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Home My WebLink About181-025MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Tuesday, June 14, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Matt Herrera P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL ConocoPhillips Alaska, Inc. 1C-06 KUPARUK RIV UNIT 1C-06 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/14/2022 1C-06 50-029-20564-00-00 181-025-0 W SPT 6326 1810250 1582 2530 2531 2532 2512 182 197 199 200 4YRTST P Matt Herrera 5/17/2022 MIT-IA performed to 1800 PSI per Operations. Test ran out an additional 15 Min due to fluctuating tubing pressure and injection temps 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:KUPARUK RIV UNIT 1C-06 Inspection Date: Tubing OA Packer Depth 500 1800 1765 1740IA 2514 199 45 Min 1725 60 Min Rel Insp Num: Insp Num:mitMFH220518131438 BBL Pumped:1.4 BBL Returned:1.2 Tuesday, June 14, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 James B. Regg Digitally signed by James B. Regg Date: 2022.06.14 13:50:47 -08'00' ry. KUP [NJ WELLNAME IC -06 WELLBORE 1C_06 ConocoPhillips Well Attributes Max Angle S MD TD FielE Name WeIIWreAPYOWI WelleoreataWe cl^^l MOnttKBI Act Sun MKBI ft1a5)'`a° hK. 5DI12AJDSgEno IN a Bonn m vna ISDI lGeSmU9a:A'.17PM I Last Tag Vagal.1a. SOPA Annotation Depth (Me) I End Data we11Wre I Last Mctl By ............................................................................................ HANGEft:me ,ni.. CONDUCTOR; 3Saile.0 I VLv; i,211fi SURFACE 31.1,3267'o- GASLIFi;Bmaa pan'tInges PACKER. 8,1515 RIPPLEIB.ta33 OVERSHOT: e331.9 UAR.Rel PACKER: U.E I11pp.;B3a9.3 'nmg.loaBaee.D- Ehh ip01a.B PRODUCTION ',H.610,Y2Sa- 0."A,V40 i Last Tag: RKE 9,fi58.0 I 8/9/2019 iC-06 lopecUl Last Rev Reason Anngamon End Dale Wellbore last MI By Rev Reason: Add Liner CTD liner top 19/62019 1C -p6 be gust, Casing Strings Casing Deactlpron 100 Into m(in) Top(nXGI Set Depm (nK8) sat DaplM1 (rvoi... wvlan (L.. cmc¢ rop rnreaa CONDUCTOR 16 15.Ofi 32.0 658 65.0 62.5a HAO WELDED Casing Description OD tin) IO and RISSB) Set OeptM1(nKal Set Dean I Iva...ssatin ll...Gmes TOPTbeatl SURFACE 10 Y4 9.95 31.3 3,287.0 2,685.1 45.50 K55 BUTT Lasing De¢ramon US unl ID pnl TOP MKBI I a. apm(MB) . map. (,go)... Wtllenu Gratle Top Thread PRODUCTION ] 628 29.6 10,2258 ],090.1 2680 K-55 BTC Tubing Strings Tiding De¢anpgon Sbbg Ma... loon( TOPMKei saroepb (n.. sal Dapm (rvm(... wt 6bllti Grade Top Connection TUBING 2p0]WO 312 2.99 26.9 9,232.9 6,387.5 9.30 L-00 8rb Completion Details Top(IVD) Top ba NominalSPFEn Top MKe) MillCI Ikm De¢ Co. m I, 26.9 26.9 1 0.011 lHANGER FMC Tubing HANGER 3.5110 2,237.6 2,021.0 4375 ISAFETY VLV 3.5"TRMAXXSE Safety Valve (Serial #HVS-]03) 2.812 9,135.5 8,313.4 39.06 PBR Baker PER seal assembly (pinned 409#) Wf2.39'spamout 3.000 9,151.5 63258 39.54 PACKER Baker FHL Packer (pinned 60M#shear) 3C00 9,193.2 6357.6 40, NIPPLE 2.813'XNipple 2,813 9,2319 8,386.7 4180 JOVERSHOT Baker Tubing Stub Overs OOta l'spaeOut 3.610 Tubinp Descdptbn Rbinp Ma... IO (In) Top in eel oepN M.. Set DeptF (No)(... WtphXq Geaie Top Connedbn TUBING 1993 WO 53/4 4.37 9,2322 9,2615 6,423.4 Completion Details Top InKB) Top(rvD) TOp Incl Nominal (flKB) (°) Ilam De¢ Com P I 9,255.2 6,4048 42.38 BBR BAKER EL -1 SBR(no full joint, TBG string Mora Moral SER ODAD) 4.375 TULIa, Dascriplian ohnp tm Ill (in) set Patients) ll Death M Death (TVD) (._ .O.S. Gratle Top Connectlon TUBING Original 312 299 281.5 9,38.72 6,498.] 9.20 K-55 BTC Completion. uemus - - - Tap(ND) TopinOlminal Top Mae) (.KS) r) I Ram Des No Cam ID(in) 9,281.5 6,423.4 43.04 PACKER BAKER FHL PACKER 3.000 9,349.3 6,472.1 44.98 NIPPLE CAM DNIPPLENO MILLEDT.1st, N llual pple 28110 behind pipe: 1C-06 L1-02 CTO liner. 9,380.9 6,4943 45.93 SOS 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top MKB) I Top(rvD) ME) I Top met (•) Des Com qan Date mdU 9,2]4.0 6,411.9 42.85 Liner Top.Lmmup into mother bOrel CTD2 L-02 Liner p. 91]02019 1 1.992 10,026.0 6,9464 44.00 Fish Vann Gun Left from original perf 101 long 1612511981 Perforations & Slots Top W13) at. KB M 1 OUR RVD) Uses) BIm jNO) MB) Linked IDne Data $hot Den¢ UshobM ) Type Com 9,4100 a.como i 65104 1 ..6Am6 I.Pu I D,C-0, C- 3, 1C-0fi 3I31I1981 12.0 Mandrel Inserts r al N Top (nKB) TOp"D) (MUS Make I Madel OD(in) is -Type VeNe latcM1 Type PoRSixe (in) TRO qUn (p¢9 Run Dah LOm 1 9,0]9.2 6,269.2 Camm MMG I 1/2 GASLR-I DMY BK I 0.000 30 11/11200] Notes: General & Safety Eadome Araucanian 12311993 NOTE: WORKOVER 42]2094 NOTE. WAIVERED WELL. T x IA COMMUNICATION 12/2KIZO1p NOTE: VIEW SCHEMATIC vaAMSILI Scheraido O 1 G06 SET WHIPSTOCK DTTM JOBTYP SUMMARYOPS CTART 9/11/19 DRILLING MOB 1G to 1C pad. Spot modules, Rig up. Accept Rig SIDETRACK @ 10:00. Complete full BOPE test. tst witness waived by Adam Earl, AOGCC. Fill Coil. Install Coil Tubing connector. Head up E -Line. 9/12/19 DRILLING Complete heading up E -line. PD BHA #1 with 2.80 D - SIDETRACK 331 mill. Perform clean out to 9450. Trip out. P/U BHA #2. Northern solutions HEW whipstock. Trip in and set TOWS @ 9430 Oriented o high side. Trip for window milling BHA #3 9/13/19 DRILLING Mill window 9432 to 9435', Rat hole to 9459. Trip out for SIDETRACK buils section BHA with 2.40 AKO motor. Trip in tie in for +3.5'. Log RA marker @ 9437.5'. TOWS=9430.5'. Drill build to 9709 Midnight depth 9/14/19 DRILLING Complete build section to 9745, Avg DLS 47.250. Drill SIDETRACK lateral 9745 to 10,586'. Swap to new mud system 1 @ 9745' MEMORANDUM TO: Jim Regg �c1 P.I. Supervisor I� FROM: Lou Laubenstein Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, October 21, 2019 SUBJECT: Mechanical Integrity Tests ConoccPhillips Alaska, Inc. I C-06 KUPARUK RIV UNIT 1C-06 Sre: Inspector Reviewed By:(g� P.I. Supry NON -CONFIDENTIAL Comm Well Name KUPARUK RN UNIT 1C-06 API Well Number 50-029-20564-00-00 Inspector Name: Lou Laubenstein Permit Number: 181-025-0 Inspection Date: 10/14/2019 Insp Num: mitLOL19101512] 125 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min IC-06 Type lnj 9 TVD 6sz6 Tubing zo6o 2060 - 2067 - 2066 ' LBBLfPumped: 1810250 Type Test SPT Test psi 1582 IA 1440 2900 2850 2840 1.6 BBL Returned: 15 pA 561 - 660 665 - 6w - Interval oTl-mR P/F P Notes: MIT -IA post lateral per PTD # 219-117 - y �tfZl1 1G-D(oL f Monday, October 21, 2019 Page 1 of 1 181020 3 13 5 2 WELL LOG TRANSMITTAL #905933390 To: Alaska Oil and Gas Conservation Comm. October 16, 2019 Attn.: Natural Resource Technician 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multi Finger Caliper: 1 C-06 Run Date: 8/25/2019 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of. Fanny Sari, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 1C-06 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-029-20564-00 RECEIVED OCT 2 3 2019 AOGCC PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com Date: DIMlIq Signed: VS -11 . PrGActive Diagnostic Services, Inc. WELL LOG TRANSM17 TAL To: AOGCC Natural Resources Technician 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE: Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection (Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: 1) Caliper Report 2) Signed Print Name: 101�t> 3 131 3 ProActive Diagnostic Services, Inc. RECEIVED Attn: Diane Williams OCT 0 9 2019 130 West International Airport Road Suite C n ®GCC Anchorage, AK 99518 0"1 l�l� i2dsanchorage(rilmemorvloa.com 08 -Sep -19 1C-06 CD 50-029-20564-00 Date: dJ lx)� PROACTIVE DIAGNOSTIC SERVICES, INC., 130W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8961 FAX: (907)245-8952 E-MAIL: PDSANCHORAGEi 181Q-)'5 31313 —__ CASED Memory Multi -Finger Caliper HOLE Log Results Summary Company: ConocoPhillips Alaska, Inc. Log Date: September 8, 2019 Log No.: 14401 Run No.: 1 Pipe Description: 3.5 inch 9.3 Ib. L-80 8rd Pipe Use: Tubing Pipe Description: 7 inch 26 Ib. K-55 Pipe Use: Casing Well: Field: State: API No. Top Log Interval: Bottom Log Interval: Top Log Interval: Bottom Log Interval: Inspection Type : Pre -CTD Sidetrack Prep Inspection COMMENTS: IC -06 Kuparuk Alaska 50-029-20564-00 8,979 Ft. (MD) 9,286 Ft. (MD) 9,286 Ft. (MD) 9,483 Ft. (MD) This caliper data is tied into the gamma, K1 @ 9194' MD in the PDC Log attached. This log was run to assess the condition of the casing with respect to corrosive and mechanical damage to assist in setting the High Expansion Wedge. The caliper recordings indicate no significant I.D. restrictions at 9,430' where the High Expansion Wedge is planned to be set, however the caliper recorded perforations from 9,412 feet to the end of the log. The caliper recorded clean pipe from approximately 9,365 feet to 9,412 feet. A 3-D log plot of the caliper recordings across the 7 inch liner logged is included in this report. The 7 inch casing logged appears to be in fair condition with respect to internal corrosive and mechanical damage. Outside of the perforation interval, a maximum wall penetration of 29% is recorded in a line of pits in joint 293 at 9,338 feet. Recorded damage appears as line of pits and isolated pitting. No significant areas of cross-sectional wall loss are recorded throughout the 7 inch casing logged. The caliper recordings indicate deposits throughout the casing logged, with heavy deposits recorded in the perforation interval, restricting the I.D. to 4.38 inches at 9,473 feet. A graph illustrating the minimum recorded diameters on a joint -by -joint basis across the casing logged is included in this report. The caliper recordings indicate the 3.5 inch tubing logged appears to be in good to fair condition, with a maximum wall penetration of 28% recorded in an isolated pit in joint 289 at 9,131 feet. Recorded damage appears as isolated pitting. No significant areas of cross-sectional wall loss are recorded throughout the 3.5 inch tubing logged. The caliper recordings indicate deposits throughout the majority of the joints of the 3.5 inch tubing, restricting the I.D. to 2.74 inches at 9,167 feet. A 3-D log plot of the caliper recordings and a graph illustrating the minimum recorded diameters on a joint -by -joint basis of the 3.5 tubing logged are included in this report. 7 INCH CASING - MAXIMUM RECORDED WALL PENETRATIONS: Dcscnpt,on I k' 1: Nc,u PeneI Depth Line of Pits 29 293 9,338 Ft. (MD) Line of Pits 23 294 9,368 Ft. (MD) Isolated Pitting 22 292 9,315 Ft. (MD) No other significant wall penetrations are recorded outside of the perforation intervals 7 INCH CASING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 3%) are recorded outside of the perforation intervals. READ Cased Hole Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: ANSA-NorthAmerica(alreadcasedhole.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 7 INCH CASING - MAXIMUM RECORDED ID RESTRICTIONS: No other significant I.D. restrictions are recorded throughout the 7 inch casing logged 3.5 INCH TUBING - MAXIMUM RECORDED WALL PENETRATIONS: Isolated Pitting M9 mnwn, Recorded Diameters Jan - 9,131 Ft. (MD) Heavy Deposits 4.38 inches 296 9, 473 Ft. (MD) Deposits 5.88 inches 293 9, 328 Ft. (MD) Deposits 5.88 inches 292 9, 312 Ft. (MD) Deposits 5.96 inches 294 9, 369 Ft. (MD) No other significant I.D. restrictions are recorded throughout the 7 inch casing logged 3.5 INCH TUBING - MAXIMUM RECORDED WALL PENETRATIONS: Isolated Pitting 28 289 9,131 Ft. (MD) Isolated Pitting 26 290 9,162 Ft. (MD) Isolated Pitting 24 288 9,077 Ft. (MD) 3.5 INCH TUBING - MAXIMUM RECORDED CROSS-SECTIONAL METAL LOSS: No significant areas of cross-sectional wall loss (> 2%) are recorded throughout the tubing logged. 3.5 INCH TUBING - MAXIMUM RECORDED ID RESTRICTIONS: nes, � mw,, Deposits 2.74 inches 290 9,167 Ft. (MD) Deposits 2.75 inches 287 9,018 Ft. (MD) No other significant I.D. restrictions are recorded throughout the tubing logged. C.Goerdt HY. Yang J. Condio -:r(s) Analyst(s) .psi READ Cased Hole Inc. / P.O. Box 1369, Stafford, TX 77497 Phone: (281) 431-7100 or (888) 565-9085 Fax: (281) 431-7125 E-mail: ANSA-NorthAmericaCalreadcasedhole.com Prudhoe Bay Field Office Phone: (907) 659-2307 Fax: (907) 659-2314 CASED er Multifin Caliper 3D Lo Plot -- HOLE g p g Company: ConocoPhillips Alaska, Inc. Field : Kuparuk Well: 1C-06 Date: September 8, 2019 Description : Detail of Caliper Recordings Across 7" Casing Logged Correlation of Recorded Damage to Borehole Profile 'Pipe 1 3.5 in (8,978.6'- 9,286.6') Well: iC-06 Pipe 2 7. in (9,286.6-9,4832) Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Survey Date: September 8, 2019 ■ Approx. Tool Deviation M ■ Approx. Borehole Profile 8,979 MMG" A i p I � I c_ L 290 9,161 v 295 9,408 296 9,450 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) Bottom of Survey = 296 ■ Perforations CASED HOLE Minimum Diameter Profile Survey Date: September 8, 2019 Tool Type: Well: 1 C-06 Field: Kuparuk Company: Conoco Phillips Alaska, Inc. Country: USA Minimum Diameter Profile Survey Date: September 8, 2019 Tool Type: UW MFC 24 Ext. No. 218183 Tool Size: 1.69 inches Tubing I.D.: 2.992 inches Minimum Measured Diameters (in.) 1.75 2 2.25 25 2.75 286 287 287.1 287.2 287.3 288 288.1 288.2 288.3 L 288.4 Z Z 288.5 c O 289 289.1 290 290.1 290.2 290.3 290.4 2905 291 291.1 8,979 9,004 9,035 9,045 9,054 9,064 9,095 9,102 9,115 9,118 9,125 9,129 9,159 9,161 9,191 9,199 9,216 9,22_2 9,247 9,254 9,286 s a v Pipe Nom.CD Weight Grade & Thread Nom.ID Top Depth Bottom Depth 3.5 in. 9.3 DDf L-80 8rd 2.992 in. 8,979 ft. 9,286 ft. Penetration (% wall) Damage Configuration (body) 10 8 6 4 2 0 Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos. Hole Number of joints damaged4totaL= 6) 6 0 0 0 0 Damage Profile (% wall) SEEN Penetration body Metal loss body 0 50 100 GLM 1 (8:30) Bottom of Survey = 291.1 CASED HOLE Body Region Analysis Well: 1C-06 Survey Date: September 8, 2019 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pipe 3.5 in. 9.3 ppf L-80 8rd Analyst: Yang Pipe Nom.CD Weight Grade & Thread Nom.ID Top Depth Bottom Depth 3.5 in. 9.3 DDf L-80 8rd 2.992 in. 8,979 ft. 9,286 ft. Penetration (% wall) Damage Configuration (body) 10 8 6 4 2 0 Isolated General Line Other Hole/ Pitting Corrosion Corrosion Damage Pos. Hole Number of joints damaged4totaL= 6) 6 0 0 0 0 Damage Profile (% wall) SEEN Penetration body Metal loss body 0 50 100 GLM 1 (8:30) Bottom of Survey = 291.1 _= CASED HOLE Well: 1C-06 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Pipe Description 3.5 in. 9.3 ppf L-80 8rd Tubing loint Tabulation Sheet Survey Date: September 8, 2019 Analyst: Yang _ Nom. ID Body Wall Top Depth Bottom Depth 2.992 in. 0.254 in. 8,979 ft. 9,286 ft. Joint Jt. Depth No. (Ft.) Pen. Upset (in.) Pen. Body (in.) Pen. Metal % Loss % Min. I.D. (in.) Comments Damage Profile (%wall) 0 50 100 286 8979_ 0 0.04 17 0 2.77 w Pit' De''its. Shalloti 287 9 Q4 0 0.03 12 0 2.75 De osits. 287.1 9035 0 01 5 0 '.2.78 Pu D it. 287.2 9045 0 0 0 i 2.82 MMG i Latch @ 8:30 287. 9054 0 0.04 14 2 2.78 Pu Denosits. 288 9064_ 0 0.06 24 1 2.76 Isolated Pittin Deposits. 288.1 9095 0 0.03 12 0 2.78 Pu Deposits. 288.2 9102 0 0 2.76 Baker PBR seal assembl 288.3 9115 0 0 0 0 2 82 Baker FHL Packer 288.4 9118 0 0.02 7 0 2.80 Pu De osits. 288.5 912 0 0.01 3 0 2.84 P Lt. D osits. 2_89 9129 0 0.07 28 2.76 Isolated Pitting Deposits. 289.1 1 9 0 0 0 0 2.7I 2.813 X Nipple 290 9161 0.04 0.07 26 0 2.74 Isolated Pittin D osits. 290.1 9191 0 0.04 17 0 2.83 Pu Shallow Pitting Lt. De osits. 290.2 290.3 9199 9216 0 0 0 0 0 0 0 0 2.88 2.85 Baker Tubing Stub Overshot + 1's 1 Pup Lt. Deposits. ace out 290.4 9222 0 0 0 02 Baker EL -1 SBR 290.5 9247 0 0 2.8 Baker FHL Packer _ 291 9254 0 0.04 15 2.90 Shallow Pitting. Lt. Deposits. 291.1 9286 0 0 0 0 1 2.78 1 Camco D Ni ple and Tubing Tail Penetration Body Metal Loss Body Page 1 CASED HOLE Well: 1 C-06 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Cross-sectional Illustration Survey Date: September 8, 2019 Tool Type: UW MFC 24 EM. No. 218183 Tool Size: 1.69 inches No. of Fingers: 24 Cross Section for Joint 289 at depth 9,130.950 ft. Tool speed = 51 Nominal ID = 2.992 Nominal OD — 3.5 Remaining wall area = 99% Tool deviation = 42° Finger = 8 Penetration = 0.071 in. Isolated Pitting 0.07 in. = 28% Wall Penetration HIGH SIDE = UP CASED HOLE Well: 1 C-06 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Cross-sectional Illustration Survey Date: September 8, 2019 Tool Type: UW MFC 24 Ext. No. 218183 Tool Size: 1.69 inches No. of Fingers: 24 Cross Section for Joint 290 at depth 9,162.050 ft. Tool speed = 53 Nominal ID = 2.992 Nominal OD - 3.5 Remaining wall area = 99% Tool deviation = 39° Finger = 9 Penetration = 0.066 in. Isolated Pitting 0.07 in. = 26% Wall Penetration HIGH SIDE = UP CASED HOLE Well: 1 C-06 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Cross-sectional Illustration Survey Date: September 8, 2019 Tool Type: UW MFC 24 Ext. No. 218183 Tool Size: 1.69 inches No. of Fingers: 24 Cross Section for Joint 290 at depth 9,167.310 ft. Tool speed = 52 Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area= 100% Tool deviation = 41' Minimum I.D. = 2.741 in. Deposits Minimum I.D. — 2.74 in. HIGH SIDE = UP CASED HOLE Cross-sectional Illustration Survey Date: September 8, 2019 Tool Type: Well: 1 C-06 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Cross-sectional Illustration Survey Date: September 8, 2019 Tool Type: UW MFC 24 Ext No. 218183 Tool Size: 1.69 inches No. of Fingers: 24 Analvst: YanR Cross Section for Joint 287 at depth 9,018.030 ft. Tool speed - 50 Nominal ID = 2.992 Nominal OD = 3.5 Remaining wall area= 100% Tool deviation = 38° Minimum I.D. = 2.754 in. Deposits Minimum I.D. = 2.75 in. HIGH SIDE = UP CASED LN �HOLE Minimum Diameter Profile 6 Survey Date: September 8, 2019 ruk Tool Type: UW MFC 24 Ext. No. 218183 coPhillips Alaska, Inc. Tool Size: 1.69 inches Tubing I.D.: 6.276 inches Minimum Measured Diameters (in.) 1.75 2 292 293 295 296 s a d Well: 1C-0 Field: Kupa Company: Cono Country: USA 1.75 2 292 293 295 296 s a d Pipe Nom.OD Weight Grade & Thread Nom.ID Top Depth Bottom Depth 7 in. 26 ppff __ K-55 6.276 in. 9,287 ft. 9,483 ft. 10 8 6 4 2 0 Penetration (% wall) 0 to 20 to 40 to over 20% 40% 85% 85% NumbQr of' in s analyzed (total = 51 0 3 0 0 Damage Configuration (body) 10 8 6 4 2 0 Isolated General Line Other Hole / Pitting Corrosion Corrosion Damage Pos. Hole Damage Profile (% wall) Penetration body Metal loss body 0 50 100 292 293 294 295 296 Bottom of Survey = 296 Perforations CASED HOLE Body Region Analysis Well: 1C-06 Survey Date: September 8, 2019 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Pipe 7 in. 26 ppf K-55 Analyst: Yang Pipe Nom.OD Weight Grade & Thread Nom.ID Top Depth Bottom Depth 7 in. 26 ppff __ K-55 6.276 in. 9,287 ft. 9,483 ft. 10 8 6 4 2 0 Penetration (% wall) 0 to 20 to 40 to over 20% 40% 85% 85% NumbQr of' in s analyzed (total = 51 0 3 0 0 Damage Configuration (body) 10 8 6 4 2 0 Isolated General Line Other Hole / Pitting Corrosion Corrosion Damage Pos. Hole Damage Profile (% wall) Penetration body Metal loss body 0 50 100 292 293 294 295 296 Bottom of Survey = 296 Perforations 'Penetration Perforations Metal Loss Perforations Page 1 Penetration Body Mehl Loss Body CASED HOLE Joint Tabulation Sheet Well: 1C-06 Survey Date: September 8, 2019 Field: Kuparuk Analyst: Yang Company: ConocoPhillips Alaska, Inc. Pipe Description Nom. ID Body Wall Top Depth Bottom Depth 7 in. 26 ppf K-55 Casing _ _ 6.276 in. 0.362 in. 9,287 ft. 9,483 ft. joint jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (in.) (in.) % (in.) 0 50 100 292 9287 0 22 2 5.88 Isolated Pittin Deposits. 293 9319 --Q.08 0.07 0.11 29 2 5.88 Line of Pits Deposits, 40 0.08 23 3 5.96 Line of Pit . Lt De osits. 295 9408 0.08 0.26 0.47 100 45 0.33 91 9 6.03 4.38 Perforations Lt. Deposits. Perforations Heavy Deposits. 296 9450 'Penetration Perforations Metal Loss Perforations Page 1 Penetration Body Mehl Loss Body CASED HOLE Cross-sectional Illustration Well: 1 C-06 Survey Date: September 8, 2019 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Cross Section for Joint 293 at depth 9,337.721 ft. Tool speed = 53 Nominal ID = 6.276 Nominal OD = 7 Remaining wall area = 97% Tool deviation = 42° Finger = 16 Penetration = 0.105 in. Line of Pits 0.11 in. = 29% Wall Penetration HIGH SIDE = UP 1 CASED HOLE Cross-sectional Illustration Survey Date: September 8, 2019 Tool Type: Well: 1 C-06 Field: Kuparuk Company: ConocoPhillips Alaska, Inc. Country: USA Cross-sectional Illustration Survey Date: September 8, 2019 Tool Type: UW MFC 24 Ext. No. 218183 Tool Size: 1.69 inches No. of Fingers: 24 Analyst: Yang Cross Section for Joint 294 at depth 9,368.391 ft. Tool speed = 53 Nominal ID = 6.276 Nominal OD = 7 Remaining wall area = 99% Tool deviation = 54° Finger = 15 Penetration = 0.083 in. CASED HOLE Cross-sectional Illustration Well: 1C-06 Survey Date: September 8, 2019 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Tubing: 7 in. 26 ppf K-55 Analyst: Yang Cross Section for Joint 296 at depth 9,472.671 ft. Tool speed = 53 Nominal ID = 6.276 Nominal OD = 7 Remaining wall area = 100% Tool deviation = 47° Minimum I.D. = 4.378 in. Heavy Deposits Minimum I.D. = 4.38 in. HIGH SIDE = UP CASED HOLE Cross-sectional illustration Well: 1 C-06 Survey Date: September 8, 2019 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 218183 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA No. of Fingers: 24 Tubing: 7 in. 26 ppf K-55 _Ana�st: Yang Cross Section for Joint 293 at depth 9,327.961 ft. Tool speed = 54 Nominal ID = 6.276 Nominal OD = 7 Remaining wall area = 98% Tool deviation = 52° Minimum I.D. = 5.878 in. Deposits Minimum I.D. = 5.88 in. HIGH SIDE = UP ConocoPhillips Alaska, Inc. ✓ Drilling & Wells ConocoPhillips Coiled Tubing Drilling Alaska 1C-06 PDC Loa waaw 9140 a y 9150 9160 = 9170 = 9180 9190 9200 9210 9220 9230 9240 9250- 9260 9270 - 6220 - - 6230 - 6240 - - 6250 - 6260 - 6270 -. 6280 - - 6290 - 6300 - 6310 - - 6320 Q 0 August 30, 2019 1C-06 Pre -CTD Procedure Page 4 of 5 Ar--\ KUP INJ WELLNAME iC-06 WELLBORE 1C_06 CO�IOCOPIIIIIIPS Alaska, Inc. 111WI Well Attributes Max Angle&MD TO ReIn Name WaIIMaPPINWI Wdkaresterua II') MD(7.9) Atl gain take) K IJPARUK RIVER UNIT 500292056400 IN3 n800 4,200.00 10,2430 Comma. H16 finum 0. Ameal Tube GKB-0n p9 rIUp Paka»beta SSSV'. TRDP Last W0: 111VK07 3901 V31/1981 1019, 111.1. 11:DS An lLntT&9 Vat.1anemalklame0 Anneal I general 1 End Date I wil Laa1Mo]By w,NGER.2aa COxglCigt:32pG.0 tool Al. 22326 SURFACE, 3?3a.]e>.p- Ger.17:e,9R] Pea: P,135smPlrvDl PMKER It1.5 NIPP E:91.2 OVERSHOL:1tA18 SeR', 8.255.2 PACKER', 92015 NIPPLE:93493 Pax: ..... FIm. III=. Pa0W 10N:Ha1028.9- Iasi Tag: RKD 9,4880 WW2019 1C leromp Last Rw Reason arnadtimI seem. I Watt a Last Moo By Rev Reewn: Tog I 718'2019 1C-0 fe"lop Casing Strings cmirg Dnaiptbn Go 9n1 IDlml TopmKB sn0epm(e.) sw Oapm lrv0)... wvLen p._Gr ao roPlxreea CONDUCTOR 16 1506 320 65.0 65.0 62.58 H<0 WELDED colla Dees moon OD(1n1 ID(MI Top MK01 5e, 0epm 1XN81 BM Dep%jiVBl... WBtar (I... GreEe Tap Txretl SURFACE 1034 9.95 31.3 328)0 2.685.1 4650 K-55 BUiT cslryBmlplbn bar Far ID9n1 TOP IRKBI sin Oplx areal BM Doe""ea)... yMen I, Grant Tap TnrM PRODUCTION 1 628 296 10,226.8 1,090.1 26.00 K-55 BTC TubingStHngs Tualy DaacrlpKon strinP ma.. mpnl Tapinne) Sm Cngx ln.. sn Bepu (lvD l... vn pdnl areae TOP Oanr.dun TUBING 2001 W0 31/2 299 26.9 9.2329 6.3975 930 L-80 8rtl Completion Details NFGVD) I TWI. Nm inel TW treat Iflxe) 1.1 Ham Dae can Ia(,.I 26.9 26.9 0.00 HANGER FMC Tubing HANGER 3.500 2.23]8 2,021.0 43,75 SAFETYVLV 35'TRMAXX-5E Safely VaNe(Serial B 11 5703) 2.812 9,135.5 6.313.4 39.06 PBR Baker PER seal assemWy(pinnflC 40MR W2.39' spaoemt 3.000 9151.5 6325.8 9.54 PA KER Baker FHL Peaker(pinned 60MB shear) 3. 7193.2 6,3576 40.7 NIPPLE %Nipple .81 9,231.9 6.386.7 41.8 OVERSHOT Baker Tubing Stub Overshm+!'spate out 3.610 r IH. Sel DeplH (NOI I... Wlllbltl Grado Tap eonreclim TUGmp Decrigbn emirq ma...lolln) Top(XKBI St.