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211-047
STATE OF ALASKA RECEIVED AIDA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS DEC 1 4 2017 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ O..- a•• s hutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate 0 Alter Casing❑ Ch l•-III. .r_• r Gm ❑ Plug for Redrill ❑ 'erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: ACID STIMULATE 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development❑ Exploratory❑ 211-047 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic Service ❑ 6.API Number: 99510 50-103-20116-61 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 2K-13AL2 ADL 25588,ADL 25589 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 10,120 feet Plugs measured None feet true vertical 6,244 feet Junk measured None feet Effective Depth measured 10,120 feet Packer measured 9,099 feet true vertical 6,244 feet true vertical 6,121 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 feet 16 " 115' MD 115 TVD SURFACE 3,814 feet 9 5/8" 3,849'MD 2913 TVD PRODUCTION 9,435 feet 7 " 9,682'MD 6250 TVD SLOTTED LINER 1,000 feet 2 3/8 " 10,123'MD 6244 TVD Perforation depth Measured depth 9129-10123 feet True Vertical depth 6140-6244 feet Tubing(size,grade,measured and true vertical depth) 3.5" J-55 9,149'MD 6,153'TVD Packers and SSSV(type,measured and true vertical depth) PACKER- BAKER HB PACKER 9,099' MD 6,121'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A SCANNED -. 3 2 4 iJ i 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: 0 0 348 1300 2515 Subsequent to operation: 0 e 478 1475 2589 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development ❑ Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG 0 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: 317-143 Contact Name: Jason Burke Authorized Name: Jason Burke Contact Email:jason.burke@cop.com Authorized Title: Staff Wells Engineer / Contact Phone: (907)265-6097 Authorized Signa '-- Date:a-- 1 /7 VTL 1/2//f A /Q' REQ S LL L. a I,. 2017 Form 10-404 Revised 4/2017 ` " Submit Original Only • 2K- 1 3AL2 DAD ACID STIMULATE DTTMST,JOBTYF SUMMARYOPS 11/30/17 ACID RIH TO TOP OF 2-3/8" SLOTTED LINER. WASH WITH S.DIESEL FROM 9,123' - 10,123' RKB (END OF AL2 LINER).. CIRCULATE DAD ACID TO END OF COIL, PUH TO 9300' AT 10FPM SQUEEZING DAD ACID TO FORMATION, PR = 0.60 BPM/3970 PSI. SQUEEZE TOTAL VOLUME 83.4 BBL DAD ACID DISPLACING COIL WITH 35 BBL S. DIESEL. POOH. RIG DOWN. TURN WELL OVER TO PRODUCTION AND RETURN TO INJECTIN. MOVE CTU TO 1A PAD. SDFN. JOB COMPLETE. KUP I 2K-13A ConocoPhillips0's Well Attribut Max Angle& D TD Alask ,o,, Wellbore API/UWI Held Name Wellbore Status ncl(") MD(ftKB) Act Btm(ftKB) C. 0-pryg)ips 501032011601 KUPARUK RIVER UNIT INJ 95.41 10,300.23 11,691.0 .-. Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 210-13A,12/12/2017 1 0:38:08 AM SSSV:LOCKED OUT Last WO: 40.29 10/1/1989 Vertical.:dlemapc.(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:RKB 9,123.0 11/4/2011 Rev Reason.MANDREL ORIENTATION pproven 3/6/2016 HANGER;•31.1 Casing Strings QP' "8 8.118- Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen g...Grade Top Thread -LICONDUCTOR 16 15.062 36.0 115.0 1150 62.50 H-40 WELDED C Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread SURFACE 95/8 8.921 35.0 3,848.9 2,913.2 36.00 J-55 BTC OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread PRODUCTION 7 6.276 33.0 9,681.6 6,249.9 26.00 J-55 BTC "-ti CONDUCTOR;36.0-115.0^�' 2'-'✓✓✓•••kkk" °Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(1...Grade Top Thread WINDOW 312 2.992 9,254 0 9,259.0 6,223.9 9.30 „__.,L, Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread A SLOTTED LINER 2 3/8 1.995 9,692.5 11,691.0 6,234.2 4.70 L-80 STL SAFETY VLV,1,811.2 Liner Details Nominal ID GAS LIFT;2,859.8 Top(RKB) Top(TVD)(ftKB) Top Incl CI Item Des Corn (in) 9,692.5 6,249.7 91.05 BILLET Anchored Billet 1.995 $ '1 9,770.2 6,248.9 90.34 BULL NOSE Ported Bull-Nose 1.995 9,770.8 6,248.9 90.35 DEPLOY Shorty Deployment Sleeve 1.995 11,690.4 6,234.1 84.35 BULL NOSE Non-Ported Bull Nose 1.995 SURFACE;35.0-3,848.9-4 Tubing Strings Tubing Description String Ma... ID(In) Top(ftKB) Set Depth(ft..,Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection GAS LIFT;5,311.6 TUBING 31/2 2.992 31.1 9,149.3 6,153.4 9.30 J-55 EUE8rdABMOD Completion Details GAS LIFT;8,626.7 ID IF Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) a 31.1' 31.1 0.00 HANGER FMC GEN IV TUBING HANGER 3.500 GAS LIFT;7,266.8 1,811.2 1,657.0 44.69 SAFETY VLV CAMCO TRDP-1A SSSV.(LOCKED OUT 5/27/1994) 2.812 9,084.8 6,112.0 50.41 PBR BAKER 80-40 w/10'Stroke PBR 3.000 GAS LIFT;7,835.4 9,098.6 6,120.7 50.08 PACKER BAKER HB PACKER 2.890 9,137.3 6,145.6 49.86 NIPPLE OTIS XN NIPPLE **MILLED OUT TO 2.80"ID 2.800 4/15/2011** 9,148.6 6,152.9 49.90 SOS BAKER SHEAR OUT 2.992 GAS LIFT;8,441.6 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD) Top Incl 7 Top(ftKB) (ftKB) (°) Des Com Run Date ID(in) 9,249.0 6,217.5 49.90 Whipstock 3.5"MONOBORE WHIPSTOCK 5/25/2011 0.000 h GAS LIFT;9,039.9 Perforations&Slots Shot Dens Top(ND) Btm(ND) (shots/ r. .. Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com PBR;9,084.8 9,703.8 9,770.2 6,249.5 6,248.9 A-4,2K-13A 5/31/2011 32.0 SLOTS Alternating solid/slotted PACKER;9,098.5 pipe-0.125"X2.5"@ 4 circumferential adjacent 11. rows,3"centers TBG Punches;9,115.0 �i�yy��i. staggered 18 deg,3'non u'8+"- -slotted ends .�,,", "' 9,771.7' 11,690.4 6,248.9 6,234.1 A-4,2K-13A 5/31/2011 32.0 SLOTS - Mandrel Inserts St t I on Top(ND) Valve Latch Port Size TRO Run 1 N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) _ (psi) Run Date Corn .188 NIPPLE;9,137.3 .8 1 2,859.8 2,331.5 MERLA TMPD 1 "GAS LIFT DMY BK 0.000 0.0 11/14/1991 2:00 # ?4y" 2 5,311.6 3,769.1 MERLA TMPD 1 GAS LIFT DMY BK 0.000' 0.0 11/18/1991 5:00 SOS;9,148.6 3- 6,626.7 4,577.9 MERLA TMPD 1 GAS LIFT DMY BK 0.000. 0.0 4/17/1990 3:00 IS 4 7,268.9 4,974.9 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/17/1990 11:30 APERF;8,222.0-5,2380- 5 7,835.4 5,328.1 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/8/1991 11:00 6 8,441.6 5,706.5 CAMCO MMG-2 11/2 GAS LIFT DMY RK 0.000 0.0 11/8/1991 7:00 7 9,039.9 6,083.3 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/9/1991 7:00 Notes:General&Safety Whipstock;9,249.0 am End Date Annotation CEMENT PLUG;9,115.0 a198 WINDOW;9,254.0-8,259.0 - 6/9/2011 NOTE:SIDETRACK'A'8 LATERALS AL1,AL2(AL2 OFF MAIN WELLBORE) SLOTS;9,128.9-10,122.6- I I AL2 SLOTTED LINER;9,123.3- 10,123.0 SLOTS;9,479.0-9,644.5 ,dio.iir: SLOTS;9,645.9-10,043.0 PRODUCTION;33.0+9,681.8 AL1 SLOTTED LINER;9,467.0- 11,712.0 SLOTS;9,703.89,770.2 t 1 1 SLOTS;9,771.7-11,690.4 1- A A SLOTTED LINER;9,802.5- 11,801.0 KUP 12K-13AL2 CanocoPhiltips 8 Well Attribute.. Max Angle&MD TD Alder Inn Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) gips501032011661 KUPARUK RIVER UNIT INJ 95.54 10,070.21 10,120.0 ,— t ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 26-13AL2,12/12/201710'.37'.33 AM SSSV:LOCKED OUT Last WO: 40.29 10/1/1989 Verscal schematic.(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag:RKB 11/4/2011 Rev Reason:UPDATE PROD CSG RKB osborl 7/16/2012 init HANGER;31.1 Casing Strings Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread AL2 SLOTTED LINER 2 3/8 1.995 9,123.3 10,123.0 4.70 L-80 STL Liner Details �DIJ Nominal ID If)f Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Corn (in) ^ L+. 9,123 3 6,136.6 50.07 DEPLOY Shorty Deployment Sleeve 1.995 ury +a. 10.122.6 BULL NOSE Non-Ported Bull Nose 1.995 _A.n CONDUCTOR;36.0-115.0 `"r^ Perforations&Slots Shot Dens Top(ND) Btm(TVD) (shots/ SAFETYVLV;1,811.2 F..,1.. Top(RKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com ., 9,128.9 10,122.6 6,140.3 A-4,A-5,2K- 6/7/2011 32.0 SLOTS Alternating solid/slotted 13AL2 pipe-0.125"x2.5"©4 circumferential adjacent GAS LIFT;2,858.8 rows,3"centers staggered 18 deg,3'non -slotted ends Notes:General&Safety End Date Annotation 6/9/2011 NOTE:SIDETRACK'A'8 LATERALS AL1,AL2(AL2 OFF MAIN WELLBORE) SURFACE;35.03,848.9—' I GAS LIFT;5,311.6 GAS LIFT;5828.7al GAS LIFT;7,258.8 I GAS LIFT;7,835.4 it GAS LIFT;8,441.6 I GAS LIFT;9,039.9 PBR,9.084.8 PACKER,9,098.5 ' TBG Punches.91150 lljj���yytt 'kd,3B�; Y d 'k d. in NIPPLE; NIPPLE;9,137.3 SOS;9,148.8 APERF',9,222.0-9,238.0 Whipstock;9,249.0 q CEMENT PLUG;9,115.0 8KB.` F Rt WINDOW;9,254.0-9,259.0 AL1 SLOTTED LINER;9,487.8- II , 11,712.0 PRODUCTION;33.0-9,681.6 SLOTS;9,128.9-10,122.8- . AL2 SLOTTED LINER;9,123.3- 10,123.0 ,123.310,123.0 of rFJ • • y,'', \�y/ks� THE STATE Alaska Oil and Gas ��9Conservation Commissionl O T TQ �ii „ 333 West Seventh Avenue x GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Vilf\"' Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Jason BurkePR 9 l l, Wells Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field,Kuparuk River Oil Pool, KRU 2K-13AL2 Permit to Drill Number: 211-047 Sundry Number: 317-143 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, 4 ' PL Cathy '. Foerster Chair DATED this If day of April, 2017. RSDM' S Li.APR 1 2 2017 ' • STATE OF ALASKA • RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION APR 0 6 2017 APPLICATION FOR SUNDRY APPROVALS Pis 4-!rij 20 AAC 25.280 , GCC 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑✓ 4 Pull Tubing ❑ Change Approved Program❑ Plug for Reda ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: _Acid Stim ❑., 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska Inc Exploratory ❑ Development ❑ 211-047 . 3.Address: Stratigraphic ❑ Service a 6.API Number: PO Box 100360,Anchorage AK 99510 50-103-20116-61 i 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 ❑., // KRU 2K-13AL2 9.Property Designation(Lease Number): pg3 10.Field/Pool(s): ADL 25588 ) j 25S. Kuparuk River Unit/ Kuparuk River 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): 10123' " 6244' , 10123' + 6244'• 3089 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 16" 115' 115' Surface 3814' 9-5/8" 3849' 2913' Intermediate Production 9649' 7" 9682' 6250' Liner 1000' 2-3/8" 10123' 6244' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9128'-10120' , 6140'-6244' 3.5" L-80 9149' Packers and SSSV Type: CAMCO TRDP-1A-SSA(LOCKED OUT) Packers and SSSV MD(ft)and ND(ft): . 1811'MD&1657'ND Baker HB Packer 9099'MD&6121'ND 12.Attachments: Proposal Summary U Wellbore schematic ❑I 13.Well Class after proposed work: Detailed Operations Program ❑., BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development❑ Service ❑., 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 4/18/2017 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG 0, GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Jason Burke Email jason.burke@cop.com Printed Name Jason Burke Title Wells Engineer Signature Phone 907-265-6097 Date 7:75.../i/7. iiipK° COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: '1- ' LI S Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ LtS( 1.4 I 1.1%1 Other: �O RDDNIS 1-1- APR 1 2 2017 Post Initial Injection MIT Req'd? Yes ❑ No In----- � Spacing Exception Required? Yes ❑ No IA Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: 4—i f—17 � 7�(p�^ � AaIfor SubmitForm(and Form 10-400/5,1(729.g..74,,,_ ised 11/2015 V 4EIL44pp12 months from the date of approval. Attachments in Duplicate 1f07-- LLL...... • • ConocoPhillips Alaska,Inc. 11.-" Drilling & Wells ConocoPhillips Well Intervention Alaska 2K-13A DAD Treatment (TBD) 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 try to restore infectivity • Coiled Tubing: Spot DAD into formation 1. MIRU CT,MU 5 port wash nozzle BHA with 1.69"XRV tool 2. Begin RIH, circulating at minimum rate until 9100', slowly enter 2-3/8" liner at 9123' 3. RIH to bottom of liner, or as deep as lock up will allow 4. Begin pumping DAD treatment. When treatment is 5 bbls from exiting the CT (depending on CT volume) shut in the backside choke and begin squeezing into formation. Chase the DAD treatment with produced water or diesel. a. Do not exceed 4500 psi surface pressure 5. As treatment is exiting POOH at 8 fpm up to 9300' or until all treatment is pumped. 6. After an additional 5 bbl of fluid has been injected behind the treatment POOH 7. 