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211-023
RECEIVED STATE OF ALASKA Ali.OIL AND GAS CONSERVATION COMMON MAR 1 5 2018 REPORT OF SUNDRY WELL OPERATIONS � 1.Operations Abandon El Plug Perforations ❑ Fracture Stimulate El Pull Tubing ii iCiGAQ „wn ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate 0 Alter Casings Change Approved Program ❑ Plug for Redrill ❑ srforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: DAD Acid_ IE 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development ❑ Exploratory ❑ 211-023-0 3.Address: P. O. Box 100360, Anchorage,Alaska Stratigraphic ❑ Service 0 6.API Number: 99510 50-029-20496-64-00 7.Property Designation(Lease Number): 8.Well Name and Number. KRU 1 E-08AL2-01 ADL 25651,ADL25648 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/Kuparuk River Oil Pool 11.Present Well Condition Summary: Total Depth measured 9,582 feet Plugs measured None feet true vertical 6,398 feet Junk measured None feet Effective Depth measured 9,570 feet Packer measured 6272,7058,7227 feet true vertical 6,400 feet true vertical 5596,6095,6193 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 48 feet 18" 80'MD 80'TVD SURFACE 2,864 feet 10-3/4" 2,896'MD 2705'TVD PRODUCTION 7,537 feet 7" 7,568'MD 6395'TVD SLOTTED LINER 2,308 feet 2-3/8" 9,570'MD 6400'TVD cQ p®��E�} Perforation depth: Measured depth: 7643'-7944',8125'-8326',8326-9569' 12ei�' True Vertical depth: 6431'-6473',6452'-6436',6436'-6399' feet Tubing(size,grade,measured and true vertical depth) 3.5" L-80 7,299'MD 6,236'TVD Packers and SSSV(type,measured and true vertical depth) PACKER-3-1/2"X5-1/2"BAKER FAB PACKER 45-FA-36 6,272'MD 5,596'TVD PACKER-3-1/2"X5-1/2"BAKER FAB PACKER 45-FA-36 7,058'MD 6,095'TVD PACKER-BAKER FAB PACKER 45-FA-36 7,227'MD 6,193'TVD SSSV-Nipple 546'MD 546'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 7300'-7987'MD Treatment descriptions including volumes used and final pressure: Pumped 100 bbl DAD acid @ 2786 psi 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 . 0 668 838 3516 Subsequent to operation: 0 0 825 1105 2648 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑✓ Exploratory ❑ Development p ❑ Service E Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG L GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-485 Contact Name: Jason Burke Authorized Name: Jason Burke Contact Email: Jason.Burke@conocophillips.com Authorized Title: Staff Wells Engineer Date: O�� //d Contact Phone: (907)265-6097 Authorized Signatur P77- 3/ 77/i( '4745 .J REcOms Form 10-404 Revised 4/2017 �'� 2� it Original Only ,,e. KUP INJ 0 1E-08A CQ AliIn� n Well Attributes Max Angle&MD TD • Alaska Inc Wellbore API/DWI Field Name Wellbore Status ncl(°) MD(MB) Act Btm(ftKB) Cmrov''uipa 500292049601 KUPARUK RIVER UNIT INJ 8,422.0 •-- - Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date DEVIATED-1E-08A,8/3120159'.30'.20 AM SSSV:NIPPLE Last WO: 1/28/2011 _ 38.99 10/28/1980 Vedical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date ------------ - - _ Last Tag SLM 7,260.0 8/28/2014 Rev Reason:PULL PLUG hipshkf 8/31/2015 ............ HANGER;24.3 811 '" i Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WtlLen(I...Grade Top Thread l CONDUCTOR 16 15.060 32.0 80.0 80.0 65.00 H-40 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread nos tum,SURFACE 10 3/4 9.950 31.8 2,895.6 2,704.5 45.50 K-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread I WINDOW A 8 6.000 5,712.0 5,722.0 5,120.5 26.00 L-80 .AAA CONDUCTOR;32.0-80.OAxn.s✓ ' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread PRODUCTION 7 6.276 30.9 7,568.0 6,394.5 26.00 K-55 BTC NIPPLE;545.8 ' Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread I LINER A 51/2 4.950 5,491.6 7,860.0 6,570.8 15.50 L-80 HD-L Liner Details GAS LIFT,2.336.5 0 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 5,491.6' 4,921.4 28.84 PACKER BAKER ZXP LINER TOP PACKER"ZXPN"w/ 5.500 5.5"Hyd 563 box down,5.50"ID 10'PBR 5,508.1 4,935.7 29.15 HANGER BAKER LINER HANGER"HMC"Liner Hanger 4.890 SURFACE;31.7.2,895.6 Tubing Strings Tubing Description String Ma...1D(in) Top(ftKB) Set Depth(ft...Set Depth(TOD)(...Wt(Ib/ft) Grade Top Connection GAS LIFT;3,479.7 TUBING 31/2 2.992 24.3 7,299.9 6236.5 9.30 L-80 EUEm0RD I Completion Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) GAS LIFT;4,532.2111 24.3 24.3 0.00 HANGER FMC Gen III TUBING HANGER 3.500 545.8 545.8 0.65 NIPPLE CAMCO 3-1/2""X"NIPPLE w/2.813" 2.813 6,253.5 5,581.2 38.05 SEAL ASSY BAKER SEAL ASSEMBLY/LOCATOR 3.000 GAS LIFT;5,396.7 6,256.7 5,583.7 38.20 PBR 80-40 PBR w/special trim OD,3-1/2"EUE box 3.000 6,270.3 5,594.3 38.83 ANCHOR BAKER 80-40 KBH-22 ANCHOR SEAL ASSEMBLY 2.960 6,271.9 5,595.6 38.90 PACKER 3-1/2"x 5-1/2"BAKER FAB PACKER 45-FA-36 3.000 7,056.1 6,093.7 54.88 ANCHOR KBH-22 Anchor Seal Assembly,EUE 8 RDL 2.960 7,057.8 6,094.7 54.88 PACKER 3-1/2"x 5-1/2"Baker FAB Packer 45-FA-36 3.000 II 7,070.1 6,101.8 54.90 NIPPLE CAMCO 3-1/2"X-NIPPLE,2.813"EUE 8 Rnd 2.813 7,224.9 6,191.9 53.35 ANCHOR BAKER ANCHOR SEAL ASSEMBLY 2.960 WINDOW A;5,712.0.5,7220-A I 7,226.6 6,192.9 53.35 PACKER -BAKER FAB PACKER 45-FA-36 3.000 ali 7,266.1 6,216.4 53.50 NIPPLE CAMCO X-NIPPLE w/2.813"profile EUE 8rd pin x pin 2.813 GAS LIFT;6,199.8 7,299.0 62360 53.61 SHOE 3-1/2"WWIRELINE ENTRY GUIDE 2.960 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl SEAL ASSY;6,253.5 - - Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 7,563.0 6,391.5 52.96 WHIPSTOCK BAKER THRU TUBING WHIPSTOCK FOR 4/4/2011 0.000 WESTERN LATERALS 1E-08AL2 8 1E-08AL2-01 PBR;6,256.7 ANCHOR;6,270.3 I i' 7,645.0 6,441.1 52.57 WHIPSTOCK BAKER THRU TUBING WHIPSTOCK FOR NEW 2/21/2011 0.000 PACKER;6,271.9 f "- LATERALS ijit- 7,698.0 6,473.4 52.51 CMT Retainer CMT RETAINER SET IN'A'FOR LATERAL 2/17/2011 0.000 SIDETRACKS Perforations&Slots Shot Dens _ Top(ND) Btm(TVD) (shots/f ANCHOR;7,056.1 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Com PACKER;7,057.8 7,517.0 7,537.0 6,363.9 6,375.9 2/17/2011 6.0 APERF TUBING PUNCHES: a. 2.5"HSD 2506 PF HMX, 111 60 Deg.Phase NIPPLE;7,070.17,564.0 7,574.0' 6,392.1 6,398.1 2/17/2011 6.0 APERF TUBING PUNCHES: ' 2.5"HSD 2506 PF HMX, al 60 Deg.Phase al 7,645.0 7,655.0 6,441.1 6,447.2 2/17/2011 6.0 APERF TUBING PUNCHES: 2.5"HSD 2506 PF HMX, ANCHOR;7,224.9 - 60 Deg.Phase PACKER;7,226.6 Cement Squeezes Il Top(ND) Btm(ND) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Com 7,047.0 7,645.0 6,088.5 6,441.1 CMT PLUG 2/20/2011 NIPPLE;7,266.1 Mandrel Inserts St on N Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com SHOE;7,299.0 1' 2,336.5 2,231.6 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/15/2011 2 3,479.7 3,199.0 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/15/2011 APERF;7,517.0.7.537.0- 3 4,532.2 4,090.4 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/15/2011 PRODUCTION;30.9-7568.0 4 5,396 7 4,838.1 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/15/2011 APERF;7,564.0-7,574.0 5 6.199.8 5,538.2 CAMCO KGB2-9 1 GAS LIFT DMY BK 0.000 0.0 1018'2014 WHIPSTOCK;7,563.0 AL2-01 Slotted Liner;7,261.7- - -.. Notes:General&Safety 9,570.0 ! End Date Annotation 8/24/2010 NOTE:View Schematic w/Alaska Schematic9.0 SLOTS;7,642.6-8,769.1 i 4/20/2011 NOTE:CTD Drilled,AL1,AL1-01,AL1-02,AL1-03,AL2,AL2-01 WHIPSTOCK;,64 AL1-01 Slotted Liner;7 .8- 1/18/2012 NOTE:WAIVERED WELL-PACKER SET TOO HIGH 10,.350.03.915 ■ u APERF;7,645.0.7,655.0 CMT Retainer;7,698.0 '.I.1,_ 1 LINER A;5,491.6-7,860.0 KUP INJ . 1 E-08AL2-01 Cd1000lhi -' • � .i Well Attributes Max Angle&MD TD • AlaskaI Wellbore API/UWI Field Name Wellbore Status ncl 7) MD(ftKB) Act Otto(ItKB) 500292049664 KUPARUK RIVER UNIT INJ 102.65 8,590.26 9,580.0 --- Comment H2S(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Date DEVIATED-1E-08AL2-01.8/31/201593527 AM SSSV:NIPPLE Last WO: 1/28/2011 38.99 10/28/1980 Vertical schemato(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date - --------------- - -- --Last Tag:SLM 7,260.0 8/282014 Rev Reason:PULL PLUG hipshkf 8/31/2015 HANGER,24.3 ..;,... .' a.It '. Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread AL2-01 Slotted Liner 2 3/8 1.995 7,261.7 9 570 0 6,399.0 4.60 L-80 STL Liner Details Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl 7) Item Des Com (in) 7,261.7 6,213.8 53.48 DEPLOY GS Full deployment sleeve(2.25 X 6'PBR) 1.000 .fn,CONDUCTOR;32.Da0.o,e4au_.ni !7° 8,325.6 6,436.3 94.10 DEPLOY Shorty deployment sleeve(ran on first liner segment) 1.000 NIPPLE;545.8 Perforations&Slots GAS LIFT;2,336.5 1W Shot Dens Top(TVD) Btm(ND) (shots/f Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn 7,643.3 7,942.8 6,430.9 6,472.5 4/19/2011 32.0 SLOTS Alternating solid/slotted F:, pipe-0.125"x2.5"@ 4 circumferential adjacent SURFACE;31.7-2,8956^4 - rows,3"centers staggered 18 deg,3'non --- -slotted ends GAS LIFT;3,479.7 8,125.0 8,326.4 6.4524 6.436.3 4/19/2011 32.0 SLOTS Alternating solid/slotted -_ _ pipe-0.1255(2.5"@ 4 circumferential adjacent rows,3"centers GAS LIFT;4,532.2 I, staggered 18 deg,3'non -slotted ends 8,326.0 9,569.0 6,436.3 6,399.1 4/19/2011 32.0 SLOTS Alternating solid/slotted pipe-0.125"x2.5"@ 4 GAS LIFT;5,396.7 Mt circumferential adjacent rows,3"centers staggered 18 deg,3'non -slotted ends Notes:General&Safety End Date Annotation -i 4/20/2011 NOTE CTD Drilled,AL1,AL1-01,AL1-02,AL1-03,AL2,AL2-01 WINDOW A;5,712.0.5,722.0—A , GAS LIFT;6,199.8 — 111 SEAL ASSY;6,253.5 PBR;6,256.7 '..r ANCHOR;6,270.3 I' PACKER;6271.9 III ANCHOR;7,056.1 PACKER;7,057.8 I I NIPPLE;7,070.1 a a a I ANCHOR;7,224.9 PACKER;7,226.6 I NIPPLE;7,266.1 I SHOE;7,299.0 P APERF;7,517.0-7,537.0 WHIPSTOCK;7,563.0 PRODUCTION;30.9-7,568.0 APERF;7,564.0-7,574.0 LINER A;5,491.67,860.0 SLOTS;7,643.3-7,942.8 SLOTS;8,125.08,326.4 4. AL 2 Slotted liner;0,5262- y.� 10.260.0 l l SLOTS;8.326.09.560.0 T r AL2-01 Slotted Leer;7.261.7- i 1 9.570.0 • • 1 E-08AL2-01 DTTMSTART JOBTYP SUMMARYOPS 02/22/18 PUMPING WAG TRACKING PUMP 90 BBLS SEAWATER ONLY PUMP 10 BBLS METH JOB COMPLETE 02/23/18 ACID RIH TO RESISTANCE DEPTH AT 7989' CTMD. SQUEEZE 100 BBL. DAD ACID, 7262' - 7989'. RETURN WELL TO INJECTION. JOB COMPLETE. or Tyi� • • hwP'1‘'\ I � s THE STATE Alaska Oil and Gas 40 0 o fA Conservati®n Commissi®n LAsKA S - _ 333 West Seventh Avenue Alaska 99501-3572 Anchorage, GOVERNOR BILL WALKER Main: 907.279.1433 OF Q„ ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Jason Burke Staff Wells Engineer SCANNED Fa 1 6 tt ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, KRU 1E-08AL2-01 Permit to Drill Number: 211-023 Sundry Number: 317-485 Dear Mr. Burke: 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, PIh — Cathy P oerster Commissioner DATED this /4iay of February, 2018. RE r.nnS r,1-- FEB 15 2C18 RECEIVED • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION OCT 1 1 2017 APPLICATION FOR SUNDRY APPROVALS OZ 4 )44.1 l 8" 20 AAC 25.280 G C C 1.Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate 0 Pull Tubing ❑ Change Appr3vv��e-d Program❑ Plug for Redrill ❑ Perforate New Pool IIIRe-enterSusp Well ❑ Alter Casing 11Ot fef.AAcid Stir/ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhilliDs Alaska, Inc. Exploratory ❑ Development ❑ 211-023-0 3.Address: ❑ 6.API Number: Stratigraphic ❑ Service P. O. Box 100360,Anchorage,Alaska 99510 50-029-20496-64-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 0 KRU 1 E-08AL2-01 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25651,ADL25648 Kuparuk River Field/Kuparuk River Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 9,582' 6,398' 9570' 6400' 3353 NONE NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 48' 16" 80' 80' Surface 2,864' 10-3/4" 2,896' 2705' Intermediate Production 7,537' 7" 7,568' 6395' AL2-01 Slotted Liner 2,308' 2-3/8" 9,570' 6400' Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 7643'-7944' 6431'-6473' 8125'-8326' 6452'-6436' 3.500" L-80 7,299' 8326'-9569' 6436'4399' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER-3-1/2"X 5-1/2"BAKER FAB PACKER 45-FA-36 MD=6272 TVD=5596 PACKER-3-1/2"X 5-1/2"BAKER FAB PACKER 45-FA-36 MD=7058 TVD=6095 PACKER-BAKER FAB PACKER 45-FA-36 MD=7227 TVD=6193 SSSV-CAMCO Nipple MD=546 TVD=546 12.Attachments: Proposal Summary ❑ Wellbore schematic ❑ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 14/4/2,111ZCommencing Operations: OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑✓ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned E 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Jason Burke Contact Name: Jason Burke Authorized Title: Staff Wells Engineer Contact Email: Jason.Burke@cop.com ( i /� Contact Phone: (907)265-6097 _ Authorized Signature �J COMMIS ON USE ONLY Conditions of approval: otify Commission so that a representative may witness Sundry Number: 3 ' LI Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No Fe Subsequent Form Required: /a " 4 a P APPROVED BY Approved by: ai COMMISSIONER THE COMMISSION Date: 2 "-/it..../8 I � � V77- 2111-,O � Submit Form and hf �Form 10 3 Revised 4/2017 Approved application is valid for 1 d t I. Attachments in Duplicate • • ConocoPhillips Alaska,Inc. Drilling&Wells ConocoPhillips Well Intervention Alaska 1E-08AL2-01 Acid Treatment (10404365) Engineer: Jason Burke Wells Engineer 907-231-4568 DAD, dynamic acid dispersion, is an acid outside-phase emulsion prepared and stabilized with dispersing agent F103. The purpose of the dispersion is to simultaneously dissolve acid-soluble minerals and remove oil paraffinic deposits. Target areas can be tubulars, perforations or the critical matrix. Objectives: Spot Dynamic Acid Dispersion (DAD) treatment with CT into perforations to increase injectivity • Coiled Tubing: Spot 100 bbl of DAD into formation 1. MIRU CT, MU 5 port wash nozzle BHA 2. Begin RIH, enter slotted liner completion at 7262' MD. 3. Continue RIH until end of first liner section at 8325' MD is reached or until CT locks up 4. When CT has reached ultimate depth begin pumping DAD treatment. When treatment is exiting the CT (depending on CT volume) shut in the choke and begin POOH at a rate that will allow treatment to be spotted from final depth to 7262' MD (At 8325' MD 100 bbl/1 BPM=100 min & 1063 ft / 100 min=10.5 fpm). Chase the DAD treatment out of the CT with produced water or diesel. a. Do not exceed 4500 psi surface pressure 5. After an additional 5 bbl of fluid has been injected behind the treatment POOH 6. RDMO CT. Return well to injection. Function SLB Code Concentration Quantity Acid corrosion inhibitor A264 4 gpt 15 gal HC1 H036 221.4 gpt 934 gal Emulsifier F103 15 gpt 63 gal Iron Control L058 20 ppt 76 lbs Non-emulsifier W054 2 gpt 19 gal Xylene A026 100 gpt 420 gal October 3, 2017 1E-08 Well Work Procedure Page 1 of 1 KUP IN 1E-08A ConocoPhillips .a Well Attribut Max Angle 0 TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) ConocoPhillips 500292049601 KUPARUK RIVER UNIT INJ 8,422.0 ••• Comment H2S(ppm) DateAnnotation End Date KB-Grd(ft) -Rig Release Date DEVIATED-1E-08A.10/10/2017 8:34:00 AM SSSV:NIPPLE I Last WO: 1/28/2011 38.99 10/28/1980 Vertical schematic(actual) _ - Annotation Depth(ftKB) End Date Annotation Last Mod By End Date MANGER;24.3 - I Last Tag:SLM 7,260.0 8/28/2014 Rev Reason:PULL PLUG hipshkf 8/31/2015 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread 1 I CONDUCTOR 16 15.060 32.0 80.0 80.0 65.00 H-40 WELDED 1 1 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread I '''''SURFACE 10 3/4 9.950 31.8 2,895.6 2,704.5 45.50 K-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WtlLen g...Grade Top Thread WINDOW A 8 6.000 5,712.0 5,722.0 5,120.5 26.00 L-80 -^4^-,CONDUCTOR;32.0-00.0• Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WtlLen(I...Grade Top Thread NIPPLE;565.8 PRODUCTION 7 6.276 30.9 7,568.0 6,394.5 26.00 K-55 BTC Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen 0...Grade Top Thread 0 LINER A 51/2 4.950 5,491.6 7,860.0 6,570.8 15.50 L-80 HD-L ' GAS LIFT;2,338.5 a. Liner Details all Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl r) Item Des Com (in) 5,491.6 4,921.4 28.84 PACKER BAKER ZXP LINER TOP PACKER"ZXPN"w/ 5.500 5.5"Hyd 563 box down,5.50"ID 10'PBR SURFACE;31.7-2,895.8-•• 4 5,508.1 4,935.7 29.15 HANGER BAKER LINER HANGER"HMC"Liner Hanger 4.890 Tubing Strings GAS LIFT;3,479.7 - Tubing Description String I Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...WI(Ib/ft) Grade Top Connection TUBING 31/21 2.9921 24.31 7,299.91 6,236.5 9.301 L-80 f EUEmBRD Completion Details GAS LIFT;6,532.2 Nominal ID i Top(ftKB) Top(ND)(IKB) Top Incl r) Item Des Com (in) 124.3 24.3 0.00 HANGER FMC Gen III TUBING HANGER 3.500 545.6 545.8 0.65 NIPPLE CAMCO 3-1/2""X"NIPPLE w/2.813" 2.813 GAS LIFT,6,096.7 6,253.5 5,581.2- 38.05 SEAL ASSY BAKER SEAL ASSEMBLY/LOCATOR 3.000 a 6,256.7 5,583.7 38.20 PBR 80-40 PBR w/special trim OD,3-1/2"EUE box 3.000 6,270.3 5,594.3 38.83 ANCHOR BAKER 80-40 KBH-22 ANCHOR SEAL ASSEMBLY 2.960 6,271.9 5,595.6 38.90 PACKER 3-1/2"x5-1/2"BAKER FAB PACKER 45-FA-36 3.000 7,056.1 6,093.7 54.88 ANCHOR KBH-22 Anchor Seal Assembly,EUE 8 RDL 2.960 7,057.8 6,094.7 54.88 PACKER 3-1/2"x 5-1/2"Baker FAB Packer 45-FA-36 3.000 7,070.1 6,101.8 54.90 NIPPLE CAMCO 3-1/2"X-NIPPLE,2.813"EUE 8 Rnd 2.813 WINDOW A.5.712.0-5.7220 I I ', 7,224.9 6,191.9 53.35 ANCHOR BAKER ANCHOR SEAL ASSEMBLY 2.960 7,226.6 6,192.9 53.35 PACKER BAKER FAB PACKER 45-FA-36 3.000 GAS LIFT:6.199.8 7,266.1 6,216.4 53.50 NIPPLE CAMCO X-NIPPLE w/2.813"profile EUE 8rd pin x pin 2.813 I 7,299.0 6,236.0 53.61 SHOE 3-1/2"WWIRELINE ENTRY GUIDE 2.960 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) SEAL ASSY;6,253.5 Top(ND) Top Incl ITop(ftKB) (ftKB) Cl Des Com Run Date ID(In) PBR;6,258.7 7,563.0 6,391.5 52.96 WHIPSTOCK BAKER THRU TUBING WHIPSTOCK FOR 4/4/2011 0.000 ANCHOR;6,270.3 WESTERN LATERALS 1E-08AL2 8 1E-08AL2-01 PACKER;8.271.9 1'U 7,645.0 6,441.1 52.57 WHIPSTOCK BAKER THRU TUBING WHIPSTOCK FOR NEW 2/21/2011 0.000 LATERALS 7,698.0 6,473.4 52.51 CMT Retainer CMT RETAINER SET IN'A'FOR LATERAL 2/17/2011 0.000 SIDETRACKS ill Perforations&Slots Shot Dens Top(TVD) Btm(ND) (shots/ ANCHOR;7,056.1 Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Corn PACKER;7,057.8 7,517.0 7,537.0 6,363.9 6,375.9 2/17/2011 6.0 APERF TUBING PUNCHES: 2.5"HSD 2506 PF HMX, It 60 Deg.Phase NIPPLE;7,070.1 7,564.0 7,574.0 6,392.1 6,398.1 2/17/2011 6.0 APERF TUBING PUNCHES: 2.5"HSD 2506 PF HMX, 60 Deg.Phase 7,645.0 7,655.0 6,441.1 6,447.2 2/17/2011 6.0 APERF TUBING PUNCHES: h` 2.5"HSD 2506 PF HMX, IF 60 Deg.Phase ANCHOR;7,224.9 Cement Squeezes PACKER;7,226.8 4 ai Top(TVD) Btm(TVD) Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Des Start Date Corn 7,047.0 7,645.0 6,088.5 6,441.1 CMT PLUG 2/20/2011 Mandrel Inserts NIPPLE;7,288.1 St a6 on Top(TVD) Valve Latch Port Size TRO Run N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (In) (psi) Run Date Corn SHOE;7,299.0 r 1 2,336.5 2,231.6 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/15/2011 2 3,479.7 3,199.0 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/15/2011 APERF;7,517.0-7,537.0 . 3 4,532.2 4,090.4 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0'7/15/2011 PRODUCTION;38.9-7.580.0 4 5,396.7 4,838.1 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 00 7/15/2011 APERF;7,584.0-7,574.0 5 6,199.8 5,538.2 CAMCO KGB2-9 1 GAS LIFT DMY BK 0.000 0.0 10/8/2014 WHIPSTOCK 7,563.0 AL2-01 Slotted Liner;7.261.7- Notes:General&Safety 9,570.0 End Date Annotation 8/24/2010 NOTE:View Schematic w/Alaska Schematic9.0 CMT PLUG;7,047.010(0 SLOTS;7,842.8-0,769.1 4/20/2011 NOTE:CTD Drilled,AL1,AL1-01,AL1-02,AL1-03,AL2,AL2-01 WHIPSTOCK 7,645.0 AL1-01 Slotted Linz;7,641.8- ' ' 1/18/2012 NOTE:WAIVERED WELL-PACKER SET TOO HIGH 10 350.0 APERF;7,845.0.7,855.0 CMT Retainer;7.698.0 P I LINER A,5.491.6-7,860.0 1.,p, KUP IN* 08AL2-01 ConoccPhilltps z Well Attribut Max Angle igig TD Alaska.It lc. Wellbore API/UWI Field Name Wellbore Status nal(") MD(ftKB) Act Btm(ftKB) Conocophillips 500292049664 KUPARUK RIVER UNIT INJ 102.65 8,590.26 9,580.0 ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date DEVIATED-IE-08AL2-01,10/10/20178:32:51 AM SSSV:NIPPLE _ Last WO: 1/28/2011 _ 38.99 10/28/1980 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER,24.3 ilir'' '• Last Tag:SLM 7,260.0 8/28/2014 Rev Reason.PULL PLUG hipshkf 8/31/2015 I. Casing Strings Casing Description 00(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread 1 ij. AL2-01 Slotted Liner 2 3/8 1.995 7,261.7 9,570.0 6,399.0 4.60 L-80 STL Liner Details III.III Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(") Item Des Com (in) _/•../,–.CONDUCTOR;32.0-8E0- 7,261.7 6,213.8 53.48 DEPLOY GS Full deployment sleeve(2.25 X 6'PBR) 1.000 NIPPLE;545.8 = 8,325.6 6,436.3 94.10 DEPLOY Shorty deployment sleeve(ran on first liner segment) 1.000 II Perforations&Slots GAS LIFT,2.336.5 Shot Dens Top(TVD) Btm(TVD) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com 7,643.3 7,942.8 6,430.9 6,472.5 4/19/2011 32.0 SLOTS Alternating solid/slotted SURFACE;31.7-2,895.6 pipe-().125"X2.5"@ 4 circumferential adjacent rows,3"centers GAS LIFT;3.479.7 staggered 18 deg,3'non -slotted ends 111 8,125.0 8,326.4 6,452.4 6,436.3 4/19/2011 32.0 SLOTS Alternating solid/slotted pipe-0.125"x2.5"@ 4 GAS LFT;4,532.2circumferential adjacent P , sows, centers deg, 18ed 3'non -slotted ends GAS LIFT;5,396.7 8,326.0 9,569.0 6,436.3 6,399.1 4/19/2011 32.0 SLOTS Alternating solid/slotted pipe-0.125"02.5"@ 4 circumferential adjacent rows,3"centers staggered 18 deg,3'non -slotted ends 1 77.I Notes:General&Safety End Date Annotation • 4/20/2011 NOTE:CTD Drilled,AL1,AL1-01,AL1-02,AL1-03,AL2,AL2-01 WINDOW A,5,712.0-5,722.0 GAS LIFT;6,199.8 IIISEAL ASSY;6,2535 PBR;6,256.7 •. ANCHOR;6,270.3 IA •PACKER;6.271.9 ' I ANCHOR;7056.1 PACKER,7057.8 i III NIPPLE;7,07E1 la B al ANCHOR,7,224.9 PACKER;7,226.6 NIPPLE:7,266.1 _ ,�. SHOE,7,299.0 APERF,7,517E-7,537E--.—• WHIPSTOCK 7,563.0 PRODUCTION;30.9-7,568.0 APERF;7.564.0-7,574.0 LINER A;5.491.6-7,86E0 CMT PLUG;7,047.0!KB SLOTS,7,643.3-7.942.8 SLOTS;8,125.08,326.4 ' t- illAL 2 Slotted liner,10,260.0 0,2 .0 S+ 10,260.0 SLOTS,8,326.0-9,569.0 j AL2-01 Slotted Liner,7,261.7- I l 9.570.0 • • Bettis, Patricia K (DOA) From: Bettis, Patricia K (DOA) Sent: Friday, October 27, 2017 2:06 PM To: Burke,Jason (Jason.Burke@conocophillips.com) Subject: FW: KRU 1 E-08AL2-01 (PTD 211-023): Sundry Application for Acid Stimulation Jason, Have you received this email? Thanks, Patricia From: Bettis, Patricia K(DOA) Sent:Thursday, October 12, 2017 10:37 AM To: Burke,Jason (Jason.Burke@conocophillips.com)<Jason.Burke@conocophillips.com> Subject: KRU 1E-08AL2-01(PTD 211-023): Sundry Application for Acid Stimulation Good morning Jason, KRU 1E-08AL2-01 is a lateral off KRU 1E-08A. In order for the AOGCC to have a complete well history of activities complete for all the wells associated with the motherbore, please submit sundry applications for KRU 1E-08A, KRU 1E- 08AL1, KRU 1E-08AL1-01, KRU 1E-08AL1-02, KRU 1E-08AL2,and KRU 1E-08AL1-03. Thank you, Patricia Patricia Bettis Senior Petroleum Geologist Alaska Oil and Gas Conservation Commission 333 West 7th Ave.,Ste 100 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. 