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186-068
Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning. They are available in the original file, may be scanned during the rescan activity or are viewable by direct inspection of the file. Well History File Identifier Organization (done) RESCAN [] Color items: [] Grayscale items: [] Poor Quality Originals:, [] Other: DIGITAL DATA [] Diskettes, No. [] Other, No/Type TOTAL PAGES: ~ ~ NOTES: ORGANIZED BY; ~ BR'EN VINCENT SHERYL MARIA LOWELL Project Proofing OVERSIZED (Scannable) [] Maps: [] Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other [] Staff Proof By: Date: PROOFED BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: Isl PAGES: ~)~-- ' (at the time of scanning) SCANNED BY: 6BREN~ VINCENI SHERYL MARIA LOWELL I O , ) ;;Z. . O'). ,s, ReScanned (done) RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: /S/ General Notes or Comments about this file: Quality Checked (done) Rev 1NOTScanned.~xl • off' r > 4,4,A //7/7`). THE STATE '1121E:2_E ` a } 333 \est Seventh Avenue �� fir GoV'ERNOR SPAN PARNFI_.I_ Anchorage, Alaska 99501-3572 • 'flair 90/.2 9 733 James Ohlinger CTD Engineer (9( ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3N-08A Sundry Number: 314-049 Dear Mr. Ohlinger: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 14 P Cathy P.7 . oerster Chair DATED this q' day of February, 2014. Encl. • nlP d .. ' ,e.as v„.41 • STATE OF ALASKA AL .A OIL AND GAS CONSERVATION COMM.__SON J 2 t APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AOGCLt 1.Type of Request: Abandon r Rug for Redrill r. Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Rug Perforations p Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r Other: r; 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. • Exploratory r Development r 186-068 • 3.Address: 6.API Number: Stratigraphic r Service p, P.O. Box 100360,Anchorage,Alaska 99510 50-029-21540-01 - 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No r • 3N-08A . 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25521• Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 6890 ' 6658 ' 6767' • 6555' ' none 6760' Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 115' 115' SURFACE 3586 9.625 3623' 3619' PRODUCTION 6818 7 6853' 6627' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6460-6470,6536-6558,6560-6590,6601-6607 6292-6301,6357-6376,6377-6403,6413-6418 3.5 L-80 6534 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER S-3 PACKER MD=6287 TVD=6144 • NIPPLE-CAMCO DS NIPPLE MD=501 TVD=501 . 12.Attachments: Description Summary of Proposal + p. 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service r. ' 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 1 `� 2/3/2014 Oil r Gas r WDSPL r Suspended JV' \ 16.Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: James Ohlinger @ 265-1102 Email: James.J.Ohlingeraconocophillips.com Printed Name James Ohlin Title: CTD Engineer Signature �� /....Z.8.4.4)....6.4... Phone:265-1102 Date //0///r Commission Use Only Sundry Number: 3}Li-0-901 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test Mechanical Integrity Test r Location Clearance r Other: 8 o -c....5, f 7Lo 4OdUp5r RBDM���� MAY 9 2014 41ferna )-c ploy p !etc c- -,-, nv-r/ app r—e,v'cd Dcr ,2U /4/3C25, I121c J Spacing Exception Required? Yes ❑ No d Subsequent Form Required: it, — 4.6 APPROVED BY Approved by: '' j P COMMISSIONER THE COMMISSION Date: Z - 9"/e( pprov d appy jtR I GcI %4J nths trom t17 e of approval. Form 10-403(Revised 0/2012) UK I '\`,' �'�� ' Submit Form and Attachments in Duplicate VLF //Z ?/J + S.t, RPC D-15 glql ill KRU 3N-08 CTD Summary for Plugging Sundry (10-403) Summary of Operations: Well 3N-08A is a Kuparuk A-sand/C-sand injection(service)well equipped with 3'/2"tubing and 7" production casing. The well was recently worked over by removing the original 2-7/8"tubing and replacing it with a 3-1/2"completion. The CTD laterals drilled from the injector well will target the Kuparuk A-sands in fault blocks adjacent and corresponding to the wells current locations. 3N-08A is planned for 2 laterals or 1,560' of total hole in the A-sand reservoir. Prior to drilling,the existing A&C-sand perfs in 3N-08A will be squeezed with cement to provide a means to kick out of the 3-1/2"and 7"casing. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1)to plug the A& C-sand perfs in this manner. After plugging off the existing A& C-sand perfs with cement, a mechanical whipstock will be placed in the 3-1/2"tubing at the planned kickoff point. The 3N-08B and BL1 sidetracks will exit through the 3-1/2"tubing and 7"casing at 6,496' MD and will target the A2 and A3 sands south of the existing well. The laterals will be completed with 2-%" slotted liner from TD with the liner top located inside the 3'/2"tubing at 6,490' MD. CTD Drill and Complete 3N-08 Laterals: Feb/Mar 2014 Pre-CTD Work 1. Positive pressure and drawdown tests on MV and SV. 2. Test Packoffs—T&IC 3. MIT-IA 4. RU slickline. Tag PBTD 5. RU Eline: Obtain SBHP and run GR/CCL for jewelry correlation log 6. RU slickline. Drift tubing with dummy whipstock 7. RU Eline: Obtain SBHP 8. RU coil: Cement Squeeze A&C-sand perforations,and fill 3-1/2"x 7" straddle annulus 9. RU slickline. Tag top of cement and pressure test. 10. RU coil: Mill out cement in the 3-1/2"tubing 11. Prep site for Nabors CDR2-AC, including setting BPV p5? 34, 4-3 0's Drilling Hazards Information and Reservoir Pressure (Requirements of 20 AAC 25.005(c)(4)) Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) A static bottom hole pressure of 3N-08 in January 2014 indicated a reservoir pressure of 3581 psi or 10.8 ppg equivalent mud weight. The maximum down hole pressure in the 3N-08 pattern is at 3N-06 with 4278 psi. It is not expected that reservoir pressure as high as 3N-06 will be encountered while drilling the 3N-08 laterals because of offset distance and faulting. Using the 3N-06 pressure as the maximum possible in 3N-08,the maximum possible surface pressure,assuming a gas gradient of 0.1 psi/ft,would be 3643 psi. I� G Cf1� Gvr. /Hrhi if4 TSS �rO�SCrA �,x �✓���1 G'�ttimg)`! -r4 C Cv/rf/'�f vt4 TS�Or�� i��'1 OK K c O�q►- from 14e �A� di 0n r4"fir r / or+e f,yf•crin�i► fiy4//,t rjl� of a Pa� ky o, /� o"( Grigt 46'1 Th 4 r4 411 Tie. I v j >O referveJ �LI 'Ate c D L,�'i r'f Page 1 of 2 70 room in,•( a.PA roti T4e Ktl� C "1 ! C JV N 1/20/2014 w4rr4' rnVy Rig Work tf vvv. 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 3N-08B Sidetrack(A2 sand) a. Mill 2.80"window at 6,496' MD. b. Drill 2.74"x 3.25"bi-center lateral to TD of 7,400' MD c. Run 2%"slotted liner with an aluminum billet from TD up to 6,745' MD 3. 3N-08BL1 Lateral (A3 sand) p 119 a. Kick off of the aluminum billet at 6,745' MD b. Drill 2.74"x 3.25"bi-center lateral to TD of 7,400' MD c. Run 2%" slotted liner from TD up to 6,490' MD, inside the 3'/2"tubing tail 4. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV 2. Obtain static BHP. Install GLV's. Page 2 of 2 1/20/2014 I-m C Y cn CC U co N o ino Q o I Q O N - o� I m p M N CO � M .- _C O V I I �r- ` ' H I V co C M M E U Q O - (0 co c-I C V co C co O N a a) co O coM 0 Ce >- Y I) N Ct _0 M CO I- 06 f` () 0 -a O co m co Cfl iE Lf, O T.) co Q Y }o O co \ P__ C6 `� � � �' LO \ �I c a co E ap Y > co to n W ,� O 5 CO m •c W .� (5 a 0 i-6 Y \ 1 0 a a) CO co J C o d w w-' p M I oo J o o °5 X a) a' O cfl (m6 (co E c' O W E) M Y 0 ai 0 0000 E I o ° o N N N N o Na) N W I I I I ((0 N i 0_ I > M M M mco co Tr) (0 H > I ii / / i 1 , l 4 . A I'§I. ii 1 i " i N. - Y � gW ----7-* W. SIt1 * *4 �14 ks • -)II I - x. 1,... �" 41 1 r P ''''':‘",i1:::',.-$.441., P 'e CD N 1 , jIf 01 H j O 11 ° v,no ) cr o a0 co 2 in 0 o u) in Ib u) L() � Vi >� i o n 100 p � M � o � a� NCO N J -� '0 = o * cMO 0-.1- XW � _' �JW � @ in Iz _co (II O N � � LO NCO o U A Q CD �l MCO ZDV (3) cam/) i KUP INJ 3N-08A ConocoPhillips III; Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore APLIUWI Field Name Wellbore Status Ind(°) MD(ORB) Act Btm(MB) 500292154001 KUPARUK RIVER UNIT INJ 32.01 5,900.00 6,890.0 con '.:OPN4ip,rs ' Comment H2S(ppm) Date Annotation End Date KB-Ord(R) Rig Release Date Well conrg:-3N-Dari,9l2r2013 44730 PM SSSV:NIPPLE Last WO: 8/18/2013 38.39 3/15/1986 Schematic-Actual _ Annotation Depth(MB) End Date Annotation Last Mod By End Date Last Tag:SLM 6,723.0 9/1/2013 Rev Reason:TAG,PULL PLUG,GLV C/O hipshkf 9/2/2013 HANGER,33- Casing Strings Casing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top Thrd CONDUCTOR 16 15.062 38.0 115.0 115.0 62.50 H-40 WELD Cuing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth TVD)...String Wt...String...String Top Thrd SURFACE 95/8 8.835 36.7 3,622.8 3,618.8 36.00 J-55 BTC Casing Description String 0... String ID...Top(ORB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd PRODUCTION 7 6.276 35.0 6,853.4 6,627.0 26.00 J-55 BT&C Tubing Strings Tubing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd TUBING WO 31/2 2.992 32.5 I 6,535.0 I 6,356.1 I 9.30 I L-80 EUE8rdABMOD IIIT Completion Details Top Depth CONDUCTOR,_ (TVD) Top Incl Nomi 38-175 Top(RKB) /RKB) Fl Rem Description Comment ID(in) 32.5 32.5 -0.64 HANGER FMC Gen IV TUBING HANGER 2.990 NIPPLE 501 lir 500.8 500.8 0.03 NIPPLE CAMCO DS NIPPLE 2.875 In 6,259.5 6,120.4 32.00 LOCATOR GBH LOCATOR SUB w/7-ft Space out 3.000 MI 6,267.1 6,126.9 31.82 PBR BAKER 80-40 PBR 2.990 111 6,286.7 6,143.6 31.33 PACKER BAKER S-3 PACKER 2.875 GAS UFT 6,307.0 6,161.0 31.16 NIPPLE HES'X NIPPLE 2.812 2.606 6,318.9 6,171.1 31.15 PERF TBG EIGHT 3/8"HOLES OFFSET 90 DEGREES-3-12",9.3#,L-80,EUE 8rd 2.960 L. AB Mod'Perforated'Tubing Pup Joint (l 6,534.0 6,355.3 31.29 WLEG MULE SHOE WIRELINE RE-ENTRY GUIDE 2.990 L Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top Depth SURFACE, (TVD) Top Incl 37-3,623 Top(RKB) (MB) r Description Comment Run Date ID(m) 6,760.0 6,547.6 31.83 FISH Two Bull Noses 1.94"x 7"LONG,LOST IN HOLE 9/26/1987 9/26/1987 0.000 6,760.0 6,547.6 31.83 FISH 1.5"DMY wIRK Latch LEFT IN RATHOLE-1/4/1992 1/4/1992 0.000 GAS 3L,969IFT.-- 6,760.0 6,547.6 31.83 FISH Grapple Blades LOST GRAPPLE BLADES 628/1999 6/28/1999 0.000 6,760.0 6,547.6 31.83 FISH PRONG FROM N2.25 CA-2 PLUG LEFT IN THE HOLE 7/192013 0.000 Perforations&Slots Shot GAS LIFT Top(TVD) Btm(TVD) Dens 4.900 _-- Top(RKB)Btm(MB) MKS) (MB) Zone Date OR- Type Comment 6,460.0 6,470.0 6,291.9 6,300.5 A-3,3N-08 9/26/1987 8.0 APERF 60 deg ph;2 1/8"Silver Jet 6,536.0 6,558.0 6,356.9 6,375.7 A-3,3N-08 1/6/1991 6.0 RPERF 0 deg ph;2 1/8"DynaStrip 6,544.0 6,545.0 6,363.7 6,364.6 A-3,3N-08 6/5/1986 1.0 APERF 90 deg.ph;SOS 4.5"Csg Gun GAS LIFT 5 611 6,547.0 6,548.0 6,366.3 6,367.2 A-3,3N-08 6/5/1986 1.0 APERF 90 deg.ph;SOS 4.5"Csg Gun 6,560.0 6,590.0 6,377.4 6,403.0 A-2,3N-08 4/27/1986 4.0 IPERF 90 deg.ph;4.5"Csg gun 6,601.0 6,607.0 6,412.6 6,417.6 A-1,3N-08 4/27/1986 4.01 IPERF 90 deg.ph;4.5"Csg gun GAS LIFT, Notes:General&Safety ¢ 6,203 A End Date Annotation 6/22/1994 NOTE:WAIVERED WELL:Tx IA COMMUNICATION 7/30/2012 NOTE:LEAKS DETECTED @ 6300'PACKER&6246'GLM 8/182013 NOTE:1484 bbls of 11.7 ppg NaCI/NaBr lost to formation during 2013 RWO LOCATOR. 6,259 PBR,6,267 } l PACKER,6,267 NI NIPPLE.6,307 IIIIIII PERF TBG, 6.319 EEL IN as 6,460.6,470 APERF,_ WLEG,6,53NIL 4 .ii APERF, 6,544.6,545 �_;'3 [ RPERF, 6,5 36-6,558 F. Mandrel Details 6,547-6,548 l` Top Depth Top Port ii S,-, (TVD) Incl OD Valve Latch Size TRO Run N...Top(RKB) MB) (°) Make Model (in) Sets Type Type (in) (Psi) Run Date Com... IPERF, 1 2,608.3 Z607.7 3.53 Cameo MMG W 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/17/2013 6' 2 3,969.5 3,964.2 2.75 Cameo MMG W 1 12 GAS LIFT DMY RK 0.000, 0.0 8/172013 IPERF, ,607 - 3 4,900.1 4,892.5 9.47 Cameo MMG W 1 12 GAS LIFT DMY RK 0.000 0.0 8/17/2013 FISH,6 FISH,6,760, 4 5,610.6 5,563.6 28.03 Cameo MMG W 1 12 GAS LIFT DMY RK 0.000 0.0 8/17/2013 FISH,6,760 FISH,6760 \V\ FISH,6,760 I, 5 6,202.8 6,072.1 32.75 Cameo MMG W 1 12 GAS LIFT DMY RK 0.000 0.0 9/12013 prpr ;57 4 7 PRODUCTION. I 356.853 TD(3N-08A). 6.890 Roby, David S (DOA) From: Ohlinger,James J <JamesJ.Ohlinger@conocophiiiips.com> Sent: Thursday,January 23, 2014 1:30 PM To: Roby, David S (DOA) Cc: Venhaus, Dan E Subject: RE: [EXTERNAL]RE:Sundry Application for well KRU 3N-08A 3N-08A is part of the A-sand redevelopment effort and targets to provide support to 3N-19, an A-sand only producer in a potentially sealed up fault block. We have a relatively thin C that contains less than 15% of the resource in the area. With our CTD wells we also typically do not target both sands because of hydraulic competition issues between the better perm C-sands and lower perm A-sands. Sent from iPhone Original Message From: Roby, David S (DOA) [dave.roby@alaska.gov] Sent: Thursday, January 23, 2014 04:28 PM Central Standard Time To: Ohlinger, James J Cc: Venhaus, Dan E Subject: [EXTERNAL]RE: Sundry Application for well KRU 3N-08A I would like a little more information on the Kup C in terms of whether or not it has been fully swept in the area of the existing well and if not if other wells in the area would be capable of sweeping/recovering any potential remaining reserves? Thanks, Dave Roby (907) 793-1232 From:Ohlinger,James 3 [mailto:James.J.OhlingerOconocophillips.com] Sent:Thursday,January 23, 2014 6:57 AM To: Roby, David S (DOA) Cc: Venhaus, Dan E Subject: RE: Sundry Application for well KRU 3N-08A The CTD Project has been about an Kup A sand redevelopment. With the seismic programs in the last couple years we are gathering a better understanding of our Injector-Producer layout and increasing the efficiency of these pairs. Danny can elaborate more if needed. 1 From: Roby, David S(DOA) [mailto:dave.robyaalaska.gov] Sent: Wednesday,January 22, 2014 6:03 PM To: Ohlinger,James J Subject: [EXTERNAL]Sundry Application for well KRU 3N-08A James, I'm reviewing the referenced sundry and have a question. The current well has Kup A and Kup C perfs but the proposed well is planned as a dual lateral in the Kup A only. Why is the proposed well targeting only Kup A in this area? Is it due to the Kup C being depleted in this portion of the pool already or some other reason? Thanks in advance, Dave Roby Sr. Reservoir Engineer Alaska Oil and Gas Conservation Commission (907) 793-1232 2 RECEIVED STATE OF ALASKA ALAMOIL AND GAS CONSERVATION COMMI ION SEP 1 7 2013 REPORT OF SUNDRY WELL OPERATIONS rAOGCC 1.Operations Performed: Abandon r Repair w ell liv Plug Perforations r Perforate r Other Alter Casing r Pull Tubing P Stimulate-Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 186-068 • 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service . 50-029-21540-01. 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25521 • 3N-08A " 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Kuparuk River Oil Pool ' 11.Present Well Condition Summary: Total Depth measured 6890 feet Plugs(measured) none true vertical 6658 feet Junk(measured) 6760 Effective Depth measured 6767 feet Packer(measured) 6287 true vertical 6555 feet (true vertical) 6144 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 115 115 SURFACE 3586 9.625 3623 3619 PRODUCTION 6818 7 6853 6627 NOV 1 4 Z013 Perforation depth: Measured depth: 6460-6470,6536-6558,6560-6590,6601-6607 True Vertical Depth: 6292-6301, 6357-6376,6377-6403,6413-6418 Tubing(size,grade,MD,and TVD) 3.5, L-80,6535 MD,6356 TVD Packers&SSSV(type,MD,and TVD) PACKER-BAKER S-3 PACKER @ 6287 MD and 6144 TVD NIPPLE-CAMCO DS NIPPLE @ 501 MD and 501 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): none Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service r• Stratigraphic r 16.Well Status after work: Oil r Gas r VVDSPL r Daily Report of Well Operations XXX GSTOR r VVINJ WAG 17 GINJ r SUSP r SPLUG r 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: 313-380 Contact Brett Packer(cry,265-6845 Email J.Brett.Packer(a),conocophillips.com Printed Name Brett Packer Title Wells Engineer Signature �%� l Phone:265-6845 Date .7/4 0 lil'' Alf/0/ /, RBDMS OCT 11 24 /0//5113 Form 10-404 Revised 10/2012 Submit Original Only $ KUP INJ 40 3N-08A ConocoPhillips O= Well Attributes Max Angle&MD TD„mu Naska,Inc. Wellbore API/UWI Field Name Wel!bore Status Inc/(°) MD(RUB) Act Btm MB) CarocoPhillips 500292154001 KUPARUK RIVER UNIT INJ 32.01 5,900.00 6,890.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date ••• WeliContlo .3N-0BA9PL20134:47:30 PM SSSV:NIPPLE Last WO: 8/182013 38.39 3/15/1986 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Lest Mod By End Date Last Tag:SLM 6,723.0 9/12013 Rev Reason:TAG,PULL PLUG,GLV C/O hipshkf 9/2/2013 HANGER,33 Irnr Casing Strings Casing Description String 0... String ID...Top(MB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd CONDUCTOR 16 15.062 38.0 115.0 115.0 62.50 61-40 WELD Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd SURFACE 95/8 8.835 36.7 3,622.8 3,618.8 36.00 J-55 BTC r Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt..String...String Top Thrd PRODUCTION 7 6.276 35.0 6,853.4 6,627.0 26.00 J-55 BT&C Tubing Strings Tubing Description 1 String 0... String ID,..[Top(ftKB) Set Depth(f...Set Depth(TVD)... String Wt...String... String Top Thrd TUBING WO 31/2 I 2.992 I 32.5 f 6,535.0 6,356.1 l 9.30 L-80 I EUEBrdAB MOD is Completion Details Top Depth CONDUCTOR,_ (ND) Top Inc! Nomi... 36115 Top(ftKB) (MB) r) Item Description Comment ID(in) IE 32.5 32.5 -0.64 HANGER FMC Gen IV TUBING HANGER 2.990 NIPPLE.501 - 500.8 500.8 0.03 NIPPLE CAMCO DS NIPPLE 2.875 I 6,259.5 6,120.4 32.00 LOCATOR GBH LOCATOR SUB w/7-ft Space out 3.000 .:. 6,267.1 6,126.9 31.82 PBR BAKER 80-40 PBR 2.990 Mkt 6,286.7 6,143.6 31.33 PACKER BAKER S-3 PACKER 2.875 GAS LIFT, I 6,307.0 6,161.0 31.16 NIPPLE HES'X NIPPLE 2.812 2,608 6,318.9 6,171.1 31.15 PERF TBG EIGHT 3/8"HOLES OFFSET 90 DEGREES-3-1/2",9.38,L-80,EUE 8rd 2.960 AB Mod'Perforated'Tubing Pup Joint U f'1 ' 6,534.0 6,355.3 31.29 WLEG MULE SHOE WIRELINE RE-ENTRY GUIDE 2.990 Other In Hole(TWireline retrievable plugs,valves,pumps,fish,etc.) Top Depth SURFACE, ' (NO) Top loci 37-3,623 Top(ftKB) (ftKB) (") Description Comment Run Date ID(in) 6,760.0 6,547.6 31.83'FISH Two Bull Noses 1.94"x 7"LONG,LOST IN HOLE 9/26/1987 9/26/1987 0.000 r_.-; 6,760.0 6,547.6 31.83 FISH 1.5"DMY w/RK Latch LEFT IN RATHOLE-1/4/1992 1/4/1992 0.000 GAS LIFT, 6,760.0 6,547.6 31.83 FISH Grapple Blades LOST GRAPPLE BLADES 6/28/1999 6/28/1999 0.000 3,969 6,760.0 6,547.6 31.83 FISH PRONG FROM N2.25 CA-2 PLUG LEFT IN THE HOLE 7/19/2013 0.000 Perforations&Slots Shot GAS LIFT. _. 5 Top(ND) Btm(TVD) Dens 4.900 Top(ftKB)Btm(ftKB) (ftKB) (ftKB) Zone Date (Sh... Type Comment 6,460.0 6,470.0 6,291.9 6,300.5 A-3,3N-08 9/26/1987 8.0 APERF 60 deg ph;2 1/8"Silver Jet Mg 6,536.0 6,558.0 6,356.9 6,375.7 A-3,3N-08 1/6/1991 6.0 RPERF 0 deg ph;21/8"DynaStrip 6,544.0 6,545.0 6,363.7 6,364.6 A-3,3N-08 6/5/1986 1.0 APERF 90 deg.ph;SOS 4.5"Csg Gun GAS LIFT, 5.611 1 6,547.0 6,548.0 6,366.3 6,367.2 A-3,3N-08 6/5/1986 1.0 APERF 90 deg.ph;SOS 4.5"Csg Gun 6,560.0 6,590.0 6,377.4 6,403.0 A-2,3N-08 427/1986 4.0 IPERF 90 deg.ph;4.5"Csg gun *' 6,601.0 6,607.0 6,412.6 6,417.6 A-1,3N-08 4/27/1986 4.0 IPERF 90 deg.ph;4.5"Csg gun MI GAS LIFT, t Notes:General&Safety 6,203 -._�. End Date Annotation 6/22/1994 NOTE:WAIVERED WELL:Tx IA COMMUNICATION 7/30/2012 NOTE:LEAKS DETECTED @ 6300'PACKER&6246'GLM ......11111 . 8/18/2013 NOTE:1484 bbls of 11.7 ppg NaCI/NaBr lost to formation during 2013 RWO LOCA6,2TOR, 59 PBR,6,267 PACKER.6,287 cam: III NIPPLE.6,307 1 PERF Ens, 6,319 tit It I APERF, 6,460.ERF. tn- III es WLEG,6,534 S APERF, 8,5446,545 RPERF. 