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206-111
TE OF ALASKA WSAK 1J-102L1 A SKA OIL AND GAS CONSERVATION COMARION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Plug Perforations Fracture Stimulate E Pull Tubing E Operations Shutdown r'. Performed: Suspend fl Perforate I-• Other Stimulate Alter Casing r Change Approved Program r-', Plug for Redrill I-` Perforate New Pool I` Repair Well I" Re-enter Susp Well I- Other: Marcit Gel Treatmnt F 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development fl Exploratory E 206-111 3.Address: 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic E Service ' 50-029-23317-60 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25661,ADL 25662 KRU 1J-102L1 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 12242 feet Plugs(measured) 5050 true vertical 3582 feet Junk(measured) None Effective Depth measured 12091 feet Packer(measured) 4673,4837,5160 true vertical 3584 feet (true vertical) 3624,3562,3625 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20 120 120 SURFACE 2600 13 2643 2255 INTERMEDIATE 5007 7.625 5047 3741 B LINER SLOTTE 6849 6.41 12093 3585 RECEIVED � I NOV 0 8 2016 Perforation depth: Measured depth: 5308-12058,5328-5333 True Vertical Depth: 3604-3585,3603-360203 y GCC Tubing(size,grade,MD,and TVD) 4.5, L80,4707 MD,3533 TVD Packers&SSSV(type,MD,and ND) PACKER=ZXP liner Top Packer @ 4673 MD and 3624TVD PACKER-ZXP Liner Top Packer @ 4837 MD and 3562 TVD PACKER=HRD Liner Top Packer @ 5160 MD and 3625 TVD NIPPLE-CAMCO DB NIPPLE @ 516 MD and 514TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): NONE - SCANI4 U ,-\'_,F. ." 3 20 i Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation - - Shut-In - - Subsequent to operation - - 1071 - 0 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: !� Daily Report of Well Operations F Exploratory r Development E Service F Stratigraphic I- Copies of Logs and Surveys Run r 16.Well Status after work: Oil E Gas la WDSPL I- Printed and Electronic Fracture Stimulation Data fl GSTOR I- WINJ F WAG I` GINJ I-, SUSP I- SPLUG I- 17. 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: 316-523 Contact John Peirce ta7 265-6471 Email John.W.Peirce@conocophillips.com Printed Name John Peirce Title Sr. Wells Engineer Signature '.,- 1/ . Phone:265-6471 Date /j /7/./...Form 10-404 Revised 5vn- 31z '// RBDMS ,\,NOV 1 0 2016 Submit Original Only zof 1l 7 • 1J- 102 L1 DTTMSTP JOBTYP SUMMARYOPS 10/13/16 MISC. MARCIT GET TREATMENT OF MBE: PUMPED SEAWATER FLUSH CAPACITY FOLLOWED BY LINEAR POLYMER TAKING RETURNS TO FLOWBACK SUSTAINMEN UNIT AT 1J-159 TO DETERMINE MBE VOLUME. IDENTIFY RETURNS T OF POLYMER AT 1J-159 AND USE 60 BBL MARCIT TREATMENT VOLUME (80 BBL ESTIMATED MBE VOLUME LESS 20 BBL SAFETY FACTOR). PUMP 60 BBL MARCIT GEL(10,000 PPM, 30:1 CROSSLINK, 5%ACCELERANT)AND DISPLACE TO MBE WITH LINEAR POLYMER, SEAWATER, AND 42 BBL OF DIESEL FREEZE PROTECT. JOB COMPLETE. '�,� KUP 1 J-1 02L1 ..ConocoPhiIIipss '/ Well Attribut Max Angl .D TD Alaska.ir'i.. Wellbore API/UWI Fold Name Wellbore Status ncl Cl MD(SOB) Act Btm(ftKB) COft00 jylggps'+' 500292331760 WEST SAK INJ 94.63 10,743.74 12,242.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1J-102L1 11/720168.37.22 AM Y SSSV:NIPPLE 100 8/14/2012 Last WO-. 