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214-088
ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Date: May 29, 2025 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W. 7th Ave Suite 100 Anchorage, AK 99501 COP reviewed cement evaluation activities for wells in response to AOGCC Industry Guidance Bulletin 25-001. There was no indication of cement evaluation logs being run for the following wells based on a review of all drilling files associated with well construction. Kuparuk River Unit/Field Well API #PTD #Comments 3G-13A 50103201370100 222-106 No cement bond logs run 2N-303A 50103203520100 214-088 No cement bond log run 2E-04 50029235050000 213-168 No cement bond log run TARN 2N-323A 50103202580100 213-159 No cement bond log run 1C-19 50029231490000 203-054 No cement bond log run By Gavin Gluyas at 9:48 am, Jun 02, 2025 2N-303A 50103203520100 214-088 ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Colville River Unit/Field Well API # PTD # Comments CD3-303 50103205680000 208-013 No cement bond log run ConocoPhillips Alaska 700 G Street Anchorage, AK 99501 Email: AKGGREDTSupport@ConocoPhillips.onmicrosoft.com Greater Mooses Tooth Unit/Field Well API # PTD # Comments MT6-06 50103207730000 218-093 Production well, CBL was not run across 7” liner • • 2-61a3 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 16, 2015 Attn.: Makana Bender DATA LOGGED 333 West 7th Avenue, Suite 100 °_ s qci�+bzoi 5 A=* '��'3r w a M.K.BENDER Anchorage, Alaska 99501 MUG132w, RE: Multi Finger Caliper(MFC) : 2N-303A Run Date: 6/30/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2N-303A Digital Data(LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50-103-20352-01 SCAOE PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: J'22..aLzaJ%,5 STATE OF ALASKA ALASPOIL AND GAS CONSERVATION COMMISSN REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations shutdown r Performed: Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well ' Re-enter Susp Well r Other:tubing patch r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F. Exploratory r 214-088-0 3.Address: 6.API Number: P. 0. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-103-20352-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 380054/ADL 380053 Us.) 2N-303A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Tarn Oil Pool 11.Present Well Condition Summary: Total Depth measured 7099 feet Plugs(measured) None true vertical 5752 feet Junk(measured) None Effective Depth measured 0 feet Packer(measured) 6596 true vertical 0 feet (true vertical) 5352 Casing Length Size MD TVD Burst Collapse CONDUCTOR 30" 105 16 140 140 SURFACE - 2598 10 2632 2297 PRODUCTION 7056 10.38 7089 5749 RECEIVED Perforation depth: Measured depth: 6612'-6632', 6725'-6740' ?ill G Z015 True Vertical Depth: 5370'-5386', 5458'-5470' sChtlEP NOV 1 6 2M J Tubing(size,grade,MD,and TVD) 3.5, L-80, 6722 MD, 5450 TVDAOGCC 3.5"Weatherford retrievable patch 6265'-6294' MD Packers&SSSV(type,MD,and TVD) PACKER-BAKER"FA"PERMANENT PACKER @ 6596 MD and 5352 TVD NIPPLE-CAMCO DS NIPPLE @ 515'MD and 515'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation n/a n/a n/a n/a n/a Subsequent to operation n/a n/a n/a n/a n/a 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 F7 Service r Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil F7 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 Kelly Lyons/Brent Ro•- s Email n1617@cop.com Printed Name K-4.; L ons Title Problem Wells Supervisor Signature / Phone:659-7224 Date: 08/07/15 ///// r RBDM AUG 1 4 2015 vrL R/2/1 A fti,.3-- Form 10-404 Revised 5/2015 Submit Original Only • • ConocoPhillips Alaska AUG 1 i. 2015 P . BOX 100360 OGCO ANCHORAGE,ALASKA 99510-0360 A August 7, 2015 Commissioner Cathy Foerster Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,AK 99501 Dear Commissioner Foerster: Enclosed please find the 10-404 Report of Sundry Operations for ConocoPhillips Alaska, Inc. well 2N-303A (PTD 214-088) for a retrievable patch set in the tubing above the packer. Please call Brent Rogers or myself @ 659-7224 if you have any questions. /ze_17 Sincerely, Kelly Lyons ConocoPhillips Problem Wells Supervisor Enclosures • • 2N-303A DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 06/06/15 LOG PPROF TO DETERMINE PURPLE/BERMUDA SAND SPLITS. PURPLE 76% BERMUDA 24%. FOUND LEAK IN TUBING AT 6293'. NO CROSS FLOW OBSERVED ON SHUT IN. FALLBACK OBSERVED GOING INTO PURPLE SANDS ON SHUT IN. 08/01/15 BRUSHED PATCH SET AREA FROM 6200' RKB TO 6350' RKB, SET 2.72"WIDEPACK LE PACKER @ 6300' SLM. *JOB IN PROGRESS * 08/02/15 SET TEST TOOL IN PACKER @ 6300' RKB, LRS PERFORM PASSING CMIT IAxT TO 2500#, PULLED TEST TOOL FROM PACKER @ 6300' RKB; READY TO SET UPPER PATCH IN MORNING. *JOB IN PROGRESS 08/03/15 SET UPPER PATCH ASSY @ 6270' RKB, SET TEST TOOL IN TOP OF PATCH, LRS PERFORMED PASSING MIT-T TO 2500#AND PASSING CMIT IAxT TO 2500#, EQUALIZED AND PULLED TEST TOOL FROM PATCH, PULLED DMY VLV FROM ST#1 © 3038' RKB, PULLED DMY VLV FROM ST#4 @ 5891' RKB. ***CATCHER IN WELL***JOB IN PROGRESS. LRS PERFORM MIT-T TO 2500#. PRE: 250/0/390/250 INITIAL 2550/0/395/250 0.2 BBLS TO PRESSURE UP. 15 MIN: 2200/0/395/350 FAIL. EQUALIZE FL DUE TO LEAKY WV. ATTEMPT AGAIN. PRE: 2000/0/395/400(FL) INITIAL: 2500/0/395/2500(FL) 15 MIN: 2400/0/395/2275(FL) 30 MIN: 2375/0/395/2200(FL) PASS LOAD IA& PERFORM CMIT IAxT TO 2500#. PRE: 2275/0/395/2175(FL) INITIAL: 2500/2500/407/2300(FL) 36 BBLS TO LOAD AND PRESSURE UP. 15 MIN: 2500/2375/406/2300(FL) 30 MIN: 2450/2350/405/2300(FL) Summary A tubing leak at 6293'was identified during a routine PPROF log. A 29'Weatherford retrievable patch was installed from 6265'-6294'. Patch integrity was established with a passing MITT against the top packer and passing CMITs that tested the bottom packer and then the tubing. .. fi •KUP PROD • 2N-303A ConocoPhillips ( " Well Attributes Max Angle&MID TD Alaska,Inc. 1 Wellbore APIIUWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) cn,a,,,,,,,ps , 501032035201 TARN PARTICIPATING AREA PROD 43.73 3,246.81 7,093.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 2N.303A,8/720157:49:51 AM SSSV:NIPPLE 25 3/13/2015 43.12 11/18/2000 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ......................................................... Last Tag:SLM 6,750.0 7/9/2015 Rev Reason:RE-SET PATCH,GLV C/O,ADD hipshkf 8/6/2015 HANGER;30.1-----,raY��� FISH Casing Strings -^^•••••••••^••^••••••••••••••••••••••••••••^••••••••^ . Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread CONDUCTOR 30" 16 15.062 35.0 140.0 62.50 H-40 WELDED Insulated Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread ••••••••••••••••••••••••••-•••-•••••••••••••••••----- . [I�- --••SURFACE 75/8 6.875 34.5 2,632.1 2,297.0 29.70 L-80 BTCM Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread PRODUCTION 51/2 4.890 32.4 7,088.7 5,748.5 15.50 L-80 HYD563 ,. , . ., ....1"'^ -alae. Tubing Strings HI Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(/blit) Grade Top Connection TUBING 31/2 2.992 30.1 6,722.21 5,456.1 9.30 L-80 EUE8rd CONDUCTOR 30"Insulated; '�� 35.0-1400 Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) NIPPLE;515.0 30.1 HANGER FMC GEN V IBTM TUBING HANGER 2.992 515.0 NIPPLE CAMCO DS NIPPLE 2.875 6,497.1 5,280.1 38.40 SLEEVE-C BAKER CMU SLIDING SLEEVE w/2.812"DS Profile- 2.812 CLOSED 6,5792 5,344.3 38.71 SEAL ASSY BAKER 80-40 LOCATOR SEAL ASSY.Locator 2 off 2.930 Fully Located 9.76'U Seal Assy.tubing tail 6,582.2 5,346.6 38.71 PBR BAKER PBR 4.010 6,595.8 5,357.3 38.69 ANCHOR BAKER K ANCHOR 3.000 SURFACE;34.5-2,632.1 6,596.3 5,357.6 38.69 PACKER BAKER"FA"PERMANENT PACKER 3.000 16,610.0 5,368.4 38.68 SLEEVE-0 SLB PCV SLIDING SLEEVE(DOWN TO OPEN)2.813"X 2.813 PROFILE GAS LIFT;3,037.6 c 6,697.2 5,436.5 38.49 ANCHOR BAKER KBH-22 ANCHOR SEAL ASSEMBLY(tied into 3.000 lower FA-1 Packer) 6,697.9 5,437.0 38.49 PACKER 'BAKER 3.5"x 5.5""FA"PERMANENT PACKER 3.000 6,710.1 5,446.5 38.43 NIPPLE LANDING"D"NIPPLE 2.75"ID 2.750 GAS LIFT;4,327.0 I 6,721.3 5,455.3 38.37 SOS WLEG SHEAR OUT SUB 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl Top(ftKB) (ftKB) (°I Des Com Run Date ID(in) GAS LIFT;5,247.8 ••. 6,265.0 5,098.7 38.75 UPPER WFD WIDEPAK LE PACKER(CAL 5.4') 8/3/2015 1.750 • • PACKER 11/ • 6,270.4 5,102.9 38.70 PATCH SPACER PIPE(OAL=24') 8/3/2015 1.750 6,294.4 5,121.7 38.49 LOWER WFD WIDEPAK LE PACKER(OAL 5.2')W/ 8/3/2015 1.750 •;l PACKER WIDEPAK SNAP LATCH SEAL ASSY(OAL=.9') GAS LIFT;5,890.7 C4: 6,711.0 5,447.3 38.43 FISH FISH-APPROX 3"x4"x1/2"RUBBER PIECE(HALF 8/1/2015 {■ OF A WED WIDEPAK LE ELEMENT).LOCATED @TD OF 6711'SLM. ' ., .._ Perforations&Slots UPPER PACKER;6,265.0 t, a Shot PATCH;6,270.4 ill -�: �l��1,;. Top(NDens D) Btm(TVD) (shots/f LOWER PACKER;6,294.4Ip- Top(ftKB) Btu(ftKB) (ftKB) (WKB) Zone Date t) Type Corn :. 6,612.0 6,632.0 5,369.9 5,385.5 S-3,2N-303 9/10/2014 6.0 IPERF 6 SPF 60 Deg Phase; Millennium Charges '� , 6,725.0 6,740.0 5,458.2 5,470.0 S-3,2N-303 9/10/2014 6.0 IPERF 6 SPF 60 Deg Phase; GAS UFT;6.378.5 ?_ .e} Millennium Charges Stimulations&Treatments Min Top Max Btm Depth Depth Top(TVD) Btm(TVD) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Corn SLEEVE-C;6,497.1 J 6,612.0 6,632.0 5,369.9 5,385.5 FRAC 9/29/2014 BERMUDA FRAC,226,343 8 16/20 CARBOLITE 6,725.0 6,740.0 5,458.2 5,470.0 FRAC 9/26/2014 PURPLE FRAC 230,260 6 1620 CARBOLITE Mandrel Inserts St SEAL ASSY;6,579.2 •1-�-�,� on Top(ND) Valve Latch Port Size TRO Run PBR;6,582.2 'WO r N Top(ftKB) (ftKB) Make Model OD(In) Sery Type Type (In) (psi) Run Date Corn 51„ iib "( 3,037.7 2,598.8 CAMCO KBG-2- 1 GAS LIFT GLV Integra 0.188 1,639.0 8/4/2015 DK- ANCHOR;6,595.8 9 I 1A: PACKER;6,596.2 •)'. 10:00 2 4,327.0 3,586.1 CAMCO KBG-2- 1 GAS LIFT DMY Integra 0.000 0.0 9/15/2014 DK- • 9 I 1A; SLEEVE-0;6,610.0 3:00 FRAC' 6612.0 iI 3 5,247.8 4,317.6 CAMCO KBG-2- 1 GAS LIFT DMY Integra 0.000 0.0 9/15/2014 DK- IPERF;6,612.0-6,632.01. 9 I 1A, 6:30 4 5,890.7 4,811.9 CAMCO KBG-2- 1 GAS LIFT OV Integra 0.313 0.0 8/4/2015 DK- 9 I 1A, 1:00 ANCHOR;6,697.2 ;,;'aur 5 6,378.5 5,187.3 CAMCO KBG-2- 1 GAS LIFT DMY Integra 0.000 0.0 7/8/2015 5:00 PACKER;6,697.8 `. 9 I Notes:General&Safety End Date Annotation NIPPLE;6,710.1 8/12/2014 NOTE:SIDETRACK WELL • FISH;6,711.0 (' SOS;6.721.3 - <, FRAC;6,725.0 . IPERF;6,725.0.6,740.0 PRODUCTION;32.4-7,086.7- ' • 21 4088 25980 WELL LOG TRANSMITTAL DATA LOGGF1 M / /2015 "�K ENDEF, To: Alaska Oil and Gas Conservation Comm. June 17, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 JUN 19 NIL RE: Production Profile: 2N-303A Run Date: 6/6/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2N-303A Digital Data in LAS format, Digital Log Image file, Interpretation Report 1 CD Rom 50-103-20352-01 Production Profile Log a) ``j 1 Color Log 50-103-20352-01 sCO° PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS ANC@halliburton.com Date: Signed: �il�-h�ry 6.e,i_eeet Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ci, i 14. _ 0gii Well History File Identifier Organizing(done) ❑ Two-sided ❑ Rescan Needed RE CAN: OVERSIZED: NOTES: C for Items: E/Maps: Grayscale Items: Logs: ❑ Poor Quality Originals: E Other: ❑ Other: BY: C2.a.-i.a Date: raptf cc /s/ 01 p Project Proofing BY: deft Date: _ i 61/5— /s/ VV1 f Scanning Preparation x 30 = go + / (c. = TOTAL PAGES (Count does not include cover sheet) BY: 411ES Date: .015115— Is/ Production Scanning Stage 1 Page Count from Scanned File: / ©7 (Count does include cover eet) Page Count Matches Number in Scanning Preparation: YES Pip NO 5'BY: 410, Date: IS' /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: 10 NO TOTAL PAGES: Digital version appended by: Meredith A A iI Michal1 MDate: 24/15 /s/ • Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: I,CPg/ Scanning is complete at this point unless rescanning is required. 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Q rn 0 0 0> V) O J a C J m 7 n v E 0o. 'a 2 U Om 0 oC1l, o Cl) r y N O N a co O V N M U I o c ( } , - E c oJ M v _ 0 Q N o O I N V z O E O 5r N 1 co co 1 C H CD > °� co p aa) E II rn 5 0 1— E 1 A Qp N c a� c co O a o o 1111 Y 15 1c c a Q c a ° m O 1 G m Z E 0 a) a) c 0 o 2 E co z m v v 3 • O c ar) co NNo7 to e >_ c , ,_ E iT co 0 _ E E F. A p O N w m coS c oel cc) o d Z Q o o 0 Z c CO 0 c 1 c c.) N 2 •� v . .� a) a o �o v E c) O Q v o O. o 0 E a o p rn — LL E 2 o E o To d E E d a 2o 3 z 0 a c7 0 0 0 v c2/4/-00 02C 33 Catherine Roso liP.� WNS Development ConocoPh i I I i ps NorthSlope Operations and Development Post Office Box 100360 Anchorage,Alaska 99510-0360 Phone: (907)265-6189 Fax(907)265-6715 January 29, 2015 Hand Carry Alaska Oil and Gas Conservation Commission Attention: Ms. Makana Bender 333 West 7th Ave, Suite 100 Anchorage, AK 99501 RE: 2N-303A, PERMIT NUM: 214-088, API# 501032035201 Paper and Electronic copies of logs Please find attached a paper copy of the following logs for final distribution: 2N-303A_Correlation_11 SEP2014 (PACKER CORRELATION) - C2 f 3 _ in_I - _ Pe , 9 _ - _ _ • ITY)- CONOCO_2N_303A_PERFORATION_10SEPT2014 (PERFORATION RECORD) - 2ifct3.3 Please find attached a CD with all electronic versions of the previous listed logs. Please sign and return transmittal to me at Catherine.Rosoconocophillips.com Sincerely, S RECEIVED JAN 3 0 Z01 Catherine Roso ACOGIGO Catherine.Roso©conocophillips.com Geoscience Support Technician WNS Subsurface Development Team ATO-1707 Anchorage, AAOGCC Received +1 907-265-6161 89 Proof of Receipt ONLY SIGN FOR RECIEPT: Pte. DATE: 24)//5 -2,5044,s ConocoPhillips TRANSMITTAL CONFIDENTIAL DATA DATA LOGGED / /201 d K.BENDER FROM: Sandra D. Lemke,AT03-0340 TO: Makana Bender ConocoPhillips Alaska, Inc. AOGCC P.Q. Box 100360 333 W. 7th Ave., suite 100 Anchorage AK 99510-0360 Anchorage,Alaska 99501 RECEIVED RE: 2N-303A NOV 0 6 2014 DATE: 11/04/2014 Transmitted: AOGCC Kuparuk River Unit, Alaska 2N-303A 1 CD and 1 hardcopy report CANRIG Final well report mud logging data for 2N-303A; 9/312014; table of contents, mud logging equipment; general well details, geologic data, pressure/formation strength, drilling data, show reports, daily reports and formation logs; color log presentations, one set each for wellbore Formation log MD&TVD Gas ratio MD&TVD � n Combo log MD&TVD Drilling dynamics MD&TVD CD contains daily reports, DML data,final well report, LAS files, Log PDF files, remarks, TIFF files, show report Please promptly sign, scan and return electronically to Sandra.D.Lemke000P.com CC: 2N-303A transmittal folder, production well files, eSearch Recei :--- �E�tiu ------ — ate: 7► ', ` GI5-Technical Data Management I ConocoPhillips !Anchorage, Alaska I Ph; 907.165.6947 STATE OF ALASKA RECEIVED o i-!' KA OIL AND GAS CONSERVATION COMIuii6SION REPORT OF SUNDRY WELL OPERATIONS OCT 2 8 2014 1 Operations Performed Abandon r Repair w ell r Rug Perforations r Perforate r Other AOGCC Alter Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extension r Change Approved Program rOperat. Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number. ConocoPhillips Alaska, Inc. Development p' Exploratory r 214-088-0 3.Address: 6 API Number: Stratigraphic r Service r P. O. Box 100360,Anchorage,Alaska 99510 50-103-20352-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 380054,380053 102,0 2N-303A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): none Kuparuk River Field/Tarn Oil Pool 11.Present Well Condition Summary: Total Depth measured 7093 feet Plugs(measured) 6710 true vertical 5747 feet Junk(measured) none Effective Depth measured 6967' feet Packer(measured) 6596,6698 true vertical 5644 feet (true vertical) 5358, 5437 Casing Length Size MD ND Burst Collapse Conductor 97' 16" 140' 140' Surface 2589' 7.625" 2632' 2298 Production 7056' 5.5" 7089' 5749' Perforation depth: Measured depth: 6612'-6632',6725-6740' True Vertical Depth: 5370'-5386', 5458'-5470' Tubing(size,grade,MD,and ND) 3.5, L-80,6722 MD, 5456 TVD Packers&SSSV(type,MD,and ND) PACKER-BAKER'FA'PERMANENT PACKER @ 6596 MD and 5358 TVD PACKER-BAKER'FA'PERMANENT PACKER @ 6698 MD and 5437 ND NIPPLE-CAMCO DS NIPPLE @ 515 MD and 515 ND 12.Stimulation or cement squeeze summary. Intervals treated(measured) 6612--6632'and 6725-6740'MD Treatment descriptions including volumes used and final pressure: Bermuda frac: 226343#of 16/20 carbolite Purple frac: 230260#of 16/20 carbolite 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation shut-in Subsequent to operation shut-in 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service r Stratigraphic r 16.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations XX GSTOR r WIND 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. 314-522 Contact Adam Klem a,263-4529 Email Adam.Klem@conocophillips.com Printed Name dam Klem Title Sr. Completions Engineer Signature Phone:263-4429 Date VL /a/;v /14 ABC MS OCT 2 8 201 Form 10-404 Revised 10/2012 Submit Original Only KUP PROD 2N-303A 1 ConotoPhillips , s Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/U WI Field Name Wellbore Status ncl(") MD(ftKB) Act Mtn(ftKB) rm.4,,,6Nn 50103203520100 TARN PARTICIPATING AREA PROD 43.73 3,246.81 7,093.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(It) 'Rig Release Date 2N-303A,10/1020147:59:08 AM SSSV:NIPPLE 35 1/14/2010 43.12 11/18/2000 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag Rev Reason:SIDETRACK,ADD FRAC,SET haggea 10/3/2014 HANGER.30 i. ._'[" PLUG,GLV C/O Casing Strings L - Casing Description CONDUCTOR 30" OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread 16 15.062 35.0 140.0 62.50 H-40 WELDED Insulated Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread "�}'1� SURFACE 75/8 6.875 34.5 2,632.1 2,297.0 29.70 L-80 BTCM 7., .. [�7 ---Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread JJ[YJJ PRODUCTION 512 4.890 32.4 7,088.7 5,748.5 15.50 L-80 HYD563 Tubing Strings Tubing Description String Ma...ID lint Top(ftKB) Set Depth Ill...Set Depth(ND)I,..Wt(Ib/fl) Grade Top Connection TUBING 31/2 2.992 Top(MB) Top(TVD)(MB) Top Ind(*) 30.1 6.722.2 5.456.1 9.30 L-80 EUEBrd Completion Details �^CONDUCTOR 30'Insulated, Nominal ID 35.0.140 0 Item Des Com (in) 30.1 HANGER FMC GEN V IBTM TUBING HANGER 2992 515.0 NIPPLE CAMCO DS NIPPLE 2.875 NIPPLE:515.0 !E.. 6,497.1 5,280.1 38.40 SLEEVE-C BAKER CMU SLIDING SLEEVE w/2.812"DS Profile- 2.812 CLOSED • •• 6,5792 5,344.3 38.71 SEAL ASSY BAKER 80-40 LOCATOR SEAL ASSY.Locator 2'off 2.930 • Fully Located 9.76'V Seal Assy.tubing tail • 6,5822 5,346.6 38.71 PBR 'BAKER PBR 4.010 l 6,595.8 5,357.3 38.69 ANCHOR BAKER K ANCHOR 3.000 6,596.3 5,357.6 38.69 PACKER BAKER"IA"PERMANENT PACKER 3.000 ' 6,610.0 5,368.4 38.68 SLEEVE SLB 3.5"SLIDING SLEEVE(Opened-9/28/14) 2.813 SURFACE;34.52.632.1 6,697.2 5,436.5 38.49 ANCHOR BAKER KBH-22 ANCHOR SEAL ASSEMBLY(tied into 3.000 lower FA-1 Packer) 6,697.9 5,437.0 38.49 PACKER BAKER 3.5"x 5.5""FA"PERMANENT PACKER 3.000 GAS LIFT;3,037.6 6,710.1 5,446.5 38.43 NIPPLE LANDING"D"NIPPLE 2.75"ID 2.750 6,721.3 5,455.3 38.37 SOS WLEG SHEAR OUT SUB 2.992 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl GAS LIFT;4,327.0 Top(ftKB) _ (ftKB) (°) Des Com Run Date ID(in) 6.710.0 5,446.5 38.43 PLUG SET 2.75"CA-2 PLUG 9/27/2014 0.000 Perforations&Slots I Shot Dens Top(TVD) Btm(TVD) (shots# GAS LIFT:5,247.6 Top(11KB) Blur MKB) (fIKB) (ftKB) Zone Date t) Type Corn 6,612.0 6,632.0 5,369.9 5,385.5 S-3,2N-303 9/10/2014 6.0 IPERF 6 SPF 60 Deg Phase; Millennium Charges i. 6,725.0 6,740.0 5,4582 5,470.0 S-3,2N-303 9/10/2014 ' 6.0 IPERF 6 SPF 60 Deg Phase; Millennium Charges GAS UFT,5,890 7 Stimulations&Treatments Min Top Max etm Depth Depth Top(ND) Btm(ND) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Com 4, 6,725.0 6,740.0 5,458.2 5,470.0 FRAC 9/26/2014 PURPLE FRAC 230,260#16/20 CARBOLITE / 6,612.0 6,632.0 5,369.9 5,385.5 FRAC 9/29/2014 BERMUDA FRAC,226,343#16/20 CARBOLITE 5 Mandrel Inserts GAS LIFT;6,37e „E: St 4 ati on Top(TVD) Valle Latch Port Size TRO Run N Top(ftKB) p(B) Make Model OD(in) Sere Type Type (in) (psi) Run Date Corn 1 3,037.7 2,598.8 CAMCO KBG-2- 1 GAS LIFT DMY Integra 0.000 0.0 9/15/2014 DK-1A 9 I SLEEVE-C;6,4971 _ 2 4,327.0 3,586.1 CAMCO KBG-2- 1 GAS LIFT DMY Integra 0.000 0.0 9/15/2014 DK-1A 9 I 3 5,247.8 4,317.6 CAMCO KBG-2- 1 GAS LIFT DMY Integra 0.000 0.0 9/15/2014 DK-1A 9 I 4 5990.7 4,811.9 CAMCO KBG-2- 1 GAS LIFT DMY Integra 0.000 0.0 9/15/2014 DK-1A SEAL ASSY;6,579.2 9 5 6,378.5 5,187.3 CAMCO KBG-2- 1 GAS LIFT DMY Integra 0.000 0.0 9/18/2014 PBR;6,5822 T_.._-T'. 9 I ANCHOR;6,595.8 •{ ; i Notes:General&Safety PACKER;6,596.2 End Date Annotation 8/12/2014 NOTE:SIDETRACK WELL •l. i SLEEVE:6,610.0 `I FRAC;6,612.0 -- IPERF;6.6120-6,632.0 ANCHOR;6.697,2 :, PACKER;6.6978 PLUG;6.7100 �� NIPPLE;6,710.1, ,fit:: SOS;6,721.3 IPERF;6.7 .B'6.740 5 00, 1` FRAC;6 . i •: F PRODUCTION;32.4.7,088.7 • 2N-303A FRAC SUMMARY DATE SUMMARY 9/18/2014 TAGGED TD © 6932' SLM; SET 2.75" CA-2 PLUG @ 6710' RKB; SET BAITED PULLING TOOL © SAME; PULLED SOV& SET DV @ 6379' RKB. MIT-T (PASSED). MIT-IA (PASSED). PULLED BAITED PULLING TOOL& PRONG @ 6710' RKB. PULLED 2.75" CA-2 PLUG BODY @ SAME. READY FOR FRAC. 9/26/2014 Performed fracture stimulation of the Purple formation placing 230,260# (100% design) 16/20 CarboLite, 2320-bbl total volume, 25# linear and x-link gel. 9/27/2014 BRUSH n' FLUSH & DRIFTED TBG W 2.785" G-RING DOWN TO D-NIPPLE © 6710' RKB. SET 2.75" CA-2 PLUG @ SAME. MIT TBG TO 4000 PSI (PASSED); SET BAIT SUB W/PULLING TOOL @ 6705' RKB. ATTEMPTED SHIFT SLEEVE @ 6610' RKB OPEN (APPEARS TO BE PARTIALLY OPEN). IN PROGRESS. 9/28/2014 VERIFIED SLEEVE OPEN @ 6610' RKB; PUMPED 3 BBLS @ 2 BPM W/ 2750 PSI ON TBG. READY FOR BERMUDA FRAC. 9/29/2014 Performed fracture stimulation of the Bermuda formation placing 227,500#(100% design) 16/20 CarboLite, 2290-bbl total volume, 25# linear and x-link gel. 10/7/2014 PERFORMED FILL CLEANOUT FROM 6290' CTMD, TO A HARD TAG AT 6692' CTMD PUMPING SLICK DIESEL AND DIESEL GEL SWEEPS, HEAVY FRAC SAND CONSENTRATIONS OBSERVED,EST. 3.5 BBLS OF SOLIDS, RUN #2 CLOSED THE CMD AT 6610' RKB, PERFORMED A PASSING MITT, JOB IN PROGRESS. 10/8/2014 PERFORM WEEKLY BOP TEST, RIH TO SHIFT CLOSED CMU @ 6505' CTMD, PRESSURED UP TO 3000 PSI TO CONFIRM CLOSED, RIH TO RECOVER CATCHER SUB AND PRONG AT 6700' CTMD, JOB IN PROGRESS 10/9/2014 FIRST ATTEMPT TO PULL CA-2 PLUG FAILED, UNABLE TO LATCH, PERFORMED FCO TO THE TOP OF THE CA-2 PLUG AT 6710' RKB, RECOVERED CA-2 PLUG ON SECOND ATTEMPT AT 6710 RKB, WELL LEFT F/P TO 6600' CTMD, JOB IN PROGRESS. 10/12/2014 PERFORMED FILL CLEANOUT FROM 6730' CTMD TO HARD TAG AT 6965' CTMD PUMPING SLICK DIESEL AND DIESEL GEL SWEEPS AT 2 BPM (EST. 225' OF RATHOLE) MAINTAINED 1:1 RETURNS THROUGHOUT CLEANOUT. MODERATE SOLIDS CONCENTRATIONS OBSERVED. EST TOTAL SOLIDS VOLUME AT 3.4 BBLS, F/P ENTIRE TBG WITH SLICK DIESEL, READY FOR SLICKLINE, JOB COMPLETE. 10/14/2014 TAGGED FILL @ 6987' SLM; SET 2.75" CAT SV @ 6710' RKB; PULLED DV& SET GLV @ 3037' RKB, PULLED DV& SET OV @ 6379' RKB; PT TBG TO 1500 PSI (PASSED). PARTED WIRE WHILE TRYING TO PULL CAT SV FISH @ 6710' RKB; DEPLOYED 5' OF 1 7/8 ROLLER STEM W/2.30 BLIND BOX ((FISH IN HOLE= EST. 6838'WIRE, 28' OF 1 7/8 TOOL STRING W/MAX OD 2.75 © GR, & 5' STEM W/2.30 BLIND BOX)) . IN PROGRESS 10/15/2014 FISHED 6838' OF .108 WIRE, 5' RLR STEM w/2.30" BLIND BOX @ 6676' SLM, & 28'x 1875"TOOL STRING W/CAT SV @ 6683' SLM; SET 2.75" CAT SV @ 6710' RKB & PULLED 1" OV @ 6379' RKB. (LEFT LRS ON LOCATION TO CIRC OUT 130 BBLS OF DIESEL) IN PROGRESS 10/16/2014 SET OV @ 6379' RKB; TEST TBG TO 1500 PSI (GOOD TEST) & PULLED 2.75" CAT SV @ 6710' RKB. JOB COMPLETE RE( `LVED 2o(2 OCT 24 ?Om SchlumbergerAOGC Drilling & Measurements Transmittal #: 200CT14 NG01 MWD/LWD LogProduct DeliveryDATA LOGGED o rzs6i2oi M.K.BENDER Customer: ConocoPhillips Alaska Dispatched To: Makana Bender Well No: 2N-303A Date Dispatched: 20-Oct-14 Job#: 14AKA0129 Dispatched By: Nathan Green Well / Product Description Hardcopy Digital Copy E-Delivery Date Color Log Prints: 5 Contents on CD N/A VISION* Resistivil 2" MD x x VISION*Resistivil 2"TVD x x VISION* Resistivil 5"MD x x VISION* Resistivil 5"TVD x x VISION* Resistivil 2"TVDSS x x LAS Digital Data N/A Contents on CD N/A x Directional Data 1 Contents on CD N/A Nad27 x x As-Built Survey 1 Contents on CD N/A Nad83 x x EOW CD 1 Contents on CD N/A Data: DLIS /ASCII x Please sign and email a copy to: Please sign and email/fax a copy to: iifesie@slb.com spacilloO,slb.com Stephanie Pacillo lfeanyi Ifesie Fax: 907-561-8317 907-265-651 ATO 1525 N MAtga42eAd(/) Received By: � � 1pp (pp pp �p �pp1 ^ el I ]e �.,0m N 100r,moa OO���NNf00 f8p0g0OpMiOe�t 282 pp1pp1118'41p yVy NO1np11�� i OmiNOO2 V V 11a 2011Mpp1110f�p1(1pp� O N q(�NgC1NNN 001010{p m)Q N 0000000/W O W W mO W h l�r 0i0 N p N N N N N N N N N N N N lV N N N N N N N c 0 b 0 0 0 0 0 0 0 0 0 0 0 0 0 0 010 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 N N N 0 0 0 0 0 c1 O J M 0 M M M M M M M M M M M M M M M M 0 M M M N M�M M M M M M M M M M M M M M M MMMM M M m OOOoOCO0000G000000NW0W0Wp0Wp0NN000N0pNpp00N hmmmm0m000N010 0 NN0WNm00W000 ` Ld . , . . . . , • , ' ' ' ' ' ' , , , ' , 1 ' 1 ' , , , , , ' ' ' . . 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N Y E u o 4o g Eg 'e 0 wa O 0O T 0.> mC VNcoY 0 a NU h0 4 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. October 15, 2014 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 DATA LOGGED Anchorage, Alaska 99501 O� 0 ` i.%/201 ;v1.K.BENDER RE: Triple Combo w/XRMI: 2N-303AU. Run Date: 9/6/2014 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Chris Gullett, Halliburton Wireline&Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 6 2N-303A Log Data in LAS/DLIS format, Digital Log Image files 1 CD Rom 50-103-20352-01 Array Comp. Resistivity, Spectral Density, Dual Spaced Neutron (2" & 5") 1 Color Log ea. 50-103-20352-01 XRMI Field Log and Processed Image (1:20 & 1:240) 1 Color Log ea. 50-103-20352..701 Borehole Volume Plot 1 Color Log 50-103-20352-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE A'11'ENTION OF: Halliburton Wireline&Perforating Attn: Chris Gullett 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3527 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: fi).,./.....,(1) `���"""C RECEIVED STATE OF ALASKA OCT 1 3 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ANIACOLC la Well Status: Oil E , Gas El SPLUG ❑ Plugged ❑ Abandoned El Suspended El lb.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑✓ • Exploratory ❑ GINJ El WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No.of Completions: Service ❑ StratigraphicTest❑ 2 Operator Name 5.Date Comp,Susp, 12 Permit to Drill Number. ConocoPhillips Alaska, Inc. • or Aband.: September 15,2014 214-088/, 3.Address' 6.Date Spudded 13 API Number: P.O. Box 100360,Anchorage,AK 99510-0360 August 31,2014 50-103-20352-01 4a.Location of Well(Governmental Section) 7.Date TD Reached 14 Well Name and Number: Surface: 5179'FNL,500'FEL,Sec 34,T1ON, R7E, UM September 3,2014 2N-303A Top of Productive Horizon 8. KB(ft above MSL): 150'RKB 15.Field/Pool(s) 2341'FNL, 1494'FWL,Sec.35,T1ON, R7E, UM GL(ft above MSL): 120'AMSL Kuparuk River Field- Total Depth: 9.Plug Back Depth(MD+TVD): 2117'FNL, 1681'FWL,Sec.35,T1ON, R7E, UM 6967'MD/5644'TVD • Tarn Oil Pool- 4b Location of Well(State Base Plane Coordinates,NAD 27): 10 Total Depth(MD+TVD) 16.Property Designation Surface: x-461093 y- 5912007 Zone-4 7093'MD/5747'TVD • ADL 380054,380053- TPI: x-463098 y- 5914935 Zone-4 11.SSSV Depth(MD+ND). 17.Land Use Permit Total Depth: x-463286 y- 5915158 Zone-4 nipple @ 515'MD/515'ND 4602,4601 18 Directional Survey. Yes El, No El 19.Water Depth,if Offshore: 20 Thickness of Permafrost MDIND: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1242'MD/1204'TVD 21 Logs Obtained(List all logs here and submit electronic and printed information per 20 AAC 25 071). 22 Re-drill/Lateral Top Window MD/TVD GR/Res, Neutron, Density _ 2752'MD/2382'ND• _ 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.58# H-40 35' 140' 35' 140' 24" 9 cu yds High Early 7.625" 29.7# L-80 35' 2632' 35' 2298' 9.875" 448 sx AS III Lite,240 sx CI G,60 sx AS I 5.5" 15.5# L-80 32' 7089' 32' 5749' 7.5" 164 sx LiteCRETE,65 sx Class G 24.Open to production or injection? Yes El 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" 6722' 6596'MD/5358'ND, 6612'-6632'MD 5370'-5386'ND 6698'MD/5437'ND 6725'-6740'MD 5458'-5470'ND 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. aidWas hydraulic fracturing used during completion? Yes No Q 1/F 'F j_j? DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED -- ... 