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212-052
CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From:Lau, Jack J (OGC) To:AOGCC Records (CED sponsored) Subject:FW: KRU 3N-07A (PTD 212-052) Report of IA Sustained Casing Pressure Date:Monday, March 24, 2025 4:44:26 PM Attachments:3N-07A 90 Day TIO Plot & Schematic.pdf From: Well Integrity Specialist CPF1 & CPF3 <n1617@conocophillips.com> Sent: Monday, March 24, 2025 4:33 PM To: Loepp, Victoria T (OGC) <victoria.loepp@alaska.gov>; Lau, Jack J (OGC) <jack.lau@alaska.gov> Cc: Livingston, Erica J <Erica.J.Livingston@conocophillips.com> Subject: KRU 3N-07A (PTD 212-052) Report of IA Sustained Casing Pressure Victoria, KRU 3N-07A (PTD 212-052) was reported by operations Saturday 3/22/25 to have an IA pressure of 2200 psi. The 7” 26 lb/ft, L-80 has a burst rating of 7240 psi (45% burst rating = 3258 psi). 3N-07A failed a TIFL 3/16/25 and was shut in 3/21/25 for slickline intervention. The IA was bled with well pressures currently at T/I/O = 1750/1652/90. Slickline started diagnostics yesterday and CPAI plans to have Slickline continue diagnostics tomorrow. These diagnostics will inform how the well should be repaired or secured. Attached is a 90 day TIO plot and wellbore schematic for reference. Please let me know if you disagree or have any questions with this plan. Thank you, Shelby Sumrall Well Integrity Specialist | ConocoPhillips Alaska O: (907) 265-6678 | M: (907) 301-9374 2000 r 1500 N a 0 0.04 0 0.02 Ul f ° 0.00 a m -0.02 s -0.04 Pressure Summary for 3N-07A N N M ❑❑❑ .� .� � N N N N❑❑ O H H H H N N N❑❑❑ H H H fVWV N N N .a .a .a .a .a .a a . .a .a N N N N N N N N N N r7 r7 n1 m m mrlrm 0 0= N N N N N N N N N N N N N N N N N N N N N N N N N N N N N CX= N N N N N N N N N N N N N N N N N N N N N N N N N N N N N NYW Date omi 70 u. 60 a 50 2 a 40 `y a E 30 20 10 — IA PRESSURE — OAPRESSURE — TUBING PRESSURE (PSI) — TEMPERATURE(DEGF) — DRY GAS (MSCFD) — MI GAS (MSCFD) — PRODUCED WATER(BPD) — SEAWATER (BPD) KUP PROD WELLNAME 3N-07A WELLBORE 3N-07A 1" conocoPhillips Alaska, ina Well Attributes Max Angle & MD TD Field Name KUPARUK RIVER NIT Wellbore API"' Wellbore 500292153901 PROD Status I cl (°) 6.29 MD (MIKE) 7,233.69 Act son (ftKB) 7,450.0 Comment HZS (ppm) Date Annotation Last WO: End Date 7/21/2012 KB-Grd (ft) 38.49 RR Date 3/7/1986 Other Elev... Annotation 1 Depth (ftKB) 1 Wellbore 1 End Date Last Mod By Last Tan:SUM I 7147.0 3N-07A 12/14/2014 hi shkf Last Rev Reason Annotation Wellbore 1 End Date Last Mod By Rev Reason: Pull IBP and Manna ran a Dun. I3N-0/A 3/5/2023 lapplaha Casing Strings Csg Des OD (in) ID (in) Top (ftKB) Set Depth (ftKB) Set Depth (TVD) (ftKB) MLen (Ibild Grade Top Thread CONDUCTOR 16 15.0E 35.01 115.0 115.0 62.50 H-00 WELDED SURFACE 9 5/8 8.92 37.0 3.691.4 3 610.2 36.00 J-55 I BT&C WINDOW 9-518" 95/8 8.00 2599.0 2616.0 2615.4 PRODUCTION 7 6.28 37.3 7040.E 6303.4 26.00 L-81 BTCM LINER 41/2 3.96 6821.9 7448.0 6588.4 12.60 L-80 IIBIM Window AL2 41/2 7209.0 7216.0 6425.5 Window AL1 41/2 7240.0 7246.0 6446.3 Tubing Strings: string max indicates LONGEST segment of string Top(ftKB) 22.8 Set Depth... 6,867.0 Set Depth...Stnng 6,182.2 Me... Tubing 31/2 Tubing Description Wt(Ib/tt) Gratle -Production 9.30 L-80 Top EUE Connection ID 2.99 (in) Completion Details: excludes tubing, pup, space out, thread, RKB... Top (ftKB) Top (TVD) (ftKB) Top Incl (°) hem Des OD Nominal (in) Cord Make Model Nominal ID (in) 22.8 22.8 0.00 Hanger 6.990 Tubing Hanger, FMC Gen 3 w/ 3.5 FMC Gen 3 2.960 522.9 522.9 0.57 Nipple -X 4.517 LPSNp0004717612- HES XNipple 2.813 2,603.1 2,602.6 6.41 Mandrel - GAS 3.500 . "x1-1/2",MMG, GLM, 3.5"x 1- SUB MMG 2.920 5,252.9 4,918.0 32.55 Mandrel - GAS 3.500 3.5"x1-1/2", MMG, GLM, 3.5"x 1- SUB MMG 2.920 6,749.7 6,098.9 44.60 Mandrel - GAS 3.500 3.5"x1-1/2", MMG, GLM, 3.5"x 1- SUB MMG 2.920 6,778.5 6,119.4 44.62 Packer 6.280 IiES MFT FeedThm 3-1/2" x 7" HES MFT 2.897 6,808.5 6,140.7 44.64 Nipple -X 4.511 2.813"X-Nipple HES XNipple 2.813 6,826.4 6,153.5 44.79 Locator 3.500 Baker 3-1/2'80-40 GBH-22 Locator Baker NO-GO 3.000 6,833.7 6,158.7 44.87 Seal Assembly 3.500 Baker seal assembly w/10'stroke w/ Baker Baker 2.992 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Ind (°) Des Com Make Model I SIN I Run Date ID (in) /,I/U.21 b,J9331 45.90 CTDLINER LINERALZ-02 9/14/2012 1.920 7,204.01 6,417.21 46.11 ITRffPSTOCK ITTWS for 3N-07AL2 exit thm4 9/1/2012 1.000 7,238.01 6,440.71 46.2E WHIPSTOCK JT ffll- 3N-07AL1 exit thm4 1 18/17/2012 Mandrel Inserts : excludes pulled inserts Top (ftKB) Top (TVD) (ftKB) Top Incl I') St ati on No Sere Valve Type Latch Type OD (in) TRO Run (psi) Run Date Com Make Model Port Sme (in) 2,603.1 2,602.E 6.41 1 GAS LIFT GLV RK 31/2 1,218.0 2/25/2023 Schlumb MMG 0.188 5,252.9 4,918.0 32.55 2 GAS LIFT GLV 3112 1,214.0 2/25/2023 umb MMG 0.188 6,749.7 6,098.9 44.60 3 GAS LIFT OV IRK 31/2 2/25/2023 umb 1 MMG 0.188 Liner Details: Excludes Liner, Pup, Joints, casing, float, sub, shoe... Top (ftKB) Top (TVD) WE) Top Incl V) Item Des OD Nominal (in) cum Make I Model Nominal ID (in) 6 821.9 6 150.3 44.74 1 PACKER 7.600 1 BAKER C-2 ZXP LINER TOP 5.000 7,326.11 6502.01 45.68 LANDING 1 4.500 COLLAR STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED By Kayla Junke at 12.54 pm, Mar 19 2023 1. Operations Susp Well Insp ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing Q Operations shutdown ❑ Performed: Install Whipstock ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Mod Artificial Lift ❑ Perforate New Pool ❑ Repair Well 0 Coiled Tubing Ops ❑ Other: Replace Tubing ❑✓ 2. Operator Name 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Q Slratigraphic ❑ Exploratory ❑ Service ❑ 1 212-062 3. Address: P.O. Box 100360 6. API Number: Anchorage, AK 99510 50-029-21539-01-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0026621 KRU 3N-07A 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): WA Ku aruk River Field/ Ku aruk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 7450' feet Plugs measured None feet true vertical 6589' feet Junk measured None feet Effective Depth measured 7450' feet Packer measured 6822' feet true vertical 6589' feet true vertical 6150' feet Casing Length Size MD TVD Burst Collapse Conductor 80, 161, 115' 115, Surface 3654' 9-5/8'. 3691, 3610' Intermediate Production 7004' 7" 7041' 6303' Liner 626' 4-1/2" 7448' 6588, Perforation depth Measured depth None True Vertical depth None Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 6867' MD 6182' TVD Packers and SSSV (type, measured and true vertical depth) Packer: HES MFT FeedThm Packer 6778' MD 6119' TVD Packer: Baker C-2 ZXP Liner Top Packer 6822' MD 6150' TVD SSSV: None WA N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13a. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operatiowl Well Remained Shut -In I - I - I - I - Subsequent to operatiowl 361 1 98 1 508 1 1212 1 174 13b. Pools active after work: Kuparuk River Oil Pool 14. Attachments (required per 2c AAC 25.070, 25.071, s 25.283) 15. Well Class after work: Daily Report of Well Operations ❑+ Exploratory ❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Gas L WDSPL Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Dighly aig,v by Emon To 1, DN'. C=US.OU-CTDIR Ddlln9 Eminw.. oe 323-NO mco P�Illbs. l"I" C N- EIIutl TUWn. E= Authorized Name Elliott TuttleCe—�lo"��°°n�mm and rn"Wa ,�,�vN, d—ee, Digital Signature with Date: D",n: »xxm.,E,o:oa.E,-oeoo Contact Name: Elliott Tuttle Contact Email: elliottluttle0conocoohillios.com Authorized Title: RWO/CTD Engineer Contact Phone: (907) 263-4742 Sr Pet Eng: ISr Pet Geo: I I Sr Res Eng: RBDMS JSB 032123 Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov Operations Summary (with Timelog Depths) 3N-07 9.6 RIG RELEASE DATE 2/16/2023 Co..31,1111 s Rig: NABORS 7ES Job: RECOMPLETION Time Log Start Time ErM Time Dur (m) Phase Activity Code Time P-T-X Operation Stan Depth (fi End Depth rtKB) 2/9/2023 2/9/2023 8.25 MIRU, MOVE MOB P Load shop. Pull pits away from sub. 00:00 08:15 Load office. Move and set office and shop. Move and stage pits on 3N. Pull sub off well. Clean up around well. Moving sub to T/ 3N. 2/9/2023 2/9/2023 7.00 MIRU, MOVE MOB P Hang tree, stage wellhead equipment in 08:15 15:15 cellar. Spot sub over 3N-07. Spot pits to sub. Spot auxiliary equipment. Cuttings tank, tiger tank, choke and tiger tank hard line. Hook up electrical and plumbing in interconnect. Turn on steam and air to pits. Berm in rig. Raise derrick. Bridal Up. Hand Bridle Lines. Berm in Rig and Cellar. 2/9/2023 2/9/2023 1.00 MIRU, MOVE MOB P R/U Circulating equipment in cellar. 15:15 16:15 2/9/2023 2/9/2023 0.75 MIRU, MOVE MOB P Complete rig up check list. Bring on 14.5 16:15 17:00 PPG LSND into pits. Complete acceptance checklist. Rig Accepted @ 17:00 Him 2/9/2023 2/9/2023 6.00 MIRU, WELCTL COND P Condition 14.5 PPG LSND T/ 14.0 PPG 17:00 23:00 LSND Valve crew service choke house, circ manifold & rig floor manifold 2/9/2023 2/9/2023 0.50 MIRU, WELCTL SFTY P PJSM w/ rig crew on well kill. 23:00 23:30 2/9/2023 2/10/2023 0.50 MIRU, WELCTL PRTS P Pump 10 Bbls 14.0 PPG LSND T/ 400 23:30 00:00 Bbls open top tank to warm up iron. PT tiger tank lines and choke house T/ 2500 PSI - Good test. 2/10/2023 2/10/2023 2.00 MIRU, WELCTL KLWL P Initial pressures TBG=400, IA=500. 00:00 02:00 Bleed tubing went straight to fluid TBG=200, IA=300. Bleed free gas off of IATBG=100, IA=200. Circ 353 Bbls 14.00 PPG LSND down tubing taking returns to tank @ 4 BPM. ICP=100, FCP=700 2/10/2023 2/10/2023 0.50 MIRU, WELCTL OWFF P OWFF-30 Min no flow. 02:00 02:30 B/D 2nd kill & tiger tank lines. 2/10/2023 2/10/2023 0.25 MIRU, WELCTL MPSP P Set ISA BPV. 02:30 02:45 2/10/2023 2/10/2023 0.25 MIRU, WELCTL PRTS P PT BPV T/ 1000 PSI from below for 10 02:45 03:00 Min - Good test. 2/10/2023 2/10/2023 0.50 MIRU, WHDBOP SFTY P Crew change out. PJSM w/ rig crew on 03:00 03:30 N/D tree & N/U BOP. 2/10/2023 2/10/2023 1.00 MIRU, WHDBOP NUND P N/D tree & adaptor spool. Inspect 03:30 04:30 hanger neck threads. M/U blanking plug. Function LDS. Blanking sub made up T/ hanger 10 turns. Blanking plug to test joint 8 1/4 turns. 2/10/2023 2/10/2023 2.50 MIRU, WHDBOP NUND P N/U DSA and BOP. 04:30 07:00 2/10/2023 2/10/2023 1.00 MIRU, WHDBOP RURD P Service choke manifold. RU testing 07:00 08:00 manifold. Test Alarms. 2/10/2023 2/10/2023 0.50 MIRU, WHDBOP SVRG P Service rig 08:00 08:30 2/10/2023 2/10/2023 2.50 MIRU, WHDBOP PRTS P Shell Test Stack. Losing pressure 08:30 11:00 through Blanking Plug to well bore. Function LDS again. Check torque on Test Joint. Drain Stack and Wash same. Re -Test. Suspect trash on ball seat. Good Shell Test. Page 116 Report Printed: 3/10/2023 Operations Summary (with Timelog Depths) 3N-07 9.6 RIG RELEASE DATE 2/16/2023 Co..31,1111 s Rig: NABORS 7ES Job: RECOMPLETION Time Log Stan Time ErM Time Dur (hr) Phase Activity Code Time P-T-X Operation Stan Depth rtKB) End Depth (ftKB) 2/10/2023 2/10/2023 5.00 MIRU, WHDBOP BOPE P BOPE test, Tested BOPE at 250/4500 11:00 16:00 PSI for 5 Min each, Test annular 250/2500 on 3-1/2" test joint. Tested, UVBR's and LVBR'd on 3-1/2" test joints. Test blinds rams. Choke valves #1 to #16, upper and lower top drive well control valves. Test 3 1/2" HT-38 FOSV and IBOP. Test 3 1/2" EUE FOSV. Test 2" rig floor Demco kill valves. Test manual and HCR kill valves & manual and HCR choke valves. Test two ea 2 1/6" gate auxiliary valves below LPR. Test hydraulic and manual choke valves to 1500 PSI and demonstrate bleed off. Perform accumulator test. Initial pressure=2980 PSI, after closure=1500 PSI, 200 PSI attained =15 sec, full recovery attained =125 sec. UVBR's= 5 sec, LVBR's= 5 sec. Annular= 27 sec. Simulated blinds= 5 sec. HCR choke & kill= 1 sec each. 5 back up nitrogen bottles average =1950 PSI. Witness waived by AOGCC rep Ead Adam. 2/10/2023 2/10/2023 0.50 MIRU, WHDBOP RURD P RD Testing Equipment. Drain BOP 16:00 16:30 Stack. Backout Test Joint and Blanking Plug. 2/10/2023 2/10/2023 0.50 MIRU, WHDBOP SVRG P Service rig. 16:30 17:00 2/10/2023 2/10/2023 0.25 MIRU, WHDBOP MPSP P Check PSI and Pull BPV. 17:00 17:15 2/10/2023 2/10/2023 0.25 COMPZN, RPCOMP RURD P M/U landing joint. Set down 1 OK block 17:15 17:30 weight. R/U tubing handling equipment. BOLDS 2/10/2023 2/10/2023 1.25 COMPZN, RPCOMP PULL T P/U hanger off seat @ 85K. P/U T/ 6,814.0 6,814.0 17:30 18:45 150K, re land hanger. P/U T/ 175K, re land hanger. P/U T/ 195K and work pipe at varying pulling string. Consult w/ town - decision made to pull to 95% of tensile on 3 1/2" L-80 & call out E-line to make a second cut on tubing string. Pull T/ 225K and work pipe at varying pulling speeds - No pipe movement. 2/10/2023 2/10/2023 1.00 COMPZN, RPCOMP CIRC P Circ STS @ 5 BPM, 940 PSI. 6,814.0 6,814.0 18:45 19:45 2/10/2023 2/10/2023 0.50 COMPZN, RPCOMP RURD P B/D TD. M/U 3 1/2" EUE FOSV. Land 6,814.0 6,814.0 19:45 20:15 sting in slips w/ 25K tension. 2/10/2023 2/10/2023 1.75 COMPZN, RPCOMP WAIT P Mobilize Yellowjacket E-line from 6,814.0 6,814.0 20:15 22:00 Deadhorse. 2/10/2023 2/11/2023 2.00 COMPZN, RPCOMP RURD P Spot and R/U YellowJacket E-Line 6,814.0 6,814.0 22:00 00:00 2/11/2023 2/11/2023 0.75 COMPZN, RPCOMP RURD T Cont rig up E-line w/ pump in sub and 6,814.0 6,814.0 00:00 00:45 packoff. 2/11/2023 2/11/2023 1.50 COMPZN, RPCOMP ELNE T RIH w/ 1.6875" string shot assembly T/ 6,814.0 6,814.0 00:45 02:15 6900'. Log was dirty F/ GLM #5 @ 6185'. Identified jewelry components. Fire shot 5' string shot F/ 8616' T/ 6821', no indication in unit that shot fired. POOH. Shot fired. 2/11/2023 2/11/2023 3.25 COMPZN, RPCOMP ELNE T Change out tool string. RIH w/2"RCT 6,814.0 6,814.0 02:15 05:30 Log T/ depth. Set anchors. Cut pipe @ 6818'. Indication cutter fired at surface. E-line temporarily detained. Pressure up and surge pump. Work wire. Pull max tension. Appears tool free. POOH w/ E-line tool string. Cutter fired. Page 216 Report Printed: 3/10/2023 Operations Summary (with Timelog Depths) 3N-07 9.6 RIG RELEASE DATE 2/16/2023 CorrocoPh➢rips Rig: NABORS 7ES Job: RECOMPLETION Time Log Stim Time Ent! Time our (m) Phase Activity Code Time P-T-X Operation Start Depth (ftKB) End Depth (ftKB) 2/11/2023 2/11/2023 0.50 COMPZN, RPCOMP RURD T Stand back E-line. RU pipe handling 6,814.0 6,814.0 05:30 06:00 equipment to pull on tubing. 2/11/2023 2/11/2023 0.75 COMPZN, RPCOMP PULL P Pull max tension 195K on tubing. No 6,814.0 6,779.0 06:00 06:45 movement. Put 1.5K ft-lbs rotational torque into tubing with top drive. No movement. Worked tubing from neutral to 195K seven times. Came free. Pulled tubing hanger to rig floor. PUW=75K 2/11/2023 2/11/2023 0.50 COMPZN, RPCOMP RURD P Blowdown top drive. RID E-line 6,779.0 6,779.0 06:45 07:15 sheaves. Lower E-line tools and equipment. RDMO E-line. 2/11/2023 2/11/2023 0.50 COMPZN, RPCOMP SVRG P Service rig 6,779.0 6,779.0 07:15 07:45 2/11/2023 2/11/2023 0.25 COMPZN, RPCOMP PULD P UD Hanger. Install Control Line to 6,779.0 6,747.0 07:45 08:00 Spooler. Pump 10 bbl Dry Job. Blow down top drive. 2/11/2023 2/11/2023 1.50 COMPZN, RPCOMP PULL P POOH with 3-1/2" Completion while 6,815.0 4,978.0 08:00 09:30 spooling up SS Control line F/ 6747' T/ SSSV @ 4978', PUW=50K 2/11/2023 2/11/2023 0.50 COMPZN, RPCOMP SSSV P UD SSSV and Secure control to spooler 4,978.0 4,978.0 09:30 10:00 and RID Same. Recovered 62 SS Control Line Bands. 2/11/2023 2/11/2023 4.00 COMPZN, RPCOMP PULL P Continue POOH laying down 3-1/2" 4,978.0 443.0 10:00 14:00 Completion F/ 4978' T/ 443', PUW=33K 2/11/2023 2/11/2023 0.25 COMPZN, RPCOMP CPBO P Fill out Hot Work Permit for cutting 443.0 443.0 14:00 14:15 Patch from Tubing. Cut and Remove Patch between Joint 197 & 198 from 3- 1/2" TBG. Joint 197 had 2 holes with heavy scale on collar. 2/11/2023 2/11/2023 0.75 COMPZN, RPCOMP PULL P Continue OOH laying down 3-1/2" 443.0 0.0 14:15 15:00 Completion F/ 443' T/ surface, PUW=35K. Joint 199 through 209 had Trace of scale and fill on and around pipe and collars. Joint 210 had hole 1 foot below collar. Joint 211 to Cut Joint on 215 had trace of scale and fill. Joint Length on Joint 215 was 14'-7" long. It measured out to be the first original cut, not the second cut with YellowJacket. 2/11/2023 2/11/2023 2.00 COMPZN, RPCOMP CLEN P Clean & Clear Rig Floor. Load 0.0 0.0 15:00 17:00 JellowJacket tools in Pipe Shed. 2/11/2023 2/11/2023 0.50 COMPZN, RPCOMP SVRG P Service rig 0.0 0.0 17:00 17:30 2/11/2023 2/11/2023 1.00 COMPZN, RPCOMP RURD P Mobilize BHA #1 T/ RF and pipe shed. 0.0 0.0 17:30 18:30 2/11/2023 2/11/2023 0.50 COMPZN, RPCOMP SFTY P PJSM w/ YellowJacket and rig crew on 0.0 0.0 18:30 19:00 P/U BHA. 2/11/2023 2/11/2023 1.75 COMPZN, RPCOMP BHAH P M/U BHA#1 Scraper T/223', 0.0 223.0 19:00 20:45 SOW=38K. Had to work through tight spot in 7" @ 47' 2/11/2023 2/12/2023 3.25 COMPZN, RPCOMP PULD P PUDP F/ 22T T/ 4226', SOW=85K 223.0 4,226.0 20:45 00:00 2/12/2023 2/12/2023 1.00 COMPZN, RPCOMP PULD P PUDP F/ 4226' T/ 5013', SOW=85K 4,226.0 5,013.0 00:00 01:00 2/12/2023 2/12/2023 1.00 COMPZN, RPCOMP SLPC P Cut and slip 95' of drill line. 5,013.0 5,013.0 01:00 02:00 Circ STS @ 3 BPM, 720 PSI. 2/12/2023 2/12/2023 0.50 COMPZN, RPCOMP SVRG P Service rig 5,013.0 5,013.0 02:00 02:30 2/12/2023 2/12/2023 2.00 COMPZN, RPCOMP TRIP P PUDP F/ 5013'T/6778', SOW=102K/ 5,013.0 6,778.0 02:30 04:30 PUW=135K Page 316 Report Printed: 3/10/2023 Operations Summary (with Timelog Depths) 3N-07 9.6 RIG RELEASE DATE 2/16/2023 Co..31,141 s Rig: NABORS 7ES Job: RECOMPLETION Time Log Stim Time ErM Time our (hr) Phase Activity Code Time P-T-X Operation Stan Depth (BKB) Entl Depth (WB) 2/12/2023 2/12/2023 1.50 COMPZN, RPCOMP CIRC P Reciprocate and Washing across 6,778.0 6,778.0 04:30 06:00 Packer Setting area f/6725' to 6775' 6.5 bpm, 2500 psi. Clean returns after circulating S/S (250 bbls). Blow down top drive and circulating manifold. 2/12/2023 2/12/2023 5.50 COMPZN, RPCOMP PULD P TOOH laying down Drill Pipe f/6778'to 6,778.0 223.0 06:00 11:30 BHA#1 at 223' 2/12/2023 2/12/2023 1.50 COMPZN, RPCOMP BHAH P Lay Down Drill Collars. UD BHA #1. 223.0 0.0 11:30 13:00 Recovered 8 small pieces of control line bands. Pull Wear Ring. 2/12/2023 2/12/2023 1.00 COMPZN, RPCOMP CLEN P Clean & Clear Rig Floor. 0.0 0.0 13:00 14:00 2/12/2023 2/12/2023 1.00 COMPZN, RPCOMP RURD P Pull wear bushing. 0.0 0.0 14:00 15:00 Unloading Tools from Rig Floor. 2/12/2023 2/12/2023 0.50 COMPZN, RPCOMP SVRG P Service rig 0.0 15:00 15:30 2/12/2023 2/12/2023 7.50 COMPZN, RPCOMP PULD P Process 3.5" IPC Tubing in Pipe Shed. 0.0 0.0 15:30 23:00 2/12/2023 2/12/2023 0.50 COMPZN, RPCOMP RURD P Verify joint count and jewelry running 0.0 23:00 23:30 order. 2/12/2023 2/13/2023 0.50 COMPZN, RPCOMP SFTY P PJSM w/ HES and rig crew on running 3 23:30 00:00 1/2" completion. 2/13/2023 2/13/2023 11.75 COMPZN, RPCOMP RCST P Run 3 1/2", 9.3#, L-80, EUE-M, ICP 0.0 6.795.0 00:00 11:45 completion T/ 6795", SOW=65K, PUW=80K. 3 1/2" EUE-M torqued T/ 2250 Ft/lbs. Run-n-seal dope used. 2/13/2023 2/13/2023 2.75 COMPZN, RPCOMP CIRC P Kelly up on Joint 213, pumping at 1 6,795.0 6,811.0 11:45 14:30 bpm, 500 psi and RIH to locate top of stub at 6814'. Tagged at 6811' several times. Tried rotating 1/4 turn, tagged same depth. PUH shut down pumps and tagged same depth. PUH rotated 1 turn, tagged same depth. Tried pumping, not pumping, rotating and non -rotating, tagged same depth at 6811' Set down weight 17K, not able to swallow over stub. UD Joint 213 and Blow down Top Drive. 2/13/2023 2/13/2023 1.50 COMPZN, RPCOMP COND T Mix up Dry Job. Circulate S/S @ 3 bpm, 6,811.0 6,795.0 14:30 16:00 600 psi. Pump 20 bbi Dry Pill. Blow Down Top Drive. Release Slickline. 2/13/2023 2/13/2023 6.25 COMPZN, RPCOMP PULL T POOH standback 3-1/2" Completion 6,795.0 0.0 16:00 22:15 String. Laying down jewelry, F/ 6795' T/ 3094" , PUW=85K. Swap out joint #93 with spare #C, change collar on joint 92. Cont to rack back completion string F/ 3094' T/ surface', PUW=55K. No indication we swallowed stub, shear screws intact. Minimal scaring on outside of mule shoe. Begin processing drill pipe string in pipe shed. 2/13/2023 2/13/2023 0.50 COMPZN, RPCOMP SVRG T Service rig. 0.0 0.0 22:15 22:45 2/13/2023 2/13/2023 0.75 COMPZN, RPCOMP CLEN T Clean and dear rig floor. 0.0 0.0 22:45 23:30 2/13/2023 2/14/2023 0.50 COMPZN, RPCOMP RURD P Install wear bushing. 0.0 0.0 23:30 00:00 2/14/2023 2/14/2023 1.00 COMPZN, RPCOMP RURD T Process remaining DP and Bea DC's in 0.0 0.0 00:00 01:00 pipe shed. Mobilize BHA#2 T/ RF. 2/14/2023 2/14/2023 0.50 COMPZN, RPCOMP SFTY T PJSM w/ YellowJacket and rig crew on 0.0 0.0 01:00 01:30 P/U BHA Page 416 Report Printed: 3/10/2023 Operations Summary (with Timelog Depths) 3N-07 9.6 RIG RELEASE DATE 2/16/2023 CorrocoPh➢rips Rig: NABORS 7ES Job: RECOMPLETION Time Log Star Time ErM Time Dur (hr) Phase Activity Code Time P-T-X Operation Stan Depth (ftK8) End Depth (ftKB) 2/14/2023 2/14/2023 1.00 COMPZN, RPCOMP BHAH T M/U BHA#2 Short catch overshot w/ cut 0.0 229.0 01:30 02:30 -lip guide T/ 229', SOW=38K. 2/14/2023 2/14/2023 6.00 COMPZN, RPCOMP PULD T RIH PUDP F/229' T/ 6785', RU Blower 229.0 6,785.0 02:30 08:30 Hose. 2/14/2023 2/14/2023 1.00 COMPZN, RPCOMP FISH T Kelly Up on Joint 209. Up Wt 135K/ DN 6,785.0 6,813.0 08:30 09:30 Wt 100K. On Line w/ Pump at 2 bpm, 660 psi, continue in and tagged 6811' w/ 1 OK down. Rotate 1-1/2" turns. Increase pump rate to 3 bpm, 900 psi. RIH and seen pressure increase to 3000 psi at 6813' w/10K down weight. Bleed down pump pressure, PUH and seen 145K on Weight. RIH again and Tagged at 6813' and came on line with pump, pressure up right away, bleed down psi and PUH 1 stand w/5K drag and was able to circulate. Pump 20 boll dry job, blow down top drive. 2/14/2023 2/14/2023 3.50 COMPZN, RPCOMP TRIP T TOOH and check for cut section and 6,718.0 229.0 09:30 13:00 seal Assy. 2/14/2023 2/14/2023 2.50 COMPZN, RPCOMP BHAH T Stand back Drill Collars and BHA#2. 229.0 0.0 13:00 15:30 Recovered the entire seal assembly. Break down Tools and remove cut joint from grapple. Found 3.70: OD Bulge spot were the second cut was supports to be. OAL of 3.5" Cut section was 16', bulge was 41 from the cut end. The OD of the bulge was 3.70" OD and the TBG was 3.60" OD. Load out YellowJacket Tools from Rig Floor. 2/14/2023 2/14/2023 1.00 COMPZN, RPCOMP CLEN P Clean and Clear Rig Floor. 0.0 0.0 15:30 16:30 2/14/2023 2/14/2023 0.50 COMPZN, RPCOMP SVRG P Rig Service. 0.0 0.0 16:30 17:00 2/14/2023 2/14/2023 1.50 COMPZN, RPCOMP WAIT P Waiting for Oversite Tools. 0.0 0.0 17:00 18:30 2/14/2023 2/14/2023 1.00 COMPZN, RPCOMP BHAH P PJSM, Pick up BHA 2-7/8" mule shoe to 0.0 93.8 18:30 19:30 drill pipe 2/14/2023 2/14/2023 3.00 COMPZN, RPCOMP TRIP P Trip in hole with mule shoe to 6800 93.8 6,800.0 19:30 22:30 2/14/2023 2/14/2023 0.75 COMPZN, RPCOMP WASH P Kelly up to wash seal ext. // Pu Wt 125K 6,800.0 6,890.0 22:30 23:15 SO Wt. 100K // Pump 3 bpm 860 psi Wash down to 6890' minimal WOB bobble 50 - 60 psi 2/14/2023 2/15/2023 0.75 COMPZN, RPCOMP CIRC P Circulate B/U 6,890.0 6,800.0 23:15 00:00 2/15/2023 2/15/2023 0.75 COMPZN, RPCOMP CIRC P Circulate surface to surface 6,800.0 6,800.0 00:00 00:45 2/15/2023 2/15/2023 6.00 COMPZN, RPCOMP PULD P TOOH laying down drill pipe. Up Wt 6,800.0 93.8 00:45 06:45 1125k / Din Wt 100k 2/15/2023 2/15/2023 1.75 COMPZN, RPCOMP BHAH P RU Handling Equipment to Break out 2- 93.8 0.0 06:45 08:30 7/8" Clean Out Assy. Break out and L/D 2 stands of drill collars. Pull Wear Bushing. 2/15/2023 2/15/2023 0.25 COMPZN, RPCOMP CLEN P Clean & Clear Rig Floor. 0.0 0.0 08:30 08:45 2/15/2023 2/15/2023 0.50 COMPZN, RPCOMP RURD P PU/MU Handling Equipment for running 0.0 0.0 08:45 09:15 completion. 2/15/2023 2/15/2023 0.25 COMPZN, RPCOMP SFTY P PJSM with all RTM's 0.0 0.0 09:15 09:30 2/15/2023 2/15/2023 6.00 COMPZN, RPCOMP PUTB P Verify running order of jewelry. PU/MU 0.0 6,867.0 09:30 15:30 and Run in hole with 3-1/2" Completion. No -Go Out 6835' End of WLEG @ 6867' after 2 foot space out on No -Go. Page 516 Report Printed: 311012023 Operations Summary (with Timelog Depths) 3N-07 9.6 RIG RELEASE DATE 2/16/2023 Co..;p illirn Rig: NABORS 7ES Job: RECOMPLETION Time Log Shm Time ErM Time our (m) Phase Activity Code Time P-T-X Operation Stan Depth (ftKB) End Depth (ftKB) 2/15/2023 2/15/2023 0.75 COMPZN, RPCOMP THGR P MU 14.43' of Space out Pup's and 6,867.0 6,867.0 15:30 16:15 Hanger. RIH and Land 3.5" Completion. RILDS. 2/15/2023 2/15/2023 0.25 COMPZN, WHDBOP MPSP P Install BPV. 6,867.0 6,867.0 16:15 16:30 2/15/2023 2/15/2023 0.25 COMPZN, WHDBOP RURD P RU Circulating Manifold 0.0 0.0 16:30 16:45 2/15/2023 2/15/2023 0.75 COMPZN, WHDBOP PRTS P Pressure Test BPV to 1000 psi for 10 0.0 0.0 16:45 17:30 mins. RD Circulating Manifold. 2/15/2023 2/15/2023 5.75 COMPZN, WHDBOP RURD P RD BOPE and RU Tree. // Test void to 0.0 0.0 17:30 23:15 5K psi good test // Pressure test tree 5K 15 min good test // pull test dart and BPV 2/15/2023 2/16/2023 0.75 COMPZN, WHDBOP CIRC P Rig up lines and pump 240 bbls Cl down 0.0 0.0 23:15 00:00 IA up through tubing Circulate out 14# LSND with 240 Bbls 10.3# Cl NaBr down IA taking returns to 400 Bbls open top tank @ 2.5 BPM reducing T/ 1.5 BPM. Increasing back pressure in choke house to 1200 PSI. 10.3 PPG returns at surface. FCP TBG=1200, IA=1300. 2/16/2023 2/16/2023 2.00 COMPZN, WHDBOP CRIH P Circulate out 14# LSND with 240 Bbls 0.0 0.0 00:00 02:00 10.3# Cl NaBr down IA taking returns to 400 Bbls open top tank @ 2.5 BPM reducing T/ 1.5 BPM. Increasing back pressure in choke house to 1200 PSI. 10.3 PPG returns at surface. FCP TBG=1200, IA=1300. 2/16/2023 2/16/2023 1.00 COMPZN, WHDBOP OTHR P Rig up lubricator // Drop Ball and Rod // 0.0 0.0 02:00 03:00 Rig down lubricator and rig up little red to set packer 2/16/2023 2/16/2023 1.00 COMPZN, WHDBOP PRTS P Rig up to set packer and test tubing // 0.0 0.0 03:00 04:00 Bring LRS online down tubing. 4850 Tubing„ IA=1400 PSI. Hold and PT tubing for 30 Min. Good test FTP=4700, FIA=1450 2/16/2023 2/16/2023 1.00 COMPZN, WHDBOP PRTS P Bleed off tubing to 1500 PSI. Line up 0.0 0.0 04:00 05:00 down IA. Pressure up to 2500 PSI down IA hold 30min good test. Bleed down tubing pressure. See SOV shear. T=200 PSI, IA=200 PSI. 2/16/2023 2/16/2023 2.00 COMPZN, WHDBOP FRZP P Line up LRS down IA returns up tubing. 0.0 0.0 05:00 07:00 Circ in 71 BBIs diesel freeze protect @ 2 BPM, ICP=600, FCP=1050. U-tube from IA to Tubing. 2/16/2023 2/16/2023 1.00 DEMOB, MOVE RURD P B/D, R/D circ manifold and tiger tank 0.0 0.0 07:00 08:00 lines. Final pressures TBG=200, IA=200, OA=100. Off Hi Line 08:00 2/16/2023 2/16/2023 4.00 DEMOB, MOVE MOB P Secure tree and clean cellar. Lay over 0.0 0.0 08:00 12:00 derrick. RDMO. Page 616 Report Printed: 3/10/2023 3N-07 RWO Summary of Operations DTTMSTART JOBTYP SUMMARYOPS 11/19/2022 ACQUIRE DATA (PRE-RWO) FUNCTION TESTED ALL T & IC LDS/GN, T-POT (PASSED) T-PPPOT (PASSED) IC -POT (PASSED) IC-PPPOT (PASSED) CMIT-T X IA (IN -PROGRESS) CDDT-T X IA (IN - PROGRESS) 11/20/2022 ACQUIRE DATA (PRE RWO) CMIT T x IA TO 2500 PSI (PASS) DDT T x IA (PASS) 1/22/2023 ACQUIRE DATA MIRU P/U BAKER MILLING ASSY, TAG MAGNA RANGE PLUG AT 6777' CTMD, MILL FOR 2.5 HOURS, MILL PLUGGED OFF, THE MILL CAME BACK WITHOUT ANY CUTTING SURFACE -- BEFORE RIH IT WAS FLAT FACED --AFTER RIH IT WAS ROUND AND SMOOTH, MAKE 2 VENTURI RUNS, FIRST RUN HAD 1/2 CUP OF METAL SHAVINGS, 2ND RUN WAS FAIRLY CLEAN, RIH W/ NEW MILL CONTINUE MILLING AT 6797.5' CTMD, JOB IN PROGRESS. 1/23/2023 ACQUIRE DATA CONTINUE MILLING TO 6798.1' CTMD, POOH TO INSPECT MILL, IT STARTED OUT FLAT FACED AND IS NOW ROUNDED WITHOUT ANY CUTTING STRUCTURE, ALMOST AS BAD AS THE 1ST MILL, RIH WITH A 2.13" 3 BLADED JUNK MILL # 3 JUNK MILL NO HOLE POOH AND P/U 2.13 SHOE RIH AND TAG 6787' CONT MILLING ON MRP PLUG TO 6820' 1/24/2023 ACQUIRE DATA PUSH MAGNA RANGE PLUG DOWN TO TAG LINER TOP @ 7171', POOH, STOP AT 6950' CTMD TO PAINT A FLAG, RIH WITH IBP, AT FLAG CORRECT DEPTH, PUH TO SET DEPTH MID ELEMENT @ 6922' RKB, STATIC WHP @ 6922 IS 1767' PSI, DROP 1/2" BALL TO INFLATE IBP, POOH PUMPING SEAWATER AND F/P TBG WITH DIESEL TO 2000' RKB, PERFORM PASSING COMBO -MIT AT SURFACE, READY FOR DHD & SLICKLINE 1/25/2023 ACQUIRE DATA (PRE-RWO) CMIT T X IA PASED TO 2750 PSI, CDDT T X IA PASSED TO 0 PSI. 1/26/2023 SUPPORT OTHER DUMP BAIL SAFE CARB ON IBP @6922'RKB IN PROGRESS OPERATIONS 1/27/2023 SUPPORT OTHER DUMP 10' OF SAFE CARB FROM 6922'RKB-6912'RKB ON TOP OPERATIONS OF IBP @6922'RKB,DEPLOY 2.77AVA CATCHER,ATTEMPT TO PULL ST#4 (UNSUCCESSFUL) IN PROGRESS 1/28/2023 SUPPORT OTHER SET 1.5"DMY VLVW/RK LATCH ST #5 @6186'RKB,REPLACED OPERATIONS ST#3 W/1.5"DMY VLV & RK LATCH,PULLED ST#2 @3895'RKB. IN PROGRESS 1/29/2023 SUPPORT OTHER SET 1.5"DMY VLV W/RK LATCH ST#2 @3895'RKB,REPLACED OPERATIONS ST#1 W/1.5"DMY VLV & RK LATCH @2640'RKB,REPLACED ST#4 W/1.5"DMY VLV W/RK LATCH @5545'RKB,PULLED 2.77"CATCHER @6222'RKB,LOCKED OUT SSSV @1818'RKB READY FOR E-LINE 2/5/2023 SUPPORT OTHER RUN 1: PERFORM STRING SHOT OVER INTERVAL: 6805' - OPERATIONS 6814'. RUN 2: CUT TUBING W/ 2" RCT AT 6814.0' RKB, CCL TO CUTTER = 13.2% CCL STOP DEPTH = 6800.8' JOB COMPLETE, READY FOR RWO 2/7/2023 PUMPING FREEZE PROTECT TRACKING ONLY PUMPED 7 BBLS DSL DWN FL PRESSURED FLOWLINE UP TO 300 PSI PER DSO 2/9/2023 RECOMPLETION Load shop. Pull pits away from sub. Load office. Move and set office and shop. Move and stage pits on 3N. Pull sub off well. Clean up around well. Move sub to T/ 3N. Hang tree, stage wellhead equipment in cellar. Spot sub over 3N-07. Spot pits to sub. Spot auxiliary equipment. Cuttings tank, tiger tank, choke and tiger tank hard line. Hook up electrical and plumbing in interconnect. Turn on steam and air to pits. Berm in rig. Raise derrick. Bridal Up. Hand Bridle Lines. Berm in Rig and Cellar. Take on 14.5 PPG LSND. Condition fluid to 14.0 PPG. Test circ manifold and tiger tank lines. Bleed free gas off of tubing and IA. 2/10/2023 RECOMPLETION Bleed free gas off of tubing and IA. Killing well with 353 Bbls 14.0 PPG down tubing taking returns to tiger tank. Shut -In and perform 30 minute no flow. Install "IS -A" BPV and pressure test to 1,000 PSI from below for 15 min. Nipple down tree and tubing head adapter. Inspect lift threads, install blanking plug, function LDS. Nipple up BOP. Pressure test BOPE as per sundry 250/4500. Pull blanking plug. Pull BPV. Make up landing joint. BOLDS. Attempt to pull completion. Consult with town, decision made to pull 95% of tensile - no pipe movement. Call out YellowJacket E-line crew. Circulate surface to surface. Set in slip with 25K tension in string. Mobilizing E-line unit from Deadhorse. Spot E-line unit. Rigging up E-Line. 2/11/2023 RECOMPLETION Cont rig up E-line w/ pump in sub and packoff. E-line RIH w/ 1.6875" string shot assembly. Fire shot F/ 6816' T/ 6821'. Pullout of hole. Makeup and run in hole with 2" RCT string. Cut pipe @ 6818'. Worked E-line and tool string free. Pull out of hole. Cutter fired. Stand back E-line. Latch onto string, worked pipe. Pipe free, pull hanger to rig floor. Release E-line. OWFF. Connect SSSV control to spooling unit. Lay down hanger and landing joint. Lay down 3 1/2" EUE completion string to SSSV. Rig down spooling unit. Cont lay down completion to tubing patch. Cut patch. Cont lay down completion to surface. Clean cut. Appears pulled from original pre rig cut. Make up BHA #1 Scraper. Pick up drill pipe T/ 4226'. 2/12/2023 RECOMPLETION Cont pick up pipe T/ 5013'. Cut and slip drill line while circulating surface to surface. Continue pick up drill pipe 6725' Obtain parameters. Wash and ream T/ 6775' Circulate surface to surface. Lay down drill pipe and BHA #1. Process 3 1/2' EUE-M ICP completion string. Verify joint count and jewelry running order. 2/13/2023 RECOMPLETION Run 3 1/2" EUE-M ICP completion string as per tally T/ 6795'. Kelly up attempt to wash over tubing stub. No pressure increase noted. Attempt to swallow tubing stub with pump on and off. Oriented string. Rotated string slowly. Tagging hard in same spot @ 6811, 7ES RKB. No indication of swallow over tubing stub. Consult with town. Decision made to pull out of hole racking back 3 1/2" EUE completion string. Call out YellowJacket fishing with a variety of fishing configuration options. Lay down single, rack back completion removing jewelry from string T/ surface. No evidence that mule shoe swallowed tubing stub, shear screw intact. Install wear bushing. Processing drill pipe and drill collars in pipe shed. 2/13/2023 SUPPORT OTHER 7ES SUPPORT RIG (JOB CANCELED). OPERATIONS 2/14/2023 RECOMPLETION Processing drill pipe and drill collars in pipe shed. Mobilize BHA #2 to rig floor. Make up BHA #2 Cut -lip overshot. Pick up drill pipe T/ 6875'. overshot seal assembly and pull from seal ext., tooh stand back collars lay down seal assembly send to baker for re -dress, pick up 2-7/8 mule shoe and 2 jts 2-7/8" pipe, RIH clean seal bore ext T/ 6890', circulate B/U 2/15/2023 RECOMPLETION Finish circulating B/U , lay down drill pipe out of the hole, lay down BHA and collars, rig up and run completion out of derrick, land hanger with BPV and test dart, wash stack nipple down, rig up tree and test, pull BPV, start circulating in Cl 2/16/2023 RECOMPLETION Pressure test tiger tank line. LRS displace 14.0 PPG LSND out of well with 10.3 PPG Cl NaBr pumping down IA taking returns to open top tank. 10.3 PPG returns to surface. Final surface pressure 1200 PSI. Load ball and rod in tree. Launch ball and rod. LRS pressure up and set packer with 4850 PSI differential pressure. Test tubing T/4850 PSI for30 Min. Test IA T/2500 PSI for 30 Min. Dump tubing pressure and shear out SOV. Establish circulation rate. LRS pump 71 Bbls diesel freeze protect down IA. U-tube well. Secure tree and cellar. Demob. 2/24/2023 SUPPORT OTHER SET BAITED CATCHER ON TOP OF BALL & ROD @ 8601' RKB. OPERATIONS JOB IN PROGRESS. 2/25/2023 SUPPORT OTHER PULLED SOV @ 6749' RKB & REPLACED W/ OV; PULLED DVs OPERATIONS @ 5253', 2603' RKB & REPLACED W/ LIVE GLVs; PULLED BALL & ROD @ 6801' RKB & RHC @ 6809' RKB. JOB COMPLETE, READY FOR COIL TUBING. KUP PROD WELLNAME 3N-07A WELLBORE 3N-07A amocOPIIlllps Alaska, Inc. CONDUCTOR: UNE, d,921.9.1M O0 CTD Well Attributes IMaxAngle D TD poll Name WNIbore APWWI Wellhore..... Id(°) Mn(IIKRI _mm mim., K PAR KRIVER NIT 221 1 PR D 6.29 7,233.69 7,450.0 Common. 112S Ippm) Gate Mm.Nian Entl pNe KBGNIflI RR pse OIM1er I....Last PC WO: 2/16od)23 38.49 1711986 Armenian DeMIN IftKBI 1 Wil" re End Drte Lart Mi By Last Tag: SLM J,1 s,.0 3N-0]A 12114/2014 Fmidid Last Rev Reason Annotation WeIINrt 1 End Dale Lax Mod By Rev Reason: Pull IBP and Magna range plug. 11. IA 111CIU11 I appleba Casing Strings set Depin sM Di Cog Dea OD lint ID lint Top Runs uses) OVDHfine) Wlhen pbml Grade TorThread CONDUCTOR 16 15.06 35.0 115.0 115.0 62.50 H40 WELDED SURFACE 9BI8 8.92 37.0 3,691.4 3,610.2 36.00 JS5 BTSC WINDOW All) -SIB" 951a 8.00 2,599.0 2,616.0 2,615.4 Csg exit) PRODUCTION 7 6.28 37.3 7,040.6 6,303.4 26.00 L-80 BTCM LINER 4112 3.96 6,821.9 7,448.0 6588.4 12.60 L-80 IBTM Window AL2 4112 7,209.0 7,216.0 6,425.5 Window AL1 4112 7,240.0 7,246.0 6,446.3 Tubing Strings: string max indicates LONGEST segment of string Torisky) sO Deper... des.2 p.n... .[Nng Ma... Taeme Desaripdon wt 111JX1 Arade TopconMafion lD(in) 228 6,8fi].0 6,1822 3112 Tubing -Production 9.30 L-80 EUE 2.99 Completion Details: excludes tubing, pup, space out, thread, RKB... on Top(TVDI Top lncl Nominal Nominal Top(..) 11KBI l°I Rem Dea (in) core Make Made) Is (in) 22.8 22.8 0.00 Hanger 5.990 Tubing Hanger, FMC Gen 3 wl 3.5 FMC Gen 2.960 EUE 8rd Bottom 522.9 5MS 0.57 Nipple -X 4.517 2.813"X-Nipple SN# 0ON717612- HES XNipple 2.813 IN 2,603.1 2,602.6 6.41 Mandrel - GAS 3.500 3.5"x1-V2", MMG, GLM, 3.5"x 1- SUB MMG 2.920 LIFT 1I2"DMY w/RK latch SN#23761-01 5,252.9 4,918.0 32.55 Mandrel -GAS 3.500 3.5"x 1.1I2", MMG, GLM, 3.5"x 1- SUB MMG 2.920 LIFT 112" DMY w/ RK Latch SN#2376R05 6749.7 6.098.9 44.60 Mantlrel - GAS 3.500 3.5"x1-1I2", MMG, GLM, 3.5"x 1- SLB MMG 2.920 LIFT 1/2" SOV wI REK Latch SN#23]61- m 6,778.5 6,119.4 44.62 Packer 6.280 HES LIFT FeedThm 3.1YY' x T' HES MFT 2.897 packer. SN40004113579-01 61808.5 6,140.7 44.64 Nipple -X 4.511 2.813"X-Nipple HES XNipple 2.813 6,826.4 6.153.5 4479 Locator 3.500 Baker 3-12'80-40 GBH22 Locator Baker NO-GO 3.000 sub, EUE-8rd-Mod box 6,833.7 6.158.7 44.87 Seal Assembly 3.500 Baker seal assembly W/10'stoke W/ Baker Baker 2.992 Make Shoe (2.0' From lolly located) Seal Assy Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top Top (man (manTopind(•) Des Core Make Matlel SN Run Di Is (in) 7,170.2 6,393.7 45.90 CTD LINER LINERAU-02 91172012 1.920 TOP 7,204.0 6,417.2 46.11 WHIPSTOCK TPNS for 3NE07AL2 exit thru 4 91112012 1.000 -112"liner 7,238.0 6440.7 46.26 WHIPSTOCK 77WS for 3N-07AL1 exit thru4 8/1712012 -1I2"liner Mandrel Inserts : excludes pulled inserts at -d Top (1KB) Top ITVD) (M(B) Top o^ Ind ( No .ery Vi Type Leach Type OD (In) TRO Run Opel) Run Dne Co. Make seal PM 8le, pid 2,603.1 2,602.6 6.41 GAS LIFT GLV RK 3112 1,218.0 2]2512023 Schlumb MMG 0.188 Latch eager 5,252.9 4,918.0 32.55 2 GAS LIFT GLV RK 3112 1,214.0 2/25I2023 Schlumb MMG 0.188 eager 6749.7 6098.9 44.60 3 GAS LIFT OV RK 3112 2/2512023 Schlumb MMG 0.188 eager Liner Details: Excludes Liner, Pup, Joints, "sing, float, sub, shoe... oD Top (1VD) Topind Nominal Nominal ID Top 11KB) 11KB) l°) fain Dev tin) Cmm Make Mudd ling 6,821.9 6,150.3 44.74 PACKER fODU BAKERC-27XPLINERTOP 5.000 I PACKER 7,326.1 6,502.0 4a.ca LANDING 4.500 3.958 COLLAR 1 Regg, James B (OGC) From:Brooks, Phoebe L (OGC) Sent:Tuesday, March 7, 2023 8:56 AM To:Cozby, Kelly Cc:Regg, James B (OGC) Subject:RE: 7ES BOP Test 2-10-23 Attachments:Nabors 7ES 02-10-23 Revised.xlsx Kelly, Attached is a revised report changing the well name to reflect KRU 3N‐07A based on PTD #2120520. I also changed the FSV Misc. test result field to “NA”. Please update your copy. Thanks, Phoebe Phoebe Brooks Research Analyst Alaska Oil and Gas Conservation Commission Phone: 907‐793‐1242 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 Phoebe Brooks at 907-793-1242 or phoebe.brooks@alaska.gov. From: Cozby, Kelly <Kelly.Cozby@nabors.com> Sent: Saturday, February 11, 2023 2:44 PM To: Regg, James B (OGC) <jim.regg@alaska.gov>; DOA AOGCC Prudhoe Bay <doa.aogcc.prudhoe.bay@alaska.gov>; Brooks, Phoebe L (OGC) <phoebe.brooks@alaska.gov>; NSK RWO CM <nskrwo.cm@conocophillips.com> Cc: Henson, James <Jim.Henson@nabors.com>; Morales, Tony <Tony.Morales@nabors.com>; Medina, Johnny <Johnny.Medina@nabors.com>; Yearout, Paul <Paul.Yearout@nabors.com>; Hobbs, Greg S <Greg.S.Hobbs@conocophillips.com>; Kneale, Michael L <michael.l.kneale@conocophillips.com> Subject: 7ES BOP Test 2‐10‐23 Thank You Kelly Cozby 7ES Rig Manager Nabors Alaska Drilling Inc. Office 907‐670‐ 6132 Cell 907‐715‐9055 kelly.cozby@nabors.com ******************************* NABORS EMAIL NOTICE - This transmission may be strictly proprietary and confidential. If you are not the intended CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. KRU 3N-07APTD 2120520 STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION *All BOPE reports are due to the agency within 5 days of testing* Submit to:jim.regg@alaska.gov; AOGCC.Inspectors@alaska.gov; phoebe.brooks@alaska.gov Rig Owner:Rig No.:7ES DATE:2/10/23 Rig Rep.:Rig Email: Operator: Operator Rep.:Op. Rep Email: Well Name:PTD #2120520 Sundry #323-040 Operation:Drilling:Workover:X Explor.: Test:Initial:X Weekly:Bi-Weekly:Other: Rams:250/4500 Annular:250/2500 Valves:250/4500 MASP:3952 MISC. INSPECTIONS:TEST DATA FLOOR SAFETY VALVES: Test Result/Type Test Result Quantity Test Result Housekeeping P Well Sign P Upper Kelly 1 P Permit On Location P Hazard Sec.P Lower Kelly 1 P Standing Order Posted P Misc.NA Ball Type 2 P Test Fluid Water Inside BOP 1 P FSV Misc 0 NA BOP STACK:Quantity Size/Type Test Result MUD SYSTEM:Visual Alarm Stripper 0 NA Trip Tank P P Annular Preventer 1 13 5/8" T90 P Pit Level Indicators P P #1 Rams 1 2 7/8' x 5"P Flow Indicator P P #2 Rams 1 Blinds P Meth Gas Detector P P #3 Rams 1 3 1/2" x 5 1/2"P H2S Gas Detector P P #4 Rams 0 NA MS Misc 0 NA #5 Rams 0 NA #6 Rams 0 NA ACCUMULATOR SYSTEM: Choke Ln. Valves 1 3 1/8" Gate P Time/Pressure Test Result HCR Valves 2 3 1/8" Gate P System Pressure (psi)3000 P Kill Line Valves 2 3 1/8" & 2"P Pressure After Closure (psi)1600 P Check Valve 0 NA 200 psi Attained (sec)15 P BOP Misc 2 2 1/16" Gate P Full Pressure Attained (sec)125 P Blind Switch Covers:All stations Yes CHOKE MANIFOLD:Bottle Precharge:P Quantity Test Result Nitgn. Bottles # & psi (Avg.):5@1950 P No. Valves 16 P ACC Misc 0 NA Manual Chokes 1 P Hydraulic Chokes 1 P Control System Response Time:Time (sec)Test Result CH Misc 0 NA Annular Preventer 27 P #1 Rams 5 P Coiled Tubing Only:#2 Rams 5 P Inside Reel valves 0 NA #3 Rams 5 P #4 Rams 0 NA Test Results #5 Rams 0 NA #6 Rams 0 NA Number of Failures:0 Test Time:5.0 HCR Choke 1 P Repair or replacement of equipment will be made within days. HCR Kill 1 P Remarks: AOGCC Inspection 24 hr Notice Yes Date/Time 2/9/23 5:20AM Waived By Test Start Date/Time:2/10/2023 11:00 (date)(time)Witness Test Finish Date/Time:2/10/2023 16:00 BOPE Test Report Notify the AOGCC of repairs with written confirmation to: AOGCC.Inspectors@alaska.gov Adam Earl Nabors All Tests with 3 1/2" Test joint. All alarms tested Kelly Cozby / Johnny Medina ConocoPhillips Dale Rowell / Kevin Barr KRU 3N-07A Test Pressure (psi): kelly.cozby@nabors.com nskrwo.cm@conocophillips.com Form 10-424 (Revised 08/2022)2023-0210_BOP_Nabors7ES_KRU_3N-07A J. Regg; 6/12/2023 1. Type of Request: Abandon Plug Perforations Fracture Stimulate Repair Well Operations shutdown Suspend Perforate Other Stimulate Pull Tubing Change Approved Program Plug for Redrill Perforate New Pool Re-enter Susp Well Alter Casing Other: Replace Tubing____ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Exploratory Development 3. Address: Stratigraphic Service 6. API Number: 7. If perforating:8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes No 9. Property Designation (Lease Number): 10. Field: Current Pools: N/A 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 7450 7450 3952 N/A N/A Casing Collapse Conductor Surface Production Liner Packers and SSSV Type: 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16. Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Contact Email: Contact Phone: 907-263-4742 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other: Post Initial Injection MIT Req'd? Yes No Spacing Exception Required? Yes No Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng N/A 7004 4.5 N/A 7448626 3.5 6588 7 Packers and SSSV MD (ft) and TVD (ft): 1818'MD/1818T'VD 6822'MD/6150'TVD 9 5/83654 1.SSSV 2. Production 2. ZXP Liner Top Pk 6589 Perforation Depth MD (ft): MD 36103691 63037041 Length Size Proposed Pools: 115 115 TVD Burst Kuparuk River Unit/ Kuparuk River Oil Pool PRESENT WELL CONDITION SUMMARY 80 16 6589 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AA25521 212-052 P.O. Box 100360 Anchorage, AK 99510-0360 50-029-21539-01-00 ConocoPhillips Alaska, Inc N/A KRU 3N-07A Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Tubing Size: L-80 6874 3/2/2023 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: AOGCC USE ONLY RWO/CTD Engineer Ellitott Tuttle elliott.tuttle@conocophillips.com Form 10-403 Revised 10/2022 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Samantha Carlisle at 9:08 am, Jan 24, 2023 323-040 Digitally signed by Elliott Tuttle DN: C=US, OU=CTD/ RWO Drilling Engineer, O="Conoco Phillips, Inc", CN=Elliott Tuttle, E=elliott.tuttle@ conocophillips.com Reason: I am approving this document Location: Date: 2023.01.24 08:43:54-09'00' Foxit PDF Editor Version: 12.0.1 Elliott Tuttle DLB 01/25/2023 X X DSR-1/26/23 BOP test to 4500 psig Annular preventer test to 2500 psig ADL0025521 DLB VTL 2/7/2023 10-404 X GCW 02/07/23 JLC 2/7/2023 2/7/2023 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.02.07 15:16:46 -09'00' RBDMS JSB 020823 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 24, 2023 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: Elliott Tuttle Senior Wells Engineer CPAI Drilling and Wells ConocoPhillips Alaska, Inc. hereby submits an Application for Sundry Approval to work over Kuparuk Producer 3N- 07A (PTD# 212-052). Well 3N-07A Sidetrack was drilled and completed in July of 2012 by Doyon 141 as a CTD Setup/ Slot Recovery A- Sand Producer . During curtailment (6/11/2020), the well failed a SI-TIFL and the tubing was unsuccessfully patched. A LDL performed 8/21/2020 found aditional leaks so the well was secured with a plug set at 6819' and LTSI waiting on RWO. Well passed a CMIT in 2020 and in December of 2022. If you have any questions or require any further information, please contact me at 907-252-3347. Tubing will be pulled and replaced with inner plastic coated tubing with a new seal asembly landed in the liner seal bore. A stack packer completion design may be run in place of a new seal assembly if seals do not pull. Digitally signed by Elliott Tuttle DN: C=US, OU=CTD/ RWO Drilling Engineer, O="Conoco Phillips, Inc", CN=Elliott Tuttle, E=elliott.tuttle@ conocophillips.com Reason: I am approving this document Location: Date: 2023.01.24 08:52:01-09'00' Foxit PDF Editor Version: 12.0.1 Elliott Tuttle 3N-07A RWO Procedure Kuparuk Producer PTD #212-052 Page 1 of 2 Remaining Pre-Rig Work 1. T-PPPOT and T-POT tests.(passed) Completed 11/19/2022 2. RU CTU: a. Mill Magna Range plug, mid element @ 6820’ MD Completed 1/23/2022 b. Set 2.13” IBP @ 6922’ RKB, in the 4 ½” Liner, load well with seawater and freeze protect, bleed ~1800 psi and monitor pressure for 30 minutes as NFT. 3. RU SL: a. Dummy off GLM’s, lowest leak path to the IA will be the known tubing leaks, due to the patch installed in the tubing not allowing the lowest most GLM to be swapped to an OV. b. Lock out the TRMAXX SSSV 4. RU Eline: a. Cut tubing @ 6814’ MD 5. Ready well within 48 hrs of rig arrival Rig Work MIRU 1. MIRU Nabors 7ES on 3N-07A. 2. Record shut-in pressures on the T & IA. If there is pressure, bleed off IA and/or tubing pressure, circulate well over to 8.5ppg seawater and complete 30-minute NFT. Verify well is dead. 3. Set BPV and confirm as barrier if needed, ND Tree, NU BOPE and test to 250/4,000 psi. Test annular 250/3,500 psi. Retrieve Tubing, Jewelry and Seal Assembly 4. Pull BPV, MU landing joint and BOLDS. 5. Pull 3-1/2” tubing down to the tubing cut @ 6814’ MD 6. Fish tubing stub and seal assembly from SBE @ 6850’ RKB Cleanout Run 7. Perform a Cleanout run if necessary based on tubing condition. Install in 3-½” Tubing with inner plastic coating 8. MU 3 ½” completion with seal assembly, GLMs, and Nipple(s). a. Stack Packer completion will be readied as contingency if Seals do not pull. 9. Once on depth, pump CI and space out as needed. 10. Pressure test tubing to 3000 psi for 5 minutes. 11. Pressure test inner annulus to 2500 psi for 30 minutes on chart. ND BOP, NU Tree 12. Confirm pressure tests, then shear out SOV with pressure differential. 13. Install BPV. 14. ND BOPE. NU tree. 15. Pull BPV, freeze protect well, and set BPV if necessary. 16. RDMO. Post-Rig Work 17. Fish IBP, Complete Gas Lift Design 18. Return to Production 3N-07A RWO Procedure Kuparuk Producer PTD #212-052 Page 2 of 2 General Well info: Wellhead type/pressure rating: FMC Gen IV, 5K Production Engineer: Brian Lewis Reservoir Development Engineer: Kaylie Plunkett Estimated Start Date: 3/2/2023 Workover Engineer: Elliott Tuttle – 907-252-3347 elliott.tuttle@conocophillips.com Current Operations: This well is currently shut in. Well Type: Producer Scope of Work: Pull the existing 3-1/2” completion down to the seal assembly, install a new 3-1/2” completion with inner plastic coated tubing to extend the life of the well. BOP configuration: Annular / Pipe Rams / Blind Rams / Pipe Ram Following subject to change/be updated with pre-rig work: MIT results: MIT-T Failed CMIT-TxIA PASSED - 11/20/2022 MIT-OA FAILED - 8/6/2014 IC POT &PPPOT PASSED – 11/19/2022 TBG POT &PPPOT PASSED – 11/19/2022 MPSP: 3952 psi using 0.1 psi/ft gradient Static BHP: 4568 psi / 6161’ TVD measured on 6/12/2019 Last Tag Annotation Depth (ftKB) End Date Wellbore Last Mod By Last Tag: SLM 7,147.0 12/14/2014 3N-07A hipshkf Last Rev Reason Annotation End Date Wellbore Last Mod By Rev Reason: Set Magna Range Millable Plug 7/23/2020 3N-07A zembaej Casing Strings Casing Description CONDUCTOR OD (in) 16 ID (in) 15.06 Top (ftKB) 35.0 Set Depth (ftKB) 115.0 Set Depth (TVD) … 115.0 Wt/Len (l… 62.50 Grade H-40 Top Thread WELDED Casing Description SURFACE OD (in) 9 5/8 ID (in) 8.92 Top (ftKB) 37.0 Set Depth (ftKB) 3,691.4 Set Depth (TVD) … 3,610.2 Wt/Len (l… 36.00 Grade J-55 Top Thread BT&C Casing Description WINDOW A (9-5/8" csg exit) OD (in) 9 5/8 ID (in) 8.00 Top (ftKB) 2,599.0 Set Depth (ftKB) 2,616.0 Set Depth (TVD) … 2,615.4 Wt/Len (l…Grade Top Thread Casing Description PRODUCTION OD (in) 7 ID (in) 6.28 Top (ftKB) 37.3 Set Depth (ftKB) 7,040.6 Set Depth (TVD) … 6,303.4 Wt/Len (l… 26.00 Grade L-80 Top Thread BTCM Casing Description LINER OD (in) 4 1/2 ID (in) 3.96 Top (ftKB) 6,821.9 Set Depth (ftKB) 7,448.0 Set Depth (TVD) … 6,588.4 Wt/Len (l… 12.60 Grade L-80 Top Thread IBTM Liner Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 6,821.9 6,150.3 44.74 PACKER BAKER C-2 ZXP LINER TOP PACKER 5.000 6,841.6 6,164.2 44.95 HANGER BAKER HYDRAULIC FLEX LOCK LINER HANGER 5.510 6,850.2 6,170.3 45.05 SBE 80-40 SEAL BORE EXTENSION 4.750 Casing Description Window AL2 OD (in) 4 1/2 ID (in) Top (ftKB) 7,209.0 Set Depth (ftKB) 7,216.0 Set Depth (TVD) … 6,425.5 Wt/Len (l…Grade Top Thread Casing Description Window AL1 OD (in) 4 1/2 ID (in) Top (ftKB) 7,240.0 Set Depth (ftKB) 7,246.0 Set Depth (TVD) … 6,446.3 Wt/Len (l…Grade Top Thread Tubing Strings Tubing Description TUBING WO String Ma… 3 1/2 ID (in) 2.99 Top (ftKB) 22.8 Set Depth (ft… 6,873.7 Set Depth (TVD) (… 6,186.9 Wt (lb/ft) 9.30 Grade L-80 Top Connection EUE Completion Details Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Item Des Com Nominal ID (in) 22.8 22.8 0.00 HANGER TUBING HANGER 2.992 1,817.7 1,817.6 0.88 SAFETY VLV CAMCO TRMAXX-CMT SSSV X-PROFILE 2.813 6,791.3 6,128.5 44.63 NIPPLE HES 'X' NIPPLE 2.813 6,835.8 6,160.2 44.89 LOCATOR BAKER GHB-22 LOCATOR SUB 3.000 6,837.1 6,161.0 44.90 SEAL ASSY BAKER SEAL ASSEMBLY 2.990 6,873.2 6,186.5 45.30 SHOE HALF MULE SHOE 2.990 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) Top (ftKB) Top (TVD) (ftKB) Top Incl (°) Des Com Run Date ID (in) SN 6,184.0 5,691.7 40.39 TUBING LEAK LDL found Tubing Leak @6184' 8/21/2020 2.992 6,209.0 5,710.7 40.76 TUBING LEAK LOCATE LEAK WITH HOLEFINDER BETWEEN 6209 - 6215' 5/27/2016 2.990 6,222.0 5,720.5 40.95 PATCH 2.716" 20' HES PERM PATCH 12/20/2014 2.250 6,229.0 5,725.8 41.05 TUBING LEAK LDL found Tubing Leak @6229'-6230' 9/12/2014 2.992 6,602.0 5,994.2 45.06 TUBING LEAK LDL found Tubing Leak @6602' 8/21/2020 2.992 6,819.0 6,148.2 44.71 MAGNA RANGE MILLABLE BRIDGE PLUG Set 2.187 TTS Magna Range Milliable Bridge Plug (2.03' OAL) 7/23/2020 0.000 7,170.2 6,393.7 45.90 CTD LINER TOP LINER AL2-02 9/14/2012 1.920 7,204.0 6,417.2 46.11 WHIPSTOCK TTWS for 3N-07AL2 exit thru 4-1/2" liner 9/1/2012 1.000 7,238.0 6,440.7 46.26 WHIPSTOCK TTWS for 3N-07AL1 exit thru 4-1/2" liner 8/17/2012 Mandrel Inserts St ati on N o/Top (ftKB) Top (TVD) (ftKB) Make Model OD (in) Serv Valve Type Latch Type Port Size (in) TRO Run (psi) Run Date Com 1 2,639.6 2,638.8 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,328.0 1/1/2017 2 3,894.7 3,780.8 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,302.0 1/1/2017 3 4,809.6 4,546.6 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,291.0 1/1/2017 4 5,545.0 5,165.4 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.188 0.0 11/24/2019 05:30 5 6,185.9 5,693.2 CAMCO MMG 1 1/2 GAS LIFT OPEN RK 1/10/2020 1:00 6 6,735.6 6,088.8 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/13/2012 11:00 DEVIATED, 3N-07A, 8/22/2020 9:21:43 AM Vertical schematic (actual) CTD LINER TOP; 7,170.2 LINER; 6,821.9-7,448.0 Window AL1; 7,240.0-7,246.0 WHIPSTOCK; 7,238.0 LINER AL1-03; 7,229.4-8,655.0 SLOTS; 7,230.2-8,069.2 Window AL2; 7,209.0-7,216.0 WHIPSTOCK; 7,204.0 PRODUCTION; 37.3-7,040.6 MAGNA RANGE MILLABLE BRIDGE PLUG; 6,819.0 GAS LIFT; 6,735.6 TUBING LEAK; 6,602.0 PATCH; 6,222.0 TUBING LEAK; 6,229.0 TUBING LEAK; 6,209.0 GAS LIFT; 6,185.9 TUBING LEAK; 6,184.0 GAS LIFT; 5,545.0 GAS LIFT; 4,809.6 GAS LIFT; 3,894.7 SURFACE; 37.0-3,691.4 GAS LIFT; 2,639.6 WINDOW A (9-5/8" csg exit); 2,599.0-2,616.0 SAFETY VLV; 1,817.7 CONDUCTOR; 35.0-115.0 KUP PROD KB-Grd (ft) 38.49 Rig Release Date 3/7/1986 3N-07A ... TD Act Btm (ftKB) 7,450.0 Well Attributes Field Name KUPARUK RIVER UNIT Wellbore API/UWI 500292153901 Wellbore Status PROD Max Angle & MD Incl (°) 46.29 MD (ftKB) 7,233.69 WELLNAME WELLBORE3N-07 Annotation Last WO: End Date 7/21/2012 H2S (ppm) 140 Date 12/3/2016 Comment SSSV: TRDP Actual CTD SidetrackLast Update: NORTH3N-07ASOUTH18-Sep-123N-07AL1, TD at 9753' MD2Ǫ" slotted liner 8238' - 9750'Liner billet at 8238'3½" TRMAXX-CMT SSSV @ 1818' TVD (2.813" X-profile)3½", 9.3#, L-80, EUE 8rd-Mod Tubing to surface3½" Camco MMG gas lift mandrels @ 2639', 3895', 4809', 5545', 6186', & 6736'3½" HES 'X' landing nipple @ 6791' MD (2.812" min ID)Baker 80-40 seal assembly @ 6837' MD (3" ID)3½" muleshoe at 6874' MD4½" Liner topBaker 7" x 5" ZXP liner top packer at 6822' MDFlexlock liner hanger @ 6842' MDBaker 80-40 PBR 9ǫ", 36#, J-55 casing. Window cut at 2599' MD (Jun-12)7", 26 ppf, L-80, BTC-Mod at 7040' MD 4½", 12.6 ppf, L-80, IBT-Mod liner 6842'-7448' MD16", 62#, H-40 shoe @ 115' MD 3N-07AL2-01, TD @ 9191' MD2Ǫ" slotted liner 7691' - 9191'Anchor billet at 7691'3N-07AL1-02, TD at 9835' MD2Ǫ" slotted liner 7964' - 9833'Anchor billet at 7964'3N-07AL1-01, TD at 9835' MD2Ǫ" slotted liner 8129' - 9835'Liner billet at 8129'3N-07AL2, TD @ 9753' MD2Ǫ" slotted liner 9108' - 9723'Anchor billet at 9108'3N-07AL2-03, TD @ 9700' MD2Ǫ" slotted liner 7941' - 9700'Liner billet at 7941'4½" thru-tubing whipstock@ 7238' MD3N-07AL1-03, TD at 8655' MD2Ǫ" slotted liner 7230' - 8655'3N-07AL2-02, TD @ 9703' MD2Ǫ" slotted liner 7170' - 9703'4½" thru-tubing whipstock @ 7205' MD2-3/8" liner top @ 7170' MD 3N-07A Proposed RWO Completion COMPLETION INFO MD (ft RKB) TVD (ft RKB) OD (in) Nom. ID (in) Weight (lb/ft)Grade Thread (top) Thread (btm) Conductor 115 115 16 15.06 62.5 H-40 Welded Welded Surface 3691.4* 3610.2* 9 5/8 8.92 36 J-55 BTC BTC Intermediate 7040.6 6303.4 7 6.28 26 L-80 BTCM BTCM Liner 7448 6588.4 4 1/2 3.958 12.6 L-80 IBTM IBTM Tubing 6873.7 6186.9 3 1/2 2.992 9.3 L-80 EUE EUE IPC Tubing (NEW)6873.7 6186.9 3 1/2 *2.5" 9.3 L-80 EUE EUE PROPOSED COMPLETION 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-½" X landing nipple at ~500' RKB (2.813" min ID) 3-1/2" Camco MMG gas lift mandrels @ TBD 3-½" X landing nipple at xxxx' RKB (2.813" min ID) 37' Lng 80-40 Seal Assembly @ 6837' RKB REMAINING COMPLETION LEFT IN HOLE 80-40 Seal Bore Extension @ 6850' RKB Liner 4 1/2" 12/6LB/FT 6842'-7448' MD Conductor Production Casing 7" *Window cut at 2599' MD (June-12) 9 5/8" Casing NORTH 3 1/2" x 4 1/2" TTWS WS: 3N-07AL2 3N-07AL2-01 3N-07AL2-02 3N-07AL2-03 SOUTH 3 1/2" x 4 1/2" TTWS WS: 3N-07AL1 3N-07AL1-01 3N-07AL1-02 3N-07AL1-03 Originated:Delivered to:3-Mar-21 Halliburton Alaska Oil and Gas Conservation Comm. Wireline & Perforating Attn.: Natural Resource Technician Attn: Fanny Haroun 333 West 7th Avenue, Suite 100 6900 Arctic Blvd.Anchorage, Alaska 99501 Anchorage, Alaska 99518 Office: 907-275-2605 FRS_ANC@halliburton.com The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of the sender above WELL NAME API #SERVICE ORDER #FIELD NAME JOB TYPE DATA TYPE LOGGING DATE PRINTS #DIGITAL # 1 3B-06 50-029-21336-00 906905927 Kuparuk River Multi Finger Caliper Field & Processed 6-Jan-21 0 1 2 3B-06 50-029-21336-00 906953734 Kuparuk River Packer Setting Record Field- Final 1-Feb-21 0 1 3 3K-03 50-029-21602-00 906961911 Kuparuk River Multi Finger Caliper Field & Processed 9-Feb-21 0 1 4 3K-27 50-029-22751-00 906880550 Kuparuk River Packer Setting Record Field- Final 22-Dec-20 0 1 5 3M-17 50-029-21729-00 906892184 Kuparuk River Packer Setting Record Field- Final 29-Dec-20 0 1 6 3M-17 50-029-21729-00 906892184 Kuparuk River Temperature Record Field- Final 30-Dec-20 0 1 7 3N-02A 50-029-21527-01 906798653 Kuparuk River Packer Setting Record Field- Final 31-Dec-20 0 1 8 3O-20 50-029-22750-00 906941859 Kuparuk River Multi Finger Caliper Field & Processed 24-Jan-21 0 1 9 3N-07A 50-029-21539-01 906604302 Kuparuk River String Shot Record Revised 16-Jul-20 0 1 10 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Fanny Haroun, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com Date:Signed: Transmittal Date: Received by the AOGCC 03/08/2021 03/08/2021 PTD: 2120520 E-Set: 34743 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED JAN 2 2 2020 AOGCC 1. Operations Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate E❑ Alter Casing E] Change Approved Program ❑ Plug for Redrill Elerforate New Pool ❑ Repair Well LY Re-enter Susp Well ❑ Other: _Tubing patch_ 0 N Opeerator COn000PhIII1pS Alaska, Inc. Well Class Before Work: 5. Permit to Drill Number: Development ❑+ Exploratory ❑ Stratigraphic ❑ Service ❑ 212-052-0 3. Address: P. O. Box 100360, Anchorage, Alaska 6. API Number: 99510 1 50-029-21539-01 7. Property Designation (Lease Number). 