-, TUBING 3"5314 4.3) 9.2322 9.2815 6.42]4 Completion Details lK Tap M2. iaplrvD) Tap I- Inxal 1'1 eam Dee can Nanlnal to lip 2552 6.4 0 42.8 SBR BAKER EL -1 SE R(no fullloir4, TM sling showing SBR 00/10) 1 4.375 egx X.. bel oapM pVD1 L.. WlpdX) Gratle TapewrrHim Ma.. ID lint iap(XKB) Sal -an'' Tubinp oac"A"T "a"" TUBINGOri'mill 31/2 299 9,2815 9,3872 6,498.7 920 K-55 BTC Completion Retells ToP ecl xommm Tap IRKS) flKB) (') Ilam be, 10(in) 9,261.5 6.423.4 43.04 PACKER BAKERFHLPACKER 3.DDD 9,3493 6AY2.1 '0 Wo NIPPLE 'AMM DNIPPLE NO GO 275 938091 5 41tut 31 4593 1 505 12.992 Other In Hole (Wireline retrievable pl s, Valves, pumps, fish, allTaplrvOl rap Inas) Topl,cl IXKB) r) ae can RUa Dem blip 100260 6,946.4 44.00 Fisn I Vann Gun Left from original pe,f. 101 long 5/1981 Perforations& Slots TW(RKB) Kingman Tae I.e., e1M1nm(.' Unatllnna DM DW (a 1�t TYP Core 9,410.0 9,4n.0 6.514.4 6,585.6 UNIT E" ",U- 3' 1C -g6 W31119H 12.0 Mandrel Inserts e H taplBKB) TaP(IW) MKBI Make Mo1e1 OD (nl 6en Nlw Free leltl, TYta Pansiie IMI TROnun ans Run Die Cam 11 9,179.2 6269.2 Can1m Nue. I 112 GAb Ull DMV BK I Boor 0.0 1f I11120D7 i atenenl & Safety EAi Dam Anmuxnn 123!1993 NOTE: WORKOVER .2712004 NOTE:WAIVEREDWELL T%IACOMMUNICATION 127292010 NET VIEW SCHEMATIC wilAleeka Schemmic9.0 CASING /TUBING / LINER DETAIL 3-112" Sinale Completion WELL: IC -06 KRU ARCO Alaska, Inc. DATE: 1/23/93 Subsidiary of Adandc Richfield Company I 1 OF 1 PAGE 4tlantic-RlchfieldCompany (,J Drillin( -Completion—WorkoVAr t nr nf or Iaa SB T ; V L72/c�srr6 ' Well number ;Date r9. 6 1 d l Dislric ounty or parish) C %J1 Province or state 147 4 A.FleA Time distribution - hour Morn. Day Eve onlraotor ROWA Rig up anti FORa n/ !f 3 tear down Drilling normal c�u req,✓ 7 `yA7' z(, H -3 /('-SS d s siw s cows drimng na, Reaming Trips chane a 61t �.. r� p �n WGLr / ALG fZIIAr1022147 Drilling with partial returns2ZY_08= I n Z a'rr 7 zs a K'3 A' --54z IN O27,y Combating lost circulation29 DJ•� ry f. mtt,wu / 8AL(�, aoA•r r6e,6Ae 4 S/903-0 /. 629.3 Conditioningmu and circulating 2 J C LINTS / Z4 iG 3 AL-65S4711.0o 7, Fishing m..e�� SNep•; a-�r 53.7 Deviation aury $ `i — ZZ X�MV%„ 6� - - S 1. o .g lubricate rig 0• g %/inuSu SAtcrRS i1Cut 341,3S rJ3i0.O!pq off drilling tine 52 7%. y 7.G+� 2-3 &-c!; Bye ('�;s�u � �_3 9.0 Repair rig i r-... 7 ` I -% S 's Z. T est ofO.O.P�g Z1190 . 7"14 r, P, ze. 90 zl.qc Sidewall O Z .g / {conventional JDiDiamond a c 'o Wire line ,��,CAl2 LocA-6p Tl1d�97TOAf .3 coLLArPr_�.y0 lCa./T E�j71//AMF I. C / �� i . d •/ AiF Lt/ 7 ',�'U �¢�3n — reef A/ .QC'-ZY7non -,gM 7. �' �� sIQpU Drill stem test open hole - Wlfe fine / _ __$//O&,AAr /Al Z:&6 A/DDLf'e&-r KGs -7.x C.$_SJ logginn openhol 44 A,' &f"2 redo7-. Plugging back 4'' 14Z STDP &.' rM tp.r6 M/Js p 6 CuV&V /OT Running casing and cementing rp' ASE it .S. ,XANhY.Ji C21/Z6_Ct2ne.R.&Cit $ Waiting on cemartt ry, Tr]—S 3e3 n Tp w.s SJNh S �� QH ! % nn s'P tL Tr a logging cased hole TTs' 3 2 7' . Z 0 , Perforating n y Wirefinetormelion lest caved hot& -C' • "��./ALFr—GE�i2t �p �a 6000 i'T-�+ To.�:�, em test casedrill thole t"s4S1N O x 3S BG 9Q Testing �� T TTA Swabbing w 00 -- Acidizing Fracturing . Tubing trips Other Totals THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY James Ohlinger Staff CTD Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1C-06 Permit to Drill Number: 181-025 Sundry Number: 319-380 Dear Mr. Ohlinger: Alaska Oil and Gas Conservation Commission 333 west Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Ww .aogcc.aIaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this 2 day of August, 2019. ABDMSW-"' AUG 3 01019 ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 20, 2019 Commissioner - State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits sundry application to set a whipstock to drill three laterals out of the KRU 1C-06 (PTD# 181-025) using the coiled tubing drilling rig, Nabors CDR3-AC. CTD operations are scheduled to begin in late September 2019. The objective will be to drill three laterals, KRU 1C-061-1, 1C-061-1-01, and 1C-061-1-02, targeting the Kuparuk C -sand interval. To account for geological uncertainties, ConocoPhillips requests a variance from the requirements of 20 AAC 25.015 to allow the actual kick-off point to be anywhere along the length of the parent lateral instead of being limited to 500' from the original point. Attached to the sundry application are the following documents: - Sundry Application Form (10-403) for 1C-06 - Operations Summary in support of the 10-403 Sundry Application - Current Wellbore Schematic - Proposed CTD Schematic If you have any questions or require additional information, please contact me at 907-263-4597. Si ncerely, Shane Germann Coiled Tubing Drilling Engineer ConocoPhillips Alaska KRU 1C-06 (PTD: 181-025) CTD Summary for Sundry Summary of Operations: KRU well 1C-06 is a Kuparuk C -Sand injector equipped with 3-1/2" tubing and 7" production casing. The CTD sidetrack will utilize three laterals to target the C -sands to the north and west of 1 C-06. The laterals will increase C -sand resource recovery and throughput. Prior to CTD rig up, E -Line will set a mechanical whipstock (High Expansion Wedge) inside the 7" casing at the planned kick off point of 9430' MD. The 1C -06L1 lateral will exit through the 7" casing at 9430' MD and drill to a planned TD at 13,000' MD, targeting the C sand to the west. The lateral will be completed with 2-3/8" slotted liner from TD up to 9900' MD with an aluminum billet for kicking off. The 1C-061-1-01 lateral will kick off at 9900' MD and drill to a planned TD of 14,300' MD targeting the C sand to the north. It will be completed with 2-3/8" slotted liner from TD up to 11,250' MD with an aluminum billet for kicking off. The 1C-061-1-02 lateral will kick off at 11,250' MD and drill to a planned TD of 13,900' MD targeting the C sand to the north-east. It will be completed with 2-3/8" slotted liner from TD up into the 3-1/2" tubing at 9330' MD with a deployment sleeve and seal bore assembly. CTD Drill and Complete 1C-06 Laterals: Pre -CTD Work 1. RU Slickline: Dummy whipstock drift, C/O GLV's 2. RU E -Line: Caliper 3. RU CTU: Mill out D -Nipple to 2.80" ID, cleanout if fill is encountered. 4. RU E -Line: Set top of high expansion wedge at 9430' MD 5. Prep site for Nabors CDR3-AC. Rug Work h 1. MIRU Nabors CDR3-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 1C -06L1 Lateral (C sand -West) a. Mill 2.80" window at 9430' MD. Drill 3" bi-center lateral to TD of 13,000' MD. c. Run 2-3/8" slotted liner with an aluminum billet from TD up to 9900' MD. 3. 1C-061-1-01 Lateral (C sand - North) a. Kick off the aluminum billet at 9900' MD. b. Drill 3" bi-center lateral to TD of 14,300' MD. c. Run 2%" slotted liner with an aluminum billet from TD up to 11,250' MD. 4. 1C -06L1-02 Lateral (C sand -North-East) a. Kickoff of the aluminum billet at 11,250' MD. b. Drill 3" bi-center lateral to TD of 13,900' MD. c. Run 2%" slotted liner with deployment sleeve and seal bore from TD up to 9330' MD. 5. Obtain SBHP, freeze protect, ND BOPE, and RDMO Nabors CRD3-AC. Post -Rig Work 1. Return to production Page 1 of 1 8/20/2019 KUP INJ WELLNAME 1C-06 WELLBORE 1C_06 Conocc Phillip$ Naska.InD. Well Attributes Max Angla&MD TD Field Name ever no APIonse WNIWrs status rid l') M."KBI Act Sun Idea) KUPARUK RIVER UNIT 500292056600 1NJ 8.00 4,20000 10,243.0 nment X331ppm1 pah Mmtaxan End pah K84N III Rip RNuea pre.SSSV'.TRDP atwo: 11/22007 39.01 313111981 R-;7 1( 711140191139'.55AM Last Tag vmiw eMeti pri Anticipation DarrimKB) 1 EM mle WNIMre I Last Mm By - - - XANOEP, ]fig CONIXICTOR, 2].265.0 SME1110 2.Re SURFACE.31,39].D- GAa11FT: ikpa2 PBR: 9,1355 PACKER:9,1515 NIPPLE, 9.19x2 WERSHOT, 92319 a&i,9p.i PACKER8.201.5 NIPPLE: 8,39A5 PM9d1pOa.905a- Fir, IO.OmO PR9WCT.2 irlsk ti- Last Tag'. RKe 9,488.0 N82019 I1 -O6 lergusp Last Rev Reason Mmmson End nth WNllwre LssIMm 6y Rev Reason: Tag ]1 812019 1C-Ofi lergusp Casing Strings caring Des[ripaon CONDUCTOR 00 (in) mpnl r2P wu6) $N ornpurel Set cepm (NOL.. Wblen it, Grade iopinreaa ifi 15.06 320 6sA 65.0 62.58 H-00 WELDED Caring Description SURFACE 00(in) to0n 1.p (nHel $K Oepruniel sal Oepin (iY➢L.. WIM1en it Grade cop Tnreaa 10314 9.95 31.3 328].0 2,fi85.1 45.50 K-55 BUTT Casing Description PRODUCTION OOlinl IO in, I Top inset se oewxlnl(fil-Dopen ..... . Wlrlan N_.Draee Top TxreM 7 628 29.6 10.225.8 70901 2600 K-55 BTC Tubing Strings cubing oescriplion airing Ma., lolinl TolnKBl gel Oewh(n..eel Do liVol l--Wtllbinl Grade Top Gonneclian TUBING 2007 WO 3112 2.99 2fi.9 9232.9 6,38].5 9.30 L-80 Bra Completion Detatis Tap(NOI Top Incl Nominal Top(nKSI Kind) I') Item oea Cam ID (inl 26.9 26.9 0.00 HANGER EMC Tui HANGER 3.500 2.237.6 2,0210 43.75 SAFETYVLV TY TRMAXX-5ESaWy Valve(Serial A HYS-703) 2.812 9,135.5--7,3-174 39.06 PBR Baker seal asrer y in nned 4UM10 W2.39' Spce0U1 9.151.5 6,325.8 39.54 PACKER Baker FHL Packer (pinned WM# sneer) 3.000 9.193.2 6,357.6 40.79 NIPPLE 2.813'% Nipple 2813 92319 5.386.7 41.80 OVERSHOT Baker Tubing Stub Overshot+l' scene out 3,610 TUMng Description Slay Ma... to/in iopinKBt $el Depth ln.. SN Oeplx (NIDIl... Wt11Wn) Gratla Tap Connection TUBING 1993 WO 5314 4.ID 9.232.2 9,281.5 6623.4 Completion Details. TopINOI TOpxKI Tap II1KB1 IM(81 1°I Ihm Des Com Nominal lolinl . 55.2 6404.0 62.36 SBR BAKER EL -I SBR (no lull joint, TBG string showing SBR ORAD) 4.375 Tubing oescriwion peiy Ma... to lint rop(nK0) 3N oepIM1 lN.. sN oepin 1iW11... W1(INM1t Grade Topicenecuo. TUBING Original 3112 2.99 9281.5 9,387.2 64987 9.20 K-55 IBTC Completion Details i0p(NDI Tap ln[I Nomin& Tap mKB) (ItKe) rl uem ods cam Kling 9.281.5 Q 23.4 63.04 PACKER BAI(Efl FHL PACKER 3.000 9.749.3 64>2.1 44.98 NIPPLE CAMCG D NIPPLE NO GO 2.750 9.380.9 6496.3 I 65.93 JSUS 2.992 Other In Hob jWlrel ine retrievable plugs, Valves, pumps, fish, etc.) rig Tap IUZb Top(ND Top Incl InKO Des Cam Ron Dale ID (iN 10,02 6,9666 44.00 4. FisM1 Vann Gun Leh from original peR.'01'long 612511981 perforations Slots i0p(M1KB) rop BM (RHBf RVO) MKS) BtmlNol (hNB) WItN Zone Dale Shot Den (ehalsm I TyFa Cars 9410.0 9.485.0 6.514.6 5,565.8 I UNIT D. C -0,C- 3. IC -06 I cep"I'all1 .0 Mandrel inserts 51 ml on N Top MKS Tap (PVblValw IRKeI Mate iiiDD fin) Se, Use Type Type pm4iee nnl TRORun IOs6 Run Dale COm 11 9,0792 6.2692 Cantu. ores 112 GASLIFT DAY BN 0000 0.0 111111200] Notes: General & Safety End oah Announcen 93 1123/19NOTE: WORKOVER 4/1 4 NOTE'. WAIVEREDWELL: Tx IA COMMUNICATION 1228201 NOTE'. VIEW SCHEMATIC /Mask. SM ... 60.0 Proposed CTD Schematic 16" 65# H-40 shoe @65'MD 10-3X'46# K-55 shoe @ 3287' MD �j�I:LRUYTih�� C -sand perfs 9410'- 9485' MD 7" 26# K-55 shoe @ 10,226' MD 3-1/2" TRMAXX-5E SSSV @ 2238' MD 3-1/2" 9.3#L-80 EDE 8rd Tubing to surface 3-1/2" Camco MMG gas lift mandrel @ 9079' Baker 3-1/2" PBR @ 9136' MD (3.0" ID) Baker FHL packer @ 9152' MD (3.0 ID) X -Nipple @ 9193' MD (2.813" ID) Baker EL -1 SBR @ 9255' MD (4.375" ID) Baker FHL Packer @ 9282' MD (3.0" ID) 3-1/2" Camoo D landing nipple @ 9349" MD (2.75' min ID, No - Go) 3-1/2" tubing tail @ 9381' MD 1C-061-1-02 wp02 TO -13,900' MD Liner top - 9320' MD 1C -06L1-01 wp02 TO -14,300' MD Billet/Liner top - 11,250' MD 1C -06L1 wp02 TO -13,000' MD Billet/Liner top - 9900' MD Loepp, Victoria T (CED) From: Germann, Shane <Shane.Germann@conocophillips.com> Sent: Tuesday, August 27, 2019 8:07 AM To: Loepp, Victoria T (CED) Subject: RE: [EXTERNAL]KRU 1C-06(PTD 181-025, Sundry 319-380) Whipstock Victoria, MPSP for this well is 3235 psi (based on max formation pressure in the area of 3888 psi in 1C-11 and gas gradient of 0.1 psi/ft). Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and 3500 psi. Annular preventer will be tested to 250 psi and 2500 psi. Thanks, Shane Germann Coiled Tubing Drilling Engineer ConocoPhillips Alaska Office: 907-263-4597 Cell: 406-670-1939 700 G St, ATO 664, Anchorage, AK 99501 From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Friday, August 23, 2019 1:17 PM To: Germann, Shane <Shane.Germann@conocophillips.com> Subject: [EXTERNALJKRU 1C-06(PTD 181-025, Sundry 319-380) Whipstock Shane, What is the MPSP and the BOPE test pressure for drilling? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil 8 Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria Loeoordalaska goy CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC). State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.gov MEMORANDA • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,May 16,2018 TO: P.I.m Regg S-121 PSupervisor $ SUBJECT: Mechanical Integrity Tests (I CONOCOPHILLIPS ALASKA,INC. 1C-06 FROM: Austin McLeod KUPARUK RIV UNIT 1C-06 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry•1152— NON-CONFIDENTIAL 11z—NON-CONFIDENTIAL Comm Well Name KUPARUK R1V UNIT 1C-06 API Well Number 50-029-20564-00-00 Inspector Name: Austin McLeod Permit Number: 181-025-0 Inspection Date: 5/12/2018 >. Insp Num: mitSAM180513195525 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 1C-06 Type Inj W TVD 6305 Tubing 2384 2384 2379 2365 PTD 1810250 -Type Test SPT Test psi 1576 IA 370 1800 - 1770 - 1770 - BBL Pumped: 1.7 - BBL Returned: 1.7 OA 177 256 - 252 - 253 Intervals 4YRTST P/F P Notes: MIT-IA SCANNED JUN 0 12018 Wednesday,May 16,2018 Page 1 of 1 Ima )roject 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 during a special rescan activity or are viewable by direct inspection of the file. JZZ-_~~ Well History File Identifier Organizing RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: .~Poor Quality Originals: [] Other: NOTES: [] Other, No/Type [] BY; BEVERLY ROBIN VINCE~~:::~MARIA WINDY Project Proofing BY: .~~OBIN VINC Scanning Preparation Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other 5NT SHERYL MARIA WINDY DA : Isl x 30 = ~'~ + TOTAL PAGES BY: BEVERLY ROBIN ~,SHERYL MARIA WINDY Production Scanning Stage I PAGE COUNT FROM SCANNED FILE: / / v Stage 2 PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: /~ YES IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES BEVERLY ROBIN VINCE~ARIA WINDY (SCANNING IE COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUAUTY. GRAYSCALE OR COLOR IMAGES ) NO NO RESCANNED BY; BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: General Notes or Comments about this file: I$1 Quality Checked i~o.~ 12/10/02Rev3NOTScanned,wpd UNSCANNED, OVERSIZED MATERIALS AVAILABLE: Iff/ ()~FILE # I múD LCJG-- To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission 1333 W. 7th Ave., Ste. 100 I Anchorage, Alaska 99501 Voice (907) 279-1433 tFax (907) 276-7542 • ConacoPhillips P.O. BOX 100360 ANQiORAGE, AIASKA 99510-0360 July 16~', 2010 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7~ Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: ~~~~1 V G s~ca !~ ~ Gas Caps. Cutnrris:hi;; ~SItCFi~r?~a ~$ ~~ ~O Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRLn. Each of these wells was found to have a void in the conductor. These voids were filled with 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 pumped November 25~' 2007 & March 21 2009, the corrosion inhibitor/sealant was pumped July 6~', 7th, 8th 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, Perry Klem ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/16/10 1A. 1C.1EPAD Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1A-11 50029206850000 1811730 10" Na 10" Na 3.4 7/8/2010 1A-12 50029206880000 1811780 2" n/a 2" Na 1.7 7/8/2010 1A-13 50029207000000 1811950 11" n/a 11" Na 3.4 7/8/2010 1A-14 50029207060000 1820100 4" n/a 4" n/a 2.1 7/8/2010 1C-01 50029205260000 1801280 SF n/a 24" Na 4.3 7/6/2010 1 C-02 50029205320000 1801350 24" n/a 24" n/a 8.5 7/6/2010 1 C-03A 50029205350100 2070630 SF n/a 16" n/a 7.7 7/6/2010 1 C-04 50029205470000 1801550 SF Na 5" n/a 2.6 7/6/2010 1C-06 50029205640000 1810250 76 17.70 32" ~11R009 9.4 7/6/2010 1C-09 50029208590000 1821850 38' 8.00 6" 11/25/2007 6.8 7/6/2010 1C-10 50029208650000 1821930 37'6" 8.00 8" 11/25/2007 6.8 7/6/2010 1E-02 50029204720000 1800500 21" n/a 21" n/a 1.7 7/7/2010 1 E-03 50029204770000 1800560 4" n/a 4" n/a 2.4 7/7/2010 1E-06 50029204930000 1800780 12" n/a 12" n/a 13.6 7/7/2010 1E-07 50029204950000 1800800 5" n/a 5" n/a 2.6 7R/2010 1 E-08 50029204960000 1800810 5" n/a 5" n/a 2.6 7/7/2010 1 E-10 50029207250000 1820360 2" Na 2" n/a 1.7 7/7/2010 1 E-13 50029207500000 1820780 5" Na 5" n/a 2.6 7/7/2010 1E-19 50029209050000 1830170 1" Na 1" n/a 1.7 7!7/2010 1 E-21 50029208920000 1830020 3" Na 3" n/a 2.6 7/7/2010 1 E-24A 50029208570100 1971870 2" Na 2" n/a 1.7 7/7/2010 1 E-25 50029208440000 1821700 3" Na 3" n/a 1.7 7/7/2010 1 E-28 50029208320000 1821580 4" n/a 4" n/a 2.5 7/8/2010 1 E-29 50029208280000 1821540 7" n/a 7" n/a 2.5 7/8/2010 ~~ MEMORANDUM To: Jim Regg ~_ (,+2~'lG P.I. Supervisor ~ L FROM: John Crisp Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Wednesday, May 26, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1 C-06 KUPARUK RIV UNIT 1 C-06 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~~ Comm Well Name: KUPARUK RIV UNIT 1C-06 Insp Num: mitJCr100523170331 Rel Insp Num: API Well Number: 50-029-20564-00-00 Permit Number: 181-025-0 Inspector Name: John Crisp Inspection Date: 5/21/2010 Packer Depth Pretest Initial l5 Min. 30 Min. 45 Min. 60 Min. Well P.T.D _~ ~~~ 1C-06~Type Inj. ~'~' 'I 1 VD ~- 1810250 ' ~`ype'I`CSt SPT ~ -Test psi ~ ~.--- ~ I __-~ 6305 / 1576 IA 1230 DA 340 2710 ~ 380 ~ 2660 380 2660 380 -{ - Interval 4~TST p/F P / Tubing ~ zls9 _ 2139 zlss zls] NOtes: 2.1 bbls pumped for test. No problems witnessed i! Wednesday, May 26, 2010 Page 1 of 1 1 C-0610-404 • Maunder, Thomas E (Df)A) From: Maunder, Thomas E (DOA} Sent: Friday, December 14, 2007 1:38 PM To: 'Gober, Howard' Cc: Allsup-Drake, Sharon K Subject: RE: 1C-0610-404 • Howard and Sharon, ~'''~~~~ ~ ~~~ ~ ~ ?fl~~ Nothing further is needed. I will make the changes on the 404. Tom Maunder, PE AOGCC Page 1 of 1 From: Gober, Howard [mailto;Howard.Gober@conocophiBips.com] Sent: Friday, December 14, 2007 11:50 AM To: Maunder, Thomas E (DOA) Cc: Allsup-Drake, Sharon K Subject: 1C-06 10-404 Tom, In response to your phone message yesterday, 1C-06 is a WAG in}ector. The purpose of the workover was to re- gain tubing integrity so that Mi could be injected into the well again. Please tet me know if you need any other information. Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907-263-4220 Office 907-240-5515 Cell Howard. Gober@conocophillips. com ~,._ i'~ r' ~ 12/14/2007 ~ R~~~~r STATE OF ALASKA []E~ Q ~) ~~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIOI~ska Oil & Gas Corns. ~~mmssia~n 1. Operations Performed: Abandon ^ Repair Well ~ ~ Plug Perforations ^ Stimulate ^ Other ' Alter Casing ^ Pull Tubing Q 'Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConOCOPhilllps Alaska, InC. Development ^ Exploratory ^ 181-025 / '' 3. Address: Strati ra hic g p ^ Service ~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20564-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 94' ~ 1 C-06 8. Propefij Designation: 10. FieldlPool(s): ADL 25649 ' Kuparuk River Field /Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 10243' feet true vertical 7102' feet Plugs (measured) Effective Depth measured 9496' feet Junk (measured) 10026' true vertical 6573' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 65' 16" 65' 65' SUR. CASING 3193' 10-3/4" 3287' 2685' PROD. CASING 10132' 7" 10226' 7090' Perforation depth: Measured depth: 9410'-9485' true vertical depth: 6514'-6566' Tubing (size, grade, and measured depth) 3-1/2" , L-80 / K-55, 9294' MD. Packers &SSSV (type & measured depth) pkr= BAKER'FHL' (2) pkr-- 9125', 9253' Camco TRMAXX-SE SSSV @ 2211' 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-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation SI - -- Subsequent to operation 3400 - -- 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service 0 Daily Report of Well Operations _X 16. Well Status after work: '~ ~~~-r>~4L Oil^ Gas^ WA GINJ^ WDSPL^ 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: 307-277 Contact Howard Gober @ 263-4220 Printed Name Howard Gober Title Wells Engineer ~~ ~Z Signature '""± Phone: 263-4220 Date ~°l/~~ Pre b Sharon A/I u -Drake 263-4612 Form 10-404 Revised 04/2006 ~c ia•iro~ Su it Original Only n • ~onocaPht~ipls Time Log Summary Weltvte~++ Web Rep°~ tfing __ Well Name: 1 C-06 Job Type: RECOMPLETION Time. L°~s_ .- - Date From To Dur S. depth E_ Depth Phase Code Subcode_ T CODA __ _ _ ~ 10/25/2007 09:00 22:00 13.00 MIRU MOVE RURD P Nabors 3S. Scope down derrick and lay down. Disconnect & pull Pipe Shed out of way. Blow down steam lines. Disconnect service line. Lower Carrier. Jack up pits and prep for truck. RU truck to pit module, move. Move Carrier across to 1 C-06. Move pits and pipe shed around. Spot rig. Move forward and place containment and rig mats. Respot carrier over well. Spot pit module and pipe shed and connect all lines. Raise derrick and scope up. Ri acce ted 22:00 hrs, 10/25/07. 22:00 00:00 2.00 COMPZ RPCOh RURD P Hold PJSM. Take on 200 bbls. of 9.7ppg brine into pits. RU FMC lubricator and pulled BPV. 250 psi wellhead pressure. Rig up to bleed down tubin and IA. 10/26/2007 00:00 06:00 6.00 COMPZ WELCT KLWL P Tubing & IA would bleed to '0' but would build up as soon as shut in. RU to reverse circulate. Pumped 3.8 bpm @ 650 ICP & 3.8 bpm @ 600 psi FCP. Pumped total of 386 bbls. of 9.7 brine surf to surf. Well ress = 0. 06:00 11:00 5.00 COMPZ WELCT NUND P Install BPV. Nd tree, NU BOPE. 11:00 16:00 5.00 COMPZ WELCT BOPE P ressue test BOP rams to 250/3500 psi, and annular to 250/2500 psi. Witnessing of test waived by Bob Noble (AOGCC).While testing the IA pressure built up to 200 psi. Bled off immediately but would not quit flowing com letel . 16:00 17:30 1.50 COMPZ RPCO{~ RCST P Checked well on both sides tubing and IA with no press. Pulled blanking plug and BPV, monitor well for 15 min. static. Install landin 't. BOLDS 17:30 19:00 1.50 COMPZ RPCO OTHR P Unland tubing hanger. String wt. 96K. Pulled up to 80% of the API yeild strenth or 114K, worked up and down. On third attempt, tubing popped loose and weight dropped off to 65K. PU and still not loose, worked up and down to max. but tubin still not loose. ~ ~ . ~ d..~ ~ _~. ~ ~~?~~ 1 ~sf 5 -----' .~ i Time Low _ Date __ From To _ , D ur S, Depth E. D~th Phase Code Subcode T COM_ 10/26/2007 19:00 00:00 5.00 COMPZ RPCOh CIRC P Backed out landing jt. MU shorter landing jt with head pin and T1W valve. Pressure tested casing to 2500 psi held for 20 min. Bled pressure off. Began circulating 1.5 bottoms up, down the tubing at 3.8 BPM @ 360 si. while waitin for SWS. 10/27/2007 00:00 00:30 0.50 COMPZ FISH CIRC P Finished pumping 3.8 BPM @ 360 psi down the tubing, 1.5 bottoms up, while waiting for SWS. Pulled tubing to 114K and no movement. 00:30 12:00 11.50 COMPZ FISH CPBO P SWS on location, hold PJSM, RU/RIH for free point log. Determined 3 1/2" tubin stuck a roximatel 5500'. 12:00 18:30 6.50 COMPZ FISH CPBO P RU wireline head for string shot and chemical cut. RIH with string shot and shoot from 5500' to 5512', POOH. RIH w/ Chemical Cutter, cut 3 1/2" tubing 5 08'. Wait 5 min. for slips to relax and POOH. 18:30 19:30 1.00 COMPZ FISH CPBO P OOH w/ SWS, lay down chemical cutter, PU on tubing ,pulled free (52K up wt.) Pulled tubing hanger to floor and finished ri in down SWS. 19:30 23:00 3.50 COMPZ RPCOh HOSO P Laid down hanger and 1 full joint of tubing. Monitored well while changing bails and elevators, well static. MU and land test plug, RILDS, PT to 3500 si, ood test, bled down to '0'. 23:00 00:00 1.00 COMPZ RPCOh NUND NP After discussion with AOGCC due to high BHP decided to add one more set of pipe rams. ND BOPE to add 1 set of rams. 10/28/2007 00:00 06:00 6.00 COMPZ RPCOh NUND NP Continue ND. Remove Koomey, kill and choke hoses. Break out 13 518" flanges on bottom spool. Slide in single gate on mat. Position in cellar. pick stack, dro off bottom spool and set on single gate. MU single gate, set on DSA and torque up. Hook up Koomey, choke and kill hoses, open doors on on lowest set of rams and chan a to 3.5". 06:00 11:30 5.50 COMPZ WELCT BOPE NP Close and tighten door on single gate, filled stack and attempt to test. Gasket on door leaking. Drain stack, open door on bottom gate and replace gasket. Retest to 250/3500 psi. Body test to 3500 psi. OK. Waived by Robert Noble @ 04:30 per phone call. Drained stack. LD test jt. MU landing ~t. Pu~~~af~ l n • Time Logs _ _ _ _ D e From To Dur S Depth E_ De th Phase Code Subco e_T COM 10/28/2007 11:30 20:00 8.50 COMPZ RPCOh PULD P BOLDS. Pull test plug to rig floor and remove. Monitor well, static. POOH laying down 3 1/2" tubing. OOH w/ 3 1 /2" tubing. Cut joint #178 was 20.95', ood clean cut. 20:00 00:00 4.00 COMPZ FISH PULD P Clear rig floor, finish loading and strapping fishing string, insta{I wear rin PU Baker fishin BHA. 10/29/2007 00:00 01:00 1.00 COMPZ FISH PULD P Finished making up Baker fishing BHA. 01:00 07:00 6.00 COMPZ FISH TRIP P PU 3 1/2" IF workstring and RIH to fish 3.5" tubing. Up wt. 70K Dwn wt. 52K. Located top of fish (a) 5486' DP measurements. 