1 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. c4j - Qc3 Well History File Identifier Organizing(done) Two-sided III 11111111 III ❑ Rescan Needed II I'III II II III RES N DIGITAL DATA OVERSIZED (Scannable) olor Items: ❑ Diskettes, No.19) 11:24s: reyscale Items: ❑ Other, No/Type: er Items Scan able by a Large Scanner �©5S ❑ Poor Quality Originals: `1 OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Date: (c)ligp /s/ , Project Proofing I IIIIIIIIII 11111 BY: aria Date: 401 I g fit, /s/ 1 ' Y P Scanning Preparation a x 30 = pD + cq 14 = TOTAL PAGES Vt. (21 r (Count does not include cover sheet) 04BY: 4111. Date: i g r g. /s/ Production Scanning IIIIIIIIIIIIIIII Stage 1 Page Count from Scanned File: '5 (Count does include cov r sheet) Page Count Matches Number in Scanning PJL1L paration: YES NO BY: te) Date: I$ /s/ M f Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. 1111E111T I I ReScanned 1111111111111111111 BY: Maria Date: /s/ Comments about this file: Quality Checked III 111111 III IIII III 0 o c 'a f0 0 0 ° 0 to V a) iu m -al cU 0) coa)Tr N a p LL 0) O. _• U C aa' d� n_Ce OCLL o \ E az` .aw " w a w p E ._.>_ > > p >U 00 d Z i) o 2 cC 2 CC i-C K c d c0 i Q To O O 13> ‘- ,, r r r r r 1,. Z N y N N N N N N LU in Q) O) co O) U 0 O Ce J co o co co co co 4 Z E c jl v) 2 p w E S 2 p p p p aci ac) N� a m Y 00 0 0 0 0 0 0 I E LL Jc .a 0 Q a) 0.'N N N N N N I co LO co to co Q. J U 3 N co a) a) co a) a) ap E W J yc � NZre (0/ 6 a t o o r- r- N c0 co L0 co U do CO CO N. r� .D W Z J C) v 0 d pa) U) Z _ � cc o O Wiz° d 'z f- Q 7 N O I J o. m � co I m I ^ 0 o c)� o 0 0 T E LL N c ZI J U U U 'N p !' 4 0 N °) w ') • 1 I a p rn �a N E n O p N 1 o J co U � N Uco J coa < 1 1i W a 1 0 Z o Z N • N lI C HTo j co v _ n ) V) a oH Q a Y I— °) < p o- ZI N .>` 0 Z o m m i i i > a) U p 2 Z w in w in mJcei4 u) aa)) aa)) cu aii) `)) Z 0 cr cC ce _ 2 j c c C C C C p a) O O O O O O 1 co SII CL Z c c c c F ,� 0 0 co Z H C 0z ', O a),_ I co E c a (>__z o f- p d 1= ..te k N 2 O O 0 W 0 Z d O 1 CL Q `o it .. a p Z �. E E I E E v • ! z 1 p t_A > 0 100 u c a)9 1 Q J w Z Q a) o) d 0 W Q a —y rn a a 0 0 0 0 0 'p 0 p r -caap) o d d' 0 F- s J 0 F- W J J J W 3 < 0 <Ce H 0 O O Tr "? (\ t0 _(/ Of N > I N U T I 9 5 c•l 0 I . Z a a Z a u) o Ce J a O cn a v CA J L J_ W = U W z J Z • - Q . 0 0 N C J o 1.1- N c r. o 2N a 75 • N r E U o CO N Q < 9 CO I— W z N CO Lt N Lt V M V) a o Q a 0 o a) QaIF 0 Z of 1-$ U E Z m rn COOD 1 N m O F- o r 3 N d d 4: O W V te+ co 03 a E E m a 0 a 0 STATE OF ALASKA ALASIw OIL AND GAS CONSERVATION COMMI`_.JN REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r Rug Perforations r Perforate r Other [ , WINJ to WAG Alter Casing r Pull Tubing r Stimulate-Frac r Waiver r Time Extension r Change Approved Program r Operat.Shutdown r Stimulate-Other r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 211-023-0 3.Address: 6.API Number: Stratigraphic r Service (v`; P. O. Box 100360,Anchorage,Alaska 99510 50-029-20496-64 ^Q a 7.Property Designation(Lease Number): 8.Well Name and Number: ADL025651;ADL025648 - 1 E-08AL2-01 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 11. Present Well Condition Summary: Total Depth measured 9582 feet Plugs(measured) None true vertical 6398 feet Junk(measured) None Effective Depth measured 9570 feet Packer(measured) 5492, 7058 true vertical 6400 feet (true vertical) 4921,6095 Casing Length Size MD TVD Burst Collapse CONDUCTOR 48 16 80 0 0 0 SURFACE 2864 13 2896 0 0 0 PRODUCTION 7537 7 7568 0 0 0 AL2-01 SLOTTED LINER 2308 2.625 9570 0 0 0 Perforation depth: Measured depth: 7643-7943;8125-8326; 8326-9569 True Vertical Depth: 6431-6473;6453-6436;6436-6399 Tubing(size,grade,MD,and TVD) 3.5, L-80,7299 MD,6236 TVD Packers&SSSV(type,MD,and TVD) PACKER-5-1/2"X 7"BAKER ZXP LINER TOP PACKER"ZXPN"@ 5492 MD and 4921 TVD PACKER-3-1/2"X 5-1/2"BAKER FAB PACKER 45-FA-36 @ 7058 MD and 6095 ND SSSV=NIPPLE @ 546 MD and 546 ND 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 3077 1158 3355 14.Attachments 15.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service 17 - Stratigraphic r 16.Well Status after work: Oil r Gas r VVDSPL r Daily Report of Well Operations GSTOR r VVINJ r WAG 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 Bob Christensen/Darrell Humphrey Email N1139L conocophillips.com Printed Name R••ert s Christens:n Title NSK Production Engineering Specialist Signature / j --7 �/ Phone:659-7535 Date ,SAeg A•r341117 VVf ter/3 44,6 OM Form 10-404 Revised 12/2012 RE3DMS MAR 2 8 2013ASubmit Original Only 4/ 2I 13 u kJ 47/6/13 ... __.. ...._.. ti 1 E-08AL2-01 DESCRIPTION OF WORK COMPLETED SUMMARY 11/24/11 STATE WITNESSED (JOHN CRISP) MIT-T( PASSED ) 03/25/12 RIH WITH TMDL PULSE NEUTRON LOGGING TOOLS AND RECORD BASELINE DATA FROM 7300'TO GAS LIFT MANDREL @ 5397' IN PREPORATION FOR MI INJECTION/ RETURN LATER TO CHECK FOR GAS MIGRATION 01/31/13 (AC EVAL) MITIA(PASSED) @ 2500 PSI, OC-POT(PASSED), OC-PPPOT(PASSED) @ 2000 PSI 03/07/13 TAGGED TOP OF LINER @ 7261' RKB. MEASURED BHP (3288 psi ) @ 7100' RKB. JOB COMPLETE. 03/20/13 Commenced WAG EOR Injection .. .. . .___.._ . • -"; KUP 1 E-08AL2-01 ConocoPhillipsSR • Well Attributes Max Angle&MD TD Wellbore APVUWI Field Name Well Status Incl(°) MD(RKB) Act Btm Ines) Alaska.Inc ,t 8v,hp,• 500292049664 KUPARUK RIVER UNIT INJ 102.65 8,59026 9,580.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date ••Well Cei,R DEVIATED-IE-06AL2-01,491201210x53:10 AM SSSV:NIPPLE Last WO: 1/28/2011 38.99 10/28/1980 Schematic•Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date —_----fLast Tag: 4/22/2011 Rev Reason.CSG CORRECTION osborl 4/9/2012 HANGER 24 - Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(t...Set Depth(TVD)...String Wt...String... String Top Thrd AL2-01 Slotted Liner 1 2 3/8 1.995 7,261.7 9,570.0 6,399.0 4.60 L-80 STL Liner Details Top Depth (TVD) Top Intl Nomi... Top(RIM) (RKB) (') Item Description Comment ID(in) 7,261.7 6,213.8 53.48 DEPLOY GS Full deployment sleeve(2.25 X 6'PBR) 1.000 CONDUCTOR, 8,325.6 6,436.4 94.09 DEPLOY Shorty deployment sleeve(ran on first liner segment) 1.000 32-80 NIPPLE,546 HE Perforations&Slots Ili Shot Top(ND) Btm(TVD) Dens GAS LIFT, E 's Top(RKB)Btm(RKB) (ftKB) (ftKB) Zone Date (oh... Type Comment 2,336 t 7,643.3 7,942.8 6,430.5 6,472.5 4/19/2011 32.0 SLOTS Alternating solid/slotted pipe- 0.125'5(2.5"@ 4 circumferential adjacent rows,3"centers staggered 18 deg,3'non-slotted ends SURFACE. � 8,125.0 8,326.4 6,453.2 6,436.3 4/19/2011 32.0 SLOTS Alternating solid/slotted pipe- 32-2,896 0.125"x2.5"@ 43 circumferential adjacent rows,3"centers staggered GAS urr. 18 deg,3'non-slotted ends 3,480 8,326.0 9,569.0 6,436.3 6,399.1 4/19/2011 32.0 SLOTS Alternating solid/slotted pipe- - 0.125"x2.5"@ 4 circumferential adjacent rows,3"centers staggered GAS LIFT 18 deg,3'non-slotted ends 4 832 Ell GAS LIFT C 91 MI WHIPSTOC, 5,71K2 WINDOW A. 5,7125,722 GAS LIFT, W. 6,2W Illr SEAL ASSY, 6.253 Il' PIK8,257 ANCHOR. I 6,270 IIIL PACKER,8272 IV Oe: I an ANCHOR. 7,056 IR •: PACKER,7,058 MI IF NIPPLE,7,070 lir_ IR ir r 1 ANCHOR, F 7,225 PACKER,7.227 1 1 NIPPLE.7,268 SHOE,7.299 I APERF, 7,517-7,537 PRODUCTION, 31-7,568 APERF, 7.574 WHIPSTOCK, Mandrel Details PIG , Depth Top Port CM?PLUG, (NO) Incl OD Valve Latch Size TRO Run 7.047 SLOTS, Stn Top(ftKB) RKB) (1 Make Model (in) Sets Type Type (m) (Poi) Run Date Com... 7.643-7.943 1 2,336.5 2,231.6 31.84 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/15/2011 LINER 5.492-7,860I 2 3,479.7 3,199.0 34.20 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/15/2011 SLOTS, 8,1255326 3 4,532.2 4,090.4 30.48 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/152011 SLOTS, 8,3265589 4 5,396.7 4,838.1 28.96 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/15/2011 AL2-01 Slotted Liner, 7,262-9,5700 5 6,199.8 5,538.0 35.58 CAMCO KGB2-9 1 GAS LIFT DMY BTM 0.000 0.0-7/16/2011 TD 9,580 AL 2 Slotted liner, I 8,525-10,260 II . STATE OF ALASKA r ALA. ,OIL AND GAS CONSERVATION COMM.-310N REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair well r Rug Perforations r Stimulate J"' Other Convert to Injector Alter Casing f Pull Tubing r Perforate New Pool r Waiver r Time Extension r Change Approved Program r Operat.Shutdown r Perforate r Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development J7 Exploratory r r 211-023-0 3.Address: 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r - 50-029-20496-64 -,C10 7.Property Designation cLease Number): 8.Well Name and Number: ADL 25651,25648 -1 E-08AL2-01 9.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 10.Present Well Condition Summary: Total Depth measured 9582 feet Plugs(measured) None true vertical 6398 feet Junk(measured) None Effective Depth measured 9570 feet Packer(measured) 6272, 7058, 7227 true vertical 6400 feet (true vertucal) 5596,6095,6193 Casing Length Size MD ND Burst Collapse CONDUCTOR 48 16 80 80 SURFACE 2864 10.75 2896 2693 PRODUCTION 5680 7 5712 5121 LINER A 2369 5.5 7860 6571 AL2-01 SLOTTEC 2308 2.375 9570 6400 ��� RECEIVED Perforation depth: Measured depth: slots 7643'-9569' 1E� 3 2" True Vertical Depth: 6431'-6399' Goc+i$�10n pS ka oil&Gas Gans. • polouge Tubing(size,grade, MD,and TVD) 3.5, L-80, 7299 MD,6236 TVD Packers&SSSV(type,MD,and TVD) PACKER-3-1/2"X 5-1/2"BAKER FAB PACKER 45-FA-36 @ 6272 MD and 5596 TVD PACKER-3-1/2"X 5-1/2"BAKER FAB PACKER 45-FA-36 @ 7058 MD and 6095 TVD • PACKER-BAKER FAB PACKER 45-FA-36 @ 7227 MD and 6193 TVD NIPPLE-CAMCO NIPPLE @ 546 MD and 546 TVD 11.Stimulation or cement squeeze summary: Intervals treated(measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 183 210 300 1150 179 Subsequent to operation 2261 550 817 13.Attachments 14.Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service `Jr Stratigraphic r 15.Well Status after work: Oil r Gas T VVDSPL r Daily Report of Well Operations XXX A. GSTOR r VVINJ r WAG r GINJ 1 SUSP r SPLUG E 1e. 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: 311-300 Contact Christensen/ Humphrey Printed Name Robert D. Christensen Title Prod Eng Specialist • Signature / Phone:659-7535 Date I/ Form 10-404 Revised 10/2010OMS DEC 1 3 2011CAdg )' Submit Original Only 1 E-08AL2-01 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 07/13/11 MEASURED BHP @ 7100' RKB: 2387 PSI. IN PROGRESS. 07/14/11 BRUSHED & FLUSHED TBG TO 7261' RKB. SET 2.813"XX PLUG @ 7070' RKB. SET CATCHER @ 7070' RKB. IN PROGRESS. 07/15/11 PULLED GLVs @ 2231', 3479', 4532', 5396', 6199' RKB. SET DVs @ 2231', 3479', 4532', 5396' RKB. LOADED WELL WITH INHIB SW& DSL CAP. IN PROGRESS. 07/16/11 SET DV @ 6199' RKB. MITIA 2500 PSI, PASSED. PULLED CATCHER &2.813"XX PLUG @ 7070' RKB. COMPLETE. 07/20/11 Commenced Water Injection KUP 1 E-08AL2-01 i GQI'1000PI1illi ell Attributes Max Angle&MD TD A . k, Wellbore APINWI Field Name Well Status Inel C) MD(MB) Act Btrn(MB) ln„�„t,,, 500292049664 KUPARUK RIVER UNIT PROD 102.65 8,590.26 9,580.0 Comment r(ppm) DsDateAnnotation End Data KB-Ord(R) Rig Release Date ..W Cones:DEVIATED-tE-06Al2-01.7117/20119 os:12 AM SSSV:NIPPLE Last WO: 1/28/2011 38.99 10/28/1980 Schmatc•Actual Annotation Depd1(RKB) End Date Annotation Last Mod...End Date Last Tag: 4/22/2011 Rev Reason:GLV CIO ninam 7/17/2011 Casing Strings HANGER,21 1=ral Casing Description String 0... String ID...Top(f AB) Set Depth(f...Set Depth(TVD)... String WL..String.. String Top Thrd AL2-01 Slotted Liner 2 3/8 1.995 7,261.7 9,570.0 6,399.0 4.60 L-80 STL Liner Details ' Top Depth / (TVD) Top Incl Nook_Top(NIB) (RKB) (°) !ternDescription Comment ID(in) 7,261.7 6,213.8 53.48 DEPLOY GS Full deployment sleeve(2.25 X 6'PBR) 1.995 MI 8,325.6 6,436.4 94.09 DEPLOY Shorty deployment sleeve(ran on first liner segment) 1.000 CONDUCTOR, iir 32-80 Perforations&Slots NIPPLE.Safi Ill Shot IMI Top(TVD) Btm(TVD) Dena Top(RK B) Btu(RKB) (RKB) (556) Zone Dab leh-. Type Comment GASZ1336 f 7,643 7,943 6,430.5 6,472.5 4/19/2011 32.0 SLOTS Alternating solid/slotted pipe- ] r 0.125'x2.5"@ 4 circumferential adjacent rows,3"centers staggered I 18 deg,3'non-slotted ends SURFACE ,J - 8,125 8,326 6,453.2 6,436.3 4/19/2011 32.0 SLOTS Altemating solid/slottedpipe- 32-2,896 0.125'x2.5"@ 4 circumferential ii adjacent rows,3"centers staggered GAS LIFT. _J 18 deg,3'non-slotted ends 3,480 8,326 9,569 6,436.3 6,399.1 4/19/2011 32.0 SLOTS Alternating solid/slotted pipe- 0.125"x2.5"@ 4 circumferential adjacent rows,3"centers staggered 18 deg,3'non-slotted ends GAS LIFT. ) 4,532 e I= GAS LIFT,__ r 5,397 Y WHIPSTOCK, 5,712 WINDOW A. 5,712-5,722 GAS LIFT, 6,200 SEAL ASSY, 6.253 1 PBR.H2O ANCHOR. R. 8,2 0tM j PACKER,6,272 8,270L MI IB ANCHOR, 7,056 lir PACKER,7,058 —_ B 1t NIPPLE,7,070 U a U I ANCHOR, ]225 IS_ PACKER.7.227 •` IE NIPPLE,7,288 ' SHOE,7.299 !■ APERF. 7517-7,537IL PRODUCTION, 31-7,568 APERF, WHIPSTOC�4757tK, I Mandrel Details 7,583 Top Depth Top Port CMT PLUG. (TVD) Incl OD Valve Latch Size TRO Run SLOTS, Stn Top(MB) (1158) C) Make Model (in) Sery Type Type (in) (pet) Run Oct. Com... 7,643-7943 1 2,336.5 2,231.6 31.84 CAMCO KBMG 1 GAS LIFT'DMY BK 0.000 0.0 7/15/2011 LINER A 6,492.7.860 ` 2 3,479.7 3,199.0 34.20 CAMCO KBMG 1'GAS LIFT DMY BK 0.000 0.0 7/15/2011 SLOTS. I 8.125-8,3261 3 4,532.2 4,090.4 30.48 CAMCO KBMG 1'GAS LIFT DMY BK 0.000 0.0 7/15/2011 SLOTS, \ 8.326-9.569111 4 5,396.7 4,838.1 28.96 CAMCO KBMG 1 GAS LIFT DMY BK 0.000 0.0 7/15/2011 AL2-01 Sbtad Liner, 5 6,199.8 5,538.0 35.58 CAMCO KGB2-9 1 GAS LIFT DMY BTM 0.000 0.0 7/16/2011 7,262-9,570 TD (1E 06AL2-01), 9.588 AL 2 Slotted liner, 8,52510,260 11 y , ALAsE A SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Robert D. Christensen Production Engineering Specialist ConocoPhillips Alaska, Inc. 1 Q �-- P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1E-08AL2-01 Sundry Number: 311-300 Dear Mr. Christensen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ZL Daniel T. Seamount, Jr. Chair DATED this day of October, 2011. Encl. It ' STATE OF ALASKA 1/1' RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION `13,, APPLICATION FOR SUNDRY APPROVALS SEP 29 2011 20 AAC 25.280 1.Type of Request Abandon r Rug for Redrill r Perforate New Pool r Repair w ell rp1� rgrEHssion Suspend r Plug Perforations r Perforate r Rill Tubing r bbl Illaiktin r Operational Shutdown Re-enter Sus Well P r P• r Stimulate r Ager casing r Other:Oil to WAG conversion pl 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r . Exploratory r 211-023-0 • 3.Address: Stratigraphic r Service r 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-029-20496-64 • 7.If perforating,closest approach in pool(s)opened by this operation to nearest property line 8.Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes IT No IT 1E-08AL2-01 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25651:25648 ' Kuparuk River Field/Kuparuk River Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 9582 • 6398 • 9570' • 6400' - Casing Length Size MD TVD Burst 1 Collapse CONDUCTOR 96 16 80' 80' SURFACE 2864 13 2896' 2705' PRODUCTION 15106 7 7568' 6395' • LINER A 2080 5-1/2" 7572' 6571' AL2-01 SLOTTED LINER 2308 2.625 9570' 6400' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Slots:7643'-7943';8125'-8326';8326'-9569' 6431'-6473';6453'-6436';6436-6399' 3.5 L-80 7296 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) NIPPLE MD=546 TVD=546 PACKER-3-1/2"X 5-1/2"BAKER FAB PACKER 45-FA-36 MD=6272 TVD=5596 PACKER-3-1/2"X 5-1/2"BAKER FAB PACKER 45-FA-36 MD=7058 TVD=6095 PACKER-BAKER FAB PACKER 45-FA-36 MD=7227 TVD=6193 12.Attachments: Description Summary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory IT Development r Service r • 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 9/28/2011 Oil r Gas r WDSPL r Suspended IT 16.Verbal Approval: Date: WINJ . GINJ r WAG F . Abandoned r Commission Representative: 74- ¶•24.er GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Christensen/Humphrey Printed Name Robert D.Christensen 1 Title: Prod Eng Specialist Signature / G 4 Phone:659-7535 Date r.-1-9// / Commission Use Only Sundry Number:3 I ` get Conditions of approval: Notify Commission so that a representative may witness // Plug Integrity r BOP Test r Mechanical Integrity Test /Location Clearance r * M I 1-T" rt$�t.r-� before eon-,•„�-, - C. I►,�e�. soh. Other: 74- W yi I . n raa J 64 A l YY a� S¢r"viC_G D.eYt��h' �.C,y►in i s f'i`at f'tP P J Subsequent Form Required: /o`yo,I APPROVED BY /a / 1,I /r)le-------9 Approved by: COMMISSIONER THE COMMISSION Date: L !/ 7 I Form 10-403 Revise OCT 0 9 G Submit in Duplicate �. .I ttrt'r V �� 'A . ALJ,;. 1 E-08AL2-01 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to begin WAG EOR injection service in Kuparuk well 1 E-08AL2- 01 post sidetrack pre-production. Well 1 E-08AL2-01 will provide water and and MI support for Kuparuk A sands to improve sweep efficiency and increase A-sand oil recovery in the 1 E-08AL2-01 pattern. The 10-3/4"Surface casing (2896' and/2705'tvd)was cemented with 1350 sx Fondu and 250 sx AS. The 7" Production casing ( 7568' and/6395'tvd)was cemented with 530 sx Class'G'and 200 sx ASII. The 5-1/2" Liner(5492' and/4922'tvd)was cemented with 247 sx Class"G". The top of Kuparuk A4 sand was found at 8560' and/6421'tvd. The Cement Bond Log (01/24/11) performed indicated marginal cement bond below the top of the C sand. The 5-1/2" Liner was perforated and cement squeezed with 88 sx Class'G'. (7517'-7537', 7564'-7574', 7645'- 7655' 645-7655' and/6364'-6376', 6392'-6398', 6441'-6447'tvd) The Cement Bond Log (03/09/11) performed indicates uniform cement bond from the tubing tail located @ 6224'tvd (7279' md)to 6432'tvd (7630' md). The A sand Sidetrack Window(AL2)top is located @ 7563' and/6391 tvd. The A sand Sidetrack Window(AL1)top is located @ 7643 and/6444'tvd. The injection tubing/casing annulus is isolated via a Baker FAB Packer located @ 6272' and/5596'tvd. A MIT-IA was performed to 2600 psi on 08/09/11. Subsequently, a State Witnessed MIT-IA passed on 08/30/11. �o (�5���Py re�,'Pw c�cPy�ur,, ill mitis cc?rif/e eJ cis c� to-Ifs iv Ce/ /i,neV..� Refer to the main well file, 1 E-08A(210-181), for information regarding this matter. 211-019 1 E-08AL 1 211-020 1 E-08AL 1-01 211-021 1 E-08AL 1-02 211-022 1 E-08AL2 211-023 1E-08AL2-01 211-044 1 E-08AL1-03 From: Maunder, Thomas E (DOA) Sent: Monday, September 19, 2011 12:36 PM To: 'NSK Problem Well Supv'; 'NSK Well Integrity Proj'; 'Alvord, Chip'; Cawvey, Von; 'Gantt, Lamar L' Cc: Schwartz, Guy L (DOA); Foerster, Catherine P (DOA); Ballantine, Tab A (LAW) Subject: RE: 1E-08A (PTD 210-181) Request to WAG to MI in prep for AA submission 09-17-11 Importance: High All, I received this request and in the course of reviewing the file have determined the following. 1. A 407 was filed 2/4/11 documenting the work accomplished with Doyon 141 to set up the well for a coil drilling work. 2. The status was listed as "oil" however this was changed to "suspended"which is correct since additional work was needed before the well would be capable of producing or injecting. 3. WL/WL work was begun 2/9/11 with CT operations following to drill the 6 laterals/spokes in March and April 2011. The CT work was completed about April 20 and the 407s for those penetrations were filed with the status of 1-oil. 3. A 404 was filed by the Production Engineer Specialist on May 4 changing the well status of 1E-08A from suspended to 1-oil. 4. Our production record shows the well complex produced 28 days in May and 25 days in June. It further shows the well complex has injected water for 12 days in July. August information has not yet been posted. Regulations require that an operator obtain approval from the Commission to convert a well from development to service prior to initiating injection. The Commission has no record of any Form 403 being filed to convert any of the penetrations to service. Any injection that has occurred is not authorized. Commissioner Foerster has been apprised of this matter and she has directed that the following be communicated to you: Pending resolution of this matter, CPAI is directed to cease injection into 1E-08A and secure the well appropriately. At your earliest convenience, prior to September 23, you should contact me or Guy Schwartz to arrange a meeting to discuss this matter. The Commission reserves the right to pursue an enforcement action in this matter. Please keep Guy and me apprised of CPAI's work accomplished to comply with the Commissioner's directive. Tom Maunder, PE AOGCC From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Saturday, September 17, 2011 12:44 PM To: Maunder, Thomas E (DOA) Subject: 1E-08A (PTD 210-181) Request to WAG to MI in prep for AA submission 09-17-11 Tom, ConocoPhillips requests permission to WAG 1E-08A(PTD 210-181)to MI in order to run diagnostics before applying for an AA. This well has a high packer and we need to confirm that no out-of-zone injection takes place while on gas. Instead of first applying for a water-only AA and then needing to amend after we get gas tests, I thought it would be expedient to conduct the MI tests first before requesting an AA. A passing, witnessed MITIA was performed on 8-30- 11. I'm not sure if you were sent the CBL data, so I've attached another copy to help base your decision. We still plan to run the same diagnostic program as was done on 1A-04A: 1. getting a baseline RST while on water, 2. putting the well on MI and getting an IPROF, 3. wagging back to water and getting a follow-up RST to look for residual gas. Thanks Brent Rogers/ Kelly Lyons Problem Wells Supervisor ConocoPhillips Alaska, Inc Desk Phone (907)659-7224 Pager(907) 659-7000 pgr 909 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 1b.