8. wen Name and Number: KRU 3N -07A ADL0025521 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): Ku aruk River Field / Ku aruk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 7,450 feet Plugs measured None feet true vertical 6,590 feet Junk measured None feet Effective Depth measured 7,147 feet Packer measured 6,837 feet true vertical 6,378 feet true vertical 6,161 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 feet 15 115' MD SURFACE 3,654 feet 11 3,691' MD PRODUCTION 7,003 feet 6 7,041' MD Tubing (size, grade, measured and true vertical depth) 3.5" L-80 6,836' MD 6,160' TVD Packers and SSSV (type, measured and true vertical depth) PATCH - 2.72" P21P (CPP35031) W/ 17 6,181' MD 5,689' TVD PATCH - 2.72" P21P (CPP35172) W/ 18' 6,201' MD 5,705' TVD PATCH - 2.716" 20' HES PERM PATCH 6,222' MD 5,721' TVD SEAL ASSY- BAKER SEAL ASSEMBU 6,837'MD 6,161'TVD 12. Stimulation or cement squeeze summary: - Intervals treated (measured): n1a Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -861 Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14. Attachments (required per 20 AAC 25070.25 071,&25.283) 15. Well Class after work: Daily Report of Well Operations ❑+ Exploratory ❑ Development Q Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil Q Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. 1 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 Name: Sara Carlisle / Stephanie Pilch Authorized Name: Stephanie Pilch Contact Email: N2549@conocophillips.com Authorized Title: Well Integrity Compliance Specialist r Contact Phone: 907-659-7126 Authorized Signature: Date: 440 tin 3/t/ao RBDMSJLrUJAN 2 3 2020 Form 10-404 Revised 4/2017 Submit Original Only Date Event Summary 05/27/1 03/29/1 03/30/1 0410111 04/02/1 06/04/1 3N -07A DESCRIPTION OF WORK COMPLETED SUMMARY 3N-07A's existing retrievable tubing patch was removed so that coiled tubing could remove scale build-up in the wellbore below the tubing patch. Coiled tubing was unable to reach the desired depth so a 30 day flow test was approved then performed to see if more coiled tubing work was needed. Following the flow test, the patch was re -set to restore tubing integrity. The pertinent wellwork is copied below. Saw that fish neck of retrievable patch was damaged: RIH WITH EV CAMERA. VIDEO LOG WITH WELL STATIC, PUMPING FILTERED FRESH WATER AND FILTERED METHANOL OF THE TOP OF PATCH @ 6196' RKB. DOWNLOADED CAMERA AND GOOD VIDEO OF THE TOP OF THE PATCH. VIDEO TO BE UPLOADED FOR REVIEW. FREEZE PROTECTED TUBING AND LRS TO FREEZE PROTECT THE IA. JOB COMPLETE. D Coil milled up patch packer so patch could be removed: MIRU CT UNIT. RIH WITH VENTURI JUNK BASKET TO 6,178' CTMD TO TOP OF TUBING PATCH AT 6,196' MD. PUMP ON VENTURI. POOH RECOVER SHEAR PIN AND RUBBER PIECE. RIH WITH 2.80" OD DIAMOND BURNING SHOE. TAG AT 6175.0' CTMD. FLAG COILED TUBING. MILL TO 6176.1' CTMD. POOH. SWFN. RIH WITH 2.8" OD BURNING SHOE TAG AT 6,179.0'. CTMD. BEGIN MILLING AT 6,1797. PUMPING SLICK SEAWATER @ 1.32 BBL/MIN. MILL STALLED 15 TIMES DURING MILLING OPERATIONS. PICK UP CT AND RE-ESTABLISH PARAMETERS AND CONTINUES MILLING. MILL TO 6,179.9'. MILL WAS SPINNING. POOH FOR INSPECTION OF 2.80" OD BURNING SHOE. BREAK OFF BHA. R/D CT UNIT. BLOW DOWN CT REEL WITH HES N2 PUMP. MOVE UNIT TO KIC YARD FOR REEL SWAP. g MIRU CT UNIT. PERFORM WEEKLY BOP TEST. RIH WITH 2.80" OD PIRAHNA MILL. TAG PATCH AT 6,180.0' CTMD. MILL TO 6,181.0'. POOH. SWFN. g RIH WITH 2.8" OD PIRAHNA MILL. TAG AT 6184.0'. CTMD. BEGIN MILLING AT 6,182.5'. CTMD PUMPING SLICK SEAWATER @ 1.73 BBL/MIN. MILL TO 6,183.6'. POOH. RIH WITH VENTURI JUNK BASKET TO OF TUBING PATCH AT 6,178' CTMD. PUMP ON VENTURI. POOH. RECOVERED IN THE JUNK BASKET WAS A HAND FULL OF METAL SHAVINGS. RDMO RIH WITH 2.80" PIRANHA MILL, TAG SSSV AT 1815', PUMP UP SSSV FROM 4K TO 5.5K. RIH MADE IT BY SSSV, TAG TOP OF PACKER AT 6195' RKB, START MILLING. WE GOT SOME MOTOR RESISTANCE AND 3 STALLS NOT MAKING ANY HOLE, OOH SWAP MILLS TO A STEP MILL 1.75-2.80" PUMP AT MIN RATE TO CLEAN UP SPACER PIPE FOR THE FISHING RUN. OOH TAKE OFF STEP MILL, MAKE UP PEAK WIRELINE PULLING TOOL, RIH TAG PACKER AT 6195' RKB, LATCHED UP START JARRING, 5TH JAR HIT WE STARTED MOVING UP HOLE., WORK FISH OOH HANGING UP PERIODICALLY ON WAY OOH. RECOVERED LOWER PORTION OF PACKER AND SPACER PIPE. WELL READY FOR SLICKLINE AND SMALLER COIL. JOB IN PROGRESS 07/19/19 08/07/1 10/18/1 10/20/1 10/21/1 10/22/1 10/24/1 10/25/1 3N -07A DESCRIPTION OF WORK COMPLETED Scale remediation: RIH AND JET BLASTWITH BEADS FROM 6100' TO 6300' CTMD. CONTINUE DOWN AND JET BLAST WITH BEADS FROM 7160' TO 7687' CTMD. SAT DOWN @ 7687' CTMD AND TIMED OUT FOR STATIONARY PUMPING WITH JET BLASTER. FINAL DEPTH IS ABOVE PERFORATING INTERVALS. POOH AND JET BLAST LINER BACK UP TO 7160' WITH BEADS. CIRCULATE OUT BEADS AND FREEZE PROTECT WELL. NEED TO RE-EVALUATE JOB SINCE UNABLE TO REACH PERF DEPTHS. 9 RIH WITH 1.80" DRIFT & 1.50" JOUST NOZZLE TO 7164' CTMD RESISTANCE DEPTH (7170' RKB TOP OF 2-3/8" SLOTTED LINER). RBIH WITH 1.75" DRIFT BHA, TAG AT SAME. SUSPEND JOB FOR COIL UNIT TO DEMOB TO DEADHORSE FOR UNPLANNED MAINTENANCE. JOB IN PROGRESS. RIH WITH 1.8" GR AND SLB JET BLASTER. SAT DOWN @ 7163' CTMD (7170' RKB LINER TOP). WORK PASSED LINER TOP WHILE PUMPING BEADS @ 0.5 BPM. WORKED AREA UNTIL CLEAN ENTRY INTO LINER. CONTINUE PUMPING BEADS @ 1.0 BPM WHILE RUNNING IN LINER. TIGHT SPOTS ENCOUNTERED @ 7246', 7273', 7305'. BEAD BLASTED LINER DOWN TO HARD TAG @ 7674' CTMD. ATTEMPTED MULTIPLE TIMES TO GET DEEPER WITH NO SUCCESS. JOB IN PROGRESS, WILL COME BACK TO PERFORATE. 9 RIH WITH 2" BDN AND TAG TOP OF LINER @ 7170' RKB. PAINT WHITE FLAG AND GET DEPTH CORRECTION. RIH WITH HALLIBURTON 1.56" PERFECTA TCP, 6 SPF, 60 DEG PHASING. SAT DOWN @ 7170' RKB, LINER TOP. MAKE SEVERAL ATTEMPTS TO GET INTO LINER WITH NO SUCCESS. FREEZE PROTECT WELL. LAY DOWN FOR THE NIGHT. JOB IN PROGRESS. 9 RIH WITH HALLIBURTON 1.56" PERFECTA TCP, 6 SPF, 60 DEG PHASING UNABLE TO GET INTO LINER TOP POOH ADDED A KNUCKLE JOINT RBIH AND STILL LIABLE TO GET INTO LINER TOP. POOH M/U 1.75" STRAIGHT BARS AND A 1.75" DJN RBIH STILL UNABLE TO GET INTO THE LINER TOP POOH. PERFORM WEEKLY BOP TEST RIH W / 1.74" TAPER MILL TAGGED AT 7159.7 COME ONLINE W / PUMP SEEN A LITTLE MOTOR WORK MADE IT THRU LINER TOP RECIP UP AND DOWN SEVERAL TIMES.. TRIED TO GO THRU DRY STILL UNABLE TO GET INTO LINER BACK ONLINE W / PUMP GET INTO LINER TOP SHUT DOWN PUMP AND DRY TAGGED AT 7166' WHERE WE LEFT OFF. ORDERED GEL AND CLEANED OUT TO 7550'.PUH ABOVE LINER TOP AND TRIED A DRY RUN AND STILL TAGGING AT LINER TOP RECIP ACROSS LINER TOP SOME MORE AND MADE THRU DRY AT AVERY SLOW RUNNING SPEED 9 RAN IN HOLE W / A 2" BDN TAGGED LINER TOP PUH GOT WT BACK AND PAINTED A FLAG FOR DEPTH CORRECTION POOH. RAN IN HOLE W / HALLIBURTON PERF GUN AND WAS UNABLE TO GET IN LINER TOP. POOH M/U NZ RBIH TO FREEZE PROTECT WELL. 9 RAN IN HOLE W / HALLIBURTON 20' PERF GUN AND WAS UNABLE TO GET IN LINER TOP.RAN IN HOLE W / HALLIBURTON 10' PERF GUN AND WAS UNABLE TO GET IN LINER TOP POOH TRIED DIFFERRENT RUNNNG SPEEDS. M/U NZ RBIH TO FREEZE PROTECT WELL. 11/07/19 11/08/19 11/10/19 3N -07A DESCRIPTION OF WORK COMPLETED Got well ready for re -patch: DRIF 61" TO TOP OF PATCH @ 6222' RKB. JOB IN PROGRESS. SET K-3 PACKOFF ON TOP OF PATCH @ 6222' RKB. SET 3" SLIP STOP ON TOP OF K-3 @ 6222' RKB. PRESSURE TBG FROM 2400 PSI TO 2900 PSI, HOLDING.DEPLOY 3" AVA CATCHER. PULL DV @ 5545' RKB. READY FOR CIRC OUT, JOB IN PROGRESS. LOAD TBG & IA W/ 150 BBLS OF CISW & 70 BBLS OF DIESEL, PUMPING DOWN TBG TAKING RETURNS FROM IA. U TUBE FOR FREEZE PROTECT. ATTEMPT CMIT TO 2500 PSI, FAILED, IN PROGRESS. SUCCESS. HAD SCARRING ON THE VALVE BODY. JOB IN PROGRESS. g ATTEMPTED TO SET OV @ 5545' RKB, NO SUCCESS HAD SCARING ON THE WOBBLE RING & THE VALVE BODY. JOB IN PROGRESS. g BRUSH OPEN POCKET & SET OV @ 5545' RKB; CHECK SET TO CONFIRMED IN PLACE & PULLED AVA CATCHER @ 6222' RKB. IN PROGRESS. 11/14/19 PULLED K-3 PLUG ASSEMBLY @ 6222' RKB. JOB COMPLETE. @ 6185' RKB, PUMPED 147 BBLS INHIBITED SEAWATER W/ 700 BBLS DIESEL DOWN TBG UP IA U -TUBE FREEZE PROTECT, PULLED BAITED HOLE FINDER @ 6222' RKB, RAN CCL & 3 1/2 SLIP STOP HOLE FINDER TO 6222' RKB LOG TO 6100' RKB TIE INTO TBG TALLY SET HOLE FINDER (ME) @ 6181' RKB, MIT TBG 3000 PASS. IN PROGRESS.MITT T/I/0= 2125/2125/120, PRESSURE TBG UP (.1 BBL) T/I/0= 3025/2125/120, 15 MIN T/1/0= 3025/2125/120, 30 MIN T/I/0= 3025/2125/120 'PASS" 01/1 3N -07A DESCRIPTION OF WORK COMPLETED (2.25") (OAL 25.57'/ SN: CPP35173), SET 3 1/2 TTS TEST TOOL @ 6201' RKB, CMIT TBG x IA 3000 PSI PASS, PRE CMIT T/I/0= 2200/2125/80, PRESSURE UP (.8 BBLS) T/I/0= 3050/3000/80, 15 MIN T/1/0= 3050/3000/80, 30 MIN T/1/0= 3050/3000/80 ""PASS'*" PULLED 3 1/2 TTS TEST TOOL @ 6201' RKB, SET UPPER 2/72" P2P SPACER & ANCHOR LATCH @ 6180.72' RKB (ME) (OAL 22.53' / SN: CPP35031 / CPAL35012), GOOD DRAW DOWN TEST ON IA FROM 2125 TO 1000 PSI, SET 3 1/2 TTS TEST TOOL IN 2.72" P2P @ 6180.72' RKB. IN PROGRESS. LRS: MIT TBG POST RELAY PATCH WORK, TBG PASSED @ 3000PSI, BLEED BACK TO 2150, (STARTING PSI) PREFORM MIT TBG TO 3000PSI, (PASS) PRE/ST115MIN/30MIN TBG 2150/3040/3010/3000 IA 1040/1060/1060/1060 OA 70/70/70/70 TOOK .2BBLS DSL TO PRESSURE UP BLEED BACK SAME DWN TO 2150PSI 01/121201 PULLED 3 1/2 TTS TEST TOOL @ 6181' RKB. JOB COMPLETE. 01/16/20 (AC EVAL) RE-TIFL (PASSED). ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 January 20, 2020 Commissioner Jessie Chmielowski Alaska Oil and Gas Conservation Commission 333 West 7 1 Avenue, Suite 100 Anchorage, AK 99501 Commissioner Chmielowski, Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well KRU 3N -07A (PTD 212-052) for tubing patch re -set. Please contact me or Sara Carlisle at 659-7126 if you have any questions. Sincerely, /d' `/ Stephanie Pilch Well Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. P77) 212-057— Loepp, 12-os2- Loepp, Victoria T (CED) From: Schwartz, Guy L (CED) Sent: Tuesday, November 12, 2019 4:42 PM To: Loepp, Victoria T (CED) Subject: RE: KRU 3N-07 (PTD# 212-052) Request for a Production Test with TAA Follow Up Flag: Follow up Flag Status: Flagged Got it done.. Q Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office 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 Guy Schwartz at (907-793-1226 ) or (Guv.schwartz®alaska.aov). From: Loepp, Victoria T (CED) <victoria.loepp@alaska.gov> Sent: Tuesday, November 12, 2019 3:21 PM To: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Subject: Fwd: KRU 3N-07 (PTD# 212-052) Request for a Production Test with TxIA Guy, Please handle. I would approve it. Thx Sent from myiPhone Begin forwarded message: From: Well Integrity Compliance Specialist WNS & CPF3 <n2549@conocophillips.com> Date: November 12, 2019 at 11:31:06 AM PST To: "Loepp, Victoria T (CED)" <victoria.loepp@alaska.xov> Cc: CPA Wells Supt <n1030@conocophillips.com> Subject: KRU 3N-07 (PTD# 212-052) Request for a Production Test with TxIA Victoria, KRU 3N-07 (PTD# 212-052) is a producer that was previously patched to repair TxIA communication. Due to decreased production, the tubing patch was removed to allow downhole coil work to be performed in the lower wellbore, which would have consisted of new perforations in the liner. Coil was able to clean out the liner but was unable to get through the liner with the pert guns and now CPAI is reconsidering if new perfs and further coil is necessary or if the clean out of the liner will be enough to increase production. To confirm if production has increased sufficiently or further coil work is required, CPA] requests permission to perform a production test with gas lift for up to 30 -days without a patch over the known TxIA: The well passed a CMIT-TxIA to 2510 psi on 11/11/2019. Please let us know if you agree with this plan. Regards, Paul Duffy for Rachel Kautz/Sara Carlisle Wells Integrity & Compliance Specialist ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 WELLS TEAM CMDCA MPs • • pi-0 .7/2— D3-2— Loepp, ZLoepp, Victoria T (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Wednesday, May 30, 2018 8:18 AM To: Loepp,Victoria T(DOA) Cc: Senden, R.Tyler Subject: KRU 3N-07A(PTD#212-052) Follow Up Flag: Follow up Flag Status: Flagged Hello Victoria— Kuparuk gas lifted producer 3N-07A(PTD#212-052) has been shut-in due to downhole scale issues. Recently,the IA pressure increased above the DNE of 2000 psi. The IA reached approximately 2350 psi. The production casing is 7", 26 lb, L-80 pipe and has a burst pressure rating of 7240 psi. At this point,the IA has not exceeded 45%of the burst pressure rating. CPAI will monitor the IA pressure and attempt troubleshooting work as soon as possible. Please let re know if you have any questions or disagree with this plan. Thanks, Travis Smith/Rachel Kautz Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 SCANNED JUN 1 a al 1 • • .2/2- - 5 2, Loepp. Victoria T (DOA) From: NSK Well Integrity Supv CPF3 and WNS <n2549@conocophillips.com> Sent: Thursday, May 04,2017 11:13 AM To: Loepp,Victoria T(DOA) Cc: Senden, R.Tyler Subject: KRU 3N-07 (PTD#212-052) High IA pressure Attachments: 3N-07 90-day 110 plot.docx Follow Up Flag: Follow up Flag Status: Flagged Victoria, Kuparuk gas lifted producer 3N-07(PTD#212-052) has been shut-in due to a suspected ice plug in the tubing. Recently, the IA pressure increased above the DNE of 2000 psi. The IA reached approximately 2150 psi and was subsequently bled down by operations. The production casing is 7",26 lb, L-80 pipe and has a burst pressure rating of 7240 psi. At this point,the IA has not exceeded 45%of the burst pressure rating. CPAI will monitor the IA pressure and investigate the high IA pressure once the ice plug is removed. Please let me know if you have any questions or disagree with this plan. Attached is a 90 day TIO plot. Regards, Rachel Kautz/Travis Smith Well Integrity Supervisor,ConocoPhillips Alaska Inc. Office:907-659-7126 Cell:907-943-0450 1 STATE OF ALASKA ALA.OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing fl Operations shutdow n r Performed: Suspend r Perforate r Other Stimulate r" Alter Casing r Change Approved Program r Plug for Redrill r Perforate New Pool r Repair Well Re-enter Susp Well r Other: Tubing patch 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development 17 Exploratory "'" 212-052-0 3.Address: 6.API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic " Service 50-029-21539-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0025521 KRU 3N-07A 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 7450 feet Plugs(measured) None true vertical 6590 feet Junk(measured) None Effective Depth measured 7204' feet Packer(measured) 6196, 6222, 6836 true vertical 6417 feet (true vertical) 5701, 5721, 6160 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80' 16 115' 115' 'ED-WINDOW A(9-5/8' 17' 9 5/8 2616' 2615' SURFACE 3654' 9 5/8 3691' 3610' PRODUCTION 7003' 7 7041' 6303' WINDOW WINDOW AL2 7' 4 1/2 7216' 6426' WINDOW AL1 6' 4 1/2 7246' 6446' .OG ,„; Perforation depth: Measured depth: 8247-8684,8698-9740,8138-8374,8389-9835,7975-8245,8259-9832,7230-8069,8084-8655,9119-9723,7703 True Vertical Depth: 6405-6404,6403-6367,6405-6391,6390-6348,6433-6388,6385-6302,6435-6433,6433-6419,6447-6447,6486 Tubing(size,grade,MD,and TVD) 3 1/2 ,L-80, 6836 MD,6160 TVD Packers&SSSV(type,MD,and TVD) SAFETY VLV=CAMCO TRMAXX-XMT SSSV X-PROFILE 07131.8''M D and 1818 TVD PATCH =2.725" P2P PACKER PATCH ASSEMBLY STUNG IN TO PERM PATCH @ 6122' RKB(TOP OF PATCH =2.716"20' HES PERM PATCH @ 6222 MD and 5721 TVD LOCATOR=BAKER GHB-22 LOCATOR SUB @ 6836 MD and 6160 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): �)J r Treatment descriptions including volumes used and final pressure: scANNEu t . . ( iy 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 17 Exploratory r Development P- Service fl Stratigraphic Copies of Logs and Surveys Run16.Well Status after work: r Oil Gas fl WDSPL Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r' GINJ fl SUSP fl SPLUG 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 Jan Byrne/Dusty Freeborn Email: n1617(&,conocophillips.com Printed Name Jan Byrne Title: Problem Wells Supervisor Signature Phone:659-7126 Date 9-24-16 VTL l6/IWI(, Form 10-404 Revised 5/2015 , lg4(fi RBDMS LA S2 2 8 2016 Submit Original Only • ConocoPhillips qECEWED Alaska 2 7 2016 P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 A OGGC September 24th, 2016 Ms. Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Dear Commissioner Foerster, Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well KRU 3N-07A (PTD 212-052) for tubing patch repair. Please call Dusty Freeborn or myself at 659-7126 or Brent Rogers/Kelly Lyons at 659- 7224 if you have any questions. Sincerely, Jan Byrne Problem Wells Supervisor Attachments • • 3N-07A DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary Operations reported that the gaslift pressure was exhibiting anomalous swings while on production. Diagnostics showed that the recently installed K-3 patch had failed and was the cause of the pressure swings. The K-3 patch was pulled and a 29' long patch stinging into the perm patch at 6222'to use as the lower seal and utilizing a Paragon II Packer as the upper seal was set. Post patch MIT-T against the upper packer and TIFL both passed proving integrity. The installation work and testing is pasted below. 9/18/2016 SET 2.725" P2P PACKER PATCH ASSEMBLY STUNG IN TO PERM PATCH @ 6222' RKB (TOP OF PATCH @ 6195.8' RKB/MIN ID 1.25"/OAL = 29.20 ) MITT TBG TO 3000 PSI PASS) DDT ON IA( PASS); JOB COMPLETE. T/I/O/FL =2350/1050/70/125 PT TBG TO 3000 PSI W/TRIPLEX. START= 3000/1060/70/175 15 MINS = 2950/1060/70/175 30 MINS = 2900/1060/70/175 RETEST. START= 3025/1060/70/175 15 = 3000/1060/70/125 30 MINS = 3000/1060/70/125 PASS. 9/23/2016 (AC EVAL) : TIFL POST PATCH (PASSED). Initial T/I/O = 175/575/165. IA FL @ 4810' (st#3, OV). S/I WV& double block AL line. Stacked WHP's to T/I/O = 550/520/118 in 20 min. IA FL @ same location. Bled AL line to 120 psi. Bled IA to 190 psi in 50 min T/I/O = 700/190/90. IA FL @ 4810' (same location). T FL @ 2406'. Monitor for 1 hour. 15 min T/I/O = 760/190/75. 30 min T/I/O = 800/190/60. IA FL @ same location. 45 min T/I/O = 850/190/45. 60 min T/I/O = 900/190/45. IA FL @ same location. Final T/I/O = 900/190/45. KUP PROD 0 3N-07A ConocoPhillips a „, Well Attributes Max Angle&MD TD Alaska,Inc. Wel!bore API/UWI Field Name Wellbore Status ncl 7) MD(ftKB) Act Bim(10KB) v aip'^ 500292153901 KUPARUK RIVER UNIT PROD 46.29 7,233.69 7,450.0 ... Comment H2S(ppm) Date Annotation End Date KBGrd(ft) Rig Release Date L EVIATEr-3N-07A,9/21/20162:3241 PM SSSV:TRDP 160 12/14/2015 Last WO: 7/21/2012 38.49 3/7/1986 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date -- - Last Tag:SLM 7,147.0 12/14/2014 Rev Reason:PULLED PATCH&SET P2P pproven 9/21/2016 PATCH Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread 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(TVD)...WI/Len(I...Grade Top Thread et 'l�SURFACE 95/8 8.921 37.0 3,691.4 3,610.2 36.00 J-55 BT&C Casing Description 'OD NO ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)TVD)...Wt/Len(I...Grade Top Thread I WINDOW A(9-5/8"csg 9 5/8 8.000 2,599.0 2,616.0 2,615.4 exit) `--..Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WULen(I...Grade Top Thread CONDUCTOR;35.0-115.0 „ PRODUCTION 7 6.276 37.3 7,040.6 6,303.4 26.00 L-80 BTCM Casing Description OD(in) ID(in) Top ORB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SAFETY VLv;1,617.7 LINER 1 41/2 3.958 6,821.9 7,448.0 6,588.4 12.60 L-80 IBTM Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Ind 7) Item Des Com (in) 6,821.9 6,150.3 44.74 PACKER BAKER C-2 ZXP LINER TOP PACKER 5.000 6,841.6 6,164.2 44.95 HANGER BAKER HYDRAULIC FLEX LOCK LINER HANGER 5.510 WINDOW A(9-5/8"csg exit); A , 6,850.2 6,170.3 45.05 SBE 8040 SEAL BORE EXTENSION 4.750 2,599.0-2,616.0 Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread Window AL2 41/2 7,209.0 7,216.0 6,425.5 GAS LIFT;2,639.6 - Casing Description OD(in) ID(in) Top(ftKB) Set Depth(eKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread Window AL1 41/2 7,240.0 7,246.0 6,446.3 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(TVD)(...Wt(Ib/ft) Grade Top Connection TUBING WO 31/2 2.992 22.8 6,873.7 6,186.9 9.30 L-80 EUE Completion Details Nominal ID Top(ftKB) Top(NO)(ftKB) Top Incl(.1_ Item Des Com (in) 22.8 22.8 0.00 HANGER TUBING HANGER 2.992 SURFACE;37.0-3,691.4-- w 1,817.7 1,817.6 0.88 SAFETYVLV CAMCO TRMAXX-XMT SSSV X-PROFILE 2.813 6,791.3 6,128.5 44.63 NIPPLE HES'X'NIPPLE 2.813 GAS LIFT;3,894.7 ,s 6,835.8 6,160.2 44.89 LOCATOR BAKER GHB-22 LOCATOR SUB 3.000 6,837.1 6,161.0 44.90 SEAL ASSY BAKER SEAL ASSEMBLY 2.990 -- 6,873.2 6,186.5 45.30 SHOE HALF MULE SHOE 2.990 GAS LIFT;4,809.6 i Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Intl Top(ftKB) (ftKB) (`) Des Com Run Dale ID(in) 6,195.8 5,700.7 40.57 PATCH 2.725"P2P PACKER PATCH ASSEMBLY STUNG 9/18/2076 1.250 GAS LIFT;5,545.0 IN TO PERM PATCH @ 6122'RKB(TOP OF ilMi PATCH @ 6195.8'RKB I MIN ID 1.25"/OAL= 29.20) III6,222.0 5,720.5 40.95 PATCH 2.716"20'HES PERM PATCH 12/20/2014 2.250 GAS LIFT;6,185.9 lir7,204.0 6,417.2 46.11 WHIPSTOCK TTWS for 3N-07AL2 exit thru 4-1/2"liner 9/1/2012 1.000 7,238.0 6,440.7 46.26 WHIPSTOCK TTWS for 3N-07AL1 exit thru 4-1/2"liner 8/17/2012 PATCH;6,195.8 Mandrel Inserts St PATCH;6,222.0 ati on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(In) Sere Type Type (In) (psi) Run Date Com -1' 2,639.6 2,638.8 CAMCO MMG 11/2 GAS LIFT GLV RK 0.188 1,248.0 11/14/2012 1:30 GAS LIFT;6,735.6 L._.. 2 3,894.7 3,780.8 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,249.0 8/17/2014 2:00 3 4,809.6 4,546.6 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.250 0.0 7/3/2016 NIPPLE;6,791.3 4 5,545.0 5,165.4 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 11/14/2012 5:30 Mr 5 6,185.9 5,693.2 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 11/14/2012 1:00 am EC Er 6 6,735.6 6,088.8 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/13/2012 11:00 LOCATOR;6,835.8 N] = CSA Notes:General&Safety 1 11 End Date Annotation SEAL ASSY;6,837.1 F 9/15/2012 NOTE:ADDED LATERALS ALI,AL1-01,AL1-02,AL1-03,AL2,AL2-01,AL2-02,AL2-03 `,.I SHOE;6,873.2 ir PRODUCTION;37.3-7,040.6 WHIPSTOCK:7,204.0 I WlndowAL2;7,209.0-7,218.0 SLOTS;7,230.2-8,089.2 _ ill LINER AL1-03;7,229A-8,655.0L..WHIPSTOCK;7,238.01 WindowAL1;7,240.0-7,246.0 ` LINER;6,821.9-7,448.0 RECEIVED III STATE OF ALASKA • JUL 19 2016 ' ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS AfGCC 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Opera ions shutdown r Performed: Suspend r Perforate r Other Stimulate Alter Casin p r 9 r Change Approved l,VProl ram Rug for Redrill r Perforate New Pool r Repair Well p Re-enter Susp Well r Other: t t V 12 r<t 'L 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: _ConocoPhillips Alaska,Inc. Development 17 Exploratory r 212-052-0 3.Address: 6.API Number: Stratigraphic r Service r P.O.Box 100360,Anchorage,Alaska 99510 50-029-21539-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL028281 KRU 3N-07A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): NA Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 7450 feet Plugs(measured) None true vertical 6590 feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) 6200,6222,6222,6791,6837 true vertical 0 feet (true vertical) 5704,5721,5721,6129,6161 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 115 115' WINDOW A(9-5/1 17 9.625 2616 2615' SURFACE 3654 12 3691 3610' PRODUCTION 7003 7 7041 6303' LINER 626 7.6 7448 6588' Perforation depth: Measured depth: 8247-8684,8698-9740,8138-8374,8389-9835,7975-8245,8259-9832,7230-8069,8084-8655,9119- 9723,7703-8035,8050-9191,7171-7742,7757-9703,7960-8028,8042-9248,9262-9700 True Vertical Depth: 6405-6404,6403-6367,6405-6391,6390-6348,6433-6388,6385-6302,6435-6433,6433-6419,6447- 6447,6486-6442,6440-6429,6394-6484,6484-6499,6455-6453,6453-6437,6436-6448 Tubing(size,grade,MD,and TVD) 3.5,L-80,6836 MD,6160 TVD Packers&SSSV(type,MD,and TVD) SAFETY VLV-CAMCO TRMAXX-XMT SSSV X-PROFILE @ 1818 MD and 1818 TVD SLIP-STOP-3 1/2"SLIPSTOP ON K3 PATCH @ 6200 MD and 5704 TVD PATCH-24'1"X 2.78"K3 PATCH ASS'Y IN HES PERM PATCH(1.25'4B)-©,6422,p4D and 5721 TVD PATCH-2.716"20'HES PERM PATCH @ 6222 MD and 5721 TVD NIPPLE-HES'X'NIPPLE @ 6791 MD and 6129 TVD SEAL ASSY-BAKER SEAL ASSEMBLY @ 6837 MD and 6161 TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): p JAN descriptions including volumes used and final pressure: SCANNED 3 1 2017 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,&25.283) 15.Well Class after work: Daily Report of Well Operations r Exploratory r Development J Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil 17 Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Dusty Freeborn/Jan Byrne 659-7126 Email: N1617(c�conocophillips.com Printed Name Dust Freeborn Title: Well Integrity Supervisor Signature �� Phone:659-7126 Date:7/17/16 Form 10-404 Revised 5/2015 J/ Submit Original Only /71 RBDMS w JUL 2 2 2016 • . �► WD ConocoPhillips JUL 19 2016 Alaska P.O. BOX 100360 AOGCC ANCHORAGE,ALASKA 99510-0360 17th day of July 2016 Ms. Cathy Foerster Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Ms. Foerster, Enclosed please find the 10-404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well KRU 3N-07A PTD 212-052 for a tubing patch set. A retrievable tubing patch was set above the existing permanent patch using the upper section of the permanent patch as the lower anchor and sealing assembly. The newly set patch acts as an extension to the existing permanent patch. Please call Jan Byrne or myself if you have any questions. Regards, t/410 Dusty Freeborn/Jan Byrne Problem Wells Supervisor ConocoPhillips Alaska, Inc. Office phone: (907) 659-7126 Cell phone: (907) 943-0450 3N-07A DESCRIPTION OF WORK COMPLETED SUMMARY A B 1 2 Date Event Summary 3 4 05/27/16 Reported to AOGCC for SCP of IA. Hole finder identified leak between 6,209'-6,215'. 5 6 05/29/16 Production casing and packer proven with passing CMIT-TxIA to 2500 psi. 7 07/09/16 Set patch using upper section of existing permanent patch at 6,222' as lower anchor and 8 sealing surface, spacer pipe and upper K3 packer and slip stop at 6,200'. Passed IA DDT. 9 10 07/15/16 Passed TIFL to prove integrity of patch. 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 KUP PROD • 3N-07A ConocoPhillips ii Well Attributes iMax Angle&MD TD Alaska,IOC. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Blot(ftKB) crraocr+lepc 500292153901 KUPARUK RIVER UNIT PROD 4629 7,233.69 7,450.0 r ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date DEVIATED-3N-07A,7/12/20164'.52:56 PM SSSV:TRDP 160 12/14/2015 Last WO: 7/21/2012 38.49 3/7/1986 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date - --HANGER;22.e -- -----Last Tag:SLM 7,147.0 12/14/2014 Rev Reason:H2S,SET PATCH&GLV C/O pproven 7/12/2016 Casing Strings Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread 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(TVD)...Wt/Len(I...Grade Top Thread SURFACE 9 5/8 8.921 37.0 3,691.4 3,610.2 36.00 J-55 BT&C B a. Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread WINDOW A(9-5/8"csg 9 5/8 8.000 2,599.0 2,616.0 2,615.4 exit) A.A./s ..�Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WI/Len(I...Grade Top Thread CONDUCTOR;35.0-115.0 ,. PRODUCTION 7 6.276 37.3 7,040.6 6,303.4 26.00 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread SAFETY VLV;1,817.7-4AILINER 41/2 3.958 6,821.9 7,448.0 6,588.4 12.60 L-80 IBTM SAFETY VLV;1,817.7 Liner Details Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°I Item Des Com (In) 6,821.9 6,150.3 44.74-PACKER BAKER C-2ZXP LINER TOP PACKER 5.000 6,841.6 6,164.2 44.95 HANGER BAKER HYDRAULIC FLEX LOCK LINER HANGER 5.510 WINDOW A(9-5/8"csg exit); 4 2,599.0-2,616.0 6,850.2 6,170.3 45.05 SBE 80-40 SEAL BORE EXTENSION 4.750 Casing Description OD(In) ID(In) `Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread GAS LIFT;2,639.6---1._4Window AL2 41/2 7,209.0 7,216.0 6,425.5 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread Window AL1 41/2 7,240.0 7,246.0 6,446.3 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING WO 3 1/2 2.992 22.8 6,873.7 6,186.9 9.30 L-80 EUE f Completion Details SURFACE;37.0-3,891.4-' Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com Nominal I ID 1 22.8 22.8 0.00 HANGER TUBING HANGER 2.992 GAS LIFT;3,894.7 .1 1,817.7 1,817.6 0.88 SAFETY VLV CAMCO TRMAXX-XMT SSSV X-PROFILE 2.813 2.813 6,791.3 6,128.5 44.63 NIPPLE HES'X'NIPPLE 6,835.8 6,160.2 44.89 LOCATOR BAKER GHB-22 LOCATOR SUB 3.000 GAS LIFT;4,809.6 6,837.1 6,161.0 44.90 SEAL ASSY BAKER SEAL ASSEMBLY 2.990 6,873.2 6,186.5 45.30 SHOE HALF MULE SHOE 2.990 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl GAS LIFT;5,5459 Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 6,200.0 5,703.8 40.63 SLIP-STOP 3 1/2"SLIPSTOP ON K3 PATCH 7/9/2016 0.000 6,222.0 5,720.5 40.95'PATCH 2.716"20'HES PERM PATCH 12/20/2014 2.420 GAS LIFT;6,165.9 - 6,222.0 5,720.5 40.95 PATCH 24'1"x 2.78"K3 PATCH ASS'Y IN HES PERM 7/9/2016 1.250 PATCH(1.25"ID) 7,204.0 6,417.2 46.11 WHIPSTOCK TTWS for3N-07AL2 exit thru 4-1/2"liner 9/1/2012 1.000 SLIP-STOP;6,200.0-- _ 7,238.0 6,440.7 46.26 WHIPSTOCK TTWS for3N-07AL1 exit thru 4-1/2"liner 8/17/2012 PATTCHCH:8,222.0,0"h - PA ;Q222 - Mandrel Inserts St ati on Top(TVD) Valve Latch Port Size TRO Run GAS LIFT;6,735.6 N Top(ftKB) (ftKB) Make Model 0D(in) Sery Type Type (in) (psi) Run Date Com i'' 2,639.6 2,638.8 CAMCO MMG 11/2 GAS LIFT GLV RK 0.188'1,248.0 11/14/2012 1:30 2" 3,894.7 3,780.8 CAMCO MMG 11/2 GAS LIFT GLV RK 0.188'1,249.0 8/17/2014 2:00 NIPPLE;6,791.3 3' 4,809.6 4,546.6 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.250' 0.0 7/3/2016 I 4 5,545.0 5,165.4 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000" 0.0 11/14/2012 5:30 - 5" 6,185.9 5,693.2 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000' 0.0 11/14/2012 1:00 i5' I88 LOCATOR;6,835.8 1.s Ink 6 6,735.6 6,088.8 CAMCO MMG 11/2 GAS LIFT DMY RK 0.000 0.0 11/13/2012 11:00 It Notes:General&Safety SEAL ASSY;6,837.1 i s,. End Date Annotation 9/15/2012 NOTE:ADDED LATERALS AL1,AL1-01,AL1-02,AL1-03,AL2,AL2-01,AL2-02,AL2-03 SHOE;6,873.2 III J PRODUCTION;37.3-7,040.6-, WHIPSTOCK;7,204.0 Window AL2;7,209.0-7,218.0 SLOTS;7.230.2-8,0892 LINER AL1-03;7,229.4-8,655.0 WHIPSTOCK;7.238.01 WindowAL1;7,240.0-7,246.0 LINER;6,821.9-7,448.0 • P ?D Z/Z —oSZ Loepp, Victoria T (DOA) From: NSK Problem Well Supv <n1617@conocophillips.com> Sent: Friday, May 27,2016 2:56 PM To: Loepp,Victoria T(DOA) Cc: Senden, R.Tyler; NSK Problem Well Supv Subject: 3N-07(PTD#212-052) Report of SCP Attachments: 3N-07A.pdf; 3N-07 90 Day TIO plotJPG Follow Up Flag: Follow up Flag Status: Flagged Victoria- Kuparuk Producer 3N-07(PTD#212-052) has exceeded the DNE of 2000 psi on the IA. Operations attempted to bleed the IA but it continued to show build up. S-line is currently on the well and suspects the leak to be just above the existing tubing patch. Diagnostics will continue to narrow down the leak point and depending on the repair options the well maybe set up for a secure to manage the IA pressure until the repair can occur. The production casing is 7" 26 lb L- 80 pipe which has a burst rating of 7240 psi. At this point in time the IA has not exceeded 2100 psi. Please let me know if you have any questions or disagree with the plans. Attached is a well bore schematic and 90 day TIO plot. Dusty Freeborn/Jan Byrne Well Integrity Supervisor ConocoPhillips Alaska, Inc. Office phone: (907)659-7126 Cell phone: (907)943-0450 4WELLS TEAM eonocas SCANNED FEE . 0 2GLL, No CD # CD CD 71 CO CD C7 --I Z I G O ' ' -nT I.., I, I . 1 . I 11 i I a I,„ I. ii 1 . 1 . 1 , 1 .1 II I I. I I I I 1 111 : : . ro -- : ti : : - T, 1 : 73 7 ' ._.s _ • OD : . 1 _ 0 _ I . . li 0 - - MU S7 +'"'11" m - • : : N Ns.) _ . '. . _ ^�.� li : : . z YI • : : co — i - -r S I aii . • •: : : SII ' _,..r't) . ii P PROD 3N-07A ConocoPhillips Well Attributes • Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status Incl(°) MD(ftKB) Act Btm(ftKB) ores,s hiiips 500292153901 KUPARUK RIVER UNIT PROD 46.29 7,233.69 7,450.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date DEVIATED-3N-07A,12/21/2014 2:42:36 PM SSSV:TRDP 100 10/3/2013 Last WO: 7/21/2012 38.49 3/7/1986 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;22.8 Last Tag:SLM 7,147.0 12/14/2014 Rev Reason:SET PATCH,REMOVE WAIVER hipshkf 12/21/2014 t@G]l Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread 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)... WULen(I...Grade Top Thread I+ SURFACE 9 5/8 8.921 37.0 3,691.4 3,610.2 36.00 J-55 BT&C ,,xnmuuuauuwuu x a,,nmwxu011exxu IIIl � I ur Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(L..Grade Top Thread �I ll WINDOW A(9-5/8"csg 9 5/8 8.000 2,599.0 2,616.0 2,615.4 exit) ..ice Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(L..Grade Top Thread CONDUCTOR;35.0-115.0 PRODUCTION 7 6.276 37.3 7,040.6 6,303.4 26.00 L-80 BTCM Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread -- LINER 4 1/2 3.958 6,821.9 7,448.0 6,588.4 12.60 L-80 IBTM SAFETY VLV;1,817.7 /!i_i' Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 6,821.9 6,150.3 44.74 PACKER BAKER C-2 ZXP LINER TOP PACKER 5.000 6,841.6 6,164.2 44.95 HANGER BAKER HYDRAULIC FLEX LOCK LINER HANGER 5.510 WINDOW A(9-5/8"csg exit); Al 2,599.0-2,616.0 6,850.2 6,170.3 45.05 SBE 80-40 SEAL BORE EXTENSION 4.750 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(i...Grade Top Thread GAS LIFT;2,639.6 l Window AL2 4 1/2 7,209.0 7,216.0 6,425.5 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread Window AL1 41/2 7,240.0 7,246.0 6,446.3 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft.. Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING WO I 3 1/21 2.9921 22.8) 6,873.71 6,186.91 9.30 L-80 EUE Completion Details Nominal ID SURFACE;37.0-3,691.4 A 41. Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 22.8 22.8 0.00 HANGER TUBING HANGER 2.992 1,817.7 1,817.6 0.88 SAFETY VLV CAMCO TRMAXX-XMT SSSV X-PROFILE 2.813 GAS LIFT;3,894.7 6,791.3 6,128.5 44.63 NIPPLE HES'X'NIPPLE 2.813 6,835.8 6,160.2 44.89 LOCATOR BAKER GHB-22 LOCATOR SUB 3.000 6,837.1 6,161.0 44.90 SEAL ASSY BAKER SEAL ASSEMBLY 2.990 GAS LIFT;4,809.6 - 6,873.2 6,186.5 45.30 SHOE HALF MULE SHOE 2.990 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) GAS LIFT;5,545.0 r 6,222.0 5,720.5 40.95 PATCH 2.716"20'HES PERM PATCH 12/20/2014 2.420 7,204.0 6,417.2 46.11 WHIPSTOCK TTWS for 3N-07AL2 exit thru 4-1/2"liner 9/1/2012 1.000 7,238.0 6,440.7 46.26 WHIPSTOCK TTWS for 3N-07AL1 exit thru 4-1/2"liner 8/17/2012 GAS LIFT;6,185.9 Mandrel Inserts St ati PATCH;6,222.0 on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Corn 1 2,639.6 2,638.8 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,248.0 11/14/2012 1:30 GAS LIFT;6,735.6 2 3,894.7 3,780.8 CAMCO MMG 1 1/2 GAS LIFT GLV RK 0.188 1,249.0 8/17/2014 2:00 3 4,809.6 4,546.6 CAMCO MMG 1 1/2 GAS LIFT OV RK 0.250 0.0 8/18/2014 9:00 4' 5,545.0 5,165.4 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/14/2012 5:30 NIPPLE;6,791.3 5 6,185.9 5,693.2 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/14/2012 1:00 6 6,735.6 6,088.8 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/13/2012 11:00 INotes:General&Safety LOCATOR;6,835.8 �- End Date Annotation II 1`, 9/15/2012 NOTE:ADDED LATERALS AL1,AL1-01,AL1-02,AL1-03,AL2,AL2-01,AL2-02,AL2-03 lirit SEAL ASSY;6,837.1 Mil , 0 s • aI SHOE;6,873.2 rn 9 I I ca- 4 0 a) -- el kr) O U Z C C T -C a) _• U II 2 EWs E N csi a. 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C OI N ' 10 �// Q 0 C O o 0 a - o Q = c Ya)- al o a`� Q c a <c 2- a O I Z E r > Ci 115 0 U 0 a 111 E as Z I II N_ N_ O I IO O I a) aa) Z N N co 1' o N 6N N Q C N g m co O o O , 0 � 3 N O N •> a ce Nd m U 0 ai c aoo▪ o • � m ^ oFo Qoa U oam n u E Z. v a) a O 2o m ¢ E o E E E a) 2 O n. 0 U 0 C O U U McMains, Stephen E (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday, August 27, 2013 9:28 AM To: Myers, Monty M Cc: McMains, Stephen E (DOA) Subject: RE: 3N-07A (PTD 212-052) Monty, Thanks for the schematics... The CBL is a mystery still .. the one attached is for the original well before sidetracking. The 10-407 for 3N-07A lists a CBL was run (box 21) .... I don't know if it ever was or not but since it is listed it is non-compliant until it is resolved. Can you also make sure that all logs that were run are listed in Box 21 on the 10-407. There are many missing (gamma ray, resistivity) from this 10-407 ... Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office From: Myers, Monty M [mailto:Monty.M.Myers@conocophillips.com] Sent: Friday, August 23, 2013 10:58 AM To: Schwartz, Guy L (DOA) Subject: RE: 3N-07A (PTD 212-052) Guy, CTD drilled 8 laterals off of the Sidetrack well I installed for them back in August of last year. Attached is the CBL for 3N-07, and a CTD schematic. Also attached is a very rough sketch of the sidetrack portion of the well. Thanks! Monty M Myers Wells Engineer ConocoPhillips Alaska 907.265.6318 office 907.538.1168 cell From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Thursday, August 22, 2013 3:55 PM To: Myers, Monty M Subject: [EXTERNAL]RE: 3N-07A (PTD 212-052) We don't have the CBL on file either. Need copy Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office From: Schwartz, Guy L (DOA) Sent: Thursday, August 22, 2013 3:50 PM To: Myers, Monty M Subject: 3N-07A (PTD 212-052) I am looking at the 10-407. Not sure when CTD will get on this well to do laterals. Do you have a better diagram than "Wellview" for the well sketch? It shows surface casing with the window above which is very misleading since you sidetracked out of the surface casing and left 7" sticking up inside. Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office 2 N a U) .1 b CI IH- H I- a ❑ ayryryQ p . es .i a0 _ 00 x]� a V C J O A® ZV X N E Q � QQ `, co m ❑ Z ❑ lq F N 3 -c93 co - - co I- m N N 0 N 0 co 1117--- O) @ 2 -Co a a rn m❑ P+ CO O U . S D Ud o m d(J a�N Ep > E i, a� o� % Z co a E v7 co .N .0 N: y 1111/0040, Q❑ .. F- ❑ a O) ita a^0 C N N 2 C c0 co a O) O 6 XX � X ccoo 2m co m o nNLa g ��� Q/m� J O m O L O In N Oa` lJ U O X x C V.' V O \ O - coO M co°� W co 7 C i�V co N c co ❑ I- rn CJ 2 a) E J d O a) N 0,5 o M m M co m a0 m R I:0 D- ODE \� $ c o \ ,� a m L A aco Ts N- Cl) v ©CI f 1.... 1, nOnnn :- f. j -114 io r I ❑ \ a \ �/.., O C q @ E.1^ I o z o E. // 2 M ❑ 'c o 2 o 2 0 m r uSm m a // I o ❑ U N O L ,Ji � 2 n eo a 3 \, oco -' ❑ i, )n m - 2 L. a 2 ii U io d❑ I N@� too 3 � a� I • mo cv .g (O M O c0 o d N N O)7- ^ r / I ~ C O M V f0 B r O I z., N it I I MCO CO m m m I I C ZO N M C N 0n- rn c ro g m co o m I I LO 20 �'v d N O)N 0 r rn Q o.5 co rte) i- yn r H a1 a`,N - C i6 O N I C i N' Z\ I F--m oa m M N J -- J 2.O J«= Q O rO z t O N V co C Z\ C co N Q f7 N J 3N-07A Slot Recovery 16"62.5#1-140 conductor set at 115' TOW at 2599' Milled 7"csg to 2621' 9-5/8"36#J-55 Surface set at 3.691' , 111b. MD/3,634 TVD 7"bridge plug set at approx 4100' 11.2 ppg drilling mud KWF Lower part of well to be abandoned by coil before rig move in ' u i TD 8-%" Hole at 7042' Run 7"Csg to Surface and cement in 2 stages Nos- 111w- ` TD 6-1/8' Hole at 7450' And run 4-'/"liner RECEIVED Nov AUG 2 9 .V..` ConocoPhillips AOGCC TRANSMITTAL CONFIDENTIAL DATA FROM: Sandra D. Lemke, ATO3-0340 TO: Makana Bender a ,g ConocoPhillips Alaska, Inc. AOGCC P.O. Box 100360 333 W. 7th Ave., Suite 100 Anchorage AK 99510-0360 Anchorage,Alaska 99501-3539 RE: 3N-07A AOGCC permit: 212-052-0 A L/ 3 DATE: 08/28/2012 Transmitted: 02:1 Kuparuk River Unit, North Slope, Alaska 3N-07A CD and hardcopy report Final Well report, Mud logging report,CANRIG;well 3N-07A(500292153901); 7/16/2012 Equipment,well data, geological data, pressure/formation strength, drilling data, daily reports,formation logs color prints; Formation log(MD) Formation log(ND) Gas ratio (MD) Gas ratio (TVD) LWD Combo (MD) LWD Combo (TVD) Drilling dynamics (MD) Drilling dynamics (TVD) CDROM contains; daily reports, DML data, final well report, LAS files, mud log PDF files, remarks and tiff files Sign, scan and return electronically to Sandra.D.Lemke0Conocophi//ips.com CC: 3N-07A transmittal folder, production well files, eSearch Receipt: _ Date: GIS-Technical Data Management I ConocoPhillips I Anchorage, Alaska I Ph; 907.265.6947 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 ❑ lb.Well Class 20AAC 25 105 20AAC 25 110 Development ❑✓ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions Service ❑ Stratlgraphic Test❑ 2 Operator Name: 5 Date Comp.,Susp, 12.Permit to Drill Number ConocoPhillips Alaska, Inc. orAband.: July 20,2012 212-052/ 3.Address 6 Date Spudded 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 July 7,2012 50-029-21539-01 4a Location of Well(Governmental Section). 7.Date TD Reached 14 Well Name and Number Surface: 1561'FSL,304'FEL,Sec.29,T13N, RO9E,UM July 16,2012 3N-07A Top of Productive Horizon: 8.KB(ft above MSL): 61'RKB 15.Field/Pool(s) 1240'FNL,568'FEL,Sec.29,T13N,RO9E,UM GL(ft above MSL): 34'AMSL Kuparuk River Field Total Depth: 9 Plug Back Depth(MD+TVD) 1082'FNL,607'FEL,Sec.29,T13N, RO9E,UM 6912'MD/6212'ND Kuparuk River Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-518096 y- 6013799 Zone-4 7450'MD/6590'ND ADL 25521 TPI: x-517819 y- 6016277 Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x-517780 y- 6016435 Zone-4 SSSV @ 1818'MD/1818'ND 2557 18.Directional Survey: Yes ❑✓ No❑ 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) 2612'MD/2611'ND 1.Loit Obtained(List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-drill/Lateral Top Window MD/TVD CBL 2599'MD/2598'ND 23 CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED _ 16" 62.5# H-40 35' 115' 35' 115' 24" 235 sx CS II ' 9.625" 36# J-55 37' 3691' 37' 3634' 12.25" 1070 sx PF"E",280 sx Class G 7" 26.0# L-80 37' 7040' 37' 6306' 8.5" 310 sx Class G,175 sx ASI Z -- 4.5" 12.6# L-80 6822' 7448' 6150' 6588' 6.125" 94 sx Class G 24 Open to production or injection? Yes ❑ No ❑ 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/ND) 3.5" 6874' 6822'MD/6151'ND not perfd ;L;m1)�:1:71 ' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED i 27 PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc) not applicable waiting on facility hook-up 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 ❑ Sidewall Cores Acquired? Yes ❑ No ❑ If Yes to either question,list formations and intervals cored(MD+ND 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 RECEIVED NONE AUG 2 0 2012 RBDMS AUG 21 20a:):'•GCC Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit original only 28 GEOLOGIC MARKERS(List all formations and markers encountered): 29 FORMATION TESTS NAME MD TVD Well tested? 0 Yes El 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 2420' 2419' needed,and submit detailed test information per 20 AAC 25.071 Kuparuk A 7220' 6428' Kuparuk Al 7299' 6483' N/A Formation at total depth: Kuparuk A 30. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final definitive directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: M.M.Myers @ 265-6318 Pnnted Name .Alvord Title' Alaska Drilling Manager ~ r Signature t �� Phone 265-6120 Date • I ? r Lc t Z— 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 1a: 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 KUP 3N-07A • ConocoPhillips a Well Attributes Max Angle&MD TD Alaska RICWellbore API/UWI Field Name Well Status Incl(') MD(ftKB) Act Bim(ftKB) 500292153901 KUPARUK RIVER UNIT PROD 46.29 7,233.69 7,450.0 `--- Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date -•• Wet Contig:-3N-07A,7124/2012 3 02 36 PM SSSV:TRDP 100 12/21/2008 Last WO: 7/21/2012 38.49 3/7/1986 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date a Last Tag: Rev Reason:WELL REVIEW SIDETRACK/WO osborl 7/24/2012 HANGER,23 f Casing Strings I Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd CONDUCTOR 16 15.062 35.0 115.0 115.0 62.50 H-40 WELDED Casing Description String 0... String ID...Top(MB) Set Depth(t...Set Depth(TVD)...String Wt..String...String Top Thrd lidort : whirl SURFACE 95/8 8.921 37.0 3,691.4 3,609.9 36.00 J-55 BTBC I Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd WINDOWA 958 8.000 2,599.0 2,616.0 2,615.4 Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt..String...String Top Thrd PRODUCTION 7 6.276 37.3 7,040.6 6,303.6 26.00 L-80 BTCM Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd LINER 41/2 3.958 6,821.9 7,448.0 6,588.4 12.60 L-80 IBTM Liner Details CONDUCTOR. Top Depth 35-775 (TVD) Top Incl tentNomi... Top(ftKB) (RKB) C) Description Comment ID(in) SAFETY VLV, I 6,821.9 6,150.6 45.55 PACKER BAKER C-2 ZXP LINER TOP PACKER 5.000 1,818 f.. I 6,841.6 6,164.4 45.58 HANGER BAKER HYDRAULIC FLEX LOCK LINER HANGER 5.510 6,850.2 6,170.5 45.59 SBE 80-40 SEAL BORE EXTENSION 4.750 Tubing Strings Tubing Description String O String ID...Top(MB) Set Depth(f...Set Depth(TVD)... String Wt...String... String Top Thrd TUBING WO 3 1/2 2.992 22.8 6,873.7 6,187.0 9.30 L-80 EUE • Completion Details r,, L4 Top Depth /�..J�[� (TVD) Top Incl Komi... AINNS W A, Top(ftKB) (MB) C) Item Description Comment ID(In) 2,599-2,616 , - 22.8 22.8 -0.02 HANGER TUBING HANGER 2.992 1,817.7 1,817.6 0.88 SAFETY VLV CAMCO TRMAXX-XMT SSSV X-PROFILE 2.920 GAS LIFT, 2.6-70 6,791.3 6,128.5 44.63 NIPPLE HES 7C NIPPLE 3.875 6,835.8 6,160.4 45.57 LOCATOR BAKER GHB-22 LOCATOR SUB 3.000 6,837.1 6,161.3 45.58 SEAL ASSY BAKER SEAL ASSEMBLY 2.990 : '., 6,873.2 6,186.6 45.62 SHOE HALF MULE SHOE 2.990 I SURFACE, A 373,691 �' C /� _ e. i GAS LIFT, j ,4-4-y-- i✓/V/"'�r'� 3,895 GASLIFT,__ 4,810 GAS LIFT, 5,545 GAS 6,186 v all all GAS LIFT, 6,736 0 all IIII NIPPLE,8,791 -- - iiii / \ Iii AI LOCATOR, Eli.. 8,836 i \ 1 SEAL ASSY. •' Oil -• 6,837 .I SHOE.8,873 Mandrel Details Top Depth Top Port (TVD) Incl OD Valve Latch Size TRO Run Stn Top(ftKB) (ftKB) (°) Make Model (in) Sem/ Type Type (in) (psi) Run Date Com... 1 2,639.6 Z638.8 8.90 CAMCO MMG 1 1/2 GAS LIFT DMY DK 0.000 0.0 7/20/2012 2 3,894.7 3,780.8 33.62 CAMCO MMG 1 1/2 GAS LIFT DMY DK 0.000 0.0 7/20/2012 3 4,809.6 4,546.2 31.66 CAMCO MMG 1 1/2 GAS LIFT DMY DK 0.000 0.0 7/20/2012 4 5,545.0 5,165.8 32.62 CAMCO MMG 1 1/2 GAS LIFT DMY DK 0.000 0.0 7/20/2012 PRODUCTION, 37-7,041 +' 5 6,186.0 5,693.1 40.42 CAMCO MMG 1 1/2 GAS LIFT DMY DK 0.000 0.0 7/20/2012 6 6,735.6 6,088.8 44.59 CAMCO MMG 1 12 GAS LIFT SOV RKP 0.000 0.0 7/20/2012 LINER. T6,622-7,448 7.450 ConocoPhillips Time Log & Summary Wellview Web Reporting Report Well Name: 3N-07 Rig Name: DOYON 141 Job Type: DRILLING SIDETRACK Rig Accept: 6/14/2012 9:30:00 PM Rig Release: 7/20/2012 11:59:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/14/2012 24 hr Summary Waiting on trucks to move to 3N-07A 21:30 00:00 2.50 MIRU WELLPF OTHR T Wait on trucks to mob. rig out. 06/15/2012 Trucks arrived 0630 hrs moved complexes,sub,pipe sheds, rock washer V 3N-07,spot up over well, hook up service lines,wait on trucks for mud,wait on highline personnel to move camp to 3N-07.(Rig Camp should be moving this morning at 07:30 hrs from 1R Pad to 3N Pad.) 00:00 06:30 6.50 MIRU WELLPF OTHR T Continue to wait on trucks. 06:30 07:00 0.50 MIRU WELLPF SFTY P Pre job safety meeting w/peak drives on moving rig V 3N-07 07:00 12:30 5.50 MIRU WELLPF MOB P Hook up pipe sheds spot out of way, Move complexes to 3N-07. 12:30 20:30 8.00 MIRU WELLPF MOB P Move sub off well,pipesheds&rock washer,move V 3N-07,spot sub over well,spot complexes. 20:30 00:00 3.50 MIRU WELLPF MOB P Hook up service lines,spot rock washer,finish containment,take on rig fuel, H2O.Wait on highline personel to move camp f/1R-14 to 3N-07.Wait on trucks to deliver mud to rig ETA 2400 hrs. 06/16/2012 Continue rigging up,rig accepted @ 0100 hrs,take on 11.2 ppg mud,R/U surface line f/displacement,berm tiger tank,test lines V 2500 psi, R/U&pull BPV, Displace well V 11.2 ppg mud @ 126 gpm 300 psi, cbserve well, blow down lines,Set BPV test from direction of flow V 1000 psi f/10 min.mark orientaion of tree, N/D tree, install blanking plug&adaptor flange, N/U BOP stack, R/U V test bops,test Bope blanking plug leaking change out, resume testing.Test waived By AOGCC Jeff Jones 00:00 01:00 1.00 0 0 MIRU MOVE MOB P Work on rig acceptance. (Rig accepted @ 01:00 June 16,2012) 01:00 02:00 1.00 0 0 MIRU MOVE OTHR P Take on 11.2 ppg 450 bbls LSND mud into pits. 02:00 07:00 5.00 0 0 SLOT MOVE OTHR P Mobilize tiger tank and berm, SIMOPS, Install scaffolding around well head.Test cement and circulating lines to Tiger tank to 2500 psi 07:00 08:00 1.00 0 0 SLOT WELLPF OTHR P Rig up and Pull BPV 08:00 08:15 0.25 0 0 SLOT WELLPF SFTY P PJSM,on circulating mud through TBG down cut at 6015' 08:15 10:00 1.75 0 0 SLOT WELLPF CIRC P Circulate well with 240 bbls of 11.2 ppg LSND mud @ 3 bpm with 700 psi. 10:00 10:30 0.50 0 0 SLOT WELLPF OWFF P Monitor well,Static, Blow down lines. 10:30 11:00 0.50 0 0 SLOT WELLPF OTHR P Set BPV,Test BPV from bottom to 1000 psi for 10 min,Mark orientation of tree. Page 1 of 38 Time Logs _ Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 11:00 11:15 0.25 0 0 SLOT WELLPF SFTY P PJSM,on N/D tree 11:15 12:00 0.75 0 0 SLOT WELLPF NUND P N/D tree 12:00 12:15 0.25 0 0 SLOT WELLPF SFTY P PJSM with new crew on tour moving out tree. 12:15 12:30 0.25 0 0 SLOT WELLPF NUND P Remove tree from cellar area. 12:30 13:30 1.00 0 0 SLOT WELLPF NUND P Dress TBG spool and install blanking plug as per FMC,install adapter flange. 13:30 13:45 0.25 0 0 SLOT WELLPF SFTY P PJSM on N/U of BOPE 13:45 16:30 2.75 0 0 SLOT WELLPF NUND P Nipple up BOPE 16:30 16:45 0.25 0 0 SLOT WELLPF SFTY P PJSM,on R/U and testing BOP. 16:45 18:30 1.75 0 0 SLOT WELLPF BOPE P M/U 2-7/8"test joint to X-over run and change out top rams to 2-7/8"X 5"VBR. 18:30 19:30 1.00 0 0 SLOT WELLPF BOPE P Rig up test equipment.AOGCC waived witness of BOPE test Jeff Jones 19:30 20:30 1.00 0 0 SLOT WELLPF BOPE P After several attempts to test,verified balanking plug leaking,pull test joint and C/O/ball in blanking plug, reinstall same. 20:30 00:00 3.50 0 0 SLOT WELLPF BOPE P Test BOP, upper 2-7/6"X 5"VBR, Choke valves 1, 12, 13&14. Manual choke kill.(Service valves 13 and 14 retest Good)#2 Test,upper IBOP, choke valves 9&11, (Serviced valve 11 &retest Good)serviced HCR kill valve. 06/17/2012 Pulled hanger and L/D 6015'of 2-7/8"TBG, R/U and Test lower pipe rams 250 low 3500 high,R/D test equip. P/U BHA#1, RIH with BHA#1 with casing scraper to 700'. 00:00 04:45 4.75 0 0 SLOT WELLPF BOPE P Test Bope,Test choke valves 1-14, upper&lower rams and blinds, upper &lower IBOP,man.&her choke and kill,4"demco TIW&DART,acc. test,pvt&gas alarms.Witness waived by Jeff Jones AOGCC. 04:45 05:30 0.75 0 0 SLOT WELLPF RURD P R/D test equip.pull blanking plug, blow down lines. 