07:00 08:30 1.50 COMPZ FISH JAR P Engaged fish. PU to 100K and let jars bleed off. Pulled up to 125K. Lowered back down and reload jars. PU to 125K hit with jars, PU to 150K still stuck. Lowered and reload jars. PU to 150K jarred one time and fish came Wt 104K. PU to first connection. LD one jt. Install head pin & TIW. 08:30 10:30 2.00 COMPZ FISH CIRC P Circulate one hole volume (320 bbls) @ 4 BPM w/525 psi. to clean well. Shut pump down and monitor well, static. 10:30 15:00 4.50 COMPZ FISH TRIP P Break out head pin and TIW. POOH standing back workstring and drill collars. 15:00 17:00 2.00 COMPZ FISH TRIP P Break out and lay down BHA. Change out tongs, slips and elevators for 3 -1/2" tubin . 17:00 22:00 5.00 COMPZ FISH TRIP P POOH laying down 3 1/2" fish. OOH with old completion. Tubing was approx. 314 cut, also heavy parrafiin build up above and below GLM. Cut joint was 14.76'. The hole was ' found in the 6' pup above the GLM @ approx. 9165'. After discussion with town engineer, decision was made to make a clean ouU dress off run. 22:00 00:00 2.00 COMPZ FISH RURD P Laid down fishing BHA, cleared floor and pipe shed, load more drill pipe. Begin making up new clean out BHA. Well static. 10/30!2007 00:00 07:00 7.00 COMPZ FISH TRIP P PU and RIH w/Baker Washover tools. BHA consist of 6" OD. Cut lip guide outside dress off shoe with 5' extension, two boot baskets 4 5/16", Bumper sub-super jar, pump out sub, 6 ea. 4 3/4" drill collars with 9,000' of 3 1/2"drill i e to com liment. 07:00 09:00 2.00 COMPZ FISH CIRC P Circulated 2 hole volumes to clean hole after ettin to bottom w/ scra er. • Time Logs _ j -- - - - 1 Date From To Dur S De th E. Depth's Phase Code Subcode T COM 10/30/2007 09:00 16:00 7.00 COMPZ FISH FISH P _ _ Begin picking up Kelly. Test Kelly to 3,500 PSI. Tagged up 17' in on joint 290. _ 9,201'. Rotate with various RPM 25-60 RPM 4,100-6,000 FTLBS torque. 2-3 BPM with 600-1,100 PSI pressure increase when no-go out on stub 16-17' in on Kelly. Witnessing no over torque while engaging top offish. Will note shoe no-go coedition when OOH with ins ection. 16:00 19:30 3.50 COMPZ FISH RURD P Continue to circulate 20K strokes while confer with Anchorage. Stand back Kelly and prepare for casing pressure test to 3,000 PSI. Note. Pump has leak between HP hammer union and pulsation dampener. Have called to repair. Will use test pump for casing test. 0 P I s ood i. 19:30 00:00 4.50 COMPZ FISH TRIP P POOH laying down drill pipe. 10/31/2007 00:00 07:30 7.50 COMPZ FISH PULL P Continue to POOH laying down drill i e, also laid down Kell . 07:30 08:30 1.00 COMPZ FISH PULL P Lay down drill collars. Monitor hole conditions. Hole stable. 08:30 10:30 2.00 COMPZ FISH PULD P Break down and lay down Baker BHA. No metal solids in boot baskets- lots of arrafin. Pull wear rin . 10:30 12:00 1.50 COMPZ FISH RURD P Rig up pipe handling equipment for 3.5" 9.3# production tubing. Load pipe shed with 69 joints to finish off tally. Stra 69 'oints & drift with 2.867" drift. 12:00 00:00 12.00 COMPZ RPCOti RCST P Pick up completion string according to pipe tally. Count joints in pipe shed. 298 joints in shed. 2 joints outside. All jewelry strapped and. accounted for. Confirm RHC lu in ni le. 11/01/2007 00:00 07:00 7.00 COMPZ RPCOh RCST P Continue to RIH w/ new 3.5" 9.3# ~ completion, ran stainless steel control line from -2,210'. Note: Ran 72 stainless steel bands total. 07:00 08:00 1.00 COMPZ RPCOti HOSO P Tag stub at 3' in on joint 292. pins sheared with 10K dwn WT. Tag out several times & set 20K down to ensure nogo out. PUH and prep to reverse out. 08:00 13:00 5.00 COMPZ RPCO CIRC P Begin reverse circulation of 9.6# brine one full sweep prior to switching over to 50 BBLS seawater then change to 300 BBLS 1 % corrosion inhibited sea water for effect. 3 BPM @ 210 PSI. 410 PSI while pumping the 1% corrosion inhibitor. ~. ~~ ~ ~- ( gage ~~ cf t.._._. • _Time Logs_ _ _ ~ Date From To _ Dur S. Depth E_ Dew _ Phase _ Code Subcode T __ _ COM __ 11!01!2007 13:00 ' 14:30 1.50 COMPZ RPCOh PACK P RIH tag up 72K up 54K dwn. 4' in on 292 for stub overshot. Drop ball & Rod (1 5/16" ball W 1 3/8" FN OAL 6.7'). Pressure up to 2,500 PSI and chart PKR set. Shear out PBR with 1,000 PSI tubing pressure. Re-sting into seals and pressure test to 500 PSI as er roceedure. Test assed. 14:30 18:30 4.00 COMPZ RPCOty HOSO P Pick up space out pups. Length given on hanger wrong. Take pups back off and install 6.04' & 2.98' Pup for 2' space out in PBR. Install hanger with SSSV control system. Land hanger. RILDS. 18:30 21:30 3.00 COMPZ RPCOh DHEQ P Pressure tested tubing to 2500 psi for 15 minutes, bled off to 2000 psi. Tested IA to 3000 psi for 30 minutes, bled down pressure to shear SOV. Witnessed good shear out, pressure test was charted. 21:30 00:00 2.50 COMPZ WELC NUND P Drained stack and install BPV. ND BODE and clear ri floor of a ui ment. 11/02/2007 00:00 06:30 6.50 COMPZ WELCT NUND P Finish ND BOPE, NU tree and re-configure to match old tree. Pressure test tree and packoffs to 250/5,000 psi and SCSSSV control line to 5,000 si. All tested ood. 06:30 12:00 5.50 COMPZ RPCOh FRZP P Pull BPV, Little Red pumped 100 BBLS of diesel down the IA for freeze protection (-2,580' MD) letting the diesel U-tube. Set BPV and release rig. Nabors 3S released @ 12:00 PM 11-2-2007 ~ e_a ~ t ~s~~ 5 ~a~ 5 ~ 1 C-06 Well Events Summary DATE Summary 10/22/07 RAN STRING SHOT AND 2 3/8" CHEMICAL CUTTER. LOG CORRELATED TO TUBING TALLY DATED 1/23/93. STRING SHOT TUBING FROM 9196-9208'. CUT TUBING AT 9206'. 11/10/07 PULLED BALL & ROD @ 9166' RKB. IN PROGRESS. 11/11/07 PULLED RHC PLUG BODY @ 9166' RKB. PULLED SOV @ 9052' RKB, REPLACED WITH DV. MITIA 2500 PSI, GOOD. BAILED FILL ON CATCHER SUB @ 9271' SLM. IN PROGRESS. 11/12/07 PULLED AVA CATCHER @ 9291' RKB. PULLED A2 EQ PRONG FROM 9291' RKB. BAILED LIGHT FILL OFF C-A2 PLUG BODY. IN PROGRESS. 11/13/07 PULLED 2.75" C-A2 PLUG FROM 9291' RKB. TAGGED AT 9478' SLM; BOTTOM PERF @ 9485' RKB. MEASURED BHP AT 9450' RKB: 3525 PSI. COMPLETE. MEMORANDUM • To: Jim Regg ~~~~ ~~~~~~ ~ P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector State of Alaska • Alaska Oil and Gas Conservation Commission DATE: Monday, December 03, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1C-06 KUPAR[1K RIV LNIT ]C-06 Src: Inspector NON-CONFIDENTIAL ~~~.o~ Reviewed By: P.I. Suprv Comm Well Name: KUPARUK RN UNIT 1C-06 Insp Num: mitCS071 130075441 Rel Insp Num: API Well Number 50-029-20564-00-00 Permit Number 181-025-0 Inspector Name: Chuck Scheve Inspection Date: t U29/2007 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well i tc-o6 +!Type Inj. I W I TVD ~ IA ~ ~ 6z93 -, s6o ! z~4o ~j' zoso ~ zo6o j ~ 1810250 !'~ypeTOSt ~ SPT ~ Vest pSl P.T. C !i 1573.25 DA ~ 260 60 ~ 360 360 Interval wRtcOVR P/F P - _ / Tubing I~, isso ~ tsso use ~ tsso ~ ~- i Notes• Initial test post workover. _ _ ~~~~~~ D E ~ ~. ~ 2007 Monday, December 03, 2007 Page 1 of 1 e s Maunder, Thomas E (DOA) From: Howarcl Gober[hgoberc~mtaontine.net] Sent: Saturday, October 27, 2007 2:40 PRA To: Maunder, Thomas E (DOA) Cc: howard.gaber(~COnocophiltips.cam; Nabors 3S Company Man; n1034@conc~cophillips.com Subject: 1C-06 BOP Configuration ~~~- ~~- j Tom, Thank you for taking the time to c~iscuss 1C-06 with me today. I reviewed the well history and discovered that the weZl was converted to MI injection on 2/5/07. The well was shut in from May 15 to June 16 of 2007. From June 16 to June 23 it was on water injection. The well was shut in on June 23. Therefore, it was only on water injection for 7 ciays after a MI cycls. Based on the criteria you and period. I have instructed the rigged up. After the chemical BPV profile. We will pull one With a BPV set, we can add the and notify them of the need to L had set, we did nat have a sufficient water injection rig to add the 2nd pipe ram. We currently have E-line cut, we will pull the hanger to the floor and inspect the joint and lay it down and then install and land the hanger. 2nd pipe ram. The rig supervisors wiil call the inspector test this ram. For your information, the hole is acting very good. Every indication is that our downhole plug is holding well. We pressure tested the casing and plug from above last night to 2500 psi with 9.6 ppg brine in the hole and it held solid. Please let me knaw if ~czu have any questions. Thanks, Howard Gober Wells Engineer ConocoPhillips Alaska, Inc. 907-240-5515 cell 907-263-4220 office ~ _ ~~ ;~,~;`~~~~~ ~~~.~:4. ~~.. . _.. ~~~»'~~ ~ · . ~1r~1rŒ (ID~ ~~~~æ~ / AI4ASIiA. OIL AND GAS / CONSERVATION COMMISSION / -- Jill Long Wells Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 5C,~NED AUG 2 8 Z007 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1C-06:." '" ¿ Sundty Number: 307-277 ............ \ ~ \ ~ !f ¡.u Dear Ms. Long: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this z;}day of August, 2007 Enc!. · CII B/Þ7,o7 . EIVED STATE OF ALASKA 8'/2. 7/7 4 ALASKA OIL AND GAS CONSERVATION COMMISSION I,:.., j 2 - 2007 APPLICATION FOR SUNDRY APPROV A.lwsb OH & Gas Con~. Comm¡$;;;~; 20 AAC 25.280 /\nchorage 1. Type of Request: Abandon 0 Suspend 0 Operational Shutdown 0 Perforate 0 Waiver 0 Other 0 Alter casing 0 Repair well 0 , Plug Perforations 0 Stimulate 0 Time Extension 0 Change approved program 0 Pull Tubing 0/ Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 0 Exploratory 0 181-025 / 3. Address: Stratigraphic 0 Service 0 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-20564-00 / 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Requires? Yes 0 No 0 1 C-06 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25649 . RKB 94' , Kuparuk River Field I Kuparuk Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10243'- 7102' .- 9496' 6573' 1 0026' Casing Length Size MD TVD Burst Collapse CONDUCTOR 65' 16" 65' 65' SUR. CASING 3193' 10-3/4" 3287' 2685' PROD. CASING 10132' 7" 1 0226' 7090' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9410'-9485' 6514'-6566' 3-1/2" K-55 9294' Packers and SSSV Type: Packers and SSSV MD (ft) pkr= BAKER 'FHL' pkr= 9253' Otis 'X' selective landing nipple @ 2015' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 15. Estimated Date for 16. Well Status after proposed work: Commencing Ope rat September 7, 2007 Oil 0 Gas 0 Plugged 0 Abandoned 0 17. Verbal Approval: Date: WAG 0 GINJ D WINJ 0 WDSPL 0 Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jill Long @ 265-1102 Printed Name Jill W. Lonq cf)1JYLa-.. Title: Wells Engineer Signature {~ 11 ..0 óJr Phone 265-1544 Date 8'/23/07 V U Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry NU!Jå-¡_ ,).'77 Plug Integrity 0 BOP Test .~ Mechanical Integrity Test ~ Location Clearance 0 Other: 3S\JO~c;\ '("J\\~\ \1"'- ~ ~'\SùV ~...~~ ~~~. ~~ \)\\\~~. \N\.\-~~~~~ ~~û. '·\-t\~~~~\û.\~\t> Subsequent Form Required: ~ '.Øh COMMISSIONER RBDMS 8Fl, AUG 2 7 2007 , .-J APPROVED BY Date: e. ~-f;;- Approved by: -..,- / THE COMMISSION Form 10-403 Revised 06/2oe5" lJ"R-tG I NAt A: :~ Duplicate ~ g·¿t/.ó ~~ v . . ~ ConocoPhillips Alaska RECE\VED AUG 2 4 2007 Alaska Oil & Gas Cons. Commission Anchorage P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 21, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk We1l1C-06 (PTD# 181-025). / Injecting well 1C-06 has been waivered for water injection only since May 2004 due to an inner annulus pressure increase while injecting MI. Past leak detection diagnostic work failed to identify the small tubing leak however a Well Leak Detect (WLD) log run in the well on July 18, 2007, identified two leak points: at the packer (9,291' MD) and near the GLM (9,172' MD). / The purpose of the proposed workover will to pull the existing 3-1/2" tubing string and replace it with a new 3-1/2" tubing string. Attached is a proposed schematic along with a general workover procedure. If you have any questions or require any further information, please contact me at 265-1102. Sincerely, {::;f~/ () ~. t1òY !~ a ~;-£:;- . v I~'?r Wells Engineer CPAI Drilling and Wells . ~ ConocoPhillips Well: 1 C-06 Field: Kuparuk . API: 500292056400 PTD: 181-025 2007 RWO PROPOSED COMPLETION WELLHEAD Lift threads: 3%" 8rd EUE BPV: 3" FMC ISA Model: FMC Gen 1 Retro CONDUCTOR 16",62.58 ppf, H-40, welded SURFACE CASING 103/4 ",45.5 ppf, K-55, BTC PRODUCTION CASING 7", 26 ppf, K-55, BTC TUBING 3%", 9.2 ppf, K-55, BTCM, IPC PERFS D, C-4, C-3 9,410'-9,485' MD 6,514-6,566' TVD 3/31/1981 A B D E F NEW COMPLETION A: SCSSV: 2.813" X Nipple profile 2,210' MD (2,000' TVD) B: Gas Lift Mandrels No. MD TVD TYPE 1 * * 1.5" MMG- SOV * at least 1 full joint above seals C: PBR Seal Assembly D: Baker FHL Packer- at least 1 full joint above the nipple E: Nipple: 2.813" X Nipple- at least 1 full joint above the overshot F: Overshot: will swallow chemical cut @ - 9,291' MD Last Updated: 21-Aug-07 Updated by: JWL · Kuparuk 1C-06 . General Workover Procedure Pre-Ria Work 1. Apply for Sundry approval 2. Set catcher sub above the plug set in the 2.75" D nipple at 9,291' RKB on 6/24/07 3. Pull the dummy valve from the GLM at -9,172' MD and load the well with 9.6 ppg brine thru the open mandrel. Replace the dummy valve. 4. Perform string shot and chemical cut the tubing at 9,206' MD. 5. Set the BPV and prepare location for arrival of Workover Rig General Workover Procedure 1. Verify Sundry approval has been acquired 2. MIRU Nabors 3S. ND tree. MU blanking plug. 3. NU and pressure test BOPE to 250/~ ~500 pc7\ 1"\..\ i\..\. ~\.) ""'-- \Sa y.\€:-,,>~ The 24 hour SIWHP obtained on 6/24/07 prior to setting the CA-2 plug in the 2.75" D t-f 7JI'1 nipple at 9,291' RKB was 1,900 psi. 4. Pull 3.5" tubing and run new 3.5" tubing/completion. 5. Circulate in corrosion inhibited seawater. Set packer. 6. r:.lðy' Space out and land tubing hanger. Set BPV and ND BOPE. ' 7. NU tree, pull BPV, set Tree Test Plug, and test tree 8. Remove tree test plug, freeze protect, and set BPV 9. RDMO workover rig Post-Ria Work 1. Pull BPV, ball and rod, and SOV. Install dummy valve. 2. Pressure test tubing and !A to 2,500 psi <::..O~ \oc...\-ptO \r) \ec "'^- ~\( So ..çé::)V' 3. Retrieve the RHC plug body. . C ". \ _. \ a.Of)\'O(")\\G.:.W ·~S '\- D~<;~~~· 4. Pull catcher sub and plug. \' X" \' r 5. Return to injection. AZ- ~b"\ ,clr3s \í~"~~~~'~·jü, ProActive Diagnostic Services, Inc. WELL LOG TRANSMITTAL To: AOGCC Chiristine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and / or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by retuming a signed copy of this transmittal letter to the attention of : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 EDE Disk 1 C - 06 Leak Detection - WLD 18-Ju1-07 1) 2) 3) 4) 5) 6) 7) U:IŒ- /1rI- Cé)6- I Séì"8o 5~ANNED JUL 2 5 2007 Signed : ~.j)~ Date: '-1 / ::x¡ ¡ 01- Print Name: Q.IA r~ ~t1 u p - ~A_~\A.V ~ PRoACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-8952 E-MAIL: PDSANCHORAGE@MEMORYI..OG.COM WEBSITE : WW\ftJ.MEMORYLOG.COM D:\Master_ Copy _00 _PDSANC-20xx\Z _ W ord\Distribution\Transmittal_ Sheet5\Transmit _Original-doc Page 1 of 3 Maunder, Thomas E (DOA) ~ ~ From: NSK Problem Well Supv [n1617@conocophiliips.com] Sent: Monday, June 25, 2007 11:Q6 AM To: tom_maunder@admin.state.ak.us; jim_regg@admin.state.ak.us Cc: NSK Problem Welf Supv Subject: FW: 1 G06 (PTD 181025Q} report of failed MIT - Permission requested to displace Mt fram tbg and near wellbore with water injection. Tom & Jim, On 06/2/07 Kuparuk injector 1 C-06 (PTD 1810250) was shut in per the requirements of the previous e-mails. Yesterday 06/24/07, the well was secured with a TTP. Diagnostics will continue to determine the communication mechanism on the well. Please let us know if you have any questions. Jerry Dethlefs Brent Rogers Problem Wel-s Supervisor 659-7224 From: NSK Problem Well Supv Se : Tuesday, June 12, 2007 12:20 PM To: as Maunder' ~"wa~'~::T:Ti~k.' ~.~#.i«. 'a .~. f li4l~ Cc: ']am egg' Subject: RE: -06 (PTD 1810250) report o~ failed MIT - Permission requested to d'rsplace MI from tbg and near wellbore with wat 'niection. Tom, Thanks. WI should start either Will keep in touch, Marie or tomorrow. I'It be here until 6/20. From: Thomas Maunder [mailto:tom_maunder@admin.s e.ak.us) Sent: Tuesday, )une 12, 20~7 12:01 PM To: NSK Problem Well Supv Cc: lames Regg Subject: Re: iC-06 (PTD 1810250) report of failed MIT - Permission req sted to displace MI from tbg and near wellbore with water in}ection. Marie, It is appropriate to inject water to sweep the MI from the tubing and immediate we re area. It is acceptable to inject for 1 week as planned and then secure the well with the tail pipe p Please notify us when the well is secured. Call or message with any questions. Tom Maunder, PE ~~ ~c ~ cflc f''~~ 10/29/2007 Q RE: lC-06 (PTD 1810250) report off ailed MIT - Permission requested... . . Subject: RE: 1 C-06 (PTD 1810250) report of failed MIT - Permission requested to displace MI from tbg and near wellbore with water injection. From: NSK Problem Well Supv <nI617@conocophillips.com> Date: Tue, 12 Jun 200712:20:04 -0800 To: Thomas Maunder <tom _ maunder@admin.state.ak.us> CC: James Regg <jim_regg@admin.state.ak.us> Tom, Thanks. WI should start either today or tomorrow. I'll be here until 6/20. Will keep in touch, Marie From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Tuesday, June 12, 2007 12:01 PM To: NSK Problem Well Supv Cc: James Regg Subject: Re: lC-06 (PTD 1810250) report of failed MIT - Permission requested to displace MI from tbg and near well bore with water injection. Marie, It is appropriate to inject water to sweep the MI from the tubing and immediate wellbore area. It is acceptable to inject for 1 week as planned and then secure the well with the tail pipe plug. Please notify us when the well is secured. Call or message with any questions. Tom Maunder, PE AOGCC SCANNED JUN 1:2 2007 NSK Problem Well Supv wrote, On 6/12/2007 11 :45 AM: Tom & Jim, 1C-06 has been SI with MI in the tbg and well bore since failing an internal waiver compliance MITIA on 5/14/07. Permission to inject water for 1 week to displace MI from the tbg and near well bore is requested due the safety hazards and risks involved with SL and Eline working on wells with MI in or near the well bore. It is safe to injection water as the well has 2 barriers between the injection water and the atmosphere, and the tbg and packer have integrity to keep all water injection within the approved zone. The tbg and packer integrity is sound as with the well has been on MI injection since 2/2007 at a tbg injection pressure of -3700 psi, the IA has been stable at 2200 to 2500 psi with no bleeds required to maintain the 1200 to 1400 psi differential. The surface casing has integrity as an MITOA to 1800 psi passed on 5/14/07. Based on trends and recent diagnostics, a leak in the production casing between the surface and the packer is the suspected cause of the failed MITIA. Diagnostics are planned to troubleshoot the failed MITIA to determine the exact location where fluids are exiting the IA as follows: 1. Sweep MI from near wellbore with 1 week of water injection. 2. Set plug in the tbg below the packer lof3 6/12/2007 12:34 PM RE: 1 C-06 (PTD 1810250) report off ailed MIT - Permission requested... . . 3. MITT & MITIA to verify initial diagnostics that the leak is in the production casing 4. Tecwel sonic leak detect log while injecting diesel into the IA to locate the IA leak depth. The well was granted an internal waivered to permit continued operation on water only injection in 2004 when it appeared the IA required frequent bleeds in MI service. Due to the oil rate loss in offset producers with the loss of EOR in this pattern, it is economic to perform a RWO to fix the minor leak. The well has been on the RWO candidate list since 2005 to replace the tbg/pkr to return the well from WI only to WAG service. Prior to moving a rig onto the well, diagnostics were planned to identify the exact location of the minor Mlleak to ensure that the planned RWO program would fix the very minor TxlA in MI service. After several log attempts with videos and nitrogen and the sonic tecwel LDL tool, no leak could be found in WI service. The well was wagged to MI for several months and the leak could not be repeated, the well was on MI and being monitored closely for any sign of communication on MI in order to catch the leak when active for diagnostic logging when the MITIA failed. The workover rig will arrive in Kuparuk next month. 1C-06 is the second well on the current rig schedule for tbg replacement, but since an IA leak is now suspected in addition to the very minor tbg or packer leak, the RWO is being delayed until the failed MITIA diagnostics are completed. Once diagnostics are completed, the well will remain SI while waiting on the RWO. Please advise if it is acceptable to displace the MI with injection water to proceed with pre-RWO diagnostics. Marie McConnell Problem Well Supervisor (907) 659-7224 n1617(â¿conocophillips.com From: NSK Problem Well Supv Sent: Tuesday, May 15, 2007 2: 12 PM To: 'Thomas Maunder'; 'James Regg'; Robert Fleckenstein Subject: 1C-06 (PTD 1810250) report of failed MIT Tom, Bob, & Jim, Wag Injector 1C-06 (PTD 1810250) failed a diagnostic MIT on 5/14/07, report attached. A liquid leak rate of 10 gpm @ 2850 psi was measured. The wellhead packoffs do no appear to be the leak path. Based on trends and diagnostic results, a leak in the 7" production casing is suspected. An MITOA to 1800 psi passed during diagnostics on 5/14/07. The well has been added to the failed MIT report for May. Additional diagnostics are planned to identify the leak location to evaluate repair options. The well has been on MI injection since 2/5/07. The MI injection will be SI today; however, to safely perform wellwork the MI gas should be swept from the tbg and near well bore area to avoid Mlleaks in the service unit's wellhead equipment and to avoid hydratelfreezing issues in the tbg with the service unit downhole tool runs. Permission to inject water for 1 week in prep for diagnostic wellwork is request. After a 1 week water injection period, the well will be SI until repaired or an administrative approval for water only injection is obtained. The tentative repair plan is to set a TIP, determine if the leak is in the tbg or the casing. Run a tecwel sonic leak detect log to locate the exact leak depth. Attached is a schematic and 90 day TIO plot. The well will remain SI while waiting on reply. Please let me know if there is any questions. Marie McConnell 2of3 6/12/2007 12:34 PM . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk I KRU /1 C-06 05/14/07 Brent Rogers / Ron Bates - AES ep \ r.¿ \' 0 Packer Depth Pretest Initial 15 Min. 30 Min. We1l11C-06 I Type Inj. I G TVD 6,402' Tubina 3550 3550 3550 Interval 0 P.T.D.!1810250 Type test I P Test psil 1600.5 Casing 2490 2850 2550 P/FI F Notes: Diagnostic test. InitiallA FL at surface. Pressured OA 200 200 200 UP IA to 2850 psi with 6 bbls, established IA LLR of 10 aDII I @ 2850 psi, pressure drODDE d off to 2550 psi in 20 mins. Weill I Tvœ Ind TVD I Tubino Interval P.T.D.I I Type testl Test psil Casino P/F Notes: OA Well I Type Inï.l TVD TubiO!:! Interval I P.T.D.I I Type testl Test psil Casina P/F Notes: OA Weill I Type Ind TVD I Tubing Interval P.T.DJ Type testl Test psil Casing P/F Notes: OA Weill I Typelnd I TVO I Tubing Interval I P.T.D.I I Type testl I Test psil Casing P/FI Notes: OA Weill I Tvœ Inj. TVD I Tubing Interval P.T.DJ I Type test I Test psil Casina P/FI Notes: OA D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water M = Annulus Monitoring P = Stand<Jrd Pressure Test R = Internal Radioactive Tracer SUlVeY A = Temperature Anomaly Survey D = Differential Temperature Test I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test duñng Workover 0= Other (descñbe in notes) MIT Report Form BFL 9/1105 MIT KRU 1C-06 05-1~7.x1s 1C-0690 no 5-1 Ix773 10f2 6/1 2:38 PM 1 C-06 (PTD 1810250) report of failed MIT . . Tom, Bob, & Jim, Wag Injector 1C-06 (PTD 1810250) failed a diagnostic MIT on 5/14/07, report attached. A liquid leak rate of 10 gpm @ 2850 psi was measured. The wellhead packoffs do no appear to be the leak path. Based on trends and diagnostic results, a leak in the 7" production casing is suspected. An MITOA to 1800 psi passed during diagnostics on 5/14/07. The well has been added to the failed MIT report for May. ;./' Additional diagnostics are planned to identify the leak location to evaluate repair options. The well has been on MI injection since 2/5/07. The MI injection will be SI today; however, to safely perform wellwork the MI gas should be swept from the tbg and near wellbore area to avoid Mlleaks in the service unit's wellhead equipment and to avoid hydrate/freezing issues in the tbg with the service unit downhole tool runs. / Permission to inject water for 1 week in prep for diagnostic wellwork is request. After a 1 week water injection period, the well will be SI until repaired or an administrative approval for water only injection is obtained. The tentative repair plan is to set a TTP, determine if the leak is in the tbg or the casing. Run a tecwel sonic leak detect log to locate the exact leak depth. J Attached is a schematic and 90 day TIO plot. The well will remain SI while waiting on reply. Please let me know if there is any questions. 