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195-171
STATE OF ALASKA • Ailk KA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon fl Rug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown Performed: Suspend r Perforate r Other Stimulate r Alter Casing rChange Approved Program Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Set Mech.Plug c'ygP 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r 195-171 3.Address: 6.API Number: Stratigraphic Service fl P. O. Box 100360,Anchorage,Alaska 99510 50-029-22616-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25645 KRU 2X-17 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 7715 feet Plugs(measured) 7140 true vertical 6455 feet Junk(measured) none Effective Depth measured 6808 feet Packer(measured) 6524 true vertical 5677 feet (true vertical) 5456 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 121 121 SURFACE 3780 7.625 3821 3356 PRODUCTION 6862 5.5 6897 5750 LINER 1099 3.5 7715 6455 RECEIVED Perforation depth: Measured depth: 7045-7124, 7150-7175, 7380-7410 J U L 0 8 2015 True Vertical Depth: 5869-5934, 5956-5976,6152-6178 cAwNEICf NOV 1 2 2015 AOGCC Tubing(size,grade,MD,and TVD) 3.5, L-80,6617 MD, 5529 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER SABL-3 PACKER @ 6524 MD and 5456 TVD NIPPLE-CAMCO TRDP BP-61 SAFETY VALVE @ 1808 MD and 1789 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): no stimulation or cement squeeze during this operation 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 58 692 1397 -- 183 Subsequent to operation 165 818 914 -- 168 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations Exploratory r Development Service r Stratigraphic Copies of Logs and Surveys Run I.. 16.Well Status after work: Oil 17 Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r 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 Tyson Wiese Cad 263-4250 Email Tyson.M.Wieseconocophillips.com Printed Name Tyso WieseTitle Sr. Wells Engineer Signature Phone:263-4250 Date 11J 1/L05 J ter` q/ z- //c RBDM$t JUL - 8 2015 ,,* Wz... Form 10-404 Revised 5/2015 Submit Original Only 2X-17 WELL WORK SUMMARY • DATE SUMMARY • 6/8/2015 LRS F/P FLOWLINE W/7 BBLS DIESEL. DRIFTED TBG W/2.55" CBP DUMMY TO 7350' SLM, BRUSHED INTERVAL BETWEEN 7110' RKB AND 7140' RKB WHILE LRS PUMPED 75 BBLS HOT DIESEL. SET BAKER 2.55"x 1.88' DIRECT SHEAR CBP © 7140' RKB TO ISOLATE A-4, A-3, & C-1 SANDS. *JOB IN PROGRESS. 6/9/2015 SET 2.75"XX PLUG IN X NIPPLE @ 6562' RKB, LRS PUMPED 19 BBL TO LOAD TBG & PERFORMED MIT-T TO 2500#, PASSED. EQUALIZED AND PULLED 2.75"XX PLUG FROM X- NIP @ 6562' RKB. *JOB COMPLETE, READY FOR C-4 SANDS PRODUCTION. 6/23/2015 PERFORMED SBHP SURVEY @ 7050' RKB (2090 PSI)AND 6926' RKB, COMPLETE • ! KUP PROD 2X-17 COY10CoP11ll1 }5 s Well Attributes Max Angle&MD_ TD Alaska,Inc, Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) cavoca„„„4,,s 500292261600 KUPARUK RIVER UNIT PROD 42.53 2,649.02 7,715.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2X-17,6111/2015120605 PM SSSV:NIPPLE Last WO: 44.80 4/16/1996 Vertical schemehc(eclueh Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 7,366.0 7/29/2011 Rev Reason:SET PLUG hipshkf 6/11/2015 HANGER,13.0 L.12111 asrng rings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 41.0 121.0 121.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade Top Thread 0 ' ' `" lSURFACEingDescription 75/8 6.875 41.0 3,820.83,356.2 29.70 L-80 BTC-MOD IIII CasOD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth WVLen Grade Top Thread PRODUCTION 51/2 4.950 34.8 6,897.0 5,749.7 15.50.50 L-80 LTC MOD Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I.. Grade Top Thread CONDUCTOR;41.d-121.0 • LINER 31/2 2.992 6,616.5 7,715.0 I 9.30 L80 BTC-M Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl("I Item Des Corn (in) 6,616.5 5,529.1 36.98 PBR BAKER LINER TIE BACK PBR 4.000 NIPPLE;Leoze 6,627.9 5,538.2 37.03 SLEEVE COIL TUBING LINER SETTING SLEEVE 3.000 6,634.0 5,543.1 37.06 BUSHING CANFIELD BUSHING 2.920 Tubing Strings Tubing Description 'Sting Ma...l ID(in) "Top(ftKB) 'Set Depth(ft f Set Depth(ND)(...I Wt(lb/ft) !Grade 'Top Connection GAS LIFT;2,830.6 I ; TUBING 3 1/2 2.992 13 0 6,616 8 5,529.4 9.30 L-80 EUE8RDMOD Completion Details Nominal ID Top(ftKB) Top(ND))ftKB) Top Ioni(") !tom Des Corn (in) I I 13.0 13.0 0.01 HANGER FMC GEN IV TUBING HANGER 3.500 1,807.6 1,789.0 24.05 NIPPLE CAMCO TRDP BP-61 SAFETY VALVE 2.812 6,524.2 5,455.6 37.73 PACKER BAKER SABL-3 PACKER 3.250 SURFACE,410-3,820.8- 1. . 6,562.4 5,485.9 3727 NIPPLE OTIS X NIPPLE 2.750 6,607.5 5,521.9 36.95 SEAL ASSY GBH-22 LOCATOR SEAL ASSEMBLY 2.970 GAS LIFT;5,307.4 ' 6,608.5 5,522.7 36.95 TBG SEAL SEAL OAL 8.3'STABS INTO LINER TOP 2.970 EXT I4 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Top(ftKB) (ftKB) p) Des Corn Run Date ID(in) GAS LIFT;6,060.0 7,140.0 5,947.2 33.62 PLUG 2.55"x 1.88'BAKER DIRECT SHEAR CBP 6/8/2015 0.000 Perforations&Slotsr ` '�i�k�nlRi�,,,; I I Shot Dens Top(TVD) Btm(TVD) (shots/f GAS LIFT;6,467.4 ,.,! Top(ftKB) Btm)ftKB) (ftKB) (ftKB) Zone Date t) Type Corn "� 7,045.0 7,090.0 5,868.6 5,905.7 C-4,2X-17 5/31/1996 4.0 IPERF 2 1/8"EJ,0 deg.ph 1141 7,090.0 7,124.0 5,905. 5,933.9 C-4,2X-17 3/27/1997 4.0 RPERF 2 1/8"EJ,0 deg.ph; Oriented(+/-)90 deg.F/ Lowside 7,100.0 7,108.0 5,914./ 5,920.6 C-4,2X-17 5/30/1996 4.0 IPERF 2 1/8"Enerjet,0 deg.ph PACKER,6,524.2 7,150.0 7,175.0 5,955. 5,976A C-1,2X-17 6/17/1998 4.0 APERF 2.5"HC DP180 deg ph, 90 deg from low side of hole 7,380.0 7,410.0 6,152. 6,178.3 A-3,A-4,2X- 4/16/1996 4.0 IPERF 180 deg.pH,2 1/8"HC l'- 17 NIPPLE;6,562.4 T Mandrel Inserts C St i on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com SEAL ASSY;6,607.5 =. 2,830.6 2,600.8 BST AXT 1 GAS LIFT GLV T-1 0.156 1,257.0 7/10/2008 3:00 ' 2 5,307.4 4,505.6 BST AXT 1 GAS LIFT GLV T-1 0.188 1,305.0 7/10/2008 9:00 TBG SEAL EXT;5608.5 P.;r1 3 6,0608 5,094.8 BST AXT 1 GAS LIFT DMY T-1 0.000 0.0 7/9/2008 1:00 /ill 4 6467 4 5,410.9 BST AXT 1 GAS LIFT OV T-1 0-188 0-0 7/9/2008 11:30 ILNotes:General&Safety End Date Annotation 8/1/2008 NOTE:+29 CORROSION @ 7126' 12/28/2010 NOTE:View Schematic w/Alaska Schematic9.0 I 8/12/2011 NOTE:Milled 3.5"Weatherford Composite Bridge Plug @ 7323'RKB on 6/13/2011 PRODUCTION;34.8-6,8970 IPERF,7,045.0-7,090.0 IPERF,7,100.0-7,108.0 RPERF,7,090.0-7,124.0 ir PLUG;7,140.0 V APERF,7,150.0-7,175.0 IPERF,7,380.0-7,410.0 LINER,6.616.5-7,715.0 116 47 • • • t49. WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 22, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MIT Caliper/Bottom Hole Pressure Survey: 2X-17 Run Date: 7/30/2011 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 2X-17 Digital Data in LAS format, Digital Log Image file, 3D Viewer 1 CD Rom 50-029-22616-00 Bottom Hole Pressure Survey Log 1 Color Log 50-029-22616-00 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 klinton.wood@halliburton.com Date: 121131 Signed: 11/4144%-li Imag~Iroject Well History File Cover~ge XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned dudng a special rescan activity or are viewable by direct inspection of the file. I ~_ - .j7/_ Well History File Identifier RES~AN DIGITAL DATA OVERSIZED (Scannable) D Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other. No/Type [] Other items scannable by large scanner [] Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: [] Logs of various kinds NOTES: [] Other Project Proofing BY: BEVERLY ROBIN VINCENT SHERY~INDY Scanning Preparation I x 30 = ~ ~) BY: BEVERLY ROBIN VINCENT SHERY~INDY TOTAL PAGES Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: "AGE COU.T M^TC.ES .UMBER ,. SCA..~.G PREP^R^T,O.: _~ YES .O BY:BEVER~V, NOENT S.E,Y' MA,,^ W,NOY DAT~_.~/~'~' ' ~~ Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPAN~RE FOUND: YES NO RESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: IS~ General Notes or Comments about this file: Quality Checked 12110102Rev3NOTScanned.wpd . • WELL LOG TRANSMITTAL PROACTIVE DIACINOSTIC SERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 .r ,. LO AU 2U'I Anchorage, Alaska 99501 (907) 659 -5102 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 : ProActive Diagnostic Services, Inc. RECEIVED Attn: Robert A. Richey 130 West International Airport Road AUG 5 2011 Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 Aloft Oil & Gas Cons. Commission Anchorage 1) Caliper Report 30- Jul -11 2X-17 1 Report / CD 50- 029 - 22616 -00 /CI 7 (7 2] Caliper Report 31-Jul-11 3G-22 1 Report / CD 50- 103 - 20147 -00 n ' n Signed : Date : 2,1it Print Name: k Lc PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAX: (907)245 -8952 E-MAIL : PDSANCHORAOEOMEMORYLOG.COM WEBSITE : WWW.MEMORYLOG.COM D:\Archives\ Distribution\ TransmittalSheets \ConowPluilips_Transmit.docx I T - 7 1 • • M ulti- Finger Caliper 1 � MOM gi) i Log Results Summary 1 Company: ConocoPhillips Alaska, Inc. Well: 2X -17 Log Date: July 30, 2011 Field: ((uparuk Log No.: 10259000 ZX70 State: Alaska I Run No.: 1 API No.: 50- 029 - 22616 -00 Pipet Desc.: 3.5 " 9.3 Ib. L -80 EUE 8RD/BTC-M Top Log Intvll.: Surface Pipet Use: Tubing & Liner Bot. Log Intvll.: 7,396 Ft. (MD) 1 Inspection Type : Pre CTD Sidetrack Inspection COMMENTS : I This caliper data is correlated to tubing detail record dated March 11, 1996. This log was run to assess the condition of the 3.5" tubing and liner with respect to corrosive and mechanical damage for use in planning CTD sidetrack operations. 1 The 3.5" tubing appears to be in good condition, with no significant wall penetrations, areas of cross - sectional wall Toss or I.D. restrictions recorded. I The 3.5" liner logged appears to be in good to poor condition with respect to corrosive and mechanical damage. The caliper recordings indicate eroded perforations from — 7,040' to —7,122', with 100% cross - sectional wall loss recorded at 7,105'. A line of pits is recorded from 7,174' to —7,350'. Slight buckling is I recorded from — 7,000' to 7,396' (end of log). A 3 -D log plot of the caliper recordings across the proposed whipstock placement interval, as well as an overlay of centered and off - center recordings depicting the interval of slight buckling, is included in this report. 1 The summary report is an interpretation of data provided by Halliburton Well Services. 3.5" TUBING - MAXIMUM RECORDED WALL PENETRATIONS: 1 No significant wall penetrations (> 16 %) are recorded throughout the tubing. I 3.5" TUBING - MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS: No significant areas of cross - sectional wall Toss (> 5 %) are recorded throughout the tubing. III 3.5" TUBING - MAXIMUM RECORDED ID RESTRICTIONS: No significant I.D. restrictions are recorded throughout the tubing. 1 3.5" LINER - MAXIMUM RECORDED WALL PENETRATIONS: I Line of Pits (45 %) (39 %) Jt. 223.2 @ 7,273 Ft. (MD) Line of Pits Jt. 224 @ 7,302 Ft. (MD) Line of Pits (36 %) Jt. 223.1 @ 7,258 Ft. (MD) I Line of Pits (30 %) (28 %) Jt. 225 @ 223 @ 7,335 Ft. (MD) Line of Pits Jt. 7,229 Ft. (MD) 1 ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDS @memorylog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 1 1 t q 5 I 1 0 • I 3.5" LINER - MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS: Eroded Perforations (100 %) Jt. 219 @ 7,105 Ft. (MD) Eroded Perforations ( 70 %) Jt. 218 @ 7,097 Ft. (MD) 1 Eroded Perforations ( 36 %) Jt. 217 @ 7,063 Ft. (MD) No other significant wall penetrations (> 13 %) are recorded throughout the liner logged. 1 3.5" LINER - MAXIMUM RECORDED ID RESTRICTIONS: 1 No significant I.D. restrictions are recorded throughout the liner logged. 1 Mandrel Orientation 2X -17 ConocoPhillips Alaska, Inc. Kuparuk July 30, 2011 Joint No. Tool Deviation Mandrel No. Latch Orientation 87.2 39 1 3:00 165.2 36 2 9:00 I 188.2 39 3 1:00 2002 37 4 11:30 1 1 1 1 1 1 1 1 Field Engineer: Galligan & E. Reginier Analyst: C. Lucasan Witness: J.Condio I ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) or (888) 565 -9085 Fax: (281) 565 -1369 E -mail: PDS @memorylog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 I 1 1 • • PDS Multifinger Caliper 3D Log Plot ■ Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2X -17 Date : July 30, 2011 ■ Description : Overlay of Centered and Off - Center Caliper Recordings Indicating Slight Buckling Maximum I.D. Depth 3 -D Log (Off - Center) Image Map (Off - Center) 3 -D Log (Centered) Image Map (Centered) 3.5 lft:350ft 0° 0° 90° 180° 270° 0° 0° 0° 90° 180° 270° 0° 1 2.5 Inches Minimum I.D. 2.5 Inches 3.5 Nominal I.D. I . 2.5 Inches 3.5 4s. 7000 ■ 4 _ 5 ■ i 7025 — WOW ■ _. �z ■ 1 . ' r 7050 1 tirit.---_-.. ._ _ ...... _ _,... _........._ ..., ______. _ ________ _ ... ........ Itat- 7075 aoillr �� am ,� `" _ -- m ■ui m. .v.,_ —1111111113119=4/ - - - - - -- - 7100 1 - — 11 - EMIER : "" — .....".7 - -NM 7125 •Jg ,. t ., a �r c 7150 _ I : iiii :! ■ __ i 7200 :0 1 ■ , • 1 1 • • 1 1 .__. __ _ _, _ 1 Rip - .. : f _ ......„,„ .. _, 1111111Amsfia■ 7225 '...` 1 ■!IS■■■ .... ■ ■O ■ ■ ■■ =Rini= , 7- ..... ... -.- _im..„ 1 mons ,„.. , ., , _ 3.-, 1 ■ ■ ■F2 —!'+ 7250 MED ...4 3 - _ . - ■ . 1.1.11 ■■ - = 7275 = _.. .... _ . ■ C S. - ■ _ 4 I ■ =WI - 7300 _ _ ■■tom! ■ I EMITS =VIA 7325 1 MINIM ■W`_ ■ M ■ ■:iir 7350 ■ ■Er-■ ■ ■a ■ i • ■ ■1 MI MI " - 1 ■■F1�- 7375 � . 1 ■ ■II - Nominal I.D. I 2.5 Inches 3.5 Minimum I.D. 2.5 Inches 3.5 I Maximum I.D. Depth 3 -D Log (Off - Center) Image Map (Off- Center) 3-D Log (Centered) Image Map (Centered) 25 Inches 3. 1ft350ft 0° 0° 90° 180° 270° 0° 0° 0° 90° 180° 270° 0° 1 1 1 1 1 1 • • PDS Multifinger Caliper 3D Log Plot Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 2X -17 Date : July 30, 2011 1 Description : Detail of Caliper Recordings Across Eroded Perforations and Proposed Whipstock PlaceinE Comments Depth Max. Penetration Maximum I.D. 3 -D Log Image Map I I 1ft:200ft 0 % 100 2.5 Inches 3.5 0° 0° 90° 180° 270° 0° Minimum I.D. I 2.5 Inches 3.5 Nominal I.D. 2.5 Inches 3.5 vwv r ire Jt 215 6990 MI ) I 1 1 ... III ... _ • ;MEMM t >E.... 7000 l.... S.... Jr ....« • ....[I. '- - 7010 =MILAN MN i...r : ... ...a .. r 111 11 ! 7 020 E . Jt.216 ` In # _ ....[f i... iiii[ > 7030 ���1.f ..IIMII •.M. 7040 iiii4liiii ....i19 i_._.. -. _ _ - 1 immlmommeku ....��J�r r - --"' immummiumiras Jt. 217 .iiii J.�7. 7oso , .�..i.ii.csEvie _ _ Eroded ■■ . 11111111111111111M.7 Mild Perforations ....�t /Ma7. 7060 iiii111i:111!