Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
203-054
ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Date: May 29, 2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W. 7th Ave Suite 100 Anchorage, AK 99501 COP reviewed cement evaluation activities for wells in response to AOGCC Industry Guidance Bulletin 25-001. There was no indication of cement evaluation logs being run for the following wells based on a review of all drilling files associated with well construction. Kuparuk River Unit/Field Well API #PTD #Comments 3G-13A 50103201370100 222-106 No cement bond logs run 2N-303A 50103203520100 214-088 No cement bond log run 2E-04 50029235050000 213-168 No cement bond log run TARN 2N-323A 50103202580100 213-159 No cement bond log run 1C-19 50029231490000 203-054 No cement bond log run By Gavin Gluyas at 9:48 am, Jun 02, 2025 1C-19 50029231490000 203-054 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Colville River Unit/Field Well API # PTD # Comments CD3-303 50103205680000 208-013 No cement bond log run ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Greater Mooses Tooth Unit/Field Well API # PTD # Comments MT6-06 50103207730000 218-093 Production well, CBL was not run across 7” liner SII. ProActive Diagnostic Services, Inc. WELL LOG TRANSM/TTAL To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : 1) Caliper Report 2) Signed Print Name: 203054 30 95 3 READ Cased Hole, Inc. RECEIVED Attn: Diane Williams 130 West International Airport Road Suite C JUL 0 5 2019 Anchorage, AK 99518 AOGCC Dianw. Will iams(r@readcasedhole.com 12 -Jun -19 1C-19 CD 4-t i&f(a4-- 50-029-23149-00 Date: 0009 PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 fax: (907)245-8952 E-MAIL: PDSANCHORAGEAMEMORYLOG.COM WEBSITE: WWW.MEMORYLOG.COM hnps://readcawdhole-my. sharepoint.w"personal/diane williams_readcasedhole commaeaaneuts/D Drive?empCaliper/1R- 35/CPM Kup_Caliper TempleWCD_Panaa2onocoPhdlips_Transmicdocx 203054 30 95 3 _= CASED Memory Multi -Finger Caliper HOLE Log Results Summary Company: Log Date: Log No.: Run No.: Pipe Description: Pipe Use: Pipe Description: ConocoPhillips Alaska, Inc. June 12, 2019 14387 2 3.5 inch 9.3 Ib. L-80 EUE-8RD Tubing 7 inch 26 Ib. L-80 BTCM Production Casinq Well: Field: State: API No. Top Log Interval: Bottom Log Interval: Top Log Interval: Inspection Type : Pre -Whipstock Setting Location Inspection COMMENTS: 1c-19 Kuparuk Alaska 50-029-23149-00 9,894 Ft. (MD) 10,068 Ft. (MD) 10,068 Ft. (MD) 10,159 Ft. (MD) This caliper data is correlated to the K7 gamma ray signature at 9,952 feet per the attached PDC Log. This log was run to assess the condition of the production casing from as deep as possible to help determine the ideal whipstock setting location prior to CTD operations. Two caliper passes were made over the intended interval from as deep as possible. The caliper recordings indicate no significant damage or I.D. restrictions to the 3.5 inch tubing and 7 inch production casing logged. Perforations were recorded from -10,153 feet to 10,159 feet (end of log) in both caliper passes. 3-D log plots of both caliper passes over the interval logged are included in this report. This is the second time a READ caliper has been run in this well and the 3.5 inch tubing and 7 inch casing has been logged. Due to the purpose of this log and short duration between the current and previous log (June 3, 2019), no comparison graph is included in this report. C. Geordt C. Waldrop J. Condio `'Id V t,ji", "I- READ Cased Hole Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: ANSA-NorthAmerica(alreadcasedhole com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 I Perforations 5 v Perforations ConocoPhillips Alaska, Inc. Drilling & Wells ConocoPhillips Coiled TubingDrillingAaska Page 4 of 4 '' KALW-V _ s55o i i 1002$ I SO050 I ' 10100 '., 10150 — .--', _ I 10175 ''. •-_-�. i _— 6500 - —L— 10100 -- KUF Pa j 6626 May 10, 2019 1C-19 Pre -CTD Procedure Page 4 of 4 KUP PROD IC -19 COtIOCOPI11II1ps Well Attributes Max Angle &MD TD '. Fkltl Nama We1Wwe APbu- WNIbme Statue Llel (') MDfflKBI Ad B1m(KKB) AOLskB, Inc. KUPARUK RIVER UNIT 500292314900 PROD fi0.17 5,856,23 10,435.0 InEat H291ppmj oafa MioWNm Enbiab KBGNIm 9.p ab,, -Dab NIPPLE 60 9/4/201] 9/2]/2013 3470 5/132003 tC19, A31rz0101Y39: C6PM Last Tag Vanktl xMmelb(sluap EMDab etob at _ Leet Moe By RKB 9/1X!017 10,18].0 .- pproven Last Rev Reason MNG5Ra9- MnMatlmi EMDab .Ise! mW By RSVReasoh. H25 7f302018 PP10ven Casing Strings IfF crllq D.bbion oDIMi IDOm TaptttK81 salDmlx lreKB1 seL Degn (M)-WbLen IL.. Gmee Top Tbr� CONDUCTOR 1fi 15.08 29.D 138.0 138.0 62.50 H40 WELDED Crmp Davulgbn DDllnl IOIMI TePINKaI 3n De vInuel stl Daps frvDl... WYLm p... Orad TOPThrem SURFACE 958 8,83 281 6.7".7 4,4]4.1 CM L80 BTCM Cri,I).i ran Op (in) ID Ib) TopftN(BI Se[DpIn 1flKB) Se[Dega (ND).. WtILan 11.. G1etle TopT. PRODUCTION ) 626 26.0 10A2>51 6.]885 260 1:80 BTCM I ODing Strings comouaioR;mnlaq.o tubba Oeanlpbon snNp ma !Olin! top mMel sal lMpM l/[.. sr vepm lrw)I... Vri llDrq Gratle Te Cwulactlml TUBING wO 31/2 2.99 22.9 tQ029.5 6,450.5 9.30 L-80 EU68rG Compladon Detags NIPPLE: 509.3 Top ITVDI Topinal Nominal rap (ftNBI (ftK01 (°) Item Dee C. 10 (In 9 229 000HANGER LNIV lut.-L 1-1, I 2.990 bwz 50921078 NIPPLE 2876 2.875 10,016Z ,4 1 IOCA ''OR 7990 10,017.6 6,4408 346] SEAL ASSY BAKER BO -40 SEAL ASSv 2.990 Tubing Desctlptian -9 Ma... lDllnl TapfRKBI Get OzpM lfL,. sel Depin lTVp)4.. W11A'al Greee Tw GanraBw TUBING OriOinal 59 30U 111121] 1015)9 6/1822 GMLIFr,3154 CO1EIpletlen Detag6 TPP (ND) "W"',Nanliul TW MKBI Mine) 1') Item Des cam ID pm 1Q,021. (I,443.83166 PBR BAKER R/SBR" W40 PBTUBING STRIN NAS 080 OF THE 3100 PBR- 6.45581.3ul PA KER BAKER SAH-„ PERMANENT PACKER W/ MILL OUT MEN 1 ,] 103.7V Ws LET; 6.014.7-- 6415] n91 NIPPLE CAM❑NIPPLE W IQ GO 275 PR FBF 2750 I 0.06]0 61815 ✓120 WLEC BAKERP/1RELOIE ENTRY VIDE 3.000 Perforations&Slots snd GURFAOF;PB."7",7 -� iW MKBI 10,150.0 B!MKB) 10,180.0 TaPmOI B1m lrv0) (KKBi IreKBI Lin..ne Deb &182003 obq t 1 4.0 T. 1PERF cam GA9 LET,.1aA Frac Summary stvLDeN 1MQW3 Propped Orler4 (el G00,300.0ro3W.0 Gormatbn pp SIgY SYM1Oete TW50.0 IKKBI B[m8001 LMbFIOM ""Vd i 1002003 10,150.0 10,180.0 <lypt>, HSiidilatlro>- Ckan (pAI Vd 9Iy1ry (bdl GA9 LIR;9,]190 9brIDaN -PRit D 1.116) Plappalrtln Grmalbnllm LIM017 200,000.0 200,283.0 Sipa 9ert0ale TW Depm laKB) BIm IkKB) Iintb Gluts 6Ydem Vd"'75' A VPI SlutrylbbD 1 9'102017 10,150.0 10,180.0 Gdletl Selt Wales HyborG 2)66.00 2,8]2.00 Mandrel Inserts sL mi GAS L1Fi', B.eA.e Tep ITV01 191Va ta[d pxl3ly TRORun N TOP(N(B) MKBI Make Maeel ODlln) Sw TyRe Type IIN (pGl) a - M, Cem 1 .595./ A MM 112 GAS LIFT LV RK 0. i, 9/1 ] 4107 CAMCO MM OD .fi 1911=7 3 .5, 01.1 C CO MMG 1 / A LIFT DMY RK 0 0. J 13 41 9.,U9 01 51121 CAMCO M 1112 G LIFT DMV RK 0. 0. 827 1.0.11; 1o.ome 51 9.955qj 63 9 MM 11/ ASLIET IDMy IRK 1 0.0001 C0 IW/2017 Notes: General & Safety 6FALA9GY, to 011.5 Em Deb Anmialion PSR; 10,0213 /11 N TE'. View Scnemmicre Alaska ema5C90 PACKER: 10.035.9 NIPPLE; 10c59.9 WIEG; 10.wo FMC 10100 PERF: m,150.01o, 1., ,",uACFran" 10,i50o I. PR0OUMi0NM0-10,4U)7- H"'"uLA V r ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS JUL 'i. Operations AbandorE] Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redril❑ erforale New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: WHIPSTOCK❑ 2. Operator 4. Well Class Before Work: Name: ConocoPhillips Alaska, Inc. 5. Permit to Drill Number: Development ❑ Exploratory ❑ 203-054 3. Address: P. O. BOX 100360, Anchorage, Alaska Slratigraphic❑ Service ❑ 6. API Number: 99510 50-029-23149-00-00 7. Property Designation (Lease Num S. Well Name and Number: AD L 25649, ADL 28242 KRU 1C-19 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): I N/A Kuparuk River Field / Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 10,435 feet Plugs measured None feet true vertical 6,794 feet Junk measured None feet Effective Depth measured 10,345 feet Packer measured 10,036 feet true vertical 6,717 feet true vertical 6,456 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 109 feet 16 P 138' MD 138' TVD SURFACE 6,717 feet 9 5/8 " 6,745' MD 4474' TVD PRODUCTION 10,403 feet 7 10,429' MD 6789' TVD Perforation depth: Measured depth: 10150-10180 10152-14619 feet True Vertical depth: 6551-6576. 6552-10392 feet Tubing (size, grade, measured and true vertical depth) 3.5 " L-80 10,068' MD 6,482' TVD Packers and SSSV (type, measured and true vertical depth) PACKER • BAKER SA&3 PERMANENT PACKER 10,036' MD 6,456' TVD SSSV•NONE 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 -Bbl Casing Pressure Tubing Pressure Prior to well operation: 469 609 1855 1127 1 311 Subsequent to operation: 818 289 1759 1374 1 318 14. Attachments (required per 20 AAC 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations 171 Exploratory ❑ Development p Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil O Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ 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: Authorized Name: James Ohlin er Contact Name: Shane Germann Sir Authorized Title: Staff CTD Engineer Contact Email: Shane.germann@cop.com Authodzed Si nature: G Contact Phone: 907 263-4597 Date: � ;� �7 V71 714111 Form 10-404 Revised 4/2017XI-f Le[71pBY7JL.6V. UL 31209 Submit Original Only KUP PROD WELLNAME 1C-19 WELLBORE iC_19 Ir -r' Well Attributes Max Angle & MD TD -A, C(�(�(�w onoco• "I'I)i_ • Alaska. IrtG. F&IE Name We11WeAP W Wellbxe3 bs KUPARUK RIVER UNIT 500292314900 PROD 11 V) M.0ps. S IDs.) .17 5,856.23 10.435.0 Comment Xi wins' 40 Dafe Annotallon Erp Dab nBGN(n) Rp Release Ba@ 914201) La61W0: 912]2013 34]0 51132003 1C-19, T/HN1913H®PM Last Tag Vmbl .(.) I %Arews, I EM Bab Wellao,s laslMM By Last Tag: RKB 10,16)0 6182019 1C-19 zelnbael Last Rev Reason .............iw.icefifue..- ..... gnnWaxon EnE Oah Well[nre lnsl MOE ey -R"-P.-.-.TAGUNKNOWN OBSTRUCTION IN CA61NU WITH ELINE 6112/2019 1C-19 cgn.ijw CALIPER Cuing Strings C..pRDesp1ftn Pipe t.0p) TOP 11x(8) sa B.plb (Itl(B) Sel Depm lNB)_. mr-en(I Grace Top TM1reaJ CONDUCTOR 15.06 290 138.0 138.0 62.50 HAD WELDED Galnp Bewxplim, OD(In) IB inl iap lnRB) %fOpN PInBI Set BepN INO).. YMLen ll... GraOe Top TM1real SURFACE 9518 883 28.0 6,]04-7 4,0]4.1 d0.00 LA0 BTCM Casing DecrlpbnOD(s) IG,, Tep1MtB1 ,A,a,IBIMtB1 %I Bepm(NDI... WYLen g...GMe Top TM1reetl PRODUCTION 7 628 26.0 10.428.7 6.788.6 26.00 LA0 BTCM Tubing Strings coxD.croR: �..+9a.9 Tubing Desarbron siring Me_. m-nI Top WE) $Bl Depm(n_Sei D;s Ir Mo11...wf Dbm) 080, IT GonneaI TUBING wO 3112 2.99 22.9 10,0295 6d50.5 9.30 L-80 EUE-Ertl Completion Details RSPLE NNID roplrvD) ropma Nominal .PD1.) Inn.) 1'1 Ibm.es Com iD lbl 2.9 2291 0.00 1 HANGER JUEN IV TUBING HANGER 2.990 .2 509.2 O-78 NIPPLE 2.075"OE"NIPPLE 2.875 10016. 6,440.1 34.fi8 LOCAT R BAKER LOCATOR 2990 GAs uFT:9199a 10.017.6 6,4408 34.6] SEAL ABY BAKER 80405EAL ASSY 2990 Tables DnC,iptlon 51xrq Me jig (in) Top MR) bel Cepb(R-I. Dep, Irs.)L_W( QMn) Orale IT., ComwCWn TUBING Original 5.9 300 10021.3 10,067.9 6,482.2 Completion Details OAS UFi:eBIaT Toplfln.l TOP 11Vol TOPmcl Nominal DKe) (°) Item Des coin ID On) 10,0213 6,4438 M66 PER BAK 8040 PBRI B -TUBING STRING HAS DIID OF THE 3.000 PBR- 10,0359 6,455.8 3452 PACKER BAK SAB -3 PERMANENT PAKE w/MILLOUI NSION 3.710 10371- 0371"10,0599 10,0599 6,475.7 34. J NIPPLE CAMCO D NIPPLE WIN0 G027YPROFILE '°°°°°'MIL ED 2.800 OUT TO 2.80'"°°"""" 10,067.0 6,481.5 3420 WLEG BAKER WIRELINE ENTRY GUIDE 3000 SURFACE:'I9.M744 T� Other In Hole (IMreline retrievable plugs, valves, pumps, fish, etc.) rap a rep Top(n1t81 InKB) 19mu Bea coin Run oah IOIIn) GAS UFT: epX.a 10,1430 ,544] J3.OJ Whipstock N.B. High expansion whipstock 6212019 10,1635 6,5619 32.61 UNKN[UNKNOWN RES TFICTION, NOTABLE TODRIFT 6112/2019 2000 RESTRICTION PAST Gni MFr ir.AD Perforation B Slots snot Den ,A Me) a. (nigh, Tolrvo)lrvD) p I, M(BI LinYM Zone Date Una:m 1 TV. CAN 10,1500 10,1800 6,550.6 6,5758 U-1 IC -19 6118200] 40 (PERF .5"H PF HYPERJET, 4 SPF res uFT: e,9ses POWERJET 10,152.0 14,819.0 6.55.2 C-0, 1C-19 J.LDI SkYW COMpbtlDD Frac Summary Ppap,ganst In 1101 SlMpab PmPWnIDKWe. (ib) 21W,3000 Formatbn 017200] LO(:nTORi 10.0186 6F .BY loon. ft. litter Gb Tap OepM MR) BM IIIKBI LAY b Field System VPIC.n(-) V',rateryibbg 1 1022003 10150.0 10,180.0 <typj" fluidnanne> Sts"Pageproppent0esgnel116) PlOppnlln Fwmatlan 1101 9/10201] 200.000.0 200,283.0 PBR. 10.M19 PACKER: f0.01.9 gmt 1 op dpIM1M 1D Brn MKB) r-M.FARISysMn Vol Oban 1001) VOI Slurty laM) Sbn Dab 111'0`1 911012017 10,1500 10.180.0 Gelled Ball Water, HyW G 2,766.OD 2972.00 Mandrel Inserts eaa NIPPLE: 10,099 H Top(NDI VeWa IebM1 Pon She iRO Run Top MaB) M E) Make Mattel OD pnl %1v Type Type IA1 IPai) --rDah .em 3,133.4 2,5957 CAMCO MMD 112 GUr LIFT GLV RN 0.188 1,233.0 911312017 WLEG:10,Ag 2 6,014.7 4,1027 CAMGO MMG 112 GAkUFT OV RK 0.250 00 911312017 3 81266 52073 AMCO MMG 112 LIFT DMY RK 0000 00 912712013 Is a CTD SYbb.av 1005Dbf!sn.o 4 9,3190 5912.1 CAMCO MMG 112 AS LIFT DMY RK 0000 0.0 91212013 5 9,956.9 6390.9 CAMCO MMG 1112 GAS LIfT DMY RK O.ODO 0.0 9172017 Notes: General & Safety wnymmox; lB,1aG Ga Dale I AnnWNlon 111112011 NOTE: View Schematic .1 Alaska Schem01119.0 UNKNONN RE6TRICTION: m,fm0 IPERF:1BISS 61 IRAG:10 SSir C XyCIGIra4L FracW,e: 10.1 W.0 PRODUCTION:96h10.49B1- 6LOTS: tO,iR.614,Ta0 ic-19 WHIPSTOCK DTTMSTJOBTYP SUMMARYOPS 6/21/19 DRILLING Completed Rig Move to 1 C -pad, removed jeeps, prepped well for rig, spotted SIDETRACK in to well 19, secured all stairs and landings, RU PUTZ, spoted Kill Tank, RU hardline, hooked up ground strap, nippled up the BOPE, serviced the wellhead, choke manifold, and well control valves, performed shell test, performed Initial BOPE test, test witnessed by AOGCC (Bixby), one fail/pass (1318), P/T Inner Reel Valve and Pac-off, P/T Kill tank line, and PDL's, PU/MU/PD NS High Expansion Wedge w/pip tags installed, RIH, log formation for depth control minus 17.5', continue IH 6/22/19 DRILLING Set whipstok at 10,143', 0° orientation, attempt to displace well to SW with SIDETRACK 50% losses. PUD setting tool, MU/PD window milling BHA, log formation made -17.5' correction. Mix and pump 2x 50 bbl super hi vis pills (100 LSRV), attempt to turn well over to milling fluid, unable to to get returns above 0.8 bpm, Dry tag TOW at 10144'. Closed choke and mill window exit, (note: High Level Vibrations 5) back ream 300 Right and Left of HS, and 1800, dry drift clean, POOH, PUD setting tools, changeout pac-offs, PD Build assembly with 1.90 ako motor, RIH, log formation for depth control (-17.0') 6/23/19 DRILLING Drilled build section from 10,173' to 10,236' on losses. Openned choke, SIDETRACK established returns, 3 tenths losses. Finshed build to 10,326'. POOH, PUD L1 Build BHA, MU/Deploy L1 Let assembly w/ 0.6° ako motor, log formation, - 9.5' correction. Drill L1 Lat from 10,327' to 10,405', new mud at the bit, continued drilling ahead to 10,727', pulled a 400' wiper, drilled ahead from 10,727' to 11,091', pulled wiper up into the casing chasing 5x5 sweeps x 2, jogged the 7" x 2, logged the RA marker for depth control (+1.5'), drilled ahead from 11,091' to 11,392'- *Note losses 15-17 bph 6/24/19 DRILLING Drilled ahead from 11,392' to 11,490', 800' wiper up hole to 10,690', RBIH SIDETRACK and drilled ahead from 11,490' to 11,890', wiper to the window w/sweeps, jogged the 7inch x2, logged RA marker for depth control, RBIH, drilled ahead from 11,890' to 12,229', with low ROP, pulled GEO wiper up to 11,229', RBIH rotated TF high side, broke through hard spot contiinued drillig ahead from 12,433'-12,610', wiper up to the window w/sweeps, jogged the 7inch x2, logged the RA marker for depth control, RBIH, drilled ahead from 12,610'- 12,824' cii S-11- ProActive Diagnostic Services, Inc. WELL LO7((a TRAN5M/7TAL To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : 1) Caliper Rel 2) Signed Print Name: 203054 30 95 1 READ Cased Hole, Inc. RECEIVED Attn: Diane Williams JUL 0 3 1019 130 West International Airport Road Suite n OGCC Anchorage, AK 99518 /-1 V l.i Diane. W ill iams(cDreadcased ho le.com 50-029-23149-00 Date: UIJG l j PROACTIVE DIAGNOSTIC SERVICES, INC., 130W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-8952 E-MAIL: PDSANCHORAGEAMEMORYLOG COM WEBSITE: WWW.MEMORYLOO.COM https:/head,as lholamy.ehmepomt. m/pmom ''dimm-wiai=s readeasedlmle eoMDoco tvDesktop/Cmocoplsillipsh md.doex L 109 pi3o 203054 30 95 1 Memory Multi -Finger Caliper Log Results Summary Company: Conoco Phillips Alaska, Inc. Well: 1C-19 Log Date: June 3, 2019 Field: Kuparuk Log No.: 15688 State: Alaska Run No.: 1 API No. 50-029-23149-00 Pipe Description: 3.5 inch 9.3 Ib. L-80 EUE-8RD Top Log Interval: Surface Pipe Use: Tubing Bottom Log Interval: 10,068 Ft. (MD) Pipe Description: 7 inch 26 Ib. L-80 BTCM Top Log Interval: 10,068 Ft. (MD) Pipe Use: Production Casing Bottom Log Interval: 10,141 Ft. (MD) Inspection Type: Corrosive and Mechanical Damage Inspection COMMENTS: This caliper data is correlated to the K1 gamma ray signature at 9,952 feet per the attached PDC Log. This log was run to assess the condition of the tubing and casing with respect to internal corrosive and mechanical damage prior to CTD operations. The caliper recordings indicate the 3.5 inch tubing appears to be in good condition, with no significant wall penetrations, areas of cross-sectional wall loss or I.D. restrictions recorded. The caliper recordings indicate the 7 inch casing logged appears to be in good condition, with no significant wall penetrations, areas of cross-sectional wall loss or I.D. restrictions recorded. 3.5 INCH TUBING - MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 17%) are recorded. 3.5 INCH TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 6%) are recorded. 3.5 INCH TUBING - MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded. 7 INCH CASING - MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 17%) are recorded throughout the casing logged. 7 INCH CASING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 6%) are recorded throughout the casing logged. 7 INCH CASING - MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the casing logged. B. Suhanek C. Waldrop E. Zemba ProActive Diagnostic Services, Inc. / P.O. Bo:.; 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: PDSAnalysisgmemorvloo com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 Correlation of Recorded Damage to Borehole Profile Pipe 1 3.5 in (-14.3'- 10,069.7) Well: 1C-19 Pipe 2 7. in (10,0697- 10,141.1') Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: June 3, 2019 . Approx. Tool Deviation ■ Approx. Borehole Profile 1 -10 50 1,532 GLM 1 3,069 150 4,636 E � GLM 2 200 6,211 a o m 250 7,749 GLM 3 GLM 4 9,344 GLM 5 1 3 10,070 10,134 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) Bottom of Survey = 3 14PDS Report Overview Body Region Analysis Well: 1C-19 Survey Date: June 3, 2019 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 10011398 Company: ConocoPhillips Alaska Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pipe 3.5 in. 9.3 ppf L-80 EUE-8RD Analyst: Waldrop Pipe Nom.OD Weight Grade &Thread Nom.ID Top Depth Bottom Depth 3.5 in. 9.3 ppf L-80 EUE-8RD 2.992 in -14 ft 10 068 ft Damage Configuration (body) 10 8 6 4 2 0 Isolated General Line Other Hole/ Pining Corrosion Corrosion Damage Pos. Hole Number of joints damagpd ftntA = 12) 5 0 7 0 0 Damage Profile (% wall) Penetration body 1111110111 Metal loss body 0 50 100 GLM 1 (10:00) GLM 2 (2:00) GLM 3 (12:00) GLM 4 (5:00) GLM 5 (2:00) Bottom of Survey = 320.9 j ps- Well: i C-19 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. PDS Report Joint Tabulation Survey Date: June 3, 2019 Analyst: Waldrop Sheet Pipe Description 3.5 in. 9.3 ppf L-80 EUE-8RD Tubing Nom. ID Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. -14 ft. 10,068 ft. JointkDepth No.Upset Pen. (in.) Pen. Body (i n.) Pen. % Metal Loss % Min. I.D. (i n.) Comments Damage Profile (%wall) 0 50 100 0.1 0 0.02 9 5 .90 Pu Lt. e i1 0 0. 2 8 2 94 1.10 0.02 9 2 2.94 Pu1.20 0.0 15 6 4 u 5 allow Line of 0 0.02 9 2 2.93 Lt. Derposits. 3 62 0 0.02 9 2 2.95 0.03 2. L De osit . 5g216 0 .0 9 4 2.9 ts. 6 0 0.02 8 2 2.93 0 0. 2 2.9 8 0 0.02 8 2 2.94 9 0 3 2.94 1 0 0.02 9 4 2.93 L. De11 0 0.02 8 2 2.94 0 0-02 9 2 2.93 Lt. DeDosits. 13 370 0 0.02 8 2 2.94 14 401 0 0.02 9 2 2.95 15 432 0 0.02 7 2 2.94 15.1 463 0 0.02 9 1 2 2.92 Pun Lt. Deposits. 15.2 473 0 0 0 1 0 2.86 2.875' DB NIPPLE 15.3 474 0 0.02 8 2 2.92 Pup Lt. Deposits. 6 485 0 0.02 7 2 2 Lt. Deposits. 17 515 0 0.02 9 2 2.93 18 546 0 0.02 9 2 294 19 1 577 0 0.03 10 3 2.94 20 608 0 0.02 9 2 2.91 Lt. Deposits. 21 639 0 0.02 9 3 2.92. Lt. Deposits. 22 1 670 1 0 0.02 7 2 2.93 23 1 701 1 0 0.02 9 2 2.93 24 731 0 0.02 9 2 2.94 25 761 0 0.02 8 2 2.93 Lt. Deposits. 26 792 0 0.02 9 1 2 2,93 Lt. Denosits. 27 823 0 0.02 8 1 2 2.94 28 854 0 0.02 7 1 2.93 Lt. Deposits. 29 885 0 0.02 7 2 2.93 Lt. Deposits. 30 916 0 0.02 8 2 2.92 1 -t -Deposits. 31 947 0 0.03 10 1 3 1 2.94 2 977 0 0.03 11 2 2.93 33 1 10089 2 2.93 Lt, Devo its. 34 1039 0 0.02 8 2 2.93 35 1070 0 0.02 8 2 2,93 L. Deposits. 36 1101 0 0.02 a 2 2.92 1 Lt. De osits. 37 1131 0 0.02 6 2 2.93 Lt. Deposits. 38 1162 0 0.02 9 2 2.93 39 1193 0 0.02 9 2 2.93 Lt. Deposits. 40 1224 0 0.02 8 3 2.93 Lt. Deposits. 41 1255 0.0 8 4 2.93 ri 42 1286 0 0.02 7 2 2.94 43 1 1316 0 1 0.02 1 7 1 2 2.93 Lt. Deposits. 44 1347 0 1 0.02 1 9 1 2 2.92 Lt. Deposits. Penetration Body Metal Loss Body Page 1 ji-4s, PDS Report Joint Tabulation Sheet Well: 1 C-19 Survey Date: June 3, 2019 Field: Kuparuk Analyst: Waldrop Company: ConocoPhillips Alaska, Inc. Pipe Docrip bon 3.5 in. 9.3 ppf L-80 EUE-8RD Tubing Nom. ID Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. -14 ft. 10,068 ft. Joint No. )t Depth (Ft.) Pen. Upset (i n.) Pen. Body (in.) Pen. % Metal Loss % Min. Damage Profile I.D. Comments (% wall) (i n.) 0 50 100 45 1378 0 0.03 10 2 2.93 Lt. Deposits. 46 1409 0 0,02 7 3 2.93 47 1440 0 0.02 7 2 2.94 48 1471 0 0.02 7 2 2.93 9 1501 0 0 7 2 2.93 50 1532 0 0.02 7 2 2.93 51 1563 0 0.02 7 2 2.94 52 1594 0 0.02 7 2 2.94 53 1625 0 0.02 7 2 2.93 54 1655 0 0.02 9 3 Z93 Lt. Deposits. 55 1687 0 0.02 6 2 2.94 56 1717 0 0.02 7 2 2.93 57 1747 0 0.02 7 2 2.94 58 1778 0 0.01 5 2 2.93 59 1809 0 0.01 5 2 2.93 0 1840 1 0 0.01 5 1 2.94 61 1871 0 0.01 5 1 1 2.93 Lt. Deposits. 62 1902 0 0.01 5 1 2.94 63 1933 0 0.02 6 2 2.93 Lt. Deposits. 64 1963 0 0.02 7 3 2.93 Lt. Deposits. 65 1994 0 0.01 5 1 2.93 66 2025 0 0.02 7 2 2.93 Lt. Deposits, 67 2056 0 0.02 6 2 2.93 68 2087 0 0 6 1 2.92 Lt. Denosits. 69 2118 0 1 0.01 5 2 1 2.93 Lt. De osits. 70 2148 0 0.02 7 2 2.93 71 2179 0 0.02 7 2 2.93 72 2210 0 0.02 7 1 2 2.93 Lt. Deposits. 73 241 0 0.02 6 2 i 74 2272 0 0.02 7 2 2.92 Lt. Denosits. 75 2303 0 0.02 7 1 2.91 Lt. Deposits. 76 2334 0 0.02 9 2 2.92 Lt. Denosits. 7 23 4 0 0.02 8 1 2.92 Lt. De sits. 78 2395 0 0.02 7 1 2.92 Lt. De osits. 79 2426 0 1 0.02 8 3 1 2.92 Lt. Deoosits. 80 2457 0 0.02 9 2 2.90 Lt. Dermsits. 81 2488 0 0.02 9 2 2.93 Lt. De osits. 82 2518 0 0.0 2 2.92 Lt. Deposits, 3 2549 0 0.03 10 1 2 2.92 Lt. Deposits. 84 2580 0 0.02 9 1 2 2.92 Lt. Deposits. 85 2609 0 0.02 9 2 2.90 Lt. Deoosits. 6 2640 0 0.03 12 2 2.91 Lt. Denosits. 87 2670 0 0.03 11 2 2.90 Lt. Deposits. 88 2701 0 0.02 9 2 2.91 s. 89 2732 0 0.02 9 2 2.92 Lt. Deposits. 90 2 0 0.02 9 3 i t. Deposits. 1 27 3 0 0.0 8 2 2.92 's 92 2823 0 0.02 9 2 2.92 Lt. Deposits. 93 2 4 8 2 .90 t Deposits. 94 2 85 0 0.02 8 2 2 9 Penetration Body Metal Loss Body Page 2 Ji Well: Field: Company: 1C-19 Kuparuk ConocoPhillips Alaska, Inc. PDS Report Joint Tabulation Survey Date: June 3, 2019 Analyst: Waldrop Sheet Pipe Description 3.5 in. 9.3 ppf L-80 EUE-8RD Tubing Nom. ID Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. -14 ft. 10,068 ft. Joint Jt. Depth No. (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. Metal % Loss % Min. I.D. (in.) Comments Damage Profile (%wall) 0 50 100 95 2916 0 0.03 11 3 2.91 Lt. De sits. 6 2945 0 0.03 10 2 2.92 Lt. Deposits. 97 2976 0 0.02 8 2 2.92 Lt. Deposits. 98 3007 0 G--02 9 2 2.9 t De its. 9 3038 0 0.02 8 2 2.91 Lt, Q�iaosits. 100 3069 0 0.02 9 2 2.90 Lt. Deposits. 100.1 3100U 0.02 9 2 2.91 Pjjp Lt. D osits. 100.2 1 31100 0 0 2. G M1 LAT H@1 0 100.3 3119 0 0.03 13 5 2.91 Pu Lt. De osits. III j 1 2 2 2. 3 Lt. o its. 102 3160 0 0.02 9 2 2.94 103 1 3121 0 0.03 13 2 Lt. DeQOSitS. 104 1 3222 1 0 003 11 2 2. Lt Qenosits. 105V125100.03 10 4 2.93 Lt. De osits. 100.02 2 Lt. osit1 7 7 Lt. sits1080.03 10 2 2.93 Lt. De osits. 1 8 2 2 to its. 11 0.0 11 .93 t. De i1110.02 8 2 2.9 t. De o11 9 2. t. De its. 11 498 0 0.02 9 2 .92 t. os' 114 3528 0 0.02 7 2 2.93 Lt. De osits. 1 60 9 .94 116 590 0 0. 2 9 2.94 117 3620 0 0.02 9 3 2.91 Lt. De osits. 11 3651 0 0.03 10 2 92 119 3682 0 0.02 9 3 2.93 Lt. De osits. 20 3713 0 0.02 9 2 2.94 121 3744 0 0.03 10 2 93 . De i 122 3774 0 0.02 9 2 2.93 Lt. De osits. 123 38Q5 0 0.02 8 2 .92 t. De ' s. 124 3836 0 0.03 11 2 2.93 . De osit . 1253867 0 0.02 8 2 2.92 Lt. De osits. 12g38970 0.02 8.92 . De o ' s. 127 1 39280.03 10 2 128 3958 0 0.02 9 2 2.94 1 9 3 890 0. 10 4 .91 130 4020 0 003 1 2 osi 1314051 0 0.02 8 2 2.94 4081 U 0.02 9 .93 t osi 13 2 0 0.03 11 2 2 Lt. osi 134 4142 0 0.04 16 3 2.92 Shallow Line of Pits. Lt. Deposits. 135 4173 0 0. 13 4 2.92 Lt. Denosits. 136 4202 0 0.03 13 3 2.93 Lt. Deposits. 137 4233 o 0.02 9 2 ,9 8 4264 0 0.03 13 3 2.94 139 4296 0 0.04 15 3 2.90 Shallow Line of Pits. Lt. De osits. 140 4327 0 0.03 = 2 T92 Lt. QQDosits. 141 4359 0 2.90 Lt. DepQsits. Penetration Body Metal Loss Body Page 3 (44� Well: Field: Company: 1C-19 Kuparuk ConocoPhillips Alaska, Inc. PDS Report Joint Tabulation Survey Date: June 3, 2019 Analyst: Waldrop Sheet Pipe Description 3.5 in. 9.3 ppf L-80 EUE-8RD Tubing Nom. ID Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. -14 ft. 10,068 fL Joint Jt. Depth No. (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. % Metal Loss % in. I.D. (i n.) Comments Damage Profile (% wall) 0 50 100 142 4391 0 10 q 143 4421 0 0.02 9 2 9 99 Lt. Deposits. 144 4453 0 0.04 14 4 2.91 Lt. Deposits. 145 4481 0 0.02 9 2 2.89 Lt. Deposits. 146 4513 0 0.03 12 2 299 It. Deposits. 147 4545 0 0.02 9 2 2.92 It. Deposits. 148 5 0 0.04 15 4 2.93 Sballow 2itfing. I t. De osi 149 4607 0 1 0.03 12 2 1 2.88 1 t. e o ' s. 150 4636 0 0.03 11 2 2.91 Lt. Deposits. 51 46 0 0.029 2 2.90 Lt. Demaits. 152 1 4700 1 0 1 0.04 14 2 2.93 Lt. Deposits. 153 4732 0 003 12 3 2 92 Lt. Dei2osits. 154 4762 0 0,02 9 2 2.93 155 4794 0 0.03 12 2 2.92 Lt. Deposits. 156 4823 0 (10-411-91 2 2.9 allow e of Pi Lt. De its. 157 4855 0 0 14 3 .8 osit . 158 4886 0 0.03 13 2 2.91 Lt. Deposits. 9 491 8 0 2 7 .90 os't . 1 4950 0.04 15 4 1 Sha w Pitfin t. Deposits. 161 4982 0 0.02 8 2 2.90 Lt. De osits. 5014 0 0. 12 3 De osi s. 16 044 0.03 10 1 Lt. sits. 164 5076 0 0.03 11 2 2.91 Lt. Deposits. 1 5107 0. 13 2.90 Deposits. 166 5139 0 0.03 11 2 2.93 Lt. Deposits. 167 5171 0 0.03 13 3 2.91 Lt. Deposits. 168 203 Q 0.02 9 2 2.92 Lt. posits. 169 5233 0 0.03 12 2 2.90 Lt. Deposits. 0 5263 0 0.04 15 4 2.88 Shallow L'n of Pits. I t. QeuosiLs. 171 5292 0 0.03 11 4 2.92 Lt. Deposits. 172 5321 0 0.02 8 2 2.92 Lt. Deposits. 173 5353 0 0.02 9 2 2.93 L. Deposits. 174 5384 0 0.03 10 2 2.89 Lt. sits. 175 5415 0 0.02 8 2 2.91 Lt. De osi ts. 176 544 0 0.03 12 1 L. osits. 177 5477 0.03 11 2 Lt. o its. 178 5506 0 0.02 8 2 2.89 Lt. Deposits. 17 538 0.02 9 2 L. e osits. 180 5561) 10 0.03 1 3 2.9 Lt. De osit . 181 5598 0 0.03 13 4 2.89 Lt. Deposits. 182 5627 0 0.03 13 2 Qn Lt. osits 183 5659 0.03 11 3 2 88 Lt. s' s. 184 5689 0 0.02 7 3 2.92 Lt. Deposits. 185 5720 0 0.02 6 2 2 3 186 5751 0 0.02 7 2 2.91 Lt. De osits. 187 5781 0 6.02 9 4 2.92 LL Oel2osita. 188 5812 0 0.02 9 2 2.93 189 5843 0 0.02 9 2 2.94 190 1 5874 0 0.03 10 2 2.92 1 It. De i. 191 1 5905 0 1 0.02 9 2 2.92 1 1 t. Deposits. Penetration Body Metal Loss Body Page 4 ji�s- Well: iC-19 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. PDS Report Joint Tabulation Survey Date: June 3, 2019 Analyst: Waldrop Sheet Pipe Description 3.5 in. 9.3 ppf L-80 EUE-8RD Tubing Nom. ID 2.992 in. Body Wall Top Depth Bottom Depth 0.254 in. -14 ft. 10,068 ft Joint Jt. DepthrPen. No. (Ft.) pset n.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Comments Damage Profile (°%wall) 0 50 100 192 5936 1 0 I n ng 7 2 2.93 Lt. De sits. 193 5966 1 0.02 8 2 2.92osi s. 193.1 59970 0.03 11 2 2.92 Pu Lt. De osits. 193. 6007 0 0 .88 C1 M 2 0 ATCH @ 2-00) 193.3 6016 1 0 1 0.03 10 2 2.92 PuI2 Lt. De its. 194 6026 0 0.02 7 2 2.94 1911117 0 00 7 95 196 60 0 02 9 2 2. 197 6119 0 0.02 7 3 2.94 1981 0 0.02 2 2 .95 199 6180 0 0.02 7 2 2.95 00 6 0.02 8 2 5 201 4 0 0.03 1 2 2.95 202 6273 0 0.02 8 2 2.94 03 3 0 0.02 2 2. 4 04 6334 0 0 9 2.95 205 6365 0 0.02 7 2 2.95 206 0 0.02 9 2 2.95 207 64 7 0 9 4 .93 . Der)o sits. 208 6457 0 0.02 7 2 2.94 6488 1 0 an2-- 2 2.94 21 6519 0 0.03 10 j 3 2.95 211 6550 0 0.03 12 4 2.95 212 6580 0 0.04 14 3 2.95 213 6610 0 0.03 10 3 94 214 6641 0 0.03 10 2 2.95 5 6672 0 0.03 10 4 95 216 6703 0 0.02 9 2 2.95 17 6734 0 0.04 15 2 . 6 Ilow Pidin . 218 6765 0 0.03 10 2 .94 219 6796 0 0.02 9 2 2.95 0 6827 0 9 2.95 221 1 6856 1 0 0. 7 3 2.95 222 6887 0 0.03 11 2 2.95 23 6918 0 0 10 2 2.95 4 6949 0 0.02 9 2 .95 225 6980 0 0.03 10 2 2.96 26 7011 0 0.03 10 2 .94 7 7042 0 0.03 10 .95 228 7072 0 Q.02 9 2 2.94 9 71 o3 0 o.o2 9 2 .95 230 134 0.0 92 294 231 7165 0 0.03 10 2 2.94 2 7196 0 0.02 9 4 .93 233 7227 0 1 0.02 9 2 2.94 234 7 7 0 0.02 8 2 2. 235 728go .0 13 4 2.95 236 73190.02 9 2 2.95 237 7003 1 2 4 238 73 Q02 9 3 1 2.94 11 Penetration Body Metal Loss Body Page 5 (Ii S Well: Field: Company: iC-19 Kuparuk ConocoPhillips Alaska, Inc. PDS Report Joint Tabulation Sheet Survey Date: June 3, 2019 Analyst: Waldrop Pipe Description 3.5 in. 9.3 ppf L-80 EUE-8RD Tubing Nom. ID Body Wall Top Depth 2.992 in. 0.254 in. -14 ft. Bottom Depth 10,068 ft. Joint Jt. Depth No. (Ft.) Pen. Upset (i n.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (i n.) Comments Damage Profile (% wall) 0 SO 100 239 7417 1 0 1 R029 4 2.94 40 7442 001 12 5 2.94 241 7472 0 1 0.02 9 2 2.96 242 7502--D I QM 9 2 2.95 243 7533 0 1 0.02 9 .95 244 7564 0 0.02 7 2 2.96 45 5 0 0.03 3 2 2 5 762 0 .02 8 2. 6 247 76560 0.04 17 4 2.95 Shallow Line of Pits. 24 7 7 0 0.02 9 9 249 7718 0 0.03 11 2 2.95 250 7749 0 .02 8 2 .95 251 7779 0 0,02 9 3 2. 252 7810 0 0.02 9 2 2.95 253 7 41 0 0.02 2 2. 6 2 872 0 7 2 .9 7903 0 0.03 12 3 2.95 P2255 7933 0 .0 9 2 2. 4 57 7964 0 0.04 14 2 2.96 25 7995 0 0.04 14 3 2.95 1 8025 0 2. 260 1 805 9 0 0.02 9 2 .95 2618086 0 0.02 9 3 2.94 61.18115 0 0.02 9 2 2.93 Pu t. e osi 261.2 8126 0 1 0 0 0 .88 3 TCH 1 :00 261.3 8136 0 0.03 11 2 2.91 Pu Lt. D---,;.- 2 2 146n om 13 .96 263 8177 0 0.03 12 3 2.94 4 8208 0 I n m 11 2 265 8239 o I nn3 10 2 2.95 0 0.03 10 2 2.96 0 10 4 .95 00 9 .94 0 0.02 7 2 2.94 [26608269 0 .0 13 2 .9 0 0.0 12 .94 0 0.03 13 2 .95 0 9 2 .95 2748516 0.04 15 1 4 2.94 Shjllow Pi 275 8546 0 0.02 9 2 2.94 7 8 76 0 0.03 12 2.95 277 1 86070.02 9 2 2.94 2788638 0 0.03 12 3 2.93 7 8669 0 0.03 3 3 9.95 280 8699 0 0.02 9 2 2.96 2M488 0 .0 2 2 2.9 2 9 2 2.94 2 0 0.02 8 2 2.94 20 0 8 2 2.95 1 0 9 2 2.94 Penetration Body Metal Loss Body Page 6 ji S- Well: Field: Company: 1 C-19 Kuparuk ConocoPhillips Alaska, Inc. PDS Report Joint Tabulation Survey Date: June 3, 2019 ;Analyst: Waldrop Sheet Pipe Description 3.5 in. 9.3 ppf L-80 EUE-8RD Tubing Nom. ID Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. -14 ft. 10,068 ft Joint Jt. Depth No. (Ft.) Pen. Upset (i n.) Pen. Body (in.) Pen. % Metal Loss % Min. I.D. (in.) Comments Damage Profile (% wall) 0 50 100 6 8 4 0 .03 = 2 294 287 8915 0 0.04 15 3 2.93 Shallow Pi 'n . 288 8945 0 0.02 9 2 2.93 289 8976 0 0,02 9 2 2.94 290 9007 0 0.02 8 2. 291 9037 0 0.02 9 2 2.95 92 9068 2 9 2 2. t. ,sit 293 9099 0 0.0 0 .93 294 1 9130 1 0 0.02 7 2 2.94 95 1 91610 2 9 4 2. 296 1 9191 1 0 0.02 7 2 2.95 297 9 2 7 2 2.95 8 0 0.02 9 .94 299 9283 0 0.02 8 2 2.95 9.1 0 0.0 8 2 .93 Pu .2 3 4 0 0 .92 M LATCH @ 5:00 299.3 9333 0 0.03 13 6 2.92 Pu Lt Deposits. 0 4 0 0.02 9 94 301 9375 .02 302 9404 0 0.02 9 2 2.96 3 9434 0 .02 7 .92 . De 't . 4 9466 0 02 305 9497 0 0.02 7 2 2.93 Lt. De osits. 9527 0 1 0.02 9 2 .94 307 1 9558 1 0 1 O-OL- 2 2. 308 1 9587 0 1 0.02 8 2 2.93 Lt. De osits. 309 618 03 2. Lt. osi 310 9649 0 0.02 9 4 2.93 Lt. De osits. 3 11968 0 .0 2 94 31 710 3 10 3 2. 313 9741 0 0.03 11 4 2.95 4 9771 0.0 7 3 315 1 9801 0 0 8 2 2. 2 Lt. sits. 316 1 9832 0 0.02 7 2 2.91 Lt. De ,sits. 17 1 986 02 318 1 9892 1 0 0:629 2 2. Lt. si s 319 1 9923 1 0 0.02 9 1 2 2.92 Lt. De osi ts. 319.1 1 954 1 0 1 0 03 11 3 2. Pu Lt D its. 31 96 0 0 0 .9 L LAT @ 0 319.3 9972 0 0.04 7 5 2.90 Pu Shallow Line of Pits. Lt. De ,sits. 978 0 -T- 0 2 2.95 320.1 10009 2 9 2 2. PuI2 LI. Del2osits, .2 10 320020 0 0 0 0 2.97 SEAL ASSEMBLY 0.3 1003 0 0 0 0 3.06 BAKER POE 320.4 1 10036 1 0 1 0 0 0 2.96 BAKER SAB-3 PERMINMENT PACKER 320.5 10050 0 0 0 0 OSS- V R 005 320.6J0068 0 .01 6 1 7 P 320.70061 0 0 0 0 2.74 CAMCO DX NIPPLE 320.80 0 0.03 13 Lt. Deposits. 0.9 0 0 0 0 3.45 W E Penetration Body Metal Loss Body Page 7 ji4�s PDS Report Overview Body Region Analysis Well: 1 C-19 Survey Date: June 3, 2019 Field: Kuparuk Tool Type: UW MFC 24 Ext No. 10011398 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pipe 7 in. 26 plaf L-80 BTCM Anal sC Waldrop Pipe Nom.OD Weight Grade & Thread Nom.ID Top Depth Bottom Depth 7 in. 26 ppf L-80 BTCM 6.276 in 10,070 ft 10,141 ft 10 8 6 4 2 0 Penetration (%wall) 0 to 20 to 40 to over 20% 40% 85% 85% Number of Joints analyzed (total = 3) 3 0 0 0 Damage Configuration (body) 10 8 6 4 2 0 Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos. Hole timber of jo 0 0 2 0 0 Damage Profile (% wall) Penetration body Metal loss body 0 50 100 1 2 3 Bottom of Survey = 3 ji S- PDS Report Joint Tabulation Sheet Well: 1 C-19 Survey Date: June 3, 2019 Field: Kuparuk Analyst: Waldrop Company: ConocoPhillips Alaska, Inc. Pipe Descripron Nom. ID Body Wall Top Depth Bottom Depth 7 in. 26 ppf L -BO BTCM Casing 6.276 in. 0.362 in. 10,070 ft 10,141 ft. Joint Jr. Depth Pen, Pen. Pen. Metal in. No. (Ft.) Upset Body % Loss I.D.ZShallowLine Com;"E(in.) (in.) % (in.) 0 0 0.0 7 6.25 2 00 0 0.06 17 .25low Pits. 3 101 34 0 0.05 15 6 6.30 Pits. Penetration Body Metal Loss Body Page 1 KUP PROD 10-19 ConoeoPhtlllpsWell Attr I Max Angle &MD jTD FI[Ia Nefna 'r MUY1N CWmmore staWs N[I 11l MO�Itl(Bl Ac[aMmIL01 A111Oti4e1G. KUPARUPRIVERUNIT 5nmR9Btaenn onn < I3S3`.r •UIVPLE 140 IPldnnn Ilmwn iC-1p.3rfN301d 1})800PM Last Tag t'Mr[e .Glamgl[IeGuel) Mnehtlen Las Tag RKB and Ort[ 942201> -PM m et La51Motl By 10,1870 'Proven Last Rev Reason M^oNIN^ Rev Rabso '. H26 emoal9 >r3G.1018 L, :I Maa ey 'proven Casing $trings CaaNp OPillptlen OD IMI Ip linl CONDUCTOR tb 1506 Tap m11B1 $alpepVr mK01 SM pepfM1 290 1380 1380 lTYy I... L'RfLen IL. grade TePTNead 82.50 H-00 WELDED Culn9 pea[rlptlen pp pnl Ip Bnl SURFACE PSIS 883 Tep 111KB1 t000. mK 01 6M papm 28.0 6)44.7 4,4)41 lTVpi... NNLen B_ Ontle Top Thud g000 X80 BTC_ Caalnp Mi[rlptlm Op INI 09n1 PRODUCTION > 8,28 ToplKKal aWpepM I.. SR Oep1ry 26.0 1.4287 8)88.6 1TYJ1,. WULon ll.. grade Tep Trutl 26.00 L -W BTCM Tubing Strings CONOUcrOR. 30 o4uB TUMneoeaonpuon . Me,. 1p ton)) T,IWBI TUBING WO 3V2 2.99 229 sN ogln m.. Ort oapM lTvp14.. 029 :-D W[femry oreae rap conneenon 930 L-Wew EUEupco Completion Details NIP0.E. saes Top1KB Tep TVpl TOPMCI 'Ra",1 1RKB1 11 nem pee Neminal Cam mpW 'OW HANGER GEN IVTUBiNGHANGER 2.890 0.78 NIPPLE 2.875' 9B' NIPPLE 2.875 89.88 LOCATOR BAKER LOCATOR 2990 t0,01J6 6,4408 346) SEAL ASSY BAKER SO -0O SEAL ASSY 2890 Tubing puoHpnon Bbiny Ma.. m Qnl Tep TUBING Original 5.8 300 10,021.3 IKKeI Stl pgOf 1M1, BN pepM INp14.. 10,G5>.9 6,4822 tttlpml pude TopCemutldn G Burr. ].1J3a Completion Details Top (TDiaP lr[I Top I.., IRKBI 1°I uem pea Nominal cam Ip pnl 10,0213 8443.8 1488 PBR BAKER 8040 PBRJSBH-TUBINGFTRING HAS 004D OF THE 3,000 PBR- 10035. 6.455.8 34.52PACKER BAKER SAB -3 PER MANENT PACKER WI MILLOUT EXTENSION 3,710 10 BJP on. uri.:-On3 10.0599 84>87 34.27 NIPPLE CAMCO 9 NIPPI£W/NO GO 275 PPRCRI 2]50 100870 64816 3420 WLEG BAKER WIRELINE ENTRY GUIDE 3 M Perforations & Slots on pm[ [unF-.:E,3 n: ]4</ TPPime 10,750.0 BM ea 1 1 10,180.0 T[PIM1'al a"l Imr01 mK(Tool Llnka63[ne =18 0.IaM1 INm Typo Cam 6/18I20m 401PERF 6D, 2 SPF 125- HYPER JET, 4SPF PO WERJET Gw:cR.tp]ec Frac Summary BMR D. 10nrz963 PMPPanl paalgmd gel prop'k.nPomgtlonle) 00,300.0 2tt. 111WOM Tdppe ,N , BNIIp3LB1 1 IU72003 10,1500 10,180.0 1M.Fum SyalM1 Ayp1>,<OWdnama> VaI CIevImWl Vol BlruA•mbll G a.S L1R;9,31pC SIu1 pWa 9110.2017 Preppmtpulpnee 1161 200000.0 proppmlln FomWlan (lh) 200,2630 gig! 1 9yRpW TOP poPM 111K01 ern IRKBI 9/10201) 10,1500 10,180.0 Wkb FIW68yHtvn G.Ind Set W.N1, Hybor G Vol CINV16b11 Vol Blunylbbll 2]66.00 2,9]2.00 Mandrel Inserts at en GA: LIFT, 99MJ on N -1p (TV01 Valve LaNM1 Top I..). I Make Mad. MI gery Type a paR3lxe IRO RVn IIW Ipef) qen OWe Cem 1 37 34 25957 C CD MMG 112 GASIJFTGLV RK 0.186 1,2330 8/13/2017 - 2 6,0147 4.102] CAMCO MO 11/2 Gq3 LIFT OV RK 0.250 00 9/131201) - 3 8,1286 5.M7 CAMCO MMG 112 GAS UFT OMT RK 1 I GWU I 0.0 9/2]/2013 4 9,3190 5.9121 CAMCO MMG 112 GA.111 DMV RK 0000 00 92]¢013 LofAiOR. IgBfaa 5 B, 056.9 61390.9 CAMCO MMG 112 GAS UFT OMY RK 0.000 00 9/)201) Notes: General & Safety SFAL Ai5V, 10,0138 End OaR MnWeflen PBR. fo.Ov3 LI12011 NOTE Vlnn S^Femati /AlaskeSMafna1c80 I.nF. l0CSs0 NIPPLE 10.0588 WLEG.10,9P10 F10.i5C0 F`"rc15O150 P10. BCO'''''��L�L ppppp 5C.0� ' PROOUCTpN. M.61Ca" ]� ConocoPhillips Alaska, Inc. Drilling & wells ConocoPhillips Coiled Tubing Drilling I Alask, May 10, 2019 1C-19 Pre -CTD Procedure Page 4 of 4 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1C-19 Permit to Drill Number: 203-054 Sundry Number: 319-285 Dear Mr. Ohlinger: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .00gcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, )esielowski Commissioner DATED this 12- day of June, 2019. RBDMSL� JUN 1 31019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 JUN p 5 2p 9 owl/ r rz(9 AOGCC I. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: —Whipstock_❑✓ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory ❑ Development ❑i . Stratigraphic ❑ Service ❑ 203-054 ' 3. Address: 6. API Number: PO Box 100360, Anchorage AK 99510 50-029-23149-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU IC -19 Will planned perforations require a spacing exception? Yes ❑ No ❑� 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 25649, A , ADL 28242 Kuparuk River Field / Kupawk River Oil Pool . 11. ��.�./'�% PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (fl): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10,435' • 6794' 10,345' 6717' 3232 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 109' 16" 138' 138' 1640 psi 670 psi Surface 6745' 9-5/8" 6745' 4474' 5750 psi 3090 psi Intermediate Production 10,403' 7" 10,429' 6789' 7240 psi 5410 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10,150'-10,180' 6550'-6576' 3-1/2" L-80 10,030 Packers and SSSV Type: Packers and SSSV MD (fl) and TVD (fl): Baker SAB -3 Permanent Packer 10,036' MD / 6456' TVD 12. Attachments: Proposal Summary 0 Wellbore schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑� ' Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 6/19/2019 OIL Q WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: James Ohlinger Contact Name: Shane Germann Authorized Title: Staff CTD Engineer Contact Email: Shane. ermann c0 .Conn Contact Phone: 907-2634597 Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Numbe /2 Plug Integrity F-1BOPTest E Mechanical Integrity Test ❑ Location Clearance ❑ B1dp �t 5 d to 36760 {p s ` 5 Other: 4T 5 '4 '-)-V7 vlQ✓IJ!'e* Vlvt �fSt /V 200 Post Initial Injection MIT Req'd/? Yes ❑ No r�' RBDMS&L JUN 13 2919 Spacing Exception Required? Yes ❑ No Subsequent Form Required: le- !� • APPROVED BY Approved by: , COMMISSIONER THE COMMISSION Date: 20 6 ///// pp pp ® I V NA pp Submit Fore and Form 1 3 Revised 412017 Approved a licat i li rid [he date of approval. y`/� Attachments it Duplicate and ,ems ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 June 3, 2019 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits applications for sundry and permits to drill one lateral out of the KRU 1 C-19 (PTD# 203-054) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin in June 2019. The objective will be to drill one lateral KRU 1C -19L1 targeting the Kuparuk C -sand interval. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. Ylo;' ) _ Attached to the permit to drill application are the following documents: - Permit to Drill Application Form (10-401) for 1C-191-1 - Detailed Summary of Operations - Directional Plan for 1 C-191-1 - Current wellbore schematic - Proposed CTD schematic Attached to the sundry application are the following documents: - Sundry Application Form (10-403) for 1C-19 - Summary of Operations - Current wellbore schematic - Proposed CTD schematic If you have any questions or require additional information, please contact me at 907-263-4597. Sincerely, Shane Germann Coiled Tubing Drilling Engineer ConocoPhillips Alaska KRU 1C-19 (PTD #203-054) CTD Summary for Sundry Summary of Operations: KRU well 1C-19 is a Kuparuk C -Sand producer equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize one lateral to target the C -sands to the north of 1C-19. The lateral will target reservoir to the north that has been sheltered due to a large sealing fault CDR3-AC will set a mechanical whipstock (High Expansion Wedge) inside the 7" casing at the planned kick off point of 10,160' MD. The 1C-191-1 lateral will exit through the 7" casing at 10,160' MD and TD at 14,503' MD, targeting the C sand to the north. It will be completed with 2-3/8" slotted liner from TD up into the 3-1/2" tubing at 10,050' MD with a deployment sleeve. CTD Drill and Complete 1C-19 Lateral: June 2019 Pre -CTD Work 1. RU Slickline: Dummy whipstock drift, C/O GLV's 2. RU E -line: Caliper 3. RU CTU: Mill out D -Nipple to 2.80" ID �hJl 4. Prep site for Nabors CDR3-AC rig. Rig Work 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 1C-191-1 Lateral (C sand- North) a. Set top of high expansion wedge at 10,160' MD. b. Mill 2.80" window at 10,160' MD. c. Drill 3" bi-center lateral to TD of 14,503' MD. d. Run 2-3/8" slotted liner with deployment sleeve from TD up to 10,050' MD. 3. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CDR3-AC rig. Post -Rig Work 1. Return well to production. Page 1 of 1 6/4/2019 A&VkI. KUP PROD 1C-19 Conoc&hilfip$Well •` Alaska. Inc. 'i Attributes Max Angle & MD TD H." B..Incll'1 MR(hKel AB atm Me) wenMte APxu1N Mo 1. KUPARUK RIVER UNIT 500292314900 PROD 60.17 5,856.23 10,435.0 ate MnWalion [ntl Dote K94rE 1N RIO Rtleau Date Comment H351ppm) D91.4'1.2 SSSV: NIPPLE 40 9/4/201] Lail WO: 9/272013 34.]0 51132003 1w9,7ma+e+zaepa PM Last Tag VdlWscnematelz<lual) Annatalien Entl Oale Deplry lhKef last MdJ By LWT., PIKE 9/12/201] 10,18].0 ppmven Last Rev Reason ................................nnxcen:as...,.