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑✓ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service ❑ StratigraphicTest❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillipsAlaska, Inc. orAband.: April 20,2011 211-023/ 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 April 13,2011 50-029-20496-64 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 1013'FSL,629'FEL,Sec. 16,T11 N, R10E, UM April 18,2011 1 E-08AL2-01 Top of Productive Horizon: 8. KB(ft above MSL): 28'RKB 15.Field/Pool(s): 401'FNL, 1953'FEL,Sec. 16,T11 N, R10E, UM GL(ft above MSL): 98.6'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 8'FSL,2196'FEL,Sec. 9,T11 N, R10E, UM 9570'MD/6400'TVD Kuparuk River Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-549890 y- 5960600 Zone-4 9582'MD/6398'TVD ADL 25651,25648 TPI: x-548532 y- 5964457 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-548286 y- 5964856 Zone-4 nipple @ 546'MD/546'TVD 469,466 18.Directional Survey: Yes ❑✓ No❑ 19.Water Depth,if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1650'MD/1650'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 8528'MD/6424'TVD 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 65# H-40 Surf. 80' Surf. 80' 24" 200 sx Permafrost 10.75" 45.5# K-55 Surf. 2896' Surf. 2693' 13.75" 1350 sx Fondu,250 sx AS 7" 26.0# K-55 Surf. 5712' Surf. 5121' 8.75" 530 sx Class G,200 sx ASII 5.5" 15.5# L-80 5491' 7860' 4921' 6571' 7" 247 sx Class G 2.375" 4.7# L-80 7261' 9570' ) 6214' 6400' 3" slotted liner / Iia kwbi$} j-.,:r 24.Open to production or injection? Yes 0 No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 3.5" 7296' 6272'MD/5596'TVD,7058'MD/6095'TVD, 7227'MD/ 6193'TVD slotted liner from 7643'-9569'MD 6431'-6399'TVD 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 'i' DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED r j. fil 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) May 5,2011 pre-produced injector Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 5/5/2011 7.1 hours Test Period--> 231 387 402 176% 1677 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 191 psi 24-Hour Rate-> 776 1301 1350 not available 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No ❑ Sidewall Cores Acquired? Yes ❑ No ❑ If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. RECEIVE ' NONE MAY 2 0 201 RBDMS MAY 2 0 2011 I,/1 _ Alaska Til&GPs Cart{.Carolina/DN.$ Form 10-407 Revised 12/2009 CONTINUED ON REVERSE fncllratgS Submit original only 6..7.(f 28. GEOLOGIC MARKERS(List all formations and markers e. .tered): 29. FORMATION TESTS NAME MD TVD Well tested? II 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 1650' 1635' needed,and submit detailed test information per 20 AAC 25.071. Top A4 8560' 6421' Top A5 9071' 6399' Top A5 9104' 6400' N/A Formation at total depth: Kuparuk A5 30. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final definitive survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jill Long @ 263-4093 0 511" Printed Nam J. L Ca a Title: Alaska Wells Manager Signature (ll Ck(Yli,LNA. Phone 265-6306 Date 05/49/// Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection,water injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13:The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 26: Method of Operation: Flowing,Gas Lift, Rod Pump, Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation,and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Ni wq I \a / � \ 11 // § & \ ) \ ( Fle 11 : 22 it P li 11 ; { ; ;f ; /f ) . \ } # § § [ j CZ { .1 \ } { / e 5/ 2 ' _ 1 ; .l , , !, j11 § ƒ NI ;.,x Rh \ \ \ ! / 2 / 0 \ E PI g Di Di 0 — & . '« } i \1M j ƒi ~\ :��k ��:� 3 1 ; Ciiil\s‘ } \ ` ) )! ! . Te / 1 \ . . ;! 22 :- ` !/ ` &| } 11 II' D 0`§!§§§E ] \\ \ \ II, ItiM E!! gib)- ( OHM . \ \ 11 !9 9§■$ 11 ] R i { . \ ( ; rR/_° PI k |/\ l rii ) 1 \ 222 ; 1!.!!! |,! A/� t 1 �d�7 KUP 1E-08AL2-01 ConocoPhillips Weli 4tt�Iwtes _ Max Angle,$MD TD Asa,k1](t1C µ,v!' ,,,,i',4.4Wellbore APUUWI Field Name Well Status Incl(°) MD(ftKB) Ad Etc(fiKB) conocN9vlhcr A9° 500292049664 KUPARUK RIVER UNIT I PROD 102651 8,590.26 9.580.0 Comment IH2S(ppm) (Date Annotation ;End Date KB Grd(ft) I Rig Release Date ..,__WeA..42rt ee,009 P]'EP 18 -0t,41262pt1$SD 51RM_ SSSV 11 NIPPLE Last WO- 1/28/2011 38.99 10/28/1980 $chedsus Aa.at 'Annotation Depth(HKB) End Date Annotation L t Mod.. End Date Last Tag- - 14/22/2011_ Rev Reason:GLV C/O _. l ninam 14/26/2011 „f.-.-•- Casing Strings rwNG..K.is let Casing Description String 0... ;String ID... p(ftKB) Set Depth(f...Set Depth(TVD; .String WI..;String String Top Thrd AL2-01 Slotted L,nen 2 3/8 1.995 I To7,261.7 I 9,570.0 I 6,399.0. I 4.60 1 L-80 I STL Liner Details_ Top DepthIII P (MD) Top Incl Nodi... T• (6KB) (U B) (°) Rem Description Comrum ID(in) -- - 7,261-7 6,213.8 53.48 DEPLOY GS Full deployment sleeve(2.25 X 6 PBR) 1.995 >ln', 8,325.6 6,436.4 94.09 DEPLOY Shorty deployment sleeve(ran on first liner segment) 1.000 CONDUCTOR, 32'80 Perforations&Slots — NIPPLE.546__- :(�. _ Shot Top(TVD) Bun(TVD) Dens INF Top(ftKB)Btm(ftKB) (MKB) (6KB) Zone Date (eh... Type Comment GAS LIFT' 7,643 7,943 6,430.5 6,472.5 4/19/2011 32.0 SLOTS Alternating solid/slotted pipe PPS- 0.125"x2.5"@ 4 circumferential adjacent rows,3"centers staggered 18 deg,3'non-slotted ends SURFACE,_ JW 8,125 8,326 6,453.2 6,436.3 4/19/2011 32.0 SLOTS Alternating solid/slotted pipe- 32.2.806 0.125"x2.5"@ 4 circumferential adjacent rows,3"centers staggered GAS LIFT, 18 deg,3'non-slotted ends 3,480 8,326 9,569 6,436.3 6,399.1 4/19/2011 32.0 SLOTS Alternating solid/slotted pipe- 0.125"x2.5"@ 4 circumferential H. adjacent rows,3"centers staggered 18 deg,3'non-slotted ends ilii.:' I GAS LIFT. .532___. 4 . GAS LIFT, 5.397 eV 117 WHIPSTOCK.___. __.. 5,712 WINDOW A. 5.712-5,722 :. GAS LIFT, 6,2(10 SEAL ASSY, flii:I. 6,253 PER,6,257 ANCHOR. _ jj 6,270 - il'il PACKER.6,272 MK '',': ANCHOR. 7,056jilt, PACKER,7,058— _ NIPPLE,7,070 JE itz ak t ANCHOR, Mk 7,225 - PACKER,7,227 : :.. NIPPLE,7,266 SHOE,7.289 I'.-: APERF, 7,517-7,537 PRODUCTION, 31-7,566 APERF,_ --. _— --- _— — 7.564-7.574 Mandrel Details . oa WHIPSTOCK, - ..._. .+`d.�s ..�., 7,563 Top Depth Top Port CUT PLUG, (TVD) Incl OD Valve Latch Sir. TRO Run SLOTS,7.047 Stn Top(WWI (RKB) C) Make Model (in) Sery Type Type DO (PA Run Data Cam... 7643-7,943 1 2,336.5 2,231.6 31.84 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,370.0 4/25/2011 LINER A, 5,492-7.8602 3,4797 3,199.0 34.20 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,342.0 4/252011 SLOTS, 6,125-8,326 - 3 4,532.2 4,090.4 30.48 CAMCO KBMG 1 GAS LIFT GLV BK 0.156 1,317.0 4/25/2011 II SLOTS, ,--- -... ._. 8,326-9,569 4 5,396.7 4,838.1 28.96 CAMCO KBMG 1 GAS LIFT GLV BK 0.188 1,332.04/242011 AL2-01 Slotted — Liner, 5 6,199.8 5,538.0 35.58 CAMCO KGB2-9 1 GAS LIFT OV Bko-3 0.250 0.0 4/24/2011 7,262-9,570 - TD (1E-08AL2-01), 1_I 9,580 Ii AL 2 Slatted IA l' ---9_.._.d.:. 8,525-10,260 Y I I a SA 111 i tittaW ma stz in V a O 0. co w ce 0 1 Q F-- >, ao' swim a co _ {= = L) a) Warn = ♦ �— • o O YY -I � 4) i i ■- = 0 Y Y 111CO 0 N 0) til ZGO Il _,o o Y a I. figi VI Iii w - o t m LO o c 0- Q= C I� c 0 >.:: O +- d M d O O O M l)- n- D O N N N 6O (n 'a N V co p ZD ` .a co c co ,- ,- N I r v a) ll - v v 0LL u) EL O c 0 O co N m Ill O CV O N i5 =CO _ N N N M > y co ` - . a) a) J Nr N O O O O N N- w CO0 O N + + J J U C) ON) ON) C C . o�O N N 0. 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O 40 O (O (O +� U Y Y W w 7 C coi c0 co cOo rn 0) Q 0 ko M (V 00 M 0) OD M CO 0 0 0 N N N.O O Qj vlo+/ C .. d 0 0 co (co 0) 00 0) N- iQr0 m V — 0 C A E= O_ O. O_ O Ln u) La `� a) , Q N rn rn m ai m m rn O N O• Oi N a) a) 7 v\-- ✓ d N U) R 1E-08 Well Work Summary DATE SUMMARY 2/9/11 PULL BPV, DRIFT TBG TO 2.78", L,OULD NOT GET PAST 6985' SLM, RAN Bi.uSH AND 2.1" G RING TO TAG @ 7712' SLM. IN PROGRESS. 2/10/11 SET CATCHER @ 6232' SLM, REPLACE SOV @ 6199' RKB W/DMY VLV, PULL CATCHER, DRIFT TO 2.77"TO 7655' SLM, PERMORM PASSING 2500 PSI MIT-IA. IN PROGRESS. 2/11/11 RUN DUMMY WHIPSTOCK TO 7670' SLM. NO OBSTRUCTIONS. READY FOR E-LINE. 2/12/11 ATTEMPT TO PERFORM GR/CCL CORRELATION LOG AND PERFORATE. DELAYED START, HAD 0- RING FAILURE DURING PT. LAYDOWN TOOLS FOR NIGHT, RESTART IN AM. 2/17/11 LOGGED GR-CCL FROM CEMENT RETAINER TO 6000' ELM. CEMENT RETAINER TAGGED AT 7698' ELM. PERFORATED 3 INTERVALS, 7645'-7655', 7564'-7574', AND 7517'-7537' USING 2.5" HSD 2506 PF HMX, 6 SPF, 60 DEG PHASING. SET 3.5"X 5.5" BAKER THRU TUBING WHIPSTOCK AT 18.9 DEG RHS. TOWS AT 7645', BOWS AT 7658'. 2 RA TAGS INSTALLED IN WHIPSTOCK. RA TAGS 7.35' FROM TOWS AT 7652.35' ELM. RDMO, RU LRS FOR INJECTIVITY TEST. PUMPED DIESEL: 0.5 BPM AT 1600 PSI, 1 BPM AT 2150 PSI, AND 1.5 BPM AT 2600 PSI. PUMP REPORT IN ATTACHMENTS. 2/19/11 RESTART TOMORROW DUE TO PROBLEMS GETTING RIGGED UP AND PRESSURE TESTED, 2/20/11 PUMPED 15BBLS NEAT CEMENT(15.8PPG), LAYED IN FROM 7640FT CTMD TO 6750FT CTMD, PERFORMED 8 HESITATION SQUEEZES, PUSHED 5.5 BBLS INTO PERFS, DROPPED BALL, RIH, TAGGED CEMENT AT 7171T CTMD, UNABLE TO WASH PAST 7171 FT CTMD, WASHED TUBING THROUGHLY, FP WELL, BACK TOMORROW TO MILL TOP OF CEMENT TO TUBING TAIL, IN PROGRESS 2/21/11 MILL CEMENT FROM HRD TAG @ 6900 CTMD TO 7047 CTMD W/2.69 BI CENTER BIT, TERMINATE JOB DUE TO PHASE II CONDITIONS, FP WELL , IN PROGRESS 2/22/11 TAGGED UP @ 4516' CTMD W/2.80" PARABOLIC DIAMOND SPEED MILL. PUMP AT MIN. RATE& GOT BY EASY. ROTATE MILL WHILE RIH, HARD STALL @ 6999' CTMD. MAKE IT TO TO 7008' CTMD, PROGRESS SLOW W/ALOT OVER PULLS. FREEZE PROTECT THE WELL, RACK BACK FOR THE NIGHT, JOB IN PROGRESS. 2/23/11 MILLING JOB SUSPENDED. PERFORM WEEKLY BOPE TEST. RIG OFF THE WELL BUT UNABLE TO LAY DOWN MAST DUE TO HIGH WINDS. 3/1/11 PRE CTD PT SV, MV(PASSED) DDT SV, MV, SSV(PASSED) TREE TEST. 4/23/11 GAUGED TBG TO 2.62"TO TOP OF LINER @ 7262' SLM. MEASURED BHP @ 7100' RKB: 2963 PSI (DECLINING). IN PROGRESS. 4/24/11 SET CATCHER @ 7257'SLM. PULLED DVs @ 6199', 5396', 4532' RKB. SET OV @ 6199', GLV @ 5396' RKB. IN PROGRESS. 4/25/11 PULLED DVs @ 3479', 2336' RKB. SET GLVs @ 4532', 3479', 2336' RKB. CONFIRMED VALVES SET. PULLED EMPTY CATCHER @ 7257' SLM. COMPLETE. .. . .. ___. ... ....... .. .... . .. ... . Conoco Phillips Time Log & Summary WelMew Web Reporting Report Well Name: 1E-08 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 3/4/2011 3:00:00 AM Rig Release: 4/21/2011 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03/03/2011 24 hr Summary Exempt rig move from 3A pad to 1 E pad. 00:00 08:00 8.00 MIRU MOVE MOB P Hook up trucks, pull off well&stage equipment for jeep&road trasit. 08:00 16:00 8.00 MIRU MOVE MOB P Transit from 3A to 1E pad 16:00 00:00 8.00 MIRU MOVE RURD P Spot equipment over well&rig up BOP,flow iron&putz.Start taking on KWF. 03/04/2011 Complete rig up. Initial BOPE test Waived by Bob Noble. Pump slack&cut pipe. 00:00 03:00 3.00 MIRU MOVE RURD P Continue rigging up MPD line, remove scaffolding from cellar and lay down secondary containment in cellar.Start working on Injector. 03:00 09:00 6.00 0 0 MIRU WHDBO CTOP T ***Rig accept"`Continue working on injector repairs. 09:00 11:00 2.00 0 0 MIRU WHDBO CTOP P Rig up cable through injector, install grapple Pull coil through injector 11:00 12:00 1.00 0 0 MIRU WHDBO CTOP P Install new packoffs, remove grapple from coil 12:00 15:00 3.00 0 0 MIRU WHDBO CTOP P Crew change, PJSM prep for BOPE Test, Clean up rig 15:00 21:00 6.00 0 0 MIRU WHDBO BOPE P Start full BOPE Test Witness waived by Bob Noble AOGCC. 1 failure on Bravo 4. Hydraulic leak during draw down.Start replacing. 21:00 23:00 2.00 0 0 MIRU WHDBO CTOP P Start filling reel&pump slack back into CT string.Test inner reel valve. Passed. 23:00 00:00 1.00 0 0 MIRU WHDBO SFTY PHold pre spud meetingwith crew that arrived today. 03/05/2011 Complete BOPE test, replace Bravo 4&re-test.Slack management cut 250 of CT(31 ft to find cable). Pull BPV&RIH with 3.5"Hailey Under reamer. Ream from 7020'to 7316'.Trip for a 5.5"BHA 00:00 04:00 4.00 0 0 MIRU WHDBO CTOP P Cut 31ft to find cable then cut a total 250'of CT&install Coil Connector. Completed repairs to hydraulic valve on B-4&re-test. 04:00 06:00 2.00 0 0 MIRU WHDBO PRTS P test tiger tank line and rig up FMC lubricator. Found the soft line to the tiger tank is froze. PJSM to break it off and thaw it out. 06:00 07:30 1.50 0 0 MIRU WHDBO PRTS P Crew Change/Check lines and valves Install BHI Encoder.Skid injector out of way Page 1 of 39 Time Logs Date From To Dur S. Death'E.Depth Phase Code Subcode T . Comment 07:30 09:30 2.00 0 0 MIRU WHDBO BOPE P Pull BPV, R/D Lubricator 09:30 12:00 2.50 0 0 MIRU WHDBO PRTS P P/U QTS and PDL, PT to 4K PT Coil connector&UQC 4K M/U Nozzle and stab on well, Open well Blled down&Flo Chk 12:00 13:06 1.10 0 0 SURPRI WELLPF MILL P P/U BHA#1 Straight Motor,Haily Under reamer to mill 3.5 tubing. Surface test coiltrack, Open EDC 13:06 15:18 2.20 0 6,814 SURPRI WELLPF MILL P RIH to Mill/Under Ream cement 15:18 15:24, 0.10 6,814 7,027 SURPRI WELLPF MILL P Stop Coil, Shut EDC, PUW=32K 15:24 17:54', 2.50 7,027 7,200 SURPRI WELLPF MILL P Initial set down then go through down to 7058'5 dry PUH to 7020 and kick on pumps PUW=34K Start underreaming.Tie in-19.5' correction. 17:54 18:54 1.00 7,200 7,250 SURPRI WELLPF MILL P 1.40 bpm,4200 psi, BHP 3300psi, rate out 1.30 bpm,WOB.5K, ROP 1.5-2.0FPM. IA17/OAO 18:54 19:39 0.75 7,250 7,231 SURPRI WELLPF MILL P Stall @ 7250'. P/U weight 37K.WOB during stall jumped from.4K to 2.3K. RIH stall in same spot. P/U& RIH slowly watching for weight loss& motor work noticed @ 7231'.Mix up a high visc sweeps. Had to work through tight spot @ 10 fph.7231-7240'-(X-nipple) 19:39 20:39 1.00 7,250 7,305 SURPRI WELLPF MILL P Underreaming-1.40 bpm,4100, BHP 3326,WOB.6K,Ct weight 15K, ROP 100 fph with good motor work. Nice cement returns over shakers, no metal detected in sample. 20:39 22:24 1.75 7,316 7,310 SURPRI WELLPF MILL P Reach 3.5'TD-backream up to TOC. RIH-open ECD-Tie in @ 7150'Correction+11ft.The first tie in was incorrect due to BHA lenght not correct in MWD file.Total depth reamed to 7316' 22:24 00:00 1.60 7,310 SURPRI WELLPF MILL P POOH with EDC Open chasing out sweep. 03/06/2011 Try Under reaming in 5.5"casing with weatherford 4.875"U/R BHA.Could not get started, P/U Hailey 5.5" U/R&started reaming cement @ 7310'. Higher vibrations on BHA.Tie in-zero corrections. 00:00 00:30 0.50 1,500 77 SURPRI WELLPF MILL P POOH pumping through EDC. 00:30 01:00 0.50 77 77 SURPRI WELLPF SFTY P Flo-check. PJSM for laying down BHA. 01:00 02:30 1.50 0 75 SURPRI WELLPF MILL P Bit-2.73"go,2.72"no. Under-reamer-out 2.91"All blades &cutters intact. P/U weatherford under-reamer with 4.875"blades. 02:30 05:30 3.00 75 7,315 SURPRI WELLPF MILL P RIH with EDC open.Tie in correction -8.5 ft.Close EDC and bring pumps online @ 7300' Page 2 of 39 Time Logs Date From -To Dur S.Depth E.Depth Phase Code Subcode T Comment 05:30 07:00 1.50 7,297 7,303 SURPRI WELLPF MILL P Open blades-had 4 stalls initally. P/U to 7297'&start reaming down slowly. 1.40 bpm,3800 psi, BHP 3360, WOB.2K,CT weight 16K, ROP 20 fph. 07:00 09:30 2.50 7,303 7,303 SURPRI WELLPF MILL P Keep working Under reamer, multiple pump rates continue stalling. Ultra light WOB. Unable to get started 09:30 12:12 2.70 7,303 73 SURPRI WELLPF MILL T POOH to inspect tool/swap reamers 12:12 12:48 0.60 73 77 SURPRI WELLPF MILL T At surface, PJSM, Flow Check, Pull BHA#2 Weatherford Under Reamer with all blades. P/U Haily under reamer with 4.757"blades. 12:48 14:00 1.20 77 77 SURPRI WELLPF CTOP T Complet injector service/Inspection, M/U injector to coil track and surface test. 14:00 16:15 2.25 77 77 SURPRI WELLPF MILL T Trip in well BHA#3 Straight motor with Haily underreamer to ream cement down to whipstock 16:15 16:30 0.25 77 7,165 SURPRI WELLPF MILL T Log tie in for a-9'correction Close EDC, PUW=36.5k 16:30 17:15 0.75 7,165 7,308 SURPRI WELLPF MILL P Dry Tag @ 7308, PUH Bring on pumps 1.36 BPM @ 4000 PSI FS, • BHP=3360 PSI 17:15 18:00 0.75 7,308 7,317 SURPRI WELLPF MILL P Stall 7314,7315,7317 with high _ down hole vibration. 18:00 20:00 2.00 7,317 7,400 SURPRI WELLPF MILL P Good under-reaming-smooth transition area. 1.40 bpm,3900psi, BHP 3380,WOB.5K, ROP 50 fph, CT weight 16K. Stall @ 7400'-P/U weight 38K 20:00 21:30 1.50 7,400 7,428 SURPRI WELLPF MILL P harder reaming from 7400'-higher vibrations on the tool&slop ROP 10 -20 fph. Good cement returns over shaker. Decreased pump rate to 1.30 bpm to lesson vibrations. Ream down to 7428'Slow going. Pump 10 bl sweep. Light cement returns over shaker. 21:30 22:30 1.00 7,428 7,428 SURPRI WELLPF MILL P Back ream to clean up area,shut down pumps @ 7310'&log upper jewelry.Zero correction. Log CCL from 7000 ft. 22:30 00:00 1.50 7,428 7,450 SURPRI WELLPF MILL P Start reaming-less vibration on bottom-1.35 bpm, 3800psi, BHP 3440, ROP 20-30 fph,WOB.6K.Ct weight 16K. 03/07/2011 Ream down to 7643'using the Hailey U/R. P/U Weatherford U/R for final pass down to 7643'. Slow Reaming through perf zones due to stalls&WOB. Page 3 of 39 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 00:00 02:00 2.00 7,450 7,485 SURPRI WELLPF MILL P Continue U/R-higher virbations on BHA starting at 7445'.Continue ROP of 20-30 fph. Getting more stalls from 7465-7480'.Circ pressure starting to increase slightly on bottom from 3900 to 4120 psi @ 1.30 bpm. 02:00 03:00 1.00 7,485 7,485 SURPRI WELLPF MILL P Pump hi-visc sweep to help with vibrations or cleaning during back-reaming. Check mud properties . Order out new SW. 03:00 06:00 3.00 7,485 7,530 SURPRI WELLPF MILL P Reaming-1.25 bpm,4250 psi, BHP 3660, ROP 20 fph,WOB.5K,Ct weight 16K. Both circ&annular pressure higher 200 psi. Possible sweep up the backside.Vibrations initally lowered but increase after 40 ft milled. 06:00 07:00 1.00 7,530 7,555 SURPRI WELLPF MILL P New batch of Bio/SW being pumped. 07:00 10:15 3.25 7,555 7,635 SURPRI WELLPF MILL P New fluid around, —300 PSI pressure drop,Vibration still high 10:15 10:51 0.60 7,635 7,165 SURPRI WELLPF MILL P Back ream up50'then continue up to K1 Marker for tie in PUW=34K 10:51 10:57 0.10 7,165 7,190 SURPRI WELLPF MILL P Log tie in for No corection 10:57 11:15 0.30 7,190 7,635 SURPRI WELLPF MILL P RBIH to ream to whipstock 11:15 11:30 0.25 7,635 7,643 SURPRI WELLPF MILL P 7635', Ream down 1.38 BPM @ 3635PSI FS BHP=3388 11:30 12:00 0.50 7,643 7,625 SURPRI WELLPF MILL P Ream Uphole—2'above top of tray PUW=35K 1.44 BPM @3750PS1 12:00 14:06 2.10 7,625 71 SURPRI WELLPF MILL P Trip out of hole, EDC Open. PUW=35K 14:06 16:24 2.30 71 75 SURPRI WELLPF MILL P At Surface, PJSM, Flo Check well, Pull BHA#3 Haily underreamer. M/U BHA#4 Weatherford U/R with 4.825 blades, New Weatherford 2 3/8" Motor,Service Injector, Stab on and surface test tool Open EDC 16:24 19:00 2.60 75 7,300 SURPRI WELLPF MILL P Trip in Hole, EDC is open,-9 ft correction.CLose EDC-RIH to 7300' P/U weight 37K. 19:00 20:30 1.50 7,300 7,526 SURPRI WELLPF MILL P Reaming-1.40 bpm,3600psi, BHP 3380, ROP 100 fph,WOB.3K, light vibrations on the tool. Light cement cutting coming over shaker. 20:30 21:00 0.50 7,526 7,540 SURPRI WELLPF MILL P Having multiple stalls @ 7526' through pelf section, made 7 attempts,slow ROP. Shut down pups&run down past to 7540'. Light metal shavings over shakers. 21:00 22:30 1.50 7,540 7,564 SURPRI WELLPF MILL P Clean reaming 1.45 bpm,3480 psi, ROP 40-60 fph. BHP 3460psi.. Stalls @ middle perfs 7564'-Make 5 attempts and stop pumping to go past. Stacked out-Dry tag @ 7562'. Page 4 of 39 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 22:30 23:30 1.00 7,564 7,562 SURPRI WELLPF MILL P Back ream up through upper perfs to 7520',Clean with some motor work detected. Shut down pump. RIH clean down to @ 7562'. Dry tag again. 23:30 00:00 0.50 7,562 7,565 SURPRI WELLPF MILL P P/U weight 36K-Start underreaming area,motor work detected @ 7565' 03/08/2011 Complete under-reaming with Weatherford BHA. Gauge 4.80"on bottom&4.77"on top. Rig up E-line and could not get past 7440'with first 2 strings. P/U slimline with 1 knuckle joint&drifted to TD. POOH to P/U slimline logging string. 00:00 02:00 2.00 7,565 7,580 SURPRI WELLPF MILL P Continue reaming down slowly through perf section. 1.40 bpm, 3560 psi, BHP 3440, ROP 2-3 fph,WOB .5K.More stalls @ 7580-7587". Light cement returns over shakers. 02:00 05:30 3.50 7,580 7,643 SURPRI WELLPF MILL P Try to work through troubled spot @ 7580'-87-very slow going with multiple stalls.Cannot run past it dry.Continue milling. Increased ROP from 7595'10-20 FPH. Pump 10 bbls sweep near TD. 05:30 06:24 0.90 7,643 7,314 SURPRI WELLPF MILL P Back ream up to Tubing tail @ 5 fpm. 06:24 07:48 1.40 7,314 7,640 SURPRI WELLPF MILL P Back ream up to 7314 stall, unable to go down,48K overpull to get loose work up to 7307.Very ratty.decide to leave cement there,open EDC to run back to bottom and pump hi vis sweep 07:48 10:30 2.70 7,640 73 SURPRI WELLPF MILL P POOH after sweep out, PUW=38K 10:30 11:45 1.25 73 0 SURPRI WELLPF MILL P PJSM,Tag up, PJSM, Flo Check well, lay down BHA#4 Prep for E-Line R/U 11:45 14:15 2.50 0 0 SURPRI WELLPF ELOG P PJSM, R/U E-Line for CBL 14:15 16:45 2.50 0 0 SURPRI WELLPF ELOG P RIH with E-Line 16:45 18:15 1.50 0 0 SURPRI WELLPF ELOG P E-Line made it to 7440', POOH to reconfig BHA,attempt to get deeper. POOH&inspect BHA. 18:15 20:00 1.75 0 0 SURPRI WELLPF ELOG P PJSM&crew change.Tool looked good. Change the centrilizer configuration with a smaller 3 blade on the bottom. Rollers between the knuckle joints. 20:00 22:00 2.00 0 0 SURPRI WELLPF ELOG P RIH with E-line.Tag at 7440'@ 80 fpm,Tag at 7460'@ 200 fpm, light over pull.Tag @ 7444'@ 250 fpm. POOH. 22:00 00:00 2.00 0 0 SURPRI WELLPF ELOG P P/U just weight bars with only 1 knuckle joint&do a slimehole run. Clean down to bottom. P/U Elog string with 1 knuckle and min. centrilizers. 03/09/2011 Under-ream from 7390-7643'. Logging run completed with good results of CBL. P/U window milling BHA with 2.80"mill. Page 5 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 03:00 3.00 0 0 SURPRI WELLPF ELOG P P/U slimline logging string with 1 knuckle joint&3 small centrilizers. Stacked out @ 7450'-POOH for Under-reaming run. Found a clump of metal cutting around the tool with packed off cement. Rig down E-line. 03:00 04:00 1.00 0 77 SURPRI WELLPF MILL P P/U Haley U/R with new blades on the top. 04:00 06:06 2.10 77 SURPRI WELLPF MILL P RIH with EDC open 06:06 06:18 0.20 7,165 7,184 SURPRI WELLPF MILL P Log tie in for-9.5'correction.Close edc 06:18 08:12 1.90 7,184 7,640 SURPRI WELLPF MILL P Trip into 7320 and Under ream down 1.39 BPM @ 4190 PSi FS RIW=17K No setdowns, minimal motor work, No Stalls 08:12 09:42 1.50 7,640 7,320 SURPRI WELLPF MILL P 7640', U/R Up, PUW=36K 1.4 BPM@ 4190PSI FS No overpulls Minimal motor work 09:42 11:30 1.80 7,320 7,640 SURPRI WELLPF MILL P 7320, Ream down 1.4 BPM @ 4190 PSI FS No Motor work, No overpulls or set downs, No Stalls Start 3 Lb/BBI pill down coil Open EDC @ Bottom,displace pill at max rate 2.0BBI/Min 11:30 13:00 1.50 7,640 7,200 SURPRI WELLPF MILL P Open EDC and jet up to 3 1/2 13:00 14:45 1.75 7,200 68 SURPRI WELLPF MILL P 7200 Trip out EDC Open 14:45 16:00 1.25 68 0 SURPRI WELLPF MILL P PJSM,flo check, Pull Coiltrack and U/R from well Reamer 4.625 Upers,3.75 Lower 16:00 16:18 0.30 0 0 SURPRI WELLPF SFTY P Pre Rig Up safety meeting with HES E-Line 16:18 17:18 1.00 0 0 SURPRI WELLPF ELOG P Rig up E-Line 17:18 20:18 3.00 0 7,643 SURPRI WELLPF ELOG P RIH-made it to TD&begin logging. Logs are good, nice cement behind. pipe. POOH. 20:18 21:18 1.00 7,643 0 SURPRI WELLPF ELOG P E-line at surface. Rig Gown HES. 21:18 22:48 1.50 0 73 PROD1 WHPST PULD P PJSM for P/U milling BHA. P/U milling BHA with .6 AKO&2.80" new mill and 2.79 go-re-run string mill. 22:48 00:00 1.20 73 5,000 PROD1 WHPST TRIP P RIH 03/10/2011 Mill window-pinch point 7648.5',exit 7653.6'. Drilled additional 10'formation to 7664'. POOH for BOPE test. Upper swab valve failed during BOPE test. 00:00 01:30 1.50 5,000 7,643 PROD1 WHPST TRIP P RIH-tie in with-9ft correction.tag TOC @ 7642.5'. P/U weight 35K. Light metal&cement returns over shaker. Page 6 of 39 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 01:30 03:00 1.50 7,643 7,648 PROD1 WHPST MILL P Start milling cement-1.45 bpm, 3400psi, BHP 3480,WOB 1.3K, ROP 8,CT weight 15K TOWS pinch point 7648.5'-1.40 bpm,3600, BHP 3630, ROP 2 fph, WOB.8K,CT weight 14.8K 03:00 06:00 3.00 7,648 7,652 PROD1 WHPST MILL P Set in auto drill @ 1.5 fph. 1.40 bpm, 3580 psi, BHP 3611,WOB 1.3K,CT weight 14K.getting light samples of metal over shakers. 