44.291 10/4/2006 Vertical achemahs(eotoel/ Annotation Depth(RKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:QC smsmith 10/26/2015 HANGER;35.8 11 Ail Casing Strings �� tic.Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...WI/Len(I...Grade Top Thread ,-coeoucroR;40.o-1z0.o• yI�aim B LINER Slotted 41/21 3.4761 5,244.91 12,093.41 3,585.21 11.601L-80 Buttress NIPPLE;515.9 -g.- €' Liner Details (1...I II 1 Nominal ID SURFACE;42.5-2,842.8 1 Top(ftKB) Top(TVD)(RKB) Top Incl Cl Item Des Com (in) GAS LIFT;2,789.2 5,244.9 3,607.4 93.51 SLEEVE Baker HR Liner setting sleeve 5.750 • 5,303.1 3,604.1 92.97 XO BUSHING Hydril 521 XO Joint 3.960 GAS LIFT;4,488.4It Perforations&Slots ISO SLEEVE;4,631.01 Shot SLEEVE-C;4,831.4 VII Dens Top(TVD) Btm(TVD) (shots/ Top(ftKB) Ellin(ftKB) (ftKB) (ftKB) Zone Date R) Type Com TOR;4,678.1 5,308.0 12.058.0 3,603.9 3,584.7 WS B,WS C, 9/22/2006 32.0 SLOTS All Perfs in this well: LOCA SEAL ASSY; TOR.4,680.9 - 1J-102L1 Alternating solid/slotted pipe-0.125'o2.5"@ 4 circumferential adjacent Itl q rows,3"centers 'li + staggered 18 degrees,3' ISO SLEEVE,4,730.0 '11* non-slotted ends iIi II 5,328.0 5.333.0 3,603.0 3,602.7 WS A2,WS 9/2/2015 6.0 IPERF 2in Powerflow HSD, A3,1J-102 2006FP.6SPF ( Notes:General&Safety End Date Annotation 10/6/2006 NOTE:MULTI-LATERAL WELL:1J-102(A-SAND),1J-102L1(B-SAND),1J-102L2(D-SAND) 'a� 0 LINER LEM,4,672.7-4,886.2 10/16/2008 NOTE:VIEW SCHEMATIC w/9.0 7/3/2014 NOTE:EXTERNAL SLEEVE(.500 X 65)WELDED ON SC FROM 42.5'TO 53.8' D LINER HH;4,727.2-4,984.9 INTERMEDIATE;40.45,9200 B LINER LEM;4,838.95,191.6. II. B LINER HH;5,048.15,2960 �1 IPERF;5,328.05,333.0 - i SLOTS;5,308.0-12,058.0 'is —I j —I I -i 1- - I l- '• - f B LINER Slotted;5,2448- i 12,0934 i 436(Moc Regg, James B (DOA) From: NSK West Sak Prod Engr <n1638@conocophillips.com> Sent: Saturday, October 22, 2016 5:48 PM Z,c7e i (z--4 I l b To: Regg,James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Ops Supv; NSK Problem Well Supv; Sullivan, Michael; NSK Prod Engr Specialist; CPF1 Prod Engr;Targac, Gary; NSK Optimization Engr; CPF1 DS Operators; Effiong, Michael Subject: Defeated LPP/SSV on CPAI well 1J-102 Jim, r". The low pressure pilot(LPP) on well 1J-102 (PTD#206-110, 206-111, 206-112)was defeated today, 10/22/16, after the well was returned to water injection service. The LPP and surface safety valves (SSV) have been tagged and their status is recorded in the "Facility Defeated Safety Device Log." The well is currently injecting 470 BWPD at a wellhead injection pressure of 2 psig. The AOGCC will be notified when the injection pressure has increased to above 100 psig and the LPP/SSV function is returned to normal, in accordance with "Administrative Approval No. CO 4066.001." Please let me know if you have any questions. Kind Regards, Scott Stanley / David Haakinson West Sak Production Engineers ConocoPhillips Alaska, Inc. Office: (907) 659-7234 Pager: (907) 659-7000 #497 n1638@conocophillips.com SCANNED ,UN �� : • • V OF Tb 4 ,\4I ,v?. THE STATE Alaska Oil and Gas OfA LAsKA.. Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 0" Q, Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov John Peirce Sr. Wells Engineer ConocoPhillips Alaska, Inc. SCANNED !, P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1J-102L1 Permit to Drill Number: 206-111 Sundry Number: 316-523 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, dV-4 /‘°) Z4"/° Cathy . Foerster Chair DATED this FT"day of October, 2016. RBDIVMS OCT 1 4 2016 • t:Li, i ' V ED STATE OF ALASKA • OCT 1 2 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION vis /01/1<-i g., APPLICATION FOR SUNDRY APPROVALS ROGGC 20 AAC 25.280 1.Type of Request: Abandon E Plug Perforations Fracture Stimulate I Repair Well I— Operations Shutdown I— Suspend Perforate E Other Stimulate[ Pull Tubing E Change Approved Program I._... Plug for Redrill 1Perforate New Pool I— Re-enter Susp Well E Alter Casing r Other: Marcit Gel Tre1tmn F . 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: / r�t ConocoPhillips Alaska,Inc. Exploratory I- Development E 206-111 3.Address: 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 Stratigraphic Service F , 50-029-23317-60 7.If perforating: a�•y, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? n ,,t/l, 1�' Will planned perforations require a spacing exception? Yes (- �VNo 17. ,/ KRU 1J-102L1 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25661,ADL 25662 . 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): 12,242' ' 3,582' • 12091 + 3584 1500psi none none Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 120' 120' Surface 2,600' 11" 2,643' 2,255' Intermediate 5,007' 8" 5,047' 3,741' Liner 6,848' 5" 12,093' 3,585' Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 5308-12058,5328-5333 • 3604-3584,3603-3603 4.500" L80 4,708' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): MD=4673 TVD=3624 PACKER=ZXP Liner Top Packer MD=4837 TVD=3562 PACKER=ZXP Liner Top Packer MD=5160 TVD=3625 PACKER=HRD Liner Top Packer NIPPLE=CAMCO DB NIPPLE MD=516 TVD=514 12.Attachments: Proposal Summary 0 Wellbore schematic E 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory Stratigraphic I Development E Service F. 14.Estimated Date for 10/18/2016 15.Well Status after proposed work: Commencing Operations: OIL E' WINJ F • WDSPL I Suspended I- 16.Verbal Approval: Date: GAS I-'. WAG I.-." GSTOR I- SPLUG I '' Commission Representative: GINJ I. '.' Op Shutdown I."' Abandoned I- 17.I hereby certify that the foregoing is true and the procedure approved John Peirce @ 265-6471 herein will not be deviated from without prior written approval. Contact Email John.W.Peirceaconocophillips.com Printed Name John Peirce Title Sr.Wells Engineer Signature /.} Phone 265-6471 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: -3`l - 5 23 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No Spacing Exception Required? Yes ❑ No ftd tj Subsequent Form Required: / — 4c, 4- RBDMS L ' OCT 1 4 2016 APPROVED BY / / Approved by: /46V../°- COMMISSIONER THE COMMISSION Date::/ —/ P (/q ' R+G4NtAsE Subn Form Duplicatee Fo403Revis d 1/20id for 12 months from the date of approval. Attachments in Duplicate • 1J-102L1 to 1J-159L1 B MBE Treatment with MARCIT Gel Proposal 1J-102 Tri-Lat injector was drilled & completed in 2006 with 4.5" slotted liners in West Sak A, B, & D sands. On 3/2/08, a B MBE occurred to offset producer 1J-159L1. A `B' Iso-Sly was set 9/28/08 before the B MBE was found. 