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194-168
Loepp. Victoria T (DOA) From: NSK Well Integrity Supv CPF1 and 2 <n1617@conocophillips.com> Sent: Wednesday, February 08, 2017 2:48 PM To: Loepp,Victoria T(DOA) Subject: RE: 1R-31 (PTD 194-168) Request for flow test with known TxIA communication Attachments: 1R-3190 day 110 plot jpg Follow Up Flag: Follow up Flag Status: Flagged Attached is a 90 day TIO plot. Brent Rogers/Kelly Lyons NSK Well Integrity Supervisor CPF 1 &2 ConocoPhillips Alaska, Inc. Desk Phone (907)659-7224 Cell Phone (907) 394-0402 SCANNED MAY re 0 2017 4WELLS TEAM ConoctiMalps From:Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Wednesday, February 08,2017 2:39 PM To: NSK Well Integrity Supv CPF1 and 2<n1617@conocophillips.com> Subject: [EXTERNAL]RE: 1R-31 (PTD 194-168) Request for flow test with known TxIA communication Please forward a TIO plot. Thanx, Victoria From: NSK Well Integrity Supv CPF1 and 2 [mailto:n1617@conocophillips.com] Sent:Wednesday, February 08, 2017 7:21 AM To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Cc:NSK Well Integrity Supv CPF1 and 2<n1617@conocophillips.com>;Senden, R.Tyler <R.Tyler.Senden@conocophillips.com>;Thomson,Stephanie<Stephanie.Thomson@conocophillips.com>; CPF1 Prod Engr<n1269@conocophillips.com> Subject: 1R-31(PTD 194-168) Request for flow test with known TxIA communication Victoria, Gas lifted producer 1R-31(PTD 194-168)was identified to have TxIA communication. A leak detect log found the tubing leak at 12,090'. While attempting to patch the tubing leak,one of the patch packers moved downhole and became stuck. Attempts to recover the packer have been unsuccessful and the well has remained shut in. A recent SBHP survey in this well indicates a significant improvement from previous surveys,which is assumed to be due to recent improved injection support in the area. Due to this change in SBHP, it is unlikely that previous well tests accurately represent the well's current capacity.A flow test is requested to gather more representative data on this well's performance,which will be used to evaluate a possible rig workover. 1 • ConocoPhillips is requesting a 30-day flow test period to allow time for the wellflush and to collect at least four steady well tests,which is about one each week as we rotate wells through test in our normal testing schedule. Attached is a wellbore schematic for reference. The well has been shut in since 04/25/16 so a TIO plot has not been attached but is available if needed. Please advise if the flow test acceptable. Please let me know if you have any questions or would like further information. Brent Rogers/ Kelly Lyons NSK Well Integrity Supervisor CPF 1 &2 ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Cell Phone (907) 394-0402 AWELLS TEAM conoc&himps 2 i • : . : • • ;i . . . : : : CO = . 1 II - — : ti' T- - - : : : c • - . . . f. F= = : : . : : c — : :' • : : . . ct a_ . 1 . ti . I if- �•ti C.0 KUP PROD 1R-31 ConocoPhillips 04 1111 Well Attributes Max Angle&MD TD Arly��1 I.1,, Wellbore APW WI Field Name Wellbore Statue Teel 1') MD(ttKB) Ant Btm(6KB) 0rlocaMMps 500292253800 KUPARUK RIVER UNIT PROD 68-91 3,070.47 12,647.0 Comment '128(ppm) Date Annotation End Date KB-Grd(6) -Rig Release Date 1R-31,42620165:22,52 PM SSSV:NIPPLE 50 7/31/2015 Last WO: 3/7/1995 40.99 1/25/1995 Vertical schematic(actual) Annotation Depth(6KB) End Date Annotation Last Mod By End Date Last Tag:SLM 12,383.0 5/5/2012 Rev Reason:SET CAT SV,GLV C/O pproven 4/28/2016 s• _ i[ Casing Strings 1 = Casing Description CONDUCTOR DD(In) ID(In) Top MKS) Set Depth(NKR) Set Depth(TVO)... WilLen(I...Grade Top Thread 16 15.062 40.0 121.0 121.0 62.58 I1,10 WELDED HANGER,366-r Casing Description ( ) ( ) p(NKR) Depth( ) Depth(TVD)... Wt1Lan(I...Grade Top Thread .',i1 g prion OD in ID In To ttKB Set ttKB Set SURFACE 95/8 8.835 38.0 6,944.0 4,024.4 40.00 L-80 BTC Casing Description OD(in) ID(In) Top MKS) Set Depth(608) Set Depth(ND)...'Wt/Len(I...Grade Top Thread decd wa____ ____Meaulr,vdeko „mom„ .,, ,r,,,, ..+:PRODUCTION 7 6.276 37.1 12,637.0 6890.7 26.00 L-80 BTC-MOD Tubing Strings CONDUCTOR;40.0.121.0 a Tubing Description String Ma...ID(in) Tp(ROB) Set Depth M.Set Depth(TVD)(...Wt(lb/ft) Grade Top Connection TUBING 31/2 2.992 36.6 12.133.8 6,498.8 9.30 L-80 ABM-EUE Completion Details NIPPLE 110.1 l an Nominal ID Top(611B) Top(TVD)(ROB) Top incl(•) hem Des Com (m) 36.6 36.6 0.07 HANGER FMC GEN IV TUBING HANGER 3.500 510.1 510.0 3.10 NIPPLE CAMCO DS LANDING NIPPLE 2.812 12,095.3 6,469.1 39.61 NIPPLE CAMCO W-1 SELECTIVE LANDING NIPPLE 2.812 GAS LIFT:3,34(2 12,103.4 6475.3 39.59 SEAL ASSY BAKER KBH-22 ANCHOR SEAL ASSEMBLY 3.000 12,104.3 6,476.0 39.58 PACKER BAKER SAB-3 PERMANENT PACKER 3.250 12,109.3 6,479.8 39.57 MILL BAKER MILLOUT EXTENSION 3,750 12,123.5 6,490.8 39.54 NIPPLE OTS XN LANDING NIPPLE 2.813"ID,w2.75 NO GO 2.750 12,133.0 6,498.2 39.51 SOS CAMCO MULESHOE SHEAR OUT SUB 2.992 GAS LIFT.6,838.8 4 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl Tp(61113) (6KB) I.) Des Com Run Date ID(In) (2,124.0 8,491.2 39.53 VALVE 2.81"X6/CAT(44'OAL) 4/25/2016 SURFACE 380-6 5446 Perforations&Slots Shot Dene Top(TVD) Stet(TVD) (shots" Tp(6KB) Btm(6KB) (ttKB) OMB) Zone Date t) Type Com GAS LIFT9537.8 k• 12.342.0 12,372.0 6,660.0' 6,683.3 A-3,1R31 4117/1995 4.0 (PERF 2 1/8 Enenet:180 deg. .. s ph:Oriented(.4-)90 deg cwaCCW 12.396.0 12,416.0 6,702.0 6,717.6 A-2,1R-31 7/16/2011 6.0 (PERF '2.5'Millenium HMX Guns,60 Deg Stimulations&Treatments Min Tp Max Btm GAS LIFT-11,1186-1 Depth Depth Top(TOD) Btm(TVD) GAS LIFT-11,1106 (MB) (MB) MOB) (6KB) Type Date Coin 12.342.0 12,3720 6,660.0 6,683.3 ACID SQUEEZE '9/302004 Treated w/7 BBLS NA4CL,13 BBLS 7.5%HCL Solution.28 BBLS 11957(OCA)1.2 BPM per program Mandrel Inserts St op On Top(TVD) Valve Latch Port Sire TRO Run GAS LIFT.12,049.8 N Tp(6KB) (ttKB) Maas Model OD(In) Sem type Type (In) (pal) Run Data Com 1 3,341.3 2,496.0 CAMCO MMM 1 12 GAS LIFT GLV RK 0.188 1,339.0 4/26/2016 2 6,638.8 3,899.1 CAMCO MMM 1 12 GAS LIFT GLV RK 0.188 1,307.0 42012016 3 9,337.8 5,004.1 CAMCO MMM 1 12 GAS LIFT OV RK 0.188 0.0 4262016 4 11,118.6 5,799.) CAMCO MMM 1 12 GAS LIFT DMY RK 0.000 0.0 9/26/2004 NIPPLE:12,005.3 5 12,049.8 6,434.0 CAMCO MMM 1 12'GAS LIFT DMY RK 0.000 0.0 9/26/2004 Notes:General&Safety 54 End Date Annotation 10/20/2010 NOTE:View Schematic w/Alaska Schematic9.0 SEAL ASSY;12,1034 PACKER;12,101.3 MILL:12,108 3 NIPPLE.12 1235 VALVE 12,124.0 SOS.12,133.0 (PERF;12 312-0-12,372.0 ACID SQUEEZE,12.912.0 IPEiF;12.366.0-12,116.0-. PRODUCTION:37.1-12637.0 L9 ID - o a) a a¢ � v 1 Su Cr., > W u � to U W x UC a s �oZ O a C/ O a) cd N a) v o 6 - 1 _1 z . . . . . . r r r r Op O H T a 9 OO. (° `0 D V O_ v v > 0 @ C41, O C 'O �/� W co >- a Q N ~ ❑ a� C -p a' v� O ..t W O O D t0 O O O t0 t0 O 1a O aJ E m J Q 0 r r y, 0O 4-4, N N _ )-d 0 a it C to Iv CC iC CO m as ^ s c c c rr F J a CCco 0 6 to toz ~ O O ct a NN M M Nr C , a1 Q a) ili 0 -0 E 0 >, cc 1— C1) c., L., J-, CU > -0 = a0 0 0 CI 0 00000 ") -I J J J J J J J J J C .1-,a W W W W W W W W W W 0 c its O O I- LL LL U. LL LL LL LL U. LL LL .L aJE 'O C O Q J J J J J J J J J J • O v co a a a Q a Q Q Q a a G Q z z z z z z z z z z uv o O @ LL LL U. LL U. U. LL LL U. LL :. u CO "Y. _ a1 p > a-+ N c W C E aj O O 0 C O _0 C a! G G O az F "CI 019 C C r >• a a LL A LL LL LL LL Q CU -C gO _ L.- 0 G O � Vto _ ❑ Q' 1-1md a a J CL ddda3 w O E oa U i')' N 1 ) (� 803 , Ck co 469 gIC aa0 �, es I,+I lbw' ..... 0 T T c SCS as .^'. 00 V d >J O J O >J J O J 8 J J co cc w t ci'Vik/11 CI d 2cc Lu ,> LL 4! 