06:00 07:42 1.70 7,652 7,654 PROD1 WHPST MILL P Crew change,—2 FPH 1.1K WOB 07:42 12:42 5.00 7,654 7,664 PROD1 WHPST MILL P Called exit @ 7653.6 Start drilling rathole 12:42 13:12 0.50 7,664 7,664 PROD1 WHPST REAM P Start reaming passes PUW=36K 1.42 BPM @ 3818 PSI FS, BHP=3666 13:12 13:42 0.50 7,664 7,664 PROD1 WHPST CIRC P Reaming complete, Dry drift looks good, Pump 30 BBIs Hi Vis sweep, recip through 5 1/2, followed by 9.6Lb flo pro 13:42 16:36 2.90 7,664 66 PROD1 WHPST TRIP P Trip out of hole, EDC is open 16:36 18:06 1.50 66 0 PROD1 WHPST PULD P At surface, Flo check well, Lay down window milling BHA#6 18:06 19:06 1.00 0 0 PROD1 WHPST SFTY P SLT meeting with both crews for Idatrod recignition. 19:06 20:36 1.50 0 0 PROD1 WHPST CIRC P Start filling CTwith fresh water. Grease&service valves on tree& choke. 20:36 23:06 2.50 0 0 PROD1 WHDBO BOPE P Start BOPE testing-Waived by John Crisp. Upper swab valve leaks,double blocked stack and tree.Tested lower valve&against master-held. Rigged up stinger with injector and flushed the stack for potential due to metal& cement debris from previous runs. large chunks of cement and medal in Possum belly on shaker. 23:06 00:00 0.90 0 0 PROD1 WHDBO BOPE P Move forward with BOP test& prepare to replace swab valve. 03/11/2011 Replaced upper swab valve, Charlie 4&choke A due to failed tests.Completed BOPE test&cut 370 ft of CT in total. Re-head CT. 00:00 06:00 6.00 0 0 PROD1 WHDBO BOPE P Continue with BOPE test.Charlie 4 &Choke A need to be replaced. Pulled apart suction&discharge of mud pumps, HP screens and found more metal shavings. 06:00 08:30 2.50 0 0 PROD1 WHDBO BOPE P Crew change,continue BOPE testing,Got good test on lower swab still unable to get test on upper swab.Test complete exect for failures 08:30 14:00 5.50 0 0 PROD1 WHDBO BOPE T PJSM,Change out upper swab, Replace C-4 and dissassemble choke A Page 7 of 39 Time Logs Date From To Dur S. Death E.Depth Phase Code Subcode T Comment 14:00 15:45 1.75 0 0 PROD1 WHDBO BOPE T Upper swab swapped out,fluid pack and test. C-4 and choke A complete. Test WH/BOP flange,Test Upper swab,Test C-4, clear choke A 15:45 17:45 2.00 0 0 PROD1 WHDBO BOPE P Skid injector to floor and remove check valves in UQC,fill coil test inner reel valve. BOP test completed with all pass tests. 17:45 18:30 0.75 0 0 PROD1 WHDBO BOPE P Crew change&blow down all BOP& tiger tank lines. 18:30 00:00 5.50 0 0 PROD1 DRILL CTOP P Set up rig floor for cutting pipe& handling material.Cut 360 ft of CT. Re-head CT connector&test. Install BHI connector. 03/12/2011 Drill Build section from 7664'7842'. landed in LA-4 pay.Tie into RA marker new Window depths. • TOWS=7643' TOW=7646' BOW=7652' 00:00 02:00 2.00 0 0 PROD1 DRILL CTOP P Complete making up CT connector. Pressure&pull test.Circulate CT to flo-pro.-Flow-check with no flow. 02:00 03:00 1.00 0 0 PROD1 DRILL SFTY P Pre-spud meeting with new crew that arrived tonight. PJSM for P/U BHA. 03:00 04:30 1.50 0 63 PROD1 DRILL PULD P P/U build BHA with 2.4 AKO motor and rebuild 2.70 Bi-center Bit. Checked pack-off s&replaced. 04:30 06:36 2.10 63 7,150 PROD1 DRILL TRIP P RIH with EDC closed pumping .3bpm. 06:36 06:48 0.20 7,150 7,167 PROD1 DRILL DLOG P Log Gamma tie in for-9'Correction PUW=31K 06:48 07:03 0.25 7,167 7,664 PROD1 DRILL TRIP P RIH to drill, Clean pass through window RIW=20K 07:03 10:18 3.25 7,664 7,810 PROD1 DRILL DRLG P 7664',drill ahead 1.36 BPM @ 3700PS1 FS, BHP=3990, RIW=16.7 WOB=2K 10:18 10:42 0.40 7,810 7,150 PROD1 DRILL WPRT P 7810,Wiper to window, PUH to K1 Marker 10:42 10:48 0.10 7,150 7,170 PROD1 DRILL DLOG P 7150,Tie into K1 marker. No Correction 10:48 11:03 0.25 7,170 7,660 PROD1 DRILL WPRT P 7170 RBIH to Log RA 11:03 11:09 0.10 7,660 7,683 PROD1 DRILL DLOG P 7660, Log RA Marker @ 7650.0 Corrected window depths Top of whipstock 7643, Pinch Point (TOW)=7646.35 BOW=7652, RIH to drill 11:09 11:15 0.10 7,683 7,810 PROD1 DRILL WPRT P Wiper trip back to bottom 11:15 12:27 1.20 7,810 7,842 PROD1 DRILL DRLG P 7810', Drill Ahead 1.36BPM @ 3818PSI FS RIW=16.4K,WOB=3K BHP=3973 Call End of build,AVG DLS=53.8 12:27 15:03 2.60 7,842 56 PROD1 DRILL TRIP P Get Good bottom sample showing sand,Trip out for RSM. Following MP Schedule 15:03 16:18 1.25 56 0 PROD1 DRILL PULD P On Surface, PJSM, Un Deploy BHA #7 Build setion BHA Page 8 of 39 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 16:18 17:03 0.75 0 0 PROD1 DRILL PULD P M/U coil track-rib steer BHA and load PDL 17:03 19:33 2.50 0 68 PROD1 DRILL PULD P PJSM, PD BHA#8, Lateral BHA with Rib Steer Motor&2.70"bi-center (new) Pressure test Tiger tank line after swapping out isolation valve. Purge with air. 19:33 22:03 2.50 68 7,842 PROD1 DRILL TRIP P RIH pumping through EDC holding MPD.-10ft correction.Close EDC. P/U weight 32K. 22:03 00:00 1.95 7,842 7,980 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,3980 psi, BHP 3980, ECD 12, ROP 65, Ct weight 15K,WHP 0, rate out 1.62 (MM not reading correctly). No losses-no gains in pits. 03/13/2011 Drilled ahead-Decent hole cleaning while drilling and found ankerite @ 8643'.Slow ROP.Good 1:1 returns all day. 00:00 01:00 1.00 7,980 7,990 PROD1 DRILL WPRT P Wiper trip-P/U 32K-MAD pass. 01:00 04:00 3.00 7,990 8,140 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,3980psi, BHP 3960psi, ECD 12, ROP 80, WOB 1.7K,CT weight 16K. 1:1 returns. 04:00 04:30 0.50 8,140 8,140 PROD1 DRILL WPRT P Wiper trip-P/U weight 31K 04:30 05:45 1.25 8,140 8,290 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,4100psi, BHP 4000psi, ECD 12, ROP 100, WOB 1.5, Ct weight 14K, 1:1 returns. Pressure are a little higher this time on bottom.Wipe up to casing next trip. 05:45 06:45 1.00 8,290 7,300 PROD1 DRILL WPRT P Wipe to WEG, PUW=31K, Good clean pass through window Leave EDC closed to mix possible cuttings in 5 1/2 06:45 06:51 0.10 7,300 7,683 PROD1 DRILL DLOG P 7663 to 7683 Log tie in for no correction 06:51 07:12 0.35 7,683 8,290 PROD1 DRILL WPRT P Continue wiper trip to bottom RIW=17.6K 07:12 09:12 2.00 8,290 8,440 PROD1 DRILL DRLG P 8290', Drill Ahead 1.40 BPM @ 3950 PSI FS RIW=14.9K,WOB=1.8K, BHP=3991 09:12 10:12 1.00 8,440 8,440 PROD1 DRILL WPRT P Wipe to window, PUW=32K 10:12 10:27 0.25 8,440 8,464 PROD1 DRILL DRLG P 8440', Drill Ahead 1.40 BPM @ 4064 PSI FS RIW=16.6,WOB=1.7K, BHP=4097 10:27 10:45 0.30 8,464 8,468 PROD1 DRILL DRLG P 8464', ROP dropped<20 FPH 8456 High Gamma, resistivity down, Lost 10:45 16:15 5.50 8,468 8,590 PROD1 DRILL DRLG P Stall, BHA wiper Slow drilling 16:15 17:15 1.00 8,590 8,590 PROD1 DRILL WPRT P 8590',Wiper to window, PUW=31K Clean P/U 1.36 @ 3900 FS, BHP=4070. Page 9 of 39 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 17:15 19:30 2.25 8,590 8,655 PROD1 DRILL DRLG P Drilling ahead-SLow ROP due to Ankwerite. Broke through @ 8650' Ratty drilling,pressure spikes& weight transfer-P/U weight 32K. Wipe up 70 ft. 19:30 20:30 1.00 8,655 8,673 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,4080, BHP 4106, ECD 12.4, ROP 30,WOB 2.2K, CT weight 13K. ROP dropping off @ 8670'P/U weight 30K-wipe up to 8400' 20:30 00:00 3.50 8,673 8,731 PROD1 DRILL DRLG P Better weight transfer and smoother drilling on bottom-1.40 bpm,4100, BHP 4100, ECD 12.5,WOB 2K, ROP 10,CT weight 14K.Ankerite and sand in samples. Ribs at 80% force. 03/14/2011 Continue slow ROP drilling to find Fault block#2.Mud swap with 1516 ft. on system. 00:00 00:42 0.70 8,731 8,740 PROD1 DRILL DRLG P Drilling Annkerite-slow ROP. Increase in ROP last 6 ft. Dropping rib force to 70%.Light cuttings to surface. 00:42 02:00 1.30 8,740 8,740 PROD1 DRILL WPRT P Planned wiper trip with Tie in-1ft correction.-P/U weight 31K, clean through shale section.Cutting stayed the same during wiper trip. 02:00 06:18 4.30 8,740 8,890 PROD1 DRILL DRLG P Drilling ahead-1.38 bpm,4100, BHP 4100, ECD 12.5,WOB 1.9K,Ct weight 15K. ROP 80 fph.light to medium cuttings over shaker. Starting to get a light trace of oil in cuttings/mud. 06:18 07:48 1.50 8,890 8,890 PROD1 DRILL WPRT P Wiper to window, PUW=32K No overpulls or setdowns. No shale activity 07:48 12:48 5.00 8,890 9,040 PROD1 DRILL DRLG P 8890', Drill ahead 1.35 BPM @ 4100PSI FS RIW=12.8K,WOB=2.36K, BHP=4180 ROP 20 to 40 FPH 12:48 14:33 1.75 9,040 9,040 PROD1 DRILL WPRT P 9040 Wiper to window, No Fault sighted PUW=32K, BHP=4170 Clean trip No overpulls or setdowns 14:33 19:03 4.50 9,040 9,120 PROD1 DRILL DRLG P 9040', Drill ahead looking for fault 1.35 BPM @ 4100 PSI FS RIW=12.7,WOB=2.8K, BHP=4170 19:03 20:03 1.00 9,120 9,133 PROD1 DRILL DRLG P Slow ROP 5-6 fph -pump a 20 bbls new flo-pro sweep. P/U 60'- Seen slight bobble @ 9130' Helped with WOB,pressures& ROP. Trucks in route for mud swap. Circ press. 3980, BHP 4110,WOB 1.9K, ROP 13 20:03 21:48 1.75 9,133 9,170 PROD1 DRILL DRLG P Drilling ahead-1.35 bpm,4380, BHP 4210,WOB 2.3K,CT weight 12K, ROP 13. ECD 12.7. Page 10 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 21:48 23:00 1.20 9,170 9,195 PROD1 DRILL DRLG P New mud-1.40 bpm,3800, BHP 3960,WOB 1.7K, ROP 46, ECD 12, CT weight 14K 23:00 00:00 1.00 9,195 9,195 PROD1 DRILL WPRT P Wiper trip-P/U weight 31K.-heavier cuttings comingover shaker during wiper trip with new mud.Tie in-2 ft. 03/15/2011 Hard time getting through clay section @ 9135&9175'.Continue drilling ahead-crossed fault and found targeted A-4 sands. Pump sweeps&pull final wiper. Stuck BHA in clay @ 9135'.Total of 320 bbls losses in 24 hours. 00:00 01:12 1.20 8,200 9,000 PROD1 DRILL WPRT P RIH after wiper-Good cutting over shaker, Weight bobble @ 9100'&tagged up @ 9130'P/U weight 33K. Rate 1.0 bpm. Lower rate to.50 bpm,trap 200psi on choke and drift ristrictions to 9165'. P/U weight 44K at first to clean up pass up to 9000'. 01:12 02:30 1.30 9,000 9,170 PROD1 DRILL WPRT T RIH through trouble area-.6 bpm, WHP 250 psi, stack out @ 9175' Overpull to 48K.Wipe up again& call town.Continue to clean past 9130'lower rate&take 10'bites @ 1 bpm to clean up section. P/U are clean through 9130'section.31K 9170'-worst section.-P/U weight 46K, Clay in samples from B/U. Continue to work. Increase clay gaurd to 3%. 02:30 03:30 1.00 9,170 9,195 PROD1 DRILL WPRT T Try reaming down from 9165'to 9172' 1.30 bpm.Clean it up-RIH .6 bpm to TD.Wipe up twice to 9050'-Clay Clean. RIH 1 bpm. 03:30 05:30 2.00 9,195 9,210 PROD1 DRILL DRLG P Drilling ahead-1.40 bpm,4060, BHP 4090, ECD 12.3, ROP 60,WOB 2.2K, CT weight 14K. 9215'-P/U wiper 32K to 9080'clean -continue drilling ahead 05:30 07:00 1.50 9,210 9,216 PROD1 DRILL DRLG P 9210 Started taking losses of 20 BBI /Hr 1.40 BPM @ 3947 PSI FS, BHP=4059 Geos calling fault @ 9216 Drill Ahead 07:00 08:15 1.25 9,216 9,309 PROD1 DRILL DRLG P 9295 to 9250 Mini Wiper a little stacking PUW=32K 1.39 BPM @ 3968 PSI FS, BHP=4041 08:15 10:45 2.50 9,309 9,360 PROD1 DRILL DRLG P Drill ahead, pu wt 36k,1k wob, 1.40 bpm @ 4200 psi 10:45 12:15 1.50 9,360 7,300 PROD1 DRILL WPRT P pull wiper to 7300'pu wt 33k 12:15 14:00 1.75 7,300 9,365 PROD1 DRILL TRIP P RBIH,stacked out @ 7670'.pu work a bit looks like pushing something down hole, 7760'to 7798'. Pick-up a little sticky, cleaned up RIH 9365' Page 11 of 39 Time Logs Date From To Dur. S. Depth E. Depth Phase Code Subcode T Comment 14:00 18:30 4.50 9,365 9,415 PROD1 DRILL DRLG P Drilling ahead ROP 12, 1.9k wob, 1.39 BPM @ 4145 FS 18:30 20:48 2.30 9,415 9,457 PROD1 DRILL DRLG P Crew change-Stall-P/U weight check 32K.fluid losses 12 bbl/hour. Mix up drillzone. Drill ahead-1.38 bpm,4280, BHP 4100, ECD 12.2, ROP 18,WOB 1.6K,CT weight 14K. Light cuttings over shaker. 20:48 23:18 2.50 9,457 9,515 PROD1 DRILL DRLG P Pump 10 bbl drillzone sweep P/U • weight 32K-1.35 bpm,4100, BHP 4145, ECD 12.2, ROP 40,WOB 1.5K, CT weight 14K. losses increased to 17bbI/hour. Pump final sweep at TD 23:18 23:48 0.50 9,515 9,135 PROD1 DRILL WPRT P TD P/U weight 33K-sweep out bit- clean off bottom 23:48 00:00 0.20 9,135 9,135 PROD1 DRILL WPRT P Light overpull @ 9175'-35K.then stuck @ 9135'max. P/U 44K-could not run back in. BHA stuck. lost returns. 03/16/2011 BHA stuck @ 9135'eventually worked free.Wiper to swab valve. RIH for liner pill&problems getting past 7667'.Work through and lay in liner pill&KWF to surface.Service equipment @ surface.Total losses=306 bbls of flo-pro&45 bbls of KWF. 00:00 02:00 2.00 9,135 9,135 PROD1 DRILL WPRT T Stuck BHA-no circulation.Stuck between DPS&RSM.Can pump down CT string but no returns past BHA. No motor work detected.Work string down as much as possible highest CT life cycle 14%. max. pull up was 46K.Sit and down motion and cycle pumps&pressures. Cycled RSM pads. 02:00 04:00 2.00 9,135 9,135 PROD1 DRILL WPRT T Conference call to town-Decision to work max. pull/push on tool.-16K& +8K moved about 1ft up hole. Locked up, lost our movement in BHA. 04:00 05:00 1.00 9,135 9,135 PROD1 DRILL WPRT P Relaxed CT&BHA to open EDC. Pumped down backside to equalize BHA-noticed weight change after 15 minutes of equalizing time. P/U on BHA&came free. P/U 42K then broke over to 32K. :) POOH and pump low-high sweep through build&window area-losing about 1/2 bpm while POOH. Holding 100 psi on choke. 05:00 07:30 2.50 7,800 0 PROD1 DRILL WPRT P Sweep out @ build section-POOH at 15 fpm through build&5.5"cased hole. Clean through window.Stop @ 7289'OPen EDC&wipe to swab valve.Shut down pumps and function test EDC. Kick on pumps and regain delta p from bore to annular,looks good. 07:30 10:00 2.50 0 8,050 PROD1 DRILL TRIP P RBIH, pumping at min rate. Start stacking wt in build section starting @ 7667'but able to make hole. Page 12 of 39 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode =T Comment 10:00 13:00 3.00 8,050 8,050 PROD1 DRILL WPRT P Pull up&do small wiper trips, RBIH clean to where we left off. Repeat several times until thru build section. Wiper back up to 7300'. RBIH,see a slight bobble but otherwise clean thru the build.Get w/mud man to make up a hi/lo sweep. 13:00 14:45 1.75 8,050 7,300 PROD1 DRILL WPRT P Pump 10 bbls/hi/lo vis sweep.Chase up @ 30 FPM to 7300'.To clean up build section&5.5"CSG. 14:45 15:45 1.00 7,300 8,825 PROD1 DRILL TRIP P RBIH,still have some slight stacking outside the window, clean after that. 15:45 18:45 3.00 8,825 70 PROD1 DRILL DISP P Start laying in liner pill,25 bbls. Paint flag @ 8168'.5(8100'EOP) Flag @ 7068.5'(7000' EOP) Gamma tool failing-Depth counter failed as POOH to surface. Continue laying KWF to surface. KWF to surface @ 1500ft. 18:45 19:15 0.50 70 0 COMPZ CASING SFTY P Flow-check @ surface. PJSM for laying down BHA&setting up floor for injector inspection.Well is on a vac.Total of 40 bbls lost since the start of KWF operations. 19:15 20:15 1.00 0 0 COMPZ CASING RGRP P Lay down BHA&close the swab valves. Bit has 3 plugged down jet nozzles&3 small chpped cutters. 20:15 21:45 1.50 0 0 COMPZ CASING CIRC P PJSM for jetting stack,surface maint.to injector, BHA, coil connector&choke/Micro motions. More cement chunks found while flushing the stack. Pumped 5 bbls to fill well after the stack was flushed.Secure well for maint. 21:45 00:00 2.25 0 0 COMPZ CASING RGRP P Injector maint. no problems, inspect CT connector, pressure test good. Tested BHI connector-good. Fixed BHI depth counter. 03/17/2011 Ran slotted liner in ALA lateral from 8821 -8300(TOB). Repair PLC reel/injector cart relay at surface. P/U BHA#10 with 1.2 AKO&2.73"Bi-center&start sidetracking @ 8300'-smooth transition&no stalls.Total KWF losses=241 bbls 00:00 01:00 1.00 0 0 COMPZ CASING RGRP P Continue working on injector and surface equipment.Top up well,8 bbls prior to P/U liner. 01:00 03:30 2.50 0 COMPZ CASING PUTB P PJSM&P/U liner 15 joints of slotted &anchored billet. 03:30 04:45 1.25 572 8,812 COMPZ CASING TRIP P RIH with EDC open pumping .3bpm, bobbled thru the build just outside the window,but otherwise smooth. 04:45 05:00 0.25 8,812 8,812 COMPZ CASING WPST P Stop @ 8811.7(top of anchored billet @ 8300'set 10 deg ROHS)Shut down pumps,shut EDC. @ Pump down coil @ neural wt but stacked 8k w/pump on)Pressure up to 3900 psi shear running tool setting billet. pick off clean. Page 13 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:00 07:45 2.75 8,812 60 COMPZ CASING TRIP P POOH, keeping hole full W/KWF. 07:45 08:30 0.75 60 60 COMPZ CASING SFTY P OOH,Watch for flow.conduct PJSM.Good no flow. Move cart a couple feet but shut down, trouble-shoot.electical issue with the cart. 08:30 11:45 3.25 60 60 COMPZ CASING RGRP T Continue to trouble-shoot electronics on cart. 11:45 12:30 0.75 60 0 COMPZ CASING RGRP T Still down. conduct PJSM,well still dead on vac. open bag. hook up tugger to BHA, remove in two pieces. shut swab. 12:30 13:30 1.00 0 72 COMPZ CASING PUTB T Electronic problem fixed on cart. Conduct PJSM, move cart back. Function test BOP's. 13:30 14:30 1.00 0 72 PROD2 STK PULD P Pick up drilling BHA with 1.2 AKO& 2.73"Bi-center razor. 14:30 17:00 2.50 72 7,600 PROD2 STK TRIP P RIH W/drilling BHA-tie in-10 ft. Slowly getting returns to surface. 17:00 18:45 1.75 7,600 8,300 PROD2 STK CIRC P Circulate KWF out of well.Close EDC-clean through window&build section. Dry tag TOB @ 8300' 18:45 00:00 5.25 8,300 8,317 PROD2 STK KOST P P/U weight 31K,Tag lightly @ 8299.5'-Pump rate 1.40 bpm,4100 psi, BHP 3975, ROP 1 fph,WOB .7K. Kick off Billet as procedure-No stalls. 03/18/2011 Drilled ahead on AL1-02.Total of 13 bbls of 9.6 drilling mud lost to formation. 00:00 00:30 0.50 8,317 8,330 PROD2 STK KOST P Complete STK off billet-no stalls. Dry pass through billet. P/U weight 31K 00:30 03:30 3.00 8,330 8,460 PROD2 DRILL DRLG P Drilling ahead-1.40 bpm,4100, BHP 4012, ECD 12.2, ROP 50,WOB 1.8K,CT weight 13K, 1:1 returns 03:30 04:30 1.00 8,460 8,460 PROD2 DRILL WPRT P Wiper trip-P/U weight 32K-clean. 04:30 07:15 2.75 8,460 8,610 PROD2 DRILL DRLG P Drilllig ahead 07:15 08:30 1.25 8,610 8,610 PROD2 DRILL WPRT P Wiper trip 08:30 11:45 3.25 8,610 8,760 PROD2 DRILL DRLG P Drilling ahead, 1.36 BPM @ 4300 psi, 12.3 ECD.WHP=0. 11:45 14:15 2.50 8,760 8,760 PROD2 DRILL WPRT P Wiper trip-P/U weight 33K-zero correction on tie in. 14:15 17:15 3.00 8,760 8,910 PROD2 DRILL DRLG P Drilling ahead-1.35 bpm,4100, BHP 4030, ROP 50,WOB 2.2K,CT weight 12K. Silt&shale in samples no sand. 17:15 18:30 1.25 8,910 8,910 PROD2 DRILL WPRT P Wiper trip-P/U weight 32K 18:30 21:45 3.25 8,910 9,060 PROD2 DRILL DRLG P Drilling ahead 1.35 bpm 4100, BHP 4021, ROP 57. Pump 10 bbls drill zone sweep. 21:45 00:00 2.25 9,060 9,060 PROD2 DRILL WPRT P Wiper Trip-pu wt 31.5k. Pull up past window into the 5.5"CSG.Open EDC, chase out up into the 3.5"tbg 500'to 6780'. Page 14 of 39 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 03/19/2011 24 hr Summary Drilled AL1-02 lateral to 9360'but unable to down past 9330'after wiper. Run wiper to swab valve(several passes in the 5.5"CSG). RBIH to lay in liner pill&KWF. Had to work it to get past 7711'&7760'.Total fluid loss of 9.6 drilling mud=39 bbls. 00:00 01:30 1.50 9,060 9,060 PROD2 DRILL WPRT P Continue Wiper Trip, RBIH.Tie into RA marker,0 correction. Stack wt. @ 7717'. pick-up, lost returns for a moment. pull up,tool face is correct. Returns are back, RBIH w/no problem. Stack out @ 8500'. pick-up, RBIH back off rate to.75 BPM,went by w/no problem. 01:30 04:30 3.00 9,060 9,200 PROD2 DRILL DRLG P Drill ahead-1.39 BPM @ 4300 PSI, BHP 4109 PSI, ECD 12.31 pump 10 bbls to/hi sweep&Stop @ 9200' 04:30 07:00 2.50 9,200 7,300 PROD2 DRILL WPRT P Pull Wiper pu wt 33k-wipe up to casing for town to decide plan forward.Open EDC&circ up& down.Seen more Al.shavings and cutting over shakers.(hole cleaning in 5.5"). 07:00 08:00 1.00 7,300 9,200 PROD2 DRILL WPRT P Close EDC-RIH to drill another 150'. • 08:00 11:00 3.00 9,200 9,360 PROD2 DRILL DRLG P Drilling ahead-1.35 bpm,4280, BHP 4150, ECD 12.6, ROP 55,WOB 2.2K. light cuttings over shaker. 11:00 15:00 4.00 9,360 9,335 PROD2 DRILL WPRT P Wiper trip-33K P/U,came up to 7800'-RIH&stacked out @ 9340'- Heavy pull 38K.Wipe up to 8800'to clean up. RIH could not get past 9333'at lower rates. Multiple tries at different rates. No luck.Try drilling off. 15:00 16:00 1.00 9,335 9,335 PROD2 DRILL DRLG P Drilling ahead slowly through bad section-1.36 bpm,4100, BHP 4133, ECD 12.5, ROP 20,WOB 1.4K. No luck.Try low rate,stuck BHA with torque on bit.Tried cleaning area but not gaining ground. 16:00 20:15 4.25 9,335 72 PROD2 DRILL WPRT P Wiper to swab valve-pump low-high sweep. Open EDC in 5.5"and cylce up&down through area. POOH. 20:15 00:00 3.75 72 7,760 PROD2 DRILL TRIP P RBIH to lay in liner pill&KWF.Tie into gamma,-3 correction.Tag tight area @ 7711'-pick up&get by.Tag another area @ 7760'. Had to wiper up several times to clean up. RBIH, get by 7760'spot. 03/20/2011 Layed in KWF to surface. Ran AL1-02 liner from 8687'to top billet @ 8210.Circulated KWF out W/used flow pro to prep for kick off of billet for AL1-03. 00:00 02:00 2.00 7,760 8,700 PROD2 DRILL TRIP P Continue to RIH.Get past 8500'with no problem, RIH to 8700'.Get liner pill build while continuing to move pipe up/dwn. Paint flag @ 8170' 02:00 06:00 4.00 8,700 72 PROD2 DRILL DISP P Send Liner pill down coil. Start laying from 8690'paint window flag @ 7071',continue POOH laying in KWF Page 15 of 39 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 06:00 06:30 0.50 72 72 PROD2 DRILL SFTY P OOH,watch for flow.Conduct pre-job safety meeting prior to UD BHA. Well is static-no-flow. 06:30 07:30 1.00 72 0 PROD2 DRILL PULD P Lay down BHA-KWF hole full with no major losses. 