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210-083
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. cili 0 - 0. 3 Well History File Identifier Organizing(done) Two-sided 1 11IIIIIIIIII ❑ Rescan Needed I 1 I[liii INN RE AN DIGITAL DATA OVERSIZED (Scannable) C for Items: ❑ Diskettes, No. ❑ Maps: Greyscale Items: ❑ Other, No/Type: ❑ Other Items Scannable by /Poora Large Scanner Quality Originals:1 fk i e' OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: BY: 40. Date: 3 I /s/ Wi P Project Proofing 1 1111111011111 BY: Maria Date: I 1/31 1 14. /s/ I(vi P Scanning Preparation I x 30 = 0 + cl 0 = TOTAL PAGES 5-6) (Count does not include cover sheet) BY: Maria Date: 31 /s/ Production Scanning 11111111111111111 Stage 1 Page Count from Scanned File: 51 (Count does include cover sheet) Page Count Matches Number in Sca ing Preparation: L/ YES NO BY: iaria,)_______ Date: 1 3 I I I /s/ YVI p 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. ll 1 IIII ReScanned IIIIIIIIIIIIII BY: Maria Date: /s/ Comments about this file: Quality Checked 11111111111111111 12/22/2011 Well History File Cover Pane rinc 1 O C o . fC 4., co c q co cos N , } 0 �1(j O) • OI > c C U d' �' Ur O o E a)La. ct � a N c 2 o ce w 2 2 , z z U � ° 3 E c c Lis i= 0 o 'p 0 0 0 0 0 M 4. V N N N N Z y y p co U O re M M 0 0 1 Z =cn E W a0 CO W C d N a) a) a) a) a) E aO+ I-N Q m c OU 0 0 0 0 0 0 E 0 C Q c :°- U O a g co ? co LO LO U7 LA, In 127 (0 (0 (0 (0 (0 m «a z CL 2 • MN = LU 6 0- = d co Z Lo 0 Ili M N CO R's W O a3 M ao o t u) CO : : : O O (, W o 1 Ce Z 3� j R 1 o �y c > I.� N c ! Z' J U U U N 0 O y a) ON a 1l a) rnw {A E d O t) N U) U) N c O E J Uto U1 roll us I J a II ■Q 9 1 I11 I I H Ce 0 II--_ • co _ co Z co Ca 0) Z CO d re c v/ tz m N Q cn Q D Ci Y g w o Q o zl w w w i Z o > > > > Ili 13 N co V) q) U rn 0 1 2 2 E J ! a) y )a a) > > to ,z j CD ce tY cC C C C C C C 75 a) 1 a) O O O o o O C 7 N N O � ■ � Z � � � � U U r y o Z co .r E O cc cz) j ! 0 ya o Q� z m Z H v c NI ce O O Y W O Z (‘I O } } OQ R .+ d y LL p. > z 2 V O (2 LL y a -) N ce • co 1 0 0 o c _� J < y z Q m b 0 W LL d Z U P• c .+ 1 Z lL 0 �'. o ;U \ l O O Ce w a) a) y J _ J 11 ::: O y T.0> I E a d l W Q G N a 0 0 0 0 a i y 0 oO t c N O O d a' O H J 0 H W J J J _w r I 3 Q > 0 <CC 1 U 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 Pull Tubing r Perforate New Fool r Waiver r Time Extension r Change Approved Rogram r Operat.Shutdow n r Perforate r Re-enter Suspended Well r 2.Operator Name: 4.Current Well Status: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development rq, Exploratory r ' 210-083 3.Address: 6.API Number: Stratigraphic r Service r P.O. Box 100360,Anchorage,Alaska 99510 - 50-029-21331-63-00 7.Property Designation: 8.Well Name and Number: ADL 25635,25640 -1 R-06AL1-01 9.Field/Pool(s): Kuparuk River Field/Kuparuk Oil Pool 10.Present Well Condition Summary: Total Depth measured 11665 feet Plugs(measured) None true vertical 6704 feet Junk(measured) None Effective Depth measured 11665 feet Packer(measured) 8435,8909 true vertical 6704 feet (true vertucal) 6266,6628 Casing Length Size MD TVD 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 6704 0 0 0 0 0 Perforation depth: Measured depth: Slots:9100-10209; 10211-11602 True Vertical Depth: 6701-6677;6676-6703 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 TVD Alaska Oil Gas CMS.Commission PACKER-BAKER'FB-1'PACKER @ 8909 MD and 6628 TVu SAFETY VLV-CAMCO TRDP-1A SSSV @ 1908 MD and 1850 ND AncioragO 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 F,Fi 15.Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations x GSTOR r WIND r WAG r 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 310-332 Contact Bob Christensen/Darrell Humphrey Printed Name Robe D. Christ- Title Production Engineering Specialist Signature / /' - Phone:659-7535 Date HBDMS DEC 0'120104, Form 10-404 Revised 10/2010 !2 /a l& Submit Original Only • 1 R-06AL1-01 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-06AL1-01 ConocoPhjlljay1�� Well Attributes ax Angle&MD TD Alaska. Wellbore APNUWI Field Name Well Statue Inc!(°) MD(ftl(B) Act Btm(IWKB) 500292133163 KUPARUK RIVER UNIT INJ 100.22 9,515.03 11,605.0 Comment 1125(ppm) Date Annotation End Date K813rd(R) Rig Release Date "' _SSSV:TRDP last WO: 37.61 5/15/1985 Well Confi9.-IR-WAL1,10/31/2010 9'.34.57 AM Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:GLV C/O,SET PLUG/CATCHER Imosbor 10/31/2010 HANGER,33 Casing Strings ill Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd AL1-01 LINER 2 3/8 1.995 8,815.4 11,605.0 4.43 L-80 STL I Liner Details Top Depth CONDUCTOR, (TVD) Top lnol Nomi... 3&110 Top MKS) (RKB) (°) Item Description Comment ID(in) 8,815.4 6,564.1 33.42 DEPLOY SHORTY DEPLOYMENT SLEEVE 1.000 SAFETY vLV, 10,210.0 6,676.2 98.32 DEPLOY TORQUE-THRU DEPLOYMENT SLEEVE 1.000 1,906 I Perforations&Slots GAS UFT, Shot 2.041 Top(IVO) Btm(TVD) Dees Top(ftKB) Btm(BBB) (SKR) (1B(B) Zone Dab OK- Type Comment GAS4,326 T, 9,100.0 10,209.0 6,700.8 6,676.3 7/5/2010 32.0 SLOT Alternating solid/slotted pipe- 0.125"x2.5"@ 4 circumferential adjacent rows,3"centers staggered SURFACE, 18 deg,3'non-slotted ends 37.4,069 GAB LIFT, 10,211.0 11,602.0 6,676.1' 6,703.1 7/5/2010 32.0 SLOT Altemating solid/slotted pipe- 5,831 0.125"x2.5"@ 4 circumferential GAS LIFT, adjacent rows,3"centers staggered 8,285 18 deg,3'non-slotted ends GAS LIFT, Notes:General&Safety e'er End Date Annotation GAS LIFT, 7/19/2010 NOTE:WELL SIDETRACK 1R-06A,AL1,AL1-01,AL2,AL2-01 7,198 C 7/19/2010 NOTE:WELL IS INJECTOR THAT WILL BE PRE-PRODUCED GAS uFr. { 7/21/2010 NOTE:View Schematic w/Alaska Schematic9.0 7,815 GAS 8,LIF061 T, GAS LIFT, 8,381 P88,6421 ij---I PACKER,8.435 CATCHER, ' 6.454 PLUG.8,455 GAS 8,47 LIFT3, MI 11.1 GAS LIFT, 8,545 MI WHIPSTOC8 K, , I 6,81 WINDOW'A', 8,820-8832 • i GAS LIFT 11 j MMG,8,890 iFL�' LOCATOR, J 6,908 PACKER,8,909 `Illl S8E,8913 CIBP,8,921 NIPPLE,8,924 - Mandrel Details SOS,8,931 Top Depth Top Port -- (TVD) Incl OD Valve Latch Size TRO Run Stn Top(ftKB) IRKS) I°) Make Model (In) Sam Type Type ON (pei) Run Dab Com... 1 2,040.8 1,963.6 33.06 CAMCO KBUG 1 GAS LIFT DMY BK 10/30/2010 FISH,9,145 - 4 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 4 6,285.1 4,787.6 48.27 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/30/2010 PRODUCTION, 5 6,762.2 5,103.9 48.28 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 sa,279 6 7,198.2 5,396.4 47.03 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 6/30/1985 7 7,615.3 5,683.7 46.14 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/30/2010 SLOT, 8 8,060.9 5,995.7 44.90 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 10,12611,583 - 9 8,381.1 6,225.9 42.60 CAMCO KBUG 1 1/2 PROD DMY rdo20 0.000 0.0 10/30/2010 1(IR.O/NSed\ I 10 8,473.5 6,294.9 40.49 CAMCO MMG-2 1 1/2 PROD OPEN 0.000 0.0 11/21/1993 TD 11,585 KUP 1 R-06AL1-01 o ConocoPhillips Alaska,1I1c _ ,«K,.1,NUmp. KB-Ord(ft) Rig Release Oct. .. 37.61 5/15/1985 Well Contd.-7 R-06AL7,107310010 9:3457 AM Schematic-Actual HANGER,33 aa� CONDUCTOR, I 3&110 SAFETY VLV, I- GAS 1908 GAS LIFT, 2,041 GAS LIFT, 4,326 SURFACE,37-4,&GAS LIFT, 5,631 LIFT, 6.285 GAS LIFT, 6.762 GAS LIFT, 7,196 GAS LIFT, 7,615 GAS LIFT, 8,061 GAS LIFT, 8,381 FOR.8,421 PACKER.8,435 CATCHER, 8.454 PLUG.8.455 GAS LIFT. 6,473 GAS LIFT, 8,545 WHIPSTOCK. I 8,819 WINDOW.K. 8,820-8,832 GAS LIFT S MMG.8,890 Lr—.JT7 LOCATOR, 8,908 PACKER,8,909 CD SBE,0,013—- -- CISP,8.921 NIPPLE.8 524 - Mandrel Details SOS,8,931- s Top Depth Top Port (TVD) Inc' OD Valve Latch Size TRO Run Stn Top MKS) (MB) (°) Make Model (In) Sery Type Type lin) (psi) Run Date Com... 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 FISH,9,195 --- ---Q 12 8,890.3 6,616.8 52.78 CAMCO MMG-2 1 1/2 PROD OPEN 0.000 0.0 5/21/2010 PRODUCTION, . 59,279 SLOT, 10,12611583 _ _ 1117 5 ✓� i LILINR, 10,117-11,585 TD(1 R.08AL1), 11,555 aa SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 Robert D. Christensen Production Engineering Specialist 013 ConocoPhillips Alaska, Inc. (' P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk Oil Pool, 1 R-06AL 1-01 Sundry Number: 310-332 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, o9 / t Daniel T. Seamount, Jr. Chair DATED this 7 day of October, 2010. Encl. • * EVf t to t° u` P STATE OF ALASKA 0 ViY ALAS, .)IL AND GAS CONSERVATION COMMISS._-1 SEP 2 q 2010 to APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Win&'PI DOW CIIIIIIIiSSion 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair well r cArgispved Program r Suspend r Rug Perforations r Perforate r Rill Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing 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 210-083 • 3.Address: Stratgraphic r Service r" 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 50-029-21331-63 ' 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-06AL1-01 ' 9.Property Designation: 4. 