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204-093
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THE STATE Alaska Oil and Gas 4)-►-t-���, of L /�, Conservation Commission ,,,,__ __ ______ 1}.2__ y - 333 West Seventh Avenue ___::_„:__, ' t GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 pF \ Q„ Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov John Peirce Sr. Wells Engineer scoNED SEP 0 :1 Z017, ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field, West Sok Oil Pool,KRU 1E-112L2 Permit to Drill Number: 204-093 Sundry Number: 317-403 Dear Mr. Peirce: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P Cathy . Foerster Commissioner DATED this Zetay of August, 2017. RBDMS L`-- ' J 0 2017 • • RECEIVED STATE OF ALASKA AUG 2 3 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION '> JJ q �l APPLICATION FOR SUNDRY APPROVALS SG 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate 0 , Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: RPPG D MBE TrtmtU 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory ❑ Development ❑ 204-093 1 3.Address: Stratigraphic ❑ Service EI , 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-23211-61 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No 0 ✓ KRU 1E-112L2 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25651,ADL 25660 ' Kuparuk River Field/West Sak Oil Pool , 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,273' 3,337' ` 6200 - 3485 . 1500 9184 NONE Casing Length Size MD TVD Burst Collapse Conductor 78' 20" 108' 108' Surface 3,001' 13 3/8 3,031' 2,311' ' Intermediate 6,896' 9 5/8 6,926' 3,606' Liner 5,403' 5 1/2 11,242' 3,338' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): + 5902-5980,6536-11240, 3424-3437,3420-3338, 4.500" L-80 5,810' 6834-6839,8997-9002 , 3403-3403,3370-3370 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): PACKER=SLZXP Liner Top Packer • 5780 MD and 3395 TVD, PACKER= ZXP Liner Top Packer a 6038 MD and 3457 ND, PACKER= HRD ZXP Liner Top Packer _ 6777 MD and3582 TVD SSSV. NONE N/A 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development❑ Service 0, 14.Estimated Date for 9/12/2017 15.Well Status after proposed work: Commencing Operations: OIL ❑ WINJ 0 • WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG 0 GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: John Peirce Contact Name: John Peirce Authorized Title: Sr.Wells Engineer Contact Email: John.W.Peirce@cop.com C� f Contact Phone: (907)265-6471 Authorized Signature: _ ! eDate: MI/Z N COMMISSION USESE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 .7-- If G E Plug Integrity 0 BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ri Spacing Exception Required? Yes ❑ No Ir Subsequent Form Required: /0 .40 T RDDMS 1vt.''' 3 0 20 7 APPROVED BY Approved by: 1340.44.41.14_ COMMISSIONER THE COMMISSION Date:g r /7 -1a) a ati 1 Submitand v77- B/Z -/i�- Form 10-403 Revised 4/2017 RAIG,e p i is valid for 12 months from the date of approval. Attachments in Formate • • West Sak 1E-1 12L2 RPPG Treatment of D MBE 1E-112L2 is a West Sak horizontal D sand injector lateral with 5.5", L-80 liner at 5839' - 11240' RKB containing alternating single -40' slotted joints and single -31' blank joints over the entire liner length. An MBE occurred in 1E-112L2 in 2009 to offset 1E-166L2 producer. An 8/20/09 IPROF evaluation resulted in perforating 1E-112L2 on 7/28/12 at 6834 - 6839' RKB and pumping of a CT Crystal Seal job the same day to treat a D MBE believed to exist at -7000' RKB. A total of 2135 lbs Crystal Seal was pumped, but the resulting treatment benefit was brief. A 12/23/15 IPROF in 1E-112L2 showed clear temperature inflections on multiple passes at -9350' RKB indicating a D MBE likely existed there. No indication existed on the 12/23/15 IPROF that an MBE was at -7000' RKB. On 2/12/17, a Cement Plug placement was attempted into a straddle constructed in the liner between 8800 - 9200' RKB to isolate the D MBE in 1E-112L2. However, the inflatable Cement Retainer set to complete the straddle failed and was POOH still attached to CT with a ruptured bag after pumping 30 bbls of 8.6# cement through the ICR. CT underreamed cement from liner 4/20/17 to a final hard tag at 8835' RKB. An IPROF on 4/22/17 in the D Lat showed -40% of PWI was still exiting through slots below 8800' RKB toward the toe MBE inthe lateral. It is proposed that a fullbore RPPG treatment now be performed to seal off the toe D MBE.I Proposed Procedure: A Plug was set 7/19/12 in a DB Nipple at 6126'RKB to isolate A lateral. The B lateral was isolated by an Iso-Slv on 2/7/17. A 'D'Diverter was set 2/8/17. 1E-112 is configured for D lateral MBE treatment. 1) Coil Tubing: RIH with 2" run OD x 5' OAL perforating gun to shoot 5' of large hole perfs at 6 spf, 60 deg phasing, in 5.5" slotted liner at -8800' RKB (target), or as deep as possible in 1E-112L2. POOH with gun. 2) Pumping: About 24 hrs before the RPPG job, shut-in 1E-166 producer, and put 1E-112L2 on PWI at 500 - 1000 BWPD to establish injection through the D MBE to 1E-166L2. RU mixing van & pumping equipment on 1E-112. Have DSO SI PWI to 1E-112 and then fullbore pump RPPG slurry at a steady rate in 1.0 - 2 bpm range. Mix slurry in 3% KCL Water (or Seawater) adding 1 - 4 mm mesh RPPG to make 0.75 ppg slurry concentration on-the-fly, while fullbore pumping slurry down 1E-112 tubing to the D MBE. Continue pumping at a steady rate and slurry concentration until WHIP reaches -800 psi, and then swap from RPPG slurry to 139 bbls 3% KCL (or Seawater) spacer, followed by 36 bbls Diesel FP to 2000' TVD, followed by Shutdown. Wait 2 days for swelling RPPG particles to fully crosslink in the D MBE to form a stout amalgamated crosslinked non-flowing gel before returning 1 E-166 to production. JWP 8/22/2017 • • Coil Tubing: 3) RIH with jet swirl nozzle and tag top of RPPG in well. Jet through RPPG and fill to deep as possible to shear and mechanically break RPPG remaining in the well, and to open slotted liner to injection as deep as possible. POOH. RD CTU. Place 1 E-112L2 on PWI to evaluate results of the MBE treatment. Evaluate 'D only' PWI performance and monitor offset producer 1 E-166 performance to verify that the D MBE has been isolated. JWP 8/22/2017 KUP 1 E-112 • ConocoPhil ips ;a . - Well Attribut Max Angl D TD Aaska Inc. `»a Wellbore API/UWI Field Name Wellbore Status (°) MD(ftKB) Act Btm(ftKB) Cprge4iphiig s 500292321100 WEST SAK INJ Inc!93.83 7,537.96 11,425.0 Comment H2S(ppm) Date Annotation End Date KB-Grtl(ft) Rig Release Date ... 1E-112,8/222117227:27 PM SSSV:NIPPLE 28 12/9/2004 Last WO: 31.19 7/31/2004 Vertical.somabcSacNal) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag Rev Reason:RESET ISO SLEEVE AND pproven 4/5/2017 .41.1%.: 11111 : a� DIVERTER,SET IBP 8 PERF HANGER;22.3 Casing Strings I' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I Grade Top Thread I`I 1 J -.au CONDUCTOR 20 19.124 30.0 108.0 108.0 94.00 K-55 WELDED Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread I •;': r%I SURFACE 133/8' 12.415 29.9 3,031.0 2,310.6 68.00 L-80 BTC -.'I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB( Set Depth(ND)...Wt/Len(I...Grade Top Thread Mil INTERMEDIATE 9 5/8 8.697 30.0 6,926.3 3,605.6 40.00 L-80 BTC-M -"-ti C-ONDUCTOR;B7I Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread TUBING;763 L2 Window 9 5/8 8.000 5,844.0 5,860.0 3,415.3 40.00 L-80 NIPPLE;507.9 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(MB) Set Depth(ND)...Wt/Len(I...Grade Top Thread L7 Window 95/8 8.000 6,096.0 6,112.0 3,470.2 40.00 L-80 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread A-SAND LINER 5 1/2 4.950 6,776.6 11,297.5 3,602.1 15.50 L-80 DWC Liner Details SURFACE,29.&3,0310--• Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl r) Item Des Com (in) la 6,776.6 3,581.6 80.46 PACKER HRD ZXP LINER TOP PACKER 6.278 GAS LIFT;3,218.8 11 6,795.2 3,584.6 80.53 NIPPLE 'RS'PACKOFF SEAL NIPPLE 5.963 • 6,798.3 3,585.1 80.54 HANGER FLEXLOCK LINER HANGER 6.276 6,808.3 3,586.8 80.58 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 GAS LIFT;5,320.1 6,827.6 3,589.9 80.65 XO BUSHING J 5.500 4 Casing DescriptionOD(in) In) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...WtlLen(I...Grade Top Thread L1 LINER LEM I 4 1/21D(i 3.9581 5,780.11 6,066.91 3,462.11 12.60 L-80 IBT NA Liner Details SLEEVE;5,369.7 'M Nominal ID Top(ORB) Top(TVD)(ftKB) Top Teel(°) Item Des Com (in) 5,780.1 3,395.3 75.57 LEM L2 SLZXP LINER TOP PACKER 6.230 PACKER 1 ..1 5,801.2 3,400.6 75.56 SBE SEAL BORE EXTENSION ASSEMBLY 4.750 LOCATOR;5,7924 i I. _I i 5,830.1 3,4078 75.54 HANGER LEM ABOVE HOOK HANGER 4.020 jiS%SEAL ASSY,5,793.5 5,837.5 3,409.7 75.54 HANGER LEM INSIDE HOOK HANGER 4.020 6,063.6 3,461.5 79.15 SEAL ASSY BAKER SEAL ASSEMBLY 3.890 DIVERTER;5,830.0 'j) Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade -Top Thread D-SAND LINER:5,839.4- (f'- L2 LINER LEM 4 1/2 3.958 6,038.4 6,822.4 3,589.1 12.60 L-80 IBT 11,241.9 !I Liner Details ; Nominal ID i6 Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) L2 Window;s,e4a.a5,eeo.o 6,038.4 3,456.6 78.64 LEM L1 ZXP LINER TOP PACKER 6.230 PACKER 6,057.0 3,460.2 79.02 SBE SBE ASSEMBLY 4.750 6,126.5 3,472.6 80.42 NIPPLE CAMCO'DB'NIPPLE 3.562 I 6,819.1 3,588.6 80.61 SEAL ASSY BAKER SEAL ASSEMBLY 3.890 Tubing Strings L1 LINER LEM;5,780.18,066.9 1 Tubing Description String Ma...ID(in( Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(Ib/ft) Grade Top Connection TUBING I 4 1/21 3.9581 22.31 5,810.51 3 402.91 12.601L-80 11 BTM 1 Completion Details ISO Sleeve;6,06.5.0 I:: Nominal ID B-SAND LINER;6,084.0. Top(ftKB) Top(TVD)(ftKB) Top Incl CI Item Des Com (in) 11,252.0 22.3 22.3 0.00 HANGER VETCO GRAY TUBING HANGER 4.500 L1 Window,6,096.06,112.0 507.9 507.8 4.23 NIPPLE CAMCO'DB-6'NO GO NIPPLE 3.958 5,369.7 3,276.3 6803 SLEEVE BAKER CMU SLIDING SLEEVE w/CAMCO 3.81"DB 3.810 • PROFILE 5,792.4 3,398.4 75.56 LOCATOR BAKER LOCATOR 3.880 111 5,793.5 3,398.7 75.56 SEAL ASSY BAKER SBE SEAL ASSEMBLY 3.880 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) i III,I Top(ND) Top Incl IgY 1® Top(ftKB) (ftKB) (°) Don Com Run Date ID(in) r 14 6,038.4 3,456.6 78.64 PLUG DB PLUG 8 PRONG 7/19/2012 0.000 7,014.0 3,616.6 84.78 Constrictor A-SAND LINER 10 CONSTRICTOR PACKERS set 7/9/2004 5.963 PKR TO ISOLATE SHALES FROM SAND,@ 7014', L2 LINER LEM,6,038.4-6 822 a sik--- 7538',7758',8368',9074',9584',9950',10370', 10648',11215' Perforations&Slots I Shot Dens Top(ND) Btm(ND) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com INTERMEDIATE;30.0-6,926.3 7,013.0' 7,514.0 3,616.6 3,610.8 WS A2,1E- 7/9/2004 40.0 SLOTS ALL PERFS IN 112 WELLBORE:Alternating solid/slotted pipe- Constrictor PKR;7,014.0AEI 0.125'k2.5"@4.0 circumferential adjacent SLOTS;7,013.0-7,514.0 •-• rows,3"centers staggered 18 deg,3'non -slotted ends - 7,759.0 8,340.0 3,594.9 3,592.3 WS A2,1E- 7/9/2004 40.0 SLOTS SLOTS;7,759.08,340.0 112 9,074.0 9,551.0 3,581.1 3,573.5 WS A2,1E- 7/9/2004 40.0 SLOTS 112 SLOTS;9,074.0-9,501.0 9,953.0 10,346.0 3,574.8 3,586.5 WS A2,1E- 7/9/2004 40.0 SLOTS -4 I-. 112 10,658.0 11,202.0 3,602.2 3,603.4 WS A2,1E- 7/9/2004 40.0 SLOTS 112 SLOTS;9,953.0-10,346.0 "- Mandrel Inserts St --4 .-- ati SLOTS;10,658.0-11,202.0 N Top(ND) Valve Latch Port Size TRO Run , -,, Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 3,218.6 2,400.5 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 1/6/2005 A-SAND LINER;6,776.6- 11,297.5 • KUP iii 1E-112 - Conoc©Phillips Alaski,h'L LOMccphlllips ••. 1E-M2,8/22/2017 227',28 PM Vertxal s bornatic(actual) HANGER;71.3 F--_ - ( Mandrel Inserts St 1 `11 II, o Top(TVD) Valve Latch PortSoe TRO Run I N Top(RKB) (ftKB) Make Model OD(inl Sery Typo Type (in) (p51) Run Date Corn 2 5,320.1 3.257.3 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 8/30/2005 111. Notes:General&Safety -A-ti CONDUCTOR;30.0-108.0 I ^ End Date Annotation TUBING,76a 7/30/2004 NOTE:TRI-LATERAL WELL-1E-112(UNDULATING A-SAND)1E-112L1(B-SAND)1E-112L2(D-SAND) NIPPLE;507.9 • 3/1/2009lll illi NOTE:View Schematic w/Alaska Schematic9.0 ' 7128/2012 NOTE:PROFILE MODIFICATION-PUMPED 2145LBS(4MM)CRYSTAL SEAL TO D'MBE x@6839 SURFACE;29.8-3,031.0 GAS LIFT;3,218.6 I 4.1 GAS LIFT;5,320.1 - 11 SLEEVE,5,369.7 I AlaiII LOCATOR;5,792.4 1)11311, SEAL ASSY;5,793.5 DIVERTER;5,830.0 4.v— i �'1# •Fi D-SAND LINER;5,839.4 "' (( 11,241.9 ..a '1 -w r L2 Window;5,844.0-5,860.0 i i I 41 LI LINER LEM;5,780.1-8,0669 • ISO Sleeve,6085.0 9/+I4 la B-SAND LINER,6094.0- lii 11.252.0 L1 Window 696.046112.0 AB 4.44 II ' _'1� 96 il r{ 41 MC L2 LINER LEM;6,038.4-6,822.4 INTERMEDIATE;30.06,926.3 Constrictor PM;7,014.0 SLOTS;7,013.0-7.514.0-4—a "-- -...4 ...- -... ...- SLOTS; -- SLOTS;7.759.0-8,340.0 SLOTS;9,074.0-9,551.0 —4 • SLOTS;9,953.0-10,348,0 SLOTS;10,658.0-11,272.0 A-SAND LINER;6,776.8- i w 11,297.5 KUP 1E-112L2 ConocoPhillips # 'h Well Attribut�l� Max Anglo TD Wellbore CoruocopMll(Ips APSUWI Field Name Wellbore Status ncl TI MD(MB)) Act Btm(ORB) FileJSk.3`Inc, 6i'r 500292321161 WEST SAK INJ 95.96 6,415-94 11,273.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1E-11212,6/10/20178.14:08 AM SSSV:NIPPLE 28 12/9/2004 Last WO 31.19 7/31/2004 Ventral ssilema7e:L:tuap. Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;22.3 rte.=-;gar Last Tag Rev Reason:RESET ISO SLEEVE AND pproven 4/5/2017 DIVERTER,SET IBP&PERF )... Wt/Len(I...Grade Top Thread �_CONDUCTOR,g00-1,x.0 J1 PLP �J �•. 4.950 1 sing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth •:1 1 :1 DWC TUBING;76.3 NIPPLE;507.9 Liner Details INominal ID SURFACE;2903,631.D Top(ftKB) Top(TVD)(ItKB) Top!noir) Item Des .: 1 SiHOOK•HANGER FOR LEM 7 111 GAS LIFT;3,218.6 * MR 5,866 7 3,416 7 76 83 • CROSSOVER 7"x 5.5" 5.000 OtherJIE GAS LIFT;5,320.1 air- las Top(TVD) Top Inc! ate SLEEVE;5,369.7 : 1 1 1 : 1 ' • • 1 r r 111 M ? 9,184.0 3,368.8 89.42 PLUG 2.5"OD BAKER IBP(INFLATABLE RETRIEVABLE 2/9/2017 0.000 LOCATOR;5,792.4 �._. BRIDGE PLUG) SEAL ASSY;5,793.5 DIVERTER;5,830.0 , � Perforations&Slots INTERMEDIATE;30.0-6,926.3. l G L1 LINER LEM;5,780743,086.9 p•'a`'r. Shot e1 Top(ND) Btm(ND) Dens sshots/ Top(ftKB) Btm(ftKB) (ORB) (ftKB) Zone Date ft) Type Com SLOTS;5,902 0-5,960.0 - 5,902.0 5,980.0 3,424.2 3,437.1 WS D,1E- 7/26/2004 40.0 SLOTS ALL PERFS IN j 112L2 WELLBORE:Alternating solid/slotted pipe- 0.125"x2.5"@4 circumferential adjacent rows,3"centers staggered 18 deg,3'non -slotted ends RPERF;6,834 0-6,839.0 GEL SOZ;6,834.0 ftKB 6,536.0 11,240.0 3,419.8 3,338.1 WS D,1E- 7/26/2004 40.0 SLOTS ALL PERFS IN 112(2 WELLBORE:Alternating solid/slotted pipe- 0.125"x2.5"@ 4 circumferential adjacent rows,3"centers staggered 18 deg,3'non -slotted ends 6,834.0 6,839.0 3,402.9 3,402.7 WS A2,1E- 7/28/2012 40.0 RPERF ALL PERFS IN 112 WELLBORE:Alternating solid/slotted pipe- . 0.125"x2.5"@ 4 circumferential adjacent rows,3"centers 4 staggered 18 deg,3'non -slotted ends 8,997.0 9,002.0 3,370.3 3,370.2 WS A2,1E- 2/11/2017 6.0 APERF SLB 2.5"POWERFLOW 112 CHARGES(2506FP HMX,6SPF,60 DEG, — .64"ENT HOLE,5.2" PEN Cement Squeezes - [ Top(ND) Btm(ND) Top(ORB) Btm(ftKB)I (ftKB) (ftKB) Des Star[Date Corn 6,834.0 6,839 0 3,402 9 3,402.7 GEL SQZ 7/28/2012 Notes:General&Safety _ End Date Annotation 7/30/2004 NOTE:TRI-LATERAL WELL-1E-112(UNDULATING A-SAND)1E-112L1(B-SAND)1E-112L2(D-SAND) 3/1/2009 NOTE:View Schematic w/Alaska Schematic9.0 T 7/28/2012 NOTE:PROFILE MODIFICATION-PUMPED 2145LBS(4MM)CRYSTAL SEAL TO'D'MBE@6839 SLOTS,6,536.0.11,240.0 ill • APERF;8,997.09,002.0 PLUG;8,184.0 _N, , 4 , 1 r H _ r D-SAND LINER;5,839.4- 11,241.9\ 1 2-a-- 0°3 WLOG TRANSMITTAL DATA LOGGED PROACTIVE DIAGNOSTIC SERVICES, INC. G,/0,/201'7 K.BENDER To: AOGCC RECEIVED Makana Bender 333 West 7th Avenue MAY 2 5 2017 Suite 100 Anchorage, Alaska 99501 (907) 793-1225 AOGCC RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: ProActive Diagnostic Services, Inc. Attn: Ryan C. Rupe 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 SCANNED JUN 0 9 HI? 1) Injection Profile 22-Apr-17 1E-112 L2 Color Log /CD 50-029-23211-61 2) Signed : �✓ Date : Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W.INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245-8952 E-MAIL: PDSANCHORAGE(p7MEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D:\Achives\MasterTemplateFi les\Templates\Distribution\TransmittalSheets\ConocoPhil li ps_Transmit.docx STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMISSIONO REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: MBE/CEMENT Isoloation Job 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: ConocoPhillips Alaska, Inc. Development❑ Exploratory❑ 204-093 3.Address: P. O. Box 100360,Anchorage,Alaska Stratigraphic Service 0 6.API Number: 99510 50-029-23211-61 7.Property Designation(Lease Number): 8.Well Name and Number: KRU 1 E-1 12L2 ADL 25651,ADL 25660 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Kuparuk River Field/West Sak Oil Pool 11.Present Well Condition Summary: Total Depth measured 11,273 feet Plugs measured None feet true vertical 3,337 feet Junk measured None feet Effective Depth measured 6,200 feet Packer measured 5780,6038,6777 feet true vertical 3,485 feet true vertical 3395, 3457,3582 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 feet 20 " 108'MD 108 SURFACE 3,001 feet 13 3/8" 3,031'MD 2311 INTERMEDIATE 5,810 feet 9 5/8" 5,840'MD 3606 D-SAND LINER 5,403 feet 5 1/2" 11,242' MD 3338 RECEIVED MAY 19 2017 Perforation Depth Measured depth 5902-5980,6536-11240,6834-6839,8997-9002 feet AOGCC True Vertical depth 3424-3437, 3420-3338,3403-3403,3370-3370 feet Tubing(size,grade,measured and true vertical depth) 4.5" L-80 5,810'MD 3,403'TVD Packers and SSSV(type,measured and true vertical depth) PACKER=SLZXP Liner Top Packer 5,780'MD 3,395'TVD PACKER=ZXP Liner Top Packer 6,038'MD 3,457'TVD PACKER= HRD ZXP Liner Top Packer 6,777'MD 3,582'ND SSSV =NIPPLE 508'MD 508'ND 12.Stimulation or cement squeeze summary: JUN r1 Intervals treated(measured): N/A SCANNED �J t +`� J 'J s Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: SHUT-IN Subsequent to operation: SHUT-IN 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development❑ Service Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG ❑ GINJ 0 SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-452 Contact Name: John Peirce Authorized Name: John Peirce Contact Email: John.W.Peirce@conocophillips.com Authorized Title: Sr.Wells Engineer IA _. t Contact Phone: (907)265 6471 Authorized Signature: f"" •e Date: /,L$1``.� I Form 10-404 Revised 4/2017 _� V� ��/j / RBDMS LJ MAY 1 9 2017 Submit Original Only • • 1E-112L2 DTTMS.JOBTYP SUMMARYOPS 2/6/17 CEMENT RIH WITH 4" GS SPEAR AND PULL TYPE-2 D LATERAL ISOLATION SLEEVE AT 5812' CTMD, JOB POOH AND LOSE INJECTOR PRESSURE, CALL OUT MECHANIC TO GET ISSUE RESOLVED AND CONTINUE POOH, RBIH AND PULL TYPE-1 B LATERAL DIVERTER AT 6072' CTMD. JOB IN PROGRESS. 2/7/17 CEMENT SWAP OUT BOPE'S, PERFORM WEEKLY BOPE TEST, RIH AND SET TYPE 1 ISOLATION JOB SLEEVE ACROSS B-LEM AT 6088' CTMD, IN PROGRESS. 2/8/17 CEMENT RIH AND SET TYPE 2 DIVERTER IN D-LEM AT 5827' CTMD, RIH WITH SLB MEMORY LOGGING JOB BHA, PERFORM DEPTH DETERMINATION LOG OF D-LATERAL FROM 9400'TO 5600', PAINT FLAGS AT 9150'AND 8750', AT SURFACE AND CONFIRM GOOD DATA. SHUT DOWN FOR PHASE 2 WEATHER ***IN PROGRESS*** 2/9/17 CEMENT RIH AND ATTEMPT TO SET 2.5" BAKER IBP, UNABLE TO MAKE IT THROUGH D LATERAL JOB DIVERTER, POOH AND INSTALL ROUNDED NOSE GUIDE WITH SHROUD ON BOTTOM OF IBP, RBIH TO EOP FLAG, CORRECT DEPTH (+17' CORRECTION), SET IBP @ 9184' RKB MID ELEMENT. ***IN PROGRESS*** 2/11/17 CEMENT RIH TO EOP FLAG AND CORRECT DEPTH (+13.5'), PERFORATE MBE INTERVAL IN D LATERAL JOB FROM 8997'-9002' RKB WITH SLB 2.5" POWERFLOW CHARGES (2506FP HMX, 6SPF, 60 DEG, .64" ENT HOLE, 5.2" PEN); ATTEMPT TO SET 2.5" BAKER CEMENT RETAINER & UNABLE TO MAKE IT THROUGH D LATERAL DIVERTER (NO VISIBLE MARKS ON RETAINER); WILL RETURN IN AM WITH NEW NOSE GUIDE AND SECOND SHROUD TO RUN ON RETAINER . ***IN PROGRESS*** 2/12/17 CEMENT RIH TO EOP FLOG &CORRECT DEPTH (+13.7'), ATTEMPT TO SET 2.5" BAKER CEMENT JOB RETAINER IN D-LATERAL W/MID ELEMENT @ 8821' RKB; UNABLE TO CONFIRM GOOD SET W/RETAINER (DISCUSS W/TOWN ENGR) &CONTINUE FORWARD W/PUMPING 30 BBLS OF 8.6 PPG ULTRA-LITE CRETE CEMENT FOLLOWED BY 5 BBLS WATER SPACER& DEPLOY 5/8" DISO BALL (NEVER SAW BALL ON SEAT); STACK WEIGHT ON RETAINER W/ NO MOVEMENT; ATTEMPT TO SHEAR OFF, PUH, SEE OVER PULL, AND WEIGHT FALL OFF. POOH &STILL HAVE CEMENT RETAINER. ***JOB SUSPENDED*** 4/18/17 IPROF RIH WITH MILLING BHA, DRY TAG CEMENT AT 6025' RKB, MILL DOWN TO 7105' RKB AND PIPE IS STUCK FOR 30 MINUTES, GOOD 1:1 WITH HEAVY CEMENT IN RETURNS, RESTART IN AM WITH UNDER-REAMER, JOB IN PROGRESS. 4/19/17 (PROF RIH WITH MOTOR AND UNDERREAMER (4.75" BLADES), BEGIN UNDERREAMING FROM 5986' RKB TO 8041' RKB, GOOD 1:1 RETURNS ALL DAY WITH HEAVY CEMENT IN RETURNS, RETURN IN AM TO FINISH MILLING, JOB IN PROGRESS. 4/20/17 IPROF RIH WITH MOTOR AND UNDER-REAMER(4.75" BLADES), UNDERREAM FROM 5800' RKB TO HARD TAG AT 8835' RKB, MAINTAINED 1:1 RETURNS WITH HEAVY CEMENT SOLIDS, OPEN CIRC SUB AND CHASE ALL SOLIDS OUT OF HOLE WITH GEL SWEEP AT 3 BPM, OPERATIONS PUT WELL ON INJECTION, RETURN IN AM FOR IPROF, JOB IN PROGRESS. 4/21/17 IPROF RIH WITH PDS MEMORY LOGGING TOOLS, PERFORM IPROF LOG FROM 5600' RKB TO 8800' RKB AT 120 FPM AND 80 FPM, F/P FLOW LINE AND TBG, SHUT IN THE WELL FOR 2 HOUR STABILIZATION, PERFORM SHUT IN WARM BACK LOG FROM 5600' RKB TO 8800' RKB AT 80 FPM, BAD DATA RECOVERED, PAD OPERATOR RETURNS WELL TO INJECTION FOR JOB RE- DO IN AM, JOB IN PROGRESS.. 4/22/17 IPROF RIH WITH PDS MEMORY LOGGING TOOLS, PERFORM (PROF LOG FROM 5600' RKB TO 8800' RKB AT 120 FPM AND 80 FPM, F/P FLOW LINE AND TBG, SHUT IN THE WELL FOR 2 HOUR STABILIZATION, PERFORM SHUT IN WARM BACK LOG FROM 5600' RKB TO 8800' RKB AT 80 FPM, GOOD DATA RECOVERED, LEAVE WELL SHUT IN, JOB COMPLETE. KUP I 1 E-1121.2 nocoPhiIlips & Well Attribu Max AnglillD TD • Alaska.Int.; Wellbore API/UWI Field Name Wellbore Status ncl C) MD(DAB) Act Btm(ftKB( 0,00,gjhig(, r 500292321161 WEST SAK INJ 95.96 6,415.94 11,273.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1E-1121.2,51172017 8 51 16 AM SSSV:NIPPLE 28 12/9/2004 Last WO: 31.19 7/31/2004 Verncel schemaoc.(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER;22.3 aa. Last Tag Rev Reason:RESET ISO SLEEVE AND pproven 4/5/2017 u:,�„�.�, ,,»,,,,,r,ae,�.,,n,,.,,,„„„n„r ,W DIVERTER,SET IBP 8 PERF ”"Casing Springs CONDUCTOR 30.0-1080 Casing Description OD(In) ID(in) Top(ftKB( Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread Mme........ .��.�. TUBING,76.3, !, '1D SAND LINER 5 1/2 4.950 5,839A 11,242.0 3,338.0 15.50 L-80 DWC NIPPLE;507.9 — Liner Details Nominal ID SURFACE;29.0-3,031.0 • L Top(ftKB( Top(TVD)(ftKB) Top Incl C) Item Des Com (in) 5,839.4 3,410.2 75.53 HANGER BAKER MODEL B-1 HOOK HANGER FOR LEM 7.000 GAS LIFT;3,218.6 5,866.7 3,416.7 76.83 XO CROSSOVER 7”x 5.5” 5.000 311 GAS LIFT;5,320.1 _ Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(TVD( Top Inel SLEEVE;5,389.7titMlitt Top(ftKB) (ftKB) (•) Des Com Run Date ID lin( mg 5,830.0 3,407.8 75.54 DIVERTER TYPE 2 DIVERTER IN D-LEM 2/8/2017 3.000 9,184.0 3,368.8 89.42 PLUG 2.5”OD BAKER IBP(INFLATABLE RETRIEVABLE 2/9/2017 0.000 LOCATOR,5,792.4 BRIDGE PLUG) SEAL ASSY;5,793.5 DIVERTER;5,830.0 Perforations&SIOts INTERMEDIATE;30.06,928.3 L1 LINER LEM,5,780.16,088.9Shot IL ——J L Top(ND) Btm(NDens D) (shots/ Top OMB) Otto(ftKB) (ftKB) (ftKB( Zone Date ft( Type co. SLOTS,5,902.0-5,980.0 5,902.0 5,980.0 3,424.2 3,437.1 WS D,1E- 7/26/2004 40.0 SLOTS ALL PERFS IN 112L2 WELLBORE:Alternating solid/slotted pipe- 0.125"x2.5"@ 4 circumferential adjacent rows,3"centers staggered 18 deg,3'non RPERF;8,834.08,839.0 -slotted ends GEL soz;6,634.0 ftKB, 6,536.0 11,240.0 3,419.8 3,338.1 WS D,1E- 7/26/2004 40.0 SLOTS ALL PERFS IN 112L2 WELLBORE:Alternating solid/slotted pipe- 0.125"x2.5"@ 4 circumferential adjacent rows,3"centers staggered 18 deg,3'non -slotted ends 6,834.0 6,839.0 3,402.9 3,402.7 WS A2,1E- 7/28/2012 40.0 RPERF ALL PERFS IN — 112 WELLBORE:Alternating solid/slotted pipe- ' 0.125"x2.5"@ 4 circumferential adjacent rows,3"centers staggered 18 deg,3'non -slotted ends 8,99/.0 9.002.0 3.370.3 3,370.2 WS A2.1E- 2/11/2017 6.0 APERF SLB 2.5"POWERFLOW — 112 CHARGES(2506FP HMX,6SPF,60 DEG, — .64"ENT HOLE,5.2" PEN Cement Squeezes — Top(TVD( Btm(ND) Top(ftKB( Btm(ftKB) (ftKB) (ftKB) Des Start Date Corn 6,834.0 6,839.0 3,402.9 3,402.7 GEL SQZ 7/28/2012 — Notes:General&Safety End Date Annotation 7/30/2004 NOTE:TRI-LATERAL WELL-1E-112(UNDULATING A-SAND)1E-112L1(B-SAND)1E-112L2(D-SAND) 3/1/2009 NOTE:View Schematic w/Alaska Schematic9.0 7/28/2012 NOTE:PROFILE MODIFICATION-PUMPED 2145LBS(4MM)CRYSTAL SEAL TO D'MBE@6839 SLOTS;0,536.0-11,240.0 APERF;8,997.03,002.0 1= PLUG;9,184.0 N 1 D-SAND LINER;5,839.4 11,241.9, KUP II) 1 E-112 ConoiC0 iJlips +�♦ Well Attribu Max Angle TD Alaska Inc, " Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) t«p,;ophggps 500292321100 WEST SAK INJ , 93.83 7,537.96 11,425.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(k) Rig Release Date 1E-112,5/17/20178:51 41 AM SSSV:NIPPLE 28 12/9/2004 Last WO: 31.19 7/31/2004 Venccelschemanc(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag Rev Reason:RESET ISO SLEEVE AND pproven 4/5/2017 �:.,._� DIVERTER,SET IBP 8 PERF HANGER;223 � ill. Casing Strings Casing Description 0D(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread `Ek)I I J' CONDUCTOR 20 19.124 30.0 108.0 108.0 94.00 K-55 WELDED I !:..ii 11 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread I SURFACE 13 3/8 12.415 29.9 3,031.0 2,310.6 68.00 L-80 BTC Casing Description 00(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/Len(I...Grade Top Thread INTERMEDIATE 95/8 8.697 30.0 6,926.3 3,605.6 40.00 L-80 BTC-M J",/- Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... WVLen(I...Grade Top Thread coNoticio U NG,76 3 L2 Window 9 5/8 8.000 5,844.0 5,860.0 3,415.3 40.00 L-80 NIPPLE;507.9 Casing Description 01)(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len II...Grade Top Thread L1 Window 95/8 8.000 6,096.0 6,112.0 3,470.2 40.00 L-80 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread IA-SAND LINER 51/2 4.950 6,776.6 11,297.5 3,602.1 15.50 L-80 DWC LLiner Details SURFACE;29.83,031.0 Nominal ID Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) GAS LIFT;3,2166 6,776.6 3,581.6 80.46 PACKER HRD ZXP LINER TOP PACKER 6.278 IF II 6,7952 3,584.6 80.53 NIPPLE 'RS'PACKOFF SEAL NIPPLE 5.963 I 6,798.3 3,585.1 80.54 HANGER FLEXLOCK LINER HANGER 6.276 6,808.3 3,586.8 80.58 SBE 190-47 CASING SEAL BORE EXTENSION 4.750 IL GAS LIFT,5,320.1 IR 6,827.6 3,589.9 80.65 XO BUSHING 5.500 Casing Description 00(in) ID(in) Top(ftKB) Set Depth IRKS) Set Depth(TVD)...WtlLen(I...Grade Top Thread L1 LINER LEM 1 4 1/21 3.9581 5,780.11 6,066.91 3,462.11 12.601 L-80 IBT MIN Liner Details SLEEVE,5,369.7 Nominal ID 11, Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 5,780.1 3,395.3 75.57 LEM L2 SLZXP LINER TOP PACKER 6.230 PACKER I t -i , 5,801.2 3,400.6 75.56 SBE SEAL BORE EXTENSION ASSEMBLY 4.750 LOCATOR;5,792.4 I 11011i 5,830.1 3,407.8 75.54 HANGER LEM ABOVE HOOK HANGER 4.020 SEAL ASSY;5,793.5 5,837.5 3,409.7 75.54 HANGER LEM INSIDE HOOK HANGER 4.020 Iii, 6,063.6 3,461 5 79.15 SEAL ASSY BAKER SEAL ASSEMBLY 3.890 I t•,4./ Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)... Wt/LenGrade Top Thread DNERTER;5,830.0 �--,b l g pion (I... DSAND LINER;5,8 .4 L2 LINER LEM 4 1/2 3.958 6,038.4 6,822.4 3,589.1 12.60 L-80 IBT 11241.9 111:IlLLiner Details [ Ind(° Nominal Top(ftKB) Top(ND)(ftKB) Top In ) Item Des Com (in) L2 Window;5,8440s,e60.0 6,038.4 3,456.6 78.64 LEM L1 ZXP LINER TOP PACKER 6.230 PACKER 6,057.0 3,460.2 79.02 SBE SBE ASSEMBLY - 6,126.5 3,472.6 80.42 NIPPLE CAMCO'DB'NIPPLE 3.562 _ _ 6,819.1 3,588.6 80.61 SEAL ASSY BAKER SEAL ASSEMBLY 3.890 Ili Tubing Strings L1 LINER LEM;5,780.1-6,0669 - Tubing DescriptionString Ma...ID(in) Top(ftKB) Set Depth(ft.. Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING Description ' 4 1/21 3. 9581 22.31 810 3,402.91 12.601 L-80 IIBTM i14 Completion Details ISO Sleeve;6,085.0 WI B-SAND LINER;6,094.0- 1 1444 ;s Nominal ID 11 2520 Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 22.3 22.3 0.00 HANGER VETCO GRAY TUBING HANGER 4.500 Ll Window;6.096.5-6,112.0 - 507.9 507.8 4.23 NIPPLE CAMCO'DB-6'NO GO NIPPLE 3.958 5,369.7 3,276.3 68.03 SLEEVE BAKER CMU SLIDING SLEEVE w/CAMCO 3.81"DB 3.810 PROFILE 5,792.4 3,398.4' 75.56 LOCATOR BAKER LOCATOR 3.880 II5,793.5 3,398.7 75.56 SEAL ASSY BAKER SBE SEAL ASSEMBLY 3.880 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) I1,1 Iff Top(TVD) Top Incl 1W i Top(ftKB) (ftKB) (3 Des Corn Run Date ID(in) ,• 6,038.4 3,456.6 78.64 PLUG DB PLUG 8 PRONG 7/19/2012 0.000 air 7,014.0 •LINER 10 CONSTRICTOR.:I 114 5.963 1_2 LINER LEM;6,038.4-6,822.4 - •1 • 1 10370', 1. 1.----1 Perforations&Slots Dens Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com INTERMEDIATE;30.0-6,926.3 7,013 1 7,514.0 004 .11 SLOTS 112 WELLBORE:Alternating lid/slotted pipe- I' Constrictor PKR;7,014.0 1 circumferential adjacent . rows,3"centers SLOTS;7,013.0-7,514.0 staggered 18 deg,3'non -slotted ends •1 8,340.0 • 11' 40.0 SLOTS SLOTS;7,759.08,340.0 9,074.0 9,551.0 • 11• '11 SLOTS 112 SLOTS;9,074.09,551.0 1 10,346.0 11• 40.0 1SLOTS 112 10,658.0 11,202.0 3,602.26I 7/9/2004 _-II SLOTS 112 SLOTS,9,953.010,346.0 Mandrel Inserts St ati " Top(TM)) Valve Latch Port Size TRO Run SLOTS;10,6580-11,202.0N Top(ftKB) (ftKB) Make Model OD(in) Sery Type Type (in) (psi) Run Date Com 1 3,218.6 411 • DMY BK 0.000 11 11 A-SAND LINER;6,776.0 11,297.5 KUP ili 0 1 E-112 CondcoPhiUUips �' rTAK r Alaska.iric.. CBwO6O7Phillips 1E-112,5/17/2017 8:51A1 AM Vor5r,I;• -m>4 rattrap HANGER,22.3 tillilialfil Mandrel Inserts it �(y •��a 0111 Top(TVD) Valve Latch PortSize TRORun (j I N Top(RKB) (RKB) Make Model 00 (in) Se" Type Type (in) (psi) Run Date Com 2 5,320.1 3,257.3 CAMCO I KBG-2 1 GAS LIFT DMY BK 0.000 0.0 8/30/2005 Notes:General&Safety -~"-CONDUCTOR;30.0-708.0 1 ti End Date Annotation TUBING,76.3 7/30/2004 NOTE:TRI-LATERAL WELL-1E-112(UNDULATING A-SAND)1E-112L1(B-SAND)1E-112L2(D-SAND) NIPPLE;507.9 1 3/1/2009 NOTE:View Schematic w/Alaska Schematic9.0 Q 7/28/2012 NOTE:PROFILE MODIFICATION-PUMPED 2145LBS(4MM)CRYSTAL SEAL TO'CV MBE@6839 SURFACE;29.83,031.0 It GAS LIFT;3,218.6 ali GAS LIFT,5,320.1lE SLEEVE.5.369.7 --- LOCATOR;5,792.4 SEAL ASSY;5,793.5 it MI DIVERTER;5,830.0 s :Ai D-SAND LINER;5,839.4- l il,- if 11,241.9 L2 Windovr,5,844.0-5,860.0 )p I Lt LINER LEM;5,780.1-6,066.9 .170ISO Sleeve;6,085.0 0 8-SAND LINER 6,0940- � €e 11,2520 L1 Window;6,096.0-6,1120 1uI It NI f: a L2 LINER LEM:6,0384-6,622.4 INTERMEDIATE;30.06,928.3 Constrictor PKR;7,014.0 SLOTS;7,013.0-7,514.0 SLOTS;7,759.0-8,340.0 SLOTS;9,074.0-9,551.0 _i _i SLOTS 9,953.0-10,346.0 — ` I-- SLOTS, SLOTS,10,656.0-11,202.0 .-- A-SAND LINER;6,776.6- 11,297.5 M4 • • 0 7 ❑ N co F- >- OcuW1 W 0 t .