6,536-6,558 APERF. Mandrel Details 6,547-6,548 Top Depth Top Port 5,,, (ND) not OD Valve Latch Sine TRO Run N...Top(ftKB) (ftKB) (°l Make Model (in) Sery Type Type (in) (pet) Run Date Coin... IPERF, 1 2,608.3 2,607.7 3.53 Camco MMG W 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/172013 i 6,560-6,590 2 3,969.5 3,964.2 2.75 Camco MMG W 1 12 GAS LIFT DMY RK 0.000 0.0 8/172013 6,601PE6, IRF, 3 4,900.1 4,892.5 9.47 Camco MMG W 1 1/2 GAS LIFT DMY RK 0.000 0.0 8/172013 607 FISH,6,760 -�- 4 5,610.6 5,563.6 28.03 Camco MMG W 1 12 GAS LIFT DMY RK 0.000 0.0 8/17/2013 FISH,6,760 FISH,6,760 5 6,202.8 6,072.1 32.75 Camco MMG W 1 12 GAS LIFT DMY RK 0.000 0.0 9/12013 FISH,8,760 lit I PRODUCTION. 35-6.853 1 TD(3N-08A), 6,890 • 3N-08A Pre and Post Well Work Sugary Pre-Workover Well Work DATE SUMMARY 6/29/2013 PULL 2.25" CA-2 @ 6337' RKB &TAG FILL @ 6555'SLM (EST. 24' OF FILL). RETURN IN 24 HOURS FOR BHP. 7/1/2013 MEASURE BHP (3720psi) @ 6570' RKB & SET CA-2 @ 6337' RKB. JOB COMPLETE 7/18/2013 SET 69"x 2.29" CATCHER @ 6319' SLM. PULLED 1-1/2" PACK-OFF DV @ 6246' RKB. IN 7/19/2013 PULLED CATCHER @ 6319' SLM. PULLED 2.25" CA-2 PLUG @ 6337' RKB. SWEEP TBG w/KJ, KJ, 2.5"JD; PRONG FROM 2.25" CA-2 PLUG LEFT IN HOLE. READY FOR DHD/BPV. 7/23/2013 (PRE-RWO)T POT- PASSED; T PPPOT- PASSED; IC POT- PASSED; IC PPPOT-FAILED (TORQUED LDS TO 550FT LBS. WOULD NOT HOLD MORE THAN 800PSI.) ALL LDS FUNCTIONAL 7/24/2013 (PRE RWO) MIT-OA(PASSED)TO 1800 PSI. Post-Workover Well Work 9/1/2013 SET CATCHER @ 6307' RKB; PULLED SOV& REPLACED W/ DV @ 6203' RKB (MITIA TO 3000 PSI/ PASS); PULLED CATCHER& 2.81"XX PLUG @ 6307' RKB; TAG TD @ 6749' RKB (EST. 142' RAT HOLE). JOB COMPLETE. • • ConocoPhillips Time Log & Summary WelMiew Web Reporting Report Well Name: 3N-08 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 8/11/2013 9:00:00 AM Rig Release: 8/18/2013 4:30:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 38/10/2013 24 hr Summary Release rig from 3N-01 and change out kelly swivel 20:00 00:00 4.00 MIRU MOVE MOB P Rig repairs during rig move. Swivel, riser and wash pipe. 38/11/2013 Change out kelly swivel and MIRU on 3N-08, accept Nordic 3. Attempted to kill well with 11.4 Brine.Weight up brine to 12# 00:00 09:00 9.00 MIRU MOVE MOB P Rig repairs during rig move. Swivel, riser and wash pipe.07:00 begin to move rig, lay down secondary containment in cellar and rig mats spot over 3N-08. 09:00 13:00 4.00 MIRU MOVE RURD P **Rig Accept 09:00**-Spot cutting tanks, rig up hard lines to kill tank, cellar and choke manifold. Load pits with 11.3+ppg NaCI/NaBr brine. 13:00 15:00 2.00 MIRU WHDBO MPSP P RU Lubricator for pulling BPV, PT lubricator @ 1,800 psi-good test. Pull BPV and lay down lubricator. OA-300 psi; IA-750 psi;TBG- 1,500 psi 15:00 18:00 3.00 MIRU WELCTL RURD P PJSM, RU hoses from well to manifold and from choke manifold to the kill tank. PT kill lines to 3000 psi 18:00 22:00 4.00 COMPZ WELCTL KLWL P SITP= 1250 psi. SIC=800 PSI . SPR @ 20 SPM=800 psi @ 880 psi @ 40SPM. Reversed circulated in 11.3 heavy brine=302 BBLs to get 11.3 heavy to surface.SIT bull headed 10 bbls to bottom perf @ 6607. SD pumps 250 psi on well. bled down pressure both IA&tubing flowing. SW recored SIP Cal. New kill wt mud 22:00 00:00 2.00 COMPZ WELCTL KLWL X weight up to new kil weight brine to 12# 38/12/2013 Killed well with 225 BBLS of 12#brine. ND tree, NU BOPE Test BOPE 00:00 02:00 2.00 COMPZ WELCTL CIRC X Reverse circulate 225 BBLS of 12# brine @ 2 BPM @ 200 psi.ICP. FCP 115 psi. 02:00 02:30 0.50 COMPZ WELCTL OPNW P Flow check well.for 30 mins. 02:30 03:00 0.50 COMPZ WHDBO MPSP P Set BPV. 03:00 04:30 1.50 COMPZ WHDBO NUND P ND Tree. 04:30 09:30 5.00 COMPZ WHDBO NUND P NU BOPE Page 1 of 6 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:30 16:30 7.00 COMPZ WHDBO BOPE P Conduct Initial BOP test @ 250/ 4,000 psi on rams and 3,500 psi on Annular. Right to witness test was waived by John Crisp @ 06:15 hrs on 8-12-13. Had multiple"Gray loc" fitting leaks(fixed)along with Upper TD(greased and ready for retest) during shell test. : Attempting to get a solid test: 04:30 to 16:30 hrs NU/test BOPE time frame as per contract. 16:30 to 24 hrs monthly contract maintenance less 2 hrs used on 8/5/13 for swivel repair. 1)Blinds, Kill hard line,3-1/2 IF Dart and CM 4,11, 12-Good Test 2)CSO's, Man Kill,3.5 If FOSV, Choke 3,7,9,10, Failed -found valve 10 to be leaking 16:30 00:00 7.50 COMPZ RIGMNT BOPE T Conduct Initial BOP test @ 250/ 4,000 psi on rams and 3,500 psi on Annular. Right to witness test was waived by John Crisp @ 06:15 hrs on 8-12-13. (2)retest CSO's, Man Kill,3.5 If FOSV,Choke 3,7,9,10, pass. (3)CSO's, HCR kill 3.5 8rd. Choke 2,5,8, Pass (4)TD Man,choke 2,5,6 PAss. (5)LWR Pipe rams 3.5 TJ Choke 1, Pass. (6) Annular 3.5 TJ.--4 Way valve on Accumulator failed replaced valve. Retest same. Failed 38/13/2013 Continue to test BOPE. Pulled BPV circulated bottoms up reverse. Pulled seal assembly free @ 40 K POOH laying down production tubing 00:00 01:30 1.50 COMPZ RIGMNT BOPE T Continue with test#6)Annular,w/ 3.5 TJ Choke#2.system still leaking. Replaced inner seals on annular that was swapped on 5-23-13 during the following operation(Release Nordic rig 3 from 1Y-19 at 10:30 hrs, Breakdown existing 11"5M Class III BOP stack for inspection and Pick up New 11"5M class III BOPE. prior to moving Nordic rig 3 from 1Y-Pad to 1E Pad.) The remaining contract maintenance hours were used up @ 01:30 hrs on 8-13-13. Nordic Rig is now on non-revenue Down time. Page 2 of 6 Time Logs • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:30 08:00 6.50 COMPZ RIGMN1 RGRP T Continue to replace inner seals on annular on non-revenue Down time. 08:00 13:00 5.00 COMPZ RIGMN7 BOPE T PJSM,Continue to test BOPE. Annular failed while testing 2-7/8 test joint. 13:00 16:00 3.00 COMPZ RIGMN7 RGRP T Pull and replace annular element 16:00 16:30 0.50 COMPZ RIGMNT BOPE T Test annular, manual kill,and CM 2,5,6 16:30 17:30 1.00 COMPZ WHDBO MPSP P Drain BOP stack and pull blanking plug. Tap BPV-no pressure. Release BPV and pull out w/dry rod. 17:30 18:00 0.50 COMPZ WHDBO THGR P MU 2-7/8 landing pup joints,and top drive. 18:00 19:30 1.50 COMPZ WELCTL CIRC P Revesed circulated @ 3 BPM @ 160 Psi ICP, Final 240 psi. 128 total vol. circulated.Well took 35 bbls to catch circulation 19:30 20:00 0.50 COMPZ WELCTL OWFF P Flkow check well for 30 min's. 20:00 21:00 1.00 COMPZ RPCOM PULL P BOLDS. pulled seal assembly free @ 75 K laid down hanger. RU Camco spooler. 21:00 00:00 3.00 6,370 4,340 COMPZ RPCOM PULL P POOH with 2 7/8 J-55 EUE 8rd tubing string and Jewelry. Recover 29 bands from cap.tubing. 38/14/2013 RIH with BHA 1 Spear assembly released Brown packer. Lighted KWM to 11.5 circulated well&monitor 14 BBI influx.weight up to 11.7 circulate in KWM. monitor well.static. POOH with packer to 920 ft. 00:00 06:00 6.00 4,340 0 COMPZ RPCOM PULL P Continue to POOH with production string. Offload from rig and clean floor. Change out floor equipment. 06:00 07:00 1.00 0 0 COMPZ RPCOM OTHR P Set wear ring 07:00 09:15 2.25 0 304 COMPZ RPCOM PULD P PJSM, MU and RIH w/BHA#1 to 304-ft 09:15 10:30 1.25 304 304 COMPZ RPCOM OTHR P Shuffle DP in derrick from rig move. 10:30 13:00 2.50 304 6,210 COMPZ RPCOM TRIP P Trip in with BHA#1 with DP from derrick to 6,210-ft 13:00 15:00 2.00 6,210 6,285 COMPZ RPCOM FISH P Break circulation,taking 37 bbls to fill hole, circulate bottoms up. Gather SPR and 115k do wt, 135k up wt. RIH to 6,280-ft and set down 7k. Straight pull to 175k,bleed jars and straight pull to 200k. Cycle jars 7 times at 40k osw and packer came free. RIH to 6,285-ft to verify packer released-5-ft past set depth. Monitor well on trip tank-14 bbls to fill and lost 21 bbls in 10 minutes after. 15:00 17:00 2.00 6,285 6,285 COMPZ RPCOM CIRC P Cut back KWF from 12.0 ppg to 11.5 ppg and swap well over to 11.5 ppg @ 6 bpm @ 2,300 psi. for 1.5 hole volumes circulated. Page 3 of 6 Time Logs • • • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:00 18:00 1.00 6,285 6,285 COMPZ RPCOM OWFF P Monitor well on trip tank with a 17 bbl gain 18:00 19:00 1.00 6,285 COMPZ RPCOM CIRC P Wieght up brine to 11.7#circulated 287 BBLs of 11.7 brine. ICP 2070 psi @6 BPM. FCP 2180 @ 6 BPM. 19:00 20:00 1.00 COMPZ RPCOM OWFF P Flow check well. no flow 20:00 20:06 0.10 6,284 690 COMPZ RPCOM TRIP P POOH with packer and spear assembly. 38/15/2013 Cleaned out with mill assembly to 6760 ft. POOH. MU RIH with BHA#3 Scraper assembly to 6760 ft. circulated well clean and spotted Heavy salt pill for fluid loss. 00:00 02:00 2.00 690 0 COMPZ RPCOM TRIP P Continue to POOH laid down brown packer and spear. Kick out tools. 02:00 04:30 2.50 0 6,528 COMPZ WELLPF TRIP P MU&RIH with BHA#2 Milling assembly 04:30 05:30 1.00 6,528 6,570 COMPZ WELLPF FCO P Est. circulation to ensure that mill is clear. Up wt. 125 K, Dwn wt 115K tagged @ 6532 ft Circulated @ 6 BPM @ 1485 Psi. Cleaned out to 6,570-ft. increase of torque taking 15K of bit weight. Recoving Silica sand. 05:30 07:45 2.25 6,570 6,581 COMPZ WELLPF MILL P Milling thru 7"casing damage in perfs from 6,570-ft to 6,581-ft @ 80 rpms w/2 to 6k torque,circulating at 8 bpm @ 2,570 psi w/2 to 18k WOM. 07:45 09:30 1.75 6,581 6,760 COMPZ WELLPF FCO P Continue to clean out fill from 6,581-ft to 6,760-ft Rotating @ 80 rpms @ 2,200 ft/lbs.torque. Circulating @ 8 bpm @ 2,584 psi. 09:30 11:00 1.50 6,760 6,760 COMPZ WELLPF CIRC P Circulate 3 ppb Flo zan 25 bbl sweep from surface to surface @ 5 bpm @ 800 psi--while reciprocating Had 44 bbl loss during circulation. 11:00 12:30 1.50 6,760 6,760 COMPZ WELLPF OWFF P Monitor well for flow-- 6.1 bbl gain in 70 minutes-ballooning then 1.1 bbl loss for the next 20 minutes 12:30 16:45 4.25 6,760 314 COMPZ WELLPF TRIP P POOH w/3-1/2 DP to 314-ft 16:45 17:30 0.75 314 0 COMPZ WELLPF PULD P POOH and lay down Mills - 17:30 18:30 1.00 0 COMPZ WELLPF OTHR P Cleaned BOPE with jetting nozzle 18:30 22:00 3.50 0 6,760 COMPZ WELLPF TRIP P MU and RIH with BHA#3 Scraper assembly to 6760 ft. 22:00 00:00 2.00 6,760 COMPZ WELLPF CIRC P Circulated 300 bbls of 11.7 brine @ 6 BPM @ 1320 Psi.followed with 30 BBL heavy salt vis pill.W/42 bbls of 11.7 brine pumping @ 2 BPM @ 140 psi. 08/16/2013 RIH with 7"storm packer.Set packer @ 100 ft and tested to 1615 Psi =3000 eqv.test. ND BOPE&tubing spool replaced seals installed new tubing spool. PT 250/3000 Psi. NU BOPE Flange test to 250/4000 psi. Released storm packer and POOH with packer and scraper assembly laying down DP and tools 00:00 00:30 0.50 COMPZ WELLPF OWFF P Flow check 30 min's. 00:30 01:00 0.50 6,760 5,885 COMPZ WELLPF TRIP P POOH to 5885 ft up wt=128K Page 4 of 6 Time Logs . • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:00 02:30 1.50 5,885 5,885 COMPZ WELLPF EQRP P cut/slpi drilling line 02:30 06:00 3.50 5,885 2,300 COMPZ WELLPF PULD P POOH with scraper assembly laying down drill pipe to 2300 ft. 06:00 07:00 1.00 2,300 97 COMPZ WELLPF PACK P PJSM, PU storm packer and set 109-ft center of element w/top @ 97-ft. 07:00 08:00 1.00 97 97 COMPZ WELLPF PRTS P Pressure test Storm packer @ 1600 psi for 15 minutes.-good test. 08:00 17:00 9.00 97 97 COMPZ WHDBO NUND P PJSM, ND BOPE and TBG Spool- No casing growth. Change out pack off. NU"New"TBG Spool. PT voids -250/3,000-good test. NU BOPE. 17:00 18:00 1.00 97 97 COMPZ WHDBO BOPE P Install Test plug and Shell test BOPE @ 250/4,000 psi-Good Test. Pull test plug. 18:00 19:30 1.50 97 2,300 COMPZ WHDBO PACK P RIH and Retrieve Storm packer and POOH laying down same. 19:30 00:00 4.50 2,300 0 COMPZ WELLPF PULD P POOH laying down 3-1/2 DP and BHA#3 38/17/2013 RIH with completion. RU schlumberger slickline ASEP unit.cor.tubing to correct depth for setting and set X plug @6301' RD Schlumberger. spaced out packer and set. PT IA to 500 psi.spaced out seals.circulated with treated sea water. landed hanger. PT TBG.to 2500 psi. PT IA to 3500 psi.sheared SOV. 00:00 09:00 9.00 0 6,498 COMPZ RPCOM PULD P Prep equipment for 3.5 EUE 8rd. Pick up and RIH with Baker S-3 packer assembly and production equipment as per program. 09:00 17:00 8.00 6,498 6,535 COMPZ RPCOM SLKL P RU and RIH w/Digital slickline w/x plug, Drop out of tubing completion and locate csg collar. Corrolate and Needed to move TBG string down to place Wleg @ 6,535-ft RKB Corrected. Spot 25 bbls of CI 11.7 ppg brine at TBG tail. Set X plug in Nipple @ 6,307-ft. POOH and RD slick line 17:00 18:00 1.00 6,535 6,535 COMPZ RPCOM PACK P Move pipe to corrected depth, Pressure up to 2,100 psi and set S-3 Packer @ 6,287-ft. 18:00 19:30 1.50 6,535 6,535 COMPZ RPCOM THGR P Spaced out tubing 7.5 ft expansion @ seals 19:30 22:30 3.00 6,535 COMPZ RPCOM CIRC P Pumped 6 BBL vis pill followed by 220 bbls of treated 8.6 sea water @ 2 BPM @ 360 psi. 22:30 23:30 1.00 COMPZ RPCOM PRTS P PT tubing to 2500 psi for 10 min's. PT IA to 3500 PSI for 30 min's chart recorded. Blew SOV @ 2500 psi. 23:30 00:00 0.50 COMPZ WHDBO MPSP P Set BPV and PT to 1000 psi from IA in flow direction 08/18/2013 Set BPV test to 1000 psi. ND BOPE. NU Tree.freeze protect with 80 bbls diesel. RDMO Release Nordic rig 3 @ 16:30 hrs 00:00 06:00 6.00 0 0 COMPZ WHDBO NUND P PJSM, Open Ram doors and inspect cavaties. Change out lower 2-7/8 x 5"VBR packer and Top seals. ND BOPE Page 5 of 6 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 08:00 2.00 0 0 COMPZ WHDBO NUND P PJSM, NU 3-1/8"5M tree. Tree Orientation was verified by Steve Page. 08:00 09:00 1.00 0 0 COMPZ WHDBO PRTS P Test hanger void @ 250/5,000 psi for 10 minutes-Good Test. 09:00 11:00 2.00 0 0 COMPZ WHDBO MPSP P Pull BPV-Well slightly out of balance-Attempt to U-tube well for 30 minutes. PU lubricator--Unable to lubricate tree test plug into place as this is against FMC Policy. 11:00 11:30 0.50 0 0 COMPZ WHDBO OWFF P Monitor well)for flow for 30 minutes. After flowing back 15 bbls to cuttings box. 11:30 13:30 2.00 0 0 COMPZ WHDBO MPSP P Set tree test plug,test tree @ 250/ 5,000 psi--Good test. Pull tree test plug. 13:30 15:15 1.75 0 0 COMPZ RPCOM FRZP P PJSM w/LRS. PT lines @????and pump 80 bbls of diesel w/60 bbls recovered w/702 psi SIP. Open up well and allow to swap-446 psi static after 5 minutes. 15:15 16:00 0.75 0 0 COMPZ WHDBO MPSP P Lubricate in BPV and RD lubricator. Bleed pressure from tree and NFT BPV w/446 psi Well bore pressure.- good test. 16:00 16:30 0.50 0 0 COMPZ RPCOM OTHR P Clean and dress tree **Release Nordic rig 3**at 16:30 hrs. Page 6 of 6 MMINVINNIN to • • THE STATE Alaska Oil and Gas °ALASKA Conservation Comissi n GOVERNOR SEAN PARNELL 333 West Seventh Avenue O Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Brett Packer Sati N��1 LOS Wells Engineer ConocoPhillips Alaska, Inc. 4 ss 6 06 P.O. Box 100360 ` Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3N-08A Sundry Number: 313-380 Dear Mr. Packer: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy '. Foerster Chair DATED this I day of August, 2013. Encl. STATE OF ALASKA p( RECEIVED ALA OIL AND GAS CONSERVATION COM•ION • APPLICATION FOR SUNDRY APPROVALS $/1 JUL 17 0 20 AAC 25.280 Ian F 13 1.Type of Request: Abandon Rug for Redrill r Perforate New Pool Repair w ell Change A •"° +4t4 a1 r Suspend 1 Rug Perforations r Perforate r Pull Tubing Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate )f Alter casing Other: "" 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 186-068 • 3.Address: Stratigraphic r Service SI. 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-21540-01. 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order govems well spacing in this pool? Will planned perforations require spacing exception? Yes is No Pr 3N-08A. 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25521. Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 6890 . 6658 J 6767' 6555' .6337' . 6585,6593,6597 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 115' 115' SURFACE 3586 9.625 3623' 3619' PRODUCTION 6818 7 6853' 6627' Perforation Depth MD(ft): • Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 6460-6470,6536-6558,6560-6590,6601-6607 6292-6301,6357-6376,6377-6403,6413-6418 2.875 J-55 6370 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft) PACKER-BROWN HB-1 PACKER " MD=6300 ND=6155 SSSV-BAKER SSSV " MD=1764 TVD=1764 12.Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory r Stratigraphic Development Service t 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 8/1/2013 Oil Gas r WDSPL r Suspended 16.Verbal Approval: Date: WINJ ‘ GINJ r WAG Abandoned Commission Representative: GSTOR r SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Brett Packer @ 265-6845 Email: J.Brett.Packer@conocophillios.com Printed Name Brett Packer Title: Wells Engineer �� Signature . Phone:265-6845 Date 7-/(&(// Commission Use Only Sundry Number 3_53-o Conditions of approval: Notify Commission so that a representative may witness Plug Integrity f BOP Test Mechanical Integrity Test r Location Clearance F- RBDMS AUG - 21 Other. 0 d p tts f fv , c, F5 c Spacing Exception Required? Yes ❑ No [ I Subsequent Form Required: /0 4 a 4'- APPROVED BY p Approved by pr ed application is vaRiRY l�.F9n�IRths from thTLNFl�tgt` I �r val• Date: D"/ - /3 Form 10-403(Re sed 10/2012) lL�r ORIGINAL Submit Form and Attachments in Duplicate vo x\rf -1131 ) 13 � �C (�.��� �J s • Nov' RECEIVED ConocoPhillips JUL 17 2013 Alaska P.O. BOX 100360 AOGGC ANCHORAGE,ALASKA 99510-0360 July 16,2013 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 an Application for Sundry Approval to workover Kuparuk Well 3N- 08A(PTD# 186-068). 3N-08 was drilled in March 1986,but the open-hole logs determined zero feet of net pay in both the A&C sands,so the original wellbore was never completed. 3N-08 was plugged back and sidetracked to its present location and became 3N-08A. This well pre-produced for approximately 5 years prior to being converted to an injector. The well remained on injection up until October 2011 when it was shut-in for TxIA communication. This well was chosen as a CTD candidate to redevelop a faulted area with low throughput. As such, the well requires a workover to upsize the existing completion, as CTD requires a minimum of 3 'h" tubing to work in. Following the RWO, a separate Application for Sundry Approval will be required for the cementing of the perforations and CTD sidetrack. This proposed workover will simply pull the existing 2 '/8"tubing, cleanout the well to PBTD, and re-install a 3 '/2" completion. This Sundry is intended to document the proposed work on this injection well. If you have any questions or require any further information,please contact me at 265-6845. Sincerely, Brett Packer Wells Engineer CPAI Drilling and Wells • • 3N-08A Ri g Workover Pull 2 '/8" Completion, Upsize to 3 1/2" (PTD #: 186-068) Current Status: This well has a tubing leak and is currently shut-in awaiting a workover. Scope of Work: Pull the 2'/8"tubing&packer,cleanout to PBTD,re-install a 3 '/2"completion. General Well info: Well Type: Injector MPSP: 1,500 psi using maximum recent SITP/SICP on 7/1/13. Reservoir Pressure/TVD: 3,720 psi/6,386' TVD(11.2 ppg)from Panex gauges on 7/1/13. Wellhead type/pressure rating: FMC Gen 3,7-1/16"5M psi top flange BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT results: MIT-T failed on 5/17/12 MIT-IA passed on 5/17/12 CMIT-TxIA passed on 5/17/12. Earliest Estimated Start Date: August 1,2013 Production Engineer: Toon Changklungdee/Suzanne Short Workover Engineer: Brett Packer(265-6845/j.brett.packer @cop.com) Pre-Rig Work 1. RU Slickline: a. Set catcher sub on top of plug at 6,337' MD. b. Pull GLV from GLM#7 @ 6,246' MD. c. Pull catcher sub. d. Pull CA-2 plug from D-nipple at 6,337' MD. 2. PT tubing and casing packoffs,FT LDS's. 3. Set BPV w/i 24 hrs of rig arrival. Proposed Procedure 1. MIRU. 2. Pull BPV. Reverse circulate 11.7 ppg mud. Obtain SITP&SICP,if still seeing pressure at surface,calculate new KWF,weight up,and repeat circulation as necessary. Verify well is dead. 3. Set BPV&blanking plug,ND tree,NU BOPE&test. 6 0/-7. 