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Home My WebLink About186-017CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:NSK DHD Field Supervisor To:Regg, James B (OGC); Brooks, Phoebe L (OGC); DOA AOGCC Prudhoe Bay; Wallace, Chris D (OGC) Cc:Well Integrity Specialist CPF1 & CPF3 Subject:3N-03,04,05 and 10 10-426 forms from 8-17-24 Date:Sunday, August 18, 2024 11:54:55 AM Attachments:image001.png MIT KRU 3N-03,04,05 and 10 SI TESTS 08-17-24.xlsx Please see the attached 10-426 form for the shut in MITIA’s from 3N-03,04,05 and 10 that were conducted on 8-17-24. If you have any questions please let me know. Bruce Richwine/Matt Miller DHD Field Supervisor KOC F-wing 2-14 (907) 659-7022 Office (907) 943-0167 Cell N2238@COP.com .581 37' Submit to: OOPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1860160 Type Inj N Tubing 1050 1250 1275 1275 Type Test P Packer TVD 6146 BBL Pump 2.0 IA 400 2100 2010 1990 Interval 4 Test psi 1537 BBL Return 2.0 OA 100 110 105 105 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1860170 Type Inj N Tubing 2000 2010 2010 2010 Type Test P Packer TVD 6157 BBL Pump 2.0 IA 120 2700 2610 2600 Interval 4 Test psi 1539 BBL Return 2.0 OA 100 100 100 100 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1860260 Type Inj N Tubing 2060 2080 2080 2080 Type Test P Packer TVD 6041 BBL Pump 2.0 IA 320 2830 2770 2760 Interval 4 Test psi 1510 BBL Return 2.0 OA 60 60 60 60 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD 1860720 Type Inj N Tubing 1860 1875 1875 1875 Type Test P Packer TVD 6303 BBL Pump 3.2 IA 210 2700 2580 2550 Interval 4 Test psi 1576 BBL Return 3.2 OA 35 45 40 40 Result P Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type Inj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result TYPE INJ Codes TYPE TEST Codes INTERVAL Codes Result Codes W = Water P = Pressure Test I = Initial Test P = Pass G = Gas O = Other (describe in Notes) 4 = Four Year Cycle F = Fail S = Slurry V = Required by Variance I = Inconclusive I = Industrial Wastewater O = Other (describe in notes) N = Not Injecting ConocoPhillips Alaska Inc, Kuparuk / KRU / 3N Pad Arend / Richwine 08/17/24 Notes: Notes: 3N-03 3N-04 3N-10 Notes: 3N-05 Notes: Notes: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MMechanical Integrity Test jim.regg@alaska.gov;AOGCC.Inspectors@alaska.gov;phoebe.brooks@alaska.gov chris.wallace@alaska.gov Form 10-426 (Revised 01/2017)2024-0817_MIT_KRU_3N-pad_4wells 9 999 9 9 9 -5HJJ • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO Jim Regg '� DATE: Monday,August 08,2016 P.I.Supervisor keel? S('I,b SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3N-04 FROM: Bob Noble KUPARUK RIV UNIT 3N-04 Petroleum Inspector Src: Inspector Reviewed B P.I.Supry =�" NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3N-04 API Well Number 50-029-21529-00-00 Inspector Name: Bob Noble Permit Number: 186-017-0 Inspection Date: 8/1/2016 Insp Num: mitRCN160801172024 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3N-04 Type Inj N. TVD 6157 - Tubing 1760 1760. 1760 - 1760 PTD 1860170 ' Type Test SPT Test psi 1539 ' IA 420 2510 , 2420 . 2400 - Interval 4YRTST P/F P V OA 10 10 - 10 10 - Notes: SCANNED MAY 14 2017 Monday,August 08,2016 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday,January 07,2015 TO: Jim Regg 7e�, ('ZZI IS P.I.Supervisor l ` SUBJECT: Mechanical Integrity Tests CONOCOPHILL1PS ALASKA INC 3N-04 FROM: Matt Herrera KUPARUK RIV UNIT 3N-04 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name KUPARUK RIV UNIT 3N-04 API Well Number 50-029-21529-00-00 Inspector Name: Matt Herrera Permit Number: 186-017-0 Inspection Date: 12/13/2014 Insp Num: mitMFH141220141729 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well 3N-04 ;Type Inj W TVD 1 6157 i Tubing 2890 2890 • 2890 I 2890 PTD 1860170 = 'Type Test SPT'Test psi 1539— IA 665 I 2022 1967 1954 - — Interval INITAL IP/F P ✓ OA 310 j 375 375 - 375 Notes: 1 BBL Diesel to pressure up IA SCANNED Wednesday,January 07,2015 Page 1 of 1 HE STATE I:7i1 and Ca \a la�.b.�.A� / \_S. is} 333 west Seventh Avenue _ GOVERNOR SEAN PARNELI. Anchorage, Alaska 99501-3572 o Main 907.279 1433 r Osx. 907.2'( % NHED AUG 061014 Ian Toomey Workover Engineer ConocoPhillips Alaska, Inc. �' P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3N-04 Sundry Number: 314-094 Dear Mr. Toomey: 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, Cathy 6. Foerster Chair DATED this day of February, 2014. Encl. STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 20 2Q14 APPLICATION FOR SUNDRY APPROVALS p•Tr Z4(11 ¢ 20 AAC 25.280 AOGCO 1.Type of Request: Abandon r Rug for Redrill r Ferforate New Pool r Repair w ell p-• Change Approved Program [— Suspend r Rug Perforations r Ferforate r Pull Tubing r . Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r Other: I- 2. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory E Development r 186-017 ' 3.Address: � 6.API Number: Vs?) Stratigraphic r Service OT...,. • P.O. Box 100360,Anchorage,Alaska 99510 50-029-21529-00-ab 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 P" • 1 3N-04 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): 7914 6572 7460' none Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 115' 115' SURFACE 4077 9.625 4114' 3586' PRODUCTION 7815 7 7850' 6516' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7574-7584,7612-7622,7625-7632,7639-7645 6274-6282,6307-6316,6318-6324,6330-6336 2.875 J-55 7510 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft) PACKER-BROWN HB-1 PACKER MD=7439 TVD=6157 - SSSV-BAKER FVL SSSV MD=1795 TVD=1765 I 12.Attachments: Description Summary of Proposal 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: 4/7/2014 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r • GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ian Toomey @ 263-4773 Email: Ian.A.Toomev@conocophillips.com Printed Name Ian Toomey Title: Workover Engineer Signature —--' Jam` ^ --�� Phone:263-4773 Date 2- 4y -/'1 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ?,\ik_(542k Plug Integrity r BOP Test PV Mechanical Integrity Test rl Location Clearance IT RBDMS*; MAY 11 2014 Other: 00 p t o 5 fa 35-00 p 5 I ,Sf atr ivy thz`s5cd /1/11 T - /A 1---c-G /1-r-r . Spacing Exception Required? Yes 0 No [i/ Subsequent Form Required: IO _40 4 I / APPROVED BY Approved by: ' T' COMMISSIONER THE COMMISSION Date: c.2 - -/ —/V / , Approved app t os y�ld,tor .Conths trom the date of approval. Form 10-403(Revised 10/2012) U I INA ?ia 0/1 A()1I' Submit Form and Attachments in Duplicate VL, 2/Z//11. RECEIVED ConocoPhillips FEB 2 0 2014 Alaska P.O. BOX 100360 AOGCC ANCHORAGE,ALASKA 99510-0360 February 11,2014 Commissioner State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby applies for an Application for Sundry Approval to workover the Kuparuk Well 3N-04(PTD# 186-017). Well 3N-04 was drilled and completed in 1986 as a pre-produced A-sand injector. The well was initially produced for 18 months and was then converted to injection service. In 1988 the C-sand was perforated and continued to inject at relatively stable rates until 1996 when injection rates began declining. An attempt to restore injectivity with a high pressure breakdown was attempted in early 2000 but the results were short lived. The well has also undergone multiple pit dewatering stimulations without lasting injection rate impacts. In the last two years the well has been shut-in(SI),the pressure in the area has fallen outside the historic norms indicating the offset producers are depleting the area. Well 3N-04 was formerly waivered for a slow leak from the tubing to the inner annulus (IA). The well now has leaks identified by leak detection log in the vicinity of the packer and the polished bore receptacle. One leak connects the area below the packer to the tubing above the nipple profile. The other leak is in the polished bore receptacle and allows the IA above the packer and the tubing to be in communication with each other. There is currently no evidence of any integrity issues with the production casing and the current problems will be mitigated by replacing tubing and stacking a packer. The well is currently SI with a wireline retrievable plug(WRP) set just below the packer. The proposed workover will pull the 2-7/8" tubing and re-complete the well with a new 2-7/8" stack packer completion (top of packer set at 7385' RKB). This Sundry is intended to document the proposed work on the injection well,as well as request approval to workover the well. If you have any questions or require any further information,please contact me at 263-4773. Sincerely, Ian Toomey RWO Engineer CPAI Drilling and Wells 3N-04 Kuparuk Injector Rig Workover (PTD #: 186-017) Current Status 3N-04 is currently shut-in with a wireline retrievable plug(WRP)set just below the packer. The MIT-T fails but no pressure is seen on the IA. The leak detect identified a leak in the tubing below the packer and above the WRP. The MIT-IA fails and the tubing tracks the IA. The leak detect log identified a possible leak in the polish bore receptacle (PBR). Scope of Work The proposed workover will pull the 2-7/8" tubing and re-complete the well with a new 2-7/8" stack packer completion (top of packer set at 7385' RKB). This Sundry is intended to document the proposed work on the injection well,as well as request approval to workover the well. General Well info MPSP: 1775 psi using max stabilized SITP on 5/30/12 prior to a plug being set. ✓ Reservoir pressure/TVD: 3178 psi at 7630' MD(6322' TVD)SBHP taken on 10/13/13 i✓2p5P�� 24<5 fi5/ Wellhead type/pressure rating: FMC Gen III, 11"5K btm x 7-1/16"5K top flange BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT Results: MIT-T: failed December 5,2013 MIT-IA: failed on December 5,2013 MIT-OA: Passed on February 2,2014 Well Type: Injector Estimated Start Date: March 18,2014 Production Engineer: Toon Changludgdee/Suzanne Short Workover Engineer: Ian Toomey(263 -4773/Ian.A.Toomey@ conocophillips.com) Pre-Rig Work Request 1. Lock out SCSSSV. 2. Pull DV from GLM#1 and leave open. 3. Set BPV. Proposed Procedure 1. MIRU 2. Pull BPV. Load well with 10.0 ppg brine. Ensure well is dead. 3. Set BPV and blanking plug or two-way check. ND tree. 4. NU BOPE. Pressure test BOPE including annular. Pull blanking plug and BPV or two-way check. 5. MU landing joint,BOLDS,POOH laying down tubing,and spooling control line. a. If tubing will not pull free,RU E-line and cut tubing in the middle of the first full joint above the PBR. b. If tubing is cut,RIH with overshot and fish seal assembly. 6. MU FH packer assembly and single in on 2-7/8"tubing to just above PBR. (Top of packer set at 7385' RKB) 7. Spot corrosion inhibited brine below the FH packer. 8. Sting into the PBR until fully located, space out 1 ft. from fully located,drop ball&rod, set the FH packer. PT the IA. Shear the PBR. 9. Space out with pups,MU hanger,load the well with corrosion inhibited brine,land the hanger,and RILDS. —Proposed Procedure Continued 10. PT the tubing and IA. Shear the SOV. 11. Install the BPV or two-way check. Pressure up on the IA to 1000 psi to test the BPV or two-way check from below. Bleed IA to 0 psi. 12. ND BOPE. NU tree. If BPV is installed,pull BPV and install tree test plug. Test tree. 13. Pull test plug/two-way check. Freeze protect well with diesel. Set BPV. 14. RDMO. Post-Rig Work request: 1. Reset well house(s)and flowlines of adjacent wells. 2. Pull BPV. 3. RU Slickline: a. Pull ball&rod b. Pull SOV and run DV c. Pull RHC plug body d. Pull WRP e. RD slickline 4. Return well over to operations. r INJ 3N-04 # • �, C� �� illips Well Attributes Max Angle&MD TD Alaska InF Wellbore API/LAM Field Name Wellbore StatusI I°) MD(ftKB) Act Btm(ftKB) 500292152900 KUPARUK RIVER UNIT INJ jnc 41.75 2,700.00 7,914.0 --- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 3N-04,12/9/20139'.23:00 AM SSSV:TRDP Last WO: 38.59 2/15/1986 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:RKB 7,649.0 11/15/2011 Rev Reason:RESET WRP lehall( 12/9/2013 asi� n rings MANGER;32.5 II��711 Casing Description OD(in) ID(in) Top(RKB) Set Depth(BOB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 16 15.062 38.0 115.0 115.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(RKB) Set Depth(BOB) Set Depth(TVD)... Wt/Len)L..Grade Top Thread SURFACE 95/8 8.921 37.0 4,114.0 3,585.9 36.00 J-55 BTC • Casing Description OD(in) 'ID(in) Top((MB) Set Depth(RKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 35.0 7,850.0 6,515.9 26.00 J-55 BTC Tubing Strings iITubing Description String Ma...IDII (in) Top(ftKB) Set Depth(R..Set Depth(ND)(...Wt(Iblft) Grade Top Connection 4�p°'TUBING 27/8 2.441 32.5 7,509.9 6,217.9 6.50 J-55 EUE8rdABMOD Completion Details • ,J` Nominal ID Top(ftKB) Top(TVD)((tKB) Top Incl(°) Item Des Com (in) CONDUCTOR:38.0-115.0 a 32.5 32.5- 0.07 HANGER FMC TUBING HANGER 2.875 1,795.2 1,764.9 25.05 SAFETY VLV BAKER FVL SAFETY VALVE ' 2.310 7,423.6 6,143.7 31.53.PBR BROWN PBR 2.312 SAFETY VLV;1.795.2 i�. 7,439.3 6,157.1 31.23 PACKER BROWN HB-1 PACKER 2.340 7,476.9 6,189.4 30.52 NIPPLE CAMCO D NIPPLE NO GO 2.250 7,509.2 6,217.3 29.98 SOS CAMCO PE-500 SHEAR OUT SUB 2.310 ! Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(NDI Top Incl Top IRKS) (ftKB) (°I Des Com Run Date ID(in) 7,460.0 6,174.8 30 04 PLUG 2.25"WRP 12/4/2013 0.000 SURFACE;37.0-4.114.0-+ Perforations&Slots Shot Den: Top(TVD) Btm(NDI (shotnR lop(ftKB) Bier(RKB) (RKB) (ftKB) Zone Dale t) Type Com GAS LIFT;7,384.5 7,574.0 7,584.0 6,273.6 6,282.3 C-4,UNIT B, 9/24/1988 4.0 APERF 0 deg.phasE;2 1/8" 3N-04 EnerJet 7,612.0 7,615.0 6,306.8 6,309.4 A-3,3N-04 9/24/1988 4.0 APERF 0 deg.phasE;2 1/8' - --. EnerJet PBR;7.42S6 7,615.0 7,618.0 6,309.4 6,312.0 A-3,3N-04 9/24/1988 4.0 APERF 0 deg.phasE;2 1/8" EnerJet PACKER;7439.47,615.0 7,616.0 6,309.4 6,310.3 A-3,3N-04 9/24/1988 5.0 APERF O deg.phasE;2 1/8" o• EnerJet 7,617.0 7,618.0 6,311.1 6,312.0 A-3,3N-04 9/24/1988 ' 5.0 APERF 0 deg.phasE;2 1/8" EnerJet PLUG;7460.0 7,618.0 7,622.0 6,312.0 6,315.5 A-3,3N-04 9/24/1988 4.0 APERF 0 deg.phasE;2 1/8" EnerJet 7,625.0 7,632.0 6,318.2 6,324.3 A-2,3N-04 4/20/1986 4.0 IPERF 90 deg ph;4"HJ II Csg Gun NIPPLE.7,4769 7,639.0 7,645.0 6,330.4 6,335.7 A-1,3N-04 4/20/1986 4.0 IPERF 90 deg ph;4"HI II Csg Gun Mandrel Inserts St aft C No Top(TVD) Valve Latch Port Size TRO Run mo Top(RKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date SOS:7,509.2 1 7,384.5 6,110.5 MMH FMHO 1 GAS LIFT DMY RK 0.000 0.0 4/27/1992 Notes:General&Safety End Date Annotation 11/30/2010 NOTE:View Schematic w/Alaska Schematic9.0 APERF;7.574.0-7584 0 - APERF;7,512.0-7,615.0 -- APERF;7.615,0-7.616.0-y APERF;7.615.0.7.616.0 APERF;7.617.0-7.618.0-tat APERF;7,61B.0-7,6 .0-t- - 1 - IPERF;7,625.0.7,632.0 - 1 r IPERF;7,639.0.7,645.0 - PRODUCTION;35.0.7,850.0 . • •WELL LOG TRANSMITTAL DATA LOGGED /23C/2013 M K BENDER To: Alaska Oil and Gas Conservation Comm. Y Attn.: Makana Bender October 14, 2013 333 West 7th Avenue, Suite 100 - 0 t7 Anchorage, Alaska 99501 Z3 3 sCANNE4 DEC 1 0 2093 RE: Plug Setting Record, Bottom Hole Pressure Survey: 3N-04 Run Date: 10/13/2013 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of Matthew Cook,Halliburton Wireline &Perforating, 6900 Arctic Blvd.,Anchorage,AK 99518 matthew.cook @halliburton.corn 3N-04 Digital Data in LAS format, Digital Log Image file 50-029-21529-00 1 CD Rom Bottom Hole Pressure Survey Log 50-029-21529-00 1 Color Log PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Matthew Cook 6900 Arctic Blvd. Anchorage,Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 matthew.cook @halliburton.corn Date: Signed: • • Pct i'6_ Regg, James B (DOA) Kic,t - --04 From: Regg, James B (DOA) �`,� �� /1( ( v Sent: Wednesday, January 11, 2012 12:44 PM `' To: NSK Problem Well Supv Cc: DOA AOGCC Prudhoe Bay Subject: RE: 3N -04 (PTD 186 -017 AIO 2B.029) questioning shut -in MITIA requirements Attachments: Industry Guidance 10- 02.pdf You should avoid MITs on shut in wells. Refer to last paragraph of AOGCC's Industry Guidance Bulletin 10 -02. We have allowed MITs on some wells at operator request to address unique circumstances — e.g., seasonal /intermittent injectors. In this particular case, the well has an Administrative Approval requiring submittal of a monthly TIO plot —that information gives the what is needed about well integrity for the shut in well. Pressure test on injector should be performed when well is operating under stable injection conditions. CPAI is always p g s free to test as you see fit, but injection Y AOGCC witnessed MIT will be when well recommences injection. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 FEB # Anchorage, AK 99501 907 - 793 -1236 From: NSK Problem Well Supv [ mailto :n1617(aconocophillips.com] Sent: Wednesday, January 11, 2012 12:13 PM To: Regg, James B (DOA) Cc: DOA AOG • dhoe Ba Subject: N -04 (PTD 1. -1 17 AIO 2B.029) questioning shut -in MITIA requirements Jim, Kuparuk Injector 3N -04 (PTD 186 -017 A10.2B.029) is due for a 2 year witnessed MITIA. It has been shut in since May 2011 and there are no plans to bring it online in the near future. I had planned to get a shut -in MITIA done tomorrow to maintain its compliance. We have done other shut in MITs so I thought this was standard practice. But while talking with Lou today, he questioned whether we should be doing this MITIA now with the well shut in. If it is up to us, we would prefer to perform the MIT now. In addition, Lou also brought up the question of a need for an MITIA when it comes back on -line. Since it was not shut in for mechanical reasons, I would think that as long as we stay in compliance and get the MIT now, we would be fine. Is this correct? Your guidance is appreciated Brent Rogers / Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907) 659 -7224 Pager (907) 659 -7000 pgr 909 1 Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, December 14, 2010 8:42 AM To: 'NSK Problem Well Supv' Subject: RE: 3N -04 (PTD# 186 -017 AA A102B.0291 approval to restart injection Hi Kelly, It appears that the integrity demonstrations are sufficient to bring the well back on as desired. Sometime in the first 2 weeks of operation plans should be made to test the OA switch and SSV. Keep me advised of how the well Thanks in advance, NED t3v (c C Q�@ Tom Maunder, PE �. AOGCC From: NSK Problem Well Supv [ mailto :n1617 @conocophillips.com] Sent: Tuesday, December 14, 2010 7:48 AM To: Maunder, Thomas E (DOA) Subject: RE: 3N -04 (PTD# 186 -017 AA AIO213.029) request approval to restart injection Hi Tom, Attached are the 3 MIT reports. Unfortunately I made an error: the combo from August 23, 2010 which I referenced was actually an MITIA. So we have 3 MITIA's, instead of the 2 MITIA's and 1 CMIT that I initially referenced. And to your question, no we haven't tested the OA pressure switch and SSV since the well has been shut in since May. Thanks Kelly From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, December 13, 2010 9:33 AM To: NSK Problem Well Supv Cc: CPF3 Prod Engrs; Kovar, Mark Subject: RE: 3N -04 (PTD# 186 -017 AA AIO2B.029) request approval to restart injection Kelly, Do can you send copies of the MITs you refer to? I don' have any email other than the original notice message from May 14. Also, has the OA pressure switch and SSV been tested? Thanks in advance, Tom Maunder, PE AOGCC From: NSK Problem Well Supv [ mailto :n1617 @conocophillips.com] Sent: Saturday, December 11, 2010 10:28 AM To: Maunder, Thomas E (DOA) Cc: CPF3 Prod Engrs; Kovar, Mark; NSK Problem Well Supv Subject: 3N -04 (PTD# 186 -017 AA AIO213.029) request approval to restart injection Tom, CPAI requests permission to restart injection into Kuparuk injector 3N -04 (PTD # 186 -017 AA A10213.029). The well has been shut in since May 12, 2010 after it failed an MITIA. On August 15 and August 16, 2010, passing 12/15/2010 • • Page 2 of 2 MITIA's to 3000 psi were performed. A CMIT TxIA to 3000 psi passed on August 23, 2010. A TecWell LDL was run on August 22, 2010 and could not identify any leak point. CPAI requests permission to restart injection so that further diagnostics can be performed. Please call if you have any questions Kelly Kelly Lyons for Martin Walters /Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone: 907 - 659 -7224 Pager: 907 - 659 -7000 pgr 909 12/15/2010 r • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: iim.regg dolaska.gov; doa.aogcc.prudhoe.bay(d alaska.gov; phoebe.brooks(cDalaska.gov; tom.maundera- alaska.gov OPERATOR: ConocoPhillips Alaska, Inc FIELD / UNIT / PAD: KRU / Kuparuk / 3N DATE: 08/23/10 OPERATOR REP: Phillips AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3N -04 I Type In'. I N TVD 6,158' Tubingl 1300 1300 1300 1300 1 Interval O P.T.D. 1860170 I Type test I P d Test psi 1539.5 Casing 1,500 3,000 2,995 2,995 P/F P Notes: Diagnostic OAJ 0 01 0 0 Well I Type In'. I I TVD I Tubing Interval P.T.D. I Type test I I Test psi Casing P/F Notes: OA Well I Type In'. TVD Tubing Interval P.T.D. I Type test I Test psi I Casing P/F Notes: OA Well I Type In'. I TVD Tubing Interval P.T.D. I Type test I Test psi Casing P/F Notes: OA Well T pe In'. TVD Tubing Interval P.T.D. I Type test I Test psi I Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test O = Other (describe in notes) Form 10 -426 (Revised 06/2010) MIT KRU 3N -04 8 -23 -10 (2).xls 0 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: iim.regp @alaska.gov; doa. aogcc.prudhoe.bav(a)alaska.gov: phoebe.brooks(a)alaska.gov; tom.maunder(a )alaska.gov OPERATOR: ConocoPhillips Alaska, Inc FIELD 1 UNIT I PAD: KRU / Kuparuk / 3N DATE: 08/16/10 OPERATOR REP: Cleland (HES) AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3N -04 I Type In'. I N TVD 1 6,158' Tubing 1250 1250 1250 1250 1 Interval O P.T.D. 1860170 I Type test I P Testpsil 1539.5 Casingl 1,500 3,0001 2,900 2,875 P/F P Notes: Diagnostic OA 0 01 0 0 1 Well I Type In'. I I TVD I Tubing Interval P.T.D.1 I Type test I Test psi I Casing P/F Notes: OA Well I Type Inj.1 I TVD I Tubing Interval P.T.D.1 I Type test I I Testpsil Casing P/F Notes: OA Well Tip e In'. I TVD I Tubing Interval P.T.D. I Type testl I Test psi I Casing P/F Notes: OA Welil I Type In'. I TVD Tubing Interval P.T.D.1 I Type testi Test si Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test O = Other (describe in notes) Form 10 -426 (Revised 06/2010) MIT KRU 3N -04 8 -16 -10 (2).xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submitto: doa. aogcc.prudhoe. bay a(_alaska.gov; phoebe.brooks(a)alaska.gov; tom.maunderCa)alaska.gov OPERATOR: ConocoPhillips Alaska, Inc FIELD I UNIT / PAD: KRU / Kuparuk / 3N DATE: 08/15/10 OPERATOR REP: Cleland (HES) AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3N -04 I Type In'. I N TVD 1 6,158' Tubing 1200 1200 1200 1200 1 1 Interval O P.T.D. 1860170 I Type test I P Test psi 1539.5 Casing 1,450 3,000 2,995 2,995 1 1 P/F P Notes: Diagnostic OA 0 0 0 0 Well I Type In'. I I TVD I Tubing Interval P.T.D. I Type test I I Test psi I Casing P/F Notes: OA Well I Type In'. TVD Tubing I I Interval P.T.D. I Type test I Test psi Casing P/F Notes: OA Well I Type In'. I TVD Tubing Interval P.T.D. I Type test I Test psi Casing P/F Notes: OA Well T pe In'. I TVD I Tubing Interval P.T.D. I Type test I Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test O = Other (describe in notes) Form 10 -426 (Revised 06/2010) MIT KRU 3N -04 8 -15 -10 (2).xls _> ,~ PeoACrive D'IAynosric SERVIar, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and /or Tubing Inspection(Caliper/ MTTj The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 1) Leak Detection - WLD 22-Aug-10 2) • ~L~ ~Vi.7 r~` 3N-04 Signed Print Name: EDE 50-029-21529-00 ~ov~9 a _ ~,,~ , _ ~_3 ~~;~. ,~~~,. Date : - -- :~; PROACTIVE DIAGNOSTIC SERVES, INC., 130 W. INTERNATIONACAIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (807)245-8951 Fax: (907`245-88952 E-MAIL : ods~rc3~or~a?~rrear?s~r•~loc~.::os~a WEBStTE : }~sv~.;raea~aor/loss.~orc' C:~DocumenLs and Settings~Diane williama~Desktop\Transnut Conoco.docx MEMORANDUM To: Jim Regg ~ P.I. Supervisor ~~ ~~~ ~~~ FROM: John Crisp Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, January 22, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3N-04 KUPARUK RIV UNIT 3N-04 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ~'~_ Comm Well Name: KUPARUK RIV UNIT 3N-04 API Well Number: 50-029-21529-00-00 Insp Num: mitJCr10012108s740 Permit Number: 186-017-0 Rel Insp Num: Inspector Name: John Crisp Inspection Date: 1/17/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ 3N-04 ~'I'ype Ind. ~ w TVD i 61 s7 IA T 580 3000 ~ P.T.D! 186017 `3,peTCSt sPT' Test psi 1 1s39 Q,d, ~ 140 0 2890 440 2880 '~ 440 Interval REQvAR _ p/F, P Tubing 2sso I 2850 _ 28s0 _ 28s0 Notes: 2.6 bbl's pumped for test. No problems witnessed {~ ~., ,~, Friday, January 22, 2010 Page 1 of 1 • ~/ ConocoPhill~ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 October 23, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501. Dear Mr. Maunder: C ~~6~~~7 3N~o~h Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRLn. Each of these wells was found to have a void in the conductor. These voids were filled with 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, ;f f~ ,~~ ~~~ .' MJ La eland ~~ ~~~~` } ~~ 2D~~ ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Datp 10/22/2008 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 ~ ~~ I /~ I P.I. Supervisor "! t FROM: Bob Noble Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, October Ol, 2008 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3N-04 KUPARtIK RIV UNIT 3N-04 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv ,`-6'~- Comm Well Name: KUPARUK RN UNIT 3N-04 API Well Number: 50-029-21529-00-00 Inspector Name: Bob Noble Insp Num: mitRCN080930090627 Permit Number: 186-01~-0 '/ Inspection Date: 9nsi2oos Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ 3N-04 Type Inj. ~' , TVD 6158 I,l, i 1860 3260 3200 3200 p T 1860170 TypeTCSt SPT ~, Test psi ~ 3260 ~ OA 30 40 , 40 ~ 40 Interval RsQvAR p~F P ~ Tubing I z7zo ~ 27zo ~ 27zo 27zo ' i NOteS' MIT-IA to max anticipated injection pressure '~',~as~ -- - Ago z3,vz9 G~ l~vu ~ "" i aka ~,' , ~ ~, i I ... r ! mw,..w ~ ~ / ~ t,.UL v Wednesday, October 01, 2008 Page 1 of 1 RE: 3N-04 (PTD 1860170) Rep~f suspect TxIA communication • Page 1 of 2 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Monday, January 28, 2008 9:14 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv ~~c j~~l b~ Subject: RE: 3N-04 (PTD 1860170) Report of suspect TxIA communication Attachments: MIT KRU 3N-04 01-26-08.x1s Tom Jim. The initial diagnostics are complete and the well was shut in on 01-27-08. The well passed a MITIA and M1TOA and the data is on the attached MIT form, The IA DD failed with a build up rate of approximatel 60 si an hour. At this time, the leak rate is to small to detect the location but a one way packer lea is suspected. It wilt be ConocoPhillips intention to submit an AA request to continue water injection and the well has already been added to the monthly MIT report for January. ___ Please let me know if you have any questions or would like any more infcirrxiation. «MIT KRU 3N-04 01-26-08.x1s» Brent Rogers Problem Wells Supervisor ConocoPhillips Aiaska, inc. Desk Phone (907) 659-7224 CeN Phone (907} 943-1999 Pager (907) 659-7000 pgr. 909 From: NSK Problem Well Supv ~(L~~~~~ FEQ ~. ~ 2QO~ Sent: Friday, January 25, 2008 12:00 PM To: 'tom maunder@alaska.gov'; 'Regg, James B (DOA)' Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: 3N-04 (PTD 1860170) Report of suspect TxIA communication Tom & Jim, Kuparuk water injector 3N-04 (PTD 1860170) was reported to have suspect TxIA communication on 01/25/04. The current TIO is 2700/2620/100. This is the second time this well has been reported however diagnostics following the previous report indicated no signs of TxIA communication. Following the first report on 12/28/07, the well has been added to the monthly MIT report. As per AIO 2B Rule 7, ConocoPhillips requests permission to leave the well on injection temporarily for diagnostic purposes since no USDW is endangered. Due to the results of the previous diagnostics, it would be preferable to do the testing in the well's current state that the suspected communication was reported. Following the immediate initial diagnostics the well will be shut in for further review. It will be ConocoPhillips intention to submit a request for Administrative Approval to continue water injection following the results of the diagnostics. Attached is a schematic and a current 6 mo TIO plot. 1/28/2008 RE: 3N-04 (PTD 1860170) Repo suspect TxIA communication Please let me know if you have anystions. « File: 3N-04 schematic.pdf» « File: 3N-04 6 mo TIO plot.png » Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Cell Phone (907) 943-1999 Pager (907) 659-7000 pgr. 909 • Page 2 of 2 1/28/2008 • L' KRU_3N-04 PTD 186-017 - "1 ~~~~ ~ ~ (o~~,; a • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Emaii to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: ConocoPhillips Alaska Inc. ~C.