_"i ` ....i�� ran - ....ii� K ....IIIE>iIIIIC . — _ As �...._�■ii..ir C —� _ 7070 ! �•iiiia1rii mar - I ..ice. =_ - z mow - ..i aiE_- Jt. 218 I ..11tinir -Z _ 1.. Eroded 70$0 E-�� _ Perforations I MM��� – – ...• C 70% , ._......�`' ...�L ICS= _ - - Cross- sectional ...�l�� ;� w au Loss 7090 ...lF7E �� µ II 7100 i -- _ 1 0 • IV 7110 i ISIiEii■i..../ _ _ .. Eroded " I a'�'F_ Perforations r . I — 0E� ��� ' 100% J � 11i1 4 1""may r Cross - sectional 7120 +••••=•1— iiirl __ __- 1 Wall Loss MIMI 0 � __ • 7130 MEN 1 4 i 1 == 7140 d ',... 1 Jt. 220 — = -,I . '!Yc 7150 E 1 _ F 7160 r_ - tiE � - t -1C== , ''- 1 -- - -€ 7170 1 -` t� =ii 1 _ = = ! dial --- Elk Jt.221 ,� trIMMWM 7180 ,ce IR. =__ T If II>•I111111 7190 - _ Fla�i '_ 1 j = . alum e LtMUIR II M 7200 i -- IR I IR -- Jt. 222 I Ili_ It E� 7210 «i 1 NI 7220 ` - - -- _ _. i a t Jt.223 7230 - - -- - I 28% Wall Penetration ac I = r (7,229') 7 _ = Line of Pits 7240 i s . 1 E= I - 7250 ; I { r . 1 ___ Pup Jt. 223.1 �� AMP 36% WaII Penetration 7260 '- I (7,258') Line of Pits - J 7270 i� ' _ 1 Pup Jt. 223.2 1 1 • • 45% Wall , ��� - 0� �� _ a EMI • Penetration ���SI1'i�M�� - °= (7,273') 7280 3 MMMMNIMMIIIIIIMIN Line of its .__�f� '__ — it- 7290 l ����11QUEM � �M�iA����� - Xtt - 11111111•111110,4111111111111111, Jt.224 r 111 , 39% Wall 7300 �� ��� t- P enetration E �_� �1.AI�� (7,302') kai MINIMMER lMEMINE - Line of Pits 7310 im��1l)• ummu �►mommo ��_ m� gimomm� IIIIMMMIIIIIIIIIIMIN 7320 la 1 7330 Jt. 225 = .....;�....... 1111111111111 f 7340 MMM�41 - �MMWS. - 1111111111111111111111PM "Ii___. 1 7350 ••••ri IMMIIIM y MMMilia -h._ Jt.226 7360 INIIIIIIIMII MMMIIM MMMMIIMMMM ILA I 7370 1111111111111111Mli MIN MMIIIIIILI MINIM - t" ���MlI•••� �. - I 7380 N■ba�i ' . •.. uim■a. ..--- - -ice =. .m.mmotisem-iz immE�mm.� +:.�M�!>E.r�' j 227 - _ 1t= -+� M111 — I 7390 � - WWI E ' MMINIIII 1 1 1 1 1 1 • • Correlation of Recorded Damage to Borehole Profile 1 • Pipe 1 3.5 in. (71.7' - 7375.81 Well: 2X -17 Field: Kuparuk 1 Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: July 30, 2011 1 1 ■ Approx. Tool Deviation ■ Approx. Borehole Profile 1 74 1 25 840 1 -. 50 1626 --+.mi 1 75 2429 1 GLM 1 p 100 I 3242 1 iv E c Z 125 4024 t 1 a Q r ° 150 4 4806 1 GLM 2 175 A 5618 1 GEM 3 1 1 GLM 4 200 6431 11 — 225 7314 227 7376 I 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) Bottom of Survey = 227 1 1 1 1 • • 1 PDS Report Overview L� „S Body Region Analysis I Well: 2X -17 Survey Date: July 30, 2011 Field: Kuparuk Tool Type: UW MFC 24 No. 10000429 (HAL) Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 I Country: USA No. of Fingers: 24 Tubing: 3.5 in. 9.3 ppf L -80 EUE8RMOD / BTC -M Analyst: C. Lucasan Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 3.5 in. 9.3 ppf L -80 EUE8RMOD / BTC -M 2.992 in. 3.5 in. 6.0 in. 6.0 in. 1 I Penetration(% wall) Damage b Profile (% wall) 250 Penetratio ody Metal loss body 0 50 100 1 200 0 150 - 100 1 50 49 -_ 0 . _ I 0 to 20 to 40 to over 20% 40% 85% 85% Number of joints analysed (total = 246) 1 235 4 1 6 GLM 1 94 1 Damage Configuration ( body ) 20 114 I GLM 2 10 1 5 GLM 3 1 90 0 GLM 4 I Isolated General Line Other Hole / Pitting Corrosion Corrosion Damage Pos. Hole I Number of joints damaged (total = 12) —. 12 0 0 0 0 Bottom of Survey = 227 1 1 1 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in. 9.3 ppf L-80 EUE8RMOD / BTC Well: 2X -17 Body Wall: 0.254 in. Field: Kuparuk I Upset Wall: 0.254 in. Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in. Country: USA Survey Date: July 30, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 0.1 72 0 0.02 7 0 2.94 Pup I 1 74 0 0.04 15 5 2.91 1.1 106 0 0.02 9 2 2.95 Pup ill 2 116 0 0.03 10 2 2.95 ■ I 3 147 0.04 16 4 2.91 ■ 4 179 0 0.04 15 4 2.90 • 5 210 0 0.03 11 3 2.93 Lt. Deposits. ■ 6 242 0 0.04 14 4 2.94 ■ 7 273 0 0.03 13 2 2.93 • 8 305 0 0.03 11 3 2.93 Lt. Deposits. • 9 336 0 0.03 13 4 2.92 ■ 10 368 0 0.03 12 4 2.93 Lt. Deposits. ■ 11 399 0 0.04 15 3 2.92 ■ I 12 431 0.04 0.04 15 4 2.92 • 13 462 0 0.02 9 3 2.94 ■ 14 494 0.04 0.04 14 5 2.91 ■ 15 525 0 0.03 10 4 2.96 ■ I 16 557 0 0.02 9 2 2.96 ■ 17 588 0 0.03 10 3 2.94 ■ 18 620 0 0.03 11 2 2.94 ■ 19 651 0 0.03 11 3 2.95 • 20 682 0 0.03 11 4 2.93 ■ I 21 22 714 0.03 0.03 11 4 2.93 ■ 745 0.03 0.04 15 5 2.91 ■ 23 777 0 0.03 11 3 2.94 ■ 24 809 0 0.03 11 3 2.94 ■ I 25 840 0.03 0.04 16 4 2.90 • 26 871 0.04 0.03 11 5 2.91 ■ 27 903 0 0.04 15 3 2.93 ■ 28 934 0 0.03 10 3 2.95 in I 29 966 0 0.03 13 5 2.92 ■ 30 997 0 0.03 12 4 2.95 ■ 31 1029 0.03 0.03 12 4 2.92 Lt. Deposits. ■ 32 1060 0.04 0.04 17 4 2.91 IN 33 1092 0 0.03 11 2 2.95 • I 34 1123 0.04 0.03 11 5 2.94 ■ 35 1154 0 0.04 14 3 2.93 ■ 36 1186 0 0.03 12 4 2.94 • 37 1217 0 0.03 , 10 3 2.95 ■ 1 38 1249 0.03 0.03 12 3 2.91 • 39 1280 0 0.03 11 3 2.95 ■ 40 1311 0 0.03 10 2 2.93 Lt. Deposits. ■ 41 1343 0 0.03 11 3 2.93 Lt. Deposits. • I 42 1374 0.04 0.03 12 5 2.90 ■ 43 1406 0 0.02 9 2 2.95 • ■ 44 1437 0 0.03 11 3 2.93 Lt. Deposits. • 45 1468 0.04 0.04 16 5 2.91 ■ 46 1500 0 0.03 12 4 2.92 ■ I 47 1531 0 0.03 11 3 2.90 Lt. Deposits. • 48 1563 0.03 0.03 12 4 2.90 Lt. Deposits. Body I Metal Loss Penetration Body Page 1 1 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 EUE8RMOD / BTC Well: 2X -17 Body Wall: 0.254 in. Field: Kuparuk I Upset Wall: 0.254 in. Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in. Country: USA Survey Date: July 30, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body °!° Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 49 1594 0 0.03 10 2 2.95 ■ 50 1626 0 0.03 13 4 2.94 • ■ 51 1657 0.04 0.03 13 6 2.91 N 52 1689 0 0.03 12 3 2.92 Lt. Deposits. • 53 1720 0 0.03 10 2 2.94 • I 54 1752 0 0.02 9 3 2.94 Iii 55 1783 0 0.03 11 4 2.93 Lt. Deposits. 55.1 1815 0 0.02 9 2 2.93 Pup 55.2 1821 0 0.02 7 0 2.97 Pup I 55.3 1826 0 0 0 0 2.81 Camco TRDP BP -61 Safety Valve 55.4 1829 0 0.01 4 0 2.97 Pup 56 1834 0 0.03 12 2 2.94 57 1866 0 0.02 6 1 2.94 I 58 1897 0 0.01 6 2 2.95 59 1928 0 0.02 7 2 2.95 60 1960 0 0.03 11 2 2.95 ■ 61 1991 0 0.03 11 2 2.96 ■ I 62 2023 0 0.02 9 1 2.95 IN 2055 0 0.03 11 2 2.96 64 2086 0 0.01 6 2 2.95 65 2117 0 0.02 7 1 2.93 66 2149 0 0.02 8 2 2.95 I 67 2180 68 2211 0 0.02 7 2 2.94 0 0.01 6 2 2.96 69 2242 0 0.01 6 2 2.95 70 2273 0 0.02 8 , 2 2.94 I 71 2305 0 0.02 9 2 2.94 72 2335 0 0.02 7 2 2.94 73 2366 0 0.02 9 1 2.95 74 2398 0 0.01 6 2 2.94 I 75 2429 0 0.01 6 2 2.93 Lt. Deposits. 76 2460 0 0.02 6 2 2.95 77 2491 0 0.02 6 3 2.94 78 2521 0 0.02 8 2 2.96 79 2553 0 0.02 7 3 2.94 I 80 2584 0 0.02 7 2 2.95 81 2615 0 0.02 7 2 2.94 82 2647 0 0.03 11 3 2.95 83 2678 0 0.02 9 2 2.94 I 84 2710 0 0.02 7 2 2.95 85 2741 0 0.02 9 2 2.95 86 2772 0 0.02 7 3 2.96 87 2804 0 0.02 6 2 2.95 I 87.1 2835 0 0.02 7 2 2.95 Pup 87.2 2847 0 0 0 0 2.89 GLM 1 (Latch @ 3:00) 87.3 2853 0 0.02 7 2 2.96 Pup 88 2865 0 0.02 7 3 2.94 89 2897 0 0.03 12 2 2.94 Shallow Pitting. I 90 2928 91 2960 0 0.02 8 2 2.94 0 0.01 6 2 2.93 Lt. Deposits. Penetration Body I Metal Loss Body Page 2 1 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in. 9.3 ppf L -80 EUE8RMOD / BTC Well: 2X -17 Body Wall: 0.254 in. Field: Kuparuk I Upset Wall: 0.254 in. Company: Conoco Alaska, Inc. Nominal I.D.: 2.992 in. Country: USA Survey Date: July 30, 201 Phillips 1 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 92 2991 0 0.02 7 2 2.93 Lt. Deposits. 93 3022 0 0.01 6 1 2.93 Lt. Deposits. 94 3054 0 0.01 6 2 2.94 1 95 3085 0 0.02 6 1 2.94 11 96 3116 0 0.02 7 2 2.94 I 97 3148 0 0.01 6 2 2.94 98 3179 0 0.01 5 1 2.93 Lt. Deposits. 1 99 3210 0 0.02 6 2 2.94 1 100 3242 0 0.01 5 2 2.93 Lt. Deposits. 1 I 101 3273 0 0.02 7 2 2.91 Lt. Deposits. 102 3304 0 0.02 7 2 2.96 1 103 3335 0 0.02 6 2 2.93 Lt. Deposits. 104 3367 0 0.02 7 2 2.93 Lt. Deposits. I 105 3398 0 0.02 6 2 2.94 106 3429 0 0.02 6 2 2.94 107 3461 0 0.02 6 2 2.94 1 108 3492 0 0.01 6 2 2.93 Lt. Deposits. 1 109 3523 0 0.02 7 1 2.95 1 I 110 3554 0 0.02 7 3 2.92 Lt. Deposits. 1 111 3585 0 0.02 9 2 2.93 Lt. Deposits. ii 112 3617 0 0.01 6 2 2.93 Lt. Deposits. 1 113 3649 0 0.01 6 2 2.95 i I 114 3680 0 0.01 6 2 2.93 Lt. Deposits. 1 115 3711 0 0.02 7 2 2.93 Lt. Deposits. 1 II 116 3743 0 0.01 6 2 2.93 Lt. Deposits. 1 117 3774 0 0.02 8 2 2.93 Lt. Deposits. V I 118 3805 0 0.02 6 2 2.93 119 3836 0 0.01 6 2 2.91 Lt. Deposits. 1 120 3868 0 0.02 6 2 2.93 Lt. Deposits. 11 121 3899 0 0.01 6 2 2.93 Lt. Deposits. 1 I 122 3931 0 0.01 6 2 2.93 Lt. Deposits. 1 123 3962 0 0.02 7 1 2.95 124 3993 0 0.02 7 2 2.95 1 125 4024 0 0.01 6 2 2.92 Lt. Deposits. 1 126 4056 0 0.03 11 3 2.92 Lt. Deposits. ■ I 127 4087 0 0.02 6 2 2.94 1 128 4118 0 0.02 6 2 2.93 Lt. Deposits. 1 129 4150 0 0.02 7 2 2.93 Lt. Deposits. 130 4181 0 0.02 7 2 2.95 I I 131 4212 0 0.02 9 2 2.94 132 4243 0 0.03 10 2 2.93 Lt. Deposits. • II 133 4275 0 0.02 9 1 2.94 • 134 4305 0 0.03 10 2 2.93 Lt. Deposits. IN I 135 4337 0 0.02 7 2 2.93 Lt. Deposits. 136 4369 0 0.02 7 2 2.92 Lt. Deposits. 137 4400 0 0.02 9 2 2.92 Lt. Deposits. 138 4431 0 0.02 7 2 2.93 1 139 4463 0 0.02 7 2 2.93 Lt. Deposits. I 140 4494 141 4525 0 0.02 7 2 2.91 Lt. Deposits. 0 0.02 9 2 2.93 • 1 il ' Penetration Body Metal Loss Body Page 3 1 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in. 9.3 ppf L -80 EUE8RMOD / BTC Well: 2X -17 Body Wall: 0.254 in. Field: Kuparuk Upset Wall: 0.254 in. Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in. Country: USA Survey Date: July 30, 2011 I Joint Jt Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 142 4556 0 0.02 7 2 2.94 143 4587 0 0.01 6 2 2.93 144 4618 0 0.02 7 2 2.92 Lt. Deposits. 145 4650 0 0.02 7 2 2.96 146 4680 0 0.03 10 2 2.93 Lt. Deposits. I 147 4712 0 0.02 8 2 2.94 148 4743 0 0.02 9 3 2.93 Lt. Deposits. 149 4774 0 0.02 6 2 2.92 Lt. Deposits. 150 4806 0 0.03 11 3 2.96 I 151 4837 0 0.01 6 2 2.95 152 4868 0 0.02 8 2 2.95 153 4899 0 0.02 7 3 2.93 154 4930 0 0.02 8 2 2.94 I 155 4961 0 0.02 7 2 2.93 Lt. Deposits. 156 4993 0 0.02 7 2 2.93 Lt. Deposits. 157 5024 0 0.02 7 2 2.94 158 5055 0 0.03 13 2 2.93 Shallow Pitting. Lt. Deposits. 159 5087 0.02 7 4 2.93 I 160 5118 ■ 0.03 11 3 2.94 161 5149 0 0.02 8 2 2.93 Lt. Deposits. 162 5181 0 0.01 6 2 2.93 Lt. Deposits. 163 5212 0 0.02 7 2 2.91 Lt. Deposits. I 164 5244 0 0.02 7 2 2.96 165 5275 0 0.02 9 2 2.92 Lt. Deposits. 165.1 5307 0 0.03 11 2 2.94 Pup 165.2 5318 0 0 0 0 2.90 GLM 2 (Latch @ 9:00) I 165.3 5326 0 0.02 7 2 2.94 Pup 166 5336 0 0.02 9 2 2.92 Lt. Deposits. 167 5368 0 0.01 6 2 2.94 168 5400 0 0.03 11 3 2.93 ■ I 169 5431 0 0.03 10 3 2.93 Lt. Deposits. 170 5462 0 0.02 7 2 2.96 171 5493 0 0.02 9 3 2.92 Lt. Deposits. • 172 5525 0 0.02 9 2 2.95 ■ 173 5556 0 0.04 14 4 2.96 Shallow Pitting. ■ I 174 5587 0 0.04 15 3 2.94 Shallow Line of Pits. • 175 5618 0 0.03 13 3 2.94 Shallow Line of Pits. ■ 176 5650 0 0.02 9 3 2.93 177 5682 0 0.02 7 3 2.96 I 178 5712 0 0.02 9 3 2.94 ■ 179 5743 0 0.03 10 4 2.94 180 5775 0 0.02 9 2 2.92 Lt. Deposits. 181 5807 0 0.01 6 1 2.96 I 182 5837 0 0.03 10 2 2.91 Lt. Deposits. 183 5869 0 0.02 8 2 2.93 Lt. Deposits. 184 5901 0 0.03 10 3 2.94 185 5932 0 0.02 7 2 2.95 186 5962 0 0.03 11 4 2.91 Lt. Deposits. I 187 5994 0 0.02 7 1 2.94 188 6025 0 0.03 11 2 2.95 Penetration Body I Metal Loss Body Page 4 Penetra 1 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in. 9.3 ppf L -80 EUE8RMOD / BTC Well: 2X -17 Body Wall: 0.254 in. Field: Kuparuk 1 Upset Wall: 0.254 in. Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in. Country: Survey Date: J A 30, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 188.1 6056 1) 0.02 8 1 2.94 Pup 188.2 6068 0 0 0 0 2.88 GLM 3 (Latch @ 1:00) 188.3 6074 0 0.02 8 2 2.94 Pup 189 6087 () 0.02 8 2 2.92 Lt. Deposits. 190 6118 0 0.03 10 2 2.92 Lt. Deposits. I 191 6150 O 0.03 11 3 2.93 Lt. Deposits. 192 6181 O 0.03 10 3 2.92 Lt. Deposits. 193 6213 O 0.01 5 2 2.95 194 6244 0 0.02 9 2 2.93 Lt. Deposits. I 195 6275 0 0.01 6 2 2.94 196 6306 0 0.02 7 2 2.94 197 6337 0 0.03 12 3 2.90 Lt. Deposits. 198 6370 0 0.02 9 2 2.93 Lt. Deposits. I 199 6400 0 0.02 7 2 2.91 Lt. Deposits. 200 6431 0 0.02 9 2 2.92 Lt. Deposits. 200.1 6463 0 0.03 10 4 2.92 Pup Lt. Deposits. 200.2 6476 0 0 0 0 2.87 GLM 4 (Latch @ 11:30) 200.3 6482 0 0.03 10 1 2.93 Pup 201 6493 0 0.02 7 2 2.92 Lt. Deposits. 201.1 6525 0 0.01 4 1 2.94 Pup 201.2 6531 0 0.01 2 0 2.98 Pup 201.3 6533 0 0 0 0 2.75 Packer I 201.4 6536 0 0.01 6 0 2.91 Pup 202 6538 0 0.01 6 1 2.92 Lt. Deposits. 202.1 6570 0 0 0 0 2.75 Otis X Nipple 202.2 6571 O 0.01 6 1 2.93 Pup 203 6578 0 0.03 11 3 2.92 Lt. Deposits. 203.1 6608 0 0.01 6 4 2.94 Pup 203.2 6614 0 0 0 0 2.99 GBH -22 Seal Assembly 204 6637 0 0 0 0 2.91 Top Of Liner I 205 6668 0.04 0.03 12 3 2.90 Shallow Pitting. Lt. Deposits. 206 6699 0.03 0.03 11 3 2.88 Lt. Deposits. 207 6730 0 0.03 10 2 2.90 Lt. Deposits. 208 6761 () 0.03 10 2 2.92 Lt. Deposits. 209 6791 1) 0.02 8 1 2.93 Lt. Deposits. I 210 6821 0 0.02 9 2 2.92 Lt. Deposits. 211 6851 (1 0.03 12 3 2.90 Lt. Deposits. 212 6882 0 0.03 12 4 2.89 Lt. Deposits. 213 6913 0 0.03 11 4 2.93 Lt. Deposits. I 214 6946 0 0.02 9 2 2.94 215 6976 0 0.02 9 3 2.94 216 7005 0 0.03 11 3 2.92 Lt. Deposits. 217 7037 0.18 0.27 100 35 2.90 Eroded Perforations. I 218 7068 I.3 3 1.73 100 70 2.93 Eroded Perforations. 219 7100 0.76 1.74 100 100 2.26 Eroded Perforations. 220 7131 0.14 0.24 94 9 2.93 Perforations. 221 7161 0.22 0.28 100 12 2.90 Perforations. 222 7191 0 0.05 18 1 2.92 Shallow Line of Pits. Lt. Deposits. I 223 7221 0.03 0.07 28 5 2.88 Isolated Pitting. Lt. Deposits. 223.1 7252 0 0.09 36 3 2.89 Pup Line of Pits. Lt. Deposits. IPenetration Body I Metal Loss Body Page 5 1 1 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in. 9.3 ppf L -80 EUE8RMOD / BTC Well: 2X -17 Body Wall: 0.254 in. Field: Kuparuk Upset Wall: 0.254 in. Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in. Country: USA Survey Date: July 30, 2011 ' Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) %, (Ins.) 0 50 100 223.2 7267 0.04 0.12 45 4 2.90 Pup Line of Pits. Lt. Deposits. ■mo 224 7283 0.04 0.10 39 5 2.88 Line of Pits. Lt. Deposits. ■mo 225 7314 0.07 0.08 30 4 2.87 Line of Pits. Lt. Deposits. ■ 226 7345 0 0.03 12 4 2.86 Lt. Deposits. ■" 227 7376 0.03 0.32 100 13 2.93 Perforations. 