1J-102 was put on A & D Sd PWI until 2015. On 6/8/15, a Plug was set at 5081' RKB to isolate A Lat. On 6/9/15, a B Diverter & D Iso-Sly were set, and a 6/10/15 IPROF in the B Lat found a large heel MBE at 5350' RKB at the first slotted joint below the B LEM. On 9/18/15, a FB Crystal Seal job was pumped to B MBE. A total of 3795 lbs of Crystal Seal was displaced to the B MBE. On 9/23/15, the B Lat was returned to PWI. On 10/4/15, 1J-159L1 production indicated that the B MBE treatment broke down. On 11/14/15, a FB retreat pumped another 2310 lbs of Crystal Seal to the B MBE. This treatment lasted for 10 days before 1J-159L1 production indicated the MBE treatment had failed. On 4/26/16, a third Crystal Seal job placed another 2970 lbs of Crystal Seal to the B MBE. This treatment allowed 1J-102 to be returned to PWI injection for —5 months before the treatment broke down 10/11/16. A fullbore MARCIT Gel treatment is now proposed to reseal the B MBE. Proposed Procedure: Pump MARCIT Gel Job: 1) MIRU Gel Pumping Unit equipment to perform a fullbore MARCIT Gel job. Fullbore pump uncrosslinked MARCIT down 4.5" Tubing at —0.5 bpm to B MBE at —5350' RKB while flowing 1J-159 to portable test separator. Grab fluid samples from 1J-159 every 15 minutes. Immediately test samples to determine initial arrival of MARCIT at 1J-159. When Gel is detected at 1J-159, SD pumping uncrosslinked Gel into 1J-102, and SI 1J-159. (Uncrosslinked Gel bbls pumped until Gel is detected at 1J159) = (1J102 bbls to MBE) + (1J159 bbls to MBE) + (MBE bbls). Calculate best guess estimated minimum MBE barrels. Resume injecting accelerated viscosity crosslinked MARCIT down tubing into 1J-102 while flowing 1J-159 to portable test separator to draw B MBE full of crosslinked MARCIT. Monitor treating pressure response. Try to maintain > or = 1:1 returns from well pair system to minimize any elevated differential pressures acting from the 1J-102 liner to the formation matrix during MARCIT Gel pumping through 1J-102L1 slotted liner. Since the B MBE is at the extreme heel of liner, any formation matrix damage potential should be minimal. Displace 1 MBE volume of crosslinked MARCIT down 1J-102 (up to maximum of 500 bbls) with Seawater and Diesel FP until the `tail' crosslinked MARCIT is 1 barrel from MBE, followed by Shutdown of all pumping into 1J-102, and a simultaneous shutdown of all flow from 1J-159. Leave both wells SI to build Gel viscosity within the B MBE at —5350' RKB. Leave 1J-102L1 SI for at least 5 days, then return 1J-102L1 to SWI while returning 1J-159 offset producer to production to evaluate results of the treatment. Coil Tubing: 2) RIH with Jet Swirl Nozzle to jet through excess MARCIT Gel left in the B lateral liner to as deep as possible while jetting Seawater. POOH with CT and Diesel FP tubing. RD CTU. JWP 10/11/2016 ,% KUP 11J-102L1 , ConocoPhillips / 3 ' Well Attribute Max Angle IIITD A(tik i.11?i, Wellbore API/UWI Field Name Wellbore Status nel C) MD(ftKB) Act Btm(ftKB) ConocaVhlgips"`'.? 500292331760 WEST SAK INJ 94.63 10,743.74 12,242.0 ... Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) 'Rig Release Date i.1-1021/,IDn2/20168.04.56AM SSSV:NIPPLE 100 8/14/2012 Last WO: 44.29 10/4/2006 Verbal schemaSo)acma9 Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason.QC smsmith 10/26/2015 HANGER,35.8...... ' 11 1' 11 a 11 Casing Strings I �- W Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...W8JLen(I...Grade Top Thread B LINER Slotted 4 1/2 3.476 5,244.9 12,093.4 3,585.2 11.60 L-80 Buttress _^-^-CONDUCTOR;40.0-120.0- 111 '�I Thread NIPPLE;515.9 