7 SCANNED MAY· 2 9 200 Marie McConnell Problem Well Supervisor (907) 659-7224 n1617@conocophillips.com . «MIT KRU 1C-06 05-14-07.xls» «1C-06.pdf» «1C-06 90 day TIO plot 5-15-07.gif» MIT KRU lC-06 Content-Description: MIT KRU lC-06 05-14-07.xls Content-Type: application/vnd.ms-excel Content-Encoding: base64 Content-Description: 1 C-06.pdf Content-Type: application/octet-stream Content-Encoding: base64 Content-Description: lC-06 90 day no plot 5-15-07.gif lC-06 90 day TIO plot 5-15-07.gif . / .f Content-Type: Image gI lof2 5/21/200711:36 AM 1 C-06 (PTD 1810250) report off ailed MIT . . Content-Encoding: base64 20f2 5/21/2007 11:36 AM . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test ~o/f t5(zt/ D 7 Email to:Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuparuk / KRU /1 C-06 05/14/07 Brent Rogers / Ron Bates - AES Packer Depth Pretest Initial 15 Min. 30 Min. Well!1 C-06 I Type Ini. I G TVD I 6,402' Tubing 3550 3550 3550 I ntervall 0 P.T.D. !181 0250 I Type test I P Test psil 1600.5 Casing 2490 2850 2550 P/F F Notes: Diagnostic test. InitiallA FL at surface. Pressured OA 200 200 200 up IA to 2850 psi with 6 bbls, established IA LLR of 10 gpm @ 2850 psi, pressure dropped off to 2550 psi in 20 mins. Weill I Type Ini.1 TVD I Tubinq Interval p.T.D.1 I Type test! Test psil Casing P/F Notes: OA Weill I Type Inj.1 TVD I Tubing Interval I p.T.D.1 I Type test! Test psi I Casing P/FI Notes: OA Weill I Type Ini.1 TVD I Tubing Interva!1 p.T.D.1 I Typetesd Test psi Casing P/F Notes: OA Weill I Type Inj.1 TVD Tubing Interval p.T.D.1 I Typetesd Test psi I Casing P/FI Notes: OA Weill I Type Inj. TVD I Tubing Interval I P.T.D.I I Type testl Test psi I Casing P/FI Notes: OA v"'" D = Drilling Waste G=Gas I = Industrial Wastewater N = Not Injecting W = Water M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover o = Other (describe in notes) MIT Report Form BFL 9/1105 MIT KRU 1C-06 05-14-07-1.xls ! C-06 90 TIO 5- x773 ¡ of 1 1/2007 AM . . KRU 1 C-06 NIP (2015-2016, OD:3.5OO) TUBING (0-9253, OD:3.5oo, ID:2.992) TVD 65 2685 Wt 62.58 45,50 Grade H-40 K-55 Thread Gas Lift 3ndrelIDummy Valve 1 (9172-9173, OD:5.793) Thread BTC-MOD BTC-MOD Comment SBR (9227-9228, OD:3.500) TRO Date Run o 6/6/2004 Vlv Cmnt ID 2.813 3.000 3.000 2.750 2.992 PKR (9253-9254, OD:6.156) TUBING (9253-9294, OD:3.500, ID:2.992) Comment Date Note 11/26/1993 TUBING STRING from 9253' on Down, Left in Hole f/ Previous Com lelion. 4/27/2004 WAIVERED WELL: T x IA COMMUNICATION NIP (9291-9292, OD:3.500) TTL (9293-9294, OD:3.5OO) PROD. CASING (0-10226, OD:7.000, Wt:26.00) Perf (9410-9485) Vann Gun (10026-10127, OD:5.000) MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg ~K/ r~.:A(.H z:;f¡tiIDw P.I. Supervisor "'(' DATE: Tuesday, May 09,2006 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC IC-06 KUPARUK RIV UNIT IC-06 ,....\..., o)B .' \.'. ." . . .... .....<0 FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv 5ßF- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT IC-06 API Well Number 50-029-20564-00-00 Inspector Name: Jeff Jones Insp Num: mitlJ060508174832 Permit Number: 181-025-0 Inspection Date: 5/8/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ¡ 1C-06 IType Inj. ¡ w : TVD 6402 ! IA 2300 3015 3000 2980 2975 . ,I lOA P.T. 1810250 ITypeTest i SPT ~ Test psi 1600.5 825 860 860 860 860 i I Interval 4YRTST P/F P Tubing 2046 2045 2045 2046 2047 Notes I bbl diesel pumped, 1 well house inspected; no exceptions noted. :"'r ~Ì!'¡"i'''"'~ ~\tnJ1"ì,:¡;L : 3 2006 Tuesday, May 09, 2006 Page 1 of I " e e ConocoPhillips Alaska, Inc. KRU 1 C-06 1C..Q6 .- API: 500292056400 Well Tvoe: INJ Anale (â) TS: 47 dea (â) 9411 SSSV Tvpe: NIPPLE Oria Completion: 3/31/1981 Angle @ TD: 44 deg @ 10243 NIP Annular Fluid: Last W/O: 11/26/1993 Rev Reason: Drift & Taa (2015-2016, -. I I Reference Loa: Ref Loa Date: Last Update: 8/1/2004 00:3.500) Last Tag: 9507 TD: 10243 ftKB Last Taa Date: 7/26/2004 Max Hole Anale: 58 dea (â) 6300 Casina Strina . ALL STRINGS I Descriotion Size Top Bottom TVD Wt Grade Thread I CONDUCTOR 16.000 0 65 65 62.58 H-40 SUR. CASING 10.750 0 3287 2685 45.50 K-55 Gas Lift I. PROD. CASING 7.000 0 10226 7090 26.00 K-55 ldrel/Oummy Tubina Strina . TUBING ITUBING STRING From 9253' on Down Left in Hole fl Previous Completion) Valve 1 Size 1 Top I Bottom I TVD I Wt I Grade I Thread (9172-9173. 00:5.793) I 3.500 I 0 I 9253 I 6402 1 9.20 1 K-55 I BTC-MOD 3.500 I 9253 I 9294 I 6432 I 9,20 I K-55 I BTC-MOD I Peñorations Summarv Interval I TVD I Zone I Status 1 Ft I SPF I Date I Tvpe I Comment 9410 - 9485 6514 - 6566 I UNIT Open I 75 /12 /3131/1981 I SBR D,C-4,C-3 (9227-9228, Gas Lift MandrelsNalves 00:3.500) St I MD I TVD I r:.~~ Man Type I VMfr I V Type I V OD I Latch I Port I TRO I Date I VI v I Run Cmnt 1 I 91721 63411 Cameo MMG-2 I I DMY I 1 .5 I RK I 0.000 I 0 I 6/6/2004 I TUBING Other II luas e Juio.. etc.) . JEWELRY (0-9253, !I Depth TVD Tvpe Description ID 00:3.500, 2015 1852 NIP Otis 'X' Selective Landina Nioole IMCX INJ Valve Pulled on 3/20/95) 2.813 10:2.992) 9227 6383 SBR Baker EL-1 3.000 PKR 9253 6402 PKR Baker 'FHL' (Followina STRING Left in Hale from Previous Completion) 3.000 (9253-9254, 00:6.156) 9291 6430 NIP Cameo 'D' Nipple NO GO 2.750 9293 6432 TTL 2.992 Fish . FISH Depth I Descriotion I Comment 10026 I Vann Gun I Left from oriainal oerf. 101' lona NIP General Notes (9291-9292, Date I Note 00:3,500) 11/26/1993 TUBING STRING from 9253' an Down, Left in Hole f/ Previous Completion. TUBING 4/27/20041 WAIVERED WELL: T x IA COMMUNICATION (9253-9294, 00:3.500, 10:2.992) TTL (9293-9294, 00:3.500) I Perf - ,...- - f-- (9410-9485) - !-- - - - - - - - - - - - - - - - - PROD. ----, - CASING - . - - - (1-10226, - - 00:7.000, - - Wt:26.00) - - - - - - - - - - - - - - - - Vann Gun . 0026-10127, 00:5.000) STATE OF ALASKA ('~'~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1374' FNL, 4419' FEL, Sec. 12, T11N, R10E, UM 5. Type of Well: Development _ Exploratory __ Stratigraphic _ Service__X (asp's 561864, 5968860) 6. Datum elevation (DF or KB feet) RKB 94 feet 7. Unit or Property name Kuparuk Unit 8. Well number 1 C-06 At top of productive interval 1336' FNL, 1276' FEL, Sec. 1, T11N, R9E, UM At effective depth At total depth 1016' FNL, 779' FEL, Sec. 1, T11 N, R10E, UM (asp's 565454, 5974528) 12. Present well condition summary Total depth: measured true vertical 10243 feet Plugs (measured) 7102 feet 9. Permit number / approval number 181-025 / 10. APl number 50-029-20564 11. Field / Pool Kuparuk Oil Pool Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 65' 16" 425 sx PF 65' 65' SUR. CASING 3193' 10-3/4" 340 sx AS U 3287' 2685' PROD. CASING 10132' 7" 535 sx Class G 10226' 7090' RECEIVED NOV 8 6 '2001 true 13. Stimulation or cement squeeze summary Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl ' Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations X i::i i i::iii::iii::i::~iiiiiiiiiiiii!ii!iiii?:! ii::i i iili i~::~i::i::i:i::i::ii!::?iii::i::iiiiii~i~ai:: ?:: :: :::: ::::: ::: :: :: :: §~:: ~ i :: i ~i -- :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: ~:~:~:~:~:.~.~:.:~:.:~:~:~:~:~:~:~:.:.:.:~:.:~:.:~:.:.:~:.:.:.:.:.:~:.:~:.:.:~:~:~:.:~:~:~:~:.:.:.:.:~:.:.:~:.:.:.:.:~:~:.:~ :::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: 17. I hereby certi~ that the foregoing is true and correct to the best of my knowledge. Questions? Call Jeff Spencer 659-7226 I e Production Engineeri~upervisor Date A~pen~r Prepared by RobeR Christensen 659-7535 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 1 C-06 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 11112/01 Icommenced EOR Injection I 1C-06 Leak Subject: 1C-06 Leak Date: Sun, 19 Sep 1999 13:59:47 -0900 From: "Beck&Zuspan" <N1052~mail.aai.arco.com> To: blair_wondzell~admin.state.ak.us Hi Blair, Was doing some QC work and came across 1C-06 injector which has a small tubing leak. I'm sure we gave the Commission a call way back when but never hurts to double check. Here's a brief history of the well. 9/19/99: Checked history and infrequent bleed of 7" the past year 6/2/98: Well passed MIT. 10/9/96: Test 7" csg to 3500# (tubing at 3000#) - held at 3400#. 8/17/96: Tightened LDS and PT voids - good tests. 3/23/95: Attempt injection rate leak test - leak too small to conduct test. 3/21/95: Check 7" hanger void and pressure test - good test. 3/20/95: PT tbg and casing, determined there was a small leak in the tubing - Mike Beck 1 of 1 9/20/99 9:40 AM STATE OF ALASKA ('~ ~ AL~ OIL AND GAS CONSERVATION COMMI~ION REPORT OF SUNDRY WELL OPERATIONS '/"/',.., - - j Stimulate w Plugging Perforate _ ~'~ I Repair well Other X 6. Datum elevation (DF or KB) "~ 1. Operations Performed: Operation Shutdown __ Pull tubing Alter casing 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service X__ 4. Location of well at surface 1381' FNL, 867' FWL, Sec. 12, T11N, R9E, UM At top of productive interval 1336' FNL, 1276' FEL, Sec. 1, T11N, R9E, UM At effective depth 1068' FNL, 848' FEL, Sec. 1, T11N, R9E, UM At total depth 1022' FNL, 776' FEL, Sec. 1, T11N, R9E,'UM 12. Present well condition summary Total Depth: measured true vertical RKB ~)4 7. Unit or Property name Kuparuk River Unit 8. Well number 1C-0§ 9. Permit number/approval number 81-25/9~.-0,53 10. APl number 5o-029-20564 11. Field/Pool Kuparuk River Oil Pool 1 0243 feet Plugs (measured) None 71 0 2 feet feet Effective depth: measured 1 01 20 feet Junk (measured) None true vertical 70 1 4 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 6 5' 1 6" 425 SX PF 6 5' 2 68 5' Surface 3251' 10 3/4" 340 SX AS II 3287' 2685' Intermediate Production 1 01 92' 7" 535 SX Class G 1 02 2 6' 709 0' Liner Perforation depth: measured RECEIVED true vertical 6514'-6566' Tubing (size, grade, and measured depth) JUN 2 5 199;5 3.5", 9.2#, J-55 @ 9293' Packers and SSSV (type and measured depth) Alaska 0JJ & Gas Cons. ~ommission PKR: Baker FHL @ 9253'; SSSV: OTIS MC Injection Valve @ 2015' Anchnmge 13. Stimulation or cement squeeze summary Installed sub-surface, spring controlled safetY valve on gas injector, 2/23/93. Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A 14. Prior to well operation Reoresentative Daily Averaae Production or Injection Data - OiI-Bbl Gas-Md Water-Bbl Casing Pressure -0- 10000 0- 1200 Tubing Pressure 3800 Subsecluent to operation -0- 10000 0- 1200 3800 15. Attachments Well Schematic CoPies of Logs and Surveys run Daily RepOrt of Well Operations X 16. Status of well classification as: Oil Gas Suspended Service Gas Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 Date SUBMIT IN DUPLICATE ARCO Alaska, Incf*~ Subsidiary of Atlantic Richfield Company WELL.SERVICE REPORT ' [OPERATION AT REPORT TIME .!'"~ A ,v /'/I - ~_ _,:, ,,,, ,~,~ ~ REMARKS _ 0~o !1!0 /45'0 't~ T 'e.,3 o o o * KUPARUK PETROLEUM ENGINEERING [--1 CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK WeatherReport , { Temp, Chill Factor J Visibility Wind Vel. °F °FJ miles STATE OF ALASKA ~ISSION OILAND ~ CC)NSERVATION CPM ' REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate Plugging Perforate Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development ... Exploratory _ Stratigraphic _ Service X 4. Location of well at surface 1381' FNL, 867' FWL, Sec. 12, T11N, R9E, UM At top of productive interval 1336' FNL, 1276' FEL, Sec. 1, T11N, R9E, UM At effective depth 1068' FNL, 848' FEL, Sec. 1, T11N, R9E, UM At total depth 1022' FNL~ 776' FELr Sec. 1~ T11N~ R9Er UM 12. Present well condition summary Total Depth: measured 1 0 2 4 3 true vertical 71 02 feet feet 6. Datum elevation (DF or KB) RKB 94 feet 7. Unit or Property name Kuparuk River Unit 8. Well number lC-06 9. Permit number/approval number 81-25/93-017 10. APl number 5o-029-20564 11. Field/Pool Kuparuk River Oil Pool Plugs (measured) None Effective depth: measured 1 01 20 feet true vertical 7014 feet Junk (measured) None Casing Length Size Structural Conductor 6 5' 1 6" Surface 3251' 10 Intermediate Production 1 01 9 2' 7" Liner Perforation depth: measured 9410'-9485' true vertical 6514'-6566' Tubing (size, grade, and measured depth) 3.5", 9.2#, J-55 @ 9293' 3/4" Cemented 425 SX PF 340 SX AS II 535 SX Class G Measured depth 65' 3287' 10226' True vertical de~h 2685' 2685' 7090' RECEIVED JUN 2 5 199;5 Alaska 0il & Gas Cons. Commission Packers and SSSV (type and measured depth) PKR: Baker FHL @ 9253'; SSSV: OTIS MC Injection Valve ~ 2015' 13. Stimulation or cement squeeze summary 14. Anchorage Converted well from a shut-in oil producer to a gas injector on 5/15/93. Intervals treated (measured) N/A Treatment description including volumes used and final pressure N/A Representative Daily Averaae Production or In!ection Dat~ OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation -0- -0- -0- 1750 -0- Subsequent to operation - 0 - 7 8 0 0 - 0 - 2 9 0 0 15. Attachments Well Schematic 16, Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil _ Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 385O Service Gas' Irfiector Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE KDC¢S Pr' ,IINO WELL REPORT FO~ 05/1~' '3 ' '- .-: ....DR ILLS t'tE ::i-C-w.::-...-:r:~::-:z::-...-..~ .... is:r:-.:~-*--*:.-.- ................ ' .... r:'._-:.- .... I' PROD,~CTION WELL STATUS OAS 'LIFT STATUS IQOR = 4000 SI BAT W Z S E 0 T CHOKE L N A OR L E "T -%'- 1 C SI 2 C SI 3 C SI 4 C SI 7 C --.S I 8 C Si OAS OAS 7" ....... 10" ........... : ..... -?:-= ........ tNd OPT OPT -- H M WC H2S CSC CSC METER VOL - RATE ~L .R I -FTP FTT' ...... %"-PPM --PSi ..... PSI:'-~-'~'~EADI.N~ ..... MSCF-" MSCFD ROOTS ...... . S'N i'OTALS' 0 0 0 0 -0 0 £) 0 0 0 1160 0 0 0 0 0 1240 0 0 0 0 0 1180 0 -"0 .... 0 O ........0 ........ 0 0 0 0 0 0 100 INdECT!ON WELL STATUS 150 0 0 900 ........... 0 ........ 0 980 0 0 0 0 0 0 I NUEC t I ON VOLUMES ~-~.., , .,.,~ .., ,, .-. . . WATER RECMD OAS 0 0.0 2400 3' 0 0.0 2400 3' 0 0.0 2400 3 0 0.0 2400 3 0 0.0 ..... 2400 0 0.0 2400 3 0 S I DATA CHOKE ............. _:7 .......... t0" ...... :' ' :::-'::;~;j:::'?": ...... tNJ OR I I',ld CSg CSQ METER VOl "RATE VOL 7. pc.;t - FTT .... PSI PSI ...... REA'DI'NQ:'::-BBLS ....... :-BWPD '::MMSCF H M"O R I D S N '-:E ......... 5 C-" 'S I 6 B ~i cZ C SI i0 C SI T'OTAL. S- ..... 0 0 .......... ..:-.0 ........ 2't00 ....... 5-50 ............... . ---: .... A400 7.5 ........... 176 '3900 99 1000 50 6588 0 0. 583 2215 75 0 '3850 t20 50 ..... 50 ':t'~'~88.:::'::"v' .... 0'-!'-:"~',':',?~'~'0-:-~':'4..'.746-- 1530 32 0 3850 117 850 190 5688 0' 'i .... '0 :i"!4.252~ i545 32 SWt- 0 + PW!' 0 = 0 0 ~.581 J U N 2 5 199,3 Alask~ Oil & Gas G0ns. ~,~,~missio~ '"- ........ .:':- · .................. Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown __ Stimulate __ Plugging m Perforate Pull tubing x Alter casing __ 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 1381' FNL, 867' FWL, SEC 12, T11N, R10E, UM At top of productive interval 1336' FNL, 1276' FEL, SEC 1, T11N, R10E, UM At effective depth At total depth 1022' FNL, 776' FEL, SEC 1, T11N, R10E, UM 12. Present well condition summary TOtal Depth: measured true vertical 10243' 7102' feet feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 94'. PAD 60' 7. Unit or Property name Kuparuk River Unit 8. Well number 1C-06 9. Permit number/approval number 81-25(Conserv Order No. 10. APl number 50-029-20564 11. Field/Pool Kuparuk River Oil Pool 261) Effective depth: measured 1 01 2 0' true vertical 7014' Casing Length Size Structural 1 1 0' 1 6" Conductor SurfaCe 3258' 1 0-3/4" Intermediate Production 1 01 97' 7" feet feet Junk (measured) Cemented 425 SX PERM Measured depth 110 3287' 10226' 3466 SX AS II 525 SX CLASS G True verticaldepth 110'' 2685' 7090' Liner Perforation depth: measured 9410'-9485' @ 12 SPF MD true vertical 6514'- 6566' @ 12 SPF TVD Tubing (size, grade, and measured depth) 3-1/2" 9.3# K-55 @ 9293' Packers and SSSV (type and measured depth) BAKER FHL RETR PKR @ 9252',,OTIS 3.5" 'X' NIPPLE @ 2015' MD 13. Stimulation or cement squeeze summary RECEIVED MAR - 9 199; Alaska 0il & Gas Cons. C0mmiss[0~ 14. Intervals treated (measured) Treatment description including volumes used and final pressure Representative Daily Avera.qe prOduction or Injection Data Prior to well operation Subsequent to operation Oil- Bbl Gas-Mcf Wate r- Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector__ Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ ~¢ ~ ~F/¢E/Title Area Drilling Engineer Fo~ ~-~¢4 Rev 05/17/89 Date ._~/g/ SUBMIT IN DUPLICATE ARCO ALASKA INC. DAILY OPERATIO~ PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: APPROVAL: lC-06 NORTH SLOPE KUPARUK RIVER 50-029-20564 ACCEPT: 01/15/93 11:00 SPUD: RELEASE: 01/24/93 18:00 OPERATION: DRLG RIG: WO/C RIG: NORDIC 1 01/16/93 (1) TD:10243 PB:10120 01/17/93 (2) TD:10243 PB:10120 01/18/93 (3) TD:10243 PB:10120 MW:10.6 NaCl/Br MOVE RIG F/2H PAD TO lC PAD. HAD TO REPLACE DRIVE CLUTCH DURING MOVE. LEVEL RIG, RU HARD LINE TO FLOW TANK. BRING IN FMC LUBE & MU SAME. UNABLE TO RET BPV ON FIRST RUN, RE-RUN & PULL BPV. RU ANN TO CHOKE, MU CIRC JT ON TREE & RU TO MANIFOLD. INITIAL WELL PRESS 1100 PSI TBG, 1725 PSI ANN. VENT GAS TO FLOW TANK @ 02:30 HRS. PMP DN TBG W/12.4 PPG MUD @ 2-1/2 BPM TO DISPLACE GAS & FLUID. WAIT ON E-LINE TO CUT TBG MW:10.6 NaCl/Br DISPLACE WELL W/12.4% MUD. CIRC & COND MUD. MONITOR WELL. WELL IS STABLE. SET BPV. ND TREE. NU BOP. HAVE BOLTS CUT @ MACHINE SHOP TO FIT 11" DSA. NU BELL NIPPLE & FUNCTION TEST BOP. TEST BOPE & CHOKE MANIFOLD TO 3000 PSI. WITNESS OF BOP TEST WAIVED BY AOGCC REP JERRY HERRING. LD TEST JT. MU 3-1/2" CENTER SPEAR. SPEAR PUP JT BELOW HGR. PU ON TBG. ATTEMPT TO SHEAR SBR W/NO SUCCESS. WORKED PIPE W/MAX PULL 114K.(80% STRENGTH OF NEW PIPE). WAIT ON HLS "E" LINE' TRUCK. HAVE LANDING SUB FOR HGR BORED OUT TO 2.9" ID. POH CHANGING CPLGS MW:10.6 NaCl/Br RU HLS. RU LUB. WOULD NOT TEST. CIRC WELL WHILE REPAIR PACKOFF. TEST LUB TO 1000 PSI. RIH W/2.65 CHEM CUTTER. CUT 3-1/2" TBG 11' BELOW BTM GLM @ 9203'. POH. RD. LD LANDING JT. SPEAR HGR. PU ON TBG. PIPE CAME FREE @ 90K. LD HGR. POH W/2 STDS TBG. SMALL AMT OF GAS BREAKING @ SURF. CBU. MONITOR WELL. WELL IS STATIC. MU BAKER STORM. PKR & SET 1' BELOW TBG HEAD. TEST SAME TO 2000 PSI. LD LJT. ND BOP & 11" FMC TBG HEAD. NU & TEST SAME. SET TEST PLUG. NU BOPE. TEST BREAK TO 3000 SPI. PULL TEST PLUG. RETRV STORM PKR. LD SAME. RIH W/2 STDS. CIRCWELL. MIX & PMP SLUG. POH CHANGING TBG CPLGS TO AB-MOD. MAR - 9 t99 Alaska OiJ & Gas Cons, Commissio~ Anchorage WELL : lC-06 OPERATION: RIG : NORDIC 1 PAGE: 3 01/22/93 (7) TD:10243 PB:10120 01/23/93 (8) TD:10243 PB:10120 01/24/93 (9) TD:10243' PB:10120 POOH W/1-3/4" WASH STRING MW:10.6 NaC1/Br POOH W/FISH. LD 3-1/2" TBG STUB & SBR. BREAK OUT & LD FISH & FISHING TOOLS. RIH W/1-3/4" DC TO PLUG IN TAIL PIPE @ 9280'. CIRC & WASH OUT TAIL PIPE. DROP BAR & OPEN CIRC SUB ABOVE PKR. CIRC & COND MUD. CIRC TAIL PIPE @ 2 BPM & ABOVE PKR @ 4.5 BPM. MUD WTS OUT F/12.4 TO 13.9 PPG. POOH WITH WASH OUT STRING. PLAN TO GO BACK W/1 JT WASH PIPE TO CLEAN UP ON OUTSIDE OF SLICK STICK. POOH & LD 3-1/2" DP MW:10.6 NaCl/Br CONT POOH W/3-1/2" DP & 1-3/4" WASH PIPE. LD 1-3/4" DC'S, MULE SHOE & GUIDE. MU & RIH W/5-3/4" X 5" WASHOVER PIPE. MUD RUNNING OVER TOP OF DC'S AS RIH. INSTALL BLEEDER PLUG & USE FOR 45 STDS. MIX & PMP 15 BBL DRY JOB. CONT RIH W/3-1/2" DP. TAG SLICK STICK @ 9219', WASH DOWN TO TOP OF PKR @ 9242'. WORK PIPE & CIRC @ 4 BPM & 1900 PSI. 12.8 TO 13.9 PPG MUD, SOMETAR BALLS COMING BACK OVER SHAKERS. MIX & PMP HI-VIS PILL TO HELP KEEP BARITE FROM SETTING OVER SLICK STICK, FOLLOWED BY DRY 'JOB. FL(1800-2400)=4 BBL(OVER SHAKERS INTO CUTTINGS BOX). POOH & LD DP. NU FMC TREE MW:10.6 NaCl/Br SERV RIG. CONT POOH W/3-1/2" DP, LD BHA. UNLOAD PIPE SHED, CHANGE OUT TONGS, RU TO RUN 3-1/2" TBG. PULL WEAR RING. LOAD PIPE SHED W/12 JTS 3-1/2" TBG & JEWELRY, DRIFT & STRAP. SLIP & CUT DRLG LINE. START RIH W/3-1/2" BTC-MOD COMP STRING. MUD OVERFLOWING TOP OF TBG AS RIH. RU BLEEDER PLUG & CONT TO RIH. @ 68 STDS MIX & PMP DRY JOB. CONT TO RIH TO JUST OVER SLICK STICK. RU CIRC HEAD. UP WT 96K, DN WT 40K. CIRC & COND MUD TO PREP FOR DISPLACEMENT. RD CIRC HEAD. RIH & TAGGED PKR, RU CIRC HEAD & PRESS UP TO VERIFY SBR IS OVER SLICK STICK. PU & SPACE OUT COMP STRING. MU HGR, DRAIN BOP STACK & LAND TBG. RILDS. RU CIRC HEAD. PRESS TEST TBG & ANN TO 2500 PSI F/15 MIN, LOST 30 PSI. HOLD PRESS ON ANN, PRESS~TBG TO 3500 PSI F/15 MIN, LOST 50 PSI W/ANN PRESS STAYING CONSTANT. RD LINES, PULL LANDING JT, SET BPV. ND BOP & REMOVE HCR & HAND VALVE, REMOVE BOP FROM CELLAR TO MAKE ROOM FOR 13-5/8" 5M STACK ON NEXT WELL. PU FMC GEN I 3-1/8" 5M TREE & BEGIN NU. NOTE: DOORS ARE BEING CUT IN NORDIC'S CELLAR AS PERARCO DIRECTIVE TO ACCOMMODATE THE LONGER LUB NECESSARY TO INSTALL VR PLUG ON 2G-07. RECEIVED MAR - 9 199: Alaska Oil & Gas Cons. Anchorage WELL : 1C-06 OPERATION: RIG : NORDIC 1 PAGE: 2 01/19/93 (4) TD:10243 PB:10120 01/20/93 (5) TD:10243 PB:10120 01/21/93 (6) TD:10243 PB:10120 POH CHANGING CPLGS MW:10.6 NaCl/Br SERVICE RIG, CHECK CROWN-0-MATiC. POOH W/3-1/2" BUTT TBG-C/O COLLARS TO AB MOD, STAND IN DERRICK. DRIFT & STRAP SAME. FIRST 4 STDS OUT OF THE HOLE CAME WET. FIRST PILL DID NOT TAKE. MIX & PMP 19 BBL PILL. 33 STDS PULLED TOTAL. LD SSSV & 36 SS BANDS. HOLE UNSTABLE. CIRC 22 BBLS W/GAS BREAKING OUT @ SURF. RD TORQUE TURN TONG & RU TO RIH. TBG FLOWING SLIGHTLY. CIRC OUT DRY JOB & RIH W/6 STDS. MUD FLOWING FROM TBG 40' ABOVE FLOOR. MIX & PMP 40 BBL, 13 PPG DRY JOB. RIH SLOWLY W/3-1/2" TBG. RAN 24 STDS IN HOLE-MUD STARTED FLOWING OVER TBG. MIX & PMP 30 BBL, 13 PPG PILL. CONT RIH TO 9100'. CIRC OUT GAS WHILE INCREASING MUD WT TO 12.7%. CONDITION MUD. MONITOR WELL WHILE SLIP & CUT DRLG LINE. WELL IS STABLE. CBU. NO GAS TO SURF. PMP SLUG. POH CHANGING SEAL RINGS IN NEW CPLGS. HOLE TAKING PROPER HOLE FILL. RU TORQUE TURN. CONT POH CHANGING CPLGS TO AB-MOD. DRIFT & STRAP SAME. LOAD PS W/3-1/2" DP MW:10.6 NaCl/Br SERVICE RIG. POOH W/3-1/2" TBG. 1 JT OUT WET. MIX & PMP 25 BBL 13.6 PILL. POOH W/3-1/2" TBG, CHANGING BTC COUPLINGS TO BTC-MOD. DRIFT & STRAP PIPE. HOLE TAKING PROPER FILL. LD.1 JT BAD TBG. PIPE PULLING WET. MIX & PMP 20 BBLS 13.6 PPG PILL. POOH W/3-1J2" TBG, CHANGING BTC COUPLINGS TO BTC-MOD. DRIFT & STRAP PIPE. HOLE TAKING PROPER FILL. LD 8 JTS BAD TBG TOTAL. LD 1 JT GOOD TBG, STOOD BACK 144 STANDS IN DERRICK. PULLED 297 JTS TOTAL. LD 8 3-1/2" X 1" GLMS, SSSV, STUB F/PIPE SHED. RD FOSTER TONGS, RU DP SPINNERS. LOAD PIPE SHED W/3-1/2" DP, REMOVE THREAD PROTECTORS, STRAP & TALLY. POOH W/3-1/2" DP & SBR MW:10.6 NaCl/Br CONT TO LOAD PIPE SHED. STEAM OFF THREAD PROTECTORS, STRAP & TALLY. SET WEAR RING. MU OVERSHOT & GRAPPLE, RIH W/FISHING BHA ON 10 JTS 3-1/2" DP. SLIP & CUT 100' DRILLING LINE. CONT PU 3-1/2" DP & RIH TO 9130'. RU CIRC HEAD. UP WT 160K, DN WT 70K. BREAK CIRC. WASH DOWN F/9130'-9160'. CIRC @ 4 BPM & 1850 PSI @ 9160'. A LITTLE GAS ON BTMS UP, WITH A CONSTANT FLOW OF ASPHALTINES & PARAFFINS.. SEEING 12.9 TO 13.2 PPG, CLEAN & COND MUD UNTIL RETURNS OF 12.7+. PRESS UP TO 2500 PSI FOR 15 MIN TO TEST PACKER & PLUG IN TAIL PIPE, NO PRESS LOSS. CONT WASHING · DOWN TO TOP OF FISH @ 9201'. WORK OVER TOP OF TBG STUB, LATCH FISH. PU SLOW, BLEED OFF JARS, SHEAR SBR @ 30K OVER PU WT. PULL ABOVE SLICK STICK & CIRC @ 4 BPM & 2000 PSI. SOME GAS BACK @ BTMS UP(MORE THAN FIRST CIRC), STILL A LOT OF PARAFFIN/ASPHALTINE "TAR BALLS" COMING OVER SHAKERS. SEEING 12.9-13.0 PPG MUD BACK. CLEAN & COND MUD. MIX & PMP DRY JOB. START POOH W/3-1/2" DP & SBR. RECEIVED WELL : 1C-06 OPERAT I ON: RIG : NORDIC 1 PAGE: 4 01/25/93 (10) TD:10243 PB:10120 RIG RELEASED MW:10.6 NaCl/Br CHANGE OUT SEALS & NUADAPTER FLANGE, NU FMC GEN I 3-1/8" 5M TREE. PULL BPV. SET TEST PLUG. TEST PACKOFF TO 5000 PSI, TEST TREE FLANGE TO 250 PSI & 5000 PSI. PULL TEST PLUG. RU COMPANION FLANGE TO WING VALVE. RU-LINES FOR DISPLACEMENT. (MCEVOY OTIS UNION ON TREE CAP, CHANGE TO FMC 4" OTIS UNION DURING DISPLACEMENT). REVERSE CIRC 280 BBL WATER TO DISPLACE MUD @ 3 BPM & 1500 PSI. WATER COMING BACK CLEAN & END OF SPACER. DISPLACE WATER W/330 BBL DIESEL @ 3 BPM & 1800 PSI. HOLDING BACK PRESS IN CASE DOWNHOLE PLUG IS LEAKING. (PMP LEAKING 40 BBL F/END OF DISPLACEMENT; FIN PUMPING DIESEL, WILL REPLACE SEALS DURING RIG MOVE). BLEED DN ANN & TBG PRESS. NO BUILDUP, PLUG HOLDING PRESS FROM BELOW. RD LINES. CLEAN MUD & DIESEL FROM PITS, SECURE WELL. SICPm0 PSI, SIDPm0 PSI. RELEASE RIG @ 18:00 HRS 01/24/93. SIGNATURE: DATE: RE CEiVED MAR - 9 t99, Alaska Oil & Gas Cons. Commissior~ Anchorage ARCO Alaska, Inc.