07:30 09:30 2.00 0 0 COMPZ CASING RGRP P Perform maint. on injector&top drive. Pull aprt MPD choke to inspect for erossion.AIII looked good. 09:30 12:00 2.50 0 538 COMPZ CASING PUTB P PJSM&P/U liner-14 joints of slotted with bullnoze&Anchored billet. Kick while P/U drill-2min 50secs. 12:00 14:00 2.00 538 8,687 COMPZ CASING TRIP P RIH with EDC open pumping .3bpm. Tie in©7537'-10ft correction. P/U weight 33K. CLose EDC. RIH stacking weight @ 7734'to 7790' continue to work down. Stacked @ 8217'(BHA in build section). 14:00 14:30 0.50 8,687 8,610 COMPZ CASING WPST P TOB @ 8610'set 180-Pump 1.2 bpm,set anchor @ 4200psi.WOB 7K. 14:30 16:30 2.00 8,610 68 COMPZ CASING TRIP P Correct depth&POOH laying in KWF. 16:30 18:45 2.25 68 68 COMPZ CASING PUTB P Flow check,conduct pre job. lay down BHA. Pick up Drilling BHA 18:45 20:45 2.00 68 7,620 PROD3 STK TRIP T RIH W/drilling BHA w/EDC open. Log GR tie in-10 correction.RIH to 7620' 20:45 23:00 2.25 7,620 7,620 PROD3 STK CIRC T Circ out KWF W/old drilling mud for Billet kick off. 23:00 00:00 1.00 7,620 8,211 PROD3 STK TRIP T Close EDC. RIH through build section W/no retrictions.Tag billet @ 8210.5' . Pick-up off billet.pumps on. high circ pressure-pull small wiper to get KWF pushed out of oprn hole. 03/21/2011 Kicked off billet @ 8210',drilled to 8290'.Tripped OOH to pick-up RSM drilling BHA. Drilled ahead to 8600'. 00:00 03:00 3.00 8,211 8,240 PROD3 STK ' KOST T Pump pressure looking better,stop @ 8209'.ease down,start time drilling @ 1 FPH. Kick off smooth, drill down to 8240' 03:00 04:30 1.50 8,240 8,290 PROD3 DRILL DRLG T Pull up hole, pump @ min rate.to 8197'. RBI H dry drill past billet clean. Pumps back on,start mud swap to new Flo-pro.Continue drilling© 8240' 04:30 07:30 3.00 8,290 62 PROD3 DRILL TRIP T POOH to surface to pick-up a RSM drilling BHA.30k off bottom. 07:30 09:00 1.50 62 0 PROD3 DRILL PULD T PJSM-Undeploy BHA 09:00 12:00 3.00 0 68 PROD3 DRILL PULD T Station RSM in PDL-PJSM for deploying RSM with 2.73"New bi-center. 12:00 14:45 2.75 68 8,290 PROD3 DRILL TRIP T RIH following MPD pumping 1 bpm through EDC.Tie in-10 ft correction. No problems in build section. Page 16 of 39 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 14:45 17:45 3.00 8,290 8,460 PROD3 DRILL DRLG T Drilling ahead-1.30 bpm,4250, BHP 3960, ECD 12.00, ROP 45,WOB 1.5K,CT weight 13K. 17:45 19:00 1.25 8,460 8,460 PROD3 DRILL WPRT T Wiper up pulled a little heavy in billet area,slacked RBIH-pulled back up ok...wiper up to 7690'. RBIH 19:00 00:00 5.00 8,460 8,600 PROD3 DRILL DRLG T Drill ahead 1.25 BPM 4140 psi, BHP 4022 PSI, ROP 46.WOB 1.02k Continue drilling ahead. 03/22/2011 Drilled to 8695'with RSM,tripped and PU 1 Deg. motor and new bit,continue drilling to 8787'. 00:00 01:00 1.00 8,600 8,610 PROD3 DRILL DRLG T Continue drilling ahead.Stalled motor @ 8609.62. 01:00 02:15 1.25 8,610 8,610 PROD3 DRILL WPRT T Wiper up 32k off btm. 02:15 05:45 3.50 8,610 8,695 PROD3 DRILL DRLG T Drill Ahead 1.31 BPM,4080 PSI, 11.4 ROP, BHP 4037 PSI.Stall @ 8630'. 05:45 08:45 3.00 8,695 8,695 PROD3 DRILL WPRT T POOH for BHA change. P/U weight 32K 08:45 10:15 1.50 8,695 60 PROD3 DRILL PULD T PJSM for undeploying BHA. Undeploy RSM.secure well&break down BHA on surface. 10:15 12:00 1.75 0 74 PROD3 DRILL PULD T PJSM, M/U and load BHA#14, 1 degree new bi center. Deploy into well,surface test tag up and set counters 12:00 13:36 1.60 74 7,165 PROD3 DRILL TRIP T RIH with BHA#14, lateral non RSM. 13:36 13:48 0.20 7,165 7,178 PROD3 DRILL DLOG T Log tie in for-12'correction 13:48 14:36 0.80 7,178 8,695 PROD3 DRILL TRIP T Trip in to 7619, close EDC Clean pass through window and build section 14:36 00:00 9.40 8,695 8,787 PROD3 DRILL DRLG T 8695', Drill Ahead RIW=15.1K 1.30 BPM @ 4024 PSI FS, WOB=1.7 Stalled a few time grabby but clean pick ups, Pressures are high WHP is normal Mud new yesterday 03/23/2011 Drilled lateral to 9223' 00:00 02:06 2.10 8,787 8,840 PROD3 DRILL DRLG T Continue drilling, 1.3 BPM,4200 CTP,4040 BHP continue having many stalls,appear to be sticking up hole,slipping and stalling... Sweeps with 3%drill-zone help, 02:06 03:48 1.70 8,840 8,840 PROD3 DRILL WPRT T Wiper to window,30K PUW 03:48 08:54 5.10 8,840 8,990 PROD3 DRILL DRLG T Continue drillling, 1.3 BPM,4200 CTP,4035 BHP, Slow ratty drilling ROP mostly 20-30 with small break to 50FPH 08:54 10:36 1.70 8,990 8,990 PROD3 DRILL WPRT T Wiper trip to window, PUW=33K Clean trip in and out Page 17 of 39 Time Logs Date From - To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:36 13:18 2.70 8,990 9,040 PROD3 DRILL DRLG T 8990', Drill Ahead 1.34 BPM @ 4210 PSI FS RIW=15.1 WOB=1.1 K, BHP=4114 ROP-30 FPH 13:18 13:24 0.10 9,040 9,040 PROD3 DRILL DRLG T 9040 ROP down to 5-15 FPH, BHA Wiper PUW=32K, BHP=4115 13:24 16:24 3.00 9,040 9,140 PROD3 DRILL DRLG T 9040', Drill ahead BHA wiper got us up to 40 FPB Start LO-HI Drill zone sweep 1.34 BPM@2418 PSI FS BHP=4115 16:24 18:24 2.00 9,140 9,140 PROD3 DRILL WPRT T 9140,Wipe to window with tie in. +1' correction PUW=32K 18:24 00:00 5.60 9,140 9,223 PROD3 DRILL DRLG T Continue drillling, 1.3 BPM,4100 CTP,4070 BHP, 03/24/2011 Drilled lateral to 9606' 00:00 02:06 2.10 9,223 9,290 PROD3 DRILL DRLG T Continue drillling, 1.3 BPM,4100 • CTP,4070 BHP, 02:06 04:18 2.20 9,290 9,290 PROD3 DRILL WPRT T Wiper to window, 30K PUW 04:18 08:48 4.50 9,290 9,440 PROD3 DRILL DRLG T Continue drillling, 1.3 BPM,4100 CTP,4090 BHP, 08:48 11:36 2.80 9,440 9,440 PROD3 DRILL WPRT P Wiper trip to TT(7310) PUW=33K Clean trip up and down through window and build section, BHP=4146 11:36 13:48 2.20 9,440 9,530 PROD3 DRILL DRLG P 9440', Drill Ahead 1.3 BPM @ 4190 PSI FS RIW=15.8K,WOB=1.5K BHP=4141 13:48 14:06 0.30 9,530 9,530 PROD3 DRILL DRLG P 9530, Pulled BHA Wiper, PUW=37K went back in and had 2 stalls, Once through losses picked up to.3 then started healing. Clean p/u after stalls.BHP=4121 14:06 15:30 1.40 9,530 9,550 PROD3 DRILL DRLG P 9550,Stall, Hard drilling,slow enough to be Ankorite Clean pick up 35K go back to drilling Losses back up to.3 15:30 16:00 0.50 9,550 9,550 PROD3 DRILL DRLG P 9550 Pump Lo Hi sweep with drill zone. Getting good weight transfer. looking more like Ankerite 16:00 16:30 0.50 9,553 9,553 PROD3 DRILL DRLG P Stall with sticky P/U,Area becoming more problematic. Stacking PUW=40-43K 16:30 00:00 7.50 9,553 9,606 PROD3 DRILL DRLG P Difficult time drilling past 9553', seeing fault at 9530'with set downs and motor work. Pumped sweeps with no benefit. Continue drilling. 03/25/2011 Drilled lateral to 9679',test BOP 00:00 00:30 0.50 9,606 9,611 PROD3 DRILL DRLG P Continue drilling, 1.3 BPM,4100 CTP,4200 BHP. Good weight transfer, 14K RIW, 10K with 2-3K WOB. Lots of ankerite in sample from 9600' Page 18 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:30 02:00 1.50 9,611 7,460 PROD3 DRILL WPRT P Wiper to window,saw fault at 9530' with motor work and slight overpull 02:00 02:12 0.20 7,660 7,690 PROD3 DRILL DLOG P Tie-in, +1' 02:12 03:42 1.50 7,690 9,611 PROD3 DRILL WPRT P Wiper back in hole, 16K RIW, start mud swap. Stacked weight and motor work at 9550'with TF at 60R,got past at HS TF. 03:42 07:30 3.80 9,611 9,680 PROD3 DRILL DRLG P Continue drilling, 1.3 BPM,3950 CTP,4150 BHP, 125 WHP 15K RIW with new mud 07:30 11:30 4.00 9,680 65 PROD3 DRILL TRIP P Geo's have seen enough,Wipe up, Circ bottoms up for sample No issues 9530 to 9550, Start Hi Vis Flo Pro pill, POOH laying in Hi Vis Pill. Pull through 5 1/2.Open EDC just below TT 11:30 13:30 2.00 65 0 PROD3 DRILL PULD P PJSM, Undeploy lateral drilling BHA #14.8 Degree motor Crew change out,Continue un deploying 13:30 15:00 1.50 0 0 PROD3 DRILL CTOP P Prep floor and rig up for BOPE Test Flush stack 15:00 00:00 9.00 0 0 PROD3 DRILL BOPE P Start BOPE Test, Bob Noble with AOGCC on location to witness test. Top set of blinds failed, replaced. 03/26/2011 Tested BOP,change out injector skates. 00:00 03:00 3.00 0 0 PROD3 DRILL BOPE P Continue testing BOP, bottom set of blinds failed 03:00 14:00 11.00 0 0 PROD3 DRILL BOPE T Continue testing BOP Exceeding the 12 hours for testing ***Start Nabors Non-Billable Repair rate*** 14:00 00:00 10.00 0 0 PROD3 DRILL RGRP T End of BOPE Test,Multiple failures, prep to unstab and repair Injector skates **Continue with Nabors Non-Billable Repair Time*** 03/27/2011 Changed out injector skates, re-stab and re-head coil. Deploy BHA#15, lateral drilling assembly. 00:00 14:30 14.50 0 0 PROD3 DRILL RGRP T Continue with injector skate replacement 14:30 15:48 1.30 0 0 PROD3 DRILL RGRP T PJSM, R/U and stab coil R/D Stabbing shackles and slings 15:48 19:48 4.00 0 0 PROD3 DRILL RGRP T PJSM Cut 15'coil, Install CTC, rehead, Pull test to 32K, PT 4K, 19:48 22:00 2.20 0 0 PROD3 DRILL RGRP T Re-assemble lubricator,work on injector head grease system 22:00 23:00 1.00 0 0 PROD3 DRILL BOPE P Cirulate water out of coil and PT lubricator connections 23:00 23:18 0.30 0 0 PROD3 DRILL SFTY P PJSM for deploy BHA Page 19 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 23:18 00:00 0.70 0 0 PROD3 DRILL PULD P Preessure deploy drilling BHA#15 with.9 Deg motor and RR HCC bicenter bit 03/28/2011 RIH with BHA#15,0.9 Deg.motor and bicenter bit and drill lateral. 00:00 02:00 2.00 0 72 PROD3 DRILL PULD P Continue with pressure deploy of BHA#15, .9 deg. motor drilling assembly 02:00 03:42 1.70 72 7,160 PROD3 DRILL TRIP P RIH,checking coiled tubing and injector 03:42 04:00 0.30 7,160 7,190 PROD3 DRILL DLOG P Tie-in,-12' 04:00 05:18 1.30 7,190 9,680 PROD3 DRILL TRIP P Continue RIH 05:18 07:18 2.00 9,680 9,830 PROD3 DRILL DRLG P Drilling ahead, 1.4 BPM,3915 CTP, 4185 BHP. 16K RIW, 13K with 2K WOB. 07:18 10:12 2.90 9,830 9,830 PROD3 DRILL WPRT P Wiper to window, PUW=36K Clean trip up,Saw 9550 with setdown, Stacked with no setdown @ 9768 10:12 14:24 4.20 9,830 9,980 PROD3 DRILL DRLG P 9830', Drill Ahead 1.4 BPM @ 3892PS1 FS RIW=7.8K,WOB=2.3K, BHP=4150, WHP=85 14:24 16:24 2.00 9,980 7,670 PROD3 DRILL WPRT P 9980',Wiper to window PUW=32K BHP=422 with tie into RA marker Pull into cased hole to reroute hydraulic hose 16:24 16:36 0.20 7,670 7,691 PROD3 DRILL DLOG P Tie into RA for+1.5'correction, RIH to drill 16:36 17:48 1.20 7,691 9,980 PROD3 DRILL WPRT P Continue wiper trip to bottom 17:48 19:42 1.90 9,980 10,114 PROD3 DRILL DRLG P Drilling ahead, 1.4 BPM,4000 CTP, 4200 BHP with 150 WHP. Hit what appears to be ankerite @ 10110'and having trouble maintaining motor&WOB work with negative surface weight. 19:42 21:54 2.20 10,114 10,114 PROD3 DRILL WPRT P Wiper to window,29K PUW 21:54 00:00 2.10 10,114 10,146 PROD3 DRILL DRLG P Drilling ahead, 1.4 BPM,4050 CTP, 4200 BHP with 100 WHP. 03/29/2011 Drill Lateral 00:00 03:15 3.25 10,146 10,170 PROD3 DRILL DRLG P Drilling ahead, 1.4 BPM,4050 CTP, 4200 BHP with 100 WHP. 03:15 07:30 4.25 10,170 10,224 PROD3 DRILL DRLG P BHA Wiper, Stacking weight, PUW=35K 1.4 BPM @ 3950 PSI FS BHP=4220 Continue Drilling 07:30 07:54 0.40 10,224 10,224 PROD3 DRILL WPRT P 200'wiper to clear BHA 07:54 08:48 0.90 10,224 10,270 PROD3 DRILL DRLG P 10224'Drill Ahead, 1.36 BPM @ 3960 PSI 08:48 11:48 3.00 10,270 10,270 PROD3 DRILL WPRT P Wiper to window, PUW=36K Page 20 of 39 Time Logs _> Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:48 14:12 2.40 10,270 10,375 PROD3 DRILL DRLG P Continue drilling, 1.4 BPM,4000 CTP,4250 BHP with 50 WHP, 13K RIW,5-10K Surface weight with 2-3K WOB 14:12 14:30 0.30 10,375 10,375 PROD3 DRILL WPRT P Stacking surface weight,200'wiper. 32K PUW 14:30 15:30 1.00 10,375 10,420 PROD3 DRILL DRLG P Continue drilling ahead, 1.4 BPM, 4000 CTP,4230 BHP,40 WHP,Zero surface weight with 2K WOB 15:30 19:00 3.50 10,420 10,420 PROD3 DRILL WPRT P Wiper trip to the window, 32K PUW 19:00 21:42 2.70 10,420 10,570 PROD3 DRILL DRLG P Continue drilling ahead, 1.4 BPM, 4000 CTP,4230 BHP,40 WHP,-2K surface weight with 2.5K WOB 21:42 00:00 2.30 10,570 10,570 PROD3 DRILL WPRT P Wiper trip to the window,32K PUW, weight bobbles seen at 9550 and 10170'. Did not pick up. Pop through minimum rate. 03/30/2011 TD Lateral 10920'. Pump sweeps,Wiper trip to swab valves. 00:00 03:00 3.00 10,570 10,686 PROD3 DRILL DRLG P Continue drilling ahead, 1.4 BPM, 4000 CTP,4260 BHP,40 WHP,-2K surface weight with 2.5K WOB. Start stacking without weight transfer. Pull wiper trip 03:00 04:00 1.00 10,686 10,686 PROD3 DRILL WPRT P Wiper trip to 10000'. RIH to drill 04:00 04:06 0.10 10,686 10,686 PROD3 DRILL DRLG P Stacking, minimal WOB.0 diff psi. Seems to be in lock up.Wiper trip to 5700'.Call town for discussion on plan forward 04:06 10:06 6.00 10,686 10,686 PROD3 DRILL WPRT P Wiper trip to 5700'. Tie-in, +1.5'. Wiper trip back to bottom. Clean trip both ways. Swap mud while RIH 10:06 12:06 2.00 10,686 10,789 PROD3 DRILL DRLG P Drilling, 1.4 BPM,4100 CTP,4278 BHP with WOC,5-10K Surface weight with 1-2K WOB 12:06 16:42 4.60 10,789 10,789 PROD3 DRILL WPRT P Wiper trip,started stacking weight with no WOB or motor work, 32K PUW. Had trouble getting past 9550'. 16:42 18:27 1.75 10,789 10,872 PROD3 DRILL DRLG P Drilling, 1.4 BPM,4140 CTP,4280 BHP with WOC, 5-10K Surface weight with 1-2K WOB 18:27 18:57 0.50 10,872 10,872 PROD3 DRILL WPRT P Stacking out, no diff psi or WOB. PUH pump low/high vis sweeps,try to drill slow.-6-7K CTW. Minimal WOB,When sweeps get around ROP increases with 4-5K CTW, 1.5K WOB. 18:57 20:45 1.80 10,872 10,920 PROD3 DRILL DRLG P Drill Ahead, pump low/high vis sweeps, cont drilling. 20:45 00:00 3.25 10,920 10,919 PROD3 DRILL WPRT P TD well,pumped low high sweeps. POOH to swab valves 03/31/2011 Complete conditioning hole. PU/MU Liner segement#1 (44jnts), RIH releasing on bottom 10917',TOL 9480'. POOH 00:00 02:00 2.00 10,919 0 PROD3 DRILL WPRT P Tag up. Reset depth. Page 21 of 39 Time Logs Date From To Dur S. Depth E, Depth Phase Code Subcode T Comment 02:00 03:45 1.75 0 7,100 PROD3 DRILL WPRT P Open EDC RIH 03:45 04:00 0.25 7,100 7,100 PROD3 DRILL DLOG P Tie in depth with Gamma-13' correction 04:00 06:00 2.00 7,100 10,917 PROD3 DRILL WPRT P RIH 06:00 09:30 3.50 10,917 0 PROD3 DRILL DISP P Lay in liner running pill, 12.0 PPG with beads and 12.0 brine from window. Paint EOP flags at 9300' and 6100' 09:30 09:54 0.40 0 0 PROD3 DRILL SFTY P PJSM while monitoring well for no-flow 09:54 11:00 1.10 0 0 PROD3 DRILL PULD P Lay down drilling BHA,flush and blow down coil-trac tools 11:00 16:00 5.00 0 1,482 COMPZ CASING PUTB P MU 44 Joints tubing and coiltrac tools. Safety joint drill. Strip on well. 16:00 18:30 2.50 1,482 7,592 COMPZ CASING RUNL P RIH 18:30 18:45 0.25 7,592 7,581 COMPZ CASING RUNL P Tie in depth to EOP flag-10.74' correction 18:45 19:45 1.00 7,581 10,917 COMPZ CASING RUNL P RIH to TD, PUW 30K at window 19:45 20:00 0.25 10,917 10,917 COMPZ CASING RUNL P Tag TD 1.5-2K WOB,Stack 1.5K more WOB, Online with pumps, 4500 psi, 1.43 BPM, PUH releasing from liner,WOB 0.TOL=9480' calculated 20:00 22:30 2.50 10,917 0 COMPZ CASING RUNL P POOH 22:30 23:30 1.00 0 0 COMPZ CASING PUTB P PJSM, LD BHA 23:30 00:00 0.50 0 0 COMPZ CASING PUTB P Prep floor for liner PU 04/01/2011 PU 4 jnts for liner segment#2 with OH anchored billet. RIH setting on depth 9479'.5,TOB=9327.8'. POOH. PU BHA#18, 1.1 deg motor. RIH tag billet 9327.9'.Sidetrack AL1-01 lateral. 00:00 01:00 1.00 0 0 COMPZ CASING PUTB P PU/MU 2nd segment liner with OH anchored billet 01:00 02:30 1.50 212 6,324 COMPZ CASING RUNL P RIH 02:30 02:45 0.25 6,324 6,311 COMPZ CASING RUNL P Tie in depth with EOP flag,-12' 02:45 03:45 1.00 6,311 9,480 COMPZ CASING RUNL P RIH 03:45 04:00 0.25 9,480 9,470 COMPZ CASING WPST P Tag TOL 9479'3K WOB, PU 1.5K WOB.Online with pumps setting anchor.At 4000psi, PUH, 29K,WOB drop off.Good set 04:00 06:24 2.40 9,470 0 COMPZ CASING RUNL P POOH 06:24 06:42 0.30 0 0 COMPZ CASING SFTY P PJSM,flow check well 06:42 08:24 1.70 0 0 COMPZ CASING PUTB P Lay down liner running BHA 08:24 09:54 1.50 0 0 PROD4 DRILL BOPE P Function test BOP 09:54 10:12 0.30 0 0 PROD4 STK SFTY P PJSM 10:12 11:42 1.50 0 0 PROD4 STK PULD P PU drilling BHA#18, 1.1 deg motor. Tested tools and found lower half of tool to be non-functional. Lay down BHA, change out components, PU and start over. Page 22 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:42 13:12 1.50 0 0 PROD4 STK PULD T BHA not functioning 13:12 14:42 1.50 0 7,160 PROD4 STK TRIP P RIH 14:42 15:00 0.30 7,160 7,190 PROD4 STK DLOG P Tie-in,-9' 15:00 16:30 1.50 7,190 9,328 PROD4 STK TRIP P Continue RIH, spacer and flo-pro down coil,stop at 9300'and start cuirculating in flo-pro while POOH 16:30 17:15 0.75 9,328 9,329 PROD4 STK KOST P Tag billet at 9327.8' and start time milling @ 1 FPH 1.3 BPM, 3800 CTP,4100 BHP 17:15 21:30 4.25 9,329 9,333 PROD4 STK KOST P Stalling slip sticking, Increase ROP 1.5 FPH 2.3K WOB, 21:30 21:45 0.25 9,333 9,333 PROD4 STK KOST P Increase ROP.5 FPH stall. 21:45 22:00 0.25 9,333 9,337 PROD4 DRILL DRLG P Drill ahead 10 FPH. 22:00 23:30 1.50 9,337 9,338 PROD4 DRILL DRLG P Hard Stall, PU slowly time drill past 1 FPH. Looked good seen nothing. 23:30 00:00 0.50 9,338 9,360 PROD4 DRILL DRLG P Drill Ahead 1.3 BPM in and out. 14K CTW, 1.4 WOB,4000 CTP,4109 BHP. 04/02/2011 Drill AL1-01 Lateral. 00:00 02:00 2.00 9,360 9,480 PROD4 DRILL WPRT P Wiper trip to window 32K PUW 02:00 04:45 2.75 9,480 9,510 PROD4 DRILL DRLG P Drill Ahead, 1.3 BPM in and out, 3892 CTP,4130 BHP, 13K CTW, 1-2K WOB 04:45 13:45 9.00 9,510 9,624 PROD4 DRILL DRLG P Lots of stalls and stacking weight. After logging realized it was not all ankerite,silt/clay at base of A5? Pump 20 Bbls sweep with 3% drill-zone to attempt to clean up bit. Definite improvement in ROP. 13:45 16:21 2.60 9,624 9,624 PROD4 DRILL WPRT P Wiper trip,31K PUW 16:21 18:51 2.50 9,624 9,687 PROD4 DRILL DRLG P Contiue drilling, 1.3BPM,4000 CTP, 4165 BHP, Still very slow ROP. Pump another 20 Bbls.3%drill-zone 18:51 19:06 0.25 9,687 9,687 PROD4 DRILL WPRT P Stack out. BHA wiper, pump 5 bbrls drill zone. 19:06 21:36 2.50 9,687 9,775 PROD4 DRILL DRLG P Continue drilling, 1.3BPM,4000 CTP,4165 BHP, Still very slow ROP. Pump 5bbrls Drill Zone. 21:36 00:00 2.40 9,775 9,775 PROD4 DRILL WPRT P Wiper trip to window,35K PUW,tie in depth to RA marker+2'. 04/03/2011 Drill AL1-01 lateral to TD 10352.5'.Condition hole. 00:00 03:00 3.00 9,775 9,925 PROD4 DRILL DRLG P Drill Ahead 1.3 in/out, 13K CTW, 4050 CTP,4153 BHP 03:00 06:00 3.00 9,925 9,925 PROD4 DRILL WPRT P Wiper Trip to window 33K PUW 06:00 09:12 3.20 9,925 10,075 PROD4 DRILL DRLG P Continue drilling,1.3 BPM,4160 CTP,4175 BHP. Swapped mud., 1.35BPM,3900 CTP 09:12 12:00 2.80 10,075 10,075 PROD4 DRILL WPRT P Wiper trip to window,30K PUW. 9600'area had some set downs and motor work on trip inhole Page 23 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12:00 15:42 3.70 10,075 10,225 PROD4 DRILL DRLG P Continue drilling, 1.35 BPM,4000 CTP,4200 BHP,7-10K Surface weight with 1-3K WOB 15:42 17:30 1.80 10,225 7,670 PROD4 DRILL WPRT P Wiper to the window,31K PUW. Pulling at 10 FPM from 9690'to 9575'lots of motor work with minimal overpulls. 17:30 17:45 0.25 7,670 7,670 PROD4 DRILL DLOG P Tie-in,+3' 17:45 19:15 1.50 7,670 10,225 PROD4 DRILL WPRT P RIH 19:15 20:00 0.75 10,225 10,281 PROD4 DRILL DRLG P Continue drilling, 1.35 BPM,4000 CTP,4200 BHP,7-10K Surface weight with 1-3K WOB 20:00 20:15 0.25 10,281 10,281 PROD4 DRILL WPRT P BHA Wiper 31K PUW 20:15 22:15 2.00 10,281 10,322 PROD4 DRILL DRLG P Drill ahead, stacking no WOB. PUH to get drilling. 22:15 22:45 0.50 10,322 10,353 PROD4 DRILL DRLG P Pump sweeps trying to drill,stacking -10K CTW,minimal WOB 22:45 23:30 0.75 10,353 10,353 PROD4 DRILL WPRT P TD lateral, pump low/high sweeps, 23:30 23:45 0.25 10,353 9,648 PROD4 DRILL WPRT P POOH 23:45 00:00 0.25 9,645 9,645 PROD4 DRILL WPRT T Stuck 9645', RIH-10K, PU max 50K. No luck. Losing returns.Cont.trying to get free,orienting in neutral wt. 04/04/2011 Condition AL1-01 lateral. PU/MU Liner#1, RIH setting on bottom 10350'.TOL 9150', POOH 00:00 00:15 0.25 9,645 9,645 PROD4 DRILL WPRT T Offline with pumps, Ann.psi and bore psi equalize. PU,CT free. 00:15 04:00 3.75 9,645 0 PROD4 DRILL WPRT P Cont. POOH to swabs 04:00 05:42 1.70 0 7,150 PROD4 DRILL WPRT P RBIH 05:42 06:00 0.30 7,150 7,190 PROD4 DRILL DLOG P Tie-in,-12' 06:00 07:48 1.80 7,190 10,352 PROD4 DRILL WPRT P Continue RIH,stacking weight and pulling heavy at 7722', 7740',7745'. final attempt going down was clean. Continue RIH 07:48 11:12 3.40 10,352 0 PROD4 DRILL CIRC P POOH laying in 12.0 PPG liner running pill to window and 12.0 PPG brine to surface, Paint flags at 9000' and 6300'EOP 11:12 12:12 1.00 0 0 PROD4 DRILL PULD P Lay down drilling BHA 12:12 13:06 0.90 0 0 COMPZ CASING PUTB P Rig up for liner operations 13:06 13:24 0.30 0 0 COMPZ CASING SFTY P PJSM 13:24 15:18 1.90 0 1,246 COMPZ CASING PUTB P PU liner string and inteq BHA 15:18 15:54 0.60 1,246 1,246 COMPZ CASING SVRG P Maintenance on injector 15:54 17:24 1.50 1,246 7,500 COMPZ CASING RUNL P RIH,-10.5'correction to EOP flag 17:24 18:24 1.00 7,650 7,760 COMPZ CASING RUNL P Tag up in window. PUH 4th time get through window. PUH 26 times 40K CTW, RIW 0.7760' 18:24 19:09 0.75 7,760 8,860 COMPZ CASING RUNL P Push liner to bottom, RIW 19K,Tag up,work liner down PU/RIH 11 times,0-45K CTW Page 24 of 39 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 19:09 20:09 1.00 8,860 8,860 COMPZ CASING RUNL P Pop free, Push liner down to bottom, 16K RIW 20:09 20:24 0.25 8,860 10,350 COMPZ CASING RUNL P Tag TD 10352'. Set down 2K WOB, Online with pumps 4400psi CTP. PU 30K CTW,-1 K WOB. Liner released. Swap to pump across top. Bottom liner 10350'.TOL 9150' 20:24 21:09 0.75 10,325 7,135 COMPZ CASING RUNL P POOH, Pull heavy 8867',8891', 8950',9340',7759-7639' 21:09 21:24 0.25 7,135 7,135 COMPZ CASING RUNL P Tie in depth to K1,-0.75' 21:24 23:09 1.75 7,135 0 COMPZ CASING RUNL P POOH 23:09 23:24 0.25 0 0 COMPZ CASING OWFF P Flow check, PJSM 23:24 00:00 0.60 0 0 COMPZ CASING PUTB P LD tools 04/05/2011 Set AL1-01 Liner from 9151'-7644', P/U&set TOWS @ 7564'20 left of HS. P/U 2.80"window Milling assembly-dry tag @ 7567.8'. Start milling from 7567.4',Window exit @ 7572'. 00:00 00:30 0.50 0 0 COMPZ CASING PUTB P Prepare to run liner 00:30 03:18 2.80 0 0 COMPZ CASING PUTB P PU/MU liner#2 03:18 05:30 2.20 0 7,185 COMPZ CASING RUNL P RIH,correct at flag-10',Weight check 30K PUW,20K RIW 05:30 05:45 0.25 7,185 9,150 COMPZ CASING RUNL P Landed liner at 9150', Release from liner 05:45 08:15 2.50 9,150 0 COMPZ CASING RUNL P POOH 08:15 08:30 0.25 0 0 PROD5 RPEQP1OWFF P Flow check, PJSM 08:30 09:30 1.00 0 0 PRODS RPEQP1PULD P LD BHA 20, PU BHA 21, (whipstock #2) 09:30 11:00 1.50 0 7,185 PROD5 RPEQPITRIP P RIH 11:00 11:15 0.25 7,185 7,185 PRODS RPEQP1DLOG P Tie in depth to K1,-11'correction 11:15 11:30 0.25 7,185 7,577 PRODS RPEQP1WPST P Close EDC,set whipstock 20L HS, 7576.98'MD, 7564'TOWS set at=2450psi,4K WOB, 11:30 13:15 1.75 7,577 0 PRODS RPEQP1TRIP P POOH,29K PUW 13:15 13:30 0.25 0 0 PRODS RPEQP1OWFF P Flow check, PJSM 13:30 14:15 0.75 0 0 PROD5 RPEQP1PULD P LD BHA 21. 