Liner Details 1 Nominal ID SURFACE;42.5.2,642.8 L Top(ftKB) Top(TVD)(ftKB) Top Incl(") Item Des Corn (in) GAS LIFT;2,789.2 5,244.9 3.607.4 93.51 SLEEVE Baker HR Liner setting sleeve 5.750 5,303.1 3.604.1 92.97 XO BUSHING Hydril 521 XO Joint 3.960 GAS LIFT;4,488.4 Perforations&Slots ISO SLEEVE;4,631 0 Shot SLEEVE-C,4,631I(tli Dens alli Top(ND) Btm(TVD) (shots/ Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Corn AM' 5,308.0 12,058.0 3,603.9 3,584.7 WS B,WS C, 9/22/2006 32.0 SLOTS All Perfs in this well: LOCATOR.4.676.1 1J-102L1 Alternating solid/slotted SEAL ASSY;4,880.8 - pipe-0.125"x2.5"@4 circumferential adjacent ' rows,3"centers staggered 18 degrees,3' ISO SLEEVE;4,7300 1 non-slotted ends 5,328.0 5.333.0 3,603.0 3,602.7 WS A2,WS 9/2/2015 6.0 (PERF 2in Powerflow HSD, A3,13-102 2006FP,6SPF Notes:General&Safety 1 End Date _ Annotation 10/6/2006 NOTE:MULTI-LATERAL WELL:1J-102(A-SAND),1J-102L1(B-SAND),1J-102L2(D-SAND) MY 3 D LINER LEM;4,672.7-4,866.210/16/2008 NOTE:VIEW SCHEMATIC w/9.0 7/3/2014 NOTE:EXTERNAL SLEEVE(.500 X 65)WELDED ON SC FROM 42.5'TO 53.8' D LINER HH;4,727.2-4,984.9 ilirai'L INTERMEDIATE;40.4-5,920.0 B LINER LEM;4,836.9-5,191.6 II LINER HH;5,046.1-5,296.0\\\ d 4 (PERF,5,328.0-5,333.0 _- M SLOTS;5,308.012,058.0 - { - I —i I- 4 i B LINER Slotted;5,244.8- /E 12,093.4 l • • • 1 20"94.0#X 34"Insulated Conductor,0-95,set at nI-8D' 10-3/4"x 4-1/2"Wellhead,5,000 psi Ort°444 Tubing,4-1/2",12.6#,IBTM,Special Drift to 3.91' ConocoPhiIiips RAHUGHES KER West Sak 7-5/8"Injector Baker°"`""'` �\ 516'MD-3.875"DB$Nipple,513'TVD,12 deg .` 2789'MD-GLM,Cameo KBMG,4-1/2"X1",2369'TVD,41 deg 1J-102 As Completed 4486'MD-GLM,CamcoKBMG,4-1/2"X1",3458'TVD,67 deg Tri-Lateral Completion 4631'MD-CMU Sliding Sleeve,w/3.81"DB Profile,3511'TVD,71 deg 2653'MD-10$14",68p Lateral EntryModule(LEM) BTC Shoe set,2252'ND `�.. 4691 MD-Casing Sealbore Receptacle 20'Length .;.*11,'N With Diverters and Isolation 4716'MD-Lateral Entry Module(LEMI Lateral Access°wetter Lateral Isolation Diverter Tubing. String / \®` a GS Running Tool String Installed In tall d 4-112"12.6#,L$0,IBTM/ 0-sand Window (3.00"Lateral Drift) (2.601 IDM 6 Drift) 1 3.958"ID,3.833"Drift iD'Sand Lateral -- t 4730 MD,3583'ND � `' G5 P fit f 111 4672'MD-5-112"X7318 4803 MD P y2on d112 116#L-80 Slotted CnilConnector nnevt 1.00/Length) a/R nn 98i m 8\g i !/i 6707'MD-Bottom CP dBl kL !ape. I snap) 6 pot t_. l�, Z%P Liner Top Packer wl .8Seal Assembly 100, A` -..._ /osi L cafng pq Hold Downs 4.]5'SeaI OD �7 1 _ 3-11Y'Gu1de Shoe �eack Pressure Valve fillet I■ `!I'�Ie � DA Length) 'I l l LateralSealsIsolation"� ' l !I f 12081'MD-4-1/2'L ner Shoe,11.6#,L$0 Flow-Then 5x+vd seal: \ � BTC,3501'TVD I,.'i (1 2E Length) Lateral Dverter ® d•36 MD-5-111 Teback Sleeve Hydraulic '�ate Ramp 4727'MD-4-112"X 7318" ® Disconnect 1Am/el TV HOOK Hanger Seal Bores ` 4984'MD-4-112'bent muleshoe Isolation/Ma nborer 3.68'ID \ at 11 Sq'Lengml Dwertar Sleeve \ 4866'MD Bottom of Seal Assembly 4.75"Seal OD ®I SGS Spear r 4837'MD 5-112 X 7-518 ZXP ®I (1.60 Length) l l' Later°Iaa. ---L 5036'MD Lateral EntryModule(LEM) 6.85 n Approx. Seals Liner Top Packer wl Hold Downs \ �\ , \f� GAL' e L B Sand Window 'Jars may be required in highly tleviated 18.6'DioWn Length 16.6 Sleeve Length. 