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HomeMy WebLinkAbout190-012 • no- V2, k kCo MAY 06 2U1u WELL LOG TRANSMITTAL#903098217 To: Alaska Oil and Gas Conservation Comm. April 28, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 ~� DATA LOGGED Anchorage, Alaska 99501 5/0.1201G M K.BENDER tED RE: Multi Finger Caliper: 2K-25 `otwi Run Date: 3/2/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2K-25 Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-103-20124-00 Multi Finger Caliper(Field Log) 1 color log 50-103-20124-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed:P3X12- 6.60'-.'"C to‘0-or2 • 2:0(0 WELL LOG TRANSMITTAL#903088888 To: Alaska Oil and Gas Conservation Comm. April 27, 2016 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 RECEIVED Anchorage, Alaska 99501 DATA LOGGED APR i2o , NPR 2 9 2V�i 1a �.9iBENDE�R RE: Perforation Record&Jewelry Log: 2K-25 Run Date: 2/24/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2K-25 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-029-20124-00 Perforation Record&Jewelry Log (Field Print) 1 color log 50-029-20124-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 SCANNED' w Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: / - ,,ctLR.4-44L, ,/ STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon I....... Plug Perforations f Fracture Stimulate E Pull Tubing P Operations Shutdown la Performed: Suspend F", Perforate if.i Other Stimulate fl Alter Casing F_., Change Approved Program P Plug for Redrill P Perforate New Pool Repair Well P Re-enter Susp Well F 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ',I Exploratory 190-012 3.Address: 6.API Number: Stratigraphic - Service P. O. Box 100360,Anchorage, Alaska 99510 50-103-20124-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25605 KRU 2K-25 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): NONE Kuparuk River Field/Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 10264 feet Plugs(measured) None true vertical 6539 feet Junk(measured) None Effective Depth measured 10230 feet Packer(measured) 7576 true vertical 6518 feet (true vertical) 4884 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 115 115 SURFACE 4047 9 5/8 4082 2918 PRODUCTION 2286 7 2319 1928 PRODUCTION 7914 7 10230 6518 LINER 4 1/2"RVA 2562 4 1/2 10127 6453 Perforation depth: Measured depth: 9918'-9938', 9860'-9880' RECEIVE L True Vertical Depth: 6321'-6333', 6285'-6297' scow JUN 2 4 2016`. APR 2 0 2016 sco Tubing(size,grade, MD,and TVD) 3 1/2, L-80, 7604 MD, 4900 TVD AOGCC Packers&SSSV(type, MD,and TVD) PACKER-2RH ZXP Liner Top Packer @ 7576 MD and 4884 TVD V SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): None Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut-in Subsequent to operation Shut-in 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Exploratory i....... Development F Service Stratigraphic I• Daily Report of Well Operations F;;" P Y Copies of Logs and Surveys Run I- 16.Well Status after work: Oil ,. Gas I- WDSPL 1- Printed and Electronic Fracture Stimulation Data 1 GSTOR P WINJ (` WAG 7 GINJ l ... SUSP SPLUG I- 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-072 Contact R. Phillips 265-6312 Email Ron.L.Phillips a(�conocophillips.com Printed Name Ron Phillips Title Senior CTD Engineer Signature (Rep, 2 Phone:263-4612 Date /aO/10^DO -g\ Form 10-404 Revised 5/2015' 5)91g. Submit Original Only TA/7k RBDMS 1_L APR 2 1 2016 • 2K-25 • DTTM:JOBTYP SUMMARYOPS 2/17 DRILLING (PRE-CTD) TREE VALVE TEST (COMPLETE) SUPPORT- CAPITAL 2/19 DRILLING RIH WITH FCO BHA, TAG AT 9909' CTMD, COULD NOT MAKE ANY HOLE. COME OUT OF HOLE SUPPORT- PICK UP MOTOR AND MILL, MILL DOWN TO 9963' RKB, CONFIRM WITH TOWN ENGINEER CAPITAL THAT THIS DEPTH WILL BE OKAY FOR WHIPSTOCK. ****FREEZE PROTECT WELL*** READY FOR ELINE 2/21 DRILLING GAUGE TBG TO 2.87"TO 7535' RKB, TAG CEMENT @ 9921' SLM, DRIFT w/2.625"X 23.25' DMY SUPPORT- PEFF GUN DRIFT TO 9920' SLM, NO ISSUES ENCOUNTERED, READY FOR ELINE CAPITAL 2/24 DRILLING PERFROM JEWELRY LOG FROM TAG AT 9950' TO 7400'. PERFORATE INTERVALS 9918'-9938' SUPPORT- AND 9860'-9880' USING 2.5" HSC LOADED 6 SPF, PHASED 60 DEG, 11.1 GM MILLENNIUM II HMX CAPITAL CHARGES. LOGS CORRELATED TO HES PET CEMENT LOG DATED 14 FEB 1990 AT 9632' K1 MARKER. READY FOR LRS. 2/29 DRILLING ATTEMPTED CALIPER LOG AND SBHP. DID NOT COMPLETE CALIPER LOG DUE TO ISSUES SUPPORT- WITH DEPTH AQUISITION SYSTEM AND DETERIORATING WEATHER. JOB IN PROGRESS. CAPITAL 3/2 DRILLING LOGGED TWO PASSES FROM 9950' TO 9300' WITH A 24 ARM CALIPER. FOUND EVIDENCE OF SUPPORT- A CEMENT SHEATH BELOW 9880'. READY FOR CTU CLEANOUT. CAPITAL 3/5 DRILLING Prep for move to 2K-Pad. Move CDR2 to 2K-25. MIRU, spot rig modules and shop. SIDETRACK 3/6 DRILLING Finish post rig move checklist. Perform initial BOPE test. Test surface lines and PDL's. Pulled TWC. SIDETRACK MU/PD BHA#1. 3/7 DRILLING RIH w/ BHA#1 Baker underreamer assembly, down ream from 9,850' to 9,950'. POOH for whipstck, SIDETRACK PUD BHA#1, PD BHA#2. RIH w/Whipstock assembly, set WS @ 9,932' TOWS @ 9,920'. POOH. PUD BHA#2, PD BHA#3. RIH w/window milling assembly, dry tag pinch point @ 9,924'. Displace to used 8.6 ppg FloPro. Start time milling window, in progress. i --' KUPD 2K-25 ConocoPhillips Well Attribut Max Angle D TD Alaska.Inc Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Corw03:KMlinips501032012400 KUPARUK RIVER UNIT PROD 57.91 3,300.00 10,264.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2K-25 4/20/20167:22:44 AM SSSV:NONE Last WO: 1/31/2016 40.09 1/26/1990 Vertical schemahcj?clual) - Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER.,31.1 Last Tag:SLM 9,647.0 2/7/2016 Rev Reason:Add Laterals;GLV C/O lehallf 4/8/2016 -S1. �) Casing Strings ;044; Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread 1,1141 LI CONDUCTOR 16 15.062 35.0 115.0 115.0 62.50 H-40 WELDED ;k4 J Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade 'Top Thread 4 ,A SURFACE 95/8 8.765 35.0 4,082.1 2,918.5 36.00 J-55 BTC 4 iA1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WtlLen(I...Grade Top Thread 4: (y A PRODUCTION 7"Tie 7 6.276 33.0 2,319.0 1,927.6 26.00 L-80 Hydril 563 4I Ii back RWO 2016 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread +i PRODUCTION 7 6.276 2,316.0 10230.1 6,518.0 26.00 J-55 BTC 44 Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...'Wi/Len(I...Grade Top Thread ) 10, LINER 41/2"RWO 2016 4 1/2 4.000 7.565.1 10,127.0 6,453.1 11.60 L-80 IBTM +; Liner Details M CONDUCTOR;35.0-115.0A.11_n.41 14,11 li 11, Nominal ID 1 Top(ftKB) Top)TVD)(ftKB) Top Incl(°I Item Des Com (in) I2. 7,565.1 4,877.8 54.96 SLEEVE 2RH ZXP wtih HD Liner Top Packer(11.54'tie back 5.250 sleeve) w i� 7,576.6 4,884.4 54.93 PACKER 2RH ZXP wtih HD Liner Top Packer(11.54'tie back 4310 PRODUCTION r Tb back 0I sleeve) RW02016;33.0-2,319.0 7,583.7 4,888.5 54.91 HANGER Double Grip Flex Lock Liner Hanger 4.390 iti 7,593.5 4,894.1 54.88 SBE Seal Bore Extension,5"TKC Pin x 5"BTC Pin 4.000 GAS LIFT;3,308.2 g., 7,612.7 4,905.2 54.64 XO Reducing Crossover Sub,5"BTCM Box x 4-1/2"IBT Pin 3.930 10,096.2 6,433.7 50.69 COLLAR Float Collar,Weatherford,4-1/2",12.6#,L-80,IBTM 2.000 Box x Pin • ! : Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(IbW) Grade Top Connection SURFACE;35.0-4,oe2.t�A TUBING RWO 2016 I 31/21 2.9921 31.11 7,604.21 4,900. 31 9.301L- 80 IEUE 8rdMod Completion Details GAS LIFT;5,287.411 TOP(ftKB) Top(TVD)(ftKB) Top Incl nItem Des Corn No(in)I ID II 31.1 31.1 0.07 HANGER Cameron Tubing Hanger,CXS,7-1/16"x 3-1/2"EUE 8rd 2.920 Box x Box,3"H BPVG 1Ai 1111 7,518.7-' 4,851.2 55.10 NIPPLE Nipple,HES,2.813"X,SN: 11X28127 2.812 GAS LIFT;6,703.8 = 7,568.2- 4,879.5 54.95 LOCATOR Locator Sub,GHB-22(bottom of locator spaced out 7.29') 2.990 7,569.3 4,880.2 54.95 SEAL ASSY Seal Assembly,80-40 2.990 Perforations&Slots GAS LIFT;7,4576 4.; Shot fif Top(NBtm D) (NDens (sD) hots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 9,778.0 9,792.0 6,234.5 6,243.1 C-4,2K-25 12/9/1993 6.0 APERF 2 1/8"EnerJet;90 deg. NIPPLE,7.518.7 Ph 9,860.0 9,880.0 6,284.9 6,297.3 A-4,2K-25 2/24/2016 6.0 APERF 2.5";60 deg.Phasing Millenium II charges) 9,860.0 9,880.0 6,284.9 6,297.3 A-5,2K-25 12/9/1993 6.0 APERF 21/8"EnerJet;90 deg. PH 9,912.0 9,948.0' 6,317.1 6,339.6 A-4,2K-25 5/17/1990 4.0 IPERF 4.5"HLS CSG Guns;180 LOCATOR 7.568.2 deg.Ph 'R.;to 9,918.0 9,938.0 6,320.9 6,333.4 A-4,2K-25 2/24/2016 6.0 APERF 2.5";60 deg.Phasing Millenium II charges) SEAL ASSY,7 569.3 iI), (l, 9,918.0 9,944.0 6,320.9 6,337.1 A-4,2K-25 11/20/1993 3.0 RPERF 2 1/8"EnerJet;Oriented ,kl rA 45 deg.CW Al Wing a Cement Squeezes T Top(ND) Btm(TVD) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com33.0 2,319.0 33.0 1,927.6 Cement 7"x 1/16/2016 9.625"Annulus f/2,319-ft tosurface7,576.0 10,127.0 4,884.0 6,453.1 Liner Cement '1/27/2016 PT cement line to 250/5000 psi(goodtest). Pump 15 19 bbls 14.5 ppg mud push at 3 BPM=1700 psi followed APERF,9,660.0-9,880.0 by 64 bbls 15.8 ppg cement at 3 BPM=1600 psi,drop the dart, and chase with 10 bbls of fresh water. Swap to the pumps,dace the DP th 11.1 ppg brine at 5 BPM=3300 psi,slow pumps to 3 BPM=2300 psi,and bumped the plugs at 3200 psi. Check the float andrig the Float is holding.isplSwapwito SLB cementers, O pressure up 4800 psi to set the liner hanger,and set ` r down 50K to ensure liner hanger is set. PU 65K and SLOTS;9,915.0-13,269.0 r y.. rotate 15 turns to the right with 4K ft-lbs free torque at Whipstock,9,921.0 *it 140K hook load to release the liner runningtool. Bring L1-01 LINER;9,814.7-13270.0, '.. w _ the pumpon line at 3 BPM=1570 psi and4 BPM= APERF;8,918.0-9938.0^ M %y `It.y 1900 psi. Pull packoff and dog sub out.Circulate 40 r 5 bbls to clear any cement off the top of the liner top y packer then slow the pumps to 2 BPM=1200 psi.SO es, oli ;y 80K to set the ZXP liner top packer(saw indicating SA #y shear),PU,and set down 80K again. PU,rotate at 15 7.• RPM=5K ft-lbs free torque,SO 50K,stop the rotary, 1. d and PU off ZXP liner top packer. P. %j,- `_I %. /a Mandrel Inserts ri St ti on Top(ND) Valve Latch Port Size TRO Run ti Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com LINER 412'RWO 2016; 7,565.1-10,127.0 1 3,308.2 2,494.6 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,285.0 3/27/2016 I I 2 5,287.4 3,598.5 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,265.0 3/27/2016 3 6,703.8 4,386.8 Camco MMG 1 1/2 GAS LIFT GLV RK 0.188 1,245.0 3/27/2016 4 7,457.6 4,816.3 Camco MMG 1 1/2 GAS LIFT OV RKP 0.250 0.0 3/26/2016 PRODUCTION;2,316.0- 10,230.1 KUPD a 2K-25 Cono€oPhillips o''''' Rask 1.In. CoegcoPhSlips •-• 2K-25,4/20/2016 7:22:45 AM Medical achernabc(actual) HANGER;31.1 Tliii. Notes:General&Safety I I 11 End Date Annotation I it NOTE S` ��CONDUCTOR,350-115.0 / 4 --." ti r' PRODUCTION T T.back g R R W O 2016;33.0-2,319 0 GAS LIFT;3,308.2LI: SURFACE;35.0-4,062.1- GAS LIFT;5,287.4 Vit- GAS LIFT;6,703.8 4 GAS LIFT 7,457.6 3 4 NIPPLE 7,5187 -!j',. LOCATOR,7,568.2 SEAL ASSY,7,569.3 I•1 4.•111 ilituinviitimilvl y. `L' APERF;9,860.0.9,880.0 /�/��� ' A.f i kyd5 ,:e,,,,::::, SLOTS;9,915.0-13,288 0 le...,,,, 889914 k;9,921.0 +y, L1-01 LINER;9,914.7-13,2700 APERF;9,918.0-9,938.0-. .;`,11 'I r X o.i E LINER 4 7?RWO 201 7,565.1-10,127.0 0 PRODUCTION;2,316.0- 10,230.1 • • PTD lgd — D / Z Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) n55vc.e Sent: Tuesday, February 23, 2016 8:45 AM ' ' „„n , Irj,n q To: 'Beat, Andrew T' \ Subject: RE: PTD 190-012a V t h fva I I y to) r Fr-cI(plan d' i —o5 i From: Beat, Andrew T[mailto:Andrew.T.Beat Uconocophillips.com] Sent: Tuesday, February 09, 2016 1:11 PM 2 K-75.4-1 To: Loepp, Victoria T(DOA) 1-1 — e2 Subject: RE: PTD 190-012 Ll _0 2 Victoria, VTL 7.12-3 is The 'Plug for Redrill' box was checked after submission for this sundry and I think that is the cause of the confusion.The cemented liner that we installed during the workover was not intended to plug the well so I think checking that box is incorrect. Without that box checked,we have a standard 403 which requires the basic 404 after completion,correct? Thanks, Andrew From: Loepp, Victoria T(DOA) [mailto:victoria.loeppCa�alaska.gov] Sent: Monday, February 08, 2016 3:19 PM To: Beat, Andrew T Subject: [EXTERNAL]Re: PTD 190-012 Andrew, This appears to be a plug for redrill. If you are abandoning a well bore than a 10-407 is required. Let me know if you still have questions. Thanx, Victoria On Feb 8, 2016, at 3:12 PM, Beat, Andrew T<Andrew.T.Beat@conocophillips.com> wrote: Victoria, I would like some clarification on the sundry approval for 2K-25.The approval we received noted that a 10-407 was required after completing the workover. My understanding is that 404's are required after workovers and 407's are reserved for the completion of the CTD work. We did not do an completing or recompleting during the workover so the 407 doesn't seem as applicable as the 404. If you could give me some guidance on this I would appreciate it. Thank you, 1 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil❑ Gas III SPLUG ❑ Other ❑ Abandoned ❑ SuspendedR• 1b.Well Class: 20AAC 25.105 20FAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ❑ WAG❑ WDSPL❑ No.of Completions: Service 0 Stratigraphic Test ❑ 2.Operator Name: 6. Date Comp(Susp,,or 14. Permit to Drill Number/ Sundry: ConocoPhillips Alaska, Inc. Aband.: 1/30/2016 190-012/315-713 3.Address: 7. Date Spudded: 15.API Number: P.O. Box 100360 Anchorage,AK 99510-0360 1/18/1990 50-103-20124-00 ' 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16.Well Name and Number: Surface: 369'FNL, 95'FEL,Sec 11,T1ON, R8E, UM 1/25/1990 KRU 2K-25 Top of Productive Interval: 9. Ref Elevations: KW 194' 17. Field/Pool(s): 782'FNL, 1153'FEL,Sec 13,T1ON, R8E, UM GL: 1154 BF:AKuparuk River Field/Kuparuk River Oil Pool Total Depth: 10. Plug Back Depth MD/TVD: 18. Property Designation: 1121'FNL,982'FEL, Sec 13,T1ON, R8E UM 9656 MD/6159 ADL 25605 • 4b. Location of Well(State Base Plane Coordinates, NAD 27): 11.Total Depth MD/TVD: 19. Land Use Permit: Surface: x- 498310 y- 5937935 Zone- 4 10264 MD/6539 TVD 2679 TPI: x- 502534 y- 5932243 Zone- 4 12. SSSV Depth MD/TVD: 20.Thickness of Permafrost MD/TVD: Total Depth: x- 502705 y- 5931904 Zone- 4 n/a 1400'MD/1379'TVD 5. Directional or Inclination Survey: Yes ❑ (attached) No (] 13.Water Depth, if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 n/a (ft MSL) n/a 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion, suspension,or abandonment,whichever occurs first.Types of logs to be listed include, but are not limited to: mud log,spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance,dipmeter,formation tester,temperature,cement evaluation, casing collar locator,jewelry, and perforation record. Acronyms may be used.Attach a separate page if necessary RECEUVEL none FEB 2 2 2016 AOGCC 23. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD FT PULLED 16 62.5 H-40 35 115 35 115 24 191 sx AS II 9.625 36 J-55 35 4082 35 2918 12.25 1300 sx AS III,450 sx Class G 7 26 L-80 33 2319 33 1927 8.5 1008 sx 15.7 ppg AS1 7 26 J-55 2316 10230 1926 6518 8.5 300 sx Class G 4 1/2 11.6 L-80 7565 10127 4878 6453 6.276 309 sx Class G 24.Open to production or injection? Yes ❑ No 0 25.TUBING RECORD If Yes, list each interval open(MD/TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3 1/2 7620 7565/4878 perf cemented off se JUN 0 0 2016 26.ACID, FRACTURE, CEMENT SQUEEZE, ETC. Ll�� Was hydraulic fracturing used during completion? Yes❑ No 1. Per 20 AAC 25.283(i)(2)attach electronic and printed information DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED cement retainer@9656 20.9 bbls 15.8 ppg Class G 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing, gas lift, etc.): Plugged Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period - Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate -► Form 10-407 Revised 11/2015 vrt- 57g/16- CONTINUEDPAGE 2 bmit ORIGINIALV' lJ ,,', ff/ , itg. sl7) ' 20 6 c� � RBDMS FEB 2 3 • • 28. CORE DATA Conventional Core(s): Yes ❑ No E Sidewall Cores: Yes ❑ No 0 If Yes, list formations and intervals cored(MD/TVD, From/To), and summarize lithology and presence of oil,gas or water(submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No 0 Permafrost-Top Surface Surface If yes, list intervals and formations tested, briefly summarizing test results. Permafrost-Base 1400 1379 Attach separate pages to this form, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. not applicable Formation at total depth: not applicable 31. List of Attachments: Summary of Daily Operations, Schematic, Cement Report Information to be attached includes, but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, Paleontological report,production or well test results,per 20 AAC 25.070. 32. I hereby certify that the foregoing is tru a d correct to the best of my knowledge. Contact: Andrew Beat @ 265-6341 Email: Andrew.T.Beat@cop.com Printed Name: G.L. Alvord Title: Alaska Drilling Manager I / Signature: (=. .` Phone: 265-6120 Date: 2 1 f 6 12'i I INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed.All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item la: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b: Well Class-Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection, Salt Water Disposal,Water Supply for Injection, Observation, or Other. Item 4b: TPI(Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level,and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment,whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs,and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability,fluid saturation,fluid composition,fluid fluorescence,vitrinite reflectance,geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey, and other tests as required including,but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only S ll]nii " Cement Detail Report &weins 2K-25 ConocoPhilijps String: Liner Cement Job: RECOMPLETION, 12/30/2015 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Liner Cement 1/27/2016 18:00 1/27/2016 18:45 2K-25 Comment PT cement line to 250/5000 psi(good test). Pump 15 bbls 14.5 ppg mud push at 3 BPM= 1700 psi followed by 64 bbls 15.8 ppg cement at 3 BPM= 1600 psi, drop the dart, and chase with 10 bbls of fresh water. Swap to the rig pumps,displace the DP with 11.1 ppg brine at 5 BPM=3300 psi,slow pumps to 3 BPM= 2300 psi,and bumped the plugs at 3200 psi. Check the float and the float is holding. Swap to SLB cementers, pressure up 4800 psi to set the liner hanger,and set down 50K to ensure liner hanger is set. PU 65K and rotate 15 turns to the right with 4K ft-lbs free torque at 140K hook load to release the liner running tool. Bring the pump on line at 3 BPM= 1570 psi and 4 BPM= 1900 psi. Pull packoff and dog sub out. Circulate 40 bbls to clear any cement off the top of the liner top packer then slow the pumps to 2 BPM= 1200 psi. SO 80K to set the ZXP liner top packer(saw indicating shear), PU,and set down 80K again. PU,rotate at 15 RPM=5K ft-lbs free torque,SO 50K,stop the rotary,and PU off ZXP liner top packer. Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement... Top Plug? Btm Plug? Liner Cement 7,565.1 10,127.0 Yes 3.0 Yes No Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 3 3 3 1,750.0 3,200.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment PT cement line to 250/5000 psi(good test). Pump 15 bbls 14.5 ppg mud push at 3 BPM= 1700 psi followed by 64 bbls 15.8 ppg cement at 3 BPM= 1600 psi, drop the dart, and chase with 10 bbls of fresh water. Swap to the rig pumps,displace the DP with 11.1 ppg brine at 5 BPM=3300 psi,slow pumps to 3 BPM= 2300 psi,and bumped the plugs at 3200 psi. Check the float and the float is holding. Swap to SLB cementers,pressure up 4800 psi to set the liner hanger,and set down 50K to ensure liner hanger is set. PU 65K and rotate 15 turns to the right with 4K ft-lbs free torque at 140K hook load to release the liner running tool. Bring the pump on line at 3 BPM= 1570 psi and 4 BPM= 1900 psi. Pull packoff and dog sub out. Circulate 40 bbls to clear any cement off the top of the liner top packer then slow the pumps to 2 BPM= 1200 psi. SO 80K to set the ZXP liner top packer(saw indicating shear), PU,and set down 80K again. PU,rotate at 15 RPM=5K ft-lbs free torque,SO 50K,stop the rotary,and PU off ZXP liner top packer. Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Production Cement 7,565.0 10,127.0 309 G 64.0 Yield(fF/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.16 5.09 15.80 0.00 Additives Additive Type Concentration Conc Unit label Antifoam 0.2 %BWOC Additive Type Concentration Conc Unit label Dispersant 0.3 %BWOC Additive Type Concentration Conc Unit label Fluid Loss Control 0.4 %BWOC Additive Type Concentration Conc Unit label Retarder 0.02 gal/sx Page 1/1 Report Printed: 2/18/2016 • Cement Detail Report �.� T1s 2K-25 ConocoPhillips String: Cement 7"x 9.625"Annulus f/2,319-ft t... Job: RECOMPLETION, 12/30/2015 00:00 Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Cement 7"x 9.625"Annulus f/2,319-ft to surface 1/16/2016 00:00 1/16/2016 03:30 2K-25 Comment Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement...Top Plug? Btm Plug? 15.7 ppg AS1 Neat+ Cement 7"x 9.625" 33.0 2,319.0 No 0.0 No No Pressure Net Annulus f/2,319-ft to surface Q Pump mit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 3 1 2 573.0 3,500.0 No No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Casing Leak Repair 33.0 2,304.6 1,008 AS1 158.2 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1 (psi) 1.17 5.25 15.70 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 2/18/2016 • II" '4:0 •,',- P� Operations Summary (with Timelog Depths) 0 2K-25 concxcit imps ' Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time : Our(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(ftKS), 12/30/2015 12/30/2015 4.50 MIRU MOVE MOB P Rig down and load shop and office. 00:00 04:30 Pull pit module and pipe shed away form Rig sub.Move to 2K Pad. 12/30/2015 12/30/2015 5.50 MIRU MOVE MOB P Lay down the derrick,pull the sub off 04:30 10:00 of well and clean around well. 12/30/2015 12/30/2015 10.00 MIRU MOVE MOB P Move Rig From 2U Pad to 2K Pad. 10:00 20:00 Pulled onto 2K Pad at 20:00 hrs. 12/30/2015 12/31/2015 4.00 MIRU MOVE MOB P Stage Rig to raise the derrick.Lay out 20:00 00:00 herculite and place wellhead equipment and Tree in the cellar.Spot Rig over 2K-25 and connect the pit module and pipe shed. 12/31/2015 12/31/2015 9.00 MIRU MOVE RURD P Stage rig over 2K-25 and lay out 00:00 09:00 herculite in the cellar.Hang Tree and wellhead equipment.Make-up pipe shed and Pit module to the rig.Raise the derrick and rig down the bridle lines.Load seawater into the pits. Rig accepted 08:00 hrs. 12/31/2015 12/31/2015 4.00 MIRU WHDBOP NUND P Take pictures of Tree orientation. 09:00 13:00 Nipple-down Tree and inspect threads.(threads good). Install blanking plug for BOP test. 12/31/2015 12/31/2015 3.00 MIRU WHDBOP NUND P Nipple-up DSA and BOP's. Install test 13:00 16:00 equipment and pick-up test joint. 12/31/2015 1/1/2016 8.00 MIRU WHDBOP BOPE P Test BOP's and choke manifold 16:00 00:00 250/4,000 psi with 2 7/8"and 4 1/2" pipe.Annular Preventer tested to 2,500 psi.2 TIW floor valves failed the high pressure test and were replaced with a new one.(good test).Lower VBR's failed high pressure test.Install new VBR's. 1/1/2016 1/1/2016 9.50 MIRU WHDBOP RGRP T Test BOP's and choke manifold 00:00 09:30 250/4,000 psi with 2 7/8"and 4 1/2" pipe.Annular Preventer tested to 2,500 psi.2 TIW floor valves failed the high pressure test and were replaced with a new one.Retest 250/4,000 psi, good test. Lower VBR's failed high pressure test.Install new VBR's.Test 250/4,000 psi,good test.CMV#11 failed high pressure test.Grease and retest 250/4,000 psi,good test. 1/1/2016 1/1/2016 0.50 MIRU WHDBOP BOPE P Performed AOGCC and CPAI 09:30 10:00 Koomey test,all good.AOGCC witness of test waived by Johnnie Hill, AOGCC Rep. 1/1/2016 1/1/2016 1.00 MIRU WHDBOP RURD P R/D BOP test equipment and rig-up to 10:00 11:00 pull blanking plug and BPPV. 1/1/2016 1/1/2016 2.00 MIRU WHDBOP MPSP P Pull blanking plug and BPV. 11:00 13:00 1/1/2016 1/1/2016 0.50 COMPZN RPCOMP PULL P Pull Hanger free at 50K,continue 9,620.0 9,620.0 13:00 13:30 pulling to 150K and work pipe. 1/1/2016 1/1/2016 1.00 COMPZN RPCOMP RURD P Lay down 10'pup and R/U circulating 9,620.0 9,620.0 13:30 14:30 equipment. Page 1/28 Report Printed: 2/18/2016 • 0 Operations Summary (with Timelog Depths) r fiilii zit';''' 2 K-25 Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (EK€E) End Depth(EKE) 1/1/2016 1/1/2016 3.00 COMPZN RPCOMP CIRC P Pump Freeze Protect from well. Pump 9,620.0 9,620.0 14:30 17:30 15 bbls of seawter down the IA at 2 bpm.Pump down the Tubing at 3 bpm to clear diesel in the IA.Continue trying to free tubing.Work pipe from 50K SOW to 150K PUW. 1/1/2016 1/2/2016 6.50 COMPZN RPCOMP 'WAIT T Call out HES to cut tubing Pump 9,620.0 9,620.0 17:30 00:00 polymer pill to slick hole up.Continue to work pipe free. 1/2/2016 1/2/2016 2.50 COMPZN RPCOMP WAIT T Wait on HES and continue to work 9,620.0 9,620.0 00:00 02:30 pipe.50K SOW, 150K PUW.Put 30K intension on string and set the slips. 1/2/2016 1/2/2016 4.50 COMPZN RPCOMP ELNE P R/U HES E-line equipment and String 9,620.0 9,620.0 02:30 07:00 shot. 1/2/2016 1/2/2016 2.00 COMPZN RPCOMP ELNE P RIH with String shot to 9566'WLM, 9,620.0 9,620.0 07:00 09:00 correlate depth and fire String shot, POOH. 1/2/2016 1/2/2016 1.00 COMPZN RPCOMP ELNE P Change out E-line tools/String shot to 9,620.0 9,620.0 09:00 10:00 RCT cutter. 1/2/2016 1/2/2016 3.00 COMPZN RPCOMP ELNE T RIH with RCT cutter to 9,566'WLM, 9,620.0 9,620.0 10:00 13:00 and correlate depth.Tools hung up, fired Jars shorting out tools. POOH to trouble shoot problem. 1/2/2016 1/2/2016 2.50 COMPZN RPCOMP ELNE P RIH with RCT cutter to 9,535'WLM, 9,620.0 9,535.0 13:00 15:30 correlate depth and fire RCT cutter. Indication of good cut, POOH. 1/2/2016 1/2/2016 1.00 COMPZN RPCOMP ELNE P R/D E-line tools and clear the floor. 9,535.0 9,535.0 15:30 16:30 1/2/2016 1/2/2016 1.00 COMPZN RPCOMP PULL P Pull the Hanger to the floor. R/U GBR 9,535.0 9,535.0 16:30 17:30 and L/D the Hanger and Landing joint, PUW 90. 1/2/2016 1/3/2016 6.50 COMPZN RPCOMP PULL P POOH and single down 2 7/8"tubing 9,535.0 7,730.0 17:30 00:00 and control line.(Recovered 29 bands) 1/3/2016 1/3/2016 5.50 COMPZN RPCOMP PULL P Single down 2 7/8"tubing.Recovered 7,730.0 0.0 00:00 05:30 1 cut joint,5 GLM's, 1 SSSV and 29 bands.Corrosion on collars started on joint 225-298.Holes in joints 243-260. Cement on joints 280-298. 1/3/2016 1/3/2016 0.50 COMPZN RPCOMP SVRG P Service TD and daily inspection of rig. 0.0 0.0 05:30 06:00 1/3/2016 1/3/2016 3.50 COMPZN RPCOMP BHAH P P/U BHA#1,Washover assembly. 0.0 377.0 06:00 09:30 377',PUW 42K,SOW 42K. 1/3/2016 1/3/2016 1.00 COMPZN RPCOMP PULD P P/U 3 1/2"HT-40 DP.Tagged buckled 377.0 738.0 09:30 10:30 casing at 738'. 1/3/2016 1/3/2016 0.50 COMPZN RPCOMP TRIP X POOH, PUW 60K,SOW 42K. 738.0 377.0 10:30 11:00 1/3/2016 1/3/2016 1.00 COMPZN RPCOMP BHAH X L/D BHA#1 377.0 0.0 11:00 12:00 1/3/2016 1/3/2016 2.00 COMPZN RPCOMP TRIP X RIH with Mule shoe and drill collars to 0.0 283.0 12:00 14:00 734'.Push pipe down to 765',SOW 10 -15K.Pull up to 283'and prep to run Storm packer. 1/3/2016 1/3/2016 1.50 PROD1 WELLPR MPSP X P/U Storm packer and set at 107' 283.0 390.0 14:00 15:30 1/3/2016 1/3/2016 1.50 PROD1 WELLPR NUND X N/D BOP stack. 390.0 390.0 15:30 17:00 Page 2/28 Report Printed: 2/18/2016 • a Operations Summary (with Timelog Depths) ss itar 1''1 2 K-25 .f;:.,a Phifllp €,k.. Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time.: End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKS) End Depth(WE)' 1/3/2016 1/3/2016 5.00 PROD1 WELLPR CUTP X Remove 7"pack-off.Spear 7"and 390.0 390.0 17:00 22:00 stretch it.Pull 10K,no movement. Started seeing movement at 100K. Pull 160K with 7 inches of stretch. Pull 195K with 11 inches of stretch,slips would not clear casing spool. Consulted with CPAI engineer. Pulled 215K and slips cleared spool. Remove slips and installed new 7"slips. Slacked weight off of casing to 180k to activate slips.Release Spear from casing. 1/3/2016 1/4/2016 2.00 PROD1 WELLPR CUTP X Cut 7"off 1'.Install pack-offs and run 390.0 390.0 22:00 00:00 in lock down screws.nipple-up Cameron"C"Bowl spool.Test spool to 3000 psi. Install test plug and run in lock down screws. 1/4/2016 1/4/2016 1.50 PROD1 WELLPR CUTP X Cut 7"casing, 1'of stick up. Install 390.0 390.0 00:00 01:30 pack-off and new tubing head and test.3,000 psi/10 minutes. 1/4/2016 1/4/2016 2.00 PROD1 WELLPR NUND X N/U BOP's,and prep for BOP test. 390.0 390.0 01:30 03:30 1/4/2016 1/4/2016 1.50 PROD1 WELLPR BOPE X Test the break on BOP stack 390.0 390.0 03:30 05:00 1/4/2016 1/4/2016 1.00 PROD1 WELLPR BOPE X R/D test equipment and pull test pllug. 390.0 390.0 05:00 06:00 1/4/2016 1/4/2016 1.00 PROD1 WELLPR MPSP X Release and pull Storm packer. 390.0 283.0 06:00 07:00 1/4/2016 1/4/2016 1.00 PROD1 WELLPR TRIP X RIH with Bull nose to 739'.Push down 283.0 0.0 07:00 08:00 to 75'0',NO GO,POOH. 1/4/2016 1/4/2016 3.00 PROD1 WELLPR TRIP X RIH with Bul nose assembly to 1,511', 1,511.0 0.0 08:00 11:00 POOH. PUW 55K,SOW 50K 1/4/2016 1/4/2016 1.00 PROD1 WELLPR BHAH X P/U BHA#4,6"Drag tooth shoe 0.0 128.0 11:00 12:00 assembly. 1/4/2016 1/4/2016 1.00 PROD1 WELLPR TRIP X RIH to 733',PUW 42K,set down 10K. 128.0 737.0 12:00 13:00 P/U and work pipe down to 737'.Set down 12K,NO GO. 1/4/2016 1/4/2016 1.00 PROD1 WELLPR BHAH X POOH and LID BHA#4. 737.0 0.0 13:00 14:00 1/4/2016 1/4/2016 1.00 PROD1 WELLPR ELNE X R/U Dutch riser for E-line work. 0.0 0.0 14:00 15:00 1/4/2016 1/4/2016 0.50 PROD1 WELLPR SVRG X Perform daily service on rig. 0.0 0.0 15:00 15:30 1/4/2016 1/4/2016 6.50 PROD1 WELLPR WAIT X Wait on E-line 0.0 0.0 15:30 22:00 1/4/2016 1/5/2016 2.00 PROD1 WELLPR ELNE X R/U HES and run a 4 3/4"Gauge ring. 0.0 0.0 22:00 00:00 1/5/2016 1/5/2016 15.00 PROD1 WELLPR ELNE X Run E-line 4 3/4"Gauge ring through 0.0 0.0 00:00 15:00 buckled casing,all good.RIH with CBL,TOC©2380 ft. Caliper log.Damage©726'-746 ft. RIH with 3 3/8"IBP and set at 2910 ft. POOH and RD Eline and Dutch riser 1/5/2016 1/5/2016 3.00 PROD1 WELLPR TRIP X Pick up drill pipe with bull nose on 0.0 2,804.0 15:00 18:00 bottom. 3K drag thru 739 ft 1/5/2016 1/6/2016 6.00 PROD1 WELLPR CIRC X Dump approx 70 ft of sand on top of 2,804.0 2,710.0 18:00 00:00 IBP @ 2910 ft Pull 1 std of drill pipe 1/6/2016 1/6/2016 1.50 PROD1 WELLPR SLPC X Slip and cut drilling line. 2,710.0 2,710.0 00:00 01:30 Page 3/28 Report Printed: 2/18/2016 ,,� 0 • , ,,, „ Operations Summary (with Timelog Depths) 2K-25 Phillips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time ', End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation {ftKB) End Depth(ftKB)I 1/6/2016 1/6/2016 0.50 PROD1 WELLPR OTHR X Tagged Sand at 2820 ft Flushed drill 2,710.0 2,820.0 01:30 02:00 pipe. 1/6/2016 1/6/2016 1.00 PROD1 WELLPR TRIP X POOH with drill pipe. 2,820.0 0.0 02:00 03:00 1/6/2016 1/6/2016 0.50 PROD1 CSGRCY BHAH X Pick up BHA#5.Muti string cutter 0.0 188.0 03:00 03:30 assembly. 1/6/2016 1/6/2016 1.25 PROD1 CSGRCY TRIP X RIH with cutter. Unable to get past 188.0 738.0 03:30 04:45 738 ft with 5 1/2"cutter.max sat on cutter= 10 K 1/6/2016 1/6/2016 1.25 PROD1 CSGRCY TRIP XT POOH with BHA#5 738.0 0.0 04:45 06:00 1/6/2016 1/6/2016 1.50 PROD1 CSGRCY TRIP XT RIH with BHA#6 4.5"Multi cutter 0.0 2,340.0 06:00 07:30 assembly.5 K down drag thru 739 ft. 1/6/2016 1/6/2016 2.00 PROD1 CSGRCY CUTP X Lacted collars at 2340 ft and 2299 ft. 2,340.0 2,315.0 07:30 09:30 Made cut at 2315 ft.communication to OA 1/6/2016 1/6/2016 1.00 PROD1 CSGRCY CIRC X Pumped 45 BBL deep clean pill, 2,315.0 2,315.0 09:30 10:30 displaced with 24 BBLs of 140°sea water. @ 2 BPM @ 940 psi.out OA port. 1/6/2016 1/6/2016 1.00 PROD1 CSGRCY WAIT X Let deep clean pill set to break down 2,315.0 2,315.0 10:30 11:30 Artic pack 1/6/2016 1/6/2016 3.50 PROD1 CSGRCY CIRC X Circulated 262 of 140°sea water 2,315.0 2,315.0 11:30 15:00 around OA @ 3 BPM @ 1200 PSI. 1/6/2016 1/6/2016 1.50 PROD1 CSGRCY TRIP X POOH with BHA#6 2,315.0 0.0 15:00 16:30 1/6/2016 1/6/2016 6.00 PROD1 CSGRCY NUND X Removed lines and ND BOPE and 0.0 0.0 16:30 22:30 Tbg spool. Install adaptor spool on stack. 