14:15 15:00 0.75 0 73 PRODS WHPST PULD P PU BHA 22, (.6 AKO with 2.8" window mill and string remeamer) 15:00 18:00 3.00 73 7,200 PROD5 WHPST TRIP P RIH BHA No.22 displacing coil first with 15-bbl viscosified FW spacer (8%KCI,2%KlaStop),then to previously used mud system for window milling. At 5589', open EDC and pick up rate,timing out milling fluid to reach BHA just above whipstock. Line up to recover KWF in reserve pits. 18:00 18:06 0.10 7,200 7,567 PRODS WHPST DLOG P Tie in with-12. Page 25 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:06 23:00 4.90 7,567 7,571 PROD5 WHPST MILL P Dry tag TOWS 7567', P/U weight 31K.Start time milling-7567.7'. 1.35 bpm,3740, BHP 3890,WOB.4, Ct weight 17k, ROP 1 FPH.Good metal returns in samples. hard time drilling off @ 7571.4'WOB 2.8K, no motor work. 23:00 00:00 1.00 7,571 7,572 PRODS WHPST MILL P P/U weight 31K. Back to smooth milling-1.35 bpm, 3750, BHP 3870, ROP 1-2 fph,WOB 1.5,CT weight 16.8K. Exit window @ 7572.4' 04/06/2011 Complete window TOWS-7563',TOW 7567', BOW 7572'. P/U lateral BHA with 2.1 AKO&2.7"Bi-center. Drill build section. 00:00 04:00 4.00 7,572 7,582 PROD5 WHPST MILL P Continue milling formation as per procedure @ 2fph. Start mud swap 5ft into formation&increase to 4 fph. 04:00 06:00 2.00 7,582 2,200 PROD5 WHPST TRIP P Backreaming passes, clean. Dry tag -clean-Open EDC&POOH following MPD. 06:00 06:45 0.75 2,200 0 PROD5 WHPST TRIP P Continue POOH conditioning hole to new 9.6#FloPro mud system. 06:45 07:00 0.25 0 139 PROD5 WHPST SFTY P At surface. Conduct pressure un-deploy safety meeting. 07:00 08:45 1.75 0 0 PRODS WHPST PULD P Pressure un-deploy window milling BHA(BHA#22). Laydown tools. 08:45 09:45 1.00 0 139 PROD5 DRILL PULD P Pick up build-section drilling BHA (BHA#23). Begin pressure deploy build-section drilling BHA. 09:45 10:15 0.50 139 139 PRODS DRILL SVRG P Perform injector maintenance. Change out BHI check valves. 10:15 11:00 0.75 139 139 PROD5 DRILL PULD P Continue pressure deploy build-section drilling BHA. 11:00 12:30 1.50 139 7,163 PRODS DRILL TRIP P RIH BHA#23 following MPD tripping schedule. 12:30 12:45 0.25 7,163 7,177 PRODS DRILL DLOG P Tie-in gamma. -12'correction. Close EDC. 12:45 13:00 0.25 7,177 7,582 PROD5 DRILL TRIP P RIH. 13:00 17:00 4.00 7,582 7,740 PROD5 DRILL DRLG P Begin drilling build 1.38-bpm; 4100-psi CTP; 0-psi WHP; 15k# RIW; 1.3k#WOB;3931-psi ANN; 4590-psi BORE;659-psi Diff. 17:00 18:30 1.50 7,740 7,740 PRODS DRILL DLOG P Logged K1 marker. Logged RA tag- TOWS 7563',TOW 7567', BOW 7572', RA tag 7570.5' 18:30 22:00 3.50 7,740 7,890 PRODS DRILL DRLG P Continue drilling ahead-1.30 bpm, 3900, BHP 3965, ROP 40,WOB 1.35K,Ct weight 18K, ECD 12.0 22:00 22:30 0.50 7,890 7,890 PROD5 DRILL WPRT P Wiper trip-P/U weight 31K 22:30 00:00 1.50 7,890 7,979 PRODS DRILL DRLG P Drilling ahead 1.35 bpm, 3910, BHP 3970, ECD 12, ROP 40,WOB 1.8K. 04/07/2011 Completed Build section @ 8148'. P/U 1st RSM tool @ surface, P/U 2nd RSM-passed. RIH and difficult time through build section with 3 set downs.Wipe from TD,second pass was clean. Drill ahead. 00:00 02:00 2.00 7,979 8,040 PROD5 DRILL DRLG P Continue drilling ahead build section. 02:00 02:30 0.50 8,040 8,040 PROD5 DRILL WPRT P Wipertrip 31K Page 26 of 39 Time Logs Date; From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:30 06:00 3.50 8,040 8,148 PROD5 DRILL DRLG P Drilling ahead-1.35 bpm, 3900, BHP 3982, ECD 12, ROP 30,WOB 2K. 06:00 08:45 2.75 8,148 56 PROD5 DRILL TRIP P TD build section and trip out of hole for lateral drilling BHA. 08:45 09:00 0.25 56 56 PROD5 DRILL SFTY P Conduct Safety Meeting for pressure un-deploy operations. 09:00 10:15 1.25 56 0 PROD5 DRILL PULD P Pressure un-deploy and LD BHA #23. 10:15 11:00 0.75 0 0 PROD5 DRILL PULD P Pick up and prepare to pressure deploy lateral drilling BHA. 11:00 11:30 0.50 0 0 PROD5 DRILL SVRG P Perform injector maintenance. 11:30 11:45 0.25 0 0 PRODS DRILL SFTY P Conduct safety meeting for pressure deploy operations. 11:45 12:15 0.50 0 0 PROD5 DRILL PULD P Pressure deploy BHA No.24 and surface test tools. 12:15 12:30 0.25 0 0 PROD5 DRILL PULD T Checking tools. Unable to establish telemetry with RSM in BHA. All other tools checking out. 12:30 12:45 0.25 0 0 PROD5 DRILL SFTY T Conduct safety meeting(change of scope)to pressure un-deploy tools. 12:45 14:45 2.00 0 0 PROD5 DRILL PULD T Pressure un-deploy tools to troubleshoot telemetry issue. Swap RSMs the other one on location. Pressure deploy BHA No.24. Surface test tools: all good. 14:45 16:30 1.75 0 7,150 PRODS DRILL TRIP P RIH BHA No.24. 16:30 16:45 0.25 7,150 7,179 PROD5 DRILL DLOG P Tie-in to gamma.-12'correction. 16:45 17:45 1.00 7,179 8,148 PROD5 DRILL TRIP P RIH to bottom. Stacked weight(5k#) at 7580'and 7633'RIH at 35-fpm. Ran back down through and saw only 500#bobble. reached TD& wiped back to window-clean pass second time. 17:45 20:45 3.00 8,148 8,310 PROD5 DRILL DRLG P Drill ahead lateral 20:45 21:45 1.00 8,310 8,310 PROD5 DRILL WPRT P Wiper trip-P/U weight 29K 21:45 00:00 2.25 8,310 8,456 PROD5 DRILL DRLG P Drilling ahead-1.35 bpm,4000, BHP 4060, ECD 12.3, ROP 80,WOB 1.7K, CT weight 15K. 04/08/2011 Continue drilling ahead AL2 lateral with RSM. Lower pump rates during wiper trip through troubles section from 8020'-7990'. 00:00 00:15 0.25 8,456 8,460 PROD5 DRILL DRLG P Drilling ahead 00:15 02:15 2.00 8,460 8,460 PROD5 DRILL WPRT P Wiper trip P/U Weight 30K. Pulled heavy with motor work @ 7995'RIH- clean second pass through area. Wipe up into cased hole.-1 ft correction,small set down @ 7580'- clean through build section. 02:15 06:00 3.75 8,460 8,550 PROD5 DRILL DRLG P Drilling ahead-1.35 bpm,3980, BHP 4050, ECD 12.3, ROP 15,WOB 2K, CT weight 15K.CLeaning pits for mud swap. Page 27 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 07:15 1.25 8,550 8,610 PROD5 DRILL DRLG P Drilling ahead: 1.36 bpm;3900 CTP; 0-psi WHP;3956 ANN; 4423 BORE; 692 DIFF; ECD 12.3; 50-fph ROP; 2k WOB; 14.8k RIW. Swap to new drilling mud. 07:15 08:30 1.25 8,610 8,610 PROD5 DRILL WPRT P Perform wiper trip(1). 29k#off bottom. 08:30 11:30 3.00 8,610 8,760 PROD5 DRILL DRLG P Drilling ahead: 1.36 bpm;3900 CTP; 50-psi WHP;4050 ANN; 4627 BORE; 561 DIFF; ECD 12.3; 20-fph ROP; 1.9k WOB; 13.9k RIW. **Note: Received call back from AOGCC regarding BOPE test 24-hr notification. At 09:28a.m., Chuck Sheve waived BOPE test witness for tomorrow.** 11:30 13:00 1.50 8,760 8,760 PROD5 DRILL WPRT P Perform wiper trip(2). 29k#off bottom. Pulled tight through 7995' and saw weight bobble back down through 7995'-8000'. 13:00 15:15 2.25 8,760 8,910 PROD5 DRILL DRLG P Drilling ahead: 1.34 bpm;3850 CTP; 45-psi WHP;4000 ANN; 4650 BORE;500 DIFF; ECD 12.2; 55-fph ROP; 1.5k WOB; 14.8k RIW. 15:15 18:00 2.75 8,910 8,910 PROD5 DRILL WPRT P Perform wiper trip(3)with tie-in. (+1' correction). 31 k#off bottom. Pulled up heavy again through 8000'. 18:00 20:00 2.00 8,910 9,060 PROD5 DRILL DRLG P Drilling ahead 20:00 22:00 2.00 9,060 9,060 PROD5 DRILL WPRT P Wiper trip P/U weight 31K,reduced pump rate from 8050-7980', clean. 22:00 00:00 2.00 9,060 9,188 PROD5 DRILL DRLG P Drilling ahead-1.40 bpm,4050, BHP 4100, ECD 12.4, ROP 60,WOB 2K, Ct weight 14K. 04/09/2011 Drilling ahead-crossed fault @ 9250'had 3 stalls while crossing fault. Drilled ahead to 9520'POOH for BOPE Test. losses for 24 hours=23 bbls. Braised bit had zero plugged nozzles. 00:00 00:30 0.50 9,188 9,210 PROD5 DRILL DRLG P Drilling ahead 00:30 02:30 2.00 9,210 9,210 PROD5 DRILL WPRT P Wiper trip P/U weight 31K. Lower rate through troubles section.Clean through build. 02:30 04:00 1.50 9,210 9,251 PROD5 DRILL DRLG P Drilling ahead-Slow ROP then Stall @ 9251'-P/U heavy,work pipe a few times, P/U 34K 100ft-clean weights.Stacked/Stall out early 9250'P/U weight 35K.Slowly work down without ribs.Ankerite in samples. 04:00 07:45 3.75 9,251 9,360 PRODS DRILL DRLG P Drill ahead-ROP 12 fph/fault crossed @ 9250'. Slight fluid losses after fault. 1-2 bbls/hour. 07:45 10:15 2.50 9,360 9,360 PROD5 DRILL WPRT P Perform wiper trip(3)with tie-in up to 7606'. (Correction+1.5'). Page 28 of 39 Time Logs Date From To Dur S. Death E. Death Phase Code Subcode T Comment 10:15 13:15 3.00 9,360 9,520 PROD5 DRILL DRLG P Drill ahead. ROP 50-fph; 1.33-bpm; 3900-psi CTP;24-psi WHP; 1.17k# WOB; 15.6k#RIW;4100-psi ANN; 4668-psi BORE; 559-psi DIFF. Pump 5-bbl each low-then high-visc pills around for sweep OOH for BOPE testing. 13:15 17:45 4.50 9,520 68 PRODS DRILL TRIP P POOH for BOPE testing. Pulled 31k#off bottom.Additional cutting over shaker near surface. 17:45 18:45 1.00 68 68 PROD5 DRILL SFTY P Crew change&PJSM for undeploying BHA 18:45 20:15 1.50 68 0 PROD5 DRILL PULD P Undeploy BHA with RSM. Bit had zero plugged nozzles&1:1 grade. RSM directional pads are sticking at surface,take out of service. 20:15 22:15 2.00 0 0 PRODS DRILL RGRP P Lay down BHA,Grease tree&stack, service injector. Continue with MPD. 22:15 22:45 0.50 0 0 PRODS DRILL CIRC P Flush CT&Stack with fresh water. More cement cuttings, rust, formation cuttings&dirty returns prior to the end of flushing the lines. 22:45 00:00 1.25 0 0 PROD5 DRILL BOPE P Start BOPE testing.***Waived by Chuck Scheve*** 04/10/2011 Finished testing BOPE. PU Lateral Drilling BHA#25 with bi-center bit and 0.9 AKO motor. Drilling ahead as planned. 00:00 08:00 8.00 0 0 PROD5 DRILL BOPE P Continue with BOPE test 250/3500 psi.C-9&10 failed, replaced, passed. ***BOPE Test finished at 08:00****. Serviced connections on the injector riser. 08:00 08:30 0.50 0 0 PRODS DRILL DISP P Displaced coil from water back over to drilling fluid(9.6 ppg Flo Pro). 08:30 08:45 0.25 0 0 PRODS DRILL SFTY P Held PJSM for picking up the BHA and pressure deploying. 08:45 10:45 2.00 0 0 PROD5 DRILL PULD P Installed UQC and LQC. PU and MU BHA#25-Lateral drilling assembly with 0.9 AKO and re-run bi-center bit. (Same bit as on BHA #24-HCC with 1 port plugged off.) Began pressure deploying. 10:45 11:30 0.75 0 0 PROD5 DRILL PULD P Moved injector cart over hole and stabbed on coil. 11:30 13:15 1.75 0 7,157 PRODS DRILL TRIP P RIH 13:15 13:30 0.25 7,157 7,157 PRODS DRILL DLOG P Tie-in at 7157'for a correction of -11.5'. PU weight=29k. 13:30 14:30 1.00 7,157 9,259 PRODS DRILL TRIP P Close EDC and continue to RIH. Window was clean when passing through. Areas at 7580'and 7996' were clean as well. 14:30 14:45 0.25 9,259 9,520 PRODS DRILL TRIP P Stacked out at 9259'. PU,adjusted TF. Tagged up again. Reduced pump rates and passed through. Trouble area looked to be from 9259' through 9275'. Continued to bottom. Tagged TD at 9520'. Page 29 of 39 Time Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 14:45 17:45 3.00 9,520 9,670 PROD5 DRILL DRLG P Begin drilling. WOB=1.3 klbf, ROP=60 fph, Rate in=1.3 bpm,Ann Press=4172 psi, Bore Press=4772 psi, ECD= 12.68 ppg. Hit a hard spot at 9641'. Appears to be ankerite. 17:45 20:15 2.50 9,670 9,670 PROD5 DRILL WPRT P Wiper trip-32K,tried to pull through 7995'at normal rate but had overpull -RIH,lower rate, came through smooth.Clean RIH with lower rate. 20:15 22:45 2.50 9,670 9,820 PROD5 DRILL DRLG P Drilling ahead-1.35 bpm,3800, BHP 4130, ECD 12.5, ROP 70,WOB 1.6K,CT weight 14K. 22:45 00:00 1.25 9,820 9,820 PROD5 DRILL WPRT P Wiper trip 33K off bottom. Slowed pump rate through trouble sections. 04/11/2011 Drilling ahead as planned.TD lateral @ 10,270'Wiper trip to surface pumping sweep @ window. Increase in cuttings during B/U. RIH to displace to KWF. 00:00 01:30 1.50 9,820 9,820 PROD5 DRILL WPRT P Continue with wiper trip-slow pump rates for troubled sections. 01:30 05:00 3.50 9,820 9,970 PRODS DRILL DRLG P Drilling ahead-1.35 bpm, Pump pressure 4050, BHP 4200, ECD 12.7, ROP 75,WOB 1.8K,CT weight 12.5K 05:00 06:30 1.50 9,970 7,592 PROD5 DRILL WPRT P Wiper trip-33K off bottom 06:30 06:39 0.15 7,592 7,592 PRODS DRILL DLOG P Tie-in fora+4'correction. 06:39 08:09 1.50 7,592 9,970 PROD5 DRILL WPRT P RBIH. Free spin=3850 psi. Tagged bottom at 9973'. 08:09 10:09 2.00 9,970 10,120 PRODS DRILL DRLG P Drilled ahead from 9973'to 10120'. (1.34 bpm, Bore 4860, BHP 4240, ECD 12.8, ROP 75,WOB 1.6K,CT weight 10K.) Pumped a 5 bbl low vis pill followed by a 5 bbl high vis pill prior to tripping. 10:09 12:39 2.50 10,120 7,000 PRODS DRILL WPRT P Performed wiper trip up into the 5.5" casing. No changes in returns noticed at the shakers. 12:39 14:09 1.50 7,000 10,120 PRODS DRILL WPRT P Ran back to bottom. Slight bobble right outside of the window at 7571'. All other previous trouble areas looked clean. 14:09 16:09 2.00 10,120 10,218 PRODS DRILL DRLG P Drilled ahead from 10120'to 10213' (1.33 bpm, Bore 4885, BHP 4220, ECD 12.8, ROP 86,WOB 1.8K,CT weight 11K.) Stacked out multiple times from 10213'to 10218'before finally working through. 16:09 16:39 0.50 10,218 10,250 PROD5 DRILL DRLG P Drilling ahead. 1.33 bpm, Bore 4890, BHP 4290, ECD 13.0, ROP 42,WOB 1.5k, CT 12k. 16:39 16:54 0.25 10,250 10,250 PRODS DRILL WPRT P Pulled BHA wiper from 10250'. PU weight=32K. Overpull at 10219'. Dropped pump rates through on way down. 16:54 17:24 0.50 10,250 10,270 PRODS DRILL DRLG P Pumped 10bbls each of hi and low vis pills before pulling wiper. Drilled to TD at 10270'. Page 30 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:24 22:24 5.00 10,270 90 PROD5 DRILL WPRT P Wiper trip to swab valves. P/U weight 33K off bottom. Pump additional sweep at window to chase out the cased hole. 30%cuttings increase in second sweep(shale cuttings). POOH.Surge of shale material near surface. Blow down choke. 22:24 00:00 1.60 90 7,600 PROD5 DRILL TRIP P RIH pumping. 7 bpm following MPD. +11 tie in. RIH&tie into pip tag. Zero correction RIH. 04/12/2011 Laid down BHA#25. PU and ran 1st liner segment for AL2 lateral. POOH with liner running tools. PU and ran 2nd liner segment for AL2 with anchored billet. BOL=10,260,TOL=8525'. In process of Laying down liner BHA. 00:00 02:00 2.00 7,600 10,270 PRODS DRILL TRIP P RIH to lay in liner pill&KWF.Clean through build&lateral.Tagged TD @ 10270'. Cycle pipe while pumping down Liner pill 02:00 06:00 4.00 10,270 0 PROD5 DRILL TRIP P POOH 45 fpm/.45 bpm pumping KWF liner pill followed by KWF. Flag pipe @ 8871 &6171. 06:00 06:15 0.25 0 0 PRODS DRILL SFTY P Safety Meeting for laying down BHA. 06:15 07:15 1.00 0 0 PRODS DRILL PULD P Lay down drilling BHA#25. Bit came out with no plugged nozzles. Graded a 1-2. 07:15 07:39 0.40 0 0 PRODS DRILL SVRG P Serviced the top drive and injector. 07:39 07:51 0.20 0 0 PROD5 DRILL SFTY P Safety Meeting for picking up liner. 07:51 09:15 1.40 0 1,407 COMPZ CASING PUTB P Picked up first liner segment (non-ported bullnose guide shoe,41 joints slotted liner,shorty deployment sleeve). Baker on location at 7:45. 09:15 12:45 3.50 1,407 10,271 COMPZ CASING TRIP P RIH pumping .3 bpm.-13ft correction. P/U weight 35K. RIH.Tag @ 7574'. P/U 33K-RIH more speed -Tag-work down past 7588',tag @ 8945'(BHA below window).Tag TD. 12:45 13:15 0.50 10,271 8,853 COMPZ CASING RCST P P/U weight-37K. up to 10,250, RIH to setting depth of 10,260'.WOB 4K, Start pumping 1.2 bpm,4100 psi, P/U weight 31K.Stop and reset counters&set up to pump down the backside while POOH. 13:15 15:45 2.50 8,853 44 COMPZ CASING TRIP P BOL= 10,260/TOL 8897'-POOH pumping down Backside.5 bpm up to 3.5".Tie in+4.5ft. POOH pumping KWF 15:45 16:45 1.00 44 0 COMPZ CASING PULD P Flow-check&PJSM. Lay down BHA 16:45 18:15 1.50 0 434 COMPZ CASING PUTB P P/U 11 joints of liner with ported nozzle&Anchored billet assembly. 18:15 20:30 2.25 434 8,900 COMPZ CASING TRIP P RIH W AL2 liner run#2, RIH to flag. Page 31 of 39 Time Logs Date From` To Dur S. Depth E. Depth Phase Code Subcode T Comment 20:30 21:00 0.50 8,900 8,900 COMPZ CASING RCST P -9.66 correction @ flag. Shut in EDC. Pick-up wt. 33k. RIH set anchor© 15 left.tag TOL @ 8900'. Pump down coil,shear @ 4200 psi&set anchor. clean pick off. 21:00 23:15 2.25 8,900 73 COMPZ CASING TRIP P POOH into the cased hole. Re-set bit depth, continue pooh keeping hole full of kill wt. 23:15 00:00 0.75 73 73 COMPZ CASING PULD P Bumped up. Flow check, conduct PJSM. Lay down BHA. 04/13/2011 Circulated out KWF to used Drilling mud. Had difficulty getting kicked off of billet due to lack of weight transfer on bit.Swapped to new drilling mud which improved weight transfer but was still having difficulties.Able to get kicked off the billet after pumping a pill of 776 lube. Drilled from 8529'to 8830'. Discovered 2 pin holes, one @ 8069'&7740'.Get pin holes to seal up on the reel and able to follow MPD tripping schedule. 00:00 01:15 1.25 72 PROD6 STK PULD P Continue laying down BHA#27. Pick-up BHA#28. 01:15 03:00 1.75 72 7,545 PROD6 STK TRIP P RIH W/drilling BHA. Send spacer pill down to get to nozzle at the window. Tie into formation 7160'to 7181'for -11.5 correction. Open EDC, RIH to just above the window. 03:00 04:30 1.50 7,545 7,545 PROD6 STK CIRC P Begin ciculating out KWF to used drilling mud for kick off. 04:30 04:45 0.25 7,545 8,529 PROD6 STK TRIP P RIH,dry tag TOB @ 8529' 04:45 06:45 2.00 8,528 8,529 PROD6 STK KOST P Start time milling billet @ 8528'- Stall slip stick from.5K to 3K @ 8529',off pumps, P/U weight 34K. WOB negative weight. 06:45 07:45 1.00 8,529 8,529 PROD6 STK KOST P Try to feather in&start again, no WOB transfer @ 8528'. No luck with different speeds. Stall with slip sticking. 07:45 09:45 2.00 8,529 8,528 PROD6 STK WPRT P P/U and wiper up&swap to new mud.Old mud has 1700'on system. New mud around system. better weight transfer-found TOB @ 8528' with 1.4K on bit. P/U weight 31K 09:45 10:45 1.00 8,528 8,528 PROD6 STK KOST P Start time milling again from 8528'. Slight motor work but no WOB.CT weight looks better, not getting it to BHA. No Al.shavings yet. P/U and hit it at a quicker speed. No luck, continue to stall 1/2 ft into it. 10:45 14:45 4.00 8,528 8,560 PROD6 STK KOST P Pump 20 bbls pill of 5%776 to slick it up. Much smoother WOB transfer, motor work @ 8527.8'. 1.35 bpm, 3870, BHP 3980, ECD 12.1, ROP 1 fph,WOB.8K,CT weight 17.5K. Start KOB procedure-Al.filings over shaker.Continue with KOB. 14:45 17:15 2.50 8,560 8,680 PROD6 DRILL DRLG P Dry run through billet-clean-Drill ahead 1.35 bpm, 3990, BHP 4030, ECD 12.3, ROP 30,WOB 1.8K, Ct weight 15K. 17:15 18:45 1.50 8,680 8,680 PROD6 DRILL WPRT P Wiper trip-P/U weight 32K Page 32 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:45 21:30 2.75 8,680 8,830 PROD6 DRILL DRLG P Drill ahead 1.35 BPM,3883, BHP 3997 21:30 22:00 0.50 8,830 8,069 PROD6 DRILL WPRT P Wiper trip, 30k clean pick-up. 22:00 22:30 0.50 8,069 7,740 PROD6 DRILL TRIP T Pin hole noticed between goose neck&reel. Shut down pump& bleed off coil. PUH slowly,get pin hole on the reel. Kick on pump, no leaks noticed. POOH slolwly @ min. rate. 22:30 00:00 1.50 7,740 7,000 PROD6 DRILL TRIP T Noticed a second pin hole between goose neck&reel. Shut down pump &bleed off coil. PUH slowly,get pin hole on the reel. Kick on pump, no leaks noticed. POOH slolwly @ min. rate.Able to pick-up rate to 1.33 @ 3440 psi, no leaks, no problem W/ Maintaining proper BHP. Continue POOH to surface. 04/14/2011 CT life 34%&627,000 running feet. Reel swap and skate change out in progress. 00:00 01:15 1.25 7,000 72 PROD6 DRILL TRIP T Continue Tripping out of the hole. 01:15 01:45 0.50 72 72 PROD6 DRILL TRIP T On surface. Conduct PJSM Prior to Pressure un-deploying.SLB has been called to dispatch out N2 unit to blow down the reel. 01:45 04:15 2.50 72 0 PROD6 DRILL PULD T Pressure undeploy BHA. 04:15 06:45 2.50 0 0 PROD6 DRILL PULD T Displace coil W/water&recover the drilling mud. SLB N2 unit on the way. 06:45 07:45 1.00 0 0 PROD6 DRILL CIRC T PJSM&purge CT string to TT,also blow down iron inside Sub structure while venting N2 to Tiger tank. 07:45 16:00 8.25 0 0 PROD6 DRILL RGRP T PJSM-Cut CT connector and unstab pipe, remove reel from iron. Pumping roughly 1/4 bbl hour down MPD Take off injector stripper to remove injector chains Set up slings&secure reel for swap. 16:00 00:00 8.00 0 0 PROD6 DRILL RGRP T Remove old reel on flat bed. line up truck with new reel. Continue working on the skates. 04/15/2011 Completed reel swap. Function tested BOP's. Pumped slack management. Cut 20'of coil to find end of the wire. 00:00 04:00 4.00 0 0 PROD6 DRILL RGRP T Continue with reel swap. 04:00 11:00 7.00 0 0 PROD6 DRILL RGRP T Stab pipe and start building pressure bulk head.***Weekly function test of BOP's*** 11:00 13:00 2.00 0 0 PROD6 DRILL RGRP T Clean up floor, close out LOTO on reel. Pre-tower meeting for crew change&PJSM for completing Bulk head instalation. Page 33 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 13:00 16:30 3.50 0 0 PROD6 DRILL RGRP T Cut&Mig cable, all testing good. Install boot on cable&line up fluid lines to pump warm sea water for slack mngt. Have pipe slip when attempting to pump slack mngt. 16:30 18:30 2.00 0 0 PROD6 DRILL RGRP T Pack off hoses reversed, pack-offs damaged by CT string when slack MNGT. Pull off well and start chasing pack-off chunks. 18:30 00:00 5.50 0 0 PROD6 DRILL RGRP T PJSM-crew change-Line up& pump slack mngt. Pump pressured up to 1000 psi. No fluid movement. Stab off&lower coil.Cut 15'of coil to see wire.cut 5'more get several feet of cable out. Check last 5'chunk of cut coil,find it was plugged up with stripping rubber. Pump thru coil conventional to the sump, good fluid movement. Rig back on the stack. Pump Slack mgnt. PT inner reel valve and hardline,good.Total of 30 ft cut. 04/16/2011 Completed Slack Mgmt. M/U CT Connector, Deploy Lateral drilling BHA#29, RIH and drill ahead 00:00 04:00 4.00 0 0 PROD6 DRILL RGRP T Install coil connector&Baker Inteq E-line head. PT CT. Displace out the water in the coil to the tiger tank. Fluid pack with drilling mud. Stab off, retract cart.Suck out stack&find another chunk of pack off rubber. 04:00 04:15 0.25 0 0 PROD6 DRILL SFTY T Conduct Pre-job for pressure deploy. 04:15 06:15 2.00 0 72 PROD6 DRILL PULD T Load up BHA in PDL. Pressure deploy by the check list. 06:15 07:15 1.00 72 72 PROD6 DRILL PULD T PJSM-complete deploying BHA with 1.0 AKO with 2.73"Razor bi-center. 07:15 10:30 3.25 72 7,646 PROD6 DRILL TRIP T RIH with EDC open pumping .7 bpm. Doing weight checks to inspect new pipe, inner reel iron&injector. Weight checks&pipe inspection looks good.Tie in+5.5 ft correction. P/U weight 31K. close EDC.Tie in at PIP tag with-1/2 ft correction. 10:30 11:30 1.00 7,646 8,500 PROD6 DRILL TRIP T Stacked out @ 7646'P/U weight 32K up to 7600'. RIH-Make an additional 5ft. P/U weight 35K.Wipe up to window.