4 E ce ❑ a, Y Y Y .)0 -Y Y Y W_ - O. = _O 7 7 0 7 7 7 a) v IL Y ¢ > o. CO CO O. o_ CO �� c N o 3 O c 3 7 3 3 3 2 0 ® 0 Y U Y Y Y Y Y Y a K X N 0 W CC 0) 0 CO .3. f` If) 03 M OD u GD Q O CO M N M M N O 0) 00 lad 0 M 0 0 0 0 O 0 0 0 fd O O O O O O O O co 0 0 0 — MINS 0cM 0 0 0 0 0 0 0 0 0 0as u) Y U v U U to ❑ a ❑ E e, r� V cc tui 0 0 0 0 Y >- >- o bpi v W ❑ U ❑ ❑ ❑ ❑ ❑ U U U 0 ® m c ill — 0 - 0 0 0 0 0 0 0 0 0 rcsu F.ifi cD 0 co 0 0 0 0 0 0 0 0 '^ 1` t0 O)tO LO 00 00 00 0) U) 0 C M •iti I-- M tO If) )f) If) tO M N .7 � N 0 M N 0 N N N N 0 u N N N N N N N N N N N F.' M 0) O) M 0) O) O 0) O) O) C a 0 N N 0 N N N N N N Q) 0 O 0 O O 0 O OU O O O O O O O O O O I() In 1n t) N in t() in In In F+ O a ) D ce co c 4-4 a a) u C CU ad CID '+' Y — rj u Q '- 2 N J 0 0 Q N- 0 r- co a 7 d 'p e-1 Q. O N M C-) M 0) N r 0 ,+~c_' E Q/ y = re N E n —10 '- u- 0 r X 0 c z d fL) a ri ,cc � N Y ILI U V N C c co nas XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE RESCAN Complete Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by~~~~ev~ed~ TO RE-SCAN Dianna Vincent Nathan Lowell Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 28, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 1R-31 Run Date: 7/16/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1R -31 Digital Data in LAS format, Digital Log Image file 1490 1 CD Rom 50- 029 - 22538 -00 a i tit r PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: ) A 11 Signed: out--)6? STATE OF ALASKA M ALASKA AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Rug Perforations r Stimulate r Other "`" Alter Casing r' Pull Tubing E Perforate New Pool r Waiver fl Time Extension r Change Approved Program r Operat. Shutdown r Perforate 1' Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory r - "' 194 -168 3. Address: 6. API Number: Stratigraphic f Service r P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 22538 -00 'OO 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25628 " — 1R-31 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 12647 feet Plugs (measured) None true vertical 6899 feet Junk (measured) None Effective Depth measured 12554 feet Packer (measured) 12104 true vertical 6823 feet (true vertucal) 6476 Casing Length Size MD TVD Burst Collapse CONDUCTOR 121 16 121 121 SURFACE 6944 9.625 6944 4024' PRODUCTION 12600 7 12637 6891 $ %14 AUG i 201 Perforation depth: Measured depth: 12342'- 12372', 12396'- 12416' RECEIVED True Vertical Depth: 6660'- 6683', 6702' -6718' AUG 1 6 2011 Tubing (size, grade, MD, and ND) 3.5, L -80, 12134 MD, 6499 ND lira 1111 & Gas Cow Commission Anchorage Packers & SSSV (type, MD, and ND) PACKER - BAKER 'SAB -3' @ 12104 MD and 6476 TVD Nipple - CAMCO 'DS' LANDING NIPPLE @ 510 MD and 510 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 179 1182 302 -- 157 Subsequent to operation 497 2411 424 -- 168 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r .. Service r Stratigraphic r 15. Well Status after work: Oil (W Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ I`" WAG r GINJ 1 SUSP r SPLUG J` 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact John Peirce as 265 -6471 Printed Name John Peirce Title Wells Engineer Signature / Phone: 265 -6471 Date e it /► /i i ......w 4 RBIMS AUG 17 2011 Form 10-404 Revised 10/2010 Submit Original Only 1R-31 Well Event Summary DATE SUMMARY • 7/7/11 FCO W /N2, CLEANED OUT TO 1 , 15 CTMD, FP, READY FOR E -LINE 7/8/11 TAGGED @ 12432' SLM / 12455' RKB, SAMPLE BAILER FULL OF FRAC SAND, DRIFTED TBG W/ 22' OF 2.64" DUMMY GUN TO @ 12427' SLM. COMPLETE. 7/16/11 PERFORATE A -2 INTERVAL: 12,396'- 12,416' WITH 2 -1/2" PROSPECTOR HMX GUNS, 6SPF, 60 DEG. LRS PUMP DOWN ASSIST (DIESEL) TO GET BELOW 8000'. WELL ON VAC PRIOR TO SHOT, 0 PSI WH P. �;.. ,;: KUP • 1 R -31 COnocoPhillips °' well Attributes _. __ -- Max Angle & MD TD AiaSi(cl InC W Ilbore API/UWI Field Name Well Status Inc! () MD (RKB) Act Bbn (fIKB) L_orxx#'h11klr. 500292253800 [Field RIVER UNIT I PROD 68. I 3,070 47 12,647.0 - Comment H2S (ppm) Date Annotation !End Date KESGrd (fl) Rig Release Date "' SSSV NIPPLE 20 8/6/2009 Last WO � 3/7/1995 4099 1/25/1995 Weu 08n 1-31, &16/1011 9 85 57 AM - - Sc R rn lin Acwal Annol I Depth (flKB) End Data Annotation (Last Mod By End Date Last Tag: SLM 12,432.0 7/8/2011 Rev Reason: TAG, PERFS ninam 8/16/2011 Casing Strings String OD String ID Set Depth Set Depth (TVD) String Wt String Casing Deuteron (in)_ (in) Top (PoCB) (flKB) (18KB) (6sm) Grade String Top Thnt CONDUCTOR 16 15.062 0.0 121.0 121.0 62.58 6140 _ SURFACE 95/8 8.765 0.0 6,944.0 4,023.9 40.00 L-80 CONDUCTOR, PRODUCTION (QC) 7 6.276 37.1 12,637.0 6,890.7 26.00 L-80 BTC -MOD 121 __. .._..___ -. Tubing Strings = ....r. ; s. r t,: ''w Strin g 9 P ( OD String ID Set Depth Set Depth (TVD) String Wt String •JKWW NIPPLE. 510 - � Tubing Description (n) (in) Top (flKB) (808) (1108 ad ) (Ibs/f1) Grade String Top Th. T - i„.11 . .. 3 1/2 2.992 0 0 12 134.0 6, 499. 5 9.30 L-80 ABM EUE 'Other In Hole (All Jewelry: Tubing Run & Retrievable, Fish, etc.)". 1 Top Depth (TVD) Top Ind' Top (flKB) (flKB) P) Description Comment Run Date ID (In) 510 509.9 3.10 NIPPLE Camco 'DS' Landing 3/7/1995 2.812 GAS LIFT, - 3,341 2,496.4 65.72 GAS LIFT CAMCO /MMM /1.5/GLV/RK/.188/1293/ Comment STA 1 9/27/2004 2.922 3 6,639 3,899.1 64.87 GAS LIFT CAMCO /MMM /1.5 /GLV/RK/.188/1294/ Comment STA 2 9/27/2004 2.922 I 9,338 5,004.6 64.73 GAS LIFT CAMCO /MMM /1.5 /OV/RK/.25 // Comment: STA 3 9/27/2004 2.922 11,119 5,799.8 56.40 GAS LIFT CAMCO /MMM /1.5IDMYIRK/ / /Comment STA 4 9/26/2004 2.922 12,050 6,435.5 39.85 GAS LIFT CAMCO /MMM /1.S/DMY/RK/U Comment STA 5 9/26/2004 2.922 12,095 6,469.8 39.71 NIPPLE Camco 'W - Selective Landing 3/7 /1995 2.812 12,104 6,476.6 39.68 PACKER Baker'SAB -3' 3/7/1995 3.250 GAS LIFT. 12,124 6,491.9 39.62 NIPPLE Otis 'X6/' Landing Nipple NO GO 3/7/1995 2.750 6639 12,133 6,498.8 39.59 SOS Camco Muleshoe 3/7/1995 2.992 12,134 6,499.5 39.59 TTL 3.5 Tubing Tail 3/7/1995 2.992 Perforations & Slots SURFACE, I . 6,944 Shot Top (TVD) Btm (TVD) Dena Top (flKB) Btu OMB) MB) (61(8) Zona Date (sh ... Comment 12,342 12,372 6,660.0 6,683.4 A - 3, 1R 4/17/1995 4.0 IPERF 2 1/8 Enerjet; 180 deg. ph; Oriented GAS LIFT, lit- (II-) 90 deg CW & CCW 9,339 _- -_. -- - -.._. __ -__ _. ;`. 12 396 124 6.702.2 6,717.8 A -2 1R -31 7/16/2011 6.0 IPERF 2. 5" Millenium HMX Guns, 60 Deg !Stimulations & Treatments Bottom Min Top Max Btm Top Depth Depth Depth Depth (TVD) (TVD) (flKB) (flK8) (flKB) (RKBI Type Date Comment 12,342.0 12,372.0 6,660.0 6,683.4 ACID SQUEEZE 9/30/2004 Treated w/7 BBLS NA4CL, 13 BBLS 7.5% HCL GAS LIFT, _ _ Solution, 28 BBLS H957 (OCA) 1.2 BPM per program Notes: General & Safff End Date Annotation 10/20/2010 NOTE: View Schematic w/ Alaska Schematic9 0 GAS IIfI _ [050 NIPPLE, 12,095 • A - .- ..._ PACKER, 4 '" r �F 12,106 y • • NIPPLE, 12,124 SOS, 12,133 Sim:. TR., 12,134 , ACID SQUEEZE, 1 ERF, -_' PRF 12,302- 12,372 _ IPERF, 12,396 - 12,416 PRODUCTION (0C). 12,6371 ■ TD, 12,647 ConocoPhillips a~ P.0. BOX 100360 ANCHORAGE, ALASKA 99510-0360----- --- February 1, 2010 Mr. Dan Seamount Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 F~E~EIVED MAR 4 5 2010 Alaska 0~ & $as Carts. Comr~ssian Anchorage ~'~ X631 1 ~:~, ~. Dear Mr. Dan Seamount: Enclosed please fmd 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 cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped December 5~`, 2009. The corrosion inhibitor/sealant was pumped December 22°d, 25~`, 26~` & 28~', 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. 