~ Post Office BOx 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Mamh 3, 1993 Mr. David W. Johnston, Chairman AlaSka Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in triplicate are multiple Application for Sundry Approvals on the following Kuparuk wells. Well Action 1 C-06 Waiver 2G-07 Waiver Anticioated Start Date February 1992 February 1992 If you have any questions, please call me at 263-4281. Sincerely, C. W. Strickland Engineer Kuparuk Petroleum Engineering Attachments ~t~ cc: V.L. Ferguson ATO-1370 (w/o attachments) ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany AR3B-6003-(~ , A~ OIL AND GAS CONSERVATION COMMI~:,&ION "' · APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend__ Operation Shutdown __ Re-enter suspended well __ Alter casing __ Repair well _ Plugging_ Time extension _ Stimulate Change approved program __ Pull tubing ~ Variance ~ Perforate __ Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) ARCO Alaska, Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1381' FNL, 867' FWL, Sec. 12, T11N, R9E, UM At top of productive interval 1336' FNL, 1276' FEL, Sec. 1, T11N, R9E, UM At effective depth 1068' FNL, 848' FEL, Sec. 1, T11N, R9E, UM At total depth 1022' FNL, 776' FEL, Sec. 1, T11N, R9E~ UM 12. Present well condition summary Total Depth: measured 1 0 2 4 3 true vertical 7102 Development Exploratory Stratigraphic Service feet feet RKB 94 7. Unit or Property name Kuparuk River Unit 8. Well number 1C-06 feet 9. Permit number 81-25 10. APl number so-029-20564 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool Plugs (measured) None Effective depth: measured 1 01 2 0 true vertical 7014 feet feet Junk (measured) None Casing Length Structural Conductor 6 5' Surface 3 2 51 ' Intermediate Production 1 01 9 2' Liner Perforation depth: measured 9410' 9485' true vertical 6514' 6566' Size Cemented 1 6" 425 Sx PF 10-3/4" 340SxASII 7" 535 Sx Class G Measured depth 65' 3287' 1 O226' True ve~ical depth 65' 2685' 7090' REcrciX/ED Tubing (size, grade, and measured depth) 3-1/2", 9.2#, J-55 @ 9290' Packers and SSSV (type and measured depth) PKR: Baker FHL @ 9255'; SSSV: TRDP @ 2046' 13. Attachments Description summary of proposal X Detailed operation program _ Install sub-surface, spring controlled safety valve in Gas injector. 14. Estimated date for commencing operation ~15. Status of well classification as: February 1993 ! Oil _ Gas 16. If proposal was verbally approved 1 /1 4/9 3 Name of approver Blair Wondzell Date approved Service Gas Iniector 17. I hereby certify th;.~.th,e_ f~r~r~,;i_;~ is true and correct to the best of my knowledge. Signed C,~J. ~ Ti tie FOR COMMISSION USE ONLY Alaska Oit & Gas Cons. Co~m~s=~O~ BOP sketch Suspended Date Conditions of approval: Notify Commission so representative may witness IApprova~.l No. Plug integrity BOP Test Location clearance I ~-~ ~"-~-~'~-~ Mechanical Integrity Test _ Subsequent form require 10- Approved b~ orde~ ol the Oommi~ion David W. dohnMOn Oommi~ioner Dine Form 10-403 Rev 09/12/90 SUBMIT IN TRIPLICATE Attachment 1 Request for Variance Kuparuk Well lC-06 As per Conservation Order No. 173, Rule 5, paragraph (a) (2), ARCO Alaska requests Commission approval to replace the existing surface controlled, subsurface safety valve in Injection Well lC-06 with a downhole, spring controlled, injection valve. This injection valve will act as a one-way check valve allowing downward injection of water and gas while preventing upward flow of reservoir fluids. The injection valve is capable of preventing uncontrolled flow by automatically closing if such a flow should occur. The proposed work would be performed during the forthcoming workover to install AB modified tubing couplings and a higher pressure rated wellhead in preparation for converting this well from shut-in oil production to gas injection service. Attached is a schematic of the proposed injection valve. TOP SUB ! PRING SEAT INSERT Otis MC Injection Valve FLAPPER VALVE AND SPRING ASSEMBLY STATE OF ALASKA COMM~',.h~ION O · OIL AND GAS CONSERVATION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend m Alter casing __ Repair well Change approved program ~ Operation Shutdown m Re-enter suspended well B _ Plugging_ Time extension _ Stimulate__ Pull tubing __ Variance _ Perforate __ Other 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 14. Location of well at surface 1381'FNL, 867'FWL, Sec 12, T11N, R10E, UM At top of productive interval 1336'FNL, 1276'FEL, Sec 1, T11N, R10E, UM At effective depth 1068' FNL, 848' FEL, Sec 1, T11N, R10E, UM At total depth 1022'FNL~ 776'FEL~ Sec 1~ T11N~ R10E~ UM 12. Present well condition summary Total Depth: measured 10243 feet true vertical 71 02 feet Effective depth: measured 1 01 20 true vertical 701 4 Casing Length Size Structural Conductor 65' 1 6" Surface 3251' 10 Intermediate Production 10192' 7" Liner Perforation depth: measured 9410'-9485' true vertical 6514'-6566' 5. Type of Well: Development _ Exploratory _ Stratigraphic __ Service ~X 3/4" feet feet Tubing (size, grade, and measured depth) 3 1/2" 9.2#, J-55 @ 9290' Packers and $SSV (type and measured depth) PKR: Baker FHL @ 9255'; SSSV: TRDP @ 2046' Plugs (measured) Junk (measured) 6. Datum elevation (DF or KB) 94 ' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 1C-06 9. Permit number 81 10. APl number _50-0Z9-20564 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool None None Cemented Measured depth True vertical depth 425 Sx PF 65' 65' 340 Sx AS II 3287 2685' 535 Sx Class G 1 0226 7090' RECEIVED JAN A~aska Oi) & Gas Cons, 13. Attachments Description summary of proposal ~ Convert well from oil producer to gas injector. 14. Estimated date for commencing operation Februarv. 1993 16. If proposal was verbally approved Name of approver Date approved Detailed operation program_ BOP sketch 15. Status of well classification as: Oil ~ Gas Suspended Service Gas Iniector 17. I I hereby certify that the fo. rego. ing FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity BOP Test ~ Location clearance ~ ~ ~,,~Tf;~,j ,,),~ , ~,~;~_ . Mechanical Integrity Test __~ Subsequent form require 10- //07 '?':;!; :_:'"L~' '~ Original S~gned By ~...: ............. David W. Johnston -' Approved by order of the Commission Commissioner Date is true and correct to the best of my knowledge. Title IApproval No. , 7 Form 10-403 Rev 09/12/90 SUBMIT IN TRIPLICATE Attachm.=nt I ( Conversion to Gas Injectioh Kuperuk Well 1C-06 ARCO Alaska requests approval to convert Well 1C-06 from an oil producer to a gas injector. This well will be operated as a Class II UIC well in compliance with Area Injection Order No. 2. Gas will be injected for the purpose of gas storage into the Kuparuk interval between the depths of 9410' and 9485' MD-RKB. This interval correlates with the strata found in ARCO's West Sak River State Well No. I between the depths of 6474' and 6880' as authorized in Rule 1 of this injection order. A Mechanical Integrity Test will be performed before injection is initiated and every four years thereafter, in compliance with Rule 6 of this order. This well's injection volumes, average injection pressure, and average annulus pressure will be reported to the AOGCC monthly. RECEIVED JAN 2 2 t99,~ oil & Gas Cons. Anch0reg~ ATTACHMENT I I KUPARUK RIVER UNIT Production Logs FEBRUARY 19, 1986 Drill' Site Well No. Log Date 1A-4 7/6/83 1A-5 10/29/83 1A-7 2/8/82 5/7/82 1A-9 1/25/82 3/23/83 1A-11 1/19/83 3/21/83 1A-12 3/8/82 1A-14 4/1/82 1A-15 6/5/82 1A-16A 5/11/82 6/8/82 lA Drill Site Well No. Log Date 18 18-1 12/26/81 18-2 6/25/81 18-3 11/16-18/81 3/12/82 18-6 11/18/81 9/10/82 18-7 11/23/81 18-8 12/28/81 8/4/82 18-9 6/24/82 8/3/84 Drill Site Well No. Log Date 1C lC-1 5/9/81 1C-2 5/8/81 1C-3 7/13/81 1C-4 11/8/81 3/9/81 1C-5 2/26/81 ~ :: 1t/30/81 1C-7 5/19/81 1C-8 ' 5/21/81 Drill Site Well No. Log Date 10 1D-1 ~ 1/80 5/23/83 10-3 8/5/80. 10-4 7/30/80 8/13/80 10-5 6/11/81 10-6 6/9/81 10-7 6/8/81 (WS-8) 5110178 Attachment Page 2 Drill Site 1H Well No. Log Date 1H-3 8/16/82 1H-4 8/13/82 1H-6 6/21/82 1H-7 7/20/82 1H-8 7/22/82 Drill Site Well No. Log Date lQ ~1Q'5~12/I785!- Drill Site 1E Wel 1 No. 1E-lA 1E-2 1E-3 1E-4 1E-5 1E-6 1E-7 1E-8 1E-12 1E-15 1E-16 1E-17 1E-20 1E-24 1E-25 1E-26 1E-27 1E-28 1E-29 1E-30 Log Date 8/19/81 8/17/81 1/17/84 10/18/81 11/7/81 8/4/80 9/2/81 11/5/81 10/27/81 10/21/81 11/12/82 10/28/81 8/28/81 11/1/81 11/28/84 8/26/82 8/29/82 9/1/82 5/7/83 2/17/83 1/17/83 1/13/83 10/31/82 10/27/82 6/13/83 10/18/82 7/18/83 10/16/82 Drill Site 1G Well No. Lo9 Date 1G-1 1G-2 1G-3 1G-4 1G-5 1G-7 1G-8 Drill Site Well No. 9/7/82 9/25/82 9/28/82 12/8/84 10/13/82 11/12/82 1F 1F-1 ..1F-2 1F-3 1F-4 1F-5 1F-6 3/12/83 Alaska Oil & Gas Cons. ,~'~orage 1F-7 Log Date 2/19/83 2/3/83 1/31/83 5/29/83 10/25/82 !0/28/82 11/19/82 5/7/83 Attach.ment Page Drill Site Well No. Log Date 1Y Drill Site 2Z' 1Y-1 6/6/83 10/21/83 1Y-2 6/10/83 3/4/84 6/18/83 1Y-4 7/2/83 1Y-5 6/29/83 1Y-6 6/27/83 1Y-8 6/22/83 1Y-9 6/20/83 ~~ 5 / 10 / 83 ~ 11/21/83 1Y-12 5/25/83 1Y-13 5/27/83 1Y-14 5/13/83 5/18/83 1Y-15 5/29/83 1Y-16 5/30/83 10/23/83 Well No. Log Date t~v~-~m~' 7/10/83 2Z-2 '; 6/24/83 7/19/83 2Z-3 ' 8/5/83 2Z-4 7/12/83 2Z-6 7/27/83 2Z-7 7/28/83 2Z-8 8/3/83 Drill Site Well No. Log Date 2C 2C-4 2/19/85 2/28/85 2C-7 10/15/84 VLF:pg:O052 Anchorage ATTACHMENT I! KUPARUK RIVER UNIT Production Logs Drill Site lA Well No. ~ lA-4 "~lA-5 '~1A-7 ~1A-9 ~1A-11 '~1A-12 '~1A-14 '~ 1A-15 ',,1A-16A L.og Date 7/6/83 10/29/83 2/8/82~x, 5/7/82/ 1/25/82~- 1/l~/v3 3/21/83 .' 3/8/82 4/1/82 6/5/82 5/11/82~ ~, 6/8/82 /~ Dri 11 Site Wel 1 No. Log Date 18 '"'18-1 12/26/81 ~18-2 6/25/81 '~18-3 11/16-18/81",~/- '~ 3/12/82/ ~'18-6 11/18/81~ '~ 9/10/82/ .~ ~18-7 11/23/81 ~18-8 12/28/81'-,> '~ 8/4/82/ ~IB-g ~ 6/24/827: ,,,,.._813184 ,' Drill Site 1C Wel 1 No. '"~lC- 1 ' '"'1C-2 "1C-3 ',~1C-4 ~w~ ~1c-5 ._ '~1c-6 "~1C-7 "~ 1C-8 Log-Date 5/g/8'1 5/8/81 7/13/81 3/9/81 2/26/81 11/30/81 5/19/81 5/21/81 Drill Site Well No. Log Date 1D 1/80~> ~' 5/23/83/* "~lD-3 8~5/80 1D-4 ~7/30/807 ~8/13/80~ ~ '~lD-5 6/11/81 ~1D-6 6/9/81 ~1D-7 6/8/81 XJlD-8 (WS-8) 5/10/78 RECEIVED FEB 21 1986 Alaska 011 & Gas Cons. Commission Anchorage ARCO Alaska, InF~f Post Offic% ~.,.,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 8/30/85 TRANSMITTAL NO: 5305 RETUtd~ TO: ARCO ALASKA, INC. KUPARUK OP~:KaTIONb ENGINEERING RECORDS CLEF, l< ATO-1115B P.O. BOX 100360 ANCHORAGE, aK 9951U TRANSMITTED HERL%~ITh ARE THE FOLLOWING IT~IS. PLEASE ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THIS TRANSbiITTAL. ~EWULNCE OF EV~.'NTS PRESbURE DATA ~-~ 2 X- 10 ~'"w~W- 1 "ShBhP ~'-lQ-9--PBU C SAND ~2A-2~" PBU A SAND "'~2AJ'~'''' PBU PRE STRESS FRAC A SAND 2A-4 PBU PRE STI<EbS FtiAC A bAND ~2E-9''~ PRESSURE REPURT ~ 2L-10-'PRE~SURE REPOttT ~REbSUPd~: REPORT _ .- J '-~="Z'E-%'~6' PRESSURE REPORT ~2U-10 PRESSURE KLPORT '"-'2U-it PREbSUKE REPORT "~' 2U- 16-'PRESSURE REPORT '~ 2U-16 ~BOTTOM-HOLE-SAMPLE "'~2U-16' PBU C SAND "~2U-14'PBU A SAND "'~2U-16-~PBU A SAND '~-2U-14'PBU C SAND ~'~2W-13 PBU 'C SAND ~"2U-16 PRESSURE REPORT RECEIPT ACKNOWLEDGED: BPAE* B. CURRIER CHEVRON* D & M* DRILLING L. JOHNSTON MOBIL* NSK CLERK DISTRIBUTION: W. PASHER EXXON PHILLIPS OIL* J. RAThMELL* 4/25/85 2/22/85 5/12/85 1/24/85 12/6/84 12/28/84 6/13/85 6/13/85 6/13/85 6/ 7/85 6/ 6/85 5/27/85 5/27/85 5/29/85 6/13/85 6/ 6/85 6/30/85 6/16/85 6/17/85 6/17/85 5/29/85 bATE: STATE OF ALASKA* SO}iIO* UNION* K . TULI~/VAULT ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, In~~f' Post Offic~...,.,x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE: 08-21-85 TI{ANSMITTAL NO: 529 6 RETURN TO: ARCO ALASKA, INC. KUPARUK OP]£RATIONS ENGINEERING RECORDS CLER/{ ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 TRANSMITTED HEREWITH ARE THE FOLLOWING ITEMS. PLEASE ACKNOWLEDGE RECEIPT AND RETURN ONE SIGNED COPY OF THIS TJtANSMITTAL. SEQUENCE OF EVENTS FROM WELL SERVICE REPORTS PRESSURE DATA ~1C-4 '- 07-23-85 '-~ 1C-5" 07-29-85 "~1C-5,~,- 07-30-85 ~-~iC- 6 ~ 07-25-85 "'-T.C- 6 ,~ 07-24-85 ~lD-8 -" 07-30-85 STATIC BHP PBU PSU STAT IC BHP STATIC BHP STATIC BHP --~. 1H_ 3~ -'-~lR-5' 07-05-85 -'-'lP,- 6'' 07-06-85 -"- 1R-8 07-U~-85 '~ 1Y-10- 07-27-85 ~ 1Y-11 -' 07-28-85 ~' 2A-2 .' 07-04-85 ~- 2]~-13" 07-30-85 ~-2U-14' 06-30-85 ~- 2U-14 .... 07-01-85 "2U-15~ 07-08-85 ~ 2V-2 07-27-85 ~' 2V-2.. 07-28-85 ~- 2W-7' 07-26-85 ~2W-7" 07-27-85 ~ 2X-15t 07-09-85 ,. ' 2X-15 ~ 07-04-85 ' 2Z-l- 07-05-85 "2Z-6- U4-08-85 ~3B-7 ~ 06-27-85 ' 3B-8~ 06-28-85 - 3B-8~ 06-27-85 ~3B-9 ~ 07-18-85 - 3B-11 07-20-85 ' 3B-12" 07-21-85 "3C-11~ 07-29-85 07-30-85 STATIC BHP DHP & MISC. BHP & MISC. STATIC Blip & STAT IC BHP END OF PBU 'C' SAND STATIC BHP PRESSUHE DATA 'A' SAND PBU 'A' SAND PBU PRESSURE TEST & HI'C. 'A' SAND PBU 'A' SAND PBU 'A' SAND ONLY PBU 'A' SAND PBU FLOWING BHP & FLUID I.D. FLOWING BHP & TEMPERATURE BHP SURVEY & MISC. STATIC BHP STATIC BHP & MISC. STATIC BHP & MISC. BHP & MISC. STATIC BHP & HISC. BHP SURVEY & MISC. STATIC BHP & MISC. STATIC BHP ,~ MISC. RECEIPT ACKNOWL]SDGED: BPA}J* B. CURRIER CHEVRON* D & [vi* DISTRIBUTION: DRILLING W. PASHER L. JOHNSTON EXXON HOBIL* PHILLIPS OIL* NSK CLERK J. RATHMELL* · ARCO Alaska, Inc. is a S-bsidiary of AHanticRichfieidCompany CAMCO DRESSER ATLAS DRESSER ATLAS CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO DRESSER ATLAS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS OTIS CAMCO CAMCO OTIS CAMCO CAMCO CAMCO CAHCO STATB O~ U~[O~* ARCO A aska, In~ Post Offic% ~,~x 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 KETUPa~ TO: ARCO aLASKA, INC. KUPARUK OPERATIONS RECORDS CLERK ATO-1115B P.O. BOX 100360 ANCHORAGE, AK 99510 ~'lB-4- ' 05-16-85 ' lC-4 07-24-85 CAHCO "lC- 6';" 07-25-85 CAMCO ' iD- 8 -~ "' 07- 30- 85 CAMCO --1H-3 "07-30-85 CAMCO ~'lQ-13/ '06-24-85 CAr]CO ~lQ-14-'~ 06-23-85 CAMCO "iQ- 15-~'' 06- 21- 85 CAMCO "lQ-16j 06-21-85 CAMCO ~ 1R- 5'''~- 07- 05- 85 CAMCO , 1R_6~-' 07-06-85 CAMCO '~ IR- 7/' 07- 06- 85 CAMCO "1R-8 ~'' 07-08-85 CAMCO ~"2A-2 .... 07-04-85 OTIS ~2~/-7'~ 07-26-85 DRESSER '~2V- 3 07-11-85 OTIS ,~2W-15~' 08-04-85 OTIS 3B-1- 06-14-85 ???? ' 3B-2~ .... 06-14-85 CAMCO -3B-3 .... 06-28-~5 OTIS ~3B-3" 06-15-85 CAMCO ~3B-4" 06-15-85 CA~CO '3B-5 ~' 06-26-85 CAMCO ' 3B-6~- 06-26-85 CA£~]CO ~3B-7'~ 06-28-85 CAMCO 3 B- 7 -- 06- 27- 85 CA/4CO 3B-8~ 06-28-85 OTIS -3B- 9' 07-18- 85 CA~]CO ~3B-10~ 07-20-85 CA~]CO -3B-11-~ 07-20-85 CAMCO 3B-i2-.~ 07-21-85 CAMCO 3B-13' 05-29-85 OTIS "3B-14 05-29-85 OTIS RECEIPT ACKNO~LEDGED: DATE: 08-21-85 TRANSMITTAL NO: 5292 ENGINEERING PLEASE ACKNOWLEDGE OTIS TRANSMITTED HERE;~ITH ARE THE FOLLOWING ITEMS. kECEIPT AND RETURN ONE SIGNED KUPARUK WELL PRESSURE REPORT--ENVELOpE FACE DATA 05-30-S5 CAMCO ~3B-15 05-30-85 CAMCO 3B_16~.-~- CAMCO ~'~3C-11~" COPY OF THIS TRANSMITTAL. 05-28-85 05-28-85 OTIS 07-29-85 CAMCO STATE OF ALASKA* SOHIO* PHILLIPS OIL* UNION* J. RATHMELL* K. TULIN/VAULT BPAE* DRILLING B. CURRIER L. JOHNSTON CHEVRON* ~BIL* D & M* NSK CLERK DISTRIBUTION: ~'i. PAShER EXXON ARCO Alaska, Inc. ~s a Subsidiary of AllanlicRichfie~dCompany ARCO Alaska, inc. [. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 DATE ' 05-t ~"J-o~'~'" '¥RAN.'~MITTAL NO :5t 85 RE'f'UI:~N Tt;]: ARCO AL_A:91(A, INC. ATTN' RIECORDS' CL. ERK A]'O-I t t 5B P,,O. BOX t00S60 ANCHOI?A(;E, Al< 99510 ]'I:~:AN3MI'I'I'EiD i-'IE:REWITH ARE THE] i::'OLL. OWING RECEIF'I' AND RETURN ONE $I(;NED COPY I I'i::.H 5'. CI( NOWLEDGE OF '¥1..i l $ 'FF<ANSH I T'IFAL, WS'I:::/5'I:'QtJENCI'Z [)F IZVENI'$ (ONE COF'Y OF EACi-I) t A-1 F:'BLI tA-t F'BU tA-2 Ir;rUN LYNES REC;ORDEiF(5' t A'-2 END P[U/RUN HRDF' t i,-,, ,?Bi'IF' t A-4 2BHP t A-'2; I::'B U tA-5 PULL F'BU t A-6 PBU ~-6 I"lAiqG OFF' LYNE.~ BOHB~' I:rOF,: F'BU t A- 6 F I N 13.' H F' B l.J tA-i0 RUN LYNE~' 'i A-1 un F'LILL LYNES' RECORDERS' i B-3 F:'BU t B-3 F'BU t C- 4 . 5' B i"1F:' t C-4 SBHP 'i C-6 RUN LYNE$ RECOI:i:I)EI:;:$ tC-6 RE'i-RIFVE LYNE$ RFC, Oi:~DIEF{.S' t E'-4 Ir<UN 5'F'INNFR/TEiMPFikA'FLJRE 5'LJRVEY.-L. EAK DETECT ]'ON t !"'~- 5 R U N F' B lJ 5' lJ R V lie Y t E- t 6 I N,J E C T I V I T Y .'i' E" Zg'F t I.:.:-t 6 INJI:'CTIVITY TES'I' t E-2V IN,JECTION 'f'l"::$T/' A'SAND t E-2'7 T EHPERATLJF;:F/5'F:' I NNER-- LEAl( DI:E'¥1EC'i'ION IF'-3 RUN LYNE5 TANDE:H F'RI75'$UI:;~F BOHD$ F'OR 1F'-3 RETRIEVE I_YNES' REC[IRDEF;~$ 1F-D RUN LYNE$ RECORDFF;:$ .... 04-2 t -85 [;AMC[) 04-'~2-85,:. CAMCO (.) 4 -' 21 -' 8 .U C A M C 0 04-23-85 CAMCO 04-1 9-85 CAMCO ' '04-t9-85 CAMCO 04-2t -85 CAMCO (~4-.22-85 CAMCO G4-2t -85 Ol' I ~' (') -"~ 5 4 ,,:. t --8 O'T' 15' 04-22-135 [)T I,.? (')4-2t -85 CAi'iCO 04-22/23-85 Cv, MCO 04-2t -85 CAHCO 04-22-85 CAMCO 04-2¢,-85 CAMCO 04-25-85 CAMCO (')4-2t -85 OTIS" 04-23-85 OTIS 04--23-85 CAMCO ¢ 4 -. 26 - 85 C A M C 0 04-t 9-85 (94-20-85 ARCO 04-22-85 ARCO 04 - 2 '7 -. 85 0 T I ~' 04-2t -85 OTIS G4-'23":85 OTIS BF'AE* B. CURRIER* C I..i 1::' V R 0 N.* D & M* 'C' ,.'?AND ONL. Y 04-2t -85 OTIS' t 1:"' - 5 R Ii'-' T R I E V E !_ Y N Ii." S I';: r:." C 0 R D [." R 2 04 -- '2 '2 -. 85 0 '¥ I $ RECEIF'T ACI(NOWLEDGED: ....... :. .............................................. .-._ D I ..'9 'F R I B t.J '¥ I 0 N: DRI L.I.. I NJ; 1,,,I, F'AS'HEF( I .... J 0 H N .'~ T 0 N E X X 0 iq * M 0 B I I... * P 1--! I L. L. I I::' $ 01 L NS'I( CLEI:;:K *-,J. F<ATt'IMELL I;: E'[' LJ I::~ N 'f 0: ! I'~A~,[S ~ Il '["l'liE I) I::~ E C lei I I':' T A N I) ARCO Alaska, Inc, Post Office 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 I).P, T E ' 0'5 - i ::' o,'..- .) '- O _) TRAi:',~SHITTAL NO:Si ARCO AI...ASI(A, liN(.'... A T 'i" N ' R E C C)I::¢ I) 5' C L E R K ANCI'IORA(]IE Al( 995t0 I--I E R E W I T I'-I A I::~ E 'T !'1E I::' [)!.. L. C) W I N (; I T E H 2. ::, ...I~E ':' ~.' E':~ ACK.- ') N 0 W L E D (; E RE'I"LJRN ONE SI(;NED COF'Y OFr '['I"IIS 'FRANSHITTAL. I... Y Nli"'S [:'BLJ ( O H [:' C f.)I::'Y CJ F E A C H, ) '[ O Lll_. ,.~" E'I' D E F:"f' I"! 7t 87 7'I '76 7476 8300 8 ?'5.,00 E~ 4 t 5 84 t 'S 6 i '5'5 70 '7.5 70 '~'''- ~ ..~ 73 t 2 7T3'12 670i 670 i '¥OOL · ~ ~7 ") i "z ,:' ,':, ,3, ..~ ,:.. · i 5t 2 i 734 t7t9 · '~ (':; ,:. 1299 i 508 I 5(')3 t 50t t 5 ,,:. 0 '1 t5t t t 3'18 t3:33 t3t? t5t5 I:;:ECI]" l F'T ACI<NOWLEI)GED ' BI::'AE.x. B ,. C LJ i:;~ I;,' I E R ~ C HI::; V F;:O N-x- I) F;: I I.. I.. I N g l.,, JLgI"INS'T' ON NC}BI I_.×' N,5'i( C I_ l""'1:::1( t'J, F:' .Pi S I"1 Ii"' I:;: ,.,~¢,~,o O,, ;~,i' ~:. , 0 E cA ~ A $1-/, A ':,:' Ii'.'.XXON .~'(;)1'-I I O.x- "--'~.~ Cons, Oot,im!ssion F:' H I I... I.. ]: F:'S 01 k-x' LJ i'( I C) N'x. J, RA'¥1"IHEL. L.-)~ K, TUI_ I N/V,&ULT ARCO- Alaska, I( Post Offi~ Box 360 Anchorage. Alaska 99510 Telephone 907 277 5637 F:; [.:7'.'r U F' i,.! 'f'(3 · r., r'iI I ....... '..'..::. I... I... .. ARCO Alaska. Inc. ,s a subsidiary' Of ~.llantlcR,chheldCompany ARCO Alaska, Inc ~ Post Office( .~60 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 02/19/85 Transmittal No: 5055 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B //0. Box 100360 chorage, AK 99510 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. BHP Reports/Static Reports CAMCO '~01/ iA-10 28/85 lA-10//D2/07/85 1G-4 ~01/24/85 2F-11/01/29-30/85 2X-9 ~/ 01/25/85 2X-10" 01/27/85 1C-6// 01/28/85 1E-5/ ~ 01/30/85 1E-30/ 02/07/85 Receipt Acknowledged: · B. Currier BPAE Chevron D&M Date: Alas:~a u~i a U:~s Coils. Commissior~ DISTRIBUTION Anchorag~ Drilling Geology G. Phillips Sohio Mobil NSK Drill Clerk Phillips Oil J. Rathmell Union Well Files ARCO Alaska. Inc. is a subsidiary of AtlanticRich!ielCCompan) "ARCO Alaska, Inc. Post Officf 360 Anchorage, ~,laska 99510 Telephone 907 277 5637 Date: 1/31/85 Transmittal No: 5019 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 an r~nsmitted herewith are the following items. Please acknowledge receipt return one signed copy of this transmittal. PBU SURVEYS .Otis-~r ~ '& SEQUENCE OF EVENTS lB-3 1/24/85 ..... ~'""'~ ~/~'~' 1E-2 1/24/85 ~ lA-.4 1/20/85 2G-7 1/23/85 2V-8A 1/24/85 2Z-4 1/19/85 2Z-6 1/19/85 2B-lO PBU SUR~EYS Lynes ~-6b/ 1/21/85 Tool #1317 //'...~-~. 1/21/85 "#1516 ,~/ ?.~z-?~1/21/85 " #1511 /cat Receipt Acknowledged: 1/21/85 "PBU" 1/21/85 "PBU" 1/21/85 "PBU" 1/21/85 "PBU" Date .- B. Currier Drilling .- BPAE Geology DISTRIBUTION W. Pasher ' G. Phillips State of AK Sohio Chevron Mobil Phillips Oil Union D&M NSK Ops. J. Rathmell Well Files ARCO Alaska. In¢. ~$ · lub~idiar¥ of AtlanticR,ch!ieloComl~an.¥ M EMORAN" UM TO: THRU FROM: State ' of Alaska ALAS~ OIL AND GAS CONSERVATION COMMISSION C. V~~er~ton DATE: February 5, 1985 Chai~ ~ " FILE NO: D. B~. 10 Lonnie C. Smith Co~issioner Ben LeNo~n SUBJECT: Petro'le~ Inspector Witness Retests of ARCO' s: 1C ,6 Low Pilot and ARCO' Kuparuk 1E-12 SSSV, Kuparuk River unit~. Saturday, February 2, 1985: I departed my home at 6:00 am for a ~%30-am~Sh0wup'~'and 7:30 a~ departure via Alaska Airlines, Flt. #55 for Deadhorse, arriving at 9:10 am. Weather: +2°F, clear. BOPE tests on ARCO's Kuparuk 2U-1 were completed, the subject of a separate report. Sunday, February 3, 1985: BOPE tests on ARCO's Kuparuk 2W-1 were comPleted, the Subject of a separate report. Low pilot on ARCO's Kuparuk 1C-6 and SSSV on ARCO's Kuparuk 1E-12 were retested successfully. Safety valve test report is attached. Monday, February 4, 1985: Twenty-one components *retested on e-igh~eeh-ARCO"P~udhoeBay wells, the subj.ect of a separate report. I departed Deadhorse via Alaska Airlines, Flt. ~56 at 5:40 pm arriving in Anchorage at 7:20 pm and at my home at 7:50 pm. In summary, I witnessed successful retests of ARCO's Kuparuk lC-6 low pilot and 1E-12 SSSV. Attachment 02-00IA(Rev. 10t79) · STATE OF ALASKA ~' OIL & GAS CO}ISERVATION COM .,ION Safety Valve Test Report Date co./' oc. PRESSURES - 'PSIG ? ~ e r a t o r ~ d~ R e pr e s e n t a t iv e ~//~. ~-~-~S ~ ~/ Well" Pilot F~G SI glxlN SSV SSSV Plt~oc No. ' High ~w TBG TBG CSG IP FP Test IP FP Test .... . ,, ~ - . ~ . , . . , .... ,. ,. . ,. , , ......... . , ......... _ ., , .... , , ., , , , , ..... , ............. ,, . ,, , .... , , , . ..... .. . , , . ,, ........ , . , ....... / , . ..... , , . . , ~. =. , , ...... = , ., , ....... Romarks: .~ . ' ' . , ,Inspect°rs ARCO Alaska, Inc...~ Post Offic~ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 Date: 1/17/85 Transmittal No: 4981 RETURN TO: ARCO ALASKA, INC. ATTN: Records Clerk ATO-1115B P.0..~"100360 ~orage, AK 99510 · . ~ /T~nsmitted herewith are the following items. Please acknowledge receipt "and return one signed copy of this transmittal. OTIS PBU SURVEYS 2w-s-< 1/o8/85 lB-7'~ 12/14184 2F-12· 1/06/85 2F-5 ..... 1/02/85 2W-5/'7. 1/07/85 W-6 .... 1/07/8 5. , w-7 ....1/07/85 illA-l~' 12/31/84 A-1 ~ 12/23/84 G-5.~- 12/25/84 2F-3 ~' '12/31/84 2V-8A -' 12/16/84 2B-10' 12/17/84 1Y-9 12/20/84 /10/84 2F-2 '" 12/29·/84 2F-15'~ 1/05/85 2F-14- 1/04/85 2F-9~ 1/02/85 2F-8- 1/01/85 CAMCO PBU SURVEYS API 02 9-21228 '029-2D616 029-21097 029-21073 -- 029-21220· -- 02 9-05900 029-20908 029-21178. 029-21084 029-21 O63 029-21048 02 9-21048 02 9-2 ~. 090 029-21077 1E-12 ~ 12/14, 16/84 /cat Receipt Acknowledged: DISTRIBUTION Date:~aska 0it & ~38 Co.~ c~[.missJo~ Anchorage B. Currier Drilling W. Pasher State of AK BPAE Chevron Geology Mobil G. Phillips Phill'ips Oil Sohio Union D&M NSK Ops. J. Ratkmell Well Files ARCO Aletka. inc. i$ · subsidiary o! AtlentlcRichfieldComl~an¥ ARCO Alaska, Inc. , ...;-':c.r.~ ~7 277 3~37 Return To: ARCD ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 Date: 10/08/84 Transmittal No: PAGE 1 of 2 4759 ansmitted herewith are the following items. and return one signed copy of this transmittal. Please acknowledge receipt · ?O~o ".S~v~s/P~SS~ ~¥szs <1A-2 5/11,12/84 Torque Turn (l~ess~re & T~ S~eys) ~- ........................ ~~ , 7/06/84 C~co ('-~xx.,~,'. ~:~. ,2'I /1B,11~::~ 7/10,12/84 C~o ..................... ),lA-10 5/10/84 /lC-1 12/17/83 zlC-6 8/04/84 /!O.lO- ' 12/2!/83 ll.QI_~ll 12/23/83 8/11/84 5/21/84 ~ 5/13,14/84 / ~G~3~ 6/26/84 ~IG-~? 6/30/84 .~ ~.