-RIH to 7660'-P/U clean- RIH-a couple of weight bobbles around 8010-8035'. 11:30 14:00 2.50 8,500 8,830 PROD6 DRILL WPRT P Wiper up to window prior to drilling ahead. Slow pump rate from 8060- 7970'as normal.Tight spot @ 7970'. had to work shale area from 8550- 8580'once we past the billet. Quick 300'wiper before drilling. Page 34 of 39 Time Logs Date From To Dur S.Depth E. Depth Phase° Code Subcode T Comment 14:00 20:00 6.00 8,830 8,980 PROD6 DRILL DRLG P Drilling ahead-1.40 bpm, 3800, BHP 4030, ECD 12.3, ROP 25,WOB 1.8K, CT weight 10K. 20:00 22:30 2.50 8,980 8,980 PROD6 DRILL WPRT P Wiper to window, PUW=32K 7970 to 8040 overpulls with stalls coming up. Needed to reduce pump rate coming up.Saw 7677 going down. 7970 to 8040 behaved @ 1 BPM RIH 22:30 00:00 1.50 8,980 9,006 PROD6 DRILL DRLG P 8980', Drill ahead 1.4 BPM @ 3940 PSI FS, BHP=4105 Midnight depth 9006 04/17/2011 Drilled from 9006 to 9358.Clean shales from well bore area 7950 to 8020 00:00 02:18 2.30 9,006 9,130 PROD6 DRILL DRLG P 9006', Drill Ahead from midnight depth 02:18 04:48 2.50 9,130 7,350 PROD6 DRILL WPRT T 9130,Wiper trip PUW=33K, Initial overpull @ 8042'36K work pipe,sticky,got packed off unable to RIH Problems until 7950. Pull up to TT to clean liner 04:48 06:03 1.25 7,350 7,350 PROD6 DRILL WPRT T Started packing off while pulling into TT @ 7320', 7310, 7292'.Work string in 5"5. 06:03 06:48 0.75 7,350 7,280 PROD6 DRILL WPRT T Pump Low/High sweep and cycle CT quicker in cased hole. Sweep pushed obstruction up hole, annular pressure dropped 150 psi.Wiped up to 7280'No over-pulls. RIH to 7525'. Clean pass back up. Seeing large shale chunks coming over the shaker. . 06:48 07:48 1.00 7,280 7,500 PROD6 DRILL WPRT T Pump additional sweep and clean tubing prior to RIH to condition build section. By-pass choke and blow out shale. RIH-tie into PIP tag.Trap pressure-hole is tight. 07:48 09:48 2.00 7,500 8,000 PROD6 DRILL WPRT T RIH slowly stacked @ 7604'-P/U weight 37K,work pipe. RIH to 7700- P/U weight 32K to window, RIH- 7800-P/U weight 31K,Swap to choke A due to plugging off during wiper. RIH-7930/P/U 31K. RIH- 8000'-Weight bobbles, P/U weight 33K, increase rate @ 7970'Annular rate higher-wipe to window. 09:48 10:48 1.00 8,000 8,500 PROD6 DRILL TRIP T RIH&stacked weight @ 8008'P/U 33K.to 7950' RIH.Weight bobble @ 8012', RIH to 8040'P/U 33K to 7950' -RIH to 8500'-clean, shale chunks to surface, small amount. Page 35 of 39 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 10:48 12:18 1.50 8,500 7,290 PROD6 DRILL WPRT T Wiper trip to 3.5"P/U weight 32K. Slowed rate through troubled section. Clean with a light overpull @ 7955'@ .5 bpm. Continue with wiper @ normal rate. Pump Low/High sweep at window.Wipe up to 3.5"-clean, No large shale particles in returns. 90%silt 10%sand. 12:18 14:18 2.00 7,290 9,130 PROD6 DRILL WPRT P RIH-tagged @ 7600', Clean P/U @ .3bpm. RIH-tie in+1ft correction, RIH smooth down to 8550'P/U weight 34K. RIH stack @ 9082'-P/U 35K,Wipe 200'-RIH.-stack 9106' P/U weight 33K. Coil is rolling as passing 9030'area. RIH to TD. 14:18 15:18 1.00 9,130 9,167 PROD6 DRILL DRLG P Drilling ahead-1.40 bpm, 3900, BHP 4130, ECD 12.6, ROP 60,WOB 1.8K,CT weight 11.5K 15:18 17:18 2.00 9,167 9,220 PROD6 DRILL DRLG P P/U 32K 100'CT weight dropped off, ROP slowed. Drill ahead 40 fph to 9220'.CT weight stacking, pump sweeps to help clean hole. 17:18 18:33 1.25 9,220 9,280 PROD6 DRILL WPRT P Wiper trip to window, PUW=32K BHP=4164, 8550 over pull with stall 8615 and 8600 tight spots 18:33 21:33 3.00 9,280 9,358 PROD6 DRILL DRLG P 9280 Drilling ahead 1.37 BPM @ 3933PSI FS, BHP=4123 RIW 9.2K,WOB 2.2K, ROP 48 FPH 21:33 00:00 2.45 9,358 9,358 PROD6 DRILL DRLG P 9358 Midnight depth 1.37 BPM @ 3950 FS BHP=4162 ECD=12.7 04/18/2011 Drill to TD @ 9581,Wiper trip to swab valve, RBIH Tie in,tag bottom 00:00 01:30 1.50 9,358 9,380 PROD6 DRILL DRLG P Drilling ahead from 8358 01:30 01:45 0.25 9,380 9,383 PROD6 DRILL DRLG P ROP @ 7-12 FPH, Pump to-hi vis sweep 1.38 BPM @ 3950 PSi FS BHP=4134 RIW=1K,WOB=2.6K 01:45 01:51 0.10 9,383 9,383 PROD6 DRILL DRLG P Weight check, PUW-32.6, ROP still low 01:51 04:15 2.40 9,383 9,430 PROD6 DRILL DRLG P Continue drilling ahead, hard to get started with stacking good drilling break @ 9384 04:15 06:45 2.50 9,430 9,430 PROD6 DRILL WPRT P Pump Lo-Hi vis sweeps,Wiper to window PUW=32.5K, BHP=4161 Did not see 8550 coming up 06:45 09:45 3.00 9,430 9,502 PROD6 DRILL DRLG P Drilling ahead-1.35 bpm,3890, BHP 4120, ECD 12.7, ROP 30,WOB 2.5, CT weight 10K. 09:45 11:15 1.50 9,502 9,520 PROD6 DRILL DRLG P BHA wiper&pump low/high sweep. P/U weight 32k. Drill ahead, CT weight transfer issue off/on. ROP down to 10 fph. Fighting weight transfer issues. Page 36 of 39 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:15 12:15 1.00 9,520 9,525 PROD6 DRILL DRLG P 300'Wiper P/U weight 32K-RIH with 15K CT weight. Start drilling with 8K, then drops to-2K CT weight.WOB 1.5-3K. ROP 9. B/U samples=2% sand,50%clay,50%Siltstone, Discuss TD 12:15 15:15 3.00 9,525 9,580 PROD6 DRILL DRLG P P/U weight-38K off bottom,came back to 32K,wipe 100'. Pump low/high sweep with increased 776% . Drill ahead-better Weight transfer initially with increased ROP 60 fph. Burns off after B/U. 15:15 19:45 4.50 9,580 120 PROD6 DRILL WPRT P TD-Wiper trip-chasing sweeps. P/U weight 32K 19:45 20:15 0.50 120 62 PROD6 DRILL WPRT P Get close to surface, Perform jog. Observed additional material over shaker —1200 to 700'while POOH 20:15 22:21 2.10 62 7,162 PROD6 DRILL WPRT P Tag stripper, reset depth to BHA 71.76', RIH 22:21 22:33 0.20 7,162 7,178 PROD6 DRILL DLOG P Log K-1 Marker for a-10.5', RIH 22:33 22:51 0.30 7,178 7,530 PROD6 DRILL WPRT P RIH to top of window, Close EDC 22:51 23:03 0.20 7,530 7,610 PROD6 DRILL DLOG P Log RA Marker for-.5'correction 23:03 00:00 0.95 7,610 9,059 PROD6 DRILL WPRT P Continue in hole to tag bottom, correct drillers TD, Pump KW liner running pill 9059 Midnight depth 04/19/2011 Circulate in KWF and POOH, replace spacer flange on reel, run lower liner string and set at 9570' 00:00 00:30 0.50 9,059 9,582 PROD6 DRILL WPRT P Continue running to bottom 00:30 00:39 0.15 9,581 9,581 PROD6 DRILL WPRT P Tag TD @ 9582, recip wait for!inner running pill to get to bit 00:39 03:30 2.85 9,581 1,200 PROD6 DRILL TRIP P Trip out laying in beaded KWF liner running pill folowed by KWF to surface Paint EOP flags @ 6200&8200 03:30 05:30 2.00 1,200 1,200 PROD6 DRILL RGRP T KWF around&to surface.Spacer flange on CT reel sheared at the weld.Stop pumping&monitor well for flow-well dead. PJSM for plan forward. Secure injector/pipe/reel. Isolate iron to reel&set up down Kill line. 1/2 bbls to top up after 2.5 hours. LOTO MWD&power source to reel. ***Start Nabors Billable downtime *** Page 37 of 39 Time Logs Date From` To Dur S. Depth E. Depth Phase Code Subcode T Comment 05:30 08:00 2.50 1,200 1,200 PROD6 DRILL RGRP T PJSM-Crew change.Closed 2" Upper Pipe/slips with 9 K on Weight indicator to secure pipe only, not Well control. Notify John Crisp. Reel secured with slings. Injector, well&pipe secured. Iron to reel vac out.Set up to tach weld spacer flange to ensure no pieces drop prior to P/U reel. Remove horsehead from reel&disconnect Reel swivel iron. 08:00 09:00 1.00 1,200 1,200 PROD6 DRILL RGRP T PJSM-Lift reel&swap out the spacer spools. 09:00 10:30 1.50 1,200 1,200 PROD6 DRILL RGRP T Secure Reel in place. Hook up high pressure iron to reel swivel. install counter and levelwind head. 10:30 11:00 0.50 1,200 1,200 PROD6 DRILL RGRP T Fill well accross top<1 BBI to fill, normal up to pump down coil ,Open upper 2" Pipe/slip rams.Close inner reel valve and PT inner reel iron wash pipe to 90 and swivel to 4K.good test ***End Nabors billable downtime 7.5 Hours*** 11:00 11:30 0.50 1,200 65 PROD6 DRILL TRIP P Continue trip out, Inspected slip marks on pipe, Counter reading 1103 when marks at cat walk. Minimal marks on pipe 11:30 11:48 0.30 65 65 PROD6 DRILL SFTY P At surface, PJSM to lay down BHA while flo checking well 11:48 12:33 0.75 65 0 PROD6 DRILL PULD P Lay down drilling BHA#29 12:33 13:00 0.45 0 0 COMPZ CASING PUTB P R/U floor to run liner 13:00 13:15 0.25 0 0 COMPZ CASING SFTY P PJSM, P/U 38 Jts slotted liner with non ported bullnose and shorty deployment sleeve 13:15 13:51 0.60 0 0 COMPZ CASING PUTB P P/U AL2-01 Lower liner segment 13:51 13:57 0.10 0 0 COMPZ CASING SFTY P BOP safety joint drill-Good drill all hands responded correctly 13:57 15:00 1.05 0 1,244 COMPZ CASING PUTB P Continue making up liner 15:00 16:00 1.00 1,244 1,244 COMPZ CASING PULD P 38 Joints in well, M/U Coil Trak to liner and land in deployment rams. 16:00 19:00 3.00 1,244 9,570 COMPZ CASING RUNL P RIH,correct to flags and set liner at 9570',top of liner at 8325' 19:00 21:30 2.50 9,570 0 COMPZ CASING RUNL P POOH,tie in to K1 and paint EOP flags. POOH 21:30 22:00 0.50 0 0 COMPZ CASING PUTB P Lay down liner running tools, 22:00 22:18 0.30 0 0 COMPZ CASING SFTY P PJSM, PU liner 22:18 23:18 1.00 0 0 COMPZ CASING PUTB P rig up for running liner 23:18 00:00 0.70 0 0 COMPZ CASING SVRG P Service injector and top drive 04/20/2011 Run upper liner string,top of deployment sleeve at 7261',displace KWF and FP well. Set BPV and RDMO Page 38 of 39 Time Logs Date - From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 03:30 3.50 0 1,108 COMPZ CASING PUTB P Run upper liner string, PU coiltrac tools 03:30 05:30 2.00 1,108 7,515 COMPZ CASING RUNL P RIH 05:30 06:06 0.60 7,515 7,507 COMPZ CASING RUNL P Stop and correct to flag,-7.4, continue in well PUW=34K, RIW=20.9K 06:06 06:18 0.20 7,507 8,327 COMPZ CASING RUNL P 8327', Stop and pump off liner, PUW=39k PUH to 8275 06:18 07:18 1.00 8,327 7,212 COMPZ CASING CIRC P PUH to 8275, Pump spacer and roll hole to seawater reset depth to remove liner set in hole-1063.9 07:18 07:24 0.10 7,212 7,130 COMPZ CASING DLOG P 7140 Tie into K1 for+1 foot 07:24 10:24 3.00 7,130 2,000 COMPZ CASING TRIP P Trip out of well, pump 22 BBIs diesel, freeze protect from 2000' 10:24 13:24 3.00 0 0 COMPZ CASING PULD P PJSM to undeploy coil track, Problems bleeding down above deployment rams Power tool up and shut EDC sub. Get bled off(nothing to do with EDC) 13:24 14:24 1.00 0 0 COMPZ CASING PULD P Pull Coil track out of PDL blow down and lay down 14:24 16:00 1.60 0 DEMOB WHDBO NUND P R/U BPV Lubricator and set BPV/ R/D and load out lubricator 16:00 00:00 8.00 DEMOB WHDBO NUND P Circulate corrosion inhibitor,blow down CT and all surface lines. ND BOP stack. RDMO • Page 39 of 39 gmcif [E AbsgEA iio [F SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 V. Cawvey Alaska Wells Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1E-08AL2-01 ConocoPhillips Alaska, Inc. Permit No: 211-023 Surface Location: 1013'FSL, 629' FEL, SEC. 16, T11N, R10E, UM Bottomhole Location: 205' FSL, 2465' FEL, SEC. 9, T11N, R10E, UM Dear Mr. Cawvey: Enclosed is the approved application for permit to re-drill the above referenced development well. The permit is for a new wellbore segment of existing well KRU 1E-08A, Permit No 210- 181, API 50-029-20496-01. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, i Daniel . Seamount, Jr. rGJ Chair DATED this day of February, 2011. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA :r. ,r i > X011 ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL -'J...=, e4,r. �, q `;Ufa C s+on 20 AAC 25.005 e la.Type of Work: , lb.Proposed Well Class: Development-Oil E •Service-Winj ❑ Single Zone 2 •lc.Specify if well is proposed for: Drill ❑ Re-drill❑✓ Stratigraphic Test ❑ Development-Gas ❑ Service-Supply ❑ Multiple Zone❑ Coalbed Gas ❑ Gas Hydrates❑ Re-entry ❑ Exploratory ❑ Service-WAG ❑ Service-Disp ❑ Shale Gas ❑ 2.Operator Name: 5. Bond: U Blanket Li Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 • 1E-08AL2-01 • 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 10000' TVD: 6321' • Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: 1013'FSL,629'FEL,Sec. 16,T11N,R10E, UM • ADL 25651,25648 • Kuparuk River Oil Pool Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 618'FNL, 1631'FEL,Sec. 16,T11N, R10E,UM 469,466 3/1/2011 Total Depth: 9.Acres in Property: 14.Distance to 205'FSL,2465'FEL,Sec.9,T11N,R10E,UM 2560 Nearest Property: 24300' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: • 98.6 feet 15.Distance to Nearest Well Open Surface:x- 549890 y- 5960600 • Zone- 4 GL Elevation above MSL: 70.7 feet to Same Pool: 1B-19,325' 16.Deviated wells: Kickoff depth: 8750' ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 100.7° deg Downhole:3000 psig • Surface:2365 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) 3" 2.375" 4.7# L-80 ST-L 2720' 7280' 6224' 10000' 6420' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured) 7860' 6570' 5736' 7714' 6483' Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 15 bbls AS II 80' 80' Surface 2896' 10.75" 1350 sx,250 sx AS 2896' 2705' Intermediate Production 7568' 7" 300 sx,200 sx 7568' 6543' Liner 2369' 5.5" 247 sx Class G 7860' 6571' Perforation Depth MD(ft): Perforation Depth TVD(ft): none none 20.Attachments: Property Plat❑ BOP Sketch❑ Drilling Program❑ Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program ❑✓ 20 AAC 25.050 requirements ❑✓ 21.Verbal Approval: Commission Representative: Date: P /01-- 9-0`11/1 22. I hereby certify that the foregoing is true and correct. Contact Jill Long @ 263-4093 Printed Name V. Cawve Title Alaska Wells Manager Seabed Re'N)44„..A4.4...00.... Phon 265-6306 Date L/14./241)/'+ Commission Use Only f Permit to Drill API Numb t"�/� Permit Approval See cover letter Number. L 50- )Z- `Z1�' < ,' ' Date: '9\t-�,) I for other requirements rI Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalb8d met ne,gas hydrates,or gas contained in shales: 41- 35t2 psc; t30,0 7- -.3-74- Samples req'd: Yes ❑ No L Mud log req'd: Yes ❑ No d Other: . zscc PS's: /4tin ma,' /es N H2S measures: Yes 0 No ❑ Directional svy req'd: Yes ' No ❑ 4c{/nini S-t{'radi✓e Aproc1 fe. u.i•,✓•ed DL. -re ean.-Icr'fiILJ +o IJec7�'ioh. APPROVED BY THE COMMISSION Z5. // DAT'. ,COMMISSIONER Form 10-401 (Revised 7/2009) This permit is v li f r,4�npgt'h01 .."' si4 r f the'.date of approval(20 C 25.005(g)) Subbmitt'n Duplicate 2-23-4 Aile9 1 �r� y.2-7. /7 ConocoPhillips Alaska ` ., P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 FEB 15 2011 February 11, 2011 3Ik°aA Aa 1TI _'° GA;COI'S.C.: Jsi011 Commissioner- State of Alaska :wig : .; .Ajtr Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits Permit to Drill (PTD) applications to drill and complete five lateral sidetracks out of Kuparuk well 1E-08A (PTD# 210-181). This work will be done with the coiled tubing drilling (CTD) rig, Nabors CDR2-AC. Operations scheduled to begin March 1, 2011. The objective of the CTD project is to drill five lateral sidetracks (1E-08AL1, 1E-08AL1-01, 1E-08AL1-02, 1E- 08AL2, and 1E-08AL2-01) targeting the A4 and A5 sands. (NOTE: In some previous documentation four lateral sidetracks were referenced as the plan. Upon more detailed directional planning, five laterals will be necessary to reach the objectives of the project.) The ultimate, intended service for these laterals is MWAG injection. The permits have been submitted as producers, as requested by the State, due to the fact that the laterals are planned to be pre-produced for a period of time beyond 30 days. Two, single-string casing exits will milled through the 5.5" liner in the parent wellbore. Three sidetracks are planned from one window and two sidetracks from the second window. Some pre-rig wellwork is necessary to prepare the wellbore for the arrival of Nabors CDR2-AC. A Sundry application to cover this work was submitted • to the State on February 3, 2011. Attached is an outline of the pre-CTD wellwork planned for 1E-08A and a brief summary of CTD work. If you have any questions or require additional information please contact me at my office 907-263-4093 or on my cell phone 907-230-7550. Attached to this application are the following documents: — 5 Permit to Drill Application Forms: 1E-08AL1, 1E-08AL1-01, 1E-08AL1-02, 1E-08AL2, 1E-08AL2-01 — Summary of Planned Operations — Proposed Schematic — Directional Plans — Anti-collision Review — BOP Schematic If you have any questions or require additional information please contact me at 907-263-4093 (office) or 907- 230-7550 (cell). Sincerely, tJcJ2-&>7"lam Jill Long Coiled Tubing Drilling engineer Permit to Drill Summary of Operations KRU 1 E-08AL1, 1 E-08AL1-01, 1 E-08AL1-02, 1 E-08AL2, 1 E-08AL2-01 Coiled Tubing Drilling Lateral Sidetracks Well History and Objective Wellbore 1E-08 was originally drilled and completed as in 1980 as a commingled producer. In 1984 a workover was performed to install a selective completion allowing for isolation between the A and C-sands. Blast rings were placed in the straddle section. The wellbore was eventually converted to water injection in 1990. A leak was detected in the straddled section of tubing in 1995. A tubing patch was used to repair the leak and from that point on the well functioned as an A-sand only injector. From 2000-2008 the well was shut-in due to a corroded well line. When placed back in service in 2008, additional leaks were found in the straddle section. Leaks to the C-sand continued to be a problem in the wellbore. Since this well had been identified as a candidate for CTD, A-sand only sidetracks, the well was shut-in in February 2010 to allow for depressurization of the A-sand by crossflowing into the C. Preparation for CTD work began in November 2010 with a rig workover. The purpose of the workover was to replace the 3.5" leaking selective completion with new 3.5" tubing. During recovery operations, the tubing in the selective section parted resulting in some blast rings falling downhole. Due to the complications and low likelihood of recovering any equipment with broken blast rings present, workover operations were abandoned. A cement retainer was set and cement pumped. A rotary sidetrack was immediately planned in order to replace the well and set it up for CTD. The rotary sidetrack began January 5, 2011. After successfully sidetracking out of 1 E-08 and reaching TD, a 5.5" liner was run to bottom. While confirming circulation with the liner in place, the hole became packed off. In an attempt to establish circulation and place cement above the Kuparuk, perforations were shot in the liner and a cement retainer was used for circulating in cement. Additional problems ensued but ultimately after a bond log was run, all parties agreed there was adequate cement above the top of the Kuparuk to proceed with running the tubing completion. This cement work will help provide additional isolation between the A and C sands. The final 3.5" completion required three packers set in the liner to isolate the upper set of cement perforations as well as a liner leak. Operations on the rotary sidetrack were completed on January 31, 2011. CTD rig, Nabors CDR2-AC, is planned to begin operations on 1 E-08A on March 2, 2011. After completion of the CTD work, the well will be pre-produced for approximately 3-6 months. After the pre-production period, the well will return to its intended service, MWAG injection. Operational Outline Pre-Rig Work 1. Changeout all gas lift valves to dummy valves. Drift wellbore with dummy whipstock. 2. Perforate the 5.5" liner across from potential CTD kickoff locations. Planned kickoff points are -7645' MD and -7564' MD. Perforations will also be shot across a backup kickoff location at-7527' MD. 3. Set the lower whipstock at-7645' MD. 4. Cement squeeze the openhole section behind the 5.5" liner. Contaminate and cleanout cement to the top of the whipstock at -7645' MD. (NOTE: This cement will provide additional isolation between the A and C sands as well as ensure there is good cement behind pipe at the kickoff locations.) 5. Drift and tag the top of the whipstock. 6. Run a cement bond log to evaluate the cement quality. 7. Set BPV and prepare wellsite for rig arrival. Page 1 of 5 ORIGINAL 2/11/2011 PTD Applications- KRU -i E-08AL1, 1 E-08AL1-01, 1 E-08AL1-v2, 1 E-08AL2, 1 E-08AL2-01 CTD Procedure Overview 1. MIRU Nabors CDR2-AC rig using 2" coil tubing. NU 7-1/16" BOPE, test. 2. Mill a 2.80", single-string window exit with high-side orientation off of the whipstock set pre-rig arrival 3. 1 E-08AL1 Lateral a. Drill 2.70" x 3" bi-center lateral in the A4 sand b. Load well with kill weight fluid. Run 2%" slotted liner with an aluminum liner-top billet from TD to the kickoff point for the 1E-08AL1-01 lateral 4. 1E-08AL1-01 Lateral a. Drill 2.70" x 3" bi-center lateral in the A5 sand b. Load well with kill weight fluid. Run 2%" slotted liner with an aluminum liner-top billet from TD to the kickoff point for the 1 E-08AL1-02 lateral 5. 1E-08AL1-02 Lateral a. Drill 2.70" x 3" bi-center lateral in the A5 sand b. Load well with kill weight fluid. Run 2%" slotted liner with a deployment sleeve on top from TD to just inside the window 6. Set the upper whipstock at-7564' MD. 7. Mill a 2.80", single-string window exit with high-side orientation off of the upper whipstock 8. 1 E-08AL2 Lateral a. Drill 2.70" x 3" bi-center lateral in the A4 sand b. Load well with kill weight fluid. Run 2%" slotted liner with an aluminum liner-top billet from TD to the kickoff point for the 1 E-08AL2-01 lateral 9. 