1/6/2016 1/7/2016 1.50 PROD1 CSGRCY PULL X Speared 7"casing pulled free at 170K. 0.0 0.0 22:30 00:00 Up wt=120 K.Removed E slips 1/7/2016 1/7/2016 2.00 PROD1 CSGRCY NUND X NU BOPE stack. 0.0 00:00 02:00 1/7/2016 1/7/2016 0.50 PROD1 CSGRCY BOPE X Shell test BOPE to 500 psi.with a 02:00 02:30 rolling test @ 1.5 BPM 1/7/2016 1/7/2016 1.50 PROD1 CSGRCY PULL X PJSM:POOH laying down 7"casing 02:30 04:00 Up WT.=106K Moved up hole with casing to 2284 ft.31 ft of free movement. Cal stretch=740 ft to sticking point.2.5"of stretch with 60 K over pull. 1/7/2016 1/7/2016 0.50 PROD1 CSGRCY OTHR XT Attempted to set casing back down 04:00 04:30 dropped 10 ft back in hole and stacked. 1/7/2016 1/7/2016 0.50 PROD1 CSGRCY CIRC XT Circulated bottoms up @ 8 BPM at 04:30 05:00 275 psi.Got back sand and artic pack. 1/7/2016 1/7/2016 0.50 PROD1 CSGRCY OTHR XT Dropped casing back to 2313 ft setting 05:00 05:30 some TD weight on it.Released spear.and laid it down 1/7/2016 1/7/2016 0.50 PROD1 CSGRCY SVRG XT Service rig and cleared rig floor. 05:30 06:00 1/7/2016 1/7/2016 1.50 PROD1 CSGRCY TRIP XT RIH with BHA#8,5.5"Muti string 0.0 737.0 06:00 07:30 cutter Page 4/28 Report Printed: 2/18/2016 rY r • 0 Operations Summary (with Timelog Depths) *t2K-25 Conaitliprs Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hi) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/7/2016 1/7/2016 0.50 PROD1 CSGRCY CPBO XT Located collars @ 686 ft and 725 ft. 737.0 706.0 07:30 08:00 Positioned cutter at 706 ft.Engaged pump at 2.5 BPM @ 200 PSI.Made cut as per Baker. RPM's @ 80, F/TQ @ FT/LB's Increased pumps to 4.5 BPM @ 620 PSI Torque fell off and pump pressure decreased.good indication of cut. 1/7/2016 1/7/2016 0.50 PROD1 CSGRCY TRIP XT POOH with BHA#8 706.0 0.0 08:00 08:30 1/7/2016 1/7/2016 1.00 PROD1 CSGRCY -FISH XT Engaged spear assembly. PU to 100 0.0 706.0 08:30 09:30 K worked casing up to 135K and pulled free. 1/7/2016 1/7/2016 1.00 PROD1 CSGRCY CIRC XT Circulated 150 BBLs of sea water @ 6 706.0 706.0 09:30 10:30 BPM @ 100 psi. 1/7/2016 1/7/2016 3.00 PROD1 CSGRCY PULL X POOH with spear and casing laying 706.0 0.0 10:30 13:30 down. Recovered 679.30 ft of 7" casing Top of cut at 706.00 with KB added. 1/7/2016 1/7/2016 3.00 PROD1 CSGRCY BHAH XT Laid down 4 3/4 drill collors. Pick up 0.0 219.0 13:30 16:30 BHA#10 5 3/4"Itco spear assembly. and 6"drill collars 1/7/2016 1/7/2016 1.50 PROD1 CSGRCY TRIP XT RIH with BHA#10 219.0 706.0 16:30 18:00 1/7/2016 1/7/2016 1.00 PROD1 CSGRCY JAR XT Engaged spear in 7"casing stump at 706.0 718.0 18:00 19:00 706 ft Up wt=54 K Down=50 K.Up Wt with fish 106 K spear depth of 718 ft. Free travel of casing of 31 ft. before it would become hung. Began working jars @ 200 K 100 over combined string wt.and pulling to 255 K.Hit jars 14 times with out any movement of the casing. Pushed casing back down. 1/7/2016 1/7/2016 1.00 PROD1 CSGRCY SFTY XT Complete post jarring inspection while 718.0 718.0 19:00 20:00 discussing next move with town Engr. 1/7/2016 1/7/2016 0.50 PROD1 CSGRCY TRIP XT Released spear assembly and POOH 718.0 219.0 20:00 20:30 with BHA#10 1/7/2016 1/7/2016 2.00 PROD1 CSGRCY BHAH XT Swap out BHA*10 to 11.4.5"Muti 219.0 189.0 20:30 22:30 string cutter 1/7/2016 1/7/2016 0.50 PROD1 CSGRCY TRIP XT RIH with BHA#11 189.0 706.0 22:30 23:00 1/7/2016 1/8/2016 1.00 PROD1 CSGRCY TRIP XT Attempt to get cutter in 7"with out 706.0 706.0 23:00 00:00 success. Sat up to 10 K down on nose and rotated 5-10 RPMs trying to roll in. Attempted to bounce in while rotating. 1/8/2016 1/8/2016 1.00 PROD1 CSGRCY TRIP XT POOH with cutter 706.0 0.0 00:00 01:00 1/8/2016 1/8/2016 0.50 PROD1 CSGRCY TRIP XT RIH with 3.5 mule shoe on drill pipe 0.0 744.0 01:00 01:30 went right in 7"no issues. 1/8/2016 1/8/2016 0.50 PROD1 CSGRCY TRIP XT POOH with drill pipe 744.0 0.0 01:30 02:00 1/8/2016 1/8/2016 2.00 PROD1 CSGRCY WAIT XT Service and clean while waiting on 0.0 02:00 04:00 cross over from Baker 1/8/2016 1/8/2016 1.00 PROD1 CSGRCY TRIP XT RIH with BHA*12:4.5"Multi cutter 0.0 706.0 04:00 05:00 with 5 ft X 3.5"Mule shoe guide Page 5/28 Report Printed: 2/18/2016 1 x Operations Summary (with Timelog Depths) #0 1 'i , v . 2K-25 ..P1ilhps ,T Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (EKE) End.Depth(ftKB). 1/8/2016 1/8/2016 1.00 PROD1 CSGRCY CPBO X Slid into 7"casing stump at 706 ft with 706.0 763.5 05:00 06:00 mule guided 4.5"multi string cutter. located first collar below damage at 738 ft.picked up 2 ft made cut.@ 763.5 ft EST.circulation at 1BPM @ 280 psi. FTQ @ 80 RPM= 1143 FT/LB Engaged torque= 1260 psi. 1/8/2016 1/8/2016 1.50 PROD1 CSGRCY TRIP X POOH with BHA#12 763.5 0.0 06:00 07:30 1/8/2016 1/8/2016 1.00 PROD1 CSGRCY BHAH X RIH with BHA#13 Spear assembly 0.0 219.0 07:30 08:30 1/8/2016 1/8/2016 0.50 PROD1 CSGRCY SVRG X Service and inspect TD 219.0 219.0 08:30 09:00 1/8/2016 1/8/2016 0.50 PROD1 CSGRCY TRIP X RIH with BHA#13. 219.0 706.0 09:00 09:30 1/8/2016 1/8/2016 0.50 PROD1 CSGRCY FISH X Engaged spear to stop.@ 717.0.Up 706.0 717.0 09:30 10:00 Wt=45K.Pulled free at 65 K.and drug up to 80 K Thru 738 ft. 1/8/2016 1/8/2016 0.50 PROD1 CSGRCY TRIP X POOH with BHA#13 and fish 717.0 219.0 10:00 10:30 1/8/2016 1/8/2016 2.50 PROD1 CSGRCY BHAH X Stood back BHA and laid down 7' 219.0 0.0 10:30 13:00 Casing Recovered 57.5 ft of 7" Total 7 7"recovered=736.8 ft.762.8 ft TOF. 1/8/2016 1/8/2016 2.00 PROD1 CSGRCY BHAH X Picked up BHA#14:8 3/8"string mill 0.0 278.0 13:00 15:00 assembly with 53 ft of 3.5 Mule shoe below. 1/8/2016 1/8/2016 0.50 PROD1 CSGRCY TRIP X RIH with mill assembly Tagged @ 727 278.0 778.0 15:00 15:30 ft. 1/8/2016 1/8/2016 8.00 PROD1 CSGRCY MILL X With Mill Pick up to 723 ft Est 778.0 793.0 15:30 23:30 parameters. Est Circulation @ 5 BPM @ 115 psi. F/TQ @ 1200 FT/LBs @ 70 RPM Got torque increase at 725 ft. 1.8 to 2.5 FT/LBs. Began milling operations @ 725 ft. with 2-3 K on mill.Milling Torque @ 4- 5.5 K Ft/LBs Torque dropped off to 1200 Ft/LB's Circulated clean. 1/8/2016 1/9/2016 0.50 PROD1 CSGRCY TRIP X POOH with BHA#14 793.0 291.0 23:30 00:00 1/9/2016 1/9/2016 0.50 PROD1 CSGRCY BHAH XT Continue to POOH with BHA#14. 291.0 0.0 00:00 00:30 Lost the double pin crossover and mule shoe assembly. Recovered pin end from mill box.Just hanging in the box. 1/9/2016 1/9/2016 4.50 PROD1 CSGRCY WAIT XT Wait on over shot from Dead Horse. 0.0 0.0 00:30 05:00 1/9/2016 1/9/2016 1.00 PROD1 CSGRCY BHAH XT Make up 8 1/8"Bowen overshot with 6 0.0 209.0 05:00 06:00 3/8 graple. BHA#15 1/9/2016 1/9/2016 1.50 PROD1 CSGRCY TRIP XT RIH with BHA#15.Tight spots @ 731 209.0 740.0 06:00 07:30 -36 ft 5 K down drag.Sat down soild at 740 ft with 6K down Unable to get past 740 ft. 1/9/2016 1/9/2016 0.50 PROD1 CSGRCY TRIP XT POOH with BHA#15 740.0 226.0 07:30 08:00 Page 6/28 Report Printed: 2/18/2016 , .;„4--,,, ,,, ,t.14,-, Operations Summary (with Timelog Depths) s c hitii Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Der(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End,Depth(ftKB)'. 1/9/2016 1/9/2016 0.50 PROD1 CSGRCY BHAH XT Make up BHA#16;4 3/4 W flex its. 226.0 226.0 08:00 08:30 drift assembly 1/9/2016 1/9/2016 1.50 PROD1 CSGRCY TRIP XT RIH with BHA#16.Tagged©745 ft. 226.0 760.0 08:30 10:00 Up wt=52 K down wt=54 K.set 14 down wt pushed thru 745'5-10 K drag pushed to 758 ft solid tag with 15K on it. 1/9/2016 1/9/2016 0.50 PROD1 CSGRCY TRIP XT POOH Up wt.=65 K draging thru tight 760.0 0.0 10:00 10:30 area.52 K out. 1/9/2016 1/9/2016 0.50 PROD1 CSGRCY BHAH XT Make up BHA#17;milling assembly. 0.0 226.0 10:30 11:00 1/9/2016 1/9/2016 0.50 PROD1 CSGRCY TRIP XT RIH with BHA#17. 226.0 733.0 11:00 11:30 1/9/2016 1/10/2016 12.50 PROD1 CSGRCY MILL XT Est parameters;Circulation rate of 733.0 745.5 11:30 00:00 6BPM @ 130 psi. F/TQ©60 RPM's= 1100 FT/LB's Began milling operations from730 ft with 1-3 K wieght on mill. 1/10/2016 1/10/2016 14.50 PROD1 CSGRCY MILL XT Continue to mill with 8 1/2"mill 745.5 750.0 00:00 14:30 assembly.Torque©2.8-3.4 K FT/ LB's @ 70 RPM's W/1.3 K weight on mill.Checked milled area 1-2 K up drag while rotating.slid down 2-3 K at 743.5 to 746'continue milling operations 1/10/2016 1/10/2016 0.50 PROD1 CSGRCY TRIP XT POOH with BHA#17 750.0 232.0 14:30 15:00 1/10/2016 1/10/2016 1.50 PROD1 CSGRCY BHAH XT Swap out BHA#17. Mill showed light 232.0 189.8 15:00 16:30 wear and shoulder building on bottom of Mill area..Pick up BHA#18 8 1/8" Bowen 150 overshot. 1/10/2016 1/10/2016 0.50 PROD1 CSGRCY TRIP XT RIH with BHA#18. 189.8 630.0 16:30 17:00 1/10/2016 1/10/2016 1.50 PROD1 CSGRCY FISH XT Tagged at 750 ft worked overshot to 630.0 762.0 17:00 18:30 756'With circulation at 7BPM @ 150 Psi.Circulated over TOF©760.0 ft Pressure increase of 70 psi.Sat 15 on fish. 1/10/2016 1/10/2016 0.50 PROD1 CSGRCY TRIP XT POOH with BHA#18.Recovered 762.0 0.0 18:30 19:00 crossovers and 2.66 ft of the top jt on the mule shoe assembly. 1/10/2016 1/10/2016 2.00 PROD1 CSGRCY BHAH XT Changed out BHA assembly to#19;5 0.0 219.0 19:00 21:00 3/4"spear assembly 1/10/2016 1/10/2016 1.00 PROD1 CSGRCY FISH XT Had to push spear assembly from 748 219.0 759.0 21:00 22:00 ft to 759'Bull nose with 5-15 K down wt.Got stop to 748' with 18K on unable to get it thru bad spot. 1/10/2016 1/10/2016 1.00 PROD1 CSGRCY TRIP XT POOH with BHA#19 759.0 237.0 22:00 23:00 1/10/2016 1/11/2016 1.00 PROD1 CSGRCY BHAH XT Reconfigure BHA#20 with 1 jt of drill 237.0 255.0 23:00 00:00 pipe between spear and bumper sub 1/11/2016 1/11/2016 0.50 PROD1 CSGRCY BHAH XT Continue to adjust BHA#20 with a jt 0.0 255.0 00:00 00:30 of drill pip[e between Spear and Bumper sub. 1/11/2016 1/11/2016 0.50 PROD1 CSGRCY TRIP XT RIH with BHA#20 255.0 760.0 00:30 01:00 1/11/2016 1/11/2016 0.50 PROD1 CSGRCY FISH X Engaged fish. Up wt=90 K Pulled 25 760.0 766.0 01:00 01:30 over at 740 ft.worked casing past. Page 7/28 Report Printed: 2/18/2016 • • Operations Summary (with Timelog Depths) 2K-25 ocoY'hitI pss Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth '..Start Time`° End Time Dur(hr) Phase Op Code Activity Code.. Time P-T-X Operation (EKE) End Depth(ftKB) 1/11/2016 1/11/2016 1.50 PROD1 CSGRCY TRIP X POOH w/BHA#20 and 7"fish. 766.0 0.0 01:30 03:00 1/11/2016 1/11/2016 1.00 PROD1 CSGRCY RURD X PJSM:RU Handling equipment for 7" 0.0 0.0 03:00 04:00 casing 1/11/2016 1/11/2016 4.50 PROD1 CSGRCY PULL X Lay down 7"Casing 1,550.0 0.0 04:00 08:30 1/11/2016 1/11/2016 1.50 PROD1 CSGRCY .BHAH X Pick up BHA#21:5 3/4"Overshot 0.0 237.0 08:30 10:00 assembly 1/11/2016 1/11/2016 4.00 PROD1 CSGRCY TRIP X RIH with BHA#21.worked past 741 237.0 2,776.0 10:00 14:00 thru 750 ft damage.Rotated down @ 10 RPM's @ 1300 FT/LB's Torque. Sat down @ 2330 ft with 5 K pulled heavy.Broke circulation @ 7 BPM @ 400 psi,.Contnue to circculate down to 2776 ft TOF. 1/11/2016 1/11/2016 0.50 PROD1 CSGRCY FISH X Attempted to engaage fish at 2776 ft 2,776.0 2,780.0 14:00 14:30 pushed down to 2780 ft with 7 K as per Baker. 1/11/2016 1/11/2016 3.00 PROD1 CSGRCY TRIP X POOH with BHA#21.No recovery. 2,780.0 0.0 14:30 17:30 Overshot full of gravel/mud pack. 1/11/2016 1/11/2016 4.50 PROD1 CSGRCY TRIP X RIH with BHA#22:Overshot 0.0 2,690.0 17:30 22:00 assembly with Ext added. 1/11/2016 1/11/2016 1.00 PROD1 CSGRCY FISH X Attempted to engage fish.3.5 drill pipe 2,690.0 2,787.0 22:00 23:00 at 2780 ft worked down to 2787 ft appeared to push down thru sand plug at 2820 ft with tail.with 10 K down wt. 1/11/2016 1/12/2016 1.00 PROD1 CSGRCY TRIP X POOH with BHA#22 2,787.0 1,300.0 23:00 00:00 1/12/2016 1/12/2016 2.50 PROD1 CASING TRIP XT Continue to POOH with BHA#22. No 1,300.0 0.0 00:00 02:30 fish recovered OS full of milling junk. 1/12/2016 1/12/2016 0.50 PROD1 CASING SVRG X Service and inspect Top drive 0.0 0.0 02:30 03:00 1/12/2016 1/12/2016 1.00 PROD1 CASING BHAH XT Make up BHA#23:5 3/4 RC junk 0.0 238.0 03:00 04:00 basket assembly 1/12/2016 1/12/2016 2.00 PROD1 CASING TRIP XT RIH with BHA#23 238.0 2,695.0 04:00 06:00 1/12/2016 1/12/2016 1.00 PROD1 CASING OTHR XT Attempted to est circulation with junk 2,695.0 2,785.5 06:00 07:00 basket.3 BPM @ 1300 psi.jets where plug at the start of circulation. No ball in DP.Tagged at 2784 ft worked basket down to 2785.5 ft. 1/12/2016 1/12/2016 1.50 PROD1 CASING TRIP XT POOH with BHA#23.recovered a 2,785.5 238.0 07:00 08:30 cup of gravel and metal 1/12/2016 1/12/2016 3.50 PROD1 CASING BHAH XT Change out BHA assemblies from 238.0 248.0 08:30 12:00 RCJB to 5 3/4"overshot with saw tooth wash shoe bottom. 1/12/2016 1/12/2016 2.00 PROD1 CASING TRIP XT RIH with BHA#24:Worked thru 248.0 2,706.0 12:00 14:00 damage at 740 ft continue to RIH to 2706.0 ft.Up wt=69 K down wt=60 K 1/12/2016 1/12/2016 2.00 PROD1 CASING FISH XT Est parameters.Circulation at 6 BPM 2,706.0 2,804.0 14:00 16:00 @ 300 psi.F/TQ @ 40 RPM's 2K.65 RWT.Tagged at 2787 ft with 10K down pressure spiked and fell off. Chased to 2804 ft with 15K down. 1/12/2016 1/12/2016 1.00 PROD1 CASING TRIP XT POOH with BHA#24. 2,804.0 248.0 16:00 17:00 Page 8/28 Report Printed: 2/18/2016 • • ` '' '-- Operations Summary (with Timelog Depths) rat. 2K-25 Oanocc;Phillilpis Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code. Time P-T-X Operation (MKS) End,Depth(MKS)', 1/12/2016 1/12/2016 3.50 PROD1 CASING BHAH XT Laid down BHA#24. No Recovery. 248.0 255.0 17:00 20:30 Pick up BHA#25.6"X 4 3/4 wash shoe assembly. 1/12/2016 1/12/2016 1.00 PROD1 CASING TRIP XT RIH with BHA#25, 255.0 780.0 20:30 21:30 1/12/2016 1/12/2016 0.50 PROD1 CASING SVRG XT Service and inspect Top drive 2,650.0 21:30 22:00 1/12/2016 1/12/2016 1.00 PROD1 CASING RGRP XT Replace/remove blower hose on TD 780.0 780.0 22:00 23:00 1/12/2016 1/13/2016 1.00 PROD1 CASING TRIP XT Continue to RIH with BHA#25 780.0 2,525.0 23:00 00:00 1/13/2016 1/13/2016 0.50 PROD1 CASING TRIP X Continue to RIH with BHA#25 2,525.0 2,708.0 00:00 00:30 1/13/2016 1/13/2016 1.00 PROD1 CASING SVRG X Service equipment/Install new blower 2,708.0 2,708.0 00:30 01:30 hose. 1/13/2016 1/13/2016 3.00 PROD1 CASING REAM X Tagged up at 2801 ft with 3 K Broke 2,708.0 2,813.0 01:30 04:30 circulation at 3 BPM @ 170 psi..F/TQ 2100 Ft/Lb's @ 50 RPM's worked shoe to 2813 ft No real wt change or pump.2813'set down with 3 K TOF at 2803 ft Circulated clean.Getting back sand. 1/13/2016 1/13/2016 1.50 PROD1 CASING TRIP X POOH with BHA#25 2,813.0 255.0 04:30 06:00 1/13/2016 1/13/2016 3.00 PROD1 CASING BHAH X Swapped out BHA#25 to 26 5 3/4" 255.0 251.0 06:00 09:00 overshot with 7 ft of swallow. 1/13/2016 1/13/2016 1.50 PROD1 CASING TRIP X RIH with BHA#26.Up wt=69K, 251.0 2,740.0 09:00 10:30 down wt=60 K 1/13/2016 1/13/2016 0.50 PROD1 CASING FISH X Est parameters.F/TQ @ 20 RPM's= 2,740.0 2,740.0 10:30 11:00 2000 FT/LB's.Circulation at 3 BPM @ 170 psi,5 BPM @ 280 psi,7 BPM @ 420 psi.Engaged fish with 3-5 K down wt.Pushed to 2816 ft.with 15 K to fully engage grapple.pulled up to 1740 ft. 1/13/2016 1/13/2016 1.50 PROD1 CASING TRIP X POOH with BHA#26. 2,740.0 251.0 11:00 12:30 1/13/2016 1/13/2016 2.50 PROD1 CASING BHAH X Laid down BHA#26.Recovered 3.5 251.0 0.0 12:30 15:00 Mule shoe assembly. 16 ft.tail plugged with sand. 1/13/2016 1/13/2016 2.50 PROD1 CASING BHAH X Pick up BHA#27;8 1/2"milling 0.0 233.0 15:00 17:30 assembly 1/13/2016 1/13/2016 1.00 PROD1 CASING TRIP X RIH with BHA#27. 233.0 720.0 17:30 18:30 1/13/2016 1/13/2016 4.00 PROD1 CASING MILL X Est parameters; Up Wt=50 K,Down 720.0 790.0 18:30 22:30 wt=52 K,Rotation wt=50 K F/TQ @ 40 RPM's @ 1200 Ft/LB's. Circulating©3BPM @ 100 psi. Reamed down from 720 ft to 748 1-2 K TQ. 1 K on mill.Increased RPM's to 60 working mill over ledge @ 748-53 ft.2-3 K on mill.pump rate at 6 BPM @ 150 psi. continue to work mill to 765 ft.reamed area 3 times 730-765.Slid mill down to 765 pull back up BS hung up at 733 ft.reamed down to 790 ft no issues. rotated out with BS above 720 ft. 1/13/2016 1/13/2016 0.50 PROD1 CASING TRIP X POOH with BHA#27 790.0 233.0 22:30 23:00 Page 9/28 Report Printed: 2/18/2016 • • ,a ate! A � 44, ,, ` ,1.. m4 , Operations Summary (with Timelog Depths) 4 ®® � 2K-25 ConomPhrmim �4 r�. Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr),, Phase Op Code .,;Activity Code Time P-T-X Operation (ftKS) End Depth(ftKB) 1/13/2016 1/14/2016 1.00 PROD1 CASING BHAH X Added 8 1/2 mill to BHA #28.and 233.0 23:00 00:00 remove BS. 1/14/2016 1/14/2016 1.00 PROD1 CASING TRIP X RIH with BHA#28.Tandem 8 1/2 230.0 720.0 00:00 01:00 milling assembly 1/14/2016 1/14/2016 3.75 PROD1 CASING MILL X EST parameters.up wt=50 K,down 720.0 790.0 01:00 04:45 wt.=52 K circulation @ 6 BPM @ 140 psi.TQ @ 65 RPM's @ 1240 FT/LB's worked mill assembly from 725 thru 790 ft.slid thru @ 3-4 Down wt. 1/14/2016 1/14/2016 0.50 PROD1 CASING SVRG X Service and inspect Top drive 790.0 700.0 04:45 05:15 1/14/2016 1/14/2016 0.75 PROD1 CASING TRIP X POOH with BHA#28 @ 230-ft 700.0 230.0 05:15 06:00 1/14/2016 1/14/2016 1.50 PROD1 CASING BHAH X POOH with BHA#28 and found 230.0 230.0 06:00 07:30 Minimal wear on upper 8-1/2"Mill. Break out Upper mill to replace with 8- 3/4"OD string mill and RIH to 230-ft with BHA#29 1/14/2016 1/14/2016 0.50 PROD1 CASING TRIP X RIH w/BHA#29 to 591-ft and set 230.0 702.0 07:30 08:00 down 5k with the 8-3/4"Mill,push thru @ 15k and continue to RIH to 702-ft. 1/14/2016 1/14/2016 3.50 PROD1 CASING MILL X Gather Parameters:Up wt-53K,Dn 702.0 755.0 08:00 11:30 wt-53K and 53K Rot wt.@ 60 RPM w/Free torque of 1.3K. Circulating @ 7 BPM @ 150 psi. Locate tight spot at 733-ft with 8-3/4"Mill,work thru to 735 -ft with 1K WOM and 2.6K TQ. Cleaned up to zero wt on mill and 1.8K TQ by third pass. Continue to RIH and set down @ 748-ft with upper 8-3/4"String mill-5K, PU to 710-ft and begin working mills thru tight spot from 748-ft to 753-ft @ w/1K WOM @ 2.6K TQ on 1st pass and no WOM and 1.4K TQ on passes 2 and 3. No Rot.slide thru at 2K. POOH and work area from 591-ft to 593-ft after pulling 10K osw. Able to slide thru all milled areas 591-593-ft,733-735-ft and 748- 753-ft @ 2K max down wt. 1/14/2016 1/14/2016 1.25 PROD1 CASING TRIP X Continue to RIH w/BHA#29 from 755.0 2,274.0 11:30 12:45 755-ft to 2,274-ft and set down 20K. 1/14/2016 1/14/2016 0.25 PROD1 CASING REAM X Wash down,rotating @ 61 RPM's @ 2,274.0 2,315.0 12:45 13:00 3.1K and fell off to 2.8K Free Torque while circulating @ 6 bpm @ 350 psi. Locate top of 7"Casing stump @ 2,315-ft 1/14/2016 1/14/2016 1.00 PROD1 CASING CIRC X Circulate 318 bbls @ 10 bpm @ 540 2,315.0 2,306.0 13:00 14:00 psi. 1/14/2016 1/14/2016 1.50 PROD1 CASING TRIP X POOH with Bha#29 2,306.0 230.0 14:00 15:30 1/14/2016 1/14/2016 1.00 PROD1 CASING BHAH X Broke down BHA 29. 230.0 0.0 15:30 16:30 1/14/2016 1/14/2016 0.50 PROD1 CASING SVRG X Service and inspect TD 0.0 0.0 16:30 17:00 1/14/2016 1/14/2016 1.50 PROD1 CASING BHAH X Made up BHA#30;sizing shoe with 8 0.0 222.0 17:00 18:30 1/2 string mill assembly Page 10/28 Report Printed: 2/18/2016 t • • R', ' Operations Summary (with Timelog Depths) x 64W _ 2K-25 Co oc.o himii�}. >3exk:> Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth ''.Start Time v End Time Our(hr) Phase OP Dade Activity Code Time P-T-X Operation (#KB) End Depth(ftKB)'. 1/14/2016 1/14/2016 1.00 PROD1 CASING TRIP X RIH with BHA#30:attempted to get 222.0 749.0 18:30 19:30 past 749 ft shoe unsuccessfully.with mutable attempts. 1/14/2016 1/14/2016 0.50 PROD1 CASING TRIP X POOH with shoe assembly.BHA#30 749.0 223.0 19:30 20:00 1/14/2016 1/14/2016 1.50 PROD1 CASING BHAH X Change out BHA#30 to 31 8 3/4X 8 223.0 230.0 20:00 21:30 1/2"stacked milling assembly.with out flex jt between. 1/14/2016 1/14/2016 0.50 PROD1 CASING TRIP X RIH with BHA#31 230.0 720.0 21:30 22:00 1/14/2016 1/15/2016 2.00 PROD1 CASING MILL X Continue to dress up 9 5/8 casing 720.0 766.0 22:00 00:00 from 730 ft thru 760 ft. Parameters:F/TQ @ 1100 FT/LB's Circulation rate @ 7 BPM @ 170 psi. Milling torque @ 13-16K @ 71 RPMs 1/15/2016 1/15/2016 1.50 PROD1 CASING MILL X Continue to dress up 9 5/8 casing. 12- 766.0 778.0 00:00 01:30 1500 fUlb's torque.slid thru 778 ft 1-23 Drag both directions 1/15/2016 1/15/2016 0.50 PROD1 CASING TRIP X POOH with BHA#31 778.0 232.0 01:30 02:00 1/15/2016 1/15/2016 2.00 PROD1 CASING BHAH X Swap out BHA 31 to 32 Sizing shoe 232.0 216.0 02:00 04:00 assembly 1/15/2016 1/15/2016 1.50 PROD1 CASING TRIP X RIH with BHA#32.Sizing mill 216.0 2,296.0 04:00 05:30 assembly.worked past 749 ft with shoe.continue to RIH. 1/15/2016 1/15/2016 2.50 PROD1 CASING MILL X Est parameters,Circulation @ 7 BPM 2,296.0 2,316.0 05:30 08:00 @ 330 psi.F/TQ @ 10 RPM's @ 2.5 K FULB's Slide over stump @ 2315. Increased RPM's to 60 3.5-4.5 Torque with 2-3 K on mill. Mill down to 2316 ft>back reamed off stump.slid over stump.Clean.Circulated clean @ 10 BPM @ 520 psi. 1/15/2016 1/15/2016 1.50 PROD1 CASING TRIP X POOH with BHA#32. 2,316.0 216.0 08:00 09:30 1/15/2016 1/15/2016 2.50 PROD1 CASING BHAH X Lay down BHA and HW drill pipe. 216.0 0.0 09:30 12:00 Clear floor. 1/15/2016 1/15/2016 2.00 PROD1 CASING WWWH X Jet stack 0.0 0.0 12:00 14:00 1/15/2016 1/15/2016 1.50 PROD1 CASING RURD X RU casing equipment.Load cement 0.0 0.0 14:00 15:30 head and stabilizers 1/15/2016 1/15/2016 6.50 PROD1 CASING PUTB X Pick up 7"Hydril 563 casing with 0.0 2,318.0 15:30 22:00 Bowen patch and HES.ES cementer in place. Up wt 80 K/down wt=75 K. Engaged Patch assembly and setWith 100 K pull test.54 Jts and 15 ft pup. 53-7"x 8-1/4"Straight Rigid Centralizers 1/15/2016 1/16/2016 2.00 PROD1 CASING PRTS X Installed HES cement head.Plug 2,318.0 2,318.0 22:00 00:00 install witnessed by Both Co-man, Tool pusher. Pressure tested casing tie back to 1000 psi for 5 min's.Opened ES cementer @ 3320 psi.circulated 20 bbl's of sea water at 3 BPM @ 190 psi. Held PJSM with all hands. Page 11/28 Report Printed: 2/18/2016 • Operations Summary (with Timelog Depths) 2K-25 c: inips ,, Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB)' 1/16/2016 1/16/2016 4.00 PROD1 CEMENT CMNT X RU Schlumberger cementer.. 2,318.0 2,318.0 00:00 04:00 PT line to 4800 psi. Pumped 5 BBL fresh water. PT lines to 4800 psi. MX/Pump. 10 BBLs AS-1 neat 137.9 BBLs AS-1 pressure net.Note Closed in rams With 150 total displacement 8 BBIs neat.dropped plug. 4 BBL's neat 5 BBLs fresh. Displaced with 43 away 100 psi well head pressure.@ 3 BPM slowed rate to 1.5 BPM @ 450 psi with 49 BBL's displaced No return. @ 77 BBIs displaced @ 475 Psi slowed rate to 1 BPM.still no returns to surface. Latched ES plug and closed @ 1850 psi. Cement in place @ 03:15 hrs Attempted to pump down IA to clear cement for top squeeze.pressured up to 1180 psi. Check surface lines.Plug in line to cutting tank.Flushed well to kill tank. 1/16/2016 1/16/2016 0.50 PROD1 CEMENT RURD X RD cement head and cementers. 2,318.0 0.0 04:00 04:30 1/16/2016 1/16/2016 1.00 PROD1 WELLPR NUND X ND BOPE stack.check cement depth. 0.0 0.0 04:30 05:30 6 ft identified.cement depth. 1/16/2016 1/16/2016 2.00 PROD1 WELLPR WWSP X Set 7"x 11"FMC emergency slips, 0.0 0.0 05:30 07:30 pour 10 gallons of cement into the annulus and displace water through the slips to fill void to surface with cement. Cut casing. Pull 24.80-ft of the 42.75-ft joint,Set BOPE and install FMC packoff. 1/16/2016 1/16/2016 1.00 PROD1 WELLPR NUND X NU Cameron 11"3M x 7-1/16"5M 0.0 0.0 07:30 08:30 TBG spool. 1/16/2016 1/16/2016 0.50 PROD1 WELLPR WWSP X Pressure test the Inner Casing Packoff 0.0 0.0 08:30 09:00 to 3,000 psi for 10 minutes-good test. 1/16/2016 1/16/2016 4.50 PROD1 WELLPR NUND X Install 7-1/16 5M x 13-5/8 5M DSA 0.0 0.0 09:00 13:30 and 13-5/8 5M BOP stack. Install riser and tie back stack and center same. 1/16/2016 1/16/2016 1.50 PROD1 WELLPR BOPE X Remove 7"Rams from lower cavities 0.0 0.0 13:30 15:00 and replace with 2-7/8 x 5"VBR's. 1/16/2016 1/16/2016 4.00 PROD1 WHDBOP RURD X Clean and clear cellar area of un- 0.0 0.0 15:00 19:00 needeed equipment and prepare for weekly BOP test. 1/16/2016 1/17/2016 5.00 PROD1 WHDBOP BOPE X Test BOPE stack 250/4000 psi. 0.0 0.0 19:00 00:00 Test witnessed by Chuck Scheve AOGCC Test with 3.5"&4.5"test Jts. 1/17/2016 1/17/2016 4.00 PROD1 WHDBOP BOPE X Continue to test BOPE 250/4000 psi 0.0 0.0 00:00 04:00 with 3.5&4.5 Test joints. RD test equipment 1/17/2016 1/17/2016 0.50 PROD1 WHDBOP RURD X Pull test plug and install wear ring. 0.0 0.0 04:00 04:30 Page 12/28 Report Printed: 2/18/2016 i 0 _` a 4 Operations Summary (with Timelog Depths) °S2K-25 Phatgps Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr)', Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/17/2016 1/17/2016 1.00 PROD1 WELLPR BHAH X Make up BHA#33;6-1/8"Drilling 0.0 219.0 04:30 05:30 assembly to 219-ft 1/17/2016 1/17/2016 1.50 PROD1 WELLPR TRIP X RIH w/BHA#33 to 2,110-ft 68K Up 219.0 2,110.0 05:30 07:00 wt,58K Dn wt 1/17/2016 1/17/2016 4.50 PROD1 WELLPR DRLG X Obtain drilling parameters: 2,110.0 2,319.0 07:00 11:30 SPR's P#1 P#2 2 Bpm 80 PSI 130 PSI 3 Bpm 80 PSI 130 PSI ROT Wt 60K @ 60 RPM's W/1.9K Free TQ,Circulating 6 BPM @ 385 PSI Wash down from 2,110-ft to 2,150-ft. Drill out Cement from 2,150-ft thru Wiper plug at 2,302-ft and past tie back at 2,319-ft @ 60 RPM's w/2.4K TQ circulating @ 8 bpm 580 psi. 1/17/2016 1/17/2016 0.50 PROD1 WELLPR CIRC X Circulate Bottoms up @ 10 bpm @ 2,319.0 2,319.0 11:30 12:00 950 psi while reciprocating and rotating @ 60 rpm's. 1/17/2016 1/17/2016 0.50 PROD1 WELLPR TRIP X RIH/w to 2,463-ft and set down. 2,319.0 2,463.0 12:00 12:30 1/17/2016 1/17/2016 2.75 PROD1 WELLPR REAM X Wash down from 2,463-ft to 2,835-ft 2,463.0 2,835.0 12:30 15:15 while rotating at 60 rpm's @ 2.4K TQ and circulating @ 8 bpm @ 725 psi. Recovering Pressure net and cement over the shakers. Tag Sand at 2,835- ft and Increase PR to 10 bpm @ 1100 psi and circulate well clean. Returning Arctic pack,sand and Pressure net from cement job. 1/17/2016 1/17/2016 0.50 PROD1 WELLPR PRTS X Pressure test 7"26#,. L-80/J-55 2,835.0 2,835.0 15:15 15:45 Casing to 3,500 psi for 15 minutes. J- 55 burst rated for 4,980 x.80=3,984 psi. Good test 1/17/2016 1/17/2016 0.50 PROD1 WELLPR DRLG X Dry drill on sand @ 2,835-ft for 30 2,835.0 2,835.0 15:45 16:15 minutes 1/17/2016 1/17/2016 1.75 PROD1 WELLPR TRIP X POOH f/2,835-ft to 219-ft 2,835.0 219.0 16:15 18:00 1/17/2016 1/17/2016 1.00 PROD1 WELLPR BHAH X POOH f/219-ft,change out 6-1/8"bit 219.0 219.0 18:00 19:00 with 6-1/8"Bladed Junk Mill BHA#34 1/17/2016 1/17/2016 1.00 PROD1 WELLPR TRIP X RIH with BHA#34:Tagged @ 2840.0 219.0 2,840.0 19:00 20:00 1/17/2016 1/17/2016 2.00 PROD1 WELLPR MILL X Dry milled on ES junk at 2845 ft.Up 2,840.0 2,852.0 20:00 22:00 75 Down wt=62 K Rotation 66K. F/TQ 2600 FT/LB's @ 50 RPM's sat down with 10 K 2850 ft torque increase to3.3 K Dry mill on junk to 2852 ft. Picked up 2845'with 4K over pull.continue to ream up. Broke circulation a 2 BPM @ 300 psi, increased to 5 BPM @ 550 psi. Increased rate to 8 BPM @ 800 psi. Circulated clean. 1/17/2016 1/17/2016 1.50 PROD1 WELLPR TRIP X POOh with BHA#34. 2,852.0 219.0 22:00 23:30 1/17/2016 1/18/2016 0.50 PROD1 WELLPR BHAH X Laid down Junk mill.Recovered 3 219.0 0.0 23:30 00:00 LB's metal shaving in boot baskets. 1/18/2016 1/18/2016 1.00 PROD1 WELLPR BHAH X Pick up BHA#35;RCJB assembly 0.0 214.0 00:00 01:00 Page 13/28 Report Printed: 2/18/2016 4 • • `w .,‹ Operations Summary (with Timelog Depths) 2K-25 Conoa31:11 Uips Jr Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-XOperation (ftK6) End Depth MICE)1/18/2016 1/18/2016 1.00 PROD1 WELLPR TRIP X RIH with BHA#S 35 214.0 2,766.0 01:00 02:00 1/18/2016 1/18/2016 1.50 PROD1 WELLPR WASH X Dropped ball.and pumped down.EST 2,766.0 2,859.0 02:00 03:30 Parameters:F/TQ 2600 @ 50 RPM's Est Circulation @ 6 BPM @ 2600 psi. Engaged Junk basket @ 2853 ft Torque increase to 3.1-3.5 K.With 5K on it.Circulated clean 1/18/2016 1/18/2016 1.00 PROD1 WELLPR TRIP X POOH with Junk basket assembly. 2,859.0 214.0 03:30 04:30 BHA#35 1/18/2016 1/18/2016 1.25 PROD1 WELLPR BHAH X Clean out Junk basket.recovered 1- 214.0 225.0 04:30 05:45 16oz coffee cup of metal shavings and 2 brass shear screws. Installed magnet in to BHA#36 and RIH w/BHA#36 to 225-ft 1/18/2016 1/18/2016 4.50 PROD1 WELLPR TRIP X RIH w/BHA#36 to 2,859-ft and Tag 225.0 225.0 05:45 10:15 sand,set down 5K. PU to 2,850-ft. Obtain parameters:75K Up wt,62K Dn wt,and 68K ROT wt at 40 rpm's w/ 2.4K Free TQ. Circulating at 6 bpm at 2,500 psi. Begin functioning RCJB and clean out to 2,871-ft. POOH to 225-ft. 1/18/2016 1/18/2016 1.75 PROD1 WELLPR BHAH X Lay down BHA#36 and recovered 1 225.0 0.0 10:15 12:00 Gallon of metal shavings and 1/2 dollar sizre pieces. 1/18/2016 1/18/2016 1.00 PROD1 WELLPR SVRG X Service rig and Top drive 0.0 0.0 12:00 13:00 1/18/2016 1/18/2016 0.75 PROD1 WELLPR BHAH X MU BHA#37 and RIH to 225-ft 0.0 225.0 13:00 13:45 1/18/2016 1/18/2016 1.25 PROD1 WELLPR TRIP X RIH w/BHA#37 to 225.0 2,772.0 13:45 15:00 1/18/2016 1/18/2016 1.00 PROD1 WELLPR RGRP XT Repair top drive 2,772.0 2,772.0 15:00 16:00 1/18/2016 1/18/2016 1.50 PROD1 WELLPR WASH X Continue to RIH with RCJB. 2,772.0 2,882.0 16:00 17:30 Dropped ball Est circulation @ 4 BPM @ 1220 psi.5 BPM @ 1850 psi.F/TQ @ 40 RPM's =2500 FT/lb's. Tagged @ 2873 ft W/5 K.Circulated down to 2882 ft W/3-5 K torque @ 5 BPM @ 1850 psi. Circulated clean with RCJB at 2870 ft. SD pump Re-tag fill at 2882 ft. 1/18/2016 1/18/2016 1.50 PROD1 WELLPR TRIP X Trip out of hole with BHA#37 2,882.0 225.0 17:30 19:00 1/18/2016 1/18/2016 1.50 PROD1 WELLPR BHAH X Broke down RCJB recovered more of 225.0 233.0 19:00 20:30 the ES cementer junk.Re dress RCJB fro BHA#38 1/18/2016 1/18/2016 1.00 PROD1 WELLPR TRIP X RIH with RCJB:BHA#38. 233.0 2,882.0 20:30 21:30 Page 14/28 Report Printed: 2/18/2016 -q • 0 Operations Summary (with Timelog Depths) :' '''' Star-V4.-At, �!„� 2K-25 ConocoPhilbps ' Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time'. End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftK9)I 1/18/2016 1/19/2016 2.50 PROD1 WELLPR WASH X Est Parameters:Up wt=75 K Down 2,882.0 2,906.0 21:30 00:00 wt=60 RWT=70K F/TQ @ 50 RPM's 2600 ft/lbs.Pumped ball on seat @ 2 BPM @ 375 psi.4 BPM @ 1100 PSI.6 BPM @ 2450 psi.wash down to 2902 ft. 1-2 K on mill to 2906 ft Set 2 K on not washing off.Slowly rotated back off IBP Circulating at 3BPM.@ 800 psi.to 2890 ft rotating @ 20 RPM's increased circulation to 5BPM @ 2200 psi.Circulated clean 1/19/2016 1/19/2016 3.00 PROD1 WELLPR TRIP X POOH with BHA#38.Recovered a 2,906.0 0.0 00:00 03:00 few more chunks of casing junk. 1/19/2016 1/19/2016 0.50 PROD1 WELLPR SVRG X Service and inspect top drive 0.0 0.0 03:00 03:30 1/19/2016 1/19/2016 0.25 PROD1 WELLPR BHAH X Pick up BHA#39.retrieving assembly 0.0 17.0 03:30 03:45 for IBP. 1/19/2016 1/19/2016 1.75 PROD1 WELLPR TRIP X RIH with BHA#39;IBP retrieving tool 17.0 2,850.0 03:45 05:30 assembly.Broke circulation at 3 BPM @ 230 psi.dropped over plug equalized Kick pump back on 1.5 BPM ©240 psi.dropped plug down to 2916 ft.let set 15 min's.pulled up 2850.0 plug is free without any over pull. 1/19/2016 1/19/2016 0.50 PROD1 WELLPR CIRC X Dropped ball to open up pump out sub 2,850.0 2,850.0 05:30 06:00 and circulate clean at 6 BPM=400 psi. 1/19/2016 1/19/2016 0.50 PROD1 WELLPR OWFF X Observe the well for flow;the well is 2,850.0 2,850.0 06:00 06:30 static. SimOps: Blow down the TD and install stripping rubber. 1/19/2016 1/19/2016 1.00 PROD1 WELLPR TRIP X TOOH with BHA#39 and IBP fish. 2,850.0 17.0 06:30 07:30 1/19/2016 1/19/2016 0.50 PROD1 WELLPR BHAH X Lay down BHA#39 and IBP fish. 17.0 0.0 07:30 08:00 Clean and clear the floor. 1/19/2016 1/19/2016 1.50 COMPZN RPCOMP WAIT P Wait for fishing tools to arrive for 0.0 0.0 08:00 09:30 fishing remaining completion. 1/19/2016 1/19/2016 2.00 COMPZN RPCOMP BHAH P Bring fishing equipment to the rig floor. 0.0 276.0 09:30 11:30 PU and MU BHA#40-5-3/4"wash pipe with drag tooth shoe. 1/19/2016 1/19/2016 3.00 COMPZN RPCOMP TRIP P TIH with BHA#40 to 3868'RKB. 276.0 3,868.0 11:30 14:30 1/19/2016 1/19/2016 5.50 COMPZN RPCOMP PULD P Continue to RIH picking up DP from 3,868.0 9,451.0 14:30 20:00 the pipe shed from 3868'to 9451'RKB (PU=190K and SO=85K). 