7f5 746 o°r' S c 4. Pull blanking plug&BPV,screw in landing joint,BOLDS's,un-land tubing hanger. 5. POOH laying down tubing. a. If tubing will not pull free,RU E-line: Fire a string shot and cut the tubing in the middle of the first full joint above the PBR. b. If tubing was cut,RIH w/overshot&grapple and pull seal assembly from PBR. 6. RIH w/spear,latch onto packer and pull packer&tailpipe. 7. RIH w/double string mill cleanout assembly down to PBTD at 6,767' MD. Reverse circulate well clean. 8. MU packer and tailpipe assembly,RIH on drillpipe to 6,700' MD. 9. RU E-line: RIH w/GR/CC1,tie into K-1 marker at 6,267' MD as referenced to the CET log dated 4/7/86.RD E-line. 10. Make depth correction,spot corrosion inhibited mud in the IA below the packer. Set the packer,PT IA to 1,500 psi to confirm packer set. Release from packer. 11. Swap out drilling mud to 9.6 ppg NaCl brine. 12. POOH laying down drillpipe. • • 3N-O8A Rig Workover Pull 2 '/8" Completion, Upsize to 3 '/2" (PTD #: 186-068) 13. MU seal assembly and 3 V2"gas lift completion,sting into PBR until fully located,pull up to neutral weight plus 7',pull out of PBR. 14. Space out w/pups,MU hanger. Load well w/corrosion inhibited brine. Land the hanger,RILDS. 15. PT the tubing to 2,500 psi,while holding 2,500 psi on the tubing,PT the IA to 3,500 psi for 30 min and record. Bleed the IA to zero,then the tubing. Ramp up the IA pressure quickly to shear the SOV. Bleed tbg to zero, then IA. 16. Pull the landing joint,install BPV,pressure up IA to 1000 psi to test BPV from below. Bleed well to zero. 17. ND BOPE,NU tree. Pull BPV,install tree test plug. Test tree. Pull tree test plug. 18. Freeze protect through the SOV,set BPV. 19. RDMO. Post-Rig Work 1. Pull BPV. 2. RU Slickline: Pull SOV,replace w/DV. 3. Pressure up to shear the shear-out-sub in the tubing tail. 4. Turn well over to operations. it 3N-08A Proposed RWO for CTD Modified by JBP 7-15-13 i 3-1/2" Camco DS nipple at 500' MD (2.875" min ID) 3-1/2" 9.3#L-80 EUE 8rd-Mod Tubing to surface 16"62# H-40 shoe @ 115' MD 3-1/2" Camco gas lift mandrels at 9-5/8" 36#J-55 shoe @ 3623' MD 3-1/2" Camco DS nipple at(2.813" min ID) Baker Model F-1 Permanent packer at–6275' RKB Baker GBH-22 Locator Seal assembly/SBE C-sand erfs p _ ® 5' perforated sub 6460-6470' MD 3-1/2", 9.3 ppf, L-80 tubing tail Critical Depths: Two 40' KO joints @ 6455'to 6535' ELMD (reference SWS CET log 4-7-86) ............wsaan - i A-sand perfs �--- Shear-out Sub (3,500 psi) 6536'-6607' MD -- — ....-- • -77 -4040(r., Casing restriction @ 6568' ELMD 7"26#J-55 shoe @ 6853' MD KUP 3N-08A ,� ConocoPhillips 014 Well Attributes Max Angle&MD TD AfBSitr3 Inc. Wellbore APUUWI Held Name Wellbore Status Inal(°) MD(ftKB) Act Btm(ftKB) _ 500292154001 KUPARUK RIVER UNIT INJ 32.01 5,900.00 6,890.0 "`" Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date ••• Well Congo -3N-OOA,7220131:31:26 PM SSSV:LOCKED OUT Last WO: 38.39 3/15/1986 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 6,555.0 6/29/2013 Rev Reason:RE-SET PLUG,TAG haggea 7/2/2013 Casing Strings _ Casing Description String 0... String ID...Top(11613) Set Depth(f...Set Depth(TVD)...String Wt...String.. String Top Thrd HANGER,33 gill , °+_ CONDUCTOR 16 15.062 38.0 115.0 115.0 62.50 H-40 WELD ,., Casing Description String 0... String ID...Top(MB) Set Depth(L..Set Depth(TVD)...String Wt...String...String Top Thrd `,- SURFACE 95/8 8.835 36.7 3,622.8 3,618.8 36.00 J-55 BTC " Casing Description String 0... String ID...Top(RKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd PRODUCTION 7 6.276 35.0 6,853.4 6,627.0 26.00 J-55 BT&C _ Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(1...Set Depth(TVD)...String Wt..String... String Top Thrd TUBING 27/8 2.441 32.5 6,370.2 6,215.1 6.50 J-55 EUE8rdABMod CONDUCTOR, Completion Details 30-115 Top Depth (TVD) Top Ind Noon... SAFETY VLV, Top(ftKB) (RKB) (°) Kelm Description Comment ID(in) 1.763 32.5 32.5 -0.64 HANGER TUBING HANGER 2.875 1,763.5 1,763.5 0.77 SAFETY VLV BAKER SAFETY VALVE(LOCKED OUT 6/26/1989) 2.310 GAS LIFT, 2,242 6,284.2 6,141.5 31.39 PBR BROWN PBR 2.500 6,299.7 6,154.7 31.17 PACKER BROWN HB-1 PACKER 2.441 r 6,337.3 6,186.8 31.14 NIPPLE CAMCOD NIPPLE 2.250 6,369.6 6,214.5 31.11 SOS CAMCO SHAER OUT SUB 2.441 I Other In Hole Wireline retrievable plugs,valves,pumps,fish,etc.) Top Depth SURFACE._ ,' ' (TVD) Top Inc! 37-3,623 Top(ftKB) (ftKB) (°) Description Comment Run Date ID(in) 6,337.3 6,186.9 31.14 PLUG 2.25"CA-2 PLUG 7/1/2013 0.000 tom'' GAS LIFT, 6,585.0 6,398.8 31.48 FISH Grapple Blades LOST GRAPPLE BLADES 6/28/1999 6/28/1999 3,723 6,593.0 6,405.6 31.50 FISH 1.5"DMY w/RK Latch LEFT IN RATHOLE-1/4/1992 1/4/1992 6,597.0 6,409.0 31.52 FISH Two Bull Noses 1.94"x 7"LONG,LOST IN HOLE 9/26/1987 9/26/1987 GAS LIFT, 4,622 a Perforations&Slots Shot GAS LIFT, Top(TVD) Btm(TVD) Dens 5.149 Top(RKB)Btm(ftKB) (MB) (ftKB) Zone Date (oh... Type Comment 6,460.0 6,470.0 6,291.9 6,300.5 A-3,3N-08 9/26/1987 8.0 APERF 60 deg ph;2 1/8"Silver Jet GAS LIFT, _... 6,536.0 6,558.0 6,356.9 6,375.7 A-3,3N-08 1/6/1991 6.0 RPERF 0 deg ph;21/8"DynaStrip 5,498 If _ 6,544.0 6,545.0 6,363.7 6,364.6 A-3,3N-08 6/5/1986 1.0 APERF 90 deg.ph;SOS 4.5"Csg Gun GAS LIFT. 1(I 6,547.0 6,548.0 6,366.3 6,367.2 A-3,3N-08 6/5/1986 1.0 APERF 90 deg.ph;SOS 4.5"Csg Gun 5.869 _ 6,560.0 6,590.0 6,377.4 6,403.0 A-2,3N-08 4/27/1986 4.0 IPERF 90 deg.ph;4.5"Csg gun 6,601.0 6,607.0 6,412.6 6,417.6 A-1,3N-08 4/27/1986 4.0 IPERF 90 deg.ph;4.5"Csg gun GAS LIFT, -_4 6,24 Notes:General&Safety End Date Annotation 622/1994 NOTE:WAIVERED WELL:To IA COMMUNICATION PBR,6,264 � 7/30/2012 NOTE:LEAKS DETECTED @ 6300'PACKER 8 6246'GLM PACKER,6,300 ilk y NIPPLE,6,337 PLUG,6,337" I SOS,6,370 APERF, _ if 6,4606,470 1:- __ 1 TT APERF, -. 6,544-6.545 RPERF, - 6.5366,556\ - - .--M APERF, 6,5476,546 IPERF, i`"'m 6,560.6,590 g 7_ ® I FISH,6,585 .: f m "-" . 1 1 KIT Mandrel Details FISH,6,593 -- 4 Top Depth Top Port (TVD) tool OD Valve Latch Size TRO Run N...Top(ftKB) (ftKB) (°) Make Model fin) Sery Type Type (In) (psi) Run Date Corn... FISH,6,597 4 1 2,241.7 2,241.6 1.94 Melia TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/8/1999 7:30 2 3,723.0 3,718.5 5.41 Merle TMPD 1 GAS LIFT DMY BK 0.000 0.0 427/1986 7:30 I 3 4,621.8 4,616.2 3.94 Merle TMPD 1 GAS LIFT DMY BK 0.000 0.0 12/30/1991 4:30 IPERF, II 111 6,601-6.607 4 5,148.9 5,135.2 15.33 Merla TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/27/1986 9:00 5 5,494.0 5,459.2 24.35 Merle TMPD 1 GAS LIFT DMY BK 0.000 0.0 427/1986 5:00 II 6 5,868.5 5,785.9 30.78 Merle TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/19/2011 8:30 7 6,246.2 6,108.9 30.77 MMH 2.875x1.5 1 12 GAS LIFT DMY BK 0.000 0.0 11/18/1999 5:00 Packet( PRODUCTION, 35-A853 TD(3N-08A), 6,890 • • Ferguson, Victoria L (DOA) From: Ferguson,Victoria L(DOA) Sent: Tuesday,July 30,2013 12:00 PM To: Packer,J.Brett(J.Brett.Packer @conocophillips.com) Subject: 3N-08A WO (PTD 186-068, Sundry 313-380) Brett, What is the BOP test pressure? Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferqusonaalaska.gov 1 • • KAI 3a - 66A 0006eo Regg, James B (DOA) From: NSK Problem Well Supv [n1617 @conocophillips.com] Sent: Wednesday, August 22, 2012 7:48 PM To: Regg, James B (DOA); Wallace, Chris D (DOA) Subject: RE: KRU monthly injector report for July Attachments: 2V -05 updated.gif Jim, Chris, Seeresponses below. SCANNED MAY 0 7 2 013 Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 From: Regg, James B (DOA) [mailto:jim.re•g©alaska.gov] Sent: Tuesday, August 21, 2012 9:48 AM To: NSK Problem Well Supv Cc: Wallace, Chris D (DOA) Subject: [EXTERNAL]RE: KRU monthly injector report for July 2V -05 (PTD 1831760; A10 2B.055) exhibits what appears to be IA repressurization; could be thermal. Do you have an updated TIO plot and any temp data that would confirm this is thermal? Have injection conditions stabilized to allow evaluation of the IA pressure? Attached is an updated SCADA readout, The IA is beginning to show signs of stabilization. The initial rise in IA pressure is directly tied to the well being returned to injection on July 1 And for the first several days, fluctuations were tied to the changes in injection rate /WHP (fluid packed pressuring /thermaling). There was also a correlated temperature / IA pressure dip on Aug 12. At this point, this does not appear out of the ordinary to me, but will continue to monitor the pressures with more scrutiny, Please let me know if you are still concerned ON-08A (PTD 1860680; A10 2B.025); why the sudden IA pressure increase on 7/31/12? On 07/30/12 we performed an ultrasonic leak detect log to try to identify the leak points for possible repair options. Following the logging, the IA was not bled down as low as the pressure was prior to starting the logging. The well is currently secured with a CA -2 plug @ 6337' Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: NSK Problem Well Supv [ mailto :n1617@conocophillips.com] Sent: Monday, August 20, 2012 7:52 PM To: Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: KRU monthly injector report for July Jim, Guy 1 • • Attached is the monthly injector report for July. Two wells were removed: 2F -17 following a tubing patch and passing witnessed MITIA 2K -25 since the well has been suspended Please let me know if you have any questions. Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr. 909 2 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Thursday, December 22, 2011 Jim Regg P.I. Supervisor ` �� j e, ( 4 f l 1 Z- SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3N -08A FROM: Matt Herrera KUPARUK RIV UNIT 3N -08A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry _.1 q NON - CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 3N - 08A API Well Number: 50 029 - 21540 - 01 - 00 Inspector Name: Matt Herrera Insp Num: mitMFH111219085334 Permit Number: 186 - 068 - Inspection Date: 12/17/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3N - 08A, Type Inj. N ' TVD 6156 IA 1850 3020 . 2980 2960 P.T.D 1860680 'TypeTest SPT Test psi 3000 ' OA o 0 0 0 Interval RE p/F P - Tubing 2070 2080 2080 2080 Notes: MITIA performed to 3000 psi k - A3 Zg ,c 2-5 ikki;✓ rt d k' s^-- -e— ,s • k&t Ct4,cc ) &it,(2e+z4 'use . ; F EE c ` I Thursday, December 22, 2011 Page 1 of 1 MEMORANDUM TO: Jim Regg ~ ~~ (~~~~ Jo P.I. Supervisor FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, December 23, 2009 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3N-08A KUPARUK RIV UNIT 3N-08A Src: Inspector NON-CONFIDENTIAL • Reviewed By: P.I. Suprv Comm Well Name: KUPARUK RIV UNIT 3N-08A API Well Number: 50-029-21540-01-00 Inspector Name: Bob Noble Insp Num: mitRCN091223072833 Permit Number: 186-068-0 Inspection Date: 12/20/2009 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. --- -- ~ -- 1 Well ~ 3N osA I'T a In'. ' w `~TVD 61s7 ~~~ ~ --I / :_ _ I 330 '' i T - -- ' 1860680 `j yp J ! 2920 3418 _-- -' - - _--- ~ _.--- SPT 3418 OA P.T.D' iTypeTest I l Test st u I o I o i o ~ ~- ----;..------ - 3380 -- --~- - - ! - ---- ~ -- - --- P -- -1- _ -!-- - - - ~ }- t-- ---- - - -- - - - 2850 2850 2850 j Interval REQvAR P/F P / Tubing ~ z8so ---I~-------_ ~-_ _ -~----_ ~------ --~_--_ ---- Notes: /~ zP,.vLs r`fi,~.~'~5 ~'~''"~~ -~-i7 l.•~~ _ C~,ti~lUpa,~e! ~q~Pl~iw; .~reS~tti~e. ~'~,. Wednesday, December 23, 2009 Page 1 of 1 • ~/ . • ConocoPh ~ I I i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 23, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~ ~W~ ~~ ~ , d~ P ~~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRiJ). 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 October 19, 2008 and the corrosion inhibitor/sealantwas pumped October 21, 2008..The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, ,% ~'j~ ~ ~ ~~~~ IvC~~ ~: ~ 200 G'~ ~` MJ La eland ConocoPhillips Well Integrity Projects Supervisor • • ConocoPhilllps Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field note 10/22/2008 A J Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 3N-01 185-313 32' 5.00 21" 10/19/2008 3.4 10/21/2008 3N-02A 186-032 66' 10.00 4"2" 10/19/2008 10.2 10/21/2008 3N-03 186-016 43' 6.00 22" 10/19/2008 5.1 10/21/2008 3N-04 186-017 83' 9.00 24" 10/19/2008 10.2 10/21/2008 3N-05 186-026 21" NA 21" NA 2.55 10/21/2008 3N-07 186-028 20' 3.50 21" 10/19/2008 3.4 10/21/2008 3N-08A 186-068 8' 1.50 21" 10/19/2008 5.1 10/21/2008 3N-09 186-030 14' 2.50 21" 10/19/2008 4.25 10/21/2008 3N-10 186-072 97' 12.00 5'8" 10/19/2008 15.3 10/21/2008 3N-12 186-079 62' 9,50 4'7" 10/19/2008 17 10/21/2008 3N-13 186-081 17' 2.00 35" 10/19/2008 4.25 10/21/2008 3N-14A 207-119 21" NA 21" NA 3.4 10/21/2008 3N-15 186-090 64' 8.00 20" 10/19/2008 6.8 10/21/2008 3N-16 186-091 71' 8.50 30" 10/19/2008 3.75 10/21/2008 3N-17 186-092 59' 6.00 22" 10/19/2008 5.1 10/21/2008 3N-18 186-093 49' 6.40 28" 10/19/2008 5.95 10/21/2008 3N-19 201-225 16" NA 16" NA 3.4 10/21/2008 MEMORANDUM To: Jim Regg k~ P.I. Supervisor 1\e~i` ~ l~i (~ FROM: Bob Noble Petroleum Inspector State of Alaska C~ Alaska Oil and Gas Conservation Commission DATE: Wednesday, October O1, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3N-OSA KLTARUK RIV UNIT 3N-08A Src: Inspector NON-CONFIDENTIAL Reviewed Bv~. P.I. Suprv ~~~ Comm Well Name• KUPARUK RN UNIT 3N-08A API Well Number: 50-029-21540-01-00 Inspector Name: Bob Noble Insp Num: mitRCN080930091924 Permit Number: 186-068-0 ~~ Inspection Date: 9/28/2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ 3N-08A 'type Inj. ~ ~' ~ TVD 6157 ~ IA I 2360 I 3420 3400 3400 p•T• i 1860680 iT)'peTCSt i SPT Test psi 3420 v OA 180 ~ 320 320 ~ 320 Interval REQVAR p~F P ~ Tubing ~ zsoo zsoo zsoo zsoo Notes: MIT-IA to max anticipated injection pressure e, • ~ti ~ ~~~~~ Wednesday, October O1, 2008 Page 1 of 1 a • Maunder, Thomas E (DOA) From: NSK Problem Well Supv jn1617Lc~convcophiAips.comj Sent: Thursday, December 27, 200710:59 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: RE: MIT KRU 3N-08A (PTD 186-~8) Attachments: 3N-08A 90 day TIO plot.png 3N-08A 90 day TIO p{ot.png (36... Jim, 3N-08A is an internally waivered well and will be added to December monthly MIT report. Attached is a 90 ay 0 plot. Please let me know if you-need ~y~3~-iTg"~1se. Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Cell Phone (907) 943-1999 c. Pager ( 907 ) 659-7000 pgr. 909 ~`~~'~~~ ~~`~ ~ ~ ~~~ -----Original Message----- From: Regg, James B {DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, December 26, 2007 5:38 PM To: NSK Problem Well Supv; Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA); DOA AOGCC Prudhoe Bay Cc: NSK Well Integrity Proj Subject: RE: MIT KRU 3N-08A (PTD 186-068) Please send TIO plot for this well. I'm a bit surprised by the high IA pressures shown in pretest column. Also please make sure this well is added to the monthly waiver report covering December rather than waiting for the admin approval. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 -----Original Message----- From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Wednesday, December 26, 2007 9:18 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA}; Fleckenstein, Robert J (DOA}; DOA AOGCC Prudhoe Bay Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: MIT KRU 3N-08A (PTB 186-068) Jim, Bob, Tom, et al, Attached are passing MITIA and MITOA tests for 3N-08A (PTD 186-068}. These tests were diagnostic pressure tests completed in preparation far an AA application. Please let us know if you have any questions. 1 a • Regg, James B (DOA) From: NSK Weli Integrity Proj [N1878@conocophiilips.com] Sent: Wednesday, December 26, 2007 10:57 PM To: Regg, James B (DOA) lz,l~i~1 Cc: NSK Problem Well Supv ~~~ Subject: RE: MIT KRU 3N-08A (PTD 186-068) Jim, I included a TIO plot in the packet for the AA. But will have Brent send in an electronic version. This well held a good differential until just recently when the injection temp increased as you will see on the plot. The AA request was mailed today and the issues with the well were reported in 2003. ----- Let us know if you have any additional questions. MJ -----Original Message----- From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] Sent: Wednesday, December 26, 2007 5:38 PM To: NSK Problem Well Supv; Maunder, Thomas E (DOA}; Fleckenstein, Robert J (DOA); DOA AOGCC Prudhoe Bay Cc: NSK Well Integrity Proj Subject: RE: MIT KRU 3N-08A (PTD 186-068} Please send TIO plot for this well. I'm a bit surprised by the high IA pressures shown in pretest column. Also please make sure this well is added to the monthly waiver report covering December rather than waiting for the admin approval. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 -----Original Message----- From: NSK Problem Well Supv [mailto:nl617Cconocophillips.com] Sent: Wednesday, December 26, 2007 9:18 AM To: Regg, James B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA); DOA AOGCC Prudhoe Bay Cc: NSK Problem Well Supv; NSK Well Integrity Proj Subject: MIT KRU 3N-08A (PTD 186-068) Jim, Bob, Tom, et al, Attached are passing MITIA and MITOA tests for 3N-08A (PTD 186-068). These tests were diagnostic pressure tests completed in preparation for an AA application. Please let us know if you have any questions. Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Cell Phone (907) 943-1999 Pager (907) 659-7000 pgr. 909 1 ~2c,t 3~ -c~~4 ~~~ ~ ~~ -- o~~ IAP FTP FTT oAP T/UO Plat - 3 N -a8 200 2500 2000 in 1500 o. 1000 500 0 27-Sep-07 150 a E a~ 100 0 s t~ 50 0 10-Oct-07 23-Oct-07 u5-wov-ur ~~-wUV-v, U~-~~~-~- ,-~ ~--~ -. Date • Maunder, Thomas E (DOA) From: James Regg (jim_regg@admin.state.ak.us] Sent: Wednesday, September 08, 2004 9:45 AM To: T©m Maunder Subject: [Fwd: RE: MiT KRU 3N-08A 09-07-04.x1s] Attachments: 3N-08 Well History Rpt.pdf; TIO 3N-08A.xls; jim_regg.vcf 3N-08 Well History TIO 3N-08A.xis (2 jim_regg.vcf (2 KB) Rpt.pdf (2 ... KB) Guess what we need to tell them is the well should be added to the monthly injector waiver report; was not there on July rpt; as we told BP, if the well has a waiver, it is to be on the monthly report Jim -------- Original Message -------- Subject: RE: MIT KRU 3N-08A 09-07-04.x1s Date: Wed, 08 Sip 2004 09:22:32 -0800 From: NSK Problem Well Supv <n1617@conocophillips.com> To: fihomas Maunder <tom maunder@admin.state.ak.us> CC: Jim Regg AOGCC (E-mail) <jim regg@admin.state.ak.us> Tom, This well has been waivered since 1994 and the AOGCC has a paper copy of the actual Waiver document. The operating criteria is as follows: Waivered well requirements: T x IA communication IA not to exceed 3000 psi. Keep sign on wellhead. Monitor WHP's daily, record weekly 2-year MITIA/LLR @ 3000 psi alternate with IA FL MITIA even years IA fluid Ievel odd years IA NS - I'm attaching the well history report and the TIO as you requested MJ Loveland ConocoPhillips Problem Well Supervisor 4~~ ~A~ .~ ~ ~~~~ 659-7224 _. _. -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Wednesday, September 0$, 2004 6:58 AM To: NSK Problem Well Supv Cc: Jim Regg AOGCC (E-mail) Subject: Re: MIT KRU 3N-08A 09-07-04.x1s MJ, Could you please provide some additional information on this well. What are the conditions of the internal waiver?? Could you also provide a TIO plot for about 3 months?? Thanks, Tom Maunder, PE AOGCC 1 r~ L NSK Problem Well Supv wrote: • > «MIT KRU 3N-08A 09-07-04.x1s» >Please find the attached MIT form for a diagnostic MITIA required by a ConoeoPhillips internal waiver on 3N-08A (PTI3 186-068). >Please let me know if you have any questions >MJ Loveland >ConocoPhillips >Problem Well Supervisor >659-7224 • • Annular Communication History 3N-08A Problem: Status: T x IA communication Injecting Planned Actio 1. PWS: Consider for video log candidate. > 01/06/01: MITIA Passed @ 3450 psi. LLR to low to measure; lost 130 psi. > 02/03/02: IA FL @ surface > 09/15/02: MITIA passed. > 09/02/03: IA FL @ SF for WC > 09/07/04: MITIA passed for WC Date Type Comment 9/7/04 MIT-IA MITIA passed, POT & PPPOT-T passed (for W C). T/U0=2240/2850/180. Pressured up IA with 1 bbl of PPPOT-T diesel to 3500 psi. 15 min T/I/0=2240/3480/180, 30 min T/I/0=2240/3480/180, for a total loss of 20 psi during test. Bled IA down to 1500 psi, in 30 min it had built up to 2150 psi. Stung into T PO with 0 psi. Pressured up T PO with hyd fluid to 4500 psi. 15 min reading-4350 psi, 30 min reading-4300 psi, for a total loss of 200 psi during test. Bled T PO to 0 psi. Final T/I/0=224012 1 5 011 80. 