~~ l ~~~~`~ FIELD /UNIT / PAD• DATE: OPERATOR REP: AOGCC REP: Kuparuk/ KRU/ 3N-04 01 /26/08 Bates - AES Packer De t Pretest initial 15 Min. 30 Min. Well 3N-04 T e In'. W TVD 6,158' Tubing 2,700 2,700 2,700 2,700 Interval O P.T.D. 1860170 T pe test P Test psi 1540 Casin 2,620 3,300 3,240 3,240 P/F P Notes: Non witnessed diagnostic MITIA OA 140 180 180 180 Well 3N-04 T e In~. W TVD x,158' Tubing 2,700 2,700 2,700 2,700 Interval O P.T.D. 1860170 T e test P Test si 1540 Casing 800 950 980 980 P/F P Notes: Non witnessed diagnostic MITOA /' OA 100 1800 1760 1750 Well T e In'. TVD Tubing Interval P.T.D. Ty e test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differentia! Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describeih notes) MIT Report Form BFL 11/27/07 2008-0126_MIT_KRU_3N-04 MITOA.xIs ---~,~ A f y Ct~!"#t~GQPfl~li~S ,AI~S~C~, t"IC~ [3N-04 _ _ API: 5002921! - ~ SSSV T e: TRDP KRU 3N-04 INJ An le ~ TS: 29 de 7569 2/15/1986 An le TD: 28 de 7914 Annular Ftuid: Last WlO: Rev Reason; TAG FILL, Est. T SSSV rathole below PERFS (1795-1796, <~ Reference Lo Ref Lo Date: Last U ate: 6/25/2006 OD:2.875) ~ _ ~ Last Ta : 7652 TD: 7914 ftKB TUBING ' ~ Last TaP Date: 8/9/2002 _ Max Hole Angle:. 42 den n ?700 -' - - 1 (0-7510. Casin~tring -ALL STRINGS - - - oD:z.s75, Descri lion Size To Bottom TVD Wt - -~ Grade Thread ID.2.347) CONDUCTOR 16.000 0 115 115 62.50 H-40 SUR. CASING 9.625 0 4114 3586 36.00 J-55 PROD. CASING _ 7.000 0 7850 6516_ 26.00 J-55 r Tubin Stnn TUBING _ __ _ __ __ _ 3ndrel/ Y e S T 0 P ~ Bolt m D ~ ~ade Thread Valve l ~ ^ ~ 875 0 ~ -- - 621 8 W~0 _ J 55 EUE 8RD AB MOD (7385-7386, L , - Perforations Summa ry _~ - Interval TVD Zone Status Ft SPF Date T e Comment 7574 - 7584 6274 - 6282 C-4,UNIT B 10 4 9/24/1988 APERF 0 de hasE; 2 1/8" EnerJet 7612 - 7615 6307 - 6309 A-3 3 4 9/24/1988 APERF 0 de hasE; 2 1/8" EnerJet 7615 - 7615 6309 - 6309 A-3 0 5 9/24/1988 APERF 0 de hasE; 2 1/8" EnerJet 7615 - 7618 6309 - 6312 A-3 3 4 9/24/1988 APERF 0 de hasE; 2 1/8" EnerJet PBR 7618 - 7618 6312 - 6312 A-3 0 5 9/24/1988 APERF 0 de hasE; 2 1/8" EnerJet (742a-7425, 7618 - 7622 6312 - 6316 A-3 4 4 9/24/1988 APERF 0 de hasE; 2 1/8" EnerJet OD:2.875) ~ 7625 - 7632 6318 - 6324 A-2 7 4 4/20/1986 IPERF 90 de h; 4" HJ II Cs Gun 7639 - 7645__ _, 6330 - 6336 _ A-1 6 _4 _ 4/20/1986 IPERF 90 dea ph 4" HJ II_C_sg Gun I Gas Lift Mandrels/Valves - - - St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Vlv Run Cmnt 1 7385 6111 MMH 2 7/8 X 1 1/2 DMY 1,0 RK 0.000 0 4/27/1992 PKR (7440-7441, ' OD:6.151) - \ ~' / Other lu s, e ui ., etc. -JEWELRY -- De th TVD T e Descri Uon ------- ID 1795 1765 SSSV Baker'FVL' 2.310 7424 6144 PBR Brown 2.500 7440 6158 PKR Brown'HB-1' 2.441 7477 6190 NIP Camco'D' Ni le NO GO 2.250 7509 6217 SOS Camco'PE-500' 2.441 7510 6218 TTL 2.441 ', NIP r r:' :. (7477-7478, , . I SOS (7509-7510, OD:2.875) TTL ~i (7510-7511, OD:2.875) Pert (7574-7584) Perf (7615-7615) Perf (7612-7622) Perf (7618-7618) Perf (7625-7632) Perf (7639-7645) FW: 3N-04 (PTD 1860170) Repo~f Suspect TxIA Communication Page 1 of 2 • Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com) Sent: Friday, January 11, 2008 2:11 PM ~~~~ 1~~~ jp~, To: Maunder, Thomas E (DOA); Regg, James B (DOA) t Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: FW: 3N-04 (PTD 1860170) Report Of Suspect TxIA Communication Attachments: MIT KRU 3N-04 12-28-07.x1s; 3N-04 schematic.pdf; 3N-04 90 day TIO plot.jpg Additional diagnostics on 3N-04 (PTD 1860170) continue to indicate that well has integrity. On 1/10/08 and additional IA drawdown test was performed with the following results: Pre T/I/O 1450/690/80 Bleed lA Initial T/I/O 1450/55/70 15 Min T/I/O 1450/70/70 30 Min T/I!O 1450/75/70 45 Min T/I/O 1450/80/70 60 Min T/I/O 1450/80/70 3.5 Hr T/I/O 1450/80/70 ~~J ~ ~~~ ~ ~ 200 Based upon these results, ConocoPhillips is preparing to reestablish injection in this well under normal well status and continue to monitor for signs of TxIA communication. Further diagnostics will be performed dependent upon well performance. ~ ~cry~~~ ~~ I~,~~p Martin Walters CPAI Problem Wells Supervisor From: NSK Problem Well Supv Sent: Sunday, December 30, 2007 1:06 PM To: 'tom.maunder@alaska.gov'; 'Regg, James B (DOA)' Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: FW: 3N-04 (PTD 1860170) Report of suspect TxIA communication Tom, Jim The initial diagnostics on 3N-04 (PTD 1860170) have shown that the IA continues to have integrity. On 12/28/07 a passing MITIA, a passing IA Drawdown test and passing Tubing Packoff tests were completed. .----~-- The results from the Drawdown test were as follows: Initial T/I/0=1920/2920/100 following the MITIA. Bled down IA; T/I/0=1920/500/90; Start 60 min. DD test; 15 min. T/I/0=1920/600/90; 30 min. T/I/0=1920/620/90; 45 min. T/I/0=1920/620/90; 60 min. T/I/0=1920/630/90. Attached is the diagnostic non-witnessed MITIA form. ~ With all of the diagnostic testing demonstrating integrity, ConocoPhillips would like to continue injection under normal well status and monitor the wellhead pressures for signs of TxIA communication should it reoccur. If signs of communication should reoccur, further diagnostics will be performed. Please let me know if you have any questions. «MIT KRU 3N-04 12-28-07.x1s» 1/16/2008 FW: 3N-04 (PTD 1860170) Repo~f Suspect TxIA Communication Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Cell Phone (907) 943-1999 Pager (907) 659-7000 pgr. 909 From: NSK Problem Well Supv Sent: Friday, December 28, 2007 9:39 AM To: 'tom.maunder@alaska.gov'; 'Regg, James B (DOA)' Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: 3N-04 (PTD 186170) Report of suspect TxIA communication Tom, Jim Page 2 of 2 Sea Water injector 3N-04 (PTD 1860170) is suspected to have TxIA communication. Immediate action taken was to bleed the IA. Following the pressure event the well was shut in for Facility reasons however it will remain shut in pending further diagnostics. The TIO prior to bleeding the IA was 2896/2950/150. Initial diagnostics will include a MITIA or a Drawdown test if the MITIA passes and testing of the wellhead Packoffs. It is ConocoPhillips intention to followup with a 10-403 for repair or an AA to continue water injection if appropriate. Attached is a 90 day TIO plot and schematic. Please let me know if you have any questions. «3N-04 schematic.pdf» «3N-04 90 day TIO plot.jpg» Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Cell Phone (907) 943-1999 Pager (907) 659-7000 pgr. 909 1/16/2008 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: ConocoPhillips Alaska Inc. ~ tr tlo~,~~' FIELD /UNIT /PAD: Kuparuk/ KRU/ 3N-04 \~~' DATE: 12/28J07 OPERATOR REP: Johnson -AES AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. Well 3N-04 Type Inj. N TVD 6,158' Tubing 1,920 1,920 1,920 1,920 Interval O P.T.D. 1860170 Ty e test P Test psi 1540 Casing 1,820 /3,000 2,940 2,920 P/F P Notes: Non witnessed diagnostic MITIA / OA 100 100 100 100 Well Ty e In'. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test si Casing P/F Notes: OA Well Ty e Inj. TVD Tubing Interval P.T.D. Ty e test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interva{ P.T.D. Type test Test si Casin P/F Notes; OA i TYPE lNJ Codes TYPE TEST Codes INTERVAL Codes D =Drilling Waste M =Annulus Monitoring I =Initial Test G =Gas P =Standard Pressure Test 4 =Four Year Cycle I =Industrial Wastewater R =Internal Radioactive Tracer Survey V =Required by Variance N =Not Injecting A =Temperature Anomaly Survey T =Test during Workover W =Water D =Differential Temperature Test O =Other (describe in notes) MIT Report Form BFL 11/27/07 MIT KRU 3N-04 12-28-07.x1s C7 ~~ -~~ - ~ • ~~ '~ KRU 3N-04 ~~~~ Go~v~aPhillips Alaska, Inc .. ... 3N-04 __ AFP 5u0292152900 Well f e: INJ An le a) TS: 29 de a) 7569 SSSV T e: TRDP Ori Com letion: 2/15/1986 An le TD: 28 de 7914 i Annular Fluid: Last W/O: Rev Reason: TAG FILL, Est. T rathole below PERFS SSSV ~ Reference Lo Ref Lo Date: Last U date: 6/25!2006 (1795-1796, OD:2.875) , ~ I - Last Ta : 7652 TD: 7914 ftKB TUBING ( ~ Last Taq natP~ R~9/2002 - -- - Max Hole 4n!~le 42 ~1e~@ 2700 (a751o, Casing_String -. ALL STRINGS __ - _ -- oD:zs75, Descri lion Size To Bottom TVD Wt Grade Thread ID:2.347) CONDUCTOR 16.000 0 115 115 62.50 H-40 SUR. CASING 9.625 0 4114 3586 36.00 J-55 PROD. CASING 7.000 0 7850 6516 26.00 J-55 ng-TUBIN Tubin g and 1 Tnp ! B7ttom_ ND T Wt GradE Thread s75 , I I r.~~~ D 73 85--7386, ~ Perforations Sum mary OD:4.750) _ P8R (7424-7425, 00:2.875) PKR (7440-7441, OD:6.151) NIP (7477-7478, OD:2.875) SOS (7509-7510, OD:2.875) TTL (7510-7511, OD:2.875) Pert (7574-7584) Perf (7615-7615) Pert (7612-7622) Pert (7618-7618) Perf (7625-7632) Interval TVD Zone Status Ft SPF Date T e Comment 7574 - 7584 6274 - 6282 C-4,UNIT B 10 4 9/24/1988 APERF 0 de hasE; 2 1/8" EnerJet 7612 - 7615 6307 - 6309 A-3 3 4 9/24/1988 APERF 0 de hasE; 2 1/8" EnerJet 7615 - 7615 6309 - 6309 A-3 0 5 9!2411988 APERF 0 de hasE; 2 1/8" EnerJet 7615 - 7618 6309 - 6312 A-3 3 4 9/24!1988 APERF 0 de hasE; 2 1!8" EnerJet 7618 - 7618 6312 - 6312 A-3 0 5 9/24/1988 APERF 0 de hasE; 2 1/8" EnerJet 7618 - 7622 6312 - 6316 A-3 4 4 9/24/1988 APERF 0 de hasE; 2 1/8" EnerJet 7625 - 7632 6318 - 6324 A-2 7 4 4/20/1986 IPERF 90 de h; 4" HJ 11 Cs Gun ~ 7639 - 7645 6330 - 6336 A-1 6 4 4/20i1Q86 IPERF --_ _ -- - has Lift MandrelsNalves __ St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port 90 deg ph: 4" H 1 II Csg Gun _ - TRO Date Vlv Run Cmnt _ 1 7385 6111 - --__ Other lu s, e ui MMH 2 7/8 X 1 1/2 - -~ .etc. -JEWELRY DMY _ _ 1.0 RK 0.000 0 4/27/1992 ~ , De th TVD T e Descri lion ID 1795 1765 SSSV Baker'FVL' 2.310 7424 6144 PBR Brown 2.500 7440 6158 PKR Brown'HB-1' 2.441 7477 6190 NIP Camco'D' Ni le NO GO 2.250 7509 6217 SOS Camco'PE-500' 2.441 7510 6218 TTL 2.441 .:~ ~`d J Perf (7639-7645) 3N-04 (PTD-,L$~~eport of s ct TxIA communication Page 1 of 1 v~-~ 7 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Friday, December 28, 2007 9:39 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) r Cc: NSK Well Integrity Proj; NSK Problem Well Supv Subject: 3N-04 (PTD 1,$~~76~Report of suspect TxIA communication Attachments: 3N-04 schematic.pdf; 3N-04 90 day TIO plot.jpg ~ Q~~ ~1~C Tom, Jim ~~ ~~~ / ~ ~"' Sea Water injector 3N-04 (PTD 1860170) is suspected to have TxIA communication. Immediate action taken was to bleed the IA. Following the pressure event the well was shut in for Facility reasons however it will remain shut in pending 3 j further diagnostics. The TIO prior to bleeding the IA was 2896/2950/150. Initial diagnostics will include a MITIA or a Drawdown test if the MITIA passes and testing of the wellhead Packoffs. v It is ConocoPhillips intention to followup with a 10-403 for repair or an AA to continue water injection if appropriate. Attached is a 90 day TIO plot and schematic. Please let me know if you have any questions. «3N-04 schematic.pdf» «3N-04 90 day TIO plot.jpg» Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Cell Phone (907) 943-1999 Pager (907) 659-7000 pgr. 909 ;~;~~ ~`~ _ ~`~~~' per; 7 4, I /8/2008 ~~~ ~~~3 - v ~ ~ K2 ~( 3,ti -~4 • ~'~`~ ~~ KRU 3N-04 ~+ ~ Gonc~caPh~lips Ai~ska, incur .... 3N-t}4 -- - API: 500292152900 vvell T e: INJ An le TS: 29 de 7569 _ j SSSV T e: TRDP Ori Com letion: 2/15/1986 An le TD: 28 de 7914 Annular Fluid: Last W/O: Rev Reason: TAG FILL, Est. T rathole below PERFS SSSV (1795-1796 ~ Reference Lo Ref Lo Date: Last U date: 6/25/2006 OD:2.a75) ' Last 7a : 7652 TD: 7914 ftKB TUBING ~ Last Tag Date: 8/9/2002 Max Hole And 42 deg to 2 700 (0-7510, Casing String -ALL S__TRINGS -- --- oD:2.a75. Descri lion Size To Bottom TVD Wt Grade Thread ID:2.347) ', CONDUCTOR 16.000 0 115 115 62.50 H-40 SUR. CASING 9.625 0 4114 3586 36.00 J-55 PROD. CASING 7 000 n X850 _ 6516 26.00 I-55 Gas Lik ~ Tubing String -TUBING - --T-- _ -- andrel/Dummy ~ Slze Top- --- Bottom TVD ~ Wt Grade - Thread _ Valve 1 ~ ~ 2 875 0 7510 6218 6.50 ~uE aRO g rnoo (7385-7386, ~ ~ i ___ - Perforations Summary ___._.