� cJ 0 z v s O 3 (� O w tin > � 11 (�Vj -I of m v w a roE Q--,; 4 c u O a; > arJ v a` a c C Y v 0 u 4 'rt ❑ s O v Q ra Q Q ❑ Q C7 N- N. 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LLo. £ y N Z F 0 d a s c..)� ' i 0 aq w a4 U > Z (i1 °' w v > oro 8 • cei coo — w 9 • � °x(f Uia EO O_ J J J O J J J N V) tn /,\:„.9 W 4 Ce frIXCeCere X W W W W W W W L" > > > > > > > Q z Y Y Y Y Y Y Y w W W W W W Cev W waaQQQQQ liA 7 0 r - U W > > > > > > O. a • C Y Y Y Y Y Y Y C N r , at W Cr o � � � � � � � X � .� cc 0 0 0 0 0 0 0 0 0 O O0 0 0 0 0 o 0 0 0 0 • m o v r; n n ❑ r- r• r- ra WLLI - > 222a2E2 •> Lo ❑ ❑ ❑ o ❑ ❑ ❑ Q u Cr g to a E Q O O O O O O O YN O 0 n O CO 0 CO 0 O O f0Q mCON O) CO CO 0 N N CO 0 0 O ) MNMM . •- a = N N N N N N N N E L p { N N N N N N ( O 0 Q1 0 O O O O O ` U V pppp 0 0 0 0 0 0 0 a-' +. OC O rl C v) u) )(f to V) U) in i1. 'O O C u 0 C v oc Q- W CC 2 NI v' E E ~ d cu d rl 13 11:5 ro Q OO O N N co O O �..CO -J NI en ToN C ` �G d EE = bao0 z7r7 � 7N- a- Ero Nv C. N W N 0 N C z H 0 0 • C ycs. Q 3 cu 0 0 F- a o. H F- • OFT • �'� THE STATE Alaska Oil and Gas kr 71, ofA LA S KA Conservation Commission x = _- 333 West Seventh Avenue 1 GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov John Peirce Sr. Wells EngineerSCA r ConocoPhillips Alaska, Inc. ���� t ~' ' P.O. Box 100360 Anchorage,AK 99510 Re: Kuparuk River Field, West Sok Oil Pool, KRU 1E-112L2 Permit to Drill Number: 204-093 Sundry Number: 316-452 Dear Mr. Peirce: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 4,1 Cath P. Foerster Chair DATED this / ay of September,2016. RBDMS LL-SLr 1 6 2016 • • STATE OF ALASKA ' ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon fa Plug Perforations E Fracture Stimulate E Repair Well Operations Shutdown E Suspend I- Perforate IT Other Stimulate Pull Tubing r— Change ApppiPrv�ogram T Plug for Redrill 1— Perforate New Pool Re-enter Susp Well IT Alter Casing 1— Other: MBEifsolation Job F . 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska,Inc. • Exploratory I.-••••.. Development T 204-093 • 3.Address: 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic I Service " 50-029-23211-61-00 • 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? NONE • Will planned perforations require a spacing exception? Yes No F KRU 1 E-112L2 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25651,ADL 25660 • Kuparuk River Field/West Sak Oil Pool ,, 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,273' s 3,337's 6200 . 3485 . 1267 psi none none Casing Length Size MD TVD Burst Collapse Conductor 78' 20" 108' 108' Surface 3,001' 13 3/8 3,031' 2,311' Intermediate 5,810' 9 5/8 6,926' 3,606' D Sand Liner 5,403' 5.5" 11,242' 3,338' Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 5902-5980,6536-11240,6834- 3424-3437,3420-3338,3403- 4.500" L-80 5,810' 6839• 3403 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): PACKER-SLZXP LINER TOP PACKER @ 5780 MD and 3395 ND 5780 MD and 3395 ND PACKER -ZXP LINER TOP PACKER @ 6038 MD and 3457 ND 6038 MD and 3457 ND PACKER-HRD ZXP LINER TOP PACKER @ 6777 MD and 3582 ND 6777 MD and 3582 ND SSSV: NONE 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program D BOP Sketch ❑ Exploratory I-••••••. Stratigraphic n Development 1— Service A ' 14.Estimated Date for 10/1/2016 15.Well Status after proposed work: Commencing Operations: OIL IT WINJ WDSPL i......:1 Suspended IT 16.Verbal Approval: Date: GAS r— WAG T GSTOR T SPLUG !— Commission Representative: GINJ Y..... Op Shutdown Abandoned I 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact John Peirce @ 265-6471 Email John.W.Peirce0,conocophillips.com Printed Name John Peirce Title Sr.Wells Engineer .e ' ^ `I- 1-16 Signature -. . Phone 265-6471 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3\co—y 5a Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance 0 p�,� Other: I 31t� �1V3 C CEI 73,::: Post Initial Injection MIT Req'd? Yes ❑ NoV SEP 0 1 Z Spacing Exception Required? Yes ❑ No I/ Subsequent Form Required: ' ., 4 0* S ,7c .... _ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date:9–/F..../4 `1',46 7 a) vee ��io l� Il3nIh �,a Submit form and Form 10-403 R ised 11/2015 / proved application r v i r ie ate of approval. RBDMJ tta c•-•1" -t� Pii9ac6 2016 • • West Sak 1E-112L2 Cement Plug Placement to isolate `D' MBE 1E-112L2 D Sand horizontal injector lateral has 5.5", L-80 liner between 5839' - 11240' RKB contains alternating single -40' slotted joints and single -31' blank joints. In 2009, an MBE in 1E-112L2 occurred to offset producer 1E-166L2. An 8/20/09 IPROF was run in 1E-112L2 to locate the MBE. (PROF evaluation resulted in perforating 1E-112L2 on 7/28/12 at 6834 - 6839' RKB and pumping a CT Crystal Seal job the same day to treat a D MBE believed to exist at -7000' RKB. A total of 2135 lbs Crystal Seal was pumped. The treatment benefit was brief. This may have due to MBE location uncertainties in evaluating the (PROF, fairly small Crystal Seal volume that had been pumped, or a difficult MBE form to treat. A 12/23/15 IPROF in 1E-112L2 shows distinct temperature inflections on multiple logging passes at -9350' RKB indicating that a D MBE likely exists in this area. No distinct indications exist on the 12/23/15 IPROF temp data that an MBE presently exists in -7000' RKB. It is proposed that a 8.6 ppg Cement Plug be pumped into a straddle constructed in the 5.5" liner between 8800 - 9200' RKB to isolate the D MBE to restore PWI to 1 E-112L2. A total of five West Sak MBE's have been isolated using this method with 100% success rate (but 2 of the 5 wells needed a retreatment likely due to the initial cement plug lengths placed being undersized). Proposed Coil Tubing Procedure: 1E-112 was reconfigured 12/24 & 12/25 for a 12/26/15 'B' lateral IPROF. We need to reconfigure (in steps 1 - 4 below) to enable CT work in the D lateral. Use 2"OD CT for the entire job procedure. 1) RIH with CT and pull 'D' Iso-Sleeve from the 'D' LEM at 5830' RKB. 2) RIH with CT and pull 'B' Diverter from the 'B' LEM at 6085' RKB. A Plug was set 7/19/12 in the DB Nipple at 6126'RKB in the A lateral main-bore. This Plug will be left set to keep the A lateral isolated during the D MBE Isolation job to be performed in step 7(below). 3) RIH with 'B' Iso-Sleeve on CT and set it over the B LEM at 6085' RKB. 4) RIH with 'D' Diverter on CT and set it in the D LEM at 5830' RKB. 5) RIH with 2.5" run OD Permanent Inflatable Bridge Plug. Inflate and set Bridge Plug in 5.5" slotted liner at -9200' RKB (target). Flag CT for depth control. POOH. 6) RIH with 2.5" run OD x -5' OAL perforating gun to shoot 5' of `large hole' perfs, at 6 spf, 60 deg phasing in 5.5" slotted liner at 8998 - 9003' RKB (target). Flag CT for depth control. POOH with gun. 7) RIH with 2.5" run OD Inflatable Cement Retainer and set the Retainer in 5.5" slotted liner at -8800' RKB (target). Pump 30 bbls 8.6# Cement to fill 400' of 5.5" slotted & blank liner between the Retainer & Bridge Plug at 8800' & 9200' RKB respectively, and to also fill -500' of adjacent 5.5" liner x 8.5" OH annulus to isolate the D MBE at -9350' RKB. PU to disconnect CT from Retainer. Spot last 0.5 bbl of cement on Retainer. POOH displacing liner & tubing with Seawater and Diesel FP to 2000' TVD. Wait on cement 7 days then return 1E-112L2 to PWI. Evaluate 'D only' PWI performance and monitor offset producer 1E-166 performance to verify that the D MBE has been isolated. Eventually an IPROF will verify satisfactory D lateral PWI conformance, and then 1E-112 well work will be performed to restore PWI service to the B and A laterals. JWP 9/1/2016 • • • Tubing String 4-112"12.6#,L-80,IBTM 3.958"ID, lore,418 18 3.833"Drift ConocoPhillipsHUGHES 507'MD-DB Nipple,3.875"Profile F i na I Baker Oil Toole West Sak 9-5/8" Injector \#1.\'.,,, 2,400'MD-GLM,Camco 1"KBG-2 5,320'MD-GLM,Camco 1"KBG-2 1E-112 As Completed 13-3/8" �` Tri-Lateral Completion Casing Shoe, 5,369'MD-CMU Sliding Sleeve, ♦....� w/3.81"DB Profile 68#,L-80, vie\ MD-Casing Sealbore Receptacle 5,803' Lateral Entry Module(LEM) BTC set k u @ - �� With Diverters and Isolation 3,031'MD, #��` 'D'Sand Lateral Lateral Access Dlverter Lateral lsolahon Dlverter 2,309'TVD `'�A` 5,830'MD-Lateral Entry Module(LEM)1A GS Running Tool String Installed Installed `` D-sand Casing Exit �^ VII- ` — --. at ,841'MDle for V" Ni� 'GS' �nProfivev 5,780'MD-7"X 9-5/8"ZXP Liner ' '. a Coil Length) /Rn glReidw ng�, C �05 1/2 15 5#L-80 Slotted Liner m Leneml I Top Packer \ Positi In/Snap n e`- `\ ® Back Pressure Valve ® II � It 60 Length) Ddlei '* : �l4e.m 5-1/2"Casing Shoe,15.5#, --III 11-11 5,835'MD-7"X 9-5/8"Model \'•IIII j r " ` L-80 DWC lIh i claw Tbmswivd seals 11 R5 LengM) \ Lateral DvMer 'B-1'HOOK Hanaer ♦, so Set @ 11,238'MD Hyduule Ramp II D-aconnec( is.,,Mainbore�. R. (1.50'Len91M1) Diverter Sleeve 6,038'MD-7"X 9-5/8"ZXP '� 6,086'MD-Lateral Entry !I Gs spear Liner Top Packer Module Module(LEM) .I�5g Lengnl Lateral Isolation�� 1 Seals �♦�; 'B'Sand Lateral 6.95RA"` _DAL' �� Lateral Entry Module(LEM) 8,058'MD-Casing B-sand CasingExit a8 maybe e4 a.nngnlyae ated Sealbore Receptacle , or tleep app)' s16'approa lmgd,} Assembly P at 6 095 85 deg i® `- inclination 5-1/2"15 5#,L-80 Slotted Liner t# «�]X BSIB x.P.Ldtr,Top \„ ; Packer with Hold Downs " ! 7.500"Tieback Ezt Ip \ r,- : sz7s-Tool eoaylD 5-1/2"Casing Shoe, '-- CasingSealboreReceptacle 6,094'MD-7"X9-5/8"Model �`� , RAAwll ,'d 15.5#,L-80 DWC 475 Ip 575"OD 'B-1'HOOK Hanger III I 15'Length Set @ 11,253'MD ■b Tubing Swivel,4-112" ,• ` 6,126'MD-3.562"DB Nipple 1Orienting Profile Automatic Alignment of LEM - — Poetive Latching Collet ® l , Indicates Correct Location 1 7 xs-s/s"zxP eA'Sand Undulating Lateral Seal Bore for Lateral Liner Top '�Isolation 068••ID I Packer � Access Window 7"X 9-5/8" l I Positive Lateral Access Yla Liner Hanger/Packer Flex Lock \ 5-1/2"15.5#,L-80 rhru-Tnbing olge,t Assembly Liner Hanger Slotted Liner 5-1/2"CasingShoe, i set @ 6,776'MD i � seal Bore for Lateral Isolation-3.66••10 6,80T MD-Casing Sealbore / wl �a 15.5# L-80 DWC Receptacle in form �," , , _ Set @ 11,296'MD Isolation Seal Asembiy Confidential 9-5/8"Casing Shoe, 4.75"Seal OD 3.875"Seal ID Me,. 12•Length Baler Hignss ZOOS.This document may not he reproduced or dlsmbuted,in whole or In partr 40.0#,L-80 BTC 1E-112-Tri-lateral WnplMnn.Inl.cw mly means recording,or t i and retrieval systeelectronic naw known or hereafter n�vented.wng ithout photocopying. n permission from Baakr'er Hughes nation cea'e- Ib'—"'Yart O.Kuck laawammc 1 xo.ltl Set @ 6,926'MD , • .-y ,:q KUP INJ 1E-112L2 ConocoPhillip$ " Well Attributes Max Angle&MD TD 6 Wellbore API/UWI Field Name Wellbore Status ncl(") MD(MB) Act Btm(ftKB) A(n95.Ss3,) <<xrlcralTpl500292321161 WEST SAK INJ 95.96 6,415.94 11,273.0 .,. ••• Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1E-1121_2 12E30/2015 2.5806 PM SSSV:NIPPLE 28 12/9/2004 Last WO: 31.19 7/31/2004 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date HANGER,22.3a. Last Tag Rev Reason:RESET ISO SLEEVE AND lehall 12/30/2015 • q II^:IFl;uy DIVERTER limo: d Casing Strings CONDUCTOR 30.0 108.0 1�� — Casing Description OD(in) ID(in) Top(ftKB) Set Depth(kKB) Set Depth(TVD(...Wt/Len(I...Grade Top Thread TUBING;76.3 " D-SAND LINER 51/2 4.950 5,839.4 11,242.0 3,338.0 15.50 L-80 DWC NIPPLE;507.9 �L Liner Details I1 Nominal ID SURFACE;29.03,031.0NM�. Top(ftKB( Top(WD)(ftKB) Top I net(") Item Des Com (in) GAS LIFT;3,218.6 5,839.4 3,410.2 75.53 HANGER BAKER MODEL B-1 HOOK HANGER FOR LEM 7.000 MI 5,866.7 3,416.7 76.83 X0 CROSSOVER 7"x 5.5" 5.000 att GAS LIFT;5,320.1 l 411118 Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) it Top(WD) Top Incl SLEEVE;5,369.7Top(ftKB) (ftKB) 13 Des Com Run Date ID(in) kat 6,085.0 3,446.3 87.98 DIVERTER TYPE)DIVERTER(OAL=21 60') 12/24/2015 2.500 LOCATOR,5,792.4 Perforations&Slots SEAL ASSY;5,7935 ISO Sleeve,5,830.0 ,rte' De L1 LINER LEM;5,780.1-6,066.9 "°- € Denns Shots INTERMEDIATE;30.06,926.3 r,3•$6 Top(TVD) Btm(IVO) (shots/f p 8II Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date t) Type Corn 6 °,f 5,902.0 5,980.0 3,424.2 3,437.1 WS D,1E- 7/26/2004 40.0 SLOTS ALL PERFS IN 112L2 WELLBORE:Alternating SLOTS;5,902.0-5,980.0solid/slotted pipe- 1 0.125"x2.5"@ 4 DIVERTER;6,085.011i ,085.0 circumferential adjacent rows,3"centers staggered 18 deg,3'non -slotted ends 6536.0 11,240.0 3,419.8 3,338.1 WS D,1E- 7/26/2004 40.0 SLOTS ALL PERFS IN L 112L2 WELLBORE:Alternating solid/slotted pipe- RPERF;6,834.0-6,839 0 1 0.125"x2.5"@ 4 circumferential adjacent rows, d staggered 18 ed 18 deg,3'non -slotted ends 5834.0 6,839.0 3,402.9 3,402.7 WS A2,1E- 7/28/2012 40.0 RPERF ALL PERFS IN 112 WELLBORE:Alternating solid/slotted pipe- 0.125"x2.5"@ 4 circumferential adjacent rows,3"centers staggered 18 deg,3'non -slotted ends rF Cement Squeezes Top(WD) Btm(WD) Top(ftKB) Btm(kKB) (ftKB) (kKB) Des Start Date Com 6,834.0 6,839.0 3,402.9 3,402.7 GEL SQZ 7/28/2012 t Notes:General&Safety I- End Date Annotation i 7/30/2004 NOTE:TRI-LATERAL WELL-1E-112(UNDULATING A-SAND)1E-112L1(B-SAND)1E-112L2(D-SAND) 4 3/1/2009 NOTE View Schematic w/Alaska Schematic9.0 { 7/28/2012 NOTE PROFILE MODIFICATION-PUMPED 2145LBS(4MM)CRYSTAL SEAL TO'D'MBE@6839 - t. i r F 4 SLOTS,6,536.0-11,240.0 1 E 1 i I 1- r 1 l 1- 1- g 1- i 1 4 4 1 4 F 1 I - }1 i 1 y 1 I- D-SAND LINER;5,839.4- 11,241.9 4 11,241.9--1 IT e e 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. ~ ÇJ y.. - 0 ç¡ 3 Well History File Identifier Organizing (done) D Two-sided 1111111111111111111 D Rescan Needed 111111111111111I111 RESCAN ¿color Items: o Greyscale Items: DIGITAL DATA OVERSIZED (Scannable) o Maps: o Other Items Scannable by a large Scanner o Diskettes, No. D Other, NOfType: o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: D logs of various kinds: NOTES: D Other:: BY: ~ Date q 1(p100 151 Project Proofing 111111111111111111I V\1P BY: ~ Datee¡ /C>/¡)~ ~ x 30 = to () Date 11 blOb 151 mp Scanning Preparation BY: l Maria J + ~ q = TOTAL PAGES <?q (Count does not include cover sheet) 151 YnP Production Scanning Stage 1 Page Count from Scanned File: q ð (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES Date:q! blób 1111111111111111111 NO Stage 1 If NO in stage 1, page(s) discrepancies were found: YES 151 Vvt f NO BY: ~ BY: Maria Date: 151 11I111111111111111I Scanning is complete at this point unless rescanning is required. ReScanned 111111111111111111I BY: Maria Date: 151 Comments about this file: Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page. doc L STATE OF ALASKA ALA" OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS 1 1. Operations Performed: Abandon r Repair w ell r Aug Perforations r Perforate r Other 17 MBE Seal P ull Tubing S - Frac Waiver Treatment Alter Casing r 9 r r r Time Extension r Change Approved Program r Operat. Shutdow n r Stimulate - Other r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r - 204 - 093 3. Address: 6. API Number: Stratigraphic r Service p P. O. Box 100360, Anchorage, Alaska 99510 , — 50 - 029 - 23211 - O 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25651, 25660 f 1 E - 112L2 .+ 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): — none Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 11273 feet Plugs (measured) None true vertical 3337 feet Junk (measured) None Effective Depth measured 6200 feet Packer (measured) 6777 true vertical 3485 feet (true vertucal) 3582 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 20 108 108 SURFACE 3001 13.375 3031 2309 INTERMEDIATE 5810 9.625 6926 3606 D -SAND LINER 5403 5.5 11242 3337 RECEIVED Perforation depth: Measured depth: 5902'- 5980'. 6536- 11240' AUG 2 2 2012 True Vertical Depth: 3423'- 3436', 3420' -3338' ;y,,44$'F- -, ; , .. D1?, AOGCC Tubing (size, grade, MD, and TVD) 4.5, L - 80, 5810 MD, 3403 TVD Packers & SSSV (type, MD, and TVD) PACKER - HRD ZXP LINER TOP PACKER @ 6777 MD and 3582 TVD NIPPLE - NIPPLE @ 476 MD and 476 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 6834' -6839' Treatment descriptions including volumes used and final pressure: 2145# of 4MM Mesh Crystal Seal 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation shut - Subsequent to operation shut - 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r Service 17 Stratigraphic r 16. Well Status after work: Oil r Gas r WDSPL r Daily Report of Well Operations XXX GSTOR r WINJ ]ri WAG r GINJ r SUSP r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -360 Contact John Peirce (a 265 -6471 Printed Name John Peirce Title Wells Engineer Signature Phone: 265 -6471 Date Q /21'1 Z. Cl ` RS ®MS AUG 2 3 2011 Submit Ori Inal Onl Form 10 -404 Revised 11/2011 , g y q�67( :t^' KUP • 1E -112L2 rat. ConocoPhillips ='; � Well Attributes Max Angle & MD TD Welibore API /UWI Field Name Well Status Inc' (°) MD (ftKB) Act Btm (RKB) Alaska. Inc 500292321161 WESTSAK INJ 95.96 6,415.94 11,273.0 Conoco lhaps Comment H2S (ppm) (Date Annotation End Date KB-Grd (R) Rig Release Date Well coma - 1E 201256 AM SSSV: NIPPLE Last WO: 31.19 7/31/2004 Schematic - A7(24ctual 1012 Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date -- -- - - -- -- - - - -- Last Tag Rev Reason: Set Plug, Iso Sleeve, & Diverter ninam 7/24/2012 HANGER. 22 — Casin Strut s Casing Description String 0... String ID ... Top (ftKB) Set Depth (r... Set Depth (TVD) ... String Wt... String . String Top Thrd CONDUCTOR, L _ _ D -SAND LINER 5 1/2 4.950 5,839.4 11,241.9 3,338.1 15.50 L -80 DC I ( Liner D etails 30108 TUBING, 76 ! Top Depth (TVD) Top Incl Noml... GAS LIFT. ( Top (ftKB) (RKB) ( °) Item Description Comment ID (in) 2,406 ' �r 5,839.4 3,410.2 75.50 HANGER 'BAKER MODEL B HOOK HANGER FOR LEM 7.000 SURFACE, 5,866.7 3,416.4 76.83 XO CROSSOVER 7' x 5.5" 5.000 30- 3,031 ----, GAS LIFT, Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) 5,320 Top Depth LOCATOR. SLEEVE, O (TVD) Top Incl R. 5,792 Top (ftKB) (ftKB) ( °) Description Comment Run Date ID (in) SEAL ASSY, 15 ' 5,845 3,411.5 75.77 DIVERTER TYPE 2 DIVERTER (OAL= 18.60') 7/20/2012 2.500 5,793 - \ DIVERTER. ,845 SLOTS, ' °'® Perforations & Slots 5,902 -5,980 Shot L1 LEM IIV Top (TVD) Btm (TVD) Dens 5,780-6,067 Top (ftKB) Btm (ftKB) (RKB) (ftKB) Zone Date Oh- - Type Comment NTERMEDIATE, 30 - 6,9 6 5,902 5,980 3,422.6 3,435.5 WS D, 1E -112L2 7/26/2004 40.0 SLOTS ALL PERFS IN WELLBORE: Z� Alternating solid/slotted pipe - .• •■ 0.125 "x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non - slotted ends 6,536 11,240 3,419.7 3,338.1 WS D, 1E -112L2 7/26/2004 40.0 SLOTS ALL PERFS IN WELLBORE: Altemating solid/slotted pipe - 0.125 "x2.5" @ 4 circumferential I adjacent rows, 3" centers staggered 18 deg, 3' non - slotted ends Notes: General & Safety End Date Annotation 7/30/2004 NOTE: TRI- LATERAL WELL - 1E -112 (UNDULATING A-SAND) 1E -112L1 (B -SAND) 1E -112L2 (D -SAND) 3/1/2009 NOTE: View Schematic w/ Alaska Schematic9.0 SLOTS, 6,536- 11,240 al 1 ii =i F „rll _-. 5. Mandrel Details Top Depth Top Port (TVD) Incl OD Valve Latch Size TRO Run Stn Top (MB) (ftKB) (°) Make Model (in) Sere Typo Type (in) (psi) Run Date Com... 1 2,408.4 2,018.9 62.78 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 1/6/2005 2 5,320.1 3,256.1 66.39 CAMCO KBG -2 1 GAS LIFT DMY BK 0.000 0.0 8/30/2005 13-SAND LINER, 5,839 - 11,242 TD (1E-112L2). 11,273 . Well Work Summary DATE SUMIMARYOPS • 7/17/12 Drive Coil Tubing Unit to 1E-1 tbom Deadhorse and perform BOP test. 7/18/12 Perform Fluff & Stuff down to 6,275' CTMD. Made second run to pull Type 2 Iso- Sleeve @5,826' MD (D -LEM). Freeze protected and secured well. Will return in am to set plug & Type 1 Iso - Sleeve (B- LEM) 7/19/12 Set plug in DB nipple @ 6,126' CTMD and complete second run to stab prong into plug. Will return in am to set Iso - Sleeve & Diverter. 7/20/12 Set Type 1 Iso- Sleeve @ 6,101 CTMD and set Type 2 Diverter in the D -LEM @ 5,845' CTMD. Successfully drifted back through Diverter into "D" Lateral. Well ready for Crystal Seal application. DSO notified well is ready to bring on -line. 7/28/12 PERFORATED LINER AT 6834' TO 6839' CTMD. OPENED CIRC SUB AND PUMPED 2145 POUNDS OF 4 MM MESH CRYSTAL SEAL INTO PERFORATIONS. WELL FREEZE PROTECTED. JOB COMPLETE. II' • • fl } r ' 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 John Peirce Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1E -112L2 Sundry Number: 311 -360 Dear Mr. Peirce: ` ,,,?*;PIr4t :13 : 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, 07 D aniel '. Seamount, Jr. Chair DATED this / to day of November, 2011. Encl. ' AgATE OF ALASKA XECEIVED ALASKA OIL ANalp CONSERVATION COMMISSION 3 ?Qll 1 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 *Aka tm & as Goys. Commission 1. Type of Request: Abandon r for Redrill r Perforate New Pool f Repair w ell RI Program r Suspend r:an:�t'`tir' 4' p r Rug Perforations � " Perforate r Pul Tubin r TirS�e tic #ension j` Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing r Other:MBE Seal Treatment i'' 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development C°`" Exploratory r 204 - 093 ° 3. Address: 6. API Number: ' Stratigraphic Service r • P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 23211 -61 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number:'f E� where ownership or landownership changes: D SAN t1 Spacing Exception Required? Yes r' No 1E - 112L2 , 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25651, 25660' Kuparuk River Field / West Sak Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11273 ' 3337 • 6200' 3485' Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 20 108' 108' SURFACE 3001 13.375 3031' 2309' INTERMEDIATE 5810 9.625 6926' 3606' D -SAND LINER 5403 5.5 11242' 3337' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5902 -5980, 6536- 11240' 3423 - 3436, 3420 - 3338' 4.5 L -80 5811 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - HRD ZXP LINER TOP PACKER MD =6777 TVD= 3482 NIPPLE - MD =476 TVD =476 12. Attachments: Description Summary of Proposal IV 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch ("" Exploratory Development Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 12'/9/2011 Oil r Gas r WDSPL " Suspended r 16. Verbal Approval: Date: WINJ 17 • 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: John Peirce © 265 -6471 Printed Name John Peirce Title: Wells Engineer Signature 7 i ► , Phone: 265-6471 Date 114»� Commission Use Only iii Sundry Numbe 1 t 6 Conditions of approval: Notify Commission so that a representative may witness �v Plug Integrity BOP Test Mechanical Integrity Test Location Clearance 9 9 Y � r 9 tY r r Other: Subsequent Form Required: /0 L ( 0 t APPROVED BY ' ///6/1 Approved by: ' - f � V �7 1 O`I 2 COMMISSIONER THE COMMISSION Date: 1 Y t ORIGINAL.. g� °' Form 10 -403 Revised 1/2010 / /�/6 °� Submit in Duplicate /..< ,,ti -_.A\ OP •E -112L2 twOnO OPhillip5 4 Well Attributes Max 1 Angle & MD TD Alaska, Inc ` W Ilbore APUUWI IF. Id Name 711 Status I lncl r) IMO(ftKB) Act Btm (1166) � I L I Le +ticaF416hs'�1 500292321161 WEST INJ 9596 6,415.94 11.2/3.0 ___ Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date •.• 1]: 1t ;2>? rtq,74-2.53;3a PM SSSV NIPPLE Last WO: 3119 _ Well gonSg 7/31/2004 "S ; nqy" 1 Annotation Depth (ftK8) End Date AnnotaL _ � _ Last Mod. End Date Last Tag I I Rev Reason: Pull ISO SLV, set Type 21S0 SLV Imosbor 1 1/27/2010 Casing Strings i Casing Description String 0... String ID Top (ftK8) Set Depth (f Set Depth (TVD) .. Str ng Wt... Str g String Top Thrd D SAND LINER 51/2 L 4950 I 5,8394 11,241 9 3,3381 l 1550 I L I DWC CONDUCTOR, - - - 3o -1W Liner Details TUBING, 76 ' 'Top Depth -- _ - -- NW ; (TVD) Top Intl Nomi... GAS LIFT, _ Top (ftKB) (668) (7 Item Description Comment ID (in) 2 ' 5,839.4 3,410.2 75.50 HANGER BAKER MODEL B HOOK HANGER FOR LEM 7.000 il, SURFACE, 5,866.7 3,416.4 76.83 X0 CROSSOVER T x 5.5" 5.000 30-3,031 ...:: GAS LIFT, ' �6' ' • Perforations & Slots _. ._. 6.320 'sYm -- -- --- -snot i Top (TVD) Btm (TVD) Dens SLEEVE, 5,370 Top (ftKB) Btm (ftK8) (ftK8) (ftK8) Zone Date (nh... Type Comment WM SLEEVE. 5,780 5,902 5,980 3,422.6 3,435.5 WS D, 1E-112L2 7/26/2004 40.0 SLOTS ALL PERFS IN WELLBORE: LOCATOR, ' a Alternating solid /slotted pipe - 5.792 0.125 "x2.5" @ 4 circumferential SEAL ASSY, r -• „ adjacent rows, 3" centers staggered 5,793 SLOTS, 18 deg, 3' non - slotted ends 5,902 - 5,980 57eo LEM, ti 6,536 11,240 3,419.7 3,338.1 WS D, 1E -112L2 7/26/2004 40.0 SLOTS ALL PERFS IN WELLBORE: L2 LEM, Alternating solid /slotted pipe - 5,738 - 6,822 0.125 "x2.5" @ 4 circumferential TERMS adjacent rows, 3" centers staggered 30 - 6,926 - 6,926 I 18 deg, 3' non - slotted ends - R ' Notes: General & Safety I ! End Date Annotation _- 7/30/2004 NOTE RI-LATERAL WELL- 1E -112 (UNDULATING A- SAND) 1E -112L1 (B -SAND) 1E -11212 (D -SAND) 3/1/2009 NOTE: VIEW SCHEMATIC w,Alaska Schematic9.0 LOT —__ 6 536 -11 240 Mandrel Details Top Depth Top Port (TVD) Inc/ OD Valve Latch Ole. TRO Run .» Stn To. Si 0 (°) Make Model (in) Sete Type Type (in) (psi) Run Date Corn... ,.,, 111 2,408.4 2,018.9 62.78 CAMCO KBG-2 1 GAS LIFT DMY ___ BK 0.000 - 0.0 1/6/2005 5,320.1 3,256.1 66.39 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 8/30/2005 0-SAND LINER, 5,839-11,242 ... , TD (16- 11212), 11,273 -- --. • • ti 1E-112L2 to 1E-166L2 MBE Treatment • A matrix bypass event (MBE) was identified in 1E-112L2 with an IPROF on 8/20/09 in the 'heel' , of the lateral at —7000' RKB behind 5.5" slotted liner. Most PWI appears to exiting the slotted liner at this MBE. Per this proposed procedure, the MBE will be sealed with Crystal Seal. CrystalSeal is a Halliburton product intended for treating injector wells to restore water flood sweep efficiency by remediating direct communication paths through formation to offset producers. CrystalSeal is water swellable dehydrated crosslinked synthetic polymer gel available in various granular mesh sizes. CrystalSeal can swell to 400 times original size by absorbing water. Due to the swellability of CrystalSeal, it is used to fill highly conductive large voids or channels (MBE's) that dominate taking injection. Procedure: Coil Tubing 1) Pull Isolation Sleeve from the D LEM at 5780' MD. 2) Set a Diverter in the D LEM at 5780' MD to enable access to 1 E -112L2 lateral. 3) RIH with BHA on 2 "coil tubing consisting from bottom to top of 5' OAL x 2.75" OD TCP Perf Gun, a 2 -1/8" OD closed Circ -Sub, and hydraulic disconnect. Park perf gun to fire 6 spf large hole charges at 6981 - 6986' RKB in the 5.5" slotted liner just above the MBE at —7000' MD. v Drop ball to fire the gun, then RIH 5' with coil to spot the Circ -Sub over the perf interval. Drop ball #2 to shift Circ -Sub open, then pump Crystal Seal through the Circ -Sub and perfs to seal the MBE. Pump: a) Seawater Pad down coil. Maintain 2.0 bpm rate during treatment through Flush (step g) to monitor treating pressures at constant rate. Swap from Seawater to 2% KCI and pump, b) 2% KCI Water with 0.05 ppg CrystalSeal (will use 4 mm mesh for all stages) down coil. Each stage volume will be decided during pumping based on treating pressure seen during the stage. c) 2% KCI Water w /0.10 ppg CrystalSeal down CT, or Flush (step g) should we see screen out. d) 2% KCI Water w /0.15 ppg CrystalSeal down CT, or Flush should we see screen out. e) 2% KCI Water w /0.20 ppg CrystalSeal down CT, or Flush should we see screen out. f) 2% KCI Water w/0.25 ppg CrystalSeal down CT, or Flush should we see screen out. g) If screenout occurs, open CT x Tbg annulus to return tank, and pump 1 CT volume of Seawater Flush to displace Crystal Seal slurry from coil into well while POOH. If screenout has not been seen prior to Flush, leave CT x Tbg annulus shut -in and pump 1 full CT volume of Seawater Flush to displace Crystal Seal Slurry from coil to MBE while POOH with CT to D LEM, then swap to 53 bbls of Diesel FP down coil, followed by 1 CT volume of Diesel ( -40 bbls) to FP CT and displace Diesel FP to tubing, followed by SD. RD CTU. Wait 6 hrs before returning 1 E -112L2 to PWI for post- treatment injectivity evaluation. STATE OF ALASKA • ALASKA O~AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Set D sd Iso Slv ~. Operations Performed: Abandon ~ Repair well ~ Plug Perforations ~ Stirrwlate [? Other ~ After Casing ~ Pull Tubing [ Perforate New Fool ^ Waiver ~ Time Extension ~ j Change Approved Program ^ Operat. Shutdow n ~ Pt;rforate ^ Re-enter uspended Well 1 2. Operator Name: 4. Current Well Status: .Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ Exploratory ^ 204-093 3. Address: Stratigraphic [~ Service Q .API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23211-61 7. Pro~ty De~nation: 8. Well Name and umber: ALK 25651 & 25660, ADL 469 & 470 1 E-112L2 9. Field/Pool(s)' Kuparuk River Field /West Sak Oil Pool 10. Present Well Condition Summary: ~- ~~ 2 2 2010 Total Depth measured ~ 11273 feet Plugs (measured) A~8Sk8t ~8~t Cerra. COthNS$10 true vertical ~ 3337 feet Junk (measured) None Anchorage Effective Depth measured 11242 feet Packer (measured) 5793 true vertical 3338 feet (true vertucal) 3399 Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 20 108 108 0 0 SURFACE 3001 13.375 3031 2309 0 0 INTERMEDIATE 5810 9.625 5840 3606 - - -0- -. -- - 0 D-SAND LINER 5403 9.625 11242 3338 0 0 Perforation depth: Measured depth: 5902-5980; 6536-11240 x~,; t~_;y ~ ~ ~ ri, ~ ~ ~ j `'"`"''°' " True Vertical Depth: 3423-3436; 3420-3338 ' ' `'' Tubing (size, grade, MD, and TVD) 4.5, L-80, 5811 MD, 3403 TVD Packers & SSSV (type, MD, and TVD) SEAL ASSY -BAKER SBE SEAL ASSEMBLY @ 5793 MD and 3399 TVD ~- . SSV =NIPPLE. @ 476 MD and 476 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 1811 426 145 Subsequent to operation 1163 310 257 13. Attachments .Well Class after proposed work: Copies of Logs and Surveys run Exploratory r Development r Service . Well Status after work: Oil r Gas ~ _; WDSPL Daily Report of Well Operations X GSTOR ~ WAG ~ GASINJ ~ WINJ ~ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt NIA Contact Bob Christensen/Darrell Humphrey Printed Nam Robert D. C istensen title Production Engineering Specialist Signature Phone: 659-7535 Date~~l~ Form 10-404 Revised 7/2009 RBDMS FEB 2.31010 ~~ z . ~. 3 •i ~ ; ~; ~~~,;~, <<` Submit Original Only • • 1 E-112L2 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 01/21/10 SET TYPE 2 ISO SLEEVE @ 5780' RKB ISOLATING THE D LATERAL. TURNED WELL OVER TO DSO. JOB COMPLETE. SLEEVE INFO: (INJECTION SLEEVE W/SIDE PORTS BLANKED, 19' LONG, 3.688" OD, 2.59" ID) ConocoPhillips Aldsk.t Ins, HANGER, TUBING, 76 GAS LIFT. 2,408 SURFACE, 30-3,03[ GAS LIFT, 5,320 SLEEVE, 5,3]0 6LEEVE. 