~ ~/28/84 4i~& 5/~a/s3 ~-~ 12/27/83 ~ ZY-5 12/1~/83 ~ 1Y-7 12/15/83 / ~)1 7/03/84 ~*~)1 ~/lO/g~ Otis Otis Static Otis Camco Camco Otis Camco ~rqueTurn(Pressure & TempSurveys) Camco Static CMinco Cmnco Camco Camco' Otis Otis Otis Otis Otis Camco HP Static Receip 7~ac~nowledged: B. Adams · F.G. Baker P. Baxter BPAE Chevron Date: DISTRIBUTION D&M Drilling Geology Mobil NSK Operations W.V. Pasher G. Phillips Phillips Oil J.J. Rathmell R & D C. R. Smith Sohio Union Well Files Date: 10/08/84 Transmittal No: 4759 PAGE 2 of 2 Return To: · . ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 smitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. 2C~Jl~' 5/28/84 - 11/09/83' " 2C-2 11/09/83 2C-6 11/08/83 2C-7 11/08/83 ~,~'-~ 4/18/83 Q'P__-.~> 4/24/83 ~2~-Zl) 4~22/83 '~> 4/30/83 · ~ 4/28/84 · > 4/29/84 _ -_53.) 5/04/84 5/06/84' 2X-5 8/12/84 5108184 3C-6 Y/19/84 3C-6 5/17/84 .. · -Otis Lynes - 'Lynes Lynes Lynes Camco Camco Camco Otis C~o Camco Dresser PBU Flow Survey (Gradient). Otis Static Gradient Otis Camco DrESser Dresser Mini Drawdown & Buildup Survey .' i /cat Receipt Acknowledged: B. Adams · F.G. Baker P. Baxter BPJ£ Chevron Date: DISTRIBUTION D & M Drilling Geology Mobil NSK Operations W.V. Pasher G. Phillips Phillips Oil J.J. Rathmell R&D C. R. Smith Sohio Union Well Miles ARCO Alaska Ir~ · ~'. L~;C~ ~ex 36[, Anchorage. Alaska gS510 Te~,.~pt'-,one 907 277 5637 Date: 9~11/84 Transmittal No: 4719 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 nsmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. PBU SURVEYS/PRESSURE ANALYSIS 2B-7 ",;"'/ 8/17/84 ~'~ 2B-9 8/17/84 ~t/,".~ ../~: ~'1 C- 9GI ~/'7 / 07 / 84' _ 1B-5 '"" 12/.3..5/84 Lynes Lynes Camco Ca~co Otis SEQUENCE OF EVENTS 8/18,19/84 <'__P__B.U. ' 8/17-19/84 (.__._._-" ] 8/17-19/84 (/~_'f .... ~ 7/08/84 Falloff Test 7/12/84 " " 12/16/84 Static BHP 1C-4~' 12/17/84 Otis Otis 12/17/84 " " 12/29/84 " " 1D-7"'"--'12/19/84 Otis 12/19/84 " " 1D-4"" 12/18/84 Otis 12/18/84 " " /cat Receipt Acknowledged: B. Adams F.G. Baker P. Baxter BPAE Chevron D & M Dzilling Geology Mobil DISTRIBUTION W.V. Pasher Date: ~'"" " '~ ~' '~' :.~ Alaska Oil & ~as Cons. Co[nmiss[o~ Anchorage C. R. Smith G. Phillips Phillips Oil J.J. Rathmell Sohio Union NSK Operations R&D Well Files ARCO Alaska, Inc. 0 '; ( - ~. ,;ct',,. 9:,- 277 5~37 Date: 8/16/84 Transmittal No: 4686 Return To: ARCO ALASKA, Inc. ATTN: Records Clerk ATO-1115B P.O. Box 100360 Anchorage, AK 99510 /~ansmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. PBU SURVEYS/Pressure Analysis lC-1 Static BHP 4/12/84 Camco lC-5 " " 4/13/84 " 1C-6 Gas Disp. 5/16/84 Otis lC-7 PBU ~ 4/20a21 Camco 1C-9C~Falloff Test 4/29/84 " lC-iOC_~%" " 5/06/84 " 1D-1 Static BHP 4/19/84 " 1D-$ Falloff Test 4/29/84 Otis 1E-12 Flow BHP/GLV 7/01/8484 Camco 1E-17 Static BHP 1/8-11/84 Otis 1E-18 " " 1/03/84 " 1E-24 Injectivity 6/21-22/84 " 2F-8 T Log PBU 5/06/84 Otis 2F-11 Initial PBU 5/22/84 Camco 2F-12 Initial Well 5/15/84 '" 2F-13 " " 5/14/84 Otis 2F-14 PBU 5/03/84 " 2F-15 PBU State 4/26/84 /cat Receipt Acknowledged: B. Adams Camco DISTRIBUTION F.G. Baker P. Baxter BPAE Dzilling Geology Mobil G. Phillips Phillips Oil J.J. Rathmell State of Alaska Sohio Union Chevron NSK Operations R&D Well Files AClantic Ritchfield Company Arco Alaska, Inc. TRAN S}~I TTAL To: Date: Wm.. Van Al'en/Sate of AK · . 31 AUgust, 1983 from: EXTENSION/EXPLORATION' · . Transmitted herewith ara the following: Mud logs f'rom the following wells' · 1A-8-~West 'Sak 12) lB-5 ~(West Sak 7) 1C-4 _,~ lC-5 lC-6 / 1D-4-' 1m-8~West Sak 8) 1F_5~'. 1G-4 ~ 1H_3~ 1H-6 j 1Y-14 ~ 2C-6 ~' 2C-7~' .. , ~ -. 2X-2" 2 Z-'4- f 8-11-81 7-22-78 "11-27-77 1-1-81 2-9-81 3-1.-81 12-31-79 4-7'78 8-20-82 10-12-82 7-24-82 5-1'9-82 2-4'83 7-8-83 6-29-83 7-2-83 6-10-83 Also-~included is an expanded core~ log from well 2X-2,--7-2-83. A blueline copy and a Sepia is provided for each well.. . R./. eipt Acknowledge: R'~turn receipt to: Date: Arco Alaska, Ina. Attn: IM~XMNgsIaY~ E. McAlister P.O. Box 100360 Anchorage, AK 99510 .. · · . Prepared by: B.Byrne TO: William VanAlen FROM: D.W. Bose/Lorie L. Johnson · ~..,..... q/~l~ ~,,,~: Transmitted herewith are the follc~ing: PLWASE NOTE: BL-B~, S- SEPIA, F- FILM, T TAPE, DATE: ~ ALASKA, INC. ATI~: LORIE L. JOHNSON - AFA/311 P. 0...BOX-360 ANCHd~, AK. 995~0 FROM' J.J. Pawelek/Ann Simonsen Transmitted herewith are tile follo'...,'ing' S - SEPT,-,, F - FILM, T - TAPE ............:: ':TI'O:i I.',ECEi?T TO'ARCO ALAS"'.,;>~ I~'~:,~. P.O. BOX 360 DATE' Gas Cons. · ~ q"~ Al]c.tor~U,, · AFA/311 ' STATE OF ALASKA ALASK ,L AND GAS CONSERVATION C ,..iMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL rX] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Thc. 81-25 3. Address 8. APl Number P.O.Box 360, Anchorage, AK 99510 50- 029-20564 4. Location of well at surface 13Bl'FNL, 867'FWL, Sec 12, TllN, RIOE, UM 9. Unit or Lease Name Kuparuk 25649 At mop Producing lnterval 1336'FNL, 1276'FEL, Sec 1, T11N, R10E, UM lO. WellNumber 1C-6 At Total Depth 1022'FNL, 776'FEL, See 1, T11N, R10E, UM 11. Field and Pool Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 94' RKB ADL 25649 Kuparuk River 0il Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 3/1/81 3/17/81 3/31/81I -- feetMSLI 1 -17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 10243' 7102' 10120' 7014' YES [~ NO []I 2034 feetMD 1650' (approx.) , , 22. Type Electric or Other Logs Run DIL/SP/GR/GHCS, FDC/CNL/NGT, CBL/VDL/CCL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD . CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING'RECORD AMOUNT PULLED . '16" 65# H-40 Surf 110' 36" 425 sx Permafrost 10 3/4" 45.5# K-55 Surf 3827' 13 3/4 3400 sx AS II 7" 26# K-55 Surf 10266' 8 3/4', 535 sx Class G '16" inslll:at'ed ;b. 0~!Lductor 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) · 9410'-9485' w/12 SPF 3 1/2" 9289 9255" . 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. '.' , DEPTH INTERVAL (MD) AMOUNT& KIND OF MAT.ERIAL USED 9410'-9485' 64 bbl 12% HCI , . , · 27. ' PRODUCTION TEsT r Date Fi[st Production ' ' i Method of Operation (Flowing, gas lift, etc.) I 12/27/81 Flowing . . Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE '=J47 LRATIO 12/1/81 10~5 TESTPER OD * .13'14 .456-- ~4/~4 GAs'oI Flow Tu~aing Casin~t Pressure.. CALCU.~.A,:TED i~1~i OIL-BBL GAS-MCF WATER'-BBL OIL GRAVITY-APl (corr) ' Press53'0 . ?24-HOUR RATE '=F' !' ~050 , .,i '1058 -- 22.2 28. CORE DATA . Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ' · : . N/^ " " ' RECEIVED · · i' MAR i 5 1982 ':. .~'~ · .. :' .- ".... $1~ 0il & Oas Cons, C0mai~ : · :,. A~chorag,.. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. . 30. GEOLOGIC MARKERS 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 R~ver Form. 9413' " 6517' Base Kuparuk River Form. 9950' 6892' I ,, 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~_ , Title Area 0ps. Enqr. 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 Hu:~,:n .~LOPE E~]GI~.IEERI:~G J. J. Pawelek/Ann Simonsen DATE' ,..~"' -,-~ F,, - o¢~.., WELL NAME: Transmitted herewith are the followine' -,.. p, ¢,~,- L~.~.~- HOTE' BL - BLUEL!HE, S - SEPIA, F - FILM, T - TAPE REEEiVED RECEIPT ._~L~'?,SE RETURN t~ECE;?T TO' DATE: Alaska Oil & Gas Cons. Comm.~ssiou ADchorage ARCO ALAS}CA, I~4C. ATT~!: AH~ SIMO;~SE~I - AFA/311 P.O. BOX 360 2"~"~'~'" ~" 9a-~lO NORTH ~LOPE E~I. GIt.~EER!i:G TRAilSHITTAL # ..///'/5' J. J. Pawelek/Ann Simonsen DATE' ,' / /Z-'~S 2.._ WELL '~" " h,~,.,E' · Trans..mitred here:.:ith are the following' PLEASE HOTE' BL - BLUEL!HE, S - SEPIA, F - FILM, T - TAPE ~.,S'E RETURN P, ECE;?T TO' Alas~<a Oil a Gas Cons. Conimissior~ A" , . ~chorage ARCO AL S~.& ATTrI' AN;i SIM0;IS~'~.~, - AFA/311 P.O. BOX 36O A:]CJ{ORAGE, AK 99510 , NORTti SLOPE Ei:GI~:EERIi:G ~ · DATE- ./~-~0-~'/' WELL - . · i , · Transmitted herewith are the:followi~g' .,.. PLEASE HOTE' BL - BLUEL!ilE, S - SEPIA, F - FILM, T - TAPE EEC:TpT~. ACK;:OWLE;'~,;~LD: (~Y .,_: ,~.,J,.,, I~ECE~FT TO': RECEIVED ' ~/¢'~-~-- BAT E' Al~s~ Oil & Gas Cons. Commlsslo~ ~chorage ARCO ALAS~tA, I~C. ATTr~: Ar;~; SI;.~0;iSE~I - AFA/311 P.O. BOX 360 A;;CH02AO2, AK 9~510 ARCO Alaska, Inc. Post Office By"" 3 Anchorage, AI~._ .a 99.510 Telephone 907 277 5637 December 17, 1981 Mr. Hoyle H. Hamilton State of Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Alaska 99504 Dear Mr. Hamilton: Attached please find subsequent reports for Kuparuk Wells: 1E-lA, 1E-3, 1E-4, 1E-5, 1E-6, 1C-6, and lB-1 Sincerely, J. S. Dayton Area Operations EAS/bl At t achment Engineer .ECEIVED Alaska 0il & Gas Cons. Anchorage STATE OF ALASKA ALASK ~L AND GAS CONSERVATION .... wMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I-IX OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska, Inc. 81-25 3. Address 8. APl Number P.O.Box 360, Anchorage, AK 99510 5o- 029-20564 4. Location of Well Surface Location' 1381' FNL, 867' FWL, Sec. 12, T11N, RIOE. 5. Elevation in feet (indicate KB, DF, etc.) KB=94' 6. Lease Designation and Serial No. ADL 25649 9. Unit or Lease Name Kuparuk 25649 10. Well Number lC-6 11. Field and Pool Kuparuk River Kuparuk River Field Oi 1 Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation ]~] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170), ~.--~ ....... F,,v~uu,~ --/~.~/u-. nv v,u ~,,u pum,,pmf,y pment. Tested to 4000 psi. RIH to 9500' MD circulating diesel. Squeezed 12% HC1 acid with additives into perforations 9410'-9485' MD. Maximum TP : 950 psi. Total acid pumped : 64 bbls. Circulated nitrogen and diesel alternately to cleanup. POH w/ CT pumping diesel. Flowed well for 1..5 hours to cleanup. Shut in well in preparation for testing. Began well test HP at 6398' SS. GOR : 340, FTP : SI well for PBU. 11/30/81. RIH w/ production logging equipm.eto~t~ and set Flowed well for 10.6 hours at a rate of~3050 3~OPD. 530 psi, FFBHP = 2724. Ran production 10gs-, FSIBHP = 3245 psi. Secured well 12/1/81. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~,~~~~ Area Operations Engineer '~il~ ;~ac r ~~ ~ use Title . . , mmissi_~ Conditions of Approval, if any.V ~ ~' C ~ i '~' ~' [~ Date Approved by Form 10-403 Rev. 7-1-80 Date Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate NORTH SLOPE ENGINEFRING Date: Transmitted herewith are the following: Please note: BL - Blueline, S - Sepia, F - Film, T - Tape E RE%lfRN RECEIPT TO: ARCO Alaska, Inc. Attn. Leo Lash / AFA-311 P. O. Box 360 Anchorage, AK 99510 RECEIVED. n~,~: MAY ? 9 1981 Alaska Oil & Gas Cons. Commission Anchorage NORTH SLOPE ENGINEFRING Transmitted herewith are the following: Please note: BL - Blueline, S - Sepia, F - Film, T - Tape PLEASE~~I~ ~: ARCO Alaska, Inc. Attn. Leo Lash / AFA-311 P. O. Box 360 Anchorage, AK 99510 RECEIYEO Gas Cons. Commission Anchorage ALASK iL AND GAS CONSERVATION C vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] . 2. Name of Operator ARCO Alaska Inc. 3. Address Box 360 Anchorage, 4. Location of Well Surface Location: 5. Elevation in feet (indicate KB, DF, etc.) KB elevation = 94' 12. Alaska 99510 1381' FNL, 867'FWL, Sec. 12, TllN, RloE I ADL 25648 6. Lease Designation and Serial No. 7. Permit No. 81-25 8. APl Number 50-029-20564 9. Unit or Lease Name .. Kuparuk 25648 10. Well Number C-6 11. Field and Pool ?rudhoe Bay Field ~uparuk River Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] , Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of Starting any proposed work, for Abandonment see 20 AAC 25.105-170). Originally planned to perforate well in lower zone (9880-9900 MD) to obtain water sample. However, did not perforate because hole angle too steep to set plug between upper and lower zones. Pro- duction flowing and shut in tests were run, starting on 4-29-81. Lubricator was tested before going in hole. .After production tests, downhole ball valve and master valve were closed. RECEIVED, o~ ~.~.-. ..... MAY 1 3 ]981 Anohorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. S igne~~'~--~~',. C~?~./j~ Title/~~~.~L The space below for Commission ~j/e ~1 Conditions of Approval, if any: Date Approved by. Form 10-403 By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate Rev. 7-1-80 and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASK L AND GAS CONSERVATION O ~IMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. ARCO Alaska Inc. 81-25 3. Address 8. APl Number Box 360 Anchorage, Alaska 99510 50- 029-20564 4. Location of Well Surface Location: 5. Elevation in feet (indicate KB, DF, etc.) KB elevation = 94' 12. 1381'FNL, 867' FWL, Sec. 12, TllN, R10E I 6. Lease Designation and Serial No. 9. Unit or Lease Name Kuparuk 25649 10. Well Number C-6 11. Field and Pool Prudhoe Bay Field KuDaruk River Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Atlantic Richfield Company proposes to perforate and flow test selected intervals within the upper and lower Kuparuk Sands. All wireline work will be done through a 3000 psi lubricator, which will be pressure tested after being installed on the well head. All perforated intervals, test volumes, and production log runs will be reported on a subsequent report. Expected Start Date 5-1-81 Verbal permission received from R~ssDouglass on 4-30-81 bv phone. Subsequent Work Ee~crted on Form No. -- Dated--/--/--- RECEIVED MAY - 1 1981 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use %J Conditions of Approval, if any: Approved by Naska 0il & Gas Cons. Commission Anchorage Returned By Order of COMMISSIONER the Commission Date '''~- /-~ j Submit "Intentions" in Triplicate Form 10-403 Rev. 7-1-80 and "Subsequent Reports" in Duplicate ARCO Alaska, In~''''~ Post OfficL~ ~ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 April 30, 1981 Mr. Hoyl e Hamil ton State of Alaska Alaska Oil and Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS 14-9A- DS 16-3 DS 1 6-4 DS 1 6-8 DS 16-9 DS 16-12 C-4 C-5 C-6 15-22 Confidential Dear Sir' Enclosed please find' · · The Completion Reports & Gyroscopic Surveys for DS 15-22 (T-l), DS 16-3, DS 16-8, DS 16-9, DS 16-12, C-4, C-5, C-6. Please note that DS 15-22 (T-l) is CONFIDENTIAL. The Completion Report and Multishot Survey for DS 14-9A'i · The Completion Report for DS 16-4. An updated Completion Report and Gyroscopic Survey will be submitted as soon as data becomes available. Sincerely, P. ^. VanDusen District Drilling Engineer PAV/KJG'sp Attachments RECEIVED MAY - 1 1981 Alaska Oil & Gas Cons. Commission Anchorage ARCO Al,1ska. Inc is ,t Subs*diary of Atl,1nticRichfieldCompany ' ' A( STATE OF ALASKA I~ " ALASK ,:iL AND GAS CONSERVATION C . ,IMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL ~ GAS [] SUSPENDED [] ABANDONED [] . ..SERVICE ~ 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 81-25 3. Address 8. APl Number P.O. Box 360 Anchorage, AK 99510 50- 029-20564 4. Location of well at surface 9. Unit or Lease Name 1381'FNL, 867'FWL, Sec 12, T11N, R10E, UM Kuparuk 25649 At Top Producing Interval 10. Well Number 1336'FNL, 1276'FEL, Sec 1, T11N~__R10E, UM C-6 At Total Depth :("~ 11. Field and Pool 1022'FNL, 776'FEL, Sec 1, T11N, R10E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) ].-6~ Lease Designation and Serial No. Kuparuk River 0i 1 Pool 94' RKBI ADL 25649 12. Date Spudded3/1/81 13. Date T.D. Reached 3/17/81 14' Date C°mp" Susp' °r Aband' I 15' Water Depth' if °ffsh°re 116' N°' °f C°mpleti°ns 3/31/81~ -- feet MSL' 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19, Directional Survey :'"i' I ..... 20. Depth where SSSV set 21. Th~'ckness of Permafrost 10243'TD 7102'TVD 10120'MD 7014'TVI)YEsEXX NO[]! 2034 feetMDI 1650' (approx) 22. Type Electric or Other Logs Run DIL/SP/GR/BHCS, FDC/CNL/NGT, CBL/VDL/CCL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED '16" 65# H-40 Surf 110' 36" 425 sx Permafrost 10-3/4' 45.5# K-55 Surf 3827' 13-3/4" 3400 sx AS II _ 7" 26# K-55 Surf 10266' 8-3/4" 535 sx Class G '16" insulated c(~nductor. 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) 3-1/2" 9289' 9255' 9410'-9485 w/12 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. .DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A · · . .. 27. PRODUCTION TEST Date Firs.t P~od, uction t Method of Operation (Flowing, gas lift, etc.) N/AI ....... Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESlZE IGAS-OILRATIO , TEST PERIOD I~ , I Flow. Tubing Casing Pressure CALCULATED I~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press.. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A : , RECEIVED Alaska 0il & Gas Cons, Commission Anchorage · Form 10-407 Rev. 7-1-80 Submit in duplicate CONTINUED ON REVERSE SIDE 29. GEOLOGIC MARKERS NAME Top Kuparuk Top Upper Sand Base Upper Sand Top Lower Sand Base Lower Sand Base Kuparuk MEAS. DEPTH 9410' 9410' 9634' 9840' 9950' 9950' TRUE VERT. DEPTH 6514' 6514' 6668' 6813' 6892' 6892' 30: FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. : N/A 31. LIST OF ATTACHMENTS Drilling History, GyroscoPic Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge 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 rrreasurements given in other spaces on this form and in any attachments. Item 16 and 24' ,~[f this well is completed for separate production from more than one interVal (multiple completion), so state in item 16, and in item24 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 KUPARUK C-6 DRILLING HISTORY Spudded well @ 1030 hrs, 3'~Z~/81. NU diverter system & 20" hydrill. Drld 13-3/4" hole to 3300'. Ran multishot. Ran 79 its 10-3/4", 45.5#, K-55 csg w/shoe @ 3287'. Cmtd csg w/3400 sx AS II lcmt ND 20" Hydrill and diverter system. Set 10-3/4" pkoff & tstd to 2000 ps' ~k. NU BOPE & tstd to 5000 psi - ok. Tstd csg to 1500 psi - ok. Drld FC, cmt, FS & 10' new formation. Tstd form to 12.5 ppg EMW - ok. Chngd over to oil-base mud. Drld 8~3/4" hole to 10,228'. Circ & cond hole for logs. Rai¥ DIL/SP/GR/BHCS, F~C/CNL/NGT, & C~B~L/,~DL/CCL/GR. Drld from 10,228' to 10,243-- TD. Ran 221 its 7~,_," 26#~ K-55, BT C ~"S-~j-'"'~-o~e @ 10,226'. C~m..t. d c____s~/5__3~ s x C 1 as s "~-~hi-i~'T ....... 6]'~'~ 1''' ~'U~"'~'~7'N-~'C 1 / NaBr. Set 7" pkoff & tstd to 3000 psi - ok Cleaned out cmt to 10,127' PBTD. Ran FDC/CNL/GR, Gyro, CBL/V~G~BJ_~CL. Arctic packed 10-3/4" x 7" annulus w/350 bbls H~O, 250 sx AS II cmt & 108 bbl Arctic Pack. Ran 3-1/2" completion assembTy. Tstd tbg to 3000 psi - ok. ND BOPE. NU tree & tstd to 3000 psi - ok. RIH w/perf gun & perfd f/9410'-9485' @ 12 spf. Bullhead 50 bbl diesel dwn tbg to 5750' - had communication. Closed SSSV. Ran CCL. Ran spi'nner/CCL & ,Y-~Q~,,]~e~k.,.,,,,~.~,~2~5~5'. Displ well w/NaCl/NaBr ND tree NU BOPE & tstd to 3000 psi L~ ok. POOH w/3-1/2" tbg assy. Changed outer b~l of SBR. RIH w/DP & fishing tools. Latched fish @ 9335' & POOH. RIH w/csg scraper. POOH. Reran 3-1/2" compl assy w/tail @ 9289' & pkr @ 9255'. Tstd tbg hngr to 3000 psi - ok. Displ well to diesel. Tstd tbg to 2000 psi & ann to 250 psi - ok. Tstd tbg to 900 psi & ann to 2000 psi - ok. NU tree & tstd to 5000 psi - ok. Secured well & released rig @ 2400 hrs 3/31/81. MAy -. 1981 Alaska Oil a 8as Cons. Com~i$$ioo Anehor~ge 1111 East 80th Anchorage, Alaska 99502 Phone 349-3541 Telex: 25-364 World Leader in Service to the Oil Industry our Gyro Survey on I{u:oaruk C-6 /ePulca! Section and Horizontal View NlaDs, -- ~,~1oo enctos~,-~ you v~i!l '~" ~ th~ ....... · ina '?ie~ d Sheet ~ ,gyro Film, . _ and Calculations. If any other information is nee'ded please cai]_ Thank you for using Scientific Drilling International o~no. please call again. Sincerely i'.'ls.n a. ser g'£C£1v£o ~ Oil &AnCbOr~ge~a~ Oons. Oor~mi~eion COMPLETION REPORT ARCO ALASKA INC GYROSCOPIC SURVEY RADIUS OF CURVATURE METHOD OF COMPUTATION COMPUTED FOR SDC BY FM LINDSEY & ASSOC 3 APR 81 KUPARUK C-6 KB ELEV 94, FT. ,JOB NO 4411 RECORD OF SURVEY TRUE MEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG, 0 0 0 0.00 100 0 0 100.00 200 0 O' 200.00 300 0 0 3OO.OO 400 0 0 400.00 500 0 0 500,00 600 5 0 599,87 700 10 0 698.98 800 14 30 796.68 900 17 30 892.79 1000 21 0 987.19 1100 25 0 1079.22 -94,00 N O,OOE 6,00 N15,15E 106,00 N14,35E 206,00 N13,55E 306,00 N12,73E 406,00 Nll,93E 505,87 N30,56E 604.98 N34.48E 702,68 N19,20E 798,79 N15,85E 893,19 N17,71E 985,22 N20,28E 1200 28 0 1168,70 1074,70 N21,83E . 1300 30 0 1256,16 1162,16 N22.08E · 1400 31 30 1342,10 1248.10 N21.91E 1500 31 30 1427,36 1333,36 N24.21E 1600 32 0 1512,40 1418,40 N24,65E 1700 33 30 1596,50 1502.50 N26,16E · 1800 35 30 1678,91 1584,91 N27,10E 1900. 36 0 1760,07 1666,07 N26,15E 2000 37 0 1840.45 1746.45 N25.01E 2100 40 0 1918,70 1824,70 N24,10E 2200 43 0 1993.59 1899.59 N23.50E :. 2~00 45 0 2065,52 1971,52 N22,30E 2~00 47 30 2134,67 2040,67 N22,13E TOTAL COORDINATES 0.00 S 0,00 W 0.00 S 0,00 W 0'00 S 0,00 W 0,00 S 0.00 W 0.00 S 0,00 W 0,00 & 0,00 W 4,04N 1,57 E 15,04 N ".-- 8,58 E 33,91.. N'']'~ 18,13 E 60,19 N 26,43 E 91,75 N 35,95 E 128,68 N 48.67 E 170,32 N 64,70 E 215,28 N 82.82 E 262.68 N 101,98 E 310,75 N 122.45 E 358,66 N 144,21 E 407.52 N 167.42 E 458,15 N 192,81 E 510.38 N 218,99 E 564,03 N 244.6'8 E 620,64 N 270,55 E 681.26 N 297,29 E 745,25 N 324e31 E 812,11 N 351,63 E CLOSURES DISTANCE ANGLE D M S 0,00 S 0 0 0 W 0.00 $ 0 0 0 W 0.00 S 0 0 0 W 0.00 S 0 0 0 W 0.00 S 0 0 0 W 0,00 S 0 0 0 W 4.34 N 21 14 59 E 17e32 N 29 42 59 E 38,46 N 28 8 10 E 65,74 N 23 42 33 E 98.54 N 21 23 51 E 137-58 N 20 43 1 E 182,19 N 20 48 2 E 230.66 N 21 2 38 E 281,78 N 21 13 2 E 334,01 N 21 30 23 E 386,57 N 21 54 17 E 440,57 N 22 20 5 E 497,07.~...N 22 49 26 E 555,38 'N 23 13 25 E 614,81 N 23 27 6 E 677,05 N 23 33 12 E 743.30 N 23 34 31 E 812-76 N 23 31 4 E 884.97 N 23 24 41 E DOG LEG SEVERITY DEG/iOOFT 0,000 0,000 0,000 0,000 0,000 0,000 5,002 5,001 4.601 3,015 3,508 4,026 3,019 2,001 1,50'1 1,202 0,515 1.570 2.025 0.598 i,081 3.024 3,013 2.088 2,502 SECT OISTANC~ 0,00 0.00 0.00 0,00 0,00 0,00 4,25 i7,29 38.33 64,91 96.59 134,52 178.2~ 225,8 276.03 327,52 979.58 433,22 489,53 547.61 606,62 668.22 733.65 802.07 873.07 ARCO KUPARUK C-6 GYROSCOPIC SURVEY dOB NO 4411 3 APR 81 RECORD OF SURVEY MEAS, DRIFT DEPTH ANGLE D M 25O0 5O 0 26O0 53 0 2700 53 0 280O 52 0 2900 51 30 3000 51 3O 3100 51 30 3200 52 30 3300 52 0 3400 52 30 3500 53 0 3600 53 0 37O0 53 0 3800 53 0 3900 53 0 400O 54 0 4100 55 0 420O 58 0 4300 58 0 4400 58 0 450O 58 0 46OO 58 0 47OO 57 30 4800 58 0 4900 57 30 5OOO 58 0 5100 58 0 5200 57 0 5300 56 0 TRUE VERTICAL DEPTH SUB DRIFT SEA DIREC DEG, 2200.59 2106,59 N21,40E 2262,84 2168,84 N21,56E 2323.02 2229.02 N21,20E 2383,90 2289.90 N21,86E 2445,80 2351,80 N22,73E 2508.06 2414,06 N21,93E 2570,31 2476,31 N22,06E 2631.87 2537,87 N21,13E 2693.09 2599.09 N21,56E 2754,32 2660,32 N20,45E 2814.85 2720.85 N19,31E 2875.03 2781.03 N19,55E 2935.21 2841,21 N19.80E 2995,39. 2901,39 N21,!8E 3055.57 2961.57 N21.50E 3115.05 3021,05 N21,16E 3173.12 3079.12 N22.00E 3228.31 3134.31 N22.68E 3281.30 3187.30 N23,20E 3334.29 3240,29 N23.05E 3387,29 3293.29 N22,91E 3440,28 3346,28 N24,20E 3493,64 3399,64 N22.36E 3547.00 3453,00 N22.90E 3600.36 3506,36 N23.18E 3653,72 3559,72 N24,35E 3706,71 3612.71 N25.13E 3760,44 3666,44 ~425,73E 3815.64 3721,64 N25.SBE TOTAL COORDINATES 881.93 N 379.50 954,75 N 408.16 1029.11 N 437.28 1102.91N 466.40 1175.57 N 496.20 1247.96 N 525,94 1320,52 N 555.25 1393.78 N 584,26 1467.43 N 613.05 1541.24 .N 641,39 1616,09 N 668.47 1691,41 N 695.04 1766.61N 721'93 1841,41N 749~88 19t5,80 N 778.95 1990.68 N 808.19 2066.38 N 838.14 2143,50 N 869.83 2221.60 N 902.89 2299.59 N 936,20 2377.66 N 969,31 2455.39 N 1003.20 2533.08 N .1036,63 2611.14 N 1069.18 2688.96 N 1102.28 2766.36 N 1136,36 2843.38 N 1171.85 2919,54 N 1208,0'7 2994-72 N 1244,15 E E E E E E E E E E E E E E E E E E E E E E E E E E E E E CLOSURES DISTANCE ANGLE O M 960,12 N 2'3 16 58 E 1038.34 N 23 8 50 E 1118,16 N 23 1 15 E 1197.47 N 22 55 21 E 1276.00 N 22 53 3 E' 1354,26 N 22 51 9 E 1432.51 N 22 48 21 E 1511.29 N 22 44 35 E 1590,34 N 22 40 25 F 1669,37 N 22 35 41 E 1748.89 N 22 28 17 5 1828.64 N" 22 20 20 E 1908,42 N 22 13 39 E 1988.25 N 22 9 28 E 2068.11 N 22 7 34 ~ 2148,48 N 22 5 47 E 2229,89".N 22 4 40 E 2313.27 N 22 5 lz+ E 2398.0(:> N 22 7 3 E 2482.86 N 22 9 7 E 2567,65 N 22 10 46 E 2652.43 N 22 I3 24 E 2736,99 N 22 15 22 rY. 2821,56 N 22 16 3 E 2906.12 N 22 17 24 E 2990,66 N 22 19 54 E 3075,40 N 22 23 53 E 3159.62 N 22 28 45 E 3242.88 N 22 33 37 E DOG LEG SEVER I TY DEG/iOOFT 2,537 3,002 0,293 1,082 0,729 0,626 0,104 1,160 0,568 0,863 0.879 0,186 0,200 1,105 0,253 1.024 1.146 3,040 0,438 0,127 0,113 1.088 1.