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 F 103 15 gpt 63 gal Iron Control L058 20 ppt 76 lbs Non-emulsifier W054 2 gpt 19 gal Xylene A026 100 gpt 420 gal April 5, 2017 2K-13A Well Work Procedure Page 1 of 1 • • • 2K 2K=13 CTD Completion Schematic 3-1/2"Camco TRDP-1A SSSV(locked out)@ 1811'RKB 16"621 H-40 3-1/2"9.3#L-80 EUE 8rd Tubing to surface shoe @ 115' MD ' 3-1/2"Camco MMG gas lift mandrels @ 2860',5312',6627',7269',7835', 9-5/8"36#J-55 shoe 8442',9040'RKB @ 3848'MD Baker 3-1/2"80/40 PBR @ 9085'RKB ";;';;;`; Baker 3-1/2"o 7"HB retrievable packer @ 9099'RKB 3-1/2"Otis'XN'nipple @ 9137'RKB(2.75"min ID)(Has been milled out to 2-3/8"liner top 2.80"for CTD) @ 9,123'MD 3-1/2"tubing tail @ 9149'RKB C-sand perfs \:\\`� 9222-9238'MD KOP @ 9,259'MD I 2K-13AL2 TD@ 10,123'MD A-sand perfs _____________ _._______________ 2K-13A 9284-9318'MD TD @ 11,691'MD . AL1 billet @ 9.693'MD1 -�•- IAL2 billet @ 9,468'MDI PBTD 949T(2/2/11) 2K-13AL1 7"26#J-55 shoe@ 9439'(3/15/11) TD@ 11,712'MD 9677'MD `` KU P 2K-13AL2 CI COOCOPEIIllIps ," Well Attributes x Angle&MD TD Al.ltih:t.hu. ,, W& .. W IboAPWI Field Name ------- --- Well Status !not(•I MD(191113) m(R ) not SlKB) ,ro,,,i.,anl,,, 501032011661 (KUPARUK RIVER UNIT PROD 95.54 10.07021 10,120.0 Comment 92S Ippm) Dab Mnotatbndn EDab W b KB-Ord(It) Rig Release Da ... Wen Conk, •2K t3Al.i 11/52011 Sit 30 AM Ani LOCKED OUT - ILBst WO: 1 40.29 10/1/ 1989 Sclemato•Ackal Annotation Depth(RAS) End 0905 Annotation last Mod End Dab Last Tag:RKB 9,123.0 11/4/2011 Rev Reason:TAG ninam 11/5/2011 Casing Strings Casing Description String 0.. String 10 Top(RKB) Set Depth it Sat Depth(TVD) String Wt 1 g Strang Top Thrd� AL2 LINER 23/8 1.995 9,123.3 10,123.0 I-4.70 ISI "Stony STL RANGER.31 - Liner Details — Top Depth (T96) Top not NontI P Top(RKa) IRKS) I•) Item Descriptwn Comment ID(In) 9.123.3 6,136.5 49.66 DEPLOY Shorty Deployment Sleeve 1.995 10,122.6 BJLL NIS Non-Ported Bull Nose -_ 1.995 I Perforati• CONDVCTOR. Sha 35-115 Top IMO) Mtn(TYCO Dens Top(IRKS)Ban INNS) (ORB) (SKS) Zone Dab (eh.- Type Comment .9 9,129 10,123 6,140.2 A-4,2K-13 6/7/2011 32.0 SLOTS Alternating solid/slotted pipe- 0.125"x2.5"@ 4 circumferential adjacent rows,3"centers staggered SAFETY Vlv, is 18 deg,3'nor!-slotted ends 1.011 i - —-- — a GAS LIF1. g 2tw SURFACE. _y. l 353849 GAS LIFT. 5.312 II I GAS LIFT, B 527 all GASLFIie ]269—._--.-._ alli I q GAS LFT. 7835____._..._.. ■ GAS LIFT 0 442 ■ ■ Ill GAS L FT 9 040 R OAR 9055 PACKER,909911111. B TB0 Purace.. ;e; 9,115 • I NIPPLE 9,137 1 Mandrel Details I Top pin Top Port (TVDDe( Incl 00 Valva Lath 5100 TRO Run SOS 9.199 Stn Top(RKB) (ORB) (•) Make Mode) (In) Sart/ Type Typ• (In) (Pm/ Run Dab Com,.. 1 2,859.8 2,331.5 51.73 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/14/1991 2 5,311.6 3,769.1 53.09 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/18/1991 SPORT, 9222-923B\ 3 6,626.7 4,577.9 51.81 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/17/1990 WTp.bct 9.255\ 4 7,268.9 4,974.9 52.41 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/17/1990 CEMENT PLUG 9115 5 7,835.4 5,328.1 50.93 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/8/1991 SLOTS 912910.tri 6 8,441.6 5,706.2 50.36 CAMCO MMG-2 1 12 GAS LIFT DMY RK 0.000 0.0 11/8/1991 PRODUCTION 9.967 \ 29-98]] I 7 9,039.9 6,083.3 50.83 CAMCO MMG-2 1 12 GAS LIFT DMY RK 0.000 0.0 11/9/1991 TD(24.13512). 10,120 AL2 LINER, 9.12310.123 Image Project Well History File Cover Page XI-IVZE 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. Q�I I_ - 0 q-_ Well History File Identifier Organizing(done) Two-sided 11 III III ❑ Rescan Needed III 1111 11 111111 RE CAN DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ Diskettes, No. ❑ Maps: Greyscale Items: ❑ Other, No/Type: ther Items Scannable by a Large Scanner joss ❑ Poor Quality Originals: OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: 1120 Date: 6 �,5 ` /s/ vviP Project Proofing I 11E111111 MI BY: ( Mari )a Date: V[16-- Is! illf Scanning Preparation a x 30 = 6() + = TOTAL PAGES cunt does not include cover s eet) BY: Date: (i / .ShILf /s/ � Production Scanning II 11111110 Mil Stage 1 Page Count from Scanned File: (05. (Count does include cove heet) Page Count Matches Number in Scanning Preparation: YES NO BY: 111=0 Date: W( f3. //L7i. /s/imp 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. II 11111111 1 1111 ReScanned I 111111111011111 BY: Maria Date: /s/ Comments about this file: Quality Checked II IIIII 111 III III o c c 9 o O \ m = u N t U 7 W cuo u. II, r a)M yI X n_ Uo r in I H EId - N g aO °as z UO OI 0 Q c •E yl 1 O 0 Z SII V N N N N N N Li I I Q I 0) r4 u) in co co co co U O N N N N Z 1�' �EI CD CO N- N- N. N C W 2 d 7 C C C C C C E N m 1 c 00 a a a) op 0. a s E a /�/� < Y 0 0 0 0 0 0 V 0 Ce J QC. IIIco a 0 0 0 0 0 0 OW ° N N N M (N.- yi. /� J V ' III a ., u) 0 O O O a y a Z ZZ� i li J_ ! 11! Z i g l' 11 W = � w co z "// N t O N- O v `i 0 C a� M M O O O CO U Cl) 0) 0) CD O) C• I a) 0 m W Z > O J a) ° U 0 Q m y w Z uo Ce a 1 re Z 1 cr o o Q c o 7 v) O J a cv s •m ca ° E CL NO zI a `UUc0 C r O J Cl)' nl) 0 lL CO °� O 5-4" a a) '° 0) E a o u N 10 1 N o E 1 J W co 1 03 N Q M I [ T r N ' a i- I2 1 2 Z m I o S N G N COM CD c D t 1 Q Q W Q Y m 0 a > > >. >. Z C _ >. a) O a) Q) -4 Q UJ Z N N V) Ca 1 C6 .o co co Z m m m 2 C C C C C C y d 0 0 O O ,O •O v c E t •� .0 .J u o N (a J o o 7 N ' 7 a) a) Z ._ m E _pto < 6 I >,- N. N. 0 Tr O J .b M •0 1 CO 0 I m cc 3E v. -tu c mcoo — 2 } 0 r Q Z t C CL .+ WOZ w O 0 m 0 m N Q p`o a ° 0 z c% > c o Z o u. (4 y _ E E _) ce u '3_ in ° co _ 0 ' 1 0 O u 0 d Q \ 4-,c in Z Q C's O 0 1�! I c J 0 0 0 'n.? E a a aE 0 �1' Q: ! 0 F- �s J O H LU 0 �_.__I J J W I Q > 0 Q� 1 U 0 4) 0 0 0 0 _ m 0 .0 c a) o 0 - STATE OF ALASKA ,./1 ' ALASKI-. AND GAS CONSERVATION COMMISSIC REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair well ❑ Rug Perforations ❑ Stimulate ❑ Other[rJ Prod to INJ Mer Casing ❑ Rill Tubing ❑ Ferforate New Fbol ❑ Waiver ❑ Time Extension ❑ Change Approved Program in Operat.Shutdown ❑ Perforate ❑ Re-enter Suspended Well r 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Development iq Exploratory ❑ "" 211-047 3.Address: 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic ❑ Service r • 50-103-20116-61--00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25588,25589 ^ 2K-13AL2 9.Field/Pool(s): Kuparuk River Field/Kuparuk River Oil Pool 10.Present Well Condition Summary: Total Depth measured 10120 feet Plugs(measured) None true vertical 6244 feet Junk(measured) None Effective Depth measured 9115 feet Packer(measured) 9085,9099,9115,9137,9149,9255 true vertical 6131 feet (true vertucal) 6112,6121,6131,6146,6153,6221 Casing Length Size MD TVD Burst Collapse AL2 LINER 1000 2.375 10123 6244 0 0 o o 0 o o 0 0 0 0 0 RECEIVED 0 Perforation depth: Measured depth: 9128-10120 True Vertical Depth: 6140-6244 FEB 0 7 2012 Alaska Oil&Gas Cons. Commission Tubing(size,grade,MD,and TVD) 3.5,J-55,9149 MD,6153 ND Anchorage Packers&SSSV(type,MD,and ND) PBR-BAKER 80-40 W/10'STROKE PBR @ 9085 MD and 6112 ND PACKER-BAKER HB PACKER @ 9099 MD and 6121 ND TBG PUNCHES-PRE-CEMENTING TUBING PUNCHES IN TTL W/2"MILLENIUM BIG HOLE,6 SPF @ NIPPLE-OTIS XN NIPPLE **MILLED OUT TO 2.80"ID 4/15/2011 **@ 9137 MD and 6146 ND SOS-BAKER SHEAR OUT @ 9149 MD and 6153 ND WHIPSTOCK-3.5"MONOBORE WHIPSTOCK @ 9255 MD and 6221 ND 11.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 163 313 139 359 278 Subsequent to operation 3334 800 2217 13.Attachments 14.Well Class after work: Copies of Logs and Surveys run Exploratory ❑ Development ❑ Service n Stratigraphic r 15.Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Daily Report of Well Operations GSTOR ❑ WINJ r WAG E GINJ ❑ SUSP ❑ SPLUG ❑ 16.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 311-351 Contact Christensen/Humphre Printed Name R R.•ert'i2 hri e n / Title Prod. Engineering Specialist Signature ,�#/ lir Phone:659-7535 Date 0,.../6.1 Form 10-404 Revised 10/2010 RBDMS FEB 0 7 2-RP' .2.;-,2- Submit Original Only 2K-13AL2 I 'y DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 01/06/12 Commenced Water injection • KUP 2K-13AL2 J ConocoPhillips Well Attributes x Angle&MD TD ,1!.1,•:,I, Wellbore API/OWI Field Name Well Statue Incl r) MD(10(B) Act Btm(141(8) (,n[xnYhlLps , 501032011661 KUPARUK RIVER UNIT PROD 95.54 10,070.21 10,120.0 Comment - 1125(ppm) Date Annotation End Date KB-(3rd(ft) Rig Release Date •' "- -—SSSV:LOCKED OUT Last WO: 40.29 10/1/1989 Well Conlg.-2K-13AL2 115/2011 924.30 AM Schematic-Actual Annotation Depth(ft18) End Date Annotation Last Mod .,End Date Last Tag:RKB 9,123.0 11/4/2011 Rev Reason:TAG ninam 11/5/2011 - Casing Strings Casing Description String 0... string ID...Top(f0(B) Set Depth(f...Bet Depth(TVD)...String Wt...String... String Top Thrd AL2 LINER 2 3/8 1.995 I 9,123.3 ret I 4.70 I L-80 I STL HANGER,31 Liner Details • mp Depm (TVD) Top Incl Nom)... Top(f0(B) (f K8) (°) Item Description Comment ID(in) 9,123.3 6,136.5 49.66 DEPLOY Shorty Deployment Sleeve 1.995 10,122.6 BULL NOSE Non-Ported Bull Nose 1.995 Perforations&Slots CONDUCTOR, She. 36115 Top(TVD) Btm(TVD) Dens Top(ftKB) Btm(ftKB) (fIKB) (MB) zone Dote Ub-- Type Comment 9,129 10,123 6,140.2 A-4,2K-13 6/7/2011 32.0 SLOTS Alternating solid/slotted pipe- 0.125''x2.5"@ 4 circumferential ii[. adjacent rows,3"centers staggered SAFETY VLV, aa.. 18 deg,3'non-slotted ends 1,811 r GAS LIFT, ' 2,860 SURFACE, . 35-3949 f GAS LIFT, r 1.111 ■` 5,312 7f GAS LIFT, 6,827 GAS.239 p IFT. 7.269 7p GAS LIFT, 7,835 GAS LIFT, 8,442 GAS UFT. 9,040 FOR,9,085 PACKER,9,099 — - Iiiiill • TBG Punches. 9,115 IIIIp NIPPLE,9,137 Mandrel Details W Top Depth Top Port (TVD) Incl OD Valve Latch Site TRO Run SOS,9,149 -- Stn Top(10(B) (FMB) (°) Make Model (In) Sery Type Type (In) (psi) Run Date Com... 1 2,859.8 2,331.5 51.73 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/14/1991 2 5,311.6 3,769.1 53.09 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/18/1991 APERF, 9,222-9,238\ 3 6,626.7 4,577.9 51.81 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/17/1990 Whipstock. 9,255\ 4 7,268.9 4,974.9 52.41 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/17/1990 CEMENT PLUG.9.115 5 7,835.4 5,328.1 50.93 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.011/8/1991 SLOTS. • 9,129-10,123 6 8,441.6 5,706.2 50.36 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/8/1991 PRODUCTION,\ 299577 7 9,039.9 6,083.350.83 CAMCO MMG-2 1 12 GAS LIFT DMY RK 0.000 0.0 11/9/1991 TO(2K-13AL2), 10,120 AL2 LINER, . 9,12310,123 1 S � i - > L S 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 Darrell Humphrey Production Engineering Specialist ,+ D1+17 ConocoPhillips Alaska, Inc. I P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2K-13AL2 Sundry Number: 311-351 Dear Mr. Humphrey: 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, 9 i Daniel T. Seamount, Jr. 7/-6 Chair DATED this 6 f day of November, 2011. Encl. 1--1TE OF ALASKA Al 1 OIL ANG ;CONSERVATION COMMISS APPLICATION FOR SUNDRY APPROVALS -I(0 20 AAC 25.280 1.Type of Request Abandon ❑ Plug for Redrill ❑ Perforate New Fbol ❑ Repair well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Ferforate ❑ Pull Tubing ❑ Time Extension ❑ Operational Shutdown ❑ Re-enter Susp.Well [j Stimulate ❑ Alter casing ❑ Other:Prod to INJ • p 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. ConocoPhillips Alaska,Inc. Development[i . Ekploratory In 211-047 ' 3.Address: Stratigraphic❑ Service ❑ 8.API Number. P.0.Box 100360,Anchorage,Alaska 99510 50-103-20116-61 7.If perforating,closest approach in pool(s)opened by this operation to nearest property line 8.Weil Name and Number where ownership or landownership changes: Spacing Exception Required? Yes ❑ No Q 2K-13AL2 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25588,25589° 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): 10120 . 6244- 9115' • 6131' • Casing Length Size MD TVD Burst Collapse AL2 LINER 1000 2.375 10123' 6244' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9128-10120 6140-6244 3.5 J-55 9149 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PBR-BAKER 80-40 W/10'STROKE PBR MD=9085 TVD=6112 EC E t VEu PACKER-BAKER HB PACKER MD=9099 TVD=6121 NOV ® 9M 11 TBG PUNCHES-PRE-CEMENTING TUBING PUNCHES IN TTL W/MD=9115 1VD=6131 l! NIPPLE-OTIS XN NIPPLE "•MILLED OUT TO 2.80"ID 4/15/2011 MD=9137 TVD=6146 �+ SOS-BAKER SHEAR OUT MD=9149 TVD=8153 Alaska Oil CSB Cons. Commission WHIPSTOCK-3.5"MONOBORE WHIPSTOCK MD=9255 TVD=6221 AI"CI"Or itC 12.Attachments: Description Summary of Proposal n 13. Well Class after proposed work: • Detailed Operations Program ElBOP Sketch ❑ Exploratory ❑ Development En Service P 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: • 12/1/2011 Oil ❑ Gas ❑ WDSPL ❑ Suspended E 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG 12 ' Abandoned ❑ Commission Representative: GSTOR El SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Darrell Humphrey Printed Name Darrell Humphrey Title: Prod.Engineering Specialist Signature 1 c(4 11- - _ _ Phone:659-7535 Date I 1 -7 - t Commission Use Only Sundry Number./,I I Conditions of approval: Notify Commission so that a representative may witness ✓ Plug Integrity❑ BOP Test ❑ Mechanical Integrity Test [vocation Clearance E Other. Subsequent Form Required: /D_ y / APPROVED BY . Approved by. // COMMISSIONER THE COMMISSION Date: /1//61 I I 1 R. \or N I� Form 10-403 RReviseD St OV 1 7 YO 0R1GINAL A �j9 /Submit in Duplicate I { 2K-13AL2 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert KRU Well 2K-13A, 2K-13AL1, 2K-13AL2 from Oil Production service to WAG Injection service.Well 2K-13A will be used for reservoir pressure support for 2K- 08,2K-14, 2K19. The 16"Conductor was cemented with 170sx ASII (121'and/121'tvd).The 9-5/8"Surface casing (3849'and /2913'tvd)was cemented with 1125sx AS III, and 500sx Class G. The 7" Production casing (9677'and/ 6519'tvd)was cemented with 300sx Class G. The top of the Kuparuk A was found at 9258'and/6223'tvd. The injection tubing/casing annulus is isolated via Baker'HB"retrievable packer 3.5"located @ 9099'and/ 6121'tvd. 11/4/11 MIT IA 3000 PSI, PASSED. Passing MITIA(8.4 bbls diesel): PreTIO=900/720/20, Initial T10=900/3000/20, 15 min=900/2880/20, 30 min=900/2840/20 ,IIva� 14,0a.