9/2/03 FL-IA IA FL @ SF for WC, T/I/O = 2750/2900/300 9/15/02 MIT-IA MITIA -passed, T/I/O = 2900/3000/50 pressure up IA with diesel to 3500 psi, start MITIA T/I/0= 2900/3500/50 15 minute reading T/I/0= 2900/3475/50, 30 minute reading T!I/0= 2900/3420/50 bleed down IA, final T/I/0= 2900/2900/50 9/2/02 AC EVAL Results of DSO work: 8/24: At about 3pm, bled IA from 2750 psi to 1750 psi. At about 4pm, 1 hr later, IA was back up to 2660psi. 8/25: At gam IA = 2870 psi. May have a measurable LLR now and a leak detect log can be ran. 2/3102 FL-IA IA FL @ surface. T/I/O = 1400/1400/0 1/6/01 LLRT-IC T/I/O=2900/2900/380PSI. MITIA PASSED @ 3450 PSI; LOST 0/0 (0 PSI TOTAL) BLEED OFF IN 30 MIT-IA MINUTES. START TEST. T/I/0=2900/3400/380; 15 MINUTE READING, T/I/0= 2900/3400/380; 30 MINUTE READING T/I/0= 2900/3400/380 PSI. FIANAL T/I/O: 2950/2950/400 psi. ~ ~ Date Type Comment 3/30/00 MISC Injector w/tbg x 7" communication. Passed in-house MIT on 11/08/99 and AOGCC-witnessed MIT on 11/09/99, but 7" continues to pressure up via tubing x 7" leak. PPPOT on tbg passed 09/18/99. Downhole work in 11/99 was again unsuccessful in repairing the leak as 7" pressured up to >2000 psi almost immediately. Continue 06!19/94 waiver. Operating constraints, with ()bracketed those which have changed or become obsolete since the waiver was issued: -- 7" annulus pressures should stay within 200-300 psi of injection pressure. -- 7" annulus pressures should not exceed 3000 psi. -- Tubing should not be bled with pressure on the 7" annulus. -- An accurate bleed record should be maintained on (KDGS) Setcim including total volume of diesel bled from the 7" annulus. -- A troubled well sign will be posted at the wellhead. -- (If cumulative vol. of more than 6 bb}s is bled from 7" beginning 04/23/94, do not SI well for more than 24 hrs.) Fluid has been swapped out in annulus during troubleshooting. If pressures climb to unacceptable levels, then additional SW may need to be placed. Waiver conditions: -- Bleed frequency required to keep the 7" annulus within revised pressure limits should not exceed KRU field guidelines for water injectors. -- Internal pressure testing should be performed annually to monitor tubing x 7" integrity. 3/30/00 W WN Review monitored well performance: After AOGCC-witness MIT on 11/09/99, the 7" annulus returned to high levels within first month. W giver review ended in EPS, and recommend that we maintain waiver on tubing x 7" casing communication. Added waiver details to EPS and added stipulations to PM reminders. __> Action Item: I sent a note to Eric Zuspan just checking on if we needed a Sundry issued to the AOGCC about the communication, even though the MIT passed. 11/9/99 MISC 09/18/99: PPPOT tubing hanger passed. 11/08/99: Slickline c/o some DV's and well passed in-house MIT. Injector w/tbg x 7" communication. Monitor post-wellwork performance; if annulus remains trouble-free after 3 months, discontinue waiver. 11/9/99 MIT-IA WITNESS 4 YEAR MIT. PT 7" IA TO 2050 PSI. HELD GOOD FOR 30 MIN. BLED TO 1400 PSI. 11/9/99 WWN After spending some time fishing in the hole for a lost KOT arm (DV at 4622' is officially unremovable) the SL crew was able to get an in-house MIT to pass 11/08. The official MIT took place today and passed also. Because work was done on the DV's, recommend that we enter a 3-month monitoring of the 7" annulus as part of a review of the waiver. The waiver was issued back in 1994 because the well could pass an MIT, but the 7" would still build pressure over time. Entered into EPS, printed new reports, made it a monitored well. 1]/8/99 MIT-IA SET 1" DV (WI PKG) @ 2242' RKB. SET 1.5" PACKOFF DV @ 6246' RKB. IN HOUSE MIT PREFORMED ON 7" CSG 2825 PSI »> 2300 PSI- GOOD TEST. 9/18/99 PPPOT-T T/I/O = 2800/2800/400 TBG HANGER PPPOT PASSED; Stung into TBG hanger PO. Pressure was at 40 psi. Bled PO to 0 psi. Flushed through PO, got back clean hydraulic oil. Pressured PO to 3000 psi. PO lost 60 psi in I S mins and a total of 80 psi in 30 mins. FINAL WHPs=2800/2800/400 9/7/99 Monitor Prudhoe DHD crew confirmed wellhead is FMC IV and scheduled PPPOT for next trip to Kuparuk. Date Type Comment 8/28/99 MISC Well failed 4-year AOGCC required MIT on 08/15/99. Well has been internally waivered since 06/19/94 to allow continued injection with 7" casing leak. Troubleshooting to locate the leak was done 12/91 to 04/94 and was unsuccessful. Annulus is filled with seawater and 2000' diesel cap. Well passed AOGCC MIT on 12/04/95. Last bleed event required to meet the waiver guidelines was on 10/22/95. Injector wJtbg x 7" communication. Pressure test tubing hanger packoff to investigate possible cause of increased leak path. Tubing hanger was last tested (successfully) to 5000# on 01/08/94. If tubing hanger still passes test downhole diagnostics will be performed to check potential for fixing or mitigating the tubing x 7" communication. If leak is uneconomic to repair enough to pass the MIT, the state will be approached with a request for variance. 8/28/99 W WN Received some guidelines from Eric Zuspan and issued PWN for the failure to pass AOGCC 4-yr MIT. Requested tubing hanger pressure test; if it passes (as it did in 1/94) Eric recommends (see Email) to run plug in tbg and check DV's. PT 7" and tbg together while valve is out and we can use this as a alternative MIT if we can't fix the problem; this will satisfy the State, showing that we have integrity testing the tbg x IA as a system. 12/4/95 MIT-IA P/T 7" TO 3500 PSI DROPPED TO 3350 PSI AFTER 30MIN.-PASSED 11/6/95 MIT-IA 4 YEAR MIT-PASSED 3000 2500 T/I/O 3N-08A i ~ 2000 a 1500 1000 500 ~- FTP I ~ ~- IAP I i OAP j • • Maunder, Thomas E (DOAj From: NSK Problem Weil Supv [n1617@ppco.com} Sent: Friday, October 12, 2001 5:01 PM To: Tom Maunder Subject: Re: 3N-08 ~ 3N-12 temp change in service Attachments: tom maunder.vcf tom_maunder.vcF (2 KB) Ok, will do. Thanks! Jerry Tom Maunder <tom maunder@admin.state.ak.us> 10/12/01 04:45 PM To: NSK Problem Well Supv/PPCO@Phillips cc: Subject: Re: 3N-08 & 3N-12 temp change in service Jerry, Looks like it is hoped that 1 month backflow will be enough, but that is unknown. I think in these cases you should likely go the full paper route. Sorry for the hassle. I will give you verbal approval to proceed as you have planned. Thanks. Tom NSK Problem Well Supv wrote: > Tom: Several months ago we had a discussion about temporary change of > service from injection to production for reservior pressure reduction prior > to drilling nearby wells. At that time you suggested for up to a month the > conversion notification could be done by email. For a month or more > the > 10-403!10-404 process would be required. The following email is from > one of > our PE's asking about temporary conversion of 3N-08A and 3N-12 from > produced water injection to production for pressure reduction. These > two wells fall right about the break in that time interval. Would you > please take a look and see if this is adaquate notification, or should > we submit the 10-403110-404? Thanks! > Jerry Dethlefs > Phillips Problem Well Supervisor > ----- Forwarded by NSK Problem Well Supv/PPCO on 10/12/01 03:45 PM > ----- > CPF3 Prod Engrs > 10/12/01 03:08 PM 1 > To: NSK Problem Well Supv/PPCO@Phillips > cc: NSK Prod Engr Tech/PPCO@Phillips, R Tyler Senden/PPCO@Phillips, Guy > Schwartz/PPCO@Phillips, CPF3 DS Lead Techs/PPCO@Phillips > Subject: 3N-08 & 3N-12 temp change in service > Jerry, > Please email Tam Maunder to notify him (in lieu of form 10-403) we > will be > backflowing PWI wells 3N-08A and 3N-12 temporarily for drilling > pressure reduction of 3N-19. > 3N-08A and 3N-12 are currently being hooked up for backflow of > produced water injection to lower pressure for 3N-19 new well > scheduled for Dee 2001. > 3N-08A has been SI since 9/13 and 3N-12 has been SI since 10/3. SBHPs > have not dropped enough to allow drilling to safely drill 3N-19. > We plan to backflow these 2 wells for about 4 weeks then SI to check > pressure. If the pressure. is still high, the wells will continue to > be on > backflow until the rig arrives in Dee. The wells will be SI when the > rig arrives and then BOI after 3N-19 is completed. > 3N-08A is in the isolated fault block that 3N-19 will be drilled into. > There are no producers to draw the pressure down. SBHP measured 10/3 > was > 3827 psi. > 3N-12 is just on the other side of the fault from 3N-19's proposed > location. Drilling requires the pressure reduction due to safety concerns > in case there is communication across the fault. SBHP measured 10/3 > was > 5368 psi. > Thanks, > Marie (See attached file: tom maunder.vcf) 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Ernail to: Torn_Maunder@adrnin.state.ak.us; Bob_Fleckenstein@adrnin.state.ak.us; and Jirn_Regg@adrnin.state.ak.us OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Inc. Kuaprukl KRU/ 3N-08A 09/07/04 Sauvageau/Rogers ASRC Packer Depth Pretest Initial 15 Min. 30 Min. well 3N-08A I Type Inj Is I T.V.D. I 6274 I Tubing I 22401 22401 22401 22401 Interval I 0 P.T.D. 1860680 Type Test P Test psi 1569 Casing 2850 3500 3480 3480 P/F P Notes: Diagnostic MITIA required by internal waiver weill I Type Inj I I T.V.D. I I Tubing I P.T.D. Type Test Test psi 1500 Casing Notes: weill I Type Inj I I T.V.D. I I Tubing I P.T.D. Type Test Test psi 1500 Casing Notes: weill I Type Inj I I T.V.D. I I Tubing I P.T.D. Type Test Test psi 1500 Casing Notes: weill I Type Inj I I T.V.D. I I Tubing I P.T.D. Type T e$t Test psi 1500 Casing Notes: Test Details: I Interval I P/F I Interval I P/F I Interval I P/F I Interval I P/F 1YPE INJ codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting 1YPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance Test during Workover 0 = Other (describe in notes) SCANNED OCT 0 9 2004 MIT Report Form Revised: 05/19/02 2004-0907 _MIT_KRU_3N-08A.xls 918/2004 1' .,.-) NOV 0 8 199,5 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MeM~nical Inl~g~ity Test Gas Cons. Commission ~chorage OPERATOR: ARCO AJask~ Inc.. FIELD 1 UNIT 1 PAD: KF;F~ KRU, DATE: ! 1/6/95 1~6 M I DIESEL 7,8~ 7~ 2~. K;~ 3.5 1~ Z~ f, 7~ 1, 755 iCOMM~N~ ~'ESS ~D 3~ S t DIESEL ~.3~ 7~. 2~, ~ 2.875 fS~ 3,0~ 2:~ 2r8~ 2,840 ~0 ' COMMENTS WITNESS ~D ....... ,, ,, ,, ,., , . , 3N-12 P ! DIE~EL 7.~1 7~ 2~, j~5 2.875 ~ ~ ~ f~ . ~0 12f5 P C~EN~S ~NESS ~D I '1 ! I I I 3~f3 g i DIE~L 7.3~ 7~ 2~, ~ 2.~75 ~ 3.~ 2~5~ 2,575 2,5~ 1~ O COMMENTS: . DISPO~L N DIE~L 28~ 7; 2~, ~ Il 2.875 I~ 1~ 1~ 1575 1575 COMMEN~: 'TUBING I]~JECTION FLUID: P = PRODUCED WATER I NJ. S=8ALTWATER1N,I ,SCANNED DEC 1 9 2002 M = MISCIBLE I NJ. I = INJECTION N = NOT INJECTING DLslril~io¢.~ c- O¢.~-'~or c-T,~ Rl~t FI~ ANNULAR FLUID: P.P.G. Grad. WELL TEST: DIESEL 6. ~7 6.36 InilieJ GLYCOL J O. 0 0 4 - Year X SALTWATER I o, oo wo~er DRILL1NG MUD J O. 00 Other OTHER I o. oo AOGCC REP SIGNATURE OPERATOR REP $1GNATU RE P~ge I WVD BY J. HERRING ERIC L. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimuble _ Change approved program Pull tubing _ Variance _ Perlorate _ Olher _X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development_ RKB 67 feet 3. Address Exploratory __ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 Service__x Kuparuk Unit 4. Location of well at surface 8. Well number 3716' FNL, 277' FEL, Sec. 29, T13N, R9E, UM (asp's 518121, 6013799) 3N-08A At top of productive interval 9. Permit number / approval number 631' FSL, 390' FEL, Sec. 29, T13N, R9E , UM 186-068 At effective depth 10. APl number 50-029-21540-01 At total depth 11. F~ld / Pool 4709' FNL, 402' FEL, Sec. 29, T13N, RgE, UM (asp'$ 518002, 6012806) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 6890 feet Plugs (measured) t~ue verfica~ 6660 feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 115' 16' 231 sx CS II 115' 115' SUR. CASING 3556' 9-5/8' lO~O sx AS II~ & 2S0 Sx C~a~ G 3623' 3619' w/150 sx ASI Top Jo~ PROD. CASING 6786' 7' 310 sx Classs G & 175 s,x AS I 6853' 6628' Per/oration depth: measured 6460-6470; 6536-6544; 6544-6547; 6547-6558; 6560-6590; 6601-6607 t~ue vertical 6294-6302; 6359-6365; 6365-6368; 6368-6377; 6349-6405; 6414-6419 Tubing (size, grade, and measured depth 2-7/8', 6.5~, J-55 Tbg O 6370' MD. Packers & SSSV (type & measured depth) BROWN 'HB-I' O 6300' MD. ~ff~l/A 13. Attachments Description summary of proposal __X Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: October 15, 2001 16. If proposal was verbally approved 10/12/01 Oil __ Gas __ Suspended __ Name of approver Tom Maunder Date approved ;Service_X Water Injector on Temporary Flowback (pressure reduction for drilling) 17. I hereby cert~ that the foregein~l.~true and,corr_ect to the best ot my k~owledge. Questions? Call Jell Spencer 659-7226 Signed / / /).a /'1., ~' '_ Title: Production Engineering Supervisor Date v Prepared b~ Robetl ChrlStensen 659-7535 Jeff A. Spencer ~"~ ~ ~ Conditions of approval:PlugN°tifYintegrityC°mmissi°n so representative may witness_ BOP Test __ Location clearance _ [ Appr°val n~-~ -,~ ~/4/~ Mechanical Integrily Test__ Subsequent f°rm required 10' ~tO~'4,,. -~-..Z ~Z',N~ '- ~'N ~..~.._~'t.~Y~.) . Approved b~..orcl~..r..?f the Commission ....... -,,.~,,~,_~ ~'j,~,~' Commissioner Date ~..~/(~ .~--' .. Form 10-403 Rev 06/15/88 · SUBMIT IN TRIPLICATE 3N-08A DESCRIPTION SUMMARY PROPOSAL Phill~:Alaska Inc. ~ ~r~Ju~g approval for a temporary conversion of well 3N-08A from prodUced water injectiontoprodUCtion, , 3N-08A will bebackfl0wed for 4'weeks then Si to check the reservoir pressure. If the pressure is stii!~igh, the weli~lCb---~in _~_-!°:be~0n.backftow untiithe rig:arrives in December. 3Nq38A Will be returned to prodUced water injection after well 3N-19 is ddlled. R~: 3N-.O.~ &' 3N-12 temp change in service Subject: Re: 3N-08 & 3N-12 temp change in service Date: Fri, 12 Oct 2001 17:01:08 -0800 From: "NSK Problem Well Supv" <n1617@ppco.com> To: Tom Maunder <tom_maunder@admin.state.ak.us> Ok, will do. Thanks! Jerry Tom Maunder <tom_maunder@admin.state.ak. us> 10/12/01 04:45 PM To: NSK Problem Well Supv/PPCO@Phillips CC: Subject: Re: 3N-08 & 3N-12 temp change in service Jerry, Looks like it is hoped that I month backflow will be enough, but that is unknown. I think in these cases you should likely go the full paper route. Sorry for the hassle. I will give you verbal approval to proceed as you have planned. Thanks. Tom NSK Problem Well Supv wrote: > Tom: Several months ago we had a discussion about temporary change of > service from injection to production for reservior pressure reduction prior > to drilling nearby wells. At that time you suggested for up to a month the > conversion notification could be done by email. For a month or more the > 10-403/10-404 process would be required. The following email is from one of > our PE's asking about temporary conversion of 3N-O8A and 3N- 12 from > produced water injection to production for pressure reduction. These two wells fall rfght about the break in that time interval. Would you please take a look and see if this is adaquate notification, or should we submit the 10-403/10-4047 Thanks/. Jerry Dethlefs Phillips Problem Well Supervisor - Forwarded by NSK Problem Well Supv/PPCO on 10/12/01 03:45 PM - - CPF3 Prod Engrs 10/1 2/01 03:08 PM To: NSK Problem Well Supv/PPCO@Phillips cc: NSK Prod Engr Tech/PPCO@Phillips, R Tyler Senden/PPCO@Phillips, Guy > Schwartz/PPCO@Phillips, CPF3 DS Lead Techs/PPCO@Phillips > Subject: 3N-08 & 3N-12 temp change in service ~ ,~f ~ 4/26/02 3:23 PM Rei 3N-Q8 &-3N-12 temp change in service > Jerry, > Please email Tom Maunder to notify him (in lieu of form 10-403) we will be > backflowing PWI wells 3N-OSA and 3N-12 temporarily for drilling pressure > reduction of 3N- 19. 3N-OSA and 3N- 12 are currently being hooked up for backflow of produced water injection to lower pressure for 3N-19 new well scheduled for Dec 2001. 3N-O8A has been SI since 9/13 and 3N-12 has been SI since 10/3. SBHPs have not dropped enough to allow drilling to safely drill 3N-19. We plan to backflow these 2 wells for about 4 weeks then SI to check > pressure. If the pressure is still high, the wells will continue to be on > backflow until the rig arrives in Dec. The wells will be SI when the rig > arrives and then BOI after 3N-19 is completed. > 3N-O8A is in the isolated fault block that 3N-19 will be drilled into. > There are no producers to draw the pressure down. SBHP measured 10/3 was > 3827 ps£ > 3N-12 is just on the other side of the fault from 3N-19's proposed > location. Drilling requires the pressure reduction due to safety concerns > in case there is communication across the fault. SBHP measured 10/3 was > 5368 ps£ > Thanks, > Marie (See attached file: tom_maunder, vcf) Tom Maunder <tom maunder(~admin.state.ak, us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 4~26~02 3:23 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulale _ Plugging _ Pull tubing _ Alter casing _ Repair well 2. Name of Operator Pl~illips Alaska, Inc. 3. ,Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 3716' FNL, 277' FEL, Sec. 29, T13N, R9E , UM 5. Type of Well: Development __ Exploratory __ Stratkjraphic __ ,Sennce__X (asp's 518121, 6013799) Pe~/ora~e _ O~her _X Temp Prod lo WAG 6. Datum elevation (DF or KB feet) RKB 67 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3N-08A ,At top of productive interva] 631' FSL, 390' FEL, Sec. 29, T13N, R9E, UM ,At effective depth At total depth 4709' FNL, 402' FEL, Sec. 29, T13N, R9E, UM (asp's 518002, 6012806) 12. Present well condition summary Total depth: measured true vertical 6890 feet 6660 feet Plugs (measured) 9. Permit number / approval number 186-068 / 10. APl number 50-029-21540-01 11. Field / Pool Kuparuk Oil Pool Effective depth measured ITue vertical feet Junk (measured) feet Casing Ler~jth CONDUCTOR 1 15' SUR. CASING 3556' PROD. CASING 6786' Size Cemented Measured Depth 16" 231 sx cs II 1 15' 9-5/8' 1060 sx AS III & 260 Sx Class G ~ 3623' 7" 310 sx Classs G & 175 ~ AS I 6853' True vertical Depth 115' 3619' 6628' Perforation depth- measured 6460-6470; 6536-6544; 6544-6547. 