05:30 06:00 0.50 0 0 SLOT WELLPFOTHR P Pull BPV 06:00 06:45 0.75 0 0 SLOT WELLPF RURD P R/U t/pull 2.875 tubing 06:45 07:30 0.75 0 5,975 SLOT WELLPF OTHR P BOLDS pull hanger to floor, 125K t/ break over PUW 75K. 07:30 08:00 0.50 5,975 5,975 SLOT WELLPF PULD P UD Hanger&landing jt. 08:00 08:15 0.25 5,975 5,975 SLOT WELLPF RURD P R/U t/circ. 08:15 09:00 0.75 5,975 5,975 SLOT WELLPF CIRC P Circ. Bottoms up stage pumps U 168 gpm 640 psi. 09:00 09:30 0.50 5,975 5,975 SLOT WELLPF OWFF P Monitor well and R/D circulatuing lines 09:30 09:45 0.25 5,975 5,975 SLOT WELLPF SFTY P PJSM, Pulling TBG Page 2 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:45 12:00 2.25 5,975 5,042 SLOT RPEQPI PULL P Pull&UD 2.875"TBG, P/U=65K, Pulling wet UD 33 jts,4 pups, 1 DSnipple,Calc.displacement=3.25 bbls,Actual=3.62 bbls 12:00 12:30 0.50 4,917 4,917 SLOT RPEQP1CIRC P Pump dry job, 19 bbl 11.8 ppg slug 12:30 12:45 0.25 4,917 4,917 SLOT RPEQP1SFTY P PJSM, Pulling TBG 12:45 18:00 5.25 4,917 0 SLOT RPEQPI PULL P Cont. UD TBG F 4916'Total of 187 jts,3 GLM's, 10'pup, 1 X-nipple and cut joint. Length of cut joint= Fill for trip,Act.= 11.5 bbls calc= 11.15 bbls 18:00 19:30 1.50 0 0 SLOT RPEQP1OTHR P Rig down 2-7/8"handling equipment, Clear rig floor. 19:30 20:15 0.75 0 0 SLOT WELLPF BOPE P Rig to test lower pipe ram 20:15 20:30 0.25 0 0 SLOT WELLPF BOPE P tEST LOWER PIPE RAMS 2-7/8"x 5"VBR with 4"test joint to 250/ 3500 psi for 5 min each and charted same. 20:30 21:00 0.50 0 0 SLOT WELLPF BOPE P Rig down test equipment 21:00 21:45 0.75 0 0 SLOT WELLPF OTHR P Install Wear Bushing 21:45 22:00 0.25 0 0 SLOT WELLPF SFTY P PJSM,on M/U BHA#1,scraper assembly 22:00 00:00 2.00 0 700 SLOT WELLPF PULD P P/U BHA#1,scraper assembly and single with 4"dp from pipe shed,drift pipe with 2.24 drift to 700'MD.Trip in displacement,Actual=2.68 bbls, calculated=2.87 bbls 06/18/2012 (_te Single in the hole w/scraper t/4157'circ hole clean, POOH UD scraper assy.M/U cem ainer, RIH W/ Bridge plug set @ 4100'test t/1500 psi f/5 min.displace t/heated seawater, POOH UD running tool RIH w/ Multi string cutter cut casing @ 4000'attempt to circ.pressure up t/500 psi. Pull up U 3600'cut casing, attempt U circ. pressure up to 1400 psi, No returns. POOH U 1140' 00:00 03:15 3.25 700 4,157 SLOT WELLPF TRIP P Continue RIH w/4"DP f/700'U 4157' PUW 90K SOW 83K 03:15 04:00 0.75 4,157 4,157 SLOT WELLPF CIRC P Break Circ.stage pumps U 399 gpm 880 psi 12 RPM 1K tq,Circ.Surface to surface shakers cleaned up, 04:00 04:15 0.25 4,157 4,157 SLOT WELLPF OWFF P Obswerve well for flow Static 04:15 07:00 2.75 4,157 0 SLOT WELLPF TRIP P POOH f/4157'U surface 07:00 07:30 0.50 0 0 SLOT WELLPF PULD P Lay down BHA#1 scraper,clear floor 07:30 07:45 0.25 0 0 SLOT WELLPF PULD P PJSM,on cast iron bridge plug 07:45 10:30 2.75 0 4,100 SLOT WELLPF PULD P M/U BHA#2 with Bridge Plug and RIH to 4100, P/U=91 K,S/O=83K 10:30 10:45 0.25 4,100 4,066 SLOT WELLPF OTHR P Set Bridge plug per Baker Rep. Release from plug and pull up to 4066'MD 10:45 11:15 0.50 4,066 4,066 SLOT WELLPF OTHR P Test bridge plug to 1500 psi for 5 min and chart same. 11:15 13:00 1.75 4,066 4,066 SLOT WELLPF OTHR P Clean pit 5,take on 130°seawater 13:00 14:00 1.00 4,066 4,066 SLOT WELLPF CIRC P Break Circ. 168 gpm 300 psi,pump 25 bbl high vis spacer,displace well U 125°heated sea water. Page 3 of 38 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 14:00 14:15 0.25 4,066 4,066 SLOT WELLPF OWFF P Observe well for flow,static. 14:15 14:45 0.50 4,066 4,066 SLOT WELLPF SFTY P Pre job safety meeting on tripping out of hole. 14:45 16:00 1.25 4,066 7 SLOT WELLPF TRIP P POOH w/BHA#2 Bridge plug running tool. 16:00 16:15 0.25 7 0 SLOT WELLPF PULD P Lay down BHA#2 clear floor of tools. 16:15 16:30 0.25 0 0 SLOT WELLPFSFTY P Per job safety meeting on M/U BHA and Tripping in hole 16:30 19:00 2.50 0 3,970 SLOT WELLPF TRIP P Trip in hole w/BHA#3 Multi string cutting tool t/3970'. 19:00 19:30 0.50 3,970 3,995 SLOT WELLPF OTHR P M/U top drive EST.parameters, PUW 90K SOW 88K ROT WT 90 K, Break Circ. 105 gpm 200 psi, Slack off locate Collar @ 4006', Pull t/ 3995'Make cut w/70 RPM, 189 gpm,Observe Pressure drop indication of cut,Verify cut as per baker Rep. 19:30 19:45 0.25 3,995 3,995 SLOT WELLPF CIRC P Line up to OA and tiger tank, Attempt to circ. pressure up U 500 psi no returns, R/D equipment. 19:45 20:30 0.75 3,995 3,593 SLOT WELLPF TRIP P POOH f/3995't/3593' 20:30 21:15 0.75 3,593 3,587 SLOT WELLPF OTHR P P/U&M/U single,establish perameters, PUW 85K SOW 83K, break Circ.84 gpm 200 psi, Locate collar @ 3590'P/U U 3587',make cut w/70 rpm 189 gpm 500 psi,drop in pressure verify cut as per Baker rep. 21:15 21:30 0.25 3,587 3,587 SLOT WELLPF CIRC P Close ann. attempt t/circ.through OA pressure up U 1400 psi no returns. 21:30 21:45 0.25 3,587 3,587 SLOT WELLPF OWFF P Observe well for flow,static 21:45 22:00 0.25 3,587 3,587 SLOT WELLPF SFTY P Pre job safety meeting on tripping out of hole 22:00 22:30 0.50 3,587 3,587 SLOT WELLPF OTHR P Attempt to slack off through cut to lay down single, take wt.4k. 22:30 00:00 1.50 3,587 0 SLOT WELLPF TRIP P POOH w/multi string cutter 06/19/2012 Made casing cuts at 3995', 3587'and 2930'could not circ through the OA, POOH N/D stack pulled packoff, reset slips with 15K over string wt. removed TBG spool installed drilling spool, N/U stack,Test BOP against formation to 1000 psi, Rig up E-Line and run CET. 00:00 00:15 0.25 0 0 SLOT WELLPF SFTY P Pre job safety meeting on UD BHA 00:15 00:45 0.50 0 0 SLOT WELLPF PULD P Change out cutters on Multi string cutting tool 00:45 02:30 1.75 0 3,596 SLOT WELLPF TRIP P RIH U 3596'UD single, P/U=83 K, S/O=80 K, Actual=21.75 bbls. 02:30 02:45 0.25 3,596 3,587 SLOT WELLPF OTHR P Break Circ. Locate cut @ 3587'2.4 bpm w/200 psi 02:45 03:00 0.25 3,587 2,935 SLOT WELLPF TRIP P POOH T/2935'Calcuated=3.78 bbls,Actual=4.49 bbls. Page 4 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:00 04:30 1.50 2,935 2,930 SLOT WELLPF OTHR P Break Circ. 101 gpm 200 psi, Locate collars @ 2889'&2933', Pick up t/ 2930', make cut 70 RPM 201 gpm 500 psi,verify cut pump pressure dropped t/150 psi. 04:30 04:45 0.25 2,930 2,930 SLOT WELLPF SFTY P PJSM,on POOH to 2653'while monitoring well 04:45 05:30 0.75 2,653 2,653 SLOT WELLPF TRIP P POOH to 2653'MD, Cal=1.62 bbls, actual=1.75 bbls. 05:30 06:00 0.50 2,653 2,653 SLOT WELLPF CIRC P Attempt t/displace annulus to tiger tank,pressure up to 1400 psi, No returns,slight bleed off in pressure, attempt to pump down annulus, pressure up to 1000 psi, no returns 06:00 07:30 1.50 2,653 0 SLOT WELLPF TRIP P Cont. POOH F/2653.0 to surface, (Note cutters had cement on blades) Cal.=15.1 bbls,Actual=15.87 bbls 07:30 07:45 0.25 0 0 SLOT WELLPF OTHR P Clean and clear rig floor 07:45 08:00 0.25 0 0 SLOT WELLPF SFTY P PJSM,C/O lower rams 08:00 09:30 1.50 0 0 SLOT WELLPF OTHR P Change lower set of rams to 7" 09:30 09:45 0.25 0 0 SLOT WELLPF SFTY P PJSM, N/D BOP 09:45 12:00 2.25 0 0 SLOT WELLPF NUND P N/D BOPE double studded adapter flange and TBG spool, casing grow installed with all threads bolts, (Casing growth was 6.750") 12:00 13:30 1.50 0 0 SLOT WELLPF OTHR X Wait on Hydra tight,SIMOPS spot DSA in cellar, Cont. N/D stack and adapter spool,strip and prep TBG spool for hydra tight. 13:30 14:45 1.25 0 0 SLOT WELLPF OTHR P Pulled wear bushing and serviced rig 14:45 15:00 0.25 0 0 SLOT WELLPF OTHR P PJSM,on hydra tight tool 15:00 15:15 0.25 0 0 SLOT WELLPF OTHR P R/U Hyra Tight tool 15:15 16:15 1.00 0 0 SLOT WELLPF OTHR P Start hydra Tight process,casing grew 6.750", R/D tool 16:15 17:15 1.00 0 0 SLOT WELLPF OTHR P Remove TBG spool and packoff, SIMOPS AAR for Hydra Tight tool. 17:15 17:30 0.25 0 0 SLOT WELLPF SFTY P PJSM,on M/U Spear BHA. 17:30 18:45 1.25 0 0 SLOT WELLPF OTHR P M/U spear assembly and single to top drive 18:45 19:15 0.50 0 0 SLOT WELLPF OTHR P Engage CSG stub with spear, P/U to 125 K,(15 K over csg string wt.) Reset slips,S/O and release spear, UD same. 19:15 20:00 0.75 0 0 SLOT WELLPF OTHR P Clean,prep and weld slips in place to 7"casing. 20:00 20:15 0.25 0 0 SLOT WELLPF SFTY P PJSM,on N/U BOPE 20:15 22:30 2.25 0 SLOT WELLPF NUND P N/U BOPE 22:30 23:15 0.75 0 0 SLOT WELLPF BOPE P Test BOP agianst the formation with binds close to 1000 psi and check for leaks(Good) 23:15 00:00 0.75 0 0 SLOT WELLPF NUND P N/U Riser on BOP's Page 5 of 38 Time Logs Date From To Dur S. Death E.Depth Phase Code Subcode T Comment 06/20/2012 24 hr summary R/U ELine CBL log f/4000'TOC 2050',M/U Multi string cutter cut casing @ 2025', POOH, P/U spear, Spear casing,Casing free WI 75K,Displace artic pack to tiger tank, UD 7"Casing,Change 7"rams to 2 7/8 X 5 VBR,test breaks in stack,250 low 3000 high 00:00 00:15 0.25 0 0 SLOT WELLPF SFTY P PJSM R/U ELine. 00:15 01:00 0.75 0 0 SLOT WELCTL RURD P R/U Eline,Spot truck, Hang top sheave. 01:00 03:30 2.50 0 0 SLOT WELLPF ELOG P RIH w/Cement Bond Log,t/4000', log out of hole,TOC @ 2050'. 03:30 04:00 0.50 0 0 SLOT WELLPF RURD P R/D Eline. 04:00 04:30 0.50 0 0 SLOT WELLPF PULD P M/U Spear, Engage 7"casing stub pull up to 200K 10"pipe stretch, Disengage spear lay down. 04:30 04:45 0.25 0 0 SLOT WELLPF SFTY P Pre Job safety meeting on M/U BHA running in hole. 04:45 05:00 0.25 0 0 SLOT WELLPF PULD P M/U BHA Multi string cutting tool. 05:00 06:30 1.50 0 2,032 SLOT WELLPF TRIP P RIH W/BHA t/2032'. 06:30 07:00 0.50 2,032 2,025 SLOT WELLPF OTHR P Pick up to 2025'Make cut in 7" casing,verify cut pressure dropped off. 07:00 07:45 0.75 2,025 2,025 SLOT WELLPF OTHR P Close Rams R/U on OA let well U tube t/tiger tank. 07:45 08:15 0.50 2,025 2,025 SLOT WELLPF CIRC P CBU t/tiger tank,artic pack @ 84 gpm 150 psi. 08:15 08:45 0.50 2,025 2,025 SLOT WELLPF OWFF P Observe well for flow,static, Blow down lies to tiger tank. 08:45 10:00 1.25 2,025 0 SLOT WELLPF TRIP P POOH f/2025't/surface. 10:00 10:30 0.50 0 0 SLOT WELLPF PULD P UD Multi string cutter,M/U spear. 10:30 10:45 0.25 0 0 SLOT WELLPF SFTY P Pre job safety meeting on displacing artic pack. 10:45 12:45 2.00 0 2,025 SLOT WELLPF OTHR P Engauge 7"casing, R/U Hot Oil test lines t/1500 psi, P/U on casing free @ 75k, Line up to tiger tank, Pump 25 bbls heated diesel 130°@ 1.5 bpm 200 psi,pump spacer,chase w/ heated sea water, increase t/126 gpm 300 psi. 12:45 13:00 0.25 2,025 2,025 SLOT WELLPF OWFF P Observe well for flow,Static 13:00 13:15 - 0.25 2,025 2,025 SLOT WELLPF CIRC P Circ. Bottoms up @ 210 gpm 150 psi,simops R/U casinfg equip. 13:15 13:30 0.25 2,025 2,025 SLOT WELLPF OWFF P Observe well for flow static. 13:30 13:45 0.25 2,025 2,025 SLOT WELLPF SFTY P Pre job safey meeting on UD casing &spear assy. 13:45 15:00 1.25 2,025 2,025 SLOT WELLPF PULD P Pull Casing to floor UD spear assy. &casing stub. 15:00 17:15 2.25 2,025 0 SLOT WELLPF PULL P Pooh&UD 7"26#J-55. 17:15 19:00 1.75 0 0 SLOT WELLPF RURD P R/D csaing equipment,clear floor. 19:00 19:15 0.25 0 0 SLOT WELLPF SFTY P Pre job safety meeting on changing rams. 19:15 20:15 1.00 0 0 SLOT WELLPF SEQP P Change out lower rams f/7"to 2 7/8 x 5 VBR. Page 6 of 38 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 20:15 20:45 0.50 0 0 SLOT WELLPF RURD P R/U test equipment. 20:45 21:30 0.75 0 0 SLOT WELLPF BOPE P Attempt to test lower rams,test plug leaking,pull test plug, clean lubricate, reseat. 21:30 22:00 0.50 0 0 SLOT WELLPF BOPE P Test lower rams,casing spool&dsa flange 250 low 3000 high. 22:00 22:30 0.50 0 0 SLOT WELLPF RURD P R/D test equipment set wear ring. 22:30 00:00 1.50 0 0 SLOT WELLPF PULD P P/U BHA components f/next run. 06/21/2012 Wash and ream down to 2137'MD, POOH and found the 7"casing inside the wash over pipe, held PJSM, wait on casing cutter,cut and laid down 87.88'of 7"casing from washpipe, P/U wash pipe and TIH. 00:00 02:30 2.50 0 347 SLOT WELLPF PULD P M/U Wash Pipe Assy. 02:30 04:00 1.50 347 1,983 SLOT WELLPF TRIP P RIH f/347't/1983' 04:00 04:30 0.50 1,983 2,030 SLOT WELLPF REAM P Wash f/1983't/2030'w/210 gpm 240 psi 50 rpm,tag casing collar 04:30 05:45 1.25 2,030 2,031 SLOT WELLPF MILL P Mill on casing collar 210 gpm 220 psi 70 rpm tq 4K,3K WOB, break through 05:45 08:30 2.75 2,031 2,072 SLOT WELLPF REAM P Wash&Ream f/2031't/2072'w/210 gpm 220 psi 70 rpm,tag collar 08:30 10:00 1.50 2,072 2,073 SLOT WELLPF MILL P Mill on casing collar f/2072't/2073' 7K WOB 210 gpm 230 psi 10:00 12:00 2.00 2,073 2,096 SLOT WELLPF REAM P Wash&ream F/2073'T/2096'WOB 2-10K,294 GPM,70 RPM,TQ 2-10 K. 12:00 14:45 2.75 2,096 2,137 SLOT WELLPF MILL P Mill on casing collar F/2096'T/2137' MD, WOB 2-10K,294 GPM,70 RPM,TQ 3-7 K. 14:45 15:15 0.50 2,137 2,137 SLOT WELLPF CIRC P CBU @ 9 BPM,with 250 psi 15:15 15:30 0.25 2,137 2,137 SLOT WELLPF OWFF P Monitor well(Static) 15:30 16:00 0.50 2,137 1,385 SLOT WELLPF TRIP P Work through tight spot @ 1970'MD with 15-50 K over pull,work until) free(3X)Line up on TT and cont. pulling to 1385"MD, Incorrect fill (started to swab)Act=2.75 bbls, Calc.=3.24 bbls 16:00 16:15 0.25 1,385 1,385 SLOT WELLPF CIRC P M/U to Top Drive and circ 9 bpm with 175 psi 16:15 16:30 0.25 1,385 1,385 SLOT WELLPF OWFF P Monitor well(Static) 16:30 17:15 0.75 1,385 347 SLOT WELLPF TRIP P Cont.to POOH to Wash over BHA F/1385' T/347' 17:15 17:30 0.25 347 347 SLOT WELLPF OWFF P Monitor well,(static) 17:30 18:45 1.25 347 0 SLOT WELLPF PULD X Rach back DCs in derrick,pull stand of wash pipe,made break and found Fish in the stand of wash pipe,safely install dogcollar clamp.Act.=17.1 bbls, Calc.=16.71 bbls 18:45 19:00 0.25 0 0 SLOT WELLPF SFTY X PJSM,on L/D fish,ordered W.A..C..H cutter to location 19:00 21:00 2.00 0 0 SLOT WELLPF OTHR X W/O/Cutter coming to location, called FMC hand out to location Page 7 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:00 00:00 3.00 0 0 SLOT WELLPF OTHR X R/U W.A.C.H.and cut 7"and lay down lower 7"casing, Break down stand of wash pipe with fish in it in the mouse hole. 06/22/2012 Ran in with wash pipe assembly and washed and reamed down to 2239'MD over 7"casing. POOH with same. 00:00 01:30 1.50 0 0 SLOT WELLPF PULD X Continue UD Fish, R/U W.A.C.H.S. cutter,cut casing, UD 87.88'of 7" casing. 01:30 02:30 1.00 0 0 SLOT WELLPF OTHR P Clean&Clear rig floor R/D WACHS cutter,Clear BHA comp.from floor. 02:30 02:45 0.25 0 0 SLOT WELLPF SFTY P PJSM on M/U BHA#9 02:45 04:00 1.25 0 375 SLOT WELLPF PULD P M/U BHA#9 04:00 05:15 1.25 375 2,074 SLOT WELLPF TRIP P RIH w/wash pipe t/2074' 05:15 06:15 1.00 2,074 2,136 SLOT WELLPF REAM P Wash f/2074't/2113'w/168 gpm 200 psi,Tag 7"casing stump, Establish Rotation 20 rpm, locate wash pipe Wash f/2013't/2136', increase pumps t/210 gpm 200 psi, 70 rpm 4K tq. 06:15 12:00 5.75 2,136 2,165 SLOT WELLPF MILL P Mill f/2136't/2165'MD,with 3 bpm 325 psi,Tq on=2-8K, Pump sweeps after each collar milled,sweep @) 8:30 hrs 75%increase in cuttings, next sweep @ 10:00 hrs had 75% I increase cuttings also. 12:00 00:00 12.00 2,165 2,239 SLOT WELLPF MILL P Cont.to mil over 7"casing F/2165' T/2239'MD with 3 to6 bpm and 150 to 350 psi, Pumped super sweeps after each collar, P/U wt=79K,5/0 wt=77K, Rot wt=80K 06/23/2012 POOH with washing&milling BHA had 7"casing come up with wash pipe, Length 82.93'layed down same and RIH with spear No-Go, POOH and P/U multi-cutter and make cut @ 2239'MD, POOH and RIH with spear recovered fish Length 41.45'R/U and test BOPE. 00:00 02:15 2.25 2,239 2,237 SLOT WELLPF MILL P Cont. Mill over casing @ 2239', Attempt to wash over, P/U on string tq spike @ 2236 t/2237',unable to work past 2237' 02:15 02:30 0.25 2,237 2,237 SLOT WELLPF OWFF P Observe well for flow Static 02:30 03:00 0.50 2,237 1,700 SLOT WELLPF TRIP P Pooh f/2237't/1700'hole fill incorrect, 03:00 03:30 0.50 1,700 1,700 SLOT WELLPF CIRC P Circ.surface to surface 210 gpm 250 psi, no notible difference on bottoms up 03:30 04:00 0.50 1,700 1,415 SLOT WELLPF TRIP P Pooh f/1700't/1415' 04:00 05:00 1.00 1,415 375 SLOT WELLPF OTHR P Pump out of the hole f/1415 t/375' 05:00 05:15 0.25 375 375 SLOT WELLPF SFTY P PJSM on Laying down BHA&casing 05:15 09:00 3.75 375 0 SLOT WELLPF PULD P Stand back collars, UD BHA as per baker hand,82.93'of 7"casing in wash pipe, LID casing,float shoe, missing crown on cutters.Clear floor Page 8 of 38 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 09:00 09:15 0.25 0 0 SLOT WELLPF SFTY P Pre job safety meeting on P/U BHA 09:15 10:45 1.50 0 214 SLOT WELLPF PULD P P/U BHA#10 Spear 10:45 12:00 1.25 214 2,195 SLOT WELLPF TRIP P RIH W/spear f/214't/2195'MD, Act=17.5 bbls,Calc=17.49 bbls 12:00 12:15 0.25 2,195 2,195 SLOT WELLPF OTHR P M/U Top Drive, P/U wt=75K,S/O= 77K, Break circ with 5 bpm& 100 psi, Engage casing stub @ 2197' MD,set down wt=5K,observed pressure increase from No-Go,shut down pumps, P/U to 50K over string wt.and fire jars, P/U w/125K, release spear. 12:15 13:00 0.75 2,195 214 SLOT WELLPF TRIP P POOH with spear assembly F/2100' to/214' 13:00 13:15 0.25 214 214 SLOT WELLPF OWFF P Monitor well, (Static) 13:15 14:00 0.75 214 0 SLOT WELLPF PULD P Rack back DC's and UD spear,Act= 18.6 bbls,calc=17.49 bbls. 14:00 14:15 0.25 0 0 SLOT WELLPF SFTY P PJSM,on picking up BHA 14:15 14:45 0.50 0 0 SLOT WELLPF PULD P M/U Multi-cutter assemnbly. 14:45 15:30 0.75 0 2,180 SLOT WELLPF TRIP P RIH to 2180'Act=13.9 bbls,Calc= 13.2 bbls. 15:30 16:30 1.00 2,180 2,239 SLOT WELLPFOWFF P M/U Top Drive, P/U wt=64K, S/0= 65K,stabonto stump, Break circ with 3 bpm with 300 psi, locate collar and make cut @ 2239'with 60 rpm,4 bpm 500 psi,Tq=1K 16:30 16:45 0.25 2,239 2,239 SLOT WELLPFSFTY P PJSM on POOH 16:45 17:30 0.75 2,239 0 SLOT WELLPF TRIP P POOH with Multi cutter F/2239'to surface,Act=13.7 bbls, Calc= 1266 17:30 18:00 0.50 0 0 SLOT WELLPF OTHR P Clear and clean rig floor 18:00 18:15 0.25 0 0 SLOT WELLPF SFTY P PJSM,on P/U spear assembly 18:15 18:45 0.50 0 214 SLOT WELLPF PULD P P/U spear assembly 18:45 20:15 1.50 214 2,132 SLOT WELLPF TRIP P RIH F/214'T/2132'Act=17.7 bbls, Calc= 17.49 bbls. 20:15 20:30 0.25 2,132 2,197 SLOT WELLPF OTHR P M/U Top Drive, P/U wt=75K.S/O wt=77K,Circ @ 5bpm 100 psi, engage Fish @ 2197'set down 15K 20:30 20:45 0.25 2,197 2,197 SLOT WELLPFSFTY P PJSM,on POOH 20:45 21:30 0.75 2,197 214 SLOT WELLPF TRIP P POOH with Fish F/2100'T/214' 21:30 21:45 0.25 214 214 SLOT WELLPF OWFF P Monitor well at DC's, (Static) 21:45 22:30 0.75 214 0 SLOT WELLPF PULD P Rack back DC's and UD fish and spear, Length of Fish=41.45'Act= 15 bbls,Calc=14.24 bbls. 22:30 23:15 0.75 0 0 SLOT WELLPF OTHR P Drain stack and pull wear ring. 23:15 00:00 0.75 0 0 SLOT WELLPF OTHR P P/U single,stack washer and flush out stack Page 9 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06/24/2012 24 hrSummary M/U 8.75 Junk mill RIH V 660'tag hard spot unable to work by, Pooh LID Mill, P/U 8.5 junk mill, RIH V 660' tag up unable to work through, Pooh LID Mill wait on swedge f/Baker,M/U Swedge&Stab, RIH V 591'work through ttight spot no drag, RIH V 2239', Pooh, LID swedge P/U 8.75 mill RIH V 660'unable to work through. Pooh LID mill, P/U 8.75 watermelon mill, RIH V 660 work through tight spot, RIH t/2239',CBU, POOH 00:00 00:15 0.25 0 0 SLOT WELLPF SFTY P Pre Job safety meeting on flushing stack. 00:15 00:45 0.50 0 0 SLOT WELLPF OTHR P Flush stack,function annular,& rams. 00:45 01:00 0.25 0 0 SLOT WELLPF SFTY P Pre Job safety meeting on testing BOP 01:00 02:00 1.00 0 0 SLOT WELLPF RURD P R/U t/test BOP's 02:00 05:30 3.50 0 0 SLOT WELLPF BOPE P Test BOP's,250 low 3000 high(due to 11"3K flange on stack Per E Mail from Guy Schwartz AOGCC),choke valves 1-14,top bottom&blind rams, HCR&man.choke&kill,4"demco, auto&man. IBOP,test ann.to 250 low 2500 high,acc.test. (Test witnessed by State Rep.Chuck Scheve) 05:30 06:30 1.00 0 0 SLOT WELLPF RURD P R/D test equipment, install wear ring, blow down lines. 06:30 06:45 0.25 0 0 SLOT WELLPF SFTY P Pre job safety meeting on P/U BHA 06:45 08:15 1.50 0 0 SLOT WELLPF PULD T P/U BHA 8.75 junk mill RIH to 660'. Mill would not pass. POOH and lay down 8.75"mill. 08:15 10:00 1.75 0 660 SLOT WELLPF TRIP T Made up 8.5"Junk Mill and RIH w/ Junk mill t/660'tag hard spot, establish rotation&circ.60 rpm 700 lbs unable to break through. Pump 5 bpm with 50 psi,40 rpm, P/U=55K, S/O=55K,TQ=2K,Stalled out took 20K overpull to free up. 10:00 10:30 0.50 660 211 SLOT WELLPF TRIP T POOH F/660'T/211' Act=9.1 bbls, Calc=9.15 bbls 10:30 12:00 1.50 211 0 SLOT WELLPF PULD T Rack back two stds DCs, LID bit sub and 8-1/2"junk mill.Clean and clear rig floor 12:00 13:00 1.00 0 0 SLOT WELLPF OTHR T Wait on tools from Baker,SIMOPS Service Top Drive and Drawworks and PJSM. 13:00 14:15 1.25 0 660 SLOT WELLPF PULD T M/U Swedge and stabilizer assembly, RIH to 660'P/U=52K, S/O=55K,hammer on tight spot with 20K,After sevral attemps picked up 5'and rotated with 40 RPM, S/O and Ream through tight spot with minimal Tq.work tight spot with no drag. 14:15 15:15 1.00 660 2,239 SLOT WELLPF TRIP T Cont. RIH to 2239', P/U=75K,S/0= 77K,set on stump with 25K. 15:15 15:30 0.25 2,239 2,239 SLOT WELLPF SFTY T PJSM, POOH 15:30 16:15 0.75 2,239 215 SLOT WELLPF TRIP T POOH with swedge assembly F/ 2239'T/215' Page 10 of 38 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 16:15 16:45 0.50 215 0 SLOT WELLPF OWFF T Monitor well @ DCs,(Static)Rack back DCs and L/D swedge assembly 16:45 17:15 0.50 0 0 SLOT WELLPF OTHR T Clear and clean rig floor 17:15 17:30 0.25 0 0 SLOT WELLPF SFTY T PJSM,Milling BHA 17:30 18:45 1.25 0 660 SLOT WELLPF PULD T M/U 8-3/4"junk milling assembly and RIH to 660'MD,took weight P/U=52K,5/0=55K,P/U 5'and set down with 15K, P/U 5'rotated @ 40 RPM,Attemp to drill/mill with 3-7 Torque, No success.(Discussed with Engineer in town) 18:45 19:00 0.25 660 211 SLOT WELLPF TRIP T POOH F/660'T/211' 19:00 19:15 0.25 211 211 SLOT WELLPF OWFF T Monitor well @ DCs(Static) 19:15 19:30 0.25 211 0 SLOT WELLPF PULD T Rack back DCs and L/D mill assembly 19:30 20:00 0.50 0 0 SLOT WELLPF PULD T Clear rig floor and P/U 8-3/4" watermelon mill and mule shoe. 20:00 20:15 0.25 0 0 SLOT WELLPF SFTY T PJSM,on M/U BHA 20:15 20:45 0.50 0 215 SLOT WELLPF PULD T M/U BHA t/215' 20:45 21:00 0.25 215 592 SLOT WELLPF TRIP T RIH f/215't/592' 21:00 21:30 0.50 592 665 SLOT WELLPF OTHR T M/U t/TD&establish circ.210 gpm 50 psi,60 rpm 1K tq,S/O throught tight spot several times 2K-5K tq, shut down rot. pumps, no drag. 21:30 22:15 0.75 665 2,239 SLOT WELLPF TRIP T RIH f/665't/2239',set down on casing stub w/5K 22:15 23:00 0.75 2,239 2,239 SLOT WELLPF CIRC T Circ. Bottoms up 504 gpm 450 psi 23:00 23:15 0.25 2,239 2,239 SLOT WELLPF OWFF P Observe well for flow static 23:15 00:00 0.75 2,239 SLOT WELLPF TRIP T Pooh f/2197't/1725' 06/25/2012 RIH with Junk Mill and milled down 3'and POOH and P/U Pilot Mill, RIH and mill 7"casing down to 2308' Hole packing off and found flowline packed off,clean out same, Back ream out to clean up metal cuttings in well bore. 00:00 00:15 0.25 1,725 1,725 SLOT WELLPFSFTY T PJSM, POOH 00:15 00:30 0.25 1,725 215 SLOT WELLPF TRIP T POOH F/1725'T/215'Act=19.68 bbls,Calc=18.26 bbls. 00:30 00:45 0.25 215 0 SLOT WELLPF PULD T Rack back DCs, Lay down BHA as per-Baker 00:45 01:00 0.25 0 0 SLOT WELLPF SFTY T PJSM,on P/U BHA 01:00 01:30 0.50 0 211 SLOT WELLPF PULD T M/U 8.750"Junk Mill BHA 01:30 02:15 0.75 211 2,238 SLOT WELLPF TRIP T TIH with BHA F/211'T/2238' Act=17.85 bbls,Calc=17.79 bbls, Parameters P/U=77K,S/O=76K, Rot=78K,6 bpm with125 psi. 02:15 08:15 6.00 2,238 2,241 SLOT WELLPF MILL T Mill F/2238'T/2241'@ 3bpm 50 psi, 80 RPM,TQ= 1K. 08:15 08:30 0.25 2,241 2,241 SLOT WELLPF OWFF T Monitor well(Static) 08:30 09:30 1.00 2,241 211 SLOT WELLPF TRIP T POOH F/2241'T/211'Act=18.9 bbls,Calc= 17.79 bbls, Page 11 of 38 Time Logs Date From To Dur S. Death E.Depth Phase Code Subcode T Comment 09:30 10:00 0.50 211 0 SLOT WELLPF PULD T Rack Back DCs and lay down BHA, clear rig floor. 10:00 10:15 0.25 0 0 SLOT WELLPF SFTY T PJSM, P/U pilot mill 10:15 11:00 0.75 0 201 SLOT WELLPF PULD T M/U Pilot Mill BHA 11:00 12:00 1.00 201 2,239 SLOT WELLPF TRIP T RIH with Pilot Mill F/201'T/2241' Act=17.5 bbls,Calc= 17.49 bbls. 12:00 23:00 11.00 2,239 2,308 SLOT WELLPF MILL T Mill F/2239'T/2308'MD,with 50 to 110 RPM, 5-7 bpm, 100-175 psi, P/U=75K,SIO=77K, Rot=76K, Tq=.5K, (Pumped two Super Sweeps during milling) 23:00 00:00 1.00 2,308 2,308 SLOT WELLPFOTHR T Observed No metal coming back, attempt to circ metal out @ 12 bpm 500psi, Observed metal in n BOP stack and found flow line packed off. (Discussed with town engineer) 06/26/2012 Clean metal out of BOPE and flowline. POOH w/pump and L/D BHA. M/U BHA,7"pilot mill and RIH t/2277' MD. Reverse circulate to clean out obstruction in drill string. Ream to bottom @ 2308'and CBU. Mill 7" casing U 2325'MD worked though tight spot @ 2293'MD.The flow line packed off the metal cuttings twice while milling. 00:00 03:15 3.25 2,308 2,308 SLOT CSGRC'OTHR T PJSM-pump down kill line to attempt to clean metal out of the flow line and stack.Cleaned metal out of the stack, but the flow line was still 100%packed with metal. Break flow line apart and clean out metal shavings. 03:15 03:30 0.25 2,308 2,308 SLOT CSGRC'PRTS T Fill hole and inspect flow line for leaks. 03:30 05:15 1.75 2,308 672 SLOT CSGRC'TRIP T POOH f/2277'MD U 672'MD w/ pump @ 8 BPM, 120 PSI,80 RPM,TQ=0. 05:15 06:00 0.75 672 672 SLOT CSGRC'SFTY T Held H2S drill,all rig personal evacuated to the safe briefing area. Donned SCBA's and secured well. 06:00 06:30 0.50 672 201 SLOT CSGRC'TRIP T POOH f/672'MDU 201'MD w/ pump @ 8 BPM, 100 PSI,80 RPM,TQ=0.Actual displacement for trip=21.7 bbls,Calculated displacement=17.49 bbls. 06:30 06:45 0.25 201 0 SLOT CSGRC'PULD T Rack back 2 stands of drill collars and L/D BHA 06:45 07:00 0.25 0 0 SLOT CSGRC'OTHR P Clean and clear floor. 07.00 08:00 1.00 0 0 SLOT WHDBO OTHR P Flush stack X 4. Function annular and rams to clear metal cuttings out of BOPE. 08:00 08:15 0.25 0 0 SLOT CSGRC'SFTY P Hold PJSM on M/U BHA and RIH. 08:15 08:45 0.50 0 201 SLOT CSGRC'PULD P M/U BHA#19,7"pilot mill as per Baker. 08:45 10:00 1.25 201 2,277 SLOT CSGRC'TRIP P RIH f/201'MD U 2277'MD.Attempt to establish parameters,drill pipe pugged off.Actual displacement= 17.4 bbls, Calculated displacement= 18.03 bbls. Page 12 of 38 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 10:00 10:15 0.25 2,277 2,182 SLOT CSGRC'TRIP P POOH f/2277'MD t/2182'MD. 10:15 10:30 0.25 2,182 2,182 SLOT CSGRC'RURD P R/U to reverse circulate. 10:30 11:30 1.00 2,182 2,088 SLOT CSGRC'CIRC P Reverse circulate attempting to unplug drill string.The pipe unplugged after two attempts. 11:30 12:00 0.50 2,088 2,182 SLOT CSGRC'REAM P Wash and ream f/2088'MD t/2182' MD @ 7 BPM, 150 PSI,80 RPM w/ OK TQ. 12:00 13:00 1.00 2,182 2,308 SLOT CSGRC'REAM P Cont.to wash and ream f/2180'MD t/casing stub @ 2308'MD. Ream @ 7.5 BPM=200 PSI,80 RPM.CBU while rot&recip, P/U wt.=76K,S/0 wt.=79K, Rot wt.=78K. 13:00 13:30 0.50 2,308 2,308 SLOT CSGRC'CIRC P Pump 29 bbl HiVis sweep w/Super Sweep Fibers @ 7.5 BPM=200 PSI rot&recip string. 13:30 16:15 2.75 2,308 2,320 SLOT CSGRC'MILL P Mill 7"casing w/80-100 RPM,TQ= 1-4K @ 6 BPM=400 PSI.Milled f/ • 2308'MD t/2320'MD. 16:15 17:00 0.75 2,320 2,320 SLOT CSGRC'CIRC P Pump HiVis sweep w/Super Sweep Fibers @ 8.5 BPM=400 PSI,jet stack through IA, rot&recip string. 17:00 19:00 2.00 2,320 2,320 SLOT CSGRC'OTHR T Observed flow line packed off. Held PJSM,disassembled,cleaned out and reassembled. 19:00 19:30 0.50 2,320 2,320 SLOT CSGRC'PRTS T Fill hole and check for leaks. Observed a crack in flow line,drain and clean for welder. 19:30 20:30 1.00 2,320 2,320 SLOT CSGRC'SVRG T Service rig, SIMOPS-weld crack in flow line. 20:30 21:00 0.50 2,320 2,320 SLOT CSGRC'REAM P Fill hole and check for leaks.(good) Bring pump rate up V 12 BPM=500 PSI,wash and ream to bottom w/ 120 RPM.Observed 10'of fill. 21:00 21:15 0.25 2,320 2,320 SLOT CSGRC'CIRC P Tag stub @ 2320'MD. P/U and CBU while rot&recip string.Work through tight spot @ 2293'MD several times pulling 5 K over. 21:15 22:00 0.75 2,320 2,321 SLOT CSGRC'MILL P Wash down and mill f/2320'MD V 2321'MD. 22:00 23:00 1.00 2,321 2,293 SLOT CSGRC'REAM T Mill packing off. P/U and work though tight spot again @ 2293'MD w/ pump @ 15 BPM=650 PSI several times pulling 5 K over. Back ream out to 2225'MD and wash back to bottom, no fill. 23:00 00:00 1.00 2,293 2,325 SLOT CSGRC'MILL P Mill 7"casing f/2321'MD t/2325' MD @ 6 BPM=150 PSI,80-110 RPM w/1-4K TQ. 06/27/2012 Milled V 2326'MD,packing off.Work pipe thought tight spot @ 2293'MD. Displace V 10.2 ppg LSND mud. Attempt V mill,packing off. POOH w/pump.Clean out metal shavings from wellhead and BOPE using Baker rope spear and magnets.M/U junk mill and RIH V to make a clean out run. Page 13 of 38 Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 00:00 01:00 1.00 2,325 2,293 SLOT CSGRC'REAM T PJSM-hole packing off @ 2293'MD- 2297'MD.Work pipe several times through spot. Pulled 15K over. Pumped HiVis weighted sweep, small amount of cuttings observed at shakers. Decision made t/change fluid over to LSND mud system. 01:00 02:00 1.00 2,293 2,290 SLOT CSGRC'OTHR T Shut down,clean and inspect flow line before fluid swap. 02:00 02:15 0.25 2,290 2,290 SLOT CSGRC'SFTY T Hold PJSM on displacement. 02:15 03:00 0.75 2,290 2,290 SLOT CSGRC'COND T Prep pits f/fluid displacement 03:00 03:15 0.25 2,290 2,290 SLOT CSGRC'DISP T Displace 8.5 ppg viscosified brine over to 10.2 ppg LSND mud @ 16 BPM=425 PSI,80 RPM w/OK TQ. 03:15 03:45 0.50 2,290 2,326 SLOT CSGRC'MILL P Mill 7"casing f/2325'MD t/2326' MD @ 10 BPM, 110 RPM w/3K TQ, WOB=10K. Hole packing off. Decision made t/circulate hole clean,no cuttings observed at shakers. Decision made to POOH. 03:45 04:30 0.75 2,326 2,268 SLOT CSGRC'CIRC P Circulate and condition mud until mud weight is even in/out 10.2 ppg. 04:30 04:45 0.25 2,268 3,368 SLOT CSGRC'OWFF P Monitor well.(static) 04:45 07:00 2.25 2,280 201 SLOT CSGRC'TRIP P POOH w/pump @ 6 BPM=175 PSI f/2268'MD t/201'MD.Actual displacement=18.03,Calculated displacement=19.6 bbls. 07:00 07:45 0.75 201 0 SLOT CSGRC'PULD P Rack back 2 stands of 6 3/4"drill collars and UD BHA.Stack full of wadded up metal cuttings. Mix and pump HiVis sweep to clean out metal shavings. 07:45 08:00 0.25 0 0 SLOT CSGRC'OTHR P Clean and clear rig floor. 08:00 09:30 1.50 0 0 SLOT WHDBO CIRC P Mix HiVis sweep.SIMOPS,hook up mud pump through wellhead and attempt to clean metal out of wellhead end BOPE. 09:30 10:00 0.50 0 0 SLOT WHDBO CIRC P Pump HiVis sweep and pump @ 8.5 BPM through wellhead.Observed very little returns. Observed stack full of wadded up metal shavings. 10:00 10:15 0.25 0 0 SLOT WHDBOOTHR P Blow down lines and drain stack. 10:15 10:30 0.25 0 0 SLOT CSGRC'SFTY T Hold PJSM on P/U tools and M/U BHA. 10:30 10:45 0.25 0 0 SLOT CSGRC'PULD T P/U Baker tools from beaver slide. 10:45 11:00 0.25 0 40 SLOT CSGRC'PULD T M/U Baker rope spear as per Baker rep. 11:00 12:00 1.00 40 20 SLOT WHDBO CIRC T Attempt to fish out metal cuttings from stack.Only the magnets had metal on them. Decision made to puck up 5"magnets and fish out more metal. Page 14 of 38 Time Logs Date From To Dur S. Death E. Death Phase Code Subcode T Comment 12:00 17:00 5.00 20 20 SLOT WHDBO CIRC T PJSM-M/U Magnet assy, make multiple passes through stack.Fill hole and circulate through IA @ 9 BPM=800 PSI.Continue to reciprocate magnets. Drain stack, function rams halfway then continue to reciprocate magnets untill stack was clear of metal.Approximately 400 lbs of metal recovered. 17:00 17:45 0.75 20 0 SLOT WHDBO OTHR T Clean floor, P/U and L/D subs via beaver slide. 17:45 19:00 1.25 0 0 SLOT WHDBO CIRC T Flush stack with stack washer and magnets @ 20 BPM=150 PSI.Clean magnets and flush stack again @ 20 BPM=150 PSI until returns cleaned up. 19:00 20:30 1.50 0 227 SLOT CSGRC'PULD P PJSM-P/U junk mill assy, BHA# 22. RIH t/227'MD,took 5-10K @ 180'MD.Actual displacement=5.7 bbls,Calculated displacement=7.41 bbls. 20:30 00:00 3.50 227 1,734 SLOT CSGRC'REAM P Wash and ream @ 14 BPM=300 PSI,60 RPM f/227'MDU 1734'MD. P/U wt.=70K,S/O wt.=70K,ROT wt.=70K.Actual displacement= 16.7 bbls,Calculated displacement=16.1 bbls. 06/28/2012 Ream to bottom w/junk mill and clean out 2'of fill.Circulate hole clean and POOH. M/U BHA,pilot mill and RIH. Mill 7"casing f/2326'MD t/2380"MD. 00:00 01:15 1.25 1,734 2,326 SLOT CSGRC'REAM P PJSM-wash and ream f/1734'MD t/ 2326'MD @ 14 BPM=300 PSI,60 RPM w/OK TQ.Observed 2'of fill on bottom. 01:15 01:30 0.25 2,326 2,326 SLOT CSGRC'MILL P Set down 5K @ 2326'MD, let mill off @ reaming rate. 01:30 02:00 0.50 2,326 2,300 SLOT CSGRC'CIRC P CBU X 3 @ 16 BPM=725 PSI,50 RPM w/0 TQ.Cement and metal shavings observed at shakers. 02:00 02:15 0.25 2,300 2,300 SLOT CSGRC'OWFF T L/D single.Monitor well. (static) 02:15 03:15 1.00 2,300 227 SLOT CSGRC'TRIP T POOH on elevators f/2300'MD t/ 227'MD.Actual displacement= 19.6 bbls,Calculated displacement= 19.29 bbls. 03:15 04:00 0.75 227 0 SLOT CSGRC'PULD T Rack back 2 stands of drill collars and L/D BHA#22 as per Baker rep. 04:00 04:15 0.25 0 0 SLOT CSGRC'OTHR T Clean and clear rig floor. 04:15 05:00 0.75 0 0 SLOT CSGRC'CIRC T Flush stack to clean out metal shaving. 05:00 05:45 0.75 0 201 SLOT CSGRC'PULD P PJSM-M/U BHA#23,pilot mill as per Baker rep. 05:45 07:00 1.25 201 2,326 SLOT CSGRC'TRIP P RIH f/201'MD t/2326'MD.Actual displacement=18.2 bbls,Calculated displacement=18.12 bbls. Page 15 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 12:00 5.00 2,326 2,345 SLOT CSGRC'MILL P Mill f/2326'MD t/2345'MD @ 10 BPM=375 PSI, 115 RPM w/4-6K TQ. P/U wt.=77K,S/O wt.=75K, ROT wt.=77K. 12:00 22:00 10.00 2,345 2,373 SLOT CSGRC'MILL P Mill f/2345'MD t/2373'MD @ 10 BPM=350 PSI, 115 RPM w/4-6K TQ,5-7K WOB. Pumping 15 bbls HiVis sweeps every 5'@ 17 BPM= 750 PSI,recip string B/U X 2. Observing 20%to 50%increase in cuttings with sweeps. 22:00 00:00 2.00 2,373 2,380 SLOT CSGRC'MILL P P/U and M/U single to allow room to work pipe.Cont t/milling f/2373'MD to 2380'MD @ 10 BPM=350 PSI, 115 RPM w/4-6K TQ,5-7K WOB. Pumping 15 bbls HiVis sweeps every 5'@ 17 BPM=750 PSI,recip string B/U X 2.Observing 20%to 50% increase in cuttings with sweeps. P/U wt.=72K,S/O wt.=76K,ROT wt.=75K. 06/29/2012 Milled 7"casing f/2380'MD t/2415'MD. Shut down and cleaned metal shavings from stack.Cont.milling f/ 2415'MD t/2454'MD 00:00 10:45 10.75 2,380 2,415 SLOT CSGRC'MILL P PJSM-Mill f/2380'MD t/2415'MD @ 10 BPM=400 PSI, 115 RPM w/ 1-4K TQ. Pumping 10 bbls sweeps every 5',bring pump rate up t/17.5 BPM and work pipe until sweep return.Observing a 20%to 50% increase in mill cuttings with sweeps and increased pump rate. 10:45 12:00 1.25 2,415 2,415 SLOT CSGRC'CIRC P Observed an increase in pump pressure and flow decreased. Shut down and drain stack.Observed stack full of metal mill cuttings. Decision made to pump through wellhead annulus. No change in the amount of metal. Decision made to mix 30 bbls HiVis sweep. 12:00 13:00 1.00 2,415 2,415 SLOT CSGRC'CIRC P Pump 30 bbls HiVis sweep @ 19 BPM=825 PSI, 115 RPM w/OK TQ. Observed a 20%increase in cuttings.Circualted until wellhead was clear on metal mill cuttings. 13:00 00:00 11.00 2,415 2,454 SLOT CSGRC'MILL P Mill f/2415'MD t/2454'MD@ 10 BPM=370 PSI, 115 RPM w/1-4K TQ. Pumping 10 bbls sweeps every 5', bring pump rate up U 17.5 BPM=950 PSI and work pipe until sweep return.Observing a 20%to 50%increase in mill cuttings with sweeps and increased pump rate. P/U wt.74 K,S/0 75K, ROT wt.= 75K,WOB 7-8K. 06/30/2012 Milled 7"casing f/2454'MD t/2535'MD. Pumping 10 bbls HiVis every 5'@ 800 GPM,sweeps returning 20% more cuttings. Page 16 of 38 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 2,454 2,488 SLOT CSGRC'IMILL P PJSM-Cont.U mill f/2454'MD U 2488'MD. Pump @ 420 GPM=370 PSI, 115 RPM w/1-4K TQ,P/U wt.= 74K, S/O wt.=75K, ROT wt.=75K, WOB=7-8K, Flow out=49%. Pump 10 bbls HiVis sweeps every 5'@ 800 GPM=950 PSI.Observing a 20% increase in mill cuttings with sweeps.Shut down pumps @ 2465' MD to precautionary inspect stack for metal cuttings,flush metal cuttings out of stack by pumping a 30 bbls HiVis sweep. 12:00 00:00 12.00 2,488 2,535 SLOT CSGRC'MILL P PSJM-Cont.U mill f/2488'MD U 2535'MD. Pump @ 420 GPM=380 PSI, 115 RPM w/2-5K, P/U wt.= 74K,S/O wt.=75K, ROT wt.=76K, WOB=7-9K, Flow out=49%. Pump 10 bbls HiVis sweeps every 5'@ 800 GPM=950 PSI.Observing a 20% increase in mill cuttings with sweeps. P 07/01/2012 Milled 7"casing f/2535'MD U 2595'MD. Pumping 10 bbls HiVis every 5'@ 800 GPM.CBU and POOH. R/U and test BOPE. 00:00 12:00 12.00 2,535 2,578 SLOT CSGRC'MILL P PJSM-Cont.U mill f/2535'MD U 2578'MD. Pump @ 420 GPM=400 PSI, 115 RPM w/1-4K TQ. Pumping 10 bbl HiVis sweeps every 5'@ 820 GPM=1025 PSI.Observing a 25% increase in cuttings with sweeps. P/U wt.=74K,S/O wt.=75K,ROT wt.=76K.Observed flow line building up cuttings. Shut down and drain stack to clean cuttings out of stack, pump 30 bbl HiVis sweep. 12:00 17:45 5.75 2,578 2,595 SLOT CSGRC'MILL P PJSM-Cont.U mill f/2578'MD U 2595'MD. Pump @ 420 GPM=400 PSI, 115 RPM w/1-4K TQ. Pumping 10 bbl HiVis sweeps every 5'@ 820 GPM=1025 PSI. Observing a 25% increase in cuttings with sweeps. P/U wt.=74K,S/O wt.=75K, ROT wt.=76K. 17:45 18:45 1.00 2,595 201 SLOT CSGRC'TRIP P CBU. PJSM-POOH f/2595'MD U 201'MD.Actual displacement= 21.42 bbls,Calculated displacement=20.37 bbls. 18:45 19:30 0.75 201 0 SLOT CSGRC'PULD P UD BHA as per Baker rep. 19:30 20:15 0.75 0 0 SLOT CSGRC'CIRC P PJSM-R/U and flush stack. 20:15 21:00 0.75 0 0 SLOT WHDBO RURD P Pull wear bushing and flush stack again. 21:00 21:30 0.50 0 0 SLOT WHDBO RURD P PJSM-R/U to test BOPE. 21:30 22:00 0.50 0 0 SLOT WHDBO BOPE P Test annular preventor U 250/3000 PSI f/5 min w/5"test joint. Page 17 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:00 00:00 2.00 0 0 SLOT WHDBO BOPE P PJSM-open rams doors on stack and clean out metal mill cuttings f/ ram cavitys. 07/02/2012 Cont U test BOPE to 250 PSI low,3000 PSI high.Witness of BOP test waived by Lou Grimaldi.Slip and cutting drilling line,service rig. M/U pilot mill and mill f/2595'MD U 2621'MD.Circulate hole clean and POOH. 00:00 00:15 0.25 0 0 SLOT WHDBO SFTY P PJSM-Fill out hazard recognition checklist and hazard recognition worksheet. 00:15 03:00 2.75 0 0 SLOT WHDBO BOPE P Open rams doors and clean metal out. 03:00 03:30 0.50 0 0 SLOT WHDBO BOPE P M/U floor valves and finish rigging up to test BOPE. 03:30 08:00 4.50 0 0 SLOT WHDBO BOPE P Cont.to test BOPE U 250 PSI low 3000 PSI high w/5"test joint.Test #1=Top pipe rams,CV 1,12,13,14 and manual kill line valve.Test#2= Upper IBOP, HCR kill,CV 9&11. Test#3=Lower IBOP,CV 5,8&10. Test#4=Dart valve,CV 4,6,&7.Test #5=Floor valve&CV 2.Test#6= HCR choke,&4"kill line demco. Test#7=Manual choke valve&HCR kill.Test#8=annular preventer.Test #9=lower pipe rams.Test#10=blind rams.Test#11=annular preventer w/4"test joint U 250 PSI low 2500 PSI high.Test#12=top pipe rams w/4"test joint.Test#13=lower pipe rams w/4"test joint.Accumulator test=system pressure,3000 PSI, pressure after closing= 1800 PSI,38 seconds U obtain 200 PSI. Full pressure obtained after 176 seconds. Five bottle nitrogen average=2000 PSI.AGOCC rep Lou Grimaldi waved witness of the BOP test. 08:00 08:30 0.50 0 0 SLOT WHDBO RURD P R/D test equipment,blow down choke, choke line and kill line. 08:30 08:45 0.25 0 0 SLOT WHDBO RURD P Install 9"wear bushing. 08:45 09:00 0.25 0 0 SLOT RIGMNTSFTY P PJSM-Fill out hazard recognition checklist and hazard recognition worksheet on slip and cut drilling line. 09:00 10:00 1.00 0 0 SLOT RIGMNT SLPC P Slip and cut drilling line. 10:00 10:30 0.50 0 0 SLOT RIGMNT SVRG P Service rig and top drive. 10:30 10:45 0.25 0 0 SLOT CSGRC'SFTY P PJSM-Fill out hazard recognition checklist and hazard recognition worksheet on M/U BHA. 10:45 12:00 1.25 0 204 SLOT CSGRC'PULD P M/U BHA#24,pilot mill as per Baker rep. Page 18 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 13:15 1.25 204 2,595 SLOT CSGRC'TRIP P PJSM-Cont t/RIH w/pilot mill f/204' MD V 2595'MD. Establish circulation,pump @ 440 GPM=445 PSI, P/U wt.=78K,5/0 wt.=81K, ROT wt.=80K. 13:15 20:30 7.25 2,595 2,621 SLOT CSGRC'MILL P Mill f/2595'MD t/2621'MD @ 420 GPM=445 PSI. Pump 10 bbls HiVis every 5'@ 780 GPM=1000 PSI. 115 RPM w/2-5K TQ,WOB=7-9K. ROP=5 FPH. 20:30 21:00 0.50 2,621 2,620 SLOT CSGRC'CIRC P Pump 30 bbl HiVis sweep @ 780 GPM,Circulate hole clean. 21:00 22:00 1.00 2,620 204 SLOT CSGRC'TRIP P POOH f/2620'MDU 204'MD.Actual displacement=20.91 bbls, Calculated displacement=19.74 bbls 22:00 22:45 0.75 204 0 SLOT CSGRC'PULD P L/D BHA as per Baker rep. 22:45 23:30 0.75 0 0 SLOT CSGRC'CIRC P R/U and flush stack. 23:30 00:00 0.50 0 0 SLOT CSGRC'RURD P Clear and clean floor. R/U to run 2-7/8"tubing. 07/03/2012 P/U 2-7/8"tbg and RIH on 4"DP.Unable to enter 7"casing stump @ 2621'MD. POOH and M/U mule shoe on 2-7/8 tbg and RIH on 4"DP t/3653'MD. Unable to go past 3653'MD. Pump 23 bbls of 17.0 ppg cement, POOH above cement and circulate.WOC. 00:00 00:15 0.25 0 0 SLOT CEMEN"RURD P R/U tongs,elevators and dog collar. 00:15 00:30 0.25 0 0 SLOT CEMEN"SFTY P PJSM on running 2.875"tubing for cement stinger. 00:30 01:15 0.75 0 720 SLOT CEMEN"PUTB P RIH w/2.875"tubing f/cement U 720' MD. 01:15 01:30 0.25 720 720 SLOT CEMEN'RURD P R/D tongs,break apart safety valve and change elevators. 01:30 02:00 0.50 720 2,621 SLOT CEMEN"TRIP P RIH w/4"drill pipe f/2607'MD. Actual displacement= 12.9 bbls, Calculated displacement=12.43 bbls. 02:00 03:15 1.25 2,621 2,621 SLOT CEMEN"TRIP P Tag up on 7"casing stump @ 2621' MD,attempt to enter stump.Tried rotating @ 5 RPM while pumping @ 10 BPM=450 PSI.Slowed pumps t/ 3 BPM and attempted to enter again. Setting down 2-5K multiple times, turn 1/4 turn at a time. ROT @ 5,10,15 RPM,no go.POOH t/pick up mule shoe. 03:15 04:00 0.75 2,621 720 SLOT CEMEN"TRIP P PJSM, POOH f/2621'MD t/720' MD.Actual displacement=14.79 bbls,Calcualted displacement= 12.43 bbls. 04:00 04:45 0.75 720 0 SLOT CEMEN'TRIP P C/O elevators and R/U power tongs. Cont.V POOH standing back 2-7/8" tbg in the derrick f/720'MD to surface. 04:45 05:15 0.50 0 726 SLOT CEMEN"PULD P Inspect all joints,good.M/U 5.3' Mule shoe. RIH w/2-7/8"tbg V 726' MD. 05:15 05:30 0.25 726 726 SLOT CEMEN"RURD P PJSM,C/O elevators and R/U power tongs. Page 19 of 38 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 05:30.08:00 2.50 726 3,653 SLOT CEMEN"TRIP P RIH f/726'MD t/2621'MD.Tag up @ 2621'MD,turn 1/4 turn to the right two times before dropping in the 7" stump.Cont. RIH tagging up @ 3653' MD. Pump @ 4 BPM=300 PSI, ROT 10 RPM w/Tq limiter set @ 1K, stalling out. Unable to get past 3653' MD. P/U wt.=76K,S/O wt.=77K. Actual displacement=17.64 bbls, Calculated displacement=17.83 08:00 08:30 0.50 3,653 3,653 SLOT CEMEN"OTHR P Call town,decision was made to set cement plug @ 3653'MD. 08:30 09:00 0.50 3,653 3,653 SLOT CEMEN"RURD P PJSM,R/U to pump cement. 09:00 10:15 1.25 3,653 3,653 SLOT CEMEN"CIRC P Circulate @ 4.5 BPM=500 PSI while batching up cement. 10:15 10:45 0.50 3,653 3,653 SLOT CEMEN'CMNT P Pressure test lines t/2750 PSI. (good)Pump 23.3 bbls of 17.0 ppg cement as per Schlumberger. Displaced cement with rig pumps, chased with w/22.7 bbls of 9.8 ppg LSND @ 6 BPM=160 PSI. 10:45 11:00 0.25 3,653 2,991 SLOT CEMEN'RURD P R/D cement equipment, POOH f/ 3653'MD t/2991'MD(collars hanging up)Actual displacement= 4.76,Calculated displacement=3.78 bbls. 11:00 11:15 0.25 2,991 2,991 SLOT CEMEN"RURD P R/U cement hose to reverse circulate. 11:15 12:00 0.75 2,991 2,991 SLOT CEMEN'CIRC P Reverse circulate surface to surface @ 10 BPM=800 PSI @ 2991'MD. 12:00 12:15 0.25 2,991 2,991 SLOT CEMEN'CIRC P PJSM,Cont.to reverse circulate @ 10 BPM=795 PSI. 12:15 12:45 0.50 2,991 2,991 SLOT CEMEN'CIRC P R/U to circulate the long way,CBU X 2 @ 10 BPM=975 PSI. 12:45 00:00 11.25 2,991 2,991 SLOT CEMEN'WOC P WOC.SIMOPS,work on MP2's, scrub and paint rig.Clean out boilers. 07/04/2012 RIH, locate TOC @ 3100'MD. Pump 2nd cement plug f/3100'MD t/2350'MD. P/U and stand back 5"drill pipe while WOC. RIH t/2367'MD locate TOC,set down 4K. POOH and M/U clean out BHA. 00:00 00:30 0.50 2,991 2,991 SLOT CEMEN'SFTY P Pre-job safety meeting on rigging up cement equipment 00:30 00:45 0.25 2,991 3,100 SLOT CEMEN'TRIP P RIH from 2991'MD to 3100'MD circulating at 1 bpm @ 150 psi. Saw pressure increase from 150 psi to 190 psi indicating TOC 00:45 01:30 0.75 3,100 3,100 SLOT CEMEN'CIRC P CBU @ 7 bpm @ 400 psi. Observed cement in returns on BU. Circulate hole clean 01:30 01:45 0.25 3,100 3,086 SLOT CEMEN"TRIP P POOH to 3086' 01:45 02:00 0.25 3,086 3,086 SLOT CEMEN'RURD P Rig up to circulate and pump cement 02:00 03:45 1.75 3,086 3,086 SLOT CEMEN"CIRC P Circulate and condidtion mud at 5 bpm,375 psi, P/U=71 k, S/O= 65k. Hold safety meeting on cement job and batch up cement Page 20 of 38 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 03:45 04:15 0.50 3,086 3,086 SLOT CEMEN'DISP P Pressure test cement lines to 2500 psi. Pump 11 bbl 12.5 ppg Mudpush,39.5 bbl 17.0 ppg cement, and 2 bbl 12.5 ppg Mudpush. 04:15 05:00 0.75 3,086 2,235 SLOT CEMEN'TRIP P POOH from 3086'to 2235'. 05:00 06:00 1.00 2,235 2,235 SLOT CEMEN'CIRC P Rig up and reverse circulate at 10 bpm,700 psi. Rid down circulating head and circulate the longway from 2 BU @ 10 bpm @ 400 psi. Blow down top drive 06:00 12:00 6.00 2,235 2,235 SLOT DRILL PULD P Pick up 6 stand of 5"HWDP and 30 stands 5"drillpipe and rack back. Clean cement valves and clean under shakers. 12:00 15:30 3.50 2,235 2,235 SLOT DRILL PULD P PJSM,Continue to pick up and stand back 5"drill pipe. 15:30 16:00 0.50 2,235 2,235 SLOT DRILL OTHR P LID tread protectors and pick up saver sub from beaver slide. 16:00 16:15 0.25 2,235 2,235 SLOT RIGMNT SFTY P Hold PJSM on changing out saver sub to 4-1/2"IF. 16:15 18:30 2.25 2,235 2,235 SLOT RIGMNT SVRG P Change saver sub, bell guide and grabber dies on top drive. 18:30 19:00 0.50 2,235 2,235 SLOT CEMEN'RURD P Put tools away and change elevators to 5". 19:00 20:30 1.50 2,235 2,235 SLOT CEMEN'CIRC P RIH f/2238'MD,pumping @ 1 BPM=130 PSI. P/U=59K,S/0= 61K.Observed a 30 PSI pump pressure increase @ 2366'MD along with a 2K bobble on weight indicator. P/U 1'and CBU @ 10 BPM=480 PSI.Observed hard cement at the shakers at bottoms up.Slowed pumps back to 1 BPM and RIH. Tagged up @ 2367'MD and set down 4K on TOC. Decision made to POOH. 20:30 21:30 1.00 2,235 726 SLOT CEMEN'TRIP P PJSM, POOH f/2367'MD V 726' MD. 21:30 22:00 0.50 726 726 SLOT CEMEN'RURD P R/U tongs,elevators and slips to 2-7/8"tbg. 22:00 23:00 1.00 726 0 SLOT CEMEN'PULD P L/D 2-7/8"tbg f/726'MD V surface. 23:00 23:30 0.50 0 0 SLOT CEMEN'OTHR P Clean and clear rig floor. 23:30 00:00 0.50 0 0 SLOT CEMEN'PULD P Pick up tools from beaver slide. 07/05/2012 RIH w/clean out BHA.Drill cement f/2367'MD to/2620'MD.CBU and R/U to test casing.Attempt to test 9-5/8"casing to 1500 PSI. Pressure bled off @ 720 PSI. POOH. P/U packer and RIH V isolate hole in 9-5/8" casing. Found damaged area in casing f/2412'MD V 2533'MD. 00:00 00:15 0.25 0 0 SLOT CEMEN'PULD P PJSM, P/U tools from the beaver slide. 00:15 00:30 0.25 0 0 SLOT WHDBO RURD P R/U to test 5"floor valves. 00:30 01:00 0.50 0 0 SLOT WHDBO BOPE P Test floor valves to 250 PSI low and 3000 PSI high. 01:00 01:15 0.25 0 0 SLOT WHDBO RURD P R/D testing equipment and floor valves.Change elevators to 5". Page 21 of 38 Time Logs Date From To Dur S.Death E. Depth Phase Code Subcode T Comment 01:15 01:45 0.50 0 0 SLOT CEMEN'SFTY P PJSM,fill out hazard recognition card and hazard recognition worksheet on M/U clean out BHA. 01:45 03:00 1.25 0 584 SLOT CEMEN'PULD P M/U BHA#26 as per Halliburton and Baker reps.Clean out BHA w/8-3/4 mill tooth bit. 03:00 03:15 0.25 584 584 SLOT CEMEN'SRVY P Pluse test MWD @ 375 GPM=800 PSI. 03:15 04:15 1.00 584 2,340 SLOT CEMEN'TRIP P RIH w/drill pipe f/584'MD t/2340' MD. Establish parameters,420 GPM=1050 PSI,80 RPM w/OK TQ, P/U=90K,S/O=88K, ROT=92K. Actual displacement=26.07 bbls, Calculated displacement=26.24 bbls. 04:15 05:00 0.75 2,340 2,367 SLOT CEMEN'WASH P Wash and ream f/2340'MD t/2367' MD @ 420 GPM=1050 PSI,80 RPM.Washing past cement stringers. 05:00 12:00 7.00 2,367 2,620 SLOT CEMEN'DRLG P Tag cement @ 2367'MD. Drill cement f/2367'MD U 2620'MD @ 420 GPM=1100 PSI, 100 RPM w/1K TQ,WOB=5-10K. 12:00 13:30 1.50 2,620 2,620 SLOT CEMEN'SRVY P PJSM,ream stand.Shoot surveys for MWD,orientation station f/2620' MD U 2498'MD. Pump 400 GPM=980 PSI, P/U=94K,S/O 95K, ROT=95K. 13:30 14:00 0.50 2,620 2,618 SLOT CEMEN'CIRC P CBU @ 420 GPM=1100 PSI. 14:00 14:45 0.75 2,618 2,618 SLOT CEMEN'PRTS P Rig up to test 9-5/8"casing, pressure up and attempt to test U 1500 PSI. Pumped 1 BPM up to 725 PSI,pressure broke over and began injecting mud. Injection rate @ 1 BPM=700 PSI. Decision made to POOH. 14:45 15:00 0.25 2,618 2,618 SLOT CEMEN'OWFF P Monitor well. 15:00 15:45 0.75 2,618 580 SLOT CEMEN'TRIP P PJSM,POOH f/2620'MDU 580' MD.Actual displacement=28.71 bbls,Calculated displacement=28.5 bbls. 15:45 16:15 0.50 580 0 SLOT CEMEN'PULD P L/D BHA. 16:15 16:30 0.25 0 0 SLOT CEMEN'OTHR P Clean and clean rig floor. 16:30 19:15 2.75 0 0 SLOT CEMEN'OTHR P Scrub and paint rig while waiting on test packer. 19:15 19:45 0.50 0 0 SLOT RIGMN1SVRG P Service rig. 19:45 20:00 0.25 0 0 SLOT CEMEN'SFTY P Hold PJSM on picking up packer. 20:00 21:45 1.75 0 1,298 SLOT CEMEN'PRTS P RIH w/retrievable packer U 1298' MD.Attempt to pressure up below packer to 1500 PSI,bleeding off @ 720 PSI. Pressure broke over and began injecting @ 1 BPM=680 PSI. Bled off pressure,test above packer to 1500 PSI f/15 min,good test. Page 22 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:45 23:15 1.50 1,298 2,608 SLOT CEMEN"PRTS P RIH t/2608'MD. R/U and pressure test below packer to 1500 PSI f/15 min,good test.Attempt to pressure up above packer to 1500 PSI, bleeding off @ 700 PSI.Pressure broke over and began injecting @ 1 BPM=680 PSI. Actual displacement=27.97,Calculated displacement=30.48.P/U=104K, 5/0=105K. 23:15 00:00 0.75 2,608 2,505 SLOT CEMEN"PRTS P R/D test equipment and stand back one stand. 07/06/2012 Isolate leak in 9 5/8"casing between 2412'MD to 2533'MD. POOH. RIH w/cement retainer U 2415'MD. AGOCC confirmed that a cement job was not needed. POOH. RIH w/whipstock and mill window,TOW @ 2599'MD BOW @2616'MD 00:00 03:00 3.00 2,505 2,412 SLOT CEMEN"PRTS P PJSM,set packer @ 2501'MD, Attempt to test IA U 1500 PSI, observed fluid circulating around packer(no test). POOH t/2412'MD. Test IA t/1500 PSI f/15min,good test. Pump down pipe @ 2412'MD, pressure broke over @ 690 PSI and began injecting fluid. RIH t/2564' MD,test down pipe t/1500 PSI f/5 min,good test. POOH t/2533'MD, test down pipe U 1500 PSI,good test. POOH t/2412'MD and perform injectivty test, 1 BPM=690 PSI,2 BPM=730 PSI,3 BPM=800 PSI,4 BPM=850 PSI,5 BPM=875 PSI. Injected a total of 23.8 bbls.Shut down and bleed pressure off.Test IA V 1500 PSI f/10 min,good test. Confirmed damaged casing f/2412' MDV 2533'MD. 03:00 03:15 0.25 2,412 2,412 SLOT CEMEN"RURD P Rig down test equipment and line up to trip tank. 03:15 04:00 0.75 2,412 745 SLOT CEMEN"TRIP P POOH f/2412'MDV 745'MD.Actual displacement=29.41 Calculated displacement=29.26 bbls 04:00 04:30 0.50 745 0 SLOT CEMEN"PULD P Rack back 6 stands of HWDP and 2 collars. UD BHA as per Baker rep. 04:30 05:00 0.50 0 0 SLOT CEMEN"OTHR P Blow down top drive,kill line and cement line. 05:00 05:15 0.25 0 0 SLOT CEMEN"SFTY P Hold PJSM on M/U cement retainer. 05:15 05:30 0.25 0 7 SLOT CEMEN"PULD P M/U cement retainer as per Baker rep. 05:30 06:45 1.25 7 2,415 SLOT CEMEN"TRIP P RIH f/7't/2415'MD.Actual displacement=23.25 bbls, Calculated displacement=20.3 bbls. 06:45 07:00 0.25 2,415 2,415 SLOT RIGMN1SFTY P Hold PJSM on servicing rig. 07:00 07:30 0.50 2,415 2,415 SLOT RIGMN1SVRG P Service rig. Page23of38 Time Logs Date From To Dur S. Death E. Death Phase Code Subcode T Comment 07:30 10:30 3.00 2,415 2,415 SLOT CEMEN"OTHR P Wait on orders from town.Approval was given by the state to not squeeze the damaged 9-5/8"casing f/2412'MD t/2533'MD 10:30 11:45 1.25 2,415 0 SLOT CEMEN"TRIP P PJSM, POOH f/2415'MD t/surface. Actual displacement=22.78 bbls, Calculated displacement=20.04 bbls. 11:45 12:00 0.25 0 0 SLOT CEMEN"OTHR P Clean and clear rig floor. 12:00 12:15 0.25 0 0 SLOT STK PULD P P/U Baker tools from the beaver slide. 12:15 14:30 2.25 0 20 SLOT STK PULD P PJSM,M/U Whipstock as per Baker rep. 14:30 15:15 0.75 20 225 SLOT STK SRVY P RIH t/225'MD and shallow hole test MWD tools,good test. 15:15 17:00 1.75 225 2,620 SLOT STK WPST P Cont t/RIH w/whipstock t/2620' MD.Actual displacement=29.7 bbls, Calculated displacement=29.9 bbls. 17:00 18:00 1.00 2,620 2,599 SLOT STK WPST P Make up top drive on stand#19, pump @ 450 GPM=975 PSI. Orient t/16 left,shut down pumps and make a connection. RIH and tag @ 2621'MD,set down 4K. P/U off bottom and pump @ 450 GPM to verify 16 left.Shut down pumps, come back down to set anchor. Slowly slacked off and observed A anchor and shear bolt sheared @ 18K. Pick up 5'; no overpull was observed,verifying shear bolt was not attached. 18:00 20:15 2.25 2,599 2,606 tLOT 3"fK f P Start mil.liagatiadow @ 2599(TOW) t/2606'MD, Pump @ 400 GPM=825 PSI,80 RPM w/1-5K TQ,WOB= v 5-7K, P/U= 105K,S/O=108K. 20:15 20:30 0.25 2,606 2,606 SLOT RIGMNT SVRG T Swivel packing leaking,lubricate 10 swivel packing. 5 20:30 22:15 1.75 2,606 2,611 SLOT STK WPST P Cont.U mill window from f/2606'MD U 2611'MD, Pump @ 400 GPM=825 PSI,80 RPM w/1-5K TQ,WOB= 5-7K, P/U= 105K,S/O=108K. Slow pump rates @ 2590'MD, MP#1 20 SPM=80 PSI,30 SPM=120 PSI. MP#2, 20 SPM=90 PSI,30 SPM= 130 PSI. 22:15 23:30 1.25 2,611 2,580 SLOT RIGMNTSVRG T PJSM,change out leaking swivel packing. 23:30 00:00 0.50 2,580 2,580 SLOT RIGMNT SVRG T R/D top drive landing and test top drive for leak after changing swivel packing. 07/07/2012 Continued to mill window U 2638'MD.Work though window and CBU X 2. Perform LOT U 13.5 ppg EWM. POOH.MM kick off BHA and RIH.Time drill f/2638'U 2653'MD. Drill ahead. Page 24 of 38 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 00:00 02:30 2.50 2,580 2,638 SLOT STK WPST T PJSM, RIH after changing swivel packing f/2580'MD t/2611'MD.Cont milling window f/2611'MD U 2638' MD @ 400 GPM=850 PSI,80 RPM w/2K TQ.TOW @ 2599'MD BOW 2616'MD.Open hole U 2638'MD,22' of new hole. 02:30 02:45 0.25 2,638 2,638 SLOT STK CIRC P Work BHA through window at two times milling rate.Shut down rotary and work through window again, good.Shut down pumps and work through window,good. 02:45 03:30 0.75 2,638 2,638 SLOT STK CIRC P Pump sweep,circulate and condition mud for FIT @ 400 GPM=850 PSI, 80 RPM w/OK TQ. 03:30 03:45 0.25 2,638 2,588 SLOT STK FIT P Stand back one stand and rig up to perform FIT. 03:45 04:15 0.50 2,588 2,588 SLOT STK FIT P Perform LOT U 13.5 ppg EMW. 04:15 04:30 0.25 2,588 2,588 INTRM1 DRILL CIRC P Obtain SPR's Pump#1:20 SPM= 100 PSI,30 SPM= 130 PSI. Pump #2:20 SPM=100 PSI,30 SPM= 130 PSI. 04:30 04:45 0.25 2,588 2,567 INTRM1 DRILL OWFF P Observe well(static). Hold PJSM f/ POOH. 04:45 06:00 1.25 2,567 815 INTRM1 DRILL TRIP P POOH f/2567'MDU 815'MD.Actual displacement= 14.28 bbls, Calculated displacement-14.9 bbls. 06:00 07:45 1.75 815 0 INTRM1 DRILL PULD P PJSM,monitor well. Stand back 6 stands of HWDP, L/D 6 joints of drill collars. L/D milling BHA as per Baker&Halliburton reps.Actual displacement=15.81 bbls, Calculated displacement=16 bbls. 07:45 08:15 0.50 0 0 INTRM1 DRILL PULD P Clean and clear floor, L/D Baker tools. 