1 Lateral Entry Module(LEM) \ erdeepaPp6ea5ana(6'"Pra'''`" ' 4856'MD Casmg Sealbore �' at 5047 MD,3fiO4'TVD 'B'Sand Lateral Assembly Receptacle 20 Length ®R ( 5118'MD-Pzyzone 4.112 11.6e BTC L-80 Slotted 8}_ 5112'X7-518 ZXP Liner Top w\\ ECP and Blank Liner •—}' Packer with Hold Downs \ '1'+^n...,., 4-112"Guide Shoe Equipment Specifications 11 5046'MD-4-1/2"X7318' A Model'B'HOOK Hanger \ 111998881 4-112"X 7-5/8"HOOK Hanger Casing Sealbore Receptacle ` ' - 12093'MD-4-1/2"Liner Shoe,11.6#,L$0 Mambore Drift:5.3T' 4.75'ID Seal Bares \J Ma nbore Drift with dweller:4.63" 244'MD 5 112 Tieback Sleeve BTC,358V ND 3 68'ID Lateral Drift,no tlwerter or LEM 3.88" r 1 Orienting Profile ;\ 5296'MD 4-1/2"bent muleshoe Lateral Drift,wl dlvetter,no LEM:3.88" I I Automatic Alignment of LEM a ` Lateral/Malnbore Dlverter OD:6.75" 4-1/2"12.6#Tubing,3.833"068 \ 5081'MD 3.562"DBE Nipple,3609 4-112"Lateral Ent Module Positive LatchingCollet3.950"ID \ •\ ND,83 deg Entry Indicates Correct Location Malnbore Drift:3.65" 5-11v.X7-5/8"2XP Mambore Drift,w/Isolation sleeve:2.50" Seal Bore for Lateral Liner Top Packer 5191'MD Bottom of Seal Assembly Isolation J.68"ID with Hold Downs 4.75'Seal OD Lateral Drift,wl cal tlrverter 1.00" \ OD of Dlvertee and Sleeve:cl 3.89" A'Sand Undulating Lateral\ d-112"11.6#BTC Lb0 Diverter and Sleeve Length a-18.s Access Window 5-112"X 73/8' 5149'MD-Liner Hanger l Packer Liner H Slotted and Blank Liner 3.112"Guide Shoe Hanger i7 Thru Tubing Diverter Assembly 5180'MD-Cazmg Sealbore 10040'MD-4-1/2"Casio Shoe,11.6#, Seal Bore for Lateral >•• 9 Isolation-3.68 ID Receptacle,20 Length x !! L$0 BTC,3746'ND Isolation Seal Asembly 5920'MD-73/8"29.7#Casing,L$0, _- = 4.75"Seal OD 3.875"Seal ID uteker HS grtheez 2ooa Thin document may ria Mrs-produced ael:bdrtee,In xnokain pan,inlay term or by BTCM,3741'ND(91 deg) osrni,euoWestSalc aOooE e w •pori 1 'no. 1 any k0450 witIoSing,ren permission W any!Melon storage and til co,r,pHlon-Inlec*ar e 5111, BIW.awk.aahereafter...,wMaawgenpmiaalo ham ekerHagM1eaInc. R low-'' .Male Iew 1a • • Loepp, Victoria T (DOA) From: Peirce,John W <John.W.Peirce@conocophillips.com> Sent: Thursday,October 13, 2016 8:55 AM To: Loepp,Victoria T(DOA) Subject: RE: Request for a Verbal Approval of 10-403 Sundry to Pump 1J-102L1 MARCIT Gel Job Procedure Today Follow Up Flag: Follow up Flag Status: Flagged Victoria, Thanks for your help. We'll start pumping the MARCIT Gel job at 1J-102L1. We should have the job completed today if all goes well. Regards, John Peirce Sr Wells Engr CPAI Drilling&Wells (907)-265-6471 office From: Loepp,Victoria T(DOA) [mailto:victoria.loepp@alaska.gov] Sent:Thursday,October 13, 2016 8:45 AM To: Peirce,John W<John.W.Peirce@conocophillips.com> Subject: [EXTERNAL]RE: Request for a Verbal Approval of 10-403 Sundry to Pump 1J-102L1 MARCIT Gel Job Procedure Today John, Approval is granted to proceed with the Marcit Gel Job treatment of KRU 1J-102L1. Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave Anchorage,AK 99501 Work: (907)793-1247 Victoria.Loeop(a�alaska.qov CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission(AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Victoria Loepp at(907)793-1247 or Victoria.Loeoo@alaska.gov From: Peirce,John W[mailto:John.W.Peirce@conocophillips.com] Sent:Thursday,October 13, 2016 8:30 AM 1 • To: Loepp,Victoria T(DOA)<victoria.loepp@alaska.gov> Subject:Request for a Verbal Approval of 10-403 Sundry to Pump 11-102L1 MARCIT Gel Job Procedure Today Victoria, As we discussed on the phone this morning, I request a verbal approval of 10-403 Application Sundry that we sent to by courier to AOGCC yesterday for 1J-102L1 MARCIT Gel Job. I have attached a copy of the 1J-102L1 Application Sundry for reference. Our planned 11-105 MARCIT job which for which we have 10-403 approval to pump MARCIT cannot be pumped right now. We are having difficulties trying to flow offset 1J-103 producer to the 1J-105 MBE.We need to be able to flow 1J- 103 while pumping MARCIT into 1J-105, but since we can't do this at the moment, we are now requesting that we pump a MARCIT treatment in 1J-102L1 as our best alternate candidate well for the MARCIT treatment. We did not realize we had a problem prevents us from pumping 1J-105 until a couple days ago. Thus,we selected 1J-102L1 as our alternate candidate well but we were then unable to get the 10-403 out for 1J-102L1 MARCIT job until yesterday. We have already pumped 3 Crystal Seal jobs to treat 1J-102L1 MBE, but our 3rd Crystal Seal treatment just failed early this week on 1J-102L1(the treatment lasted"'5 months). Thus,we now wish to try a MARCIT treatment on 1J-102L1. We have crew and equipment on standby at 11-102 today and they are ready to pump the MARCIT job today. Thanks, John Peirce Sr Wells Engr CPAI Drilling&Wells (907)-265-6471 office 2 STATE OF ALASKA A•KA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon E Plug Perforations E Fracture Stimulate Pull Tubing fl Operations Shutdown Performed: Suspend I- Perforate Other Stimulate Alter Casing fl Change Approved Program E Plug for Redrill EPerforate New Pool fl Repair Well ERe-enter Susp Well FT Other:Crystal Seal MBE Trtmnt 17 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development Exploratory I- 206-111 3.Address: 6.API Number: P.O. Box 100360,Anchorage,Alaska 99510 Stratigraphic Service 50-029-23317-60 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25661,ADL 25662 KRU 1J-102L1 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): E$FCI E D NONE Kuparuk River Field/West Sak Oil P 11.Present Well Condition Summary: MAY 18 2016 Total Depth measured 12242 feet Plugs(measured) 5050 AO GCC true vertical 3582 feet Junk(measured) None Effective Depth measured 12091 feet Packer(measured) 4673,4837, 5150 true vertical 3584 feet (true vertical) 3524, 3562,3625 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20 120 120 SURFACE 2600 10 3/4 2643 2255 INTERMEDIATE 5007 7 5/8 5920 3741 B LINER SLOTTE 6849 4 1/2 12093 3585 Perforation depth: Measured depth: 5308-12058,5328-5333 True Vertical Depth: 3604-3585, 3603-3603 SCANNEDJ ,N' 2 8IQJ7 Tubing(size,grade,MD,and ND) 4 1/2, L-80,4707, 3533 Packers&SSSV(type,MD,and ND) PACKER-ZXP Liner Top Packer @ 4673 MD and 3524 ND, PACKER-ZXP Liner Top Paker @ 4837 MD and 3562 ND, PACKER-HRD Liner Top Packer @ 5150 MD and 3625 ND SSSV: NONE 12.Stimulation or cement squeeze summary: Intervals treated(measured): none 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 - - 815 - 3 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations F Exploratory r Development F Service r- Stratigraphic F, Copies of Logs and Surveys Run F_®••••••. 