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210-059
• Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. 4 0 - O s 9 Well History File Identifier Organizing (done) /wo-sided 1 III! ❑ Rescan Needed IH 1 1111 HIM RES N DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ Diskettes, No. ❑ Maps: %Greyscale Items: ❑ Other, No/Type: ❑ Other Items Scannable by a Large Scanner Poor Quality Originals: ` ar OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: Date: ' 3 0 /s/ vYif Project Proofing I 1 BY: (Maria) Date: 1/30j11 /s/ f Mari Scanning Preparation I x 30 = 30 + 16 = TOTAL PAGES 4L4 3 0 / (Count does not include cover sheet)�� BY: Maria Date: /s/ Production Scanning I 1111111 11111 Stage 1 Page Count from Scanned File: (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: iVe YES NO BY: 11- .. Date: 30 /Lc /s/ fVj f Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. I ReScanned I 11111111 III BY: Maria Date: /s/ Comments about this file: Quality Checked III 111111 II III III 1 opy7p,n11 \niou 4.■01„r.,MI.(`nvcr P ,e,a.,,. 1 ° c 0 CO m r M (� ,\ 0 F U a) C a'U U CC CC U (7 �. ce o Z c'n c Uwe 2 2 3. Q To o v 0 0 0 0 0 0 �, Q.. V N N N N Z N H o 0 0 0 0 ['( U 5 o M M M M z E co co co co QQ c co N :Si c OU 0 CL CL CL CL CL 0.0 0 0 O O ! o 0 1 ca 0 < u) I 0 cc Q m 0000 0 N j co O co cco U) co c U) co N N Z a J 0 V - m 0 0 0 0 0 0 a�.i t- W J °' m cn z ce d C t N 0 0 0 V K 0 a�. M co co co M r) o, C) Cl) co co co 0 m o)W z d U °C o c .a Z po o v E a � z W Z o c a) 5 o J 0. m co = m CL 04 O in o ay o 0 o c -. E co ZI 2 1 0 0 0 m 0 ci N '� 01 d a) O) o , M) E D. 0 0 N U[) U) U ; N U I E co J � V) J < a 9 _ m z > CO Y I t Q 0 I u) O. a Y o I— a o Q zi � � � 1 Q Z oo w > '> > '> aTi aTi a) U o N N N V) 2 2 I J N ca co N 7 7 1 I 1 Z 2 c c c c c c ' I d .. a) .2 .O O .2 o o 1 .. m 1 ' co v' v' '0 v' a, a, I c 0 co w I c c c c 0 0 'a z 1 La cc) O O ca .0 o Q�i m NCC ZO O O W 0 Z N O } CC O E Z -' d ce c m c.• m 0 o 0 1 0 i c O d \ \ {Q� y Z 2 o C-. c C07 H °) J m rn rn rn C) 0 o- m$ E j E Z. a) 0 w Q a m rn a 0 o 0 0 0 I m 0 a) r c a) I o 0 O. 0 H 3 w —I —I —I w Ce 1 3 Q 0 < 0 U STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r Rug Perforations r Stimulate r Other r! PROD to WINJ Alter Casing r Pill Tubing r Perforate New Pool r Waiver r Time Extension Change Approved Program r Operat.Shutdown r Perforate r Re-enter Suspended Well [j 2.Operator Name: 4.Current Well Status: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. - Development r Exploratory r - 210-059 3.Address: 6.API Number: Stratigraphic r Service r P.O. Box 100360,Anchorage,Alaska 99510 • 50-029-21331-62 0 0 7.Property Designation: 8.Well Name and Number: ADL 25635' 1 R-06AL2-01 9.Field/Pool(s): Kuparuk River Field/Kuparuk Oil Pool 10.Present Well Condition Summary: Total Depth measured 10850 feet Plugs(measured) None true vertical 6776 feet Junk(measured) None Effective Depth measured 10825 feet Packer(measured) 8435,8909 true vertical 6773 feet (true vertucal) 6266,6628 Casing Length Size MD ND Burst Collapse CONDUCTOR 72 16 110 110 0 0 SURFACE 4622 12 4659 3694 0 0 WINDOW"A" 12 8 8832 8832 0 0 PRODUCTION 9244 7 9279 6729 0 0 "A"LINER 785 2.625 10245 6773 0 0 0 0 0 Perforation depth: Measured depth: Slots: 8782-8846;9150-10822 True Vertical Depth: 6537-6583;6699-6772 RECEIVED Tubing(size,grade,MD,and ND) 3.5,J-55,8931 MD,6640 TVD DEC 0 1 2010 Packers&SSSV(type,MD,and ND) PACKER-BAKER'FHL'PACKER @ 8435 MD and 6266 NiPaska 0i; & Gas Cons. Commission PACKER-BAKER'FB-1'PACKER @ 8909 MD and 6628 ND Anctorsg® SAFETY VLV-CAMCO TRDP-1A SSSV @ 1908 MD and 1850 TVD 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 429 1195 109 1500 159 Subsequent to operation 1089 700 1864 13.Attachments 14.Well Class after proposed work: Copies of Logs and Surveys run Exploratory r Development r Service r 15.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations X GSTOR r WIND r WAG T GINJ r SUSP r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt 310-334 Contact Bob Christensen/Darrell Humphrey Printed Name d R•,•ert i. Christen_en Title Production Engineering Specialist ii,Signature / / Phone:659-7535 Date -- /V2,0/2 Form 10-404 Revised 10/2010RBDMS DEC 0`1201Q / 1-l6 Submit Original Only 1 • • 1 R-06AL2-01 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary Pre Produced Injector turned to Water Injection service 10/28/10 TAG LINER TOP @ 8781'RKB: PERFORMED 30 MINS SBHPS @ 8500' RKB= 1943 PSI, 145 DEG F. 15 MIN GRADIENT STOP @= 1938 PSI. 10/29/10 SET 3.5"WEATHERFORD WRP@ 8455'USING 1-11/16"SHORTY LONGSTROKE SETTING TOOL. CCL-ME=15.7'CCL STOP DEPTH-8439.3' 10/30/10 DEPLOYED 2.75 AVA CATCHER SUB ONTOP OF WRP @ 8455'RKB. PULLED GLVS @ 2043',4326', 6285', 7615' RKB AND SET DVS. PULLED OV©8381' RKB AND LEFT POCKET OPEN FOR CIRC OUT. 10/31/10 CIRC OUT TBG X IA. SET DV @ 8381'RKB. MIT TBG TO 2500 PSI. PASSED. MIT-IA TO 3000 PSI-PASS. IN PROGRESS. 11/01/10 PULLED CATCHER SUB AND WRP @ 8455'RKB. 11/27/10 Commenced Water Injection service KUP 1 R-06AL2-01 Conoco Phillips 04 Well Attributes !C)x Angle&MD TD AfaMd.0 r.; Wellbore APUUWI Field Name Well Status MO(ttKB) Act Btm(MB) crnlcoFtaleps 500292133162 KUPARUK RIVER UNIT INJ 96.52 9,375.49 10,850.0 Comment 1425(ppm) Date Annotation End Date KB-Ord(ft) Rig Release Date ••• Well Connp.-1R-06AL2-01,10/31r2010 10.04.40AM SSSV:TRDP Last WO: 37.61 5I15/1985 Schematic-Actual Annotation Depth(880) End Date Annotation Last Mod...End Date Last Tag: _ Rev Reason:GLV C/O,SET PLUG/CATCHER Imosbor 10/31/2010 i. ..mlrtilir....Casing Strings MANGER,33 I Casing Description Strip 0... Strip ID...To (ORB) Set Depth r...Set Depth TVD Strip Wt...Strip AL2-01 LINER I 23/8 I 1.995 I 8,781.2 I 10,823.0 I 6,772.5 1 4.70 I L-80 STL STL Thrd Liner Details CTOR, ' Top Depth CONDU 36110 (TVD) Top Joel Noml... fn1 Top(ORB) (ORB) 1•) Item Description Comment 10(In) II 8,781.2 6,536.5 36.23 Deployment DEPLOYMENT SLEEVE 1.000 sleeve SAFETY VLV, 1.908 {C°] Perforations&Slots OAS LIFT. I 1 Shot 2,041 Top(TVD) Bile(TVD) Dens Top(11KB) Bbn(ORB) (ORB) (ORB) Zone Doh 1811-�- Type Comment OAS LIFT. 8,782.0 8,846.0' 6,537.1 6,581.9 7/182010 '32.0 SLOT Alternating solid/slotted pipe- ` 0.125"12.5"@ 4 circumferential adjacent rows,3"centers staggered SURFACE. 18 d 3'non-slotted ends 37-4,&5.9 OAS LIFT, 1 9,150.0 10,822.0 6,698.4 6,772.4 7/18/2010 32.0 SLOT Alternating solid/slotted pipe- 5,531 L 0.125"x2.5"@ 4 circumferential OAS LIFT, j adjacent rows,3"centers staggered S.zas 1 r 18 deg,3'non-slotted ends GAS LIFT, 1 C Notes:General&Safety 5,762 End Date Annotation OAS LIFT. _ 7/19/2010 NOTE:WELL SIDETRACK 1R-06A,AL1,AL1-01,AL2,AL2-01 7,198 GAS 7/192010 NOTE:WELL IS INJECTOR THAT WILL BE PRE-PRODUCED LIFT, 7.518 7/21/2010 NOTE:View Schematic w/Alaska Schematic9.0 OAS LIFT1, 8,08 It OAS LIFT. 8,381 P8R,8421 PACKER.8,435 CATCHER._ I 8,454 Ibt'I PLUG.8,455- - % i. OAS IFT, 8,473 OAS LIFT, 8,545 IF 8.782 SL-0,OT, 848 AAA WHIPSTOCK, - -z 8,819 WINDOW'K. 8,8208.832 a Y-I•i.i GAS LIFT M MA LIFT 1C: '.1 LOCATOR. -MM. SOR _ PACKER 8909 - .�` SPE 8913 — •_•. -1 CIBP,8,921 1• al NIPPLE,8,924 +m; Mandrel Details VII Top Depth Top Port (TVD) Inc! OD Valve Latch Sice TRO Run Stn Top(1808) (MB) 11 Make Model (in) Sery Type Type ON (Psi) Run Date Corn... SOS,8,931 ? 1 2,040.8 1,963.6 33.06 CAMCO KBUG 1 GAS LIFT DMY BK 10/30/2010 2 4,326.0 3,449.3 43.06 CAMCO KBUG 1 GAS LIFT DMY BK 0.000' 0.0 10/30/2010 3 5,630.9 4,355.6 49.21 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 FISH,9,145 - 4 6,285.1 4,787.6 48.27 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/30/2010 5 6,762.2 5,103.9 48.28 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 6 7,198.2 5,396.4 47.03 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 6/30/1985 PRODUCTION, 7 7,615.3 5,683.7 46.14 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/30/2010 SLOT N 8 8,060.9 5,995.7 44.90 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 9,150-10,822— AL2-01 LINER. 