08:15 08:45 0.50 0 0 INTRM1 DRILL OTHR P Flush stack with stack washer. 08:45 09.00 0.25 0 0 INTRM1 DRILL SFTY P Hold PJSM on M/U BHA. 09:00 10:15 1.25 0 550 INTRM1 DRILL PULD P M/U BHA as per Halliburton rep. 10:15 10:30 0.25 550 692 INTRM1 DRILL SRVY P P/U 1 stand of HWDP and perform shallow pulse test @ 410 GPM=900 PSI. Inserted MI-SWACO corrosion rings on top of the 1st stand of HWDP. 10:30 10:45 0.25 692 2,544 INTRM1 DRILL TRIP P Cont t/RIH t/2544'MD 10:45 12:00 1.25 2,544 2,590 INTRM1 DRILL CIRC P Kelly up and wash down t/2590'MD. Orient 15L, shut down pumps and hold PJSM on mud displacement. 12:00 13:00 1.00 2,590 2,638 INTRM1 DRILL REAM P PJSM,pump @ 400 GPM,orient t/ 15L to slide through window @ 2599' MD. Ream f/2606'MD U 2638'MD. P/U=97L,5/0=100K 13:00 21:30 8.50 2,638 2,653 INTRM1 DRILL DRLG P Displace well U 9.6 ppg LSND mud system.Time drill f/2638'MD V 2653'MD.Time drill @ 1.2"per 5 minutes. Page 25 of 38 Time Logs Date From To Dur S. Depth E.Death Phase Code Subcode T Comment 21:30 00:00 2.50 2,653 2,746 INTRM1 DRILL DRLG P Drillling ahead f/2638'MD t/2738' MD,ND 2738'.ART=1.43,AST= 7.79,ADT=9.22,Total jar hrs=N/A, Bit hrs=9.21, P/U= 103k, S/0=104K, ROT= 104K,TQ On= 1K, TQ Off-1K, Flow=35%,WOB= 5-7K, RPM=50,400 GPM=1050 PSI. SPR @ 2635'MD,ND 2635', MW=9.6+,Time 18:00, Pump#1: 20 SPM=110 PSI,30 SPM= 150 PSI. Pump#2:20 SPM=110 PSI,30 SPM=150 PSI. 07/08/2012 Drilled U 3005'MD with kick-off BHA.CBU and POOH.C/O BHA and M/U MWD tools. RIH and MAD pass f/ 2630'MD U 3005'MD. Drill ahead to 3322'. 00:00 05:45 5.75 2,746 3,005 INTRM1 DRILL DRLG P Drilling ahead f/2746'MD U 3005' MD,ND=2995'.ART=2.09,AST= 1.40,ADT=3.49.Total jars hrs=0, P/U= 109K,S/O= 107K, ROT= 108K,TQ:on=2-3K,off= 1.5K. Flow out=44%@ 500 GPM ,WOB=5K, RPM=50. 05:45 06:15 0.50 3,005 3,005 INTRM1 DRILL CIRC P Shoot survey,CBU and obtain SPRs.Monitor well. SPR @ 3005'MD,ND 2996'MW= 9.6+6:00hrs. Pump#1 30 SPM= 180 PSI,40 SPM=230 PSI. Pump #2 30 SPM= 190 PSI,40 SPM=240 PSI. 06:15 08:15 2.00 3,005 692 INTRM1 DRILL TRIP P POOH U 2674'MD. Re-shoot survey. Cont U POOH, BHA pulled thru the window with no issues.Monitor well at window and pump dry job. POOH on elevators U 692'MD. 08:15 10:00 1.75 692 0 INTRM1 DRILL PULD P Monitor well,static.Stand back 4 stands of HWDP and UD 3 joints of HWDP.Stand back drill collars and UD BHA.Actual displacement=35.7 bbls,Calculated displacement=34.5 bbls. 10:00 10:30 0.50 0 0 INTRM1 DRILL SFTY P Hold PJSM on M/U BHA,fill out HRW. 10:30 10:45 0.25 0 0 INTRM1 DRILL PULD P Clean and clear floor. P/U tools from the beaver slide. 10:45 12.00 1.25 0 0 INTRM1 DRILL PULD P M/U BHA t/42.41'MD.Orient mud motor. 12:00 14:00 2.00 0 450 INTRM1 DRILL PULD P PJSM, P/U BHA,flex collars,jars and HWDP. Shallow hole test MWD tools @ 450'MD. 14:00 17:45 3.75 450 3,005 INTRM1 DRILL TRIP P RIH on elevators U 2590'MD. Fill pipe,orient tools and go slowly though window U 2630'MD.MAD pass f/2630'U 3005'MD pumping @ 450 GPM=975 PSI,40 RPM w/1K TQ. Run @ 250'per hour. Page 26 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:45 00:00 6.25 3,005 3,322 INTRM1 DRILL DRLG P Drilling ahead f/3005'MD t/3322' MD TVD 3270'.ART=1.28,AST= 2.43,ADT=3.7,Total jar hrs=3.7, Bit hrs=3.7, P/U=116K,S/O=114K, ROT=116,TQ:on= 1-2K,off= 1K. ECD=10.34 ppg EWM, Flow=43% @ 575 GPM= 1550 PSI, WOB=2-4K, 50 RPM SPR @ 3005'MD ND-2997',MW 9.6+ppg, 17:30 hrs Pump#1: 30 SPM=170 PSI,40 SPM=240 PSI. Pump#2:30 SPM= 190 PSI,40 SPM=240 PSI. 07/09/2012 Drilled f/3005'MD t/5000'MD 00:00 11:30 11.50 3,322 4,258 INTRM1 DRILL DRLG P Drilled f/3322'MDU 4258'MD TVD 4083'. ART=5.49,AST= 1.54,ADT= 7.03. P/U=134K,S/O=124K, ROT= 130K.TQ:on=3-7K, off=3K. Max gas=463 units, ECD=10.31 ppg EMW. Pump @ 590 GPM=1775 PSI. SPR @ 4166'MD ND 4007, MW=9.6+ Pump#1: 30 SPM=240 PSI,40 SPM=290 PSI. Pump#2: 30 SPM=230 PSI,40 SPM=280 PSI. Highline power went out @ 10:00 hrs 11:30 12:00 0.50 4,258 4,258 INTRM1 RIGMNT SVRG P Adjust drawworks brakes. 12:00 12:15 0.25 4,258 4,258 INTRM1 RIGMNT SVRG P PJSM,Cont.to adjust drawworks breaks pumping @ 170 GPM=275 PSI. 12:15 18:00 5.75 4,258 4,720 INTRM1 DRILL DRLG P Drilled f/4258'MD t/4720'MD TVD 4471'.ART=3.5,AST=.52,ADT= 4.02.Total jar hrs= 14.75, Bit hrs= 14.75. P/U= 145K, S/O=131K, ROT=137K.TQ: on=5-7K,off=3K, ECD=10.54 ppg, Pump @ 600 GPM=2100 PSI, Flow out=42%, WOB=8-10K, RPM=90. SPR @ 4227'MD ND 4057, MW 9.5+. 12:00 Hrs Pump#1:30 SPM=240 PSI,40 SPM=290 PSI. Pump#2: 30 SPM=240 PSI,40 SPM=290 PSI. 18.00 00:00 6.00 4,720 5,000 INTRM1 DRILL DRLG P Drilled f/4720'MD t/t/5000'MD ND 4707'.ART=3.3,AST=.79, ADT=4.09.Total jar hrs=18.85, Bit hrs=18.85. P/U=149K,S/0= 134K, ROT=141K.TQ:on=6K,off=3K. ECD=10.60 ppg, Flow=47%, WOB=12-15K, RPM=90, Pump @ 600 GPM=2200 PSI Page 27 of 38 Time Loge Date From To Dur S. Death E.Depth Phase Code Subcode T Comment 07/10/2012 24 hr Summary Drill F/5000'MD T/6130'MD, 00:00 06:00 6.00 5,000 5,552 INTRM1 DRILL DDRL P Drill F/5000'MD-T/5552'MD, TVD=5173'ART=3.01,AST=0.35, ADT=3.36,Jar hrs=22.88 06:00 12:00 6.00 5,552 5,788 INTRM1 DRILL DDRL P Drill F/5552'MD T/5788'MD,TVD= 5373'ART=3.48,AST= 1.68,ADT= 5.16,Jar hrs=27.37, P/U= 161K, SIO=145K, Rot= 151K,Tq on= 5-8K,Off=4K, Max Gas Units=107, ECDs= 10.66 ppg 12:00 18:00 6.00 5,788 5,935 INTRM1 DRILL DDRL P Drill F/5788'MD T/5935'MD,TVD= 5496'ART=3.43, AST=1.82, ADT= 5.25,Jar hrs=32.62, P/U= 164K, S/O= 147K, Rot= 155K,TQ on= 5-6K,Off=4K,WOB= 13-17K, RPM=100,GPM=600 with 2350 psi 18:00 00:00 6.00 5,935 6,130 INTRMI DRILL DDRL P Drill F/5935'MDT/6130'MD,TVD= 5653'ART= 1.98,AST=2.59,ADT= 4.57,Jar hrs=37.19, P/U= 167K, S/O=150K, Rot= 157K,TQ on= 5-6K,Off=4K,WOB=20-30K, RPM=100,GPM=600 with 2300 psi 07/11/2012 _ __..,CaledfL.6130'T/7Q42'TD.made short trip with no problems,Circ 3 bottoms up. 00:00 06:00 6.00 6,130 6,404 INTRMI DRILL DRLG P Drill F/6130'MDT/6404'MD,TVD= 5916',ART=2.3,AST=3.18,ADT= 5.48, Jar hrs.42.67, Bit hrs 42.67, Max gas 147 units, ECD=10.65, PUW-168,SOW-151, ROT-160, TQ on 5-8,TQ off-4.5 06:00 12:00 6.00 6,404 6,666 INTRM1 DRILL DDRL P Drill F/6404'MDT/6666'MD,TVD= 6039',ART=2.23,AST=1.48,ADT= 3.71, P/U=171K, S/O=161K, ROT= 160K,TQ on=5-8K,Off=6K,Max Gas=582 units,Jar hrs=46.38, Bit hrs=46.38 12:00 17:30 5.50 6,666 7,042 INTRMI DRILL DRLG P Drill f/6666't/7042', 6304'TVD, ART-2 69,AST-1.65,ADT-4.34, Total Jar HRS-50.72, Bit HRS- 50.72, PUW-179,SOW-154, ROT- 165,Tq On-5-7 K Off-4K, ECD- 10.6, RPM 90,580 GPM 17:30 19:30 2.00 7,042 7,042 INTRM1 DRILL CIRC P Circ. Bottoms up x 3 @ 500 gpm 2025 psi,shakers cleaned up 19:30 19:45 0.25 7,042 7,042 INTRM1 DRILL OWFF P Observe well for flow(static) 19:45 22:00 2.25 7,042 2,590 INTRM1 DRILL TRIP P POOH on elevators F/7042'MD T/ 2590'MD 22:00 22:30 0.50 2,590 2,590 INTRMI DRILL OWFF P Monitor well(static) 22:30 00:00 1.50 2,590 4,185 INTRMI DRILL TRIP P RIH F/2590'MDT/4185'MD 07/12/2012 Pooh F/7042'no hole issues,circ.bottoms up at shoe,slip and cut drill line, pooh LID BHA,flush stack pull wear ring,set test ply change out up,Eer rams t/7"test to 250 low 3500 high, R/D test equip. R/U casing equip. PJSM, P/U casing bottom nose of shoe broke,wait on replacement jt. RIH w/7"casing as per detail t/ 129'. Page 28 of 38 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 00:00 01:00 1.00 4,185 6,947 INTRM1 DRILL TRIP P Continue RIH T/4185'T/6947', no hole issues. 01:00 01:30 0.50 6,947 7,042 INTRM1 DRILL WASH P Wash F/6947'T/7042'500 gpm, 2350 psi. 01:30 03:00 1.50 7,042 7,042 INTRMI DRILL CIRC P Circ. bottoms up x three,575 gpm 2590 psi,max gas observed 338 units. 03:00 03:15 0.25 7,042 7,042 INTRM1 DRILL OWFF P Observe wel for flow static. 03:15 06:00 2.75 7,042 2,590 INTRM1 DRILL TRIP P POOH F/7042'T/2590'no hole issues. 06:00 06:45 0.75 2,590 2,590 INTRM1 DRILL CIRC P Circ.botoms up 520 gpm 1600 psi. 06:45 07:00 0.25 2,590 2,590 INTRM1 DRILL SFTY P PJSM,on cutting drilling line 07:00 08:15 1.25 2,590 2,590 INTRM1 DRILL SLPC P Slip&cut drill line 60'monitor well on trip tank, no gain no loss. 08:15 09:15 1.00 2,590 741 INTRMI DRILL TRIP P Continue POOH T/741'MD 09:15 09:30 0.25 741 741 INTRM1 DRILL OWFF P Monitor well(static) 09:30 11:00 1.50 741 0 INTRM1 DRILL PULD P Stand back 4 stands HWdp, UD 5 jts HWdp. UD jars and 3 joints NMDCs 11:00 12:00 1.00 0 0 INTRM1 DRILL OTHR P Down load MWD. 12:00 13:15 1.25 0 0 INTRM1 DRILL PULD P UD BHA Clear floor 13:15 15:00 1.75 0 0 INTRMI CASING OTHR P P/U Jt of drill pipe flush stack, pull wear ring,flush stack,set test plug 15:00 15:15 0.25 0 0 INTRM1 CASING SFTY P Pre Job safety meeting on changing rams. 15:15 16:30 1.25 0 0 INTRM1 CASING OTHR P Change upper rams U 7"solid body, simops change saver sub t/4"XT 39. 16:30 17:15 0.75 0 0 INTRMI CASING RURD P R/U and test 7"rams and door seals V 250 low 3500 high. R/D test equipment. 17:15 17:30 0.25 0 0 INTRM1 CASING SFTY P Pre job safety meeting on rigging up to run casing. 17:30 20:15 2.75 0 0 INTRM1 CASING RURD P R/u t/run 7"casing,bails franks tool elevators,spiders,power tongs&p/u sling. 20:15 20:30 0.25 0 0 INTRM1 CASING SFTY P Pre Job safety meeting on running 7" casing. 20:30 20:45 0.25 0 0 INTRM1 CASING RNCS P P/U first shoe jt. Bottom nose broke off. Lay down same wait on replacement jt. 20:45 22:45 2.00 0 0 INTRM1 CASING RNCS T Wait on replacement shoe jt.f/ warehouse 22:45 00:00 1.25 0 129 INTRM1 CASING RNCS P Run in hole w/7"casing as per detail t/129' 07/13/2012 Continue RIH w/7"casing t/7038',break circ.every 500'in open hole, No hole issues,circ botoms up 105 gpm 600 psi, R/D casing equip. M/U cement head,Circ and condition mud stage pumps U 210 gpm 600 psi, Perform first stage cement job, bump plug test floats,open HES cementer,estab. circ.perform 2nd stage cement job land plug close,cementer. R/D cement equip., Nipple down stack 00:00 00:15 0.25 129 129 INTRMI CASING RNCS P Check float equip.floats good 00:15 11:30 11.25 129 7,038 INTRM1 CASING RNCS P Continue RIH w/7"casing as per detail T/7038'MD Page 29 of 38 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 11:30 12:00 0.50 7,038 7,042 INTRM1 CEMEN'CIRC P CBU with Franks tool,2.5 BPM 600 psi P/U= 185K,S/O=145K. 12:00 12:45 0.75 7,042 7,042 INTRM1 CEMEN'CIRC P Continue Circ&Cond. mud with Franks tool,2.5 bpm 600 psi. 12:45 13:30 0.75 7,042 7,042 INTRMI CEMEN"OTHR P UD Franks fill up tool and M/U cement head. 13:30 16:30 3.00 7,042 7,042 INTRMI CEMEN"CIRC P Circ&Cond Mud for cement job @ 4.5 bpm,600 psi, P/U=180K,S/0= 145K. 16:30 16:45 0.25 7,042 7,042 INTRM1 CEMEN"CMNT P Pre Job Safety Meeting on cementing i 16:45 19:00 2.25 7,042 7,042 INTRM1 CEMEN"CMNT P Pump 5 bbls CW-100, Pressure test 1 - lines U 4500 psi,test good,25 bbls CW-100,28 bbls mudpush 12 ppg, drop bottom plug,pump 2 bbls mudpush, load top plug,42.5_ bbls of 15.8 ppg cement,drop top plug,20 bbls H2O,displace w/rig 243 bbls 10.5 ppg mud,bump plug,pressure up U 1000 psi(500 psi over FCP) bleed off check floats held. 1850 CIP 19:00 19:45 0.75 7,042 7,042 INTRM1 CEMEN"CIRC P Load plug f/sencond stage cement / job, pressure up U 3000 psi,open ✓ HES stage collar,circ. Bottoms up @ 210 gpm 250 psi. 19:45 20:00 0.25 7,042 7,042 INTRM1 CEMEN"SFTY P Pre job safety meeting for second stage cement job. 20:00 20:15 0.25 7,042 7,042 INTRMI CEMEN"CMNT P Batch up,Continue to circ @ 5 bpm with 250 psi. 20:15 21:15 1.00 7,042 7,042 INTRM1 CEMEN"CMNT P Pump 2nd stage per detail.20 bbls CW-100,30 bbls mudpush 11.3 ppg, 32 bbls 12.5 cement,drop plug and displace with 108 bbls 10.5 ppg mud, close ES cementer with 1600 psi and held 1500 psi for 5 mins,bleed off and check cementer good. 21:15 21:30 0.25 7,042 7,042 INTRM1 CEMEN"OWFF P Monitor well(static) 21:30 21:45 0.25 7,042 7,042 INTRM1 CEMEN"SFTY P PJSM on rigging down cement head 21:45 22:30 0.75 7,042 7,042 INTRM1 CEMEN'CIRC P rig down cement head drain stack and vac out casing stump 22:30 22:45 0.25 7,042 7,042 INTRM1 CEMEN"SFTY P PJSM on nipple down stack 22:45 23:30 0.75 7,042 7,042 INTRMI CEMEN"NUND P Nipple down stack 23:30 00:00 0.50 7,042 7,042 INTRM1 CEMEN"OTHR P P/U 50K and set slips with FMC 07/14/2012 R/U WACHS cutter,cut casing,dress cut,simops lay down casing equipment, N/D BOP&drilling spool, set and test pack off, N/U tubing spool&BOP stack,set wear ring, P/U tam port shifting tool, RIH w/4"DP f/ derrick U 2018'and freeze protect 9-5/8"X 7"with 54 bbls diesel. 00:00 00:45 0.75 7,042 0 INTRM1 CEMEN"RURD P R/U WACHS cutter&cut 7"casing, simops UD casing equip. 00:45 01:15 0.50 0 0 INTRM1 CEMEN"OTHR P Dress and cut&L/D casing stub. (Leng.of cut joint 30.06') 01:15 01:30 0.25 0 0 INTRM1 CEMEN"SFTY P PJSM on N/D drilling spool 01:30 02:00 0.50 0 0 INTRM1 CEMEN"NUND P Nipple down drilling spool,simops R/D casing equip. Page 30 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 02:15 0.25 0 0 INTRM1 CEMEN'SFTY P PJSM on Packoff 02:15 02:45 0.50 0 0 INTRM1 CEMEN'OTHR P Set pack off per FMC. 02:45 03:00 0.25 0 0 INTRM1 CEMEN'SFTY P PJSM N/U tbg spool, adapter flange 03:00 06:00 3.00 0 0 INTRM1 CEMEN'NUND P Nipple up Tuging spool,double studded adaptor flange,test 7" packoff&11 x 3 spool t/250 low 3000 high for 10 min. 06:00 06:15 0.25 0 0 INTRM1 CEMEN'SFTY P PJSM on N/U BOPE 06:15 08:00 1.75 0 0 INTRM1 CEMEN'NUND P Nipple up BOPE 08:00 08:30 0.50 0 0 INTRM1 CEMEN'OTHR P Set wear bushing 6.25 ID,move HWDP, change elevators 08:30 08:45 0.25 0 0 INTRMI CEMEN'SFTY P PJSM Shuffle 5 HWdp in Derrick. 08:45 09:15 0.50 0 0 INTRM1 CEMEN'OTHR P Move 5"HWdp to other side of Derrick. 09:15 09:45 0.50 0 0 INTRM1 CEMEN'PULD P P/U BHA with tam port shifting tool. 09:45 12:00 2.25 0 0 INTRM1 CEMEN'TRIP P RIH w/4"dp from derrick. 12:00 12:30 0.50 2,021 2,021 INTRMI CEMEN'OTHR P M/U single and engage Tam port Collar @ 2021'MD, Latch up and confirm, Line up OA to pits and test seals to 500 psi(Good), Bleed off to 250 psi and set down&open ports with 25K,Observed psi drop off with 1 foot down travel. 12:30 13:00 0.50 2,021 2,021 INTRM1 CEMEN'CIRC P Circ down dp and flush OA with water @ 6 BPM 1000 psi, untill clean,pumped 3 Annulur volumes. 13:00 13:15 0.25 2,021 2,021 INTRM1 CEMEN'OTHR P PJSM on R/U little Red and freeze protection. 13:15 13:30 0.25 2,021 2,021 INTRMI CEMEN'OTHR P R/U little Red test lines to 2000 psi, Observed fluid had dropped in hole due seals relaxing& U-Tube from IA to dp, Filled hole with water and closed annulur. 13:30 14:30 1.00 2,021 2,021 INTRM1 CEMEN'CIRC P Reverse Freeze protection down OA through port up dp with 54 bbls of diesel @ 1.25 bpm 200 psi and final at 500 psi,shut well in. 14:30 15:00 0.50 2,021 2,021 INTRM1 CEMEN'OTHR P P/U with string and close port with 15K, Pressure up on dp with 100 psi to confirm port was closed,Good, Bleed off and open kill,slack off and release tool with 1/4 right turn, P/U 2' and shear check valve with 2200 psi. 15:00 15:45 0.75 2,021 2,021 INTRM1 CEMEN'CIRC P Circ and balance out well to 10.0 ppg @ 5 bpm 350 psi. 15:45 16:00 0.25 2,021 1,985 INTRM1 CEMEN'PULD P Lay down single&pup, Blow down Top Drive 16:00 16:15 0.25 1,985 1,985 INTRM1 CEMEN'OWFF P Monitor well(Static) 16:15 17:30 1.25 1,985 0 INTRM1 CEMEN'TRIP P POOH with Tam Port tool 17:30 18:15 0.75 0 0 INTRM1 CEMEN'OTHR P Clear and clean rig floor, inspect saver sub(Bad) Page 31 of 38 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 18:15 19:00 0.75 0 0 INTRM1 CEMEN'OTHR P Drain stack, Pull wear ring,Obtain RKB measurements and set test plug. 19:00 19:15 0.25 0 0 INTRM1 CEMEN"SFTY P PJSM on changing out rams and saver sub 19:15 00:00 4.75 0 0 INTRM1 CEMEN"OTHR P C/O Upper 7"rams to 3.5"X 6" VBRs, rebult Lower 2-7/8"X 5"VBR and blind rams,while changing out saver sub and rigging up to test 07/15/2012 Replace Ram door seal,Test BOPE,hang blocks slip&cut 277'drilling line,service rig, P/U drilling BHA, shallow test,and pick up singles from shed. 00:00 00:15 0.25 0 0 INTRM1 CEMEN"SFTY P Pre Job Safety Meeting 00:15 01:00 0.75 0 0 INTRM1 CEMEN"NUND P C/O Blind rams, install choke line 01:00 01:45 0.75 0 0 INTRM1 CEMEN"RURD P R/U test equip. Fill stack&surface lines,attempt body test,door seals leaking tighten up bolts.(Test waived by Chuck Scheve with AOGCC) 01:45 05:45 4.00 0 0 INTRM1 CEMEN-BOPE P Retest same door seals leaking, drain stack, blow down lines,remove choke lines,open blind rams change door seals, close doors install choke line,fill lines and stack with water, R/U t/test BOP's 05:45 12:00 6.25 0 0 INTRM1 CEMEN'BOPE P Test BOP's,test all Rams and choke valves T/250 low/3500 high,Test annulur T/2500 psi and record on chart.Tested with 3.5"&4.5"test Po° joints.Accumulator Test=Inital /v{Y pressure 3000 psi, Pressure after closing= 1800 psi, Full pressure atained in 45 sec,full pressure attained in 193 sec. Bottles avg= 1950 psi 12:00 12:30 0.50 0 0 INTRM1 CEMEN"BOPE P C/O test joint F/3.5"T/4.5" 12:30 13:45 1.25 0 0 INTRM1 CEMEN'BOPE P Test lower 2-7/8"x 5"VBR, Upper 3.5"x 6"VBR to 250 low/3500 high and record same on chart. 13:45 14:30 0.75 0 0 INTRM1 CEMEN"OTHR P R/D test equipment,set wear ring and clear floor. 14:30 14:45 0.25 0 0 INTRM1 CEMEN'SFTY P PJSM,on slip and cut drilling line 14:45 16:30 1.75 0 0 INTRM1 CEMEN"SLPC P Hang blocks and slip and cut 277'of drilling line. 16:30 17:30 1 00 0 0 INTRM1 CEMEN'SVRG P Service Top Drive, Drawworks, Iron roughneck and Skate 17:30 18:00 0.50 0 0 INTRM1 CEMEN"SFTY P PJSM on bring tools to rig floor and P/U BHA with Sperry service hands 18:00 18:15 0.25 0 0 INTRM1 CEMEN'OTHR P Bring subs and tools up to rig floor 18:15 20:15 2.00 113 113 INTRM1 CEMEN'PULD P M/U BHA#31 to 113' 20:15 21:30 1.25 113 175 INTRM1 CEMEN'PULD P Up load MWD data 21:30 21:45 0.25 175 175 INTRM1 CEMEN'PULD P P/U NM DCs,X/O and 10'pup and make up to Top Drive 21:45 22:15 0.50 175 175 INTRM1 CEMEN"CIRC P Shallow test MWD tools with 6 bpm and 1150 psi Page 32 of 38 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 22:15 22:30 0.25 175 175 INTRM1 CEMEN"PULD P PJSM with Sperry on sources 22:30 22:45 0.25 175 175 INTRMI CEMEN"PULD P Load Sperry nuke sources into tools 22:45 00:00 1.25 175 393 INTRM1 CEMEN"TRIP P RIH with BHA F/175.2 T/393' 07/16/2012 Single in the hole with drilling BHA, Rotate through tam port collar,tag&drill HES cementer @ 3350', continue RIH tag cement stringers @ 6850'wash t/6890', R/U and perform casing test t/3500 psi f/30 min. test good,drill baffle collar shoe track and 20'of new hole t/7062'displace mud t/11.1 ppg perform Fit t/ 11.58 ppg EMW, Drill t/TD @ 7450',6950 TVD 00:00 00:15 0.25 393 393 INTRM1 CEMEN"SFTY P Pre job safety meeting on tripping in hole 00:15 03:00 2.75 393 3,337 INTRM1 CEMEN"TRIP P RIH t/1983', M/U top drive rotate throught tam port collar,continue single in hole U 3337' 03:00 03:30 0.50 3,337 3,337 INTRM1 CEMEN"CIRC P Circ bottoms up 210 gpm 1125 psi, 03:30 04:30 1.00 3,337 3,337 INTRM1 CEMEN"PRTS P R/U&test casing to 3500 psi f/10 min.good test, R/D test equipment. 04:30 06:45 2.25 3,337 3,352 INTRM1 CEMEN"DRLG P Wash U 3350'drill ES cementert 3352', 168 gpm 900 psi,40 rpm 2k torque. 06:45 09:00 2.25 3,352 6,850 INTRM1 CEMEN"TRIP P Continue RIH f/3352'U 6850'tk wt. 09:00 09:15 0.25 6,850 6,890 INTRM1 CEMEN"WASH P Break Circ.210 gpm 1600 psi 40 rpm wash through cement stringer U 6890' 09:15 10:15 1.00 6,890 6,890 INTRM1 CEMEN"CIRC P Circ&condition mud 210 gpm 1600 psi 10:15 11:30 1.25 6,890 6,890 INTRMI CEMEN"PRTS P R/U&test 7"casing U 3500 psi f/30 min.Good Test, R/D test equipment. 11:30 14:00 2.50 6,890 7,062 INTRMI CEMEN"DRLG P Drill cement U 6914'drilling baffle collar,210 gpm 1500 psi 40 rpm 4K torque,continue drilling cement U 6957'drill shoe track U 7042'drill U 7062' 14:00 14:45 0.75 7,062 7,062 INTRM1 CEMEN"CIRC P Displace well U 11.1ppg @ 210 gpm 1750 psi. 14:45 15:30 0.75 7,062 7,062 INTRM1 CEMEN"FIT P R/U&perform FITU 15.82ppg EMW. 15:30 16:00 0.50 7,062 7,062 INTRM1 DRILL OTHR P Obtian PWD base line 16:00 18:00 2.00 7,062 7,150 PROD1 DRILL DRLG P Drilling f/7062'U 7150,295 gpm 3400 psi art 2.27,ast 0, adt 2.27, tatoal jar hrs. 134.27,bit hrs 2.27 ecd-12.68 18:00 00:00 6.00 7,150 7,450 PROD1 DRILL DRLG P Drilling f/7150'U TD @ 7450'MD 6950 TVD,art 2.19,ast 1.08,adt 3.27,jar hrs 137.54, bit hrs 5.54,ecd 12.84. 07/17/2012 Circ. Bottoms up x 3 300 gpm 3250 psi,80 rpm 3k tq,pump 25 bbls Hi-VIs sweep.Observe well for flow static, Pooh on elevators U 6995'incorrect displacement,observe well for flow static, RIH U 7450',circ bottoms up x 3, 1200 units of gas on bottoms up,pump 25 bbls Hi-Vis sweep,pump out of hole U 6988' Observe well for flow,slight ooze, RIH U 7450 weight up U 11.6ppg MW, Observe well for flow static, POOH on elevators U 5286'. 00:00 00:30 0.50 7,450 7,450 PROD1 DRILL CIRC P Continue CBU X 3 @ 300 gpm,3250 psi, Rotate 80 RPM, Pump 25 bbl hi-vis sweep, ECD-12.67 ppg. L_ Page 33 of 38 Time Logs Date From To Dur S. Death E. Depth Phase Code Subcode T Comment 00:30 00:45 0.25 7,450 7,450 PROD1 DRILL OWFF P Monitor well(static) 00:45 01:15 0.50 7,450 7,040 PROD1 DRILL WPRT P POOH on elevators to shoe, P/U= 135K,S/O=110K, Incorrect hole displacement 01:15 01:30 0.25 7,040 7,040 PROD1 DRILL OWFF P Minotor well(static) 01:30 01:45 0.25 7,040 7,450 PROD1 DRILL WPRT P RIH T/7450'MD,Actual=3.7 bbl, Calculated=2.16 bbl. 01:45 03:00 1.25 7,450 7,450 PROD1 DRILL CIRC P CBU X 3 @ 300 gpm,3250 psi, Rotate 80 RPM,pump 25 bbl hi-vis sweep,(1200 units of gas on btms up.) 03:00 04:15 1.25 7,450 6,988 PROD1 DRILL TRIP P POOH, Pump out of hole, F/7365' MD T/6988'MD with 30 spm and 800 psi. 04:15 05:15 1.00 6,988 6,988 PROD1 DRILL OWFF P Monitor well,slight flow after 20 min, CBU 300 gpm with 3150 psi, 1200 units of gas on bottoms up. 05:15 05:30 0.25 6,988 6,988 PROD1 DRILL OWFF P Monitor well,slight flow,decision to RIH and weight up to 11.6 ppg. 05:30 06:00 0.50 6,988 7,450 PROD1 DRILL TRIP P RIH T/7450'MD 06:00 0815 2.25 7,450 7,450 PROD1 DRILL CIRC P Circ @ 7450'300 gpm, rotate 50 RPM and weight up to 11.6 ppg 08:15 08:45 0.50 7,450 7,450 PROD1 DRILL OWFF P Monitor well, Pull one stand, observed fluid drop in stack 08:45 09:30 0.75 7,450 6,893 PROD1 DRILL TRIP P POOH with 5 stands on elevators T/6893'MD, P/U=135K, 1.5 bbl displacement. 09:30 09:45 0.25 6,893 6,893 PROD1 DRILL OWFF P Monitor well,Static,drop 2-3/8" Rabbit on wire on stand 65 09:45 12:00 2.25 6,893 5,286 PROD1 DRILL TRIP P POOH on elevators T/5286'MD, Calculated=11.1 bbls,Actual=8.4 due to slug falling 12:00 13:30 1.50 5,286 660 PROD1 DRILL TRIP P Coninue POOH F/5286'T/660'MD' 13:30 14:00 0.50 660 660 PROD1 DRILL OWFF P Monitor well(Static) 14:00 14:30 0.50 660 236 PROD1 DRILL PULD P UD HWT. F/660'MD T/236'MD 14:30 14:45 0.25 236 236 PROD1 DRILL SFTY P PJSM on Nukes and BHA 14:45 16:00 1.25 236 90 PROD1 DRILL PULD P UD 2 NM DCs,unload sources and last DC 16:00 17:15 1.25 90 90 PROD1 DRILL OTHR P Down load MWD darta 17:15 18:00 0.75 90 0 PROD1 DRILL PULD P UD rest of BHA 18:00 18:45 0.75 0 0 PROD1 CASING OTHR P Clear and clean rig floor 18:45 20:00 1.25 0 0 PROD1 CASING OTHR P R/U 4.5"casing tools 20:00 20:15 0.25 0 0 PROD1 CASING SFTY P PJSM running liner 20:15 21:00 0.75 0 75 PROD1 CASING PUTB P M/U&run 12.6 ppf, 4.5" L-80, IBTM liner,Attempt to RIH tight tight tolerance on centrailizer,2 jts total, (Centrailizer measured 5.5"OD on Bands and 7.250"on center of blades) Page 34 of 38 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 21:00 22:30 1.50 0 0 PROD1 CASING OTHR T Take off bow spring centrailizer and restock and bring 5.875"Ridge Full Body slip on Centrailizers to rig floor. 22:30 00:00 1.50 75 0 PROD1 CASING OTHR T Call town and discuss options, decision to change them out. 07/18/2012 PJSM, run 4.5 liner per detail, 17 jts,8 straight blade centrilizers, M/U seal bore ext.&hanger,w/running tool,M/U 4"dp RIH t/4852',break circ.gass cut mud on bottoms up, circ.gas out,cont. RIH t/7020',circ. cond. mud, Rih t/7450'M/U cement head.est.circ.stage pumps t/168 gpm 800 psi Pump cement as per dowel!,set hanger,set packer, circ bottoms up, Displace well t/11.3ppg brine, R/D cement lines,Safety stand down with both crews. 00:00 00:15 0.25 0 0 COMPZ CASING PUTB P PJSM on run 4.5"liner 00:15 01:15 1.00 0 578 COMPZ CASING PUTB P Run 4.5"liner per detail 17 joints with 8 straight blade centralizers T/ 577.74'MD 01:15 02:00 0.75 578 633 COMPZ CASING PUTB P M/U Seal Bore Extention and hanger with running tool T/633.38'MD 02:00 02:30 0.50 633 633 COMPZ CASING RUNL P M/U stand of 4"dp and break circulation with 4 bpm 200 psi, P/U= 40K,S/0=40K 02:30 04:30 2.00 633 3,090 COMPZ CASING RUNL P RIH with 4.5"liner on 4"dp T/3090' MD 04:30 05:00 0.50 3,090 3,090 COMPZ CASING CIRC P Break circulation due to gas cut mud, pumped 3 bpm with 300 psi, CBU. 05:00 06:15 1.25 3,090 4,852 COMPZ CASING RUNL P Continue to RIH F/3090'MDT/4852' MD 06:15 07:30 1.25 4,852 4,852 COMPZ CASING CIRC P Break circulation again due to gas cut mud with 3 bpm and 350 psi, CBU. 07:30 09:00 1.50 4,852 7,020 COMPZ CASING RUNL P Continue RIH F/4852'MD T/7020' MD 09:00 10:30 1.50 7,020 7,020 COMPZ CASING CIRC P Fill pipe and circ.and cond.mud, weight up to 11.6 ppg 10:30 12:00 1.50 7,020 7,450 COMPZ CASING RUNL P Continue RIH F/7020'MDT/7433' MD, P/U= 125K,S/O=110K, M/U single with cement head and wash down to 7450'MD,Calcuated=44.6 bbls,Actual=52 bbls. 12:00 14:45 2.75 7,450 7,448 COMPZ CASING CIRC P Tag Bottom @ 7450'MD,set down with 3K, P/U 2',stage pumps up to 4 bpm with 800 psi,Circulate and Condition mud,SIM-OPS, held PJSM for cementing and displacement,and Batch up cement. Page 35 of 38 Time Logs I Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 14:45 15:45 1.00 7,448 7,448 PROD1 CASING PUCM P Pump 5 bbls CW-100, PT cmt lines to 500/4500 psi.(good)pumped 5 bbls of CW-100, 15 bbls of 13.0 ppg C,t4 mudpush II and 19 bbls of 15.8 ppg Gasblock cement,i ut in and flush lines with 11.6 ppg mud,drop dart and displace with 79.3 bbls of 11.6 ppg mud from Dowell,Observed latch up and bump dart,pressure up to 3500 psi and held for 3 min,bleed off and check floats(good). Reciprocated liner through out'/ cement job, parked 2'off bottom @ 7448'MD. 15:45 16:00 0.25 7,448 7,448 PROD1 CASING OTHR P S/O and set liner hanger with 50K, P/U to netral,set down 20K. 16:00 16:15 0.25 7,448 7,448 PROD1 CASING CMNT P Rig down cementing line. 16:15 16:30 0.25 7,448 6,821 PROD1 CASING OTHR P Release liner with 10 right turns, pressure up to 700 psi, P/U and observe pack-off clear liner top,Circ 10 bbls to clear cement @ 4 bpm 700 psi,Set down with 40K to set packer as per-Baker rep. 16:30 17:00 0.50 6,821 6,821 PROD1 CASING CIRC P CBU @ 8 bpm with 1675 psi Estimated 7 Bbls cement returned to Rock Washer. 17:00 17:45 0.75 6,821 6,821 PROD1 CASING CIRC P Displace well 11.6 ppg LSND to 11.3 ppg NaCUNaBR Brine. Pumped 25 bbl of hi-vis 11.6 ppg LSND and 35 bbl surfactant water sweep,350 bbl chased with 11.3 Brine. 17:45 18:00 0.25 6,821 6,821 PROD1 CASING OTHR P R/D cement head,blow down Top Drive and cement lines. 18:00 21:00 3.00 6,821 0 PROD1 CASING TRIP P POOH with kliner running tool F/ 6840'and UD runnign tool, Fill for trip=Calculated=39 bbls,Actual= 10.8 bbls. 21:00 23:30 2.50 0 0 PROD1 CASING OTHR P Clear rig floor,break down cement head, R/U t/UD 5"dp. 23:30 00:00 0.50 0 0 PROD1 CASING SFTY P Safety stand down with both crews 07/19/2012 Had Safety Stand Down with both crews, PJSM Lay down 70 stds of 5"dp in mouse hole from derrick, PJSM R/U and ran 215 jts of 3.5"TBG,spaced out and landed,Tested tubing to 3500 psi, bled tubing down to 2500 psi and tested annulus to 3500 psi,OK. hold for 30 min,bled tubing off and sheared valve. 00:00 00:30 0.50 0 0 COMPZ CASING SFTY P Safety Stand Down with both crews 00:30 00:45 0.25 0 0 COMPZ CASING SFTY P PJSM on UD 5" 00:45 01:00 0.25 0 0 COMPZ CASING OTHR P Change to 5"elevators 01:00 07:00 6.00 0 0 COMPZ CASING OTHR P Lay down 5"dp in mouse hole(228 jts)from derrick. 07:00 08.00 1.00 0 0 COMPZ CASING OTHR P Clear and clean rig floor, UD mouse hole, Pull wear ring,M/U floor safety valve, Bring up tongs to rig floor. 08:00 08:45 0.75 0 0 COMPZ CASING PRTS P R/U and test liner lap top t/3500 psi and record on chart for 15 min, R/D test equipment. Page 36 of 38 Time Logs Date From To Dur S. Depth E. Deoth Phase Code Subcode T Comment 08:45 09:00 0.25 0 0 COMPZ RPCOM SFTY P PJSM on R/U Tubing tools. 09:00 09:15 0.25 0 0 COMPZ RPCOM RCST P R/U to run tubing. 09:15 09:30 0.25 0 0 COMPZ RPCOM SFTY P PJSM on running tubing. 09:30 12:00 2.50 0 1,706 COMPZ RPCOM RCST P Run 3.5"9.3 ppf TBG per running order to 1706'MD, P/U=45K,S/O= 47K,Calculated=5.4 bbls,Actual= 5.8 bbls. 12:00 12:15 0.25 1,706 1,706 COMPZ RPCOM SFTY P PJSM with new crew on tour 12:15 13:00 0.75 1,706 2,226 COMPZ RPCOM RCST P Continue running completion TBG to 2226'MD, Found joints were being over torqued and a discrepency in tally. 13:00 13:15 0.25 2,226 2,226 COMPZ RPCOM SFTY T PJSM on stand back TBG 13:15 15:00 1.75 2,226 545 COMPZ RPCOM OTHR T POOH and stand back tbg in derrick to 545 MD, Replaced 6 jts over torqued and add two jts under first GLM. 15:00 16:00 1.00 545 2,226 COMPZ RPCOM TRIP T RIH with TBG from derrick F/545' T/2226.0' 16:00 16:30 0.50 2,226 2,226 COMPZ RPCOM OTHR T Adjust Running order in shed 16:30 19:30 3.00 2,226 5,063 COMPZ RPCOM RCST P RIH with 3.5"TBG F/2226'MDT/ 5063'MD 19:30 19:45 0.25 5,063 5,063 COMPZ RPCOM SFTY P PJSM,With Camco on spooler 19:45 21:00 1.25 5,063 5,063 COMPZ RPCOM OTHR P R/U controler spool and line 21:00 00:00 3.00 5,063 6,781 COMPZ RPCOM RCST P Continue RIH wit 3.5"TBG F/5063' MDT/6781'MD,Total 07/20/2012 Land tubing on no-go space out,land tubing on hanger @ 6873'RILDS,Test tubing and ann.t/3500 psi, shear DCK valve, install BPV test in direction of flow, nipple down bop's, nipple up tree,test t/5000 psi, freeze protect well w/90 bbls of diesel,allow to u-tube,secure wellhead, lay down 4"dp,clean rig drip pans, sumps, release rig @ 2400 hrs 00:00 00:30 0.50 6,781 6,879 COMPZ RPCOM PUTB P Continue t/rih w/3.5 tubing V 6879' tag no go 00:30 00:45 0.25 6,879 6,879 COMPZ RPCOM PRTS P R/U&test seal bore ext.t/500 psi f/ 10 min, R/D 00:45 02:30 1.75 6,879 6,873 COMPZ RPCOM PULD P Lay down tubing joints,pick up space out pups,and joint of tubing& hanger,Terminate control line, land tubing on hanger @ 6873'RILDS 02:30 05:45 3.25 6,873 0 COMPZ RPCOM PRTS P R/U&test tubing t/3500 psi f/30 min, bleed tubing psi t/2200 psi,test Ann.V 3500 psi f/30 min. Bleed off tubing psi and shear DCK valve. bleed off and rig down test equip. 05:45 06:15 0.50 0 0 COMPZ RPCOM OTHR P Set BPV,Test in direction of flow t/ 1500 psi. R/D test equip. 06:15 06:45 0.50 0 0 COMPZ RPCOM OWFF P Observe well for flow static monitor f/ 30 min. 06:45 07:00 0.25 0 0 COMPZ RPCOM SFTY P Pre job safety meeting on nippling down BOP Page 37 of 38 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:00 10:30 3.50 0 0 COMPZ RPCOM NUND P Nipple down BOP&DSA, nipple up adaptor flange and test t/5000 psi f/ 15 min. Nipple up tree terminate control line through wellhead. 10:30 10:45 0.25 0 0 COMPZ RPCOM SFTY P Pre job safety meeting Testing tree. 10:45 13:00 2.25 0 0 COMPZ RPCOM PRTS P Pull BPV,set tree test plug Fill with diesel, R/U test equip.test tree t/ 5000 psi f/5 min, R/D test equip. Pull tree test plug. 13:00 13:15 0.25 0 0 COMPZ RPCOM RURD P R/U surface lines t/freeze protect. 13:15 13:30 0.25 0 0 COMPZ RPCOM SFTY P Pre job safety meeting on freeze protecting well. 13:30 16:00 2.50 0 0 COMPZ RPCOM FRZP P Pressure test lines t/2500 psi,good, displace ann.w/90 bbls 70°diesel, put ann.and tunbing in communication u-tube diesel static in 1 hr. R/D lines,secure wellhead. 16:00 16:15 0.25 0 0 COMPZ RPCOM SFTY P Pre job safety meeting on laying down drill pipe from derrick using mouse hole. 16:15 22:00 5.75 0 0 COMPZ RPCOM PULD P Lay down 4"dp from derrick 77 stands 22:00 00:00 2.00 0 0 COMPZ RPCOM OTHR P Clean rig drip pans,pollution pan, cellar sump,finish off loading pits. Rig realeased @ 23:59 hrs 7/20/2012 Page 38 of 38 n 1 ill a� 1 a� ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 3N Pad 3N-07A hT 11 5 Sperry Drilling a Definitive Survey Report 20 July, 2012 I i L s I i W 0 " HALLIBURTON k" Iii Sperry Drilling ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 3N-07 Project: Kuparuk River Unit TVD Reference: 3N-07A @ 60.95ft(D141 (28.1+33.9)) Site: Kuparuk 3N Pad MD Reference: 3N-07A @ 60.95ft(D141 (28.1+33.9)) Well: 3N-07 North Reference: True Wellbore: 3N-07A Survey Calculation Method: Minimum Curvature Design: 3N-07A Database: CPAI EDM Production Project Kuparuk River Unit Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well , 3N-07 Well Position +N/-S 0.00 ft Northing: 6,013,799.44 ft Latitude: 70°26'55.956 N +El-W 0.00 ft Easting: 518,096.21 ft Longitude: 149°51'8.533 W I Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 33.90ft Wellbore 3N-07A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2011 7/7/2012 20.45 81.01 57,638 Design 3N-07A Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 2,599.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (0) 27.05 0.00 0.00 353.22 Survey Program Date From To (ft) (ft) Survey(Wellbore) Tool Name Description Survey Date 93.95 2,599.00 3N-07(3N-07) GCT-MS Schlumberger GCT multishot 1/15/2001 12:C 2,640.47 2,974.03 3N-07A(3N-07A) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7/7/2012 12:0C 2,974.03 7,003.07 3N-07A(3N-07A) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7/7/2012 12:OC 7,003.07 7,415.77 3N-07A(3N-07A) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7/7/2012 12:0C Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°/100') (ft) Survey Tool Name 27.05 0.00 0.00 27.05 -33.90 0.00 0.00 6,013,799.44 518,096.21 0.00 0.00 UNDEFINED 93.95 0.32 57.72 93.95 33.00 0.10 0.16 6,013,799.54 518,096.37 0.48 0.08 GCT-MS(1) 193.95 0.45 31.27 193.95 133.00 0.58 0.60 6,013,800.03 518,096.81 0.22 0.51 GCT-MS(1) 293.95 0.48 10.48 293.94 232.99 1.33 0.88 6,013,800.77 518,097.08 0.17 1.22 GCT-MS(1) 393.95 0.48 359.18 393.94 332.99 2.16 0.95 6,013,801.60 518,097.15 0.09 2.04 GCT-MS(1) 493.95 0.53 355.27 493.94 432.99 3.04 0.90 6,013,802.48 518,097.11 0.06 2.91 GCT-MS(1) 593.95 0.67 341.50 593.93 532.98 4.06 0.68 6,013,803.50 518,096.88 0.20 3.95 GCT-MS(1) 693.95 0.75 329.45 693.92 632.97 5.18 0.16 6,013,804.62 518,096.36 0.17 5.12 GCT-MS(1) 793.95 0.68 327.00 793.92 732.97 6.24 -0.49 6,013,805.68 518,095.70 0.08 6.25 GCT-MS(1) 893.95 0.67 326.23 893.91 832.96 7.22 -1.14 6,013,806.66 518,095.05 0.01 7.31 GCT-MS(1) 993.95 0.83 323.80 993.90 932.95 8.29 -1.89 6,013,807.73 518,094.30 0.16 8.46 GCT-MS(1) 7/20/2012 10:28:51AM Page 2 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 3N-07 Project Kuparuk River Unit TVD Reference: 3N-07A @ 60.95ft(D141 (28.1+33.9)) Site: Kuparuk 3N Pad MD Reference: 3N-07A @ 60.95ft(D141 (28.1+33.9)) Well• 3N-07 North Reference: True Wellbore: 3N-07A Survey Calculation Method: Minimum Curvature Design: 3N-07A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi ND TVDSS +N/-S +El-W Northing Easting OLS Section (ft) (0) (0) (ft) (ft) (ft) (ft) (ft) (ft) (°l100') (ft) Survey Tool Name 1,093.95 0.87 318.93 1,093.89 1,032.94 9.45 -2.82 6,013,808.88 518,093.37 0.08 9.72 GCT-MS(1) 1,193.95 0.88 314.45 1,193.88 1,132.93 10.56 -3.87 6,013,809.99 518,092.32 0.07 10.94 GCT-MS(1) 1,293.95 0.78 312.90 1,293.87 1,232.92 11.56 -4.91 6,013,810.99 518,091.27 0.10 12.06 GCT-MS(1) 1,393.95 0.97 309.20 1,393.86 1,332.91 12.56 -6.07 6,013,811.98 518,090.11 0.20 13.19 GCT-MS(1) 1,493.95 1.03 306.18 1,493.84 1,432.89 13.62 -7.45 6,013,813.04 518,088.73 0.08 14.41 GCT-MS(1) 1,593.95 1.07 304.00 1,593.82 1,532.87 14.68 -8.95 6,013,814.09 518,087.23 0.06 15.63 GCT-MS(1) 1,693.95 1.10 303.55 1,693.81 1,632.86 15.73 -10.52 6,013,815.14 518,085.65 0.03 16.86 GCT-MS(1) 1,793.95 0.88 306.68 1,793.79 1,732.84 16.72 -11.94 6,013,816.13 518,084.23 0.23 18.01 GCT-MS(1) 1,893.95 0.90 305.22 1,893.78 1,832.83 17.63 -13.20 6,013,817.04 518,082.97 0.03 19.06 GCT-MS(1) 1,993.95 0.85 306.03 1,993.77 1,932.82 18.52 -14.44 6,013,817.92 518,081.73 0.05 20.09 GCT-MS(1) 2,093.95 0.80 308.88 2,093.76 2,032.81 19.39 -15.58 6,013,818.79 518,080.58 0.06 21.10 GCT-MS(1) 2,193.95 0.67 312.97 2,193.75 2,132.80 20.23 -16.55 6,013,819.63 518,079.61 0.14 22.04 GCT-MS(1) 2,293.95 0.52 324.12 2,293.74 2,232.79 21.00 -17.25 6,013,820.39 518,078.91 0.19 22.88 GCT-MS(1) 2,393.95 0.45 326.78 2,393.74 2,332.79 21.69 -17.73 6,013,821.09 518,078.43 0.07 23.63 GCT-MS(1) 2,493.95 1.72 341.58 2,493.72 2,432.77 23.44 -18.42 6,013,822.84 518,077.74 1.29 25.45 GCT-MS(1) 2,593.95 6.07 359.92 2,593.47 2,532.52 30.16 -18.90 6,013,829.55 518,077.24 4.47 32.18 GCT-MS(1) 2,599.00 6.13 0.50 2,598.49 2,537.54 30.70 -18.90 6,013,830.09 518,077.24 1.64 32.71 GCT-MS(1) 2,640.47 8.93 353.96 2,639.60 2,578.65 36.11 -19.22 6,013,835.50 518,076.91 7.06 38.13 MWD+IFR-AK-CAZ-SC(2) 2,696.84 10.66 347.76 2,695.15 2,634.20 45.56 -20.78 6,013,844.94 518,075.32 3.59 47.69 MWD+IFR-AK-CAZ-SC(2) 2,786.44 11.39 337.90 2,783.10 2,722.15 61.85 -25.87 6,013,861.23 518,070.19 2.25 64.48 MWD+IFR-AK-CAZ-SC(2) 2,823.08 12.01 343.25 2,818.98 2,758.03 68.86 -28.33 6,013,868.22 518,067.72 3.41 71.72 MWD+IFR-AK-CAZ-SC(2) 2,880.85 13.29 345.47 2,875.35 2,814.40 81.04 -31.73 6,013,880.40 518,064.29 2.37 84.22 MWD+IFR-AK-CAZ-SC(2) 2,974.03 15.34 345.98 2,965.63 2,904.68 103.37 -37.40 6,013,902.71 518,058.56 2.20 107.06 MWD+IFR-AK-CAZ-SC(2) 3,014.20 16.08 347.30 3,004.30 2,943.35 113.95 -39.91 6,013,913.28 518,056.03 2.05 117.87 MWD+IFR-AK-CAZ-SC(3) 3,107.87 17.54 350.19 3,093.96 3,033.01 140.52 -45.17 6,013,939.83 518,050.71 1.80 144.87 MWD+IFR-AK-CAZ-SC(3) 3,200.95 20.09 353.93 3,182.07 3,121.12 170.24 -49.25 6,013,969.54 518,046.55 3.03 174.86 MWD+IFR-AK-CAZ-SC(3) 3,293.22 24.17 356.97 3,267.52 3,206.57 204.88 -51.92 6,014,004.17 518,043.79 4.59 209.57 MWD+IFR-AK-CAZ-SC(3) 3,344.75 27.03 359.82 3,313.99 3,253.04 227.13 -52.52 6,014,026.42 518,043.14 6.04 231.74 MWD+IFR-AK-CAZ-SC(3) 3,382.74 29.16 0.69 3,347.50 3,286.55 245.02 -52.44 6,014,044.30 518,043.19 5.71 249.49 MWD+IFR-AK-CAZ-SC(3) 3,434.96 31.11 1.30 3,392.66 3,331.71 271.23 -51.98 6,014,070.51 518,043.58 3.78 275.47 MWD+IFR-AK-CAZ-SC(3) 3,478.97 32.23 1.43 3,430.12 3,369.17 294.33 -51.43 6,014,093.61 518,044.08 2.55 298.34 MWD+IFR-AK-CAZ-SC(3) 3,571.54 32.34 0.78 3,508.38 3,447.43 343.76 -50.47 6,014,143.04 518,044.91 0.39 347.32 MWD+IFR-AK-CAZ-SC(3) 3,661.06 31.48 0.31 3,584.37 3,523.42 391.08 -50.02 6,014,190.36 518,045.25 1.00 394.25 MWD+IFR-AK-CAZ-SC(3) 3,746.76 32.33 0.84 3,657.12 3,596.17 436.37 -49.56 6,014,235.64 518,045.59 1.04 439.17 MWD+IFR-AK-CAZ-SC(3) 3,844.21 33.82 2.48 3,738.78 3,677.83 489.52 -48.01 6,014,288.79 518,047.02 1.78 491.77 MWD+IFR-AK-CAZ-SC(3) 3,942.01 33.54 2.33 3,820.16 3,759.21 543.71 -45.73 6,014,342.98 518,049.16 0.30 545.31 MWD+IFR-AK-CAZ-SC(3) 4,035.80 33.38 2.70 3,898.41 3,837.46 595.37 -43.46 6,014,394.64 518,051.31 0.28 596.34 MWD+IFR-AK-CAZ-SC(3) 4,126.22 33.67 3.01 3,973.79 3,912.84 645.25 -40.97 6,014,444.52 518,053.67 0.37 645.57 MWD+IFR-AK-CAZ-SC(3) 4,218.58 34.35 3.48 4,050.35 3,989.40 696.82 -38.05 6,014,496.10 518,056.47 0.79 696.44 MWD+IFR-AK-CAZ-SC(3) 4,312.81 33.77 2.66 4,128.41 4,067.46 749.52 -35.22 6,014,548.80 518,059.18 0.79 748.44 MWD+IFR-AK-CAZ-SC(3) 7/20/2012 10:28:51AM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips (Alaska) Inc. Definitive Survey Report Company: ConocoPhillips(Alaska)Inc. Local Co-ordinate Reference: Well 3N-07 Project: Kuparuk River Unit TVD Reference: 3N-07A @ 60.95ft(D141 (28.1+33.9)) Site: Kuparuk 3N Pad MD Reference: 3N-07A @ 60.95ft(D141 (28.1+33.9)) Well: 3N-07 North Reference: True Wellbore: 3N-07A Survey Calculation Method: Minimum Curvature Design: 3N-07A Database: CPAI EDM Production Survey Map Map Vertical MD Inc Azi TVD TVDSS +N/-S +E/-W Northing Easting DLS Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°1100') (ft) Survey Tool Name 4,403.92 32.95 1.35 4,204.51 4,143.56 799.59 -33.46 6,014,598.86 518,060.81 1.20 797.95 MWD+IFR-AK-CAZ-SC(3) 4,498.05 32.77 359.11 4,283.58 4,222.63 850.65 -33.25 6,014,649.93 518,060.90 1.31 848.63 MWD+IFR-AK-CAZ-SC(3) 4,589.67 32.35 359.35 4,360.80 4,299.85 899.96 -33.92 6,014,699.22 518,060.11 0.48 897.67 MWD+IFR-AK-CAZ-SC(3) 4,682.49 32.23 358.98 4,439.27 4,378.32 949.54 -34.64 6,014,748.80 518,059.27 0.25 946.99 MWD+IFR-AK-CAZ-SC(3) 4,773.66 32.40 358.23 4,516.32 4,455.37 998.26 -35.83 6,014,797.51 518,057.97 0.48 995.51 MWD+IFR-AK-CAZ-SC(3) 4,867.36 32.53 358.79 4,595.38 4,534.43 1,048.54 -37.13 6,014,847.78 518,056.54 0.35 1,045.59 MWD+IFR-AK-CAZ-SC(3) 4,960.66 33.94 358.54 4,673.41 4,612.46 1,099.66 -38.33 6,014,898.89 518,055.22 1.52 1,096.50 MWD+IFR-AK-CAZ-SC(3) 5,052.12 33.22 358.61 4,749.61 4,688.66 1,150.23 -39.58 6,014,949.45 518,053.84 0.79 1,146.86 MWD+IFR-AK-CAZ-SC(3) 5,144.98 33.09 358.24 4,827.35 4,766.40 1,200.99 -40.98 6,015,000.21 518,052.32 0.26 1,197.44 MWD+IFR-AK-CAZ-SC(3) 5,237.49 32.56 357.22 4,905.09 4,844.14 1,251.10 -42.96 6,015,050.31 518,050.21 0.83 1,247.43 MWD+IFR-AK-CAZ-SC(3) 5,330.31 32.48 357.50 4,983.36 4,922.41 1,300.95 -45.26 6,015,100.14 518,047.79 0.18 1,297.20 MWD+IFR-AK-CAZ-SC(3) 5,422.16 32.24 357.35 5,060.94 4,999.99 1,350.06 -47.47 6,015,149.25 518,045.47 0.28 1,346.23 MWD+IFR-AK-CAZ-SC(3) 5,516.23 31.39 356.82 5,140.88 5,079.93 1,399.59 -49.99 6,015,198.76 518,042.83 0.95 1,395.71 MWD+IFR-AK-CAZ-SC(3) 5,608.45 32.10 357.12 5,219.30 5,158.35 1,448.04 -52.55 6,015,247.20 518,040.15 0.79 1,444.12 MWD+IFR-AK-CAZ-SC(3) 5,701.49 31.34 356.68 5,298.44 5,237.49 1,496.88 -55.20 6,015,296.04 518,037.39 0.85 1,492.94 MWD+IFR-AK-CAZ-SC(3) 5,794.19 31.68 355.80 5,377.48 5,316.53 1,545.23 -58.37 6,015,344.37 518,034.09 0.62 1,541.32 MWD+IFR-AK-CAZ-SC(3) 5,886.07 33.83 354.56 5,454.74 5,393.79 1,594.76 -62.57 6,015,393.88 518,029.78 2.45 1,591.00 MWD+IFR-AK-CAZ-SC(3) 5,978.78 36.19 352.06 5,530.68 5,469.73 1,647.57 -68.80 6,015,446.67 518,023.42 2.98 1,644.17 MWD+IFR-AK-CAZ-SC(3) 6,072.76 38.08 350.50 5,605.60 5,544.65 1,703.64 -77.41 6,015,502.71 518,014.67 2.25 1,700.87 MWD+IFR-AK-CAZ-SC(3) 6,164.42 40.11 348.02 5,676.73 5,615.78 1,760.41 -88.21 6,015,559.45 518,003.74 2.80 1,758.52 MWD+IFR-AK-CAZ-SC(3) 6,256.78 41.45 346.41 5,746.67 5,685.72 1,819.23 -101.57 6,015,618.24 517,990.24 1.84 1,818.50 MWD+IFR-AK-CAZ-SC(3) 6,349.89 44.39 345.50 5,814.85 5,753.90 1,880.73 -116.97 6,015,679.69 517,974.69 3.23 1,881.39 MWD+IFR-AK-CAZ-SC(3) 6,441.90 44.49 345.53 5,880.54 5,819.59 1,943.10 -133.08 6,015,742.02 517,958.43 0.11 1,945.23 MWD+IFR-AK-CAZ-SC(3) 6,534.76 44.84 344.14 5,946.59 5,885.64 2,006.10 -150.16 6,015,804.97 517,941.20 1.12 2,009.81 MWD+IFR-AK-CAZ-SC(3) 6,627.77 45.14 343.46 6,012.37 5,951.42 2,069.25 -168.50 6,015,868.07 517,922.70 0.61 2,074.67 MWD+IFR-AK-CAZ-SC(3) 6,720.89 44.58 344.18 6,078.38 6,017.43 2,132.33 -186.81 6,015,931.10 517,904.24 0.81 2,139.47 MWD+IFR-AK-CAZ-SC(3) 6,813.05 44.64 344.43 6,143.99 -6,083.04 2,194.64 -204.32 6,015,993.36 517,886.58 0.20 2,203.41 MWD+IFR-AK-CAZ-SC(3) 6,907.01 45.67 345.55 6,210.25 6,149.30 2,258.98 -221.57 6,016,057.65 517,869.18 1.38 2,269.34 MWD+IFR-AK-CAZ-SC(3) 7,003.07 45.80 347.45 6,277.30 6,216.35 2,325.87 -237.62 6,016,124.49 517,852.97 1.42 2,337.66 MWD+IFR-AK-CAZ-SC(3) 7,086.46 45.94 347.38 6,335.36 6,274.41 2,384.28 -250.66 6,016,182.87 517,839.78 0.18 2,397.20 MWD+IFR-AK-CAZ-SC(4) 7,138.53 45.71 347.88 6,371.64 6,310.69 2,420.76 -258.66 6,016,219.32 517,831.70 0.82 2,434.37 MWD+IFR-AK-CAZ-SC(4) 7,233.69 46.29 346.63 6,437.75 6,376.80 2,487.52 -273.77 6,016,286.04 517,816.43 1.12 2,502.45 MWD+IFR-AK-CAZ-SC(4) 7,327.80 45.67 346.24 6,503.15 6,442.20 2,553.31 -289.64 6,016,351.78 517,800.40 0.72 2,569.65 MWD+IFR-AK-CAZ-SC(4) 7,415.77 44.38 346.13 6,565.32 6,504.37 2,613.74 -304.50 6,016,412.17 517,785.40 1.47 2,631.41 MWD+IFR-AK-CAZ-SC(4) 7,450.00 44.38 346.13 6,589.79 6,528.84 2,636.98 -310.24 6,016,435.40 517,779.60 0.00 2,655.17 PROJECTED to TD /720/2012 1 :2 : 1 AM 0 8 5 Page 4 COMPASS 2003.16 Build 69 `Z'D5 Z WELL LOG TRANSMITTAL To: State of Alaska August 8, 2012 Alaska Oil and Gas Conservation Commission Attn.: Howard Okland 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501-3539 RE: LWD Formation Evaluation Logs: 3N-07A AK-MW-0008472258 3N-07A 50-029-21539-01 2" x 5" MD TRIPLE COMBO Logs: 1 Color Log 2" x 5"ND TRIPLE COMBO Logs: 1 Color Log Digital Log Images &LWDG-formatted LIS Data w/verification listing; 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Attn: Buster Bryant/Ben Schulze 6900 Arctic Blvd. Anchorage,Alaska 99518 Office: 907-273-3539/907-273-3536 Fax: 907-273-3535 Buster.Bryant(ihalliburton.com Ben'lamin.Schulze@ihalliburton.com 11 Date: � l to (��— Signed: Ferguson, Victoria L (DOA) From: Ferguson, Victoria L(DOA) Sent: Friday, July 06, 2012 10:18 AM To: 'Myers, Monty M' Cc: Schwartz, Guy L (DOA) Subject: RE: 3N-07A-9-5/8"Surface casing leak Monty, You have permission to proceed as outlined below. Thanx, Victoria From: Myers, Monty M Jmailto:Monty.M.Myers@conocophillips.coml Sent: Friday, July 06, 2012 8:21 AM To: Schwartz, Guy L(DOA); Ferguson, Victoria L (DOA) Subject: 3N-07A - 9-5/8" Surface casing leak Good morning all! We discovered a leak in our 9-5/8" surface casing at 2412' last night. We are able to pump in to the leak with 725 psi at 1 bpm using 9.9 ppg fluid. This give us a LOT of 15.7 ppg equivalent at that depth. I would like permission to proceed with cutting a window and drilling the intermediate section based on the plan forward. • The window will be at approximately 2600' • We only need a minimum LOT after we cut the window of 13.5 ppg • The intermediate section will topset the Kuparuk • We have an Ugnu D formation from 2740'-2840' MD that will be covered with cement • The cement will be placed 500'above and below the Ugnu D • This cement will also cover the leak I believe with the design of the well and the pressures of the reservoir that there will be no risk with drilling ahead to intermediate casing point. Please review and let me know if we have permission to proceed. If you need any other information please let me know. Thank you very much! Have a great Friday! Monty M Myers Drilling Engineer ConocoPhillips Alaska 907.265.6318 office 907.538.1168 cell 1 s('.6a, 1 [IF dr r SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W 7th AVENUE,SUITE 100 CONSERVATION CO1'IItiISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 G. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3N-07A ConocoPhillips Alaska, Inc. Permit No: 212-052 (revised) Surface Location: 1561' FSL, 304' FEL, SEC. 29, T13N, RO9E, UM Bottomhole Location: 1103' FNL, 610' FEL, SEC. 29, T13N, RO9E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit supersedes and replaces the permit previously issued for this well dated April 25, 2012. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, A ' P'46.4,4„ Cathy r. Foerster Chair DATED this /Q day of July, 2012. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) • RECEIVED STATE OF ALASKA JUL l i 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL AOGCC 20 AAC 25.005 P I-S1 o''' • 1a.Type of Work: , lb.Proposed Well Class: Development-Oil 2 . Service-Winj ❑ Single Zone Q •1c.Specify if well is proposed for: Drill ❑ Re-drill❑., Stratigraphic Test ❑ Development-Gas❑ Service-Supply ❑ Multiple Zones Coalbed Gas ❑ Gas Hydrates❑ Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: LJ Blanket U Single Well 11.Well Name and Number: ConocoPhillips Alaska,Inc. Bond No. 59-52-180 • 3N-07A • 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD:7429' • TVD: 6589' • Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 1561'FSL,304'FEL,Sec.29,T13N,RO9E,UM - ADL 25521 • Kuparuk River Oil Pool • Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1250'FNL,571'FEL,Sec.29,T13N, RO9E, UM 2557 5/7/2012 Total Depth: 9.Acres in Property: 14.Distance to 1103'FNL,610'FEL,Sec.29,T13N, RO9E, UM . 2560 Nearest Property: >1 mile 4b Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 62 feet ' 15.Distance to Nearest Well Open Surface:x- 518096 y- 6013799 Zone- 4 GL Elevation above MSL: 34 feet ' to Same Pool: 3N-07,230'@ 7200' 16.Deviated wells: Kickoff depth: 2600' ft. 17.Maximum Anticipated Pressures in psig(see 20 MC 25.035) Maximum Hole Angle: 45° deg Downhole:3500 psig Surface:2863 psig 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD 1 MD TVD (including stage data) 8.75" 7" 26# L-80 BTCM 7034' 32' 32' 7034' 6310' 6,17('A Sat—, a .4,00') 2 -54-pc- e'H f 6.125" 4.5" 11.6# L-80 IBT-M 595' 6834' 6169' 7429' 6589' 75s,c. "(i " 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth TVD(ft): Junk(measured) 7793' 6733' 7129' 7624' 6606' 7516' Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 235 sx CS II 115' 115' Surface 3656' 9.625" 1070 sx PF'E',280 sx Class G 3691' 3634' Intermediate Production 7672' 7" 310 sx Class G,175 sx AS I 7707' 6669' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 7349'-7356',7407-7427',7443'-7465' 6402'-6407',6446'-6460',6472'-6489' 20.Attachments: Property Plat❑ BOP Sketch❑ Drilling Program❑ Time v.Depth Plot❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report❑ Drilling Fluid Program Q 20 MC 25.050 requirements Q 21.Verbal Approval: Commission Representative: c3.i�1.t S L-w'a"fit -CP'ei• •2 Date: i 22. I hereby certify that the foregoing is true and correct. Contact M 265-6318S. Printed Name G. Alvord Title Alaska Drilling Manager Signature 265-6120 Date 'iit/2o f Z A..(0,,_ Commission Use Only Permit to Drill API Number: 1 Permit Approval /� /,� See cover letter `�Number: 212-052 50- 029-21539-01-00 Date: 1 `1 J� for other requirements Conditions of approval:77�If boxoxis checked,well may not be used to explore for,test,or produce coalbed ethane,gas hydrates,or gas contained in shales: 2/ Or�91 LAZ fl!7 S/if tt 4144 y,r/u Samples req'd: Yes ❑ No LJ Mud log req'd: Yes ❑ No E E( Other: REVISED 6.29.12 �^'ff'O H2S measures: Yes Er No ❑ Directional svy req'd: Yes [✓] No ❑ ps P ROVED B THE COMMISSION DATE: ?-t 5 COMMISSIONffl v ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage,Alaska 99510-0360 ConocoPhillips Telephone 907-276-1215 June 28,2012 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 Re: Revised: Application for Permit to Drill Rotary Sidetrack CTD Setup 3N-07A Producer Dear Commissioner: ConocoPhillips Alaska,Inc. hereby applies for a Permit to Drill/Sidetrack an onshore producer well from the 3N pad for CTD setup. The expected spud date for this well is May 7,2012 conducting operations with Doyon Rig 141. The 3N-07 wellbore will be temporarily abandoned per separate sundry with 15 bbls of cement placed in the IA between 6,629'- 7,045' and as well as inside the 3-1/2"tubing from 6,727' to 7,129'MD. The proposed plan is to pull the un- cemented tubing and set a 7"bridge plug at approximately 4,100' MD.A CBL will be run to assess where to cut the 7" casing. The plan is to cut and pull the 7"at approximately 2025'MD,and then washover or mill the 7"from 2025' to 2600' to recover the 9-5/8"slot. Next,approximately 65 bbls of 15.8 ppg cement will be pumped to form a plug from 4100' to 2600' inside the 7"casing. JWe will clean out cement and dress off cement plug to approximately 2600' MD and set a 9-5/8"whipstock. A window will be milled and 20' of new formation will be drilled.After 20' of new formation is drilled,a leak off test will be performed to 16.0 ppg EMW.A required minimum leak off of 125 pp EMW must be obtained. The intermediate hole section will be drilled to 7,034' MD/6,310' TVD. The interme lad to hole section will be cased with 7"26#L-80 and cemented in two stages. The 7"shoe will be cemented in the 1St stage with 1000' of cement behind pipe and the 2nd stage will cover the Ugnu D from 3,240 to 2,240'. Cement will encompass the window on the 2nd stage.Approximately 20' of new formation will be drilled with a 6-1/8"bit,and a leak off test will be performed to 16.0 ppg EMW,with a required minimum leak-off of 13.5 ppg EMW. The production hole section will then be drilledwi h a 6-1/8"bit to 7,429' MD/ 6,589' TVD. The production hole section will be lined from 7,429' MD to 6,834' MD with 4-1/2" 11.6#L-80 casing. A 3-1/2"tubing completion will be landed in a seal bore receptacle at the liner top packer at 6,834' MD. Doyon 141 will then rig down and move off for CTD to sidetrack in the A-sands. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: :g 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d)(2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a)and(b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Monty M Myers at 265-6318 or Liz Galiunas at 265-6247. JAt4 !O ! C) Sincerely, Monty M Myers Drilling Engineer Application for Permit to Drill Document Kuparuk Well 3N-07A Well Name Requirements of 20 AAC 25.005(f) The well for which this application is submitted will be designated as 3N-07A. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (2)a plat identifying the property,and the property's owners and showing (A)the coordinates of the proposed location of the well at the sioface,at the top of each objective formation,and at total depth,referenced to governmental section lines. (B)the coordinates of the proposed location of the well at the surface,referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C)the proposed depth of the well at the top of each objective formation and at total depth, Location at Surface 1561'FSL, 304'FEL, Sec 29, T13N,RO9E,UM • NGS Coordinates RKB Elevation 62'AMSL • Northings: 6,013,799.4' Eastings: 518,096.2' Pad Elevation 34'AMSL • Location at Top of 1250'FNL,571' FEL,Sec 29,T13N,RO9E,UM Productive Interval (Kuparuk A Sand) NGS Coordinates Measured Depth,RKB: 7,280' Northings: 6,016,267.24' Eastings: 517,816.32' Total Vertical Depth,RKB: 6,437' Total Vertical Depth, SS: 6,390' Location at Total Depth 1103' FNL, 610' FEL, Sec 29,T13N,RO9E,UM ' NGS Coordinates Measured Depth,RKB: 4' 'I 2��,� 2,11-V Northings: 6,016,413.59' Eastings: 517777.09' Total Vertical Depth,RKB: 6,589' Total Vertical Depth, SS: 6,527' and (D)other information required by 20 AAC 25.050(b), Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated,the application for a Permit to Drill(Form 10-401)must (1)include a plat,drawn to a suitable scale,showing the path of the proposed wellbore,including all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment: Directional Plan No close approach issues exist. Separation factors are above 1.5 once the sidetrack is greater than 100' MD beyond the KOP and continue to increase with depth. The 1/4"mile pool scan of the top of Kuparuk A4 Sand shows the closest approach to be the original 3N-07 wellbore 230'away at 7200' MD. And (2)for all wells within 200 feet of the proposed wellbore (A)list the names of the operators of those wells,to the extent that those names are known or discoverable in public records,and show that each named opercitor has been furnished a copy of the application by certified mail;or (B)state that the applicant is the only affected owner. The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(0(3) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application (3)a diagram and description of the blowout prevention equipment(ROPE)as required by 20 AAC 25.035,20 AAC 25 036,or 20 AAC 25.037,as applicable, Please reference BOP schematics on file for Doyon 141. Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application. (4)information on drilling hazards,including (A)the maximum downhole pressure that may be encountered,criteria used to determine it,and maximum potential surface pressure based on a methane gradient: The maximum potential surface pressure (MPSP)while drilling 3N-07A is calculated using a maximum reservoir pressure of 3,500 psi, a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk A sand at 6,370' TVD (WP07): A Sand SIBHP = 3,500 psi A Sand estimated depth (WP07) = 6,370' TVD Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 637 psi (6,370' TVD * 0.10 psi/ft) MPSP= SIBHP—gas column = 2,863 psi J (3,500 psi—637 psi) (B)data on potential gas zones, The well bore is not expected to penetrate any gas zones. . And (C)data concer Hing potential causes of hole problems such as abnormally geo-presumed strata,lost circulation zones,and zones that have a propensity for differential sticking; See attached 3N-07A Drilling Hazards Summary Requirements of 20 AAC 25.005(c)(5) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application: (5)a description of the procedure for conducting formation integrity tests,us required under 20 A.4C 25.0300; A procedure is on file with the commission for performing LOT's. For 3N-07A the leak off test for the intermediate hole will occur after kicking off the cement plug and 20' of new formation is drilled. The formation at the KOP depth will be pressured until leak-off occurs or to 16.0 ppg EMW is reached, which ever comes first. A required minimum leak off of 12.5 ppg EMW must be obtained. After setting the 7" intermediate at 7,034' MD /6,310' TVD, 20' of hole will be drilled, and the formation will be pressure tested until leak-off occurs or to 16.0 ppg EMW is reached,which ever comes first. A required minimum leak off of 13.5 ppg EMW must be obtained. • Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application (6)a complete proposed casing and cementing program as required by 20 A.4C 25.030,and a description of any slotted liner,pre-perforated liner,or screen to be installed Casing Program Casing Hole weight Top Btm OD Size (lb/ft) Grade Connection Length MD/TVD MD/TVD 16" Conductor 62.5 H-40 Weld 115' Surface 34' 115' / 115' Original 9-5/8" 10-5/8" 36 J-55 BTC 3,691' Surface 33' 3,691'/3,634' Wellbore 7" 8-1/2" 26 J-55 BTC 7,706' Surface z 32' 7,706'/6,734' Sidetrack 7"Casing 8-3/4" 26 L-80 BTCM 7,034' Surface z 32' 7,034'/6,310' Below 9- 4-1/2"Liner 6-1/8" 11.6 L-80 IBTM 588' 6,834'/6,169 7,429'/6,589 5/8"Surf Csg. 3-1/2" Tubing 9.3 L-80 EUE 6,834' Surface 28' 6,834'/6,169' Two Stage Cement Program—Intermediate Hole The 1st stage cement will be placed from the intermediate TD at 7034' MD to 6034' MD . The 2nd stage cement will be placed from 3240' MD to 2240' MD. The casing shoe will be at 7034' MD and will be landed at surface +1- 32'. The slurry consists of 207 sacks of Class G cement plus additives at 15.8 ppg with 50% excess yielding 1.17 ft3/sx for the 1St stage, and 180 sacks of Class G cement plus additives at 15.8 ppg with 50% excess yielding 1.17 ft3/sx for the 2nd stage. 1/ 1st Stage Cement System Preflush: 40 bbls Chemical Wash Spacer: 40 bbls MudPush II Lead Slurry: 207 sacks Class G Cement+ additives Yield= 1.17 ft3/sx oi` Length Capacity 3 Slurry Volumes (ft) (ft3) Excess Total(ft) Total(sacks) Open Hole x Casing OD 1000 150 50% 225 192 8.75"x 7.00" Shoe Track ID 80 17 0% 17 15 6.276" Total 242 207 2nd Stage Cement System Preflush: 30 bbls Chemical Wash Spacer: 30 bbls MudPush II Lead Slurry: 131 sacks Class G Cement+ additives Yield= 1.17 ft3/sx Length Capacity Total Slurry Volumes (ft) (ft3) Excess Total(ft3) (sacks) Open Hole x Casing OD 8.75"x 7.00" 640 96 50% 144 123 Surf Casing ID x Casing OD 9.625"x 7.00" 320 61 50% 92 79 Total 236 202 Single Stage Cement Program—Production Hole Cement will be placed from TD at 7,429' MD to 100' above the top of liner. The liner shoe will be at 7,429' MD and the top of liner set at 6,834' MD (approximately 200'of overlap inside the 7" casing). The slurry consists of 85 sacks of Class G cement plus additives at 15.8 ppg with 20% excess yielding 1.17 ft3/sx. Cement System Preflush: 15 bbls Chemical Wash Spacer: 15 bbls MudPush II Lead Slurry: 85 sacks Class G Cement+additives Yield= 1.17 ft3/sx Mix Water= 5.1 gal/sx Length Capacity 3 Slurry Volumes (ft) (ft3) Excess Total(ft) Total(sacks) Liner Lap 200 22 0% 22 19 6.276"x 4.50" Open Hole x Liner OD 388 37 20% 44 38 6.125"x 4.50" Shoe Track ID 80 7 0% 7 6 4.0" Liner Cap 200 26 0% 26 22 6.276" Total 99 85 Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items,except for an item already on file with the commission and identified in the application (7)a diagram and description of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); This rotary sidetrack will be drilled out from under existing 9-5/8" casing. BOPE will be installed prior to pulling the existing tubing completion, and therefore no diverter is required. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied br each of the following items,except for an item already on file with the commission and identified in the application: (8)a drilling fluid program,including a diagram and description of the drilling fluid system, as required by 20 MC 25.033; Mud Program Summary Depth MD Mud Wt. Funnel API Fluid (ft) (ppg) Vis(cp) PV YP Loss pH Comments (cc/30min) LSND 9.5-11.0 60-80 25-35 7-8 <6 9.5-10 2,600'-7,034' LSND 11.0-12.0 60-80 25-40 5-6 <6 9.5-10 7,034'—7,429' Intermediate and Production Hole Sidetrack Fluid: A 9.8 ppg LSND drilling fluid will be used to drill the intermediate hole to 7,034' MD/6,310' TVD. An 11.3 ppg LSND drilling fluid will be used to drill the production hole to 7,429' MD/6,589' TVD. The drilling mud weight is calculated using an A Sand EMW f 10. pg plus 0.5 ppg trip margin to result in an 11.1 ppg. Fluid weight will have sufficient density to verba nce the pressure of uncased formations penetrated. Additional focus will be on minimizing the potential of a hydrostatic pressure surge or swab and good hole cleaning practices. These practices include monitoring tripping speeds and PWD data, controlling ROP,pumping regular sweeps, adjusting rheology, and charting drag weights. Diagram of Doyon 141 Mud System on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) N/A -Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) N/A- Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) N/A- Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) An application for a Permit to Drill mast he accompanied by each of the following items,except for an item already on file with the commission and identified in the application• 3N-07 P&A Pre Rig Work(previous sundry): a. RIH with 2.20"(min run OD)x 14' OAL dummy drift to 6900' RKB to verify that a 2.125"run OD x 14.6' OAL Baker Inflatable Cement Retainer will drift to target set depth. (only an inflatable retainer is currently available) b. Set Catcher Sub on XXN Plug at 7129' RKB. Pull GLV's from GLM#1 (2705' RKB), GLM#2 (4235' RKB), GLM#3 (5454' RKB),and pull OV from GLM#4(6383' RKB). Install DV's in GLM's#1,2, 3,&4 to dummy off tubing for MIT's. c. MITT to 2500 psi to verify tubing&XXN Plug integrity. Perform MITIA to 2500 psi. d. Pull DV from GLM#5 at 6973' RKB. Leave pocket open to enable circulating cement to IA. If DV in GLM#5 cannot be pulled for any reason,request E-line tubing punch at 7005'RKB at middle of a full joint.Pull DV from GLM #1 (2705' RKB) and leave pocket open to enable circulating from the IA to Tbg x CT during the cement P&A.Pull Catcher Sub. e. Verify that 15 bbls of cement is mixed and ready to pump, then swap to pumping 15 bbls of 15.8 ppg Class G cement at 1.0- 1.5 bpm down coil while continuing to take returns from the Tbg x CT annulus, followed by: continued pumping of 5 bbls of Seawater spacer at 1.0 - 1.5 bpm down coil while continuing to take returns from the Tbg x CT annulus, followed by —45 bbls of Biozan Gel, while taking all returns from the Tbg x CT annulus. Pump 14 bbls of cement at—1.0 bpm through the Cement Retainer while continuing to take 1:1 returns from the Tbg x CT annulus to spot the cement on top of the XXN Plug at 7129' RKB, and into the 7" x 2-7/8" IA. Do not over-displace cement to IA to avoid displacing cement too high up the IA. With 14 bbls of cement through the Cement Retainer,PU CT off the Retainer and pump the last barrel of cement on top of the Retainer to- 6727'RKB while POOH with CT and taking returns from Tbg x CT annulus. f. WOC 24 hours. Notify AOGCC Inspector(659-2714;659-3607 pager)of the timing of the post-cement plug tag and PT. RIH&drift tubing to PBTD (TOC). Perform CMIT (GLM#1 at 2706' RKB has open pocket)to 2500 psi to PT cement plug in tubing and IA,and hold for 30 minutes.Record test results.Perform a drawdown test by bleeding down the tubing and IA pressure to open top tank. Tubing & IA should bleed down to 0 psi to verify good cement P&A integrity.Record the test results. Set a DV in GLM#1 at 2706' RKB. This enables circulating only through tubing cut after E-line cuts the tubing(step#7)to verify indication of a good cut. g. RIH with Halliburton 1-9/16" run OD RCT tubing cutter with anchor arms for 2-7/8"tubing. Cut tubing at +/- 4400'RKB near middle of a full joint. This cut location is—400' below planned sidetrack KOP of 4000' RKB. POOH with tubing cutter. Pump diesel down the tubing while taking returns from the IA noting rates and pressures to verify indication of a successful cut. Set BPV. Pull well house and prepare site for the rig. 1. Move Doyon 141 on 3N-07A and rig up. 2. Pull BPV and VR plugs. Record tubing,IA,and OA pressures. Circulate out freeze protect through tubing cut and monitor well for pressure. 3. Set BPV and nipple down tree. M/U blanking plug in tubing hanger and nipple up BOPE. • Notify AOGCC field inspector 24 hours prior to BOPE test. • Test BOPE to 250 psi low/3,500 psi high against upper 3 'h"X 7"VBR as per drilling permit. • Lower Pipe Rams are 2 7/8"X 6"VBR • A FOSV is to be kept on the floor at all times with pertinent X-over for DP or Casing thread in rotary table. 4. Pull blanking plug and BPV. Pull tubing hanger and lay down 3-1/2"completion. 5. Run 7"casing scraper to approximately 4,100' MD. 6. Set 7"bridge plug bottom at approximately 4,100' MD. 7. Cut 7"casing at approximately 2,025' and pull 7"packoff. 8. Lay down 7"casing. 9. Perform washover and milling operations to get 7"casing removed from original well bore,down to 2,600' _ 10. RIH to bridge plug set at 4100'with tubing tail on DP and pump 30 bbls of Class G cement plus additives at 15.8 ppg 11. Pull up 750'to 3350' and pump 30 bbls of Class G cement plus additives at 15.8 ppg Qc.Z1) 12. POOH and WOC minimum of 12 hrs 13. Stage in hole to top of cement plug and dress it off with bit to 2,600'. 14. POOH and PU 9-5/8"whipstock and TIH and set it at 2,600'. 15. Shear off and begin milling window from 2,600'to 2,620' 16. Perform LOT with rig pump as per CPAI procedure to 16 ppg EMW. Minimum acceptable leak off is 12.5 ppg EMW." 17. POOH and PU 8-3/4"bit and directional BHA 18. TIH and Orient MWD and motor through and begin drilling directional plan. 19. Drill 8-3/4"hole from 2,600' MD to 7,034'MD(above C Sand). 20. At total depth,circulate hole clean and perform wiper trip to KOP. Once back on bottom,circulate until hole is clean. Pull out of hole and rack back drill pipe and BHA. Pull wear bushing. 21. Run 7",26 ppf,L-80 casing to TD. a/o /2A-11A-i re 7" • 22. Cement casing in 2 stages.Bring Pt stage to 6,034' with 15.8 ppg Class G slurry and 50%excess and cement 2nd stage / from 3,240' to 2,240'with 15.8 ppg Class G slurry and 50%excess. $fry` C 23. WOC and change over to drill 6-1/8"production hole. 17, i- L�s r 4 Z- ' Psi 24. PU 6-1/8"bit and directional BHA w/LWD and TIH 25. Drill out shoe track and 20' of new formation. Displace hole to 11.3 ppg MW. Perform open hole leak off to 16.0 ppg EMW. Minimum acceptable leak off is 13.5 ppg EMW. 26. Drill 6-1/8"hole from 7,034'MD to 7,429' (TD). 27. At total depth,circulate hole clean and perform wiper trip to 7"shoe. Once back on bottom,circulate until hole is clean. Pull out of hole and rack back drill pipe and BHA. Pull wear bushing. 28. Pick up and run 4-1/2" 11.6#L-80 liner. The top of liner will be placed at approximately 6,834' MD allowing for 200' of overlap. 29. Cement liner to top with 15.8 ppg Class G slurry and 35%excess. Set liner hanger. Slackoff and set liner top packer. Circulate out excess cement above liner. P.T c.4- 30. Monitor well then pull out of hole laying down drill pipe. 31. Run 3-1/2"upper completion as per procedure with SSSV and 5 GLMs. 32. RD and MO Doyon 141. Coil tubing drilling rig will return at a future date to drill A Sand producers. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) An application for a Permit to Drill music be accompanied bi each of the following items,except foi an item a/readi'on file with the commiciion and identified in the application. (14)a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 2.5.080 for an annular disposal operation in the well, Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. Attachments: Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic Attachment 4 Cement Proposal Y } Via, 4 ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3N Pad '' _ 3N-07 3N-07A Plan: 3N-07A (wp09) Standard Proposal Report I 28 June, 2012 1 } t iiiimmoime HALLIBURTON Sperry Drilling Services k is .__. ..... ._ .. .._.... . HALLIBURTON Project: Kuparuk River Unit WELL DETAILS: 3N-07 Sperry Drilling Services Site: Kuparuk 3N Pad Ground Level: 33.90 Well: 3N-07 +N/-S +E/-W Northing Easting Latittude Longitude Slot Wellbore: 3N-07A 0.00 0.00 6013799.44 518096.21 70°26'55.956 N 149°51'8.533W Plan: 3N-07A (wp09) REFERENCE INFORMATION Co-ordinate(N/E)Reference:Well 3N-07,True North 3000— Vertical(TVD)Reference: Plan:3N-07A @ 61.906(0141(28+33.9)) Measured Depth Reference: Plan:3N-07A @ 61.900(0141(28+33.9)) Calculation Method: Minimum Curvature CASING DETAILS: 3N-07A(wp09) MD TVD TVDSS Name Size Hole Size 2750— 109.90 109.90 48.00 16"Conductor 16 24 �A09) 3N-07A(wp07)A3 2600.02 2599.51 2537.61 9 5/8"TOW 9-5/8 13-1/2 313 DD Polygon @ 95%cord. 7033.97 6309.90 6248.00 7"x 8 1/2" 7 8-1/2 a uz°x 6 1/8"._ i1\ • g9 7429.28 6589.43 6527.53 4 1/2"x 6 1/8" 4-1/2 6-1/8 ------ bS�� TD @ 7429'MD,6589'TVD:1103'FNL,610'FEL-Sec29-T13N-R09E 4650 2500— --- -Top KupA3 @ 7215'MD,6438'TVD:1250'FNL,571'FEL-Sec29-T13N-R09E 6'1") Top KupD @ 7048'MD,6320'TVD:1364'FNL,541'FEL-Sec29-T13N-R09E _ 7" 8 1/2" 6250 7Casing @ }t " 7034'MD,6310'TVD:1373'FNL,639'FEL-Sec29-T13N-R09E _ _ 2250 60� 3N-07A (wp09) DDI = 5.302 2000— 50 _ S5p0 1750— 350° C _ 5500 5250 - w.� +1500 5250 yyO ^ 50p0 5000 1250— 4750 4750 1000— 4500 358° 4500 4250 750— 4000 4250 500— 3750 4000 3500 D 9 5/8" / -9 5/8" 250— 3S00 325' T M Azimuths to True North Magnetic North:16.16° '7250 Magnetic Field 3 Strength:57385.7snT 9 5/8"TOW_____ Dip Angle:79.99° 0— Tie-on 3850'MD,3772'TVD:1592'FSL,323'FEL-Sec29-T13N-R09E ' 500 Date:6/2 M2012 C° � Model: BGGM2011 I I I I I I III I I I I I I I I I I I I I I I IIIIII I I I I III -1250 -1000 -750 -500 -250 0 250 500 750 1000 1250 West(-)/East(+)(350 ft/in) ConocoPhillips Aasla - 0" V _ N g), 6. y N^N co Q w _ Cl) �Y 'MCO '_00'0 W O —O �� o 2 2 S ce 0 _ O 1..� 0 03 mY DL z w N s ) Y Y .�01 b co(�N Z M 0• O V Y pc'^ a s Cl)' ^ W M I- Lo- Lo O Q v, Q 4 Y Y0 Ce N y co -- 0 n n �_ V n 3 _ a ? -00co 0 rn v> 0 (iF:3--1 Q 2 p1"oo'o 17 W (Ni 0 vZ LL W Goo K k O J U- N _ 0 o ps. 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(n a I I I 111111 1 I rn 1- O l 1 ' I 11111 I —o OS I 1 I I 11 1 I 1 _ w I I co I 1 1 I 11111 1 -_ 1 o '1(1 I 1 I I 11111 I 0; I 1 I I 11111 I 11 - N Lc,N; 0 CO I I I 11 11 1 1 _ -a I I I I II II1 I —0 I ai I I 11111 I - I R -LI.,II II I1 11 - � l 111II 1 —0n OI 2 (-F (� 'I(n = N Z 1 �( Y I I IIIII I, .z4 - 0 0 1 > > oil', u Q m - (n l Y Y ®It I;Il1i� �/ , Q n - I"' a p n 3 co till/1,j , , ."' -o G ti J a ill�l 1,1,," , 1111 , - M C I I r+`d�1r�r 0 J_ L I I I I I I I I I SI I I ISI I � I IIS I � � l1 I I II I � II I � 1 I I I I I I Il1 � � � I � 1 � I I I I I II I � � I I , I I I I , I I I 11I I ,, I �1 I YI�'f� l Il I I , - 00 Yi' O 0 O O 0 O 0 0 O O O O O 0 O 0 0 O O J N n O LO N ca O O N On r cn O N n r O MD N (on Ns N N N M m M M V d t '7 in (n (n to (O (O (O O 4 (u!f4 OSL)43daa!eo!�lan erul 1 m Halliburton - Sperry • HALLIBURTDN Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 3N-07 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:3N-07A @ 61.90ft(D141 (28+33.9)) Project: Kuparuk River Unit MD Reference: Plan:3N-07A @ 61.90ft(D141 (28+33.9)) Site: Kuparuk 3N Pad North Reference: True Well: 3N-07 Survey Calculation Method: Minimum Curvature • Wellbore: 3N-07A Design: 3N-07A(wp09) Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 3N Pad Site Position: Northing: 6,013,799.17ft Latitude: 70°26'55.957 N From: Map Easting: 517,946.19ft Longitude: 149°51'12.938 W Position Uncertainty: 0.00 ft Slot Radius: 0" Grid Convergence: 0.14 ° Well 3N-07 - -- -- - -- Well Position +N/-S 0.00 ft Northing: 6,013,799.44 ft Latitude: 70°26'55.956 N +E/-W 0.00 ft Easting: 518,096.21 ft Longitude: 149°51'8.533 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 33.90 ft Wellbore 3N-07A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (0) (nT) BGGM2011 6/22/2012 16.16 79.99 57,386 Design 3N-07A(wp09) Audit Notes: Version: Phase: PLAN Tie On Depth: 2,600.00 Vertical Section: Depth From(ND) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 28.00 0.00 0.00 353.22 Plan Sections Measured Vertical ND Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (ft) (°) (°) (ft) ft (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) 2,600.00 6.13 0.50 2,599.49 2,537.59 30.70 -18.90 0.00 0.00 0.00 0.00 2,616.50 8.37 0.50 2,615.86 2,553.96 32.78 -18.88 13.60 13.60 0.00 0.00 2,646.50 8.37 0.50 2,645.54 2,583.64 37.15 -18.84 0.00 0.00 0.00 0.00 2,746.50 10.37 0.50 2,744.20 2,682.30 53.43 -18.70 2.00 2.00 0.00 0.00 3,467.62 31.99 358.02 3,412.63 3,350.73 312.32 -24.80 3.00 3.00 -0.34 -3.57 5,805.51 31.99 358.02 5,395.50 5,333.60 1,550.12 -67.57 0.00 0.00 0.00 0.00 6,414.55 45.00 345.14 5,871.90 5,810.00 1,921.66 -128.74 2.50 2.14 -2.12 -36.90 7,214.99 45.00 345.14 6,437.90 6,376.00 2,468.72 -273.93 0.00 0.00 0.00 0.00 7,369.28 45.00 345.14 6,547.00 6,485.10 2,574.17 -301.92 0.00 0.00 0.00 0.00 7,429.28 45.00 345.14 6,589.43 6,527.53 2,615.18 -312.80 0.00 0.00 0.00 0.00 6/28/2012 5:26:43PM Page 2 COMPASS 2003.16 Build 69 Halliburton - Sperry HALLIBURTON Standard Proposal Report • Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 3N-07 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:3N-07A @ 61.90ft(D141 (28+33.9)) Project: Kuparuk River Unit MD Reference: Plan:3N-07A @ 61.90ft(D141 (28+33.9)) Site: Kuparuk 3N Pad North Reference: True Well: 3N-07 Survey Calculation Method: Minimum Curvature Wellbore: 3N-07A Design: 3N-07A(wp09) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-5 +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) -33.90 28.00 0.00 0.00 28.00 -33.90 0.00 0.00 6,013,799.44 518,096.21 0.00 0.00 94.90 0.32 57.72 94.90 33.00 0.10 0.16 6,013,799.54 518,096.37 0.48 0.08 109.90 0.33 52.55 109.90 48.00 0.15 0.23 6,013,799.59 518,096.44 0.22 0.12 16"Conductor 194.90 0.45 31.27 194.90 133.00 0.58 0.60 6,013,800.03 518,096.81 0.22 0.51 294.90 0.48 10.48 294.89 232.99 1.33 0.88 6,013,800.77 518,097.08 0.17 1.22 394.90 0.48 359.18 394.89 332.99 2.16 0.95 6,013,801.60 518,097.15 0.09 2.04 494.90 0.53 355.27 494.89 432.99 3.04 0.90 6,013,802.48 518,097.11 0.06 2.91 594.90 0.67 341.50 594.88 532.98 4.06 0.68 6,013,803.50 518,096.88 0.20 3.95 694.90 0.75 329.45 694.87 632.97 5.18 0.16 6,013,804.62 518,096.36 0.17 5.12 794.90 0.68 327.00 794.87 732.97 6.24 -0.49 6,013,805.68 518,095.70 0.08 6.25 894.90 0.67 326.23 894.86 832.96 7.22 -1.14 6,013,806.66 518,095.05 0.01 7.31 994.90 0.83 323.80 994.85 932.95 8.29 -1.89 6,013,807.73 518,094.30 0.16 8.46 1,094.90 0.87 318.93 1,094.84 1,032.94 9.45 -2.82 6,013,808.88 518,093.37 0.08 9.72 1,194.90 0.88 314.45 1,194.83 1,132.93 10.56 -3.87 6,013,809.99 518,092.32 0.07 10.94 1,294.90 0.78 312.90 1,294.82 1,232.92 11.56 -4.91 6,013,810.99 518,091.27 0.10 12.06 1,394.90 0.97 309.20 1,394.81 1,332.91 12.56 -6.07 6,013,811.98 518,090.11 0.20 13.19 1,494.90 1.03 306.18 1,494.79 1,432.89 13.62 -7.45 6,013,813.04 518,088.73 0.08 14.41 1,594.90 1.07 304.00 1,594.77 1,532.87 14.68 -8.95 6,013,814.09 518,087.23 0.06 15.63 1,694.90 1.10 303.55 1,694.76 1,632.86 15.73 -10.52 6,013,815.14 518,085.65 0.03 16.86 1,794.90 0.88 306.68 1,794.74 1,732.84 16.72 -11.94 6,013,816.13 518,084.23 0.23 18.01 1,894.90 0.90 305.22 1,894.73 1,832.83 17.63 -13.20 6,013,817.04 518,082.97 0.03 19.06 1,994.90 0.85 306.03 1,994.72 1,932.82 18.52 -14.44 6,013,817.92 518,081.73 0.05 20.09 2,094.90 0.80 308.88 2,094.71 2,032.81 19.39 -15.58 6,013,818.79 518,080.58 0.06 21.10 2,194.90 0.67 312.97 2,194.70 2,132.80 20.23 -16.55 6,013,819.63 518,079.61 0.14 22.04 2,294.90 0.52 324.12 2,294.69 2,232.79 21.00 -17.25 6,013,820.39 518,078.91 0.19 22.88 2,394.90 0.45 326.78 2,394.69 2,332.79 21.69 -17.73 6,013,821.09 518,078.43 0.07 23.63 2,494.90 1.72 341.58 2,494.67 2,432.77 23.44 -18.42 6,013,822.84 518,077.74 1.29 25.45 2,594.90 6.07 359.92 2,594.42 2,532.52 30.16 -18.90 6,013,829.55 518,077.24 4.47 32.18 2,600.00 6.13 0.50 2,599.49 2,537.59 30.70 -18.90 6,013,830.09 518,077.24 1.64 32.72 Tie-on @ 3850'MD,3772'TVD:1592'FSL,323'FEL-Sec29-T13N-R09E 2,600.02 6.13 0.50 2,599.51 2,537.61 30.70 -18.90 6,013,830.09 518,077.24 0.00 32.72 9 5/8"TOW 2,616.50 8.37 0.50 2,615.86 2,553.96 32.78 -18.88 6,013,832.17 518,077.25 13.62 34.78 2,646.50 8.37 0.50 2,645.54 2,583.64 37.15 -18.84 6,013,836.54 518,077.28 0.00 39.11 2,700.00 9.44 0.50 2,698.39 2,636.49 45.43 -18.77 6,013,844.82 518,077.33 2.00 47.33 2,746.50 10.37 0.50 2,744.20 2,682.30 53.43 -18.70 6,013,852.82 518,077.38 2.00 55.26 2,800.00 11.97 0.02 2,796.68 2,734.78 63.79 -18.65 6,013,863.18 518,077.40 3.00 65.55 2,900.00 14.97 359.40 2,893.92 2,832.02 87.09 -18.79 6,013,886.47 518,077.22 3.00 88.69 3,000.00 17.97 358.97 2,989.81 2,927.91 115.43 -19.20 6,013,914.81 518,076.73 3.00 116.89 3,100.00 20.96 358.67 3,084.08 3,022.18 148.74 -19.89 6,013,948.12 518,075.96 3.00 150.05 3,200.00 23.96 358.44 3,176.48 3,114.58 186.93 -20.86 6,013,986.30 518,074.90 3.00 188.09 3,300.00 26.96 358.26 3,266.76 3,204.86 229.90 -22.10 6,014,029.27 518,073.55 3.00 230.91 3,400.00 29.96 358.11 3,354.66 3,292.76 277.53 -23.62 6,014,076.89 518,071.92 3.00 278.38 3,467.62 31.99 358.02 3,412.63 3,350.73 312.32 -24.80 6,014,111.66 518,070.66 3.00 313.06 6/28/2012 5:26:43PM Page 3 COMPASS 2003.16 Build 69 • Halliburton -Sperry • HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 3N-07 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:3N-07A @ 61.90ft(D141 (28+33.9)) Project: Kuparuk River Unit MD Reference: Plan:3N-07A @ 61.90ft(D141 (28+33.9)) Site: Kuparuk 3N Pad North Reference: True Well: 3N-07 Survey Calculation Method: Minimum Curvature Wellbore: 3N-07A Design: 3N-07A(wp09) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (0) (°) (ft) ft (ft) (ft) (ft) (ft) 3,378.20 3,500.00 31.99 358.02 3,440.10 3,378.20 329.46 -25.39 6,014,128.80 518,070.02 0.00 330.15 3,600.00 31.99 358.02 3,524.91 3,463.01 382.40 -27.22 6,014,181.74 518,068.07 0.00 382.94 3,700.00 31.99 358.02 3,609.72 3,547.82 435.35 -29.05 6,014,234.67 518,066.11 0.00 435.73 3,800.00 31.99 358.02 3,694.54 3,632.64 488.29 -30.88 6,014,287.61 518,064.15 0.00 488.53 3,900.00 31.99 358.02 3,779.35 3,717.45 541.24 -32.71 6,014,340.54 518,062.19 0.00 541.32 4,000.00 31.99 358.02 3,864.17 3,802.27 594.19 -34.54 6,014,393.48 518,060.24 0.00 594.11 4,100.00 31.99 358.02 3,948.98 3,887.08 647.13 -36.37 6,014,446.42 518,058.28 0.00 646.90 4,200.00 31.99 358.02 4,033.79 3,971.89 700.08 -38.20 6,014,499.35 518,056.32 0.00 699.69 4,300.00 31.99 358.02 4,118.61 4,056.71 753.02 -40.02 6,014,552.29 518,054.36 0.00 752.48 4,400.00 31.99 358.02 4,203.42 4,141.52 805.97 -41.85 6,014,605.22 518,052.40 0.00 805.27 4,500.00 31.99 358.02 4,288.24 4,226.34 858.91 -43.68 6,014,658.16 518,050.45 0.00 858.07 4,600.00 31.99 358.02 4,373.05 4,311.15 911.86 -45.51 6,014,711.09 518,048.49 0.00 910.86 4,700.00 31.99 358.02 4,457.86 4,395.96 964.80 -47.34 6,014,764.03 518,046.53 0.00 963.65 4,800.00 31.99 358.02 4,542.68 4,480.78 1,017.75 -49.17 6,014,816.97 518,044.57 0.00 1,016.44 4,900.00 31.99 358.02 4,627.49 4,565.59 1,070.69 -51.00 6,014,869.90 518,042.61 0.00 1,069.23 1 5,000.00 31.99 358.02 4,712.31 4,650.41 1,123.64 -52.83 6,014,922.84 518,040.66 0.00 1,122.02 5,100.00 31.99 358.02 4,797.12 4,735.22 1,176.59 -54.66 6,014,975.77 518,038.70 0.00 1,174.82 5,200.00 31.99 358.02 4,881.93 4,820.03 1,229.53 -56.49 6,015,028.71 518,036.74 0.00 1,227.61 5,300.00 31.99 358.02 4,966.75 4,904.85 1,282.48 -58.32 6,015,081.64 518,034.78 0.00 1,280.40 5,400.00 31.99 358.02 5,051.56 4,989.66 1,335.42 -60.15 6,015,134.58 518,032.82 0.00 1,333.19 5,500.00 31.99 358.02 5,136.38 5,074.48 1,388.37 -61.98 6,015,187.51 518,030.87 0.00 1,385.98 5,600.00 31.99 358.02 5,221.19 5,159.29 1,441.31 -63.81 6,015,240.45 518,028.91 0.00 1,438.77 5,700.00 31.99 358.02 5,306.01 5,244.11 1,494.26 -65.64 6,015,293.39 518,026.95 0.00 1,491.56 5,805.51 31.99 358.02 5,395.50 5,333.60 1,550.12 -67.57 6,015,349.24 518,024.88 0.00 1,547.27 5,900.00 33.91 355.48 5,474.79 5,412.89 1,601.42 -70.51 6,015,400.52 518,021.82 2.50 1,598.55 6,000.00 35.98 353.05 5,556.76 5,494.86 1,658.39 -76.27 6,015,457.48 518,015.93 2.50 1,655.80 6,100.00 38.11 350.86 5,636.57 5,574.67 1,718.03 -84.72 6,015,517.09 518,007.33 2.50 1,716.02 6,200.00 40.27 348.87 5,714.08 5,652.18 1,780.21 -95.87 6,015,579.24 517,996.03 2.50 1,779.09 6,300.00 42.46 347.04 5,789.13 5,727.23 1,844.82 -109.68 6,015,643.81 517,982.07 2.50 1,844.88 6,400.00 44.68 345.37 5,861.59 5,799.69 1,911.74 -126.13 6,015,710.68 517,965.46 2.50 1,913.27 6,414.55 45.00 345.14 5,871.90 5,810.00 1,921.66 -128.74 6,015,720.59 517,962.82 2.50 1,923.42 6,428.69 45.00 345.14 5,881.90 5,820.00 1,931.33 -131.30 6,015,730.25 517,960.23 0.00 1,933.33 Top HRZ 6,500.00 45.00 345.14 5,932.33 5,870.43 1,980.06 -144.24 6,015,778.95 517,947.18 0.00 1,983.25 6,600.00 45.00 345.14 6,003.04 5,941.14 2,048.41 -162.38 6,015,847.24 517,928.88 0.00 2,053.26 6,700.00 45.00 345.14 6,073.75 6,011.85 2,116.75 -180.52 6,015,915.54 517,910.57 0.00 2,123.26 6,708.70 45.00 345.14 6,079.90 6,018.00 2,122.70 -182.09 6,015,921.48 517,908.98 0.00 2,129.36 Upper Kalubik(Base HRZ) 6,800.00 45.00 345.14 6,144.46 6,082.56 2,185.10 -198.65 6,015,983.83 517,892.27 0.00 2,193.27 , 6,867.09 45.00 345.14 6,191.90 6,130.00 2,230.95 -210.82 6,016,029.65 517,879.99 0.00 2,240.24 Lower Kalubik(K Mkr) 6,900.00 45.00 345.14 6,215.17 6,153.27 2,253.44 -216.79 6,016,052.12 517,873.97 0.00 2,263.28 7,000.00 45.00 345.14 6,285.88 6,223.98 2,321.79 -234.93 6,016,120.42 517,855.67 0.00 2,333.29 7,033.97 45.00 345.14 6,309.90 6,248.00 2,345.00 -241.09 6,016,143.62 517,849.45 0.00 2,357.07 7"Casing @ 7034'MD,6310'TVD:1373'FNL,639'FEL-Sec29-T13N-R09E-7"x 8 1/2" 6/28/2012 5:26:43PM Page 4 COMPASS 2003.16 Build 69 Halliburton -Sperry HALLIBURTO118 Standard Proposal Report • Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 3N-07 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:3N-07A @ 61.90ft(D141 (28+33.9)) Project: Kuparuk River Unit MD Reference: Plan:3N-07A @ 61.90ft(D141 (28+33.9)) Site: Kuparuk 3N Pad North Reference: True Well: 3N-07 Survey Calculation Method: Minimum Curvature Wellbore: 3N-07A Design: 3N-07A(wp09) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 6,258.00 7,048.11 45.00 345.14 6,319.90 6,258.00 2,354.67 -243.66 6,016,153.28 517,846.86 0.00 2,366.97 Top KupD @ 7048'MD,6320'TVD:1364'FNL,541'FEL-Sec29-713N-R09E-Kuparuk D 7,100.00 45.00 345.14 6,356.59 6,294.69 2,390.13 -253.07 6,016,188.71 517,837.36 0.00 2,403.29 7,141.45 45.00 345.14 6,385.90 6,324.00 2,418.46 -260.59 6,016,217.02 517,829.78 0.00 2,432.31 C4 7,164.08 45.00 345.14 6,401.90 6,340.00 2,433.93 -264.69 6,016,232.47 517,825.63 0.00 2,448.15 Cl-B 7,200.00 45.00 345.14 6,427.30 6,365.40 2,458.48 -271.21 6,016,257.00 517,819.06 0.00 2,473.30 7,206.51 45.00 345.14 6,431.90 6,370.00 2,462.92 -272.39 6,016,261.45 517,817.87 0.00 2,477.86 A5 7,214.99 45.00 345.14 6,437.90 6,376.00 2,468.72 -273.93 6,016,267.24 517,816.32 0.00 2,483.80 Top KupA3 @ 7215'MD,6438'ND:1250'FNL,571'FEL-Sec29-T13N-R09E-A3-3N-07A(wp07)A3 7,243.27 45.00 345.14 6,457.90 6,396.00 2,488.05 -279.06 6,016,286.56 517,811.14 0.00 2,503.60 A2 7,284.29 45.00 345.14 6,486.90 6,425.00 2,516.08 -286.50 6,016,314.57 517,803.63 0.00 2,532.31 Al 7,300.00 45.00 345.14 6,498.01 6,436.11 2,526.82 -289.35 6,016,325.30 517,800.76 0.00 2,543.31 7,362.07 45.00 345.14 6,541.90 6,480.00 2,569.24 -300.61 6,016,367.69 517,789.40 0.00 2,586.76 Miluveach 7,369.28 45.00 345.14 6,547.00 6,485.10 2,574.17 -301.92 6,016,372.61 517,788.08 0.00 2,591.81 7,400.00 45.00 345.14 6,568.72 6,506.82 2,595.16 -307.49 6,016,393.59 517,782.45 0.00 2,613.32 - 7,429.28 45.00 345.14 .6,589.43 6,527.53 2,615.18 -312.80 6,016,413.59 517,777.09 0.00 2,633.82 TD @ 7429'MD,6589'TVD:1103'FNL,610'FEL-Sec29-T13N-R09E-4 1/2"x 6 1/8" I Targets Target Name -hit/miss target Dip Angle Dip Dir. ND +N/-S +EI-W Northing Easting -Shape (0) (°) (ft) (ft) (ft) (ft) (ft) 3N-07A(wp07)A3 0.00 0.00 6,437.90 2,468.72 -273.93 6,016,267.24 517,816.32 -plan hits target center -Circle(radius 150.00) Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name C') C') 7,033.97 6,309.90 7"x 8 1/2" 7 8-1/2 7,429.28 6,589.43 4 1/2"x 6 1/8" 4-1/2 6-1/8 2,600.02 2,599.51 9 5/8"TOW 9-5/8 13-1/2 109.90 109.90 16"Conductor 16 24 6/28/2012 5:26:43PM Page 5 COMPASS 2003.16 Build 69 Halliburton -Sperry • HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 3N-07 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:3N-07A @ 61.90ft(D141 (28+33.9)) Project: Kuparuk River Unit MD Reference: Plan:3N-07A @ 61.90ft(D141 (28+33.9)) Site: Kuparuk 3N Pad North Reference: True Well: 3N-07 Survey Calculation Method: Minimum Curvature Wellbore: 3N-07A Design: 3N-07A(wp09) Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (°) (°) I 7,214.99 6,437.90 A3 0.00 7,362.07 6,541.90 Miluveach 0.00 6,708.70 6,079.90 Upper Kalubik(Base HRZ) 0.00 7,048.11 6,319.90 Kuparuk D 0.00 7,284.29 6,486.90 Al 0.00 7,164.08 6,401.90 B 0.00 7,243.27 6,457.90 A2 0.00 6,867.09 6,191.90 Lower Kalubik(K Mkr) 0.00 6,428.69 5,881.90 Top HRZ 0.00 7,141.45 6,385.90 C4 0.00 7,164.08 6,401.90 Cl 0.00 7,206.51 6,431.90 A5 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 2,600.00 2,599.49 30.70 -18.90 Tie-on @ 3850'MD,3772'TVD:1592'FSL,323'FEL-Sec29-T13N-R09E 7,033.97 6,309.90 2,345.00 -241.09 7"Casing @ 7034'MD,6310'TVD:1373'FNL,639'FEL-Sec29-T13N-R09E 7,048.11 6,319.90 2,354.67 -243.66 Top KupD @ 7048'MD,6320'TVD:1364'FNL,541'FEL-Sec29-T13N-R09E 7,214.99 6,437.90 2,468.72 -273.93 Top KupA3 @ 7215'MD,6438'TVD:1250'FNL,571'FEL-Sec29-T13N-R09E 7,429.28 6,589.43 2,615.18 -312.80 TD @ 7429'MD,6589'TVD:1103'FNL,610'FEL-Sec29-T13N-R09E 6/28/2012 5:26:43PM Page 6 COMPASS 2003.16 Build 69 ■ ■ I ■ ■ C) C) m m g C) m 0 m . 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I� v W Z Z W 0 _ _ p ca' Z 7 O CO Z - W W -. Z Z - -' (T O1 COO 60) OW O OV W N) 0 - O N 0) 11 y a< o < Z y < D L, Z < G < < <G < z < < < � < Z Z - R'') O I < W �. CO (n< 0 o -g 0 <o 7:1o< n x vim) b N c, D Separation Factor (2.50 /in) m rt 7 C) N _ r N gR7 gS7 _ c 8 1 I I I M M M I T I I I I T S I I 1 I , I , I T , I I I T I I 1 1 1 I I I 1 1 I I -n m o _ n N• o 0 CO N —.__ .._._.... ......__- — o X C CD V _ M : I N —' ---- -- - ----------- ---- � I .-44 W Z O < �1 `, is-1/46,..., y '`:.__ c co M. _-..._.................... ...._.... .........._..._ W cn cn 13 Q CDo CV -i cc CD 0 v , CD Cn O T Cn - .. l h 41# 4 + + * * 4 + + + 4 + + + * + I,t co CO G) (n) G) G) G) W W 0) CJ CO CO CJ G) G) G) 0) CO 03 W W W W CJ 17 zz z z ? F z z z z z zz zb b zz z z zv b b b b b b b b b. b D ao CO N A A A W -' -` --' -, U) U) co Cr co A ---.1J N O NN) co co D co W co co G) W (.J co co co co co co co co co co co co co G) G) Z g zb w E E E ? E ? E E z z b 7b g g zb zb g E E b b g r,' o Dco A D A D co D D D D cn cn m rn co A ,I N o D N 0 r O c, w `D 6.) w r-Ni I- N w w w ca w w w 0) D w w w w m 0 w 0) z w - Z Z b Z ( b co CD CZ A 0) N o - N co m 0" D < N) < Z y < D It It co < < < < < < < < g < < < D < Z z -. a A < _g y D _, D a No 0 'O A N CO 0 < N O 03 Z 0 0 o b ~ < 0 P y R — x 1 (0 o 0 7•• n ,- N Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, June 29, 2012 11:36 AM To: 'Myers, Monty M' Subject: RE: Revised Permit and new directional plan for 3N-07A(PTD I2 2_- 052. Monty, You have verbal approval to proceed as outlined in our revised PTD application. The major changes as stated are exiting the 9 5/8" surface casing at about 2600' and vs the original plan pulling the 7" casing below the surface shoe and kicking off at about 3800' and in OH. The changes are due to the unexpected presence of cement in the 7"X 9 5/8" annulus around the casing shoe area. Please submit a hard copy of the revise PTD to the Commission as soon as possible. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Myers, Monty M [mailto:Monty.M.Myers@conocophillips.com] Sent: Friday, June 29, 2012 10:43 AM To: Schwartz, Guy L (DOA) Subject: Revised Permit and new directional plan for 3N-07A Guy, Please find the new permit for 3N-07A attached, and let me know if you have any questions! Have a great weekend and good days off next week. Monty M Myers Drilling Engineer ConocoPhillips Alaska 907.265.6318 office 907.538.1168 cell 6/29/2012 Page 1 of 1 Schwartz, Guy L (DOA) From: Myers, Monty M [Monty.M.Myers@conocophillips.com] Sent: Thursday, June 28, 2012 10:58 AM To: Schwartz, Guy L (DOA) Subject: 3N-07A change of plans ( PTD 182-028 &212-052) Guy, Attached is a CBL from the intermediate hole on 3N-07A. I want to discuss some options with you going forward on this well. Our original plan was to sidetrack from below, the 9-5/8" surface casing shoe that is at(3691'), and re-drill an 8-3/4" hole and re-run 7". With the information we have gathered now with the attached CBL and the issues we have encountered, we might very possibly need to sidetrack this well from inside the 9-5/8" surface casing, from 2550-2600'. We have cuts in the 7" (from bottom to top)at 3995, 3587'and 2930'. After we ran the CBL we cut the fish off at 2025' and recovered the 7" casing and have been working to get the 7" out of the hole since then. With the way we are currently progressing, it may still take a few days to get down to 2550' or deeper to sidetrack out of the 9-5/8' casing. At this depth, our Anti-collision concerns with the surrounding wells, 3N-05, 3N-06 and 3N-08, go away. The plan would be to cement the inside of the 7" casing from at least 3630' to above our 7"fish (say 2600' c:thct cc_~;, set a -5/8 whipstock and drill our 8-3/4 hole from here and re-run 7" and continue MontiLllr, p y 1! ili if c�l4 it S tE: TRANSMITTAL LETTER CH CKLIST WELL NAME ekii ' G PTD# 2-f z_ zr' - 6/ Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: ltr c.1 42 �� POOL: Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev:9/09/2011 L_ 1 a) L O) iIO E C_O aNi w 3 O j N CO 0 O IIUN COc o 0 C a a r -0 .3 -0 E -o=' v Lu a) m a E ix O5 o n a) n CV-EE O cn E t. iti o CO ` a) N _ a) ' a) o ) ac) n 3 3 a) m m C a.) 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Q CO O 3- 0 LI oU Q Li- q O 0 ,,K W Q q7 ITA 1 , I t,Tr SEAN PARNELL, GOVERNOR �,i; ;; Lin-6 ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 G. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 3N-07A ConocoPhillips Alaska, Inc. Permit No: 212-052 Surface Location: 1561' FSL, 304' FEL, SEC. 29, T13N, R9E, UM Bottomhole Location: 1103' FNL, 610' FEL, SEC. 29, T13N, R9E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. 00an Sincerel or� is ioner DATED this <day of April, 2012. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APR 1 12012 PERMIT TO DRILL AOGCC 20 AAC 25.005 1a Type of Work: , lb Proposed Well Class: Development-Oil ❑✓ . Service-Win) ❑ Single Zone E - lc.Specify if well is proposed for: Drill ❑ Re-drill ❑., Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond. U Blanket Li Single Well 11.Well Name and Number: tJ ConocoPhillips Alaska, Inc. Bond No. 59-52-180 ' 3N-07A Sir-1.(f 3.Address: 6 Proposed Depth 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD:7494', TVD: 6589' - Kuparuk River Field 4a Location of Well(Governmental Section) 7.Property Designation(Lease Number): Surface: 1561'FSL,304'FEL,Sec.29,T13N, RO9E,UM ADL 25521 • Kuparuk River Oil Pool Top of Productive Horizon: 8.Land Use Permit. 13.Approximate Spud Date. 1250'FNL,571'FEL,Sec.29,T13N, RO9E, UM 2557 5/7/2012 Total Depth 9.Acres in Property. 14.Distance to 1103'FNL,610'FEL,Sec.29,T13N, RO9E, UM 2560 Nearest Property: >1 mile 4b Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 62 feet 15.Distance to Nearest Well Open Surface:x- 518096 - y- 6013799 - Zone- 4 GL Elevation above MSL: ,34 feet to Same Pool 3N-07,230'@ 7200' 16 Deviated wells: Kickoff depth 3850' - ft. 17.Maximum Anticipated Pressures in psig(see 20 MC 25 035) Maximum Hole Angle: 45° - deg Downhole:3500 psig. Surface:2863 psig . 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 8.75" 7" 26# L-80 BTCM 7100' 32' 32' 7100' 6310' _ - v 6.125" 4.5" 11.6# L-80 IBT-M 588' 6900' 6169' 7494' 6589' 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft). Total Depth TVD(ft): Plugs(measured) Effective Depth MD(ft) Effective Depth ND(ft): Junk(measured) 7793' 6733' 7129' 7624' 6606' 7516' Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 235 sx CS II 115' 115' Surface 3656' 9.625" 1070 sx PF'E',280 sx Class G 3691' 3634' Intermediate Production 7672' 7" 310 sx Class G, 175 sx AS I 7707' 6669' Liner Perforation Depth MD(ft): Perforation Depth ND(ft): 7349'-7356',7407'-7427',7443'-7465' 6402'-6407',6446-6460',6472'-6489' 20 Attachments: Property Plat❑ BOP Sketch❑ Drilling Program❑✓ Time v Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25 050 requirements ❑✓ 21 Verbal Approval Commission Representative Date- M M M 22. I hereby certify that the foregoing is true and correct Contact M. M. Myers @ 265-6318 Printed Name G. Alvord Title Alaska Drilling Manager Signature � e,ak Phon 265-6120 Date 411 h a l L Commission Use Only Permit to Drill API Number: Permit Approval See cover letter Number: ,L / ,' ' !' '.... 50-r".,�?.. .,,.f t---_,: ' j-el.- Date: i\ 1 1 Z for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coal ed methane,gas hydrates,or gas contained in shales: Er .jr 35DJ psi- �O -73---5 1- Samples req'd: Yes ❑ ,No L Mud log req'd: Yes ❑ No ril Other: .71_ 7 //���� A /�- f 6,;(412S measures: Yes ❑r` I,•a./'a f1' nal svy req'd: Yes Ef No ❑ f 4 ..M� APPROVED BY THE COMMISSION DATE "/ l� A Or ,COMMISSIONER ,' ( � R I ( Duplicate ) Form 10-401 R vised 7/2009) This permit is valid for o t 4. al25.005(g)) in r 1(' V—� `15 4 I2J It'Z if-z .r 2-- it /ubOt ,e__ A• ConocoPhillips Alaska, Inc. Post Office Box 100360 y,- Anchorage,Alaska 99510-0360 ConocoPhillips Telephone 907-276-1215 April 3,2012 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 Re: Application for Permit to Drill Rotary Sidetrack CTD Setup 3N-07A Producer Dear Commissioner: ConocoPhillips Alaska,Inc.hereby applies for a Permit to Drill/Sidetrack an onshore producer well from the 3N pad for CTD setup. The expected spud date for this well is May 7,2012 conducting operations with Doyon Rig 141. • s3 312-'1(3 The 3N-07 wellbore will be temporarily abandoned per separate sundry with 15 bbls of cement placed in the IA between 6,629'-7,045' and as well as inside the 3-1/2"tubing from 6,727' to 7,129'MD. The proposed plan is to pull the un- cemented tubing and set a 7"bridge plug at approximately 4,400' MD.A CBL will be run to assess where to cut the 7" casing. The plan is to cut and pull the 7"at approximately 4300' MD,however,it may be necessary to washover the 7" from 3,691' to 4,300' to recover the 7"casing. Next,approximately 80 bbls of 15.8 ppg cement will be pumped to form a kick off plug from 4,300' to 3,491'. We will clean out cement and dress off cement plug to approximately 3,850' MD and kick off the cement plug with an 8-3/4"bit. After 20' of new formation is drilled,a leak off test will be performed to 16.0 ppg EMW.A required minimum leak off of 12.5 ppg EMW must be obtained. The intermediate hole section will be drilled to 7,100' MD/ 6,310' TVD. The intermediate hole section will be cased with 7"26#L-80 and cemented(TOC 5200' MD). Approximately 20' of new formation will be drilled with a 6-1/8"bit,and a leak off test will be performed to 16.0 ppg EMW,with a required minimum leak-off of 13.5 ppg EMW. The production hole section will then be drilled with a 6- • 1/8"bit to 7,494' MD/6,589' TVD. The production hole section will be lined from 7,494' MD to 6,900' MD with 4- 1/2" 11.6#L-80 casing. A 3-1/2"tubing completion will be landed in a seal bore receptacle at the liner top packer at 6,900' MD. Doyon 141 will then rig down and move off for CTD to sidetrack in the A-sands. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d)(2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a)and(b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Monty M Myers at 265-6318 or Liz Galiunas at 265-6247. ORIGINAL ConocoPhillips Alaska, Inc. Post Office Box 1 ConocoPhillips Anchorage,Alaskaa 995 99510-0360 Telephone 907-276-1215 April 20,2012 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 Re: Application for Permit to Drill Rotary Sidetrack CTD Setup 3N-07A Producer Dear Commissioner: ConocoPhillips Alaska,Inc.hereby applies for a Permit to Drill/Sidetrack an onshore producer well from the 3N pad for CTD setup. The expected spud date for this well is May 7,2012 conducting operations with Doyon Rig 141. The 3N-07 wellbore will be temporarily abandoned per separate sundry with 15 bbls of cement placed in the IA between 6,629'-7,045' and as well as inside the 3-1/2"tubing from 6,727' to 7,129'MD. The proposed plan is to pull the un- cemented tubing and set a 7"bridge plug at approximately 4,400' MD. A CBL will be run to assess where to cut the 7" casing.The plan is to cut and pull the 7"at approximately 4300' MD, however, it may be necessary to washover the 7" from 3,691' to 4,300' to recover the 7"casing. Next,approximately 80 bbls of 15.8 ppg cement will be pumped to form a kick off plug from 4,300' to 3,491'. We will clean out cement and dress off cement plug to approximately 3,850' MD and kick off the cement plug with an 8-3/4"bit.After 20' of new formation is drilled,a leak off test will be performed to 16.0 ppg EMW.A required minimum leak off of 12.5 ppg EMW must be obtained. The intermediate hole section will be drilled to 7,100' MD/ 6,310' TVD. The intermediate hole section will be cased with 7"26#L-80 and cemented(TOC 5200' MD). Approximately 20' of new formation will be drilled with a 6-1/8"bit, and a leak off test will be performed to 16.0 ppg EMW,with a required minimum leak-off of 13.5 ppg EMW. The production hole section will then be drilled with a 6- 1/8"bit to 7,494' MD/6,589' TVD. The production hole section will be lined from 7,494' MD to 6,900' MD with 4- 1/2" 11.6#L-80 casing. A 3-1/2"tubing completion will be landed in a seal bore receptacle at the liner top packer at 6,900' MD. Doyon 141 will then rig down and move off for CTD to sidetrack in the A-sands. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 Application for Permit to Drill per 20 ACC 25.005 (a). 2. Pressure information as required by 20 ACC 25.035 (d)(2). 3. Casing and Cementing program. 4. A drilling fluids program summary. 5. A proposed drilling program. 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b). 7. A proposed completion diagram. Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a)and(b). 2. A description of the drilling fluids handling system. 3. Diagram of riser set up. If you have any questions or require further information, please contact Monty M Myers at 265-6318 or Liz Galiunas at 265-6247. Sincerely, Monty M Myers Drilling Engineer Application for Permit to Drill Document Kuparuk Well 3N-07A Well Name Requirements of 20 AAC 25.005(f) The well for which this application is submitted will be designated as 3N-07A. Location Summary Requirements of 20 AAC 25.005(c)(2) In applrcanon fin a l'crnml 10 lh rl!rnrn/hr accompanied ht caelr of the /o//on fn,),.;)Items,eu cpr for an aenr))bride on fil, rl!)Inc e onIn1t 1(0)r and rdrnnficd In!hr appitcanon (2)a plat rdt tallying Iht proper n and(hi prapern's otrner+and shun 1/0/ 11111( e oorda)ates of the p)opou d 101 alum of the well al the oil late al 1h) lop of cad)ohlea!rt a founatlon and 01 final depth r e lerenc ed ro go/ernnrenlul se)non line+ (Thaw coordinate+of the proposed lot alron of!hc a ell(II the lar/act' referenCed!o rhe +lase plan) cooldn)alr n'sn'm/o Ihr+ Viae as nwnaamed hr he 1 atonal(n'odelic Sur t e t In!ht Savona/Ocean,'and lano+phcra' rdnnni,nzlllnn (( Ilia pi opou d da p1/i of Iht It)1i at 111, lop of)ilei oh/et In I fornrannn and and foal‘1,1,112 Location at Surface 1561' FSL, 304' FEL, Sec 29, T13N,RO9E,UM NGS Coordinates RKB Elevation 62' AMSL Northings: 6,013,799.4' Eastings: 518,096.2' Pad Elevation 34' AMSL Location at Top of 1250' FNL,571' FEL, Sec 29,T13N,RO9E,UM Productive Interval (Kuparuk A Sand) NGS Coordinates Measured Depth, RKB: 7,280' Northings: 6,016,267.24' Eastings: 517,816.32' Total Vertical Depth,RKB: 6,437' Total Vertical Depth, SS: 6,390' Location at Total Depth 1103'FNL, 610' FEL, Sec 29,T13N,RO9E,UM NGS Coordinates Measured Depth, RKB: 7,494' Northings: 6,016,413.59' Eastings: 517,777.09' Total Vertical Depth, RKB: 6,589' Total Vertical Depth, SS: 6,527' and (I))ohe r Dime-ma/um r out,ed ht 211 1 IC 25 050(1)). Requirements of 20 AAC 25.050(b) If a hell is n,ha int(nnonallh dee runs the application/o, a l'e)ell to D1)ill(Form I041)1)twist I 11 mrchnA a plat.dr an m to a vmlab!, sea/e shots mg the path of the proposed n e//bort. ma ladrrr,g all aa//ac enl 11(111,01 es n WWI 21)11 fee/of ant'porlio) o/lire pr op/led It cl/. Please see Attachment: Directional Plan No close approach issues exist. Separation factors are above 1.5 once the sidetrack is greater than 100' MD beyond the KOP and continue to increase with depth. The 1/4" mile pool scan of the top of Kuparuk A4 Sand shows the closest approach to be the original 3N-07 wellbore 230'away at 7200' MD. in,/ (2)for all 01/Il unhor 21111 fiIlof the proposed uellhot e I)list the name s of the opt r alms of!hose It e/h, to the e Ven/that!hose mime 1 all Anou n o1 disc of e r ah/c In pmhha rec o ds,and shote that cath nunred opt I arot has herr!1111 d a e'opl'of the apphc anon ht'c tv)died marl. 01 (R)slave that the applicant n Ilre only affecicd on mer The Applicant is the only affected owner. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) 1n 0/1/1/rc alum/01 1l I'(1 mil re Urrll nnnt 11 acc,,mpanlyd h( rurh 11/1h, /0//01(al,/hills 1 1(rp1 Ph cul nem 1(h lath 1'm lilt a nh the cY1l/In)r1111,n unrl hie Milled n1'the(INV(atiall (iIa(h(h1miluadd1u71ptio11(jthe h/1niourp1c>rntloncorium ill IBOI'/Ja+1ryuu(dht 1) I I('25(135,20 I IC'51136.or 311.1-1('25 Ili_ us apph(ahl( Please reference BOP schematics on file for Doyon 141. Drilling Hazards Information Requirements of 20 AAC 25.005(c)(4) In application lot a pc rine to Di ill must h(ca r onq,ulnrd ht (1/111 u/Ihr/o//on lng Items,cscc pi lot an item all rade on til( a Nh the(annuli von and 1lrnll/I>d in du application (4)information on d1IN1ni/lra_a/ill 101 hiding (.1)the nravnuon dou•nho/11)1111111(MU)MTh'he 111(•011111(7 rd c 1 il(1lu 1(1111 ro d(tcrnunr II.and nur.crinan polrnnal 1m/1(c 1 prlluu'r hau•d on a median( ,r od1(nr. The maximum potential surface pressure (MPSP) while drilling 3N-07A is calculated using a maximum reservoir pressure of 3,500 psi, a gas gradient of 0.10 psi/ft, and the estimated depth of the Kuparuk A sand at 6,370' TVD (WP07): A Sand SIBHP = 3,500 psi A Sand estimated depth (WP07) = 6,370' TVD Gas Gradient = 0.10 psi/ft as per 20 AAC 25.005 (c)(4)(A) Hydrostatic of full gas column = 637 psi (6,370' TVD * 0.10 psi/ft) MPSP = SIBHP—gas column = 2,863 psi (3,500 psi—637 psi) (R)chaI on pollIllIal•Lal=WW1. The well bore is not expected to penetrate any gas zones. Ind (c data con(1'1 nm;porrntiul(urn(/of biter/u ohllnrl 1111 h a(0l>nurntu(h Cu-//1111111 rd 111 air 1011 10 c rrlatron=un11 and.70r1r+ Iha1 hu(( a 1)l0/r1vt1 101 d11/1l>m1>1/ ool nig See attached 3N-07A Drilling Hazards Summary Requirements of 20 AAC 25.005(c)(5) to upphrutiun/01 >1/'rrnut l0 Ih1//nmv h1 111 rnmpanlld hr('11(11 01 till'/0//011'11,'nCm1 1 1o(p1 l,1( an n(1n ah(11t1 on/11( n trh the r0nuln vin and uh'ntllild m the application (5)a dllcnpti0n o11h1 plocc'durl for rondurrrng lorman011 oul,gnn 11/11 a1 r(yao1d 11,1111, 211 I I('35.11311111 A procedure is on file with the commission for performing LOT's. For 3N-07A the leak off test for the intermediate hole will occur after kicking off the cement plug and 20' of new formation is drilled. The formation at the KOP depth will be pressured until leak-off occurs or to 16.0 ppg EMW is reached, which ever comes first. A required minimum leak off of 12.5 ppg EMW must be obtained. After setting the 7" intermediate at 7,100' MD /6,310' TVD, 20' of hole will be drilled, and the formation will be pressure tested until leak-off occurs or to 16.0 ppg EMW is reached, which ever comes first. A required minimum leak off of 13.5 ppg EMW must be obtained. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) la application for/'ermii to/)i ill aim/lie acranipanii d br each of the fol/on m,;items, eli eil lot an thin al eac/t'on file with the c on/mn+run uml idr'nIilied FII du application Ihl a c ompleh pi oposed(Ming and cent(wing in qgi ani as i c anti rd hr'll I_-1( 251)30 and a do ae i/plum of ant sinned line,,pi,-I),i lot a/eel lair/.oi trre/n/o h, inshilld Casing Program Casing Hole weight Top Btm OD Size (lb/ft) Grade Connection Length MD/TVD MD/TVD 16" C'euluclar 62.5 11-40 Weld I15- Surface 3-4- 115" 115' Uri;final I0-5 X" 36 .1-55 BTC 3.691 Surface 33� 3.691- ' 3.634 \�'rllhc rr 9-5,8 7.' 8-1 2" 26 .1-55 BTC 7.706' Surface 32' 7.706' ,'6.73.4- Sidetrack 7"Casing 8-3/4" 26 L-80 BTCM 7,100' Surface 32' 7,100'/6,310' Below 9- 4-1/2"Liner 6-1/8" 11.6 L-80 IBTM 588' 6,900'/6,169 7,494'/6,589 5/8" Surf Csg. 3-1/2" Tubing 9.3 L-80 EUE 6900' Surface 28' 6,900'/6,169' Single Stage Cement Program—Intermediate Hole Cement will be placed from the intermediate TD at 7,100' MD to 1500' below the surface casing shoe z 5100'MD . The casing shoe will be at 7,100' MD and will be landed at surface z 32'. The slurry consists of 380 sacks of Class G cement plus additives at 15.8 ppg with 35% excess yielding 1.17 ft3/sx. Cement System Preflush: 40 bbls Chemical Wash Spacer: 40 bbls MudPush II Lead Slurry: 380 sacks Class G Cement+ additives Yield= 1.17 ft3/sx Mix Water= 5.1 gal/sx / Length Capacity ; ,/Slurry Volumes (ft) (ft3) Excess Total(ft ) Total(sacks) Open Hole x Casing OD 2006 302 35% 407 347 8.5"x 7.00" Shoe Track ID 80 17 0% 17 15 6.276" _ 362 424 Total T _ e, . Single Stage Cement Program—Production Hole Cement will be placed from TD at 7,494' MD to 100' above the top of liner. The liner shoe will be at 7,494' MD and the top of liner set at 6,900' MD (approximately 200'of overlap inside the 7" casing). The slurry consists of 85 sacks of Class G cement plus additives at 15.8 ppg with 20% excess yielding 1.17 ft3/sx. Cement System Preflush: 15 bbls Chemical Wash Spacer: 15 bbls MudPush II Lead Slurry: 85 sacks Class G Cement+ additives Yield= 1.17 ft3/sx Mix Water= 5.1 gal/sx Length Capacity ; Slurry Volumes (ft) (ft') Excess Total(ft ) Total(sacks) Liner Lap 200 22 0% 22 19 6.276"x 4.50" Open Hole x Liner OD 388 37 20% 44 38 6.125"x 4.50" Shoe Track ID 80 7 0% 7 6 4.0" Liner Cap 200 26 0% 26 22 6.276" Total 99 85 Diverter System Information Requirements of 20 AAC 25.005(c)(7) I n apple(hon 101 a/'c 1 mil 10 1)1 III must 1,1 01 cumpamrd III c ac 11 01 1/0 1011011 1111;la 111s 111 c p1 101 un 11(m 11/1.1101 un 1111 111111 111c c 0n1nn/vun and 111111,(1 111 1/1< app/1c anon (7)a diagram and description of the diveiter system as required by 20 MC 25.035, unless this requirement is waived by the commission under 20 MC 25.035(h)(2); This rotary sidetrack will be drilled out from under existing 9-5/8" casing. BOPE will be installed prior to pulling the existing tubing completion, and therefore no diverter is required. y 3o( k::1( 6 qe '-F— w t 5-000 Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) In application 101 a 1'11 m11 10 1)11//101/11 he acrunlpanlyd 111 c ach 01 III( 10//011111,Y la 1115 (I«111/01 an 110m 1111 c adl nn lila 111111 lilt c(11nm11 von cmd 1drm1/it'd 111 lilt appllc al10n (8)a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 MC 25.033; Mud Program Summary Depth MD Mud Wt. Funnel API Fluid (ft) (ppg) Vis(cp) PV YP Loss pH Comments (cc/30min) LSND 9.5-11.0 60-80 25-35 7-8 <6 9.5-10 3,691'-7,100' L' 11.0-12.0 60-80 25-40 5-6 <6 9.5-10 7,100'——7,494' Intermediate and Production Hole Sidetrack Fluid: A 9.8 ppg LSND drilling fluid will be used to drill the intermediate hole to 7,100' MD /6,310' TVD. An 11.3 ppg LSND drilling fluid will be used to drill the production hole to 7,494' MD/6,589' TVD. The drilling mud weight is calculated using an A Sand EMW of 10.6 ppg plus 0.5 ppg trip margin to result in an 11.1 ppg. Fluid weight will have sufficient density to overbalance the pressure of uncased formations penetrated. Additional focus will be on minimizing the potential of a hydrostatic pressure surge or swab and good hole cleaning practices. These practices include monitoring tripping speeds and PWD data, controlling ROP, pumping regular sweeps, adjusting rheology, and charting drag weights. Diagram of Doyon 141 Mud System on file with AOGCC. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005(c)(9) N/A -Application is not for an exploratory or stratigraphic test well. Seismic Analysis Requirements of 20 AAC 25.005(c)(10) N/A -Application is not for an exploratory or stratigraphic test well. Seabed Condition Analysis Requirements of 20 AAC 25.005(c)(11) N/A - Application is not for an offshore well. Evidence of Bonding Requirements of 20 AAC 25.005(c)(12) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. Proposed Drilling Program Requirements of 20 AAC 25.005(c)(13) In application!111 a I'c i ma in Ib 1/l mcnr h(a((umpum,d hi c u(l1 al the/n//mi uie thins c tc c IN lu1 an 11(111 all naclr on Ill, a Nh flu commission and n/c nn11i(d 1n nhc uh/,hc anon 3N-07 P&A Pre Rig Work(previous sundry): a. RIH with 2.20" (min run OD)x 14' OAL dummy drift to 6900' RKB to verify that a 2.125"run OD x 14.6' OAL Baker Inflatable Cement Retainer will drift to target set depth. (only an inflatable retainer is currently available) b. Set Catcher Sub on XXN Plug at 7129' RKB. Pull GLV's from GLM #1 (2705' RKB), GLM #2 (4235' RKB), GLM#3 (5454' RKB), and pull OV from GLM #4 (6383' RKB). Install DV's in GLM's#1, 2, 3,&4 to dummy off tubing for MIT's. c. MITT to 2500 psi to verify tubing&XXN Plug integrity. Perform MITIA to 2500 psi. d. Pull DV from GLM #5 at 6973' RKB. Leave pocket open to enable circulating cement to IA. If DV in GLM#5 cannot be pulled for any reason,request E-line tubing punch at 7005' RKB at middle of a full joint. Pull DV from GLM #1 (2705' RKB) and leave pocket open to enable circulating from the IA to Tbg x CT during the cement P&A.Pull Catcher Sub. e. Verify that 15 bbls of cement is mixed and ready to pump, then swap to pumping 15 bbls of 15.8 ppg Class G cement at 1.0- 1.5 bpm down coil while continuing to take returns from the Tbg x CT annulus, followed by: continued pumping of 5 bbls of Seawater spacer at 1.0 - 1.5 bpm down coil while continuing to take returns from the Tbg x CT annulus, followed by-45 bbls of Biozan Gel, while taking all returns from the Tbg x CT annulus. Pump 14 bbls of cement at-1.0 bpm through the Cement Retainer while continuing to take 1:1 returns from the Tbg x CT annulus to spot the cement on top of the XXN Plug at 7129' RKB, and into the 7" x 2-7/8" IA. Do not over-displace cement to IA to avoid displacing cement too high up the IA. With 14 bbls of cement through the Cement Retainer, PU CT off the Retainer and pump the last barrel of cement on top of the Retainer to 6727' RKB while POOH with CT and taking returns from Tbg x CT annulus. f. WOC 24 hours. Notify AOGCC Inspector(659-2714; 659-3607 pager) of the timing of the post-cement plug tag and PT. RIH & drift tubing to PBTD (TOC). Pe`orm CMIT(GLM #1 at 2706' RKB has open pocket) to 2500 eick psi to PT cement plug in tubing and IA, and hold for 30 minutes. Record test results. Perform a drawdown test by bleeding down the tubing and IA pressure to open top tank. Tubing & IA should bleed down to 0 psi to verify good cement P&A integrity. Record the test results. Set a DV in GLM #1 at 2706' RKB. This enables circulating only through tubing cut after E-line cuts the tubing(step#7)to verify indication of a good cut. g. RIH with Halliburton 1-9/16" run OD RCT tubing cutter with anchor arms for 2-7/8"tubing. Cut tubing at +/ 4400' RKB near middle of a full joint. This cut location is-400' below planned sidetrack KOP of-4000' RKB. POOH with tubing cutter. Pump diesel down the tubing while taking returns from the IA noting rates and pressures to verify indication of a successful cut. Set BPV. Pull well house and prepare site for the rig. 1. Move Doyon 141 on 3N-07A and rig up. 2. Pull BPV and VR plugs. Record tubing,IA,and OA pressures. Circulate out freeze protect through tubing cut and monitor well foLpr ss e. --wc n- 13 e 3. Set BPV and nipple down tree. M/U blanking plug in tubing hanger and nipple up BOPE. • Notify AOGCC field inspector 24 hours prior to BOPE test. • Test ROPE to 250 psi low/3,500 psi high against upper 3 '/z"X 7"VBR as per drilling permit. • AA (.4" I,,• Lower Pipe Rams are 2 7/8"X 6"VBR e C,i+ii • A FOSV is to be kept on the floor at all times with pertinent X-over for DP or Casing thread in rotary table. lc 4. Pull blanking plug and BPV. Pull tubing hanger and lay down 3-1/2"completion. t7 5. Run 7"casing scraper to approximately 4,400' MD. 6. Set 7"bridge plug bottom at approximately 4,400' MD. ;DP's'( 7. Cut 7"casing at approximately 4,300' and pull 7"packoff. Onoo oa3ing i3 out wc arc working in OII,thcrcforc wc arc S 1�3 working on 2 wock BOP test cycle. - 3(2 8. Lay down 7"casing. 9. RIH to top of cut at approximately.4,300' with DP and pump 80 bbls of Class G cement plus additives at 15.8 ppg for FLA kick off plug. 10. POOH and WOC minimum of 12 hrs `.1L��1 L 11. While WOC prep directional tools and PU bit,motor and MWD tools and perform housekeeping. I 12. Pick up DC's and HWDP and DP and run in hole to 3,000' and displace hole. 13. Stage in hole to top of cement plug and dress it off to 3,900'. 14. Orient MWD and motor and begin time drilling off of cement kick off plug...-1 2 ik &f 61 15. Perform LOT with rig pump as per CPAI procedure to 16 ppg EMW. Minimum acceptable leak off is 12.5 ppg EMW. ��� 16. Drill 8-1/2"hole from 4,000' MD to 7,100' MD(above C Sand). )j17. At total depth,circulate hole clean and perform wiper trip to KOP. Once back on bottom,circulate until hole is clean. Pull out of hole and rack back drill pipe and BHA. Pull wear bushing. /‘P 18. Run 7",26 ppf,L-80 casing to TD and land on mandrel in wellhead. 19. Cement casing to 5,200' with 15.8 ppg Class G slurry and 35%excess. 20. Drill out shoe track and 20' of new formation. Displace hole to 11.3 ppg MW. Perform open hole leak off to 16.0 ppg ?(a EMW. Minimum acceptable leak off is 13.5 ppg EMW. 21. Drill 6-1/8"hole from 7,100' MD to 7,494' (TD). 22. At total depth,circulate hole clean and perform wiper trip to 7"shoe. Once back on bottom,circulate until hole is clean. Pull out of hole and rack back drill pipe and BHA. Pull wear bushing. 23. Pick up and run 4-1/2" 11.6#L-80 liner. The top of liner will be placed at approximately 6,900' MD allowing for 200' of overlap. 24. Cement liner to top with 15.8 ppg Class G slurry and 35%excess. Set liner hanger. Slackoff and set liner top packer. Circulate out excess cement above liner. 25. Monitor well then pull out of hole laying down drill pipe. 26. Run 3-1/2"upper completion as per procedure with SSSV and 5 GLMs. 27. RD and MO Doyon 141. Coil tubing drilling rig will return at a future date to drill A Sand producers. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005(c)(14) In application lot a Penult 10 1)1 rll music he arcom/tttmrd/o t at h of the follow lug heat,t tt c/Il 101 (ill item ah t 111/1 on filr ilia,the t'omnut 510tH and Mollified In Ih( tgtftht altos /4)agenerttl des(11141011 of/1011 Ihc 0/)t'I0101/titins/o Ills/too'u/‘11111111g 11111(1 and cu 9uI t and a i101t'lllt'lll u/n hrlhrt Ihc o/tcrtltot Intend/10 rt'yucV 111/1/10/1:11/011 uncict 2/) I I('25 OSI)for an annuli', dnittttal operation un Ihc Itcl/ Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved disposal well, or stored, tested for hazardous substances, and used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. Attachments: Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic Attachment 4 Cement Proposal ConocoPhillips (Alaska) Inc. -Kup2 Kuparuk River Unit Kuparuk 3N Pad 3N-07 3N-07A Plan: 3N-07A (wp07a) Standard Proposal Report 21 March, 2012 Amommo HALLIBURTON Sperry Drilling Services ORIGINAL HALLIBURTON Project: Kuparuk River Unit WELL DETAILS: 3N-07 Sperm Origins_____s Site: Kuparuk 3N Pad Ground Level: 33.90 Well: 3N-07 +N/-S +E/-W Northing Easting Latittude Longitude Slot Wellbore: 3N-07A 0.00 0.00 6013799.44 518096.21 70°26'55.956N 149°51'8.533W Plan: 3N-07A(wp07a) REFERENCE INFORMATION Co-ordinate(N/E)Reference:Well 3N-07,True North Vertical(TVD)Reference:Plan:3N-07A @ 61.908(D141(28+33.9)) Measured Depth Reference: Plan:3N-07A @ 61.908(0141(28+33.9)) Calculation Method:Minimum Curvature 3000— CASING DETAILS: 3N-07A(wp07a) MD TVD TVDSS Name Size Hole Size 109.90 109.90 48.00 16"Conductor 16 24 368630 3628.84 3566.94 9 5/8" 9-5/8 13-1/2 7099.66 6309.90 6248.00 7"x 8 1/2" 7 8-1/2 • 2750- 31.407494.97 6589.43 6527.53 4 1/2"x 6 1/8" 4-1/2 6-1/8 b A t 7" - �' 89 65550 4 I/2"x 6 1/8" TD Q 7495'MD,6589'TVD:1103'FNL,610'FEL-Sec29-T13N-R09E • 650° 2500- 3 07A(wp07) Top KupA3 @ 7281'MD,6438'TVD:1250'FNL,571'FEL-Sec29-T13N-R09E - Top KupD Q 7114'MD,6320'TVD:1364'FN1.,541'FEL-Sec29-T13N-R09E •`_ Casing Point @ 7100'MD,6310'TVD:1373'FNL,539'FEL-Sec29-T13N-R09E €250 7"x 8 1/2" 2250- - 3N-07A (wp07a) DDI = 5.413 6000 2000— _ 000— S0 5500 1750- 0 5500 5%50 1500 5250 0 5p00 1250— g000 4150 4750 1000— ._ g500 4500 750 - 3.04_250 t° 500— 4000 KOP @ 3850'MD,3772'TVD:1953'FSL,155'FEL-Sec29-T13N-R09E 9 5/8" • 350 T M Azimuths to True North - / Magnetic North:16.75° 250— 3,54, Magnetic Field Strength:57362.5snT 32.50 Dip Angle:79.92° Date: 3/25/2011 - Model:BGGM2010 16"Conductor 0 II 1 1 , 1111 -1250 -1000 -750 -500 -250 0° 250 500 750 1000 1250 West(-)/East(+)(350 ft/in) Conn OPhiIIips ORIGINAL Alaska W LLI 0) O 2' 0) ^ N CC Z ILL,..03 N Z M_ _N = Q O v V 0 N N W m H co _ 8 NY �00� O N ~ - - co N d a CON U 0 -co 1 d 0 / O c o3 mY y° ami CO 0 -_ v _ V N �� YY Nlo 00 h� 1-" J CO 0 C f)L N - r S r co c 2 p 0 _ • , . 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I I I I 11111 I - I I I II 1 1 a \ O I I 1 I II 011 I —(co O \ OS I I I I II 1 1 I _ co 1 I I 1 II 11 I - \ SS I I I I 11111 1 -0 \\ O 1 1 I 11111 I - o \ OOe I I I - 1 11 11 1 - I O '0 , 1 I Y 111 I I —el O I Y I 11 I I _ 00 I 1 N \ I I m I 11111 I - 1 I 1 Y I II 11 I I __-N 11 _ E I I 0 y X111 I - 00 I ru i 2 11 11 1 I —o O I I j II j11 I - 1 y 1 Y 11111 I - r` I I 1111 I _—N Y I I.!1 m Q c0 - I a I I U 1 c Q - (+) I D I I 111111 1 1 N _ V z y `� 1 - I U �I1(Ir i¢ I o, I 1 11 111 Ir ¢ -(0n 0 I 1( III�1! f,' / t E--____ � a = I 1�A1 . , ,,, ,i... I o , 1,00,,,,, - CC _ .:, IIII , IIII1IIII ( IIII , IIII , IIII , IIII , IIII , � � � � ( IIII ( IIIII IIII , IIII , IIII 1, II � ,, lu tylll ll , llll , f Ea J co 0 h m 0 hM 0 CO 0 M 0 h M 0 M M 1f) CO 00 0 - M (p (0 c0 O M 0) (0 c0 O M J 0 N 00 (0 0 M 0) N- 0) CO 00 c0 00o N (C) CO _ i co co co co M ; V' 00 00 00 (0 (0 co (0 (0 (0 (0 (0 (0 (u1/4 099) a�I !.10 a 1 Halliburton -Sperry I-IALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 3N-07 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:3N-07A @ 61.90ft(D141 (28+33.9)) Project: Kuparuk River Unit MD Reference: Plan:3N-07A @ 61.90ft(D141 (28+33.9)) Site: Kuparuk 3N Pad North Reference: True , Well: 3N-07 Survey Calculation Method: Minimum Curvature Wellbore: 3N-07A Design: 3N-07A(wp07a) Project Kuparuk River Unit,North Slope Alaska,United States Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 3N Pad Site Position: Northing: 6,013,799.17ft Latitude: 70°26'55.957 N From: Map Easting: 517,946.19ft Longitude: 149°51'12.938 W Position Uncertainty: 0.00 ft Slot Radius: 0" Grid Convergence: 0.14 ° Well 3N-07 Well Position +N/-S 0.00 ft Northing: 6,013,799.44 ft ' Latitude: 70°26'55.956 N +E/-W 0.00 ft Easting: 518,096.21 ft Longitude: 149°51'8.533 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 33.90 ft • Wellbore 3N-07A Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2010 3/25/2011 16.75 79.92 57,363 Design 3N-07A(wp07a) Audit Notes: Version: Phase: PLAN Tie On Depth: 3,850.00 Vertical Section: Depth From(TVD) +N/-S +El-W Direction (ft) (ft) (ft) (1 28.00 0.00 0.00 353.22 Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Inclination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (ft) (°) (°) (ft) ft (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) 3,850.00 30.92 28.26 3,771.56 3,709.66 391.52 148.52 0.00 0.00 0.00 0.00 3,880.00 30.92 28.26 3,797.30 3,735.40 405.10 155.82 0.00 0.00 0.00 0.00 3,980.00 30.85 18.51 3,883.17 3,821.27 452.08 176.14 5.00 -0.07 -9.75 -95.00 4,468.34 37.81 345.69 4,289.65 4,227.75 718.43 178.91 4.00 1.42 -6.72 -83.64 6,300.19 37.81 345.69 5,736.95 5,675.05 1,806.51 -98.72 0.00 0.00 0.00 0.00 6,480.23 45.00 345.14 5,871.90 5,810.00 1,921.66 -128.74 4.00 3.99 -0.31 -3.10 7,280.68 45.00 345.14 6,437.90 6,376.00 2,468.72 -273.93 0.00 0.00 0.00 0.00 7,434.97 45.00 345.14 6,547.00 6,485.10 2,574.17 -301.92 0.00 0.00 0.00 0.00 7,494.97 45.00 345.14 6,589.43 6,527.53 2,615.18 -312.80 0.00 0.00 0.00 0.00 3/21/2012 5:49:22PM Page 2 COMPASS 2003.16 Build 69 ORIGINAL Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 3N-07 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:3N-07A @ 61.90ft(D141 (28+33.9)) Project: Kuparuk River Unit MD Reference: Plan:3N-07A @ 61.90ft(D141 (28+33.9)) Site: Kuparuk 3N Pad North Reference: True Well: 3N-07 Survey Calculation Method: Minimum Curvature Wellbore: 3N-07A Design: 3N-07A(wp07a) 'Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 3,574.59 3,694.90 27.27 32.85 3,636.49 3,574.59 326.14 109.47 6,014,125.81 518,204.87 2.30 310.94 3,794.90 30.28 30.62 3,724.14 3,662.24 367.09 134.74 6,014,166.82 518,230.04 3.20 348.63 3,850.00 30.92 28.26 3,771.56 3,709.66 391.52 148.52 6,014,191.28 518,243.76 2.48 371.26 KOP @ 3850'MD,3772'TVD:1953'FSL,155'FEL-Sec29-T13N-R09E 3,880.00 30.92 28.26 3,797.30 3,735.40 405.10 155.82 6,014,204.87 518,251.03 0.00 383.88 3,900.00 30.85 26.32 3,814.46 3,752.56 414.22 160.52 6,014,214.01 518,255.71 5.00 392.38 3,980.00 30.85 18.51 3,883.17 3,821.27 452.08 176.14 6,014,251.90 518,271.23 5.00 428.13 4,000.00 30.95 16.96 3,900.33 3,838.43 461.86 179.27 6,014,261.69 518,274.34 4.00 437.48 4,100.00 31.71 9.41 3,985.78 3,923.88 512.40 191.07 6,014,312.25 518,286.02 4.00 486.27 4,200.00 32.89 2.25 4,070.34 4,008.44 565.48 196.44 6,014,365.34 518,291.25 4.00 538.35 4,300.00 34.46 355.61 4,153.58 4,091.68 620.84 195.34 6,014,420.69 518,290.02 4.00 593.46 4,400.00 36.35 349.52 4,235.12 4,173.22 678.21 187.78 6,014,478.04 518,282.32 4.00 651.32 4,468.34 37.81 345.69 4,289.65 4,227.75 718.43 178.91 6,014,518.23 518,273.36 4.00 692.30 4,500.00 37.81 345.69 4,314.66 4,252.76 737.24 174.11 6,014,537.03 518,268.52 0.00 711.54 4,600.00 37.81 345.69 4,393.67 4,331.77 796.64 158.96 6,014,596.38 518,253.22 0.00 772.31 4,700.00 37.81 345.69 4,472.67 4,410.77 856.03 143.80 6,014,655.74 518,237.92 0.00 833.08 4,800.00 37.81 345.69 4,551.68 4,489.78 915.43 128.65 6,014,715.09 518,222.62 0.00 893.85 4,900.00 37.81 345.69 4,630.69 4,568.79 974.83 113.49 6,014,774.45 518,207.32 0.00 954.63 5,000.00 37.81 345.69 4,709.70 4,647.80 1,034.23 98.33 6,014,833.80 518,192.02 0.00 1,015.40 5,100.00 37.81 345.69 4,788.70 4,726.80 1,093.63 83.18 6,014,893.16 518,176.72 0.00 1,076.17 5,200.00 37.81 345.69 4,867.71 4,805.81 1,153.02 68.02 6,014,952.51 518,161.43 0.00 1,136.94 5,300.00 37.81 345.69 4,946.72 4,884.82 1,212.42 52.87 6,015,011.87 518,146.13 0.00 1,197.71 5,400.00 37.81 345.69 5,025.73 4,963.83 1,271.82 37.71 6,015,071.22 518,130.83 0.00 1,258.48 5,500.00 37.81 345.69 5,104.73 5,042.83 1,331.22 22.55 6,015,130.58 518,115.53 0.00 1,319.25 5,600.00 37.81 345.69 5,183.74 5,121.84 1,390.62 7.40 6,015,189.93 518,100.23 0.00 1,380.03 5,700.00 37.81 345.69 5,262.75 5,200.85 1,450.01 -7.76 6,015,249.29 518,084.93 0.00 1,440.80 5,800.00 37.81 345.69 5,341.76 5,279.86 1,509.41 -22.92 6,015,308.64 518,069.63 0.00 1,501.57 5,900.00 37.81 345.69 5,420.76 5,358.86 1,568.81 -38.07 6,015,368.00 518,054.33 0.00 1,562.34 6,000.00 37.81 345.69 5,499.77 5,437.87 1,628.21 -53.23 6,015,427.35 518,039.04 0.00 1,623.11 6,100.00 37.81 345.69 5,578.78 5,516.88 1,687.60 -68.38 6,015,486.71 518,023.74 0.00 1,683.88 6,200.00 37.81 345.69 5,657.79 5,595.89 1,747.00 -83.54 6,015,546.06 518,008.44 0.00 1,744.65 6,300.19 37.81 345.69 5,736.95 5,675.05 1,806.51 -98.72 6,015,605.53 517,993.11 0.00 1,805.54 6,400.00 41.79 345.36 5,813.61 5,751.71 1,868.36 -114.70 6,015,667.33 517,976.99 4.00 1,868.84 6,480.23 45.00 345.14 5,871.90 5,810.00 1,921.66 -128.74 6,015,720.59 517,962.82 4.00 1,923.42 6,494.37 45.00 345.14 5,881.90 5,820.00 1,931.33 -131.30 6,015,730.25 517,960.23 0.00 1,933.33 Top HRZ 6,500.00 45.00 345.14 5,885.88 5,823.98 1,935.17 -132.32 6,015,734.09 517,959.20 0.00 1,937.26 6,600.00 45.00 345.14 5,956.59 5,894.69 2,003.51 -150.46 6,015,802.38 517,940.90 0.00 2,007.27 6,700.00 45.00 345.14 6,027.30 5,965.40 2,071.86 -168.60 6,015,870.68 517,922.60 0.00 2,077.28 6,774.39 45.00 345.14 6,079.90 6,018.00 2,122.70 -182.09 6,015,921.48 517,908.98 0.00 2,129.36 Upper Kalubik(Base HRZ) 6,800.00 45.00 345.14 6,098.01 6,036.11 2,140.20 -186.74 6,015,938.97 517,904.29 0.00 2,147.29 6,900.00 45.00 345.14 6,168.72 6,106.82 2,208.55 -204.88 6,016,007.26 517,885.99 0.00 2,217.29 6,932.78 45.00 345.14 6,191.90 6,130.00 2,230.95 -210.82 6,016,029.65 517,879.99 0.00 2,240.24 Lower Kalubik(K Mkr) 3/21/2012 5:49:22PM Page 3 COMPASS 2003.16 Build 69 OR0NAL Halliburton -Sperry FI LLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 3N-07 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:3N-07A @ 61.90ft(D141 (28+33.9)) Project: Kuparuk River Unit MD Reference: Plan:3N-07A @ 61.90ft(D141 (28+33.9)) Site: Kuparuk 3N Pad North Reference: True Well: 3N-07 Survey Calculation Method: Minimum Curvature Wellbore: 3N-07A Design: 3N-07A(wp07a) Planned Survey Measured Vertical Map Map Depth Inclination Azimuth Depth TVDss +N/-S +E/-W Northing Easting DLS Vert Section (ft) (°) (°) (ft) ft (ft) (ft) (ft) (ft) 6,177.53 7,000.00 45.00 345.14 6,239.43 6,177.53 2,276.89 -223.02 6,016,075.56 517,867.69 0.00 2,287.30 7,099.66 45.00 345.14 6,309.90 6,248.00 2,345.00 -241.09 6,016,143.62 517,849.45 0.00 2,357.07 Casing Point @ 7100'MD,6310'TVD:1373'FNL,539'FEL-Sec29-T13N-R09E-7"x 8 1/2" 7,100.00 45.00 345.14 6,310.14 6,248.24 2,345.24 -241.16 6,016,143.85 517,849.39 0.00 2,357.31 7,113.80 45.00 345.14 6,319.90 6,258.00 2,354.67 -243.66 6,016,153.28 517,846.86 0.00 2,366.97 Top KupD @ 7114'MD,6320'TVD:1364'FNL,541'FEL-Sec29-T13N-R09E-Kuparuk D 7,200.00 45.00 345.14 6,380.85 6,318.95 2,413.58 -259.29 6,016,212.14 517,831.08 0.00 2,427.32 7,207.14 45.00 345.14 6,385.90 6,324.00 2,418.46 -260.59 6,016,217.02 517,829.78 0.00 2,432.31 C4 7,229.77 45.00 345.14 6,401.90 6,340.00 2,433.93 -264.69 6,016,232.47 517,825.63 0.00 2,448.15 Cl-B 7,272.19 45.00 345.14 6,431.90 6,370.00 2,462.92 -272.39 6,016,261.45 517,817.87 0.00 2,477.86 A5 7,280.68 45.00 345.14 6,437.90 6,376.00 2,468.72 -273.93 6,016,267.24 517,816.32 0.00 2,483.80 Top KupA3 @ 7281'MD,6438'TVD:1250'FNL,571'FEL-Sec29-T13N-R09E-A3-3N-07A(wp07)A3 7,300.00 45.00 345.14 6,451.56 6,389.66 2,481.93 -277.43 6,016,280.44 517,812.78 0.00 2,497.32 7,308.96 45.00 345.14 6,457.90 6,396.00 2,488.05 -279.06 6,016,286.56 517,811.14 0.00 2,503.60 A2 7,349.97 45.00 345.14 6,486.90 6,425.00 2,516.08 -286.50 6,016,314.57 517,803.63 0.00 2,532.31 Al 7,400.00 45.00 345.14 6,522.27 6,460.37 2,550.27 -295.57 6,016,348.73 517,794.48 0.00 2,567.33 7,427.76 45.00 345.14 6,541.90 6,480.00 2,569.24 -300.61 6,016,367.69 517,789.40 0.00 2,586.76 Miluveach 7,434.97 45.00 345.14 6,547.00 6,485.10 2,574.17 -301.92 6,016,372.61 517,788.08 0.00 2,591.81 7,494.97 45.00 345.14 6,589.43 6,527.53 2,615.18 -312.80 6,016,413.59 517,777.09 0.00 2,633.82 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +NI-S +EI-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) 3N-07A(wp07)A3 0.00 0.00 6,437.90 2,468.72 -273.93 6,016,267.24 517,816.32 -plan hits target center -Point 109.90 109.90 16"Conductor 16 24 3,686.30 3,628.84 9 5/8" 9-5/8 13-1/2 7,099.66 6,309.90 7"x 8 1/2" 7 8-1/2 7,494.97 6,589.43 4 1/2"x 6 1/8" 4-1/2 6-1/8 3/21/2012 5:49:22PM Page 4 COMPASS 2003.16 Build 69 U IRI Halliburton -Sperry HALLIBURTON Standard Proposal Report Database: EDM 2003.16 Single User Db Local Co-ordinate Reference: Well 3N-07 Company: ConocoPhillips(Alaska)Inc.-Kup2 TVD Reference: Plan:3N-07A @ 61.90ft(D141 (28+33.9)) Project: Kuparuk River Unit MD Reference: Plan:3N-07A @ 61.90ft(D141 (28+33.9)) Site: Kuparuk 3N Pad North Reference: True Well: 3N-07 Survey Calculation Method: Minimum Curvature Wellbore: 3N-07A Design: 3N-07A(wp07a) I Formations Measured Vertical Vertical Dip Depth Depth Depth SS Dip Direction (ft) (ft) ft Name Lithology (0) (0) 6,932.78 6,191.90 Lower Kalubik(K Mkr) 0.00 7,280.68 6,437.90 A3 0.00 6,774.39 6,079.90 Upper Kalubik(Base HRZ) 0.00 7,349.97 6,486.90 Al 0.00 7,207.14 6,385.90 C4 0.00 7,229.77 6,401.90 Cl 0.00 6,494.37 5,881.90 Top HRZ 0.00 7,308.96 6,457.90 A2 0.00 7,427.76 6,541.90 Miluveach 0.00 7,272.19 6,431.90 A5 0.00 7,113.80 6,319.90 Kuparuk D 0.00 7,229.77 6,401.90 B 0.00 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 3,850.00 3,771.56 391.52 148.52 KOP @ 3850'MD,3772'TVD:1953'FSL,155'FEL-Sec29-T13N-R09E 7,099.66 6,309.90 2,345.01 -241.09 Casing Point @ 7100'MD,6310'TVD:1373'FNL,539'FEL-Sec29-T13N-R09E 7,113.80 6,319.90 2,354.67 -243.66 Top KupD @ 7114'MD,6320'TVD:1364'FNL,541'FEL-Sec29-T13N-R09E 7,280.68 6,437.90 2,468.72 -273.93 Top KupA3 @ 7281'MD,6438'TVD:1250'FNL,571'FEL-Sec29-T13N-R09E 7,494.97 6,589.43 2,615.18 -312.80 TD @ 7495'MD,6589'TVD:1103'FNL,610'FEL-Sec29-T13N-R09E 3/21/2012 5:49:22PM Page 5 COMPASS 2003.16 Build 69 G Z0 L I— 0 a D in W L J J L Q m = a N CO Om = d iE I. • C. > H N U CC o L R C NO N Off N O U N O CO O 00..... 1) c -d - a F- CC w _ O /� R x O V/ al) L az R ± //�� IlLi o® co NM w ® E 0-^+ j nnM e N a CO m. 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Cif- • . . , . . . . \ .,..... , . .- . . . . . . . . . . , CL . 0 —.--.-- = ciTh LI 0 CD = = ciThc= clip C CD = 0 = CIM \---- CID 1 \ c-Th • 3N-07A Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) 8-3/4" Hole with 7" Casing Interval* REvent lvel Mitigation Strategy LeDifficult to wash over 7" Low Set whipstock in 9-5/8" surface casing and sidetrack casing down Window/Open Hole leak Moderate Squeeze cement below 9-5/8" casing at window off less than required Hole instability while Moderate Utilize a mud weight to stabilize formations without drilling shale section sustaining losses Directional control Moderate Placement of KOP and bottom hole location to allow for 4° DLS. Ream 8-3/4"hole with hole opener and proper mud weight Run casing to bottom Moderate for hole stability, directional plan with 4° DLS and a tangent from HRZ to TD, and run 7"casing. Reduced trip speeds, real time equivalent circulating Hole swabbing/surging Moderate density(ECD)monitoring, mud rheology, and proper hole filling. Pump and rotate out of hole as necessary. Abnormal Reservoir BOPE drills,keep mud weight above 9.5 ppg, check for Pressure Low • flow during connections and if needed increase mud weight. Reduced pump rates, real time equivalent circulating Lost Circulation Low density(ECD)monitoring, mud rheology, and LCM. Use GKA LC decision tree as needed. Cement Bonding Moderate Run liner with centralization for standoff. Reciprocate . during circulation and pump 35%excess cement. H2S drills, detection systems, alarms, and standard well Hydrogen Sulfide Gas Low control practices. *See Well Plan for more detailed risk information and offset data. n r 4 i `ct .` 'r1. 6-1/8" Hole with 4-1/2" Liner Interval* Event lelve Mitigation Strategy Leak off test less than Low Squeeze 7" casing shoe. required Hole instability while Moderate Utilize a mud weight to stabilize formations without drilling shale section sustaining losses Directional control Low Tangent part of well. Run liner to bottom Moderate Drill 6-1/8"hole with proper mud weight for hole stability, directional plan, and run 3-1/2"liner. Reduced trip speeds, real time equivalent circulating Hole swabbing/surging Moderate density(ECD)monitoring,mud rheology, and proper hole filling. Pump and rotate out of hole as necessary. Abnormal Reservoir .BOPE drills,keep mud weight above 11.5ppg, check for Pressure Moderate flow during connections and if needed increase mud weight. Reduced pump rates,real time equivalent circulating Lost Circulation Low density(ECD)monitoring, mud rheology, and LCM. Use GKA LC decision tree as needed. Cement Bonding Moderate Run liner with centralization for standoff. Reciprocate during circulation and pump 35% excess cement. Hydrogen Sulfide Gas Low H2S drills, detection systems, alarms, and standard well control practices. *See Well Plan for more detailed risk information and offset data. I 3N-07A Slot Recovery 16"62.5#H40 J::::: conductor set at 115' 3 %2" TRMAXX-CMT SCSSV 2.813"ID @ 1800' 0,ti0 MD/1800'TVD ��uk @, 12 ""qQ g :,:,:: 4-\--------- -3 9-5/8"36#J-55 Cut/pull 7" Surface set at 3,691' Wash over 7"to+/-300'below , MD/3,634 TVD surface shoe @ 3,691'MD \,\ ST+/-300'below surface shoe Approx-3991'(wp07) GLM# TVD ft MD ft Valve Type Mandrel Type 1 2,500 2,500 Dummy 3-1/2"x 1-'/z' NNG 2 3,700 3,766 Dummy 3-1/2"x 1-%" NNG 3 4,600 4,863 Dummy 3-1/2"x 1-1/2"NNG 4 5,300 5,748 Dummy 3-1/2"x 1-'/z' NNG Cut 7"csg at approx 4300' 5 5,850 6,463 Dummy 3-1/2"x 1-'/z' NNG 6 6,275 6,800 SOV 3-1/2"x 1-W NNG *SOV(annulus to tubing shear) Lower part of well ti) to be abandoned by SSD coil before rig move . 3-1/2"9.3#,L-80,Design TBD,Surf-6,900' in ft)(' MD re 0 e ::: .„! !ori • i.:.:.:: ::::4,11 r,..i: : .4iii: :•:: ::i::: .3 'h" HES"X"selective nipple w/ 2.813"ID @ 6,860'MD/6,141'TVD ►: ' • .: : 6,,ii ::: Baker 4-'/i"X7"ZXP liner packer hanger @ \\\111 6,900'MD/6,169 TVD' 7"casing set(topset) \\\ @ 7,106'MD/6,315'TVD _,,1, wed 4-1/2"Liner set ,/(e`:15/. Z @ 7,494'MD/6,589'TVD ORIGINAL. 3N-07A Schlumberger CemCADE Preliminary Job Design 4-1/2" Production Liner Permit, WP-07) Preliminary Job Design based on limited input data.For estimate purposes only. Rig: Doyon 141 Volume Calculations and Cement Systems Location: Kuparuk Client:CPAi Revision Date: 03/22/2012 Volumes are based on 20% excess. Displacement is calculated with a 4.0"- 15.7#drill Prepared by: Mike Martin pipe using mud. Location:Anchorage,AK Phone: (907)263-4207 Tail Slurry Minimum thickening time: -145 min. (pump time plus 120 min.) Mobile: (907)748-6900 15.8 ppg Class G +2.0 gps D600G + adds- 1.17 ft3/sk email:martin13@slb.com Annular Volume: 0.0942 ft3/ft x(7494'-7106')x 1.20 (20% excess) = 44 ft3 Lap Volume: 0.1044 ft3/ft x(7106'-6900')x 1.00 (no excess)= 22 ft3 Top of Slurry at end of pumping Cap Volume: < 6,700'MD 0.1276 ft3/ft x(6900'-6700')x 1.00 (no excess)= 26 ft3 Shoe Volume: < Liner Top at 0.0854 ft3/ft x 80'x 1.00 (no excess)= 7 ft3 -6,900' MD Totals: 44ft3+ 22ft3+26ft3+7ft3= 99ft3 99 ft3/ 1.17 ft3/sk= 85 sks (-90 on site) 7",26#casing at 7,106'MD BHST= 158 °F, Estimated BHCT= 120 °F. (BHST calculated using a gradient of 2.1 °F/100 ft.from surface) PUMP SCHEDULE 4-1/2", 12.6#liner in 6-1/8" hole Pump Rate Stage Stage Time Cumulative Stage (bpm) Volume (min) Time (bbl) (min) CW100 5.0 15.0 3.0 3.0 MUDPUSH II 5.0 15.0 3.0 6.0 Latex Slurry 5.0 17.4 3.5 9.5 Pause 0.0 0.0 3.0 12.5 Seawater 5.0 10.0 2.0 14.5 Pause 0.0 0.0 3.0 17.5 Mud 5.0 59.2 11.8 29.3 Slow,pick up plug and 3.0 9.0 3.0 32.3 bump C4 at-7,214'MD MUD REMOVAL Recommended Mud Properties: 11.5 ppg, Pv<20,Ty< 15. As thin and light as possible to aid in mud removal during cementing. TD at-7,494'MD Spacer Properties: 13.0 ppg MudPUSH* II, Pv 25- 30,Ty=35-40 (6,589'TVD) Centralizers: As per CPAi program * Mark of Schlumberger ORIGINAL 3N-07A Schlumberger CemCADE Preliminary Job Design 7" Intermediate - Permit (wp07) Preliminary Job Design based on limited input data.For estimate purposes only. Rig: Doyon 141 Location: Kuparuk Client: CPAI Revision Date: 03/22/2012 Volume Calculations and Cement Systems Prepared by: Mike Martin Volumes are based on 35% excess. The topof the tail slurryis designed to be Location:Anchorage,AK g Phone: (907)263-4207 -5100' MD. Mobile: (907)748-6900 email: martinl3©slb.com Tail Slurry Minimum pump time: -195 min. (pump time plus 120 min.) 15.8 ppg Class G +2 gps D600G +adds- 1.17 ft3/sk 0.1503 ft3/ft x(7106-5100')x 1.35(35%excess)= 407 ft3 0.2148 ft3/ft x 80' (Shoe Joint) = 17 ft3 407 ft3+ 17 ft3 = 424 ft3 370 ft3/ 1.17 ft3/sk= 363 sks Previous Csg. Round up to 380 sks < 9-5/8",36.#casing at 3,691'MD BHST= 145°F, Estimated BHCT= 114°F. (BHST calculated using a gradient of-2.1°F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Cumulative Stage Time Stage Volume Time (bpm) (bbl) (min) (min) CW100 5.0 40.0 8.0 8.0 MUDPUSH II 5.0 40.0 8.0 16.0 Pause 0.0 0.0 5.0 21.0 Latex Slurry 6.0 75.6 12.6 33.6 Pause 0.0 0.0 5.0 38.6 Seawater 5.0 10.0 2.0 40.6 Pause 0.0 0.0 3.0 43.6 Mud 6.0 249.8 41.6 85.2 < Top of Cement at Mud 3.0 9.0 3.0 88.2 -5,100'MD MUD REMOVAL Expected MUD Properties:9.5- 11 ppg, Pv<25, Ty<20. < 7",26#casing v. in 8-3/4"OH Spacer Properties: 12.0 ppg MudPUSH* II, Pv=20-25, Ty=35-40 Centralizers: As per COP program TD at 7,106'MD (6,589 TVD) *Mark of Schlumberger ORIGIN I .w n ni �/ —J I/trG0o0 11R 351 ��p-Vl 7 ff J F-,L; 1-'m --, l Ilia ma 1 .3------- tiI I ,- `;,MEI - / I /1 5000 I{7-4o,1 1? ® _ I !kk IF .•411_;:, m ,7)---- [ -a i _ -,_.,' a la r o e• ,- •: J 74 3., i I - --- I = I -,,- I--- --------- I,�I ,- 'ILII or , fa / t c , . 41 h3r ; i SID---- ,1- CIF iII) _f _ ___ 0 : Q W _ __-11-50no lit-531 I ,C,133 _ 11 i_i iii 111 I i d /925 (a 1= �I - -Iii I My�' • 1 IIa► . [ .1 , � �Qyi � ) ll r10 or j I I I iai I A _t / , I'0 ~ L _ r __!---i _ Y- c --DA'FFTER' HEAL' pr,/00-230 jA I ----i 0 1 1:71 ''3 5'R"UD O JD r---"---,-T\ -TOD I ED -, I 757 ARCO ALASKA INC. KUPARUK FIELD I (ITEM il FART NUMBER i OESCFIRTIu^! I CH 110 6e, LAND INA RINC.16'_,0 �^ 130 719 CASING HANGER Y-5,u_EL C00 _-- - I1 3u0 4414 CA'.1t11.HD ASSY.0-29 114,3'3 CSG - - ThW, 2 Ii 16-33_,TC,[P OUT I�-00'13)-IL SI iH 0 4 ASSY,II v _____ RE,:SR H-Ri"i - I aR3-,00-0278 TLIAINI,IIG ROSY,TCM Cl,9'90 ATM _ REDUCER 1 1.16-SN M; 2 1716-56 OUT U _ Pf 41510X' U 6 R3-160-3�5 REDUCER 60531140 393,9 A A _32_147-236 -HANCER,TC-IA-EN.]16 1,16 H 3 2'9JD 636.1;-8 WELLHEAD I O EIVI,� ,x� 0::'35 _ _ 8 02-043 6188 MR-1-778 TIAF PREP,F4 5495 EN:LIC31 NGP1 W/ ___ '.,E I`�. i v I�1,I,up QI�U�' 03 IN IS �3.. '� D ,-14J- fAC10 0 AS$3.5R. .11_ -1— _ __ --_ — EI ILIA I�IEIV' s tots,., ops iv,s %tiOnDMlntrD54; OVERSIZED DOCUMENT INSERT This file contains one or more oversized documents. These materials may be found in the original hard file or check the parent folder to view it in digital format. TRANSMITTAL LETTER CHECKLIST WELL NAME �iZ ->/�•� r '/ PTD# V Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD• _� f 'l r uc/�— :�r, .."'• POOL• ..`� z t 44-'04... �-r= L r Check Box for Appropriate Letter I Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. 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N „"", v d v aa)) E -4 N 0 a) O 6....N it I- a ✓T a J O a 0 .V1 F- Q Q (n w Q C9 c� Q cn 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. 2tZc 2 Sperry-Sun Drilli Services 2t`Co LIS Scan Ut—ty $Revision: 3 $ LisLib $Revision: 4 $ Tue Aug 07 07:46:49 2012 Reel Header Service name LISTPE Date 12/08/07 Origin STS Reel Name UNKNOWN Continuation Number 01 Previous Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Tape Header Service name LISTPE Date 12/08/07 Origin STS Tape Name UNKNOWN Continuation Number 01 Previous Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kuparuk River Field MWD/MAD LOGS WELL NAME: 3N-07A API NUMBER: 500292153901 OPERATOR: ConocoPhillips Alaska Inc. LOGGING COMPANY: Sperry Drilling TAPE CREATION DATE: 07-AUG-12 JOB DATA MWD RUN 4 MWD RUN 5 JOB NUMBER: -XX-0008472258 -XX-0008472258 LOGGING ENGINEER: JACK KLEINHA JACK KLEINHA OPERATOR WITNESS: GUY WHITLOCK GUY WHITLOCK SURFACE LOCATION SECTION: 29 TOWNSHIP: 13N RANGE: 9E FNL: FSL: 1561 FEL: 304 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 60. 95 GROUND LEVEL: 33. 90 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.750 9. 625 2599.0 2ND STRING 6.125 7. 000 7040.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) , UNLESS OTHERWISE NOTED. r e THESE DEPTF RE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD) . 3. THIS WELL WAS DRILLED OFF OF A WHIPSTOCK, THE TOP OF WHICH WAS AT 2599'MD/2598 'TVD AND THE BOTTOM WAS AT 2616'MD/2615'TVD, IN 3N-07. 4 . MWD RUNS 100-300 WERE DIRECTIONAL ONLY - NO MWD TOOLS WERE INCLUDED IN THE BHA - NO DATA ARE PRESENTED. 5. MAD DATA WERE ACQUIRED FROM THE WHIPSTOCK TO THE END OF MWD RUN 3 WHILE RIH FOR RUN 4. THESE MAD DATA WERE MERGED WITH THE RUN 4 MWD DATA. RSPD DATA ARE PRESENTED FOR THE MAD INTERVAL TO BETTER CORRELATE WITH THE LOG RESPONSES. NO SEPARATE MAD PRESEN- TATION IS INCLUDED. 6. MWD RUN 400 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTIL- IZING GEIGER-MUELLER TUBE DETECTORS, AZIMUTHAL DEEP RESISTIV- ITY (ADR) , PRESSURE WHILE DRILLING (PWD) , AND DRILLSTRING DYNAMICS SENSOR (DDSr) . 7. MWD RUN 500 COMPRISED DIRECTIONAL, DGR, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-P4) , PWD, DDSr, COMPENSATED THERMAL NEUTRON POROSITY (CTN) , AND AZIMUTHAL LITHO-DENSITY (ALD) . 8. LWD DATA ARE CONSIDERED PRIMARY DEPTH CONTROL PER A PHONE CONVER- SATION BETWEEN MIKE WERNER (CPAI) AND BUSTER BRYANT (SD) ON 6 AUGUST 2012. 9. MWD RUNS 100-500 REPRESENT WELL 3N-07A WITH API #50-029-21539-01. THIS WELL REACHED A TOTAL DEPTH OF 7450'MD/6589'TVD. MNEMONICS CURVE DESCRIPTION ROPA AVERAGE RATE OF PENETRATION RSPD TOOL RUNNING SPEED DURING MAD PASS DGRC DGR COMBINED GAMMA RAY R09P 9 INCH PHASE RESISTIVITY R15P 15 INCH PHASE RESISTIVITY R27P 27 INCH PHASE RESISTIVITY R39P 39 INCH PHASE RESISTIVITY EWXT EWR FORMATION EXPOSURE TIME ARH16P Avg 16in 2 MHz PHASE RES ARH32P Avg 32in 2 MHz PHASE RES ARM48P Avg 48in 500 KHz PHASE RES ADXT ADR FORMATION EXP TIME TNPS CTN POROSITY - SANDSTONE TNFA CTN FAR AVERAGE COUNT RATE TNNA CTN NEAR AVERAGE COUNT RATE ACDL/ALCDLC ALD LCRB COMPENSATED DENSITY ADCL/ALDCLC ALD LCRB DENSITY CORRECTION APEL/ALPELC ALD LCRB Pe FACTOR ALRP/ALRPM ALD RPM (SLIDE INDICATOR) AHSI/ALHSI P TOLE SIZE INDICATOR PARAMETERS USED IN NUCLEAR LOG PROCESSING: HOLE SIZE: 6. 125" FIXED MUD WEIGHT: 10. 1 - 11.3 PPG WHOLE MUD CHLORIDES: 500 - 600 PPM CL FORMATION WATER SALINITY: 14545 PPM CL FLUID DENSITY: 1.0 G/CC MATRIX DENSITY 2. 65 G/CC LITHOLOGY: SANDSTONE TEMPERATURE: DYNAMIC FROM EWR-P4, 133.5°F @ TD ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0. 6 FT, EXCEPT FOR ROP AND GAMMA RAY. THESE CURVES ARE SMOOTHED WITH A 1. 1 FT WINDOW. GAP FILL IS SET TO 5 FT FOR ALL CURVES. File Header Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/08/07 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 2538.5 7394 .5 AH1P 2590.0 6987.0 AH2A 2590.0 6987.0 AM3P 2590.0 6987 .0 FET 2600.5 7401.5 ROP 2616.0 7450.0 RPM 7030.0 7401.5 RPS 7030.0 7401.5 FCNT 7030.0 7366.5 RPX 7030.0 7401.5 RPD 7030.0 7401.5 NPHI 7030.0 7366.5 NCNT 7030.0 7366.5 PEF 7030.0 7381.5 CALN 7030.0 7381.5 DRHO 7030.0 7381.5 RHOB 7030.0 7381.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 4 2538.5 7042. 0 MWD 5 7042.0 7450.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RHOB MWD G/CC 4 1 68 4 2 DRHO MWD G/CC 4 1 68 8 3 CALN MWD IN 4 1 68 12 4 PEF MWD B/E 4 1 68 16 5 AH1P MWD OHMM 4 1 68 20 6 AH2P MWD OHMM 4 1 68 24 7 AM3P MWD OHMM 4 1 68 28 8 GR MWD API 4 1 68 32 9 FET MWD HR 4 1 68 36 10 RPX MWD OHMM 4 1 68 40 11 RPS MWD OHMM 4 1 68 44 12 RPM MWD OHMM 4 1 68 48 13 RPD MWD OHMM 4 1 68 52 14 ROP MWD FPH 4 1 68 56 15 FCNT MWD CP30 4 1 68 60 16 NCNT MWD CP30 4 1 68 64 17 NPHI MWD PU 4 1 68 68 18 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2538.5 7450 4994.25 9824 2538.5 7450 RHOB MWD G/CC 1.554 3.227 2.47049 704 7030 7381.5 DRHO MWD G/CC -1.144 0.487 0.0777415 704 7030 7381.5 CALN MWD IN 5. 63 8.35 6.36371 650 7030 7381.5 PEF MWD B/E 2.87 15.83 5.53582 704 7030 7381.5 AH1P MWD OHMM 0.2 5000 6.53604 8795 2590 6987 AH2P MWD OHMM 0.04 5000 7. 94371 8795 2590 6987 AM3P MWD OHMM 0.02 2000 9. 94181 8795 2590 6987 GR MWD API 10.37 468. 63 113.021 9713 2538.5 7394.5 FET MWD HR 0.25 119.95 2.82274 9518 2600.5 7401.5 RPX MWD OHMM 1.42 1044 .45 9.21262 744 7030 7401.5 RPS MWD OHMM 0.56 569.27 7.83585 744 7030 7401.5 RPM MWD OHMM 0. 61 2000 48.5249 744 7030 7401.5 RPD MWD OHMM 0.55 2000 44 . 6586 744 7030 7401.5 ROP MWD FPH 1.56 471.43 131.297 9669 2616 7450 FCNT MWD CP30 104. 64 2612. 67 427.762 674 7030 7366.5 NCNT MWD CP30 14499.5 51667. 6 24811. 9 674 7030 7366.5 NPHI MWD PU 8.23 63. 92 31.3245 674 7030 7366.5 First Reading For Entire File 2538.5 Last Reading For Entire File 7450 File Trailer Service name STSLIB.001 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/08/07 Maximum Physical Record65535 File Type LO Next File Name STSLIB.002 Physical EOF File Header Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/08/07 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DGRC 2538.5 6967.0 AH2P 2590.0 6987.0 AM3P 2590.0 6987.0 AH1P 2590.0 6987.0 ADXT 2600.5 6987.0 ROPA 2616.0 7042.0 LOG HEADER DATA DATE LOGGED: 11-JUL-12 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.47 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 7042.0 TOP LOG INTERVAL (FT) : 3005.0 BOTTOM LOG INTERVAL (FT) : 7042.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 16. 1 MAXIMUM ANGLE: 45.8 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10436490 ADR Azimuthal Deep Resis BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 8.750 DRILLER'S CASING DEPTH (FT) : 2599.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 9. 65 MUD VISCOSITY (S) : 55.0 MUD PH: 9. 9 MUD CHLORIDES (PPM) : 600 FLUID LOSS (C3) : 6.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 2.200 78.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.260 141.4 MUD FILTRATE AT MT: 2.200 78.0 MUD CAKE AT MT: 2.200 78.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 . 1IN Max frames per record Undefined Absent value -999 Depth Units Datum Specification Block sub-type. . . 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 AH1P MWD040 OHMM 4 1 68 4 2 AH2P MWD040 OHMM 4 1 68 8 3 AM3P MWD040 OHMM 4 1 68 12 4 GR MWD040 API 4 1 68 16 5 ROP MWD040 FPH 4 1 68 20 6 FET MWD040 HR 4 1 68 24 7 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2538.5 7042 4790.25 9008 2538.5 7042 AH1P MWD040 OHMM 0.2 5000 6.53604 8795 2590 6987 AH2P MWD040 OHMM 0.04 5000 7.94371 8795 2590 6987 AM3P MWD040 OHMM 0.02 2000 9. 94181 8795 2590 6987 GR MWD040 API 10.37 468. 63 114 .88 8858 2538.5 6967 ROP MWD040 FPH 1.56 471.43 133.465 8853 2616 7042 FET MWD040 HR 0.25 46. 62 2.59377 8774 2600.5 6987 First Reading For Entire File 2538.5 Last Reading For Entire File 7042 File Trailer Service name STSLIB.002 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/08/07 Maximum Physical Record65535 File Type LO Next File Name STSLIB.003 Physical EOF File Header Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 Date of Generation 12/08/07 Maximum Physical Record65535 File Type LO Previous File Name STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data f each bit run in separate file BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH DGRC 6967.5 7394 .5 APEL 7030.0 7381.5 R27P 7030.0 7401.5 EWXT 7030.0 7401.5 TNFA 7030.0 7366.5 R39P 7030.0 7401.5 TNNA 7030.0 7366.5 AHSI 7030.0 7381.5 R15P 7030. 0 7401.5 ADCL 7030. 0 7381.5 TNPS 7030. 0 7366.5 ACDL 7030.0 7381.5 R09P 7030.0 7401.5 ROPA 7042.5 7450.0 LOG HEADER DATA DATE LOGGED: 16-JUL-12 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 88.47 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT) : 7450. 0 TOP LOG INTERVAL (FT) : 7042. 0 BOTTOM LOG INTERVAL (FT) : 7450.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 44 . 4 MAXIMUM ANGLE: 46.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 10470040 CTN COMP THERMAL NEUTRON 11219441 EWR4 Electromag Resis. 4 11301872 ALD Azimuthal Litho-Dens 10508969 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) : 6. 125 DRILLER'S CASING DEPTH (FT) : 7040.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G) : 11.20 MUD VISCOSITY (S) : 50. 0 MUD PH: 9.3 MUD CHLORIDES (PPM) : 550 FLUID LOSS (C3) : 4 .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : 1. 100 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .580 139.7 MUD FILTRATE AT MT: .850 70.0 MUD CAKE AT MT: 1.500 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Rec;".d Data Record Type 0 Data Specification Block Type 0 Logging Direction Down Optical log depth units Feet Data Reference Point Undefined Frame Spacing 60 .1IN Max frames per record Undefined Absent value -999 Depth Units 11 Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RHOB MWD050 G/CC 4 1 68 4 2 DRHO MWD050 G/CC 4 1 68 8 3 CALN MWD050 IN 4 1 68 12 4 PEF MWD050 B/E 4 1 68 16 5 GR MWD050 API 4 1 68 20 6 FET MWD050 HR 4 1 68 24 7 RPX MWD050 OHMM 4 1 68 28 8 RPS MWD050 OHMM 4 1 68 32 9 RPM MWD050 OHMM 4 1 68 36 10 RPD MWD050 OHMM 4 1 68 40 11 ROP MWD050 FPH 4 1 68 44 12 FCNT MWD050 CP30 4 1 68 48 13 NCNT MWD050 CP30 4 1 68 52 14 NPHI MWD050 PU 4 1 68 56 15 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6967.5 7450 7208.75 966 6967.5 7450 RHOB MWD050 G/CC 1.554 3.227 2. 47049 704 7030 7381.5 DRHO MWD050 G/CC -1.144 0.487 0.0777415 704 7030 7381.5 CALN MWD050 IN 5. 63 8.35 6.36371 650 7030 7381.5 PEF MWD050 B/E 2.87 15.83 5.53582 704 7030 7381.5 GR MWD050 API 34. 96 169.83 93.7669 855 6967.5 7394.5 FET MWD050 HR 0.36 119.95 5.52289 744 7030 7401.5 RPX MWD050 OHMM 1.42 1044.45 9.21262 744 7030 7401.5 RPS MWD050 OHMM 0.56 569.27 7.83585 744 7030 7401.5 RPM MWD050 OHMM 0. 61 2000 48.5249 744 7030 7401.5 RPD MWD050 OHMM 0.55 2000 44. 6586 744 7030 7401.5 ROP MWD050 FPH 1.74 274 .19 107.777 816 7042.5 7450 FCNT MWD050 CP30 104 . 64 2612. 67 427.762 674 7030 7366.5 NCNT MWD050 CP30 14499.5 51667. 6 24811. 9 674 7030 7366.5 NPHI MWD050 PU 8.23 63. 92 31.3245 674 7030 7366.5 First Reading For Entire File 6967.5 Last Reading For Entire File 7450 File Trailer Service name STSLIB.003 Service Sub Level Name Version Number 1 0 0 1 Date of Generation 12/08/07 Maximum Physical Record65535 File Type LO Next File Name STSLIB.004 Physical EOF Tape Trailer Service name LISTPE Date 12/08/07 Origin STS Tape Name UNK. 4N Continuation Number 01 Next Tape Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name LISTPE Date 12/08/07 Origin STS Reel Name UNKNOWN Continuation Number 01 Next Reel Name UNKNOWN Comments STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File FINAL WELL REPORT MUDLOGGING DATA 3N-07A Provided by: Approved by: Michael Werner Compiled by: John Lundy B r i t t e n A d a m s Distribution: 8/6/12 T.D. Date: 07/16/2012 3N-07A 1 TABLE OF CONTENTS 1 MUDLOGGING EQUIPMENT & CREW ................................................................................................ 2 1.1 Equipment Summary ...................................................................................................................... 2 1.2 Crew................................................................................................................................................ 2 2 WELL DETAILS ..................................................................................................................................... 3 2.1 Well Summary................................................................................................................................. 3 2.2 Hole Data ........................................................................................................................................ 3 2.3 Daily Activity Summary ................................................................................................................... 4 3 GEOLOGICAL DATA ............................................................................................................................. 9 3.1 Lithostratigraphy ............................................................................................................................. 9 3.2 Mudlog Summary .......................................................................................................................... 11 3.2.1 Window to HRZ ..................................................................................................................... 11 3.2.2 HRZ ....................................................................................................................................... 12 3.2.3 Kalubik ................................................................................................................................... 13 3.2.4 Kuparuk “D” Sand .................................................................................................................. 13 3.2.5 “B” Shale ................................................................................................................................ 15 3.2.6 Kuparuk “A” Sand .................................................................................................................. 15 3.2.7 Top Miluveach ....................................................................................................................... 17 3.3 Connection Gases ........................................................................................................................ 18 3.4 Trip and WiperTrip Gases ............................................................................................................. 18 3.5 Sampling Program / Sample Dispatch .......................................................................................... 18 3.6 Show Reports ................................................................................. Error! Bookmark not defined. 4 PRESSURE / FORMATION STRENGTH DATA ................................................................................. 19 4.1 Pore pressure evaluation .............................................................................................................. 19 4.2 Quantitative Methods .................................................................................................................... 19 5 DRILLING DATA .................................................................................................................................. 21 5.1 Survey Data .................................................................................................................................. 21 5.2 Bit Record ..................................................................................................................................... 23 5.3 Mud Record .................................................................................................................................. 23 6 DAILY REPORTS .................................................................................. 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Enclosures: 2”/100’ Formation Log (MD/TVD) 2”/100’ Drilling Dynamics Log (MD/TVD) 2”/100’ LWD / Lithology Log (MD/TVD) 2”/100’ Gamma/Slide Log (MD) 2”/100’ Gas Ratio Log (MD/TVD) Final Well Data on CD/ROM 3N-07A 2 1 MUDLOGGING EQUIPMENT & CREW 1.1 Equipment Summary Parameter Equipment Type / Position Total Downtime Comments Ditch gas QGM Agitator (Mounted in possum belly) Flame ionization total gas & chromatography. 0 Effective Circulating Density (ECD) From Sperry-Sun 5063’ to TD 0 Hook Load / Weight on bit Totco WITS Feed 2 hrs Totco data feed in and out during network interruptions Mud Flow In Derived from Strokes/Minute and Pump Output 2 hrs See above Mud Flow Out Totco WITS Feed 2 See above Mudlogging unit computer system HP Compaq Pentium 4 (X2, DML & Rigwatch) 0 Mudlogging unit DAC box In-unit data collection/distribution center 0 Pit Volumes, Pit Gain/Loss Totco WITS Feed 2 hrs See above Pump Pressure Totco WITS Feed 2 hrs See above Pump stroke counters Totco WITS Feed 2 hrs See above Totco Well Monitoring Components Totco computer networked in Mudlogging Unit 2 hrs See above Rate of penetration Totco WITS Feed 2 hrs See above RPM Totco WITS Feed 2 hrs See above Torque Totco WITS Feed 2 hrs See above 1.2 Crew Unit Type : Steel Arctic Unit Number : ML056 Mudloggers Years *1 Days *2 Sample Catcher Years Days John Lundy 20 9 Dickey Hudgins 5 9 Britten Adams 1 9 Steve Franzen 5 9 *1 Years experience as Mudlogger *2 Days at wellsite between spud and total depth of well 3N-07A 3 2 WELL DETAILS 2.1 Well Summary Well: 3N-07A API Index #: 50-029-21539-01-00 Field: Kuparuk River Field Surface Coordinates: 1561’ FSL, 304’ FEL, Sec. 29, T13N, R09E Borough: North Slope Primary Target Depth: 7272’ State: Alaska TD Depth: 7450’ Rig Name / Type: Doyon 141, Arctic Triple Suspension Date: Primary Target: Top of A License: Spud Date: 7 July 2012 Ground Elevation: 34’ MSL Completion Date: 17 July 2012 RT Elevation: 62’ MSL Completion Status: Run 4 ½ Liner. Secondary Target: Depth: None Classification: CTD Setup - Production TD Date: 16 July 2012 TD Formation: Miluveach Days Testing: None Days Drilling: 9 2.2 Hole Data Hole Section Maximum Depth TD Formation Mud Weigh t (ppg) Dev. (oinc) Coring Casing/ Liner Shoe Depth LOT (ppg ) MD (ft) TVDSS (ft) MD (ft) TVD (ft) 8 ¾”” 7042’ 6304’ Torok 10.5 45.0 No 7”-26lb 7040’ 6303.1’ 15.8 6 1/8” 7450 6589.79 Miluveach 11.2 44.38 No 4 ½" - - 15.8 Additional Comments The original 3N-07 well was drilled in 1986 as a producer. This rotary sidetrack (3N-07A) will relocate the wellbore approximately 2622’ to the northwest as a setup for future CTD laterals. The well will eventually be used to produce the A sand. After initial problems with de-completion, the whipstock was set and sidetrack was made by milling a window in the 9 5/8” casing from 2614 to 2638’ . Sidetrack was established at 2699’ MD. The well was spudded using an 8.75” tri-cone bit and continued to 3005’ MD/2995.6’ TVD where the BHA/bit was replaced with directional equipment and a PDC bit. Drilling continued with no major problems to a depth of 7042’ MD/6304.6’ TVD where 7”-26 lb/ft casing was set. TD was reached at 7450’ MD/6589.79’ TVD with a 6 1/8” PDC bit 3N-07A 4 2.3 Daily Activity Summary 6/21/12: PJSM-M/U washed pipe assembly at 347.85’ MD, RIH at 1983’ MD obtain milling parameters, P/U=77K; S/O=75K; calibrate gain equals 18.46 BBLS but is actually 17.68 BBL, wash from 1983’MD to 2023 ’MD ROT at 50 RPM and tag collars at 2029’ MD, milled over 7’ CSG from 2029’ MD to 2096’ MD at 7 BPM; 300 PSI; 70 RPM; TQ-2-10K; 2-10K WOB, pumped 4 super sweeps; two 10 BBLS and two 20 BBL with 75% increase in cuttings. 