5,780 LOCATOR, 6,792 SEAL ASSV, 5,]93 sLOrs, sLOrs, 6,536-11,240 r KUP ~ 1 E-112L2 Attributes x An le & MD TD Wellbore API/UWI Field Name Well ShNs Incl (°) 500292321161 WEST SAK INJ 95.96 MD (ftKB) 6,415.94 Act Btm (HKB) 11,273.0 Comment H2S (ppm) SSSV: NIPPLE Data Annotation End Dale Last WO: KB-Grd (ft) 31.19 Rig Raleasa Date 7/31/2004 Annotation last Tag Depth (ftKB) Entl Date Annotation Rev Reason: Pull ISO SLV, set Type 2 ISO SLV Lest Motl ... Imosbor End Date 1/27/2010 Casin Strin s Casing Descripton String 0... Slring ID ... Top (ftKB) Sal Depth (t... Set DepN (TVD) ... String Wt... String ... String Top Thrd 0.SAND LINER 51/2 4.950 5,839.4 11,241.9 3,338.1 15.50 L-80 DWC Liner Details Top (RKB) Top Depth (TVD) (RKB) Top Incl (°) I tem Description Comment Nomi... ID (in) 5,839.4 3,410.2 75.50 H ANGER BAKER MODEL B-1 HOOK HANGER FOR LEM 7.000 5,866.7 3,416.4 76.83 X O CROSSOVER T' x 5.5" 5.000 Pertoratlons & Slots Top (RNB) etm (RKB) Top (TVD) (RKB) Btm (TVD) (RKB) Zone Dete Shot Dana (sh... Type Comment 5,902 5,980 3,422.6 3,435.5 WS D, 1E-112L2 7/26/2004 40.0 SLOTS ALL PERFS IN WELLBORE: Alternating solidlslotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends 6,536 11,240 3,419. 7 3,338.1 WS D, 1E-112L2 7/26/2004 40.0 SLOTS ALL PERFS IN WELLBORE: Alternating solid/slotted pipe- 0.125"x2.5" @ 4 dreumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends Notes: General 8r Safe End Date Annotation 7130/2004 NOTE: TRI-LATERAL WELL - 1 E-112 (UNDULATING A-SAND) t E-112L1 (B-SAND) 1 E-112L2 (0.SAND) 3/1/2009 NOTE: VIEW SCHEMATIC wlAlaska Schematic9.0 Mandrel Details Stn Top (itKB) Top Depth (TVD) (RKB) Top Incl (°) Meka Motlel OD Ilnl Sarv Valve Type Latch Type Port Size lint TRO Run (pal) Run Data Com... 1 2,406.4 2,018.9 62.78 CAMCO K BG2 1 GAS LIFT DMY BK 0.000 0,0 1/6/2005 2 5,320.1 3,256.1 66.39 CAMCO K BG2 1 GAS LIFT DMY BK 0.000 0.0 8/30/2005 D-6AN0 I LINER, 5,839-11 242 TD (1 E-112L2), 11,273 • f • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Pertormed: Abandon ^ Repair Wel) ^ Plug Perforations ~ Stimulate ~ Other Q pulled D sand Alter Casing ^ Pull Tubing ^ Perforate New Poo1 ~ Waiver ^ Time E~ension ^ isoiation sleeve Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: . Permit to Drill Number: ConoCOPhillips Alaska, Inc. Development ^ Exploratory ^ 204-093 3. Address: Stratigraphic ^ Service ~^ API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-029-23211-61 KB Elevation (ft): . Well Name and Number: 95' ~~'11 + 13 1 E-112L2 . Property Designation: Field/Pool(s): ALK 25651 & 25660, ADL 469 & 470 Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth ~ measured ~• 11273' feet ~ ~ true vertical P~ ~~~~e~ feet Plugs (measured) None 33 Effective Depth measured 6200' feet Junk (measured) true vertical 3485' feet Casing Length Size MD ND Burst Collapse CONDUCTOR 108' 20" 108' 108' SURFACE 2936' 13-3/8" 3031' 2309' INTERMEDIATE 6831' 9-5/8" 6926' 3606' D-SAND SLOTTE 5403' S-1/2" 11242' 3337' Perforation depth: Measured depth: 5902- 5980, 6536- 11240 { j', ,: n!!? ,,~ `~ ~ ~~~:~,~~~~. , . . , x ~ ~G~~~ true vertical depth: 3443-3436; 3420-3338 Tubing (size, grade, and measured depth) 4-1/2" , L-80, 6822' MD. Packers & SSSV (rype & measured depth) PKR = ZXP Liner Top Packers KR= 5780' 6038', 6777', and 10 constrictor packers to isolate shales SSSV= NIP SSSV= 508' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 1569 715 140 Subsequent to operation 1616 769 1 14. Attachments . Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ~^ Daily Report of Well Operations X . Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ ^~ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.o. Exempt: N/A contact B. Christensen/ D. Humphrey Printed Name o t Chris e en Title Production Engineering Specialist Signature Phone: 659-7535 Date ~` ~ ~ ~ Form 10-404 Revised 04/2004 ~ R8 ~o~ 1 3 L~~ i~~/•~L'~ Submit Original Only ~ • 1 E-112L2 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary PULLED TYPE 2 ISO SLEEVE FROM D-LEM 5835 CTMD, PULLED TYPE 1 DIVERTOR FROM B-LEM @ 6105, ATTEMPT TO RUN TYPE 1 ISO SLEEVE FOR B-LEM, UNABLE TO PASS THROUGH D-LEM @ 5835 CTMD, SENT ISO BACK TO BAKER FOR FURTHER INSPECTIONS, RTN IN A.M. TO ISOLATE B-LATERAL. WELL IS FREEZE PROTECTED. I .-, Cor~ocoPhillips :Vif~SM:~. IIX; ••• Wal MIINGER, 22 GAS LIFT, 5.32~ SLEEVE,5,370 LOCATOR, 5.792 SEALASSY, 5.793 L2 Wintlow, 5.841-S.BW L2 LEM, KUP ~ 1 E-112 IEOra APIIUWI Fieltl Name ~ Wall SfaN~ Incl ~°) MD ~RNB) Act Btm ~ftKB) 500292321100 WESTSAK INJ 93.83 7,537.96 17,425.0 imant M23 (ppm) DaEe Mnotatlon EnU Data NB-0M ~h) Rig Releasa Dal iV: NIPPLE Last WO: 31.19 7/31/2004 Last Tag I r ~ I~ ~~ I Rev Reason: Set ISO SLV &Lat, Pull DLat ISO SLV I` Imosbor I 1029Y2009 Casing Dexriptlon 34Inp 0... Strlnp ID ... Top (Po(B) Set Dapt~ ~f... Set UepN ~TVU) ... Strlnp Wt... Striny ... 341np Top T~M CONDUCTOR 20 19.124 30.0 108.0 108.0 94.00 K-SS WEIDED Casing Oe~crlptlon Strinp 0... Strlnp ID ... Top (Po(B) Sat Dspth ~f... Sat Dept~ (TVO) ... Strlnp Wt... String ... String Top T~M SURFACE 133/8 12.415 29.8 3,031.0 2,303.7 68.00 L-80 BTC Casinp Oescriptlon Strinp 0... Strlnp ID ... 7op ((tKB~ Set Dept~ (f... Sat Dept~ ~TVD) ... 3lrlnp Wt... 3tring ... String Top T~rE INTERMEDIATE 9 S~8 8.697 29.7 6,926.0 3,603.3 40.00 1-80 BTC-M Casing Descriptlon Strlnp 0... String ID ... Top ~HXB) Sat Dept~ ~f... Set Depth ~TVD) ... String Wt... Strlnp ... String Top T~N ~z w~,doW s sa a.oaa s,ana.o s,aso.o s,aiz.s ao.oo ~-so Casing Dascriptlon Strinp 0... Strlnp iD ... Top ~Po(8) Set DepM (f... Set Depth ~TVD) ... Sding Wt... Slrlnp ... String Top ThM L1 Window 95~8 8.000 6,096.0 6,112.0 3,4702 40.00 L-80 Casinp Descriptlon Strlnp 0... Strlnp ID ... Top ~Po(8~ Sat Dapt~ (f... Set Dept~ ~iVD) ... Strlnq Wt.. Strinp ... Strinp Top T~rE ASAND LWER 5 1/2 4.950 6J76.6 11297.5 3.6022 15.50 L-80 DWC IL1 LEM---' r--" I--4 1l2 I"'3.958...I 5.738.4 I 6.822.4... I-"-3.589.1 V,... I~..12.60...I ,L-80.. I_~..."IBT ...~ I io IBT 70137 Sl( 7.7598 Inc Comment 5,839-i1 B-SAND LINER, 6.W0-11.252 Top (Itl(B) ~"^°~ 1'1 De~crlptlon Commen[ Run Dafe ID ~In) 7,014 3,616.0 84.78 Constrictor ASAND LINER 10 CONSTRICTOR PACKERS set TO 7/9/2004 5.963 PKR ISOLATE SHALES FROM SAND, @ 7014', 7538', 7758', 8368', 9074', 9584'. 9950', 10370'. 10648'. 11215' Btm '~.ng solidslotted pipe - ?.5' @ 4 dreumferential 1 rows. 3' centers sta9gered 3' non-slotted ends I I ^ MSANO I I LINER, 8.717-11,298 ~ TD (1 E-112). 17.~25 IStnlTop~ttNB)I ~R B) I II`) I Maka I MoCel I O) I Serv I Type I Type IS~~) ITRP.Runl RunDate ICOm...l ~ Conoco`Phillips , AI:~Sic.~. If F, NIPPIE,]6 SURFACE. 303,031 OAS LIFT, 3,219 GAS LIFT, 5,320 SIEEVE,5,370 Fisn, ~,sis SLOTS. Q131 ~11.1 ]6 PERF S~Z. 9,005 PLUG, 9,098 KUP all Attributes IboreAPl/UWI FiBIEN 500292321160 WES1 ent iV:NIPPLE 1 E-112L1 ._..._._.._.. ....,_ ......... ........_.~ ....~,....~„~~ ~...~~,...... ~~~..,...o Last Tag Rev Reason: Set ISO SLV &Lat, Pull 0.Lat ISO SLV Imasbor 1029/2009 CeSin $trin 8 Casing DescripHOn String 0... Slrlnp 10 ... Top (ftlt8) Sat Dap!h (f... Set Deplh ~TVD~ ... String Wt... Shing ... Strinp Top T~rtl BSAND LINER 5 1/2 4.950 6,094.0 11,252.0 3,410.4 15.50 L-80 DWC Liner Details Top Dept~ ~TVD~ Top Incl 7op (ftl(B) (RKB) (°) Ibm Oe~crlption Commenl ID Ilnl 7op (Itl(6) ~~~^~~ ~"~ Descriptlon Comment Run Dafe ID ~in~ 6,094 3,467.4 79.72 SLEEVE ISO SLEEVE SET IN 8-SAND LEM 10/26/2009 6.000 7,815 3,4362 88.81 FISH LOST 3 CENTRALIZE ARMS FROM MEMORY LOGGING 8/14/2009 0.050 TOOL IN BSAND LEM ~~ng soliNslotted qpe - ?.5" @ 4 dreumfereMial ~ rows, 3" centers staggered 3' non-slotted ends Run 9-SAND LINER, 8,03/-11,252 TD (1 E-111L1), 11.285 .~ ~OIlOCO~'ll~~lp5 eil Attributes ~ ~ .~~~~~~~..~. KUP Ai i,,k ~ ~n, weucore naiiuwi F~eia n 1 E-112L2 ~Last TaS] ~ ~ ~Rev Reason: Set ISO SLV &Lat, Pull 0.Lat ISO SLV ~ ImaSbor ~ 10/29/2009 ~ NIPPLE, ]6 SURFAGE. 30-3 031 GAS LIFT, 3,219 Comment SLDiS, 6.536~11,240 Valw i" @ 4 CifCUm(CfCMl81 ~ws, 3" centers staggered non-slotted ends t rows, 3" centers staggered 3' rwn-slotted ends Run Data I Com... O SANO I LINER, 5,8~-11 207 TD(1E-11712~, 11,7~3 Tubing SVing 4-1/2" 12.6#, L-80, IBTM 3.958" ID, 3.833" Drift 507' MD - DB Nipple, 3.875" Profile 2,400' MD - GLM, Camco 1" KBG-2 13-3/8" \ Casing Shoe, 68#, L-80, BTC set @ 3,031' MD, 2,309' ND 5,780' MD - 7" X 9•5/8" ZXP Liner Top Packer 5,835' MD - 7" X 9-5/8" Mode1 'B-1' HOOK Hanaer 6,038' MD - 7" X 9-5/8" Liner Top Packer Lateral Entrv Module (LEMI Assemblv ~__ 7" X 9S18" ZXP Llner Top Packar with HolO Downs 7.500" Tiaback Ert. ID 6.278" Tool Body ID ~~ Casiny Saalbore Rauptacle 4.75" ID, 5.75" OD 15' Lanpth TuDiny Swiwl, 4'll2" Oriantinp ProTile Automatlc Allynmant ot LEM Poskiw Latohiny Collat Indieatas Comct Location ~ ~~ Bore ~o~ ~~~~ laolation - 3.68" ID ~ Access Wlntlow Posltiva Labnl Accass Vla Thru-Tubiny Divarter Seal Bore for Latanl Isolation - 3.68" ID ~ laolation Saal Asambly 4.76" Seal OD 3.875" Seal ID 12' Lanyth 5,803' MD - Casing Sealbore Receptacle ConocoPhillips West Sak 9-5/8" Injector 1E-112 Tri-Lateral Completion s,aso' MD - Lateral Entry Module (LEM) 'D' Sand Lateral D-sand Casing Exit / at 5,841' MD , 5-1/2" 15.5#, L-80 Slotted Liner 6,058' MD - Casing Sealbore Receptacle 6,094' MD - 7" X 9-518" alodel 'B-1' HOOK Hanaer 6,126' MD - 3.562" DB Nipple 5-1/2" Casing Shoe, 15.5#, L-80 DWC Set @ 11,253' MD r~ X 9-5/8^ zxP ~ 'A' Sand Undulating Lateral Liner Top Packer 7" X 9-5/8•• Liner Hanger / Packer Flex Lock 5-1/2" 15.5#, L-80 Assembly Liner Hanger Slotte Liner set @ s,ns~ nn~ 5-1/2" Casing Shoe, 6,807' MD - Casing Sealbore __ 15.5#, L-80 DWC Receptacle Set @ 11,296' MD Confidential 9-~~8~~ Casing Shoe, e,e.~ Huon.s zow. rni. e«~m.m ~y o« w r.Proa~~w o~ m:~ne~ew, in wna. or i~ p.n. i~ .~y io~ or 4~.~#, L-80 BTC °"° ""': ~ e-»: -Te~.,r c~pai~ -i~~.ao~ byanymunssNCtmnfcwm~chanlW.InUu41n9PhaoeoPN~Y.~oMlnp.orEyanylnlortnatlonstoray~ Ce` ~ C'~^C~ ~D Myrc0.KUek a~W rNrlovd sys~am now tnown or hareaMr Imanted. wlt~out wrlttm p~~mlaslon Irom Bat~r Huyh~s Inc. J ~ p LO ~•: a""" sY ~~~ i 5,320' MD - GLM, Camco 1" KBG-2 ~ 5,369' MD - CMU Sliding Sleeve, w/ 3.81" DB Profile 5-1/2" Casing Shoe, 15.5#, L-80 DWC Set @ 11,238' MD 6,086' MD - Lateral Entry ~ Module (LEM) 'B' Sand Lateral Bsand Casing Exit Final As Completed M~ Es Baker Oil Tools Lateral Entrv Module (LEM1 With Diverters and Isolation Lateral Access Diverter l-~tenl laolatlon DIwrW GS Runninp Tod Strinp ~~+~ ~ ~^s~+~ 'GS' Profileiw ~p~ C~~~ ! RunninplRetriavirq ti (1.00' ~ength) Snap InlSn+P Out Bxk Pressure Valve / PosiOw LocaCnpti caw ~~.eo• ~e~qm~ e ~ i a n -' r Fbw-TNU Svivel um~ . . o~ ~yi (1.25 LenyM) Hydnulic ! Labral DiwrOw Ramp IaolaOONMainbaa~ ( ~ ~~~) Divertar Sleew ~ GS Spear ~~ ~ (~.so~ ~erqm) ~rxd ~sownon ~ 6.85 tt Approx. OAL' 'Jara may be requiretl in hiphly Aeviatatl or dcep app~iwtions (6' approx kvqM). ~ at 6,095 , 85 deg inclination 5-1/2" 15.5#, L-80 Slotted liner ~~ ~ • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ~. Operations Pertormed: Abandon ^ Repair Well ^ Plug Perforations ~ Stimulate ^ Other ~^ Set ~ sand Alter Casing ^ Pull Tubing ^ Perforate New Pool ~ Waiver ^ Time Extension ^ ~solation Sleeve Change Approved Program ^ Operat. Shutdown^ Perforate ~ Re-enter~~uspended Well ^ 2. Operator Name: 4. Current Well Status: '~, Permit to Drill Number: ConoCOPhilllps Alaska, InC. Development ^ Exploratory ^ 204-093 3. Address: Stratigraphic ^ Service ~^ . API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23211-61 7. KB Elevation (ft): Well Name and Number. RKB 95' 1 E-112L2 8. Prop't~~ty De ' nation: 10. Field/Pool(s): ALK 25651 & 25660, ADL 469 & 470 Kuparuk River Field / West Sak Oii Pool 11. Present Weil Condition Summary: ~ Total Depth measured ~ 11273' feet ' \ feet Plugs (measured) true vertical 3337 Effective Depth measured 6200' feet Junk (measured) true vertical 3485' feet Casing Length Size MD ND Burst Collapse CONDUCTOR 108' 20" 108~ 108' SURFACE 2936' 13-3/8" 3031' 2309' INTERMEDIATE 6831' 9-5/8" 6926' 3606' D-SAND SLOTTE 5403' 5-1/2" 11242' 3337' Perforation depth: Measured depth: 5902- 5980, 6536- 11240 ~'~'~~~~~ '~'~'' `} ~'? G ~~~~ trueverticaldepth: 3443-3436; 3420-3338 Tubing (size, grade, and measured depth) 4-1/2" , L-80, 6822' MD. ~pr ~vK~Q Packers & SSSV (type & measured depth) PKR = ZXP Liner Top Packers KR= 5780' 6038', 6777', and 10 constrictor packers to isolate shales SSSV= NIP SSSV= 508' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 117 734 Subsequent to operation 574 1 14. Attachments 1 Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service 0 Daily Report of Well Operations X . Well Status after proposed work: Oil^ Gas^ WAG^ GINJ^ WINJ 0 WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A contact B. Christensen/ D. Humphrey Printed Name R rt . hrist Title Production Engineering Specialist Signature phone:659-7535 Date ~~ ~3 ~ ~' ~ ~Y1.5 f ~ ~ /a./~.o~ Form 10-404 Revised 04/2004 Submit Original Only • • 1E-112L2 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 09/28/09 PULLED TYPE 2 DIVERTOR FROM D-LEM @ 5847 CTMD, INSTALLED TYPE 2 ISO SLEEVE IN D-LEM @ 5847 CTMD, WELL IS FREEZE PROTECTED, TURNED OVER TO DSO. , Cor~ocoPhillips AI:~Sk,f. I~ w: KUP ~ 1 E-112L2 IboraAPllUWI FIeltlName WeIIShNs Incl(°) MD(ftl(B) Ac[Blm(ttNB~ 500292321161 WESTSAK INJ 95.96 6,415.94 11,273.0 ment H73 (ppm) Dab Mnotation Entl Oa4 K813r0 (fl) Rlg Release Oat SV: NIPPLE ~ast W0: 31.19 7/31/2004 otation DepN (Itl(8) En0 Date Mnotatbn La~t Motl By Entl Uata ~d Tag Rev Reason: Pull Diverter, Set ISO SLV in L2 Imosbor 9/30I2009 NIPPLE. ]6 \~ I ~ "_...e _'__""' suaFnce. 0.SAND LINER csii°:'. Liner Detail. 3,279 Top 0 GAS LIFT, (TV 5.320 ToP (~g) ~RN EEVE,5.370 ~ocnroR, 5,839.4 3,4 5.~92 SEALASSV, S,SBG.~ 3~4 Date SLOTS, 6,53fi-11,240 Altemating solid/slotted pipe - 0.125"x2.5" @ 4 circumferential adjacent rows. 3" centers staggered 18 deg, 3' non-slotted ends 6,536 11,240 3,419.7 3,338.1 WS D, 1E-112L2 7Y262004 40.0 SLOTS ALL PERFS IN WELLBORE: Altemating solid/slotted pipe - 0.125"~.5" @ 4 circumferential adjacent rows, 3" centers staggered 18 deg, 3' non-slotted ends IStn I7op ~ItKB~ I lRK I I 1°) I Make I MoCet I O 1 I Serv I TYPa I T Pa I ~~^) IT (D lun I Run Date I Com... I D-SANO I LINER 5,839-11 2s2 ~ TD (1 E~117L7) 11,2~3 Tubing String 4-1/2" 12.6#, L-80, IBTM 3.958" ID, 3.833" Drift 13-3/8" Casing Shoe, - - 68#, L-80, ' BTC set @ 3,031' MD, r O 2,309' ND ~ ~f0 f ~ 5,780' MD - X 9-5/8" ZXP Liner Qk~ Top Packer 507' MD - DB Nipple, 3.875" Profile 2,400' MD - GL•M, Camco 1" KBG-2 5,320' MD - GLM, Camco 1" KBG-2 ~ 5,369' MD - CMU Sliding Sleeve, w/ 3.81" DB Profile 5,803' MD - Casing Sealbore Receptacle s,aso' MD - Lateral Entry Mqdule (LEM) 'D' Sand Lateral D-sand Casing Exit ~ at 5,847' MD , 5-1/2" 15.5#, L-80 Slotted Liner 5,835' MD - 7" X 9-5/8" Model 'B-1' HOOK Hanqer 6,038' MD - 7" X 9-5/8" Liner Top Packer Assemblv 7" X 9S18" 2XP Liner Top Packer with Nold Down6 7.500" Tiehack Ext. ID 6.278" Tool Body ID ~- Casing Sealbore Recaptaele 4.75" ID, 5.75" OD I 75' Lenqth Tubing Swivel, 4-t12" ~ Orienting Protile Automatic Alignment of LEM Positive Latchiny Collet . InCiqtes Correct Location ~ Seal Bore for Latenl ~ Isolation -3.66" ID Access Window ` Positive Lateral Accass Vla ~ Thru-Tubing Diverter Seal Bore for Latenl IsoWtion - 3.68" ID ~ Isolation Seal Asembly 4.75" Seal OD 3.875" Seal ID ~2' Length 6,058' MD - Casing Sealbore Receptacle 6,094' MD - 7" X 9S/8" ~{jgl 'B-1' HOOK Hanaer ConocoPhillips West Sak 9-5/8" Injector 1E-112 Tri-Lateral Completion 5-1/2" Casing Shoe, 15.5#, L-80 DWC Set @ 11,238' MD 6,086' MD - Lateral Entry ' Module (LEM) B-sand Casing Exit at 6,095', 85 deg inclination 6,126' MD - 3.562" DB Nipple 7" X 9-5/8" ZXP ~ ~ Liner Top Packer 7" X 9-5/8•• Liner Hanger / Packer Flex Lock Assembly Liner Hanger set @ 6,776' MD / 6,807' MD - Casing Sealbore Confidential Receptacle Baker MuqhK I003. Tl~ls dxument maynot ba np~otlucatl or tllstrlbu~atl, In whola or In part, in any }orm or byany muns aledronlc or mx~anlul, Inclutlln9 P~otxopyln9~ recortllnp, or by any Informa[lon storoqa .oe re~~.~v:y:~.m ~ow mo..~ o~ n.re,n.r iow.~~.a,.imo~e w~m.~ wrmi::ioo n~ a.e.~ H~on.: i~o. 'B' Sand Lateral Final As Com pleted M~{JGfiR ES Baker Oil Tools Lateral Entry M With Diverters odule (LEM1 and Isolation Lateral Access Diverter Lamnl Isolation DiverOer GS Running Tod String Insta4ed Installetl 'GS' Profile for Coil Connector ~ Running/Retrievirg ~ (1.00'Length~ Snap INSnap Out ~-BxkPressureValve /POSiOVeLocatingti ~~.eo~ ~ensm) caae Laterel hdation ~~ r Fbw-Thru Svivel ~ys (7.25 Length) , Hydnulic J Lateral Diverter Ramp r Disconnect IsolaCON Mainbore~ (1.50' LenOth) Divartar Slceve ~~ GS Spear ~ (1.50' Length) lamrel Isolatlon ~~ ~ 6.85 tt Appro~c OAL' 'Jars may be requi~ed in highly deviafed ~ or tlmp appli~anons (6' approx knglli). ~ 15.5#, L-80 Slotted Liner 5-1/2" Casing Shoe, 15.5#, L-80 DWC Set @ 11,253' MD 'A' Sand Undulating Lateral 5-1/2" 15.5#, L-80 Slotte~l Liner 9-5/8" Casing Shoe, 40.0#, L-80 BTC Set CD_ 6.926' MD 5-1/2" Casing Shoe, 15.5#, L-80 DWC Set @ 11,296' MD 1 E.113 . Trlaatenl Completlon - w.w~ er: Marc D. Ku<k ~ i i I/~/~"LL LQ~' T,RAN~M/~'T'.~L • To: AOGCC Christine Mahnken ~33 West 7th Qvenue Suite 100 Anchorage, Alaska 99501 (907) 659-5102 RE : Cased Hole/Open Hole/Mechanical Logs and/orTubing Inspection(Caliper/ MTT] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the foltowing : BP E~loration (Alaska), Inc. Pe~trotechnical Data Center Attn: Joe Lastufka LR2-1 9f~ Benson Bhrd. Anchorage, Alaska 99508 and ,gqq~,'q V 4 L~VJ 2w ~..3! ~L% ~ff 1GWF~YP'~ ~~~J ~~~ Q .1. ~ ~ ~ c ~o~l - o~ 3 ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fa~c: (907) 245-8952 1~ Injection Profiie 19-Aug-09 1 E~112 L2 BL / EDE 2) Warmback Log 20-Aug-09 1~112 L2 ~ t i, Signed : • Print Name: 1 ~`~~ l ~~l 50-029-23211-61 BL/ E~ ~ ~ 1~'I-61 Date : pUG 2 ~ 2009 ~laska ~il ~ ~as Cons. Corn~°~issior Anc4~or~e PROACTIVE DlAGNOSTIC SERVICfS, MIC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCNORAGE, AK 99518 PHONe: (907)245-8951 Fax: ~9p7j245-88952 E-quLl.: pdsanchoeaae(aamemaryloa.com WEBSiTE:www.memorvloa.com ^ C:~Da:tunents and Settings\Owner~Desktop\Transmit BP.docx ~~ }~ • • MICROFILMED 03/01 /2008 DO NOT PLACE .~ .` _ ~ P ~•;" .. ~~ ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_Inserts\Microfilm_Marker.doc J) A-~ DATA SUBMITTAL COMPLIANCE REPORT 8/2/2006 Permit to Drill 2040930 Well Name/No. KUPARUK RIV U WSAK 1E-112L2 Operator CONOCOPHILLlPS ALASKA INC Sp~¿' .Â-l ~ ~ cr API No. 50-029-23211-61-00 MD 11273 /' TVD 3333 ./ Completion Date 7/31/2004 /' Completion Status 1-01L Current Status 1WINJ UIC Y ~~_.~ REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GRlRes Well Log Information: (data taken from Logs Portion of Master Well Data Maint Interval . OH/ Start Stop CH Received Comments 5840 11273 8/2/2004 108 11273 Open 10/29/2004 RWD/GRlMPR 108 11273 Open 1 0/29/2004 RWD/GRlMPR 108 11273 Open 1 0/29/2004 RWD/GRlMPR 108 11273 Open 10/29/2004 RWD/GRlMPR Log/ Electr Data Digital Dataset Type Med/Frmt Number Name Rpt Directional Survey j;.Q" C J; ,F ...' S 12809 Induction/Resistivity ~ 12809 Induction/Resistivity ~ 12809 Induction/Resistivity 12809 LIS Verification Log Log Run Scale Media No 25 Blu 25 Blu Well Cores/Samples Information: ./ Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORM~ Well Cored? Y{¡J;y/ Daily History Received? .~ 'QN . Chips Received? '( / r..¡ Formation Tops Analysis Received? '" Y IN Comments: Compliance Reviewed By: ~ )~~ Date: n.",. vv """ ..,,,,, LL..,-' ,... U'J"'''''VI VHHH'" VV HH UC;'. LX .r . « Thanks Pete. NSK West Sak Prod Engrwrote, On 8/17/20054:21 PM: Tom, This email is to notify the AOGCC that West Sak injector 1 E-112 has been placed on injection 8/17 with the lPP defeated in accordance with AOGCC Rule Amendment No. C0406B.001 dated 6/14/05. The LPP has been tagged and recorded in the facility safety defeat log. ConocoPhillips will notify the AOGCC again when this is injector is shut-in or the injection pressure has built to 500 psi and the lPP activated. Currently the well is injecting at 580 bwpd on a vacuum. Thanks, Peter Nezaticky / Hai Hunt ConocoPhillips Alaska Inc. West Sak Production Engineer Ph: (907) 659-7061 Fax: (907) 659-7314 1 of 1 8/18/20053:37 PM .~. .. v~. u~, U'J~~.v. ~.. '~U~H~'" . ~H't' tt"H"'''' ""''''H'''VU ''''1... e Subject: RE: West Sak Injector LPP Variance - Temp Variance extension request lE-112 & lB-102 From: NSK Problem Well Supv <n1617@conocophillips.com> \..... dO ~_ \""'\ ...... Date: Mon, 27 Jun 2005 08:07:02 -0800 (,j r:i- To: Thomas Maunder <tom_maunder@admin.state.ak.us> CC: jimJegg@admin.state.ak.us "f <70l..\ - O~ \ ¡:)OL\-O<; d- dOL\ -0'\ ~ Tom, Thanks for the quick response. Marie -----Original Message----- From: Thomas Maunder (mailto:tom_maunder@admin.state.ak.us] Sent: Monday, June 27,20057:54 AM To: NSK Problem Well Supv Cc: jim_regg@admin.state.ak.us Subject: Re: West Sak Injector LPP Variance - Temp Variance extension request 1E-1l2 & 18-102 Marie, We did receive the "request" regarding the LPPs on WS wells and we are nearly finalized with "our" document. With regard to these specific wells, it is acceptable to defeat the LLP due to the low injection pressures. The LPP must be returned to service when the injection pressure reaches 500 psi. A copy of this authorization should be available should the Inspector request it. Tom Maunder, PE AOGCC NSK Problem Well Supv wrote: Tom, Two low wellhead pressure West Sak injectors are planned to be brought on injection for reservoir diagnostics. Our records show the last temp LPP variance expired 6/20/05. CPAI would like to request another temp variance to defeat the LPPs on 1 E-112 and 1 B-1 02 for 30 days without a 24 hr man watch. 1 E-112 will be brought on injection as soon as an extension is granted. Downhole gauges were installed on 6/25/05 to record data for 30 days in conjunction with surface tiltmeter data gathering. The well has been ready to bring on injection, but operations is waiting on a variance extension. The well has been intermittently on injection in the last month with the injection wellhead pressure ranging between 0 to 35 psi. 1B-102 will be BOI for a week in the next month when a production profile can be scheduled on 1C-178. 1 B-1 02 will be BOI a few days prior to the PPROF and 51 a few days later. The last time 1 B-1 02 was on injection for reservoir diagnostics the injection wellhead pressure ranged between 0 to 25 psi. On 6/13/05, Jerry sent a letter to the AOGCC requesting approval to defeat LPPs on West Sak water injectors with low tubing pressure. Has the AOGCC had a chance to consider this request? Please let me know if you have any questions. Marie McConnell Problem Well Supervisor 659-7224 I of I 6/27/20058:25 AM 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 7. KB Elevation (ft): RKB 28', 99' AMSL 8. Property Designation: ALK 25651 & 25660/ ADL 469 & 470 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural CONDUCTOR SURFACE INTERMEDIATE SLOTTED 'D' UN Perforation depth: . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS Repair Well 0 Pull Tubing 0 Operat. ShutdownD Other o Convert to Injector o o Stimulate 0 Waiver 0 Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Status: Development 0 Stratigraphic 0 Time Extension Re-enter Suspended Well Exploratory 0 Service 0 5. Permit to Drill Number: 204-093 / 304-477 6. API Number: 50-029-23211-61 9. Well Name and Number: 1E-112L2 10. Field/Pool(s): Kuparuk River Field / West Sak Oil Pool measured 11273' feet true vertical 3333' feet measured 6200' feet true vertical 3485' feet Length Size MD 108' 20" 108' 3003' 13-3/8" 3031' 6900' 9-5/8" 6926' 5403' 5-1/2" 11242' Plugs (measured) Junk (measured) TVD Burst Collapse 108' 2309' 3606' 3337' Measured depth: slots in liner 5902'-5980', 6536'-11242' RECEIVED APR 2 6 2005 Alaska Oil & Gas Cons. Commission Anchorage true vertical depth: 3421'-3433',3420'-3338' Tubing (size, grade, and measured depth) 4-112" , L-80, 6822' MD. Packers & SSSV (type & measured depth) Baker ZXP packer @ 5780' Landing Nipple @ 508' 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/A 13. Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casin¡¡ Pressure Tubin¡¡ Pressure Prior to well operation Subsequent to operation 14. Attachments Copies of Logs and Surveys run _ 4025 15. Well Class after proposed work: Exploratory 0 Development 0 Service 0 16. Well Status after proposed work: oilD GasD WAG 0 GINJD WINJ 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Daily Report of Well Operations _X Gary Targac @ 265-6586 Printed Name Gary Targac ~,~ Form 10-404 Revised 04/2004 Contact Signature WDSPL D Title Phone West Sak Coordinator 907-659-6586 Date Preoared bv Sharon AI/suo-Drake 263-4612 f{ ~j) (\/~ 'S tt ()~ t ðÇ Submit Original Only . 1 E-112 Well Events Summary . Date Summary 01/03/05 OBTAINED BHP @6092'WLM (975 PSI @69 DEGREES); DRIFTED TBG W/ 3.83" SWAGE TO 5370' RKB; SET 3.813" DB-6 BLANKING PLUG @ 5370' RKB, IN PROGRESS. [Pressure Data, GL V, MIT] 01/04/05 PULLED GLV & SET DV @2414' RKB. PULLED OV @5320' RKB. LOADED IA & TBG W/ SW & DSL CAP. ATTEMPTED SET DV @ 5320' RKB. IN PROGRESS. [GLV] 01/05/05 PULLED DV @ 5320' RKB. JOB SUSPENDED FOR PHASE 2 WEATHER. IN PROGRESS. [GL V] 01/06/05 PULLED & SET 1" DV @ 5320' RKB. VERIFIED DVs FULLY SET @ 2414' & 5320' RKB. MITIA 3000 PSI, PASSED. JOB SUSPENDED FOR WEATHER. IN PROGRESS. [GLV, MIT] 01/07/05 MITIA 3000 PSI, PASSED. PULLED 3.81" DB-6 BLANKING PLUG @ 5370' RKB. [MIT] 01/14/05 SET CHOKE W/1/2" ORIFICE ON 3.875" DB-6 LOCK@ 508' RKB. 01/24/05 PULLED DOWNHOLE CHOKE @ 508'RKB [Open-Close A Sand] 01/24/05 SET 3.875" DB-6 LOCK XO 2.875" MCX INJECTION VALVE WITH .75" BEAN AND NO FLAPPER @ 508'RKB [Open-Close A Sand] 01/26/05 PULLED & SET DOWNHOLE CHOKE WITH 5/8" BEAN ON 4.5" DB LOCK @ 508'RKB [Maintenance] 02/15/05 PULLED DOWNHOLE CHOKE @ 508' RKB. CHOKE IN NEW CONDITION, NO EROSION. MEASURED BHP @6080'WLM IS (1290 PSI @ 100 DEG F.). SET 3.81" DB LOCK,FLOW THRU SUB,SHOCK & DUAL PANEXES @ 5370' RKB. [Pressure Data] 02/24/05 PULLED DUAL PANEX ASS'Y @ 5370' RKB. SET DUAL SPARTEC ASS'Y (12' OAL) @ 5370' RKB. [Pressure Data] 03/06/05 PULLED SPARTEK GAUGES ON DB LOCK @ 5370' RKB. [Pressure Data] 03/08/05 RAN IPROF -- SPLITS: 12% D SAND /88% B SAND / 0% A SAND -- CROSS FLOW FROM D SAND TO B SAND WITH WELL SHUT IN -- USED WELL TEC TRACTOR FROM 6020' TO 6112' - UNABLE TO TRAVEL PAST B SAND LEM WITH TRACTOR BUT SPINNER ASSB. 04/08/05 RIGGED UP CTU#8; PERFORMED BOP TEST, RIGGED UP I-COIL / FIBER OPTIC BHA. ATTEMPTED TO DISPLACE COIL W/ WARM DIESEL TO TANKS, OVER-PRESSURED RUPTURE DISK (1500 PSI BURST). 04/09/05 ATTEMPTED TEMPERATURE /INJECTION PROFILE ON B SAND LATERAL. DTS/I-COIL TOOLS FUNCTIONED PROPERLY. CYCLED 90 DEG (15 DEG PER) W/ DISCOVERY ML T TRYING TO LOCATE WINDOW. 04/10/05 ATTEMPTED TO FISH DISCOVERY ML T W/2-5/8 RELEASEABLE OVERSHOT. TAGGED WHAT WE BELIEVED WAS FISH AT 6060' CTM, DIDN'T LATCH FISH- NO CLEAR MARKS ON TOOLS. RECEIVED APR 2 6 2005 Alaska Oil & Gas Cons. Commission Anchorage . 1 E-112 Well Events Summary . 04/11/05 ATTEMPTED TO FISH DISCOVERY ML T TOOLSTRING W/2-1/8" MHA&JARS/2-1/4 DISCONNECT/3-1/8" HYDRAULIC OVERSHOT W/6" MULESHOE. 1ST RUN, RIH TO 7327' CTM, TAGGED HARD-STACK WGT/RUN INTO IT HARD/FIRE JARS DN 2X, CAME OOH EMPTY, NO MARKS INSIDE OS. RECEIVED APR 2 6 2005 Alaska Oil & Gas Cons. Commission Anchorage ConocoPhillips Ala", Inc. 11E-112L2 API: 500292321161 SSSV Type: NIPPLE Annular Fluid: Reference Log: 28' RKB Last Tag: Last Tag Date: Casing String - ALL STRINGS· Description Size SURFACE 13.375 INTERMEDIATE 9.625 CONDUCTOR 20.000 SLOTTED D-SAND LINER 5.500 Tubing String':' TUBING Size I Top 4.500 0 Perforations Summary Interval TVD 5902 - 5980 3421 - 3433 TUBING (0-6822, 00:4.500, 10:3.958) SURFACE - (0-3031, 00:13.375, Wt:68.DO) TERMEOIATE - (0-6926, 00:9.625, Wt:40.00) Gas Lift .ndrel/Oummy Valve 2 (5320-5321, 00:5. 984) SlEEVE-C (5370-5371, 00:5.470) PACKER (5780-5781, 00:8.430) SEAL (5792-5794, 00:4.750) SBE (5801-5802, 00:6.240) Perf (5902-5980) . KRU £-112L2 Well Type: INJ Orig Completion: 7/31/2004 Last W/O: Ref Log Date: TD: 11273 ftKB 96 de¡¡ @ 6416 Angle @ deg @ Angle @ TO: 92 deg @ 11273 Rev Reason: Pull Choke & Gauges Last Update: 3fl12005 Top o o o 5839 Bottom 3031 6926 108 11241 TVD 2312 3401 108 3338 Wt 68.00 40.00 94.00 15.50 Grade L-80 L-80 K-55 L-80 Thread BTC BTC-M WELDED DWC Zone WSD Status Ft SPF Date Type Comment 78 40 7/26/2004 IPERF Slotted Liner Alternating w/Blank Pipe, 2.5" L x .125" W, in 4 circumferential rows/ft 4704 40 7/26/2004 IPERF Slotted Liner Alternating w/Blank Pipe, 2.5" L x .125" W, in 4 circumferential 6536 - 11240 3420 - 3338 WSD Gas'Lift MandrelsNalves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO 2414 2021 CAMCO KBG-2 DMY 1.0 0.000 2 5320 3257 CAMCO KBG-2 DMY 1.0 Other (plugs, equip., etc.) - COMMON JEWELRY Depth TVD Type Description 22 22 HANGER VETCO GRAY TUBING HANGER W/MCA TOP CONNECTION 508 508 NIP CAMCO DB-6 NIPPLE 5370 3276 SLEEVE-C BAKER CMU SLEEVE w/CAMCO DB-6 PROFILE 5792 3398 SEAL BAKER LOCATOR/SEAL ASSEMBLY Other (plugs, equip., etc.) - D-8AND SLOTTED LINER JEWELRY Depth TVD Type Description 5780 3395 PACKER BAKER ZXP LINER TOP PACKER 5801 3401 SBE BAKER 190-47 SBE 5830 3408 ENTRY MOD LEM #2 HOOK HANGER 5839 3410 HANGER HOOK HANGER #2 General Notes Date Note 7/30/2004 TREE: ABB VETCO GRAY / HORZ / 4-1/16" 5M (w/PENETRATOR WIRE) TREE CAP CONNECTION: 9" OTIS THIS IS A TRI-LATERAL WELL - THIS SCHEMATIC FOR L2 - REFER TO BAKER HUGHES SCHEMATIC FOR COMPLETE TRI-LATERAL VIEW OF WELL Date Run 1/6/2005 1/6/2005 Vlv Cmnt ID 4.500 3.875 3.810 3.880 ID 7.000 4.750 3.680 6.290 RECEIVED APR 2 6 2005 Alaska Oil & Gas Cons. Commission Anchorage Subject: RE: West Sak 1E-I From: "Targac, Gary" <Gary. Targac@conocophillips.com> Date: Wed, 30 Mar 2005 16:48:37 -0900 To: Thomas Maunder <tom_maunder@admin.state.ak.us> ~ \..<L~ 0 '-t- 0 c;. ~ We have narrowed it down to the B Sand. We are working on a log down the lateral to see what the mechanism is? Right now, we have 4 plausible causes: 1) fracturing, 2) fault communication, 3) matrix event (high perm streak) or 4)fluidization event (ie. wormhole or weak sand interval). ;;;)~ L\ -OS \ ~jaL\.- oS J Will keep you posted. Gary -----Original Message----- From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Wednesday, March 30, 2005 4:40 PM To: Targac, Gary Subject: Re: West Sak lE-112 Gary, Your proposal is acceptable. Is there any feeling as to the mechanism regarding communication to 1 E-166?? Is it specific to one interval or have you been able to determine it down that far?? As noted in our earlier emai1s, the cement is suspect but suspect cement would more of concern for "getting out" in the vicinity of the well bore not communicating to another wellbore. Keep us informed with the diagnostics. Tom Maunder, PE AOGCC Targac, Gary wrote: Tom, per our discussion, ConocoPhillips Alaska is requesting deferral of the warmback injection survey on Well 1E-112. 