1/19/2016 1/19/2016 1.00 COMPZN RPCOMP CIRC P Circulate the well clean staging up the 9,451.0 9,451.0 20:00 21:00 pump rate from 2 BPM=300 psi to 5 BPM=1080 psi. 1/19/2016 1/19/2016 2.00 COMPZN RPCOMP SLPC P PJSM. Cut and slip 95'(14 wraps)of 9,451.0 9,451.0 21:00 23:00 drilling line while continuing to circulate. Inspect the brass,draw works,breaks,rollers. Grease the draw works. Change out absorbent under the draw works and calibrate the block height. 1/19/2016 1/19/2016 0.50 COMPZN RPCOMP FISH P Attempt to establish rotating 9,451.0 9,451.0 23:00 23:30 parameter but the torque was too high. Page 15/28 Report Printed: 2/18/2016 • S Operations Summary (with Timelog Depths) 2K-25 COnOCOPhiiiipS Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/19/2016 1/20/2016 0.50 COMPZN RPCOMP CIRC T Add 3 drums of SafeLube(0.6%)to 9,451.0 9,451.0 23:30 00:00 the system and circulate at 5 BPM= 890 psi while reciprocating. 1/20/2016 1/20/2016 1.00 COMPZN RPCOMP CIRC T Continue to circulate at 5 BPM=890 9,451.0 9,451.0 00:00 01:00 psi while reciprocating. Torque continues to stall out. Add 1 additional drum of SafeLube bring the system to 0.8%but torque stalls out at 12K n- ibs. 1/20/2016 1/20/2016 2.00 COMPZN RPCOMP WAIT T Remaining supply of SafeLube on 9,451.0 9,451.0 01:00 03:00 location is frozen. Wait for additional product to arrive while continuing to circulate. Free torque at 20 RPM= 11K ft-lbs. 1/20/2016 1/20/2016 1.00 COMPZN RPCOMP CIRC T Add 4 additional drums of SafeLube 9,451.0 9,451.0 03:00 04:00 bring the system 1.8%and circulate around to get the free torque at 40 RPM= 10K ft-lbs. 1/20/2016 1/20/2016 4.00 COMPZN RPCOMP WASH P Wash down from 9451'to 9577' 9,451.0 9,577.0 04:00 08:00 rotating at 40RPM with 10.2K torque while circulating 5 BPM=900 psi(saw top of fish at 9518'). 1/20/2016 1/20/2016 0.50 COMPZN RPCOMP FISH P Shut off rotary,PU on drill string, 9,577.0 9,542.0 08:00 08:30 engaged T-dog overshot under coupling at 9538'.Pull free at 35K over string weight of 175K.PU to 9542' RKB. 1/20/2016 1/20/2016 1.00 COMPZN RPCOMP CIRC P Circulate and condition 1.5 bottoms up 9,542.0 9,542.0 08:30 09:30 at 5 BPM=780 psi. 1/20/2016 1/20/2016 0.50 COMPZN RPCOMP OWFF P Monitor well for flow while installing 9,542.0 9,542.0 09:30 10:00 wiper rubber,removing blower hose and blow down top drive. 1/20/2016 1/20/2016 3.00 COMPZN RPCOMP TRIP P TOOH from 9542'to 5200'RKB. 9,542.0 5,200.0 10:00 13:00 1/20/2016 1/20/2016 0.25 COMPZN RPCOMP SFTY P Kick while tripping drill. Well secured 5,200.0 5,200.0 13:00 13:15 in 28 seconds and all hands in position in 86 seconds. Held an AAR with the crew. 1/20/2016 1/20/2016 2.25 COMPZN RPCOMP TRIP P Continue to TOOH from 5200'to 275' 5,200.0 275.0 13:15 15:30 RKB. 1/20/2016 1/20/2016 2.50 COMPZN RPCOMP BHAH P Lay down BHA#40-5-3/4"wash pipe 275.0 0.0 15:30 18:00 with drag tooth shoe. Lay down fish; recovered cut joint,GLM,and seal assembly. No visual evidence of chemical cut in the joint of tubing below the GLM. Clean and clear the floor. 1/20/2016 1/20/2016 1.00 COMPZN RPCOMP PRTS T Open the blind rams,purge the kill 0.0 0.0 18:00 19:00 line,and close the blind rams. Attempt to pressure test the 7"casing to 3500 psi but were unable to get the pressure above 2500 psi at 2 BPM. Shut in the well and the pressure leveled off at 1500 psi. Bleed the pressure to 0 psi and open the blind rams. 1/20/2016 1/20/2016 1.50 COMPZN RPCOMP BHAH P PU and MU BHA#41 -wavy bottom 0.0 397.0 19:00 20:30 shoe assembly. 1/20/2016 1/21/2016 3.50 COMPZN RPCOMP TRIP P TIH with BHA#41 to 5121'RKB at 397.0 5,121.0 20:30 00:00 midnight(PU= 105K and SO=75K). Page 16/28 Report Printed: 2/18/2016 • f , Operations Summary (with Timelog Depths) +��''�'witv � :. 2K-25 ConocciPhillips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time` End Time Dur(hr) Phase Op Code Activity Code Time.P-T-X Operation (ftKB) End Depth((KB), 1/21/2016 1/21/2016 0.25 COMPZN RPCOMP SFTY P Kick while tripping drill. Well secured 5,121.0 5,121.0 00:00 00:15 in 48 seconds and all hands in position in 75 seconds. Held an AAR with the crew. 1/21/2016 1/21/2016 0.50 COMPZN RPCOMP SVRG P Daily top drive service and inspection. 5,121.0 5,121.0 00:15 00:45 1/21/2016 1/21/2016 3.25 COMPZN RPCOMP TRIP P Continue to TIH with BHA#41 -wavy 5,121.0 9,478.0 00:45 04:00 bottom shoe assembly from 5121'to 9478'RKB(PU=175K and SO= 95K). 1/21/2016 1/21/2016 0.50 COMPZN RPCOMP FISH P Establish parameters: PU= 175K,SO 9,478.0 9,572.0 04:00 04:30 =95K,rotating weight=120 at 10 RPM,free torque=10K. Attempt to increase the RPM but the torque stalls out at 11K while washing down to 9572'RKB. 1/21/2016 1/21/2016 3.50 COMPZN RPCOMP CIRC T Circulate in viscous lube system at 5 9,572.0 9,572.0 04:30 08:00 BPM=800 psi while reciprocating. 1/21/2016 1/21/2016 1.00 COMPZN RPCOMP WASH P Attempt to wash over PBR at 9623'at 9,572.0 9,614.0 08:00 09:00 5 BPM=810 psi,60 rpm, 10.6K torque but no torque increase and not milling off. 1/21/2016 1/21/2016 4.50 COMPZN RPCOMP TRIP P TOOH from 9614'to 396'. 9,614.0 396.0 09:00 13:30 1/21/2016 1/21/2016 1.50 COMPZN RPCOMP BHAH P Lay down BHA#41 -wavy bottom 396.0 0.0 13:30 15:00 shoe. Clean and clear the rig floor. 1/21/2016 1/21/2016 0.50 COMPZN RPCOMP BHAH P PU and MU BHA#42-2-13/16"spear 0.0 306.0 15:00 15:30 assembly for the PBR. 1/21/2016 1/21/2016 3.50 COMPZN RPCOMP TRIP P TIH with BHA#42 to 9576'(PU= 306.0 9,576.0 15:30 19:00 160K and SO=100K). 1/21/2016 1/21/2016 0.50 COMPZN RPCOMP FISH P Establish parameters: Pump#1 -2 9,576.0 9,624.0 19:00 19:30 BPM=600 psi/3 BPM= 1000 psi; Pump#2-2 BPM=580 psi/3 BPM= 960 psi. Wash down at 2 BPM to 9618'RKB and engage the spear at 9624'RKB with 10K down. 1/21/2016 1/21/2016 3.50 COMPZN RPCOMP JAR P PU to 185K bleed the jars,SO 10K 9,624.0 9,624.0 19:30 23:00 down,and PU to 200K to fire the jars. Continue working the jars up to 260K (100K over)with straight pull to 276K (116K over). 1/21/2016 1/22/2016 1.00 COMPZN RPCOMP FISH P Attempt to release the packer with 9,624.0 9,624.0 23:00 00:00 right hand rotation. Put 2 right hand turns at 4K torque,work torque down, put 1 right hand turn at 4K torque,and work the torque down. While working the 4th right hand turn down the spear released. Put 2 left hand turns and torque to bottom to engage the grapple into the PBR. 1/22/2016 1/22/2016 0.75 COMPZN RPCOMP JAR P Continue jarring from 225K to 260K 9,624.0 9,624.0 00:00 00:45 with straight pull to 276K(116K over). Got 1'-2'of movement,worked the pipe without jarring from 110K to 275K,and the fish came free at 265K. Total jar hits=175. 1/22/2016 1/22/2016 0.25 COMPZN RPCOMP OWFF P Observe the well for flow for 10 9,624.0 9,624.0 00:45 01:00 minutes;the well is static. 1/22/2016 1/22/2016 0.25 COMPZN RPCOMP TRIP P Stand back 2 stands of DP. 9,478.0 9,478.0 01:00 01:15 Page 17/28 Report Printed: 2/18/2016 • i "' , y Operations Summary (with Timelog Depths) fe F 2K-25 « nidi; 4. ;', Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time'. End Time Our(hr) Phase _ Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB). 1/22/2016 1/22/2016 1.25 COMPZN RPCOMP CIRC P Drop the shear out sub dart and open 9,478.0 9,478.0 01:15 02:30 the shear out sub at 2430 psi. Circulate bottoms up at 5 BPM=800 psi. 1/22/2016 1/22/2016 0.50 COMPZN RPCOMP SFTY P Post jarring derrick inspection. 9,478.0 9,478.0 02:30 03:00 1/22/2016 1/22/2016 0.50 COMPZN RPCOMP SVRG P Daily top drive service and inspection. 9,478.0 9,478.0 03:00 03:30 1/22/2016 1/22/2016 4.50 COMPZN RPCOMP TRIP P TOOH with BHA#42/fish from 9478' 9,478.0 2,315.0 03:30 08:00 RKB with drag to 2650'RKB were 15K over pull observed. Work through and continue to TOOH to 2315'were 25K over pull observed.Attempt to work through but unable to making multiple attempt working string up to 25K over pull. - 1/22/2016 1/22/2016 0.50 COMPZN RPCOMP CIRC T MU TD,bring the pumps up to 6 BPM 2,315.0 2,315.0 08:00 08:30 =310 psi,and attempt to work through but unable to making multiple attempt working string up to 25K over pull. SimOps: Discuss options with Brett Packer and Andrew Beat- decision was made to PU 7"Casing scraper and run past the casing patch. 1/22/2016 1/22/2016 0.50 COMPZN RPCOMP BHAH T Blow down the TD. PU and MU 7" 2,315.0 2,326.0 08:30 09:00 casing scraper with crossover(BHA #42+casing scrapper= BHA#43) 1/22/2016 1/22/2016 1.00 COMPZN RPCOMP TRIP T TIH to 2272'RKB(casing scraper 2,326.0 4,726.0 09:00 10:00 depth;bottom of fish at 4663'RKB). 1/22/2016 1/22/2016 1.00 COMPZN RPCOMP CIRC T MU the TD and bring the pump up to 6 4,726.0 4,726.0 10:00 11:00 BPM=540 psi. Continue in the hole, seen slight bobble at 2303'RKB, continue to 2320'RKB putting the casing scraper through the casing patch/ES cementer. Work past both several times and circulate bottoms up (a little sand,cement,and metal debris at bottoms up). 1/22/2016 1/22/2016 1.00 COMPZN RPCOMP TRIP T TOOH to the casing scraper. 4,726.0 2,326.0 11:00 12:00 1/22/2016 1/22/2016 0.50 COMPZN RPCOMP BHAH T Lay down 7"casing scraper with 2,326.0 2,315.0 12:00 12:30 crossovers(BHA#43-casing scraper = BHA#42). 1/22/2016 1/22/2016 1.00 COMPZN RPCOMP TRIP T TOOH from 2315' to 305'RKB(did 2,315.0 305.0 12:30 13:30 not see any bobbles while passing through the casing patch/ES cementer). 1/22/2016 1/22/2016 1.00 COMPZN RPCOMP BHAH T Lay down BHA#42-spear assembly 305.0 0.0 13:30 14:30 with no fish. Grapple broken but not missing any pieces. 1/22/2016 1/22/2016 1.00 COMPZN RPCOMP BHAH T PU BHA#44-6-1/8"string mill 0.0 309.0 14:30 15:30 assembly. 1/22/2016 1/22/2016 1.00 COMPZN RPCOMP TRIP T TIH with BHA#44 to 2294'RKB(PU= 309.0 2,294.0 15:30 16:30 65K and SO=62K). 1/22/2016 1/22/2016 0.50 COMPZN RPCOMP REAM T Washing and reaming at 6 bpm,410 2,294.0 2,294.0 16:30 17:00 psi,rotate down at 60 rpm 1.8K torque.Work from 2,294'to 2,335' RKB three times.No indication of obstruction or reduced ID. Page 18/28 Report Printed: 2/18/2016 • Operations Summary (with Timelog Depths) ,, P 2K-25 iiitio ConocoP itlips tr Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time. End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (RKB) End Depth.(ftKB)'.. 1/22/2016 1/22/2016 1.00 COMPZN RPCOMP TRIP T Blow down top drive,remove blower 2,294.0 309.0 17:00 18:00 hose,and install stripping rubber. TOOH with BHA#44 from 2294'to 309'RKB. 1/22/2016 1/22/2016 1.00 COMPZN RPCOMP BHAH T Lay down BHA#44-6-1/8"string mill 309.0 0.0 18:00 19:00 assembly(no wear on the string mill). 1/22/2016 1/22/2016 0.50 COMPZN RPCOMP BHAH T PU and MU BHA#45-spear 0.0 306.0 19:00 19:30 assembly for PBR. 1/22/2016 1/22/2016 4.25 COMPZN RPCOMP TRIP T TIH with BHA#45 to 9000'RKB. 306.0 9,000.0 19:30 23:45 1/22/2016 1/23/2016 0.25 COMPZN RPCOMP SFTY T Well control drill-kick while tripping. 9,000.0 9,000.0 23:45 00:00 Well shut in time=37 seconds and CRT= 105 seconds. AAR with rig crew. 1/23/2016 1/23/2016 1.50 COMPZN RPCOMP SLPC T PJSM. Cut and slip 86'(13 wraps)of 9,000.0 9,000.0 00:00 01:30 drilling line. Inspect the brass,draw works,breaks,rollers. Grease the draw works and calibrate the block height. 1/23/2016 1/23/2016 0.50 COMPZN RPCOMP TRIP T Continue to TIH with BHA#45- spear 9,000.0 9,573.0 01:30 02:00 assembly for PBR from 9000'to 9573' RKB(PU=157K and SO= 107K). 1/23/2016 1/23/2016 1.00 COMPZN RPCOMP FISH T Break circulation: 2 BPM=700 psi 9,573.0 9,600.0 02:00 03:00 and 3 BPM= 1200 psi. Shut down the pumps. RIH to 6915'RKB,wash down at 2 BPM=700 psi to 9643' RKB,and set 5K down. Shut down the pumps,PU,and SO tagging in the same spot. Work the pipe to ensure that the grapple is engaged into the PBR. Set down 20K twice and observed 10-15K over pull. PU to 9600'RKB with 3K drag. 1/23/2016 1/23/2016 2.50 COMPZN RPCOMP TRIP T TOOH with BHA#45 and fish from 9,600.0 6,077.0 03:00 05:30 9600'to 6077'RKB(PU= 125K). 1/23/2016 1/23/2016 0.50 COMPZN RPCOMP SVRG T Daily top drive service and inspection. 6,077.0 6,077.0 05:30 06:00 1/23/2016 1/23/2016 2.50 COMPZN RPCOMP TRIP T Continue to TOOH with BHA#45 and 6,077.0 2,301.0 06:00 08:30 fish from 6077'to 2301'RKB were 20K over pull was observed. Work PBR/packer fish past ES cement. 1/23/2016 1/23/2016 1.00 COMPZN RPCOMP TRIP P Continue to TOOH with BHA#45 and 2,301.0 306.0 08:30 09:30 fish from 2301'to 306'RKB. 1/23/2016 1/23/2016 3.00 COMPZN RPCOMP PULL P Lay down BHA#45-spear assembly. 306.0 0.0 09:30 12:30 Recovered PBR,HB packer, 1 joint of 2-7/8"tubing,D Nipple, 10'pup joint and shear out sub(SOS). Clean and clear the rig floor. 1/23/2016 1/23/2016 1.00 COMPZN WELLPR BHAH T PU BHA#46-test packer assembly 0.0 380.0 12:30 13:30 and TIH one stand of DP. 1/23/2016 1/23/2016 0.50 COMPZN WELLPR MPSP T Set the test packer. Pressure up on 380.0 380.0 13:30 14:00 the IA to 1500 psi to test the 7"casing and test packer(good test). Unset the test packer. Manipulate the test packer back into run mode. 1/23/2016 1/23/2016 4.50 COMPZN WELLPR TRIP T TIH wtih BHA#46 from 380'to 8050' 380.0 8,050.0 14:00 18:30 RKB(PU=135 and SO=95K). Page 19/28 Report Printed: 2/18/2016 • ,050 Operations Summary (with Timelog Depths) 2K-25 iilips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftK6) End Depth(ftKB)'.. 1/23/2016 1/23/2016 3.00 COMPZN WELLPR MPSP T Set the test packer(center of element 8,050.0 7,663.0 18:30 21:30 at 8014'RKB). Attempt to PT the IA to 3500 psi but unable to get pressure above 2500 psi at 1 BPM(failed test). Unset test packer and pull 1 stand. Set the test packer(center of element at 7948'RKB). Attempt to PT the IA to 3500 psi but unable to get pressure above 2500 psi at 1 BPM(failed test). Unset test packer and pull 4 stands. Set the test packer(center of element at 7568'RKB). Pressure up on the IA to 3500 psi to test the 7"casing above the test packer for 5 minutes(good test). Unset the test packer, manipulate the test packer back into run mode,and TIH 2 stands. Set the test packer(center of element at 7757' RKB). Pressure up on the IA to 3500 psi to test the 7"casing above the test packer(failed test). Unset test packer and pull 1 stands. Set the test packer (center of element at 7663'RKB). Pressure up on the IA to 3500 psi to test the 7"casing above the test packer for 5 minutes(good test). Unset the test packer and manipulate the test packer back into run mode. `*7"casing is good from 7663'RKB to surface" 1/23/2016 1/24/2016 2.50 COMPZN WELLPR TRIP T TOOH with BHA#46 from 7663'to 7,663.0 2,467.0 21:30 00:00 2467'RKB at midnight(PU=68K and SO=60K). 1/24/2016 1/24/2016 1.00 COMPZN WELLPR TRIP T Continue to TOOH with BHA#46-test 2,467.0 293.0 00:00 01:00 packer assembly from 2467' to 293' RKB. 1/24/2016 1/24/2016 0.50 COMPZN WELLPR BHAH T Lay down BHA#46. 293.0 0.0 01:00 01:30 1/24/2016 1/24/2016 0.50 COMPZN WELLPR RURD P PU a joint of DP,MU wear ring pulling 0.0 0.0 01:30 02:00 tool,pull wear ring and lay down wear ring. 1/24/2016 1/24/2016 1.00 COMPZN WELLPR WWWH P PU and MU magnet and stack jetting 0.0 0.0 02:00 03:00 tool.Jet the stack. Clean off magnet (recovered some metal debris). Lay down magnet,stack jetting tool,and joint of DP. Blow down the TD. 1/24/2016 1/24/2016 1.50 COMPZN WELLPR SVRG P Change out the saver sub on the TD 0.0 0.0 03:00 04:30 due to wear on the threads due to use. Perform daily TD inspection. 1/24/2016 1/24/2016 4.00 COMPZN WHDBOP RURD P RU BOPE testing equipment. Install 0.0 0.0 04:30 08:30 test plug. Fill the BOP stack and choke manifold with fresh water. Shell test the BOP stack to 250/5000 psi (good test). Page 20/28 Report Printed: 2/18/2016 • Operations Summary (with Timelog Depths) 2K-25 ContacciPhitlips R@ssk:.s Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation MKS) End Depth(5KB) 1/24/2016 1/24/2016 1.50 COMPZN WHDBOP BOPE P Conduct weekly BOPE test to 0.0 0.0 08:30 10:00 250/4000 psi: test 2-7/8"x 5"VBR's (upper and lower pipe rams)with 3- 1/2"and 4-1/2"test joints;test annular to 250/2500 with 3-1/2"and 4-1/2"test joints;conducted Koomey drawdown test(all tested passed). The states right to witness was waived by AOGCC inspector Brian Bixby via email on 1/23/16 at 12:11 hours. Tests: 1) Blind Rams,2"Demco Kill,Upper IBOP,Outer Test Spool,Chokes 1,2, 3,&16(Passed) 2) Blind Rams,HCR Kill, Inner Test Spool,Chokes 4,5,&6(Passed) 1/24/2016 1/24/2016 0.50 COMPZN WHDBOP BOPE P Blow down the TD and PU 3-1/2"test 0.0 0.0 10:00 10:30 joint. 1/24/2016 1/24/2016 1.00 COMPZN WHDBOP BOPE T Attempt to test Upper Pipe Rams with 0.0 0.0 10:30 11:30 3-1/2"test joint, Manual Kill,Dart Valve,HT-38 TIW,Chokes 7,8,&9 (Failed-test plug leaking due to the rig not properly centered over the well) 1/24/2016 1/24/2016 0.50 COMPZN WHDBOP BOPE P Pull 3-1/2"test joint with test plug. 0.0 0.0 11:30 12:00 Test plug rubber elements looked good. Install test plug and PU 4-1/2" doughnut test joint. 1/24/2016 1/24/2016 0.50 COMPZN WHDBOP BOPE P 3) Upper Pipe Rams with 4-1/2" 0.0 0.0 12:00 12:30 doughnut test joint, Manual Kill,Dart Valve,3-1/2"HT-38 TIW,Chokes 7& 9(Failed high pressure test). Grease Chokes 7&9 and Manual Kill. Re- test passed 1/24/2016 1/24/2016 1.50 COMPZN WHDBOP BOPE P Pull test plug and change out the 0.0 0.0 12:30 14:00 rubber elements. 1/24/2016 1/24/2016 2.50 COMPZN WHDBOP BOPE P 4) Upper Pipe Rams with 4-1/2" 0.0 0.0 14:00 16:30 doughnut test joint,Chokes 8, 10,& 11(Passed) 5) Super Choke and Manual Adjustable Choke(Passed) 6) Upper Pipe Rams with 4-1/2" doughnut test joint, HCR Kill,Chokes 12, 13,&15(Passed) 7) Lower Pipe Rams with 4-1/2" doughnut test joint(Passed) 8) Annular with 4-1/2"doughnut test joint(Passed) 1/24/2016 1/24/2016 0.50 COMPZN WHDBOP BOPE P Pull 4-1/2"doughnut test joint and PU 0.0 0.0 16:30 17:00 3-1/2"doughnut test joint. Page 21/28 Report Printed: 2/18/2016 S e' Operations Summary (with Timelog Depths) rot n Conoconfillips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB)'. 1/24/2016 1/24/2016 1.50 COMPZN WHDBOP BOPE P 9) Upper Pipe Rams with 3-1/2" 0.0 0.0 17:00 18:30 doughnut test joint,3-1/2"EUE 8rd TIW,Choke 14(Passed) 10)Upper Pipe Rams with 3-1/2" doughnut test joint,HCR Choke (Passed) 11)Lower Pipe Rams with 3-1/2" doughnut test joint(Passed) 12)Annular with 3-1/2"doughnut test joint(Passed) Conduct Koomey Draw Down Test: Starting Accumulator Pressure=2800 psi Accumulator Pressure After Closer= 1650 psi Pressure Gain of 200 psi= 14 seconds Full System=87 Seconds Average N2(5 Bottles)=1948 psi 1/24/2016 1/24/2016 1.00 COMPZN WHDBOP RURD P Blow down all BOPE testing 0.0 0.0 18:30 19:30 equipment,RD BOPE testing equipment,and lay down test joint. 1/24/2016 1/24/2016 0.50 COMPZN WELLPR RURD P MU wear ring running tool,install wear 0.0 0.0 19:30 20:00 ring,lay down wear ring running tool, and lay down joint of DP. 1/24/2016 1/24/2016 1.00 COMPZN WELLPR BHAH P PU and MU BHA#47-Bladed Junk 0.0 317.0 20:00 21:00 Mill cleanout assembly. 1/24/2016 1/25/2016 3.00 COMPZN WELLPR TRIP P TIH with BHA#47 from 317'to 8200' 317.0 8,200.0 21:00 00:00 RKB at midnight(PU=115K and SO =80K). 1/25/2016 1/25/2016 0.75 COMPZN WELLPR TRIP P Continue to TIH with BHA#47- 8,200.0 8,830.0 00:00 00:45 Bladed Junk Mill cleanout assembly from 8200'to 8830'RKB. 1/25/2016 1/25/2016 0.25 COMPZN WELLPR SFTY P Well control drill-kick while tripping. 8,830.0 8,830.0 00:45 01:00 Well shut in time=37 seconds and CRT=79 seconds. AAR with rig crew. 1/25/2016 1/25/2016 0.75 COMPZN WELLPR TRIP P Continue to TIH with BHA#47- 8,830.0 9,680.0 01:00 01:45 Bladed Junk Mill cleanout assembly from 8830'to 9680'RKB. 1/25/2016 1/25/2016 0.25 COMPZN WELLPR MILL P Obtain parameters for mill cement: 9,680.0 9,680.0 01:45 02:00 PU= 160K,SO= 105K,rotating weight=130K,20 RPM=7K ft-lbs free torque 1/25/2016 1/25/2016 1.00 COMPZN WELLPR COND P Load the pits with 14.2 ppg WBM with 9,680.0 9,680.0 02:00 03:00 micronized barite. Mud coming off the truck was 13.9 ppg,weight up to 14.2 ppg,and blend into the active system. Build hi vis seawater and hi vis mud pills. 1/25/2016 1/25/2016 4.00 COMPZN WELLPR DISP P PJSM. Swap the well over from 8.6 9,680.0 9,680.0 03:00 07:00 ppg seawater to 14.2 ppg WBM. Pump 25 bbls hi vis 9 ppg seawater spacer pill at 3 BPM=500 psi followed by 50 bbls hi vis 14.2 ppg mud spacer pill at 3 BPM=328 psi chased with 14.2 ppg mud at 3 BPM while rotating and reciprocating(ICP= 85 psi and FCP=1250 psi). Page 22/28 Report Printed: 2/18/2016 • S Operations Summary (with Timelog Depths) 9 x 2K-25 Cancmc;Phillips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (RKB) End Depth(ftKB). 1/25/2016 1/25/2016 5.00 COMPZN WELLPR MILL P Obtain parameters: Mud pump 1 &2: 9,680.0 9,820.0 07:00 12:00 2 BPM=970 psi and 3 BMP= 1140 psi.Wash from 9680'to 9690'RKB and tagged cement.Start milling out cement at 6.5 BPM =3900 psi,60 RPM=9-10K ft-lbs torque,PU= 145K,SO=82K,and rotating weight= 100K. Mill cement from 9690'to 9820' RKB with 5-10K weight on bit. 1/25/2016 1/25/2016 5.00 COMPZN WELLPR MILL P Progress slowed way down,not 9,820.0 9,840.0 12:00 17:00 milling off with 10K WOB. With 15K WOB torque steady out at 9.5K ft-lbs and milling off slowly. Back ream from 9820'with 25K overpull and torque 10.5K ft-lbs on the way up. Rotate back down from 9770'to 9816'with no torque or drag increase. Engage rotary at 60 RPM=9K ft-lbs free torque and rotating weight= 110K. Mill cement down to 9840'RKB varying RPMs and pumps rates to make hole. Unable to mill past 9840' RKB with erratic torque and up to 20K WOB. Back ream with overpull and stalling out at 11.5K ft-lbs torque. Work pipe but no parameters changed. 1/25/2016 1/25/2016 1.00 COMPZN WELLPR TRIP T Blow down the TD. TOOH with BHA 9,840.0 8,263.0 17:00 18:00 #47 from 9840'to 8263'RKB(PU= 145K and SO=80K) 1/25/2016 1/25/2016 0.50 COMPZN WELLPR CIRC T Pump 15 bbl 15.7 ppg dry job at 2 8,263.0 8,263.0 18:00 18:30 BPM=900 psi. Blow down the TD. 1/25/2016 1/25/2016 4.50 COMPZN WELLPR TRIP T Continue to TOOH with BHA#47 from 8,263.0 317.0 18:30 23:00 8263'to 317'RKB. Monitor the well for 5 minutes;well is static. 1/25/2016 1/26/2016 1.00 COMPZN WELLPR BHAH T Lay down BHA#47-Bladed Junk Mill 317.0 0.0 23:00 00:00 cleanout assembly. Bladed junk mill balled up with cement and a couple water courses on the string mills were packed with cement. 1/26/2016 1/26/2016 1.00 COMPZN WELLPR BHAH T PU and MU BHA#48-Tri Cone bit 0.0 309.0 00:00 01:00 cleanout assembly. 1/26/2016 1/26/2016 1.25 COMPZN WELLPR TRIP T TIH with BHA#48 from 309'to 4566' 309.0 4,566.0 01:00 02:15 RKB(PU=95K and SO=65K) 1/26/2016 1/26/2016 0.25 COMPZN WELLPR SFTY T Well control drill-kick while tripping. 4,566.0 4,566.0 02:15 02:30 Well shut in time=37 seconds and CRT=101 seconds. AAR with rig crew. 1/26/2016 1/26/2016 2.00 COMPZN WELLPR TRIP T Continue to TIH with BHA#48 from 4,566.0 9,768.0 02:30 04:30 4566'to 9768'RKB(PU=170K and SO=85K). 1/26/2016 1/26/2016 6.00 COMPZN WELLPR DRLG T Obtain parameters: Rotating weight= 9,768.0 10,127.0 04:30 10:30 110K,80 RPM=10K ft-lbs free torque,and 5 BPM=2450 psi. Wash down to cement tag at 9848'RKB with 10K down. Mill cement at 80 RPM= 10.2K ft-lbs torque with 5K WOB,and 5 BPM=2550 psi to 10124'RKB. Tag 10217'RKB with pumps on and no rotation. Page 23/28 Report Printed: 2/18/2016 • S =.;:,-;;;&-,--.`v:';',2,,,,. Operations Summary (with Timelog Depths) t-4 2K-25 ConocoPhillips Rig: NABORS 7ES Job: RECOMPLETION Time Log ', Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (RKB) End Depth(WE) 1/26/2016 1/26/2016 1.50 COMPZN WELLPR CIRC T Circulate two bottoms up while 10,127.0 10,127.0 10:30 12:00 rotating and reciprocating at 6 BPM= 3500 psi 80 rpm=9.7K ft-lbs torque. 1/26/2016 1/26/2016 1.00 COMPZN WELLPR PMPO T Shut down the pump and tag at 10127' 10,127.0 9,768.0 12:00 13:00 RKB. TOOH from 10127'to 9768' RKB while pumping out of hole(PU= 175K and SO=82K). 1/26/2016 1/26/2016 0.50 COMPZN WELLPR RURD T Pump dry job.Blow down top drive, 9,768.0 9,768.0 13:00 13:30 remove blower hose. Drop 1.90"rabbit to drift DP for cement wiper plug. Install stripping rubber. 1/26/2016 1/26/2016 2.50 COMPZN WELLPR TRIP T Continue to TOOH from 9768'to 3531' 9,768.0 3,531.0 13:30 16:00 RKB(PU=72K). 1/26/2016 1/26/2016 4.00 COMPZN WELLPR PULD T POOH laying down DP from 3531'to 3,531.0 309.0 16:00 20:00 500'.Monitor well for 5 minutes;the well is static.Lay down remaining drillpipe from 500'to 309'. 1/26/2016 1/26/2016 1.00 COMPZN WELLPR BHAH T Lay down BHA#48-tri cone bit 309.0 0.0 20:00 21:00 cleanout assembly. 1/26/2016 1/26/2016 1.00 COMPZN RPCOMP WWWH P PU and MU stack jetting tool with 0.0 0.0 21:00 22:00 magnet. Jet the stack. Lay down magnet(did not recover any metal debris)and stack jetting tool. Blow down the TD. 1/26/2016 1/26/2016 1.25 COMPZN RPCOMP RURD P RU GBR power casing tongs. Change 0.0 0.0 22:00 23:15 elevators from 3-1/2"DP to 4-1/2" casing. Organize the pipe shed into running order. 1/26/2016 1/26/2016 0.25 COMPZN RPCOMP SFTY P PJSM for running 4-1/2"cemented 0.0 0.0 23:15 23:30 liner with rig crew,GBR,and Baker. 1/26/2016 1/27/2016 0.50 COMPZN RPCOMP PUTB P PU and MU liner shoe track to 106' 106.0 23:30 00:00 RKB. 1/27/2016 1/27/2016 3.75 COMPZN RPCOMP PUTB P PU,MU,and RIH with 4-1/2", 11.6#,L 106.0 2,508.0 00:00 03:45 -80, IBTM liner. 1/27/2016 1/27/2016 0.75 COMPZN RPCOMP OTHR P PU and MU SBE and liner hanger/liner 2,508.0 2,568.0 03:45 04:30 top packer assembly with liner wiper plug. 1/27/2016 1/27/2016 0.50 COMPZN RPCOMP RURD P RD GBR power casing tongs. Change 2,568.0 2,568.0 04:30 05:00 elevator from 4-1/2"tubing to 3-1/2" DP. 1/27/2016 1/27/2016 0.50 COMPZN RPCOMP RUNL P TIH with 3 stands of DCs and 1 joint of 2,568.0 2,877.0 05:00 05:30 heavy weight DP. 1/27/2016 1/27/2016 0.50 COMPZN RPCOMP CIRC P Circulate one liner volume: ICP=550 2,877.0 2,877.0 05:30 06:00 psi at 2 BPM and FCP=900 psi at 5 BPM. Blow down the top drive. 1/27/2016 1/27/2016 2.50 COMPZN RPCOMP RUNL P PU,MU,and RIH with 3-1/2"heavy 2,877.0 3,857.0 06:00 08:30 weight DP from the pipe shed from 2877'to 3857'RKB. 1/27/2016 1/27/2016 7.50 COMPZN RPCOMP RUNL P 'TIH with 4-1/2"liner on DP from 3857' 3,857.0 10,103.0 08:30 16:00 to 10103'RKB(PU= 145K,SO= 82K). 1/27/2016 1/27/2016 0.50 COMPZN RPCOMP RURD P PU and MU cement head and MU the 10,103.0 10,103.0 16:00 16:30 TD to a single joint of DP. RU SLB Cementing hard lines. 1/27/2016 1/27/2016 0.50 COMPZN RPCOMP CIRC P Bring on pumps to 1 BPM=1225 psi 10,103.0 10,127.0 16:30 17:00 and tag bottom at 10128'RKB. PU 1' and circulate at 4 BPM=2170 psi. Page 24/28 Report Printed: 2/18/2016 • • Operations Summary (with Timelog Depths) oro Moi 2K-25 ConocoPhitliips _. Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Dur(hr) Phase Op Code Activity Code Tone P-T-X Operation (RKB) End Depth(ftKB) 1/27/2016 1/27/2016 2.00 COMPZN RPCOMP CMNT P PT cement line to 250/5000 psi(good 10,127.0 10,127.0 17:00 19:00 test). Pump 15 bbls 14.5 ppg mud push at 3 BPM=1700 psi followed by 64 bbls 15.8 ppg cement at 3 BPM= 1600 psi,drop the dart, and chase with 10 bbls of fresh water. Swap to the rig pumps,displace the DP with 11.1 ppg brine at 5 BPM=3300 psi, slow pumps to 3 BPM=2300 psi,and bumped the plugs at 3200 psi. Check the float and the float is holding. 1/27/2016 1/27/2016 1.50 COMPZN RPCOMP PACK P Swap to SLB cementers,pressure up 10,127.0 7,630.0 19:00 20:30 4800 psi to set the liner hanger,and set down 50K to ensure liner hanger is set. PU 65K and rotate 15 turns to the right with 4K ft-lbs free torque at 140K hook load to release the liner running tool. Bring the pump on line at 3 BPM =1570 psi and 4 BPM=1900 psi. Pull packoff and dog sub out. Circulate 40 bbls to clear any cement off the top of the liner top packer then slow the pumps to 2 BPM=1200 psi. SO 80K to set the ZXP liner top packer(saw indicating shear),PU, and set down 80K again. PU,rotate at 15 RPM=5K ft-lbs free torque,SO 50K,stop the rotary,and PU off ZXP liner top packer. 1/27/2016 1/27/2016 1.00 COMPZN RPCOMP DISP P Displace the well to seawater by 7,630.0 7,630.0 20:30 21:30 pumping 130 bbls 11.1 ppg brine mud push at 3 BPM=1556 psi chased with 8.6 ppg seawater at 2 BPM=708 psi and bring the pumps up to 5 BPM= 1295 psi. Got good seawater to surface,shut down the pump, monitored the well for 5 minutes,and the well is static. 1/27/2016 1/27/2016 1.00 COMPZN RPCOMP RURD P Blow down circulating lines and RD 7,630.0 7,630.0 21:30 22:30 the cement head. 1/27/2016 1/27/2016 0.50 COMPZN RPCOMP PULD P POOH laying down DP from 7630'to 7,630.0 7,567.0 22:30 23:00 7567'RKB. 1/27/2016 1/27/2016 0.50 COMPZN RPCOMP PRTS P Pressure up on the IA and DP to 3500 7,567.0 7,567.0 23:00 23:30 psi for 10 minutes to test the 4-1/2" liner and liner top packer(good test). Bleed off pressure and blow down the TD. 1/27/2016 1/28/2016 0.50 COMPZN RPCOMP PULD P Continue POOH laying down DP from 7,567.0 7,441.0 23:30 00:00 7567'to 7441'at midnight(PU=160K and SO=80K) 1/28/2016 1/28/2016 5.50 COMPZN RPCOMP PULD P Continue POOH laying down DP from 7,441.0 1,385.0 00:00 05:30 7441'to 1385'RKB. 1/28/2016 1/28/2016 0.50 COMPZN RPCOMP TRIP P TIH with the remaining four stands of 1,385.0 1,732.0 05:30 06:00 DP from derrick from 1385'to 1732' RKB. 1/28/2016 1/28/2016 0.50 COMPZN RPCOMP PULD P POOH laying down DP from 1732'to 1,732.0 1,353.0 06:00 06:30 1353'RKB. 1/28/2016 1/28/2016 2.00 COMPZN RPCOMP PULD P Lay down 33 joints of 3-1/2"heavy 1,353.0 65.0 06:30 08:30 weight DP and 9 joints of 4-3/4"drill collars. Page 25/28 Report Printed: 2/18/2016 S .�E.. •• • ,,, Operations Summary (with Timelog Depths) •. .: i o 2K-25 Conoco ro Phillips , Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time'. End Time Dur(hr) Phase Op Code Activity Code Time P-T-X Operation (MKS) End Depth(ftKS) 1/28/2016 1/28/2016 0.50 COMPZN RPCOMP BHAH P Lay down liner running tool. 65.0 0.0 08:30 09:00 1/28/2016 1/28/2016 0.50 COMPZN RPCOMP PRTS P Close the blinds and PT the 7"casing, 0.0 0.0 09:00 09:30 4-1/2"liner,and liner top packer to 2500 psi for 10 minutes(good test). Blow down the kill line. 1/28/2016 1/28/2016 0.50 COMPZN RPCOMP RURD P PU cement head and break out the 0.0 0.0 09:30 10:00 crossovers. 1/28/2016 1/28/2016 0.50 COMPZN RPCOMP RURD P Clean and clear the floor. 0.0 0.0 10:00 10:30 1/28/2016 1/28/2016 0.50 COMPZN RPCOMP RURD P PU and MU wear ring pulling tool to a 0.0 0.0 10:30 11:00 joint of DP,pull the wear ring,lay down the wear ring pulling tool,and lay down the joint of DP. 1/28/2016 1/28/2016 1.00 COMPZN RPCOMP RURD P RU GBR power tubing tongs. Change 0.0 0.0 11:00 12:00 elevator from 3-1/2"DP to 3-1/2" tubing elevators. 1/28/2016 1/28/2016 7.50 COMPZN RPCOMP PUTB P PJSM. PU and MU seal assembly. 0.0 7,527.0 12:00 19:30 RIH with 3-1/2"gas lift completion to 7527'RKB(PU=85K and SO=64K). 1/28/2016 1/28/2016 0.50 COMPZN RPCOMP SFTY P Well control drill. Well shut in time= 7,527.0 7,527.0 19:30 20:00 58 seconds and CRT=100 seconds. AAR with rig crew. 1/28/2016 1/28/2016 0.50 COMPZN RPCOMP PUTB P Continue RIH with 3-1/2"tubing,roll 7,527.0 7,620.0 20:00 20:30 the pumps at 2 BPM= 110 psi, engage the seal assembly into the SBE at 7603'RKB(200 psi increase), pumps off,continue to no-go at 7620' RKB with 10K down. 1/28/2016 1/28/2016 0.50 COMPZN RPCOMP HOSO P Lay down three joints. PU and MU 7,620.0 7,585.0 20:30 21:00 space out pups 4.18', 10.27',&10.18" and joint#234. 1/28/2016 1/28/2016 0.50 COMPZN RPCOMP THGR P PU and MU tubing hanger. MU 7,585.0 7,585.0 21:00 21:30 landing joint with circulating equipment. 1/28/2016 1/28/2016 0.50 COMPZN RPCOMP CIRC P Circulate at 2 BPM= 100 psi,RIH until 7,585.0 7,590.0 21:30 22:00 first seal engages the SBE(100 psi increase), PU until pressure bleeds off,and PU additional 2'. 1/28/2016 1/28/2016 0.25 COMPZN RPCOMP SFTY P PJSM for pumping corrosion inhibitor 7,590.0 7,590.0 22:00 22:15 with rig crew and third parties. 1/28/2016 1/28/2016 1.25 COMPZN RPCOMP CRIH P Circulate the well over to corrosion 7,590.0 7,590.0 22:15 23:30 inhibited seawater by pumping 275 bbls of 8.6 ppg corrosion inhibited seawater(ICP at 3 BPM=190 psi and FCP at 5 BPM=570 psi. Flush the surface lines with 8 bbls of seawater. 