- Mnotallon Entl Oalo 1a51MM Dy Rev Reesgn: H2S 7/302018 ppmven Casing Strings Casing Description 00(NI IDlinl Tcy1hKB Set Depin lxKB 5¢I D¢pIM1 I1V01.. ntl... retl¢ Top TM1reatl CONDUCTOR 16 15.06 29.0 130.0 1380 62.50 H-00 WELDED Casing D-eriplian OO kn) IDgnl Tap (rtKB Set Deptn@KBI BN O.7no" pD1... atle Top TMeatl SURFACE 95/0 0.83 28.0 Man 6.744] 4,4]d.t 40.00 LEO BTCM casing Dsscripnon DD gnl ID(Inl rn MDI Set DePeh(nKBI ne Men IiVD)- VVW,v ll... GrWe TopUe- PRODUCTION 7 6.28 26.0 10,4283 6.78aD 2fi.00 LEO BTCM Tubing Strings Tuhing Descriplbn 9ttnq Ma..ID lln) iop(hKIB SN one Ift.. 9N 0epIM1 jrVp)I., w111MD etatle iap Cann¢lbn coxoucroR;sal3eo TU01NG w0 312 2.99 22.9 10.029.5 6,450.5 9.30 LEO EUE-8r6 Completion Details Tup(IP) IDp Ind Nominal MPPIE:5GA3 Top InK9 (M1KB ('1 Item Des Co,n IDllnl 22.9 22.9 0.00 HANGER EN)V TUBING ANGER 2.990 509.2 509.2 078 NIPPLE 2.875""DB"NIPPL. 2.875 10,016.8 6.440.1 34.68 LOCATOR BAKER LOCATOR 2.990 ,01].6 6,A40.8 34.6 SEALA$SY BAKER 8040SEALP Y 2.990 Tuhing Descnplian SMnO Me... IDlinl Top IXKB Set Oeprnln„SIXDBpd,RCDI1-. wlllofh) cmtle Top Conneatlon TUBING Original 89 3.00 10.021.3 10.067.9 8,482.2 GAs uFT; 41x. Completion Details Top(TVD) Top lna Nnmmal Top lnxal Inxel 1'I IRm De. Co. IDlinl 0,021.3 644.8 M,66 PER BAKER RGAO PBRISSR"'TUBING STRING HAS ODOD OF THE 3000 PBR"" 0 5.9 6.45. 34.5 PA KER AKER AB- PERMANENTPACKER a/MILLOUT XTENSI N 3710 103]1" DASUFT', e01av 10,059,9 6.475] .2]NIPPLE CAMCODNIPPL'WING 75 -PROFILE 2350 10,06].0 6. 81. 34. WLEG BAK R WfRELIN EN V 1 E 3.000 Perforations & Slots en' cee Ta BIm (=) Top (nKel elm (nND) (XKB ,.6) (nNB K8) Li111Rbge Gale ) Type Com 10.150.0 10,180.0 8,550.6 6.575.8 C4./ 1 6/182003 4.0 IPERF SURFACE¢e. J,P.v- NYPERJHWERJ.2SPF ET, 4 SPF Am POWERJET Frac Summary eAs uFr: et)B.a slaty Dnle Prcpgnt Uee nese) Fmnseen(lh) 10012003 ,igarLln ZOQ300A 5y4 SI+rI Me Top OeplM1 MKe) BM MNeI Vd Okan@q) VW Slurry(hhg 1 10n2003 10,150.0 10,180.0 .....5:,- SbrcData Propwnt Design etl llhl op Fnmdkn(IN IP 91101201] 200,0004 200.2630 GAB DFT: H.318.0 ean(hhg W. /NKlhd) V2d,9 1 91102]$2IY.0rry0017o 0,150.0 10,180.0 WHyboe G 2,766.0 Mandrel Inserts SI .I GAS UFT. O.x on N Top mKB TMKB ) Naive MW., OOkn) Sam Type TypeVaha, Po`n) iRO0 Run Date Com 1 3,133,4 25953 C 112 GASLIFT GLV RK 0.188 1,233.0 91131201] 2 8.014.] 4.1023 C 112 GAB LIFT OV RK 0.250 0.0 91131201] 3 8,126fi 5,20]3 CAMCO MMG 1 L2 GAS LIFT DMV RK 0.000 0.0 92712013 4 9.3190 5,912.1 CAMCO MMU 112 GASLIFT DMY RK 0,000 0.019F270013 m0AT0e, 10.016a 5 9,956.9 8,3909 CAM O MMG 112 GASLIFT DMY RK 0.000 0.0 90201] Notes: General & Safety sEALA55v: mons end Date Mnmalan 11 V Ol NOTE: View ScM1emmicwl AlaskaSNematic9.0 P.t0.Mt3 PACKER: 100x9 NIPPLE', IO.l .2 NLEG: K... FRAC: 10,150.0 IPFAF: Hldrvul. 10n0 Fa6101a00o� p y PROOpCTION:M.6f0,42&]- IC -19 Proposed CTD Schematic 16" 62.5# H-40 shoe @138'MD j58" 40# L-80 shoe 6745' MD IKOP @ 10160' MD I C -sand perfs 10150' - 10180' MD 7" 26# L-80 shoe @ 10,429' MD Modified by SJG 5/30/19 3-1/2" DB Nipple@ 509' MD (2.875" ID) 3-1/2" 9.3#L-80 EUE 8rd Tubing to surface 3-1/2" Cameo MMG gas lift mandrel @ 3133', 6015', 8127', 9319'. & 9957' MD Baker 3-1/2" PBR @ 10,021' MD (3.0" ID) Baker SAB -3 packer @ 10,036MD (3.710" ID) Cameo D -Nipple @ 10,060' MD (2.75" ID) 3-1/2" WLEG @ 10,067' MD C wp03 503' M D Liner top —100 DM EIVED STATE OF ALASKA NAL OIL AND GAS CONSERVATION COM• CTION 2017 z-`��153 REPORT OF SUNDRY WELL OPERATIONS G( C 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate 0 Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ 'erforate New Pool El Repair Well ❑ Re-enter Susp Well❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development p Exploratory❑ 203-054 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic❑ Service❑ 6.API Number: 99510 50-029-23149-00 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 1C-19 ADL 25649,ADL 28242 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 10,435 feet Plugs measured None • feet true vertical 6,794 feet Junk measured None feet Effective Depth measured 10,344 feet Packer measured 10,036 feet true vertical 6,716 feet true vertical 6,456 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 109 feet 16 " 138'MD 138 TVD SURFACE 6,717 feet 9 5/8" 6,745'MD 4474 ND PRODUCTION 10,403 feet 7 " 10,429' MD 6789 TVD Tubing(size,grade,measured and true vertical depth) 3.5" L-80 10,068'MD 6,482'TVD Packers and SSSV(type,measured and true vertical depth) PACKER-BAKER SAB-3 PERMANENT PACKER 10,036' MD 6,456'TVD SSSV-NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): 10,150-10,180 SCANNED NOV 0 320173 Treatment descriptions including volumes used and final pressure: Y Total well- 1 stage 200,00 lbs placed see attached schematic for full FRAC details 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 200 300 1800 910 250 Subsequent to operation: 665 1490 2970 1150 267 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) `�1A 15.Well Class after work: Daily Report of Well Operations 0 t7�JY_ \p\\gl Exploratory CIDevelopment 11] Service❑ Stratigraphic ❑ Copies of Logs and Surveys Run CI1 16.Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data El GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-390 Contact Name: Sandeep Pedam Authorized Name: Sandeep Pedam Contact Email: Sandeep.Pedam@cop.com Authorized Title: Staff Completions Engineer 01000) Q/ � / '1Contact Phone: (907)263-4724 Authorized Signature: Date: / ` Form 10-404 Revised 4/2017 / ioM , a El Submit Original Only C'w /01/1/2017 • • 1C- 19 DTTMS JOBTYP SUMMARYOPS 9/10/17 DRILLING PERFORMED C SAND FRACTURE TREATMENT USING 25#HES SUPPORT- HYBOR G FLUID SYSTEM @-18 BPM. STEPPING UP SAND EXPENSE CONCENTRATIONS FROM SCOUR 0.25/0.50 PPG 16/20 PROPPANT REI DURING TO 1, 2, 3, &3.5ppg DURING SUBSEQUENT STAGES. 200,300# OF SAND PLACED IN FORMATION, 100% OF DESIGN). WELL FP'D W/ 25 BBLS MINERAL OIL. NOTE: Will attach HES treatment report once wnihhlc 9/12/17 DRILLING PERFORMED C SAND FRACTURE TREATMENT USING 25# HES SUPPORT- HYBOR G FLUID SYSTEM @-18 BPM. STEPPING UP SAND EXPENSE CONCENTRATIONS FROM SCOUR 0.25/0.50 PPG 16/20 PROPPANT REI DURING TO 1, 2, 3, &3.5ppg DURING SUBSEQUENT STAGES. 200,300# OF SAND PLACED IN FORMATION, 100% OF DESIGN). WELL FP'D W/ 25 BBLS MINERAL OIL. NOTE: Will attach HES treatment report once available. 9/13/17 DRILLING PULLED DVs @ 6015' &3133' RKB (NO DAMAGE ON RK LATCHES) SET SUPPORT- OV @ 6015' &GLV @ 3133' RKB. GOOD DDT ON IA(900 PSI DP) EXPENSE READY FOR FLOWBACK. REI • . co `° -� O o v -, a) °' L3. co v N C CO W -, m Z - , CD O C v ,, 0 0 �.O a. 6 71 0 -sa)) < 0 TI a) 0 D` O CS O 75 0 =. ((D O c 0_ 7 N _D �' Cl) v -9 , g 1- Z O- Z 7 N 0 D C 'TI 0 m 0 n v 0 cQ 0 c Z c o 0_ M. �h c 3 col m m c n. a 0 3 cr m v a s m `, cP 7 - 3 m m (1) Woo `, `G cD cD N r p0 "0 o M Fii ca WNW o_ (D '+ ) 00 -11 s 0 0. D c 8 0 O o O _ o 0 01 0. 0 o C * * 3 0 N a) 75 N e m � co P11-1.O I (D CD CO O W CD 0 l, G.) 7 OJ o (4-). Q CO ( co N y Cco D cin Z N 0 _, 0 9(LI' D o o 3 ca., v Cn Z ' Z N 0 O O N O j 0 o 0) coo 0 0 o 0 CO cn o - CO O CD .-r nc � cr3 • 0 CO wn m D3 � � �n >It 0 c' o v 2 a [ i n :iii Q 5. 0 5 o rn 3 0- 3.CD 0. 3 0 N c) 0 o M0 0 O 0 0 f Sli, N ''' 5 ° 5 K o"- suirli —1 CD 0 x O I 3 -n , 00. 3 n) .... vl 3 o 0 • • I m 0 » ¢ Cl) m 2 7I -02 00 Fri 0 p 00 2 0 0 \ er = gR \ a) / \ Z 6 & \ 7q / -I n z - w c / m ® 0 o / / () r- o m \ m c @ m 2 \ Co I:. m 3 - >2 / 2 0 I I I I_ _ _ \/ E. E. / \ / / / / / / } \ \ _ _ _ _ _ _ _ _ 2 G Z 0 0 CO 2 >s 2 0 O CO 3 co 3 c \ I 3 3 \ \ / y ƒ / / / 0 \ \ m - = = = f = _ . \ e ƒ > = ° — ƒ & \ - i & E E E E E E E c = e e e z z = e \ \ \ \ \ \ \ \ CO CO CO CO CO CO CO CO m m m m e o m m ƒ \ƒ \ƒ *ƒ \ • i 3 v 0 a/ D.) CD a. CD z 2 CD CP .'-j'" a CD CD X. C) CD 0 0 n o_ co Cl) ' CD m' o v 7i m > cn m > CD > 'a 2 0 CO -0 m -0 -0 G) -I m -0 CD O ..(-2, 0 EO) > K o v 3 0o o s• � o 0 3 5- F o m x o o o n- c oc w n- o v' •,7 3 = c c cc) Ea v C a m- C-17 E 3 ) x 3 0 < 0) v C , Cl) c - c 0 o = - o :-'4- _ m y 3 — S v ' o V_, `G p N o `G O cD `� CD cn 0 () O (Q C' x 0 3 CT Q) Q" 5- CD o A,><<, c °) �' c' v�n c w Q c c c S a n n = v c 3 0 0 3 o a — 3 3 S a o o n- m m 0 3 3 c- °-_, o s Q n a ,� 3 o- n c 3 = 0) -,, o - 5 0 w o cn `< m o o o m m - rn co-c v ° x 3 — = n x v Q � � o Q N � c o_ 3 n) C a CO m 0) o v 0) n) cn o m 0 0 x O 6' CD C o v c) OY S o- ...< CD m v m 0) `.< = 5.2 0_ 0) CD v N m m m m o = 5. a a a -� -., O) --� U1 "I O) O) 1) 'D 01 O) —, --, CO —, —, CO -I O) —• - — _N. a r N W CO CO O "I OD A --1 ^t CD A W O O W W O O) -->. A O) OD W e -.....i _s. N —, N O v 0 0 O ' - CO O A O O A -.4 A CO O O 0) - O O N O O V CO A -0 -0 ' O O O) co co —.I Co O) —, N N — CD 00 01 1 v N 0• 0• CO V 01 W up CD 1 W W W - O A CO 4 CO C)) N) o.) O � d7 co N N A 01 Co N O 0) �I 01 A 01 A O) O) W c- CO N O) A A �I ' CO O) N= N W N O , O —, A (Jl , O v CO (y_4 v O C71 `� `� CO "4 N .. 0 O :) l) _, —, — —N. CO W O O W W O) 6) O) O) O W CO W O O CJ1 01 O O O O O O O O O O O —, O U1 U1 CP A O O O O O O OO O — O O O O O O O O O O O O O O O O O O O O O co co O co co) O O co co O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O C) O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O 1 O O O O O O O O O O O O O O O O O O W 01 01 C.71 "I V O O O O O O O O O O O O O — -- 00 00 OD W � _, — O O co O O N N N N A 01 �l CO (r (Il 01 O A A W A 01 A v CO OO O_ O) CO O O N O O) N_ N_ N_ O W W W W CO W A 0) CO O --4 "4 CO CO C4 W CO A -4 co - v v O) —, N —, A N N 0) co Co Co — N A W CO CO CO N W W CO 00 CO E j/ \\ 4110 E` xzE E/ @ ] 5g ) \\ \\ Fes% /( \C/ ka no \) }\ 0_, St «a j \ 6 \ \0101 • 03E \o O0E =E EE7 27 \/ n/ 2- \/ \G\ - 0 2\ Ds \ 5 \ E° \- : O- f§ Jm / &\ Z\\ >e ! /2 t o w e > n G @ -s G -0 I = e Z -2 ? is-: 5 0 CO w o 0 \ \ `-7 § \ \ 0,• < ) \J ] \ § ® \ ] ] ® ] 9 e = ] 5- R \ 3013 e s & \ oo c / _ « CD \ 9 = $\ o- - \ = \_ ' % % & § ƒ C \ \ 0 ° E / § o 5 \\\ / / ] x = \ \\ {{ c / \ \ \ \ % \ k{ / i0- C \ \ 9 7= 2 .a N - / ƒ ® m m k { 5i.` 7 \ 2 \ 0 \ \ \ \ / / 3 \ \ 0 0 \ \ \ / 6 \ % 7 G 0 ® © 7 \- \ / \ \ / - \ / / 6 . a0 \ J /• } 3 ^ ® / a ( / co\ D o o - o a o o a Cl) ƒ 5 2 0 0 \ 6 \ 6 6 6 \ a 6 3 0 0 0 0 0 0 0 0 0 0 0 0 Er, o 0 o c o 0 0 0 0 0 0 0 0 k o co 0 0 0 0 0 0 0 0 0 0 0 / = 0 0 0 0 0 0 0 0 0 0 0 0 o co9 9 9 9 9 o 9 9@ 9@ 9 g g 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 \ \ o 0 0 0 0 0 0 0 0 0 0 0 0 0 - - a a a o o E w w u o c E CO e o o w a a o CO 0) \ ƒ D ƒ \ Co = ] = 7 rn - 00 _ = 2 w 6- w = _ ee �. o % x § /� \ ƒ / /\ Z - m z KUPfir D 1 C-19 ConocoPF uDD1ps s, Well Attributes Max Angle D TD Alaska,Ii 1C, Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) cot •pimps ,. 500292314900 KUPARUK RIVER UNIT PROD 60.17 5,856.23 10,435.0 . ... w. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) 'Rig Release Date 1c-1s,9/26/201712.38.14 PM SSSV:NIPPLE 50 9/10/2016 Last WO: 9/27/2013 34.701 5/13/2003 Vertical schematic(actual) 'Annotation Depth(ft)(B) End Date Annotation Last Mod By End Date Last Tag:RKB 10,187.0 9/12/2017 Rev Reason:TAG,GLV C/O,MISSING FRAC pproven 9/22/2017 INFO(from 9/10/2017) Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread HANGER 22.9- illi CONDUCTOR 16 15.062 29.0 138.0 138.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(RKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.835 28.0 6,744.7 4,474.1 40.00 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(RKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread 1� PRODUCTION 7 6.276 26.0 10,428.7 6,788.6 26.00 L-80 BTCM I Tubing Strings IL Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)I...Wt(Ib/ft) Grade Top Connection TUBING WO 31/2 2.992 22.9 10,029.5 6,450.5 9.30 L-80 EUE-8rd Completion Details j wu� - - Nominal ID Top(ftKB) Top(ND)(RKB) Top Incl(°) Item Des Com (in) 22.9 22.9 0.00 HANGER GEN IV TUBING HANGER 2.990 ,---; 509.2 509.2 0.78 NIPPLE 2.875""DB"NIPPLE 2.875 CONDUCTOR;29.0-1380 10,016.8 6,440.1 34.68 LOCATOR BAKER LOCATOR 2.990 10,017.6 6,440.8 34.67 SEAL ASSY BAKER 80-40 SEAL ASSY 2.990 Tubing DescriptionString Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection NIPPLE,509.3 TUBING Original I 5.91 3.0001 10.021.3 10 ,067.91 6,482.21 I 1 Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top not 0 Item Des Com (in) 10,021.3 6,443.8 34.66 PBR BAKER 80-40 PBR/SBR""TUBING STRING HAS OD/ID 3.000 OF THE PBR"" 10,035.9 6,455.8 34.52 PACKER BAKER SAB-3 PERMANENT PACKER w/MILLOUT 3.710 EXTENSION ID 3.71" GAS LIFT 3.1334 10,059.9 6,475.7 34.27 NIPPLE CAMCO D NIPPLE w/NO GO 2.75"PROFILE 2.750 if 10.067.0 6,481.5 34.20 WLEG BAKER WIRELINE ENTRY GUIDE 3.000 Perforations&Slots Shot Den Top(TVD) Btm(TVD) (shots/ Top(ftKB) Btm(ftKB) (RKB) (ftKB) Zone Date _ ft) Type Com 10,150.0 10,180.0 6,550.6 6,575.8 C-4,1C-19 6/18/2003 4.0 IPERF 2.5"HSD,2 SPF GAS LIFT;6,014.7 - HYPERJET,4 SPF POWERJET Stimulations&Treatments Proppant Designed(lb) 1 Proppant In Formation(lb) Date 200,300 0 10/7/700 3 Stimulations&Treatments 't Vol Clean Pump Stg kTop(ftKB) Btm(RKB) Date Stim/Treat Fluid (bbl) Vol Slurry(bbl) SURFACE;28.0-6,744.7 1I 10,150.01 10,180.010/7/2003 <fluidname>,<fluidtyp> • Mandrel Inserts St GAS LIFT;8,128.8 ' eti I N Top(TVD) Valve Latch Port Size TRO Run Top(RKB) (RKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 3,133.4 2,595.7 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,233.0 9/13/2017 2 6,014.7 4,102.7 CAMCO MMG 1 1/2 GAS UFT OV RK 0.250 0.0 9/13/2017 11 3 8,126.6 5,207.7 CAMCO 'MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/27/2013 GAS LIFT;9,319.0 4 9,319.0 5,912.1 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 9/27/2013 ,1 5 9,956.9 6,390.9 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0/9/7/2017 Notes:General&Safety End Date Annotation 1/11/2011 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT;9,966.9 LOCATOR;10,016.8 SEAL ASSY;10,017.8 `�, PBR;10,021.3 Ni:- PACKER;10,035.9 NIPPLE;10,059.9 WLEG;10,087.0 ill ; FRAC;10:150:0_1n _I 101500-10180 PRODUCTION;26.0-10,428.7 OF 7v_ • • ,„.0" I//j� � THE STATE Alaska Oil and Gas 7 iffALAsKA n Conservation Commission tt}#x 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 ®F Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Sandeep Pedam Staff Completions Engineer ConocoPhillips Alaska, Inc. 5ARM ;F F' 0 6201-1 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1C-19 Permit to Drill Number: 203-054 Sundry Number: 317-390 Dear Mr. Pedam: 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, 06 Cathy 7 Foerster Commissioner DATED this 3)54day of August,2017. RBDMS /." SEP - 5 2017 • • RECEIVD STATE OF ALASKA 1 ,',-r. s .? ALASKA OIL AND GAS CONSERVATION COMMISSION O g , 5 (1 APPLICATION FOR SUNDRY APPROVALS A ) 7 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations 0 Fracture Stimulate El• Repair Well El Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well El Alter Casing ❑ Other:❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development 0• 203-054 3.Address: Stratigraphic CIService ❑ 6.API Number: P. 0. Box 100360,Anchorage,Alaska 99510 50-029-23149-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A KRU 1C-19 - Will planned perforations require a spacing exception? Yes 0 No 0/ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25649,ADL 28242 • Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10,435' • 6,794' , 10344 • 6716 . NONE NONE Casing Length Size MD TVD Burst Collapse Conductor 109' 16" 138' 138' Surface 6,717' 10" 6,745' 4,474' Production 10,403' 7" 10,429' 6,789' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10150-10180 , 6551-6576 3.500" L-80 10,068' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-BAKER SAB-3 PERMANENT PACKER W/MILLOUT EXTENSION ID MD=10036 TVD=6456 3.71" 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development D. Service ❑ 14.Estimated Date for 9/1/2017 15.Well Status after proposed work: Commencing Operations: OIL 0 ' WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Sandeep Pedam Contact Name: Sandeep Pedam Authorized Title: Staff Compeltion Engineer Contact Email: Sandeep.Pedam@cop.com Contact Phone: (907)263 4724 Authorized Signature: 40 dif , � Date:/� 76 COM ION USE ONLY Conditions of approval: Notify-ommission so that a representative may witness Sundry Number: 3t-7- 390 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No V RBDMS ip" SE.? - 5 2017 Spacing Exception Required? Yes ❑ No wr Subsequent Form Required: it — 4 b APPROVED BY Approved by: -fes COMMISSIONER THE COMMISSION Date : ig_3(._/7 114) 811 ii- vi-i- /3`)// A 01)4 a/►x/20/ 0 D liG4"imiig.i.,„IForm 10 403 Revised 4/2017 Submit Form and valid for 12 months from the date of approval. Attachments in Duplicate • • ✓ „ RECEIVED ConocoPhillips AUG 14 2017 Alaska, Inc. AOGCC Paul K.Wharton Staff Landman P.O.Box 100360—Suite ATO 1482 Anchorage,Alaska 99510-0360 Phone(907)263-4076 Pau I.K.Wharton@conocophi Ilips.com To: Operator and Owners (shown on Exhibit 2) Re: Notice pursuant to 20 AAC 25.283 (1) 1C-19 Well Kuparuk River Unit, Alaska ADL 28242, KRU Tract 37; and ADL 25649 KRU Tract 38 Dear Sirs: ConocoPhillips Alaska, Inc. ("CPAI") as Operator and on behalf of the Kuparuk River Unit ("KRU") working interest owners, hereby notifies you that it intends to submit an Application for Sundry Approvals for stimulation by hydraulic fracturing pursuant to the provisions of 20 AAC 25.280 ("Application") for the 1C-19 Well (the "Well"). The Application will be filed with the Alaska Oil and Gas Conservation Commission ("AOGCC") on or about July 27, 2017. This Notice is being provided pursuant to 20 AAC 25.283. The Well has been drilled as a directional well as shown on the attached plat (Exhibit 1). Exhibit 1 shows the location of the Well and the lands that are within a one-half mile radius of the current proposed trajectory of the Well ("Notification Area"). Exhibit 2 is a list of the names and addresses of all owners, landowners, and operators of record of all properties within the Notification Area. Upon your request CPAI will provide a complete copy of the Application to you. If you require any additional information, please contact the undersigned. Very truly yours, 62A44.4 K. Paul Wharton Staff Landman cc: Sandeep Pedam Rebecca Swensen • 1C-19 Hydraulic Fracturing Notice Letter July 27, 2017 Page 2 Exhibit 1 1C-11L1 1C-152 1C-153 i ADL025638 1C-154 '--- DL02-------- 1C-150 ,4155 West � Kuparuk PA i _ 1c-174 10170 ,C-11 35.1 Sak PA.( t Prudhoe 34) 701781.1 3 - ADL047449 Bay Unit 1C-178 !- 1 1C-11L1-02 1C-1111-0, 1G17\ II T1, R1JL_ - T-12NR11`� i AtL02 1C-07AL1 1C-07 4-06 Kuparuk 1G,sRiver ,c IAPB, 1c-07A Uni;c-22 1C-74A1Ct78L1PB21C-0AL1P81,C-0BL1 1 10-151 110-08.1981 1G770P81 ` 1414,. 10'15.1 1 /" 1C-08 1G178L1PB1 .G172 A1C-111 1C-18 ' 3' 1024.1-01 \\' ' ADL028242 39 •.0% \• \ )/3111 /�� 1C 15 1C-23 1C172kt2 ```\1\ � 1C-2511 �` 1 4 �1C-01 4 ��. 1C-23941 I X25 1C-119 1C-11J '�h IC-. ,1 1C-04 1D-143 1D-143L2L1C * , IC-01L1-02 14104941 10-172 •:�10-127 1C-121 f � 70133 1C-0111 101 1D-105A 10-07.1-01 ! 1C-27 1C-125 ' i 1C-123 24 `i 1110.1 111110.4,3 11.1-03 1G21L2 1C-21L1------,1e,281C-03 1C-102.1 ilC-102 1,C-109.1`+1C-109 1C-02 1 1C-21.3 1G172At2PB2 1 f 1C-I1311I\ I C'28P4) 1C-104.1 1C-104/ ---- � 1C-172A 1C-172AL1 tel(:2011 1C-21 1C-10 I ,420 \1C-26 1C-20941 14190 1C-184 1C-12 1M ADL025650 56' 1c•135Pe1 I ADL025243 0 • Frac Points D0 1NR10E , 11NR11E s , -Well Trajectory 1C-135 -Wel Open Interval n Half Mile Frac Point Radius n Half Mile Tmlectory Radius . Wells within Trajectory Radius L ; Kuparuk PA N ConocoPhillips L West Sak PA Alaska,Inc. — • `._.rAKUnit 1C-19 KRU_Lease_Tracts 0 0.2 0.4 0.6 o.8 1 Lease Plat 5661 Miles CPAI Leases I 7/25/2017 1C-19 Hydraulic Fracturing Notice Letter • July 27, 2017 Page 3 Footages Location FNL FEL Township Range Section Meridian Surface 1615' 3922' T12N R10E 12 Umiat Boundary#1 5280' 2739' T12N R10E 1 Umiat Boundary#2 4888' 1106' T12N R11E 6 Umiat Top Open Interval 1055' 4855' T12N R11E 6 Umiat Bottomhole 926' 4776' T12N R11E 6 Umiat • 1C-19 Hydraulic Fracturing Notice Letter July 27, 2017 Page 4 Exhibit 2 Mineral Owners: Operator: ConocoPhillips Alaska, Inc. 700 G Street, Suite ATO 1220 (Zip 99501) P.O. Box 100360 Anchorage, AK 99510-0360 Attention: Erik Keskula, Manager, NS Development Non-Operators: BP Exploration (Alaska) Inc. P.O. Box 196612 900 E. Benson Boulevard (Zip 99508) Anchorage, AK 99519-6612 Attention: Mr. John Dittrich Chevron U.S.A. Inc. 1400 Smith Street Room 40116 Houston, TX 77002 310 K Street, Suite 406 Attention: Mr. Dave White ExxonMobil Alaska Production Inc. 3700 Centerpoint, Suite 600 P. O. Box 196601(Zip for PO Box 99519) Anchorage, AK 99503 (Street zip) Attention: Mr. Jamie Long Surface Owners: State of Alaska Department of Natural Resources Division of Oil and Gas 550 West 7th Avenue, Suite 1100 Anchorage, AK 99501-3560 Attention: Director i TO THELASKA OIL AND GAS CONSERVATION COMMISSION Before the Commissioners of the ) Alaska Oil and Gas Conservation ) Commission in the Matter of the ) AFFIDAVIT OF Paul K.Wharton Request of ConocoPhillips Alaska, Inc.for ) Hydraulic fracturing for the 1C-19 Well ) under the Provisions of 20AAC 25.280 ) STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) Paul K.Wharton, being first duly sworn, upon oath, deposes and states as follows: 1. My name is Paul K.Wharton,and I have personal knowledge of the matters set forth herein. 2. I am Staff Landman for the well operator, ConocoPhillips Alaska, Inc. ("CPAI") 3. Pursuant to 20 AAC 25.283(1)CPAI prepared the attached Notice of Operations("Notice"). 4. On or about July 27, 2017, CPAI sent a copy of the Notice by certified mail to the last known address of all other owners, landowners,surface owners,and operators of record within a one-half mile radius of the current proposed well trajectory. Subscribed and sworn to this 27th day of July, 2017. 614 X. e-a Paul K.Wharton STATE OF ALASKA ) ) §§ THIRD JUDICIAL DISTRICT ) This instrument was acknowledged before me this 27th day of July,2017, by Paul K.Wharton. "AA S Cti-eAn Notary Public, State of Alaska My Commission Expires: STATE OF ALASKA .. NOTARY PUBLIC REBECCA SWENSEN 417/.74, M Commission Ex.res A27,27,2020. • • Section 1 - Affidavit 10 AAC 25.283 (a)(1) Exhibit 1 is an affidavit stating that the owners, landowners, surface owners and operators within one- half mile radius of the current or proposed wellbore trajectory have been provided notice of operations in compliance with 20 AAC 25.283(a)(1) Affidavit 0 • Section 2 - Plat 20 AAC 25.283 (a)(2) Plat 1:Wells within 0.5 mile IC-110 tC IL?v-l'' ! ADL025638 s 154 'r.:- 10,150 IC IS.,.. west I Kuparuk PA 1c-174 ic-inlc 1, ,- , Sak PA I ; i Prudhoe 34 lc rireliii i 1 ,00e- i ADL047449 Bay Unit 1C-178 # ! 1 1C 111 1 02 lc Ho(-1 1C-1/ i , AIL02 Iri t, IC,C7k1 ,c„..0 '',C 0i i ' Kuparuk River lc 7Apcp tcom lc 14.4 Unit:... Irc:1,78LIPE12 1C-0?A,_.P01 (.IC-rk_it \ IC-151 L,.....\\CCe1.1191 i IC-170PSI \114, , I 1r,14 , ipp K-45, 1^7-ON i IC-,17,3L1PB1 i r,,7, ,,!r AM-028242 11,23 N. at v ;,.. 4, 1 ir 76 . ..........—_,,ammigE2,PRIW •"' —.... I ML*-04I.,'143 i 'L. le 1111 1 ( Tr.. ic464psy 1 C-,T2ALF,B1 'IC'' \ ill iir It,133 1•C,0 LI 4'.---„,.: 1C-12: .C-010 Oi likk,,,1/4 -K,1-211. Ic.., 4 ic 123 Az 00,14 . ,L,02 i . /- ,e,„ 11 IC-03 tc,-IO2L1 i'.,.. IC Nt I-10 111,32 I 1C-172Ac2$42 IC-104L1 1C-104f I I I\ i 1C'3 1 IC 21 IC I72A ic.1?2A0 1. ...,,, ,,'q€ i Ic XPEI : 1C-1W I ADLO25650 56 1C-135P11t t i ADL028243 • Frec Pcnntsi — 1 1NR-10E 1 T 1 1 NR 111 E 57 *I:- IA:ell Trajectory tC-••35 ...............Well Open Interval I. i Half Mile Frac Point Radius Half Mile Trajectory Radius I Wells imettin Trajectory Radius L.,.._,,i Kuparuk PA N ConocoPhillips West Sak PA A A aska,Inc ' •1AK Unit i C-'1 9...-.1 - KRU Lease Tracts 0 0.2 0.4 0.6 0.6 1 Lease Plat 5661 -., r 1 CPA!Leases Miles 1 7/25/2017 • i Table 1:Wells within 0.5 mile Wells within 0.5 mile buffer of well track * Data from SDE layer: AK_WELL_BOTTOM_TD_ATDB_DD83 API WELL NAME Well Type Status 500292052600 1C-01 PROD ACTIVE 500292052660 1C-01L1 PROD ACTIVE 500292052661 1C-01L1-01 PROD ACTIVE 500292052662 1C-01L1-02 PROD ACTIVE 500292052663 1C-01L1-03 PROD ACTIVE 500292053200 1C-02 PROD ACTIVE 500292053500 1C-03 PROD PA 500292053501 1C-03A PROD ACTIVE 500292054700 1C-04 PROD PA 500292055000 1C-05 INJ ACTIVE 500292056400 1C-06 INJ ACTIVE 500292056900 1C-07 PROD PA 500292056901 1C-07A PROD ACTIVE 500292056960 1C-07AL1 PROD ACTIVE 500292056971 1C-07AL1PB1 EXPEND PA 500292056970 1C-07APB1 EXPEND PA 500292058500 1C-08 PROD ACTIVE 500292058560 1C-08L1 PROD ACTIVE 500292058561 1C-08L1-01 PROD ACTIVE 500292058570 1C-08L1PB1 EXPEND PA 500292085900 1C-09 INJ ACTIVE 500292086500 1C-10 INJ ACTIVE 500292303700 1C-102 PROD ACTIVE 500292303760 1C-102L1 PROD ACTIVE 500292307600 1C-104 PROD ACTIVE 500292307660 1C-104L1 PROD ACTIVE 500292307670 1C-104PB1 EXPEND PA 500292304700 1C-109 PROD ACTIVE 500292304760 1C-109L1 PROD ACTIVE 500292271400 1C-11 PROD ACTIVE 500292302900 1C-111 INJ ACTIVE 500292302700 1C-117 INJ ACTIVE • • 500292303400 1C-119 INJ ACTIVE 500292271460 1C-11L1 PROD ACTIVE 500292271461 1C-11L1-01 PROD ACTIVE 500292271462 1C-11L1-02 PROD ACTIVE 500292271900 1C-12 PROD ACTIVE 500292301500 1C-121 INJ ACTIVE 500292301600 1C-123 INJ ACTIVE 500292304400 1C-125 INJ ACTIVE 500292302400 1C-127 INJ ACTIVE 500292285600 1C-13 PROD ACTIVE 500292304100 1C-131 INJ ACTIVE 500292301300 1C-133 INJ ACTIVE 500292305300 1C-135 PROD ACTIVE 500292305370 1C-135PB1 EXPEND PA 500292286100 1C-14 INJ PA 500292286101 1C-14A INJ ACTIVE 500292293200 1C-15 INJ ACTIVE 500292349600 1C-150 INJ ACTIVE 500292349700 1C-151 PROD ACTIVE 500292354800 1C-152 INJ ACTIVE 500292354900 1C-153 PROD ACTIVE 500292355900 1C-154 INJ ACTIVE 500292356100 1C-155 PROD ACTIVE 500292293260 1C-15L1 INJ ACTIVE 500292293400 1C-16 PROD ACTIVE 500292287200 1C-17 INJ ACTIVE 500292315400 1C-170 PROD ACTIVE 500292315470 1C-170PB1 EXPEND PA 500292315900 1C-172 PROD PA 500292315901 1C-172A PROD ACTIVE 500292315960 1C-172AL1 PROD ACTIVE 500292315961 1C-172AL2 PROD ACTIVE 1C- 500292315970 172AL2PB1 EXPEND PA 1C- 500292315971 172AL2PB2 EXPEND PA 500292314000 1C-174 INJ ACTIVE 500292314400 1C-178 PROD ACTIVE • • 500292314460 1C-178L1 PROD ACTIVE 500292314470 1C-178L1PB1 EXPEND PA 500292314471 1C-178L1PB2 EXPEND PA 500292293900 1C-18 INJ ACTIVE 500292315500 1C-184 PROD ACTIVE 500292313600 1C-190 INJ ACTIVE 500292327300 1C-20 INJ ACTIVE 500292327370 1C-20PB1 EXPEND PA 500292325300 1C-21 PROD ACTIVE 500292325360 1C-21L1 PROD ACTIVE 500292325361 1C-21L2 PROD ACTIVE 500292325362 1C-21L3 PROD ACTIVE 500292312700 1C-22 INJ ACTIVE 500292294200 1C-23 PROD PA 500292294270 1C-23PB1 EXPEND PA 500292306300 1C-24 PROD ACTIVE 500292294100 1C-25 INJ ACTIVE 500292294160 1C-25L1 INJ ACTIVE 500292294400 1C-26 INJ ACTIVE 500292294300 1C-27 INJ ACTIVE 500292327000 1C-28 PROD ACTIVE 500292327060 1C-28L1 PROD ACTIVE 500292327070 1C-28PB1 EXPEND PA 500292284301 1D-105A PROD ACTIVE 500292352800 1D-143 PROD ACTIVE 500292352861 1D-143L2 PROD ACTIVE • • Section 3 - Freshwater Aquifers 20 AAC 25.283(a)(3) There are no freshwater aquifers or underground sources of drinking water within one-half mile radius of the current or proposed wellbore trajectory. None as per Aquifer Exemption Title 40 CFR 147.102(b)(3), "That portions of the aquifers on the North Slope described by a 1/4 mile area beyond and lying directly below the Kuparuk River oil and gas producing field". / • • Section 4 - Plan for Baseline Water Sampling for Water Wells 20 AAC 25.283(a)(4) There are no water wells located within one-half mile of the current or proposed wellbore trajectory and fracturing interval. A water well sampling plan is not applicable. • • Section 5 - Detailed Cementing and casing information 20 AAC 25.283(a)(5) All casing is cemented in accordance with 20 AAC 25.030(b) and tested in accordance with 20 AAC 25.030(e)when completed. See Wellbore schematic for casing details. ! • Section 6 - Assessment of each casing and cementing operation to be performed to construct or repair the well 20 AAC 25.283(a)(6) Casing &Cement Assessments: The 7" casing cement pump report on 05/12/2003 shows that the job was pumped as designed, indicating competent cementing operations. The cement job was pumped with 50 bbls of 15.8 ppg Class G with additives. The pump bumped at 500 psi and floats were checked and they held. TOC was estimated at 9281'. 1C-19 did not have any documented losses while drilling. Summary All casing is cements in accordance with 20 AAC 25.030 and each hydrocarbon zone penetrated by the well is isolated. Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successful fractured within design limits. • i Section 7 - Pressure test information and plans to pressure test casing and tubings installed in the well 20 AAC 25.283 (a)(7) 20 AAC 25.283. Hydraulic fracturing (a) Before hydraulic fracturing, the operator must submit an Application for Sundry Approvals (Form 10- 403) under 20 AAC 25.280. Unless modified or altered by pool rules established under 20 AAC 25.520, the application must include (7) pressure test information if available and plans to pressure-test the casings and tubing installed in the well; On 05/08/2003 the 9-5/8" casing was tested on rig to 2500 psi prior to drilling the production hole. This well has an open OA shoe and was previously permitted for annual disposal. No current pressure test data is available due to the open shoe. On 09/27/2013 the 7" casing was pressure tested to 2500 psi. On 09/27/2013 the 3.5"tubing was pressure tested to 3000 psi. It will be tested to 4,140 psi prior to the fracture job. Table 1: Required Pressures AOGCC Required Pressures [all in psi] Maximum Predicted Treating Pressure (MPTP) 5,395 Annulus pressure during frac 2,500 Annulus PRV setpoint during frac 2,600 Annulus pressure test 2,750 Tubing pressure Test 4,140 Nitrogen PRV 5,795 Highest pump trip 5,595 • • Section 8 - Pressure ratings and schematics for the Wellbore, Wellhead, BOPE and Treating head 20 AAC 25.283(a)(8) 20 AAC 25.283. Hydraulic fracturing (a) Before hydraulic fracturing, the operator must submit an Application for Sundry Approvals (Form 10- 403) under 20 AAC 25.280. Unless modified or altered by pool rules established under 20 AAC 25.520, the application must include (8) accurate pressure ratings and schematics for the wellbore, wellhead, BOPE, and treating head; Size Weight Grade API Burst API Collapse 9 &5/8" 40.0 L-80 5,750 psi 3,090 psi 7 26.0 L-80 7,240 psi 5,410 psi 3 &%2" 9.3 L-80 10,159 psi 10,533 psi Table 2: Pressure Ratings • • Stimulation Surface Rig-Up Bleed/Tattle Tale Tani, •' - • �' i1 2 t1 11 un 0 D8(31444 1[Tal C5 R da ti 11 E Nr ` 3111J l dwnd Pop•OB Tads ---( � — Pump Truck Pop-Off Tank ary 05 co 41 2.1 �Z> dcn. �� T d , Frac Pump {=x} is ' . Frac Purnp w Frac Pump ` . 4y Oy'rj' Frac Pump Frac Pump NJ 4 I'! (r-A Frac Pump • !II Tree Saver With Wellhead rI OIL STATES PROPOSAL Energy Services (Canada) inc, QUOTE#: DATE: Maximum Allowable Pumping Rates SIZE ID OD RATE in'iniin CSG 2.250 3.750 10 m3imin 3 1/2"Big Bore 1.750 2.750 6 tre/min 2 7/8" &3 112" 1.438 2.360 4 resimin 2 3/8" 1.000 1.9002 relmin ..._ . .................____ 3 1/16&4 1116 with tapered mandrel 2.750 4,000 16 eirnin 4 1/16 X Tool Mandrel 3 610 4,760 24 m3/m In OPEN POSITION CLOSED POSITION NJ MAI k 4 4,..t it N IkWat.wst Ortu,114 ) Nwomn.novwto ( ( ,4144104 VA1101 '...1) , 1 42." rm.. 1,ir ( '.'- *5 ,avaterx 1 1111 nom(IMMO /mum wevi 2gli , 0 T L. — i . t-k 1 . j,. ..i , I 414....-= .', / V,4 4 L"1 I h ,J14,410 at ARV /4 4t ill rt.*vom wattomit V00.11 On§ 'A. %WHIM§ i YAMS- 1., Of t411$ ' at IkAtl, ,i.: I tt 041000,10 04 run 04 NOM 1 KO tslit*MG. c; 1;,' vvww.osescanada.com Pressure rating: 15,000psi • • Wellbore schematic - . KUP PROD 1C-19 ConocoPhillips 41111;i:,\Well Attributes MaxAngle&MD TO / tldd Nr.. Won..tauana.1 NI E. .1111,...1111,... .3.29. 2. .__ <.FYaK. - R:E ' R LINT FRi:,C 43 5 356 23 .12.435.2 ... 4..1 HE151,RVnt L An•.#lfw krt,L22 AA-L..1!n4IR14.I.a.t --- a'. 47.4 53 9'C.:- JI ..:. _kW4EMNE 1.,[t.4 MW41 41,4 E....1. L]ETE:SKS 'p,'43.2 50322 Rn,45410+ 1-22.-AC ,.Sr:., ____3t Casing Strings g..Lrwryeffien .AI1,-! IU11,11 w 11IK4,1 :r:cpm 14451 ]..Jgin 11.41 .11 i- ..{r.;:.•..., 7?1 22,5342-2,.. 'S 25: :92 30 13 3 42-C rt.3 ,,SELL OC R e-e'a I:aw w i web', .c IManl ]e1).p.m rnnnr w Jnem 11 vL JR,.E c1,'+ 4.8 S. 6..14 4, 1 4.3321193 E'2k' 1. ' Tu .•p P 1, tL 1 1 1 1 s .kPn 3 4214 itl JqM 11 W rr ...•wr: P,�T E 0 .E 4 711 $-S3 4,22.! g Stenos 'lPV.n v. IL 111,1 1.,.e.1fP:1t S.rms..52 k 194`4* 1 I vy,w:vi4.r 1E1 ti Completion TLfi'N3eti 2.5-12 229a 12,3_ 1 :. 1._2 242 129-13] Camp et on tletais '••.• 1,4x4 awyu.>suww.mAu T.IV.•14 -p lT.it augl1 T.Pld.t r', n.li+oo MI .c....?, Ilei 32 223 1 CCO.L{µ3E!9 GE1, C,'_SRNh0C-44.` s�N.. 252 SC3 2 2.74 NIPPLE 414 E cawCticraR aalv 1: ICfi 6:142. 34 Si C.{'-DR B{ -22,-3S 9C 'y C.217.4 5,+.422 24.57 _El{CC3 BAKE 42,3 _ .92 ■ .;;t6.7,1.-;;":7„.; t Ja.n4I's, tW1 W 'L"1.,,,11-'711.3''',71'-‘,--- L 1 1 _ ] Lw*+.S Lelk4 9 t mal. 133''''''' 176NG Dr;Ira' 9 .+_.l ._'.3 1.357.E E-'4.12.. "''''' wmu.arr:l I Completion Oetais :.1 jY I.,34+.C. P upP+2144291 I.pI.d r. inn on ) 3 CGt3 ,.I.,^.CC_I 1,443 3 34.EE FBF 6{4'44{r:C PER ER it RG 214412:f5{.^.CCPD O.1-4 FER"' 2224 E_14 34.42 TACKER fiMCR 5E-3 PERI.3•{NENTF{„KER M'41104=- 3.714 EATEN 122 C 3 1' vL,C34'.i !.L'3' 34.2 11271.E C,VAL`O 72225E t*NC GCI:.?S Iv FRC=tLE _ .. C16b U1'.]luH 12,2570 6,-8'.4 34.2'1,LE3 6{KP:C;iRELINE EµTRY 3L CE 9994 Perfora66ns.&Slots '7;7'41' W f7.51i Em I[1, r .,1.,1.131 44.51 1/M21I 7RF ■ 3.'42: 12:'579 £,?47.5 6,_75.8 C-L 12,1 2.15_333 4.0 IPERF CS 522 NYPERlE-.2S. ..A...1 Stimulations&Treatments nmirti..Js4M.i In, I npp.d..19.,1.3..1141 Lot, _-".333 Stimetatwns&Treatments S.4i µ:;,1n91 etre 1111,..41 1141 .-.1-. .....r.t11.1. .c en. •._lust.-I. `n.1E3.3 ^C'143.3 E3'.CC3 sJltF*t, EEX44.1- Mandrel Inserts 'Pp2LI .a,. I.b1. 3b119{w 17'115 Nan ,- ',EV1llntii `11W�1 NA. Nudd :.0 nnl a.t. 1.p. lyp 11,11 3x1, _ OASLIU,WS.II 't .333 243E7 05510 bN:IG 3{2_' C',. FI*. 2.210 2.3 1_42:0 1 4.2147 4,12,27 0523 Aq.:, 2 0{ C. FK C.2E0 0.3 1_'2C'i IIa B 121 0077 \5410 .411 _ {__' OLP' €K C203 2.3 3 22 1 3 3.3152 S.9,:121 :AV= 1.714_ ,0.{:_r DWI'' FA: [272 C3 3 _ . i =t__= 4..523 2.•..:•. “i.,0 - _:a'.: DIV' Ft: C.22,2 ..7 23 2C _..e ,319.1. Notes:General&.Safety cl.LEat S...mwl, ' +._'_ .t..oer..3.c a 131121 21Ir4L 03.3 111 G.1.411 44ana II LOLA MR.1401164 ...at AS.:Int/F71, Ma:3.1214 11"0414,1 Ia.!, . MEM....a1Gs4 III 5414100510 j'. r1118.1a1ni n I I 1,i.pl 411]6.Ir Is 4-11 .L 2::�11MLS6]n.:x.i- 0 • Section 9 - Data for Fracturing zone and confining zones 20 AAC 25.283(a)(9) CPAI has formed the opinion based on seismic, well and other subsurface information currently available that: the Kuparuk interval is approximately 410'TVD thick, with the top picked at 10,085'MD/6,410' TVDSS. The entire Kuparuk interval was not penetrated in this well so there is no pick for the base Kuparuk.The Kuparuk interval thickness is derived from a correlation with offset wells.The Kuparuk Interval is composed of fine-grained sandstones, siltstones and shale interbeds. The estimated fracture gradient for the Kuparuk interval is 12-14 ppg. The overlying confining zone consists of greater than 400'TVD of Lower Kalubik, Upper Kalubik and HRZ mudstones. The fracture gradient for each of these zones is estimated to be 15-16 ppg. The top of the HRZ was encountered at 9565'MD/5998'TVDSS. The underlying confinement zone consists of greater than 500'TVD of mudstones comprising the Miluveach Shale. The Top Miluveach was not encountered in 1C-19 but is estimated at 6820'TVDSS based on offset well thicknesses where the entire Kuparuk interval was penetrated.The estimated fracture gradient for the Miluveach Shale is 15-18ppg with fracture gradient increasing with depth. Stress orientation in 1C-19 is interpreted to be approximately North-South and we expected the fractures to propagate parallel to this maximum stress direction. If there are indications that a fracture has intersected a fault during fracturing operations, ConocoPhillips will go to flush and terminate the stage immediately. CPAI has formed the opinion, based on seismic, well and other subsurface information currently available that the apparent faults will not interfere with containment. • • Section 10 - Location, Orientation and a Report on Mechanical Condition of Each Well that may Transect Confining Zone 20 AAC 25.283(a)(10) The plat shows the location and orientation of each well that transects the confining zone. ConocoPhillips has formed the opinion, based on the following assessments for each well and seismic, well, and other subsurface information currently available that none of these wells will interfere with containment of the hydraulic fracturing fluid within one-half mile radius of the proposed wellbore trajectory. Casing&Cement assessments for all wells that transect the confining zone: 1C-06 No reports of lost circulation while drilling this well.A CBL was run on 03/21/1981 indicating top of cement at 5226' MD.The report on 3/20/1981 from the 7" casing cement job states 173 bbls of 12.3- 14.3 ppg Class G cement was pumped while reciprocating.The plug was bumped to 3000 psi, okay, bled back, and floats holding okay. PTD 181-025 1C-16 No reports of lost circulation while drilling this well. Previously permitted as an annular disposal well. The report on 12/30/1998 from the 7" casing cement job states that it was pumped as designed while reciprocating with good returns throughout.A total of 65 bbls of 15.8 ppg Class G cement was pumped. The plug was bumped and a pressure test on the casing to 3500 psi for 30 min was good.They bled off pressure and floats checked okay.Top of cement was calculated at 10800' MD. PTD 198-246 1C-19 No reports of lost circulation while drilling this well. Previously permitted as an annular disposal well. The report on 05/12/2003 from the 7" casing cement job states that it was pumped as designed. A total of 50 bbls of 15.8 ppg Class G cement was pumped. The pump bumped at 500 psi and floats were checked and they held.Top of cement was calculated at 9281' MD. PTD 203-054 1C-155 No reports of lost circulation while drilling this well.This is a West Sak well. It does not penetrate below the West Sak D Sand.The 9-5/8" intermediate casing was cemented on 10/20/2015.A total of 187 bbls of 15.8 ppg Class G cement was pumped with full returns and the plug was bumped.The calculated top of cement was 3758' MD. A 4.5" openhole standalone screen was run through the D Sand production interval with packer set at 6188'. PTD 215-180-0 • • O -a - -0 u a) m in a) � Ln co s—I co r1 co o O co r-I 'E , - O Q 0 Q N us N Q O NI V OA Q a N Q LO , O Q CT a) ~ N N L- H F., a) CO Q) ro cu Oo _a sn- n. 0O s- ,�.., N Q o_ a) O o `N p N p , �0 00 _ E_ E Ln _ a) C >' fo v) Lil U d COvl f6 U Ln ' N m Q IV 7 ° 0 ° ' LL -a o CC _, VI m w a) • } co a , o ra v o o v -C 0 E U vi Q c Q. N Q O - 22 N d CO O -O Y -O cio O of L • E• co E E -7-, 00 E E -o v -0 m V b i a°1i o o o a, o N v CO < a) v Ln o c v N Ln o _ _C oo a) U 0 In 0_ -o c--1 0 .0 co 0 .0 r-i s00 IZ U 00 U U +., Q a.., r-I U i Q Z co Y ca Y co oo c 3 C 4-, 0 4-' (.) +• N il) +., vl 0 O a) a 0 a co 0 a) rv-I m to a) o o E o E o 2 E o a o v 0 o " m U g 0 co ,_' u ,_ nr, co "- 0 4- Ln `~ o a, C CC o " cn i0 O O O �O ,-i O O Y 00 a) v) C o_ co r-I o_ N rn o_ co c..o Q E o 00 C a, o O N i O N }, 0 0 CO (1) r-I () a) N H Ol co H Ln co H ,-I o_ U lO 3 C2 > to U, C C C C C a) C i 0 0 0 0 pa) C L O 0 �, co O v cc0 O p ro O v C C C 0 p o C C O C U O C C C -0 a) O in tea i a) p i a) a) i a) p Q CC a p a) +, v n. a) o_ a) o_ L c) 2 cc N co.. o o_ o_ o .c o_ o o_ 0 V o. a) -p -0 -0 C a) a) a) + 4-' + ,} C4-, 4-+E ca co co o 0) D n = v o_ E 0 o 0 a o a) a) >- co co co co H o "a C U U U U Z 00 0 co00 O c \ ccc C co co G C NO O00 \o_ E co CO \ N CO CO \ Q O a) N i Ln N i . 0 (-,4 N c-i I— U Cn 0 0 if) O m r-i c-i m r-I Z O Cl- lO r-I Ln l0 I ) 0 01 o_ 0 c-1 szt c-I c--I d- LO r-I N O 0 0 Ln Ln v--I if) N 00 H o_ c-I Qo CT QD .-i Q0 s..0 m CO OA C Co - N .N U - o ra N II) -' ill• 0 0 U v )N N N as c Ct 0_ N v) O -0 -0 "0 CC ° A.O O N d c ca. 4 If) a) Ql lO lO ill E c-I 0 r-I N--1a) co Z • • Section 11 - Location of, Orientation of and Geological Data for Faults and Fractures that may Transect the Confining Zones 20 AAC 25.283(a)(11) CPAI has formed the opinion, based on seismic, well and other subsurface information currently available that there are six seismically-mappable faults transecting the Kuparuk interval with a 1/2 mile radius of the frac point; however,the 1C-19 wellbore itself doesn't intersect any of these faults. One mapped fault within the half-mile radius is intersected by the 1C-06 wellbore in the Kuparuk interval, approximately 950'to the SW of 1C-19. No losses were encountered during the drilling of 1C-06. Seismic data indicates all faults terminating within shales in the overburden. 1C-19 Area Faults Orientation Representative Throw Fault#1 West-East 15' DTN Fault#2 North-South 30' DTE Fault#3 ' North-South 35' DTW Fault#4 North-South j 40' DTE Fault#5 West-East 100'DTN Fault#6 West-East j 20' DTN I • Plat 2: 1C-19 Fault Analysis est Kuparuk PA ; 1C-155 1 35 k PA; Prudhoe A01.025638 ADL04740 Bay Unit 16, i 4ANNI-ft, 11611k41 11.‘ 1C,t01 111, Kuparuk ff; Rivernit Unit 41f 4 - ADL025649 ADL0282,12 38 IC ADL.025650 • Frac Points ADL028243 Well Trajectory Well Open Interval 1-1 Half Mile Frac Point Radius El Half Mile Trajectory Radius Faultsl,vithin Frac Point Radius - Wells within Frac Point Radius LJ Kuparuk PA N ConocoPhillips West Sak PA • •AK Unit Imo•im•i 1C-119 KRU_Leasejracts 0 0.2 0.4 0.6 0.8 1 Frac Plat 4361 61Miles CPA'Leases 811/2017 • Section 12 - Proposed Hydraulic Fracturing Program 20 AAC 25.283(a)(12) Well 1C-19 was drilled and completed in 2003 as a slant producer in the Kuparuk C sand formation. The well was completed with 3.5"tubing and a 7" production casing with perforations.A single stage fracture job was also performed in 2003.A rig workover was completed in 2013 to pull and replace corroded tubing, in kind.A single stage refracture job is proposed to be pumped through the existing perforations. Proposed Procedure: Halliburton Pumping Services: (C Sand Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre-frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000'TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 6 clean insulated Frac tanks,with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 100° F seawater(approx. 2,242 bbls are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU HES Frac Equipment. 7. PT Surface lines to 9,000 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Pump the 45 bbl breakdown stage (25# Hybor) according to the attached excel HES pump schedule. Bring pumps up to maximum rate of 18 BPM as quick as possible, pressure permitting. Increase annulus pressure to 2,500 psi. Ensure sufficient volume is pumped to load the well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 11. Pump the Frac job by following schedule with a maximum expected treating pressure of 5,395 psi. • • Section 13 - Post-Fracture Wellbore Cleanup and Fluid Recovery Plan 20 AAC 25.283(a)(13) Flowback will be initiated through a third party flowback vendor until the fluids clean up at which time the well will be turned over to production. Flowback fluids will be taken to the appropriate disposal well until they are clean enough for the production facilities. • KUP PROD • 1C-19 Cono(coi hillips 01 Well Attributes Max Angle&MD TD Alaska,leo. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) mr,000sKv,,R! 500292314900 KUPARUK RIVER UNIT PROD 60.17 5,856.23 10,435.0 ..- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1C-19,5/23/20I7 10,40:27 AM SSSV:NIPPLE 50 9/10/2016 Last WO: 9/27/2013 34.70 5/13/2003 Vertical schematic(actual) - Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:RKB 10,149.0 5/20/2017 Rev Reason: H2S,TAG pproven 5/23/2017 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread HANGER;22.9- CONDUCTOR 16 15.062 29.0 (38.0 138.0 62.50 H-40 WELDED 00 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.835 28.0 6,744.7 4,474.1 40.00 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...-Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 26.0 10,428.7 6,788.6 26.00 L-80 BTCM ♦ �r Tubing Strings - Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING WO 3 1/2 2.992 22.9 10,029.5 6,450.5 9.30 L-80 EUE-8rd I '; Completion Details ,, taut Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(.) Item Des Com (in) 22.9 22.9 0.00 HANGER GEN IV TUBING HANGER 2.990 509.2 509.2 0.78 NIPPLE 2.875""DB"NIPPLE 2.875 CONDUCTOR;29.0-138.0 10,016.8 6,440.1 34.68 LOCATOR BAKER LOCATOR 2.990 11 10,017.6( 6,440.8 34.67 SEAL ASSY BAKER 80-40 SEAL ASSY 2.990 II Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING Original 5.9 3.000 10,021.3 10,067.9 6,4822 NIPPLE;509.3 Completion Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl 7) Item Des Com (in) 10,021.3 6,443.8 34.66 PBR BAKER 60-40 PBR/SBR'""TUBING STRING HAS OD/ID 3.000 OF THE PBR**** 10,035.9 6,455.8 34.52 PACKER BAKER SAB-3 PERMANENT PACKER w/MILLOUT 3.710 EXTENSION ID 3.71" 10,059.9 6,475.7 34.27 NIPPLE CAMCO D NIPPLE wl NO GO 2.75"PROFILE 2.750 GAS LIFT;3,133.4 10,067.0 6,481.5 34.20 WLEG Top(TVD) Btm(TVD) BAKER WIRELINE ENTRY GUIDE 3.000 Perforations&Slots Shot Dens (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zane Date t) Type Com P10,150.0 10,180.0 6,550.6 6,575.8 C-4,1C-19 6(18/2003 4.0 IPERF 2.5"HSD,2 SPF HYPERJET,4 SPF POWERJET GAS LIFT;6,014.7 Stimulations&Treatments Proppant Designed(lb) Proppant In Formation(Ib) Date 10/7/2003 Stimulations&Treatments Vol Clean Pump Stg# Top(ftKB) Btm(ftKB) Date Slim/Treat Fluid (bbl) Vol Slurry(bbl) 1 10,150.0 10,180.0 10/7/2003 SURFACE;28.0-6,744.7-+ Mandrel Inserts St ati on Top(TVD) Valve Latch Port Size TRO Run N Top(RKB) (ftKB) Make Model OD(in) Sent Type Type (in) (psi) Run Date Com GAS LIFT;8,126.6 1' 3,133.4 2,595.7 CAMCO MMG 11/2 GAS LIFT OV RK 0.250 0.0 12/2/2016 2 6,014.7 4,102.7 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.250 0.0 12/1/2016 3 8,126.6 5,207.7 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/27/2013 4 9,319.0 5,912.1 CAMCO MMG 1 1/2 GAS LIFT 'DMY RK 0.000 0.0 9/27/2013 51 9,956.9 6,390.9 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/27/2013 GAS LIFT;9,319.0 Notes:General&Safety End Date Annotation 1/11/2011 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT;9,956.9 LOCATOR;10,016.8 SEAL ASSY;10,017.6 I .i PBR;10,021.3 PACKER;10,035.9 NIPPLE;10,059.9 E@ WLEG;10,067.0 ; FRAC.;10,150.0 09IPERF10 150 0-10 180 I� y PRODUCTION;28.0-10,428.7 0 • s 4 R '4 4 22 a R W R w9 d cxE bcxE caxE ExE - 8 g a@J„ oUu oau E s E 2 2s .. mg E Po9 ,z p O O O 9 Y i K1 U x x x 8s F E �$x _ - .- g-"L, E n a y W o ¢`. U c - a ¢ a a 222 2 2 i3 !aq O 2 Z Z Z Z Z 2 w i m p 4 B' a II m ,2RAEL,A 'LI 70 Ea E c oli x91..2-9.w` g LL E o.� o a . „ _ .,,;00„0. o o 0,�,o r,o,o 0 0 C LL 8x -- ,°,1,i E C D ti 2 n n m '� r a m 13, '1- ti ., n r .-i .� - g 14 1 E E o s o U •i' 22 03(-1 3 3 3 cc 3 0 3 3 3 n v, 8 A 0= E '�^ ` m 2 mm - a - -.°, - z 4 z z 4a W z 2 gAM.% .p o '1.' as m" m m m Tr, 9 R n. 9 mg4d 9 5m N�m d'�°- o u<NE a "6.3 .3 y Si 2 W7 a n a a zgy.s_m a - ,c-omn onnn 11.:§TE v 2 a mc, w p m r 741, ?a a N _ c o - Ig m - 2 PE p c= Ag' 8. .1 m4 .v a ro- E - N E Syys o� vc \"o in$ c 2- E c - IT g.EY. 2 .m •amo co 1.52 2),1! ,21 0 ill o 0 0 3 0 5 4 E m '^ E9 c n 7 c E rvi1T o C '1' v m um m - - a - Eb ._ Ec o E0, .� v aEEEuu rn� o'Er iNm 2 `m m a 's a a m ,'E .. a _;0, t ort` _ E E E E E E S 2C -.7,.. .m ;c p .. E g m 7-.' m o v .t E m o w W;011 g. a gaaa"--v--a - a E 2 EE .n '.n .� , ,_n a a vv v c�iii2z aNu�m°v°imv°i3 'aN E m .L- 4' o m`v c m 5 o E a_ <r g r y a c o f •,,, _ v > C o`OA ` m O m "i mo ` - s �$ a a 2 E= o a y Pi; 2 t o t .cu m y l'. a 5 E my 'O J h mr ' m y . ro ao a o x m mS o E m m v U z n ` c7 a a !N7-_ LL 5 uc v ..v o• do= c _ . c SE o Pi 3D cc vm a = _= ° ao _ E§ a ` cuo NOxxxxx _NO ' ,mL °n _ g E 6' 2O Wz __ ca ELL E-221 z ! 'a ` o IP, .1-0.,6 b q 3 - .8 -% z1 3 0 3 " iNigwi N z ¢ Sx • • \ E e = 4 d6E = - 40 0 p 8 S O S S S u 4 \ O ¢ti o, 0p ryN o o0na tO C' w O ! 0 0 0 0 0 +o m - . \m a o 0 SSSSS S ' a g \4 E 3 N N N n 0 0 0 ry 3 a" 8 0 0. 1-' ',g U O o 0 0 0 0 0 0 0 U a v co \ m E m U 0 ` M V \> J a O m m m o m o J -, E n c o o c c o 0 0 0 0 ¢ u u u , Q • -- S SSSS S 8 2 `o 2 20 0 0 0 °:: :1 S `',7, S S S \$" q o o A ` a E EE > - - C r9 R c _ E N ry ry '-. .. ,. o 0 0 0 0 a a � 0 k 2 I m g z E. S e 2N 5tO o 2. W E m y ui g o T. [ " = 0 0 0 0 0 0 0 0 0 ry = « C 3 0 m Ag S t LL ct T. O a O S o S H 8 Z .yJ m m :° 2 5 a .n F a 2 ry t 0 cO o a • 3" x 0 w . i. Nms N ci n C ¢ NryNNN x cmo y 92 o V r N ry N ry ry ry N ECE, o v:, x o 0 m m , SS 0 Q 5Q� f f `7' ‘g o o S S SS § 8 0 T.Z. ' g i g 0.5 2 m - a m t= o n E ". '-t o m> '� m .y ti ti n .r w .i m F 2 2. n OF _ O m m E. N ¢a 0 0 0 0 0 0 0 0 .- 0 K j 0 c OO a m 0 n .; ry o e U LAa 0 V m V v m W Q -a -a g • F , E,' S o u u u u v u 22 E n E .E n LI F 00 - n O a J .. 2-3 F - N 0 r a C �o112 LL T,-, LL "_ � D a a a a n a E > m ' Y Ux U = O 0 O 0V', ClOUU - r 0 z - *c _ FOLL ^UNx ,zxxxxxtt � m .Ei, D y:, ry ry ry ry ry ry ry LL ''„' LL. L 0 0 = n Y x f ._ _ T YE , vu, 0nm 5ti .,'. o m ; i ,Z w m z' 0. ,1142 ! I ' t' -: L r= 02 a x x - Edo 4C041691.310131.01.'OS LOt@ ¢ LL E W o - L .. pueg 0d t leniatui w ti ", U iia C 0 U 0 • C1) C '0 Y.) N N i CO C a.., t1A ate., .C 0 co Q }' 4 Q V +-+ m a) •— N QJ co -0 O i = v }'CO c�i) _ 2 4-, co N OO -0 (11 NU t1A ro b. OEN C M O a1 N O N O .- E E a, — O It U cr i CD a) La v 4- ' co O i cn a) Q c6 +-+ <O *ca O' O - O 2 > _� +:+ N a) O N N N 4-- Q rn 0 .� v U co 0 ,N + fa > .� N c 0 N viN N -0 — p N a) aJ O cu L- c c E c _c a.) 0 N OD .a�'p Q .a) O N o (] :N C4— N O O 0 c f6 0N .O VO -o N tip c.) H .N Q m c co N }' 0 • V) KUP P D 1C-19 Con©coPhillips 4 Well Attribute. Max Angle 0 TD Alaska,Irl Wellbore APW WI Field Name Wellbore Status Ind(°) MD(ftKB) Act Btm(ftKB) C..orrocodMnihps 500292314900 KUPARUK RIVER UNIT PROD 60.17 5,856.23 10,435.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1C-19,8/14/201710;0037 AM SSSV:NIPPLE 50 9/10/2016 Last WO: 9/27/2013 34.70 5/13/2003 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:RKB 10,149.0 5/20/2017 Rev Reason: H2S,TAG pproven 5/23/2017 Casing Strings Casing Description 01)(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread HANGER;22.9 s CONDUCTOR 16 15.062 29.0 138.0 138.0 62.50 H-40 WELDED Casing Description OD(in) 113(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SURFACE _ 95/8 8.835 28.0 6,744.7 4,474.1 40.00 L-80 BTCM 1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(9KB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread i PRODUCTION 7 6.276 26.0 10,428.7 6,788.6 26.00 L-80 BTCM • U. Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..f Set Depth(WD)(...Wt(Ib/ft) Grade Top Connection TUBING WO 31/2 2.992 22.9 10,02951 6,450.5 9.30 L-80 EUE-8rd Completion Details I Nominal ID Top(9KB) Top(WD)(ftKB) Top Incl r) Item Des Com (in) 22.9 22.9 0.00 HANGER GEN IV TUBING HANGER 2.990 509.2 509.2 0.78 NIPPLE 2.875""DB"NIPPLE 2.875 CONDUCTOR,zs 0-730.0 A 10,016.8 6,440.1 34.68 LOCATOR BAKER LOCATOR 2.990 10,017.6 6,440.8 34.67 SEAL ASSY BAKER 80-40 SEAL ASSY 2.990 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..!Set Depth(WD)(...Wt(lb/ft) Grade Top Connection TUBING Original 5.9 3.000 10,021.3 10,067.9 6,482.2 NIPPLE,509.3 Completion Details lill' Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl C) Item Des Corn (in) 10,021.3 6,443.8 34.66 PBR BAKER 80-40 PBR/SBR""TUBING STRING HAS OD/ID 3.000 OF THE PBR""` ` 10,035.9 6,455.8 34.52 PACKER BAKER SAB-3 PERMANENT PACKER w/MILLOUT 3.710 EXTENSION ID 3.71" 10,059.9 6,475.7 34.27 NIPPLE CAMCO D NIPPLE w/NO GO 2.75"PROFILE 2.750 • GAS LIFT;3,133.4 10,067.0 6,481.5 34.20 WLEG BAKER WIRELINE ENTRY GUIDE 3.000 Perforations&Slots Shot Dene Top(TVD) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKa) (ftKB) Zone Date ft) Type Com 111 10,150.0 10,180.0 6,550.6 6,575.8 C-4,1C-19 6/18/2003 4.0 IPERF 2.5"HSD,2 SPF HYPERJET,4 SPF GAS LIFT,6,014.7 - POWERJET 11 Stimulations&Treatments ( Proppant Designed(lb) Proppant In Formation(Ib) Date 10/7/2003 • • Stimulations&Treatments Vol Clean Pump Stg 8 Top(ftKB) Btm(ftKB) Date Stint/Treat Fluid (bbl) Vol Slurry(bbl) ii 1 10150-0 10,180.0 10/7/2003 SURFACE;28.08,744.7 Mandrel Inserts St ab N Top(ND) Valve Latch Port Size TRO Run GAS LIFT;6,126.8 Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1 3,133.4 2,595.7 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.250 0.0 12/2/2016 2 6,014.7 4,102.7 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.250 0.0 120/2016 3 8,126.6 5,207.7 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/27/2013 4 9,319.0 5,912.1 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/27/2013 5 9,956.9 6,390.9 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/27/2013 GAS LIFT;9,319.0 Notes:General&Safety End Date Annotation 1/11/2011 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT,9,956.9 LOCATOR;10,016.8 SEAL ASSY;10,017.6 PBR;10,021.3 PACKER;10,035.9 NIPPLE;10,(59.9 WLEG;10,0670 • FRAC;10,150.0 (PERF;10,150.0-10.180.0_ 1 PRODUCTION;26.0-10,420 7- • • CD c 'D N vi N +, m0... +, a) +- OO 5 0v NU aAN O C6 N n 4-J N c O 4- O N +-+ m L7 •� N N v o �' I 5 E i U u O v v La v Q ` 0 — L Q = O 7-13ca+-, Lo • 0. O= .- 4A +, O Q 01 i E E ?r 0 a) U cS `—i O N N c co 0 room m qA co +-+ U 0 •Ln� N D •� vi N N c N -0 N v — 0 Q cl3 v v o v s,- v c c ao N 00 V) v N .O ° N z CD 0 o Li L v Li) •- •- O v co O b uI- .N0_ mt CD I . 0 . • • ---- a) •- C +-) LE o � _C 0 CO Q a-' Q> m _ cam 03 `+- o D c a) o 0v4-7; t).0O ra U "Lj O cn }, Nc O ON .0 m 'in co taD CT) N vi a) 4..J0 O _ E a) .5E ' o L .41 c- U L a) N '- a) 4_- 4- Q v i L v , `- co O L N a) 0_ `}- - 0 — i- Q c Q ca 4J (D •- o_ O - O = C13 rt3 .o v •Q > CL — � E E E 01 To OO R V 1-5 (n 4- 00 i ) •� 2 co °' I 4- U c cu a � 0 E o C O r-I o N N C ca ~ U co co O 4A �--) U 0 N N C r", -0-o v — O N .- a) v S- CD v 0 CU L- wo • .- +-, NJ 0 v v a o � O '47. o �- 0 o N o �' `a -0 Z -o c a) E Zi ( = N vtto o a c- •o u 0 coN v) 0 . • • M 0 GJ N a m m m m ; CO m CO m CO r-i Y Y Y Y ! X Y X X 0 0E 0 0 M . a0.. a. C . a. O. a. a. u u o. u u �, t,� 40 /� 7 O r 113 a 0 O M T CO 75 C L.) O O E a IIMIM O - l4 p 1 C +'O a r1 i 0 u O C u vu M Cz fla 0 iii • O o 0 .'Q � v t •0 N O te .Q da .--i -p 4-, g -0 3 0 E Ln UC `� LL OO O• co V O' au N i - Gan V O _ V r-: 0 a) 0 C C , ca• o 0 oa v ai C S E i= a LL E N +d = 0 ., a s a. &. m O co 4.... C o a16 ba U v ca Ir. V ` N N z° si 0 I i-II" V .0 °. •O E O .. v a c O O ii v "O 'L3 +' �: Q N CO X i2 p...- V1 ci Q .0 Q C o °�' cLaI 3 3 = w a C L °' tn a C CO O a O +' o a a+ E .a `.�- 0- C pip a i- a; a rue CNI N w@L tn O CO 2 z '.0 a a - O 0 amO N H • CU Vz I\ OOi aN C a 4 OI 'o o a � f6 0 C 0. a co + vcco a � ' a 'a a V) 5 Q ofla1 ' 0 caEoo ca Q • a Qa) m cu o -O N 3 a. _i oZ G1-1 �a Z X' EC- Z Z a' a. Zai a N• ica d._ .a = Q1 a ot0 eea O d pS_ I Z O -a -2 _ a°, °a' • a0i -- Cu o ° o o a .0 a 01 � E c O v a H '6 a, M ce 3 a ,,; 4 c ; ° �= o a a c_ 00 I- to v a e C a a D u N • V. v i n, "- y'- b y a �i a " , •111 0 10 a v 0- o 4' v v E a v '`ao c N .. a ELI 3 o .0i = 3 • 3a ° °� •� � � � 0.) CI- Q a v -c •a ,c c +" Cs a-,, $ a w v Q a 3 i v a a o (1) o Le) o {; _ Z Q Cl. m LL w CO 0 U HiQ E m a �i N `N.. �N... .N.. E N �• tO la N a • h a CU a a o a a t o a a i o 0 o yc o o a •H a °�'a. c L. 0 ' O to I O O 'aol"5 I a a- L Q 0. saw. ' c.") (0 0 d • • r•, I r-1 40 _a m m m m E V d Oa. d U U a 1tao u° ° 0 Q C of +. a, C -Ocu kti 4-1 . c co a, cco c M N ^ 0 o 4.-C 00 i _ a! ) O O • C N L a _c c0 E +' U Z U __ e-I ° 0 ao a F- w a, .c N V M c• - E c0 ai a o I In of GJ 0• ) a, N a°1�o s 0. r° a o •� o a ( C ,-I Y cc I a 4-, x (0 I. '� O F a, o 1 ai �,1`� O o 2 _ o - c D ° V z N � � � N 3!� � 00 Q co UZ = xY _ Ic co In >'I!n of I a c i +., ,�,; - - 's- _ c L vim, F- O x U a ' Y a) O co O O "a > vl v v �Lri � s > w v Q N v .� • x O O O to t*o (� "a .N "O `. • O Y aJ -C ifa in i c6 > •--I O i`7I c6 C6 a-' Q) V \ 01 O E cu +' a, Y O cp H 1' to00 'O /n a' C CO � Cci) co vs 4-, ,,� O as Cr eN m a, Y c o CC L a < M +., _ . v 0 L) 0 O 2 V) li, u as >. V/ — 4-1 C_1 to^ 0 •y •3 a] L" N N O tI_W a, �+ O o.0 i-+ O ii a a) > $ OA - on -1 l:0 (u To NI • 4- •`?� CD C V c 3 as Oi Ol v01 .� nJ Y c a, ° v1 = N N -a c a, sca _ rn 4- >. c L • � o i _c c i C x Ol > O a) ±' a, O (O v, e i O ....1.) GJ 0 to x O C > c _Ni i v, - +).._ -C - O a a, a- a -• (0 I ✓ Z N L U c O O O U Q N Y Y a', a) a, E _c v �.c°- D ca .R CD N CU ? -..E- .en co 4' Y = -3 > "a 'a7 O O Cl) cc C a, o In l L O m O C Q 3 O a a ;is O O caa.)a� +O v � a U +' a v,1 ba LL I. i` •- cv O O O O 3 c0 - L � c >, a co V O. a LL v a 3 u1 I- t- Z lc x a a co a, 3 0 O � co O a. •11•10 %mi.0110111. v CU 4. c 13 V o o o N ° c v fl ic- o to Q cam, -0 o N 'Q O O '17:".. I _ o c N v a, a, 31 o c 0 4, a.., 0,, N '' O ., 3 0 M 0. c 0 C3 o o `'°CU o aI a U "' 0 to 0 Lu E cu �IN • ° • Od O = Q � O�` o o Io ° v an -. ' a,° ci c c C C CV n ;v o �, oo a a 3o Q L ° Z.a a, c ° C = c .ca0 b Q a 3 a ; O a > a a o o 0 3 s a L f4 coa u I U C7 L 0 Q • • 1Ii o ! 711 Q. 0 0 0 0 0 0 0 0 ' m U U U U U U U U +-, crs U wo O 4 a CI) s O >. Q +a en c 0 Ots d. -0 Vf 1 0 ca tia a) 4- +-, N O ,_ •�C ;.:1 I o CO o v 3 -C o 0 vi +, c i L s VI CO w 0. -c a) . i 0 • a) w . a) 0 a) +, L 4-' VI +' U (In Q c O oa o "- •• — E a; c `Do � o oo( Z +-, a, 0- Lca a, L I i ° ° o o mtts jol so ai s o lip-CL U CU L13 fa O Ts � N s a) E a) v c o, C >- c Q L 'r''O O M .' N O a) LO V -r.,, Q. r6 dA -� U;0 � ! 6 ca ,--t r� ra • A E —>' O • •.-' L cv +� .c o ;� . O \ ^ ..i L 00 tis r-i Q .VA X B Q O t Q v 0 'j• c N N Q O ,; Q = ao v o N +' o° 'V N 1 CO Q .5-< N o .O +' O V a) c O ao 1+ c ra o L v 0 co m ra a) = I ca N `i m dA M a) L a as' - 0) 4� a) I- C a a, 0 av •i N VI .� 3 .v ca m .i a s -a co CD 2 a *' t — L O `� zmt C o o C E U N of v, s o TS 0 CU L.0 44 V Z > i) U �n CO 7 C a-+j a) �O Y a) Q' p CO ice+ l""4 U G L a) L' co � �_ Q. _c V1 M L Q a) U D Q •X t to }' N c O +'! a vn a)i •> > p X aD c a0� 0. U.• IMIIM v-- CO (a .1-, o p .s m N O O p +co.' O c �' co U CI. w u_ cu E .- 40.. u > 4o Y v`_E a a N 2 ti; 8 a) 6 a Ol a, 3 O a, CU r-I _ E L., g .E L 1 i N 0 O v L. 13 r ' 44 >` ri a L Q ! i]) vs a▪t a O L• Q 'a 3 `h L. M a a, o CO Y E 0 a) 1 v z- L�.coo J E a a o a a, v a N Ca C ° c a a v CU o 1 z °. L. • O a o a v cz1 L o N Z ,6 ct a > o o o 44 i v I a 10 vl -a O .O c a a c c 0 4-, O CC CO 0a O Q -- a v p 4--50 0) *E2 ° o OZ ..6-- z , s -.-.. N ,Li' Z ,, O. _ _ _ v' E N O OIC R 4) ^_ N N a'': h ry u eNy a N N M a) a Q. a o o a `moi a o = a 0.a Qg o a O. fo ' to ra to O. U U U 0 Q 4. • N n. 0 0) N C. 0 0 a a a a m I U U U U U +' o U o0 by 0 Q 01 001 4.0 M 0>C +�+ M LA d a)a ,y o N vs u M cu o Il° LA o QJ • 0 LA . ± Z N al co • > II a) � -ts vii i) 0. I >► U a °4.' v 0 c L `^ (a H co O. •O 1 0 13 N a to as N 0 .� C C a 2 �. a) ,c5 O z . te le.0 fX ro Coo o "a _ L.4- H 0. Q. d' • 0 •ZrLn cxo . a aa) rn '� Q L/1 c � o o i g '�, aXi Q. � 0. 4 co O N Y U1 a. P{ i j�N M 4-I (a , at Q LA fl 43 U9 a °- N cD cli O N 0 'a o +,, •= o 8O Ql `A 0 e-1 II * ° o ca i N r, N o vsd• vo .c a) a O Q o ''� n ° 4fteU Z *' Cr) m v �' CD o ° ( 0 m a a .c °+) -i--. i- 0 c u o o N " • a a) E to LL v ! O a o a) co :u- •A < c Z cB L.) CI. 1-•' a ►- a .-, i- .0 3 0. — _.c 0 a. cb CO e-1 cutn Ln 13 MI cu a 0 v aVv 0 � v4:3 poe-1 cO . ef) C4 ca 00 Y ao ° c a •o a v a p c a = a a N a �°' o L. ° a1 o L) _, tV Z a. .0 �' o °�) o c ~; o n. a, a o < E 30 CI) ° = jam^ o 3 ' N • V (Q t) �, u 0 h p L c u •u ,..-- z ^ a U 1— '- i 0 +,+ 0 Z U Gn L O O N _ v v N N H ft Div E v t�-c N v a o -. v o ° ate, o ^, —. o) p, of y 4-, o a a v C on tc is o� 06 QJ CC CI j E v jQJ : o c . Baa`s V v ° i'. °t3 QJ ' Z.: O eJ C a. CIL C LL. C1 j U v) •Ha'Q N CVC U �p i O u p N ,1 p p, S o u > I� a. � a. Z c O a • • N o ellN ,wa i e-I 0. m VI O a cnM .▪.... r♦ u M .� V z 1 c .a +▪ + = o N f� 'Cr Q In a o anrn•—• N = 0 1 4a I CD Q a L1. 1._ b v a __ co = al -0 I 1 4. v Cil CC a • 0 0 ),;a 1 CI In Nil) Z a..a = o110 5 Z � o `o,41 C) v, -a c i o a U C N o; c 3 i C� c L Q 0 �' O o z i o u N O � o A C) a, o is °I Iih 3 a 4., a , o°. E - o a u y ` . i... Q • • Wallace, Chris D (DOA) From: Wallace, Chris D (DOA) Sent: Friday,August 18, 2017 9:53 AM To: Pedam, Sandeep Subject: Hydraulic Fracturing Application Sundry 317-390 1C-19 (PTD 2030540) Sandeep, We are reviewing the Frac stimulation sundry for 1C-19. 20 AAC 25.283(a)(12)(F) requires the fractures, height, length, MD, and TVD to top and description of fracturing model use. I see a frac model that is based on tops 7904 MD and 7672 ND but the perforation zone is 10150 to 10180 ft MD, 6550 - 6575.8 ND? Please provide. Please provide at your earliest so we can progress the sundry application. Thanks and Regards, Chris Wallace,Sr.Petroleum Engineer,Alaska Oil and Gas Conservation Commission,333 West 7th Avenue,Anchorage,AK 99501,(907)793-1250(phone),(907)276- 7542(fax),chris.wallace@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Chris Wallace at 907-793-1250 or chris.wallace@alaska.gov. 1 d— a) c00 _ fJ ~ T �^^rau w l•J�(� Ooh N -0 O 0c ONw CU -CaA +-' f6 > ra JCI e m n ra LH 10 O ra �1 F- Y + C N U 'n L Q�. U Cr. a c C ? �O Li ra O T Q 0 .J W I N- r` r N r` r` N r N- N- r„.. a 0 m L u k 0' T T T >+ >, T T E a".' t '.- O N Qccs R R Co COr0 r6 CO CO ra C C C C 1 +' +J L N C '~ NNNNNM M M N M 0 CO L C zi) >tl) -O a) cc gH 'v O c + U +' r00 I- Qa.) Q 0 0 0 0 0 0 0 0 0 0 0 0 C � v 0L a J J J J J J J J J J J J b If U LO ) - W W W W W W W W W W W W •rn v0 ' F LL LL LL LL LL LL LL LL LL LL LL LL +' 01 a) a) 75 O '=Q J J J J J J J J J J J J Q _0 > +-C U `*" Q Q Q Q Q Q Q Q Q Q Q Q a) `^ C w i G g h Qp Z Z Z Z z Z Z Z Z Z Z Z 0 co o) 0• v LL LL LL LL LL L1. LL. LL LL LL LL LL C[ .0 C > a 0 Q L U O 2 0 °_ OA U a) U (1;,,.. 0C O r ra • •441 v h E T., 1' U -C > U a) 4-+ z O U E ~ c ra Q 0 0 ai g U ILI Q CD Q rn C Q y o 0_ a J 0 LL 0- 0 2 0_ 0. 0 0 a `4 G1 {? 'c .CO m o a ctS O a v Ma CO a a m N co U U 0 LL N U U O G F p Q U > Ow ? C4 p r. z Z g ( g x w O W C„ . d J J J J J J J J J J J J ral g xa "' W � � � 3 � � 3 � 33 � � 3 i. W 0 or.--0( v- CLIXCLIXCLWWWWCCIX (t W W W W W W W W W W W W w > > > > > > > > > > > > z Y Y Y Y Y Y Y Y Y Y Y Y L N w Q Q Q Q Q Q Q Q Q Q Q Q ® ly a d d d d d LL LL d d d d > > > > > > > > > > > COC Q Y Y Y Y Y Y Y Y Y Y Y Y cc ILL1- U cc w _ r CO CO O 0 N M M N O n x to .� (V 0 CO CO CO CO O) O) O) O) O) OW ) 0) at O O O O O O O O O O O O O O O O O O O O O O O O 0) W /\ 0 0 0 0 0 0 0 0 0 0 0 0 0 p 0 v r; r- N- r` r, N- r; r` n 1- 1- V � � � � � � � � � � � � It > > E E E 2 2 2 2 2 2 E 2 E U 0 w 0 0 0 0 0 0 0 0 0 0 0 0 Qa c W Q o E Y OO 0 0 0 N 0 0 0 0 0 0 +'' O ra O O O O O O 0 O O O O O NY Q OU) ) Co 0CO OO M CO N • ) * tt 0) CO t0 Cr1- O) O O O - (.0 I)) CO N N CO 0 r 0 0 0 N 0 0 £ = = N ENNNN N N N N N N N N H L F...- Q o) 8 8 o) o) o) M M M o) 8 M C a 0 N N N N N N O O 0as N N O Q1 0 0 0 0 0 O OC) L 0 0 0 0 0 0 0 0 0 0 0 0 0 0 a+ +, C O C Oq C u7 If7 u7 LO In N N In N u7 Ill 117 a d O O a, w ^ll1 E GJ c C . (.J zF �i E u w Y w cc In E E CO CO 9 U `�` p,{ Q O O O T m O N co O ++ a) c Y M a Z ti ha Z ,_ ,_ C O O N O O N J+ E w a) al d Q N O W W O N N M N a N h N N v) Z CU O O Ts c ^ 3 L a E E E STATE OF ALASKA RECEIVED ALA OIL AND GAS CONSERVATION COM•ION OCT 10 2013 REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair well fl Rug Perforations fi Perforate r Other rAOGGC Alter Casing r Pull Tubing ri Stimulate-Frac fi Waiver fl Time Extension Change Approved Program fOperat. Shutdown f' Stimulate-Other r Re-enter Suspended Well fi 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 1 Exploratory r 203-054 3.Address: 6.API Number: Stratigraphic r Service P. O. Box 100360,Anchorage,Alaska 99510 50-029-23149-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25649 i Abt.00 2-`61;12. 1 C-19 • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool • 11.Present Well Condition Summary: Total Depth measured 10435 feet Plugs(measured) 10060 true vertical 6794 feet Junk(measured) none Effective Depth measured 10344 feet Packer(measured) 10036 true vertical 6716 feet (true vertical) 6456 Casing Length Size MD ND •• Burst Collapse CONDUCTOR 109 16" 138 138 SURFACE 6717 9.625" 6745 4474 PRODUCTION 10403 7" 10429SCAa, 6789 Perforation depth: Measured depth: 10150'-10180' True Vertical Depth: 6551'-6576' Tubing(size,grade,MD,and ND) 3.5, L-80, 10030 MD,6451 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER SAB-3 PERMANENT PACKER @ 10036 MD and 6456 TVD NIPPLE-DB NIPPLE @ 509 MD and 509 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory fi Development F.7; . Service fi Stratigraphic fi 16.Well Status after work: Oil F Gas r WDSPL Daily Report of Well Operations )00( GSTOR r WIND r WAG ""` GINJ r SUSP r SPLUG 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: none Contact Jonathan Coberly a,265-1013 Email Jonathan.Coberly(a�conocophillips.com Printed Name o athan Coberl Title Sr. Wells Engineer Signature / Phone:265-1013 Date /0_if,2,0 0 VLF ,/e/a/fci /0//57/ 3 RB MS OCT 11 sil Form 10-404 Revised 10/2012 Submit Original Only :: if„ KUP PROD 1C-19 COt1000P11lli 5 Well Attributes Max Angie&MD TD Alaska,'IfIC. ,Y Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) r.r uxann .r<` 500292314900 KUPARUK RIVER UNIT PROD 60.171 5,856.23 10,435.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1C-19,10/9201310:20:59 AM SSSV:NIPPLE 90 8/14/2012 Last WO: I 9/27/2013 34.701 5/13/2003 Vertical.schematic(actual) _ --- Annotation I Depth(ftKB) End Date Annotation I Last Mod By I End Date Last Tag:SLM 10,134.0 7/28/2013 Rev Reason:WORKOVER haggea 10/7/2013 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread , HANGER,22 9- CONDUCTOR 16 15.062 29.0 138.0 138.0 62.50 H-40 WELDED TM"" Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread SURFACE 95/8 8.835 28.0 6,744.7 4,474.1 40.00 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD).. Wt/Len(I...Grade Top Thread l Jt PRODUCTION 7 6.276 26.0 10428.7 6,788.6 26.00 L-80 BTCM of J Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft 'Set Depth(ND)(..Wt(Ib/ft) Grade Top Connection I.1 TUBING WO 31/2 2.9921 22.91 100295 6,450.51 930 L80 JEUE-8rd t 1 Completion Details i Nominal ID• I I�'.. I Top(ftKB) Top(ND)(ftKB) Top Inot(°) Item Des Core (in) 22.9 22.9 0.00 HANGER GEN IV TUBING HANGER 2.990 5092 509.2 0.78 NIPPLE 2.875""DB"NIPPLE 2.875 CONDUCTOR;29.0-138.0 10,016.8 6,440.1 34.68 LOCATOR BAKER LOCATOR 2990 10,017.6 6,440.8 34.67 SEAL ASSY BAKER 80-40 SEAL ASSY 2.990 Tubing Description String Ma...ID(in) Top(ftKB) --Set Depth(ft..Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING Original 5.9 3.0001 10,021.3 10,067.9 1 6,482.2 NIPPLE;509.3 - Completion.Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Inc!(°) Item Des Com (in) 10,021.3 6,443.8 34.66 PBR BAKER 80-40 PBR/SBR"'TUBING STRING HAS OD/ID 3.000 OF THE PBR'"` 10,035.9 6,455.8 34.52 PACKER BAKER SAB-3 PERMANENT PACKER w/MILLOUT 3.710 EXTENSION ID 3.71" 10,059.9 6,475.7 34.27 NIPPLE CAMCO D NIPPLE w/NO GO 2.75"PROFILE 2.750 GAS LIFT,3,133.4 10,067.0 6,481.5 34.20 WLEG BAKER WIRELINE ENTRY GUIDE 1000 Other In Hole�reiine retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Inc( I Top(ftKB) (ftKB) (°) Des Corn Run Date ID(!n) 10,056.9 6,473.1 34.30 CATCHER 2.72"CATCHER,(OAL=124) 8/26/2013 0.000 10,059.9 6,475.6 34.27 PLUG CA-2 PLUG 8/26/2013 0.000 Perforations&Slots GAS LIFT,6,014.7 Shot II Dens Top(TVD) Btm(TVD) (sh s/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn 10,150.0 10,180.0 6,550.6 6,575.8 C-4,1C-19 6/18/2003 4.0 IPERF 2.5"HSD,2 SPF HYPERJET,4 SPF P0WERJET Stimulations&Treatments Min Top Max Btm SURFACE;280-6,744.7 Depth Depth Top(ND) Btm(TVD) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 10,150.0 10,180.0 6,550.6 6,575.8 FRAC 10/7/2003 PUMPED 142,2040 16/20 PROPPANT IMandrel Inserts GAS LIFT;8,126.6 St I ati on 0 No Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date in 1 3,1314 2,595.7 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 9/27/2013 2 6,014.7 4,102.7 CAMCO MMG 1 1/2 GAS LIFT SOV RKP 0.000 0.0 9/27/2013 DCR-1 GAS LIFT;9,319.0 shear II 3 8,126.6 5,207.7 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 9/27/2013 4 9,319.0 5,912.1 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/27/2013 • 5 9,956.9 6,390.9 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 9/27/2013 lit Notes:General&Safety End Date Annotation GAS LIFT;9,956.9 1/11/2011 NOTE:View Schematic w/Alaska Schematic9.0 I I LOCATOR;10016.8 all SEAL ASSY;10,017.6 �'�, PBR,10,021.3 4R Iii PACKER;10,035.9 CATCHER;10.0569 .1.(I PLUG,10,059 9 NIPPLE;10.05991 / WLEG,10,067.0 FRAC.;10,1500 T IPERF;10,150.0-10,180.0 LI PRODUCTION,26.0-10.428.7- Pre-Rig Work (2013) Well Date Event Description 1C-19 9/2/13 (PRE-RWO):SCLD(COMPLETE),PUSHED OA FL FROM 678'TO 1026'IN 4 HOURS W/LIFT GAS @ 1382 PSI. 1C-19 8/26/13 PULL 2.75"CA-2 PLUG BODY W/GAUGES© 10060' RKB; SET 2.75"CA-2 PLUG @ 10060'RKB. SET 2.72" JUNK CATCHER @ 10050' RKB; PULL DV @ 9937' RKB. READY FOR CIRC OUT/ CMIT. LRS CMIT 8-27-13 SEE ATTACHMENTS. 1C-19 8/25/13 PULL CATCHER&CA-2 PRONG @ 10060'RKB. IN PROGRESS 1C-19 8/25/13 (PRE-RWO): SCLD-IN PROGRESS. PUSHED OA FLUID FROM 396' TO 516' IN 4HRS WITH LIFT GAS @ 820 PSI. 1C-19 8/24/13 (PRE-RWO):SCLD-IN PROGRESS. PUSHED FLUID LEVEL FROM SF TO 282' WITH GAS @ 860 PSI. 1C-19 8/17/13 (PRE RWO) T POT (PASSED), T PPPOT (PASSED), IC POT (PASSED), IC PPPOT (PASSED), FUNCTION T AND IC LDS. 1C-19 8/8/13 HOIST GYRODATA GYRO FROM SURFACE TO 10000', MAKING GYRO SURVEY STOPS AT 50', 100',725', 1015',1800',3400',5700',7900',AND 10000'. 1C-19 8/3/13 PERFORMED A LEAK DETECTION LONG AND MULTIFINGER CALIPER SURVEY ON 1C-19. LEAK WAS LOCATED IN THE TUBING AT 8556'. AN UP-DOWN OVERLAY AND STOP CHECKS AT 8565', 8560', 8559', 8558', 8557',AND 8556'WERE DONE. 24 ARM CALIPER WAS LOGGED FROM 10050 TO SURFACE. CALIPER FINGERS CAUGHT ON GLM AT 7930'. FINGERS HAD TO BE CLOSED TO PASS. MFC DATA WAS LOST FROM 7903' TO 7928' . LITTLE RED CAME ONLINE AT .5 BPM, 2500 PSI, SENDING A TOTAL OF 49 BARRELS OF DIESEL DOWN THE TUBING. JOB COMPLETE. 1C-19 7/31/13 Pulled DV @ 7921'RKB; Set DV's @ 5941'RKB&3236'RKB; (Circ Out W/Inhibited Sea Water and Diesel Freeze Protect); CMIT 2500 PSI ( PASS); Set DV @ 7921' RKB. In Progress(Awaiting Plan Forward Poss.Leak Detect). 1C-19 7/30/13 With Holefinder Narrow Leak between 8692'&8477' RKB; Pulled Cat SV @ 10,060' RKB&Set 2.75" CA-2 Plug w/Spartek Gauge;Set Catcher on top of plug @ 10,060'RKB;Pulled GLV @ 3236'RKB& OV @ 5941'RKB.In Progress. 1C-19 7/29/13 Set 2.75"Cat SV @ 10,060'RKB; Replaced OV(Check Stuck Open) in Kind @ 5942'RKB(Tbg x IA Communication Remains);With Holefinder Identify Leak between 8016' & 9083' RKB (Establish Leak Rate of 0.72 BPM @ 2500 PSI). In Progress. 1C-19 7/28/13 Drift Tbg to 2.72"&Tag @ 10,134'SLM(Est—26'Fill). In Progress. 1C-19 7/18/13 (AC EVAL): PROACTIVE TIFL FAILED, IA INFLOW OF 2531' DURING BLEED AND MONITOR. IA PRESSURE INCREASE OF 115 PSI DURING MONITOR. Como hillips Time Log & Summary WeMew Web Reporting Report 4444-44,ly„ ;1l4 Ii�b ili '` �� e, r, !df , -7 r IEi Well Name: 1C-19 Rig Name: DOYON 141 Job Type: RECOMPLETION Rig Accept: 9/16/2013 10:30:00 AM Rig Release: 9/28/2013 4:00:00 AM � p .'y,.x r .�-�. � �I �" i�ii u � nisi i nIl IC���;, Date From To , t ur S.Death Deoth,Phase Code �� Subco'oe �T Comment a :-. 39/16/2013 24 hr Summary Move modules to 1C pad and move sub towards 1C pad(to CPF-3). 00:00 01:00 1.00 0 0 MIRU MOVE MOB P PJSM, Pull pipe sheds apart and spot on corner of 3Q pad. 01:00 02:00 1.00 0 0 MIRU MOVE MOB P Pull power pack apart and line up on 3Q pad to be mobilized to 1C pad. 02:00 06:30 4.50 0 0 MIRU MOVE MOB P On hold,waiting on road to be matted as per ASRC. 06:30 09:45 3.25 0 0 MIRU MOVE MOB P Mobilize power pack to 1Q pad and stage. 09:45 10:15 0.50 0 0 MIRU MOVE MOB P Pull sub off well 3Q-03. 10:15 12:00 1.75 0 0 MIRU MOVE MOB P Mobilize sub and pipesheds to CPF-3. 12:00 14:00 2.00 0 0 MIRU MOVE MOB P Stage pipe sheds and sub @ CPF-s, hook up to power pack,wait on rig mats to move power pack. 14:00 23:00 9.00 0 0 MIRU MOVE MOB P Move boiler, motor, puumps, pits complex from 1q to 1C, Mob PEAK trucks to CPF3. 23:00 00:00 1.00 0 0 MIRU MOVE MOB P Move pipe sheds and sub to 1C. 39/17/2013 Move sub to 1C and spot rig and modules over 1C-19.Work on rig acceptance. Move Rig Camp to 1C pad. Accept rig and take on fluids. R/U to circulate 9.6 brine into well. 00:00 02:00 2.00 0 0 MIRU MOVE MOB P PJSM, Mobilize sub and pipe sheds from CPF-3 to 1C pad. 02:00 03:00 1.00 0 0 MIRU MOVE MOB P Spot sub over well 1C-19 03:00 03:45 0.75 0 0 MIRU MOVE MOB P Lay mats for power pack. 03:45 07:30 3.75 0 0 MIRU MOVE MOB P Spot up ower pack to sub,set rockwahser and pipe sheds. 07:30 10:30 3.00 0 0 MIRU MOVE MOB P PJSM,work on rig acceptance check list. calibrate gas alarms, build scaffolding. RIG ACCEPTED @ 10:30 am 10:30 11:30 1.00 0 0 MIRU WHDBO RURD P Load 9.6 brine into pits.take on fuel and water. 11:30 12:00 0.50 0 0 MIRU WHDBO RURD P P/U lubricator as per FMC rep. R/U circ lines in cellar.cont to build scaffolding. 12:00 12:30 0.50 0 0 MIRU WHDBO RURD P PJSM, Cont to set scaffolding. SIMOPS:take on 620 bbls 9.6 briine. 12:30 13:30 1.00 0 0 MIRU WHDBO RURD P PJSM, R/U lubricator, Pressure test same to 250 psi/1500 psi for 5 min each. Pull BPV per FMC rep. R/D lubricator.Tubing=800 psi, OA= 840 psi, IA=600 psi. Page 1 of 13 • • J Date From ,Tti°6 ip 4I Dur S. Depth E rDeoth Phase , ':Comment i61;1111 = a °I "16 13:30 15:00 1.50 0 0 MIRU WHDBO RURD P PJSM, R/U Cir hoses,clear cellar, measure RKBs. 15:00 22:30 7.50 0 0 MIRU WHDBO RURD T Wait on hard line and tiger tank, move tiger tank 100'away from wellhead. SIMOPS: Clean and clear rig floor. Load and process 3.5" production tubing. 22:30 00:00 1.50 0 0 MIRU WELCTL KLWL P PJSM, Blow air thru lines, PT circ lines to 2000 psi, bleed IA&tubing to zero,shut in and monitor pressures. 09/18/2013 Kill well. N/D tree, N/U BOPE.Test BOPE to 250/4000 PSI.Attempt to pull 3.5"tubing, pulled 182K,did not pull free. Mobilize E-Line to make RCT cut, OWFF. 00:00 01:00 1.00 0 0 MIRU WELCTL CIRC P PJSM,waiting on vac truck due to tiger tank volume too small. 01:00 02:00 1.00 0 0 MIRU WELCTL CIRC T Attempt to pump down tubing taking returns to tiger tank.cold not establish circ. Max pressure= 1900 psi. Line up to circ down IA taking returns out tubing,still no circ, decision made to call town. 02:00 02:15 0.25 0 0 MIRU WELCTL OTHR T Call town decision made to try and pump with higher pressure. 02:15 05:00 2.75 0 0 MIRU WELCTL CIRC P Pump down taking returns to tiger tank,established circ @ 1900 psi, pressure climbed to 2450 psi then dropped down to 200 psi @ 2 bpm, FCP=3000 psi. Pumped 390 bbls, returned=390 bbls. 05:00 06:00 1.00 0 0 MIRU WELCTL OWFF P Monitor well slight flow down to static. 06:00 06:45 0.75 0 0 MIRU WHDBO PRTS P Set BPV and test to 1000 psi. (Charted) 06:45 07:45 1.00 0 0 MIRU WHDBO RURD P PJSM Blow down lines, R/D Lines and scaffolding. 07:45 08:30 0.75 0 0 MIRU WHDBO NUND P Bleed off void pressure, N/D tree. 08:30 09:00 0.50 0 0 MIRU WHDBO RURD P Install tree test plug and testjt to check clearance for bottom rams. 09:00 09:30 0.50 0 0 MIRU WHDBO RURD P Drop adapter flange off stack. 09:30 11:00 1.50 0 0 MIRU WHDBO NUND P N/U BOPE. 11:00 12:00 1.00 0 0 MIRU WHDBO RURD P Send riser to shop.add 13.25"R/U to test BOPE. 12:00 13:45 1.75 0 0 MIRU WHDBO RURD P PJSM, R/U to test BOPE, install riser, re-torque adapter flange bolts. Pa ,e 2 of 13 • Time Logs .. �r o ro� u�imam�n Date From To Du'r`` S.Det thKE.Depth Phase code Subcode T Comme°fi ' 1111 t 13:45 18:00 4.25 0 0 MIRU WHDBO BOPE P PJSM,test BOPE with 3.5"test joint to 250 psi and 4000 psi for 5 min each,test annular to 250 psi and 3500 psi. #1 top pipe rams,valves 1,12,13,14 and manual kill;#2 Upper IBOP, HCR kill,valves 9,11;#3 Lower IBOP,valves 5,8,10;#4 dart valve and valves 4,6,7;#5 Floor valve and valve 2;#6 HCR choke,4"kill line DEMCO valve;#7 manual choke valve, HCR kill,;#8 Annular preventer;#9 lower pipe rams;#10 blind ram,valve 3.System pressure 3000 psi, pressure after closed 1690 psi,200 psi attained in 43 sec,full pressure attained in 206 sec, nitrogen bottles average 2000 psi. John Crisp with AOGCC waived witness of BOPE test. 18:00 19:30 1.50 0 0 COMPZ RPCOM RURD P PJSM, R/D test eqpt, back out acme bklanking plug,vac out stack, pull BPV per FMC Rep. 19:30 20:00 0.50 0 0 COMPZ RPCOM RURD P PJSM, M/U landing joint and M/U to tubing hanger, BOLDS. SIMOPS: R/U casing eqpt. 20:00 23:00 3.00 0 0 COMPZ RPCOM PULL T PJSM, Pull on tubing staging from 140k to 185k. Monitor well using trip tank while attempting to pull seals free. 23:00 00:00 1.00 0 0 COMPZ RPCOM RURD T Land hanger, RILDS, L/D landing joint, CIO elevators, P/U 3 pup jts for E-line job. 09/19/2013 R/U E-line. RIH w/string shot assembly, no go, POOH. RIH w/cutter assembly, no go at bottom GLM, P/U and cut at 9112' MD. Pull tubing free w/35K drag. Rev Circ with large amounts of sand returns. 00:00 08:00 8.00 0 0 COMPZ RPCOM T PJSM,wait on Halliburton wire-line (timed out).Work on MP-2s, clean rig. 08:00 08:45 0.75 0 0 COMPZ RPCOM RURD T Spot Halliburton trucks and Prep tools. 08:45 09:00 0.25 0 0 COMPZ RPCOM SFTY T PJSM on P/U and M/U wireline. 09:00 10:00 1.00 0 0 COMPZ RPCOM PULD T P/U and M/U wire-line tools as per Halliburton Rep. 10:00 11:00 1.00 0 0 COMPZ RPCOM ELNE T Build strong shot and M/U as per Halliburton Rep. 11:00 12:00 1.00 0 0 COMPZ RPCOM ELNE T RIH with string shot as per Halliburton Rep. 12:00 13:00 1.00 0 9,937 COMPZ RPCOM ELNE T PJSM, Cont RIH with string shot E-Line run,could not get past 9937' MD. 13:00 13:30 0.50 0 0 COMPZ RPCOM ELNE T R/U Circ eqpt to assist E-Line, Circ @ 0.5 bpm,400 psi, 1 bpm,950 psi, No Go,decision made to POOH w/ string shot. 13:30 15:30 2.00 0 0 COMPZ RPCOM ELNE T POOH w wireline, UD string shot per Halliburton Rep. Page 3of13 jme=Log8 .th o erKe p Di • -Date Frorrt��To« � Dur ,�� S. D�athDepth f?hase Dade �Subctj�e T° _ tsmrri�nt. I'i(H�" � . . �@..h 15:30 17:00 1.50 0 0 COMPZ RPCOM PULD T M/U and P/U cutting tool assembly. 17:00 19:45 2.75 0 9,912 COMPZ RPCOM ELNE T RIH with wire-line cutting tool. No go at GLM.Cut at 9912'MD, POOH with the same. SIMOPS: Load pipe shed with 4"DP. 19:45 20:15 0.50 9,912 9,912 COMPZ RPCOM RURD T PJSM, R/D E-Line, M R 20:15 20:30 0.25 9,912 9,892 RP 892 COMPZ CO RURD T R/U Circ hoses, latch up and pull on tubing, pull to 180k,slack off, pull to 145k and tubing string broke free. P/U weight when landed was 114K, string has 31K of drag. Pull tubing to rig floor. Line up to reverse circulate. 20:30 21:30 1.00 9,892 9,892 COMPZ RPCOM CIRC T PJSM, break circ @ 1 bpm 700 psi, staging up to 3.5 bpm 1800 psi, @ 50 bbls pumped pressure dropped to 1100 psi,staged pump to 5 bpm 1350 psi @ 150 bbls pumped shakers got overloaded with sand and burned drag chain belts,drag chain then became overloaded with sand, pumps shut down. 21:30 22:30 1.00 9,892 9,892 COMPZ RPCOM SVRG T PJSM,clean and clear drag chain, replace belts, B/D circ lines and mud manifold. 22:30 00:00 1.50 9,892 9,892 COMPZ RPCOM COND T Build 80 bbls 9.6 brine and cont to clean out sand from drag chain. 09/20/2013 Circulate hole clean. Pull and L/D 3.5"tubing.Test BOPE w/4"test jt. RIH with overshot fishing assembly. Engage fish and attempt to jar fish free. 00:00 00:15 0.25 9,892 9,892 COMPZ RPCOM SFTY T PJSM, continue to build Brine. 00:15 01:15 1.00 9,892 9,892 COMPZ RPCOM CIRC T Reverse Circulate @ 5 bpm,650 psi until shakers cleaned up. 01:15 01:45 0.50 9,892 9,892 COMPZ RPCOM OWFF P Monitor well(STATIC) 01:45 09:15 7.50 9,892 0 COMPZ RPCOM PULL P POOH w/3.5"tubing.total jts=314 +cut jt,4 GLMs, 1 nipple;length= 9891'.Actual fill=34.34 bbls, Cal fill =33.6 bbls. 09:15 10:00 0.75 0 0 COMPZ RPCOM RURD P R/D casing eqpt,clean and clear rig floor. 10:00 10:30 0.50 0 0 COMPZ RPCOM RURD P Drain stack, R/U to test BOPE 10:30 11:45 1.25 0 0 COMPZ RPCOM BOPE P Test w/4"joint.Annular to 250 psi/ 3500 psi; 3.5"x 6",top rams,2.875" x 5"bottom rams to 250 psi/4000 psi. 11:45 12:00 0.25 0 0 COMPZ RPCOM RURD P R/D drain stack, R/D test eqpt and blow down. 12:00 13:30 1.50 0 0 COMPZ RPCOM PULD T PJSM P/U Baker tool from beaver slide. Load Drill collars and drill pipe in shed and strap. 13:30 15:30 2.00 0 315 COMPZ RPCOM PULD T PJSM, M/U Over shot BHA per Baker Rep. 15:30 19:15 3.75 315 5,045 COMPZ RPCOM PULD T RIH P/U 4"Drill pipe from 315'to 5045'. P�4 of 13 1 Time Log s . � ,,,"11141' .^ .; Iii �a�i iw of ai li d' Date : .- From To Dur S. depth E. DeothPhase Code Subcode T Comment fs 19:15 19:45 0.50 5,045 5,045 COMPZ RPCOM OWFF T OWFF @ 5045'f/30 min due to improper hole fill.Slight flow, .38 bbl over 18min then stopped. 19:45 21:30 1.75 5,045 7,886 COMPZ RPCOM PULD T Cont RIH P/U drill pipe f/5045'to 7886'. 21:30 22:00 0.50 7,886 7,886 COMPZ RPCOM OWFF T OWFF @ 7886'f/30 min due to improper hole fill.Slight flow, .50 bbl over 17min then stopped. 22:00 23:00 1.00 7,886 9,900 COMPZ RPCOM PULD T Cont RIH P/U drill pipe f/7886'to 9900'.P/U=175K, S/O=98K, ROT=130K,Tq=9K. Calc displacement=59.9 bbls,Actual displacement=62.39 bbls. 23:00 00:00 1.00 9,900 9,920 COMPZ RPCOM FISH T Wash down @ 3 BPM=250 PSI f/ 9900'to 9915',tagged up on sand. P/U 5'wash down to 9920'and fully enguage fish w/4.8'of swallow. 09/21/2013 Attempted to jar fish free,fired jars 100K over and pulled to max pull @ 166K over, no go. POOH and C/O BHA. M/U shear pin guide sub w/Pac pipe and RIH to top of tbg @ 9918. Shear out Pac pipe and wash sand of tbg. 00:00 01:15 1.25 9,920 9,917 COMPZ RPCOM FISH T PJSM,fully engage over shot @ 9920'MD,set down 15k,attempt to pump @ 2 bpm, pressured up to1000 psi, beld off, P/U and fire jars at 225k (3x),Jar@ 250k(2x),Jar at 275k (3x), pull to 300k(125k over)with no success,attempt to cock jars and took weight 2'high(Jars packed off) decision made to release from fish and CBU. 01:15 02:00 0.75 9,917 9,917 COMPZ RPCOM CIRC T CBU @ 10 bpm,2400 psi. 02:00 04:00 2.00 9,917 9,920 COMPZ RPCOM FISH T Latch up on fish @ 9920'MD,set down 15k, attempt to establish circ (no go)Fire jars off several times @ 225k,pull up to 340k(no change), decision made to rev circ. 04:00 04:30 0.50 9,920 9,817 COMPZ RPCOM CIRC T RIH 0.5'above fish, R/U and Rev circ @ 7 bpm, 1500 psi. (Small amount of sand @ bottom up). 04:30 05:00 0.50 9,817 9,774 COMPZ RPCOM RURD T R/D Circ egpt, POOH from 9817'MD to 9774' MD, UD 2 jts, Blow down. 05:00 05:30 0.50 9,774 9,774 COMPZ RPCOM OWFF T Perform post derrick jarring inspection. Monitor well(STATIC) 05:30 08:45 3.25 9,774 315 COMPZ RPCOM TRIP T POOH from 9774'MD to 315'MD, Calc fill=59.9 bbls,Act fill=64.6 bbls 08:45 09:00 0.25 315 315 COMPZ RPCOM OWFF T Monitor well(STATIC) 09:00 09:30 0.50 315 39 COMPZ RPCOM PULD T L/D accelerator jars, rack back 3 stds drill collars. 09:30 10:30 1.00 39 0 COMPZ RPCOM PULD T UD Over shot BHA as per Baker Rep. 10:30 11:30 1.00 0 0 COMPZ RPCOM RURD T Clean and clear rig floor. 11:30 12:00 0.50 0 0 COMPZ RPCOM SVRG P Service rig. ! Page 5of13 • 4110 Date From ,To � kiDurgo,,, ...Depth E.Depth Phase Codee.�.. .Subcode T Oommen uo , 12:00 13:00 1.00 0 0 COMPZ RPCOM RURD T PJSM, Load p i p e shed w/2 11/16" pipe and shear pin guide sub w/mule shoe. 13:00 14:15 1.25 0 0 COMPZ RPCOM PULD T P/U tools from Beaver slide,strap tools(ID, OD,fishneck) 14:15 16:00 1.75 0 429 COMPZ RPCOM PULD T PJSM, M/U BHA#2(stinger run). 16:00 21:15 5.25 429 9,888 COMPZ RPCOM TRIP T RIH from 429' to 9888'.Actual displacement=62.39 bbls, Calculated displacement=59.46 bbls. 21:15 22:30 1.25 9,888 9,888 COMPZ RPCOM CIRC T PJSM, Circulate and condition fluid. Add Flowzan and Safelube to 9.6 ppg brine system to reduce torque and drag. Pump @ 6 BPM=900 PSI. 22:30 23:00 0.50 9,888 9,918 COMPZ RPCOM FCO T Establish parameters: pump @ 3 BPM=400 PSI, P/U= 150K, S/0= 105K, ROT= 122K,Tq=5.5K.Wash down from 9888'to 9914',observed pressure increase as shear pin guide sub engaged tbg stub.Wash down again to fully located,set down 4K, observed screws shear. 23:00 00:00 1.00 9,918 9,939 COMPZ RPCOM FCO T Wash down and clean out frac sand from 3-1/2"tbg, pump @ 4 BPM= 600 PSI.Wash down from 9918'to 9939'. 39/22/2013 POOH and L/D BHA. M/U wash over BHA and RIH.Wash over 3-1/2"to the top of GLM. POOH and L/D BHA. M/U Guide shoe BHA and RIH. 00:00 02:00 2.00 9,939 10,040 COMPZ RPCOM WASH T PJSM„wash down from 9939'MD to 10040'MD @ 4.5 bpm,650 psi, stagin up to 1000 psi, 50%flow. set down 5k down on shear pin guide sub on top of stump. 02:00 03:00 1.00 10,040 10,040 COMPZ RPCOM CIRC T Circ on top of stump @ 7 bpm, 1200 psi staging up to 8 bpm 1500 psi, 57%flow until hole cleaned up. 03:00 03:15 0.25 10,040 10,040 COMPZ RPCOM OWFF T Monitor well(STATIC) 03:15 03:30 0.25 10,040 9,983 COMPZ RPCOM TRIP T POOH 2 jts from 10040'MD to 9983' MD. 03:30 06:45 3.25 9,983 429 COMPZ RPCOM TRIP T POOH from 9983'MD to 429'MD. Act fill=67.2 bbls, Calc fill=65.99 fill. 06:45 07:00 0.25 429 429 COMPZ RPCOM OWFF T Monitor well(STATIC) 07:00 08:00 1.00 429 0 COMPZ RPCOM PULD T Rack back 3 stands Drill Collars and L/D BHA as per Baker Rep. 08:00 08:15 0.25 0 0 COMPZ RPCOM RURD T Clean and clear rig floor. 08:15 09:30 1.25 0 333 COMPZ RPCOM PULD T PJSM, P/U and M/U wash pipe BHA per Baker Rep. P/U 3 stands drill collars. 09:30 12:00 2.50 333 4,115 COMPZ RPCOM TRIP T RIH w/wash pipe from 333'MD to 4115'MD,Act disp=26.6 bbls,Cale disp=29.47 bbls. Page 66f13 lime Lbgs„t .,w. P N8 nm ti 5 9 �I @VPi� � :�1 I ipi7a�M:� i io�iM1'�i i i �, � t �� bate From �dt S. Depth E.Deoth Phase Code Subcode T Co met o 12:00 14:45 2.75 4,115 9,887 COMPZ RPCOM TRIP T RIH w/wash pipe from 4115'MD to 9883'MD,Act disp= bbls, Calc disp= bbls. 14:45 15:45 1.00 9,887 9,935 COMPZ RPCOM TRIP T PJSM, Cont RIH from 4115'MD to 9883'MD. 15:45 16:30 0.75 9,935 9,935 COMPZ RPCOM CIRC T Circ 1.5 bottoms up @ 12 bpm,2100 psi 16:30 16:45 0.25 9,935 9,915 COMPZ RPCOM RURD T L/D single R/U to reverse circ. 16:45 17:30 0.75 9,915 9,934 COMPZ RPCOM CIRC T Go back down to 9934'MD, Rev Circ @ 6bpm=950 psi. 17:30 18:00 0.50 9,934 9,934 COMPZ RPCOM OWFF T PJSM, L/D 2 single, R/D, B/D lines, Monitor well(STATIC) 18:00 21:00 3.00 9,934 333 COMPZ RPCOM TRIP T PJSM, POOH for 9918'MD. 21:00 21:15 0.25 333 333 COMPZ RPCOM OWFF T Monitor well(STATIC). 21:15 22:30 1.25 333 0 COMPZ RPCOM PULD T PJSM,stand back 3 stands Drill Lollars, L/D BHA. 22:30 22:45 0.25 0 0 COMPZ RPCOM RURD T Clean and clear rig floor. 