~97 0.630 0,539 0.977 0.664 1,085 1.009 SECTION DISTANCE 946.85 1023.5'~ llO1.Sb 1179.66 1256.87 1333.82 1410.69 1487.99 1565.48 1542,d7 17Z0,45 1798,14 1875,92 1953e94 2032,20 2110.98 2190.83 2272.8~ 235b,3~ 2439.96 2523.52 2607,22 2690.62 2773,86 2857.20 2940.72 3024.68 3108.32 3191.05 ARCO KUPARUK C-6 GYROSCOPIC SURVEY JOB NO 4411 3 APR 81 RECORD OF SURVEY MEAS, DRIFT DEPTH ANGLE D M 5400 5500 5600 5700 5800 5900 6000 6100 6200 6300 6400 6500 6600 6700 6800 6900 7000 7100 7200 -7300 7400 7500 7600 7700 7800. 7900 8000 8100 8200 55 30 55 0 55 0 58 0 58 0 58 0 58 0 58 0 58 0 58 0 57 30 57 3O 57 30 57 30 57 30 56 0 55 0 53 3O 52 30 51 0 49 0 47 0 45 0 43 30 43 0 42 30 41 30 40 0 39 30 TRUE VERTICAL DEPTH 3871.92 3928.92 3986.27 4041.46 4094.45 4147.45 4200.44 4253.43 4306.42 4359.41 4412.77 4466.50 4520.23 4573.96 4627.69 4682.52 4739.16 4797.59 4857.77 4919.67 4983.95 5050.86 5120,32 5191.95 5264.79 5338.22 5412.53 5488.29 5565.17 SUB SEA 3777.92 3834.92 3892.27 3947.46 4000.a5 4053.45 4106.44 4159.43 4212.42 4265,41 4318.77 4372.50 4426.23 4479.96 4533.69 4588.52 4645.16 4703.59 4763,77 4825.67 4889,95 4956.86 5026.32 5097.95 5I?0.79 5244.22 5318.53 5394.29 5471.17 DRIFT DIREC DEG. N25,01E N24.48E N23.68E N29.50E N31.35E N33.25E N34.26E N32,55E N32.66E N32.40E N32.31E N33.Q3E N32.63E N32.43E N32.23E N34.10E N35.76E N36.53E N37.83E N38.45E N41.30E N42.45E N43.90E N44.21E N46.65E N44.36E N44.70E N44.95E N47.88E TOTAL COORDINATES 3069.47 N 1279.44 E 3144.09 N 1313.84 E 3218.87 N 1347.27 E 3293.40 N 1384.57 E 3366,52 N 1427.52 E 3438.20 N 1472.83 E 3508,70 N 1519.96 E 3579.49 N 1566,65 E 3650,93 N 1612,35 E 3722'43 N 1557,96 E 3793.87 N 1703.22 E 3864,86'N 1748,75 E 3935.73 N 1794.48 E 4006.83.N 1839,84 E 4078.09 N 1884.95 E 4148,09 N 1930.69 E 4215.65 N 1977.88 E 4281.18 N 2025,76 E 4344.81 N 2074.02 E 4406.57 N 2122.52 E 4465.35-N 2171.63 E 4520.68 N 2221.23 E 4573.14 N 2270,44 E 4623,28 N 2318.97 E 4671.36 N 2367.78 E 4718.93 N 2416.20 E 4766.62 N 2463.12 E 4812.92 N 2509.14 E 4857.00 N 2555.45 E CLOSURES DISTANCE ANGLE D M DOG LEG SEVER I TY DEG/iOOFT 3325.45 N 22 37 40 E. 3407,56 N 22 40 44 E 3489.45 N 22 42 42 E 3572.61 N 22 48 8 E 3656,68 N 22 58 42 E 3740.38 N 23 11 20 E 3823.78 N 23 25 19 E 3907.32 N 23 38 15 E 3991,11 N 23 49 39 E 4074.96 N 24 0 28 E 4158.66 N 24 10 38 E 4242.09 N 24 20 44 E 4325.52 N 24 30 37 E 4409e05 N 24 39 48 E 4492,65 .... N 24 48 k5 E 4575.40 N 24 57 33 F 4656.58 N 25 8 5 E 4736.27 N 25 19 20 E 4814e45 N 25 31 4 E 4891.11 N 25 43 7 E 4965.41 N 25 56 5 E 5036,91 N 26 10 1 E 5105.73 N 26 24 11 E 5172.27%N 26 38 15 E 5237.17 N 26 52 44 E 5301.54 N 27 6 48 E 5365.42 N 27 19 38 E 5427.71 N 27 32 4 E 5488.24 N 27 45 2 E SECTION D ! STANCE 0,611 3Z72.99 0,615 3354,3~ 0,655 3435,3i 5,146 3b18,16 1,569 3602.89 1.611 3687.69 0.862 3772.48 1.456 3~57,28 0.099 3942.08 0,226 4026,88 0.504 4111,45 0.604 4195.79 0.337 4280.13 0.169 4364,47 0e169 4448,80 1.974 4532,43 1,500 4514.78 1.580 4695-8~ 1.292 4'775.4, le546 4853.62 2.576 4929.63 2,092 5003.01 2,127 5073.77 1.507 5142,21 1.237 5209.06 1,156 5275.28 1,011 5340.80 1,288 5466.79 ARCO KUPARUK C-6 GYROSCOPIC SURVEY JOB NO 4411 ~ APR 81 RECORD OF SURVEY TRUE MEAS, DRIFT VERTICAL SUB DRIFT DEPTH ANGLE DEPTH SEA DIREC D M DEG. TOTAL COORDINATES 8300 39 0 5642.61 5548.61 8400 38 0 5720,87 5626.87 8500 37 30 5799.94 5705,94 8600 37 0 5879.54 5785,54 8700 36 0 5959.92 5865.92 8800 35 0 6041,33 5947,33 8900 34 0 6123,74 6029.74 9000 36 0 6205,66 6111,66 9100 38 0 6285.51 6191,51 9200 41 0 6362.67 6268,67 9300 43 30 6436,68 6342,68 9400 46 30 6507,39 6413,39 9500 47 0 6575.91 6481.91 9600 46 30 6644,42 6550.42 9700 45 30 6713.89 6619.89 9800 45 0 6784,29 6690,29 9900 44 0 6855.61 6761.61 10000 44 0 6927.55 6833,55 10100 44 0 6999.48 6905,48 N48,86E 4899.03 N 2602,75 E N47.86E 4940.38 N 2649.27 E N48,20E 4981e32 N 2694,79 E N49.15E 5021,29 N 2740.25 E N49,36E 5060.11N 2785,31E NSO,18E 5097,61N 2829.65 E NSO.98E 5133.57 N 2873.41 E N52.38E 5169'13 N 2918.41 E N53.85E 5205,25. N 2966,54 E N54,68E 5242,39 N 3018.17 E N54.65E 5281.28 N ~3073.01E N56.85E 5321,071N 3131.45 E N59.46E 5359.49 N 3193'32 E N57,75E 5397.43 N 3255,50 E N56.95E 5436.24 N 3316.06 E N58.46E 5474.18 N 3376,09 E N57.86E 5511.14 N 3435.64 E N57.65E 5548,20 N 3494.40 E N57,43E 5585,48 N 3553.01 E THE FOLLOWING INFORMATION IS EXTRA 10243 44 0 7102.35 7008,35 N57 POLATED TO TD · 43E 5638,96 N 3636,73 E DOG LEG C L 0 S U R E S SEVERITY DISTANCE ANGLE DEG/iOOFT O M S 5547.50 N 2'7 58 50 E 0,634 5605.89 N 28 12 8 E 1,069 5663,52 N 28 24 44 E 0.515 5720,34 N 28 37 20 E 0.607 5776,05 N 28 49 49 E 1,003 5830.32 N 29 2 3 E 1,035 5883,03 N 29 14 13 E 1,031 5936,08 N 29 26 ~4 E 2,058 5991.25 N 29 40 45 E 2,076 6049.14 N 29 55 48 E 3,021 6110,26 N 30 11 37 E 2,500 6174,12 ~ 30 28 36 E 3,216 6238,71 N 30 47 15 E 1,486 6303.21 N 31 5 47 E 1,032 6367.81 N 31 22 58 E 1.080 6431,53 N 31 39 48 E 0,908 6494.33'. N 31 56 21 ~ 1,041 6556,93 N 32 12 13 E 0,151 6619.78 N 32 27 39 E 0,151 6709,96 N 32 49 8 E 0,000 SECTION DISTANCE 5527,74 5646,7~ 5705.01 5762.06 5817,61 5871,55 592~.~2 598Z,26 6041,45 6103,86 6158.97 6234,79 8~65.81 6430.23 6493.57 6556,5~ 6619,6~ 6709.96 BOTTOM HOLE CLOSURE 6709,96 FEET AT N 32 49 8 E ARCO KUPARUK C-6 GYROSCOPIC SURVEY dOB NO 4411 3 APR 81 INTERPOLATED TRUE VERTICAL DEPTHS9 COORDINATES AND CLOSURES FO~ GIVEN DEPTHS TRUE CODE MEASURED VERTICAL NAME DEPTH DEPTH TOTAL COORDINATES C L 0 S U R E DISTANCE ANGLE D M S ,SUB SEA K-13 5087 3699.83 W,SAK SD-T 5332 3833.57 W.SAK SD-B 5510 3934,65 K-10 6809 4632.54 K=5 7950 5375,23 K-4 8384 5708.27 K-3 8444 5755.59 K-2 8837 6071.71 KGRS-B 9076 6266.54 K-1 9143 6319.10 KRS1-D 9344 6468,25 TK KRS1-C 9410 6514,27 TUS KRS1-C 9410 6514,27 KRS1-B 9452 6543,10 KRS1-A 9488 6567,72 BUS KRS2 9634 6667.90 TIDAL SHAL 9652 6680.39 TLS KRS3-D 9840 6812.67 KRS3-C 9847 6817,66 KRS3-B 9872 6835,52 KRS3-A 9904 6858,49 BLS KI SHA 9950 6891,58 BK KIN SHA 9950 6891.58 PLUG BACK 10120 7013,87 TD 10243 7102,35 2833,53 N 3018,75 N 3151,57 N 4084.52 N 4743,11 N 4934,36 N 4958,74 N 5111,19 N 5196,90 N 5221,33 N 1166.88 E 1255.35 E 1317.17 E 1888.97 E 2439.55 E 2641.41E 2669,11 E 2845,83 E 2954.43 E 2988.05 E 5299.10 N i 3097,95 E 5325,11 N 3137.48 E 5325,11 N 3137.48 E 5341,77 N 3163,07 E 5355.65 N 3185,37 E 5410.8.8 N 3276'08 E' 3064,40 N 22 22 56 E 3605,83 3269.36 N 22 34 48 E 3739,97 3415.75 N 22 40 55 E 3840.65 4500,17 N 24 49 9 E 4538.54 5333.71 N 27 13 6 E 5281.23 5596,88 N 28 9 38 E 5614.27 5631.45 N 28 17 31 E 5661.59 5850.05 N 29 6 30 E '5977.71 5978,00 N 29 37 5 E 0i72,54 6015,87 N 29 46 53 E 6225,10 6138.23 N 30 18 40 E 6374,25 6180.66 N 30 30 21 E 6420.27 6180.66 N 30 30 21 E 6420.27 6208,03 N 30 37 53 E 6449,10 6231.34 N 30 44 34 E 6473,72 6325,38 N 31 11 35 E 6573,90 5418.03 N 5489.19 N 5491,83 N 5501,25 N 5512,66 N 5530.06 N 5530,06 N 5593.05 N 5638,96 N 3286,90 E: ~ 6337.09 N 31 14 36 E 6586,39 3399.94 E 3404.09 E 3418.83 E 3437.97 E 3464.77 E 3464.77 E 3564,66 E 3636.73 E 6456.85 N-, 31 46 25 E 6718.67 ' 6461,27 N 31 47 33 E 6723.66 6477.05 N 31 51 34 E 6741,52 6496,85 N 31 56 59 E 6764,49 6525.81 N 32 4 6 E 6797,58, 6525.81 N 32 4 6 E 6797,58 6632.43 N 32 30 39 E 6919.87 6709,96 N 32 49 8 E 7008,35 ARCO KUPARUK C-6 GYROSCOPIC SURVEY gOB NO 4~11 ~ APR 81 MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 194 194, 100 0 0 0.00 294 294. 200 0 0 0.00 394 394. 300 0 0 0.00 494 494. 400 0 0 0,00 594 . 594, 500 0 0 3,61 695 694. 600 0 0 14.38 797 794. 700 3 3 33.28 901 894. 800 7 4 60.48 1007 994. 900 13 6 94.16 1116 1094. 1000 22 9 135.09 1229 1194, 1100 34 12 183,01 1344 1294, 1200 49 15 235.91 1461 1394, 1300 67 18 292.18 1578 149.4, 1400 84 17 348.19 1697 1594, 1500 102 18 406.20 1818 1694. 1600 124 22 467.48 1942 1794, 1700 148 24 532.72 2068 1894, 1800 173 25 602.09 2200 1994, 1900 206 33 681.26 2341 2094, 2000 246 40 772,37 2490 2194. 2100 295 49 874,77 2651 2294. 2200 357 62 992.77 2816 2394, 2300 422 65 1114.67 2977 2494. 2400 483 61 1231.59 3138 2594. 2500 544 61 1348.20 3301 2694, 2600 607 63 1468,16 3465 2794, 2700 671 64 1589,90 3631 2894e 2800 737 66 1714.81 3797 2994, 2900 803 66 1839,41 3964 3094, 3000 870 67 1963,72 4137 3194, 3100 942 72 2094,67 4324 3294e 3200 1030 88 2240,29 4512 3394, 3300 1118 88 2387.09 4700 3494, 3400 1206 88 2533.08 4888 3594. 3500 1294 88 2679,95 S 0.00 W S 0,00 W S 0.00 W S 0,00 W N 1.31 E N 8.00 E N 17.76 E N 26.51 E N 36.69 E N 51,01 E N 69.61 E N 91,07 E N 113,84 E N 139.12 E iN 166,35 E N 197.55 E N 229.79 E N 262.16 E N 297.29 E N '. 335.27 E N 376,37 E IN 422,76 E N 470.93 E N 518,39 E N 556,33 E N 513.33 E N 658.79 E N 703,10 E N 748.39 E N 797,34 E N 8/+9.57 E N 910,83 E N 973.14 E N 1036,63 E N 1097,60 E ARCO KUPARUK C-6 GYROSCOPIC SURVEY JOB NO 4411 MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, 3 APR 81 TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 5076 3694. 3600 1382 88 5261 3794, 3700 1467 85 5439 3894, 3800 1545 78 5613 3994. 3900 1619 74 5799 4094, 4000 1705 86 5987 4194o 4100 1793 88 6176 4294, 4200 1882 89 6365 4394, 4300 1971 89 6551 4494. 4400 2057 86 6737 4594, 4500 2143 86 6920 4694. 4600 2226 83 7094 4794. 4700 2300 74 7259 4894, 4800 2365 65 7415 4994, 4900 2421 56 7562 5094, 5000 2468 47 7703 5194. 5100 2509 41 7840 5294, 5200 2546 7975 5394, 5300 2581 35 8107 5494, 5400 2613 32 8237 5594, 5500 2643 30 8366 5694. 5600 2672 29 8492 5794, 5700 2698 26 8618 5894e 5800 2724 26 8742 5994. 5900 2748 24 8864 6094, 6000 2770 22 8986 6194, 6100 2791 21 9111 6294. 6200 2816 25 9242 6394, 6300 2847 9381 6494, 6400 2886 39 9526 6594. 6500 2932 46 9671 6694, 6600 2977 45 9814 6794. 6700 3020 43 9953 6894. 6800 3059 10092 6994. 6900 3098 39 10231 7094, 7000 3137 39 2825.06 N 2965.82 N 3098.52 N 3228.67 N 3366.11 N 3499.77 N 3634.15 N 3769.06 N 3901,04 N 4033,29 N 4161.81 N 4277.78 N 4381.77 N 4473.87 N 4553,87 N 4624,68 N 4690.35 N 1162,97 E 1229.65 E 1292.87 E 1351,51 E 1426.54 E 1513.49 E 1600,80 E 1687,10 E 1772.02 E 1856,37 E 1939,98 E 2022,15 E 2102,17 E 2179,05 E 2251.44 E 2320.31 E 2387.17 E 4755,11N-- 2451.14 E 4816,15 N 4872,96 N 4926,72 N 4978,48 N 5028,41 N 5076.16 N 5121,03 N 5164,46 N 2512,27 E 2572.68 E 2633.15 E 2690,79 E 2748.44 E 2803,91 E 2857,56 E 2911.36 E 5209,26 N -~. 2971,87 E 5258,76 N '3040.69 E 5314,12 5369.35 5425,58 5479.32 5531.20 5583.01 5535.05 3119,58 E 3209.56 E 3298.26 E 3384,30 E 3466.52 E 3547,99 E 3629.33 E ARCO KUPARUK C-6 GYROSCOPIC SURVEY gOB NO 4411 3 APR 81 INTERPOLATED VALUES FOR EVEN 1000 TRUE MEASURED VERT I CAL SUB DEPTH DEPTH SEA 1000 987. 893. 2000 1840. 1746. 3000 2508. 2414. 4000 3115. 3021. 5000 3653. 3559. 6000 4200e 4106m 7000 4739. 4645e 8000 54!2. 5318. 9000 6205, 6111. 10000 6927. 6833e FEET OF MEASURED DEPTH. TOTAL COORDINATES 91e87 N 35,52 E 564.06 N 244.60 E 1248.38 N 524.88 E 1990.85 N 807m76 E 2766.52 N 1136.00 E 3508e92 N 1519.64 E 4216,01 N 1977e37 E 4767.06 N 2462.68 E 5169.67 N 2917.98 E 55~+8.98 N 3493.90 E HORIZONTAL VIEW ARCO ALASKA INC. KUPARUK C-6 RADIUS OF CURVATURE GYROSCOPIC SCALE: I" = I000~ APRIL 6~ 1981 Il T. II N.~ R. !0 E.~ U.M. 867' TVD = 7102' TMD = 10,24:5' ALL DEPTHS SHOWN ARE TVD VERTICAL SECTION ARCO ALASKA INC. KUPARUK C-6 RADIUS OF CURVATURE SURFACE LOCATION IS GYROSCOPIC = I000 1581' SNL~ 867' EWL~SEC. I~. SCALE; I" ' T. II N., R. IO E,~ UM APRIL 6~ 1981 ° ._ . 5600~ - 4000 ~ .. . ...... 4800 '~ 5600 ~ 6000 ~~ ~8oo ~ TVD= 7102~ TMD = 10~243' Check Form for timely compliance with our regulations. · ' [ Operator; ~Wel 1 I,!~u~ and Number Reports and Materials .to be received by: Completion Report Wel 1 History Samples Mud Log Core Chips Core Description Registered Survey Plat Inclination Survey ...,T~_7~.~'~.,..~-,.~'~:~-~.x':~~' ~... 'I~(,~' ~ ........ .~,~ .... ~,~ ~. lre~lonal Su ~ ~ ~" ,~ / Drill St~ Test Re~s Prcduction Test Reports Digitized Log Data Required 3,-I -Fl Yes Yes I PI Date Date Received Remarks Yes NORIH SLOPE ENGINEERING Transmitted herewith are the following: Please note: BL- Blueline, From: S - Sepia, F - Film, ~.~OMM ~L_~ :' J. J. Pawelek / Leo Lash 1 4 .... T- Tape DZ- SFZ. //~ RE~ RECEIPT TO: ARCO Alaska, Inc. Attn. Leo Lash / AFA-311 P. O. Box 360 Anchorage, AK 99510 ~PR 1 5 1981 A~O}i & ~a~ Cons. Commi881o. ~chorage Transmitted herewith are the following- Please note: BL- Blueline, S - Sepia, F - Film, T Tape .'. CBt- vD E ' ~ ' RE, liMN RECEIPT TO: ARCO Alaska, Inc. Attn. Leo Lash / AFA-311 P. O. Box 360 Anchorage, AK 99510 RE£EI'VED' APR 1 5 1981 .Alaska Oil & Gas Cons. Commission Anchorage Thru: ALASKA OIL & GAS CONSERVATION COMMISSION Hoyle H. Hamilton .... March 10, 1981 Chairman Commie sion~ Lonnie C. Smith Commissioner Bobby Foster ' Petroleum Inspector · Witness BOPE test On ArCO~S Well C-6 ~eci'i21 TllN. R10E UM Permit #81-25 Friday.., March 6, 1981 I traveled this date to P~r~dhoe Bay. after be%ng contacted by Doug Amos. After arriving ~at 'Pru~oe Bay I' 60nta6tea- Doug and he.requested that I c~e'~ t° .ArC0,.S i. C~',i'an. d'iW_{~nessl the up coming BOPE test. The BOPE test began at 8:~06 p.m. and was completed at 11:30 p.m. As the BOPE field re~o~t~ ~hows, "thgre ~'~s .one · failure. The bonnet gasket on the UpP.er pipes leake , '"' ThiS~WaS tightened and retested. I requested that isolatiwn'~'valves be installed on the accumulator bottle banks ,..,.a~d M,a.¢~Mc~ty~ %nfo..rmed me that he w.ould not install themii'. "ii ,r'ep0rted'·this ~t0'~ the commiSsioner Lonnie Smith and a decisib~~ is'to'be ~de, In summary I witnessed the~BOPE test on Arco's C-6 , 4/80 STA'I'E OF AI,ASKA OIL & GAS CONSERVATIO?~ COb .~ SION B.O.P.E. InspecZion Report Location: Sec /~ T Rt~Etl ~m /0. Casing S~ r~z-~-~/ ~'- Drilling Contractor ~~/~/~7 Rig ~~ Represe~tative.~~~ ~~ ~cation, General ~ .. . ACCUMUI~,TOR SYSTI'2-, ~ ~Ct~ Well Sign Full Charge Pressur ~ -- pszg Reserve pit ~~ 200 ps ig Above Precharge Attained: -- mi~ s Controls: Master ~~ BOPE Stack '' Test Pres~re Kell~ aha Floor Safety Valves Pipe Rams f~ [ ~~ Lower Kelly / Test Pressur~ Blind R~s / ~0 Ball Type... / Test Pressure ~/~ Choke Li~e Valves. ~ ~O~ Inside BOP / Test Pressure ~/~'~ H.C.R. Valve / ~~ ~ Choke Manifold~Zest Pressure~~ Kill, ~o. va~s, / ~ Line Valves ~ [~ .................. ......... .. ................................ R~pai'r or Replacement of failed equipment to be made within (flays and '" Inspector/Commission office notified. , o:ig. - Ao~:c cc - Operator :P'e~rua.r~ 2~, Letter of Noa-ObJee~ion ~. ia ~ advise a~Jee~ ~ (formerl~ ~ ~o. ¢-~) as ae~ for~ ia your letters of Ver~ trul~ Original'Signed By W. C, Morrison V. ¢. Morr~$on ce: ~a~e of ~k~ Oil aad ~e~ Ccaeervation C~saion Surface Diverter System 1. 16" Bradenhead. 2. 16" x '20" 2000 psi double studded adapter. 3. 20" 2000 psi drilling spool w/lO" side outlets. 4. 10" ball valves, hyraulically actuated, w/10" lines to reserve pit. Valves to open automati- cally upon closure of annular preventer. 5. 20" 2000 psi annular preventer. 6. 20" bell nipple. Maintenance & Operation ~- - 1. Upon initial installation close annular ! preventer and verify that bal 1 valves ! have opened properly. · I 2. Close annular preventer and blow air ~__ . through diverter lines every 12 hours. 3. Close annular preventer in the event that gas or fluid flow to surface is detected.. If necessary, manually over- ride and close ball valve to upwind diverter line. Do not shut in well under an~/ circumstances. 16" Conductor REC IYED F£B 2 1 81 Alaska Oil & (~as' Cons. Commission Anchorage ( 3 -5/8" 5000 PSI RSRRA BOP STA<" RNNULRR PREVENTOR 9 , ) BLIND RRMS 2. 3. 4. Be 6. e FEB ? 16" Bradenhead 16" 2000 PSI x 10" 3000 PSI casing head 10" 3000 10" 3000 adapter 13-5/8" 13-5/8" and kill 13-5/8" 13-5/8" 13-5/8" PSI tubing head PSI x 13-5/8" 5000 PSI spool 5000 PSI pipe rams 5000 PSI drilling spool w/choke lines 5000 PSI pipe rams 5000 PSI blind rams 5000 PSI annular ACCUMULATOR CAPACITY TEST 1. CHECK AND FI~LL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT ACCUHULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. 'OBSERVE TIME THEN CLOSE ALL UNITS SIMULTANE- OUSLY AND RECORD THE TIME AND PRESSURE REMAIN- ING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. m13.--.,5/8'' BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RE- TRACTED. PREDETE~,tINE 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 MANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR l0 MINUTES. $. INCREASE PRESSURE TO 1800 PSI AND HOLD FOR l0 MINUTES. BLEED TO ZERO PSI. 6. OPEN ANNULAR PREVENTER AND CLOSE TOP SET OF PIPE RAMS. 7. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR l0 MINUTES. 8. CLOSE VALVES DIRECTLY UPSTRE~,I OF CHOKES. BLEED DOWNSTREAM PRESSURE TO ZERO PSI TO TEST VALVES. TEST R~IAINING UNTESTED MANIFOLD VALVES, IF ANY, WITH 3000 PSI UPSTRE~',I OF VALVE AND ZERO PSI DOWNSTREAM. BLEED SYSTEM TO ZERO PSI. ~ 9. OPEN TOP SET OF PIPE RAMS AND CLOSE BOTTOM SET OF PIPE P~AMS. 10. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. ll. OPEN BOTTOM SET OF PIPE RAMS. BACK OFF RUN- NING JOINT AND PULL OUT OF HOLE. CLOSE BLIND PAl, iS AND TEST TO 3000 PSI FOR l0 HINUTES. BLEED TO ZERO PSI. 12. OPEN BLIND RD, iS AND RECOVER TEST PLUG. MAKE SURE FIAIIIFOLD A~;D LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN DRILLI?;G POSITION. 13. TEST STANDPIPE VALVES TO 3000 PSI. 14. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOiIEY PUHP. · RECORD TEST INFOR2ATIO~4 ON BLC~OUT PREVE~iTER TEST FORM SIGN A~;D SE~D TO DRILLI~;G SUPE~- VISOR. · PERFO~.I C~IPLETE BOPE TEST ONCE A WEEK A~iD FUNCTIONALLY OPERATE BOPE DAILY. February 24, 1981 Mr. P. A. Va nDusen District Drilling Engineer ARCO Oil and Gas Company P. O. Box 360 Anchorage, Alaska 99510 Re= Kupar~k 25649 C-6 Atlantic Richfield Company Permit No. 81-25 Sur. Loc.: 1381'FNL, 867'FWL, Sec 12, TllN, R10E, UM. Bottomhole Loc.: 821'FNL, 1031'FEL, Sec 1, TllN, RiOE, UM. Dear Mr. VanDusen: Enclosed is the approved application for permit to drill the above referenced well. Well samples and a mud log are not required. A directional survey is required. If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs, velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous fish. Operations in these areas are subject to AS 16.50.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by the Habitat Coordinator's office, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to Mr. P. A. VanDusen Kuparuk 25649 C-6 -2- 'February 24, 1981 commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is being notified of the issuance of this permit to dri 11. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also ltke to be notified so that a repre- sentative of the commission may be present to witness testing of blowout preven~r equipment before surface casing shoe is dri 1 led. In the event of' suspension or abandonment, please give this office adequate advance notification so that we may have a witness present. Very truly yours, · Hoyl H. Hamilton BY ORDER OF THE CO~'~,'];$$10N Chairman of " Alaska 0il & Gas COnservation Co=mission Eno 1 o sure Cc= Department of Fish & Game, Habitat Section w/o eno1. Department of Environmental Conservation w/o/encl. Department of .Labor ~ Supervisor, Labor Law Compliance Division w/o encl. ARCO Alaska, Inc. ~ Post Office 8~,'~ . 360 Anchorage. Alaska 99510 Telephone 907 277 5537 February 20, 1981 Mr. Hoyl e Hami 1 ton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Kuparuk C-6 Dear Sir: Enclosed please find the following: · 2. 3. 4. 5. 6. The Application for Permit to Drill Kuparuk C-6 and a $100.00 check for the application fee. A diagram showing the proposed horizontal and vertical projections of the wellbore. An as-built drawing of "C" pad indicating the proposed surface location. A proximity map indicating any and all wells within 200' of the proposed wellbore. A diagram and description of the surface hole diverter system. A diagram and description of the BOP equipment. In addition', per telephone conversations with Mr. Lonnie Smith, it is our intention to continue our efforts to mitigate the "C" pad surface gas bubbling problem. For well C-6, these efforts include the following: 1. Continued use of insulated conductor and cementing technique as utilized for well C-5. 2. Continued use of sub-base ventilation system as used for wel 1 C-5. 3. Continued use of recording gas detectors to monitor both ditch gas and cellar gas, if any. 4. Continued use of AS II cement for the 10-3/4" surface casing cement job. 5. Continued effort to maintain drilling fluid temperature as low as is practical with available equipment. We were well pleased-with the results obtained through the use of the above five items at well C-5 and trust that you will find their continued use at well C-6 to be acceptable. Si ncerely yours, P. A. VanDusen District Drilling Engineer FEB 2 3 1981. Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska. Inc. is a Subsidiary of AttanticRicrlfieldCompany STATE OF ALASKA ALASKA LAND GAS CONSERVATION C ~MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL iX-] DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC [] SINGLE ZONE MULTIPLE ZONE [] 2. Name of operator Atlantic Richfield Company 3. Address P.O. Box 360, Anchora9e, Alaska 99510 4. Location of well at surface h 1381'FNL, 867'FWL, Sec 12, TllN, RIOE, UM RECEIVE At top of proposed producing interval 1320'FNL,. 1320'FEL, Sec ], TllN, R10E, UM FEB2 3 1981 At total depth 82l' FNL, 1031 'FEL, Sec l, TllN, Ri0E, UM Alaska 0il & Gas Cons. Corn 5. EJevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial n~.rlcrl0ra§e 55'GL, 60'Pad, 94'RKB I ADL 25649 9. Unit or lease name Kuparuk 25649 10. Well number C-6 11. Field and pool ~isSi~rudhoe Bay Kuparuk River 0il Pool 12. Bond information (see 20 AAC 25.025) Type Statewide Surety and/or number Fed Ins Co 8011-38-40 Amount $500,000 15. Distance to nearest drilling or' completed we, (at surf.) 120 feet 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mi NW of Deadhorse miles (at TD) 821 feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 10089'MD/7058' TVD feet 2560 19. If deviated (see 20~050) 120. Anticipated pressures KICK OFF POINT/,//' bO(,} ?et. MAXIMUM HOLE ANGLE 50 oI (see 20 AAC 25.035 (c) (2) 18. Approximate spud date 3-1-81 2. 7 3 7 psig@ 600'_ Surface 3266 ,.psig~ 6574..ft. 'T'~(TVD) Proposed Casing, Liner and Cementing Program SIZE Hole I Casing .Weight 13-3/ 10-3/4 8-3/~ [ 7" - *1 6" ilnsulate 22. Describe proposed program: 45.5 26 Q condu, CASING AND LINER Grade I Couplingl H-40 )Wel dedJ K-55 ;tot Length MD 80' )ad 3279' pad 10055 pad SETTIN£ TOP TV D pad pad pad DEPTH (RKB) MD BOTTOM TVD 114' !114' 33i3' '1 2700' 10089'1 7058' I I QUANTITY OF CEMENT (include stage data) 425 sx 3750 sx AS II 900 sx Class "G" Atlantic Richfield Company proposes to drill a Prudhoe Bay Kuparuk River Oil Pool develop- ment well to approximately + lo,089'MD, + 7058'TVD. Selected intervals will be logged. A 20" x 2000 psi annular dEvOter will be i-nstalled on the 16" conductor while drilling the surface hole. A 13-5/8" 5000 psi RSRRA BOPE stack will be installed on the 10-3/4" sur- face pipe. It will be tested upon installation and weekly'thereafter. Test pressure will be 3000 psig. Expected maximum surface pressure will be 2737 psig*. The well will be completed with 3½" 9.2# J-55 buttress tubing. Nonfreezing fluids will be left on unce- mented annuli thru the permafrost interval. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A downhole safety valve will be installed and tested upon conclusion of job. *Based on co.olino of oas bubble risino at constant volume. . - 23. I hereby certify that th'~ forego~g is true and correct to th~'best of my knowledge tSIGNED TITLE District Drlg. Engineer DATE ~. 8/ The space lee ow or Co~n'missi-on u'~e · ,r i Samples required ~ Mud log required ) [--)YES /~0 []YES [~0 t Permit number ~ i_.l_~...- Approval date 02/24/81 APPROVEDBY CONDITIONS OF APPROVAL IDirectional Survev required I APl number SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE February 24:1981 , by order of the Commission Form 1.0-401 Submit in triplicate -?'~RCO FILRSKR, .'INC.:, il PAD C; WELL NO: 6"PROPOSED~-: ;L~J(UPRRUK FIELD, ,NORTH SLOPE,·'.RI ~'~';d"I"L'O~THRN NHIPSTOCK rl-f"H-t~ J /' i , ' '.,.:L~:F[~!/:! ;1::,t ,7';."~T"t :'-: :'?T T?/l :-Hi..'!, ../, '.-. !,. ! 5URFA£E_.L~. · , 12 -- BU I LO --3 ,D PER~ !00 F 8p§~ ~£~ARFRosT 48 EocTvo=IgBb fHO~i66 OEP=68; POINT 9336 DEP LOIdER:SRNDS: TV0=6894 KUP:--SflND$---'-TVD:6994 .-..9989 ~TVD=7058 .THO=lO089 0EP=6'749 -~; i' .i ......... BO F'I!, I . -:'-~ '-TTRRGET - , / ' ..!_!. : ',, .,T.0:.~6 .. : ....... 