1E-112 started injection on Jan 13, 2005. The well was SI on Feb 12, 2005 due to the water breakthrough event to 1E-166. It has been on periodic injection twice since then while doing reservoir pulse testing and injection logging. More periodic injection is planned while we continue logging and pulse testing in the coming months to evaluate a remediation for the well. As noted on the Sundry, a warmback injection survey is required after thermally stable (-60 days). Due to the well being SI for some period, I would like to defer the warmback survey until (60 days) after we resume normal injection that is currently forecast to be June or July 2005. This note is requesting approval to do so. Please call me if you have any questions. Gary 907-265-6586 lof2 3/3 1/2005 9:21 AM h..L_', .....l...ÚlK lL 11..... . . -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Tuesday, December 14, 2004 7:46 AM To: Targac, Gary; Allsup-Drake, Sharon K Cc: Shultz, Steven M¡ McKeever, Steve Subject: Re: 1E-112, et al Gary, Sharon, et al: Robin Smyth delivered the bond log yesterday. In the lower portions of the section logged, the presentation shows pretty good coverage however it gets poorer the higher one goes. In order to evaluate further, I will need the operations reports for the intermediate cementing operation. All I have to examine now are the daily summaries attached to the completion report. Thanks for your assistance. Tom Maunder, PE AOGCC Thomas Maunder wrote: Gary and Sharon, I have looked further and I do have the plots for the well, at least as it was planned, but I will need the log. Tom Thomas Maunder wrote: Gary and Sharon, I have received the sundries for the multi-lateral wellbores. I do not have a copy of the bond log and am also in need of the proximity information. Such plot should start at the top of the sand above the L2 lateral and proceed out all the well path(s) to TD. Steve Shultz and Vern Johnson have previously provided me such information on other wells. From my review of the completion report, it appears that the cementing operation went fairly well. An e copy of the bond log is acceptable. Tom Maunder, PE AOGCC 20f2 3/31/2005 9:21 AM . ( ~~!Æ~E ([ F !Æ~JL.~~~!Æ ... . ;)Pl- i!? "'1'3 AI,.SIiA OILAlWD GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Gary Targac West Sak Coordinator ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska Re: Kupaurk 1E-112, 1E-112L1 & lE-1l2L2 Sundry Numbers: 304-479,304-478 & 304-477 Dear Mr. Targac: Enclosed are the approved Applications for Sundry Approval relating to the above referenced wells. Please note the conditions of approval set out in the enclosed fonD.. 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 rehearing. A request for rehearing 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. Aperson may not appeal a Commission decision to Superi C unless rehearing has been requested. DATED this ¡6day of December, 2004 Encl. . STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION . APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Operation Shutdown 0 Plug Perforations 0 Perforate New Pool 0 1. Type of Request: Abandon 0 o o Suspend 0 o o Alter casing Repair well Change approved program Pull Tubing 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: P. O. Box 100360, Anchorage, Alaska 7. KB Elevation (ft): RKB 28', 99' AMSL 8. Property Designation: ALK 25651 & 25660/ ADL 469 & 470 11. Total depth MD (ft): 11273' Casing Total Depth TVD (ft): Effective Depth MD (ft): 3333' 6200' Length Size CONDUCTOR 108' 20" SURFACE 3003' 13-3/8" INTERMEDIATE 6900' 9-5/8" SLOTTED 'B' LINER 5403' 5-1/2" Perforation Depth MD (ft): slots in liner 5902'-5980',6536'-11242' Packers and SSSV Type: Baker ZXP Perforation Depth TVD (ft): December 20,2004 Date: Perforate 0 o Stimulate k II~ ...ø /è~ ~ ~ 3<.. Waiver o o o Other 0 Convert to Annular Disp. 0 Time Extension Re-enter Suspended Well Inif3rtnr 5. Permit to Drill Number: \ E=-\ \d ~~'\.~ ~l\t:~It~-\-'"'> . 4. Current Well Class: Development _ 0 Stratigraphic 0 Exploratory 0 o Service 204-093 6. API Number: 50-029-23211-61 9. Well Name and Number: 1 E-112L2 10. Field/Pool(s): Kuparuk River Field I West Sak Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth TVD (ft): Plugs (measured): Junk (measured): 3485' MD 108' 3031' 6926' 11242' Collapse RFCtIV~~v 2309' - 3606' DEC 1 0 2004 3337Alask. Oil & Gss Cnn C.. An h . f. 0 "missIon c orage TVD 108' Tubing Size: 4-1/2" Packers and SSSV MD (ft) packer @ 5780' Landing Nipple @ 508' 13. Well Class after proposed work: Exploratory 0 Development 0 15. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 Contact: Title: Phone Commission Use Only Burst Tubing Grade: L-80 Tubing MD (ft): 6822' 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Ope rat 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Ga~TarQac S;9"a,"~ - /'(j '-r:- i') \... Service 0 Plugged 0 WINJ 0 Abandoned 0 WDSPL 0 Gary Targac @ 265·6586 w..~: ~7~~if Isun~3}JL1~r: 471 Conditions of approval: Notify Commission so that a representative may witness ~~~\£\:¡~".;/ Plug Integrity 0 BOP Test 0 Mechanical'ntegrity Test 0 Location CI~a~nce 0 Other: >(.~ ~CJ'-\ - \.{ "'\ <; Form 10-403 Revised 12/2003 RBDMS BFL DEt 2 0 2DD4 Daæ 'ffur COMMISSIONER BY ORDER OF THE COMMISSION INSTRUCTIONS ON REVERSE ORIGINAl Submit in Duplicate TUBING (0-6822, 00:4.500, 10:3.958) SURFACE ~ (0-3031, 00:13.375, Wt:68.00) TERMEOIATE (0-6926, 00:9.625, Wt:40.00) Gas Lift MandrelNalve 2 (5320-5321, SLEEVE-O (5370-5371, 00:5.470) PACKER (5780-5781, 00:8.430) SEAL (5792-5794, 00:4.750) SBE (5801-5802, 00:6.240) Perf (5902-5980) SLOTTEO LINER (5839c11241, 00:5.500, Wt:15.50) Perf (6536-11240) Gas lift MandrelsNalves $t MD TVD Man Man Type V Mfr V Type V 00 latch Port TRO Mfr 2414 2021 CAMCO KBG-2 GLV 1.0 BK 0.188 1456 2 5320 3258 CAMCO KBG-2 OV 1.0 BK 0.313 0 Other (plugs, eqUip., etc.) - COMMON JEWELRY Depth TVD Type Description 22 22 HANGER VETCO GRAY TUSING HANGER W/MCA TOP CONNECTION 508 508 NIP CAMCO DS-6 NIPPLE 5370 3277 SLEEVE-O SAKER CMU SLEEVE w/CAMCO 5792 3396 SEAL BAKER LOCA TORISEAL ASSEMBLY etc.} - LINER JEWELRY BAKER ZXP LINER TOP PACKER SAKER 19()"47 SSE LEM #2 HOOK HANGER 5839 3404 General Notes Date Note 7/30/2004 TREE: ABB VETCO GRAY I HORZ 14-1/16" 5M (w/PENETRATOR WIRE) TREE CAP CONNECTION: 9" OTIS 1E-112L2 API: 500292321161 SSSV Type: NIPPLE Annular Fluid: Reference Loç¡: 28' RKB Last Tag: Last Ta!,) Date: String - ALL STRINGS SURFACE INTERMEDIATE CONDUCTOR SLOTTED LINER String - 4.500 Perforations Interval 5902 - 5980 3414 - 3427 6536 -11240 3413 - 3334 5801 5830 SSE ENTRY MOD HANGER KRU 1 1212 Well Type: PROD Orig 7/31/2004 Completion: Last W/O: Ref Loç¡ Date: TD: 11273 ftKS Max Hole Anf1le: 96 deg @J 6414 Angle @J TS: deg @J Angle @ TD: 93 deg @ 11273 Rev Reason: NEW WELL L2 Last Update: 8/14/2004 Size Top Bottom TVD Wt Grade Thread 13.375 0 3031 2312 68.00 L-80 STC 9.625 0 6926 "..... 3394 40.00 L-80 STC·M 20.000 0 108 108 94.00 K·55 WELDED 5.500 5839 11241 3334 15.50 L-80 owe Bottom TVD Wi Grade Thread 6822 3397 L-80 1ST Zone WSD Status Ft SPF Date Type Comment 78 40 7/26/2004 IPERF Slotted Liner Alternating w/Blank Pipe, 2.5" Lx .125" W, in 4 circumferential rows/ft 4704 40 7126/2004 ¡PERF Slotted Liner Alternating w/Blank Pipe, 2.5" Lx .125" W, in 4 circumferential rows/lt WSD Date Run 8/5/2004 8/5/2004 Vlv Cmný 10 4.500 3.875 3.810 3.880 ID 7.000 4.750 3.680 6.290 HOOK HANGER #2 THIS IS A TRI-LA TERAL WELL - THIS SCHEMATIC FOR - REFER TO SAKER HUGHES SCHEMATIC FOR COMPLETE TRI·LA TERAL VIEW OF . . . ;O~-o~, d-04 --os J ~()4 \)c;"3>. \l.. Q 0 - L ~ - Ld.- . . MECHANICAL INTEGRITY REPORT· ....... :..IG RELE;..S::':: . OPER & FIELD C ~J¿.- r "W""ELL NUMBER \ \:: - \ \ d :: ?UD DA::::: . '15/ (S :L..\IL'~b. ~c. ~ ~LL DATA TD: . MD.. C 5/ U' . Cas ing: ~ 1'0 Shoe: bc;d<O MD ~=-:1er: Shoe: TVD; :?BTD: MD TVD 3(l)~ TVD¡ DV: \..)b,.. MD ·DlD TVD¡ :OP: l-ID :-VD MD :~bi!1g: 4'/;;) Packer 5S03 HI) Q\ I'" II ::'ole Size Q ~ anå TVD¡ Set: at: ~X-d:2 ~o~o~L?~\~O~ ~.ð'4"~ C\=><L", \...ð\t. I ~\ \Q.~~ \ Perfs :-::EC?..Alnc;·.L INTEGRITY - PART 11 Annulus Press Test: ~p 15 min ; 30 min Comments: ,- ~CHÞ_1'ncþ..L INTEGRITY - PART /2 rd. Co \ b '!> \.5. Cement: Volumes :.. .Amt. Liner ~~ Csg <'0'1<;. ~y. j DV ~ ~ . C¡¡¡t -"01 to cover perfs \\5 'D'o\c:.. ,"d-<ö.Ç ~~ ') ~~ ':>ù~\ ~Cè"-~ 4--c (.O\J~\ \-"(è L d- Cè..i.\\- ~\~\- ~\~~ soot <".A.\\(:)~"~ :!J'2~ "'S Theoret:ical TOC CJ..~""\{) ""20 ~ <:> ì~_h~e\~ \ TOÇ . \'"::> ~~:);, ' . I/lO-C'-\ Cement Bond Log (Yes or No) '\~S ; In AOGCC File .~ ~ _. . ~1 ~,,-\-,:,«;~~'o ~c..öfá\~\<:t>~~(\ CEL 7va~uat~on, ~one, aDove perfs œc\.V~~~') -:L~c~~~\8..~~ a. ~~~~ ~~~~.,\o...~\.ot--..c.sø.",<",-~ \~ ~~~~-\- (. \)~-+- ~\O~~ ~~ ,~\~\t: ~l1.~\:h~ "-I~\...~~~\..i\-~ ~~\- \0 ~~t~~o~~~~ Ctf)"-~~~ ~"'~'?Q.rÐ"i'-.~~o..\~. ~~s.~.\~~ ~~~o~~o;". ~ ~c~ Proåuc.tion Log: Type ; Evaluation . ~'o~w"<: . ~o~k~ CONCbUSIONS: . ? art :1: -r:\"... CS}~..":..~I-..~ ~ c::e""'Ç k\£). "-.I"'\-I'€S~ \1..(\ ~, ?art :Z: t-·ì\.:r:\.~\\\cå...,. \~~~~M..~~~\~ S~~,\~ ~ ~"- ~Q ~<oO ~'f; c...~ '"~\. \. '-~ (:)ti\..'\,'\.\ <sc.:.~'¢'.... k'O:n# . ~~J'rflS%( e STATE OF ALASKA e ALASKA Oil AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG WAG 0 1a. Well Status: Oil 0 Gas U GINJ 0 2. Operator Name: o WDSPL 0 WINJ ConocoPhillips Alaska, Inc. 3. Address: Plugged 0 Abandoned U 20AAC 25.105 No. of Completions _ P. O. Box 100360, Anchorage, AK 99510-0360 4a. Location of Well (Govemmental Section): Surface: 191' FSL, 226' FEL, Sec. 16, T11N, R1OE, UM At Top Productive Horizon: Total Depth: 1469' FNL, 2229' FEL, Sec. 22, T11 N, R1OE, UM 1561' FNL, 2265' FWL, Sec. 27, T11N, R1OE, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 550300 y- TP/: x- 553591 y- Total Depth: x- 552853 y- 18. Directional Survey: Yes 0 NoU 21. Logs Run: GR/Res 22. CASING SIZE WT. PER FT. 94# 68# 40# 15.5# GRADE K-55 L-80 L-80 L-80 20" 13.375" 9.625" 5.5" 5959781 5958143 5952766 Zone-4 Zone-4 Zone-4 Suspended 0 20AAC 25.110 Other _X Pre-Produced Injector 5. Date Comp., Susp., or Aband.: July 31,2004 6. Date Spudded: June 26, 2004 7. Date TD Reached: July 25, 2004 8. KB Elevation (It): 28' RKB I 99' AMSL 9. Plug Back Depth (MD + TVD): 6200' MD I 3485' TVD 10. Total Depth (MD + TVD): 11273' MD 13333' TVD 11. Depth where SSSV set: Landing Nipple @ 508' 19. Water Depth, if Offshore: N/A CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD TOP BOTTOM TOP BOTTOM 28' 108' 28' 108' 28' 3031' 28' 2309' 28' 6926' 28' 3606' 5839' 11242' 3408' 3337' 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): slots in liner from 5902'-5980', 6536'-11242' slots are 40 slots/ft 26. Date First Production September 7, 2004 Date of Test Hours Tested 24. SIZE 4.5" 1b. Well Class: Development 0 Exploratory 0 Service 0 Stratigraphic Test 0 12. Permit to Drill Number: - 204-093 13. API Number: 50-029-23211-61 14. Well Name and Number: 1 E-112L2 15. Field/Pool(s): Kuparuk River Field West Sak Oil Pool 16. Property Designation: ALK 25651 & 25660 17. Land Use Permit: ADL 469 & 470 feet MSL 20. Thickness of Permafrost: 1584' MD HOLE AMOUNT CEMENTING RECORD SIZE PULLED 42" 268 sx AS I 16" 618 sx ASIII, 219 sx DeepCrete 12.25" 649 sx DeepCrete 8.5" slotted liner TUBING RECORD DEPTH SET (MD) PACKER SET 6822' 5780', 6038' & 6777' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED Test Period --> Calculated 5470 3639 CORE DATA nla -RBDMS 8Ft SEP 2 CONTI~_ Dr'" TEL;'~" f~\ , U \. ,II· t t _,_f f f \: Production for OIL-BBL 979 OIL-BBL PRODUCTION TEST Method of Operation (Flowing, gas lilt, etc.) Flowing (shared production with 1 E-112 and 1 E-112L 1) GAS-MCF W A TER-BBL CHOKE SIZE 787 0 GAS-MCF W A TER-BBL 9/7/2004 Flow Tubing press. 330 psi 27. 17 hours Casing Pressure 1367 24-Hour Rate -> 129% OIL GRAVITY - API (corr) IGAS-OIL RATIO 665 not available Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". CVì\1PLb:¡ätil I?ß$J ¡ V91Ji2J) i L:~:-j Form 10-407 Revised 12/2003 NONE , t ............,,., RECEIVED SEP 1 7 2004 Alaska Oil & Gas Cons. CommìsG~n Anchorage C, f" G GEOLOGIC MARKERS e 29. e FORMATION TESTS 28. NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 1E-112L2 West Sak D 5834' 3408' N/A RECEIVED S£p 1 Alaska Oil &. 7 2004 Gas Cans. Co ~. < Anchorage fI.rrU~ll;ìo¡¡ 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 31 < I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve Shultz @ 263-4620 Printed Name Randy Thomas Signature ~~ Title: Phone Kuparuk DrillinQ Team Leader 2.6) '-830 Date "('3/0'(" Prepared by 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. 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 elevation in feet abour mean low low water. 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: True vertical thickness. 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, Other (explain). Item 27: If no cores taken, indicate "none". Item 29: List all test information. If none, state "None". Form 1 0-407 Revised 2/2003 e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-112 1 E-112 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 6/25/2004 Rig Release: 7/31/2004 Rig Number: Spud Date: 6/26/2004 End: 7/31/2004 Group: 6/25/2004 08:00 - 12:00 4.00 MOVE MOVE MOVE Hold PJSM wI Toolpusher, Peak truck pusher, & rig crew. Stage rock washer & rig complex's down the pad. Move sub & spot same over well. 12:00 - 15:30 3.50 MOVE MOVE MOVE Spot Pits, Pump Room, Motor room, boliler complex, rock washer & pipeshed. Rig up Complex's. 15:30 - 17:00 1.50 MOVE RURD MOVE Rig up Rig. Complete rig acceptance checklist. Rig accepted on 1 E-112 @ 17:00 hrs 6/25/2004. 17:00 - 19:00 2.00 MOVE RURD MOVE Load pipeshed with 5' DP. Mix spud mud in pits. 19:00 - 21 :00 2.00 MOVE RURD MOVE MIU Diverter system and cotinue to mix spud mud. 21 :00 - 00:00 3.00 MOVE RURD MOVE P/U 5' DP and rack in derrick. Continue to mix spud mud. 6/26/2004 00:00 - 04:00 4.00 RIGMNT RGRP RIGUP Work on top drive, replace traction motor encoder. Test same, OK. 04:00 - 09:00 5.00 DRILL PULD RIGUP Continue PU 5" DP, 29 jts 5" HW, & jars. Rack back same in derrick. 09:00 - 09:30 0.50 WELCTL BOPE RIG UP Perform Accumulator & Diverter function test. AOGCC rep John Crips waived witness test. 09:30 - 10:15 0.75 DRILL PULD RIGUP Clear rig floor and PU BHA. 10:15 - 10:30 0.25 DRILL SFTY RIGUP PJSM wI directional driller, Toolpusher, & rig crew on handling BHA. 10:30 - 12:00 1.50 DRILL PULD RIGUP MU 16" Bit, 9.5' motor w/1.6 deg AKO, NMDC, NM stabalizer, NM XO, & MPR. 12:00 - 14:00 2.00 DRILL PULD RIGUP MU MWD, initialize & orient. 14:00 - 14:30 0.50 DRILL RIRD RIGUP RU Halliburton wireline for planned surface Gyro. 14:30 - 15:30 1.00 DRILL CIRC RIGUP Pressure Test lines to 1000 psi. Flood system & check for leaks. 15:30 - 16:30 1.00 DRILL DRLG SURFAC Drill 16" surface hole f/108' to 197'. Spud well @ 15:30 hrs 6/26/2004. 16:30 - 17:30 1.00 DRILL PULD SURFAC Rack back 5' HWDP & PU (3) 8" Drill Collars. 17:30 - 00:00 6.50 DRILL DRLG SURFAC Drill 16" surface hole f/197' to 740' MD 1739' TVD, ART = 2.2 hrs, AST = 2.4 hrs, WOB 10/15K, 500 GPM @ 1300 psi, UP 75K, DN 75K, ROT 75K, TO (on/off) 2/1. Gyro surveys @ 262' MD and 351' MD. 6/27/2004 00:00 - 12:00 12.00 DRILL DRLG SURFAC Drill ahead from 740' MD /739' TVD to 1900' MD 11765' TVD, ADT = 7.1 hrs, ART = 1.0 hrs, AST = 6.1 hrs, WOB = 20/45K, 525 GPM @ 1700 psi, ROT = 60 RPM, UP 102K, DN 92K, ROT 96K, TQ (on/off) 4/3. 12:00 - 15:00 3.00 DRILL DRLG SURFAC Drill ahead from 1900' MD 11765' TVD to 2180' MD /1912' TVD, ADT = 2.0 hrs, ART = 0.6 hrs, AST = 1.4 hrs, WOB = 15/20K, 615 GPM @ 1700 psi, ROT = 65 RPM, UP 108K, DN 82K, ROT 93K, TQ (on/off) 6/4. 15:00 - 15:30 0.50 DRILL CIRC SURFAC Circulate hole clean for TOH. 15:30 - 18:00 2.50 DRILL TRIP SURFAC Observe well & backream out of hole to 900' MD. 18:00 - 19:00 1.00 DRILL TRIP SURFAC TOH on elevators to MWD @ 104' MD. 19:00 - 20:00 1.00 DRILL PULD SURFAC Dowload MWD tool. 20:00 - 20:30 0.50 DRILL PULD SURFAC Rack back MWD tool and UD motor. 20:30 - 22:00 1.50 DRILL PULD SURFAC MU BHA # 2, 16' bit, 9.5" motor wI 1.3 deg AKO, NMDC, NM stab, NM XO, & MPR. 22:00 - 23:30 1.50 DRILL TRIP SURFAC RIH f/68' to 2126' MD with no problems. 23:30 - 00:00 0.50 DRILL TRIP SURFAC Wash & ream from 2126' MD to 2180' MD (26' of fill) 6/28/2004 00:00 - 09:30 9.50 DRILL DRLG SURFAC Drill ahead from 2180' MD 11912' TVD to surface hole TD at 3045' MD / 2315' TVD, ADT = 6.8 hrs, ART = 2.8 hrs, AST = 4.0 hrs, WOB = 20/45K, 615 GPM @ 1800 psi, ROT = 100 RPM, UP 124K, DN 72K, ROT 94K, TO (on/off) 5-13/8. 09:30 - 10:00 0.50 DRILL CIRC SURFAC Circulate hole to clear BHA. Observe well, static. 10:00 - 13:30 3.50 DRILL TRIP SURFAC Back ream out of hole from 3045' MD to HWDP at 920' MD. Back ream at 110 RPM & 615 GPM. 13:30 - 14:30 1.00 DRILL TRIP SURFAC TOH on elevators from 920' MD to MWD at 105' MD. 14:30 - 15:00 0.50 DRILL PULD SURFAC Download MWD tool. Printed: 8/18/2004 1 :24:05 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-112 1 E-112 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 6/25/2004 Rig Release: 7/31/2004 Rig Number: Spud Date: 6/26/2004 End: 7/31/2004 Group: 6/28/2004 15:00 - 16:00 1.00 DRILL PULD SURFAC Stand back NMDC, UD stabalizer, MWD, motor, & bit. 16" MXC1 bit grade: 1-1-WT-A-E-I-SS-TD. 16:00 - 18:30 2.50 CASE RURD SURFAC Clear rig floor. Rig up to run 13-3/8" surf csg. Make dummy run with Vetco Grey casing hanger. PJSM with all crews on running 13-3/8" csg. 18:30 - 00:00 5.50 CASE RUNe SURFAC Run 13-3/8" Weatherford Float shoe, 1 its 13-3/8", 68#, L-80, BTC csg, Weatherford Float collar, 50 of 75 its 13-3/8",68#, L-80, BTC csg. Ran 13-3/8"x 16" Bow spring centralizers as follows = 1-10' above shoe, no centralizer between it. #1 & #2, 1 on every collar on its #3 thru #17, Total of 15 centralizers and 1 stop ring. Tight spot at 900' MD. Circulate hole clean and continue running casing. 6/29/2004 00:00 - 02:00 2.00 CASE RUNe SURFAC Continue to run 13-3/8" surface casing to btm. Ran last 25 of 75 jts. Float shoe @ 3,031.17', Float collar @ 2,987.94'. 02:00 - 03:15 1.25 CEMENTCIRC SURFAC Circ btm's up with Frank's tool. Break circulation at rate of 2.5 bpm @ 350 psi. Stage up rate to 7 bpm @ 450 psi. Reciprocate csg ??'- UP ??K, DN ??K. 03:15 - 03:45 0.50 CEMENT RURD SURFAC UD Frank's tool and RlU cement head. Break circulation. 03:45 - 05:00 1.25 CEMENTCIRC SURFAC Circ and Cond mud for cement. Stage up rate to 7 BPM @ 450 psi. Final mud properties 9.2 ppg, 45 vis, PV 15 YP 12, Gels 3/4, PH 8.0. 05:00 - 05:30 0.50 CEMENT SFTY SURFAC PJSM for surface cmt job with Co Man, TP, rig crew, cmt crew, & vac truck drivers. 05:30 - 08:45 3.25 CEMENT PUMP SURFAC Rig Up Dowell, Mix & pump 10 bbls CW100 at 8.3 ppg at rate of 5.5 bpm @ 120 psi, Shut down, Test lines to 3500 psi, Continue pumping CW100 to total of 50 bbls, Mix & pump 50 bbls MudPUSH II with red dye added mixed at 10.5 ppg at rate of 5.0 bpm @ 95 psi, Shut down and drop btm plug, Mix & pump 618 sxs (489.98 bbls) Lead ArcticSet III cmt mixed at 10.7 ppg w/ additives at rate of 7.0 bpm @ 150 psi, Followed by 219 sxs (100.35 bbls) Tail DeepCRETE cmt mixed at 12.0 ppg w/ additives at rate of 6.5 bpm @ 190 psi, Shut down and drop top plug, Displace cmt wI 20 bbls fresh water, Shut down and turn over to rig pumps and continue to displace wI 421 bbls 9.2 ppg mud (total of 441 bbls to bump plug) at rate of 7.0 bpm @ 400 to 720 psi, Slowed rate to 3.0 bpm @ 500 psi for last 10 bbls of displacement, Bump plug wI 1000 psi and held 5 min, Floats held- OK, CIP @ 08:45 hrs 6/29/04, Had good returns thru out job, Reciprocate csg. 15' until dropping top plug, Had 106 bbls good cmt returns to surface. 08:45 - 09:30 0.75 CASE MIT SURFAC Test casing to 2500 psi for 30 min. on chart -- OK. 09:30 - 10:30 1.00 CEMENT RURD SURFAC Check float equipment -- OK. Flush stack & flowline, RID Dowell cement head, UD landing jt. 10:30 - 13:30 3.00 WELCTL NUND SURFAC UD csg equip. NID diverter system & clear floor. 13:30 - 15:00 1.50 WELCTL NUND SURFAC N/U & Orient Vetco Gray Wellhead. Test to 5000 psi for 10 min. 15:00 - 18:00 3.00 WELCTL NUND SURFAC NIU BOPE and R/U to test. 18:00 - 23:30 5.50 WELCTL BOPE SURFAC Test BOPE to 250 psi low and 5000 psi high, Hydrill to 250 psi low and 3500 psi high. Test witnessed by John Spaulding AOGCC. 23:30 - 00:00 0.50 DRILL RIRD SURFAC Clear rig floor & install wear ring. 6/30/2004 00:00 - 01 :00 1.00 WELCTL NUND SURFAC RID BOPE test equip. Install wear bushing. 01 :00 - 04:30 3.50 DRILL PULD SURFAC Pick up 12-1/4" AutoTrak BHA = Bit, AutoTrak, NM FS, NM Stab, 3-NMCSDP, XIO, 3-HWDP, Jars, 26-HWDP, Ghost Reamer, Program & load tools, Surface test same. 04:30 - 05:30 1.00 DRILL DEQT SURFAC Shallow Test AutoTrak tool n OK. 05:30 - 06:30 1.00 DRILL TRIP SURFAC RIH to 2915' MD. 06:30 - 07:00 0.50 DRILL REAM SURFAC Break circ, wash & ream f/2915' to 2941' MD. Tag cement @ 2941' 07:00 - 08:30 1.50 CEMENT DSHO SURFAC Drill cement, float equipment, & 20' of new hole to 3065' MD 12323' Printed: 8/18/2004 1 :24:05 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-112 1 E-112 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 6/25/2004 Rig Release: 7/31/2004 Rig Number: Spud Date: 6/26/2004 End: 7/31/2004 Group: 6/30/2004 07:00 - 08:30 1.50 CEMENT DSHO SURFAC TVD. 08:30 - 09:30 1.00 DRILL CIRC SURFAC Circulate & displace hole with clean 9.2 ppg LSND mud. 09:30 - 10:30 1.00 DRILL LOT SURFAC RIU and perform LOT w/568 psi surface pressure, for an EMW of 13.9 ppg. 10:30 - 12:00 1.50 DRILL DRLG INTRM1 Drill 12-1/4" hole with AutoTrak f/3065' to 3098' MD /2342' TVD. ADT = 1.1 hrs, WOB = 5-35K Ib, 740 GPM @ 2500 psi, ROT = 110 RPM, UP 120K, DN 75K, ROT 93K, TO (on/off) 5-14/5-11. 12:00 - 00:00 12.00 DRILL DRLG INTRM1 Drill 12-1/4" hole with AutoTrak f/3098' to 4305' MD 12855' TVD. ADT = 8.8 hrs, WOB = 10-25K Ib, 720 GPM @ 2000 psi, ROT = 120 RPM, UP 118K, DN 85K, ROT 102K, TO (on/off) 5-1017. "Note: Had 600 units connection gas @ 3400' MD 12480' TVD. Gas stayed up 200-600 units for two stds, then back below 100 untils by 3560' MD. "Note: HotOil reestablished injection into 01 A of locked up annular disposal well 1 E-33. Broke at +/- 3000 psi. HotOiI pumped 85 bbls diesel 1 bpm @ 1350 psi & 80 bbls water 2 bpm @ 1600 psi. 7/1/2004 00:00 - 12:00 12.00 DRILL DRLG INTRM1 Drill 12-1/4" hole with AutoTrak f/4305' to 5565' MD 13347' TVD. ADT = 8.6 hrs, WOB = 10-30K Ib, 700 GPM @ 2200 psi, ROT = 120 RPM, UP 128K, DN 92K, ROT 106K, TO (on/off) 10/8. 12:00 - 00:00 12.00 DRILL DRLG INTRM1 Drill 12-1/4" hole with AutoTrak f/5565' to 6050' MD /3461' TVD. ADT = 10.0 hrs, WOB = 10-30K Ib, 700 GPM @ 2300 psi, ROT = 120 RPM, UP 140K, DN 90K, ROT 110K, TO (on/off) 9/8. Pump 30 bbl hi-vis weighted sweep at 5696' MD, saw no cuttings increase on btms up. Had 500 units connection gas at 5880' MD, and 700 unit spike at 5945' MD. Hard spots at 5900' MD & 5940' MD. 7/2/2004 00:00 - 12:00 12.00 DRILL DRLG INTRM1 Drill 12-1/4" hole with AutoTrak f/6050' to 6810' MD 13588' TVD. ADT = 8.9 hrs, WOB = 20-30K Ib, 740 GPM @ 2400 psi, ROT = 120 RPM, UP 135K, DN 86K, ROT 106K, TO (on/off) 11/10. Connection gas 700-1500 units, background gas 150-300 untis. 12:00 - 16:30 4.50 DRILL DRLG INTRM1 Drill 12-1/4" hole with AutoTrak f/6810' to TD at 6933' MD 13607' TVD. ADT = 3.2 hrs, WOB = 20-30K Ib, 740 GPM @ 2600 psi, ROT = 120 RPM, UP 137K, DN 85K, ROT 107K, TO (on/off) 1019. Connection gas 700-800 units, background gas 120-300 units. 16:30 - 17:00 0.50 DRILL CIRC INTRM1 Circulate while read logs & pick TD @ 6933 MD. 17:00 - 17:30 0.50 DRILL CIRC INTRM1 Circulate hole clean to clear BHA. 17:30 - 22:30 5.00 DRILL TRIP INTRM1 Observe well, static. Backream out of hole to 3020' MD with no problems. 22:30 - 23:00 0.50 DRILL CIRC INTRM1 Observe well, static. Circulate hole clean at 13-3/8" shoe. 23:00 - 00:00 1.00 DRILL TRIP INTRM1 Pump dry job and POH on elevators to 2000' MD. 7/3/2004 00:00 - 01 :00 1.00 DRILL TRIP INTRM1 POOH to BHA. 01 :00 - 03:00 2.00 DRILL PULD INTRM1 Download MWD & UD same. 03:00 - 04:00 1.00 CASE OTHR INTRM1 Pull wear bushing & make dummy run with landing jt. Install test plug. 04:00 - 05:00 1.00 WELCTL BOPE INTRM1 Change out top set of rams to 9-5/8" and test to 3500 psi high & 250 psi low. Chart 5 min. 05:00 - 06:30 1.50 CASE RURD INTRM1 RU equip. to run 9-5/8" csg. 06:30 - 07:00 0.50 CASE SFTY INTRM1 PJSM on running 9-5/8" csg. 07:00 - 12:00 5.00 CASE RUNC INTRM1 Run 9-5/8" casing to 3015' MD. At 13-3/8" csg shoe, UP 115K & DN 98K. 12:00 - 13:00 1.00 CASE CIRC INTRM1 Circulate casing at 13-3/8" shoe, staging up to 7 BPM @ 400 psi. 13:00 - 18:30 5.50 CASE RUNe INTRM1 Continue running 9-5/8" csg to btm. Worked thru bridge at 4024' MD. Total 175 jts ran. 18:30 - 21 :30 3.00 CEMENTCIRC INTRM1 Circ & cond mud for cement. UD Frank's running tool & MIU Dowell cement head. Printed: 8/18/2004 1 :24:05 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-112 1E-112 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 6/25/2004 Rig Release: 7/31/2004 Rig Number: Spud Date: 6/26/2004 End: 7/31/2004 Group: 2.50 CEMENT PUMP INTRM1 RlU Dowell, Mix & pump 10 bbls CW100 at 8.3 ppg at rate of 4.0 bpm @ 230 psi, Shut down, Test lines to 3500 psi, Continue pumping CW100 to total of 40 bbls at rate of 5.0 bpm @ 280 psi, Mix & pump 40 bbls MudPUSH II mixed at 10.5 ppg at rate of 4.6 bpm @ 265 psi, Shut down and drop btm plug, Mix & pump 649 sxs (260.1 bbls) DeepCRETE cmt mixed at 12.5 ppg w/ additives at rate of 5.5 bpm @ 300 psi, Shut down and drop top plug, Displace cmt w/3 bbls fresh water, Shut down and turn over to rig pumps and continue to displace w/521.2 bbls 9.0 ppg oil based mud at rate of 7.5 bpm @ 300 to 800 psi, Slowed rate to 3.0 bpm @ 500 psi for last 10 bbls of displacement, pumped calculated displacement of 519.3 bbl plus 3 bbl (1/2 shoe track) for total displacement of 522.3 bbl, Plug did not bump, Floats held- OK, CIP @ 23:59 hrs 7/3/04, Had good returns throughout job, reciprocated casing throughout job & finally set on btm @ 3656 stks into displacement. UP 200K, DN 105K with 9-5/8" csg on btm. 7/3/2004 21 :30 - 00:00 7/4/2004 00:00 - 01 :30 1.50 CEMENT PULD INTRM1 01 :30 - 02:30 1.00 WELCTL OTHR INTRM1 02:30 - 03:30 1.00 DRILL LOT INTRM1 03:30 - 05:00 1.50 WELCTL EORP INTRM1 05:00 - 05:30 0.50 WELCTL OTHR INTRM1 05:30 - 09:00 3.50 DRILL PULD PROD 09:00 - 12:00 3.00 DRILL TRIP PROD 12:00 - 13:30 1.50 DRILL TRIP PROD 13:30 - 14:30 1.00 DRILL TRIP PROD 14:30 - 15:30 1.00 RIGMNT RSRV PROD 15:30 - 16:00 0.50 DRILL TRIP PROD 16:00 - 16:30 0.50 DRILL CIRC PROD 16:30 - 19:00 2.50 CASE DEQT PROD 19:00 - 22:00 22:00 - 22:30 22:30 - 23:00 3.00 DRILL 0.50 DRILL 0.50 DRILL TRIP PROD PULD PROD PULD PROD 23:00 - 00:00 1.00 DRILL TRIP PROD 7/5/2004 00:00 - 01 :30 1.50 DRILL TRIP INTRM1 01 :30 - 02:00 0.50 CASE MIT INTRM1 02:00 - 03:30 1.50 DRILL TRIP INTRM1 03:30 - 05:00 1.50 CASE MIT INTRM1 RID cement head & UD 9-5/8" landing jt. Install Vetco Gray 9-5/8" pack off. Test same to 2500 psi for 30 min - OK. Rig up & pump down 13-3/8" X 9-5/8" annulus w/9.5 bbls mud, pumped away 2 bbls, monitor for 10 min held 480 psi. Leak off at 540 psi = 13.5 ppg EMW. Change out top rams to 3-1/2" X 6". Test same to 250 psi low and 5000 psi high. - OK. RID test jt & install wear bushing. Pick up 8-1/2" BHA, Bit, AutoTrak Gen 2.5, ORD caliper tool, MAP sub, NMFS, NM Stab, 3-NMCSDP, XO, 3-HWDP, Jars, 2-HWDP, 21 jts 5" DP, & 8-1/2" Ghost Reamer. PU 76 jts 5" DP from pipe shed. Shallow test AutoTrak 30 min at 1600' MD. Cont. PU 5" DP from pipe shed. Total 114 jts PU from pipe shed. RIH from derrick to 6565' MD. Service rig, cut 90' drilling line. RIH to 6753' MD. Wash f/6753' to 6842' MD. Tagged up on cmt at 6842' MD, 6' above float collar (5 stks). CBU for casing test. Attempted to test 9-5/8" csg with no success. 