4222'-5750'cement plug 31 bbls of 15.8#Class G 5750'-6234'cement plug 24 bbls of 15.8#Class G 6224'cement retainer 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc) 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 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+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed) Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25 071. NONE RBS'MF OCT 13 20`1 Form 10-407 Revised 10/2012frT` `/1/i i.5— CONTINUED ON REV��GG ;KZi 1114 (� Submit original only n 29 GEOLOGIC MARKERS(List all formations and mai,._._encountered): 30 FORMATION TESTS NAME MD TVD Well tested? Yes ❑✓ 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 1242' 1204' needed,and submit detailed test information per 20 AAC 25 071. Campanian Sand 2979' 2556' C-37 5191' 4274' Iceberg 5428' 4458' Top Bermuda 6540' 5314' Base Bermuda 6646' 5397' Top Purple 6677' 5422' Base Purple 6765' 5490' N/A Formation at total depth: Bermuda 31 LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final Directional survey, cement detail sheets 32 I hereby certify that the foregoing is true and correct to the best of my knowledge. aM.S Contact: Steve Shultz @ 263-4297 Email Steve.Shultz(a)contractor.conocobhillios.com Printed Name /GGA.. L.Alvord Title. Alaska Drilling Manager Signature Phone 265-6120 Date tON IZOf`1- _ 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 10/2012 KUP PROD 2N-303A ConocoPhillips ® Well Attributes Max Angle&MD TD • Alaska,Inc. Wellbore APIIUWI Field Name Wellbore Status ncl IT MD(ftKB) Act Btm(ftKB) r rmnYNillipr 50103203520100 TARN PARTICIPATING AREA PROD 43.73 3,246.81 7,093.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) `Rig Release Date 25-3034,10/7/20149.11.14 AM SSSV:NIPPLE 35 1/14/2010 43.12 11/18/2000 - Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:SIDETRACK,ADD FRAC,SET haggea 10/3/2014 • .........HANGER;30.1- _j PLUG,GLV C/0 Casing Strings ....................................._..._.............................. I Casing Description CONDUCTOR 30" OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WVLen(I...Grade Top Thread 16 15.062 35.0 140.0 62.50 H-40 WELDED Insulated Casing Description OD(in) ID lin) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WVLen(I...Grade Top Thread SURFACE 7 5/8 6.875 34.5 2,632.1 2,297.0 29.70 L-80 BTCM 't F,"""""Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread • PRODUCTION 5 1/2 4.890 324 7,088.7 5,748.5 15.50 L-80 HYD563 Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(tt..Set Depth(ND)1...Wt(Ibtft) Grade Top Connection TUBING I 31/21 2.9921 30.11 6,722.2 5,456.11 9.301 L-80 1EUE8rd ICompletion Details ��•CONDUCTOR 30"Insulated: II . III Nominal ID 35.0.140.0 Top(ftKB) Top(TVD)(ftKB) Top Incl 1°) Item Des Corn (in) 30.1 HANGER FMC GEN V IBTM TUBING HANGER 2.992 515.0 NIPPLE CAMCO DS NIPPLE 2.875 NIPPLE;515.0 T( 6,497.1 5,280.1 38.40 SLEEVE-C BAKER CMU SLIDING SLEEVE w/2.812"DS Profile- 2.812 CLOSED 6,5792 5,344.3 38.71 SEAL ASSY BAKER 80-40 LOCATOR SEAL ASSY.Locator 2'off 2.930 Fully Located 9.76'U Seal Assy.tubing tail 6,582.2 5,346.6 38.71 PBR BAKER PBR 4.010 6,595.8 5,357.3 38.69 ANCHOR BAKER K ANCHOR 3.000 6,596.3 5,357.6 38.69 PACKER BAKER"FA"PERMANENT PACKER 3.000 6,610.0 5,368.4 38.68 SLEEVE SLB 3.5"SLIDING SLEEVE(Opened-9/28/14) 2.813 SURFACE;34.5-2,632.1 6,697.2 5,436.5 38.49 ANCHOR BAKER KBH-22 ANCHOR SEAL ASSEMBLY(tied into 3.000 lower FA-1 Packer) 6,697.9 5,437.0 38.49 PACKER BAKER 3.5"x 5.5""FA"PERMANENT PACKER 3.000 GAS LIFT;3.037.6 : 6,710.1 5,446.5 38.43 NIPPLE LANDING"D"NIPPLE 2.75"ID 2.750 6,721.3 5,455.3 3837 SOS WLEG SHEAR OUT SUB 2.992 111'1 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl GAS LIFT;4,327.0 4 Top(ftKB) (ftKB) I (°) I Des I 9/27/2014 Com I Run Date I ID 0(in).000 6,710.0 5,446.5 38.4311 PLUG SET 2.75"CA-2 PLUG Perforations&Slots • Shot Dens GAS LIFT;5,247.8 , II: To ftKB Bhn(ftKB) Top B) Btm(TVD) (shtI P(ftKB) ( 1 1�8) rytKel Zone Date tl Type tom 6,612.0 6,632.0 5,369.9 5,385.5 S-3,2N-303 9/10/2014 6.0 IPERF 6 SPF 60 Deg Phase; Millennium Charges 6,725.0 6,740.0 5,458.2 5,470.05-3,2N-303 9/10/2014 6.0 IPERF 6 SPF 60 Deg Phase; 419 Millennium Charges GAS LIFT;5,890.7 Stimulations&Treatments Min Top Max Btm Depth Top(ND) Btm(ND) (ftKB) (ftKB) (ftKB) (ftKB) Type Date Corn 6,725.0 6,740.0 5,458.2 5,470.0 FRAC 9/26/2014 PURPLE FRAC 230,260 8 16/20 CARBOLITE 6,612.0 6,632.0 5,369.9 5,385.5 FRAC 9/29/2014 BERMUDA FRAC,227,500 8 16/20 CARBOLITE GAsuFr;6a7e.e IDepth Mandrel Inserts St ati on Top(ND) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com fi 3,037.7 2,598.8 CAMCO KBG-2- 1 GAS LIFT DMY Integra 0.000 0.0 9/15/2014 DK-1A 9 I SLEEVE-C;6,497.1 I 2 4,327.0 3,586.1 CAMCO KBG-2- 1 GASLIFT DMY Integra 0.000 0.0 9/15/2014 DK-1A 93 5,247.8 4,317.6 CAMCO KBG-2- 1 GAS LIFT DMY Integra 0000 0.0 9/15/2014 DK-1A 4 5,890.7 4,811.9 CAMCO KBG-2- 1 GAS LIFT DMY Integra' 0.000 00 9/15/2014 DK-1A SEAL ASSY;6,579.2 • 9 I L- '' 5 6,378.5 5,187.3 CAMCO KBG-2- 1 GAS LIFT DMY Integra 0.000 0.0 9/18/2014 PBR;6,582.2 9 I ANCHOR;6.595.8 '.li`� I Notes:General&Safety PACKER;6,5962 -; End Date Annotation 8/12/2014 NOTE:SIDETRACK WELL SLEEVE;6.6100 .I..-: FRAC;6.612.0 IPERF;6,612.06,632.0 ANCHOR;6.697.2 '-�i.9N". , PACKER;6.698 'I 7 I 6, ., '. NIPPLE;PLUG;6.717100.10 4�.,:: 1111 SOS;6,721.3 r 1' IPERF;6,725.06,740.0 i. FRAC;6,725.5 �_ .,I .I I PRODUCTION;324-7.088.7- . 2N-303 PRE-RIG WELL SUMMARY • DATE SUMMARY 9/11/2013 GAUGED TBG TO 2.78"TO PLUG @ 6250' RKB. PULLED CA-2 PLUG @ 6250' RKB. TAGGED @ 6548' SLM. MEASURED BHP @ 6254' RKB: 1829 PSI. SET NEW 2.75" CA-2 PLUG @ 6250' RKB. TEST PLUG, GOOD. COMPLETE. 12/12/2013 (PRE-RWO); FUNCTION TESTED ALL T&IC LDS/GN ASSEMBLIES, ALL FUNCTIONED. T-POT PASSED. T-PPPOT PASSED. IC-POT PASSED. IC-PPPOT PASSED. 1/28/2014 GAUGED TBG TO 2.795" TO PLUG @ 6250' RKB. SET CATCHER ASS'Y @ SAME. ATTEMPTED PULL DV @ 6206' RKB, NO SUCCESS. IN PROGRESS. 1/29/2014 PULLED DV @ 6206' RKB. LOADED TBG / IA WITH 135 BBL DSL. PULLED 2.75" CA-2 PLUG @ 6250' RKB. TAGGED © 6541' SLM. MEASURED BHP © 6579' RKB: 1964 PSI. BRUSHED PLANNED RETAINER SET DEPTH, 6189' - 6250' RKB, WHILE PERFORMING SRIT. SET HOLEFINDER © 4893' RKB, TESTED TBG 1000 PSI. READY FOR PRE-RST PLUG BACK. 5/3/2014 SET DV @ 6206' RKB. READY FOR CTU. 5/20/2014 CREW ATTENDED IFC CLASS, DRIVE UNIT TO 2N PAD, MIRU, STAB PIPE INTO INJECTOR, PERFORM WEEKLY BOP TEST 5/21/2014 PERFORMED NITRIFIED FILL CLEANOUT USING SLICK DIESEL WITH DIESEL GEL SWEEPS, PUMPING 500 SCFM WITH N2, DRY TAG TOS © 6564' CTMD, CLEANED OUT TO HARD TAG @ 6932' CTMD WHILE MAINTAINING 1:1 RETURNS, LIGHT SOLIDS OBSERVED IN GEL SWEEPS, CHASE FILL OOH TO SURFACE AND WAIT 1 HOUR FOR ANY FILL SETTLING, RIH FOR POST FCO DRY TAG, TAGGED AT 6920', EST 350' OF RATHOLE BELOW PERFS (275' BELOW PERFS TO BE ADDED, F/P TBG WHILE POOH, READY FOR DSL, JOB IN PROGRESS. 5/24/2014 TAG TD 6902' RKB(RECOVER 1/4 CUP OF FRAC SAND), BRUSH 6200-6850' SLM, FLUSH W/40 BBLS DIESEL. RUN 2.69"WRP DRIFT TO 6864' SLM, RUN 2.74" DRIFT TO 6864' SLM, RUN 20'x2" DUMMY PERF GUN TO 6864' SLM. IN PROGRESS 5/26/2014 SHOOT 2" HSD POWERJET GUN, CCL STOP DEPTH 6610.6' RKB, CCL TO TOP SHOT= 14.4', SHOT INTERVAL= 6625'-6645' RKB (6 spf, 60 DEG PHASING). ATTEMPTED TO GET TUBING STOP TO DEPTH, BUT UNABLE TO GET THROUGH D NIPPLE AT 6250'. SET 2.69"WFD WRP W/STATIC GAUGES ON BOTTOM, CCL STOP DEPTH= 6571.6' RKB, CCL TO MID ELEMENT= 28.4', MID ELEMENT SET DEPTH= 6600' RKB(LIH=104"), PERFORM 30min STATIC STOP @ 6562' RKB(1982.3 psi, 139.1 deg F). READY FOR S/L IN 72 HRS 5/30/2014 PULLED WRP W/GAUGES @ 6600' RKB: BHP @ 2015 PSI; LRS PERFORMED SRIT. SET CATCHER @ 6250' RKB; PULLED 1" DV© 6206' RKB & PULLED CATCHER. READY FOR PRE- RST PLUG BACK. 6/26/2014 PERFORM WEEKLY BOP TEST, RIH TO LOCATE NIPPLE AT 6233' CTMD, PAINT FLAG, POOH F/P TBG, JOB IN PROGRESS. 6/27/2014 RIH TO FLAG, CORRECT DEPTH TO 6248.9' (MID ELEMENT OF RETAINER, SET CEMENT RETAINER AT 6234' RKB, PUMP 24 BBLS OF 15.8#CLASS G CEMENT, 13 BBLS BELOW RETAINER, UNSTING & PUMP 6 BBLS CMT UP THE IA, LAY IN REMAINING 5 BBLS CMT IN THE 3 1/2" TBG, CONTAMINATE TO TOC AT 5759' RKB, F/P TBG FROM TOC TO SURFACE, ALLOW 24-30 HRS BEFORE DSL TAG,CBL, JOB IN PROGRESS 7/8/2014 TAG TOC © 5711' SLM, CMIT TO 2000psi FAILED 4x. IN PROGRESS 7/9/2014 STATE TAG WITNESS WAIVED BY JOHN CRISP. TAG TBG TOC @ 5750' RKB, PERFORM CBL FROM TOC @ 5750' RKB TO 3700' RKB, FOUND FREE PIPE ABOVE 5360' RKB, SHOOT 10' TUBING PUNCH W/ 1.56" OD W/4SPF, 0 DEG, SMALL CHARGE, TOP SHOT= 5310' RKB, BOTTTOM SHOT= 5320' RKB, CIRC 10 BBLS DIESEL FROM TBG TAKING RETURNS OFF IA @ 2 BPM, 1100psi. JOB COMPLETE 7/23/2014 RAN A PDS ARCHER LEAK DETECT. LOGGED BASELINE PASS FROM SURFACE TO 7540'. LOGGED FIRST PASS UP AFTER PRESSURING IA&TUBING TO 2000 PSI. INCREASE IA PRESSURE TO 3300 PSI, PUMP DIESEL UNTIL EMPTY. LOG DOWN TO 5740'. DATA TO BE PROCESSED. 7/31/2014 TAGGED TOC 6053' RKB. PUMPED 31 BBLS 15.8#CMT- 12 BBLS TO IA, 19 TO TUBING. EST TOC IN IA 4352' RKB, EST TOC IN TBG 4783' RKB. WASHED CT AND TBG WITH POWER-VIS AND CHASED OOH. *READY FOR DSL* 8/2/2014 *** STATE WITNESS TAG TOC, MIT-T& MIT-IA TO 2000psi WAIVED BY JOHN CRISP*** TAG TOC @ 4222' RKB (RECOVER SAMPLE OF CEMENT), PASSING MIT-T TO 2000psi ON 2ND ATTEMPT, PASSING MIT-IA TO 2000psi ON 1ST ATTEMPT, IN PROGRESS 8/3/2014 (PRE-RWO)T POT- PASSED; T PPPOT- PASSED; IC POT- PASSED; IC PPPOT- PASSED; FUNCTION TESTED LDS . FUNCTIONAL •8/4/2014 PERFORM CBL FROM TOL, @ 4222' RKB TO 2400' RKB, FIND TOC IIS ,,,@ 3782' RKB, SHOOT 10'x1.56" TUBING PUNCH FROM 3735'- 3745' RKB(4 SPF, 0 DEG PHASING). POOH. OBSERVE CHARGES NOT ALIGNED WITH SCALLOPS. TBG NOT PERFORATED. UNABLE TO PERFORM CIRC OUT. IN PROGRESS 8/5/2014 SHOOT 10'x1.56"TUBING PUNCH FROM 3735'-3745' RKB (4 SPF, 0 DEG PHASING), **READY FOR LRS TO PERFORM CIRC OUT** IN PROGRESS 8/6/2014 CIRC -OUT FOR DIGITAL SLICKLINE/42 BBLS S/W/42 BBLS DIESEL/ U-TUBE/JOB COMPLETE 8/7/2014 CUT TUBING @ 3107' RKB. JOB COMPLETE Conoco hillips Time Log & Summary WeNview Web Reporting Report Well Name: 2N-303 Rig Name: NABORS 9ES Job Type: DRILLING SIDETRACK Rig Accept: 8/20/2014 11:59:00 PM Rig Release: 9/15/2014 11:59:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08/12/2014 24 hr Summary Clean and clear cellar, Move pits away from sub, Pull matting boards and herculite, Pull sub off well stage to transport,Tool house laying mats to transport sub t/2N pad. Clean&clear pad. RDMO 12:00 12:30 0.50 0 0 MIRU MOVE RURD P Secure cellar, raise doors,clean and clear cellar box. 12:30 15:00 2.50 0 0 MIRU MOVE RURD P Bridal up blocks,suck out brine tanks, prep f/rig move 15:00 16:00 1.00 0 0 MIRU MOVE RURD P Lower derrick and perform derrick inspection. 16:00 18:00 2.00 0 0 MIRU MOVE RURD P Hook up peak sow t/pits and pull pits away from sub. 18:00 00:00 6.00 0 0 MIRU MOVE RURD P Move sub off well,clean and clear pad, remove matting boards and heculite. Spot sub f/transport. 08/13/2014 Move Nabors 9ES towards 2N pad on single mats, at.5 miles road became soft, begin running on double mats. 00:00 00:00 24.00 0 0 MIRU MOVE MOB P Move sub off 2L pad,move mats f/ entrance to in front of rig, move on single mats1/2 mi.broke through mats,work on blocking and sand bagging mats up move sub, Sub moving begin t/double mat roadway, tool house brought out 100 mats to assist in double mat operation. 08/14/2014 Continue moveing sub on double mats move.5 mi.toward 2N pad 00:00 00:00 24.00 0 0 MIRU MOVE MOB P Continue to move sub on double mats,tool house swapping mats and staging in front of sub.Welder working on repairing riser and suction lines. 38/15/2014 Continue moving t/2N pad on double mats. 1/2 mi.distance moved,total 1.5 mi.Add 100 mats to rig move 00:00 00:00 24.00 0 0 MIRU MOVE MOB P Continue to move sub on double mats,tool house swapping mats and staging in front of sub.Welder working on repairing riser and suction lines.Add another 100 mats to rig move. Move 1/2 mi.total 1.5 mi moved. 38/16/2014 Continue moving on double mats,trouble shoot planetary, change drive motor, 00:00 12:00 12.00 0 0 MIRU MOVE MOB P Continue moving rig f/2L to 2N pad on double mats. 12:00 16:00 4.00 0 0 MIRU MOVE RGRP T Trouble shoot drive system C/O drive motor on front wheel well drillers side. Page 1 of 23 l Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:00 00:00 8.00 0 0 MIRU MOVE MOB P Continue moving sub t/2N pad f/2L moving on double mats. 08/17/2014 Continue moving on double matting boards%mi. 2.3 mi traveled t/2N from 2L 00:00 00:00 24.00 0 0 MIRU MOVE MOB P Continue moving sub t/2N pad f/2L moving on double mats, Move%mi. total 2.3 mi moved 08/18/2014 Continue moving on double matting boards%mi.total moved 2.8 mi.traveling f/2L to 2N 00:00 00:00 24.00 0 0 MIRU MOVE MOB P Continue moving sub t/2N pad f/2L moving on double mats, Move%mi. total 2.8 mi moved 08/19/2014 Finish moving sub t/2N-303. Spot over well with rig. 00:00 17:30 17.50 0 0 MIRU MOVE MOB P Continue to move sub to 2N Pad. 17:30 00:00 6.50 0 0 MIRU MOVE RURD P Remove matting from 2N access road and prep to move remaining rig equipment from 2L pad to 2N pad. 08/20/2014 Continue to move in rig components and set in place. Berm up and lay kill line from well to kill tank. 00:00 06:00 6.00 0 0 MIRU MOVE RURD P Transport center sub up over well 2N-303,set mats and set Nabors 9ES down. Prep for raising the derrick and setting pit module. 06:00 09:00 3.00 0 0 MIRU MOVE RURD P Move in,set and rig up pit module to rig sub base. Berm up both modules. 09:00 12:00 3.00 0 0 MIRU MOVE RURD P Raise derrick, install cattle chute, RU man rider and tugger lines. Make up stand pipe. RD and move office and shops from 2L pad to 2N Pad. 12:00 00:00 12.00 0 0 MIRU MOVE RURD P Continue to MIRU equipment in preparation for acceptance. Set and Berm up kill tank. Lay kill line from well to tank. Load pits with 9.6 ppg LSND fluid. (Acceptted rig @ 23:59 hrs,8/23/2014) 08/21/2014 R/U and test surface lines, adaptor spool and lubricator. Circulate freeze protect out with hot seawter and swap over to LSND mud. Install 2 way check and nipple down tree. 00:00 04:30 4.50 0 0 SLOT WELCTL PRTS P R/U and test surface line to IA to 2500 psi. Test IA and BPV in the direction of flow to 2000 psi. 920 PSI on the OA, open OA and monitor while bleeding psi off to kill tank. 04:30 08:00 3.50 0 0 SLOT WELCTL RURD P Install and test tree adaptor to 5000 psi. P/U lubricator and test to 2000 psi. Pull BPV and R/D lubricator. 08:00 12:00 4.00 0 0 SLOT WELCTL KLWL P Circulate diesel freeze protect out through the tubing cut at 3000'MD with hot seawater. Swap over to 9.6 ppg kill weight LSND mud through the tree taking returns to the kill tank. Monitor well for flow 30 minutes. 12:00 13:30 1.50 0 0 SLOT WHDBO MPSP P Set 2 way BPV Page 2 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 16:00 2.50 0 0 SLOT WHDBO NUND P Nipple down tree. 16:00 00:00 8.00 0 0 SLOT WHDBO NUND P N/U 13 5/8", 5M, BOPE with 3 1/2"X 6"upper and lower VBR's 08/22/2014 Test BOPE, upper rams failed, change out 3.5"X 6"VBR's, finish testing. Pull hanger, 60K PUW, no problems laying hanger down. Lay down 1,007'of 3.5"tubing. 00:00 02:30 2.50 0 0 SLOT WHDBO NUND P Nipple up BOPE 02:30 06:00 3.50 0 0 MIRU WHDBO BOPE P Test BOPE 250 psi low and 3500 psi high. Test#1, valves 1,2,3 and 16, blinds, kill Demco and choke. kill line Unibolt failure, tighten Unibolt,( good test). Test#2, choke, 4,5,6, and HCR kill, (good). Test#3, choke, 7,8,9, and manual kill(good). Test#4, manual choke, hydraulic choke, 7,9, HCR(good). Test#5, choke, 10 and 11, (good). Test#6, choke, 12, 13, 14(good). 06:00 16:00 10.00 0 0 MIRU WHDBO RGRP T Test with 5.5"test joint,lower rams, upper rams and bag, upper rams failed. Lay down test joint,emty stack and change out 3.5"X 6" VBR's. 16:00 19:30 3.50 0 0 MIRU WHDBO BOPE P Retest 3.5", 4"and 5.5"test joints. Test manual IBOP on TD, inner and outter test spool valves. Perform Kommey test per AOGCC, 25 sec to build 200 psi, 180 sec to 3000 psi accumulator pressure. Average NO2 charge 2025 psi. CPAI accumulator draw down,18 sec to 2500 psi with air pumps,45 sec to 3000 psi with electric pump. 19:30 20:30 1.00 0 0 MIRU WHDBO RURD P R/D test tools, bow down choke and kill lines, line up choke and secure cellar. 20:30 21:00 0.50 0 0 MIRU WHDBO MPSP P Pull 2 way BPV 21:00 22:00 1.00 0 0 SLOT RPCOM RURD P R/U to pull hanger and tubing. 22:00 23:00 1.00 0 0 SLOT RPCOM PULL P Pull hanger, PUW 60K, no problems laying hanger down. 23:00 00:00 1.00 3,007 2,000 SLOT RPCOM PULL P L/D 1,007'of 3 1/2"9.3#L-80 tubing. 38/23/2014 L/D 2,000'of 3.5"tubing. R/U Haliburton"E"line and run gauge ring/junk basket to 3000'. R/U and run CBL with temperture log F/3000'to 2600'. R/U Baker K-1 cement retainer dressed as CIBP on wire line to 2800'. Pull out of hole and test CIBP to 2500 psi for 10 minutes. 00:00 03:30 3.50 2,000 0 SLOT RPCOM PULL P POOH laying down 3-1/2 EUE tubing from 2,000-ft to surface 53k up wt and 43k do wt. Calc/dipl. = 10.08 bbl's and actual= 10.3 bbl's. Total pipe recovered was 97 jts plus 16.34-ft of 98 difference in depth-WLM =3,108-ft and 3,094.53-ft as per tally conducted. Page 3 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:30 04:00 0.50 0 0 SLOT RPCOM RURD P RD GBR tubular running equipment, clean and clear work area. 04:00 09:30 5.50 0 0 SLOT EVALWE RURD P PJSM, Install Dutch riser. Load Halliburton E-Line Pressure control equipment to rig floor. 09:30 11:00 1.50 0 0 SLOT EVALWE RURD P Pressure test E-Line pressure control equipment to 250/2,000 psi -good test. 11:00 15:00 4.00 0 0 SLOT EVALWE GRJB P MU and RIH w/4.825"Gauge ring and junk basket to 3,000-ft. POOH and recovered minimal trash. RD Junk basket. 15:00 19:00 4.00 0 0 SLOT EVALWE SRVY P MU and RIH w/Gyro Data survey tools to 3,050-ft and POOH. RD survey tool. 19:00 22:00 3.00 0 0 SLOT PLUG MPSP P MU running tools for Baker K-1 CIBP,attach 5.5 CIBP and RIH to 2,800-ft+/- and correlate to collar at 2,796-ft and set with center of element at 2,810-ft. Seen weight loss and pull away with less up wt. Set 100 lbs down for verification. POOH. 22:00 22:30 0.50 0 0 SLOT PLUG PRTS P Fill hole above blind rams, close blind rams and pressure up to 2,500 psi for 10 minutes. 22:30 00:00 1.50 0 0 SLOT PLUG CPBO P Rig up Weltec radial cutting torch on wire line. Function test in pipeshed. RIH w/cutter @ midnight. OA had 100 psi @ 2300 hrs, bleed down to kill tank while RIH w/cutter. 08/24/2014 Run Welltec cutter on Haliburton"E"line and cut 5 1/2"liner at 2,745'. Pull out of the hole, closed blind rams on the welltec tools. Test lower rams to 250 psi low and 3500 psi high. Open the blind ram doors and inspect rams, no sign of damage. Test blind rams 250 psi low and 3500 psi high, Attempt to spear pack-off, no go. Pull pack-off with running tool. Attempt to pull liner hanger with spear, failed to get enough of grapple to pull hanger.M/U landing joint and made two attempts to pull hanger. 4 threads the first attempt and 3 3/4 threads the second. Haliburton trucking Jet cutters form Deadhorse. 00:00 04:30 4.50 0 0 SLOT PLUG CPBO P P/U and run Welltec 5 1/2"cutter.to 2,745'. Start cut at 01:05 hrs holding 500 psi on the IA, 0 psi on OA. 5 1/2"liner cut complete at 04:17 hrs. No pressure drop on the IA and no increase in pressure on the OA. Bled pressure off of the IA and opened the OA and pull cutter. 04:30 05:30 1.00 0 0 SLOT PLUG ELNE P Pull wireline out of the hole. Closed the blind rams on the welltec cutting tools. B/D Haliburton"E" line tools and leave on the rig floor, L/D circulating equipment and Dutch Riser. 05:30 09:00 3.50 0 0 SLOT PLUG BOPE T Drain stack, install test plug and test the lower rams, 250 psi low and 3500 psi high. (Two tesedt barriers before opening blind ram doors.) Page 4 of 23 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:00 14:00 5.00 0 0 SLOT PLUG RGRP T PJSM, open blind ram doors and inspect rubbers and rams. No signs of damage,closed doors and M/U bolts. 14:00 15:00 1.00 0 0 SLOT PLUG BOPE T Open lower rams, L/D test joint and test blind rams 250 psi low and 3500 psi high. 15:00 17:00 2.00 0 0 SLOT PLUG FISH P M/U Spear assembly on 4"DP and TD. Engage spear into pack-off, set dwon 4K and pick-up 15K over, no go. Only two blades of the grapple below top ring. ( Pack-off ID 4.812", grapple OD 4.936") 17:00 19:00 2.00 0 0 SLOT PLUG RTWH T M/U pack-of running tool and attempt to pull pack-off, no go,tool would not seat Pull running tool and remove rubber ring gasket, run back in and pull pack-off. 19:00 19:30 0.50 0 0 SLOT PLUG FISH T M/U spear assembly and engage spear 3"into hanger. Release spear and L/D assembly. 19:30 21:30 2.00 0 0 SLOT PLUG RTWH T P/U landing joint and attempt to M/U liner hanger. Made two attempts to M/U landing joint on hanger,4 threads the first attempt and 3 3/4 threads the second. (Call drilling engineer for plan forward.) 21:30 22:00 0.50 0 0 SLOT PLUG SVRG T Service Rig 22:00 00:00 2.00 0 0 SLOT PLUG OTHR P Haliburton trucking Jet cutters from Deadhorse. 08/25/2014 Truck Haliburton Jet cutters from Deadhorse. R/U Haliburton"E"line, lubricator and Jet cutter. R/D Haliburton Jet cutter and R/U FMC pack-off running tool. Attempt to set pack-off, no go, R/U Haliburton Jet cutter. Run in the hole to 2,580'POOH, curculate 9.6 ppg mud up the annulus. Observed annulus until mud returned,shut down and closed the bag,displaced the well with 9.6 ppg mud. Shut down and observed well, still flowing, continue circulating to the Kill tank. 00:00 05:00 5.00 0 0 SLOT PLUG OTHR P Haliburton trucking Jet cutters from Deadhorse. 05:00 06:30 1.50 0 0 SLOT PLUG RURD P R/U Haliburton"E"line lubricator and jJet Cutter to Dutch Riser. Flood Dutch Riser and wireline BOP W/9.6 ppg mud. 06:30 07:00 0.50 0 0 SLOT PLUG SEQP P Test Dutch Riser,250 psi low,2000 psi high. 07:00 08:30 1.50 0 0 SLOT PLUG OTHR T Waiting on plan forward from CPAI. 08:30 10:00 1.50 0 0 SLOT PLUG WWSP T L/D Haliburton lubricator and Jet cutter on the rig floor. R/D Dutch _Riser and surface equipment. 10:00 12:00 2.00 0 0 SLOT PLUG RURD T R/U FMC pack-off running tool and _set pack-off as per FMC rep. 12:00 13:30 1.50 0 0 SLOT PLUG RTWH T Attempt to set pack-off, set down 20K on top, no go. Consult with CPAI engineer. Page 5 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:30 19:00 5.50 0 ISLOT PLUG RURD T R/U Dutch Riser, Haliburton"E"line lubricator and Jet cutter. Attempt to run in the hole with Jet cutter, wireline won't go through the hanger. Break and P/U wireline BOP's and guide cutting tools through hanger. 19:00 20:30 1.50 0 0 SLOT PLUG CUTP T Run in the hole with Haliburton Jet cutter, Shut OA and monitor pressure during Iner cut. Cut was completed at 19:30 hrs, no peressure change on the OA. (Shot good) 20:30 22:00 1.50 0 0 SLOT PLUG RURD P R/D wierline equipment and pick up tools and landing joint to pull 5 1/2" casing hanger. 22:00 22:30 0.50 0 SLOT PLUG DISP P M/U landing joint to liner hanger and pull 40K over. S/D and monitor well. Circulate 24 bbls up the annulus until fluid was observed. Close bag and displace well with 9.6 ppg mud, taking returns to the Kill tank. 22:30 23:00 0.50 0 0 SLOT PLUG DISP P Displace well with 9.6 ppg mud taking returns to the Kill tank, 3 BPM, 215 psi. S/D at 23:30 hrs to check for flow. Well still flowing, continue circulating to the Kill tank. 23:00 00:00 1.00 0 0 SLOT PLUG CIRC P Continue circulaing well to Kill tank. R/D wireline tools to pipe shed. 08/26/2014 Pull the 5 1/2"casing hanger free, 30K PUW, pull hanger and 61 JTS of 5 1/2' liner. P/U Fishing tools, DC's, HWDP and 4" DP and run in the hole for Fish at 2,745'. Engage Fish, pull free from cement,work Fish while attempting to circulate. Broke circulation while staging pumps up slowly, monitor shakers for cuttings. Monitor well, static, POOH with Fish. 00:00 02:00 2.00 0 0 SLOT PLUG PULL P Monitor well for 30 minutes, pull casing hanger with 30K up weight, no problems. Lay down Haliburton and FMC tools. 02:00 04:00 2.00 0 0 SLOT PLUG PULL P L/D 5 1/2"hanger and 61 joints of 5 1/2"liner. The cut was on Joint#61 34.38', 8.49'from the collar of joint #62. The cut was made at the centralizer flaring the end of it 6 5/8" on one side and 6 1/2"on the other, leaving no junk in the hole. The hanger ID is 4.875'and the spear grapple colapse is 4.875', explaining why we could not spear the hanger. 04:00 04:30 0.50 0 0 SLOT PLUG RURD P L/D GBR casing tools and clear floor. 04:30 05:00 0.50 0 0 SLOT PLUG SVRG P Service rig 05:00 08:30 3.50 0 0 SLOT PLUG PULD P Load fishing tools, 12-DC's and 69 JTS of 4" DP into the pipe shed. 08:30 12:00 3.50 0 410 SLOT PLUG PULD P PJSM, P/U fishing BHA,Bull nose, Pack-off assembly,Spear, Jars, 12- 4 3/4"DC's and 18- 4" HWDP, (per Baker rep.), and 4" DP. 12:00 16:30 4.50 410 2,574 SLOT PLUG PULD P Continue to P/U 4" DP F/410' T/2574' Page 6 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 16:30 17:30 1.00 2,574 2,591 SLOT PLUG FISH P Tag no go at 25.91',ste down 10K, Top of fish 2583, pull up 50K over to125K,set Jars off,continue to 155k, Fish came free,work Fish to get returns. 17:30 19:30 2.00 2,591 2,745 SLOT PLUG CIRC P Attempt to circulate while working Fish F/2728'T/2633'. Worded backside free from cement, PUW 85K, SOW 70K,slowly stage pumps up to 6 BPM,447 psi. P/U joint 52 and wash to bottom. Continue to circulate and monitor shakers for cuttings, a lot of sand. 19:30 21:00 1.50 2,745 2,540 SLOT PLUG CIRC P Pull up F/2745'T/2540' ,circulate B/U staging pumps to 7.3 BPM, 585 psi. Monitor well for 10 minutes, static, line up on trip tank. 21:00 00:00 3.00 2,540 397 SLOT PLUG TRIP P POOH with Fish F/2,540'T/397', PUW 50K, SOW 50K,ease in and out of slips with Fish,watch for the Fish hanging up. Calculated hole fill 14.1 bbls,Actual hole fill 13.2 bbls. 08/27/2014 POOH and L/D Fish,165'5 1/2"liner. P/U 3 1/2"cement string and run it in with 4"DP, cement the KOP at 2,808'. POOH laying down the 3 1/2"cement string. 00:00 05:00 5.00 397 0 SLOT PLUG PULD P L/D the BHA and Fish(165'of 5 1/2" liner). Clear the floor and load the 3 1/2"cement string into the pipe shed. 05:00 07:30 2.50 0 900 SLOT PLUG PULD P P/U the 3 1/2"cement string, PUW 40K, SOW 38K, Calculated disp.2.9 bbls,Actual disp, 3.2 bbls. 07:30 10:30 3.00 900 2,518 SLOT PLUG TRIP P TIH with 17 stands of DP F/900' T/2518', PUW 50K, SOW 47K. 10:30 12:00 1.50 2,518 2,808 SLOT PLUG PULD P P/U 4"DP F/2518'T/2740',space out and tag bottom @ 2745'. Circulate and condition mud as per MI. PUW 63K, SOW 57K, Pressure 173 psi,4 BPM,tag bridge plug @ 2808'. Calculated disp. 13.6 bbls, Actual disp. 15.8 bbls. 12:00 13:00 1.00 2,808 2,808 SLOT PLUG CIRC P Circulate and conditon mud, PUW 63K, SOW 57K, SPM 107, BPM 7.3, 350 psi. 13:00 14:00 1.00 2,808 2,808 SLOT PLUG RURD P R/U head pin and cement lines. 14:00 15:00 1.00 2,808 2,808 SLOT PLUG CIRC P Circulate through cement lines, BPM 6, PSI 400,stage up pumps, BPM 8, PSI 603. Line up to take returns to choke, BPM 4, PSI 350, back pressure 40-50 psi. Pre-Job with cement crew. Page 7 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 15:00 16:00 I 1.00 2,808 2,808 SLOT PLUG PLUG P 15:05-Pump 2.2 bbls of mud push ahead to flood Iines.15:10-Shut in valve on DP for pressure test, 520 psi low 3500 psi high. Pump15.2 bbls of mud push,15:18-5 bbls away at 4.8 BPM, 673 psi,density12.55 ppg. 15:19-10 bbls away,4.8 BPM, 631 psi,density 12.55 ppg, 15:20- 15.2 bbls away,4.9 BPM,601 psi, density 12.6. 15:22-Shut down load foam ball and batch 17 ppg cement. 15:47-open choke, 15:51 - start pumping cement,15:52-5 bbls away,4.4 BPM, 151 psi, density 17.07 ppg,15:53- 10 bbls away, 4.3 BPM, 182 psi, density17.02 ppg,15:55-at15 bbls away, 3.1 BPM, 73 psi, density 16.99 ppg,15:56-at 23.7 bbls away, 3.0 BPM, 170 psi, density 14.82 ppg. 15:58-pump 4.6 bbls mud push behind cement,4 BPM, 181 psi, density 12.5 ppg. 16:00-pump 1 bbl of water from displacement tank and turn over to rig for displacement,15 bbls of mud, 80 SPM, 134 psi. 16:01 - 100 STKS, 83 SPM, 140 psi,16:03 - 170 STKS, 70 SPM, 265 psi, 16:05 -210 STKS, 32 SPM, 236 psi. 16:07-open bag and break down cement lines. 16:32- 17:01 POOH slow, 7.3 min/std F/2808'T/2420'. 16:00 16:30 0.50 2,808 2,808 SLOT PLUG RURD P Clear lines to truck and R/D cement lines and equipment. 16:30 17:00 0.50 2,808 2,422 SLOT PLUG TRIP P POOH slowly,7.3 min/std, F/2,808' T/2,422', PUW 67K, SOW 57K, 17:00 18:00 1.00 2,422 2,422 SLOT PLUG CIRC P Drop ball, circulate pipe clean, stage pumps up to 12 BPM, PSI 490, recpricate pipe, PUW 60K, SOW 53K, monitor well. 18:00 19:00 1.00 2,422 900 SLOT PLUG TRIP P TIH F/2,422'T/900', PUW 50K, SOW 49K. 19:00 21:00 2.00 0 260 SLOT PLUG PULD P L/D 20 JTS of 3 1/2"tubing. 21:00 22:00 1.00 260 260 SLOT PLUG SFTY T Safety Stand down-While laying down 3 1/2"tubing the tubing was not centered on the pipe skate. When a floorhand unlatched the tubing the tubing came off of the skate backstop and dropped into the pipe shed. No injuries and minor equipment damage, a broken thread protector. 22:00 23:00 1.00 26 0 SLOT PLUG PULD P Continue to L/D 3 1/2"tubing cement string. 