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 3/1/2010 1G.1L ~ 1R Pad 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 1 G-17 50029229450000 1990620 SF n/a 17" n/a .7.65 12/26/2009 1L-01 50029211960000 1841730 52' 7.7 31" 12/5/2009 10.15 12/22/2009 1 L-02 50029211930000 1841700 45' 5.7 35" 12/5/2009 10.15 12/22/2009 1 L-04 50029211790000 1841540 40' 3.9 24" 12/5/2009 5.8 12/22/2009 1 L-06 50029211640000 1841330 2'5" n/a 2'5" - n/a 7.22 12/26/2009 1 L-08 50029211750000 1841500 34' 3.7 40" 12/5/2009 10.2 12/26/2009 1L-09 50029220250000 1900340 11" n/a 11" n/a 1.27 12/26/2009 1 L-11 50029220340000 1900450 16" n/a 17" n/a 2.25 12/25/2009 1 L-12 50029220330000 1900440 7" n/a 15" n/a 3.4 12/25/2009 1 L-13 50029221500000 1910420 13' 2.2 27" 12/5/2009 5.52 12/26/2009 1 L-17 50029221510000 1910430 26' 4.0 18" 12/5/2009 9.35 12/26/2009 1 L-19 50029220490000 1900610 9' 2.5 19" 12/5/2009 4.25 12/25/2009 1 L=23 50029221670000 1910620 SF n/a 17" n/a 2.12 12/26/2009 1 L-26A 50029221730100 2000150 SF n/a 17" n/a 2.97 12/25/2009 1 R-14 50029213860000 1851510 SF n/a 29" n/a 5.95 12/28/2009 1 R-31 50029225380000 1941680 6" n/a 24" n/a 7.22 12/28/2009 1 R-32 50029225230000 1941460 SF n/a 24" n/a 5.95 12/28/2009 1 R-33 50029225290000 1941560 SF n/a 24" n/a 4.67 12/28/2009 STATE OF ALASKA ALASKA all AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon D RepairWell D Plug Perforations D Stimulate [2] Other D Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program D Operat. ShutdownD Perforate D Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development - [2] Exploratory D 194-168/ 3. Address: Stratigraphic D SelViee D 6. API Number: P. O. Box 100360, Anchorage, Alaska 50-029-22538-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 86' 1 R-31 8. Property Designation: 10. FieldlPool(s): ADL 25628, ALK 2561 Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 12647' feet true vertical 6899' feet Plugs (measured) Effective Depth measured 12501' feet Junk (measured) true vertical 6784' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 121' 16" 121' 121' SUR. CASING 6858' 9-5/8" 6944' 4025' PROD. CASING 12551' 7" 12637' 6891' Perforation depth: Measured depth: 12342'-12372' RECEIVED true vertical depth: 6660'-6684' OCT 2 1 2004 Tubing (size, grade, and measured depth) 3-1/2" , L-80, 12134' MD. Alaska Oil & Gas COntL ComrnissÎCm Anchorage Packers & SSSV (type & measured depth) pkr= BAKER 'SAB-3' pkr= 12104' SSSV= Cameo 'OS' @ 510' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 12342'-12372' Treatment descriptions including volumes used and final pressure: 7 bbls Na4CI, 13 bbls 7.5% HCI, 28 bbls H957 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubinn Pressure Prior to well operation 546 729 415 -- 226 Subsequent to operation 630 724 568 -- 234 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run - Exploratory D Development [2] Service D Daily Report of Well Operations _X 16. Well Status after proposed work: Oil [2] GasD WAGD GINJD WINJD WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Mike Mooney @ 263-4574 Printed Name Mi¡'MoOney Title Wells Group Team leader 9f/I.O¡{;4 Signature M .p(Yj Phone Date p, h'nA~/~D~~2ß~4ßI2 - Form 10-404 Revised 04/2004 ORIGINAL R~5 ~nlY 1 R-31 Well Events Summary Date Summary 08/18/04 RAN GR/CCl FOR DEPTH DETERMINATION: TAGGED BOTTOM AT 12428' -- RAN PST TOOL AND STIMULATED A-3 PERFS 12342' -12372' 09/30104 PUMPED 3.5 BBlS 15% HCl "PICKLING" SOLUTION TO PREP COIL. TREATED PERFS FROM 12,342'-12,372' W/7 BBlS NA4Cl, 13 BBlS 7.5% HCl SOLUTION, 28 BBlS H957 (OCA), @ 1.2 BPM,650 PSI PER PROGRAM. PTS ON LOCo PERFORMING POST-ACID FlOWBACK---ONGOING. [Other Stim] NIP (510-511, OD:3.500) Gas Lift andrelNalve 1 (3341-3342, Gas Lift andrelNalve 2 (6639-6640, Gas Lift andrelNalve 3 (9338-9339, Gas Lift ldreliDummy Valve 4 1119-11120, OD:6.018) Gas Lift ldrel/Dummy Valve 5 2050-12051, OD:6.018) NIP 2095-12096, OD:3.500) PKR 2104-12105, OD:6.156) NIP 2124-12125, OD:3.500} TUBING (0-12134, OD:3.500, ID:2.992) 50S 2133-12134, OD:3.500) ACID SQUEEZE 2342-12372) Perf 2342-12372) ConocoPhillipS Alaska, Inc. KRU RefL Size To 16.000 0 9.625 0 7.000 0 Size 3.500 Interval TVD Zone 12342 - 12372 6660 - 6684 A-3 1 R-31 Last U date: TVD 121 4025 12637 Date 4/1711995 Man Type VMfr V Type VOD latch Port GLV 1.5 RK 0.188 GLV 1.5 RK 0.188 OV 1.5 RK 0.250 OMY 1.5 RK 0.000 OMY 1.5 RK 0.000 Descri tion Cameo 'OS' Landin Cameo W-1' Selective Landin Baker 'SAB-3' Otis 'XN' Landin Ni Ie NO GO Cameo Muleshoe 3.5 Tubin Tail Wt 62.58 40.00 26.00 Grade H-40 L-80 L-80 Comment 2 1/8 Enerjet; 180 deg. ph; Oriented (+/-) 90 deg CW & CCW TRO Date Run 1294 9/27/2004 1294 9/27/2004 0 9/27/2004 0 9/26/2004 0 9/26/2004 Thread Vlv Cmnt ID 2.812 2.812 3.250 2.750 2.992 2.992 Mike Mooney Wells Group Team Leader Drilling & Wells Conoc~ ill i ps P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 October 19, 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ¡th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for 1 R-31 (APD # 194-168) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent stimulation operations on the Kuparuk well 1 R-31. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, 1d~ Wells Group Team Leader CPAI Drilling and Wells MM/skad RECEIVED OCT 2 1 2004 Alaska Oil & Gas Cons. Commission Anchorage ORIGINAL ON OP- BEFORE 9 ~ i 6 8 ,"... D F,: ,/' K :i: i',d. A L ~ 6 9 0 0 i x 6 0 0 I 0 .,. '.'; / i '? / APe dr'y d'¥tch samples i-'"equ:i'r'ed? yes ~t'~d r'.ece-Yved'..~' ',:,'~ Was -!:he we'J'J cor'od? yes no AnaJys'is & descr"-i'p~.:'i'oi'~ r'-ece'i'ved'? yes no A r' e WOi i 'Ys 'i'n ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 5, 1995 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1R-3 l(Permit No. 94-168) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the recent operations on KRU 1R- 31. Sincerely, M. Zanghi Kuparuk Drillsite Development Supervisor MZ/skad A~as~a 0it & Gas Cons. Commission Anch0rr STATE OF ALASKA AL~,SKA OIL AND GAS CONSERVATION COM~v,,,JSION /% WELL COMPLETION OR RECOMPLETION REPORT N-p, LOG 1 Status of Well Classificatio; of" OIL ~] GAS ~ SUSPENDED [~] ABANDONED [] SERVICE ['~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 94-168 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 i" :.'~ 7.-: :::: :-~- ": 50-029-22538 4 Location of well at surface i ...... "i~:..-~ .... ~- 9 Unit or Lease Name ~Z_~_~__~ ! Kuparuk River Unit 473' FSL, 215' FEL, Sec. 18, T12N, R10E, UM ~. -~' ~' I ~J~'~"JJ~ ~ 10 Well Number At Top Producing Interval ! ~;,E~:~{_:!; ~ At Total Depth ............... ' ..... ' ~?~.~i. 11 Field and Pool 752' FNL, 1666' FWL, Sec. 7, T12N, RIOE, UM KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Serial No. RKB 86' 44.8' PadI ADL 25628 ALK 2561 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 116 No. of Completions 14-Jan-95 23-Jan-95 3/8/1995 (Comp) NA feet MSLJ 1 12647' MD & 6899' TVD 12554' MD & 6823' TVD YES ~ NO ~ feet MD 22 Type Electric or Other Logs Run GR/CDR/DWOB(MEL) 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE VV'I- GRADE TOP BTM HOLE SIZE CE. MENT REC_,ORD 16. 62.5# H-40 surf 121' 24" 210 SX ASl Lead 9.625 40# L-80 surf 6944' 12.25" 1480 sxs AS III Lead, 710 sx Class G Tail 7. 26# L-80 surf 12637' 8.5" 300 sxs Class G tail 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 IMD) 3-~/2", 9.3#, L-80 12134' 12104' 4 Sp! 1 80° phasing 12342' - 12372' MD (6660' - 6684' TVD) 26 ACID, FRACTURE, CEMENT SQUEEZE, ETD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12342'-12372' 8.5 Mlbs 20/40 153.1 Mlbs 12/18 & 17.5 Mlbs 10/14 Mesh ceramic proppant 27 PRODUCTION TEST Date First Production Method of Operation (Rowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO I TEST PERIOD FIowTubing Casing Pressure CALCULATED 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 orwater. Submit core chips. RECEIVED ,;UN -7 1995 Alaska 0il & Gas Cons. Commission Anchorc Form 10-407 Submit in duplicate Rev, 7-1-80 CONTINUED ON REVE. RSESIDE 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 C 1 21 47 6510 Base Kuparuk C 121 99 6550 Top Kuparuk A 1 2319 6642 Base Kuparuk A 1 24 79 6767 RF. CEIYED ~ i Ala. ska 0fi & Gas Cons. Commission l~nchor: . :- 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowlege. 