�i> � 4f qfre �DaI�C�'/ �4) c/ , N' fee/ P" pia CQ sf4 r,' • P IP 13AL2 Conocornulip6 a Well Attributes Max Angle& TD Wellbore APINWI Field Name Well Status Incl(°) MD(Po(8) Pct Btm(RKB) ' ..o„oo „I„P, 501032011661 ,KUPARUK RIVER UNIT PROD 95.54 10,070.21 10,120.0 Comment H2S(ppm) Date Annotation End Date KB43rd(ft) Rig Release Date ”' _SSSV:LOCKED OUT Last WO: 40.29 10/1/1989 Well Conte-2K-13AL2,117572011 92430 AM Schematic-Actual Annotation Depth(RK8) End Date Annotation Last Mod...End Date Last Tag:RKB 9,123.0 11/4/2011 Rev Reason:TAG ninam 11/5/2011 Casing Strings Casing Description string o... 'String ID .Top(1tK8) Set Depth(L..Set Depth(TVD) String Wt...String... Siring Top Thrd AL2 LINER 12 3/8 1.995 I 9,123.3 I 10,123.0 I I 4.70 I L-80 STL HANGER,31 Liner Details Top Depth (TVD) Top Incl Komi_ Top(RKB) (R") (°) Kam Description Comment ID(In) 9,123.3 6,136.5 49.66 DEPLOY Shorty Deployment Sleeve 1.995 10,122.6 I Perforations&Slots BULL NOSE Non-Ported Bull Nose 1.995 CONDUCTOR, Shot' 38-115 Top(TVD) atm(TVD) Dens Top(RKB) Btm(RKB) (RKB) (ORB) Zone Date (0— Type Comment 9,129 10,123 6,140.2 A-4,2K-13 6/7/2011 32.O'SLOTS Alternating solid/slotted pipe- 0.125'x2.5"@ 4 circumferential • adjacent rows,3"centers staggered SAFETY VLV 18 deg,3'non-slotted ends 1 GAS LIFT, 2,860 I SURFACE, .1 l 35-3,849 r GAS L.IFT IFT. 7iF 5 r 1 GAS,62LIFT, �. 87 GAS LIFT, 7,259 GAS LIFT, - 1 4 7935 GAS LIFT. 8, -f 4T. Js GAS LIFT 1_ j 4 PBR,9,085 PACKER,9.099 TBG Punches, 9,115 NIPPLE,9,137 Mandrel Details Top Depth Top Port (TVD) Incl OD Valve Latch Size TRO Run SOS,9,149 Ste Top(RKB) (RKB1 I") Make Model (in) Sery Type Type (In) (psi) Run Dote Com... 1 2,859.8 2,331.5 51.73 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/14/1991 2 5,311.6 3,769.1 53.09 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/18/1991 9,222-9,238 N 3 6,626.7 4,577.9 51.81 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/17/1990 Whipstock, 9,255 4 7,268.9 4,974.9 52.41 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/17/1990 CEMENT PLUG,9,115 5 7,835.4 5,328.1 50.93'MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/8/1991 SLOTS, 9,129-10,123 6 8,441.6 5,706.2 50.36 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/8/1991 PRODUCTION,\ 28e,677 7 9,039.9 6,083.3 50.83 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/9/1991 r TD(24-13AL2), 10,120 AL2 LINER, 9,123-10,123 RFCENED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION I i111'.F WELL COMPLETION OR RECOMPLETION REPORT AND LO,O A la.Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned❑ Suspended ❑ 1b.Well Class: ,ty(16� ,3t 1f1�1$310f1 20AAC 25.105 20AAC 25.110 Development ❑� , '"..•.' zpitory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service ❑ Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: June 7,2011 211-047/ 3.Address: 6.Date Spudded: 13.API Number: P.O.Box 100360,Anchorage,AK 99510-0360 June 5,2011 50-103-20116-61 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 69'FNL,94'FEL,Sec. 11,T1ON, R8E, UM June 6,2011 2K-13AL2 Top of Productive Horizon: 8. KB(ft above MSL): 154'RKB 15.Field/Pool(s): 1856'FNL, 1385'FEL,Sec. 10,T1ON, R8E, UM GL(ft above MSL): 118'AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 1878'FNL, 1331'FEL,Sec. 10,T1ON,R8E, UM 9115'MD/6131'TVD Kuparuk River Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-498310 y- 5938235 Zone-4 10120'MD/6244'TVD ADL 25588,25589 TPI: x-491741 y- 5936452 Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x-491795 y- 5936430 Zone-4 1811'MD/1657'TVD 2674,2675 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) 1502'MD/1424'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 9468'MD/6253'TVD 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 36' 115' 36' 115' 24" 170 sx AS II 9.625" 36# J-55 36' 3849' 36' 2913' 12.25" 1125 sx AS III,500 sx Class G 7" 26# J-55 36' 9677' 36' 6519' 8.5" 300 sx Class G 2.375" 4.7# L-80 9123' 7 10120'' 6137' 6244' 3" slotted liner 24.Open to production or injection? Yes a No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/ND) 3.5 9149' 9099'MD/6121'TVD slotted liner from 9128'-10120'MD 6140'-6244'TVD 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. .S F10�1 !' IV DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED ° tolaLA:1 ji: 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) June 18,2011 gas lift oil Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 6/21/2011 21 hours Test Period--> 1285 2792 647 176% 2466 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 318 psi not available 24-Hour Rate-> 1329 3279 722 not available 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No E Sidewall Cores Acquired? Yes ❑ No ❑✓ If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. NONE RBDMS JUL 0 5 1011 .4171 Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit original only 28.,GEOLOGIC MARKERS(List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ 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 1502' 1424' needed,and submit detailed test information per 20 AAC 25.071. A4 9467' 6253' A5 10062' 6248' N/A Formation at total depth: Kuparuk A4 30. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: J.Ohlinger @ 265-1102 9(�. G/90/// Printed Name L. antt Title: CTD Engineering Supervisor / Signature C tiAlkdk rf Phone 263-4021 Date 6/3d//r 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 Imo. ps - KUP 2K-13AL2 Ct)11UCt3f�ifjl Max Angie&MD Ti) A(aSrtB Wellbore APW WI Field Name Well Stat Incl() MD(ftKB) Act Btm(ftKB) _ 4444 i.cnx. Isar_. 501032011661 KUPARUK RIVER UNIT PROD _95.54 ( 10,070.21 _ Comment N2S(ppm) Date Annotation End Dat KB-Grd(ft) Rig Release Date "' D -..2K.?.. 1:4t1A71-LA9.7971M SSSV:LOCKED OUT - _(Last WO: 40 29 10/1/1989 �� _�g L_ Annotation s (Depth MKS) End Date �Atatr Last Mod End Date Last Tag:SLM 9,392.0 3/15/2011 Rev Reason:ADD NEW LATERALS _ warn_ 6/16/2011 Casing Strings Casing Description I String 0... String ID...'Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...'String Top Thrd HANGER.31— r AL2 LINER 23/8 � 1.995 1-.-.9,123.3 I10,123.0 4.70 L-80 STL .pc Liner Details Top Depth 1 r. (TVD) Top incl Noml... Top(ftKB) ( B) (°) ltrm ne Deiptbn Comment ID(in) 9,123.3 6,136.5 49.66 DEPLOY Shorty Deployment Sleeve 1.995 ,.•.:e. - .: ._ 10,122.6 BULLNOSE Non-Ported Bull Nose 1.995 CONDUCTOR, Perforations&Slots 36-115 —__— Shot —_ --_ tTop(TVD) She(TVD) Dane ;.: Top(81KB) Ben(MCB), (BKB) KIM Zone Date (ah-- Type Comment SAFEttvtV, We- 9,129 10,123 6,140.2 A-4,2K-13 6/7/2011 32.0 SLOTS Alternating solid/slotted pipe- 1 811 .. 0.125"x2.5"@ 4 circumferential adjacent rows,3"centers staggered I, 18 deg,3'non-slotted ends GAS LIFT. --''Z- 2,860 SURFACE, _i 35-3,848 GAS LIFT, 5,312 GAS LIFT, mwile 6,627 GAS LIFT, if_ 7,269 - GAS LIFT, 7,835 GAS LT, 8402IF I GAS LIFT, r, 9.040 PER,9,085 _.-.-r .....I PACKER,8,099 --- TBG Punches, 9,115 1 Ir NIPPLE,9,137 , SOS,9,149 - APERF. _ 9.222-9,238 -.-.. Whipstock, 9,255 CEMENT PLUG,9,115 SLOTS, 9,129-10,123 -f ".'. PRODUCTION. " 29-9,677 .. _, Mandrel Details 4_444. ._ Top Depth Top Port (ND) Incl 01) Valve Latch Size TRO Run ^^"^^ Ste fop(NKB) (ftKB) (") Make Model (01_ Darn Type Type (in) (psi) Ron Dab Com... V' 1 2,859.8 2,331.5 51.73 MERLA TMPD 1 GAS UFT DMY BK 0.000 0.0 11/14/1991 SLOTS, 9,704.9,770ME _ 2 5,311.6 3,769.1 53.09 RLA r 1 GAS LIFT DMY BK 0.000 0.0 11/18/1991 "" -.,=.7.- 3 6,626.7 4,577 9 51.81 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/17/1990 .,.",..Z;,7.-... 4 7,268.9 4,974.9 52.41 MERLA TMPD 1 GAS LIFT DMY BK 0.000' 0.0 4/17/1990 5 7,835.4 5,328.1 50.93 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/8/1991 ~ 6 8,441.6 5,706.2 50.36 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/8/1991 AL2 LINER, '-. 7 9,039.9 6,083.3 50.83 CAMCO MMG-2 1 12 GAS LIFT DMY RK 0.000 0.0 11/9/1991 9,123-10,123 `. SLOTS, 9,772-11,690 A LINER, ' ' 9,693-11,691 TD(2413AL2), 11,891 1 0 2 H Yo r N JQ C7 @ Y OV N H 2 inO - 0 y ih O = C co E Q O o m N a Ip RN H Et m = \;s:\N Y I� i _ i m co d' P 11 co i .. O ,fit. 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CO (0 O M (O O N IO CD V Is- 0 CO (O CO N u) CO V h CO N t� i.e (a ' v_ In In In (n (o 0 (o I.-- is-- n (CI ao co CO_ 0) 0) 0) Q 0 0 0 T� a d _ s m O co co CO 0i of 0) 0) 0) 0CO CO 0i 0) 0) 0 0 0 0) 0 0 O O O O U E '0 CD76a ((wVj ConocoPhiIIips Time Log & Summary We/Mew Web Reporting Report Well Name: 2K-13 Rig Name: NABORS CDR2-AC Job Type: DRILLING SIDETRACK Rig Accept: 5/15/2011 6:00:00 AM Rig Release: 6/9/2011 12:00:00 AM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/14/2011 24 hr Summary Move to 2K-13 20:00 00:00 4.00 0 0 MIRU MOVE MOB P Mobilize rig to 2K-13 05/15/2011 MIRU,Complete BOPE test witnessed by John Crisp AOGCC, Pull BPV 00:00 06:00 6.00 0 0 MIRU MOVE MOB P Get modules spotted, Rigging up 06:00 06:30 0.50 0 0 MIRU WHDBO SFTY P PJSM 06:30 08:30 2.00 0 0 MIRU WHDBO NUND P NU BOP, Continue RU 08:30 10:30 2.00 0 0 MIRU WHDBO CIRC P Move injector to well, reverse circulate coil with inhibited water and _ fresh water 10:30 11:06 0.60 0 0 MIRU WHDBO BOPE P Test inner reel valve,John Crisp with AOGCC on location to witness BOP testing. 11:06 21:06 10.00 0 0 MIRU WHDBO BOPE P Continue with testing,swab valves _ leaking,called out grease crew. 21:06 23:30 2.40 0 0 MIRU WHDBO BOPE P PJSM, R/U BPV Lubricator and pull BPV First time out no BPV,Got BPV on second attempt R/D and load out lubricator. SIWP=370PS1 23:30 00:00 0.50 0 0 MIRU WELLPF CTOP P PJSM, Install checks in upper Q/C 05/16/2011 Milled cement in tubing tail and into casing. Cement was of poor quality. PU under reamer. 00:00 00:09 0.15 0 0 MIRU WELLPF CTOP P Install Check valves in UQC(cont) 00:09 00:54 0.75 0 0 MIRU WELLPF SFTY P Hop Pre spud meeting with night crew 00:54 01:42 0.80 0 0 SURPRI WELLPF PULD P PJSM, Load BHA#1,Cement pilot hole, .8 degree motor and D-331 01:42 02:42 1.00 0 0 SURPRI WELLPF PRTS P M/U PDL to well, PT PDL&TT line 02:42 04:42 2.00 0 62 SURPRI WELLPF PULD P PJSM, Deploy BHA#1, Surface test tool Initial SIWP=1270. Line up and bleed off to TT. S/I and check for build up 04:42 07:24 2.70 62 9,000 SURPRI WELLPF TRIP P RIH,WHP bled to 50, EDC open, weight checks every 1000' 07:24 07:54 0.50 9,000 9,100 SURPRI WELLPF TRIP P Weight check at 9000',37K PUW. Close EDC, 1.33 BPM, 3150 pump PSI,200 WHP, 3430 BHP,biozan 15 Bbls out mill,315 DP at motor. Continue RIH to tag at 9100 CTMD, not tied in. 16K RIW Page 1 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:54 08:18 0.40 9,100 9,113 SURPRI WELLPF MILL P Start milling, at 60 FPH with 300 WOB,75 PSI motor work 08:18 08:36 0.30 9,113 9,116 SURPRI WELLPF MILL P Bio back to surface,Weight check, 35K PUW, 16K RIW, 1.33 BPM, 3500 pump pressure, 320 DP,3800 BHP with 250 WHP,cement in returns. Stalls at 9116.4'still not tied in. 08:36 12:06 3.50 9,116 9,130 SURPRI WELLPF MILL P Several stalls at 9116-9117',CCL log indicates that this is the milled out XN nipple. Worked through very slowly unsing the CRTF method. Had difficult time all the way to the TT 12:06 13:06 1.00 9,130 9,152 SURPRI WELLPF MILL P Continue milling ahead,able to mill at 75 FPH at<500 WOB and 150 psi motor work 13:06 13:36 0.50 9,152 9,150 SURPRI WELLPF MILL P PUH and log K1, +26.5'correction 13:36 15:42 2.10 9,150 0 SURPRI WELLPF TRIP P POOH 15:42 16:57 1.25 0 0 SURPRI WELLPF PULD P At surface, undeploy BHA#1 16:57 18:00 1.05 0 0 SURPRI WELLPF PULD P Lay down BHA#1 /Crew change 18:00 21:15 3.25 0 0 SURPRI WELLPF PULD P M/U BHA#2 Weatherford Motor and Haily underreamer. Load into PDL and pressure deploy.Surface test coil track 21:15 00:00 2.75 0 8,858 SURPRI WELLPF TRIP P RIH 05/17/2011 RIH begin Underreaming cement from 9170'. Slow ROP throughout the day with multiple stalls starting U/R process. 00:00 00:18 0.30 8,858 8,858 SURPRI WELLPF TRIP P ;RIH 00:18 01:18 1.00 8,858 8,858 SURPRI WELLPF SFTY P Suspend ops for Iditarod Hazzard Hunt Luncheon 01:18 01:48 0.50 8,858 9,090 SURPRI WELLPF TRIP P Close EDC,start RIH to tie in at .15BPM, Pressured up, PUH to clear, RIH dry to tie in 01:48 02:00 0.20 9,090 9,160 SURPRI WELLPF DLOG P Tie into K-1 for+26', 02:00 05:00 3.00 9,160 9,170 SURPRI WELLPF UREM P RIH to ensure we are out of TT, Pumps online, Pressured up. Make several attempts to spin motor,work 10'area to open blades. 05:00 17:00 12.00 9,170 9,210 SURPRI WELLPF UREM P Underreaming 1.10 bpm,4050, BHP 3730,diff press 1400psi,WOB 1.2K, ROP 1 -2 fph.Multiple stalls getting started. P/U weight 38K. Light metal shavings on magents. 17:00 00:00 7.00 9,210 9,234 SURPRI WELLPF UREM P Add water to system to Iwer LSRV to help with pump pressure. 1.10 bpm, 3990psi, BHP 3680, Diff press. 1440 psi, ROP 1 -2 fph,WOB 1K. Light metal shavings on magnets. ROP 3- 4 fph from 9222'. IA 885 psi/OA 620 psi. 05/18/2011 POOH to change BHA&U/R. Dep0loy BHA#3 with BOT motor and 6.14"U/R blades. RIH-encoutered gas influx near bottom.Circ. out gas&try to start Underreaming. Hard time getting started @ 9237'. Page 2 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 05:00 5.00 9,234 9,241 SURPRI UREAM IUREM P 1.1 bpm,3850 psi, BHP 3640,diff 1450, ROP 2-3 fph,WOB 1.2K, light metal shavings with cement returns.41K P/U off bottom. 