1 Penetration Body Metal Loss Body 1 1 1 1 1 1 1 1 1 1 111 Page 6 1 1 1 • • 1 1-73..S. PDS Report Cross Sections I Well: 2X -17 Kuparuk Survey Date: July 30, 2011 Field: Tool Type: UW MFC 24 No. 10000429 (HAL) Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 1 Tubing: 3.5 in. 9.3 ppf L -80 EUE8RMOD / BTC -M Analyst: C. Lucasan 1 1 Cross Section for Joint 223.2 at depth 7272.560 ft Tool speed = 37 Nominal ID = 2.992 I Nominal OD = 3.5 Remaining wall area = 96% Tool deviation = 31° 1 / / 1 1 1 / 1 1 —..I I Finger = 24 Penetration = 0.115 in. Line of Pits 0.12 in. = 45% Wall Penetration HIGH SIDE = UP 1 1 1 1 1 1 • • 1 PDS Report Cross Sections I Well: 2X -17 Survey Date: July 30, 2011 Field: Kuparuk Tool Type: UW MFC 24 No. 10000429 (HAL) Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 1 Tubing: 3.5 in. 9.3 ppf L -80 EUE8RMOD / BTC -M Analyst: C. Lucasan 1 1 Cross Section for Joint 224 at depth 7301.920 ft Tool speed = 37 Nominal ID = 2.992 I Nominal OD = 3.5 Remaining wall area = 96% Tool deviation = 29° 1 1 1 1 1 \ i 1 \ // 1 ■ 1 Finger = 15 Penetration = 0.099 in. Line of Pits 0.10 in. = 39% Wall Penetration HIGH SIDE = UP 1 1 1 1 1 1 • • 1 TaS,_ PDS Report Cross Sections I Well: 2X -17 Kuparuk Survey Date: July 30, 2011 Field: Tool Type: UW MFC 24 No. 10000429 (HAL) Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 1 Tubing: 3.5 in. 9.3 ppf L -80 EUE8RMOD / BTC -M Analyst: C. Lucasan 1 1 Cross Section for Joint 219 at depth 7104.. s e Tool speed = 37 Nominal ID = 2.992 \ I Nominal OD = 3.5 Remaining wall area = 0% Tool deviation = 32° I 1 1 1 1 1 1 1 Finger = 6 enetration = 1 26 in. \ 1 g Eroded Perfora ons Cross - sectional all Loss 100% HIGH SIDE = UP 1 1 1 1 1 1 0 • 1 PDS Report Cross Sections I Well: 2X -17 Survey Date: Tool Type: July 30, 2011 Field: Kuparuk UW MFC 24 No. 10000429 (HAL) Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 1 Tubing: 3.5 in. 9.3 ppf L -80 EUE8RMOD / BTC -M Analyst: C. Lucasan 1 1 Cross Section for Joint 218 at depth 7097.070 ft Tool speed = 37 Nominal ID = 2.992 `\ 1 Nominal OD = 3.5 Remaining wall area = 30% Tool deviation = 33° \ 1 1 1 1 1 1 1 I Finger = 20 Penetration 1.72)81 in. Eroded Perfor. iory 70° , Cross- sectioral Wall Lo : HIGH SIDE = UP 1 1 / 1 1 1 I 1, , KUP Wdlhore 2X -17 COI10C� g 1jflipS Attributes A1:1U.a. Ilv APINWI !Field m gle & MD TD d Nae Well Status Ind (°) ND MB) A68 BM, 00030003) Lonaaortrepa 500292261600 I KUPARUKRIVEP. UNIT PROD 42.53 2,649.02 7,715.0 Comment H2S (ppm) Date Annotation End Date KB-0rd (R) Rig Release Date . °. Well coned -zx -t7 6/16/2011 1042 of AM 70 7/1/2008 Last W0: 44.80 4/16/1996 I Schematic -Actual Annotation Depth (RKB) End Date Annotation Last Mod ... End Date Last Tag: 7,097.0 8/1/2008 Rev Reason: SET PLUG ninam 6/16/2011 HANGER, 21 Casing Strings Casing Description - String 0... String ID... Top MB) Set Depth (f... Set Depth (7VD)... String Wt... String... String Top Thrd 0 CONDUCTOR 16 15.062 41.0 121.0 121.0 62.50 H - 40 WELDED I v Casing Description String 0... String ID ... Top (908) Set Depth (L. Set Depth (7VD)... String Wt... String ... String Top Thrd SURFACE 75/8 6.875 41.0 3,820.8 3,356.3 29.70 L BTC Casing Description String 0... String ID ... Top (IWB) Set Depth (f... Set Depth (7VD)... String W1.. String... String Top Thrd PRODUCTION 51/2 4.950 34.8 6,897.0 5,749.7 15.50 L LTC - MOD I Casing Description String 0... String ID ... Top ma) Set Depth (r... Set Depth (ND) ... String Wt.. String ... String Top Thrd LINER 31/2 2.992 6,617.0 7,715.0 9.30 L-80 BTC -M Tubing Strings Tubing Description String 0... String ID ... Top (9148) ( Set Depth (L.. Set Depth (TVD) ... ( String Wt... String ... ( String Top Thrd C0NOU41 o2. _" TUBING 3 1/2 2.992 21.3 I 6.616.8 5,529.1 9.30 L-80 EUE8RDMOD Completion Details Top Depth (TVD) Top Ind Nom... Top (RK8) IRK 2 1 (°) hem Descnpfian Comment ID (i8) SAFETY � 21.3 21.3 0.00 HANGER FMC GEN IV TUBING HANGER 3.500 2.812 1,016 ° 1,815.9 1,796.3 24.12 SAFETY VLV CAMCO TRDP BP-6I SAFETY VALVE - 6,532.5 5,462.2 37.55 PACKER BAKER SABL -3 PACKER 3.250 1. 11. 6,570.7 5,492.6 37.20 NIPPLE OTIS X NIPPLE 2750 I ` 6,615.8 5,528.2 36.18 SEAL ASSY GBH -22 LOCATOR SEAL ASSEMBLY 2.992 Mr GAS LIFT, In Hole (reline retrievable lu s, valves, um s fish, etc. 2,839 TO MSS p g p p r ) (TVD Top Top(N(B) (RKB) CI Description Comment Run Date ID (in) 7,323 6,102.6 29.59 PLUG 3.5" Weatherford Composite Bridge Plug 6 /13/2011 0.000 I Perforations & Slots 51601 Top ("ND) etch (7VD) Dens SURFACE, as' Top (IIKB) Btin (N®) gtKB) (n148) Zone Dale NB.- type Comment ala,921 7,045 7,090 5,868.6 5,905.7 C-4, 2X -17 5/31/1996 4.0 IPERF 2 1/8" 8.1, 0 deg. ph I 7,090 7,124 5,905.7 5,934.0 C-4, 2X -17 7 ,100 7,108 5,914.0 5,921.0 C4, 2X -17 3/27/1997 4.0 RPERF 2 1/8" EJ, 0 deg. ph; Oriented ( + / -) 90 deg. F/ 0 LowSde 5/30/1996 4.0 IPERF 21/8 Ever t 0 de GAS LIFT, " " 6,316 )e g. ph 7,150 7,175 5,955.5 5,976.5 C-4, 2X -17 6/17/1998 4.0 APERF 2.5" HC DP180 deg ph, 90 deg from low side of hole I - 7,380 7,410 6,152.2 6,178.6 A-3, A-4, 2X -17 4/16/1996 4.0 IPERF 180 deg. pH, 2 1/8" HC Notes: General & Safety GAS LIFT. End Date Annotation 6' J 8/1/2008 NOTE: +29 CORROSION @ 7126' ri al NI 12/28/2010 NOTE: View Schematic w/ Alaska Schematic9.0 I/ GAS LIFE. MI i 1111 8.478 1111 PACKER, 6,532 1 'APPLE. o 5 ?1 1 11.1 1 • SEAL ASSY. 6.616 I I I PRODUCTION. 36-6,897 IPERF, 7.045 -7.090 Mandrel Details Top Depth Top Port 7.100 (7VD) Ind OD Valve Latch Size 7RO Rim RPERF. Stn Top ( RKB) MK ( °) Make Model (In) Sery Type Type (in) Umi) Run Date Com... 7.000 - 7.124 1 2,838.9 2,607.1 40.69 BST AXT 1 GAS UFT GLV T -1 0.156 1,257.0 7/10/2008 2 5,315.7 4,512.2 37.24 BST AXT 1 GAS LIFT GLV T -1 0.188 1,305.0 7/10/2008 3 6,0603 5,101.2 39.54 BST AXT 1 GAS LIFT DMY T -1 0.000 0.0 7/9/2008 I 7,150.7 3 4 6,475.7 5,417.4 37.99 BST AXT 1 GAS LIFT OV T -1 0.188 0.0 7/9/2008 PLUG, 7,323 I IPERF, 7,380 -7410 LINER, 8.817-7.715 TO. TD, 7,715 s ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Sept 14, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 ~~~~~~ S b ~ ~ ~a~$ Dear Mr. Maunder: {, '' ~° _. ~. ri~'~~^~v° ~~' 1~5" Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pum~ed August 20~' -Sept 11th, 2008. The corrosion inhibitor/sealant was pumped Sept 12 - 13 ,2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, ~~~y~~ ~ Perry ei ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant T~ Report of Sundry Operations (10-404) Kuparuk Field n~•o ---- .7/ 1'F1LUV0 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # cement um ed cement date inhibitor sealant date ft bbls ft al 1C-178 203-041 8' 1.50 8" 9/11/2008 4.68 9/12/2008 2F-17 196-204 12' 10" 2.25 8" 9/11/2008 7.65 9!12/2008 3R-20 192-022 9' 4" 1.50 16" 9/11/2008 1Y-27 193-088 11' 9" 3.00 20" 8/24/2008 2.97 9/12/2008 1 Y-29 188-091 41' 6.00 5' 8/20/2008 10.20 9/12/2008 1 Y-32 188-093 27' 8" 4.40 32" 8/20/2008 6.80 9/12/2008 1Y-34 193-091 8' 1.10 27" 8/20/2008 5.95 9/12/2008 1 E-33 197-151 9' 6" 2.10 20" 8/24/2008 7.23 9/12/2008 1 E-104 204-227 7' 1.40 9" 8/24/2008 1.70 9/12/2008 2X-01 183-084 10" NA 10" NA 3.40 9/13!2008 2X-02 183-103 23" NA 23" NA 3.40 9/13/2008 ZX-03 183-109 6" NA 6" NA 1.28 9/13/2008 2X-05 183-107 8" NA 8" NA 5.10 9/13/2008 2X-06 183-110 6" NA 6" NA 1.70 9!13/2008 2X-07 183-113 6" NA 6" NA 1.28 9/13/2008 2X-08 183-114 6" NA 6" NA 1.28 9/13/2008 2X-17 195-171 6" NA 6" NA 1.70 9/13/2008 '~~~~`'; ~'r~~ .~ ~? ~~~~ J" 2X-17 Failed TIFL • Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Tuesday, July 01, 2008 7:47 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv Subject: 2X-17 Failed TIFL Attachments: 2X-17.pdf; 2X-17.png -~' Tom /Jim, Page 1 of 1 I'~ 1a5-I-7~ Yesterday well 2X-17 (PTD 195-171) a gas lift oil producer failed a TIFL. CPF2 PE has been informed and will go through proper channels to get a new GLV string installed. Current TI s are 1775/1625/100. Attached are current 3 month TIO, and well schematic. Please let me know if you have any questions Russ Problem Wells Supervisor «2X-17.pdf» «2X-17.png» 7/31 /2008 KRU 2X-17 PTD 195-171 Tlll~ Plot - 2K-17 1500 ~y 1000 a 500 ~~o X~i l1-ir o ~ 01-Apr-08 14-Apr-08 27-Apr-08 10-May-08 23-May-08 05-Jun-08 18-Jun-OS Date 200 150 a d 100 8 v 50 0 r: ;~'~* ~~ ~ ~1 ~ KRU 2X-17 ~~~ C~7t~~Cd~h1I~1~S ~11~15~(~r ~~tA{." -f7 API: 500292261600 W eil T e: PROD An le TS: 35 de 7045 SSSV T e: W RDP Ori Com letion: 4/16/1996 An le TD: 23 de 7700 ' Annular Fluid: Last W/O: Rev Reason: Set Plug, Tag Est. 18' SSSV Fill I (1816-1817, Reference Lo Ref Lo Date: Last U date: 12/19/2006 OD:3.5o0) -- _ ~ Last Ta : 7392' RKB TD: 7715 ftKB ` ', Last Ta Date: 11/29/2006 Max Hole An le: 43 de 2649 I Casin Strin -ALL STRINGS ', ~i Descri lion Size To Bottom ND Wt Grade Thread CONDUCTOR 16.000 0 121 121 62.50 H-40 SUR. CASING 7.625 0 3821 3356 28.00 L-80 Gas Lift PROD. CASING 5.500 0 6897 5250 16.00 L-80 MandrelNalve r ~ - LINER 3.500 6617 7715 771 5 9.30 L-80 BTC-M 1 2839 2840 ~ a°-~ ~~ Tubin Strin -TUBING ( - , Size To Bottom ND Wt Grade Thread 3.500 0 6617 5530 9.30 L-80 BTC/EUE Perforations Summa Interval ND Zone Status Ft SPF Date T e Comment 7045 - 7090 5869 - 5906 C-4 45 4 5/31/1996 IPERF 2 1/8" EJ, 0 de h Gas Lift M lN l - ` -~ 7090 - 7100 5906 - 5914 C-4 10 4 3/27/1997 RPERF 2 1!8" EJ, 0 deg. ph; Oriented andre ve a 2 __ ~,;~,,,~ +/- 90 de . F/ Lowside (5316-5317, ---- -- 7100 - 7108 5914 - 5921 C-4 8 8 3/27/1997 RPERF 2 1/8" EJ, 0 deg. h Oriented P +/_ 90 de . F/ Lowside 7108 - 7124 5921 - 5934 C-4 16 4 3/27/1997 RPERF 2 1/8" EJ, 0 deg. ph; Oriented +/- 90 de . F/ Lowside 7150 - 7175 5955 - 5977 C-1 25 4 6/17/1998 APERF 2.5" HC DP180 deg ph, 90 deg from low side of hole Gas Lin 7380 - 7410 6152 - 6178 A-0,A-3 30 4 4/16/1996 IPERF 180 de H, 2 1/8" HC andrel/Dummy Valve 3 _ Gas.LiftMantlrelsNalves (sose~oss, St MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Viv OD:a.75o) Cmnt 1 2839 2607 BST AXT GLV 1.0 T-1 0.156 1278 7/19/2003 2 5316 4512 BST AXT GLV 1.0 T-1 0.188 1327 7/19/2003 I 3 6068 5101 BST AXT DMY 1.0 T-1 0.000 0 11/7!1996 4 6476 5418 BST AXT OV 1.0 T-1 0.188 0 7/19/2003 Gas Lift MandrelNalve - Other lu s, ui ., etc. - JEWELRY 4 ~ De th ND T e Descri lion ID (6476-6477, = 1816 1797 SSSV Camco BP-61 2.812 6532 5462 PKR BakerSABL-3 3.250 6571 5493 NIP Otis 'X' Ni le 2.750 6617 5530 PKR BakerSABL-3 3.250 6617 5530 TTL 2.992 PKR ~ 7140 5947 PLUG Set 3.5" Weatherford Com osite Brid a Plu on 12/17/2006 0.000 (6532533, ~ OD:5.650) NIP (6571-6572, -~ OD:3.500) II TUBING (0-6617, OD:3.500, ID:2.992) TTL / (6617-6618, OD:3.500) Perf (7045-7090) -~ ~- ~-~-- - - Perf ___ ____. ._..__.. (7100-7108) __- Perf (7090-7124) ___ .-__ ~ PLUG (7140-7142, OD:3.500) I Perf ____ ___ I _______. (7380-7410) ____ -- -____-- . RECEIVED STATE OF ALASKA . FEB 0 9 2007 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA TIOMSta Oil & Gas Cons. Commission 1. Operations Performed: Abandon D Repair Well D Plug Perforations D Stimulate D OtherAnCnOme .\ ";?c\ 0.\ ~ Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D ~<1(~~ Change Approved Program D Opera!. ShutdownD Perforate D Re-enter Suspended Well D :)1, ..t 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0- Exploratory D 195-1711 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-22616-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 41' , 2X-17 8. Property Designation: 10. Field/Pool(s): ADL 25645, ALK 2576 Kuparuk River Field 1 Kuparuk Oil Pool , 11. Present Well Condition Summary: Total Depth measured 7700' feet true vertical 6441' . feet Plugs (measured) 7140' Effective Depth measured 7392' feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 16" 121' 121' SUR. CASING 3780' 7-5/8" 3821' 3356' PROD. CASING 6856' 5-1/2" 6897' 5750' LINER 1098' 3-1/2" 7715' 6455' Perforation depth: Measured depth: 7045'-7124',7150'-7175',7380'-7410' true vertical depth: 5869'-5934',5955'-5977',6152'-6178' SCANNED FEB 1 4 2007 Tubing (size, grade, and measured depth) 3-1/2" , L-80, 6617' MD. Packers & SSSV (type & measured depth) pkr= BAKER SABL-3; BAKER SABL-3 pkr= 6532'; 6617' Cameo BP-61 SSSV= 1816' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubinn Pressure Prior to well operation 91 1728 1896 -- 185 Subsequent to operation 208 641 379 -- 174 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: OilO GasD WAGD GINJD WINJD WDSPL D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A it C.O. Exempt: N/A Contact Guy Schwartz @ 265-6958 Printed Name Guy' .... \._ Title Wells Group Engineer Signature C')W-f ~ ~ Phone Date ;(-8-07- Prenared bv Sharon AI/sun-Drake 263-4612 Form 1 o~r/:;;;;~ed 04/2004 'LiR RBDMS BFl Þ ~. ''1.(;>7 ~ ' {OO7 .< 1..., .. Submi . rigin ;On IGINAL /~~t(1ðl DATE 11/29/06 11/30/06 12/2/06 12/3/06 12/14/06 12/15/06 12/17/06 . 2X-17 Well Events Summary . Summary WORKED 2.735" SWAGE THROUGH BOTH SABL-3 PKRS,TAGGED @ 7392' RKB EST 18' FILLlN PROGRESS DRIFTED THROUGH BOTH SABL-3 PKRS WITH 2.74" SWAGE TO BELOW IPB SETTING DEPTH 7135' RKB.BRUSH AND FLUSH LINER TO 7170' RKB ATTEMPT TO SET TTS PLUG (OD= 2.72"). TOOL TAGGED @ 7073'. MAX SPEED WAS 200 FPM. MAX OVERPULL OBSERVED WHILE PULLING FREE WAS 600 LBS. DECISION MADE TO POOH WITH TOOL STRING. WELL LEFT SHUT IN. BRUSHED TBG AND LINER FROM 6500' RKB DOWN TO 7150' RKB (ABLE TO SEE PKR @ 6532' RKB, X-NIPPLE @ 6571', AND TIGHT SPOT IN LINER @ 7092' RKB). DRIFTED INTO LINER DOWN TO 7182' RKB W/2.735 BROACH AND 2.745 BROACH. ATTEMPTED TO DRIFT LINER W/10' X 2.74 DUMMY DRIFT AND 10' X 2.72 DUMMY DRIFT BUT UNABLE TO GET BY TIGHT SPOT @ 7092' RKB. GAUGED TBG TO 2.74" TO 7160', NO RESTRICTIONS. DRIFT WITH 2.6 x 11.5' DRIFT, SAME RESULT. ATTEMPT DRIFT WITH BARBELL ASS'Y (2.71" CENT, 5'x2.625" STEM, 2.70" SWAGE), UNABLE TO WORK PAST 7098' RKB. IN PROGRESS. DRIFTED TBG TO 7250' RKB WITH BARBELL ASS'Y (2.71" CENT, 22" x 2.625" STEM, 2.70" SWAGE). ENCOUNTERED NO RESTRICTIONS. .../.. SET WEATHERFORD COMPOSITE BRIDGE PLUG AT 714~CORRELATED TO . PPROF DATED 09-NOV-2006. TOOL STOPPED ON SEVERAL ATTEMPTS JUST OUTSIDE TUBING TAIL AT 6629'. DID NOT ATTEMPT TO CORRELATED BACK THRUGH C4 PERFS (PREVIOUS ATTEMPTS TO SET PLUG STOPPPED HERE) OR TUBING TAIL. CORRELATED OVER INTERVAL 9250'-9100' . ConocoPhillips Alaska, Inc. 2X-17 SSSV (1816-1817, 00:3.500) Gas Lift MandrelNalve 1 (2839-2840, Gas Lift MandrelNalve 2 (5316-5317, Gas Lift 'ndrel/Dummy Valve 3 (6068-6069, 00:4.750) Gas Lift MandrelNalve 4 (6476-6477, I PKR (6532-6533, 00:5.650) NIP (6571-6572, 00:3.500) TUBING (0-6617, OD:3.5oo, 10:2.992) TTL (6617-6618, 00:3.500) Perf (7045-7090) - - - - - - ~ ~ Perf = = (7100-7108) ~ ~ Perf - - (7090-7124) ~ ~ = = - - = = - - PLUG (7140-7142, 00:3.500) Perf - - (7380-7410) r - - .., lS 0 - 'ì \"\~ - - - - API: 500292261600 SSSV Type: WRDP Annular Fluid: Well Type: PROD OriQ Completion: 4/16/1996 Last W/O: Reference LOQ: Last TaQ: 7392' RKB Last lag ua¡e: Casino DeseriDtion CONDUCTOR SUR. CASING PROD. CASING LINER Tubino Strino - TUBING Size Top 3.500 0 Interval 7045 - 7090 7090 - 7100 7100 - 7108 7108 - 7124 7150 - 7175 7380 - 7410 I n;",. St MD 1 2839 2 5316 3 6068 4 6476 Otnel\¡li luas, Depth TVD 1816 1797 6532 5462 6571 5493 6617 5530 6617 5530 7140 5947 . KRU 2X-17 Anole @ TS: 35 deQ @ 7045 Anole @ TD: 23 dea !