23:00 00:00 1.00 0 0 SLOT PLUG SVRG P Service rig and finish loading 4" DP in the pipe shed. Page 8 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 38/28/2014 24 hr Summary P/U 144 joints of 4" DP and stand it back in the derrick. R/U and test BOP's,witnessed by Lou Grimaldi. 00:00 01:00 1.00 0 0 SLOT PLUG SVRG P Service rig 01:00 05:00 4.00 0 0 SLOT PLUG PULD P P/U 4" DP, strap and tally, RIH 05:00 07:00 2.00 0 0 SLOT PLUG TRIP P POOH and stand back 24 stds 4" DP 07:00 09:30 2.50 0 0 SLOT PLUG PULD P P/U 4" DP, strap and tally, RIH 09:30 11:00 1.50 0 0 SLOT PLUG TRIP P POOH and stand back 24 stds 4" DP 11:00 12:00 1.00 0 0 SLOT WHDBO RURD P Remove wear bushing, clean floor. drain stack and R/U for test. 12:00 13:00 1.00 0 0 SLOT WHDBO RURD T Intall test plug,won't go, pull plug and check rubber, re-install plug all good, L/D JT. 13:00 14:30 1.50 0 0 SLOT WHDBO BOPE P Fill choke and stack and perform body test on BOP's. Lou Grimaldi on locaton to witness test,test started 14:22 hrs. 14:30 00:00 9.50 0 0 SLOT WHDBO BOPE P Test choke manifold and BOP's 250 psi low, 3500 psi high. Test valves 1-16, kill Demco, manual kill, choke valves on stack, HCR kill/choke. P/U test joints, 3 1/2"and 4". Test TD manual, TIW, IBOP, gas monitors and PVT,Accumulator, 6 NO2 bottles-average pressure, 1966 psi. AOGCC Test: Koomey pressure 3000 psi, Manifold pressure 1500, function rams-Koomey pressure1600 psi, 33 seconds to attain 200 psi, 152 seconds full pressure. CPAI Koomey test, function rams, 72 secs to attain 2500 psi, both air and electric pumps to attain full pressure 195 secs.. 08/29/2014 Finished BOP test. RIH and taga cement at 2426',test casing 2,500 psi, 30 minutes. Drill cement F/2426' T/2453'. Trouble shoot problems with Top Drive. Changing out lube pump motor. 00:00 03:30 3.50 0 0 SLOT WHDBO BOPE P Continue testing with 4"test joint, 250 psi low, 3500 psi high. Test lower rams, upper rams, annular preventer,test inner and outer test spool. Clean out mud system, blow down choke maniffold and put 3 1/2" tubing into pipe shed. 03:30 05:00 1.50 0 0 SLOT WHDBO BOPE P P/U 5 1/2"test joint and lower rams, upper rams, and annular preventer. 250 low and 3500 psi high. 05:00 07:00 2.00 0 0 SLOT WHDBO RURD P Pull test plug, L/D 5 1/2"test joint, install wear bushing, L/D test equipment. 07:00 09:00 2.00 0 ' 706 SLOT PLUG PULD P PJSM, P/U BHA as per DD, 6 1/2" X7 1/2" BI-Center drilling assembly. 09:00 12:00 3.00 706 1,500 SLOT PLUG TRIP P TIH F/706'T/1500', PUW 61 K, SOW 48K. Page 9 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 13:00 1.00 1,500 1,500 SLOT PLUG DHEQ P Shallow test MWD tools at 1499', 780 psi, 200 GPM, 70 SPM, PUW 60K, SOW 56K. 13:00 14:00 1.00 1,500 2,426 SLOT PLUG TRIP P TIH F/1500'T/2426',tag cement, PUW 75K, SOW 63K. 14:00 15:00 1.00 2,426 2,395 SLOT PLUG PRTS P Pressure test 7 5/8"casing at 2395', 2500 psi F/30 minutes. 15:00 16:00 1.00 2,395 2,426 SLOT PLUG CIRC P Circulate and condition mud 16:00 17:00 1.00 2,426 2,453 SLOT PLUG DRLG P Drilling cement F/2426'T/2453', PUW 75K, SOW 65K, ROT 69K, RPM 30, PSI ON 3000, PSI OFF 825,TQ ON 3000K, TO OFF 1500K, GPM 200, SPM 68,WOB 5K. 17:00 00:00 7.00 2,453 2,543 SLOT PLUG RGRP T Trouble shoot Top Drive. Breaker goes off when powering up on Top Drive, change out lube pump motor. 38/30/2014 Cont.to repair TD, drill cement and sidetrack off of KOP. Drill to 2,675'and pull back into casing and repair TD. 00:00 14:00 14.00 2,454 2,454 SLOT PLUG RGRP T Cont. to repair top drive. 14:00 21:30 7.50 2,454 2,675 SLOT PLUG DDRL P Drilling cement f/2454'to 2670' -off cmt plug Drill to 2675''GPM 250, PSI ON 1100, PSI OFF 130, RPM 30, TQ ON 2700K,TQ OFF 1800K, PUW 80K SOW 65K, ROT 70K, ART.38 HRS,ADT 2.98 HRS, BIT 2.98 HRS, JARS 2.98 HRS, MW 9.6 PPG. 21:30 00:00 2.50 2,675 2,675 SLOT PLUG RGRP T Trouble shoot problems with Top Drive. 38/31/2014 D/D with 6 1/2"X7 1/2" Bi-Center bit and motor F/2675'T/2700'. Perform FIT,went to leak off @ 460 psi, EMW 13.4 ppg. D/D from 2700'to 3976'. 00:00 02:00 2.00 2,675 2,700 PROD1 PLUG DDRL P D/D with 6 1/2"X 7 1/2" Bi-Center BHA F/2,675'T/2,700'. 02:00 03:00 1.00 2,700 2,700 PROD1 PLUG LOT P Pull back into casing and perform LOT. Leak-off pressure=460 psi, EMW= 13.4 ppg. 03:00 12:00 9.00 2,700 3,120 PROD1 DRILL DDRL P Go back to bottom 2,700', D/D ahead with 6 1/2""X 7 1/2" Bi-Center BIT and motor F/2700'T/2834'. GPM 245, PSI ON 2018, PSI OFF 1875, RPM 30, TQ ON 3K, TQ OFF 3, PUW 83K, SOW 65, ROT 72K. SPR'S taken at 04:00 hrs, MD 2706', TVD 2315'. Pump#1 at 2 BPM=300 psi, 3 BPM=450 psi. Pump#2 at 2 BPM=300 psi, 3 BPM =470, MW 9.6 ppg.ART 2.44 hrs,ADT 5.38 hrs, BIT 8.36 hrs, JARS 8.36 hrs. Page 10 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 00:00 12.00 3,120 3,976 PROD1 DRILL DDRL P !DID with Bi-Center bit and motor F/3120 T/3976'. GPM 300, PSI ON 2560, PSI OFF 2500, RPM 150, TQ ON 3-6K, TQ OFF 3-6K, PUW 100K, SOW 70K, ROT 82K,ART 8.4 hrs, adt 4.66 hrs, BIT 17.95 hrs, Jars 17.95. SPR's taken at 21:20 hrs, MD 3785', TVD 3150'. Pump#1 at 2 BPM =380 psi, 3 BPM=580 psi. Pump#2 at 2 BPM =380 psi, 3 BPM=600 psi, MW 9.6 ppg. 09/01/2014 Drilled 6 1/2"x 7 1/2"hole w/motor&BiCenter bit f/3976'to 4832'-Wiper trip f/4832'to 3885'-RIH to 4437'- Wash down to 4832'-Drilled 6 1/2"x 7 1/2"hole w/motor&Bi Center bit f/4832'to 5404' 00:00 06:00 6.00 3,976 4,353 PROD1 DRILL DDRL P Drilled 6 1/2"x 7 1/2"hole w/motor & Bi Center bit f/3976'to t/4353', TVD 3606', WOB 20K, GPM 300, PSI ON 2750, PSI OFF 2633, RPM150, TO ON 4K,TO OFF 4K, PUW 104K, SOW 77K, ROT 84K, ART 2.08 hrs,ADT 3.3 hrs,AST 1.22 hrs, Total bit hrs. 21.25 hrs, Total jars hrs. 21.25 hrs. SPR's taken at 05:00 hrs, 2458' MD, 3517'TVD. Pump#1 at 2 BPM =390 psi, 3 BPM =630 psi. Pump#2 at 2 BPM =400 psi, 3 BPM =630 psi. MW 9.7 06:00 12:00 6.00 4,353 4,769 PROD1 DRILL DDRL P Drilled 6 1/2"X 7 1/2"hole w/motor& Bi-Center bit f/4353'to 4769'. TVD 3935', WOB 20, GPM 300, PSI ON 2715, PSI OFF 2602, RPM 150, TQ ON 4K, TO OFF 4K, PUW 118K, SOW 82K, ROT 85K, ART 3.05 hrs, ADT 3.59 hrs, AST .54 hrs Total bit hrs 25.09 hrs, Total jar hrs 24,84 hrs. SPR's taken at 11:30 hrs, 4737'MD, 3902'TVD. Pump#1 at 2 BPM=370 psi, 3 BPM=570 psi, Pump#2 at 2 BPM =390 psi, 3 BPM =590 psi, MW 9.7 ,ppg. Page 11 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 13:00 1.00 4,769 4,832 PROD1 DRILL DDRL P Drilled 6 1/2"x 7 1/2"hole w/motor & Bi Center bit f/4769'to 4832'MD- 3981'TVD WOB 20 RPM 150 GPM 300© 2710 psi on btm/2600 psi off btm String wt PU 118 SO 82 ROT 86 Torque on btm 5 k/off btm 4 k SPR's©4832'MD 3981'TVD #1 430 psi @ 2 bbls/min 630 psi© 3 bbls/min #2 400 psi @ 2 bbls/min 630 psi ©3 bbls/min 13:00 13:30 0.50 4,832 4,832 PROD1 DRILL CIRC P Circ hole clean for wiper trip @ 300 gpm @ 2600 psi-take survey& SPR's-Flow Ck(static) 13:30 15:00 1.50 4,832 3,885 PROD1 DRILL WPRT P Wiper trip f/4832'to 3885'-PU wt 120 SO wt 86 No tight hole obseved 15:00 15:30 0.50 3,885 3,885 PROD1 DRILL SVRG P Service rig-grease draw works&top drive(Monitor well-Static) 15:30 17:00 1.50 3,885 4,832 PROD1 DRILL WPRT P RIH f/3885'to 4830'-SO wt. 73- Wash down f/4830'to 4832' 17:00 00:00 7.00 4,832 5,404 PROD1 DRILL DDRL P Drilled 6 1/2"x 7 1/2"hole w/motor & Bi Center bit f/4832'to 5404' MD- 4439'TVD WOB 20 k RPM 150 GPM 300© 2845 psi on btm/2580 psi off btm String wt PU 120 SO 84 ROT 96 Torque 6.7 k on btm/5.6 k off btm ADT-6.75 hrs ART-4.45 hrs AST- 1.30 hrs Total bit hrs. 31.61 Total jar hrs. 31.61 SPR's @ 5303'MD 4362'TVD #1 430 psi @ 2 bbls/min 660 psi @ 3 bbls/min #2 420 psi @ 2 bbls/min 640 psi© 3 bbls/min 09/02/2014 Drilled 6 1/2"x 7 1/2" hole w/motor& Bi Center bit f/5404't/6735' 300 GPM 150 RPM Pumping Hi Vis Sweeps as needed f/hole cleaning Footage 1331'f/Day Page 12 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 5,404 6,069 PROD1 DRILL DDRL P Drilled 6 1/2"x 7 1/2"hole w/motor &Bi Center bit f/5404'to 6069'MD- 4945'TVD WOB 20 k RPM 150 GPM 300 @ 2920 psi on btm/2850 psi off btm String wt PU 135 SO 92 ROT 105 Torque 7kenbtm/7koff btm ADT- 11.26 hrs ART-6.37 hrs AST- 4.89 hrs Total bit hrs.40.23 Total jar hrs. 39.98 SPR's @ 5783' MD 4723'TVD #1 440 psi©2 bbls/min 670 psi @ 3 bbls/min #2 430 psi @ 2 bbls/min 650 psi @ 3 bbls/min 12:00 00:00 12.00 6,069 6,735 PROD1 DRILL DDRL P Drilled 6 1/2"x 7 1/2"hole w/motor &Bi Center bit f/6069'to 6735'MD- 5463'TVD WOB 20 k RPM 150 GPM 300 @ 2950 psi on btm/2750 psi off btm String wt PU 142 SO 93 ROT 113 Torque 9kenbtm/7koff btm ADT-9.11 hrs ART-5.18 hrs AST- 3.93 hrs Total bit hrs. 49.34 Total jar hrs. 39.34 SPR's @ 6735'MD 5463'TVD #1 470 psi @ 2 bbls/min 690 psi @ 3 bbls/min #2 480 psi @ 2 bbls/min 700 psi @ 3 bbls/min 09/03/2014 Drilled 6 1/2"x 7 1/2"hole w/motor&Bi Center bit f/6735't/7093', 300 GPM, 150 RPM, Footage 358', Circ& Cond hole pump 3 30 bbl hi vis sweeps, cir 4 bottoms ups @ 300 gpm 150 rpm, Ream out of the hole 300 gpm 150 rpm standing back stand every 30 min f/7093't/6450', POOH f/6450't/5308', pump dry job blow down top drive, POOH f/5308't/739', L/D BHA, R/U Halliburton E-Line Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 06:00 6.00 6,735 7,093 PROD1 DRILL DDRL P Drilled 6 1/2"x 7 1/2"hole w/motor &Bi Center bit f/6735'to 7093'MD- 5736'TVD WOB 15 k RPM 150 GPM 300 @ 2670 psi on btm/22463 psi off btm String wt PU 146 SO 105 ROT 115 Torque 7konbtm/6koff btm ADT- 3.85 hrs ART-2.32 hrs AST- 1.53 hrs Total bit hrs. 53.19 Total jar hrs. 52.94 SPR's @ 7093'MD 5736'TVD #1 420 psi @ 2 bbls/min 600 psi @ 3 bbls/min #2 430 psi @ 2 bbls/min 610 psi @ 3 bbls/min 06:00 08:30 2.50 7,093 7,093 PROD1 EVALWE CIRC P Circulate and condition hole clean, pump 3 30 bbl hi vis sweeps, pump 4 bottoms ups, 300 gpm 1780 psi 150 rpms 08:30 12:00 3.50 7,093 6,450 PROD1 EVALWE REAM P POOH w/pumps standing back stand every 30 min, 300 gpm 2190 psi 150 rpm f/7093't/6450' 12:00 13:30 1.50 6,450 5,308 PROD1 EVALWE TRIP P POOH f/6450'V 5308' PUW-140 SOW-99k hole took proper fill 13:30 14:00 0.50 5,308 5,308 PROD1 EVALWE CIRC P Pump 25 bbl dry job install stripping rubbers blow down top drive. 14:00 18:00 4.00 5,308 739 PROD1 EVALWE TRIP P POOH f/5308'V 739' hole took proper fill 18:00 21:00 3.00 739 0 PROD1 EVALWE PULD P Stand back&L/D BHA, download MWD in pipe shed 21:00 00:00 3.00 0 0 PROD1 EVALWE ELOG P R/U Halliburton E-Line PJSM w/ E-Line, P/U hoisting equipment, M/U tools string. 39/04/2014 R/U Halliburton E-Line, RIH w/Logging tools, set down @ 2950' Unable to get down, POOH, change out 6" nose cone t/3 5/8" hole finder, RIH w/Eline Logging tools t/2950'set down,work through tight spots continue in hole V 6200'set down, attempt/work through,tools stuck,fire jars tools free, unable t/get through, POOH w/E-Line tools, R/D Eline equipment, M/U cleanout BHA RIH t/2627', CBU, RIH f/shoe V 6736'filling pipe every 20 stands 00:00 03:00 3.00 0 0 PROD1 EVALWE ELOG P R/U Halliburton E-Line, hang top sheave, P/U tool string and equip. 03:00 04:30 1.50 0 0 PROD1 EVALWE ELOG T RIH w/113'tool string,w/6"cabbage head on bottom, RIH V 2950 set down unable to work through, Eline cable spool back lashed, POOH V casing shoe @ 2650', respool back lash, Attepmt V RIH set down @ 2950',work tool sunable to get _through. 04:30 06:00 1.50 0 0 PROD1 EVALWE ELOG T POOH w/E-Line tool string change 6"cabage head V 3 5/8" hole finder Page 14 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 09:30 3.50 0 0 PROD1 EVALWEIELOG T RIH w/E-Line Logging tools set down @ 2950'work through tight spot, continue RIH w/Logging tools U 6200'work tool string tools stuck, work tools fire jars,tools free work up hole t/6115' unable to get deeper. 09:30 11:30 2.00 0 0 PROD1 EVALWE ELOG T POOH w/E-Line Logging tools. 11:30 12:30 1.00 0 0 PROD1 EVALWE ELOG T R/D E-Line equipment. 12:30 16:00 3.50 0 738 PROD1 EVALFN PULD T P/U clean out BHA as per MWD /DD. 16:00 18:00 2.00 738 2,627 PROD1 EVALFN TRIP T RIH w/Clean out BHA f/738't/2627' shallow test tools @ 1499'230 gpm 1200 psi 18:00 19:00 1.00 2,627 2,627 PROD1 EVALFN CIRC T Circulate and condition mud @ shoe 300 gpm 1300 psi 19:00 00:00 5.00 2,627 6,736 PROD1 EVALFN TRIP T RIH w/Clean out BHA f/2627't/ 6736'filling pipe every 20 stands. 145 k PUW 95k SOW 39/05/2014 Cont RIH f/6736'to 7022'-Wash down to TD @ 7093'-Circ hole clean-BROOH f/7093't/Casing shoe @ 2627' Circ&Cond hole clean pump 50 bbl Hi Vis Sweep, POOH on elevators t/739', L/D BHA as per MWD/DD, R/U Halliburton E-Line f/open hole logging. 00:00 00:30 0.50 6,736 7,093 PROD1 EVALFN TRIP T Cont.RIH w/clean out assembly f/ 6736'to 7022'-MU TD-wash down 1/7022'to 7093'@ 285 gpm @ 2429 psi-No fill on btm Calc displacement 35.7 bbls Actual _displacement 34.9 bbls 00:30 03:00 2.50 7,093 7,093 PROD1 EVALFN CIRC T Circ hole clean @ 300 gpm @ 150 rpm's-PU wt 115 SO 114 ROT 113 03:00 06:00 3.00 7,093 6,261 PROD1 EVALFN REAM T BROOH f/7093'to to 6261'@ 300 gpm @ 1937 psi w/ 150 rpm's-ROT wt 108 SPR's @ 7093' MD 5736'TVD@ 0300 hrs. #1 2 bbls/min 390 psi 3 bbls/min 570 psi #2 2 bbls/min @ 400 psi 3 bbls/min 570 psi 06:00 15:30 9.50 6,261 2,627 PROD1 EVALFN REAM T Continue BROOH 1/6261't/2627' 200 GPM 150 RPM 760 psi 15:30 16:30 1.00 2,627 2,627 PROD1 EVALFN CIRC T Circ and condition mud @ shoe, pump 50 bbl hi vis sweep t/clean _casing, 200 gpm 700 psi 16:30 18:00 1.50 2,627 739 PROD1 EVALFN TRIP T POOH on elevators f/2627't/739' 18:00 22:00 4.00 739 0 PROD1 EVALFN PULD T L/D BHA as per MWD/DD download ,MWD in shed. 22:00 00:00 2.00 0 0 PROD1 EVALFN RURD T R/U halliburton E-Line equipment f/ open hole logging. Page 15 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 39/06/2014 24 hr Summary R/U Halliburton E-Line RIH,open hole log f/7093'U casing shoe, POOH-RD HES-RU to run 5 1/2" production casing,Trouble shoot casing equipment, RIH w/5.5"Casing U 172'taking weight work string in hole U 370'w/pumps 210 gpm 600 psi unable to get string down, R/D Volant, R/U double stack tongs, POOH L/D 5.5"removing centralizers. 00:00 00:45 0.75 0 0 PROD1 EVALFN ELOG T Continue M/U open hole logging tools, RWCH, SWVL, HFCS, MCEJ, GTET, HGCS, DSNT, SDLT, SDLP, FLEX,XRMI,XRMI-I,ACRT, HFSC, ACRT, SP, HLFD,TOTOAL LENGTH OF TOOL STRING 113.86'MAX OD 5" 00:45 06:00 5.25 0 0 PROD1 EVALFN ELOG P Open Hole Logging operations RIH U 7093'log out of hole 30'a min to top of zone of interest,open hole calliper log out of hole @ 50'min U 7 5/8" casing shoe, POOH 06:00 08:30 2.50 0 0 PROD1 EVALFN ELOG P R/D Halliburton E-Line equipment. 08:30 12:00 3.50 0 0 COMPZ CASING RURD P R/U U run 5.5"casing w/Volant CRT, C/O saver sub install long bails. Remove wear ring. 12:00 15:00 3.00 0 0 COMPZ CASING RURD P Continue Rigging up casing equipment, Slips elevators and Volant tool. 15:00 16:30 1.50 0 0 COMPZ CASING RURD T Continue R/U U run 5.5"Casing, slips and Volant tool dressed to wrong size, redress and rig up 16:30 17:00 0.50 0 0 COMPZ CASING SFTY P Pre Job Safety Meeting on Running Casing with all involved parties. 17:00 22:30 5.50 0 370 COMPZ CASING PUTB P Run 5.5 casing as per detail U 370' taking weight unable to get down, work string f/172'-370'w/pumps 210 gpm 600 psi, unable to work down. 22:30 00:00 1.50 370 298 COMPZ CASING PULL T R/U double stack tongs, UD Volant CRT tool, UD 5.5 casing removing centralizers U 298' 09/07/2014 Finish POOH L/D 5.5"Casing Removing Centralizers, R/D lay down equipment, R/U&RIH w/5.5"Casing Using Volant CRT U 6000' Filling pipe every jt, Circ&shoe 3600',4800'No Hole Issues rotate jts 6-21 down unable to slack off without rotation no issues from 22 on. 00:00 03:00 3.00 298 0 COMPZ CASING PULL T Continue POOH UD 5.5"Casing removing all centralizers and stop rings, Clean and inspect threads, Centralizers showed abnormal wear, stop collars were wearing on Surface casing. 03:00 03:30 0.50 0 0 COMPZ CASING RURD T R/D Double stack tongs and L/D equipment. 03:30 04:00 0.50 0 0 COMPZ CASING SFTY P Pre Job Safety Meeting on Running 5.5"Casing 04:00 12:00 8.00 0 2,117 COMPZ CASING PUTB P RIH w/5.5"Casing as per detail w/ Volant CRT U 2117', M/U torque 7k, Rotate jts 6-21 down,the rest hole without issues,filling every joint. 12:00 17:30 5.50 2,117 3,663 COMPZ CASING PUTB P Continue RIH w/Casing as per detail w/Volant CRT f/2117'U 3663 Page 16 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:30 18:00 0.50 3,663 3,663 COMPZ CASING CIRC P Circulate bottoms up 200 gpm 886 psi PUW-91k SOW-54k 18:00 21:00 3.00 3,663 4,836 COMPZ CASING PUTB P Continue t/RIH w/5.5"Casing f/ 3663't/4836' PUW-116k SOW- 56k 21:00 21:30 0.50 4,836 4,836 COMPZ CASING CIRC P Circulate and condition mud 180 gpm 815 psi PUW-116k SOW-56k 21:30 00:00 2.50 4,836 6,000 COMPZ CASING PUTB P Continnue RIH w/5.5"Casing f/4836' t/6000' PUW- 130k SOW-63k 09/08/2014 RIH w/5 1/2"casing f/6000' to 7051'-PU hanger&landing jt. -Land casing-Circ&condition for cmt job- Cement 5 1/2"casing w/48 bbls lead&13.5 bbls tail-RD f/cmt job-Set&test pack-off-freeze protect OA w/44 bbls diesel-RU&LD 4"Dp 00:00 03:30 3.50 6,000 7,051 COMPZ CASING PUTB P Cont. RIH w/5 1/2" 15.5#L-80 Hyd 563 casing f/6000'to 7051.32' (168 jts total in hole)PU wt 155 k SO wt 70 k 03:30 04:00 0.50 7,051 7,084 COMPZ CASING HOSO P MU FMC csg hanger w/pups jts. & landing jt.-Land casing on hanger in wellhead w/shoe @ 7083.62' -FC @ 6996.49' -PU wt 155 k SO wt 72 k 04:00 04:30 0.50 7,084 7,084 COMPZ CASING RURD P RD Volant casing running tool-RU cmt head and lines 04:30 08:00 3.50 7,084 7,084 COMPZ CEMEN-CIRC P Break circ&stage pump up to 5 bbls/min @ 770 psi-Circ& condition for cement job- reciprocating casing w/25'stroke- PUwt130k SOwt80k- Schlumberger cementers spotting equipment&rigging up 08:00 08:30 0.50 7,084 7,084 COMPZ CEMEN-SFTY P Held PJSM w/rig crew,truck drivers &Schlumberger cementers ( Continued to circ during PJSM) 08:30 09:30 1.00 7,084 7,084 COMPZ CEMEN-CMNT P Cemented 5 1/2"casing as follows: Pumped 5 bbls CW-100-Tested lines to4500 psi-Pumped 25 bbls CW-100 @ 5 bbls/min @ 650 psi- Mixed&pumped 32 bbls 11,0 ppg (61 MudPush @ 5 bbls/min @ 725 psi- ,f Mixed&pumped-Dropped btm plug -Mixed&pumped 48 bbls Lead slurry( LiteCrete Gasblok)@ 12.0 ppg @ 5 bbls/min @ 850 psi-Mixed &pumped 13.5 bbls Tail slurry(, GasBlock)@ 15.8 ppg @ 5 bbls/min @ 700 psi-Shut down- Close in head&flush lines w/8.4 bbls water Page 17 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09:30 10:30 1.00 7,084 7,084 COMPZ CEMEN-DISP P Line up&dropped top plug- Displaced cement w/Seawater @ 5 bbls/min @ 1800 psi for 149 bbls.- Slowed pump to 2 bbls/min @ 1100 psi-Bumped plug @ 166 bbls total displacement -pressure up to 1800 psi-Held for 5 mins. -Bled off pressure to check floats-floats held OK- Reciprocated pipe w/25' stroke until 4 bbls of tail slurry out shoe landed back on hanger-Full circulation through job-CIP @ 10:15 hrs 10:30 12:00 1.50 7,084 7,084 COMPZ CEMEN RURD P RD cmt lines&remove cmt head- blow down lines-LD landing jt- Drain stack 12:00 14:00 2.00 7,084 7,084 COMPZ CEMEN VWVSP P Change bales(ong to short)MU pack-off running tool-Set pack-off 9 Test to 5000 psi for 10 mins. -Set wear bushing 14:00 16:30 2.50 7,084 7,084 COMPZ CEMEN OTHR P Flush mud system lines-clean under rotary table- Clean pits 16:30 21:00 4.50 7,084 7,084 COMPZ CEMEN FRZP P RU&flush OA w/48 bbls freah water -Pumped @ 2.5 bbls/min @ 520 psi -RU Little Red Services and pumped 44 bbls diesel down OA @ 2 bbls/min @ 700 psi-Changed out TD saver sub- Remove blower hose- Removed kelly hose for laying down DP while Little Red was pumping diesel freeze protect 21:00 00:00 3.00 COMPZ CEMEN PULD P Lay down 4" DP f/derrick via mouse hole 09/09/2014 LD 4" DP. Freeze Protect well with ISOTHERM. Load shed with PH-6 work string. RU Halliburton E-Line and PU tools. 00:00 05:00 5.00 7,084 7,084 COMPZ CEMEN-PULD P Lay down 4" DP f/derrick via mouse hole 05:00 06:30 1.50 7,084 7,084 COMPZ CEMEN-FRZP P Pump ISOTHERM Freeze Protect. 7.5ppg and 60 degrees at time of pumping, extremely viscous and thick consistency. Initial Pressure 700 psi @ 1 bpm. Final Pressure 850 psi @ 0.7 bpm. SIMOPS: Continue lay down 4" DP f/derrick via mouse hole 06:30 09:30 3.00 7,084 7,084 COMPZ CEMEN PULD P Continue lay down 4" DP f/derrick via mouse hole 09:30 11:30 2.00 7,084 7,084 COMPZ CEMEN SFTY T Safety inspection of Derrick due to ice falling from derrick to rig floor. Rig floor cleared and work stopped until all ice that might potentially fall is removed from derrick. 11:30 14:00 2.50 7,084 7,084 COMPZ CEMEN-PULD P Continue lay down 4" DP f/derrick via mouse hole Page 18 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:00 16:00 2.00 7,084 7,084 COMPZ PERF ELNE P Install dutch riser. SIMOPS: Clean and clear rig floor, mud system, rotary table with super sucker. Load 3.5"PH-6 pipe in shed. 16:00 18:00 2.00 7,084 7,084 COMPZ PERF SVRG P Service Top Drive and Drawworks. Install Kelly Hose. SIMOPS: Load 3.5"PH-6 pipe in shed. 18:00 20:00 2.00 7,084 7,084 COMPZ PERF ELNE P Make Up Lubricator. Load into pipe shed. Load Halliburton tools to pipe shed. 20:00 22:30 2.50 7,084 7,084 COMPZ PERF ELNE T Halliburton trailer disconnect broken. Trouble shoot trailer disconnect in order to spot up unit. 22:30 00:00 1.50 7,084 7,084 COMPZ PERF ELNE Continue to rig up E-Line tool and lubricator. 09/10/2014 Continue R/U V E-Line, M/U Dummy Gun Run, RIH V 6790' POOH, P/U Perf Run#1 6 SPF 60° Phase Millenium Charges RIH, Perf f/6740'V 6725' POOH P/U Perf Run#2 6 SPF 60° Phase Millenium Charges, RIH, Perf f/6632'V 6612', POOH L/D Guns, P/U 4.85 Gauge Ring/Junk Basket Tool string, RIH V 6790', POOH, P/U Baker Lower Packer Assy. RIH take wt @ 136'work through V 313'unable to get deeper, 900 Lbs Over Pull, POOH L/D Tool string, R/D E-Line Clear Floor, R/D Dutch Riser. 00:00 03:00 3.00 0 0 COMPZ PERF ELNE P Continue R/U E-Line f/dummy gun run, M/U Lubricator and dummy gun tool string. 03:00 04:00 1.00 0 0 COMPZ PERF ELNE P Pressure test lubricator t/1500 psi, trouble shoot leaking pack off, retest same good test. 04:00 07:00 3.00 0 0 COMPZ PERF ELNE P RIH w/dummy gun tool string V 6967' POOH Tool String 29.19' L/D Tool String 07:00 07:30 0.50 0 0 COMPZ PERF SFTY P Pre Job Safety Meeting with all parties involved on P/U Perforating Guns, 07:30 12:30 5.00 0 0 COMPZ PERF ELNE P P/U perf gun assembly 3.125"6 SPF 60° Phase Millenium Charges, RIH V shot depth correlate and fire guns Perf f/ 6725'-6740'Tool string 29.19' POOH . CCL t/top shot 7.7' CCL to Bottom Shot 22.5'CCL Stop Depth 6717.3' 12:30 13:00 0.50 0 0 COMPZ PERF SFTY P Pre Job Safety Meeting on L/D Perf Guns and P/U new Perf guns. 13:00 16:00 3.00 0 0 COMPZ PERF ELNE P L/D spent guns all shots verified fired, P/U second perf assembly 6 SPF 60° Phase Millenium Charges, RIH V shot depth correlate perf guns, fire perf guns 6612'-6632'Tool String 29.19', CCL to top shot, 7.7' CCL V Bottom Shot 27.5'CCL Stop Depth 6604.3' POOH 16:00 16:30 0.50 0 0 COMPZ PERF SFTY P Pre Job Safety Meeting Discussing Perf Gun Handling. 16:30 18:30 2.00 0 0 COMPZ PERF ELNE P L/D Perf Guns/Change Out tools V Gauge ring Junk basket,4.85 OD RIH V 6970' POOH No hole Issues, L/D Junk Basket&Gauge Ring. Page 19 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:30 21:30 3.00 0 0 COMPZ RPCOM ELNE T M/U Packer Assy. on HES E-Line RIH,Take Weight @ 136'Work E-Line Continue RIH t/302'Taking weight observe 400lbs over pull f/ 296'down,Work tool string t/313' observe over pull 900 lbs unable to work past 313' POOH Observe over pull @136' 21:30 00:00 2.50 0 COMPZ RPCOM ELNE P L/D E-Line Tool String R/D HES E-Line, R/U Dutch Riser, Blow Down Lines, Clean&Clear Floor, P/U BHA Components f/Next Run 09/11/2014 R/U handling equipment f/3'/2'Work String, M/U FA-1 Packer Assy, RIH w/3'/2' PH6 work string f/shed t/ 6756', Slip&Cut 118'of Drilling Line, R/U HES E-Line, RIH w/CCL&Gamma t/6703'Corelate Packer w/RA tag @ 6445.83' POOH, R/D E-Line Equipment, Space out packer, Tubing tail @ 6711' Packer @ 6688', Circulate pipe Volume. 00:00 02:30 2.50 0 0 COMPZ RPCOM RURD P R/U GBR Power Tongs and handling equipment. 02:30 04:00 1.50 0 35 COMPZ RPCOM PUTB P M/U FA-1 Packer Assembly BHA, RIH 04:00 12:00 8.00 35 4,099 COMPZ RPCOM PULD T RIH w/3'/2' PH6 work string f/35't/ 4099', P/U f/shed,60'per/min running speed 75k-PUW 55k- SOW 12:00 17:30 5.50 4,099 6,756 COMPZ RPCOM PULD T Continue RIH w/3'/2' PH6 Work String P/U V shed V 4099't/6756' 17:30 19:00 1.50 6,756 6,756 COMPZ RPCOM SLPC P Slip and Cut Drilling Line 118'Service _ Draworks and Break Linkage 19:00 20:00 1.00 6,756 6,756 COMPZ RPCOM ELNE T R/D HES E-Line w/CCL&Gamma to corelate Packer 20:00 22:00 2.00 6,756 6,756 COMPZ RPCOM ELNE T RIH w/E-Line t/corelate packer set down @ 6703'Corelate w/RA marker @ 6445.83' POOH w/Eline 22:00 00:00 2.00 6,756 6,756 COMPZ RPCOM ELNE T R/D HES E-Line and pressure control equipment. 09/12/2014 POOH UD Packer Running Assy#1, P/U Packer Assy#2 111'Total length RIH t/6500'Establish Parameters, ease in the hole and tag top of FA-1 packer#1 Latch and set packer#2 as per baker rep.test paker t/1000 psi V 10 min,good test, release V packer, POOH standing back 5 stands,set baker storm packer&test t/500 psi, Pull wear ring set test plug, R/U and Test BOPE 00:00 00:30 0.50 6,756 6,711 COMPZ RPCOM HOSO T L/D 1 jt P/U 4'above rotary table, tubing tail @ 6711'packer @ 6688' 00:30 01:30 1.00 6,711 6,711 COMPZ RPCOM PACK P Circulate tubing volume @ 3 bpm 540 psi, shut down drop ball pump t/ seat @ 2 bpm 220 psi Ball on seat pressure up t/1500 psi hold pressure V 5 min, P/U 30k over string weight @ shear off of FA-1 Packer. 01:30 02:15 0.75 6,711 6,690 COMPZ RPCOM CIRC T Circulate bottoms up 4.5 bpm 1300 psi 02:15 07:45 5.50 6,690 43 COMPZ RPCOM TRIP T POOH w/3'h"PH6 Work String, f/ 6690't/43' 07:45 08:45 1.00 43 0 COMPZ RPCOM PULD P L/D Packer running tool f/#1 packer, 08:45 10:45 2.00 0 111 COMPZ RPCOM PUTB P M/U#2 Packer BHA as per detail 111.41'Total Page 20 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:45 19:45 9.00 111 6,500 COMPZ RPCOM TRIP P RIH w/FA-1 Packer Assy#2 on 3'/z' PH6 Work String f/111't/6500' 19:45 21:30 1.75 6,500 6,684 COMPZ RPCOM PACK P Establish Parameters PUW-115 SOW-74 Slack off and engage Lower Packer Assy. set packer @ 6596.67'pressure up t/2000 psi pull 50k over string weight X 3, Set packer, R/U&Test annular t/1000 psi f/10 min charted,good test, release f/packer w/5 turns t/right. 21:30 22:00 0.50 6,684 6,419 COMPZ RPCOM TRIP P Stand Back 5 stands in Derrick 22:00 22:45 0.75 6,419 6,479 COMPZ RPCOM MPSP P M/U&RIH w/Baker Storm Packer set @ 60'&test t/500 psi good test, L/D 2 jts 22:45 23:15 0.50 6,479 6,479 COMPZ WHDBO RURD P R/U&Pull Wear Ring&Set test Plug,fill choke manifold, Bleed Air 23:15 00:00 0.75 6,479 6,479 COMPZ WHDBO BOPE P Test BOPS w/3.5"Test jt t/ 250/3500 psi,test#1 Blinds choke valve#1,2,3& 16,2"Demco 09/13/2014 Finish Testing BOPE, R/D Test Equip, Pull Storm Packer, POOH L/D 3'/Z"Work String, L/D Baker RunnignTool, R/U&Run Upper Completion As per Detail t/288'(Work through tight spot f/150't/220') 00:00 06:00 6.00 6,479 6,479 COMPZ WHDBO BOPE P Continue testing BOPE w/3'/z'test jt,Test choke valves 1-16,Auto& Man. IBOP, HCR&Man. Choke& Kill,TIW&Dart,2" Demco, Upper Lower&Blind Rams,Annular, Man &Htd Choke,t/250/3500 psi f/5 min. State Inspector Jeff Jones Waived Witness of test.Accumulator test 06:00 07:00 1.00 6,479 6,479 COMPZ WHDBO RURD P R/D Test equipment Blow down lines, Pull test plug&Set wear ring RILDS. 07:00 09:00 2.00 6,479 6,419 COMPZ RPCOM MPSP P P/U 2 jts of 3'/z'PH6 RIH Unable t/ Engage packer, Kelly up Wash down U top of packer, Engage packer, P/U t/release packer, POOH L/D as per baker rep. Gravel found in connection. 09:00 14:30 5.50 6,419 3,495 COMPZ RPCOM PULD P POOH L/D 3'/2' PH6 f/6419'U 3495' 14:30 15:00 0.50 3,495 3,964 COMPZ RPCOM TRIP P RIH w/remaining 5 stands f/Derrick f/3495't/3964' 15:00 19:00 4.00 3,964 45 COMPZ RPCOM PULD P POOH L/D 3%" PH6 f/3964'U 45' 19:00 19:30 0.50 45 0 COMPZ RPCOM PULD P L/D Packer running tool as per Baker 19:30 20:00 0.50 0 0 COMPZ RPCOM RURD P R/U&Pull Wear Ring 20:00 20:30 0.50 0 0 COMPZ RPCOM RURD P Clean&Clear Rig Floor, P/U Completion Equip. 