05:00 07:12 2.20 9,241 111 SURPRI UREAM TRIP P Trip out to inspect BHA, ROP<2 FPH, PUW=40K 07:12 10:12 3.00 111 111 SURPRI UREAM TRIP P PJSM, Undeploy BHA#2, Weatherford straight motor and Haily underreamer 10:12 11:42 1.50 111 0 SURPRI UREAM PULD P Undeploy BHA#2, Lay down BHA, All blades and mill on surface 11:42 15:00 3.30 0 0 SURPRI UREAM CTOP P S/B on Under reamer, Run injector head tests while waiting on tools 15:00 16:00 1.00 0 0 SURPRI UREAM PULD P Baker under reamer on location. BOT rep stated can't run Baker under reamer on weatherford motor. Break out weatherford motor/P/U baker motor 16:00 17:15 1.25 0 64 SURPRI UREAM PULD P PJSM, Deploy BHA#3, Baker Under reamer on baker motor, M/U to coil track,surface test 17:15 22:15 5.00 64 9,237 SURPRI UREAM TRIP P RIH-tie in with+22.5 ft correction. P/U weight 42K. Rlh to 9170'close EDC and start working down with U/R. Trap 120 psi on WHP due to light gas migration from trip in hole.Tag and stall at 9237'. Pump B/U to clear out fluid/gas migration. ECD 12.1. Difficult time getting started due to multiple stalls. Increase ECD to 12.3. 1:1 returns,gas cleaned up. 22:15 00:00 1.75 9,237 9,237 SURPRI UREAM UREM P Begin reaming-WHP 280 psi, ECD 12.3, 1.40 bpm,3780psi, BHP 3790, diff 740 psi,WOB.5K.Slow ROP, max able to make it down is 9237.14' continue to stall at different speeds, rates etc. back reamed up to ensure clean. P/U and try to dry drift past. No-luck. Max. CT cycle in area 13% 05/19/2011 POOH to lay down BHA#3 BOT U/R. Pick up hailey U/R 6.150. RIH to continue U/R process from 9237'. Better ROP. 00:00 01:30 1.50 9,237 9,237 SURPRI UREAM UREM P Call town and discuss lack of footage with U/R, BHA or slip sticking.Try one more time to make hole from 9237.14'. Stall @ 7237.17'& _7237.24'speed less than 1 fph. 01:30 04:30 3.00 9,237 64 SURPRI UREAM TRIP P POOH following MPD for BHA change. haily UR&weatherford motor in route. 04:30 06:00 1.50 64 0 SURPRI UREAM PULD P PJSM-Undeploy BHA. Drill out orfice on hailey U/R from 8/32 to 9/32. Page 3 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 08:00 2.00 0 0 SURPRI UREAM PULD P PJSM-crew change P/U BHA#4 with 2 3/8"Weatherford motor and new Hailey U/R.,Make up coil track to coil, Surface test. PT TT line to manifold 08:00 10:15 2.25 0 9,100 SURPRI UREAM TRIP P RIH, EDC Open,follow MP schedule 10:15 10:30 0.25 9,100 9,156 SURPRI UREAM DLOG P Gamma tie in for+19.5',close EDC 10:30 11:06 0.60 9,156 9,239 SURPRI UREAM TRIP P Trip into 9163,bring pumps online 1 BPM @ 4081, Stall @ 9239 a couple times,time mill past this spot 11:06 18:06 7.00 9,239 9,250 SURPRI UREAM REAM P U-ream ahead. Making 2 to 4 FPH with random stalls. Holding—12.2 ECD 18:06 00:00 5.90 9,250 9,265 SURPRI UREAM REAM P Crew change, ream Ahead 1.04 BPM @ 3950 FS,300 PSI WHP, 12.34 ECD,5150 BHP. Multiple stalls @ 9260'worked through. 05/20/2011 Complete U/R down to 9278'. Pump Sweep&SW. perform injection test-min. injection. Static WHP 2560 psi, BHP 5550 psi. 10 min. leak down-WHP 1670, BHP 4274 psi. POOH, purge CT&swap reels. 00:00 02:00 2.00 9,265 9,277 SURPRI UREAM UREM P Continue U/R-1 bpm, 3900 psi, BHP 3870,WHP 280, ECD 12.3, ROP 7 fph,differential 1180 psi.Mix up visc pill. 02:00 04:00 2.00 9,277 9,278 SURPRIUREAM UREM P Pump down 20 bbl HI-visc Bio pill while reaming last couple of feet. Back ream up past 9230'.20 bbl Bio sweep/20 bbl Bio/followed by SW. choke pluggin off as sweep came to surface. 04:00 05:00 1.00 9,278 9,250 SURPRI UREAM UREM P Stop pumping,trap 900 psi. Open EDC. Flush choke SW in coil and 40 bbls up the backside. Injectivity test. Start=WHP 950 psi, BHP 3960,Circ 1100psi,depth 9250'. IA 825/OA 275 pump.3 bpm-WHP 2560 psi, BHP 5550,circ 2550 psi no injection.-10 min.draw down final= WHP-1670 _psi, BHP-4274 psi. Circ 1380psi 05:00 07:30 2.50 9,250 96 SURPRI UREAM TRIP P POOH holding MPD pumping 1.40 bpm SW 07:30 09:30 2.00 96 0 SURPRI UREAM PULD P PJSM,Tag up and space out, PUD _BHA#4, Blow down tool 09:30 12:30 3.00 0 0 SURPRI WELLPF SQEZ P PSSM, Mix and pump corrosion inhibitor, N2 Reel blowdown 12:30 17:00 4.50 0 0 SURPRI WELLPF SQEZ P Unstab injector,Cut off CTC, Dress coil for grapple connector, R/U and unstab coil back to reel and secure 17:00 22:00 5.00 0 0 SURPRI WELLPF SQEZ P Remove E-coil&install work string. 22:00 00:00 2.00 0 0 SURPRI WELLPF SQEZ P Install grapple connector and putt test for stabing pipe. PJSM Stab pipe. Page 4 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/21/2011 24 hr Summary Perfrom cement squeeze-Pump 150 bbls heated SW-15 bbls 17#cement followed by 1.5#BIO. Injection rate.25 bpm @ 3700 psi.Squeezed 7 bbls behind pipe. Start pressure 2100 psi,end pressure 3600 psi. Drop ball,Jet down to 9115'with BIO, POOH @ 80%with 1:1 returns holding 1900 psi on WH. Flush stack, lines &all valves at surface. 00:00 04:00 4.00 0 0 SURPRI WELLPFSQEZ P Pull pipe across and stab pipe. Secure reel&injector. Install counters and reel iron rig up for cement job. 04:00 05:30 1.50 0 0 SURPRI WELLPF SQEZ P Set up mud pumps to fill CT with SW &pump 2"wiper dart through CT string.Zero pump counter when water at inner reel iron. 30.50 bbls until dart&fluid reached EOP. 05:30 10:30 5.00 0 7 SURPRI WELLPF SQEZ P M/U CTC, Pull test 32K, PT CTC and Inner reel iron, M/U Cementing BHA with 5'stinger and 2.25 ball drop nozzle, Inspect pack offs, PT Lubricator and stack to 4K, Perform Lo-Hi PT on inner reel valve. 10:30 13:15 2.75 7 9,238 SURPRI WELLPF SQEZ P RIH,WHP=1000 to maintain 1 to 1 returns,Tag bottom and correct to 9278, PUH 5'and paint flag. 13:15 14:45 1.50 9,238 9,100 SURPRI WELLPF SQEZ P Circulate hot seawater 150 BBIs recip up to TT, 1.8 BPM @ 3200 PSI WHP=1000PSI to maintain 1 for 1 14:45 15:30 0.75 9,100 9,100 SURPRI WELLPF SQEZ P Injectivity test.25 BPM @ 3700 PSI, Trip in well 15:30 16:00 0.50 9,100 9,273 SURPRI WELLPFSQEZ P PJSM with crew, cementers,truck drivers 16:00 16:36 0.60 9,273 9,273 SURPRI WELLPF SQEZ P At flag, pump 5 BBI spacer followed by 15 BBIs 17Lb/GI cement/5 BBIs fresh water 16:36 17:00 0.40 9,273 9,273 SURPRI WELLPF SQEZ P Goto Bio following Cement with rig pumps, 1.15 BPM @ 2850 Circ pressure, 1050 WHP 17:00 17:45 0.75 9,273 7,360 SURPRI WELLPF SQEZ P 3 BBI out PUH in 7"1 BPM @ 40 FPM, PUH to TT,Slow pumps to.5 pull @ 55 FPM slowing down as we gained on TOC down to 37 FPM. Pull out of cement @ 8228. Pull up to safety @ 7350,Worst case TOC 7975 WHP=1000PSI 17:45 18:00 0.25 7,360 7,353 SURPRI WELLPFSQEZ P S/I well @ 1000PSI, Pump 2.4 BBIs WHP up to 3700PSI,Shutdon pump WHP dropped to 2550, Pump.8BBIs back up to 3700,S/D pump fell rapidly to 2400 PSI., pump.9 to 3800PSl. Double block surface lines and pump. Static @ 2200 psi. PJSM -crew change Page 5 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 20:00 2.00 7,353 7,353 SURPRI WELLPF SQEZ P 15 min.-Step#3-pumped .9 bbl, WHP 3100 psi,Circ.4000psi. END WHP 2160 psi,Circ.2170. 10 min-Step#4-pumped.6 bbl, WHP 3600 psi,Circ 3840 psi. END WHP 2450, Circ.2500 15 min-Step#5-pumped .4 bbls, WHP 3600, Circ 3800 psi END WHP 2940, circ 2940 30 min-Step#6-pumped .22 bbls, WHP 3700, Circ 3790,Solid straight line. Drop ball in reel while waiting& rig down cement line. Final-WHP 3600,Circ 3640. 20:00 20:30 0.50 7,353 9,115 SURPRI WELLPF TRIP P Estimated 7 bbls behind pipe- pumping ball around with 1.5#bio holding 1900 psi on WH. P/U weight 24K. RIH jetting Blo.Auto choke acting up. Stop flush&reset. good 1850 with 1:1 returns. Circ press. increased to 4150 when ball hit. P/U weight 30K. @ 8650' 8900'circ press climbing slightly. Weight check 28K. RIH-Circ press 4250 @ 1.5 bpm. RIH speed 50 fpm, WHP 1850, 1:1 returns. 20:30 21:15 0.75 9,115 6,000 SURPRI WELLPF TRIP P POOH 29K Weight swings from 24- 31 K.at 80%pumping 1.5 bpm,60 fpm holding 1900 psi WHP 1:1 returns to open top. Heavy Cement/Bio returns. Increase to 80 fpm @ 8900'@ 1.3 bpm. Jet GLM while POOH. IA 880/ OA 97 21:15 21:30 0.25 6,000 5,400 SURPRI WELLPF TRIP P Cement returns to open top cleaned up, reduce pump rate to 1.1 bpm,80 fpm,WHP 1900 psi. 1:1 returns. Final count 110 bbls into open top. 21:30 21:45 0.25 5,400 6,300 SURPRI WELLPF TRIP P RIH to fix reel spool, reel drag issues while POOH. 21:45 23:15 1.50 6,300 15 SURPRI WELLPF TRIP P POOH holding 1900 WHP 1:1 returns-clean BIO. Pull up slowly through mast/shut swab valves.Trap 1960 psi on Well. 23:15 00:00 0.75 15 0 SURPRI WELLPF CIRC P Grease crew on location to grease tree valves for BOP test. Pop off injector and inspect BHA. Recover Ball . Set up to flush BOP stack and all surface valves. 05/22/2011 Full BOPE test waived by John Crisp. Pump inhibitor through workstring, install foam pig&purge with N2. Unstab pipe&remove hard line. Replace shaker bed in mud pits. 00:00 03:30 3.50 0 0 SURPRI WHDBO CIRC P Flush and grease all surface lines, valves and stack after cement job. Replace pack off on injector. 03:30 06:30 3.00 0 0 SURPRI WHDBO BOPE P ***"Start BOPE test'"'test inner reel iron and tree valves. Page 6 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:30 10:30 4.00 0 0 SURPRI WHDBO BOPE P End BOPE Test 10:30 10:45 0.25 0 0 SURPRI WELLPF SQEZ P Pump up manage pressure line to 1500PS1,Open up to well, WH P=1385 Consult with town, Plan forward pump corrsion inhibitor N2 Reel blowdown 10:45 12:30 1.75 0 0 SURPRI WELLPF SQEZ P PJSM,M/U nozzle to coil and stab on well, Pump 30bbl fresh water,30 BBI inhibitor, 30BBIs fresh water 12:30 14:12 1.70 0 0 SURPRI WELLPF SQEZ P SLB N2 Unit on location, R/U, Break inner reel iron and install foam pig PT N2 Line to 3K 14:12 14:30 0.30 0 0 SURPRI WELLPF SQEZ P N2 Online, 1500 SCM 14:30 15:30 1.00 0 0 SURPRI WELLPF SQEZ P N2 off line,saw dart hit connector, bleed down 15:30 19:00 3.50 0 0 SURPRI WELLPF SQEZ P PJSM, Unstab injector,cut off CTC. Prepare for reel swap Recovered coil pig in nozzle 19:00 00:00 5.00 0 0 SURPRI WELLPF SQEZ P Begin unstabing Coil from injector. Had difficult time with coil position on reel&gooseneck. Stop job, clamp off coil and cut pipe -40 feet. Re-head cable and pull pipe to get the lifting eyes in the correct position.Clamp and secure reel. Update reel string with 40 ft cut. 05/23/2011 Complete reel swap, injector service, replace motor brakes. Replace Shaker bed. pressure test inner reel iron,CT connector&pack-off. Bleed down Well to zero-no flow. RIH Tag TOC 9077'. Numerous stalls getting started. 00:00 03:00 3.00 0 0 SURPRI WELLPF SQEZ P Remove reel iron&flanges. Lower work string onto Bed truck. 03:00 06:00 3.00 0 0 SURPRI WELLPF SQEZ P P/U E-string off bed truck. Install reel iron and prepare to stab pipe. 06:00 07:45 1.75 0 0 SURPRI WELLPF SQEZ P Crew change, PJSM, Stab coil, R/D stabbing equipment 07:45 09:45 2.00 0 0 SURPRI WELLPF SQEZ P Wire up inner reel line and test E-line -61 Ohmes Prep coil and install conector, Pull test to 30K, 09:45 10:15 0.50 0 0 SURPRI WELLPF SQEZ P Rehead E-Line and test 10:15 11:15 1.00 0 0 SURPRI WELLPF SQEZ P PJSM, Load PDL BHA#6, Pilot hole mill, .8 degree motor 11:15 13:30 2.25 0 0 SURPRI WELLPF SQEZ P Change Injector brakes and service injector, Inspect choke B 13:30 14:06 0.60 0 0 SURPRI WELLPF SQEZ P PJSM, Pump up well via MP line to 2500, Shut R1 and stabilized @ 2450, Bled down to 2421 in 30 Minutes Page 7 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 14:06 14:48 0.70 0 0 SURPRI WELLPF SQEZ P Install pressure cap,circ fluid around and fill stack. Equilize across swab valves and open. Bleed well to shaker 14:25 start No Flo Test,test for 20 minutes Good test 14:48 17:48 3.00 0 0 SURPRI WELLPF SQEZ P M/U coil on well and fill coil,Shell test wash pipe and new reel swivel, PT Inner reel valve 17:48 19:00 1.20 0 62 PROD1 WHPST PULD P P/U BHA#6 with D331 Bit&0.8 AKO motor. 19:00 22:00 3.00 62 8,500 PROD1 WHPST TRIP P RIH with EDC open monitoring potential electrical surges. POOH from 2000'. Injector&motor surges off/on, minimal. Check for lower amperage off/on, not specific timing with D141 operations. RIH 8500' Close EDC. 22:00 22:30 0.50 8,500 9,078 PROD1 WHPST TRIP P 8570'heard a loud pop on rig floor. Stop&inspect injector.WOB& string weight is normal. P/U weight 36K. up to 8400'-pipe looks good. Injector motor has slight vibration noises. RIH-good.Tag cement top @ 9080' P/U 41K. Increase pump rate to 1.4 bpm.Starting to get dirty water/bio fluid in returns,scale mixture to surface. No oil or gas. take returns to Tiger tank. IA 880/ OA 0 22:30 23:30 1.00 9,078 9,078 PROD1 WHPST MILL P Circ 2600 psi at 1.5 bpm.CT weight 33K. RIH light tag @ 9078'Stall, Motor work @ 2600psi&stall at 3400psi.-TF 20 right. B/U-Bring returns inside, clean Blo with cement cuttins.Start time milling due to 8 stalls. 23:30 00:00 0.50 9,078 9,078 PROD1 WHPST MILL P Start time milling.-cannot tie in to correct depth at 9100'.CTES EOP depth 9033'. 