6/22/12: Continued to burn over CSG with 7 BPM; 400 PSI at 70 RPM; 3-7K TQ at 2191’ MD; pump sweep after last collar, CBU at 9 BPM; 250 PSI and back reamed stand to 2043’ MD, monitor well static, pull one stand and observe fluid drop in well, worked through tight spot at 1970’ MD with 15K to 50K over pull when string came free, worked until no drag was observed, line up to TT and continued to pull out hole from 1950’ MD to 1385” MD, incorrect fill (Started to Swabb), fill from trip=ACT 2.75 BBL; CALC 3.24 BBL, circulated S/S at 9 BPM; 175 PSI, monitor well static, rack back DC’s, pulled stand off wash pipe, P/U 1’ and observe fish in stand, safely install dog collar, fill from trip=ACT 17.1 BBL; CALC 16.71 BBL, P/U 6’ to install second dog collar, wait on W.A.C.H cutter, R/U W.A.C.H cutter, cut CSG, Lay down LWR fish, break down stand off wash pipe, continued lay down fish, R/U W.A.C.H cutter, cut CSG, lay down 87.88’ of 7” fish, clear and clean rig floor, R/D W.A.C.H cutter, M/U 7” wash pipe BHA to 375.52’ MD, run in hole with wash pipe to 2074’ MD; BBL gain actually 18.45 BBL; CAL gain 19.05 BBL, wash from 2074’ MD to 2113’ MD tag 7” stump ESTB ROT.ROT. over stump at 20 RPM; TQ=500 FT/LBS; wash from 2015’ MD to 2129’ MD; 4 BPM; 200 PSI wash and ream from 2129’ MD to 2136’ MD; 5 BPM; 200 PSI; 70 RPM; TQ=1=4K, MILL from 2136’ MD to 2165’ MD at 3 BPM-300 PSI; 4 BPM-325 PSI; TQ=2-8K, pump 12 BBL HI-VIS sweep at 08:30pm with 75% increase in cuttings on returns, pump 20 BBL sweep at 10:00pm. 6/23/12: Continue to MILL over CSG from 2165’ MD to 2239’ MD at 80 RPM with 3-6 BPM; 150-350 PSI; pump super sweeps after each collar, P/U WT 79K; S/O WT 77K; ROT WT 80k, continued MILL over CSG at 2239’ MD, couldn’t go pass 2239’ MD, P/U and rework collar section and looked at spike at 2236’ MD to 2237’ MD, unable to work pass 2237’ MD, decision made to pull out hole, monitor well static, POOH from 2237’ MD to 1700’ MD swabbing, circulated to surface, POOH from 1700’ MD to 1415’ MD still swabbing, decision made to pump out of hole; pump out of hole from 1415’ MD to 375’ MD, actual fill equal 21.24 BBL; CALC fill equal 18.1 BBL, lay down intensifier; rack back drill collars, lay down jars and bumpers (as per Baker Hughes rep), lay down wash pipe and 2 JTS 7” CSG (as per Baker Hughes rep), clean and clear rig floor, P/U tools for next run, PJSM on M/U spear, M/U BHA #9 spear (as per Baker Hughes rep), run in hole with spear from 214’ MD to 2195’ MD; ACT DISP=17.5 BBL; CALC DISP=17.49 BBL 6/24/12: M/U to T/D, P/U WT 75K, S/O WT 77K, break circulation at 5 BPM; 100 PSI, S/O enguage CSG stub at 2197’; set down with 5k, observed pressure from no circulation; shut down pump, P/U to 50K O/P and fire jars, P/U with 125K, S/O and release spear, rack back stand and lay down single, pull out of hole with spear asst from 2100’ MD to 214’ MD, monitor well at DC’s, rack back DC’s and lay down spear assy, total fill from trip equals ACT 18.6 BBL; CALC equals 17.49 BBL, M/U to T/D, P/U WT 64K; S/O WT 65K, S/O and stab into stump, break circulation at 3 BPM PSI, S/O and locate collar at 2240’ MD, P/U 1’ and make cut at 2239’ MD; 60 RPM; 4 BPM; 500 PSI; 1K TQ, maintain 500 PSI with rate up to 5.5 BPM, set down with 5K and held for 5 minutes, PJSM, pull out of hole with MSC assy from 2239’ MD, fill from trip equals actual 13.7 BBL and calculated 12.66 BBL, clean and clear floor, PJSM, P/U WT 75K; S/O WT 77K; break circulation at 5 BPM; 100 PSI. S/O engage fish at 2197’, set down with 15K; P/U with 76K (fish on) rack back stand and lay down single observe fluid drop in well, PJSM, pull out of hole with fish from 2100’ MD to 214’ MD, monitor well, rack back, lay down fish and spear assy, length of fish is 41.45’, total fill from trip equal actual 15 BBL and calculated 14.24 BBL, drain stack and pull wear bushing, P/U single, stack washer and flush stack, R/U and test BOPE; tested to 250 low and 300 high, tested top pipe rams choke valves 1,212,13,14 and kill line valve; upper IBOP, choke valve 9 and 11; lower IBOP; choke valve 5,8 and 10; dart valve; choke valve 4 and 7; floor valve and choke valve 2; HCR choke; 4” kill LIN DEMCO valve; manual choke valve; NCR kill, R?D test equipment vlow down line, install wear ring, PJSM on P/U and M/U bottom hole assembly, P/U Baker Hughes tools from beaver slide, M/U BHA #12 8.75” junk mill and 2 drill collars (as per Baker Hughes Rep), Run into hole with 8.75” junk mill from 211’ MD to 660’ MD, tagged up, P/U and M/U top drive break circulation at 5 3N-07A 5 BPM; 50 PSI, P/U and S/O WT equals 55K tag up and set 1K down, decision made to pull out of hole and P/U 8.5 “ junk mill, actual DISP equals 9.1 BBL; Calculated DISP equals 9.15 BBL, pull out of hole from 660’ MD to 211’ MD, rack back 2 stands drill collars, break and lay down 6.75” junk mill, M/U BHA #13 8.5” junk mill and 2 drill collars (as per Baker Hughes rep), run in hole with 8.5” junk mill from 210’ MD to 660’ MD, Tagged up set down 2K torque up, installed out; took 20K over pull to free up, decision to POOH from 660’ MD to 210’ MD, actual fill 9.1 BBL; calculated fill 9.15 BBL, rack back 2 stands drill collars, lay down bit sub and junk mill, clean and clear rig floor. 6/25/12: Wait on tools from Simops service T/D and Drawworks, PJSM M/D swedge and stab mill assy bottom hole assembly #14, run in hole to 591’ MD, M/U to T/d, P/U weight 52K, S.O weight 55K, continue to run in hole to 660’MD and hammer on tight spot with up to 20K, after several attempts pull up 5’; with ROT at 40 RPM, S/O and ream through tight spot with minimal TQ, recip through several times; no drag, continue run in hole to 2239’ MD; P/U weight 75K; S/O weight 77K, set down on CSG stub with 25K; DISP from trip equals actual 19 BBL and calculated 17.86 BBL, monitor well at DC’s, rack back DC’s and lay down swedge assy, clean and clear floor, PJSM M/U milling assy bottom hole assembly #15 and run in hole to 660’ MD; P/U weight 52K; S/O weight 55K, set down with 5’ S/O and set down with 15K; P/u 5’ and M/U to T/D, ROT at 40 RPM and 56K, attempt to drill mill with 3-7K TQ at 658’ MD, S/O down to 660’ MD; stall, P/Y 5’, break circulation at 5 BPM 50 PSI and attempt to ream through, no success, DISP from trip equal actual 10.4 BBL and calculated 9.15 BBL, pull out of hole from 660’ MD to 211’ MD, fill from trip equal actual 9.2 BBL and calculated 9.15 BBL, monitor well at DC’s static, rack back DC’s and lay down mill assy, clean and clear floor, pull up 8 3/4 upper water melon mill and mule shoe, PJSM M/u clean out assy bottom hole assembly #16 run in hole to 592’ MD, M’U to T/D and EST parameters, pull out weight 52K; S/O weight 52K; ROT weight 56K, S/O to 660’ MD and set sown with 5K, pull up 5’ and break circulation at 5 BPM 50 PSI;60 RPM; 1K TQ, ream through tight spot several times, 2-5K TQ, shut down pump and rotary, work through tight spot several times, no drag, run in hole from 660’ MD to 2239” MD; set down on casing stub with 5K; Pull up 3’, DISP from trip equal actual 18.7 BBL and calculated 19.34 BBL, CBU at 12 BPM 450 PSI, rack back stand and monitor well static, pull out of hole from 2197’ MD to 1725’ MD; pull up weight 70K; S/O weight 70K; fill from trip equal actual 3.4 BBL and calculated 2.7 BBL,PJSM pull out of hole from 1725’ MD to 215’ MD; actual fill equals 19.68 BBL and calculation 18.26 BBL, rack back 2 stands, lay down bottom hole assembly (as per Bakers Hughes rep), PJSM M/U #17 bottom hole assembly 8.75’ junk mill (as per Bakers Hughes rep), run in hole with 8.75” junk mill from 211’ MD to 2238’ MD; actual DISP equals 17.85 BBL and calculated DISP is 17.79 BBL, tag up at 2238’ MD, EST parameters P/U weight 77K; S/O weight 76K; ROT weight 78K; pump 6 BPM; 125 PSI, mill from 2238’ MD to 2241’ MD at 3 BPM; 50 PSI; ROT 80 RPM, TQ equals 1K, monitor well, pull out of hole from 2241’ MD to 211’ MD; actual fill 18.9 BBL and calculated fill is 17.79 BBL, rack backs 2 stands drill collars and lay down bottom hole assembly (as per Baker Hughes rep), clean and clear rig floor, PJSM on M/U pilot mill and run in hole, M/U pilot mill (as per Baker Hughes rep), run in hole with pilot mill from 201’ MD to 2241’ MD; actual DISP equal 17.5 BBL and calculated is 17.49 BBL. 6/26/12: EST parameter; pull up weight 75K; S/O weight 77K; ROT weight 76K, set down on casing stub with 5K, pull 5’; ROT at 50 RPM, 5K TQ; 5 BPM; 100 PSI. S/O and mill casing from 2239’ MD to 2308’ MD with 50 to 110 RPM, 5-7 BPM, 100 to 175 PSI, 1-4K TQ, pumped high vis sweep every 30’ at 7.5 BPM, 200 PSI at 2270’ MD and 300 PSI at 2300’ MDE, no metal in returns attempt to circulation out metal and 12 BPM 500 PSI while ROT RECIP string, still no metal in returns, shut down and observe metal shaving in BOPE stack and flow line packed off with metal shavings above flow line jet, discuss option, PJSM pump down kill line to attempt clean metal out of stack and flow line, stack cleaned up; but flow line 100% packed off; break apart flow line and clean out metal shaving, fill hole and inspect flow line from leak, pull out of hole at 8 BPM; 120 PSI; 80 RPM; TQ equals 0 from 2277’ MD to 672’ MD, held H2S drill all rig hands evacuated to safe briefing area and put on air pack and secure well, pull out of hole at 8 BPM; 100 PSI; 80 RPM TQ equals zero from 672’ MD to 201’ MD; total DISP from trip actual equals 21.7 BBL and calculated is 17.49 BBL, rack back two stands drill collars and lay down bottom hole assembly, cleans and clear rig floor, flush stacks 4 times function bag and ram to clear metal cuttings out to stack, PJSM on M/U bottom hole assembly and run in hole, M/U bottom hole assembly #19 (as per Baker Hughes per), run in hole from 201’ MD to 2277’ MD, try EST parameters but drill pipe plugged off; actual DISP equals 17.4 BBL and calculated is 18.03 BBL, pull out of hole from 2277’ MD to 2182’ MD, R/U to REV circulation, REV circulation trying to unplug drill pipe; unplugged after two attempts. Wash and ream from 2088’ MD to 2182’ MD; 7 BPM; 150 PSI; 80 RPM and zero TQ, continue to wash and ream from 2180’ MD to casing stub and tag at 2308’ MD with 7.5 BPM 200 PSI; 80 3N-07A 6 RPM; CBU while ROT and RECIP, pull up weight 76K; S/O weight 79K; ROT weight 78K, pump 29 BBL of high viscosity super sweep at 7.5 BPM, Mill 7’ casing with 80-110 RPM; 6 BPM 150 PSI; 1-4K TQ; from 2308’ MD to 2320’ MD, pump high viscosity super sweep at 8.5 BPM 400 PSI and 80 RPM, jet stack through IA, ROT and RECIP string, observed flow line packed off, disassembled and clean out, reassemble, fill hole and check for leaks, crack in flow line, service rig Simops weld crack in flow line, fill hole and check for leak (GOOD), bring pump rate up to 12 BPM 500 PSI and wash to BTM; with 120 RPM; had 10’ of fill, tag stub at 2320’ MD, work through tight spot at 2293’ MD several times, wash down stub and mill from 2320’ MD to 2321’ MD, mill packing off, P/U and work through tight spot again at 2293’ MD with 15 BPM 650 PSI several times, back ream out to 2225’ MD and wash to BTM (No Fill), continue to mill with same parameter from 2321’ MD to 2325’ MD. 6/27/12: PJSM hole packing off at 2293’ MD to 2297’ MD, work pipe several times through spots, no change, pump high viscosity weight sweep, small amount of cutting in returns, decision made to change fluid over to 10.2 PPG LSND mud, shut down and clean inspect flow line before fluid swap, PFSM on displacement, PREP pit from fluid displacement, displace 8.5 PPG brine over to 10.2 PPG LSND mud at 16 BPM; 425 PSI; 80 RPM and 0 TQ, mill from 2325’ MD to 2326’ MD at 10 BPM; 110 RPM; TQ equal 0-3K; weight on bit equals 10K, packing off, decision made to circulated cutting to surface, no cuttings at BU, decision made to pull out of hole, circulated and condition mud until mud weight is even in/out 10.2 PPG, monitor well static, pull out of hole at 6 BPM and 175 PSI from 2268’ MD to 201’ MD, calculated fill equals 19.6 BBL; actual fill equals 18.03 BBL, rack back two stands of 6.75” collars and lay down bottom hole assembly, stack full of wadded up metal, decision made to mix high viscosity sweep, clean and clear rig floor, Simops hook up mud pump to pump through well head with attempt to clean out metal from stack, pump high viscosity sweep at 8.5 BPM through well head, little to none returns, blow down line and drain stack, PJSM on tools and M/U rope stack, pull up Baker’s tool from beaver slide, M/U Baker’s rope spear (as per Baker’s Hughes rep), attempt to fish out metal cuttings from stack, only magnets had metal, decision made to pull up 5’ magnets and try fish out more metal. 6/28/12: PJSM M/U magnet assy and make multiple passes through stack, fill hole and circulated through IA at 9 BPM 800 PSI, continue RECIP magnets; drain stack, function rams halfway and continue to RECIP magnets until stack cleared, a proximally 400 LBS of shaving recovered, clean floor; pull up and lay down subs VIA beaver slide, flush stack with stack washer and magnets at 20 BPM 150 PSI, clean magnets and flush again at same rate until returns and magnets cleaned up, PJSM pull up junk mill magnet assy bottom hole assembly #22 and run in hole to 227’ MD; took 5-10K at 180’ MD; DISP from trip equals actual 5.7 BBL and calculated 7.41 BBL, wash and ream at 14 BPM 300PSI; 60 RPM from 227’ MD to 1734’ MD; DISP from trip equals actual 16.7 BBL and calculated 16.1 BBL, wash and ream from 1734’ MD to 2326’ MD at 14 BPM 300 PSI, set down 5K at 2326’ MD; drill off at reaming rate, CBU 3 times at 16 BPM; 735 PSI; 50 RPM; 0 TQ, cement and metal shaving in returns, lay down single and monitor well static, pull out hole on elevators from 2300’ MD to 227’ MD; actual fill 19.6 BBL and calculated fill is 19.29 BBL, rack back two stands drill collars; lay down BHA #22 (as per Bakers Hughes rep), clean and clear rig floor, flush stack twice, M/U bottom hole assembly #23 pilot mill (as per Baker Hughes rep), run in hole from 201’ MD to 2326’ MD, mill from 2326’ MD to 2345’ MD. 6/29/12: Continue milling from 2345’ MD to 2373’ MD at 10 BPM and 350 PSI. Sent high viscosity sweeps every 5’ at 17 BPM and 750 PSI. P/U and M/U single to allow room for reciprocation. Continue to milling from 2373’ MD to 2380’ MD with same parameters. PJSM mill from 2380’ MD to 2415’ MD at 10 BPM and 4000 PSI. Pumped 10 BBL sweeps every 5’. Brought pump rate up to 17.5 BPM, and work pipe until sweep comes back. 20% extra cutting came back with sweep. Shut down drain stack. Observe stack full of metal. Decision made to pump through well head annulus. 6/30/12 to 7/3/12; Canrig On standby. 7/4/12: Continue to reverse circulate at 10 BPM at 795 PSI. Circulate bottoms up 10 BPM at 975 PSI. Working on MP2’s; scrub and paint rig. Clean out boilers too. Run in with cement equipment from 2991’ MD to 3100’ MD with 1 BPM. They saw pressure increasing from 150 PSI to 190 PSI, therefore decision was made to come back out the hole. At 7 BPM and 400 PSI rig observe cement at bottoms up. Pull out of hole from 3100’ MD to 3086’ MD. Run back in to circulated and pump cement. Rig circulated and condition mud at 5 BPM and 375 PSI. Pressure test cement line to 2500 PSI and pumped 11 BBL. Test was good. Pull out the hole from 3N-07A 7 3086’ MD to 2235’ MD with calculated fill equal to 3.75 BBL and actual fill is 4.08 BBL. Reverse circulated at 10 BPM with 700 PSI. Waited on cement while, SIMOPS’s pull up 6 stands of 5” HWDP and 30 stands 5” drill pipe. Cleans valves and under shakers. 7/5/12: PJSM continue to pull up 5” drill pipe. Lay down thread protectors and pull up saver sub. C/O saver sub, bell guide, and grabber die on top drive. Put tools away. Run in hole from 2238’ MD and pumped at 1BPM/130 PSI. While running in hole saw a 30 PSI increase at 2366’ MD and saw 2K bobble. At bottom up saw hard cement at shakers, therefore slowed pumps back to 1 BPM and continue to run in hole. Tagged up at 2367’ MD and set down 4K and decision was made to pull out hole from 2367’ MD to 726’ MD. Tongues, elevators, and slip were lay down. Clean and velar rig floor. Run up to test 5” floor valves from 250-3000 PSI. Run down test equipment, floor valves and change elevators. PJSM, HRC, and HRW on M/U bottom hole assembly clean out run. M/U BHA #26 clean out run (as per Halliburton and Baker Hughes rep). Pulse test MWD at 375 GPM and 800 PSI (GOOD). Run in hole with drill pipe from 584’ MD to 2340’ MD. Wash and ream from 2340’ MD to 2367’ MD at 10 BPM and 1050 PSI. Tag cement at 2367’ MD. Drill cement from 2367’ MD to 2620’ MD at 10 BPM at and 1100 PSI. Ream stand and shot surveys for MWD from 2620’ MD to 2498’MD. R/U to test casing at 2615’ MD and attempt test to 1500 PSI. Pumped at 1 BPM to 725 PSI and pressure broke over. An injection rate at 1 BPM/ 700 PSI made decision to pull out of hole. Monitor well from 2620’ MD to 580’ MD. Lay down bottom hole assembly. Clean and clear rig floor. Scrub and paint rig while waiting on tools. Run in hole with retrievable packer to 1298’ MD. Pressure up below packer to 720 PSI and pressure broke over. Pressure and tested above packer to 1500 PSI and held on chart for 15 minutes. Continue to run in hole to 2608’ MD. Pressure up below packer to 1500 PSI and held 15 minutes. Test above packer and pressure up to 600 PSI and established and injection rate (1 BPM/ 680 PSI). P/U rack back a stand. 7/6/12: Set packer at 2501’ MD. Test IA to 1500 PSI and fluid circulation around packer (GOOD). R/U on drill pipe injection at 1 BPM/690 PSI. Test drill pipe injection, bleed pressure and packer performance injection (GOOD). Run down test equipment. Line up to trip tank. Pull out of hole from 2412’ MD to 745’MD. Rack back 6 stands collars and lay down BHA. Blow down top drive, kill line, and cement line. M/U cement retainer. Run in hole from 7’ MD to 2415’ MD. PJSM on servicing rig. Wait on order from town. Pull out of hole from 2415’ MD. Clean and clear rig floor. Run in hole to complete shallow hole test (GOOD) at 225’ MD. Continue to run in hole with whipstock. On stand 19 orientated to 16L and shut down pumps. Make a connection. Run in hole and tag up at 2621’ MD. Pull up off bottom and verify 16L by shut down pumps. Come back down to set anchor. Slowly slacked off and saw anchor shear at 18K; also shear bolt sheared. Pull up 5’ and saw no over pull verifying shear bolt was not attached. Start milling at 2599’ MD to 2606’ MD. Lubricate rig swivel packing. Continue to mill from 2606’ MD to 2611’ MD. C/O swivel packing. Run down top drive landing and test top drive for leaks (GOOD). 7/7/12: Run in hole from 2574’ MD tag up at 2611’ MD. Milled from 2611’ MD at 400 GPM/950 PSI. Work bottom hole assembly through window at milling rate X2. Shut down rotation work through window. Shut down pumps and work through window again. Pump sweet, circulated, and condition the mud at 400 GPM. Perform leak off test. Pull out of hole from 2567’ MD to 815’ MD. Monitor well, rack back 6 stands of 5” heavy weight. Lay down 2 stands of drill collars and BHA. Clean and clear rig floor. Flush stack X2 with stack washers. M/U BHA. P/U 1 stand of heavy weight and perform shallow plush test at 410 GPM/900 PSI (GOOD). Continue to run in hole with heavy weight drill pipe from 692’ MD to 2544’ MD. Kelly up wash down to 2590’ MD. Orientated to 15L and shut down pumps. Pump at 400 GPM and orientated to 15L. Slide through window at 2599’ MD and start reaming at 2606’ MD to 2638’ MD. Displace the well with new mud. Start time drilling from 2638’ MD to 2653’ MD. 7/13/12: Check equipment and continue to run in hole with 7”casing. Break circulation every 500’. Run in hole to 7004’ MD and wash to 7038’ MD with 2.5 BPM/600 PSI. Circulate bottom up with franks tool. Lay down Frank’s tools and move up cement head. Circulate and condition mud at 4.5 BPM/600 PSI. Pump 5 BBL, 100 CW, and put cement line to 4500 PSI. Pump first stage cement with 25 BBL. Launch wiper dart, pump 2 BBL, mud push, load top plug, and pump 42.5 BBL. Launch closing dart and chase with20 BBL H2O, swap over to rig and displace with 243 BBL. Pressure up 1000 PSI and hold from 5 minutes. Bleed off pressure and check floats (GOOD). Load plug from second stage cement job, pressure up and open cementer with 3300 PSI. 3N-07A 8 Circulate bottom up at 5 BPM/250 PSI. PJSM from second stage cement job, batch up, and continue circulating at 5 BPM/ 250 PSI. Pump second stage cement job with 20 BBL. Close estimated cementer with 1600 PSI and held 1500 PSI from 5 minutes (GOOD). Monitor well then run down cement head. Drain stack and vacate out casing stump. N/D bope stack and P/U with 50K. 7/14/12: R/U wachs casing cutter and cut casing and Simops lay down casing equipment. Dress off cut and lay down casing stubs. N/D drilling spool with Simops lying down spider and C/O bails. Set pack off which FMC rep prefers. N.U tubing spool, DBL studded adapter flange, and test 7” packoff. Nipple up the bottom of pipe equipment. Set wear bushing to 6.25 ID. PJSM shuffle 5” heavy weight drill pipe in derrick. C/O elevators and M/U TPC opening tool. Run in hole with TPC open top to 1997’ MD. R/U LRS and put lines to 2000 PSI. Observed fluid had dropped in hole due to seal relaxing and u-tube of IA to drill pipe. Shut in drill pipe and fill hole with water (Close annular). Reverse circulation freeze protect down through port up drill pipe with 54 BBL at 1.25 BPM/200 PSI. P/U on string and close port with 15K. Pressure up on drill pipe to 100 PSI to conform port closed (GOOD). Bleed off pressure, open kill, drill pipe, and annular. Release tool with ¼ turn to the right. P/U 2” shear check valve with 2200 PSI. Circulate and balance well to 10 PPG at 5 BPM 350 PSI. Lay down single and pump down to total depth. Monitor the well. Pull out the hole from 1985’ MD to lay down TCP tool. Clear and clean floor on rig floor. Drain stack, pull wear bushing, obtain RKB measurements and set test plug. C/O rams and saver sub. C/O upper 7” PR to 3.5” x 6” VBR. LWR 2 7/8” x 5” to rebuilt 2 7/8” x 5” VBR’s and rebuild rams. C/O saver sub and R/U test equipment. 7/15/12: PJSM-continue to C/O blind rams and install choke line. R/U test equipment flood stacks, choke, and kill line. Body test bottom of pipe equipment, ODS blind ram door leaking, tight therefore, tighten up bolts. Retest same door seals leaking, drain stacks, blow down lines, and remove choke line. Open blind ram door, C/O door seal, close door to install choke line, and fill lines and stack with water. R/U test equipment. Test BOPE and all rams and chokes valves to 250 PSI. Test high to 3500 PSI. Test annular to 2500 PSI. Record information on chart and test with 4”.3.5 & 4.5 test joints accumulators test equals 3000 PSI and later 1800 PSI. The end of the test was good and waive by Chuck Scheve. C/O test joint from 3.5” to 4.5”. Test lower 2 7/8”x 5” VBR. Upper 3.5x6” VBR to 250/3500 PSI and annular to 250/2500 PSI with 4.5” test joints for 5 minutes. Run down test equipment, blow down choke, and kill lines. Set wear bushing and clear floor. Continue to hang blocks. PJSM-slip and cut drilling line 277’ MD. Service T/D, draworks, iron roughneck, and skate. Pull up subs from bottom hole assembly. M/U BHA #31 to 113’ MD. Also upload MWD. Pull up NMDC.X/O, 10’ pup & M/U to T/D. Shallow pulse test MWD at 6 BPM/1150 PSI. Load nuclear sources and continue to run in hole with bottom hole assembly to 393’ MD. 7/16/12: PJSM-continue single in hole to 1983’ MD. Break circulation at 2 BPM/300 PSI. Rotate 25 RPM and rotate bit through TCP at 2018’ MD. Continue single in hole with 4” drill pipe to 3337’ MD. Circulate bottom up at 3337’ MD at 5 BPM/1125 PSI. Run up test equipment and test casing to 3500 PSI. Record on chart from10 minutes. Run down test equipment. Run in hole to 3350’ MD drilling out estimated cementer at 4 BPM/900 PSI. Continue to run in hole to 6850’ MD and tag cement. Break circulation at 6840’ MD at 50 SPM/200 GPM. Drill cements stringers to 6890’ MD. Circulate and condition mud at 200 GPM/50 SPM. R/U test equipment test casing to 3500 PSI and record on chart for 30 minutes. Run down test equipment. Wash and ream to 6914’ MD and drill baffle 200 GPM/1500 PSI. Obtain SPR’s at 6914’ MD. Wash down to 6957’ MD and drill out shoe track & 20’ of new hole from 7042’ MD to 7062’ MD. Displace well from 10 PPG to 11.1 PPG at 5 BPM/1750 PSI. Obtain SPR’s at 7062’ MD. Rack back stand, line up cement and kill lines. Flood same line and close upper VBR’s. Perform fit at 6985’ MD. Open VBR’s and blow down line. Wash down to 7050’ M at 200 GPM/1750 PSI. Drilling from 7062’ MD to 7150’ MD. Drilling from 7150’ MD to 7450’ MD. 7/17/12: Continue circulate x3 at 300 GPM/3250 PSI. Monitor well and pull out of hole onelevators to shoe. Monitor well again and run in hole to 7450’ MD. Circulate x3 at 300 GPM. 1200 units of gas on bottom up. Pump pull out of hole from 7365’ MD to 6988’ MD. Monitor well and slight flow after 20 minutes. Circulate back 3N-07A 9 up at 300 GPM/3150 PSI. Monitor well and slight flow. Decision made to run in hole and weight up to 11.6 PPG. Run in hole to 7450’ MD and circulated ay 7450’ MD (300 GPM). Monitor well and pull 1 stand to dry. Observe fluid to drop in stack. Pull out of hole 5 stands on elevators to 6893’ MD. Monitor well and drop 2 3/8’ rabbit on wire at stand 65. Pull out of hole on elevators to 5286’ MD. Pull out of hole to 5286’ MD to 660’ MD. Monitor well for 30 minutes. Lay down heavy weight from 660’ MD to 236’ MD. PJSM- lay down 2 NMDC’s and unload nuclear sources. Down load MWD. Lay down bottom hole assembly. Clean and clear rig floor. Run down 4.5’ casing handling equipment. Tight tolerance on centralizer on 2 stands. Wait on order from town. Decision made to C/O bow-spring centralizers, POOH, remove single centralizer and restock to 5.875” straight blade style centralizer. 3 GEOLOGICAL DATA 3.1 Lithostratigraphy LWD tops refer to provisional picks by the town geologist. FORMATION PROGNOSED LWD PICK MD (ft) TVDSS (ft) MD (ft) TVDSS (ft) UGNU B 2748 2745.9 UGNU A 2850 2845.78 NA 2940 2932.95 NB 2978 2969.48 NC 3020 3010.09 WEST SAK D 3135 3120.5 WEST SAK C 3182 3165.03 WEST SAC B 3218 3198.62 WEST SAK A4 3262 3239.05 WEST SAK A3 3312 3248.84 WEST SAK A2 3384 3347.32 WEST SAK A1 3522 3467.16 WEST SAK BASE 3645 3570.87 C-60 6084 5614.89 C-30 6263 5844.29 C-20 6621 6008.14 BASE HRZ 6774 6018 6748 6098.14 Top Upper Kalubik 6774 6018 6748 6098.14 K-1 Marker 6932 6130 6680 6191.23 3N-07A 10 Top Lower Kalubik 6932 6130 6680 6191.23 TD for Intermediate CSG 7100 6310 7042 6304.6 KUPARUK RIVER 7125 6328 7061 6317.89 Top Kuparuk D 7125 6328 7061 6317.89 Top Kuparuk C 7207 6386 7158 6385.56 Top B Shale 7230 6402 7180 6400.87 Top A5 7272 6432 7220 6428.7 Top A3 7281 6438 7238 6441.23 Top A1 7350 6487 7299 6483.66 Top Miluveach 7428 6542 7373 6535.64 TD 7494 6589 7450 6589.79 3N-07A 11 3.2 Mudlog Summary 3.2.1 Window to HRZ 2614’ to 6494' MD (263.55' to 5918.9' TVD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 709 0.8 123 928 1 49 This interval includes siltstone, claystone, sand, and sandstone/sandstone conglomerate, until approximately 6000’, when carbonaceous shale is encountered similar to the underlying HRZ. Carbonaceous material and carbonates were also encountered in this zone. Sand/conglomeratic sand in the upper portion was dominantly medium to medium light brownish gray; disaggregated loose sand with occasional small slightly indurated fragments; medium lower to fine upper, medium upper and coarse lower grains; primarily translucent white and smoky to clear quartz; very abundant light gray and brown lithics; trace dark gray to black mafic mineral grains and occasion-al mica flakes; slightly frosted; few spots of free oil; light golden brown to orange visual fluorescence; bright white to milky cut fluorescence; white streamer under cut fluorescence; slight oil odor in sample. Claystone was predominantly medium gray to medium dark gray with slight olive brown color; slight silty to sandy; low to moderate density; malleable to sectile; hydrophilic; soft to easily friable; irregular blocky to structure-less cuttings habit with occasion nodular cuttings; earthy fracture; dull to earthy with mineral sparkling luster; amorphous to colloidal with occasional matte and silty texture; massive to slightly soft sediment deformation; slight oil odor; dominant orange to golden brown with small traces of yellow to slight lime green pale visual fluorescence; milky white cut fluorescence with few white streamers. Siltstone/claystone encountered in the lower zone was light olive medium gray brown to very light gray when dry, medium grey to medium dark gray when wet; traces of clear quartz and black traces of mafic minerals; soft to easily friable; dominant bit pulverized to malleable with occasion flaky to crumbly fragments; nodular to tabular cuttings habit; locally tuffaceous; dull when dry to spark- ling when wet luster; matte to gritty occasionally amorphous clumpy to pasty consistency; thin to lenticular bedding structure; calcarious mineral with strong HCl reaction in sample; scattered spots of yellowish visual fluorescence; slight milky yellow fluorescence cut; no streamers in sample; no oil odor; Shale/siltstone above the HRZ was typically medium to medium dark brownish gray ; slightly firm to firm; waxy; thinly fissile; silty; abundant brown plant remains and dark gray carbonaceous staining on bedding; interbedded with very thin to moderate beds of primarily very fine grain sand; non adhesive when crushed; low density material separates to surface in sample preparation; interbedded with similar siltstone and occasional thin beds of light to medium greenish gray tuffaceous siltstone; tuffaceous material is slightly to abundantly micro-laminated with black carbonaceous remains; non to trace calcareous. Sand/sandstone in the lower part of the section was typically dis-aggregated loose sand and scattered very fine grain sandstone; well sorted; fine lower to very fine upper grain; scattered larger grains; sub-angular to angular; predominantly translucent white to clear quartz/ volcanics; common to abundant medium and light gray lithics; trace to common dark gray and black mineral/lithics; trace orange chert becoming scattered as depth increases; scattered pale blue and green mineral grains; scattered brown grains; trace very fine lower grain ashy sandstone flakes; occasional thin (1mm =/-) hard waxy white ash stringers; interbedded with firm fissile brownish gray silty shale and siltstone; slight odor at the shakers; very slight odor in samples fades with time; slight dull yellow fluorescence overall, disappears with time; slight clear yellow cut fluorescence; very slight trace brown residue cuts to clear yellow; trace calcareous. Thin sandstone conglomerate and conglomerate interbeds were occasionally seen throughout the section. 3N-07A 12 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 2685 149 41982 2711 256 56313 2769 928.981 191304 2854 94.609 19482.4 3168 277.252 62639.6 186.772 68.036 44.023 19.01 24.013 3217 221.611 163.997 130.842 90.712 221.611 163.997 29 3260 532.696 79597.9 345.962 459.296 336.526 333.114 319.074 17.045 3306 257.687 37313.6 187.004 283.687 241.399 238.021 122.261 13.95 3398 379.774 73610.6 346.042 427.021 369.223 385.422 39.852 74.012 3492 288.47 55048.4 227.387 285.502 424.069 457.227 242.157 11.316 3601 219.6 21175.9 81.65 144.482 211.402 239.205 121.885 15.609 3668 316.8 85224.2 289.654 167.501 290.611 321.715 68.651 30.198 4049 64.591 12269.1 75.885 9.699 30.994 40.002 64.211 132.408 4146 99.826 19376.9 131.597 14.8 29.6 37 61.667 61.667 4775 95.009 18461.6 286.428 95.845 15.553 24.85 4955 99.339 17312.8 303.852 113.759 28.432 69.801 15.62 4.418 5105 106.8 20056.6 343.014 126.437 12.554 61.593 5170 93.18 chromo lost 6210 59.039 11201.3 488.984 188.543 22.39 9.669 6260 142.591 23865.9 1199.97 576.444 133.646 226.16 6358 329.217 51352.4 2228.56 964.197 206.031 416.024 6409 592.904 97165.2 3712.48 1177.35 170.29 343.256 91.996 115.117 3.2.2 HRZ 6494’ to 6774' MD (5918.2' to 6098.14' TVD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 634 2 110 600 64 236 The HRZ includes carbonaceous shales and some interbedded sands and minor ash fall tuff. The shale is typical HRZ, variably silty claystone with slight to moderate bookleaf partings of carbon matter or carbon residue, traces of pyrite normally seen in the HRZ were not observed. Some thin laminations of sandstone, siltstone, and ash, also with carbon partings, and some interbedded sandstone is also noted. Sand/sandstone consisted of dis-aggregated loose sand and scattered very fine grain sandstone; well sorted; fine lower to very fine upper grain; scattered larger grains; sub-angular to angular; predominantly translucent white to clear quartz/ volcanics; common to abundant medium and light gray lithics; trace to common dark gray and black mineral/lithics; trace orange chert becoming scattered as depth increases; scattered pale blue and green mineral grains; scattered brown grains; trace very fine lower grain ashy sandstone flakes; occasional thin (1mm =/-) hard waxy white ash stringers; interbedded with firm fissile brownish gray silty shale and siltstone. Slight raw petroleum odor in samples fades with time; slight dull yellow fluorescence overall, disappears with time; slight clear yellow cut fluorescence; very slight trace brown residue cuts to clear yellow; trace calcareous.. Shale/siltstone seen in this interval was medium to medium dark brownish gray ; slightly firm to firm; waxy; thinly fissile; silty; common brown plant remains and dark gray carbonaceous staining on bedding; interbedded with very thin to moderate beds of primarily very fine grain sand; non adhesive when crushed; low density material separates to surface in sample preparation; interbedded with similar siltstone and occasional thin 3N-07A 13 beds of light to medium greenish gray tuffaceous siltstone; tuffaceous material is slightly to abundantly micro- laminated with black carbonaceous remains; non to trace calcareous. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 521.583 83619.59 4123.741 1506.797 220.895 483.478 135.909 148.481 521.583 600.365 762227.7 17552.49 10086.21 2192.095 5090.648 1995.977 2684.402 600.365 3.2.3 Kalubik 6748 to 7061’ MD (6098.14’ to 6317.89’ TVD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 292 3 1000.2 628 1 135 This is primarily a shale section with dark grayish brown to dark brownish gray to brown shales, and carbonaceous shales grading to mudstone. Overall slightly to locally moderately calcareous Occasional interlaminated siltstone and sandstone, thin sandstone interbeds and traces of calcite fracture fill were noted. Shale/siltstone was typically medium to medium dark brownish gray ; slightly firm to firm; waxy; thinly fissile; silty; common brown plant remains and dark gray carbonaceous staining on bedding; interbedded with very thin to moderate beds of primarily very fine grain sand; non adhesive when crushed; low density material separates to top sample preparation; interbedded with similar siltstone and occasional thin beds of light to medium gray tuffaceous siltstone and ash/tuff; tuffaceous material is slightly to abundantly micro-laminated with black carbonaceous remains; non to trace calcareous. Carbonaceous shale was dark gray to grayish brown with a mix of dark yellowish brown color; mod to high density; crunchy to tough with occasional brittle tenacity; mod hard to hard with occasion very hard induration; platy to irregular wedge-like with bladed cutting habits; hackly to sub-hackly fracture; dull with sub-resinous luster; micro-crystalline to gritty and abrasive texture; banded to massive with slight laminae bedding structures; no free oil; no oil odor in sample; scattered yellowish mineral fluorescence; pale white fluorescence cut; slight HCl reaction due to calcareous cementation. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 6818 144 19654 1812 900 135 273 101 126 6911 145 22316 1583 595 81 167 73 70 7004 545 81916 5156 1549 182 336 83 135 3.2.4 Kuparuk “D” Sand 7061’ to 7158' MD (6317.89' to 6385.56' TVD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 210 2 77.4 190 2 22.2 The Kuparuk “D” sands are interbedded with sands, siltstone, carbonaceous shale, and shale. Shale and sand were abundant in this section. Shale had a black to greenish color with moderate to fine cutting due to bit pulverizing. Siltstone color was light gray to medium gray and it bit pulverized which graded it down to mudstone. Quartz was dominant in sands with pyrite and mica as accessories minerals. 3N-07A 14 Siltstone was light grayish to medium gray with occasional light olive gray to medium dark gray color; crumbly due to bit pulverizing with occasional brittle to crunchy tenacity; easily friable to friable induration; platy to wedge-like with bladed edges cutting habits; earthy to sub-hackly fractures; waxy to sparkling when wet luster; microcrystalline to silty and gritty texture; thick to lenticular bedding structure; slight brown to straw visual cut in sample; no free oil; no oil odor by shakers; slight oil odor in sample; bright milky white to slight yellowish fluorescence cut; few yellowish mineral in visual fluorescent; test done in bulky crushed sample; no other oil indictors. Carbonaceous shale was dark gray to grayish brown with a mix of dark yellowish brown color; mod to high density; crunchy to tough with occasional brittle tenacity; mod hard to hard with occasion very hard induration; platy to irregular wedge-like with bladed cutting habits; hackly to sub-hackly fracture; dull with sub-resinous luster; micro-crystalline to gritty and abrasive texture; banded to massive with slight laminae bedding structures; no free oil; no oil odor in sample; scattered yellowish mineral fluorescence; pale white fluorescence cut; slight HCl reaction due to calcareous cementation. Sand was clear to translucent with slight grayish orange to pale yellowish orange color; upper fine to lower medium sand size; moderate to poorly sorting; surrounded to rounded grains; 90% quartz with occasional pyrite; and micas; grains are disaggregated; no free oil; no odor by shakers; slight oil odor in sample; few yellowish mineral in visual fluorescence; slight brown to straw color in visual cut; milky white to slight yellowish fluorescent cut with no streamer; no other oil indictors. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 7132 190.800 23452.9 1350.08 861.712 212.339 498.716 181.734 214.576 3.2.5 Kuparuk “C” 7158’ to 7180' MD (6385.56' to 6400.87' TVD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 423 21 145.2 84 15 58 Kuparuk “C” was decreasing in sand as depth increases. The light gray to medium gray siltstone increased to 40%. The shale stays at 40%-45%. Quartz was the dominant mineral in sands. Shale and siltstone still bit pulverized. Gas units have risen in this depth. Siltstone was light grayish to medium gray with occasional light olive gray to medium dark gray color; crumbly due to bit pulverizing with occasional brittle to crunchy tenacity; easily friable to friable induration; platy to wedge-like with bladed edges cutting habits; earthy to sub-hackly fractures; waxy to sparkling when wet luster; microcrystalline to silty and gritty texture; thick to lenticular bedding structure; slight brown to straw visual cut in sample; no free oil; no oil odor by shakers; slight oil odor in sample; bright milky white to slight yellowish fluorescence cut; few yellowish mineral in visual fluorescent; test done in bulky crushed sample; no other oil indictors. Carbonaceous shale was dark gray to grayish brown with a mix of dark yellowish brown color; mod to high density; crunchy to tough with occasional brittle tenacity; mod hard to hard with occasion very hard induration; platy to irregular wedge-like with bladed cutting habits; hackly to sub-hackly fracture; dull with sub-resinous luster; micro-crystalline to gritty and abrasive texture; banded to massive with slight laminae bedding structures; no free oil; no oil odor in sample; scattered yellowish mineral fluorescence; pale white fluorescence cut; slight HCl reaction due to calcareous cementation. 3N-07A 15 Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 7178 84.36 10581.53 612.872 367.980 83.962 197.418 63.874 69.119 3.2.5 “B” Shale 7180’ to 7220' MD (6400.87' to 6428.7' TVD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 181 18 94.8 1193 50 212.3 The “B” consists of carbonaceous shale, siltstone, sand, and shale. Siltstone is dominant in this section with light gray to medium gray color. Siltstone and shale fragments are fine due to pulverizing. Sand is still decreasing as depth increases. In oil testing, a pale to straw color is occurring in visual cuts. Siltstone light grayish to medium gray with occasional light olive gray to medium dark gray color; crumbly due to bit pulverizing with occasional brittle to crunchy tenacity; easily friable to friable induration; platy to wedge- like with bladed edges cutting habits; earthy to sub-hackly fractures; waxy to sparkling when wet luster; microcrystalline to silty and gritty texture; thick to lenticular bedding structure; slight brown to straw visual cut in sample; no free oil; no oil odor by shakers; slight oil odor in sample; bright milky white to slight yellowish fluorescence cut; few yellowish mineral in visual fluorescent; test done in bulky crushed sample; no other oil indictors. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 7208 1194 151591.77 8812.04 5093.65 1101.52 2592.09 759.998 753.228 3.2.6 Kuparuk A Sand A5 7220’ to 7238' MD (6428.7' to 6441.23' TVD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 128 78 103.8 65 11 23.4 A5 is a thin section with 10% carbonaceous shale, 30% shale, 10% sand, and 50% siltstone. The siltstone is beginning to change color from light/medium gray to slight dusky reddish brown. Shale is transitioning from friable to firm friable. Sand is still quartz dominant but accessory minerals are decreasing in samples. Siltstone was light grayish to medium gray with occasional light olive gray to medium dark gray color; crumbly due to bit pulverizing with occasional brittle to crunchy tenacity; easily friable to friable induration; platy to wedge-like with bladed edges cutting habits; earthy to sub-hackly fractures; waxy to sparkling when wet luster; microcrystalline to silty and gritty texture; thick to lenticular bedding structure; slight brown to straw visual cut in sample; no free oil; no oil odor by shakers; slight oil odor in sample; bright milky white to slight yellowish fluorescence cut; few yellowish mineral in visual fluorescent; test done in bulky crushed sample; no other oil indictors. 3N-07A 16 Carbonaceous shale was dark gray to grayish brown with a mix of dark yellowish brown color; mod to high density; crunchy to tough with occasional brittle tenacity; mod hard to hard with occasion very hard induration; platy to irregular wedge-like with bladed cutting habits; hackly to sub-hackly fracture; dull with sub-resinous luster; micro-crystalline to gritty and abrasive texture; banded to massive with slight laminae bedding structures; no free oil; no oil odor in sample; scattered yellowish mineral fluorescence; pale white fluorescence cut; slight HCl reaction due to calcareous cementation Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N None noted A3 7238’ to 7299' MD (6441.23' to 6483.66' TVD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 210 16 121 266 34 122.1 In A3 is siltstone dominant with carbonaceous shale, shale, and sand. Carbonaceous shale disappears at 7345’ MD. Shale is increasing in hardiness. Sand is at 10% and accessories mineral are decreasing in depth. Quartz is still dominant in sample. Sand was clear to translucent with slight grayish orange to pale yellowish orange color; upper fine to lower medium sand size; moderate to poorly sorting; surrounded to rounded grains; 90% quartz with occasional pyrite; and micas; grains are disaggregated; no free oil; no odor by shakers; slight oil odor in sample; few yellowish mineral in visual fluorescence; slight brown to straw color in visual cut; milky white to slight yellowish fluorescent cut with no streamer; no other oil indictors Shale black to grayish black with slight dusky yellowish brown and grayish brown color; moderate density; crunchy to brittle with occasional tough tenacity; firm friable to moderated hard induration; wedge-like to bladed cutting habits; hackly to sub-hackly fracture; resinous to waxy with sparkling when wet luster; abrasive to slight gritty texture; thin to planar bedding structure; no free oil in sample; slight oil odor in sample; no oil odor near shakers; bright milky white fluorescent cut; pale brown to straw visual cut; no other oil indictors. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 7269 464 60449.712 3539.803 1887.33 357.391 842.873 177.790 108.915 7272 281 36666.772 2147.877 1140.61 214.404 505.717 104.202 60.502 A1 7299’ to 77373 MD (6483.66' to 6535.64' TVD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 213 3 121.1 1193 24 177.4 3N-07A 17 A1 is a siltstone abundant section with 10%-20% sand and 20% shale section. The hardiness of shale and siltstone increased and cutting are not bit pulverized into mud. Both shale and siltstone color are changing to slight brownish red colors. Gas unit has increased in the section too. Shale black to grayish black with slight dusky yellowish brown and grayish brown color; moderate density; crunchy to brittle with occasional tough tenacity; firm friable to moderated hard induration; wedge-like to bladed cutting habits; hackly to sub-hackly fracture; resinous to waxy with sparkling when wet luster; abrasive to slight gritty texture; thin to planar bedding structure; no free oil in sample; slight oil odor in sample; no oil odor near shakers; bright milky white fluorescent cut; pale brown to straw visual cut; no other oil indictors. Siltstone very dusky red to dark reddish brown color; crunchy to brittle tenacity; friable to firm friable induration; tabular to platy cutting habits; sub-hackly fracture; resinous to mineral sparkling luster; abrasive to silty texture; massive bedding structure; straw to pale brown visual cut; bright milky to yellowish fluorescent cut; no free oil in sample. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 7307 561 101287.41 6192.527 2850.98 451.442 1042.96 298.197 293.104 7324 1194 293764.11 17921.43 8494.73 1480.53 3337.27 814.926 907.305 7342 234 57275.007 3435.612 1755.24 349.811 776.442 128.218 141.737 3.2.7 Top Miluveach 7373’ to 7450' MD (6535.64' to 6585.79' TVD) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 204 20 121.3 547 31 97.1 Miluveach is 70% dominant by reddish dusky brown siltstone with crunchy tenacity. Shale and sand complete to 30% left. Both shale and siltstone became tougher in tenacity and cutting habits have feature of wedge-like to tabular. The sand is 90% quartz with brownish translucent colors. The gas unit stayed above 50 unit in this section. Shale black to grayish black with slight dusky yellowish brown and grayish brown color; moderate density; crunchy to brittle with occasional tough tenacity; firm friable to moderated hard induration; wedge-like to bladed cutting habits; hackly to sub-hackly fracture; resinous to waxy with sparkling when wet luster; abrasive to slight gritty texture; thin to planar bedding structure; no free oil in sample; slight oil odor in sample; no oil odor near shakers; bright milky white fluorescent cut; pale brown to straw visual cut; no other oil indictors. Siltstone very dusky red to dark reddish brown color; crunchy to brittle tenacity; friable to firm friable induration; tabular to platy cutting habits; sub-hackly fracture; resinous to mineral sparkling luster; abrasive to silty texture; massive bedding structure; straw to pale brown visual cut; bright milky to yellowish fluorescent cut; no free oil in sample. Peaks Depth TG C1 C2 C3 C4I C4N C5I C5N 7441 547 78722.37 5926.47 4367.13 1057.08 2677.53 486.848 216.047 3N-07A 18 3.3 Connection Gases There were no verifiable connection gases in this well 3.4 Trip and WiperTrip Gases 1unit = 0.05% Methane Equivalent Depth (feet) Trip to (feet) Gas (units) T 3005 SURFACE 117 WT 7042 2500 298 T 7042 SURFACE 604 WT 7450 7042 1200 T 7450 0 TO 4877 RIH 2320 T 7450 0 (Off Bottom) 3020 3.5 Sampling Program / Sample Dispatch Samples were collected for logging purposes only. No reference sets were kept. Frequency was locally altered according to drill rate constraints and zones of interest, but was at least every 20’. 3N - 0 7 A 19 4 P R E S S U R E / F O R M A T I O N S T R E N G T H D A T A Th e w e l l w a s d r i l l e d s l i g h t l y o v e r b a l a n c e d a s w a s i n d i c a t ed b y n o c o n n e c t i o n g a s s e s a n d l o w t r i p a n d w i p e r g a s s e s . 4. 1 P o r e p r e s s u r e e v a l u a t i o n Fo r m a t i o n In t e r v a l Pr i m a r y Li t h o l o g y (% ) Se c o n d a r y Li t h o l o g y (% ) In t e r v a l T o p s E s t . P o r e P r e s s u r e ( M W ) Tr e n d In d i c a t o r s MD (f t ) TV D (f t ) Mi n (p p g ) Ma x (p p g ) Tr e n d Ki c k o f f P o i n t S d 7 0 % Cl y s t 3 0 % 25 9 9 2 5 9 8 . 5 9 . 5 9 . 7 U p BG , C G , T G , WG HR Z S l t s t 5 5 % Sd / C g s d 4 0 % , Sh 5 % P6 4 5 0 5 8 9 6 . 9 4 9 . 7 9 . 7 E v e n BG , C G , T G , WG Ka l u b i k S h 4 0 % Ts l t s t 2 0 % , Sl t s t 3 0 % 10 % S d 67 4 8 6 0 9 8 . 1 4 9 . 7 9 . 9 D o w n B G , C G Ku p a r u k C S d / S s t 3 0 % Sl t s t 3 0 % , Ts l t s t 1 0 % , Sh 3 0 % 70 6 1 6 3 1 7 . 8 9 9 . 7 9 . 8 D o w n B G , C G , T G B S h a l e S l t s t T s l t s t 5 5 % Sd 1 5 % , S h 30 % 71 8 0 6 4 0 0 . 8 7 9 . 7 9 . 9 U p B G , C G , T G A S a n d S l t s t 5 0 % Sd 1 5 % , S h 35 % 72 2 0 6 4 2 8 . 7 0 9 . 7 9 . 9 U p B G , C G , T G Mi l u v e a c h S l t s t 8 0 % Sh 1 5 % , Sd 5 % 73 7 3 6 5 3 5 . 6 4 9 . 7 9 . 9 U p B G , C G , T G NO T E : D u r i n g c i r c u l a t i o n a t T D w h i l e o n b o t t o m w i t h 4 ½ ” l i n e r , mu d w e i g h t w a s i n c r e a s e d t o 1 1 . 2 p p g t o s u p p r e s s g a s p r i o r t o c e menting. NO T E : C l y s t = C l a y s t o n e / C l a y , S d = S a n d , C g s d = C o n g l o m e r a t i c s an d , S l t s t = S i l t s t o n e , S h = S h a l e , S s t = S a n d s t o n e , A s h = A s h F all Tuff, CSltst = C a r b o n a c e o u s S i l t s t o n e 4. 2 Q u a n t i t a t i v e M e t h o d s Th e p r i m a r y i n d i c a t o r s u s e d f o r P P G e v a l u a t i o n w e r e g a s t r e n d s re l a t i v e t o m u d w e i g h t ( M W ) a n d e f f e c t i v e c i r c u l a t i n g d e n s i t y ( E CD), including increases in b a c k g r o u n d g a s ( B G ) , a p p e a r a n c e a n d t r e n d s o f c o n n e c t i o n g a s ( C G ) , an d m a g n i t u d e s o f t r i p g a s ( T G ) a n d w i p e r g a s ( W G ) . R e g i onal pore pressure 3N - 0 7 A 20 tr e n d s f r o m s o n i c d a t a , p r o v i d e d b y C o n o c o P h i l l i p s , a n d s u r f a c e ma n i f e s t a t i o n s o f h o l e c o n d i t i o n s w e r e a l s o c o n s i d e r e d . As a r e f e r e n c e , P P G i s c a l c u l a t e d i n i t i a l l y w i t h a f o r m u l a p r ov i d e d b y C a n r i g D r i l l i n g T e c h n o l o g y L T D , a n d t h e n m o d i f i e d u s i n g the indicators described ab o v e , D X C a n d r e s i s t i v i t y ( R E S ) d a t a . T h e f o r m u l a u s es D X , E C D , a n d B G a s m e a s u r e d b y t o t a l d i t c h g a s : PP G = E C D – ( 0 . 6 - ( ( . 0 0 1 * T L G S U ) + ( 0 . 0 5 * D X ) ) ) Th e f o r m u l a h a s c e r t a i n l i m i t a t i o n s , s u c h t h a t i t d o e s n o t a l l o w f o r a P P G m o r e t h a n 1 p p g l e s s t h a n t h e E C D , a n d T L G S U m u s t b e differentiated from sh o w g a s a n d g a s c a r r i e d f r o m o v e r p r e s s u r e z o n e s , a n d i s d e p e n d e n t on r e l i a b l e D X d a t a . H o w e v e r , t h e f o r m u l a p r o v e d u s e f u l i n helping formulate a PP G r a n g e , w h e n e s t i m a t i n g t r e n d s , a s w i t h D X C d a t a , w i t h d a t a p o i n t s i n s h a l e i n t e r v a l s . 3N-07A 21 5 DRILLING DATA 5.1 Survey Data Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (ft) Dogleg Rate (o/100ft) 2,599.00 6.13 0.5 2,598.50 30.7 -18.9 32.72 0 2,640.50 8.93 353.96 2,639.64 36.12 -19.22 38.14 7.05 2,696.80 10.66 347.76 2,695.12 45.56 -20.78 47.69 3.59 2,786.40 11.39 337.9 2,783.07 61.85 -25.87 64.47 2.25 2,823.10 12.01 343.25 2,819.01 68.87 -28.33 71.73 3.4 2,880.80 13.29 345.47 2,875.31 81.04 -31.73 84.22 2.37 2,974.00 15.34 345.98 2,965.61 103.37 -37.4 107.06 2.2 3,014.20 16.08 347.3 3,004.31 113.96 -39.91 117.87 2.04 3,107.87 17.54 350.19 3,093.97 140.52 -45.17 144.87 1.8 3,200.95 20.09 353.93 3,182.08 170.25 -49.25 174.87 3.03 3,293.22 24.17 356.97 3,267.53 204.89 -51.93 209.58 4.59 3,344.75 27.03 359.82 3,314.00 227.13 -52.52 231.75 6.04 3,382.74 29.16 0.69 3,347.51 245.02 -52.44 249.5 5.71 3,434.96 31.11 1.3 3,392.67 271.23 -51.98 275.47 3.78 3,478.97 32.23 1.43 3,430.13 294.33 -51.43 298.35 2.55 3,571.54 32.34 0.78 3,508.39 343.77 -50.48 347.32 0.39 3,661.06 31.48 0.31 3,584.38 391.08 -50.02 394.26 1 3,746.76 32.33 0.84 3,657.13 436.38 -49.57 439.18 1.04 3,844.21 33.82 2.48 3,738.79 489.53 -48.01 491.77 1.78 3,942.01 33.54 2.33 3,820.18 543.72 -45.73 545.31 0.3 4,035.80 33.38 2.7 3,898.42 595.38 -43.47 596.35 0.28 4,126.22 33.67 3.01 3,973.80 645.25 -40.98 645.58 0.37 4,218.58 34.35 3.48 4,050.36 696.83 -38.05 696.45 0.79 4,312.81 33.77 2.66 4,128.43 749.53 -35.22 748.45 0.79 4,403.92 32.95 1.35 4,204.52 799.6 -33.46 797.95 1.2 4,498.05 32.77 359.11 4,283.60 850.66 -33.26 848.64 1.31 4,589.67 32.35 359.35 4,360.82 899.96 -33.92 897.68 0.48 4,682.49 32.23 358.98 4,439.28 949.54 -34.64 946.99 0.25 4,773.66 32.4 358.23 4,516.33 998.27 -35.83 995.51 0.48 4,867.36 32.53 358.79 4,595.39 1,048.55 -37.14 1,045.60 0.35 4,960.66 33.94 358.54 4,673.43 1,099.67 -38.33 1,096.50 1.52 5,052.12 33.22 358.61 4,749.62 1,150.24 -39.59 1,146.87 0.79 5,144.98 33.09 358.24 4,827.36 1,201.00 -40.98 1,197.44 0.26 5,237.49 32.56 357.22 4,905.10 1,251.11 -42.97 1,247.43 0.83 5,330.31 32.48 357.5 4,983.37 1,300.96 -45.26 1,297.20 0.18 5,422.16 32.24 357.35 5,060.95 1,350.07 -47.47 1,346.23 0.28 5,516.23 31.39 356.82 5,140.89 1,399.59 -49.99 1,395.71 0.95 3N-07A 22 Measured Depth (ft) Incl. (o) Azim. (o) True Vertical Depth (ft) Latitude (ft) N(+), S(-) Departure (ft) E(+), W(-) Vertical Section (ft) Dogleg Rate (o/100ft) 5,608.45 32.1 357.12 5,219.31 1,448.05 -52.56 1,444.12 0.79 5,701.49 31.34 356.65 5,298.46 1,496.89 -55.21 1,492.94 0.86 5,794.19 31.68 355.8 5,377.49 1,545.23 -58.4 1,541.32 0.6 5,886.07 33.83 354.56 5,454.75 1,594.76 -62.6 1,591.00 2.45 5,978.78 36.19 352.06 5,530.69 1,647.57 -68.82 1,644.18 2.98 6,072.76 38.08 350.06 5,605.61 1,703.61 -77.66 1,700.86 2.39 6,164.42 40.11 348.02 5,676.75 1,760.34 -88.67 1,758.50 2.62 6,256.78 41.45 346.41 5,746.68 1,819.16 -102.03 1,818.49 1.84 6,349.89 44.39 345.5 5,814.86 1,880.66 -117.43 1,881.37 3.23 6,441.90 44.49 345.53 5,880.55 1,943.03 -133.54 1,945.21 0.11 6,534.76 44.84 344.14 5,946.60 2,006.03 -150.62 2,009.79 1.12 6,627.77 45.14 343.46 6,012.38 2,069.18 -168.97 2,074.66 0.61 6,720.89 44.58 344.18 6,078.39 2,132.26 -187.27 2,139.46 0.81 6,813.05 44.64 344.43 6,144.00 2,194.57 -204.78 2,203.40 0.2 6,907.01 45.67 345.55 6,210.26 2,258.91 -222.03 2,269.33 1.38 7,086.46 45.94 347.38 6,335.36 2,383.99 -252.13 2,397.09 0.75 7,138.53 45.71 347.88 6,371.64 2,420.47 -260.13 2,434.25 0.82 7,233.69 46.29 346.63 6,437.75 2,487.23 -275.24 2,502.33 1.12 7,327.80 45.67 346.24 6,503.14 2,553.02 -291.11 2,569.53 0.72 7,415.77 44.38 346.13 6,565.32 2,613.45 -305.97 2,631.29 1.47 P 7450.00 44.38 346.13 6,589.79 2,636.98 -310.24 2,655.17 0 3N - 0 7 A 23 5. 2 B i t R e c o r d Bi t S i z e M a k e T y p e / S # J e t s / T F A De p t h I n MD / To t a l Fo o t a g e Bi t Hr s Av g . RO P (f t / h r ) WO B (K l b s ) RP M W e a r B H A 1 8 . 5 ” B a k e r 1 1 7 0 5 8 4 8 Wi n d o w Mi l l / 50 1 4 4 8 2 8 . 5 1 . 6 8 7 8 . 3 3 7 8 . 3 3 ¼ o u t 1 2 8 . 5 ” H D B S F X 5 5 + / 1 1 7 8 5 5 2 8 5 x 1 3 5 0 6 2 2 2 1 1 3 9 . 7 8 2 . 0 1 9 . 4 4 1 . 7 1 - 6 - B T - S - X - I - E R - T D 2 3 6 . 1 2 5 H D B S FX 5 5 5 Z P D C 11 1 2 2 7 5 4 3x 1 3 7 0 4 2 4 0 8 5 . 5 4 7 3 . 6 5 8 . 2 7 4 . 2 LIKE NEW, GRADE NOT RECORDED 29 5. 