22:45 00:00 1.25 0 16 COMPZ RPCOM PULD T P/U Guide shoe BHA. X9/23/2013 R/U and RIH w/RCT on E-line, cut tbgt below GLM @ 9967'. POOH with E-Line and R/D. M/U Fishing BHA and RIH to fish GLM. 00:00 01:30 1.50 16 2,945 COMPZ RPCOM TRIP T PJSM, RIH w/wireline entry guide assembly from 16'MD to 2945'MD. 01:30 01:45 0.25 2,945 2,945 COMPZ RPCOM CIRC T Pump 18 bbls 10 ppg slug due to fluid over flowing pipe on trip in. 01:45 04:15 2.50 3,945 9,570 COMPZ RPCOM TRIP T Cont RIH from 2945'MD to 9570' MD.Act disp=60.60 bbls, Calc disp =63.06 bbls. 04:15 04:30 0.25 9,570 9,882 COMPZ RPCOM PULD T P/U singles from pipe shed from 9570'MD to 9882'MD. 04:30 05:15 0.75 9,882 9,917 COMPZ RPCOM WASH T M/U to top drive,establish parameters, P/U wt= 145k, S/0 wt = 105k, Rot wt= 122k,TQ=5k. S/O to tubing stub set down 3k @ 9913' MD, P/U 8', Rot 20 rpm,S/O and ream over tubing stub,set down 3k @ 9913'MD. P/U 8'Rot 30 rpm, Ream down over tubing stub,set down 5k. Cut lip @ 9917'MD,Top stub @ 9913'MD. P/U 6"and set slips. 05:15 05:30 0.25 9,917 9,917 COMPZ RPCOM RURD T M/U X-Over to string. 05:30 07:00 1.50 9,917 9,917 COMPZ RPCOM PULD T PJSM, P/U and M/U cutter as per Halliburton Rep. 07:00 09:00 2.00 9,917 9,917 COMPZ RPCOM ELNE T RIH w/cutter on E-Line,cut @ 9967' (E-Line depth) 09:00 10:15 1.25 9,917 9,917 COMPZ RPCOM RURD T Talk to Company Rep about cut. R/D E-Line as per Halliburton Rep. 10:15 10:30 0.25 9,917 9,854 COMPZ RPCOM PULD T POOH from 9917'MD to 9854'MD. L/D 2 jts, 1 pup jt and crossover. 10:30 11:30 1.00 9,854 9,854 COMPZ RPCOM SLPC T PJSM, Slip and cut drilling line, 11 wraps(72'). Page 7 of'13 • Tame LOgS k 3 98 rMii ii g P 11")0 h11 Date From To f,r hDur S.Deoth E.Depth"Phase Code' Subcotfe,«T"tbomment 11:30 12:00 0.50 9,854 9,854 COMPZ RPCOM SVRG P Service rig. 12:00 16:00 4.00 9,854 116 COMPZ RPCOM TRIP T POOH from 9854'MD to 116'MD. Actual displacement=64.4 bbls, Calculated displacement=62.69 bbls. 16:00 16:15 0.25 116 116 COMPZ RPCOM OWFF T Monitor well(STATIC). 16:15 16:45 0.50 116 0 COMPZ RPCOM PULD T PJSM, L/D BHA as per Baker Rep. 16:45 17:15 0.50 0 0 COMPZ RPCOM RURD T Clean and clear rig floor 17:15 18:30 1.25 0 315 COMPZ RPCOM PULD T PJSM, P/U BHA#5. I 18:30 19:15 0.75 315 2,018 COMPZ RPCOM TRIP T PJSM, RIH from 315' to 2018'. 19:15 19:45 0.50 2,018 2,018 COMPZ RPCOM SVRG P Service rig 19:45 00:00 4.25 2,018 7,602 COMPZ RPCOM TRIP T Cont RIH f/2018'to 7602'.Actual displacement=47.65 bbls, Calculated displacement=50.31 bbls. 39/24/2013 RIH and engaged fish, pumped fish free.CBU X 2 and POOH. L/D BHA and fish. M/U washover BHA and RIH. Washed over tbg stub down to top of PBR @ 10020'.CBU X 2 and POOH. 00:00 00:45 0.75 7,602 9,865 COMPZ RPCOM TRIP T PJSM, RIH f/7602'to 9865'.Actual displacement= 14.7 bbls, Calculated displacement= 15.6 bbls. 00:45 01:15 0.50 9,865 9,913 COMPZ RPCOM FISH T Make up top drive @ 9865', Est parameters, P/U= 155K, S/O= 107K, ROT= 130K,Tq=5K. Pump @ 3 BPM=400 PSI w/50%flow.Wash down to top of 3-1/2"tbg stub @ 9913.5'and set down 3K. P/U and rotate @ 20 RPMs,wash down to top of stub and set 2K down,stalled out w/6.5K Tq. Release torque and P/U, observed 10K overpull. S/0 to 9919'and set down 10K,fully engaged. P/U to 20K overpull and increased pumps to 5 BPM=700 PSI, observed weight decrease, pumping sand away from fish. P/U to 45K overpull and observed weight decrease one again and drill string raise. P/U 5'no overpull,fish free from sand. 01:15 02:00 0.75 9,913 9,913 COMPZ RPCOM CIRC T Circulate hole clean @ 8 BPM= 1150 PSI. 02:00 02:15 0.25 9,913 9,866 COMPZ RPCOM CIRC T Obtain SPR @ 9914'with 9.6 ppg viscosified brine. Stand back one stand to 9866'and blow down top drive. 02:15 02:45 0.50 9,866 9,866 COMPZ RPCOM OWFF T OWFF,static. 02:45 07:00 4.25 9,866 315 COMPZ RPCOM TRIP T POOH f/9866'to 315'.Actual displacement=67.20 bbls, Calculated displacement=65.90 bbls. Page 8of13 410 ime Logs i XI Date from' o Our S Deb h .IlDeofh Phase Code .Subcode,r,.T ornr»enf : 1 l 1di11 07:00 08:45 1.75 315 0 COMPZ RPCOM PULD T OWFF,static. Stand back drill collars and L/D BHA as per Baker rep. Recovered GLM,2 pups and 2 cut joints,total length=50.22'. 08:45 09:15 0.50 0 0 COMPZ RPCOM PULD T Clean and clear rig floor. 09:15 12:00 2.75 0 370 COMPZ RPCOM PULD T PJSM, M/U Wash pipe BHA as per Baker rep, 12:00 19:15 7.25 370 9,920 COMPZ RPCOM TRIP T PJSM, RIH f/370'to 9920'.Actual displacement=60.55 bbls, Calculated displacement=66.31 bbls. 19:15 19:30 0.25 9,920 9,920 COMPZ RPCOM FCO T Establish parameters, P/U= 157K, S/O= 105K, ROT= 128K,Tq=6.5K, Pump @ 3 BPM=400 PSI. 19:30 20:15 0.75 9,920 10,020 COMPZ RPCOM FCO T Wash down to the top of the tbg stub @ 9964', set down 4K and P/U 6'. Rotate @ 30 RPM's,wash and ream over tbg stub to 9970'. Stop rotary, P/U 5'and increase pump to 5.5 BPM=800 PSI,cont.to wash down cleaning out frac sand.Took weight @ DS nipple(9980')P/U and rotate @ 20 RPMs,wash and ream over DS nipple to 9988'. Stop rotary, P/U 5'and cont.washing down increasing pump rate to 6.5 BPM=1000 PSI. Observed slight bobble @ tbg collar (10012')cont.washing down to top of PBR @ 10020', set down 5K and P/U 2'. 20:15 20:45 0.50 10,020 10,018 COMPZ RPCOM CIRC T CBU X 2 @ 12 BPM=2350 PSI. 20:45 21:00 0.25 10,018 9,921 COMPZ RPCOM TRIP T Shut down pumps, P/U 3'and S/O to set down 6K on PBR. Confirmed top @ 10020',stand back 2 stands to clear tbg stub. 21:00 21:15 0.25 9,921 9,921 COMPZ RPCOM OWFF T OWFF,static. Blow down top drive. 21:15 00:00 2.75 9,921 2,732 COMPZ RPCOM TRIP T POOH f/9921'to 2732'.Actual displacement=44.8 bbls, Calculated displacement=45 bbls. 39/25/2013 Cont/POOH. R/U and test BOPE to 250/4000 PSI,Annular to 250/3500 PSI, Jeff Jones of AOGCC waived witness of test. M/U BHA and RIH,jar seal assy free. Circulate sweep around, POOH and L/D fish. 00:00 00:30 0.50 2,732 367 COMPZ RPCOM TRIP T PJSM, POOH f/2732'to 367'.Actual displacement=22.40 bbls, Calculated displacement=21.31 bbls. 00:30 00:45 0.25 367 367 COMPZ RPCOM OWFF T OWFF,static. 00:45 01:45 1.00 367 0 COMPZ RPCOM PULD T Stand back 3 stands on drill collars, L/D wash pipe BHA as per Baker rep. 01:45 02:00 0.25 0 0 COMPZ RPCOM PULD T Clean and clear rig floor. 02:00 02:15 0.25 0 0 COMPZ WHDBOSFTY T Hold PJSM on rigging up testing equipment. Page 9 of 13 • Time-og& t .. o 'bate From Tx Dur 5,y'Deoth E.Depth Phase Code 1!'Subcode Tom'Comment '2h 02:15 03:30 1.25 0 0 COMPZ WHDBO SEQP T Drain stack, remove wear bushing and set test plug. R/U BOP testing equipment. 03:30 09:00 5.50 0 0 COMPZ WHDBO BOPE T Test BOPE to 250/4000 PSI with 3-1/2"and 4"test joints for 5 min each,Annular to 250/3500 PSI.Test #1:Top pipe rams, CV 1,12,13,14, and manual kill. Test#2: Upper IBOP, HCR Kill, CV 9 and 11. Test #3: Lower IBOP,CV 5,8 and 10. Test#4: Dart valve, CV 4,6 and 7. Test#5: Floor valve and CV 2, CV 2 failed, installed valve packing and retested-good. Test#6: HCR choke, 4"kill line demco. Test#7: Manual choke and HCR kill. Test#8: Annular preventer to 250/3500 PSI. Test#9: Lower pipe rams. Test#10: Blind rams and CV 3. System pressure=3000 PSI, pressure after closing= 1700 PSI,200 PSI attained after 29 sec,full pressure attained after 161 sec. Five bottle nitrogen avg.=2000 PSI.Jeff Jones of AOGCC waived wittiness of test. 09:00 09:30 0.50 0 0 COMPZ WHDBO RURD T R/D BOP testing equipment, blow down kill and choke lines and set wear bushing. 09:30 10:45 1.25 0 317 COMPZ RPCOM PULD T PJSM, P/U and M/U fishing BHA, (overshot w/3-1/2"grapple)as per Baker rep. 10:45 15:15 4.50 317 9,903 COMPZ RPCOM TRIP T PJSM, RIH f/317'to 9903'.Actual displacement=60.5 bbls, Calculated displacement=62.2 bbls. 15:15 15:30 0.25 9,903 9,903 COMPZ RPCOM FISH T Establish parameters, P/U= 165K, S/O= 104K, ROT=128K, Tq=6.5K. 15:30 15:45 0.25 9,903 9,971 COMPZ RPCOM FISH T Wash down @ 3 BPM=400 PSI f/ 9903'to 9964'.tag up on tbg stub. P/U 5'and ROT @ 30 RPM's, S/O over tbg stub and observed pressure increase. P/U and shut down pumps, S/O and set 10K down on tbg stub @ 9971',fully engaged. 15:45 16:15 0.50 9,971 9,939 COMPZ RPCOM FISH T P/U and fire jars twice @ 40K overpull and twice @ 50K overpull, staged up to 100K overpull then 140K straight pull after jars fired. Turn on pumps and increase pump pressure to 1000 PSI,observed string weight decrease from 310K to 170K. P/U 20', pulled seal assy free. 16:15 18:00 1.75 9,939 9,903 COMPZ RPCOM CIRC T CBU then pump 30 bbls of high vis sweep around @ 7 BPM=950 PSI. Minimal increase of sand observed with the sweep. 18:00 18:30 0.50 9,903 9,903 COMPZ RPCOM OWFF T OWFF,static. Blow down top drive. Page 10 Of13 • • � flme Logs ,m,,oilii . w�ii ;. I q1WPii4oadl01111ih Date ,,From To Our „,.. S. Debth E Depth.=Phase, Code Subco e' T omm€nt uu iia 18:30 21:45 3.25 9,903 317 COMPZ RPCOM TRIP T POOH f/9903'to 317'. OWFF @ dill collars,static. 21:45 23:00 1.25 317 112 COMPZ RPCOM PULD T PJSM,stand back drill collars. UD pump out sub,jars and bumper sub. Break apart overshot and UD cut joint/grapple. 23:00 00:00 1.00 112 0 COMPZ RPCOM PULD T UD fish; 1 cut joint, 1 full joint DS nipple and Seal Assy=67.2'.Actual displacement=66.28 bbls, Calculated displacement=65.93 bbls. 09/26/2013 M/U scraper BHA and RIH to top of PBR, rev circ hole clean. RIH and clean out PBR to 10046'CBU , POOH to 9987',test 7"casing to 2500 PSI. Slip and cut drilling, POOH and L/D BHA. RIH w/3-1/2"completion as per detail. 00:00 00:15 0.25 0 0 COMPZ WELLPF PULD P Clean and clear Baker tools off rig floor. 00:15 01:30 1.25 0 338 COMPZ WELLPF PULD P PJSM, P/U and M/U Scraper BHA as per Baker rep. 01:30 05:00 3.50 338 9,987 COMPZ WELLPF TRIP P RIH 338'to 9987', P/U= 155K, S/O= 105K.Actual displacement=64.75 bbls, Calculated displacement= 66.49 bbls. 05:00 05:15 0.25 9,987 10,016 COMPZ WELLPF TRIP P P/U single and RIH to 10016', R/U to reverse circulate. 05:15 05:45 0.50 10,016 10,016 COMPZ WELLPF CIRC P Reverse circulate @ 5.5 BPM=850 PSI,observed a moderate amount of sand at shakers. 05:45 06:30 0.75 10,016 10,046 COMPZ WELLPF FCO P UD working single. M/U stand and RIH to 10,020'(top of PBR, rig observed depth)S/0 to 10030'took 2K, P/U 5'and establish circulation @ 6 BPM=800 PSI.Wash down to 10046',took 3K string weight, confirmed solid tag @ 10046'. 06:30 07:00 0.50 10,046 10,046 COMPZ WELLPF CIRC P Circulate surface to surface @ 8.5 BPM= 1400 PSI, 58%flow. 07:00 07:30 0.50 10,046 9,984 COMPZ WELLPF TRIP P POOH f/10046'to 9984', blow down top drive and R/U to test 7"casing. 07:30 08:15 0.75 9,984 9,984 COMPZ WELLPF PRTS P Test 7"casing to 2500 PSI for 30 minutes,good. 08:15 09:15 1.00 9,984 9,984 COMPZ WELLPF SLPC P PJSM,slip and cut 59'(9 wraps)of drilling line. 09:15 12:30 3.25 9,984 317 COMPZ WELLPF TRIP P PJSM, POOH f/9984'to 340'.Actual displacement=68.1 bbls, Calculated displacement=66.49 bbls. 12:30 12:45 0.25 317 317 COMPZ WELLPF OWFF P OWFF @ drill collars,static. 12:45 14:00 1.25 317 0 COMPZ WELLPF PULD P PJSM, UD clean out BHA as per Baker rep. 14:00 14:45 0.75 0 0 COMPZ RPCOM RURD P Clean and clear rig floor and pull waer bushing. 14:45 15:30 0.75 0 0 COMPZ RPCOM SFTY P Hold PJSM on running 3-1/2" completion. 15:30 23:45 8.25 0 9,855 COMPZ RPCOM RCST P Run 3-1/2"completion as per detail to 9855',Actual displacement=34.65 bbls, Calculated displacement=33.6 bbls. Page 14 of 13 . . • • Time cede z1V I o i bate `^ry` From To -butt S.1Deoth"E.Oeoth Phase. Code 01Subcode rN'IriComment .,001 ,% 09/27/2013 24 hr Summary Cont RIH w/3-1/2"completion, land tbg 3.7'off located position.Test tbg to 3000 PSI and annuals to 2500 PSI. N/D BOPE and N/U tree,test tree to 5000 PSI. Freeze protect well with 75 bbls of diesel and L/D 4"drill pipe. 00:00 00:45 0.75 9,855 10,021 COMPZ RPCOM RCST P RIH and tag top of PBR @ 10021', set down 5K. P/U and establish circulation @ 1.5 BPM= 150 PSI., slack off and observed pressure increase as seals entered the PBR. Shut down pumps and fully locate on no-go. P/U to top of PBR @ 10021'. P/U= 105K,S/O=68K. 00:45 01:30 0.75 10,021 10,029 COMPZ RPCOM HOSO P Space out as per Co Rep and Baker. P/U 2 pup joints, 2.40'and 8.25'.and one full joint, M/U hanger and landing joint. 01:30 01:45 0.25 10,029 10,029 COMPZ RPCOM RURD P Rig up to reverse circulate well. 01:45 02:00 0.25 10,029 10,029 COMPZ RPCOM SFTY P Hold PJSM on reverse circulating in Inhibited brine. 02:00 03:45 1.75 10,029 10,029 COMPZ RPCOM CIRC P Reverse circulate,pump 65 bbls of 9.6 ppg clean brine,275 bbls of 9.6 ppg inhibited brine(1%CRW-132) followed by 10 bbls of fresh water to clear lines. 03:45 04:15 0.50 10,029 10,029 COMPZ RPCOM THGR P Land tubing hanger as per FMC, RILDs. Landed 3.7'off located position. 04:15 06:00 1.75 0 0 COMPZ RPCOM PRTS P With IA open,test 3-1.2"tbg to 3000 PSI for 15 minutes,good. Bleed tbg to 1500 PSI,while holding 1500 PSI on tbg test IA to 2500 PSI for 30 minutes,good. Bleed off tbg and IA pressure, ramp up and shear SOV @ 2100 PSI.All tests on chart. 06:00 06:30 0.50 0 0 COMPZ RPCOM OWFF P OWFF,static. 06:30 07:00 0.50 0 0 COMPZ RPCOM SEQP P Install FMC BPV and test to 1000 PSI from below. 07:00 07:30 0.50 0 0 COMPZ WHDBO RURD P Blow down cement lines in cellar, kill and choke lines. Flush pumps with fresh water, pull mouse hole and clean floor. 07:30 09:15 1.75 0 0 COMPZ WHDBO NUND P PJSM, N/D BOPE and set back. 09:15 12:45 3.50 0 0 COMPZ WHDBO NUND P Prep hanger, pick up tree adapter flange and set as per DSO. M/U tree and tighten bolts. 12:45 14:00 1.25 0 0 COMPZ WHDBO RURD P R/U to test tree and build scaffolding in cellar. 14:00 15:15 1.25 0 0 COMPZ WHDBO PRTS P PJSM, R/U Lubricator,test to 250/1000 PSI and pull BPV 15:15 16:30 1.25 0 0 COMPZ WHDBO PRTS P Set tree test plug and test tree to 250/5000 PSI for 5 minutes. Pull tree test plug. 16:30 17:00 0.50 0 0 COMPZ WHDBO RURD P R/U to freeze protect well. Page'12 of 13 • F.m �O? VI iii I e g S x oil i a1i01;hilll ■Date 2From:r To " �Our S. Depth E. Depth Phase Code Subcode T' Com errt - �l 17:00 19:00 2.00 0 0 COMPZ WHDBO FRZP P PJSM, pressure test lines to 250/2000 PSI. Freeze protect well, pump 75 bbls of diesel down IA @ 1 BPM=250 PSI. SIMOPS, R/U to L/D drill pipe. 19:00 22:00 3.00 0 0 COMPZ WHDBO FRZP P Allow well to U-tube, SIMOPS L/D 4" drill pipe in derrick. 22:00 00:00 2.00 0 0 COMPZ WHDBO PULD P Set BPV, L/D lines and cont.to lay down drill pipe. 09/28/2013 Cont. L/D drill pipe, R/D and release rig @ 4:00 hours. 00:00 04:00 4.00 0 COMPZ WHDBO PULD P Cont. LID drill pipe, R/D and release rig @ 4:00 hours. II Page 13 of'13 • • 2_0'7 - 05i WELL LOG TRANSMITTAL DATA LOGGED \.ONO/2013 M K BENDER To: Alaska Oil and Gas Conservation Comm. September 23, 2013 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 OLT 1 0 2O1., RE: Radial Cutting Torch Record: 1C-19 Run Date: 9/19/2013 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Matthew Cook, Halliburton Wireline& Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 matthew.cook@halliburton.com 1C-19 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-23149-00 pN DEC 0 2D13 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline&Perforating Attn: Matthew Cook 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook@halliburton.com Date: '.o(\o j'3 Signed: f.)) • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 10, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Bottom Hole Pressure Survey: 1C -19 Run Date: 5/8/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1C -19 Digital Data in LAS format, Digital Log Image file 1 g 1 CD Rom 50- 029 - 23149 -00 Bottom Hole Pressure Survey Log 1 Color Log 50- 029 - 23149 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 kinton .wood @halliburton.com Date: ! ( YOU 1 I Signed: U id 0161 6 S--ti • • "'~'_-~ MICROFILMED 03/01/2008 DO NOT PLACE ~.r«` ~_~ ~` ~, .-~ .; ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFiche\CvrPgs_Inserts\Miicrofilm Marker.doc . . ~ ConocoPhillips Alaska JUL 0 3 2007 8~ Gas Cons, P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 2, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 ab3-0SLt 5(.;ANNED JUL 0 5 ZOO? Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Some of these wells were found to have a void in the conductor by surface casing annulus. The volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Please call Perry Klein or M.J. Loveland at 907-659-7043, if you have any questions. ~~ M.J. Loveland ConocoPhillips Well Integrity Supervisor c-----/ . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/1/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft na qal 1C-19 203-054 28" none 28" na 12 6/24/2007 1 C-123 201-084 22" none 22" na 24 7/1/2007 1C-127 201-114 18" none 18" na 12 7/1/2007 1 C-133 201-077 16" none 16" na 8.5 7/1/2007 1 C-190 203-003 27" none 27" na 10 6/24/2007 ill .xx ¡W?m';¡m;¡;¡;¡;¡¡¡;¡;¡¡¡¡m¡! - tx ¡II ::,::,XX'ii';;'! 3K-12 186-165 none 6" na 3 6/24/2007 3K-19 201-108 6" none 6" na 3 6/24/2007 3K-20 201-088 4" none 4" na 1 6/24/2007 3K-23 197-097 8" none 8" na 5 6/24/2007 3K-24 198-249 4" none 4" na 1 6/24/2007 3K-25 198-081 6" none 6" na 3 6/24/2007 3K-26 197-077 8" none 8" na 5 6/24/2007 3K-27 197-046 6" none 6" na 3 6/24/2007 3K-31 198-082 8" none 8" na 5 6/24/2007 3K-34 198-077 7" none 7" na 4 6/24/2007 3K-35 197-109 3" none 3" na 2 6/24/2007 ) £> JVit" ,,~~ ç~ .J DATA SUBMITTAL COMPLIANCE REPORT 7/6/2005 Permit to Drill 2030540 Well Name/No. KUPARUK RIV UNIT 1C-19 Operator CONOCOPHILLlPS ALASKA INC fi1~ )fYbf. ~~) API No. ~~029-23149-00-00 MD 10435 ./ TVD 6794./ Completion Date 6/18/2003./ Completion Status 1-01L Current Status 1-OIL UIC N - "--------- -~---- REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes - -------- ------- -------------- DATA INFORMATION Types Electric or Other Logs Run: GRlReslDensity-Neutron Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name (data taken from Logs Portion of Master Well Data Maint) Rpt : Log 12064 LIS Verification 12064 Induction/Resistivity Log Log Run Interval OH/ -- Scale Media No Start Stop CH Received Comments Final 0 10435 Open 5/29/2003 MWD 1-3 6744 10435 Open 7/28/2003 25 Final 138 10435 Open 7/28/2003 RWD - Caliper Corrected Neutron, Optimized Density - MD 25 Final 138 1 0435 Open 7/28/2003 RWD - Caliper Corrected Neutron, Optimized Density - TVD 25 Final 138 10435 Open 7/28/2003 RWD - Multiple Propagation Resistivity, Gamma Ray - MD 25 Final 138 10435 Open 7/28/2003 RWD - Multiple Propagation Resistivity, Gamma Ray - TVD -- 25 Final 138 1 0435 Open 7/28/2003 RWD - Caliper Corrected Neutron, Optimized Density - MD 25 Final 138 10435 Open 7/28/2003 RWD - Caliper Corrected Neutron, Optimized Density - TVD 1-3 6744 10435 Open 7/28/2003 25 Blu Final 138 1 0435 Open 7/28/2003 RWD - Multiple Propagation Resistivity, Gamma Ray - MD 25 Blu Final 138 10435 Open 7/28/2003 RWD - Multiple Propagation Resistivity, Gamma Ray - TVD - - -------- ---- Rpt Directional Survey ED C Asc 12064 LIS Verification ED C Pds 12064 Neutron I ,ED C Pds 12064 Neutron ED C Pds 12064 I nd uction/Resistivity ED C Pds 12064 Induction/Resistivity ED C Pds 12064 Density ¡ED C Pds 12064 Density Log 12064 Induction/Resistivity DATA SUBMITTAL COMPLIANCE REPORT 7/6/2005 Permit to Drill 2030540 Well Name/No. KUPARUK RIV UNIT 1C-19 MD 10435 Log TVD 6794 - - -------- 12064 Density Log 12064 Density ~ Perforation Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y (0 Chips Received? ~ Analysis _ Y / N Received? . - - -- --- - ------ ------_.- ----- Comments: --- --------------- ------------ Compliance Reviewed By: Completion Date 6/18/2003 Interval Start Stop ~ ~ Operator CONOCOPHILLlPS ALASKA INC Completion Status 1-01L Current Status 1-01L 25 Blu Final 138 10435 Open 7/28/2003 25 Blu Final 138 10435 Open 7/28/2003 5 Blu 9840 10337 Case 7/23/2003 Sent Sample Set Number Comments Received Daily History Received? t})N ®N Formation Tops Date: API No. 50-029-23149-00-00 UIC N RWD - Caliper Corrected Neutron, Optimized Density - MD RWD - Caliper Corrected Neutron, Optimized Density - TVD Perforating Record, Jewelry Log/SBHPS ---~.' cf ~ ~O -' 1 . Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation 10. (h)(1) drilling mud, drilling cuttings, reserve pit fluids cement-contaminated drilling mud, completion fluids, formation fluids and any necessary water added D or Final 0 (h)(2) drill rig wash fluids and drill rig domestic waste water Previous totals (bbls): 2003 / 2nd 31325 100 2003 / 3rd 0 0 2003 / 4th 0 0 2004/1st 0 0 Total Ending Volume 31325 100 (bbls): STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 4a. Well Class: Stratigraphic D Service D Development 0 Exploratory D 4b. Well Status: Oil 0 Gas D WAGD GINJ D WINJ D WDSPL D Sa. Sundry number: Sb. Sundry approval date: 303-148 (h)(3) Other Commission approved substances (include descriptions in block 12) 5/16/2003 Volume (bbls): Number of days disposal occurred 6. Permit to Drill Number: 7. Well Name: 8. API Number: 203-054 1 C-19 .~ 0 31425 35 5/13/2003 6/24/2003 1 C-170, 1 C-184, 1 C-172 0 0 0 0 0 0 0 0 0 ¡ ~ o 31425 11. Attach: Disposal Performance Data: Pressure vs. Time D Other (Explain) D 12. Remarks and Approved Substances Description(s): Step Rate Test D I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~~' ~ ~ Printed Name: Randy Thomas Form 10-423 Rev. 2/2004 Date: Title: Kuparuk Drilling Team Leader INSTRUCTIONS ON REVERSE SIDE 35 50-029-23149-00 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: Report is due on the 20th of the month fol/owing the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. 7(210€.-( Phone Number: (907) 265-6830 Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: 4a. Well Class: Stratigraphic D Service D Development [2] Exploratory D 4b. Well Status: Oil [2] Gas D WAGD GINJ D WINJ D WDSPL D Sa. Sundry number: 5b. Sundry approval date: 6. Permit to Drill Number: 7. Well Name: 8. API Number: 203-054 1 C-19 P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation 10. (h)(1) drilling mud, drilling cuttings, reserve pit fluids cement-contaminated drilling mud, completion fluids, formation fluids and any necessary water added 50-029-23149-00 9. Field: o or Final D (h)(2) drill rig wash fluids and drill rig domestic waste water 303-148 (h)(3) Other Commission approved substances (include descriptions in block 12) 5/16/2003 Volume (bbls): Number of days disposal occurred Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: ~ Previous totals (bbls): 2003 1 2nd 31325 100 0 31425 35 5/13/2003 6/24/2003 1C-170, 1C-184, 1C-172 2003 1 3rd 0 0 0 0 0 2003 14th 0 0 0 0 0 20041 1st 0 0 0 0 0 ~ Total Ending Report is due on the 20th Volume 31325 100 0 31425 35 (bbls): of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time D Step Rate Test D October 20 for the third quarter, and January 20 for the Other (Explain) D fourth quarter. 12. Remarks and Approved Substances Description(s): I hereby certify that the foregoing is true and correct to the best of my knowledge. ~\ ~~~~ ~~'-oJt ~c.-.- S ) Signature: Date: l-( /r 6/0'1 Printed Name: Title: ~~lj re~..._ Lc~J Phone Number: L.6S' b~~o Form 10-423 Rev. 9/2003 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation of Disposal 0 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added Previous totals (bbls): 2003 / 2nd 8297 100 2003 / 3rd 22928 100 2003 / 4th 2004 / 1 st Total Ending Volume (bbls): 31225 200 11. Attach: Disposal Performance Data: Other (Explain) D 12. Remarks and Approved Substances Description(s): Pressure vs. Time 0 4a. Well Class: Stratigraphic D Service D Development 0 Exploratory D 4b. Well Status: Oil 0 Gas D WAGD GINJ 0 WINJ D WDSPL D Sa. Sundry number: 5b. Sundry approval date: 303-148 (h)(3) Other Commission approved substances (include descriptions in block 12) 5/16/2003 Volume (bbls): Number of days disposal occurred o 8397 o 23028 23 o 31425 35 Step Rate Test 0 I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: ~ ~ - Printed Name: ~"..( y \'L....,..... __-a .3 Title: Form 10-423 Rev. 9/2003 Date: ~ t-S Te-r..... L.£-..( INSTRUCTIONS ON REVERSE SIDE 6. Permit to Drill Number: 7. Well Name: 8. API Number: 203-054 1 C-19 50-029-23149-00 9. Field: Kuparuk River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: J -' 12 5/13/2003 5/31/2003 1C-170,1C-184 6/2/2003 6/24/2003 1 C-184, 1 C-172 ~' Report is due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. t (ê..t; (0 "1 Phone Number: ZGr b-B 30 Submit in Duplicate (903 -ost..l Annular Disposal during the second quarter of 2003: h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes 3S-10 9972 100 0 10072 388 21204 31664 March April 3S-21, 3S-08, 3S-23 2003 2003 1C-22 21553 100 0 21653 0 27044 48697 March May lC-190, lC-174, lC-178, lC-19 2003 2003 Puviaq #1 5063 100 0 5163 0 4731 9894 March April Puviaq 1 ') 2003 2003 CD2-46 31393 100 0 31493 371 0 31864 April May 2003 CD2-51, CD2-12 2003 3S-16 31006 100 0 31106 357 0 31463 April May 2003 3S-23, 3S-17, 3S-06, 3S-16 2003 Hansen 1 47382 100 0 47482 0 67796 115278 January June 2003 Hansen, Hansen 1 A 2002 1C-19 31325 100 0 31425 0 0 31425 May 2003 June 2003 lC-184, lC-170, lC-172 3S-08B 31610 100 0 31710 290 0 32000 May 2003 June 2003 3S-24,3S-03,3S-19 CD2-19 30860 100 0 30960 377 0 31337 May 2003 June 2003 CD2-58, CD2-52 CD2-41 3900 100 0 4000 377 0 4377 June 2003 June 2003 CD2-20 3S-17A 4559 100 0 4659 361 5020 5020 June 2003 June 2003 3S-19 Total Volumes into Annuli for which Disposal Authorization Expired during the second quarter 2003: ) Freeze Protect Total Volume Start End Source Wells Total h(l) Total h(2) Total h(3) Fluids Injected Date Date Well Name Volume Volume Volume Volume Status of Annulus CD2-17 17709 100 0 372 18181 Open, Freeze Protected May 2002 Feb 2003 CD2-08, CD2-48, CD2- 46 CD2-32 31337 100 0 379 31816 Open, Freeze Protected June 2002 July 2002 CD2-19, CD2-41, CD2- 23 CD2-50 31530 100 0 370 32000 Open, Freeze Protected July 2002 Sept 2002 CD2-41, CD2-38 1D-11 32102 100 0 235 32437 Open, Freeze Protected May 2002 June 2002 1 D-l 03 1C-18 32251 100 0 373 32724 Open, Freeze Protected June 2002 July 2002 lC-104 ) ConocóPhillips Mike Mooney ) Wells Group Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 October 28,2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 1C-19 (APD # 203-054) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operation on the Kuparuk well 1 C-19. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, ¡/l ( ;l// trI~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells REceIVED fl. I,·,.. j ,):: 1 ,... 200J ¡,ija$l{a 01! & Gas C/U'i~ C. . J"'~U...t. :.Iamm~jl't,.¡ 1:1,. ~ ~~Uß fiJ;C~~@fJ:;a . MM/skad 1\, ! Abandon Alter Casing Change Approved Program 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): RKB 28',87' AMSL 8. Property Designation: ADL 25649 & 28242, ALK 467 11. Present Well Condition Summary: 1. Operations Performed: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE PRODUCTION Perforation depth: ') STATE OF ALASKA ) ALASKA OILAND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS D Suspend D Operation Shutdown D D Repair Well D Plug Perforations D D Pull Tubing D Perforate New Pool D Variance D Annular Disp. D D D Perforate D Stimulate 0 Time Extension Other D 4. Current Well Status: Development 0 Stratigraphic D Re-enter Suspended Well 5. Permit to Drill Number: 203-054/ 6. API Number: 50-029-23149-00 Exploratory Service D D 9. Well Name and Number: 1 C-19 10. Field/Pool(s): Kuparuk River Field 1 Kuparuk Oil Pool measured 10435' feet true vertical 6794' feet measured 10308' feet true vertical 6685' feet Length Size MD 122' 16" 122' 6716' 9-5/8" 6744' 10400' 7" 10428' Plugs (measured) Junk (measured) TVD Burst Collapse 122' 4474' 6788' Measured depth: 10150' - 10180' RECEIVED l\,','J \/ 1 \~. 2003 ¡¢~i'~si-a O~! & ~ ,.,. ~'"¡, R 8u... Ï\Jas, \,¡OílS. CommiSSjOf, A~~(i'1m1'2:~~~ true vertical depth: 6551' - 6576' Tubing (size, grade, and measured depth) 3-1/2" , L-80, 10066' MD. Packers & SSSV (type & measured depth) Baker'SAB-3' packer @ 10036' Camco '0' Landing Nipple nipple = 497' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 10150' - 10180' pumped 142204# 16/20 proppant Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casinç¡ Pressure Tubinq Pressure Prior to well operation 586 1060 42 239 Subsequent to operation 1624 2111 303 398 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory D Development 0 Service D Daily Report of Well Operations _X 16. Well Status after proposed work: oil0 GasD WAGD GINJD WINJ D WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Printed Name Signature Mike Mooney @ 263-4574 Mike Mooney !:(. ;J/~ Title Phone Wells Group Team Leader Date II f¡~, :3 Prepared by S';:¡' ~:SUP-Drake 263-4612 -, : I,' .,'," . \\ /\ ~ tlJy I ð 'jiJra SUBMIT IN DUPLICATE Form 10-404 Revised 2/2003 · IAIOIS 18!F1L" ' ') ~) ConocoPhillips Alaska, Inc. 1C-19 TUBING (0-10066, OD:3.500, ID:2.992) FRAC (10150-10180) II~ ~ :~ ,I ll---c; ..,::': , ". . ,: :,~ _ð ]i1I': 1 f: .~~.... ]il-~ II I;;. ~ [] ~ KRU 1C-19 API: 500292314900 SSSV Type: NIPPLE Angle@TS: 33 deg @ 10144 Angle@TD: 31 deg@ 10435 Well Type: PROD Orig 5/13/2003 Completion: Last W/O: Rev Reason: GLV design, FRAC, post FRAC tag Last Update: 10/14/2003 Annular Fluid: Reference Log: 28' RKB Last Tag: 10308 Last Tag Date: 10/11/2003 Ref Log Date: TD: 10435 ftKB Max Hole Angle: 60 deg @ 5856 Casing String - ALL STRINGS Description Size CONDUCTOR 16.000 SURFACE 9.625 PRODUCTION 7.000 Tubing String - TUBING Size I Top 3.500 0 Perforations Summary Interval TVD 10150 -10180 6551 - 6576 Grade H-40 L-80 Thread WELDED BTCM Bottom 138 6744 TVD 138 4474 Bottom 10066 Zone C-4 Status Ft SPF Date Type Comment 30 4 6/18/2003 IPERF 2.5" HSD, 2 SPF HYPERJET, 4 SPF POWERJET Type Stimulations & Treatments Interval I Date I 10150 -10180 10/7/2003 FRAC Gas Lift MandrelsNalves St MD TVD Man Man Mfr Type 1 3237 2651 CAMCO MMG 2 5942 4066 CAMeO MMG 3 7930 5101 CAMCO MMG 4 9138 5795 CAMCO MMG 5 9937 6375 CAMCO MMG Other l)lugs, equip., etc.: - JEWELRY Depth TVD Type 497 497 NIP 9983 6412 NIP 10021 6444 PBR 10036 6456 PACKER 10060 6476 NIP 10066 6481 WLEG General Notes Date Note 5/14/2003 TREE: FMC 11" /5M / GEN 5 TREE CONNECTION: FMC 3 1/8" 5M W/OTIS Comment 16/20 PROPPANT V Mfr V Type V aD Latch Port TRO Date Vlv Run Cmnt 1336 I 0/12/200~ 1322 I 0/12/200~ 1307 10/12/200~ 1330 10/12/200~ o Description ID 2.875 2.813 3.000 3.250 2.750 2.992 CAMCO 'D' LANDING NIPPLE CAMeO 'DS' NIPPLE BAKER PBRlSBR BAKER 'SAB-3' PACKER WITH MILLOUT EXTENSION id 3.71" CAMeo 'D' NIPPLE WINO GO 2.75" PROFILE Date 10/07/03 10/10/03 10/11/03 10/12/03 ) 1 C-19 Event History ") Comment PUMP FRACTURE TREATMENT AT 20 BPM USING 30# LGD X-LINKED GEL. PUMPED A TOTAL OF 168,649# OF 16/20 CERAMIC PROPPANT. SCREENED OUT WITH 9 PPA ON PERFS, PLACING 142,405# PROPPANT BEHIND PIPE. RECOVERED 50% OF TREESAVER RUBBER. [FRAC-REFRAC] CLEANED OUT TO 10330' CTMD. 1FOR 1 RETURNS STEADY ALL DAY ,RETURNS CONSISTED OF PROP AND GEL .WASHED GAS LIFT MANDRELS ON WAY OUT OF HOLE.FREEZE PROTECTED TO 2200' WITH DIESEL [FCO] DRIFT TBG W/2.70" GAUGE RING, TAGGED FILL @ 10308' RKB EST. 128' OF RAT HOLE, PULLED SIDE POCKET GAUGE (PETRADAT) @ 9937' RKB IN PROGRESS. [FRAC-REFRAC] INSTALLED NEW G/L DESIGN, SET OV @ 9937', SET GLV'S @ 9138',7930',5942',3237', RKB BLED IA GLV'S SET COMPLETE. [GLV] Page 1 of 1 10/20/2003 ') ConocóPhillips ) Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 August14,2003 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Report for 1 C-19 (APD # 203-054) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Report for the recent drilling operations of the Kuparuk well 1 C-19. If you have any questions regarding this matter, please contact me at 265-6830 or Shane Cloninger at 265-6829. Sincerely, ~,~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad . . .~.~ ORIGINAL ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Plugged D Abandoned D 20AAC 25.105 No. of Completions _ Suspended D WAG D 20AAC 25.110 Other Gas U 1a. Well Status: Oil 0 1b. Well Class: Development 0 Exploratory D Service D Stratigraphic Test D 12. Permit to Drill Number: WINJ D WDSPL D GINJ D 2. Operator Name: 5. Date comp.,~u p., ð vAA D or Aband.: , 2003 ~ 6. Date Spudded: ' May 2, 2003 . 7. Date TO Reached: May 10, 2003 8. KB Elevation (ft): 28' RKB 1 87' AMSL 9. Plug Back Depth (MD + TVD): 10344' MD 1 6716' TVD 10. Total Depth (MD + TVD): 10435' MD 1 6794' TVD 203-054 1 13. API Number: 50-029-23149-00 14. Well Name and Number: 1 C-19 15. Field/Pool(s): Kuparuk River Field Kuparuk River Pool ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Governmental Section): Surface: 1616' FNL, 1360' FWL, Sec. 12, T11N, R10E, UM At Top Productive Horizon: 1055' FNL, 32' FWL, Sec. 6, T11N, R11E, UM Total Depth: 926' FNL, 111' FWL, Sec. 6, T11 N, R11 E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x-562368 y- TPI: x- 566268 y- Total Depth: x- 566346 y- 18. Directional Survey: Yes 0 NoU 16. Property Designation: ADL 25649 1 28242 Zone-4 Zone- 4 Zone-4 5968624 5974498 5974628 11. Depth where SSSV set: Land Nipple @ 497' 19. Water Depth, if Offshore: N/A feet MSL 17. Land Use Permit: ALK 467 20. Thickness of Permafrost: 1863 MD 21. Logs Run: G R/Res/Density-Neutron 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED Surface 122' 42" 175 sx ArcticCrete Surface 6745' 12.25" 655 bbls AS III Lite, 144 bbls Class LiteCrete Surface 10429' 8.5" 240 sx Class G CASING SIZE WT. PER FT. 16" 62.5# 9.625" 40# 7" 26# GRADE B L-80 L-80 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): TUBING RECORD DEPTH SET (MD) 10073' 24. SIZE PACKER SET (MD) 1 0036' 3.5" 10150' - 10180' MD 6551' - 6576' TVD 6 spf 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED N/A 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) July 28, 2003 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 7/28/2003 25 hours Test Period --> 598 190 36 100 334 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF W A TER-BBL OIL GRAVITY - API (corr) not available not available 24-Hour Rate -> 535 179 34 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", '--'i~',:"· .:;::'_""-~:-', :~'.':"F ¡ .-6.~/£-~; i.."::..:::fj¿~~;,:::.; NONE CONTINUED ON REVERSE SIDE ORIGINAL Form 10-407 Revised 2/2003 Submit in duplicate f \j RBIDMS BFl ALJG 2: u 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". 1 C-19 Unit 0 Unit C Unit B 10085' 10144' 10294' 6496' 6546' 6673' N/A 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: Shane Cloninger @ 265-6829 Printed Na,p"1p C' _ _ R. T~as\\.... Signature \ ~, ~ Title: P.EM Ii. Kuparuk Drilling Team Leader Date õ II '-t (i:) 3 Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 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 1 0-407 Revised 2/2003 ORIGiNAL ) ) ConocoPhilliþs Alaska OperationsS u mm aryReport Page 1 of 6 Legal Well Name: 1 C-1 9 Common Well Name: 1 C-1 9 Spud Date: 5/2/2003 Event Name: ROT - DRILLING Start: 5/1/2003 End: 5/13/2003 Contractor Name: n 1334@ ppco.com Rig Release: 5/13/2003 Group: Rig Name: Doyon 141 Rig Number: Date From - To Hours Code Sub Phase Description of Operations Code 5/112003 07:30 - 08:00 0.50 MOVE MOVE MOVE Move Pipesheds and Rock washer down pad. 08:00 - 09:00 1.00 MOVE MOVE MOVE Move Pit, Pump, Motor & Boiler modules down pad. 09:00 - 10:30 1.50 MOVE MOVE MOVE Move sub off 1C-178 and spot over 1C-19 (210' move). 10:30 - 12:00 1.50 MOVE MOVE MOVE Spot and set Pit & Pump modules in line. 12:00 - 13:00 1.00 MOVE MOVE MOVE Spot and Set Motor & Boiler modules in line. 13:00 - 14:00 1.00 MOVE MOVE MOVE Spot and Set Rock Washer & both pipe sheds - Berm rock washer. 14:00 - 15:30 1.50 MOVE RURD MOVE M/U all interconnects - Work Rig acceptance list - Spot Tioga Heater. Inspect rig. *** Rig Accept**** 1530 hrs 05/01/2003. 15:30 - 16:00 0.50 DRILL RIRD SURFAC N/U 22" Risor to diverter system - Fill pits to mix Spud mud. 16:00 - 18:00 2.00 DRILL RIRD SURFAC C/O handling tools to 5" - Load pipe shed wi DP - Con't mixing spud mud. 18:00 - 19:00 1.00 RIGMNT RSRV SURFAC Slip & Cut drill line ( 71' cut). 19:00 - 19:30 0.50 DRILL SFTY SURFAC Pre-Spud meeting wi Crew on days,Well engineer, Team leaders, Kup Safety rep and all contractors. 19:30 - 20:00 0.50 WELCTL OTHR SURFAC Fuction test diverter system - Full Acc test - Test gas detectors Knife valve open 20 sec, Annular closed in 26 sec. Acculator Full recovery time 3 min 23 sec AOGCC rep John H. Crisp waived witness test. 20:00 - 20:30 0.50 DRILL RIRD SURFAC Strap DP in shed - PJSM 5 min on Picking up DP 20:30 - 00:00 3.50 DRILL PULD SURFAC P/U 5" G-105 DP out of shed - M/U in stds and Std Bk in derrick (@ midnight had 33 stds p/u) 5/2/2003 00:00 - 04:30 4.50 DRILL PULD SURFAC Con't to P/U 5" G 105 DP from pipe shed and std bk in derrick ( Have total 66 stds (6129' )5" DP in derrick. P/U & Std bk 10 stds 5" HWDP wi Jars 04:30 - 05:30 1.00 DRILL PULD SURFAC P/U 1 std NMDCs std bk in derrick 05:30 - 07:00 1.50 DRILL PULD SURFAC P/U BHA #1 - P/U Bit, Mach 1 C Navi Drill wi 1.4 AKO, and orient, PU MWD, lead collar, stab, 1 std 8" NMDCs 07:00 - 07:15 0.25 DRILL SFTY SURFAC PJSM on Spill containment and filling circu system 07: 15 - 07:45 0.50 DRILL CIRC SURFAC Fill Conductor - Air boot on stack riser leaking - Drain stack 07:45 - 08: 15 0.50 DRILL TRIP SURFAC Std Bk std NMDCs 08:15 - 08:45 0.50 RIGMNT RGRP SURFAC Replace Riser air boot 08:45 - 09:00 0.25 DRILL TRIP SURFAC TIH & Tag @ 122' 09:00 - 12:00 3.00 DRILL DRLG SURFAC Drlg,Slide & Survey 12.25" hole 122' to 262' MD ( 262' TVD). WOB= 20-30K, RPM= 60, PR= 465 gpm, Press= 1150 psi. 12:00 - 12:15 0.25 DRILL SFTY SURFAC Crew Hazard awareness training on pinch points wi Doyon toolpusher & Field Superintendant fl accident prevention using rotary tongs. 12:15 - 00:00 11.75 DRILL DRLG SURFAC Drlg,Slide & Survey 12.25" hole f I 262' to 1355' MD ( 1341' TVD) ART 3.2 hrs, AST 3.7 hrs, WOB 25/35k, 70 RPMs, PR 140 spm, 594 gpm, PP 1350 psi. - Up wt 94k, Dn wt 92k, RW 94k, Torqe on bttm 4k ft-Ibs, Off bttm 2k ft-Ibs 5/3/2003 00:00 - 12:00 12.00 DRILL DRLG SURFAC Drlg,Slide & Survey 12.25" hole f 11355' to 2562' MD (2282' TVD) ART 2.7 hrs, AST 4.6 hrs, WOB 10/30k, 80 RPMs, PR 140 spm, 594 gpm, PP 1600 psi. - Up wt 106k, Dn wt 96k, RW 103k, Torqe on bttm 3-7k ft-Ibs, Off bttm 2-3k ft-Ibs. Mud wt 9.0,Vis 120 12:00 - 16:00 4.00 DRILL DRLG SURFAC Drlg,Slide & Survey 12.25" hole f I 2562' to 3027' MD (2536' TVD) ART 2.8 hrs, AST 0.3 hrs, WOB 10/30k, 100 RPMs, PR 140 spm, 594 gpm, PP 1750 psi. - Up wt 112k, Dn wt 97k, RW 104k, Torqe on bttm 3-7k ft-Ibs, Off bttm 2-3k ft-Ibs. Mud wt 9.1+,Vis 118. No problems drilling, going well. At this point we have filled 3 cuttings bins (70% cap. concidered full). Bin capacity is 20 cu. yard. 16:00 - 17:30 1.50 DRILL CIRC SURFAC Pump 2 Sweeps - #1 sweep 35 bbls w/.2 ppb of barolift @ 11.5 ppb, #2 sweep Hi Vis only, PR 600 gpm, RPMs 100 - Recip DP full 94' - Printed: 6/3/2003 10:53:33 AM ') ') ConocoPhillips Alaska Operations Summary Report Page 2 of 6 Legal Well Name: 1 C-1 9 Common Well Name: 1 C-1 9 Spud Date: 5/2/2003 Event Name: ROT - DRILLING Start: 5/1/2003 End: 5/13/2003 Contractor Name: n1334@ppco.com Rig Release: 5/13/2003 Group: Rig Name: Doyon 141 Rig Number: Date From;. To Hours Code Sub Phase Description of Operations Code 5/312003 16:00 - 17:30 1.50 DRILL CIRC SURFAC Circu until clean. 17:30 - 17:45 0.25 DRILL CIRC SURFAC Monitor Well" Static" - Pump dry job - Blow down Top Drive 17:45 - 21 :00 3.25 DRILL TRIP SURFAC TOH on elevators - Had minor drag spots wI 15-20k over, fl 2510' thru 1900' - Work clean - Hole took proper fill. 21 :00 - 21 :45 0.75 DRILL TRIP SURFAC Std bk BHA - cIa bits - Guage tools - M/U Bit#2 - Ck scribe - RI std Dcs 21:45 - 22:15 0.50 DRILL TRIP SURFAC TIH to 1050' - P/U Ghost reamer (1050.20' behind bit) 1 jt dn from top of HWDP 22:15 - 23:00 0.75 DRILL TRIP SURFAC TIH to 2290' - Tight hole 23:00 - 23:15 0.25 DRILL REAM SURFAC Wash & Ream thru tight spot fl 2290' to 2380' - PR 500 gpm, 100 RPMs. 23: 15 - 23:45 0.50 DRILL TRIP SURFAC TIH - Wash 80' to bttm - No fill. 23:45 - 00:00 0.25 DRILL DRLG SURFAC Drlg, Slide & Survey 12.25" hole f I 3027' to 3050' MD ( 2548' TVD) ART 0 hrs, AST 0.1 hrs, WOB 10/25k, PR 140 spm, 594 gpm, PP 1750 psi. - Up wt 109k, Dn wt 95k, RW 104k, T orqe on bttm 5k ft-Ibs, Off bttm 1-2k ft-Ibs. Mud wt 9.2+,Vis 106 - Had large amount of cutting to surface @ BU. 5/4/2003 00:00 - 12:00 12.00 DRILL DRLG SURFAC Drlg,Slide & Survey 12.25" hole f I 3050' to 4290' MD ( 3212' TVD) ART 4.7 hrs, AST 2.2 hrs, WOB 10/30k, 100 RPMs, PR 150 spm, 636 gpm, PP 1750 psi. - Up wt 142k, Dn wt 97k, RW 115k, Torqe on bttm 6-14k ft-Ibs, Off bttm 8-9k ft-Ibs. Mud wt 9.1 ppg,Vis 87- No problems - Drilling going well *** Note *** All cutting, if any, from 4200' MD down will be put in the G & I cutting bins. We ended up with 3.5 bins ( app 51 cu. yd) of recycle gravel. Test samples will be sent in ASAP. 12:00 - 00:00 12.00 DRILL DRLG SURFAC Drlg,Slide & Survey 12.25" hole f I 4290' to 5355' MD ( 3766' TVD) ART 6.7 hrs, AST 1.8 hrs, WOB 5-25k, 100 RPMs, PR 150 spm, 636 gpm, PP 1900 psi. - Up wt 158k, Dn wt 104k, RW 126k, Torqe on bttm 12k ft-Ibs, Off bttm 11 k ft-Ibs. Mud wt 9.0 ppg,Vis 82 - *** Note***Our Maximum total bbls for the 1 C-22 annulus (48,000) should be about up sometime in the morning. We will save 2500 bbl space to use to get rid of fluid on the long 9.625" surface csg cmt job. This will save money by allowing us to use fewer trucks to move fluid before, during & after Cmt job.We have double checked the injection total figures and they are currant up to midnight @ 44,228 bbls 5/5/2003 00:00 - 12:00 12.00 DRILL DRLG SURFAC Drlg, Slide & Survey 12.25" hole f I 5,355' to 6,193' MD (4192' TVD) ART 8.3 hrs, AST 0.2 hrs, WOB 10-30k, 100 RPMs, PR 153 spm, 650 gpm, PP 2500 psi. - Up wt 167k, Dn wt 108k, RW 130k, Torqe on bttm 10-25k ft-Ibs, Off bttm 13-14k ft-Ibs. Mud wt 9.3 ppg, Vis 82 - Drilling going well - Rap is inconsistent - Runs 30 to 150 fph off and on - Torq has been steady wI slow increase with depth. 12:00 - 18:45 6.75 DRILL DRLG SURFAC Drlg, Slide & Survey 12.25" hole f 16,193' to 6,755' MD (4479' TVD) ART 4.8 hrs, AST 0.2 hrs, WOB 10-30k, 100 RPMs, PR 153 spm, 650 gpm, PP 2550 psi. - Up wt 182k, On wt 11 Ok, RW 135k, Torque on bttm 10-17k ft-Ibs, Off bttm 12-13k ft-Ibs. Mud wt 9.3+ ppg, Vis 90 - No Problems. 18:45 - 21 :00 2.25 DRILL CIRC SURFAC Pump 30 bbl WtJ Barolift sweep (.2 ppb @ 11.8 ppg) PR 650 gpm, RPMs 150 followed by 28 bbl Hi Vis sweep and circu until shakers show clean (App 2.5 BUs) Had a 15% increase in cuttings on BU but shakers seemed to clean up soon after. 