05/24/2011 Mill cement pilot hole 9077'to 9275'. Drift cement pilot with Dummy WS. 00:00 02:15 2.25 9,078 9,081 PROD1 WHPST MILL P Time milling-1.55 bpm,2780psi, BHP 3270,WHP 0,WOB.55, CT weight 15K. P/U weight 39K.20 right TF. Stalls. Pressure seem lighter than normal.with higer P/U weights 40K. P/U 200 ft to clean area. Getting very light cement and scale in returns with Bio. 02:15 03:15 1.00 9,081 9,091 PROD1 WHPST MILL P Roll TF to low side to see if it helps with stalls due to possible cement stringers/ramp. 1.55 bpm,2870, BHP 3320, ROP 6 fph,WOB.3K, CT weight 14.5K. Much better ROP 20 fph.WOB.5K Cement over shakers with samples of scale. Page 8 of 20 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 03:15 04:15 1.00 9,091 9,100 PROD1 WHPST MILL P Continue milling ahead Lowside until tie-in depth. 1.55 bpm,3070psi, BHP 3365, ROP 20,WOB.65, CT weight 15K.Good cement returns to surface. 04:15 06:00 1.75 9,100 9,123 PROD1 WHPST MILL P Roll to 20 ROHS. 1.55 bpm, 3100 psi, ROP 12,WOB.7K.Good hard cement&motor work from 9105'. 1.55 bpm, 3400 psi, BHP 3430, ROP 10,WOB 1.1K.Tie in correction depth= 06:00 12:00 6.00 9,123 9,160 PROD1 WHPST MILL P Crew change,Continue to mill ahead.Still no depth correction 1.55 BPM @ 3270 BPM,TF 20RHS 12:00 16:00 4.00 9,160 9,275 PROD1 WHPST MILL P Casing contact at 9160.7' uncorrected depth. Continue milling at 1.5 BPM, 3950 CTP,0 WHP, 11.16 ECD,2.5 WOB, 250 motor work and 50 FPH. Increase WHP to maintain 12.0 ECD 16:00 16:24 0.40 9,275 9,075 PROD1 WHPST REAM P PUH, low side tool face from 9190'to 9150'. Continue up to 9075' 16:24 16:54 0.50 9,075 9,275 PROD1 WHPST DLOG P Tie-in, no correction. 16:54 17:24 0.50 9,275 9,275 PROD1 WHPST REAM P Dry-drift pilot hole 17:24 19:54 2.50 9,275 0 PROD1 WHPST TRIP P POOH 19:54 20:09 0.25 0 0 PROD1 WHPST SFTY P At surface, PJSM 20:09 21:09 1.00 0 0 PROD1 WHPST PULD P Undeploy BHA 6 21:09 22:39 1.50 0 0 PROD1 WHPST PULD P Deploy BHA 7,WS drift 22:39 00:00 1.35 71 9,158 PROD1 WHPST TRIP P RIH take weight at 9140 and 9148'. 1-2K 05/25/2011 Drift cement pilot hole with Dummy WS BHA,down to 9275'. POOH, RIH to Dress cement pilot through transition area with DS331 mill with sidecutters and.8 AKO, POOH, RIH with WS. Set WS at 9255'TOWS oriented high side. 00:00 03:00 3.00 0 0 PROD1 WHPST TRIP P At Surface, PJSM 03:00 06:00 3.00 0 0 PROD1 WHPST PULD P Undeploy Dummy whipstock,deploy milling BHA with D331 with ridge set cutters and 0.8 deg motor 06:00 08:30 2.50 0 9,275 PROD1 WHPST TRIP P RIH,tie in to K1, +21' At 9148'saw 700 WOB with 120 psi motor work 08:30 10:00 1.50 9,275 9,040 PROD1 WHPST REAM P Tag bottom, PUH, pumping at 1.6 BPM,3600 CTP,340 WHP for 3900 BHP. Ream up at 6 FPM oriented 180, 135,225 seeing motor work and negative WOB at 9150'each time 10:00 10:30 0.50 9,040 9,240 PROD1 WHPST DLOG P CCL log to confirm TT depth, no correction Page 9 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 10:30 12:00 1.50 9,240 9,000 PROD1 WHPST REAM P Continue with back reaming passes, 90 and 270. Final pass at 180 slowing to 1 FPM from 9155'to 9135' Dry-drift looks good pump 5 Bbls low vis and 10 Bbls high vis sweeps 12:00 14:42 2.70 9,000 0 PROD1 WHPST TRIP P POOH 14:42 15:00 0.30 0 0 PROD1 WHPST SFTY P PJSM 15:00 17:30 2.50 0 0 PROD1 WHPST PULD P Undeploy milling BHA 17:30 18:00 0.50 0 0 PROD1 RPEQP1SVRG P Service Injector head, reel 18:00 18:30 0.50 0 0 PROD1 RPEQPI SFTY P Crew change PJSM 18:30 19:30 1.00 0 0 PROD1 RPEQP1PULD P Deploy BHA(whipstock) 19:30 21:45 2.25 72 9,100 PROD1 RPEQP1TRIP P RIH 21:45 22:00 0.25 9,100 9,100 PROD1 RPEQPI DLOG P Tie in depth+20.5'correction 22:00 22:30 0.50 9,100 9,266 PROD1 RPEQP1WPST P RIH to 9270', PUH to set WS 9265.5. TOWS=9255'. 22:30 22:45 0.25 9,266 9,266 PROD1 RPEQP1WPST P Oreint 0 deg TF,Set WS,4200pst CTP,set odwn 2.5K WOB. Looks good. 22:45 00:00 1.25 9,266 7,000 PROD1 RPEQP1TRIP P POOH 38K PUW. 05/26/2011 Mill window 9258-9264'.Mill rat hole to 9276'. Back ream HS,30L and 30R of HS. Dry drift, POOH 00:00 00:30 0.50 7,000 0 PROD1 RPEQP1TRIP P POOH 00:30 00:45 0.25 0 0 PROD1 RPEQP1SFTY P At surface, PJSM 00:45 01:30 0.75 0 0 PROD1 RPEQP1PULD P Undeploy BHA 9 01:30 02:00 0.50 0 0 PROD1 RPEQPI PULD P LD BHA 02:00 03:00 1.00 0 0 PROD1 WHPST PULD P Deploy BHA 10 03:00 05:30 2.50 9,100 PROD1 WHPST TRIP P RIH 05:30 05:45 0.25 9,100 9,100 PROD1 WHPST DLOG P Tie in depth 05:45 06:15 0.50 9,255 9,255 PROD1 WHPST TRIP P RIH to TOWS 06:15 06:48 0.55 9,255 9,255 PROD1 WHPST CIRC P Swap hole over to used Flo-Pro for milling window 06:48 14:30 7.70 9,259 9,264 PROD1 WHPST MILL P Tag WS dry at 9259', PUH and start pumping at 1.4 BPM,4000 CTP, 13.5K RIW,WOC for 4050 BHP. Stall at 9258.6'. Start time milling 1 FPH, up to 2K WOB and 200 PSI motor work 14:30 17:18 2.80 9,264 9,268 PROD1 WHPST MILL P WOB dropped to 600 and motor work dropped to 100 psi. Bottom of window,continue at 1 FPHto 9264.6 then increase ROP to 2 FPH. 1.4 BPM,4000 CTP,4070 BHP with WOC 17:18 19:18 2.00 9,268 9,277 PROD1 WHPST MILL P Drilling foramtion at 3-4 FPH Page 10 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 19:18 20:39 1.35 9,277 9,276 PROD1 WHPST MILL P PUH backreaming HS, 30L adn 30R of HS 9269-9255'. Pump 1 Obbrl high vis sweep.All reaming Looked good. Dry drift window, Looks Good 20:39 23:09 2.50 9,276 0 PROD1 WHPST TRIP P Open EDC, POOH 23:09 23:24 0.25 0 0 PROD1 WHPST SFTY P At surface, PJSM 23:24 00:00 0.60 0 0 PROD1 WHPST PULD P Undeploy/LD BHA 10(window mill 2.79"No-Go,2.80 Go, String mill 2.79"No-Go,2.80"Go) 05/27/2011 Drill build section 9276-9350', POOH, Undeploy BHA 11, Perform BOPE function test. Deploy BHA 12 (Rib-Steer motor). Perform mud swap. Drill A Lateral 9276'-9660'. 00:00 01:45 1.75 0 0 PROD1 DRILL PULD P PU/MU and Deploy BHA 11 (2.4 AKO, Hughes Bi-Center-RR) 01:45 03:45 2.00 63 9,100 PROD1 DRILL TRIP P RIH 03:45 04:00 0.25 9,100 9,100 PROD1 DRILL DLOG P Tie in depth+21'correction 04:00 04:30 0.50 9,100 9,276 PROD1 DRILL TRIP P RIH to drill 04:30 05:36 1.10 9,276 9,320 PROD1 DRILL DRLG P Drill Ahead 1.4 BPM,4150 CTP, 4070 BHP with WOC, 13.5K RIW 05:36 06:06 0.50 9,320 9,320 PROD1 DRILL DLOG P Tie in K1 and RA,TOW 9258', RA at 9264' 06:06 06:48 0.70 9,320 9,350 PROD1 DRILL DRLG P Continue drilling, 1.4 BPM,3850 CTP,4070 BHP with WOC, 13.5K RIW 06:48 09:30 2.70 9,350 0 PROD1 DRILL TRIP P POOH following MPD tripping schedule 09:30 09:42 0.20 0 0 PROD1 DRILL SFTY P PJSM for undeployment 09:42 11:00 1.30 0 0 PROD1 DRILL PULD P Undeploy BHA#11 11:00 11:30 0.50 0 0 PROD1 DRILL SFTY P Crew change, PJSM 11:30 12:18 0.80 0 0 PROD1 DRILL PULD P Complete undeployment 12:18 13:18 1.00 0 0 PROD1 DRILL SVRG P Service injector and lay down rig floor mats 13:18 15:06 1.80 0 0 PROD1 DRILL PULD P Deploy BHA#12 for drilling"A" lateral with RSM and USR 15:06 17:21 2.25 0 9,100 PROD1 DRILL TRIP P RIH, Start new mud down CT while tripping 17:21 17:36 0.25 9,100 9,100 PROD1 DRILL DLOG P Tie in depth 21.5'Correction.Closed EDC 17:36 17:51 0.25 9,100 9,350 PROD1 DRILL TRIP P RIH 17:51 21:06 3.25 9,350 9,510 PROD1 DRILL DRLG P Continue drilling, 1.4 BPM, 3950 CTP,4110 BHP with WOC, 13.5K RIW 21:06 21:51 0.75 9,510 9,510 PROD1 DRILL WPRT P Wiper trip to window 33K PUW, MAD pass 9355-9280' 21:51 23:24 1.55 9,510 9,660 PROD1 DRILL DRLG P Continue drilling, 1.4 BPM,3900 CTP,4115 BHP with WOC, 13.5K RIW 23:24 00:00 0.60 9,660 9,660 PROD1 DRILL WPRT P Wiper Trip to window,33.5K PUW 05/28/2011 Drill A Lateral 9660'to 10357'.Temporarly stuck 9860'9934'bit depth. Pull free both instances 55K holding MP with pumps off. Hold fire drill in Generator 2 room. Hold safety discussion after drill. Page 11 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 02:15 2.25 9,660 9,810 PROD1 DRILL DRLG P Continue drilling, 1.4 BPM,3955 CTP,4125 BHP with WOC, 13.5K RIW 02:15 03:00 0.75 9,810 9,810 PROD1 DRILL WPRT P Wiper Trip back to window, 33K PUW, No correction to tie in with RA marker 03:00 04:15 1.25 9,810 9,887 PROD1 DRILL DRLG P Continue drilling, 1.4 BPM,3975 CTP,4120 BHP with WOC, 13.5K RIW 04:15 04:45 0.50 9,887 9,887 PROD1 DRILL WPRT P PU for GEO wiper.Trip back to window 04:45 06:24 1.65 9,887 9,903 PROD1 DRILL DRLG P Continue drilling, 1.4 BPM, 3950 CTP,4118 BHP with WOC, 13.5K RIW, after a stall got hung up at 9860'bit depth,shut down pump with choke shut in and came free. Wiper trip during crew change to 9615' 06:24 08:48 2.40 9,903 9,934 PROD1 DRILL DRLG P Continue drilling, 1.3 BPM,3650 CTP,4100 BHP with WOC, 13K RIW. Slow drilling 08:48 09:48 1.00 9,934 9,934 PROD1 DRILL DRLG T Annular pressure started to increase by 100 psi, Picked up and became stuck, unable to get any indication on DH WOB up or down. After CBU shut in well with 3900 BHP,stacked down weight to-5K then PUH to 55K and came free. 09:48 10:42 0.90 9,934 9,934 PROD1 DRILL WPRT T Wiper to window,circulated 5 bbls lo-vis, pressures came back to normal. 10:42 14:48 4.10 9,934 10,085 PROD1 DRILL DRLG P Continue drilling ahead, 1.35 BPM, 3700 CTP,4150 BHP with WOC, 13K RIW, ROP increasing 14:48 15:48 1.00 10,085 10,085 PROD1 DRILL WPRT P Wiper to window,31K, 13K RIW 15:48 18:18 2.50 10,085 10,235 PROD1 DRILL DRLG P Drilling ahead, 1.32 BPM,3750 CTP, 4236 BHP with WOC, 18:18 20:33 2.25 10,235 10,235 PROD1 DRILL WPRT P Wiper Trip to window,33.5K PUW,0 correction with tie in to RA marker, last 10'see drag 700lbs on WOB at window 9280'. Mix up hi/low sweeps for next wiper 20:33 00:00 3.45 10,235 10,357 PROD1 DRILL DRLG P Drilling ahead, 1.32 BPM,4000 CTP, 4273 BHP with WOC, 05/29/2011 Drill A Lateral 10357'to 11285'. Swap out mud. 00:00 00:45 0.75 10,357 10,385 PROD1 DRILL DRLG P Drilling ahead, 1.32 BPM, 3975 CTP, 4236 BHP with WOC, 00:45 02:00 1.25 10,385 10,385 PROD1 DRILL WPRT P Wiper trip to window, chase 10bbrl low/high sweep. 34K PUW 02:00 04:30 2.50 10,385 10,535 PROD1 DRILL DRLG P Drilling ahead, 1.32 BPM,4100 CTP, 4236 BHP with WOC, 04:30 06:06 1.60 10,535 10,535 PROD1 DRILL WPRT P Wiper Trip to window,34K PUW, 14K RIW 06:06 07:36 1.50 10,535 10,685 PROD1 DRILL DRLG P Continue drilling ahead, 1.35 BPM, 3950 CTP,4260 BHP with WOC, 13K RIW 07:36 08:24 0.80 10,685 9,278 PROD1 DRILL WPRT P Wiper to window, 33K PUW Page 12 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:24 08:36 0.20 9,278 9,310 PROD1 DRILL DLOG P Tie-in, -2 08:36 09:18 0.70 9,310 10,685 PROD1 DRILL WPRT P Wiper back in hole, 13.5K RIW 09:18 10:24 1.10 10,685 10,835 PROD1 DRILL DRLG P Continue drilling ahead, 1.33 BPM, 3930 CTP,4260 BHP w/WOC 10:24 12:12 1.80 10,835 10,835 PROD1 DRILL WPRT P Wiper trip to window, 31K PUW, 14K RIW 12:12 13:42 1.50 10,835 10,985 PROD1 DRILL DRLG P Drilling ahead, 1.35 BPM,3950 CTP, 4260 BHP w/WOC 13:42 15:42 2.00 10,985 10,985 PROD1 DRILL WPRT P Wiper to window,31K PUW, 13.5K RIW 15:42 16:54 1.20 10,985 11,135 PROD1 DRILL DRLG P Continue drilling ahead,started mud swap with returns to TT. 1.33 BPM, 3950 CTP,4300 BHP with WOC, WHP=90 while going to TT. 16:54 19:24 2.50 11,135 11,135 PROD1 DRILL WPRT P Wiper to window, 30K PUW, +3' correction to RA marker 19:24 21:39 2.25 11,135 11,285 PROD1 DRILL DRLG P Drilling ahead, 1.35 BPM,3957 CTP, 4194 BHP w/WOC 21:39 00:00 2.35 11,285 11,285 PROD1 DRILL WPRT P Wiper Trip to window,33K PUW 05/30/2011 TD"A"Lateral 11687'.Wiper trip to swap valves. RBIH lay in liner runnning pill displacing well to KWF. 00:00 03:15 3.25 11,285 11,475 PROD1 DRILL DRLG P Drilling ahead, 1.35 BPM,3957 CTP, 4194 BHP w/WOC 03:15 05:48 2.55 11,475 11,475 PROD1 DRILL WPRT P Wiper Trip to window 34K PUW 05:48 07:48 2.00 11,475 11,620 PROD1 DRILL DRLG P Continue drilling, 1.34 BPM, 3900 CTP,4320 BHP, Pumped low/high sweeps, 07:48 08:18 0.50 11,620 11,620 PROD1 DRILL WPRT P Wiper trip to 11300, 29K PUW and 13K RIW 08:18 09:48 1.50 11,620 11,687 PROD1 DRILL DRLG P Continue drilling, 1.34 BPM, 3900 CTP,4320 BHP, low/high sweeps, TD at 11687' 09:48 13:24 3.60 11,687 120 PROD1 DRILL WPRT P Wiper to swab valve 13:24 15:54 2.50 120 9,100 PROD1 DRILL WPRT P RBIH with EDC open 15:54 16:09 0.25 9,100 9,100 PROD1 DRILL DLOG P Tie in K1 marker.-1.5'correction 16:09 17:39 1.50 9,100 11,698 PROD1 DRILL WPRT P RIH to TD 17:39 19:09 1.50 11,698 9,264 PROD1 DRILL WPRT P Tag TD, 11698.95', 11'deeper???. POOH laying in liner running pill 19:09 19:15 0.10 9,264 9,130 PROD1 DRILL DLOG P Tie into RA marker,-21.5' correction. PUH to K1 19:15 19:21 0.10 9,130 9,130 PROD1 DRILL DLOG P Tie in to K1 marker-.5'correction 19:21 22:00 2.65 9,130 0 PROD1 DRILL TRIP P POOH laying in KWF 22:00 22:15 0.25 0 0 PROD1 DRILL SFTY P At surface, Flow check,. PJSM 22:15 22:45 0.50 0 0 PROD1 DRILL PULD P LD BHA 12. 22:45 23:15 0.50 0 0 COMPZ CASING PULD P Prepare floor to run liner 23:15 23:30 0.25 0 COMPZ CASING SFTY P PJSM 23:30 00:00 0.50 COMPZ CASING PUTB P PU/MU liner Page 13 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 05/31/2011 24 hr Summary RIH set liner&anchored billet from 11,699'-9693'. P/U drilling BHA with 0.8 AKO and 2.73"Bi-center. RIH& _circulate out KWF. 00:00 02:00 2.00 0 0 COMPZ CASING PUTS P Cont. picking up liner 02:00 02:15 0.25 0 0 COMPZ CASING SFTY P BOP Drill 02:15 03:30 1.25 0 0 COMPZ CASING PUTB P Cont. running liner 03:30 05:18 1.80 1,964 9,164 COMPZ CASING RUNL P RIH, Correct depth at flag, +24.3',wt check,38K PUW(-12K on DHWOB), 17K RIW 05:18 06:12 0.90 9,164 11,699 COMPZ CASING RUNL P Continue RIH 06:12 06:24 0.20 11,699 9,235 COMPZ CASING RUNL P Tag TD, 11699'. Pump at 1 BPM, 4500 CTP, released from liner, POOH 06:24 06:48 0.40 9,235 9,275 COMPZ CASING DLOG P Log RA,-4',top of liner at 9774' 06:48 09:48 3.00 9,275 0 COMPZ CASING RUNL P POOH 09:48 10:03 0.25 0 0 COMPZ CASING SFTY P At surface, PJSM 10:03 10:30 0.45 0 0 COMPZ CASING SVRG P LD BHA,Service injector head 10:30 11:45 1.25 0 0 COMPZ CASING PUTB P PU BHA 14, (2 jnts STL Slotted liner with OH anchored billet) 11:45 13:45 2.00 138 9,170 COMPZ CASING RUNL P RIH 13:45 14:00 0.25 9,170 9,170 COMPZ CASING DLOG P Close EDC,Tie into K1 marker+19' correction. 