9 8,381.1 6,225.9 42.60 CAMCO KBUG 1 12 PROD DMY rdo20 0.000 0.0 10/30/2010 8,791-18.823 - TO 10 8,473.5 6,294.9 40.49 CAMCO MMG-2 1 12 PROD OPEN 0.000 0.0 11/21/1993 (1R-OBAL2-01), I 10.800 • • E KUP 1 R-06AL2-01 • ConocoPhillips tAno ■PMnpn KB-Grd(ft) Rig Release Date ... Well Gonne -1R.06AL2-01,10731MTO10.04:10AM 37.61 5/15/1985 Schematic-Actual HANGER,33 f 1 CONDUCTOR, 38-110 fl SAFETY VLV. I 1,908 GAS.0 tl 1 2 1 GAS LIFT, 1,328 1 F SURFACE, •J 371659 GAS LIFT. 5,631 GAS LIFT, 8285 GAS LIFT,6.762 r 6.762 GAS.143 j 7,1 T,GAS LIFT,7,615 GAS LIFT, 8,061 GAS LIFT, 8,331 PBR,8,421 PACKER,8,135 CATCHER, 8,454 I•RdH' PLUG,8,455 GAS LIFT, 8.173 GAS LIFT, 8.545 t!� SLOT, 8782 8 846 WHIPSTOCK, B 819 WINDOW'A'. 8,820-,832 1. I�° GAS LIFT I HMO.8,890 LOCATOR, 8,908 PACKER.8,909 SBE,8,913 •��� CIBP,8,921 - 111 !�1 NIPPLE,8,921 Mandrel Details - Top Depth Top Port I�I (TVD) Incl OD Valve Latch Sloe TRO Run Stn lop(IOKB) MRS) (°) Maks Model (in) Ssry Type Type (In) (pal) Run Dab Con.... SOS.8.931 - - 11 8,544.5 6,349.5 39.15 CAMCO MMG-2 1 1/2 PROD DMY RK 0.000 0.0 5/21/2010 12 8,890.3 6,616.8 52.78'CAMCO MMG-2 1 1/2 PROD OPEN 0.000 0.0 5/21/2010 FISH,9,145 PRODUCTION, 35-9,27T9 SLO, 9,150.10, AL2-01 LINER. 8781-10,8231 D \ T (1R-06AL2-01), 10850 — cirg [E O SEAN PARNELL,GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMrIISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Robert D. Christensen Production Engineering Specialist ConocoPhillips Alaska, Inc. I o P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk Oil Pool, 1R-06AL2-01 Sundry Number: 310-334 Dear Mr. Christensen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. e Chair DATED this'f day of October, 2010. Encl. s , ft o STATE OF ALASKA ED ( , ALA AIL AND GAS CONSERVATION COMMISS. ��(' S► SEP2Q2010 ' ∎° IV APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Alas a a&Or Caw Cl scion 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r Change Aram r Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Wet r Stimulate Alter casing • r g r Other: PROD to WINJ r 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. Development r Exploratory r 210-059 • 3.Address: Stratigraphic r Service r 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-029-21331-62 • 7.If perforating,closest approach in pool(s)opened by this operation to nearest property line 8.Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No r 1R-06AL2-01 • 9.Property Designation: 10.Field/Pool(s): ADL 25635 ' Kuparuk River Field/Kuparuk Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth M ft): Total Depth N ft): Effective Depth M : Effe�ctiv Depth TVQ ft): Plugs(measured): Junk(measured): iD 1D8diT1,..:i.&"(;1746 ��+/1- i - U12 '"v (.4 I� i�gg, Jo.` I ,, Casing Length Size MD TVD Burst Collapse CONDUCTOR 72 16 110' 110' SURFACE 4622 12 4659' 3694' WINDOW"A" 12 8 8832' 8832' PRODUCTION 9244 7 9279' 6729' "AL2-01"LINER 2042 2.625 10823' 6773' • Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Slots:8782-8846;9150-10822 6537-6583;6699-6772 3.5 J-55 8931 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft) PACKER-BAKER'FHL'PACKER MD=8435 TVD=6266 PACKER-BAKER'FB-1'PACKER MD=8909 TVD=6628 SAFETY VLV-CAMCO TRDP-1A SSSV MD=1908 TVD=1850 12.Attachments: Description Summary of Proposal rs 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development r Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 10/15/2010 Oil r Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r • GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob Christensen/Darrell Humphrey Printed Name Robert D. Christensen Title: Production Engineering Specialist Signature r Phone:659-7535 Date Vo2- 70 40 Commission Use Only Sundry Number: 3/0 -3�/ Conditions of approval: Notify Commission so that a representative may witness ��yy Plug Integrity r BOP Test r Mechanical Integrity Test Location Clearance r Other: Subsequent Form Required: /b, ` d1' ' APPROVED BY /� Approved b : it COMMISSIONER THE COMMISSION Date: / �/< pP y 1 (7. Form 10-40: !': %/ ■ 1i 04 111- -. /O• t(./v Su mi 'n Duplicae � Rl .� iIUAL mig 1 R-06AL2-01 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert KRU Well 1 R-06AL2-01 (PTD 210-059) from Oil Production service to Water Injection service. Well 1 R-06AL2-01 (CTD Sidetrack)was completed in the Kuparuk formation on July 19, 2010 as a pre-producing injector with initial production commencing on July 25, 2010. Conversion to Injection service is required due to potential reservoir depletion. The 16" Conductor was cemented with 215sx of CS II. The 9-5/8" Surface casing (4659' and/3694' tvd)was cemented with 1390sx Permafrost E and 425sx PF C. The 7" Production casing (9279' and/6729' tvd)was cemented with 510 sx Class"G"and 250sx PFC. The top of the Kuparuk B sand was found at 8820' and/6568'tvd. The top of the Kuparuk A3 sand was found at 9344' and/6723'tvd. The injection tubing/casing annulus is isolated via Baker FHL Packer located @ 8435' and/6266' tvd. ,, 4 I ..,, KUP 1R-06AL2-01 ConocoPhillips +� ell Attributes ax Angle&MD TD Alaska Inc. Wellbore API/UWI Field Name Well Status Inc](°) MD(NEB) Act Wm(ftKB) 500292133162 KUPARUK RIVER UNIT INJ Comment 1425(ppm) Date Annotation End Date KB-Ord(R) Rig Release Date Well coae9:-1R-a6AL2-01,71212010 12:46:0/PM -SSSV:TRDP Last WO: 37.61 5/15/1985 • Schematic-Actual Annotation Depth(508) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:SIDETRACKS,GLV C/O Imosbor 7/21/2010 HANGER,33 ' Casing Strings I Casing Description ing 0... ing ID...Top( B) Set Depth(L.Set Depth(TVD)...String Wt_.String... String Top Thrd AL2-01 LINER I Slr 23/8 I Sir RK 1.995 8,781.2 i 10,823.0 I I 4.70 I L-80 I STL Liner Details CONDUCTOR, 1 Top Depth 38-110 (TVD) Top Inc! Noon... 0 Top(ftEB) 111013) (°) Item Description Comment ID(in) 8,781.2 DEPLOY DEPLOYMENT SLEEVE 1.000 SAFETY VLV, 1-__T 1,908 Perforations&Slots Shot I OAS LIFT, _ Top(TVD) Btm(TVD) Dens 2,041 Top(RKB) Btm(RKB) (MB) (ROB) Zone Dots (oh--- Type Comment GAS LIFT, 8,782 8,846 7/18/2010 32.0 SLOT Alternating solid/slotted pipe- 4,320 - 0.125"x2.5"@ 4 circumferential adjacent rows,3"centers staggered SURFACE, J 18 deg,3'non-slotted ends 37.4,859 0AS LIFT. 9,150 10,822 7/18/2010 32.0 SLOT Alternating solid/slotted pipe- ss31 0.125"x2.5"@ 4 circumferential adjacent rows,3"centers staggered OAS LIFT, c _ 18 deg,3'non-slotted ends 8,285 GAS LIFT, ® Notes:General&Safety 6,782 End Date Annotation GAB LIFT, 7/19/2010 NOTE:WELL IS INJECTOR THAT WILL BE PRE-PRODUCED •I 7.198 7/21/2010 NOTE:View Schematic w/Alaske Schematic9.0 OAS LIFT, 515 r 7,815 GAS LIFT, 8,081 OAS LIFT, 4� _ 8,381 - FOR,8,421 PACKER,6,435 OAS LIFT, 8.473 OAS LIFT. 8,545 • SLOT, 8,782-8.848 --_ WHIPSTOCK, 6,519 - WINDOW"A', - _ 8,820-8.832 = 11 i GAS LIFT 1Ca.. HMG,8,890 i.1 LOCATOR glom PACKER.8.909 _ SBE.8,913 •IMF 1• 1 CIBP,8,921 1111 1•I NIPPLE,8.924 ill' 4 SOS.8.931 M' Mandrel Details • Top Depth Top Port FISH,9145 (TVD) Inc' OD Valve Latch Sloe TRO Run Stn Top(fIKB) (RKB) I') Make Model (In) Sery Type Type (In) (psi) Run Date Com... 1 2,040.8 CAMCO KBUG 1 GAS LIFT GLV BK 0.125 1,317.0 7/21/2010 2 4,326.0 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,333.0 7/21/2010 3 5,630.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 PRODUCTION, _ 4 6,285.1 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,319.0 7/21/2010 . ? • 358,279 SLOT, 5 6,762.2 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 9,Q7-10,244, 6 7,198.2 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 6/30/1985 SLOT 9,15-10,8 2 7 7,615.3 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,342.0 7/21/2010 'A'LINER, 8 8,060.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 9,480.10,245 AL2-01 LINER, 9 8,381.1 CAMCO KBUG 1 1/2 PROD OV rdo20 0.188 0.0 7/21/2010 8,781-10,823 _ -- TD -10 8,473.5 CAMCO MMG-2 1 1/2 PROD OPEN 0.000 0.0 11/21/1993 (1R-08AL2-01), 10,940 IP W, ..., ,,, ,....KI lo 4= ,c3 , 4 - - , _:.„ _. „„ _. lii=1 _ , ,_ ate' :"....... 7, 5,. mm . CD al a is do is al O E ----- ca g C U ' U ` U U v U_ _ �. o � a. `/ w U J J U J 3� N N N N>_ o W W W r W W Q 0 a) a) a) C() J •C E . LL- C 0 a L_ d cr a W a. m a W Q O T TEN T a, T v) Co i O 7 a� 2 -pL c - -ct 3 - -a_ :E c � Q (U O � 2 r C7 LL 0 U U U _N r6 r6 ! c� C T; o .C '1 0 C ai O. J co O N ✓ Q _ O C N c° 9'w O a. U 0 U co O S `o C O NO.0 O U 3 N x M CO L O M a E m N O co d O M O 2 r• ,� v- 3 u• d 0 0 N C) •� y co �.: CO M CD c E R o r- C _c 0 . .