âJ 7700 Rev Reason: Set Plug, Tag Est. 18' Fill Last Update: 12/19/2006 ININ\. Ref Lag Date: TD: 7715ftKB Max Hale AnQle: 43 de!:! @ 2649 Size 16.000 7.625 5.500 3.500 I Bottom I 6617 rv[ Zone 5869 - 5906 C-4 5906 - 5914 C-4 5914 - 5921 C-4 5921 - 5934 C-4 5955 - 5977 C-1 6152 - 6178 A-4.A-3 TVD Man Mfr Man Type 2607 BST AXT 4512 BST AXT 5101 BST AXT 5418 BST AXT ;n ...~ I _ II::We: DV TVDe SSSV PKR NIP PKR TTL PLUG Camco BP-61 Baker SABL-3 Otis 'X' Nipple Baker SABL-3 V Mfr Top o o o 6617 I I TVD 5530 Bottom 121 3821 6897 7715 Wt 62.50 28.00 16.00 9.30 BTC-M Status Ft I SPF 45 4 10 4 Grade H-40 L-80 L-80 L-80 TVD 121 3356 5750 7715 Thread I I GraDe L-80 I Type Comment IPERF 21/8" EJ, 0 deQ. ph RPERF 2 1/8" EJ, 0 deg. ph: Oriented 1(+1-) 90 deQ. FI Lowside RPERF 2 1/8" EJ, 0 deg. ph; Oriented I (+I-) 90 deg. FI Lowside RPERF 2 1/8" EJ, 0 deg. ph: Oriented 1(+1-) 90 deQ. FI Lowside APERF 2.5" HC DP180 deg ph, 90 deg from low side of hole IPERF 1180 deg. DH. 2 1/8" HC' Port TRO Date Run Vlv Cmnt 8 8 16 4 25 4 30 4 V Type GLV GLV DMY OV wt 9.30 Thread 1:!1l;/tUE I Date 5/31/1996 3/27/1997 3/27/1997 3/27/1997 611711998 4/16/1996 VOD Latch 1.0 1.0 1.0 1.0 T-1 0.156 T-1 0.188 T-1 0.000 1- U.HR 1278 7/19/2003 1327 7/19/2003 o 11/7/1996 o 7119/2003 Description ID 2.812 3.250 2.750 3.250 2.992 0.000 Set 3.5" Weatherford Composite Brid!:!e Plu!:! on 12117/2006 11/21/06 Sc~lInbepg8P NO. 4049 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth 9'í(if C r .nO '" {;', Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 I Cï\5- 1--:;- ( Field: Kuparuk Well Job# Log Description Date BL Color CD 2U-09 11416231 SBHP SURVEY 10/29/06 1 3J-18 . 11483494 GlS 11/13/06 1 3J-13 11483495 INJECTION PROFilE 11/14/06 1 1 R-07 11486070 SBHP SURVEY 11/11/06 1 2X-17 . 11486068 PRODUCTION PROFilE 11/09/06 1 1 D-36 . 11486077 SBHP SURVEY 11/19/06 1 1D-120 " 11486073 INJECTION PROFilE 11/14/06 1 1 R-35 - 11486074 PROD PROFilE-INCOMPLETE OPERATION 11/15/06 1 t Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. 0/. lÍ--- . . ¡ I[,:a I : " 1 ¡--'I " 'L ' I ~~ I~~! 'i I ., '::1 . J. . , (0;.:... ) AlASKA OIL Al\ID GAS CONSERVATION COltlltDSSION FRANK H. MURKOWSKJ, GOVERNOR November 9, 2005 333 W. 7111 AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ]Vir. Paul Dubuisson Kuparuk Field Manager ConocoPhillips Alaska, Inc. P. O. Box 100360 Anchorage, AK 99510-0360 C6';(, \ ~ 'd.-*' \~ Dear Mr. Dubuisson: The Alaska Oil and Gas Conservation Commission C""Comnlission") performed an inspection of your well safety valve system (SYS) at Kuparuk River Unit 2X ("KRU 2X") pad on October 7, 2005. Attached is a copy of the Inspection Report. Regulation at 20 AAC 25.265 in conjunction vvith Conservation Order 348 requires all wells in the Kuparuk River tìeld to be equipped with a C0f11111issíon approved fail-safe autolllatic surtàce SYS capable of preventing uncontrolled now by shutting off flo\v at the wellhead and shutting down any artifìciallift system where an overpressure of equipment nlay occur. If installed, a subsurface safety valve nlust be maintained in working order and is subject to performance testing as part of the SVS. An SVS COlllpOnent failure rate of 11.1 percent was identiíied during the above-noted inspection. COillmission test interval requirements provide that the testing frequency will be increased when a failure rate exceeds 10 percent. Effective October 7, 2005 and until an acceptable level ofperfonnance is achieved, the safety valve systems associated 'with wells located on KRU 2X nlust be tested every 90 days. When testing is scheduled, you must notify the Commission Field Inspector (907-659-2714) at least 24 hours in advance to provide an opportunity to witness the SVS test. Sincerely, ,,/ .......~... '----y ~ ;~;:,~jZ~ ~~i( Petroleum Inspection Supervisor Attachment '. ..,....------ cc: AOGCC Inspectors SGANNEL NO\f 1 '1 2005 ,. . Safety Valve & Well Pressures Test Report Reviewed By: P.I. Suprv Comm Pad: KHU_2X Jnsp Dt J 0/7/2005 Inspected by John Spaulding Interval 90 Days InspNo svsJS05J 0072 1364J Field Name KUPARUK RIVER Operator CONOCOPHILLIPS ALASKA TNC Operator Rep Nob]e Related Insp; Reason 180-Day Src: Inspector Well Permit Separ Set LIP Test Test Test Date SI Oil,WAG,GfNJ, Inner Outer Tubing Number Numuer PSI PSJ Trip Code Code Code GAS,CYCLE, SI PSI PSI PSI Yes/No YeslNo '1_ 2X-09 --is-41620 '-96 r-7Ò 60 P --'----4 -1- j r---I-OII=--- -(1200 ¡ 900 -----200------ Yes ! No r---- 2X-JU 184/630 ¡--96 -1-70 60 P P ¡-- r-- ----!-J-OIL---l-iT5ü--r---¿-OO ISO Y;s~---I No 2X- j ]84 -I64() - -;-96 1--70 70 p put --l -t- I :õll~ --I--1250--i- 1200 150 Yes -1- Yes ~~::~ ::::~;~. ~: ¡ ~~ ~~ I ~ :: lTT- ::~;;u:~~~_ - ;~~ :~~ ~::j~:-T ________n ----- -- -I- - - -- ----- - ------ i j-- -__._____ -- ____ ------ i~::~ - '-':::Hi~j~jiL . ~~. j --f; i _ t:~6¡~+u:j;~ 19~:ou~~~ _ ~:: 2X-17 1951710 96 I 70 65 P P ¡¡I-OIL 1000 600 200 2X-I8 __I?Si6Qg____ ~6-1 ~Q- 60___P___ ~p---_ -=-J=-~_ -=_I~_.]~OI~__~~_-122-L__~~~Of£~=__= 20~-I Yes - -- ----~- - No retested tripped at 65psi ok --I--N~-- ---- ---- -------- t --N~---u-I- ---- _~________.J_____ ____ _ u_u________ _ _________ -___~___~~_1__ __ ______________ ,-( ---- ~-=J ¡ --1 , J Yes CO/lllllents Performance - ------" -~. ---- 2 Failu;~-R~te--U--I ! i I 11.11% ___,__~~__._ u___ 2-12a wing Iclikcd -lIn<Jhle 10 test, requested repairs prior 10 testing again Wells Components 9 18 -.--- - -- -. Failures ,~ ( ~, U' - -¥ p If-<-.!" t Wtdllcsday, Novt:ll1bcr OC), 2005 , ) ) AI,ASIiA. ORAND GAS CONSERVATION COMMISSION ¡ / October 25,2004 ç;~,,...t 11 ~r=-;J ~~-e~ T @ ~ @ ~~~ f6\ @ -- JL.. ,1 ~ J W~~j~~'ùW FRANK H. MURKOWSKI, GOVERNOR 333 W. "JTH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mr. Mike Wheatall Operations Manager ConocoPhillips Alaska, Inc. P. O. Box 100360 J\nchorage,A}( 99510-0360 Dear Mr. Wheatall: The Alaska Oil and Gas Conservation Commission ("Commission") performed an inspection of your well safety valve system (SVS) at~1.î,.~;R.:i"erl.Jllit2X("KRl.J 2X") pad on October 15, 2004. Attached is a copy of the InspecfionReport. Regulation at 20 AAC 25.265 requires all wells to be equipped with a Commission approved fail-safe automatic surface SVS capable of preventing uncontrolled flow by shutting off flow at the wellhead and shutting down any artificial lift system where an overpressure of equipment may occur. If installed, a subsurface safety valve must be maintained in working order and is subject to performance testing as part of the SVS. An SVS component failure rate of 12.5 percent was identified during the above-noted inspection. Commission policy, as outlined in a letter dated November 14, 1995, states that the testing frequency will be increased when a failure rate exceeds 10 percent. The AOGCC-AOGA Safety Valve System Task Force report issued June 13, 2003, supported retention of the 10% failure thresho ld. . Also noted during the Commission's inspection were unsupported flow piping and pilots on KRl.J 2X pad, specifically Wells 2X-03 and 2X-09. These were not included in the failure rate calculation but clearly are deficiencies in the SVS that must be corrected. Effective October 15, 2004, and until an acceptable level of performance is achieved, the safety valve systems associated with wells located on KRU 2X must be tested every 90 days. When testing is sched ed, you must notify the Commission Field Inspector at 907-659-2714 to provide ~ortu' 0 witness the SVS test. I" ~ Sincerely, '- ~Ji. Nonnan Chairman 0.%¿/ o~ Daniel T. Seamount, Jr. Commissioner Attach. copy by email: Bob Fleckenstein; AOGCC Inspectors SCANNEÖ No\r 0 4 I:OOi~ Safety Valve & Well Pressures Test Report Reviewed By: P.I. Suprv..:J:ߣ- \Ð Z5lù4- Comm Pad: KRU_2X Insp Dt 10/15/200 Inspected by Jeff Jones Interval 90 Days InspNo svsJJ041019163228 Field Name KUP ARUK RIVER Operator CONOCOPHILLIPS ALASKA INC Operator Rep Bob Noble Related Insp: Reason ISO-Day Src: Inspector Well Permit Separ Set UP Test Test Test Date SI Oil,WAG,GINJ, Inner Outer Number Number PSI PSI Trip Code Code Code GAS,CYCLE, SI PSI PSI YeslNo Y eslNo 2X-03 1831090 I 2700 I 2000 1900 I P I P I W AGIN Flow piping & pilot not supported properly; loose & wobbly. 2X~08 1831140 2700 2000 1750 P P W AGIN 2X -09 1841620 98 70 50 P P I-OIL Flow piping & pilot not supported properly; loose & wobbly. 2X-IO 1841630 98 70 60 P P I-OIL ~ 2X~11 1841640 98 70 65 P 4 I-OIL 750 900 175 No Yes IA x OA communication 2X-12A 1951760 98 70 65 P P I-OIL wing valve leaks. 2X~13 1841740 98 70 44 3 P I-OIL 2X~14 1841750 98 70 75 P P I-OIL 2X.IS 1841760 98 70 55 P 7 I-OIL wing & pit valves leak. 2X.16 1841720 98 70 52 P P I-OIL 2X.17 1951710 98 70 50 P P I-OIL 2X-18 1951600 98 70 55 P P I-OIL Comments Performance The SSV on weIl2X.II failed the pressure test & will require repair. The pilot on we1l2X-13 tripped Wells Components Failures Failure Rate low & was cycled & passed a re-test. Both the wing and pit valves leaked on we1l2X-15 and the SSV could not be tested. I inspected 12 well houses. 12 24 3 12.5% '-" Monday, October 25, 2004 MEMORANDUM TO: Julie Heusser, Commissioner THRU:. Tom Maunder, P. I. Supervisor State of Alaska Alaska Oil and Gas Conservation Commission DATE: FROM: Chuck $cheve; SUBJECT: Petroleum Inspector January 25, 2001 Safety Valve Tests Kuparuk River Unit 2X Pad Thursday, January 25, 2001: I traveled to. the Kuparuk River Field. and witnessed the 90-day retest of the safety valve systems on 2X Pad. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 12 wells and 24 components with one failure observed. The Surface Safety Valve on. Well 2X-14 had a slow leak when pressure tested. This valve was serviced and I witneSsed a .successful retest on 1-26-01. Earnie. Barndt conducted the testing today he 'demonstrated good test procedure and was a pleasure to work with All the wellhouses entered at this location were clean and all related equipment appeared to be in good. condition. Summary: Field. I witnessed the 90,day SVS testing at 2X Pad in the Kuparuk River KRU 2X Pad, 12 wells, 24 components, 1 failure 4.1% failure rate 15 wellhOuse inspections Attachment: SVS KRU 2X Pad 1-25-01 CS Unclassified Confidential (Unclassified if doc. Removed) SVS KRU 2X Pad 1-25-01 CS.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: p ',,hiJl~s Operator Rep: Eamie Bamdt AOGCC Rep:, Chuck Scheve Submitted By: Chuck Scheve Date: Field/Un. ad: Kuparuk / KRU / 2X Pad Separator psi: LPS, 99. HPS i I II Well Permit Separ Set L/P Test Test Test Date on, WAG, Number Number psi PSI Trip. Co, de Code Code Passed ~or, C~O_~ 2X-01 1830840 " 2X'~J2' '18~31030 3750 "2000 1800 P "'P' WAG 2X-03 1831090 2X-04 ' 1831180 3750 2000 2000 p ,, P , .. ,, ' .WAG 2X.05 . 1831070: , 2X-06 1831100 2X-07 ' 183i130 375~0 · '2000 2000 P" P ~ '. WAG · i , i i i i i 2X-08 1831146 ..... · ' 2X-09 1841620 99 60 60 P P OIL 2X-10 1841630. ,. . 2X-11 ' 184'1640 ' 99 60 50 P P OI~ 2X'12A · 1951760! 9'~ '~ 60. ' 5~5 "' 'P P ' ' ' OIL 2X-13. .,, .184.1740 , 99i 60 55 P , P : 0IL, 2X-i4 1841750 ':99. 60 · 55 . P 4 1/26/01 OIL 2X-15 1841760 ' 99 . · 60 55 P P ' OII~ 2X-16 "1841720 ' 99 60 55 P P · OIL 2X-17' ,~i,,:::':', 99 60 ' 60 i P ' ' P ' , OIL 2X-1. 8 1951600 99 60 66 P P OILg 2X-19 '19~1750 '" " ..... "- . , Wells: 12 Components: 24 Failures: 1 Failure Rate: 4.17% [3 90 Day Remarks: S .ur_fa ,ce Safet~ on well 2X-14 had ve.~, .slo~ le, ~ak w,,hen pres .su. re, test,ed, y, alve to be serviced and retested by,operator. , RJF.I/16/01 Page 1 ofl SVS KRU 2X Pad 1-25-01 CS.xls MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount, Commissioner DATE: July 22, 2000 THRU: Blair Wondzell, ~ SUBJECT: P. I. Supervisor FROM: John H Spauldin¢ ~'~--~ Petroleum Inspector SVS Tests Pads 1E & 2X Kuparuk River Unit Kuparuk River Field July 22~ 2000: I traveled to Philips Alaska Inc.'s Kuparuk Field to witness the SVS Tests on 1E and 2X pads. The AOGCC form is attached for reference. As noted on the test reports a minimal amount of failures were observed (1 on each pad). Ernie Barndt the PAl representative and his helper did an excellent job of testing. SUMMARY: I witnessed the SVS tests on: PAl, KRU, 1E & 1X 1E - 8 wells, 16 components, 1 failure,-9 % failure rate, 12 well house insp. 2~X-~-. ~tOwells~20 compnents. 1 failure,-5 % failure rate. 12 well house insp. Attachment: Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: ,,Phillips Alaska Inc Operator Rep: E. Bamdt AOGCC Rep: John H. Spaulding Submitted By: John H. Spauld Date: Field/Unit/Pad: Kupamk/Kuparuk R. U./1 Separator psi: LPS 91 HPS 7/22/00 Well Permit Separ Set L/P Test Test Test Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code GAS or CYCLE 1E-02 1800500~ 91 70 65 P P OIL ,, 1E-03 18005601 SI ,., 1E-05 1800580 1E-06 1800780 SI 1E-07 1800800 91 60 55 P P OIL . 1 E- 10 1820360 ,. 1E-11 1820510 .., 1 E- 12 1820600 SI 1E-14 1820790 1E-18 1830160 91 60 46 P P OIL 1E-19 · 1830170 1E-20 1830050 91 60 48 P P OIL 1E-21 1830020 . 1E-23 1821840 ~ 1E-24A 197'1870 91 70 70 P P OIL 1E-26 1821660 SI 1E-28 1821580 SI 1E-29 1821540 SI 1E-31 1971380 91 70 70 P P OIL 1E-33 1971510 1E-34 .1971660 91 70 70 P P OIL 1E-36 1982130 91 70 70 P P OILI ,, Wells: 8 Components: 16 1 Failure Rate: 9.0% [Z] 90 r)av Remarks: 8/7/00 Page 1 of 1 svs kupamk kru 1 e 7-22-00js.xls Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Inc Submitted By: John Spaulding Date: 22-Jul Operator Rep: E. Bamdt Field/Unit/Pad: Kupanak/Kupamk R./2X AOGCC Rep: John H. Spaulding Separator psi: LPS 96 HPS Well Permit Separ Set L/P Test Test Test Oil, WAG, GIN& Number Number PSI PSI Trip Code Code Code GAS or CYCLE 2X-01 1830840 2X-02 1831030 2X-03 1831090 2X-04 1831180 3000 2000 2000 P P WAG 2X-05 1831070, 3000 2000 2000 P 4 WAG 2X-06 1'831100 3000: 2000 2000 p P WAG 2X-07 1831130 3500 2000~ 2000 p P WAG 2X-08 1831140 2X-09 184.1620! 