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 Date: 05/30/95 Page: 1 ARCO Alaska Inc. DAILY DRILLING REPORT WELL:iR-31 RIG:PARKER 245 WI: 55% SECURITY:2 WELLID: AK8039 AFE: AK8039 TYPE:DEV AFE EST:$ 1801M/ 1459M AREA/CNTY:NORTH SLOPE STATE:AK API NUMBER:50-029-22538 FIELD: KUPARUK RIVER SPUD:01/14/95 START COMP: FINAL: 01/15/95 (1) TD: 1190' (1190) SUPV:JT 01/16/95 ( 2) TD: 5250' (4060) SUPV: JT 01/17/95 ( 3) TD: 6887'(1637) SUPV:JT 01/18/95 (4) TD: 6955'( 68) SUPV:JT 01/19/95 (5) TD: 7940'(985) SUPV:JT 01/20/95 ( 6) TD:ll008' (3068) SUPV: RLM 01/21/95 ( 7) TD:11795' (787) SUPV:RLM MW: 9.2 PV/YP: 21/24 APIWL: 10.8 DRLG SURFACE HOLE Move rig f/1R-34 t/1R-31. Spud well and drill f/121' t/l190' DAILY:S89,840 CUM:$89,840 ETD:SO EFC:$1,890,540 MW: 10.0 PV/YP: 25/28 APIWL: 11.2 DRILLING SURFACE HOLE Move rig f/1R-34 t/1R-31. Spud well and drill f/121' DAILY:S79,913 CUM:$169,753 ETD:SO EFC:$1,970,453 MW: 10.1 PV/YP: 27/26 APIWL: 11.0 DRLG SURFACE HOLE DRLG F/5250' T/5928'. CBU. PUMP PILL. BIT TRIP. HOLE TIGHT F/2510' T/1855'. LD DOT SUB. DRLD F/5928' T/6887'. DAILY:S86,773 CUM:$256,526 ETD:SO EFC:$2,057,226 MW: 10.1 PV/YP: 24/16 APIWL: 11.8 NIPPLE DOWN DIVERTER Drill from 6887 to 6948'. adt=0.4. CBU. Short trip to 5900'. Drill to 6955'. CBU. POOH, lay down BHA for inspection. Rig up to run casing. Held pre-job safety meeting. Rig up Tam packer (90 min.) 41 min. to m/u pup. run 9.625" casing, taking wt at 1890'. circ. at 1890'. Ran 9.625" casing to 6944'. Broke circ. at 4190'. Lay down Tam packer and blow down top drive. Circ. and condition for cement job. Cement casing, lost returns 242 bbls. into displacement. DAILY:S190,842 CUM:$447,368 ETD:SO EFC:$2,248,068 MW: 8.7 PV/YP: 4/ 3 APIWL: 17.2 DRILLING Pumped 150 sx AS 3, had 13.8 ppg cmt returns to surface. CIP @ 0812 hrs. 1/18/95. Nipple up 13 5/8" BOPE. Test. Witness of test waived by AOGCC representative. DAILY:S135,598 CUM:$582,966 ETD:SO EFC:$2,383,666 MW: 9.1 PV/YP: 14/13 APIWL: 7.8 DRILLING DIRECTIONAL DRILL 8.5" HOLE FROM 7940' TO 11008' DAILY:S81,003 CUM:$663,969 ETD:SO EFC:$2,464,669 MW: 10.9 PV/YP: 19/18 APIWL: 5.2 POOH DIRECTIONAL DRILL 8.5" HOLE FROM 11008' TO 11795'. CBU. POSSIBLE TURBINE FAILURE. POOH ~F~$2,570,512 DAILY: $105,843 CUM: $769,812 ETD:SO R ~IV~D Alaska Oil a Bas Cons. Commission Anchor: Date:05/30/95 Page: 2 01/22/95 (8) TD:12163' (368) SUPV: RLM 01/23/95 (9) TD:12440' (277) SUPV:RLM 01/24/95 (10) TD:12647' (207) SUPV:RLM 01/25/95 (11) TD'12647' ( 0) SUPV:JT 01/26/95 (12) TD:12647' ( 0) SUPV: JT ARCO Alaska Inc. DAILY DRILLING REPORT MW: 10.9 PV/YP: 26/26 APIWL: 4.8 TRIP FOR WASHOUT. DIRECTIONAL DRILL 8.5" HOLE FROM 11795' TO 12163'. CHECK SURFACE SYSTEM FOR WASHOUT AND MONITOR WELL. DAILY:S77,477 CUM:$847,289 ETD:SO EFC:$2,647,989 MW: 10.9 PV/YP: 26/20 APIWL: 4.0 DRILLING POOH SLOW LOOKING FOR WASHOUT. DIRECTIONAL DRILL 8.5" HOLE FROM 12163' TO 12414'. BRAKE BAND BROKE. RIG DOWN TIME. DIRECTIONAL DRILL 8.5" HOLE FROM 12414' TO 12440'. DAILY:S75,441 CUM:$922,730 ETD:SO EFC:$2,723,430 MW: 10.9 PV/YP: 24/19 APIWL: 4.2 RUNNING 7" CASING Directional drill 8.5" hole from 12440' to 12647. Run 7" casing to 5200'. DAILY:S76,278 CUM:$999,008 ETD:SO EFC:$2,799,708 MW: 10.9 PV/YP: 28/22 APIWL: 3.8 LDDP, PREPARE TO MOVE Run and cement 7" production casing at 12637' Cement casing with 60 bbls Class G cement, displace same, did not bump plug. Nipple down BOPE, Inject 300 bbls water and 70 bbls diesel down annulus. Lay down BHA for inspection, lay down drill pipe and prepare to move to 2Z pad. DAILY:S226,496 CUM:$1,225,504 ETD:SO EFC:$3,026,204 MW: 0.0 PV/YP: 0/ 0 RIG RELEASED, WOW LDDP. Phase 3 weather conditions; WOW. DAILY:S79,289 CUM:$1,304,793 ETD:SO APIWL: 0.0 EFC: $3,105,493 RECEIVED ,.JUN 7 i or. Alaska Oil & ~as Cons. Commission Anchor; Date: 05/30/95 Page: 3 ARCO Alaska Inc. DAILY DRILLING REPORT REMEDIAL AND COMPLETION OPERATIONS WELL: WELLID: AK8039 AREA/CNTY: FIELD: SPUD: RIG:NORDIC WI: 0% SECURITY:0 AFE: AK8039' TYPE:DEV AFE EST:$ 1801M/ 1459M STATE: API NUMBER: START COMP: FINAL: O3/O4/95 (13) DIESE TD:12647' PB:12554' SUPV:DB/CF 03/05/95 (14) TD:12647' PB:12554' SUPV:DB 03/06/95 (15) TD:12647' PB:12576' SUPV:DB 03/07/95 (16) TD:12647' PB:12576' SUPV:DB 03/08/95 (17) TD:12647' PB:12576' SUPV:DB 03/09/95 (18) TD:12647' PB:12576' SUPV:DB PREPARE TO RIH PICKING UP MW: 0.0 SEAWATER & Accept rig @ 1630hrs 3/3/95. RU floor to RIH picking up DP. DAILY:S29,869 CUM:$29,869 ETD:SO EFC: $1,830,569 DRILLING CEMENT @12340 MW: 8.6 SEAWATER RIH PU 200 jts 3-1/2" DP. Drill soft cement and stringers to 12332'. Drill firm to hard cement to 12340'. DAILY: $32,932 CUM: $62,801 ETD:SO EFC: $1,863,501 POH-LDDP MW: 8.6 SEAWATER Continue drilling firm cement from 12340-12560'. Test 7" casing to 3500 psi, OK. POH-LDDP. 125 jts DP laid down @ 0600. DAILY:S31,750 CUM:$94,551 ETD:SO EFC:$1,895,251 RUNNING 3-1/2" COMPLETION ASSEMBLY MW: 8.6 SEAWATER Load 3-1/2" tubing & jewelry into pipe shed. Run 3-1/2" single completion assembly. DAILY: $30,818 CUM: $125,369 ETD:SO EFC: $2,061,866 PREP TO TEST TREE MW: 8.6 SW & DIESEL Continue running 3-1/2" single completion assembly. Land hanger. Set packer. Test packer and casing. Set test plug. RU lines to test tree. DAILY:S135,797 CUM:$261,166 ETD:SO EFC:$2,061,866 RIG RELEASED MW: 8.6 SW & DIESEL Test tree. Test packoff. Secure well. Rig released @ 0800 hfs 3/8/95.. DAILY:S27,083 CUM:$288,249 ETD:SO EFC: $2,061,866 End of WellSummary for Well:AK8039 RECEIVED JUIW -7 1995 Gas Cons. Co~¥~mJssJon Anchor~ ,"~. ~ uu.'~F~,~ ARCO T ~ A~T~,~ AT ~-u,w:n~=:'~c: ANGLE 0,00 ~J~LL NURSER 0 -. ~., ,,N/-5; 0,00 ."." ..... T~,.m TARGET AZIMUTH ~:OM ~,.,~T~.~-;: :' .... TO iS TIE iH POINT(TIP) : M~ASURED :.-'EFTH 121,00 TRUE VEF;? ~,EPTH 121,00 IHCL!NATiC~ 0:00 AZi~JTH 0,00 b~Ti~JDE(N./-~:) O, O0 342:50 ORIGINAL DBPTH DBPTH ft ft ft !21,00 0,0 !21,00 3~n,oO 94,0 ,vu 90,0 a45 '~ . . 740,66 803,00 lw~,90 suo,lO 1196,36 !291,59 1574,45 1669,42 1763,08 1856,39 i950,23 2042,78 2!35,20 ~30,56 2323,10 2417,82 2604,80 2698,~ 2792,57 2885,84 o070,48 3253,i2 3446,98 3634,42 ~ ~ 54 400o,u~ 4380,38 4¢o/,r4 4,~,8~ 114,6 645,04 95,0 739 '~ 62,3 ~3,50 ..y,? 917,30 89,0 100.2,52 93,3 t!~,16 95,2 1266,80 94,5 1354,62 ¢,/ !440,73 94,7 152.5,74 95,0 !611,03 93,7 1692,29 93,3 1770,53 93,8 1844,02 92,5 17!0,2Z 92,4 197!,65 95,4 ~,5 20~3,87 94,7 2132,42 94,6 2!~,24 92,3 2213,40 a,, 2250,i5 94,3 ~86,89 93,1 ~ 82 io~ o ~90,'~ 1~,6 2460,2A !93,? ~40,-22 187,4 2621,22 187,I 184,5 2785,40 187,1 2867,49 187,2 2949,99 187,.~ ~Ozy,~fi !84,9 31C6,~0 ~Rus: LATI~JDE SECTION iNglN, N/-S 0,00 0,00 O,CO O,C~3 -0,08 0,50 245,00 -0 'V+U/ h 1,32 =~,.,,00 0,82 15,ii 6,66 345,50 !4,90 28,48 9,52 340.42 27,,'.',4 o=,.~ i0,75 342,00 ~ O~ ::o,o~ t5,29 ~' ~' 63,2A 91,82 !a,lO 335,7! 86,77 l:v,o. 18,97 33.4,89 4 .-'-. ~Sv,77 19,07 ~.oz ,,', !82,64 20,.59 334,1'? 170.01 2!7,01 '"~' ,,',,,Y 332,28 20i,10 · .. 2..-,,_,,~ 336.~q 234,3.~ 292,92 25,91 336,01 270,63 33~,18 28,93 ~2,$2 382,i4 30,71 ~ .z 35!,5A ~OO, / ,., . 4?2,39 35,27 . ~o 41 58 335,04 450,03 554,14 .46,93 697,08 53 ~ c~y 640,3~ 772,~3 57,05 .. 341,12 7ii,80 854,!9 61,26 340,12 788.50 938,44 64,93 ~8,97 867,54 !022,45 66,26 ~0,79 946,50 1108,31 67,41 340,91 t07v,64 ~'"= ~ '~ iii0.C4 1.=o,18 66,74 128i,04 87,85 342,42 1191,83 ~a~= oA 68,91 ~" o,o,oi 1356,17 1778,a6 64,83 1967,00 63,96 345,72 1852,21 ~qa Ao A3,A5 344,97 2014,65 2299,84 63,a¥ 2467,42 64,06 346,55 ' 2339.!,5 ~m= c~4 ~,66 347,03 2502,81 ~ · ~,.. ,-V~ ~ .... r.~,.,. ~s,~, 345,80 2831,04 1R-3! DEF'ARTUR~ ........ " .... "~ ,-.m,m p.a c- · .-,.~, LML.~ ~I. .=~.' .p/-i..J ,~-~,,/ . ft ft des i00ft 0,C0 0,00 0,00 0~00 -r,,53 0,57 .....nn 0,3? -I ~* 249,64 , o~ I, 40 0 - !, 79 ~', ?., 294, ,.'-, 4 2, n7 -!,65 5,24 341~67 -3,n' 15,20 '~ ~ "10 -7,02 28,52 345,74 :3,1! -t0,55 39,47 344,50 2,02 -~n,la .... ', 342,~a 3,89' .... 00,07 -30,'" -- ' l~ zo 71.~ 340 *~ z, _ -42,05 l=O,,'o 339,62 Io'= _~ z= 15!,08 o~fi,ZY 0,44 ~, m.~ . %8,17 183,17 338,i5 !,54 -83,89 2!7,89 337,36 2,75 -9~.83 2=',.,,5 o36. y3 -i15,79 294,~5 336,84 2,5! -134,79 338,03 336,50 3+58 -!55,79 384,53 .-~6,10 i,'79 -!77,91 435,30 335,88 4,90 .... ~ 393,5A 3~5,,--U 6,74 -LV£, ~ ~ , - - -230,2! 558,i4 335,64 5.79 -2.58,97 627,23 335,61 3,40 -287,18 701,81 335,35 -312,84 777,51 336,Z7 4, -339,83 856,6i 336,68 4,53 -369,32 942:,58 ..-. 6,94 4,03 -398,24 :u_. ,o/ 337,18 2,30 4,.~,, 42 11~ 2,,40 33/,-'~ _ .. ~,~., -480,!2 _-1284,90 ~8,06 1,23 : -530,30 1456,16 338,64 -6t..;,40 .... = !,50 -666,82 !968,58 340,20 0,47 -709,29 2!35,86 340,60 0,40 -/.8,/4 2300,62 341,01 I,~" -o, == 2467,86 341,41 -824,95 2635,26 34!,76 0,3! -864,95 2804,38 342,04 I+33 -90~,44 2~72,6t 342,25 0,!2 . ME~..=U?i) !,~ERVAL VERTICAL ft ft ft 5501 ""' * ~" ' ~'~ ~ ~r',02 ~&~,9 3489+82 ./g.'1%3, ~ff ,6.246,40 ·. e14 /.