1st attempt - pressured up to 2900 psi max (could not build to 3000 psi). Bled off to 1000 psi in 5 min. 2nd attempt - pressured up to 1810 psi max. Bled off to 700 psi in 5 min. Pump dry job and POOH. UD AutoTrak, breakdown & remove sources. MlU Baker Retrievomatic Packer per Baker rep and RIH to 70' MD in order to pressure test casing hanger & pup. Closed bag & Pressured up DP to 1180 psi and bled to 970 psi in 2 min. Tested backside to 1640 psi, held 5 min. RIH f/70' MD to 760' MD. RIH f/760' to 3540' MD. Set PKR & pressure test backside (casing) to 1500 psi, held 5 min. Increased pressure up to 3000 psi, held 5 min. RIH f/3540' to 6830' MD. Set PKR above shoe track & below lowest collar. Test 9-5/8" casing to 3000 psi on chart for 30 min - OK. Printed: 8/18/2004 1 :24:05 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-112 1 E-112 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 6/25/2004 Rig Release: 7/31/2004 Rig Number: Spud Date: 6/26/2004 End: 7/31/2004 Group: 7/512004 05:00 - 08:00 3.00 DRILL TRIP INTRM1 08:00 - 08:30 0.50 DRILL PULD INTRM1 08:30 - 09:00 0.50 DRILL PULD INTRM1 09:00 - 12:00 3.00 DRILL TRIP INTRM1 12:00 - 12:30 0.50 DRILL TRIP INTRM1 12:30 - 14:30 2.00 CEMENT DSHO INTRM1 14:30 - 15:00 0.50 DRILL CIRC INTRM1 15:00 - 15:30 0.50 DRILL LOT INTRM1 15:30 - 16:15 0.75 DRILL DRLG PROD 16:15 - 16:45 0.50 DRILL CIRC PROD 16:45 - 17:00 0.25 DRILL CIRC PROD 17:00 - 00:00 7.00 DRILL DRLG PROD 7/6/2004 00:00 - 03:30 3.50 DRILL DRLG PROD 03:30 - 05:00 1.50 DRILL TRIP PROD 05:00 - 12:00 7.00 DRILL DRLG PROD 12:00 - 15:30 3.50 DRILL DRLG PROD 15:30 - 16:15 0.75 DRILL DRLG PROD 16:15 - 00:00 7.75 DRILL DRLG PROD 7/7/2004 00:00 - 02:30 2.50 DRILL DRLG PROD 02:30 - 03:00 0.50 WAlTON ORDR PROD 03:00 - 12:00 9.00 DRILL DRLG PROD 12:00 - 21 :45 9.75 DRILL DRLG PROD 21 :45 - 22:00 0.25 DRILL DRLG PROD 22:00 - 23:00 1.00 DRILL DRLG PROD POOH fl 6830' MD wI Baker Retrievomatic Packer. UD Baker Retrievomatic Packer & clean rig floor. Pick up 8-1/2" BHA, Bit, AutoTrak Gen 2.5, ORD caliper tool, MAP sub, NMFS, NM Stab, 3-NMCSDP, XO, 3-HWDP, Jars, 2-HWDP, 21 jts 5" DP, & 8-1/2" Ghost Reamer. RIH to 6100' MD. Shallow tested AutoTrak at 1454' MD. RIH f/6100' to 6842' MD. Drill out cement, float collar @ 6848' MD, cmt, shoe @ 6925' MD, cmt to 6933' MD. Drill new hole f/6933' to 6953' MD 13610' TVD. WOB = 5-10K Ib, 600 GPM @ 2900 psi, ROT = 110 RPM, UP 135K, DN 76K, ROT 100K, TQ (on/off) 9/8. Circ hole clean. Rig up & perform LOT of 12.8 EMW wI 9.2 ppg OBM, 678 psi, 3610' TVD. Drill 8-1/2" hole with AutoTrak f/6953' to 7028' MD. WOB = 5-10K Ib, 600 GPM @ 2900 psi, ROT = 110 RPM, UP 145K, DN 75K, ROT 102K, TO (on/off) 8.5/8. Circ hole clean. Perform PWD base line test. Clean hole ECD's at 600 GPM & 110 RPM = 10.26 ppg EMW. Drill 8-1/2" hole with AutoTrak f/7028' to 7750' MD 13595' TVD. ADT = 4.6 hrs, WOB = 5-20K Ib, 600 GPM @ 2900 psi, ROT = 110 RPM, UP 156K, DN 68K, ROT 100K, TQ (on/off) 818. Drill 8-1/2" hole with AutoTrak f/7750' to 8023' MD 13581' TVD. ADT = 2.0 hrs, WOB = 5-10K Ib, 600 GPM @ 2900 psi, ROT = 110 RPM, UP 152K, DN 73K, ROT 100K, TQ (on/off) 918. Backream out to 7800' MD for open hole sidetrack. Perform open hole sidetrack f/7800' MD to 7903' MD. ADT = 3.7 hrs, WOB = 0-2K Ib, 600 GPM @ 2950 psi, ROT = 90 RPM, UP 146K, DN 76K, ROT 98K, TQ (on/off) 9/10. Cont. open hole sidetrack f/7903' MD to 7961' MD 13585' TVD. WOB = 5-1 OK Ib, 600 GPM @ 2900 psi, ROT = 110 RPM, UP 155K, DN 70K, ROT 100K, TO (on/off) 7/8.5. Cont. open hole sidetrack fl 7961' MD to 8023' MD. Back to total depth before sidetrack at 16: 15 hrs. Drill 8-1/2" hole with AutoTrak f/8023' to 8699' MD 13592' TVD. ADT = 8.15 hrs, WOB = 5-1 OK Ib, 600 GPM @ 2900 psi, ROT = 110 RPM, UP 165K, DN 63K, ROT 100K, TQ (on/off) 9/10. Drill 8-1/2" hole with AutoTrak f/8699' to 8977' MD 13584' TVD. ADT = 1.1 hrs, WOB = 5-10K Ib, 600 GPM @ 3050 psi, ROT = 110 RPM, UP 170K, DN 65K, ROT 100K, TO (on/off) 8/10. Geologist evaluate Logs· Circu, Rotate & Recip drill string - PR 600 gpm, 110 RPM Drill 8-1/2" hole with AutoTrak f/8977' to 9904' MD 13576' TVD. ADT = ?? hrs, WOB = 5-10K Ib, 600 GPM @ 3100 psi, ROT = 110 RPM, UP 175K, DN 65K, ROT 105K, TO (on/off) 10112 Drill 8-1/2" hole with AutoTrak f/9,904' to 10,948' MD 13604.5' TVD. WOB = 5-10K Ib, 600 GPM @ 3100 psi, ROT = 110 RPM, UP 180K, DN 60K, ROT 105K, TO (on/off) 10/12 Stuck at 10,948' while drilling ahead. (Torque went to 25K ft-Ib). Worked pipe, jars would not go off. Pulled 120K overpull (325K), and pulled free. A small fault(??), is suspected. Recip and rotate, pump hi-vis weighted, sweep, and circ hole clean. Printed: 8/18/2004 1 :24:05 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-112 1 E-112 ROT - DRILLING n 1334@ ppco.com Doyon 141 Start: 6/25/2004 Rig Release: 7/31/2004 Rig Number: Spud Date: 6/26/2004 End: 7/31/2004 Group: 7/7/2004 23:00 - 00:00 1.00 DRILL DRLG PROD 7/8/2004 00:00 - 04:45 4.75 DRILL DRLG PROD 04:45 - 05:15 0.50 DRILL CIRC PROD 05:15 - 05:30 0.25 DRILL SURV PROD 05:30 - 12:00 6.50 DRILL REAM PROD 12:00 - 13:30 1.50 DRILL REAM PROD 13:30 - 14:00 0.50 DRILL CIRC PROD 14:00 - 16:30 2.50 DRILL TRIP PROD 16:30 - 18:00 1.50 DRILL CIRC PROD 18:00 - 22:00 4.00 WAlTON EOIP PROD 22:00 - 00:00 2.00 DRILL CIRC PROD 7/9/2004 00:00 - 01 :00 1.00 DRILL CIRC PROD 01 :00 - 06:30 5.50 DRILL TRIP PROD 06:30 - 07:00 0.50 DRILL OBSV PROD 07:00 - 11 :00 4.00 DRILL TRIP PROD 11 :00 - 12:30 1.50 DRILL PULD PROD 12:30 - 12:45 0.25 CASE SFTY CMPL TN 12:45 - 13:30 0.75 CASE RURD CMPL TN 13:30 - 18:30 5.00 CASE PULR CMPL TN 18:30 - 20:00 1.50 CASE PULR CMPL TN 20:00 - 22:00 2.00 CASE RUNL CMPL TN 22:00 - 22:15 0.25 CASE CIRC CMPL TN 22:15 - 00:00 1.75 CASE RUNL CMPL TN 7/10/2004 00:00 - 02:00 2.00 CASE RUNL CMPL TN 02:00 - 02:30 0.50 CMPL TN PCKR CMPL TN Drill 8-1/2" hole with AutoTrak f/10,948' to 11,010' MD 13605' TVD. WOB = 5-10K Ib, 600 GPM @ 3100 psi, ROT = 150 RPM, UP 185K, DN 75K, ROT 11 OK, TO (on/off) 12/11. ADT = 6.4 hrs Drill 8-1/2" hole with AutoTrak f/11 ,010' to 11,425' MD 13604' TVD. WOB = 12-14K Ib, 550-600 GPM @ 3550 psi, RPM = 150, UP 185K, DN 74K, ROT 111 K, TO (on/off) =12-14K 111 K ft-Ib. ECD - 11.3-11.6 ppg ADT = 2.7 hrs Circ sweep to surface -- MW 9.4=>9.3 ppg, FV 84=>75 sec. Survey and downlink AutoTrak for backreaming. Backream from 11,425' -7,960' at 100 RPM, 600 GPM. Continue backreaming to 6,900' at 100 RPM and 600 GPM. No problems, hole was clean. Circ hole clean at 9-5/8" shoe. RIH to TD at 11,425'. Pump high-Vis, weighted sweep, and circulate hole clean. Circ and Cond mud. - Hot Oil heating OBM in storage tanks - Had two mechanical problems wI Vac Trucks( 1 tracter had to be replaced (leaking radiator) & 1 had a problem with pony motor. Displace hole to new solids free OBM. Fin Displacing hole to new solids free OBM and circ hole to shear new mud, circ at 600 gpm at 3,500 psi. rot wt 111K, up wt 185K, dn wt 74K Precautionary pumped out of hole from 11,425' to 6,900' to up inside 9 518" csg with no problems, pumped out at 420 gpm at 1,700 psi Monitored well at shoe-static Pumped dry job and POOH on elevators from 6,900' to 63', stood back HWDP Down loaded MWD/Auto trak and stood back same Held PJSM on RU and running 5 1/2" liner RU Doyons 5 1/2" liner running tools PU and ran 5 1/2" liner per well program, ran 5 1/2" ROT silver bullet guide shoe with no float, 144 jts, 4,465.33' of 5 1/2" 15.5#, L-80, DWC liner, placed blank liners across shale sections per geology, ran 64 jts (1,969.15') of blank liner and 80 jts (2,496.18') of slotted liner, ran 1- 5 1/2" x 81/4" spiralglide centralizers 1/jtto shoe (144 total) then ran 10 restrictor packers with 20 spacer rings placed on blank liner to isolate shale sections, liner wt 77K up, 68K dn MU Baker 190-47 csg seal bore ext, 7" x 9 5/8" Flexlock liner hanger, "RS" pack-off seal nipple and "HRD" ZXP liner top packer, liner wt with hanger 80K up and 70K dn RIH with 5 1/2" liner on 5" DP to 6,850' (Csg Shoe @ 6,926') with full returns and no problems Circ 1 DP volume at csg shoe, staged pump rate up to 6 bpm at 550 psi, st wt up 106K, dn wt 84K, set torque limiter on top drive to 8,500 ft-Ibs and est rotation at 10 rpm's with 3,500 ft-Ibs torque Cont RIH with liner on 5" DP from 6,850' to 8,803' with full returns and no losses Cont RIH with 5 1/2" liner on 5" DP from 8,803' to 11,297', no problems in open hole or mud losses, st wt up 153K, dn wt 85K Dropped 29/32" ball and pumped down to seat, staged up pump rate to 5 bpm at 580 psi, with ball on seat pressured up to 2,500 psi to set hanger, then pressure up to 3,500 psi to set packer and pressure bleeding down past ball seat, cont to set packer by PU and releasing dogs then setting 50K string wt down, then rotated at 50 rpms and set Printed: 8/18/2004 1 :24:05 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1E-112 1 E-112 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 6/25/2004 Rig Release: 7/31/2004 Rig Number: Spud Date: 6/26/2004 End: 7/31/2004 Group: 7/10/2004 02:00 - 02:30 0.50 CMPL TN PCKR CMPL TN 80K down wlrotating, packer set with no problems, set lower lateral liner with TOL @ 6,776' and shoe at 11 ,297', st wt after setting liner 142K up and 105K dn with 115K rotating wt 02:30 - 03:00 0.50 CMPL TN DEQT CMPL TN RU and tested annulus above ZXP packer to 1,000 psi for 5 min, good test 03:00 - 03:15 0.25 CMPL TN OBSV CMPL TN Monitored well-static 03:15 - 07:30 4.25 CMPL TN TRIP CMPL TN Pumped dry job and POOH LD liner setting tool 07:30 - 10:00 2.50 LOG RURD CMPL TN Held PJSM, then RU Schlumberger wireline (SWS) scheaves and 7" shooting nipple with pack-off 10:00 - 15:00 5.00 LOG ELOG CMPL TN Ran USIT Bond log with GRlCCL, logged up from 6,700' to 4,700' with log showing fair to good bond, POOH 15:00 - 16:30 1.50 LOG RURD CMPL TN LD logging tools and RD SWS 16:30 - 17:00 0.50 WINDOWPULD CMPL TN PU Whipstock and mills to rig floor 17:00 - 22:00 5.00 WINDOWPULD CMPL TN PU and MU Baker seal assembly, 20 jts of 5" DP for space out and 9 5/8" Baker btm trip whipstock, milling assembly with LWD/MWD and oriented BHA #7 22:00 - 22:45 0.75 WINDOWTRIP CMPL TN RIH WI HWDP on BHA #7 to 1,600' and shallow tested MWD, circ at 296 gpm at 550 psi 22:45 - 00:00 1.25 WINDOWTRIP CMPL TN TIH with whipstock assembly (BHA #7) from 1,600' to 3,100' 7/11/2004 00:00 - 01 :45 1.75 WINDOWTRIP CMPL TN RIH with whipstock on 5" DP (BHA #7) from 3,100' to 5,977' 01 :45 - 03:00 1.25 WINDOWCIRC CMPL TN Est Circ and made MADD pass to correlate DP to K-13 sand, Logged down from 6,044' to 6,092' (GR depth 5,305' to 5,353') shifted MWD down 2' to put on depth 03:00 - 03:30 0.50 WINDOWTRIP CMPL TN Cont RIH with whipstock to 6,730', st wt up 132K, dn wt 90K 03:30 - 04:15 0.75 WINDOWSETW CMPL TN Oriented whipstock and RIH, tagged top of liner at 6,776', set btm trip anchor and whipstock at 10 deg left of high side, set top of whipstock at 6,096', worked 45K wt down and sheared bolt, st wt up after setting whipstock 118K and 80K dn 04:15 - 05:30 1.25 WINDOWCIRC CMPL TN Displaced out 9.3 ppg solids free MOBM with 9.0 ppg reconditioned OBM, circ at 8 bpm at 1,000 psi 05:30 - 10:00 4.50 WINDOWSTWP CMPL TN Milled window in 9 5/8" csg, top of window at 6,096', btm of window at 6,112', drilled 81/2" hole to 6,134' (38'), 2-3Kwom, 60-100 rpm's, 470 gpm, 1,300 psi, rot wt 107K, up wt 142K, dn wt 85K, torque off btm 8K ft-Ibs, on btm 1 0-12K ft-Ibs 10:00 - 11 :00 1.00 WINDOWCIRC CMPL TN Pumped hi vis sweep and circ hole clean while working mills thru window, had 10% increase in cuttings back from sweep, circ at 550 gpm at 2,000 psi, shut pumps down and ran mills thru window without any problems 11 :00 - 11 :15 0.25 WINDOWOTHR CMPL TN Monitored well-static 11 :15 - 13:30 2.25 WINDOWTRIP CMPL TN Pumped dry job and POOH from 6,134' to 930' to BHA #7 13:30 - 15:30 2.00 WINDOWPULD CMPL TN Monitored well at HWDP-static, POOH standing back HWDP, downloaded MWD and LD milling assembly, upper mill in gauge, cleared rig floor 15:30 - 16:30 1.00 WELCTL TRIP CMPL TN RIH with 5 stds HWDP, MU HES 9 5/8" RTTS/Storm packer and set same at 48', pressure tested to 1,500 psi and ck ok **Note** Storm packer was set due to open fromations to provide 2 nd barrier. 16:30 - 17:30 1.00 WELCTL CIRC CMPL TN Pulled wear bushing and flushed out BOP stack after milling window 17:30 - 23:30 6.00 WELCTL BOPE CMPL TN RU and tested BOPE, tested valves, manifold and rams to 250 psi low and 5,000 psi high, tested annular to 250 psi and 3,500 psi, performed accumulator test, RD Test equipment. NOTE: John Spaulding W/AOGCC waived witnessing of test 23:30 - 00:00 0.50 WELCTL TRIP CMPL TN Installed wear bushing, RIH to 47' with packer retrieving tool and Printed: 8/18/2004 1 :24:05 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-112 1 E-112 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 6/25/2004 Rig Release: 7/31/2004 Rig Number: Spud Date: 6/26/2004 End: 7/31/2004 Group: 7/11/2004 23:30 - 00:00 0.50 WELCTL TRIP CMPL TN washed top of storm packer NOTE: RU MI Swaco's solids control van 7/12/2004 00:00 - 01 :00 1.00 WELCTL TRIP CMPL TN Latched onto Storm Packer at 48' and unseated pkr, well-static, POOH LD pkr and stood back 5 stds HWDP 01 :00 - 03:30 2.50 DRILL PULD PROD2 PU & MU 81/2" BHA #8 with Bakers AutoTrak tool and RIH to 157', PU AutoTrak and LD ORD caliper tool and uploaded same 03:30 - 07:00 3.50 DRILL TRIP PROD2 RIH from from 157' to 6,000', PU ghost reamer at 980' and shallow test Autotrak tool at 1,450' then RIH to 6,000' 07:00 - 08:30 1.50 RIGMNT RSRV PROD2 Slip and cut 45' of drlg line and serviced rig 08:30 - 09:00 0.50 DRILL REAM PROD2 Est Circ and RIH from 6,000', no problems going thru window at 6,096', then washed 20' to btm at 6,134' 09:00 - 00:00 15.00 DRILL DRLG PROD2 Drilled 8 1/2" hole with AutoTrak from 6,134' to 7,763' MD/3,430' TVD, (1,629') ADT 9.5 hrs, 5-15K wob, 110-150 rpm's, 640 gpm, off btm pressure 3,125 psi, on btm 3,200 psi, off btm torque 11 K ft-Ibs on btm 12K ft-Ibs, rot wt 98K, up wt 168K, dn wt 66K, 9.0+ ppg MW, ave ECD 10.4 ppg, ave BGG 350 units, max gas 1,600 units 7/13/2004 00:00 - 12:00 12.00 DRILL DRLG PROD2 Drilled 8 1/2" hole with AutoTrak tool from 7,763' to 8,618' MD/3,439' TVD (855') ADT 8.2 Hrs, 5-25K wob, 150 rpm's, 640 gpm, off btm pressure 3,150 psi, on btm 3,225 psi, off btm torque 10K ft-Ibs, on btm 11 K ft-Ibs, rot wt 98K, up wt 165K, dn wt 64K, pumped weighted hi vis sweep at 8,050' with 50% increase in cuttings back, drilled thru several calcite stringers, 9.0+ MW ECD ave 10.4 ppg, ave bgg 400 units max gas 1,900 units 12:00 - 00:00 12.00 DRILL DRLG PROD2 Drilled 8 1/2" hole with AutoTrak tool from 8,618' to 9,712' MD/3,426' TVD (1,094') ADT 8.2 Hrs, 5-25K wob, 150 rpm's, 640 gpm, off btm pressure 3,400 psi, on btm 3,425 psi, off btm torque 1 OK ft-Ibs, on btm 12.5K ft-Ibs, rot wt 97K, up wt 168K, dn wt 55K, cont to drill thru calcite stringers, 9.1 MW ECD ave 10.7 ppg, ave bgg 400 units max gas 1,200 units 7/14/2004 00:00 - 12:00 12.00 DRILL DRLG PROD2 Drilled 81/2" hole with AutoTrak tool from 9,712' to 10,543' MD/3,422' TVD (831') ADT 8.3 Hrs, 5-25K wob, 150 rpm's, 640 gpm, off btm pressure 3,400 psi, on btm 3,500 psi, off btm torque 13K ft-Ibs, on btm 15K ft-Ibs, rot wt 100K, up wt 180K, dn wt 53K, cont to drill thru calcite stringers, 9.1 MW ECD ave 10.7 ppg, max ECD 10.9 ppg, ave bgg 300 units max gas 800 units, pumped 1-weighted hi vis sweep with no increase in cuttings, at 10,359' began running HWDP for push pipe 12:00 - 00:00 12.00 DRILL DRLG PROD2 Drilled 8 1/2" hole with AutoTrak tool from 10,543' to 11,178' MD/3,413' TVD (635') ADT 8.3 Hrs, 5-25K wob, 150 rpm's, 640 gpm, off btm pressure 3,700 psi, on btm 3,800 psi, off btm torque 13K ft-Ibs, on btm 15K ft-Ibs, rot wt 110K, up wt 180K, dn wt 50K, 9.0+ MW ECD ave 10.7 ppg, max ECD 11.0 ppg, ave bgg 200 units max gas 1800 units, pumped 1-weighted hi vis sweep with no increase in cuttings, ran a total of 8 stds HWDP for push pipe 7/15/2004 00:00 - 01:15 1.25 DRILL DRLG PROD2 Drilled 8 1/2" hole with AutoTrak tool from 11,178' to 11,271' (93') 01:15 - 01:45 0.50 RIGMNT RSRV PROD2 Changed out 2 valves on #2 mud pump, circ hole at 460 gpm at 2,300 psi 01 :45 - 02:30 0.75 DRILL DRLG PROD2 Drilled 8 1/2" hole with AutoTrak tool from 11,271' to 11,285' MD/3,408' TVD (14') (TD) ADT 1.3 Hrs, 5-10K wob, 150 rpm's, 630 gpm, off btm pressure 3,550 psi, on btm 3,700 psi, off btm torque 13K ft-Ibs, on btm 14K ft-Ibs, rot wt 108K, up wt 180K, dn wt 50K, 9.0 MW ECD ave 10.7 ppg, max ECD 11.1 ppg, 02:30 - 02:45 0.25 DRILL OBSV PROD2 Monitored well-static 02:45 - 03:00 0.25 DRILL CIRC PROD2 Circ hole to clear BHA, 630 gpm, 3,550 psi Printed: 8/18/2004 1 :24:05 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-112 1 E-112 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 6/25/2004 Rig Release: 7/31/2004 Rig Number: Spud Date: 6/26/2004 End: 7/31/2004 Group: 7/15/2004 03:00 - 03:30 0.50 DRILL REAM PROD2 Began backreaming out of hole, backreamed out from 11,285' to 11,180' at drlg rate 03:30 - 04:30 1.00 RIGMNT RGRP PROD2 High line SCR breaker on rig failed, started and supplemented hi-line power with rig motors while repairing breaker, no problems reported at CPF 1 04:30 - 05:30 1.00 DRILL REAM PROD2 Backreamed out of hole from 11,180 to 10,630' at drlg rate, 640 gpm, 3,550 psi and 150 rpm's when swivel packing failed on top drive 05:30 - 06:30 1.00 RIGMNT RSRV PROD2 Changed out swivel packing on top drive, circ hole at 255 gpm at 900 psi, rig back on highline at 06:30 hrs Note: Roustabout relieving on rig floor got a small amount of OBM in left eye when swivel packing failed, flushed eye at rig then, sent to KOC Medic and had eyes flushed again and returned to work 06:30 - 13:15 6.75 DRILL REAM PROD2 Fin backreaming out of hole from 10,630' to 6,002' to above top of window at 6,096', circ and rotated at 630 gpm, 2,500 psi and 150 rpm's with no problems 13:15 - 14:30 1.25 DRILL CIRC PROD2 Monitored well at window-static, circ hole clean by circ 2X btms up at 640 gpm, 2,500 psi, no increase in cuttings at btms up, st wt up 135K, 85K dn 14:30 - 16:45 2.25 DRILL TRIP PROD2 Pumped dry iob and POOH from 6,002' to 330', SLM no corr. 16:45 - 19:00 2.25 DRILL PULD PROD2 POOH standing back HWDP, downloaded Autotrak and LD same 19:00 - 20:30 1.50 DRILL PULD CMPL T2 PU & MU Baker fixed lug whipstock retrieving tool, BHA #9 with MWD and orient same 20:30 - 21 :45 1.25 DRILL PULD CMPL T2 RIH with BHA #9 with 9 stds HWDP, PU additional 18 its of 5" HWDP from pipe shed while RIH to 1,482', shallow tested MWD and ck ok 21 :45 - 00:00 2.25 DRILL TRIP CMPL T2 TIH with BHA #9 from 1,482' to 6,030' ( Top of window @ 6,096') 7/16/2004 00:00 - 01 :15 1.25 DRILL CIRC CMPL T2 Est Circ and oriented whipstock retrieving tool, latched onto whipstock and released same by pulling 67K over st wt to release, st wt up 148K, dn 85K 01:15 - 02:00 0.75 DRILL CIRC CMPL T2 Circ btms up after releasing whipstock, circ at 420 gpm 1,500 psi, no gas on btms up 02:00 - 02:15 0.25 DRILL OBSV CMPL T2 Monitored well-static 02:15 - 07:00 4.75 DRILL TRIP CMPL T2 POOH from 6,102' to 5,550', hole taking calc fill, pumped dry job and cont POOH to 116', stood back HWDP, no problems POOH 07:00 - 11 :00 4.00 DRILL PULD CMPL T2 LD whipstock retrieving BHA #9 with MWD, LD whipstock and 20 its of 5" DP used as spacer pipe, cleared rig floor 11 :00 - 11 :30 0.50 CASE RURD CMPL T2 RU Doyon's 51/2" liner running tools and held PJSM 11:30-15:15 3.75 CASE PULR CMPL T2 PU and RIH with 5 1/2" 15.5#, L-80 DWC liner to 5,124'. ran 5 1/2" guide shoe with no float, blank bent jt with insert pack-off on btm, then RIH with 71 slotted its and 69 its of blank liner, altemating slot/blank its, ran 71 its, 2,913.10' of slotted and 71 its, 2,205.48' of blank liner, ran 140 SpiralGlide centralizers 15:15 - 15:30 0.25 CASE RURD CMPL T2 RD 5/12" Tongs and RU to run 31/2" wash string, held PJSM 15:30 - 22:30 7.00 CASE OTHR CMPL T2 MU HR liner wash string assembly, RIH PU 161 its of 3 1/2" Hydril 511 tbg and tagged pack-off bushing and spaced out wash string 22:30 - 00:00 1.50 CASE PULR CMPL T2 MU Baker's model B-1, 7" x 9 5/8" Hook liner hanger assembly for LEM, MU 1 std of 5" DP, RIH to 5,156' and est circ thru wash string at 168 gpm, (4 bpm) at 600 psi, st up wt 11 OK, dn wt 84K, RD 3 1/2" handling tools and cleared rig floor 7/17/2004 00:00 - 01 :00 1.00 CASE RUNL CMPL T2 TIH with liner and hook hanger assembly on 5" DP from 5,156", went past top window at 6,096' and tagged SBE on lower lateral 01 :00 - 04:00 3.00 CASE OTHR CMPL T2 PU liner to above top of window at 6,096' and rotated liner, RIH and tagged up again at SBE at 6,808', PU and RIH and tagged SBE a 3rd time, PU to above top of window at 6,096' and rotated liner at 10 rpm's Printed: 8/18/2004 1 :24:05 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-112 1 E-112 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 6/25/2004 Rig Release: 7/31/2004 Rig Number: Spud Date: 6/26/2004 End: 7/31/2004 Group: and 6,500 ft-Ibs of torque, liner would only rotate when going down, tagged btm of window at 6,112', released torque RIH thru window and cant RIH, RIH from 6,112' to 11,245', ran 51 stds DP and 15 stds HWDP for push pipe, worked last 2 stds thru bridges to btm, no other problems RIH Est circ at 168 gpm at 850 psi, st wt up 185K, dn 65K, located window and latched hook hanger, tagged 3' high, unhooked from window and was able to work liner deeper past window, PU and rehooked hanger in window, tagged at 6,115', 3' deeper than btm of window at 6,112', verified hook by PU and unhooking then relatching hanger 1.25 CASE OTHR CMPL T2 Dropped 29/32" ball and pumped down to seat, pressured up to 4,350 psi and sheared ball seat, PU and verified running tool was released Set top of hook hanger at 6,095' with shoe at 11,252' 2.75 CASE CIRC CMPLT2 Monitored well-static, took on solids free MOSM into pits, then displaced out OSM in 5 1/2" x 8 1/2" annulus with 229 bbls of 9.2 ppg solids free MOSM, circ at 294 gpm at 1,625 psi, unstung from pack-off and displaced inner annulus 3 1/2" x 51/2" with 123 bbls of 9.2 ppg MOSM, circ at 294 gpm at 1,400 psi Pumped dry iob and POOH with 15 stds HWDP (dry), POOH with 51 stds of DP (wet), POOH to setting tool, SLM No Corr. Pumped additional dry iob to LD wash string RU 3 1/2" tools to LD 3 1/2" wash string LD hanger running tool POOH from 5,200' to 2,500' LD 70 its 3 1/2" wash pipe, tubing tongs failed Changed out rigs hydraulic tubing tongs POOH LD an additional 31 its of 31/2" wash pipe, 101 total LD (60 its remaining in hole) Fin POOH LD 60 jts (161 total) of 31/2" wash string LD setting tool and RD 3 1/2" tools and RU 4 1/2" handling tools Held PJSM with rig crews on PU and running of 4 1/2" tbg and LEM assembly PU and MU 4 1/2" seal assembly, 22 its (681.20') of 4 1/2", 12.6#, L·BO 1ST tubing, pup jt, 3.562" DS nipple, pup it and LEM/Seal Sore ReceptaclelZXP liner top packer assembly (794.81' total) RIH with LEM assembly on 5" DP from 795' to 6,094', latched into hook hanger setting 30K wt down then PU 10K over sl. wt to verify latch, st wt up 155K, dn wt 108K Dropped 29/32" ball and pumped ball down to seat, pressured up to 3,000 to release from running tool and ball seat blew early, packer set early and HRD running tool not released, top of ZXP packer set at 6,038' Dropped 2nd ball, (11/2") and attempted to pump down and well pressured up to 600 psi, shut down Installed safety valve and Cleaned rig floor waiting on HES slickline unit RU HES slickline and RIH with 2.7" swedge tool and attempted to push ball down to seat, was unable to get deeper than 5,590', POOH Pumped 31 bbls to seat ball with no success, pumped at 2 bpm pressure increased to 650 psi and after 13.5 bbls pressure dropped back to 490 psi, shut down after 31 bbls Sled well to -0- and monitored well, bled back 11.5 bbls then well was static Dropped 13/4" ball then RIH with slickline and 2.5" gauge ring, worked 7/17/2004 01 :00 - 04:00 3.00 CASE OTHR CMPL T2 04:00 - 07:00 3.00 CASE RUNL CMPL T2 07:00 - 11 :00 4.00 CASE OTHR CMPL T2 11:00-12:15 12:15 - 15:00 15:00 - 19:00 4.00 CASE RUNL CMPL T2 19:00 - 19:15 0.25 CASE CIRC CMPL T2 19:15 - 19:45 0.50 CASE RURD CMPL T2 19:45 - 20:15 0.50 CASE OTHR CMPL T2 20:15 - 22:30 2.25 CASE PUTS CMPL T2 22:30 - 23:00 0.50 RIGMNT RSRV CMPL T2 23:00 - 00:00 1.00 CASE PUTS CMPL T2 7/18/2004 00:00 - 02:00 2.00 CASE PUTS CMPL T2 02:00 - 02:45 0.75 CASE RURD CMPL T2 02:45 - 03:00 0.25 CMPL TN SFTY CMPL T2 03:00 - 05:30 2.50 CMPL TN PULD CMPL T2 05:30 - 09:15 3.75 CMPL TN RUNT CMPL T2 09:15 - 10:00 0.75 CMPL TN PCKR CMPL T2 10:00 - 10:30 0.50 CMPL TN PCKR CMPL T2 10:30 - 13:00 2.50 WAlTON EQIP CMPL T2 13:00 - 16:30 3.50 CMPL TN SUN CMPL T2 16:30 - 17:30 1.00 CMPL TN PCKR CMPL T2 17:30 - 19:00 1.50 CMPL TN OSSV CMPL T2 19:00 - 21 :30 2.50 CMPL TN PCKR CMPL T2 Printed: 8/18/2004 1 :24:05 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-112 1E-112 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 6/25/2004 Rig Release: 7/31/2004 Rig Number: Spud Date: 6/26/2004 End: 7/31/2004 Group: 7/18/2004 19:00 - 21 :30 2.50 CMPL TN PCKR CMPL T2 ball down to 5,700' and was unable to go deeper, POOH 21 :30 - 22:00 0.50 CMPL TN PCKR CMPL T2 Pumped 7.5 bbls to seat ball, pressured up to 3,800 psi and blew ball seat 22:00 - 00:00 2.00 CMPL TN PCKR CMPL T2 Attempted to release setting tool with no success, worked pipe up to 200K st WI (45K over) while working left hand torque (7K Ft-Ibs) down hole with no success, discussed options with office and continued to work left hand torque into pipe 7/19/2004 00:00 - 00:45 0.75 CMPLTN PCKR CMPL T2 Continued to work left hand torque in DP to release HR running tool, with DP in neutral WI and putting 3 tums to left with 14K ft-Ibs of torque, running tool released, st up WI 150K, dn 108K 00:45 - 01 :00 0.25 CMPL TN DEQT CMPL T2 Tested ZXP packer to 1,500 psi for 5 min and ck ok 01:00 - 01:15 0.25 CMPL TN OBSV CMPL T2 Monitored well-static 01:15 - 04:00 2.75 CMPL TN TRIP CMPL T2 Pumped dry job and POOH to running tool 04:00 - 05:00 1.00 CMPL TN PULD CMPL T2 LD Baker HR running tool, all 3 balls in ball seats, cleared rig floor 05:00 - 09:30 4.50 WINDOWPULD PROD3 PU and MU Baker seal assembly, 4 jts and 2-pups of 5" DP for space out and 9 5/8" Baker btm trip whipstock, milling assembly with LWD/MWD and oriented BHA #10 09:30 - 10:15 0.75 WINDOwrRIP PROD3 RIH W/ HWDP on BHA #10 to 1,030' and shallow tested MWD 10:15 - 13:15 3.00 WINDOwrRIP PROD3 TIH with whipstock assembly (BHA #10) from 1,030' to 5,619' 13:15 - 16:30 3.25 WINDOWCIRC PROD3 Est Circ and made MADD pass to correlate DP to K-13 sand from 5,619' to 5,666', POOH 1 std to 5,610' and re-Iog from 5,575' to 5,615', shifted MWD down 2' to put on depth, st up WI 148K, dn WI 94K 16:30 - 17:00 0.50 WINDOwrRIP PROD3 TIH with whipstock assembly (BHA #10) from 5,610' to 6,022' 17:00 - 17:30 0.50 WINDOWSETW PROD3 Oriented whipstock and RIH, tagged top of ZXP packer at 6,038', set btm trip anchor and whipstock at 15 deg left of high side, set top of whipstock at 5,841' MD/3,410' TVD, st WI up after setting whipstock 153K and 104K dn 17:30 - 23:30 6.00 WINDOWSTWP PROD3 Milled window in 9 5/8" csg for "D" sand lateral, top of window at 5,841', btm of window at 5,857', drilled 8 1/2" hole to 5,880' MD/3,420' TVD (39' total), 2-10K wom, 60-90 rpm's, 428 gpm, 1,400 psi, rot WI 120K, up WI 153K, dn WI 104K, torque off btm 8K ft-Ibs, on btm 10K ft-Ibs, pumped hi vis sweep at 5,847' while milling window 23:30 - 00:00 0.50 WINDOWCIRC PROD3 Pumped 30 bbl hi vis sweep and began circ hole clean while working mills thru window, circ at 428 gpm at 1,400 psi 7/20/2004 00:00 - 00:45 0.75 WINDOWCIRC PROD3 Finish pumping 30 bbl hi vis sweep and circ hole clean while working mills thru window, circ at 428 gpm at 1,400 psi 00:45 - 05:00 4.25 WINDOwrRIP PROD3 Monitor well, Dry pipe, POOH & lay down milling assembly, All mills in guage. 05:00 - 06:30 1.50 WINDOWOTHR PROD3 Pull wear bushing, Flush out metal shavings from BOP stack, Reinstall wear bushing. 06:30 - 08:45 2.25 DRILL PULD PROD3 Make up 8-1/2" bit & Autotrak tools, Program tools. 08:45 - 12:30 3.75 DRILL TRIP PROD3 RIH, Pick up Ghost reamer & surface test tools @ 987', RIH & test down link on Autotrak @ 3,586', RIH to 5,835'. 12:30 - 13:30 1.00 DRILL REAM PROD3 Work thru window - tagged @ 5,848', Rotated at 20 RPM @ 5,851', Work down to 5,880'. 13:30 - 21 :00 7.50 DRILL DRLH PROD3 Drill 8-1/2" hole fl 5,880' to 6,556' ADT = 4.8 hrs, WOB 5/20K, RPM 150,640 gpm @ 3100 psi, UP 136K, DN 70K, ROT 97K, TQ on 9K1 off 9K, Ave. ECD's 10.2 ppg @ 9.1 ppg mud. Note; Dropped down below sand into shale f/6,054' to 6,327'. 21 :00 - 21 :45 0.75 DRILL CIRC PROD3 Lost communication with Autotrak, Trouble shoot same, Reset Autotrak several times, Regain contact. 21 :45 - 22:30 0.75 DRILL DRLH PROD3 Drill 8-1/2" hole f/ 6,556' to 6,649' ADT = 0.5 hrs, WOB 5/20K, RPM 150,640 gpm @ 3100 psi, UP 136K, DN 70K, ROT 97K, TQ on 9K1 off Printed: ß/18/2004 1 :24:05 PM - e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-112 1 E-112 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 6/25/2004 Rig Release: 7/31/2004 Rig Number: Spud Date: 6/26/2004 End: 7/31/2004 Group: 7/20/2004 21 :45 - 22:30 0.75 DRILL DRLH PROD3 9K, Ave. ECD's 10.2 ppg @ 9.1 ppg mud. 22:30 - 23:00 0.50 DRILL CIRC PROD3 Lost communication with Autotrak, Unable to reset Autotrak. 23:00 - 00:00 1.00 DRILL TRIP PROD3 Pump out of hole to 6,180'. 7/21/2004 00:00 - 01 :00 1.00 DRILL TRIP PROD3 Back ream slow fl 6,180' to 6,094' due to packing off, Pump out fl 6,094' to 5,908' with no problems, Pull slow thru window @ 5,857' to 5,841' with no problems, pull to 5,815'. 01 :00 - 01 :30 0.50 DRILL CIRC PROD3 Circ btm's up & hole clean @ 5,815' at rate 01 615 gpm @ 2400 psi. 01 :30 - 05:15 3.75 DRILL TRIP PROD3 Monitor well, POOH, Down load Autotrak, Lay down Autotrak & Bit. 05:15 - 07:00 1.75 DRILL TRIP PROD3 Pick up new Autotrak & bit, Program Autotrak. 07:00 - 12:00 5.00 DRILL TRIP PROD3 RIH, Surface test tools @ 970', RIH, Slide thru window @ 5,841' with no problems, RIH, Wash 116,550' to 6,649'. 12:00 - 00:00 12.00 DRILL DRLH PROD3 Drill 8-1/2" hole 116,649' to 7,805' ADT = 8.8 hrs, WOB 5/25K, RPM 150,615 gpm @ 2550 psi, UP 143K, DN 60K, ROT 96K, TQ on 9K1 off 10K, Ave. ECD's 10.5 ppg @ 9.2 ppg mud, Max gas 571 units. 7/22/2004 00:00 - 05:00 5.00 DRILL DRLH PROD3 Drill 8-1/2" hole 117,805' to 8,191' ADT= 2.7 hrs, WOB 5/15K, RPM 150,615 gpm @ 2600 psi, UP 148K, DN 63K, ROT 96K, TO on 10/11K1 off 11/12K, Ave. ECD's 10.5 ppg @ 9.2 ppg mud, Ave. BGG 350 units, Max gas 614 units, Pumped 1 weighted Hi-vis sweep @ 8,150' with 10-15% increase in cuttings. Note; Hydralic system on AutoTrak steering unit failed. 05:00 - 09:30 4.50 DRILL TRIP PROD3 Monitor well, Back ream out 01 hole to 6,085' (Mild packing off f/ 6,187' to 6,094'), Pull & pump out thru window to 5,806' with no problems. 09:30 - 10:00 0.50 DRILL CIRC PROD3 Circ 2 times btm's up & hole clean @ 5,806' at rate of 615 gpm @ 2150 psi. 10:00 - 14:30 4.50 DRILL TRIP PROD3 Monitor well, POOH, Break bit, Down load AutoTrak, Lay down same. 14:30 - 20:00 5.50 WELCTL BOPE PROD3 Pull wear bushing, Set test plug, Test all BOPE to 250 psi low & 5000 psi high, Hydril to 250 psi low & 3500 psi high, Test waived by AOGCC John Spaulding. 20:00 - 21 :30 1.50 RIGMNT RGRP PROD3 Change out Wash pipe packing on top drive. 21 :30 - 00:00 2.50 DRILL PULD PROD3 Make up AutoTrak & Program same. 7/23/2004 00:00 - 04:30 4.50 DRILL TRIP PROD3 RIH to 980', Surface test AutoTrak- OK, RIH to 8,044' with no problems. 04:30 - 05:00 0.50 DRILL REAM PROD3 Break eire, Wash 118,044' to 8,191', Stage pump rate up to 615 gpm @ 2600 psi. 05:00 - 12:00 7.00 DRILL DRLH PROD3 Drill 8-1/2" hole 118,191' to 8,783' (3,374' TVD) ADT= 4.3 hrs, WOB 5/20K, RPM 120, 615 gpm @ 2750 psi, UP 152K, DN 58K, ROT 96K, TQ on 10/12K1 off 11/12K, Ave. ECD's 10.5 ppg @ 9.0+ ppg mud, Ave. BGG 300 units, Max gas 372 units. 12:00 - 00:00 12.00 DRILL DRLH PROD3 Drill 8-1/2" hole 1/8,783' to 9,760' (3,362' TVD) ADT= 8.9 hrs, WOB 5/15K, RPM 160, 615 gpm @ 2800 psi, UP 150K, DN 48K, ROT 95K, TO on 12K1 off 12K, Ave. ECD's 10.6 ppg @ 9.0 ppg mud, Ave. BGG 300 units, Max gas 394 units. 7/24/2004 00:00 - 04:45 4.75 DRILL DRLH PROD3 Drill 8-1/2" hole 11 9,760' to 9,882' ADT = 4.0 hrs, WOB 5/15K, RPM 150,615 gpm @ 2800 psi, UP 146K, DN 54K, ROT 95K, TO on 12K1 off 11K, Ave. ECD's 10.6 ppg @ 9.0 ppg mud, Ave. BGG 300 units, Max gas 350 units. 04:45 - 05:30 0.75 RIGMNT RGRP PROD3 Work pipe and replace air boot in bell nipple. 05:30 - 16:45 11.25 DRILL DRLH PROD3 Drill 8-1/2" hole 119,882' to 10,533' (3,350' TVD) ADT= 8.4 hrs, WOB 5/15K, RPM 150, 615 gpm @ 2900 psi, UP 160K, DN 60K, ROT 105K, TO on 12/13K I off 12K, Ave. ECD's 11.0 ppg @ 9.0 ppg mud, Ave. BGG 300 units, Max gas 405 units. 16:45 - 17:15 0.50 RIGMNT RGRP PROD3 Circ & work pipe while changing valve & seat on #2 mud pump. 17:15 - 00:00 6.75 DRILL DRLH PROD3 Drill 8-1/2" hole f/1 0,533' to 11,230' (3,339' TVD) ADT = 5.0 hrs, WOB 5/15K, RPM 150, 595 gpm @ 3050 psi, UP 185K, DN 60K, ROT 115K, Printed: 8/18/2004 1 :24:05 PM - e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-112 1 E-112 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 6/25/2004 Rig Release: 7/31/2004 Rig Number: Spud Date: 6/26/2004 End: 7/31/2004 Group: 7/24/2004 17:15 - 00:00 6.75 DRILL DRLH PROD3 TQ on 131<1 off 13K, Ave. ECD's 10.9 ppg @ 9.1 ppg mud, Ave. BGG 300 units, Max gas 625 units, Pumped 1 Hi-vis weighted sweep @ 10,989' with very little increase in cuttings. 7/25/2004 00:00 - 00:45 0.75 DRILL DRLH PROD3 Drill 8-1/2" hole f/11,230' to 11,273' (3,336' TVD) ADT= 0.8 hrs, WOB 5/15K, RPM 150,595 gpm @ 3200 psi, UP 180K, DN 60K, ROT 120K, TO on 131<1 off 13K, Ave. ECD's 10.9 ppg @ 9.1 ppg mud, Ave. BGG 300 units, Max gas 625 units. 00:45 - 01 :30 0.75 DRILL CIRC PROD3 eire, Survey, Retract AutoTrak blades, Monitor well. 01 :30 - 02:30 1.00 DRILL TRIP PROD3 Backream out of hole at drilling rate f/11,273' to 10,536'. 