20:30 21:00 0.50 0 0 COMPZ RPCOM SFTY P Pre Job Safety Meeting on Running 3'/2' Upper Completion 21:00 00:00 3.00 0 288 COMPZ RPCOM PUTB P Run 3%"Uper Completion as per detail U 288', M/U torque 2240 ft/lbs Work through tight spot f/150'U 220' Page 21 of 23 I Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 39/14/2014 24 hr Summary Run Upper Completion as per Detail t/6597'engage K-Anchor Shear PBR, Space out&M/U Hanger, Displace well w/77 bbls Corrosion Inhibited sea water, Land hanger, RILDS,test tubing t/2500 f/30 min, bleed off t/2000 psi,Test Annulus t/2500 f/30 min, bleed tubing shear SOV, Set BPV&Test in direction of flow,shear WLEG w/3500 psi, N/U stack 00:00 12:15 12.25 288 6,595 COMPZ RPCOM PUTB P RIH w/3%" EUE 9.3#Upper Completion as per detail f/288't/ 6595'PUW-93k SOW-64k 12:15 15:00 2.75 6,537 6,597 COMPZ RPCOM HOSO P Slack off latch into K anchor @ 6597' Pull 20k Over,good latch, Pressure up&Shear PBR w/2000 psi. 15:00 17:00 2.00 6,597 6,504 COMPZ RPCOM HOSO P L/D 3 jts P/U Space out Pup, M/U Hanger&Landing Jt. 17:00 18:30 1.50 6,504 6,540 COMPZ RPCOM CRIH P Displace well t/corrosion Inhibited sea water, 3 bpm 650 psi, 18:30 19:30 1.00 6,540 6,579 COMPZ RPCOM THGR P Land on Hanger w/2'space out f/ fully located, RILDS, L/D landing jt. R/D GBR 19:30 21:00 1.50 0 0 COMPZ RPCOM PRTS P Test tubing t/2500 psi f/30 min, good test, bleed pressure t/2000 psi, Pressure test annulus t/2500 psi f/30 min, good test, Bleed tubing pressure off and shear DCK Valve @ 2000 psi. 21:00 22:00 1.00 0 0 COMPZ WHDBO MPSP P Set H Type BPV, R/U&test in direction of flow t/1500 psi f/10 min, Continue pressuring up t/3500 psi& shear WLEG 22:00 23:00 1.00 0 0 COMPZ WHDBO RURD P R/D all test equip, Blow Down lines, Suck out stack, prep cellar t/N/D BOP Stack 23:00 00:00 1.00 0 0 COMPZ WHDBO NUND P N/D stack, remove kill line&riser, start breaking bolts on BOPE Stack 09/15/2014 MU adaptor flange onto the well head and MU tree as pre FMC rep. Test tubing spool adaptor void to 250/5000 psi for 10 minutes(good test). Pull BPV and set two-way check. Fill tree with diesel and test tree to 250/5000 psi for 5 minutes(charted,good test). RD test equipment. Freeze protect the well(IA=200 psi, Tbg=370 psi)by pumping 45 bbls diesel @ 1.5 BPM= 1050 psi down the IA taking returns out the tubing. Shutdown LRS. Allow diesel to u-tube and equalize(IA= 150 psi,Tbg=0 psi). Set 3"'H' BPV per FMC rep. Secure the wellhead per FMC rep. Install gauges on the IA, OA, and top of tree. RD and prep the rig to move. ***RIG RELEASE @ 23:59 HOURS 9/15/14*** 00:00 03:30 3.50 0 0 COMPZ WHDBO NUND P Pull mouse hole and set in pipe shed. Remove turn buckles from stack and prep cellar for setting stack back on the stump. PJSM will all involved personnel. Pull stack from the wellhead,set back,and secure on the stump. Remove all rig equipment from annulus and install flanges/gauges. 03:30 08:00 4.50 0 0 COMPZ WHDBO NUND P MU adaptor flange onto the well head and MU tree as pre FMC rep. Test tubing spool adaptor void to 250/5000 psi for 10 minutes(good test). Pull BPV and set two-way check. L_ Page 22 of 23 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 09:30 1.50 0 0 COMPZ WHDBO PRTS P Fill tree with diesel and test tree to 250/5000 psi for 5 minutes(charted, good test). RD test equipment. 09:30 12:00 2.50 0 0 COMPZ WHDBO FRZP P RU LRS. RU to U-tube 12:00 12:30 0.50 0 0 COMPZ WHDBO SFTY P PJSM with LRS to freeze protect. 12:30 15:00 2.50 0 0 COMPZ WHDBO FRZP P Freeze protect the well (IA=200 psi, Tbg=370 psi)by pumping 45 bbl's diesel @ 1.5 BPM= 1050 psi down the IA taking returns out the tubing. Shutdown LRS. Allow diesel to u-tube and equalize(IA= 150 psi, Tbg=0 psi). 15:00 16:00 1.00 0 0 COMPZ WHDBO FRZP P Blow down and RD hoses, valves, and soft line from cuttings tank. Suck out wellhead to set BPV. 16:00 16:30 0.50 0 0 COMPZ WHDBO MPSP P Set 3"'H' BPV per FMC rep. 16:30 17:30 1.00 0 0 DEMOB MOVE RURD P Secure the wellhead per FMC rep. Install gauges on the IA, OA, and top of tree. 17:30 00:00 6.50 0 0 DEMOB MOVE RURD P Suck out the pits and cuttings box. Move all DP from the front of the sub in prep to move the rig. Move 3rd party units and auxiliary fuel tank. RD scaffolding off cuttings box. RD Berm for fuel tank and cuttings box. Move cuttings box. Spot 3rd party units. Jack up the sub and pull mats from under sub. Move pits across location. 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NY NLo mNONM�A 0 to 0.y O 00 (�pp aO�pp In. 4 OO M 0O INO00r OO.(0 NO NN N000 N n w NOO Io 00100OON n'000r°0N PY0000 et 100 n o N MN N N N N NN N N N N M M M M M 0 CO M CO M M M M V Y000Oet<O et et V Y00000001(10 0 (y C n 00 0... N rr U 2 'OC N �p o �p p 0 0 _ �:.INOOmrOOOND�AmmNro000O0OrO00r�p•�(pO�pNN W O�pt00�pO0m0OOo.W�CND00ONrN001 0 8 E ar M OO = N COOMM0C0')M«vv OV et V Y V V V v fr000OOa0 V V<v N.M M M O Q V V V V'Q OO)t0'l0 M * LL v N M z. NnO 0 CC N OO N p0p f cr H V -11-10 0. O M0O1 CCO VCY CO r v Ae NCOO r(00(p0e1.00(p0r CD M V 00((CO 0p0000003 NM rO00)OMO COV COV 0000Yr(NOr O 0 0 0 L r r r r LLOLL `vCO vo-CO V C V MMMMMMMMMMMMMMM(hMMCOY(0+1(0+1vv V v V aMCOYMMMCOYCOYno.*M9 Ll rlj 6Oi O O 11 M d C 0 0 J Co J 0 LL 2416 JU00 N. co Or M mrNOM(pTV VOroYWs-OTmrO0INop rNrM0NMN0 rTMAOC0..ON00DO0,00.0retr O01O (OOV = eN I 0 pp( OM0O00y0 NO� 0p0r00pNN0YMM( l .1VReaVDet0000O00000Nmm0N00n , a� O C In O OJ a N E u V I1 m 0 p 0 00 O V Y y v w r L1507 0 E �m 2 22 m = V (A a m ('. , p . . . . _ . . . . . _ . . • 0 o !+ ) ;£ / / k / o - % \ co • z• ` < , a 0- E { / ƒ r.) ` (.3 ° E)) o0 §`f ) - \ - [ k°I �f \ ▪E. a•}• ƒ \�k\( \ a , %6 )eEEe k § .. co r2, kce cO ( ( 6 • Cement Detail Report 01; 2N-303 ConocoPhillips String: Cement 5.5" Production Job: Cement Details Description Cementing Start Date Cementing End Date Wellbore Name Cement 5.5"Production 9/8/2014 10:40 9/8/2014 00:00 2N-303A Comment Cemented 5 1/2"casing as follows: Pumped 5 bbls CW-100-Tested lines to4500 psi-Pumped 25 bbls CW-100 @ 5 bbls/min @ 650 psi-Mixed&pumped 32 bbls 11,0 ppg MudPush @ 5 bbls/min @ 725 psi-Mixed&pumped-Dropped btm plug-Mixed&pumped 48 bbls Lead slurry(LiteCrete Gasblok)@ 12.0 ppg @ 5 bbls/min @ 850 psi-Mixed&pumped 13.5 bbls Tail slurry(GasBlock)@ 15.8 ppg @ 5 bbls/min @ 700 psi-Shut down-Close in head&flush lines w/ 8.4 bbls water Line up&dropped top plug-Displaced cement w/Seawater @ 5 bbls/min @ 1800 psi for 149 bbls.-Slowed pump to 2 bbls/min @ 1100 psi-Bumped plug @ 166 bbls total displacement -pressure up to 1800 psi-Held for 5 mins. -Bled off pressure to check floats-floats held OK- Reciprocated pipe w/25'stroke until 4 bbls of tail slurry out shoe landed back on hanger-Full circulation through job-CIP @ 10:15 hrs Cement Stages Stage#1 Description Objective Top Depth(ftKB) Bottom Depth(ftKB) Full Return? Vol Cement.. Top Plug? Btm Plug? Cement 5.5"Production 4,689.0 7,093.0 No Yes Yes Q Pump!nit(bbl/m...Q Pump Final(bbl/...Q Pump Avg(bbl/... P Pump Final(psi) P Plug Bump(psi) Recip? Stroke(ft) Rotated? Pipe RPM(rpm) 5 2 5 1,100.0 1,800.0 Yes 25.00 No Tagged Depth(ftKB) Tag Method Depth Plug Drilled Out To(ftKB) Drill Out Diameter(in) Comment Cemented 5 1/2"casing as follows: Pumped 5 bbls CW-100-Tested lines to4500 psi-Pumped 25 bbls CW-100 @ 5 bbls/min @ 650 psi-Mixed&pumped 32 bbls 11,0 ppg MudPush @ 5 bbls/min @ 725 psi-Mixed&pumped-Dropped btm plug-Mixed&pumped 48 bbls Lead slurry(LiteCrete Gasblok)@ 12.0 ppg @ 5 bbls/min @ 850 psi-Mixed&pumped 13.5 bbls Tail slurry(GasBlock)@ 15.8 ppg @ 5 bbls/min @ 700 psi-Shut down-Close in head&flush lines w/ 8.4 bbls water Line up&dropped top plug-Displaced cement w/Seawater @ 5 bbls/min @ 1800 psi for 149 bbls.-Slowed pump to 2 bbls/min @ 1100 psi-Bumped plug @ 166 bbls total displacement -pressure up to 1800 psi-Held for 5 mins.-Bled off pressure to check floats-floats held OK- Reciprocated pipe w/25'stroke until 4 bbls of tail slurry out shoe landed back on hanger-Full circulation through job-CIP @ 10:15 hrs Cement Fluids&Additives Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) CW 100 2,081.0 3,385.0' 30.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 8.30 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) MudPush II 3,385.0 4,689.0 32.0 Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(lb/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 11.00 Additives Additive Type Concentration Conc Unit label Fluid Fluid Type Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) LiteCrete Gasblok-- 4,689.0 6,653.0 164 Litecrete Gasblock 48.0 Lead Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(Ib/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.64 5.58 12.00 6.25 Additives Additive Type Concentration Conc Unit label D046 Antifoam 0.2 BWOB Additive Type Concentration Conc Unit label D047 Antifoam 0.1 gal/sx Additive Type Concentration Conc Unit label D065 Dispersant 0.25 BWOB Additive Type Concentration Conc Unit label D600G GasBlock 2.0 gal/sx Fluid Fluid Type - Fluid Description Estimated Top(ftKB) Est Btm(ftKB) Amount(sacks) Class Volume Pumped(bbl) Intermediate Gasblok 7,088.0 6,653.0 65 G Gas Block 13.5 --Tail Yield(ft'/sack) Mix H2O Ratio(gal/sa... Free Water(%) Density(Ib/gal) Plastic Viscosity(Pa•s) Thickening Time(hr) CmprStr 1(psi) 1.17 5.24 15.80 5.01 Page 1/2 Report Printed: 10/8/2014 .. `' Cement Detail Report 0:',,, 2N-303 ilIps String: Cement 5.5" Production Job: Additives Additive Type Concentration Conc Unit label D186 Accelarator 0.1 gallsx Additive Type Concentration Conc Unit label D047 Antifoam 0.2 gal/sx Additive Type Concentration Conc Unit label D065 Dispersant 0.35 %BWOC Additive Type Concentration Conc Unit label D600G GasBlok 2.0 gal/sx Page 2/2 Report Printed: 10/8/2014 Zia�3 k4 0`6 c6 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. September 30, 2014 Attn.: Malcana Bender DATA LOGGED to/b/2014 333 West 7th Avenue, Suite 100 Id.K.BENDER Anchorage, Alaska 99501 Kaaav Iry ,y i.r� )CT 0 3 014 RE: Perforation Record- Packer Correlation: 2N-303A 'C' Run Date: 10-11 SEPT, 2014 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 FRS_ANC@halliburton.com 2N-303A Digital Data(LAS), Digital Log file 1 CD Rom 50-103-20352-01-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3572 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: 1,0 l (IN 2-t Signed `4 4 I .e4c4'it �w��\��%%%� TIDE STATE �, - w, Tr 3 �r Grac is � s�#— — —_ �' ../. .,,„..)_,_.,..,_ .__,„,._j ,____,, ,_ � 333 West Sc-.'Fr1h Avenue ,,,101-:=_----- �� GOVERNOR SEAN PARNFLL Anchorage, AlasKa 99501-3572 ilif.:0, Mom 907 279 1233 Adan Klem Sr. Completions Engineer ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Tarn Oil Pool, KRU 2N-303A Sundry Number: 314-522 Dear Mr. Klem: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, /9/4- 54,-..-- Cathy P. oerster Chair iL DATED this I'? day of September, 2014. Encl. STATE OF ALASKA RECEIVED • AL,-,,<A OIL AND GAS CONSERVATION COMM, DN SEP 1 $ 2014 'L APPLICATION FOR SUNDRY APPROVALS 9 / 2J( f--- 20 AAC 25.280 AOGCC 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r Change Approved Program 1.-- Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate p., Alter casing rOther: Fyq G Sf/lvr Id 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. , Exploratory r Developrrent �, 214-088-0 3.Address. Stratigraphic r Service �" 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-103-20352-01 . 7. If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception'? Yes r No J' 2N-303A .. 9.Property Designation(Lease Number): 10 Field/Pool(s): ADL 380054,380053 • Kuparuk River Field/Tarn Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft) Effective Depth TVD(ft): Plugs(measured): Junk(measured): 7099 % 5757 . 2800' none none Casing Length Size MD TVD Burst Collapse Conductor 97' 16" 140' 140' Surface 2589' 7.625" 2632' 2298' Production 7056' 5.5" 7084' 5755' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade. Tubing MD(ft): 6612'-6632',6725-6740' 5370'-5386',5458'-5470' 3.5 L-80 6711 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) Packer MD=6688 TVD=5429' no SSSV 12.Attachments Description Summary of Proposal 13 Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r'• Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work. 9/19/2014 Oil R . Gas r WDSPL r Suspended 1--- 16.Verbal Approval. Date. WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Adam Klem @ 263-4529 Email. Adam Klem@conocophillips com Printed Name am Klem Title: Sr. Completions Engineer Signature Phone:263-4429 Date g//7//ii Commission Use Only Sundry Number: ^ Conditions of approval. Notify Commission so that a representative may witness %kA{^52` Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Spacing Exception Required? Yes ❑ No [' Subsequent Form Required. /0— 0 4- e) APPROVED BY Approved by: 9COMMISSIONER THE COMMISSION Date:9—/5 /X – Approved application is valid for 12 months from the date of approval. ,,�� Form 10-403(Revised 10/2012) 'f lid 51i 0 Submit Form and ARE Rup p 2 4 1U I'� 1-�TL q/10/ 14 ORIGINAL ,�� 9' 2N-303A Sundry Application 2N-303A was drilled and the production liner casing was landed on 9/8/14. (A schematic of the completion is attached). The well was perforated in both the Purple and Bermuda, and will be fracture stimulated in both zones. We expect the production to be 300bopd in 2014 if a successful stimulation is achieved. Proposed Procedure: Schlumberger Pumping Services: (Bermuda sand Frac) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre-frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10-403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 6 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10%. Load tanks with 100° F seawater (approx. 8400 are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU Stinger Tree Saver Equipment and SLB Frac Equipment. 7. PT Surface lines to 8,000 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Pump the 54 bbl injectivity test (25# linear gel, WF127) according to the attached excel SLB pump schedule. Bring pumps up to maximum rate of 20 BPM as quick as possible, pressure permitting. Slowly increase annulus pressure from 3,000 psi to 3,500 psi as the tubing pressures up. 10. 16. Perform a hard shut down. Record ISIP and Monitor shut down 15-20 mins. 11. 17. Pump the 261 bbl Data Frac (25# crosslinked gel, YF125ST) according to the attached excel SLB pump schedule. Bring pumps up to maximum rate of 20 BPM as quick as possible, pressure permitting. 12. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 13. Pump the Frac job by following schedule @ 20bpm with a maximum expected treating pressure of 2,953 psi. Purple: • 470 bbls YF125ST Pad • 195 bbls YF125ST w/ 2 ppa 16/20 Carbolite • 310 bbls YF125ST w/4 ppa 16/20 Carbolite • 220 bbls YF125ST w/ 5 ppa 16/20 Carbolite • 240 bbls YF125ST w/ 6 ppa 16/20 Carbolite • 320 bbls YF125ST w/ 8 ppa 16/20 Carbolite • Flush with 37 bbls of linear fluid (WF125) and 19 bbls freeze protect AK • Total Sand: Approx. 226,000 lbs 16/20 Carbolite 14. Monitor the surface pressure fall-off at the end of the job for 30 minutes, if the well does not screen out. 15. Freeze Protect the tubing and wellhead if not able to complete following the flush. 16. Well is ready for Post Frac slickline prep for Bermuda frac. 17. PT Surface lines to 8,000 psi using a Pressure test fluid. 18. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 19. Pump the 61 bbl injectivity test (25# linear gel, WF127) according to the attached excel SLB pump schedule. Bring pumps up to maximum rate of 20 BPM as quick as possible, pressure permitting. Slowly increase annulus pressure from 3,000 psi to 3,500 psi as the tubing pressures up. 20. 16. Perform a hard shut down. Record ISIP and Monitor shut down 15-20 mins. 21. 17. Pump the 268 bbl Data Frac (25# crosslinked gel, YF125ST) according to the attached excel SLB pump schedule. Bring pumps up to maximum rate of 20 BPM as quick as possible, pressure permitting. 22. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 23. Pump the Frac job by following schedule @ 20bpm with a maximum expected treating pressure of 2,953 psi. Bermuda: • 470 bbls YF125ST Pad • 195 bbls YF125ST w/ 2 ppa 16/20 Carbolite • 310 bbls YF125ST w/4 ppa 16/20 Carbolite • 220 bbls YF125ST w/ 5 ppa 16/20 Carbolite • 240 bbls YF125ST w/ 6 ppa 16/20 Carbolite • 320 bbls YF125ST w/ 8 ppa 16/20 Carbolite • Flush with 35 bbls of linear fluid (WF125) and 19 bbls freeze protect • Total Sand: Approx. 226,678 lbs 16/20 Carbolite 24. Monitor the surface pressure fall-off at the end of the job for 30 minutes, if the well does not screen out. 25. Freeze Protect the tubing and wellhead if not able to complete following the flush. 26. Flowback will be initiated through Expro until the fluids clean up at which time it will be turned over to production. (Initial flowback fluids to be taken to appropriate disposal well until they are clean enough for production.) Cement Evaluation of 2N-303A and wells within 1/4 mile of 2N-303A 2N-303A: 5 1/2" Casing cement job was pumped on 9/9/2014 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, AK displaced by 8.5ppg seawater. The plug was bumped @ 1800 psi; the floats held. Good returns were observed during the job. 2N-306: 5 1/2" Casing cement job was pumped on 5/31/2004 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg "GasBLOK" G cement, displaced by 8.5 ppg seawater. The plug was bumped @ 2300 psi; the floats held. Good returns were observed during the job. Summary Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. It has also been determined that the frac will not adversely affect any nearby wells. AK Stimulation Surface Rig-Up S Bleed f Tattle Xyy-1 Tale Tank 2.JI •1 11 i;1 w> • Minimum pressure rating on all surface treating lines 10,000 psi • Main treating line PRV is set to 95%of max )8Q1110111 treating pressure • IA parallel PRV set to 3500 psi • Frac pump trip pressure setting are staggered and Cre 10011 set below main treating line PRV • Tree saver used on all fracs rated for 15,000 psi. E AI N N d C V- , N Horul dwnd r Tank :•43 Pump Truck Pop-Off Tank CN p Z> dna F J T r N 2„3 Frac Pum Frac Pump Frac Pump Nj}- N -- Frac Pump Frac Pump NAI "81— -- }--PFd-- Frac Pump AK Stimulation Tree Saver OPEN POSITION CLOSED POSITION (PRIOR TO MANDREL INSERTION) (MANDREL INSERTED) FRAC IRON �CONNECTION tl, i • El• ,, • ..i1 • j EMOTE OPERATED r i MASTER VALVE so a►. s s. t * 4.--. MANUAL OPERATED �411.0. MASTER VALVE O®1 0S....flit9 / Stinger / Stinger /MANDREL ` 4L. \ VENT ti `1®I.4--VALVE I - •\ OPEN ', , !lilt' hit OI`, J 0I /i'A� FLOW TEE AND •++/• !•• VENT VALVE WELLHEAD IS).;AL VALVES %///NImoi, OPEN Y WELLHEAD , VALVES CLOSED .. SX h. or N ,I o a %, /' .."-4 d f ._. OUAD PACKOFF - �' . ASSEMBLY IN •'1: — i• PLACE IN TUBING ; \ ,r., i- II1i, .I \ TUBING t ., 4 • The universal tool is rated for 15,000 psi and has 84" of stroke. • Tool ID 2.25" down 4 1/2 tubing and 1.75"down 3 %2 tubing. • Max rate with 2.25"mandrel is 60 bpm and with 1.75"mandrel 36 bpm AK Tarn 2N-303A Science(wp03) Rotary Sidetrack Selective Slant Producer ConocoPhillips Proposed Wellbore Schematic _ _,FMC Gen V 3-%"TREE 16" Existing Cemented Conductor: Klem:9/8/14 16"62.6#H-40 140' MD i 31/."Camco DS Nipple 2.875" 500'MD LSND ( ' Existing 7-5/8"Port Collar at 1,018'MD 9.6 for Cut& Pull 3'A"Camco KBG2-9 Existing Surface Casing: 7-5/8"29.7#L-80 BTCM 2,632' MD/2,298'TVD @ 39° 3'A"Camco KBG2-9 Sidetrack KOP off cement plug @ 39 degrees in open hole @ 2,790'MD Campanian Top 2,962'MD (2550'Tvo) \` LSND 9.6 PPG 6-Y2 x 7-1/2" Bi-Center Bit Keep up with Production Hole Dilution 3%"Camco KBG2-9 iceberg Top 5,367'MD(4,416'TVD) \11,\\ TOC 15.8 ppg @'i-4.689'MD 3'"Camco KBG2-9 T in : 3-'/2"9.3#L-80 EUE8RD ` Baker CMU Sliding Sleeve CLOSED w/2.813"DS Profile .; 3-'/."x 5-'/.",Baker FA Packer 6,550'MD • Selective Tubing: Top of Bermuda 6,484'MD 5,285'TVD 3-1/2" 9.3#TN-110SS Hydril 563 Bermuda Pore Pressure 7.1 ppg (1,956 psig) LSND 9.6 PPG = SLB High Burst sleeve CLOSED wi 2.813"X Profile,4.1" 3'/,",9.3#, Perls:6,612'-6,632' TN110SS,Hydril 563 tubing:6,622' Base of Bermuda 6,622'MD 5,391'TVD 3-1/2"x 5-%",Baker FA Packer 6,680'MD 3%"01111 Camco 2.75"D Nipple 3''/."Shearour sub To.Pur.le 6 647'MD 5411'TVD urple Pore Pressure Perfs:6,725'-6,740' 7.2 ppg (2,015 psig) Base Purple 6,705'MD 5,456'TVD Existing Production Casing: Production Casing: 5.5"x 3.5"L-80 15.5#&9.3#BTC-M 5-'/2" 15.5#L-80 Hydril 563 7,049'MD/5,739'TVD Existing completion P&A'ed in hole 5-1/2" 15.5#TN-110SS Hydril 563 for bottom 1,000 feet 7,084' MD/5,755'TVD @ 39° S O _ O O d U W M O O CDf, ti 0 N a z< Z ; M s 0 3° N � O o O W M Cr) 0 L; • w 7 FS m MO O CO M N N C 2 80 O 0 W —O do I r Z4.1� N O V..-.1 O T ch a) co w O Q co) —cD a N— • M CV o i M Z al N = a O _O ti N M Z• f I I 3 O O O O 0 O O O O O O O O N 1 L() CO d N. ci N d co (i�.j00L) (+ }JoN/(-)urO TS ca E cD ca 73 071) c -0 cz o a) 2 a" U m L. 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C._F _E..0 - 333 West Seventh Avenue -4/ GovI'RNOR SFAN PARNLLI Anchorage, Alaska 9950i 3572 Main 90/ 2i9 1433 ALI— G. L. Alvord Alaska Drilling Manager ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Tarn Oil Pool, 2N-303A ConocoPhillips Alaska, Inc. Permit No: 214-088 Surface Location: 5179' FNL, 500' FEL, Sec. 34, T1ON, R7E,UM Bottomhole Location: 2130' FNL, 3592' FEL, Sec. 35, T10N, R7E, UM Dear Mr. Alvord: Enclosed is the approved application for permit to 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 AOGCC 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 AOGCC 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 AOGCC order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, A Cathy P oerster Chair DATED this3 day of July, 2014. RECEIVED 2 kz-k,- OOq STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 1 7 2014 PERMIT TO DRILL � � 20 AAC 25.005 1 a Type of Work lb Proposed Well Class Development-Oil Qa Service-Winj ❑ Single Zone Q, 1c Specify if well is proposed for Drill ❑ Lateral ❑ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Redrill 1=1, Reentry❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Geothermal ❑ Shale Gas ❑ 2 Operator Name 5 Bond U Blanket. U Single Well 11 Well Name and Number. ConocoPhillips Alaska, Inc. Bond No 59-52-180 . 2N-303A, 3 Address: 6 Proposed Depth 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD:7088' . TVD. 5753'. Kuparuk River Field 4a Location of Well(Governmental Section) 7.Property Designation(Lease Number). Surface.5179"FNL,500'FEL,Sec.34,T1ON, R7E, UM ADL 380054,380053 Tarn Oil Pool - Top of Productive Horizon 8 Land Use Permit 13 Approximate Spud Date: 4153'FNL, 105'FEL,Sec.34,T1ON, R7E,UM 4602,4601 7/20/2014 Total Depth 9.Acres in Property. 14,43 14.Distance to 2130'FNL, 3592'FEL,Sec. 35,T1ON, R7E, UM ,fig--Sj Zo Nearest Property 1 mile 4b Location of Well(State Base Plane Coordinates-NAD 27) 10.KB Elevation above MSL' t 148 2 feet 15 Distance to Nearest Well Open Surface:x- 461093 y- 5912007 Zone- �t4 , GL Elevation above MSL . 120 2 feet to Same Pool 2N-302,245' 16 Deviated wells Kickoff depth 2790 'TY. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25 035) Maximum Hole Angle ,41° deg Downhole:2015 psig I Surface: 1474 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) 7.5" 5.5" 15.5# L-80 Hyd563 7060' 28' 28' 7088' 5753' 557 sx 15.8 Class G 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) 7057' 5744' none 6977 5686 none Casing Length Size Cement Volume MD TVD Conductor/Structural 97' 16" 10 cu yds High Early 140' 140' Surface 2589' 7.625" 448 sx AS III LW,240 sx G 2632' 2298' Production 7006' 3.5"x 5.5" 320 sx 15.8 CI G& 7049' 5739' 80 sx 13.0#Cl G Perforation Depth MD(ft): Perforation Depth TVD(ft): 6562'-6576', 6625'-6645' 5344'-5356', 5393'-5409' 20 Attachments Property Plat❑ BOP Sketch❑ Drilling Program Q Time v Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program ❑ 20 AAC 25.050 requirements Q 21.Verbal Approval' Commission Representative Date i/i 22 I hereby certify that the foregoing is true and correct Contact Steve Shultz @ 263-4297 Email Steve.Shultz@contractor.cop.com Printed Name G. L. Alvord Title Alaska Drilling Manager Signature ,4.0,�,.011/4.—_ /Phone:265-6120 Date G((6 1 2_0 (4- Commission Use Only Permit to Drill API Number. 1 Permit Appr vain f // See cover letter Number �1 M 0 21 50- /o3-a o 3 5,,Z-0/ -04 Date --/ l f1 17 Ifor other requirements Conditions of approval: If box is checked,well may nqt be used to explore for,test,or produce coalbed m thane,gas hydrates,or gas contained in shales Other: BOP -71-e-5/- o 3 SO p S Samples req'd. Yes No [ Mud log req'd: Yes❑ No DI H2S measures' Yes No Directional svy req'd: Yes El No Spacing exception req'd: Yes ❑ No Inclination-only svy req'd: Yes❑ No[' � :. iT / Approved by MMISSI ti R\ 1 1 Gf. ....1. t Date' 7 - 3 - `/ I T Form 10-401(Revs ed 10/2012) Vi h s p1 it is valid for Zttivnths off[h�111,date of approval(20 AAC 25.005(g)) /0 6.X/y ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 ConocoPhillips Telephone 907-276-1215 June 10, 2013 Alaska Oil and Gas Conservation Commission n eo 333 West 7th Avenue, Suite 100 �s �V Anchorage,Alaska 99501 Re: Application for Permit to Re-Enter and Re-Drill 2N-303/2N-303A / nn 20/4 Dear Sir or Madam: 0Gcrt ConocoPhillips Alaska, Inc. hereby applies for a permit to re-enter and sidetrack the 2N-303 slimhole monobore producer from the Tarn 2N drilling pad. This well, originally drilled in November 2000 has been shut-in since May of 2010 due to a hole in the 3'/"production tubing and the well has failed a C-MIT which is believed to have been caused by casing corrosion. The intended spud date for this well is July 20th,2014 using Nabors 9ES. In a pre-rig Sundry request(#314-052 approved 1/29/2014), prior to Nabors 9ES rig move onto 2N pad, pre-rig work will include spotting a 15.8 ppg cement plug in the 31/2"tubing and the IA. This will all be done with coiled tubing to isolate the Bermuda Sand below. Once the cement plug has been spotted the 3W tubing will be cut approximately at 3,000'MD. When Nabors 9ES rig moves onto 2N-303A, the proposed plan is to side track the well will commence by pulling the existing 3W tubing previously cut. Then run a 5'/2"CIBP on wireline and set it at+/-2,750' MD. A wireline casing cutter will then be run and the 51/2"casing will be cut at+/-2,730' MD. Once wireline has been rigged down, the 5'/"casing will be pulled. Drill pipe will be run in the hole and a 17 ppg kickoff plug will be spotted from 2,730' MD up to+/-2,400'MD. The well will be kicked off at+/-2,650'MD and re-drilled to+/-7,088' MD. The new hole will be cased with 5'/" 15.5#L-80 Hydril 563 casing and cemented in place. Cement is to be 500 feet above the C-37 formation. Once the well has been secured, perforating guns are to be picked up and perforations will be shot in the Bermuda and Purple formations. A final completion of 3W production tubing is to be run complete with gas lift mandrels, a sliding sleeve and nipples. 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. A proposed drilling program 3. A drilling fluids program summary. 4. Proposed completion diagram 5. Pressure information as required by 20 ACC 25.035(d)(2). 6. Directional drilling/collision avoidance information as required by 20 ACC 25.050(b). 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 Steve Shultz @ 263-4297. Sincerely, Ls 04 Chip Alvord CPAI Drilling Manager Attachments cc: 2N-303A Well File/Sharon Allsup-Drake ATO 1530 Liz Jolley ATO 1568 App. .on for Permit to Drill,Well 2N-303A Saved: 16-Jun-14 2N-303A Application for Permit to Drill Document Drilling I &Wells ConocoPhillips Table of Contents 1. Well Name (Requirements of 20 AAC 25.005 (t)) 2 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) 2 Requirements of 20 AAC 25.050(b) 2 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) 2 4. Drilling Hazards Information (Requirements of 20 AAC 25.005 (c)(4)) 2 ASP CALCULATIONS 3 5. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5)) 3 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) 4 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) 4 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) 4 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005 (c)(9)) 5 10. Seismic Analysis (Requirements of 20 AAC 25.005 (c)(10)) 5 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) 5 12. Evidence of Bonding (Requirements of 20 AAC 25.005 (c)(12)) 5 13. Proposed Drilling Program (Requirements of 20 AAC 25.005 (c)(13)) 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal 7 (Requirements of 20 AAC 25.005 (c)(14)) 7 2N-303A APD D I iu_' K Printed:16-Jun-14 App. ..on for Permit to Drill,Well 2N-303A Saved: 16-Jun-14 15. Attachment 1 — Drilling Hazards Summary 8 16. Attachment 2 — Proposed Well Schematic 9 17.Attachment 3 — Cement Summary 10 18. Attachment 4 — Directional Plan 11 1. Well Name (Requirements of 20 AAC 25.005(f)) The well for which this application is submitted will be designated as 2N-303A. 2. Location Summary (Requirements of 20 AAC 25.005(c)(2)) This well is planned as a rotary sidetrack of 2N-303 to improve Bermuda oil recovery and pattern sweep efficiency at Tarn. Planned operations include cutting and pulling the existing 3%" tubing and 5'/" production casing in the area near, but below the existing 7%" surface casing shoe, and setting a cement kickoff plug. The rig will then drill a 7%2" intermediate hole, run 5'/2"casing through the Bermuda and Purple reservoirs and finally cement with the top of cement at least 500' MD above the C-37 formation. A 3%" production tubing complete with gas lift mandrels will be run for the final completion Location at Surface 5,279' FNL 500' FEL Sec 34 T1ON R7E NAD 1927 RKB Elevation 148.2' AMSL Northings: 5,912,007.38 Eastings: 461,093.12 Pad Elevation 120.2' AMSL Location at Sidetrack Point ✓ 4,153.2' FNL 105.2 FEL Sec 34 T1ON R7E Nad 1927 Measured Depth, RKB: 2,790' Northings: 5913131.03 Eastings: 461,492.15 Total Vertical Depth, RKB: 2,419' Total Vertical Depth, SS: 2,271' Location at Total Depth 2,130.1 FNL 3592.3 FEL Sec 35 T1ON R7E Nad 1927 Measured Depth, RKB: 7,088' Northings: 5,915145.01 Eastings: 463292.33 Total Vertical Depth, RKB: 5,753' Total Vertical Depth, SS: 5,605' Requirements of 20 AAC 25.050(b) Please see Attachment 1: Directional Plan The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information (Requirements of 20 AAC 25.005(c)(3)) Please reference BOP schematics on file for Nabors 9ES. 4. Drilling Hazards Information (Requirements of 20 AAC 25.005(c)(4)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: 2N-303A APD Page 2 of 11 ORIGINAL Printed. 