- -- -_... oD:a.7so) Interval TVD Zone Status Ft _ SPF _ Date T e Comment 7574 - 7584 6274 - 6282 C-4,UNIT B 10 4 9/24/1988 APERF 0 de hasE; 2 1!8" EnerJet 7612 - 7615 6307 - 6309 A-3 3 4 9/24/1988 APERF 0 de hasE; 2 1/8" EnerJet 7615 - 7615 6309 - 6309 A-3 0 5 9/24/1988 APERF 0 de hasE 2 118" EnerJet PBR (7424-7425, OD:2.875) PKR (7440-7441, OD:6.151) " , NIP (7477-7478, OD:2.875) =.S SOS (7509-7510, OD2.875) TTL (7510-7511, OD:2.875) ------ Perf (7574-7584) Pert (7615-7615) Perf (7612-7622) Ped (7618-7618) Pert (7625-7632) 7615 - 7618 6309 - 6312 A-3 3 4 9/24/1988 APERF 0 de hasE; 2 1/8" EnerJet 7618 - 7618 6312 - 6312 A-3 0 5 9/24!1988 APERF 0 de hasE; 2 1!8" EnerJet 7618 - 7622 6312 - 6316 A-3 4 4 9/24/1988 APERF 0 de hasE; 2 1/8" EnerJet 7625 - 7632 6318 - 6324 A-2 7 4 4/20!1986 IPERF 90 de h; 4" HJ II Cs Gun 7639 - 7645 Gas Lift Mandrels St MD TVD 6330 - 6336 A-1 6 4 _Nalves Man Mfr Man Type V Mfr V Type 4/20/198_6 _ IPERF ~ V OD LatchT Port 90 deg ph_4" HJ__II Csg Gu_ n_ _ TRO Date Vlv Run Cmnt 1 7385 6111 -- - .Other lu s, e u (p g q De th ND MMH 2 7/8 X 1 1/2 i p=etch -JEWELRY T e DMY 1.0 RK escri lion 0.000 0 4/27/1992 __ ID 1795 1765 SSSV Baker'FVL' 2.310 7424 6144 PBR Brown 2.500 7440 6158 PKR Brown'HB-1' 2.441 7477 6190 NIP Camco'D' Nioole NO GO 2.250 Pert (7639-7645) MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg. veä. ~/24 /04- P.I. Supel"VlSor N t1 DATE: Thursday, August 19,2004 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 3N-04 KUPARUK RIV UNIT 3N-O4 FROM: Jeff Jones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv .::s!3:I2---- Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 3N-04 API Well Number: 50-029-21529-00-00 Inspector Name: Jeff Jones Insp Num: mitJJ040818100730 Permit Number: 186-017-0 Inspection Date: 8/15/2004 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 3N-O4 Type Inj. s TVD 6571 IA 1000 1975 1940 1920 P.T. 1860170 TypeTest SPT Test psi 1539.5 OA 170 220 220 220 Interval 4YRTST P/F P Tubing 2930 2920 2920 2920 Notes: 1.3 BBLS diesel pumped. Thursday, August 19,2004 Page 1 of I STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELl_ OPERATIONS 1, Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate _ Pull tubing _ Alter casing _ Repair well _ Other __ 2, Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1562' FSL, 379' FEL, Sec. 29, T13N, R9E, UM At top of productive interval 1371' FNL, 1884' FWL, Sec. 29, T13N, R9E, UM At effective depth At total depth 1260' FNL, 1766' FWL, Sec. 29, T13N, R9E, UM 5. Type of Well: Development _ Explorato~__ Stratigraphic__ Service__X (asp's 518019, 6013800) (asp's 514991, 6016142) (asp's 514872, 6016253) 6. Datum elevation (DF or KB feet) RKB 67 feet 7. Unit or Property name Kuparuk Unit 8. Well number 3N-04i 9. Permit number / approval number 186-017 10. APl number 50-029-21529 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length CONDUCTOR 115' SURF CASING 4047' PROD CASING 7783' 7914 feet Plugs (measured) 6572 feet 7640 feet Junk (measured) 6331 feet Size Cemented 16" 223 Sx CS II 9-5/8" 1225 Sx PF E & 300 G 7" 350 Sx G & 175 Sx PFC Tagged PBTD (12/8/99) @ 7640' MD. Measured Depth True verticalDepth 115' 115' 4114' 3586' 7850' 6516' Perforation depth: measured 7574 - 7584'; 7612 - 7622'; 7625 - 7632'; 7639 - 7645' true vertical 6274 - 6282'; 6307 - 6316'; 6318 - 6324'; 6330 - 6336' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, J-55, Tubing @ 7510' MD. RECEIVED Packers & SSSV (type & measured depth) Brown 'HB-I' Packer @ 7440' MD. Baker 'FVL' @ 1795' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure Alaska Oil & Gas Cons. Commission Anchorage 14. Prior to well operation Subsequent to operation OiI-Bbl Representative Daily Average Production or Injection Data Gas-Mci Water-Bbl - 800 - 1100 Casing Pressure . Tubing Pressure 2900 2875 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations ___X 16. Status of well classification as: Oil __ Gas __ Suspended __ Service __(Water Inj).__ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 Rev 06/15/88 · Prepar'6d by John Peirce 265-6471 SUBMIT IN DUPLICATE 3N-04i DESCRIPTION OF WORK COMPLETED HIGH PRESSURE BREAKDOWN TREATMENT 12/8/99: RIH & tagged PBTD at 7640' MD. 1/31/00: MIRU & PT equipment. Pumped a Fullbore High Pressure Breakdown treatment through the open perforation intervals located at: 7574- 7584' MD 7612-7622' MD 7625- 7632' MD 7639- 7645' MD Pumped Stage #1' a) 300 bbls Slick Seawater @ 15 - 28 bpm & 8700 psi, followed by b) Gelled Scour Slurry with 1,887 lbs of 20/40 mesh proppant @ 20 - 28 bpm, followed by c) Shutdown. ISIP @ 2985. Pumped 590 bbls in Stage #2: d) Gelled Diesel w/2 ppa Rock Salt Diverter, followed by e) Gelled Scour with 2,100 lbs of 20/40 mesh proppant, followed by f) Shutdown. ISIP @ 2979. Pumped Stage #3: g) Gelled Diesel w/2 ppa Rock Salt Diverter, followed by h) Gelled Scour with 6,062 lbs of 20/40 mesh proppant @ 23 bpm, followed by i) Shutdown. Rigged down. Saw excellent diversion response w/rock salt diverter stages. Pumped total of 3000 lbs rock salt. Returned well to water injection & obtained a valid injection rate. MEMORANDUM TO: Dan Seamount Commissioner THRU: BlairWondzell ~ P.I. Supervisor ~/"'r FROM: Jeff Jones ¥o.~ ~. Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Sept. 1,2000 SUBJECT: Mechanical Integrity Tests Phillips Alaska Inc. 31 Pad 31-02, 31-06, 31-07, 31-09, 31-12, 31-13, 31-14, 31-16 KRU/Kuparuk River Field NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. WellI 31-02 I Typelnl. I S I T.V.D. I 6228 ITubingl 2920I 2920I 2920I 2920 I lntervall 4 P.T.D.I 1853080 ITypetestl P- ITestpsil 15'57 I Casingl 1000 I 1810 J 1810 I 1800 I P/F I P Notes: WellI 31-06 I Typelnj. I S I T.V.D.I ,0~, ITu~in, I ~,00 I =,00 I ~,00 I 2,00 I lntervall 4 P.T.D.I 1890380 ITypetestl P ITestpsil 1516 I Casingl 980 I 1840 I 1800 I 1790 I P/F I P Notes: We,I 31-07 ITypelnj. I S I.T.V.D. I~, I Tubingl 2850I 2850I 2850I 2850 Ilntervall 4 P.T.D.I 1860390 ITypetestl P ITestpsil 1530 I Casingl 11801172011700117001 P/F IP Notes: WellI 31-09 I Typelnj. I S IT'V'D' I 6156 ITubingl 28501 28501 28501 2850 I lntervall 4 P.T.D.I 186O550 3'ypetestI P ITestpsil 1539 I Casingl 1050I 18001 17901 17851 P/F I P Notes: WellI 31-12 Type lnj.I S I T.V.D. I 5031 ITubingl I =.oo I = oo I ,ooI lntervall 4 P:T.D.I 1860600 iTypetestI P ITestpsil 1258-1CasingI 760 118901186o118501 P/F I E Notes: 31-13 Notes: 'WellI 31-14 P.T.D. I 1860620 Notes: WellI 31-16 P.T.D..J 1890220 Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test' 4= Four Year Cycle V= Required by Vadance W= Test dudng Workover O= Other (describe in notes) Test's Details Friday, Sept. 1, 2000: I traveled to Phillips Alaska Inc.'s KRU 3I pad to witness the 4 year M1T's on wells # 02, 06, 07, 09, 12, 13, 14, 16. jerry Dethlcfs was the PLA rep. In charge of testing. The standard annulus pressure test was Performed with all eight wells Passing thc 30 minute pressure test. Summary.: I witnessed eight successful MIT, s on PIA's KRU 3I Pad. . .I,T.'s performed: _8 . Number of Failures: Attachments: Well schematics 0 Total Time during tests: 3 hrs cc: MIT report form 5/12/00 L.G. MIT KRU 31 9-1-00 JJ.xls 9/5/00 MICROFILMED 9/11/00 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Type of Request: Operation Shutdown Stimulate Plugging Perforate X Pull tubing Alter casing 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 ,X. , 4. Location of well at surface 1562' FSL, 379' FEL, Sec. 29, T13N, R9E, UM 6. Datum elevation (DF or KB) §7' RKB 7. Unit or Property name Kuparuk River Unit 8. Well number 3N-04 feet At top of productive interval 1371' FNL, 1884' FWL, At effective depth 1309' FNL, 1816' FWL, At total depth 1260' FNL, 1766' FWL, 12. Sec. 29, T13N, R9E, UM Sec. 29, T13N, R9E, UM Sec. 29, T13N, R9E, UM Present well condition summary Total Depth: measured true vertical 9. Permit number/approval number Verbal approval by L. Smith 10. APl number 50-029-21529 11. Field/Pool Kuparuk River Oil Pool 7914' feet Plugs (measured) None 6 5 71' feet Effective depth: measured 7 76 8' feet Junk (measured) None true vertical 6443' feet Casing Length Size Cemented Structural Conductor report Conductor 8 0' 1 6" not available Surface 4077' 9 - 5 / 8" 1225 Sx PF"E" & Intermediate 300 Sx Class "G" Production 781 5' 7" 350 Sx Class "G" & Liner 175 Sx PF "C" Perforation depth: measured 7574'-7584', 7612'-7622', 7625'-7632', true vertical 6274'-6282', Tubing (size, grade, and measured depth) 6307'-6316', 6317'-6323', 2 7/8", 6.5# J-55 AB mod. tubing with tail set @ 7510' Packers and SSSV (type and measured depth) Brown HB-1 pkr @ 7439'; Baker FVL SSSV @ 1795' Measured depth 115' 4114' 7850' 7639'-7645' 6329'-6335' True vertical depth 115' 3583' 6515' MD TVD · , 13. Stimulation or cement squeeze summary initial perforations in 'C' sand; reperforatincj 'A' sand Intervals treated (measured) 7574'-7584' MD ('C' sand), 7612'-7622' MD ('A' sand) Treatment description including volumes used and final pressure Perforated both zones at 4 spf with 0° phasing 14. Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 926 1000 2650 2188 1000 2650 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations X 16. Status of well classification as: Oil Gas Suspended Service Water Inj.._ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed .~v,~ . Title .x..,'~,-~/~ Form 10-404 CRev 06/15/88 SUBMIT IN DUPLICATE .riCO Alaska, Inc~' Subsidiary of Atlantic Richfield Company "ONTRACTOR REMARKS IOPERATIOI~J.~,T REPOI~IT TIME WELL SERVICE REPORT I. F-] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Temp. Chill Factor I Visibility )Wind Vel. Report "F "FI milesI knots ARCO Alaska, Inc. Date: February 17, 1989 Transmittal Ct: 7429 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. Please acknowledge receipt and return one signed copy of this transmittal. 3 F- 1 I Sub. Surface Pressure Survey I 0 o 0 6 - 8 8 3 H - 1 2 Kuparuk Well Pressure Report 8 - 2 9 - 8 8 3 O-0 7 Kuparuk Well Pressure Report 1 2 - 2 0 - 8 8 3 F- 1 0 Kuparuk Well Pressure Report 8 - 2 9 - 8 7 3 F - 0 6 Kuparuk Well Pressure Report 8 - 2 9 - 8 7 3 F- 0 2 Kuparuk Well Pressure Report 8 - 2 9 - 8 9 3 F- 1 6 Kuparuk Well Pressure Report 8 - 1 7 - 8 7 3 F - 1 6 Kuparuk Well Pressure Report 8 - 1 7 - 8 7 3 F- 1 1 Kuparuk Well Pressure Report 8 - 2 9 o 8 7 3 F o 0 4 Kuparuk Well Pressure Report 6 - 2 6 - 8 7 3 F- 0 5 Kuparuk Well Pressure Report 1 2 - 1 2- 8 8 3 F- 1 3 Kuparuk Well Pressure Report 1 2- 3 1 - 8 8 3 N - 1 0 Kuparuk Well Pressure Report 6 - 1 1 - 8 7 3 N - 1 0 Kuparuk Well Pressure Report 6 - 1 1 - 8 7 3 N - 0 4 Kuparuk Well PressQre Report 9 o 0 1 - 8 7 3 N - 0 9 Kuapruk Fluid Level Report 5 - 0 4 - 8 7 3 O- 1 4 Kuparuk Fluid Level Report 2- 1 3 - 8 9 30 o 1 4 Kuparuk Fluid Level Report 2 - 1 0 - 8 9 3 M - 1 8 Kuparuk Fluid Level Report 2- 1 0 - 8 9 3 F- 1 6 Kuparuk Fluid Level Report 6 - 0 5 - 8 7 3 F- 1 3 Kuparuk Fluid Level Report 6 - 0 9 - 8 7 3 F- 1 3 Kuparuk Fluid Level Report 6 - 1 8 - 8 7 3 F- 1 3 Kuparuk Fluid Level Report 6 - 1 6 - 8 7 3 F- 1 3 Kuparuk Fluid Level Report 6 - 21 - 8 7 3 F ° 0 8 Kuparuk Fluid Level Report 5 - 0 8 - 8 7 3 F- 1 6 Kuparuk Fluid Level Report 8 - 1 8 - 8 7 3 F- 1 6 Kuparuk Fluid Level Report 8 - 2 4 ° 8 7 3 F- 1 3 Kuparuk Fluid Level Report 6 o 0 5 o 8 7 3 F- 1 6 Kuparuk Fluid Level Report 6 - 2 / 3 - 8 7 3 F- 1 6 Kuparuk Fluid Level Report 8 - 5 - 8 7 3 F- 1 6 Kuparuk Fluid Level Report 6 - 5 - 8 7 3 F- 1 4 Kuparuk. Fluid Level Report 9 o 8 - 8 7 #7-889 Amerada Sand 'A' Amerada Amerada Amerada Sand 'A' Sand 'A' Amerada Sand 'A' Both Sands Both Sands Sand 'A' Casing Casing Casing Casing Tubing Casing Casing Casing Ar~ch0rage Tubing Casing Casing 3F-14 3F-06 3F-14 3F-08 3F-14 3F-09 3F-05 3F-09 3F-06 3F-05 3N-10 3N-10 3N-11 3N-10 3N-05 3N-04 3N-13 3N-11 3N-18 3N-17 3N-07 3N-15 3N-05 3N-09 3N-04 3N-14 3N-08 3N-06 3N-02 3N-10 3N-10 3N-10 3N-10 3N-10 3N-10 3N-10 3N-07 3N-01 3N-04 3N-04 3N-09 3N-10 Receipt Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Kuparuk Fluid Acknowledged: Level Re 3ort Level Re 3ort Level Re ~ort Level Re 2ort Level Re ~ort Level Re ~ort Level Re ~ort Leyel Report Level Report Level' Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Report Level Re )orr Level Re 3orr Level Re aort Level Re aort Level Re ~ort Level Re 2orr Level Re ~ort Level Re ~ort Level Re ~ort Level Re ~ort Level Re ~ort Level Re~ort Level Re~ort Level Re )orr Level Rel)ort Level Re )orr Level Re )orr Level Report Level Report 9-11-87 12-06-86 9-11-87 10- 11 -87 9-16-87 4-11-88 4-08-88 4-01 -88 3-26-88 1 -30-88 10-12-87 10-15-87 10-28-87 10-28-87 10-28-87 10-28-87 3-19-87 9-12-87 9-10-98 9-10-87 9-10-87 9-12-87 9-08-87 9-01 -87 9-01 -87 9-06-87 9-06-87 9-06-87 9-06-87 6-01 -87 5-31 -87 6-03-87 6-06-87 .6-08-87 6-09-87 6-25-87 4-17-87 4-18-87 6-17-87 6-20-87 5-07-87 8-24-87 ........................... Date: Casing Tubing Casing Tub,ng Casing Casing Casing Casing Casing Casing Casing Casing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Tubing Casing Casing Casing Casing Casing Casing Casing Casing Casing Casing ...... Alaska 0il & Gas Cone. ....... ¢r~7~orage COmlmssjoij DISTRIBUTION: D&M State of Alaska - Mobil Chevron Unocal SAPC ARCO Alaska, Inc. Post Office Bo.~ ,00360 Anchorage, Alaska 99510-0360 Telephone 907 276 12!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, 3N-12, 3N- 13, 1E-21, 1E-19, 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 If you have any questions, please call me at 265-6840. Sincerely, G. B. Srr/flllwood Senior Operations Engineer Attachments cc: J. Gruber M. b Hagood S. P. Twiggs KOE1.4-9 ATO 1478 ATO 112O ATO 113O RECEI.VED Nov 16 1988 ..... ' "",~: ~c/iorage. '..~'~'" ARCO Alaska. Inc. is a Subsidiary of AtlanticRichfieldCompany Type of Request: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown__ Stimulate m Plugging Perforate Pull tubing Alter casing Repair well Pull tubing 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Location of well at surface 1562' FSL, 379' FEL, Sec. 29, T13N, R9E, UM At top of productive interval 1371' FNL, 1884' FWL, Sec. 29, T13N, R9E, UM At effective depth 1309' FNL, 1816' FWL, Sec. 29, T13N, R9E, UM At total depth 1260' FNL, 1766' FWL, Sec. 29, T13N, R9E, UM 12. Present well condition summary Total Depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 7914' MD feet 6571' MD feet 7768' MD feet 6443' MD feet Other 6. Datum elevation (DF or KB) RKB 67 7. Unit or Property name Kuparuk River Unit 8. Well number 3N-4 ,'~ '~ ~-'~ 9. Permit number/approval number 7-804 10. APl number 5o-02~)-.2152~) 11. Field/Pool Kuparuk River Oil Pool Plugs (measured) NONE Junk (measured) NONE Length Size Cemented Measured depth Conductor report 80' 1 6" not available 115' MD 4077' 9 5/8" 1225 Sx PF"E" 4114' MD & 300 SX Class G 7815' 7" 350SxClassG 7850' MD & 175 PF "C" measured 7615', 7625'-7632' MD; 7618', 7639'-7645 'MD true vertical 6308', 6317'-6323' TVD; 6311', 6329'-6335' TVD Tubing (size, grade, and measured depth) 2-7/8", J-55, tbg w/tail @ 7510' Packers and SSSV (type and measured depth) HB-1 13kr @ 7439' & EVL SSSV @ 1795' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Prior to well operation True vertical depth 115' TVD 3583' TVD 6515' TVD Subsequent to operation 15. Attachments Copies of Logs and Surveys run .0il & Gas Cons. Commission Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 239 195 0 1 2 0 0 0 0 730 1 1 O0 16. Status of well classification as: Daily Report of Well Operations X Oil ,,. Gas Suspended J,, Service Water Injection 17. I hereby certify that the foregoing is true and correct to the.