02:30 - 03:00 0.50 RIGMNT RGRP PROD3 Hiline power tripped, Reset same. 03:00 - 09:45 6.75 DRILL TRIP PROD3 Continue to backream out of hole with no probelms to 5,816' 09:45 - 10:45 1.00 DRILL CIRC PROD3 Circ 3 times btm's up at rate of 595 gpm @ 2200 psi & 80 RPM. 10:45 - 14:00 3.25 DRILL TRIP PROD3 POOH to AutoTrak. 14:00 - 16:00 2.00 DRILL PULD PROD3 Down load AutoTrak, Lay down same, Clear floor. 16:00 - 20:30 4.50 DRILL TRIP CMPL T3 Make up Fixed lug whipstock retrieveing tools, RIH to 5,787'. 20:30 - 22:30 2.00 DRILL CIRC CMPL T3 Circ btm's up, Wash whipstock face & Latch onto whipstock @ 5,847' (Retrieving slot), Pull whipstock loose w/ 60K over pull, Observe well. 22:30 - 23:00 0.50 DRILL CIRC CMPL T3 Pull to 5,757', Circ btm's up. 23:00 - 00:00 1.00 DRILL TRIP CMPL T3 POOH to 5,380', Observe well- OK, Pump dry job. 7/26/2004 00:00 - 04:30 4.50 DRILL TRIP CMPL T3 Continue POOH w/ whipstock slow (50 ftImin.) due to mild swabbing if pulled to fast (Hole took proper fill). Note; Whipstock also snagged @ 1,655', 1,400', 1,000'. 04:30 - 06:30 2.00 DRILL PULD CMPL T3 Lay down all whipstock tools. 06:30 - 07:45 1.25 CASE RURD CMPL T3 Clear rig floor, Rig to run 5-1/2" liner, Monitor well. 07:45 - 13:00 5.25 CASE PULR CMPL T3 PJSM, Pick up 5-1/2",15.5#, L-80, DWC Blank & slotted liner as per detail (Total of 152 jts.). 13:00 - 19:30 6.50 CASE PUTB CMPL T3 PJSM, Pick up 3-1/2" inner wash string. 19:30 - 20:00 0.50 CASE PULR CMPL T3 Pick up Baker model B-1 Hook Hanger for LEM, Break eire, UP 118K, DN 90K. 20:00 - 20:30 0.50 CASE RUNL CMPL T3 RIH w/liner to 5,780'. 20:30 - 22:00 1.50 CASE CIRC CMPL T3 Circ hole volume at rate of 244 gpm @ 1100 psi, UP 122K, DN 90K, ROT 102K, TO 5/6K. 22:00 - 00:00 2.00 CASE RUNL CMPL T3 RIH wI liner to 7,550'. 7/27/2004 00:00 - 02:00 2.00 CASE RUNL CMPL T3 RIH wI liner to 11,241', Had to work last 60' to btm. 02:00 - 02:45 0.75 CASE RUNL CMPL T3 Hook hanger 3' low @ 5,860', Unhook and rehook to confirm- OK, Shoe @ 11,241' 02:45 - 05:00 2.25 CASE CIRC CMPL T3 Break eirc at rate of 5 bpm @ 1000 psi, Drop ball and pump down at 2.5 bpm @ 590 psi, Release from liner & blow ball wI 3800 psi. 05:00 - 05:45 0.75 CASE CIRC CMPLT3 Circ btm's up wI 8 bpm @ 2000 psi, Monitor well. 05:45 - 07:00 1.25 CASE CIRC CMPL T3 Pump 360 bbls 9.2 ppg Solids free OBM at rate of 8 bpm @ 2000 psi and flush 8-1/2"x 5-1/2" annulus, Pull out of seals and pump 68 bbls 9.2 ppg Solids free OBM to flush 5-1/2"x 3-1/2" annulus. 07:00 - 11 :00 4.00 CASE OTHR CMPL T3 POOH slow to 5,691' at 45 ftImin. due to pulling 3-1/2" inner string out of liner, Pump dry job. 11 :00 - 16:30 5.50 CASE OTHR CMPL T3 Rig & lay down 3-1/2" inner string. 16:30 - 22:30 6.00 CMPL TN PCKR CMPL T3 Clear floor, Rig & make up LEM assembly, RIH slow to 6,030' - OK. 22:30 - 23:30 1.00 CMPL TN CIRC CMPL T3 POOH to 5,720', Drop ball & circ down at 4 bpm @ 580 psi- Seat ball. 23:30 - 00:00 0.50 CMPL TN PCKR CMPL T3 RIH wI LEM assembly to 6,032' 7/28/2004 00:00 - 02:45 2.75 CMPL TN PCKR CMPLT3 RIH to 6,039' (Top of liner on "B" Lateral), Work thru TOL @ 6,039', Work thru BTM of tie back sleeve @ 6,048', Work down to Top of Seal Bore Extension @ 6,058' and unable to get past. 02:45 - 04:30 1.75 CMPL TN CIRC CMPL T3 POOH to 5,756', Rig & reverse ball from ball seat at rate of 3 bpm @ 400 psi, Lost 14 bbls while reversing. Printed: 8/18/2004 1 :24:05 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-112 1 E-112 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 6/25/2004 Rig Release: 7/31/2004 Rig Number: Spud Date: 6/26/2004 End: 7/31/2004 Group: 7/28/2004 04:30 - 09:00 4.50 CMPL TN PCKR CMPL T3 Rig down circ equip., Monitor well- OK, Pump dry job, POOH to 391 '. 09:00 - 11 :00 2.00 CMPL TN PCKR CMPL T3 Rig & lay down ZXP Packer, SBE & LEM Assembly, Found some scratches on seal assembly and seals damaged. 11 :00 - 14:30 3.50 CMPL TN TRIP CMPL T3 Make up 4-1/2' Mule shoe for Wash Assembly, RIH to 6,015'. 14:30 - 16:00 1.50 CMPLTN CIRC CMPL T3 Circ & wash f/6,015' to 6,058'- Unable to work past 6,058'. 16:00 - 20:30 4.50 CMPL TN TRIP CMPL T3 Monitor well, POOH & lay down Mule shoe Assembly. 20:30 - 21 :00 0.50 RIGMNT RSRV CMPL T3 Service top drive. 21 :00 - 21 :30 0.50 CMPL TN RURD CMPL T3 Rig to run 2-7/8" drill pipe, Unload & strap 2-7/8" drill pipe in pipe shed. 21 :30 - 00:00 2.50 FISH PULD CMPL T3 Make up 4-11/16" Mill & reverse circ basket, XIO's, 3 jts 3-1/8" De's, 7 jts 2-7/8" Drill pipe, Bumper sub & jars. 7/29/2004 00:00 - 02:45 2.75 FISH TRIP CMPL T3 RIH w/4-11/16' mill assembly to 5,975', Wash down to 6,056' & tag junk. 02:45 - 03:45 1.00 FISH MILL CMPL T3 Mill on junk f/6,056' to 6,056.5' UP 145K, DN 107K, ROT 121K, TO 4/5K ftr/lb, 50 RPM, 5 bpm @ 1450 psi, Fell thru & wash down to 6,076' (Btm of Seal bore Extension), Wipe thru to ensure free of junk. 03:45 - 08:45 5.00 FISH TRIP CMPL T3 Monitor well, Dry pipe, POOH, Lay down 7 jts 2-7/8' drill pipe, 3 jts 3-1/8" DC's, Break & clean out junk from Reverse circ basket- Recovered 6 peices of metal centralizer blades. 08:45 - 09:45 1.00 FISH PULD CMPL T3 Make up 3.4" milling assembly. 09:45 - 12:00 2.25 FISH TRIP CMPL T3 RIH to 4,849', Attempt to break circ- Pipe plugged, Attempt to clear pipe- No good. 12:00 - 16:00 4.00 FISH TRIP CMPL T3 POOH- wet to Mill, Clean out metal shavings from BHA. 16:00 - 19:00 3.00 FISH TRIP CMPL T3 Make up 3.4" mill assembly, RIH to 4,850' (Breaking circ every 10 stands). 19:00 - 21 :00 2.00 FISH CIRC CMPL T3 Wash f/4,850' to 6,076'. 21 :00 - 21 :15 0.25 FISH MILL CMPL T3 Mill f/6,076' to 6,078' UP 140K, DN 107K, ROT 123K, 4/5K ftIlb, 50 RPM, 5 bpm @ 1050 psi Fell thru, RIH to 6,098' set down, Mill to 6,099' fell thru, RIH to 6,200' very free. 21 :15 - 22:30 1.25 FISH CIRC CMPL T3 Pump Hi-vis weighted sweep at rate of 8 bpm @ 2200 psi, Had some small metal shavings in sweep on btm's up. 22:30 - 23:30 1.00 FISH TRIP CMPL T3 Monitor well - OK, Pump out of hole at rate of 8 bpm @ 2200 psi to 5,390'. 23:30 - 00:00 0.50 FISH TRIP CMPL T3 Pump dry job, POOH. 7/30/2004 00:00 - 04:45 4.75 FISH TRIP CMPL T3 POOH to BHA, Rig & lay down 2-7/8" drill pipe, 3-1/8" De's, Baker mill assembly. 04:45 - 06:30 1.75 CMPL TN PCKR CMPL T3 PJSM, Rig and make up LEM assembly. 06:30 - 11 :00 4.50 CMPL TN TRIP CMPL T3 RIH wI LEM assembly to 6,066', Top of linertop packer @ 5,780'. 11 :00 - 13:00 2.00 CMPL TN PCKR CMPL T3 Latch & set LEM, Set ZXP Packer wI 3000 psi, Neutralize wI 3700 psi, Test ZXP wI 1500 psi f/15 min., Shear out ball wI 5600 psi. 13:00 - 16:30 3.50 CMPL TN TRIP CMPL T3 Monitor well, Pump dry job, POOH & Lay down LEM running tool, Pull wear bushing. 16:30 - 17:30 1.00 CMPL TN RURD CMPL T3 Rig to run 4-1/2" completion string. 17:30 - 23:00 5.50 CMPL TN RUNT CMPL T3 PJSM, Run 4-1/2" Completion to 5,780'. 23:00 - 00:00 1.00 CMPL TN RURD CMPL T3 Rig pump lines to circ down and locate Seal bore extension. 7/31/2004 00:00 - 01 :00 1.00 CMPL TN SOHO CMPL T3 Break eire, Locate SBE, Pick up pups & space out tbg, Make up Vetco Gray Tubing hanger, Land tbg wI tail @ 5,810'. & RILDS. Note; See Tubing tally for full details. 01 :00 - 02:45 1.75 CMPLTN DEOT CMPL T3 Rig & test 4-1/2' annulus to 2500 psi for 15 min, 3000 psi for 30 min. on chart, Pressure up and shear RP valve w/ 3700 psi. 02:45 - 03:15 0.50 CMPL TN PULD CMPL T3 Lay down landing joint, Set BPV. 03:15 - 04:15 1.00 WELCTL OTHR CMPL T3 Make up stack washer, Flush out stack, Lay down stack washer. 04:15 - 05:15 1.00 WELCTL NUND CMPL T3 Nipple down BOPE. 05:15 - 06:45 1.50 WELCTL NUND CMPL T3 Nipple up tree, Test bonnet to 5000 psi f/10 min. Printed: 6/18/2004 1 :24:05 PM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 E-112 1 E-112 ROT - DRILLING n1334@ppco.com Doyon 141 Start: 6/25/2004 Rig Release: 7/31/2004 Rig Number: Spud Date: 6/26/2004 End: 7/31/2004 Group: 7/31/2004 06:45 - 10:45 4.00 WELCTL NUND CMPL T3 10:45 - 20:30 9.75 DRILL PULD CMPL T3 20:30 - 22:00 1.50 CMPL TN FRZP CMPL T3 22:00 - 00:00 2.00 WELCTL NUND CMPL T3 Build scaffold around tree, Rig up lubricator, Pull BPV, Set 2-way check, Test tree to 250 psi low & 5000 psi high, Pull2-way check. Rig & lay down 5" drill pipe from derrick, Displace 4-1/2"x 9-5/8" annulus thru GLM @ 5,320' with 394 bbls. diesel, Freeze protect 9-5/8"x 13-3/8" annulus with 120 bbls diesel to 2,000' MD, 1,800' TVD. Set BPV, Rig down scaffold. Install wing valve on tree, Dress tree wI all guages, Wash down tree, Record all pressures = Tbg. 150 psi, 4-1/4"x 9-5/8" 250 psi, 9-5/8"x 13-3/8" 250 psi, Flush and freeze protect injection well 1 E-33. Note: Release rig at 00:00 hrs 7/31/2004. Printed: 8/18/2004 1 :24:05 PM .... ConocoPhillips ConocoPhillips Alaska, Inc.,Slot #112 Pad iE, Kuparuk River Unit,North Slope, Alaska . . SURVEY LISTING Page 1 Wellbore: 112 L2 Wellpath: MWD w/Sag <6043 - 11273> Date Printed: 28-Jul-2004 .¡. BAKER HUGHES INTEQ ,2tY/( -0 q 3 Wellbore Name 112 L£ '-- I Created 'L~0-Julc£º{!4_ ! La§t Revised : ~ª-Jul-2004 ----------~- Wéll Name 112 I Govemment ID ! 50-029-23211-00 I Last Revised 23-Jun-2004 Slot Name Slot #112 Grid NorthinQ 5959781.0000 I Grid EastinQ i 550301.0000 I Latitude N70 18 3.1987 LonQitude W149 35 33.3560 I North 191.43N lEast i225.93W Installation , ,/I!ª!)1e fastinQ I NorthinQ I Coord System Name . . .... I North AIÎQnment i Pqd 1E__--===-' -"~,__ 5505~1;t1,~__~9Þ9º-91.109~ AK.:4 on NORTH AM~RICAN DATUM-i9:Údatu~ '.__ True.J -,-~- Field -- I EastinQ - 487754.6208 I NorthinQ 5948985.8206 I Coord System Name -- I North AIiQnment AK-4 on NORTH AMERICAN DATUM 1927 datu~ True Name Kuparuk River Unit '--'-"-"'~---'---'-'- l--__,_~_._._.___._~__......____....____._._.__._. 2 ~ ~'--\ All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig ( Doyon #141 RKB 95.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 186.41 degrees Bottom hole distance is 7459.16 Feet on azimuth 160.45 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ConocriÁ1i11ips . ConocoPhillips Alaska, Inc.,Slot #112 Pad 1E, Kuparuk River Unit, North Slope, Alaska SURVEY LISTING Page 2 Wellbore: 112 L2 Wellpath: MWD w/Sag <6043 - 11273> Date Printed: 28-Jul-2004 .¡¡. BAKER HUGHES INTI':Q Wellpath (Grid) Report MD[ft] i Inc[deg] Azi[deg] I TVO[ft] 8tation 8tation J~_ Position(Y) Position(X) 5840.00M~ 75.53_186.79 341º~_~ 1665.15~_ 3277.34E 6043.18· 85.42 185.76 3443.88 1864.088 3255.50E __ 6138.45, 91.2~~1> 3446.65,~J!J~_ 324LQ11õ: _6230.68 ,_ 90.73 __191.23J_~5.05 _.2048.49~_;3222.64E 6323.42' 95.47 191.34· 3440.04 2139.288 3204.53E ~tl>.96 i~~95.96 __~~~" 3430.ª~Z£29.84~L~187.92E 6509.24 i 94.79 189.59 3422.08 2321.43S 3172.57E 6605.89 95.88 192.00 3413.10 2415.95S 3154.55E 6697.96 91.79 189.00 3406.94 2506.25S 3137.82E 6790.96 91.73 188.78 3404.08 2598.09S 3123.45E _6883.45 91.27187.71~01.66 2689.59S 3110.19E 6976.20 91.33 188.04 1 3399.56 2781.448 3097.49E _ 7068.91 91.06 187.4~__ 3397.62_ 2873.288 3084,99E --L161.64 91.39. 188.01 3395.64 2965.15S 3072.51E 7254.80 91.18 188.411 3393.55 _3057.3;3~_;3059.21E 7347.87 91.15 18ª.J~_L, 3391.6!L--L-;3149.41S 3045.84E 7440.01 91.36 189.64. . 3389.64 I 3240.43S 3031.62E =~~;~:~~ Ht~}-- ~~~:~~ --..;;~~:~~--{~;~:~~~ ;~~~:~;~ -- I -~-~.- 7718.80 i 91.21 190.87 3384.09 3513.98S 2978.21E 7811.18! 91.33 192.43 3382.04. 3604.43S 2959.56E --7904.44 -I 91.02 192.36 3380.13 '----¡--3695.508 2939.55E 7997.21! 88.66 190.11 3380.38 3786.48S 2921.47E 8090.21 88.48 191.98 3382.70 3877.73S 2903.66E 8154.79 87.86 191.50 3384.77 3940.928 2890.53E 8180.29 88.06 190.64 3385.68 3965.93S 2885.64E 8273.29 92.88 188.60 3384.91 4057.59S 2870.10E 8366.00 93.98 190.31 3379.36, 4H8.87S_ 2854.90E 8457.56 92.02 189.38 3374.57; 4238.958 2839.27E -----a551.08 89.96 - 187.05 3372.96 1 43Ú.498 2825.91E 8642.08 89.71 187.10 3373.22 i 4421.808 2814.70E 8735.51 90.02 186.46 3373.44 ¡ 4514.578 28'03.67E 8828.12 90.82 183.34 3372.76 4606.838 2795.76E 8920.21 90.85 -- 182.81 3371.42 _I 4698.788 2790.82E 9010.90 90.88 182.42 3370.05 4789.368 2786.68E 9103.22 . 90.63 182.46 ,3368.83. 4881.598 2782.76E 9197.35 89.22 182.70 3368.96 4975.62S 2778.52E 9293.15 89.84 182.15 3369.74 I 5071.33S 2774.47E 9381.96 90.20 183.07 3369.71 5160.05S 2770.42E 9473.77 I 91.13 183.95 3368.65 5251.68S 2764.80E ~Q~_, 91.03_ 186.60;3366.82 i 5347.998 2755.91E 9661.24 91.34 187.94 3364.95· 5437.96S 2744.43E 9751.42 i 91.37 191.38 ~62.81 I 5526.82S 2729.30E - 9847.62 91.13 191.66 "I' 336D:71J-5621.068 ·_2110.10E 9940.64 91.83 190.24 3358.31 ¡ 5712.368 2692.43E --..1.QQ33.57 94.14 189~8L----=-~353.47 5803.748 2676.27E 10123.76 90.02 190.03 3350.20, 5892.50S 2660.74E 10214.81 89.87 189.281 3350.29i 5982.2¡¡S--' 2645.47E 10304.98 89.74 189.231 3350.59 6071.258 2630.97E 10395.36 89.90 185.72 I 3350.88 i 6160.8'58 2619.21E --.1Q,486.39 .----ªºJ4 186.JM._..L_ 3350.8-º----L__6251.32S 2609.18E . Dogleg Severity Vertical ! Sectionfftl 1288.73 1488.86 1583..!~2 1675.78 1768.02 1859.87 1952.61 2048.55 2140.15 2233.02 2325.4,3 2418.12 21>10.79 2603.47 2696.56 2789.56 2881.59 2974.47 3065.83 3159.40 3251.37 3344.11 3436.53 3529.20 3593.46 3618.86 3711.68 ..3804.09 389l?36 3988.80 4079.80 4173.23 4265.79 4351.71 4448.19 4540.28 4634.20 4729.76 4818.38 4910.06 ß006.77 5097.46 5187.45 5283.25 5375.94 5468.55 555MO 5649.40 5739.46 5829.81 5920.84 0.00 4.89 8.77 0.80 5.11 m.2.11 1.26 2.73 5.50 0.25 1.26 0.36 0.69 0.69 0.48 0.31 1.66 1.77 0.38 0.82 1.69 0.34 3.51 2.02 1.21 3.46 5.63 2.19 2.37 3.33 0.28 0.7_6 3.4ß 0.58 0.43 0,27 1.52 0.87 1.11 1.39 2.74 1.52 3.81 0.38 1.70 __2.53 4.57 0.84 0.15 3.89 1.37 Easting Northing 553589.09 595813L9~ 553568.58 5957938.93 I 553554.72 595Zß44.81_, 553536.96 5957754.33 553519.46 5957663.43 .~~5º.3.46 5957572..?~ 553488.72 5957481.09' 553471.34 5957386.46 553455.21 5957296.06 553441.46 5957204.13 553428.82 5957112.56 553416.73 5957020.63 55;3.4º.4~_,~5956928. 72 553392.99 5956836.78 553380.31 5956744~ _~5§';3.367.55___ i 5956652.;31?~ . ~~.3;353.94~· 5956561.£~ ,_5l?;3;3,37.66 5956469.6-º--,-- 553320.06 5956379.60 553302.37 5956287.38 n~;3Z84.33 5956196.81 553264.93 5956105.62 553247.46 5956014.53 553230.27 5955923.18 553217.56 5955859.90 553212.83 5955834.87 553197.91 5955743.12 9.5,3183.32 5955651.74 553168.30 5955561.57 553155.56 595546ª~ 553144.96 5955378.~_ 553134.55 5955285.74 553127.26 , 5955193.44J 553122.~.,j_955101.48 J 553119.40 ' 5955010.87 5Q;3116.09 5954918.63 553112.49 5954824.58 553109.07 5954728.86 553105.62 5954640.12 553100.62 5954548.47 553092.37 5954452.10 i . 553081.50 5954362.0~7! 553066.97 5954273.12' 553048.39 59541L~ 553031.34, 5954087.36 ~53015.79 5953995.88 553000.86 5953907.03 552986.19 595;3817.18 552972.29 5953728.09 552961.13 5953638.43 i 552951.70 5953547.90 I All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVO's are from Rig ( Doyon #141 RKB 95.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 186.41 degrees Bottom hole distance is 7459.16 Feet on azimuth 160.45 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated .....- ConocoPhillips . ConocoPhillips Alaska, Inc.,Slot #112 Pad 1 E, Kuparuk River Unit, North Slope, Alaska . SURVEY LISTING Page 3 Well bore: 112 L2 Well path: MWD w/Sag <6043 -11273> Date Printed: 28-Jul-2004 rei. BAKER HUGHES INTEQ Wellpath (Grid) Report MD[ft] Inc[deg] Azi[deg] I TVD[ft] I Station Station ¡Dogleg Severity Vertical Easting Northing Position(Y~~jtJon(X) i i Section[ftl 10577.07 . .90.88. __----.1l!7.71 3350.04 6341,26S_ J597.61E.... 1.18 '..6011.50 !,;!,;:294O.75 !,;9'§:H57.9D 10667.57 90.94 187.41 3348.60 6430.96S 2585.71E 0.34 610.1.97 552929.44 5953368.13 10759.15 ~QJ.L........ 187.39.. ~4Llº-_.L .6521.77:8 2573.92E . Q.91 6193.!';3 552918.26 59532ZL~ ~'þQ,~9P.J.L...----1l!Qj}L~_:i347.59. 6612.4~__.2~62.54E _"_ 0.51 6~84.86 !';52907.49 59!';3186.55 10941.56 91.16 190.51 3346.58 6702.40S 2548.74E 4.11 6375.84 552894.30. 5953096.47 _ 11 029.J!.9..-...--9.Q,~ ... 190.73..-r---l-345.01 ... : 6789 .2QS__:2_532.4 7E 0.40. 64.63.92 552878.60. 5953Qº~ 11125.72 91.83 189.05 3342.74 6883.58S 2516.01E 2.01 6559.54 552862.78 5952915.10. 11225.97 92.72 187.63 3338.76 6982.69S 2501.48E 1.67 6659.65 552848.92 5952815.91 11273.00 92.20. 186.80 3336.74 7029.30S 2495.58E 2.08 6706.63 552843.33 5952769.26 All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVD's are from Rig ( Doyon #141 RKB 95.Dft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 186.41 degrees Bottom hole distance is 7459.16 Feet on azimuth 160.45 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated . , , 'P' ConocoPhillips . ConocoPhillips Alaska, Inc.,Slot #112 Pad 1E, Kuparuk River Unit,North Slope, Alaska . SURVEY LISTING Page 4 Wellbore: 112 L2 Wellpath: MWD w/Sag <6043 - 11273> Date Printed: 28-Jul-2004 'Ii. BAKER HUGHES INTEQ Comments I MD~_ iTVD~_lNorthfft]~aÆLf!l__IComrnenL__ _________ ... i ~_.11273.Q~__.L~:33Q~L_.J0~9.:3~L.__._2~5.5ßE ._i Pro~cteçLPƪ.~.NO.SUR~EY___________________~ ~-~~- _.~-~- .~-- Hole Sections Diameter ! Start Start Start I Start End End I End Start [in] I MDrft] TVDrft] Northrftl Eastfft] MDfft] TVDfft] I Northfft] Eastfft] __ 16.0Q!L_L-ºJ1º-___0.0º__ _--º.OOI'L -'_-º.cOOe _~045.QL_--.£317.1.L-.-l__180.46S__1MP__ºQLllUB1_______i 121/4 3045.00 2317.11 180.46S I 1516.06E 6933.00 3606.57 2738.67S 3103.47E 112 PB1 81/2 5840.00 3410.30 1665.15S I 3277.34E 5940.00 3431.14 1762.29S 3266.23E 112L2 81/2 5880.00 3419.63 1703.78S 3272.82E 11273.00 3336.74 7029.30S 2495.58E 112L2 Wellbore I Casinas i Name - ¡Top Top Top I Top Shoe Shoe I Shoe Shoe Wellbore ¡ ____~MDJID__ TV.QlftL__r-m~.Jças!fftL~~__ TVDrf!L_-1'!QrthrnL_~astr~______-l _~O" CQnd\Jctor I 0.00 _---º.OQ___-º.cOON_--L 0.00E___108.00__~8.00_L-.tì~--º·00~~PBL___-' 133/8" Surface I 0.00 0.00 O.OON O.OOE 3029.44 2309.89 ¡ 176.93S 1502.73E 112 PB1 casinQ 95/8" Intermediatel 0.00 0.00 O.OON O.OOE 6924.58 3605.33 2712.71S 3079.82E 112 PB1 caslnQ ; 51/2" Liner I 5839.00 3410.05 1664.19S I 3277.46E 11241.00 3338.07 6997.57S 2499.52E 112 L2 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Doyon #141 RKB 95.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 186.41 degrees Bottom hole distance is 7459.16 Feet on azimuth 160.45 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated Re: 14 Day BOPE Test-IE-112 and lateral (204-091, 204-092, 204-093) . . Subject: Re: 14 Day BOPE Test-1E-112 and lateral (204-091, 204-092, 204-(93) From: Thomas Maunder <tom_maunder@admin.state.ak.us> Date: Thu, 24 Jun 2004 15:02:14 -0800 To: "Shultz, Steven M" <Steven.M.Shultz@conocophillips.com> Steve, r concur with your assessment of the performance of Doyon 141. By copy of this email, a BOP test interval not to exceed 14 days is authorized for KRU 1E-112 and laterals. Tom Maunder, PE AOGCC Shultz, Steven M wrote: Tom, As you know we have permitted 1E-112 for "Drill and Complete" prior to the acceptance by AOGCC for the 14 day BOPE testing. r am requesting that 1E-112 be given permission from the state to also under the 14 day ruling for the following: 1. Doyon 141 has been the rig drilling all of the West Sak wells for the last 1 1/2 years and has a good record of BOP testing, of course at start up the rig had some issues with the variable rams but since then the tests have been good 2. The West Sak area being drilled is expected to be at or below normal formation pressures (8.4 to 8.6 ppg MWE) 3. There has been no injection of water or WAG in the areas to be drilled 4. Doyon 141 has an excellent record of compliance for state regulations and will continue to do so under the auspices of ConcoPhillips Thanks Steve Shultz I of 1 6/24/20043:02 PM (Ü" ¡"-'J I,',~,','\ 1::'1') IT] ',' 1 r " I' 1.1 (Ù) ¡I.! i'l, \ ,i IL, . [, r,1,',,' 1 '",II ': (~\\ I' ".. ' I, \ !, . IrÙ c(~? I t~7 1;\,\ t , ) \ ' ~,\)' , ; J '--j - ..}) f I, '., ,.. -, ¡ 'I ¡ I ~ \ \. 1,/ ;, t \,.\ ¡!, \ \ FRANK H. MURKOWSKI, GOVERNOR AI~ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279-1433 FAJ< (907)276-7542 Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk lE-1l2L2 ConocoPhillips Alaska, Inc. Permit No: 204-093 Surface Location: 191' FSL, 225.5' FEL, SEC. 16, TlIN, RlOE, UM Bottomhole Location: 1407' FNL, 2983' FEL, SEC. 27, TllN, RI0E, UM Dear Mr. Thomas: This transmittal letter is revised to correct the well name and penn it number in my June 9, 2004 letter. The provisions of the original approved permit dated June 9, 2004 remain in effect. BY ORDER OF JHE COMMISSION DATED this§day of June, 2004 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. . mEF . '1 rr\ (Q:J I ,^,' i '~l '" \. , . í I!:::. \ n'ì' LJL ...b u u ~g) 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAJ< (907)276-7542 FRANK H. MURKOWSK/, GOVERNOR AI,ASIiA. OIL AND GAS CONSERVATION COMMISSION Randy Thomas Kuparuk Drilling Team Leader ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, Alaska 99510-0360 Re: Kuparuk IE-I 12 ConocoPhillips Alaska, Inc. Pennit No: 204-091 Surface Location: 191' FSL, 225.5' FEL, SEC. 16, TlIN, RIOE, UM Bottomhole Location: 1407' FNL, 2983' FEL, SEC. 27, TlIN, RlOE, UM d-üct ê/)(~ Dear Mr. Thomas: Enclosed is the approved application for pennit to drill the above referenced development well. In your application it was stated that this well and the subsequent multi-lateral wellbores would be pre- produced and then converted to injection service after approximately 6 months. Regulation 20 AAC 25.402(c)(15) requires detennination of the mechanical condition of any well penetrating the injection zone within a one-quarter mile radius of a proposed injection well. In the case of IE-112, existing well IE-22 (182-214) is approximately 750' distant at the A-2 sand depth (--3700' tvd). The surface casing of IE-22 was set well above the West Sak sands (2600' md, 1845' tvd) and neither the Ugnu nor West Sak sands are covered with cement As currently planned, IE-I 12 and the laterals are designed to meet the requirements for injection wells as specified in 20 AAC 25.412. However prior to converting IE-I 12 and laterals to injection service CPAI must provide infonnation sufficient for the Commission to detennine that the West Sak intervals in lE-22 are or have been isolated to confine any fluids within zone. This pennit to drill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit 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 tenns and conditions of this pennit may result in the revocation or suspension of the pennit. Please provide at least twenty-four hours notice for a representative of the Commission to witness any required test. Contact the 0 ission's petroleum field inspector at (907) 659-3607 (pager). BY ORDER 2J THE COMMISSION DATED this+ day of June, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. \' Conoc~illips Alaska . Post Office Box 100360 Anchorage, Alaska 99510-0360 Steve Shultz Phone (907) 263-4620 Email: Steven.M.Shultz@ConocoPhillips.com May 27,2004 RECEIVED MAY 2 tJ 2004 AIa8ka Oil & G8s Cons. ~ AndJOf!ge Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill, West Sak Injector, 1E-1l2 L2 Dear Commissioners: , ',' ''''\ " . , ,-'1>.,. . ....£1 \,,>e .- ÇI ~'-ccu I Ie e:'..L-,h ¿r7<-- þv ¿, :) c 7 ConocoPhillips Alaska, Inc. hereby applies for a Permit to Drill for an onshor~wellbore, the upper lateral wellbore of a multilateral horizontal well, in the West Sak "D" sand. The main bore of this well will be designated 1E-112 and has been permitted under a separate application, submitted on May 27,2004. This application is for the upper lateral of that well, to be designated 1 E-1l2L2. The expected date that operations will begin on 1E-1l2L2 is July 15, 2004. Please find attached for the review of the Commission a Form 10-401 and the information required by 20 ACC 25.005 for each of this well bore. Under separate cover, ConocoPhillips is applying for a spacing exception for this well bore, under the terms of 20 MC 25.055 Please contact Steve Shultz at 263-4620 if more information is needed to issue a Permt to Drill for 1E- 112L2. 2~OC!:'t' dJ Ç¡ ¿¿~~ eve Shultz'",-- GKA Drilling Consultant P.O. Box 100360 Anchorage, AK 99510-0360 4a. Location of Well (Governmental Sec!ion): '() / ::> '0'f 1'- .,Ç>, '" Surface: 191' FSL, 225.5' FEL, Se~11N, R10E, UM Top of Productive Horizon: 1374' FNL, 2379' FEL, Sec. 22, T11N, R10E, UM Total Depth: 1407' FNL, 2983' FEL, Sec. 27, T11 N, R1OE, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 550301 16. Deviated wells: Kickoff depth: 5696' 18. Casing Program Size 1a. Type of Work: Drill~ Re-entry 0 2. Operator Name: ConocoPhillips Alaska, Inc. 3. Address: Hole 42" 16" 12.25" 8.5" Casing 20'x34 " 13-3/8 " 9-518" 5.5" 19 Total Depth MD (It): Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): e STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION /re" /8' PERMIT TO DRILL 20 AAC 25.005 RedrillU \)~~~~\~\~\- ~'1C/?5 EXPlorato~U Development Oi~ Multiple Zone 0 Service Development Gas 0 Single Zone 0 5. Bond: J Blanket U Single Well 11. Well Name and Number: Bond No. 59-52-180 1E-112L2 6. Proposed Depth: 12. FieJd/Pool(s): MD: 11046' TVD: 3310' Kuparuk River Field 11b. Current Well Class: Stratigraphic Test 0 7. Property Designation: ALK 25651 & 25660 8. Land Use Permit: West Sak Pool 13. Approximate Spud Date: 7/14/2004 ADL 469 & 470 9. Acres in Property: 2560 14. Distance to Nearest Property: 15. Distance to Nearest 10. KB Elevation y- 5959781 Zone- 4 (Height above Gl): 28 feet Well within Pool: 17. Anticipated Pressure (see 20 MC 25.035) ft. Maximum Hole Angle: 95° Max. Downhole Pressure: 1516 psig / Max. Surface Pressure: 1113 psig Setting Depth Quantity of Cement Specifications Top Bottom c. f. or sacks Weight Grade Coupling Length MD TVD MD TVD (including stage data) 94# K-55 Welded 80' 28' 28' 108' 108' 260 cf ArcticCrete 68# L-80 BTC 3172' 28' 28' 3200' 2314' 616 sx AS Lite, 206.5 sx DeepCrete 40# L-80 BTCM 6884' 28' 28' 6912' 3600' 638 sx DeepCrete 15.5# L-80 DWC 5350' 5696' 3379' 11046' 3310' slotted liner PRESENT WELL CONDITION SUMMARY Total Depth TVD (It): Plugs (measured) (To be completed for Redrill and Re-Entry Operations) I Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Cement Volume MD n :CF=IV1!fJ ,. MAY 2 b' 2004 ~ (.HI & ~ ('.ono Q." . . , An~(q.~ JIiJlitsion Length Size L..J Property Plat 0 U Diverter Sketch 0 perforation Depth TVD (ft): J)Øll~Þ"" 0 Seabed Report 0 U 20 MC 25.050 requirements 0 U Drilling Fluid Program 0 Date: 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Randy Thomas Signature ?ø.-ß. ¡1f~ '#1& XI4NÞY -r;,0¡IIf"~ Contact Steve Shultz @ 263-4620 Title Kuparuk Drilling Team Leader Phone ZC.'Õ-¿.g30 Date 65/27/04- PreDared bv Sharon AllsuD-Drake Commission Use Only Permit to Dril,l '" (/" ", I API Numbe, r. I Permit Approval Isee cover letter Number: x-"T·-{;/?,5 50-óZ51 Z-!5z/I--(;, I Date: forotherrequirements Conditions of approval: Samples required 0 Yes ~No Mud log required 0 Yes ~ No Hydrogen sulfide measures 0 Yes ~NO Directional survey required ~ Yes 0 No Other: "'"'- ~O~ -\~c::.~ \-J\ ,\ , . COMM~SIONER :~:::~:K)N D_ 71 ðf I Form 10-401 Revised 3/2003 . 0 RIG , N A L Su mit in duplicate e APPliCa. for Permit to Drill, Well 1 E-112 L2 ,. Revision No.O May 27,2004 Permit It - West Sak Well #1E-112 L2 ("D" Sand) Application for Permit to Drill Document MQxin'lizE Well VQII,I~ Table of Contents 1. Well Name..................................................................................................... ................2 Requirements of 20 AAC 25.005 (f) .............. ................. ....... ...... .................. .... ............... ......... .......... 2 2. Location Su m mary ....................................................................................................... 2 Requirements of 20 AAC 25.005(c)(2) ......... ............................... .......... ....... .............. ..... ........... ......... 2 Requirements of 20 AAC 25.050(b) ...... ....... ........ ...... ... ........ ...... ........ .............. ........ ....... .......... ......... 3 3. Blowout Prevention Equipment Information ............................................................3 Requirements of 20 AAC 25. 005(c)(3) ................................................................................................ 3 4. Dri Iii ng Hazards Information ...................................................................................... 3 Requirements of 20 AAC 25.005 (c)(4) ............................................................................................... 3 5. Procedure for Conducting Formation Integrity Tests.............................................3 Requirements of 20 AAC 25.005 (c)(5) ............................................................................................... 3 6. Casing and Cementing Program ....... ......... ............................ ....................................4 Requirements of 20 AAC 25. 005(c)(6) ................................................................................................ 4 7. Diverter System Information ......................................................................................4 Requirements of 20 AAC 25. 005(c)(7) ................................................................................................ 4 8. Dri II i ng Flu id Program................................................................................................. 5 Requirements of 20 AAC 25. 005 (c)(8) ................................................................................................ 5 Lateral Mud Program (MI FloPro NT) ....... ...... ......... ......... ........ ...... ........ ........ ...... ........ ...... ................. 5 9. Abnormally Pressured Formation Information ........................................................5 Requirements of 20 AAC 25.005 (c)(9) .......... ........ ........ ......... ...... ........ ............................. ......... ........ 5 1 O. Seism ic Analysis.......................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) .............................................................................................5 11. Seabed Condition Analys is .............................. .......................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ............................................................................................. 5 12. Evidence of Bonding ...................................................................... ............................. 6 Requirements of 20 AAC 25.005 (c)(12) ........ ....... ...... ........... ...... ....... .......... .... ......... ....... ......... ......... 6 ORIGINAL L2 PERM/T IT (Injector) RevO.doc Page 1 of? Printed: May 27,2004 e Applic_ for Permit to Drill, We1l1E-112 L2 . Revision No.O May 27,2004 13. Proposed Drilling Program ................... ......................................................... ............. 6 Requirements of 20 AAC 25.005 (c)(13) ..... ........ ...... ......... ........ ....... .............. ........ ........ ...... ......... ..... 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal........................6 Requirements of 20 AAC 25.005 (c)(14) . ........ ....... ....................... ........ .............. ......... ............... ........ 6 15. Attach ments.................................................................................................................. 7 Attachment 1 Directional Plan (8 pages) ....:........................................................................................ 7 Attachment 2 Drilling Hazards Summary (1 page)............................................................................... 7 Attachment 3 Well Schematic (1 pages).... ........ ....... ........ ........ ........ ....... .............. ......... ...... ...... ........ 7 1. Well Name Requirements of 20 AAC 25.005 (f) Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.040(b). For a well with multiple well branche~ each branch must similarly be identified by a unique name and API number by adding a suffix to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1E-112 L2. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmental section lines. (B) the coordinates of the proposed location of the well at the surface, referenced to the state plane coordinate system for this state as maintained by the National Geodetic Survey in the National Oceanic and Atmospheric Administration; (C) the proposed depth of the well at the top of each objective formation and at tota.1 depth; . / ,/. /!.þ '" :3 ô '1 Location at Surface I FNL:5088.5', FEL:225.5', S~l1N/RlOE, UM ASP Zone 4 NAD 27 Coordinates I RKB Elevation I 94.3' AMSL Northings: 5,959,781 Eastings: 550,301 Pad Elevation 66.3' AMSL Location at Top of Productive Interval (West Sak "D" Sand) ASP Zone 4 NAD 27 Coordinates Northings: 5,958,237 Eastings: 553,441 FNL:1374.3', FEL:2379', Sec22, T11N/R10E, UM Measured Depth RKB: Total Vertical Depth RKB: Total Vertical Depth/55: 5696' 3379' 3284.7' Location at Total Depth ASP Zone 4 NAD 27 Coordinates Northings: 5,952,921 Eastings: 552,883 FNL:1406.8', FEL:2983', Sec 27,TllN/R10E, UM Measured Depth RKB: 11046' Total Vertical Depth RKB: 3310' Total Vertical Depth/55: 3215.7' and (D) other information required by 20 MC 25.050(b); ORIGINAL L2 PERM/T /T (/njector) RevO.doc Page 2 of? Printed: May 27,2004 e App1ica for Permit to Drill, Well 1 E-112 L2 ., Revision No.O May 27,2004 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must (1) include a pla~ drawn to a suitable scale, showing the path ofthe proposed wellbore, including all adjacent wellbores within 200 feet of any portion of the proposed well,· Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed wellbore (A) list the names of the operators of those well~ to the extent that those names are known or discoverable in public records, and show that each named operator has been furnished a copy of the application by certified mail,· or (B) st¡;¡te that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 MC 25. 03~ 20 AAC 25.036r or 20 MC 25.03~ as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1E-112 L2. Please see information on Doyon 141 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (4) information on drilling hazard~ including (A) the maximum downhole pressure that may be encountered, criteria used to determine i~ and maximum potential surface pressure based on a methane gradien~' The expected reservoir pressures in the West Sak sands in the 1E-112 L2 area vary from 0.0.41 to 0.0.44 psi/ft, or 7.9 to 8.5 ppg EMW (equivalent mud weight). These pressures are predicted based on actual bottom hole pressure data from the nearby West Sak wells. The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11) and the deepest planned vertical depth of the West Sak B sand formation is 1,422 psi, calculated thusly: MPSP =(3446 ft)(0.0.44 - 0.11 psi/ft) =1113.31 psi (B) data on potential gas zones,· The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of hole problems such as abnormally geo-pressured strat0 lost circulation zones, and zones that have a propensity for differential sticking,· Please see Attachment 2: Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file wIth the commission and identified in the application: (5) a description of the procedure for conducting formation integrity test~ as required under 20 M C 25. 030( f); The parent wellbore,lE-112, will be completed with 95/8" intermediate casing landed in the West Sak A- Sand. The casing shoe will be drilled out and a formation integrity test will be performed in accordance ORIGINAL L2 PERMIT IT (Injector) RevO.doc Page 3 of? Printed: May 27,2004 e ApplicA for Permit to Drill, Well 1 E-112 L2 . Revision No.O May 27,2004 with the "Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (6) a complete proposed casing and cementing program as required by 20 M C 25. 030, and a description of any slotted liner, pre- perforated liner, or screen to be installed/ Casing and Cementing Program See also Attachment 3, APD for lE-112: Cement Summary Csg/Tbg 00 (in) 20 X 34 Hole Size (in) 42 13 3/8 16 9 5/8 12 1/4 Weight (Iblft) 94 Top MD/TVD (ft) 28 / 28 Btm MD/TVD (ft) 108 / 108 Cement Program Cemented to surface with 260d ArcticCRETE Cemented to Surface with 616 sx ASLite Lead, 206.5 sx DeepCRETE Tail Cement Top planned @ 3400' MD / 2404' TVD. Cemented w/ 638 sx DeepCRETE Slotted- no cement 5 1/2 8 1/2" "A" slotted Lateral (lE- 112) 5 1/2 8 1/2" slotted "B" Lateral (-5~~-~~~~El0 ~~~oo slotted "D" Lateral cement (lE-112 L2) l ~ 7. Diverter System Information Requirements of 20 AAC 25. 005 (c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (7) a diagram and description of the diverter system as required by 20 MC 25. 035, unless this requirement is waived by the commission under 20 MC 25.035(h)(2)/ Grade K55 Connection Welded Length (ft) 80 68 28 / 28 3200/2314 L-80 BTC 3172 40 L-80 BTCM 28 / 28 6912/3600 6884 15.5 L-80 6827/3600 11071/3545 DWC 4244 15.5 L-80 DWC 5986/3446 11052/3370 5066 Slotted- no cement \ ) ,. / --------....- ~ -- ----------- No diverter system will be utilized during operations on lE-112 L2 ORIGINAL L2 PERMIT IT (Injector) RevO.doc Page 4 of 7 Printed: May 27,2004 e Applicafor Permit to Drill, Well 1 E-112 L2 .. Revision No.O May 27,2004 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling flUId system, as requíred by 20 MC 25.033/ Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (Versapro, Oil Base Mud) Properties Density (ppg) Funnel Viscosity (seconds) Yield Point (cP) Electric Stability Chlorides (mg/I) pH API filtrate (cc / 30 min) **HTHP filtrate (cc / 30 min) MBT (Ib / gal) Value 9 30 :/ 18-28 650-900 40000 N/A <4 <10 <5 Drilling fluid practices will be in accordance with appropriate regulations stated in 20 AAC 25.033. Please see information on file with the Commission for diagrams and descriptions of the fluid system of Doyon 141 Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (c)(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 MC 25.033(f),· Not applicable: Application is not for an exploratory or stratigraphic test well. 9. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drill must be accompanied by each of the followíng items, except for an item already on file with the commission and ídentified in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysís as required by 20 AAC 25.061(a)/ Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Drill must be accompanied by each of the following item~ except for an item already on file with the commission and identified in the application: (11) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up ri{k or floating drilling vessel, an analysis of seabed conditions as required by 20 AAC 25.061(bJ· Not applicable: Application is not for an offshore well. ORIGINAL L2 PERMIT IT (Injector) RevO.doG Page 5 of? Printed: May 27,2004 e Applicafor Permit to Drill, Well 1 E-112 L2 .. Revision No.O May 27,2004 11. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (12) evidence showing that the requirements of 20 AAC 25.025 (Bonding}have been met.: Evidence of bonding for Phillips Alaska, Inc. is on file with the Commission. 12. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: The proposed drilling program for lE-112 L2 is listed below. Please refer also to Attachment 5, Well Note: Previous operations are covered under the 1E-112 Application for Permit to Drill. 1. Run and set Baker WindowMaster whipstock system, at window point of 5696' MD 3379' TVD, the top of the B sand. 2. Mill 8 1/2" window. POOH. 3. Pick up 8 1/2" drilling assembly with LWD and MWD and PWD. RIH. 4. Drill to TD of "B" sand lateral at 11046' MD / 3310'TVD, as per directional plan. 5. POOH, back reaming out of lateral. POOH. 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. PU and run 5 1/2" slotted liner. 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool. Displace liner annulus and liner to 9 ppg weighted brine. 10. POOH, if the well is to be an injector then pick up a lateral entry module (LEM), RIH and set into the "D" sand hook hanger, if the well is to be a producer then the lateral entry module will be run at a later date depending on need. 11. POOH and lay down drill pipe 12. MU completion equipment for injection well and RIH 13. Locate top of PBR on the hook hanger, space out and stab seal assembly into PBR 14. Install BVP, and ND BOPE, NU X-mas tree, Shear out gas lift mandrel and freeze protect well. 15. Secure well, rig down move out 16. RU wireline, replace shea rout valve on GLM with dummy valve 17. RD wireline and place well on 180 days of pre-production through gas lift prior to injection service. 13. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An application for a Permit to Drill mustc be accompanied by each of the following items, except for an Item already on file wIth the commission and identified in the application: (14) a general description of how the operator plans to dispose of drilling mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well..: Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on 1E Pad, or by hauling the fluids to a KRU Class II disposal well. All cuttings generated will be disposed of either down a permitted annulus on 1E Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved OR'G'~JAL L2 PERMIT IT (Injector) RevO.doc Page 6 of? Printed: May 27,2004 e Applic_ for Permit to Drill, Well 1 E-112 L2 .. Revision No.O May 27,2004 disposal well, or stored, tested for hazardous substances, and (if free of hazardous substances) used on pads and roads in the Kuparuk area in accordance with a permit from the State of Alaska. 14. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic ORIGINAL L2 PERMIT IT (Injector) RevO.doc Page 7 of 7 Printed: May 27,2004 e e lE-112L2 Drillina Hazards Summary (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 8 1/2" Open Hole / 5 1/2" Liner Interval Hazard Abnormal Reservoir Pressure Stuck Pipe Low Mitigation Strategy Stripping drills, Shut-in drills, Increased mud weight. Good hole cleaning, PWD Tools, Hole Opener, Decreased mud weight Reduced pump rates, Mud rheology, LCM Trip speeds, Proper hole filling (use of trip sheets), Pumping out Risk Level Low Lost Circulation Hole Swabbing on Trips Moderate High 1 E-112 Drilling Hazards Summary prepared by Steve Shultz 5/27/2004 9:43 AM ORIGI~JAL Tie-In 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 45 47 48 49 50 51 52 53 54 56 58 59 60 61 62 Aker Hughes Incorporatett Anticollision Report NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 25.00 ft Depth Range: 5696.16 to 11045.84 ft Maximum Radius: 5280.00 ft Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse Survey Program for Definitive Wellpath Date: 1/12/2004 Validated: No Planned From To Survey ft ft 0.00 5696.15 Planned: 1E-112 Vers#3 V17 (0) 5696.15 11045.84 Planned: 1E-112L2Vers#3V9 Version: 0 Toolcode Tool Name MWD+SAG MWD+SAG MWD + Sag correction MWD + Sag correction Summary Pad 10 116 1O-116V1 Out of range Pad 10 122 10-122 VO Out of range Pad 10 124 10-124 VO Out of range Pad 10 125 10-125 V1 5762.82 5779.00 4110.60 166.86 3943.74 Pass: Major Risk Pad 10 126 10-126 VO 6434.70 6700.00 3084.07 209.59 2874.48 Pass: Major Risk Pad 10 127 10-127 VO 8256.34 7416.00 3074.49 324.02 2750.47 Pass: Major Risk Pad 1D 128 10-128 VO 7073.04 6564.00 4024.72 243.77 3780.95 Pass: Major Risk Pad 10 129 1D-129VO 6400.74 4950.00 5180.96 197.95 4983.01 Pass: Major Risk Pad 10 131 10-131 VO 7773.22 6275.00 4990.38 283.47 4706.91 Pass: Major Risk Pad 10 3 1 D-03 VO Out of range Pad 10 7 10-07 VO 7646.41 7725.00 5076.12 328.25 4747.87 Pass: Major Risk Pad 1E 10 1E-10VO Out of range Pad 1 E 102 102 B-Lateral VO Plan: Out of range Pad 1E 102 102 D-Lateral VO Plan: Out of range Pad 1E 103 103 VO Plan: 1E-103 VE Out of range Pad 1E 104 104 VO Plan: 1E-104 VE Out of range Pad 1 E 105 105 A2-Lateral VO Plan 5703.40 8525.00 2101.02 170.25 1930.77 Pass: Major Risk Pad 1 E 105 105 B-Lateral VO Plan: 5698.37 8550.00 2084.16 159.61 1924.56 Pass: Major Risk Pad 1 E 105 105 D-Lateral VO Plan: 5708.74 8575.00 2083.98 160.47 1923.51 Pass: Major Risk Pad 1 E 11 1E-11 VO Out of range Pad 1 E 112 1E-112VO Plan: 1E-112 5700.00 5700.00 0.02 145.14 -145.12 FAIL: Major Risk Pad 1 E 112 1E-112L 1 VO Plan: 1 E-1 5700.00 5700.00 0.02 145.14 -145.12 FAIL: Major Risk Pad 1 E 114 114 A2-Lateral VO Plan Out of range Pad 1E 114 114 B-Lateral VO Plan: Out of range Pad 1E 114 114 D-Lateral VO Plan: Out of range Pad 1E 117 117 A2-Lateral VO Plan 11000.00 7825.00 1274.02 512.23 761.79 Pass: Major Risk Pad 1E 117 117 B-Lateral VO Plan: 11000.00 7825.00 1274.02 512.22 761.80 Pass: Major Risk Pad 1E 117 117 D-Lateral VO Plan: 11000.00 7825.00 1274.02 512.22 761.80 Pass: Major Risk Pad 1 E 119 119 VO Plan: 1E-119 Ve 10208.70 7242.30 2028.46 452.02 1576.43 Pass: Major Risk Pad 1 E 1 1 E-01 VO 6050.68 4300.00 3428.04 173.72 3254.32 Pass: Major Risk Pad 1 E 1 1 E-01A VO 6087.35 4500.00 3260.27 134.43 3125.84 Pass: Major Risk Pad 1 E 121 121 B-Lateral VO Plan: Out of range Pad 1 E 121 121 D-Lateral VO Plan: Out of range Pad 1 E 12 1E-12 VO Out of range Pad 1E 123 1E-123 L1 V1 Plan: 1E- Out of range Pad 1E 123 1E-123 V8 Out of range Pad 1E 126 126 A2-Lateral VO Plan 10798.16 12054.87 1090.90 519.77 571.13 Pass: Major Risk Pad 1 E 126 126 B-Lateral VO Plan: 10796.52 12066.71 1110.03 508.93 601.10 Pass: Major Risk Pad 1 E 126 126 D-Lateral VO Plan: 10797.73 12062.49 1105.96 512.10 593.86 Pass: Major Risk Pad 1E 13 1E-13 VO Out of range Pad 1E 14 1E-14 VO Out of range Pad 1 E 15 1E-15 VO Out of range Pad 1 E 16 1E-16 VO Out of range Pad 1 E 166 166 A2-Lateral VO Plan 10987.15 8875.00 983.02 502.50 480.52 Pass: Major Risk Pad 1E 166 166 B-Lateral VO Plan: 10983.15 8850.00 955.18 491.01 464.17 Pass: Major Risk Pad 1E 166 166 D-Lateral VO Plan: 10990.70 8850.00 953.88 492.15 461.73 Pass: Major Risk Pad 1E 168 168 A2-Lateral V3 Plan 6259.88 5800.00 514.77 145.70 369.07 Pass: Major Risk Pad 1 E 168 168 B-Lateral VO Plan: 6259.88 5800.00 514.77 145.69 369.07 Pass: Major Risk Pad 1 E 168 168 D-Lateral VO Plan: 6259.88 5800.00 514.77 145.69 369.07 Pass: Major Risk Pad 1 E 170 170 A2-Lateral VO Plan 10981.72 7275.00 2303.95 504.02 1799.93 Pass: Major Risk ORIGINAL aker Hughes Incorporate. Anticollision Report Summary Pad 1 E 170 170 B-Lateral VO Plan: 10981.72 7275.00 2303.95 504.01 1799.94 Pass: Major Risk Pad 1E 170 170 D-Lateral VO Plan: 10981.72 7275.00 2303.95 504.01 1799.94 Pass: Major Risk Pad 1E 17 1E-17 VO Out of range Pad 1 E 18 1E-18 VO Out of range Pad 1E 19 1E-19VO Out of range Pad 1 E 20 1 E-20 VO Out of range Pad 1 E 21 1 E-21 VO Out of range Pad 1 E 2 1 E-02 VO 6923.06 5800.00 1984.16 171.22 1812.94 Pass: Major Risk Pad 1 E 22 1 E-22 VO 6076.15 5350.00 489.96 129.06 360.91 Pass: Major Risk Pad 1 E 23 1 E-23 VO 6129.58 5275.00 1273.98 135.42 1138.55 Pass: Major Risk Pad 1E 24 1 E-24 VO 5750.00 5300.00 2855.70 95.13 2760.57 Pass: Major Risk Pad 1E 24 1 E-24A VO 5868.56 6900.00 2725.23 85.91 2639.32 Pass: Major Risk Pad 1 E 25 1 E-25 VO Out of range Pad 1E 26 1 E-26 VO 5720.93 3125.00 3536.58 131.69 3404.88 Pass: Major Risk Pad 1E 26 1 E-26A VO 5716.90 3175.00 3568.21 123.45 3444.76 Pass: Major Risk Pad 1E 27 1 E-27 VO Out of range Pad 1E 28 1 E-28 VO 5725.10 3275.00 4278.10 118.47 4159.63 Pass: Major Risk Pad 1 E 29 1E-29 VO 5698.65 3925.00 4027.08 109.50 3917.58 Pass: Major Risk Pad 1 E 30 1 E-30 VO 5697.36 4150.00 4574.63 111.71 4462.92 Pass: Major Risk Pad 1 E 31 1 E-31 V1 9512.91 10005.00 3384.41 263.40 3121.01 Pass: Major Risk Pad 1 E 31 1E-31PB1 VO 9254.67 8725.00 4012.16 320.41 3691.75 Pass: Major Risk Pad 1 E 3 1 E-03 V1 5696.15 7950.00 2694.29 129.67 2564.62 Pass: Major Risk Pad 1 E 32 1 E-32 VO 9513.03 7475.00 2679.67 360.49 2319.18 Pass: Major Risk Pad 1 E 33 1 E-33 VO 5696.15 6550.00 1529.11 160.53 1368.58 Pass: Major Risk Pad 1 E 33 1E-33PB1 VO 5696.15 6550.00 1529.11 160.53 1368.58 Pass: Major Risk Pad 1 E 34 1 E-34 VO 8200.73 7300.00 2104.81 272.33 1832.48 Pass: Major Risk Pad 1 E 35 1 E-35 VO 9562.80 7350.00 1285.99 296.72 989.27 Pass: Major Risk Pad 1 E 35 35A VO Plan: 35A ST Ve 9600.59 7400.00 1277.94 289.71 988.23 Pass: Major Risk Pad 1E 36 1E-36 VO 10982.19 10925.00 4440.29 467.59 3972.70 Pass: Major Risk Pad 1E 4 1 E-04 VO 5724.71 3575.00 4380.33 133.84 4246.50 Pass: Major Risk Pad 1E 5 1 E-05 VO Out of range Pad 1E 6 1 E-06 VO Out of range Pad 1E 7 1 E-07 VO Out of range Pad 1 E 8 1 E-08 V1 Out of range Pad 1 E 9 1 E-09 VO Out of range Pad 1 E WSR#2 WS2 V1 5922.62 3425.00 1387.76 130.68 1257.09 Pass: Major Risk Pad 1J 10 1J-10 VO Out of range Pad 1J 1J-DQ 1J-L6 A Lateral V1 Pia 8720.89 11640.58 4956.78 437.73 4519.05 Pass: Major Risk Pad 1J 1J-DS 1J-L5 A Lateral V1 Pia 8857.87 12531.63 3722.57 437.14 3285.43 Pass: Major Risk Pad 1J 1 J-DU 1J-L4 A Lateral V1 Pia Out of range Pad 1J 1J-DW 1J-L3 A Lateral V1 Pia Out of range Pad 1J 9 1J-09 VO 10983.45 9725.00 4704.83 349.96 4354.87 Pass: Major Risk ORIGINAL e e ConocJ"Pt,illips ConocoPhillips Alaska, Inc.,Slot #112 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 1 Well bore: 112L2 Well path: 112L2 Ver#3 Date Printed: 19-May-2004 _i. BAKER HUGHES INTEQ Wellbore Name 112L2 I Created 26-Apr-2004 I Last Revised 14-May-2004 Well Name 112 10 Slot Name Slot #112 I Grid NorthinQ 5959781.0000 I Grid EastinQ 550301.0000 N70 18 3.1987 I LonQitude W149 35 33.3560 I North 191.43N lEast 225.93W Installation Name Pad 1E I Eastina 550528.1946 I Northina 5959591.1090 I Coord Svstem Name INorth Alianment AK-4 on NORTH AMERICAN DATUM 1927 datum True Field Name KUDaruk River Unit I Eélstina · 487754.6208 I Northina 5948985.8206 IcoordSvstem Name.' NorthAlianment AK-4 on NORTH AMERICAN DATUM 1927 datum True All data is in Feet unless otherwise stated Coordinates are from Slot MO's are from Rig and TVD's are from Rig (Doyon #141 RKB 95.00 above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 186.41 degrees Bottom hole distance is 7330.55 Feet on azimuth 159.76 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated O î", ~ . &{," .',' ! ì ä e e Conoc6'Phillips ConocoPhillips Alaska, Inc.,Slot #112 Pad 1 E, Kuparuk River Unit, North Slope, Alaska PROPOSAL LISTING Page 2 Wellbore: 112L2 Wellpath: 112L2 Ver#3 Date Printed: 19-May-2004 rei. BAKER HUGHU INTEQ Well path Report MD[ft] Inc[de Azi[deg] TVD[ft] Vertical North[ft] East[ft] Station Station Dogie Vertical 8tation Comment g] Depth 8S Position(Grid Position(Gridg 8ectìon[ North) East) [deg/1 ft] 0001 5696.16 75.00 186.41 3379.00 3284,00 1565.148 3129.901:, 5958237,00 553441,00 0,00 1205.81 Top Whipstock Face. Tie on 5712,66 77.24 186.41 3382,96 3287,96 1581,068 3128.11E. 5958221.07 553439,32 13.60 1221 ,83. Base Whiostock Face. End of Build 5732,66 77.24 186.41 3387.37 3292.37 1600.448 3125,94F 5958201,68 553437.27 0.00 1241.34 End Milled Ooenhole. KOP, End of Hold 5800.00 81.28 186.41 3399.92 3304,91 1666.188 3118,551:, 5958135,90 553430,32 6,00 1307.48 5900.00 87.28 186.41 3409,87 3314.87 1765.018 3107.44E 5958037.00 553419.88 6.00 1406,94 5937,61 89.54 186.41 3410.91 3315.91 1802,378 3103.24E 5957999.62 553415.93 6.00 1444.54 EOC. 2DX8 Kick off Point 6037.61 92.54 186,41 3409.09 3314,09 1901.718 3092.07E. 5957900,22 553405.43 3,00 1544.5C End of Build 6100.00 92.54 186.41 3406.33 3311,33 1963.658 3085.11 E 5957838.24 553398.88 0,00 1606.8~ 6200.00 92.54 186.41 3401,90 3306.89 2062.938 3073,95E 5957738.90 553388.39 0.00 1706,74 6224.32 92.54 186.41 3400.82 3305.82 2087.088 3071,241:, 5957714.73 553385.83 0.00 1731.04 End of Hold 6324.32 89.54 186.41 3399.00 3304.00 2186.388 3060.07F 5957615.37 553375,34 3,00 1830.97 End of DroD 6400.00 89,54 186.41 3399,61 3304,61 2261,58S 3051.62E 5957540.12 553367,39 0.00 1906.64 6500.00 89,54 186,41 3400.41 3305.41 2360,958 3040.451:, 5957440,68 553356.88 0.00 2006.64 6600.00 89.54 186.41 3401.21 3306.21 2460.328 3029.28E 5957341.25 553346,38 0,00 2106.63. 6698.81 89,54 186.41 3402,00 3307,00 2558,51S 3018.24E 5957243,00 553336,00 0,00 2205.44 W8 1E 04 D-MDPT#1 RV8D042104. 3DJ Kick off Point 6700.00 89.58 186.41 3402,01 3307.01 2559.708 3018.11E 5957241.82 553335,88 3,00 2206.63. 6755,98 91,26 186.41 3401.60 3306.60 2615.328 3011,86E 5957186.16 553330.00 3.00 2262,6QEnd of BuildlTum 6800.00 91.26 186.41 3400,64 3305.64 2659,068 3006,94E 5957142,39 553325.38 0.00 2306.62, 6900.00 91.26 186.41 3398.45 3303.45 2758.418 2995.78E 5957042.98 553314.88 0.00 2406.59- 7000,00 91,26 186.41 3396.25 3301.25 2857,768 2984,62E 5956943.57 553304.38 0.00 2506,57 7100,00 91 .26 186.41 3394.06 3299.06 2957.118 2973.461:, 5956844,15 553293.89 0.00 2606.54 7200.00 91.26 186.41 3391.87 3296.87 3056.468 2962.29E 5956744.74 553283.39 0,00 2706.52- 7300,00 91.26 186.41 3389.68 3294,68 3155.818 2951.13E 5956645.33 553272.90 0.00 2806,5Q 7400,00 91 .26 186.41 3387.49 3292.49 3255,168 2939,97E 5956545,91 553262.40 0.00 2906.47 7500.00 91.26 186.41 3385.29 3290.29 3354.518 2928.81F 5956446.50 553251.90 0.00 3006.4~ 7600,00 91.26 186.41 33ß3.10 3288.10 3453.868 2917.64F 5956347.09 553241.41 0,00 3106.4? 7700.00 91.26 186.41 3380,91 3285.91 3553.218 2906.48E 5956247,67 553230.91 0.00 3206.40 7800.00 91.26 186.41 3378.72 3283.72 3652.578 2895.32E. 5956148.26 553220.42 0.00 3306.3a 7900.00 91.26 186.41 3376,53 3281.53 3751.928 2884.16E. 5956048.85 553209,92 0,00 3406.3~ 8000,00 91 .26 186.41 3374.33 3279,33 3851.278 2872,99E 5955949.43 553199.42 0.00 3506.3~ 8100.00 91 .26 186.41 3372.14 3277.14 3950.628 2861.83E 5955850,02 553188.93 0,00 3606.3C- 8200.00 91.26 186.41 3369.95 3274.95 4049.978 2850.67E 5955750.60 553178.43 0,00 3706,28, 8300.00 91.26 186.41 3367,76 3272,76 4149,328 2839,511:, 5955651,19 553167.94 0.00 3806.26 8400.00 91,26 186.41 3365.57 3270.57 4248.678 2828.34E 5955551.78 553157.44 0.00 3906.2:l 8500.00 91.26 186.41 3363.37 3268.37 4348.028 2817.18E 5955452.36 553146,94 0.00 4006.21 8600,00 91 .26 186.41 3361.18 3266,18 4447,378 2806,02E 5955352.95 553136.45 0,00 4106.18 8699.53 91 .26 186.41 3359.00 3264.00 4546.268 2794,91E 5955254.00 553126.00 0,00 4205.69 W8 1 E D4 D-MDPT#2 RV8D0421 04. 3DJ Kick off Point 8700,00 91.25 186.40 3358,99 3263.99 4546,728 2794.86E 5955253,54 553125,95 3,00 4206.16 8702.87 91.20 186.33 3358.93 3263.93 4549,58S 2794,54E. 5955250,68 553125.65 3.00 4209.0~End of DroDlTurn 8800.00 91.20 186.33 3356.90 3261 ,90 4646.098 2783.83F 5955154.11 553115.59 0.00 4306.14 8900.00 91.20 186.33 3354,81 3259,81 4745.468 2772,811:, 5955054.68 553105.24 0.00 4406,12, 9000.00 91.20 186.33 3352.72 3257.72 4844,838 2761, 79E. 5954955.25 553094.88 0.00 4506.09- 9100.00 91 .20 186.33 3350.64 3255,64 4944.208 2750.76E 5954855.82 553084,52 0,00 4606.07 9200.00 91 .20 186,33 3348,55 3253,55 5043,578 2739.741:, 5954756.39 553074.17 0.00 4706.05 9300.00 91.20 186.33 3346.46 3251 .46 5142,948 2728,72E. 5954656.96 553063.81 0.00 4806.0:i 9400.00 91.20 186,33 3344.37 3249.37 5242.308 2717,70E. 5954557.52 553053.46 0.00 49Q6.01 9500,00 91,20 186.33 3342,28 3247.28 5341,678 2706.67E. 5954458.09 553043,10 0.00 5005.98 All data is in Feet unless otherwise stated Coordinates are from 810t MD's are from Rig and TVD's are from Rig (Doyon #141 RKB 95.0ft above mean sea level) Vertical 8ection is from O,OON O.OOE on azimuth 186.41 degrees Bottom hole distance is 7330.55 Feet on azimuth 159.76 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated np "'uP Ò '. e ConocJ'Phillips ConocoPhillips Alaska, I nc.,Slot #112 Pad 1 E, Kuparuk River Unit,North Slope, Alaska e rei. BAKER HUGHES INTEQ PROPOSAL LISTING Page 3 Well bore: 112L2 Well path: 112L2 Ver#3 Date Printed: 19-May-2004 We II path Report MD[ft] Inc[de Azi[deg] rvD[ft] Vertical North[ft] East[ft] Station Station Dogie Vertical Station Comment g] Depth S8 Position(Grid Position(Grid 9 Section[ North) East) [deg/1 ft] OOftl 9600.00 91.20 186.33 3340.19 3245.19 5441.048 2695.651; 5954358.66 553032.74 0.00 5105.96 9700.00 91.20 186.33 3338.11 3243.11 5540.418 2684.63E.. 5954259.23 553022.39 0.00 5205.94 . 9800.00 91.20 186.33 3336.02 3241.02 5639.78S 2673.60F 5954159.80 553012.03 0.00 5305.9? 9900.00 91.20 186.33 3333.93 3238.93 5739.15S 2662.581; 5954060.37 553001.67 0.00 5405.90 10000.00 91.20 186.33 3331.84 3236.84 5838.52S 2651.56E 5953960.94 552991.32 0.00 5505.87 10100.00 91.20 186.33 3329.75 3234.75 5937.88S 2640.53E 5953861.51 552980.96 0.00 5605.8Gi 10200.00 91.20 186.33 3327.67 3232.66 6037.25S 2629.51 I; 5953762.08 552970.60 0.00 5705.83 10300.00 91.20 186.33 3325.58 3230.58 6136.62S 2618.49E 5953662.65 552960.25 0.00 5805.81 10400.00 91.20 186.33 3323.49 3228.49 6235.99S 2607.47E 5953563.22 552949.89 0.00 5905.79- 10500.00 91.20 186.33 3321.40 3226.40 6335.36S 2596.441; 5953463.79 552939.54 0.00 6005.77 10600.00 91.20 186.33 3319.31 3224.31 6434.73S...2585.42F 5953364.36 552929.18 0.00 6105.74 10700.00 91.20 186.33 3317.22 3222.22 6534.10S 2574.40E 5953264.93 552918.82 0.00 6205.72, 10800.00 91.20 186.33 3315.14 3220.14 6633.47S 2563.381; 5953165.50 552908.47 0.00 6305.70 10900.00 91.20 186.33 3313.05 3218.05 6732.83S 2552.35E 5953066.07 552898.11 0.00 6405.6(' 11000.00 91.20 186.33 3310.96 3215.96 6832.20S 2541.33F 5952966.64 552887.75 0.00 6505.66, 11045.90 91.20 186.33 3310.00 3215.00 6877.81 S 2536.27E 5952921.00 552883.00 0.00 6551 .55 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Doyon #141 RKB 95.00 above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 186.41 degrees Bottom hole distance is 7330.55 Feet on azimuth 159.76 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated O R I h 't\IA·- ¡ <\Jd~a L e ConocJ'Phillips ConocoPhillips Alaska, Inc.,Slot #112 Pad 1 E, Kuparuk River Unit,North Slope, Alaska e PROPOSAL LISTING Page 4 Well bore: 112L2 Well path: 112L2 Ver#3 Date Printed: 19-May-2004 Bi. BAKER HUGHES INTEQ Comments MDrfl.l TVDrfl.l Eastrfl.l Northfftl Comment 5696.16 3379.00 3129.90E 1565.14S Too Whiostock Face 5712.66 3382.96 3128.11E 1581.06S Base Whiostock Face 5732.66 3387.37 3125.94E 1600.44S End Milled Openhole, KOP 5937.61 3410.91 3103.24E 1802.37S EOC 11045.90 3310.00 2536.27E 6877.81S TO Hole Sections Diameter Start Start Start Start End End End End\nEast[ft] Wellbore [inl MDrfl.l TVDrfl.l Northrftl Eastrftl MDrfl.l TVDrfl.l Nörthrfl.l 16.000 0.00 0.00 O.OON O.OOE 3169.62 2300.00 ~11.94S 1683.70E 112 42.000 0.00 0.00 O.OON O.OOE 120.00 120.00 O.OON O.OOE 112 121/4 2949.87 2200.00 164.48S 1493.87E 6913.28 3607.00 2771.60S 2994.30E 112 81/2 5696.16 3379.00 1565.14S 3129.90E 11045.90 3310.00 6877.81S 2536.27E 112L2 Casinas Name Top Top Top Top Shoe Shoe Shoe Shoe Well bore MDrfl.l TVDrfl.l Northrftl Eastrftl MOrfl.l TVDrfl.l NQrthrftl Eastrfl.l 20.000in 0.00 0.00 O.OON O.OOE 120.00 120.00 O.OON O.OOE 112 Conductor 13 3/8in Surface 0.00 0.00 O.OON O.OOE 3169.62 2300.00 211.94S 1683.70E 112 casina 9 518in 0.00 0.00 O.OON O.OOE 6913.28 3607.00 2752.71S 2996.45E 112 Intermediate casino 5 1/2in Liner 5696.16 3379.00 1565.14S 3129.90E 11045.90 3310.00 6877.81 S 2536.27E 112L2 Taraets Name Northrttl Eastrfl.l TVDrfl.l Latitude Lonaitude Eastina Northina WS 1E D4 2558.51S 3018.24E 3402.00 N70 17 38.0300 W149 34 5.3915 553336.00 5957243.00 D-MDPT#1 RVS0042104 WS 1E D4DTOE 6877.81S 2536.27E 3310.00 N70 16 55.5517 W149 34 19.4806 552883.00 5952921.00 RVSD042104 WS 1E D4 4546.26S 2794.91 E 3359.00 N70 17 18.4815 W149 34 11.9219 553126.00 5955254.00 D-MOPT#2 RVS0042104 All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVO's are from Rig (Doyon #141 RKB 95.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 186.41 degrees Bottom hole distance is 7330.55 Feet on azimuth 159.76 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated ORIG {j .J '.. e Conoc6'Phillips ConocoPhillips Alaska, Inc.,Slot #112 Pad 1 E, Kuparuk River Unit, North Slope, Alaska e PROPOSAL LISTING Page 5 Wellbore: 112L2 Wellpath: 112L2 Ver#3 Date Printed: 19-May-2004 -¡. BAKER HUGHES INTEQ Survey Tool Program Reference Survev Name 660051 Planned MDfftl 11045.90 TVDrftl 3310.00 Survev Tool ISCWSA MWD 660118 Planned 5696.16 3379.00 ISCWSA MWD Error Model MWD+SAG - ISCWSA - 28 Jan 03 OJH MWD+SAG - ISCWSA - 28 Jan 03 OJH All data is in Feet unless otherwise stated Coordinates are from Slot MD's are from Rig and TVD's are from Rig (Doyon #141 RKB 95.0ft above mean sea level) Vertical Section is from O.OON O.OOE on azimuth 186.41 degrees Bottom hole distance is 7330.55 Feet on azimuth 159.76 degrees from Wellhead Calculation method uses Minimum Curvature method Prepared by Baker Hughes Incorporated nR ~;,_ /'. of 'i 0 ::::0 G; ¢:: 0 10 2400 II E 0 ~ 2700 .! ~ 3000 .... Q. CD C 3300 ns (.) :e 3600 ~ CD 3900 ~ ... l- I V 4200 4500 .£ lÑ'Trj)······· Point Tie on End of Hold End of BuildfTurn End of Build End of Build End of Build End of Build KOP End of Turn End of Hold End of Build/Turn Target WS '1 E D4 D TOP End of Hold End of Build End of Hold End of Build/Turn End of Build End of Hold End of Drop End of Drop End of Hold End of Build End of Build End of Hold End of Drop/Turn End of Drop End of Hold End of Build End of Build End of Hold End of Drop KOP T.D. & Target WS 1 E D4 1 ~~. - <¿''<>f0 0",'<..~"Çj <¿,'l>'t- ] oÇ~\òr:> 0 ~0"''<.. ~ 0~a~oç ConocoPhillips Alaska, Inc. Conoc~illips Location: North Slope, Alaska Slot: Slol#112 Field: Kuparuk River Unil Well: 112 Installation: Pad 1 E Wellbore: 112 Created by : Planner Data plottad : 1 g·May·2004 WELL PROFILE DATA Plot reference Îs 112. MD In. Azi 1VD North East dog/100ft V.Sect Raf wallpath is 112 Var#3. 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Coordinates are in feet reference Slot #112. 500.00 0.00 0.00 500.00 0.00 0.00 0.00 0.00 True Vartical Depths are reference Rig Datum. 833.33 10.00 95.00 831.64 ·2.53 28.90 3.00 -0.71 Measured Depths are reference Rig Datum, 1083.33 20.00 95.00 1072.82 ·8.16 93.28 4.00 ·2.31 Rig Datum: Doyon #141 RKB 1112.40 21.45 95.00 1100.00 -9.06 103.53 5.00 -2.56 Rig Datum to mean sea level: 95,00 ft. 1332.76 28.06 95.00 1300.00 ·17.10 195.41 3.00 ·4.83 Plot North is aligned to TRUE North. 