% 66i7,,33 ft de.:', 3!45,43 ,6.6,~ ~1o~,-:: ga,lO 3484,08 ..'3.5,'76 3625,0P 64,',;'3 . . ~ q~4.~ 41fin,o4 g~ 188,~ ........ ........... 187,3 ~7;7 ..... ~m ~, 63,9! 18%~ 38&,~n 4496,45 63,~= 186,0 3890,£5 4663,79 4~ '~ . , ,07 AZ!~UTH LATITUDE deo ft' 341,51 341,46 3444~61 342,~7 ~Er~n~Un: :TS~'LA:EMEh7 at ft ft -949,80 3!45,44 -!05i,01 3484,08 -1104,34 3655,4! ,. deo/ dec 'iOOf: 34£ 342,44 0,38 342,.,~ 342,~3 4~ 3843 '" -!207,75 .... ':~ 341,!8 3964,94 -!2,32,08 4160,'3'6 342,34 0,28 ~ * ~O'~t ~,~ A~ 9A ~ ~' ~'~ 34i,63 4283,00 -!369,03 4496,48 342,27 0,17 -~.o.~.~ 4441,1! 6802,02 7094,72 7559,71 7743,54 8307,04 ~588,28 8867,04 9!50,76 184,4 3%6,67 4631,40 66,27 ~72,7 4087,1~ 5097,79 188,4- 4166,~q ~2~8,n~ ' · - - ~- ~ '-~7,0 ,=,-:,~ 5520,90 66,87 16o,~ 4~2~,!0 2~u7,0£ .. . 281,3 4465,55 5947,17 66,97 282,2 4574,54 6207,42 67.60 '~ '-' ~87,22 A464,90 65,16 £~i,~ ..... L78,8 48¢6.,08 6716,82 64,37 283,7 4925,84 6973,74 65,69 340,27 '="~" .. . ' 4a7~,~5 -!48i,a.4 4835,49 342,15 O,.s7 336,8~ 4~8~65' '='~ 13 5097,~/ . -~2,'~, '"? 342,0i 0~60 ,~o 5009,u3 ...... = 52~,;'? 341 '"~ - 4d ,7J , .~,~,.. -I/!o,55 5521,18 o41,'~2 0,68 343 "'~ ' ' ,or 5408,96 -t764,86 5689,6~ 341,~3 342, ,.~, :~ .~A55~50.. -~4u,~ .~947,42. 341,97 0,~. _ ~ 24 =~0~ n~ '~""~,40 ~9.~7 :£ 342 n. O~t_ . ~, J2~u2 -~TL~ ,.,~t~ ,,., ,~ 0,60 344,70 6153,35 -£983,15 6465.03 342,14 ~'~ ~' 6396,90 -~v48,.8 '"' 5ff~/ n'~ '~ O/£6, ~'~., ~4~,~,_. 0 ,q4~. ~..,.a~ -21i4,46 6973,77 ~a?,3~ 0,.47 9434,83 97!5,32 ,',,-.-,n 7770~ ,, !02~0,17 284,1 5046.06 ? .... "" ,130,~ M,,24 343,30 6893,06 280,5 =' .... "~ ~oT,~a 7482,65 63,'35 341,92 7!33,2! 283,2 5295+w //oo,28"~'~'63,a~ 344,~ '~'=" 281,7 5416,24 'e"'* "- /.~u,~ 65,48 '343,94 7620,50 -2!84,74 7231,00 342,4! 0,75 · '~"' 95 7482 ~ ~'~ 0,54 -2334,iS 7736,29 342,44 0,70 -2404,40 7990,a~ 342,49 0,57 -2~7.~,05 .... 8246,i7 342,~ O,na~. 1(~6.89,37 107.~4 ~ 10879,30 10774,32 1!070,13 11164,83 11260,03 11449,72 ...~,, ~ ~61,77 65,53 342,67 79'76,~ 94,8 =A'"' ~= J.~v,z/ 8447,07 95,0 57,.~,9! 86i3,00.~,,~" .... 34~,~ 82i6,97 95,8 .%'772,848694,76 57,76 342,13 3295,C~ 94,7 58Z5~29 877.3,60 54,77 342,50 8370,!8 9S,2 5881,'74 ,.~,',.~n --,CIO ~"~ " '"~ * 'no', ~ 8997 ~= 49,£n 344,o~ '= ' ~= 94,~, 6064,42 9068,37 47,?0 -343.9~ 6~=,y~" -2509,7i 8361,77 -~34,83 8447,07 -2558,58 8530,74 -258!,,6.9 8613,00 -~605,89 -8694.77 2~ 0,92 342,54 3.02 342,55 2~39 _. 342,56 2,09 : -2627,85 87'73.60 342.58 2,'77 -2652,62 8850,11 342,56 .:,lo~ '~ -?A73,73 ~923 "'= ~4~,~.~ ~,¢q _.: -. ~ 7d 0 ,~ ~'.' ~ .~ ~" .... 26 2,25 -=...~,,u4 8997, 342,58 -2713,30 9068,~,q__ n42,~'''_ ~r 1,46 ....... ,~u¢.~£ 43,29 342,~= _. 94,8 A2AA,,45 ....... 9PA9.16 41,.~ 343,~ 8644.71 !48,2 63??,07 9365,77 37,91 34:,90 8?37,11 -~733,82 9!38.22 ,-,~ .-:~ -2772,72 9269,20 F'A.~ NJ,, 4 · '.3'EPTH .u:r: H ft ft ft THE LAST SURVEY !E: i2647,00 !OE.O 6398,67 TARGr? ........ ~:CiiuN INCLN, ft dee dec LATI~JDE DEPARTURE DIS?LACEF!ENT at AZI~UTE DLS bV-S Ei-W 4e,~/ ft ft ft deo lOOfr ,~ -£908 ,,~- ...... 9787.03 342,60 0,02 ARCO Alaska, Inc. Date: March 29, 1995 Transmittal #: 9219 RETURN TO: ARCO Alaska, Inc. Attn: Brian Hebert Kuparuk Operations File Clerk ATO-1119B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted here with are the following items. Please acknowledge receipt and return one signed copy of this transmittal. LIS Tape and Listing LWD Open Hole Edit LIS Tape and Listing LWD Open Hole Edit LIS Tape and Listing LWD Open HOle Edit 3/13/95 95009 3/13/95 95060 3/09/95 95061 Receipt Acknowledged: Date 'RECEIVED MAR 0 1995 DISTRIBUTION: Larry Grant AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Date' March 16, 1995 RETURN TO: ARCO Alaska, Inc. At'tn: Bdan Hebert Kuparuk Operations File Clerk ATO-1119 B P.O. Box 100360 Anchorage, AK 99510-0360 Transmittal #: 92~,~ / Transmitted below are the following open hole items. Please acknowledge receipt and return one signed copy of this transmittal. 1 R-31 CDR Finar~-~nt Acknowledged: ...~-L'~~~/~ 1/18/95 Ref#95061 RECEIVED DISTRIBUTION' Mr. Vernon E Pringle, Jr. (Geology) DeGIoyer and MacNaughton One Energy Square Dallas, TX 75206 Sharon AIIsup-Drake DS Development ATO- 1205 Alaska 0ii & [~as 0ohs. Cor~missio, Cli' Anchorage Erickson/Zuspan NSK Central Files NSK 69 Larry Gram (+Sepia) AOGCC 3001 Porcupine Drive Anchorage, AK 99501 Sandy Lemke ATO 1336 ARCO Alaska, Inc. Date: March 16, 1995 Transmittal #: 9212 RETURN TO: ARCO Alaska, Inc. Attn: Bdan Hebert Kuparuk Operations File Clerk ATO-1119 B P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted below are the following open hole items. Please acknowledge receipt and return one signed copy of this transmittal. 1R-31 CDR Final Pdn, ct~~ Acknow,edged: r~' 1/18/95 Ref#95061 Date: RECEIVED DISTRIBUTION: Mr. Vernon E Pringle, Jr. (Geology) DeGIoyer and MacNaughton One Energy Square Dallas, TX 75206 Sharon AIIsup-Drake DS Development ATO- 1205 MAR '! ~ 1995 Alaska 0il & Gas Cons. C0mmissj.0n Anchorage Erickson/Zuspan NSK Central Files NSK 69 Larry Grant (+Sepia) AOGCC 3001 Porcupine Ddve Anchorage, AK 99501 Sandy Lemke ATO 1336 Cli' MEMORANDI' -I TO: David John~, ChairmafF~ State Alaska Alaska Oil and G~s Conservation Commission Blair Wondzetl, ~ P. I. Supervisor c(~ FROM: Jerry Herring, ~ ~ SUBJECT: Petroleum Inspector DATE: January 14, 1995 FIlE NO: eaxkancd.doc Diverter Test - Parker 245 ARCO Kuparuk River Unit KRU 1 R-31 PTD # 94-168 Saturday, January 14, 1995: I traveled to ARCO's Kuparuk River Unit to witness a diverter test on 1R-31. The Diverter Test Report is attached. The diverter function test went smoothly. Parker 245 is utilizing a straight 16' line and the setup is a good one. The rig was in excellent condition. Summary: I witnessed a diverter test on Parker 245 drilling well KRU 1R-31. Attachment: eaxkancd.xis ' STATE OF ALASKA ALASKA OI1_ AND GAS CONSERVATION COMMItiSION Diverter Systems Inspection Report Operation: Drlg Contractor. Parker Drilling Rig No. Operator: Arco KRU Oper. Rep.: Well Name: 1R-31 Rig Rep.: Location: Sec. 18 T. 12N R. 10E Date: 1/14/95 Development X Exploratory: 245 PTD # 94-168 Rig Ph. # 659 - 7670 James Trantham John Crisp Merdian Umiat MISC. INSPECTIONS: Location Gen.: OK Well Sign: OK Housekeeping: OK (Gen.) Drlg. Rig: OK Reserve Pit: N / A Flare Pit: N / A DIVERTER SYSTEM INSPECTION: Diverter Size: 20 Divert Valve(s) Full Opening: YES Valve(s) Auto & Simultaneous: YES Vent Line(s) Size: 16 Vent Line(s) Length: 90 Line(s) Bifurcated: NO !Line(s) Down Wind: YES Line(s) Anchored: YES Turns Targeted / Long Radius: N/A in. in. ACCUMULATOR SYSTEM: Systems Pressure: 3000 Pressure After Closure: 1700 200 psi Attained After Closure: 0 min. Systems Pressure Attained: 3 min. Nitrogen Bottles: Six Bottles 2300 Ave. 32 MUD SYSTEM INSPECTION: Light Alarm Trip Tank: N/A N/A Mud Pits: OK OK Flow Monitor: OK OK GAS DETECTORS: Light Alarm Methane OK OK Hydrogen Sulfide: NT hiT psig psig sec. sec. psig NORTH ~1~ Prevailing -.