~-,,best of my knowledge. ~. /'~'~ - c.~dP- ~' Form 10-404 R~ 06/15/88 feet Tubing Pressure 112 1600 .riCO Alaska, Subsidlar~ of Atlantic Richfield Compan) · :LL I PBDT ~-4 CONTRACTOR r~EMARKS FIELD- DISTRICT- STATE OPERATION AT REPORT TIME WELL SERVICE REPORT [DAV~ IDATE '7-0 0il & G~s Cons. Commission I'-} CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK WeatherReport Temp. ~F Chill Factor. F II Visibility miles I Wlnd Vel. knots J Signed ARCO Alaska, Ine .... Post Office .~,~ 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 13, 1987 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99501 Commi s s i on Dear Mr. Chatterton' Attached in triplicate are multiple on Kuparuk wells. The wells were listed below. Applications for Sundry Approvals both conversions and fractures as Well Action Anticipated Start Date 2A-3 Convers i on 2A-6 Conversion 2A-7 Conversion October 19, 1987 October 19, 1987 October 19, 1987 3K-15 Conversion October 15, 1987 3N-4 Conversion 3N-5 Conversion 3N-11 Conversion October 15, 1987 October 15, 1987 October 15, 1987 3Q-5 Conversion 3Q-12 Conversion 3Q-15. Conversion October 15, 1987 October 15, 1987 October 15, 1987 If you have any questions, please call Sincerely, Senior Operations Engineer GBS:pg:0117 Attachments cc: File KOE1.4-9 me at 265-6840. RECEIVED OC']- 1 6 1981 Alaska 0ii & Gas Cons. Commissi0n Anchorage ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ...... STATE OF ALASKA ALA,.,,'A OIL AND GAS CONSERVATION CO,,..,nSSION 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 E] Perforate FI Other . Name of Operator ARCO Alaska, Inc 3. Address PO Box 100360, Anchorage, AK 99510 4. Location of well at surface 1562' FSL, 379' FEL, Sec 29 T13N R9E UM At top of pro~luctive interval ' ' ' ~ ]371' FNL, 1884' FWL, Sec. 29, T13N, RgE, UM At effective depth 1309' FNL, 1816' FWL, Sec. 29, T13N, RgE, UM At total depth ]260' FNL, 1766' FWL, Sec.29, T]3N, RgE: UM 11. Present well condition summary Total depth: measured 7914' MD feet true vertical 657]' TVD feet 5. Datum elevation (DF or KB) RKB 67 6. Unit or Property name Kuparuk River Unit 7. Well number 3N-4 8. Permit number Permit #86-17 9. APl number 50-- 029-21529 10. Pool KuDaruk River Oil Pnnl , Plugs (measured) None feet Effective depth: measured 7768' MD feet true vertical 6443' TVD feet Casing Length Size X X X ~Zr'/~'~lK X X X X Conductor 80 ' 16" Surface 4077' xxx~~0~te Production 7815' xxx~-~m~xxxx Perforation depth: measured 7615' 7618' 9-5/8" Junk (measured) None ,1 , 7625'-7632' MD , 7639'-7645' MD -6323' TVD -6335' TVD Cemented Measured depth True Vertical depth Conductor report not available 115' MD 115' TVD 1225 SX PF "E" & 4114' MD 3583' TVD 300 SX Class G 350 SX Class G & 7850' MD 6515' TVD 175 SX PF "C" true vertical6308, , 6317' 6311', 6329' Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail @ 7510' Packers and SSSV (type and measured depth) HB-1 pkr ~ 7439' & FVI. S.qgV @ 17qR' 12.Attachments Description summary of proposal ~ Convert a producer to a water injection well, 13. Estimated date for commencing operation October 15, 1987 Detailed operations program L-J BOP sketch 14. If proposal was verbally approved Name of approver Date approved 15. I here.,~certify that t,.b..9 foregoing is true and correct to the best of my knowledge Signed/<_/~//_/c//~ )/~/'?'~'~~ Title Sr. 0per at ions Engineer Commission Use Only Conditions of approval Approved by Date10/12/87 Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance ~l~turned Commissioner I*ppr°valN°' ~_.-- :: ~ by order of the commission Date Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Alaska, In¢, Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Date: March 18, 1987 Transmittal #: 5936 RETURN TO: ARCO Alaska, Inc. -Attn: Kuparuk Records Clerk ATO-1119 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. 2A-12 CET. 3-8-86 6410-7007 3F-16 CET 1-13-86 7740-8443 2A-lO CBL 3-20-86 6500-7042 3N-4 CET 3-25-86 6690-7736 3N-3 CET 3-25-86 6587-8016 3Q-7 CBL 2-15-87 6698-8908 3Q-6 CBL 2-14-87 7494-9545 3Q-2 CBL 2-15-87 7843-9752 ___3Q-5 CBL 2-15-87 7809-9941 3N-5 CET 3-25-86 5590-7456 2T-17 CET 9-5-86 6947-8236 2T-13 CET 9-1-86 6900-7752 2T-10 CET 9-4-86 4700-8118 'Receipt Acknowledged: DISTRIBUTION: NSK Drilling Mobil SAPC ~gh°r~;evron Unocal Vault (film) ARCO Alaska, Inc. Is a Subsidiary of AtlantlcRichfieldCompany ARCO Alaska. h Post Office Box 100360 Anchorage. AlasKa 99510-0360 Telephone 907 276 1215 DATE 0-~" ~4 ~ TRANSMITTAL # 5701a RETURN TO: ARCO ~, INC. ATT~: Kuparuk Records Clerk ATO 1119 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. Open Hole Final Prints: Schl: One * of each 3N-5 5" 2" 5" 2" Den/Neu-GR (poro) 5" Den/Neu-GR (raw) ~ 2" Den/Neu-GR (raw) Cyberlook 3N-4 5" DIL/SFL-GR 2" DIL/SFL-GR ~~ 5" Den/Neu 2" Den/Neu 7/7 5" 2" Den/Neu Cyberlook 3N-3 5" DIL/SFL-GR 2" DIL/SFL-GR / 5" Den/Neu 2" Den/Neu '5" Den/Neu ~ ~t 2" Den/Neu (raw) Cyb~rlook 3J;16 5" DIL/SFL-GR ~, 2" DIL/SFL-GR '/'~ 5" Den/Neu 2" Den/Neu 5" Den/Neu 2" Den/Neu Cyberlook DIL/SFL-GR 02-21-86 Run #1 DIL/SFL-GR 02-21-86 Run #1 Den/Neu-GR (poro) 02-21-86 Run #1 02-21-86 Run #1 02-21-86 Run #1 02-21-86 Run #1 02-21-86 Run #1 02-14-86 Run #1 02-14-86 Run #1 (poro) 02-14-86 Run #1 (poro) 02-14-86 Run #1 (raw) 02-14-86 Run #1 (raw) 02-14-86 Run #1 02-14-86 Run #1 02-17-86 Run #1 02-17-86 Run #1 (poro) 02-17-86 Run #1 (poro) 02-17-86 Run #1 (raw) 02-17-86 Run #1 02-17-86 Run #1 02-17-86 Run #1 02-15-86 Run ~ 02-15-86 Run #1 (poro) 02-15-86 Run #1 (poro) 02-15-86 Run #1 (raw) 02-15-86 Run #1 (raw) 02-15-86 Run #1 02-15-86 Run #1 0190-7593 0190-7593 6980-7568 6980-7568 6980-7568 6980-7568 6980-7568 2000-7896 2000-7896 4111-7870 4111-7870 4111-7870 4111-7870 7200-7840 1700-7986 1700-7986 7450-7960 7450-7960 7450-7960 7450-7960 7450-7937 4453-8718 4453-8718 8100-8695 8100-8695 8100-8695 8100-8695 8100-8671 ~ Oil & G~ Cons, Comm~ss~c An~omge Receipt Acknowledged: Date: state of AK*bl/se Drilling*bi NSK Clerk*bl D & M*bl Ratkmell*bl Vault*films ARCO AIIII[I. Inc. ,S · Sul~S,~,ary O! AtllntlCR~cl~fleldComl~lm? ARCO Alaska. I, Post Office Box 100360 Anchorage. AlasKa 99510-0360 Telel3hone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 07-14-86 TRANSMITTAL # 5701b Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. Open Hole Finals Continued..., 3I-5 . 5"' DIL/SFL-GR 2" DIL/SFL-GR ' ~~ 5" Den/Neu 5" Den/Neu 2A-10 2" Den/Neu Cyberlook 2" DIL/SFL-GR (poro) (poro) (raw) (raw) 5" Den/Neu-GR (poro) 2" Den/Neu-GR (poro) 5" Den/Neu-GR (raw) 2" Den/Neu-GR (raw) Cyberlook 02-09-86 Run #1 02-09-86 Run #1 02-09-86 Run #1 02-09-86 Run #1 02-09-86 Run #1 02-09-86 Run #1 02-09-86 Run #1 02-06-86 Run #1 02-06-86 Run #1 02-06-86 Run #1 02-06-86 Run #1 02-06-86 Run #1 02-06-86 Run #1 02-06-86 Run #1 1500-8061 1500-8061 4950-8035 4950-8035 4950-8035 4950-8035 7350-8012 6680-7132 6680-7132 6680-7107 6680-7107 6680-7107 6680-7107 6680-7107 ~,.,,...,,~ kmska 0tl & Gas Cons. Commi~ic: Receipt Acknowledged: sta~e -of AK*bl/se Drilling*bi NSK Clerk*bl D & M*bl Date: Rathmell*bl Vault*films ARCO AIIIkl, InC. ,! · Sul~l,~l,ity of AlllntlcRIchhelclComl~any I~ WBI. L, COMPI,,ETION OR REI~OMPLETIOR REPORT AND kOt;i 1. Status of Wall Classification of Service Well OIL ~( GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 86r!7 . . 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21529 4. Location of well at surface 9. Unit or Lease Name 1562' FSL, 379' FEL, Sec.29, T13N, RDE, UN Kuparuk River Unit 10. Well Number At Top Producing Interval 1371' FNL, 188/+' FWL, Sec.29, T13N, RDE, UN 3N-/+ At Total Depth 11. Field and Pool 1260' FNL, 1766' FWL, Sec.29, T13N, RDE, UM . Kuparuk River Field 5. Elevation in'f;et (ir~alcat'e' KB,'DF, etc.) e, Lease Desijnation 'and S'erial N~, ' KuParuk River Oil Pool 67' RKB I ADL 25521 ALK 2557 I 1:~. [~ate Spudded 13, Date T.D, Reached 14, Date C0'm'i~b~uj.~t'~r Aband, 1B. Water Depth, if offshore J 16. No, of Completions N/A feet MSL I 02/09/86 02/1/+/86 "~,, 05/27/86*. ~ . 1 ........ r .... 17.'+;~ta~DeFthiMD:~tv'~;l' 18.F~ugBackDepthIMD+~VDIh!~--m.~Survev I 20'De~th~"eresssvset I2l'~h~c~"ess°f"erme~r°st 22, Type Electric or Other kogs Run DIk/GR/$P/SFL~ FDC/C~L~ GR~ Cal~ .~, ~". ..... ...'~'..' ..... '.~ .... '. '....' ............ ~ ..... ~.~s.:,~?~.~.~ c~u,~'~'.~.~.' ..~ '~"_ '. ~ ' '" ..... ' SETTING DEPTH MD CA~G $~ZE W~. ?~.R FT. GRADE TOP ..... ~0~OM __ H~O~E_.~!Z~ . ~EMENT!NG RECORD .... AM~,UNT PULLED, mb" bZ.~ H-~U 5urt 115' 2M' ~ 233 sx CS Il · .~m.~/~,. ~6.0~ 'J'55 · Surf ...... ~1~' i2~i/~i~ 122'5-sx-~F ,E,, & 300 Sx Class G m ?''m I m 26.0~ ..... J-55' ' ' Surf " 7850' 8-1/2" 350 sx Class G & 175 sx PF "C" 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) . PACKER SET (MD) 7615 'MD 6308 'TVD 2-7/8" 7510 ' 7~39' 7618'MD 6311 'TVD 7625' -7632 'MD 6317 ' -6323 'TVD 26. ACID, FRACTURE, CEMENT'SQUEEzE, ETC. ..... 7639'-76~5'MD 6329' -6335 'TVD DEpTH i~NTERVAL(.MD)....AMOUNt.& KIND 0F MATERIAL USED . See a~tached add.e.n, lu~ dated 6/9/86, for frac data. 'Date Fi';st PrJdu~';ion · Method o~ ~pera'd'ron (Fi0wi~g', g;J ~ft, ~t~'.) TEST PERIOD e J I Flow Tubing O~in~ Pr~t~ur~ 0ALOULATED OIL-BSL GAS-MOF WAT~R-BBL OIL G~AVlTY-API 28. CO~E DATA Brief description of lithologY, porosity, Jr~cture~, ~pp~rent dip~ ~nd p~esence o~ oil, g~ or wBttr. Submit core chip~. None cC[ VED J U L 0 1 ]988 Form 10-407 * NOTE: Drilled RR 2/15/86. Well perf'd & tubing run /+/20/86. Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicat~ 29. NAME Top Kuparuk C Base Kuparuk C Top Kuparuk A Base Kuparuk A GEOLOGIc MEAS. DEPTH 7567' 7583' 7603' 7650' TRUE VERT. DEPTH 6266' 6280' 6298' 6339' 30. , 'FORMATION TESTS .. · Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Addendum (dated 6/9/86) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~ ~ Title 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- ing and the location of the cementing tool. Item 27: Method of Operation- Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL: 3/03/86 5/27/86 3N-4 Arctic Pak w/175 sx PF "C", followed by 54.5 bbls Arctic Pak. Dowell frac'd Kuparuk "A" sand perfs 7625'-7632', 7615', 7618' & 7639'-7645' in 8 stages per 6/8/86 (revised) procedure using diesel, Musol, gelled diesel, 100 mesh & 20/40 sand. Press'd ann to 1900 psi w/diesel. Tst lns to 8200 psi; OK. Stage #1: Pmp'd 40 bbls 140° diesel w/5% Musol @ 5 BPM w/3400 psi. Stage #2: 60 bbls gelled diesel spacer @ 20 BPM w/6200-4400 psi. Stage #3: 10 bbls gelled diesel pad @ 20 BPM w/4500-4600 psi. Stage #4: 18 bbls gelled diesel w/1 ppg 100 mesh @ 20 BPM w/4600-4550 psi. Stage #5: 65 bbls gelled diesel pad @ 20 BPM w/4550-4500 psi. Stage #6: 19 bbls gelled diesel w/3 ppg 20/40 @ 20 BPM w/4500-4550 psi (on fly). Stage #7: 29 bbls gelled diesel w/8 ppg 20/40 @ 20 BPM w/4550-5950 psi (batch mix). Stage #8: 40 bbls gelled diesel flush @ 20 BPM w/5950-6300 to 5140 psi. Pmp'd 750# 100 mesh & 11,600# 20/40 in formation leaving 540# 20/40 in casing. Load to recover 287 bbls of diesel. Job complete @ 1500 hrs, 5/27/86. Turn well over to Production. Drilling Supervisor Date STATE OF ALASKA -- ALASK~ _,IL AND GAS CONSERVATION COMMi,..,ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operatign shutdown"fq Stimulate [] Plugging ~ Alter Casing [] Other ~ ~..~1~101~'~¢., 2. Name of Operator I ARCO Alaska, Inc. 3. Address P.0. Box 100360 Anchoraqe~ AK 99510 4. Location of well at surface 7. Well number 1562'FSL, 379'FEL, Sec.29, T13N, R9E, UM 3N-4 At top of productive interval 8. Approval number 1371' FNL= 1884'FWL, Sec.29, T13N, R9E, UM Permit #86-17 At effective depth 9. APl number 1309'FNL, 1816'FWL, Sec.29, T13N, R9E, UM 50-- 029-21529 At total depth 10. Pool 1260'FNL, 1766'FWL, 5ec.29, T13N, R9E, UN Kuparuk River Oil Perforate'"~ Pull tubing 5. Datum elevation (DF or KB) RKB 67 ' 6. Unit or Property name Kupar-k River Unit Pool Feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Conductor 7914 6571 Surface Production 7768 6443 Length Size 80 ' 1 6" 4077 ' 9-5/8" 7815 ' 7" feet Plugs (measured) feet N o n e feet Junk (measured) feet None Cemented Conductor report not available. 1225 sx PF "E" & 300 sx Class C 350 sx Class G & ,175 sx PF "C" Measured depth 115'MD 4114'MD 7850'MD True Vertical depth 11 5 'TVD 3583 'TVD 651 5 'TVD Perforation depth: measured 761 5 ' M D 761 8 'MD true vertical 6308 ' TVD 6311 'TVD Tubing (size, grade and measured depth) 2-7/8", J-55, tbg w/tail (~ 7510' Packers and SSSV (type and measured depth) HB-1 pkr @ 7439' & FVL SSSV ~ 1795' 7625' - 7632 'MD 7639' - 7645 'MD 6317' - 6323'TVD 6329' - 6335'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 with Addendum) Daily Report of Well Operations ~ Copies of Logs and Surveys Run 1,5. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85~/j Title Associate Enqineer Date (DAM) $W0/001 Submit in Duplicate ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. I Accounting District ICounty or Parish I State Alaska North Slope Borough Field Ihease or Unit Kuparuk River I ADL 25521 Auth. or W.O. no. ~Title AFE AK1118 I Completion cost center code Alaska Nordic #1 API 50-029-21529 no. 3N-4 Operator ARCO Alaska, Inc. A.R.Co. W.I. 56.24% Spudded or W.O. begun Date Complete 4/20/86 Date and depth Complete record for each day reported as of 8:00 a.m. 4/20/86 Iotal number of wells (active or inactive) on this I est center prior to plugging and bandonment of this well I our ~Prior status if a W.O. 0800 hrs. I 7" @ 7850' 7510' TT, RR~ 6.8 ppg Diesel in tbg & ann Accept ri~ @ 0800 hfs, 4/20/86. ND tree, NU & tst BOPE. Perf "A" sand f/7639'-7645', 7625'-7632', w/4~_~un, 4 SPF, 90° phasing. Perf 7615' & 7618 W/4" gun,~ RU & rn 2-7/8" single compl w/TT @ 7510'. SSSV @ 1795', & HB-1 pkr @ 7439'. ND BOPE,'NU & tst tree. Displ well to diesel, set BPV. RR @ 2245 hrs, 4/20/86. Old TD I New TD I! PB Depth I Released rig ~ Date Kind of rig 2245 hrs. I 4/20/86 Rotary Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing , Kuparuk Sands Potential test data Well no. Date Reservoir Producing interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor ADDENDUM WELL: 3/03/86 3N-4 Arctic Pak w/175 sx PF "C", followed by 54.5 bbls Arctic Pak. Drilling Supervisor q-/-, ~/~ Date EXACT RRO!US OF CURVATURE METHO0 TIE-IN LOCATION MEASUREO OEPTH TRUE VERTICAL 0EPTH OISTANCE NORTH OISTANCE EAST BOTTOM HOLE LOCATION COURSE LENOTH COURSE AZIMUTH MEASUREO OEPTH TRUE VERTICAL DEPTH OISTANCE NORTH OISTANCE WEST 0.0 FT 0.0 FT 0.0 FT 0,0 FT ~98B.6 FT ~08.! OEO 79~4.0 FT 6S?1.2 FT 24S8.9 FT 9194.? FT REF 71385 STATE Of ALASKA ALASKA. L AND GAS CONSERVATION C01 lVIISSION COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well 1. Status of Well OIL [] GAS [] SUSPENDED/~ ABANDONED [] SERVICE [] Name of Operator ,. 