16-Jun-14 App .ion for Permit to Drill,Well 2N-303A Saved: 16-Jun-14 Csg Setting Fracture Pore Casing Size Depth Gradient pressure ASP (in) MD/TVD(ft) (lbs. /gal) (psi) Drilling (psi) 16 140/ 140 10.9 N/A N/A 7% 2,626/2,292 14.5 N/A N/A 51/2 7,088/5,753 15 2,300 1,504 3g-opsi O • NOTE: The Nabors 9ES 5000 psi BOP equipment is adequate. Test BOP to 4000 psi. eart5'5tt 'i PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) w! a1V-303 pevy far.-adv, 5,/kid (A)ASP is determined as the lesser of 1)surface pressure at breakdown of the formation casing (314-3 seat with a gas gradient to the surface, or 2)formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052)-0.1]D Where: ASP =Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in lb/gal 0.052 = Conversion from lb. /gal to psi/ft 0.1 = Gas gradient in psi/ft D =true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP-(0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point ASP CALCULATIONS 1. Drilling below surface casing (7%") ASP = [(FG x 0.052)-0.1] D _ [(14.5 x 0.052)-0.1] x 2,298' = 1,502 psi OR ASP = FPP-(0.1 x D) =2,015-(0.1 x 5,411') = 1474 psi (B)Data on potential gas zones; The well bore is not expected to penetrate any gas zones. (C) Data concerning potential causes of hole problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2- Drilling Hazards Summary S. Procedure for Conducting Formation Integrity Tests (Requirements of 20 AAC 25.005(c)(5)) Drill out from surface casing shoe and perform LOT or FIT in accordance with the Kuparuk LOT/ FIT procedure that ConocoPhillips, Alaska has on file with the Commission. 2N-303A APD Page 3 of 11 ORIGINAL Printed:16-Jun-14 App __.ion for Permit to Drill,Well 2N-303A Saved: 16-Jun-14 6. Casing and Cementing Program (Requirements of 20 AAC 25.005(c)(6)) Casing and Cementing Program Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD(in) (in) (lb/ft) Grade Conn. (ft) (ft) (ft) Cement Program 16 20 62.5 H-40 Welded 80' Surf 108'/108' Existing:Driven 7%" 9%" 40.0 L-80 BTC 2,609' Surf 2,637'/2,298' Existing:Cemented to Surface with 448 sx AS III LW&240 sx Class G 5'/2" 7'/2" 15.5 L-80 Hyd563 7,060' Surf 7,088'/5,753' Planned:Cement Top planned @ 4,689' MD/3889'TVD 690 ft 15.8 ppg Class G 3'/2" 9.3 L-80 EUE8R 6,622' 100' 6,650'/5,413' Uncemented tubing Casing / Liner Design: The 85% collapse and burst ratings are listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 75/8 29.7 L-80 3 BTCM 4,790 psi 4,071 psi 6,890 psi 5,857 psi 5W 15.5 L-80 3 Hyd563 4,040 psi 3,434 psi 4,810 psi 4,089 psi 3.5" 9.3 L-80 3 EUE8rd 10,530 psi 8,951 psi 10,160 psi 8,636 psi 7. Diverter System Information (Requirements of 20 AAC 25.005(c)(7)) Please reference diverter schematic on file for Nabors 9ES. 8. Drilling Fluid Program (Requirements of 20 AAC 25.005(c)(8)) Drilling will be done using LSND mud systems having the following properties: Drilling Fluid Properties Production Hole 7'/2" hole 5'/2" Casing _ Density 10.0 ppg / PV 12- 18 YP 22 -24 Initial Gels 18-22 10 minute gels 23 -27 API Filtrate <4 HPHT Fluid Loss at 160 <10 cc/30 min PH 9.3- 10 2N-303A APD Page 4 of 11 ORIGINAL Printed: 16-Jun-14 App. ,on for Permit to Drill,Well 2N-303A Saved: 16-Jun-14 Production Hole Section: LSND mud system. Plan to have good hole cleaning by maintaining low end rheology and pumping of regular sweeps. Maximize fluid annular velocity. There is pot,ntial for lost circulation in the target Bermuda reservoir. Maintain mud weight at or below 10.0 ppg and be prepared to add lost circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids will all be important in maintaining wellbore stability. Diagram of Nabors 9ES Mud System is on file. Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. 9. Abnormally Pressured Formation Information (Requirements of 20 AAC 25.005(c)(9)) N/A-Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis (Requirements of 20 AAC 25.005(c)(10)) N/A-Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis (Requirements of 20 AAC 25.005 (c)(11)) N/A-Application is not for an offshore well. 12. Evidence of Bonding (Requirements of 20 AAC 25.005(c)(12)) Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program (Requirements of 20 AAC 25.005(c)(13)) The proposed drilling program is listed below. Please refer to Attachment 2: Well Schematic. CP Tc5 f2 5 ' i 1. Rig is already in place and ready to drill since just finishing the plug back for side track. - yrs'S +' ' 2. Pick up 63/4"X 71/2" Reed Hycalog bi-centered bit, motor, MWD/LWD and RIH on 4"drillpipe. Tag TOC and IttAmay' pressure test 7%"surface casing and the cement kick off plug to 2,500 psi for 30 minutes. Record on chart, :14/2 per AOGCC. 3. Rig up E-line. Perform an E-line Gyro Survey down the drill pipe for orientation. 4. Dress off cement kickoff plug and control drill to below surface casing shoe to jump off of plug. 5. Drill out 20'of new formation once sidetracked. Perform FIT to 12.5 ppg EMW,if the well leaks off with less then 12.5 ppg MWE contact town engineer. 6. Directionally drill ahead with the 6%"X 71/2" bi-centered bit to the Iceberg at+/-5,368'MD maintaining 200 feet instantaneous ROP,once the top of the Iceberg is reached discontinue back reaming every stand on connections,just make standard connections. 7. Drill ahead to 7,088'MD with 150 RPM and 600+gpm 8. POOH on elevators while LD 4"drill pipe 9. Run 51/2" 15.5#, L-80, Hydril 563 casing to TD and land mandrel hanger in wellhead (ensure emergency slips on location). 2N-303A APD ORIGINAL Printed:16-Jun-14 App, .ion for Permit to Drill,Well 2N-303A . Saved: 16-Jun-14 10. RU cement equipment and test surface lines to 3500 psi. 11. Pump cement job with 12 ppg LiteCRETE GASBLOK slurry using 100%excess in open hole and displace with brine. 12. Freeze protect 51/2"x 7%"annulus to the surface shoe by bullheading 100 bbls seawater followed by 40 bbls diesel. 13. Test 51/2"casing to 3,000 psi for 30 minutes. Record on chart, per AOGCC. 14. PU 2/", 10.4#,S-135, HTPH-6 drill pipe and stand back in derrick 15. RU wireline, RIH with perforating guns and shoot the production intervals in the"Bermuda"and"Purple" Formations. POOH with wireline 16. MU gauge ring and junk basket on wireline, RIH to 6660'MD, POOH 17. MU 31/2 shear out sub,3%"tubing pup,Camco 31/2" "D" Nipple,3W tubing pup and a 3%"X 7%" Baker"FA" permanent packer 18. RIH on wireline and set packer at+/-6,620'MD, RD wireline 19. MU 31/2" Baker"K"anchor, 31/2'sliding sleeve(Schlumberger High Burst sleeve)with handling pups,3 1/2"tubing joints for space out and a 31/2"X 7%" Baker"FA"permanent packer with a PBR 20. RIH on the 2/8" 10.40#,S-135, HTPAC drill pipe, latch K-anchor in to bottom FA packer,set upper"FA"packer at+/-6,450'MD, pressure test packer to 3000 psi 21. Release B-2 running tool and POOH while laying down 2/"drill pipe 22. MU 31/2" Baker Seal Assembly,31/2"tubing jt,31/2" Baker Sliding Sleeve,31/2"tubing with four GLMS'(KBG-2's), 31/2"Camco "D" Nipple(@+/-500'MD)with 31/2"tubing to surface 23. RIH with completion assembly,once on bottom space out and land 31/2"tubing 24. Drop ball and and once ball is on seat, pressure test the 31/2"tubing to 3,000 psi,then bleed to 2,000 psi. Pressure test IA to 2,500 psi,then bleed tubing to zero which will shear SOV(in lowest GLM). These should be tested for 30 minutes and recorded on chart, per AOGCC. 25. Close in the back side and pressure up the tubing to 4,000 psi to shear the shearout sub. 26. Pressure test hanger seals to 5,000 psi, install blanking plug(or 2 way check valve),and test to 1,500 psi for 10 minutes. 27. Nipple down BOP. 28. Install tubing head adapter assembly and 4%e"tree. Pressure test adapter assembly and tree to 5,000 psi. 29. Remove blanking plug(or 2 way check valve). 30. Circulate 100 bbl freeze protect diesel down IA,taking returns up tubing through SOV. 31. Install 'H' BPV. 32. Secure well, RDMO. 2N-303A APD Page 6 of 11 ORIGINAL Printed: 16-Jun-14 App, ,on for Permit to Drill,Well 2N-303A . Saved: 16-Jun-14 14. Discussion of Mud and Cuttings Disposal and Annular Disposal (Requirements of 20 AAC 25.005(c)(14)) Waste fluids generated during the drilling process will be disposed of by hauling the fluids to a KRU Class II disposal well (1R-18 or new facilities at DS1B). 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 (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. 2N-303A APD Page 7 of 11 ORIGINAL Printed: 16-Jun-14 Api_ on for Permit to Drill,Well 2N-303A Saved: 16-Jun-14 15. Attachment 1 — Drilling Hazards Summary (To be posted in Rig Floor Doghouse Prior to Spud) Risk Description Mitigation Stuck 5W Casing Cutting & Pulling 5'/" casing Utilize wireline cutting tool Lost Circulation Lost circulation possible Reduced pump rates, trip Zones speeds, real time PWD monitoring, mud rheology, LCM addition Shallow Gas Watch for gas when Drill the interval with caution approaching the Campanian and prepare to weight up. Sand Make frequent flow checks to verify static prior to POOH. Swab/Surge Multiple BHA&tripping runs Reduced tripping speeds, mud properties, proper hole filling practices, pumping out of hole, real time ECD, weighted sweeps Abnormal Reservoir Drilling into an injection Follow mud weight schedule Pressure conduit and don't fall behind. Increase mud weight as needed. Ensure adequate kick tolerance prior to drilling Bermuda Well Proximity Risks: Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) is provided in the attachments. 2N-303A wp03 fails major risk analysis with the parent wellbore 2N-303, however, the new lateral will separate from original lateral wellbore once kicked off. Besides the old well, the closest well to the proposed 2N-303A well path is 2N-302. The closest ellipse separation is 245'at 2,883' MD. In general, no significant clearance issues exist with the sidetrack well plan. Drilling Area Risks: Reservoir Pressure: Bottom hole pressures were taken from the Bermuda and Purple formations on the original 2N-303 prior to the plug and abandonment. The pressure values obtained were 1,956 1 psi (7.1 ppg MWE) and 2,015 psi (7.2 ppg'MWE) respectively. This well should not be a risk for over pressure and as such will not require a toset. 5-3u, Lower Shale Stability: Higher mud weights in the intermediate will require higher mud weights to stabilize. Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation if needed. 2N-303A APD Page 8 of 11 ORIGINAL Printed:16-Jun-14 App--Lion for Permit to Drill,Well 2N-303A Saved: 16-Jun-14 16. Attachment 2 — Proposed Well Schematic Tarn 2N-303A Sc in nco, 333,13an,Billotrank SFIACIIVN SIAflIl PrOillICAX COnOCOPhd lips Proposed Wglibure Schorna tic FMC Gorr,V 3-W!2L — 16"Existing Cemented Conductor: Lr -...i..,-,.-:..ilt 16'82_8#H-41) A 1138'MO .'—. tmvsenitm mum= tgiNg i I ;;•..,3Prr.,3 7 5 .'Port C:rdn,.:0 I.1.11:MD 3 V'cirke.33SW 3 .7.J _ Ex iStirkg Surf:fee Casing: 7-5;8"25.7#L40 BTCM 2.832MD?2.29)'TVO fie 3g' 3 r.'Corn.KINGT-3 7:—/ th4xii KOF al rerrien1 Visa et•39 dives&nisxn-43e 027971V1.) . ...... - . ':':,*e.*16:41!.riir gg.'. .1(Y-freii.liti: ..,"::::::::.":: ::::: ::•:.] ."::::j.::. : 7"..: ::. ...: ".": . . 6,,,,,,I,7.W Bi-Ccntr Protiuntinn Hole 4 1 .:1-y :'- . ',, ::: : : : :::::i*:.::.::::::::: ::::::.::::::::::::::: IC;15 II tt 6 i4 E$ *,:.'"Carno 153362.3,. Tubing: \ '.. '6-'4-9.3o L-80 EUE8RD 1 \ +Ctill 61442&N.'',c„Losro wi 2 Kr EIS Prz1;4 oit 3-33-I V:.lia3ar FA Parker 6,451'MD 1 goo Seloclivg Ttabinn: ii.ji ei Scrtr Ws t AV 3I.:.113:2S Ril., ''..'•',"9 m IN-1 1 riss Hydra 5fi3 ., IE mitem2.3 IN,.F31.thutio FIT-7.3- ..... T:\ C,;1.ri, .hri!•.7.0311-- ,"1,43. .:,--- g.fi PPG ELF!Hie/Burat Wawa CLC+7,,:-.12 v., .0.0 2 li!3'X Cralls.A 1"03 SW,cr'Exin..1.1 6.1742'FIC.Fla 1 T.S) i. so s...•.i....e.41.10.FA,pmio,f AK,'FdP.S...33.1"TeD •...•v.:m-0 7 7,'I, vq,rm,ri 3;1:•17 IJI)!.I,I 1.11 --- .. r,-•7..;.;;H..., ,,,,, )---... Ewe Mr,*r,IN:!:,*I.T.t.L.3P re; plialiia 13teductIon Ckilog I- 1"' &C" FiT::.-3.1 _7033'kr,;,57.1.7 PM Fliming swap si re,FIA.nil.r.rfri 'roduction CoBillgi 5-14'15.5161,130 Hydit1563 541"15,5#TN-110SS Hydra 563 tnr tintinm I 110g filet :7,038'MD f 5,753'TVD 2N-303A APD Page 9 of 11 ORIGINAL Printed. 16-Jun-14 Apt .ion for Permit to Drill,Well 2N-303A Saved: 16-Jun-14 17. Attachment 3 — Cement Summary 5 1/2" Casing Cement Job The only cementing operation to be done on the drilling portion of this well will be the 5 '/" production casing. This casing will cover both the Bermuda and the Purple formations and as such will require cement from the shoe of the 5 '/2" casing to a depth of+/-4689'. Cement 5'/2" casing from the shoe @ 7,088' MD to 4,689' MD (minimum of 500' above the top of the C-37 with Class G+Adds @ 15.8 PPG.Assume 40%excess in the annular volume. 7W X 5'/" Cement: (7088'—4,689')x 0.141 ft3/ft x 1.40 (40% excess) =473.6 ft3 in open hole 80' shoe track x 0.024 ft3/ft x 1.0 (0% excess) = 1.92 ft3 Total volume=474 ft3+ 2 ft3=476 ft3=> 557 Sx @ 1.17 ft3/sk System: 557 Sx Class G @ 15.8 PPG 2N-303A APD Page 10 of 11 Printed:16-Jun-14 ORIGINAL Appt.__,lon for Permit to Drill,Well 2N-303A Saved: 16-Jun-14 18. Attachment 4- Directional Plan 2N-303Awp03 Section View 2N-303Awp03 Plan View 0- 360. --..-- 2y3Q9 960- *op 512'x7-V2'. 90. 3000 'Q%.L 00- qv `0 \y_7.Si8'.....50- $ 4? - £800 /4b 1.3600- e2 •SFP 4200 W 756 4750- 4{P ,, 6.. 5700- 61/2'47.112'.............. . JppO -1900 -950 0 960 1900 2850 3600 4750 6700 0 tfr--.....-- Vortical Section a133.00°(950 loin) -1260 900 0 600 1200 1800 2400 3000 3600 WeneyEast(.)(600 tin) 2N-303Awp03 5.611 Plan Summary SURVEY PROGRAM Depth From Depth To Survey/Plan Tool 2513[) 200.74 2790.00 2N-303 IFR(2N-303) MWD.IFR-AK-CAZ-SC 2790.00 7087.60 2N-303Awp03(Plan:2N-303A)MWD+IFR-AK-CAZ-SC . CASING DETAILS \�~``� TVD MD Name Size 110.09 110.09 16 16 �\, 4/l 2292.09 2626.20 7-5/8" 7-5/8 „� _ 5753.24 7087.90 5-1/2"x 7-1/2" 5-1/2 4 • • 16 11'$:r S 5- 7.5.16- Ar 6'a'6a Saki 497 -$ 0-60o 00•� �- _ 1 18 t ?. --. .....,... ,... n i" 697 J �T - 4 1 O' (75 ' �i • .. ' 6s9 a n 6 V7 a 7112'650 :E0 ♦♦ T7 t J Q♦ r1 1 Ti Ji i � 1 1 .._...1..._ . ......_ I -. 0 2000 4000 I 6000 61.2'.7-1.2' 0 1550 1 111001 116501 122001 127501 133001 188501 Measured Depth Horizontal Departure rt 4 i 1. f>♦ 1 t .._1 _1 1 - ..__e 9� Bo I ( _ I 1 i I_ I 1 _ i-- •... s --' t--- t `tip - 11 111111 II Ste' ,-4.>_ �, O 700140. 2100 2800 3500 4200 4900 5600 6300 leo __ SECTION DETAILS 14.-no Sec MD Inc Axi TVD 11/068 1.2-2 ..E./.W Northing Earning.Lep TFace VSec Target E:3g16,1,1 2790.00 39.38 18.86 2418.72 2270.52 1125.80 39328 6912879.96 180152629 0.00 0.00 1158.37 2 2840.00 41.12 20.38 2456.99 2908.69 1156.22 404.14 6912910.32 1601637.30 4.00 30.00 1199.80 9 3330.25 39.03 43.09 263405 2885.85 1421.60 666.61 661317473 1801701.14 9.00 106.78 1600.77 4 6508.60 30.03 43.09 6303.20 5166.00 2883.03 5033.10 6014829.00 1803076.76 0.00 0.00 3471.13 2003034 ES 3108113 Topaerm 6 7087.00 99.03 43.00 6763.24 6606.04 3149.42 218297 6914804.06 160332629 0.00 0.00 383028 Campanian Sand -3842.2 660 -4086.3 640 -42782 697 -4417.1 CO78artn -48232 1aj6aa9 -50732 T-4.1 -6293.2 « Surface Location Geodetic Damm: North American Datum 1083 Magnetic Model: S0GM 2013 TM Depth Reference: Plan:1202.26 0 148.208(Nabors 0ES) Ma9neuc Model Data: 01-Nov-13 Mag be De linalbn 1964' yetom(SS Rolor9xe: Moen 599 LC9a1 To*omen a Ma ac Direction to a True.rection.Add 19.64•Emt North/Y: 5911756.33 Ground Lwo�/Mud Lino. 120.20 9r1a East/X: 1601127.21 Rip: Nabors OES GLOBAL FILTER APPLIED:NI we90h pa .win 200'. 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Cc: Bettis, Patricia K(DOA) Subject: RE: KRU 2N-303A: Permit to Drill Application Hi Patricia, Currently,we are planning on running a triple combo (gamma ray, resistivity, and neutron-density) as well as a micro resistivity for 2N-303A. Cheers, Kelly Umlauf Kelly Umlaut- Geologist mlaufGeologist ConocoPhillips Alaska GKA Satellites,ATO-1362 700 G St. Anchorage, AK, 99501 Office +1 907-265-6183 From: Shultz, Steve (Orbis Engineering, Inc.) Sent: Friday, June 20, 2014 12:36 PM To: Umlauf, Kelly K Subject: FW: KRU 2N-303A: Permit to Drill Application Kelly, Can you address this for the AOGCC and CC me on it. Thanks, Steve From: Bettis, Patricia K(DOA) [mailto:patricia.bettis@alaska.gov] Sent: Friday, June 20, 2014 12:31 PM To: Shultz, Steve (Orbis Engineering, Inc.) Subject: [EXTERNAL)KRU 2N-303A: Permit to Drill Application Good afternoon Steve, What logs does ConocoPhillips plan to acquire for the proposed sidetrack well? Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Avenue 1 r • Anchorage,AK 99501 Tel: (907)793-1238 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 Patricia Bettis at(907)793-1238 or patricia.bettis@alaska.gov. 2 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: K(kt,, e2A) —303/}- PTD: .9..)`i W 8e Development Service _Exploratory Stratigraphic Test _Non-Conventional FIELD: X 1„j< POOL: '`tAec.J 9\t\/1r 'AM Ci) I Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK OPTIONS TEXT FOR APPROVAL LETTER MULTI LATERAL The permit is for a new wellbore segment of existing well Permit (If last two digits No. , API No. 50- - - - . in API number are Production should continue to be reported as a function of the original between 60-69) API number stated above. 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 Pilot Hole ( PH) and API number (50- - - - ) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 MC 25.055. Approval to produce / inject is contingent upon issuance of a Spacing Exception conservation order approving a spacing exception. (Company Name) Operator assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the AOGCC must be in no greater Dry Ditch Sample than 30' sample intervals from below the permafrost or from where samples are first caught and 10'sample intervals through target zones. Please note the following special condition of this permit: Production or production testing of coal bed methane is not allowed for Non-Conventional (name of well) until after (Company Name) has designed and Well implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the AOGCC to obtain advance approval of such water well testing program. Regulation 20 MC 25.071(a) authorizes the AOGCC to specify types of well logs to be run. In addition to the well logging program proposed by (Company Name) in the attached application,the following well logs are Well Lo in also required for this well: gg g Requirements Per Statute AS 31.05.030(d)(2)(B) and Regulation 20 MC 25.071, composite curves for well logs run must be submitted to the AOGCC within 90 days after completion, suspension or abandonment of this well. Revised 4/2014 To a) m °a a) N a) O `o m - 7 ui To C a) • Q m as -o L 7 o_ E LE 0) `L')_ a a c a) o' O 3 o 2 o c o > L Q m w N 7 n ov a m CN V O 'O E O 12 0 c c 3a) m c 3 o 0 N 0 = > C a) 0 = . 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V V V .. a) O N aO O2 O C ) ° Ce CO o ( m N 00 m CI O 0 p oNo wW o c ° a v _ CO `° a) E a a) >, 0 E J NI d 0l O — �)Iw aUW Oa s a s ' a a > aSQ 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. FINAL WELL REPORT MUDLOGGING DATA 2N-303A Provided by: Approved by: Kelly Umlauf Compiled by: Allen Odegaard James Foradas Distribution: 10/24/2014 T.D. Date: 9/3/2014 2N-303A 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.............................................................................................................................7 3.1 Lithostratigraphy .............................................................................................................................7 3.2 Mudlog Summary............................................................................................................................8 3.2.1 C-80.........................................................................................................................................8 3.2.2 Campanian Sand.....................................................................................................................8 3.2.3 C-50.......................................................................................................................................11 3.2.4 C-40.......................................................................................................................................12 3.2.5 C-37.......................................................................................................................................13 3.2.6 Iceberg...................................................................................................................................13 3.2.7 T-7 .........................................................................................................................................14 3.2.8 T-4.1 ......................................................................................................................................15 3.2.9 Bermuda Sand.......................................................................................................................16 3.2.10 Base of Bermuda to top of Purple .........................................................................................16 3.2.11 Purple ....................................................................................................................................17 3.2.12 Base of Purple to C-35 ..........................................................................................................17 3.2.13 C-35 to TD.............................................................................................................................18 3.3 Isotube Summary..........................................................................................................................19 3.4 Sampling Program / Sample Dispatch..........................................................................................20 4 PRESSURE / FORMATION STRENGTH DATA.................................................................................21 4.1 Pore Pressure Evaluation.............................................................................................................21 4.2 Pore Pressure Plot........................................................................................................................23 4.3 Quantitative Methods....................................................................................................................24 5 DRILLING DATA..................................................................................................................................25 5.1 Survey Data Surface to Production Hole TD ................................................................................25 5.2 Bit Record.....................................................................................................................................27 5.3 Mud Record ..................................................................................................................................28 6 SHOW REPORTS ...............................................................................................................................29 7 DAILY REPORTS ................................................................................................................................30 Enclosures: 2”/100’ Formation Log (MD/TVD) 2”/100’ Drilling Dynamics Log (MD/TVD) 2”/100’ LWD / Lithology Log (MD/TVD) 2”/100’ Gas Ratio Log (MD/TVD) Final Data CD 2N-303A 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. 0.25 hrs. Power surge disabled sample pump Effective Circulating Density (ECD) From Schlumberger 2750’ to 6517’ 0 hrs. — Hook Load / Weight on bit From Schlumberger & Encoder from (Canrig Drilling Technology LTD.) 0 hrs. — Mud Flow In Derived from Strokes/Minute and Pump Output 0 hrs. — Mud Flow Out Nabors 9ES 0 hrs. — Mudlogging Unit Computer System HP Compaq Pentium 4 (X2, DML & Rigwatch) 0 hrs. — Mudlogging Unit DAC box In-unit data collection/distribution center 0 hrs. — Pit Volumes, Pit Gain/Loss Canrig Drilling Technology LTD pit sensors 0 hrs. — Pump Pressure Nabors 9ES 0 hrs. — Pump stroke counters Nabors 9ES (Stroke counter #1 & #2) 0 hrs. — Rate of Penetration Nabors 9ES 0 hrs. — RPM Nabors 9ES 0 hrs. — Torque Nabors 9ES 0 hrs. — 1.2 Crew Unit Type : Steel Arctic Unit Number : ML059 Mudloggers Years *1 Days *2 Sample Catchers Years Days *2 Technician Days Allen Odegaard 17 15 Kirk Wallander 15 11 Travis Smith 1 James Foradas 7 15 Larry Turner 10 11 *1 Years experience as Mudlogger *2 Days at wellsite between spud and total depth of well 2N-303A 3 2 WELL DETAILS 2.1 Well Summary Well: 2N-303A ‘Science’ API Index #: 50-103-20352-01-00 Field: Kuparuk River Field Surface Co- Ordinates: 1' FSL, 500' FEL, Sec 34,T10N,R7E,UM(NAD27) Borough: North Slope Primary Target Depth: 7,093’ MD State: Alaska TD Depth: 5,752’ TVD Rig Name / Type: Nabors 9ES, Arctic Triple Suspension Date: N/A Primary Target: Tarn Bermuda Permit to Drill Number: 214088 Spud Date: 8/21/2014 Ground Elevation: Pad 120.2’ MSL Completion Date: 9/8/2014 RT Elevation: RKB 148.2' MSL Completion Status: Completed Secondary Target: Depth: None Classification: Sidetracked producer TD Date: 9/3/14 TD Formation: K-3 Days Testing: 2 Days Drilling: 15 2.2 Hole Data Maximum Depth Shoe Depth Hole Section MD (ft) TVDSS (ft) TD Formation Mud Weight (ppg) Dev. (oinc) Coring Casing/ Liner MD (ft) TVD SS (ft) FIT / LOT (ppg) 6.875”* 2627’ -2135’ Schrader Bluff 9.6 39.47o none 7.625” 2627’ -2135’ 13.4 7.5” 7093’ -5408’ K-3 9.7 36.08o none 5.5” 7052’ -5577’ * * The surface hole was the existing bore if 2N-303 previously cased with 7.625” 29.7# casing to the KOP. Canrig was not present for testing of the completion casing 2N-303A 4 2.3 Daily Activity Summary 8/27/2014 TOOH with Fish from 397’ MD to surface; L/D BHA; L/D 4 ¾” collars, easy in and out of slips with fish watch for hang ups; PJSM with GBR L/D 167' of 5.5” fish; clean clear rig floor; get all 5.5” casing out of pipe shed; load 3.5” cement string in pipe shed; R/U GBR running tools for 3.5” cement string; TIH, single in hole; C/O elevators to 4'' R/U rig tongs M/U XO'S, TIH out of derrick 17 stands, from 900' to 2518.21'; P/U DP single in hole from 2518.21' to 2740', space out tag bottom at 2745' MD; P/U 1'; C&C per mud engineer; tag cast iron plug at 2808' MD ; C&C per mud engineer; install cement lines - L/D JNT 61, M/U pup joint, install head pin wit cement hose, R/U chart, blow down Top Drive; C&C/displace – circulating with cement hose; BPM-6, PSI-400, BPM-8, PSI-603, line up to take returns to choke; primary cementing - fill lines; PT to 3500 psi; pump 15bbls mud push, 12.5ppg at 4.8bpm, 670 psi; drop ball; pump 22bbls 17ppg cement @ 4.4bpm, 182psi; pump 4bbls 12.5ppg, 4bpm 180 psi; swap to rig pump, pump 15bbls mud (215 strokes, 6bpm 380 psi); cement in place at 17:01 hours; R/U to run casing - R/D cement hose, blow back to cement truck, prep for POOH; TOOH from 2804' to 2422';C&C; drop ball, circulate pipe clean, stage pumps up to 12bpm 490psi; RICP from 2422' to 2337', monitor well; TOOH from 2337' to 900', R/B 16 stands; R/U to L/D 3.5” cement stinger; completion-trip tubing/DP - L/D 20 joints 3.5” 8R EUE; C/O tong dies due to collar OD; safety stand-down - talk to crew about why we watch the backstop when we unlatch the elevators and red zones in pipe shed, take photo's and continue to L/D tubing from 300' to surface, noticed cement on collars from 182' to mule shoe; R/D tongs; C/O elevators to 4" DP; service rig - load last 48 joints for picking up pipe; clean clear floor. 