~ , Winds \ 0 0 0 20" Annular Preventer With 16" FO Hydraulic Knife Valve 90' of 16" Vent Line~__~/~' Mounted on 22" Dual Wheels Non Compliance Items 0 Repair Items Withir 0 Day (s) And contact the Inspector @ 659-3607 Remarks: The rig was found to be in excellent condition. Distribution odg. - Well File c - OpedRep c - Tdp Rpt File c- Inspector The Gas Detection Guidelines dated 12/15/94 was left with the company rep. AOGCC REP.: FI-022 (Rev. 7/93 EAXKANCD.XLS !,~,...,.' t-i'!)i~ i]'x~ , / ! ALASKA OIL AND GAS :" 'CONSERVATION COi*II~SSIO~ / TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 January 4, 1994 Michael Zanghi Drill Site Develop Supv ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River 1R-31 ARCO Alaska, Inc. Permit No: 94-168 Sur. Loc. 473'FSL, 215'FEL, Sec. 18, T12N, R10E, UM Btmhole Loc. 653'FNL, 1588'FWL, Sec. 7, T12N, R10E, UM Dear Mr. Zanghi: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. David W. Johnsto~ dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASrv-~ OIL AND GAS CONSERVATION COMMISSi,. PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill X Redrill F'] lb Type of Well Exploratory D Stratigraphic Test ~--] Development Oil X Re-Entry ~--! Deepen r"l Service r-1 Development Gas [~ Single Zone X aultipleZone 2.. Name of Operator 5. Datum Elevation (DF or KB) 1 0. Field and Pool ARCO Alaska, Inc. RKB 41', Pad 45' feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25628, ALK 2561 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2O AAC 25.O25) 473' FSL, 215' FEL, Sec. 18, T12N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET) 8. Well number Number 850' FNL, 1650' FWL, Sec. 7, T12N, R10E, UM 1R-31 #U-630610 At total depth 9. Approximate spud date Amount 653' FNL, 1588' FWL, Sec. 7, T12N, R10E, UM 1/12/95 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1R-1 0 12667' MD 653'~ TD feet 15' ~ 20' MD feet 2437 6904' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035(e)(2)) Kickoff depth 400' feet Maximum hole angle 64.77° Maximumsudace 2383 psig At total depth (TVD) 3800 pslg 18. Casing program Setting Depth size Specifications Top Bottom Quantit~ of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include sta~le dataI 24" 16" 62.5# H-40 Weld 80' 41' 41' 121' 121' _+200 CF 12.25" 9.625" 40.0# L-80 BTC 6938' 41' 41' 6979' 4026' 1480 Sx Arcticset III & HF-ERW 710 Sx Class G 8.5" 7" 26.0# L-80 BTCMO£ 12242 41' 41' 12283' 6610' HF-ERW 8.5" 5" 18.0# L-80 LTC 384' 12283' 6610' 12667' 6904' 440Sx ClassG HF-ERW Top 500' above Kuparuk 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Structural Length Size Cemented RECEi 'I~~ depth True Vertical depth Conductor Surface Intermediate Production DEC 2_ 7 1994 Liner A!as 0il .& Gas Cons. Commission Perforation depth: measured ~ ~ true vertical 20. Attachments Filing fee X Property plat [-] BOPSketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot [~ Refraction analysis r"] Seabed report [-~ 20 AAC 25.050 requirements X that th foregoing i true and correct to the best of my knowledge Signed , Title Drill Site Develop. Supv. Date Commission Use Only Permit Number I APl b<f'mber I Appr°val ~/ate~ ~Z_~ -- ~',.~ ISee c°vor letter f°r ~;> ~7/- ~'~' ~ I 5 O- 0 .~- ~'- ~ ~ ,~'~ ~ other re(:]uirements Conditions of app~oval Samples required D Yes ~! No Mud log required D Yes [] No Hydrogen sulfide measures r~ Yes ~ No Directional survey required [] Yes ~] No Required working pressure for BOPE [] 2M ~i~ 3M [] SM F=] 10U D 15M Other:Original Signed By / David W. Johnston by order of/ //..//(~'""-' Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 in triDlicate GENERAL DRILUNG PROCEDURE KUPARUK RIVER FIELD 1R-31 I , , , , , , , , , 10. 11. 12. 13. 14. 15. 16. 17. 18. Move in and rig up Parker #245. Install diverter system. Drill 12-1/4" hole to 9-5/8" surface casing point (6,979')according to directional plan. Run and cement 9-5/8" casing. Install and test BQPE. Test casing to 2000 psi. Drill out cement and 10' of new ~ole. Perform leak off test to 12.5 ppg EMW. Drill 8-1/2" hole to total depth (12,667') according to directional plan. Run open hole evaluation logs or LWD tools as needed. Run and cement 7" x 5" casing. (If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030. Alternatively, if significant hydrocarbon zones occur within 200' TVD of the surface casing shoe, cement will be down squeezed in the annular space between the surface and production casing after the primary cement job is completed.) ND BOPE. NU tubinghead & full opening valve for cased hole logging. Secure well and release rig. Run cased hole cement evaluation. ND full opening valve and NU master valve and cap. Move in and rig up Nordic #1. Install and test BOPE. Pressure test 7" x 5" casing to 3500 psi. Perforate and run completion assembly. This is a "packerless" completion that utilizes a 4" seal bore extension (SBE) run in the 7" x 5" casing string. The seal assembly is run on the end of the completion string, stung into the SBE, and tested to ensure tubing x casing annular integrity. ND BOPE and install production tree. Shut in and secure well. Clean location and release rig. RECEIVED DEC 2 0il & Gas Cons. Commission Anch0r;~ DRILLING FLUID PROGRAM Well 1R-31 Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casing 9.0-10.0 15-25 15-35 50-80* 5-15 15-40 10-12 9.5-10 +_10% Drill out to weight up 8.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 11.4 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling Fluid System: Tandem Brandt Shale Shakers Triple Derrick Shale Shakers Solids Processing System to minimize drilling waste Mud Cleaner, Centrifuges, Degasser Pit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators Notes' Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur before a surface pressure of 2,383 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. The nearest well to 1R-31 is 1R-10. As designed, the minimum distance between the two wells would be 15'@ 20' MD. Incidental fluids developed from drilling operations will be hauled to the nearest permitted disposal well or will be pumped down the surface/production casing annulus of the last well drilled. That annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The annulus will be sealed with 225 sx of cement followed by Arctic pack upon completion of fluid pumping. Risks in the 1 R-31 drilling area include lost circulation and high pressures in the Kuparuk. Lost circulation above the Kuparuk will be addressed with lost circulation matedal (LCM) and reduced circulating rates as needed. The 7" casing will be topset above the Kuparuk and a 5" liner run to TD if lost circulation cannot be controlled with LCM and reduction of circulating pressure alone. Efforts to reduce Kuparuk geopressure at the target location and careful analysis of pressure data from offset wells show that a mud weight of 11.4 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement. The 9-5/8" casing shoe will be tested to an equivalent mud weight of 12.5 ppg upon drilling out of the surface casing. *Spud mud should be adjusted to a FV between 50-80 sec/qt to drill gravel beds. RECEIVED DEC 2 7 I994. ~!~$.k~ .0il .& Gas Cons. Cornrnj$$j0n /tnc/]or-u - ARC 0 ALASKA Structure : Pod 1R Well : 31 Field : Kuparuk River UnH Location : North Slope, Alaska: Created by : jones For: D PETRASH ',Date plotted · 13-Dec-9¢ Plot Reference is .51 Version #8. ;Coordinates ore in feet reference slot iTrue Vertical Depths are reference RKB. Baker Hughes INTEQ --- N 17.5 DEG W 9685' (TO TARGET) ***P!..,~E OF PROPOSAL*,** IID LOCATION: 653' FNL, 1588' FWL SEC. 7, T12N, R10E TARGET LOCATION: I 850' FNL, 1650' FWL SEC. 7, T12N, R10E TARGET - A3 SNDS TVD=6659 TMO: 12.347 DEP=9685 NORTH 9237 WEST 2912 900 1350 2700t 3150 1 _ 3600_ - - - 4950_ - 5~_ iRKB ELEVATION: 86' 300 KOP 1WD--400 TMO-400 DEP-O ' BEGIN TURN TO TARGET TVO:566 TMD=567 DEP=6 8.62 1 20.54 5 DEG / 100' BLS 26.29 52.26 72O0 3150 2700 2250 1800 1350 900 4.50 O 4-50 I I I I I i I I I I I I I I I ! i '~38.24- B/ PERMAFROST TVD=1651 TMD-1757 OEP=4-46 4¢~.2x~.2516.20 54 TMD=2587 DEP=,Og8 ] $NDS TVD-2761 TMD=4011 DEPi2.386 T/ W SAI4 SNDS TVD=3316 TMD:5313 OEP=S564 ~ B/ W SAK SNDS '[VD-.=3826 TMD=6510 DEP=4646 ~ 9 5/8" CSG PT '1%r0=4026 TMD=G979 OEP=5071 ~ SURFACE LOCATION: 473' FSL, 215' FEL SEC. 18. T12N, RIOE TARGET ANGLE 40 DEG MAXIMUM ANGLE 64.77 DEG BEGIN ANGLE DROP TVD-S632 TMD=I074~ K-Ia TVD--5706 TMB=10911 OEP=8625 ~ 62c~8.00 DROP 20E6 / ~00' '~'",..... 