10.Field/Pool(s): ADL 25635,25640 Kuparuk River Field/Kuparuk Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total D pth ND(ft): Effective D9pth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): il�4 D94e�'�.`I e-)2 2s (4 !lc'. III 4 r 713q 4)N 4 't' Casing �l 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' "AL1-01"LINER 2790 2.625 11605' 6704' Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Slots:9100-10209; 10211-11602 6701-6677;6676-6703 3.5 J-55 8931 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft) PACKER-BAKER'FHL'PACKER MD=8435 ND=6266 PACKER-BAKER'FB-1'PACKER MD=8909 ND=6628 SAFETY VLV-CAMCO TRDP-1A SSSV MD=1908 ND=1850 • 12.Attachments: Description Summary of R-oposal p 13. Well Class after proposed work: Detailed Operations Program T 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 E Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r - GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG E 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 �,,L✓1 S ignature 4E Phone:659-7535 Date O Va2 V/0 Commission Use Only Sundry Number:3 0-3-3„a Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test /Location Clearance r Other: Subsequent Form Required: /O .449 L/ APPROVED BY Approved by: O`' 4 9f}�If l)'‘ COMMISSIONER THE COMMISSION Date: /a/ /0 Form 10-403 Revised 1/2010 LtIRI t I NA �/ �O. y/O Duplicate /t"�lm • 1 R-06AL1-01 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to convert KRU Well 1R-06AL1-01 (PTD 210-083) from Oil Production service to Water Injection service. Well 1R-06AL1-01 (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'bid)was cemented with 1390sx Permafrost E and 425sx PF C. The 7" Production casing (9279' and/6729'bid)was cemented with 510 sx Class"G"and 250sx PFC. The top of the Kuparuk B sand was found at 8820' and/6568'bid. The top of the Kuparuk A3 sand was found at 10248' and/6670' bid. The injection tubing/casing annulus is isolated via Baker FHL Packer located @ 8435' and/6266'bid. KU P 1 R-06AL1-01 ConocoPhillips t' well Attributes !Max Angle&MD TD AI I,h 1 111, Wellbore APIIUWI Field Name Well Status Inol(°) MD(f6KB) Act Btm(ftKB) LoKxoHrn,w 500292133163 KUPARUK RIVER UNIT INJ Comment H2S(ppm) Date Annotation End Date KB-Ord(R) Rig Release Date' Well tonne:-1R 06AL1-01,701/201012:43.31 PM —SSSV:TRDP Last WO: 37.61 5/15/1985 - Schematic-Actual Annotation Depth(RKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:SIDETRACKS,GLV C/O Imosbor 7/21/2010 HANGER,33 Casing Strings '1 Caging Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String W..String... String Top Thrd AL1-01 LINER I 23/8 I t. 1.995 I 8,815.4 I 11,605.0 I I 4.43 I L-80 STL Liner Details CONDUCTOR, I I Top Depth 38-110 (TVD) Top Incl Noml... Top(RKB) (RKB) 1°) Item Description Comment ID(In) 8,815.4 DEPLOY SHORTY DEPLOYMENT SLEEVE 1.000 LV, 1. SAFETY vV "4. _ 10,210.0 I DEPLOY TORQUE-THRU DEPLOYMENT SLEEVE 1.000 GAS LIFT, _ Perforations&Slots 2,041 •Shot GAS LIFT, • Top(TVD) Btm(TVD) Dens 4.328 Top(MOM Btm(Rita) (MB) 18KB) Zone Date Ish•.•_ Type Comment 9,100 10,209 7/5/2010 32.0 SLOT Alternating solid/slotted pipe- SURFACE. .A 0.125"x2.5"@ 4 circumferential 37.4,859 adjacent rows,3"centers staggered GAS LIFT, 18 deg,3'non-slotted ends 5,831 GAS LIFT, 10,211 11,602 7/5/2010 32.0 SLOT Alternating solid/slotted pipe- 6,285 - 0.125"x2.5"@ 4 circumferential Gas LIFT, adjacent rows,3"centers staggered 6,762 18 deg,3'non-slotted ends GAS LIFT, Notes:General&Safety 7'198 End Date Annotation GAS LIFT, �- 7/19/2010 NOTE:WELL IS INJECTOR THAT WILL BE PRE-PRODUCED 7515 i♦ 7/21/2010 NOTE:View Schematic w/Alaska Schertlatic9.0 GAS LIFT, 8,061 GAS LIFT. 8,381 ' - PBR,8,421 PACKER.8,435 a( ) GAS LIFT, r 8,473 l GAS LIFT, f 8545 • Ili WHIPSTOCK. 8.819 i OW WINDOW°A 8,D '32 2 I GAS LIFT_ 1E.-MMG,8,890 f-f LOCATOR, 8,906 NMI PACKER,8,909 SBE,8,913 1.55 1=1 1.1 CIBP,8,921 �_- I.' NIPPLE.8,924 IBM. I.' 505,8,931 I If FISH.9.145 Mandrel Details Top Depth Top Port (TVD) Intl OD Valve Lath Size TRO Run PRODUCTION, Stn Top(MEI) IRKS) 11 Make Model _ (in) Sery Type Type (W (psi) Run Date Com... 359279 1 2,0406 CAMCO KBUG 1 GAS LIFT GLV BK 0.125 1,317.0 7/21/2010 SLOT. 9,10a1Q209T,-\ 2 4,326.0 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,333.0 7/21/2010 SLO 9,471-10.244 3 5,630.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 4 6,285.1 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,319.0 7/21/2010 �I. . 5 6,762.2 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 'A'LINER, �( 6 7,198.2 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 6130/1985 9,480-10.245 7 7,615.3 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,342.0 7/21/2010 SLOT, 1o.2n-11,TD 8 8,060.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 • rD DR-gsA10,940 9 8,381.1 CAMCO KBUG -1 12 PROD OV rdo20 0.188 0.0 7212010 10.940 10 8,473.5 CAMCO MMG-2 -1 12 PROD OPEN 0.000 0.0 11/21/1993 AL1-01 LINER. 8815.11,605 vi mi limiZ HMO miMa clz Cd 1 _ .- 4', '-x,.. '7,,-);,-",, t,..1,...:-,,..,' _.:.,.5,, L4.,-..., ',`e-:::,'---1. 3;---'t - -- .—liar.,4,11.t.:.—...:a.:....-, i '...r.:.:-_- . —-- , , , Asi'■,. ',........-......Lr.. .1 .-..6 , ,--, ,-- ) ...,- i. ._ 1 1 I - 3 .,--,•-f-_, = ...... _....., ... 1,L1 P _...) ._ f , _.. ca ...,...-.., cu o . ic cu 'es = I 0 0) co fel C8 < co z 0 = a: To . E i -- cm 6t =, 0 ot =1 c-5t =1 0 ‹ 0\ ._ 0 b- a) u., - tri - w - Lii u- c 1: LL co >, _ - 0 - 0 - ±'.... 1- ' Egil= " E col- L- E 01- III . . . ..- - _ ...... 0013 - 00o 90 "5 CU 17_ I' - 0 .- o _ i 4- , co /.'6 R (1) 0 &11. C13 co 0 i 0 0 mm = um0 = c) mm = o m - i - i ,- E -0 _ :-• .,.. cn •. , r't a. ri co ...-4- O N _ o fr co a. O .- 0 O VI o s. 0 c..9 c 0 0 o = .0- -0 . 0 CD .0 co el E co c4 3 . o 2 , 3 o el o co 45 L'; o u? em 5 o r? - c N 6 Cli 0 W C c E <73 0 t- 0 0 0 1 0. - , - a) O (° CI ni CI3 M 1.0 Zt; 3 «3 Ln E CI Z TT; .- co .c ,- „- va- = 0) 2 -6 - ....• ..- , 0) 0 .0 > 0 ...0▪ m -w- c0- 0e0 < c c .xm _ (,) ,- m = t4m ,35WemE w - = 0 — m _c I- :5 a- -. En 0 :E 0 -.... 0 - a 2 t. a; 'E sr,, ai "±- -a cn oi , ...1 = w- m a Z o_i _c _ 00. - -4.. ._ 0..cm 0 = a) .w cr) -c o x cn 0 2."- cr)e-.- S ''"' Cri = >, cl: = g 0 8 - 0.) . •• 0 0 ° ijj c4 (..) .— a) ■-. a) 1-101- ce 0 '6 0 o 8 0) _1 o 4;4 5 ,-; _, ., tPw .2 > gm = 720 § = = < 0 0 - p c c ca z--- a x- /.... C, C.) C -. ---' •■•• . U oui - ,; i.) ,-,6 *- c, u1-LI W0 ' ooccoml- oco0 6. 0 .c2caZ0 ,-. cm4"-tc ...„.. 12Locm Om cez300c000z < 1... .suE = < (..) el < m 0. 0 a. < C.) co a_ < nu in Li) < 0 I- STATE OF ALASKA ALASK. ,IL AND GAS CONSERVATION COMMI. .1N REPORT OF SUNDRY WELL OPERATIONS 1.Operations Performed: Abandon r Repair w ell r Rug Fbrf orations r Stimulate r Other r Pre-Prod Inj Alter Casing Pull Tubing <30 days 9 r 9 r Perforate New Pool r Waiver r Time Extension r Change Approved Program r Operat.Shutdown r Perforate r Re-enter Suspended Well r 2.Operator Name: 4.Current Well Status: \Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 210-083 3.Address: G.API Number: P. O. Box 100360,Anchorage,Alaska 99510 Stratigraphic r Service r 50-029-21331-63 7.Property Designation: 8.Well Name and umber: ADL 25635,25640 1 R-06AL1-01 9.Field/Pool(s): Kuparuk River Field/Kuparuk Oil Pool 10. Present Well Condition Summary: Total Depth measured 11605 feet Plugs(measured) None true vertical 6704 feet Junk(measured) None Effective Depth measured 11605 feet Packer(measured) 8435, 8909, 8921 true vertical 6704 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 2790 2.375 11605 0 0 0 Perforation depth: Measured depth: Slots 9100-10209; 10211-11602 RECEIVED True Vertical Depth: 6701-6677;6677-6703 AU f 1 3 2010 Tubing(size,grade,MD,and ND) 3.5,J-55,8931 MD,6640 TVDl�4S�($ u &�3.C .Commission Artcit'trage Packers&SSSV(type,MD,and ND) PACKER-BAKER'FHL'PACKER @ 8435 MD and 6266 ND 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 Printed Name / R•bert D. Chri _ensen Title Production Engineering Specialist Signature / / , Phone:659-7535 Date 6 dv/InD :-(G-/o Form 10-404 Revised 7/2009 RBDMS AUG 13 a Submit Original Only • 1 R-06AL1-01 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 e, KUP 1 R-06AL1-01 ConocoPhilli , g Well Attributes Max Angle&MD TO Welibore API/UWI Field Name Well Status Inc!I') MD(ftKB) Act Btu/(ftKB) iorpcoRvllips 500292133163 KUPARUK RIVER UNIT INJ Comment H2S(ppm) Date Annotation End Data KB-Ord(ft) Rig Release Date "' SSSV:TRDP Last WO: 37.61 5/15/1985 Well Contg.