8/28/2014 Continued to bring in last 48 joints of 4'' DP to pipe shed and strap and tally; continued to clean and service rig; P/U 4'' DP and racked back stands; install/remove wear bushing; clean and clear rig floor; PJSM drain stack; pull W/R; set test plug; P/U test tools - install test plug, won't set down all the way; POOH insure LDS are back out; all good; inspect rubber; test choke manifold - fill choke and stack; perform body test on BOP's, good test with AOGCC Lou Grimaldi on location to witness tests. The tests started at 14:22 hrs and continue at time of report. 8/29/2014 Completed testing BOP’s install/remove wear bushing; pull test plug and install W/R; R/D test equipment; L/D test joint prepare floor for BHA; PJSM for P/U BHA; P/U BHA as per DD; PJSM to TIH; C/O elevators to 4''; TIH L/D top joint of HWDP on last stand; TIH with 4'' DP out of derrick from 739.53' MD to 1500' MD; C&C shallow test at 1499'; TIH from 1499' to 2426'; tag cement; C&C fill pipe; CBU (6 units gas maximum); B/D Top Drive; R/U to test casing; pressure test casing/shoe to 2500psi for 30min; C&C; R/D test equip, BD lines; drilling cement from 2426' to 2454'; downtime to troubleshoot the top drive, electrical, SCR, lube pump, and electric motor; waiting on parts to C/O electric motor for lube pump and complete top drive repairs at time of report. 8/30/2014 Completed top drive repairs at 14:00 hrs; started drilling cement at 14:30 hrs at 2454'; drilled cement to 2675’ with spot samples collected every half hour after 2620’ in order to determine the percentage of cuttings of formation in relation to cement; downtime to troubleshoot the top drive at 21:30 hrs; top drive repairs in progress at time of report. 8/31/2014 Completed top drive repairs, TIH to 2633’ and resumed drilling and slide drilling at 00:45 hrs; drilling and slide drilling to 2700’ MD; C&C; PJSM; B/D top drive, R/U “LOT'' perform ''LOT'' as per Conoco Company Rep., (LOT = 13.4ppg) pumped 1bbl, B/D test equipment and HCR kill and R/D test equipment; commenced drilling and slide drilling per plan; currently connecting and preparing to drill at time of report. 9/01/2014 Continued drilling and slide drilling per plan from 3974’ to 4832’ MD; C&C; CBU; establish survey, SPR's; 2N-303A 5 monitor hole for 10 minutes; Short Trip from 4832' to 3885'; Service rig; TIH to 4830' washing down last stand; drill ahead from 4832’; preparing to drill after connection at 5402’ at time of report. 9/02/2014 Continued drilling and slide drilling per plan from 5402’ to 6735’ MD midnight depth; drilling at time of report. 9/03/2014 Continued drilling and slide drilling per plan from 6735’ to 7093’ TD; C&C as per 'MI'' Mud Enginer; pump three 30bbl High Vis sweeps; pump 4 BU as per Conoco Rep. (max gas 27units); TOOH PJSM; TOOH R/B stand every 30min from 7093' to 6450' MD; B/D Top Drive; TOOH from 6450' to 5308'; observed no swab or tight hole; C&C pump dry job, install stripping rubbers; TOOH PJSM; TOOH from 5308', to 739'; L/D BHA ; closed out bit; monitored hole 10min; R/U E-line to run open hole logs; presently R/U E-line at time of report. 9/04/2014 Continued R/U E-line to run open hole logs; PJSM; run open hole logs, OD 5.5, overall length 113', WT 2500; RIH to 3150’ MD unable to go down; P/U to 2627 @ SHOE; RIH to 2950' MD unable to go down; POOH R/U Hole Finder; rig maintenance and housekeeping around rig; Continued to run open hole logs; wireline unit at 6200' MD unable to reach bottom; e-line consult with town; decision to POOH; L/D wire line BHA; R/D wire line equipment; clean and clear rig floor; P/U BHA #1 for clean out run; monitor hole 10min, rotate thru tight hole at 340'-370'; TIH from 738' to 2627' conducting shallow pulse test at 1499’; RIH T/ SHOE at 2627' C&C and FILL PIPE, (15u gas) monitor hole 10min; TIH from 2627' to 6736' filling pipe every 20 stands; presently RIH on clean out run with BHA #1 at time of report. 9/05/2014 Continued TIH from 6736' to 7022' MD, K/U wash down to bottom 7092'MD C&C mud as per Mud Engineer; back reaming PJSM; BROOH at 10min a stand from 7092' to 2627; pump 50bbl Hi Vis sweep at shoe; monitor well 10min and POOH on elevators from 2627' to 739' MD, no signs of swab; monitor hole 10 min at BHA; L/D BHA; R/B 4 HWDP, lay down rest in the shed; PJSM with all involved to run open hole logs and R/U E-line; R/U E-line at time of report. 9/06/2014 Continued M/U E-line BHA; started in hole at 0045; RIH with e-line to 7092' with the following tools: RWCH, SWVL, HFCS, MCJE, MCEJ, GTET, HGCS, DSNT, SDLT, SDLP, FLEX, XRMI, XRMI-I, ACRT, HFCS, ACRT, SP, HFND (Total length of tools = 113.86', total weight of tools = 2531.82lbs, Max OD OF tools = 5.00"); POOH logging 30-50fpm; PJSM with all involved to L/D e-line; L/D E-line tools as per Halliburton; R/U to run casing: prep rig floor for casing run; C/O saver sub T/ 4 ½”IF and gripper block/stab in guide; C/O to long set of bails; install/remove wear bushing; pull WR; Dummy Run, VOLANT tool, spiders, cement head, slips, elevators; waiting on 3rd party tools 3rd party troubleshooting VOLANT tool, and spiders; finish rigging up to run 24 joints of TN-110, 144 joints OF L-80, 15.50 LB casing; RKB to LDS 27.47, taking weight on Joint 5 (UWT 41K, DWT 36K); began circ 5bpm at 2000 hrs; worked down joints 5-9 from 172' to 370'; decided to L/D casing and remove centralizers; mobilize welder; L/D VOLANT tool, R/U double stacks at time of report. 9/07/2014 Continued pulling remaining casing (a total of 10 joints) from 298' to surface, removing all centralizers and stop rings, and inspecting and cleaning all threads; R/U to run casing, set back double stacks and R/U to run casing with VOLANT Running Tool; PJSM with all involved to run casing; M/U 5.5" CSG to 7K-ftlbs with VOLANT Running Tool, P/U 50 joints and RIH to 2117' filling each joint; continue running with Joint 51 at 2117' , filling on the fly and topping off every 10 joints; CBU on Joint 62 (5 units max gas, Flow 31.5%); greased washpipe, installed blower hose; Joint 74 had bad threads, was removed from the tally and the numbers were adjusted accordingly; continued RIH with casing; C&C at Joint 87, 3663' (52 units max gas, flow 26%); continued RIH with casing from 3663’ to 4836’; C&C and CBU (66 units max gas, Flow 30.5); continued RIH with casing from 4836’; RIH with casing at 6000’ at time of report. 2N-303A 6 9/08/2014 Continued RIH with casing from 6000’ to 7051.32', (for a total of 168 joints of 5.5" casing), filling each joint while running in; M/U Hanger and Landing Joint; R/D from casing operations; R/D VOLANT running tool; R/U spiders and cement head; line up to circulate with the rig on the cement line through cement head; C&C; break circulation ( units max gas) and stage pumps up to 5bbl/min with 770 psi; circulate until mud properties are correct as per Mud Engineer, and SLB cementers are R/U; PJSM with all involved in cement job; primary cementing: pump 5bbl of CW100 at 5bpm, pumping through cement lines to 4500psi; pump 25bbls of CW100 at 5bpm; pump 30bbls of 11ppg mud push at 5bpm; drop bottom plug; pump 45bbl of 12ppg lead cement at 5bpm; pump 12.5 bbls of 15.8ppg tail at 5bpm; drop top plug and flush lines with H2O; chase with 166.9 bbls of sea water at 5bpm with 1800psi; slow dn to 2bpm with 1200psi; bump plug @ 2338 strokes - 1823psi at 1015hrs and hold for 5min; verify no flow; R/D cement head and spiders; B/D all cement lines; pull Landing Joint; drain stack and prepare to set pack off; I/R wear bushing; continue to C/O bales; R/U and set packoff; test packoff; install wear ring; clean out mud system; flush lines, rotary table, and choke; clean pits; C&C freeze protect, R/U freshwater to rig pump, pump 48bbl down OA at 108gpm 520psi, 37spm; preparing to R/U Lil Red to pump diesel at time of report. At this time the Canrig DML Mudlogging Unit was released by the Conoco Rep, and started rigging down. Note: this is the last daily geologic (mudlogging) report for this well. 2N-303A 7 3 GEOLOGICAL DATA 3.1 Lithostratigraphy LWD tops refer to provisional picks by the wellsite geologist. PROGNOSED LWD PICK FORMATION MD (ft) TVD (ft) MD (ft) TVD (ft) KOP 2,790’ 2,421’ 2,671’ 2,320’ C-80 2,889’ 2,497’ 2,899’ 2,498’ Campanian Sand 2,958’ 2,551’ 2,979’ 2,556’ C-50 4,541’ 3,780’ 4,656’ 3,849’ C-40 4,925’ 4,078’ 4,964’ 4,093’ C-37 5,185’ 4,280’ 5,191’ 4,274’ Iceberg 5,399’ 4,446’ 5,428’ 4,458’ T-7 5,875’ 4,815’ 6,070’ 4,950’ T-4.1 6,201’ 5,068’ 6,229’ 5,070’ Top Bermuda 6,529’ 5,322’ 6,540’ 5,314’ Top Seismic Bermuda 6,577’ 5,360’ 6,594’ 5,357’ Base Bermuda 6,630’ 5,401’ 6,646’ 5,397’ Top Purple 6,660’ 5,424’ 6,677’ 5,422’ Base Purple 6,743’ 5,488’ 6,765’ 5,490’ C-35 6,789’ 5,524’ 6,850’ 5,557’ TD 7,088’ — 7,093’ 5,752’ 2N-303A 8 3.2 Mudlog Summary 3.2.1 C-80 2899’ to 2979' MD (-2170' to -2406' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 306.1 20.9 87.6 29 8 15.9 Claystone, Unconsolidated Sand, and Siltstone (2810' - 2910') = medium to dark gray; unconsolidated to soft; non to very poor induration; pulverulent to slightly malleable; very clayey texture with occasional gritty and silty; mushy to pasty consistency; waxy to greasy luster; no discernible cuttings habit, fracture, or structure; sand is light to medium gray overall; upper very fine to upper fine grained; moderate to high sphericity; rounded to sub-rounded; moderate to well sorted; unconsolidated; 75% quartz grains with the remainder made up of dark green to light olive green lithics; no reaction to HCl; trace white to off white to grayish yellow to grayish orange ash; no hydrocarbon indicators. Claystone, Unconsolidated Sand, and Siltstone (2910' - 3010') = medium to dark gray; unconsolidated to soft; non to very poor induration; pulverulent to slightly malleable; very clayey texture with occasional gritty and silty; consistency ranges from mushy to pasty; greasy to waxy luster; no discernible cuttings habit, fracture, or structure; sand is light to medium gray overall; upper very fine to upper fine grained; moderate to high sphericity; rounded to sub-rounded; moderate to well sorted; unconsolidated; 75% quartz grains with the remainder made up of dark green to light olive green lithics; no reaction to HCl; trace white to off white to grayish yellow to grayish orange ash; no hydrocarbon indicators. Peaks MD Depth TG C1 C2 C3 C4I C4N C5I C5N 2854’ 51 9299.538 0 222.953 0 0 0 0 3.2.2 Campanian Sand 2979’ to 4656’ MD (-2406' to -3699' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 361.3 1.0 124.7 49 1 13.9 Claystone, Unconsolidated Sand, and Siltstone (3010' - 3110') = medium to dark gray; unconsolidated to soft; non to very poor induration; pulverulent to slightly malleable; very clayey texture with occasional gritty and silty; consistency ranges from mushy to pasty; greasy to waxy luster; no discernible cuttings habit, fracture, or structure; sand is light to medium gray overall; upper very fine to upper fine grained; moderate to high sphericity; rounded to sub-rounded; moderate to well sorted; unconsolidated; 75% quartz grains with the remainder made up of dark green to light olive green lithics; no reaction to HCl; trace white to off white ash; no hydrocarbon indicators. Claystone, Unconsolidated Sand, and Siltstone (3110' - 3200') = medium to dark gray; unconsolidated to soft; non to very poor induration; pulverulent to slightly malleable; very clayey texture with occasional gritty and silty; mushy to pasty consistency; waxy to greasy luster; no discernible cuttings habit, fracture, or structure; sand is light to medium gray overall; upper very fine to upper fine grained; moderate to high sphericity; rounded to sub-rounded; moderate to well sorted; unconsolidated; 75% quartz grains with the remainder made up of dark green to light olive green lithics; no reaction to HCl; rare trace white to off white ash; no hydrocarbon indicators. 2N-303A 9 Claystone, Unconsolidated Sand, and Siltstone (3200' - 3300') = medium to dark gray; unconsolidated to soft; non to very poor induration; pulverulent to slightly malleable; very clayey texture occasionally grading to gritty or silty; consistency ranges from mushy to pasty; greasy to waxy luster; no discernible cuttings habit, fracture, or structure; sand is light to medium gray overall; upper very fine to lower fine grained; moderate to high sphericity; rounded to sub-rounded; moderately to well sorted; unconsolidated; 75% quartz grains with the remainder made up of dark green to dark gray to black lithics; no reaction to HCl; rare trace white to off white ash; no hydrocarbon indicators. Claystone, Unconsolidated Sand, and Siltstone (3300' - 3390') = medium to dark gray; unconsolidated to soft; non to very poor induration; pulverulent to slightly malleable; very clayey texture with occasional gritty and silty; mushy to pasty consistency; waxy to greasy luster; no discernible cuttings habit, fracture, or structure; sand is light to medium gray overall; upper very fine to upper fine grained; moderate to high sphericity; well rounded to sub-rounded; moderate to well sorted; unconsolidated; 75% quartz grains with the remainder made up of dark green to dark gray to black lithic fragments; no reaction to HCl; rare trace white to off white ash; no hydrocarbon indicators. Claystone, Unconsolidated Sand, and Siltstone (3390' - 3490') = medium to dark gray; unconsolidated to soft; non to very poor induration; pulverulent to slightly malleable; very clayey texture with occasional gritty and silty; mushy to pasty consistency; waxy to greasy luster; no discernible cuttings habit, fracture, or structure; sand is light to medium gray overall; upper very fine to lower fine grained; moderate to high sphericity; well rounded to sub-rounded; moderate to well sorted; unconsolidated; 80% quartz grains with the remainder made up of dark green to dark gray to black lithic fragments; no reaction to HCl; trace white to off white ash; no hydrocarbon indicators. Siltstone, Unconsolidated Sand, and Claystone (3490' - 3600') = medium to dark gray with light olive hues; slight to moderately adhesive; colloidal; clumpy to curdy consistency; crumbly to pulverulent tenacity; irregular to earthy fracture; nodular to amorphous cuttings habit; dull earthy to slightly waxy luster; gritty to fine colloidal texture; thin to massive structure; siltstone and claystone intergrades with thin stringers of unconsolidated sand and traces of sandstone; sand is pale brown to medium brownish gray; lower very fine to lower fine grained; mod to well sorted; subrounded to round; unconsolidated; composition is mostly clear translucent to gray quartz with common dark green, dark gray and black lithic fragments; slight reaction to HCl; trace white to off white ash; no hydrocarbon indicators. Siltstone, Unconsolidated Sand, and Claystone (3600' - 3700') = medium to dark gray with light olive hues; slight to moderately adhesive; colloidal; clumpy to curdy consistency; crunchy to pulverulent tenacity; irregular to earthy fracture; nodular to tabular cuttings habit; dull earthy to slightly waxy luster; very gritty to colloidal texture; thin to massive structure; siltstone and claystone intergrades with thin stringers of unconsolidated sand and thin sandstone; sands are pale brown to medium brownish gray; lower very fine to lower fine grained; mod to well sorted; subrounded to well rounded unconsolidated to soft; composed mostly clear translucent to gray quartz with common dark green, dark gray and black lithic fragments; increasingly calcareous and arenaceous with depth; trace ash; no hydrocarbon indicators. Siltstone and Unconsolidated Sand (3700' - 3800') = medium to dark gray with light olive hue; slightly adhesive; curdy to clumpy consistency; malleable to pulverulent tenacity; irregular blocky fracture; tabular to nodular cuttings habit; dull to earthy luster; clayey to gritty granular texture; some thin laminae; thin to thick structure; interbedded with unconsolidated sand occurring in thin beds and stringers; sand is brownish gray to dark gray; lower very fine to lower medium grained; fair sorted; subangular to round; low to moderate high sphericity; some signs of mechanical abrasion on grains; soft to unconsolidated; grading to matrix supported sandstone in places; composed predominantly of quartz with common dark brown and black lithics; moderate HCl reaction; siltier with depth in this interval. Siltstone, Unconsolidated Sand, and Claystone (3800' - 3950') = medium to dark gray with light olive hues; mushy; moderately adhesive; colloidal; clumpy to curdy consistency; brittle to pulverulent tenacity; irregular to earthy fracture; nodular to tabular cuttings habit; dull earthy to slightly waxy luster; clayey to gritty colloidal textures; thin to massive structure; siltstone and claystone intergrades with thin stringers of 2N-303A 10 unconsolidated sand and thin sandstone; sands are medium brown to dark brownish gray; lower very fine to lower fine grained; fair to well sorted; subrounded to well rounded unconsolidated to soft; composed mostly of clear translucent to gray quartz with common dark green, dark gray and black lithic fragments; samples less calcareous and arenaceous with depth; trace ash; no hydrocarbon indicators. Siltstone, Unconsolidated Sand, and Claystone (3950' - 4050') = medium to dark gray with light olive hues; mushy to pasty; slightly adhesive; colloidal; clumpy to curdy consistency; brittle to pulverulent tenacity; irregular to earthy fracture; nodular to tabular cuttings habit; dull earthy to slightly waxy luster; clayey to gritty granular textures; thin to massive structure; siltstone and claystone intergrades with thin sands that are medium to dark gray to dark brownish gray; textures lower very fine to lower fine grained; fair to well sorted; subrounded to well rounded unconsolidated to soft; composed mostly of clear translucent to gray quartz with common dark green, dark gray and black lithic fragments; samples only slightly calcareous; clayier with depth; trace ash; no hydrocarbon indicators. Siltstone, Claystone and Sandstone/Sand (4050' - 4150') = medium to dark olive gray; pasty; slightly adhesive; mushy; clumpy to curdy consistency; brittle to malleable tenacity; irregular blocky to earthy fracture; amorphous to nodular cuttings habit; dull earthy to slightly waxy luster; clayey to gritty granular textures; thin to massive structure; intergrading with sandstone and thin sands that are medium to dark olive gray to dark brownish gray; textures lower very fine to lower fine grained; fair to well sorted; subrounded to well rounded unconsolidated to firm; composed mostly of clear translucent quartz with common dark lithics; non-calcareous; slightly clayier with depth; trace ash; no hydrocarbon indicators. Siltstone, Claystone and Sandstone/Sand (4150' - 4250') = medium to dark olive gray; slightly adhesive; mushy; some curdy in consistency; crumbly to pulverulent tenacity; irregular blocky to earthy fracture; fine wedgelike to tabular cuttings habit; dull earthy luster; gritty granular to colloidal textures; thin structure; intergrading to thin sandstone and interbedded with sands that are medium to dark olive gray to dark brownish gray; textures lower very fine to lower fine grained; fair to well sorted; subangular to well rounded unconsolidated to firm; composed mostly of clear translucent quartz with common dark lithics; slightly calcareous; trace ash; no hydrocarbon indicators. Siltstone, Claystone and Sandstone/Sand (4250' - 4380') = light brownish gray to brownish gray to dark olive gray; slightly adhesive; mushy to pasty with some curdy consistency; crumbly to pulverulent tenacity; irregular blocky to earthy fracture; fine wedgelike to tabular cuttings habit; dull earthy luster; gritty granular to colloidal textures; thin structure; intergrading to thin sandstone and interbedded with sands that are medium to dark olive gray to dark brownish gray; textures lower very fine to lower fine grained; fair to well sorted; sub-angular to well rounded grains; unconsolidated to firm; composed mostly of clear translucent quartz with common dark lithic fragments; slightly calcareous; rare trace ash; trace shale observed; no hydrocarbon indicators. Siltstone, Claystone and Sandstone/Sand (4380' - 4490') = light brownish gray to brownish gray to dark olive gray; slightly adhesive; mushy to pasty, some curdy consistency; crumbly to pulverulent tenacity; irregular blocky to earthy fracture; fine wedgelike to tabular cuttings habit; dull earthy luster; gritty granular to colloidal textures; thin structure; interbedded with thin sandstone ranging from medium gray to dark olive gray to dark brownish gray; very fine to lower fine grained; fair to well sorted; sub-angular to well rounded grains; unconsolidated to firm; composed mostly of clear translucent quartz with common dark lithic fragments; slightly calcareous; rare trace ash; trace shale observed; no hydrocarbon indicators. Siltstone, Claystone and Sandstone/Sand (4490' - 4600') = light brownish gray to brownish gray to dark olive gray; slightly adhesive; mushy to pasty with some curdy consistency; crumbly to pulverulent tenacity; irregular blocky to earthy fracture; fine wedgelike to tabular cuttings habit; dull earthy luster; gritty granular to colloidal textures; thin structure; intergrading to thin sandstone and interbedded with sands that are medium to dark olive gray to dark brownish gray; textures lower very fine to lower fine grained; fair to well sorted; sub-angular to well rounded grains; unconsolidated to firm; composed mostly of clear translucent quartz with common dark lithic fragments; slightly calcareous; trace white to yellow gray ash, which percentage increases with depth, especially past 4500; trace shale observed; no hydrocarbon indicators. 2N-303A 11 Siltstone, Claystone and Sandstone/Sand (4600' - 4700') = light brownish gray to brownish gray to dark olive gray; slightly adhesive; mushy to pasty with some curdy consistency; crumbly to pulverulent tenacity; irregular blocky to earthy fracture; fine wedgelike to tabular cuttings habit; dull earthy luster; gritty granular to colloidal textures; thin structure; often grading to thin sandstone and interbedded with sands that are medium to dark olive gray to dark brownish gray; textures lower very fine to lower fine grained; fair to well sorted; sub-angular to well rounded grains; unconsolidated to firm; composed mostly of clear translucent quartz with common dark lithic fragments; non-calcareous; trace ash; trace to 10% shale observed; no hydrocarbon indicators. Peaks MD Depth TG C1 C2 C3 C4I C4N C5I C5N 2982’ 48 8663.415 184.223 328.471 0 0 0 0 4295’ 28 5802.953 139.674 119.515 99.356 0 0 0 4500’ 17 3131.713 8.277 146.839 0 60.752 0 0 3.2.3 C-50 4656’ to 4964' MD (-3699' to -3943’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 250.2 14.3 121.7 43 5 19.5 Siltstone, Claystone and Sandstone/Sand (4600' - 4700') = light brownish gray to brownish gray to dark olive gray; slightly adhesive; mushy to pasty with some curdy consistency; crumbly to pulverulent tenacity; irregular blocky to earthy fracture; fine wedgelike to tabular cuttings habit; dull earthy luster; gritty granular to colloidal textures; thin structure; often grading to thin sandstone and interbedded with sands that are medium to dark olive gray to dark brownish gray; textures lower very fine to lower fine grained; fair to well sorted; sub-angular to well rounded grains; unconsolidated to firm; composed mostly of clear translucent quartz with common dark lithic fragments; non-calcareous; trace ash; trace to 10% shale observed; no hydrocarbon indicators. Siltstone, Claystone and Sandstone/Sand (4700' - 4800') = light brownish gray to brownish gray to dark olive gray; slightly adhesive; mushy to pasty, some curdy consistency; crumbly to pulverulent tenacity; irregular blocky to earthy fracture; fine wedgelike to tabular cuttings habit; dull earthy luster; gritty, granular to colloidal textures; thin structure; interbedded with thin sandstone ranging from medium gray to dark olive gray to dark brownish gray; very fine to lower fine grained; fair to well sorted; sub-angular to well rounded; unconsolidated to firm; composed mostly of clear translucent quartz with common dark lithic fragments; non-calcareous; trace ash; trace to 10% shale pieces observed; no hydrocarbon indicators. Siltstone, Claystone and Sandstone/Sand (4800' - 4900') = light brownish gray to brownish gray to dark olive gray; slightly adhesive; mushy to pasty, curdy consistency; crumbly to pulverulent tenacity; irregular blocky to earthy fracture; fine wedgelike to tabular cuttings habit; dull earthy luster; gritty, granular to colloidal textures; thin structure; interbedded with thin sandstone ranging from medium gray to dark olive gray to dark brownish gray; very fine to lower fine grained; fair to well sorted; sub-angular to well rounded; unconsolidated to firm; composed mostly of clear translucent quartz with common dark lithic fragments; slight reaction to HCl; trace ash; trace to 10% shale also observed; no hydrocarbon indicators. Siltstone, Claystone and Sandstone/Sand (4900' - 5000') = light brownish gray to brownish gray to dark olive gray; moderately adhesive; mushy to pasty, curdy consistency; crumbly to pulverulent tenacity; irregular blocky to earthy fracture; fine wedgelike to nodular cuttings habit; dull earthy luster; gritty, granular to colloidal textures; thin structure; interbedded with thin sandstone ranging from medium gray to dark olive gray to dark brownish gray; very fine to lower fine grained; fair to well sorted; sub-angular to well 2N-303A 12 rounded; unconsolidated to firm; composed mostly of clear translucent quartz with common dark lithic fragments; slight reaction to HCl; trace ash; trace to 10% shale that can be carbonaceous in places also observed; no hydrocarbon indicators. Peaks MD Depth TG C1 C2 C3 C4I C4N C5I C5N 4896’ 16 2,914.383 150.927 158.625 26.544 90.136 116.680 54.463 4951’ 42 8235.037 224.325 137.516 50.327 57.931 0 0 3.2.4 C-40 4964’ to 5191’ MD (-3943' to -4124' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 253.2 3.6 122.2 43 7 28.7 Siltstone, Claystone and Sandstone/Sand (4900' - 5000') = light brownish gray to brownish gray to dark olive gray; moderately adhesive; mushy to pasty, curdy consistency; crumbly to pulverulent tenacity; irregular blocky to earthy fracture; fine wedgelike to nodular cuttings habit; dull earthy luster; gritty, granular to colloidal textures; thin structure; interbedded with thin sandstone ranging from medium gray to dark olive gray to dark brownish gray; very fine to lower fine grained; fair to well sorted; sub-angular to well rounded; unconsolidated to firm; composed mostly of clear translucent quartz with common dark lithic fragments; slight reaction to HCl; trace ash; trace to 10% shale that can be carbonaceous in places also observed; no hydrocarbon indicators. Siltstone, Claystone and Sandstone/Sand (5000' - 5100') = light brownish gray to brownish gray to dark olive gray; moderately adhesive; mushy to pasty, curdy consistency; crumbly to pulverulent tenacity; irregular blocky to earthy fracture; fine wedgelike to nodular cuttings habit; dull earthy luster; gritty, granular to colloidal textures; thin structure; interbedded with thin sandstone ranging from medium gray to dark olive gray to dark brownish gray; very fine to lower fine grained; fair to well sorted; sub-angular to well rounded; unconsolidated to firm; composed mostly of clear translucent quartz with common dark lithic fragments; slight reaction to HCl; trace ash; trace to 10% shale also observed; no hydrocarbon indicators. Siltstone, Claystone and Sandstone/Sand (5100' - 5200') = light brownish gray to brownish gray to dark olive gray; mod to very adhesive; mushy to pasty, curdy consistency; crumbly to pulverulent tenacity; irregular blocky to earthy fracture; fine wedgelike to nodular cuttings habit; dull earthy luster; gritty, clayey and colloidal textures; thin structure; interbedded with thin sandstone ranging from medium gray to dark olive gray to dark brownish gray; very fine to upper fine grained; fair to well sorted; sub-angular to well rounded; unconsolidated to soft; composed of clear translucent quartz and common dark lithic fragments; slight reaction to HCl; trace ash; trace to 10% shale also observed; no hydrocarbon indicators. Peaks MD Depth TG C1 C2 C3 C4I C4N C5I C5N 5000’ 36 6,327.398 140.598 150.490 45.397 0 0 0 5075’ 43 8773.672 243.251 207.596 0 0 0 0 5165’ 34 6150.707 219.130 151.951 0 0 0 0 2N-303A 13 3.2.5 C-37 5191’ to 5428' MD (-4124' to -4308’ TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 330.3 20.7 127.5 49 15 27.4 Siltstone, Claystone and Sandstone/Sand (5200' - 5300') = light brownish gray to brownish gray to dark olive gray; somewhat adhesive; mushy to pasty, curdy consistency; crumbly to