5400 K-5 ~/D=6071 TMD=lI550 DEP=9149'%. S0.00 46.00 ~' 4200 r/ ZONE 0 - EOD P¢0-6.382 TMO-1 1985 0EP=9453 · T/ ZONE C TVD:6489 TMD=12125 OEP=9542 T/ ZONE A T~=6641 rMD=12323 DEP=9670 ', TARGET - A3 SNDS TVD=6659 TMD=12347 DEP=9685 B/ KUP SNOS TV0-6751 TMDi~2457 0EP-9762 ID - 7" CSG PT TVD=SD04 TMD=L2687 DEP=gggi k9900 9450 fg000 f8550 b B!o0 t7650 ~7200 6750 i 350 900 ;15 ~s0 o© I 6300 5850 t 4950 4500 I4050 i3600 ~ 3150 L ~ 2700 2250 ,800 I I I I I I I I I I I I I I I I I I I I I I ! i I I ! ! I I I I I I I I I I i I I i i ~ ~ 1 450 0 450 9OO 1350 1800 2250 2700 .3150 .3600 4050 4500 4950 5400 5850 6300 6750 7200 7650 8100 8550 90'3,39450 9300 1'3350 Scale 1 : 225.00 Vertical Section on 342.50 azimuth with reference 0.00 N, 0.00 E from slot #31 Created by 'jones ;Date plotted · 14-Dec-94- :Plot Reference is .31 Version #8. Coordinotes are in feet reference slot True Vertical Depths ore reference RKB. ,o0 ALASKA, Inc. Sfrucfure: Pod 1R Well : .51 Field : Kuparuk River Unit Location :Norfh Slope, Al(~sko --- Baker Hughes INTEQ < - - W e s f sc o,e, · :o.0o 600 560 520 480 440 400 360 320 280 240 200 160 120 80 40 0 40 80 120 160 200 240 250 7~_ 17~ 1700~ 520 _ 1700 2~ 2~ ~ ._ ~ ~ 2~ _ ~ ._ .. _ O t . I I I I I I I I i j I I t I · I I I i I i I I ~ I I I i i ~ ~ '- 600 <-- West ~o,~: .... , r 640 L 500 _ 520 -- -- ._ 440A _ 220 Creot:ed by : jones Dote plotted : 14-Dec-94 Plot Reference is .31 Version #8. Coordinotes (]re in feet reference slot #31. iTrue Verticol Dep(hs ore reference RKB. --- Boker Hughes INTEQ 1760t 17201 _ 152O_ 1480_ . 1440_ _ 14.00. _ 1360_ 1320_ _ 1280_ - 124o_ 12O0_ - ,ARCO ALASKA, Inc. Structure · Psd 19 Well · .31 Field : Kuporuk River Unit Loc~fion : North Slope, Alesko <-- West o.oo 1120_ 1080_ 840 800 760 720 680 640 600 560 520 480 440 400 360 320 280 240 200 160 120 80 40 0 I I I I II fI II I I II II II II I I II I I II II II II I I I I l~ 2300 \ 26OO t l720 2700 il~O F1640 -- 26O0 _1560 _1520 _1480 2~0 _1440 920 .. 840 800 760 720 680 640 600 560 520 480 440 400 560 West 1320 ~ 280 1240 h~160 L~2o : 080 ~I~ 950 ,20 320 280 240 200 160 120 80 40 O ' 540 ~ Sc,ale Casing Design / Cement Calculations 21-Dec-94 Well Number: Surface Csg MD: Surface Csg TVD: Production Csg MD: Production Csg TVD: Top of West Sak, TMD: Top of Kuparuk, TMD: Top of Target, A3 Sands, TVD: Estimated Pressure: Surface Casing Choice · Production Csg Choice: Production Casing Frac. Pressure 1R-31 6,979 ft 4,026 ft 12,667 ft 6,9O4 ft 5,313 ft 11,985 ft 6,641 ft 3800 psi 3,500 psi Maximum anticipated surface pressure Estimated BH pressure at top of target zone TVD surface shoe {(13.5'0.052)-0.11}*TVDshoe 4,026 ft 2,383 psiJ Estimated Pressure= Top of Target, TVD = Overbalance, psi= Anticipated Mud Weight 3,800.0 ppg 6,641 ft 150 psi 11.4 PPgl Surface lead: Top West Sak, TMD = 5,313 ft Design lead bottom 500 ft above the Top of West Sak = 4,813 ft Annular area = 0.3132 cf/If Lead length * Annulus area = 1,557 cf Excess factor = 85% Cement volume required = 2,881 cf Yield for Permafrost Cmt = 1.94 Cement volume required =[ 1,480 sxJ Surface tail: TMD shoe = 6,979 ft (surface TD - 500' above West Sak) * (Annulus area) = 678 cf Length of cmt inside csg = 80 ft Internal csg volume = 0.4257 cf/If Cmt required in casing = 34 cf Total cmt = 712 cf Excess factor = 15% Cement volume required = 819 cf Yield for Class G cmt = 1.15 Cement volume required =1 710 sxJ Casing Design / Cement Calculations Production tail: 21-Dec-94 TMD = 12,667 ft Top of Target, TMD = 11,985 ft Want TOC 500' above top of target = 11,485 ft 5" casing tail top (100' above A sand) =l 12,283 ftJ 5" Annulus area (9" Hole) = 0.3054 7" Annulus area (9" Hole) = 0.1745 (5" Casing Top-TOC)*7" Annulus area + (5" to TD)* 5" Annulus area = 257 cf Length of cmt wanted in csg = 80 ft Internal csg volume = 0.0997 Cmt required in casing = 8 cf Total cmt = 265 cf Excess factor = 100% Cement volume required = 529 cf Yield for Class G cmt = 1.19 Cement volume required =1 440 sxI TENSION - Minimum Design Factors are: T(pb)=l.5 and T(js)=l.8 Surface (Pipe Body): Casing Rated For: Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =[ 91600O lb 6,979 ft 40.00 Ib/ft 279160.0 lb 47494.3 lb 231665.7 lb 4.0! Surface (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =1 979OOO lb 6,979 ft 40.00 Ib/ft 279160.0 lb 47494.3 lb 231665.7 lb 4.2] Production (Pipe Body): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt/ft) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Pipe Body) = Design Factor =[ 604000 lb 12,667 ft 26.0O Ib/ft 329342.0 lb 56815.8 lb 272526.2 lb 2.2J Production (Joint Strength): Tension (Pipe Body) = Dead Wt in Air - Buoyant Force Dead Wt in Air = Length * (Wt./fi) Buoyancy = Weight of displaced mud Casing Rated For: Length = Casing Wt (Ib/ft) = Dead Wt in Air = Buoyancy = Tension (Joint Strength) = Design Factor =J 667000 lb 12,667 ft 26.00 Ib/ft 329342.0 lb 56815.8 lb 272526.2 lb 2.4] Casing Design / Cement Calculations BURST- Minimum Design Factor = 1.1 Surface Casing: Burst = Maximum surface pressure Casing Rated For: Max Shut-in Pres = Design Factor =1 Production Csg: 1. Design Case - Tubing leak while well is SI Inside pres=Csg Frac pres (3500 psi)+Mud Wt*.052*TVD Outside Pres=Backup Gradient (8.9ppg *0.052*TVD) Net Pressure = Pressure inside-Pressure outside Design Factor = Rating / Net Pressure Casing Rated For: Inside pressure = Outside Pressure = Net Pressure = Design Factor =[ COLLAPSE- Minimum Desion 'Factor = 1.0 -- Surface Casing 1. Design Case - Lost circulation and Fluid level drops to 2000' TVD with 9.0 # Mud 2. Ext. Pres=Mud Wt*0.052*TVD-(2000'TVD of 9# Mud) Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =1 Production Csg 1. Worst Case - Full evacuation of casing 2. Mud weight on outside = Mud Wt * 0.052 * TVD Casing Rated For: Mud Gradient = Ext. Pres. @ Bottom = Design Factor =[ 21-Dec-94 5750 psi 2383.4 psi 2.41 7240 psi 7606 psi 3195 psi 4411 psi 1.6! 3090 psi 0.595 Ib/ft 1459 psi 2.11 5410 psi 0.595 Ib/ft 4106 psi 1.3J Casing Design / Cement Calculations 21 -Dec-94 Surface Casing Choices OD ID Ib/ft Grade Metal X-Section I 9.625 8.681 47 L-80 13.5724 sq. in. 2 o9.625 8.835 40 L-80 11.4538 sq. in. 3 9.625 8.921 36 J-55 10.2545 sq. in. 4 10.750 9.950 45.5 J-55 13.0062 sq. in. Jt Strength Body Strength Collapse Burst 1161000 lb 1086000 lb 4750 psi 6870 psi 979000 lb 916000 lb 3090 psi 5750 psi 639000 lb 564000 lb 2020 psi 3520 psi 931000 lb 715000 lb 2090 psi 3580 psi Production Casing Choices OD ID Ib/ft Grade Metal X-Section I 7.000 6.276 26 L-80 7.5491 sq. in. I 5.000 4.276 18 L-80 5.2746 sq. in. 2 7.000 6.276 26 J-55 7.5491 sq. in. Jt Strength Body Strength Collapse Burst 667000 lb 604000 lb 5410 psi 7240 psi 376000 lb 422000 lb 10490 psi 10140 psi 490000 lb 415000 lb 4320 psi 4980 psi RECEIVED DEC 2 7 199zi. Oil & Gas Cons. Commission Anchor~ ,UPARUK RIVER UNi 20" DIVERTER SCHEMATIC 6 4 I, 3 O---1 DO NOT SHUT IN DIVERTER AND VALVE AT SAME TIME UNDER ANY CIRCUMSTANCES. . MAINTENANCE & OPERATION UPON INITIAL INSTALLATION: · CLOSE VALVE AND FILL PREVENTER WITH WATER TO ENSURE NO LEAKS. · CLOSE PREVENTER TO VERIFY OPERATION AND THAT THE VALVE OPENS IMMEDIATELY. CLOSE ANNULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN VALVE TO ACHIEVE DIVERSION. ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) 1. 16" CONDUCTOR. 2. SLIP-ON WELD STARTING HEAD. 3. DIVERTER ASSEMBLY WITH ONE 2-1/16"- 2000 PSI BALL VALVE. 4. 20"-2000 PSI DRILLING SPOOL WITH ONE 16" OUTLET. 5. ONE 16" HCR KNIFE VALVE WITH 16" DIVERTER LINE. THE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTER. DIVERTER LINE WILL BE PLACED FOR OPTIMUM DISPERSION IN PREVAILING WIND CONDITIONS. 6. 20" - 2000 PSI ANNULAR PREVENTER. DKP 11/°J94 13 5/8" 5000 BOP STACK 7 , 6 5 I3 8. 9. 10. 11. 12. 13. 14. ACCUMULATOR CAPACITY TEST CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST FILL BOP STACK AND MANIFOLD WITH WATER. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 3 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED TO ZERO PSI. OPEN ANNULAR PREVENTOR AND MANUAL KILL AND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KILL AND CHOKE LINES. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. CONTINUE TESTING ALL VALVES, LINES, AND CHOKES WITH A 250 PSI LOWAND ~ PSI HIGH. TESTAS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. OPEN TOP PIPE RAMS AND CLOSE BO'I-I'OM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSI AND 3000 PSI FOR 3 MINUTES. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO 3000 PSI FOR 3 MINUTES. BLEED TO ZERO PSI. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILUNG POSITION. TEST STANDPIPE VALVES TO 3000 PSI FOR 3 MINUTES. TEST KELLY COCKS AND INSIDE BOP TO 3000 PSI WITH KOOMEY PUMP. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16" - 2000 PSI STARTING HEAD 2. 11" - 3000 PSI CASING HEAD 3. 11" - 3000 PSI X 13-5/8" - 5000 PSI SPACER SPOOL 4. 13-5'8" - 5000 PSI PIPE RAMS 5. 13-5/8' -5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - ~ PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8" - 5000 PSI ANNULAR RECEIVED DEC 2'/' i99A m~,~:'"~' '~' 0ii & Gas Cor~s. Commission Anchor; WELL PERMIT CHECKLIST PC' COMPANY GEOL / -31 UNIT# PROGRAM: exp [] dev/~ redrll [] serv [] o~/OFF s~oa~ ADMINISTRATION 1. Permit fee attached .................. 2. Lease number appropriate ............... 3. Unique well name and number .............. 4. Well located in a defined pool ............. 5. Well located proper distance from drlg unit boundary.. 6. Well located proper distance from other wells ..... '7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party .............. 10. Operator has appropriate bond in force ......... 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval..' 13. Can permit be approved before 15-day wait ....... ENGINEERING 14. Conductor string provided ............... N 15. Surface casing protects all known USDWs ........ 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............ 21. If a re-drill, has a 10-403 for abndnmnt been approved. ~ 22. Adequate wellbore separation proposed ......... ~ N 23. If diverter required, is it adequate .......... .~ N 24. Drilling fluid program schematic & equip llst adequate N 25. BOPEs adequate ..................... N BOPE press rating adequate; test to -~rO psig.Q N 26. 27. Choke manifold complies w/API RP-53 (May 84) ...... ~ 28. Work will occur without operation shutdown ....... ~~ 29. Is presence of H2S gas probable ............. Y~ GEOLOGY ? 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... 32. Seismic analysis .of shallow gas zones .......... Y [exploratory only] GEOLOGY: ENGINEERING: COM~ON: J'DR' ~ RAD C~mments/Instructions: Well History 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 APPENDIX. , No special effort has been made to chronologically organize this category of information. RECEIVED Alaska O/i & Gas Cons. Cora~[88[ort AncJ]orage .. iS War'.e Ver..if~.cation Lj, stino chlumherger alaska Comped. ti. no Center 995 15: ! 3 8FRV.! CE l,i a I..,: ~' .' paj'F : 95103/ 9 GPIGIN : TAPF h.'Ar.'F; : 0506! CO~KNT : At:CO AI, ASKA :{'.~C., KiJPAPOK R,[VE~ U!,;TT, I.R-31, APE 50-029-22538 }~aL~.aruK River Unit WELT, ~,~AME: APl Nt.}~4B,EP: bOGgI~JG ('.['~;qPANY: d 0 B D ~. T A 9 5 6 5002022538 Arco Alaska !r~c, SCHL!..',I,BERGER dELL SEPVICKS 9-MA~-95 BIT RUN 2 4 7 3 2]. 5 8t,~. O0 PAGE: IS Tape verffi, cat.Ion ~,istt.f;o o-!,,ihp-~995 15:13 cb/t~mbern~r ~!ask8 Computin~ Cef~ter P ROf.)I~CT I r~5', S !,IS Ff~.~hT DATA PACE: ,ipped curves NO PEPTii S~.~IF'T ~PPLTED ./~$ PER DAVE Si"IAFER. TI~E] ATVP ANI) PSVP C!},~VES DO 'Nfl]; OVERLAY THE FIELD PPlNT AS THUS[f Ct.I~VES wER~ RECAI,CUI,!TEt.)USING INPUT S bit runs t,,879 IVAI L.f,~l'i I~NSNI[47E.I,,, .!.. 2647.0 DATA chlumberqer AlasKa C. omputinc~ Center q-l,~AR-199S 15: J.;S PAGg: DATA. ** -999.250 -999,250 2.479 2,292 I,~ Tape V~rtficatio~ I, istinn ChlUr,'~berc~r .A)asKa ~omput. i,n~ 900...:) O (..', DWPT. 9000. {300 ¥ ~!p. ?. wD 2.9f:7 D [: P T. 7 () 00.0 () i t 500 -99g.250 250 Center 9-~,AP,-~.9q5 !5:13 2., 8 F' O P o ~.! '~,~ 1'.) 56.78? 226.667 FET. ~,WD 3.543 V R/~.. ,~ ~ D GR. i'qb' [) P p. i,:i V~ D 94. 595 kf3P. awi) 93.03 S p, [~ p · fa: w ~) 91. 541 kOP. ~'~WD 240.000 3.106 299.051 3.247 !35.337 3.103 FET.~,~a'D FET.~WD FET.~D ~ P. I~,.' ~! D - 99 g. 250 I..~ ~i: ~..q. w D - 999.250 V R A. ~ W D PAGE: 0.731 2.327 0.447 3,523 0.396 2.71% 0.306 3.101 0.364 2.765 -999.250 -999.250 , (] 0,2 FTLF: ~t,E~DE~ Curve~ a~d lo9 header c! a t: a for each bit run, i.n separate files. Wane Verif. J. cat!of I, isti. nq chlumberqor AlasKa CO~.'~ti.Do Center PAGE: FTbF CDP J PATE LOGCED: DO~NHF) LF. SOFTt'~A TD D!.~]I,I, ER (FT) TOP !,fig D. OTTOf4 b~G I~,T~RVAI., ~I.T I~OTATING SPEED n[".!!~E [NCI, I~ATIa~'~ (DEa) STCP 9EPTH STRING (T(2P D O R ~! O O b C D R I b !'.., E P S C A 5 I t'3 I.., E C O t,t D I T I O i~ S ),aUD DENSITY ~IJD VISCOSITY (S) F'I.,,UI[~ bOSS [C3) S ~ S T I V I T Y U D A T ~q E ~l.j9 FILTRATE P3-d ~.I-95 FA$'.~' 2.5 12647.0 6880.0 12572.0 43.3 67.6 ~ (:; 8 n 55 500 6n44.o l ('), 90 155.0 2,640 0,00 0 ~ .65 ~, 5 0 0 1,5 00 75.0 '74.0 0.0 ChlUmberqer f, laska Computi~q Cer~ter DATA IF'oR~,~AW SPFCTFTCATT~)N [~F, CUg'I) ** SET TYPE - C',HAN ** I T 'V I A P ! g P I A [> I A P I F ]:. [.., EN U. ,.S R E p E S S m O0 00() O0 0 2 I 1 4 680000000000 F:fHP O0 000 O0 0 2 ! 1, 4 68 0000000000 R 00 000 00 () 2 ! 1. 4 68 0000000000 ~ ~,~ P~ 00 000 00 0 2 ! 1. 4 68 0 () 00000000 ~'~ ~.~: ~.~ 00 000 O 0 0 2 1 1. 4 68 0000000000 * * D A Th * * IS WaDe Verificat.ion Iisti~q cb~lUmbero...er Alaska Computinn (:enter b,~ PT. 11795. 000 c,e. b~ 1 ~ TP. !,w ~ -9~9.25 o PSR. I_~W .1. I.:.F P 1'. 1.1 or~,q. 00(', ¢iR, LV'~ 1 a 'r P, t, w .1 2.366 P S R. L ~,' 1 DFPT. 1 n()00.00 (1 C-R. L,W 1 ~TP. I,W ~ 3.5{~7 F'SP. LW 3. DFPT, 9(100, aTP. i,W 1 3. ~T~. L'~~ J 3.151 PSk.. bW ! DFP'r. 7()0(). UO0 CR. t..,W ! 6879. 500 ¢:R. L,W 1 -999. 250 PSR. I.,W 1 ** END {,.)F' T) ATA ** -999.25n -099. 250 DER. t.,W 1 . 2 437 3.563 ,h~.R. LW 1 94. 595 P.i)PE. bW 1 3.092 D El R. L i',~ 1 93.03a ROPE:. b'W1 3. 304 DER. Lw I 3. 254 L) ER. 5WI 47. 196 Pi~PE. bW 1 -~:99. 750 I)FR. LW 1 52.633 -999.250 56.7B2 2.410 226.667 3.543 2~0.000 3.106 299.951. 3.247 135.337 3.103 -99o.250 -999.25O TAR.I,W1 TAg. I,W .1. TAB.I..wl PAGE: -999.250 0.731 0.447 0.396 0.306 0.364 -999.250 SF~RV ICI~ : F'b I,C VFRSI['IN [}~T~: : 951031 9 ~,X P~:C SIZe: : 1024 LIST FiLE F !' I,,F: HE;ADKR F!t,P N~,J~BER 3 Curves and !.oq header data DKPTt.{ I'NCRE~Et~T: 0.5000 ~or each bit rum in separate .files. ES 'rape Verification chlumber~r Alaska Com[)~tin~ Center 15:!3 PAGE: .................' a"7; .... CD~ 1 ~ 47. LOG HRADER DATA P~TE b!')G~ED: S~R~ACE SOF'Y~.,ARE VER:51~;N: D/'~,TA ~YPE fNiF'i.,ii'iR~ Or TP I~PlI,I. ER (FTI: 90TTO~,~ b[lG INTERVAL nI~' ~OTAm:[F~G SPEFI) NI')I,,E INCI~INATi. Ob (DEG) ~,! A X I ~ llW, ANGLE: v F ~,a O 0 ~ T 001,, C: P J.) E T 0 t) 1'., C n R C O ~,,~ P .. R(.i~REHOLE A.I,.tD CASIhG DAtA DRI L!..ERS CAS!t,IG ~ 0 R E H U I, E C r} ~.~ !)I T I P ~q 8 )~'i [.,I D T Y P F,: N~)I,> DE~$itY (LB/G): ~qI..iD VTSCOSIT'Y ($)~ FI,,UID bOSS (C3): N lXI~illM ~]Ct':IR!]:ED TE~PF, RATt~RE RESTSTiVITY (OH~N) AT TEF'!PERATt.i~E Si. iD AT aEASURED TE'MPERATIJRE ,Ur') AT M,AX CI:RCI, JI,,ATI ~t./D F'iLTP. ATE AT (FIT) '~4UD CAKE; AT ~ E !~ T ~ [) N T O 0 b ~'4 AT~ I X: a a T R I' X !3 E', :~',~ S I ',t:" Y: Ti) Ob 5~AIqD[:)FF [I)'1): R [!: ~:i a I;,: F' 8: 23',J h:1=95 FaST 2,5 !2647.0 6asn,o 3S.3 43.3 6944.0 155,0 2 , 640 2 · 460 0. (:) 0 (,) S A N D 8 T 0 N F: 2.6,.5 1. · 500 ***************************** ~ 1 f) istance ~es, ~o P, It, : 65 , 9(') f,t, 75.0 74 0 Tape verf~ff..cat.ion L,,ist.~nq cb!umber.get Alaska Computin~ Center 15:!.3 ','~el] Dr i ,l., ,l ed ~'rom:t,~955 ft.. to 117q5 Lt. L)~gtaDce GR To Rit: 75,93 ft. O~stasce 9es. ~'o ~it: 65,51 It, · ~11 hr]!]ed From: ~1795 ft, to 1~647 ~t. PAGE: TYPE RFPP C(~DF", ¥~LUE I 66 . A P .I .A P I ~. P 1 A. P I F .'I l., E N I] N B Ntl ~'l H S I Y, E R ~ P R p R 0 C ~ S S LOG TYPF C[,~SS ~OD NU'Mg $~P ELEM CfJDF, (HEX) O0 000 000311 4 68 000000000 o 00 0 (,) 0 00 () 3 ! 1 4 68 0000000000 O0 000 OO 0 3 1. ] 4 68 0000000000 0 o 000 () 0 (.) 3 ]. ! 4 68 0000000000 () 0 00 O 00 0 3 l, ~, 4 6 8 0000000000 oO o00 O0 0 3 ~. 4 68 0000000000 Tape Veri f~cation Center pvp?. 12647. (>C!0 eR. L~,.'2 !,5:1,3 -aga.250 DF.,R. bw2 b7 .75g 137.250 -999.250 90.9.,95 -999.250 205 -999.250 -999. 250 PAGE: 10 -999.250 2.479 -999.250 SERVICE : FLIC VFRSIO~ : O0!CO1 l:) ~ Tv : 95/03/ FILW TYPE !,,~ S~ FILE : SERVICE ~,tAI:~E : EDIT D~TF : 95103t 9 UPICIN ~ PblC T~PF NA,~E : o5()61 pPEVI~US T~PE C~.~'~ENT : ARCO ALASK~ INC. , K i] P A R U I4.: R i. V E P It }',i I T , 1R'31,, APE; 50-029-2253t::! APE 50-029-22538