-1R.06AL1-01,7/21/201012.43'.31 PM -- -- Schematic-Actual Annotation Depth(KKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason:SIDETRACKS,GLV C/O Imosbor 7/21/2010 HANGER,33 Casing Strings Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String... String Top Thrd AL1-01 LINER 23/8 1.995 8,815.4 11,605.0 4.43 L-80 STL Liner Details CONDUCTOR, I Top Depth 3B-110 (TVD) Top Incl Noml... Tap(68KB) (RKB) (^) Item Description Comment ID(In) 8,815.4 DEPLOY SHORTY DEPLOYMENT SLEEVE 1.000 SAFETY W.V. I ---*111---' ,10,210.0 DEPLOY TORQUE-THRU DEPLOYMENT SLEEVE 1.000 1,908 GAS LIFT 2,041 1 I - Perforations&Slots Shot GAS LIFT, Top(TVD) Btm(TVD) Dens 4,325 Top(SKS) BEn(ftKB) (KKB) MKS/ Zone Deb (sh... Type Comment 9,100 10,209 7/5/2010 32.0 SLOT Alternatingsolid/slottedpipe- SURFACE. ,♦ d, 0.125"x2.5"@ 4 circumferential 37-4,659 adjacent rows,3"centers staggered GAS LIFT, 5,631 4 18 deg,3'non-slotted ends E GAS LIFT, 10,211 11,602 7/5/2010 32.0 SLOT Alternating solid/slotted pipe- 6.25 ° " 0.125"x2.5"@ 4 circumferential I♦ adjacent rows,3"centers staggered GAS LIFT. 6,762 4 18 deg,3'non-slotted ends GAS LIFT, i Notes:General&Safety 7'198 End Date Annotation GAS LIFT, �r _ 7/19/2010 NOTE:WELL IS INJECTOR THAT WILL BE PRE-PRODUCED 7,615 7/21/2010 NOTE:View Schematic w/Alaska Schematic9.0 GAS LIFT, f 8,081 C GAS LIFT, 6,381 PBR,8,421 ir PACKER,8,45 I� GAS LIFT, 8,473 GAS LIFT. 8,545 / 1 El WHIPST8.812 OCK, 1 I WINDOW'A', 8,8200.832 I.1 GAS LIFT IC: MMG,8,890 LOCATOR, i 1 1 8,908 ___ PACKER.8,909 ��� SBE,8913 1=i 1n1 CIBP,8,921 ,ll. l.� NIPPLE.8.924 1 IIj I. SOS.8,931 IM III FISH,9,145 Mandrel Details Top Depth Top Port (TVD) Inc' OD Valve Latch Size TRO Run PRODUCTION, Stn Top MKS) MS) r) Make Model (In) Sery Type Type lint (psi) Run Dab Com... 35-9.279 1 2,040.8 CAMCO KBUG 1 GAS LIFT GLV BK 0.125 1,317.0 7/21/2010 SLOT. 9.1DU1o•2aeN 2 4,326.0 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,333.0 7/21/2010 SLOT, 9,471-10,244 3 5,630.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 4 6,285.1 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,319.0 7/21/2010 E 5 6,762.2 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 •A•LINER, 6 7,198.2 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 6/30/1985 9,46040245 7 7,615.3 - CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,342.0 7/21/2010 SLOT, 10,211-11,602 r. 8 8,060.9 CAMCO KBUG 1 GAS LIFT DMY 8K 0.000 0.0 11/10/1987 TD IIR-06AL1-01), 9 8,381.1 CAMCO KBUG 1 12 PROD OV rdo20 0.188 0.0 7/21/2010 10,940 10 8,473.5 CAMCO MMG-2 1 12 PROD OPEN 0.000 0.0 11/21/1993 AL1-01 LINER, 8,81511,805 KUP 1 R-06AL1-01 ConocoPhillips +► "' Alaska.Inc. ` KB-t3rd(R) Rig Release Date ••• Well Con69 -1R-06AL1-01 721201012'.43'.31 PM - 37.61 5/15/19$5 Schemalc•Actual HANG ER.33 CONDUCTOR, I 38-110 SAFETY VLV, "11 1,908 GAS LIFT, 2,041 GAS LIFT, JIII 4.326 SURFACE. 37-4,659 GAS LIFT, 5.631 GAS LIFT, 6.285 GAS LIFT, r 6,762 l GAS LIFT. 7.198 GAS LIFT, _ 7,615 GAS LIFT, 13E161 GAS LIFT, 8,381 PBR,8,421 PACKER,8,435 666 GAS LIFT, 8,473 GAS LIFT, yr 8,545 L- A WHIPSTOCK, , I 8,819 WINDOW ��l 6820-13,832'A. GAS LIFT MUG.8,890 LOCATOR. 8,906 PACKER,8,909 58E.5,913 ear CI6P,8,921 •rM, 8, NIPPLE. 924 I SOS.8.931 if FISH,9,145 Mandrel Details Top Depth Top Port (TVD) Inc' OD Valve Latch Sire TRO Run PRODUCTION, Stn Top(DNB) (6KB) 1) Make Model (In) Sero Type Type (In) (p•i) Run Dab Corn... 359,279 11 8,544.5 CAMCO MMG-2 1 1/2 PROD DMY RK 0.000 0.0 5/21/2010 SLOT, "'V818518209\ 12 8,890.3 CAMCO MMG-2 1 1/2 PROD OPEN 0.000 0.0 5/21/2010 T. 9,471-10.24 1\11' A'LINER, 9,486 SLOT, SLOT, 10,211 41,602 TD (1R-06AL1-01), 10,940 AL1-01 LINER, 8.815-11,605 • . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la.Well Status: Oil 0 Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended ❑ 1b.Well Cla 20AAC 25.105 20AAC 25.110 Development Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No.of Completions: , 1 Service L Stratigraphic Test❑ 2.Operator Name: 5.Date Comp.,Susp., 12.Permit to Drill Number: • ConocoPhillips Alaska, Inc. orAband.: July 19,2010 210-0830/ • 3.Address: 6.Date Spudded: 13.API Number: P.O. Box 100360,Anchorage,AK 99510-0360 June 29,2010 • 50-029-21331-63 ' 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 2,2010 1 R-06AL1-01 • Top of Productive Horizon: 8.KB(ft above MSL): 84'RKB . 15.Field/Pool(s): 188'FNL, 1002'FWL,Sec.30,T12N,R10E,UM GL(ft above MSL): AMSL Kuparuk River Field Total Depth: 9.Plug Back Depth(MD+ND): 353'FNL,2291'FWL,Sec.30,T12N,R10E,UM 11605'MD/6704'TVD Kuparuk River Oil Pool • 4b.Location of Well(State Base Plane Coordinates,NAD 27): 10.Total Depth(MD+ND): 16.Property Designation: Surface: x-539470 • y- 5990930 • Zone-4 . 11605'MD/6704'TVD• ADL 2564 25640 • TPI: x-535900 y- 5985716 Zone-4 11.SSSV Depth(MD+TVD): 17.Land Use Permit: Total Depth: x-537190 y- 5985557 Zone-4 1908'MD/1850'TVD 2560 18.Directional Survey: Yes ell 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'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 10115'MD/6682'TVD 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD _ SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# 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 8822' 11605' 6569' 6704' 3" slotted liner 24.Open to production or injection? Yes II 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" 8932' 8435'MD/6266'TVD slotted liner from 9100'-11602'MD 6700'-6703'ND _ 8909'MD/6628'ND COMPL-Elaal 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. I DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED l' t ; none 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 0 Sidewall Cores Acquired? Yes ❑ No Q 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. RECEIVED NONE AUG 0 4 2010 A�� Alaska Ofl&Gat Cars.Omission • �BPMS AUG 0.4 201 Anchar3ge Form 10-407 Revised 12/ CONTINUED ON REVERSE Submit original only 17 rr7 •I 28. GEOLOGIC MARKERS(List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? El Yes El No If yes,list intervals and formations tested, Permafrost-Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form,if Permafrost-Bottom 1550' 1527' needed,and submit detailed test information per 20 AAC 25.071. Top Kuparuk A Sand 10248' 6670' 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 Na V a e Tine: Alaska Wells Manager ��� l \ Signature Phone 265-6306 Date V 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 Logs Date ` From To Dur S Depth`E. Depth Phase Code Subcode °,T Comment 00:00 01:30 1.50 0 0 PROD2 DRILL CIRC P Circulate CT from KWF to water. BOPE test PJSM. 01:30 11:00 9.50 0 0 PROD2 DRILL BOPE P Perform BOPE test. Replace actuator on B5. 11:00 12:18 1.30 0 0 PROD2 DRILL DISP P Displace FW from coil with KWF, install checks in UQC, RU floor for liner ops,confirm hole is full,2.3 Bbls to fill 12:18 12:42 0.40 0 0 COMPZ CASING SFTY P PJSM for liner operations,discuss safety joint drill 12:42 15:00 2.30 0 1,468 COMPZ CASING PULD P Start running liner,safety joint drill after first joint in hole. Total of 45 joints slotted liner 15:00 16:00 1.00 1,468 1,513 COMPZ CASING PULD P MU aluminum billet,GS and Inteq liner running BHA, MU injector 16:00 17:42 1.70 1,513 8,713 COMPZ CASING RUNL P RIH 17:42 18:24 0.70 8,713 10,744 COMPZ CASING RUNL P Correct depth at flag,+14'. Wt. check,29K PUW, 13KRIW. Run through window and continue in open hole at 50 FPM. 18:24 19:18 0.90 10,744 11,033 COMPZ CASING RUNL P 10742'Stack weight to-12K, PU 3 times to get by,40K PUW 11031', PU 3 times 11062', PU 1 time 19:18 20:03 0.75 11,033 11,590 COMPZ CASING RUNL P Tag TD. Pump at 1.3 BPM,4000 psi to release liner. PUH pumping down backside. 20:03 20:33 0.50 11,590 10,297 COMPZ CASING DLOG P Tie in:-5'correction. Correction places TOL at 10116'; BOL 11585'. 20:33 22:30 1.95 10,297 0 COMPZ CASING TRIP P POOH pumping KWF 0.72 BPM,0.2 BPM returns. 22:30 23:00 0.50 0 0 COMPZ CASING PULD P At surface. Flow check well. Conduct PJSM regarding lay down and P/U tools. 23:00 23:15 0.25 0 0 COMPZ CASING PULD P Lay down liner running tools. 23:15 00:00 0.75 0 0 PROD3 STK PULD T P/U drilling assembly#3(BHA#11). 