pulverulent tenacity; irregular blocky to earthy fracture; fine wedgelike to nodular cuttings habit; dull earthy luster; gritty, clayey and colloidal textures; thin structure; interbedded with thin olive gray to dark brownish gray sand; very fine to upper fine grained; fair to well sorted; sub-angular to well rounded; unconsolidated to soft; composed of clear translucent quartz and dark gray lithic fragments; slight reaction to HCl; trace ash; trace to 10% shale also observed; no hydrocarbon indicators. Siltstone, Claystone and Sandstone/Sand (5300' - 5430') = light brownish gray to brownish gray to dark olive gray; somewhat adhesive; mushy to pasty, curdy consistency; crumbly to pulverulent tenacity; irregular blocky to earthy fracture; fine wedgelike to nodular cuttings habit; dull earthy luster; gritty, clayey and colloidal textures; thin structure; interbedded with thin sandstone ranging from medium gray to dark olive gray to dark brownish gray; very fine to upper fine grained; fair to well sorted; sub-angular to well rounded; unconsolidated to soft; composed of clear translucent quartz and dark gray lithic fragments; slight reaction to HCl; trace ash; trace to 10% shale also observed; no hydrocarbon indicators. Peaks MD Depth TG C1 C2 C3 C4I C4N C5I C5N 5226’ 38 7147.060 244.534 327.033 33.056 16.350 17.417 0 5372’ 49 9438.362 377.211 247.339 0 0 0 0 3.2.6 Iceberg 5428’ to 6070' MD (-4308' to -4800' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 228.9 2.0 101.2 163 7 24.2 Sandstone/Sand (5430' - 5500') = light to medium gray with green brown hues; lower very fine to lower medium grained; poor to fair sorted; angular to round; low to high sphericity; some impact and grinding features on grain surfaces indicative of mechanical abrasion; soft to unconsolidated; some grain enlargement by cementing of smaller grains; grain supported with common silt matrix; moderate reaction to HCl in sample; composed of clear translucent, white, and gray quartz with common brown green and dark gray lithics; trace greenstone and ash; dull brownish yellow to gold sample fluorescence; very weak milk cut; no odor or visible cut; some contamination possible by oil added to mud; sandstone and sand occurs in thin beds and stringers interbedded with thin siltstone, shale and clay beds as described above. Siltstone, Claystone and Sandstone/Sand (5500' - 5600') = light to medium gray with brownish and dark gray hues; somewhat adhesive; mushy to pasty, curdy to clumpy consistency; pulverulent to malleable; irregular blocky to earthy fracture; fine wedgelike to nodular cuttings habit; dull earthy luster; gritty, clayey and colloidal textures; thin structure; interbedded with thin sands and sandstone as described above along with up to 20% dark gray shale; HCl reaction varies from none to moderate; no hydrocarbon indicators. Siltstone, Claystone and Sandstone/Sand (5600' - 5700') = light to medium gray with brownish and dark gray hues; somewhat adhesive; mushy to pasty, curdy consistency; pulverulent to malleable; irregular 2N-303A 14 blocky to earthy fracture; fine wedgelike to tabular and nodular cuttings habit; dull earthy luster; gritty and colloidal textures; thin structure; interbedded with thin sands and sandstone as described above along with some dark gray shale; slight HCl reaction; no hydrocarbon indicators. Siltstone, Claystone and Sandstone/Sand (5700' - 5780') = light to medium gray with brownish and dark gray hues; somewhat adhesive; mushy to pasty, curdy to clumpy consistency; pulverulent to malleable; irregular blocky to earthy fracture; fine wedgelike to nodular cuttings habit; dull earthy luster; gritty, clayey and colloidal textures; thin structure; interbedded with thin sands and sandstone as described above along with up to 20% dark gray shale; HCl reaction varies from slight to moderate; no hydrocarbon indicators. Siltstone, Claystone and Sandstone/Sand (5780' - 5850') = light to medium gray with some brownish and dark gray hues; somewhat adhesive; mushy to pasty, curdy to clumpy consistency; pulverulent to malleable; irregular blocky to earthy fracture; fine wedgelike to nodular cuttings habit; dull earthy luster; gritty, clayey and colloidal textures; thin structure; interbedded with thin sands and sandstone as described above along with up to 10% dark gray shale; slightly to moderately calcareous; no hydrocarbon indicators. Sandstone/Sand (5850' - 5960') = light to medium gray to greenish gray; lower very fine to upper fine grained; poor to fair sorting; very angular to rounded; low to high sphericity; some impact and grinding features on grain surfaces indicative of mechanical abrasion; soft to unconsolidated; some grain enlargement by cementing of smaller grains; grain supported with common silt matrix; moderate reaction to HCl in sample; composed of clear translucent, white, and gray quartz with common brown green and dark gray lithics; trace ash; trace pyrite; rare trace yellow sample fluorescence; no cut; no odor at shakers; sandstone and sand occurs in thin beds and stringers interbedded with thin siltstone, shale and claystone as described above. Siltstone, Claystone and Sandstone/Sand (5960' - 6040') = light to medium gray with some brownish and dark gray hues; somewhat adhesive; mushy to pasty, curdy to clumpy consistency; pulverulent to malleable; irregular blocky to earthy fracture; fine wedgelike to nodular cuttings habit; dull earthy luster; gritty, clayey and colloidal textures; thin structure; interbedded with thin sands and sandstone as described above along with up to 10% dark gray, splintery, stiff to brittle shale; very slightly to non-calcareous; no hydrocarbon indicators. Peaks MD Depth TG C1 C2 C3 C4I C4N C5I C5N 5500’ 13 2,478.236 162.320 248.567 42.673 49.941 5459’ 163 31240.387 1241.348 418.903 74.491 57.073 0 0 5537’ 32 5902.499 273.298 240.524 0 0 0 0 6000’ 16 2,914.383 150.927 158.625 26.544 90.136 116.680 54.463 3.2.7 T-7 6070’ to 6224’ MD (-4800' to -4920' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 215.5 10.6 102.7 44 8 17.9 Sandstone/Unconsolidated Sand, Siltstone and Shale (6040' - 6140')= light to medium gray, occasionally ranging to brownish and dark gray hues; lower fine to lower medium, a rare few upper medium pieces; poor to moderate sphericity; angular to rounded; moderate sorting grades into well sorted; mostly unconsolidated with small rare chunks of consolidated matrix supported sandstone; 75% quartz with the remainder dark greenish gray lithics; grinding to frosted surface abrasion; slightly to occasionally moderately calcareous; siltstone dark greenish gray, easily friable to firm friable, well to moderately 2N-303A 15 indurated, crumbly to brittle, silty texture, dull luster; interbedded with thin claystone layers as described above along with up to 10% dark gray, splintery, stiff to brittle shale; no hydrocarbon indicators. Sandstone/Unconsolidated Sand, Siltstone and Shale (6140' - 6260')= light to medium gray, occasionally ranging to brownish and dark gray hues; lower fine to lower medium, a rare few upper medium pieces; poor to moderate sphericity; angular to rounded; moderate sorting grades into well sorted; mostly unconsolidated with small rare chunks of consolidated matrix supported sandstone; 80% quartz with the remainder dark greenish gray lithics; grinding to frosted surface abrasion; slightly to occasionally moderately calcareous; siltstone dark greenish gray to light gray; easily to firm friable, well to moderately indurated, crumbly to brittle, silty texture, dull luster; interbedded with thin claystone layers as described above along with up to 10% dark gray, splintery, stiff to brittle shale; trace white ash; no hydrocarbon indicators. Peaks MD Depth TG C1 C2 C3 C4I C4N C5I C5N 6091’ 44 9011.480 505.731 544.759 208.138 417.088 19.883 117.426 6209’ 23 4782.612 206.391 194.454 12.328 50.957 147.105 8.013 3.2.8 T-4.1 6229’to 6540' MD (-4920' to -5164' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 267.7 2.1 94.3 32 4 18.9 Sandstone/Unconsolidated Sand, Siltstone and Shale (6260' - 6380')= light to medium gray, occasionally ranging to brownish and dark gray hues; lower fine to lower medium, a rare few upper medium pieces; poor to moderate sphericity; angular to rounded; moderate sorting grades into well sorted; mostly unconsolidated with small rare chunks of consolidated matrix supported sandstone; 75% quartz with the remainder dark greenish gray lithics; grinding to frosted surface abrasion; slightly to occasionally moderately calcareous; siltstone dark greenish gray to light gray; easily to firm friable, well to moderately indurated, crumbly to brittle, silty texture, dull luster; often interbedded with thin claystone layers as described above along with up to 10% dark gray, splintery, stiff to brittle shale; trace white ash; no hydrocarbon indicators. Claystone, Siltstone, Sandstone, Sand and Shale (6380' - 6450')= light to medium gray, with dark gray and brownish hues; moderately adhesive; clumpy to curdy; brittle to malleable tenacity; irregular blocky to earthy fracture; nodular to fine wedgelike and tabular cuttings habit; dull earthy to micro-sparkling luster; silty to gritty textures; lamina and thin beds intergrading to light gray sandstone and brownish gray sand as described above, that is also occurring in thin beds and stringers; slight HCl reaction in sample; increasingly siltier and shaly with depth in interval; trace gold fluorescence in a few sandstone cuttings; no other hydrocarbon evidence. Siltstone, Claystone, Sandstone, Sand, and Shale (6450' - 6570')= light to medium gray, with dark gray and brownish hues; slightly adhesive; curdy to stiff; dense to pulverulent; irregular blocky to earthy fracture; fine wedgelike to tabular cuttings habit; clayey to gritty and granular texture; laminar to thin structure; fissile in places intergrades between more abundant siltstone and coarser and finer rocks occurring as thin stringers; vigorous to mild reaction to HCl in bulk sample; trace ash; sandstone lower fine to fine grained, composed of quartz and dark lithics; no hydrocarbon indicators; abrupt contact with underlying sandstone. 2N-303A 16 Peaks MD Depth TG C1 C2 C3 C4I C4N C5I C5N 6395 29 5895.008 277.998 280.271 58.726 59.828 54.782 23.066 6500 16 2,926.854 163.505 182.144 80.484 0 0 0 6530 16 3,113.213 220.376 233.518 63.556 68.102 0 0 3.2.9 Bermuda Sand 6540’ to 6646' MD (-5164' to -5247' TVDSS) Note: Seismic Bermuda Top: 6594’ MD, -5207’ TVDSS Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 225.3 3.4 123.6 388 10 146.6 Sandstone, Siltstone (6570' - 6670') = light to medium gray with yellowish and pale brown white hues; lower very fine grained; fair to well sorted; sub-angular to round; moderate to high sphericity; some impact and frosting and other signs of mechanical abrasion; soft to easily friable; common grain enlargement due to silica and possibly calcite cement evident from vigorous reaction to HCl in bulk sample; composition 80- 90% translucent and clear quartz; common black and dark brown lithics; grain supported with some silty matrix; interbedded with siltstone in places; no odor slight stain; dull golden yellow fluorescence; yellow cut; delayed pale milk cut; residual pale yellow fluorescence and crush cut. Peaks MD Depth TG C1 C2 C3 C4I C4N C5I C5N 6560’ 20 4,016.546 221.956 245.713 49.483 0 0 0 6583’ 234 41,694.956 4,178.846 2,613.331 366.352 893.167 159.318 231.040 6620’ 388 73,422.075 6,950.920 4,064.518 562.921 1,271.648 205.822 261.867 3.2.10 Base of Bermuda to top of Purple 6646’ to 6677' MD (-5247' to -5272' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 53.1 4.2 26.8 40 19 35.5 Sandstone, Siltstone (6670' - 6730') = light to medium gray; lower very fine to fine grained; fair to well sorted; sub-angular to round; low to moderate to high sphericity; some impact and frosting and other signs of mechanical abrasion; soft to easily friable; common grain enlargement due to silica and possibly calcite cement evident from vigorous reaction to HCl in bulk sample; composition 80-90% translucent and clear quartz; common black; trace light colored lithics; trace pyrite; dull golden to yellow fluorescence; very pale milk cut; yellow cut fluorescence; no other indicators. Peaks MD Depth TG C1 C2 C3 C4I C4N C5I C5N 6650’ 28 4,192.062 464.843 439.534 111.676 179.541 0.000 82.584 6655’ 40 6274.893 665.094 608.527 144.615 241.407 5.838 104.846 2N-303A 17 3.2.11 Purple 6677’ to 6765' MD (-5272' to -5340' TVDSS), TD Production Hole Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 282.5 6.0 143.0 239 28 123.0 Sandstone, Siltstone (6730' - 6830') = light to medium gray with white and greenish brown hues; lower very fine to fine grained; fair to well sorted; sub-angular to round; low to moderate to high sphericity; some impact and frosting and other signs of mechanical abrasion; soft to easily friable; common grain enlargement due to silica and possibly calcite cement evident from vigorous reaction to HCl in bulk sample; composition 80-90% translucent and clear quartz; common black and brown colored lithics; trace stain; dull golden to yellow fluorescence; no sample cut; intergrading with darker gray siltstone in thin beds. Peaks MD Depth TG C1 C2 C3 C4I C4N C5I C5N 6680’ 195 35,177.133 3,041.028 2,277.324 308.925 734.056 169.750 170.360 6710’ 236 42,610.487 3,690.702 2,691.689 407.210 845.289 202.109 232.987 6740’ 36 4,515.310 492.883 516.335 115.308 235.674 140.751 141.480 3.2.12 Base of Purple to C-35 6765' to 6850' MD (-5340' to -5407' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 261.1 14.5 106.1 47 19 32.0 Sandstone, Siltstone (6730' - 6830') = light to medium gray with white and greenish brown hues; lower very fine to fine grained; fair to well sorted; sub-angular to round; low to moderate to high sphericity; some impact and frosting and other signs of mechanical abrasion; soft to easily friable; common grain enlargement due to silica and possibly calcite cement evident from vigorous reaction to HCl in bulk sample; composition 80-90% translucent and clear quartz; common black and brown colored lithics; trace stain; dull golden to yellow fluorescence; no sample cut; intergrading with darker gray siltstone in thin beds. Peaks MD Depth TG C1 C2 C3 C4I C4N C5I C5N 6765' 47 6378.124 608.890 670.145 116.629 220.501 199.569 151.166 6796’ 33 4,749.784 386.250 453.545 51.893 77.402 150.237 75.680 6830’ 20 1,963.886 165.479 314.990 40.857 161.794 62.419 45.429 2N-303A 18 3.2.13 C-35 to TD 6850' to 7093' MD (-5407' to -5602' TVDSS) Drill Rate (ft/hr) Total Gas (units) Maximum Minimum Average Maximum Minimum Average 288.8 4.8 162.1 52 20 37.5 Siltstone, Sandstone, Sand, and Shale (6830' - 6940') = light to medium gray, with dark gray and brownish hues; slightly adhesive; curdy to stiff; dense to pulverulent; irregular blocky to earthy fracture; fine wedgelike to tabular cuttings habit; clayey to gritty and granular texture; laminar to thin structure; fissile in places intergrades between more abundant siltstone and coarser and finer rocks occurring as thin stringers; moderately to highly calcareous; trace to common ash; sandstone lower fine to fine grained, composed of quartz and dark lithics; trace to 10% claystone; no hydrocarbon indicators. Siltstone, Sandstone, Sand, and Shale (6940' - 7090') = light to medium gray, with dark gray and brownish hues; stiff consistency; dense to brittle to occasionally pulverulent; irregular, blocky to earthy fracture; fine wedgelike to tabular cuttings habit; granular to gritty texture; laminar to thin structure; fissile in places, oft intergrades between more abundant siltstone and coarser and finer rocks occurring as thin stringers; moderately to highly calcareous; trace to common ash; sandstone lower fine to fine grained, composed of quartz and dark lithics; trace to 10% claystone; no hydrocarbon indicators. Peaks MD Depth TG C1 C2 C3 C4I C4N C5I C5N 6860 35 5,826.600 361.764 367.402 143.908 183.256 44.029 64.737 6951 42 7,798.618 515.790 425.523 48.121 105.661 130.849 78.852 6962 52 9925.451 641.704 508.094 62.244 154.372 129.378 85.683 6982 47 7,798.618 515.790 425.523 48.121 105.661 130.849 78.852 7010 27 4,546.483 319.110 321.737 52.931 60.832 146.110 84.875 7040 42 7,910.433 510.261 416.182 69.457 104.629 79.826 201.480 7070 43 7,612.259 515.790 332.634 71.273 178.716 102.911 71.064 7093 36 6,440.569 521.714 349.240 70.819 160.143 77.448 85.991 2N-303A 19 3.3 Isotube Summary Isotube Depth Box Sample MD ft TVD ft Gas units Methane ppm Ethane ppm Propane ppm Iso Butane ppm Normal Butane ppm Iso Pentane ppm Normal Pentane ppm 1of1 1 2,982 2,558 48 8,663.415 184.223 328.471 1of1 2 3,500 2,936 8 1,198.119 0.000 140.630 1of1 3 4,000 3,327 2 153.153 1of1 4 4,500 3,724 17 3,131.713 8.277 146.839 0.000 60.752 1of1 5 5,000 4,122 36 6,327.398 140.598 150.490 45.397 1of1 6 5,500 4,514 13 2,478.236 162.320 248.567 42.673 49.941 1of1 7 6,000 4,896 16 2,914.383 150.927 158.625 26.544 90.136 116.680 54.463 1of1 8 6,500 5,283 16 2,926.854 163.505 182.144 80.484 1of1 9 6,530 5,307 16 3,113.213 220.376 233.518 63.556 68.102 1of1 10 6,560 5,330 20 4,016.546 221.956 245.713 49.483 1of1 11 6,583 5,348 234 41,694.956 4,178.846 2,613.331 366.352 893.167 159.318 231.040 1of1 12 6,620 5,377 388 73,422.075 6,950.920 4,064.518 562.921 1,271.648 205.822 261.867 1of1 13 6,650 5,400 28 4,192.062 464.843 439.534 111.676 179.541 0.000 82.584 1of1 14 6,680 5,423 195 35,177.133 3,041.028 2,277.324 308.925 734.056 169.750 170.360 1of1 15 6,710 5,447 236 42,610.487 3,690.702 2,691.689 407.210 845.289 202.109 232.987 1of1 16 6,740 5,470 36 4,515.310 492.883 516.335 115.308 235.674 140.751 141.480 1of1 17 6,796 5,515 33 4,749.784 386.250 453.545 51.893 77.402 150.237 75.680 1of1 18 6,830 5,542 20 1,963.886 165.479 314.990 40.857 161.794 62.419 45.429 1of1 19 6,860 5,566 35 5,826.600 361.764 367.402 143.908 183.256 44.029 64.737 1of1 20 6,951 5,638 42 7,798.618 515.790 425.523 48.121 105.661 130.849 78.852 1of1 21 6,982 5,663 47 7,798.618 515.790 425.523 48.121 105.661 130.849 78.852 1of1 22 7,010 5,687 27 4,546.483 319.110 321.737 52.931 60.832 146.110 84.875 1of1 23 7,040 5,710 42 7,910.433 510.261 416.182 69.457 104.629 79.826 201.480 1of1 24 7,070 5,734 43 7,612.259 515.790 332.634 71.273 178.716 102.911 71.064 1of1 25 7,093 5,752 36 6,440.569 521.714 349.240 70.819 160.143 77.448 85.991 2N-303A 20 3.4 Sampling Program / Sample Dispatch Set Type / Purpose Well Section Sampling Frequency Sampling Interval* Dispatched to A Washed, screened & dried Reference Samples Set owner: CPAI Sidetrack 50’ 2700’ – 7093’ Alaska Archives 1300 W. 56th Avenue Unit 14 Anchorage, AK 99518 Attn: D. Przywojski 265-6340 B Washed, screened & dried Reference Samples Set owner: CPAI Sidetrack 50’ 2700’ – 7093’ Alaska Archives 1300 W. 56th Avenue Unit 14 Anchorage, AK 99518 Attn: D. Przywojski 265-6340 C IsoTube® Natural Gas Samples Set owner: CPAI Sidetrack 500’ 30’ 2982’ – 6500’ 6500’ – 7093’ Isotech Laboratories 1308 Parkland Court Champaign, IL 61821 (217) 398-3490 Sample frequency was locally altered according to drill rate constraints and zones of interest. 2N - 3 0 3 A 21 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 e d by l o w 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 In t e r v a l T o p s Po r e P r e s s u r e ( M W ) 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 (% ) MD (f t ) TV D S S (f t ) Mi n (p p g ) Ma x (p p g ) Tr e n d Trend Indicators C- 8 0 S L T S T 5 0 % SD 1 0 % CL Y S T 4 0 % 2, 8 9 9 ’ - 2 , 3 4 8 ' 9 . 9 7 1 0 . 2 8 I n c r e a s e B G , C G , M W Ca m p a n i a n S a n d S L T S T 5 0 % SD 2 0 % CL Y S T 3 0 % 2, 9 7 9 ’ - 2 , 4 0 6 ' 9 . 1 0 1 0 . 8 1 I n c r e a s e B G , C G , M W C- 5 0 S L T S T 6 0 % SD 2 0 % CL Y S T 2 0 % 4, 6 5 6 ’ - 3 , 6 9 9 ' 1 0 . 0 4 1 0 . 5 3 Sl i g h t In c r e a s e BG,CG, MW C- 4 0 S L T S T 5 0 % SS T 1 0 % SD 1 0 % SH 1 0 % CL Y S T 2 0 % 4, 9 6 4 ’ - 3 , 9 4 3 ' 9 . 9 9 1 0 . 4 3 Sl i g h t De c r e a s e BG,CG, MW C- 3 7 S L T S T 5 0 % SD 1 0 % SH 1 0 % CL Y S T 3 0 % 5, 1 9 1 ’ - 4 , 1 2 4 ' 9 . 9 8 1 0 . 3 3 Sl i g h t De c r e a s e BG,CG, MW Ic e b e r g S S T 4 0 % SH 1 0 % CL Y S T 2 0 % SL T S T 3 0 % 5, 4 2 8 ’ - 4 , 3 0 8 ' 9 . 7 0 1 0 . 1 9 Sl i g h t De c r e a s e BG,CG, MW T- 7 C L Y S T 5 0 % SS T 1 0 % SD 1 0 % SH 1 0 % SL T S T 2 0 % 6, 0 7 0 ’ - 4 , 8 0 0 ' 9 . 7 7 1 0 . 1 2 Sl i g h t In c r e a s e BG,CG, MW T- 4 . 1 SD 3 0 % SS T 1 0 % SH 1 0 % SL T S T 3 0 % CL Y S T 2 0 % 6, 2 2 9 ’ - 4 , 9 2 0 ' 9 . 8 1 1 0 . 2 5 Sl i g h t In c r e a s e BG,CG, MW 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 , 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 . 2N - 3 0 3 A 22 Po r e P r e s s u r e E v a l u a t i o n ( C o n t ) In t e r v a l T o p s Po r e P r e s s u r e ( M W ) 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 (% ) MD (f t ) TV D S S (f t ) Mi n (p p g ) Ma x (p p g ) Tr e n d Trend Indicators To p B e r m u d a S L T S T 6 0 % SS T 1 0 % SD 1 0 % SH 1 0 % CL Y S T 1 0 % 6, 5 4 0 ’ - 5 , 1 6 4 ' 9 . 8 0 1 0 . 1 9 Sl i g h t In c r e a s e BG,CG, MW To p S e i s m i c B e r m u d a S S T 9 0 % S L T S T 1 0 % 6 , 5 9 4 ’ - 5 , 2 0 7 ' 9 . 9 3 1 0 . 1 2 Sl i g h t In c r e a s e BG,CG, MW Ba s e B e r m u d a S S T 9 0 % S L T S T 1 0 % 6 , 6 4 6 ’ - 5 , 2 4 7 ' 9 . 6 1 1 0 . 0 8 Sl i g h t De c r e a s e BG,CG, MW To p P u r p l e S S T 8 0 % S L T S T 2 0 % 6 , 6 7 7 ’ - 5 , 2 7 2 ' 9 . 5 5 1 0 . 0 8 Sl i g h t De c r e a s e BG,CG, MW Ba s e P u r p l e S S T 7 0 % S L T S T 3 0 % 6 , 7 6 5 ’ - 5 , 3 4 0 ' 9 . 5 5 1 0 . 0 4 Sl i g h t De c r e a s e BG,CG, MW C- 3 5 S S T 5 0 % SL T S T 4 0 % SH 1 0 % 6, 8 5 0 ’ - 5 , 4 0 7 ' 9 . 5 5 1 0 . 0 1 Sl i g h t De c r e a s e BG,CG, MW 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 , 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 . 2N-303A 23 4.2 Pore Pressure Plot Pore Pressure Gradient C-80 Campanian Sand C-50 C-40 C-37 Iceberg T-7 T-4.1 Top BermudaTop Seismic Berm Top Purple 2500 3500 4500 5500 6500 7500 8 8.5 9 9.5 10 10.5 11 11.5 12 Pore Pressue (ppg) Me a s u r e d D e p t h ( f t ) PPG C-80 Campanian Sand C-50 C-40 C-37 Iceberg T-7 T-4.1 Top Bermuda Top Seismic Berm Top Purple C-35 2N-303A 24 4.3 Quantitative Methods The primary indicators used for PPG evaluation were gas trends relative to mud weight (MW) and effective circulating density (ECD), including increases in background gas (BG), appearance and trends of connection gas (CG), and magnitudes of trip gas (TG) and wiper gas (WG). Regional pore pressure trends from sonic data, provided by ConocoPhillips, and surface manifestations of hole conditions were also considered. As a reference, PPG is calculated initially with a formula provided by Canrig Drilling Technology LTD, and then modified using the indicators described above, DXC and resistivity (RES) data. The formula uses DX, ECD, and BG as measured by total ditch gas: PPG = ECD – (0.6-((.001*TLGSU) + (0.05*DX))) The formula has certain limitations, such that it does not allow for a PPG more than 1 ppg less than the ECD, and TLGSU must be differentiated from show gas and gas carried from over pressure zones, and is dependent on reliable DX data. However, the formula proved useful in helping formulate a PPG range, when estimating trends, as with DXC data, with data points in shale intervals. 2N-303A 25 5 DRILLING DATA 5.1 Survey Data Surface to Production Hole TD 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) 2,576.13 39.40 17.32 2,253.75 N 996.21 E 349.95 1,026.09 — 2,671.70 39.55 20.00 2,327.52 N 1,053.76 E 369.39 1,084.94 1.79 2,768.30 41.84 25.00 2,400.78 N 1,111.88 E 393.53 1,146.84 4.12 2,837.83 42.22 30.10 2,452.44 N 1,153.12 E 415.06 1,193.15 4.94 2,865.16 42.02 29.52 2,472.71 N 1,169.03 E 424.17 1,211.45 1.60 2,961.58 43.37 35.07 2,543.60 N 1,224.23 E 459.11 1,276.77 4.15 3,056.03 43.53 33.69 2,612.17 N 1,277.83 E 495.78 1,341.70 1.02 3,152.24 43.40 31.10 2,682.01 N 1,333.71 E 531.24 1,407.87 1.86 3,246.81 43.73 34.00 2,750.54 N 1,388.63 E 566.30 1,473.03 2.14 3,342.82 43.12 35.47 2,820.27 N 1,442.87 E 603.90 1,539.00 1.23 3,437.00 42.42 38.82 2,889.41 N 1,493.84 E 642.49 1,602.76 2.53 3,532.37 41.79 41.19 2,960.17 N 1,542.82 E 683.59 1,666.22 1.79 3,626.56 39.49 42.75 3,031.64 N 1,588.43 E 724.59 1,726.81 2.67 3,721.92 38.29 41.63 3,105.87 N 1,632.78 E 764.80 1,785.91 1.46 3,818.45 37.31 41.63 3,182.14 N 1,677.01 E 804.11 1,844.40 1.02 3,909.41 37.04 40.29 3,254.62 N 1,718.51 E 840.14 1,898.83 0.94 4,006.07 37.72 42.69 3,331.43 N 1,762.45 E 879.01 1,956.86 1.66 4,098.89 36.86 43.01 3,405.28 N 1,803.68 E 917.26 2,012.27 0.95 4,192.42 38.00 46.02 3,479.55 N 1,844.19 E 957.11 2,067.95 2.30 4,288.96 37.46 45.88 3,555.91 N 1,885.27 E 999.57 2,125.52 0.57 4,385.10 37.27 45.81 3,632.32 N 1,925.91 E 1,041.44 2,182.41 0.20 4,482.05 36.61 45.73 3,709.80 N 1,966.55 E 1,083.18 2,239.23 0.68 4,577.82 37.36 45.00 3,786.30 N 2,007.03 E 1,124.18 2,295.51 0.91 4,671.85 37.57 46.00 3,860.94 N 2,047.12 E 1,164.98 2,351.35 0.68 4,762.73 37.46 46.86 3,933.03 N 2,085.26 E 1,205.07 2,405.18 0.59 4,863.00 37.58 46.10 4,012.55 N 2,127.32 E 1,249.35 2,464.56 0.48 4,958.95 37.68 46.18 4,088.54 N 2,167.91 E 1,291.59 2,521.61 0.12 5,054.82 36.55 46.99 4,164.99 N 2,207.67 E 1,333.61 2,577.84 1.28 5,150.65 37.64 47.22 4,241.43 N 2,247.01 E 1,375.95 2,633.90 1.15 5,243.77 39.06 45.26 4,314.46 N 2,286.98 E 1,417.67 2,690.14 2.01 5,340.42 38.95 45.88 4,389.56 N 2,329.56 E 1,461.11 2,749.51 0.42 5,435.18 38.82 46.41 4,463.33 N 2,370.77 E 1,504.00 2,807.44 0.38 5,529.96 39.25 45.65 4,536.95 N 2,412.22 E 1,546.96 2,865.59 0.68 5,625.79 40.39 46.01 4,610.55 N 2,454.97 E 1,590.98 2,925.42 1.21 5,721.82 40.18 43.36 4,683.81 N 2,499.11 E 1,634.64 2,986.22 1.80 5,817.13 40.95 44.48 4,756.21 N 2,543.75 E 1,677.63 3,047.07 1.11 5,909.80 40.60 39.98 4,826.41 N 2,588.53 E 1,718.29 3,106.78 3.19 6,004.33 40.38 39.45 4,898.30 N 2,635.75 E 1,757.51 3,167.73 0.43 2N-303A 26 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) 6,101.90 40.06 39.89 4,972.80 N 2,684.24 E 1,797.73 3,230.31 0.44 6,195.28 39.48 42.95 5,044.58 N 2,729.03 E 1,837.23 3,289.39 2.19 6,291.37 38.48 40.84 5,119.28 N 2,774.01 E 1,877.60 3,349.10 1.73 6,385.95 38.80 40.82 5,193.16 N 2,818.70 E 1,916.21 3,407.60 0.34 6,482.22 38.34 42.58 5,268.43 N 2,863.51 E 1,956.13 3,466.93 1.24 6,577.66 38.71 42.80 5,343.09 N 2,907.21 E 1,996.44 3,525.53 0.41 6,672.17 38.62 40.21 5,416.89 N 2,951.42 E 2,035.56 3,583.91 1.71 6,765.92 38.15 41.17 5,490.38 N 2,995.56 E 2,073.51 3,641.60 0.81 6,859.32 37.42 39.95 5,564.19 N 3,039.03 E 2,110.72 3,698.33 1.12 6,958.01 36.60 38.04 5,643.00 N 3,085.19 E 2,148.11 3,757.40 1.43 7,030.78 36.08 38.96 5,701.62 N 3,118.94 E 2,174.95 3,800.32 1.04 7,093.00 36.08 38.96 5,751.91 N 3,147.43 E 2,197.99 3,836.77 — 2N - 3 0 3 A 27 5. 2 B i t R e c o r d Bi t Si z e Ma k e Ty p e / S N # Je 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 ) Av g . WO B (K l b s ) Av g . RP M Av g . PP (p s i ) Wear BHA 1 6 . 5 ” Re e d Hy c a l o g PS D H 1 4 2 1 3 0 Bi - C e n t e r A1 8 9 7 9 3 4x 1 0 , 3 x 8 0. 4 5 4 2, 5 2 7 ’ 4 , 5 6 6 ’ 5 3 . 2 8 3 . 5 1 3 . 8 1 1 2 26 5 1 2-3-CT-G-X-2-NO-TD 1 2N - 3 0 3 A 28 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 ( A S c h l u m b e r g e r C o . ) Mu d T y p e : W B M - O t h e r Da t e De p t h (f e e t ) MW (p p g ) Te m p VI S (s / q t ) PV YP Ge l s FL (c c ) FC So l s (% ) O/ W Ra t i o Sd (% ) pH Cl (ml/l) Ca (ml/l) 8/ 2 7 / 1 4 2 , 5 2 6 9 . 6 1 2 0 5 0 8 1 9 1 3 / 1 4 / 1 5 6 . 0 1 / - 7 . 0 3 / 9 0 - 1 0 . 2 3 9 0 0 1 2 0 8/ 2 8 / 1 4 2 , 5 2 6 9 . 6 1 2 0 5 4 8 1 9 1 3 / 1 4 / 1 5 6 . 0 1 / - 7 . 0 3 / 9 0 - 8 . 1 3 0 0 0 1 2 0 8/ 2 9 / 1 4 2 , 5 2 6 9 . 6 1 2 0 5 2 9 1 4 1 1 / 1 2 / 1 3 6 . 0 1 / - 7 . 0 3 / 9 0 - 9 . 5 3 0 0 0 1 8 0 8/ 3 0 / 1 4 2 , 6 7 6 9 . 6 5 0 4 7 1 0 2 3 1 1 / 1 4 / 1 5 6 . 5 1 / - 7 . 0 3 / 9 0 - 8 . 9 3 8 0 0 4 8 0 8/ 3 1 / 1 4 3 , 4 3 7 9 . 6 8 1 5 1 6 4 1 1 4 / 1 9 / 3 0 4 . 0 1 / - 7 . 5 4 / 8 9 1 0 . 0 2 7 0 0 1 8 0 9/ 1 / 1 4 5 , 2 2 5 9 . 7 8 5 4 8 1 2 2 6 1 5 / 1 8 / 3 2 4 . 0 1 / - 7 . 5 5 / 8 8 9 . 9 2 1 0 0 1 8 0 9/ 2 / 1 4 6 , 5 6 0 9 . 7 9 0 4 8 1 8 2 8 1 0 / 1 4 / 1 5 3 . 5 1 / - 9 . 0 4 / 8 7 - 1 0 . 0 2 4 0 0 8 0 9/ 3 / 1 4 7 , 0 9 3 9 . 7 6 0 4 4 1 0 2 2 1 0 / 1 2 / 1 4 3 . 5 1 / - 8 . 0 4 / 8 8 - 8 . 9 2 3 0 0 1 2 0 9/ 4 / 1 4 7 , 0 9 3 9 . 7 6 5 4 7 8 2 1 8 / 9 / 1 0 3 . 5 1 / - 8 . 0 4 / 8 8 - 8 . 9 2 3 0 0 1 2 0 9/ 5 / 1 4 7 , 0 9 3 9 . 6 7 8 4 5 1 1 2 0 1 0 / 1 1 / 1 2 4 . 0 1 / - 7 . 5 4 / 8 8 - 9 . 9 2 3 0 0 8 0 9/ 6 / 1 4 7 , 0 9 3 9 . 6 6 0 5 0 1 0 2 0 9 / 1 0 / 1 1 4 . 0 1 / - 7 . 5 4 / 8 9 - 9 . 8 2 3 0 0 1 2 0 9/ 7 / 1 4 7 , 0 9 3 9 . 7 6 5 5 7 1 3 2 0 1 1 / 1 4 / 1 6 3 . 5 1 / - 7 . 7 5 4 / 8 8 - 9 . 