3 M u d R e c o r d Co n t r a c t o r : M I S W A C O Da t e D e p t h MW (p p g ) EC D (p p g ) VI S (s / q t ) PV Y P G e l s FL (c c ) FC So l s (% ) O/ W Ra t i o Sd (% ) pH Cl (ml/l) Ca (ml/l) 6/ 2 7 / 1 2 2 3 2 3 ’ 1 1 . 1 N R 5 0 7 2 6 9 / 1 0 / 1 2 N C 2 1 0 0 / 9 0 0 1 0 . 5 1 8 0 0 2 2 0 6/ 2 8 / 1 2 2 3 7 8 ’ 1 1 . 1 N R 5 8 9 3 7 1 9 / 2 1 / 2 3 N C 2 1 0 0 / 9 0 0 9 . 5 4 0 0 0 5 2 0 7/ 4 / 1 2 2 6 2 1 ’ 9 . 5 N R 5 3 7 3 7 1 3 / 1 5 / 1 8 N C 1 9 0 / 9 1 0 9 . 5 1 1 6 0 0 4 0 0 7/ 5 / 1 2 2 6 2 1 ’ 9 . 5 N R 4 4 8 2 4 5 / 6 / 8 N C 1 9 0 / 9 1 T R 1 1 . 2 1 7 0 0 4 8 0 7/ 6 / 1 2 2 6 2 1 ’ 9 . 5 N R 4 4 1 0 2 4 6 / 7 / 8 N C 1 9 0 / 9 1 T R 1 0 . 2 1 6 0 0 2 2 0 7/ 7 1 2 2 7 9 0 ’ 9 . 7 N R 4 5 1 0 2 2 8 / 9 / 1 1 7 1 5 2 / 9 3 T R 1 0 . 0 5 0 0 4 0 7/ 8 / 1 2 3 2 9 6 ’ 9 . 7 N R 5 6 1 6 2 6 1 0 / 1 4 / 1 5 6 . 4 1 6 2 / 9 2 T R 9 . 9 4 5 0 4 0 7/ 9 / 1 2 5 0 6 5 ’ 9 . 7 N R 5 3 1 4 2 5 1 0 / 1 1 / 1 2 5 . 4 1 9 2 / 8 9 T R 8 . 9 5 0 0 4 0 7/ 1 0 / 1 2 6 1 3 0 ’ 9 . 7 N R 5 1 1 4 2 6 1 0 / 1 2 / 1 3 4 . 4 1 9 3 / 8 8 0 . 2 5 9 . 5 4 5 0 4 0 7/ 1 1 / 1 2 7 0 4 2 ’ 9 . 7 N R 4 6 1 0 2 8 1 0 / 2 4 / 3 0 3 . 4 N C 1 1 3 / 8 6 0 . 2 5 9 . 6 7 0 0 8 0 7/ 1 2 / 1 2 7 0 4 2 ’ 9 . 7 N R 5 1 1 5 3 0 1 0 / 2 5 / 2 9 3 . 6 1 1 3 . 5 3 / 8 4 0 . 2 5 9 . 7 7 0 0 8 0 7/ 1 3 / 1 2 7 0 4 2 ’ 9 . 7 N R 4 3 1 1 2 0 5 / 1 0 / 0 N R 1 N R N R N C N R N R N R 7/ 1 4 / 1 2 7 0 4 2 9 . 7 N R 6 0 2 0 2 6 1 0 / 2 9 / 4 0 3 . 8 1 1 3 . 5 3 / 8 4 N R 9 . 7 7 0 0 8 0 7/ 1 5 / 1 2 7 0 4 2 9 . 7 N R 4 5 8 1 5 4 / 8 / 1 0 4 1 8 . 6 N R N R 8 . 6 6 0 0 N R 7/ 1 6 / 1 2 7 3 7 2 9 . 7 N R 5 3 1 5 3 2 9 / 1 5 / 3 3 N R 1 1 0 N R N R 8 . 6 6 0 0 N R 7/ 1 7 / 1 2 7 4 5 0 9 . 7 N R 5 9 1 7 3 0 9 / 1 3 / 2 9 N R 1 1 6 N R N R 9 . 6 5 5 0 8 0 7/ 1 7 / 1 2 7 4 5 0 1 1 . 2 N R 5 3 1 5 3 2 9 / 1 5 / 3 3 4 1 1 4 . 5 3 / 8 3 N R 9 . 5 5 5 0 8 0 Ab b r e v i a t i o n s MW = M u d W e i g h t G e l s = G e l S t r e n g t h S d = S an d c o n t e n t E C D = E f f e c t iv e C i r c u l a t i n g D e n s i t y WL = W a t e r o r F i l t r a t e L o s s C l = C h l o r i d e s V I S = F u n n e l V i s c o s i t y F C = F i l t e r C a k e Ca = H a r d n e s s C a l c i u m P V = P l a s t i c V i s c o s i t y S o l s = S o l i d s O / W = O i l t o W a t e r r a t i o YP = Y i e l d P o i n t N R = N o t R e p o r t e d 3N - 0 7 A 24 6 D A I L Y R E P O R T S 25 ConocoPhillips Alaska Inc. 3N07A Daily Report Report for: Larry Hill Michael Werner` Date: 6/21/12 Time: 12:00am Current Depth (MD): 2096 Current Depth (TVD): Current Operations: Decomplete 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: FV: PV: YP: FL: Gels: Sol: pH: Cl -: Ca ++: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: PJSM-M/U washed pipe assembly at 347.85’ MD, RIH at 1983’ MD obtain milling parameters, P/U=77K; S/O=75K; calibrate gain equals 18.46 BBLS but is actually 17.68 BBL, wash from 1983’MD to 2023 ’MD ROT at 50 RPM and tag collars at 2029’ MD, milled over 7’ CSG from 2029’ MD to 2096’ MD at 7 BPM; 300 PSI; 70 RPM; TQ-2-10K; 2-10K WOB, pumped 4 super sweeps; two 10 BBLS and two 20 BBL with 75% increase in cuttings. Calibrations: None; Rig up Canrig unit 56 Failures: None Daily Cost: 4650.00 CPAI DAILY WELLSITE REPORT 3N-07A REPORT FOR Larry Hill DATE , 6-21-12 DEPTH 2096 PRESENT OPERATION Decomplete TIME 12:00am YESTERDAY N/A 24 HOUR FOOTAGE N/A CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0.0 @ 0 @ 0.0 FT/HR SURFACE TORQUE 0 @ 0 @ 0.0 AMPS WEIGHT ON BIT 0 @ 0 @ 0.0 KLBS ROTARY RPM 0 @ 0 @ 0.0 RPM PUMP PRESSURE 0 @ 0 @ 0.0 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 0 @ 0 @ 0.0 TRIP GAS CUTTING GAS 0 @ 0 @ 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 0 @ 0 @ 0.0 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 0 @ 0.0 AVG PROPANE (C-3) 0 @ 0 @ 0.0 CURRENT BUTANE (C-4) 0 @ 0 @ 0.0 CURRENT BACKGROUND/AVG PENTANE (C-5) 0 @ 0 @ 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY PJSM-M/U washed pipe assembly at 347.85’ MD, RIH at 1983’ MD obtain milling CANRIG PERSONNEL ON BOARD Britten Adams, John Lundy DAILY COST $4650.00 REPORT BY Britten Adams ConocoPhillips Alaska Inc. 3N07A Daily Report Report for: Larry Hill Michael Werner Date: 6/22/12 Time: 12:00am Current Depth (MD): 2239’ Current Depth (TVD): Current Operations: Decomplete 24 hr Footage (MD): 143’ Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: FV: PV: YP: FL: Gels: Sol: pH: Cl -: Ca ++: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Continued to burn over CSG with 7 BPM; 400 PSI at 70 RPM; 3-7K TQ at 2191’ MD; pump sweep after last collar, CBU at 9 BPM; 250 PSI and back reamed stand to 2043’ MD, monitor well static, pull one stand and observe fluid drop in well, worked through tight spot at 1970’ MD with 15K to 50K over pull when string came free, worked until no drag was observed, line up to TT and continued to pull out hole from 1950’ MD to 1385” MD, incorrect fill (Started to Swabb), fill from trip=ACT 2.75 BBL; CALC 3.24 BBL, circulated S/S at 9 BPM; 175 PSI, monitor well static, rack back DC’s, pulled stand off wash pipe, P/U 1’ and observe fish in stand, safely install dog collar, fill from trip=ACT 17.1 BBL; CALC 16.71 BBL, P/U 6’ to install second dog collar, wait on W.A.C.H cutter, R/U W.A.C.H cutter, cut CSG, Lay down LWR fish, break down stand off wash pipe, continued lay down fish, R/U W.A.C.H cutter, cut CSG, lay down 87.88’ of 7” fish, clear and clean rig floor, R/D W.A.C.H cutter, M/U 7” wash pipe BHA to 375.52’ MD, run in hole with wash pipe to 2074’ MD; BBL gain actually 18.45 BBL; CAL gain 19.05 BBL, wash from 2074’ MD to 2113’ MD tag 7” stump ESTB ROT.ROT. over stump at 20 RPM; TQ=500 FT/LBS; wash from 2015’ MD to 2129’ MD; 4 BPM; 200 PSI wash and ream from 2129’ MD to 2136’ MD; 5 BPM; 200 PSI; 70 RPM; TQ=1=4K, MILL from 2136’ MD to 2165’ MD at 3 BPM-300 PSI; 4 BPM-325 PSI; TQ=2-8K, pump 12 BBL HI-VIS sweep at 08:30pm with 75% increase in cuttings on returns, pump 20 BBL sweep at 10:00pm. Calibrations: Chromatograph, THA. Failures: None Daily Cost: 2150.00 CPAI DAILY WELLSITE REPORT 3N-07A REPORT FOR Larry Hill DATE , 6-22-12 DEPTH 2239 PRESENT OPERATION Decomplete TIME 12:00am YESTERDAY 2096 24 HOUR FOOTAGE 143 CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0.0 @ 0 @ 0.0 FT/HR SURFACE TORQUE 0 @ 0 @ 0.0 AMPS WEIGHT ON BIT 0 @ 0 @ 0.0 KLBS ROTARY RPM 0 @ 0 @ 0.0 RPM PUMP PRESSURE 0 @ 0 @ 0.0 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 0 @ 0 @ 0.0 TRIP GAS CUTTING GAS 0 @ 0 @ 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 0 @ 0 @ 0.0 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 0 @ 0.0 AVG PROPANE (C-3) 0 @ 0 @ 0.0 CURRENT BUTANE (C-4) 0 @ 0 @ 0.0 CURRENT BACKGROUND/AVG PENTANE (C-5) 0 @ 0 @ 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continued to burn over CSG with 7 BPM; 400 PSI at 70 RPM; 3-7K TQ at 2191’ CANRIG PERSONNEL ON BOARD Britten Adams, John Lundy DAILY COST $2150.00 REPORT BY Britten Adams ConocoPhillips Alaska Inc. 3N07A Daily Report Report for: Larry Hill Michael Werner Date: 6/23/12 Time: 12:00am Current Depth (MD): 2239’ Current Depth (TVD): Current Operations: RIH W/ spear from 214’ MD to 2195’ MD 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: FV: PV: YP: FL: Gels: Sol: pH: Cl -: Ca ++: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Continue to MILL over CSG from 2165’ MD to 2239’ MD at 80 RPM with 3-6 BPM; 150-350 PSI; pump super sweeps after each collar, P/U WT 79K; S/O WT 77K; ROT WT 80k, continued MILL over CSG at 2239’ MD, couldn’t go pass 2239’ MD, P/U and rework collar section and looked at spike at 2236’ MD to 2237’ MD, unable to work pass 2237’ MD, decision made to pull out hole, monitor well static, POOH from 2237’ MD to 1700’ MD swabbing, circulated to surface, POOH from 1700’ MD to 1415’ MD still swabbing, decision made to pump out of hole; pump out of hole from 1415’ MD to 375’ MD, actual fill equal 21.24 BBL; CALC fill equal 18.1 BBL, lay down intensifier; rack back drill collars, lay down jars and bumpers (as per Baker Hughes rep), lay down wash pipe and 2 JTS 7” CSG (as per Baker Hughes rep), clean and clear rig floor, P/U tools for next run, PJSM on M/U spear, M/U BHA #9 spear (as per Baker Hughes rep), run in hole with spear from 214’ MD to 2195’ MD; ACT DISP=17.5 BBL; CALC DISP=17.49 BBL Calibrations: Chromatograph, THA. Failures: None Daily Cost: 2150.00 CPAI DAILY WELLSITE REPORT 3N-07A REPORT FOR Larry Hill DATE 6-23-12 DEPTH 2239 PRESENT OPERATION RIH W/ spear from 214’ TIME 12:00am YESTERDAY 2239 24 HOUR FOOTAGE 0 CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0.0 @ 0 @ 0.0 FT/HR SURFACE TORQUE 0 @ 0 @ 0.0 AMPS WEIGHT ON BIT 0 @ 0 @ 0.0 KLBS ROTARY RPM 0 @ 0 @ 0.0 RPM PUMP PRESSURE 0 @ 0 @ 0.0 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 0 @ 0 @ 0.0 TRIP GAS CUTTING GAS 0 @ 0 @ 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 0 @ 0 @ 0.0 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 0 @ 0.0 AVG PROPANE (C-3) 0 @ 0 @ 0.0 CURRENT BUTANE (C-4) 0 @ 0 @ 0.0 CURRENT BACKGROUND/AVG PENTANE (C-5) 0 @ 0 @ 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continue to MILL over CSG from 2165’ MD to 2239’ MD at 80 RPM with 3-6 BPM; CANRIG PERSONNEL ON BOARD Britten Adams, John Lundy DAILY COST $2150.00 REPORT BY Britten Adams ConocoPhillips Alaska Inc. 3N07A Daily Report Report for: Larry Hill Michael Werner Date: 6/24/12 Time: 12:00am Current Depth (MD): 2239’ Current Depth (TVD): Current Operations: Clean and clear rig floor. 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: FV: PV: YP: FL: Gels: Sol: pH: Cl -: Ca ++: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: M/U to T/D, P/U WT 75K, S/O WT 77K, break circulation at 5 BPM; 100 PSI, S/O enguage CSG stub at 2197’; set down with 5k, observed pressure from no circulation; shut down pump, P/U to 50K O/P and fire jars, P/U with 125K, S/O and release spear, rack back stand and lay down single, pull out of hole with spear asst from 2100’ MD to 214’ MD, monitor well at DC’s, rack back DC’s and lay down spear assy, total fill from trip equals ACT 18.6 BBL; CALC equals 17.49 BBL, M/U to T/D, P/U WT 64K; S/O WT 65K, S/O and stab into stump, break circulation at 3 BPM PSI, S/O and locate collar at 2240’ MD, P/U 1’ and make cut at 2239’ MD; 60 RPM; 4 BPM; 500 PSI; 1K TQ, maintain 500 PSI with rate up to 5.5 BPM, set down with 5K and held for 5 minutes, PJSM, pull out of hole with MSC assy from 2239’ MD, fill from trip equals actual 13.7 BBL and calculated 12.66 BBL, clean and clear floor, PJSM, P/U WT 75K; S/O WT 77K; break circulation at 5 BPM; 100 PSI. S/O enguage fish at 2197’, set down with 15K; P/U with 76K (fish on) rack back stand and lay down single observe fluid drop in well, PJSM, pull out of hole with fish from 2100’ MD to 214’ MD, monitor well, rack back, lay down fish and spear assy, length of fish is 41.45’, total fill from trip equal actual 15 BBL and calculated 14.24 BBL, drain stack and pull wear bushing, P/U single, stack washer and flush stack, R/U and test BOPE; tested to 250 low and 300 high, tested top pipe rams choke valves 1,212,13,14 and kill line valve; upper IBOP, choke valve 9 and 11; lower IBOP; choke valve 5,8 and 10; dart valve; choke valve 4 and 7; floor valve and choke valve 2; HCR choke; 4” kill LIN DEMCO valve; manual choke valve; NCR kill, R?D test equipment vlow down line, install wear ring, PJSM on P/U and M/U bottom hole assembly, P/U Baker Hughes tools from beaver slide, M/U BHA #12 8.75” junk mill and 2 drill collars (as per Baker Hughes Rep), Run into hole with 8.75” junk mill from 211’ MD to 660’ MD, tagged up, P/U and M/U top drive break circulation at 5 BPM; 50 PSI, P/U and S/O WT equals 55K tag up and set 1K down, decision made to pull out of hole and P/U 8.5 “ junk mill, actual DISP equals 9.1 BBL; Calculated DISP equals 9.15 BBL, pull out of hole from 660’ MD to 211’ MD, rack back 2 stands drill collars, break and lay down 6.75” junk mill, M/U BHA #13 8.5” junk mill and 2 drill collars (as per Baker Hughes rep), run in hole with 8.5” junk mill from 210’ MD to 660’ MD, Tagged up set down 2K torque up, installed out; took 20K over pull to free up, decision to POOH from 660’ MD to 210’ MD, actual fill 9.1 BBL; calculated fill 9.15 BBL, rack back 2 stands drill collars, lay down bit sub and junk mill, clean and clear rig floor. Calibrations: Chromatograph, THA. QGM Online Failures: None Daily Cost: 2235.00 CPAI DAILY WELLSITE REPORT 3N-07A REPORT FOR Larry Hill DATE 6-24-12 DEPTH 2239 PRESENT OPERATION Clean and clear rig floor. TIME 12:00am YESTERDAY 2239 24 HOUR FOOTAGE 0 CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0.0 @ 0 @ 0.0 FT/HR SURFACE TORQUE 0 @ 0 @ 0.0 AMPS WEIGHT ON BIT 0 @ 0 @ 0.0 KLBS ROTARY RPM 0 @ 0 @ 0.0 RPM PUMP PRESSURE 0 @ 0 @ 0.0 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 0 @ 0 @ 0.0 TRIP GAS CUTTING GAS 0 @ 0 @ 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 0 @ 0 @ 0.0 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 0 @ 0.0 AVG PROPANE (C-3) 0 @ 0 @ 0.0 CURRENT BUTANE (C-4) 0 @ 0 @ 0.0 CURRENT BACKGROUND/AVG PENTANE (C-5) 0 @ 0 @ 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Circulated the hole and tried to mill casing. CANRIG PERSONNEL ON BOARD Britten Adams, John Lundy DAILY COST $2235.00 REPORT BY Britten Adams ConocoPhillips Alaska Inc. 3N07A Daily Report Report for: Larry Hill Michael Werner Date: 6/25/12 Time: 12:00am Current Depth (MD): 2308’ Current Depth (TVD): Current Operations: RIH with pilot mill from 201’ MD to 2241’ MD. 24 hr Footage (MD): 69 Drilling Parameters ROP: Current: 0 Max: 15.2 Torque: Current: 0 Max: 3602 WOB: Current 2.7 Max: 13.2 RPM: Current: 0 Max: 125 PP: Current: 13 Max: 15 Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: 8.5 FV: PV: YP: FL: Gels: Sol: pH: Cl -: Ca ++: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Wait on tools from Simops service T/D and Draworks, PJSM M/D swedge and stab mill assy bottom hole assembly #14, run in hole to 591’ MD, M/U to T/d, P/U weight 52K, S.O weight 55K, continue to run in hole to 660’MD and hammer on tight spot with up to 20K, after several attempts pull up 5’; with ROT at 40 RPM, S/O and ream through tight spot with minimal TQ, recip through several times; no drag, continue run in hole to 2239’ MD; P/U weight 75K; S/O weight 77K, set down on CSG stub with 25K; DISP from trip equals actual 19 BBL and calculated 17.86 BBL, monitor well at DC’s, rack back DC’s and lay down swedge assy, clean and clear floor, PJSM M/U milling assy bottom hole assembly #15 and run in hole to 660’ MD; P/U weight 52K; S/O weight 55K, set down with 5’ S/O and set down with 15K; P/u 5’ and M/U to T/D, ROT at 40 RPM and 56K, attempt to drill mill with 3-7K TQ at 658’ MD, S/O down to 660’ MD; stall, P/Y 5’, break circulation at 5 BPM 50 PSI and attempt to ream through, no success, DISP from trip equal actual 10.4 BBL and calculated 9.15 BBL, pull out of hole from 660’ MD to 211’ MD, fill from trip equal actual 9.2 BBL and calculated 9.15 BBL, monitor well at DC’s static, rack back DC’s and lay down mill assy, clean and clear floor, pull up 8 3/4 upper water melon mill and mule shoe, PJSM M/u clean out assy bottom hole assembly #16 run in hole to 592’ MD, M’U to T/D and EST parameters, pull out weight 52K; S/O weight 52K; ROT weight 56K, S/O to 660’ MD and set sown with 5K, pull up 5’ and break circulation at 5 BPM 50 PSI;60 RPM; 1K TQ, ream through tight spot several times, 2-5K TQ, shut down pump and rotary, work through tight spot several times, no drag, run in hole from 660’ MD to 2239” MD; set down on casing stub with 5K; Pull up 3’, DISP from trip equal actual 18.7 BBL and calculated 19.34 BBL, CBU at 12 BPM 450 PSI, rack back stand and monitor well static, pull out of hole from 2197’ MD to 1725’ MD; pull up weight 70K; S/O weight 70K; fill from trip equal actual 3.4 BBL and calculated 2.7 BBL,PJSM pull out of hole from 1725’ MD to 215’ MD; actual fill equals 19.68 BBL and calculation 18.26 BBL, rack back 2 stands, lay down bottom hole assembly (as per Bakers Hughes rep), PJSM M/U #17 bottom hole assembly 8.75’ junk mill (as per Bakers Hughes rep), run in hole with 8.75” junk mill from 211’ MD to 2238’ MD; actual DISP equals 17.85 BBL and calculated DISP is 17.79 BBL, tag up at 2238’ MD, EST perameters P/U weight 77K; S/O weight 76K; ROT weight 78K; pump 6 BPM; 125 PSI, mill from 2238’ MD to 2241’ MD at 3 BPM; 50 PSI; ROT 80 RPM, TQ equals 1K, monitor well, pull out of hole from 2241’ MD to 211’ MD; actual fill 18.9 BBL and calculated fill is 17.79 BBL, rack backs 2 stands drill collars and lay down bottom hole assembly (as per Baker Hughes rep), clean and clear rig floor, PJSM on M/U pilot mill and run in hole, M/U pilot mill (as per Baker Hughes rep), run in hole with pilot mill from 201’ MD to 2241’ MD; actual DISP equal 17.5 BBL and calculated is 17.49 BBL Calibrations: Chromatograph, THA. QGM Online Failures: None Daily Cost: 2235.00 CPAI DAILY WELLSITE REPORT 3N-07A REPORT FOR Larry Hill DATE 6-25-12 DEPTH 2308 PRESENT OPERATION RIH with pilot mill. TIME 12:00am YESTERDAY 2239 24 HOUR FOOTAGE 69 CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0.0 @ 0 @ 0.0 FT/HR SURFACE TORQUE 0 @ 0 @ 0.0 AMPS WEIGHT ON BIT 0 @ 0 @ 0.0 KLBS ROTARY RPM 0 @ 0 @ 0.0 RPM PUMP PRESSURE 0 @ 0 @ 0.0 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 0 @ 0 @ 0.0 TRIP GAS CUTTING GAS 0 @ 0 @ 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 0 @ 0 @ 0.0 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 0 @ 0.0 AVG PROPANE (C-3) 0 @ 0 @ 0.0 CURRENT BUTANE (C-4) 0 @ 0 @ 0.0 CURRENT BACKGROUND/AVG PENTANE (C-5) 0 @ 0 @ 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continue to mill casing. CANRIG PERSONNEL ON BOARD Britten Adams, John Lundy DAILY COST $2235.00 REPORT BY Britten Adams ConocoPhillips Alaska Inc. 3N07A Daily Report Report for: Larry Hill Michael Werner Date: 6/26/12 Time: 12:00am Current Depth (MD): 2323’ Current Depth (TVD): Current Operations: Milling with parameters. 24 hr Footage (MD): 15’ Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: 1573 Max: 2191 WOB: Current 8.7 Max: 9.7 RPM: Current: 109 Max: 115 PP: Current: 390 Max: 994 Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: 8.5 FV: 70 PV: YP: FL: Gels: Sol: pH: 10.7 Cl -: Ca ++: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: 6/26/12 : EST parameter; pull up weight 75K; S/O weight 77K; ROT weight 76K, set down on casing stub with 5K, pull 5’; ROT at 50 RPM, 5K TQ; 5 BPM; 100 PSI. S/O and mill casing from 2239’ MD to 2308’ MD with 50 to 110 RPM, 5-7 BPM, 100 to 175 PSI, 1-4K TQ, pumped high vis sweep every 30’ at 7.5 BPM, 200 PSI at 2270’ MD and 300 PSI at 2300’ MDE, no metal in returns attempt to circulation out metal and 12 BPM 500 PSI while ROT RECIP string, still no metal in returns, shut down and observe metal shaving in BOPE stack and flow line packed off with metal shavings above flow line jet, discuss option, PJSM pump down kill line to attempt clean metal out of stack and flow line, stack cleaned up; but flow line 100% packed off; break apart flow line and clean out metal shaving, fill hole and inspect flow line from leak, pull out of hole at 8 BPM; 120 PSI; 80 RPM; TQ equals 0 from 2277’ MD to 672’ MD, held H2S drill all rig hands evacuated to safe briefing area and put on air pack and secure well, pull out of hole at 8 BPM; 100 PSI; 80 RPM TQ equals zero from 672’ MD to 201’ MD; total DISP from trip actual equals 21.7 BBL and calculated is 17.49 BBL, rack back two stands drill collars and lay down bottom hole assembly, cleans and clear rig floor, flush stacks 4 times function bag and ram to clear metal cuttings out to stack, PJSM on M/U bottom hole assembly and run in hole, M/U bottom hole assembly #19 (as per Baker Hughes per), run in hole from 201’ MD to 2277’ MD, try EST perameters but drill pipe plugged off; actual DISP equals 17.4 BBL and calculated is 18.03 BBL, pull out of hole from 2277’ MD to 2182’ MD, R/U to REV circulation, REV circulation trying to unplug drill pipe; unplugged after two attempts. Wash and ream from 2088’ MD to 2182’ MD; 7 BPM; 150 PSI; 80 RPM and zero TQ, continue to wash and ream from 2180’ MD to casing stub and tag at 2308’ MD with 7.5 BPM 200 PSI; 80 RPM; CBU while ROT and RECIP, pull up weight 76K; S/O weight 79K; ROT weight 78K, pump 29 BBL of high viscosity super sweep at 7.5 BPM, Mill 7’ casing with 80-110 RPM; 6 BPM 150 PSI; 1-4K TQ; from 2308’ MD to 2320’ MD, pump high viscosity super sweep at 8.5 BPM 400 PSI and 80 RPM, jet stack through IA, ROT and RECIP string, observed flow line packed off, disassembled and clean out, reassemble, fill hole and check for leaks, crack in flow line, service rig Simops weld crack in flow line, fill hole and check for leak (GOOD), bring pump rate up to 12 BPM 500 PSI and wash to BTM; with 120 RPM; had 10’ of fill, tag stub at 2320’ MD, work through tight spot at 2293’ MD several times, wash down stub and mill from 2320’ MD to 2321’ MD, mill packing off, P/U and work through tight spot again at 2293’ MD with 15 BPM 650 PSI several times, back ream out to 2225’ MD and wash to BTM (No Fill), continue to mill with same parameter from 2321’ MD to 2325’ MD Calibrations: Chromatograph, THA. QGM Online Failures: None Daily Cost: 2235.00 CPAI DAILY WELLSITE REPORT 3N-07A REPORT FOR Larry Hill DATE 6-26-12 DEPTH 2323 PRESENT OPERATION Milling with parameters. TIME 12:00am YESTERDAY 2308 24 HOUR FOOTAGE 15 CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 0.0 @ 0 @ 0.0 FT/HR SURFACE TORQUE 0 @ 0 @ 0.0 AMPS WEIGHT ON BIT 0 @ 0 @ 0.0 KLBS ROTARY RPM 0 @ 0 @ 0.0 RPM PUMP PRESSURE 0 @ 0 @ 0.0 PSI DRILLING MUD REPORT DEPTH MW VIS PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 0 @ 0 @ 0.0 TRIP GAS CUTTING GAS 0 @ 0 @ 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 0 @ 0 @ 0.0 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 0 @ 0.0 AVG PROPANE (C-3) 0 @ 0 @ 0.0 CURRENT BUTANE (C-4) 0 @ 0 @ 0.0 CURRENT BACKGROUND/AVG PENTANE (C-5) 0 @ 0 @ 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Flow line was plug and had a leak in the valve. Problem was fixed. CANRIG PERSONNEL ON BOARD Britten Adams, John Lundy DAILY COST $2235.00 REPORT BY Britten Adams ConocoPhillips Alaska Inc. Well Name (change the name at beginning of job) Daily Report Report for: Larry Hill Date: 6-27- 12 Time: 12;00am Current Depth (MD): 2323 Current Depth (TVD): Current Operations: Fish metal cutting out stacks. 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: 1.98 Max: 4.59 Torque: Current: 1307 Max: 2545 WOB: Current 6.5 Max: 44 RPM: Current: 114 Max: 114 PP: Current: 238 Max: 916 Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: 10.24 FV: 44 PV: YP: FL: Gels: Sol: pH: Cl -: Ca ++: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: PJSM hole packing off at 2293’ MD to 2297’ MD, work pipe several times through spots, no change, pump high viscosity weight sweep, small amount of cutting in returns, decision made to change fluid over to 10.2 PPG LSND mud, shut down and clean inspect flow line before fluid swap, PFSM on displacement, PREP pit from fluid displacement, displace 8.5 PPG brine over to 10.2 PPG LSND mud at 16 BPM; 425 PSI; 80 RPM and 0 TQ, mill from 2325’ MD to 2326’ MD at 10 BPM; 110 RPM; TQ equal 0-3K; weight on bit equals 10K, packing off, decision made to circulated cutting to surface, no cuttings at BU, decision made to pull out of hole, circulated and condition mud until mud weight is even in/out 10.2 PPG, monitor well static, pull out of hole at 6 BPM and 175 PSI from 2268’ MD to 201’ MD, calculated fill equals 19.6 BBL; actual fill equals 18.03 BBL, rack back two stands of 6.75” collars and lay down bottom hole assembly, stack full of wadded up metal, decision made to mix high viscosity sweep, clean and clear rig floor, Simops hook up mud pump to pump through well head with attempt to clean out metal from stack, pump high viscosity sweep at 8.5 BPM through well head, little to none returns, blow down line and drain stack, PJSM on tools and M/U rope stack, pull up Baker’s tool from beaver slide, M/U Baker’s rope spear (as per Baker’s Hughes rep), attempt to fish out metal cuttings from stack, only magnets had metal, decision made to pull up 5’ magnets and try fish out more metal. Calibrations: Chromatograph, THA. Failures: None Daily Cost:$2785.00 CPAI DAILY WELLSITE REPORT 3N-07A REPORT FOR Larry Hill DATE 6-27-12 DEPTH 2323 PRESENT OPERATION Fish metal cutting out stacks. TIME 12:00am YESTERDAY 2323 24 HOUR FOOTAGE 0 CASING INFORMATION SURVEY DATA DEPTH INCLINATION AZIMUTH VERTICAL DEPTH BIT INFORMATION INTERVAL CONDITION REASON NO. SIZE TYPE S/N JETS IN OUT FOOTAGE HOURS T/B/C PULLED DRILLING PARAMETERS HIGH LOW AVERAGE CURRENT AVG RATE OF PENETRATION 4.59 @ 2318 0 @ 2275 3 1.98 FT/HR SURFACE TORQUE 2545 @ 2322 0 @ 2271 1900 1307 AMPS WEIGHT ON BIT 44 @ 2272 0 @ 2267 6.5 6.5 KLBS ROTARY RPM 114 @ 2322 0 @ 2289 114 114 RPM PUMP PRESSURE 916 @ 2292 0 @ 2266 170 238 PSI DRILLING MUD REPORT DEPTH MW 10.24 VIS 44 PV YP FL Gels CL- FC SOL SD OIL MBT pH Ca+ CCI MWD SUMMARY INTERVAL TO TOOLS GAS SUMMARY (units) HIGH LOW AVERAGE DITCH GAS 0 @ 0 @ 0.0 TRIP GAS CUTTING GAS 0 @ 0 @ 0.0 WIPER GAS CHROMATOGRAPHY (ppm) SURVEY METHANE (C-1) 0 @ 0 @ 0.0 CONNECTION GAS HIGH ETHANE (C-2) 0 @ 0 @ 0.0 AVG PROPANE (C-3) 0 @ 0 @ 0.0 CURRENT BUTANE (C-4) 0 @ 0 @ 0.0 CURRENT BACKGROUND/AVG PENTANE (C-5) 0 @ 0 @ 0.0 HYDROCARBON SHOWS INTERVAL LITHOLOGY/REMARKS GAS DESCRIPTION LITHOLOGY PRESENT LITHOLOGY DAILY ACTIVITY SUMMARY Continue to send sweeps to clear stack from metal cutting from casing. CANRIG PERSONNEL ON BOARD Britten Adams, John Lundy DAILY COST $2785.00 REPORT BY Britten Adams ConocoPhillips Alaska Inc. 3N-07A Daily Report Report for: Larry Hill Date: 6-28- 12 Time: 12;00am Current Depth (MD): 2378’ Current Depth (TVD): Current Operations: Continue to mill casing. 24 hr Footage (MD): 55’ Drilling Parameters ROP: Current: 3.55 Max: 6.82 Torque: Current: 1219 Max: 2981 WOB: Current 4.7 Max: 5.8 RPM: Current: 116 Max: 117 PP: Current: 393 Max: 788 Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: 9.9 FV: 58 PV: 9 YP: 37 FL: 0 Gels: 19/21/23 Sol: 10 pH: 9.5 Cl -: 4000 Ca ++: 520 MW Change: Depth: 2378’ From: 10.24 To: 9.9 Reason: Mud Loss event: Depth: N/A Volume: N/A Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: PJSM M/U magnet assy and make multiple passes through stack, fill hole and circulated through IA at 9 BPM 800 PSI, continue RECIP magnets; drain stack, function rams halfway and continue to RECIP magnets until stack cleared, a proximally 400 LBS of shaving recovered, clean floor; pull up and lay down subs VIA beaver slide, flush stack with stack washer and magnets at 20 BPM 150 PSI, clean magnets and flush again at same rate until returns and magnets cleaned up, PJSM pull up junk mill magnet assy bottom hole assembly #22 and run in hole to 227’ MD; took 5-10K at 180’ MD; DISP from trip equals actual 5.7 BBL and calculated 7.41 BBL, wash and ream at 14 BPM 300PSI; 60 RPM from 227’ MD to 1734’ MD; DISP from trip equals actual 16.7 BBL and calculated 16.1 BBL, wash and ream from 1734’ MD to 2326’ MD at 14 BPM 300 PSI, set down 5K at 2326’ MD; drill off at reaming rate, CBU 3 times at 16 BPM; 735 PSI; 50 RPM; 0 TQ, cement and metal shaving in returns, lay down single and monitor well static, pull out hole on elevators from 2300’ MD to 227’ MD; actual fill 19.6 BBL and calculated fill is 19.29 BBL, rack back two stands drill collars; lay down BHA #22 (as per Bakers Hughes rep), clean and clear rig floor, flush stack twice, M/U bottom hole assembly #23 pilot mill (as per Baker Hughes rep), run in hole from 201’ MD to 2326’ MD, mill from 2326’ MD to 2345’ MD. Calibrations: Chromatograph, THA. Failures: None Daily Cost:$2385.00 ConocoPhillips Alaska Inc. 3N-07A Daily Report Report for: Larry Hill Date: 6-29- 12 Time: 12;00am Current Depth (MD): 2406’ Current Depth (TVD): Current Operations: Continue to mill casing. 24 hr Footage (MD): 31’ Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: FV: PV: YP: FL: Gels: Sol: pH: Cl -: Ca ++: MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Continue milling from 2345’ MD to 2373’ MD at 10 BPM and 350 PSI. Sent high viscosity sweeps every 5’ at 17 BPM and 750 PSI. P/U and M/U single to allow room for reciprocation. Continue to milling from 2373’ MD to 2380’ MD with same parameters. PJSM mill from 2380’ MD to 2415’ MD at 10 BPM and 4000 PSI. Pumped 10 BBL sweeps every 5’. Brought pump rate up to 17.5 BPM, and work pipe until sweep comes back. 20% extra cutting came back with sweep. Shut down drain stack. Observe stack full of metal. Decision made to pump through well head annulus Calibrations: Chromatograph, THA. Failures: None Daily Cost:$2385.00 ConocoPhillips Alaska Inc. 3N-07A Daily Report Report for: Guy Whitlock Date: 7-10- 12 Time: 12:00am Current Depth (MD): 6185’ Current Depth (TVD): Current Operations: Drilling ahead. 24 hr Footage (MD): 1097’ Drilling Parameters ROP: Current: 55 Max: 228 Torque: Current: 5633 Max: 7012 WOB: Current 30 Max: 32 RPM: Current: 102 Max: 103 PP: Current: 2707 Max: 2774 Lag: Strokes: Time: 53:07 Surf-Surf: Strokes: 7801 Time: 12:00AM ECD: Current: Max: Mud Properties @ MW: 9.7 FV: 51 PV: 14 YP: 26 FL: 4.4 Gels: 10/12/13 Sol: 1 pH: 17.5 Cl -: 450 Ca ++: 40 MW Change: Depth: N/C From: To: Reason: Mud Loss event: Depth: N/C Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 44 5815’ 11 1833.206 51.786 0.842 24.796 0.416 0 0 45 5874’ 8 1331.401 34.743 14.193 0 9.848 0 0 46 5899’ 10 1823.550 45.367 18.208 0 10.063 0 0 47 5959’ 15 3108.389 83.160 20.922 6.968 11.593 0 0 Lithologies: Current: 80% Siltstone, 20% Sand. Last 24 hrs: 10% Claystone, 40% Siltstone, 10% Sandstone, 20% Sand, 20% Conglomerate Sand Operational Summary: Continue drilling from 5000’ MD to 5552’MD. Drilling from 5552’MD to 5788’ MD. Continue drilling from 5788’ MD to 5935’ MD. Drilling from 5935’ MD to 6130’ MD. Calibrations: Chromatograph, THA. Failures: None Daily Cost:$3235.00 ConocoPhillips Alaska Inc. 3N-07A Daily Report Report for: Guy Whitlock Date: 7-11- 12 Time: 12:00am Current Depth (MD): 7042’ Current Depth (TVD): Current Operations: TD intermediate casing. CBU and POOH. 24 hr Footage (MD): 857’ Drilling Parameters ROP: Current: 0 Max: 148 Torque: Current: 0 Max: 7705 WOB: Current 0 Max: 21.7 RPM: Current: 0 Max: 98 PP: Current: 0 Max: 2931 Lag: Strokes: Time: 70.56 Surf-Surf: Strokes: 8749 Time: 12:00AM ECD: Current: Max: Mud Properties @ MW: 9.7 FV: 46 PV: 10 YP: 28 FL: 3.4 Gels: 10/24/30 Sol: 11 pH: 9.6 Cl -: 700 Ca ++: 80 MW Change: Depth: N/C From: To: Reason: Mud Loss event: Depth: N/C Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 136 5815’ 570 1833.206 51.786 0.842 24.796 0.416 0 0 137 5874’ 309 1331.401 34.743 14.193 0 9.848 0 0 139 5899’ 201 1823.550 45.367 18.208 0 10.063 0 0 140 6024’ 6 1221.613 36.856 13.543 0 0 0 0 Lithologies: Current: 70% Shale, 20% Siltstone, 10% Sand. Last 24 hrs: 80% Siltstone, 20% Sand Operational Summary: Drilling from 6130’ MD to 6404’MD with TVD-5916’, P/U=168K, S/O=151K, and ROT=160K. Drilling from 6404’ MD to 6666’ MD with TVD-6039’, P/U=171K, S/O=161K, and ROT=160K. Max gas equals 582 units. Drilling from 6666’ MD to 7042’ MD with P/U=179K, S/O 154K, and ROT=165K. Circulated 3x pumps at 500 GPM and 2025 PSI. Monitor the well. Pull out of hole on elevators from 7042’ MD to 2590’ MD. Calibrations: Chromatograph, THA. Failures: None Daily Cost:$3235.00 ConocoPhillips Alaska Inc. 3N-07A Daily Report Report for: Guy Whitlock Date: 7-12- 12 Time: 12:00am Current Depth (MD): 7042’ Current Depth (TVD): Current Operations: RIH in with 7” casing. 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: 0 Max: 3662 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 82 PP: Current: 159 Max: 1969 Lag: Strokes: Time: 3.49 Surf-Surf: Strokes: 101 Time: 12:00AM ECD: Current: Max: Mud Properties @ MW: 9.7 FV: 51 PV: 15 YP: 30 FL: 3.6 Gels: 10/25/29 Sol: 13.5 pH: 9.7 Cl -: 700 Ca ++: 80 MW Change: Depth: N/C From: To: Reason: Mud Loss event: Depth: N/C Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N ’ ’ ’ Lithologies: Current: Last 24 hrs: 70% Shale, 20% Siltstone, 10% Sand. Operational Summary: Continue to run in hole from 4185’ MD to 6947” MD (NO PROBLEMS). Wash and ream to 7038’ MD. Circulated bottom up 3x at 575 GPM and 250 PSI. Monitor well then pull out the hole 175K to 2590’ MD. Circulated bottom up to window at 520 GPM and 1600 PSI. Slip and cut 60’ drilling line. Continue to pull out of hole to 741’ MD. Monitor well, rack back 4 stands of heavy weight drill pipe, and lay down 5 joint of heavy weight drill pipe with jars. Down load MWD information. Continue laying down bottom hole assembly. Clean and clear rig floor. Pull up joints 5” drilling pipe and flush stacks. Pull wear bushing and flush stack a second time. C/O rams and saver subs. R/U and test 7” rams 250/3500 PSI. Run down test equipment. R/U casing equipment bails, franks tools, elevators, spiders, power tongs, and sling. Run 7” casing. P/U shoe joints nad discovered bottom of shoe broken off. Wait on new shoe joint and service rig. Strap new shoe joint and continue running in hole with 7: casing to 129’ MD. Calibrations: Chromatograph, THA. Failures: None Daily Cost:$3235.00 ConocoPhillips Alaska Inc. 3N-07A Daily Report Report for: Guy Whitlock Date: 7-13- 12 Time: 12:00am Current Depth (MD): 7042’ Current Depth (TVD): Current Operations: Cementing casing. 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: 0 Max: WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: Time: 0 Surf-Surf: Strokes: 0 Time: 12:00AM ECD: Current: Max: Mud Properties @ MW: 9.7 FV: 43 PV: 11 YP: 20 FL: 0 Gels: 5/12/0 Sol: 0 pH: 0 Cl -: 0 Ca ++: 0 MW Change: Depth: N/C From: To: Reason: Mud Loss event: Depth: N/C Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N ’ ’ ’ Lithologies: Current: Last 24 hrs: . Operational Summary: Check equipment and continue to run in hole with 7”casing. Break circulation every 500’. Run in hole to 7004’ MD and wash to 7038’ MD with 2.5 BPM/600 PSI. Circulate bottom up with franks tool. Lay down Frank’s tools and move up cement head. Circulate and condition mud at 4.5 BPM/600 PSI. Pump 5 BBL, 100 CW, and put cement line to 4500 PSI. Pump first stage cement with 25 BBL. Launch wiper dart, pump 2 BBL, mud push, load top plug, and pump 42.5 BBL. Launch closing dart and chase with20 BBL H2O, swap over to rig and displace with 243 BBL. Pressure up 1000 PSI and hold from 5 minutes. Bleed off pressure and check floats (GOOD). Load plug from second stage cement job, pressure up and open cementer with 3300 PSI. Circulate bottom up at 5 BPM/250 PSI. PJSM from second stage cement job, batch up, and continue circulating at 5 BPM/ 250 PSI. Pump second stage cement job with 20 BBL. Close estimated cementer with 1600 PSI and held 1500 PSI from 5 minutes (GOOD). Monitor well then run down cement head. Drain stack and vacate out casing stump. N/D bope stack and P/U with 50K. Calibrations: Chromatograph, THA. Failures: None Daily Cost:$3235.00 ConocoPhillips Alaska Inc. 3N-07A Daily Report Report for: Guy Whitlock Date: 7-14- 12 Time: 12:00am Current Depth (MD): 7042’ Current Depth (TVD): Current Operations: R/U test equipment.. 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: 0 Max: WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: Time: 0 Surf-Surf: Strokes: 0 Time: 12:00AM ECD: Current: Max: Mud Properties @ MW: 9.7 FV: 60 PV: 20 YP: 26 FL: 3.8 Gels: 10/29/40 Sol: 13.5 pH: 9.7 Cl -: 700 Ca ++: 80 MW Change: Depth: N/C From: To: Reason: Mud Loss event: Depth: N/C Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N ’ ’ ’ Lithologies: Current: Last 24 hrs: . Operational Summary: R/U wachs casing cutter and cut casing and Simops lay down casing equipment. Dress off cut and lay down casing stubs. N/D drilling spool with Simops lying down spider and C/O bails. Set pack off which FMC rep prefers. N.U tubing spool, DBL studded adapter flange, and test 7” packoff. Nipple up the bottom of pipe equipment. Set wear bushing to 6.25 ID. PJSM shuffle 5” heavy weight drill pipe in derrick. C/O elevators and M/U TPC opening tool. Run in hole with TPC open top to 1997’ MD. R/U LRS and put lines to 2000 PSI. Observed fluid had dropped in hole due to seal relaxing and u-tube of IA to drill pipe. Shut in drill pipe and fill hole with water (Close annular). Reverse circulation freeze protect down through port up drill pipe with 54 BBL at 1.25 BPM/200 PSI. P/U on string and close port with 15K. Pressure up on drill pipe to 100 PSI to conform port closed (GOOD). Bleed off pressure, open kill, drill pipe, and annular. Release tool with ¼ turn to the right. P/U 2” shear check valve with 2200 PSI. Circulate and balance well to 10 PPG at 5 BPM 350 PSI. Lay down single and pump down to total depth. Monitor the well. Pull out the hole from 1985’ MD to lay down TCP tool. Clear and clean floor on rig floor. Drain stack, pull wear bushing, obtain RKB measurements and set test plug. C/O rams and saver sub. C/O upper 7” PR to 3.5” x 6” VBR. LWR 2 7/8” x 5” to rebuilt 2 7/8” x 5” VBR’s and rebuild rams. C/O saver sub and R/U test equipment. Calibrations: Chromatograph, THA. Failures: None Daily Cost:$3235.00 ConocoPhillips Alaska Inc. 3N-07A Daily Report Report for: Guy Whitlock Date: 7-15- 12 Time: 12:00am Current Depth (MD): 7042’ Current Depth (TVD): Current Operations: .. 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: 0 Max: 752 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 1193 Lag: Strokes: Time: 0 Surf-Surf: Strokes: 0 Time: 12:00AM ECD: Current: Max: Mud Properties @ MW: 9.7 FV: 45 PV: 8 YP: 15 FL: 4 Gels: 4/8/10 Sol: 10 pH: 8.6 Cl -: 600 Ca ++: 0 MW Change: Depth: N/C From: To: Reason: Mud Loss event: Depth: N/C Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N ’ ’ ’ Lithologies: Current: Last 24 hrs: . Operational Summary: PJSM-continue to C/O blind rams and install choke line. R/U test equipment flood stacks, choke, and kill line. Body test bottom of pipe equipment, ODS blind ram door leaking tight therefore, tighten up bolts. Retest same door seals leaking, drain stacks, blow down lines, and remove choke line. Open blind ram door, C/O door seal, close door to install choke line, and fill lines and stack with water. R/U test equipment. Test BOPE and all rams and chokes valves to 250 PSI. Test high to 3500 PSI. Test annular to 2500 PSI. Record information on chart and test with 4”. 3.5 & 4.5 test joints accumulators test equals 3000 PSI and later 1800 PSI. The end of the test was good and waive by Chuck Scheve. C/O test joint from 3.5” to 4.5”. Test lower 2 7/8”x 5” VBR. Upper 3.5x6” VBR to 250/3500 PSI and annular to 250/2500 PSI with 4.5” test joints for 5 minutes. Run down test equipment, blow down choke, and kill lines. Set wear bushing and clear floor. Continue to hang blocks. PJSM-slip and cut drilling line 277’ MD. Service T/D, draworks, iron roughneck, and skate. Pull up subs from bottom hole assembly. M/U BHA #31 to 113’ MD. Also upload MWD. Pull up NMDC.X/O, 10’ pup & M/U to T/D. Shallow pulse test MWD at 6 BPM/1150 PSI. Load nuclear sources and continue to run in hole with bottom hole assembly to 393’ MD. Calibrations: Chromatograph, THA. Failures: None Daily Cost:$3235.00 ConocoPhillips Alaska Inc. 3N-07A Daily Report Report for: Guy Whitlock Date: 7-16- 12 Time: 12:00am Current Depth (MD): 7372’ Current Depth (TVD): Current Operations: Drilling from 7150’ MD to 7450’ MD 24 hr Footage (MD): 330’ Drilling Parameters ROP: Current: 0 Max: 197 Torque: Current: 2854 Max: 3222 WOB: Current 4.5 Max: 10.6 RPM: Current: 83 Max: 101 PP: Current: 3245 Max: 3467 Lag: Strokes: Time: 129.38 Surf-Surf: Strokes: 9315 Time: 12:00AM ECD: Current: Max: Mud Properties @ MW: 9.7 FV: 53 PV: 15 YP: 32 FL: 0 Gels: 9/15/33 Sol: 14.5 pH: 9.5 Cl -: 550 Ca ++: 80 MW Change: Depth: N/C From: To: Reason: Mud Loss event: Depth: N/C Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases 7322’ 218911.642 13379.670 6288.438 1077.468 2433.823 620.223 690.961 None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N ’ ’ ’ Lithologies: Current: 20% Shale, 70% Siltstone, 10% Sand. Last 24 hrs: Operational Summary: PJSM-continue single in hole to 1983’ MD. Break circulation at 2 BPM/300 PSI. Rotate 25 RPM and rotate bit through TCP at 2018’ MD. Continue single in hole with 4” drill pipe to 3337’ MD. Circulate bottom up at 3337’ MD at 5 BPM/1125 PSI. Run up test equipment and test casing to 3500 PSI. Record on chart from10 minutes. Run down test equipment. Run in hole to 3350’ MD drilling out estimated cementer at 4 BPM/900 PSI. Continue to run in hole to 6850’ MD and tag cement. Break circulation at 6840’ MD at 50 SPM/200 GPM. Drill cements stringers to 6890’ MD. Circulate and condition mud at 200 GPM/50 SPM. R/U test equipment test casing to 3500 PSI and record on chart for 30 minutes. Run down test equipment. Wash and ream to 6914’ MD and drill baffle 200 GPM/1500 PSI. Obtain SPR’s at 6914’ MD. Wash down to 6957’ MD and drill out shoe track & 20’ of new hole from 7042’ MD to 7062’ MD. Displace well from 10 PPG to 11.1 PPG at 5 BPM/1750 PSI. Obtain SPR’s at 7062’ MD. Rack back stand, line up cement and kill lines. Flood same line and close upper VBR’s. Perform fit at 6985’ MD. Open VBR’s and blow down line. Wash down to 7050’ M at 200 GPM/1750 PSI. Drilling from 7062’ MD to 7150’ MD. Drilling from 7150’ MD to 7450’ MD. Calibrations: Chromatograph, THA. Failures: None Daily Cost:$3235.00 ConocoPhillips Alaska Inc. 3N-07A Daily Report Report for: Guy Whitlock Date: 7-17- 12 Time: 12:00am Current Depth (MD): 7450’ Current Depth (TVD): Current Operations: Changing centralizer. 24 hr Footage (MD): Drilling Parameters ROP: Current: 0 Max: 0 Torque: Current: 0 Max: 0 WOB: Current 0 Max: 0 RPM: Current: 0 Max: 0 PP: Current: 0 Max: 0 Lag: Strokes: Time: 0 Surf-Surf: Strokes: 0 Time: 12:00AM ECD: Current: Max: Mud Properties @ MW: 9.7 FV: 59 PV: 17 YP: 30 FL: 0 Gels: 9/13/29 Sol: 16 pH: 9.6 Cl -: 550 Ca ++: 80 MW Change: Depth: N/C From: To: Reason: Mud Loss event: Depth: N/C Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N ’ ’ ’ Lithologies: Current: Last 24 hrs: Operational Summary: Continue circulate x3 at 300 GPM/3250 PSI. Monitor well and pull out of hole on elevators to shoe. Monitor well again and run in hole to 7450’ MD. Circulate x3 at 300 GPM. 1200 units of gas on bottom up. Pump pull out of hole from 7365’ MD to 6988’ MD. Monitor well and slight flow after 20 minutes. Circulate back up at 300 GPM/3150 PSI. Monitor well and slight flow. Decision made to run in hole and weight up to 11.6 PPG. Run in hole to 7450’ MD and circulated ay 7450’ MD (300 GPM). Monitor well and pull 1 stand to dry. Observe fluid to drop in stack. Pull out of hole 5 stands on elevators to 6893’ MD. Monitor well and drop 2 3/8’ rabbit on wire at stand 65. Pull out of hole on elevators to 5286’ MD. Pull out of hole to 5286’ MD to 660’ MD. Monitor well for 30 minutes. Lay down heavy weight from 660’ MD to 236’ MD. PJSM- lay down 2 NMDC’s and unload nuclear sources. Down load MWD. Lay down bottom hole assembly. Clean and clear rig floor. Run down 4.5’ casing handling equipment. Tight tolerance on centralizer on 2 stands. Wait on order from town. Decision made to C/O bowspring centralizers, POOH, remove single centralizer and restock to 5.875” straight blade style centralizer. Calibrations: Chromatograph, THA. Failures: None Daily Cost:$3535.00 ConocoPhillips Alaska Inc. 3N-07A Daily Report Report for: Guy Whitlock Date: 7-4-12 Time: 12:00am Current Depth (MD): 2621’ Current Depth (TVD): Current Operations: Cementing 24 hr Footage (MD): Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: 9.8 FV: 53.0 PV: 8.0 YP: 34.0 FL: NC Gels: 12.0 Sol: 9.0 pH: 9.0 Cl -: 1600.0 Ca ++: 320.0 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Continue to reverse circulate at 10 BPM at 795 PSI. Circulate bottoms up 10 BPM at 975 PSI. Working on MP2’s; scrub and paint rig. Clean out boilers too. Run in with cement equipment from 2991’ MD to 3100’ MD with 1 BPM. They saw pressure increasing from 150 PSI to 190 PSI, therefore decision was made to come back out the hole. At 7 BPM and 400 PSI rig observe cement at bottoms up. Pull out of hole from 3100’ MD to 3086’ MD. Run back in to circulated and pump cement. Rig circulated and condition mud at 5 BPM and 375 PSI. Pressure test cement line to 2500 PSI and pumped 11 BBL. Test was good. Pull out the hole from 3086’ MD to 2235’ MD with calculated fill equal to 3.75 BBL and actual fill is 4.08 BBL. Reverse circulated at 10 BPM with 700 PSI. Waited on cement while, SIMOPS’s pull up 6 stands of 5” HWDP and 30 stands 5” drill pipe. Cleans valves and under shakers. Calibrations: Chromatograph, THA. Failures: None Daily Cost:$3885.00 ConocoPhillips Alaska Inc. 3N-07A Daily Report Report for: Guy Whitlock Date: 7-5-12 Time: 12:00am Current Depth (MD): 2621’ Current Depth (TVD): Current Operations: Test equipment and rack back one stand 2505’MD. 24 hr Footage (MD): Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: 9.85 FV: 44 PV: 8 YP: 24 FL: N/C Gels: 8 Sol: 9 pH: 11.2 Cl -: 1700 Ca ++: 480 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: : PJSM continue to pull up 5” drill pipe. Lay down thread protectors and pull up saver sub. C/O saver sub, bell guide, and grabber die on top drive. Put tools away. Run in hole from 2238’ MD and pumped at 1BPM/130 PSI. While running in hole saw a 30 PSI increase at 2366’ MD and saw 2K bobble. At bottom up saw hard cement at shakers, therefore slowed pumps back to 1 BPM and continue to run in hole. Tagged up at 2367’ MD and set down 4K and decision was made to pull out hole from 2367’ MD to 726’ MD. Tongues, elevators, and slip were lay down. Clean and velar rig floor. Run up to test 5” floor valves from 250-3000 PSI. Run down test equipment, floor valves and change elevators. PJSM, HRC, and HRW on M/U bottom hole assembly clean out run. M/U BHA #26 clean out run (as per Halliburton and Baker Hughes rep). Pulse test MWD at 375 GPM and 800 PSI (GOOD). Run in hole with drill pipe from 584’ MD to 2340’ MD. Wash and ream from 2340’ MD to 2367’ MD at 10 BPM and 1050 PSI. Tag cement at 2367’ MD. Drill cement from 2367’ MD to 2620’ MD at 10 BPM at and 1100 PSI. Ream stand and shot surveys for MWD from 2620’ MD to 2498’MD. R/U to test casing at 2615’ MD and attempt test to 1500 PSI. Pumped at 1 BPM to 725 PSI and pressure broke over. An injection rate at 1 BPM/ 700 PSI made decision to pull out of hole. Monitor well from 2620’ MD to 580’ MD. Lay down bottom hole assembly. Clean and clear rig floor. Scrub and paint rig while waiting on tools. Run in hole with retrievable packer to 1298’ MD. Pressure up below packer to 720 PSI and pressure broke over. Pressure and tested above packer to 1500 PSI and held on chart for 15 minutes. Continue to run in hole to 2608’ MD. Pressure up below packer to 1500 PSI and held 15 minutes. Test above packer and pressure up to 600 PSI and established and injection rate (1 BPM/ 680 PSI). P/U rack back 1 stand. Calibrations: Chromatograph, THA. Failures: None Daily Cost:$3235.00 ConocoPhillips Alaska Inc. 3N-07A Daily Report Report for: Guy Whitlock Date: 7-6-12 Time: 12:00am Current Depth (MD): 2612’ Current Depth (TVD): Current Operations: Run down top drive landing and test top drive for leaks 24 hr Footage (MD): 0 Drilling Parameters ROP: Current: 6.94 Max: 13 Torque: Current: 1396 Max: 2338 WOB: Current 4.2 Max: 9 RPM: Current: 81 Max: 82 PP: Current: 870 Max: 980 Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: 9.56 FV: 44 PV: 10 YP: 24 FL: N/C Gels: 8 Sol: 9 pH: 10.2 Cl -: 1600 Ca ++: 220 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: Current: Last 24 hrs: Operational Summary: Set packer at 2501’ MD. Test IA to 1500 PSI and fluid circulation around packer (GOOD). R/U on drill pipe injection at 1 BPM/690 PSI. Test drill pipe injection, bleed pressure and packer performance injection (GOOD). Run down test equipment. Line up to trip tank. Pull out of hole from 2412’ MD to 745’MD. Rack back 6 stands collars and lay down BHA. Blow down top drive, kill line, and cement line. M/U cement retainer. Run in hole from 7’ MD to 2415’ MD. PJSM on servicing rig. Wait on order from town. Pull out of hole from 2415’ MD. Clean and clear rig floor. Run in hole to complete shallow hole test (GOOD) at 225’ MD. Continue to run in hole with whipstock. On stand 19 orientated to 16L and shut down pumps. Make a connection. Run in hole and tag up at 2621’ MD. Pull up off bottom and verify 16L by shut down pumps. Come back down to set anchor. Slowly slacked off and saw anchor shear at 18K; also shear bolt sheared. Pull up 5’ and saw no over pull verifying shear bolt was not attached. Start milling at 2599’ MD to 2606’ MD. Lubricate rig swivel packing. Continue to mill from 2606’ MD to 2611’ MD. C/O swivel packing. Run down top drive landing and test top drive for leaks (GOOD). Calibrations: Chromatograph, THA. Failures: None Daily Cost:$3235.00 ConocoPhillips Alaska Inc. 3N-07A Daily Report Report for: Guy Whitlock Date: 7-7-12 Time: 12:00am Current Depth (MD): 2781’ Current Depth (TVD): Current Operations: Drilling ahead. 24 hr Footage (MD): 169’ Drilling Parameters ROP: Current: 65.4 Max: 212 Torque: Current: 144.47 Max: 2272 WOB: Current 6 Max: 12.1 RPM: Current: 50 Max: 51 PP: Current: 1083 Max: 1103 Lag: Strokes: Time: Surf-Surf: Strokes: Time: ECD: Current: Max: Mud Properties @ MW: 9.7 FV: 45 PV: 10 YP: 22 FL: 7 Gels: 8/9/11 Sol: 5 pH: 10 Cl -: 500 Ca ++: 40 MW Change: Depth: N/C From: 9.5 To: 9.7 Reason: N/C Mud Loss event: Depth: N/C Volume: N/C Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 1 2634’ 2.120 354 2 2641’ 2.251 304 3 2648’ 3.161 1080 4 2650’ 4.11 1166 Lithologies: Current: Last 24 hrs: Operational Summary: Run in hole from 2574’ MD tag up at 2611’ MD. Milled from 2611’ MD at 400 GPM/950 PSI. Work bottom hole assembly through window at milling rate X2. Shut down rotation work through window. Shut down pumps and work through window again. Pump sweet, circulated, and condition the mud at 400 GPM. Perform leak off test. Pull out of hole from 2567’ MD to 815’ MD. Monitor well, rack back 6 stands of 5” heavy weight. Lay down 2 stands of drill collars and BHA. Clean and clear rig floor. Flush stack X2 with stack washers. M/U BHA. P/U 1 stand of heavy weight and perform shallow plush test at 410 GPM/900 PSI (GOOD). Continue to run in hole with heavy weight drill pipe from 692’ MD to 2544’ MD. Kelly up wash down to 2590’ MD. Orientated to 15L and shut down pumps. Pump at 400 GPM and orientated to 15L. Slide through window at 2599’ MD and start reaming at 2606’ MD to 2638’ MD. Displace the well with new mud. Start time drilling from 2638’ MD to 2653’ MD Calibrations: Chromatograph, THA. Failures: None Daily Cost:$3235.00 ConocoPhillips Alaska Inc. 3N-07A Daily Report Report for: Guy Whitlock Date: 7-8-12 Time: 12:00am Current Depth (MD): 3334’ Current Depth (TVD): Current Operations: Drilling ahead. 24 hr Footage (MD): 553’ Drilling Parameters ROP: Current: 220 Max: 230 Torque: Current: 0 Max: 2985 WOB: Current 9.3 Max: 9.3 RPM: Current: 0 Max: 55 PP: Current: 1439 Max: 1505 Lag: Strokes: Time: 31:02 Surf-Surf: Strokes: 4487 Time: 12:00AM ECD: Current: Max: Mud Properties @ MW: 9.7 FV: 56 PV: 16 YP: 26 FL: 6.4 Gels: 10/14/15 Sol: 6 pH: 9.9 Cl -: 450 Ca ++: 40 MW Change: Depth: N/C From: To: Reason: Mud Loss event: Depth: N/C Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 15 3120’ 54 16813 27.503 16 3145’ 43 8619.047 18.421 17 3184’ 190 36519.204 129.515 18 3234’ 65 41113.377 248.503 204.245 167.747 124.296 292.043 34.153 Lithologies: Current: 60% Claystone, 30% Sand, 10% Conglomerate Sand. Last 24 hrs: 20% Claystone, 80% Sand. Operational Summary: Drilling from 2746’ MD to 3005’ MD. Pull out of hole to 2674’ MD and reshoot survey for MWD. Continue to pull out of hole and pull through window (NO PROBLEMS). Monitor well and pump slug. Pull out of hole to 692’ MD. Monitor well and rack back 4 stands heavy weight drill pipe. Clear and clean rig floor. Pull up bottom hole assembly. M/U bottom hole assembly to 42.21’ MD. Drilling from 2746’ MD to 3005’ MD. Pull up bottom hole assembly and complete shallow hole test at 450’ MD (GOOD). Run in hole on elevators from 450’ MD to 2590’ MD. Fill pipeline through window to 2630’ MD. Decision was made to mad pass from 2630’ MD to 3005’ MD. Drilling from 3005’ MD to 3322’ MD. Calibrations: Chromatograph, THA. Failures: None Daily Cost:$3235.00 ConocoPhillips Alaska Inc. 3N-07A Daily Report Report for: Guy Whitlock Date: 7-10- 12 Time: 12:00am Current Depth (MD): 5088’ Current Depth (TVD): Current Operations: Drilling ahead. 24 hr Footage (MD): 1754’ Drilling Parameters ROP: Current: 126 Max: 190 Torque: Current: 4459 Max: 6018 WOB: Current 27 Max: 28 RPM: Current: 92 Max: 93 PP: Current: 2293 Max: 2403 Lag: Strokes: Time: 43.52 Surf-Surf: Strokes: 6761 Time: 12:00AM ECD: Current: Max: Mud Properties @ MW: 9.7 FV: 53 PV: 14 YP: 25 FL: 5.4 Gels: 10/11/12 Sol: 9 pH: 8.9 Cl -: 500 Ca ++: 40 MW Change: Depth: N/C From: To: Reason: Mud Loss event: Depth: N/C Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : Gas Events Depth (MD/TVD) C1 C2 C3 C4I C4N C5I C5N Trip Gas Connection Gases C1 C2 C3 C4I C4N C5I C5N None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 25 3663’ 92 17299.624 58.801 34.402 59.742 65.132 124.875 14.026 26 3735’ 70 13230.640 53.877 26.975 45.144 53.830 98.974 10.127 27 4796’ 39 6872.537 112.063 30.747 5.335 9.675 15.011 0.000 29 4849’ 14 2119.655 45.028 19.480 6.152 10.742 16.894 0.000 Lithologies: Current: 10% Claystone, 40% Siltstone, 10% Sandstone, 20% Sand, 20% Conglomerate Sand Last 24 hrs: 60% Claystone, 30% Sand, 10% Conglomerate Sand. Operational Summary: Drilling from 3322’ MD to 4258’ MD. Adjust “draworks” brakes. Off high line @ 1000 hours. PJSM continue to adjust brakes pumping 170 GPM. 275 PSI. Drilling from 4258’ MD to 4720’ MD. Total jars hours 14.75 and bit hours 14.75. Drilling from 4720’ MD to 5000’ MD. Calibrations: Chromatograph, THA. Failures: None Daily Cost:$3235.00
