2861 9550 10980 FET MWD150 HOUR 0.21 20.42 1.66754 2861 9550 10980 NPHI MWD150 PU-S 9.134 48.612 34.9428 2942 9509.5 10980 FCNT MWD150 CNTS 635 4348 1176.46 2942 9509.5 10980 NCNT MWD150 CNTS 120460 226835 153266 2942 9509.5 10980 RHOB MWD150 G/CM 2.032 4.198 2.26061 1422 9522.5 10980 DRHO MWD150 G/CM -0.056 0.547 0.0498094 1422 9522.5 10980 PEF MWD150 G/CM 1.5 4.39 2.35499 1422 9522.5 10980 CALA MWD150 INCH 8.84 11.06 9.22784 2938 9511.5 10980 First Reading For Entire File..........9509.5 Last Reading For Entire File...........10980 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/16 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/16 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 16 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NPHI 10889.5 15569.0 FCNT 10889.5 15569.0 NCNT 10889.5 15569.0 RPM 10980.5 15615.0 CALA 10980.5 15572.0 GR 10980.5 15623.0 RPS 10980.5 15615.0 ROP 10980.5 15661.0 RPD 10980.5 15615.0 FET 10980.5 15615.0 RHOB 10980.5 15582.5 DRHO 10980.5 15582.5 • PEF 10980.5 RPX 10980.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BTT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 15582.5 15615.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON ASLD Azimuthal Litho-Den ACAL Acoustic Caliper BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 04-AUG-05 Insite 66.37 Memory 15661.0 10980.0 15661.0 90.3 92.1 TOOL NUMBER 163686 134760 105918 143795 143795 8.500 9391.0 Oil Based 9.00 83.0 .0 43000 .0 .000 .0 .000 147.4 .000 .0 .000 .0 Name Service Order Units Size Nsam Rep Code Offset Channel • • DEPT FT 4 1 68 0 1 ROP MWD160 FT/H 4 1 68 4 2 GR MWD160 API 4 1 68 8 3 RPX MWD160 OHMM 4 1 68 12 4 RP5 MWD160 OHMM 4 1 68 16 5 RPM MWD160 OHMM 4 1 68 20 6 RPD MWD160 OHMM 4 1 68 24 7 FET MWD160 HOUR 4 1 68 28 8 NPHI MWD160 PU-S 4 1 68 32 9 FCNT MWD160 CNTS 4 1 68 36 10 NCNT MWD160 CNTS 4 1 68 40 11 RHOB MWD160 G/CM 4 1 68 44 12 DRHO MWD160 G/CM 4 1 68 48 13 PEF MWD160 BARN 4 1 68 52 14 CALA MWD160 INCH 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10889.5 15661 13275.3 9544 10889.5 15661 ROP MWD160 FT/H 0.14 530.06 161.201 9362 10980.5 15661 GR MWD160 API 45.25 89.16 66.1274 9286 10980.5 15623 RPX MWD160 OHMM 20.19 111.5 54.3657 9270 10980.5 15615 RPS MWD160 OHMM 21.73 84.64 60.1525 9270 10980.5 15615 RPM MWD160 OHMM 25.7 517.81 66.6867 9270 10980.5 15615 RPD MWD160 OHMM 30.47 930.26 63.6058 9270 10980.5 15615 FET MWD160 HOUR 0.21 14.25 0.6827 9270 10980.5 15615 NPHI MWD160 PU-S 10.9 45.49 39.7345 9360 10889.5 15569 FCNT MWD160 CNTS 863 4242 1056.6 9360 10889.5 15569 NCNT MWD160 CNTS 140797 225093 152523 9360 10889.5 15569 RHOB MWD160 G/CM 1.977 2.735 2.1329 9205 10980.5 15582.5 DRHO MWD160 G/CM -0.067 0.314 0.0380779 9205 10980.5 15582.5 PEF MWD160 BARN 1 4.54 1.92616 9205 10980.5 15582.5 CALA MWD160 INCH 8.87 11.06 9.05587 9184 10980.5 15572 First Reading For Entire File..........10889.5 Last Reading For Entire File...........15661 File Trailer Service name .............STSLIB.006 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......05/11/16 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.007 Physical EOF Tape Trailer Service name .............LISTPE Date .....................05/11/16 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library Reel Trailer Scientific Technical Services Service name .............LISTPE Date .....................05/11/16 Origin ...................STS Reel Name ................UNKNOWN ~• • Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File