- o) Cr) > O a 0 0 e0 c E .rY T, -1, Y o Y O. Vic) E — D o O a) a w �wW ._. a) o L a) �v O c ea co W ca Z co ce 0 j •a+ - m A 0 Q Z O O) n3 O Y " U) 0 N Nl fA m N - - U a ca Q p F- y m 0 Y < c c Q <a y a- co n Y 4- m .� iv y R er U, co II Rao ¢ �_ � � .sQ .� c°� . `—° gQ JNQ , _y > c O Y •C m Q C F- a H - Cr) t — ti - si 2 n ai c a), m 'o w m ; R L d o d Z O.J L N L (/) Q ` 0) L c0 =' w r C) L O Cr)Z i s- 0) t• Q .., 0) C x W c = o p ,I.c H C d . (0 - O W ' N U C co) co N D O E w V" O `' o O . ` a) J O a p d oo 02 C) O Z O L O a� O p m L W � m L - 7 L W F¢-- -0 U C c co = c Y H o o c ....,.-02t2-- '17. , > 0 v y O o cao c cn p ca lZO 3 000L no 0Z<N• < t� E - = aUcM) Q maciaCI C9n. Q rt � LoQ 0 r- = • I STATE OF ALASKA ALASK#..AL AND GAS CONSERVATION COMMISbiJN REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r Plug Perforations r Stimulate r Other r Pre-Prod lnj Alter Casing r Pull Tubing r Fbrforate New Pool Waiver <30 days r r Time Extension r Change Approved Program r Operat.Shutdown r Perforate r Re-enter Suspended Well r 2.Operator Name: 4.Current Well Status: `6. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 210-059 1 3.Address: API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service F 50-029-21331-62 7.Property Designation: 8.Well Name and Number: ADL 25635 1 R-06AL2-01 9. Field/Pool(s): Kuparuk River Field/Kuparuk Oil Pool 10.Present Well Condition Summary: Total Depth measured 10850 feet Plugs(measured) None true vertical 6776 feet Junk(measured) None Effective Depth measured 10823 feet Packer(measured) 8435, 8909,8921 true vertical 6773 feet (true vertucal) 6266,6628,6634 Casing Length Size MD TVD Burst Collapse CONDUCTOR 72 16 110 110 0 0 SURFACE 4622 9.625 4659 3694 0 0 PRODUCTION 9244 7 9279 6729 0 0 Slotted Liner 2042 2.375 10823 6773 0 0 Perforation depth: Measured depth: Slotted 8782-8846;9150-10822 RECEIVED True Vertical Depth: 6537-6583;6699-6772 AUG 1 3 2010 Tubing(size,grade,MD,and ND) 3.5,J-55,8931 MD,6640 TVD Moth 1111&Gas C .Commission Packers&SSSV(type,MD,and TVD) PACKER-BAKER'FHL' PACKER @ 8435 MD and 6266 TVD $80 'ar'tQ PACKER-BAKER'FB-1'PACKER @ 8909 MD and 6628 ND SAFETY VLV-CAMCO TRDP-1A SSSV @ 1908 MD and 1850 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 _ Subsequent to operation 781 3029 760 1267 164 13.Attachments 14.Well Class after proposed work: Copies of Logs and Surveys run Exploratory r Development r Service" r 15.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations X GSTOR r WAG r GASINJ r \WINJ r SPLUG r 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Bob Christensen/Darrell Humphrey / .v44.1/ Christensen Title Production Engineering Specialist Printed Name Robert D. hristens Signature , I�_� Phone:659-7535 Date ©0,40 Form 10-404 Revised 7/2009 RBDMS AUG 13 2010 *,1 ,.rc 14- - _fOSubmit Original Only 1 R-06AL2-01 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 07/20/10 MEASURED BHP @ 8500' MD: 3154 PSI. SET CATCHER. PULLED DV @ 8381' RKB, SET. 3/16" OV @ SAME. PULLED DVs @ 7615' &6285' RKB, SET GLVs @ SAME. IN PROGRESS 07/21/10 PULLED DVs @ 4326'&2041' RKB. SET GLVs @ SAME. BLED IA TO CONFIRM GLVs SET. PULLED CATCHER. COMPLETE. 07/25/10 OPEN WELL- RETURN TO SERVICE • KUP 1 R-06AL2-01 .p'1. ConocoPhillips a weelllr�mbu Field Name Well spas Max Angie&MD TD tm(RKB) Ata',k„t.If K,. <<,,,r,%nI„�=-, 500292133162 KUPARUK RIVER UNIT INJ Comment H2S(ppm) Date Annotation End Date KB-Ord(R) Rig Release Date Well Cont9:-tR-06AL2-01 721!01012:45:04 PM SSSV:TRDP Last WO: 37.61 5/15/1985 Schematic-Actual Annotation Depth(CAB) End Date Annotation Last Mod.. End Date Last Tag: Rev Reason:SIDETRACKS,GLV C/O Imosbor 7/21/2010 HANGER Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)... String Wt...String... String Top Thrd AL2-01 LINER 23!8 1.995 8,781.2 10,823.0 4.70 L-80 STL Liner Details CONDUCTOR, , Top Depth 38.110 I (TVD) Top Inc' Noml... O Top(ftKB) (RKB) (°) item Description Comment ID(in) 8,781.2 DEPLOY DEPLOYMENT SLEEVE 1.000 SAFETY VL 8 —='.°J 1,908 Perforations&Slots snot GAS LIFT. riri:/11::' Top(TVD) Btm(TVD) Dens 2.Wt Top(1808) Bfm(RKB) IRKS) (RKB) Zone Dab ( T Comment eh... YPe GAS LIFT. 8,782 8,846 7/18/2010 32.0 SLOT Alternating solid/slotted pipe- 4, 0.125"x2.5”@ 4 circumferential J adjacent rows,3”centers staggered SURFACE, 18 deg,3'non-slotted ends 37-1,&58 GAS LIFT. 9,150 10,822 7/18/2010 32.0 SLOT Alternating solid/slotted pipe- 5,631 _ 1 r 0.125"x2.5"@ 4 circumferential I adjacent rows,3"centers staggered GAS LIFT, 18 deg,3'non-slotted ends 6,285 GAB LIFT,_ -1 T Notes:General&Safety 6.762 End Date Annotation GAS LIFT, 7 7/19/2010 NOTE:WELL IS INJECTOR THAT WILL BE PRE-PRODUCED 7,198 1 7/21/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT. f ' 7,875 1 GAS LIFT, jC 8,061 l GAS LIFT, j 8,381 1 PER,0431 PACKER,13,435 illk GAS LIFT, 8,473 GAS LIFT, 8,545 1 .,.. SLOT, 8,782-8,846 WHIPSTOCK. 8.819 WINDOW'A', 8,820-8,832 I" 1I■. l.i GAS LIFT MMG,8,890 ■C: LOCATOR, 1.11 8,909 .__ PACKER,8,909 SSE.8,913 •E 1o1 CInP.8,921 • !ir N.PPLE,E,924 ON In SOS,8,931 'ig! Mandrel Details Top Depth Top Port FISH,9,145 ` (TVD) Inc! OD Valve Latch Size TRO Run Stn Top MKS) MO) 1°) Make Model (In) Sery Type Type tin) (pal) Run Date Corn... 1 2,040.8 CAMCO KBUG 1 GAS LIFT 'GLV BK 0.125 1,317.0 7/21/2010 2 4,326.0 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,333.0 7/21/2010 3 5,630.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 PRODUCTION, _ 4 6,285.1 CAMCO KBUG 1 GAS LIFT 'GLV BK 0.156 1,319.0 7/21/2010 159,279 SLOT, 5 6,762.2 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 9./7t-1o.zO9,471-11t4,1 T,\ 6 7,198.2 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 6/30/1985 SL 9,150-10,822 7 7,615.3 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,342.0 7/21/2010 'A'LINER, 8 8,060.9 CAMCO KBUG 1 GAS LIFT'DMY BK 0.000 0.0 11/10/1987 9,4130.10,245 AL2-01 LINER, 9 8,381.1 CAMCO KBUG 1 1/2 PROD OV rdo20 0.188 0.0 7/21/2010 8,781-10,823 TD 10 8,473.5 CAMCO MMG-2 1 1/2 PROD OPEN 0.000 0.0 11/21/1993 II R.06AL2.01), 10,940 • KUP 1 R-06AL2-01 ConocoPhillips a A�.1`iNJ.111,.. lonoco{lvlllps KB-Ord(It) Rig Release Dete "' 37.61 5/15/1985 Well Contg.-1R-06AL2-01,721201012'.45'.04 PM Schematic Actual HANGER,33 CONDUCTOR, 38-110 SAFETY VLV, o 1,908 GAS LIFT, 2,041 GAS LIFT, _ 4.326 r SURFACE, 37F7-4 1,C39 GAS 5,531 T GAS LIFT, 6,285 GAS LIFT, 8,762 GAS LIFT, 7,198 { r GAS LIFT, 7,615 GAS LIFT, 8.061 GAS LIFT, �. 8,381 r PER,8,421 PACKER,8.435 GAS LIFT. 9473 GAS LIFT, 8,545 1E" SLOT, 8,782-8,846 WHIPSTOCK, 8,819 WINDOW'A', 8.820-8832 ■ ICI GAS LIFT MMG,8,890 AC: I. LOCATOR 8.908 __-�_ PACKER,8,909 586,8,9/3 1-E 0187,8,921 IMP mil NIPPLE.8.924 I■I SOS,8,931 l�; Mandrel Details Top Depth Top Port FISH,9,145 (TVD) Inc! OD Valve Latch Size TRO Run Stn Top(6KB) (MB) (1 Make Model (In) SemY Type Type (in) (poi) Run Data Corn... 11 8,544.5 CAMCO MMG-2 1 1/2 PROD DMY RK 0.000 0.0 5/21/2010 12 8,890.3 CAMCO MMG-2 1 1/2 PROD OPEN 0.000 0.0 5/21/2010 PRODUCTION, 59,279 SLOT, 9,471-10,244 SLOT, 9,15610,822 'A'LINER. 9,48610,245 AL2-01 LINER, 8,781-10.823 TD (18-06Al2.01), 10,940 • . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil Q Gas ❑ SPLUG ❑ Other ❑ Abandoned❑ Suspended ❑ lb.Well Cla 20AAC 25.105 20AAC 25.110 Development . Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: Service t . Stratigraphic Test 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: July 19,2010 • 210-0590/ 3.Address: 6.Date Spudded: 13.API Number: P.0.Box 100360,Anchorage,AK 99510-0360 July 16,2010 • 50-029-21331-62 4a.Location of Well(Governmental Section): 7.Date TD Reached: 14.Well Name and Number: Surface: 272'FNL,222'FEL,Sec. 19,T12N,R10E, UM • July 18,2010 • 1R-06AL2-01 • Top of Productive Horizon: 8.KB(ft above MSL): 84'RKB 15.Field/Pool(s): 1312'FSL,958'FWL,Sec. 19,T12N, R10E,UM GL(ft above MSL): AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+TVD): 2495 FNL, 1229'FNL,Sec. 19,T12N,R10E,UM 10823'MD/6773'ND Kuparuk River Oil Pool 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+TVD): 16.Property Designation: Surface: x-539470 • y- 5990930 • Zone-4 . 