2030.08 62.93 95.00 1781.27 -59.78 683.25 5.00 ·16.90 2608.85 62.93 95.00 2044.66 ·104.69 1196.65 0.00 ·29.60 2810.00 62.93 104.Q4 2136.35 ·134.27 1373.04 4.00 ·19.91 4064.37 62.93 104.04 2707.17 ·405.20 2456.65 0.00 128.31 5596.17 75.00 18641 3353.12 ·1469.16 3140.69 5.00 1109.23 5696.16 7500 '186.41 3379.00 -1565.14 3129.90 0.00 12058'1 e 5808.15 75.00 18641 3407.99 ·1672.64 3117.82 000 1313.99 5974.60 80.00 186.41 3444.00 ·1834.07 3099.68 3.00 1476.44 6924.04 80.00 186.41 3608.87 ·2763.24 2995.26 0.00 2411.45 7202.69 91.15 186.41 3630.34 ·3036.69 2964.29 4.00 2688.84 7335.21 94.46 186.41 3623.86 ·3170.40 2949.51 2.50 2821.18 7721.68 94.46 186.41 3593.82 ·3553.29 2906.49 0.00 3206.48 7854.20 91.15 186.41 3587.34 ·3684.81 2891.71 2.50 3338.82 7988.04 87.80 186.41 3588.57 ·3817.79 2876.77 2.50 3472.64 8366.76 87.80 186.41 3603.11 ·4193.66 2834.51 0.00 3851.08 8500.60 91.15 186.41 3604.34 ·4326.84 2819.57 2.50 3984.90 8638.76 94.60 186.41 3597.42 ·4463.95 2804.16 2.50 4122.86 9023.04 94.60 186.41 3566.60 ·4844.59 2761.39 0.00 4505.90 9153.22 91.34 186.32 3559.85 ·4973.78 2746.99 2.50 4635.89 9285.54 88.Q4 186.32 3560.57 -5105.27 2732.44 2.50 4768.19 9674.11 88.04 186.32 3573.89 ·5491.26 2689.72 0.00 5156.53 9806.43 91.34 186.32 3574.61 -5622.76 2675.17 2.50 5288.83 9938.71 94.65 186.32 3567.70 ·5754.04 2660.64 2.50 5420.91 10326.06 94.65 186.32 3536.29 ·6137.77 2618.17 0.00 5806.99 10458.34 91.34 186.32 3529.38 ·6269.05 2603.64 2.50 5939.07 10583.22 88.22 186.32 3529.86 -6393.16 2589.91 2.50 6063.93 11071.07 88.22 186.32 3545.00 ·6877.81 2536.27 0.00 6551.55 .~0~ 'v~ (i>~ <:>" ~<;) 112L2 ~ ~<;) 112L 1 e - ~"\ ~'1-. -- ~ '<..~ \:J~ 0 . ~ « \:J\:J'ò~. ~a ",\~ ~\~ "c,'<><Q\Ò <:>\<6 \~ \,-,'1- 600 900 1200 1500 Scale 1 em = 150 ft 1800 .^0~ v" (i>~ <:>" 2100 2400 2700 3000 3300 3600 3900 4200 4500 4800 5100 5400 Vertical Section (feet) -> Azimuth 186.41 with reference 0.00 N, 0.00 E from Slot #112 5700 6000 6300 6600 6900 7200 II: I.() -350 I"- /I E (.) -0 Q) ëij ú (f) 350 700 Q 1050 ;Ii ~ <:::¡;g1400 -A :;;It 1750 ~ f-t-' 2100 I ~ _ 2450 ... l- I V 2800 C I.;:,¡JiifQ·----- ! 20.000'0 C""""" KOP 6.00 Bid 4/100 18.00 Bid 5/100 Bid 3/100 27.45 Bid 5/100 3806 Base Permafrost 48.06 Top T-3 EOC ConocoPhillips Alaska, Inc. Location: North Slope, Alaska Field: Kuparuk River Unit Installation: Pad 1E Slot: Slot #112 Well: 112 Wellbore: 112 TopK-15 Trn 4/100 62.92 EOC ::; 13 3/8" Casing PI 3150 3500 3850 4200 Tor:> Ugnu C BldlTrn 5/100 DLS: 5.00 deg/100ft Top Ugnu B Top Ugnu A 66.09 K-13 61.93 61.47 61.49 112L2 112L 1 112 -350 0 350 Seale 1 em = 175 ft 700 1050 1400 1750 2100 2450 2800 3150 3500 3850 4200 4550 4900 Vertical Section (feet) .> Azimuth 104.04 with reference 0.00 N, 0.00 E from Slot#112 C~illips Created by : Planner ,_ Date plotted 19-May-2004 Plot reference IS 112 Ref wellpath IS 112 Vei#3 I Coordinates are In feet reference Slot #112 True Vertical Depths are reference Rig Datum Measured Depths are reference Rig Datum I Rig Datum Doyon #141 RKB Rig Datum to mean sea level: 95.00 ft. Plot North is aligned to TRUE North. e e l r-~-- ..: íNi~Q ~" . -~------ . . .- _~~=O~c~~~I~~~~ Ala~:':~~2c·1 Field: Kuparuk River Unit Well: 112 Installation: Pad 1E Well bore: 112 ~u_________"'.________. ~~ Scale 1 em = 250 ft -2500 -2000 -1500 -1000 -500 ESTIMATED SURFACE LOCATION: 191' FSL, 226' FEL SEC. 1~T11N.R10E -- o 500 East (feet\ -> 1000 15ðo WOO 2500 3000 3500 4000 4500 5000 5500 EOC Top West Sak D Bid 3/100 Top West Sak B EOC A4 A-3 ~ b.\" \\)\)R) 95 Az 'f-o%\~\òt~\\~\\~G 'f-':~\\)\) ..¿J ~;\! ~\ò <Ç -<; o"9í..~~~oG -----<J OS\. -<;,~ ~<S'i--~ -<; o~ ,?0 o ~'ð-S v<:£~~':J\\\)\) -<;o%\ò\ \ 104.04 Az <?0 <i,\~1êð 'Ó' G'õ> \':1 ':1\ Top Ugnu B Top Ugnu A K-13 . T~~~ST SAK D LOCA TIONJ !. 137S'FNL,2379'FEL SEC. 22, T11 N, R10E r··OP.··.·.·.·.w.·.·.·.·.·.·.·.··.E.·..·..·.·.S.·. T SAK B LOCATION, . 1655' FNL, 2411' FEL SEC. 22, T11N,R10E 9 5/8" Casing ptJ L ~ël4/100 EOC TOP WEST SAK A2 LOCATION: 2S62'FNL,2515'FEL SEC. 22, T11N,R10E - 00 9" w - >- N LTD 5 112in liner Conoc~illips Created by: Planner Date ploUed: 18-May-2004 . Plot reference is 112. Ref well path is 112 Ver#3. Coordinates are in feet reference Slot #112. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum. Rig Datum: Doyon #141 RKB I Rig Datum to mean sea level: 95.00 ft. Plot North is aligned to TRUE North. 500 o -500 - -1000 - -1500 .- -2000 - -2500 - -3000 - -3500 f' Z o - -4000;:¡" =r ;; - -4500 ~ - - -5000 .- -5500 .. -6000 - -6500 - -7000 1 E-112/1 E-112L 1/1 E-112L3 TD LOCATIONS: 1407'FNL,2296'FWL SEC. 27, T11N,R10E - -7500 en o Q) ãï - -8000 ~ 3 " - -8500 ~ o ;: ! I ~\J!~ L ConocoPhilIipsAlaska., Inc. Kupa.uk River Unit Installation: Pacl1 E Well: 112 Wellbore: Seale 1 ern'" 100 ft 2200 2400 East ifeet\ -> 2600 2sðo 3600 3200 3400 3600 -200 -400 -600 -soo -1000 - -1200 -1400 3400 -1600 -1800 -2000 ^ , -2600 -- -2800 - -3000 -3200 -3600 (f) (") -3800 15- -" o o -4200 ;:j! ConocoPhillips Alaska, Inc. Location: North Slot: Field: Kupa,uk Rive, Unit Well: 112 installation: Pad 1E Wellbore: 112 Scale 1 em 100ft East !feet~ ~> 2000 2200 2400 26 0 2 00 3000 3200 3400 I __.1 I I -3200 F&IFJ -3400 "../ --/ "-./) -3600 -3800 -4000 3600 -4200 -4400 -4600 -4800 -5000 ^ I 3560 -5200 -5400 -5600 -5800 -6000 -6200 -6400 4720 4760 -6600 4800 I 4840 3540 (j) 0 4880 -6800 !)J ro 4920 0 -7000 :3 II ..... <:) <:) -7200 ;:: ! Created by ; Planner 19w~~x~99~ _ PTOfrefurinçe is Re:fwe!lpath ¡$112Ver#3, Coordinates are- ín feet reference Slot #112. True Vertical Depths are reference Rig Datum. Measured Depths are reference Rig Datum> Doyon #141 RKB leve!: 9$.00 ft e Tie-In 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34 35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 63.62 3100.55 553330.16 842.678 56 64.76 3144.11 553370.40 923.416 57 66.09 3185.73 553403.30 1008.368 58 67.60 3225.08 553428.58 1096.888 59 69.27 3261.86 553446.08 188.298 60 71.08 3295.79 553455.64 1281.898 61 73.03 3326.62 553457.20 1376.998 62 75.00 3353.12 553451.14 1469.168 63 75.00 3354.11 553450.75 1472.848 64 75.00 3379.00 553441.00 1565.148 65 75.00 3379.99 553440.61 1568.838 66 75.00 3405.88 553430.47 1664.828 67 75.00 3407.99 553429.64 1672.648 68 78.00 3431 .32 553419.43 1769.268 69 80.00 3444.00 553412.58 1834.078 70 80.00 3448.41 553409.95 1858.938 71 80.00 3465.78 553399.61 1956.808 72 80.00 3483.14 553389.27 2054.668 73 80.00 3500.51 553378.93 2152.538 74 80.00 3517.87 553368.59 2250.398 75 80.00 3535.24 553358.25 2348.268 76 80.00 3552. 553347. 2446.128 77 80.00 3569.96 553337.56 2543.998 78 80.00 3587.33 553327.22 2641.858 79 80.00 3604.69 553316.88 2739.728 80 80.00 3608.87 553314.39 2763.248 81 83. 3620.07 553306.51 2837.898 82 87.04 3628.72 553296.05 2936.878 83 91.04 3630.40 553285.55 3036.228 84 91.15 3630.34 553285.27 3038.898 85 93.65 3626 553274.78 3138.178 86 94. 3623.86 553271.37 3170.408 87 94.46 3618.83 553264.59 3234.598 88 94.46 3611.05 553254.12 3333.678 89 94.46 3603.28 553243.66 3432.748 90 94.46 3595.50 553233.19 3531.818 91 94.46 3593.82 553230.92 3553.308 92 91.96 3588.22 553220.44 3652.518 93 91.15 3587.34 553217.02 3684.818 94 88.65 3587.52 553206.52 3784.188 95 87.80 3588.57 553202.97 3817.798 96 87.80 3589.03 553201.72 3829.668 97 87.80 3592.87 553191 .23 3928.978 98 87.80 3596.71 553180.73 4028.278 99 87 3600.55 553170.24 4127.578 100 87.80 3603.11 553163.24 4193.868 101 90.30 3604.77 553152.74 4293.228 102 91.15 3604.34 553149.19 4326.848 103 93.65 3600.16 553138.70 4426.128 104 94.60 3597.42 553134.70 4463.958 105 94.60 3592.51 553128.29 4524.608 106 94.60 3584.49 553117.83 4623.668 107 94.60 3576.47 553107.36 4722.718 108 94.60 3568. 553096.90 4821.778 109 94.6 3566.60 553094.49 4844.598 110 92.67 3561.72 553086.46 4920.928 111 91.34 3559.85 553080.95 4973.788 112 88.34 3559.69 553070.61 73.168 113 88.04 3560.57 553067.28 5105.278 114 88.04 3561.06 553065.78 5119.648 115 88.04 3564.49 553055.46 5218.978 116 88.04 3567.92 553045.13 5318.318 117 88.04 3571.35 553034.80 5417.648 118 88.04 3573.89 553027.15 5491.268 0.00 119 90.54 3575.14 553016.82 5590.648 2. 120 91.34 3574.61 553013. 5622.768 2. 121 93.84 3570.09 553003. 5722.048 2. 122 94.65 3567.70 552999.83 5754.048 2. 123 94.65 3562.73 552993.52 14.758 0 124 94. 3554.62 552983.22 5913.828 0.00 125 94.65 3546.51 552972.92 6012.898 0.00 126 94.65 3538.41 552962.62 6111.958 0.00 127 94.65 3536.29 552959.94 6137.778 0.00 128 92.15 3530.36 552949.63 6236.988 2.50 129 91.34 3529.38 552946.29 6269.058 2.50 130 88.84 352922 552935.96 .448 2.50 131 88.22 3529.86 552933.39 6393.168 2.50 132 88.22 3530.38 552931. 6409.828 O. 133 88.22 3533.48 552921.33 6509.178 O. 134 88.22 3536. 552911.00 6608.518 O. 135 88.22 3539. 552900.67 6707.868 0 136 88.22 3542.79 552890.34 6807.208 0.00 137 88.22 3545.00 552883.00 6877.818 0.00 *Tublng Head Assy, 20" X 13-3/8" X 9-6/8" X 4-1/2", 13-5/S" API 5M flange up, *Tubing Hanger, concentric, no penetrations *Conductor, 20" X 34" Insulated, set at SO', Tubing, Special Drift ¡IIi 7" X 9-5/8" ZXP :t~~H:~: ;:~:f í'.I '~""··"I Tubing SWivel, 4~1/2" DE! Nlpple,for Possible SSSV, set at +/- 500' MD GLM, Camco 1-1/2" MMG 1 E West Sak 9-5/8" Injector Tri-Lateral Completion Well #: 1 E-112 13-3/13" Surface Casing Shoe 61#, J-55, E!TC 3200' MD, 2314' TVD, GLM, Camco 1" KE!MG CMU Sliding Sleeve, w/ DE! profile, for Tubing MIT's TUbing String 4-1/2" 12,6#, L-aO, I~ Casing Seal bore Receptacle Lateral Entry Module(LEM) Orienting Profile D-sand Window / at 5,,9,,' MD, 3379' TVD ~Dª Sâñd Lateral 5-1/2" Guide Shoe 5-1/2" Casing Shoe @ 11046' MD, 3310' TVD 7" X 9-518" Model 'B' HOOK Hanaer Tubing Swivel, 4-112" 7" X 9-518" ZXP Liner Top Packer with Hold Downs Lateral Entry Module{LEM) Orienting Profile Casing Sealbore Receptacle 8-sand Window at 59S6' MD, 3446' TVD '8' Sand Lateral 5-112"15.5#, L-80 Slotted Liner 5-1/2" Bent Joint 5-112" Guide Shoe 7" X 9-518" Model 'B' HOOK Hancer 6-1/2" Casing Shoe @ 11052' MD, 3370' TVD 4-112" 12.6# Tubing 7" X 9-518" ZXP Lìner Top Packer Liner Hanger I Packer Assembly @+/-6762'MD, 3600' TVD Sea! Assembly Undulatina 'A' Sand Lateral 7" X 9-5/8" HMC Liner Hanger 5~1/2" Eccentric Guide Shoe CasÎng Sealbore Receptacle 5-112" Casing Shoe @ 11071' MD, 3545' TVD 1111. .,.. 9.51S" Casing Shoe 40.0#, L-SO eTC 12-1/4" Hole @ 6512' MD, 3600' TVD Baker Oil Tools e . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME I<-klX I E~-1/2L Z-- PTD# 2DC¡~Cft3 t/< Development Service CHECK WßA T APPLIES ADD-ONS (OPTIONS) MULTI LATERAL ¿/ (If API number last two (2) digits are between 6.0-69) Exploration Stratigraphic "CLUE" The permit is for alew weJJbore segment of existing well }:::.Æ?~ /E -:-/1 2--- '7 -? ,.' ,. . Permit No,2PIf-t."kll API No. 5c')û2f-..:-? 2//-06 Production should continue to be reported as a function 'of the original API number. stated above. BOLE In accordance with 2.0 AAC 25..0.05(1), an records, data and Jogs acquired for tbe pilot bole must be dearly differentiated In both name (name on permit plus PH) and API Dumber (5.0 7.0/8.0) from records, data and Jogs acquired for well (name on permit). Pn.-OT (PH) SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject ·to full compliance with 2.0 AAC 25..055. Approval to perforate and produce is contingent upon issuance of t\ conservation order approving a spacing e:JCeption. (Company Name) assumes the liability of any protest to the spacinge:xception tbat may occur. All dry ditch sample sets submitted to the Commission must be in no greater tban 3D' sample intervals from below tbe permafrost or from where samples are first caugbt and ].0' sample intervals tbrough target zones. ~ D _ Well bore seg Annular Disposal On Program DEV On/Off Shore Name: KUeABUK RIV U WSAK 1E-112L2 GeoArea Unit 11160 Multi-lateral w~1 890 bore Wel E'EI'LD DE~1 -_ f~e oot re_quired, We_st SaJ<_QilP_ool will lie _entirely wtth.in un.itized State leasesAD_L025651 CQn_ser:vatipo Ord_er No. 40QA. _KupaJuk_Ri\{er Uoit NQminal spa_ctng withio th~ pooJ is10_acr~s.Wel andAD_L025&60. be Ipcated_ more injection Sak P¡iu:ticipating Are¡l..and wi Neare_st whjch are c;ommitted _to the West '^D'"'' Jil)es-"'I/h~œ_ownership ch_ange_s._ f}OOJee_t ¡lWay. productioJ19r than ;30Q feetJrplJ\ any ph..",e.." welJ open to wi the pool e Inje_ction_ Order No, 28 bor~ gOllerrted by Aœa multiolateraL well IS.ßU :11;-33. KRU_lE~22_ Willbepre-producedfor_abouL1SQ days per Lniection Yes Yes _Yes Yes Yes Yes Yes _Yes Yes Yes Yes Yes Yes Yes Yes Yes ClasslType Initial KUPARUK RIVER. WEST SAK OIL - 490150 INC Field & Pool Pe(rT) it fee attached leas_e _number -nn., _U_niq\.le welLna nd oumb_er located ~..",.opriate in_a d_efioedpool Wel Well Well b_ouod.a()' _ from drilling uoit w~lIs located proper _distance located prpper distançe_ from other S_utficieot . Itdeviatec in driUiog unit ioclud~d _acr~age_aYail¡;¡bl~ .is_ wellbore plat only affect~d party bas_apprppriate_ Qond tnJorce can be issued without can be issued without co_nservatioo order admioistrative apprpval Perm it PelJT)it Can permit be approved before 15-day wait Well located within area and_strata authorized by_ Jnjectioo Order #I (put 10# in_ cpmments)_ (For _All wells_within $eN.ieeweU Steve Shultz:, 6/1/200<1. Jl4J'tliLe_area_of reyi~w ideotified dur¡;¡tion_of prei>roduc;tioo less than_ 3 mooths (Fors~rvtce w~1I only) 0011') (Fpr 2 3 4 5 6 7 8 9 o 11 12 13 14 15 16 7 Administration _Operator _Oper_ator Date 6/3/2004 Appr SFD - jn the motherbore._lE-t12 :147.102(b)(3). the moth_erbpre, Con_duc;tor was set 1\1[ "'111"11':" ~I""" ð"...."""'nt. SUI Jente_d to surface_ io ......_wOJe_.... "^~._....ied 40 Cfß 1;-112, be _cemeoted_ above_ any hydJQC¡;Jrboo Intermediate casing wi Slotted liner planoe_d. Wa_stetQ ao approyed artnulU$ Qrdisposal weJI._ No r~seJlle_pitplanOed, Rig jSßq\.lippe_dwith steel pits. -:-150'Jvd_ deeper. lE-112l-1 I?rp~imtty- an¡;¡lysis perfprme_d, Closest wellboreJs BOI? will_alreadY be in place. _ _ B/-IF? exp~cted be!ween 7,9_- _8.5£MW. e. Sak. to testto 5000 psi. Hig is ~qujpp~d with_s_en$ors_ and _alarms_. rig, _the_ isawar~of 1::i2S Mud_ should pœcludeH2-8_o_n 1 E-22 is further JrpIJ\L2 _than _L-t _CPAI NA Yes NA Yes No_ No_ Yes Yes NA .Yes NA Yes Yes Yes Yes Yes No_ Yes this proiect inj~ctor Con_si.$tency_h_as beenj~sued_ for_ stril1g_PJQvided _Cpndu_ct_or Surface "a known USQWs CMT vpl j~c u.ate to circ!Jlate oncond_uctoc PJ~-produ_ced ACMP Finding 9f 18 19 20 Engineering _..~ing_pJotects al & surf_csg _CMT vol adeQu.ateJo tie-tn long _string to surf ~g_ l<oowJ1prQductiye hon;z:ons C.T. B_&permafr_ost _CMT will c;oyeral' C_asing designs adequaí~ for reserve pit _Adequate_tQnkage OJ abandooment beßO apPJoved JtaJe-drilt hQs_a 10~03 fOJ A~equate we!lbor~ separatjo_n _proposed Jtdjver::ter req!Jired, dQes it meet r~gulatioos_ _Drillio9 fJujd_ program sc.hematic_& ectuip listadequate _B0P~s.dp 9.0 .in West MASF? calc;uJate_d_at1t13psi. 35QOp.$iappcopriate_.CPAJ Ijkely 21 22 23 24 25 126 27 28 29 30 31 32 33 34 Plaoned MW _(put psig incomm~ot$) r~gulatioo ra_tiog appropriate; test to _Choke_manifold complies w/API RF?-53 (May 64) Work wiJI occur withoyt _operation _sbytdown they meet B_OPEpress App Date TEM~." 6/8./~. 004 Jq'V v- the oeed to address integrjty of lEo2.2. is _uolikely. wells withio ~OR yeriJiec! (for_ s_ervice well only) H2S gas prob_abl~ _coodjtion of Js presençe_ of MeCha_nical than 7 ppmH.2S jn August _20Q3_. IS.RU WestSal< wells_1}2 miJe_ to east m_easure_dJess Exp~cted œservoir pressure i.$ 7.9 - _8,5 P.P9 EMW; wi Yes Yes NA NA NA can be tssu_ed wlo_ hydrogen s_ulfide meaS!Jres Permit _D_ata_pres~oted on pote_ntial pveJ :¡res_Sure _zones be drilled wjth 9.0 ppg mud. _Seismicanalysjs_ of shaJlow gaszpoes (if off-shore) _Seabedcoodjtipo survey 35 36 37 38 139 Geology Date 6/3/2004 Appr SFD Proposed tri-Iateral injection well bore. Initially classified as a development well bore as it will be pre-produced for about 180 days. Prior to conversion to injection, the operator must satisfy the requirements of regulation 20 Me 402 (e) concerning integrity of wells within Area of Review. ¡: Date ~/~ CQnta_ct l1arnelphooeJor_weekly progr~ssreports [explorato()'only] Date Engineering Commissioner r/~ Date: ( b Geologic Commissioner: 1)~ e -- Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information. information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. **** REEL HEADER **** LDWG 04/10/21 AWS 01 **** TAPE HEADER **** LDWG 04/10/21 01 *** LIS COMMENT RECORD *** . !!!1!! 1! 1! 1!!! 1! 1! 1 LDWG File Version 1.000 ! ! !! ! ! ! 1 ! ! ! !! !! ! ! !! Extract File: LISTAPE.HED TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 1 S. TUFTON F. HERBERT MWD RUN 10 10 G. SUTING F. HERBERT # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD 1ST STRING 2ND STRING . c:2o{-09, j/ )À p6~ lE-112L2 500292321161 ConocoPhillips Alaska, Inc. BAKER HUGHES INTEQ 20-0CT-04 13.375 3031. 0 MWD RUN 2 2 D. GONZALES F. HERBERT MWD RUN 11 11 F. WENDLER F. HERBERT 16 11N 10E 95.00 67.00 MWD RUN 3 3 S. TUFTON D. GLADDEN MWD RUN 12 12 G. SUTING F. HERBERT OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 16.000 . . # REMARKS: 3RD STRING 12.250 PRODUCTION STRING 8.500 5867.0 11273.0 Tape Subfile: 1 9.625 PER CONOCOPHILLIPS ALASKA STANDING ORDER, THE GAMMA RAY CURVE FROM THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. AS SUCH, NO DEPTH SHIFTS HAVE BEEN APPLIED. INDIVIDUAL MWD RUN DATA WAS MERGED IN THE FIELD PRIOR TO DELIVERY FROM THE WELL SITE. SURFACE LOCATION: LAT: N 70 DEG 18' 03.199" LONG: W149 DEG 35' 33.356" LOG MEASURED FROM D.F. AT 95.0 FT. ABOVE PERM. DATUM (M.S.L.) . COMMENTS: (1) Baker Hughes INTEQ runs 1 and 2 utilized a Gamma Ray Directional service from 108 - 3045 feet MD (108 - 2316 TVD) . (2) Baker Hughes INTEQ run 3 utilized an AutoTrak RCLS (Rotary Closed Loop System) along with RNT (Reservoir Navigation Tool) Resistivity, and Gamma Ray services from 3045 - 6933 feet MD (2316 - 3607 TVD). (3) Baker Hughes INTEQ run 9 utilized a Gamma Ray Directional service with a whipstock assembly to set a whipstock, mill a window in the 9 5/8" casing of the parent well, 1E-112, and drill to 5880 feet MD (3420 TVD) . (4) Baker Hughes INTEQ runs 10, 11, & 12, utilized an AutoTrak RCLS (Rotary Closed Loop System) along with RNT (Reservoir Navigation Tool) Resistivity, Gamma Ray, and Modular Annular Pressure (MAP) services from 5880 - 11273 feet MD (3420 - 3336 TVD). REMARKS: (1) Depth of 13 3/8" Casing Shoe - Logger: 3031 feet MD (2311 TVD) Depth of 13 3/8" Casing Shoe - Driller: 3031 feet MD (2311 TVD) (2) This D-sand lateral (lE-112L2) was kicked off the parent wel1bore (lE-112) through a window in the 9 5/8" casing. Top of 9 5/8" Casing Window: 5841 feet MD (3411 TVD) Bottom of 9 5/8" Casing Window: 5867 feet MD (3417 TVD) (3) The interval from 11242 to 11273 feet MD (3338 - 3336 TVD) was not logged due to sensor-bit offset at TD. $ 88 records... Minimum record length: Maximum record length: 8 bytes 132 bytes LDWG .001 **** FILE HEADER **** 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILE001.HED FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE MWD $ . . 1 and clipped curves; all bit runs merged. .5000 START DEPTH 154.0 STOP DEPTH 11273.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD $ # REMARKS: BIT RUN NO 1 lR 2 7 8 8R MERGE TOP 154.0 2130.0 2995.0 5841. 0 6617 . 0 8173.0 MERGE BASE 2130.0 2995.0 5841. 0 6617.0 8173.0 11273.0 MERGED PASS. NO DEPTH SHIFTS WERE APPLIED AS THIS LOG IS THE DEPTH REFERENCE FOR THIS WELL. $ # *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT le-112L2 5.xtf 150 ConocoPhillips Alaska, Inc. lE-11212 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ---------------------------------------------------- ODEP GR GR GRAM 0.0 RPD RPD RPD 0.0 RPS RPS RPS 0.0 ROP ROP ROPS 0.0 FET FET RPTH 0.0 MTEM MTEM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 28 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 36 . . One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth 10: F 6 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 GAPI 4 4 2 RPD MWD 68 1 OHMM 4 4 3 RPS MWD 68 1 OHMM 4 4 4 Rap MWD 68 1 FPHR 4 4 5 FET MWD 68 1 HR 4 4 6 MTEM MWD 68 1 DEGF 4 4 ------- 24 Total Data Records: 618 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 154.000000 11273.000000 0.500000 feet **** FILE TRAILER **** Tape Subtile: 2 663 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .002 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILEOll.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 2 log header data for each bit run in separate tiles. 1 .2500 START DEPTH 154.0 STOP DEPTH 2130.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE 27-JUN-04 . SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM}: HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3}: RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: BIT RUN 1 (MWD Run 1). GR/Dir. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) ROPS - RATE OF PENETRATION (FPHR) TCDM - TEMPERATURE (DEGF) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1e-112L2.xtf LCC 150 CN ConocoPhillips Alaska, I WN 1E-112L2 FN Kuparuk River COUN North Slope STAT Alaska *** INFORMATION TABLE: CIFO . MSB 18655 8.25 GAM MEMORY 2180.0 154.0 2130.0 o 0.0 60.5 TOOL NUMBER DHA 6437 SRIG 8017 16.000 108.0 SPUD 9.50 .0 .0 500 .0 .000 .000 .000 .000 78.0 .0 .0 .0 .00 .000 .0 o . . MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM ROPS TCDM GRAM ROPS TCDM GRAM ROPS TCDM 0.0 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 16 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 63 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 3 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAPI 4 4 2 ROPS MWD 68 1 FPHR 4 4 3 TCDM MWD 68 1 DEGF 4 4 ------- 12 Total Data Records: 126 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 154.000000 2130.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 3 201 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .003 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!! ! !!!!!!!!!!!!!!!!!! ! FILE HEADER FILE NUMBER: RAW MWD LDWG File Version 1.000 Extract File: FILE012.HED 3 . . header data for each bit run in separate files. lR .2500 Curves and log BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ START DEPTH 2130.0 STOP DEPTH 2995.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: BIT RUN 1R (MWD Run 2). GR/Dir. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) ROPS - RATE OF PENETRATION (FPHR) TCDM - TEMPERATURE (DEGF) $ # *** INFORMATION TABLE: CONS MNEM VALU 28-JUN-04 MSB 18655 8.25 GAM MEMORY 3045.0 2130.0 2995.0 o 60.5 63.5 TOOL NUMBER DHA 6437 SRIG 8017 16.000 108.0 SPUD 9.45 .0 .0 400 .0 .000 .000 .000 .000 78.0 .0 .0 .0 .00 .000 .0 o . . -------------------------------- WDFN LCC CN WN FN COUN STAT le-112L2. xtf 150 ConocoPhillips Alaska, I lE-112L2 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM ROPS TCDM GRAM ROPS TCDM 0.0 0.0 0.0 GRAM ROPS TCDM * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 16 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: (F ] Number of frames per record is: 63 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 3 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAPI 4 4 2 ROPS MWD 68 1 FPHR 4 4 3 TCDM MWD 68 1 DEGF 4 4 ------- 12 Total Data Records: 55 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 2130.000000 2995.000000 0.250000 feet **** FILE TRAILER **** Tape Sub file: 4 130 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .004 . 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILEOI3.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 4 . log header data for each bit run in separate files. 2 .2500 START DEPTH 2995.0 STOP DEPTH 5841. 0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR RNT GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL RES. NAV. TOOL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # 02-JUL-04 MSB 18655 8.25 ATK MEMORY 6933.0 2995.0 5841. 0 o 63.5 80.8 TOOL NUMBER ATK 23702 RNT 2058 RNT 2058 12.250 3031. 0 SPUD 9.40 .0 .0 200 .0 .000 .000 .000 .000 120.0 .0 .0 .0 .00 .000 .0 o REMARKS: # . . BIT RUN 2 (MWD Run 3). GR/RNT. This D-sand lateral (lE-112L2) was kicked off the parent wellbore (IE-112) through a window in the 9 5/8" casing at 5841' MD. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILLIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT le-11212.xtf 150 ConocoPhillips Alaska, I lE-11212 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPCH RPCH RPS 0.0 RACL RACL RAD 0.0 RACH RACH RAS 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 36 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 28 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: 0.250 * F . Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAPI 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 ROPS MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 8 TCDM MWD 68 1 DEGF 4 4 ------- 32 Total Data Records: 407 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 2995.000000 5841.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 5 500 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .005 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !!!!!!!!!!!!!!!!!!! Extract File: FILEOI4.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 5 . log header data for each bit run in separate files. 7 .2500 START DEPTH 5841. 0 STOP DEPTH 6617.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) 20-JUL-04 MSB 18655 6.75 ATK MEMORY 6648.0 5841. 0 6617.0 o . MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR RNT GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL RES. NAV. TOOL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: . 85.4 96.0 TOOL NUMBER ATK 98745 RNT 20105 RNT 20105 8.500 5867.0 OBM 9.15 .0 .0 39000 .0 .000 .000 .000 .000 104.0 .0 .0 .0 .00 .000 .0 o BIT RUN 7 (MWD Run 10). GR/RNT. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILLIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN 1e-112L2.xtf LCC 150 CN ConocoPhillips Alaska, I WN 1E-1l2L2 FN Kuparuk River COUN North Slope STAT Alaska . . *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPCH RPCH RPS 0.0 RACL RACL RAD 0.0 RACH RACH RAS 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD ( TYPEi¥ 64) Data record type is: 0 Datum Frame Size is: 36 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 28 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth 10: F 8 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAPI 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 ROPS MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 8 TCDM MWD 68 1 DEGF 4 4 ------- 32 Total Data Records: 111 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 5841.000000 6617.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 6 201 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .006 . 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 ! !! ! ! ! !! !! ! ! !! !! !!! Extract File: FILE015.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 6 . log header data for each bit run in separate files. 8 .2500 START DEPTH 6617.0 STOP DEPTH 8173.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DIR RNT GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL RES. NAV. TOOL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # 22-JUL-04 MSB 18655 6.75 ATK MEMORY 8191. 0 6617.0 8173.0 o 87.9 91. 8 TOOL NUMBER ATK 35406 RNT 1062 RNT 1062 8.500 5867.0 OBM 9.00 .0 .0 40000 .0 .000 .000 .000 .000 122.0 .0 .0 .0 .00 .000 .0 o . . REMARKS: BIT RUN 8 (MWD Run 11) . GR/RNT. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILLIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT le-112L2.xtf 150 ConocoPhillips Alaska, I lE-112L2 Kuparuk River North Slope Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPCH RPCH RPS 0.0 RACL RACL RAD 0.0 RACH RACH RAS 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 36 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 28 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units Size Length . 1 GRAM MWD 68 1 GAPI 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 ROPS MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 8 TCDM MWD 68 1 DEGF 4 4 ------- 32 Total Data Records: 223 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 6617.000000 8173.000000 0.250000 feet **** FILE TRAILER **** Tape Subfile: 7 313 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** FILE HEADER **** LDWG .007 1024 *** LIS COMMENT RECORD *** !!!!!!!!!!!!!!!!!!! LDWG File Version 1.000 !! !! !! ! ! ! !! !! !! !! !! Extract File: FILE016.HED FILE HEADER FILE NUMBER: RAW MWD Curves and BIT RUN NO: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE MWD $ 7 . log header data for each bit run in separate files. 8R .2500 START DEPTH 8173.0 STOP DEPTH 11273.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: # 25-JUL-04 MSB 18655 6.75 ATK MEMORY 11273.0 8173.0 11273.0 o 88.1 94.2 . TOOL STRING (TOP TO VENDOR TOOL CODE DIR RNT GRAM $ BOTTOM) TOOL TYPE DIRECTIONAL RES. NAV. TOOL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # . TOOL NUMBER ATK 59544 RNT 20047 RNT 20047 8.500 5867.0 OBM 9.05 .0 .0 35000 .0 .000 .000 .000 .000 132.0 .0 .0 .0 .00 .000 .0 o BIT RUN 8R (MWD Run 12). GR/RNT. CURVE GLOSSARY: GRAM - GAMMA RAY APPARENT (MWD-API) RPCL - DEEP PHASE RESISTIVITY (OHMM) RPCH - SHALLOW PHASE RESISTIVITY (OHMM) ROPS - RATE OF PENETRATION (FPHR) RPTH - FORMATION EXPOSURE TIME (MIN) TCDM - TEMPERATURE (DEGF) PER CONOCOPHILLIPS ALASKA (WAYNE CAMPAIGN), THE FOLLOWING CURVES ARE NOT PRESENTED ON THE MPR RESISTIVITY LOG BUT ARE PRESENTED HERE FOR THE SAKE OF COMPLETENESS: RACL - DEEP ATTENUATION RESISTIVITY (OHMM) RACH - SHALLOW ATTENUATION RESISTIVITY (OHMM) $ REMARKS: # *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN le-112L2.xtf LCC 150 CN ConocoPhillips Alaska, I WN lE-112L2 FN Kuparuk River COUN North Slope STAT Alaska *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP . . ---------------------------------------------------- GRAM GRAM GRAM 0.0 RPCL RPCL RPD 0.0 RPCH RPCH RPS 0.0 RACL RACL RAD 0.0 RACH RACH RAS 0.0 ROPS ROPS ROPS 0.0 RPTH RPTH RPTHM 0.0 TCDM TCDM TCDM 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 36 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.250000 Frame spacing units: [F ] Number of frames per record is: 28 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.250 * F ONE DEPTH PER FRAME Tape depth ID: F 8 Curves: Name Tool Code Samples Units Size Length 1 GRAM MWD 68 1 GAPI 4 4 2 RPCL MWD 68 1 OHMM 4 4 3 RPCH MWD 68 1 OHMM 4 4 4 RACL MWD 68 1 OHMM 4 4 5 RACH MWD 68 1 OHMM 4 4 6 ROPS MWD 68 1 FPHR 4 4 7 RPTH MWD 68 1 MINS 4 4 8 TCDM MWD 68 1 DEGF 4 4 ------- 32 Total Data Records: 443 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 8173.000000 11273.000000 0.250000 feet **** FILE TRAILER **** Tape Sub file: 8 533 records... Minimum record length: Maximum record length: 8 bytes 4124 bytes **** TAPE TRAILER **** LDWG 04/10/21 01 **** REEL TRAILER **** LDWG 04/10/21 AWS 01 Tape Subfile: 9 Minimum record length: Maximum record length: . . 2 records... 132 bytes 132 bytes