6547-6558; 6560-6590; 6601-6607 true vertical 6294-6302; 6359-6365; 6365-6368: 6368-6377; 6349-6405:6414-6419 (size, grade, and measured depth) 2-7/8', 6.5#, J--55 T'Dg O 6370' MD. Packers & SSSV (type & measured depth) BROVVN 'HB-I' 0 6300' MD. ~N/A 13_ Stimulal~on or cement squeeze summary Intervals treated (measured) N/A Treatment descfiplJon including volumes used and final pressure 14. Prior to well operabon Subsequent to operabon OikBbl Representative Daily Avera.qe Production or Injeclion Data Gas- Md Water- Bbl 29 592 C,:~sing Pressure Tubing Pre~-~ure 1280 130 2357 1280 1080 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Opecations __X Oil __ Gas __ Suspended __ Service _X WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Questions? Call Jeff Spencer 559-7226 Signed Jeff A. Ti'de Production Engineering Supervisor ..?BDMS BFL repamed by Robert Chf,stenseq 559- 3N-08A DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary J sv^ve or ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1_ Type of request Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Change approved program _X 2_ Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 3716' FNL, 277' FEL, Sec. 29, T13N, R9E, UM At top of producth/e interval 631' FSL, 390' FEL, Sec. 29, T13N, RgE, UM At effective depth ,At total depth ~,709' FNL, 402' FEL, Sec. 29, T13N, R9E, UM 12. Present well corKJiUon surnrn~y Total depth: measured true vertical Plugging _ T~me exlension _ Slimulale _ Pull tubing _ Va~a~ ce _ Perforate _ 5. Type of Well: Development _X Exploralo~7 __ Stratigraphic _ (asp's 518121, 6013799) (asp's 518002, 6012806) 6890 feet Plugs (measured) 6660 feet 6. Datum elevation (DF or KB feet) RKB 67 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3N-08A 9. Permit number / approval number 186-068 10. APl number 50-029-21540-01 11. Field / Pool Kuparuk Oil Pool Other _ Effective depth: measured flue vertical Casing Length CONDUCTOR 115' SUR. CASING 3556' PROD. CASING 6786' feet Junk (measured) feet Size Cemented Measured Depth 1 6" 231 sx cs u 115' 9-5/'8' lO6O sx AS III & 260 Sx Class G 3623' w/150 sx ASI Top Job 7" 3~0 sx Classs G & 175 sx AS I 6853' True vertical Depth 115' 3619' 6628' Perforation depth: measured 6460-6470; 6536-6~; 6544-6547; 6547-6558; 6560-6590; 6601-6607 flue verticaJ 6294-6302; 6359-6365; 6365-6368; 6368-6377; 6349-6405; 6414-6419 Fubing (size. grade, and measured depth Pack~=-rs & SSSV (type & measured depth) 2-7/8', 6.5#, J-55 Tbg 0 6370' MD. BROWN 'HB-I' @ 6300' MD. ,eN/A 13. Attachments Description summary of proposal __X Detailed operations program __ 15. Status of well classification as: 14. Estimated date for commencing operation January 1, 2002 16. If proposal was verbally approved IXlame of approver Date approved RECEIVED L. i F' ' BOP sketc~ ,..,~h~3~ Oil __ Gas __ Suspended __ Service_X Water Injection 17. ! hereby certify that the Ioregoing is true and correct to the best ol my imowledge. Questions? Call Jerl Spencer 659-7226 .~~~ ~ /'~"~l~fl'~''''~' ~''~'''~'~lzngIneering ~~supervlsor ~-///~.,'~ Signed je ~ e: Production Date Prepare~l b~ Robefl Chr~$rensen 659- 7535 FOR COMMISSION USE ONLY Conditions of approval: NoM~ Commission so representa§ve may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test__ Subsequenl form required 10- ['IL~'~ I prova,,o. - _ C Approved by order of the Commission Original Signed By Commissioner Date 3N-O8A DESCRIPTION SUMMARY PROPOSAL Phillipas Alaska Inc. is requesting approval to convert 3N-O8A from temporary oil production to Water injection service. 3N-08A was put on backflow in November 2001 for reservoir pressure reduction in support of new well ddlling operations fy 3N-19. 3N-08A will be tumed to Water injection service after 3N-19 is cased. Tom, Here's a short summary regarding the status of 3N-08A and 3N-12. Both wells were temporarily converted to production to reduce reservoir pressure in the area so that drilling operations could safely commence on 3N-19. Because the wells were expected to be produced longer than 4 weeks, PAI filled out Sundry Form 10-403 and 10-404's for the temporary conversion of these wells. Sundry Form 10-403's were recently filled out to return the wells to water injection service once 3N-19 drilling operations are completed (approx. the first week in January). Once the P-to-I conversions are actually completed, Sundry Form 10-404's will be generated and forwarded to the AOGCC. I-to-P I-to-P P-to-I P-to-I 10-403 10-404 10-403 10-404 3N-08A WI 09/07/91 10/14/01 10/29/01 12/09/01 Jan. '02 3N-12 WI 04/01/87 10/14/01 10/29/01 12/09/01 Jan. '02 Let me know if you need anything else. Jeffrey A. Spencer Production Engineering & Offiake Supervisor Phillips Alaska, Inc. 907-659-7226 Slope jspencer~ppco.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging Pedorate Pull tubing _ Alter casing _ Repair well Other X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development_ RKB 67 feet 3. Address Exploratory _ 7. Unit or Properfy name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 Service x Kuparuk Unit 4. Location of well at surface 8. Well number 3716' FNL, 277' FEL, Sec. 29, T13N, R9E, UM (asp's 518121, 6013799) 3N-08A At top of productive interval 9. Permit number / approval number 631' FSL, 390' FEL, Sec. 29, T13N, R9E, UM 186-068 / At effective depth 10. APl number 50-029-21540-01 At total depth 11. Field / Pool 4709' FNL, 402' FEL, Sec. 29, T13N. R9E, UM (asp's 518002. 6012806) Kuparuk Oil Pool 12. Present well condition summary Total depth: measured 6890 feet Plugs (measured) true vertical 6660 feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 115' 16' 231 sx cs II 115' 115' SUR. CASING 3556' 9-5/8' lO6O sx AS III & 26O Sx Class G ~ 3623' 361 9' PROD. CASING 6786' 7" 31o sx Classs G & 175 sx AS I 6853' 6628' Perforation depth: measured 6460-6470; 6536-6544; 6544-6547; 6547-6558: 6560-6590; 6601-6607 true vertical 6294-6302; 6359-6365; 6365-6368: 6368-6377; 6349-6405:6414-6419 ..- " Tubing (size, grade, and measured depth) 2-7/8". 6.5#, ,_1-55 Tbg @ 6370' MD. Packers & SSSV (type & measured depth) BROWN 'HB-I' @ 6300' MD. ¢N/A .. 13. Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 336 2680 2856 Subsequent to operation 650 2680 150 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __ Gas __ Suspended __ Service _X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Jeff Spencer 659-7226 Signed %~-.- ~ .~~~~ 'l-itle Production Engineering Supervisor //-~o~'-~/ Date Jeff A. Spencer-- / r~repafecl Dy r2ooert Chr, stensen 659-7555 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 3N-08A DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 10/18/011Injection well put on temporary flowback to production for reservoir pressure reduction ! 1 MICROFILMED 9/11/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE · l,/ · ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 February 1 4, 1994 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 Applications for Sundry Approval on the following Kuparuk wells. Well ¢u~-- ~'5~ 1L-06 S~, -(~5 3N-08A ~ i'a~ 3Q-15 Action Variance (SSSV) Change Program (Inj Valve) Change Program (Inj Valve) If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Attachments RECEIVED FEB 1 6 1994 Alaska 0il & Gas Cons. Commission Anchorage AR3B-6003-93 242-2603 - ARCO Alaska, Inc. April 20, 1994 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in duplicate is a Report of Sundry Well Operations (Form 10-404) notice in the Kuparuk field. The well is listed below. WELL ACTION 3N-08A Other (Inj Valve) If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Engineer Kuparuk Petroleum Engineering Well Files (Atch only) FTR042096 (w/o atch) EC£1¥ED ! . ~., ~_,:;:~ c.~.,;:~. 0~mmission STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown __ Stimulate Plugging_ Pull tubing Alter casing Repair well Perforate Other X 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 1561' FSL, 279' FEL SEC. 29, T13N, R9E, UM At top of productive interval 802' FSL, 361' FEL, SEC. 29, T13N, R9E, UM At effective depth 631' FSL, 390' FEL, SEC.29, T13N, R9E, UM At total depth 567' FSL, 401' FEL, SEC.29, T13N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 6890' feet Plugs (measured) 6659' feet 6. Datum elevation (DF or KB) RKB 67' 7. Unit or Property name Kuparuk River Unit Ieet 8. Well number 3n-08A 9. Permit number/approval number 86-68 / 94-042 10. APl number 50-029-2154001 11. Field/Pool Kuparuk River Field Kuparuk River Oil Pool 13. Effective depth: measured true vertical 6767' feet Junk (measured) 6555' feet Casing Length Size Structural Conductor 8 0' I 6" Surface 358 6 9 5/8" Intermediate Production 6 81 8' 7" Liner Perforation depth: measured 6460'-6470', true vertical 6294'-6302', Cemented Conductor Rpt Not Available 1060 Sx AS III & 260 Sx Class G 310 Sx Class G 6536'-6558', 6560'-6590', 6359 '-6377', 6379'-6404', Tubing (size, grade, and measured depth) 2-7/8"6.5#, J-55, ABM, @6370' Packers and SSSV (type and measured depth) SSSV: Baker FVL (1763'), Packer: Stimulation or cement squeeze summary Installed MCV Injection Valve Intervals treated (measured) BROWN HB-1 (6300') Treatment description including volumes used and final pressure Measured depth True vertical depth 115' 115' 3623' 3619' 6853' 6628' 6601'-6607' 6414'-6419' RECEIVED ~. U:, ,3. C;:3 ~C;;!5. (.,Jiit,~,'iS$iOr' Anch~r?g~ 14. Prior to well operation Subsec]uent to operation Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 0 0 752 0 0 706 Tubing Pressure 2812 2811 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector _X_._ Oil Gas Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed P~'~ "P~----~ Title Sr. En,(]ineer Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE WELL ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company CONTRACTOR REMARKS IPBDT . WELL SERVI¢ FIELD - DISTRICT- STATE OPERATION AT REPORT TIME 0~_3 o - · R kLkl v ~t-.~ [--I CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK =W.e..a2h..,er I Temp. I Chill Factor I Visibility l Wind Vel. ISigned KUPARUK WELL 3N-08A WATER INJECTION WELL APl#: 50-029-21540-01 ADL LEASE: 25521 SPUD DATE: 03/16/86 COMPLETION DATE: 04/27/86 SURFACE LOCATION: 1561' FSL, 279' FEL, SEC 29, T!3N, R9E, UM TOP OF KUPARUK: 631' FSL, 390' FEL, SEC 29, TI3N, R9E, UM ~ LOCATION: 567' FSL, 401' FEL, SEC 29, T13N, R9E, UM PERMIT~: WORKOVER DA~. ORIGINAL RKB: 67 TUBING SPOOL: 33 PAD ELEVATION: 33 FMC GEN III 2-9/16" HGR AIIDepthsare MD-RKBtotopofequipmentunle~ othe~isenoted CASING and TUBING DETAILS s~z~ ~ZGHT GRADE ~ 16" 62.5 H-40 115' 9.625" 36.0 J-55 3623' 7" 26.0 J-55 6853' 2.875" 6.5 J-55 ABM 6370' MISC. DATA DESCRIPTION KICK OFF POINT: MAX HOLE ANGLE: 32° ANGLE THRU KUP: 31° IArD TO UPPER PKR: TVD TO TOP C SD PERF TVD TO TOP A SD PERF VOLUME TO t~T VOLUME TT TO TOP PERF VOLUME 7" ANNULUS 4500' 6700' 6157' 6294' 6359' 36.7 BBLS 3.4 BBLS 189.0 BBLS RECEIVED PERFORATION DATA ~ ZONE SPF PHASE ~ 6460-6470 C1 8 60° STRIP GUNS 6536-6558 A3 6 0° STRIP GUNS 6560-6590 A2 4 90° 4" GUNS 6601-6607 A1 4 90° 4" GUNS L 1763': BAKER FVL SSSV (2.31" I.D.) MCX INJECTION VALVE SN 204 2242': MERLA TMPD 1" GLM (DV) 3723': MERLA TMPD 1" GLM (DV) 4622': MERLA TMPD 1" GLM (DV) 5149': MERLA TMPD 1" GLM (DV) 5494': MERLA TMPD 1" GLM (DV) 5869': MERLA TMPD 1" GLM (DV) 6246': MMY HUGHES 1.5" GLM DV P~C~FF 6284': BROWN P~ 6300': BROWN HB-1 FKR 6337': CAMCO D NIPPLE (2.25" I.D.) 6370': CAMCO BII~AR OUT SUB NOTE: 1-1/2" DV · 6593' TWO 1.94' X 7" BULLNOSES O 6597' 6593': LAST TAG (09/17/91) 6767': PBTD (6488' SUB-SEA) REVISION DATE: 03/13/94 REASON: INSTALL DV PACKOFF BY: LBA:CH STATE OF ALASKA ALA,SKA OIL AND GAS GONSF_FIVATION ~ APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon 2. Name of Operator Alter casing __ Repair well Change approved program X 5. Type of Well: Development Exploratory Stratigraphic measured 6 8 9 0' feet true vertical 6 6 5 9' feet ARCO Alaska. Inc. 3. Address J P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 1561' FSL, 279' FEL SEC. 29, T13N, R9E, UM At top of productive interval 802' FSL, 361' FEL, SEC. 29, T13N, R9E, UM At effective depth 631' FSL, 390' FEL, SEC.29, T13N, R9E, UM At total depth 567' FSL~ 401' FELt SEC.29r T13Nr R9E~ UM 12. Present well condition summery Total Depth: Operation Shutdown m Re-enter suspended well __ _ Plugging_ Time extension _ Stimulate _ Pull tubing __ Variance _ Perforate __ Other Plugs (measured) 6. Datum elevation (DF or KB) RKB 67' feet 7. Unit or Property name Kuparuk River Unit 8. Well number 3N-08A ,' --" 9. PeflTtit number 86-68 " 10. APl number · 5o-02921 54001 .~' 11. Field/Pool Kuparuk River Fii~'ld Kuparuk R~ ~I,.P~)I~ ,- m KI LEIVEL] Effective depth: measured 6 7 6 7' feet true vertical 6 5 5 5' feet Casing Length Size Structural Conductor 8 0' 1 6" Surface 3 5 8 6 9 5/8" Intermediate Production 681 8' 7" Liner Perforation depth: measured 6460'-6470', Junk (measured) Conductor Rpt Not Available 1060 Sx AS III & 260 Sx Class G 310 Sx Class G .. ,.;~,a U~i & 6as Cons. Commission Anchorage Measured depth True vertical depth 115' 115' 3623' 3619' 6853' 6628' 6536'-6558', 6560'-6590', 6601'-6607' true vertical 6294'-6302', 6359'-6377', 6379'-6404', 6414'-6419' Tubing (size, grade, and measured depth) 2-7/8"6.5#, J-55, ABM, @6370' Packers and SSSV (type and measured depth) SSSV: Baker FVL (1763')r Packer: BROWN HB-1 (6300') 13. Attachments Description summary of proposal X Detailed operation program _ Install MCV Injection Valve BOP sketch 14. Estimated date for commencing operation February_. 1994 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Gas se~ca Water Iniector 17. I her.~~~ 7 ~ true and correct to the best of my knowledge. Sicjned Title Sr. Engineer FOR ~ION USE ONLY Conditions of approval: Notify Commission so representative mey witness Plug integrity BOP Test _ Location clearance Mechanical Integrity Test _ Subsequent form require 10- ~O% IApproval No. Approved by order of the Commission Form 10-403 Rev 09/12/90 Original Signed By David W, Johnston Commissioner ~,uproved Copy Returned SUBMIT IN TRIPLICATE Attachment 1 Request for Variance Kuparuk Well 3N-08 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 3N-08A with a downhole, spdng 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 proposed work is to install an injection valve to prevent uncontrolled flow by automatically closing if upward flow of fluids should occur. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 ORiGI? Ai September 27, 1991 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston' Attached in duplicate is a Report of Sundry Well Operations for the well listed below. WE LL ACTION 3N-08A Conversion If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Operations Engineer CC: W. H. Carter ATe 1176 KeEl .4-9 w/o attachments REEEIVED ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company '. - · STATE OF ALASKA ~ OIL AND GAS CON,.O~RVATION C_,OMMIS;51ON REPORT OF SUNDRY WELL OPERATIONS ORiGiNAl 1. Operation Performed' Operation Shutdown__ Pull tubing Alter casing Stimulate __ Plugging Repair well Perforate 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 ~ ~ r'~ 4. Location of well at surface 1561' FSL, 279' FEL, Sec. 29, T13N, R9E, UM At top of productive interval 802' FSL, 361' FEL, Sec. 29, T13N, R9E, UM At effective depth 631' FSL, 390' FEL, Sec. 29, T13N, R9E, UM At total depth 567' FSL, 401' FEL, Sec. 29, T13N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 6890' 6659' feet Plugs (measured) feet 6. Datum elevation (DF or KB) 67' RKB 7. Unit or Property name Kuparuk River Unit feet 8. Well number 3N-08A 9. Permit number/approval number 86-68 10. APl number 50-029-21540-01 11. Field/Pool Kuparuk River Oil Pool Effective depth: measured 6 76 7' true vertical 6555' feet Junk (measured) feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth 80' 16" 115' 3586' 9 5/8" 1060 Sx AS III & 3623' 260 Sx Class G 6818' 7" 300SxClassG 6853' measured 6544'-6547', 6560'-6590', 6601 '-6607' MD true vertical 6365'-6368', 6379'-6404', 6414'- 6419' TVD Tubing (size, grade, and measured depth) 2 7/8" J-55 tubing w/ tail @ 6370' md Packers and SSSV (type and measured depth) SSSV: ~ 1763', Packer: Brown HB-1 Pkr ~ 6300' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure True vertical depth 115' 3619' 6628' RECEIVF. D OOT u 1991 4/e ka Gas Cons. C n lon 14. Prior to well operation Reoresentative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 3OO 130 0- 1120 Tubing Pressure 100 Subsequent to operation -0- -0- 2000 1200 9OO 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Water Injector X Oil _ Gas Suspended Service J17. I he, r~by certify that the fo. regoing is true and correct to the best of my knowledge. Signed ' Title ,~_ /~1/,, Form 10-404 Rev 09/12/90 SUBMIT IN DUPLICATE ARCO Alaska, Inc. Subsidiary of Atlantic Richfield Company WELL CONTRACTOR REMARKS PBDT IFIELD - DISTRICT- STATE OPERATION AT REPORT TIME WELL SERVICE REPORT DAYS DATE /_3 ~/~ I££ g /4,20 / 2 o3g -~CHECK THIS BLOCK If SUMMARY CONTINUED ON BACK Weather Temp. Chill Factor ~ Visibility Wind Vel. i Signed ,:~/,. ,~ ]. Re~)ort .. .... REMARKS CONTINUED: CAMCO OTIS SCHLUMBERGER DRESSER-ATLAS i DOWELL :,HALLIBURTON ARCTIC COIL TUBING ', FRACMASTER i B.J. HUGHES DESCRIPTION" DALLY ACSUM. TOTAL__ ;Roustabouts i Diesel : Methanol ~ Supervision Pre-Job Safety Meeting AFE TOTAL FIELD ESTIMATE ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 25, 1991 Mr. David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Attached in triplicate is an Application for Sundry Approval on the following well. This well is within the the Kuparuk River Unit, but is not completed in the Kuparuk Oil Pool. W~ll Action Anticipated Start Date 3N-08A Conversion September, 1991 If you have any questions, please call me at 263-4241. Sincerely, P. S. White Senior Operations Engineer CC: M. E. Eck ATO 1120 S. M. Renke ATO 1126 KOE1.4-9 w/o attachments RECEIVED J U L 3 1 t99! Alaska Oil & Gas Oons. Commission Anchorage ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company l ;KA OIL AND G/~ ~VATI(DN ~...SIGN 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 _ Pedorate _ Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development ~ ARCO Alaska. Inc. Exploratory _ RKB 67 feet 3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service _ Kuparuk River Unit 4. Location of well at surface 8. Well number 1561' FSL, 279' FEL, Sec. 29, T13N, R9E, UM 3N-08A At top of productive interval 9. Permit number 802' FSL, 361' FEL, Sec. 29 T13N, R9E, UM 86-68 At effective depth 10. APl number 631' FSL, 390' FEL, Sec. 29, T13N, R9E, UM so-029-21540-01 At total depth 11. Field/Pool Kuparuk River Field 567' FSL~ 401' FEL~ Sec. 29~ T13Nr R9E~ UM Kuparuk River Oil Pool 12. Present well condition summary Total Depth: measured 6 8 9 0' feet Plugs (measured) true vertical 6 6 5 9' feet Norle Effective depth: measured 6 76 7' feet Junk (measured) true vertical 6 5 5 5' feet Nolle Casing Length Size Cemented Measured depth True vertical depth Structural Conductior Report cor~k~ 8 0' I 6' Not Available 1 1 5' 1 1 5' Surface 3586' 9 5/8' 1060 Sx AS III & 3623' 3619' Intermediate 260 Sx Class G Production 6 81 8' 7 ' 310 Sx Class G 6 8 5 3' 6 6 2 8' Uner Perforation depth: measured ~) J.- ~." ~' ~ ~/ ~ [-"j 6544'-6547', 6560'-6590', 6601 '-6607' md true vertical 6365'-6368', 6379'-6404', 6414'-6419' TVD JUL -;¢ ! !.~9~ Tubing (size, grade, and measured depth) L!'~ 2 7/8" J-55 tubing w/ tail @ 6370' ........ Packers and SSSV (type and measured depth) Anchcra;e Brown HB-1 Pkr ~ 6300'~ & SSSV ~ 1763' 13. Attachments Description summary of proposal _ Detailed operation program _ BOP sketch_ Convert well from oil producer to water injector. (Wellbore schematic attached). 14. Estimated date for commencing operation 15. Status of well classification as: SeDtember. 