21 :00 - 22:30 1.50 DRILL WIPR SURFAC Wiper Trip 14 stds ( 200' past the lowest point the ghost reamer ran) No high excess drag - No problems - Hole took proper fill on trip. 22:30 - 00:00 1.50 DRILL CIRC SURFAC Circu & Condition to run Csg - Pump 35 bbl WtJ Barolift sweep (.2 ppb Printed: 6/3/2003 10:53:33 AM ') ) Page 3 of 6 ConocoPhillips Alaska Operations Summary Report· Legal Well Name: 1 C-1 9 Common Well Name: 1 C-1 9 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Sub Phase Code 5/5/2003 22:30 - 00:00 1.50 DRILL CIRC SURFAC 5/6/2003 00:00 - 03:30 3.50 DRILL CIRC SURFAC 03:30 - 07:45 4.25 DRILL TRIP SURFAC 07:45 - 09:30 1.75 DRILL TRIP SURFAC 09:30 - 10:45 1.25 CASE RURD SURFAC 10:45 -11:00 0.25 CASE SFTY SURFAC 11 :00 - 12:00 1.00 CASE RUNC SURFAC 12:00 - 14:45 2.75 CASE RUNC SURFAC 14:45 - 15:30 0.75 CASE CIRC SURFAC 15:30 - 20:00 4.50 CASE RUNC SURFAC 20:00 - 20:45 0.75 CASE RUNC SURFAC 20:45 - 00:00 3.25 CASE CIRC SURFAC 5/7/2003 00:00 - 00:30 0.50 CEMENT SFTY SURFAC 00:30 - 06:00 5.50 CEMENT SFTY SURFAC Start: 5/1/2003 Rig Release: 5/13/2003 Rig Number: Spud Date: 5/2/2003 End: 5/13/2003 Group: Description of Operations @ 11.8 ppg) RP 650 gpm, RPMs 150 followed by 30 bbl Hi Vis sweep. Had a small increase in cutting on BU. Con't circu & Condition. Con't to Circu & Condition - Reduce mud wt from 9.4+ to 9.2 - Spot 1 % lube pill in open hole - Pump dry job - Blow down Top Drive TOH - No excess drag - No problems - UD ghost reamer - Reamer was FULL guage UD BHA #2 R/U to run 9.625" 40# L80 BTC Csg. PJSM - Review Running Csg & Csg detail - Review known running hazards. Run 9.625", 40#, L80, BTC Csg to 350' - (@ it #4 pump tested float equip) "OK" Con't to run 9.625" 40# L80 BTC Csg to 3,006'. Circ btms up at 5 BPM and 500 psi. Run 9.625", 40#, L80, BTC Csg to 6,744' (175 jts total). Made up csg to the mark. Install bow spring centralizers on jts 1 and 3 wi stop collars, install free floating Rigid cents on jts 2 and 4-15. Instal TAM combo tool at 1,021' wi bow cent on jts above and below wi stop rings. RD Frank's Fill-up tool, blow dwn TD, PU Landing Jt and Csg Hngr, Land Csg. MU cmt head. Circ and Cond mud while reciprocating csg. Stage pumps up to 8 bpm and 450 psi. UWT = 285K, DWT = 135K. Circu & Condition - Hold PJSM with crew and all contractors - Review Csg CMT detail and fluid disposal plans with all parties concerned. Review known hazards and backup plans. CMT 9.625" Csg - Pump 5 bbls CW100, Test lines to 3500 psi, Pump remaining 45 bbls CW1 00, 50 bbls 10.5 ppg MudPush, Drop bttm plug, pump 655 bbls of 10.7 ppg Arcticset Lite lead slurry, 144 bbls of 12.0 ppg LitecreteTail slurry, Drop Top plug, kick out plug wi 20 bbls washup, turn over to Rig - Rig displaced with 485.8 bbls (Calc) Bumped plug wi 4,827 stks (Calc bump stks 4807)- Had 160 bbls 10.7 ppg CMT to surface. After shutting down and dropping top plug we could no longer recip csg (288 bbls lead cmt in ann)-CIP 05:55 AM - Complete job went well. 06:00 - 09:00 3.00 CEMENT RURD SURFAC RID CMT head & Line - UD landing jt - RID all Csg equip 09:00 - 11 :30 2.50 DRILL RIRD SURFAC NID Diverter system 11 :30 - 12:00 0.50 DRILL RIRD PROD N/U Csg head & Tbg adapter 12:00 - 14:30 2.50 DRILL RIRD PROD Set BPV - N/U BOPs - Test 5? metal to metal seal to 1000 psi hold f/ 10 min "OK" - Pull BPV 14:30 - 15:30 1.00 DRILL RIRD PROD C/O bttm Rams to 5" DP - Install test it - R/U to test BOPs 15:30 - 18:30 3.00 WELCTL BOPE PROD Test BOPs - Test BOPs and Choke manifold 250 Lol 5000 psi high, Test Annular to 250 Lo I 3500 psi high. Preform Accum. test & record. No failures - AOGCC rep John Spaulding waived witness test. 18:30 - 19:00 0.50 WELCTL BOPE PROD Pull test plug - Set wear bushing - UD test it 19:00 - 23:15 4.25 DRILL DRLG PROD P/U BHA #3 23: 15 - 00:00 0.75 DRILL TRIP PROD TIH wi BHA picking up DP singles out of pipe shed 5/8/2003 00:00 - 03:30 3.50 DRILL TRIP PROD TIH - PIU 114 jts DP (38 stds) in singles from pipe shed - Con't TIH wi stds from derrick to 6574' 03:30 - 03:45 0.25 DRILL CIRC PROD Brk Circu - Circu dn to tag @ 6665' - Circu air from system - Recip Drill string at all times. Std bk 1 std DP - Blow dn Top Drive 03:45 - 04:45 1.00 RIGMNT RSRV PROD Slip & Cut drill line ( 72' cut) 04:45 - 05: 15 0.50 RIGMNT RSRV PROD Service Top Drive Printed: 6/3/2003 10:53:33 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 5/8/2003 5/9/2003 5/10/2003 ) ) Page 4 of 6 ConocoPhillipsAlaska Operations Summary Report 1 C-1 9 1 C-19 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 5/1/2003 Rig Release: 5/13/2003 Rig Number: Spud Date: 5/2/2003 End: 5/13/2003 Group: Sub From - To Hours Code Code Phase 05: 15 - 05:30 05:30 - 06:30 06:30 - 08:30 08:30 - 09:30 09:30 - 10:30 10:30 - 12:00 12:00 - 00:00 00:00 - 12:00 12:00 - 00:00 00:00 - 02: 15 02:15 - 04:15 04: 15 - 06:30 06:30 - 07:00 07:00 - 08:30 08:30 - 10:45 10:45 - 12:00 12:00 - 13:15 13:15 - 16:45 16:45 - 20:30 20:30 - 21 :45 0.25 DRILL 1.00 DRILL 2.00 DRILL 1.00 DRILL 1.00 DRILL 1.50 DRILL 12.00 DRILL 12.00 DRILL 12.00 DRILL 2.25 DRILL CI RC PROD DEQT PROD DRLG PROD CIRC PROD LOT PROD DRLG PROD DRLG PROD DRLG PROD DRLG PROD DRLG PROD 2.00 DRILL CIRC PROD 2.25 DRILL WIPR PROD 0.50 RIGMNT RSRV PROD 1.50 DRILL WIPR PROD 2.25 DRILL CIRC PROD 1.25 DRILL 1.25 DRILL 3.50 DRILL 3.75 DRILL TRIP PROD TRIP TRIP TRIP PROD PROD PROD 1.25 DRILL PULD PROD Description of Operations Circu & Condition to test Csg Test 9.625" #40 L80 BTC Csg to 2500 psi & hold for 30 min. Test on chart. Lost 25 psi after 30 min. Mud wt 9.3 ppg, Vis 79 Drlg shoe track + 20' new hole from 6755' to 6775' MD, 4490' TVD Displace well & system over to New 9.0 ppg LSND mud. Vis 93 Preform LOT - Test w/9.0 ppg @ 4479' TVD - Test leak off @ 1400 psi at surface = EMW 15.0 ppg - Plotted on CPI PIT form. Drlg, Slide & Survey 8.5" hole fl 6775' to 6854' MD (4530' TVD) ART 0.8 hrs, AST 0.0 hrs, WOB 10-20k, RPMs 100, PR 130 spm, 552 gpm, PP 2650, Up wt 200k, Dn wt 100k, Rwt 135k, Torq on bttm 15k, off bttm 15k, Mud wt 9.1ppg, Vis 47 - Drilling going well-No problems Drlg, Slide & Survey 8.5" hole fl 6,854' - 8,248' MD (5,274' TVD) ART = 7.2 hr, AST= 0.6hr, WOB 5-20, RPMs 100, PR 130 spm, 552 gpm, PP 2400, Up wt 205k, Dn wt 105k, Rwt 140k, Torq on bttm 15-16k, off bttm 15k, Mud wt 9.1 ppg, Vis 45 - Drilling going well -No problems - Pump sweeps as needed to maintain clean hole. Pump 3 lube pills for Torq #1 pill ,1 drum EP & 2 drums BDF 263, #2,2 drums EP, 4 drums BDF 263, #3 = 4 drums EZ glide + 4 drums TorqTrim. Drlg,Slide & Survey 8.5" hole fl 8284' to 9362' MD ( 5941' TVD) ART 7.1 hrs, AST 0.7 hrs, WOB 10-20k, RPMs 100, PR 130 spm, 552 gpm, PP 3050 psi, Up wt 230, Dn wt 127k, RW 164k, Torq on bttm 14-16k ft-Ibs, Off bttm 16-18k ft-Ibs, Mud wt 9.8 ppg, 55 vis, Drilling going well - No problems Drlg,Slide & Survey 8.5" hole fl 9362' to 10,198' MD ( 6591' TVD) ART 4.4 hrs, AST 2.3 hrs, WOB 10-20k, RPMs 100, PR 130 spm, 552 gpm, PP 3100, Up wt 205, Dn wt 130k, RW 165k, Torq on bttm 14-16k ft-Ibs, Off bttm 14k ft-Ibs, Mud wt 10.4 ppg, Vis 53. Weight up from 9.8 ppg to 10.4 ppg before drilling the K1. Top of K1 @ 9950' MD (6377' TVD) - Flow ck well after drilling cap "OK" - No show of gas cut or any change @ BU after drilling Kuparuk cap. Drilling going well. No problems Drlg,Slide & Survey 8.5" hole fl 10,198' to 10,435' MD ( 6794'TVD) ART 1.3 hrs, AST 0.0 hrs, WOB 15/20k, RPMs 100, PR 130 spm , 552 gpm, PP 3150 psi, Up wt 250k, Dn wt 144k, RW 187k, Mud wt 10.4 ppg, 46 Vis - No Problems - All going well ** Note** Average ROP for section 6755' to 10,435', Rotating 157.7 fph, Sliding 111.1 fph, Total on Bttm drilling hrs Drlg & Sliding = 24.4 hrs Circu & Condition - Pump 20 bbls Wt I Barolift sweep @ 12.9 ppg wi .18 ppb barolift, PR 552 gpm, 100 RPMs. Recip DP full std. Std Bk 1 std I hr. Minimal show of sand @ BU - Circu hole clean - 2+ X BUs. TOH on elevators to Shoe @ 6755' - No excess drag ( Av 5-20k) No Swab, No problems, Hole took proper fill. Service Rig & Top Drive TIH to Bttm 10,435'( Fill DP @ 8527') - No problems - No tight hole Circu & Condition - Circu BU X 2+ , Mud wt 10.4 ppg, 45 Vis, YP 18, PV 17, Gels 5/8/1 0 TOH on elevators - No Tight hole - No excess drag ( @ 8990' end of tour) Con't TOH to 6114' (Observe well for flow @ shoe"OK") TOH UD 5" DP (UD 162 jts) UD BHA #3 - UD HWDP + Jars - UD 3 NMCSDP - 5 min PJSM @ rotary on RA sources - Remove source - Dn load MWD - Brk Bit - UD MWD, XO, Stab & Motor- Clear tools from rig floor Doyon Field Supt wanted to only keep 40 stds in derrick for move - Run Printed: 6/3/2003 10:53:33 AM ) ) ConocoPhiUipsAlaska Operations Summary Report Legal Well Name: 1 C-1 9 Common Well Name: 1 C-1 9 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To · Hours Code Sub Phase Code 5/1 0/2003 20:30 - 21 :45 1.25 DRILL PULD PROD 21 :45 - 22:00 0.25 DRILL RIRD PROD 22:00 - 23:00 1.00 WELCTL EaRP PROD 23:00 - 00:00 1.00 CASE RURD PROD 5/11/2003 00:00 - 00:15 0.25 CASE SFTY PROD 00:15 - 03:15 3.00 CASE RUNC PROD 03: 15 - 03:45 0.50 CASE CIRC PROD 03:45 - 04:00 0.25 CASE RUNC PROD 04:00 - 04:15 0.25 CASE RURD PROD 04: 15 - 04:45 0.50 CASE RURD PROD 04:45 - 11 :00 6.25 FISH SUN PROD 11 :00 - 12:00 1.00 FISH SUN PROD 12:00 - 12:45 0.75 FISH SUN PROD 12:45 - 13:00 0.25 CASE SFTY PROD 13:00 - 14:30 1.50 CASE RURD PROD 14:30 - 18:30 4.00 CASE OTHR PROD 18:30 - 20:00 1.50 CASE RUNC PROD 20:00 - 00:00 4.00 CASE RUNC PROD 5/12/2003 00:00 - 01 :30 1.50 CASE RUNC PROD 01 :30 - 02:00 0.50 CASE CIRC PROD 02:00 - 03:30 1.50 CASE RUNC PROD 03:30 - 04:00 0.50 CASE CIRC PROD 04:00 - 05:00 1.00 CASE RUNC PROD 05:00 - 07:30 2.50 CASE SFTY PROD 07:30 - 08:00 0.50 CASE SFTY PROD 08:00 - 10:00 2.00 CASE RUNC PROD 10:00 - 10:45 0.75 CASE RUNC PROD 10:45 - 12:00 1.25 CASE CIRC PROD 12:00 - 15:00 3.00 CASE CIRC PROD Page 5 of 6 Start: 5/1/2003 Rig Release: 5/13/2003 Rig Number: Spud Date: 5/2/2003 End: 5/13/2003 Group: Description of Operations 10 more stds 5" DP in hole - UD same Pull wear bushing - Install test plug Install 7" csg rams in top pipe ram - Test door seals 1000 psi "OK" Pull test plug R/U 7" Csg tools - M/U Frank's fill tool PJSM Running Csg - Review Csg detail wi crew & contractors. Review know hazards & Risk.Review running procedure and responsibilitys of each crew member. Run 7" 26# L80 STCM csg to 2959' Circu csg volume (114 bbls) - PR 5 bpm, 400 psi Run 7" 26# L80 STCM csg to 3004' - Frank's Fillup tool parted When driller picked up the elevators off of jt# 72 the bttm section of fill tool extenion had parted. The piece is 4' 3" long, 4.60" to 5.25" OD , Made of metal, Wt app 60 Ibs. UD Damaged Frank's fillup tool Evaluate and discuss options Order out Slick line unit & Fishing tools.Will make overshot run on slick line. RIH wi Overshot & 5" grapple to enguage fish. POOH wi Slickline & Overshot - No recovery of fish - RID Slickline PJSM on Laying down 7" Csg - Review all know hazards - Explain to crew each man's job and risk R/U to UD 7" Csg - Mix & pump dry job ( 20 bbls, 3 Ibs over) Pull 72 jts 7" 26# L80 STCM - No problems - Retrieve fish off top of float collar - No damage to Float Collar Rig back up to run 7" Csg - Clean Rig floor - Clear all tools off rig floor Run 7" 26# L80 csg to 1900' - Full returns on displacement Con't Run 7" 26# L80 STCM Csg to 2959' Circu pipe volume - 5 bpm @ 410 psi Run 7" 26# L80 STCM Csg to 6722' Circu pipe volume - 5 bpm @ 440 psi Run 7" 26# L80 STCM Csg to 8160 - On jt #193 the 7" csg came out of the pick up sling while picking up the joint,dropping (apprx 20') back to the rig floor. In the process of falling to the rig floor 2 men were struck with glancing blows by the pipe.Tourpusher notified the Rig Supv @ 0514 hrs and the Rig Supv called for the Emergency Evac crew. The EMTs were on site in 18 min. The crew member was evaluated to the KOC clinic and found to be in fair shape with some bruising and abrasions. He was sent to Anchorage for further evaluation. STOPPED the job - Safety Shut down - Record all information on witness statements - Record with pictures the work area, sling placement & position of csg jt after incident. Held Safety meeting with all crew members to make sure everyone understood what had happened and how we could prevent it from happening again - Circu & Recip Csg to prevent sticking PJSM wi All hands & CPAI rep to con't running Csg - Review what was learned about incident - Discussed running hazards & risk Con't Running 7" Csg ( 246 JTS TOTAL) UD Franks Fillup tool - M/U hanger & Landing jt - M/U CMT head Circu & Condition - Stage up pumps slowly to 7 bpm @ 800 psi. Circu & Condition - Stage up pumps slowly to 7 bpm @ 800 psi. Printed: 6/3/2003 10:53:33 AM ConocoPhillips Alaska Operations Summary Report ) Legal Well Name: 1 C-1 9 Common Well Name: 1 C-1 9 Event Name: ROT - DRILLING Contractor Name: n1334@ppco.com Rig Name: Doyon 141 Date From - To Hours Code Sub Phase Code 5/12/2003 12:00 - 15:00 3.00 CASE CIRC PROD 15:00 - 16:45 1.75 CEMENT PUMP PROD 16:45 - 17:15 0.50 CEMENT RURD PROD 17:15 - 18:30 1.25 CEMENT SEaT PROD 18:30 - 19:30 1.00 CMPL TN NUND PROD 19:30 - 20:30 1.00 CMPL TN RURD PROD 20:30 - 20:45 0.25 CMPL TN SFTY PROD 20:45 - 00:00 3.25 CMPL TN RUNT PROD 5/13/2003 00:00 - 05:30 5.50 CMPL TN RUNT PROD 05:30 - 06:00 0.50 CMPL TN OTHR PROD 06:00 - 06:30 0.50 CMPL TN PCKR PROD 06:30 - 07:00 0.50 CMPL TN PCKR PROD 07:00 - 08:00 1.00 CMPL TN SOHO PROD 08:00 - 08:30 0.50 CMPL TN OTHR PROD 08:30 - 10:30 2.00 CMPL TN NUND PROD 10:30 - 12:00 1.50 CMPL TN NUND PROD 12:00 - 12:45 0.75 CMPL TN SEaT PROD 12:45 - 15:30 2.75 CMPL TN DEQT PROD 15:30 - 17:00 1.50 CMPL TN CIRC PROD 17:00 - 18:00 1.00 CMPL TN FRZP PROD 18:00 - 22:00 4.00 CMPL TN OTHR PROD 22:00 - 00:00 2.00 CMPL TN OTHR PROD ) Page·6 of 6 Start: 5/1/2003 Rig Release: 5/13/2003 Rig Number: Spud Date: 5/2/2003 End: 5/13/2003 Group: Description of Operations Held PJSM wI Co rep, Rig crew,Cmt crew and Contractors - Discuss CMT detail and backup contingency plans. Up wt 270k, Dn wt 11 Ok Cement per well plan - Pump 10 bbls CW100, Test lines to 3500 psi, pump remaining 30 bbls CW100,Drop Bttm plug #1, pump 50 bbls 12 ppg MudPush, Drop #2 Bttm plug, pump 50 bbls (240 sxs) 15.8 ppg slurry, Drop Top plug, Kick out plug with 5 bbls water & turn over to rig. Av CMT rate 5.4 bpm - Rig displace wI 8.5 ppg seawater 3920 stks,bump plug wI 500 psi over. Hold psi 5 min - Bleed off- Floats held - CIP 1645 hrs RID CMT head & lines - UD landing jt M/U Packoff - RIH - RILDS - Test to 5000 psi fl 10 min C/O Top pipe rams to 3.5" X 6" VBRs - Test door seals to 2500 psi - Clear rig floor of 7" csg tools R/U to run 3.5" completion PJSM - Review Tbg detail - Discuss known hazards & Risk - Stress good communications between crew members Run 3.5" 9.3# L80 EUE 8rd Tbg ( 90 jts total) per detail. Continue running 3.5" 9.3# L-80 EUE 8rd mod tbg. Drop 2" setting ball-rig up circ. equip & pump ball down. Pressure tbg. to 2500#-slack off 15k-pressure to 3000# hold for 5 mins.-Bleed down to 1000#. Pick up to 135k to shear pbr-pressure to 3800# to shear ball seat Space out-land tbg.-rilds. Pressure to 3500#-hold 5 mins.-bleed down & rig down landing jt. Install 2 way check & nipple down bope. Nipple up adapter flange & tree. Test tbg. hanger & adapter flange to 5000k for 10 mins-test tree 5000-pull 2 way check. Rig up & test tbg. to 3500# for 30 mins. (chart same) test 3.5" x 7" annulus 3500# 30 mins.Shear rp valve. Circ. clean seawater 370 bbls. @ 5 bpm 870#. Pump 70 bbls. diesel down 3.5" X 7" annulus-'U' tube annulus-install bpv. Rig up & perform LOT on 7" X 9 5/8" annulus (13.9) pump 190 bbls. water & 60 bbls. diesel down 7" X 9 5/8" annulus. Blow down water & steam lines-rig down service lines & prepare rig for move. (release rig @ midnight 5-13-03.) Printed: 6/3/2003 10:53:33 AM Date 05/11/03 05/23/03 05/24/03 06/16/03 06/17/03 06/18/03 06/19/03 06/20103 08/01/03 ) ) 1 C-19 Event History Comment ATTEMPT TO FISH RIG'S FRANK TOOL FROM CASING SAT DOWN @ 2952'WLM WI BAKER OVER SHOT TAP DOWN GET MORE PU WEIGHT POOH WIO FISH [FISH] UNABLE TO START JOB DUE TO BPV IN TREE. DRIFTED TBG WI 22' X 2.625" DUMMY GUN TO 9958' WLM. DISCOVERED DRILLING MUD IN TBG. INSTALLED DV @ 9937' RKB [TAG, GLV] PERFORMED A FCO TO 10,326' CTMD. LOADED WELLBORE WITH DIESEL TO PBTD. RETURNS 1-1. PUMPED A TOTAL OF 780 BBLS FLUID FOR FCO. READY FOR WIRELlNE DRIFT AND TAG. [FCO] DRIFTED TBG WI 23' X 2.585"DUMMY GUN TO 10334' RKB. EST. 1561 RATHOLE. [TAG] PERFORATING. LOG JEWELRY PASS FROM TD (***TAGGED AT 10338' ***) TO 9840'. CORRELATED TO BAKER HUGHES GR/DENSITY/POROSITY MWD LOG FINISHED 8 MAY 2003. PERFORATE THE INTERVAL: 10150-10180 USING 2.5" HSD GUNS LOADED 6 SPF (4 SPF POWERJET, 2 SPF HYPERJET) DRIFTED TBG 2.735" & TAGGED @ 10338' RKB, EST. 158' RATHOLE. SET 2.75" CR LOCK- FLOWTRU SUB- DUAL PANEX ASS'Y @ 10060' RKB. IN PROGRESS. [PRESSURE DATA, GLV] SET 1/4" OV @ 32371 RKB. [GL V] PULLED PANEX GAUGES @ 10,060' RKB, REPLACED OV WI DV @ 3273' RKB [PRESSURE DATA, GLV] Page 1 of 1 8/12/2003 ) " ConocoPhillips Alaska, Inc. Pad lC 19 slot #19 Kuparuk River Unit North Slope, Alaska SUR V E Y LIS TIN G by Baker Hughes INTEQ Your ref Our ref License MWD <0-10435'> svy6880 Date printed Date created Last revised 23-May-2003 2-May-2003 l4-May-2003 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.173,w149 30 19.124 Slot location is n70 19 29.287,w149 29 39.384 Slot Grid coordinates are N 5968624.300, E 562368.100 Slot local coordinates are 1615.10 S 1361.51 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ) ConocoPhillips Alaska, Inc. Pad lC,19 Kuparuk River Unit, North Slope, Alaska Measured Inclin Depth Degrees .0..0.0 138..0.0 297.18 39.0.49 478.74 568.18 658.84 748.36 84.0.44 931. sa 1.021.44 1114 . 33 12.08..06 1299.67 1392.72 1485.6.0 1578.47 1671.37 1765.29 1855.97 1949..05 2.042..08 2134.43 2227.65 232.0..03 2412.85 25.05.69 2598.71 2691.55 2784.5.0 2877.45 2976.26 3.071.4.0 3162.93 3256..05 3348.33 344.0.49 3534.14 3628..09 3719.92 3812.88 39.05.48 3998.94 4.091.42 4184..07 4276.98 437.0..03 4462.97 4556..02 4648.83 .0..0.0 .0..0.0 .0.31 .0.69 .0.79 .0.77 4.32 6.12 6.73 8.23 1.0.52 13.6.0 14.83 16..02 2.0.18 23.16 25.43 27.8.0 31.27 33.39 35.98 39.32 43.87 46.41 49.16 51.98 54.58 56.85 56.85 56..07 57.73 55.58 57.8.0 57.18 58.54 57.95 58.38 59.82 58.82 58.52 58..04 57.94 55.8.0 56.16 56.69 59.38 59..02 57.66 56.97 57.86 Azimuth Degrees .0..0.0 .0..0.0 269.34 274.55 272.71 41. 43 63.61 66.43 63.22 63.64 64.48 57..08 55.49 52.1.0 48.88 46.52 44.34 41. 64 38.36 35.7.0 34.82 33.66 34.55 34.77 35.96 34.74 33.98 33.47 33.31 34.54 33.66 33.79 33.81 32.5.0 32.36 32.83 33.42 33..04 32.78 31.45 32.85 33.81 33.77 33.28 33.65 34.56 36.19 35.56 36.2.0 34.88 True Vert Depth .0..0.0 138..0.0 297.18 39.0.49 478.73 568.16 658.72 747.87 839.37 929.65 1.018.38 11.09.22 12.0.0..08 1288.39 1376.82 1463.12 1547.76 163.0.82 1712.53 1789.15 1865.68 1939.33 2.0.08.38 2.074.13 2136.19 2195.14 225.0.65 23.03..04 2353.81 24.05.17 2455.93 251.0.24 2562.48 2611.68 2661.21 27.09.78 2758.39 28.06.48 2854.42 29.02.17 2951..05 3.0.0.0.13 3.051.21 31.02.95 3154.19 32.03.37 3251..02 3299.8.0 335.0..05 34.0.0..03 ) SURVEY LISTING Page 1 Your ref MWD <.0-1.0435'> Last revised : 14-May-2.o.o3 R E C TAN G U L A R Dogleg Vert COO R DIN ATE S Deg/1.o.oft Sect .o..o.oN .o..o.oN .o..o.oS .o..o4N .o.l1N .o.59N 2.56N 5.97N 1.o.36N 15.66N 22..o6N 31.65N 44.43N 58.84N 77.29N 1.o.o.4.oN 127.23N 157.7.oN 193.19N 231.91N 275.17N 322.15N 372.89N 427.23N 483..o1N 541. 49N 6.o2.92N 666.84N 731.74N 796..o2N 86.o.5.oN 929.15N 995.22N 1.o59.83N 1126.39N 1192.49N 1258..o6N 1325.28N 1393.11N 1459.55N 1526.49N 1592.1.oN 1657.14N 1721..o4N 1785.44N 185.o.69N 1915.86N 1979.95N 2.o43.41N 21.o7..o4N .o..o.oE .o..o.oE .o.43W 1.24W 2.38W 2.6.oW .o.86E 8.26E 17.57E 28.18E 41.36E 58.18E 77 . 32E 96.96E 119.19E 144.52E 171.71E 2.o.o..o5E 229.74E 258.91E 289.47E 321.42E 355.81E 393.39E 432.99E 474.45E 516.44E 559.11E 6.o1.89E 645.12E 688.77E 734.59E 778.82E 821..o4E 863.32E 9.oS>.59E 948.37E 992.41E 1.o36.31E 1.o78..o1E 112.o..o8E 1163.23E 12.o6.75E 1249..o9E 1291.65E 1335.85E 1382.12E 1428.48E 1474.38E 1519.83E .0..0.0 .0..0.0 .0.19 .0.41 .0.12 .0..0.0 .0..0.0 -.0.25 -.0.67 -1.25 G RID Easting 562368.1.0 562368.1.0 562367.67 562366.86 562365.72 562365.5.0 562368.94 562376.31 562385.59' 562396.15 5624.09.27 562426..02 562445..05 562464.56 562486.64 562511.78 562538.75 562566.84 562596.24 562625..09 562655.3.0 562686.86 56272.0.83 562757.96 562797.11 562838..09 562879.58 562921.72 562963.96 563.0.06.67 563.049.78 563.095..05 563138.73 56318.0.42 563222.15 563263.88 5633.06.13 563349.61 563392.95 563434.1.0 563475.63 563518.23 563561. 23 5636.03..03 563645..07 563688.73 563734.47 56378.0.3.0 563825.68 56387.0.6.0 COO R D S Northing 5968624.3.0 5968624.3.0 5968624.29 5968624.33 5968624.39 5968624.87 5968626.87 596863.0.34 5968634.8.0 596864.0.19 5968646.69 5968656.42 5968669.36 5968683.92 59687.02.55 5968725.86 5968752.91 5968783.6.0 5968819.33 5968858.29 59689.01.79 5968949..02 5969.0.0.0..03 5969.054.67 596911.0 . 77 5969169.57 5969231.34 5969295.6.0 596936.0.84 5969425.47 596949.0.29 5969559.3.0 5969625.72 596969.0.67 5969757.56 5969824..0.0 5969889.91 5969957.48 597.0.025.66 597.0.092.42 597.0159.7.0 597.0225.65 597.0291..04 597.0355.27 597.042.0..01 597.0485.61 597.0551.15 597.0615.61 597.0679.43 597.0743.43 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot '19 and TVD from Est. RKB (0-141) (87..0.0 Ft above mean sea level). Bottom hole distance is 72.01.61 on azimuth 34..0.0 degrees from wellhead. Vertical section is from wellhead on azimuth 34.12 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 1.57 3.99 2..03 .0.77 1. 65 -.0.97 2.61 9.57 18.44 28.77 2.55 3.7.0 1.38 1. 63 4.6.0 41. 46 58.84 8.0.16 1.03.1.0 13.0.85 3.34 2.63 2.86 4..07 2.81 164.18 2.01.65 242.76 288.8.0 337.22 2.83 3.67 4.97 2.73 3.13 39.0.18 446.99 5.08.28 5'74.35 642.75 3.2.0 2.88 2.48 .0.14 1. 39 714 . 41 788.82 865.67 943.4.0 1.02.0.87 1.95 2.18 2.33 1.38 1. 47 1.098.73 1181.27 126.0.77 1337.94 1416.76 .0.77 .0.72 1.58 1. .09 1.28 1495.19 1573.48 1653.82 1734.6.0 1812.99 1.38 .0.89 2.29 .0.59 .0.66 1892..02 197.0.53 2.048.79 2125.44 22.02.62 3..01 1.55 1. 57 .0.94 1.53 2281.44 2361.34 244.0.41 2518.69 2596.86 ) ConocoPhillips Alaska, Inc. Pad 1C,19 Kuparuk River Unit,North Slope, Alaska Measured Inclin Depth Degrees 4741.68 4834.59 4927.32 5020.40 5112.27 5206.10 5299.36 5391.54 5483.43 5578.65 5670 .11 5763.16 5856.22 5949.05 6041.77 6134.41 6227.29 6320.05 6413.02 6505.68 6598.48 6691.28 6865.33 6958.08 7051.58 7143.96 7237.92 7329.89 7423.94 7515.79 7609.39 7701 .14 7793.41 7886.53 7979.56 8071 .99 8165.99 8258.24 8351.26 8443.81 8537.33 8629.57 8722.21 8817.25 8910.61 9001.01 9093.69 9186.69 9281.23 9373.62 58.57 58.24 59.61 58.45 58.17 59.50 58.92 58.95 58.70 57.92 59.63 60.10 60.17 60.03 59.92 59.51 59.37 59.76 59.67 59.36 58.85 58.99 59.11 59.01 59.10 58.91 59.11 58.61 58.02 57.32 57.03 56.33 56.04 56.92 57.53 57.23 56.93 56.72 56.37 56.09 55.71 54.81 54.48 53.23 52.43 51.77 50.46 50.57 49.12 47.54 Azimuth Degrees 33.59 33.09 33.05 33.99 33.39 32.60 33.21 33.75 33.44 32.92 33.08 33.94 32.44 33.36 34.54 33.71 34.24 33.73 34.12 33.72 34.03 34.67 34.23 35.02 32.63 35.40 35.58 34.78 31.81 30.89 31.98 31.37 30.58 32.22 32.75 32.38 32.49 32.56 33.14 34.34 34.46 32.13 30.99 30.83 30.46 29.29 30.50 29.66 32.10 32.30 True Vert Depth 3448.94 3497.62 3545.48 3593.38 3641.64 3690.20 3737.94 3785.50 3833.07 3883.09 3930.50 3977 .22 4023.56 4069.84 4116.23 4162.95 4210.17 4257.16 4304.05 4351.06 4398.71 4446.61 4536.13 4583.81 4631.90 4679.48 4727.85 4775.42 4824.82 4873.94 4924.68 4975.08 5026.43 5077 .86 5128.22 5178.05 5229.13 5279.61 5330.89 5382.34 5434.77 5487.34 5540.94 5597.00 5653.40 5708.94 5767.12 5826.25 5887.22 5948.65 ) SURVEY LISTING Page 2 Your ref MWD <0-10435'> Last revised : 14-May-2003 RECTANGULAR COORDINATES Dogleg Vert Deg/100ft Sect 2172.29N 2238.41N 2304.96N 2371.50N 2436.54N 2503.88N 2571.14N 2637.00N 2702.49N 2770.30N 2835.89N 2902.98N 2970.52N 3038.09N 3104.68N 3170.90N 3237.22N 3303.54N 3370.15N 3436.41N 3502.53N 3568.15N 3691.24N 3756.70N 3823.31N 3888.94N 3954.52N 4018.86N 4085.74N 4152.02N 4219.13N 4284.37N 4350.10N 4416.36N 4482.34N 4547.95N 4614.55N 4679.65N 4744.85N 4808.82N 4872.72N 4936.06N 5000.44N 5066.29N 5130.29N 5192.14N 5254.68N 5316.79N 5378.80N 5437.20N 1564.22E 1607.72E 1651.06E 1695.13E 1738.49E 1782.21E 1825.73E 1869.28E 1912.79E 1957.13E 1999.72E 2044.15E 2088.33E 2132.04E 2176.87E 2221.75E 2266.44E 2311.15E 2355.95E 2400.51E 2444.90E 2489.74E 2574.18E 2619.38E 2664.02E 2708.31E 2755.07E 2800.42E 2844.35E 2884.73E 2925.75E 2966.01E 3005.47E 3045.92E 3087.93E 3129.83E 3172.15E 3213.67E 3255.76E 3298.49E 3342.24E 3383.86E 3423.40E 3462.83E 3500.75E 3536.28E 3572.23E 3608.20E 3645.27E 3682.04E 1. 41 0.58 1. 48 1.52 0.63 2675.78 2754.91 2834.32 2914 .12 2992.29 G RID Easting 563914.46 563957.42 564000.21 564043.73 564086.56 564129.72 564172.69 564215.71 564258.67 564302.46 564344.51 564388.39 564432.01 564475.17 564519.45 564563.78 564607.93 564652.09 564696.35 564740.37 564784.21 564828.52 564911.94 564956.61 565000.69 565044.44 565090.67 565135.49 565178.87 565218.71 565259.18 565298.90 565337.82 565377.72 565419.19 565460.56 565502.33 565543.31 565584.87 565627.08 565670.30 565711. 39 565750.41 565789.29 565826.69 565861.72 565897.15 565932.62 565969.17 566005.47 COORDS Northing 5970809.03 5970875.49 5970942.39 5971009.27 5971074.66 5971142.34 5971209.95 5971276.16 5971341.99 5971410.15 5971476.08 5971543.53 5971611.41 5971679.33 5971746.27 5971812.85 5971879.53 5971946.20 5972013.17 5972079.79 5972146.25 5972212.23 5972335.99 5972401.81 5972468.77 5972534.76 5972600.71 5972665.41 5972732.64 5972799.23 5972866.67 5972932.23 5972998.27 5973064.85 5973131.16 5973197.11 5973264.04 5973329.47 5973395.00 5973459.32 5973523.56 5973587.23 5973651.93 5973718.08 5973782.39 5973844.52 5973907.34 5973969.74 5974032.04 5974090.73 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot '19 and TVD from Est. RKB (D-141) (87.00 Ft above mean sea level). Bottom hole distance is 7201.61 on azimuth 34.00 degrees from wellhead. Vertical section is from wellhead on azimuth 34.12 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ 1.59 0.84 0.50 0.40 0.94 3072.56 3152.66 3231.61 3310.23 3391.24 1. 88 0.95 1.40 0.87 1.11 3469.43 3549.90 3630.59 3711.04 3791. 32 0.89 0.51 0.63 0.37 0.50 3871 . 31 3951.29 4031.27 4111.55 4191.40 0.62 0.61 0.23 0.74 2.19 4271.03 4350.51 4499.77 4579.32 4659.50 2.58 0.27 0.92 2.76 1.14 4738.68 4819.21 4897.91 4977 . 92 5055.44 1.03 0.94 0.78 1. 75 0.81 5134.00 5210.60 5287.15 5364.69 5442.87 0.47 0.33 0.24 0.64 1.12 5520.70 5599.57 5676.75 5754.34 5831.27 0.42 2.29 1.06 1.32 0.91 5908.71 5984.49 6059.97 6136.59 6210.85 1.26 1. 74 0.71 2.50 1.72 6281.99 6353.93 6425.52 6497.65 6566.63 ) ) ConocoPhillips Alaska, Inc. SURVEY LISTING Page 3 Pad lC,19 Your ref MHD <0-10435'> Kuparuk River Unit,North Slope, Alaska Last revised : 14-May-2003 Measured Inclin Azimuth True Vert RECTANGULAR Dogleg Vert G RID C OORDS Depth Degrees Degrees Depth COO R DIN ATE S Deg/100ft Sect Easting Northing 9466.03 44.62 34.31 6012.74 5492.84N 3718.56E 3.53 6633.17 566041.53 5974146.66 9559.00 41.80 34.69 6080.50 5545.29N 3754.60E 3.05 6696.82 566077.14 5974199.40 9651.41 41.20 36.15 6149.71 5595.19N 3790.09E 1.23 6758.03 566112.21 5974249.58 9744.82 39.48 32.07 6220.92 5645.21N 3824.01E 3.37 6818.47 566145.73 5974299.87 9836.98 36.75 32.18 6293.42 5693.38N 3854.26E 2.96 6875.31 566175.58 5974348.28 9930.13 34.93 31.80 6368.93 5739.64N 3883.15E 1.97 6929.81 566204.09 5974394.77 10022.68 34.66 33.93 6444.93 5783.99N 3911.80E 1.35 6982.60 566232.38 5974439.35 10115.74 33.69 31. 76 6521.93 5827.90N 3940.16E 1.67 7034.86 566260.38 5974483.48 10208.03 31.60 31. 96 6599.63 5870.18N 3966.44E 2.27 7084.60 566286.31 5974525.97 10301.37 31.33 30.95 6679.25 5911.74N 3991.86E 0.63 7133.27 566311.39 5974567.73 10352.71 30.68 30.99 6723.25 5934.42N 4005.47E 1.27 7159.67 566324.81 5974590.51 10435.00 30.68 30.99 6794.03 5970.41N 4027.09E 0.00 7201.60 566346.14 5974626.68 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot 119 and TVD from Est. RKB (D-14l) (87.00 Ft above mean sea level). Bottom hole distance is 7201.61 on azimuth 34.00 degrees from wellhead. Vertical section is from wellhead on azimuth 34.12 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ) ) ConocoPhillips Alaska, Inc. Pad lC,19 Kuparuk River Unit,North Slope, Alaska SURVEY LISTING Page 4 Your ref MWD <0-10435'> Last revised : l4-May-2003 Comments in wellpath MD TVD Rectangular Coords. Comment ----------------------------------------------------------------------------------------------------------- 10435.00 6794.03 5970.41N 4027.09E Projected Data - NO SURVEY Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- 0.00 0.00 O.OON O.OOE 6744.00 4473.76 3605.35N 2515.41E 9 5/8 CSG Targets associated with this wellpath Geographic Location T.V.D. Rectangular Coordinates Revised Target name ----------------------------------------------------------------------------------------------------------- 1C-B C4 TGT 16 SEP 0 566280.000,5974500.000,0.0000 6537.00 5844.26N 3959.92E 17-Sep-2002 ) Transmittal Form INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie Reference: lC-19 II! Contains the following: .. . '\ 19L- I 1 LDWG Compact Disc '\Ð 0 (Includes Graphic Image files) \ 1 LDWG lister summary 1 blueline - MPR Measured Depth Log 1 blueline - MPR TVD Log 1 blue line - CCN/ORD Measured Depth Log 1 blueline - CCN/ORD TVD Log LAC Job#: 465069 Sent By: Glen Horel .... ~ ReceivedBY:~~~ '{.:D'('Ü~~'v' ) ~¡"ì\~ -OC.L; \ ,.U~ _J '&1. BAKER HUGHES Anchorage GEOScience Center Date: July 24, 2003 Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COpy FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 F''''\¡r-'''''CE\VED t<C JUL 2 8 2003 ÞJa8KS Œi & Gas Conti. CQmmt~ ~(\l1chOf~ Ir:~~~~~'~~T:T~'___ ~- : IMQ,t:W o,wJ\l ..~ ~I~ WI" ;,' '" ... . ., ..... -- IIIIMI'"":,, '-III'P:I .ult' ""'.01.(. .~.... .. '.. .... ." .,¡ ..... ,.-.._.,._....~..__._.,-~~ ---_.._~_..'.'.._--~..__..__. ~'..... -'(I " ,..........,.., ",..,......,..... -...... ". _. .,.. w w.._',~ ."_.~-~_.._,-~- -~-- "-"._-- :~~.~.. --,-- -- ~__,._ ____.__.._n_________·____·~ . ) y ConocoPhillips ) Post Office Box 100360 Anchorage, Alaska 99510-0360 Steve Shultz Phone (907) 263-4620 Fax: (907) 265-153~ . Email: steven.n.shultz(ã¿conocophillips.com May 14,2003 Alaska Oil and Gas Conservation Commission 222 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on Well1C-19 Dear Sir: ConocPhillips Alaska, Inc. hereby requests that 1 C-19 be permitted for annular pumping of fluids occurring as a result of drilling operation, per regulation 20 ACC 25.080. It is intended to begin annular disposal operation on 1 C-170 as soon as possible. Please see the attached form 10-403 and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Surface Casing Description 4. Surface Casing Cementing Report and Daily Drilling Reports during cement ops 5. Casing and Formation Integrity Report (LOT at surface casing shoe) 6. Production Casing Description 7. Production Casing Cementing Report and Daily Drilling Report during cement ops 8. Plan View of Existing Adjacent Wells 9. Plan View of Existing and Planned Adjacent Wells 10. Pressure Integrity Test If you have any questions or require further information, please contact Steve Shultz at 263- 4620 in the Conoco/Phillips office. . ¿t-"t-~ "J//:':,¿<.'/> .... '-'~/ ' , Steve Shultz Drilling Consultant /' I ;1/; // ./' ... RECEIVED MAY 1 5 2003 Alaska Oil & Gas Cons. Commission Anchorage ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operational shutdown D D D ) 1. Type of Request: D Repair well D D D Alter casing D D Abandon Suspend Change approved program Pull Tubing 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 99510 7. KB Elevation (ft): 28' RKB 8. Property Designation: ADL 25649 I 28242 / ALK 467 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): 10435' 6794' Casing Length Size Structural Conductor 94' 16" Surface 6727' 9.625" Intermediate Production 10400' 7" Liner ) Plug Perforations Perforate D D Stimulate Perforate New Pool 4. Current Well Class: Development 0 Stratigraphic D Exploratory D Service D fç( I <0 ft~ "'>//;6' Variance D Annular Dispos.0 Time Extension D Other D Re-enter Suspended Well D 5. Permit to Drill Number: 203-054 6. API Number: 50-029-23149-00 9. Well Name and Number: 1 C-19 10. Field/Pools(s): Kuparuk River Field / Kuparuk River Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured) Junk (measured): MD TVD Burst Collapse 122' 122' 6745' 4474' 10428' 6790' Perforation Depth MD (ft): None Packers and SSSV Type: Baker SAB-3 packer, Camco '0' nipple 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch D 14. Estimated Date for Commencing Operations: 5/21/2003 16. Verbal Approval: Date: Commission Representative: ;L 17: I hereby cert~'fy th. at t regoing .is t. rue and erect 0 the best of my knowledge. Contact Pnnted Name R. T~r Y Title Kuparuk Drilling Team Leader Signature c,.'4.cd:...¿/ ~ ~;p--g1Jý Phone 265-6830 ~ 7<:.....0'; COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Perforation Depth TVD (ft): None Packers and SSSV MD (ft): packer @ 10036', nipple @ 497' 13. Well Class after proposed work: Exploratory D Development 0 15. Well Status after proposed work: Oil 0 Gas D WAG D GINJ D Plug Integrity D BOP Test D Mechanical Integrity Test D Other: Tubing Size: 3.5" Location Clearance D Subsequent Form Required: \1é~\\ c \- o.~~ \<3\~<?~~ \ BY ORDER OF THE COMMISSION Approved by: ~~ fB)MS¿L Form 10-403 Revised 2/2003 ~ ~ COMMISSIONER.. ORIG NA_ MAY 1 ~ lOtH Tubing Grade: L-80 Tubing MD (ft): 10073' Service D Plugged D WINJ D Abandoned D WDSPL D Steve Shultz 263-4620 Date .ÇßÞ3 ~~~;!R;~ð'~ MAY 1 5 2003 Alaska Oil & Gas C C ons. ommission Anchorage Date: 1)(/ flo 3 SUBMIT IN DUPLICATE ) ) Annullar Disposal Transmittal Form-WelllC-19 A. B. Designation of well to receive drilling wastes: The depth to the base of freshwater aquifers and permafrost, if present. A stratigraphic description of the interval exposed to the open annulus and other information sufficient to support a commission finding that the waste will be confined and will not come to the surface or contaminate freshwater. A list of all publicly recorded wells within one- quarter mile and all publicly recorded water wells within one mile of the well to receive drilling waste. C. D. E. Identify the types and maximum volume of waste to be disposed of and the estimated density of the waste slurry. . F. An estimate of maximum anticipated pressure at the outer casing shoe during annular disposal operations and calculations showing how this value was determined. Details that show the shoe of the outer casing is set below the base of any freshwater aquifer and permafrost, if present, and cemented with sufficient cement to provide zone isolation: Details that show the inner and outer casing strings have sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations: Any addition data required by the Commission to confirm containment of drilling wastes: G. H. I. 1 C-19 No Aquifers/Base ofPermafrost=±1863' MD/1790'TVD From the 9 5/8" shoe to the Cement top all that is open is interbedded claystone, siltstone and shale with occasional minor non- hydrocarbon bearing sands. See attached horizontal plane clearance report and plot indicating that there are no wells within a quarter of a mile from the 9 5/8" surface casing shoe, There are no water wells within one mile of the 1 C Pad. Types of waste can be drilling mud, drilling cuttings, cement-contaminated drilling mud, completion fluids, diesel, formation fluids associated with the act of drilling a well, domestic waste water, and any added water needed to facilitate pumping of drilling mud or drilling cuttings. Maximum volume to be pumped is 75,000 bbls. Maximum anticipated differential pressure at casing shoe during disposal operation is 2197 psi. See attached calculation page. See Attached: cementing reports, LOT/FIT reports and casing reports. See attached casing summary sheet and calculation pages. 6.744. ~ 4,474' TVD Well: lC-19 Date: 5/14/03 ~" Surface Csg TOC Est. @ 12686'MD 5790'rVf)--------------------- 10,427' MD 6,794' TVD 1V17" 3 Yz" ~ Production Csg ) ') Assumptions Maximum surface injection pressure of 1000 psi Maximum density of the injection fluid is 13.0 ppg Pressure Gradient at the 9 5/8" casing shoe is .79 psi/ft Column of Gas to Bottom Mandrel with no gas lift pressure Going to 85% of 7" Collapse values Gas down to lower GLM and no header pressured Maximum Differential Pressure at Surface Shoe Max Disposal MW 13.0 ppg Max. Pressure @ 9 5/8" Shoe 2197 psi (Max Differential Pressure=Max Disposal Press + (Max Disposal MW)(.052)(TVD)-(Fluid Wt. On Backside )(.052)(TVD» (LOT performed on surface casing shoe to 15.3 PPG MWE or 3560 psi) Production Casine; Size Wt. Grade Collapse @ 100% Collapse @ 91.7% Gas Depth (TVD of bottom GLM) Gas Gradient Max Disposal Pressure with 13.0 ppg Collapse Pump Pressure in 9 5/8" Annulus No header pressure 100% collapse rating of 7" · Column of gas to last GLM · No gas lift pressure · 13.0 ppg mud in annulus · CPC=4598-13(.052)(4474)-9(.052)(6400-4474)+.l1 (6400)=1377 Maximum Mud Weight 14.6 ppg (to collapse casing with 1000 psi pump pressure) MMW= Pc@85%+(Gas Gradient)(Gas TVD)-Max.Disposal Pressure (TVD) (.052) 7.000 In. 26.00 lbs. L-80 5410 psi 4598 psi 6400 ft. 0.11 ppg 1000 psi 1377 psi Surface Casine; Size Wt. Grade Burst @ 100% Burst @ 85% Fluid Weight on Backside Max Disposal Pressure Maximum Surface Burst Pressure · 13.0 ppg mud in annulus MSBP=(Fluid wt. backside)(.052)(TVD)-MW (.052)(TVD shoe)+85% Burst Maximum Mud Weight 25.0 ppg (to burst casing with 1000 psi pump) MMW= Pb@ 85% +(Fluid Weight on Backside)(.052)(TVO)-Max Disposal Press (.052)(TVD) 9.625 In. 40.00 lbs. L-80 5750 psi 4887 psi 8.33 ppg 1000 psi 3800 psi The preceding calculations are based on the assumption that the well has gas to the lowest GLM and that there is no header pressure. If this scenario does not occur then thee should be no risk in collapse of the 7" with higher injection pressures. As far as the surface casing goes the integrity is there and should not be affected. ) ConocoPhillips Alaska, Inc. Pad I C 19 slot #19 Kuparuk River Unit North Slope, Alaska HORIZONTAL PLANE CLEARANCE REPORT by Baker Hughes INTEQ Your ref: MWD <0-] 0435'> Our ref: svy6880 License : Date printed: ]4-May-2003 Date created: 2-May-2oo3 Last revised: 14-May-2003 Field is centred on n70 ]6 ]8.576,wI50 556.536 Structure is centred on n70 ] 9 45.173, w] 49 30 ] 9. ] 24 Slot location is n70]9 29.287,w]49 29 39.384 Slot Grid coordinates are N 5968624.300, E 562368.100 Slot ]ocal coordinates are ] 6]5.10 S ] 361.5] E Projection type: alaska - Zone 4, Spheroid: Clarke - ]866 Reference North is True North Report is limited to clearances less than 2000 feet DECREASING CLEARANCES of less than 1000 feet are indicated by an asterisk, e.g. 487.4* ) ) ConocoPhillips Alaska, Inc. Pad IC,19 Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 2 Your ref: MWD <0-10435'> Last revised: 14-May-2003 Reference wellpath Object wellpath : PMSS <0 - 11918'>" ] 6,Pad Ie Horiz Horiz Min'm M.D. T.V.D. Rect Coordinates M.D. T.Y.D. Rect Coordinates Bearing Dist Dist 6744.0 4473.8 3605.3N 2515.4E 7340.0 4473.8 3521.4N 3744.9E 93.9 J 232..1 956.4 All data is in feet unless otherwise stated. Casing dimensions are not included. ') ) Coordinates from slot #19 and TVD from Est. RKB (D-141) (87.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 34.12 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ConocoPhillips Alaska, Inc. Pad lC,19 Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 3 Your ref : MWD <0-10435'> Last revised: 14-May-2003 Reference welIpath Object welIpath: GMS <0-10243'>,,6,Pad IC Horiz Horiz Min'm M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Dist 6744.0 4473.8 3605.3N 2515.4E 6526.3 4473.8 4116.9N 1267.5E 292.31348.7 1333.3 ) ) All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #19 and TVD from Est. RKB (D-14I) (87.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 34.12 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ) ) Structu re ConocoPhillips Alaska, Well: 19 North ..... n'............. .... 'ë~~'~t~d' '¡;~'¡;;:¡~'h'~'~ï'" Data plotted: 14-Mcy-200J . Plot RaterclnCa r~ MWD <0-104J5'), ¡ Coordlnatc:! ore In rClet retorancC! ,lot 1/19. ¡True VertIcal Dapthll crt! referancCI Eat. RK8 (0-141)'1 i .,Iff- i ~ 1 ........... .. ......."...,...,~.~:~..,~:y.,',.,. ., ,.. "........".....................J Field: Pad IC River Unit Inc. ~/ ConocoPhillips Location ./<9 East (feet) -) 2200 2300 2'00 2600 2600 2700 2600 2900 3000 3100 3200 3300 3'00 3600 3MO 3700 3600 3900 4000 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I " 5.300 1500 1600 Scale 1 inch = 100 ft 1700 1600 1900 2000 2100 I I I , I I I I I I I r I I I I I I I I I / ,/ / // / // / S ~"/2UO.' I / I I 't 7 C..'o, / / § 1320 ft <§t/ - 6100 ^ £,_ I >'7 - 3700 ~ / - ;: 9~/lJ Ca,ln\! "./ II ./ CD ~ / / ../ ~ 3400 ./ ./ ././ ./ / ./ ./ ./ ~ 3200 ,/ ./"./ ./ " /" ./ " ./ " ./ " //' ././ ./ " ./ ./ U1 ~ 2300 0 " ~ 2200 ~ o o ;: ) ) RUNNING DETAIL ONLY TUBING DETAIL ConocoPhillips Alaska # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN WELL: 1C-19 DATE: 5/12/2003 1 OF 1 PAGES LENGTH DEPTH TOPS Doyon RT -LDS Hanger FMC 'GEN 5' Tbg. Hanger wi EUE 8rd Mod Pin down Jt303-317 3.5" 9.3# L-80 EUE 8rd Mod pup 00 4.48" 10 2.992" 3.511 Cameo 'D' nipple wI 2.87511 Profile OD 4.52011 ID 2.87511 Jt215-302 3.5" 9.3# L-80 EUE 8rd Mod pup 00 4.48" 10 2.992" Pup 3.5" 9.3# L-80 EUE 8rd Mod pup 00 4.48" 10 2.992" GLM #5 3.511 X 1.511 Cameo 'MMG' wI Dummy, RK Lateh OD 5.96811 ID 2.92011 Pup 3.5" 9.3# L-80 EUE 8rd Mod pup 00 4.48" 10 2.992" Jt.129-214 3.5" 9.3# L-80 EUE 8rd Mod Tbg. 004.48" 102.992" Pup 3.5" 9.3# L-80 EUE 8rd Mod pup 00 4.48" 10 2.992" GLM #4 3.511 X 1.511 Cameo 'MMG' wI Dummy, RK Lateh OD 5.96811 ID 2.92011 Pup 3.5" 9.3# L-80 EUE 8rd Pup 00 4.54" 10 2.992" Jt.66-128 3.5" 9.3# L-80 EUE 8rd Mod Tbg. 004.48" 102.992" Pup 3.5" 9.3# L-80 EUE 8rd Mod pup 00 4.48" 10 2.992" GLM #3 3.511 X 1.511 Cameo 'MMG' wI Dummy, RK Lateh OD 5.96811 ID 2.92011 Pup 3.5" 9.3# L-80 EUE 8rd Mod pup 00 4.48" 10 2.992" Jt.28-65 3.5" 9.3# L-80 EUE 8rd Mod Tbg. 00 4.48" 10 2.992" Pup 3.5" 9.3# L-80 EUE 8rd Mod pup 00 4.48" 10 2.992" GLM #2 3.511 X 1.511 Cameo 'MMG' wI Dummy, RK Lateh OD 5.96811 ID 2.92011 Pup 3.5" 9.3# L-80 EUE 8rd Mod pup 004.48" 102.992" Jt. 3-27 3.5" 9.3# L-80 EUE 8rd Mod Tbg. 00 4.48" 10 2.992" Pup 3.5" 9.3# L-80 EUE 8rd Mod pup 004.48" 102.992" GLM #1 3.511 X 1.511 Cameo 'MMG' wI DCR shear RK Lateh 3000# Pup 3.5" 9.3# L-80 EUE 8rd Mod pup 00 4.48" 10 2.992" Jt. #2 3.5" 9.3# L-80 EUE 8rd Mod Tbg. 00 4.48" 10 2.992" 3.511 Cameo liDS' Nipple 2.813 No Go Profile OD 4.52011 jt # 1 3.5" 9.3# L-80 EUE 8rd Mod Tbg. 00 4.48" 10 2.992" Pup 3.5" 9.3# L-80 EUE 8rd Mod pup 00 4.48" 10 2.992" 3.511 Baker '80-40' PBR pinned for 30k Shear Baker 3.511 X 711 IISAB-311 Permanent Paeker wI Mill out Extension Pup 3.5" 9.3# L-80 EUE 8rd Mod pup 00 4.48" 10 2.992" Pup 3.5" 9.3# L-80 EUE 8rd Mod pup 00 4.48" 10 2.992" 3.511 CAMCO IIDII Nipple with 2.7511 No Go Profile OD 4.52011 Pup 3.5" 9.3# L-80 EUE 8rd Mod pup 00 4.48" 10 2.992" BAKER wire line entry guide wI Shear out sub 22.85 4.15 469.73 1.60 2732.26 6.05 8.39 6.01 2684.64 6.11 8.38 6.00 1967.71 6.04 8.44 5.98 1187.90 6.06 8.40 5.99 778.51 6.06 8.41 6.00 31.29 .97 31.32 6.05 14.60 12.00 6.01 6.01 1.00 6.04 .92 22.85 27.00 496.73 498.33 3230.59 3236.64 3245.03 3251.04 5935.68 5941.79 5950.17 5956.17 7923.88 7929.92 7938.36 7944.34 9132.24 9138.30 9146.70 9152.69 9931.20 9937.26 9945.67 9951.67 9982.96 9983.93 10015.25 10021.30 10035.90 10047.90 10053.91 10059.92 10060.92 10066.96 10073.00 Remarks: String Weights with Blocks:112K# Up, 70K# On, 35K# Blocks. Ran xxx joints of tubing. Drifted tubing & hanger with 2.867" plastic rabbit. Used Arctic Grade API Modified No Lead thread compound on all connections. Tubing is non-coated. All tubing is new Note! Sheared PBR and Landed 2.41' From fully inserted Doyon 141 Drilling Supervisor: Donald L. Wester/M Heim Well: 1 C-19 Date: 5/3/2003 DEPTH LENGTH TOPS ') ) ?;~PHILLIPS Alaska, Inc. ~ A Subsidiary of PHILLIPS PETROLEUM COMPANY Casing Detail 9 5/8" Surface CasinQ Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Jts 150 to 175 DOYON 141 RKB to Landing ring (27.80) 95/8" FMC Gen. V Casing Hanger 26 Jts 9 5/8", 40#, L-80 BTC Csg ID 8.835" 95/8" Tam Port collar 147 Jts 95/8",40#, L-80 BTCM Csg ID 8.835" 95/8" Weatherford float collar ID 8.835" 2 Jts 95/8",40 #, L-80 BTCM Csg ID 8.835" 9 5/8" Weatherford float shoe 28.00 1.53 991 .73 2.93 5640.80 1.51 76.47 1.71 Jts 3 to 149 Jts 1 to 2 TD 12 1/4" Hole Run the following centralization on the casing Total = 11 Straight centrz & 4 Bow Spring Stop Rings = 4 total Run 1 Bowspring in the center of joints 1 & 3 on stop collars Weathertord Gemco short, Straight, Rigid, 9 5/8" X 12" each 10" Ing One per joint, Jt's 2 & 4 thru 13 Run one Bow Spring Centtilizer on stop collars in the center of the joints directly above & below the TAM Port Collar. Remarks; String weights with Blocks: Up Wt ???k, Dn Wt ??k, Blocks 35k. Ran 175 Joints casing. Drifted casing with 8.625" plastic rabbit. Used Arctic grade Jet-Lube thread compound on all connections. Baker-locked the first 3 connections. Doyon 141 28.00 29.53 1021.26 1024.19 6664.99 6666.50 6742.97 6744.68 6755.00 Supervisor: Fred Herbert / Dear! Gladden CASING TEST and FORMATION INTEGRITY TEST Well Name: 1C-19 5/8/2003 Supervisor: Wester / Gladden Date: o Initial Casing Shoe Test Reason(s) for test: D Formation Adequacy for Annular Injection D Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 95/811, 40 ppf, L-80, BTC Casing Setting Depth: 6,744' TMD Hole Depth: 6,7751 TMD 4,474' TVD 4,4901 TVD Mud Weight: 9.0 ppg Length of Open Hole Section: 31' EMW= Leak-off Press. + Mud Weight 1 ,400 psi + 9.0 ppg 0.052 x TVD = 0.052 x 4,490' EMW for open hole section = 15.0 ppg Pump output = 0.1010 bps 2,800 psi - 2,700 psi - 2,600 psi 2,500 psi - 2,400 psi - 2,300 psi - 2,200 psi - 2,100 psi - 2,000 psi - 1,900 psi - 1 ,800 psi - W 1,700 psi - a: 1,600 psi - :J 1,500 psi - (J) 1 ,400 psi - fa 1 ,300 psi - a: 1,200 psi - a. 1 ,100 psi - 1,000 psi - 900 psi - 800 psi - 700 psi - 600 psi - 500 psi - 400 psi - 300 psi - 200 psi - 100 psi - o psi Fluid Pumped = 7.3 bbl I I ¡ I I ¡ I II I I I I I I .....LEAK-OFF TEST ~CASING TEST LOT SHUT IN TIME ~,- CASING TEST SHUT IN TIME -+- TIME LINE ¡ j o 2 4 6 6 10121416162022242626303234363640424446465052545656606264666670727476766062646666909294969610101010101111111111121212121213 MMMMMMMMMMMMMMMMMMMMMMM....M..M.....