06/29/2010 Losses for 24 hours 208 bbls. KOB from 10116',drilling ahead-tagged Ankerite @ 10278'.Slow ROP until 10,321' 00:00 00:30 0.50 0 0 PROD3 STK PULD T Complete injector and packoff maintenance that was being performed concurrently with P/U tools. Stab on well and line up to run in hole. 00:30 03:15 2.75 0 8,870 PROD3 STK TRIP T RIH pumping 0.2 BPM KWF followed by 9.4#Powervis,timing out mud to reach BHA with BHA at stop above window. 03:15 04:45 1.50 8,870 8,870 PROD3 STK CIRC T Stop at 8780'and swap hole to 9.4# Powervis. Pumpin 1.0 BPM, initially 0.3 BPM retums gradually increasing to 0.7 BPM. Close ECD in BHA. Page 13 of 33 Time Logs ' Date - From ;To Dur S.Depth E.Depth Phase Code Subcode T Comment 04:45 05:30 0.75 8,870 10,115 PROD3 STK TRIP T RIH; 11K do wt. Clean through window. Once through window, come online 9.4#Powervis 1.2 BPM, 1.2 BPM returns,3000 CTP, 125 WHP,3976 BHP. 05:30 08:00 2.50 10,115 10,125 PROD3 STK KOST T Tag billet at 10,116'dry. PU 1',start circ,begin time milling sequence. Saw motor work immediately,so PU another 0.5'and restart time milling. 1.4 bpm in&out,0 psi WHP,3500 psi CTP,4085 psi BHP. 08:00 09:54 1.90 10,125 10,264 PROD3 DRILL DRLG T Continue drilling ahead, 1.4 BPM,full returns,3550 CTP Getting some losses at 10,246'. Returns down to 1.0 bpm. 3900 psi CTD,0 psi WHP,4130 psi BHP, 1.45 bpm in. 09:54 11:21 1.45 10,264 10,264 PROD3 DRILL WPRT T Wiper to 9150',29K PUW 11:21 20:51 9.50 10,264 10,321 PROD3 DRILL DRLG T Drilling ahead. Hit ankerite at 10278'. PU with 10k overpull, run back down to drill ahead. Returns fluctuating 50-70%but gradually improving. Several stalls while in ankerite. 3200 psi CTP,0 psi WHP,4000 psi BHP, 1.33 bpm in. 20:51 22:33 1.70 10,321 10,415 PROD3 DRILL DRLG T Drilled through ankerite.losing roughly 4 bbls an hour for losses. Continue drilling ahead-ROP 50, WOB 2.5,CT weight 5.7K, 1.48 bpm,rate out 1.36, circ 3700psi. 22:33 00:00 1.45 10,415 10,415 PROD3 DRILL WPRT T Wiper trip-CT weight 29K,started losing.4 bpm prior to wiper trip. Slight overpull @ 10265'to 38K. POOH to 9150'-RIH seen light tag @ 10,280'(ankerite section). 06/30/2010 Continue drilling ahead. Performed mud swap with 1631'on system.Tight spot @ 10,275',clear drift with 90L TF. 140 bbl losses for 24 hours. 00:00 03:00 3.00 10,415 10,455 PROD3 DRILL DRLG T Continue drilling ahead-good ROP to 10,443'-hit ankerite.Slow ROP. Losses roughly 7 bbls/hour. 03:00 04:00 1.00 10,455 10,565 PROD3 DRILL DRLG T Broke through-drilling ahead-ROP 90 fph,WOB 2.2K,Ct weight 6.5K, 1.40 bpm, returns 1.15 bpm, Circ. 3650, BHP 4052 psi, ECD 11.9. 04:00 06:00 2.00 10,565 10,565 PROD3 DRILL WPRT T Wiper trip with tie in-29K off bottom. -5'correction. RIH,set down 1.5k WOB at 9060 and 1.5k at 10280'but get past without pickup or dropping rate. 06:00 07:45 1.75 10,565 10,715 PROD3 DRILL DRLG T Drilling ahead with excellent ROP. Losses 8-10 bbl/hr. 3500 psi CTP,0 psi WHP, 1.33 bpm in, 1..5 bpm out,4115 psi BHP. Page 14 of 33 Date From To Dur S.Depth E. Depth Phase Code ` Subcode T Comment 07:45 09:45 2.00 10,715 10,715 PROD3 DRILL WPRT T Wiper trip to 9150'. 29k clean PU off bottom. RIH,set down twice at 10,275. Got past by orienting at 90L,pumping 0.3 bpm, and slowing to 20 fpm. Drilled TF was 85L. Start mud swap while RIH. Mud system had drilled 1631'and had 0.6% solids. 09:45 10:45 1.00 10,715 10,812 PROD3 DRILL DRLG T Back on bottom drilling. Fresh 9.4 ppg Powervis at the bit. CTP=3800 psi, BHP=4050 psi, WHP=0 psi,WOB=2.8k,CW= 2k,dP=280 psi, In=1.45 bpm,Out =1.29 bpm. 10:45 11:45 1.00 10,812 10,865 PROD3 DRILL DRLG T Hit a little hard streak at 10812'. Drilling ahead. CTP=3700 psi, BHP=4010 psi, WHP=0 psi,WOB=2.7k,CW= -2k, In=1.47 bpm,Out= 1.29 bpm. 11:45 13:51 2.10 10,865 10,865 PROD3 DRILL WPRT T Wiper to 9150'MD. PU=29k. RIH, no bobble at all at 10,275'when followed same process as last time. 13:51 15:21 1.50 10,865 10,950 PROD3 DRILL DRLG T Back on bottom drilling. Losses=4 bbl/hr. CTP=3680 psi, BHP=4080 psi, WHP=50 psi,WOB=2.8k,CW= 1k, In=1.44 bpm,Out= 1.3 bpm. 15:21 16:21 1.00 10,950 11,015 PROD3 DRILL DRLG P Drilling ahead. 16:21 19:21 3.00 11,015 11,015 PROD3 DRILL WPRT P Wiper to tie-in correction-5 ft. Slight overpull at 10,275'.Orientate 90 left. Slight weight bobble @ 9058'RIH, nothing else. 19:21 22:21 3.00 11,015 11,070 PROD3 DRILL DRLG P Drilling ahead-1.40 bpm, 1.30 returns,circ 3700 psi, WOB 1.7,Ct weight 1K, BHP=4080 psi, ROP 10, ECD 12. May have faulted into A-5- turning down.SLOW ROP from 11025'. 22:21 23:21 1.00 11,070 11,090 PROD3 DRILL DRLG P Starting to have weight transfer issues @ 11070'.A-5 formation in samples-shale/silt.Mix up a sweep of drillzone-1.48 bpm,3800 psi, BHP 4060, ECD 11.9, ROP 20, WOB 1.8K,CT weight-10K. 23:21 00:00 0.65 11,090 11,113 PROD3 DRILL DRLG P BHA wiper while pumping down the 5 bbl drillzone sweep into CT. Lost prime when came online. P/U weight 31K. Drilling ahead-Weight transfer stayed about the same but ROP increased to 60 fph. 07/01/2010 Drilling ahead-Slow ROP due to weight transfer, POOH for Agitator.Drilling ahead-diff.stuck @ 11437' Pulled free. 128 bbls losses. Page 15 of 33 Time Logs Date From To Dur S. Depth E. Depth Phase Code < Subcode T Comment 00:00 02:00 2.00 11,113 11,165 PROD3 DRILL DRLG P Drilling ahead-1.45 bpm,3800 psi, BHP 4050, ECD 11.9,ROP 55, WOB 2.2,CT weight-12K. 11130' Pump another 7 bbl sweep, ROP dropping off-poor weight transfer. 02:00 04:00 2.00 11,165 7,500 PROD3 DRILL TRIP P Wiper trip&POOH to P/U agitator- still having weight transfer issues to bit.CT weight-13K WOB 1.7K. P/U weight 30K. 04:00 04:30 0.50 7,500 7,500 PROD3 DRILL SFTY P H2S drill(leak in cellar)-Rig evacuation and muster. Lessons learned captured. 04:30 06:15 1.75 7,500 0 PROD3 DRILL TRIP P Continue POOH following MP schedule holding 11.5 ppg EMW at window. Losses—6 bph. 06:15 10:15 4.00 0 0 PROD3 DRILL PULD P Undeploy lateral BHA#11. Pressure deploy Agitator BHA#12. 10:15 13:45 3.50 0 11,165 PROD3 DRILL TRIP P RIH. No problem getting past window. Slight WOB bobble at 9060. 13:45 16:45 3.00 11,165 11,315 PROD3 DRILL DRLG P Drilling ahead. 1.35 bpm,3950 psi, BHP 4080, ECD 12.0,WOB 2.6,CT weight-1 K. 16:45 19:30 2.75 11,315 11,315 PROD3 DRILL WPRT P Wiper trip-P/U weight 32K.Wipe up to 9143'Had to work through Shale section(last 200')to get back to bottom. 19:30 21:30 2.00 11,315 11,437 PROD3 DRILL DRLG P Drilling ahead-1.35 bpm,4000 psi, BHP 4140psi, ECD 12.2, ROP 90, WOB 1.3, Ct weight 3K. 21:30 23:00 1.50 11,437 11,437 PROD3 DRILL CIRC T Indication of stacking-went to P/U 40K and are differentially stuck. Good returns, pump B/U and then sit pumps down for 10 minutes(BHP 3900-WHP 550).CT popped free on 6th attempt @ 55 fpm pulled 58K on CT string. 23:00 00:00 1.00 11,437 9,300 PROD3 DRILL WPRT P Wiper trip&pulled heavy @ 11,110', worked free continue with wiper trip. BHI counter stopped working during wiper-fix&tie in at window. . 07/02/2010 Drilled to TD of 11605'. Pumped sweeps,laid in liner running pill and KWF. P/U liner assembly.Total losses 96 bbls. 00:00 02:30 2.50 9,300 11,437 PROD3 DRILL WPRT P Continue with Wiper trip-Tie in due to BHI counter slippage(fixed). RIH- have to work CT to botttom from 11030'to TD by cycling pumps and speed. P/U weight clean 29K. 02:30 07:24 4.90 11,437 11,512 PROD3 DRILL DRLG P On bottom drilling-1.35 bpm,3800 psi, BHP 4140, ECD 12,WOB 2.2K, CT weight-2K, ROP 60. Drill ahead. Found ankerite at 11450' -ROP 8 fph. Broke thru at 11468. DPS sensor began malfunctioning while drilling ankerite,perhaps due to agitator. Internal P and WOB sensors off scale. Page 16 of 33 Time'Logs Date From To Dur S.Depth E. Depth Phase Code Subcode T Comment 07:24 09:54 2.50 11,512 9,150 PROD3 DRILL WPRT T Wiper to 9150'to check hole conditions around shaley section and to decide plan forward. PU=32k. Had a 3k overpull(surface weight)at 11,305',and 8-10k overpulls at 11256', 11232', 11222',and 11210'. The overpull at 11222'also gave a motor stall, possibly trying pack off. No problems remainder of trip. 09:54 10:12 0.30 9,150 11,512 PROD3 DRILL WPRT T Wiper back in to 10900'. Drop rate to 0.5 bpm to work thru shaley section. Saw several bobbles between 11140-11310 but no setdowns. Increase rate, RIH to TD. 10:12 12:24 2.20 11,512 11,605 PROD3 DRILL DRLG P Back on bottom drilling. Circ 5 bbl to-vis/5 bbl hi-vis sweep. 1.33 bpm,3950 psi, BHP 4200, ECD 12.25,CT weight-3K. WOB sensor is toast. 