1~)91 Oil ~ Gas ~ Suspended _ 16. If proposal was verbally approved Name of approver Date approved Service .Water Iniector 17. I he.y certJ.fl/~t the~ true and correct to the best of my knowledge. FOR COMMISSION USE (~ILY Conditions of approval: Notify Commission so representative may witness IApproval No. Plug integrity ~ BOP Test __ Location clearance __ Mechanical Integrity Test X~ Subsequent form require 10-¥~)~ ' Original Signed By David W. Johnston ._~ Approved b)~ order of th® Commission Commissioner Da~ Form 10-403 Rev 09/12/90 SUBMIT IN TI ilPLICATE Approved Copy ~ I~etume__d KUPARUK WELL 3N-08A APl #: 500292154001 SPUD DATE: 03/16/86 ADL LEASE: 25521 COMPLETION DATE: 04/27/88 PERMIT #: WORKOVER DATE: ORIGINAL RKB: SURFACE LOCATION: 1561 'FSL,279'FEL,SEC29,T13N,R9E TOP OF KUPARUK: 631'FSL,390'FEL, SEC29,T13N,RgE TD LOCATION: 567'FSL,401'FEL, SEC29,T13N,R9E All deplf~ am MD-RI(B to t~p of equipment unless olheneise noted 67 PAD ELEVATION: rTEM sssv WRDP PKR CASING and TUBING DETAILS SIZE WEIGHT GRADE DEPTH 16' 62.5~ I-t-40 115 9.625' 36~ J-55 3623 2.875' 6.5~ J-55 ABM 6370 UNER DETAILS WEIGHT GRADE TOP BTM SIZE TUBING JEWELRY TYPE ID DEPTH BAKER FVL 2.31 · 1763 CAMCO 1.12' BROWN PBR 6284 BROWN HB-1 630O CAMCO 'D' NIPPLE 2.25' 63,37 CAMCO PE-5(X) 6370 TUBING SPOOL: 33 WELLTYPE: PRODUCER MISC. DATA DESCRIPTION DEPTH KICK OFF POINT: 4500 MAX HOLE ANGLE: 32 deg 6700 HOLE ANGLE THRU KUP: 31 deg LAST TAG DATE: 07/04/89 6603 RATHOLE: -4 It FISH/OBSTRUCTION: 6597 TWO 1.94'ZT"BU~ PBTD: 6767 .-.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:.:-:.:.:. .:-;.;.;-;.:.;,;.;-:.:-;.;.:-:.;.:.;.;-;.:-;-;.:v;.;.:--;.:.:.. :::::::::::::::::::::::::::::::::::::::::::::::::::::::: ..:... INTERVAL 646O-6470 6601-6607 GAS UFT and FLOW INFORMATION VALVE STN DEPTH 2 3723 3 4622 4 5149 5 5494 6 5869 7 6246 PORT MANDREL SIZE SIZE MERLA TMPD 1' 0.1563 MERLA TMPD 1' DV MERLA TMPD 1' 0.1875 MERLA TMPD 1' DY MERLA TMPD 1 · DV MERLA TMPD 1' DY MCMURRY HUC_~ES 1.5' 0.2500 PERFORATION DATA ZONE FT SPF PHASE COMMENTS Cl 10 8 60 2-1/8'SILVERJET A3 22 6 0 1/6/91 Reperf A2. 30 4 90 4' HYPERJET II A1 6 4 90 4' HYPERJET II R ECEiV- ,..; r-,,., REVISION DATE: 07/12/89 REASON: LOCKED OUT SSSV ARCO Alaska. Inc. -- Pos[ Cffice Bc 00360 Ancnorace. AlasKa 99510-0,360 Teie.gnone 907 276 !2!5 November 9, 1988 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Attached in duplicate are multiple Reports of Sundry Well Operations on the following Kuparuk wells. Conversions 3N-11, 3N-10, 3N-05, 3N-04, 3F-12, 3F-03, 3F-08, 3N-03, 13, 1E-21, 1Eo19, 1E-23, 1E-lA, 1E-04, 1E-16 and1E-27 Fractures and Stimulations 3K-14, 3C-16, 3K-17, 1E-14, 3N-17, 3F-16 and 2V-12 Perforations 3N-11, 3F-11 and 3N-8A 1E-30 Failed MIT 3N-1 2, 3N- If you have any questions, please call me at 265-6840. Sincerely, G. B. Srrt~llwood ,/~..¢,.-./.~. Senior C)perations Engineer Attachments cc: J. Gruber M. b Hagood S. P. Twiggs KOE1.4-9 ATC) 1478 ATC) 1120 ATC) 113O RECEIVED NOV 1 1988 '"~,,. ~nc~orage ~RCC Alaska..nc .s a Su~.slalar¥ ot AtlantlcRicntieJcC.;m~,~.mv STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Pull tubing Alter casing Stimulate m Plugging Perforate X Repair well Pull tubing 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 4. Location of well at surface 1561' FSL, 279' FEL, Sec. 29, T13N, R9E, UM At top of productive interval 802' FSL, 361' FEL, Sec. 29, T13N, R9E, UM At effective depth 631' FSL, 390' FEL, Sec. 29, T13N, R9E, UM At total depth 567' FSL, 401' FEL, Sec. 29, T13N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical 6. Datum elevation (DF or KB) RKB 67 7. Unit or Property name Kuparuk River Unit 8. Well number 9. Permit number/approval number 7-617 10. APl number 5o-029-21540-01 11. Field/Pool Kuparuk River Oil Pool 6890' MD feet Plugs (measured) NONE 6659' TVD feet feet Effective depth: measured 6767' M D feet true vertical 6555' TVD feet Junk (measured) NONE Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth Conductor Reports 80' 1 6" Not Available 115' MD 3586' 9 5/8" 1060 Sx ASIII 3623' MD & 260SX ClassG 681 8' 7" 310SxClassG 6853' MD measured 6544'-6547', 6560'-6590', 6601'-6607' MD True vertical depth 115' TVD 3619' TVD 6628' TVD true vertical 6365'-6368', 6379'-6404', 6414'-6419' TVD Tubing (size, grade, and measured depth) 2-7/8", J-55 tbg w/tail @ 6370' Packers and SSSV (type and measured depth) HB-1 pkr @ 6300' & SSSV ~1763' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure . ...;:,,a 8;l & 6;.~ Cons. 14. Prior to well operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 328 412 0 1 300 Tubing Pressure 122 Subsecluent to operation 515 451 0 1 3O0 1600 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil%X,~~'-b Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~)ned ./,~..) Form 10-404 .,, ~,..- ~/,-,--~, Title 06/15~88 Service Water Iniection z, ¢- >7 / SUBMIT IN DUPLICATE -ARCO Alaska, Inc-~ Subs~liary of Atlantic Richfield Compan') WELL CONTRACTOR FIELD - DISTRICT- STATE OPERATION AT REPORT TIME WELL SERVICE REPORT JDA~ HEMARKS Z.c~5 - 2250 - A r 57Z5'. 6469' [] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather i Temp. Chill Factor I Visibility I Wind Vel, Report ~ 'F ~ °F J miles I knots I s~ned/~Y~ ~~ ARCO Alaska, Inc. Date: September 7, 1988 Transmittal #: 7285 RETURN TO: ARCO Alaska, Inc. Attn: Brenda K. Miernyk Kuparuk Records Clerk ATO- 1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. one signed copy of this transmittal. Please acknowledge receipt and return 3F-13 3K-18 3B-13 '3Q-15 3N-08A N 3H-14 ' 1E-12 '~, 3K-14 '31-03 1Y-06 1Y-07 Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Fluid Level Report Kuparuk Well Pressure Report Kuparuk Well Pressure Report 8-27-88 8-27-88 8-26-88 8-27-88 8-26-88 8-26-88 8-26-88 8-26-88 8-26-88 8-26-88 8-26-88 Casing Tubing Casing Casing Casing Casing Casing Casing Casing Both Sands Sand 'A' Receipt Acknowledged. DISTRIBUTION; D&M State of Alaska ' -- Ancnorsge Chevron Unocal Mobil SAPC ll'j' ~,~'~ ~i i~ ~,' ( ' DEPARTMENT OF NATURAL RESOURCES DIVISION OF OIL AND GAS July 6, 1988 STEVE COWPEt ~ S_R ENG PO BOX 7034 ANCHORAGE. ALA (907)762-25 STA~~ R ECEIV, ' ' John Wood, Area Landman ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-360 Alaska Oil & Gas Cons. Commission Anchoram, Dear Mr. Wood: In your July 5, 1988 letter you requested extended confidentiality for the data from the Kuparuk River Unit development wells 3N-5, 3N-7, 3N-8 and 3N-8A. These wells are situated south of an unleased tract at Oliktok Point, U. S. Survey No. 4275, with surface reserved for the U. S. Air Force (see attached map). The 3N-7 and 3N-8A wells are scheduled to be released on July 7, and the 3N-5 well is scheduled for release on July 9, 1988. The 3N-8 well was released on April 14, 1988. On July 6, 1988 you and other ARCO staff members met with division staff to discuss your request. Following your written request, and after careful consideration of the discussion between our staffs, I am denying your request to extend the confidentiality of the 3N-5, 3N-7 and 3N-8A wells. Under AS 31.05.035(c): "If the con~issioner of natural resources finds that the required reports and information contain significant information relating to the valuation of unleased land in the same vicinity, the commissioner shall keep the reports and information confidential for a reasonable time after the disposition of all affected unleased lands." Significant reports and information from the ARCO Oliktok Pt. No. 1 Well, as well as data from the 3N-4 and 3N-8 wells, are already available to the public. The data from the Oliktok Pt. No. 1 Well, situated directly between the unleased tract and the three wells in question, are particularly significant to the valuation of the unleased tract. There are already several wells which have been released to the public which provide a good data base for valuation; therefore, we do not think that the data from these three wells would make a significant difference to an interpretation of the geology in the valuation of the unleased land at Oliktok Point. There are several other wells in this area scheduled to be released within the next year. So that you may evaluate any future requests for confidentiality extensions, we would like to advise you of our current leasing plans. January 1989 is the earliest month that the Oliktok Point tract could be offered for John Wood July 6; 1988 Page 2 lease. The division is considering offering the tract in January 1989 if all manpower, noticing, ownership and other legal requirements can be met. If this timing does not prove possible, September 1989 will present the division's next practical opportunity to offer this acreage. The division received your request only one day prior to the release date of the data from the 3N-7 and 3N-8A wells. We encourage you to submit any requests for extended confidentiality not more than 90 days prior to, but at least 30 days prior to, any release date in order to provide sufficient time for request evaluation, consideration, decision and notification of Alaska Oil and Gas Conservation Con~niss~on (AOGCC). By copy of this letter I am advising the AOGCC to proceed with' release of the ARCO Kuparuk River Unit 3N-5, 3N-7, and 3N-8A wells as previously scheduled. Si ncerely, ames E. Eason irector Attachment 1526E cc: C. V. Chatterton, Con~nissioner, AOGCC Judith M. Brady, Con~nissioner, DNR 1 526E STATE OF ALASKA - ALA, ,A OIL AND GAS CONSERVATION CO~, .,ioSlON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon - Suspend -- Operation Shutdown - Re-enter suspended well ' Alter casing Time extension _- Change approved program ~ Plugging -- Stimulate - Pull tubing - Amend order Perforate Z Other 2. Name of Operator ARCO Alaska, Inc 3. Address PO Box 100360, Anchorage. AK 99510 4. Location of well at surface 1561' FSL. 279' FEL, Sec. 29 T13N RgE UN At top of productive interval ' ' ' 802' FSL, 361' FEL, Sec.29, T13N, R9E, UN At effective depth 631' FSL, 390' FEL, Sec.29, T13N, R9E, UM At total depth 567' FSL. 401' FEL. Sec. 29. T13N: R9E: UM 5. Datum elevation (DF or KB) RKB 67 6. Unit or Property name Kuparuk River Unit 7. Well number 3N-SA 8. Permit number Permit #86-68 9. APl number 50-- 029-21540-01 10. Pool Kuparuk River Oi 1 P~nl 11. Present well condition summary Total depth: measured 6890' HD feet true vertical 6659' TVD feet Effective depth: measured 6767' MD feet true vertical feet 6555' TVD Casing Length Size XXX~[KK~:IXXXXX Conductor 80' !6" Surface 3586' 9-5/8" X X X ~'~1~ ~'lXCd4 ~te Production 6818' / xxx~j4~e~xxxx Perforation depth' Plugs (measured) NoPe 1 Junk (measured) ..... ~'~ ~one S~-~ ~ ~ ' Cemented Measu ed depth _,.. '/~ ~~' al depth Conductor Reports 115' TVB 3619' TVD 6628' TVD Not Available 115' MD 1060 SX ASIII & 3623' MD 260 SX Class G 310 SX Class G 6853' MD measured 6544'-6547' 6~60'-6590' 6601'-6607' MD true vertica16365'-6368' 6379'-6404' 6414' 6419' TVD Tubing (size. grade and measured depth) 2-7/8", J-55 tbg w/tail ~ 6370' Packers and SSSV (type and measured depth) HB-1 pkr @ 6300' ~, gg_gV fa 17~3' 12.Attachments Description summary of proposal % Detailed operations program BOP sketch 4ddinq perforations to a previously perforated interval apda nc, w int-¢rval 13. Estimated date for commencing operation September 20, 1987 Date approved 9/16/87 14. If proposal was verbally approved Name of approver L. Smith 15. t hereby certify that the foregoing is true and correct to the best of my knowledge Sr. Engineer Signed .-._.',,,{<.~ /'~ ,'i/",)"r'~'~L''' -r..,..~..~,.:' Title ~.pera~ons / Commission Use Only Conditions of approval Notify commission so representative may witness _- Plug integrity - BOP Test - Location clearance Date 9/16/87 Approved by JApproval No. / --./ ~- ,.~: /' /' Commissioner Form 10-403 Rev 12-1-85 by order of the commission Date _ ~.~/ ~¢_-_ feet Submit in triplica~,~,~ ARCO Alaska, Inc. Post Office ~,_ < 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: April 28, 1987 Transmittal #: 5961 RETURN TO: ARCO Alaska, Inc. Attn: Kuparuk Records Clerk ATO-11i9 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~3N-9 ~3N-8A ~2T-7 ~2T-4 ~T-15 ~2T-11 CEL 4-7-86 7500-9272 CEL 4-7-86 5100-9272 CET/CEL 10-29-86 6200-6712 CET/CEL 10-4-86 7350-8160 CET/CEL 10-7-86 6900-7465 CET/CEL 10-11-86 5965-6620 tt&o Receipt Acknowledged: DISTRIBUTION: NSK Drilling Mobil SAPC State of Alaska (+ sepia) Unocal Vault (film) BPAE Chevron ARCO Alaska, Inc. is a Subsidiary of AtlanlicRichfieldCompany STATE OF ALASKA C~' ALASKA OIL AND GAS CONSERVATION L, dMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well REV I 5ED OIL ~X GAS ~ SUSPENDED -' ABANDONED ~ SERVICE Z 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-68 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21540-01 4. Location of well at surface 1561' FSL, 279' FEL, Sec.29, T13N, RgE, UN At Top Producing Interval 631' FSL, 390' FEL, 5ec.29, T13N, R9E, UN At Total Depth 567' FSL, 401' FEL, Sec.29, T13N, R9E, UN 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. RKB 67' I ADL 25521 ALK 2557 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 03/16/86 I 03/18/86 06/07/86* I 17. Total Depth (MD+TVD) 18. Plug Back Depth(MD+TVD) 19. Directional Survey 6890'ND, 6659'TVD 6767'MD, 6555'TVD YES '~ NO -~ 22. Type Electric or Other Logs Run DIL, FDC/CNL, Ca1, CCT, CET 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 3N-8A 11. Field and Pool Kuparuk River Fi eld Kuparuk River Oil Pool 15. Water Depth, if offshore ! 16. No. of Completions N/A feet MSL i 1 20. Depth where SSSV set 21. Thickness of Permafrost 1763' feet MD 1700' (approx) 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE 1 WT. PER FT. ' 62.5# GRADE H-40 TOP Surf 24. Perforations open to Production (MD+TVD of Top and interval, size and number) BOTTOM HOLE SIZE 115' 24" 9-5/8" 36.0// J-55 Surf 3623 ' 12-1/4" 7" 26.0# J -55 Surf 6853 ' 8-1/2" lottom and 25. TUBING RECORD 6365'-6368'TVD 6379'-6404'TVD 6414'-6419'TVD 6544'-6547'MD 6560'-6590'MD 6601'-6607'MD CEMENTING RECORD AMOUNT PULLED 231 SX C,5 II 1060 sx AS III & 260 sx Class C Top job performed w/150 sx AS I 310 sx Class O & 175 s: AS I t SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" 6370' 6300' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL(MD) IAMOUNT& KIND OF MATERIAL USED ] See Addendum attac~ed to Well Completion Report, dated 7/I/86. 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) ' I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL ! CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ Flow Tubing Casing Pressure CALCULATED ~, OIL-BBL GASoMCF WATER-BBL lOlL GRAVITY-APl (corr) Press. 24-HOUR RATE I 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED *Note: Drilled RR 3/20/86. Alaska 0il & Gas Cons. Anchorage Well perforated & tubing run 4/27/86. wC3/32:DANI Submit in duplicate Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A GEOLOGIC MARKERS MEAS. DEPTH 6436' 6468 ' 6527' 6657' TRUE VERT. DEPTH 6272' 6300' 6350' 6461' 30. ~'FOF~MATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, a--.d-t;me of each phase. N/A 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Associate Engineer 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- lng 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 10407 ARCO AlasKa. Ir Post Office Box 100360 Ancl~orage. AlasKa 99510-0360 Tetel3~one 907 276 1215 P~rURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 08-21-S6 TRANSMITTAL # 5746-B Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Final Prints: Schl: Open Hole: One * of each 3N-8A~'-5" DIL/SFL-GR --2'.' DIL/SFL-GR ~/~_-~ ~ ~i: Den/Nou-GR (poro) Den/Neu-GR (poro) / /~5" Den/Neu-GR (raw) ~~2" Den/Neu-GR (raw) -~~. ~Cyberlook 03-19-86 03-19-86 03-19-86 03-19-86 03-19-86 03-19-86 03-19-86 Run #2A 3624-6859 Run #2A 3624-6859 Run #2A 6170-6834 Run ~2A 6170-6834 Run #2A 6170-6834 Run #2A 6170-6834 Run #2A 6170-6834 The following logs are Run #1 and 2 combined. They are listed according to Run #2 to save space and time. (Only the DIL's) 3N-9 --5~' DIL/SFL ~--2" DIL/SFL ~% -~2J' Oen/Neu ~./ O~:; Den/Neu Den/Neu ~ z Den/Neu ~Cyberlook (poro) (poro) (raw) (raw) 03-27-86 03-27-86 03-27-86 03-27-86 03-27-86 03-27-86 03-27-86 Run #2 4671-9376 Run #2 4671-9376 Run #2 8300-9350 Run #2 8300-9350 Run #2 8300-9350 Run #2 8300-9350 Run #2 8700-9330 3N-10 -5" DIL/SFL-GR '~2~' DIL/SFL-GR ~5" Den/Neu-GR (poro) ~2" Den/Neu-GR (poro) -5" Den/Neu-GR (raw) ~2" Den/Neu-GR (raw) ~-~yberlook 04-03-86 04-03-86 04-03-86 04-03-86 04-03-86 04-03-86 04-03-86 Run #1 0100-9379 Run #1 0100-9379 Run #1 6880-9354 Run ~1 6880-9354 Run ~1 6880-9354 Run #1 6880-9354 Run #1 8650-9175 Receipt Acknowledged: State Of AK*bl~se~ Drilling*bi Date: Rathmell*bl D&M *bi ARCO AIIIII. Il'lC ,l · $ul)l,OlAIr~ Of AIIIrttlCl~lCl'lf,ell~ComDafl}, STATE OF ALASKA (~ ALASKA O~L AND GAS CONSERVATION CO,¥,MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG /_. Classification of Service Well .I GAS ~ SUSPENDED a ABANDONED ~ SERVICE "~ ~' I' 1. Status of Well OiL _~"~, 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86-68 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21540-01 9. Unit or Lease Name Kuparuk River Unit 4. Location of well at surface 1561' FSL, 279' FEL, Sec.29, T13N, R9E, UM At Top Producing Interval 631' FSL, 390' FEL, Sec.29, T13N, R9E, UM At Total Depth 567' FSL, 401' FEL, 5ec.29, T13N, R9E, UN 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 67' RKB I ADL 25521 ALK 2557 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 03/1 6/86 03/1 8/86 06/07/86* 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionaISurvey 6890 'MD,6659 'TVD 6767 'MD,6555 'TVD YESX~ NO .'--1, 10. Well Number 3N -SA 11. Field and Pool Kuparuk River Fi eld Kupaurk River Oil Pool 15. Water Depth, if offshore 116. No. of Completions N/A feet MSL/ 1 20. Depth whereSSSV set I 21. Thickness of Permafrost 1763 feet MD I 1700' (approx) 22. Type Electric or Other Logs Run DIL, FDC/CNL, Cal, GCT, CET 23. CASING, LINER AND CEMENTING RECORD CASING SIZE i6~ 9-5/8" WT. PER FT. 62 36.0# 7" 26.0# 6560 ' -6590 'MD 6601 ' -6607 'MD GRADE H-4O SETTING DEPTH MD TOP ' Surf BOTTOM 115' HOLE SIZE 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 6544'-6547 'MD 6365 '-6368'TVD 6379'-6404 'TVD 6414 '-6419'TVD CEMENTING RECORD 24" 231 sx CS II J-55 Surf 3623' 12-1/4" 1060 sx AS III & 260 sx Top job performed w/150 J-55 Surf 6853' $-1/2" 310 sx Class G 25. TUBING RECORD JAMOUNT PULLED C1 ass G sxAS I SIZE 2-7/8" 26. DEPTH SET (MD) IPACKER SET (MD) 6370' J 6300' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED See attached addenqlum, dated 6/11/86, for fracture data / 27. N/A PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD I~ OIL-BBL GAS-MCF WATER-BBL ;OIL GRAVITY-APl (corr) Flow Tubing Casing Pressure CALCULATED j 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. None RECEIVED J U L 1 0 1986 AiaSl<it 0ii & Gas Cons. Cornrniss!s? Ancnor.~ge Form 10407 * NOTE: Drilled RR 3/20/86. Well perf'd & tubing run 4/27/86. Rev. 7-1-80 CONTINUED ON REVERSE SIDE WC1/082 Submit in duplicate / 30. 29. :~ GEOLOGIC MARKERs ~ORMATION 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 6436' 6272' N/A Base Kuparuk C 6468' 6300' Top Kuparuk A 6527' 5350' Base Kuparuk A 6657' ~:~461' · 31. LIST OF ATTACHMENTS Addendum (dated 6/11/86) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ , TitIeASS°ciate Engineer Date__ 7-2-~ , 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 inject;on, 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- lng 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 ADDENDUM WELL: 6/7/86 3N-8A Frac'd Kuparuk "A" sand perfs 6544', 6547', 6560'-6590' & 6601'-6607' in 9 stages per 6/5/86 procedure using Musol, diesel, gel/diesel, 100 mesh & 20/40 sand. Press'd annulus to 1800 psi w/diesel. Tst Ins to 8500 psi; OK. Stage #1: Pmp'd 20 bbls 130° diesel w/5% Musol @ 4 BPM w/2320 psi Stage #2: 42 bbls gel/diesel @ 20 BPM w/5830 psi #2A: 20 bbls @ 20 BPM w/4490 psi Stage #3: 21 bbls pre-pad @ 20 BPM w/4370 psi Stage #4: 24 bbls gel/diesel w/1 ppg 100 mesh @ 20 BPM w/4370-4160 psi Stage #5: 128 bbls gel/diesel Pad @ 20 BPM w/4160-4120 psi Stage #6: 19 bbls gel/diesel w/3 ppg 20/40 @ 20 BPM w/4120-3830 psi ("on fly") Stage #7: 40 bbls gel/diesel w/6 ppg 20/40 @ 20 BPM w/3830-4980 psi ("batch") Stage #8: 15 bbls gel/diesel w/8 ppg 20/40 @ 20-17.5 BPM w/4980-5500 psi ("batch") Stage #9: 42 bbls gel/diesel flush @ 17.5 BPM w/5500-5650 psi Pmp'd 1000# 100 mesh & 17,250# 20/40 in formation leaving 270# 20/40 sand in csg. Load to recover 371 bbls of diesel. Job complete @ 1020 hrs, 6/7/86. Turn well over to Production. (Note: Production to rn post frac logs.) Drilling Supervisor Date ~UB.