10850'MD/6776'ND ADL 25635 • TPI: x-535849 y- 5987217 Zone-4 11.SSSV Depth(MD+ND): 17.Land Use Permit: Total Depth: x-536113 y- 5988690 Zone-4 1908'MD/1850'ND 2560 18.Directional Survey: Yes 0 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) 1550'MD/1527'ND. 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 9344'MD/6723'ND 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CEMENTING RECORD CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 Surf. 110' Surf. 110' 24" 215 sx CS II 9.625" 36# J-55 Surf. 4659' Surf. 3694' 12.25" 1390 sx Permafrost E,425 sx PF C 7" 26# J-55 Surf. 9278' Surf. 6975' 8.5" 510 sx Class G,250 sx PFC 2.375" 4.7# L-80 8781' 10823' 6536' 6773' 3" slotted liner 24.Open to production or injection? Yes is No ❑ If Yes,list each 25. TUBING RECORD Interval open(MD+TVD of Top&Bottom;Perforation Size and Number): SIZE DEPTH SET(MD) PACKER SET(MD/TVD) 3.5" 8932' 8435'MD/6266'ND slotted liner from 9150'-10821'MD 6699'-6772'ND 8909'MD/6628'ND 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. COMPLETION ' DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED $L I t one 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,gas lift,etc.) July 25,2010 pre-produced injector-flowback in progress Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO 7/31/2010 16 hours Test Period--> 389 2317 459 209% 5952 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API(corr) Press. 165 psi 1263 24-Hour Rate-> 584 3476 689 not available 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No Q Sidewall Cores Acquired? Yes ❑ No If Yes to either question,list formations and intervals cored(MD+ND of top and bottom of each),and summarize lithology and presence of oil,gas or water (Submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. RECEIVED NONE AU a 0 4 2010 Alaska Cl St Gas Carts.Commission P. ue Anchora e Form 10-407 Revised 9 * AUG V CONTINUED ON REVERSE Submit original Only G • 28. GEOLOGIC MARKERS(List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes Q 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 1550' 1527' needed,and submit detailed test information per 20 AAC 25.071. Top Kuparuk A Sand 9344' 6723' N/A Formation at total depth: Kuparuk A3 • 30. LIST OF ATTACHMENTS Summary of Daily Operations,schematic,final directional survey 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Conta • (Gary Eller @ 263-4172 Printed N e Caw Title: Alaska Wells Manager /ZOO^ Signature Phone 265-6306 Date S 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 Time"LogsE;: Date From " To bur S.Depth E.Depth Phase Code " Subcode T Comment 01:00 04:00 3.00 10,916 0 COMPZ CASING RUNL T Smooth run in hole with no set downs. Release from liner with 1.5 BPM 4500 CTP. POOH pumping down backside,tie in at RA for-3' correction. Circulate down coil whil continue POOH. Paint flag at 8000 EOP. 04:00 06:00 2.00 0 0 COMPZ CASING PUTB P Lay down liner running BHA, RU for liner ops, PU liner string and anchored billet 06:00 07:24 1.40 0 696 COMPZ CASING PUTB P P/U Coil track,M/U FVS,Scribe, stab on,surface test,strip down injector,Open rams,Tag up, set counters 07:24 09:12 1.80 696 8,665 COMPZ CASING TRIP P Trip in well with AL2 liner second run, BHA#29 09:12 09:54 0.70 8,665 9,981 COMPZ CASING TRIP P Correct+10 at flag,close EDC, PUW=30K 09:54 10:18 0.40 9,981 9,380 COMPZ CASING TRIP P Tag @ 9982 with 3.5K WOB, PUW=31 K Set back down to 9978 w 1.7K WOB, Release Liner POOH 10:18 12:18 2.00 9,380 8,746 COMPZ CASING TRIP P 9380, reset counter to bottom of TS -634',Open EDC Continue Out of well 12:18 13:03 0.75 8,746 0 COMPZ CASING PULD P PJSM,At surface, Flow check Lay down liner running tools BHA #29 13:03 14:18 1.25 0 72 PRODS DRILL PULD P P/U Drill by BHA#30 Surface test,Tag up and set counters 14:18 15:48 1.50 72 8,350 PROD5 DRILL TRIP P RIH with BHA#30 15:48 16:00 0.20 8,350 8,392 PROD5 DRILL DLOG P Log Gamma tie in for a+8.5' correction, RIH to window to displace KWF 16:00 16:12 0.20 8,392 8,760 PROD5 DRILL TRIP P RIH to above window Circ out KWF 16:12 18:30 2.30 8,760 8,760 PROD5 DRILL CIRC P Circ out KWF trying to maintain 1 for 1,starting at.3 BPM 18:30 21:00 2.50 8,760 0 PRODS DRILL TRIP T Toolface indicator not working properly. Pulled up hole to 8200'and it appeared to begin working,further checks indicate it is in fact not accurate. POOH. 21:00 22:00 1.00 0 0 PROD5 DRILL PULD T Undeploy BHA#30 22:00 23:30 1.50 0 0 PROD5 DRILL PULD T deploy BHA#31. Had trouble with the jib arm for PDL not returning to center,spent about 20 minutes checking it out then it started working again? Mechanic will trouble shoot during day shift. 23:30 00:00 0.50 0 2,406 PROD5 DRILL TRIP T RIH 07/16/2010 Kicked off aluminum billet at 9344',drilled to 9505'and tripped for RSM,continue drilling AL2-01 lateral 00:00 01:30 1.50 2,406 8,350 PRODS DRILL TRIP T Continue RIH Page 30 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase, Code Subcode T Comment 01:30 02:00 0.50 8,350 9,344 PROD5 DRILL TRIP P Tie in,continue RIH through window and open hole 02:00 06:30 4.50 9,344 9,355 PROD5 STK MILL P Tag billet at 9344'and begin time milling. Having some stacking issues requiring PU and restarts 06:30 07:00 0.50 9,355 9,385 PROD5 DRILL DRLG P Start drilling ahead after completing time milling 1.43 BPM @ 3436 PSI FS, BHP =4145 ROP=55 FPH,WOB=1.3K, RIW=9.5K 07:00 07:06 0.10 9,385 9,385 PRODS DRILL WPRT P 9385, Mini wiper up past liner top billit PUW=29K.Good clean pass past billit 07:06 09:06 2.00 9,385 9,505 PRODS DRILL DRLG P Drill Ahead 1.31 BPM @ 3551 PSI FS, BHP =4187 ROP=55 FPH,WOB=1.5K, RIW=8.7K 09:06 11:36 2.50 9,505 0 PRODS DRILL TRIP P 9505', POOH for RSM PUW=30K, BHP=4157 11:36 11:54 0.30 0 0 PROD5 DRILL TRIP P Stop close EDC,Tag UpCrew change 11:54 13:09 1.25 0 0 PROD5 DRILL PULD P PJSM, Undeploy BHA#31 13:09 14:45 1.60 0 0 PROD5 DRILL PULD P Deploy BHA#32 RibSteer with Hugh Bicenter 14:45 16:30 1.75 0 8,350 PROD5 DRILL TRIP P RIH with RibSteer, EDC Open 16:30 16:42 0.20 8,350 8,375 PRODS DRILL DLOG P Log tie in fora+8.5,Close EDC PUW=8.5k 16:42 17:18 0.60 8,375 9,505 PROD5 DRILL TRIP P Trip In to Drill,start mud swap 17:18 20:48 3.50 9,505 9,655 PROD5 DRILL DRLG P Drilling ahead, 1.4 BPM,3300 CTP, 4150 BHP,50 WHP w/WOC. 26K PUW, 10K RIW. 20:48 22:24 1.60 9,655 9,655 PRODS DRILL WPRT P Wiper trip to window 22:24 00:00 1.60 9,655 9,780 PRODS DRILL DRLG P Drilling ahead, 1.4 BPM,3300 CTP, 4170 BHP,50 WHP w/WOC. 26K PUW, 10K RIW. 07/17/2010 Drilled AL2-01 lateral. 00:00 00:30 0.50 9,780 9,805 PRODS DRILL DRLG P Drilling ahead, 1.4 BPM, 3300 CTP, 4170 BHP,50 WHP w/WOC. 00:30 01:36 1.10 9,805 9,805 PRODS DRILL WPRT P Wiper to window,28K PUW, 10K RIW 01:36 05:06 3.50 9,805 9,955 PROD5 DRILL DRLG P Drilling ahead, 1.4 BPM,3300 CTP, 4220 BHP,58 WHP w/WOC. 26K PUW, 10K RIW. 05:06 05:54 0.80 9,955 8,825 PRODS DRILL WPRT P Wiper to window,28K PUW 05:54 06:00 0.10 8,825 8,844 PRODS DRILL DLOG P Tie in,+1'Correction 06:00 06:30 0.50 8,844 9,555 PRODS DRILL WPRT P Continue wiper trip to bottom, Clean wiper up and down No sign of billit Page 31 of 33 Time Logs Date From To Dur S.Depth E.Depth Phase Code Subcode T Comment 06:30 10:30 4.00 9,555 10,105 PROD5 DRILL DRLG P 9550 Drill Ahead 1.37 BPM @ 3100PSi FS BHP=4159, RIW=8.8K,WOB=1.2K 10:30 11:54 1.40 10,105 10,105 PROD5 DRILL WPRT P Wipe to window PUW=28K 11:54 15:54 4.00 10,105 10,255 PROD5 DRILL DRLG P 10105',drill ahead 1.42 BPM @3525PSI FS RIW=5.7K w/2.3K WOB BHP=4212 15:54 17:30 1.60 10,255 10,255 PROD5 DRILL WPRT P 10255,Wiper to window PUW=32 17:30 19:18 1.80 10,255 10,405 PRODS DRILL DRLG P 10255',Drill ahead 1.36 BPM @ 3250PSI FS BHP=4200 19:18 20:24 1.10 10,405 8,825 PROD5 DRILL WPRT P Wiper to window,30K PUW 20:24 20:30 0.10 8,825 8,860 PRODS DRILL DLOG P Tie in, 20:30 21:18 0.80 8,860 10,405 PRODS DRILL WPRT P RIH, 10 K RIW 21:18 22:48 1.50 10,405 10,555 PROD5 DRILL DRLG P