96 70 60 p P OIL 2X-10 1841630 96 70 65 p P OIL 2X-11 1'841640 96 60 60 p p OIL 2X-12A 1951760 2X-13 1841740 2X- 14 1841750 2X-15 1841760 96 70 70 p p OIL 2X- 16 1841720 !~ 1.951710. 96 60 50 P p .~ OIL 2X-18 · 195.1600 .. 96 60 5'0 e p OIL 2X-19 1951750 Wells: 10 20 Failures: 1 Failure Rate: 5.0% [] 90 ray Remarks: 8/15/00 Page 1 of 1 svs kuparuk kru 2x 7-22-00j s.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown _ Stimulate_ Plugging _ Perforate __X Pull tubing _ Alter casing _ Repair well _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum of elavation (DF or KB feet): ARCO Alaska, Inc. Development X. 41' RKE 3. Address: Exploratory __, 7. Unit or Property: P.O. Box 100360 Stratagrapic Anchorage, AK 99510-0360 Service _~ Kuparuk River Unit 4. Location of well at surface: 8. Well number: 689' FSL, 240' FEL, Sec 4, T11N, R9E, UM 2X-17 At top of productive interval: 9. Permit number/approval number: 2540' FSL, 2640' FEL, Sec 3, T11N, R9E, UM 95-171 At effective depth: 10. APl number: 2601' FNL, 2377' FEL, Sec 3, T11N, R9E, UM 50-029-22616-00 At total depth: 11. Field/Pool: 2595' FNL, 2358' FEL, Sec 3, T11N, R9E, UM Kuparuk River Field / Oil Pool 12. Present well condition summary Total Depth: measured 7715 feet Plugs (measured) None true vertical 6455 feet Effective Deptt measured 7651 feet Junk(measured) None true vertical 6396 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 16" 235 Sx AS I 121' 121' Surface 3780' 7-5/8" 600 Sx AS III & 3821' 3356' 340 Sx Class G Production 6861' 5-1/2" 110 Sx Class G 6897' 5750' Liner 1098' 3-1/2" 37 Bbls Class G 6617'-7715 5530'-6455 Perforation Depth measured 7045'-7124'; 7150'-7175'; 7380'-7410' true vertical 5869'-5934'; 5956'-5977'; 6152'-6178 Tubing (size, grade, and measured depth) 3.5", 9.3 Ib/ft, L-80 @ 6596' Packers and SSSV (type and measured depth) Packer: Baker SABL-3 @ 6532' & Baker SABL-3 @ 6617' SSSV: Camco BP-61 @ 1816' 13. Stimulation or cement squeeze summary . "ORIGINAL Perforate 'C' sands on 6/17/98. Intervals treated (measured) 7150'-7175' Treatment description including volumes used and final pressure Perforated well w/2.5" gun HC w/DP charges at 4 spf, fp was 1000 psi. 14. Representitive Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 90 192 1132 1284 163 Subsequent to operation 215 366 2348 1310 166 15. Attachments MIT form 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations _~ Oil _X Gas _ Suspended _ Service 17. I hereby ce.rtify that the foregoing is true and correct to the best of my knowledge. Signed ~~~ Title: Production Engineering Supervisor Date Form 10-404 Rev ~]~1 ~i/88 .q~ IRIk41T IlXl I~I"IPl l~"'flTl~ .,aska, Inc. KUPARUK RIVER UNIT .~liil~ (' (~ .JELL SERVICE REPORT ~1~ 2X-17(4-1)) WELL JOB SCOPE JOB NUMBER 2X-17 PERFORATE, PERF SUPPORT 0313981009.4 UNIT NUMBER DATE 06/17/98 DAY 3 FIELD ESTIMATE DAILY WORK ADD NEW PERFORATIONS OPERATION COMPLETE I SUCCESSFUL I~ Yes O No I ~'~ Yes O No AFC# ICC# I DAILY COST KAWWRK 230DS28XL $11,380 InitiaITbg I FinalTbg I Initial IA I 1000PSII 1000PSII 750 PSI I IKEY PERSON SWS-JOHNSON ACCUM COST $29,162 Final IA I Initial OA IFinal OA ITTL Size 1400 PSI 0 PSI 0 PSII 0.000 " SUPERVISOR SCHWENDERMAN Signed IMin ID I Depth 0.000" 0 FT DAILY SUMMARY RAN 2-1/2" HC/DP/4SPF/180 DEG PHASING 90 DEG F/LOW SIDE. PERFORATE 25' F/7150'- 7175'. [Perf] I TIME LOG ENTRY 07:30 MIRU SWS (JOHNSON AND CREW) TGSM JOB OVERVIEW. MU PERF GUN ASSEMBLY #1 20' 2-1/2" HC/DP/4SPF/180 DEG PHASING (PERF GUN/CCL/SWIVEL/HEAD) TL=25' PT 3500 PSI. 09:15 RIH TO 7330' RKB LOG UP AND TIE IN W/SCHLUMBERGER CBL SLT-J (DATED 4/11/1996. PERFORATE 3-1/2" LINER F/7175' -7155' (20'). GOOD SURFACE INDICATIONS. POH. GUN PULLED TIGHT AT 7125' ACCROSS OLD PERFS. ONCE PAST 7100' PULLED SMOOTH. 11:00 AT SURFACE RD ALL SHOTS FIRED. MU PERF GUN #2, 5' LOADED SAME AS ABOVE. RIH TO 7330' RKB LOG UP AND TIE IN AND PERFORATE 5' F/7150' TO 7155'. HAD GOOD SURFACE INDICATIONS. POH NO RESTRICTIONS. 15:00 AT SURFACE RD. ALL SHOTS FIRED. RETURN WELL TO DSO TO BRING WELL ON. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $84.00 APC $200.00 $6,700.00 DIESEL $0.00 $126.00 DOWELL $0.00 $7,800.00 HALLIBURTON $0.00 $1,712.59 LITTLE RED $0.00 $1,560.00 SCHLUMBERGER $11,180.00 $11,~ 80.00 TOTAL FIELD ESTIMATE $11,380.00 $29,162.59 ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May 19, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2X- 17 (Permit No. 95-171) Memo to File Dear Mr. Commissioner: Pursuant to our telephone conversation today, we are submitting this memo to the file on KRU 2X- 17 to correct an error on the completion report. The original well plan called for running the ARC5 resistivity tool across the Kuparuk interval. However, due to severe lost circulation, the well had to be topset above the Kupamk interval and later drilled out with 4-3/4" hole. Resistivity/LWD tools are not available which are capable of being run into a 4-3/4" hole. Therefore, no resistivity logs were run. Sorry for any inconvenience this may have cauged. If there are any questions, please call 263-4622. Sincerely, W. S. Isaacson Drilling Engineer Kupamk Drill Site Development WSI/skad PERMIT DATA 95-171 CBL 95-171 DIR SURV 95-171 PROD PROF AOGCC Individual Well Geological Materials Inventory T DATA PLUS ~SEPIA Page: 1 Date: 04/20/98 RUN RECVD 04/26/96 06/03/96 FINAL 10/07/96 T ~o-4o? ~O~ZT~O~ ~TZ ~///~/~/ DAILY WELL OPS R /1/ ~/~ TO ~/3:~/~/ Are dry ditch samples required? yes ~__~.And received? Was the well cored? yes ~Analysis & description received? Are well tests required? yes n~ .... Received? ~ Well is in compliance Initial COMMENTS STATE OF ALASKA ( .... ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown m Pull tubing Alter casing Stimulate Plugging Perforate X Repair well Other ~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 689' FSL, 240' FEL, Sec. 4, T11N, R9E, UM At top of productive interval 2540' FSL, 2640' FEL, Sec. 3, T11N, At effective depth 2601' FNL, 2377' FEL, Sec. 3, T11N, At total depth 2595' FNL, 2358' FEL, Sec. 3, T11N, 12. Present well condition summary Total Depth: measured true vertical R9E, UM R9E, UM R9E, UM 771 5 feet 6441 feet 6. Datum elevation (DF or KB) RKB 41 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2X-17 9. Permit number/approval number 95-171 10. APl number 5o-029-22616-00 11. Field/Pool Kuparuk River Field/Oil Pool Plugs (measured) None Effective depth: measured 7 6 5 1 true vertical 5 6 7 7 feet feet Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 16" 3780' 7-5/8" 6861' 1098' measured 7100'-7108', true vertical 5921 '-5928', Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., L-80 @ 6617' Cemented 235 Sx AS I 600 Sx AS III & 340 Sx Class G 110 Sx Class G 37 BBLs Class G 7045'-7124', 7380'-7410' 5873'-5934', 6163'-6189' Measured depth 121' 3821' 6897' 7715' True vertical depth 121' 3356' 5750' 6441' ORIGINAL Packers and SSSV (type and measured depth) Pkr's: Baker SABL-3's @ 6532' & 6617'; SSSV: None, nipple @ 1816' 13. Stimulation or cement squeeze summary Perforate "C" sands on 3/27/97. Intervals treated (measured) 7090'-7124' Treatment description including volumes used and final pressure Perforated using 2-1/8" EJ guns w/ DP charges, 4 SPF, fp = 950 psi. 14. Representative Dailv Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Alaska Oil & 6as Cons, Commis~, Anchorage Tubing Pressure Prior to well operation I 1 3 54 932 1266 158 Subsequent to operation 2 5 0 185 1107 1273 155 15. Attachments Copies of Logs and Surveys run m Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. Form 10-)~)~ I~ev/0~/l~ ~ / I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Wells Superintendent Date ~ --Y'--77 SUBMIT IN DUPLICATE Alaska, Inc. KUPARUK RIVER UNIT ,~' WELL SERVICE REPORT ~' K1(2X-17(W4-6)) WELL JOB SCOPE JOB NUMBER 2X-17 PERFORATE, PERF SUPPORT 0303972121.6 ,,,, DATE DAILY WORK UNIT NUMBER 03/27/97 PERFORATE "C" SANDS UNIT #1 DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR I (~) Yes (~ ~oI ® Yes ~ No SWS-M. BAILEY e~ FIELD AFC.4f CC.~ DAILY COST ACCUM COST 'g ESTIMATE KAVVWRK 230DS28XL $15,225 $17,332 Initial Tb.~ Press Final Tb.q Press Initial Inner Ann Final Inner Ann I Initial Out Outer Ann 850 PSI 950 PSI 900 PSI 900 PSII 0 PSII 0 PSI DAILY SUMMARY (4 SPF TOTAL). PERFORATED "C" SANDS F/7090 - 7124' ELM W/2-1/8" EJ DP CHARGES @ 2 SPF +90 DEG & 2 SPF -90 DEG F/LOW SIDE OF HOLE TIME 08:00 11:00 LOG ENTRY MIRU SWS (M. BAILEY & CREW) & LRS. SI WELL & FREEZE PROTECT FLOWLINE & TUBING. MU GUN ASSY #1 (2-1/8" EJ/CCL/GR) TL-26'. PT BOPE TO 4000 PSI. TGSM - JOB OVERVIEW / WEATHER RIH W/GUN ASSY #1 TO 7200' ELM. TIE IN W/4-11-96 SWS CBL/SLTJ. PERFORATE F/7107 - 7124' ELM W/2-1/8" EJ DP GUNS. NO INDICATION @ SURFACE. POOH. 12:45 AT SURFACE, ALL GUNS'FIRED. MU GUN ASSY #2 (SAME AS BEFORE W/90 DEG F/1ST RUN). RIH TO 7200' ELM & TIE IN. PERFORATE F/7107- 7124. SMALL INDICATION @ SURFACE. 15:15 POOH W/GUN ASSY #2, ALL GUNS FIRED. MU GUN ASSY #3 (SAME AS BEFORE). RIH TO 7200' ELM &TIE IN. PERFORATE F/7090 - 7107' ELM. NO INDICATION @ SURFACE. 17:30 POOH W/GUN ASSY #3, ALL SHOTS FIRED. MU GUN ASSY #4 (SAME AS BEFORE W/90 DEG F/LAST RUN). RIH TO 7200' ELM & TIE IN. PERFORATE F/7090 - 7107' ELM. 19:30 POOH W/GUN ASSY #4, ALL SHOTS FIRED. RD SWS. PROBLEM REMOVING FUSIBLE. 22:30 OFF LOCATION. TURN OVER TO PRODUCTION. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $o.oo $5o.oo APC $750.00 $750.00 ARCO $300.00 $300.00 ,,,, HALLIBURTON $0.00 $1,058.00 , LITTLE RED $660.00 $1,660.00 SCHLUMBERGER $13,515.00 $13,515.00 TOTAL FIELD ESTIMATE $15,225.00 $17,333.00 ..... 10/3/96 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10437 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Kuparuk (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia Floppy Disk 1Q-2A c~ ~--_ I~jH CBT 960806 I 1 1 Y- 13 ~ ~ - (~ ~ ~- INJECTION PROFILE 96 082 0 I 1 1 Y- 25 '~ <~ - O %~ PRODUCTION PROFILE .W/DEFT 96 0821 I 1 2X.12A c~_ I"}~o GAS LIFT SURVEY 960810 I 1 2 X- 17 c~ ~- - I -I [ PRODUCTION PROFILE 96 081 0 I 1 3A-la c~.~ _ t.~--~j USlT 960907 I 1 3A-18 ~5- CBT 960907 I 1 3G.25X C~(~ - I~ CBT 960809 I I SIGNED::~ Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. RECEIVED ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 20,1996 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2X-17 (Permit No. 95-171) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 2X-17. If there are any questions, please call 263-4622. Sincerely, W. Isaacson Drilling Engineer Kuparuk Drill Site Development WSI/skad RECEIVED JUN 2 1 1996 Alaska 0il & Gas Cons. commission Anchorago ALL STATE OF ALASKA ~v 6KA OIL AND GAS CONSERVATION CO ,,SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well OIL F~ GAS I--! SUSPENDED F--1 ABANDONEI~ SERVICE F--I 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 95-171 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360f,,,, , , ~..~- 50-029-22616 689' FSL, 240' FEL, Sec. 4, T11 N, ROE, UM ~ .~/~~A~TF~,1 ~ Kuparuk River Unit At Top Produci.g,nterva, i' . l '"' 10 We,, Number At lotal Dopth ~.~...._~._~j 11 Fiold and Pool 2595' FNL, 2358' FEL, Sec. 3, T11 N, ROE, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. RKB 41', Pad 77'I ADL 25645 ALK 2576 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 116 No. of Completions 05-Nov-95 11 -Mar-96 16-Apr-96 (perf'd) NA feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directionalr~ Survey~ 20 Depth where SSSV set 21 Thickness of permafrost 7700' MD & 6441' TVD 6808' MD & 5677' TVD YES ~ NO ~ NA feet MD = 1380' ss APPROX 22 Type Electric or Other Logs Run ARC5/GR, GR/CCL/SLT-J 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT GRADE TOP BTM HOLE SIZE CEMENT RECOF~ 16" 62.58# H-40 SURF. 121' 24" 235 sx AS I 7.625" 29.7# L-80 SURF. 3821' 9.875" 600 sx AS III Lead, 340 sx Class G Tail 5.5" 15.5# L-80 SURF. 6897' 6.75" :110 sx Class G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET {MD) PACKER SET (MD) 3.5" 8851' 8829' 7380'-7410' MD 4spf 6163'-6189'TVD 7045'-7090' MD 4 spf 5873'-5912'TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 7100'-7108' MD 4 spf 5921'-5928' TVD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7380'-7410' 200,372# behind pipe with 14 ppa of #10/14 at perfs. Left 726# in wellbore. (15579# 20/40, 168628# 12/18, and 16891# of #10/14) 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) Apr-96I FLOWING DateofTest Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 6/7/96 5.8 TEST PERIOD I~ 1 34 140 188 176I 1043 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 151 1000 24-HOUR RATE I~ 553 577 776 =24° 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. " RIGINAL RECEIVED JUN 2 1 1996 Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Alaska 0;i & Gas Coi~s..Co~,~IS~ . ,~uDmI! inQupllcate Anchorage 30. GEOLOGIC MAI:~ERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7045' 5868' Bottom Kuparuk C 7176' 5976' Top Kuparuk A 7335' 6113' Bottom Kuparuk A 7485' 6244' RECEIVED JUN 2 1 1996 Alaska 011 & 6as Cons. Commission Anchorage FREEZE PROTECT 5.5" x 7-5/8" ANNULUS 31. LIST OF A'I-rACHMENTS Daily Drilling History, Directional Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed 7..J'~ ~o ~,.~.