4 2 1 0 0 1 2 0 9/ 8 / 1 4 * 7 , 0 9 3 - - - - - - - - - - - - - - * P i t s e m p t y a t t i m e o f r e p o r t / R i g d o w n 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 a n d c o n t e n t E C 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 FL = 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 p H = p H ( a t T e m p ) T e m p = F l o w l i n e T e m p e r a t u r e 2N-303A 29 6 SHOW REPORTS Hydrocarbon Show Report # 1 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 6571'MD 6650'MD Country: 5339'TVD 5400'TVD Averages Before During After Maximum ROP (fph) 28 138 17 225 WOB 4 8 6 14 RPM 1 133 1 152 Mud Weight 9.7 9.7 9.7 9.7 Chloride 2,400 2,400 2,400 2,400 Total Gas 32 193 33 388 C1 (ppm) 5,143 34,629 5,193 73,422 C2 (ppm) 526 3,333 529 6,950 C3 (ppm) 467 2,095 469 1,895 C4 (ppm) 285 1,007 285 1,895 C5 (ppm) 83 288 83 485 Lithology Cuttings Analysis Odor None Fluorescence Cut Fluorescence Residual Cut Stain Amount 40% Type Immediate Amount Amount 10% Distribution Even Intensity Bright Color Color Yellow brown Intensity Dull Color Yellow white Residual Fluorescence Cut Color Orange Intesity Color None Color Show Rating 3 Free Oil in Mud Comments Report by: Pale James Foradas No odor slight stain; dull golden yellow fluorescence; yellow cut; delayed pale milk cut; residual pale yellow fluorescence and crush cut. Free oil and slight odor reported at shakers by mud engineer. Yes FROM OIL SHOW SUMMARY Yellow North Slope Borough Alaska United States ConocoPhillips : 50-103-20352-01-00 2N-303A Tarn Oil Pool Nabors 9ES September 2, 2014 9:38pm to 10:33pm Light Pale milk Sandstone, Siltstone (6570' - 6670') = light to medium gray with yellowish and pale brown white hues; lower very fine grained; fair to well sorted; sub-angular to round; moderate to high sphericity; some impact and frosting and other signs of mechanical abrasion; soft to easily friable; common grain enlargement due to silica and possibly calcite cement evident from vigorous reaction to HCl in bulk sample; composition 80- 90% translucent and clear quartz; common black and dark brown lithics; grain supported with some silty matrix; interbedded with siltstone in places; no odor slight stain; dull golden yellow fluorescence; yellow cut; delayed pale milk cut; residual pale yellow fluorescence and crush cut. 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 Hydrocarbon Show Report # 1 Operator: Well: API Number: Field: Date: Rig: Time: County: Depth Start End State: 6677'MD 6768'MD Country: 5421'TVD 5492'TVD Averages Before During After Maximum ROP (fph) 17 143 137 282 WOB 6 6 10 12 RPM 1 119 155 151 Mud Weight 9.7 9.7 9.7 9.7 Chloride 2,300 2,300 2,300 2,300 Total Gas 33 120 36 239 C1 (ppm) 5,193 21,357 5,134 46,590 C2 (ppm) 529 1,911 431 4,034 C3 (ppm) 469 1,528 503 2,944 C4 (ppm) 285 769 167 1,369 C5 (ppm) 83 386 251 603 Lithology Cuttings Analysis Odor None Fluorescence Cut Fluorescence Residual Cut Stain Amount 70% Type None Amount Amount Trace Distribution Even Intensity Color Color Yellow brown Intensity Dull Color Residual Fluorescence Cut Color Golden Intesity Color None Yellow Color Show Rating 2.5 Free Oil in Mud Comments Report by: None James Foradas Trace stain; dull golden to yellow fluorescence; no sample cut. No FROM OIL SHOW SUMMARY North Slope Borough Alaska United States ConocoPhillips : 50-103-20352-01-00 2N-303A Tarn Oil Pool Nabors 9ES September 3, 2014 12:12am to 2:16am None Sandstone, Siltstone (6730' - 6830') = light to medium gray with white and greenish brown hues; lower very fine to fine grained; fair to well sorted; sub-angular to round; low to moderate to high sphericity; some impact and frosting and other signs of mechanical abrasion; soft to easily friable; common grain enlargement due to silica and possibly calcite cement evident from vigorous reaction to HCl in bulk sample; composition 80-90% translucent and clear quartz; common black and brown colored lithics; intergrading with darker gray siltstone in thin beds. 1 10 100 1000 10000 1 2 3 4 pp m DRY GAS GAS CONDENSATE OI L NON PRODUCTIVE C1/C2 C1/C4 C1/C5 C1/C3 2N-303A 30 7 DAILY REPORTS ConocoPhillips Alaska, Inc. 2N-303A Daily Geologic Report Report for: G. Rizek J. Riley, D. Mickey Date: 9/08/14 Time: 18:39 Current Depth (MD): 7093’ Current Depth (TVD): 5752’ Current Operations: Freeze Protect DML Rigdown 24 hr Footage (MD): 0’ Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: 2201 Time: 22:46 Surf-Surf: Strokes: 2201 Time: 22:46 ECD: Current: 10.79 Max: 10.79 Mud Properties @ 7052’ @ 1830 hrs – Pits empty MW: - FV: - PV: - YP: - FL: - Gels: - Sol: - pH: - Cl -: - Ca ++: - MW Change: Depth: 7052’ From: 9.7 To: N/A Reason: Cemented in Mud Loss event: Depth: 7052’ Volume: 494bbl* *Reason: Pits emptied (see below) Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res3 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas 7093’/5752’ 159 Connection Gases - - Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: - No new formation drilled. Operational Summary: Continued RIH with casing from 6000’ to 7051.32', (for a total of 168 joints of 5.5" casing), filling each joint while running in; M/U Hanger and Landing Joint; R/D from casing operations; R/D VOLANT running tool; R/U spiders and cement head; line up to circulate with the rig on the cement line through cement head; C&C; break circulation (159 units max gas) and stage pumps up to 5bbl/min with 770 psi; circulate until mud properties are correct as per Mud Engineer, and SLB cementers are R/U; PJSM with all involved in cement job; primary cementing: pump 5bbl of CW100 at 5bpm, pumping through cement lines to 4500psi; pump 25bbls of CW100 at 5bpm; pump 30bbls of 11ppg mud push at 5bpm; drop bottom plug; pump 45bbl of 12ppg lead cement at 5bpm; pump 12.5 bbls of 15.8ppg tail at 5bpm; drop top plug and flush lines with H2O; chase with 166.9 bbls of sea water at 5bpm with 1800psi; slow dn to 2bpm with 1200psi; bump plug @ 2338 strokes - 1823psi at 1015hrs and hold for 5min; verify no flow; R/D cement head and spiders; B/D all cement lines; pull Landing Joint; drain stack and prepare to set pack off; I/R wear bushing; continue to C/O bales; R/U and set packoff; test packoff; install wear ring; clean out mud system; flush lines, rotary table, and choke; clean pits; C&C freeze protect, R/U freshwater to rig pump, pump 48bbl down OA at 108gpm 520psi, 37spm; preparing to R/U Lil Red to pump diesel at time of report. At this time the Canrig DML Mudlogging Unit was released by the Conoco Rep, and started rigging down. Note: this is the last daily geologic (mudlogging) report for this well. Failures: 0.25 hrs, sample pump down on gas trap due to power surge in rig power. ConocoPhillips Alaska, Inc. 2N-303A Daily Geologic Report Report for: G. Rizek J. Riley, D. Mickey Date: 9/07/14 Time: 23:59 Current Depth (MD): 7093’ Current Depth (TVD): 5752’ Current Operations: Running casing 24 hr Footage (MD): 0’ Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: 2201 Time: 22:46 Surf-Surf: Strokes: 2201 Time: 22:46 ECD: Current: 10.79 Max: 10.79 Mud Properties @ 7093’ MW: 9.7 FV: 57 PV: 13 YP: 20 FL: 3.5 Gels: 11/14/16 Sol: 7.75 pH: 9.4 Cl -: 2100 Ca ++: 120 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res3 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas 2117’/2117’ 3663’/3061’ 4764’/3935’ 5 52 66 Connection Gases - - Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: - No new formation drilled. Operational Summary: Continued pulling remaining casing (a total of 10 joints) from 298' to surface, removing all centralizers and stop rings, and inspecting and cleaning all threads; R/U to run casing, set back double stacks and R/U to run casing with VOLANT Running Tool; PJSM with all involved to run casing; M/U 5.5" CSG to 7K-ftlbs with VOLANT Running Tool, P/U 50 joints and RIH to 2117' filling each joint; continue running with Joint 51 at 2117' , filling on the fly and topping off every 10 joints; CBU on Joint 62 (5 units max gas, Flow 31.5%); greased washpipe, installed blower hose; Joint 74 had bad threads, was removed from the tally and the numbers were adjusted accordingly; continued RIH with casing; C&C at Joint 87, 3663' (52 units max gas, flow 26%); continued RIH with casing from 3663’ to 4836’; C&C and CBU (66 units max gas, Flow 30.5); continued RIH with casing from 4836’; RIH with casing at 6000’ at time of report. Failures: None ConocoPhillips Alaska, Inc. 2N-303A Daily Geologic Report Report for: G. Rizek J. Riley, D. Mickey Date: 9/06/14 Time: 23:59 Current Depth (MD): 7093’ Current Depth (TVD): 5752’ Current Operations: Run casing 24 hr Footage (MD): 0’ Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: 2201 Time: 22:46 Surf-Surf: Strokes: 2201 Time: 22:46 ECD: Current: 10.79 Max: 10.79 Mud Properties @ 7093’ MW: 9.6 FV: 50 PV: 10 YP: 20 FL: 4 Gels: 9/10/11 Sol: 7.5 pH: 9.8 Cl -: 2300 Ca ++: 120 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res3 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas 5480’/4499’ 6 Connection Gases - - Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: - No new formation drilled. Operational Summary: Continued M/U E-line BHA; started in hole at 0045; RIH with e-line to 7092' with the following tools: RWCH, SWVL, HFCS, MCJE, MCEJ, GTET, HGCS, DSNT, SDLT, SDLP, FLEX, XRMI, XRMI-I, ACRT, HFCS, ACRT, SP, HFND (Total length of tools = 113.86', total weight of tools = 2531.82lbs, Max OD OF tools = 5.00"); POOH logging 30-50fpm; PJSM with all involved to L/D e-line; L/D E-line tools as per Halliburton; R/U to run casing: prep rig floor for casing run; C/O saver sub T/ 4 ½”IF and gripper block/stab in guide; C/O to long set of bails; install/remove wear bushing; pull WR; Dummy Run, VOLANT tool, spiders, cement head, slips, elevators; waiting on 3rd party tools 3rd party troubleshooting VOLANT tool, and spiders; finish rigging up to run 24 joints of TN-110, 144 joints OF L-80, 15.50 LB casing; RKB to LDS 27.47, taking weight on Joint 5 (UWT 41K, DWT 36K); began circ 5bpm at 2000 hrs; worked down joints 5-9 from 172' to 370'; decided to L/D casing and remove centralizers; mobilize welder; L/D VOLANT tool, R/U double stacks at time of report. Failures: None ConocoPhillips Alaska, Inc. 2N-303A Daily Geologic Report Report for: G. Rizek J. Riley, D. Mickey Date: 9/05/14 Time: 23:59 Current Depth (MD): 7093’ Current Depth (TVD): 5752’ Current Operations: R/U E-line 24 hr Footage (MD): 0’ Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: 3575 Time: 36.48 Surf-Surf: Strokes: 3575 Time: 36.48 ECD: Current: 10.79 Max: 11.04 Mud Properties @ 7093’ MW: 9.6 FV: 45 PV: 11 YP: 20 FL: 4 Gels: 10/11/12 Sol: 7.5 pH: 9.9 Cl -: 2300 Ca ++: 80 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res3 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas 4940’/4074’ 26 Connection Gases - - Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: - No new formation drilled. Operational Summary: Continued TIH from 6736' to 7022' MD, K/U wash down to bottom 7092'MD C&C mud as per Mud Engineer; back reaming PJSM; BROOH at 10min a stand from 7092' to 2627; pump 50bbl Hi Vis sweep at shoe; monitor well 10min and POOH on elevators from 2627' to 739' MD, no signs of swab; monitor hole 10 min at BHA; L/D BHA; R/B 4 HWDP, lay down rest in the shed; PJSM with all involved to run open hole logs and R/U E-line; R/U E-line at time of report. Failures: None ConocoPhillips Alaska, Inc. 2N-303A Daily Geologic Report Report for: G. Rizek J. Haynes, D. Mickey Date: 9/04/14 Time: 23:59 Current Depth (MD): 7093’ Current Depth (TVD): 5752’ Current Operations: RIH on Cleanout Run with BHA#1 24 hr Footage (MD): 0’ Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: 3575 Time: 36.48 Surf-Surf: Strokes: 3575 Time: 36.48 ECD: Current: 10.79 Max: 11.04 Mud Properties @ 7093’ MW: 9.7 FV: 44 PV: 10 YP: 22 FL: 3.5 Gels: 10/12/14 Sol: 8 pH: 8.9 Cl -: 2300 Ca ++: 120 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res3 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas 2627’/2293’ 15 Connection Gases - - Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: - No new formation drilled. Operational Summary: Continued R/U E-line to run open hole logs; PJSM; run open hole logs, OD 5.5, overall length 113', WT 2500; RIH to 3150’ MD unable to go down; P/U to 2627 @ SHOE; RIH to 2950' MD unable to go down; POOH R/U Hole Finder; rig maintenance and housekeeping around rig; Continued to run open hole logs; wireline unit at 6200' MD unable to reach bottom; e-line consult with town; decision to POOH; L/D wire line BHA; R/D wire line equipment; clean and clear rig floor; P/U BHA #1 for clean out run; monitor hole 10min, rotate thru tight hole at 340'-370'; TIH from 738' to 2627' conducting shallow pulse test at 1499’; RIH T/ SHOE at 2627' C&C and FILL PIPE, (15u gas) monitor hole 10min; TIH from 2627' to 6736' filling pipe every 20 stands; presently RIH on clean out run with BHA #1 at time of report. Failures: None ConocoPhillips Alaska, Inc. 2N-303A Daily Geologic Report Report for: G. Rizek J. Haynes, D. Mickey Date: 9/04/14 Time: 23:59 Current Depth (MD): 7093’ Current Depth (TVD): 5752’ Current Operations: RIH on Cleanout Run with BHA#1 24 hr Footage (MD): 0’ Drilling Parameters ROP: Current: Max: Torque: Current: Max: WOB: Current Max: RPM: Current: Max: PP: Current: Max: Lag: Strokes: 3575 Time: 36.48 Surf-Surf: Strokes: 3575 Time: 36.48 ECD: Current: 10.79 Max: 11.04 Mud Properties @ 7093’ MW: 9.7 FV: 47 PV: 8 YP: 21 FL: 3.5 Gels: 8/9/10 Sol: 8 pH: 8.9 Cl -: 2300 Ca ++: 120 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res3 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas 2627’/2293’ 15 Connection Gases - - Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: - No new formation drilled. Operational Summary: Continued R/U E-line to run open hole logs; PJSM; run open hole logs, OD 5.5, overall length 113', WT 2500; RIH to 3150’ MD unable to go down; P/U to 2627 @ SHOE; RIH to 2950' MD unable to go down; POOH R/U Hole Finder; rig maintenance and housekeeping around rig; Continued to run open hole logs; wireline unit at 6200' MD unable to reach bottom; e-line consult with town; decision to POOH; L/D wire line BHA; R/D wire line equipment; clean and clear rig floor; P/U BHA #1 for clean out run; monitor hole 10min, rotate thru tight hole at 340'-370'; TIH from 738' to 2627' conducting shallow pulse test at 1499’; RIH T/ SHOE at 2627' C&C and FILL PIPE, (15u gas) monitor hole 10min; TIH from 2627' to 6736' filling pipe every 20 stands; presently RIH on clean out run with BHA #1 at time of report. Failures: None ConocoPhillips Alaska, Inc. 2N-303A Daily Geologic Report Report for: G. Rizek J. Haynes, D. Mickey Date: 9/03/14 Time: 23:59 Current Depth (MD): 7093’ Current Depth (TVD): 5752’ Current Operations: Drilling 24 hr Footage (MD): 358’ Drilling Parameters ROP: Current: 117 Max: 288 Torque: Current: 6854 Max: 9553 WOB: Current 3 Max: 25 RPM: Current: 146 Max: 149 PP: Current: 2603 Max: 2908 Lag: Strokes: 3575 Time: 36.48 Surf-Surf: Strokes: 3575 Time: 36.48 ECD: Current: 10.79 Max: 11.04 Mud Properties @ 7093’ MW: 9.7 FV: 44 PV: 10 YP: 22 FL: 3.5 Gels: 10/12/14 Sol: 8 pH: 8.9 Cl -: 2300 Ca ++: 120 MW Change: Depth: 6750’ From: 9.7 To: 9.65 Reason: Drilling 6884’ 9.65 9.6 Drilling Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 0 Max: 239 Depth (MD/TVD): 6708’/5445’ Avg BG : 36.6 LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res3 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas 7093’/5752’ 33 Connection Gases 6831’/5542’ 6927’/5619’ 7022’/5695’ 5 21 8 Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 1-16 6740 36 4,515.310 492.883 516.335 115.308 235.674 140.751 141.480 1-17 6796 33 4,749.784 386.250 453.545 51.893 77.402 150.237 75.680 1-18 6830 20 1,963.886 165.479 314.990 40.857 161.794 62.419 45.429 1-19 6860 35 5,826.600 361.764 367.402 143.908 183.256 44.029 64.737 1-20 6951 42 7,798.618 515.790 425.523 48.121 105.661 130.849 78.852 1-21 6982 47 7,798.618 515.790 425.523 48.121 105.661 130.849 78.852 1-22 7010 27 4,546.483 319.110 321.737 52.931 60.832 146.110 84.875 1-23 7040 42 7,910.433 510.261 416.182 69.457 104.629 79.826 201.480 1-24 7070 43 7,612.259 515.790 332.634 71.273 178.716 102.911 71.064 1-25 7093 36 6,440.569 521.714 349.240 70.819 160.143 77.448 85.991 Lithologies: - Predominantly sandstone above 6830’ MD (lower Purple formation). Siltstone and shale with lesser amounts of sandstone from 6830’ MD to TD below the C-35 marker in the K3. Operational Summary: Continued drilling and slide drilling per plan from 6735’ to 7093’ TD; C&C as per 'MI'' Mud Enginer; pump three 30bbl High Vis sweeps; pump 4 BU as per Conoco Rep. (max gas 27units); TOOH PJSM; TOOH R/B stand every 30min from 7093' to 6450' MD; B/D Top Drive; TOOH from 6450' to 5308'; observed no swab or tight hole; C&C pump dry job, install stripping rubbers; TOOH PJSM; TOOH from 5308', to 739'; L/D BHA ; closed out bit; monitored hole 10min; R/U E-line to run open hole logs; presently R/U E-line at time of report. Failures: None ConocoPhillips Alaska, Inc. 2N-303A Daily Geologic Report Report for: G. Rizek J. Haynes, D. Mickey Date: 9/02/14 Time: 23:59 Current Depth (MD): 6735’ Current Depth (TVD): 5466’ Current Operations: Drilling 24 hr Footage (MD): 1333’ Drilling Parameters ROP: Current: 190 Max: 282 Torque: Current: 9175 Max: 11032 WOB: Current 8 Max: 71 RPM: Current: 149 Max: 156 PP: Current: 2798 Max: 3148 Lag: Strokes: 3376 Time: 34.45 Surf-Surf: Strokes: 3376 Time: 34.45 ECD: Current: 10.9 Max: 11.14 Mud Properties @ 2808 ’ MW: 9.7 FV: 48 PV: 18 YP: 28 FL: 3.5 Gels: 10/14/15 Sol: 9 pH: 10.0 Cl -: 2400 Ca ++: 80 MW Change: Depth: 6162’ From: 9.7 To: 9.6 Reason: Drilling 6640’ 9.6 9.7 Drilling Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 22 Max: 388 Depth (MD/TVD): 6620’/5377’ Avg BG : 38.3 LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res3 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas N/A Connection Gases 5880’/4804’ 5974’/4876’ 6069’/4948’ 6165’/5022’ 6260’/5095’ 6735’/5466’ 5 10 4 5 11 9 Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 1-6 5500 13 2478.2364 162.3198 248.5674 42.673 49.9414 1-7 6000 16 2914.383 150.927 158.625 26.544 90.136 116.680 54.463 1-8 6500 16 2926.854 163.505 182.144 80.484 1-9 6530 16 3113.213 220.376 233.518 63.556 68.102 1-10 6560 20 4016.546 221.956 245.713 49.483 1-11 6583 234 41694.956 4178.846 2613.331 366.352 893.167 159.318 231.040 1-12 6620 388 73422.075 6950.920 4064.518 562.921 1271.648 205.822 261.867 1-13 6650 28 4192.062 464.843 439.534 111.676 179.541 0.000 82.584 1-14 6680 195 35177.133 3041.028 2277.324 308.925 734.056 169.750 170.360 1-15 6710 236 42610.487 3690.702 2691.689 407.210 845.289 202.109 232.987 Lithologies: - Predominantly siltstone and claystone with lesser to trace amounts of sandstone, sand, and shale above 5750’ MD. Several thicker sand/sandstone beds drilled below this depth. Predominantly sandstone (Bermuda and Purple formations), with some siltstone below 6670’ MD. Operational Summary: Continued drilling and slide drilling per plan from 5402’ to 6735’ MD midnight depth; drilling at time of report. Failures: None ConocoPhillips Alaska, Inc. 2N-303A Daily Geologic Report Report for: G. Rizek J. Haynes, D. Mickey Date: 9/01/14 Time: 23:59 Current Depth (MD): 5402’ Current Depth (TVD): 4575’ Current Operations: Connection during drilling 24 hr Footage (MD): 1428’ Drilling Parameters ROP: Current: 96 Max: 330 Torque: Current: 5515 Max: 7479 WOB: Current 20 Max: 42 RPM: Current: 152 Max: 156 PP: Current: 2789 Max: 3126 Lag: Strokes: 2637 Time: 26.9 Surf-Surf: Strokes: 2637 Time: 26.9 ECD: Current: 11.14 Max: 11.14 Mud Properties @ 2808 ’ MW: 9.7 FV: 48 PV: 12 YP: 26 FL: 4 Gels: 15/18/32 Sol: 7.5 pH: 9.9 Cl -: 2100 Ca ++: 180 MW Change: Depth: 4255’ From: 9.6 To: 9.7 Reason: Drilling Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 22 Max: 49 Depth (MD/TVD): 5372’/4415’ Avg BG : 20 LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res3 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas None 44 Connection Gases 4927’/4064’ 5022’/4140’ 5117’/4215’ 5213’/4291’ 5308’/4365’ 5402/4438 7 11 1 2 9 12 Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 1 4000’ 2 153.153 2 4500’ 17 3131.713 8.277 146.839 3 5000’ 36 6327.398 140.5982 150.4897 Lithologies: - Predominantly siltstone and claystone with lesser to trace amounts of sandstone, sand, and shale. Operational Summary: Continued drilling and slide drilling per plan from 3974’ to 4832’ MD; C&C; CBU; establish survey, SPR's; monitor hole for 10 minutes; Short Trip from 4832' to 3885'; Service rig; TIH to 4830' washing down last stand; drill ahead from 4832’; preparing to drill after connection at 5402’ at time of report. Failures: None ConocoPhillips Alaska, Inc. 2N-303A Daily Geologic Report Report for: G. Rizek J. Haynes Date: 8/31/14 Time: 23:59 Current Depth (MD): 3974’ Current Depth (TVD): 3306’ Current Operations: Connection during Drilling 24 hr Footage (MD): 1300’ Drilling Parameters ROP: Current: 231 Max: 361.3 Torque: Current: 4685 Max: 5347 WOB: Current 27 Max: 37 RPM: Current: 147 Max: 153 PP: Current: 2709 Max: 2729 Lag: Strokes: 1845 Time: 18.83 Surf-Surf: Strokes: 1845 Time: 18.83 ECD: Current: 11.3 Max: 11.64 Mud Properties @ 2808 ’ MW: 9.6 FV: 51 PV: 6 YP: 41 FL: 4 Gels: 14/19/30 Sol: 7.5 pH: 10.0 Cl -: 2700 Ca ++: 180 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: 11 Max: 51 Depth (MD/TVD): 2982’/2705’ Avg BG : 13.5 LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res3 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas None Connection Gases None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 1 2982’/2705’ 48 8663 184 328 2 3947’/3416’ 14 2568 91 168 Lithologies: - N/A In cemented cased hole. Operational Summary: Completed top drive repairs, TIH to 2633’ and resumed drilling and slide drilling at 00:45 hrs; drilling and slide drilling to 2700’ MD; C&C; PJSM; B/D top drive, R/U 'LOT''perform ''LOT'' as per Conoco Company Rep,(LOT = 13.4ppg) pumped 1bbl,B/D test equipment and HCR kill and R/D test equipment; commenced drilling and slide drilling per plan; currently connecting and preparing to drill at time of report. Failures: None ConocoPhillips Alaska, Inc. 2N-303A Daily Geologic Report Report for: G. Rizek J. Haynes Date: 8/30/14 Time: 23:59 Current Depth (MD): 2454’ Current Depth (TVD): 2454’ Current Operations: Servicing top drive 24 hr Footage (MD): 219’* * in cement Drilling Parameters ROP: Current: 0 Max: 189.1 Torque: Current: 0 Max: 2806 WOB: Current 0 Max: 11 RPM: Current: 0 Max: 28 PP: Current: 0 Max: 1448 Lag: Strokes: 1133 Time: 15 Surf-Surf: Strokes: 1133 Time: 15.3 ECD: Current: 10.5 Max: 10.5 Mud Properties @ 2808 ’ MW: 9.6 FV: 47 PV: 10 YP: 23 FL: 6.5 Gels: 11/14/15 Sol: 7 pH: 8.9 Cl -: 3800 Ca ++: 480 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : 1 11.9 2656’/2656’ LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res3 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas None Connection Gases None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N 1 2642’/2642’ 20 3384 2 2370’/2370’ 4 393 Lithologies: - N/A In cemented cased hole. Operational Summary: Completed top drive repairs at 14:00 hrs; started drilling cement at 14:30 hrs at 2454'; drilled cement to 2675’ with spot samples collected every half hour after 2620’ in order to determine the percentage of cuttings of formation in relation to cement; downtime to troubleshoot the top drive at 21:30 hrs; top drive repairs in progress at time of report. Failures: None ConocoPhillips Alaska, Inc. 2N-303A Daily Geologic Report Report for: G. Rizek J. Haynes Date: 8/29/14 Time: 23:59 Current Depth (MD): 2454’ Current Depth (TVD): 2454’ Current Operations: Servicing top drive 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 @ 2808 ’ MW: 9.6 FV: 52 PV: 9 YP: 14 FL: 6 Gels: 11/12/13 Sol: 7 pH: 9.6 Cl -: 3000 Ca ++: 180 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas 2448’ 6u Connection Gases None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: - N/A In cemented cased hole. Operational Summary: Completed testing BOP’s install/remove wear bushing; pull test plug and install W/R; R/D test equipment; L/D test joint prepare floor for BHA; PJSM for P/U BHA; P/U BHA as per DD; PJSM to TIH; C/O elevators to 4''; TIH L/D top joint of HWDP on last stand; TIH with 4'' DP out of derrick from 739.53' MD to 1500' MD; C&C shallow test at 1499'; TIH from 1499' to 2426'; tag cement; C&C fill pipe; CBU (6 units gas maximum); B/D Top Drive; R/U to test casing; pressure test casing/shoe to 2500psi for 30min; C&C; R/D test equip, BD lines; drilling cement from 2426' to 2454'; downtime to troubleshoot the top drive, electrical, SCR, lube pump, and electric motor; waiting on parts to C/O electric motor for lube pump and complete top drive repairs at time of report. Failures: None ConocoPhillips Alaska, Inc. 2N-303A Daily Geologic Report Report for: G. Rizek J. Haynes Date: 8/28/14 Time: 23:59 Current Depth (MD): 3000’ Current Depth (TVD): 2550’ Current Operations: Testing BOP 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 @ 2808 ’ MW: 9.6 FV: 54 PV: 8 YP: 19 FL: 6 Gels: 13/14/15 Sol: 7 pH: 8.1 Cl -: 3000 Ca ++: 120 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas None Connection Gases None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: - N/A In cemented cased hole. Operational Summary: Continued to bring in last 48 joints of 4'' DP to pipe shed and strap and tally; continued to clean and service rig; P/U 4'' DP and racked back stands; install/remove wear bushing; clean and clear rig floor; PJSM drain stack; pull W/R; set test plug; P/U test tools - install test plug, won't set down all the way; POOH insure LDS are back out; all good; inspect rubber; test choke manifold - fill choke and stack; perform body test on BOP's, good test with AOGCC Lou Grimaldi on location to witness tests. The tests started at 14:22 hrs and continue at time of report. Failures: None ConocoPhillips Alaska, Inc. 2N-303A Daily Geologic Report Report for: G. Rizek J. Haynes Date: 8/27/14 Time: 23:59 Current Depth (MD): 3000’ Current Depth (TVD): 2550’ Current Operations: Loading DP 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 @ 0’ MW: 9.6 FV: 50 PV: 8 YP: 19 FL: 6 Gels: 13/14/15 Sol: 7 pH: 10.2 Cl -: 3900 Ca ++: 120 MW Change: Depth: From: To: Reason: Mud Loss event: Depth: Volume: Gas Data Ditch Gas: Current: Max: Depth (MD/TVD): Avg BG : LWD Summary Tools Run Depth Interval(MD/TVD) Hi Low Avg Comments GR N/A N/A N/A N/A N/A Res1 N/A N/A N/A N/A N/A Res2 N/A N/A N/A N/A N/A Res23 N/A N/A N/A N/A N/A Neutron N/A N/A N/A N/A N/A Sonic N/A N/A N/A N/A N/A Gas Events Depth (MD/TVD) Total Trip Gas 2808’ 10u Connection Gases None Gas Samples No. Depth (MD/TVD) TG C1 C2 C3 C4I C4N C5I C5N Lithologies: - N/A In cemented cased hole. Operational Summary: TOOH with Fish from 397’ MD to surface; L/D BHA; L/D 4 ¾” collars, easy in and out of slips with fish watch for hang ups; PJSM with GBR L/D 167' of 5.5” fish; clean clear rig floor; get all 5.5” casing out of pipe shed; load 3.5” cement string in pipe shed; R/U GBR running tools for 3.5” cement string; TIH, single in hole; C/O elevators to 4'' R/U rig tongs M/U XO'S, TIH out of derrick 17 stands, from 900' to 2518.21'; P/U DP single in hole from 2518.21' to 2740', space out tag bottom at 2745' MD; P/U 1'; C&C per mud engineer; tag cast iron plug at 2808' MD ; C&C per mud engineer; install cement lines - L/D JNT 61, M/U pup joint, install head pin wit cement hose, R/U chart, blow down Top Drive; C&C/displace – circulating with cement hose; BPM-6, PSI-400, BPM-8, PSI-603, line up to take returns to choke; primary cementing - fill lines; PT to 3500 psi; pump 15bbls mud push, 12.5ppg at 4.8bpm, 670 psi; drop ball; pump 22bbls 17ppg cement @ 4.4bpm, 182psi; pump 4bbls 12.5ppg, 4bpm 180 psi; swap to rig pump, pump 15bbls mud (215 strokes, 6bpm 380 psi); cement in place at 17:01 hours; R/U to run casing - R/D cement hose, blow back to cement truck, prep for POOH; TOOH from 2804' to 2422';C&C; drop ball, circulate pipe clean, stage pumps up to 12bpm 490psi; RICP from 2422' to 2337', monitor well; TOOH from 2337' to 900', R/B 16 stands; R/U to L/D 3.5” cement stinger; completion-trip tubing/DP - L/D 20 joints 3.5” 8R EUE; C/O tong dies due to collar OD; safety stand-down - talk to crew about why we watch the backstop when we unlatch the elevators and red zones in pipe shed, take photo's and continue to L/D tubing from 300' to surface, noticed cement on collars from 182' to mule shoe; R/D tongs; C/O elevators to 4" DP; service rig - load last 48 joints for picking up pipe; clean clear floor. Failures: None