12:24 14:30 2.10 11,605 11,605 PROD3 DRILL CIRC P TD hole at 11605'. PU=32k. Circulate 10 bbl lo-vis/10 bbl hi-vis sweep bottoms up while slowly working pipe to/from 11470'. No shale chunks in returns,only fines and'clay balls'. After sweep displaced,pumped beaded liner pill down coil. 14:30 15:30 1.00 11,605 8,850 PROD3 DRILL DISP P POH laying in liner pill,40 fpm at 0.4 bpm. 15:30 15:45 0.25 8,850 8,870 PROD3 DRILL DLOG P Tie into RA marker,+3'correction. 15:45 18:00 2.25 8,870 0 PROD3 DRILL DISP P POH laying in 11.5 ppg NaBr KWF, 60 fpm at 0.6 bpm. 18:00 19:00 1.00 0 0 PROD3 DRILL SFTY P CT @ surface, KWF to surface.Stop and perform no-flo check and safety meeting with crew change out. 19:00 20:30 1.50 0 0 PROD3 DRILL PULD P Lay down drilling BHA and Agitator 20:30 21:30 1.00 0 0 COMPZ CASING SFTY P Prep the floor and prepare to P/U liner. Safety joint drill. 21:30 00:00 2.50 0 0 COMPZ CASING PUTB P Start P/U liner.Total 43 joints. 07/03/2010 RIH with liner, unable to get past 10280'. POH, reconfigure shoe, rerun liner with no luck. POOH for FCO BHA. 00:00 01:00 1.00 1,438 1,438 COMPZ CASING PUTB P Finish making up BHI tools and prepare to RIH with CT 01:00 03:00 2.00 1,438 8,737 COMPZ CASING RUNL P RIH with EDC closed pumping.3 bpm.Stop pumping @ 6000' 03:00 04:30 1.50 8,737 10,280 COMPZ CASING RUNL P Stop @ flag-correct-5 ft Weight check in cased hole 31K-continue RIH.Tag up @ 10280'-P/U weight 39K.tried 12 times slower speed. P/U 100 ft and try again.Tried 10 more times no luck. 04:30 07:18 2.80 10,280 0 COMPZ CASING RUNL T POOH to change BHA configuration. Lost only 9 bbl of KWF during round trip. Page 17 of 33 Time Logs Date .< '(From -To Dur S. Depth E.Depth Phase Code Subcode T Comment 07:18 08:00 0.70 0 0 COMPZ CASING PULD T PJSM. Lay down CoilTrak BHA. 08:00 10:30 2.50 0 0 COMPZ CASING PULL T Lay down liner assembly(avg.5 jnts per 12 minutes). Hole standing full. Unique shoe was packed full of clay and beads-unable to rotate. Nose on the Unique shoe was also just hand-tight. 10:30 14:00 3.50 0 0 COMPZ CASING PUTB T Reconfigure shoe with Unique indexing shoe,2'pup, 1.5-deg bent sub,and R&R Indexing tool. Lift is equivalent to a 1.8-deg drilling BHA. PU 43 jnts slotted liner. 14:00 15:00 1.00 0 0 COMPZ CASING PULD T Install torq-thru deployment sleeve and torq-thru GS. PU Coiltrak BHA with HOT. 15:00 17:18 2.30 0 8,820 COMPZ CASING TRIP T RIH with segment#1 of 2-3/8"liner assembly. 17:18 18:00 0.70 8,820 10,280 COMPZ CASING TRIP T Tie into pipe flag. PU=28k. Run past window into open hole. 18:00 20:00 2.00 10,280 10,280 COMPZ CASING TRIP T Tagged up @ 10280'cycle R&R indexing tool 12 times to try to roll through trouble spot.No luck P/U. Start Orientating around the world in 30 degree increments. No luck.Sat down and tried to roll in with no luck also. 20:00 22:00 2.00 10,280 1,457 COMPZ CASING TRIP T POOH for clean out assembly pumping KWF.4 bpm. 22:00 00:00 2.00 1,457 1,457 COMPZ CASING PULD T Ct @ surface,flow-check&lay down BHA&set up rig floor for pipe handling. 07/04/2010 Lay down Liner assembly, P/U D-331 FCO BHA. Drifted through trouble spot no problem. Had difficulty working down through shales starting @ 11,000'.worked down to TD,condition hole for Liner run. P/U liner assembly. 00:00 03:00 3.00 1,457 0 COMPZ CASING PULL T Laying down liner assembly.Bottom of the guide shoe was loose again, but otherwise shoe assembly was clear and free to rotate/index. 03:00 04:00 1.00 0 62 COMPZ CASING PULD T P/U Milling/FCO BHA with 1.1 AKO 04:00 05:30 1.50 62 8,820 COMPZ CASING TRIP T RIH-shale and clay balls coming over shakers while RIH. 05:30 05:42 0.20 8,820 8,820 COMPZ CASING DLOG T Tie-in. +4'correction. 05:42 07:00 1.30 8,820 8,820 COMPZ CASING DISP T Displace out 11.5 ppg KWF with 10 bbl hi-vis spacer and 9.4 ppg Powervis mud at 1.0 bpm. Good recovery: lost total of 42 bbl KWF after two attempts to run liner. Page 18 of 33 Time'Logs_ Date_ From To Dur S.Depth E.Death Phase Code Subcode T Comment 07:00 09:12 2.20 8,820 10,310 COMPZ CASING REAM T RIH for fill clean out. At 10280'orient to 90L and RIH at 35 fpm. Pass by ledge with only a slight bobble. RIH to 10300'. Back ream 90L to 10250 at 10 fpm. Repeat 2X with same results. RIH to 10310,orient to 70L and backream at 10 fpm. Downream at 20 fpm at 70L and again don't really see much either. Repeat passes at 70L. At 10310,orient to 50L and backream at 10 fpm. Downream at 20 fpm at 50L and no problem passing ledge. Repeat 50L pass. At 10310,orient to 110L and backream at 10 fpm. Downream at 20 fpm at 110L and still no problem. Repeat pass at 110L. 09:12 10:18 1.10 10,310 11,250 COMPZ CASING FCO T Continue in hole. Lot of difficulty getting past shales at 11130-11250'. Having to cycle pumps to get thru several tight spots. Unable to pass 11250,45k overpull getting back out. 10:18 13:12 2.90 11,250 11,000 COMPZ CASING WPRT T POH to 11100'. Circ 10 bbl lo-vis& 10-bbl hi-vis pill. Chase out of hole to 9150'. Run back in hole to 11000'. 13:12 13:48 0.60 11,000 11,605 COMPZ CASING WPRT T Cut rate to 0.5 bpm to try to work past shales. Get past without any setdowns. Beyond worst shales tried to increase rate to 1.3 bpm but start having setdowns,so keep rate at 0.5 bpm until TD. 13:48 15:30 1.70 11,605 8,820 COMPZ CASING DISP T Circulate bead pill. Begin POOH laying in liner pill from TD. 15:30 19:00 3.50 8,820 63 COMPZ CASING TRIP T POH laying in 11.5 ppg KWF. 19:00 20:30 1.50 63 0 COMPZ CASING PULD T Flo-check,lay down BHA. 20:30 21:30 1.00 0 0 COMPZ CASING CIRC T Move injector over WH,close swabs and circulate new KWM mud through CT string. 21:30 00:00 2.50 0 COMPZ CASING PUTB T Start P/U liner with 1.5 bent sub and bull nose guide. 07/05/2010 RIH with liner assembly to TD. PU and RIH with 2nd liner segment. Liner Set from 11605'-8822'. P/U WS assembly.Set Top of whipstock @ 8800.5'. 00:00 00:30 0.50 1,450 1,450 COMPZ CASING PUTB T Continue to P/U and scribe liner assembly. 00:30 03:30 3.00 1,450 11,605 COMPZ CASING RUNL T RIH with CT pumping 0.3 bpm through GS.Weight check above window 27K,Stop pumping-RIH. Small weight bobble @ 10,280', 10436'. made it to bottom no problems. Page 19 of 33 Time Logs Date From To Dur S. Depth E.Depth Phase Code Subcode T Comment 03:30 04:30 1.00 11,605 8,800 COMPZ CASING TRIP P p/U weight 38K,Set back down, bring pump up to 1.2 bpm, disconnect off liner-P/U weight 26K. come up 20 ft and set up to pump down backside while POOH to window. Liner segment#1 set 10209'- 11605'. 04:30 07:18 2.80 8,800 0 COMPZ CASING TRIP P POOH Pumping 11.5 ppg KWF down the CT. NOTE:Inteq counter slipped-400' while POOH. Counter wheel showed _ _ wear-replaced. 07:18 08:18 1.00 0 0 COMPZ CASING PULD P LD BHA. 08:18 11:30 3.20 0 0 COMPZ CASING PUTB P PJSM. PU liner segment#2- indexing shoe,34 jnts slotted,9 jnts solid,4'pup,shorty deployment sleeve. 11:30 11:54 0.40 0 0 COMPZ CASING PULD P MU BHA#17 onto liner. 11:54 14:54 3.00 0 8,820 COMPZ CASING RUNL P RIH with liner segment#2. Bobble at 9060'but otherwise run to bottom without trouble. 14:54 15:06 0.20 8,820 8,820 COMPZ CASING TRIP P Circulate to release liner. Liner segment#2 set 8814'-10209'. POH. 15:06 15:12 0.10 8,820 8,350 COMPZ CASING DLOG P Tie into K1 marker,+8'correction. Top of liner(corrected)=8822'. 15:12 17:18 2.10 8,350 0 COMPZ CASING TRIP P POH. 17:18 17:48 0.50 0 0 COMPZ CASING PULD P PJSM, LD BHA#17. 17:48 19:30 1.70 0 71 PROD4 RPEQP1PULD P PU whipstock BHA#18 19:30 22:00 2.50 71 8,800 PROD4 RPEQP1TRIP P Open EDC-RIH slowly the first 300 ft,Start pumping. 