14:00 14:15 0.25 9,170 9,355 COMPZ CASING RUNL P PUW 31K, RIH tie into RA marker +1'correction 14:15 14:30 0.25 9,355 9,774 COMPZ CASING RUNL P RIH to TOL 14:30 14:36 0.10 9,771 9,771 COMPZ CASING RUNL P Set OH anchored billet 195TF 4250 psi CTP.TOB=9693'. 14:36 17:06 2.50 9,771 44 COMPZ CASING RUNL P POOH 30K PUW 17:06 18:06 1.00 44 0 COMPZ CASING PULD P Lay down Billet BHA-perform injector maint. 18:06 19:36 1.50 0 72 COMPZ CASING PULD P PJSM-Pick up BHA#15-Bi-center with 0.8 AKO 19:36 22:00 2.40 72 9,155 PROD2 STK TRIP P RIH pumping through EDC-Pump 13 bbls of MI Hi Visc&20 bbls of low visc water spacer prior to Window. +20 ft correction 22:00 23:30 1.50 9,155 9,155 PROD2 STK CIRC P Sit&circulate out KWF. 23:30 00:00 0.50 9,155 9,155 PROD2 STK SFTY P Safety award dinner. 06/01/2011 KOTB @ 9693'-clean drift. Drilling ahead on AL1 lateral. Difficult drilling and heavy overpulls @ 10,070'. Drilling cleaned up,continue drilling ahead. Mud swap with 1345 ft on system with.6%solids. 00:00 01:00 1.00 9,155 9,155 PROD2 STK SFTY P Safety dinner&presentation. Sit in cased hole&circulate. Close EDC. P/U weight 31K 01:00 01:30 0.50 9,155 9,693 PROD2 STK TRIP P RIH-clean through window.Stop pump and dry tag TOB @ 9693.70' P/U 20 ft. 'i� Page 14 of 20 , Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:30 02:30 1.00 9,693 9,694 PROD2 STK KOST P Start time milling KOTB @ 9693.50- TF 225 LOHS pump 1.35 bpm,3850, BHP 4170, ECD 13.2,WOB.7,CT weight 15K. 02:30 05:00 2.50 9,694 9,705 PROD2 STK KOST P Getting light Al. returns over shakers. KOTB as per procedure.9698' Increase to 10 fph 05:00 05:30 0.50 9,705 9,730 PROD2 STK KOST P Increase to regular ROP for 30 ft prior to dry-drift.Clean drift 05:30 06:45 1.25 9,730 9,840 PROD2 DRILL DRLG P Drill ahead 06:45 07:15 0.50 9,840 9,840 PROD2 DRILL WPRT P Wiper trip to window 33K PUW 07:15 09:00 1.75 9,840 9,990 PROD2 DRILL DRLG P Drill ahead 4180 CTP,4262 BHP, 11K CTW, 1.3BPM 09:00 09:30 0.50 9,990 9,990 PROD2 DRILL WPRT P Wiper Trip to window 32K 09:30 10:45 1.25 9,990 10,065 PROD2 DRILL DRLG P Drill ahead 4180 CTP,4262 BHP, 11K CTW, 1.3BPM 10:45 11:30 0.75 10,065 10,065 PROD2 DRILL WPRT P PUH 32K into casing for Recognition Safety Award Dinner. 11:30 12:30 1.00 10,065 10,065 PROD2 DRILL TRIP P RBIH,Tle into RA marker.-1.5' correction 12:30 13:51 1.35 10,065 10,068 PROD2 DRILL DRLG P Drill ahead 4180 CTP,4262 BHP, 11K CTW, 1.3BPM, hard drilling. 13:51 14:45 0.90 10,068 10,070 PROD2 DRILL DRLG P PUH, 39K, loose returns. 1.3 in 1 out. Hard drilling. Hold 100 psi on MP choke,drill ahead 14:45 15:00 0.25 10,070 10,070 PROD2 DRILL DRLG P PUH stuck 45K,WOB increase, annular psi increase, below orienter.Trap psi on choke. Offline with pump. let psi equalize. PU 50K Pull free.Wiper trip to billet. 15:00 16:00 1.00 10,070 10,070 PROD2 DRILL DRLG P Drill ahead,4300 BHP,4000 CTP, 11K CTW. Increase choke psi 150, maintaining 1 for 1 returns 16:00 16:06 0.10 10,070 10,070 PROD2 DRILL WPRT P Unable to drill. PU 39K.Ann. psi increase 4585psi.Cont. PUH 9940. RBIH to drill 16:06 19:30 3.40 10,070 10,215 PROD2 DRILL DRLG P Drill 4000 CTP,4187 BHP,WOC 19:30 20:30 1.00 10,215 10,215 PROD2 DRILL WPRT P Wiper trip-P/U weight 36K-More than normal cuttings to surface top of wiper trip. Start building sweeps in pits. 20:30 23:30 3.00 10,215 10,340 PROD2 DRILL DRLG P Drilling ahead- 1.38 bpm,4040, BHP 4210, ECD 13.3, ROP 35,WOB 1.9, CT weight 6K..Call out trucks for mud swap, 23:30 00:00 0.50 10,340 10,354 PROD2 DRILL DRLG P Start pumping new mud-1.34 bpm, 4120, BHP 4230, ECD 13,3, ROP 19,WOB 1.8, CT weight 5-7K. 06/02/2011 Continue drilling ahead in AL1 lateral. 00:00 00:15 0.25 10,354 10,365 PROD2 DRILL DRLG P Drilling ahead. 00:15 01:45 1.50 10,365 10,365 PROD2 DRILL WPRT P Wiper trip-P/U weight 35K Page 15 of 20 • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 01:45 04:15 2.50 10,365 10,515 PROD2 DRILL DRLG P Drilling ahead-1.40 bpm, 3940, BHP 4180, ECD 13.2,WHP 120, ROP 55, L WOB 2,CT weight 12K 04:15 05:45 1.50 10,515 10,515 PROD2 DRILL WPRT P Wiper trip P/U weight 34K, tie in-2 ft correction. 05:45 07:00 1.25 10,515 10,665 PROD2 DRILL DRLG P Drilling ahead-1.40 bpm, 3940, BHP 4180, ECD 13.2,WHP 120, ROP 55, WOB 2,CT weight 12K 07:00 08:30 1.50 10,665 10,665 PROD2 DRILL WPRT P Wiper trip to window 32K 08:30 10:00 1.50 10,665 10,815 PROD2 DRILL DRLG P Drilling ahead-1.40 bpm, 3940, BHP 4180, ECD 13.2,WHP 120, ROP 55, WOB 2, CT weight 12K 10:00 12:00 2.00 10,815 10,815 PROD2 DRILL WPRT P Wiper trip to window, 32K 12:00 14:15 2.25 10,815 10,955 PROD2 DRILL DRLG P Drilling ahead-1.40 bpm,3940, BHP 4190, ECD 13.2,WHP 120,WOB 2, CT weight 12K 14:15 16:15 2.00 10,955 10,955 PROD2 DRILL WPRT P Wiper Trip to window, 32K, Correction to RA marker-4'. RBIH 16:15 18:15 2.00 10,955 11,105 PROD2 DRILL DRLG P Drilling ahead-1.40 bpm,3940, BHP 4200, ECD 13.2, 18:15 20:00 1.75 11,105 11,105 PROD2 DRILL WPRT P Wiper trip 32K P/U weight 20:00 21:00 1.00 11,105 11,206 PROD2 DRILL DRLG P Drilling ahead-1.40 bpm,4140, BHP 4215, ECD 13.3, ROP 140,WOB 2.2,CT weight 8K 21:00 23:30 2.50 11,206 11,206 PROD2 DRILL WPRT P Wiper trip-P/U weight 32K 23:30 00:00 0.50 11,206 11,331 PROD2 DRILL DRLG P Drilling ahead 06/03/2011 Drill AL1 lateral to TD 11,710'Wiper to swab valves, RIH lay in liner pill&KWF. 00:00 01:00 1.00 11,331 11,410 PROD2 DRILL DRLG P Drilling ahead-1.40 bpm,3970, BHP 4270, ECD 13.5, ROP 144,WOB 2, CT weight 8K Pump 5/5 sweep 01:00 03:30 2.50 11,410 11,410 PROD2 DRILL WPRT P Wiper trip-34K,tie in-4 ft correction. 03:30 05:30 2.00 11,410 11,560 PROD2 DRILL DRLG P Drill ahead-1.35 bpm,4100, BHP 4250, ECD 13.4, ROP 55,WOB 2.2, CT weight 7K. 05:30 08:00 2.50 11,560 11,560 PROD2 DRILL WPRT P Wiper trip to window 32K PUW 08:00 10:00 2.00 11,560 11,710 PROD2 DRILL DRLG P Drill ahead-1.35 bpm,4100, BHP 4250, ECD 13.4, ROP 55,WOB 2.2, CT weight 7K. 10:00 13:30 3.50 11,710 0 PROD2 DRILL WPRT P TD lateral 11710', Pump low/high sweeps, POOH to swab valves,32K PUW 13:30 16:45 3.25 0 9,100 PROD2 DRILL WPRT P RBIH 16:45 16:57 0.20 9,100 9,100 PROD2 DRILL DLOG P Tie in depth to K1,-3.5'correction 16:57 17:09 0.20 9,100 11,710 PROD2 DRILL DLOG P Tie into RA marker. Unsure of correction, PU perform tie in again to RA marker.-14'correction 17:09 19:09 2.00 11,710 11,710 PROD2 DRILL TRIP P RIH to TD-Tag TD at 11707.6'- __ POOH laying in liner pill. 19:09 22:09 3.00 11,710 72 PROD2 DRILL TRIP P POOH from window laying in KWF as per schedule. KWF at surface 2000' Page 16 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 22:09 23:09 1.00 72 0 PROD2 DRILL PULD P Tag up-flow check at surface. PJSM, lay down BHA 23:09 00:00 0.85 0 0 COMPZ CASING SVRG P Service top drive&injector.Set up liner runing equipment. 06/04/2011 Run liner run#1 from 11712-9640'. Run liner&anchored billet from 9640-9467. Set and POOH for BOPE test. 00:00 01:00 1.00 0 0 COMPZ CASING SVRG P Injector,top drive maint.Set up liner running equipment. 01:00 04:00 3.00 0 2,067 COMPZ CASING PUTB P PJSM-P/U liner.Start picking up 44 slotted,7 solid, 12 slotted. 04:00 05:00 1.00 2,067 2,110 COMPZ CASING PULD P P/U Upper Coiltrack assembly. Strip injector down. 05:00 06:30 1.50 2,110 9,100 COMPZ CASING RUNL P RIH pumping.3 bpm with the EDC closed. 06:30 06:36 0.10 9,100 9,100 COMPZ CASING RUNL P Correct depth to EOP flag. +23'. Weight check 36K PUW 06:36 07:15 0.65 9,100 11,187 COMPZ CASING RUNL P RIH to TD with liner 07:15 08:00 0.75 11,187 11,716 COMPZ CASING RUNL P Tag up, 11187, 11400' 11628' 1163'. PUH 43K. RIH 60 FPM Attempt to push liner down. 08:00 08:06 0.10 11,716 11,716 COMPZ CASING RUNL P Stop RIH @ 11716'.Assure liner break in good sand, Release liner 3900psi,33K PUW. 08:06 08:36 0.50 11,716 9,265 COMPZ CASING RUNL P POOH 08:36 08:48 0.20 9,100 9,100 COMPZ CASING RUNL P Tie into K1 marker-1'correction 08:48 09:00 0.20 9,100 9,250 COMPZ CASING RUNL P RIH tie into RA,-3.5'correction 09:00 11:30 2.50 9,250 0 COMPZ CASING RUNL P POOH 11:30 11:45 0.25 0 0 COMPZ CASING OWFF P At surface flow check 11:45 12:45 1.00 0 0 COMPZ CASING PULD P LD BHA 12:45 13:45 1.00 0 0 COMPZ CASING PULD P PU BHA 17,(5 jnts with OH anchored billet) 13:45 16:00 2.25 238 9,019 COMPZ CASING RUNL P RIH 16:00 16:15 0.25 9,019 9,645 COMPZ CASING RUNL P Correct to EOP flag-19', PUW 30K, RIH to TOL 16:15 16:30 0.25 9,645 9,645 COMPZ CASING RUNL P Set OH Anchor 4200psi.210 TF, TO B=9467.84 16:30 19:30 3.00 9,645 52 COMPZ CASING RUNL P POOH 19:30 20:30 1.00 52 0 COMPZ CASING PULD P PJSM-flow check. Lay down BHA 20:30 22:00 1.50 0 0 COMPZ CASING CIRC P FLush coil&stack to fresh water for BOPE test.Grease crew arrived for WH valves. Cycle&function all tree &choke valves. 22:00 00:00 2.00 0 0 PROD3 WHDBO BOPE P **Start BOPE test waived by Jeff Jones**250 low&4000 psi High. 06/05/2011 Completed BOPE test(annular bag replaced). RIH with BHA#18 2.73"razor bit&1.5 AKo. Circ out KWF with a total of 19 bbls losses. KOTB from 9467'-Mud swap with 1350 ft on system. 00:00 02:00 2.00 0 0 PROD3 WHDBO BOPE P JContinue with BOPE testing. Page 17 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 02:00 06:00 4.00 0 0 PROD3 WHDBO BOPE P Annular bag failed. Continue on with BOPE test&schedule to repair Annular upon completion of testing. 06:00 10:00 4.00 0 0 PROD3 WHDBO BOPE P Change annular and test 10:00 11:00 1.00 0 0 PROD3 STK CIRC P Circulate CT back to KWF 11:00 12:30 1.50 0 0 PROD3 STK PULD P MU BHA 18 12:30 14:45 2.25 0 0 PROD3 STK TRIP P RIH 14:45 15:00 0.25 72 9,100 PROD3 STK DLOG P Tie into K1 marker+18.5 Correction 15:00 16:15 1.25 9,100 9,468 PROD3 STK CIRC P Swap hole over to FP 16:15 16:45 0.50 9,468 9,468 PROD3 STK KOST P RIH Dry Tag TOB=9467.55'. PUH Online with pumps 16:45 18:45 2.00 9,467 9,467 PROD3 STK KOST P ST AL2 Lateral, offbottom 3750 psi, 15K CTW, Set autodriller for 1 FPH. Three stalls to start, possible slip sticking. 18:45 20:00 1.25 9,467 9,468 PROD3 STK KOST P Set up to swap to new mud due to slip sticking&Doyon rig move tonight. 1360'on old system. Continue milling- 1.35 bpm,3800, BHP 4120, ECD 13.1, ROP 1 fph, WOB.2,Ct weight 14. Starting to see light Al.shavings over shakers. 20:00 22:00 2.00 9,468 9,500 PROD3 STK KOST P Better weight transfer with new mud- stall&trip pump once new mud came around backside. Milling ahead as per procedure. 1.35 bpm, 3660, BHP 4130, ECD 13.1, WHP 110, ROP 2 fph,WOB.6, CT weight 16K. Increase to 15 fph @ 9470'. 22:00 22:15 0.25 9,500 9,500 PROD3 STK KOST P P/U weight 31K. Dry-drift through Billet.Clean. 22:15 23:45 1.50 9,500 9,620 PROD3 DRILL DRLG P Drilling ahead-1.40 bpm, 3980, BHP 4180, ECD 13.2,WHP 90,WOB 1.2K,Ct weight 14K, ROP 90 23:45 00:00 0.25 9,620 9,620 PROD3 DRILL WPRT P Wiper trip 32K P/U. 06/06/2011 Drill to TD of 10,120'.Wiper trip to swab valves, RIH tie in with-14ft correction.Tag TD @ 10,120'-POOH laying in liner pill& KWF. 00:00 02:00 2.00 9,620 9,770 PROD3 DRILL DRLG P Drilling ahead-1.38 bpm, 3900, BHP 4130, ECD 13,WHP 80, ROP 80,WOB 2.5, Ct weight 13.5K 02:00 03:00 1.00 9,770 9,770 PROD3 DRILL WPRT P Wiper trip-P/U weight 33K. 03:00 07:45 4.75 9,770 9,920 PROD3 DRILL DRLG P Drilling ahead-1.37 bpm,3940, BHP 4170, ECD 13.1,WHP 0, ROP 80, WOB 2K, Ct weight 12K. ROP dropped to 10 fph @ 9860' 07:45 08:45 1.00 9,920 9,920 PROD3 DRILL WPRT P Wiper Trip to window 35K PUW.Zero correction on tie in. 08:45 11:30 2.75 9,920 10,085 PROD3 DRILL DRLG P Drilling ahead- 1.37 bpm, 3840, BHP 4120, ECD 13.1,WHP 0, 11:30 12:45 1.25 10,085 10,085 PROD3 DRILL WPRT P Wiper Trip to Window 32K PUW Page 18 of 20 Time Logs Date From To Dur S. Death E. Death Phase Code Subcode T Comment 12:45 15:45 3.00 10,085 10,120 PROD3 DRILL DRLG P Drilling ahead-1.37 bpm,3859, BHP 4130, ECD 13.1,WHP 0, 10K CTW 15:45 20:15 4.50 10,120 10,120 PROD3 DRILL WPRT P Wiper tro swab valves-RIH tie in= -14 ft at K-1.Zero correction at window. RIH to TD. Pump beads as RIH.Tag @ 10,120' 20:15 00:00 3.75 10,120 72 PROD3 DRILL TRIP P Cycle pipe until Liner beads reach the bit.-POOH laying in Liner pill followed by KWF. Flag pipe accordingly. EOP-9000'&8100'. 