1/28/2016 1/29/2016 0.50 COMPZN RPCOMP THGR P Drain the BOP stack,land the tubing 7,590.0 7,620.0 23:30 00:00 hanger,and RILDS. 1/29/2016 1/29/2016 2.00 COMPZN RPCOMP PRTS P PT the tubing to 3000 psi for 30 0.0 0.0 00:00 02:00 minutes(good test),bleed the tubing down to 1500 psi,and PT the IA to 2500 psi for 30 minutes(good test). Bleed the IA to 0 psi and bleed the tubing to 0 psi. Quickly ramp up the pressure on the IA to shear the SOV (sheared at 2200 psi). Pump 1 bbl each way to confirm flow through the SOV. Page 26/28 Report Printed: 2/18/2016 • • Operations Summary (with Timelog Depths) 2K-25 Conocaftliffips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr) Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth MKS)', 1/29/2016 1/29/2016 0.50 COMPZN RPCOMP RURD P RD circulating equipment,lay down 0.0 0.0 02:00 02:30 landing joint,and blow down circulating lines. 1/29/2016 1/29/2016 0.50 COMPZN WHDBOP MPSP P Install 3"'HP'BPV. Pressure up on 0.0 0.0 02:30 03:00 the IA to 1000 psi to test the BPV from below in the direction of flow(good test). 1/29/2016 1/29/2016 0.50 COMPZN WHDBOP WWWH P PU a joint of DP and MU stack jetting 0.0 0.0 03:00 03:30 tool. Jet the BOP stack,lay down the stack jetting tool,and lay down the joint of DP. 1/29/2016 1/29/2016 1.00 COMPZN WHDBOP OTHR P Blow down the TD,choke manifold,kill 0.0 0.0 03:30 04:30 line,hole fill,and mud line. 1/29/2016 1/29/2016 1.50 COMPZN WHDBOP SVRG P Perform CPAI Between Wells 0.0 0.0 04:30 06:00 Maintenance(BWM)on the BOP stack: Break bolts on the lower ram doors,open doors,and function ram pistons to the closed position. Remove the 2-7/8"x 5"VBRs. The wear plate on the rams were bad; remove bad wear plate. Inspect ram cavities,sealing surfaces,and door seals. Install 7"solid body rams in the lower ram cavities. Close the lower ram doors and tighten the bolts (photos taken of all components and of stack cavities). 1/29/2016 1/29/2016 2.00 COMPZN WHDBOP SVRG P Clean out under the rotary table and 0.0 0.0 06:00 08:00 steam tables with the super sucker. 1/29/2016 1/29/2016 1.00 COMPZN WHDBOP SVRG P CPAI BWM on the BOP stack: Break 0.0 0.0 08:00 09:00 bolts on the upper ram doors,open doors,and function ram pistons to the closed position. Remove the 2-7/8"x 5"VBRs due to erosion on the corners of both rams. Inspect ram cavities, sealing surfaces,and door seals 1/29/2016 1/29/2016 2.50 COMPZN WHDBOP SVRG T Change out the wear plate and seals 0.0 0.0 09:00 11:30 on the 2-7/8"x 5"VBRs from the lower ram cavity. 1/29/2016 1/29/2016 2.00 COMPZN WHDBOP SVRG P CPAI BWM on the BOP stack: Install 0.0 0.0 11:30 13:30 the set of VBRs from the lower ram cavity with new wear plate and seals into the upper ram cavity. Close the upper ram doors and tighten the bolts (photos taken of all components and of stack cavities). 1/29/2016 1/29/2016 2.50 COMPZN WHDBOP SVRG P CPAI BWM on the BOP stack: Break 0.0 0.0 13:30 16:00 bolts on blind ram doors,open doors, and function ram piston to the closed position. Inspect ram cavities,sealing surfaces,and door seals. Inspect blind upper seal and front packer assembly.Change out the top seal on the blind rams.Close blind ram doors and tighten bolts(photos taken of all components and of stack cavities). 1/29/2016 1/29/2016 1.00 COMPZN WHDBOP SVRG P CPAI BWM on the BOP stack: Install 0.0 0.0 16:00 17:00 3-1/2"joint of DP and function annular checking for excessive wear and overall condition(photos taken of annular). Page 27/28 Report Printed: 2/18/2016 • • ` � Operations Summary (with Timelog Depths) IfTr 2K-25 ConocoPhillips Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Depth Start Time End Time Our(hr)', Phase Op Code Activity Code Time P-T-X Operation (ftKB) End Depth(ftKB) 1/29/2016 1/29/2016 2.00 COMPZN WHDBOP NUND P RU the lift ring to the bridge cranes. 0.0 0.0 17:00 19:00 ND the BOP stack,ND the DSA,and set the stack back on the stump. 1/29/2016 1/29/2016 2.75 COMPZN WHDBOP NUND P NU the tubing head adapter and set 0.0 0.0 19:00 21:45 the tree onto the tubing head adapter. DSO checked the orientation of the tree which match the original orientation but decided that a different orientation would be better. NU the tree to the tubing head adapter. Break the connection above the master valve,change the orientation of the wing valve per DSO,and tighten bolts on the flange connection. Torque the bolts on the tree and tubing head adapter. 1/29/2016 1/29/2016 1.25 COMPZN WHDBOP PRTS P PT the tubing hanger void to 250/5000 0.0 0.0 21:45 23:00 psi for 5 minutes each(good test). PT the tree to 250/5000 psi for 5 minutes each(good test). RD and blow down tree testing lines. 1/29/2016 1/29/2016 0.50 COMPZN WHDBOP MPSP P Pull 3"'HP'BPV with dry rod. 0.0 0.0 23:00 23:30 1/29/2016 1/30/2016 0.50 COMPZN WHDBOP FRZP P RU circulating lines to freeze protect 0.0 0.0 23:30 00:00 the well. 1/30/2016 1/30/2016 0.50 COMPZN WHDBOP FRZP P Continue RU circulating lines to freeze 0.0 0.0 00:00 00:30 protect the well and RU Little Red Services(LRS). 1/30/2016 1/30/2016 1.25 COMPZN WHDBOP FRZP P PT LRS lines and circulating lines to 0.0 0.0 00:30 01:45 2500 psi(good test). With LRS pump 88 bbls of diesel down the IA taking returns out the tubing to the cutting box at 2 BPM(ICP=700 psi and FCP =900 psi)and suck back 2 bbls. 1/30/2016 1/30/2016 1.25 COMPZN WHDBOP FRZP P Place the tubing and IA in 0.0 0.0 01:45 03:00 communication allowing the well to u- tube and equalize. SimOps: RD LRS. 1/30/2016 1/30/2016 0.50 COMPZN WHDBOP MPSP P Install 3"'H'BPV with dry rod. 0.0 0.0 03:00 03:30 Final well pressures: Tubing=0 psi, IA=0 psi,and OA=0 psi. 1/30/2016 1/30/2016 1.00 DEMOB MOVE RURD P RD all cellar lines and RD annulus 0.0 0.0 03:30 04:30 valve. Install Cameron manifold, secure the well,and secure the cellar. Release the rig at 04:30 hours Page 28/28 Report Printed: 2/18/2016 KUP J • 2K-25 ConocoPhillips Well Attrib Max Angle&MD TD AJdBki'2,)11 C„ Wellbore APUUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Conoot7Nldhps 501032012400 KUPARUK RIVER UNIT INJ 57.91 3,300.00 10,264.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 24-25,2/18/201610.37.20 AM SSSV:NONE Last WO: 40.09 1/26/1990 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:SLM 9,647 1 l 6 Rev Reason:WORKOVER lehallf 2/17/2016 HANGER;31.1 1/.til.iftll, 111- Casing Strings %K Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(1...Grade Top Thread w CONDUCTOR 16 15.062 35.0 115.0 115.0 62.50 H-40 WELDED �T111 '�III Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I..Grade Top Thread �+��i .- SURFACE 95/8 8.765 35.0 4,082.1 2,918.5 36.00 J-55 BTC +tyi Casing Deuription 0D(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread r► PRODUCTION 7"Tie 7 6276 33.0 2,319.0 1,927.6 26.00 L-80 Hydril 563 .� 0 ,.,f4i backRWO2016 y�q Lasing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread y4 . PRODUCTION 7 6.276 2,316.0 10,230.1 6,518.0 26.00 J-55 BTC ;iii a 4 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread LINER 4 1/2"RWO 2016 4 1/2 4.000 7,565.1 10,127.0 6,453.1 11.60 L-80 IBTM k IIII Liner Details Nominal ID i+ Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Dec Corn lin) �ti CONDUCTOR;30.0115 0- 4,877.8 54.96 PACKER 2RH ZXP wtih HD Liner Top Packer(11.54'tie back 4.310 y ,,� sleeve) 4 y 4,888.5 54.91 HANGER Double Grip Flex Lock Liner Hanger 4.390 '0'.,.4, 4,894.1 54.88 SBE Seal Bore Extension,5"TKC Pin x 5"BTC Pin 4.000 `v 4,905.2 54.64 XO Reducing Crossover Sub,5"BTCM Box x 4-1/2"IBT Pin 3.930 PRODUCTION T TM back t *4 10,096.2 6,433.7 50.69 COLLAR Float Collar,Weatherford,4-1/2",12.6#,L-80,IBTM 2.000 RWO 2016;33.0-2,319.0 Box x Pin Tubing Strings GAS LIFT,3,315.1 Tubing Description Ma...ID(in) Top(ftKB) Set Depth(ft.(Set Depth)TVD)(...Wt(l ) Grade Top Connection E TUBING RWO 2016 1String 3 1/21 2.9921 31.11 b /ft 7,620.3 4,909.61 9.301 L- 80 I EUE 8rd Mod . I li, Completion Details Nominal ID Top(MB) Top(ND)(ftKB) Top Incl(°) Item Des Cam (dd 31.1 31.1 0.07 HANGER Cameron Tubing Hanger,CXS,7-1/16"x 3-1/2"EUE 8rd 2.920 I Box x Box,3"H BPVG SURFACE 35.0-4.082.1--• 7,534.7 4,860.3 55.05 NIPPLE Nipple,HES,2.813"X,SN: 11X28127 2.812 7,584.3 4,888.8 54.91 LOCATOR Locator Sub,GHB-22(bottom of locator spaced out 7.29') 2.990 GAS LAG 5.2986 7,585.4 4,889.4 54.90 SEAL ASSY Seal Assembly,80-40 2.990 Perforations&Slots Shot 4 Dens Top(ND) Mtn TVD) (shots/ GAS LIFT;6,718.1 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 9,778.0 9,792.0 6,234.5 6,243.1 C-4,2K-25 12/9/1993 6.0 APERF 2 1/8"EnerJet;90 deg. Ph 9,860.0 9,880.0 6,284.9 6,297.3 A-5,2K-25 12/9/1993 6.0 APERF 2 1/8"EnerJet;90 deg. PH GAS LIFT;7,473.6 9,912.0 9,948.0 6,317.1 6,339.6 A-4,2K-25 5/17/1990 4.0 (PERF 4.5"HLS CSG Guns;180 deg.Ph 9,918.0 9,944.0 6,320.9 6,337.1 A-4,2K-25 11/20/1993 3.0 RPERF 2 1/8"EnerJet;Oriented 45 deg.CW NIPPLE,7534 7 ;37..::: Squeezes .. I Top(ND) Btm(ND) Top(ftKB) Btm(ftKB) )ftKB) (ftKB) Des Start Date Com 33.0 2,319.0 33.0 1,927.6 Cement?"x 1/16/2016 9.625"Annulus f/ 2,319-ft to t a surface a V 7,565.1 10,127.0 4,877.8 6,453.1 Liner Cement 1/27,2016 PT cement line to 250/5000 psi(good test). Pump 15 it'' y bbls 14.5 ppg mud push at 3 BPM=1700 psi followed LOCATOR;7,584.3 A V by 64 bb's 15.8 ppg cement at 3 BPM=1600 psi,drop irargt the dart,and chase with 10 bb's of fresh water. Swap 0 ,y to the rig pumps,displace the DP with 11.1 ppg brine SEAL ASSY;7,585.4 lit,LN.14c at 5 BPM=3300 psi,slow pumps to 3 BPM=2300 psi,and bumped the plugs at 3200 psi. Check the I-atr 0 float and the float is holding. Swap to SLB cementers, '47-11Tir. pressure up 4800 psi to set the liner hanger,and set Or down 50K to ensure liner hanger is set. PU 65K and Or= rotate 15 turns to the right with 4K ft-lbs free torque at 140K hook load to release the liner running tool. Bring the pump on line at 3 BPM=1570 psi and 4 BPM= 1900 psi. Pull packoff and dog sub out. Circulate 40 bbls to clear any cement off the top of the liner top packer then slow the pumps to 2 BPM=1200 psi. SO 80K to set the ZXP liner top packer(saw indicating .i; shear),PU,and set down 80K again. PU,rotate at 15 RPM=5K ft-lbs free torque,SO 50K,stop the rotary, and PU off ZXP liner top packer. i kV rit r4 Mandrel Inserts Y r at i, i S� onTop(ND) Valve Latch Port Size TRO Run el1�-:'l N Top(ftKB) (ftKB) Make Model OD(in) Ser, Type Type yn) (psi) Run Date Corn DMY 0.000 1/28/2016 #'6'�kl EEIiiI ®®®a ® 1 1111111 1 6 .t . 1 a 1111 1 •ii 4 7,473.6 4,825.4 Camco MMG 11/2 GAS LIFT DMY RKP 0.000 0.0 2/7/2016 mo�iy/,, Notes:General&Safety .44����'' F End Date Annotation 7` eil 2/11/2010 NOTE:LEAK FOUND BETWEEN GLM#3 @ 7557'&GLM#4 @ 8450' LINER 412°RWO 2016; SiQ ck? 5/8/2010 NOTE PACKER LEAK @ 9654',LLR=0.5 gpm @ 3000 psi 7,56E1-10,127.0 5/9/2010 NOTE:Confirmed Tubing Leaks @ 8087',8187',8244'w/Eline LDL 11/5/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 PRODUCTION;2,316.0- 10,230.1 V OF 71. 1,1 yy,..6. THE STATE Alaska Oil and Gas ti ..___— ••• ••• =--7,',1 4A /� ]� Conservation Commission i,,,, op, ,, 333 West Seventh Avenue "-`� GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 O!"ALAS' Fax: 907.276.7542 www.aogcc.alaska.gov Ron Phillips Senior CTD EngineerEB ?0`1 j ConocoPhillips Alaska, Inc. P.O. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2K-25 Permit to Drill Number: 190-012 Sundry Number: 316-072 Dear Mr. Phillips: 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, /317R24.,,))-4 . Cathy P oerster Chair DATED this I?day of February, 2016. RBDMS I t- FEB 1 9 2016 RECEIVED • 0 1-EB 0 3 2016 STATE OF ALASKA ��� —) 1I ALASKA OIL AND GAS CONSERVATION COMMISSION A C /6 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate 0 • Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well Q + Alter Casing ❑ Other. ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number ConocoPhillips Alaska Inc Exploratory ❑ Development ❑ 190-012 3.Address: Stratigraphic ❑ Service 0 , 6.API Number P.O.Box 100360 Anchorage,AK 99510-0360 50-103-20124-00 - 7.If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? 4i0 3Z L KRU 2K-25• Will planned perforations require a spacing exception? Yes ❑ No❑� / 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 0025605 Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY(post RWO Jan.2016) Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10,264' . • 6539' • 10230' • 6518' 4170 psig none none Casing Length Size MD TVD Burst Collapse Conductor/Structural 80' 16" 115' 115' Surface 4,047' 9-5/8" 4,082' 2,919' Production 10,197' 7" 10,224' 6,514' Scab Liner 2,562' 4-1/2" 10,133' 6,457' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): perfs will be cemented off 3.5 L-80 7,620' Packers and SSSV Type: SSSV-NONE Packers and SSSV MD(ft)and TVD(ft): SSSV-N/A PACKER-BAKER ZXP LINER TOP PACKER PACKER-7571'MD,4881'TVD 12.Attachments: Proposal Summary Q Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program n BOP Sketch ❑ Exploratory ❑ Stratigraphic El Development❑✓ Service El 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 2/17/2016 OIL [)5 WINJ ❑ WDSPL ❑ Suspended Li 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact: R.Phillips @ 265-6312 Email: Ron.LPhillips@cop.com Printed Name: Ron Phillips Title: Senior CTD Engineer Signature: Z OA, Phone: 265-6312 Date: 02/02/2016 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 31 (J—01 a Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes No ❑ Spacing Exception Required? Yes ❑ No g/ Subsequent Form Required: /d —4 0 4 RBDMS I.L FEB 1 9 2016 a/67APPROVED BY Approved by: 6 -�L/ ( COMMISSIONER THECDate: 2 [ 7 / �OII T �` 2i'��l 0 R� (Subbmiitt Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 on sJ0NAt approval. Attachments in Duplicate • • KRU 2K-25 CTD Summary for Re-perforating Sundry (10-403) Summary of Operations: Well 2K-25 was a Kuparuk A-sand/C-sand injection(service)well equipped with 31/2'tubing and 7" production casing. The well was worked over by cementing a 4-1/2" scab liner in place and completing with a new 3-1/2"completion. The scab liner covered the A-sand and C-sand perforations and was cemented in place. Three CTD laterals will be drilled from the 2K-25,two to the south and one to the north of the current location and will target the Kuparuk A4/5-sands. Lateral 2K-25A is planned for 3480',2K-25AL1 is planned for 3278' and 2K-25AL3 is planned for 1780'. Prior to drilling,the plugged A-sand perfs in 2K-25 will be re-perforated(for pressure monitoring purposes)from 9938'-9918' and 9880'-9860' and a whipstock will be set in the A-sand perforations. The laterals will be completed with 2-%" slotted liner from TD to the final liner top located inside the 41/2"scab liner just above the whipstock at 9915' MD. CTD Drill and Complete 2K-25 Lateral: March 2015 Pre-CTD Work 5 1. Pull the BPV,re-perforate the Kuparuk A-sands and drift for a whipstock. j - c1 v 2. Set a whipstock, perform a SBHP test and set a BPV. 3. Prep site for Nabors CDR2-AC. Rig Work 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE,test. w S 2. 2K-25A sidetrack(A4 sand south) a. Mill 2.80"window at 9,920' MD. b. Drill 3"bi-center lateral to TD of 13,400' MD. c. Run 2%"slotted liner with an aluminum billet from TD up to 10,122' MD. 3. 2K-25AL1 Lateral(A5 sand south) a. Kick off of the aluminum billet at 10,122' MD. b. Drill 3"bi-center lateral to TD of 13,400' MD. c. Run 2%" slotted liner from TD up to 10,020' MD. 4. 2K-25AL2 Lateral(A4/5 sands north) a. Kick off of the aluminum billet at 10,020' MD. b. Drill 3"bi-center lateral to TD of 11,800' MD. c. Run 2%"slotted liner from TD up to 9,915' MD,just above the whipstock 5. Freeze protect. Set BPV,ND BOPE. RDMO Nabors CRD2-AC. Post-Rig Work 1. Pull BPV. 2. Install GLV's 3. Return to production. Page 1 of 1 2/3/2016 • 0 2K-25 Post RWO Schematic Modified by RLP 2/2/2016 3'/z"9.3#L-80 EUE 8rd-Mod tubing to surface 3'/2'Camco gas lift mandrel @ 3315,5299',6718',7474' RKB 16",62.5#,H-40 at 115'MD 31/2'X-nipple @ 7535'RKB (2.813"min ID) 11- 3'/2'9.3#L-80 Mule Shoe @ 7620'RKB Baker ZXP packer @ 7571'RKB 9-5/8",36#,J-55 at 4082'MD Baker Flexlock liner hanger at 7590'RKB Baker SBE @ 7600'RKB 4'/2'scab liner cemented in place. **Three KO joints 9820'-9946'PDC for CTD exits ti .;: **E-line not needed to log in place,but instead use existing ,ti jewelry to correlate depth** L. ti. '/ 2**No centralizers on these 3 kickout joints.All other 4 ' Lk joints are centralized. * ti **Landing collar @ 10065'MD** ti ▪., C-sand perfs(sgz'd) ti. -- 9778'-9792'MD ... ;ti: L5 ei ti ;i: Ikl ti: Lk Ikl Lk ez ▪. Lti .- .i �, A-sand perfs isgz'i) ▪? 9860'-9880'MD Lkti �' 9912'-9948'MD L —_ :- ;. 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G, C. , ,,,. .1�:{.:..R:,....,.{:ti::.:a:L..Lr.Lf.... ,II'•:%.:t.:ti:t1 ........".........:'-'7:4:d:'.:'". rlj.i'�.�,1 -c - }r'}r r'}�i}i}, COViareffie }g}}r} r'}, ;r}}}w'1} UII_.r.......r:r.r•ey!......1.1.r.r.r.r.r.r.r , r.r.r........7.1 .........................1r1.j.1. ;`,11.1.14;•r'Ji`, O Q IIt li ' 465 ❑❑ CL o g N o oLOp N °')N 'tN �❑❑ CO 01 =32 LC)Y - 00 O co 1*-rCO N � Vc- N Od. a. 11 n NN 4)N CO aD Q W m CM t :1 O _ O (O Nn -0 CD OOOO r c- ,- Um 03ON dCOCO 'O L N O gd c <O)O) -0 , , C N 2 m a_ < 0)0) NCU -I^-' L N N- Y N N • • • Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) ,V Sent: Friday, February 12, 2016 9:35 AM , o To: 'Phillips, Ron L' v\r Subject: RE: KRU 2K-25(PTD 190-012, Sundry 316-072), KRU 2K-25L1, -L-3" Ron, Could you please send me the updated wellbore schematic with the named laterals. I don't see the schematic in the submitted revised PTDs. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp@a laska.Qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeop@alaska.gov From: Phillips, Ron L [mailto:Ron.L.Phillips@conocophillips.com] Sent: Monday, February 08, 2016 8:00 AM To: Loepp, Victoria T(DOA); Eller, J Gary Cc: Bettis, Patricia K(DOA) Subject: RE: KRU 2K-25(PTD 190-012, Sundry 316-072), KRU 2K-25L1, -L2, -L3 Victoria, I can name the laterals 2K-25L1,-L2 &-L3 as you suggest or I can name them 2K-25L1, -L1-01 and—L1-02 since the second and third laterals kick off the—L1 lateral. I have all the paper work completed with the names you suggested (2K- 25L1,-L2 &-L3)then Gary Eller recommended (2K-25L1,-L1-01 and—L1-02). It makes little difference to us,we just need to get this done as soon as possible since we are now moving off the KRU 3G-04 well due to poor pre-rig cement.The plan is to move to 1G-11 then back to 3G-04 if we can get a good cement job before moving to 2K-25. Thanks, Ron L. Phillips Senior CTD Engineer ConocoPhillips Alaska Phone 265-6312 Cell 317-5092 1 • • From: Loepp, Victoria T(DOA) [mailto:victoria.loeppt alaska.gov] Sent: Friday, February 05, 2016 11:23 AM To: Eller, J Gary Cc: Phillips, Ron L; Bettis, Patricia K(DOA) Subject: [EXTERNAL]RE: KRU 2K-25(PTD 190-012, Sundry 316-072), KRU 2K-25L1, -L2, -L3 Thanx, Gary, I think the correct way to name these 3 laterals is as 2K-25L1,-L2&-L3. It looks like there will still be open A sand perforations after the whipstock is set although you expect little or no fluids. We have not assigned API #s or PTD#s yet so we would like you to resubmit the three laterals with the corrected names. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loepp(cD_alaska.gov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victorialoeoo@alaska.gov From: Eller, J Gary [mailto:J.Gary.Eller(aconocophillips.com] Sent: Friday, February 05, 2016 11:01 AM To: Loepp, Victoria T(DOA) Cc: Phillips, Ron L Subject: RE: KRU 2K-25(PTD 190-012, Sundry 316-072), KRU 2K-25A? Victoria—I'm open to suggestions on how you want to name these. My thinking was that we're strictly perforating for purposes of capturing a static BHP,and it's likely that the unstimulated perfs will produce little to no fluids. But that being said, it really makes little difference to me whether we label the first CTD borehole as a sidetrack or a lateral. Please let me know how you prefer to do it, and that's what we'll do this time and going forward. -Gary Eller From: Loepp, Victoria T(DOA) [mailto:victoria.Ioepp©alaska.gov] Sent: Friday, February 05, 2016 9:59 AM To: Phillips, Ron L Subject: [EXTERNAL]KRU 2K-25(PTD 190-012, Sundry 316-072), KRU 2K-25A? Ron, If the A Sand is reperforated in KRU 2K-25 and is capable of producing from the A sand then the three laterals would all be laterals;there would be no 2K-25A(redrill). Please clarify. Thanx, 2 • I Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppaa laska.qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepo@alaska.gov 3 ,ao- o‘z • • 2C0`6 t 3 WELL LOG TRANSMITTAL#903036600 To: Alaska Oil and Gas Conservation Comm�ECEirt February 5, 2016 Attn.: Makana Bender FEB 1 0 2010 333 West 7th Avenue, Suite 100 DATA LOGGE 2./25/201c9 Anchorage, Alaska 99501 AOGCC M.K.BENDEr, RE: String Shot, RCT, Cement Bond Log, Plug, and Multi Finger Caliper Records: 2K-25 Run Date: 1/2/2016 ANS 1/5/2016 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage,AK 99518 FRS_ANC@halliburton.com 2K-25 Data in LAS format, Digital Log Image files 1 CD Rom 50-103-20124-00 String Shot,RCT,Cement Bond Log,Plug, and Multi Eager_Caliper.Recc Records__ 1 Color Log-each 50-103-20124-00 %WYnC'pp�MM$q�' PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: / ,Al,�2, , t., alb • 1G - G t �_ Loepp, Victoria T (DOA) From: Loepp, Victoria T (DOA) Sent: Monday, February 08, 2016 3:19 PM To: Beat, Andrew T Subject: Re: PTD 190-012 Follow Up Flag: Follow up Flag Status: Completed scANNED MAY 1 9 2U16 Andrew, This appears to be a plug for redrill. If you are abandoning a well bore than a 10-407 is required. Let me know if you still have questions. Thanx, Victoria On Feb 8, 2016, at 3:12 PM, Beat, Andrew T <Andrew.T.Beat@conocophillips.com>wrote: Victoria, I would like some clarification on the sundry approval for 2K-25. The approval we received noted that a 10-407 was required after completing the workover. My understanding is that 404's are required after workovers and 407's are reserved for the completion of the CTD work. We did not do an completing or recompleting during the workover so the 407 doesn't seem as applicable as the 404. If you could give me some guidance on this I would appreciate it. Thank you, Andrew Beat Senior Wells Engineer ConocoPhillips Alaska (281)928-0463 cell (907) 265-6341 office <2K-25 10-403 Approved Sundry Application.pdf> 1 • • Loepp, Victoria T (DOA) From: Phillips, Ron L <Ron.L.Phillips@conocophillips.com> Sent: Monday, February 08, 2016 8:00 AM To: Loepp, Victoria T (DOA); Eller,J Gary Cc: Bettis, Patricia K (DOA) Subject: RE: KRU 2K-25(PTD 190-012, Sundry 316-072), KRU 2K-25L1, -L2, -L3 Follow Up Flag: Follow up Flag Status: Flagged Victoria, I can name the laterals 2K-25L1,-L2&-L3 as you suggest or I can name them 2K-25L1,-L1-01 and—L1-02 since the second and third laterals kick off the—L1 lateral. I have all the paper work completed with the names you suggested (2K- 25L1,-L2 &-L3)then Gary Eller recommended (2K-25L1, -L1-01 and—L1-02). It makes little difference to us,we just need to get this done as soon as possible since we are now moving off the KRU 3G-04 well due to poor pre-rig cement.The plan is to move to 1G-11 then back to 3G-04 if we can get a good cement job before moving to 2K-25. Thanks, Ron L. Phillips Senior CTD Engineer ConocoPhillips Alaska Phone 265-6312 Cell 317-5092 From: Loepp, Victoria T(DOA) [mailto:victoria.loeDDOalaska.gov] Sent: Friday, February 05, 2016 11:23 AM To: Eller, J Gary Cc: Phillips, Ron L; Bettis, Patricia K (DOA) Subject: [EXTERNAL]RE: KRU 2K-25(PTD 190-012, Sundry 316-072), KRU 2K-25L1, -L2, -L3 Thanx, Gary, I think the correct way to name these 3 laterals is as 2K-25L1,-L2 &-L3. It looks like there will still be open A sand perforations after the whipstock is set although you expect little or no fluids. We have not assigned API #s or PTD Us yet so we would like you to resubmit the three laterals with the corrected names. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppft,alaska.aov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended 1 recipient of this e-mail,please delete it,wi out first saving or forwarding it,and,so that the ACC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeaa@alaska.gov From: Eller, 3 Gary [mailto:J.Gary.Eller(u�conocophillips.com] Sent: Friday, February 05, 2016 11:01 AM To: Loepp, Victoria T(DOA) Cc: Phillips, Ron L Subject: RE: KRU 2K-25(PTD 190-012, Sundry 316-072), KRU 2K-25A? Victoria—I'm open to suggestions on how you want to name these. My thinking was that we're strictly perforating for purposes of capturing a static BHP, and it's likely that the unstimulated perfs will produce little to no fluids. But that being said, it really makes little difference to me whether we label the first CTD borehole as a sidetrack or a lateral. Please let me know how you prefer to do it, and that's what we'll do this time and going forward. -Gary Eller From: Loepp, Victoria T(DOA) [mailto:victoria.loepp@ alaska.gov] Sent: Friday, February 05, 2016 9:59 AM To: Phillips, Ron L Subject: [EXTERNAL]KRU 2K-25(PTD 190-012, Sundry 316-072), KRU 2K-25A? Ron, If the A Sand is reperforated in KRU 2K-25 and is capable of producing from the A sand then the three laterals would all be laterals;there would be no 2K-25A(redrill). Please clarify. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeppa.a laska.q ov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loepo@alaska.gov 2 • • LGA-ial ZK--?5 Pr6 1600 ' Regg, James B (DOA) From: Regg, James B (DOA) 116116, Sent: Wednesday,January 06, 2016 11:53 AM To: Beat, Andrew T Cc: Packer,J.Brett; Herbert, Frederick 0; Kanady, Randall B; DOA AOGCC Prudhoe Bay; Loepp, Victoria T (DOA); Schwartz, Guy L (DOA) Subject: RE: 2K-25 (Nabors 7ES)Weekly BOP Test Waiver Request Andrew and Brett— Thank you for taking time this morning to meet with us regarding the well work on suspended well KRU 2K-25 (PTD 1900120) and the request (below)to delay the BOPE test. Based on the information provided and discussions this morning, your request to delay the BOPE test is approved. To confirm the integrity after re-installation of BOP stack (after pulling the tubing head), the BOP stack flange connection to the casing spool must be tested (no test report, no AOGCC witness required; retain chart for your records). The next BOPE test will be required at the first opportunity after re-installing the 7"tubing head. Jim Regg Supervisor, Inspections AOGCC sCOtEw SEP U 6 2O1 333 W.7th Ave,Suite 100 Anchorage,AK 99501 907-793-1236 CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information. The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Jim Regg at 907- 793-1236 or iim.reggt alaska.gov. From: Beat, Andrew T [mailto:Andrew.T.Beat©conocophillips.com] Sent: Wednesday, January 06, 2016 9:53 AM To: Regg, James B (DOA); Loepp, Victoria T(DOA) Cc: Packer, J.Brett; Herbert, Frederick 0; Kanady, Randall B Subject: 2K-25 (Nabors 7ES) Weekly BOP Test Waiver Request Jim, We are requesting a waiver from the weekly BOP test for Nabors 7ES on 2K-25 on account of having to do a subsidence c repair. Attached is an overview of the current situation that we briefly discussed over the phone.This is a previously suspended well that still has a cement plug set around the perfs and production packer. It has passed all DDT's since it was pumped 4 years ago. We have also set an additional plug in the 7" below the zone where we will be doing our repairs. 1 • We need to remove the tuba+ in order to pull the 7" and will lose the abilit• pressure test our stack from that 'time until we land our new 7" and re-install the tubing head.At that time, we will test our BOP stack to the required pressures. Please let me know if you have any questions. Thanks, Andrew 2 ConocoPhillips 2K-25 p KR Injector U CTD Setup w/ 4.5" Well Details: API: 501032012400 Cemented Liner PTD: 190-012 Wellhead: FMC Gen IV 5M Tree:WKM 3"5M Casing/Tubing Details: Planned 7" Casing Cut @ 2,320' KB 16"62.5#H-40 Conductor to 115' KB 9-5/8" 36#J-55 Surface to 4,082' KB 7"26#J-55 Production to 10,230' KB 3-1/2"9.3#L-80 Tubing to—9,650' KB IBP 2,910' KB 4-1/2" 11.6#L-80 Liner to—9,950' KB 9-5/8" Casing Shoe On-Rig Tubing Cut GLM #6 Pre-Rig Tubing Cut �'; • PBR ' . Packer • r 1,11 Pt, rtA "PASSE, Z► WAS iUr4.PE• IA) .//////// C Sand Perfs A Sand Perfs Date: January 5,2016 I Drawn By: Andrew Beat ConocoPhillips 0 ! Alaska Calculations Char. Subject Sheet number KAt 2k--Z7 prn t6loolzk,, of File By Date C./ .a t) " ,` , (k)61-.LI:\` ' 7E-5 to , A. kikt3 T A f *7 1 y ;a 7F ' t x , � ;,. P� Ga tet . f � . , Al f t , , P Ui' t 1 i i 1 7— I i E o S R Aloe; [—"I ta)9, f,12 A t .L, �_ I s ,.-1)...w,2, _ p , 1.I ,t 'v °,k2 4.,.fir, a ConocoPhillips 0 S Alaska Calculations Chari e SubjectSheet number kretA Z�� Z 106)1 of File By Date C\\Ic•--r 1;ElYit bt)(4-1.-Aikt,--' tt t i MCIT ter. C ? " 0 P i4017~~r c 1-0 i t'w°wm`I (--1,0c--, ., e_po€v ,} 'm.'1k 't ins.,/ A W tr v -%. TIJF tt V1 t i .. VL-;& o c :.. ,,,);.. 7" 11,,r T; p . ' " .(t/ea .__ A- . - V 'J Lao. (20: t :) ' \} k ___ ___ ,, „ ,)1,:t ': Wa4- '' 1 AA LA, E 1 1 ui zj3 , 'N -C _f oLuT J1-AJG THE. f lit).0 1 ..., itRA 4^,�d 4i tJ t' f, ,,,,IV ri irr ezr'Y .. m�, Fa v) i,)owr A?) L. { To "i " / Gti _r —v1tr?pTe Ptir -- 1 r" O € °- li `.,,.' wP c_ k...., Cape,pit.(c1 g_ tVA►Lp • ti ®F 7, 4. • S I y77;s), THE STATE Alaska Oil and Gas • 4F of Conservation Commission LAsKA. s - 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 L_XS Fax: 907.276.7542 www.aogcc.alaska.gov Andrew T. Beat coNS) DEC 0 3 2015 Sr. Wells Engineer Igo- D (- ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 2K-25 Sundry Number: 315-713 Dear Mr. Beat: 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, )0)/I Daniel T. Seamount, Jr. 3-"/ ' ' Commissioner DATED this day of December, 2015 Encl. 3C- 5 RBDMS X,e412015 i • RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION NOV 20 2015 APPLICATION FOR SUNDRY APPROVALS �► 20 AAC 25.280 A no 1.Type of Request: Abandon ❑ Plug Perforations E. Fracture Stimulate ❑ Repair Well C Operations shutdown Suspend ❑ , .<. Perforate ❑ Other Stimulate ❑ Pull Tubing P•`)1 Change Approved Program❑ Plug for Redrill L Perforate New Pool ❑ Re-enter Susp Well VA + Alter Casing yr- Other: CTU Se 1-7, i 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. ' Exploratory ❑ Development ❑ 190-012 3.Address: 6.API Number: Stratigraphic ❑ Service P. P.O. Box 100360,Anchorage,Alaska 99510 50-103-20124-00 7. If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n/a KRU 2K-25 Will planned perforations require a spacing exception? Yes ❑ No 0 / 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 0025605 . Kuparuk River Field/ Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10,264' 6,539' . 10230 ' 6518 . 3867 none none Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 16" 115' 115' Surface 4,047' 10" 4,082' 2,918' Intermediate Production 10,197' 7" 10,230' 6,518' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9778'-9944' ' 6234'-6337' 2.875" L-80 9700' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-BAKER HB PACKER MD=9650 TVD=6155 SAFETY VLV-OTIS FMX SSSV(LOCKEPEN) MD=1814 TVD=1628 12.Attachments: Proposal Summary Wellbore schematic 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service 0 14.Estimated Date for 15.Well Status after proposed work: 1/4/2016 Commencing Operations: OIL CI WINJ [ . WDSPL CI Suspended lc 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Andrew T.Beat @ 265-6341 Email Andrew.T.Beat@conocophillips.com Printed Name Andrew T.Beat @ 265-6341 Title Sr.Wells Engineer Signature _=••• Date II/20/Z'i6 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: KA-1 06i) r s z /..?o e T Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes LI No 7( Subsequent Form Required: / L<, — el c -ii.. 0APPROVED BY I z �1 1_5Approved by: r COMMISSIONER THE COMMISSION Date: it 2-i--/.s— fik X1123 J/s Form Revised 11/2015 ORIGINAL, 2 months from the date of approve. dttach fienuplicate • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 November 20,2015 Commissioner State of Alaska Alaska Oil&Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage,Alaska 99501 Dear Commissioner: ConocoPhillips Alaska,Inc.hereby submits an Application for Sundry Approvalwork over Kuparuk Injector 2K-25 (PTD# 190-012). (C-to 2K-25 was originally drilled and completed in 1990 as an'A' and 'C' sand,gas lifted producer in Kuparuk. In 2002, the well was converted to injection. In 2010,communication between the tubing and IA was reported and the well -7 was suspended in 2011,This well has been identified as a candidate for our 2016 CTD program. / The proposed workover scope for 2K-25 will cover pulling the existing 2-7/8"completion, cleaning up any remaining cement debris,and installing a new 3-1/2"completion with a 4-1/2"cemented liner set below the production packer. ti L (Led (� J,.