~URFACE DIRECTIONAL ~URVEY ~[UIDANCE r~ONTINUOUS ~-[OOL Company Well Name Field/Location ARCO ALASKA INCORPORATED WELL 3N-8A (1561'FSL, 279'FEL, S29, T13N, R9E) ! · KUPARUK, NORTH SLOPE, ALASKA I I Joia Reference No. 71413 Loaaecl SARBER 0ate 15-APRIL-1986 Computed By: HALSTEAD -., ''r"d' ;Ti i , ,.'- ' '.,'Ti. 'AL "' ']. }J O.UO - :?.OD 10,3. DJ ) ~. ')< _,_. ).5 2,3').3 } i 35. ,,- 1,22. ~.5 ':'., 3 ~''''~ · 0 ..,r'~ ~' ) '~ · ,' > f 3 £. ) '::> . .. 303.33 :,~;. ~'. '~ '2. ~> 13,3. ~t'; ::, ~..'" :,l ;. :~ I 3,,.3'3. ] j :) '~ )..,, ,.,, 1133.3J lO :~.)., 120:3.')3 11 :;,..;-., 1333.jG 129,}. ),, 14 O 0. ',)'} 13 1520.33 I ,5, 0.3. ,)'3 1 1730.03 1 ~ ] 0.0 J i 1 ~90. 3 ] 1~: ~). ~,3 233'3..')d i = ,) :~. ' z 210,3.23 2J')~. ~.:, clOG.OD 31 ~..2 2337.?.; "~ ~.~.".. 2400. 3,., .~ ~ 3.-,.-, -' 0 3 . .3 " '..t, ~ , · . '733.03 "_~ ' 7.: 25'3C'. ,} ~ 27~. :" 2 ~9).'3.5 '_' ~ .,, .-,.., ' ~ i ' 0 · '3 } 3 30 ]. 3 ) 3503.03 3503. 33 3703. )3 3300. 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D~T 3.z SJR?-¥: 7 A°:~ ,~6 ~];'T-~/S'-IOTq ::4ST/W ST DIST. 3.00 ri ,3.'}0 ' O.O0 O.C-'; S 0.03 f'_ 3.08 O. 51 S 3.Il E 0.55 ,}.~ ; 0.-.;4 : 0.73 0.~7 S 0.59 E 0.75 J.5~ S 0.'~2 ~ 1.06 j,S1 > 1,}7 E l, 19 3.71 S 1.il ~ 1.35 0.7~ 5 1.42 _= l. 51 0.55 $ 1.22 ~- 1.34 ~.57 ; !l.5~ ~ 12.~2 5.26 S 23.1,~ E Z'].~5 -.4fi ~ ..~I.57 =_ .-.:* !1.52 S ~.22 c 3). )~ 1:.4= 5 4~.61 ~_ 47.22 57.00 FT AZIMUTH D~3 MIN .5 ',,I - ..-1 ~ · '!T '4') 'LLiT:' "1SUqTM= V'qT£~L~ V RTI-~L 3EPTq D"?F.q 51~!.77 5167.)3 5256.73 5502.15 5,57.00 5613.'~1 572.q.63 5'57.30 53~5.~ ~767.3J 71.5' 7-'.37 /:.. 5'} '/7. ~ 'i ., ,? o 7'" 36.51 _5?. 1L 1~.l~ 7 - · 4.j 57.23 }.~T ' 3: SU~,,i':Y: 1 ~P~ ,:it < 'LLY ~'JS-tl:','J ~:j-~-S'a 3:PTH ::"T F~T )1.45 [! 130.19 93..~) E 132.20 ~39. 51 c 132 . 32 '~'3.2.5 ~ .132.34 -.'S. ~, :_ 132.28 :iS. ~7 C' 132.24 8~ ~1 ; 1~2.75 ~'3.-5 'f_ 134.93 7J.Sq ~ 13~.15 6'). ! 6 ~ 146. 50 14'4. 54 !=~.74 i )0.,]! 21~.71 )5* 7~ 2~5.01 343.~9 55 ). ) 2 516.2- 50.5S :: 172.33 2~.32 E 22!.65 17. ~4 E 255.,1 5. ~'3 i 2)0.07 7.16 W 143. ~7 '~.65 w 39).45 ).]7 ~ ~5).~,0 f77.71 335 7--. :.i,- ~15.67 ~70.2I S3'1.31 ~)3 · 73 50.32 w 00.23 70.57 ,~ 700.27 91.21 ~ 760.~ 91.59 ~4 ~2,3.~0 i01.5~ ~ ~2.~1 I12.2~ a 44~.01 121.g4 W 1031.10 57. OO ar 05 >2 RT!J q" AZ I"llJTm DE,3 MIN S 4, 37 : S 43 29 'E S 4~ 37 - S *1 4j ~ S ~1 5 L S 40 29 : S 3'~ 1.2 ; 3 35 ~6 ~ S 32 56 : S 2~ 1,O r~ S 22 29 c ' 17 3 E S 12 2 : S 1 36 ._ S 1 8 S 1 11 4 S 2 40 ,~ :~ 3 37 a S 4 22 W S 5 2., W S 5 47 W S 6 7 ;.i S 6 37 ,{ KJPAKJK .'57.00 ~T - P .J .1 <, - ::,., :' F ~ C E LOCATION ~T £7)' ;:L, 59C 29, T13N, h-lkTm/S3UT-I E~ST/WEST ji ~, J P.q q J,q 57.00 FT '1 ' ',q T2D T? K ,J P ,.~ -, ,j ~ .~, KU,DAR,jx L, -. [ I' 'j; · }: 27. ,': C ~' 7. 3," -,7 --,7 · .? C !',= 1::'51' = 't, S j,', c,~- -'., ,.. -OC&TION Z7')' F':L, ~ 'C 29, f13'~, ~9,':, ~ ' CT~:,I "JL&~ COgRDI'.'~&T-'5 ',i_i~<TM/5 ]UT q E~1ST/W:ST 759.33 S ~1,73 775, 53 ; .9~,65 3}5.$3 S 39. 137 ~.72,5~ S 101,24 ~7'). 7~ S 11,3.'~9 ))3.75 ~ 121.)~ SCHLUMBERGER D ]; RFCT ]; ONAL SURVEY COMPANY ARCO ALASKA INC NELL 3N-SA FIELD KUPARUK RIVER COUNTRY USA RUN 1 DATE LOGGED 07 - APR - 86 REFERENCE 000071413 WELL 3N-8A (1561'FSL, 279'~ S29, T13N, R9E) ORIZONTAL PROJECTION 400 REF 0000714 ! B $CI~_E = I / ZOO I N/FT -!ooo ................... : ........ '~'-' :mmo'j ........... sou.,~,-,~oo :":':':i::-:!:':':i'::'t:' :::::::::::::::::::::::::::::: '-'i- i -800 -600 -400 -200 0 200 400 NEST 600 800 EAST WELL 3N-8A (1561'FSL, 279'FEL, S29, T13N, R9E) VERTICAL PROJECTION -400 -200 0 0 200 400 600 SO0 ! 000 iZO0 13. - ! ] ] J' ' J ! ] J i'rl . . fl PROJECT~ON ON YE~TICAL PLqNE 199 - ]3. SC~ED ~N vE~TIC~::~L GEP~S , '~R,? =C~L= = 1/200 EXACT RAOIUS OF CURVATURE METHOD TIE-IN LOCATION MEASURED DEPTH TRUE VERTICAL DEPTH DISTANCE NORTH DISTANCE EAST BOTTOM HOLE COURSE LENGTH COURSE AZIMUTH LOCAT I ON MEASURED DEPTH TRUE VERTICAL DEPTH DISTANCE SOUTH DISTANCE WEST 0.0 FT 0.0 FT 0.0 FT 0.0 FT 1001.3 FT ]87.0 DEO 6890.0 FT 66S9.3 FT 993.8 FT 122.0 FT Form to be inserted in each "Active" well folder to check . - for timely compliance with our regulations. 'OPERATOR; WELL NAME AND NUMBER Reports and Materials to be received by:~ 'D,'ate Required Date Received Remarks Completion Report Well History Samples /~ Mud Log Core Chips Core Description - .. Regts r~d Survey Plat Inclination Survey Directional Survey ~~- ~'~ ~~/ ~ ~'~C ~- i Drill St. em Test Reports .. Production Test Reports ( Log Run Digitized Data/ ~O~ ~ '~ "~" - STATE OF ALASKA ALASK,. _~IL AND GAS CONSERVATION COMM~, ,ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown -- Stimulate - Plugging - Perforate~'~ Pull tubing Alter Casing _-- Other ,~ Cl::)mlP164¢..~ 2. Name of Operator ARCO A!aska, Inc. 3. Address P.0· Box 100360 Anchoraqe, AK 99,51 4. Location of well at surface 1561 'FSL, 279'FEL, Sec.29, T13N, R9E, UM 5. Datum elevation (DF or KB) RKB 67 ' 6. Unit or Property name Kuparuk River Unit 7. Well number 3N-SA At top of productive interval 802' FSL, 361 'FEL, Sec.29, At effective depth 63! 'FSL, 390'FEL, Sec.29, At total depth 567'FSL, 401 'FEL, Sec.29, T13N, R9E, UM T13N, R9E, UN T13N, R9E, UM 8. Approval number 51 9. APl number 50-- 029- 21540-01 10. Pool Kuparuk River 0i ] Pool Feet 11. Present well condition summary Total depth: measured 6890 true vertical 6659 Effective depth: measured 6767 true vertical 65'55 Casing Length Size Conductor 80' 16" Surface 3586' 9-5/8" Production 6818' 7" feet feet feet feet Plugs (measured) None Junk (measured) None Cemented Measured depth Conductor report 115'MD not avai 1 able. 1060 sx AS I I I & 3623 'MD 260 sx Class C 310 sx C1 ass C 6853 'MD True Vertical depth 115'TVD 3619'TVD 6626'TVD Perforation depth: measured 6544 ' 6.560 ' true vertical 6365 ' 6379 ' Tubing (size. grade and measured depth) 2-7/8", J-55 tbg w/tai ] ¢ 6370' Packers and SSSV (type and measured depth) HB-1 pkr (~¢ 6300' & SSSV ~' 1763' - 6547'HD - 6590'MD 6368'TVD 6404'TVD 6601' 6414' - 6607 'HD - 6419 ' TVD 12. Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Completion Well History) Daily Report of Well Operations ~ Copies of Logs and Surveys Run 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~.~ ~',~,)0j'/~,~ ,¢.,~ ~ Title Form 10-404 Rev. 12-1-85 J Associate Engineer (DAN) SW0/014 Date ,~7-1Z -~.~.~ Submit in Duplicate ARCO Oil and Gas Company Daily Well History-Final Report Instructions: PreDate and submit the "Final Report" on the ~irst Wednesday after a';owab~e has been assigned or wel! is Plugged. Abandoned. or Sold "Final Report" should be submrtted also when operations are suspended for an rider:ate or aD¢rec~able length of time On wo,koverS when an official test is not required upon completion, report completion and representative :est data ~n D~CC~S p'ov,Ced The "Final Report" form may be used for reporting the entire Accounting cost center code Alaska North Slope Borough s:a:e Alaska Field. Lease o- Ur',t Well no Kuparuk River ADL 25521 3N-8A Auth. or W.O. no. Title AFE AKll51 Completion Nordic #1 API 50-029-21540-01 Operator [ A. R. CO. W.I. ARCO Alaska, Inc. [ 56.24% Spudded or W.O. begun Date Complete 4/26/86 Date and depth as of 8:00 a.m. Old TD Released rig Complete record for each day reported IotaJ number of wells (active or reactive) on th~s~ ost center prior to plugging and 1 bandonment of this well our I Prior status if a W.O. 1230 hrs. I 4/26/86 4/27/86 0500 hrs. Classifications loll. gas, etc.) Oil Flowing 7" @ 6853' 6767' PBTD, RR 9.9 ppg NaC1/NaBr Accept rig @ 1230 hfs, 4/26/86. NU & tst BOPE. RU Schl, perf f/6560'-6590', 6544'-6547', & 6601'-6607' w/4" gun, 4 SPF, RD Schl. RU & rn 203 its, 2-7/8", 6.5~, J-55 EUE 8RD AB Mod IPC tbg w/SSSV @ 1763', PBR@ 6284', EB-1Pkr @ 6300', TT @ 6370'. Set pkr, shear out PBR, tst tbg, ann & SSSV. ND BOPE, NU & tst tree. Displ well w/diesel. Ri{ @ 0500 hfs, 4/27/86. Producing method New TD Date PB Depth 4/27/86 jK nd of rig Type completion (single. dual. etc.) Single 6767 ' PBTD Rotary Official reservmr name(s) Kuparuk Sands Potential test data Well no. Date Reservoir Producing Inte~al Oil or gas Test time ProduCt*On Oil on test Gas per day Pump size, SPM X length Choke size TP. C.P. Water % GOR Gravity AIIowaiole Effective date corrected The above is correct _ - '-' ~ For form preparation and distribution, see Procedures Manual. Section 10, Drilling, Pages 86 and 87. Drilling Supervisor STATE OF ALASKA ALASK~ JIL AND GAS CONSERVATION COMMI,.,,.,ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request.: Abandon -- Suspend -- Operation Shutdown ~ Re-enter suspended well - Alter casing _- Time extension _-- Change approved program- Plugging .~ Stimulate ~ Pull tubing- Amend order- Perforate ~. Other 2. Name of Operator ARCO Alaska, Inc 3. Address P. 0. Box 1 00360 Anchoraqe, AK 4. Location of well at surface 1561'FSL, 279'FEL, Sec.29, T13N, 5. Datum elevation (DF or KB) 67' RKB 6. Unit or Property name 99510 Kunaruk River Hnit 7. Well number R9E, UM 3N-SA At top of productive interval 8. Permit number 679'FSL, 392'FEL, Sec.29, T13N, R9E, UM (approx.) 86-68 At effective depth 9. APl number 622'FSL, 404'FEL, Sec.29, T13N, R9E, UM (approx.) 501029-21540-01 At total depth 10. Pool 558'FSL, 415'FEL, Sec.29, T13N, R9E, UM (approx.) Kuparuk River Oil Pool feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 3586' Production 6818' 6890' feet Plugs(measured) None 6660' feet 6767' 6556' Perforation depth: measured None true vertical N o n e feet Junk (measured) feet No ne Size Cemented Measured depth 16" Conductor report 115' not available. 9-5/8" 1060 sx AS I I I & 3623' 260 sx Class C 7" 310 sx Cl ass C 6853' Rue Verticaldepth 115' 3619' Tubing (size. grade and measured depth) None Packers and SSSV (type and measured depth) None 12.Attachments Description summary of proposal -- Wel I Hi story Detailed operations program - BOP sketch - 13. Estimated date for commencing operation May , 1986 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~ ~~..,, TitleAss°ciate Engineer Commission Use Only (DAH) SA/014 Date Conditions of approval Notify commission so representative may witness Z Plug integrity -- BOP Test - Location clearance Approved by Commissioner IApproval No. ,_,,- --/ by order of the commission Date---J' - --' ~ - Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Oil and Gas Company Well History- Initial Report- Daily I~lt~lctiona: Prepare and submit the "Initial Rl~orl~' on tS fi~t Wednesday after a well is spudded or wor~.over operations are star, ed. Daily wort< prior to SPudcling should be summ~l~Zld on the form giving inclusive dates only. District Alaska Field Kuparuk River Auth. or W.O. no. AFE AKll51 ICounty. pan~ or t)orougn North Slope Borough ILea~e or Unit ADL 25521 ITitle Drill Istate Alaska lw ' °8/3N-8A Doyon 9 AP1 50-029-21540 Operator ARCO Alaska, Inc. Spudded or W.O. begun Spudded 3/08~86 thru 3/10/86 3/11/86 3/12/86 3/13/86 Data and depth a~ of 8:00 a.m. 3/8/86 Complete record for each day repel'ted I ARCO W I Hour IPr, or StIIUl If I W.O. I 1300 hrs 56.24% 16" @ 115' 3637', (3522'), Tst BOPE Wt. 9.0, PV 15, YP 12, PH 8.5, WL 12.8, Sol 5 Accept rig @ 1100 hfs, 3/8/86. NU diveter sys. Spud well @ 1300 hfs, 3/8/86. Drl & surv 12¼" hole to 3637', short trip, C&C, POH. RU Schl, rn DIL/SFL/GR/SP/FDC/CNL/CAL f/3635'-surf. Rn Sonic/GR f/3590'-surf, RD loggers. RIH to 3637', circ hole, POOH. RU & rn 83 jts, 9-5/8", 36~ BTC csg w/FS @ 3623', FC @ 3533'. Cmt w/1060 sx AS III w/10~/sx Gilsonite, followed by 260 sx C1 "G" w/1.0% S-1 & .2% D-46. Displ cmt using rig pmps, bump plug. CIP @ 2355 hrs, 3/9/86. ND diverter. Perform 150 sx AS I top Job. NU & tst BOPE. 1471', .40°, S 0.09E, 1471 TVD, 5.4 VS, 3.3S, 6.1W 1943', 1.20°, S74.53E, 1942.9 TVD, 0.9 VS, 8.2S, 2.4W 2496', 2.70°, S85.49E, 2495.6 TVD, -17.9 VS, ll.5S, 16.1E 2775', 4.30°, S61.30E, 2774.1TVD, -34.7 VS, 16.3S, 32.3E 3008', 4.30°, S49.00E, 3006.4 TVD, -50.5 VS, 26.3S, 46.6E 9-5/8" @ 3622' 5331', (1694'), Drlg 8½" hole Wt. 9.0+, PV 5, YP 3, PR 9.5, WL 10.4, Sol 5 Tst BOPE. RIH to FC, tst csg to 2000 psi. DO FC & cmt to 3605', tst cs$ to 2000 psi. Drl cmt, FS + 10' new hole. Chg over to 8.6 ppg Polymer mud. Tst formation to 11.9 ppg EMW. Drl, Navi-Drl & surv 8½" hole to 5331'. 3907', 3.8°, S 3.90E, 3902.3 TVD, -94.6 VS, 90.1 S, 80.0 E 4633', 0.7°, S37.00E, 4628.02 TVD, -91.16 VS, 106.42S, 84.00E 5173', 2.4°, N57.10W, 5167.93 TVD, -87.34 VS, 110.57S, 79.34E 9-5/8" @ 3622' 6386', (1055'), POOH Wt. 9.8+, PV 13, YP 8, PH 9.5, WL 5.2, Sol 10 Navi-Drl & surv 8½" hole to 6386'. 5305', 5.20°, N68.10W, 5299.5 TVD, -78.8 VS, 110.5S, 60.2E 5555', 12.80°, N76.90W, 5546.0 TVD, -38.5 VS, 100.1S, 21.2E 5898', 12.60°, N73.90W, 5880.4 TVD, 37.6 VS, 79.5S, 52.4W 9-5/8" @ 3622' 6451', (63'), POOH Wt. 9.8+, PV 12, YP 8, PH 9.5, WL 5.2, Sol 11 Cut core #1, 6388'-6416', rec'd 26.5'. Core #2, 6416'-6451' POOH. The above is correct Signature For form preparation and distribll~ion, see Procedures Manual, Section~0, Drilling, Pages 86 and 87. Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim Initrucliona: This form is used during drilling or workover operations. If testing, COrlngr or perforating, show formation name in describing work performed Number ail drill stem tests sequentially. Attach description of ail cores. Wort( performed by Producing Section will be reported on "lnl~rim" sheets until final completion. Repot1: official or representative test on "Final" form. 1) Submit "Interim" sheets when fdled out but not less frequently than every 30 days. or (2) on Wednesday of the week in which Od string is set. Submit weekly for workovers and following setting of oil string until completion District Field Date and depth as of 8:00 a.m. l County or Parish Alaska North Slope Borough I Lease or Unit Kuparuk River ADL 25521 Complete record for each day while drilling or workoYer in progress 3/14/86 3/15/86 thru 3/17/86 3/18/86 3/19/86 IState Alaska Well no 3N-8/3N-SA 9-5/8" @ 3622' 6706', (255'), Short trip Wt. 9.9, PV 13, YP 7, PH 9.5, WL 4.8, Sol 10 Rec'd 33.5' f/core #2. Core #3, 6451'-6458', rec'd 9'. MU BHA & RIH to 6387', rm core hole to 6458', drl 8½" hole to 6706', circ f/wiper trip. 9-5/8" @ 3622' 4453' PBTD, (523'), Drlg 8½" hole Wt. 9.0, PV 8, YP 6, PH 10, WL 9.2, Sol 4 Wipe hole 5 stds to 6288', circ hole cln, POOH. RU & rn DIL/SFL/SP/CAL/GR/FDC/CNL f/6676'-3625', rn BHC/Sonic/GR f/6676'-3625', rn SEDT/GR f/6676'-3625', rn VSP f/6640'-120', RD loggers. RIH w/OEDP to 6505', pmp 95 sx C1 "G" w/2% S-1 & 2% D-46 f/6505'-6300'. Pull to 4794', pmp 180 sx C1 "G" w/2% S-1 & .2% D-46 f/4794'-4400'. Plugged & Abandoned 3N-8 03/15/86. Pull to 4073', rev circ, POOH & LD DP. Spudded well 3N-8A @ 0215 hrs, 3/16/86. RIH w/BHA, tag TOC @ 4420', drl soft cmt f/4420'-4453', WOC. Drl soft cmt f/4453'-4466', WOC. Drl firm cmt f/4466'-4496', circ hole cln, POOH. RIH w/Mach I1 BHA to 4496', Navi-Drl & surv 8½" hole to 4976. 4555', 2.20°, S32.25W, 4549.8 TVD, 101.0 VS, lll.0S, 68.4E 4778', 6.90°, S26.25W, 4772.0 TVD, 117.7 VS, 126.5S, 59.5E 4872', 9.20°, S29.25W, 4865.1TVD, 130.1VS, 138.3S, 53.3E 9-5/8" @ 3622' 5723', (747'), Drlg 8½" hole Wt. 9.2, PV 10, YP 6, PH 9.5, WL 6.8, Sol 6 Navi-Drl & surv 8½" hole to 5723'. 4966', 11.10°, S27.25W, 4957.6 TVD, 145.8 VS, 152.9S, 45.5E 5187', 16.40°, S21.25W, 5172.2 TVD, 196.4 VS, 201.6S, 25.9E 5442', 23.10°, S16.25W, 5412.2 TVD, 280.7 VS, 282.9S, 1.6W 9-5/8" @ 3622' 6890', (1167'), RU Schl Wt. 9.9+, PV 16, YP 8, PH 9.0, WL 6.2, Sol 11 Navi-Drl & surv 8½" hole to 6890', wipe hole to 4320', circ hole cln, POH. RU Schl. 5695', 29.90°, S10.25W, 5638.3 TVD, 393.0 VS, 392.6S, 29.3W 6356', 31.20°, S10.20W, 6205.7 TVD, 731.7 VS, 726.3S, 89.4W 6830', 32.50°, S9.25W, 6608.9 TVD, 980.7 VS, 972.0S, 130.8W The above is correct Signature ,~ Drilling, Pages 86 and 87 Date Drilling Superintendent ARCO Oil and Gas Company Daily Well History-Final Report Instructions: ~,eDare and sucre,! the "Final Report" on t'~e '~rs: Wednesday after a,:owaP~e "as =een assigned or ,',e :s P*ugged Abandoned or Sold "Final Report" should De suom*'.ted also when operations am susaenced for an mdefimte o' apprec~aDfe ',ength of t~me On ,~or~ove,s ,,,"eh an offroal ;est ,s not required upon ComPletion. 'eoo.,'t Completion and ,eDresentat,ve test data in Dloc~(s provided The "Final Report" form may De used for repor!,ng the ant,re operat:on ,f space .s a,a ,ae,e Accounting cost center code CJstr,ct Alaska Field tCo.¢nty or ~arlsh Lease or bmr Tit!e North Slope Borough State Alaska IWe~= ~o 3N-8/3N-8A ADL 25521 Drill API 50-029-21540 Kuparuk River Auth. or W.O. nc AFE AKll51 Doyon 9 O~erator IAR Co W I. ARCO Alaska, Inc. I 56.24% Scudded or W O. begun ~ Date Spudded J 3/8/86 Date and de,th Complete record for eact~ day re!~orted as of 8:00 a.m 3/20/86 3/21/86 Old TD Released 1100 hrs. Classifications {oil. gas. etc.1 Oil ~roducing method Flowing Iotal numOer of wells (active or ~nactwe) on th~s I DSt center prior to plugging and bandonment of this well our I Prior status if a W O I 1300 hrs. 7" @ 6853' 6890' TD, (0'), Displ'g cml 9.8 ppg NaC1 Rn DIL f/6842'-3625', FDC/CNL f/6842'-6165', CAL f/6842'-5284' RD loggers. Make cond'g rn. RU & rn 168 jt + mkr jr, 7" w/FS @ 6853', FC @ 6767'. Cml w/100 sx Cl "G" 50/50 Flyash & 210 sx C1 "G" w/3% KC1, .9% D-127, .3% D-13 & .2% D-46. Displ cml w/9.8 ppg Nad1. 7" @ 6853' 6890' TD, 6767' PBTD, RR 9.8 ppg NaC1 Fin displ'g cmt w/9.8 ppg Nad1, bump plug. 3/20/86. ND BOPE, instl & tst tbg spool. 3/20/86. dIP @ 0702 hrs, RR @ 1100 hrs, New TD I PB De,th 6890 ' TD Date [Kmd Of r~g I 3/20/86 Type comcletion (single. dual. etd ) Sin$1e Official ,eservo~r name~s~ Kuparuk Sands 6767' PBTD Rotary Potent!al test data Well no Cate Reservoir P,oducing Intervai Oil or gas Test t~me Product'on OH on test Gas per day Pump size, gPM X length Choke size T P C.P Water % GOR Gravity Allowable Effect=ye date corrected The aOove ~s correct Signature Date tTitle For form creoaration and diSt~:)ution. see Procedures Manual. Section 10, Drilling. Pages 86 and 87. Drilling Superintendent - STATE OF ALASKA - ALASKA C,._ AND GAS CONSERVATION CON,,¢IlSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS il. Drilling well Workover operation _ !12. Name of operator 7. Permit No. ARCO Alaska, Inc. 86-68 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50 029-21580-01 4. Location of Well at surface 1561' FSL, 279' FEL, 5ec.29, T13N, R9E, UN 5. Elevation in feet (indicate KB, DF, etc.) ~ 6. Lease Designation and Serial No. 67' RKB ADL 25521 ALK 2557 9. Unit or Lease Name Kuparuk River Unit 10. Well No. 3N -8A 11. Field and Pool Kuparuk River Fie]d Kuparuk River Oil Pool For the Month of. Harch ,19 86 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded we]] ~' 0215 hfs, 3/16/86. Dr]d cmt f/4820' - 4496'. Dr]d 8-1/2" hole to 6890'TD (3/18/86). Ran, cmtd, & tstd 7" csg. PBTD = 6767' Secured well & RR ~ 1100 hfs, :3/20/86. Ran logs. 3. Casing or liner run and quantities of cement, results of pressure tests 7", 26.0#/ft, J-55, BTC csg w/shoe ¢ 6853'. Cmtd w/310 sx Class G. 14. Coring resume and brief description None 15, Logs run and depth where run DIL f/6842' - 3625' FDC/CNL f/6842' - 6165' Cal f/6882' - 5284' 16. DST data, perforatingdata, showsof H2S, miscellaneousdata None 17. I herebv certifv that the foregoing is true and correct to the best of my knowledge. ,;~ /"Jm~,, /"~,,./,,, Associate Engineer SIGNED ~ I./JIU~,.,I _,Z_~'LLL~ TITLE ....... DATE NOTE Report c~this form is required for each calendar month, regardless of the status of operations, and must be f~led in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month unless otherwise directed. Form 10~,04 D~2/MR21 Submit ,n duplicate ARCO AlasKa. h Post Off,ce Box 100360 Anchorage, AlasKa 99510-0360 Telephone ~07 276 1215 RETUP.N TO: ARCO ALASKA, INC. AI~i~: Kupar~k Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 04-01-86 ~"q~kNSMII'fAL - 5613 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. OH LIS Tapes plus Listings: Schl: One of each 3N-9 03-23-86 3N-8 03-14-86 Run 3N- 8A 03-19- 86 R,.