3bpm, RIH 60 fpm.Tie in @ 8350.Corection+8ft. Weight check-27K. RIH to 8815' P/U to 8810'26K, HS orientation. IA -300 OA"0" 22:00 22:30 0.50 8,800 8,800 PROD4 RPEQP1WPST P Close EDC-Bring pumps up to 1 bpm,3600 psi,Setting tool pressure drop to 1500 psi. Set down 3K WOB.Top of WS set @ 8800.55'- Good set 22:30 00:00 1.50 8,800 83 PROD4 RPEQP1TRIP P POOH laying in KWF. 07/06/2010 Mill 3.5"window exit from 8802.0 to 8808.0. POOH, Perform BOPE Function test, RIH with 7"exit BHA,Tag @ 8807.2 _ 00:00 01:00 1.00 83 0 PROD4 RPEQP1PULD P Ct @ surface-flow check well. Lay down WS BHA. 01:00 01:30 0.50 0 73 PROD4 WHPST PULD P P/U Milling BHA.Open EDC. 01:30 03:30 2.00 73 8,780 PROD4 WHPST TRIP P RIH pumping.3 bpm.Tie in correction+8 ft. 03:30 04:30 1.00 8,780 8,802 PROD4 WHPST CIRC P Circulate B/U to recover KWM. 04:30 05:00 0.50 8,802 8,802 PROD4 WHPST MILL P Stop pumping,Close EDC. Dry tag TOWS @ 8802.2', P/U start pumping 1.45 bpm,3600 psi free spin. Page 20 of 33 KU P 1 R-06AL1-01 C l i I ` Well Attributes Max Angle&MD TO ps { 1 Wellbore APWWI Field Name IWell Status Inc'P) IMO(ftKB) ActBtm(HKB) - 1arincai'F1ivs f 500292133163 JKUPARUK RIVER UNIT INN Comment H2S(ppm) Date Annotation End Date I KB•Grd(6) Rig RaMase Date "' SSSV:TRDP Last WO: 1 -37.61 5/15/1985 WaI ci9gt „t-0 J/2 .1243:31 PM Shcernayc;Actual Annotation 'Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: Rev Reason.SIDETRACKS,GLV C/O Imosbor 7/21/2010 WINGER,33 ._ r ' -' Casing Strings Casing Description IStr g 0... String ID...Top(HKB) Set Depth(1...Set Depth(TVD)...String Wt...I String..String Top Thnl ' '` i ALl-01 LINER I 2.3/8 1.995 8815.4 11,605.0 443 j L-80 STL Liner D�tts CONDUCTOR, I Top Depth 38-110 (TVD) Top Intl Nomi... ill , Top(811(B) (11KB) (°) Item Description Comment ID(in) 8,815.4 DEPLOY SHORTY DEPLOYMENT SLEEVE 1.000 SAFETY VLV, 1,908 pink 10,210.0 DEPLOY TORQUE-THRU DEPLOYMENT SLEEVE 1.000 i . [ GAS LIFT, 2,041 - Perforations$Slots . may! Shot GAS LIFT, � Top(TVD) Ben(TVD) Dens 4,326 " Top(1tKB) Ben(61KB) (1KB) (HKB) Zone Date (oh... Type Comment 9,100 10,209 7/5/2010 32.0 SLOT Alternating solid/slotted pipe- SURFACE, •� 0.125"x2.5"@ 4 circumferential 3744,659 adjacent rows,3"centers staggered GAS LIFT, 18 deg,3'non-slotted ends 5,631 GAS LIFT, 10,211 11,602 7/5/2010 32.0 SLOT Alternating solid/slotted pipe- 6,285 - ` 0.125"x2.5"C 4 circumferential adjacent rows,3"centers staggered GAS LIFT, 6,762 to-�,,, 18 deg,3'non-slotted ends GAS LIFT, Notes:General&Safety 7,198 End Date Annotation GAS LIFT, - - I:. 7/19/2010 NOTE:WELL IS INJEC FOR II IA WILL BE PRE-PRODUCED 7,615 GAS LIFT, - , 7/21/2010 NOTE:View Schematicw/Alaska Schematie9.0 8,061 GAS LIFT, 8,381 PBR,8,421-- --- PACKER,8,435- - GAS LIFT, 8,473 illti'r." GAS LIFT, 8,545 - F v'S`y9 Iii WHIPSTOCK, . 8,819 WINDOW•A•, 8,820-8,832 is GAS,LIFT .. MMG,8,690 ii_ aLOCATOR, PACKER,8,909 SBE,8,913- -- ..-. 11 15- I.: CIBP,8,921 --- _ 1p NIPPLE,8,924 ypp i.! k SOS.8,931-- a FISH,9,145 -- -`EC 1 Mandrel Details_ Top Depth Top ..,,,.. _.._ Port (TVD) Intl OD Valve Latch Size TRO Run PRODUCTION, _... 1 1_; Stn Top(HKB) (HKB) C) Make Model (in) Sery Type Type (in) (psi) Run Date Can... 35-9,279 -- 1 2040.8 CAMCO KBUG 1 GAS LIFT GLV BK 0.125 1,317.0 7212010 SLOT, 9,100-10,209N 2 4,326.0 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,333.0 7/21/2010 SLOT, s 1 9,471-10,244 ( _ 3 5,630.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 4 6,285.1 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,319.0 7212010 5 6,762.2 CAMCO KBUG--- 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 A LINER, 6 7,198.2 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 6/30/1985 9.460-16.245 7 7,615.3 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,342.0 7/21/2010 SLOT, 10211-11,602 8 8,060.9 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 11/10/1987 TO (1R-06Q1-01), 9 8,381.1 CAMCO KBUG 1 12 PROD OV rdo20 0.188 0.0 7212010 10,940 10 8,473.5 CAMCO MMG-2 1 12 PROD OPEN 0.000 0.0 11/21/1993 AL1-01 LINER, ----- 8,815-11,605 KU P 1 R-06AL1-01 CanatcPhiiiips Alaska. . _... KB-Grd(k) Rig Release Date W000-!L9..18,441'i,1G1lZ11p124539 PM-_ -, 37.61 S17S/1985 SCIMatk_Actual. .-._...___ I `� I HANGER,33 A r CONDUCTOR, 38-110 SAFEfY1.908 GAS LIFT, 1;I, . 2,041 GAS LIFT, ' g. 4,326 SURFACE, 37-4,659 GAS LIFT, 5,631 i. GAS LIFT, �tle's<,, 6,285 +*i pi iv GAS LIFT, 6,762 _- `' GAS LIFT, h 7,198 Itt- IS GAS LIFT, 7,615 GAS LIFT, 8,061 .-. MI GAS LIFT, 8,381 t PAR,8,421 PACKER,8,435- GAS LIFT, � ... 8,473 GAS LIFT, OE 8,54.5 I` INF I I, 1. 1 WHIPSTOCK, 8,819 WINDOW'A', 8,820-8,832 y A GAS LIFT _. MMG,6,890 III LOCATOR, 8,908 id imittdi PACKER,8,909 SEE,8,913 -- It CIBP,8,921 �a C:_. NIPPLE,8,924 - )y{ iti• SOS,8,931 -- ; '- 1 FISH,9,145 -.C.2 I Mandrel Details .� 5 w ide >R1?r„13 A,tli44„ Top Depth Top Port (TVD) Inc) OD Valve Latch Size TRO Run PRODUCTION, _ 1 I Stn Top MKS) MKS) (1 Make Mcdel (in) Sere Type Typo (in) (Psi) Run Date Con... 35-9,279 11 8,544.5 CAMCO MMG-2 1 112 PROD DMY RK 0.000 0.0 5/21/2010 SLOT, 9,100-14209 - 12 8,890.3 CAMCO MMG-2 1 1/2 PROD OPEN 0.000 0.0 5/21/2010 SLOT, 9,471-10,244 ... 'A'LINER, 9,460-10,245 SLOT, 10,211-11,602 TD (1R.O6AL1-01), - 10,940 AL1-01 LINER, 8,815-11,605 N .g N YYJ - ^ O 0 �mp.1..": C O t0 N-' .- Nm ...Z N b O o�1 p� Oo ^^N O A z. r ' 0 h m C C O 0 0 G O N N O p Q o m N ` g m O'N m r c m m b-_ 0 a m N 3 S j m a " -O Na aDN to W o Lal j C 3 C N M `,M C y ' M C N M a r=_ O Q N Q N C J Q N- Q N -. o n aNm m J • , .‘\•..,.•,,...,.,t,It'..,',.....11\‘s.‘:::::::::::\ rn o N co N N Q m 0 g R a' o o 0 v C c m N °arn 'f c a O r- . 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M V D CD O 7 Y Q Q O r r C e O V O O O N m O I. O O N O Ni N O O - —. m O m 0 m CG 0 CO r n r- O O m m O 00 O O n f` • a NI CD M CD O 0 O ct et N O CD O M M N 0 N O Q N M .- M .- M M C) N M O V O V O V V M N V 0 O Y O Y) 6 6 O O O CO O y O y O O 0 6 0 0 0 Y C C m V 0 0 C >. Q co sr h O M CO O N O o V N- M CD O N O CO O O O O O N N N M M M V v v O O O (O 0 E o m m m > a U c.) o. co 0 to 1\if e a SEAN PARNELL,GOVERNOR 0 ALASKA. OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSION ANCHORAGE,ALASKA 99501-3539 PHONE (907)279-1433 FAX (907)276-7542 V. Cawvey Alaska Wells Manager ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1R-06AL1-01 ConocoPhillips Alaska, Inc. Permit No: 210-083 Surface Location: 272' FNL, 222' FEL, Sec. 19, T12N, R10E, UM Bottomhole Location: 450'FNL, 2365' FWL, Sec. 30, 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. Sincerely, )2), Daniel T. Seamount, Jr. Chair DATED this 2's day of June, 2010. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 June 23, 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 a permit to drill application for an additional lateral out of Kuparuk Well 1R-06 (PTD# 185-071) using the coiled tubing drilling rig, Nabors CDR2-AC. Permits for four Kuparuk A- sand laterals/sidetracks have previously been approved: 1 R-06A (210-056), 1 R-06AL1 (210-057), 1 R-06AL2 (210-058), and 1 R-06AL2-01 (210-059). Complex geology plus operational difficulties have made it necessary to add the 1R-06AL1-01 lateral to achieve the same formation objectives as the original AL1 lateral proposal. This additional AL1-01 lateral will not affect the quarter-mile review that was previously submitted. Attached to this application are the following documents that explain the proposed job operations: — Permit to Drill Application Forms for 1 R-06A, 1 R-06AL1, 1 R-06AL2, 1 R-06AL2-01 — Proposed Wellbore Schematic(updated) — Detailed Summary of Operations (updated) — Directional Plans Proposed operations for the new 1 R-06AL1-01 lateral are shown in blue in the enclosed wellbore schematic and summary of operations. If you have any questions or require additional information please contact me at my office 907-263-4172. cerely, Gary ler ConocoPhi ' Alaska Coiled Tubing Drilling Engineer STATE OF ALASKA FCFJVED ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL ..ii w ;' `, 610 20 AAC 25.005 �p $$IOD �ssle Ad Et pr C - 1 a.Type of Work: 1 b.Proposed Well Class: Development-Oil ❑ Service-Winj 0 . Single Zone c.Specify' we�II its pr ..sed for. Drill Re-drill El Strati ra hic Test Development-Gas lft LJ i�' ❑ ❑ g p ❑ p ❑ 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 • 1 R-O6AL1-01 ' 3.Address: 6.Proposed Depth: 12.Field/Pool(s): P.O. Box 100360 Anchorage,AK 99510-0360 MD: 11650' ' ND: 6551' 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 25635,25640 Kuparuk River Oil Pool • Top of Productive Horizon: 8.Land Use Permit: 13.Approximate Spud Date: 1031'FSL, 1073'FWL,Sec. 19,T12N,R10E,UM 2568,2571 6/27/2010 Total Depth: 9.Acres in Property: 14.Distance to 450'FNL,2365'FWL,Sec.30,T12N,R10E,UM 2560 Nearest Property: 18550' - 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: 1G-08,870' 16.Deviated wells: Kickoff depth: 10300 •ft. 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 102° deg Downhole:3115 psig . Surface:2545 psig■ 18.Casing Procram: Specifications Top - Setting Depth -Bottom Cement Quantity,c.f.or sacks Hole Casing Weight Grade Coupling Length MD 1VD MD - TVD (including stage data) 3" 2.375" 4.7# L-80 ST-L 2836' 8814' 6483' 11650' 6551' 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 TVD(ft): Junk(measured) 9303' 6998' 9188' 6890' 9145' Casing Length Size Cement Volume MD ND 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 ND(ft): 8582'-8588',8692'-8742',8860'-8867',8976'-8984',8994'-9024',9028'-9038' 6379'-6383',6465'-6505',6801'-6607',6700'-6707',6715'-6741',6745'-6754' 20.Attachments: Property Plat❑ BOP Sketch is Drilling Program 0 Time v.Depth Plot ❑ Shallow Hazard Analysis ❑ Diverter Sketch❑ Seabed Report ❑ Drilling Fluid Program Q 20 AAC 25.050 requirements El 21.Verbal Approval: Commission Representative: Date: cL Q`Z4'\U 22. I hereby certify that the foregoing is true and correct. Contact J. G. r @ 263-4172 Printed Name V. Cawvey Title Alaska Wells Manager Si nature �"' � n /_Phon Date 24/76 Commission Use Only Permit to Drill _ API Number: t / Permit Appr val See cover letter Number. 