06/07/2011 Run AL2 Liner to 10,123,TOL@9123', Freeze protect to 2500', Set BPV,N2 Reel blowdown, Start cutting coil in support of 3H well 00:00 01:00 1.00 72 0 PROD3 DRILL PULD P PJSM-flow check&lay down BHA 01:00 01:45 0.75 0 0 COMPZ CASING SVRG P Service top drive&rig flor for liner 01:45 03:15 1.50 0 1,000 COMPZ CASING PUTB P P/U 30 joints slotted, 5 ft pup& shorty GS. Kick while tripping drill 2 min.45 secs. 03:15 04:00 0.75 1,000 1,044 COMPZ CASING PULD P P/U Coiltrack BHA 04:00 04:45 0.75 1,044 3,300 COMPZ CASING RUNL P RIH pumping .3 bpm with EDC closed 04:45 05:30 0.75 3,300 1,044 COMPZ CASING RUNL T Short in Coil Track, POOH 05:30 06:00 0.50 1,044 1,044 COMPZ CASING OWFF T Flow check, Prepare for BHa swap 06:00 06:15 0.25 1,044 1,044 COMPZ CASING SFTY T Crew change, PJSM 06:15 07:15 1.00 1,044 1,044 COMPZ CASING PULD T Diagnose short, Swap out Coil Track -troubled flo-sub 07:15 10:15 3.00 1,044 10,123 COMPZ CASING TRIP P RIH-P/U weight @ window 34K- RIH tag bottom 10:15 10:45 0.50 10,123 9,123 COMPZ CASING RUNL P P/U weight 38K-RIH tag bottom . Pick up pump rate to 1.1 bpm,CT weight 32K. Liner set from 10,123'to 9,123'TOL 10:45 15:15 4.50 9,090 44 COMPZ CASING TRIP P Circ out KWF with SW.Start POOH to displace well&freeze protect. Diesel from 2500'to surface.Tag up at surface. 15:15 17:00 1.75 44 0 COMPZ CASING PULD P PJSM-Undeploy BHA, Blow down and lay down tools 17:00 18:30 1.50 0 0 DEMOB MOVE DMOB P PJSM, Rig up and set BPV, Rig down FMC 18:30 20:30 2.00 0 0 DEMOB MOVE CRIH P Pump 20 Fresh water spacer, 30 BBIs corrosion inhibitor through coil and rig lines followed by 25 bbl spacer fresh water to TT 20:30 22:15 1.75 0 0 DEMOB MOVE CTOP P PJSM,Coil tubing N2 Reel blowdown /rig lines&tree 22:15 00:00 1.75 0 0 DEMOB MOVE CTOP P PJSM, R/U coil cutter,cut 4800'in prep for 3H well 06/08/2011 Complete trimming coil,swap coil strings, replace injector skates 00:00 08:00 8.00 0 0 DEMOB MOVE CTOP P Continue cutting coil in support of 3H well.total of 9220'left on string. Clean up rig floor and prepare to unstab pipe Page 19 of 20 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:00 14:00 6.00 0 0 DEMOB MOVE CTOP P Unstab pipe, prepare reel for swap. Remove injector pack-off and roll chains out for skate change. 14:00 20:00 6.00 0 0 DEMOB MOVE CTOP P Remove old reel&install new one. Continue with injector repairs. 20:00 00:00 4.00 0 0 DEMOB MOVE DMOB P Complete repairs to Injector ***Rig Release @ 24:00*** Page 20 of 20 Letter of Transmittal FARE .42 BAKER Date: June 13, 2011 HUGHES 4e4 4)0 To: Fro Christine Mahnken c arl Ulrich/ Sachin Gandra AOGCC 4 Baker Hughes INTEQ 333 West 7th Ave, Suite 100 795 East 94th Avenue Anchorage, Alaska 99501 Anchorage, Alaska 99515 Please find enclosed the directional survey data for the following well(s): 2K-13A 2ti— 0tis- 2K-13AL1 A,,— o efts 2K-13AL2 2q_ c N7 (3) total prints Enclosed for each well(s): 1 hardcopy print of directional survey reports (NAD27) 1 compact disk containing electronic survey files Note: Please feel free to send us an email in place of return mail. Sachin Gandra, Baker Hughes Operations Engineer Sachin.Gandra@BakerHughes.com Carl.Ulrich, Baker Hughes Survey Manager Carl.Ulrich@BakerHughes.com oifSEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COM IISSION 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, 2K-13AL2 ConocoPhillips Alaska, Inc. Permit No: 211-047 Surface Location: 69' FNL, 94' FEL, SEC. 11, T1ON, R8E, UM Bottomhole Location: 2062' FNL, 992' FEL, SEC. 10 T1ON, R8E, UM Dear Mr. Cawvey: Enclosed is the approved application for permit to redrill the above referenced service well. The permit is for a new wellbore segment of existing well KRU 2K-13A, Permit No 211- 045, API 50-103-20116-01. 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, "4" aniel T. S-amount, Jr. 7/4 Chair DATED this .day of April, 2011. cc: Department of Fish 86 Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) RECE1 STATE OF ALASKA MAR 2W ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL �� 6as Caps•�orrissioin 20 AAC 25.005 1j1Char$ ge la.Type of Work: • lb.Proposed Well Class: Development-Oil ❑ Service-Winj a • Single Zone a • 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 ❑Single Well 11.Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 • 2K-13AL2 • 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD: 10250' • TVD: 6101' • Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:69'FNL,94'FEL,Sec. 11,T1ON, R8E,UM • ADL 25588,25589 Kuparuk River Oil Pool . Top of Productive Horizon: 8.Land Use Permit 13.Approximate Spud Date: 1361'FNL, 1009'FEL,Sec. 10,T1ON, R8E,UM 2674,2675 5/1/2011 Total Depth: 9.Acres in Property: 14.Distance to 2062'FNL,992'FEL,Sec. 10,T1ON,R8E, UM 2560 i Nearest Property: 12250' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL:)5KTeet 15.Distance to Nearest Well Open Surface:x- 498310 • y- 5938235 • Zone- 4 Gy ev nn�bvy MSL: /$/,(feet to Same Pool: 2K-19,1670' 16.Deviated wells: Kickoff depth: 9355 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 95• deg Downhole:4078 psig Surface:3481 psig 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD TVD MD ND (including stage data) - 3" 2.375" 4.7# L-80 ST-L 1135' 9115' 6131' 10250' 6101' slotted liner ✓ 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth TVD(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured) 9700' 6517' 9600' 6449' Casing Length Size Cement Volume MD TVD Conductor/Structural 79' 16" 170 sx AS II 115' 115' Surface 3814' 9.625" 1125 sx ASIII,500 sx Class G 3849' 2913' Intermediate Production 9649' 7" 300 sx Class G 9677' 6519' Liner Perforation Depth MD(ft): Perforation Depth ND(ft): 9222'-9238',9284'-9318' 6200'-6210',6240'-6262' 20.Attachments: Property Plat❑ BOP Sketch a Drilling Programa Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Programa 20 AAC 25.050 requirements a 21.Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact J. Ohlinger @ 265-1102 .d Printed Name V. Cawvey Title Alaska Wells Manager ' ���.0> Signature ___— Phon 265-6306 Date 3/24_`Z6)I Commission Use Only / Permit to Drill � / API Numb : Permit Approv I ,^• See cover letter Number: �! 7 50-/O.3-G.e'/i(!j "6l I Date: v, ) I I for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed' ane, as hydrates,or gas contained in shales: ! pS(_ aOP (G Si- Samples req'd: Yes ❑ No Mud log req'd: Yes ❑ No L�f Other: 25,‘,..,r f` Ann T,/_(,a�, s measures: Yes [i No ❑ Directionalti�nsvy req'd: Yes Qr No ❑ (•Fi , d p.er��oG. is h- tc�c.. JJ•• wJl/q•1 O 215? - A ` IT r e 1 c4.A✓'.e.-.Q —./ APPROVED BY THE COMMISSION s ` / DATE: /� ,COMMISSIONER Form 10-401 (Revised 7/2009) This permit is slid f•! rtfrinths from the date of approval(20 AAC 25.005(8)) ubmit i pplicate y-ii<rr ` /-5J 3 3�•�r Permit to Drill Summary of Operations KRU 2K-13A, 2K-13AL1, and 2K-13AL2 Laterals Coiled Tubing Drilling Overview: Well 2K-13 is currently completed in both the A and C sand, without a selective completion equipped with 3'/" tubing and 7"production casing.Three proposed A-sand CTD laterals will increase injection and reservoir exposure for the offset planned 2K-19 CTD production laterals. Prior to drilling,the existing C and A-Sand perfs in 2K-13 will be squeezed with cement to provide a means to kick out of the 7"casing. After plugging off the existing perfs with cement, a pilot hole will be drilled through the cement to 9,320' MD and a mechanical whipstock will be placed in the pilot hole at the planned kickoff point. The 2K-13A sidetrack will exit the 7"casing at 9,255' MD and will target the A4 sand west of the existing well with a 2945' lateral. The hole will be completed with a 2%"slotted liner to the TD of 12,200' MD with an aluminum billet at 9,950' MD. The 2K-13AL1 lateral will kick off from the aluminum billet at 9,950' MD and will target the A4 sand paralleling south of the 2K-13A lateral with a 1750' lateral. The hole will be completed with a 2%"slotted liner to the TD of 11,700' MD with an aluminum billet at 9,355' MD. The 2K-13AL2 lateral will kick off from the aluminum billet at 9,355' MD and will target the A4 sand south of the existing well with an 895'lateral. The hole will be completed with a 2%"slotted liner to the TD of 10,250' MD with the final liner top located inside the 3'/2"tubing at 9,115' MD. Operational Outline Pre-Rig Work • Slickline: Dummy perf gun drift. Obtain SBHP. MIT-IA. • E-line: Run GR/CCL jewelry log/tie-in log (K1 Marker to Tubing Tail). Shoot holes in the 3'/z" tubing below the Baker HB Retrievable Packer from 9115' to 9120' RKB. • Coil: Mill out the XN-nipple at 9137' RKB to 2.80" • Coil: Lay in cement plug from PBTD up to the perf holes @ 9115' RKB. • Slickline: Tag TOC and PT to 1500 psi. • Prepare well site for rig arrival. Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU BOPE and test. Pull BPV 2. Mill 2.80"window at 9,255' in the 7"casing 3. 2K-13A Lateral a. Drill a 2.70"x 3"bi-center lateral to a TD of 12,200' MD b. Run the 2%"slotted liner to TD with an aluminum liner top billet at 9,950' MD. 4. 2K-13AL1 Lateral a. Kick off of the aluminum liner top billet at—9,950' MD b. Drill a 2.70"x 3"bi-center lateral to a TD of 11,700' MD c. Run the 2%" slotted liner to TD with an aluminum liner top billet at—9,355' MD. Page 2 of 5 3/22/2011 ORIGINAL Permit to Drill Summary of ations Cont. KR 13A,2K-13AL1,and 2K-13AL2 5. 2K-13AL2 Lateral a. Kick off of the aluminum liner top billet at -9,355' MD b. Drill a 2.70" x 3"bi-center lateral to a TD of 10,250' MD c. Run the 2%" slotted liner from TD up to 9,115' (inside the 3-1/2" tubing) 6. ND stack, Set BPV ) 7. RDMO Mud Program • Chloride-based Biozan brine (8.9 ppg) for milling operations, and chloride-based Flo-Pro mud (-9.80 ppg) for drilling operations. • 2K-13 does have a Camco TRDP-1A SSSV however it was locked out May'94, therefore a completion fluid will be utilized to kill the well for liner running. 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 Top Btm Liner Details Other Details MD MD 2K-13A 9,950 12,200 2%", 4.7#, L-80, ST-L slotted Unanchored aluminum billet 2K-13AL1 9,355 11,700 2%', 4.7#, L-80, ST-L slotted Unanchored aluminum billet 2K-13AL2 9,115 10,250 2%', 4.7#, L-80, ST-L slotted Existing Completion Details: Category OD Weight Grade Top Btm Burst Collapse (ppf) MD MD psi psi Conductor 16" 62 H-40 36 115 1,640 630 Surface 9 5/8' 36 J-55 35 3,849 3,520 2,020 Casing 7" 26 J-55 29 9,677 4,980 4,330 Tubing 31" 9.3 J-55 31 9,149 6,990 7,400 Well Control: • Two well bore volumes of KWF will be available to the rig during drilling operations. The kill weight fluid. may or may not be stored onsite, but if it is stored offsite it will be in the Kuparuk Field within a short drive to the rig. • 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 4000 psi. Maximum potential surface pressure is 3481 psi assuming a gas gradient to surface based on the potential pressure from the combined A and C-sand interval that measured 4078 psi at 5968'TVDss. • The annular preventer will be tested to 250 psi and 2500 psi. Page 3 of 5 ORIGINAL 3/24/2011 Permit to Drill Summary of Operations Cont. KRU 2K-13A,2K-13AL1,and 2K 13AL2 Directional: • See attached directional plans. • 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 2K-13A 12,990' 2K-13AL1 13,350 2K-13AL2 12,250' • Distance to Nearest Well within Pool(toe measured to offset well) Lateral Name Distance Offset 2K-13A 972' 2K-27 2K-13AL1 1478' 2K-27 2K-13AL2 1670' 2K-19 Logging MWD directional, resistivity, and gamma ray will be run over the entire open-hole sections. Reservoir Pressure A combined zone SBHP was obtained on this well. The C and A Sand SBHP as of 1/14/11 was 4078 psi at a depth of 5968' TVD which is equivalent to a 13.1 ppg EMW. The well has been on MI injection with a previous SBHP of 4383 psi on 11/14/10. The well has been shut in since then to reduce reservoir pressure for CTD operations and will be brought on to production to increase the reduction. Hazards • Maintain sufficient ECD to overbalance. A 9.8 ppg mud system and annular friction will supply enough pressure to overbalance the expected reservoir pressure. Choke pressure can be applied to if higher pressures are encountered as we near the surrounding injectors. • 2K-27 had the maximum H2S level at 400 ppm on the 2K pad as measured on Jan. '09. All H25 monitoring equipment will be operational. Managed Pressure Drilling Managed pressure drilling (MPD) techniques will be employed to provide constant bottom hole pressure by using 9.80 ppg drilling fluid in combination with annular friction losses and if needed 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 for the 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 located between the BOPE choke manifold and the mud pits, and will be independent of the BOPE choke. Using this technique will require deployment of the BHA with trapped wellhead pressure. Pressure deployment of the 2%" BHA will be accomplished utilizing the 2%" pipe rams and slip rams. Well 2K-13 SSSV has been locked out, so the well will have to be loaded with completion fluid prior to running slotted liner. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following charts show the different pressure parameters in both"pumps on" and"pumps off'conditions. Page 4 of 5 3/22/2011 Permit to Drill Summary of Operations Cont. KRU 2K-13A,2K-13AL1,and 2K-13AL2 Drilling Conditions: Pressure at the Window Using MPD(FloPro) Pumps On Pumps Off (1.5 bpm) Formation Pressure 4080 psi 4080 psi Mud Hydrostatic(9.80 ppg) 3090 psi 3090 psi Annular Friction 880 psi 0 psi Mud+Annular Friction 3970 psi 3090 psi (no choke pressure) (underbalance (underbalanced d-110 psi) -990 psi) _Target Pressure(13.1 ppg) 4150 psi 4150 psi Choke Pressure Required 180 psi 1060 psi to Maintain 13.1 ppg Example: Using the 2K-13 SBHP from Jan. '11 with a reservoir pressure of 4080 psi at 5968 TVDss(13.1 ppg EMW). The pressure is expected to be lower by the start of CTD operations. The well and surrounding area has been shut in to injection and the well is planned to be brought on for production to further reduce the pressure. While drilling and circulating at 1.5 bpm with 2"e-coil, head from the 9.80 mud(3090 psi), plus an estimated 880 psi of annular friction (assuming friction of 95 psi/1000 ft)and 110 psi applied to the Managed Pressure Drilling line will provide 4150 psi BHP(13.1 ppg EMW) and will be balanced with the reservoir. More pressure can be applied to overbalance the reservoir. When circulation is shut down,the mud will be underbalanced to the reservoir pressure. However maintaining-1060 psi at surface when the pumps are shut down will maintain a constant 13.1 ppg EMW to promote wellbore stability. Quarter-Mile Iniection Review The following wells lay within one-quarter mile of the proposed 2K-13 CTD laterals. The distances noted are the closest proximity between these wellbores and any point along the planned CTD laterals. - 2K-27 (active producer) -This wellbore is to the west of the 2K-13. The well is a 3-1/2" monobore at a TD of 14,037', the 5-1/2" production is set at 12,571', and 7-5/8" casing at 6,776'. Currently completed in both the A and C sand,without a selective completion. Lateral Center-Center Distance • 2K-13A 752' • 2K-13AL1 937' - 2K-19(active producer)-This well will be sidetracked with CDR2-AC and completed with 3 laterals in the A-sand, and is the offset producer for the 2K-13 injection laterals. The original A-sand perforations will be cement squeezed during the CTD pre-rig work. The mother-bore has 3-1/2"tubing 7"casing. Lateral Center-Center Distance • 2K-13AL2 -1670' Page 5 of 5 3/22/2011 R ; GNAL p4 if Well AttriiAPI/buteKUPFleid ams ell Su... MInc(•, 2K-13 CC/tlUCflf�11��1 S � � ax Angle&MD; TD Al2 a,it MD(ftKB) Act Btm(RKB) tomcat.Alps I 501032011600 ;KUPARUK RIVER UNIT I INJ 55.59 3,800.00 9,700.0 Comment 1H2S(ppm) Dale 'Annotation End Date ,KB-Ord(R) Rig Release Data °•• Well GanbQ-2K•13.3/18/20119:53:03 AM SSSV:LOCKED OUT Last WO: 40.29 10/1/1989 Schematic-Actual Annotation Depth(MB) IEnd Date AnnotationLast Mod_.End Date Last Tag:SLM 9,392.0 13115/2011 i Rev Reason:TAG I Imosbor 3/17/2011 Casing Strings Casing Description String 0... 1String ID...Top(M11(8) Set Depth(f._Set Depth(TVD)._String Wt...String._String Top Thrd CONDUCTOR 16 15.062 I 36.0 115.0 115.0 62.50 H-40 N Casing Description String 0... String ID._Top(RKB) Set Depth(L_Set Depth(TVD)...String WL_String...String Top Thrd HANGER,31 '. (= SURFACE 95/8 8.765 I 35.0 3,848.9 2,913.2 36.00 J-55 BTC Mt; Casing Description String 0... String ID._Top(RKB) Set Depth(t_Set Depth(TVD).-String Wt...String...String Top Thrd PRODUCTION 7 6.151 28.7 9,677.3 6,502.1 26.00 J-55 BTC Tubing Strings I Tubing Description String 0... String ID...Top(MB) Set Depth(f._Set Depth(TVD)...String WL..String...String Top Thrd TUBING 31/2 2.992 31.1 9,149.3 6,153.4 9.30 J-55 EUESrdABMOD Completion Details Top Depth CONDUCTOR, - 96 115 (TVD) Top Ino/ Nomi... Top(fIKB) (RKS) (°) Item Description Comment ID(in) 31.1 31.1 -0.61 HANGER FMC GEN IV TUBING HANGER 3.500 1,811.2 1,657.0 44.72 SAFETY VLV CAMCO TRDP-1A SSSV.(LOCKED OUT 5/27/1994) 2.812 SAFETY VLV, 9,084.8 6,111.9 49.98 PBR BAKER 80-40 w/10'Stroke PBR 3.000 811 9,098.6 6,120.7 50.03 PACKER BAKER HB PACKER 2.890 9,137.3 6,145.6 49.79 NIPPLE OPS XN NIPPLE 2.750 GAS LIFT, - 9,148.6 6,152.9 49.90 SOS 'BAKER SHEAR OUT 2.992 2,860 sty Perforations&Slots 1i Shot Top(TVD) Btnl(TVD) Dans Top(1B(B)Btm(RKB) (RKB) (tI(B) Zone Date (eh. Type Comment 9,222.0 9,238.0 6,200.1 6,210.4.0-4,2K-13 1/9/2001 6.0 APERF 2.5"HSD PJ Chgs,60 deg Phase 9,284.0 9,318.0 6,240.1 6,261.6 A-4,2K-13 4/17/1990 4.0(PERF 4.5"Casing Guns;180 deg.Phase SURFACE, 9,284.0 9,311.0 6,240.1 6,256.9 A-4,2K-13 8/5/1990 4.0 RPERF 2.5"Titan Hollow St 180 deg.Phase 3 5- 3.040 Notes:General&Safety End Date Annotation GAS 5,3LIFT,12 11/3/2010 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 GAS LIFT, 6,627 GAS LIFT, 7.269 GAS LI8TFT, , I I GAS LIFT, 1 8,442 1 a_ I GASFT, ,540 It 9 1 PBR,9,085 PACKER,9.099 111 I NIPPLE.9.137 ,■ I SOS,9,149IV '.. APERF, 9,222-9,238 Mandrel Details Top Depth Top Port (TVD) Ind OD Velve Latch Size TRO Run -- Stn Top(M(8) (RKB) (°I Make Model (in) Sere Typo Type (n) (psi) Run Date Corn... RPERF, 1 2,859.8 2,331.5 51.73 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 11/14/1991 9,2849,311 \ _ - IPERF, 2 5,311.6 3,769.1 53.09 MERLA TTMPD 1 GAS LIFT DMY BK 0.000 0.0 11/18/1991 • 9 289,318 3 6,626.7 4,577.9 51.81 MERLA(TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/17/1990 - - 4 7,268.9.4,974.9 52.41 MERLA TMPD 1 GAS LIFT DMY BK 0.000 0.0 4/17/1990 5 7,835.4 5,328.1 50.93 MERLA TMPD 1 GAS LIFT DMY BK 10.000 0.0 11/&1991 6 8,441.6 5,706.2 50.36 CAMCO MMG-2 1 1/2 GAS LIFT DMY RK 0.000 0.0 11/8/1991 7 9,039.9 6,083.3 50.83ICAMCO MMG-2 1 1/2 GAS LIFT DMY RK 10.000 0.0 11/9/1991 PRODUCTION, 29-0677\ TD.9,700 n o j 0 N g niO o lq n r" N I- C) 0 •, N 2 j O 'j • N 20 N :t � 'I n of 0 0 ' ii cD N N 0 I i N E i Es" m1 M N .0 • COcc .I V y ij - g ce QC II ; p� ii VO O I 1 m 0 N @ r v j 6 CO y N o oo m m Y m 0 w C N m F.-. a g o .B" m _ I. w 63 �" @ W m d > 0 a_m 0 m n et ow 2 Y o — m n o 0 Ce m x Z p DC at• J U Cl .9m C m p o a 2 0 0i 0 rn r1 r1 0 2 10 N lV N<�V 0 0 Nin p ` W /' N N a,CCOO CO CO C 1 N aS © m a I 0 c Ea- En N O1 Y liiiii III AAL U N ., lal>I' ®.1 o a na. U 4i CWw 11IIII _ 77VM1 00 0 i 0 Ci, CL o in N 0 01 010 44 a MI YEn �0 '22 0 0— _ #2 m ][ C a CO N. N� co a 9 W ami OD hof N mm 60 "� mN .k CCI? N CY V Q C) RIGNAL Nabors CDR-2AC Kuparuk Managed Pressure Coil Tubing Drilling BOP Configuration for 2" Coil Tubing 1 Lubricator Riser 7 Annular() Blind/Shear 2"Pipe/Slipl (CT) Pump into Lubricator 4/�/J L� 4� above BHA rams ►V �� V� I Choke 1 2-3/8"Pipe/Slip(BHA) Choke Equalize Manifold 2-3/8"Pipe/Slip(BHA) Kill 10><><� L1><1><-7i ► I ► 1r Blind/Shear 2"Pipe/Slip(CT) 1 r Choke 2 Swab Valves M Wing Valves All I. K Tree Flow Cross 0 Surface Safety Valve BOPE: 7-1/16", 5M psi, TOT 7 c Choke Line: 2-1/16", 5M psi 0 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 ` � IG1NL • ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 2K Pad 2K-13 2K-13AL2 Plan: 2K-13AL2 wp03 Standard Planning Report 22 March, 2011 BAKER HUGHES ORIGINI\ L vs-' ConocoPhillips ConocoPhillips Planning Report BAKER Alaska HUGHES 4 Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2K-13 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-13 @ 154.00ft(Doyon 14) Site: Kuparuk 2K Pad North Reference: True Well: 2K-13 Survey Calculation Method: Minimum Curvature Wellbore: 2K-13AL2 Design: 2 K-13AL2_wp03 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 2K Pad Site Position: Northing: 5,938,600.18ft Latitude: 70°14'36.519 N From: Map Easting: 498,310.17ft Longitude: 150°0'49.133 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: -0.01 ° Well 2K-13 Well Position +N/-S 0.00 ft Northing: 5,938,235.31 ft Latitude: 70°14'32.930 N +E/-W 0.00 ft Easting: 498,310.37 ft Longitude: 150°0'49.125 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 118.50ft Wellbore 2K-13AL2 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2010 5/14/2011 16.61 79.77 57,335 5 Design 2K-13AL2_wp03 Audit Notes: Version: Phase: PLAN Tie On Depth: 9,355.00 Vertical Section: Depth From(TVD) +W-S +E/-W Direction (ft) (ft) (ft) r) -118.50 0.00 0.00 184.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +NI-S +EI-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (1100ft) (°) Target 9,355.00 90.12 259.96 6,104.00 -1,326.97 -6,387.69 0.00 0.00 0.00 0.00 9,385.00 94.54 250.42 6,102.78 -1,334.62 -6,416.63 35.00 14.72 -31.79 295.00 9,565.00 91.17 187.42 6,092.80 -1,467.58 -6,523.80 35.00 -1.87 -35.00 269.00 9,645.00 91.15 177.82 6,091.18 -1,547.39 -6,527.44 12.00 -0.02 -12.00 270.00 9,945.00 89.76 141.84 6,088.71 -1,824.36 -6,425.68 12.00 -0.47 -11.99 268.00 10,250.00 85.64 105.43 6,101.39 -1,990.42 -6,176.34 12.00 -1.35 -11.94 263.00 3/22/2011 11.30:03AM Page 2 COMPASS 2003.16 Build 69 ' OR1GNAL ConocoPhillips '- ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2K-13 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-13 @ 154.00ft(Doyon 14) Site: Kuparuk 2K Pad North Reference: True Well: 2K-13 Survey Calculation Method: Minimum Curvature Wellbore: 2K-13AL2 Design: 2 K-13AL2_wp03 Planned Survey Measured TVD Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (ft) (°) (') (ft) (ft) (ft) (ft) (°/100ft) (°) (ft) (ft) 9,355.00 90.12 259.96 6,104.00 -1,326.97 -6,387.69 1,769.32 0.00 0.00 5,936,909.91 491,923.02 TIP/KOP 9,385.00 94.54 250.42 6,102.78 -1,334.62 -6,416.63 1,778.97 35.00 -65.00 5,936,902.27 491,894.08 2 9,400.00 94.42 245.16 6,101.61 -1,340.27 -6,430.47 1,785.57 35.00 -91.00 5,936,896.62 491,880.24 9,500.00 92.82 210.12 6,095.09 -1,406.48 -6,503.04 1,856.68 35.00 -91.41 5,936,830.43 491,807.67 9,565.00 91.17 187.42 6,092.80 -1,467.58 -6,523.80 1,919.08 35.00 -93.70 5,936,769.34 491,786.90 3 9,600.00 91.17 183.22 6,092.09 -1,502.42 -6,527.04 1,954.06 12.00 -90.00 5,936,734.51 491,783.65 9,645.00 91.15 177.82 6,091.18 -1,547.39 -6,527.44 1,998.95 12.00 -90.09 5,936,689.54 491,783.23 4 9,700.00 90.91 171.22 6,090.18 -1,602.10 -6,522.19 2,053.16 12.00 -92.00 5,936,634.84 491,788.47 9,800.00 90.45 159.23 6,088.98 -1,698.61 -6,496.73 2,147.66 12.00 -92.12 5,936,538.33 491,813.91 9,900.00 89.97 147.24 6,088.61 -1,787.72 -6,451.78 2,233.42 12.00 -92.26 5,936,449.21 491,858.84 9,945.00 89.76 141.84 6,088.71 -1,824.36 -6,425.68 2,268.15 12.00 -92.31 5,936,412.57 491,884.93 5 10,000.00 88.96 135.29 6,089.33 -1,865.57 -6,389.30 2,306.72 12.00 -97.00 5,936,371.36 491,921.29 10,100.00 87.54 123.37 6,092.40 -1,928.80 -6,312.13 2,364.42 12.00 -96.93 5,936,308.11 491,998.44 10,200.00 86.23 111.42 6,097.85 -1,974.67 -6,223.64 2,403.99 12.00 -96.56 5,936,262.24 492,086.91 10,250.00 • 85.64 105.43 6,101.39 i -1,990.42 • -6,176.34 • 2,416.42 12.00 -95.91 5,936,246.47 492,134.20 TD Targets Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape (°) r) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 2K-13AL2 t1 (copy) 0.00 0.00 6,089.00 -1,827.84 -6,422.58 5,936,409.10 491,888.02 70°14'14.927 N 150°3'55.794 W -plan hits target center -Point 2K-13AL2 Polygon(cc 0.00 0.00 0.00 -1,323.78 -6,344.68 5,936,913.08 491,966.03 70°14'19.885 N 150°3'53.542 W -plan misses target center by 6097.13ft at 9565.00ft MD(6092.80 TVD,-1467.58 N,-6523.80 E) -Polygon Point 1 0.00 -1,323.78 -6,344.68 5,936,913.08 491,966.03 Point 2 0.00 -1,560.82 -6,392.62 5,936,676.08 491,918.04 Point 3 0.00 -1,782.83 -6,344.55 5,936,454.08 491,966.06 Point 4 0.00 -1,924.77 -6,083.49 5,936,312.10 492,227.06 Point 5 0.00 -2,011.74 -5,964.45 5,936,225.11 492,346.07 Point 6 0.00 -2,146.80 -6,130.43 5,936,090.10 492,180.08 Point 7 0.00 -2,019.86 -6,399.49 5,936,217.09 491,911.07 Point 8 0.00 -1,837.89 -6,566.56 5,936,399.07 491,744.06 Point 9 0.00 -1,584.90 -6,684.64 5,936,652.07 491,626.05 Point 10 0.00 -1,362.86 -6,629.70 5,936,874.07 491,681.03 Point 11 0.00 -1,200.79 -6,423.72 5,937,036.08 491,887.03 Point 12 0.00 -1,323.78 -6,344.68 5,936,913.08 491,966.03 2K-13AL2 t2(copy) 0.00 0.00 6,101.00 -1,989.80 -6,176.51 5,936,247.10 492,134.03 70°14'13.336 N 150°3'48.639 W -plan hits target center -Point 3/22/2011 11:30:03AM Page 3 COMPASS 2003.16 Build 69 ORIGINAL ConocoPhillips ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 2K-13 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 2K-13 @ 154.00ft(Doyon 14) Site: Kuparuk 2K Pad North Reference: True Well: 2K-13 Survey Calculation Method: Minimum Curvature Wellbore: 2K-13AL2 Design: 2 K-13AL2_wp03 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (1 3,848.00 2,758.66 9 5/8" 9-5/8 12-1/4 10,250.00 6,101.39 2 3/8" 2-3/8 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 9,355.00 6,104.00 -1,326.97 -6,387.69 TIP/KOP 9,385.00 6,102.78 -1,334.62 -6,416.63 2 9,565.00 6,092.80 -1,467.58 -6,523.80 3 9,645.00 6,091.18 -1,547.39 -6,527.44 4 9,945.00 6,088.71 -1,824.36 -6,425.68 5 10,250.00 6,101.39 -1,990.42 -6,176.34 TD 3/22/2011 11.30:03AM Page 4 COMPASS 2003.16 Build 69 ORIGINAL II/ .0 0. 43) 1- V i .§ .0 c=' 0 421 .0-'" C LC? 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TRANSMITTAL LETTER CHECKLIST WELL NAME bleu � --(3,1 PTD# 7-1/0 7 Development I/ Service Exploratory Stratigraphic Test Non-Conventional//Well) FIELD: G�-s 44,.k POOL: 44,044.1+C 4 �,..t. v�t Circle Appropriate Letter I Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing ✓ (If last two digits in well ,k: a.Z Permit No //O ZQ - r. , ��(' o API number are 7S ,API No. 50 �3- 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(0, 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 Cf) D m O ,g 3 cn D a - m -0 o r m m a 3 0 M o 0 az 0 a CD o a r 'O 3.o w A 3' w D o m Cno -. 0 A 0 co v 0 v 73 0�• o o m coo COW C.) 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