~~..~~......~.0246602466024660 k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k k 51 51 51 51 51 51 51 51 51 51 51 51 51 51 51 51 kkkkkkkkkkkkkkkk STROKES NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE r--------------r--Õ-stks--r--2õ-psr--1 r--------------r--.¡-stks--T---.¡1Õ-psr-1 r--------------r--ã-stks--r-24Õ-psr-1 r--------------r-12-stks--r-3SÕ-psr-1 r--------------r-1S-stks-r-49Õ-psr-1 r--------------r-2Õ-stks-r-S3Õ-psr-1 r--------------r-24-stks--r-73õ-psr-l r--------------r-2S-stks--r-s3õ-psr-l r--------------r-32-stks-r-93õ-psr-l r--------------r3S-stks--r;f;õ-4õ-psrl r--------------r-4Õ-stks--r;f;f3õ-psrl r--------------r-44-stks-r1-;2-2õ-psrl r--------------r-4S-stks-r1-;ä-2Õ-psr1 I---------------,..--------------,..----------------~ I I 52 stks I 1,400 psi: :---------------+--------------+----------------~ : I 54 stks : 1,335 psi I :- ---- ----------+--------------+--------------:-~ : ; 56 stks I 1,290 pSI: I---------------+--------------+--------------:-~ I : 58 stks : 1,250 pSI ; :---------------+--------------+--------------:-i : I 60 stks I 1,225 pSI I :---------------+--------------+--------------:-i ; : 62 stks I 1,200 pSI I :---------------+--------------+--------------:--i : : 64 stks : 1,180 pSI: r--------------r--ŠS-stks--r-1-;fjõ-psr1 r--------------r--ŠS-stks-r-1-;fšõ-psr1 r--------------¡--jõ-stks-¡-1-;fsõ-psr1 r-------------I--72-siiëš--¡-;¡;f4õJ)sr1 I I -------------- : - I SHUT IN TIME: SHUT IN PRESSURE r--õ~ö-mfñ--r-------------r1J4opsil ~~~1~Q~!!!~~~~¡~~~~~~~~~~~~~~¡~~~~~~~~ë~~~~ ~--?.:-º-!!!~~--+--------------+--~~º-~~~---t ~--ª.:-º-!!!~~--+--------------+--~~º-~~~---t !---~.:-º-!!!~~--l.--------------l.--~~º-~~~---! L--~.:-º-!!!~~-_l--------------L--~~º-~~~--.l L-?.:-º-!!!~~--L-------------L-~~º-~~~---1 ~--?.:-º-!!!~~--L-------------J--~z?..-~~~---! I 80 . I I 875 . I ~--_.:_-_!!!~~--.¡.--------------.¡.---------~~~---~ ! 9.0 min ¡ ¡ 870 psi ! r-1-õ~o-mTñ-r-------------r-s65-psr-1 -----------------------------------------------. CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE r-------------T--õ-siksmr----š-õ-¡;sr---¡ r-m---------r--2"-siks--r--23Õ-psr-1 r-------------r--¡-siks--r--i3Õ-psr-1 r_-------------r--Š--st-ks--T--4-šõ-ps¡--1 r_-------------T--ã-siks--T--š-sõ-psrl r_-------------T-1-Õ-stks-T--ssõ-psr-¡ r-------------T-1-2--stks-T--fiõ·psi . c ..---------------..---------------..---------------~ ! ! 14 stks ! 850 psi ! r----------m--r--rËfstks-r--g-3õ-psr-l r--------------r--rä-stks--r---g-Sõ-psr-l r---------------r--2"õštks-r-.¡:ö7"õ--pši-l r---------------r--2"išiks--r--.¡:1-Š-õ-pšfl r--------------T-2"s-štks-r-.¡:33õ--pšfl ..---------------~--------------- r----n---- ------"T I I 30 stks I 1,490 psi: ~------ ---------~------------- -- ~---- -------------1 : : 34 stks I 1,600 psi I ~---------------~---------------.---------------;:--I I : 38 stks I 1,760 pSI I ~---------------~- --------------. ---------------;:--1 I I 42 stks : 1,930 pSI: ~---------------.---------------.---------------;:--I I I 46 stks : 2,150 pSI : ~ ---- --- -- -- ---- .--------------- .---------------;:--1 I I 50 stks I 2,350 pSI : ~--------------- .---------------t--- - ----------':--1 I : 53 stks I 2,500 pSI I ; : ---------------" . ; SHUT IN TIME: SHUT IN PRESSURE t--õ~õ--rñiñ---t---------------f--2-,5õõ-p-si-! r-1-~õ--rñiñ---t---------------r2:51-õ-pšf1 r--2~Õ--ñiìn--r---------------r2~5ÖÕ--p-Š,. r-3~õ-rñiñ--r_-------------T2:5õõ--pšiY r--4~õ--rñiñ--r--------------T2:49Š-pšf1 r--5~õ--rñiñ---r--------------1-2:49š--p-sf1 r--6~õ--rñiñ--r---------------r-2:49š-pšfl r_-7~õ--rñiñ--r-------------nr2:49š--p-sil r_-8~õ--rñiñ--r_--------------r2:49Š-pšfl r--9~õ--rñiñ-T-------------r2:49š--pšfl r-Tõ~õïiiiñ--r-----m--_---r2:49õ--pšfl r-:fs:õ-iiiiñ--r---------------r2:49õ-pšfl r2õ~õ-iiiiñ-T--------------r2:49õ--pšfl r-25~õ-iiiiñ--r--------------T2:48Š--pši-l [~º~º~~!0~I~~~~~~~~~~~~~I~~~~~~Ë~~IJ NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY ) ) ConocoPhillips Alaska Cementing Report Legal Well Name: 1C-19 Common Well Name: 1C-19 Event Name: ROT - DRILLING Hole Size: TMD Set: Date Set: Csg Type: Csg Size: Primary 12.250 (in) 6,744 (ft) 5/6/2003 Surface Casing 9.625 (in.) Cmtd. Csg: OPEN HOLE Cement Co: Dowell Schlumberger Rot Time Start: : Rec Time Start:20:45 Type: Pre-Flush Volume Excess %: Meas. From: 160 Time Circ Prior To Cementing: 4.50 Mud Circ Rate: 210 (gpm) Mud Circ Press: 178 (psi) Report #: Start: 1 5/1/2003 Cement JOb Type: Primary Page t of 3 Spud Date: 5/2/2003 Report Date: 5/7/2003 End: Plug Hole Size: Top Set: (ft) BTM set: (ft) Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Cmtd. Csg: Cementer: Don from Cody Pipe Movement Pipe Movement: Reciprocating Type: LSND Density: 9.0 (ppg) Visc: 53 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type: Squeeze Open· Hole· Hole Size: , 44 74 TV!) SO TMD: (ft) SO Date: SO Type: Time End: : Time End: 02:45 RPM: SPM: 80 Init Torque: (ft-Ibf) Stroke Length: 1.0 (ft) Avg Torque: (ft-Ibf) Max Torque: (ft-Ibf) Drag Up: 285,000 (Ibs) Drag Down: 135,000 (Ibs) Start Mix Cmt: 01 :40 Start Slurry Displ: 01 :40 Start Displ: 04:23 End Pumping: 05:50 End Pump Date: 5/7/2003 Top Plug: Bottom Plug: Squeeze Casing Hole Size: TMD Set: Date Set: Csg Type: SO TMD: SO Date: Cmtd. Csg: Stage No: t of 3 Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 6.50 (bbl/min) 8.00 (bbl/min) (psi) (psi) (min) Returns: 100 Total Mud Lost: (bbl) Cmt Vol to Surf: (bbl) Ann Flow After: Mixing Method: Jet Density Meas By: densiomete Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Mud Data PV/yP: 18 (cp)/16 (lb/100ft2) Gels 10 sec: 4 (lb/100ft2) Gels 10 min: 5 (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: (ppg) Volume: (bbl) StageNó:1Slurry No: 10f2 To: (ft) Description: CW100 Cmt Vol: (bbl) Slurry Vol: (sk) Temperature: (OF) Temperature: (OF) Temperature: (OF) Density: 8.50 (ppg) Water Vol: (bbl) Class: Yield: (ft3/sk) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Purpose: Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 5/14/2003 1: 14:41 PM ) ) ConocoPhillips Alaska Cementing Report Legal Well Name: 1C-19 Common Well Name: 1 C-19 Event Name: ROT - DRILLING Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) To: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Type: Cement Casing Volume Excess %: 1.25 Meas. From: 160 Time Circ Prior To Cementing: 4.50 Mud Circ Rate: 8 (gpm) Mud Circ Press: (psi) Report #: Start: 1 5/1/2003 Stage No: 1. Slurry No:2of2 Page 2 of3 Spud Date: 5/2/2003 Report Date: 5/7/2003 End: Description: MUDPUSH XL Class: Cmt Vol: (bbl) Density: 50.00 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Purpose: SPACER Mix Water: (gal) Foam Job: N Temperature: (OF) Temperature: (OF) Temperature: (OF) Start Mix Cmt: Start Slurry Displ: 01 :40 Start Displ: 04:28 End Pumping: 05:50 End Pump Date: 5/7/2003 Top Plug: Y Bottom Plug: Y Time Compressive Strength 1: Compressive Strength 2: Stage No:2of 3 Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 5.00 (bbl/min) 6.00 (bbl/min) Y 625 (psi) 880 (psi) 10 (min) Y Temp (OF) (OF) Pressure (psi) (psi) Mud· Data Returns: 100 Total Mud Lost: Cmt Vol to Surf: (bbl) 160.00 (bbl) Ann Flow After: N Mixing Method: jet Density Meas By: desiometer Type: LSND Density: 9.0 (ppg) Visc: 53 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type: PV/yP: 18 (cp)/16 (lb/100ft2) Gels 10 sec: 4 (lb/100ft2) Gels 10 min: 5 (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: (ppg) Volume: (bbl) Type: Cement Casing Volume Excess %: 45.00 Meas. From: 0 Time Circ Prior To Cementing: 4.50 Mud Circ Rate: 8 (gpm) Mud Circ Press: 650 (psi) Start Mix Cmt: 00:00 Start Slurry Displ: 03:52 Start Displ: 04:23 End Pumping: 05:50 End Pump Date: 5/7/2003 Top Plug: Y Bottom Plug: Y Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 5.00 (bbl/min) 6.00 (bbl/min) Y 630 (psi) 880 (psi) 10 (min) Y Returns: 100 Total Mud Lost: (bbl) Cmt Vol to Surf: (bbl) Ann Flow After: N Mixing Method: batch Density Meas By: densiometr Type: LSND Density: 9.0 (ppg) Visc: 53 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type: PV/yP: 18 (cp)/16 (lb/100ft2) Gels 10 sec: 4 (lb/100ft2) Gels 10 min: 5 (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: (ppg) Volume: (bbl) Mud Data Printed: 5/14/2003 1: 14:41 PM ) ) ConocoPhillips Alaska Cementing Report Page 3 013 Legal Well Name: 1 C-19 Common Well Name: 1 C-19 Event Name: ROT - DRILLING Report #: Start: 1 5/1/2003 Spud Date: 5/2/2003 Report Date: 5/7/2003 End: Casing Test Shoe Test Liner Top Test T est Press: (psi) For: (min) Cement Found between Shoe and Collar: Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Tool: Tool: Log/Survey. Evaluation Interpretation Summary CBL Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: Remarks Run 9.625", 40#, L80, BTC Csg to 6,744' (175 jts total). Made up csg to the mark. Install bow spring centralizers on jts 1 and 3 wi stop collars, install free floating Rigid cents on jts 2 and 4-15. Instal TAM combo tool at 1,021' wi bow cent on jts above and below wi stop rings. CMT 9.625" Csg - Pump 5 bbls CW100, Test lines to 3500 psi, Pump remaining 45 bbls CW100, 50 bbls 10.5 ppg MudPush, Drop bttm plug, pump 655 bbls of 10.7 ppg Arcticset Lite lead slurry, 144 bbls of 12.0 ppg LitecreteTail slurry, Drop Top plug, kick out plug wi 20 bbls washup, turn over to Rig - Rig displaced with 485.8 bbls (Calc) Bumped plug wi 4,827 stks (Calc bump stks 4807)- Had 160 bbls 10.7 ppg CMT to surface. After shutting down and dropping top plug we could no longer recip csg (288 bbls lead cmt in ann)-CIP 05:55 AM - Complete job went well. Printed: 5/14/2003 1: 14:41 PM TMD I TVD I DFS 6,755.0 4,479.0 4.62 I FIELD NAME I OCS NO. AUTH MD I DAILY TANG Kuparuk River 10,427.0 0 ACCIDENTS LAST 24 HRS. ? DAILY INT WIO MUD o DATE OF LAST SAFETY MEETING DAILY TOTAL 5/6/2003 126,261 LEAKOFF AFE 10029185 I NEXT CASING 7.000 (in) @ 10,427.0 (ft) o I CUMCÖST Pf/Mf CI Ca 10 ) ConocOPhil1 ips,· Alaska Daily Drilling· Report WELL NAME I JOB NUMBER I EVE~;~DE 124 HRS PROG 1 C-19 SUPERVISOR I RIG NAME & NO. Fred Herbert I Dearl Glad n1334@ppco.co Doyon 141 CURRENT STATUS Displace cmt and bump plug-okay. 24 HR FORECAST ND/NU. Test BOPE- PU BHA #2 - P/U DP (single from shed) TIH LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP LAST SURVEY: DATE TMD INC AZIM I LAST CASING 5/5/2003 6,691.28 58.990 34.670 9.625 (in) @ 6,474.0 (ft) DENSITY(ppg) 9.25 Ipp I IECDI IMUDDATAI DAILY COST I FV. PVNP GELS WUHTHP FCIT.SOL OIUWAT %SandIMBT Ph/pM 52 18/14 315 8.21 21 I 0.1/17.5 8.01 BHANO. I 2 I BAA WT.BELOW JARS 32 BHA/HOLECONDITIONS STRING WT. DN STRING WT. ROT 110 134 NO JTS LENGTH 1 1.00 1 28.21 1 9.35 1 5.38 1 29.38 1 1.55 1 30.33 1 30.70 1 5.75 1 30.59 1 2.45 4 121.25 1 30.27 24 723.99 1 6.00 1 30.06 99 5,669.00 STRINGWT. UP 182 ITEM DESCRIPTION BIT 12 1/4"FGX1VC NAVIDRILL M1C NM LEAD DC NMST AB MWD CROSSOVER NMDC NMDC NMST AB NMDC CROSSOVER HWDP JARS HWDP GHOST REAMER HWDP DRILL PIPE ) O.D. 12.250 12.125 7.750 7.687 8.000 7.813 7.875 8.000 8.000 7.875 8.000 5.000 6.187 5.000 7.000 5.000 5.000 TORQUE / UNITS ft-Ibf I.D. 2.810 2.875 2.500 2.875 2.875 2.875 2.750 2.875 3.000 3.000 2.250 3.000 2.813 3.000 4.281 Page 1 012 I REPT NO. I DATE 6 5/6/2003 ICUM. TANGO CUM INT ANG WI MUD o CUM COST WI MUD 942,091 AUTH. LAST BOP PRES TEST H2S o LIME ES BrrNO. I 2 BHA LENGTH 6,755.26 CONN SIZE CONNTYPE BITS BIT / RUN SIZE MANUF. TYPE SERIAL NO. JETSORTFA DEPTH IN DATE IN I-O-D-L-B-G-O-R 21 2 12.250 SMITH FGX1 VC MM3795 20/20/20/1411 3,027.0 5/3/20032-3-RG-G-E-1-SS-TD BIT OPERATIONS BIT / RUN WOB RPM GPM PRESS PBIT HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 21 2 / 1 00 I 100 650 2,550 316 103.70 29.10 3,728.0 128.11 NO. 1 2 PUMP I HYDRAULIC DATA STROKE (In) LINER (In) SPM Q (gpm) PRESS. (psi) 12.000 6.000 70 296.11 2,550 12.000 6.000 70 296.11 2,550 TOTAL Q 592.22 592.22 OPERATIONS SUMMARY PHASE DESCRIPTION SURFAC Con't to Circu & Condition - Reduce mud wt from 9.4+ to 9.2 - Spot 1% lube pill in open hole - Pump dry job - Blow down Top Drive SURFAC TOH - No excess drag - No problems - UD ghost reamer - Reamer was FULL MAKE OF PUMP Emsco Emsco FROM TO 00:00 03:30 HOURS 3.50 CODE DRILL P TROUBLE SUB CIRC 03:30 07:45 TRIP 4.25 DRILL P KILL SPM / PRESSURE Printed: 5/14/2003 1: 18:00 PM " ') 1 C-19 ConocoPhHlips,Alaska DailyPri II ihgReport I JOB NUMBER I EVE~DC~DE 124 HRS PROG I T~~755.0 Page 2 of 2 WELL NAME TVD I DFS 4,479.0 4.62 I REPT NO. I DATE 6 5/6/2003 OPERATIONS SUMMARY FROM TO HOURS CODE TROUBLE· SUB PHASE DESCRIPTION 03:30 07:45 4.25 DRILL P TRIP SURFAC guage 07:45 09:30 1.75 DRILL P TRIP SURFAC UD BHA #2 09:30 10:45 1.25 CASE P RURD SURFAC R/U to run 9.625" 40# L80 BTC Csg. 10:45 11:00 0.25 CASE P SFTY SURFAC PJSM - Review Running Csg & Csg detail - Review known running hazards. 11 :00 12:00 1.00 CASE P RUNC SURFAC Run 9.625", 40#, L80, BTC Csg to 350' - (@ it #4 pump tested float equip) "OK" 12:00 14:45 2.75 CASE P RUNC SURFAC Con't to run 9.625" 40# L80 BTC Csg to 3,006'. 14:45 15:30 0.75 CASE P CIRC SURFAC Circ btms up at 5 BPM and 500 psi. 15:30 20:00 4.50 CASE P RUNC SURFAC Run 9.625", 40#, L80, BTC Csg to 6,744' (175 its total). Made up csg to the mark. Install bow spring centralizers on its 1 and 3 wi stop collars, install free floating Rigid cents on its 2 and 4-15. Instal TAM combo tool at 1,021' wi bow cent on its above and below wi stop rings. 20:00 20:45 0.75 CASE P RUNC SURFAC RD Frank's Fill-up tool, blow dwn TO, PU Landing Jt and Csg Hngr, Land Csg. MU cmt head. 20:45 00:00 3.25 CASE P CIRC SURFAC Circ and Cond mud while reciprocating csg. Stage pumps up to 8 bpm and 450 psi. UWT = 285K, DWT = 135K. 24 HR SUMMARY: Circu & Condition - Spot lube pill - TOH - UD BHA - R/U & Run 9.625" csg - Circu & COndition to Cmt COMPANY SERVICE PERSONNEL DATA· NO. HOURS COMPANY 3 Baker MWD 29 APC 5 Baroid 2 SERVICE NO. HOURS 2 2 2 CPAI Doyon DUO Baker Inteq DD ITEM UNITS .--.-! gals bbls MATERIALS I CONSUMPTION USAGE ....-.-.-....--..- ON HAÑ'C '--1' ITEM 980 11,124 Water, Drilling 5 170 Water, Potable UNITS bbls bbls USAGE 975 100 ON HAND 287 122 Fuel Freeze Protect RESERVOIR NAME 1 C-22 1 R-18 G&I 1 C-19 1 C-19 1 C-19 RESERVOIR AND INTERVAL DATA ZONE TOP BASE 230 0 870 0 o 0 COMMENTS Printed: 5/14/2003 1: 18:00 PM .J ') ConocoPhillips,Alaska Daily Drilling Report WELL NAME 1 JOB NUMBER 1 EVE~TDC~DE 124 HRS PROG TMD I TVD 1 DFS 6,755.0 4,479.0 5.62 1 FIELD NAME I OCS NO. AUTH MD I DAILY TANG Kuparuk River 10,427.0 0 ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD o DATE OF LAST SAFETY MEETING DAILY TOTAL 5/6/2003 603,105 ILEAKOFF AFE 10029185 I NEXT CASING 7.000 (in) @ 10,427.0 (ft) o I CUM COST I ÞfJMf CI Ca 0.04/0 1 C-19 SUPERVISOR 1 RIG NAME & NO. Don Wester/Dearl Gladd n1334@ppco.co CURRENT STATUS Doyon 141 RU & test csg 24 HR FORECAST Drlg 20' new hole - Preform LOT - Drlg I JAR HRS OF SERVICE 1 BHA HRS SINCE INSP LAST SURVEY: DATE TMD INC AZIM 1 LAST CASING 5/5/2003 6,691.28 58.990 34.670 9.625 (in) @ 6,474.0 (ft) DENSITY(ppg) 9.00 I PP I I ECD I I MUD DATAl DAILY COST I FV PVNP GELS WUHTHP FCIT~SOL OIUWÄT . %SandIMBT Ph/pM 53 18/16 415 5.81 2/ 0.0/5.0 8.51 LITHOLOGY BHA No.1 3 I BHAWT. BELOW JARS STRING WT. UP BHA I HOLE CONDITIONS STRING WT; DN STRING \NT. ROT ITEM DESCRIPTION NOJTS 1 1 1 1 1 1 1 1 1 3 1 4 1 25 99 BIT HCM605 TURBOBACK STAB MACH 1 XL MTR NON-MAG STAB CROSSOVER MPR ORD/CCN MWD CROSSOVER NMCSDP CROSSOVER HWDP JARS HWDP DRILL PIPE LENGTH 1.00 1.07 31.51 5.75 1.49 17.09 15.38 25.57 1.35 92.38 2.51 121.25 30.27 754.05 9,098.00 O.D. 8.500 8.437 8.375 8.375 6.250 6.750 6.750 6.750 6.000 5.000 6.750 5.000 6.187 5.000 4.281 BIT / RUN 31 3 SIZE MANUF. 8.500 HCC BITS TYPE SERIAL NO. JETS OR TFA HCM605 7101484 12/12/12/12/12/ BIT OPERATIONS GPM I PRESS I P BIT I HRS I 24Hr DIST I 24HrROP I CUM HRSI CUM DEPTH I CUM ROP OPERATIONS SUMMARY PHASE DESCRIPTION SURFAC Circu & Condition - Hold PJSM with crew and all contractors - Review Csg CMT detail and fluid disposal plans with all parties concerned. Review known hazards and backup plans. SURFAC CMT 9.625" Csg - Pump 5 bbls CW100, Test lines to 3500 psi, Pump remaining 45 bbls CW100, 50 bbls 10.5 ppg MudPush, Drop bttm plug, pump 655 bbls of 10.7 ppg Arcticset Lite lead slurry, 144 bbfs of 12.0 ppg LitecreteTail slurry, Drop Top plug, kick out plug wi 20 bbls washup, turn over to Rig - Rig displaced with 485.8 bbls (Calc) Bumped plug wi 4,827 stks (Calc bump stks 4807)- Had 160 bbls 10.7 ppg CMT to surface. After shutting down BIT/RUN WOB RPM FROM TO 00:00 00:30 HOURS 0.50 CODE TROUBLE SUB CEMENT P SFTY 00:30 06:00 5.50 CEMENT P SFTY Page 1 of 2 1 REPT NO. 1 DATE 7 5/7/2003 ICUM. TANGO CUM INTANG WI MUD o CUM COST WI MUD 1,545,196 AUTH. LAST BOP PRES TEST 5/8/2003 H2S o LIME ES TORQUE ¡UNITS BIT NO. I 3 .. BHA LENGTH 10,198.67 CONN SIZE CONN TYPE I.D. 2.000 2.000 2.750 2.875 2.875 2.875 2.750 3.000 2.250 3.000 4.281 DEPTH IN DATE IN I-O-D-L-B-G-O"R 6,755.0 5/7/20030-0-BT-C-D-2-NO-TD Printed: 5/14/2003 1: 17:35 PM ) ') Page 20f 2 1 C-19 COl1ocoPhHlips,A.laska Daily Drilling Report 1 JOB NUMBER 1 EVE~TDC~DE 124 HRS PROG IT~~755.0 ITVD I DFS 4,479.0 5.62 I REPT NO. I DATE 7 5/7/2003 WELL NAME OPERATIONS SUMMARY FROM TO HOURS CODE TROUBLE SUB PHASE DESCFUPTIÓN 00:30 06:00 5.50 CEMENT P SFTY SURFAC and dropping top plug we could no longer recip csg (288 bbls lead cmt in ann)-CIP 05:55 AM - Complete job went well. 06:00 09:00 3.00 CEMENT P RURD SURFAC RID CMT head & Line - UD landing jt - RID all Csg equip 09:00 11:30 2.50 DRILL P RIRD SURFAC NID Diverter system 11 :30 12:00 0.50 DRILL P RIRD PROD N/U Csg head & Tbg adapter 12:00 14:30 2.50 DRILL P RIRD PROD Set BPV - N/U BOPs - Test 5? metal to metal seal to 1000 psi hold fl 10 min "OK" - Pull BPV 14:30 15:30 1.00 DRILL P RIRD PROD C/O bUm Rams to 5" DP - Install test jt - R/U to test BOPs 15:30 18:30 3.00 WELCTL P BOPE PROD Test BOPs - Test BOPs and Choke manifold 250 Lol 5000 psi high, Test Annular to 250 Lo I 3500 psi high. Preform Accum. test & record. No failures - AOGCC rep John Spaulding waived witness test. 18:30 19:00 0.50 WELCTL P BOPE PROD Pull test plug - Set wear bushing - UD test jt 19:00 23:15 4.25 DRILL P DRLG PROD P/U BHA #3 23:15 00:00 0.75 DRILL P TRIP PROD TIH wI BHA picking up DP singles out of pipe shed 24 HR SUMMARY: Cont. PU BHA #3, Cut and Slip DL, RIH. COMPANY SERVICE PERSONNEL DAtA .N~ HOURS COMPANY 3 Baker MWD 29 APC 5 Baroid 2 SERVICE NO. HOURS 3 2 2 CPAI Doyon DUO Baker Inteq DO ITEM UNITS gals bbls USAGE 1,905 60 MATERIALS I CONSUMPTION ON HAND ITEM 9,219 Water, Drilling 110 Water, Potable UNITS bbls bbls USAGE 615 ON HAND 2,052 122 Fuel Freeze Protect 1 C-19 1 C-19 1 C-19 RESERVOIR··.·AND···INTERVAL··.DA,-A ZONE TOP BASE 1777 0 470 0 o 0 RESERVOIR NAME 1C-22 1 R-18 G&I COMMENTS Printed: 5/14/2003 1: 17:35 PM ) ) CÓnocoPhillips Alaska Cementing. Rt!port Legal Well Name: 1 C-19 Common Well Name: 1 C-19 Event Name: ROT - DRILLING Primary Hole Size: 8.500 (in) TMD Set: 10,427 (ft) Date Set: 5/12/2003 Csg Type: Production Casing Csg Size: 7.000 (in.) Cmtd. Csg: Production Casing Cement Co: Dowell Schlumberger Rot Time Start: : Ree Time Start:11 :00 Report #: Start: 2 5/1/2003 Cement Job Type: Primary Squeeze..Open Hole Hole Size: sa TMD: (ft) sa Date: sa Type: Cmtd. Csg: Cementer: Jerry Time End: : Time End: 14:30 RPM: SPM: 70 'nit Torque: (ft-Ibf) Stroke Length: 12.0 (ft) Avg Torque: (ft-Ibf) Max Torque: (ft-Ibf) Drag Up: 240,000 (Ibs) Drag Down: 120,000 (Ibs) Type: Cement Casing Volume Excess %: 75.00 Meas. From: 0 Time Circ Prior To Cementing: 3.50 Mud Circ Rate: 295 (gpm) Mud Circ Press: 600 (psi) Start Mix Cmt: Start Slurry Displ: Start Displ: End Pumping: End Pump Date: Top Plug: Bottom Plug: 16:45 5/12/2003 Y Y Type: LSND Density: 10.3 (ppg) Visc: 45 (s/qt) Bottom Hole Circulating Temperature:120 (OF) Displacement Fluid Type:Seawater Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Squeeze Casing Hole Size: TMD Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Page 1 of3 Spud Date: 5/2/2003 Report Date: 5/12/2003 End: Plug Hole Size: Top Set: (ft) BTM set: (ft) Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Pipe Movement Pipe Movement: Reciprocating Stage No:1 of1 Disp Avg Rate: Disp Max Rate: Bump Plug: Press Prior: Press Bumped: Press Held: Float Held: 6.00 (bbl/min) 7.00 (bbl/min) Y 1,000 (psi) 1,650 (psi) 10 (min) Y Returns: 100 Total Mud Lost: (bbl) Cmt Vol to Surf: (bbl) Ann Flow After: N Mixing Method: batch Density Meas By: densiomtr PV/yP: 17 (cp)/18 (lb/100ft2) Gels 10 sec: 5 (lb/100ft2) Gels 10 min: 7 (lb/100ft2) Bottom Hole Static Temperature: 160 (OF) Density: 8.6 (ppg) Volume: 395.00 (bbl) Mud Data Stage No: 1 Slurry No: 1014 To: (ft) Description: CW100 Cmt Vol: (bbl) Slurry Vol: (sk) Temperature: (OF) Temperature: (OF) Temperature: (OF) Density: 8.30 (ppg) Water Vol: (bbl) Class: Yield: (ft3/sk) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Purpose: SPACER Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 5/14/2003 1: 14:25 PM ) ConocoPhillips Alaska Cementing· Report Legal Well Name: 1 C-19 Common Well Name: 1 C-19 Event Name: ROT - DRILLING Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) To: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Slurry Data Fluid Type: Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Report #: Start: 2 5/1/2003 Stage No: t Slurry No: 2of4 ') Page 2 of 3 Spud Date: 5/2/2003 Report Date: 5/12/2003 End: Description: MUDPUSH XL Class: Cmt Vol: (bbl) Density: 12.10 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Slurry Data Fluid Type: PRIMARY Description: Slurry Interval: 10,427.00 (ft)o: 5,864.00 (ft) Cmt Vol: 50.0 (bbl) Water Source: Slurry Vol:240 (sk) Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Stage No: 1 Slurry No: 3014 To: (ft) Description: Cmt Vol: (bbl) Slurry Vol: (sk) Temperature: (OF) Temperature: (OF) Temperature: (OF) Density: (ppg) Water Vol: (bbl) Class: Yield: (fP/sk) Other Vol: 0 Purpose: Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Time Compressive Strength 1: Compressive Strength 2: Purpose: Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Test Data Thickening Time: 2.83 Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) Trade Name D-600G B155 0-65 D-47 0-29 CELLOPHANE Temperature: (OF) Temperature: (OF) Temperature: (OF) Class: G Density: 15.80 (ppg) Yield: 1.16 (ft3/sk) Water Vol: (bbl) Other Vol: 0 Time Compressive Strength 1: Compressive Strength 2: Stage No: 1 Slurry No: 4 of 4 - Additives Type GAS BLOCK DISPERSANT DEFOAMER L.C.M. Concentration Units 2.00G P S 0.02 %BWOC 3.00 %BWOC 0.2C G P S 0.25 %BWOC Purpose: PRIMARY Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Liquid Cone. Units 2.00 GAL Printed: 5/14/2003 1: 14:25 PM ) ·ConocoPhillips Alaska Cementing. RE!.port Legal Well Name: 1 C-19 Common Well Name: 1C-19 Event Name: ROT - DRILLING Report #: Start: Casing Test Shoe Test Test Press: (psi) For: (min) Cement Found between Shoe and Collar: Pressure: (ppge) Tool: Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: Log/Survey Eval.uation ) 2 5/1/2003 Page 3 of 3 Spud Date: 5/2/2003 Report Date: 5/12/2003 End: . Liner Top. Test Tool: Tool: Interpretation Summary CBL Run: Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: Hrs Prior to Log: Cement Top: (ft) How Determined: TOC Sufficient: Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: Printed: 5/14/2003 1: 14:25 PM ) ) ConocoPhHlips, Alaska DaHyDri II ing Report TMD I TVD I DFS 10,435.0 6,794.0 9.62 I FIELD NAME I OCS NO. AUTH MD I DAILY TANG Doyon 141 Kuparuk River 10,427.0 0 ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD Run 7" Csg (on jt # 192 of 246) 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL Run & CMT 7" Csg - MIU & TIH wI 3.5" completion assy. 5/11/2003 99,843 LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE 15.00 10029185 LAST SURVEY: DATE TMD INC AZIM I LAST CASING I NEXT CASING 5/10/2003 10,435.00 30.680 30.990 9.625 (in) @ 6,744.0 (ft) 7.000 (in) @ 10,427.0 (ft) DENSITY{ppg) 10.40 I ppl IECP I I MUDDATAlpAILYCOST 0 I CUM COST I FV PVNP GELS WUHTHP FCIT;SOL OIUWAT %SandIMBT Ph/pM Pf/Mf CI Ca 47 17/18 5/7 4.8/12.0 21 I 0.1/15.0 9.01 0.08/1 Page 10f 2 WELL NAME I JOB NUMBER I EVE~DC~DE 124 HRS PROG I REPT NO. I DATE 11 5/11/2003 I CUM. TANGO CUM INTANG WI MUD o CUM COST WI MUD 2,084,709 1 C-19 SUPERVISOR I RIG NAME & NO. Don Wester/Dearl Gladd n1334@ppco.co CURRENT STATUS AUTH. LAST BOP PRES TEST 5/8/2003 H2S o LIME ES OPERATIONS SUMMARY FROM TO HOURS CODE TROUBLE sua PHASE DESCRIPTION 00:00 00:15 0.25 CASE P SFTY PROD PJSM Running Csg - Review Csg detail wI crew & contractors. Review know hazards & Risk.Review running procedure and responsibilitys of each crew member. 00:15 03:15 3.00 CASE P RUNC PROD Run 7" 26# L80 STCM csg to 2959' 03:15 03:45 0.50 CASE P CIRC PROD Circu csg volume (114 bbls) - PR 5 bpm, 400 psi 03:45 04:00 0.25 CASE P RUNC PROD Run 7" 26# L80 STCM csg to 3004' - Frank's Fillup tool parted When driller picked up the elevators off of jt# 72 the bttm section of fill tool extenion had parted. The piece is 4' 3" long, 4.60" to 5.25" 00 , Made of metal, Wt app 60 Ibs. 04:00 04:15 0.25 CASE T EOIP RURD PROD UD Damaged Frank's fillup tool 04:15 04:45 0.50 CASE T EOIP RURD PROD Evaluate and discuss options 04:45 11 :00 6.25 FISHT EOIP SUN PROD Order out Slick line unit & Fishing tools.Will make overshot run on slick line. 11:00 12:00 1.00 FISHT EOIP SUN PROD RIH wI Overshot & 5" grapple to enguage fish. 12:00 12:45 0.75 FISHT EOIP SUN PROD POOH wI Slickline & Overshot - No recovery of fish - RID Slickline 12:45 13:00 0.25 CASE T EOIP SFTY PROD PJSM on Laying down 7" Csg - Review all know hazards - Explain to crew each man's job and risk 13:00 14:30 1.50 CASE T EOIP RURD PROD RIU to UD 7" Csg - Mix & pump dry job ( 20 bbls, 3 Ibs over) 14:30 18:30 4.00 CASE T EOIP OTHR PROD Pull 72 jts 7" 26# L80 STCM - No problems - Retrieve fish off top of float collar - No damage to Float Collar 18:30 20:00 1.50 CASE T EQIP RUNC PROD Rig back up to run 7" Csg - Clean Rig floor - Clear all tools off rig floor 20:00 23:30 3.50 CASE T EOIP RUNC PROD Run 7" 26# L80 csg to 2959' - Full returns on displacement 23:30 00:00 0.50 CASE P CIRC PROD Circu Csg Volume - 5 bpm @ 400 psi ( 115 bbls pumped) 24 HR SUMMARY: PJSM - Run 7" Csg - Circu - Franks tool parted - Order SL Unit & Fish tools - Attempt recovery of fish - Pull Csg - Repair Frank's Tool- Run 7" Csg COMPANY SERVICE PERSONNEL DATA NO. HOURS COMPANY 3 Baker MWD 29 APC 5 Baroid 2 SERVICE NO. HOURS 3 2 2 CPAI Doyon DUO Baker Inteq DO ITEM UNITS gals bbls USAGE 940 MATERIALS I CONSUMPTION ON HAND ITEM 5,739 Water, Drilling 110 Water, Potable UNITS bbls bbls USAGE 435 90 ON HAND 1,782 123 Fuel Freeze Protect Printed: 5/14/2003 1: 15:51 PM WELL NAME 1 C-19 RESERVOIR NAME 1 C-22 1 R-18 G& I 1 C-19 1 C-19 1 C-1 9 ) ) ConocoPhillips, Alaska Dai lyDri llingReport I JOB NUMBER I EVEONTOCRODE 124 HRS PROG I TMD I TVD 10,435.0 6,794.0 RESERVOIR AND INTERVAL DATA ZONE TOP BASE o 0 o 0 o 0 IDFS 9.62 COMMENTS Page 2 of 2 I REPT NO. I DATE 11 5/11/2003 Printed: 5/14/2003 1: 15:51 PM ) ') CASING DETAIL KUPARUK INJECTOR WELL:1C-19 DATE: 5/11/2003 1 OF 1 PAGES LENGTH DEPTH TOPS ConocoPhillics # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN 3 - 246 Doyon Rig 141 Rotary Table to Landing ring 7" Ham:ler 7" ,26#, L-80, BTC-M Csg 7" Float Collar 7" ,26#, L-80, BTC-M Csg 7" Float Shoe 26.00 1.85 10317.28 1.30 80.82 1.49 26.00 27.85 10345.13 10346.43 10427.25 10428.74 1-2 Jts Shoe 71 of RAT HOLE TOTAL DEPTH 8.5" HOLE 10435.00 Centralizers = 27 total Install one 8 1/2" X 1" Bowspring centralizer in the middle of Jt #1,2 & 3 on stop rings, Then one 8 1/2" X 7" Bowspring centralizer on Jts# 4 thru 27 CenterinQ Guides = 17 total Run one 8 3/8" X 7" centering guide floating on Jts# 89, 90, 91, 92 & 93 Run one 8 3/8" X 7" centering guide floating on Jts# 234 thru 245 = Remarks: String weight up xxxK Down weight xxK, Block 35K . Ran 246 joints of casing. Drifted casing and hanger with 6.15111 platic rabbit. Used Arctic grade Jet-Lube No Lead thread compound on all connections. Doyon 141 Drilling Supervisor: Don Wester / Dearl Glanden KRU - 1 C-19 PrtJucer Longstring Base Case Proposed Completion Schematic Single Completion II-fur I ~ i ~ I I I ~ I I i I J 8J ~ I ....,ø ~ ~ i! 2 11 ~ 9-518" Port Collar II ~ I Stnd Gracie BTC q~ I ~ Threads (+/- ~ ~ 1000' MD) 21 I I I I I I I !! I I ~ 2 ~ I 21 ~ I ....a ~ ~ i _~ I ~ ~ ~ ~ ~ ~ ~ ~ ~ I ~ I ~ ~ -~ I I ~ ~ ~ I I ~ ~ ~ ~ ~ I ~ I ~ ~ -~ ~ ~ ~ ~ ~ ~ I ~ I ~ ~ I I ~ I ~ ~ ~ ~ ~ rf! ~ ~ ~ ~ I I I I ~ ~ I ~ ~ iI. ~ ~ ~\... ~ ~ ..- I ~ ~ I ~ ~ I ~ I I I ~ ~ ~ I ~ - ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ I ~ ~ S I ~ ~ I I ~.~ I ~ I ~ ~ I I .c ~ ~ ~ ~ ~ ~:u" ~ j t- -.,¡:: Y:":' _.~ ~ ~ ~ I ~ I ~ ~ ~ Gemén~ ¿ 16"x30" insulated conductor @ +/- 1 ~8' MD Surlace csg. 9-5/8"40# L-80 BTC @ +/- 6,737' MD / 4,484' TVD (Csg point 200' TVD below the base of the West Sak) Kuparuk C Sand Peñs (to be done post rig) Production csg. 7" 26# L-80 BTCM @ +/- 10,427' MD / 6,787' TVO I I 2: ~ I r I ~..... K r- ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ) ConocóPhillips r ~ I ~ I ... 3-1/2" FMC Gen V tubing hanger, 3-1/2" L-80 EUE8RD pin down. Special Drift 2.91" 3-1/2", L-80, 9.3# EUE8RD Spaceout Pups as Required. Special Drift 2.91" 3-1/2" 9.3# L-80 EUE8RD Tubing to Surlace Special Drift 2.91" 3-1/2" Camco OS Landing Nipple with 2.875" 10 No-Go profile set @ +/- 500' MD. 9~5/8" @ +/- 6,737'MD /4,484' TVD G M Placement: Valves #1-4: 3-%" x 1-~" MMG . Place gas-lift mandrels at the following depths: :r& 2550' 4075' 5150' 5850' APproximate MD 3237' 5989' 7929' 9145' VALVE #5: 3-1/2" x 1-1/2" 'MMG' GLM w/ OCR Dump Kill Valve (3000 psi casing to tubing shear). 6' L-80 handling pups installed on top and bottom of mandrel. 1 Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 3-1/2" Camco 'DS' nipple w/2.813" No-Go profile 1 Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 6' Handling Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. Baker '80-40' PBR. Baker 7" x 3-1/2" 'SAB-3' Permanent Packer set +/- 100' MO above top planned perl. Minimum 10 through the packer 3.00". 6' Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 3-1/2" Camco 'D' nipple w/2.75" No-Go profile. 6' Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. Baker 3-1/2" WL Re-entry Guide w/ shear out sub. Tubing tail 50' above top planned perloration. TD @ 10,427' MO /6,787' TVD SDC 03/18/03 .) ) ConocoPh i II i ps,Alaska Ðai Iy Ðri IlingReport TMD I TVD I DFS 10,435.0 6,794.0 10.62 I FIELD NAME I OCS NO. AUTH MD I DAILY TANG Doyon 141 Kuparuk River 10,427.0 0 ACCIDENTS LAST 24 HRS. ? DAILY INT WIO MUD Run 3.5" Completion 0 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL Run 3.5" completion assy. - Set Packer - Shear off PBR 5/11/2003 288,718 LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE 15.00 10029185 LAST SURVEY: DATE TMD INC AZIM I LAST CASING I NEXT CASING 5/10/2003 10,435.00 30.680 30.990 7.000 (in) @ 10,428.0 (ft) (in) @ (ft) DE NSITY(ppg) 10.40 I PP I [ECDI ¡MUD DATA I DAILY COST [ 0 I CUM cOST I FV PVNP GELS WUHTHP FCIT.SOL OIUWAT· %Sand/MBT Ph/pM PflMf CI Ca 44 20/15 5/5 6.6/ 2/ I 0.1/12.5 8.0/ /1 Page 10f2 1 C-19 SUPERVISOR I RIG NAME & NO. Don Wester/Dearl Gladd n1334@ppco.co CURRENT STATUS I JOB NUMBER I EVE~DC~DE 124 HRS PROG I REPT NO. I DATE 12 5/12/2003 ICUM. TANGO CUM INT ANG WI MUD o CUM COST WI MUD 2,373,427 WELL NAME AUTH. LAST BOP PRES TEST 5/8/2003 H2S o LIME ES OPERATIONS SUMMARY FROM TO . HOURS CODE TROUBLE SUB PHASE DESCRIPTION 00:00 01:30 1.50 CASE T EOIP RUNC PROD Run 7" 26# L80 BTCM Csg 01:30 02:00 0.50 CASE P CIRC PROD Circu pipe volume - 5 bpm @ 410 psi 02:00 03:30 1.50 CASE P RUNC PROD Run 7" 26# L80 BTCM Csg to 6722' 03:30 04:00 0.50 CAS E P CIRC PROD Circu pipe volume - 5 bpm @ 440 psi 04:00 05:00 1.00 CASE P RUNC PROD Run 7" 26# L80 BTCM Csg to 8160 - On jt #193 the 7" csg came out of the pick up sling while picking up the joint,dropping (apprx 20') back to the rig floor. In the process of falling to the rig floor 2 men were struck with glancing blows by the pipe.Tourpusher notified the Rig Supv @ 0514 hrs and the Rig Supv called for the Emergency Evac crew. The EMTs were on site in 18 min. The crew member was evaluated to the KOC clinic and found to be in fair shape with some bruising and abrasions. He was sent to Anchorage for further evaluation. 05:00 07:30 2.50 CASE T SFTY PROD STOPPED the job - Safety Shut down - Record all information on witness statements - Record with pictures the work area, sling placement & position of csg jt after incident. Held Safety meeting with all crew members to make sure everyone understood what had happened and how we could prevent it from happening again - Circu & Recip Csg to prevent sticking 07:30 08:00 0.50 CASE T SFTY PROD PJSM w/ All hands & CPAI rep to con't running Csg - Review what was learned about incident - Discussed running hazards & risk 08:00 10:00 2.00 CASE P RUNC PROD Con't Running 7" Csg ( 246 JTS TOTAL) 10:00 10:45 0.75 CASE P RUNC PROD UD Franks Fillup tool - M/U hanger & Landing jt - M/U CMT head 10:45 12:00 1.25 CASE P CIRC PROD Circu & Condition - Stage up pumps slowly to 7 bpm @ 800 psi. 12:00 15:00 3.00 CASE P CIRC PROD Circu & Condition - Stage up pumps slowly to 7 bpm @ 800 psi. Held PJSM w/ Co rep, Rig crew,Cmt crew and Contractors - Discuss CMT detail and backup contingency plans. Up wt 270k, Dn wt 11 Ok 15:00 16:45 1.75 CEMENT P PUMP PROD Cement per well plan - Pump 10 bbls CW1 00, Test lines to 3500 psi, pump remaining 30 bbls CW1 OO,Drop Bttm plug #1, pump 50 bbls 12 ppg MudPush, Drop #2 Bttm plug, pump 50 bbls (240 sxs) 15.8 ppg slurry, Drop Top plug, Kick out plug with 5 bbls water & turn over to rig. Av CMT rate 5.4 bpm - Rig displace w/ 8.5 ppg seawater 3920 stks,bump plug w/ 500 psi over. Hold psi 5 min - Bleed ott- Floats held - CIP 1645 hrs 16:45 17:15 0.50 CEMENT P RURD PROD RID CMT head & lines - UD landing jt 17:15 18:30 1.25 CEMENT P SEOT PROD M/U Packott - RIH - RILDS - Test to 5000 psi f/1 0 min 18:30 19:30 1.00 CMPL TN P NUND PROD C/O Top pipe rams to 3.5" X 6" VBRs - Test door seals to 2500 psi - Clear rig Printed: 5/14/2003 1: 15:25 PM ) ) Page 2 of 2 1 C-19 ConocoPhiUips,Alaska Daily DriUing Report I JOB NUMBER I EVENOTDCRODE 124 HRS PROG I TMD I TVD 10,435.0 6,794.0 IDFS 10.62 I REPT NO. I DATE 12 5/12/2003 WELL NAME OPERATIONS SUMMARY FROM TO HOURS CODE TROUBLE SUB . PHASE DESCRIPTION 18:30 19:30 1.00 CMPL TN P NUND PROD floor of 7" csg tools 19:30 20:30 1.00 CMPL TN P RURD PROD R/U to run 3.5" completion 20:30 20:45 0.25 CMPL TN P SFTY PROD PJSM - Review Tbg detail - Discuss known hazards & Risk - Stress good communications between crew members 20:45 00:00 3.25 CMPL TN P RUNT PROD Run 3.5" 9.3# L80 EUE 8rd Tbg ( 90 jts total) per detail. 24 HR SUMMARY: Run 7" Csg - Csg dropping incident - Safety shut down to investigate causes - PJSM & Review - Con't running Csg - Circu & COndition - CMT Csg - RID CMT tools - Set & Test packoff - Change rams - Run Tbg completion COMPANY SERVICE· PERSONNEL DATA NO; HOURS COMPANY 3 Baker MWD 29 APC 5 Baroid 2 SERVICE NO. HOURS 2 2 2 CPAI Doyon DUO Baker Inteq DD ITEM UNITS gals bbls USAGE 880 5 MATERIALS ¡CONSUMPTION ON HAND ITEM 4,859 Water, Drilling 279 Water, Potable UNITS bbls bbls USAGE 600 100 ON HAND 1,182 103 Fuel Freeze Protect RESERVOIR NAME 1 C-22 1 R-18 G&I 1 C-19 1 C-19 1 C-1 9 RESERVOIR ANDINTERV AL DATA ZONE TOp· BASE 1186 0 570 0 o 0 COMMENTS Printed: 5/14/2003 1:15:25 PM PRESSURE INTEGRITY TEST PHILLIPS Alaska, Inc. Rig: Doyon #141 Date: 5/13/2003 Don Wester / Dear! W. Gladden I Pump used: I Other - See commen~ ... cVe~¡D /¡h~b >e~ J- C:J3i,,~ c._ _ -:-ut LOT/FIT ... Pumping down annulus. ... Well Name: Drilling Supervisor: 1 C-1 9 I· Casing Shoe Depth 6,744 Ft-MD 4,474 Ft-TVD 19-5/8" 40# 1Ft L-80 BTC Hole Depth 6,775 Ft-MD 4,490 Ft-TVD 1·1 9.0 ppg Lb/100 Ft2 2,500 psi Lbs 35,000 Lbs 5.1 bbls Pressure IntearitvTest Mud Weight: 10.4 ppg Mud 10 min Gel: l ]] W Lb/100 Ft2 Rotating Weight: 195,000 Lbs BlocksfTop Drive Weight: 35,000 Lbs Desired PIT EMW: 16.1 ppg Estimates for Test: 1326 psi 2.2 bbls I· 1·1 EMW = Leak-off Pressure + Mud Weight = 1150 10 4 0.052 x TVD 0.052 x 4474 + . EMW at 6744 Ft-MD (4474 Ft-TVD) = 15.3 ppg 1500 . 1000 . w a: ::J en en w a: a. 500 . o ~CASING TEST Comments: PIT 15 Second Shut-in Pressure, psi 950 ~ (\A,os~ !'l.\'-\'\,-\\ "'\IJ, L.: &~ / ~ I] _. -=. \l..\:\ $J¡fJ E :: :3: ......____.0______..___ -~.:::::::::::::::::::::::::::::::::::::::::::: 2 4 8 Barrels 5 10 15 20 25 30 Shut-In time, Minutes o PIT Point ~LEAK-OFF TEST Volume Input Volume/Stroke Pump Rate: Strokes .. 0.0224 BblsfStrk .. 20.0 Strk/min ... Casing Test Pressure Integrity Test Pumping Shut-in Pumping Shut-in Strks psi Min psi Strks psi Min psi 0 20 55 0 975 1 40 \'4$"""250 0.25 950 2 60 \'"\5'"425 0.5 950 3 80 ¡~550 1 9?') 4 100 (OÒ650 1.5 92'5/ 5 120 ~"'Ü850 2 6 140 ps' 975 2.5 925 7 160 ioò1075 3 925 8 180 ;IS- 11 00 3.5 925 9 200 v 1100 4 925 10 220 () 11 00 4.5 925 15 240 ~ç¡ 125 5 925 20 260.)s'1150 5.5 925 25 280 0 J 150 6 925 30 300 ..·~~1 000 6.5 925 320 1000 7 925 340 1000 7.5 925 360 1000 8 925 8.5 925 9 925 9.5 10 ~. Volume Pumped 0.0 i::Sbls Volume Bled Back 2.8 i::Sbls Volume Pumped 8.1 i::Sbls Volume Bled Back 3.2 i::Sbls Type of Test: Hole Size: 18-1/2" RKB-CHF: 28.0 Ft Casina Size and Description: .Casina Test Mud Weight: Mud 10 min Gel: Test Pressure: Rotating Weight BlocksfTop Drive Weight: Estimates for Test: ) ) Note to File 1 C-19 (203-054.. .303-148) Kuparuk River Unit ConocoPhillips Alaska, Inc Phillips has made application for annular disposal in the subject well. The pertinent information for the well has been examined and the following determination made. SURFACE HOLE AND SURFACE CASING --No unusual events were reported while drilling the surface hole of the well. --Surface casing was cemented to surface. No unusual events were reported cementing the surface casing. The attachments to the application note that 160 bbls of lead cement were circulated to surface. The actual pumped volume was reviewed using the spreadsheet and the XS volume left in the hole was calculated at 72%. It is indicated that the casing is well cemented. INITIAL LEAKOFF TEST --On the Initial leakoff test, the formation yielded at 15.0 ppg EMW with a slow decline with continued pumping to 13.8 EMW. The pump in pressure appears to be stabilizing at this EMW. When pumping was stopped, the pressure dropped to 900 psi (12.8 EMW) in 2 minutes. The pressure slowly continued to decline and reached 865 psi (12.7 EMW) at 10 minutes. PRODUCTION HOLE AND PRODUCTION CASING --No unusual events were reported while drilling the 8-1/2" hole section. --7" casing was successfully run and cemented. SUBSEQUENT INJECTIVITY TEST --A subsequent injectivity test was done down the 9-5/8" x 7" annuli of the well. Initial failure happens at 15.0 EMW with a later drop in the pumping pressure to 14.7 EMW. After stopping pumping the pressure declined to 14.4 EMW in 1 minute and remained there during the observation period. The injectivity tests does shows that the formations at the shoe are competent and will accept solids laden fluid at BHP EMWs less than the LOT EMW. M:\tommaunder\ Well Information\By Subject\Annular Disposal\030516-203-054- KRU lC-19.doc ,) ) PROXIMATE WELLS The proximity analysis shows that the surface casing shoe of C-16 is about % mile distant from 1 C-19. There are no other proximate wellbores. Based on examination of the submitted information, I recommend approval of Phillips' requests for the subject wells. þ(YNt 7f1~ Tom Maunder, PE Sr. Petroleum Engineer May 16, 2003 M:\tommaunder\Well Infonnation\By Subject\Annular Disposal\030516-203-054- KRU lC-19.doc t ) ~~~~~ ~ F !Æ ~l.fÆ~~~ FRANK H. MURKOWSK/, GOVERNOR ~ A.I/A.