-i( Cep e,, , a-L . /r.s6•l S If you have any questions or require any further information,please contact me at 265-6341. Sincerely, Andrew Beat Wells Engineer CPAI Drilling and Wells • • 2K-25 Rig Workover • CTD Setup—3-1/2"Tbg w/4-1/2"Cmtd Liner (PTD#: 190-012) Current Status: This well has been suspended since 2011 and is currently waiting to be worked over to prepare the well for CTD. Scope of Work: Pull the existing 2-7/8"tubing,cleanout cement debris,and install new 3-1/2"completion with a 4-1/2"cemented liner. General Well info: Well Type: Injector MPSP: 3,867 psi using 0.1 psi/ft gradient Reservoir Pressure/TVD: 4,484 psi/6,174' TVD(14.0 ppg EMW)measured on 04/09/2011 Wellhead type/pressure rating: FMC Gen IV,7"5M psi top flange BOP configuration: Annular/Pipe Rams/Blind Rams/Mud Cross/Pipe Rams MIT results: CMIT-TxIA failed-05/07/2010 Earliest Estimated Start Date: January 2,2016 Production Engineer: David Neville Workover Engineer: Andrew Beat(263-6341/Andrew.T.Beat@ConocoPhillips.com) Pre-Rig Work 1. Inspect pad and work area for hazards.Complete the PJSM. 2. Mill cement inside tubing past retainer with coil tubing. 3. Obtain an updated SBHP survey. 4. Perform a CBL to find top of cement behind tubing. -�i^c n. a c 5. Pull dummy valve from GLM#5. E- 6. Cut the tubing at 9,655 RKB (5'below packer). 7. PT POs and FT LDS. Set BPV w/i 24 hrs of rig arrival. Workover Procedure 1. MIRU. 2. Pull BPV.Reverse circulate KWF. Obtain SITP&SICP,if still seeing pressure at surface,calculate new KWF, weight up, and repeat circulation as necessary.Verify well is dead. 3. Set BPV,ND tree,NU BOPE&test to 250/ psi. Oval a. If the lower pipe rams are unable to be tested because of the blanking plug position,the lower pipe rams will be tested upon pulling the completion. 4. Pull BPV,screw in landing joint,BOLDS's,unland tubing hanger. 5. POOH laying down 2-7/8"tubing. 6. MU and RIH with 2-7/8"spear. Spear the PBR and jar the packer free.POOH with packer. 7. MU burn shoe wash pipe.Burn over cemented tubing tail down past the cement retainer. POOH. 8. MU o ershot assembly and latch onto tubing tail.POOH with tubing tail. 9. MU cleanout assembly and cleanout to PBTD. 10. RIH with 4-1/2"liner and liner top packer. 11. Pump cement around liner and set liner hanger and liner top packer. 12. Swap the well over to seawater and POOH. %_ =u s,"}�� {fi Zs��P l 13. RIH with new 3-1/2"tubing and sting into SBE until fully located. Space out and MU hanger. 14. Pump corrosion inhibited fluid around and re-engage seals. 1 • • 2K-25 Rig Workover • CTD Setup—3-1/2"Tbg w/4-1/2"Cmtd Liner (PTD#: 190-012) 15. Land the tubing hanger,RILDS. 16. PT the tubing,bleed tubing,PT the IA,and record.Bleed the IA to zero,then tubing.Ramp up the IA pressure quickly to shear the SOV. 17. Pull the landing joint,install BPV.Pressure test the BPV from below. 18. ND BOPE. 19. NU tree.Pull BPV and install tree test plug.Test tree and pull test plug. 20. Freeze protect well with diesel. Set BPV. 21. RDMO. Post-Rig Work 1. Pull BPV. a• 4.0, 2. RU Slickline to pull SOV and run gas lift design. ? ( D V ' 3. Reset well house(s)and flowlines of adjacent wells. 4. Turn well over to operations. 2 2K-25 ConocoPhillips I KRU Injector CTD Setup w/ 4.5" Well Details: Cemented Liner API: 501032012400 PROPOSED PTD: 190-012 I Wellhead: FMC Gen IV 5M 4 COMPLETION Tree: WKM 3" 5M Casing/Tubing Details: 16"62.5#H-40 Conductor to 115' KB Baker Orbit Valve — 3,800' 9-5/8" 36#J-55 Surface to 4,082' KB 7"26#J-55 Production to 6,517' KB 3-1/2" 9.3# L-80 Tubing to-9,650' KB 4-1/2" 11.6# L-80 Liner to-9,950' KB Misc Details: Max Inclination: 57.91° Max Dogleg: 5.41 °/100' Last Tagged Fill: 9,603' KB (TOC) Total Depth: 10,264' KB — Camco 3-1/z" x 1-1/2" MMG GLM's Perforation Details: 9,778'-9,792' KB-C-4 Sand 9,860'-9,880' KB-A-5 Sand 9,912'-9,948' KB-A-4 Sand 9,918'-9,944' KB-A-4 Sand 2.813" X Nipple Baker 80-40 PBR ' . Baker ZXP Liner Top Packer C Sand Perfs tJ�L( a and �� srt Date: November 20,2015 I Drawn By: Andrew Beat KUP • 2K-25 ConocoPhillips : Well Attrib Max Angle&MD TD Al.ivka Inc;, Wellbore APVUWI Field Name Wellbore Status ncl I') MD(ftKB) Act 8tm(ftKB) Carw,,e0hali,, 501032012400 KUPARUK RIVER UNIT INJ 57.91 3,300.00 10,264.0 ... V Comment H25(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2K-25,11/20/2015 10:5240 AM SSSV:LOCKED OPEN Last WO: 40.09 1/26/1990 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:TOC(SLM)9,603.0 3/12/2015 Rev Reason:TAG TOC hipshkf 3/15/2015 1;p 'f HANGER,31.1 i�(e 111f Casing Strings 1A"' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ORB) Set Depth(TVD)... WtlLen(I...Grade Top Thread se .4 CONDUCTOR 16 15.062 35.0 115.0 115.0 62.50 H-40 WELDED i iCasing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.765 35.0 4,082.1 2,918.5 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread �� �f��PRODUCTION 7 6.276 33.0 10,230.1 6,517.9 26.00 J-55 BTC Tubing Strings -.-,•••CONDUCTOR;35 0.715.0 Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING 27/8 2.441 31.1 9,700.0 6,186.4 6.501-80 EUE-mod Completion Details Nominal ID SAFETY VLV;1,814.2 1%. Top(ftKB) Top(TVD)(ftKB) Top Incl('1 Item Des Com (in) 31.1 31.1 0.07 HANGER FMC GEN IV TUBING HANGER 2.875 I1,814.2 1,628.3 51.94 SAFETY VLV 'OTIS FMX SSSV(LOCKED OPEN) 2.313 GAS LIFT;3,020.5 9,635.7 6,146.4 51.43 PBR BAKER 80-32 w/10'Stroke PBR w/3.25"SEAL BORE 2.430 9,649.7 6,155.1 51.48 PACKER BAKER HB PACKER 2.430 9,687.6 6,178.7 51.64 NIPPLE CAMCO D NIPPLE 2.250 9,699.2 6,185.9 51.69 SOS BAKER SHEAR OUT 2.441 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl L Top(ftKB) (ftKB) r) Des Corn Run Date ID(in) SURFACE;35.0<,082.1 9,656.0 6,159.0 51.51 TBG CMT 2.13"x9.41'CEMENT RETAINER-PUMPED 20.9 4/17/2011 0.530 Retainer BBLS CEMENT 15.8ppg'G'TYPE;APPROX 25 bbl GAS LIFT;5,842.8 ON TOP OF RETAINER;APPROX TOC @ 9615' 9,675.0 6,170.9 51.59 TBG Punches TUBING PUNCHES,4 SPF,0 degree phase,2" 4/16/2011 2.441 al circulation charges GAS LIFT;7,557.1 9,705.0 6,189.5 51.72 CSG CMT CEMENT RETAINER;MILLED DOWN TO 9692' 4/10/2011 IIIRetainer w/2.36"REAMER FOR TUBING PUNCHES GAS LIFT;8,449.8ll Perforations&Slots 111 Shot Dens Top(ND) Btm(ND) (shoal I Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 9,778.0 9,792.0 6,234.5 6,243.1 C-4,2K-25 12/9/1993 6.0 APERF 2 1/8"EnerJet;90 deg. GAS LIFT;9,030.3 Ph 9,860.0 9,880.0 6,284.9 6,297.3 A-5,2K-25 12/9/1993 6.0 APERF 2 1/8"EnerJet;90 deg. PH I 9,912.0 9,948.0 6,317.1 6,339.6 A-4,2K-25 5/17/1990 4.0 IPERF 4.5"HLS CSG Guns;180 deg.Ph 9,918.0 9,944.0 6,320.9 6,337.1 A-4,2K-25 11/20/1993 3.0 RPERF 2 1/8"EnerJet;Oriented 45 deg.CW GAS LIFT;9,588.1 Cement Squeezes ,. Top(ND) Btm(TVD) as Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com r>`"A 9,575.0 9,730.0 6,108.4 6,204.9 CSG Cement 4/13/2011 CEMENT PLUG MILLED w/2.36"REAMER TO 9692' Plug PBR,9,635.7 •�*9.. " .a 9,615.0 9,700.0 6,133.5 6,186.4 TBG Cement 4/17/2011 PACKER;9,649.7 Plug n}.-'i�, Mandrel Inserts TBG CMT Retainer;9,W`60 ' f4 ��� Make Martel OD(in) se n, ��Rog � Run Date Com TBG Punches,9,875.0 1 1 1 • 1 0.000 11 11 ,k.A.�k 1' • 1 0.000 11 2/11/2010 •• • 0.000 I 1 11 NIPPLE;9,6878 4"I , ® 8,449.8 5,409.9®�M®�� 0.000 1 1 11 _ © 9,030.3®i' MENIMIELE®EMENEMEMM 0.000 1 1 11 _ •• OPEN RK 0 000 00 10/22/2010 SOS;9,699.2 ;ii EV't Notes:General&Safety '.:k End Date Annotation CSG CMT Retainer;9,7050 iilli 2/11/2010 NOTE.LEAK FOUND BETWEEN GLM 43 @ 7557'&GLM 44 @ 8450' 5/8/2010 • 0.5 gpm @ 3000 psi 5/9/2010 • :1' • APERF;9,778.0-9,792.0 11/5/2010 • 1 APERF;9,860.0-9,880.0 (PERF;9,912.09,948.0 RPERF,9,918.0-9,944.0 PRODUCTION;33.0-10,230.1 STATE OF ALASKA AIIKA OIL AND GAS CONSERVATION CO ISSION ` REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing E Operations shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter Casing rChange Approved Program Rug for Redrill rPerforate New Pool rRepair Well r Re-enter Susp Well Other:Susp Well lnsp (� 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 190-012 3.Address: 6.API Number: Stratigraphic r Service F P. O. Box 100360,Anchorage,Alaska 99510 50-103-20124-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025605 KRU 2K-25 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 10264 feet Plugs(measured) None true vertical 6539 feet Junk(measured) None Effective Depth measured 9615 feet Packer(measured) 9650 true vertical 6133 feet (true vertical) 6155 Casing Length Size MD TVD Burst Collapse CONDUCTOR 120 16 115 115 1640 630 SURFACE 4047 9 5/8 4082 2919 3520 2020 PRODUCTION 10197 7 10230 6518 4980 4320 satileo NOV 1 22'0'15 RECEIVED Perforation depth: Measured depth: 9778-9944' True Vertical Depth: 6234-6337' AUG 12 2015 Tubing(size,grade,MD,and TVD) 2.875, L-80, 9699 MD,6186 TVD AOGCC Packers&SSSV(type,MD,and TVD) PACKER= BAKER HB PACKER @ 9650 MD and 6155 TVD SSSV=OTIS FMX SSSV(LOCKED OPEN)@ 1814 MD and 1628 TVD 12.Stimulation or cement squeeze summary: NA Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14.Attachments(required per 20 AAC 25.070,25.071,&25.253) 15.Well Class after work: Daily Report of Well Operations F Exploratory r Development r Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil E Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r VVINJ r WAG [ GINJ r SUSP Fr. SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: NA Contact MJ Loveland/Martin Walters Email n1878i7conocophillips.com Printed Name Martin Walters Title Well Integrity Supervisor Signature 7/4� � �„a/ ,P� Phone:659-7043 Date:Aug 7, 2015 - ri., el /Z/15- RBDM$ IIP, 1 4 2015 /4 L/Z%.— Form 10-404 Revised 5/2015! Submit Original Only • • ConocoPhillips _RECEIVED Alaska AUG 12 Z015 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 AOGCC August 7, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West'7th Avenue, Suite 100 Anchorage, AK 99501 Re: Suspended Well Inspection 10-404 Sundry Kuparuk River Unit 2K-25 (PTD 190-012) Dear Commissioner Foerster: Enclosed please find the quinquennial suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. Kuparuk River Unit well 2K-25 (PTD 190-012). The following documents are attached: - 10-404 Sundry - Suspended Well Check List - Wellbore Schematic - Location Plot Plan - Photographs Please call MJ Loveland or me at 659-7043 if you have any questions. Sincerely, /76/Pg ()tA Martin Walters ConocoPhillips Well Integrity Projects Supervisor • S Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: KUPARUK RIV UNIT 2K-25 Field/Pool: KUPARUK RIVER Permit#(PTD): 190-012 Sundry 311-103 API Number: 50-103-20124-00-00 Operator: ConocoPhillips Alaska, Inc. Date Suspended: 4/17/2011 Surface Location: 369' FNL, 95' FEL Section: 11 Township: 10N Range: 8E Nearest active pad or road: KRU DS2K Meridian: UMIAT Take to Location Digital camera Map showing well location/Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good Pad or location surface: Good Location cleanup needed: None Pits condition: NA Surrounding area condition: Good Water/fluids on pad: None Discoloration, Sheens on pad, pits or water: None Samples taken: None Access road condition: Good Photographs taken (#and description): None Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2)well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: Good Cellar description, condition, fluids: Good Rat Hole: NA Wellhouse or protective barriers: Wellhouse Good Well identification sign: Yes Tubing Pressure (or casing if no tubing): 500 Annulus pressures: 550/ 140 Wellhead Photos taken (#and description): 3 of wellhouse, wellhead, and cellar Work Required: None y� {�� Operator Rep (name and signature): Martin Walters /%(G Com+. / AOGCC Inspector: Johnnie Hill Other Observers: Will Lomer Inspection Date: 8/7/2015 AOGCC Notice Date: 8/3/2015 Time of arrival: 9:50 AM Time of Departure: 10:00 AM Site access method: Passenger Truck KUP INJ • 2K-25 `1. COV/p-11iii1ps _ Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status !(3 MD(ftKB) Act Btm(ftKB) ci..d.-ulfips 501032012400 KUPARUK RIVER UNIT INJ �ne57.91 3,300.00 10,264.0 "." Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 2K-25,3/15/2015 902.08 AM SSSV:LOCKED OPEN Last WO: 40.09 1/26/1990 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:TOT(SLM)9,603.0 3/12/2015 Rev Reason:TAG TOC hipshkf 3/15/2015 ff� CasingStrings HANGER,31.1 i� 9 ` Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread L� [ � CONDUCTOR 16 15.062 35.0 115.0 115.0 62.50 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.765 350 4,082.1 2,918.5 36.00 J-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ,,:. :: amt.PRODUCTION 7 6.276 33.0 10,230.1 6,517.9 26.00 J-55 BTC Tubing Strings -K.A/CONDUCTOR;35.0-t150. •IIII - Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft...Set Depth(ND)(...WI(Ib/ft) Grade Top Connection TUBING 27/8 2.441 31.1 9,700.0 6,186.4 6.501-80 EUE-mod ® Completion Details _ Nominal ID SAFETY VLV;1,814.2 Ril Top(ftKB) Top(TVD)(ftKB) Top Incl C) Item Des Com (in) 31.1 31.1 0.07 HANGER FMC GEN IV TUBING HANGER 2.875 II1,814.2 1,628.3 51.94 SAFETY VLV OTIS FMX SSSV(LOCKED OPEN) 2.313 GAS LIFT;3,020.5 9,635.7 6,146.4 51.43 PBR BAKER 80-32 w/10'Stroke PBR w/3.25"SEAL BORE 2.430 9,649.7 6,155.1 51.48 PACKER BAKER HB PACKER 2.430 9,687.6 6,178.7 51.64 NIPPLE CAMCO D NIPPLE 2250 • • 9,699.2 6,185.9 51.69 SOS BAKER SHEAR OUT 2.441 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) i Top(TVD) Top Inc! L Top(ftKB) (ftKB) C) Des Com Run Date ID(in) SURFACE;35.0-4,082.1-A • 9,656.0 6,159.0 51.51 TBG CMT 2.13"x9.41'CEMENT RETAINER-PUMPED 20.9 4/17/2011 0.530 Retainer BBLS CEMENT 15.8ppg'G'TYPE;APPROX.25 bbl GAS LIFT;5,842.6 ON TOP OF RETAINER;APPROX TOC @ 9615' 9,675.0 6,170.9 51.59 TBG Punches TUBING PUNCHES,4 SPF,0 degree phase,2" 4/16/2011 2.441 circulation charges GAS LIFT;7,557.1 9,705.0 6,189.5 51.72 CSG CMT CEMENT RETAINER;MILLED DOWN TO 9692' 4/10/2011 Retainer w/2.36"REAMER FOR TUBING PUNCHES • Perforations&Slots GAS LIFT;8,449.8 Shot Dens Top(TVD) Btm(TVD) (shotsff II Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com 9,778.0 9,792.0 6,234.5 6,243.1 C-4,2K-25 12/9/1993 6.0 APERF 2 1/8"EnerJet;90 deg. Ph GAS LIFT;9,030.3 9,860.0 9,880.0 6,284.9 6,297.3 A-5,2K-25 12/9/1993 6.0 APERF 2 1/8"EnerJet;90 deg. I PH I 9,912.0 9,948.0 6,317.1 6,339.6 A-4,2K-25 5/17/1990 4.0 IPERF 4.5"HLS CSG Guns;180 deg.Ph 9,918.0 9,944.0 6,320.9 6,337.1 A-4,2K-25 11/20/1993 3.0 RPERF 2 1/8"EnerJet;Oriented 45 deg.CW GAS LIFT;9,588.1 I. Cement Squeezes I Top(ND) Btm(ND) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com 9,575.0 9,730.0 6,108.4 6,204.9 CSG Cement 4/13/2011 CEMENT PLUG MILLED w/2.36"REAMER TO 9692' Plug • PBR;9,635.7 se r 9,615.0 9,700.0 6,133.5 6,186.4 TBG Cement 4/17/2011 Me Plug :: ," PACKER;9,649.7 Mandrel Inserts TBG CMT Retainer;9,656.0 Sl ati • Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sent Type Type (in) (psi) Run Date Cent • f 3,020.5 2,329.7 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/2/2002 • TBG Punches;9,675.0 2 5,842.6 3,908.8 MERLA TMPD 1 GAS LIFT DMY 'BK 0.000 0.0 2/11/2010 3 7,557.1 4,873.2 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/2/2002 4 8,449.8 5,409.9 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/2/2002 NIPPLE;9,687.6 5 9,030.3 5,770.9 MERLA TGPD 11/2 GAS LIFT DMY RK 0.000 0.0 3/2/2002 6 9,588.1 6,116.6 MERLA TGPD 11/2 GAS LIFT OPEN RK 0.000 0.0 10/22/2010 • SOS;9,699.2 • Notes:General&Safety End Date Annotation 2/11/2010 NOTE:LEAK FOUND BETWEEN GLM#3 @ 7557'8 GLM#4 @ 8450' CSG CMT Retainer;9,705.0 - 5/8/2010 NOTE:PACKER LEAK @ 9654',LLR=0.5 gpm @ 3000 psi 5/9/2010 NOTE:Confirmed Tubing Leaks @ 8087',8187',8244'w/Eline LDL 11/5/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 APERF;9,778.0.9,792.0- APERF;9,860.0-9,880.0-_ _ I (PERF;9,9120-9,948.0 RPERF;9,918.0-9,944.0 . PRODUCTION;33.0-10.230.1 • • N 0 ~ W - >OD o o 1 13 Od flj W - a_ =OO _CO 3 Oiq r M O inct o i oa U V a rx W O - aiC++ ¢f0 ONO F~~ D— O FFWo z F 1 i Z O W V Oo p w w coi a a w a I -1- JWx ° jC w WQ o O Z >< 4-0 ` W ® v 3 akw X y >< Lla �' opt m� 0 w iiix >-- (�= C a) O J J r_-_—j Lil Q (./)Z ~� � U LUOQ moo, r' l Z � m - w a In L.O L.L. 0_:E-0 � �.- oo '/"} Yom 0I U _Z 3 • —I J N 2 w W LLI \\\\� O w _ ..__. 09- ` 1- 1-1-1 N_ C N w CC) 0££ ozz -,\ 0 w J 1 W N �(11 `^ � I Mme® \ U) I— Z Q �OQ o g I 1,44 4 ;' C CI 0OI O t41 Oit p. m O I n y 0 1in z fl flu 2 wQ Z% Q i 8 -. a CD z �t va gka < z; / \o < sa IP �_, , w w 0 O ' I Q Q N L-1 0 '�' _ 0 m � O a o of ai N �i W ix < �^�© W U O Y Z Iii J is 4 U a � w a a a O U Z a F- 'r 4 N \\ O O w \ / N N \ re N 0 0 w s m re C-i V) QcoN N a' g-04.O p 63 z Y N N ® W a a O a) c0 N- > 3 Y S' _ , a> U O w§auar rZ4.1 w0 I L J Z aw< < Q U~ ZVz o wIgZO �+ Z t W z im 0 I:4a CO O O H" p Oa, co = o o d 'C CC CC W N co Q -o o - v ¢ C-) U W N Z O 0 \ Z I I I I I 17 \\ W0N Nrn Lo C7 \ i'i o 0 .- _i �I „G T'� N. cD LC) I • 'b"*.1/4****"6'*-''-*m :, ,' -_ , . , , „.4., 44,,.. , , 4� ,44 .2_,, , . . ..,/-_,_.:0:_:,..i ,.,,,,,,,, ....„,„,. .'*****3/4*3/4";'****%*>, . ,,,.....t.,.,,,,..:,,,,,,.. _ , , 1 .4,4„.4., '. - - ' --- ' _ .... .., . , _ _.... L.,. , J, - . lir ...?':‘.- - ' a ,'" i t'''''''''''''''-:i',..„,;.,:, x. .. , 1 1 i 4 J. ra ' %' 25 . �.. / ,.............„..„,... t . -,.. ... .A.,,,A,4 . -, i , , ., , f 4 t,4''', '''''../.. `S �' .4 � Y' ' . �Y » r� ,. § moi 'a z ,8 I Ys 2 K-25- PTD 193,?' O- l ©ConocoPhi lips Alaska, Inc. This photo :is copyrighted- by - ConocoPhillips Alaska, Inc. and -` cannot be released or published . ., - wit,hout express written consent f Conoc oConocoPhillips Alaska • • ........_ „ ....... .. , , , .,. , .,. , ,,,. , / ,, - .,. , , ,,,, . „,.. stCC)t Col° Well Name: 2K-25 ` API Number. �O�-13"`2tt������g°; `.e�� 11 PTO: 190-012 Sur, location: 369' Full. ON,5 RBE, UM Sec, ll, T1 7. e 1 2K-25 PTD 190-012 ©ConocoPhillips Alaska, Inc. This photo is copyrighted by ConocoPhillips Alaska, Inc. and cannot be released or published without express written consent of ConocoPhillips Alaska • .. rur * , , ., , , ,,./.,./ J( ' ' ' F ill 'a5-4'c'1:1' iffif / / / / / iiifil ,, , „ 1,i)iii i i , i 1 i /,/ / / / - i i , / ill 1)i t/Lj�, ... ,f • / / 3. M Mtirt;‘,_ k ‘. if, .,. 41 iihk . ,..,-- , - v v • 0- (....) C6 .� l _cp f If U i cn ra (N 4—I co •i c- ) Q (N Q N N g ds �. � —I -E •v) •— Q_ cL Q t / vf /, N O 8 3 0 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 08/08/15 Inspector: Johnnie Hill Operator: ConocoPhillips Alaska Inc - Well Name: KRU 2K-25 Oper. Rep: Martin Walters PTD No.: 1900120 Oper. Phone: 659-7043 Location Verified? Yes Oper.Email: _n1878[riconocophillips.com_ If Verified, How? LAT/LONG Onshore/Offshore: Onshore Suspension Date: 04/17/11 Date AOGCC Notified: 08/03/15 Sundry No.: 311-103 Type of Inspection: Subsequent Wellbore Diagram Avail.? No Well Pressures(psi): Tubing 500 - Photos Taken? Yes IA 55 OA 140 Condition of Wellhead: good SCANNED SEP 0 6 2016 Condition of Surrounding Surface Location: good gravel Follow Up Actions Needed: none Comments: well was verified by pad well location map • Attachments: Photos(2) REVIEWED BY: Insp.Supry 771; 12-'1 15 VS Comm PLB 06/2014 2015-0808_Suspend_KRU_2K-25jh.xlsx Suspended Well Inspection—KRU 2K-25 PTD 1900120 Photos by AOGCC Inspector J. Hill 8/8/2015 ..„„„.._ A ConocoPhillips ...„„r-, Well Name: 2K-25 Alaka API Number: 50-103-2012400-00 PTD: 190-012 Sur. Location: 369' FNL,95' FEL Sec. 11,T10N,ROE,Um tit l • 1 1- i q... i) i„ _ Ili ff *110*,- %. ly.1_ . / " l'ril ;fir`-' " o-` e *- . 4 `! moi' x- �` t 14' 1 II rs,,, 1".401 \ ' b' L 2015-0808_Suspend_KRU_2K-25_photos jh.docx • Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. ' - el File Number of Well History File PAGES TO DELETE Complete RESCAN ❑ Color items - Pages: ❑ Grayscale, halftones, pictures, graphs, charts - Pages: ❑ Poor Quality Original - Pages: ❑ Other - Pages: DIGITAL DATA • ❑ Diskettes, No. ❑ Other, No/Type OVERSIZED ❑ Logs of various kinds ❑ Other COMMENTS: C C • • Scanned by: Beverly Dianna Vincent Nathan Lowell I W\ Date: L - 0 l ❑ TO RE -SCAN Notes: • • Re- Scanned by: Beverly Dianna Vincent Nathan Lowell Date: Is! • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 09/06/11 Inspector: Lou Grimaldi Operator: Conoco Phillips Alaska Inc. Well Name: KRU 2K -25 Oper. Rep: Martin Walters PTD No,: 190 -012 Oper. Phone: 659 -7043 Location Verified? Yes Oper. Email: n1787Ccr?Conocophilli s.com If Verified, How? Other (specify in comments) Onshore/Offshore: Onshore Suspension Date: 05/10/11 Date AOGCC Notified: 09/05/11 Sundry No.: Well Completion Rpt Type of Inspection: Initial Wellbore Diagram Avail.? yes Well Pressures (psi): Tubing 1769 - Photos Taken? yes IA 1895 OA 165 Condition of Wellhead: Inside welfhouse OK , Weathered OK , valves c cled and OK, Gau.es OK , No oil in cellar. ' SSSV hydraulic port pressured up (2200 psi). Condition of Surrounding Surface Established pad in good shape. "S" riser and A.L Location: Follow Up Actions Address pressure on SSSV control port. - Needed: Location verified by pad map. Attachments: Photos (2) 1YIH 7 'LUIZ REVIEWED BY: Insp. Supry Z(Z� r Comm PLB 09/2010 2011- 0906_Suspend KRU_2K -25_Ig r Suspended Well Inspection — KRU 2K -25 PTD 1900120 Photos by AOGCC Inspector L. Grimaldi 9/6/2011 . 'S 011 ) lk . 1 - , 4 p. ' #tai,... , ,,,, ''' . 14014410,,,,__ ,,,,,,_ ;i ii , 4 t 4' IIII ,... . . .. .. . . , . _ _ _ _ _ , 4 .. , 4 . , 4 . , • t ' . , , , ,, .... _ .. Y .. . 777 r A 91f - o rr'...'r r �� ., µ _ �T �� j - • • ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 September 10, 2011 RECEIVE; Commissioner Dan Seamount SEP 14 2P Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Alaska Oil & Gas Cons. Commissio Anchorage, AK 99501 Anchorage Re: Suspended Well Inspection 10 -404 Sundry Kuparuk River Unit 2K -25 (PTD 190 -012) Dear Commissioner Seamount: Enclosed please find the quinquennial suspended well inspection documentation as required by 20 AAC 25.110 for ConocoPhillips Alaska, Inc. Kuparuk River Unit well 2K -25 (PTD 190 -012). The following documents are attached: - 10 -404 Sundry 4 °; P 2 8 2V - Suspended Well Check List - Wellbore Schematic - Location Plot Plan - Photographs Please call MJ Loveland or me at 659 -7043 if you have any questions. Sincerely, //6 i Martin Walters ConocoPhillips Well Integrity Projects Supervisor Enclosures 0 STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair well r Rug Perf orations r Stimulate T Other Fi Suspended Well Pull Tubing Perforate New Pool Waiver Inspection Alter Casing r 9 (� r r Time Extension r Change Approved Program r Operat. Shutdown r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r • 190 - 012 3. Address: 6. API Number: Stratigraphic r Service 1 P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20124 - 00. 430 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0025605 4.. 2K - 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 10264 feet Plugs (measured) None true vertical 6539 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 9650 true vertical 0 feet (true vertucal) 6155 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 115 115 SURFACE 4047 9 -5/8 4082 2919 PRODUCTION 10197 7 10224 6514 CEIVE SEP 14 2011 Perforation depth: Measured depth: 9778 -9792, 9860 -9880, 9912 -9948, 9918 -9944 True Vertical Depth: 6234 -6243, 6285 -6297, 6317 -6340, 6321 -6337 Alaska Oil & Gas Cons. Corte' r. Anchorage Tubing (size, grade, MD, and TVD) 2.875, L - 80, 9700 MD, 6186 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER HB PACKER @ 9650 MD and 6155 TVD SSSV - OTIS FMX (LOCKED OPEN) 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure I I Prior to well operation NA NA NA NA NA I Subsequent to operation NA NA NA NA NA 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service r . Stratigraphic r 15. Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations X GSTOR r WIND r WAG r GINJ r SUSP F SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact MJ Loveland /Martin Walters Printed Name Martina Walters ���/ , Title: Well Integrity Project Supervisor Signature � ,( ' _ Phone: 907 - 659 -7043 Date: 09-10 -11 REIMS SEP 1 2011 g23•Kiz III Form 10 -404 Revised 10/2010 Submit Original Only • • Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Nell Name: Kuparuk River Unit 2K -25 Field /Pool: Kuparuk River /Kuparuk River Pool Permit# (PTD): 190 -012 Sundry 311 -103 API Number: 50103201240000 Operator: ConocoPhillips Date Suspended: 4/14/2011 Surface Location: Section: 369' FNL, 95' FEL, Sec 11 Twsp: T1 ON Range: R8E UM Nearest active pad or road: KRU DS2T Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good Pad or location surface: Good. Gravel pad Location cleanup needed: No Pits condition: N/A Surrounding area condition: Good Water /fluids on pad: Dry Discoloration, Sheens on pad, pits or water: No sheen Samples taken: No Access road condition: Good Photographs taken (# and description): None Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead /tree /valve description, condition: Weathered, OK. Cycled SV, SSV, MV, IA valve, and OA valve. SSSV control line pressure at 2200 psi. Cellar description, condition, fluids: No oil in cellar. Gravel cellar with conductor mounted floor clamp Rat Hole: No Wellhouse or protective barriers: Wellhouse - Good Well identification sign: Stenciled on wellhead and wellhouse Tubing Pressure (or casing if no tubing): 1769 psi Annulus pressures: IA = 1895 psi, OA = 165 psi Wellhead Photos taken (# and description): 2 of wellhead and cellar Work Required: Address SSSV pressure Operator Rep (name and signature): Martin Walters /�' (G,( y . �' AOGCC Inspector: Lou Grimaldi Other Observers: Carney / Mouser Inspection Date: 9/6/2011 AOGCC Notice Date: 9/1/2011 Time of arrival: Time of Departure: Site access method: Highway Vehicle • KUP • 2K -25 ConocoPhillips is Well Attributes Max Angle & MD TD Alaska. Inc. Wellbore API /UWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) w>+cut+alnps 501032012400 KUPARUK RIVER UNIT INJ 57.91 3,300.00 10264.0 Comment F12S (ppm) Date Annotation End Date KB (ft) Rig Release Date ••• WeIlCanfi4: - 2K - 25 4H6201110'1J26 SSSV: LOCKED OPEN Last WO: 40.09 1/26/1990 Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: TOC 9,575.0 4/13/2011 Rev Reason: TBG CEMENT PLUG Imosbor 4/18/2011 c - Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER. 31 CONDUCTOR 16 15.062 35.0 115.0 115.0 62.50 H Casing Description String 0... String ID... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.765 35.0 4,082.1 2,918.5 36.00 J - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.151 26.8 10,223.9 6,514.0 26.00 J -55 BTC C Tubing Strings CONDUCTOR, Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 35 TUBING 27/8 2.441 31.1 9,700.0 6,186.4 6.50 1 -80 EUE -mod Completion Details Top Depth SAFETY VLV, (TVD) Top Inc! Nomi... 1,614 �] Top (ftKB) (ftKB) ( °) item Description Comment ID (in) 31.1 31.1 0.20 HANGER FMC GEN IV TUBING HANGER 2.875 GAS LIFT, 1,814.2 1,633.1 57.73 SAFETY VLV OTIS FMX SSSV (LOCKED OPEN) 2.313 3.020 9,635.7 6,146.2 51.33 PBR BAKER 80-32 w /10' Stroke PBR 2.430 9,649.7 6,155.0 51.41 PACKER BAKER HB PACKER 2430 9,687.6 6,178.7 51.62 NIPPLE CAMCO D NIPPLE 2.250 9,699.2 6,185.9 51.69 SOS BAKER SHEAR OUT 2.441 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) ( Top Depth S 35 - 082 �, 1 I (TVD) Top Intl 1 1 ) Top (ftKB) (ftKB) ( °) Description Comment Run Date ID (in) GAS LIFT 1 9,656.0 6,159.0 51.44 TBG CMT 2.13'X9.41' CEMENT RETAINER - PUMPED 20.9 BBLS 4/17/2011 0.530 5.843 j. Retainer CEMENT 15.8ppg'G' TYPE; APPROX .25 bbl ON TOP OF RETAINER; APPROX TOC @ 9615' GAS LIFT, 9,675.0 6,170.8 51.55 TBG Punches TUBING PUNCHES, 4 SPF, 0 degree phase, 2" circulation 4/16/2011 2.441 7,557 charges 1 j 9,705.0 6,189.5 51.72 CSG CMT CEMENT RETAINER; MILLED DOWN TO 9692 w/2.36" 4/10/2011 GAS LIFT, Retainer REAMER FOR TUBING PUNCHES 9.450 Perforations & Slots Dent Top (TVD) Btm (NO) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date Oh- Type Comment GAS 91 _ 9,778.0 9,792.0 6,234.5 6,243.1 C-4, 2K -25 12/9/1993 6.0 APERF 21/8" EnerJet; 90 deg. Ph 11 9,860.0 9,880.0 6,285.1 6,297.3 A -5, 2K -25 ' 12/9/1993 6.0 APER 2 1/8" EnerJet; 90 deg. PH 9,912.0 9,948.0 6,317.1 6,339.8 A -4, 2K -25 5/17/1990 4.0 IPERF 4.5" HLS CSG Guns; 180 deg. Ph I 9,918.0 9,944.0 6,320.9 ' 6,337.3 A-4, 2K -25 11/20/1993 3.0 RPERF 2 1/8" EnerJet; Oriented 45 deg. CW `a 6 1 E Notes: General & Safety 1 End Date Annotation �1 2/11/2010 NOTE: LEAK FOUND BETWEEN GLM tt3 @ 7557' & GLM 64 @ 8450' GAS LIFT. 9,588 5/8/2010 NOTE: PACKER LEAK © 9654', LLR = 0.5 gpm @ 3000 psi I. 5/9/2010 NOTE: Confirmed Tubing Leaks @ 8087', 8187', 8244' w /Eline LDL 11/5/2010 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 PBR. 9.636 PACKER, 9,650 TBG CMT 1i Retainer, 9.656 j , . a TBG Punches, - 9,675 III NIPPLE.9,688 i1 MR, SOS, 9.699 TBG Cement +- Plug, 9,615 CSG CMT 1 (. Retainer, 9,705 CSG Cement Plug, 9.575 APERF, 9,778 -9,792 II Mandrel Details APER, Top Depth Top Port 9,860 -9,880 (ND) Intl OD Valve Latch Size TRO Run Stn Top(ftKB) (SKB) (1 Make Model (in) Sery Type Type (in) (poi) Run Date Com... 1 3,020.5 2,329.4 54.00 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/2/2002 IPERF, 2 5,842.6 3,908.8 56.13 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 2/112010 9,9125,948 R 3 7,557.1 4,873.6 55.61 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/2/2002 9,918 - 9,944 - 5,044 4 8,449.8 5,409.9 50.86 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/2/2002 ' 5 9,030.3 5,770.9 51.91 MERLA TGPD 1 GAS LIFT DMY RK 0.000 0.0 3/2/2002 6 9,588.1 6,116.6 51.24 MERLA TGPD 1 12 GAS LIFT OPEN RK 0.000 0.0 10/22/2010 PRODUCTION, 27-10,224 75,10,264 POWERLINES aglow "' EN CULVERT gm P1pEI -114E CAUTION �� Ill THIS DRILL SITE IS CV r � - TRL ROOM CONSIDERED TO BE XFRM- ' PROD HEATER AN H AREA �1l '0,. METH TANK RESERVE PIT GUARD RAIL. : LAUNCHER BLDG u in i i TEST SEPARATOR .16--- PROD M•I m0000 2 PROD MOD 0 A _,—,° - � • 2 272.2123222 281 131 15151 1, 2811 18 9 3 7 3 5 3 2 123 u ®cla ♦®®♦ [ ®®o , ® ® *(1) @ ®• * •® ®® _ 111 13 SPACES 0 25 -300' 45 45 I 12 SPACES 0 25' -300' I `` TO OS 2II LEGEND FEATURE LOCATIONS G EXISTING PRODUCER • EXISTING INJECTOR LEGEND 0 CONVERTED FROM PRODUCER TO INJECTOR ® RESCUE EQUIPMENT // – CLEAN SNOW DUMP AREA, ALL EQUIPMENT. * SCBA LOCATIONS NOTE Z ABANDONED CONDUCTOR x.4. ■ - ENVIRONMENTAL AREA –NO SNOW DUMPING. 1 V 1 DESIGNATED SAFE AREA (PRIMARY)( EXISTING CONDUCTOR - , – POWERLINE –WATCH CLEARANCE!!. KODIAK , PARTIAL TREE BLOWERS MAY HIT LINES WITH DISCHARGE. 2 I DESIGNATED SAFE AREA (SECONDARY) NO SNOW IS TO BE PLACED IN 4 "s – KODIAK BLOWERS MAY DISCHARGE OVER Q EVACUATION ROUTES DEPENDING ON WIND ANY RESERVE PIT OR LINED PIT. PIPELINES. r WINDSOCK I. •:I – NO SNOW DUMPING AREA. ® BARRICADE /ESCAPE ROUTE • A LOUNSBURY, INC 4 , � FIRE EXTINGUISHER l FORM: ASIZEL Conoc AREA: 2K MODULE:XXXX UNIT: D2 Alaska, Inc.. APPROVAL: _ j DS2K FACILITY EXPANSION 5 04/25/03 Add Well 27, Rev Per K03060ACS RLS MRT DATE: 10/25/96 LK621112 FEATURE LOCATION 4 05/01/02 Add Well 28, Rev Per K02013ACS MRT SCT , DRAWING NO. PART: REV: REV APP DATE REVISIONS BY CHK ENGRENG�R CEA -D2KX -3321 1 5 NO. APP • • 2K -25 (PTD# 190 -012) 0 © ConocoPhillips Alaska, Inc. This photo is copyrighted by ConocoPhillips Alaska, Inc. and cannot be released or tit' f published without express written consent of ConocoPhillips Alaska tz .. "'^ R. .. t 1 . C , t4 a.x'. A f . • I 25 .111111t . fi ° ��. , w , tics > i .,. . , 4 .../ I/ i fit/ It ...,, ," ■ i t i,4 r r A **'''''' ' .V.k.