~._~_ Title ~,t,t~l~t~ '~l,t~t(~, DATE INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 DAILY: 03/02/95 (9) TD: 7151'(239') SUPV:MBM/ACB DAILY: 03/03/96 ( 10) TD: 7181'( 30') SUPV:MBM/ACB DAILY: 03/04/96 (11) TD: 7181'( 0) SUPV:MBM/ACB DAILY: 03/05/96 (12) TD: 7181'( 0) SUPV:MBM/ACB DAILY: 03/06/96 (13) TD: 7181'( 0) SUPV:MBM/ACB 03/07/96 (14) TD: 7181' ( 0) SUPV:GTG/Hupp DAILY: 03/08/96 (15) TD: 7375'(194') SUPV:GTG/Hupp DAILY: 03/09/96 (16) TD: 7700'(325') SUPV:GTG/Hupp DAILY: RIH W/ BHA #2, tag @ 6795' ctm, Drill cement to 6900' SD, check SITCP and establish SPP. $43,956 CUM: $200,782 MW: 11.1 PV/YP: 14/72 APIWL: 2.6 LD BHA #1 Drill out shoe to 6909'.LOT @ 12.7% EMW. Drill to 7151. Bit trip (23 hrs on tri-cone) SET INJECTOR ON DECK AND LD BHA #2 $32,011 CUM: $228,124 MW: 10 PV/YP: 11/58 APIWL: 4.4 CALL FOR DIESEL LD BHA #2. MU & RIH W/BHA #3. Drill frkom 7151' to 7181', Stuck pipe 5' off bttm, start centrifuge to lower mud wt. Mud wt. @ 9.7 ppf (2930 psi) No flow $29,794 CUM: $258,078 MW: 9.6 PV/YP: 10/78 APIWL: 4.4 CIRCULATE Free pipe by circulating diesel and lowering BHP to +/-2800psi. POH/ C/O BHA.RIH.Stuck pipe 50' out shoe and bridged off in casing above 5000' Pulled free and resume circulating. Make cleanout pass to 1500' while raising viscosity to 85,00 LSRV. Trip to btttm, note washout, POH. Hole in coil @ 6400'. $30,114 CUM: $288,192 MW: 9.8 PV/YP: 11/76 APIWL: 4.4 POH & LD BHA Note washout on bttm, POH, hole in coil @ 6400'.RD CTU to weld pipe. WEll started to flow, stab safety calve and close annular. Call out CTU, SI WHP 160# after 7 hrs.RU CTU #2, RIH to 6750',and circulate w/9.55# mud. No gas or oil returns. SD -no flow. Circulate and wt up to 9.8ppg. POH and LD BHA. $28,692 CUM: $316,884 MW: 0.0 NO REPORT AVAILABLE PV/YP: 0/ 0 APIWL: 0.0 MW: 9.8 PV/YP: 11/76 APIWL: 4.4 RIH RIG on standby waiting on coil.Pump ball thru coil.Test BOPS.Dispaced coil to mud. PU BHA #5 & RIH. $31,270 CUM: $381,320 MW: 9.9 PV/YP: 13/101 APIWL: 4.4 DRILLING PU BHA #5 & RIH circulating @ 3.5-4.0 bpm. Reamed dn to 7181'. DRid to 7375'.Short tripped every 50 ft. $30,364 CUM: $412,184 MW: 9.9 PV/YP: 15/97 APIWL: 4.6 POH TO RUN LOGS Drilled to 7375'.Pooh for bit.RIH. Drilled from 7375'to 7700' short tripped every 50-75'.POH to run OH logs. $39,124 CUM: $451,308 RECEIVED JUN 2 1 1996 Alaska 011 & Gas Cons. Commission Anchorage 03/10/96 (17) TD: 7700' ( 0) SUPV: GTG/HUPP DAILY: MW: 10 PV/YP: 13/100 APIWL: 4.8 CIRCULATED ON BOTTOM TO THIN MUD POH.MADE 2 ATTEMPTS TO RUN GR/DIL.STOPPED 10' OUT OF SHOE @ 6895' ELM.MADE CLEAN OUT TRIP. RU SWS. MADE 3RD UNSUCCESSFUL CR/DIL ATTEMPT.RD SWS. RAN 35 JTS 3.5" BTC MOD LINER TO 7700'. $50,808 CUM: $502,116 03/11/96 (18) TD: 7700'( 0) SUPV:GTG/Hupp DAILY: MW: 10.0 PV/YP: 13/100 APIWL: 4.8 SHUT IN WELLAND MONITOR WHP BUILD-UP Circulated OH vol. Released f/liner. Cemented liner w/22 bbls 15.8 ppg cement. Circ out contaminated mud. POH. L/D liner tools. Welded on coil conn. RIH. Jetted out liner. POH. Cleaned pits & turned well over to seawater. Pt'd wellbore -> leaking. $53,600 CUM: $590,076 03/12/96 (19) TD: 7700' ( 0) SUPV:HUPP/REEM DAILY: MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 LOADING 3.5" TBG MONITOR WH PRESSURE:380 PSI W/8.34 PPG SW.TEST LNR W/SEAL ASSY. PT'D TO 2500 PSI OK.LEAK IS @ LINER LAP. LOADED WELL W/10 PPG BRINE. WELL IS DEAD. RD CTU. MOVING IN PIPE SHED AND LOADING 3-1/2"TBG. $42,371 CUM: $632,447 03/13/96 (20) TD: 7700'( 0) SUPV:MBM/REEM DAILY: MW: 0.0 PV/YP: 0/ 0 PREP TO RUN SSSV MOVED IN PIPE SHED. LOADED 3-1/2" COMPLETION. $25,624 CUM: $658,089 APIWL: 0.0 03/14/96 (21) TD: 7700'( 0) SUPV:MBM/REEM DAILY: MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 PREP TO NU TREE FINISHED RUNNING 3-1/2" COMPLETION, SET & TESTED PACKER, CIRC'D OUT t0 PPG BRINE WITH SEAWATER, FP'D W/DIESEL, SET DPV, ND BOPS. NU TREE. $20,128 CUM: $663,236 03/15/96 (22) TD: 7700'( 0) SUPV:MBM/REEM DAILY: MW: 0.0 PV/YP: 0/ 0 APIWL: 0.0 RIG RELEASED NIPPLE UP TUBING HEAD AND TREE. TEST SEALS AND TREE TO 5000 PSI. TIG DONW AND RELEASE RIG. $20,128 CUM: $663,236 End of WellSummary for Well:AK8341 RECEIVED JUN ? I ~996 Alaska Oil & G~s Ceos CommIssion Anchom§e ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(2X-17(W4-6)) WELL JOB SCOPE 2X-17 PERFORATE, PERF SUPPORT DATE 04/1 6/96 DAY 2 DAILY WORK PERFORATE A SAND OPERATION COMPLETE I SUCCESSFUL I KEY PERSON YES YES SWS-BAILEY IJOB NUMBER 0322961455.2 UNIT NUMBER SUPERVISOR GOLDEN DAILY SUMMARY I CW F/THE HIGH SIDE OF THE HOLE. HAD TO PULL 1400-1500# ABOVE NORMAL WEIGHT TO FREE BOTH GUNS AFTER FIRING. PERFORATED A SAND F/7380'-7410' WITH 2-1/2" HOLLOW CARRIER (BIG HOLE CHARGES), 4 SPF, 180 DEG PHASING, 47 DEG ,,, TIME LOG ENTRY 09:00 MIRU SWS. TGSM: DANGER AROUND WELLHEAD BARRIER. 10:00 10:50 11:45 12:30 14:30 15:30 PT LUBRICATOR TO 3000 PSI -GOOD. RIH W/WB, GR, CCL, MPD, 10'-2 1/2" HOLLOW CARRIER (4 SPF, 180 DEG PHASING, 47 DEG CW F/HIGH SIDE OF HOLE). TIED INTO CBL DATED 4/11/96.WHP (BEFORE) = 460 PSI, PERFORATED 7400'-7410', WHP (AFTER)=370 PSI.GUN STUCK. BLED WHP TO 0 PSI-UNABLE TO PULL FREE. WHP REMAINED AT 0 PSI.PRESSURED UP TBG TO 1000 PSI-UNABLE TO PULL FREE.BLED WHP TO 0 PSI-UNABLE TO PULL FREE. WELL IS NOT TAKING FLUID OR BUILDING PRESSURE. MIRU APC DHP.PRESSURED WHP TO 1500 PSI-UNABLE TO PULL FREE. BLED WHP TO 0 PSI-UNABLE TO PULL FREE.PRESSURED WHP TO 2000 PSI-UNABLE TO PULL FREE. BLED WHP TO 0 PSI-UNABLE TO PULL FREE. PRESSURED WHP TO 2300 PSI-ABLE TO ESTABLISH 0.5 BPM INJECTION.BLED WHP TO 0 PSI-UNABLE TO PULL FREE. DISPLACED WELL WITH 70 BBLS OF DIESEL AT 2250 PSI, 2.5 BPM. BLED WHP TO 200 PSI-UNABLE TO PULL FREE. WHP WILLNOW BUILD WHEN BLEEDING IS STOPPEDBEGAN INCREASING TENSION IN 200# INCREMENT, PULLED FREE AT 2900# 11400# ABOVE THE NORMAL WEIGHT OF 1500#). POOH. OOH W/GUN #1-ALL SHOTS FIRED. OD OF GUN #1 AFTER FIRING = 2.50" (PERFORATION BURRS SLIGHTLY LARGER 2.6-2.7"). PT LUBRICATOR TO 3000 PSI. RIH W/CCL, MPD, 20'-2 1/2" HOLLOW CARRIER (4 SPF, 180 DEG PHASING, 47 DEG CW F/HIGH SIDE OF HOLE). TIED INTO CBL DATED 4/11/96.WHP (BEFORE) = 1860 PSI, PERFORATED 7380'-7400', WHP (AFTER) = 1790 PSI.GUN STUCK. BLED WHP TO 0 PSI-PULLED FREE AT 2700# (1500# ABOVE THE NORMAL WEIGHT OF 1200#). POOH. 16:30 OOH W/GUN #2-ALL SHOTS FIRED. CONDITION OF GUN #2 IS SIMILAR TO GUN #1. 16:45 ESTABLISHED INJECTION RATE OF 2.0 BPM AT 2500 PSI FOR 10 BBLS.TOTAL DIESEL PUMPED 80 BBLS. Cons. Commission ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT A W~ ~. JOB SCOPE 2X-17 PERFORATE, PERF SUPPORT DATE 05/30/96 DAY 1 DAILY WORK PERF 'C' SAND OPERATION COMPLErE I SUCCESSFUL YES I YES KEY PERSON SWS-SCHWARTZ Kl(2X-17(W4-6)) IJOB NUMBER 0523960531.1 UNIT NUMBER SUPERVISOR PAIGE Initial Tbg Press I 1600 PSI I Final Tbg Press I 1750 PSI I Initial Inner Ann Final Inner Ann Initial Outer Ann I 1400 PSI 1400 PSI 200 PSI I Final Outer Ann 200 PSI DAILY SUMMARY IPERFORATED 'C' SAND INTERVAL F/7100''7108' USING 2-1/8'' EJ w/DP CHARGES' 4 SPF' 0 DEG PH TO SHOOT THE LOWSIDE'INCR 150~. TWO MORE RUNS TO COMPLETE IN THE AM. WHP I TIME LOG ENTRY 15:30 MIRU SWS. HELD SAFE~Y MTG. 16:15 PT LUB TO 3000g; TEST OK. RIH W/GUN#1 - WGT. BAR, MPD, CCL, 2-1/8" EJ W/DP CHARGES, 4 SPF, 0 DEG PH TO SHOOT THE LOWSIDE F/7100'-7108' ,, 17:30 TIED INTO SLTJ DATED 4/11/96; FIRED GUN#1. 18:00 AT SURF W/GUN#I; ALL SHOTS FIRED. WHP INCR 150~. 18:30 RDFN. Alaska 0il & Gas Cons. Commission KUPARUK RIVER UNIT WELL SERVICE REPORT Kl(2X-17(W4-6)) WI:I I. JOB SCOPE 2X-17 PERFORATE, PERF SUPPORT DATE DAILYWORK 05/31/96 PERF 'C' SAND DAY OPERATION COMPLETE I SUCCESSFUL 2 ~ YES I YES I Ill 1850 PSI 1850 PSI 1400 PSI DAILY SUMMARY ,I! JOB NUMBER ~ 0523960531.1 UN1T NUMBER KEY PERSON SUPERVISOR SWS-SCHWARTZ PAIGE Final Inner Ann I' Initial Outer Ann I Final Outer Ann 1400 PSI 200 PSI 200 PSI PERF 'C' SAND INTERVAL FROM 7045'-7090' (REF SLTJ DATED 4/11/96) USING 2-1/8" EJ W/DP CHARGES, 4 SPF, 0 DEG PH TO SHOOT ! LOWSIDE. I TIME LOG ENTRY 07:30 MIRU SWS. HELD SAFETYMTG. 08:30 PT LUB TO 3000g; TEST OK. RIH W/GUN#2 - WGT BAR, MPD, CCL, 2-1/8" EJ W/DP CHARGES, 4 SPF, 0 DEG PH TO SHOOT LOWSIDE F/7065'-7090' 09:20 ' TIED INTO SLTJ DATED 4/11/96; FIRED GUN~2. POH. 09:45 AT SURF W/GUN#2; ALL SHOTS FIRED. 10:15 PT LUB TO 3000~; TEST OK. RIH W/GUN#3 - WGT BAR, MPD, CCL, 2-1/8" EJ W/DP CHARGES, 4 SPF, 0 DEG PH TO SHOOT LOWSIDE F/7045'-7065' 11:05 TIED INTO SLTJ DATED 4/11/96; FIRED GUN#3. POH. 11:30 AT SURF W/GUN#3; ALL SHOTS FIRED. 12:00 RDMO TO 3H-21. ,, , . RECEIVED JUN 2 1 1996 Alaska 01t & !las Cons, CommissJor~ A~chorzg~ gyro/data ARCO ALASKA INC. WELL NO:2X-17 KAPARUK FIELD, ALASKA Gyro Multishot Survey Of 3.5" Tubing Survey date · 12 APRIL 1996 Job number' AK0496C337 RECeiVE JU~I 03 199G 0il & Gas Cons. Commission Anchorage SR337DOC Gyrodata Incorporated P.O. Box 79389 Houston, Texas 77279 713/461-3146 Fax: 713/461-0920 May 15, 1996 - Mr. Bill Isaacson Room ATO- 1290 Arco Alaska, Inc. "P.O.Box 100360 Anchorage, AK 99519-6611 Re: 2x PAD, WELL #2X-17, KAPARUK FIELD, AK Enclosed please find one (1) original and four (4) copies and one (1) disk of the completed survey of WelI#2X-17 We would like to take this opportunity to thank you for using Gyrodata and we look forward to serving you in the future. Sincerely, Operations Manager RS/fcc R CE Alaska (31 & Gas Cons. Commission Anchorage Serving the Worldwide Energy Industry with Precision Survey Instrumentation gym,/data CONTENTS JOB NUMBER :AK0496C337 . DISCUSSION, SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. INRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT REPORT SR337DOC gyro/data 1. DISCUSSION, SURVEY CERTIFICATION SHEET SR337DOC gyro/data DISCUSSION JOB NUMBER' AK0496C337 Tool 746 was run in well# 2X-17 on ATLAS 5/16" Wireline inside casing. The survey was run without problems. - SR337DOC gyro/data SURVEY CERTIFICATION SHEET JOB NUMBER' AK0496C337 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the original data obtained at the wellsite. Checked by :- ROB SHOUP OPERATIONS MANAGER SR337DOC gyro/data 2. SURVEY DETAILS SR337DOC gyro/data SURVEY DETAILS JOB NUMBER' AK0496C337 CLIENT · B.P. EXPLORATION RIG ' MAST TRUCK LOCATION · WELL · LATITUDE · KAPARUK FIELD, ALASKA 2X-17 70.325000 N LONGITUDE: 149 W SURVEY DATE' 12 APRIL 1996 SURVEY TYPE · MULTISHOT IN 3.5" TUBING DEPTH REFERENCE' MAX. SURVEY DEPTH · ROTARY TABLE ELEVATION 118 FT. 7601 SURVEY TIED ONTO · NA SURVEY INTERVAL' 100' FROM 0 TO 1000' 50' FROM 1000' TO 1650' 49- 50' FROM 1699' TO 7601' UTM CO-ORDINATES · TARGET DIRECTION · GRID CORRECTION · N/A CALCULATION METHOD' MINIMUM CURVATURE SURVEYOR · TOM STODDARD SR337DOC A Gyroda t a Di r e c t i ona i Survey for ARCO ALASKA INC. WELL: 2X-17, 3.5" TUBING Location: 2X PAD, KUPARUK FIELD, ALASKA Job Number: AK0496C337 Run Date: 12-Apr-96 0:39:43 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.325000 deg. N Sub-sea Correction from Vertical Reference: 118 ft. Azimuth Correction: Syro: Bearings are Relative to True North Vertical Section Calculated from Well Head Location Slosure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyrodat a D ire c t iona i .ARCO ALASKA INC. NELL: 2X°-17, 3.5" TUBING Location: 2X PAD, KUPARUK FIELD, Job Number: AK0496C337 ALASKA MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SUBSEA SECTION DEPTH feet feet Survey DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg. / feet deg. 100 ft. 0.0 0.0 0.0 0.00 0.00 0.0 0.0 -118.0 0.00 0 - 7601 FT. GYRO MULTISHOT RUN INSIDE 3.5" TUBING ALL DEPTHS REFERENCED TO ORIGINAL R.K.B. OF 118 FEET ABOVE M.S.L. Page HORIZONTAL COORDINATES feet 0.00 N 0.00 E 100.0 .08 353.44 100.0 .1 -18.0 .08 200.0 .18 290.09 200.0 .2 82.0 .16 300.0 .11 249.78 300.0 .2 182.0 .12 400.0 .28 250.12 400.0 .1 282.0 .17 500.0 .33 236.30 500.0 -.1 382.0 .09 600.0 .32 233.52 600.0 -.5 482.0 .02 700.0 .38 224.18 700.0 -.9 582.0 .09 800.0 .32 244.45 800.0 -1.2 682.0 .14 900.0 '.17 269.93 900.0 -1.4 782.0 .18 1000.0 .40 49.03 1000.0 . -1.1 882.0 .54 1050.0 2.08 57.44 1050.0 -.5 932.0 3.38 1100.0 3.96 54.24 1099.9 1.0 981.9 3.77 1150.0 6.06 52.52 1149.7 3.6 1031.7 4.20 1200.0 7.30 52..27 1199.4 7.1 1081.4 2.48 1250.0 8.24 52.42 1248.9 11.3 1130.9 1.89 1300.0 8.53 53.50 1298.4 15.7 1180.4 .65 1350.0 9.13 53.48 1347.8 20.2 1229.8 1.20 1400.0 9.75 54.01 1397.1 25.1 1279.1 1.26 1450.0 10.65 55.22 1446.3 30.2 1328.3 1.85 1500.0 11.53 54.81 1495.4 35.7 1377.4 1.76 .1 353.4 .3 319.4 .5 298.3 .7 278.0 1.2 263.1 1.7 254.1 2.3 247.5 2.9 244.5 3.3 245.6 3.1 248.6 2.1 255.2 1.0 10.5 5.1 45.7 10.9 49.2 17.7 50.4 25.0 51.2 32.6 51.7 40.8 52.1 49.7 52.6 59.3 53.0 .07 N .01 W .19 N .16 W .22 N .40 W .10 N .71 W .14 S 1.19 W .47 S 1.65 W .87 S 2.11 W 1.23 S 2.59 W 1.36 S 3.00 W 1.13 S 2.88 W .53 S 1.99 W .97 N .18 E 3.59 N 3.68 E 7.13 N 8.28 E 11.26 N 13.63 E 15.65 N 19.45 E 20.22 N 25.62 E 25.07 N 32.23 E 30.19 N 39.45 E 35.71 N 47.33 E A Gyroda t a Di re c t ional Survey %RCO ALASKA INC. ~ELL: 2X-17, 3.5" TUBING Location: 2X PAD, KUPARUK FIELD, Iob Number: AK0496C337 ALASKA Page ~EASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet 1550.0 12.57 54.30 1544.3 1600.0 14.84 53.05 1592.9 1650.0 16.22 51.98 1641.0 1699.0 18.67 51.55 1687.8 1749.0 20.70 52.01 1734.8 VERTICAL SECTION feet 41.8 48.8 56.9 66.0 76.4 SUBSEA DEPTH feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. 1426.3 2.08 69.7 53.2 1474.9 4.58 81.6 53.3 1523.0 2.83 95.0 53.2 1569.8 5.01 109.6 53.0 1616.8 4.07 126.5 52.8 HORIZONTAL C O O R D I N~A T E S feet 41.76 N 55.84 E 48.78 N 65.37 E 56.93 N 75.99 E 66.03 N 87.53 E 76.45 N 100.76 E 1799.0 23.69 52.29 1781.1 1849.0 25.76 52.90 1826.5 1899.0 28.23 52.82 1871.1 1949.0 30.33 53.30 1914.7 1999.0 32.03 54.15 1957.5 88 100 114 129 144 .0 .7 .4 .1 .4 1663.1 5.97 145.4 52.7 1708.5 4.18 166.3 52.7 1753.1 4.95 189.0 52.7 1796.7 4.22 213.4 52.8 1839.5 3.51 239.3 52.9 88.03 N 115.68 E 100.73 N 132.29 E 114.43 N 150.38 E 129.13 N 169.93 E 144.44 N 190.80 E 2049.0 33.96 55.02 1999.4 2099.0 35.11 55.72 2040.6 214~.0 37.10 56.17 2081.0 2199.0 38~05 56.52 2120.6 2249.0 40.50 57.67 2159.3 2299.0 40.86 58.00 2197.3 2349.0 40.22 58.24 2235.2 2399.0 39.99 58.47 2273.5 2449.0 39.48 58.17 2311.9 2499.0 38.77 57.99 2350.7 160 176 192 209 226 244 261 278 295 311 .2 .3 .8 .7 .9 .2 .4 .3 .1 .8 1881.4 3.97 266.5 53.1 1922.6 2.45 294.8 53.3 1963.0 4.00 324.3 53.5 2002.6 1.95 354.7 53.8 2041.3 5.10 386.3 54.0 2079.3 .84 418.9 54.3 2117.2 1.31 451.3 54.6 2155.5 .54 483.4 54.9 2193.9 1.09 515.3 55.1 2232.7 1.45 546.8 55.2 160.21 N 212.99 E 176.31 N 236.32 E 192.81 N 260.73 E 209.71 N 286.11 E 226.89 N 312.68 E 244.24 N 340.27 E 261.41 N 367.86 E 278.31 N 395.28 E 295.09 N 422.48 E 311.77 N 449.26 E 2549.0 38.68 57.71 2389.7 2599.0 40.66 57.94 2428.2 2649.0 42.53 58.17 2465.6 2699.0 42.45 58.18 2502.5 2749.0 41.69 57.93 2539.6 328 345 363 380 398 .4 .4 .0 .8 .5 2271.7 .39 578.1 55.4 2310.2 3.96 610.0 55.5 2347.6 3.76 643.1 55.6 2384.5 .17 676.9 55.8 2421.6 1.55 710.4 55.9 328.42 N 475.74 E 345.41 N 502.76 E 362.97 N 530.93 E 380.78 N 559.62 E 398.51 N 588.05 E A Gyrodat a Di re c t i ona i Survey ~RCO ALASKA INC. ~ELL: 2X-17, 3.5" TUBING Location: 2X PAD, KUPARUK FIELD, Yob Number: AK0496C337 ALASKA Page ~EASURED DEPTH feet 2799.0 2849.0 2899.0 2949.0 2999.0 I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet 41.38 57.80 2577.0 40.65 57.79 2614.8 40.47 57.74 2652.7 40.09 57.54 2690.9 39.51 57.31 2729.3 VERTICAL SECTION feet 416.1 433.6 451.0 468.3 485.5 SUBSEA DOGLEG CLOSURE DEPTH SEVERITY DIST. AZIMUTH. feet deg./ feet deg. 100 ft. 2459.0 .65 743.5 56.0 2496.8 1.46 776.3 56.0 2534.7 .37 808.8 56.1 2572.9 .79 841.1 