~n 3N-7 03-06-86 Run 31-12 03-22-86 Run 3I-9 03-13-86 R'~n 31-8 03-02-86 2T-17 03-08-86 R-.xn ~l 009z.0-4424.~.. ~.1 ozz5.0-66vo %1 1986. 5-7568. ~~3~ -~ _~ ~ --/~ - '~ ~5°°-°-9~2~-~d~9.3 ~I 1500 0-9204. ReceipU A-J~nowled~e-2: Sta~e 0-f ~K. March 17, 1986 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Telecopy: (907) 276-7542 Re: 3N-8A ARCO Alaska, Inc. Permit ~!o. 86-68 Sur. Loc. 1561'FSL, 279'FEL, Sec. 29, T13M, P, 9E, UM. Btmhole Loc. 525'FSL, 430'FEL, Sec. 29, T13N, R9E, IP~. Dear Mr. Kewin: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this o~fice 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office ~4 hours prior to commencing equipment installation so that the Co~ission may witness testing before drilling below the shoe of the conductor pipe. C. V. Chatterton Chairman o f Alaska Oil and Gas Conservation Co~ission BY ORDER OF THE COM~-~ISSION dl= Enclosure cc: Department of Fish & Game, Habitat Section w/o enc!. Department os Environmental Conservation w/o enc!. Mr. Doug L. Lowery - STATE OF ALASKA - ALASKA ~L AND GAS CONSERVATION CO,v~MISSlON MAR ! 7 ]9136 PERMIT TO DRILL 20 AAC 25.005 alas~a 0ii & G¢,5- Coq$ Commission DRILL ~)¢~X lb. Type of well EXPLORATORY ~- SERVICE ] STRA~IJ~J'~IO~J~IC ~-- ~ , REDRILL ] i DEVELOPMENT OIL~ SINGLE ZONE ~ DEEPEN _ t DEVELOPMENT GAS ~ MULTIPLE ZONE _ ~ la. Type of work. 2. Name of operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 1561' FSL, 279' FEL, 5ec.29, T13N, R9E, UN At top of proposed producing interval 679' FSL, 392' FEL, Sec.29, T13N, R9E, UN At total depth 525' FSL, 430' FEL, Sec.29, T13N, R9E, UN 9. Unit or lease name Kuparuk River Unit 10. Well number 3N-8A 1 1. Field and pool Kuparuk River Field Kuparuk River Oil Pool 5. Elevation in feet (indicate KB, DF etc.) ~[ 6. Lease designation and serial no. RKB 67', PAD 33' / ADL 25521 ALK 2557 12. Bond information tsee 20 AAC 25.025) Federal Insurance Company Type Statewide Surety andor number #8088-26-27 Amount SS00,000 13. Distance and direction from nearest town 15. Distance to nearest drilling or completed 30 mi. NW of Deadhorse 3N-7 well 25' ~, surface feet 16. Proposed depth (MD & TVD) 6890 'ND, 6656'TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 4500 feet. 21 14. Distance to nearest property or lease line miles 4755' ~ TD feet 17. Number of acres in lease feet 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 29 o (see 20 AAC 25.035 (c) (2) 1 8. Approximate spud date 03/1 7/86 2905 psig@_ 80°F Surface 3337 psig@ 6482 ft. TD (TVD) Proposed Casing Liner and Cementing Program SIZE Hole : Casing 8-i/2~ Weight 26.0# CASING AND LINER Grade } Coupling j Length ' J-~ ' BIC ' 6856' HF-ERW MD SETTING DEPTH TVD / MD BOTTOMTVD 34'), 6890~ I 6656' TOP i , , I / . QUANTITY OF CEMENT linclude stage data) 300 sx Class G neat 22. Describe proposed program: ARCO Alaska, Inc., proposes to sidetrack Kuparuk well 3N-8. Selected intervals will be logged. The 13-5/8", 5000 psi, RSRRA BOP stack on the 9-5/8" surface casing will be tested to 3000 psig upon installation and weekly thereafter. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calculated with an unexpanded gas bubble at the surface, including temperature effects. Casing will be tested to 3000 psi prior to releasing the drilling rig. Reserve pit fluids will be disposed of by pumping them down the 7" x 9-5/8" annulus of this well. The 7" x 9-5/8" annulus will be left with a non-freezing fluid during any interruptions in the disposal process. Upon completion of the disposal process, the 9-5/8" x 7" annulus will be sealed with a minimum of 175 sx cement followed by Arctic Pack. The well will be completed by the workover rig using 3-1/2" or 2-7/8" tubing. Selected intervals will be perforated within the Kuparuk formation and reported on subsequent reports. A subsurface safety valve will. be installed and tested upon conclusion of the job. After the workover rig has moved off location, this well will be fracture stimulated. 23. I hereby cer~at the foregoing is true and correct to the best of my knowledge . SIG Z~' TITLE Regional Drilling Engineer DATE T eh space IJWflC~r~isTn ~ - --~-- ~ / / / CONDITIONS OF APPROVAL Samples required Mud log required Directional Survey required I APl number ----YES ~'NO ]YES _~NO ~'~YES :NO I 50 d'' ') Permit number APPROVED BY Form t0-401 Approval date SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE March 17, 1986 by order of the Commission Submit in triplicate ARCO ALASKA. !NC'~ .... PAD 3N. WELL NO, 8 PROPOSED SIDETRACK KUPARUK FIELD, NORTH SLOPE,'ALASKA . EASTMAN WHIPSTOCK __ ._ :__ ._ID:._ ' __~URFACE : __ ............. 1DOO., · . 6000_ _ · VERTICAL SECTION ...................... S 7 DE(; 34 PLOTTING PLANE MIN W ......... o- -. ~ooo - - ~ooo_ - ' ~"ERTIDAE: SEC'FtON .... :-,-~ "'L __ __-._...;_'2L__ i ............... · ...... B/ KUP SNDS TVD-6482 TMD-6690 DEP-949 TD (LOG PT) - TVD-6656 TffiD--6890 DEP-1047 - __ . . _KOP ....TVD=4495 TMD=450Q DEP=98 _ ...... 5000_ --~5--5~ ....... Z.DF.~/~DO-FI' .....- .................. I[\ DOGLEG I1~2151 : . . I~---~.- ...... K-5--TVD 541Z T,D 5466 DEP 350 -' :---"1~'~ ~":- ; ....'- ~- AVERAGE ANGLE ' l l--- -'X-- '* ' 29 DEG 29 MI N ' [ - ~ ~ T/ ZONE C- TVD-6285 TMD=6464 DEP-838 J.. ~~.~':_ T./. ZONEF. A'..:.TVD-6~75 T~-656~ DEP-889 ..... ~- TARSET ONTR TVD-6429 TMD-6629 DEP-919 SCALE P~ 0 J E C.T..T. ON ............. - 200.FEET'__' -._._---: :- ' .__;:::-. ; . .................................... . ............. ,-- .- q_¢; -~CO ALASKA. I NC.-: ..... ' _ :. ~- '_-:-'"-T_._~~'T_ -:-_ ___~, _;E~;_ ..::._;;~,-'__~ __ PAD 3N. WELL NO, 8' PROPOSED SIDETRACK ' :. '/ !1 ~ ' - ? -' KUPARUK FIELD. NORTH SLOPE,--ALASKA ...... :./-~.~ ~'.-- . _ :~ " . ........ : _:::-:E::-. _.(: - - -WE-ST-EAST ' -- - -- 600 --__ 400 : .... 200__'-,_- O - ~ 200 .... - .................. 1561' F'SL. 279' FEL - t ............. SEC. 29,' T13N;'T_.RgE'---_ _ --- ................... - ....... _ _ :_:_--_-..L__ -T --~ _ _ TI£-tH POI#T _ TYD-4-495 TI"iD-4500" OEP-98 -- - SOUTH lO9 EAST 72 .- ....... _ _ --:L ......... 200 __.--_£ .......................... ' -. ...... z 400. - ......... 600__ BO0 ..... _ ._ ; .................... TVD,-6429 ............ ~ -, ......... TD LOCAT['DN, ............... ' ....... -' ...... TAROT LOCATION; .............. ......... 525' FSL-, 430'-FEL' '"' : ---6S0'--FSL.-400'-FEL ......... ~ ...... ._ _-' SEC. 29._T13#. RgE ...... ' SEC. .... 29. T13N. RgE: ..... : ........ 800 ?00 600 500 400 :300 200 I00 0 ' 100 00_ '00 _ 100 _ ~00 _ !00 _ j, I I 2000 / / / / / / 1500 .. qSO0 · 3000 I 500 I , J I I 3000. I I ' I I, I I I I ~ I I I 1 500, I I I I I I I I ,, I I I 800 700 600 500 400 300 200 1 O0 0 1 O0 < < J 7 6 > ¼ D,', AG~AM # I I. 16" - 2000 4. 1~8" - 5. 1~8" - K~ L~ 6. 1~8' - ACCLIN&IL, ATCg~ CAPACITY TEST I. O-EO4 ~ FIlL AG'C'_-_I.4J_~TCR l~..,,~g~O!R TO.-~ L_E-V~ WITH HYERAL3_lC FLUID. 2__. ~ THAT AG~_dVLLATCI~ P~'~ IS ~ PSI W~TH 3. ~ TIME, T~EN G..OSE ALL LI~TS SII,4J_TANE~Y 4. i::~E~ tIN ~ ~T, ~ AC;C::L'=7~ L~ :IS 45 ,.~F_~ C~_C:IS:IINI3 TLI~_ ~ l~gO PSI 5 4 3 2 J, 9. JO. I1. 13. 14. 13-5/8" BCP STACX T~ST FiLL ~ STACX AN:) O..KXE I~NW~Fg_D Vt!TM A.%'TIC C~E.O( TI-~aT IALL L~ ~ F'LLLY ~?T.~L~. SEAT WiTH RLt~i,~ ,JT ~ RLIN ~N L~ L~INE VALVES ~~ TO ~~ ~ TO ~ ~i ~ ~ ~~ TO 0 ~!. L:~ V~VES. ~ T~ ~iPE ~ ~ ~ V~VES ~ ~ ~ ~E L:~S. T~7 TO 2~ PS~ ~ 3~ ~I. ~ ~I. F~ SI~, ~ ~ TO ~l~l~ ~l~. CHECK I, IST FOR NEW WELL PERMITS Company Lease & Well No. ITEM APPROVE DATE (1) Fee , ~ ,_?)-/[~ 1. (2) Loc (2 thru 8) (3) Admtn?~/~._ - /(,~ 9. ~.j~.u 12) 10. · , (10 and 12) 12. (4) Casg ~.~,~. (13 thru 21) (5) BOPE ,~.~~3-/8r~~ (22 thru 26) (6) Add: ~_~_~ J- )g-F~ 2. Is well to be located tn a defined pool ..................... 3. Is well located proper distance from property line .......... 4. Is well located proper distance from other wells ............ 5. Is sufficient undedicated acreage available in this pool .... 6. Is well. to be deviated and is wellbore plat included ........ 7. Is operator the only affected party ......................... 8. Can pemntt be al)proved before ten-day wa:it .................. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. Is the permit fee attached .......................................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed .., ................................ ltl tl~o lease ~mml)or ,l)l)rol~rlate ..................................... Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all knom productive horizons ..................... Will surface casing protect fresh water zones ....................... Will ali casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-603 ............ Is adequate wellbore separation proposed ............................ l{ EM^ R K S Is a diverter system required ....................................... Are necessary diagrams of-_~-' .... -7~- BOP equipment attached ....... Does BOPE have sufficient pressure rating - Test to ~~ psig .. Does the choke manifold comply w/API RP-53 (Feb.78) .................. Is the presence of H2S gas probable ................................. Additional requirements ............................................. /~ Additional Remarks: I ' cD Geology: Eng~neering: .w _tt_ _ _ HJH~ JAL~ rev: 03/13/85 6.011 ' INIT'IA-L GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE = =. 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. ~ .... SCHLJ~BERGER .... $ LIS T4PE CERIFIC~TION LISTING RECEIVED APR 1 5 19B6 Naska 011 & Gas Cons. Commissio~ ~ .... SCHLUMBERGER .... ~ LIS T&PE VERIFICATION LISTING .VP '~lO.HO2 VERIFIC&TI]~ LISTIN] P&G6 1 :;:~ REEL HE6DER ~;:',~ ;ERVICE NAME : ESIT )ATE :75/03/22 ]~ISZN : ~E~. NAME : 149B12 ~O~TINU~TZ]N ~ ~REVIOdS REEL : 'OMMENTS :LZSR&RY T~PE ;:~ TAPE HE~DER ;EqVICE NAME :EDIT )~TE :95/03/22 ]RISIN :OOO0 FAmE N~ME :1352 ]3NTINU&TIDN m :01 ~RSVIO'JS T~PE : ]DMMENTS :LIBRARY T~PE :ILE NAME :EDI~ ~ER¥ICE N~ME : ~ERSION ~ : )ATE : ~XIMUM LENGTH : :ILE TYPE : 'REVIOdS ~ILE : .001 1024 ~, INFDRM&TIgN RECJRDS ~ INEM CONTENTS 'N : ~RSO ~L&SK~ INC ~N : 3N-SA :N : KUPARUK RIVER I~NG: 9E 'OWN: I~N ;ECT: 29 ;OJN: N.SL~PE ;TAT: AL&SKA ]T~Y: US& qNEM CONTENTS ~RES: E t~: ~'OMM'ZNTS~ .,..,. UNIT dNIT TYPE 000 OOO 000 OOO 000 000 000 000 000 TYPE 000 CATE 000 300 DO0 000 O00 DO0 300 300 000 C~TE 000 SIZE 018 005 01~ 002 004 002 O1Z 005 003 SIZE 001 C30E 065 065 065 065 065 O65 065 065 065 CODE 065 ,V~ Olg.H22 VERIFIC~TI]N LISTIN3 P&~S& 2 ~ SCqLUM5:RSmR ¢¢ JOB NU~ER AT &CC: 71352 ~UN ~2~, D&TE L]GGED: 19-M~R-86 _O~: M. O$DEN '4SING : 9.825" FYPE FLJID : LSNC) DENSITY : 9.90 LB/3 ~/ISCOSITY : ¢3.0 S ~H : 9.0 :LJIC LOSS = 5.2 C3 ~4T~IX S~,N]STONE 3622.0° BIT SIZE RM RMF RMC RM ~T : 8.5" TO $885.0 ' : 2.590 : 2. 500 : 2. 550 : 1.336 65.0 $5.0 138. OF DF DF ,VP OIO.HOZ V~I~IC&TIS~ LISTIN3 ~3~ 3 S3HLU~BEP3ER LOGS INCLUDEC WITH T~IS MA~N£TIC T~Z: INDJ'TI]~ SP~ERISALLY FDC~JSE] LO~ (CIL) DATA AVAILABcE: 555~.0' TO 3624.0' FDRMATION DENSITY COMPENSATE2 LO~ (FIN) '~ CDMP=NSATED ~EUTR3N LIS (FDN) ~T~ AVAILABLE: 5~.0' TO ~170.~' FIELD DATA ()IL) IS ~PPRIX. ~+' LESS THAN THE BLO=_LINE DEPICTS (IN CASING). ::~ ]AT~ FORMAT REC~R9 ~: ~,NTRY ~LOCKS TYPE SIZE REaR CD3E ENTRY Z 1 66 0 G 1 66 1 '~ 4 65 .lin 16 1 56 1 .'vP 010.~02 V~RI¢IC~TIDN L!$TIN$ ~&GE 4 ]AFJM SPECiFIC&TI2N BL]SKS 4N~M SERVICE SE,RVICE JNIT 19 ORDER ~ 3E~T SP NPHi DEPT SP RH]5 DEPT SP RHg5 NPHI gEPT SP RHg~ NPHI 3E~T SP NP~I DEPT SP ~H35 NPqI 6886.0000 SFLJ -12.~980 GR Z.4944 DRH3 38.9548 NCNL 5~00.0000 SFLJ -17.9951 GR 2.5295 ORqD 37.6~65 NCNL 6700.0000 SFLJ -2~.9)51 jR 2.~573 DRH] 38.7595 NCNL 6600.0000 SFLJ -27.9951 GR 2.4045 DRH2 34.1309 NCNL ~500.0000 SFLJ -33.9,]83 SR 2.5~52 0~3 30.7517 NCNL $~00.0000 S;LJ -41.~8~3 2R 2.5042 DRH3 33.3008 NCNL 66 4Pl 4Pi LOG TYPE CL4SS M30 NO. O0 O00 O0 0 0 O0 220 01 O O0 120 45 0 O O0 120 ~ 0 0 O0 013 01 0 O0 310 O1 D 0 O0 310 O1 0 0 O0 280 01 0 0 O0 350 02 O 0 O0 355 01 0 0 O0 420 O1 0 0 O0 OOO JO 0 0 O0 890 O0 3 0 O0 330 31 0 0 O0 330 30 0 O . 1ZZ. O. 1977. . 117. O. 193I. . 99. O. 2139. . 51. O. 2457. . ~5. O. ~219 ~ · 8~20 1523 1289 5875 826~ 0898 0742 6875 0273 0430 5000 3875 9023 0005 5000 1492 7148 OZlO 5000 1545 4548 0483 5000 . 127. O. 2271. ILO GR NR4T FCNL ILO GR NR~T FCYL ILD GR NR~T FCNL ILg GR NR&T FCNL NR4T FCqL ltd GR NR~T ~CNL 2.~92~ ILM 122.1523 C~LI 3.2598 RNR& 622.3125 2.5342 IL4 117.0898 C~LI 3.2209 RNR4 638.8125 2.3303 ILM 99.0273 CALI 3.2776 RNR~ 6~6.3125 5.2468 ILM 81.9323 C4LI 3.0276 RNR& 8~0.3125 5.2351 ILM 85.7148 CALI 2.81~6 RNR~ 835.8125 3.8574 ILM 127.4548 C~LI 3.0256 RNR~ 720.3125 PROSESS (2CT~L) 00'300000000000 DODO0000000000 O00000OO00OO00 O00000OO000000 OO9000OO000000 OOOOOOOO000300 O0000000000OO0 00000000000000 00000000000000 00000000000000 OOOO000OOO3000 O00000~O000000 00003000000000 00000000000000 OOOOO300000000 2.6057 8.5020 3.1780 2.5409 8.7832 3.0237 2.3518 8.7363 3.3088 4. 9890 8.7598 2.9358 5.1950 8.5379 2.5545 3.7366 9.3066 3.1526 DEPT 6300.0000 SFLJ 1.9219 ILO 1.6280 ILM 1.5954 ,VP Oi,].HO2 VSqi=ICATI]~ LISTIN3 ~36 5 )E~T ;P ~H3~_ i P..,l I ;P 4P9I )EPT SP 4P41 )EPT ~H3.~ ~PgI 3EPT qP'qI 3EPT SP RH3B NPHI DEPT SP RH3B NPHI DE;~T SP RH35 NPqI DEPT SP NPgI 3E~T SP RH3'3 NPqI -39.48~3 GR 2.3147 3Rt3 w9.4141 NCNL 5200.0003 SFLJ 45,507~ 6100.2000 S~LJ -55.~883 -993.2300 3R93 -999.2500 NCNZ 5000,0000 SPLJ -61,9583 SR -999.2500 DRH3 -999,2300 NCNL 5900,0000 -65,9727 SR -999,2500 -999,2500 NCNL 5800,0000 SFLJ -70,¢727 GR -999,2500 ORH3 -999,2500 NCN~ 5700,0000 SFL~ -60,9853 GR -999,2500 ORH3 -999,2500 NCNL 5500.0000 SFLU -66.4727 -999,2500 DR~3 -999.2500 NC~. 3500,0000 SFLJ -72.9727 GR -9'99,2500 DR93 -999,2500 NCNL 5400.0000 SFLJ -76.9727 -999.2500 DRH2 -999.2500 NCNL 5300,0000 SFLU -81,9727 5R -999.2503 DR93 -999.2500 NCNL 122.2173 Gq 0.0264 Nq~T 15~8.58T5 FCqL 2.2776 ILl 119.6323 3R 0,0532 NR~T 1772.$875 cCNL ~.~005 ILl 175.1875 GR -9~9.2500 NR~T -9t9.2500 :CNL 4,0710 136,4375 GR -9~9.2500 NR&T -9)9,2500 FC4L 3,1077 122.0898 GR -9~9,2500 NR~T -9~9.2500 FCNL 5.5528 ILD 135.6523 GR -9~9.2500 NR~T -999.2500 FCNL 2.0667 ILD 132.9023 GR -9~9.2500 NR~T -9)9.2500 FCNL 1,9981 ILO 08.9023 GR - 99,2500 NR~T -999,2500 ~C~L 2,5276 IL3 89,02T3 GR -999.2500 NR~T -999.2500 FCNL 1,8282 110,2773 -999,2500 NR~T -999,2300 FCN~ Z,~Z6~ ILO 101.3398 GR -999.2500 NR~T -999.2500 FCNL 122.2173 3.8~23 432.3936 2.0~32 11~.0523 3.6fl97 489.8~06 2,6077 175,1875 -99~.2500 -999.2500 2.9241 136.4375 -999.2300 -999.2500 2.9953 122.0898 -999.2300 -999.2500 3.6780 105.6523 -999.2500 -999.2500 1.9962 102.9323 -999.2500 -999.2500 2.0217 138.9323 -999,2500 -999.2500 2.19:17 8'9.0273 -999.2500 -999.2500 1.5157 110.2173 -999.2500 -999.2500 2.6133 101.3398 -999.2500 -999.2500 CaLl R~R~ !LM C4LI IL4 CALl RNR~ ILM C4LI IL~ RNR4 ILM CALl ILM CALl RNR4 ILM C~LI RNR~ ILM C~LI RNR& C4LI RNR~ ILM CaLI RNR~ 9.1552 3.g230 2.1252 9.2~32 3.6174 2.7327 9.1348 -99~.2500 3.0549 9.6504 -999.2500 3.1155 9.7129 -999.2500 4.0632 9.4082 -999.2500 2.0569 8.7441 -999.2500 2.0920 8.5801 -999.2500 2.2522 8.6582 -999.2500 1.6202 8.8223 -999.2500 2.6838 9.1816 -999.2500 Va ~13.~32 VE~[FiC~TI]~ LISTIN; o~'3E ~ E~I' 5200.0000 SFLJ P -3~.'~383 P~I -999.2500 NCN_ E~T 5100.0000 S~LJ P -35.9383 SR PHI -999.2500 NCNL )EPl' 5000.0003 SFLJ ~P -37.9383 .3R ~H]B -999.2500 ORH3 ~PWI -999.2500 NCN~ )E~T 4900.0000 SmLJ ~P -39.9883 GR ~H]5 -999.2500 DRff] qPHI -399.2~00 NCNL 3EPT 4~00.0000 SFLJ SP -~6.~883 SR RHD3 -~9~.2500 DRn] ~PqI -~99.2500 NCN~ DEPT 4700.0000 SFLJ SP -~$.~583 GR RH3? -999.2500 DRH3 NPHI -ggg.2500 NCNL DEPT ~$00.0000 SFLJ SP -47.4553 SR RH3~ -999.2500 ORH3 NPMI -999.2500 NCNL DEPT 4500.0000 SFLJ SP -70.4727 GR ~H3~ -999.2500 DRM3 NPAI -999.2500 NCNL 3EPT ~00.0000 SFL3 SP -53.9883 GR RH35 -999.2500 9R~3 NPHI -999.2500 NCNL 3EPT ~300.0000 SFLJ SP -59.4B~3 GR ~H33 -999.2500 ORM3 ~P~I -999.2500 NCNL gE~T 4.200.0000 SFLJ SP -64.9727 GR RH3B -999.2500 ORq3 NPHI -999.2500 NCNL 2.)202 139.B33B 3R -399.2500 N~T -999.2500 ~CNL 3.0100 iLD 1Z0.~395 S~ -939.2500 NR&T -999.2500 FCNL 3.9143 ILl 102.2148 GR -9}9.2500 NR~T -999.2500 ;CNL 3.~292 94.5523 GR -999.2500 NRAT -9)9.2500 FCNL 3.2~05 95.3398 GR -999.2500 NR&T -999.2500 ~CNL 3.1135 ILO 102.0273 GR -999.2500 NR~T -999.2500 FCNL 2.2385 ILD 100.~548 GR -999.2500 NR&T -9~9.2500 FCNL 2.2893 ILD 51.7773 GR -999.2500 NR~T -999.2500 FCNL 2.3499 ILD ~8.9023 GR -999.2500 NR&T -9~9.2500 FCNL 2.7307 ILD 90.71~8 GR -999.2500 NR~T -~99.2500 FCNL 2.6799 95.0898 GR -999.2500 NR~T -999.2500 ~CNL 2.377Z -999.2500 -9)9.2500 -999.2500 2.8147 -9~9.2~00 -9~.2500 3.537~ -999.2500 -99'3.2500 3.53T~ -9~9.2500 -999.2500 -999.2500 3.1526 -999.2500 -'999.2500 -999.2500 3.0120 -999.2500 -999.2500 -999.2500 2.1526 -999.2500 -9R9.2500 -999.2500 2.1838 -999.2500 -999.2500 -999.2500 2.2520 -999.2500 -999.2500 -999.2500 2.6721 -999.2500 -999.2500 -999.2500 2.7092 -99~.2500 -9~9.2500 -999.2500 IL~ CALl IL~ C&LZ RNR~ ILM CALI RNR~ CALl RNR4 ILM CALl RNR~ ILM CALI RNR& ILM CALI RNR& ILM CALI RNRA ILM C~LI RNR~ ILM CALI RNR~ ILM C~LI RNR4 2.5413 -9)9.2530 2.9909 -~99.2500 -999.2500 3.5624 -999.2500 -999.2500 3.5702 -999.2500 -999.2500 3.1917 -999.2500 -999.2500 3.0002 -999.2500 -939. 2500 2.1667 -999.2500 -999.2500 2.150~ -999.2500 -999.2500 2.2620 -999,2500 -999.2550 2.6311 -999.2500 -999.2500 2.66~3 -999.2500 -9R9.2500 .VO 010.~02 VERI=IC~TI,]'~ LISTIN5 PAGE ? )EPT 4100.0000 SF~-J ~P -o%.¥727 3[< ~H35 -999.2500 DR'i] qPqI -999.2500 NC'~ ]EmT 4000.000J S~L3 SP -5'9.4727 GR ~H]~ -999,2500 DRH3 qPql -999.2~20 NCNL DE~T 3'900.0000 S~LJ SP -71,G727 GR qH]~ -999.2500 DRH] ~PHI -999.2500 NCNL ]E~T 3~00,0000 SmLJ SD -69.9727 qM]5 -9~9,2500 NP~I -999,2500 NCN. JEPT 3700,0000 SP -70,9727 qHJ5 -999,2500 DRH] ~P~I -~99.2500 NCNL DE~T 3500,0000 SFLJ SP -67,9727 3R RH]5 -999.2500 ORq3 NPqI -999,2500 NCNL DE~T 3500.0000 SFLJ SP -70,~727 2H]~ -999,2500 DRH3 NPHI -999.2500 NCNL 9EmT 3G22,0000 SFLJ SP -70,9?2? GR RH2~ -~99,2500 DRH3 NPHI -999,2500 NCN. ~* FILE T~ILER ~:~ FIL~ NAME :EDIT ,001 SERVICE NAME : VERSI'2N ~ : DATE : MAXIMUM LENGTH : 1024 ~ILE TYPE : WEXT mILE N~ME : 2,5127 ~2,0273 -999.2500 NR&T -9~9,2500 FCNL 2.~45 ILl 105.0273 GR -9~9.2500 NR~T -999,2500 FCNL ~.5~52 ILD 57,9023 -9)9,2500 NRAT -999,2500 FC~L 2,0~32 ILD ~2,1523 GR -999,2500 NRAT -9~9,2590 FCNL 2.4065 ILD 73.7773 SR -999.2500 NRAT -999.2500 FCNL 2000.6875 ~9.7930 GR -9'~9.2500 NR~T -9~9.2500 FCNL 20J0,6875 ILD 53,57~2 GR -999,2500 NR&T -9~9,2500 FCNc 2000,6~75 ILl 51,4180 GR -999.2500 NR~T -999,2500 FCNL 2.8)28 -'9¢9.2500 -9~.2500 -999.2500 2.95'90 -999.2500 -999.2500 -99'9.2500 3,5547 -))9,2500 -999,2500 -999.2500 2.5%52 -999.2500 -99~.2500 -999.2500 2.?034 -999.2500 -999.2500 -999.2500 19.7236 -999.2500 -999.2500 -999.2500 13,6551 -999,2500 -999,2500 -999,2500 20.3~86 -999.2500 -999.2500 -999.2500 ILM CALl ILM CALl RN~ IL'~ C&LI RNR~ ILM C~LI RNa4 ILM CALl RNR~ ILM CALi RNR~ ILM CALI RNRA ILM CALl RN2~ 2.8127 -~'~9.2500 2.5909 -~99.2500 -999.2500 3.4~95 -999.2500 -999.2500 2.3~01 -999.2500 -999.1500 2.5198 -999.2500 -999.2500 2000,6~T5 -999.2500 -999,2500 2000.6875 -999.2500 -999.2500 2000.6875 -999.2500 -999.2500 Vp Ol~].'~J2 VEe.rFIC~TI']N LISTIN] PA'SE ~ ~;',.' ~EEL T~ILE~ ;',~ ~E~ViCE N~E :E3IT ~TE 3RI~IN : :ONTINLJ&TION m :01 ~EXT REEL NAME : :OqMENTS : LISR&RY TAPE