‘* . • , - / . t. ,.. 'to •?, ,'".„ ', : i ' i - ., ' '4, • ..11„„ ,;.' _ ,. ':',.. ' ., , ,,-' , ,,1,..4.; '' / • ... ., , , ....... - . . 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" 6 :1.0 i J O 17/ „,t,■ - II- = /4,ii( 44:4,,,,,4>e ' . .0 C -,* . aS 0. 0 ild _ fief 1 ,7 1 1 Ar113)iffil I i 4" ,,, Ia., JIZAILt a ., if ' d I id d ....1 .1 I • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended Q 1b. Well Class: 20AAC 25.105 20AAC 25.110 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service El Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: April 17, 2011 190 - 012 / 311 - 103 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 January 18, 1990 50 103 - 20124 - 00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number. Surface: 369' FNL, 95' FEL, Sec. 11, T1 ON, R8E, UM January 25, 1990 2K - 25 Top of Productive Horizon: 8. KB (ft above MSL): 40' RKB 15. Field /Pool(s): 782' FNL, 1153' FEL, Sec. 13, T1ON, R8E, UM GL (ft above MSL): 154' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 1121' FNL, 982' FEL, Sec. 13, T1ON, R8E, UM 9656' MD / 6159' TVD Kuparuk River Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 498310 y 5937935 Zone 4 10264' MD / 6539' TVD ADL 25605 TPI: x - 502534 y - 5932243 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 502705 y - 5931904 Zone 4 SSSV @ 1814' MD / 1633' TVD 2679 18. Directional Survey: Yes ❑ No 0 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1400' MD / 1379' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re drill /Lateral Top Window MD/TVD none not applicable 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 Surf. 115' Surf. 115' 24" 191 sx AS II 9.625" 36# J -55 Surf. 4082' Surf. 2919' 12.25" 1300 sx AS III, 450 sx Class G 7" 26# J -55 Surf. 10224' Surf. 6514' 8.5" 300 sx Class G 24. Open to production or injection? Yes ❑ No Q If Yes, list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET ( MD/TVD) 2.875" 9700' 9650' MD / 6155' TVD pert cemented off r� 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ,� x a `i MA,N g Z U 1, DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED tom' tea+ cement retainer @ 9656' 20.9 bbls 15.8 ppg Class G „/ 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) plugged Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS - OIL RATIO Test Period - -> Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. psi 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No Q Sidewall Cores Acquired? Yes ❑ No 0 If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. L ❑\ NONE i ,It,,, RBDMS MAY 1.01011 r, �;, ia Chi & A Ceti. Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Atoka �t1L�� Submit ori only ?‘ g:/o.// ....17;111:( 28. GEOLOGIC MARKERS (List all formations and markers flinte 29. • FORMATION TESTS NAME MD TVD Well tested? ❑ Yes in No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1400' 1379' needed, and submit detailed test information per 20 AAC 25.071. not applicable N/A Formation at total depth: not applicable 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. j�� Contact: D. Herrmann @ 263 - 4619 Printed NameG L . Alvord Title: Alaska Drilling Manager / Signature Ay ak_ Phone 265 - 6306 Date 5 i (4 '(- 49 C( Sharon Allsup -Drake 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item la: Classification of Service wells: Gas injection, water injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 12/2009 ' f KUP III Al aska, toe, 5o reAPI/ WI _ Max Angle K MD TD_ _ -- C� � Alaska, Field Name Well Status 1 M ( °) MD (k KB) T Btm (RKB) � we u 0 1 032012 I ' KIJPARUK RIVER UNIT INJ 1 I 3,300 00 10,2640 e ttn utes "" Commenl 1125 (ppm) Date 'Annotation End D to f IKB -Grd (ft) Rig Release Date W C,o8 2K-2 4M 0111 0:1328 AM SSSV LOCKED OPEN Last WO 40 09 1/26/1990 __ fro 5 e . T.14. - _ _ _ - - Sdtbne4iP- Actual Annotation Dept h lkK6) End Date Annotation L 51 Mod ... End Date Last Tag TOC I s.5 5.0 4/13/2011 l Rev Reason: TBG CEMENT PLUG I Imosbor 4/18/2011 using Strings Casing Description String 0... String ID ... Top (RKB) Set Depth (6... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 35.0 115.0 115.0 62.50 H HANGER, 31 _ "Y Casing Description String O... String ID... Top(ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String... String Top Thrd xil SURFACE 95/8 8.765 35.0 4,082.1 2,918.5 36.00 J -55 BTC g --- --... -- - - - Cu n O Casing Description String 0... String ID ... Top (ftK6) Set Depth (9... Set Depth (TVD) ... String W Wt... String ... String Top Thrd PRODUCTION 7 6.151 26.8 10,223 9 6,514.0 26.00 J -55 BTC Tubing Strings _ CONDUCTOR, Tubing Description String 0 .. String ID .. Top (RKB) Set Depth (f_. Set Depth (TOD) ... String Wt. String ... String Top Thrd 35 TUBING 2 7/8 I 2.441 31.1 9,700.0 6,186.4 6.50 1-80 EUE -mod • Com. letion Details Top Depth _ -- SAFETY VLV, _ (ND) Top Intl Nom••• 1,814 To• ftKB ("KB) 0) Item Description Comment ID(In) 31.1 31.1 0.20 HANGER FMC GEN IV TUBING HANGER 2.875 GAS LIFT 1,814.2 1,633.1 57.73 SAFETY VLV OTIS FMX SSSV (LOCKED OPEN) 2.313 3,020 9,635.7 6,146 2 51.33 PBR BAKER 80-32 w/10' Stroke PBR 2.430 9,649.7 6,155 0 51.41 PACKER BAKER HB PACKER 2.430 I 6,170, 51.62 NIPPLE CAMCO D NIPPLE 2.250 9,699.21 6 185.1 `.;1.69 SOS BAKER SHEAR OUT 2.441 1 n Hole (Wireline retrievable plugs, valves,_ pumps fish etch SURFACE, - ( P Top Depth _- 35.4,082 (7301 'Top Intl _ -- - I To (ftKB) (9K8) (°) Description Comment Run Date ID (in) GAS LIFT, 9 6,159.0 51.44 TBG CMT 2.13 "x9.41' CEMENT RETAINER - PUMPED 20.9 BBLS 4/17/2011 0.530 5,843 Reta iner CEMENT 15.8ppg 'G' TYPE: APPROX .25 bbl ON TOP OF RETAINER: APPROX TOC @ 9615' GAS LIFT, , " 9,675.0 6,170.8 51.55 TBG Punches TUBING PUNCHES, 4 SPF, 0 degree phase, 2" circulation 4/16/2011 2.441 7,557 :" :._: charges 9,705.0 6,189.5 51.72 CSG CMT CEMENT RETAINER: MILLED DOWN TO 9692' w/2.36" 4/10/2011 GAS ,FT, a "' Retainer REAMER FOR TUBING PUNCHES 8,450 . , .______- Perforations & Slots Shot Dens Top (RKB) BUS (ttKB) T ( B U) (RKB) Lane Date (sh••• Type Comment GAS 0. 9,030 9,778.0 9,792.0 6,234.5 6,243.1 C 2K - 25 12/9/1993 6.0 APERF 2 1/8" EnerJet 90 deg. Ph s,o3o 9,860.0 9,880.0 6,285.1 6,297.3 A -5, 2K-25 12/9/1993 6.0 APER 2 1/8" EnerJet 90 deg. PH ' 9,912.0 9,948.0 6,317.1 6,339.8 A -4, 2K -25 5/17/1990 4.0 IPERF 4.5" HLS CSG Guns;180 deg. Ph � 9,918.0 9,944.0 6,320.9 6,3373 A-4, 2K -25 11/20/1993 3.0 RPERF 2 1/8" EnerJet Oriented 45 deg. CW a Notes: General & Safety End Dab Annotation ' 0 2/11/2010 NOTE: LEAK FOUND BETWEEN GLM #3 @ 7557'8 GLM #4 @ 8450' GAS LIFT, 9 .588 t 5/8/2010 NOTE: PACKER LEAK @ 9654', LLR = 0.5 gpm @ 3000 psi 5/9/2010 NOTE' Confirmed Tubing Leaks @ 8087', 5787', 8244' w/Eline LDL 11/5/2010 NO E VIEW SCHEMATIC /Alaska Schematic9.0 PBR, 9,638 TBG CMT \ _ )4'4 ) . - Retainer, 9,656 $� W TBG Punches, a • 9,675 NIPPLE, 9,688 -. g •> A fie SO8, 9,699 ' . w TBG Cement Plug, 9,615 CSG CMT Retainer, 9,705 CSG Cement Plug, 9,575 APERF, . 9,778-9,792 r Mandrel Details ._ Top Deplh Top Port APER, (7301 Intl OD Valve Latch Size TRO Run 9.860.9.880 Stn Top (RKB) (8KB) ( °) Make Model (in) Sera TYP. Type Pe) (psi) Run Dab Com... _... • 1 3,020.5 2,329.4 54.00 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/2/2002 IPERF, T T 2 5,842.6 3,908.8 56.13 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 2/11/2010 9,912 3 7,557.1 4,873.6 55.61 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/2/2002 9,918 - 9,944 _ - - 4 8,449.8 5,409.9 50.86 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 3/2/2002 5 9,030.3 5,770.9 51.91 MERLA TGPD 1 GAS LIFT DMY RK 0.000 0.0 3/2/2002 6 9,588.1 6,116.6 51.24 MERLA TGPD 1 1/2 GAS LIFT OPEN RK 0.000 0.0 10/22/2010 I PRODUCTION, 27- 10,224__ TD, 10,264 2K -25 Well Work Summary DATE SUMMARY • 3/12/11 (IN PROGRESS) MITOA - FAILED, STABLISHED LLR ON OA 4/2/11 TAGGED CA -2 PLUG WITH 48" x 2.25" DUMMY PLUG @ 9688' RKB. TAGGED CA -2 PLUG @ 9688' RKB WITH 17.41' x 2.125" DUMMY DRIFT (MAX OD= 2.25 "). READY FOR GYRO. 4/9/11 PULLED CA -2 PLUG @ 9688' RKB, MEASURED BHP 4484 psi @ 9680' RKB, GRADIENT 4440 psi @ 9518' RKB, TAG @ 10021' SLM, COMPLETE. 4/10/11 PUMP CEMENT SQUEEZE THRU RETAINER, DIFFICULTIES RIGGING UP LUBRICATOR TO WH DUE TO TREE LEANING, PERFORM 30 BBL INJ TEST IN 7" TO FORMATION. ATTEMP TO PMP 30 BBL 15.8 G CMT W/ AGGREGATE THRU A CMT RETAINER @ 9705.7 CTMD, CMT FAILED TO EXIT THE NOZZLE, MADE SEVERAL ATTEMPS TO PUMP DN COIL AND REVERSE OUT AFTER STINGING OUT OF RETAINER, POH HOLE, 4/11/11 AT SURFACE BREAK OFF TOOL STRING, CUT COIL CC, RIG UP ON WELL & ATTEMP TO PMP DN COIL & REVERSE OUT TWICE BOTH WAYS, UNSUCCESSFUL, LRS FP TUBING & IA, IN PROGRESS 4/12/11 MOBILIZE CTU # 3 TO 2K, PERFORM BOP TEST, MU BHA READY FOR TAG ON RETAINER TOMORROW, IN PROGRESS, 4/13/11 ATTEMP TO TAG RETAINER @ 9705 CTMD, DIFFICULTIES RIGGING UP TO WELL DUE TO LEANING TREE, TAG CEMENT @ 9575 CTMD. APPROX 130 FT ABOVE RETAINER. ATTEMP TO WASH DOWN TO RETAINER, UNABLE TO WASH DN, BACK TOMORROW TO MILL TO RETAINER, WELL FP, IN PROGRESS 4/14/11 UNDER REAM 2 7/8" TUBING, CORRECT CTMD & MILL FROM 9599 CTMD TO 9686 CTMD, APPROX 2 FT. ABOVE D NIPPLE, MILLED BACK UP HOLE FROM 9686 CTMD TO 9600, ENCOUNTERED NO HRD TAGS OR STALLS MILLING, WH FP, IN PROGRESS, 4/15/11 ATTEMPT TO SHOOT 2.0" TUBING PUNCH GUN AT 9669'- 9681'. 6.5GRAM MILLENNIUM CIRC CHARGES ODEG PHASING 4SPF 48 TOTAL SHOTS(12' LOADED GUN) TOOLSTRING SAT DOWN AT APPROX 9660' CCL- BOTTOM OF TOOSTRING =23' CCL PICKUP AT 9636'. SECOND ATTEMPT TO GET THROUGH OBSTRUCTION AT 9660' WITH 1.69" SLICK TOOLSTRING GR /CCL . TOOLSTRING SAT DOWN AT SAME SPOT AS RUN #1 (9660') 4/16/11 MILL CEMENT W/ 2.36" UNDER REAMER, TAG @ 9662 CORRECTED ELINE RKB, MILLED TO 9698 MD, ENCOUTERED NO STALL, STOPPED MILLING WHEN WE SEEN WEIGHT ON BIT& AN INCREASE IN CIRC PRES, RIH FOR DRI TAG @ 9692 MD, WH FP, IN PROGRESS, 4/16/11 PERFORATED TUBING FROM 9675' -9687' USING 2" CIRCULATION CHARGES, 4 SPF, 0 DEG PHASING. READY FOR COIL. 4/17/11 CEMENT THRU RETAINER, SET RETAINER @ 9660 MD "MID ELEMENT" PUMPED APPROX 20.9 BBL 15.8 PPG TYPE G CEMENT TO THE 7" THRU THE RETAINER, PUSHED APPROX 6.8 BBL BEHIND PERFS, LAYED, 0.25 BBL ON TOP OF RETAINER, ESTIMATED TOP OF CMT @ 9615 MD, WELL FP, IN PROGRESS 4/30/11 PRE STATE WITNESSED CMIT(PASSED), DD TEST(PASSED) • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg 2f 5 ', a . ( D ATE: May 8, 2011 P. I. Supervisor I FROM: Bob Noble SUBJECT: Weill Suspension Plug Petroleum Inspector KRU 2K -25 CPAI PTD 1900120 May 8, 2011: Went out to witness the pressure test on the 7" pipe. Well has a history of annular communication problems (multiple tubing leaks). Prior to my arrival at location, CPAI pumped cement plug on top of an inflatable cement retainer set in the tubing below the packer to isolate the reservoir and leave the well suspended. I witnessed a 30 minute pressure test of the tubing and production casing with the following results: Pretest (psi) Initial (psi) 15 min (psi) 30 min (psi) IA 80 2590 2540 2520 OA 80 320 330 330 Tubing 0 2500 2430 2420 The test showed less than 10% pressure loss with a stabilizing trend. Summary: I witnessed a successful test of a downhole suspension plug in KRU 2K -25. Attachments: none ,a MAY t 8 20) i 2011- 0508_Suspend_KRU_2K -25 bn.doc • . WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. April 19, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Tubing Punch Record: 2K -25 Run Date: 4/17/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2K -25 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50 -103- 20124 -00 &,,,./ MAY 2 3 2011 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 190 _ ! a 90 5 "?-q Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wop2l tan.99m -7- t, 7) Date: � �-' % '� Signed: / • • suiri Lunstm SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Dan Herrmann Wells Engineer ,L/ '3 - ConocoPhillips Alaska, Inc. \q 0 P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2K -25 Sundry Number: 311 -103 Dear Mr. Herrmann: APR 0 4 2011 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair s DATED this ) day of April, 2011. Encl. STATE OF ALASKA ��\� ALASKOL AND GAS CONSERVATION COMMISS �J " "' 1 . APPLICATION FOR SUNDRY APPROV S 4' 20 AAC 25.280 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r Change Approved Program r Suspend Flug Perforations fl Perforate r Pull Tubing r Time Extension r Operational Shutdown `" Re -enter Susp. Well r Stimulate r Alter casing r Other: 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 190 - 012 ' 3. Address: 6. API Number: Stratigraphic r Service , P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20124 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No fri 2K -25 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25605 • 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): 10264 - 6539 • 10138' 6460' 9688' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 115' 115' SURFACE 4047 9.625" 4082' 2918' PRODUCTION 10197 7 10224' 6514' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9775 9792', 9860' 9880', 9912' - 9948' 6235 6243', 6285 6297', 6317' - 6340' 2.875 L - 9700 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER 'HB' RETRIEVABLE PACKER MD= 9650 TVD= 6155 TRDP - OTIS 'FMX "LOCKED OPEN* MD= 1814 TVD= 1628 12. Attachments: Description Summary of Proposal S' 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Development Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 4/1/2011 Oil r Gas r WDSPL r Suspended 16. Verbal Approval: Date: WINJ r- GINJ r WAG r Abandoned Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Dan Herrmann @ 263 -4619 Printed Name a errmann Title: Wells Engineer Signature G ,_. Phone: 263 -4619 Date /9 /) Commission Use Only Sundry Number: 3 1 L f 03 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity V BOP Test r Mechanical Integrity Test r Location Clearance r RECEIVED' Other: (x/04 ,:x. S-n r Gct Z Ii G c / bR e 0 th Z L A4c 7/' r 1 /o (. h� � tG r y Subsequent Form Required: J Al2Rke OH & E3c rents. Cdr / e _ yo 7 : .- 1 rage C ril APPROVED BY / � Approved by: COMMISSIONER THE COMMISSION Date: `7 / j) ;. ;e.H Form 10 -403 Re& APR 04 R1G1 101 N Al. 3 /l! Submicate • Well 2K -25 Proposed Well Suspension 2K -25 is a Kuparuk Injector the well is currently shut -in due to a lack of off take and annular- communication problems. The well currently has a failed MITOA, multiple tubing leaks and a failed CMIT with a LLR of approximately 0.5 gpm @ 3000 psi. A leak detect log was performed and the leak was found to be a packer leak on the backside of the tubing. We are planning to pump cement to isolate O the reservoir and leave the well suspended for future development evaluation. Proposed Well Suspension Procedure: Procedure Slickline Unit 1. RIH and pull CA -2 plug set @ 9688' RKB. Coiled Tubing & Cementing Unit 2. RIH w/ 2 1/8" Inflatable Cement Retainer (ICR) and set @ 9695' RKB (In case the cement job fails we will be able to perforate below the packer and re- aqueeze cement). Pump 30 bbls of 15.8 Class G cement slurry (approx. 150% of casing volume below tubing tail) down coiled tubing through the ICR displace w/ seawater. Sting out of the ICR and circulate 1 bbl of Biozan to clean the coiled tubing and circulate seawater while POOH, leave well with 2000 ft of diesel freeze protect. During pumping bleed the IA down and monitor to confirm there is no communication between the IA and formation. Estimated TOC — 9695' RKB Note: Do not exceed a fracture gradient of .65 psi /ft during the cement job. Slickline 3. Contact AOGCC for State witnessed Pressure test & ICR. 4. After minimum of 24 hours pressure test cement plug to 2000 psi then bleed tubing to 0 psi. Record pressures. Drift & tag to Top of Cement retainer @ approx. 9695' RKB. KIP • 2K -25 C b�t)F t111i�5 Well Attributes 'Max Angle & MD ,TD - WeIt bore APW Wl F Id Name Well Status Inc! ( °) _LBO (RKB) Act Bim COKE) Ala Inc ` „ 501 :KUPARUK RIVER UNIT JINJ 57.91 3,30000 102640 J Comment H25 (ppm) Dab Annotation End Data KB -Grd (R) ( Release Date w eu, n6g 2 ?m o1oz5�24AM SSSV LOCKED OVEN Last WO: I_ 40 09 L 1/26/1990 Se/Snore ArC S _.. Annotation O •pth (RKB) End Date Mob n li on Last Mod By End Date Last Tag- 1 0,022.0 8/5/2007 R ev Reason: GLV C/0_ _ Innosbor 10/30/2010 Casin r Strings - String OD String ID Set Depth Set Depth (ND) String Wt String Casing Dacr _ (in) (in) Top (ftKBk (RKB) (RKB) (Ibs/ft) Grade String Top Thrd CONDUCTOR - - 16 15.062 0.0 115.0 115.0 62.50 H-40 CONDUCTOR, SURFACE 95/8 8.765 0.0 4,082.0 2,918.4 36.00 J-55 PRODUCTION 7 6.151 0.0 10,224.0 6,514.1 26.00 J -55 sAFETVVLV, Tubing Strings 1 914 String OD String ID Set Depth Set Depth (ND) String Wt String , .n Tubing Description (in) (in) TpjftKB) (RKB) (f1KB) (Ibs)tt) Grade Strn To Thrd _ I TUBING 27/8 2.441 0.0 9,700.0 6,186.4 6.50 L-80 EUE -MOD 1_ Other In Hole (All Jewelry: Tubing Run & Retrievable, Fish, etc.) _ Top Depth GAS LIFT, (TVD) Top Intl 3,020 Top (MB) (RKB) (°) Description Comment Run Date ID (in) 1 1,814.0 1,633.0 57.73 SAFETY VLV Otis 'FMX"Locked Open° (8/6/91) 5/18/1990 2.313 3,020.0 2,329.1 54.00 GAS LIFT MERLA/TMPD /1 /DMY /BK/ // Comment: STA 1 3/2/2002 2.375 SURFACE, ! 5,853.0 3,914.6 56.14 GAS UFT MERLA/TMPD /1 /DMY /BK/ // Comment: STA 2 2/11/2010 2.375 7,557.0 4,873.6 55.61 GAS LIFT MERLA/TMPD /1 /DMY /BK/ // Comment: STA 3 3/2/2002 2.375 ^ - - -? 8,450.0 5,410.0 50.86 GAS LIFT MERLA/TMPD /1 /DMY /BK/ // Comment: STA 4 3/2/2002 2.375 GAS LIFT, 5,853 -- -- 9,030.0 5,770.7 51.91 GAS LIFT MERLA/TGPD /1.5 /DMY /RK/// Comment STA 5 3/2/2002 2.375 9,588.0 6,116.6 51.24 GAS LIFT MERLA/TGPD /1.5 /OPEN / /// Comment STA 6 10/22/2010 2.375 9,636.0 6,146.4 51 33 PBR Baker'80-32' w/ 10' stroke 5/18/1990 2.430 9,650.0 6,155.2 51.41 PACKER Baker'HB' RETRIEVABLE PACKER 5/18 /1990 2.430 GAS LIFT, I ,557 7,557 9,688.0 6,178.9 51.62 PLUG CA -2 PLUG 2/8/2010 0.000 9,688.0 6,178.9 51.62 NIPPLE Cameo 'D'Nipple NO GO 5/18/1990 2.250 9,699.0 6,1852 51.68 SOS Baker 5/18/1990 2.441 ` 9,700 0 6,186 1. °1 69 TTL 5/18/1990 2.441 GAS ,450 8650 s ' Perforations & Slots Shot Top (TVD) Btm ( 9,778.0 9,792.0 6,234.5 6,243.1 __ - -- (TVD) Dens Top (RKB) Btm OMB) OMB) (ftKB) Zone Date (oh- Type Comment C -4, 2K -25 12/9/1993 6 0 APERF 2 1 8" EnerJet 90 deg. Ph GAS LIFT, 9,860.0 9,880 0 6,285.1 6,297.3 AS, 2K -25 12/9/1993 6.0 APER 2 1/8" EnerJet 90 deg. PH 9.030 9 ,912.0 9 948.0 6,317.1 6,339.8 A -4, 2K -25 5/17/1990 4.0 IPERF 4.5" HLS CSG Guns;180 deg Ph 9,918.0 9,944 D 6 320.9 6,337.3 A-4, 2K -25 11/20/1993' 3 O 2 1/8" EnerJet, Oriented 45 deg. CW ' Notes: General & Safety GAS LIFT, End Date Annotation 9,588 2/112010 NOTE: LEAK FOUND BETWEEN GLM 83 @ 7557' 5 GLM #4 @ 8450' 5/8/2010 NOTE: PACKER LEAK @ 9654', LLR = 0.5 gpm @ 3000 psi 5/9/2010 NOTE Confirmed Tubing Leaks @ 8087, 8187, 8244' w /Ellne LDL PBR, 9,636 - -- __ 3 PACKER, 9,650 _ NIPPLE, 9,688 I � PLUG, 9,688 - - -- ..'f �Y �) 8 i. r c. i `'" — 30 a63 (, 5- c"`r" SOS,9,699 ': 1,,,.....e TTL, 9,700 - r 1,,,.....e 1,,,.....e APERF. _"" 9,778 -9,792 APER, 9,860 -9,880 - IPERF, '" 9,912 -9,9 46 9,91 — R -9,944 89,944 , to a PRODUCTION, 10,224 TO, 10,264 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Leak Detect Log: 2K-25 Run Date: 5/9/2010 e., July 23, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention o£ Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2K-25 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50-103-20124-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 rafael.barret halliburton com ~~ ~t. •F ~^ ;~ of t ~ Ca ~ i Date: a '~ `?, d~~3~ Signed: o? II/~lELL LAG TRANSII~f/TTAL ''. PrtoAcrive Dinywosric SeevicES, Inc_ 2K-25 EDE 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/ MTT) 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 08-May-10 2) V ._L ~ 1 `? ~ -CU I `~ lg~s ~S Date Signed Print Name: ~ ~t~~~~ ~ i~~ ~~~~, s.~~ ;rr.. w 50-103-20124-00 -~ °: ~ - ~`- MAY ~ '~ 2010 PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : pdsanchoraaeCcBmemorvlog.com WEBSITE : www.memorvloa.com C:\DocumenLc and Settings\Diane Williams\Desktop\Transmit_Conoco.doac WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multifinger Imaging Tool (MIT): 2K-25 Run Date: 3/22/2010 • April 7, 2010 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2K-25 Digital Data in LAS format, Digital Log Image file, Casing Inspection repc 1 CD Rom 50-103-20124-00 w~~,.~~~~; AFB .~ ~ 201 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Rafael Barreto 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-2 - 3s~ -~~ ,~,~, rafael. ' on.com ~. ~~~ ~ ~~~ Date: •• 6g5 ~!~ Signed: • • ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 29, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped June 30, July 4 and July 20, 2008. The corrosion inhibitor/sealant was pumped June 29, June 30, JulylO,and July 24, 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, G~'f. ~~ M.J. Loveland 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) Date Kuparuk Field 7/29/2008 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 2K-01 188-122 SF NA 10" 6/30/2008 2 6/29/2008 2K-02 188-121 SF NA 10" 6/30/2008 2 6/29/2008 2K-03 188-120 24" NA 24" 6/30/2008 8.5 6/29/2008 2K-05 188-118 SF NA 10" NA 2.55 7/10/2008 2K-06 189-082 SF NA 15" NA 1.27 7/10/2008 3K-13 189-095 8'1" 1.00 25" 7/4/2008 6.38 7/10/2008 2K-15 189-089 SF NA 6" 6/30/2008 1 6/30/2008 2K-17 189-119 10" NA 10" 6/30/2008 23.8 6/30/2008 2K-18 .189-108 SF NA 11" NA 2.12 .7/10/2008 2K-21A 198-158 20' 2.70 14" 7/4/2008 4.68 7/10/2008 2K-22 189-115 6" NA 6" 6/30/2008 5.1 6/30/2008 2K-25 190-012 SF NA 12" NA 2.55 7/10/2008 2K-26 190-015 SF NA 10" 6/30/2008 2 6/29/2008 2K-28 201-154 „ 310 NA " 3' 10 6/30/2008 23.8 6/30/2008 2M-04 192-093 SF NA 20" NA 3.4 7/10/2008 2M-27 192-071 9'9" 1.2 18" 7/4/2008 2.55 7/10/2008 2B-07 184-024 20' 2.7 34" 7/4/2008 5.95 7/10/2008 2V-01 183-158 24" NA 24" NA 20.4 7/24/2008 2V-02 183-161 11" NA 11" NA 1.3 7/24/2008 2V-03 183-164 24' 6" 3.40 8" 7/20/2008 5.5 7/24/2008 2V-04 183-165 20' 4" 2.80 8" 7/20/2008 5.1 7/24/2008 2V-05 183-176 SF NA 4" NA 2.1 7/24/2008 2V-09 185-037 SF NA 4" NA 1.7 7/24/2008 2V-11 185-049 SF NA 4" NA 1.7 7/24/2008 2V-12 185-050 40' S.4 8" 7/20/2008 8.5 7/24/2008 2V-13 185-030 18" NA 18" NA 3.8 7/24/2008 2V-14 185-031 SF NA 4" NA 1.7 7/24/2008 2V-15 185-032 SF NA 4" NA 1.7 7/24/2008 ~ "~ (''s , s , n ~ ii ', Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth i~rti`~~~~~ ~~~ ~` ~ ~~~~ Well Job # Log Description N0.4445 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 10/15!07 2N-343 (REDO) 11745232 MEM INJECTION PROFILE ` ~ C '~ 08/08/07 1 16-i4 11837493 PRODUCTION PROFILE - ~ - 08/27/07 1 1A-18 11839651 PRODUCTION PROFILE d- 08(30!07 1 1Y-18 11837499 PRODUCTION PROFILE C 08/30/07 1 1G-i4 11839652 INJECTION PROFILE ~ ~j- 08/31/07 1 1A-01 NIA USIT 08/31/07 1 1Y-04 11839653 INJECTION PROFILE fC5 ~ 09/01/07 1 1Y-32 11839655 PRODUCTION PROFILE j~ - 09102/07 1 2T-TAB-01 11839656 INJECTION PROFILE e - - 09/03/07 1 2K-25 11846439 INJECTION PROFILE U =' j 09/06/07 1 2K-18 11846440 INJECTION PROFILE / 09/07/07 1 1B-18 11846441 PRODUCTION PROFILE </- (p 09108/07 1 2T-20 11846442 PRODUCTION PROFILE ~' .j -- 09109107 1 2N-310 11850433 SONIC SCANNER 7b`~ _O b 09/16!07 1 2N-310 11850433 SONIC SCANNER-FMI ~ - C7~ 09/16/07 1 1J-176 11846443 USIT ~ '~ - 09!17!07 1 1E-29 NIA UCI ( - ~ 09!19/07 1 3F-21 11837503 RSTI WFL - 09/20/07 1 26-10 11839661 INJECTION PROFILE ~ - 09/22/07 1 1G-OS 11837506 INJECTION PROFILE v=C - 09/23/07 1 2H-13 11839662 INJECTION PROFIL L - 09/23107 1 1B-05 11837508 INJECTION PROFILE ~ ~C, 09/24107 1 3H-O8 11839663 PRODUCTION PROFILE - ~ 09/24/07 1 1Y-31 11839664 PRODUCTION PROFILE Jai - 09125!07 1 1G-06 11839665 INJECTION PROFILE 09126/07 1 2Z-01A 11837512 USIT - J ( 09/27/07 1 2V-08A 11837511 ISOLATION SCANNER y(- 09/28/07 1 1G-11 11837513 PRODUCTION PROFILE 09/29/07 1 1Y-22 11837515 PRODUGTION PROFILE - 6 09/30107 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. • • MEMORANDUM . State of Alaska . Alaska Oil and Gas Conservation Commission TO: Jim Regg 9f'¿, b If:" I,; 7 P.I. Supervisor !ì ¿It {' {' DATE: Wednesday, June 06, 2007 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC FROM: Chuck Scheve Petroleum Inspector 2K-25 KUPARUK RIV UNIT 2K-25 O\'d- \~O' Src: Inspector Reviewed By: P.I. Suprv_~ Comm NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 2K-25 API Well Number: 50-103-20124-00-00 Inspector Name: Chuck Scheve Insp Num: mitCS07060 1182517 Permit Number: 190-012-0 Inspection Date: 6/1/2007 v Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 2K-25 Type Inj. w TVD 6155 IA 1500 2450 2440 2440 P.T.D 1900120 TypeTest SPT Test psi 1538.75 OA 0 0 0 0 Interval 4YRTST P/F P -/ Tubing 2500 2500 2500 2500 Notes: Pretest pressures were observed and found stable. Well demonstrated good mechanical integrity. /' SCANNED JUN, 2 0 2007 Wednesday, June 06, 2007 Page 1 of 1 MEMORANDUM ) ) State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Wednesday, August 17,2005 SUBJECT: Mechanical Integrity Tests CONOCOPHlLLIPS ALASKA INC 2K-25 KUPARUK RIV UNIT 2K-25 Jim Reggv C\ I ,j P.I. Supervisor f\~( (/3{D<s" FROM: Chuck Scheve Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Well Name: KUPARUK RIV UNIT 2K-25 Insp Num: mitCS050812191946 Rei Insp Num: API Well Number: 50-103-20124-00-00 Permit Number: 190-012-0 Packer Depth Pretest Wen 1__2K-25rp;, IIlL!W i ~!>-I _6155 I I_~-~o--i P.T. .1 1900120.,Typ~Test sP~J~Test psi L...1538.75_.1 OA l-- 100_1. Interval. 4YRTST. ___fl~ P ..__ Tu~i_~L==~_~. Notes: Pretest pressures observed for 30+ minutes and found stable. Initial 2080 150 2275 ...,", II Ir il.\.~rc:~·. ('E~) ~::: 1 2.005 :;'~II~"\.5~~-';'\~.¡.:.¡LI ,,~ - ¡ y o .) 0\ \~ Reviewed By: P.I. Suprv :JBf2- Comm Inspector Name: Chuck Scheve Inspection Date: 8/12/2005 15 Min. 30 Min. 45 Min. 60 Min. 2080 T 2080 -'T" 1-------· _n_._~__.._ --'-_._____¡-_______ 150 I ISO! · 2275 __ .J~2_~_~_.__~L·_=- "j_.-=-~-= Wednesday, August 17,2005 Page I of 1 11/26/03 Schlumberger NO. 3053 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Company: Alaska Oil & Gas Cons Comm Anchorage, AK 99503-5711 Attn: Lisa Weepie A TTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Well Job# Log Description Date BL Color CD ( 3H-13A 9 (0 -¡crT PRODUCTION PROFILE 11/08/03 1 3A-09 9:; \ .. '9 L\ PRODUCTION PROFILE 11/09/03 1 2K-24 ~ '¡<1-/?r-: SBHP SURVEY 11/10/03 1 2K-25 q ()-êJr~ SBHP SURVEY 11/10/03 1 10-12 qg ~ r)?)L. ÌF'LUG SET & SBHP SURVEY 09/11/03 1 , ( ...~' ~ or\I:8,..Ii\IiIIa.....~"",.. ~#..4 t: II t: ~V t:: i ' Jí...~' . ow "--', ~ \' ~~ DATE: DEC 22 2002 SIGNED: l''I ,t ,",,'" '-\..-'~'~.::l-. /~~ '- i~h3ka O'! & ",' ,,-.;" ..; 0':' v\.HI;;;. ""VÎ i/j S~IOL Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. Anchorage ~~~(\\ ~ ~(Çt~[~~!NEfl) Jð4N 2 @ 2004, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development_X RKB 154 feet 3. Address ExPloratory_ 7. Unit or Property name P. O' Box 100360 Stmtlgraphlc ~ Anch0ra~le, AK 99510-0360 serVice_ Kuparuk Unit 4. Location of well at surface 8. Well number 368' FNL, 94' FEL, Sec. 11, T10N, R...8...~::, '~ (asp's 49a31o, 5e37935) 2K-25 At top of productive interval ~ =. ~ 9. Permit number / approval number At effective depth 10. APl number At total depth 11.' Field / Pool 1122' FNL, 983' FEL, SeC. 13, T1 ON, R8E, UM (asp'~ $02702, 5931902) Kuparuk Oil Pool 12. Present well condition summary true vertical 6539 feet Casing Length Size Cemented Measured Depth T~ue vertical Depth Tubing (size, grade, and measured depth ' "' * ' ' g · {~aS~'nn~ ^ Packers & SSSV (type & measured depth) BAKER 'HB' RETR. O 9650' MD. OTIS 'FMX' *LOCKED OPEN* (8/6/91) O 1814' MD. 14. Estimated date for commencing operation 1,5. Status of well classification as: 17. I hereby certify that the Ioregolng Is true and correct to the best o! my knowledge. Questions? Call Jeff Spencer 659-7226 Signed ~.~s~.~r'~'~ , 'ritie: Production Engineering Supervisor Date "'~'~. Je Prepared b7 Robert Christen$en FOR COMMISSION USE ONLY Condition, of approval: Notify Commission so representative may witnessII Approval no_. ~, Plug Integrity __ BOP Test _ Location clearance _ ~ - Subsequent form required 10- ~'{,~'"~ ~.._~.,~)~,.~.l~,~..~.Mec~lcal Integrity Test_ Approved by order of the Commlssion ~ ~ ~J~.~-, ~ Commissioner Date O ~/,~//~'~ RI]I~ BI:L NAY Form 10-403 Rev 06/15/88 · tab ORiGiNAL SUBMIT IN TRIPLICATE ~. ( -. 2K-25 -" '. DESCRIPTION SUMMARY PROPOSAL Phillips Alaska Inc. requests approval to change the approved progamforwelt2K-25 from Oil production to WAG injection. Well 2K-25 is a single completion with perforations in both the A & C sands. A Halliburton Pulse Echo Cement Evaluation (PET) log was run on 2/14/90. Due to questionaþle bond above the C sand interval, a Waterflowlog will be conducted. A MIT and Tubing pressure testis scheduled and will be completed prior to cOJwen:;ion. D9800 NOTE TO FILE Kuparuk River Unit (KRU) 2K-25 PTD 190-012 302-007 Phillips submitted a 403 to request conversion of a production well to an injector. The request was filed in early 2002. Following the request, the engineer sent an email with a commitment to perform additional logging. The logging information was received in August documenting the work accomplished earlier in the year. This document evaluates the request and recommends acceptance of the information submitted. This well was originally completed as a production well in August 1990. According to the production record, the well produced for roughly 9 months witWa GOR less than 1000. Between May 1991 and March 1994, the well only produced for 16 months (40%) with GORs mostly near 2000 although it is evident that in some months the GOR was reduced likely due to SI time allowing the reservoir to repressure. Until the conversion proposal, the well had not operated for nearly 9 years. In the email sent following the application for conversion, it is noted tha~ the bond log "is questionable, but looks like a potential channel". In the email, the engineer proposed to place the well in service and then run a water flow log (VVFL) to verify zonal isolation. When a bond log is questionable, the process has been to allow the well to be placed into service and perform the WFL log or other log to assess proper fluid containment. The well was placed in service in March 2002 and the WFL run March 8, 2002. The log was finally delivered to the Commission in late August. In the intervening period, the well had been in service from March - June and then SI. The well was returned to water .service in December 2002. · 4 WFL stations were logged in the well, with repeat stations logged at each depth. The investigative depths examined sections of the wellbore above the packer, along the tailpipe below the packer, above the C sand perforations and between the single C and A intervals. There is a difference in the number of energizing cycles used for the initial and repeat passes. 6-7 cycles were used for the repeat pass stations with the goal to give better resolution due to the poor bond log and some difficulty interpreting the main station WFL results. A letter was provided by the Schlumberger logging engineer providing his interpretation of the results. His conclusion is that there is no flow evident above the perforated intervals. Area Injection Order 2B allows injection into the Kuparuk River Oil Pool. The BHL of well 2K-25 is located in the covered area. The portion of aquifers described by a 1/4 mile area beyond and lying directly beneath the Kuparuk River Unit are exempted for Class II injection activities by 40 CFR 147.102(b)(3) and 20 AAC 25.440(c). I recommend acceptance of the submitted diagnostic information. As a follow up to this original diagnostic work, ConocoPhillips should plan to run a temperature log to confirm continued isolation. Sr. Petroleum Engineer April 30, 2003 M:\UIC File Reviews\030430-KRU 2K-25.doc GKA Sundry Reporls Subject: GKA Sundry Reports · Date: Mort, 7 Jan 2002 10:18:04 -0900 From: "Jeff A Spencer" <jspencerC~ppco.com> To: tom_rnaunden~admin.state.ak.us Tom, Just wanted to give you a quick heads up that we are sending in 8 Sundry Reports (one 403, seven 404's) for your review and approval. Also, just wanted to give a little more info on two of the wells. 