56.2 2611.3 1.21 873.1 56.2 HORIZONTAL COORDINATES feet 416.14 N 616.12 E 433.63 N 643.89 E 450.97 N 671.39 E 468.27 N 698.69 E 485.50 N 725.66 E 3049 3099 3149 3199 3249 .0 .0 .0 .0 .0 39.29 57.22 2767.9 38.76 57.02 2806.8 39.45 56.74 2845.6 42.00 56.69 2883.5 41.92 56.58 2920.7 502.7 519.8 537.0 554.9 573.3 2649.9 .45 904.8 56.3 2688.8 1.09 936.3 56.3 2727.6 1.42 967.8 56.3 2765.5 5.10 1000.5 56.3 2802.7 .22 1033.9 56.3 502.66 N 752.36 E 519.75 N 778.80 E 536.98 N 805.21 E 554.88 N 832.48 E 573.27 N 860.40 E 3299 3349 3399 3449 3501 3551 3601 3651 3701 3751 .0 .0 .0 .0 .0 .0 .0 .0 .0 .0 41.48 56.44 2958.0 40.89 56.13 2995.6 40.62 55.88 3033.5 40~07 55.69 3071.6 39.73 55.51 3111.5 39.62 55.26 3150.0 40.03 56.18 3188.4 40.79 57.32 3226.4 40.43 57.17 3264.4 40.01 56.94 3302.6 591.6 609.9 628.1 646.4 665.2 683.3 701.4 719.1 736.7 754.3 2840.0 .90 1067.1 56.3 2877.6 1.23 1100.1 56.3 2915.5 .65 1132.7 56.3 2953.6 1.13 1165.1 56.3 2993.5 .68 1198.4 56.3 3032.0 .39 1230.4 56.3 3070.4 1.44 1262.4 56.2 3108.4 2.12 1294.8 56.3 3146.4 .75 1327.3 56.3 3184.6 .90 1359.6 56.3 591.62 N 888.14 E 609.90 N 915.53 E 628.15 N 942.59 E 646.35 N 969.35 E 665.20 N 996.88 E 683.33 N 1023.15 E 701.36 N 1049.61 E 719.13 N 1076.72 E 736.74 N 1104.09 E 754.30 N 1131.18 E 3801.0 3851.0 3901.0 3951.0 4001.0 39.74 56.89 3341.0 39.81 55.71 3379.4 39.21 54.33 3418.0 38.77 54.19 3456.8 38.54 53.80 3495.9 771.8 789.5 807.8 826.2 844.5 3223.0 .55 1391.7 56.3 3261.4 1.52 1423.7 56.3 3300.0 2.13 1455.5 56.3 3338.8 .91 1486.9 56.2 3377.9 .67 1518.1 56.2 771.80 N 1158.04 E 789.55 N 1184.65 E 807.79 N 1210.72 E 826.16 N 1236.25 E 844.52 N 1261.52 E A Gyrodata LRCO ALASKA INC. YELL: 2X-17, 3.5" TUBING Location: 2X PAD, KUPARUK FIELD, Iob Number: AK0496C337 ALASKA 4EASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet 4051.0 38.02 52.67 3535.1 4102.0 36.82 51.98 3575.6 4152.0 37.19 55.02 3615.6 4202.0 36.05 55.92 3655.7 4251.0 36.06 56.26 3695.3 4301.0 39.30 61.36 3734.9 4352.0 42.15 63.50 3773.5 4401.0 42.19 63.37 3809.8 4452.0 41.79 62.41 3847.7 4501.0 41.59 61.48 3884.3 4551.0 41.35 60.66 3921.8 4602.0 40.96 60.40 3960.2 4651.0 40.98 60.25 3997.2 4702.0 40~07 59.95 4036.0 4752.0 39.87 59.98 4074.3 4801.0 40.05 60.70 4111.8 4852.0 39.99 60.55 4150.9 4901.0 39.81 60.48 4188.5 4951.0 39.43 60.47 4227.0 5001.0 39.08 60.47 4265.7 5052.0 38.89 60.59 4305.4 5101.0 38.57 60.26 4343.6 5151.0 38.74 60.06 4382.6 5201.0 38.41 60.20 4421.7 5252.0 38.18 59.57 4461.8 863.1 882.0 899.9 916.8 932.9 948 964 978 994 1009 1025 1042 1058 1074 1090 1106 1122 1137 1153 1169 1184 1200 1215 1231 1246 .7 .0 .8 .3 .6 .6 .2 .1 .6 .6 .2 .3 .8 .5 .1 .9 .0 Directional Survey SUBSEA DOGLEG CLOSURE DEPTH SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. 3417.1 1.75 1549.0 56.1 3457.6 2.48 1580.0 56.1 3497.6 3.74 1610.0 56.0 3537.7 2.52 1639.8 56.0 3577.3 .40 1668.7 56.0 3616.9 9.00 1699.2 56.1 3655.5 6.22 1732.2 56.2 3691.8 .19 1764.9 56.3 3729.7 1.50 1798.8 56.4 3766.3 1.32 1831.2 56.5 3803.8 1.19 1864.2 56.6 3842.2 .84 1897.7 56.7 3879.2 .20 1929.8 56.8 3918.0 1.83 1962.9 56.8 3956.3 .39 1994.9 56.9 3993.8 1.01 2026.3 56.9 4032.9 .23 2059.1 57.0 4070.5 .37 2090.4 57.0 4109.0 .77 2122.3 57.1 4147.7 .69 2153.8 57.1 4187.4 .40 2185.9 57.2 4225.6 .79 2216.5 57.2 4264.6 .43 2247.7 57.3 4303.7 .68 2278.8 57.3 4343.8 .88 2310.4 57.3 Page 4 HORIZONTAL COORDINATES feet ~63.06 N 1286.33 E 882.00 N 1310.86 E 899.89 N 1335.05 E 916.80 N 1359.62 E 932.88 N 1383.55 E 948.66 N 1409.70 E 964..04 N 1439.20 E 978.75 N 1468.62 E 994.30 N 1498.99 E 1009.62 N 1527.75 E 1025.64 N 1042.15 N 1058.06 N 1074.57 N 1090.65 N 1106.22 N 1122.30 N 1137.78 N 1153.49 N 1169.08 N 1184.86 N 1199.99 N 1215.53 N 1231.06 N 1246.92 N 1556.73 E 1585.95 E 1613.86 E 1642.59 E 1670.39 E 1697.74 E 1726.32 E 1753.68 E 1781.42 E 1808.95 E 1836.88 E 1863.55 E 1890.64 E 1917.67 E 1945.01 E A Gyrodata ARCO ALASKA INC. WELL: 2X-17, 3.5" TUBING Location: 2X PAD, KUPARUK FIELD, Job Number: AK0496C337 ALASKA MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet 5301.0 37.40 57.84 4500.5 5351.0 37.13 56.83 4540.3 5401.0 36.97 56.05 4580.2 5451.0 36.68 55.99 4620.2 5501.0 36.69 55.98 4660.3 5502.0 36.61 55.95 4661.1 5602.0 39.26 59.84 4740.0 5651.0 39.74 61.43 4777.8 5701.0 39.31 61.49 4816.4 5752.0 39.46 61.52 4855.8 5801.0 38.88 61.43 4893.8 5851.0' 38.93 61.15 4932.7 5901.0 39.05 60.59 4971.5 5951.0 38'.99 60.29 5010.4 6001.0 39.21 59.70 5049.2 6052.0 39.50 58.89 5088.6 6101.0 39.61 58.15 5126.4 6152.0 39.83 57.90 5165.6 6201.0 39.48 57.70 5203.4 6251.0 39.52 57.55 5241.9 6302.0 39.14 57.46 5281.4 6352.0 38.79 56.70 5320.3 6401.0 38.26 55.65 5358.6 6451.0 37.95 55.08 5397.9 6501.0 38.03 54.46 5437.3 1262.5 1278.9 1295.5 1312.3 1329.0 1329 1361 1377 1392 1407 1422 1437 1453 1468 1484 1500 1517 1534 1551 1568 1585 1602 1619 1637 1654 .3 .9 .2 .4 .8 .6 .7 .0 .5 .3 .8 .1 .4 .0 .1 .4 .5 .5 .0 .8 Di re SUBSEA DEPTH feet 4382.5 4422.3 4462.2 4502.2 4542.3 4543.1 4622.0 4659.8 4698.4 4737.8 4775.8 4814.7 4853.5 4892.4 4931.2 4970.6 5008.4 5047.6 5085.4 5123.9 5163.4 5202.3 5240.6 5279.9 5319.3 c t i o n a 1 Survey DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. 2.68 2340.4 57.4 1.34 2370.7 57.4 1.00 2400.8 57.3 .58 2430.8 57.3 .02 2460.6 57.3 7.89 2461.2 57.3 3.57 2522.7 57.3 2.28 2553.8 57.4 .87 2585.5 57.4 .30 2617.8 57.5 1.20 2648.7 57.5 .37 2680.0 57.6 .74 2711.4 57.6 .40 2742.8 57.6 .85 2774.4 57.7 1.16 2806.7 57.7 .99 2837.9 57.7 .52 2870.5 57.7 .75 2901.7 57.7 .21 2933.5 57.7 .76 2965.9 57.7 1.17 2997.3 57.7 1.73 3027.8 57.7 .94 3058.6 57.6 .78 3089.4 57.6 Page HORIZONTAL COORDINATES feet 1278.85 N 1295.51 N 1312.26 N 1328.97 N 1329.30 N 1361.90 N 1377.18 N 1392.39 N 1407.83 N 1422.61 N 1437.69 N 1453.00 N 1468.53 N 1484.30 N 1500.82 N 1517.11 N 1534.37 N 1551.03 N 1568.06 N 1585.42 N 1602.51 N 1619.49 N 1637.03 N 1654.79 N 1970.67 E 1996.16 E 2021.26 E 2046.11 E 2070.86 E 2071.36 E 2123.44 E 2150.61 E 2178.56 E 2207.00 E 2234.19 E 2261.73 E 2289.22 E 2316.60 E 2343.91 E 2371.71 E 2398.32 E 2425.97 E 2452.43 E 2479.29 E 2506.55 E 2532.94 E 2558.30 E 2583.69 E 2608.82 E A Gyrodat a Di re c t iona i Survey ARCO ALASKA INC. WELL: 2X-17, 3.5" TUBING Location: 2X PAD, KUPA_RUK FIELD, Job Number: AK0496C337 ALASKA Page MEASURED DEPTH feet I N C L AZIMUTH VERTICAL DEPTH. deg. deg. feet VERTICAL SUBSEA SECTION DEPTH feet feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 6552.0 37.37 53.83 5477.7 6601.0 36.92 53.26 5516.8 6651.0 37.13 52.64 5556.7 6701.0 38.48 53.77 5596.2 6751.0 38.61 53.60 5635.3 1673.1 5359.7 1690.6 5398.8 1708.8 5438.7 1727.1 5478.2 1745.6 5517.3 1.51 3120.5 57.6 1.16 3150.0 57.5 .85 3180.0 57.5 3.04 3210.6 57.5 .34 3241.7 57.4 1673.05 N 1690.63 N 1708.77 N 1727.12 N 1745.58 N 2634.10 E 2657.90 E 2681.93 E 2706.47 E 2731.58 E 6802.0 38.53 53.09 5675.2 6851.0 38.33 51.95 5713.5 6901.0 37.92 51.51 5752.9 6951.0 36.78 53.56 5792.6 7001.0 36.32 58.35 5832.8 1764.6 5557.2 1783.1 5595.5 1802.2 5634.9 1820.7 5674.6 1837.3 5714.8 .64 3273.4 57.4 1.51 3303.8 57.3 .97 3334.5 57.3 3.37 3364.7 57.2 5.78 3394.5 57.2 1764.56 N 1783.09 N 1802.21 N 1820.67 N 1837.33 N 2757.09 E 2781.25 E 2805.49 E 2829.56 E 2854.21 E 7051.0 34.59 58.88 5873.5 7101.0 34.16 58.08 5914.8 7151.0 33.47 56.72 5956.3 7201.0 32'.07 57.61 5998.4 7251.0 31.39 60.23 6040.9 7302.0 30.64 62.47 6084.6 7351.0 29.59 64.87 6127.0 7401.0 29.59 64.67 6170.5 7451.0 27.93 66.16 6214.3 7501.0 26.22 68.26 6258.8 1852.4 5755.5 1867.2 5796.8 1882.2 5838.3 1896.9 5880.4 1910.4 5922.9 1923.0 5966.6 1934.0 6009.0 1944.5 6052.5 1954.5 6096.3 1963.3 6140.8 3.52 3423.4 57.2 1.25 3451.7 57.3 2.03 3479.5 57.3 2.97 3506.6 57.3 3.07 3532.8 57.3 2.71 3559.0 57.3 3.26 3583.5 57.3 .20 3608.0 57.4 3.62 3631.8 57.4 3.92 3654.2 57.5 1852.44 N 1867.20 N 1882.19 N 1896.86 N 1910.44 N 1923.04 N 1933.95 N 1944.47 N 1954.49 N 1963.32 N 2878.97 E 2903.03 E 2926.47 E 2949.21 E 2971.73 E 2994.78 E 3016.81 E 3039.14 E 3061.01 E 3081.98 E 7551.0 24.25 69.94 6304.1 7601.0 22.83 72.19 6349.9 1970.9 6186.1 1977.4 6231.9 4.19 3675.1 57.6 3.37 3694.5 57.6 1970.93 N 1977.42 N 3101.89 E 3120.77 E Final Station Closure: Distance: 3694.51 ft Az: 57.64 deg. A Gyro da t a D i re c t i ona i Survey for ARCO ALASKA INC. WELL: 2X-17, 3.5" TUBING Location: 2X PAD, KUPARUK FIELD, ALASKA Iob Number: AK0496C337SS ~un Date: 12-Apr-96 0:39:43 Surveyor: TOM STODDARD ~alculation Method: MINIMUM CURVATURE Survey Latitude: 70.325000 deg. N Sub-sea Correction from Vertical Reference: 118 ft. ~zimuth Correction: 3yro: Bearings are Relative to True North Yertical Section Calculated from Well Head Location ]losure Calculated from Well Head Location ~orizontal Coordinates Calculated from Local Horizontal Reference A Gyrodata ~RCO ALASKA INC. 4ELL: 2X-17, 3.5" TUBING Location: 2X PAD, KUPARUK FIELD, /ob Number: AK0496C337SS ALASKA Directional SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DOGLEG CLOSURE DEPTH DEPTH SECTION SEVERITY DIST. AZIMUTH feet deg. deg. feet feet deg./ feet deg. 100 ft. -118.0 0.00 0.00 0.0 0.0 0.00 0.0 0.0 ~ - 7601 FT. %LL DEPTHS REFERENCED TO ORIGINAL R.K.B. GYRO MULTISHOT RUN INSIDE 3.5" TUBING OF 118 FEET ABOVE M.S.L. Survey Page HORIZONTAL COORDINATES feet 0.00 N 0.00 E 100.0 .17 282.83 218.0 .2 .16 .5 315.6 200.0 .14 249.84 318.0 .2 .13 .7 294.6 300.0 .29 247.63 418.0 .1 .16 1.2 275.3 400.0 .33 235.80 518.0 -.2 .08 1.7 261.5 500.0 .33 231.84 618.0 -.5 .03 2.3 252.9 600.0 .37 227.83 718.0 -.9 .10 2.9 246.9 700.0 .29 249.04 818.0 -1.3 .15 3.3 244.7 800.0 .21 230.15 918.0 -1.3 .25 3.1 246.2 900.0 1.00 52.06 1018.0 -.9 1.56 2.1 251.0 1000.0 4.72 53.62 1118.0 1.9 3.93 5.1 23.3 1100.0 7.65 52.33 1218.0 8.7 2.26 17.7 49.7 1200.0 8.77 53.50 1318.0 17.5 .87 32.6 51.4 1300.0 10.14 54.53 1418.0 27.2 1.51 49.7 52.3 1400.0 12.01 54.58 1518.0 38.5 1.91 69.7 53.1 1500.0 15.56 52.49 1618.0 53.0 3.67 95.0 53.2 1600.0 19.98 51.84 1718.0 72.7 4.41 126.5 52.9 1700.0 25.37 52.78 1818.0 98.3 4.52 166.3 52.7 .. 1800.0 30.46 53.36 1918.0 130'.3 4.16~ 239.3 52.8 1900.0 34.48 55.34 2018.0 167.5 3.28 294.8 53.2 2000.0 37.99 56.50 2118.0 208.6 2.09 354.7 53.7 .20 N .21 W .19 N .46 W .11 S .80 W .20 S 1.27 W .54 S 1.73 W .94 S 2.19 W 1.26 S 2.66 W 1.31 S 2.98 W .91 S 2.56 W 1.92 N 1.45 E 8.69 N 10.29 E 17.46 N 21.90 E 27.24 N 35.30 E 38.51 N 51.27 E 53.04 N 70.91 E 72.72 N 96.03 E 98.34 N 129.16 E 130.31 N 171.54 E 167.47 N 223.52 E 208.59 N 284.42 E A Gyrodata ARCO ALASKA INC. WELL: 2X-17, 3.5" TUBING Location: 2X PAD, KUPARUK FIELD, Job Number: AK0496C337SS ALASKA Dire'ct SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DOGLEG DEPTH DEPTH SECTION SEVERITY feet deg. deg. feet feet deg./ 100 ft. 2100.0 40.51 58.13 2218.0 2200.0 39.37 58.14 2318.0 2300.0 40.13 57.88 2418.0 2400.0 42.13 58.08 2518.0 2500.0 40.63 57.78 2618.0 2600.0 39.68 57.38 2718.0 2700.0 38.96 56.94 2818.0 2800.0 41.93 56.58 2918.0 2900.0 40.73 55.98 3018.0 3000.0 39.71 55.47 3118.0 3100.0 40.63 57.06 3218.0 3200.0 39.90 56.92 3318.0 3300.0 39.21 54.32 3418.0 3400.0 3'8.24 53.16 3518.0 3500.0 37.12 55.08 3618.0 3600.0 37.92 59.19 3718.0 3700.0 42.11 63.16 3818.0 3800.0 41.37 60.74 3918.0 3900.0 40.49 60.09 4018,0 4000.0 40.04 60.68 4118.0 253.6 297.7 340.9 388.2 435.1 480.4 524.7 572.0 620.7 668.3 715.2 761.3 8O7.8 855.0 900.9 941.9 982.1 1024.0 1066.9 1108.8 1149.8 1189.9 1229.6 1269.7 1311.3 4100.0 39.52 60.47 4218.0 4200.0 38.78 60.48 4318.0 4300.0 38.44 60.18 4418.0 4400.0 37.28 57.40 4518.0 4500.0 36.69 55.99 4618.0 1.10 1.15 3.01 .75 1.36 1.09 1.18 .57 .89 .63 1.97 .76 2.13 1.28 3.67 5.33 .47 1.20 1.07 .89 .68 .53 .66 2.09 .61 i o n a 1 CLOSURE DIST. AZIMUTH feet deg. 451.3 54.5 546.8 55.1 610.0 55.5 710.4 55.8 808.8 56.0 873.1 56.2 967.8 56.3 1033.9 56.3 1132.7 56.3 1230.4 56.3 1294.8 56.3 1391.7 56.3 1486.9 56.3 1549.0 56.2 1639.8 56.0 1699.2 56.0 1798.8 56.3 1864.2 56.6 1962.9 56.8 2059.1 56.9 2122.3 57.1 2216.5 57.2 2278.8 57.3 2370.7 57.4 2430.8 57.3 Survey Page HORIZONTAL COORDINATES feet 253.62 N 355.34 E 297.70 N 426.66 E 340.90 N 495.58 E 388.19 N 571.51 E 435.11 N 646.23 E 480.43 N 524.73 N 571.96 N 620.68 N 668.26 N 717.73 E 786.43 E 858.40 E 931.52 E 1001.32 E 715.19 N 761.34 N 807'.81 N 854.98 N 900.92 N 1070.70 E 1141.98 E 1210.75 E 1275.51 E 1336.55 E 941.93 N 982.10 N 1024.02 N 1066.92 N 1108.75 N 1398.55 E 1475.17 E 1553.79 E 1629.27 E 1702.25 E 1149.81 N 1189.86 N 1229.58 N 1269.71 N 1311.34 N 1774.93 E 1845.69 E 1915.09 E 1981.89 E 2044.74 E A Gyroda t a D i r e c t .~RCO ALASKA INC. NELL: 2X-17, 3.5" TUBING Location: 2X PAD, KUPARUK FIELD, 3ob Number: AK0496C337SS ALASKA SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DOGLEG DEPTH DEPTH SECTION SEVERITY. feet deg. deg. feet feet deg./ 100 ft. 4600.0 38.52 58.76 4718.0 4700.0 39.32 61.49 4818.0 4800.0 38.91 61.26 4918.0 4900.0 39.04 60.17 5018.0 5000.0 39.59 58.32 5118.0 1352.8 4.77 1393.0 .84 1432.0 .68 1471.6 .49 1513.5 1.03 5100.0 39.49 57.65 5218.0 5200.0 38.81 56.75 5318.0 5300.0 37.99 54.76 5418.0 5400.0 36.92 53.24 5518.0 5500.0 38.55 53.67 5618.0 1557.5 .55 1601.5 1.15 1646.1 .86 1691.2 1.15 1737.4 1.53 5600.0 38.28 51.90 5718.0 5700.0 36.49 56.58 5818.0 5800.0 34.10 57.98 5918.0 5900.0 31.76 58.82 6018.0 6000.0 29.81 64.36 6118.0 1785.3 1.45 1831.2 4.89 1868.4 1.31 1903.1 3.02 1931.6 3.14 6100.0 27.79 66.33 6218.0 6200.0 23.82 70.62 6318.0 6231.9 22.83 72.19 6349.9 1955.2 3.64 1972.9 3.94 1977.4 3.37 i o n a 1 Survey Page CLOSURE DIST. AZIMUTH feet deg. 2522.7 57.3 2617.8 57.4 2680.0 57.5 2774.4 57.6 2837.9 57.7 2933.5 57.7 2997.3 57.7 3089.4 57.6 3180.0 57.5 3241.7 57.4 3334.5 57.3 3394.5 57.2 3479.5 57.3 3532.8 57.3 3583.5 57.3 3654.2 57.4 3694.5 57.6 3694.5 57.6 HORIZONTAL C 0 0 R D I N A T E S feet 1352.82 N 1393.03 N 1432.00 N 1471.63 N 1513.49 N 2108.93 E 2179.75 E 2251.35 E 2321.96 E 2392.41 E 1557.50 N 1601.51 N 1646.07 N 1691.19 N 1737.42 N 2462.63 E 2531.41 E 2596.48 E 2658.65 E 2720.48 E 1785.26 N 1831.19 N 1868.35 N 1903.13 N 1931.63 N 2784.00 E 2845.13 E 2904.84 E 2959.60 E 3012.13 E 1955~.22 N 1972.91 N 1977.42 N 3062.75 E 3107.63 E 3120.77 E ?inal Station Closure: Distance: 3694.51 ft Az: 57.64 deg. 9Tmldata QUALITY CONTROL REPORT JOB NUMBER: AK0496C337 TOOL NUMBER: 746 MAXIMUM GYRO TEMPERATURE: 76.70 C MAXIMUM AMBIENT TEMPERATURE: 56.2 C MAXIMUM INCLINATION: AVERAGE AZIMUTH: 42.53 53.9263 WIRELINE REZERO VALUE: 0.0 REZERO ERROR / K: CALIBRATION USED FOR FIELD SURVEY: 1425 CALIBRATION USED FOR FINAL SURVEY: 1425 PRE JOB MASS BALANCE OFFSET CHECK: POST JOB MASS BALANCE OFFSET CHECK] : CONDITION OF SHOCK WATCHES UPON ARRIVAL AT RIG: -.48 USED N/A OK UPON COMPLETION OF SURVEY: OK UPON RETURN TO ATLAS OK BOTTOM LINE COMPARISIONS M.D. INC AZIMUTH TVD NORTHING EASTING FIELD SURVEY FINAL SURVEY 7601 22.83 72.19 0349.9 1977.40N 3120.80E 7601 22.83 7219 6349.9 1977.42N 3120.77E SR337DOC gyro/data FUNCTION TEST JOB NUMBER' AK0496C337 5 Survey stations were collected at the measured depth shown below. The tables show the ~'epeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ff 1 2 3 4 5 7603 22.77 22.77 22.77 22.77 22.77 AZIMUTH M.D. ft 1 2 3 4 5 7603 70.10 70.19 70.13 70.21 70.18 SR337DOC gyro/data, , $. EQUIPMENT REPORT SR337DOC gyro/data EQUIPMENT REPORT JOB NUMBER: AK0496C339 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOE'No. 746 GYRO SECTION A0119 DATA SECTION C0063 POWER SECTION C0059 BACKUP TOOL No. 705 GYRO SECTION A0082 DATA SECTION C0031 POWER SECTION C0046 COMPUTER POWER SUPPLY PRINTER INTERFACE COMPUTER POWER SUPPLY PRINTER INTERFACE A0222 A0085 A0079 A0074 A0246 A0107 A0029 A0071 WIRELINE COMPANY: CABLE SIZE: ATLAS WIRELINE 5/16" RUNNING GEAR 2 1/2" SYSTEM TOTAL LENGTH OF TOOL: MAXIMUM O.D.: TOTAL WEIGHT OF TOOL: 32.0 feet 3.6 INCHES 270Lbs RECEIVED JUN 0 $1996 Alaska Oil & Gss Cor~s. ~;o~'~;.mission Anchorage SR337DOC ARCO Alaska, Inc. Date: May 16, 1996 Transmittal # 9691 RETURN TO: ARCO Alaska, Inc. ATTN: Julie Nash Kuparuk Operations File Clerk ATO-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Gyroscopic Survey items. Please acknowledge receipt and return one signed copy of this transmittal. 