1/6' o��� 50- C\1-7_C,-1- 1( 3 1 - k (_-c Date: a in for other requirements Conditions of approval: If box is checked,well may not be used to explore for,test,or produce coalbed meth ne,gas hydrates,or gas contained in shales: 2' 'CSC) \ h�r- c Samples req'd: Yes ❑ t o Mud log req'd: Yes ❑ No 2' Other: aSCIC�?S", ,�,,,�\mac StgA `v..t`, H2S measures: Yes Q/No ❑ D' ctional svy req'd: Yes [r No ❑ _v\Ne .o �,,A‘©NI--,•>\4\c).ck w q‘00 aiS cT c`c s \ APPROVED BY THE COMMISSION ^ u DATE: ,COMMISSIONER Form 10-401 ( d 7/2009) This permit is valid for r t a a roval(20 AAC 25.005(9)) Submit in Duplieat (..z ic. KRU 1R-06A, AL1, AL1-01, AL2, AL2-01 — Coiled Tubing Drilling Summary of Operations: Well 1R-06 is a Kuparuk A-sand and C-sand injection well equipped with 3'/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 1R-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 3'/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 23/" 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 a liner top aluminum billet at 10,300' MD. • The 1 R-06AL1-01 lateral will kick off from the aluminum billet at 10,300' MD and will target the A4 sand south of the existing well with a 1350' lateral. The hole will be completed with a 2%" slotted liner to the TD of 'f` • 11,650' MD with the final liner top located just inside the 3'/2"tubing at 8814' MD. The 1 R-06AL2 lateral will make another 2-string exit through the 3'/2"tubing and 7"casing at 8791' MD via a second mechanical whipstock placed in the 3'/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-06AL2-01 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 3'h"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 3'/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 3'/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 May 5,2010, FINAL OR I G 1 N A L Updated June 23,2010 KRU 1R-06A, AL1, AL1-01, 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. Set 31/2"monobore whipstock in 3'/2"tubing at 8819' MD with high-side orientation. b. Mill 2.80"2-string window with high-side orientation at 8819' MD. c. Drill 2.70"x 3"bi-center lateral to TD of 11,700' MD. d. Run 23/8"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 with an aluminum liner-top billet from TD up to 10,300' 4. 1 R-06AL 1-01 Lateral (A4 sand, south) - a. Kick off of the aluminum billet at 10,300' MD • b. Drill 2.70"x 3"bi-center lateral to TD of 11,650' MD. ' c. Run 2%"slotted liner from TD up to 8814' MD, up inside the 7"casing 5. 1R-06AL2 Lateral(A3 sand,north) a. Set 31/2"monobore whipstock in 31/2"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' 6. 1R-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'/2"tubing 7. Freeze protect. ND BOPE. RDMO Nabors CRD2-AC. 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 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 10,300' MD to 11,600' MD —* • 1R-06AL1-01: 2%",4.7#,L-80, ST-L slotted/solid liner from 8814' MD to 11,650' MD • 4- • 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 Page 3 of 5 May 5,2010, FINAL ORIGINAL Updated June 23,2010 KRU 1R-06A, AL1, AL1-01, AL2, AL2-01 — Coiled Tubing Drilling Existing Casing/Liner Information 5 Surface: 9/8 , J-55, 36 ppf Burst 3520 psi; Collapse 2020 psi Production: 7",J-55,26 ppf Burst 4980 psi; Collapse 4320 psi 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. 1 R-06AL 1,plan#3 --V 3. 1R-06AL1-01, plan#1 • 4. 1R-06AL2,plan#2 5. 1 R-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,&AL1-01): 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 H2S,both being measured on 8/6/09. The maximum H2S level on the pad is 150 ppm from • well 1R-20(8/15/05). All H25 monitoring equipment will be operational. • III Page 4 of 5 May 5,2010, FINAL Updated June 23,2010 ORIGINAL KRU 1R-06A, AL1, AL1-01, 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 re g g 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 3'/2"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 p p g p ressure will be increased to maintain overbalan ce. Additional choke pressure or increased mud weight t 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,AL1 &AL1-01): • 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 1R-06AL1. 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 May 5, 2010, FINAL Updated June 23,2010 • . \ ] 3 0 { _ k i ii § \. � \ <` ee=\ <°_ r\D < , lii 0 , ", ', ', ', il 1:: \\:\'''lcill.',,,, , } \ \\ ! « & © ! \ ik \} ) \ ` 7 Ca / E:_®_ _;! / k Bo 2 / • \2 r a! «$� \ (\ j }\\ // ) �, !\) \ MW! th | %� )/\ « o olo®co co \ /�( P 1 #k ® 2 A ....? # ,..w,-- •D , _ / , . . 1 --- ' — \ _ In v / • 1 : \ ^k — = a 1J 2 . . _ CI T 1 II-- .. U NI 1 _ CD \ ; • « } » CL 9 !2 2 , \ ; { \ k ( /;cr co co N til \ ` �� _� a )) f �)�� -- ° ���° ) re 0 § _ _ _ *B@g T. § ¥ 6@ee . 2 k R | G | N A L - - ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1R Pad 1R-06 1 R-06AL1-01 Plan: 1R-06AL1-01 wp01 Standard Planning Report 23 June, 2010 r' I BAKER HUGHES ORIGINAL .T . ConocoPhillips Veal 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 Wellbore: 1 R-06AL1-01 Design: 1 R-06AL1-01_wp01 Project Kuparuk River Unit Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 1R Pad ' Site Position: Northing: 5,991,050.01 ft • Latitude: 70°23'11.370 N From: Map Easting: 539,829.93ft Longitude: 149°40'33.803 W Position Uncertainty: 0.00 ft Slot Radius: " Grid Convergence: 0.31 ° Well 1 R-06 Well Position +NI-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: 0.00 ft 1 Wellbore 1R-06AL1-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2009 7/1/2010 17.20 79.85 57,390 - --------- Design 1R-06AL1-01_wp01 Audit Notes: Version: Phase: PLAN Tie On Depth: 10,300.00 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) r) 1 0.00 0.00 0.00 100.00 Plan Sections Measured TVD Below Dogleg Build Turn Depth Inclination Azimuth System +N/S +E/-W Rate Rate Rate TFO (ft) r) r) (ft) (ft) (ft) (°/100ft) (1100ft) (°/100ft) (0) Target 10,300.00 89.20 100.71 6,591.41 -5,156.89 -3,501.65 0.00 0.00 0.00 0.00 10,345.00 95.95 100.71 6,589.39 -5,165.25 -3,457.50 15.00 15.00 0.00 0.00 10,375.00 99.84 98.43 6,585.27 -5,170.19 -3,428.21 15.00 12.97 -7.61 330.00 10,405.00 102.07 94.45 6,579.57 -5,173.50 -3,398.95 15.00 7.42 -13.28 300.00 10,545.00 91.14 76.36 6,563.36 -5,162.18 -3,261.14 15.00 -7.80 -12.92 240.00 10,795.00 91.51 113.87 6,557.35 -5,184.08 -3,016.63 15.00 0.15 15.00 89.00 10,970.00 93.13 87.65 6,550.14 -5,216.46 -2,846.36 15.00 0.92 -14.98 274.00 11,300.00 88.99 137.00 6,543.62 -5,338.01 -2,550.60 15.00 -1.25 14.95 94.00 11,650.00 88.59 84.49 6,551.54 -5,457.65 -2,234.70 15.00 -0.11 -15.00 269.00 6/23/2010 10:15:03AM Page 2 COMPASS 2003.16 Build 69 ORIGINAL -10-- ConocoPhillips la.. 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: 1R-06 Survey Calculation Method: Minimum Curvature Wellbore: 1 R-06AL1-01 Design: 1 R-06AL1-01_wp01 Planned Survey i I i Measured ND Below Vertical Dogleg Toolface Map Map Depth Inclination Azimuth System +N/-S +E/-W Section Rate Azimuth Northing Easting (ft) (°l (°) (ft) (ft) (ft) (ft) (°100ft) (°) (n) (ft) 10,300.00 89.20 100.71 6,591.41 -5,156.89 -3,501.65 -2,552.97 0.00 0.00 5,985,755.42 535,995.70 TIP/KOP 1R-06AL1_wp06 10,345.00 95.95 100.71 6,589.39 -5,165.25 -3,457.50 -2,508.04 15.00 0.00 5,985,747.30 536,039.88 2 10,375.00 99.84 98.43 6,585.27 -5,170.19 -3,428.21 -2,478.33 15.00 -30.00 5,985,742.51 536,069.2011 3 10,400.00 101.70 95.12 6,580.60 -5,173.09 -3,403.83 -2,453.82 15.00 -60.00 5,985,739.74 536,093.59 10,405.00 102.07 94.45 6,579.57 -5,173.50 -3,398.95 -2,448.94 15.00 -60.62 5,985,739.36 536,098.47 4 10,500.00 94.72 82.10 6,565.66 -5,170.58 -3,305.27 -2,357.19 15.00 -120.00 5,985,742.77 536,192.13 1 10,545.00 91.14 76.36 6,563.36 -5,162.18 -3,261.14 -2,315.20 15.00 -121.81 5,985,751.40 536,236.20 5 10,600.00 91.27 84.62 6,562.20 -5,153.10 -3,206.96 -2,263.41 15.00 89.00 5,985,760.76 536,290.33 10,700.00 91.44 99.62 6,559.81 -5,156.78 -3,107.34 -2,164.67 15.00 89.17 5,985,757.61 536,389.96' 10,795.00 91.51 113.87 6,557.35 -5,184.08 -3,016.63 -2,070.60 15.00 