7. Permit Number ARCO Alaska, Inc. 86-17 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21529 4. Location of well at surface 1562' FSL, 379' FEL, Sec.29, T13N, R9E, UN (approx) At Top Producing Interval TO be submitted when gyro is received. At Total Depth To be submitted when gyro is received. 5. Elevation in feet (indicate KB, DF, etc.) 67 ' RKB 6. Lease Designation and Serial No. ADL 25521 ALK 2557 9. Unit or Lease Name Kuparuk River Unit 10. Well Number 3N-4 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 16. No. of Completions 02/09/86 02/14/86 02/15/86 I N/A feet MS L N/A 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 7914'MD 7768'MD YES [] NO I~ N/A feet MD I 1700' (approx) 22. Type Electric or Other Logs Run DIL/GR/SP/SFL, FDC/CNL, GR, Cal 23. CASING, LINER AND CEMENTING RECORD CASING SIZE 16" 9-5/8" WT. PER FT. GRADE 62.5# 36.0# 26.0# H-40 J-55 · J-55 SETTING DEPTH MD TOP !BOTTOM Surf 115' Surf 4114' Surf 7850' 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) None HOLE SIZE 24" ;I,2-1/4" 8-1/2" CEMENTING RECORD Conductor report not 1225 sx PF "E" & 300 350 sx Class G & 175 AMOUNT.,~P,ULLED . vailable. C1 ass G x PF "C" 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. N/A PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) I Date of Test I Hours Tested Flow TubingI Casing Pressure Press. PRODUCTION FOR IOIL-BBL CALCULATED 10IL-BBL 24-HOUR RATE GAS-MCF GAS-MCF 28. CORE DATA WATER-BBL WATER-BBL CHOKE SIZE GAS-OIL RATIO OIL GRAVITY-APl (Cor~' Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED APR0 4 1986 ~:1 & G~s Cons. C0mml~sl~n Submit in duplicate Form 10-407 DAM 2/WC08 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ,,:-:::..:; 30. GEOLOGIC MARKERS FC NAME Include interval tested, pressu MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. N/A 31. LIST OF ATTACHMENTS Well Hi story 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~D ~- ~ Title Associate Engine data, all fluids recovered and gravity, )RMATION TESTS ,er Da,e 4-~'~/J INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska.. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 AtlanticRichfieldCompany Daily Well History-Initial Report Instructions: Prepare and submit the "lnitisl Report" on the first Wednesday after a wall is spudded or workover operations are started, Daily work prior to spudding should be summarized on the form giving inclusive dates only. District I County or Parish I Alaska Field ~Lease or Unit I Kuparuk River Auth, or W.O. no. ITitle I AFE AKlll8 North Slope Borough ADL 25521 Drill State Alaska IWell no. 3N-4 Doyon 9 API 50-029-21529 Operator ARCO Alaska, Inc. I D ate Spudded A.R.Co's W.I. Hour JPr or status if a W.O. 2/9/86 0030 hrs. 56.24% Spudded or W.O. begun Date and depth as of 8:00 a.m. 2/08/86 thru 2/10/86 2/11/86 2/12/86 Complete record for each day reported 16" @ 115' 3005', (2890'), Drlg Wt. 9.3, PV 12, YP 15, PH 8.5, WL 14.2, Sol 6 Accept rig @ 2100 hrs, 2/8/86. NU diverter sys. Spud well @ 0030 hrs, 2/9/86. Drl & surv 12¼" hole to 3005'. 692', Assumed vertical 767', 1.3°, N55.75W, 767.0 TVD, 0.8 VS, 0.5N, 0.7W 1250', 10.1°, N51.75W, 1244.7 TVD, 68.0 VS, 38.8N, 55.9W 2004', 33.0°, N48.75W, 1949.0 TVD 320.2 VS,190.5N,257.6W 16" @ 115' 4136', (1131'), Rn'g 9-5/8" Wt. 9.3+, PV 17, YP 12, PH 8.5, WL 11.8, Sol 7 Fin RIH, drl 12¼" hole to 4136', short trip, C&C, POOH f/csg. RU & begin rn'g 9-5/8" csg. 3112', 39.0°, N54.75W, 2796.0 TVD, 1033.2 VS, 640.7N, 810.6W 3551', 37.4°, N47.75W, 3141.2 TVD, 1304.2 VS, 806.4N, 1024.9W 4066', 35.8°, N43.75W, 3552.6 TVD, 1613.1VS, 1014.3N, 1254.6W 9-5/8" @ 4114' 4157', (21'), Drlg 8½" hole Wt. 8.4, PV 2, YP 2, PH 8.5, WL 16.2, Sol 1 Rn 104 its, 9-5/8", 36#, J-55 BTC csg w/FC @ 4032', FS @ 4114' Cmt w/1225 sx PF "E" cmt w/5#/sx Gilsonite, followed by 300 sx C1 "G" w/2% CaCi_. Displ using rig pmps, bump plug. CIP @ 1230 hrs, 2/11/8~. Good rtns thru out job. ND diverter sys. NU & tst BOPE. RIH w/BHA, tst csg to 2000 psi. DO cmt & flt equip + 21' new hole. Conduct formation tst to 12.5 ppg EMW. The above is correct For form preparation ~d distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87, IDate / / ITitle Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Su~mit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District ICounty or Parish IState Alaska North Slope Borough Field ILease or Unit Kuparuk River I ADL 25521 Complete record for each day while drilling or workover in progress Date and depth as of 8:00 a.m. 2/13/86 2/14/86 Alaska JWell no. 3N-4 9-5/8" @ 4114' 7167', (3010'), Drlg Wt. 9.2, PV 4, YP 2, PH 9.5, WL 6.8, Sol 6 Navi-Drl & surv 8½" hole to 7167'. 4336', 39.6°, N45.75W, 3766.2 TVD, 1777.0 VS, 1131.5N, 1320.8W 4778', 40.7°, N51.75W, 4103.3 TVD, 2062.5 VS, 1313.0N, 1591.3W 5407', 40.8°, N53.75W, 4580.7 TVD, 2471.9 VS, 1558.0N, 1919.4W 6039', 40.7°, N51.75W, 5059.0 TVD, 2884.8 VS, 1802.3N, 2252.6W 6354', 40.1°, N53.75W, 5298.9 TVD, 3088.9 VS, 1925.9N, 2415.1W 6981', 37.2°, N51.75W, 5785.6 TVD, 3484.0 VS, 2167.7N, 2727.6W 9-5/8" @ 4114' 7927', (760'), Circ hole cln Wt. 10.1, PV 12, YP 8, PH 9.5, WL 5.6, Sol 11 Drl & surv 8½" hole to 7927', CBU, short trip to shoe, circ hole cln. 7259', 33.5°, N49.75W, 6012.3 TVD, 3644.8 VS, 2269.5N, 2852.1W 7616', 29.1°, N45.75W, 6317.2 TVD, 3829.7 VS, 2394.1N, 2989.3W 7867', 27.7°, N42.75W, 6538.0 TVD, 3948.0 VS, 2479.6N, 3072.6W The above is correct Signature //~ For form preparation an,~distribution see Procedures Manual '~ection 10, Drilling, Pages 86 and 87 Drilling Superintendent AtianticRichfieldCompany '~, Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended' for an indefinite or appreciable length of time. On workovers when an official test is not required upon completio., report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. !Accounting cost center code District Alaska County or Parish Lease or Unit ITte Alaska Field Kuparuk River Auth. or W,O. no. AFE AKlll8 Doyon 9 Operator ARCO Alaska, Inc. North Slope Borough State JWell no. 3N-4 ADL 25521 Drill Spudded or W.O. begun API 50-029-21529 Spudded Date and depth as of 8:00 a.m. IA.R.Co. W.I. 56.24% IDato 2/9/86 Old TD Complete record for each day reported I otal number of wells (active or inactive) on this ost center prior to plugging and bandonment of this well I our I Prior status if a W,O. 0030 hrs. I 2/15/86 thru 2/16/86 7" @ 7850' 7914', (0'), RR Fin POOH. RU Schl, log DIL/GR/SP/SFL f/4111'-7902', cont w/GR to 2000'. Log FDC/CNL f/7200'-7902' & 4111'-4500', CAL f/4111'-7902'. Make cond'g trip, POOH. RU & rn 189 jts, 7", 26#, J-55 BTC csg w/FC @ 7768', FS @ 7850'. Cmt w/lO0 sx 50/50 Pozz, followed by 250 sx Cl "G" w/.6% FDP-C344 & .25% HR-5. Displ_w/10.1 ppg brine, bump plug. CIP @ 1715 hrs, 2/15/86. ND BOPE, NU & tst tree to 3000 psi. RR @ 2000 hrs, 2/15/86. 2/22/86 Arctic packed well w/175 sx PF "C". New TO IPB Depth Kind of rig 7914' 7768' Released rig Date 2000 hrs. 2/15/86 Rotary Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing Kuparuk Sands Potential test data Well no. Date Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P, C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature ~ Date// ITitle For form prol3aratio-n an~distribution'--'~ see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Superintendent SUB-~URFACE DIRECTIONAL ~URVEY [~UIDANCE ~ONTINUOUS ~"~OOL Company Well Name ARCO ALASKA INCORPORATED · WELL 3N-4' (1562'FSL, 379'FEL, S29, T13N, R9E)_ Field/Location KUP ,ARUK, NORTH SLOPE, ALASKA Job Referen ,ce No; 71385 PEPPEL Date,, 06-APRIL-86 Computed HALSTEAD 3CT 3 i ~ i:' CT ! ]~,,i ~ L TANG~NTf~L- LiN"'aR HOR~ ~TST NCRT~ SLSP~!, &L&SK~ PR~'~ J':C TED_ C~'.I TTM~. '-i T~'ST. :, A ZI~,IUTH NOR T H 51 DE 3 51 WEST COMPUThTIgN OhT~: 5-h~q-,35 PaGE ! AR~O ~L~.SK~, 3N-4 KUPARUK NgRTH SLOOE,ALASK2 iqT=q:~SL~T-3 VALJES '=OR TRUE SJ5-S~2 iE&SURED VERTICAL V~RTI'~L JEPTH OEPTH D-PTH CSJqS"- 3:VZ&TZ'"'N. &ZI~'IUTH. 0.00 0.00 -57.00 100.00 100.00 33.00 200.00 200.30 133.30 300. O0 300.00 :233. O0 400.00 400.00 333.00 500.00 500.03 433.00 500.00 600.00 533.00 ?00.00 /00.00 533.00 $00.00 799.~7 732.97 900.00 899.50 332.50 1000.30 998.22 931.2£ 1100.00 1096.,9 1029.49 1200.00 1194.85 I127.:35 1300.00 1293.26 1228.!6 1400.00 1391.35 1324.35 1500.00 14~8.70 1421,70 1500.00 15~4.41 1517.41 1700.00 1677.70 1610.70 1800.00 1759.36 1702.3,5 1900.00 1857.78 179J.7~ 2000.00 1942.29 2100.00 2022.82 2200.00 2100.13 2300.00 2177.55 2400.00 2254.25 2500.00 2329.89 2500.00 2405.12 2700.00 2479.~4 2~00.00 2554..55 2900.00 2629.46 t875.2~ 33 1955.32 35 41 2033.13 2110.55 39 17 2187.25 40 37 2262.89 40 59 233~.12 41 g412.94 41 2487.55 41 2552.46 3000.00 2704.47 3100.00 2781.13 3200.00 2858-55 3300.00 2936.$3 3~00.00 3015.29 3500.00 3094.59 360~.00 3174.~5 3700.00 3253.B0 3800.00 3332.5~ 3900.00 3412.52 2637.47 ~1 3 N 52 5~ W 271¢.13 3~ 13 N 54 35 W 2791.65 ~9 3 iq {4 ~ W 2859.63 3~ 26 N 53 9 W 2948.29 37 ~ N 52 3 W 3027.59 37 15 N 50 57 W 3107.4.5 35 53 q 5:0 Z,~ W 3186.80 ~ !2 q 51 1! ~ 3265.5:8 37 30 q 40 51 W 3345.62 36 i3 N 47 9 W :VEN V=~TI¢ S-Cfl -- -- - . --0. --I. --!. O. 24. 43. 6!. 7). 121 · 150. 1~,5. l 71 · 325. 575. 5aO. 705. ,772, '~39. g 7 ! · 11335. 1151. 1223. i 234. 1344. la05. i4,55. 1526. 103 AL T O0 11 3~ 52 53 77 10 32 54 22 31 31 O7 7O 37 '3 ~ 57 24 7~ 51 7'~ 37 12 7O 44 35 54 3'7' 95 =-- "T S 3gL'f.$ SEV:RITY 3:G/lO'~,. O.O0 2.55 3.13 · ~ I 7 ~.77 5.91 1.19 0 · ~4 ~'.20 3.7'~ 1.'~5 _:3.74 5.59 3.-~7 i}. 39 O. 53 O.~& 0.35 2.5: 0.45 3.62 0.33 3.71 0.7,: I. O '5 1.03 1.00 2.07 i. 91 K-LLY qUSd!q'3 5LEVaTION: 67.00 FT 7,13RT~/S 0.0 3.4 0.9 1.3 1.5 1.9 1.O Ii .5 21.5 32.7 44.! 5~.6 71 .1 ~ 7.5 105.7 126.6 154.7 188.5 226.5 255.S 307.5 343.6 390.0 ~32.£ 474.1 5!3.3 553.6 593 · 9 531 · .5 705.5 743.0 751.0 ~13.2 ~57.7 ::.,95 · 7 ~35.a 'JL&q CO3~OI'~T~S HD4!Z. DEPARTURE O'JTW E,aST/WEST 315r. &ZI~UTH 0.00 = 0.00 ~ O 0 E 0.11 E 0.12 S 553 2 0.16 E 0.~+5 S 20 2 0.!0 r:_ 0./'3 S 3 0 0.32 : 0.~5 S 1 2.5 E 0.94 W 1.30 S 1 51 W O.1O ~ 1.$5 S 3 22 0.1~ ': !.)5 S 4 10 1. 3! W 1.55 S 52 11 W 7.~4 ~'~ 3.,34 N 6'3 55 W 4 22.~2 ;,,J 25.26 N 62 34 W 6 ~.i 37.)5 W 43.70 'q 60 17 W 9 N 52.20 W 6!.65 N 57 51 i4 5 "'~ 45. 74 W '79.28 N 56 S W 7 '.-~ ~:O.TO W 9':~.50 :~ 54 55 W 5 ~ 9~.37 W 121.41 q 54 7 W ~ ~',1 1-22.03 W 150.21 q 54 20 W ~ >~ 153.33 W 13,b.05 q 55 22 W 1 N 1SI.la W 225.94 ~t 55 55 W 4 N 22~.28 W 272.48 N 55 23 W 265.55 W 325.76 N 3~ 36 311.06 ~ 384.82 ~ 53 55 ~AO., .,J:~_ W 44.~,.1,5 N 5;3 ~7 40~.50 W 511.35 ~ 53 1 457.7~ W 575.84 N 52 42 50~.~4 ~ 640o~1 q 52 30 559.06 W 706.55 N ~2 17 610.50 W 772.~7 ~ 52 10 663.94 W 83'9.53 N 52 15 715,88 W 305.77 51 52 1~ 769.34 W 97i.90 ~1 52 20 821.29 W 103,5.08 N 52 26 872.64 W 109~.20 N 52 32 923.04 W 1161.80 N 52 36 '97'2.09 W 1223.54 q 52 36 1019.73 W 1234.45 N 52 33 1066.26 W 1344.62 N 52 27 1113.33 W 1&05.43 hi 52 23 1161.02 W 1437.00 N 52 19 12~5.92 W 152~.81 N 52 19 W W W W W i,/ {' ARCO &LASKfi, INC. 3N-4 KUPARUK NDRTH SLDPE,ALhSKA COMPU'T~TION ZNT=q?]L6TES V~LJZS =OR EVEN lOS C,UJ~Si V=~TICAL DSGL 3:VI&TIDN $Z!MUTq S~CTZ]N S-V= 40 35 N 54 ~ W 2219.02 40 37 N ~4 I0 .N 2234.04 40 ~+1 N 54 19 W !349.16 40 ~ N ~ 30 ~ 2414.~0 42 50 xj 5~ 45 W 2479. 52 40 37 N S~ 55 ~1 2544..~6 40 57 7t 5~ 35 W 25!0.31 40 ~4 N 5~ 53 W 27~!.32 40 57 N 5~ 52 W 2306.72 40 ~3 N Sa 3.5 W 40 39 N ;~+ Z1 ;~ 2937.19 40 32 N ~ i'~ W 3002.27 40 12 N =$ 1~ W ~ ~6 ~ ~a7 40 0 N 54 16 W 3!31.39 3') &O N ~4 9 W '319~.27 ~ 31 N 54 0 W 325G.'~3 39 I0 :'~53 33 ,~ 3322.36 3;5 37 ~,153 1 ~ W 3~;55. 17 37 ~4 H 53 2 W 3~6.97 36 %4 N 51 22 W 3507.45 35 59 N 51 23 W 35~bS.$2 34 35 q 50 29 W 3624.72 33 ~ N 49 11 W 35'~0.!5 31 59 N 4~5 3 W 3734.14 30 5 N 45 0 W 3785. 74 29 3 ~,J a5 19 W 3J3~.5i Z~ 25 N 45 I1 W 33~2.31 23 25 N 4~ 11 W 3)29.59 23 25 N 45 II J 3976.~ TRUE SJE-S':& IE&SURED VSRTICSL VZRTI'aL DEPTH 3;PTd DZPTH 4000.00 34'93.79 3425.79 4100,00 3574.11 3507.11 4ZOO.O0 3653.30 35.~5..~0 4300.00 3732.~3 3665.43 4400 O0 ~809 3~ 374~ 3'~ 4500.00 3855.78 331,3.7:3 4600.00 3961.97 3894.~7 4700.0~ 4037.59 3970.69 4800.00 4113.46 4046.4.6 4900.00 4189.19 ~.122.1~ 5000.00 4265,01 419~.01 5100.00 ~340.~ ~273.'94 5200.00 4416. 79 ~34~.7~ 5300.00 4492.50 4425.60 5400.00 4565.34 4501.34 5500.00 4643.95 4576.96 5600.00 4719o~9 4652.49 5700.00 47~4.93 4727.93 5800.00 4870.~3 ~803.43 5900.00 4946.00 4879.00 6000.00 5021.50 ~954.60 6100.00 5097.~5 5030.a5 6200.00 5173.32 5105.32 6300.00 5249.52 5182.52 6~00.00 5325.95 5253.95 6500.00 5402.85 5335.85 6600.00 54?9'92 5412.92 6700.00 5557..10 5490.20 6800.00 5634,99 5567.99 6930.00 $713.60 5645.60 7000.00 5793.23 5726.23 7100.00 5873.7.0 ~805.70 7200.00 5955.22 5885.22 7300.00 603,8-42 5971.42 7400.00 6122.54 5055.54 7500.00 6208'08 614'1.08 7600.00 6295.21 622~.21 7700.00 5382.87 6315.$~7 7800.00 5470.82 $40S.82 7900.00 6558.75 5491.76 -21TY .5~ .64 .23 .95 .2~ .22 .13 .15 .3 ! .I~ .21 .12 .27 .3~ · :57 .42 .43 .CO .OO .OO q~-CTgN ~75. 1019. i105. 1191. 123!. 1279. 130~. i$47. gTc 3= SURVEY: 26 M~R :54 5LLY .:3USHINS =LEV~TiON: 67.00 FT =~GIN~=R: p=aPEL 213J.31 kl 278,0.49 W 350'7.63 N 52 26 W 2i74.95 N 2827.20 W 3567.00 N 52 25 N 2211.45 N 2872.16 W 3624.~"39 N 52 24 W !247.t9 N 2914o57 W 3580.30 N 52 22 W 2!