2X-17 Gyro Multishot Survey 04/12/96 Receipt 4/. ~ ~~/ Acknowledged:__~ ~ DISTRIBUTION: #:AK0496C337 RECEIVED Date:. d U N Alaska Oil & Gas Cons. Commission Anchorage Mr. Vernon E. Pringle Jr. DeGloyer and MacNaughton One Energy Square Dallas, TX 75206 ~y: Grant AOGCC 3001 Porcupine Drive Anchorage, AK 99501 ARCO Alaska, Inc. Date: April 23, 1996 Transmittal #: 9673 RETURN TO: ARCO Alaska, Inc. Attn.: Julie Nash Kuparuk Operations File Clerk ATO-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following Cased Hole items. receipt and return one signed copy of this transmittal. %-o?;,.1F.19 qf"'-t ~,~ 1Q-21 '~¢'-..l~ol Q-22A ~-f,~ 2X- 17 ~..~¢ 3H-24 Receipt Acknowledge' Cement Bond Log SLTJ-GR/CCL 04/12/96 Cement Bond Log SLTJ-'GR/CCL 04/14/96 Cement Bond Log SLTJ-GR/CCL 04/14/96 Cement Bond Log SLTJ-GR/CCL 04/11/96 Cement Bond Log SLTJ-GR/CCL 04/14/96 DISTRIBUTION' Date' Sharon AIIsup-Drake DS Development ATO-1205 Larry Grant (+sepia) AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Please acknowledge 6682-9356 9155-10318 8172-9383 6000-7644 10910-11912 Chapman/Zuspan NSK Wells Group NSK69 TONY KNOWLE$, GOVERNOR A A$1 A' OIL AND GAS C ONSER¥ TION CO IMIS$ION 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-,3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 November 2, 1995 Mike Zanghi, Drill Site Develop. Supv. ARCO Alaska Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Unit 2X-17 · ARCO Alaska; Inc.. ......... "PermitNo.'95-171 .... . .'" Surf Loc 689'FSL, 240'FEL, Sec. 4, TI 1N, RgE, UM Btmhole Loc 2414'FNL, 2357'FEL, Sec. 3, TI1N, RgE, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before ddiling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, . Commissioner BY ORDER OF THE COMMISSION '/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o enct STATE OF ALASKA ,A OIL AND GAS CO~SERVA~ ~MI N PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill D I b Type of Well Exploratory D Stratigraphic Test D Development Oil X Re-Entry E] Deepen E] Service E] Development Gas D Single Zone X Multiple Zone n 2. Name of Operator 5. Datum Elevation (DF or KB) 1 0. F~d and Pool ARCO Alaska~ Inc. RKB 41'~ Pad 77' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360~ Anchoracje, AK 99510-0360 ADL 25645~ ALK 2576 4. Location of well at surface 7. Unit or property Name 1 1. Type Bond (see 20 AAC 25.025) 689' FSL, 240' FEL, Sec. 4, T11N, R9E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 2486' FNL, 2461' FEL, Sec. 3, T11N, R9E, UM 2X-17 #U-630610 At total depth 9. Approximate spud date Amount 2414' FNL, 2357' FEL, Sec. 3, T11N, R9E, UM 1 1/3/95 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 2X-18 7700' MD 2357 ~ TD feet 14.0' ~ 300' MD feet 2560 6386' TVD feet 16, To be completed for deviated wells 17. Anticipated pressure (see 2O AAC 25.035(e)(2)) Kickoff depth 1000' feet Maximum hole angle 39.2° Maximurnsurface 2006 psig At total depth (TVD) 3400 psig 18. Casing program Settin~i Depth size Specifications Top Bottom Quantit7 of cement Hole Casing Weight Grade Coupling Len~lth MD 3VD MD TVD (include stage data) 24" 16" 62.5# H-40 Weld 80' 41° 41' 121' 121' +200 CF 9.875" 7.625" 29.7# L-80 LTC 3790' 41' 41' 3831' 3388' 600 Sx Arcticset III & HF-ERW 520 Sx Class G 6.75" 5.5" 15.5# L-80 LTCMOD 7659' 41' 41' 7700' 6386' 170SxClassG HF-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor '~ ED Surface Intermediate '~,. i '~ Production LinerOCT 2 5 1995 Perforation depth: measured true vertical /-~35~a Lid & Gas Cons, Commission 20. Attachments Filing fee X Property plat D BOPSketch X Diverte?'~l~[~"u~( Drilling program X Drilling fluid program X Time vs depth plot E] Refraction analysis D Seabed report D 20 AAC 25.050 requirements X 21. I hereby certify that the foregoing is true and correct to the best of my knowledge t~ ~.~~r -- ~ requirements I Signed ; Title Drill Site Develop. Supv. Date Commission Use Onl~/ I PP771.,d~ Isee c°ver letter f°r Permit Number A Conditions of approval Samples required E] Yes J~ No Mud log required E] Yes [] No Hydrogen sulfidemeasures [~ Yes E] No Directional surveyrequired ~;~ Yes D No Required working pressure for BOPE D 2M [] 3M D 5M B 10M D 15M Other: ORIGINAL SIGNED BY' RUSSELL A. DOUGLA~ .... by order of Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triolicate ,, . e . . . 1 . = 10. 11. 12. 13. 14. 15. 16. 17. GENERAL DRILUNG PROCEDURE KUPARUK RIVER FIELD 2X-17 Move in and rig up Parker #245. Install diverter system. Drill 9-7/8" hole to 7-5/8" surface casing point (3,831')according to directional plan. Run and cement 7-5/8" casing. Install and test BOPE to 3000 psi. Test casing to 2000 psi. Drill out cement and 10' of new hole. Perform leak off test to 12.5 ppg EMW. Drill 6-3/4" hole to total depth (7,700') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 5-1/2" casing string. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) ND BOPE. NU tubinghead & either full opening valve (if logging planned) or master valve and upper tree assembly (if no logging planned). Note: As a dedicated producer, no cased hole cement bond logs will be run unless there are problems with the cement job. Secure well and release rig. Move in and rig up Nordic #1. Install and test BOPE. Pressure test 5-1/2" casing to 3500 psi. Run completion assembly. Set and pressure test packer. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig in preparation for perforating. OCT 2 5 'i995 0il & Gas' Cons. C0mmissior~ Anchorage DRILLING FLUID PROGRAM Well 2X-17 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 15-25 15-35 50-80* 5-15 15-40 10-12 9.5-10 +_10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes' Weight up to TD 11.6 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% ~r, ,,/ OCT 2 5 1995 Alaska 0il & Gas Cons. Commission Drilling fluid practices will be in accordance with the appropriate regulation'§'~'~'f~d in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur before a surface pressure of 2,006 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest existing well to 2X-17 is 2X-18. As designed, the minimum distance between the two wells would be 14.0' @ 300' MD. Annular Pumping Activities' Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of an existing well. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2X-17 surface/production casing annulus will be filled with diesel after setting the 5-1/2" casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, the annulus will later be sealed with cement from the surface shoe to the base of the permafrost, with Arctic pack fluid or diesel from the base of the permafrost to the surface, if the surface shoe is within 200' TVD of the top of the hydrocarbons. Alternatively, if the hydrocarbons are far below the shoe then sufficient cement volume will be pumped during the production cement job to cover the formation. It is requested that 2X-17 be permitted for annular pumping occurring as a result of the drilling project on DS 2X, per proposed regulations 20 AAC 25.005 (k). Any zones containing significant hydrocarbons will be isolated prior to initiating any annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Surface casing will be set in the Creatceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The 2X surface casing shoes will be set _+100' vertical below the base of the West Sak into the heart of the shales. Drillin~l Area Risks: Risks in the 2X-17 drilling area include lost circulation and high pressures in the Kuparuk formation. Lost circulation above the Kuparuk will be addressed with lost circulation matedal (LCM) and reduced circulating rates as needed. 5-1/2" casing will be topset above the Kuparuk and either Nordic Rig #1 or a coiled tubing unit will drill out a 4-3/4" hole, and run a 3-1/2" liner to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 11.6 ppg will provide sufficient overpressure to safely ddll, trip pipe, and cement. The 7-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. 0CT 2 5 1995 Alaska 0il & Gas Cons. Commissior) Anchorage Creoted by : jones For: D PETRASH Date plotted : 13-0ct-95 Plot Reference is 17 Version ~[5. Coordinates ore ;n feet reference slot True Vertical D~pths ore reference RI(B (Parker t~245). 350 0 o 700 1050_ 1.4.00_ ,.,j.=.. 1750_ © _ (~ 2100_ _ 2450. 0 - ~ 2500. e~ I _ 3150_ 3500_ 3850_ _ 4200_ 4550_ -- 4900_ 5250_ 5600_ 5950_ 6300_ 6650 ARCO ALASKA, Inc. Structure : Pod 2X Well : 17 Field : Kuparuk River Unit Location : North Slope, Alaska Scale 1 : 175.00 East 350 0 350 700 1050 1400 1750 21 O0 2450 2800 ,3150 3500 I I I I I I I I I I ~ I I I I I I I I I I I 24.50 RKB ELEVATION: 118' TARGET LOCATION: ~ - SEC. 3, T11N, RgE ~,... ~/ TARGET /OA 'xz 1750 'TVD=6231 / ~'ee. '~o.. - TMD= 7500 DEP= 3713 / '~ '> - NORTH 2105 ~ 14-00 EAST 3059 /.~,., - KOP TVD:IO00 TMD:IO00 DEP=O 3.00 / '~"6~ - o / % _,o o ~ ',2.00 ~ - ~ 15.oo B/ PERMAFROST TVD=1510 TMD=1516 DEP=69 .,,~% ~ 33.00 T/ UGNU SNDS ~=2034 TMD=2093 DEP=304 ~ ~**r ~ 39.00 EOC ~D=2207 TUD=2307 DEP=450 ~ '%~ ~+~e. 0 K SNDS W0=2612 TMD=2829 DEP=760 350 ,,~ B/ W SAK SNDS ~D=3280 TMD=3691 DEP=1305 N 55.47 DEG E %~ 7 5/8" CSO PT WD=3388 TMO=3831 0EP=1593 ~ ~ SNDS WD=3495 TMD=3969 DEP=1481 3713' (TO TARGET) AVERAGE ANGLE 39.21 DEG D=4720 TMD=5550 DEP=2480 B/ HRZ ~D=5647 TMD=6746 DEP=3237 ~ K-1 ~=5790 TMD=693~ DEP=3353 ~D~5 TM~7028 DEP=3415 ~ T/ C UN~ ~D=5869 TM0=7033 OEP=3418 ~ T/ B UNIT WD=5971 TMD=7165 DEP=5501 T~GET - B/ KUP SNDS ~ T/ A UNiT WD=6~02 mD=7334 DEP=3608 , , , , , , , , , , , , , , , , , , , , , , , ' ' ' OCT 25 ~995 0 350 700 1050 1400 1750 2100 2450 2800 3150 3500 3850 4200 Scale 1 : 175.00 Vertical Section on 55.47 azimuth with reference 0.00 N, 0.00 E from slot ~17 TI3 LOCATION: 2414' FNL, 2557' FEL SEC. 5, TllN, RgE /x I I Z 0 Ataska Oil & Gas Cons. Commissi0~ Anchorage Cre~ted by : jones For: D PETRASI] Dote plotted : 13-0ct-95 Plot Reference is 17 Version ~5. Coordinotes ore in feet reference slot t~17, True Verficol Depths ore reference RKB (Porker Scole 1 : 20.00 ARCO ALASKA, Inc. Structure : Pod 2X Well : 17 Field : Kuparuk River Unit Location : North Slope, Alaska East --> /k f- 520 440 400 360 320 280 240 2OO 160 120 120 160 2OO 40 0 40 80 120 160 200 240 280 320 360 400 440 480 520 560 600 I I II II II II II II I I I I I I II II I I I I I . 1000 lOO0 1100 1100 1200 1200 13O0 1500 2200 % 1500 1800 5700 1900 1600 3900~ ZOO0 9O0 340(: 1700 1800 1400 1300 1200 1100 1000 1900 40 0 40 80 120 160 200 240 280 320 360 400 440 480 520 560 600 Scale 1 ' 20.00 E o st> 520 48O 44-0 400 360 320 280 24o /~ 200 ] le0 Z 0 ~o ~ 40 4O 8O 120 160 " 200 0 Created by : jones For: D PETEASI,] D~te plotted : 13-0ct-95 Plot Reference is 17 Version ~5. Coordinetes ere in feet reference slot ~17. True Vertical Depths are reference RKB (Parker ARCO ALASKA, IIIC. Structure : Pad 2X Well : 17 Field : Kuparuk River Unit Location : North Slope, Alaska 880_ _ 840_ 800_ 360 320 280. 0 240_ - .. · - 200_ U') 160 East 440 480 520 560 600 640 680 720 760 800 840 880 920 960 1000 1040 1080 1120 I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I I 880 .840 _800 _ _760 _ _720 _ _680 - _640 _ _600 A - I _560 J -- _520 Z ~80 0 - _440 ~'- _ _400 _ _360 _ _320 _ _280 _ _24-0 O - ~ _200 ' ' 160 0 I I I I I I I I I I I I I I I I I [ I I II I i I I I I I I I I I 440 480 520 560 600 640 680 720 760 800 840 880 920 960 1000 1040 1080 1120 Scale 1 ' 20.00 E a st-- -- > ~i'JPARUK RIVER UNI'i~'~' 20" DIVERTER SCHEMATIC I4 I 5 3 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. . . MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20" - 2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PSI ANNULAR PREVENTER. DKP 1 lP~94 ,6 , 5 4 13 5/8" 5000 PSI COp STACK AQQUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. ?_ ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER UMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. I BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER. 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. 6. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE MNES. 7. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, MNES, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BOTTOM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BUND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. 10. OPEN BUND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. 12. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. VBRS WILL ACCOMODATE 3-1/2" TO 5-1/2" PIPE ODS. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5/8" - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL UNES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR ~ ~ ~4P~eq::~!~l/T'dO-~.~ ' OllJOH Z (%/0 =o~ ..~o/~o ~///'