~1iA OIL AND GAS CONSERVATION COMMISSION Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips (Alaska), Inc. PO Box 100360 Anchorage AK. 99510-0360 333 w. PH AVENUE,· SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Unit 1 C-19 ConocoPhillips (Alaska), Inc. Permit No: 203-054 Surface Location: 1615' FNL, 1360' FEL, Sec. 12, TIIN, RIOE, UM Bottomhole Location: 932' FNL, 124' FEL, Sec. 6, TI1N, RIlE, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or 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 witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). S&:1; ~«-- Randy Ruedrich Commissioner BY ORDER OF THE COMMISSION DATED this1L2 day of April, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section ~.) ConocoPhillips ) Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907) 265-6830 Fax: (907) 265-1535 Email: rlthomas@ppco.com March 21,2003 Cammy Oechsli Taylor, Chair Alaska Oil and Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 (907) 279-1433 Re: Application for Permit to Drill, producer 1 C-19 Dear Commissioner Taylor: ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill an onshore production well, KRU 1 C-19, a development well. Please find attached for the review of the Commission the information required by 20 ACC 25.005 (c). If you have any questions or require any further information, please contact Shane Cloninger at 265- 6829. Sincerely, ~~~ \ ~ Randy Thomas GKA Drilling Team Leader fiä. , ,....'..:...;. -,...1 'I ~ .11:".7.;; ;'.,1 ',',':",) I~~: 4 ··..1 .~ lOR'S NA- ""'--" AL,..·.,.~·. -:' .'; ""., (~'.~Y'. '~;'_J..;::~..;on r ~:I.';~ ~^l.~{t"'~; ! I 01 try! ~ ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 . 1 a. Type of work: ~ Drill Redrill D Re-entry DDeepen D 2. Name of Operator ConocoPhillips Alaska, Inc. 3. Address P.O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surlace 1615' FNL, 1360' FWL, Sec. 12, T11N, R10E, UM At top of productive interval 1053' FNL, 44' FWL, Sec. 06, T11 N, R11 E, UM At total depth 932' FNL, 124' FWL, Sec. 06, T11 N, R11 E, UM 12. Distance to nearest property line 13. Distance to nearest well 124' @ TO feet 1C-22 , 32' @ 699' 16. To be completed for deviated wells Kickoff depth: 500' MD 18. Casing program size 1 b. Type of well. Exploratory 0 Stratigraphic Test D Service 0 Development Gas 0 Single Zone 0 5. Datum elevation (DF or KB) RKB 28 feet 6. Property Designa~~L 2'l,.z.1r:. Kuparuk River Field ADL 25649/ A[J('46T ~ Kuparuk Oil Pool 7. Unit or property Name 11. Type Bond (see 20 AAC 25.0251) Kuparuk River Unit Statewide 8. Well number Number 1 C-19 #59-52-180 9. Approximate spud date Amount May 7,2003 $200,000 14. Number of acres in property 15. Proposed depth (MD and TV D) 2560 ~ ' MD / 6787 I TVD 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) ICJ¥ 2-7 'A1.b ,/1> Maximum surface 2746 psig At total depth (TVD) 3400 psig Setting Depth 20. Attachments Filing fee 0 Property Plat D BOP Sketch 0 Diverter Sketch 0 Drilling program 0 Drilling fluid program 0 Time vs depth plot Defraction analysis D Seabed report D 20 AAC 25.050 requirements 0 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Shane Cloninger 265-6829 Signed' \ ~~~ Randy Thomas Commission Use Only Permit Number ~ i I API number ~ -:2/1 /£:)/-I^ I Approval date 1/ }..() ;:) -(;>ç 50- ot.Jl - ¿..-;::) ~7 .....""c....; f / /( ~ Conditions of approval S mples required D Yes ~ No Mud log re6uired Hydrogen sulfide measures 00 Yes 0 No Directional survey required ~ Yes Required working pressure for BOPE D2M; D 3M; 0 5M; 0 10M; D 0 Other: ~ 5 00 \>~, ~\.~, ~ ~ ~ ~cS~ -\e.. ~ \-, ß..-/¡ ¡P~¡ '--~comm;ss;one' O:fG ,NAL Maximum hole angle Hole Casing Weight 42" 16" 62.5# 12.25" 9.625" 40# 8.5" 7" 26# Specifications Grade Coupling H-40 welded L-80 BTC L-80 BTCM Length 80' 6709' 1 0399' 19. To be completed for Redrill, Re-entry, and' Deepen Operations. Present well condition summary Total Depth: feet feet measured true vertical Effective Depth: measured true vertical feet feet Casing Conductor Surface Production Length Size Cemented Liner Perloration depth: measured true vertical Approved by Form 10-401 Rev. 12/1/85· Development Oil 0 Multiple Zone D 10. Field and Pool 580 Top Bottom Quantity of Cement MD TVD MD TVD (include stage data) 28' 28' 138' 138' 9 cy High Early 28' 28' 6737' 4484' 810 sx AS III Lite & 360 sx Litecrete 28' 28' 1 0427' 6787' 240 sx Class G Plugs (measured) Junk (measured) Measured depth True Vertical depth ~",..:' Ml\R 24: 1 I '. _..f. .....,,'.,~,.~:~ Title: Kuparuk Team Leader ~/2:J/O 3 Date Pn::marArf hv Pat (;nrffrAv ~ee cover letter for other requirements Yes ~ No o No by order of f/ 7 /~3 the commission Date Submit in triplicate ) Apr"~tion for Permit to Drill, We1l1C-19 } Revision No.O , Saved: 21-Mar-03 Permit It - Kuparuk We1l1C-19 Application for Permit to Drill Document Ml)ximizE W~II VOIUE; Table of Contents 1. Well Name..... ................... ........... ...... ...................... ..... ............. ....... ........... ..... ... ...... 2 Requirements of 20 AAC 25.005 (f)........................................................................................................2 2. Location Su m mary ....... .... ........... .... ... ........ ... ...... ...... ... ..... ........ ...... ....... ... ....... ... ..... 2 Requirements of 20 AAC 25.005(e)(2) .... .............................................. ..................... ............................ 2 Requirements of 20 AAC 25. 050(b)........ ................................................................................................ 2 3. Blowout Prevention Equipment Information ......................................................... 3 Requirements of 20 AAC 25.005(e)(3) ........................... .................................. ......................................3 4. Dri II i ng Hazards Information .................................. ... ... ............. .................. ............ 3 Requirements of 20 AAC 25.005 (e)( 4) .................................................................................................. 3 5. Procedure for Conducting Formation Integrity Tests ........................................... 3 Requirements of 20 AAC 25.005 (e)(5) .................................................................................................. 3 6. Casing and Cementi ng Program .............................................................................4 Requirements of 20 AAC 25.005(e)(6) .......................................... ............ ............................................. 4 7. Diverter System Information....... ................. .......... .... ................................... ... ....... 4 Requirements of 20 AAC 25.005(e)(7) ...................................................................................................4 8. Dri II i ng FI u id Prog ram ........................ ........ ....... .......... ....................... ......... ... ...... ... 4 Requirements of 20 AAC 25. 005( e)(B) ................................................................................................... 4 9. Abnormally Pressured Formation Information ...................................................... 5 Requirements of 20 AAC 25.005 (e)(9) ................... .................... ........................................................... 5 10. Seism ic Analysis.................... ... ... ..... ........ ...... ........... .... .... ....... ....... ..... ............ ... .... 5 Requirements of 20 AAC 25.005 (e)(10) ................................................................................................5 11. Seabed Condition Analysis .....................................................................................6 Requirements of 20 AAC 25.005 (e)(11) ............................................................... ................... .............. 6 12. Evidence of Bond i ng ...... ......... ........... ............... ...... ........ ... .......... ...... .............. ....... 6 Requirements of 20 AAC 25.005 (e)(12) ................... ....... ................................. .... ..................... ............ 6 1C-19 PERMIT IT. DOC Page 1 of 7 Printed: 21-Mar-03 1C~19 PERMIT /TDOC Page 2 of 7 Printed: 21-Mar~03 Requirements of 20 AAC 25.050(b) If'a well is to be intentionally deviatecf, the applk."iltion for a Permit to Drill (FOI717 10-4m) must (1) include a plat; drawn to a suitable 5calt~ s170wing tlle path ol the proposed wellbore" inäuding all adþcent wellbores wIthin 200 féet olany portion ol the propo.s-ed wel¿' Please see Attachment 1: Directional Plan 10,427' 6,787' 6,700' 10,138' 6,537' 6,450' 28.0' AMSL 59.0' AMSL and (D) ot/ìer information required by.20 AAC ]5:050(b); Sec 06, T11N, R11E, UM Measured Depth, RKB: Total Vertical Depth, RKB: Total Vertical Depth, 55: Location at Total Depth I 932' FNL, 124' FWL, NGS Coordinates Northings: 5,974,621 Eastings: 566,359 Measured Depth, RKB: Total Vertical Depth RKB: Total Vertical Depth, 55: Eastings: 566,280 Location at Top of Productive Interval (Kuparuk "C" Sand) NGS Coordinates Northings: 5,974,500 1053' FNL, 44' FWL, Sec 06, T11N, R11E, UM 11615' FNL, 1360' FWL, Sec 12, T11N, R10E, UM RKB Elevation Eastings: 562,368 Pad Elevation Location at Surface NGS Coordinates Northings: 5,968,624 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application (or a Permit to Drill must be accompimied by each of the l(¡llowing item5~ except tÒr an item already on file wiih the commis.,sion and ident/lied in the application: (2) a plat identlfj¡jng the property and the property's' owners- and ~<ihowing (A)the coordk7ates Of'tI7é:! proposeä location ot'the well at the sl/Iface" at the top of each objective formationl ând at total depth¡ retèn:.mced to governmental sì:?ction lines, (B) the C'OoniilNJMs of'the pmpOSéyj location of the well at the surfáa~ referenced to tlN:? state plane coordinate system lor this stati? as maintained by tl7e National (;¡è()detk~ Survey in the National Oceanic and Atmospheric Admim:'itration,,' (C) the proposed depth of t/7e well at the top of eac/7 objective formation and at total depth' 1. Well Name Requirements of 20 AAC 25.005 (f) Eaäì well must be ie/entified by a unique name designated by the operator and a unique API number as:.çigned by the commission under 20 MC 25. 040(b). For a well wIth multiple well bra!lcf¡es~ each branch mu~"t slimïady be identified by a unique name and API numÖer by adding a suffix to the name designated for the well by the operator and to the number a.fis~qned to the well by the commlfision. The well for which this application is submitted will be designated as lC-19. 15. Attachments .................... .'...... ....... ....... ......................................................... ........... 7 Attachment 1 Directional Plan .... ....... ..................... ........ ........... ....... ....... .... ...................... ...... ............... 7 Attachment 2 Drilling Hazards.................,.,...."................................................................... 7 Attachment 3 Well Schematic..,.................................. '....................................................",.. 7 14. Discussion of Mud and Cuttings Disposal and Annular Disposal....................... 7 Requirements of 20 AAC 25.005 (c)(14) .................. .................... ...... ..................... ................ .... ........... 7 13. Proposed Drilling Program .....................................................................................6 Requirements of 20 AAC 25.005 (c)(13) ...... ....... .... .......... ........ .... .......... .... ........ ............................. ......6 ''3tion for Permit to Drill. We1/1C-19 Revision No.O Saved: 21-Mar-03 'í ht .~ Af 'ation for Permit to Drill, We1l1C-19 Revision No.O Saved: 21-Mar-03 and (2) for all vi/ells wIthin 200 feet of tl7e proposed wellbore (A) list the names of the operators of those well~ to the extent that tl70se names are known or discoverable in public records¡ and show that each named operator has been furnished a copy of the application by certified mai¿' or (B) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Pe!7l71t to Drill must be accompanied by each of the followli7g Items¡ except f..f)f" an Item already on file with the commission and identified in the application: (3) a diagram and description of the bIO!~,¡out prevention equipment (BOPE) as required by 20 MC 25.03~ 20 AAC 25.03fÝ¡ or 20 AAC 25.037 as applicable/· Please reference BOP schematics on file for Doyon rig 19. 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 following Hems~ except for an Item already on file with the commission and identified in the applic;ation: (4) information on drillìng hazards~ ineluding (A) the maxlinum downhole pressure that may be encountered¡ crìteria Lôì:?d to determlÌ7e it, and maximum potent/~:J! surface pressure based on a methane grtJdìent; Based on reservoir modeling and history match of production/injection data, the estimated pressure is to be 3400 psi at 6450' TVD SS. Therefore, the highest expected pressure is 0.53 psijft or 10.1 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) while drilling lC-19 is calculated using above maximum reservoir pressure, a gas gradient of 0.11 psijft, and the Kuparuk C sand target at 6537' tvd: MPSP =(6537 ft)*(0.53 - 0.11 psijft) = 2746 psi (8) data on potentk'Jl gas zones~' The well bore is not expected to penetrate any gas zones. and (C) dlJt¡;¡ concermi7g potential causes of hole problems such a.5 abnormally geo··pre,,;;:sï.Jred strata/ lost circulation zones¡ t:1nd zones fflat 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 {or a Pelmìt to D/il/ must be accompanied by each of" the fb/lowing Items¡ except for an Item already on file with the commission and identifìed in the app/ìcatìon: (5) a description of the procedure for conducting formation integrity test~ as required under 20 AAC 25: 030(f); A procedure is on file with the commission for performing LOT's. 1C-19 PERM/T /T.DOC Page 3 of 7 Printed: 21-Mar-03 ( Aij" ... 3.tion for Permit to Drill, Well 1 C-19 , Revision No.O Saved: 21-Mar-03 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Dr/II 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 MC 25. 030/ and a description of any slotted liner;. pre- pefforated liner;. or screen to be 1i7stallecf.-' Casinq and Cementinq Proqram Hole Top Btm Csg/Tbg Size Weight Length MO/TVO MO/TVO 00 (in) (in) (/bltt) Grade Connection (ft) (ft) (ft) Cement Program 30 X 16 42 62.5 H-40 Welded 110 28/28 138/138 9 cy High Early Insulated 9-5/8 12-1/4 40 L-80 BTC 6,709 28/28 6,737/4,484 Lead: 810 sx 10.7 ppg AS III Lite Tail: 360 sx 12.0 ppg 'LiteCRETE' . (Yield=2.24 cuft/sk) Planned TOC=Surface 7 8-1/2 26 L-80 BTC-Mod 10,399 28/28 10,427/6,787 240 sx 15.8 ppg 'G' wI add. Planned TOC= 9,281' An open-hole leak-off test will be performed on the 8 '12" open hole interval after reaching the contingent casing point. If the leak-off test indicates insufficient formation integrity, 7" casing will be top-set above the Kuparuk C sand. In this case, 6 1/8" hole would be drilled to total depth and a 3 '12" 9.3 ppf L-80 SLHT production liner will be cemented across the productive interval. 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An applk-ation lor a Permit to Drill must be acyxJmpanied by each of the fÒllowli7{j Items~ except for an Item already on file with the commission and Identified In the application: (7) a diagram and desaiption a/the dlverter system as required by 20 AAC 25. 035,: unless t{¡is requirement is waived by the comml<;slol7 under 20 AAC 25.035(17)(2); Please reference diverter schematic on file for Doyon rig 19. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(B) An application tor a Pel7Tlit to Dlill must be accompanied by each of the following itern~ except for an Item already on file with the commis:,ìon and identified in tile application: (8) ð drilling flUId prvgram/ includìng a díagram and desctiptiofl of"tfle dnlling fluíd system, as required by 20 MC 25.033/ Drilling will be done using mud systems having the following properties: 1C-19 PERM/T /TOOC Page 4 of 7 Printed: 21-Mar-03 A( 'ation for Permit to Drill, We1l1C-19 Revision No.O Saved: 21-Mar-03 Suface Hole (extended bentonite) Spud to Base of Permafrost Base of Permafrost to Total Depth Initial Value Final Value Initial Value Final Value Density (ppg) 8.5 .$.9.2 .$.9.2* 9.2* Funnel Viscosity 150-200 150-200 150 65-75 (seconds) Yield Point 30-60 30-60 20-40 18- 30 (cP) Plastic Viscostiy 8-15 11- 22 15-30 15-30 (lb1100 sf) 10 second Gel 10- 30 10-25 10-25 10-25 Strength (lb1100 sf) 10 minute Gel 25-55 25-55 20-40 20-40 Strength (lb1100 sf) pH 8-9 8-9 8-9 8-9 API Filtrate(cc) 8-15 6 5-6 5-6 Solids (%) 5-8 5-8 5-8 6-11 Production Hole (LSND) Initial Value Final Value Density (ppg) 9.2 lOA Funnel Viscosity 40-55 40-55 (seconds) Yield Point 5-8 18-26 (cP) Plastic Viscostiy 6-13 14-25 (lb1100 sf) 10 second gel 3-7 4-7 10 minute gel 6-13 6-14 pH 9-10 9-10 API filtrate <6 <4 HTHP filtrate NC <10 Solids % 4-10 6-12 Diagram of Doyon rig 19 Mud System on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An applicatto/7 for a PermIt to Drill must be aL.Y.ompanied by each of the following Items¡ except fi.?r a/7 item already on file with the commis-sion and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths o(predkted abnormally geo-pressured strata as requÙ'ed by 20 AAC 25.033(f); Nj A - Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Penmt to Drill must be accompanied by each of the fbllowing Items, except for an item already on file with the commission and identified in the application: (10) for an exploratmy or stratigraphic test well a sei..'imic refraction or ref1ection analy..':;.ì:<; as required by 20 MC 25:061(a); Nj A - Application is not for an exploratory or stratigraphic test well. 1C-19 PERMIT IT. DOC Page 5 of 7 Printed: 21-Mar-03 A( 'ation for Permit to Drill, We1l1C-19 Revision No.O Saved: 21-Mar-03 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Pem7lt to Drill must be accompanied by each of the following item~ except for an item already 0/7 file with the commission and identified in the application: (11) for a well drilled from an offsl1Ore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(b); N/ A - Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Dlill must be accompanied by each of the fòl/oy'v'Ìng items, except for an item already 0/7 file with the commission and identified 1i7 the application: (12) eVidence showing tl7at the requirements of 20 MC 25.02.5 {Bonding}have /)een met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the fvllowing items, except for an Item already 017 tile with the commission and identified in the application: The proposed drilling program is listed below. Please refer as well to Attachment 3, Well Schematic. 1. MIRU Doyon 19. 2. Install diverter system. 3. Drill 12-1/4" hole to 9-5/8" surface casing point according to directional plan. 4. Run and cement 9-5/8" 40#, L -80 BTC casing string to surface. Employ lightweight permafrost cement lead slurry and LiteCRETE tail slurry. Pump adequate excess to ensure cement reaches the surface. If cement does not circulate to surface, perform top job. Install and test BOPE to 5000 psi. Test casing to 2500 psi. 5. Drill out cement and 20' of new hole. Perform LOT. 6. Drill 8-1/2" hole to contingent top-set casing point according to directional plan. Run LWD logging equipment with GR, resistivity, and neutron density. Perform second LOT to evaluate long string option. Drill well to total depth according to directional plan, and run 7" 26# L -80 BTCM casing to surface and cement. Note: If significant hydrocarbon zones are present above the Kuparuk C sand, sufficient cement will be pumped for isolation in accordance with 20 MC 25.030(d)(3)(C). 7. Run 3-1/2" 9.3#, L-80 8rd EUE 8rd-Mod completion assembly w/ SAB-3 permanent packer and PBR. Set packer, shear out of PBR, P/U tubing hanger, and land tubing. Pressure test tubing to 3500 psi. Pressure test 3 '12" x 7" annulus to 3500 psi. Burst shear valve for freeze protect. 8. Set TWC and ND BOPE. Install and pressure test production tree. 9. Freeze protect. Secure well. Rig down and move out. 10. Handover well to Operations Personnel. Note: If the deep LOT indicates insufficient formation integrity to continue drilling, 7" 26# L -80 BTCM casing will be run and cemented above the Kuparuk C sand. 6 1/8" hole will be drilled to total depth according to the directional plan and a 3 '12" 9.3# L-80 SLHT liner will be ran and cemented across the productive interval. 1C-19 PERMIT IT. DOC Page 6 of 7 Printed: 21-Mar-03 ( l' 'ation for Permit to Drill, Well 1 C-19 Revision No.O Saved: 21-Mar-03 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a PermIt to Drill mustc be accompanied by each of ttìe following Items" except for an item already on file with the commission and identified in the application: (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 MC 25080 for an annular disposal operation in the well./ Waste fluids generated during the drilling process will be disposed of down a permitted annulus on 1C pad or hauled to a KRU Class II disposal well. All cuttings will be disposed of either down a permitted annulus on 1C pad or hauled to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. At the end of drilling operations, an application may be submitted to permit 1C-19 for annular pumping of fluids occurring as a result of future drilling operations on 1C pad. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic. 1C-19 PERMIT IT.DOC Page 7 of 7 Printed: 21-Mar-03 '~ ConocoPhillips Alaska, Inc. ConocoPhillips .""......."" ...... - . C'eoled by bm;choel For: S Cloninger 500 - 1000 - 1500 - ,,--... 2000 - +- Q) Q) '+- '--" 2500 - ..r: +- 0.. Q) 3000 - 0 0 3500 - Ü +- !..... Q) > 4000 - Q) :J !..... 4500 - l- I V 5000 - 5500 - 6000 - 6500 - 7000 - Structure: Pad 1 C Well: 19 Date plotted: 19-!t.iar-200J Plot Reference is 1 C-19 Version ".A. Field: Kuparuk River Unit Location: North Slope. Alaska, 34.12 AZIMUTH 7059' (TO TARGET) ...Plane of Proposal... o - ! ESTIM'D RKB ELEV: 87' KOP 2.00 6.00 Build/Turn 3/100 15.48 21.24 27.10 DLS: 3.00 deg per 100 ft 33.01 Base Permafrost 38.95 44.89 50.85 56.82 EOC TANGENT ANGLE 58.15 DEG Bose West Sak TARGET ANGLE 30 DEG ~~~~6 Drop 52¡8~ 7~40 44.76 HRZ 36.76 . 32.76 _ _ Target-C4-EOC .~ ~. U. Kalubik L. Kalubik Top Kuparuk Ct:2 C1 B/B5 B4 TO - Casing pt. o 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 Vert ¡co I Sect ion (t e e t) - > Azimuth 34.12 with reference 0.00 N, 0.00 E from slot #19 ==== PROFILE CO~AMENT DATA ==== ----- Point ----- MD Inc Dir TVD No rt h East V. Sect Oeg/100 KOP 500.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 Build/Turn 3/100 1000.00 10.00 60.00 997.4 7 21.76 37.69 39.16 2.00 Base Permafrost 1863.09 34.88 37.50 1790.00 259.09 256.56 358.40 3.00 EOC 2644.57 58.15 33.41 2324.21 719.88 579.85 921.22 3.00 Ugnu C 4332.54 58.15 33.41 3215.00 1916.75 1369.31 2354.89 0.00 Ugnu B 4859.32 58.15 33.4 1 3493.00 2290.27 1615.69 2802.32 0.00 West Sak 5552.86 58.15 33.41 3859.00 2782.03 1940.06 3391.37 0.00 Base West Sa k 6358.20 58.15 33.41 4284.00 3353.06 2316.71 4075.38 0.00 9 5/8 Casing 6737.18 58.15 33.41 4484.00 3621.78 2493.96 4397.27 0.00 C80 7065.00 58.15 33.41 4657.00 3854.22 2647.28 4675.71 0.00 Begin Drop 8730.64 58.15 33.41 5536.01 5035.25 3426.30 6090.41 0.00 9062.41 51.51 33.41 5727.00 5261 .52 3575.54 6361 .45 2.00 9604.00 40.68 33.41 6102.00 5586.77 3790.08 6751 .05 2.00 ~~-=-,,- 9860.82 35.54 33.41 6304.00 5719.05 3877.33 6909.50 2.00 9949.57 33.77 33.41 6377.00 5761.18 3905.12 6959.96 2.00 1 0081 . 1 3 31 .14 33.41 6488.00 5820.10 3943.98 7030.55 2.00 10138.02 30.00 33.41 6536.99 5844.25 3959.91 7059.48 2.00 10181.91 30.00 33.41 6575.00 5862.58 3972.00 7081.42 0.00 10214.25 30.00 33.41 6603.00 5876.07 3980.90 7097.59 0.00 10274.29 30.00 33.41 6655.00 5901.13 3997.43 7127.61 0.00 10310.09 30.00 33.41 6686.00 591 6.07 4007.28 7145.51 0.00 10322.79 30.00 33.41 6697.00 5921.37 4010.78 7151.86 0.00 - Casing Pt. 10426.71 30.00 33.41 6787.QO 5964.75 4039.39 7203.81 0.00 "W·/ ConocoPhillips Well: 19 Structure : Pad 1 C Created by bmichael For: S Cloninger Date platted: 20-Mar-2003 Plat Reference is 1C-19 Version #1.A. Coordinates are in feet reference slot #19. Vertical Depths are re:e~¡¡ Est. RKB R.S.Ë~ -~ Field : Kuparuk River Unit Location: North Slope, ConocoPhillips Alaska, Inc. Cr.alod by Om;ch..' For: S Cloninger Dote plotted : '9-~or-200J Plot Reference i5 IC-19 Vef"Sion '1.A. Coordinates ore in feet re'erence slot ~, 9. True Vertical Depth:s orc reference: E:st. RK8 (D-141). IffiII! IUUCIiII HUGHES INTEQ 6300 - 5950 - 5600 - 5250 - 4900 - 4550 - 4200 - 3850 - ^ 3500 - I ~ +- 3150 - Q) Q) '+- '--" ...c 2800 - +- !.... 0 Z 2450 - 2100 - 1750 - 1400 - 1050 - 700 - 350 - Alaska, Inc. Well: 19 Location : North Slope, Alaska 34.12 AZIMUTH 7059' (TO TARGET) ...Plane of Proposal... ~ ì-\ I , TRUE <V ~ Tap West Sak ~ ':)' ~ Ugnu B - ~1> o -6\:) Build/Turn 3/100 KOP 350 350 350 700 ESTIMATED SURFACE LOCATION: 1615' FNL, 1360' FWL SEC. 12, T11N, R10E 1050 1400 1750 2100 2450 2800 3150 3500 East (feet) -> I{ ConocoPhillips J~ - Casing Pt. CB(B5 TO LOCATION: 932' FNL, 124' FWL c52 SEC. 6, T11 N. R11 E Ta1a~<Le;~r~~-EOC U~'K~?J~Pkk HRZ TARGET LOCATION: 1053' FNL, 44' FWL SEC. 6, T11N, R11E 3850 4200 4550 4900 ;( { ConocoPhillips Alaska, Inc. Pad lC 19 slot #19 Kuparuk River Unit North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref 1C-19 Version #l.A Our ref prop5411 License Date printed 19-Mar-2003 Date created 4-Mar-2003 Last revised 19-Mar-2003 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.173,w149 30 19.124 Slot location is n70 19 29.287,w149 29 39.384 Slot Grid coordinates are N 5968624.300, E 562368.100 Slot local coordinates are 1615.10 S 1361.51 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ConocoPhillips Alaska, Inc. PROPOSAL LISTING Page 1 Pad 1C,19 Your ref 1C-19 Version #l.A Kuparuk River Unit,North Slope, Alaska Last revised : 19-Mar-2003 Measured Inclin. Azimuth True Vert R E C TAN G U L A R Dogleg Vert Depth Degrees Degrees Depth COO R DIN ATE S Deg/100ft Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 500.00 0.00 0.00 500.00 0.00 N 0.00 E 0.00 0.00 KOP 600.00 2.00 60.00 599.98 0.87 N 1.51 E 2.00 1. 57 700.00 4.00 60.00 699.84 3.49 N 6.04 E 2.00 6.28 800.00 6.00 60.00 799.45 7.85 N 13 .59 E 2.00 14.12 900.00 8.00 60.00 898.70 13 . 94 N 24.14 E 2.00 25.08 1000.00 10.00 60.00 997.47 21. 76 N 37.69 E 2.00 39.16 Build/Turn 3/100 1100.00 12.68 53.14 1095.51 32.69 N 54.00 E 3.00 57.35 1200.00 15.48 48.68 1192.50 48.09 N 72.81 E 3.00 80.66 1300.00 18.35 45.57 1288.16 67.93 N 94.08 E 3.00 109.01 1400.00 21. 24 43.29 1382.24 92.14 N 117.75 E 3.00 142.32 1500.00 24.17 41. 53 1474.49 120.66 N 143.74 E 3.00 180.52 1600.00 27.10 40.13 1564.63 153.41 N 172 . 00 E 3.00 223.48 1700.00 30.05 38.98 1652.44 190.30 N 202.44 E 3.00 271 . 10 1800.00 33.01 38.03 1737.66 231. 23 N 234.99 E 3.00 323.24 1863.09 34.88 37.50 1790.00 259.09 N 256.56 E 3.00 358.40 Base Permafrost 1900.00 35.98 37.21 1820.07 276.10 N 269.54 E 3.00 379.76 2000.00 38.95 36.50 1899.44 324.76 N 306.01 E 3.00 440.51 2100.00 41.92 35.88 1975.55 377.10 N 344.29 E 3.00 505.31 2200.00 44.89 35.33 2048.19 432.97 N 384.28 E 3.00 574.00 2300.00 47.87 34.83 2117.17 492.22 N 425.88 E 3.00 646.38 2400.00 50.85 34.38 2182.28 554.68 N 468.96 E 3.00 722.25 2500.00 53.83 33.96 2243.37 620.18 N 513.42 E 3.00 801.41 2600.00 56.82 33.57 2300.25 688.54 N 559.12 E 3.00 883.64 2644.57 58.15 33.41 2324.21 719.88N 579.85 E 3.00 921. 22 EOC 3000.00 58.15 33.41 2511.78 971 . 90 N 746.09 E 0.00 1223.11 3500.00 58.15 33.41 2775.65 1326.43 N 979.94 E 0.00 1647.78 4000.00 58.15 33.41 3039.51 1680.96 N 1213.79 E 0.00 2072.45 4332.54 58.15 33.41 3215.00 1916.75 N 1369.31 E 0.00 2354.89 Ugnu C 4500.00 58.15 33.41 3303.37 2035.49 N 1447.63 E 0.00 2497.13 4859.32 58.15 33.41 3493.00 2290.27 N 1615.69 E 0.00 2802.32 Ugnu B 5000.00 58.15 33.41 3567.24 2390.02 N 1681.48 E 0.00 2921.80 5500.00 58.15 33.41 3831.10 2744.54 N 1915.33 E 0.00 3346.47 5552.86 58.15 33.41 3859.00 2782.03 N 1940.06 E 0.00 3391.37 Top West Sak 6000.00 58.15 33.41 4094.97 3099.07 N 2149.18 E 0.00 3771.15 6358.20 58.15 33.41 4284.00 3353.06 N 2316.71 E 0.00 4075.38 Base West Sak 6500.00 58.15 33.41 4358.83 3453.60 N 2383.03 E 0.00 4195.82 6737.18 58.15 33.41 4484.00 3621.78 N 2493.96 E 0.00 4397.27 9 5/8" Casing 7000.00 58.15 33.41 4622.70 3808.13 N 2616.88 E 0.00 4620.50 7065.00 58.15 33.41 4657.00 3854.22 N 2647.28 E 0.00 4675.71 C80 7500.00 58.15 33.41 4886.56 4162.66 N 2850.73 E 0.00 5045.17 8000.00 58.15 33.41 5150.42 4517.18 N 3084.58 E 0.00 5469.84 8500.00 58.15 33.41 5414.29 4871.71 N 3318.43 E 0.00 5894.52 8730.64 58.15 33.41 5536.01 5035.25 N 3426.30 E 0.00 6090.41 Begin Drop 8800.00 56.76 33.41 5573.32 5084.05 N 3458.49 E 2.00 6148.87 8900.00 54.76 33.41 5629.58 5153.06 N 3504.01 E 2.00 6231.53 9000.00 52.76 33.41 5688.69 5220.39 N 3548.41 E 2.00 6312.18 9062.41 51. 51 33.41 5727.00 5261. 52 N 3575.54 E 2.00 6361. 45 C40 9100.00 50.76 33.41 5750.58 5285.95 N 3591.66 E 2.00 6390.71 9200.00 48.76 33.41 5815.18 5349.67 N 3633.69 E 2.00 6467.04 All data is in feet unless otherwise stated. Coordinates from slot #19 and TVD from Est. RKB (D-141) (87.00 Ft above mean sea level). Bottom hole distance is 7203.81 on azimuth 34.11 degrees from wellhead. Total Dogleg for we11path is 87.48 degrees. Vertical section is from wellhead on azimuth 34.12 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ All data is in feet unless otherwise stated. Coordinates from slot #19 and TVD from Est. RKB (D-141) (87.00 Ft above mean sea level). Bottom hole distance is 7203.81 on azimuth 34.11 degrees from wellhead. Total Dogleg for wellpath is 87.48 degrees. Vertical section is from wellhead on azimuth 34.12 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ConocoPhil1ips Alaska, Inc. PROPOSAL LISTING Page 2 Pad 1C,19 Your ref 1C-19 Version #l.A Kuparuk River Unit,North Slope, Alaska Last revised : 19-Mar-2003 Measured Inclin. Azimuth True Vert R E C TAN G U L A R Dogleg Vert Depth Degrees Degrees Depth COO R DIN ATE S Deg/100ft Sect 9300.00 46.76 33.41 5882.40 5411.46 N 3674.45 E 2.00 6541.06 9400.00 44.76 33.41 5952.16 5471.27N 3713.89 E 2.00 6612.69 9500.00 42.76 33.41 6024.38 5529.00 N 3751.98 E 2.00 6681. 85 9600.00 40.76 33.41 6098.97 5584.59 N 3788.65 E 2.00 6748.44 9604.00 40.68 33.41 6102.00 5586.77 N 3790.08 E 2.00 6751.05 HRZ 9700.00 38.76 33.41 6175.84 5637.98 N 3823.86 E 2.00 6812.39 9800.00 36.76 33.41 6254.89 5689.10 N 3857.57 E 2.00 6873.62 9860.82 35.54 33.41 6304.00 5719.05 N 3877.33 E 2.00 6909.50 U. Kalubik 9900.00 34.76 33.41 6336.03 5737.88 N 3889.75 E 2.00 6932.06 9949.57 33.77 33.41 6377.00 5761.18 N 3905.12 E 2.00 6959.96 L. Kalubik 10000.00 32.76 33.41 6419.17 5784.27 N 3920.35 E 2.00 6987.62 10081.13 31.14 33.41 6488.00 5820.10 N 3943.98 E 2.00 7030.55 Top Kuparuk 10100.00 30.76 33.41 6504.19 5828.20 N 3949.33 E 2.00 7040.25 10138.02 30.00 33.41 6536.99 5844.25 N 3959.91 E 2.00 7059.48 Target-C4-EOC 10138.04 30.00 33.41 6537.00 5844.26 N 3959.92 E 2.00 7059.49 1C-B C4 TGT 16 SEP 02 10181.91 30.00 33.41 6575.00 5862.58 N 3972.00 E 0.00 7081. 42 C3 10214.25 30.00 33.41 6603.00 5876.07 N 3980.90 E 0.00 7097.59 C2 10274.29 30.00 33.41 6655.00 5901.13 N 3997.43 E 0.00 7127.61 C1 10310.09 30.00 33.41 6686.00 5916.07 N 4007.28 E 0.00 7145.51 B/B5 10322.79 30.00 33.41 6697.00 5921.37 N 4010.78 E 0.00 7151.86 B4 10426.71 30.00 33.41 6787.00 5964.75 N 4039.39 E 0.00 7203.81 TD - Casing Pt. \ ,:1 ,t 3959.92E 17-Sep-2002 5844.26N 1C-B C4 TGT 16 SEP 0 566280.000,5974500.000,0.0000 6537.00 ---------------------------------------------------------------------------------------------,-------------- Revised Rectangular Coordinates T.V.D. Geographic Location Target name ------------------------------------- ------------------------------------- Targets associated with this wellpath 9 5/8 CSG 7" CSG 2493.96E 4039.39E 3621.78N 5964.75N 4484.00 6787.00 O.OOE 6737.18 O.OOE 10426.71 O.OON O.OON 0.00 0.00 0.00 0.00 500.00 500.00 0.00 N 0.00 E KOP 1000.00 997.47 21. 76 N 37.69 E Build/Turn 3/100 1863.09 1790.00 259.09 N 256.56 E Base Permafrost 2644.57 2324.21 719.88 N 579.85 E EOC 4332.54 3215.00 1916.75 N 1369.31 E Ugnu C 4859.32 3493.00 2290.27 N 1615.69 E Ugnu B 5552.86 3859.00 2782.03 N 1940.06 E Top West Sak 6358.20 4284.00 3353.06 N 2316.71 E Base West Sak 6737.18 4484.00 3621.78 N 2493.96 E 9 5/8" Casing 7065.00 4657.00 3854.22 N 2647.28 E C80 8730.64 5536.01 5035.25 N 3426.30 E Begin Drop 9062.41 5727.00 5261. 52 N 3575.54 E C40 9604.00 6102.00 5586.77 N 3790.08 E HRZ 9860.82 6304.00 5719.05 N 3877.33 E U. Kalubik 9949.57 6377.00 5761.18 N 3905.12 E L. Kalubik 10081.13 6488.00 5820.10 N 3943.98 E Top Kuparuk 10138.02 6536.99 5844.25 N 3959.91 E Target-C4-EOC 10138.04 6537.00 5844.26 N 3959.92 E 1C-B C4 TGT 16 SEP 02 10181.91 6575.00 5862.58 N 3972.00 E C3 10214.25 6603.00 5876.07 N 3980.90 E C2 10274.29 6655.00 5901.13 N 3997.43 E C1 10310.09 6686.00 5916.07 N 4007.28 E B/B5 10322.79 6697.00 5921. 37 N 4010.78 E B4 10426.71 6787.00 5964.75 N 4039.39 E TD - Casing Pt. Casing positions in string 'A' ------------------------------ ------------------------------ Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing ----------------------------------------------------------------------------------------------------------- ----------------------------------------------------------------------------------------------------------- Comment Rectangular Coords. TVD MD -------------------- -------------------- Comments in wellpath PROPOSAL LISTING Page 3 Your ref 1C-19 Version #l.A Last revised : 19-Mar-2003 ConocoPhillips Alaska, Inc. Pad 1C,19 Kuparuk River Unit,North Slope, Alaska :( ConocoPhillips Alaska, Inc. Pad lC 19 slot #19 Kuparuk River Uni t North Slope, Alaska PRO P 0 S ALL I S TIN G by Baker Hughes INTEQ Your ref lC-19 Version #l.A Our ref prop5411 License Date printed 19-Mar-2003 Date created 4-Mar-2003 Last revised 19-Mar-2003 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on n70 19 45.173,w149 30 19.124 Slot location is n70 19 29.287,w149 29 39.384 Slot Grid coordinates are N 5968624.300, E 562368.100 Slot local coordinates are 1615.10 S 1361.51 E Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #19 and TVD from Est. RKB (D-141) (87.00 Ft above mean sea level). Bottom hole distance is 7203.81 on azimuth 34.11 degrees from wellhead. Total Dogleg for wellpath is 87.48 degrees. Vertical section is from wellhead on azimuth 34.12 degrees. Grid is alaska - Zone 4. ConocoPhillips Alaska, Inc. PROPOSAL LISTING Page 1 Pad lC,19 Your ref lC-19 Version #l.A Kuparuk River Unit,North Slope, Alaska Last revised : 19-Mar-2003 Measured Inclin Azimuth True Vert R E C TAN G U L A R G RID COO R D S G E 0 G RAP H I C Depth Degrees Degrees Depth COO R DIN ATE S Easting Northing COO R DIN ATE S 0.00 0.00 0.00 0.00 o .OON O.OOE 562368.10 5968624.30 n70 19 29.29 w149 29 39.38 500.00 0.00 0.00 500.00 o .OON O.OOE 562368.10 5968624.30 n70 19 29.29 w149 29 39.38 600.00 2.00 60.00 599.98 0.87N 1. 51E 562369.60 5968625.18 n70 19 29.30 w149 29 39.34 700.00 4.00 60.00 699.84 3.49N 6.04E 562374.11 5968627.84 n70 19 29.32 w149 29 39.21 800.00 6.00 60.00 799.45 7.85N 13 .59E 562381. 63 5968632.26 n70 19 29.36 w149 29 38.99 900.00 8.00 60.00 898.70 13 .94N 24.14E 562392.13 5968638.43 n70 19 29.42 w149 29 38.68 1000.00 10.00 60.00 997.47 21.76N 37.69E 562405.61 5968646.36 n70 19 29.50 w149 29 38.28 1100.00 12.68 53.14 1095.51 32.69N 54.00E 562421.83 5968657.43 n70 19 29.61 w149 29 37.81 1200.00 15.48 48.68 1192.50 48.09N 72.81E 562440.51 5968672.98 n70 19 29.76 w149 29 37.26 1300.00 18.35 45.57 1288.16 67.93N 94.08E 562461.62 5968692.98 n70 19 29.96 w149 29 36.64 1400.00 21.24 43.29 1382.24 92 .14N 117.75E 562485.08 5968717.38 n70 19 30.19 w149 29 35.95 1500.00 24.17 41.53 1474.49 120.66N 143.74E 562510.85 5968746.11 n70 19 30.47 w149 29 35.19 1600.00 27.10 40.13 1564.63 153.41N 172 .OOE 562538.83 5968779.09 n70 19 30.80 w149 29 34.36 1700.00 30.05 38.98 1652.44 190.30N 202.44E 562568.97 5968816.22 n70 19 31.16 w149 29 33.47 1800.00 33.01 38.03 1737.66 231.23N 234.99E 562601.18 5968857.41 n70 19 31.56 w149 29 32.52 1863.09 34.88 37.50 1790.00 259.09N 256.56E 562622.52 5968885.44 n70 19 31.84 w149 29 31.89 1900.00 35.98 37.21 1820.07 276.10N 269.54E 562635.36 5968902.55 n70 19 32.00 w149 29 31.51 2000.00 38.95 36.50 1899.44 324.76N 306.01E 562671.43 5968951.51 n70 19 32.48 w149 29 30.45 2100.00 41. 92 35.88 1975.55 377.10N 344.29E 562709.28 5969004.15 n70 19 33.00 w149 29 29.33 2200.00 44.89 35.33 2048.19 432.97N 384.28E 562748.81 5969060.34 n70 19 33.54 w149 29 28.16 2300.00 47.87 34.83 2117.17 492.22N 425.88E 562789.92 5969119.92 n70 19 34.13 w149 29 26.95 2400.00 50.85 34.38 2182.28 554.68N 468.96E 562832.49 5969182.72 n70 19 34.74 w149 29 25.69 2500.00 53.83 33.96 2243.37 620.18N 513 .42E 562876.41 5969248.57 n70 19 35.39 w149 29 24.39 2600.00 56.82 33.57 2300.25 688.54N 559.12E 562921.55 5969317.30 n70 19 36.06 w149 29 23.06 2644.57 58.15 33.41 2324.21 719.88N 579.85E 562942.03 5969348.80 n70 19 36.37 w149 29 22.45 3000.00 58.15 33.41 2511.78 971.90N 746.09E 563106.19 5969602.14 n70 19 38.84 w149 29 17.60 3500.00 58.15 33.41 2775.65 1326.43N 979.94E 563337.13 5969958.53 n70 19 42.33 w149 29 10.77 4000.00 58.15 33.41 3039.51 1680.96N 1213 .79E 563568.06 5970314.91 n70 19 45.82 w149 29 03.94 4332.54 58.15 33.41 3215.00 1916.75N 1369.31E 563721.65 5970551.93 n70 19 48.13 w149 28 59.40 4500.00 58.15 33.41 3303.37 2035.49N 1447.63E 563799.00 5970671.29 n70 19 49.30 w149 28 57.11 4859.32 58.15 33.41 3493.00 2290.27N 1615.69E 563964.96 5970927.41 n70 19 51. 81 w149 28 52.20 5000.00 58.15 33.41 3567.24 2390.02N 1681.48E 564029.94 5971027.68 n70 19 52.79 w149 28 50.28 5500.00 58.15 33.41 3831.10 2744.54N 1915.33E 564260.88 5971384.06 n70 19 56.27 w149 28 43.44 5552.86 58.15 33.41 3859.00 2782.03N 1940.06E 564285.29 5971421.74 n70 19 56.64 w149 28 42.72 6000.00 58.15 33.41 4094.97 3099.07N 2149.18E 564491.81 5971740.44 n70 19 59.76 w149 28 36.61 6358.20 58.15 33.41 4284.00 3353.06N 2316.71E 564657.26 5971995.76 n70 20 02.26 w149 28 31.72 6500.00 58.15 33.41 4358.83 3453.60N 2383.03E 564722.75 5972096.83 n70 20 03.25 w149 28 29.78 6737.18 58.15 33.41 4484.00 3621.78N 2493.96E 564832.30 5972265.88 n70 20 04.90 w149 28 26.54 7000.00 58.15 33.41 4622.70 3808.13N 2616.88E 564953.69 5972453.21 n70 20 06.73 w149 28 22.94 7065.00 58.15 33.41 4657.00 3854.22N 2647.28E 564983.71 5972499.54 n70 20 07.18 w149 28 22.05 7500.00 58.15 33.41 4886.56 4162.66N 2850.73E 565184.62 5972809.59 n70 20 10.22 w149 28 16.11 8000.00 58.15 33.41 5150.42 4517.18N 3084.58E 565415.56 5973165.98 n70 20 13.70 w149 28 09.27 8500.00 58.15 33.41 5414.29 4871.71N 3318.43E 565646.50 5973522.36 n70 20 17.19 w149 28 02.44 8730.64 58.15 33.41 5536.01 5035.25N 3426.30E 565753.02 5973686.76 n70 20 18.79 w149 27 59.28 8800.00 56.76 33.41 5573.32 5084.05N 3458.49E 565784.82 5973735.81 n70 20 19.27 w149 27 58.34 8900.00 54.76 33.41 5629.58 5153.06N 3504.01E 565829.76 5973805.18 n70 20 19.95 w149 27 57.01 9000.00 52.76 33.41 5688.69 5220.39N 3548.41E 565873.62 5973872.86 n70 20 20.61 w149 27 55.71 9062.41 51. 51 33.41 5727.00 5261. 52N 3575.54E 565900.41 5973914.21 n70 20 21. 02 w149 27 54.92 9100.00 50.76 33.41 5750.58 5285.95N 3591.66E 565916.33 5973938.76 n70 20 21.26 w149 27 54.45 9200.00 48.76 33.41 5815.18 5349.67N 3633.69E 565957.83 5974002.82 n70 20 21. 89 w149 27 53.22 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #19 and TVD from Est. RKB (D-141) (87.00 Ft above mean sea level). Bottom hole distance is 7203.81 on azimuth 34.11 degrees from wellhead. Total Dogleg for wellpath is 87.48 degrees. Vertical section is from wellhead on azimuth 34.12 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ConocoPhillips Alaska, Inc. PROPOSAL LISTING Page 2 Pad1C,19 Your ref 1C-19 Version #1. A Kuparuk River Unit, North Slope, Alaska Last revised : 19-Mar-2003 Measured Inclin Azimuth True Vert R E C TAN G U L A R G RID COO R D S G E 0 G RAP H I C Depth Degrees Degrees Depth COO R DIN ATE S Easting Northing COO R DIN ATE S 9300.00 46.76 33.41 5882.40 5411 . 46N 3674.45E 565998.09 5974064.94 n70 20 22.49 w149 27 52.03 9400.00 44.76 33.41 5952.16 5471.27N 3713.89E 566037.04 5974125.05 n70 20 23.08 w149 27 50.87 9500.00 42.76 33.41 6024.38 5529.00N 3751.98E 566074.65 5974183.09 n70 20 23.65 w149 27 49.76 9600.00 40.76 33.41 6098.97 5584.59N 3788.65E 566110.86 5974238.97 n70 20 24.20 w149 27 48.69 9604.00 40.68 33.41 6102.00 5586.77N 3790.08E 566112.28 5974241.16 n70 20 24.22 w149 27 48.65 9700.00 38.76 33.41 6175.84 5637.98N 3823.86E 566145.63 5974292.64 n70 20 24.72 w149 27 47.66 9800.00 36.76 33.41 6254.89 5689.10N 3857.57E 566178.93 5974344.02 n70 20 25.22 w149 27 46.67 9860.82 35.54 33.41 6304.00 5719.05N 3877.33E 566198.44 5974374.13 n70 20 25.52 w149 27 46.09 9900.00 34.76 33.41 6336.03 5737.88N 3889.75E 566210.70 5974393.06 n70 20 25.70 w149 27 45.73 9949.57 33.77 33.41 6377.00 5761.18N 3905.12E 566225.88 5974416.48 n70 20 25.93 w149 27 45.28 10000.00 32.76 33.41 6419.17 5784.27N 3920.35E 566240.92 5974439.69 n70 20 26.16 w149 27 44.84 10081.13 31.14 33.41 6488.00 5820.10N 3943.98E 566264.26 5974475.71 n70 20 26.51 w149 27 44.15 10100.00 30.76 33.41 6504.19 5828.20N 3949.33E 566269.54 5974483.86 n70 20 26.59 w149 27 43.99 10138.02 30.00 33.41 6536.99 5844.25N 3959.91E 566280.00 5974499.99 n70 20 26.75 w149 27 43.68 10138.04 30.00 33.41 6537.00 5844.26N 3959.92E 566280.00 5974500.00 n70 20 26.75 w149 27 43.68 10181.91 30.00 33.41 6575.00 5862.58N 3972.00E 566291. 93 5974518.41 n70 20 26.93 w149 27 43.33 10214.25 30.00 33.41 6603.00 5876.07N 3980.90E 566300.72 5974531.98 n70 20 27.06 w149 27 43.07 10274.29 30.00 33.41 6655.00 5901.13N 3997.43E 566317.04 5974557.17 n70 20 27.31 w149 27 42.58 10310.09 30.00 33.41 6686.00 5916.07N 4007.28E 566326.78 5974572 .19 n70 20 27.45 w149 27 42.29 10322.79 30.00 33.41 6697.00 5921 . 