Drilling ahead, 1.4 BPM, 3500 CTP, 4270 BHP with WOC, 1-3K WOB, 200-300 psi motor work 22:48 00:00 1.20 10,555 8,820 PRODS DRILL WPRT P Wiper to window,30K PUW 07/18/2010 TD well at 10850', Kill well with brine and run liner. Shoe left at 10823, liner top at 8781'. Displace well to seawater 00:00 01:18 1.30 8,820 10,555 PROD5 DRILL WPRT P Continue wiper trip. 01:18 02:30 1.20 10,555 10,705 PROD5 DRILL DRLG P Drilling ahead, 1.4 BPM, 3570 CTP, 4285 BHP with WOC, 1-3K WOB, 200-300 psi motor work 02:30 04:42 2.20 10,705 10,705 PROD5 DRILL WPRT P Wiper trip to window,31K PUW 04:42 08:03 3.35 10,705 10,850 PRODS DRILL DRLG P Drilling ahead, 1.4 BPM,3550 CTP, 4295 BHP with WOC, 1-3K WOB, 200-300 psi motor work. hard spot with three stalls @ 10827 08:03 09:51 1.80 10,850 8,825 PRODS DRILL WPRT P Reach TD @ 10850,Wipe up hole Lo-Hi sweeps heading down coil Sweeps around corner,wipe to window chasing sweeps 09:51 09:57 0.10 8,825 8,841 PRODS DRILL DLOG P Log RA Marker for a+1'correction 09:57 10:57 1.00 8,841 10,845 PRODS DRILL WPRT P Trip in well to lay in beaded liner pill/ KWF 10:57 14:12 3.25 10,845 0 PRODS DRILL TRIP P POOH laying in beaded liner pill followed by KWF PUW=31K, Paint EOP Flags @ 8600&6600' 14:12 15:15 1.05 0 0 PRODS DRILL PULD P PJSM,Flo Check, Review Pulling BHA from dead well. Pull BHA#32 from well 15:15 15:30 0.25 0 0 COMPZ CASING SFTY P PJSM to P/U liner while flo testing well 15:30 18:48 3.30 0 2,085 COMPZ CASING PUTB P P/U AL2-01 Liner 18:48 20:24 1.60 2,085 8,686 COMPZ CASING RUNL P RIH Page 32 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T' Comment 20:24 22:48 2.40 8,686 10,823 COMPZ CASING RUNL P Correct depth at flag,+5.5',30K PUW, 10K RIW,continue RIH. Started stacking weight at 9952'with 50K PUW,multiple stacking the rest of the way in hole with PUW up to 60K and RIW down around zero. Release liner at 10823',liner top at 8781' 22:48 00:00 1.20 10,823 8,750 DEMOB WELLPF DISP P Displace brine with SW, 07/19/2010 POOH after running liner, Freeze Protect from 2100", RDMO 00:00 02:00 2.00 8,750 0 DEMOB WELLPF TRIP P POOH,lay in diesel from 2100'to surface 02:00 03:30 1.50 0 0 DEMOB WELLPF DCSG P Undeploy BHA, 170 WHP. 03:30 06:00 2.50 0 0 DEMOB WHDBO NUND P Set BPV 06:00 09:00 3.00 0 0 DEMOB WHDBO DMOB P Blowdown Reel and Rig, blled off air, R/D PUTZ 09:00 10:00 1.00 0 0 DEMOB WHDBO DMOB P Lift BOP stack off tree, Flange Up Wellhead flange and PT to 4K 0 DEMOB WHDBO DMOB P Rig Release @ 10:00 II Page 33 of 33 KU P 1 R-06AL2-01 ConocoPhiUips Well Attributes Max Angle&MD TO ska ^"',--,,. Wallbore APVUWI 'Field Name Well Status InInd(°) MD(ftKB) Act Blm(ftKB K8) Conn<oFTlik 500292133162-_ JKUPARUK RIVER UNIT INJ _ Comment IH2S(ppm) (Date Annotation End Date KB-Grd(ft) Rig Release Date ••• Wet Cavil -tl£969L�o1,7R1291012A.Oa CM SSSV:TRDP Last WO: i _ 37 61 5/15/1985 $rx�e0y acwat.__ Annotation !Depth ftK6 End Date Annotation 'Last Mod.. End Date ( ) Last Tag: Rev Reason SIDETRACKS,GLV C/O Im_osbor 7/21/2010 HANGER,33 3: I Casing Strings Casing Description !String 0... I String ID...Top(ftKB) Set Depth(f...Set Depth(TVD) 'String Wt...String...String Top Thrd "' - - .7 s: - AL2-0 1 LINER l 2 3/8 li 1 995 �..-8,781 2 10,823.0 I I_ 4 70 I L-80 STL Liner Details CONDUCTOR, I pD pthi 38-110 (TVD) 'Top 1001 Komi._p,l Top(81KB) (ftKB) (°) Item Description Comment ID(in) 8,781.2 DEPLOY DEPLOYMENT SLEEVE 1.000 SAFETY.1908 Perforations&Slots _ I Shot I GAS LIFT, 2,041 Top(TVD) Btm(TVD) Dens Top(aKe)Ban(ttKe) MKS) MS) Zone Dap. (an- Type Comment GAS LIFT, - 8,782 8,846 7/18/2010 32.0 SLOT Alternating solid/slotted pipe- 4,326 -_ 0.125"x2.5"@ 4 circumferential , adjacent rows,3"centers staggered SURFACE, 18 deg,3'non-Slotted ends 37-4,659 Alternating solid/slotted pipe- GAS LIFT, 9,150 10,822 7/18/2010 32.0 SLOT 5,631 �,, 0.125'7(2.5"@ 4 circumferential adjacent rows,3"centers staggered GAS LIFT, 18 deg,3'non-slotted ends 6,285 GAS LIFT. Notes:General&Safety 6'762 End Date Annotation GAS LIFT _ 7/19/2010 NOTE:WELL IS INJECTOR THAT WILL BE PRE PRODUCED 7,198 7/21/2010 NOTE:View Schematic w/Alaska Schematic-9.0 GAS 7,LIFT. 615 F' GAS LIFT, 8,061 GAS LIFT, 8,381 PBR,8,421 PACKER,8,435- I' GAS LIFT, __.. 8,473 GAS LIFT, 8,545 I, r ia"I 4.::. ie '- SLOT, 8,782-8,846 WHIPSTOCK, . 8,819 WINDOW"A", 8,820.8,832 eve err IF GAS LIFT I MMG,8,890 'A 61I LOCATOR, 8,908 PACKER,8,913 SSE,8,913 el t CIBP,8,921 NIPPLE,8,924- 0 1. A.. i pp:• SOS,8,931 -...... .. A 7(' 'K M •! < 4,11471 4„^.!. F'. rft Top Depth Top Port FISH,9,145 (TVD) net OD Valve Latch Size TRO Run Stn Top 51K81 MKS) ('I Make Model fn) Sera TYpe TYpe (in) (pap Ran Date Com... 1 2,040.8 CAMCO KBUG 1 GAS LIFT GLV BK 0.125 1,317.0 7/21/2010 2 4,326.0 CAMCO IKBUG 1 GAS LIFT GLV BK 0.156 1,333.0 7/21/2010 3 5,630.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 PRODUCT1B,27B ON, 4 6,285.1 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,319.0 7/21/2010 35 sLOT,. 5 6,762.2 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 9,471-10,2M sLOT, - 6 7,198.2 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 6/30/1985 9,150-10,822 7 7,615.3 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,342.0 7/21/2010 "A"LINER, 8 8,060.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 9,460-10,245 AL2-01 LINER, 9 8,381.1 CAMCO KBUG 1 12 PROD OV rdo20 0.188 0.0 7/21/2010 8,781-10,823 --- TD - 10 8,473.5 CAMCO MMG-2 1 12 PROD OPEN 0.000 0.0111/21/1993 10,940 • KU P 1 R-06AL2-01 ConocoPhillips Alaska.inc. ... KB-GFd MO Rig Rabsaa Data 37.61 5/15/1985 .wAssoki.=21.94442 41 alf2t24.'t9,72 694,.M_.._. HANGER,33 a• __.— -_- _ - CONDUCTOR, , I 38-110 SAFETY VLV, ._. 1,908 GAS LIFT, 2,041 4,326 SURFACE, 37-4,659 GAS LIFT. 5,631 GAS LIFT, 6,285 GAS LIFT,____ 6,762 GAS LIFT, 7,198 GAS LIFT, 6 7,615 )F GAS LIFT._ 8,061 GAS LIFT, 8,381 PSR,8,421- PACKER,8,435 r' GAS LIFT,_. 8,6 GAS OFT, 6,50.5 SLOT, 8,782-8,846 WHIPSTOCK, : 8,819 WINDOW'A' _^,. ,'.1,. . 1 8,820-8,832 �.... .._,,,, GAS LIFT MMG.8,890 LOCATOR, 8,908 PACKER,8,909 SHE,8,913— ■�'`,, CIBP,8,921– s NIPPLE,8,924 SOS.8,931 Egt, Mandrel Details Top Depth Top Port FISH,9,145 (TVD) Ind OD Valve Latch 0,0 TRO Run Stn Top1RICB) Man (1 Make Model (In) soy Type Type En) (psi) Run Dab Com... g 11 8,544.5 CAMCO MM,-.-2 11/2 Pb OD L 1Y HK 0000 0.0 5/21/2010 qt 12 8,890.3 CAM( )MMG-2 ®PROD OPEN 10.000 0.05/21/2010 PRODUCTION, 7 tl 35-9,279 7 u' SLOT, 9,471-10,244\ SLOT, 9.150-10.822 'A'LINER, 9,460.10,245 AL2-01 LINER, 8,781-10,823 TD (1R-06AL2-01),� �• 10,940 in co co in o m� ohm °`° p C') I -A H 7.s c N 7 c.i II N�.- N C 0 C r II co _ 0 N m N 1-N O) p,-� l l m 9°� N W O � p N N F_ - i--m .it.'E. d d m a m_o"a m n nmn JN so -,'�n` t a dao0° J c co a Nt•N J N y N .l J f?L. 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CO CO OD CO CO CO CO CO CO CO CO CO 0 CO CO CO 0 CO CO CO CO CO 'L O I v Cn co 0 N a CD C CI co n M 0) N 0) N- cD N-03 0 M }M� cD cD 0 00 OD O c0 cD c0 0D M 0 n O ll9 C 0 0 co n O 7t• .• 0 0 0 O O O O O O O 0 0 O O O a 0 0) n O C P', N N CO V n 0 M O 0 N Y] co C n O M co 0 N 0 N N N M M M V V K N N N co fD co n n n n co_ 00 a m m 0 0 O O O O O O O O O O 0 0 0 0 0 0 0 0 0 0 0 E • CI m m '0 N at 0a` ) 0 U) 3 � tlA,ppAY1 :,�r....a fled � � 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 Von Cawvey Alaska Wells Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1R-06AL2-01 ConocoPhillips Alaska, Inc. Permit No: 210-059 Surface Location: 272' FNL, 222' FEL, Sec. 19, T12N, R10E, UM Bottomhole Location: 2485' FNL, 1162' FWL, Sec. 19, T12N, R10E, 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 1R-06A, Permit No. 210- 056, API 50-029-21331-01. 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. .incer ly, Daniel T. Seamount, Jr. Chair DATED this Z day of May, 2010. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 0 6 2010 PERMIT TO DRILL 20 AAC 25.005 Jaska 011&nn Gas Cons.Commission la.Type of Work: ,, 1 b.Proposed Well Class: Development-Oil ❑ Service-wnj Q , Single Zone Q - 1c.Specify if wt T�1300d for: Drill ❑ Re-drill Q 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 U Single Well 11.Well Name and Number: ConocoPhillips Alaska,Inc. Bond No. 59-52-180 1 R-06AL2-01 ' 3.Address: 6.Proposed Depth: 12. Field/Pool(s): P.O.Box 100360 Anchorage,AK 99510-0360 MD: 10750' • TVD: 6625' ' Kuparuk River Field 4a. Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface:272'FNL,222'FEL,Sec. 19,T12N,R10E,UM ' ADL 25635 - Kuparuk River Oil Pool . Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1041'FSL, 1086'FWL,Sec. 19,T12N,R10E,UM 2568 6/15/2010 Total Depth: 9.Acres in Property: 14.Distance to 2485'FSL, 1162'FWL,Sec. 19,T12N,R10E,UM 2560 Nearest Property: 19500' 4b.Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: - 84 feet 15.Distance to Nearest Well Open Surface:x- 539470 • y- 5990930 • Zone- 4 GL Elevation above MSL: , 41 feet to Same Pool: 1R-08,1050' 16.Deviated wells: Kickoff depth: 9250 ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 95° deg Downhole:3115 psig - Surface:2545 psig' 18.Casing Program: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 3" 2.375" 4.7# L-80 ST-L 1970' 8780' 6460' 10750' 6625' slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured) Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured) 9303' 6998' 9188' 6890' 9145' Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 16" 215 sx CS II 110' 110' Surface 4575' 9.625" 1390 sx PF E,425 sx PF C 4659' 3694' Intermediate Production 9194' 7" 510 sx Class G,250 sx PF C 9278' 6975' Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): 8582'-8588',8692'-8742',8860'-8867',8975-8984',8994'-9024',9028'-9038' 6379'-6383',6465'-6505',6801'-6607',6700'-6707',6715-6741',6745-6754' 20.Attachments: Property Plat❑ BOP Sketch 0 Drilling Program Q Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements 0 21.Verbal Approval: Commission Representative: Date: S r f`O 22. I hereby certify that the foregoing is true and correct. Contact J. G. Eller @ 263-4172 Printed Name V. Cawvey Title Alaska Wells Manager Signature h k S� * \ ��Vc� Phon 265-6306 Date 5tSitc) CoMffiission Use Only Permit to Drill API Number: / Permit Approval See cover letter .2__/Number: �-- (_ V(1)S19." (. C 50- (-4 g-- 2,1' 7 f-6-2, CC)Date: �I '-' D for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas contained in shales: KI.--' *3500 pg� Qa{' -eS 4- Samples req'd: Yes ❑ No Er Mud log req'd: Yes ❑ No [V Other: r H2S n1)easures: Yes [r] /No ❑ Directional svy req'd: Yes [� No ❑ Z.560 105 i. 4,7^w�w-i � � :� / > APPROVED BY THE COMMISSION 5 7 / 7/F O DAT a 401/ ,COMMISSIONER Form 10-401 (Revised 7/2009) This permit is vaWilfo 2 o s r.mY he date of approval(20 AAC 25.005(g)) S bmit in Dupli to i-51'i.io �3to 5•••fL. 25 KRU 1R-06A, AL1, AL2, AL2-01 —Coiled Tubing Drilling Summary of Operations: Well 1R-06 is a Kuparuk A-sand and C-sand injection well equipped with 31/2"tubing x 7"casing.Four proposed A-sand CTD laterals will improve sweep efficiency and reserve recovery. Prior to drilling,the existing C-sand perfs in 1 R-06 will be squeezed with cement and the A-Sand perfs will be plugged with a bridge plug. After squeezing the existing C-sand perfs with cement, a mechanical whipstock will be placed in the 31/2" tubing at the first kickoff point. The 1R-06A sidetrack will make a 2-string exit through the 31/2"tubing and 7" casing at 8819' MD. It will target the A3 sand south of the existing well with a 2881' lateral. The hole will be completed with a 2%" slotted liner to the TD of 11,700' MD with a liner top aluminum billet at 9350' MD. The 1R-06AL1 lateral will kick off from the aluminum billet at 9350' MD and will target the A4 sand south of the existing well with a 2250' lateral. The hole will be completed with a 2%" slotted liner to the TD of 11,600' MD with the final liner top located just inside the 3'/2"tubing at 8814' MD. The 1R-06AL2 lateral will make another 2-string exit through the 31/2"tubing and 7"casing at 8791' MD via a second mechanical whipstock placed in the 31/2"tubing. It will target the A3 sand north of the existing well with a 2259' lateral. The hole will be completed with a 2%" slotted liner to the TD of 11,050' MD with a liner top aluminum billet at 9250' MD. The 1R-06AL2-0l lateral will kick off from the aluminum billet at 9250' MD and will target the A4 sand north of the existing well with a 1500' lateral. The hole will be completed with a 2%" slotted liner to the TD of 10,750' MD with the final liner top located just inside the 31/2"tubing at 8780' MD. CTD Drill and Complete 1R-06: June 2010 Pre-Rig Work 1. Test packoffs—T&IC. 2. Positive pressure and drawdown tests on master valve& swab valve 3. Load tbg&IA. MIT-IA. MIT-OA. 4. Obtain updated static BHP on A-sand&C-Sand 5. Permanently lock out the SCSSV at 1908' MD 6. Set 31/2"CIBP at 8920' MD to plug off A-sand perfs 7. Shoot squeeze perfs thru the 3'/2"tubing and 7"casing at 8791' & 8819' ELM 8. Lay in cement on top of CIBP isolating A-sand. Squeeze the C-sand perfs with cement. 9. RU slickline. Tag cement top. Pressure test cement squeeze. 10. Drill out cement from the 31/2"tubing to 8920' using special clearance bi-center bit 11. Run whipstock dummy 12. Run slimhole CBL to evaluate C-sand squeeze 13. Prep site for Nabors CDR2-AC. Page 2 of 5 nnIrIN1 A, 4 May 5,2010, FINAL KRU 1R-06A, AL1, AL2, AL2-01 —Coiled Tubing Drilling Rig Work 1. MIRU Nabors CDR2-AC rig using 2"coil tubing. NU 7-1/16"BOPE,test. 2. 1R-06A Lateral (A3 sand, south) a. Mill 2.80"2-string window with high-side orientation at 8819' MD. b. Drill 2.70"x 3"bi-center lateral to TD of 11,700' MD. c. Run 2%"slotted liner with an aluminum liner-top billet from TD up to 9350' 3. 1 R-06AL 1 Lateral (A4 sand, south) a. Kick off of the aluminum billet at 9350' MD b. Drill 2.70"x 3"bi-center lateral to TD of 11,600' MD. c. Run 2%"slotted liner from TD up to 8814' MD,up inside the 7"casing 4. 1R-06AL2 Lateral (A3 sand,north) a. Set 3'/2"monobore whipstock in 3'h"tubing at 8791' MD with high-side orientation. b. Mill 2.80"2-string window with high-side orientation at 8791' MD. c. Drill 2.70"x 3"bi-center lateral to TD of 11,050' MD. d. Run 2%"slotted liner with an aluminum liner-top billet from TD up to 9250' 5. 1 R-06AL2-01 Lateral(A4 sand,north) _ a. Kick off of the aluminum billet at 9250' MD b. Drill 2.70"x 3"bi-center lateral to TD of 10,750' MD. c. Run 2%"slotted liner from TD up to 8780' MD,up inside the 3'h"tubing 6. Freeze protect. ND BOPE. RDMO Nabors CRD2-AC. T f tt Post-Rig Work 1. Obtain static BHP 2. Run GLVs 3. Flow back well to the system for clean up prior to putting on injection 4. Conduct MIT-IA 5. Put well on injection Mud Program: • Will use chloride-based Biozan brine or used drilling mud(8.6 ppg)for milling operations, and chloride- based Flo-Pro mud(8.6 ppg)for drilling operations. Because the SCSSV installed in 1R-06 will be locked out,we will have to kill the well to deploy 2%"slotted liner. 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. Casing Program: • 1R-06A: 2%",4.7#, L-80, ST-L slotted/solid liner from 9350' MD to 11,700' MD • 1R-06AL1: 2%",4.7#, L-80, ST-L slotted/solid liner from 8814' MD to 11,600' MD • 1R-06AL2: 2%",4.7#, L-80, ST-L slotted/solid liner from 9250' MD to 11,050' MD • 1R-06AL2-01: 2%",4.7#,L-80, ST-L slotted/solid liner from 8780' MD to 10,750' MD Existing Casing/Liner Information Surface: 9%",J-55, 36 ppf Burst 3520 psi; Collapse 2020 psi Production: 7",J-55,26 ppf Burst 4980 psi; Collapse 4320 psi Page 3 of 5 A R I ri May 5,2010, FINAL KRU 1R-06A, AL1, AL2, AL2-01 — Coiled Tubing Drilling Well Control: • Two well bore volumes(—.205 bbl)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 3500 psi. Maximum potential surface pressure in 1R-06 is 2545 psi assuming a gas gradient to surface and maximum potential formation pressure. Maximum potential formation pressure is based on the highest recent measured bottom hole pressure in the vicinity,which is 3115 psi at 6490 SSTVD(i.e. 9.3 ppg)from 1R-08 to the . north in September 2009. • The annular preventer will be tested to 250 psi and 2500 psi. Directional: • See attached directional plans: 1. 1R-06A,plan#4 2. 1R-06AL1, plan#3 3. 1R-06AL2, plan#2 4. 