~'2.88 N 2955.19 W 373~.26 N 52 lB W ~31~ 17 N 2993 09 W m785 33 N 52 !4 W 2352.55 N 3028.10 W 3834.56 N 52 9 W 2385.43 N 3062.27 W 3382.34 N 52 4 W 2~19.99 N 3096.06 W 3929.50 N 51 59 W =4~ ~4 N 3129.51 W 3~76.38 N 51 54 W 1753. !~01. ! ,~39. !~77. 1 915. I,~5£. 1999. 2027. ,-~ ~06~, .::lO i. 1355.:]8 "J 1733.13 W 2219.10 N 51 21 W 142~.07 "4 172-x.85 W 2284.10 q 51 25 W 1462.09 N !535,75 W 2~a9,20 N 51 30 W 1500.05 N 1~91.78 W 241~.33 N 51 35 W !53'/.:~+ W 19~5.02 W 2~79.53 N 51 40 ;~ !575.50 N 19~.3.5j W 2544.37 x] 51 45 ;4 ~,~I~. ~.14~ N °057~ _. 1~. W -PS10. 31 N 51 49 W !550.~3 N !105.92 W 2575.~4 ~ 51 54 W 15:38.43 N 2159.64 ~4 27~1.32 'q 51 53 N 1725.06 N 2213.25 ~ 2805.74 ~ 52 3 'N 83 N 2266.71 W 2372.12. N 52 6 N 73 N 2319.73 W 2937.24 N 52 9 W 72 N 2372.54 W 3002.33 N 52 12 W 45 N 2425.27 W 3067.05 q 52 15 W 05 N 2477.6~ W 3131.4'9 N 52 17 ',4 43 N 2529.53 W 3195.39 N 52 20 N 31 N 2581.12 W 3259.07 N 52 22 ~ 26 N 2632.35 W 3322.51 N 52 23 ~ 56 N 2682.~5 W 3385.34 N 52 25 W 55 N 2732.35 W 3447.14 '~ 52 25 W '~9 N 1247.74 W 1584.34 N 51 56 N 27 N 1289.38 W 1543.99 N 51 41 W 2'2 N' 1332.~0 ~ 1703.~ ~4 51 25 W 60 ~,~ 1375.07 W i7,5~.32 N 51 12 N 61 W 1422.60 W 1~29.05 >4 51 3 W 54 N !471.55 ~ 1~93.53 H 50 59 N 56 N 152!.54 W 195.3.2~ ~ 51 1 Wi 4x N 1575.~02 W 2323.55 N 51 6 W 56 5~ 1589.35 W 2153.97 N 51 16 W :3UL~ CUOROI."~6TES H32IZ. O$PhRTUR: S3~JTH E~ST/W=ST DIST. ~ZIMUTH T ~-"T =~ET 0-'3 D O~OTH ~RGO ~LASK~, IqC. 3N-4 KUPARUK N]RTH SLDPE,~1L~SK~ C~MPUT~TIDN iNT=ROOL~T~3 VALUUS FOR ;VEN 10O ===T CF TRUE SU6-S=~ IE~SUR:D VERTICAL V~RTIC~L DEPTH DEPTd C=PTH CSJRSE :O": V I aT I 3N N 45 11 7914.00 5571.37 5304.07 28 25 f, rT_. C, T 7.. ,3 I'.4 i~ "'- V '- i,l l T Y ..= -f .~ T D'"'S/130 3':)93.49 0 . 00 ~3RIZ. 3EP~RTiJRE DIST. ~ZiMUTH 3983.50 N 51 53 W COM°UT~Ti2N O~TE: ~-~P~-gS P4GE 4 ARCO &L,&SK~, INC. 3N-4 KUPARUK NORTH SLO~E,AL&SK~ TRUE ,E&SURED VERTIC2L DEPTH D=PTH 0.00 0.00 1000.00 998.22 2000.00 1942.£9 3000.00 2704.47 ~000.00 3~93.79 5000,00 4265,01 6000.00 5021.50 7000,09 5793,23 7914.00 6571.37 iNT~:q°3L-1T.~C VAL,J~q :JR :VEN 1000 ==---T 3r- V~'~TI-~L 3EViATIg~ AZIMUTH '~CTION $=V-P'T'f -67.OO 931,22 1~75.2') 2637,&7 34£6,79 &lgB,O1 ~95~,.50 5725.23 550~.07 gAT:_ .~": SU~V;Y:_ 26 .qAR ~6 K~LLY 5USHi;'43 EL~V.~TISN: 57,00 FT g DE~T 0,00 ~.00 0.0 24.82 1.1~ 11,5 325.39 ~.05 l~e.6 371.~7 2.50 533.9 15~a.~:{ 1,65 ~76.9 !219.02 0.25 13B5.~ 2372.0~ 0,45 1763.9 3507,45 0,~7 219~,~ O,O0 E 0,00 N 0 0 E 22.42 W 25,26 N 62 34 W 265,55 W 325,7~ N 54 36 W 759.3~ W 971.~0 N 52 20 W 1247,9~ W i5~4,~ N 51 56 N !733,13 W 2219.10 H _51 21 W 275J,49 W 3507,63 N 52 26 W C9~°UTAT!SN ARCD ~L~SKA, INC. 3N-4 NORTH SLODE,AL~SK~ DATE: · · IE~SURE3 DEPTH iNT:R°OL'~TSD V~LJ=S 'OR EVeN C:]JqSz ]~ViATIDH AZIqUTH 0 67 157 267 367 467 567 567 757 857 TRU= VERTICAL VZqTl~&L 958 1069 1171 1273 1375 1477 1581 1688 1797 1910 · 00 0.00 -57.00 · 00 67.00 0.00 · 00 167.00 lOg. DJ .00 257.0.3 200.00 · 00 367.00 300.00 .00 467.00 ~00.00 .OO 567.00 503.03 · 00 ~67.00 533.0,3 · 01 767.00 703.00 .19 857.00 ~09,00 2029 2157 2286 2416 2549 2682 2816 2950 3081 3210 ,25 967,00 900.00 · 98 1067,00 1000.00 ,70 1167.00 llO0.OO · 31 1267,00 1200.00 · 10 1367,00 13J0.00 · 62 1467.00 1400.00 .5~ 1567.00 1500.OO · ~J 1667,00 1600,00 · 39 1767,00 1700,00 .73 1867.00 1SOD.O0 VErTICaL DSSL 333B 3465 3590 3716 3843 3967 4091 4216 4344 4475 · 95 1957.00 1900.00 · lZ 2067.00 2000.00 · 37 2167.00 2100.00 .83 2267.00 2200.00 · 25 2367,00 £300.00 · 67 2467,00 2400.00 · 56 2567-00 2500.00 .05 2667~00 2600.00 · T6 2767,00 2703,00 · 76 2867.00 2~00.00 0.00 -0.01 ! -0.33 O -0 · 4~ - iD . 60 0 -0.5} -0.39 O · - 1.2 .~ -0. $4 2 - .71 296:7'00 2900.00 .25 30!6:7'0'0 3000.00 · 71 3167'00 3100.00 .83 3267-00 3200.00 · 22 3367.00 3300.00 · 12 3467.00 3400.00 .08 3567.00 3500.00 · 53 3657.00 3500.00 · 59 3757.00 3700.00 .39 3867.00 3800.00 B~ ~9 13 40 44 41 1~ 41 35 41 26 39 l 3 16 1 64 1 ~0 1 27 .D 27 2 10 5 35 2 342.22 420.77 502.f3 5,36.35 .373.13 F:31.43 3 50 · 5 ;~, 9:33..~ 4 i~24,50 1105,90 3,3 11 37 28 36 52 36 53 35 32 37 8 37 31 3'3 '43 40 i2 t1~5.70 1415. Bi 1493.05 1555.93 1713.97 ~T: ~ qUTVEY: 25 M~R ~6 ~SLLY BUSMING ELEV'~TiDN: 67,00 =T ENGT":ER:_, ~=OOEL. .._ : OF SU=,-S:~ 2EDT~ orTy 100 .00 O.O0 N .50 O.Ol q .30 0.31 S .05 O.x* x · 10 2.,59 S .il 1.15 S .95 I .55 S .23 1.~5 ~ _,~ 1.5~ S .44 1.90 >,,l .43 199.53 .3 ! 24 9.35 .31 301.00 .51 .7" ~67.i!0 .51 520.41 · 2~ 573.79 .93 624,94 .:~! 572.33 · 0:~ 720.31 · 6~ 767.73 .SY S15.65 .913 ;~64.29 .1~ 31 3.75 .35 953.59 .33 1015,43 .Of 1069.40 )4 ~125 45 i & .03 !191.F+4 OlNAT~S /'.4: ST T HJRIZ. OIST. JEP~RTUR: -TMUTH 353 ~IN O.O0 0.02 0.17 0.12 9.07 0.05 O. 0 5 0.17 0.51 0.00 N 0 0 E 0.02 N 50 29 E 0.35 S 2.~ 38 E 0.53 S 10 31 E 0.39 S 4 27 E 1.19 S 2 21 W 1.55 S I ~5 ~ 1.37 '~ 5 4 ~ 1.75 S 15 47 W 5.)0~ N 6,q_ 3:.. W 17. 3.3. 45. 52. 75. 94. liS. 14 9. 1 ? 5. ~_2 ::3. 37 40 34 15 72 96 25 22 55 19.52 38.14 N 61 7 W 56.5'9 N 58 30 74.52 N 55 33 93.43 N 55 11 115.95 N 54 13 W 144.22 N 54 11 W 13!,67 N 55 14 224.83 N 55 55 W 277,~5 N 55 18 W 27 S. 339. 401. 465. 533. 601 · 672. 743. 811. 878- 53 O3 -- 3 5 83 13 88 14 342.52 ~ 2 O. 9 '7 502.7~ 5~6.4t 573.16 751.,4 550.60 933.87 1024,55 1105.99 N 54 22 N 53 33 N 53 4 q 52 40 N 52 24 N 32 10 N 52 16 N 32 19 N 52 24 N 52 33 W W W W W w W W 942.2 1003.3 1061.9 1121.4 1180.8 1234.3 1286'0 1339,5 1396,5 1459.3 0 W 0 W 7 W 3 W 7 W 9 W 1 W 2 W 5 W 1185.81 N 52 35 W 1263.35 N 52 34 !4 1339.05 N 52 28 N 1415.87 N 52 22 d 1493.09 N 52 15 ~ 1555.94 N 52 1 W 1633,63 N 51 42 W 1714.03 N 51 23 W 1793,58 N 51 8 W 1377,64 N 51 0 W ARCO ALASKA, INC. 3N-4 KUP~RUK NCRTH SLCPE,AL4SK~ ZNT"RDSL~T:'C VALUES FO~ =VEN 10C =::T b~ TRU; SJ6-S"A E~SURED VERTICAL VERTI'~,L DEPTH DEPTH DE~TH 4506.52 3967.00 3~00.00 4738.71 4067.00 ~000.00 4870.69 4167.00 4100.00 5002.62 ~267.00 ~200.00 5134.33 4367.00 5256.27 4467.00 4400.00 5398.23 ~567.00 ~500.00 5530.51 ~667.0g ~800.00 5562.97 ~767.00 5795.46 4867.00 5927.83 ~957.D0 4900.00 6059.88 5067.00 5000.00 6191.67 5167.00 5100.~0 6322.88 5267.00 5200.00 6~53.~5 5367.00 5300.00 6583.24 5~67.00 6712.6~ 5567.00 5500.00 6840.87 5667..00 5600.30 6957.23 5767.00 S?O0.O0 7091.73 5857.00 5~OO.O0 7214.31 5957.00 5900.00 7334.10 5067.00 5000.00 7~52.23 6167.00 8100.00 755'7.72 6267.00 ~200.00 7681.96 5367.00 5300.30 7795.65 5467.00 5400.00 7909.37 6567.00 5500.90 7914.00 6571.07 5504.07 C]JqSr- VERTICAL 933LE} ]EVI2TIO~J AZ iVdT't ~=CTi2i,: S~:V=qZTY D-- '~!iq D =,3 MI~,,' ~='~T '3E'$/IO:J 40 39 N 53 15 W 1962.3') 0.:31 40 ~4 N 53 40 W 2948.65 3.25 40 i6 N 53 55 4 Z13~.73 j.l£ 40 3~ N ~4 ~ W _~__~°0.72 n~.Z7 40 3~ N 5~ 1~ W 2305.37 ,-J.2~ 4C 42 N 5~ 2~ W 2392.36 ~.~2 ~0 50 N 5~ ~5 W =~7'~..._~ O. 51 40 36 H 5~ 55 W !564.34 3.29 41 g N 35 5~ W 2651.57 0.07 40 c4 N =4. 58 W P73~ ~5 C ~O 40 53 N 5~+ 43 W 2'32.4.95 0.67 40 ~0 N 54 25 W £911.99 0.32 40 34 N ~4 13 W 29q6.$5 3.35 ~0 11 N 54 20 W 3031.73 0.1~ 39 ~O N 55 13 ~ 3!65.60 38 14 W ~3 1~ W 341S.5'9 1.10 37 3 N 52 35 W :3487.30 1.45 35 4 ~ 51 27 W 3551.95 1.33 C&T= Sm SURV=Y: 26 ~i~q 86 <=LLY 5dS~lq- EL-VDTION: 67.00 R:ST~I FEE S'3!JT~ cAST/W-ST 'DIST. AZI'qUT~ T FE~T =:=T D':G MiN 123~. 12~5. 1335. 13~5. !~37. l~e7. 1537. 1537. ! 636 · 1535. 14 N 1525.00 W 1952.59 N 51 2 N ~4 ~~'5o5. .3'9 W ~)948.31 N 51 S W 30 ~,l 16o~.90 W 2134.!5 N 31 14 C~ N !73~.51 W 2220.31 N 51 21 3} ~J 1333.9~ ,4 2305.42 '4 51 27 W 2~ ~ 1~73.~0 W 2392.39 17 N 1'94~.05 ~,1 2578.37 09 '~ 20!4.~1 W £564.B4 N 51 46 W ~ W lO~6.Ol 4 2651.57 N 51 52 W T~ N 2157.2! N 27~{.35 N 51 ~'736. ! 736. 1~35. ! '9:35. 2032. Ii) 79. :'i26 · 2171. 5'7 N 722-].18 W 2324.97 N 52 4 W 51 N 229:3.50 ;,i 2911,13 ~i 32 8 J 55 N 2368.24 W 2995,92 N 52 I2 W. 07 N 24~7,27 W 30~I.~1 N 52 15 N 08 ~.,l.~05.~ .44 W _R1~5.71. N 5~,. 19 W 55 9 2572.49' w 324:~.41 N 32 21 W O~ N 253,~.79 W 3330.50 N 52 24 W 87 N 2703.23 W 3410.76 N 52 25 W 34 N 276~.~0 W 3~/.9'3 ;',] 52 .76 W ~2 N 2323.al W 356!.14 N 52 25 W 2215.61 N 2878. 2259.40 "] 2928. 2301.33 q 2975. ~'~41 54 N 3016. 2380.39 N 3056. 241~,.53 N 3094. 2'4.5,5.53 N 3132, 2~5~.24 N 3134, ~2 W 3533.00 ;14 32 24 W 61 W 389q~.37 N :5',:. 21 W 42 W 3761.58 N 5£ 16 W )3 W 3~1~,98 N 52 11 1'9 W 3373,~2 N 52 5 W 37 W 3927.55 N 51 59 97 W 3981,31 N 54 W 3~83.50 N 31 53 J ' A~CO ALASKA, INC. 3N-4 KUPARUK N3RTH SLOPf,ALASKA MARKER TOP KU?ARIJK C BASE KUmARUK C TOP KUAPRUK A BASE KUPARUK ~ PBTD TO COMPUT&TIgN INTER~DL~T=O V~LUES ',I=&SU~ES D£~TH ~ELOW K8 7567.00 7583.00 7503.00 7550.00 7768.00 7914.00 ., ,:-OR ~HOS"N 5-APR-35 5266.37 5442.57 6571.07 OPIGI W= l'VJ 1562 ' S ~ S E~ 52!3.3= 6171 · 96 53v5.~7 6504.07 PaGE 7 gATE 05 Sij~V~Y: 25 M~R 56 <TLLY 3USHING 7LEVaTION: 67.00 E'~GIW~ER: ~EDPEL SURFACE ' 3C&TZJN ~T 379' ::EL, S=C 29, T13N~ q --CT&NGULAR COOR,DINa. TES N'3~ F~/S3dT't EAST/4EST 2341.29 N 3015.55 W ,23~6.7¢ N 3922.22 W 2253.57 N 3029.1a W 2359.60 N 30~5.22 W 2409.25 N 30g5.23 W 2458.24 N 313~.54 W FT RgE, A~O ~LASKA, INC. 3N-4 KUPARU~ NORTH SLOPE,ALASK& .MARKER TOP KUPARUK S BASE KJPARUK C TOP KUA~RUK A BASE KU~ARUK A PBTD TD CDMPUT~TZ]~ O~TE: 7S57.00 7753.00 791~.00 $265.~7 5259.35 5297..~3 533q.'95 557i.07 PAGE SURVEY: Z$ ;',I~R S6 KELLY BUSHING :LEVATION: 57.00 FT -x~GiNEBR: PEPPEL Jq=Gl~.~:. 1~6°~ ~' SJ~-SZ~ S 379 ' Ri'CT JqF~C: L]C. AT!]N ~T =L, S.:C 29, T13q, i.WGULAR COJR]INAT:~S TH/SBUTq EAST/WEST 5713.35 6 '~ "''~ 3 '~ ~,~7~ ~, 5~75-, · 57 a7 23 ~_3 23 23 f. 41.29 N 3016.59 ,$.7& iW 3022.22 $3.57 q 302).1~ 09.25 iq 3085.23 5~.2~ N 3134.5a RgE, FIN.~L WELL LSCATi]N ~T TS: TRJE SU3-Si~ MEASURED VERTICAL V~RTIS~L DEPTH DEPTH DEPTH T91~.00 $571.07 $504.07 Wgql LSNT~L OiSTANCE 3 9 3 3. F. 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NORTH PROJECTION ON VERTICAL PLANE NORTH - SOUTH SCALED IN VERTICAL OEPTHS HORIZ SCALE = 1/ 1000 IN/FT WELL 3N-4 (1562'FSL, B79'FEL, S29, T13N, R9E) VERTICAL PROJECTION -2000 - I000 0 0 1000 2000 3000 4000 SO00 gO00 308. PROJECTION ON VERTICAL PLANE 308. - 128). SCALED IN VERTICAL O£PTHS HORIZ SCALE = l/lDO0 IN/FT Form to be inserted in each :'Active" well folder to check for timely compliance ~ith our regulations. Reports and Materials to be received by:~ Required Date Received Remarks !Completion Report Samples Mud Log Core Chips Core Description ~~.~ . Inclination Survey ~birectional Surs~ .d .... , . . ~ , . Digitized Data .,. Y~ 3--'/~.~ ,:X ., ~-- STATE OF ALASKA ..... ¢¢~...- ALASKA C._ AND GAS CONSERVATION CO,..,¢IlSSION % ,o.,.,,..,o., o. o.,..,.o WO..OV.. O...*., O.. · Drilling well ~ operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 86-17 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21529 4. ~_ocation of Well atsurface 1562' FSL, 379' FEL, Sec.29, T13N, R9E, UM (approx.) 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 -4 11. Field and Pool Kuparuk River Field Kuparuk River 0il Pool For the Month of. February , 19 86 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ¢ 0030 hfs, 2/9/86. Drld 12-1/4" hole to 4136'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 7914'TD (2/14/86). Ran logs. Ran, cmtd, & tstd 7" csg. PBTD = 7768'. Secured well & RR ~ 2000 hfs, 2/15/86. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 16" 62.5#/ft H-40 weld conductor set ~ 115' Conductor report not yet received 9-5/8", 36.0#/ft, J-55, BTC csg w/shoe ~ 4114'. Cmtd w/1225 sx PF "E" & 300 sx Class G. 7", 26.0#/ft, J-55, BTC csg w/shoe ~ 7850'. Cmtd w/350 sx Class G. 14. Coring resume and brief description None 15. Logs run and depth where run DIL/GR/SP/SFL f/4111 ' - 7902' FDC/CNL f/7200' - 7902' & 4111' - 4500' GR f/2000' - 7902' Cal f/4111' - 7902' 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. (~/')ll, a~u , ,/b~hl.,l ..... Associate Engineer SIGNED -x~ i~&, I v ~' ~~ Il/Lb DATE ~ ''~'~ NOTE--Report ¢/this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas ConServation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 DAM/MR42 Submit in duplicate ARCO Alaska, Post OffiCe ~ox 100360 Anchorage. Alaska 99510-0360 Telephone 907 276 1215 RETURN TO: ARCO ALASKA, INC. ATTN: Kuparuk Records Clerk ATO 1119 P. O. Box 100360 Anchorage AK 99510-0360 DATE 03-04-86 TRANSMITTAL # 5588 Transmitted herewith are the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~ 3N-2 '~3J-16 ~3I-5 ~i-4 3I-3 ~A-11 "~2A-10 2A-9 OH Lis Tapes Plus listings/ SCHL/ One of each ~3N-4 02-14-86 REF #71279, ~ ~3N-~ 02~07-86 01-27-86 ~F ~71272~ 02-15-86 ~F ~71278~ 02-09-86 ~F ~71273~ ~~~--~ 02-02-86 01-26-86 ~F ~71242 01-28-86 ~F ~71243~ 0 -06-86 0 - 7-86 Receipt Acknowledged: Anchorage ARCO Alaska. Inc. it · Sublldiary of AtlanticRichfieldComplny MEMORANPUM State of Alaska TO: TH RU: FROM: ALASKA Ob AND GAS O~NSERVATION O3!~ffSSIOI~ ¸,% C. ~. ~Jtejrton ~issioner Bobby Foster Petroleum inspector DATE: FI LE NO.: TELEPHONE NO.' SUBJECT: Febr~mry 19, 1986 Tuck,.. Ferry 11, 1986: ccfispleted at' 8:30 p-m. As the attached BOPE test report shows there ~re no failures. In .~z~a~,, I witnessed the BOPE test on AR~O's 3N-4. ,'~. BOPE Test on '~ ARCO - K.R.U. Permit #86-17 ~-.:: Kupard~ River Field The BO~E test ~~ at 7=30 p.m. ~d ~s AttaChnent 32-001 A (Rev I STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Date .Inspecto _ ~ ~. ~~ O p era t o r. Z~~ R epr e s e n t a t ive wen · -Location, Sec~ ,~~,M '" Dr illin, Cont-rac~or~~~~y -- Location, General O~ Well Sign~ ACC~LATOR SYST~ General Housekeeping ~ Rig Reserve Pit... ~ ~ud Systems Visual Trip Tank / Pit Gauge / Flow Monitor ---~- Gas Detectors ~-~ Audio BOPE Stack Test Pressure Annular Preventer Pipe Rams Blind Rams Choke Line Valves H.C.R. Valve · Kill Line Valves Check Valve · 7 :! ' 'i~ i Full Charge Pressure ~._~ ~ ~ psig Pressure After Closure /~_5~ psig Pump incr. clos. pres. 200 psig Full Charge Pressure Attained: Controls: Master c~.,~ ! mi . 3 sec. psig Remote c~ Blinds switch cover~.