89.53 5,985,730.80 536,480.80 6 10,800.00 91.57 113.12 6,557.21 -5,186.07 -3,012.05 -2,065.74 15.00 -86.00 5,985,728.83 536,485.40 10,900.00 92.54 98.15 6,553.61 -5,212.93 -2,916.09 -1,966.57 15.00 -86.02 5,985,702.48 536,581.49 10,970.00 93.13 87.65 6,550.14 -5,216.46 -2,846.36 -1,897.29 15.00 -86.56 5,985,699.31 536,651.22 7 11,000.00 92.80 92.14 6,548.58 -5,216.41 -2,816.41 -1,867.80 15.00 94.00 5,985,699.53 536,681.17 11,100.00 91.61 107.11 6,544.71 -5,233.07 -2,718.17 -1,768.17 15.00 94.23 5,985,683.38 536,779.49 11,200.00 90.32 122.05 6,543.01 -5,274.55 -2,627.51 -1,671.68 15.00 94.81 5,985,642.39 536,870.36 11,300.00 88.99 137.00 6,543.62 -5,338.01 -2,550.60 -1,584.91 15.00 95.07 5,985,579.34 536,947.60 8 11,400.00 88.77 122.00 6,545.58 -5,401.42 -2,473.67 -1,498.14 15.00 -91.00 5,985,516.34 537,024.85 11,500.00 88.63 106.99 6,547.86 -5,442.75 -2,382.95 -1,401.62 15.00 -90.71 5,985,475.50 537,115.78 11,600.00 88.58 91.99 6,550.31 -5,459.19 -2,284.63 -1,301.94 15.00 -90.36 5,985,459.58 537,214.17 11,650.00 88.59 84.49 6,551.54 -5,457.65 -2,234.70 -1,253.04 15.00 -90.00 5,985,461.38 537,264.09 TD at 11650.00 6/23/2010 10:15:03AM 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 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-06AL1-01 Design: 1 R-06AL1-01_wp01 Targets -_-- - Target Name -hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting -Shape r) r) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 1R-06AL1 t4(copy) 0.00 0.00 6,578.00 -5,174.94 -3,133.99 5,985,739.31 536,363.41 70°22'19.309 N 149°42'16.055 W -plan misses target center by 27.87ft at 10673.53ft MD(6560.47 TVD,-5153.27 N,-3133.56 E) -Point 1R-06 A,AL1 HARDL 0.00 0.00 0.00 -3,977.78 -3,520.71 5,986,934.29 535,970.41 70°22'31.081 N 149°42'27.385 W -plan misses target center by 6674.00ft at 10600.00ft MD(6562.20 TVD,-5153.10 N,-3206.96 E) -Polygon Point 1 0.00 -3,977.78 -3,520.71 5,986,934.29 535,970.41 Point 2 0.00 -4,414.15 -3,650.00 5,986,497.29 535,843.44 Point 3 0.00 -4,922.30 -3,633.66 5,985,989.28 535,862.46 Point 4 0.00 -4,414.15 -3,650.00 5,986,497.29 535,843.44 1R-06AL1 t1 (copy) 0.00 0.00 6,616.00 -4,537.48 -3,775.70 5,986,373.31 535,718.41 70°22'25.575 N 149°42'34.838 W' -plan misses target center by 677.78ft at 10300.00ft MD(6591.41 TVD,-5156.89 N,-3501.65 E) -Point 1R-06A,AL1 Fault 1 ( 0.00 0.00 0.00 -4,604.43 -3,409.01 5,986,308.31 536,085.41 70°22'24.919 N 149°42'24.108 W -plan misses target center by 6588.19ft at 10600.00ft MD(6562.20 TVD,-5153.10 N,-3206.96 E) -Polygon Point 1 0.00 -4,604.43 -3,409.01 5,986,308.31 536,085.41 Point 2 0.00 -5,021.03 -3,685.22 5,985,890.30 535,811.43 Point 3 0.00 -5,342.59 -3,967.93 5,985,567.28 535,530.45 Point 4 0.00 -5,021.03 -3,685.22 5,985,890.30 535,811.43 1R-06 A,AL1 Polygor 0.00 0.00 0.00 -3,977.78 -3,520.71 5,986,934.29 535,970.41 70°22'31.081 N 149°42'27.385 W -plan misses target center by 6674.00ft at 10600.00ft MD(6562.20 TVD,-5153.10 N,-3206.96 E) -Polygon Point 1 0.00 -3,977.78 -3,520.71 5,986,934.29 535,970.41 Point 2 0.00 -4,414.15 -3,650.00 5,986,497.29 535,843.44 Point 3 0.00 -4,922.30 -3,633.66 5,985,989.28 535,862.46 Point 4 0.00 -5,311.46 -2,080.52 5,985,608.36 537,417.48 Point 5 0.00 -5,590.31 -2,113.98 5,985,329.37 537,385.49 Point 6 0.00 -5,252.42 -3,616.38 5,985,659.29 535,881.48 Point 7 0.00 -5,047.45 -3,989.35 5,985,862.27 535,507.47 Point 8 0.00 -4,571.34 -3,999.87 5,986,338.27 535,494.44 Point 9 0.00 -4,147.34 -3,800.63 5,986,763.28 535,691.42 Point 10 0.00 -3,977.78 -3,520.71 5,986,934.29 535,970.41 1 R-06AL1 t7(copy) 0.00 0.00 6,522.00 -5,345.44 -2,474.82 5,985,572.31 537,023.41 70°22'17.634 N 149°41'56.769 W -plan misses target center by 50.91ft at 11362.95ft MD(6544.81 TVD,-5380.30 N,-2504.08 E) -Point 1R-06AL1 t5(copy) 0.00 0.00 6,539.00 -5,247.89 -2,954.36 5,985,667.31 536,543.41 70°22'18.592 N 149°42'10.799 W -plan misses target center by 44.32ft at 10873.04ft MD(6554.75 TVD,-5208.18 N,-2942.59 E) -Point 1 R-06AL1 t3(copy) 0.00 0.00 6,591.00 -5,021.00 -3,685.25 5,985,890.32 535,811.40 70°22'20.820 N 149°42'32.184 W -plan misses target center by 228.42ft at 10300.00ft MD(6591.41 TVD,-5156.89 N,-3501.65 E) -Point 1R-06A,AL1 Fault 2( 0.00 0.00 0.00 -4,866.65 -2,993.35 5,986,048.30 536,502.41 70°22'22.341 N 149°42'11.944 W -plan misses target center by 6559.98ft at 11021.85ft MD(6547.56 TVD,-5217.85 N,-2794.64 E) -Polygon Point 1 0.00 -4,866.65 -2,993.35 5,986,048.30 536,502.41 Point 2 0.00 -5,174.95 -3,133.98 5,985,739.30 536,363.42 Point 3 0.00 -5,392.14 -3,293.13 5,985,521.29 536,205.44 Point 4 0.00 -5,174.95 -3,133.98 5,985,739.30 536,363.42 1 R-06AL1 t6(copy) 0.00 0.00 6,524.00 -5,315.75 -2,794.70 5,985,600.31 536,703.41 70°22'17.925 N 149°42'6.127 W -plan misses target center by 100.05ft at 11039.06ft MD(6546.82 TVD,-5219.85 N,-2777.56 E) -Point 1R-06AL1 t2(copy) 0.00 0.00 6,602.00 -4,634.57 -3,761.21 5,986,276.31 535,733.41 70°22'24.621 N 149°42'34.413 W' 6/23/2010 10:15:03AM Page 4 COMPASS 2003.16 Build 69 ! i f C t J i f L 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 Wellbore: 1 R-06AL1-01 Design: 1 R-06AL1-01_wp01 -plan misses target center by 583.36ft at 10300.00ft MD(6591.41 TVD,-5156.89 N,-3501.65 E) -Point Casing Points p i, z � Measured Vertical l Y'141' 1 p :'''':,`,17:,--==-1.7-141, Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") ( ) 11,650.00 6,551.54 2 3/8" 2-3/8 3 Plan Annotations Measured Vertical Local Coordinates Depth Depth +N/-S +E/-W (ft) (ft) (ft) (ft) Comment 10,300.00 6,591.41 -5,156.89 -3,501.65 TIP/KOP 1R-06AL1_wp06 10,345.00 6,589.39 -5,165.25 -3,457.50 2 10,375.00 6,585.27 -5,170.19 -3,428.21 3 10,405.00 6,579.57 -5,173.50 -3,398.95 4 10,545.00 6,563.36 -5,162.18 -3,261.14 5 10,795.00 6,557.35 -5,184.08 -3,016.63 6 10,970.00 6,550.14 -5,216.46 -2,846.36 7 11,300.00 6,543.62 -5,338.01 -2,550.60 8 11,650.00 6,551.54 -5,457.65 -2,234.70 TD at 11650.00 6/23/2010 10.15.03AM Page 5 COMPASS 2003.16 Build 69 ORIGINAL - 8 III a ° 1 . 0 W _ 4 a MNM 8 i T N - 1 .m 7. 7. 0 8 a ---.Y .......�.....�. c... ._...._N O c 8a . s a t I ti a r a o a, a q a o 1a .m a y 11111 _ ° F-, 11.-1 z3 illgo IAN ° 1 I ° ri a _ a go p E. a Z 11 e g µ III °o, 0 io h $ h 8 8 �° 8 N b ° S 8 1 0 - g ..' 8 a u!!$OSI +4uoN/-y3no$ 8 .? 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C §&la§i 8 288888 8888 '.1m33�#i ++° 8V�g 8o8E '3 S6'6'386-2',2m �o N-NMOMOD,mm ✓ 8 J e p / O f0 i O ,. N 4 j' * /��i ms �``/� / 7 // � _ lea! C z gES4 /// /, ///,, s,/ ,z,z,--, __—__ \\ O / - / JJ // Y i J Y C I / l�I / \ Q. et., 181 c, 9 K`- o �N U • re 1 u$3 :1 \� $ � .�W i i � O L Si v+ L c 0� A V ��' ` V` E ° N PA C ,..., ORIGINAL t Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, June 24, 2010 10:55 AM To: 'Eller, J Gary' Subject: RE: PTD Submittal for 1 R-06AL1-01 Hi Gary, We have the application in hand and are working on it. Tom Maunder, PE AOGCC From: Eller, 3 Gary [mailto:J.Gary.Eller @conocophillips.com] Sent: Wednesday, June 23, 2010 4:35 PM To: Maunder,Thomas E (DOA) Subject: FW: PTD Submittal for 1R-06AL1-01 Tom—I got a note back saying that Guy is out for a few days. Can you help on this? Thanks. -Gary From: Eller, 3 Gary Sent: Wednesday, June 23, 2010 4:22 PM To: 'Schwartz, Guy L(DOA)' Subject: PTD Submittal for 1R-06AL1-01 Guy—We're preparing a drilling permit application for 1 R-06AL1-01 which I hope to give you guys tomorrow. We're adding a lateral due to geologic complexity and operational difficulties with one of our current CTD laterals. The bottom hole pressure information and quarter-mile injection review previously presented are unaffected by this addition. We could possibly spud this lateral by Sunday, June 27, so I request oral authorization from the Commission to proceed with drilling operations without interruption as per 20 AAC 25.015(b)(2) unless you're able to finish your review and get it approved before the weekend. Thanks much, and please let me know if you need anything else. 3. Gary Eller Wells Engineer ConocoPhillips - Alaska work: 907-263-4172 cell: 907-529-1979 fax: 907-265-1535 6/24/2010 TRANSMITTAL LETTE R CCHECKLIST/ / WELL NAME 1 / / —O��/1 L PTD# 2--/C) Development V Service Exploratory Stratigraphic Test Non-Conventional Well L1111 :FIELD '(�f� /� �- POOL: r >-%/ ( Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well <ia{ /// - (If last two digits in x ��= API number are Permit No. 7 Jt,(;z„�,,API No. 50-r -1 5 -6 . 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. 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