2K.25: (P-to-I Conversion Candidate) CBL was questionable (not run under pressure, but looks like a potential channel to me). Anyway, we submitted a Form 10-403 but plan on running a Water Flow Log to verify zonal isolation and will forward the results to you as soon as we get it. 2M-09A: (H20 to WAG Injector) In our ongoing efforts to reconcile AOGCC records with PAl's records we noticed that this well's Form 10-404 was missing and so submitted a new 10-404 showing initial gas injection commencing in March 2000. ~, Hope you had a great Holiday Seasonl Jeffrey A. Spencer Production Engineering & Offtake Supervisor Phillips Alaska, Inc. 907-659-7226 Slope jspencer~ippco.com 1 of I 7/25/2002 4:37 PM Re: 2K-25 Water Flow Log Subject: Re: 2K-25 WaterFIow Log 'Date: Wed, 28 Aug 2002 16:12:26 -0800 From: Tom Maunder <tom_maunder@admin.state.ak.us> To: Nina M Woods <nwoods@ppco.com> Nina, I would be happy to meet with you, although I may have to make a quick trip across the Inlet. Please check with our receptionist (call 279-1433, press 0) and she will know. Don't hold up delivery of the information if I'm not here. Thanks. Tom Maunder Nina M Woods wrote: I should be able to have everything together by tomorrow morning for 2K-25. Since you are located just down the street, I can meet with you sometime tomorrow to exchange the information and go over the log if you have any further questions. Thanks, Nina Woods CPF2 Surveillance Engineer 263-4526 NSK Problem Well Supv 08/28/2002 07:33 AM To: torn_maunder@admin.state, ak. us · cc: Nina M Woods/PPCO@Phillips Subject: 2K-25 Water Flow Log Tom: I have done some detective work regarding the water flow log information you wanted on 2K-25. I have asked the Drillsite Engineer (Nina Woods, 263-4526) to make sure you get what you need. Apparently an analysis and letter from us regarding the WFL may have fell through the cracks. > Jerry Dethlefs > Phillips Problem Well Supervisor Tom Maunder <tom maunder~admin.state.ak.us> Sr. Petroleum Engineer Alaska OII and Gas Conservation Commission 1 of 1 4/25/2003 2:21 PM PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 J. Putnam Phone (907) 266-6970 August 27, 2002 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 hand delivered Attachments: 2K-25 Water Flow Log Interpretation by Schlumberger Engineer 2K-25 Water Flow Log Procedure dated 1/14/2002 Form 10-404 Subject: 2K-25 Injection Well Status (API 4/50-103-20124 PTD 190-0120) Dear Mr. Maunder: This letter is concerning a producer-injector conversion completed March 2002. The 1990 Cement Bond Log showed questionable cement bonding immediately above the Kuparuk formation. Phillips proposed that a Water Flow Log ~WFL) be run to demonstrate zonal isolation. The following list summarizes the work that has been completed to date: 01/14/2002: Procedure Issued for WFL to determine zonal isolation 03/05/2002: Well put on water injection (injecting ~ 1000 BWPD) 03/08/2002: WFL ran, zonal isolation confirmed 04/27/2002: Performed post conversion MIT test for AOGCC, Test Passed. With the results of the final WFL (attached) confirming zonal isolation, Phillips requests that 2K-25 continues on normal MWAG operations. The final sundry form has already been completed and submitted to the AOGCC prior to this letter. If you have any questions regarding this matter, I can be reached at 263-4526 ~ ~W~~~ely' 2K Drillsite Engineer PAI Ms. Nina Woods Phillips Alaska 700 G Street Anchorage, Alaska Dear Ms. Woods: Upon review of the Waterflow log on Kuparuk well 2K-25 dated 08-March-2002. I have come to the conclusion that the log does not show any fluid movement above the uppermost perforations at 9,778'. Thus confirming that all the water injection is staying within the perforated zones. Upon first glance the Stations labeled "Main Station Log" showed some random results. They showed some spurious data and possibility of up flow. Upon further examination there~ were 4 pulse cycles being stacked for interpretation. The water flow measurement is a statistical measurement. Thus by stacking more pulse cycles together the greater degree of accuracy the measurement holds. The stations were all repeated stacking 6 pulse measurements together. These stations showed no signs of flow above the uppermost injection perforations. From these stations I concluded that there is no evidence of flow above the intended injection zone~. Sincerely;/-) ! SeniOr Sales Engineer Schlumberger Oilfield Services ~940 Artic BIvd, Suite 300 Anchorage, Alaska General Well Work Request Form Well: 2K -25 Type (Inilprod)_~P~r~d~. Date: ,... 1./. 1.~2. 0.0...2.... From: ........................... B...a.!.°,,~ ../.,..D.°. r..n.a,n, ........................... Phone/Page x 7.§.1. 9~/. ~._a ~.e~r ~ 5...~2. Budget Category: I~' Distribution Job Scope: J knnComm ~' :::::::::::::::::::::::::: Paper IE-mail Capital or Expense: ..E...x.p...e..n..s...e. ................................................ Wells IPE Supv. Property Code/AFC: 230DS28KL/K85486 IWells supv. ICPF Supv. IDS Lead Estimated Cost: $3,000 NOB: 0 ISurv. Eng. ICentral Files JOb Types: SIIckline E Line Tag Fill ~' Water Row Log I Gauge Tbg ~' Coil Tubing Other Justification Well is a producer to water injector conversion with a Ready For Operations date of 02/15/02. The Cement Bond Log run in 1990 does not show 50' of cement isolation above the Kuparuk Formation. Describe the oblectives of this lob and order of importance: Run Water Flow Log to determine if the existing cement provides zonal isolation between water injected in the Kuparuk Formation and the zones above. Procedure Slickline: 1) RU and RIH to tag for fill. Last tag @ 9925' MD on 01/12/97. 2) RD and turn well over to DSO. E-line: 1) RU with Water Flow Log, Gamma Ray and CCL head. 2) RIH and tie into SWS Perforating Record dated 12/09/93 3) Set up WFL tool to detect flow upward behind pipe from 9850' MD-RKB to 9650' MD-RKB with Stop Counts at 9830' MD-RKB, 9750' MD-RKB, 9700' MD-RKB & 9650' MD-RKB. The top of the C4 sand is at 9778' MD-RKB. 4) If behind pipe upward flow is detected between readings or at any WFL stop appears to be anomalous, repeat the WFL at the requested stop counts. 5) If behind pipe upward flow is detected between reading during repeat pass, make WFL stops every 10' to determine the extent of the upward flow of water. 6) Well to maintain a minimum water injection rate of 500 bwpd while logging. 7) RD and turn well over to DSO to return to water injection service as A/C injector. ALASKA INDIVIDUAL WELL PRODUCTION AS OF 08/22/2002 WELL-NAME: KUPARUKRIVUNIT 2K-25 FIELD/POOL: KUPARIIK RIVER, KUPARUK RIVER API: 103-20124-00 LEASE: ADL0025605 OPERATOR: PHILLIPS ALASKA INC. SALES CD - 40 ACCT GRP - 211 FINAL STATUS: DEV i-OIL CURRENT STATUS: SER WAGIN ** OIL PRODUCTION ** 1990 JAN FEB MAR APR MAY JUN JUL METH DAYS OIL WTR GAS 1990 TOTALS OIL 25,328 WATER 111 GAS 13,944 CUM OIL 1991 JAN FEB MAR APR MAY JUN JUL METH GAS LIFT GAS LIFT GAS LI~T GAS LIFT GAS LIFT GAS LIFT GAS LIFT DAYS 31 28 31 26 31 30 25 OIL 3,167 2,520 2,234 1,616 4,254 4,224 2,876 WTR 33 31 35 24 33 94 C~D~g 2,236 1,540 1,711 1,274 7,174 8,747 7,878 1991 TOTi~LS OIL 45,223 -WATER 264 GAS 62,451 CUM OIL AUG SEP OCT NOV DEC GA~ LIFT GAS LIFT GAS LIFT GAS LIFT GAS LIFT 5 18 25 27 30 556 3,329 7,456 7,536 6,451 6 19 26 28 32 269 1,584 4,124 4,187 3,780 25,328 CUM WATER 111 CUM GAS 13,944 AUG SEP OCT NOV DEC SHUT-IN GAS LIFT GAS LIFT GAS LIFT GAS LIFT 21 31 30 31 6,475 7,568 5,124 5,165 14 7,139 8,281 8,113 8,358 70,55% CUM WATER 375 CUM GAS 76,395 1992 JAN FEB MAR APR MAY JUN JUL AUG SEP METH GAS LIFT GAS LIFT GAS LIFT GAS LIFT SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN DAYS 31 16 5 8 OIL 4,813 1,775 605 1,082 GAS 6,843 2,045 632 1,107 ~ 1992 TOTALS OIL 12,238 WATER GAS 14,790 CUM OIL 82,789 CUM WATER OCT NOV DEC GAS LIFT GA~ LIFT FLOWING 15 13 2 2,077 1,753 133 2,091 1,877 195 375 CUM GAS 91 185 1993 JAN METE SHUT-IN DAYS OIL WTR GAS 1993 TOTALS OIL 1994 JAN METH GAS LIFT DAYS - 5 OIL WTR 765 GAS 288 1994 TOTALS OIL FEB MAR APR MAY JUN JUL AUG SEP SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHIT~-IN 2,186 WATER FEB MAR GAS LIFT GAS LIFT 4 30 111 7,748 197 1,304 111 WATER 1995 JAN FEB MAR METE SHUT-IN SHUT-IN SHUT-IN DAYS O~L WTR GAS 1995 T~TALS OIL WATER 1,358 GAS 1,401 CUM OIL 84,975 CUM WATER APR MAY JUN JUL AUG SEP SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN 8,513 GAS 1,789 CUM OIL 85,086 CUM WATER APR MAY JUN JUL AUG SEP SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN OCT NOV GAS LIFT GAS LIFT 18 3 1,911 275 1,053 305 1,260 141 1,733 CUM GAS OCT NOV SHUT-IN SHUT-IN DEC SHUT- IN 92,586 DEC SHUT-IN GAS CUM 0IL 85,086 CUM WATER 10,246 CUM GAS 94,375 10,246 CUM GAS 94,375 OCT NOV DEC SHUT-IN SHUT-IN SHUT-IN i ivin PRODUCTION AS OF 08/22/2002 1996 JAN METH SHUT- IN DAYS OIL WTR GAS 1996 TOTALS OIL 1997 JAN METH GAS LIFT DAYS 15 OIL 333 WTR 923 GAS 286 1997 TOTALS OIL 1998 JAN METH SHUT-IN DAYS OIL WTR GAS 1998 TOTALS OIL 1999 JAN METH SHUT-IN DAYS OIL WTR GAS 1999 ToTALs OIL 2000 JAN METH SHUT-IN DAYS OIL WTR GAS 2000 TOTALS OIL 2001 JAN METH SHUT-IN DAYS OIL WTR GAS 2001 TOTALS OIL 2002 JAN METH SHUT-IN DAYS OIL 2002 TOTALS OIL FEB SHUT- IN MAR APR MAY SHUT-IN SHUT-IN GAS LIFT 2 WATER FEB MAR SHUT-IN SHUT-IN 333 WATE~ FEB MAR SHUT-IN SHUT-IN WATER FEB MAR SHUT-IN SHUT-IN WATER FEB MAR SHUT-IN SHUT-IN WATER FEB MAR SHUT-IN SHUT-IN FEB WATER MAR WATER APR MAY SHUT- IN SHUT- IN 923 GAS APR MAY SHUT- IN SHUT- IN APR MAY SHUT- IN SHUT- IN APR MAY SHUT- IN SHUT- IN APR MAY SHUT- IN SHUT- IN APR MAY GAS JUN JUL AUG SEP OCT NOV DEC SHUT- IN SHUT- IN SHUT- IN SHUT- IN SHUT- IN SHUT- IN SHUT- IN 1 CUM OIL 85,086 CUM WATER 10,246 CUM GAS 94,376 JUN JUL AUG SEP OCT NOV DEC SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT~IN SHUT-IN 286 CUM OIL 85,419 CDMWATER 11,169 CUM GAS 94,662 JUN JUL AUG SEP OCT NOV DEC SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN CUM OIL 85,419 CUM WATER 11,169 CUM GAS 94,662 JUN JUL AUG SEP OCT NOV DEC SHUT-IN F~3T-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN CUM OIL 85,419 CUM WATER 11,169 CUM GAS 94,662 JUN JUL AUG SEP OCT NOV DEC SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN CUM OIL 85,419 CUM WATER 11,169 CUM GAS 94,662 JUN JUL AUG SEP OCT NOV DEC SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN CUM OIL 85,419 CUM WATER 11,169 CUM GAS 94,662 JUN ~ JUL AUG SEP OCT NOV DEC CUM OIL 85,419 CUM WATER 11 169 CUM GAS 94,662 Summary. by Month: Individual Well Injection / Disposal Well Name: KUPARUK RIV UNIT 2K-25 APl: 50-103-20124-00-00 Permit to Drill: 1900120 Operator: CONOCOPHILLIPS ALASKA INC Field/Pool: KUPARUK RIVER, KUPARUK RV OIL Sales Cd: 40 Acct Grp: 211 Final Status: 1-OIL Current Status: WAGIN 2002 . Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Met~ WAG WAG WAG WAG Shut-In Shut-In Shut-In Shut-In Shut-In Days 28 30 31 16 0 0 0 0 0 Wtr 31,392 3 t,0~6 27,590 13,245 0 0 0 0 0 Gas 0 0 0 0 0 0 0 0 0 2002 Totals: Water 123,793 Gas 0 CumWtr 123,793 Cum Gas 0 2003 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov WAG 25 20,540 0 Dec Meth WAG WAG ' WAG Days 31 28 31 Wtr 22,804 19,349 17,414 Gas 0 0 0 2003 Totals: Water 59,567 Gas 0 Cum Wtr 183,360 Cum Gas 0 Monday, April 28, 2003 Page 1 OPERATOR: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test E-Mail to; Tom_Maunder@admin.state.ak.us and Bob_Fleckenstein@admin.state.ak.us Phillips Alaska, Inc. · FIELD / UNIT / PAD: Kuparuk / GKA / MISC DATE: PTD: 2011390 Diesel 883 Well#: lC-119 SW 5.5'/15.5#/L-80 1,500 1,100 COMMENTS: Initial MIT- witnessed Well#: 1C-123 N P SW I 4,843 ~ 7-5/8"/29.7#/L-80 13.5001 1,500 COMMENTS: Initial MIT-- IA did not pressure up. Diagnostics in progress - witnessed Well #: IR-18 N P SW 4,007 9-5/8'/36#/J-55 2.875 1,500 0 1,670 1,610 COMMENTS: D#lling disposal well post workover- v~nessed · ~~:., S P SW 9,650 7"/26# / J-55 2.875 900 COMMENTS: Post conversion MIT 820 1,000 I 1,600 1007 Well#: 2K-28 S P SW 7,109 5.5"/15.5# / L-80 3.500 1,150 COMMENTS: Initial MIT 12,20012,200 2,200I 2, 725 2, 725 2, 725 1505 2,300 2,300 2,300 2,675 2,675 TBG. INJ. FLUID CODES F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Distribution: or~g-- Well File c- Opera~ c- Database c - Trip Rpt File c - Inspector TEST TYPE: M = ANNULUS MONITORING P = STD ANNULUS PRESSURE TEST R = INTERNAL RAD. TRACER SURVEY A = TEMPERATURE ANOMALY TEST D = DIFFERENTIAL TEMPERATURE TEST OPERATOR REP SIGNATURE: Jerry Dethlefs ANNULAR FLUID: DIESEL GLYCOL SALT WATER DRILLING MUD OTHER P.P.G. Grad. 0.00 0.00 0.00 0.00 0.00 WELL TEST: Initial X 4 - Year Workover X Other , AOGCC REP SIGNATURE: John Spaulding where noted 020425-MIT KRU MISC.xls (Rev 9~23~99) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__ RKB 154 feet 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 Exploratory Stratigraphic Service.__X 4. Location of well at surface 368' FNL, 94' FEL, Sec. 11, T10N, R8E, UM At top of productive interval 784' FNL, 1211' FEL, Sec. 13, T1 ON, R8E, UM At effective depth (asp's 498310, 5937935) At total depth 1122' FNL, 983' FEL, Sec. 13, T10N, R8E, UM (asp's 502702, 5931902) 12. Present well condition summary Total depth: measured true vertical 10264 feet Plugs (measured) 6539 feet 7. Unit or Property name Kuparuk Unit 8. Well number 2K-25 9. Permit number / approval number 190-012/ 10. APl number 50-103-20124 11. Field / Pool Kuparuk Oil Pool Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured Depth True vertical Depth CONDUCTOR 115' 16" 191 sx AS il 115' - 115' SUR. CASING 3928' 9-5/8' 1300 sx AS III & 450 sx Class G 4082' 2918' PROD. CASING 10070' 7' 300 sx Class G 10224' 6514' :~;~.'-:~:6~;::b80:~!.~.:: ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: .......... ::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::::: .... · ' ' Packers & SSSV (type & measured depth) 13. Stimulation or cement squeeze summary ;: ::::: :: :: :::::;:: :::::: :: :::::::::: :::::::: :::::: :; :::; :; :;:: :::::;:: :: :: :: :::: :; ;;-::: :: :;:: :::: :: :: :;:: :::: :: :; :; :: :; :: :: :: :;:: :: :::: :: :::: :::: :;:: :; :::: :: :::: :: :::::: :; :: :::: :::::: :: :::: :: :; :; :: :; :::: :: :; :::: :: :::::; ::: ::: ;: :: :; :; :: :: :: :::: :: :::::; ::_-; :.-_-: :.-:; :.-:: :¥ :-':: :-. :; Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative .Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '"X/__, ~" Title Production Engineering Supervisor Jeff A. Spencer Questions? Ca# Jeff Spencer 659-7226 Prepared by Robert Chdstenser~ 659-7535 SUBMIT IN DUPLICATE 2K-25 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary ~' .- '~: ..... :ii/: ~"..~i-i._ -'~i'!~"/17.'-?~'-'.:', '.'.'~..'*":/i'i' :7'~' .- ~-:? ~' '-.-~i.i-':~.--.-.- - :-' '- .: ".'F'_~.- '- -".-~ ..... :':.'_-.7 .... ~- - ..... ~ -~_.-~' -.~-~-~i:.~-:::.~? !~'..~.'.~:~'..-:v - 3/~r~-:i~~~;.~A~i-~o-,~i~J~i~i!.~' :~ :':-~.'~?-''. ':-' :--:~--" ...... :.::::'?-~--~"~-?~_~'~-~:-;~?.~::~-~-'-'~' ~:;-~:-~'~-::-:::~.~'?~??~.~; ~t ., STATE OF ALASKA ALA-~t~,A OIL AND GAS CONSERVATION COMiviISSION WELL COIIIPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of Service Well -. OIL [~] GAS [~] SUSPENDED E~] ABANDONED [-'] SERVICE ["--'] · 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 90-12 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20124 4 Location of well at surface _~'.--,---,,~_. ~1 ~ 9 Unit or Lease Name I 'fit-~ ~ -~ 369' FNL, 95'FEL, SEC 11, T10N, R8E UM ' ~-"~,;PL_~.r/.,, , l KUPARUKRIVER ! At Top Producing lnterval ~/'/~/-~_ i :' rr~ ! 10 WellNumber 782' FNL, 1153' FEL,SEC 13, T10N, R8E UM _ '*,..:. ~'~ i''u: .... ~--i 2k-25 At Total Depth /E~ ' .2' ' '--'-~'~'~' ii Field and Pool ii2i' FNL, 982' FEI, SEC 13, TiON, RSE UM-~-~ KUPARUK RIVER FIELD 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. KUPARUK RIVER OIL POOL RKB 154' ADL: 25605 ALK: 2679 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 115 Water Deplh, if offshore 116 No. of Completions 1/18/90. 1/25/90. 5/19/90.J NA feet MSLJ 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set I 21 Thickness of permafrost I I 10264' MD & 6539' TVD 10138' MD & 6460' TVD YES X~J NO LJ 1814' feet MD 1400' APPROX 22 Type Electric or Other Logs Run DIL/SFL/GR/SP/FDC/CNL/CAL/CBL/GYRO 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 62.5# H-40 SURF 115' 24" 191 SX AS II 95/8" 36~ J-55 SURF 4082' 12-1/4" 1300 SX AS III, 450 SX CLASS G 7" 26~ J-55 SURF 10224' 8-1/2" 300 SX CLASS G 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) ~SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" 9700' 9650' 9912' - 9948' W/4-1/2" Csg gun @ 4 SPF MD 6317' - 6340' TVD 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) I AMOUNT & KIND OF MATERIAL USED SEE ATTACHED ADDENDUM 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) I Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I ~AS-OIL RATIO I TEST PERIOD ~ Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE ~ 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Fractured 8/14190-- "~jArJchO['~l~'"'~~;":!' :;,:.--:~:' :.~ Form 10-407 Submit in duplicate Rev. 7-1-80 ~NUED ON REVERSE SIDE GEOLOGIC MARKERS FORMATION TESTS NNv~ Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and 'dme of each phase. KUPARUK C TOP 9776' 6233' NA KUPARUK C BO'I-rOM 9792' 6243' KUPARUK A TOP 9836' 6270' KUPARUK A BO'FI'OM 10035' 6395' 31. LIST OF ATTACHMENTS GYRO, Frac addendum, Daily Operations 32. I hereby certify that the foregoing is true and correct to the best of my knowledge INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion repeal and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none". Form 10-407 ADDENDUM WELL 2K-25 8/14/90 Frac Kuparuk "A" sand perfs 9912'-9948' 180 deg oriented 164 deg ccw in seven stages as follows. Stage 1: Pmp 200bbls Gel H20 w/HyBor prepad @ 20 bpm 5900-6240 psi 45 bbls Gel H20 w/HyBor @ 15 bpm 4815+4880 psi 30 bbls Gel H20 w/HyBor @ 10 bpm 3710-3860 psi Stage 2:62 bbls Slick H20 flush @ 20 bpm 6715-6150 psi Stage 3:1000 bbls HyBor pad @ 20 bbls 5455-6590 psi Stage 4:92 bbls HyBor w/2ppg 16/20 Carbolite @ 20-18 bpm 6590-7530-7140 psi Stage 5:102 bbls HyBor w/4ppg 16/20 Carbolite @ 18-17-16-15.5 bpm 7140-7740-7320 psi Stage 6:90 bbls HyBor w/6ppg 16/20 Carbo]ite @ 15.5 bpm 7320-7940 psi Stage 7:62 bbls Slick Diesel flush @ 15 bpm 7850-6920 psi Fluid to recover: 1684 bbls Sand in zone: 54,672 lbs Sand in csg: 580 lbs Avg pressure: 6600 psi D~pervisor Date ARCO Oil m,d Gas Company Well History - Initial Report - Daily Instructions: Prepare and submit the "l~liflil R~rt" on the first Wednesday after a well is spudded or workover operations are started. Daily wort< prior to spudding should be summarized on the form giving inclusive dates only. District .~_. ARCO ALASKA INC. ICounty, parish or borough NORTH SnOPE Lease or Unit Title A~L'- 25605 COMP LETI ONS lSrete AK KUPARUK RIVER UNIT Auth. or W,O. no. AK4567 ALK: 2679 J Well no. 2I~-25 Operator Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. 05/18/90 (10) TD: 0 PB:10143 SUPV:DEB ARCO W.I. I Oate Hour Prior status 01/18/90 00:00 Complete record for each day reported NORDIC RIG I RD HLS E-LINE 7"@10223' MW:10.0 NaCl/Br RIG MOVE 2K-24 TO 2K-25, ND LOWER TREE, TST BOPE, RU HLS E-LINE, RIH W/ GUN #1 CCL WKNG INTERMTTENTLY, POH, CHANGE CCL, RE-RUN GUN #1, PERF @ 9932-9948, ASF, RIH W/ GUN #2, PERF @ 9912-9932, ASF, RD HLS E-LINE DAILY:S29,506 CUM:$859,611 ETD:S859,611 EFC:$1,536,200 The above is correct For form preparation~anJl dlstribution,~..~ see Procedures Man~/ Section 10, Drilling, Pages 86 and 87. AR3B-459-1-D Number all dally well hlstoi'y forme consecutively as they m'e prepared for each well. iPage no. ARCO C. 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 s_uspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report cornpletloll 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 County or Perish ARCO ALASKA I~C. NORTH SLOPE Field KUPARUK RIVER UNIT ITitle ADL: 25605 ALK: 2679 2~-25 I I COMPLETIONS Slate Auth, or W.O. no. AK4567 Operator A.R.Co. W.I. ARCO 55. 8533 Spudded or W.O. begun Date SPUD 01/18/90 Date and depth Complete record for each day reported as of 8:00 a.m. 05/19/90 (11) TD: 0 PB:10143 SUPV:DEB NORDIC RIG 1 Iotal number of wells (active or inactive) on this osl center prior to plugging and bandonment of this well our J Prior status if a W.O. I 00:00 RIG RELEASED 7"@10223' MW:10.0 NaCl/Br FINISH RD HLS E-LINE, RUN 2 7/8" COMP. ASS., SET PKR, TST SSSV, OK, ND BOP, N',J FMC GEN IV, TST PCKOFF, OK, SHEAR SOS @ 3300PSI, REVERSE 6 BBLS DIESEL INTO ANNULUS, INJECT 1.5 BBLS DIESEL INTO TUBING, SECURE WELL, RELEASE RIG @ 24:00 5/18/90 DAILY:S167,964 CUM:$1,027,575 ETD:S1,027,575 EFC:$1,536,200 Old TD New TD PB Deplh Released rig Date Kind of rig Classifications (oil, gas, etc.) I Type completion (single, dual, etc.) Producing method I Official reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR ; Gravity %llowable Effective date corrected The above is correct For form preparal0~and distribution, see Procedures M'~,~al, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C Date / / Tit .1~. as they are iiCi OFILME, D SURVEY REPORT ARCO ALASKA INC. KUPARUK FIELD, PAD 2K WELL NO. 25 NORTH SLOPE, ALASKA FEBRUARY 23, 1990 Gyrodata Incorporated P.O. Box 79389 Houston. Texas 77224 713/461-3146 Fax: 713/461-0920 February 23, 1990 Mr. Tim Billingsly Arco Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk Field, Pad 2K Well No. 25 North Slope, Alaska Dear Mr. Billingsly' Enclosed please find one (1) original and nine (9) copies of the completed survey of Well No. 25. We would like to take this opportunity to thank you for using Gyrodata and we look forward to serving you in the furore. Sincerely, Vice President, Technical Services GU/cv Enclosures Gyrodata Services, Inc. Houston, TX / Lafayette, LA / New Orleans, LA/Ventura, CA / Aberdeen, U.K. / Calgary, Alberta Anchorage, AK / Kuantan, Malaysia i Buenos Aires, Argentina / Bergen, Norway A Gyrodata Directional for Survey ARCO ALASKA INC. KUPARUK FIELD, PAD 2K, WELL NO. 25 NORTH SLOPE, ALASKA Date Run: 14-FEB-90 02:48:19 Job Number: AK0290G207 Surveyor: MIKE HOWATT Calculation Method: RADIUS OF CURVATURE Survey Latitude: 70deg 14min 30sec N Sub-sea Correction from Vertical Reference: 118.0 ft Bearings are Relative to TRUE NORTH Proposed Well Direction: S 36deg 13min 0sec E Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyrodata Directional Survey RCO ALASKA INC. JPARUK FIELD, PAD 2K, WELL NO. 25 3RTH SLOPE, ALASKA 3b Number: AK0290G207 Page MEAS INCL BORE HOLE DEPTH BEARING ft deg min deg min .0 0 0 N 0 0 E 100.0 200.0 300.0 400.0 500.0 6O0.0 700.0 800.0 900.0 1000.0 1100.0 1200.0 1300.0 1400.0 1500.0 1600.0 1700.0 1800.0 1900.0 2000.0 2100.0 2200.0 2300.0 2400.0 0 14 N 83 22 E 0 18 S 54 25 E 0 9 S 22 1E 2 20 S 32 49 E 4 46 S 31 15 E 7 53 S 31 3 E 12 4 S 28 34 E 15 48 S 27 15 E 19 25 S 30 25 E 21 5 S 34 43 E 24 15 S 36 32 E 28 32 S 36 41 E 32 13 S 36 29 E 35 12 S 36 28 E 4.0 37 S 36 42 E 45 17 S 34 23 E 48 45 S 32 27 E 51 18 S 32 27 E 55 49 S 34 14 E 53 36 S 34 42 E 53 14 S 33 40 E 52 38 S 32 58 E 53 53 S 35 34 E 53 45 S 36 42 E DOG-LEG VERT VERT SEVERITY DEPTH SECTION deg/100' ft ft CLOSURE DISTANCE BEARING ft deg min .00 .0 .0 .0 N 0 0 E MULTI SHOT SURVEY IN 7 INCH CASING ALL DEPTHS ARE REFERENCED TO KB ELEVATION KB TO GROUND = 36 FT. ( KB ELEVATION = 154 FT. ) .24 100.0 .1 .2 N 83 22 E .20 200.0 .5 .7 S 82 3 E .19 300.0 .8 1.0 S 65 57 E 2.18 400.0 3.0 3.0 S 39 7 E 2.44 499.8 9.2 3.12 599.1 20.1 4.20 697.6 37.4 3.75 794.7 61.2 3.73 890.0 91.2 9.2 S 34 21 E 20.2 S 32 36 E 37.5 S 31 18 E 61.5 S 29 59 E 91.8 S 29 36 E 2.23 983.8 125.7 3.26 1076.0 164.2 4.27 1165.6 208.7 3.70 1251.9 259.2 2.98 1335.0 314.7 126.3 S 30 25 E 164.7 S 31 38 E 209.0 S 32 41E 259.5 S 33 27 E 314.9 S 33 59 E 5.41 1413.9 376.1 4.94 1487.1 444.2 3.73 1555.2 517.3 2.55 1619.5 593.7 4.74 1678.9 674.1 376.3 S 3~ 24 E 444.4 S 34 35 E 517.5 S 34 25 E 594.1 $ 34 10 E 674..5 S 34 4 E 2.25 1736.6 755.6 .91 1796.2 835.9 .83 1856.5 915.6 2.44 1916.3 995.6 .92 1975.4 1076.4 756.1 S 34 6 E 836.4 S 34 7 E 916.2 S 34 3 E 996.3 S 34 4 E 1077.0 S 34 13 E HORIZONTAL. C O O R D I N A T E S,ii. feet .00 N .00 E .02 N .21 E .09 S .65 E .40 S .89 E 2.32 S 1.89 E 7.57 S 5.17 E 17.00 S 10.87 E 32.03 S 19.48 E 53.31 S 30.75 E 79.80 S 45.33 E 108.95 S 63.95 E 140.27 S 86.39 E 175.94 S 112.90~= 216.54 S 143.02~ 261.17 S 176.01 _ 310.48 S 212.62 E 365.90 S 252.21 E 426.96 S 292.49 E 491.61 S 333.60 E 558.79 S 377.81 E 626.08 S 424.00 E 692.51 S 469.11 E 759.19 S 512.93 E 825.41 S 558.05 E 890.59 S 605.64 E ~CO ALASKA INC. JPARUK FIELD, PAD 2K, WELL NO. 25 )RTH SLOPE, ALASKA ~b Number: AKO290G207 A Gy rodat a Directional Survey Page MEAS INCL BORE HOLE DOG-LEG DEPTH BEARING SEVERITY ft deg min deg min deg/100' 2500.0 55 21 S 37 34 E 2600.0 56 16 S 40 6 E 2700.0 55 48 S 38 15 E 2800.0 55 12 S 38 13 E 2900.0 54 40 S 37 28 E 3000.0 54 14 S 36 45 E 3100.0 54 11 S 36 42 E 3200.0 54 25 S 36 6 E 3300.0 57 54 S 40 7 E 3400.0 57 42 S 39 35 E 3500.0 57 14 S 38 44 E 3600.0 56 49 S 37 49 E 3700.0 56 38 S 36 22 E 3800.0 56 22 S 36 22 E 3900.0 56 17 S 35 41 E 4000.0 56 27 S 33 29 E 4100.0 55 30 S 32 52 E 4200.0 55 25 S 33 34 E 4300.0 55 27 S 33 55 E 4400.0 55 36 S 33 29 E 4500.0 ,~'55 27 S 34 17 E 4600.0 '55 40 S 34 21 E 4700.0 .?~55 51 S 34 16 E 4800.0 ' ~'~:":55 42 ~ S 34 46 E 4900.0 , , ;~:.~ 55~2~~. 2 ~:~:~i~,~,,, ~ S 34 12 E ,~f '.,]~ 1.75 2.29 1.61 .61 .81 .72 .08 .55 4.83 .50 .85 .88 1.23 .27 .57 1.83 1.08 .58 .29 .39 .68 .22 .19 .44 .50 VERT DEPTH ft 2033.4 2089.6 2145.4 2202.1 2259.5 2317.7 2376.1 2434.5 2490.2 2543.5 2597.3 2651.7 2706.6 2761.8 2817.2 2872.6 2928.6 2985.3 3042.0 3098.6 3155.2 3211.8 3268.0 3324.3 3380.5 VERT C L 0 S U R E SECTION DISTANCE BEARING ft ft deg min 1157.8 1240.4 1323.3 1405.6 1487.4 1568.8 1649.9 1731.1 1814.1 1898.5 1982.7 2066.6 2150.1 2233.5 2316.8 2400.0 2482.7 2565.0 2647.2 2729.6 2812.0 2894.4 2977.0 3059.7 3142.3 1158.4 S 34 25 E 1240.9 S 34 43 E 1323.6 S 35 0 E 1405.8 S 35 11 E 1487.6 S 35 20 E 1568.9 S 35 25 E 1650.0 S 35 29 E 1731.2 S 35 32 E 1814.2 S 35 39 E 1898.6 S 35 50 E 1982.7 S 35 59 E 2066.6 S 36 .4 E 2150.1 S 36 7 E 2233.5 S 36 7 E 2316.8 S 36 7 E 2400.0 S 36 4 E 24.82.8 S 35 58 E 2565.0 S 35 53 E 2647.3 S 35 49 E 2729.7 S 35 45 E 2812.1 S 35 42 E 2894.5 S 35 39 E 2977.2 S 35 37 E 3059.8 S 35 35 E 3142.5 S 35 33 E HORIZONTAL C 00RD INA T E S~ feet 955.53 S 654.82 E 1019.96 S 706.68 E 1084.26 S 759.07 E 1149.00 S 810.07 E 1213.64 S 860.27 E 1278.52 S 909.36 E 1343.54 S 957.86 E 1408.90 S 1006.05 E 1.474.24 S 1057.28 E 1539.21 S 1111.50 E 1604.57 S 1164.73 E 1670.42 S 1216.70 E 1737.11 S 1267.12 E 1804.26 S 1316.56 E 1871.58 S 1365.50 E 1940.12 S 1412.75!~ 2009.48 S 1458.10 2078.39 S 1503.22 E 2146.86 S 1548.96 E 2215.44 S 1594.70 E 2283.88 S 1640.66 2351.98 S 1687.16 2420.26 S 1733.76 2488.38 S 1780.61 2556.54 S 1827.43 RE0 ALASKA INC. 5PARUK FIELD, PAD 2K, WELL NO. 25 )RTtt SLOPE, ALASKA 3b Number: AKO2900207 A Gyrodata Directional Survey Page MEAS INCL BORE HOLE DOG-LEG DEPTH BEARING SEVERITY ft deg min deg min deg/lO0' 5000.0 55 42 S 34 6 E 5100.0 55 40 S 34 24 E 5200.0 55 49 S 34 45 E 5300.0 55 58 S 34 49 E 5400.0 56 3 S 35 17 E 5500.0 55 57 S 35 22 E 5600.0 55 58 S 35 31 E 5700.0 56 4 S 35 32 E 5800.0 56 8 S 35 36 E 5900.0 56 11 S 35 44 E 6000.0 56 16 S 35 20 E 6100.0 56 14 S 35 37 E 6200.0 56 16 S 35 28 E 6300.0 56 1.0 S 35 27 E 6400.0 56 27 S 35 21 E 6500.0 56 26 S 35 30 E 6600.0 56 29 S 35 32 E 6700.0 55 58 S 35 49 E 6800.0 55 0 S 36 26 E 6900.0 55 18 S 36 24 E 7000.0 55 22 S 36 21 E 7100.0 55 20 S 36 11 E 7200.0 55 22 S 36 9 E 7300.0 55 4 S 36 35 E 7400.0 55 8 S 36 24 E .18 .25 .33 .16 .39 .12 .13 .11 .08 .12 .33 .24 .14 .10 .29 .12 .06 .57 1.09 .30 .O8 .14 .04 .47 .17 VERT DEPTH ft 3436.8 3493.2 3549.5 3605.5 3661.4 3717.4 3773.3 3829.2 3885.0 3940.7 3996.3 4051.9 4.107.4 4163.0 4218.5 4273.8 4329.0 4384.6 444.1.3 4498.5 4555.3 4612.2 4669.1 4726.1 4,783.3 VERT C L O S U R E SECTION DISTANCE BEARING ft ft deg min 3224.9 3307.5 3390.1 3472.9 3555.8 3638.7 3721.5 3804.4 3887.4 3970.5 4053.6 4136.7 4219.9 4303.0 4386.2 4469.5 4552.8 4635.9 4718.3 4800.4 4882.6 4964.9 5047.2 5129.3 5211.3 3225.2 S 35 31E 3307.7 S 35 29 E 3390.4 S 35 28 E 3473.2 S 35 27 E 3556.1 S 35 27 E 3639.0 S 35 26 E 3721.9 S 35 26 E 3804.8 S 35 26 E 3887.8 S 35 27 E 3970.8 S 35 27 E 4.054.0 S 35 27 E 4137.1 S 35 27 E 4220.2 S 35 27 E 4303.4 S 35 27 E 4386.5 S 35 27 E 4469.9 S 35 27 E 4800.8 S 29 E 4883.0 S 35 30 E 4965.3 S 35 31 E 5047.5 S 35 31 E 5129.7 S 35 32 E 5211.7 S 35 33 E HORIZONTAL. C 0 0 R D I N A T E ~i' feet ' 2624.97 S 1873.84 E 2693,23 S 1920.33 E 2761.28 S 1.967.23 E 2829.29 S 2014.47 E 2897,17 S 2062.08 E 2964.81 S 2110.02 E 3032.33 S 2158.06 E 3099.81 S 2206.25 E 3167.32 S 2254.52 E 3234.80 S 2302.94 E 3302.45 S 2351.25 E 3370.15 S 2399.51 E 3437.80 S 244.7.84 E 3505.50 S 24.96,05 E 3573.32 S 2544.25 E 3641.22 S 2592.56 3709.05 S 2640 9~ 3776.57 S 2689.47 E 3843.13 S 2738.04 E 3909.16 S 2786.76 E 3975.38 S 2835.53 E 4041.70 S 2884.20 E 4108.12 S 2932.74 E 4174.25 S 2981.45 E 4240.19 S 3030.22 E A Gyrodata Directional Survey ~CO AI,ASKA INC. JPARUK FIELD, PAD 2K, WELL NO. 25 )RTH SLOPE, ALASKA ~b Number: AK0290G207 Page blEAS INCL BORE HOLE DOG-LEG DEPTH BEARING SEVERITY ft deg min deg min deg/100' 7500.0 55 9 S 36 15 E 7600.0 54 52 S 35 56 E 7700.0 53 7 S 36 46 E 7800.0 53 7 S 37 49 E 7900.0 53 31 S 38 9 E 8000.0 53 51 S 37 37 E 8100.0 53 35 S 37 46 E 8200.0 53 51 S 38 7 E 8300.0 50 55 S 40 19 E 8400.0 50 32 S 41 58 E 8500.0 51 1 S 41 49 E 8600.0 51 21 S 41 34 E 8700.0 51 23 S 41 40 E 8800.0 51 55 S 42 11 E 8900.0 51 52 S 41 30 E 9000.0 51 51 S 42 19 E 9100.0 52 0 S 41 33 E 9200.0 52 8 S 42 29 E 9300.0 52 4 S 42 49 E 9400.0 51 31 S 42 25 E 9500.0 50 54 S 40 1 E 9600.0 5,1 17 S 36 25 E 9700.0 51 41 S 32 33 E 9800.0 ~52 15 S 29 39 E 9900 0 ~,i$1 37 S 28 49 E ,,,.:?-, ?? .11 .39 1.88 .84 .49 .55 .31 .39 3.41 1.34 .5O .38 .09 .67 .55 .65 .63 .75 .28 .63 1.96 2.83 3.05 2.36 .92 VERT DEPTH ft 4840.5 4897.8 4956.6 5016.7 5076.4 5135.6 5194.8 5254.0 5315.0 5378.3 5441.5 5504.2 5566.7 5628.7 5690.4 5752.2 5813.9 5875.3 5936.8 5998.6 6061.2 6124.0 6186.3 6247.9 6309.6 VERT C L 0 S U R E SECTION DISTANCE BEARING ft ft deg 5293.4 5375.3 5456.2 5536.1 5616.3 5696.8 5777.4 5858.0 5937.1 6014.2 6091.3 6168.8 6246.6 6324.6 6402.9 6481.2 6559.5 6638.0 6716.4 6794.5 6872.2 6949.9 7028.1 7106.6 7184.7 5293.7 S 35 34 E 5375.6 S 35 34 E 5456.5 S 35 35 E 5536.4 S 35 36 E 5616.6 S 35 38 E 5697.1 S 35 40 E 5777.6 S 35 4.2 E 5858.2 S 35 44 E 5937.2 S 35 47 E 6014.3 S 35 51 E 6091.4 S 35 55 E 6168.9 S 36 .0 E 6246.6 S 36 4 E 6324.6 S 36 8 E 6402.9 S 36 13 E 6481.2 S 36 17 E 6559.6 S 36 21 E 6638.0 S 36 25 E 6716.5 S 36 29 E 6794.6 S 36 33 E 6872.3 S 36 37 E 6950.1 S 36 38 E 7028.3 S 36 36 E 7106.7 S 36 33 E 7184.8 S 36 28 E HORIZONTAL COORDINATES( feet .4306.29 S 3078.82 E 4372.49 S 3127.08 E 4437.63 S 3175.03 E 4501.26 S 3223.48 E 4564.46 S 3272.84 E 4628.06 S 3322.32 E 4691.85 S 3371.61 E 4755.42 S 3421.16 E 4816.79 S 3471.23 E 4875.08 S 3522.16 E 4932.75 S 3573.88 E 4990.93 S 3625.70 E 5049.32 S 3677.59 E 5107.67 S 3730.00 E 5166.29 S 3782.49 E 5224.82 S 3835.02~ 5283.38 S 3887.62~ 5341.98 S 3940.41 E 5400.02 S 3993.87 E 5457.85 S 4047.07 E 5516.48 S 4098.43 E 5577.60 S 4146.57 E 5642.09 S 4190.87 E 5709.53 S 4231.55 E 5778.23 S 4269.99 E .