~ / Kelly and Floor Safety Valves Upper Kelly / Test Pressure ~-~ Lower Kelly / Test Pressure Ball Type / Test Pressure Inside BOP ti Test Pressure Choke Manifold ~~Test Pressure No. Valves No. flanges Z~ Adjustable Chokes Hydrauically operated choke days and Inspector/ hrs. Test Results: Failures ~]). Test Time / Repair or Replacement of failed equipment to be made within Commission office notified. Remarks:, Distribution orig. - AO&GCC cc - Operator· cc - Supervisor ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 - January 31, 1986 A/ Mr. C. V. Chatterton Commi ss ioner State ~of Alaska Alaska Oil & Gas Conservation Commi ssi on 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT- Conductor As-Built Location Plat - 3N Pad (Wells 1- 18) Dear Mr. Chatterton- Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU13/L45 Enclosure If Al~,ska Oil & ARCO Alaska, Inc. is a Su:: idiary of AtlanticRichfieldCompany LOCATED IN PROTRACTED SEC's 28 8 ,.~TI3 N, R 9E,U.M. LOCATED IN PROTRACTED SEC. 29, TISN, R~E, U.M. I - Y = 6,013,799.67 LAT. 70°26'55.9615'' X = 517,946.19 LONG.149°51'12.938" 454' FEL, 1562' FSL OG = 28.2 PAD = 33.7 2 - Y = 6,013,799.65 LAT. 70°26'55.9606" X = 517,971.21 LONG.149°51'12.203'' 429' FEL, 1562' FSL OG = 28.2 PAD = 33.8 3 - Y = 6,013,799.54 LAT. 70°26'55.9590" X = 517,996.25 LONG.149°51'11.468" 404' FEL, 1562' FSL OG = 28.4 PAD = 33.9 4 - Y = 6,013,799.50 LAT. 70026'55.9580" X = 51B,021.16 LONG. 149°51'10.736" 379' FEL, 1562' FSL OG = 28.4 PAD = 33.7 5 - Y = 6,013,799.48 LAT. 70°26'55.9572" X = 518,046.18 LONG. 149°51'lO.O02" 354' FEL, 1562' FSL OG = 28.5 PAD = 33.7 6 - Y = 6,013,799.44 LAT. 70026'55.9562'' X = 518,071.24 LONG. 149°51'O9.266'' 329' FEL, 1562' FSL OG = 28.5 PAD = 33.9 7 - Y = 6,013,799.44 LAT. 70°26'55.9556" X = 518,096.21 LONG. 149°51'08.533" 304' FEL, 1561' FSL OG = 28.5 PAD = 33.9 8 - Y = 6,013,799.45 LAT. 70°26'55.9551'' X = 518,121.15 LONG.149°51'07.800" 279' FEL, 1561' FSL DG = 28.6 PAD = 33.9 9 - Y = 6,013,799.42 LAT. 70026'55.9542" X = 518,146.15 LONG. 149°51'07.066'' 254' FEL, 1561' FSL OG = 28.6 PAD = 34.0 NOTES I. ALL COORDINATES ARE A.S.P.,ZONE4. 2. SECTION LINE D!STANCES ARE TRUE. 10- 11- 12- LOCATED IN PROTRACTED SEC. 29, TI3N, R9E, U.M. Y = 6,013,799.37 X = 518,221.07 179' FEL 1561' FSL Y = 6,013,799.32 X = 518,246.03 155' FEL 1561' FSL Y = 6,013,799.45 X = 518,270.89 130' FEL 1561' FSL 6,013,799.41 518,295.97 FEL 1561' FSL 6,013,799.33 518,320.91 FEL, 1561' FSL 6,013,799.28 518,345.77 FEL, 1561' FSL 6,013.799.25 518,370.74 FEL, 1561' FSL 6,013,799.26 518,395.63 FEL, 1561' FSL LAT. 70°26'55,9519" LONG,149°51'04,865" OG = 28,5 PAD : 34.0 LAT, 70°26'55,9508.. LONG. 149°51'04.132'' OG = 28.5 PAD = 33.8 LAT, 70°26'55,9515'' LONG, 149°51'03.403" OG = 28,5 PAD .= 34,0 LAT, 70°26'55.9505" LONG,149°51'D2,666" OG · 28,5 PAD - 34.1 LAT, 70°26'55.9491" LONG,149°51'Ol,934" OG = 28,5 PAD · 34.0 LAT, 70°26'55,9480'' LONG,149°51'01,204'' OG = 28,5 PAD = 34,0 LAT, 70°26'55,9471'' LONG.149°51'O0.470" OG = 28,5 PAD = 34,1 LAT, 70°26'55,9466'' LONG,149°50'59,739" OG = 28,5 PAD = 34,1 SEC. 28,TI3N, R9E, U.M. 18 - Y = 6,013,799.15 LAT. 70°26'55.9449'' X = 518,420.80 LONG.149°50'59.O00'' 20' FWL, i561' FSL OG = 28.5 PAD = 34.0 3. HORIZONTAL POS':TIONS BASED ON ON-PAD P.~LING CONTROL PER LHD E~ ASSOC. 4. VERTICAL POSITIONS BASED ON MODULE PILES 3dOI--8 & 3J01-4. INTERPOLATED FROM S/C DRAWING CED-RIXX-3090 rev./~. 5.0. G. ELEVATIONS CERTIFICATE OF SURVEYC~ - -a,, ,, -. - I SURVEYED :hr ~) D~TE 14 JAN 8~ ~ ' DRILL SITE 3N CONDUCTOR 8SSOG, L& DWG. NC. NSK 86-3 ~3~5 4fCt/C Bou/evar(]. S~/te 20 ! ~,~ora~e, 4/as~,a January 10, 1986 Mr. J. B. Kewin Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Dear Mr. Kewin: Kuparuk River Unit 3N-4 ARCO Alaska, Inc. Permit No. 86-17 Sur Loc 1562'FSL, . . . 379'FEL, Sec. 29, T13N, R9E, Btmhole Loc. l187'FNL, 1678'F~L Sec 29 T13N R9E UI~! 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 office 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 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. ~) tr¥1j~y?~rs,~ Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE CO}~E~ISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, In~ Post Office ~ox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 3, 1986 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 3N-4, Permit to Drill Dear Mr. Chatterton: Enclosed are: An application for Permit to Drill 3N-4, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore o Proximity plots o A diagram and description of the BOP equipment We estimate spudding this well on January 28, 1986. any questions, please call me at 263-4970. Sincerely, JBK/LWK/tw PD/L207 Enclosures If you have Gas Cons. Cornm~ssior~ ,Anchorage ARCO Alaska, inc, is a Subsidiary of AtJanticRichfieldCompany · ?~' STATE OF ALASKA ALASKA ,~iL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.O05 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well EXPLORATORY [] DEVELOPMENT OIL I~x DEVELOPMENT GAS [] SERVICE [] STRATIGRAPH lC SINGLE ZONE ~!~ MULTIPLE ZONE 2. Name of operator ARCO Alaska, Inc, 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 /'~'/,,_ 4. Location of well at surface ¢,~ ( ~]-~ ~, | 9. Unit or lease name , , '~."I I 1562 FSL, 379 FEL, Sec.29, T13N, R9E, UM (Approx.) - ? ~ ~/.;~-,,Kuparuk River Unit At top of proposed producing interval '"<¢,% '~/? £i ~ [~1~). Well number 1374' FNL, 1917' FWL, Sec.29,, T13N, R9E, UN '" d~;,, , ':" ,,"'*.,~,. -,,, I 3N-4 At total depth ~ ~ [~:'~ ~.. ~'~ ~ ' ''~ I 11. Field and poo~ 1187' FNL, 1678' FilL, Sec.29, T13N, R9E, UN '~)?C/'O Wh2':' ",. IJ Kuparuk River Field 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. ~8 -'"z;lz~,..,, Kuparuk River 0i l Pool RKB 67', PAD 33' ADL 25521 ALK 2557 ~r;7o4, I 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number #8088-26-27 Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 30 mi. NW of Deadhorse miles 379' ~ surface feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 7976' MD, 6529' TVD feet 2560 19. If deviated (see 20 AAC 25.O50) 20. Anticipated pressures KICK OFF POINT 1000 feet. MAXIMUM HOLE ANGLE 40 o (see 20AAC25.035 (c) (2) 15. Distance to nearest drilling or completed 3N-3 well 25' 0 surface feet 18. Approximate spud date 1/28/86 2857 psig@. 80°F Surface Proposed Casing, Liner and Cementing Program 3280 psig@ 6377 ft. TD (TVD) SIZE Hole ! Casing ~4;" 16" 12-1/4" 9-5/8" 8-1/2" 7" , 22. Describe proposed Weight 62,5# 36.0# J 26.0# J program: CASING AND LINER Grade Coupling Length H-40 / Weld -55/HF-E1W BTC SETTING DEPTH MD TOP TVD 80' 35' I 35' 4114' 35' I 35' I 34' 34 MD BOTTOM TVD 115'1 115' 4149'; 3612 , 7976'1 6529' I __ QUANTITY OF CEMENT (include stage data) + 200 cf 1225 sx PF "E" & 300 sx~:F,,,Class "G" 300 sx Class "G" neat ARCO Alaska, Inc., proposes to drill a Kuparuk River Field development well to approximately 7976' MD (6529' TVD). Selected intervals will be logged. A 20", 2000 psi annular diverter will be installed on the 16" conductor while drilling the surface hole. The 13-5/8", 5000 psi, RSRRA BOP stack will be installed on the 9-5/8" surface casing. The stack and related equipment will be tested to 3000 psig upon installation and weekly thereafter. Expected maximum surface pressure is 2857 psi. Pressure calculations are based on virgin reservoir pressure. Surface pressure is calcu]ated with an unexpanded gas bubble at surface, including temperature effects. Casing will be tested to 3500 psi prior to releasing the drilling rig. Non-freezing fluids wi]l be left in uncemented annuli through the permafrost interval. 3N-4 will be 25' away from 3N-3 at the surface. There are no closer wellbores anywhere downhole. 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. (continued on attached sheet) 23. I hereby, A~y that the foregoing is true and correct to the best of my knowledge // ,,~ // SIGNED L/~'~-/~_~/~'. ~.,('.,~~ TITLE Regional Drilling Engineer DATE Th e spa~lo~ f~/O~m/ssi'~n use CONDITIONS OF APPROVAL Samples required Mud log required Permit number Approval date f & -/'Z--. .J .-m.-,O1 / 10~86 Form 10-401 (LWK) PD/PD207~ / ' Directional Survey required IAPl number E NO I 5o- SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE January 10, 1986 by order of the Commission Submit in triplicate pER~~ ~0 DRILL · . a minimum of ~?.5 s.x cement ~" . ~,, annulUS ~ ~_ using 3'~/~ u'_.,,ent reportS-. _ roceSS~ .... _ ~ted b~ ~'~" .... nd repu'~ ~er %he d~SPusa] P- ' be comp]" _.,u {ormatlu~' a ~ ~h~ %ob. _ m %etion of the. ~he we]] w%~] .... :n the Kuparu~ __,~usion o~ upon uo P. ~rctiC pack- _.rotated w~n' ~ ~ested upon fo~lov~ed by ~-valS ~il~ be pe, ._s+al]ed anu ~ . .... ted inter -~ve ~%~% be ~' [ ~ractUre be~_~ace safety v~, we]] will be · subSUr' _ ~, this moved off ;. ~ .... ~ , ~ _ , , , ~ ' ...... ~ ' . . ~ · . : ~ . ~ ~, .. ...... ~ ............ , ~~_ , _ ~ .... ....... , .................... . .............. ~ ........ --------- I L i i ii LII ~ I~11 ~ ~ ~ ~ i i ii ii i ii i i i iii i i i i ii i i ilmu i _ ~ · :- ~ - -- ...................... ~ : ~ ~.~ -- ~ .... - ~ ................ : ....... ~ ......................... ~ ............. } .................... KUPARUK RT VER UN:IT 2_0" .D~ VERTER SCHEMAT I C 8 DE SCR I PT I ON i. 16' C~CTOR. 2. TAI~I<O STARTER HEAD. 5. TANKO SAVER SUB. 4, TANKO LOWER QUICK-C~CT ASSY. 5. TANKO UPPER QUICK-C~CT ASSY. 6. 20" 2000 PSI DRILLING SPOOL W/I O' OUTLETS, ?. I0' HCR BALL VALVES W/lO' DIVERTER LINES, VALVES OPEN AUTOMATICALLY UPON CLOSURE OF A~AR PREVENTER. 8. 20' 2000 PSI ANDaJLAR PREVENTER. 7 6 7 4 MA! NTENANCE & OPERAT ! ON I. UPON INITIAL INSTALLATIOf~ CLOSE PREVENTER AND VERIFY THAT VALVES HAVE OPENED PROPERLY. 2. CLOSE AhINULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE At~NULAR PREVENTER IN THE EVENT THAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. IF NECESSARY° MANUALLY OVERRIDI~ AND CLOSE APPROPRIATE VALVE TO ACHIEVE DOt~NWlND DIVERSION. DO NOT SHUT IN WELL ill UKIDER ANY CIRCUMSTANCES. · 5 .> > 1. I~' - 2CDC:) ~l:X~,~! 'r'N%KCC) S'rART21M~ IF. AD 2. ][' - ~ 1 C,D, S2N~tT. AD ~,.l~.5/B' - SC:X::D PS2 P2PE. KILL LIh~ A~ATO~. CApAciTY T~ST .1.C3=ECX AhD F'ZLL ACO. MJ_ATER REEE~0IR TO PRCPE~ · LEVEL W~TH HYDRAL~IC FLUID. 2..ASSLRE THAT A~TCR ~ ZS ~ i:~I W"Ig'H 3. ~ TZ~,, 'fi-EN CLOSE ALL LI~T$ $3~LL'TANECU~¥ .ALL UNETE ARE CLCESE:D WZTH O-IAl~lh~ PLIVP ~'F. ~$ 45 SE~ CLOS[N~ TZ~E A~D 1200 PS[ REMA[N2N~ 4 14. · . ,13--5/8" BqP STACX 1. FILL BOP S'rACX AND 'O-D(E 'ta~EF~.D WTTH A~'TZC C3.~CX 'r~'T ALL LDO( ~ SC:REt~ IN ~_! lEAD FULLY R~'RACll~. SE. AT 'rE:s'T PLUG 2N ~ I_ ~F. AD V~TH ~ht~N~ JT AND RUN ZN LOCXDCV~ ~. L.II~E VALVES AD, JACEI~rr 'ro l~P Si'ACK. ALL 0TI-ER 4. PRESSURE UP TO 250 PSI ~ NCI. D FIR 10 14IN. IN- ~ ~ TO 3,CO0 PSI AN:) HOLD FCR I0 ~u ~r'r~ PEESSL$~ T0 0 PSZ. U~E VALVES, CLCS~ 'tm P~ ~ ~D .C~ V~v~s 6.' 3~S'r. TO 250 PSI AND 3000 PS2 AS IN STEP 4. 7.' C CI4rII,4JE TESTIN~ ALL VALVES, LII~.S, AND WI'D-{ A 2.50 PS~! LC~ AND 3000 PS2 H2GH. TEST AS 2N NOT A F'~_L (;L. OS].I~ PC~IT/VE SEAL Q,-p~. 8.. ~ TC:F' P2PE ~ AhD CLC:E~ BcTr'Tc~ P2F~ TEST BC)TTC~ PZPE ~ TO 250 PS! AhD :30C:D PS2. PS2.. ;TEST'.~~I~ VALVES, KELLY, WF!I_Y CO0~o DRILL :P2PE SAFETY VALVE, A~D INSZDE t~C]= TO 250 PSI A~D FC3a~ SIC~L A~D SE~D TO DRILL2NC~ .; -. .. '" ~, ~, iLi -.. . -'. '.. ,,.~'. · , ~ '.:', AlaSka Oit & Gas . , 51C)C)~400 i REV. 2 · MAY 15, 19~5 ITEM APPROVE DATE (2 thru 8) Company'~'-~.~-//<' d ~ Lease & Well No. yES NO 1. Is the permit fee attached .......................................... 2, 3. 4. 5. 6. 7. ' L ~ l .,, . (3) Admin /-~ o~ 9 (9/ thru 12) 10. h/J ' : . (10 and 12~ 12. '(13 thru BOPE /~, 13. .14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. (22 thr~ 26) REMARKS Is well to be located in a defined pool ......................... · ... ~;~ ..... Is well located proper distance from property line ............. Is well located proper distance from other wells . ........ ii! 'i i~/~/~~'' '' Is sufficient undedicated acreage available in this pool . . Is well to be deviated and is wellbore plat included ................ ,~ Is operator the only affected party ................................. Can permit be approved before ten-day wait .......................... Does operator have a bond in force .................................. .~ Is a conservation order needed ...................................... Is administrative approval needed ................................ Is the lease number appropriate ............... Is conductor string provided ............ ............................ .~.~ Is enough cement used to circulate on conductor and surface ......... .~ ..... Will cement tie in surface and intermediate or production strings ...~J~ Will cement cover all known productive horizons .................... ~,~ . Will surface casing protect fresh water zones ......... Will all 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 10-403 ............ Is adequate wellbore separation proposed ............................ Is a diverter system required ....................................... Are necessary diagrams of diverter and BOP equipment attached ....... Does BOPE lmve suf£icient pressure rating - Test to ~,~-~D psig ..~7~ -- Does the choke manifold comply w/API RP-53 (Feb.78) .................. /~7- Is the presence of H2S gas probable .................................. ~-~ Additional requirements ............. , ............................... Additional Remarks :,, ~.~/.~ -3/~-~ ~3I~1 ~ ~.,~-',F~D/~7 2/~-~ (6) Add: Geology: JAL Engineering: ,.cs rev: 03/13/85 6.011 INITIAL 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. j N i T 0!2, = t,7... ..... ] E :' T S ? 2': ,:-' T 3 5 , !.5, :).} :* '4 '".: _ -':' :i 2 .5 '4 5 7 m, . ? :! 7 3 . .5 5 7 :, . i ? ,! L . 77 73 2 2 T ::~ L ) 3,3 '* ''~ O O 0 3 O '2, :3 :~', :; ') O ' ~' ,'" .. ,,,, .. · ::! 0 J ? 0 O ,., ~., 3 u .} :7," ,,,,u '] :'1 '"' 0 ?, ': 0 0 ;., ~ ,... n ] 3 3 ":' ~, '..~ 0 0,3 0 9 9 ,} O 0 O 0 ,:~00 .6272 .4~'?~ ,~ 2 "..,' . : 5 5 9 ~51 2 5 9 0 5 2 } 7' 2, % l 55 i._ 3' !c. :37 '~, 3 - } ~9 . 25 O0 - }?9.25O3 - } 7S', ~ 5:30 - g ~?. l:; u u -9 g '-:;, .. 2 5 () '3 3. 3327 - ;'., .¢o ':. i.) ',.; ' ,,_ -3,:~. i I 3 3 3.4., ,:,; ',.') .':, !t4 R i',i R ,l 2. ~553 ..37!5 !500 25 O O - Y, { ?. 25 f) O -9 ~ 9.2503 -:3 ....... " '3 0 -999.2500 3.6 0 '7 7 ~,, I 0.:! ~ 3 1 0.0 :; ! 0 S P -] :7.i_(:t. 2--< L C', :} :.. ? :'.? i.._ x ' · ]7~,.} q'it" }}':',,2~?, ] "z -'9 ':-) 9 ,,, 2 '5 } 0 - :'~ '..':~ } ,, .::t 5 (} ,'ii -}~?· 25'7,? t. ':? 7 Z } I C. ~ ~ 7 9 -9'}'9. Z -O0 - :} q' ;:, 3, 5 ''~,., :0 3 7.2 6 i 7 U7,3742