1R-06AL2-01, plan#2 • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. . • 1R-06 CTD southern laterals(A&AL1): 18,550' to property line,—870' to well 1G-08 • 1R-06 CTD northern laterals(AL2 &AL2-01): 19,500' to property line, 1050' from well 1R-08 Logging • MWD directional,resistivity, and gamma ray will be run over the entire open hole section. Reservoir Pressure • The most recent static BHP survey in well 1R-06 was taken April 2010 after several months of shut-in. . The measured A-sand reservoir pressure was 2998 psi at 6571' SSTVD, corresponding to 8.7 ppg EMW. We generally expect to encounter similar pressure as the laterals are drilled away from the mother well. Hazards • Lost circulation is usually not particularly troublesome in the A-sand,but it is a possibility in 1R-06 . because of the generally low formation pressure in this area. • Shale stability is a potential problem,particularly in the build section where the A6 sand will be encountered. Will mitigate potential sloughing problems by cutting this interval at less than 70°hole angle,and by holding a constant pressure on the formation throughout drilling operations. • Well 1R-06 has no measured H2S since it is an injection well. Well 1R-05 is located 60' to the right side and 1R-07 is 60' to the left side of the 1R-06 surface location. Well 1R-05 has 40 ppm H2S and 1R-07 has 25 ppm 112S,both being measured on 8/6/09. The maximum H25 level on the pad is 150 ppm from well 1R-20(8/15/05). All H2S monitoring equipment will be operational. Page 4 of 5 Q ( 1 f May 5,2010, FINAL KRU 1R-06A, AL1, AL2, AL2-01 —Coiled Tubing Drilling Managed Pressure Drilling Managed pressure drilling(MPD)techniques will be employed to provide constant bottom hole pressure by • using 8.6 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allow use of less expensive drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure is installed between the BOPE choke manifold and the mud pits, and is independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the 2%"BHA will be accomplished utilizing the 2%"pipe rams and slip rams. The annular preventer will act as a secondary isolation during deployment and not as a stripper. The SSSV in well 1R-06 will be locked out, so the well will have to be killed 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 scenario is expected at TD: • Expected reservoir pressure is 2933 psi at 8819' MD(6483' SSTVD), or 8.7 ppg EMW. • • Expected annular friction losses while circulating: 882 psi(assuming annular friction of 100 psi/1000 ft due to the 3V2"tubing) • Planned mud density of 8.6 ppg equates to 2899 psi hydrostatic bottom hole pressure at 6483' SSTVD • While circulating 8.6 ppg mud,bottom hole circulating pressure is estimated to be 3781 psi or 11.2 ppg . EMW without holding any additional surface pressure. This is sufficient to overbalance expected formation pressure in 1R-06. If increased formation pressure is encountered,mud weight or choke pressure will be increased to maintain overbalance. Additional choke pressure or increased mud weight may also be employed for improved borehole stability, but not necessarily for well control. • When circulation is stopped,—880 psi of surface pressure shall have to be applied to maintain the same borehole pressure as during drilling operations. Quarter-Mile Injection Review The following wells lie within one-quarter mile of the proposed 1R-06 CTD laterals. • 1R-06 motherbore(injector). This well is a selective completion in the Kuparuk A-sand and C-sand. The A-sand perfs will be isolated with a cast iron bridge plug in the tubing tail and the C-sand perfs will be squeezed with cement. • 1R-06 CTD southern laterals(A&AL 1): • 1R-05 (active producer). This wellbore is located—1335' to the northeast of wells 1R-06A and 1R- 06AL1. It is a selective completion in the Kuparuk A-sand and C-sand. The Kuparuk sands are isolated by cemented 7"casing. • 1G-08 (plugged& sidetracked producer)—This abandoned wellbore is located---873' to the southeast of wells 1R-06A and 1 R-06AL 1. The Kuparuk interval was abandoned in June 2004 with a balanced cement plug placed on top of a 7"retainer prior to being sidetracked. • 1R-06 CTD northern laterals(AL2 &AL2-01): • 1R-08 (active injector)—This wellbore is located 1055' to the north of wells 1R-06AL2 and 1R- - 06AL2-01. It is a selective completion in the Kuparuk A-sand and C-sand. The Kuparuk sands are isolated by cemented 7"casing. Page 5 of 5 't""1It�! May 5,2010, FINAL J E 4 .,e P.,... Nabors CDR-2AC Kuparuk Managed Pressure Coil Tubing Drilling BOP Configuration for 2" Coil Tubing ql I Lubricator E :1 Riser r 7 Annular/ Blind/Shear 2" Pipe/Slip(CT) Pump into Lubricator ����P�'TT��' J above BHA rams ��� ■=. ■ Choke 1 2-3/8"Pipe/Slip(BHA) Choke — Equalize Manifold 2-3/8"Pipe/Slip(BHA) L Kill W>4V✓ J I L ∎ II C I I I 1 r Blind/Shear 2" Pipe/Slip (CT) Choke 2 I 1-gl-Swab Valves Wing Valves A nallb.._� Tree Flow Cross C Surface Safety Valve BOPE: 7-1/16", 5M psi,TOT I C Choke Line: 2-1/16", 5M psi Xi 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 ORIGINAL : 2. 2 FS N o O a n `a N < a, a <. m p - m o mm° m 2,-..I VI N A-O N I '' L°" N 'O 1 N•U g o °¢ � a a�J D ¢O J (^1 J U' • U) mwm "� m a „ \...I% j i UU)i 0 H �.'n r.: m O a 2 _ F 4 m w^ZA; N c c1.a a. � o O Y.N CEi II ;! ii ;!-.. to eo O !at i n n iff ill CD A l_ � . � �; 1I: i..........„:... 0 Il i I I1 o a �� o. a m. .w CO w w o m m#m - C&a� tmN� t',7 # m A Y C- m N O N 6NAm d U_ mn . r .O y m m m 00 W. Y m ,- m m m Q ce O q LV N O V ..: b-O,m N A 0) io ORIGINAL ,P KUP _ 1R-06 Corr coPhiilips Well_Attributes = ConocóPhiIli ps Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1R Pad 1R-06 1 R-06AL2-01 Plan: 1 R-06AL2-01 wp02 Standard Planning Report 30 April, 2010 Mal BAKER HUGHES ORIGINAL ' ConocoPhillips ConocoPhillips Planning Report BAKER .Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1 R-06 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 R-06 @ 84.00ft(1 R-06) ' Site: Kuparuk 1R Pad North Reference: True Well: 1 R-06 Survey Calculation Method: Minimum Curvature 4 Wellbore: 1 R-06AL2-01 Design: 1 R-06AL2-01_wp02 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 1R Pad Site Position: Northing: 5,991,050.01ft Latitude: 70°23'11.370 N From: Map Easting: 539,829.9311 Longitude: 149°40'33.803 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.31 ° Well 1 R-06 Well Position +N/-S 0.00 ft Northing: 5,990,930.21 ft Latitude: 70°23'10.210 N +E/-W 0.00 ft Easting: 539,469.74 ft . Longitude: 149°40'44.368 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00ft Wellbore 1 R-06AL2-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2009 7/1/2010 17.20 79.85 57,390 Design 1R-06AL2-01_wp02 1 Audit Notes: 1 Version: Phase: PLAN Tie On Depth: 9,250.00 Vertical Section: Depth From(TVD) +WS +E/-W Direction (ft) (ft) (ft) r) 0.00 0.00 0.00 15.