~CO ALASKA INC. JPARUK FIELD, PAD 2K, WELL NO. 25 3RTH SLOPE, ALASKA ob Number: AK0290G207 A Gyrodata Directional Survey Page MEAS INCL BORE HOLE DEPTH BEARING ft deg min deg min 10000.0 50 28 S 29 2 E 10100.0 50 42 S 24 21 E 10138.0 51 3 S 23 32 E Final Station Closure: 7366.8 feet DOG-LEG VERT VERT SEVERITY DEPTH SECTION deg/100' ft ft 1.16 6372.5 7261.8 3.62 6436.0 7338.0 1.90 6459.9 7366.8 South 36 deg 13 min 57 sec East CLOSURE DISTANCE BEARING ft deg min 7261.8 S 36 23 E 7338.0 S 36 17 E 7366.8 S 36 14 E HORIZONTAL C 00 R D I N A T E S~' feet 5846.29 S 4307.59 E 5915.30 S 4342.28 E 5942.24 S 4354.24 E by GREAT LAND DIRECTIONAL DRILLING, INC. for Gyrodata Services, Inc.' 07/24/90 Client .... : ARCO ALASKA, INC. Field ..... : KUPARUK Well ...... : KRU 2K-25 Section at: S 36.22 E Engineer..' MIKE HOWATT Computation...: RADIUS OF CURVATURE Survey Date...: 07/17/90 RKB Elevation.: 154.00 ft API Number .... : 50-103-20124 Job Number .... : AK0290G207 INTERPOLATED MARKERS REPORT Surface Location: 369 SNL 95 WEL Sll T10N R8E MARKER IDENTIFICATION 9-5/8" CASING TOP KUPARUK C BASE KUPARUK C TOP KUPARUK A MEAS INCLN DEPTH ANGLE 0 0.00 4082 55.66 9776 52.12 9792 52.21 9836 52.02 VERT-DEPTHS SECT BKB SUB-S DIST BEARING 0 -154 0 N 0.00 E 2918 2764 2468 S 32.98 E 6233 6079 7088 S 30.34 E 6243 6089' 7100 S 29.87 E 6270 6116 7135 S 29.34 E DIRECTION REL-COORDINATES FROM-WELLHEAD ON 0E 1997 S 1450 E 5693 S 4222 E 5704 S 4228 E 5734 S 4245 E BASE KUPARUK A PBTD 7" LINER TD 10035 50.54 10138 51..04 10224 51.04 10264 51.04 6395 6241 6460 6306 6514 6360 6539 6385 7288 S 27.39 E 7367 S 23.53 E 7432 S 23.53 E 7462 S 23~53 E 5870 S 4320 E 5942 S 4354 E 6003 S 4381 E 6032 S 4393 E' ItOUS fON INSTRU 1'4 EN T AUSTIn. TEXAS CHART NO. 1015 -ill-, , i i , I_L - 4----t-.T?'__:_' _.:__i_~ ..... · _ _ { ~ ~ ! : : , = '. : , ~:!~n- ~. ...1- ~,..;:. ,: --~:}--~.l;l_: :.l:,,: · :: :l :-. ~: ,:l :':''l' -: ': : :'~ - i i!~---~!--i--~ll~--i -- 'I- ! i ~:ll .:-~-- -: .... -n--H-'' [4~--~ 'm.=i':K- - F-l~- -F l_;_ ........................ ~ ......... : : ........ :_ _ .... ~-)-,-,..; ........ ~.. ; ..... {~! -- ~ ...... : . . : : _ · ~ · ~ , . , . , . ~.,-i-r~'~'~"- _ ' :~:-'-"ii'~"'~':' '~ ' ' :' ' ' ~ ' ~ .....I ~ i I - - · :: ............. : , : -; ..... d - ~ ! ; ! ~ ~: ! .... : ....... - ro; ' i ' ' i~, !':'=:,:~'-, · . · . ........... : .... : ......... ~_.,_,.._.~..,_,_, ............................... ~~ -i%r' _ : _ ~/__~ _ , ,_ . , . . . ~ - . ~ , . , i , ) ; . : ~ -t -'~ ,--{'-- ~{--' : ~:'t .'-l- i -'{ [ ' :...:_l ~: : : · : ..... ....... : '= i ; i : i.: : : ~ ii.. _4_l_~t_ - - / .-: ,'-i.'-'~--~-,q- ' -.y~.- '~-.'- - !,~ , ., : ~ .I · : : ~, : , ....... ; ~-I- -h-l-i ii- i. Lil~'; .... I~,,~P!- . ~., ......... i _ ,,, · ., ',: ............... . ...... :. ;, ::, :!'. ~ :--="-i't: :' '' : ' ...... ......._. j.~]~ ...... l-~t~"'l' q ' ; ' ~-' I" -' ; .......... !': ~ : ........... ...... : : t · ' t : ~' ; ' t t ' ~ ..... ' ; ........ ' ' '.-? ._]~_ . ,_ j _~ , . . . . . , . , , . . . . : , : :, - . ±:-! '-,- , l-i-,'!- H+t--q-i--F,-~,-~ _ L[~ ~j ~ ,; .......... :, ::.~ : : :.: . : : I .......... :, ........ ........ .... : .... . .:. ........ -. - - '~- '1-71 ~ -' :- ........ .'t i'i'~'~ '" ','''' .'': ::'' '': ........... : .... '1 ....... :~ ....... ..~: ; ½ ,:-~ :{-,~'~:-~-~'; !~+-~ :~!~:,:L-Li.:i.': I~; ~-+', - -~-i~- ~+.~,-~!-!-~- i~ , ..... ~ ....... FIRE(] aLFtS~2 [NC ............ ............................... , ............ ....... ~ ....... ~' tUPB~U~ 'f:'IE'LO~' PBO ~ NELL: :~'.; .... +".:::[~;~¥. '::. %zN(l~]~..~:SEOpEv. FREBB~R ..... :':::~:.:..;. u:.:...~ ........... : b82c06257 ....... !.; :-. ...;..:.: ; : ; '": ......... T ........ ['~'[ _. ' , :'::'",:,':~ : ........ : ~'. :~-:: ': :.:. ~:::::.., ; ': ':~7" .~ . . ;_: ..... . : ..:-~,: ...... ; .: .... : , ..: :;,' ':-:-: .... ;"~ ~ .... ~ .......... ; ........ ~V"::- :":-":'-~ ....... ; , : . ~ ; ~ ' . ' ' :~:-:::'~' '::. ::'.:'::., ::::::::::::::::::::::::: ~::::~'"¥'~ :":""':~:':' :~:::'':': '-::' ':' '':'/~:'' .. ~.-.:-~ ..... ~ ; .........~~[][/[~~. ~/~~~:.-: ....... :---.~ ..........i : ............ ~ .-~ ~ ........... ~ ..... ~ :-- :-[-.-: :-.-.: ; ...... ........ :: ..... ..... , ..... , : . : ; ": ~ ..... : ....... : ..... ~ --:': '~':': :~":'lll::~l~:~ t" ~':":" : : ::' ":] ~ :- -~:'"::':':"~:~,,---.~,: : ::.': :~-" ............. I ........ ]~ .... : ~ ....... '.~_ ........................ , ............. ~ ~ , ; ; ........ ' : ............. ~i ............. .... ~ '~ ...... :'':' '"' '' 7~"~:::"-:[: :'~C: ~::~ ~¥:-::~-: ::. ~.~. '~:~ -::: ,~ ": ~' :2:::-: ;',:'-::;' ::':::' ::~-~:: -:.~ : ~-.~_.: :~ ,. . ...:-?::: -: :: :_:::-.: :~.:-:--~.:.:-:-:. ~:.-:.:, :-:-::. :::::::::::::::::::::: ~ .:::~:': :::L :::::::::::::::::::::: .':[ .... ..... ........ ',':' ~ :::~:_ ::':::'~:L:: :::' 7:::' ::: ~ _~ ~ ~__ ~ , '~.. ,':~, : .... ~., .,.: : , . -~t~:- , -:q-F- ':: ~- ' : ' :~ ~i'~-:- i:~-- - ~- '-'~ -~--- - ' ...... F ~ , _ L__~ ,, , ~ ,~ .......... , ~,,, , , ,~, , __LL --, .... :, ---' ..... ~--, ........ .............. :_~ .... ~,,_.-,.-~-~ , ~.._...,_._: ..... . . .-.-~:,,,, ~,~ ......... COMPLETION ,r',,-,-r- u,t..ll, I r_ /-'~'- WELL NAME ~. O ~U. I~UI~I AOGCC GEOLOGICAL MATERIALS INVENTORY LIST [ check off or list data as it is received ] _cored intervals' core ,altaJ~isI dl~ ditch !,n, tervals di~lital, data i , I I i I j l ~0 ff I I I I i i , i LOG TYPE RUN INTERVALS SCALE NO. ,,, .,. 11] ~] I I i l I~] .... " i i ii 19) i i iiii i i "I ARCO Alaska, Inc. Date' May 17, 1990 t EEEIVED lEA y £ I 1990 ' . Transmittal #: 7760 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File 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. 2K-24 2K-26 2K -23 2K-25 2K-13 KRU State #1 Receipt Pulse Echo Evaluaton PET Pulse Echo Evaluaton PET Pulse Echo Evaluaton PET Pulse Echo Evaluaton PET Pulse Echo Evaluaton PET - Pulse Echo Evaluaton PET Acknowledged- 2-13-90 7800-9696 2-19-90 .,~-10220 2 12 90 ~,¢~. 2-14-90 8146-10130 2-1 I -90 6400-9464 2-27-90 559~-7140 o DISTRIBUTION: Drilling NSK State of Alaska(+Sepia) - . · ¢ STATE OF ALASKA /%~SKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend _ Alter casing _ Repair well Change approved program _ 5. Type of Well: Development Exploratory Stratigraphic Service 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 Operation Shutdown ~ Re-enter suspended well _ _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Variance _ Perforate _ Other 6. Datum elevation (DF or KB) RKB 154' feet 7. Unit or Property name Kuparuk River Unit 8. Well number 2K-85 9. Permit number 90-12 10. APl number 50-103-20124 11. Field/Pool Kupurak River Field/ Kuparuk River Oil Pool 4. Location of well at surface 369' FNL, 95' FEL, Sec. 11 T10N, RSE, UM At top of productive interval 784' FNL, 1211' FEL, Sec. 13, T10N, RSE, UM (approx) At effective depth 1058' FNL, 1058' FEL, Sec. 13, T10N, RSE, UM (approx) At total depth 1131' FNL, 997' FEL, Sec. 13,T10N, RDE, UM (approx) 10264' feet Plugs (measured) 6545' feet None i12. Present well condition summary Total Depth: measured (approx) true vertical 10142' feet Junk (measured) 64 68' feet None None Measured depth True vertical depth 115' 115' 4082' 2921' (approx) 10223' 6519' (approx) RE¢I IVED Effective depth: measured (approx) true vertical MAR - 1_ 1990 Alaska 0il & Gas Con Ano or Size Cemented 16" 9 5/8" 1300 Sx AS III & 450 Sx Class G 7" 300 Sx Class G Casing Length Structural 8 0' Conductor Surface 4046' Intermediate Production 1 01 8 7' Liner Perforation depth: measured true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None 13. Attachments Description summary of proposal _ Detailed operation program ~( BOP sketch _ 15. Status of well classification as: Oil X Gas __ Suspended Service 14. Estimated date for commencing operation March, 1990 16. If proposal was verbally approved Name of approver JApproval No. Date approved 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~tned (/~¢4,~-~-~ '~' ~'~~ Title Area Drillin~ En~]ineer / FOR COMMISSION USE ONLY Commissioner Date ~ '- ,,~ --~'~ SUBMIT IN TRIPLICATE Conditions of approval: Notify Commission so representative may witness Plug integrity_ BOP Test_ Location clearance__ Mechanical Integrity Test _ Subsequent form require 10- '~ ~tJ~IgfNAL SIGNED BY LONNIE C. ~MITH Approved by the order of the Commission Form 10-403 Rev 06/15/88 ARCO C,,, and Gas Company Well History- Initial Report - Daily Inltmcflonl: Prepare and submit the "Initial Rel~' on the first Wednesday after a well Is spudded or workover operations are started. Dally work prior tO ~Puddln~.;~hould be summarized on the form giving inclusive dates only. District JCounty, parish or borough I ARCO ALASKA INC. I NORTH SLOPE Field I Le~.~ or Unit KUPARUK RIVER FIELD ITma ADL: 25605 Auth. or W.O. no. I ' AK4567 ~ DRILLING ALK: 2679 KRU 2K-25 IWell no. Operator AECO Spudded or W.O. begun IDate Hour SPUD I 01/18/90 18: 00 Date and depth as of 8:00 a.m. 01/19/90 (1) TD: 1391'( 1391 SUPV:TM 01/20/90 ( 2) TD: 4100' ( 2709 SUPV:TM 01/21/90 (3) TD: 4100'( 0 SUPV:TM 01/22/90 (4) TD: 6898'( 2798 SUPV:TM 01/23/90 (5) TD: 9396'( 249~ SUPV:TM 01/24/90 (6) TD: 9650' ( 254 Complete record for each day reposed DOYON 14 ARCO W.I. 55.8533 Pr or status if a W.O. DRILLING MW: 8.8 VIS: 76 FINISH MOVING RIG, NU DIVERTER, PU BHA, CUT DRLG LINE, SPUD WELL AT 1800HRS ON 1/18/90, DRLG 12.25" HOLE. DAILY:S72,339 CUM:$72,339 ETD:S72,339 EFC:$1,536M POOH FOR CSG 9-5/8"@ 4082' MW: 9.5 VIS: 58 DRLG SURFACE HOLE TO 4100', CIRCULATE, SHORT TRIP, CIRCULATE, POOH FOR CSG. DAILY:S65,995 CUM:$138,334 ETD:S138,334 EFC:$1,536M FINISHING BOPE TEST 9-5/8"@ 4082' MW: 0.0 VIS: 0 FINISH POOH, RU AND RUN 9.625" CASING, CMT W/ 1300 SX ASIII & 450 SX CLASS GSAME,NU BOPE, TEST SAME. DAILY:S205,319 CUM:$343,653 ETD:S343,653 EFC:$1,536M DRLG 9-5/8"@ 4082' MW: 9.4 VIS: 38 PU BHA, TIH AND TEST CSG, DRILL OUT SHOE TEST FORMATION, DRILL F/4110 T/6898. DAILY:S73,700 CUM:$417,353 ETD:S362,653 EFC:$1,536M SHORT TRIP 9-5/8"@ 4082' MW: 9.4 VIS: 37 DRLG F/6898 T/9396, CIRC. AND COND.,SHORT TRIP. _ ~ . ~ ~D~:~.¥:$55,'/35 CUM:$474,088 ETD:S474,088 EFC:$1,536M ' '~C; ' 9-5/8"8 4082' ~: 9.5 VIS: 37 P~H:FOR LE~ OFF, P~ED IN AT 10.3PPG, POOH TO LD TURBINE SUPV:TM 01/25/90 (7) TD:10264' ( 614 SUPV:CD M 01/26/90 (8) TD:10264' ( 0 SUPV:CD AND'MWD,RIH WITH LCM IN MUD, DRLG F/9396 T/9650, POOH TO TEST FORMATION, PUMPED IN AS BEFORE, RIH, ADDING LCM, CIRC. DAILY:S59,803 CUM:$533,891 ETD:S552,891 EFC:$-19,000 POOH FOR MAD PASS 9-5/8"@ 4082' MW: 9.9 VIS: 36 CIRC AND ADD LCM, TEST FORMATION TO 10.5PPG, OK, WEIGHT UP TO 9.9PPG, DRLG F/ 9650 T/ 10264, CIRC, SHORT TRIP, CIRC, POOH LD 25 JTS FOR REPEAT PASS W/RLL. DAILY:S83,106 CUM:$616,997 ETD:S616,997 EFC:$1,536 RUNNING 7" CASING 7"@10223' MW: 9.9 VIS: 38 REAM F/ 9442 T/ 10264, CIRC., POOH, LDDP,RUN 7" CASING. DAILY:S93,457 CUM:$710,454 ETD:S710,454 EFC:$1,536M MAR -1 1990 0il -' A~Oh For form prepar~n ~d dlstributi~ see Procedure~nu~ Section 10, Drilling. Pages~and 87. AR3B-459-1-D Number all daily well hlstor~ forms consecutively as they are prepared for each well. iPage no. ARC(.. 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, rel~ort completion and represelltative test data in blocks provided. The "Final Report" torm may be used for reporting the entire operation if space is available. District County or Parish ARCO ALASKA TNC, NORTH SLO?P. Field Lease or Unit KUPARUK RIVER FIELD ADL: 25605 ALK: 2679 KRU 2K-25 Auth. or W.O. no. Title AK4567 DRILLING Operator ARCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. Accounting cost center code State AK IWell no. 01/27/90 ( TD:10264 PB:10142 SUPV:CD A.R.Co. W.I. I 55.8533 IDate I 01/18/90 Complete record for each day reposed DO¥ON 14 Iotal 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. 18:00 RIG RELEASED 7" @ 10223' MW: 9.9 NaCl FINISH RUNNING CASING, CIRC. CSG, CMT W/300SKS G, DISP W/ 10.0PPG BRINE, SET SLIPS,CUT CSG, INSTALL PACKOFF, NU FMC TBG SPOOL, TEST TO 3000PSI, RELEASE RIG 2100HRS-1/26/90. DAILY:S119,651 CUM:$830,105 ETD:S849,105 EFC:$-19,000 MAR-1 1990 Alaska Oil & Gas Cons. ¢ommi~tO-[~ Anctlorag~ New TD Date Old TD P8 Depth Released rig Kind of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Offic a reservoir name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest 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,~,Q{rect Signature~ ~ ,Date// For form preparatio~nd ;istribution, ~ / see Procedures M~n~l. Section 10. Drilling. Pages 8~d 87. AR3B-459-3-C Number all daily well history forms consecutively es they are prepared for each well. iPage no. Olvl-lon of AtlsntlcRIchfleldCompany ARCO Alaska, Inc. Date: February 8, 1989 Transmittal #: 7662 RETURN TO: ARCO Alaska, Inc. Attn: Jenny Gamage Kuparuk Operations File Clerk ATO-1119 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith are the following items. Please acknowledge receipt and return one signed cop~ of this transmittal. - 't o ¢- 0- 0-1° 2 K - 2 5 LIS Tape and Listing I - 3 1 - 9 0 # 9 0 - 0 1 - 002AK 2 K - 1 4 LIS Tape and Listing I 0 - 1 7 - 8 9 8 9 - 1 0 - 0 2 2 Receipt Acknowledged: DISTRIBUTION: Lynn Goettinger State of Alaska ARCO Alaska, Inc. Date: February 8, 1990 Transmittal #: 7663 RETURN TO: ARCO Alaska, Inc. ATTN: Jenny Gamage Kuparuk Operations File Clerk ATO-1 11 9 P.O. Box 100360 Anchorage, AK 99510-0360 Transmitted herewith is the following items. Please acknowledge receipt and return one signed copy of this transmittal. ~2K-25 Electmmagnetic Resistivity/Dual Gamma Ray 1-2 5-9 0 4082-10264 2K-25 Dual Gamma Ray/Compensated Neutron Porosit~ 1-2 5-9 0 4082-1O264 Receipt Acknowledged: Date: DISTRIBUTION: D & M Franzen NSK State of Alaska(+sepia) Drilling 3anuary 12, 1990 'e~ecopy~ (907)276-7542 P. J. Arc'ney Regional Drilli~g Engi~eer AkCO Alaska, l~c. P. O. Box 100360 f~chorage, Alaska 99510-0360 Re: ~upaz'um River U~liu 2K-25 ARCO Alaska, Inc. Permit No. 90-12 Sur. Loc. 369'FNL, 95:FEi, Sec. i!, TiON, RSE, UM. Btmt~oie Loc ii04'FNL, 970'FEL, Sec 13, TION RSE, Dear bit. Archey: Enclosed is the approved application for permit to drill the above refere~ced well. The permit to drill does not exempt you from obtaining additional permits required by law from other goverrm~ental agencies, and does not authorize conductins drilling operations until all other required permitting determinations are~de. To aid us in scheduling field work, please notify this ozrzce 04 hours prior to co~nencing installation of the blowout prevention equipment ~o 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 co~encing equipment installation so that the Coma~ission may witness testing before drilling below the shoe of the conductor pipe. Veery. nru~y ;yours, / ..i...-.:/' / / .-? : b~ ', . ~ . .'1 /.,...: · ~ ~, ". ' ' ~' = ...._~/ / .... .~ / .':. .zc~ . / C. V. Chatter~o'ti Chairma~t of Alaska Oil and Gas Conaerva[ion Comission BY ORDER OF THE COI~,IISSION dlf E~'~c io sure cc: Depar~me~ oi Fish & Game, Habitat Section w/o encl. Department of E~vironmentai Conservation w/o encl. STATE OF ALASKA ALA,~K,~ OIL AND GAS CONSERVATION COMMIt'ION PERMIT TO DRILL 2O AAC 25.005 i la. Type of Work Drill X Redrill Re-Entry _ Deepen --I Service _ Development Gas __ Single Zone ~ Multiple Zone _ ~. Name ol Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska,, lng, RKB 154, Pad 118' GL feet Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchora~]e, AK 99510-0360 ADL 25605 ALK 2679 ~. Location ol well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 369' FNL, 95' FEL, Sec. 11 , T10N, R8E, UM Kuparuk River Unit Statewide At top of productive interval (TARGET) 8. Well number Number 900' FNL, 1120' FEL, Sec. 13, T10N, R8E, UM 2K-25 #U630610 At total depth 9. Approximate spud date Amount 1104' FNL, 970' FEL, Sec 13, T10N, RSE, UM 01-12-90 $200,000 1'2. Distance to nearest 13. Distance t° nearest well 14. Number of acres in properly 15. Proposed depth (MD and TVD) properly line 2K-24 10224 MD 970' ~ TD feet 25' at SURFACE feet 2560 6486TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 300 feet Maximum hole angle 55° Maximum sudace 1744 psig At total depth (TVD) 6486 3380 psig 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement , Hole Casing Weic, lht Grade Coupling Length IVD 'I'VD IVD TVD (include stage data) 24 16" 62.5# H-40 Weld 80' 35' 35' 115' 115' _+200 CF 12.25 9.625 36.0# J-55 BTC 4028 35' 35' 4028 2947' 1300 Sx AS Ill & HF-ERW 450 Sx Class G 8.5 7" 26.0# J-55 BTC 10224 35' 35' 10224i 6486' 300 Sx ClassG & HF-ERW Top 500' above Kuparuk 1'9. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured true vertical feet Casing Length Size Cemented Measured depth Tru~ Vetlical depth Structural Conductor Surface Intermediate ! -~ ~' ' "-~ Production , ' · · Liner Perforation depth: measured true vertical 20. Attachments Filing fee ~ Property plat Drilling fluid program ~ Time vs depth plot 21. I hereby certify that the foregoing is true and correct to the best of my knowledge ' / "~ '~ ~ Area Drilling Engineer Date Sic~ned i Title Commission Use Only Permit Number I AP, number I Approva' ~)~e/-i ?_./9 0 I See cover 'etter for ~'(~ ,.,,/~,-,~_ 50-/O .~ - .~-~/2, ~ other requirements Condiiions ~f approval Samples required __Y e s '.~ N o Mud log required __ Ye s .~ N o Hydrogen sulfide measures__ Yes ~' N o~,Directi°nal survey required ~Yes __ N o Required working pressur or BOPE __2 · 43M~ 5M' __ 10M' __ 1 5M Other: ~ ~.~ ~~/.~ by order of Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 // i~ riplicate qORIZONTAL PROJECTIO · _~ SCALE ! IN. - 1000 FEET ARCO ALASKA. lne. Pad 2K. Well No, 25 Propoeed Kupmruk Field. North Slope. Almmke 1000 1000 , ~ 1000 _ 2000 z (:3 , 3000 4000 5000 6000 70O0 WEST-EAST 1 000 2000 I I S~AC~E LOCATION, 3~g' FNL. 95' FEL SEC. 11. TI09I. ~ 3000 400O 5OOO I I I S 36 DEG 13 PIlN E 7202' (TO TARGET) TAROT TVD-6310 THD-GGI G S'OUTH ~l ! T~T LOCATION ' g(X)' FilL. I1~0' FEI.. gEC. 13. TION. ~ TD LOCAT [ ~. 1104' FILL. g?O' FEL SEC. 13. TION. RSE ARco ALASKA, Ine. Pad 2K, Idell No~ 2,5 Pr'opoaed Kupar'uk F'leld, Nor, th Slope, Aleeka 1 000 _ 2000_ ~000_ 4000_ 5000_ 6000_ ?000 . RKB ELEVATION ~ KOP TVDm300 THD-300 DEP-O 3 9 BUILD 3 DEG I $ PER 1 Go FT 21 27 33 B/ PERHAFROST TVD'1424 THD-I$02 DEP-366 39 T/ UGNU SNDS TVD-,1544 THD-1655 DEP=461 51 EOC TVD-1868 THD"2139 DEP-81g T/ N SAK SNDS TVD-2164 THD-2658 DEP-1245 B/ N SAK SNDS TVD-2747 THD-3678 DEP-2083 9 5/8' CSO PT TVD-2947 THD=4028 DEP=2370 K-lO TVD-3224 THD-4513 DEP-2768 K-5 TVD-4654 THD-?OI? DEP-4823 AVERAGE ANGLE 55 DEG 10 MI N T~ ZONE C TVD-6214 THD-9748 DEP-?064 T/ ZONE A TVD-6247 THD=9806 DEP-?112 TARGET CNTR TVD=6310 THD-9916 DEP-7202 B/ KUP SNDS TVD-6372 THD-lO024 DEP-Z291 TD (LOG PT) TVD-6486 THD-10224 DEP=7456 ! 1 1 000 2000 [ I I I 3000 4000 5000 6000 VERTICAL SECTION ?~ ? ? ;~.-~ ~ ~, / iF 7000 1 8000 lO0 5O 5O 100 150 20O 25O 300 150 100 50 0 50 100 150 I I I L I I I 2000 150 / / / 1 / / / / / / 400 1 200 / / / / · 1200 1600 1 400 '-4'00 ,J'800 800 600 ~00 'k,6oo \ \ \ 1000~, 800 \ \ 1200 1400 ~0 200 '\1 000 100 5O 5O 100 150 200 100 5O 100 I 150 .250 3O0 DRILLING FLUID PROGRAM (2K-25) Spud to 9-5/8" Drill out to Weight up surface (;asing .weight up to TD Density 8.8-9.0 8.6-9.4 10.0 PV 15-30 8-10 10-14 YP 20-40 5-8 7-1 0 Viscosity 70-80* 35-40 35-50 Initial Gel 5-15 2-4 4-6 10 Minute Gel 15-30 4-8 5-12 APl Filtrate 10-15 7-9 4-5 pH 9- 1 0 8.5-9 8.5-9.5 % Solids 10 +/- 4-7 <12 Drilling Fluid System: - Triple Tandem Shale Shaker - (2) Mud Cleaners - Centrifuge - Degasser - Pit Level Indicator (Visual and Audio Alarm) - Trip Tank - Fluid Flow Sensor - Fluid Agitators Notes: - Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. - Maximum anticipated surface pressure is calculated using a surface casing leak-off of 13.5 ppg EMW and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur before a surface pressure of 3000 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3000 psi. - The nearest well to 2K-25 is 2K-24. As designed, the minimum distance between the two wells would be 25' at surface. The wells would diverge from that point. - Excess non-hazardous fluids developed from well operations and those fluids necessary to control the fluid level in reserve pits will be pumped down the surface/production casing annulus. The annulus will be left with a non-freezing fluid during any extended shut down in pumping operations. The annulus will be sealed with 175 sx of cement followed by arctic pack upon completion of fluid pumping. * Spud mud should be adjusted to a funnel viscosity between 100-120 to drill gravel beds. 7 , 6 5 4 I I 13 5/8" 5000 P 'BOP STACK ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAUUC FLUID. 2. ASSURE THAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER EMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL 2. CHECK THAT ALL HOI.D-t:X)~ SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WlLL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. INCREASE PRESSURE TO 3000 PSI AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTORAND MANUAL KILLAND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS AND HCR VALVES ON KlM. AND CHOKE UNES. 6. TEST TO 250 PSI AND 3000 PSI AS IN STEP 4. 7. CC~TINUE TESTING AL VALVES, UNE$, AND CHOKES WITH A 250 PSI LOW AND 3000 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOTA FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMSAND CLOSE BOTTOM PIPE RAMS. TEST Bo3'rOM RAMS TO 250 PSI AND 3000 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. CLOSE BLIND RAMS AND TEST TO ~ PSI FOR 10 MINUTES. BLEED TO ZERO PSI. 10 OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND ENES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILUNG POSITION. 11. TEST STANDPIPE VALVES TO 3000 PSI. 12. TEST KELLY COCKS AND INSIDE BOP TO 3(X)0 PSI WITH KOOMEY PUMP. 13. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 14. PERFORM COMPLETE BOPE TEST ONCE A WEEKAND FUNCTIONALLY OPERATE BOPE DAILY. 1. 16' - 2(X)0 PSI STARTING HEAD 2. 11' - 3000 PSI CASING HEAD 3. 11 ' - 3000 PSI X 13-5/~' - 5000 PSI SPACER SPOOL 4. 13-5/8' - 5000 PSI PIPE RAMS 5. 13-5/8" - 5000 PSI DRLG SPOOL W/ CHOKE AND KILL LINES 6. 13-5/8" - 5000 PSI DOUBLE RAM W/ PIPE RAMS ON TOP, BLIND RAMS ON BTM 7. 13-5/8' - 5000 PSI ANNULAR SRE 8/22/89 DOYON 14 KUPARUK RIVER UNIT 20 DIVERTER SCHEMATIC j DESCRIPTION 1. 16" CONDUCTOR 2. FMC SLIP~3N WELD STARTING HEAD 3. FMC'DIVERTER ASSEMBLY WFFH TWO 2-1/16' 2000 PSI BALL VALVES 4. 20' 2000 PSI DRILLING SPOOL WI10" OUTLETS 5. 10' HCR BALL VALVES WI10' DIVERTER LINES, A SINGLE VALVE OPENS AUTOMATICALLY UPON CLOSURE OF ANNULAR PREVENTEi~ VALVES CAN BE REMO~_LY ~ TO ACHIEVE DOWNWIND DIVERSION. 6. 20' 2000 PSI ANNULAR PREVENTER ARCO ALASKA, INC., REQUESTS APPROVAL OF THIS DIVERTER SYSTEM AS A VARIANCE FROM 20AAC25.035(b) MAINTENANCE & OPERATION 1. UPON INITIAL INSTALLATION, CLOSE PREVENTER AND VERIFY THAT VALVE OPENS PROPERLY. . CLOSE ANNULAR PREVENTER AND BLOW AIR THROUGH DIVERTER LINES EVERY 12 HOURS. CLOSE ANNULAR PREVEN3~R IN THE EVENTTHAT AN INFLUX OF WELLBORE FLUIDS OR GAS IS DETECTED. OPEN APPROPRIATE VALVE TO ACHIEVE DOWNWIND DIVERSION. DO NOT SHUT IN WELL UNDER ANY CIRCUMSTANCES JG 4/26/88 GENERAL DRILLING PROCEDURE KUPARUK RIVER FIELD DEVELOPMENT WELLS 1_) MIRU. 2) Install FMC diverter system. 3) Drill 12-1/4" hole to g-5/8" surface casing point according to directional plan. 4) Run and cement 9-5/8" casing. 5) Install and test BOPE. Test casing to 2000 psig. 6) Drill out cement and 10' new hole. Perform leak off test. 7) 'Drill 8-1/2" hole to logging point according to directional plan. 8) Run open hole logs. 9) Continue drilling 8-1/2" hole to provide 100' between PBTD and bottom of Kuparuk sands. 10) Run and cement 7" casing. Pressure test to 3500 psig. 11) Downsqueeze Arctic pack' and cement in 7" x 9-5/8" annulus. 12) ND BOPE and install temporary Xmas tree. 13) Secure well and release rig. 14) Run cased hole logs. 15) Move in Workover rig. NU BOPE. 16) PU 7" casing scraper and tubing, TIH to PBTD. Circulate hole with clean brine and TOH standing tubing back. 17) Perforate and run completion assembly, set and test packer. 18) ND BOPE and install Xmas tree. 191 Change over to diesel. 20) Flow well to tanks. Shut in. 21} Secure well and release rig. 22} Fracture stimulate. MUD CLEANER SHALE SHAKERS TYPICAL MUD SYSTEM SCHEMATIC CHECK LIST FOR NEW WELL PERMITS ITEM APPROVE DATE (1) Fee .~./~, ~//,~./?~ 1. .oc (2' thru ~ (3) Admin hY //q/?~ 9. -~'(9-~hru i3')' ' 10. (10 and 13) 12. 13. (4) Casg ~~.~./-/~'~ (14 thru 22) (5) BOPE (23 thru 28) Lease & Well No. /~Z~ ~<7~D~' ~~, YES NO R~MARKS Is the permit fee attached .......................................... 2. Is well to be located in a defined pool ............................. 3. Is well located proper distance from property line .................. 4. Is we-~i..located proper distance from other wells .................... 5. Is suzficient undedicated acreage available in this pool ............ 6. Is well to be deviated and is wellbore plat included ................ 7. Is operator the only affected party ................................. 8. Can permit be approved before fifteen-day wait ...................... Does operator have a bond in force .................................. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is the lease number appropriate ..................................... Does the well have a unique name and number ......................... 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Is conductor string provided ........................................ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water ...................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... 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 ....................................... Is the drilling fluid program schematic and list of equipment adequate.,~ Are necessary diagrams and descriptions of diverter and BOPE attached. D~es BOPE have sufficient pressure rating - Test to .~p~>~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of H2S gas probable ................................. (6) OTHER <:5~ th~u ~3f) (6) Add: Geology: EngiBeering: DWJ ~'LCS rev: 01/30/89 6.011 For 29. 30. 31. 32. exploratory and Stratigraphic wells: Are data presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of Seabed conditions presented Additional requirements ............................................. INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE 0 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. **** LIS READ **** (NOTE: MAXIMUM RECORD LENGTH - 8192 BYTES) ** REEL HEADER ** REEL SEQUENCE # 1 SERVICE NAME: SPERRY DATE: 90/01/31 ORIGIN OF DATA: RLL REEL NAME: ARCO CONTINUATION #: 01 PREVIOUS REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** TAPE HEADER ** SERVICE NAME: RLL DATE: 90/01/31 ORIGIN OF DATA: 2K25 TAPE NAME: KUPARUK CONTINUATION #: 01 PREVIOUS TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ********** END OF FILE (EOF # 1) ********** ** FILE HEADER ** FILE SEQUENCE # 1 FILE NAME: 2K-25.MWD SERVICE NAME: RLL VERSION #: V 2.40 DATE: 90/01/31 MAX. RECORD LENGTH: 1024 FILE TYPE: EO PREVIOUS FILE NAME: ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API ID ORDER# DEPT ROP MWD EWR MWD FXE MWD NFO MWD NFl MWD NN0 MWD NN1 MWD GRC MWD CAL MWD DRHO MWD NPSC MWD RHOB MWD LOG TYP CLS MOD FT 0 0 0 0 FT/H 0 0 0 0 OHMM 0 0 0 0 HOUR 0 0 0 0 CTS 0 0 0 0 CTS 0 0 0 0 CTS 0 0 0 0 CTS 0 0 0 0 API 0 0 0 0 INCH 0 0 0 0 G/C3 0 0 0 0 P.U. 0 0 0 0 G/C3 0 0 0 0 FILE SZE PROC SPL REPR NO. LVL CODE 1 4 0 1 68 1 4 0 1 68 1 4 0 1 68 1 4 0 1 68 1 4 0 1 68 1 4 0 1 68 1 4 0 1 68 1 4 0 1 68 1 4 0 1 68 i 4 0 1 68 1 4 0 1 68 1 4 0 1 68 1 4 0 1 68 ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API ID ORDER# DEPT ROP MWD EWR MWD FXE MWD NF0 MWD NFl MWD NN0 MWD NN1 MWD GRC MWD CAL MWD DRHO MWD NPSC MWD RHOB MWD LOG TYP CLS MOD FT 0 0 0 0 FT/H 0 0 0 0 OHMM 0 0 0 0 HOUR 0 0 0 0 CTS 0 0 0 0 CTS 0 0 0 0 CTS 0 0 0 0 CTS 0 0 0 0 API 0 0 0 0 INCH 0 0 0 0 G/C3 0 0 0 0 P.U. 0 0 0 0 G/C3 0 0 0 0 FILE SZE PROC SPL REPR NO. LVL CODE 1 4 0 1 68 1 4 0 1 68 1 4 0 1 68 1 4 0 1 68 1 4 0 1 68 1 4 0 1 68 1 4 0 1 68 1 4 0 1 68 1 4 0 1 68 1 4 0 1 68 1 4 0 1 68 1 4 0 1 68 1 4 0 1 68 ** DATA VERIFICATION (every 500 FT) ** DEPT ROP EWR FXE NF0 NFl NN1 GRC CAL DRHO NPSC RHOB 3900.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 4000.000 2408.000 -999.250 266.732 -999.250 48.570 8.570 -.043 4500.000 2744.000 586.629 5.541 .309 100.661 8.600 .007 5000.000 2734.055 257.306 4.166 .453 91.022 8.440 .007 5500.000 2810.786 313.941 3.501 .499 86.657 8.900 .007 6000.000 355.717 4.202 .412 3091.446 81.402 8.430 -.026 6500.000 364.746 3.497 .398 2896.272 126.043 8.510 .007 7000.000 3032.000 244.556 3.863 .383 95.403 8.630 .006 7500.000 2632.000 247.500 2.970 .573 152.303 8.590 .000 8O00.0O0 2872.000 218.382 4.381 .688 89.274 8.400 .011 8500.000 2940.771 236.206 2.738 .767 115.207 8.430 .019 9000.000 206.445 4.617 .508 2756.192 123.417 8.860 .009 9500.000 65.227 4.220 .787 2628.121 142.711 8.720 -.008 10000.000 2692.010 56.088 4.821 1.128 98.179 8.400 -.009 ** 677 DATA RECORDS ** FROM ** FILE TRAILER** FILE NAME: 2K-25.MWD SERVICE NAME: RLL VERSION #: V 2.40 DATE: 90/01/31 MAX. RECORD LENGTH: FILE TYPE: EO NEXT FILE NAME: 1024 -999.250 -999.250 424.000 54.606 639.000 36.263 641.593 37.172 672.506 31.470 675.748 30.270 719.976 31.152 759.000 27.546 727.000 37.130 751.000 31.481 738.180 30.778 698.240 31.499 748.499 35.615 685.739 37.135 3900.00 TO -999.250 -999.250 449.000 2.553 655.000 2.041 651.324 2.029 696.506 2.325 706.512 2.472 767. 614 2.267 847.000 2.426 727.000 2.358 767.000 2.107 781.783 2.393 699.192 2.550 772.630 2.535 717. 431 2.480 10325.00 FT NN0 -999.250 2312.000 2680.000 2701.186 2793.393 3037.983 2887.608 2952.000 2520.000 2920.000 2912.795 2836.192 2539.515 2635.416 ********** END OF FILE (EOF # 2) ********** ** FILE HEADER ** FILE SEQUENCE # 2 FILE NAME: 2K-25.RPT SERVICE NAME: RLL VERSION #: V 2.40 DATE: 90/01/31 MAX. RECORD LENGTH: 1024 FILE TYPE: 2K PREVIOUS FILE NAME: ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID DEPT RATE REPEAT EWR REPEAT FXE REPEAT NF0 REPEAT NFl REPEAT NN0 REPEAT NN1 REPEAT GRC REPEAT CAL REPEAT DRHO REPEAT NPSC REPEAT RHOB REPEAT ORDER# LOG TYP CLS MOD NO. LVL CODE FT 0 0 0 0 2 4 0 1 68 FT/H 0 0 0 0 2 4 0 1 68 OHMM 0 0 0 0 2 4 0 1 68 HOUR 0 0 0 0 2 4 0 1 68 CTS 0 0 0 0 2 4 0 1 68 CTS 0 0 0 0 2 4 0 1 68 CTS 0 0 0 0 2 4 0 1 68 CTS 0 0 0 0 2 4 0 1 68 API 0 0 0 0 2 4 0 1 68 INCH 0 0 0 vn 2 4 0 1 68 G/C3 0 0 0 0 2 4 0 1 68 P.U. 0 0 0 0 2 4 0 1 68 G/C3 0 0 0 0 2 4 0 1 68 ** DATA FORMAT SPECIFICATION ** ENTRY BLOCKS TYPE SIZE REP CODE ENTRY 4 1 66 255 0 1 66 DESCRIPTION LOG DIRECTION, DOWN TERMINATOR (NO MORE ENTRIES) DATUM SPECIFICATION BLOCKS NAME SERVICE SERVICE UNIT API API API API FILE SZE PROC SPL REPR ID DEPT RATE REPEAT EWR REPEAT FXE REPEAT NF0 REPEAT NFl REPEAT NN0 REPEAT NN1 REPEAT GRC REPEAT CAL REPEAT DRHO REPEAT NPSC REPEAT RHOB REPEAT ORDER# LOG TYP CLS MOD NO. LVL CODE FT 0 0 0 0 2 4 0 1 68 FT/H 0 0 0 0 2 4 0 1 68 OHMM 0 0 0 0 2 4 0 1 68 HOUR 0 0 0 0 2 4 0 1 68 CTS 0 0 0 0 2 4 0 1 68 CTS 0 0 0 0 2 4 0 1 68 CTS 0 0 0 0 2 4 0 1 68 CTS 0 0 0 0 2 4 0 1 68 API 0 0 0 0 2 4 0 1 68 INCH 0 0 0 0 2 4 0 1 68 G/C3 0- 0 0 0 2 4 0 1 68 P.U. 0 0 0 0 2 4 0 1 68 G/C3 0 0 0 0 2 4 0 1 68 ** DATA VERIFICATION (every 500 FT) DEPT RATE EWR FXE NN1 GRC CAL DRHO NFO NFl NPSC RHOB 9377.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 9.660 -.048 -856.457 3.051 9500.000 94.871 4.585 35.358 591.000 663.000 2248.000 134.621 9.320 .004 35.500 2.513 10000.000 177.573 5.148 15.788 607.000 631.000 2520.000 96.184 8.500 .009 36.204 2.472 ** 94 DATA RECORDS ** FROM 9377.00 TO 10264.00 FT ** FILE TRAILER** FILE NAME: 2K-25.RPT SERVICE NAME: RLL VERSION #: V 2.40 DATE: 90/01/31 MAX. RECORD LENGTH: FILE TYPE: 2K NEXT FILE NAME: 1024 ********** END OF FILE (EOF # 3) ********** NN0 -999.250 2280.000 2504.000 ** TAPE TRAILER** SERVICE NAME: RLL DATE: 90/01/31 ORIGIN OF DATA: 2K25 TAPE NAME: KUPARUK CONTINUATION #: 01 NEXT TAPE NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT ** REEL TRAILER ** SERVICE NAME: SPERRY DATE: 90/01/31 ORIGIN OF DATA: RLL REEL NAME: ARCO CONTINUATION #: 01 NEXT REEL NAME: COMMENTS: PETROLEUM COMPUTING INC.- LIS FORMAT