'EnST . : . : J .... t . . · i ~ooo }ooo 3960 FT / 4000 · _5000' 1 .4000' 9000 _ 2000 IlOOO o WELL '1 Y = 5,968,522.46 X .... )oz,372.O5 LAT = 70o]9?'28°285`` LONG = I;9°29'39o.293'' ,, WELL ~2 Y = 5,968,589°53 X = 562 271,.78 LAT = 70°19'~8o953'' LONG = 149°29~42~204'' WELL #3 Y'= 5,968,655',,42 X = 562,t72.58 LAT = 70°i9~29o6i0'' LONG = 149°29'45.084'' WELL ~ Y = 5,968,722.03 X = 562,072.98 LAT = 70019'30-273'' LONG = 149°29~47.975'' .WELL /5 Y = 5,968,788.41 X = 561 °73 O0 .... -~ LAT = 70°19'30,934'' LONG = 149°29'50,.878'' WELL -:6 ',' ~ 5,965,8-~.07 × = 56],872-65 LAT = 70°19~31.~98'' LONG = 149°29'53o79I'~ I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS AH AS- BUILT SURVEY MADE BY ME, AHD THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT, AS OF: DATE = 1/7/~0 WELL ~ 7 Y = 5,968, ,m2 l'. 16 X = 561,772°33 LONG = 14729'56.68':~ 'WELL :z8 ' 'y = 5,968,987.86 X = 3ol,6/2.2~ LAT : 70°19'32o920'' LONG = 149o29'59,,608'' I ii i iii ii ii iiii I I iii ii I11 _ i II I I I ii I i ......... ..............___.......__....... _...,...,,...._......_........ ' ............. n~ ~:~ [ ....... t ........... ALASKA DISTRICT ~-- KUPARUK ~/'7...~ ..... [ _1 i i .... i 11 i ii i i ...... i llll 3111 i IIII I ii i ii I UPRRUK FIELD, NORTH SLOPE, RLRSKR i .. i, .x,~. ~ .......... i ' ! '; ~-J'i-.i_;';i] i: iERSTHRN .HIP.STaCK. INC.'--- : ..... . ....... · ..f..,~,:!.?..:.-' .i". .. ,-...:~.,, .,;. ~. . - .. .. . . .. . COIViI-:'AN ', U.S.A'. , :,,. ,%,.,, ::, ,, AVENUE OF THE STA~'tS - LOS ANGE. LELL CALIFOt',iIIA 9036'/ (~13) , , PRO ') ,J C'I', ,"~ i'-,I WES'rLI~N '~ovemBer-.iT-I9B0 In re- Letter of Non-Objec Deviation of Wells (1]AAC22.050) Arco Oil and Gas Company North Slope District P.O. Box 360 Anchorage, Alaska 99510 Attention' Mr. Sylvesl:er R. Jaime Gent lemen · By ].etters dated Septe. mber 24 and October 22, 1980, you have adviSed Exxon Corporat.ion that you propose to directiona].ly deviate three of )'our developmen~ wel].s as follows: N~!~.C~,_-_]~~]]ed from a surface location 1650 feet SNL, %%1] 'i~,-~4 .... :~i!:;~Scc'tion 12, TI.].N, R10E, U.M. will be deviated to a bottom hole location 1320 feet SNL, 1320 feet WEL, Section 12, TllN, R].0E, ~ well. No. c--5 dri].led f.rom a surface locatSon 1381 feet SNL, 967 feet EWL, Section 12, TllN., R10E, U.M. will be deviated to a bottom hole location at 1320 feet SNL, 1320 feet WEL, Section 1, TllN, RIOE, U.M. lVe].l No. D-2 drilled from a surface locatJ, on 117 feet North and 601 feet %'¢.,.st from t]~e SE Corner of Section 14, TllN, R10E, U.M. wi]] be d(;viated 't(; a bottom hole location 1320 feet SNL and TllN R10E U 1320 %%'EI,, Sect ion ].3, , , . . ,: Exxon Corpora'[::icon, being' one. o£ the lessees under State of Alaska Oil and Gas Lease AI)I,-22242 covering lands which offset on the east the above-dc:scr.ibe, d S~:ctions 1, 12 and 13, TllN, RIOE, U.M., comes within the defin:ition o:[ "an affe, cted operator" set forth in llAAC22.050. As such an af:[ccted op(.~rn, tor, Exxon Corporation does not object to the above-descrY, bed deviations of the well in which it is to occur. You may use this ~,.s; a lo'trot of non-obSection i'or tne-purPbses of llAAC22. 050. Very truly yours, EXXON CORPORATION 1. ts A-'ttorne'y in Fact' APPROV[ Mobil Oil Corporation 5444 COLORADO 17,0217 October 20, 1980 Alaska Oil and Gas Conservation Con~ission 3001 Porcupine Dr. Anchorage, Alaska 99501 LETTER OF NON-OBJECTION ARCO OIL AND GAS LEASE ADL 25651 NORTH SLOPE ALASKA Gentlemen: We have received corresponde, nce from Atlantic Richfield Company advising of their intent to directionally drill three wells on the captioned lease as follows: Well No. Bottom Hole Location C-1 C-5 D-2 1320' SNL, 1320' WEL, Sec. 12-TllN-R10E, UM 1320' SNL, 1320' WEL, Sec. 1-TllN-R10E, UM 1320' SNL, 1320' WEL, Sec. 13-TllN-RiOE, UM Mobil owns an interest of 50 percent in two leases (ADL #28243 and ADL #47449) which will be affected by the propssed action. Pursuant to 11 AAC 22.050 this is to advise Mobil Oil Corporation does not object to the proposed drilling. JLDouglass/nb Yours very truly, L. C. Case Division Regulatory Engineer cc: ARCO Oil and Gas Co. Box 360 Anchorage, AL 99510 Attn: Sylvester R. Jaime CHECK LIST FOR NEW WELL PERMITS Item 3~p~rove Date (I) Fee ~ ' ~-~'f (2) Yes No 1. Is the permit fee attached ............... . .... , ..................... 2. Is well to be located in a defined pool .......................... '.,Z~,._. ._ 3. Is a registered survey plat attached .............................. .~./~_ 4. Is well located proper distance frcm property line ................. ~. Is well located proper distance frcm other wells ................... / Lease & Well NO. /~.~ Remarks 6. Is sufficient undedicated acreage available in this pool ........... 7. Is well to be deviated ............................................. .~~ 8. Is operator the only affected party ................................. , ,,, 9. Can permit be approved before ton-day wait ........................ '.. / 10. Does operator have a bond in force ................................ .. 11. Is a conservation order needed ...................................... .... ~ 12. Is administrative approval needed ................................... .~ / 13. Is conductor string provided ........................................ 6~ 14. Is enough cement used to circulate on conductor and surface ......... (~ (4) Casg. ~ ~-.f~..'~fs! 15. Will cement tie in surface and intermediate or production strings ... ~ ~6. Will cement cover all known productive horizons ..................... ~ ... ) 17. Will surface casing protect fresh water zones ....................... ~. . ( 5 ) BOPE 18. Will all casing give adequate safety in collapse, tension and burst.. ~ ~.19. Does BOPE have sufficient pressure rating - Test to ~ O~ psig . .~__ Approval Recked: Additional Requirements: C,,,,~,~..~.....~&O ~_-~.]-~/ t~ C..~ Geology: Engin~r~g: LCS ~,.~_ BEW~~. JAL.~~_ rev: 03/05/80 Well Histocy File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPEI~I. DIXi .. No special'effort has been made to chronologically organize this category of information. o. ~800,000 ~ -999 250 ~OB -999~250 3700,000 G~ '999.250 RHOB -999,250 3625,000 GR '999 250 RHOB '999:250 SUMMARY OF DATA RECORDS NUMBER OF RECORDS: 474 LENGTH OF RECORDSl 1014 BYTES LENGTH OF LASI RECORD: 114 BYTES FILE T~AILE~ LENGTH: 62 BYTES FILE NAME~ EDIT .005 MAXIMUM PHYSICAL RECORD 5ENGTH~ NEXT FILE NA~E: EOF TAPE TRAILER LENGTH: 132 B~TE$ TAPE NA~E~ 56231 SERVICE NAME: EDIT TAPE C~NTINUATION NU~BER~ NEXT TAPE NA~E: 01 CALI NRAT CAbI NRAT CA~I NRAT ~999 250 DRHO '999,250 NPN! ~999'250 FCN5 -999:50 NCNL g99,250 FCNL -999 ~50 DR.HO -999,250 NPHI -999: 50 NCNb '999,250 FCNI~ 1024 BYTES DA~= 8t/ 5/ 8 -999,250 .999.250 ,999:250 '999,~50 ~999. 50 /C 5700,000 5600,000 5500,000 5400,000 5300,000 5200,000 5!00,000 5000,000 4900,000 4800,000 4700,000 DEPTH 4600,000 4500.000 4400,000 4300.000 4200.000 4100.000 4000,000 3900.000 GH RHOB RHOB. RHOB GR RHOB RHOB RHOB G.R RHOB RHOB RHOB ~NE~ONIC GR '(iR GR RHOB GR RHOB RHOB RHOB RHOB GR RHOB 2 O, 20 3 l,OgO N~A~ 52,406 2 · 094 289 NRAT 64,500 2 · 232 -999,250 -999,250 '999; 250 ' 999 ' 250 -999.250 NRA~ ~999.250 999,250 - g 99 · 250 -999.250 BRAT 999-250 VAbUE MNE -999,250 - 999 · 250 '999. 250 999~250 N -999,25~ -999 .'999'250 999.250 NRAT '999.250 "999'250 '999 ' 250 -9991250 · '999 ' 250 -999 '250 -999,250 NRA', 742 NCNi 6 I 0 0 97. 93 · 97, 9t N 40, 000~. ~ FC'NL 324, .24,, 000 FCN'L 43.4, , 2501!50 ' : N~"H2FcN~ -~99~,.99 ' '999, , : 746 234 2-50 25O 25O 25O 25O '0 f '999,250 250 ; 'FCNb "999 ~ 250 99 · 250 25O '999.250 ,250 ,250 25O ,250 ,250 '999 250 '999:2'50 999,250 999.250 '999.250 '999,250 '999.250 7700,000 7600,000 7500.000 7400.O00 7300.000 7200.000 7100,000 7000.000 6900,000 6800.000 6700.000 6600.000 DEPTH 6500.000 6400.000 6300.000 6200,000 6i00,000 6000.000 5900.000 5800.000 G~ RHOB RHOB GR RHOB RHOB RHOB GR RHOB O~ RHOB GR RHOB GR RHOB RHOB GR RHOB RHO8 RHOB 990 20,203 ! .990 20 03 t: ,o 20,203 1,990 20 203 1:990 20.203 I'990 20.203 1,990 20.203 I'990 2~,203 .990 20.203 1,990 20' 203 !,990 2O 1 2O 1 2O 1. 20 20 ! 20 ! 2O 1 20 CAt`! 6,445 NEA~ DRHO · 38 .:39.746 97,188 39 746 :39,-746 97,.I88 39,74~ 97'18 CALI 6'445 DRHO '0,85i . NPHI 39,746 NRAT 3.582 NCNI~ :381-',2.50 "0 NPHi ,746 ,188 C NPHI :39,74.6 fiRAT N 250 FCNL 97. 188 CA]bi 6,445 DRHO -0.851 NPHI .39,.746 NEAT 3~:582 NCN5 :'3Bi:~250. ' FCN~ .97-188 ,990 .203 ,990 ,203 ,990 .203 '990 ,203 .990 ,203 '990 ,203 6 445 i NPH! :250 'FCNb 851 NPH! NPH! NRA' CA~ 445 NPHI NEAT NPHI NPHI 250 FCNt` - NPH! NPH! 39,746 9~.i88 ?. 88 88 :~9.746 ''?,i88 39,746 ~loe 39.746 39,746 970188 ~.746 ,i88 39,746 ,188 39,746~ 9700,000 9600,000 9500,000 9400,000 9300,000 9200,000 9100,000 9000,000 8900.000 8800,000 8700,000 8~00.000 8500.000 DEPTH 8400.000 8288,000 8200.000 8100,000 8000.000 7900,000 7800.000 RHOB GR R{tOB RHOB RHOB GE RHOB GR RHOB RHOB RHOB O~ RHOB GR RHOB RHOB RHOB RHOB ~NEMONIC RHOB G~ RHOB RHOB GR RHOB GR RHOB GR RHOB GR RHOB 2O 2O 1 2O 1 2O I 2O t 2O I 20 1 20 20 ! 2O 1 2O 1. 2O VALU 20. lo 20, 20. 1, 20, 1, 20, l, 20 20 ,203 .990 .203 .990 ,203 ,990 203 ~990 ,203 .990 2O3 ~990 , ~0 .203 .990 .203 .990 ,203 .990 03 go{ 9O AbI 6,445 RAT ]-582 CAb! 6'448 NRAT 3.582 CALl 1.445 NRA? 2582 CAbI NRAT 3'552 CALl 6.4~5 CAb! CALl NRAT CALl NRAT CAb! NRAT 3 582 CAbI .6,445 NRAT 3'582 Cl.b-I 6,44 NRAT 3,582 203 ¢tLI 6.445 990 ,NRAT. 3~,~1582 E ~E~O~IC VAbO£ 03 CALl 6.445 90 NRA~ :3~582 203 Cibl 6,445 990 NRA. T .3,582 2o3 CALl 6.445 990 NRAT ~ !3~582 90 NRAT 3 203 ~AbI ~.445 990 RAT ~. ~582 203 CAbI :- :-6~445 990 NR~T 3.582 203 ClhI 6,445 990 -'NR~T 3~i582 6 3 582 NCNb · = 6,445 DRHO ,8~ NPHI DRHO-' -0 8~1'' ~' NCNb 381:250 rCNb FCN,b ,746 39,.746 ~97;188 DRHO ;'0,851 NCNb 381'250 DRHO -0,851 NPHI 'FCN 85t NPHI 250 FCNb 3 ,250 NPH! ;39-746 FCNb 97.188 39,746 ~97 ~:t88 746 NPHI- ~.39,746 FCNb 97;1.88 DRHO -0,851 NPH! 39,746 NCNb -..38~250 :'',FCNb 97,188 85I' ' ~: NPH! 4~,746 NCNb 250 FCNL . ;188 DRHO -0,85 NPHI '39,746 NCNb ~38i~25~ rCNb 50 FCNL ;188 DRHO '0,851 NCNb ~:38t~250 :DRHO DRHO NPH! 39,146 FCNL 97,.,88 - '0,85 i N.PHI ~ ;186 .38, i,250 FCNb 97':746 :381';250 .!FCNb ..97-,i88 DRHO NCNb 3:8 ~,l,~ 2:50 CN-L NPH! NCNL 25O DRHO .., 0,85 i NPHI 39 NCNi~: :38.i.250 '~::- .' 'rCNb :97 746c i88~ DATA FORMAT 8PEC!FICATION LENGTH: .370 E...TRY BLOCKS: TYPE DATUM ~PECIFiCATIO N B DOCKS NAME ¢ 7 NRAT"CN5 C/C 42 42 8 NCNLI CNL CPS 42 34 9 9 FCNLLCNL CPS 42 34 93 USER DEFINED OUIPUT ARRAY OUTPUT GR AT 2 OUTPUT CALi AT 3 OUTPUT DEMO AT 4 OUTPUT NPHI AT 5 OUTPUT RHOB AT 6 OUTPUT NEAT AT 7. OUTPUT NCNb OUTPUT FCNL AT 9 DEPTH MNEMONIC VADUE 10248.000 GR RHOB 10200.000 GR RHOB 10100,000 GR RHOB 10000,000 GR RHOB 9900,000 GR RHOB 9800.000 G~ 3 20.203 1.990 20.20~ 1.99 20.203 1.990 20,203 1.990 20.203 1,990 1024 BYTES SIZE REP CODE :ENTRY I 66 0 APl FILE :SIZE SAM REP o ¸8 0 0 4 I .68 PROCESS INDICATORS MNEMONIC NRAT VALUE MNEMONIC .VALUE MNEMONIC 6.445 DRHO '0,85t NPHI 3~582 NCNb 138t~,250 'FCNb :DRHO '0'85! NPH! NEAT 3 NCNb ~381',250 FCNb CALI 6.445 DRHO '0.$51 NpHI NRAT 3~582 NCNb ~381,250 -FEND CAb! :6.445 - DRHO o0,85'{ NPHI NEAT 3.582. NCNb 38~'25Q FCNb CALI 6'445 DR.O -0,891 NPHI NEAT 3;582 -NCNb ~38~'250 FCNb CAbI B,445 -DRHO ~ .-0,85i 'NPHi NRAT 3.582 NCN5 381.25~ FCNI VALUE 39,746 :97,188 7, 88 39,146 97. 88 9,747,18~ {9,.746 97'i88 4700. OO0 GR 4600,000 GR DEPTH MNEMONIC 4500,000 GR 4400.000 GR 29.984 .P(IU 1.008 PCK 0,009 43.688 VA~UE MNEMONIC ~VALUE -MNEMONIC VA~UE ...NEMONIC VALUE 37,969 PCT-H 6w473- -PCU ~'151' 0,010 45.56] !H U 2.729 PCA 0,015 4300,000 GR 64,688 PCTH 9,977 -PCU -I~;300 · PCK 0,019 4200.000 GR 54.813 0.016 4100.000 GR 52.000 PCTH- : 8'281 ~> -P~!U ~ :~ ~I.,785~ PeK, 0,013 4000 000 GR 36 219 PCTH 5,238 PCU 0,596 PCK 0,009 ]900,000 GR 37,406 PCT:H ~ 4~:I:~-7~<:i: _.'PCU~:-: ~-~ ;<~'9~.'- PCK : 0,014 : - :: 3800,000 OR 39,469 PCTH 4,855 PCU !~,58B PCK 0,016 3700,000 -'GR 48,5~1 PCTH '.5'~26 PCU 0,019 3625.000 GR 42.969 PC~H 6.496 PCU ~.~9~ 'PCK 0.015 _ · SUMMARY OF DATA RECORDS NUMBER OF RECO~D${ 265 LENGTH OF RECORDS{ LENGTH OF hAST RECORD: 946 BYTES LENGTH: 62 BYTES FILE ~AME= EDIT ~04 MAXIM M PHYSICAL R~ NEXT FILE FI~E TRAILER 6700.000 6600.000 6500.000 6400.000 6300,000 6200,000 61.00.000 6000.000 5900,000 5800,000 5700.000 5600.000 5500,000 5400.0OO 5300,000 GR G~ GR GR GR GR GR GR GR G~ 58.156 58,1B6 58,i56 58,156 58,156 58'156 PCTH · 6,969 PCU 2,291 PCK : · . PCTH .6-96. ' -:PCU 2,29i PeK PCTH 6.969 PCU 2,291 PCK _PCTH -6-969 PCU 2S29! PeK PC?H -6.969 PCU 2,29i · . PCK ,PCTH -6-969 - PCU 2,29t PCK 58,156 PCTH 6 ,,, 969 PCU 2 , 29 ! PCK 58,156 PCTH 6'969 ! PCU' 2'291 PCK 58 156 PC?H 6,969 PC{.{ 2,29i PCK . - · - 58.156 PC~H 6'969: i PCU 2'291 PCK PCK 58,t56 PCTH 6~96g : :PCU, 2,2gt. PCK P(ITH 7 7 :U 1-,:.312 PCK 56,531 38,906 PC~H :5'527 ~ PCU 2,07{'PCK · 62,688 PCU 3,068 PCK 0,022 0.0~2 0,022 0,022 0,022 0.022 0,022 0,022 0,022 0,022 0,022 0,022 O,Oi? 0,013 0.021 5200,000 5100,000 5000,000 4900,000 4800.000 GR G~ Git GR 51,750 PCTH 7'430 - 'PCU 2,016 PCK 50.250 p,:?~ 6 t57 l~ ,,o9 pek 52.719 -PCTH 8.000 PCU 3,475 PeK 49,250 PCTH 6,203 PCU 1.:,445 PCK 41-,.469 PCTH .~,08.2 PCU ~- .'PCK 0,017 0,017 O,Oig 0,017 0,016 8bO0.O00 8500,000 g400,O00 8300.000 8200.000 GR GR 58 - 15{5 P~T~ 6'g6g L ~P~U ,2-'2g i 58 156 PCTH 6,969 PCU 2.29t PCK 58.156 PCTH 6*969: .. PCU : ,2.29[ PEK 0.022 0,022 0,022 0,022 58.i56 0.022 8100.000 8000.000 7900.000 7800.000 7700.000 7600.000 7500.000 DEPTH 7400.000 7300.000 7200.000 7i00.000 7000.000 6900.000 6800.000 GR GR GR GR 'GR G~ 58.i56 PCTH ,6,969 _ PCU 2,29. i PCK 0.022 P(:TH 6 i 9 PCU 2' PCK 0.022 58.156 . ~58,156 PCT~ - ', '6'969 _,~. PCU : :2,'291-~, PeK 0,022 58.156 PCTH 6 6 PCK 0,022 58,i56 .PCTH -6'969 ,PCU 2,;29I.- -PeK 0.022 58,,156 P, 'H 69 PCK 0.022 58.i56 PCTH 6.969 =PCU 2.2.9I PCK 0.022 VAhUE 58.1,56 58.156 OR 58 · 156 O R 58. i 56 p( T H GR GR 58. t56 NNE ' :MNE C -VAbUE PCTH 9 · ~ PCK 0.022 PCTH 6 969 PCO PCK 0.022 PCTH . 2 i.. PCK 0.022 6 I PCK 0,022 PCTH 6'969 ~' PCU . - ..2--29[ : PCK 58.156 : ::6.969~C:U -2~29i 0'022 PCK 0,022 PCK O,022 4 PdU NGRS UMER DEFINgD OUTPUT ARRAY OUTPUT GE AT 2 OUTPUT PCTH AT 3 OUTPUT PCU AT 4 OUTPUT PCK AT 5 DEPTH NNENONIC 1.0248,000 G~ 10200,000 GR 31 VAbUE 58,156 58,156 00 0 0 4 .1 68 0 0 0 0 4 I 68 . · PCTH .6~969 ::PCU 2,291 PCK 0,022 i PCU 2,291 PCK 0,022 10100,000 GR 10000,000 GR 9900,000 9800,000 GR 9700,000 GR 9600,000 GR -58'I56 55,156 PCTH 6'969 ~ PCU 6,969 PCO 2,29t PCK 0,022 2,291 PCK 0,022 58-t56 PCTH 6':969 - PCU 2 . 29 ! PCK ,9 0,022 PCO 2,291 PCK 0,022 -SS.t56 PC. TH 6'969 PCU 58,156 )69 PCU 2.29t PCK 0,022 2,29t PCK 0,022 9500,000 9400,000 GR 9300,000 GR 9200,000 9100.000 GR 9000,000 GR 8900,000 GR 58,156 PCTH 6' - :PCU 2,291. PCK 58,156 PCTH t69 PCU 2,29i PCK 58,156 ~PCTH 6~969: 2,291 PCK 58 156 .PCTH 6-969 PCU 2.291 PCK 58,156 PCTH 6-969 PCU 2,29~ PCK ;. - 58 156 PCTH 6,969 PCU 2,291 PCK . ~ 58, i56 PCTH -6'969 'PCU 2,291 ' PCK 0,022 0,022 0,022 0,022 0,022 0,022 0,022 8800,000 GR 8700,000 Git 58,156 PCU 2,2gi PCK 58,156 PCTH 6-969 PCU. 2,291- PeK 0,022 4200.000 OR 69,000 4100,000 GR 58,375 4000,000 GR 38,7!9 ]900,000 GR 51,469 3800,000 OR 54.875 3700,000 GR 49,563 3625 000 GR 57,156 SUMMARY OF DATA RECORDS NUMBER LENGTH LENGTH DT 135 DT 139,500 DT 124,000 DT 0 OF RECORDS: OF LAST :RECORD:"'47i FILE TRAILER LENGTH{ ~2 BYTES FILE NAM~t EDiT .,003 MAXIMU~~HYSICAL RECORD LENGTH~ 1, 24 NEXT' FILE NAMEI * * EOF * * FILE HEADER PREVIOUS FILE NAME: · FILE COMMENTS NOT TOOL .FR.OM 5611"3265 DATA FORMAT SPECIFICATION LENGTH: 210 BYTES ENTRY BLOCKS: TYPE o DATUM SPECIFICATION BLOCK$~ NAME TOOL UNIT 1 DEPT FT 2 GR NGRS GAPI 3 ~PCTH NGRS )E :ENTRY :66 0 APl APl APl -API FILE ,SAM 0 0 0 31 ]1 32 0 0 _4 31 0 0 0 0 4 t 7100,000 ?000.000 6900,000 6800,000 6700,000 6600.000 6500,000 6400,000 6300,000 6200,000 6100,000 6000,000 5900.000 5800.000 5700,000 5600.000 5500.000 5400.000 5300,000 5200.000 5100,000 5000.000 4900.000 4800,000 4700.000 4600 000 4500,000 4400,000 4300,000 GR O~ G~ G~ G~ GR G~ GR G~ GR GR G~ NNEMONIC GR GR 86.875 82,000 DT i05~i88 j i j 17,625 90,563 DT~ !09;!88 98,500 DT 108,5631 89 · 813 86,063 DT 80,375 i!3~50 87 ,. 563 DT ;' 80;5 89,375 BT 74,438 DT 80':000 76 · 250 66'000 78 · 000 DT ~0~ '~56 ~ 74.750 DT 58,375 DT 58 -86 67 77 82 62 57 38 063 I25 : 875 7:19 BT 969 DT 20 938 · ?2,000 DT : 84,250 DT 10100.000 I0000,000 9900,000 9800,000 9700,000 9600,000 9500,000 9400,000 9300.000 9200,000 9100,000 9000,000 8900.000 8800,000 8700.000 8600.000 8500,000 8400,000 8300.000 8200,000 8100.000 SO00.000 7900,000 7800,000 7700,000 7600,000 7500 000 ~P~. 7400,000 7300,000 7200,000 GR GR GR GR GR MNEMONIC GR g0,063 97,250 38,438 90,563 iDT 93,i88 77,500 DT 5'~. 4 o 6 o ~r :9 ~ .188 83 875 DT 86,'188 ' ~ 112.06] DT I'14..~50 . ~.75o D~ D~ g9'~75 246,875 192,750 DT !15.750 . ~0 D T UT UT DT 10 120,000 110,875 I15,625 125,938 163,875 DT , t08.375 DT 159,750 D! 163,375 DT 63 0 121,375 8 97,500 000 9~.~88 o 92.875 DT 9 VAbOE 91,3 ~. 3 : 92,688 99,500 I . 362§.000 GR 53.313 RHOB 2'088 DUNMAH¥ OF DATA RECORDS NUMBER OF RECORDS~ 474 LENGTH OF RECORD~ 1014 LENGTH OF bAST RfCORD~ 114 BYTES NEXT FlEE NAME~ EOF $ , , FILE HEADER bENGT FlEE MAXIM VI PREFi BHC DATA N~ H{ 62 BYTES NAME: EDIT .003 UM ~PHYSICAL RECORD bENGT t OUS FILE NAME: bE COMMENTS TOOb FROM 10248-32~8 ~FORMAT SPECIFICATION LENGTHI 130 BYTES ENTRY DATUN SPECIFICATION 8EOCKSI ORS NAME TOOL UNIT I DEPT FT 2 GR BHC GAP! 3 DT BHC US/F USER DEFINKD OUTPUT ARRAY OUTPUT GR AT 2 OUTPUT DT AT 3 DEPTH MNEMONIC 10248.000 OR I0200.000 OR 0 6O 6O 52 32 0 0 4 1 68 VALUE MN 101.438 DT 0 95,688 DT 103.00,, ' :i ' : . ' - · - 42 676 -475:750 5500.000 5400.000 5300,000 5200.000 5100,000 5000.000 4900,000 4800.000 4700,000 DEPTH 4600,000 4500.000 4400.000 4300,000 4200.000 4100,000 4000,000 3900,000 3800,000 3700,000 RHOB RHOB GR {~HOB GR RHOB GR GR RHOB RHOB GR RHOB ,OR RH00 RHOB G~ RHOB GR RHOB GR flHOB Ga RHOB RHOB GR GR RHOB GR RHOB GR RHOB GR RHOB 2,293 ,000 6~.332 55 531 ! i 2:438 NRAT ' 402 61· 875~ '324 80.500 2,301 N O0 -0 00~ DRHO O0 OOl 000 3~.031 ' 037 2 ' 102 2,0'72 6'7,3.75 2 ~ 227 7 5' 0 2,289 76,000 CAb{: 2' i54 66.250 2'180 40,969 2' 0 125 N 52.156 2' 154 51,125: N 2,086 'DRH0 DRI N{ DRHO DRHG DRHO E -0 008 000 005 )00 -0 008 0oo 0.09 000 0 03 0 000 FCNb N PM NPH! FCNb NPHI FCNb NPH! FCNb rc b- NPH! NPHI NPHI- FCNb NPH! 475.250 40.869 559'000 29.248 702,000 38,330 576,500 36.768 593,000 44,531 482'250 50O 57,~.650 500 ~39 063 564 500 42 285 -488 000 MNEMONIC VAL{ NPH! 43.2i3 rCNb 432-000 NPH! 48-,242 429,500 NPH! 44,727 rCab '480~000 NPHI ~5,996 rCNb 4 2,500 NPH! -52,295 rCNb 340~750 Ne-HI 48.779 rCNL 457,500 FCNb 569,000 NPHI rCNb 38.037 '66~,000 -42,090 542,000 7500.000 7400,000 7300,000 7200,000 7100,000 7000,000 6900,000 6800,000 6700,000 6bO0,O00 DEPTH 6500,000 6400,000 6300,000 6200.000 6i00,000 6000.000 5900,000 5800,000 5700,000 5600,000 RHOB GR RNOB RHOB GR GR RHOB GR RHOB GR RHOB GR RHOB RHOB GR RHOB MNEMONIC GR RHOB GR RHOB GR RHOB GR RHOB OR RHOB GR RHOB GR RNOB OR RHOB GR RHOB GR -999 -999 76 2 76 2 76 2 76 438 2:285 76,438 2'285 '285 7~,43 76'438 i;!iCA~ii! 2,285 NRAT . 8 vAbu¢ MNE 76 438 76'438~ 2,285 76,438 CAbI 2,285 ,438 7~,285 N{ 76.438 CAb! 2 · 285 76.438 2.285 76 2 ,250 ~CAL! ;250 N{ 250 FCNL ,438 CAb! ;285 NRAT .438 Cibi 8~500 DRHO :- 0,007 NPHI 285 NRAT 3,438 NCNb 1737,000 rcNb ,438 ,289 { CAb! 8'5:00 DRHO 0.007 NPH! NRA~ 3;43B NCN~ i?)?'000 ~CN~ _ C~ )RHO 0 ~? NPHI rCN6 ,438 ,285 ,438 ,285 .438 7~,285 NRAT 76,438 CALI 8 8 NRAT CA 8 8 O0 rCNb NPH! rCNb MN~MO ~,! E DRHO 0 007 NCNb !RHO 500 10 0 25O -999:250 ,~55 , 50 41,455 475,250 41,455 475,250 4~ 455 47s: so 41,455 475,250 45 475, 4 455 ,250 NPHI -41~,455 rCNb' :475,250 NEMONI¢ VAbUE 4 ,455 ;250 4i,455 FCNG 475;250 7 NPH 4:.455 '2SO NPH! 41",455 000 rCNb 475.250 007 NPHI 41,455 000 FCNL 475.250 ~ 4~,455 25O Nb 47,,, NPH! .4i,455 rCNb 475,250 NPHI 41,455 FCNb 475.,250 NPHI 40.576 9500.000 9400,000 9300,000 9200,000 9100.000 9000,000 8900.000 8800,000 8700,000 8600,000 8500,000 DEPTH 8400oOO0 8300.000 8200.000 8100.000 8000,000 7900.000 7800,000 .7700,000 7600.000 GR RHOB RHOB RHOB RHOB GR RHOB GR RHOB GR RHOB GR GR .RHOB GR MNEMONIC GR RHOB RHOB GR RHOB 'GR RHOB GR gHOB GR RHOB GR 'RHO8 GR RI. lOB GR RHOB · 3~,313 CA DRHO ,242 NE 490:500 93.188 2~324 NR~ ~.i23 ~C.N~ i301..,000 FCNb 400*250 ?99.250 -999 250 999.250 '999'2501 '999,250 NR -999.250 -999,250 :999.2so 999,250 -999,~50 -999, ~0 -999.250 -999,250 NR '999. -999.250 NR :999.250 999,25~0 VAbUg -999.250 999' 999,250. -999:2501 -999,250~ -999,250 -999,250 -999 -999 -999 0 :999,250 999;2!50 :999.25C 999.250 :999. s N( · ,9! N( 'CNb -999. -999,250 "9'99 ;2'50 -999 · 250 "99 ,25~ "999,250 CNb -999.250 -99 N~H][ ,,999.250 ,250 ,250 .250 NPH! '999 NPH '99 '999,250 '"999,250 999,250 99.250 .250 ;250 5O -999.250 '250 NPH! ' "999.250 rCNb '999.250 NPH! -999.250 :FCNb "999 · 2 S 0 I '"999 Nb 4'999 250 250 250 2~0~ I CNb/FDC bOG FROM 10141-9335 DATA FORMA? SPECIFICATION bENGTHI )lO BYTES DATU M .SPECIFICATION NAME TOOb UNIT 1DEPT FT 2 GR tnb GAPI 4 DRHO 5 NPHI CNb PU 6 RHOB CNb G/C3 7 NRAT CNb C/CCpS 8 NCNb CNb 9 FCNb. CNb CPS BbOCKSl AP1 AP[ APl API F~E $~ZE SAM REP PROCESS ~NDfCATOR$ · , - 0 0 0 '0 0 4 i 68 ~2 31 32 0 0~4 42 28 t 0 0 4 1 42 44 0 0 0 4~ [ 68 ) 0 '0 4 1 68 42 ~2 42 42 USER DEFINED OUTPUT ARRAY OUTPUT GR AT OUTPUT CAbI AT OUTPUT DRHO AT OUTPUT NPHI AT OUTPUT RHO~ AT OUTPUT NRAT AT OUTPUT NCNL AT OUTPUT FCNL AT DEPTH 10248,000 10200,000 10100,000 10000.000 MN· 6 ? 8 9 EMON lC GR ,RHOB GR RHOB GR !RHOB RHOB 'R G. RHOB OR RHOB GR RHOB GR RHOB g900,O00 9800.000 9700,000 9600,000 MNEMONIC VAbUE ~MNEMONIC ~VAbUE V A b U g : 8~.OoO i~ 2 ' 350 MNEMONIC VAbUE 0 242 NPHI 30,957 000 rCNb ~43~,.000 84,563 2' 252 85,.563 2,340 NCN[ N( I, 957 000 ,000 4~ 2:98 ~ - NPHI- .42,5'78 000 rCNb 297,750 63',500 2 ,393 NR T 0 57 3t33 :~ 395 2,' 36 °ooo 6c~.342 NP'HI 26,172 FCNb -489,250 NPHI- 28,809 FCN'b 517,500 N~ I 857 5OO NPHI .07~~~ 5000.000 4900.000 4800.000 4700,000 4600.000 DEPTH MNEMONIC 4500,000 4400,000 4300,000 4200,000 4100,000 4000,000 ILD 3900,000 3800,000 IbP 3700,000 3625,000 IbD SUmmARY OF NUMBER OF LENGTH OF 6.926 ?, 621 6{,,594 '11,180 VALUE ' 9 06 000 ;R ~R G{ 62 ,,729 969 9.484 8,414 9, i56 8.008 9,086 bAST RECORD: 278 BYTES NEXT ;FILE NAME= EOF .FILE HEADER LENGTH: 62 · PREVIOUS FILE NAME= FILE COMMENTS 7900,000 7800,000 7700,000 7600,000 750 000 7400,000 7~00,000 7200,000 7100,000 7000,000 6900,000 6800,000 6700,000 6600,000 6500,000 6400,000 6300,000 6200,000 6100,000 6000.000 5900,000 5800,000 5700,000 5600,000 5500,000 5400,000 5300,000 5200.000 5100,000 MN 2,082 2,645 2.309 2,541 2 879 2,840 3,125 3,473 3.592 2,572 2.736 3.068 3,668 3,549 4,551 4,063 4.117 7,445 4.594 3,582 3,930 5,43O 7.012 6.277 9.484 23,781 9.563 7.945 7.6t7 MNEMON IbM IbM I~M 2.037 _fir 128. 000 2.596 :GR 12t.375 2- 252 GR g 7,500 2 -461 GR 91. 188 2,770 2.982 3,439 :3..566 2.496 2.646 2,973 3,449 4.I09 .7,691 4.238 3,402 zb~ 5.805 z~ 6,605 Ge IbM 5,984 IbM g 8 26 7 84O OR -91,3!3 GR . 92.688 OR 99,500 Ga 66.O00 GR 86,875 OR 82,000 GR 117.625 'GR 90,563 GR 98.500 GR 89,81] 86,063 GR 80,375 GR 87,563 GR 89,375 OR 74,.~38 GR 76'-: GR ;R GR GR GR 74 ? 0 5 ~6 86 875 67 06] 77 125 IPD DI~ 4 GR USER DgFINfD OUTPUT ~OUTPUT IbM AT OUTPUT G~ AT DEPTH t0248,000 i0200,000 iOZO0,O00 iO000,O00 9900,000 9800,000 9700,000 9600,000 9500,000 g400,000 9300,000 9200,000 glO0,O00 9000,000 8900,000 8800,000 8700,000 8600,000 8500,000 8400,000 8300,000 8200,000 8ZO0,O00 8000,000 OH~M OHNM GAPI OUTPU~ .ARRAY 2 MNEMONIC IbD ILD ILD IbD lbo ILO I[~D 0 0 0 '0 O. 4/ . t ? !2 4 7 31 32 0 0 4 -. VALUE MNEMONIC VALUE : 2.311 · IbM 2"~ 2t0 OR 2,500 IbM 2~547 '- ' ' ' 2,488 IbM 2,.593 .OR 9 .063 2,244 ~lb~ "2~7 ..~ -GR .- 97,250 2.252 lb~ 2'.,355 ::~-GR:; ~ 38'438 4'262 ibm 4-406~:, 3.389 -{~404~. GR: J _: :;83-125 4,750 :IbM ..4~840-::~'~; 'GR:...-. ~ ~'59140-6 2,879 'ibm - :' ~ I08'-i88 t.898 :. [b~ ; ::~t>~827. 1,412 , IbM -: ~:i::;~ 390: :.:-: "'-'::,~ i-12 ~06_{ 2,373 IbM - - ':2'~404 2.783 .~IbM ::2~'760 2.~5 [~ 2~-1.$2' ~L ~ ~GE ~" '-120'000': 2,777 ~ 2';865-~' 2,504 IbM ' 2'i45.:7 . G:R _125,~9:3:8 ~i63,8~5 4,480 lb~ :99:: 2,699 IbM :' 2:g527 :_ BIS VERSION lb,H01 80/03/20 LENGTH: 132 BYTES REEL NAMEI PBD COMP S~RVICE NAME~ EDIT REEL CONTIN[JATION NUMBER~ PREVIOUS TAPE HEADER bEN~TH~ i32 BYTES TAPE NAME: 56231 SERVICE NAME: EDIT TAPE iCONTINUATION NUMBER~ PREVIOUS TAPE NAME: COMMENTSt EOF FILE HEADER LENGTH: 62 BYTES FILE NAME,' EDiT ',.001 MAXIMUM PHYSICAL RECORD PREVIOUS FILE NAHE~' FILE COMMENTS O1 LENGTH~ 1024 BYTES DIb COMPANY TYPE 0 DATUM SPECIFICATION BbOCKS~ C-6 (31 i 11N'"lOE) NAME TOOL UNIT APl API API~. API FILE :~MI~!ESAM/REP 'PROCE&S INDiCAtORS