1E-08AL2-01 Lateral a. Drill 2.70" x 3" bi-center lateral in the A5 sand 71 .3 b. Load well with kill weight fluid. Run 2%" slotted liner with a deployment sleeve on top from TD to p-�- up inside the tubing tail 10. Freeze protect. ND BOPE. RDMO Nabors CRD2-AC. Handover to Production group. Page 2 of 5 2/11/2011 PTD Applications- KRU 1 E-08AL1, 1 E-08AL1-01, 1 E-08AL1-u2, 1 E-08AL2, 1 E-08AL2-01 Operational Details Hazards - Shale stability in the A4/A5 interface is a potential problem, as was seen in offset CTD wells 1E-12 and 1E- 15. Cutting through these sections at high inclinations and ensuring no motor transitions occur within a close proximity should help mitigate the problem. - The 1 E-08AL1 lateral is very long, -4000'. Weight transfer towards the end of the lateral is a concern and so the lateral has been planned with minimal doglegs utilizing rib-steer motor(RSM) technology. - Drillsite 1E is an H25 pad. The maximum recorded H2S reading on the pad in 2010 was 130 ppm at well 1E-02 (09/15/2010). Well 1E-121 is the closest producing well to 1E-08 (located -30' to the right on surface) and had an H25 reading of 30 ppm on (09/15/2010). All H25 monitoring equipment should be operational. Fluids Program - Chloride-based Biozan brine (8.6 ppg)will be used for window milling operations. - Chloride-based Flo-Pro mud (9.8 ppg) for drilling operations. - 1 E-08A does not contain a subsurface safety valve so completion kill weight fluid will be used for running completions. Disposal - No annular injection on this well. - Class II liquids to KRU 1R Pad Class II disposal well - Class II drill solids to Grind & Inject at PBU Drill site 4 - Class I wastes will go to Pad 3 for disposal. New Completion Details Lateral Name Liner Liner Liner Liner Liner Details Top Btm Top Btm MD MD TVD TVD 1 E-08AL1 8950 11700 6462 6525 23/8', 4.7#, L-80, ST-L slotted liner; aluminum liner top billet on top. 1 E-08AL1-01 8050 10800 6471 6459 23/8', 4.7#, L-80, ST-L slotted liner; aluminum liner top billet on top. 1 E-08AL1-02 7600 8950 6414 6397 2%" 4.7#, L-80, ST-L slotted liner; shorty deployment sleeve on top. 1 E-08AL2 8750 10375 6435 6477 23/8', 4.7#, L-80, ST-L slotted liner; aluminum liner top billet on top. 1 E-08AL2-01 7280 10000 6224 6420 23/8' 4.7#, L-80, ST-L slotted liner; deployment sleeve on top. Existing Casing/Liner Information Category OD Weight Grade Connection Top Btm Top Btm Burst Collapse (ppf) MD MD TVD ND psi psi Conductor 16" 65 H-40 Welded 0 80 0 _ 80 1640 630 Surface 10%" 45.5 K-55 BTC 0 2896 0 2705 3580 2090 Casing 7" 26 K-55 BTC 0 5736 0 5133 4980 4330 Liner 5'/" 15.5 L-80 HDL 5491 6780 4921 5933 7000 4990 Liner 5'/2" 15.5 L-80 STL 6780 7860 5933 6571 7000 4990 Tubing 3%" 9.3 L-80 EUE-M 0 5441 0 4877 10160 10540 Tubing 3%" 9.3 L-80 IBT-M SCC 5441 7297 4877 6235 10160 10540 Page 3 of 5 ORIUINAL 2/11/2011 PTD Applications- KRU -i E-08AL1, 1 E-08AL1-01, 1 E-08AL1-u2, 1 E-08AL2, 1 E-08AL2-01 Directional Planning - See attached directional plans for each of the three laterals. - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. - Distance to Nearest Property Line(measured to KPA boundary at closest point) Lateral Name Distance 1 E-08AL1 20250' 1 E-08AL1-01 21050' 1 E-08AL1-02 22800' 1 E-08AL2 23900' 1 E-08AL2-01 24300' - Distance to Nearest Well within Pool (toe measured to offset well) Lateral Name Distance Well 1 E-08AL1 150' 1E-18 1 E-08AL1-01 175' 1E-18 1 E-08AL1-02 1050' 1E-18 1 E-08AL2 375' 1B-19 1 E-08AL2-01 325' 1B-19 Logging MWD directional, resistivity, and gamma ray will be run over the entire openhole section. Reservoir Pressure The most recent static BHP survey in well 1E-08 was taken October 21, 2010. The reservoir pressure was measured at 2760 psi at 7274' MD/6286' TVDss, corresponding to 8.4 ppg EMW. Well Control - Two well bore volumes (-215 bbl) of 12.0 ppg kill weight fluid will be within a short drive to the rig during drilling operations. In this situation, a "wellbore volume" is defined as the tubing volume plus the volume of the longest lateral. - BOP diagram is attached for operations with 2" coil tubing. - Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. Maximum surface pressure anticipated while sidetracking out of 1E-08 is -2365 psi, assuming a gas gradient to surface. This maximum potential surface pressure is calculated using the maximum expected reservoir pressure of 3000 psi based on recent pressures within the area and assuming a gas gradient of 0.1 psi/ft. - The annular preventer will be tested to 250 psi and 2500 psi. Managed Pressure Drilling Managed pressure drilling (MPD) techniques will be employed to provide constant bottomhole pressure by using 9.6 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allows use of less expensive drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure is installed between the BOPE choke manifold and the mud pits, and is independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the 2%" BHA will be accomplished utilizing the 2%" pipe rams and slip rams. The annular preventer will act as a secondary containment during deployment and not as a stripper. The well will be loaded with overbalanced fluid prior to running completions. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. Page 4 of 5 2/11/2011 PTD Applications- KRU 1 IE-08AL1, 1 E-08AL1-01, 1 E-08AL1-u2, 1 E-08AL2, 1 E-08AL2-01 A°K Quarter-Mile Injection Review The following wellbores lay within one-quarter mile of the noted CTD sidetrack wellplans at any point along the planned wellpath. Approaching Name Service Status Sands Completion Comments Wellplans 1E-19 Water Shut-in A& C Selective Shut-in since -2006 due to a de-rated 1 E-08AL1 & Injector completion flowline. 1E-08AL1-01 1E-18 Producer Online A& C Selective Currently producing with both the A 1 E-08AL1, completion and C sands open however production 1E-08AL1-01, logs indicate 100% of production is 1E-08AL1-02 coming from the C. The long-term development plan for this well is to plug off the A sands and make this well a C sand only producer. During CTD drilling operations on 1 E-08A, the A sand is planned to be mechanically isolated. 1 E-10 Producer Shut-in A& C Single Long-term shut-in due to a fish stuck 1 E-08AL2 & completion. in the wellbore. No flowline exists and 1 E-08AL2-01 A sand is there are no plans to put this well back cement in service. plugged. 1 E-08 Abandoned - - Cement Original wellbore 1 E-08 was a selective 1 E-08AL1, plugged completion in the A and C sands. A 1 E-08AL1-02, workover occurred in later 2010 in an 1E-08AL2, attempt to replace the tubing that had 1 E-08AL2-01 leaks in the selective section. The tubing fell apart during retrieval and the workover was abandoned. Cement was pumped and a plug set. A rotary sidetrack occurred in January 2011 to replace the parent wellbore. 1 E-07 Producer Online A& C Selective This wellbore is currently an A and C 1 E-08AL1 completion sand producer however it is a planned CTD project in 2011. The CTD sidetracks will be C only sidetracks. The A sand will be cement plugged prior to sidetracking making this an A only wellbore. 1 B-04 Water Online A& C Selective This well is an active water injector. 1 E-08AL2 & Injector completion Currently the C sands are shut-in and 1E-08AL2-01 injection is only into the A sand. 1B-15AL2 Producer Online A CTD CTD sidetracks in this wellbore exist in 1E-08AL2 sidetracked both the A and C sands. The 1 B- single 15AL2 lateral is solely in the A sand. completion 1B-19 Abandoned - - Cement Perforations in this wellbore were 1 E-08AL2 & plugged cemented prior to CTD sidetracks that 1 E-08AL2-01 V occurred in January 2011. r' 1B-19L1 Producer Online C CTD This is a C-sand only lateral. 1E-08AL2 & sidetrack '� 1E-08AL2-01 1B-1 L1-01 Producer Online C CTD lateral This is a C-sand only lateral. ✓ 1E-08AL1, sidetrack 1E-08AL2, & 1 E-08AL2-01 1B-19L1-02 Producer Online C CTD lateral This is a C-sand only lateral. 1 E-08AL2 & �: sidetrack 1 E-08AL2-01 Page 5 of 5 2/11/2011 Nabors CDR-2AC Kuparuk Managed Pressure Coil Tubing Drilling BOP Configuration for 2" Coil Tubing 0 — Lubricator Riser \Annular/ Blind/Shear 2"Pipe/Slip(CT) Pump into Lubricator0'><><J L �� above BHA rams > 1 r Choke 2-3/8"Pipe/Slip(BHA) Choke Equalize Manifold 2-3/8"Pipe/Slip(BHA) 7 J L L Kill ►><>< »> ► ��7 C ► r r Blind/Shear 2"Pipe/Slip(CT) .' Choke 2 ;Swab Valves • MIL ■ Wing Valves I4414� Tree Flow Cross Surface Safety Valve BOPE: 7-1/16", 5M psi, TOT Choke Line: 2-1/16", 5M psi Master Valve Kill Line: 2-1/16", 5M psi Equalizing Lines: 2-1/16", 5M psi Choke Manifold: 3-1/8", 5M psi Riser: 7-1/16", 5M psi, C062 Union !SI no. ma_ v2 wom Zoo o-@ � ' ',.',2 ,: -r m m m " 4 �@I CO w O° ,, rm v m LI) an 1, , m CO N 1 ., , 1, ry 3 E ::1 i I , 1 woo i ii it iit I j1 11\\ ,' it II 11 0 it I, m v 1 i, v j ii N E i i 1 1 4 N i', mom- i ,I -tm ,1 1 1 Q1 m� r 1, O I I ,,1 1, 11 I I '09 LS E O It ni I 1E '1I0 I1\1\- -x C x x , , II72 III1:' em m n m n n ,:W � II �10 va°' ►="7 i 1 _ - 1,11111II _ = � __: � II N_ � � o I m 3 5 t U J N o o.n Af _ � v.`n 64 - x ��E =" v #"`',m ° c av NCm @ r m m c LI o ORIGINAL 10," ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1E Pad 1E-08 1 E-08AL2-01 Plan: 1 E-08AL2-01_wp01 Standard Planning Report 11 February, 2011 HIM BAKER HUGHES w ConocoPhillips 111r ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1E-08 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: IE-08A @ 98.62ft(D141 (27.92+70.70)) Site: Kuparuk 1 E Pad North Reference: True Well: 1E-08 Survey Calculation Method: Minimum Curvature Wellbore: 1 E-08AL2-01 Design: 1 E-08AL2-01_wp01 Project Kuparuk River Unit Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 1E Pad Site Position: Northing: 5,959,760.24ft Latitude: 70°18'3.022 N From: Map Easting: 549,889.51 ft Longitude: 149°35 45.358 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.38° Well 1 E-08 Well Position +N/-S 0.00 ft Northing: 5,960,600.23 ft Latitude: 70°18'11.283 N +E/-W 0.00 ft Easting: 549,889.82 ft Longitude: 149°35 45.186 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 70.70ft Wellbore 1 E-08AL2-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2010 3/6/2011 16.90 79.85 57,354 Design 1E-08AL2-01_wp01 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,750.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (0) -70.70 0.00 0.00 317.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (0) Target 8,750.00 87.15 291.18 6,336.37 3,648.47 -1,009.80 0.00 0.00 0.00 0.00 8,840.00 100.65 291.18 6,330.26 3,680.84 -1,093.34 15.00 15.00 0.00 0.00 8,940.00 95.25 277.04 6,316.38 3,704.83 -1,189.12 15.00 -5.40 -14.14 250.00 9,040.00 90.62 291.33 6,311.23 3,729.26 -1,285.66 15.00 -4.63 14.29 107.50 9,220.00 90.55 318.33 6,309.35 3,831.12 -1,432.03 15.00 -0.04 15.00 90.00 9,320.00 90.53 303.33 6,308.40 3,896.32 -1,507.47 15.00 -0.02 -15.00 270.00 9,470.00 90.49 325.84 6,307.04 4,000.94 -1,613.61 15.00 -0.03 15.00 90.00 9,620.00 87.97 348.20 6,309.07 4,138.13 -1,671.81 15.00 -1.68 14.91 96.50 9,820.00 88.24 318.18 6,315.83 4,314.49 -1,760.94 15.00 0.14 -15.01 270.00 10,000.00 88.44 345.19 6,321.14 4,471.43 -1,845.49 15.00 0.11 15.01 90.00 2/11/2011 3:25:58PM Page 2 COMPASS 2003.16 Build 69 low-' ConocoPhillips Fe"' ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1E-08 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: IE-08A @ 98.62ft(D141(27.92+70.70)) Site: Kuparuk 1E Pad North Reference: True Well: 1E-08 Survey Calculation Method: Minimum Curvature Wellbore: 1 E-08AL2-01 Design: 1 E-08AL2-01_wp01 Planned Survey Measured ND Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +NI-S +E/-W Section Rate Azimuth Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (1100ft) (°) (ft) (ft) 8,750.00 87.15 291.18 6,336.37 3,648.47 -1,009.80 3,357.01 0.00 0.00 5,964,241.56 548,855.92 TIP/KOP 8,800.00 94.65 291.18 6,335.58 3,666.52 -1,056.39 3,401.98 15.00 0.00 5,964,259.30 548,809.22 8,840.00 100.65 291.18 6,330.26 3,680.84 -1,093.34 3,437.65 15.00 0.00 5,964,273.37 548,772.18 2 8,900.00 97.46 282.65 6,320.81 3,698.04 -1,149.97 3,488.85 15.00 -110.00 5,964,290.19 548,715.44 8,940.00 95.25 277.04 6,316.38 3,704.83 -1,189.12 3,520.52 15.00 -111.34 5,964,296.72 548,676.25 3 9,000.00 92.49 285.63 6,312.32 3,716.59 -1,247.75 3,569.11 15.00 107.50 5,964,308.09 548,617.54 9,040.00 90.62 291.33 6,311.23 3,729.26 -1,285.66 3,604.23 15.00 108.08 5,964,320.51 548,579.56 4 9,100.00 90.61 300.33 6,310.59 3,755.38 -1,339.60 3,660.12 15.00 90.00 5,964,346.27 548,525.45 9,200.00 90.57 315.33 6,309.55 3,816.54 -1,418.35 3,758.55 15.00 90.10 5,964,406.90 548,446.30 9,220.00 90.55 318.33 6,309.35 3,831.12 -1,432.03 3,778.55 15.00 90.25 5,964,421.39 548,432.53 5 9,300.00 90.54 306.33 6,308.59 3,884.90 -1,491.06 3,858.14 15.00 -90.00 5,964,474.77 548,373.15 9,320.00 90.53 303.33 6,308.40 3,896.32 -1,507.47 3,877.68 15.00 -90.11 5,964,486.08 548,356.66 6 9,400.00 90.52 315.33 6,307.66 3,946.94 -1,569.23 3,956.82 15.00 90.00 5,964,536.28 548,294.57 9,470.00 90.49 325.84 6,307.04 4,000.94 -1,613.61 4,026.58 15.00 90.11 5,964,589.98 548,249.84 7 9,500.00 89.98 330.31 6,306.91 4,026.39 -1,629.48 4,056.02 15.00 96.50 5,964,615.32 548,233.81 9,600.00 88.30 345.21 6,308.42 4,118.68 -1,667.22 4,149.25 15.00 96.52 5,964,707.35 548,195.46 9,620.00 87.97 348.20 6,309.07 4,138.13 -1,671.81 4,166.61 15.00 96.29 5,964,726.76 548,190.74 8 9,700.00 88.02 336.19 6,311.88 4,214.11 -1,696.22 4,238.82 15.00 -90.00 5,964,802.57 548,165.83 9,800.00 88.19 321.18 6,315.20 4,299.25 -1,748.01 4,336.41 15.00 -89.58 5,964,887.36 548,113.48 9,820.00 88.24 318.18 6,315.83 4,314.49 -1,760.94 4,356.38 15.00 -89.08 5,964,902.51 548,100.44 9 9,900.00 88.28 330.19 6,318.26 4,379.22 -1,807.65 4,435.57 15.00 90.00 5,964,966.92 548,053.31 10,000.00 ' 88.44 345.19 6,321.14 4 4,471.43 , -1,845.49 4,528.82 15.00 89.63 5,965,058.87 548,014.87 TD 2/11/2011 3:25:58PM Page 3 COMPASS 2003.16 Build 69 ConocoPhillips ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1E-08 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: IE-08A @ 98.62ft(D141(27.92+70.70)) Site: Kuparuk 1 E Pad North Reference: True Well: 1E-08 Survey Calculation Method: Minimum Curvature Wellbore: 1 E-08AL2-01 Design: 1 E-08AL2-01_wp01 Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +EI-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 1E-08AL2,AL2-01 Pol 0.00 0.00 0.00 3,310.90 -23.58 5,963,910.58 549,844.26 70°18'43.846 N 149°35'45.874 W -plan misses target center by 6421.53ft at 8750.00ft MD(6336.37 TVD,3648.47 N,-1009.80 E) -Polygon Point 1 0.00 3,310.90 -23.58 5,963,910.58 549,844.26 Point 2 0.00 3,423.82 -8.83 5,964,023.59 549,858.26 Point 3 0.00 3,562.26 -73.93 5,964,161.58 549,792.25 Point 4 0.00 3,634.02 -187.47 5,964,232.58 549,678.24 Point 5 0.00 3,673.15 -358.23 5,964,270.57 549,507.24 Point 6 0.00 3,689.50 -714.17 5,964,284.55 549,151.24 Point 7 0.00 3,825.04 -1,097.32 5,964,417.53 548,767.23 Point 8 0.00 4,106.09 -1,403.50 5,964,696.52 548,459.22 Point 9 0.00 4,397.20 -1,567.61 5,964,986.50 548,293.20 Point 10 0.00 4,758.57 -1,769.25 5,965,346.49 548,089.19 Point 11 0.00 5,116.54 -2,060.93 5,965,702.48 547,795.16 Point 12 0.00 4,719.26 -2,177.56 5,965,304.47 547,681.18 Point 13 0.00 4,513.96 -1,983.89 5,965,100.48 547,876.19 Point 14 0.00 4,233.16 -1,867.72 5,964,820.49 547,994.22 Point 15 0.00 3,933.26 -1,736.68 5,964,521.49 548,127.23 Point 16 0.00 3,670.55 -1,482.38 5,964,260.50 548,383.25 Point 17 0.00 3,497.82 -1,070.47 5,964,090.53 548,796.25 Point 18 0.00 3,413.94 -634.97 5,964,009.55 549,232.26 Point 19 0.00 3,482.57 -274.48 5,964,080.57 549,592.25 Point 20 0.00 3,448.82 -160.69 5,964,047.58 549,706.25 Point 21 0.00 3,263.87 -170.91 5,963,862.58 549,697.26 Point 22 0.00 3,310.90 -23.58 5,963,910.58 549,844.26 1E-08AL2-01 t2 0.00 0.00 6,307.00 4,033.04 -1,535.94 5,964,622.59 548,327.29 70°18'50.947 N 149°36'29.994 W -plan misses target center by 81.85ft at 9445.45ft MD(6307.25 TVD,3981.08 N,-1599.19 E) -Point 1E-08AL2-01 t3 0.00 0.00 6,321.00 4,496.79 -1,790.88 5,965,084.59 548,069.30 70°18'55.507 N 149°36'37.435 W -plan misses target center by 60.21ft at 10000.00ft MD(6321.14 TVD,4471.43 N,-1845.49 E) -Point 1E-08AL2-01 t1 0.00 0.00 6,316.00 3,730.64 -1,178.91 5,964,322.59 548,686.28 70°18'47.973 N 149°36'19.577 W -plan misses target center by 26.95ft at 8934.43ft MD(6316.90 TVD,3704.11 N,-1183.62 E) -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 2,889.62 2,600.85 10 3/4" 10-3/4 12-1/4 10,000.00 6,321.14 2 3/8" 2-3/8 3 2/11,12011 3:25:58PM Page 4 COMPASS 2003.16 Build 69 � , �., v= ConocoPhillips rer. ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1E-08 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: IE-08A @ 98.62ft(D141(27.92+70.70)) Site: Kuparuk 1E Pad North Reference: True Well: 1E-08 Survey Calculation Method: Minimum Curvature Wellbore: 1 E-08AL2-01 Design: 1 E-08AL2-01_wp01 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 8,750.00 6,336.37 3,648.47 -1,009.80 TIP/KOP 8,840.00 6,330.26 3,680.84 -1,093.34 2 8,940.00 6,316.38 3,704.83 -1,189.12 3 9,040.00 6,311.23 3,729.26 -1,285.66 4 9,220.00 6,309.35 3,831.12 -1,432.03 5 9,320.00 6,308.40 3,896.32 -1,507.47 6 9,470.00 6,307.04 4,000.94 -1,613.61 7 9,620.00 6,309.07 4,138.13 -1,671.81 8 9,820.00 6,315.83 4,314.49 -1,760.94 9 10,000.00 6,321.14 4,471.43 -1,845.49 TD 2111/2011 3:25:58PM Page 5 COMPASS 2003.16 Build 69 OR1G ' NAL.. 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HUGHES Company: ConocoPhillips(Alaska)Inc.-Kup1 Local Co-ordinate Reference: Well 1E-08 Project: Kuparuk River Unit TVD Reference: IE-08A @ 98.62ft(D141 (27.92+70.70)) Reference Site: Kuparuk 1E Pad MD Reference: IE-08A @ 98.62ft(D141 (27.92+70.70)) Site Error: 0.00ft North Reference: True Reference Well: 1E-08 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore 1E-08AL2-01 Database: EDM Alaska Prod v16 Reference Design: 1E-08AL2-01 wp01 Offset TVD Reference: Offset Datum Reference 1 E-08AL2-01_wp01 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of referen Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 8,750.00 to 10,000.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,197.21ft Error Surface: Elliptical Conic Survey Tool Program Date 2/10/2011 From To (ft) (ft) Survey(Wellbore) Tool Name Description 104.22 5,704.22 1E-08 GyroData(1E-08) GYD-CT-CMS Gyrodata cont.casing m/s 5,712.00 7,499.06 1E-08A(1E-08A) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 7,499.06 8,750.00 1E-08AL2 wp01 (1 E-08AL2) MWD MWD-Standard 8,750.00 10,000.00 1 E-08AL2-01_wp01 (1 E-08AL2-01) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (•') 0 2,889.62 2,699.47 103/4" 10-3/4 12-1/4 10,000.00 6,419.76 2 318" 2-3/8 3 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) Kuparuk 1B Pad 1B-19-1B-19-1 B-19 9,955.25 8,475.00 262.06 247.55 22.81 Pass-Major Risk 1B-19-1B-19L1-1B-19L1 9,833.14 8,800.00 196.96 215.19 20.10 Pass-Major Risk 1B-19-1B-19L1-01-1B-19L1-01 8,902.03 9,771.00 131.67 163.70 23.00 Pass-Major Risk 1B-19-1B-19L1-02-1B-19L1-02 9,419.10 9,200.00 148.39 1.50 148.16 Pass-No Errors Kuparuk 1E Pad 1E-08-1E-08AL2-1 E-08AL2_wp01 8,750.00 8,750.00 0.00 0.32 -0.22 FAIL-No Errors 1E-10-1E-10-1E-10 9,350.00 7,811.00 1,137.69 231.19 907.68 Pass-Major Risk 1E-11 -1E-11 -1E-11 Out of range 1E-12-1E-12-1E-12 Out of range 1E-12-1E-12L1-1E-12L1 Out of range 1E-12-1E-12L1-01-1E-12L1-01 Out of range 1E-12-1 E-12L1 PB 1-1 E-12L1 PB1 Out of range 1E-12-1E-12L2-1E-12L2 Out of range / 1E-12-1E-12L2-01-1E-12L2-01 Out of range 1E-12-1E-12L2-01PB1 -1E-12L2-01PB1 Out of range V 1E-12-1E-12L2PB1-1E-12L2PB1 Out of range CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 2!11/2011 1:55:46PM Page 2 of 12 COMPASS 2003.16 Build 69 "� 1 G �4 1 Note to File 1E-08A & 1E-08AL1 , L1-01,L1-02 , L2 ,L2-01 p7-7D Z/I—Oz 3 The sidetrack 1E-08A was drilled as a CTD setup ( 5 laterals are planned out of this ST wellbore ) after the failed RWO attempt on the 1E-08 left junk in the wellbore. Many difficulties were encountered in getting the 5 '/2 liner cemented ... the initial primary job packed off before any cement was pumped and the remedial shoot and sqz cementing went poorly also. There is enough cement above the Kuparuk zone to assure injection control but later during the completion phase a leak was also found in the liner at 6293' and so an additional packer was run above that to isolate it. This puts the top packer 1350' away from the injection zone (see attached 1E-08A well schematic) .... Well past the normal 200' limit for injectors. Additional sqz perfs have been shot below the lower packer and cement placed(for A to C sand isolation) ... the current operation is under-reaming the cement and then acquire another CBL in the 5.5" liner section below the packers. The well will initially be pre-produced for 3-6 months with it used ultimately as an injector( CPAI may request MWAG service). With the marginal cement quality and the placement of the upper packer an Administrative Approval (AA) should be generated for this well to insure extra safeguards and monitoring are in place before injection is started. G hwartz Senior Petroleum Engineer 2-23-11 1E-1 _k. Rotary Sidetrack - C1 Setup Completion Depth (Actual) 4 L. 16"65#H-40 casing @ •3-1/2"Gen IV Tubing Hanger ID 80'MD/80'TVD 9.3#1 •HES"X"Nipple 2.81"ID 500'/500' •3-i29.3#L s •3-1/2"X 1"KBMG GLM 2.867"ID 2,335'/2,230' •3-112"9.3#L-80 EUE 8RD •3-1/2"X 1"KBMG GLM 2.867"ID 3,483'/3,300' ____ -6 -.... .• •3-1/2"9.3#L-80 EUE 8RD •3-1/2"X 1"KBMG GLM 2.867"ID 4,542'/4,100' •3-1/2"9.3#L-80 EUE 8RD `� •3-1/2"X 1"KBMG GLM 2.867"ID 5,400'/4,840' t� 10-3/4"45.5#K-55 •3-1/2"9.3#L-80 EUE 8RD Al 1t.::! casing @ 2,896'MD/ •3-1/2'9.3#L-80 EUE Box X IBT-M SCC 5,450'/4,884' 2,705'TVD •3-1/2"9.3#L,, , •3-1/2"X 1"KBG-2-9 GLM 2.867"ID 6,190'/5,530' - w/2000 psi shear valve Drifted to 2.81" •3-1/2"9.3#L,._ , 5-'/2"TOL @ •3-1/2"9.3#L-80 IBT-M SCC Box X EUE 5,491'MD/4,921' •GBH-22 80-40 PBR,EUE 8 RD •KBH-22 Anchor Seal Assembly,EUE 8 RD TVD Sidetrack KOP •3-1/2"X 5-1/2"FAB Production Packer 6,265'/5,589' •3-1/2"9.3#L-80 NU 10RD Box X EUE 8RD thru window in 7"@ •„-1,2 d.3#Ln0 is-r-M SCC 5,712'MD/5,112'TVD •KBH-22 Anchor Seal Assembly,EUE 8 RD •3-1/2"X 5-1/2"FAB Production Packer 7,050'/6,090' •3-1/2"9.3#L-80 NU 10RDBox XEUE 8RD •3-1/2"9.3#L-80 IBT-M SCC •KBH-22 Anchor Seal Assembly,EUE 8 RD •3-1/2"X 5-1/2"FAB Production Packer 7,220'/6,189' •3-1/2"9.311E L-80 NU 10RD Box X EUE 8RD •3-1/2"9.3#L-80 EUE 8RD •HES"X"Nipple 2.81"ID Baker"K-1"CIBP _ •3-1/2"9 3#L-80 EUE 8RD Bottom set @ 5,736' •3-1/2"Mule Shoe WLEG MD/5,124'TVD i Packer 6,265'/5,589' 4 Packer 7,050'/6,090' Lower Kalubik 7,150'/6,148' 5-1/2"15.5#L-80 HD-L /\ ,.;;.. ,/ Liner(1,300') Tubing cmt retainer ._ Leak at 6,293' D / ��i C-Sand 7,294'/6,233' @ 6,753'MD/ ' , i 5,993'TVD 5-1/2"15.5#L-80 HD-L X/o 4/4( ., . ,• ST-L @ 6,779'MD/5,930' 6 �, B-Shale 7,432'/6,313' TVD Perfs 7,175'/6,160' A-Sand 7,602'/6,415' Packer 7,220'/6,189' 1 i iluveach 7,795'/6,532' 1 Ai Retainer 7,720'/6,493' � Perfs 7,725'/6,498' > '.i i. 7"Open Hole TD @ ' 7,860'MD/6,571'TVD 5-1/2"15.5#L-80 ST-L liner(1,038')@ 7,860'MD/6,571'TVD 7"26#K-55 casing Revised by: ..- , �e @ 7,568'MD/6,543'TVD Elmo Cecchetti Jan. 27, 2011 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 PTD# 7 Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: L ��c Ck � POOL: � !� /� LrG Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well KA [ (If last two digits in API number are Permit No. 2/C -/� ( ,API No. 50-L1 2�' /'t 1 - f. between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 •0 0 In0) D CD 0 D CO 0) D O. - CD 0 r b -n 71 ° n r- ( 0 N N 7 N .•' O (n co o.co w 0 w 0 w O 0 W O (7 N d N O N 0) O O "E O O CD O CD I O CD or CD , _, 0 o W W W co W W co W W CO N N N N IV N N N N IV . . CA CT A W N 0 CO CO V 0) 01 A W N -, +z co co V CO (1 W N — 0 CO OD V C) C1 A W N — 0 CO COW 0 (n 0) :0 -0 w) * 0 00 W 0 -* D - D 0 0 0 0 0) 0 - D 2` 0 - -0 O O =. 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