37N 4010.78E 566330.23 5974577.52 n70 20 27.51 w149 27 42.19 10426.71 30.00 33.41 6787.00 5964.75N 4039.39E 566358.48 5974621.12 n70 20 27.93 w149 27 41.36 3959.92E 17-Sep-2002 5844.26N 1C-B C4 TGT 16 SEP 0 566280.000,5974500.000,0.0000 6537.00 ----------------------------------------------------------------------------------------------------------- Revised Rectangular Coordinates T.V.D. Geographic Location Target name - - ------- - - ------- --- --- ----- --- ----- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - --- Targets associated with this wellpath 2493.96E 9 5/8 CSG 4039.39E 7" CSG 3621.78N 5964.75N O.OOE 6737.18 4484.00 O.OOE 10426.71 6787.00 o .OON O.OON 0.00 0.00 0.00 0.00 ----------------------------------------------------------------------------------------------------------- 500.00 500.00 O.OON O.OOE KOP 1000.00 997.47 21.76N 37.69E Build/Turn 3/100 1863.09 1790.00 259.09N 256.56E Base Permafrost 2644.57 2324.21 719.88N 579.85E EOC 4332.54 3215.00 1916.75N 1369.31E Ugnu C 4859.32 3493.00 2290.27N 1615.69E Ugnu B 5552.86 3859.00 2782.03N 1940.06E Top West Sak 6358.20 4284.00 3353.06N 2316.71E Base West Sak 6737.18 4484.00 3621.78N 2493.96E 9 5/8" Casing 7065.00 4657.00 3854.22N 2647.28E C80 8730.64 5536.01 5035.25N 3426.30E Begin Drop 9062.41 5727.00 5261.52N 3575.54E C40 9604.00 6102.00 5586.77N 3790.08E HRZ 9860.82 6304.00 5719.05N 3877.33E U. Kalubik 9949.57 6377.00 5761.18N 3905.12E L. Kalubik 10081.13 6488.00 5820.10N 3943.98E TOp Kuparuk 10138.02 6536.99 5844.25N 3959.91E Target-C4-EOC 10138.04 6537.00 5844.26N 3959.92E 1C-B C4 TGT 16 SEP 02 10181.91 6575.00 5862.58N 3972.00E C3 10214.25 6603.00 5876.07N 3980.90E C2 10274.29 6655.00 5901.13N 3997.43E C1 10310.09 6686.00 5916.07N 4007.28E B/B5 10322.79 6697.00 5921.37N 4010.78E B4 10426.71 6787.00 5964.75N 4039.39E TD - Casing Pt. Casing positions in string 'A' --- - --------- --- - - - ------ ----- ---- - - ---------- - -- ------ -- --- TOp MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing -- --- - - - -- - -- - -- - - -- - ---- ----- -- - -- ---- - - - - --- - - - - - - - ---- - -- - - - - - - - ------ -- - -- - - -- --- - - -- - - - - - - - - - - - --- Comment Rectangular Coords. TVD MD - ------ -- - - - ----- --- -- -- --- - - -- -- ------- Comments in wellpath PROPOSAL LISTING Page 3 Your ref 1C-19 Version #l.A Last revised : 19-Mar-2003 ConocoPhillips Alaska, Inc. Pad 1C,19 Kuparuk River Unit,North Slope, Alaska Presented by Baker Hughes INTEQ ~.' ConocoPhillips Alaska, Ine. Structure: Pad 1 C Well: 19 ConocoPhillips ................",......................,-...,..,.......,,,... C,.olod b~ brn;.ho.' For: S Cloninger' Date: plotted: 19-Uor-200J Plot Reference is 1C-19 Ver3ion 'LA. Coordinates ore in feel reference sIal "9. Field : Kuparuk River Unit Location: North Slope. Alaska True Vðrtic:ol Depths ore reference Est. RK8 (D-141). ¡¡'¡¡~iì IIAK8r tlUGlES INTEl) East (feet) -> 120 40 40 120 200 240 320 400 440 480 280 360 80 160 80 /& / / / / / / / / / / / / / / / / / / / / / / / / 12100 / / / / / / / / / / / / / / / / / / / 11900 / / / I / I / I ........ ......... I ......,. ~. ~...(,~.., ....,~;'Í. .'~ ....., ,., "/'*,-,?300 / " 11 700 """"." I I I I / I I I I ;I í 500 ,..... ....... .,............ II .....··1<300..........···· " ~~... / . ·:::--.....··..~'11·~~· _:::;.;¡;;,;E,...... ;II/{100 / / / / / ;11-1500 / / / / / / <& !lv. . ~~~ ~"........~.~.. '~~~. "··,......,~100 ....-~- . ...... ", ~"'" '. ~"'" , ....~ -..... ...<I+"1'3'ÓÓ ......,.. '" '" 520 @ - 640 - 600 - 560 - 520 - 480 - 440 - 400 ...-'59- 360 ...- - 320 ^ I Z o :¡ ::r - 280 "."1'fÓO r'~"'~"~~~'- 1700.. ..fST 240 < +..... .. ):jf;r ....... - 200 ~ -h CD CD -+- '--" '. ". ""01 - 80 2700 .......(9- ....::::::~~.:::~::~........WB- 40 1500 .,.." '" ............ .~~~.~".~~. . .~~ . '" ...,...'." , ...... '....... .......~::::::~.?~.~1:.3ÔQ:·::··· . "....... ..,......966 ..,..",.~ ........ ...................~ . '. '... ' ,..... , " '.. '. " @'. 900.. .<¡¡:::::::::~:~7Ô·0 ..JIK,::¡6Ô- 300 / .¡ f 900 "",-5'ÓÓ/ .", -:'300 ..<~;:.: .0" :;:.~:...':;':; .~~...., _"I:'~"" ~500 1300..... "'............. ....23'6õ'..-· . 1500 .....1..!..o.g.. .. 1,nn ........ 0/ 900;~0 . .",.. , 5(11)" - ~:~:I 1 11:1\). IjO,:' ... ...90Ö::.. ..... '~'.".' ~ .. '~~~~.:1.,:,'~~'9~;1.;':,)'~, YCO" .~ .. <§1'." (5)"'1'9'00 ._,.-.,~ .~ 1700 .....'" 1700 ."'............ 700 . 30Q,.. 500 '" \ /300 ~ '" 300 , 1 77~00 >1< -30(}" W ....-..."."", ".......... ..... 1 :.I:ICI I ~ '>:1 160 120 o ..ê)- - 40 .........[lD- - 80 ConocoPhillips Alaska, Inc.· ConocoPhillips ë'~~t~db;b;;;;~;;~~IF~~: S cl~~iitg~r· Dote plotted: 19-t.4or-2003 Structure : Pad 1 C Well : 19 Field: Kuparuk River Unit Location: North Slope, Alaska Plot Reference ¡" 1C-1g Vtl:~ion ItA Coordinates ore in leot refer once 'Slot '19. True Vertical Depth:!! ore reference Est. RKB (D-141). æ:it\i BlUCIiII tIUÇfE5 lNTJ:;Q / J]S00,¡(4900 ¡ 6400 // ¡ 61 00 / 15800//4600 : I I I ¡ 5500/ / I //4300 i 5200 /~ / : I / /1 i 4~oroOO / 1/ I , /4'00 / f 3700 ! I /4/00 / / I i 3400 ¡ 4.ÓOO / / , I / / i it¿@~oo 0/ L::J/ ¡ S I 5200" I I I I I 4900>11 I I I I I 460011 I I I I I 4300 I I I I I 4000 ¡ I / // I I /,,:3700 :0 6400 3700,/ ./' ~ II .-: / .~ 61 00 529C2.K~ - 2450 *,~400 r ~ /1 .// ~øtJO 3400 0/ + 5800 ".,...... - I »<3;/00 ",,:.46'oå - 2100 I / ~ 5500.,,,,,·3'400 ~ / /1/ ...",./4'300 ...."'.~O I ¡ (2800 ~ Õ·6 rbo 2207/1,;':;00 ,*~~;r:~~~:~:~:~~02.ðÓ-'520Õ'~'ðð" c / / I ~500 "''''''2;'~~~ô'ó' .. ..~..37·ÓO 190~,</ II' ......."'..2~§Õ::>·.::~.."'..31.dÕ··"'·04·ÖO ~.. II .19'00 ",.·n:ró·o "".2"860 W 12200 ... .... .,.,···.;..25ÚO 5200 ,'~',;?:~ii~:'ª~~t~~::~~:=::,~;=~oõ:::c: -f¿~~o,/ o 350 East (feet) -> 700 2450 4550 4900 5250 5600 3150 3500 3850 4200 1400 1750 2100 2800 1050 []] /",'7000 . ....·6700 )11,6400 {B100 )I((~OO *--5500 67~ 6400V I 6100 I ,,/ I I 5800 l I I I I 5500 , / ~(S800 / / ...5200 / ,..-5500 ;1<-5200 / / /)1,/4900 / ,./4600 / / I / ¡¡o/4300 / .I. / / I )1</4000 rï51 ~'o100 3400 ,..j~~3. .;?.~g ~·1*'¿1~·8::::.::·: :::::::::::~:¡:g~;:;::;":'. 5950 6650 - 6300 - 5950 - 5600 ;:§J - 5250 - 4900 - 4550 - 4200 - 3850 ^ I - 3500 Z 0 .., -+ ::J - 3150 ............ --¡., CD CD - 2800 -+ "--" - 1750 - 1400 - 1050 ..._",4.~ 700 - 350 - 0 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well 100 \.. \ 1200 1 30 '\ ''\~ 1 500 '\ ';'. \ 1'4 .\ \~ \. \ 1 50 \. \ \,,,\ \ \\.. \ ~ \'" ~ ~..~ 170 180 // ¡ /1200 270 190 & I ,// 220,/ / I , ,/ 216' I , /1200 / , / / i 1 500 Ii éf 230 160 120 250 260 270 80 280 70 ...{g) 290~· 60 300 50 310 ....·······40 320 ..........G1) 30 210 330 20 340 TRUE NORTH ~ ~ 350 0 10 I True Vertical Depth3 ore reference Ë:sL RKB H"".. BAKU! HUGÆS INn:Q Field Kuparuk River Unit Location: North Slope, Alaska Plot Reference i, 1C-19 Version NI.A.. Coordinates orc in feet reference slot #19. Conoc;Phillips Data plaited : 20-~ar-200J Well 19 Structure: Pad 1 C C,.ct'-d·"b; b;;'¡chc.1 For: S·-Cï~ninger ConocoPhillips Alaska, Inc. .-..dker Hughes Incorporaté Anticollision Report Company: ConocoPhillips Alaska, Inc. Field: Kuparuk River Unit Reference Site: Pad 1 C Reference Well: 19 Reference Wellpath: 1C-19 Vers#1a NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD + Stations Interval: 100.00 ft Depth Range: 0.00 to 10426.71 ft Maximum Radius: 10000.00 ft Survey Program for Definitive Wellpath Date: 11/7/2002 Validated: No Planned From To Survey ft ft 0.00 10426.71 Planned: 1C-19 Ver#1a V5 Summary <-----------. Offset Wellpath --:--------.-> Site Well Wellpath Date: 3/19/2003 CO-i)rdinate(NE) Reference: Vertical (TVD) Reference: Version: Toolcode MWD+SAG Reference MD ft 591.43 589.81 493.00 586.80 585.34 673.87 493.00 581 . 19 574.58 659.08 284.98 284.98 484.80 484.80 484.80 184.99 184.99 185.00 384.95 0.00 585.90 484.98 384.96 384.96 2181.57 384.96 284.98 185.00 185.00 576.95 484.95 192.98 942.35 963.84 3263.65 185.00 399.84 200.00 399.98 399.98 578.51 199.80 698.68 877.70 877.70 495.95 981.04 391.99 787.51 398.85 398.73 Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C Pad 1 C 01 02 03 04 05 06 07 08 09 10 102 102 104 104 104 109 109 111 11 113 115 117 119 121 12 123 125 127 131 13 133 135 14 15 16 17 172 174 178 178 18 190 22 23 23 24 25 26 27 b (PB) f (IB) 1 C-01 V2 1 C-02 VO 1 C-03 VO 1 C-04 VO 1 C-05 VO 1 C-06 VO 1 C-07 VO 1 C-08 VO 1 C-09 VO 1C-10 VO 1C-102 V5 1C-102L1 V3 1C-104 VO 1C-104L1 V1 1C-104PB1 VO 1C-109 VO 1C-109L1 VO 1 C-111 VO 1 C-11 VO 1C-113 VO Plan: 1C-113 1C-115 VO Plan: 1C-115 1 C-117 VO 1 C-119 VO 1C-121 VO 1C-12 VO 1C-123 VO 1C-125 VO 1C-127 VO 1C-131 VO 1C-13 VO 1C-133 VO 1C-135 VO 1C-14 VO 1 C-15 V1 Plan: 1 C-15L 1 1C-16 VO 1C-17 VO 1 C-172 Vers#1.c V1 Pia 1C-174 Vers#1.c V13 1C-178 BLat Vers# 2.b 1C-178 D Lat Vers# 2.b 1C-18 VO 1C-190 V8 1C-22 V3 1 C-23A V2 1C-23PB1 VO 1C-24 VO 1 C-25 VO 1C-26 V2 1 C-27 V1 1 C-PB Vers#O.a VO Plan 1 C-IB Vers#1.a VO Plan Offset MD ft 600.00 600.00 500.00 600.00 600.00 700.00 500.00 600.00 600.00 700.00 300.00 300.00 500.00 500.00 500.00 200.00 200.00 200.00 400.00 0.00 600.00 500.00 400.00 400.00 2600.00 400.00 300.00 200.00 200.00 600.00 500.00 200.00 1000.00 1000.00 3200.00 200.00 400.00 200.00 400.00 400.00 600.00 200.00 700.00 900.00 900.00 500.00 1000.00 400.00 800.00 400.00 400.00 Reference: Error Model: Scan Method: Error Surface: Time: 15:33:17 Page: Well: 19, True North Wellhead(87') 87.0 Db: Oracle Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse Tool Name MWD + Sag correction Ctr-Ctr No-Go Distance Area ft 102.64 103.85 198.00 310.88 427.41 547.92 665.64 787.48 851.49 702.06 787.07 787.07 759.05 759.05 759.05 675.33 675.33 646.06 821.57 618.76 592.97 565.42 539.04 513.09 338.29 489.01 461.67 438.52 392.29 523.33 370.41 352.51 133.31 34.99 347.75 827.83 322.37 280.56 200.98 200.98 379.09 40.54 32.20 41.10 41.10 89.40 68.95 88.92 81.69 121.09 80.28 ft 10.33 10.30 8.56 10.25 10.23 11.83 8.56 10.15 13.46 11.62 4.82 4.82 8.51 8.51 8.51 3.08 3.08 2.94 6.98 13.73 8.88 6.50 6.54 80.86 6.62 4.95 2.95 3.00 10.44 8.66 3.16 25.67 22.99 167.31 2.94 7.56 3.27 7.38 7.38 9.98 3.22 13.62 19.13 19.13 9.77 20.34 6.60 15.96 7.53 7.53 Allowable Deviation ft 92.31 93.55 189.44 300.64 417.19 536.08 657.08 777.32 838.03 690.44 782.25 782.25 750.56 750.56 750.56 672.26 672.26 643.12 814.60 579.25 556.54 532.55 506.55 276.69 482.38 456.72 435.57 389.30 512.89 361.76 349.35 107.66 11.98 264.79 824.89 314.83 277.29 193.60 193.60 369.11 37.32 18.59 22.24 22.24 79.63 48.78 82.32 65.75 113.57 72.76 Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk No Offset Stations Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Pass: Major Risk Company: Field: Reference Site: Reference Well: Reference Wellpath: í_..ker Hughes Incorporated Anticollision Report ConocoPhillips Alaska, Inc. Kuparuk River Unit Pad 1 C 19 1C-19 VerS#1a Date: 3/19/2003 Time: 15:33:17 Co-ordinate(NE) Reference: Vertical (TVD) Reference: Well: 19, True North Wellhead(87') 87.0 Summary < Offset Wellpath - > Site Well Wellpath Pad 1 C WS-1 WS1 V1 Pad 1 C WS-24 WS-24 VO Reference MD ft 3753.97 10345.24 Offset MD ft 3100.00 6500.00 Ctr-Ctr No-Go Distance Area ft ft Allowable Deviation ft 7598.00 142.43 7456.94 5257.05 437.81 4858.21 Page: 2 Db: Oracle Warning Pass: Major Risk Pass: Major Risk i...ker Hughes Incorporatel Error Ellipse Survey Report Company: Field: Site: Well: Wellpath: ConocoPhillips Alaska, Inc. Kuparuk River Unit Pad 1 C 19 1C-19 Vers#1a Date: 3/19/2003 Time: 15:34:53 Page: Co-ordinate(NE) Reference: Well: 19, True North Vertical (TVD) Reference: Wellhead(87') 87.0 Section (VS) Reference: Well (0.00N,O.00E,34.11Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Field: Kuparuk River Unit North Slope, Alaska USA Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 Site: Pad 1 C North Slope. Alaska Site Position: Northing: 5970228.13 ft Latitude: 70 19 45.173 N From: Map Easting: 560993.64 ft Longitude: 149 30 19.124 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 60.50 ft Grid Convergence: 0.24 deg Well: 19 Slot Name: Well Position: +N/-S -1615.10 ft Northing: 5968624.30 ft Latitude: 70 19 29.287 N +E/-W 1361.51 ft Easting : 562368.10 ft Longitude: 149 29 39.384 W Position Uncertainty: 0.00 ft Wellpath: 1C-19 Vers#1a Drilled From: Surface Tie-on Depth: 0.00 ft Current Datum: Wellhead(87') Height 87.00 ft Above System Datum: Mean Sea Level Magnetic Data: 11/7/2002 Declination: 25.63 deg Field Strength: 57496 nT Mag Dip Angle: 80.74 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 0.00 0.00 0.00 34.11 Survey Program for Definitive Wellpath Date: 11/7/2002 Validated: No Version: Planned From To Survey Toolcode Tool Name ft ft 0.00 10426.71 Planned: 1C-19 Ver#1a V5 MWD+SAG MWD + Sag correction ()osition uncertainty and bias at survey station All uncertainties at . 2.6 standard deviation Highside---":-> Lateral------> Vertical------> Magn. Semi-major Semi-minor MD IuCl Azim TVD Unc. Bias Unc. Bias Unc. Bias of Bias Unc. Unc. . Azimuth Tool ft deg deg ft ft ft ft ft ft ft ft ft ft deg 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE LINE 100.00 0.00 0.00 100.00 0.11 0.00 0.11 0.00 2.96 0.00 0.00 0.11 0.11 0.00 MWD+SAG 200.00 0.00 0.00 200.00 0.40 0.00 0.40 0.00 2.96 0.00 0.00 0.40 0.40 0.00 MWD+SAG 300.00 0.00 0.00 300.00 0.69 0.00 0.69 0.00 2.97 0.01 0.01 0.69 0.69 0.00 MWD+SAG 400.00 0.00 0.00 400.00 0.98 0.00 0.98 0.00 2.97 0.02 0.02 0.98 0.98 0.00 MWD+SAG 500.00 0.00 0.00 500.00 1.27 0.00 1.27 0.00 2.98 0.03 0.03 1.27 1.27 0.00 MWD+SAG 600.00 2.00 60.00 599.98 1.49 0.00 1.49 0.00 2.98 0.04 0.04 1.49 1.49 107.51 MWD+SAG 700.00 4.00 60.00 699.84 1.67 0.00 1.69 0.00 2.99 0.06 0.06 1.69 1.68 93.03 MWD+SAG 800.00 6.00 60.00 799.45 1.88 -0.01 1.96 0.00 2.99 0.08 0.08 1.97 1.90 75.19 MWD+SAG 900.00 8.00 60.00 898.70 2.11 -0.01 2.34 0.01 2.99 0.10 0.10 2.34 2.14 68.32 MWD+SAG 1000.00 10.00 60.00 997.47 2.35 -0.01 2.83 0.02 2.99 0.13 0.13 2.83 2.40 65.39 MWD+SAG 1100.00 12.68 53.14 1095.51 2.63 -0.02 3.45 0.03 2.98 0.15 0.16 3.47 2.69 62.81 MWD+SAG 1200.00 15.48 48.68 1192.50 2.94 -0.03 4.24 0.04 2.97 0.18 0.19 4.28 3.01 59.61 MWD+SAG 1300.00 18.35 45.57 1288.16 3.25 -0.05 5.21 0.06 2.96 0.21 0.22 5.27 3.33 56.44 MWD+SAG 1400.00 21.24 43.29 1382.24 3.55 -0.06 6.37 0.09 2.95 0.24 0.26 6.44 3.65 53.64 MWD+SAG 1500.00 24.17 41.53 1474.49 3.85 -0.08 7.72 0.11 2.93 0.28 0.30 7.80 3.97 51.26 MWD+SAG 1600.00 27.10 40.13 1564.63 4.15 -0.09 9.25 0.14 2.93 0.31 0.35 9.34 4.28 49.25 MWD+SAG 1700.00 30.05 38.98 1652.44 4.43 -0.11 10.97 0.17 2.93 0.35 0.40 11.07 4.60 47.53 MWD+SAG 1800.00 33.01 38.03 1737.66 4.71 -0.13 12.86 0.21 2.94 0.38 0.45 12.97 4.91 46.06 MWD+SAG 1900.00 35.98 37.21 1820.07 4.99 -0.16 14.93 0.25 2.97 0.42 0.50 15.04 5.22 44.79 MWD+SAG 2000.00 38.95 36.50 1899.44 5.25 -0.18 17.16 0.29 3.02 0.46 0.56 17.28 5.52 43.69 MWD+SAG 2100.00 41.92 35.88 1975.55 5.51 -0.21 19.54 0.34 3.10 0.49 0.62 19.67 5.81 42.72 MWD+SAG ldker Hughes Incorporat~: Error Ellipse Survey Report Company: ConocoPhillips Alaska, Inc. Date: 3/19/2003 Time: 15:34:53 Page: 2 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 19, True North Site: Pad 1 C Vertical (TVD) Reference: Wellhead(87') 87.0 Well: 19 Section (VS) Reference: Well (0.00N,O.00E,34.11Azi) Well path: 1C-19 VerS#1a Survey Calculation Method: Minimum Curvature Db: Oracle Position uncertainty and bias at survey station All uncertainties at 2.6 standard deviation Highside--> Lateral-> Vertical--> Magn. Semi-major Semi-minor MD Incl Azim TVD Unc. Bias Unc. Bias Unc. Bias of Bias Unc. Unc. Azimuth Tool ft deg deg ft ft ft ft ft ft ft ft ft ft deg 2200.00 44.89 35.33 2048.19 5.76 -0.23 22.08 0.39 3.20 0.53 0.68 22.21 6.10 41.85 MWD+SAG 2300.00 47.87 34.83 2117.17 5.99 -0.26 24.76 0.44 3.34 0.56 0.74 24.90 6.37 41.09 MWD+SAG 2400.00 50.85 34.38 2182.28 6.22 -0.30 27.57 0.49 3.50 0.59 0.81 27.71 6.64 40.40 MWD+SAG 2500.00 53.83 33.96 2243.37 6.44 -0.33 30.51 0.55 3.70 0.62 0.88 30.66 6.89 39.77 MWD+SAG 2600.00 56.82 33.57 2300.25 6.64 -0.36 33.57 0.61 3.94 0.65 0.95 33.72 7.13 39.21 MWD+SAG 2644.57 58.15 33.41 2324.21 6.73 -0.38 34.97 0.63 4.04 0.66 0.98 35.12 7.24 38.97 MWD+SAG 2700.00 58.15 33.41 2353.46 6.94 -0.38 36.73 0.66 4.20 0.67 1.01 36.88 7.35 38.70 MWD+SAG 2800.00 58.15 33.41 2406.24 7.33 -0.38 39.90 0.72 4.52 0.70 1.09 40.04 7.55 38.27 MWD+SAG 2900.00 58.15 33.41 2459.01 7.72 -0.38 43.08 0.78 4.85 0.73 1.16 43.21 7.75 37.90 MWD+SAG 3000.00 58.15 33.41 2511.78 8.12 -0.38 46.27 0.83 5.18 0.76 1.23 46.39 7.95 37.59 MWD+SAG 3100.00 58.15 33.41 2564.55 8.52 -0.38 49.45 0.89 5.52 0.79 1.31 49.56 8.15 37.32 MWD+SAG 3200.00 58.15 33.41 2617.33 8.93 -0.38 52.64 0.94 5.86 0.82 1.38 52.75 8.35 37.08 MWD+SAG 3300.00 58.15 33.41 2670.10 9.33 -0.38 55.83 1.00 6.20 0.85 1.46 55.93 8.56 36.87 MWD+SAG 3400.00 58.15 33.41 2722.87 9.74 -0.38 59.02 1.06 6.55 0.88 1.54 59.11 8.76 36.68 MWD+SAG 3500.00 58.15 33.41 2775.65 10.15 -0.38 62.21 1.11 6.90 0.91 1.62 62.30 8.97 36.51 MWD+SAG 3600.00 58.15 33.41 2828.42 10.56 -0.38 65.40 1.17 7.24 0.94 1.70 65.49 9.18 36.36 MWD+SAG 3700.00 58.15 33.41 2881.19 10.97 -0.38 68.60 1.23 7.60 0.98 1.78 68.68 9.39 36.22 MWD+SAG 3800.00 58.15 33.41 2933.96 11.39 -0.38 71.79 1.28 7.95 1.01 1.87 71.87 9.60 36.10 MWD+SAG 3900.00 58.15 33.41 2986.74 11.80 -0.38 74.99 1.34 8.30 1.05 1.95 75.06 9.81 35.98 MWD+SAG 4000.00 58.15 33.41 3039.51 12.22 -0.38 78.18 1.39 8.66 1.08 2.04 78.25 10.02 35.88 MWD+SAG 4100.00 58.15 33.41 3092.28 12.63 -0.38 81.38 1.45 9.01 1.12 2.13 81.45 10.23 35.78 MWD+SAG 4200.00 58.15 33.41 3145.06 13.05 -0.38 84.57 1.51 9.37 1.16 2.22 84.64 10.45 35.69 MWD+SAG 4300.00 58.15 33.41 3197.83 13.47 -0.38 87.77 1.56 9.73 1.19 2.31 87.83 10.66 35.61 MWD+SAG 4400.00 58.15 33.41 3250.60 13.89 -0.38 90.97 1.62 10.08 1.23 2.40 91.03 10.88 35.53 MWD+SAG 4500.00 58.15 33.41 3303.37 14.31 -0.38 94.16 1.68 10.44 1.27 2.49 94.22 11.09 35.46 MWD+SAG 4600.00 58.15 33.41 3356.15 14.73 -0.38 97.36 1.73 10.80 1.31 2.58 97.42 11.31 35.40 MWD+SAG 4700.00 58.15 33.41 3408.92 15.15 -0.38 100.56 1.79 11.16 1.35 2.68 100.62 11.53 35.33 MWD+SAG 4800.00 58.15 33.41 3461.69 15.57 -0.38 103.76 1.84 11.52 1.39 2.77 103.81 11.75 35.28 MWD+SAG 4900.00 58.15 33.41 3514.47 15.99 -0.38 106.96 1.90 11.88 1.44 2.87 107.01 11.97 35.22 MWD+SAG 5000.00 58.15 33.41 3567.24 16.41 -0.38 110.15 1.96 12.24 1.48 2.97 110.21 12.18 35.17 MWD+SAG 5100.00 58.15 33.41 3620.01 16.84 -0.38 113.35 2.01 12.60 1.52 3.06 113.40 12.40 35.12 MWD+SAG 5200.00 58.15 33.41 3672.78 17.26 -0.38 116.55 2.07 12.96 1.57 3.16 116.60 12.62 35.07 MWD+SAG 5300.00 58.15 33.41 3725.56 17.68 -0.38 119.75 2.13 13.33 1.61 3.27 119.80 12.84 35.03 MWD+SAG 5400.00 58.15 33.41 3778.33 18.10 -0.38 122.95 2.18 13.69 1.66 3.37 123.00 13.07 34.99 MWD+SAG 5500.00 58.15 33.41 3831.10 18.53 -0.38 126.15 2.24 14.05 1.71 3.47 126.19 13.29 34.95 MWD+SAG 5600.00 58.15 33.41 3883.88 18.95 -0.38 129.35 2.29 14.41 1.76 3.58 129.39 13.51 34.91 MWD+SAG 5700.00 58.15 33.41 3936.65 19.38 -0.38 132.55 2.35 14.77 1.80 3.68 132.59 13.73 34.88 MWD+SAG 5800.00 58.15 33.41 3989.42 19.80 -0.38 135.75 2.41 15.14 1.85 3.79 135.79 13.95 34.84 MWD+SAG 5900.00 58.15 33.41 4042.19 20.22 -0.38 138.95 2.46 15.50 1.90 3.90 138.99 14.18 34.81 MWD+SAG 6000.00 58.15 33.41 4094.97 20.65 -0.38 142.15 2.52 15.86 1.95 4.01 142.19 14.40 34.78 MWD+SAG 6100.00 58.15 33.41 4147.74 21.07 -0.38 145.35 2.58 16.23 2.01 4.12 145.39 14.62 34.75 MWD+SAG 6200.00 58.15 33.41 4200.51 21.50 -0.38 148.55 2.63 16.59 2.06 4.23 148.59 14.85 34.72 MWD+SAG 6300.00 58.15 33.41 4253.29 21.92 -0.38 151.75 2.69 16.95 2.11 4.34 151.78 15.07 34.69 MWD+SAG 6400.00 58.15 33.41 4306.06 22.35 -0.38 154.95 2.74 17.32 2.16 4.46 154.98 15.29 34.67 MWD+SAG 6500.00 58.15 33.41 4358.83 22.78 -0.38 158.15 2.80 17.68 2.22 4.57 158.18 15.52 34.64 MWD+SAG 6600.00 58.15 33.41 4411.60 23.20 -0.38 161.35 2.86 18.04 2.27 4.69 161.38 15.74 34.62 MWD+SAG 6700.00 58.15 33.41 4464.38 23.63 -0.38 164.55 2.91 18.41 2.33 4.81 164.58 15.97 34.60 MWD+SAG 6800.00 58.15 33.41 4517.15 24.05 -0.38 167.75 2.97 18.77 2.39 4.93 167.78 16.19 34.58 MWD+SAG 6900.00 58.15 33.41 4569.92 24.48 -0.38 170.95 3.03 19.13 2.44 5.05 170.98 16.42 34.55 MWD+SAG 7000.00 58.15 33.41 4622.70 24.91 -0.38 174.15 3.08 19.50 2.50 5.17 174.18 16.64 34.53 MWD+SAG 7100.00 58.15 33.41 4675.47 25.33 -0.38 177.35 3.14 19.86 2.56 5.29 177.38 16.87 34.51 MWD+SAG 7200.00 58.15 33.41 4728.24 25.76 -0.38 180.55 3.19 20.23 2.62 5.42 180.58 17.10 34.50 MWD+SAG 7300.00 58.15 33.41 4781.01 26.19 -0.38 183.75 3.25 20.59 2.68 5.54 183.78 17.32 34.48 MWD+SAG É..-ker Hughes Incorporated- Error Ellipse Survey Report Company: ConocoPhillips Alaska, Inc. Date: 3/19/2003 Time: 15:34:53 Page: 3 Field: Kuparuk River Unit Co-ordinate{NE) Reference: Well: 19, True North Site: Pad 1 C Vertical (TVD) Reference: Wellhead(87') 87.0 WeU: 19 Section (VS) Reference: Well (0.00N,0.00E,34.11Azi) WeUpath: 1C-19 Vers#1a Survey Calculation Method: Minimum Curvature Db: Oracle Position uncertainty and bias at survey station All uncertainties at 2.6 standard deviation Highside---> Latera 1-> Vertical---> Magn. Semi-major Semi-minor MD Incl Azim TVD Unc. Bias Unc. Bias Unc. Bias of Bias Unc. Unc. Azimuth Tool ft deg deg ft ft ft ft ft ft ft ft ft ft deg 7400.00 58.15 33.41 4833.79 26.61 -0.38 186.95 3.31 20.96 2.74 5.67 186.98 17.55 34.46 MWD+SAG 7500.00 58.15 33.41 4886.56 27.04 -0.38 190.15 3.36 21.32 2.80 5.80 190.18 17.77 34.44 MWD+SAG 7600.00 58.15 33.41 4939.33 27.47 -0.38 193.35 3.42 21.68 2.87 5.93 193.38 18.00 34.43 MWD+SAG 7700.00 58.15 33.41 4992.11 27.89 -0.38 196.55 3.48 22.05 2.93 6.06 196.58 18.23 34.41 MWD+SAG 7800.00 58.15 33.41 5044.88 28.32 -0.38 199.75 3.53 22.41 3.00 6.19 199.78 18.45 34.39 MWD+SAG 7900.00 58.15 33.41 5097.65 28.75 -0.38 202.95 3.59 22.78 3.06 6.32 202.98 18.68 34.38 MWD+SAG 8000.00 58.15 33.41 5150.42 29.17 -0.38 206.15 3.64 23.14 3.13 6.45 206.18 18.91 34.36 MWD+SAG 8100.00 58.15 33.41 5203.20 29.60 -0.38 209.35 3.70 23.51 3.19 6.59 209.38 19.14 34.35 MWD+SAG 8200.00 58.15 33.41 5255.97 30.03 -0.38 212.55 3.76 23.87 3.26 6.73 212.58 19.36 34.34 MWD+SAG 8300.00 58.15 33.41 5308.74 30.46 -0.38 215.76 3.81 24.24 3.33 6.86 215.78 19.59 34.32 MWD+SAG 8400.00 58.15 33.41 5361.52 30.88 -0.38 218.96 3.87 24.60 3.40 7.00 218.98 19.82 34.31 MWD+SAG 8500.00 58.15 33.41 5414.29 31.31 -0.38 .222.16 3.93 24.97 3.47 7.14 222.18 20.05 34.30 MWD+SAG 8600.00 58.15 33.41 5467.06 31.74 -0.38 225.36 3.98 25.33 3.54 7.29 225.38 20.27 34.29 MWD+SAG 8700.00 58.15 33.41 5519.83 32.16 -0.38 228.56 4.04 25.70 3.61 7.43 228.58 20.50 34.27 MWD+SAG 8730.64 58.15 33.41 5536.01 32.30 -0.38 229.54 4.06 25.81 3.63 7.47 229.57 20.57 34.27 MWD+SAG 8800.00 56.76 33.41 5573.32 32.54 -0.23 231.10 4.09 25.96 3.68 7.57 231 . 12 20.65 34.27 MWD+SAG 8900.00 54.76 33.41 5629.58 32.66 0.00 232.40 4.15 26.02 3.76 7.72 232.43 20.66 34.26 MWD+SAG 9000.00 52.76 33.41 5688.69 32.74 0.23 233.71 4.20 26.08 3.85 7.87 233.73 20.67 34.26 MWD+SAG 9100.00 50.76 33.41 5750.58 32.79 0.46 235.01 4.25 26.14 3.94 8.03 235.03 20.68 34.25 MWD+SAG 9200.00 48.76 33.41 5815.18 32.79 0.70 236.30 4.29 26.20 4.04 8.18 236.32 20.70 34.25 MWD+SAG 9300.00 46.76 33.41 5882.40 32.75 0.95 237.58 4.33 26.25 4.15 8.34 237.60 20.70 34.24 MWD+SAG 9400.00 44.76 33.41 5952.16 32.67 1.20 238.84 4.37 26.31 4.26 8.50 238.86 20.71 34.24 MWD+SAG 9500.00 42.76 33.41 6024.38 32.54 1.45 240.08 4.41 26.36 4.39 8.67 240.10 20.72 34.23 MWD+SAG 9600.00 40.76 33.41 6098.97 32.38 1.71 241 .29 4.45 26.40 4.52 8.83 241.31 20.73 34.23 MWD+SAG 9700.00 38.76 33.41 6175.84 32.17 1.97 242.47 4.48 26.44 4.66 9.00 242.49 20.73 34.23 MWD+SAG 9800.00 36.76 33.41 6254.89 31.92 2.24 243.62 4.51 26.48 4.81 9.17 243.64 20.74 34.22 MWD+SAG 9900.00 34.76 33.41 6336.03 31.62 2.50 244.72 4.53 26.51 4.96 9.34 244.75 20.74 34.22 MWD+SAG 10000.00 32.76 33.41 6419.17 31.28 2.78 245.79 4.56 26.54 5.12 9.52 245.81 20.74 34.21 MWD+SAG 10100.00 30.76 33.41 6504.19 30.90 3.05 246.81 4.58 26.56 5.29 9.69 246.83 20.73 34.21 MWD+SAG 10138.04 30.00 33.41 6537.00 30.75 3.16 247.18 4.59 26.57 5.36 9.76 247.21 20.72 34.21 MWD+SAG 10200.00 30.00 33.41 6590.66 30.85 3.16 248.07 4.60 26.63 5.47 9.87 248.09 20.81 34.21 MWD+SAG 10300.00 30.00 33.41 6677.26 31.18 3.16 249.93 4.62 26.80 5.65 10.05 249.95 21.10 34.20 MWD+SAG 10400.00 30.00 33.41 6763.87 31.50 3.16 251.79 4.64 26.97 5.83 10.24 251.81 21.39 34.20 MWD+SAG 10426.71 30.00 33.41 6787.00 31.59 3.16 252.29 4.64 27.01 5.88 10.29 252.31 21.46 34.19 MWD+SAG ( ( lC-19 Drillina Hazards Summary 12-1/4" Hole / 9-5/8" Casing Interval Event Broach of Conductor Gas Hydrates Gravel/Sand Sloughing to 500' Hole Swabbing/Tight Hole on Trips Possible thaw bulb Lost Circulation Risk Level I Mitiqation Strateqy Moderate Monitor cellar continuously during interval. Moderate Moderate Moderate Low Moderate If observed - control drill, reduce pump rates, and reduce drilling fluid temperatures. Additions of Drilltreat. Increase mud weight / viscosity, High viscosity sweeps. Monitor fill on connections. Circulate hole clean prior to trip. Proper hole fill (use of trip sheets), Pumping out of hole as needed. Watch return viscosity for signs of thinning. Increased mud weight/viscosity as needed. Prevent by keeping hole clean. If losses occur - reduce pump rates and mud rheology, use LCM. 8-1/2" Hole / 7" Casinq Interval Risk Level I M itiqation Strateqy Low Control with higher MW and proper drilling practices. Event Shale stability in HRZ and K-l High ECD and swabbing with higher MW's required Barite Sag Differential Sticking Abnormal Reservoir Pressure Lost Circulation Moderate Low Moderate Moderate Moderate Condition mud prior to trips. Monitor ECD's while drilling across pay interval. Pump and rotate out on trips as a last resort. Good drilling practices as documented in well plan. Periodic wiper trips. Do not leave pipe static for extended period of time. Follow mud weight schedule and do not fall behind. Stripping Drills, Shut-in Drills, and Increase mud weight as needed. Ensure adequate kick tolerance prior to drilling pay interval. Reduced pump rates, Mud rheology, LCM. Use GKA LC decision tree. 1C-19 Drilling Hazards Summary. doc prepared by Shane Cloninger 11/14/02 Page 1 of 1 KRU - 1C-19 Pro( Longstring Base Case Proposed Completion Schematic Single Completion 16"x30" insulated conductor @ +1- 138' MD ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ j ~ ...,. ~ 9-518" Port Collar ~ Stnd Grade BTC ~ Threads (+/- ~ 1000' MD) ~ ~ ~ ~ ~ ~ ..,j Surface csg. 9-5/8"40# L-80 BTC @ +1- 6,737' MD I 4,484' TVD (Csg point 200' TVD below the base of the West Sak) Kuparuk C Sand Perfs (to be done post rig) Production csg. 7" 26# L-80 BTCM @ +1-10,427' MD I 6,787' TVD ~ ~ ~ ~ ~ ~ ~ - ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ -. . ~ ~ ~ ~ ~ ~ ~ ~ ~ I -f'á' I ~ ~ w""""'" ~ ~tl~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ j t.N ...-:-~ j ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ø ~ ......-. . '--y~ ~ ~ ~ ~ ~ ~ ~ j r i-_-- þ¡:--- r- ~ ~ ~ ~ ~ ~ ~ ~ ~ 3í ~ qèmej1( ... ~ \ 111II':__ ConocoPhillips .car ~ ~ ~ ~ ~ ~ l... 3-1/2" FMC Gen V tubing hanger, 3-1/2" L-80 EUE8RD pin down. Special Drift 2.91" 3-1/2", L-80, 9.3# EUE8RD Spaceout Pups as Required. Special Drift 2.91" 3-1/2" 9.3# L-80 EUE8RD Tubing to Surface Special Drift 2.91" 3-1/2" Cameo DS Landing Nipple with 2.875" 10 No-Go profile set @ +1- 500' MD. 9-5/8" @ +1- 6,737' MD I 4,484' TVD GLM Placement: Valves #1-4: 3-%" x 1-%" KBUG Place gas-lift mandrels at the following depths: DlQ. 2550' 4075' 5150' 5850' Approximate MD 3237' 5989' 7929' 9145' VALVE #5: 3-1/2" x 1-1/2" 'MMG' GLM wI DCR Dump Kill Valve (3000 psi casing to tubing shear). 6' L-80 handling pups installed on top and bottom of mandrel. 1 Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 3-1/2" Camco "DS' nipple wI 2.813" No-Go profile 1 Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 6' Handling Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. Baker '80-40' PBR. Baker 7" x 3-1/2"'SAB-3' Permanent Packer set +1- 100' MD above top planned perf. Minimum 10 through the packer 3.00". 6' Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. 3-1/2" Cameo 'D' nipple wI 2.75" No-Go profile. 6' Pup Joint 3-1/2", L-80, 9.3# EUE 8rd Mod Tubing. Baker 3-1/2" WL Re-entry Guide wI shear out sub. Tubing tail 50' above top planned perforation. TD @ 10,427' MD 16,787' TVD SDC 03/18/03 ""UliQ·..t""," .l~._... ':Od660061.1.'·2 {~ · 6800001.2?25?~60dd " '" DCiL(Af.]S /if Valid Up ì 0 5000 DO/fars ~î~ 1033 /J'1T£ '~1Jf..~",,- ' ~. . ~S 62"41311 ~.-.¡ /Ý t) CI-t4.SE! CO". ~.""~,." "'~:~=A' - "" "'Me., eo_~. "'"., 0, "'" , . -. p/!}'J'O t)RiJf:P. - PSH· I{ ALLSUP-DRAKE ILLIPS PETROL 700 G Sr. A TO 1530 £UM COMPANY ANCHORAGE AK 99501 '\ TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER K¿tt Ie -/er þO 3 -oçtj WELL NAME PTD# CHECK WHAT APPLŒS ADD-ONS (OPTIONS) MULTI LATERAL (H API number last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function' of the original API number stated above. BOLE In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below tbe permafrost or from where samples are first caught and 10' sample intervals through target zones. WELJ... ~ER'MIT CHECKLIST Company ÇJ)NO_C_QPHllLlPS--.ALASKAJJ...LC_ Well Name: KUPARUJS:J~JY-W~JJ / e. -'-2-- Program J2~Y____ Well bore seg 0 prD #~ 2030540-" . i=i~ld & ¡;ooIKUPARUJ~.EJ~EB.J~.UEARU.KBJV - 'irIS/C)?") Initial Classrrype __QE~L1:_0JL_. GeoArea Unit -5jjLO On/Off Shore .Qo_. Annular Disposal 0 Administration 1 P~:ml1itfee. ~ttached. . _ . _ . . _ _ _ _ _ _ _ . _ . . . _ _ _ _ . . _. _ _ . _ . _ . Y~s . _ _ . _ . . . . . _ .. _ _ . .. . _ _ . _ _ _ . .. _ _ _ . _ _ . . . . _ . _ _ _ . . . _ . . . . . - . .. - - . - . - - . 2 .Le~s~ _number app.rQPJiçit~ _ . _ . _ _ _ . _ . _ . _ . .. . _ _ _ _ _ . .. . . _ . _ . _ .. _ _ _ . . _ . ... No. . _ _ . . Su.rface location in ADL 25649; Top productive intervaL and TD jn ADL Q28242. AdditiQn.ma.de tQ to:-40.:1._ _ _ _ _ . 3 _U_ni~l)~ w~ltn..alJle _a!:ld lJu_ll1b~r _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y~$ _ _ _ _ _ .. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - .. - - - - - - - - - - - - - - 4 WeJI Jo_cated tn.a.d_e{ined pool_ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ . _ _ _ . _ _ . _.. .. _ . _ _ _ . Y~s .. _ _ _ . _ . .. . _ _ _ _ _ _ .. .. . _ _ _ . . . _ . _. ..... _ _ _ . . .. _ . . - . - - - 5 WeJI Jo_cated proper di.stance_ from. driJling unitb_ound.ar:y _ . .. _ _ , _ _ , _ _ _ _ _ _ .. _ . . , . . _ . Y~s .. _ ,_. _ . . _ ' _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ . - - - - .. .. - - - . - - - . - - - - 6 WeJI Jo_cated proper dtst.a!:lc.e_ from otheJ wells_ _ .. _ _ _ _ _ _ .. _ _ , _ _ . _ .. _ .. . Y~s _ _ .. _ _ ,. _ _ _ _ , . . .. . _ _ _ _ . . _ .. . _ , _ _ _ _ . . _ . . _ _ _ _ _ _ . . . _ . - - - - - . .. - - - - - - - - - 7 _S.ufficientacreage.available tn..drilJilJg.unjt. . _ _ _ _ . _ . _ _ _ _ _ _ . _ _ _ _ _ _ . _ _ _ . . Y~s _ . , _ _ _ _ . _ _ . .. _ _ _ _ _ _ _ _ _ . _ _ _ _. _ . _ .. . . .. . _ _ _ _ _ , _ _ _. _ . . - . - _ .. - - .. - - - , . 8 .If_deviated, js.weJlboJe plaUnc!uded. _ _ , _ .. _ _ .. _ _ _ _ _ _ _ _ _ _ _ _ _ _ . .. _ _ _ _ . _ _ _ Y~$ . . . . _ _ _ _ _ _ _ _ .. _ _ ,. _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ . _ _ _ _ - . _ - - - - . - - - - - _. .. - .. . .. . .. 9 Qper.ator O/1ly_ aff~çted pa_rty. _ _ . _ _ . _ . . _ _ _ _ . _ _ _ . _ _ _ .. _ _ _ _ _ . _ .. . . _ _ _ _ Y ~s _ _ _ _ _ _ . _ . . . _ _ _ _ _ .. _ _ _ _ _ . . _ _ _ , _ _ _ _ . _ _ . _ , . _ .. . _ . . . . - _ - - - - - - . . . . - - - .. - . . - . - . - - - 10 Qper.ator ba.s_approprlate_b_o[1d in .fQrce_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ _ _ _ .. _ _ _ _ _ _ _ _ _ _ _ _ _ _ .. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - - - - - .. - - - - - - - - - - - - - - - - - - - - - 11 Per:milcao be i.$$u_ed wjtho_ut c.onservatiO/1 order _ _ _ _ . _ , _ _ _ _ _ _ _ _ _ _ _ _ _ _ ,. _ .. .. .. _ _ Y~s _ _ _ _ _ _ _ .. .. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . . . _ _ _ _ _ _ .. _ _ _ _ . . _ . _ _ _ _ _ _ _ .. .. . - .. - - - - - - . - - - -. - - - - - - 12 Per:milcao be i.$$u.ed wjtho_ut adJ11il1i~tr,ativ.e_approvaJ _ .. _ _ _ _ _ _ _ . . _ . _ _ _ _ _ _ _ _ _ _ . .. Y~s _ _ _ .. _ _ _ _ _ _ _ .. .. . _ .. _ _ _ _ _ _ _ _ _ _ . , _ _ _ _ _ _ .. _ . _ _ .. _ _ _ _ .. _ _ _ .. _ _ - - - - - .. .. .. - .. - - . - - - - - .. .. - .. - , ~rl")) 4/1/2003 13 Can permit be approved before 15-day wait Yes 14 WeJI Jo_cated within area an..d..strata authorized by..lojection Order::ft: (putIO# in_comm~otS).(for.. NA _ _ _ _ _ . _ .. _ _ _ _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ .. _ _ - , ,- .. - - .. - . - . - - - - - - - . - - . - . - - - - - 15 All wells_within ..1l4_l1)il~_are_a_of r:eview [delJtlfied (F9r:s_ervjc~_w~1J only-).. _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA.. _ _ _ _ _ _ _ _ _ _ .. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .. _ _ _ _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - .. - .. 16 Pre:-produçed_ injector:. duratjo.n .of pre~produG.tion less. than, 3. mon.ths. (for .seryiçe welt QnIY) _ _ NA. _ _ , .. . _ _ _ . . . . . _ _ _ _ _ _ _ _ _ . _ . _ _. .. . . - - _ - . - - . ' - - - - - - - - . - . . . . 17 ACMPFinding _ot CQnsish~ocy_has been js_suedJorJbis proj~çt _ _ _ _ _ _ _ _ _ _ _ _ _ . _ NA_ _ . . _ . _ _ _ _ . _ _ _ _ _ _ _ _ _ _ .. _ .. .. .. _ _ _ . _ . . _ , _ _ _ , . _ _ _ 18 .cooduçlor strjn.9_prQvlded _ _ . _ . , _ . _ . . _ _ _ _ _ _ _ . . _ _ _ . _ , _ .. _ _ .. _ _ _ _ _ . . .Y~s _ _ _ _ _ .. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .. . . . . . . _ _ - _ - - - - - .. - . - , - - - - - - - - - ' - - . - - - 19 _Surface_casjng_prQtects.aILknown.USQWs _ _ _ _ _ _ _ _ . _ _ . _ _ _ _ _ _ _.. _ _ _ _ . . _ _ _ _ NA _ _ _ _ _ _ _Altaquifersex~mpt~d,AP.cFRJ~7.1Q2..(bU3t _ _ . .. _ .. _ _ - _ - - . . - - - - - - - - - . . - , - -. - - - - . - - - 20 _CMTvol.a,dequ.ateJQ çirc!Jl.ate.on _cond!Jetor_& $u.rfq;g _ .. _ _ _ _ _ _ _ _ _ _ _ _ . _ . , _ . , _ _ _ Yes _ . _ . _ _ _ _ _ _ _ _. .. _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ , - _ - - - . - - - - - - - - - - . , - , - . - - . - - - - . - . . . - - 21 .cMTvol.a.dequ_ateJo tieHn JQngstriog to ,surf cs.g. _ . _ _ , _ _ _ _ _ . _ _ _ . _ . _ _ . . _ . No_ _ _ _ _ _ _ _ _ . .. _ _ _ _ _ . _ _ _. _.. _ _ _ . _ . .. _ , _ _ - . _ - - - . . - . - - - - - . - . .. - . . - - -. . . 22 .cMTwill cover_a!! Knownpro.ductive hQrizQn_s_ _ _ .. _ _ _ _ _ _ _ . _ . . . . . . _ _ _ _ . _ _ _ _ _ _ Y~$ _ _ _ _ . _ . . , , _ _ .. _ _ _ .. _ _ . _ . _ _ _ _ _ _ _ . _ _ _ .. _ _ . . .. _ _ _ _ . _ - . - - - , - - - -- .. - .. - - . . . , 23 _Casiog de_sign~ ad.equate_ for: C, T. B .&.p_ermafrost . _ _ _ _ _ _ _ _ _ _ .. . _ _ . _ . . . . .Y~s _ _ _ . _ , , _ . .. _ _ _ . _ _ _ _ . _ . _ _ _ _ - - - _ . . - . - - - , - - - - - - - , - - , - - - - - - .. - .. . - - - - 24 Adequat~ _té:!n.kage_or re.$erve pit _ _ , _ . _ _ . _ _ _ _ _ _ . , _ _ . _ _ , _ _ _ .. _ .. _ _ . . _ _ _ _ . Y~s . _ No ceserve_ pitplanoed, -Rig is equjpped with_ $.tee.1 pits., Muçl and_ cutting$. di~p.osa.l via annulus or Cla$.sJL _ , _ _ _ 25 H_a_re-dcill. lJas_a_ to:-4_03 for aba_nçlonment beeo apprQved _ _ _ _ _ _ _ _ _ _ _ _ _ _ , . . . . . . _ NA .. . _ .. _ _ _ _ _ .. _ . . _ . _ . _ _ _ _ _ _ _ .. . . _ . _ _ _ _ - - - 26 Açlequat~ _wellbore_ s_eparç¡tjo.n propO$.eçl_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .. _ _ _ _ _ _ ..Y ~$ _ _ _ _ _ _ _ Appro_act} an_a!y~i~ performed, _Gyro_ s_urveys_ p..o~$.iQle. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .. - _ - - - - - - - - . .. - - 27 J(diverter require_d, do.es it meet regulations_ _ .. _ _ _ Y~s _ _ _ _ _ _ _ _ _ _ _ . _ . - . . - . . , . . - - - - - - - - - - - - - Appr Date 28 DrilJingfluid_prQgramschemattc,&_equipJistadequate_ _' _ _' _ _' _ _ _ _ Yes. _ ,4Expected.maxJorm_ation.pres$ure,.tOJ.EMW,pJanned.MW.tO, _ _ _ _ _. _ _ _.. TEM 4/4/2003 29 _BOPEs..doth_eymeetreguJation _ _ _ _ _ . _ _ . _ _ _ _ _ _ . . _ _ Y~s _ . _ _ _ . _ . _ _ _ . . _ _ _ _ _ _ _ _ . _ _ . _ _ _ _ _ _ _ _ . "Æ-?W? 30 BOPE.pre.ss rating é:!ppropriate; test to-<put psig in _commentsL . , . _ Yes. . _ .. MASP e$.til11ated at27~6 psi._ 35.00 psi ,test appropriate,PPCo testsJo 5QOP.psi. - . u. 'ì/.:"\Ù~ 31 .choke_ma.nifQld cQmpJies_ w/API.RP-53. (May 84L _ _ _ _ . _ _ _ _ _ . . Y~s _ _ _ _ _ . 32 Work wiU occur: withoutoperation $lJutdown _ _ _ . _ _ . _ .. _ Y~s , _ _ _ , ' . - - - - - - - .. 33 Js_ pres.eoce oJ H2S gas. pJob_able _ _ _ . _ _ _ _ _ _ No , H2S may_ be_encQuntered.in. the Kup_aruk, however H2S is_not expected_at surface. _ 134 Mecha_ni.caLcond.itto!:l of, wells with.in AOR verified. (For_s.ervice well on.ly) _ _ NA . . . _ _ _ _ 135 Per:mit can be i$su_eo wlo_ hydrogen s.ulfide measur_es _ _ . ----- No . KRU 1 C-Pad well$ range i.n .me_asured_ H2S from 1. O. to ~ 1 ppm, & _ avg .30 ppm -;~the_ J;~~200;-KßU H2S Repo.rt, 136 .Datapresented on.pote.ntial overpressure zones, . . _ _ _ _ . Yes _ . Est. pressure attop of .K!Jparuk. product!veintervaJ is.1 O.~ ppg EMW, .Interval wi.lI.be dr:illed with 10--4 ppg.. Date 137 Seismi.c_analys.is_o.fshaJlowgas.zone.s... _.. _ _ _ _ _ _ _ _... _. _. _ _ .. _ NA.. _. _DrillingHazards.Summary_discuss.esrisk.leveto.fhydrates_andabnormalpressureaIQngwithm.itigationmeasures. 4/3/2003 :38 Seabeo çondition survey .(it off-shore) . . . NA _ _ . . _ . _ . _ _ _ _ _ _ _ . _ _ _ _ _ _ . _ _ _ _ . .. _ , _ . _ _ , _ _ . :39 . Co.ntaçt nam_e/phone Jor weekly progre$.s .reports [explQratory ..only]. _ NA. Geologic Commissioner: Date: 0r11/1!C;; Appr Date Engineering Geology Appr SFD \ Engineering Commissioner: Public ~p ~~~ Date ~ "" " ~ ) ) Well History File APPENDIX Information of detailed nature that is not particular1y germane to the Well Pennilling Process but is part of the history file. To improve the readability of the Well History file and to sim,plify fìnding infomlalion. 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. -: ;¡.;i!¡m~~:{it<Dn n 2003 'l'1 20 0)L 0 "."":'i;¡~CE'VED Rt:,. .,.>=1· . . PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE # REMARKS: 6744.0 10435.0 9.625 1ST STRING 2ND STRING 3RD STRING 12.250 PRODUCTION STRING 8.500 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) # WELL CASING RECORD 12 11N 10E # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 87.10 59.10 MWD RUN 3 3 F. WENDLER D. WESTER MWD RUN 2 2 G. SUTING D. GLADDEN MWD RUN 1 1 D. LABRECQUE F. HERBERT JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: LDWG File Version 1.000 Extract File: LISTAPE.HED ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! TAPE HEADER KUPARUK RIVER UNIT MWD /MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 1C-19 500292314900 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 24-JUN-03 *** *** LIS COMMENT RECORD 01 **** TAPE HEADER **** LDWG 03/07/21 AWS 01 **** REEL HEADER **** LDWG 03/07/24 ') ) c903--05~ BASELINE DEPTH # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- 1 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ STOP DEPTH 10435.0 START DEPTH 6744.0 clipped curves; all bit runs merged. .5000 LDWG File Version 1.000 Extract File: FILE001.HED *** *** LIS COMMENT RECORD 1024 LDWG .001 **** FILE HEADER **** 8 bytes 132 bytes Minimum record length: Maximum record length: 73 records... Tape Subfile: 1 GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR TO DELIVERY FROM THE WELL SITE. SURFACE LOCATION: LAT: N 70 DEG 19' 29.287" LONG: W149 DEG 29' 39.384" LOG MEASURED FROM D.F. AT 87.1 FT. ABOVE PERM. DATUM (M.S.L.) . COMMENTS: (1) Baker Hughes INTEQ runs 1 and 2 utilized NaviTrak Directional only services from 138-6755 feet MD (138 - 4479' TVD). (2) Baker Hughes INTEQ run 3 utilized the Advantage Porosity Logging Service (APLS) which includes the Optimized Rotational Density (ORD), Caliper Corrected Neutron (CCN), along with MPR Resistivity services from 6755 - 10435 feet MD (4479-6794' TVD). REMARKS: (1) The 12 1/4" hole section from 138 to 6755 feet MD (138 - 4479' TVD) was drilled with a directional only tool. As such, no logs are presented over this interval (2) Depth of 9 5/8" Casing Shoe - Logger: 6744 feet MD (4474' TVD) Depth of 9 5/8" Casing Shoe - Driller: 6744 feet MD (4474' TVD) (3) The interval from 10391 to 10435 feet MD (6756 - 6794' TVD) was not logged due to sensor-bit offset at TD. $ ) ) ) ) $ # MERGED DATA SOURCE PBU TOOL CODE MWD $ BIT RUN NO MERGE TOP 2 6744.0 MERGE BASE 10435.0 # REMARKS: MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT lc-19 5.xtf 150 - ConocoPhillips Alaska, Inc. lC-19 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR GR GRAM 0.0 RPD RPD RPD 0.0 RPM RPM RPM 0.0 RPS RPS RPS 0.0 RPX RPX RPX 0.0 RHOB RHOB BDCM 0.0 DRHO DRHO DRHM 0.0 PEF PEF DPEM 0.0 NPHI NPHI NPCKSM 0.0 CALN CALN CALM 0.0 ROP ROP ROPS 0.0 FET FET RPTH 0.0 MTEM MTEM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 56 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 18 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Samples Units Size Length MSB 18704 6.75 TC MEMORY 10435.0 6707.0 10435.0 10-MAY-03 # 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): STOP DEPTH 10435.0 START DEPTH 6707.0 FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ log header data for each bit run in separate files. 2 .2500 2 !!!!!!!!!!!!!! !!!!! LDWG File Version 1.000 ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! !! Extract File: FILE011.HED *** LIS COMMENT RECORD *** 1024 1 GR MWD 68 1 GAP I 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPM MWD 68 1 OHMM 4 4 4 RPS MWD 68 1 OHMM 4 4 5 RPX MWD 68 1 OHMM 4 4 6 RHOB MWD 68 1 G/C3 4 4 7 DRHO MWD 68 1 G/C3 4 4 8 PEF MWD 68 1 BN/E 4 4 9 NPHI MWD 68 1 PU-S 4 4 10 CALN MWD 68 1 IN 4 4 11 ROP MWD 68 1 FPHR 4 4 12 FET MWD 68 1 HR 4 4 13 MTEM MWD 68 1 DEGF 4 4 ------- 52 Total Data Records: 411 Tape File Start Depth = 6744.000000 Tape File End Depth = 10435.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = feet **** FILE TRAILER **** Tape Subfile: 2 459 records... Minimum record length: 8 bytes Maximum record length: 4124 bytes **** FILE HEADER **** LDWG .002 ) ) ) BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: o 30.7 59.2 # TOOL STRING (TOP TO VENDOR TOOL CODE DIR CCN ORD MPR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL CAL. COR. NEUTRON OPT. ROT. DENSITY MULT. PROP. RESIS. GAMMA RAY TOOL NUMBER SDS 4361 CCN 29572 ORD 6010 MPR 6245 SRIG 60809 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 8.500 6744.0 # 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 TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: LSND 9.75 .0 .0 450 .0 .000 .000 .000 .000 134.0 .0 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): SANDSTONE .00 .000 # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): .0 o # REMARKS: BIT RUN 2 (MWD Run 3). GR/MPR/oRD/cCN. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPSL - MEDIUM PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) RPSH - EXTRA SHALLOW PHASE RESISTIVITY (OHMM) BDCM - BULK DENSITY COMPENSATED (G/cc) DRHM - DENSITY CORRECTION (G/CC) DPEM - PHOTOELECTRIC CROSS SECTION (B/E) NPCK - NEUTRON POROSITY, CALIPER & SALINITY CORRECTED (SANDSTONE PU) CALM - ACOUSTIC BOREHOLE CALIPER (IN) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RASL - MEDIUM ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) RASH - EXTRA SHALLOW ATTENUATION RESISTIVITY (OHMM) $ # ) ) *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT 1c-19.xtf 150 ConocoPhillips Alaska, I 1C-19 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPSL RPSL RPM 0.0 RPCH RPCH RPS 0.0 RPSH RPSH RPX 0.0 RACL RACL RAD 0.0 RASL RASL RACSLM 0.0 RACH RACH RAS 0.0 RASH RASH RACSHM 0.0 BDCM BDCM BDCM 0.0 DRHM DRHM DRHM 0.0 DPEM DPEM DPEM 0.0 NPCK NPCK NPCKSM 0.0 CALM CALM CALM 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 72 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 14 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 17 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAP I 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPSL MWD 68 1 OHMM 4 4 4 RPCH MWD 68 1 OHMM 4 4 5 RPSH MWD 68 1 OHMM 4 4 6 RACL MWD 68 1 OHMM 4 4 7 RASL MWD 68 1 OHMM 4 4 8 RACH MWD 68 1 OHMM 4 4 9 RASH MWD 68 1 OHMM 4 4 ) 10 BDCM MWD 68 1 G/C3 4 4 11 DRHM MWD 68 1 G/C3 4 4 12 DPEM MWD 68 1 BN/E 4 4 13 NPCK MWD 68 1 PU-S 4 4 14 CALM MWD 68 1 INCH 4 4 15 ROPS MWD 68 1 FPHR 4 4 16 RPTH MWD 68 1 MINS 4 4 17 TCDM MWD 68 1 DEGF 4 4 ------- 68 ) Total Data Records: 1066 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 6707.000000 10435.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 1178 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 03/07/21 01 **** REEL TRAILER **** LDWG 03/07/24 AWS 01 Tape Subfile: 4 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes