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/-S +E/-W Rate Rate Rate TFO (ft) r) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) Target 9,250.00 78.40 358.32 6,632.83 -3,902.89 -3,824.40 0.00 0.00 0.00 0.00 9,280.00 82.83 359.11 6,637.72 -3,873.30 -3,825.06 15.00 14.78 2.62 10.00 9,361.67 94.90 1.23 6,639.33 -3,791.81 -3,824.82 15.00 14.77 2.59 10.00 9,561.67 94.74 31.34 6,622.13 -3,602.74 -3,769.59 15.00 -0.08 15.05 89.00 9,686.67 93.72 50.11 6,612.83 -3,508.70 -3,688.62 15.00 -0.82 15.02 92.40 9,786.67 90.01 35.57 6,609.56 -3,435.61 -3,620.87 15.00 -3.71 -14.54 256.00 10,136.67 85.25 343.22 6,625.13 -3,102.65 -3,565.51 15.00 -1.36 -14.96 264.00 10,311.67 90.13 9.04 6,632.30 -2,929.72 -3,577.15 15.00 2.79 14.76 80.00 10,491.67 92.16 35.97 6,628.64 -2,764.99 -3,508.92 15.00 1.13 14.96 85.50 10,721.67 90.08 1.52 6,624.01 -2,550.51 -3,436.15 15.00 -0.90 -14.98 267.00 10,750.00 87.64 358.04 6,624.58 -2,522.18 -3,436.25 15.01 -8.61 -12.30 -125.03 4/30/2010 12.21:23PM Page 2 COMPASS 2003.16 Build 69 ORIGINAL , ConocoPhillips ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1 R-06 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1R-06 @ 84.00ft(1R-06) Site: Kuparuk 1R Pad North Reference: True Well: 1 R-06 Survey Calculation Method: Minimum Curvature Wellbore: 1 R-06AL2-01 Design: 1 R-06AL2-01_wp02 Planned Survey Measured ND 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) 9,250.00 78.40 358.32 6,632.83 -3,902.89 -3,824.40 -4,759.73 0.00 0.00 5,987,007.58 535,666.361 TIP/KOP 9,280.00 82.83 359.11 6,637.72 -3,873.30 -3,825.06 -4,731.32 15.00 10.00 5,987,037.15 535,665.551 2 9,300.00 85.79 359.63 6,639.71 -3,853.41 -3,825.28 -4,712.16 15.00 10.00 5,987,057.05 535,665.22 9,361.67 94.90 1.23 6,639.33 -3,791.81 -3,824.82 -4,652.54 15.00 9.95 5,987,118.64 535,665.36 3 9,400.00 94.98 7.00 6,636.03 -3,753.73 -3,822.08 -4,615.06 15.00 89.00 5,987,156.73 535,667.89 9,500.00 94.94 22.05 6,627.34 -3,657.57 -3,797.17 -4,515.72 15.00 89.50 5,987,253.01 535,692.30 9,561.67 94.74 31.34 6,622.13 -3,602.74 -3,769.59 -4,455.62 15.00 90.81 5,987,307.98 535,719.58 4 9,600.00 94.48 37.10 6,619.05 -3,571.16 -3,748.12 -4,419.55 15.00 92.40 5,987,339.68 535,740.89 9,686.67 93.72 50.11 6,612.83 -3,508.70 -3,688.62 -4,343.83 15.00 92.86 5,987,402.44 535,800.04 5 9,700.00 93.23 48.17 6,612.02 -3,499.99 -3,678.56 -4,332.81 15.00 -104.00 5,987,411.20 535,810.06 9,786.67 90.01 35.57 6,609.56 -3,435.61 -3,620.87 -4,255.69 15.00 -104.12 5,987,475.88 535,867.40 6 9,800.00 89.80 33.58 6,609.58 -3,424.63 -3,613.31 -4,243.13 15.00 -96.00 5,987,486.90 535,874.91 9,900.00 88.26 18.65 6,611.28 -3,335.11 -3,569.42 -4,145.30 15.00 -96.00 5,987,576.64 535,918.32 10,000.00 86.83 3.71 6,615.59 -3,237.38 -3,550.10 -4,045.90 15.00 -95.74 5,987,674.46 535,937.12 10,100.00 85.62 348.72 6,622.21 -3,138.10 -3,556.66 -3,951.70 15.00 -95.10 5,987,773.69 535,930.04 10,136.67 85.25 343.22 6,625.13 -3,102.65 -3,565.51 -3,919.76 15.00 -94.11 5,987,809.09 535,921.00 7 I 10,200.00 86.95 352.59 6,629.44 -3,040.94 -3,578.74 -3,863.57 15.00 80.00 5,987,870.72 535,907.451 10,300.00 89.79 7.32 6,632.29 -2,941.27 -3,578.81 -3,767.31 15.00 79.36 5,987,970.39 535,906.85' 10,311.67 90.13 9.04 6,632.30 -2,929.72 -3,577.15 -3,755.73 15.00 78.94 5,987,981.94 535,908.45 8 10,400.00 91.16 22.25 6,631.31 -2,844.85 -3,553.38 -3,667.60 15.00 85.50 5,988,066.92 535,931.77 10,491.67 92.16 35.97 6,628.64 -2,764.99 -3,508.92 -3,578.95 15.00 85.65 5,988,147.01 535,975.81 9 10,500.00 92.09 34.72 6,628.33 -2,758.20 -3,504.10 -3,571.14 15.00 -93.00 5,988,153.83 535,980.59 10,600.00 91.23 19.74 6,625.42 -2,669.57 -3,458.49 -3,473.73 15.00 -93.05 5,988,242.69 536,025.72 10,700.00 90.29 4.77 6,624.08 -2,572.14 -3,437.34 -3,374.14 15.00 -93.48 5,988,340.22 536,046.36 10,721.67 90.08 1.52 6,624.01 -2,550.51 -3,436.15 -3,352.94 15.00 -93.68 5,988,361.86 536,047.44 10 10,750.00 87.64 358.04 6,624.58 -2,522.18 -3,436.25 -3,325.61 15.01 -125.03 5,988,390.18 536,047.18 TD 4/30/2010 12:21:23PM Page 3 COMPASS 2003.16 Build 69 ORG1NAL ConocoPhillips la di ConocoPhillips Planning Report BAKER Alaska HUGHES Database: EDM Alaska Prod v16 Local Co-ordinate Reference: Well 1R-06 Company: ConocoPhillips(Alaska)Inc. TVD Reference: Mean Sea Level Project: Kuparuk River Unit MD Reference: 1 R-06 @ 84.00ft(1 R-06) Site: Kuparuk 1R Pad North Reference: True Well: 1 R-06 Survey Calculation Method: Minimum Curvature Wellbore: 1 R-06AL2-01 Design: 1 R-06AL2-01_wp02 Targets Target Name -hit/miss target Dip Angle Dip Dir. ND +N/S +E/-W Northing Easting -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 1R-06 AL2,AL2-01 PI 0.00 0.00 0.00 -3,970.82 -3,513.68 5,986,941.29 535,977.41 70°22'31.150 N 149°42'27.179 W -plan misses target center by 6630.81ft at 9700.00ft MD(6612.02 TVD,-3499.99 N,-3678.56 E) -Polygon Point 1 0.00 -3,970.82 -3,513.68 5,986,941.29 535,977.41 Point 2 0.00 -4,153.34 -3,800.67 5,986,757.28 535,691.42 Point 3 0.00 -3,962.83 -3,894.68 5,986,947.27 535,596.41 Point 4 0.00 -3,752.81 -3,893.58 5,987,157.28 535,596.40 Point 5 0.00 -2,168.47 -3,542.26 5,988,743.29 535,939.32 Point 6 0.00 -2,240.23 -3,206.60 5,988,673.31 536,275.32 Point 7 0.00 -3,970.82 -3,513.68 5,986,941.29 535,977.41 1R-06AL2-01 t3 0.00 0.00 6,625.00 -2,522.09 -3,436.00 5,988,390.27 536,047.43 70°22'45.398 N 149°42'24.926 W -plan hits target center -Point 1R-06 AL2,AL2-01 H, 0.00 0.00 0.00 -2,168.50 -3,542.15 5,988,743.26 535,939.43 70°22'48.875 N 149°42'28.037 W -plan misses target center by 6634.86ft at 10750.00ft MD(6624.58 TVD,-2522.18 N,-3436.25 E) -Polygon Point 1 0.00 -2,168.50 -3,542.15 5,988,743.26 535,939.43 Point 2 0.00 -2,240.26 -3,206.49 5,988,673.28 536,275.44 Point 3 0.00 -3,970.85 -3,513.57 5,986,941.27 535,977.52 Point 4 0.00 -2,240.26 -3,206.49 5,988,673.28 536,275.44 1 R-06AL2-01 t2 0.00 0.00 6,632.00 -2,965.36 -3,581.37 5,987,946.28 535,904.42 70°22'41.038 N 149°42'29.174 W -plan hits target center -Point 1 R-06AL2-01 t1 0.00 0.00 6,610.00 -3,403.30 -3,600.68 5,987,508.29 535,887.42 70°22'36.731 N 149°42'29.733 W -plan hits target center -Point Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name r) ('7 10,750.00 6,624.58 2-3/8" 2-3/8 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 9,250.00 6,632.83 -3,902.89 -3,824.40 TIP/KOP 9,280.00 6,637.72 -3,873.30 -3,825.06 2 9,361.67 6,639.33 -3,791.81 -3,824.82 3 9,561.67 6,622.13 -3,602.74 -3,769.59 4 9,686.67 6,612.83 -3,508.70 -3,688.62 5 9,786.67 6,609.56 -3,435.61 -3,620.87 6 10,136.67 6,625.13 -3,102.65 -3,565.51 7 10,311.67 6,632.30 -2,929.72 -3,577.15 8 10,491.67 6,628.64 -2,764.99 -3,508.92 9 10,721.67 6,624.01 -2,550.51 -3,436.15 10 10,750.00 6,624.58 -2,522.18 -3,436.25 TD 4/30/2010 12:21:23PM Page 4 COMPASS 2003.16 Build 69 iGINA IP W -§ am= 8 y, K n o sZ _ N h h Q M _% , P *4soy 8 + ° o % R/, M 8 A O to N X i_p Q•f• O Q Q „ M ,-, M 'A8- : V h v M d h iii• i W 8� $ _g o w 3m $ °NN 8 ° 8 ° 8 ° $ ° 8 b $ 8 ° cl Q' F .� • N N N N ° 7, M Q M 1; .� O Nq . m a (uW/8 OM(+)1NnN/() noS V ••e •° $ m iiii ~ g U el 11 o o > 9 oY i Zz 8a C O p 4 8 v o k 74 v$ �� 3 44 _. 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BOX 100360 ANCHORAGE,ALASKA 99510-0360 May 5, 2010 Commissioner-State of Alaska Alaska Oil &Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits permit to drill applications for four lateral sidetracks out of Kuparuk Well 1R-06 (PTD# 185-071) using the coiled tubing drilling rig, Nabors CDR2-AC. Work is scheduled to begin on 1R-06 in June 2010. The CTD objective is to drill four A-sand lateral sidetracks (1R-06A, 1 R-06AL1, 1 R-06AL2, and 1R-06AL2-01). The original wellbore perforations will be plugged with cement and a bridge plug prior to CTD operations(Sundry application is attached). Attached to this application are the following documents that explain the proposed job operations: — Permit to Drill Application Forms for 1R-06A, 1 R-06AL1, 1 R-06AL2, 1 R-06AL2-01 — Proposed & Current Wellbore Schematic — BOP Schematic — Detailed Summary of Operations — Directional Plans — Sundry application for plugging the KRU 1R-06 motherbore If you have any questions or require additional information please contact me at my office 907-263-4172. S cerely, Ak, Gary Eller ConocoP • • Alaska Coiled Tubing Drilling Engineer -\ '' r cr) % 1111 w k.ti y f 1 tp a co i v to O = \ 'f T .7t. C O r _F a C O u7 O N A �tj r r t-- �' oo e N to 1 J a r 1 a '‘- r r ( ■ T. r m M VI m OG �» r r ; ./) •- �I a ra ,ay r r I - II co r r , x 11, r ( ^a ., ./ q N g / -," may. a O !ie kr) O " �r CI 00 • _ C> N G C1 'f 3 Qp C co O r r k Q r U oo r ; M r r :::)::\,1:1_ , 1 Kkc ? a. rte. p ( *-r-n t_ �-�f� \._ ' y cl `.: I ./:;:l'-- 1.-.. 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TRANSMITTAL LETTER CHECKLIST WELL NAME >�/c �� //<— (4 L 2_ 1' PTD# 2-- /C %' �_% _�7( Development ✓Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: �� � � r t-�C—C POOL: kc _ wll c�- ,!v LYC4 L�.- /� ,311 PP J / 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 well /-( //�--OO6 (If last two digits in g Permit No. ?-/ S1 ,API No. 50-O21 - l _5 3 / -r/. API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to 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 co TO 0) 0 N a a) a , L - 3 , Nc , Q . 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