16.Well Status after work: Oil F-' Gas F-••••. WDSPL F- P r i n ted -Printed and Electronic Fracture Stimulation Data FT GSTOR FT•'•••••. WINJ 1.7.. WAG GINJ F® SUSP FT SPLUG F` 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: 315-660 Contact John Peirce(a.265-6471 Email John.W.Peircea,conocophillios.com Printed Name John Peirce Title Sr.Wells Engineer SignaturePhone:265-6471 Date 511 '&/16. 4 _l_til- •- ,-.,,,,_,_,._:— Form 10-40 Revised 5/2015 "a- 1/Z11 L RBDMS Li- MAY 1 9 2016 Submit Original Only KUP 1J-102 ConocoPh Blips Well Attribut Max Angle D TD Alaska.Inc Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(kKB) Act Btm(ftKB) c:o,,,,,,fglil8ps 500292331700 WEST SAK INJ 94.25 6,155.17 11,025.0 ... n Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 1J-102,5/18/20168.08.06 AM SSSV:NIPPLE 100 8/14/2012 Last WO: 44.29 10/4/2006 Vertical schematic tactual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:Crystal Seal Job,SEE NOTES pproven 5/4/2016 HANGER;35.81111 - - -- � Casing Strings R R Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade Top Thread II 1 CONDUCTOR 20 19.124 40.0 120.0 120.0 94.00 H-40 Welded Casing Description OD(in) ID(in) Top(ftKB) 'Set Depth(ftKB) Set Depth(TVD)...Wt/Len(I...Grade 'Top Thread -^-ti CONDUCTOR;40.0-120.0- SURFACE 10 3/4 9.950 42.5 2,642.8 2,255.0 45.50 L-80 BTC NIPPLE;515.9 _ Casing Description OD(in) ID(in) Top(ftKB) 'Set Depth(ftKB) Set Depth(TVD)...WtlLen(I...Grade 'Top Thread INTERMEDIATE 7 5/8 6.875 40.4 5,920.0 3,741.1 29.70 L-80 BTC-mod Casing Description OD(in) ID(in) 'Top(ftKB) Set Depth(ftKB) Set Depth(ND)...VW/Len(I...Grade Top Thread SURFACE;42.5-2,642.8 D LINER LEM 4 1/2 3.688 4,672.7 4,866.2 3,567.8 12.60 L-80 IBT-mod GAS LIFT;Z789.2 Liner Details I Nominal ID Top(ftKB) Top(ND)(ftKB) Tap Inel C) Item Des Com (in) GAS LIFT;4,488.4 4,672.7 3,523.5 73.15 PACKER ZXP Liner Top Packer 4.940 4,691.7 3,528.8 74.19 SBR '109-47 Casing Seal Bore receptacle 4.750 ISO SLEEVE;4,831.0 SLEEVE-C;4,831.4 ;Ail 4,711.3 3,534.0 75.26 XO Bushing XO Bushing 3.930 4,716.6 3,535.3 75.54 HANGER LEM Above Hook Hanger 3.668 LOCATOR;4,879.1 4,727.2 3,537.9 76.12 HANGER LEM Below Hook Hanger 3.688 - _ - SEAL ASSY;4,e89.e, - 4,862.9 3,567.1 77.80 SEAL I Seal Assembly 4.000 Casing Description00(in) ID(in) Top(MB) Set Depth(ftKB) Set Depth(TVD)...WtlLen(1...Grade Top Thread D LINER HH 1 41/21 3.688 4,727.21 4,984.9 3,591.91 11.601L-80 Buttress a ;1 Liner Details ISO SLEEVE;4,730.0 '�'aT' Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) I 4,727.2 3,537.9 76.12 HANGER •FLANGED HOOK HANGER 3.990 4,744.0 3,541.8 77.03 HANGER FLANGED HOOK HANGER 3.990 4,802.5 3,554.2 77.79 ECP PAYZONE EXTERNAL CASING PACKER 3.950 Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... WtlLen(I...Grade Top Thread B LINER LEM 1 4 1/21 3.5631 4,836.91 5,191.61 3,632.61 12.751L-80 I Liner Details '- Nominal ID D LINER LEM;4,872.7-4,886.2 I Top(ftKB) Top(ND)(ftKB) Top net(°) Item Des Com (in) iM 4,836.9 3,561.5 77.72 PACKER ZXP Liner Top Packer 5.500 4,856.0 3,565.6 77.75 SBR 109-47 Casing Seal Bore receptacle 4.750 D LINER HH;4,727.2-4,984.9 ,. 4,875.7 3,569.8 77.91 XO Bushing XO Bushing 4.500 IP (1 5,036.4 3,602.1 78.69 HANGER LEM Above Hook Hanger 3.958 `A,•11 5,047.1 3,604.2 78.66 HANGER LEM Below Hook Hanger 3.958 TYPE I DIVERTER;5,047.0 'll-- 1:Z741 I 5,081.4 3,611.0 78.47 NIPPLE CAMCO"DB"Nipple 3.563 PLUG;5,049.8 5,188.4 3,632.0 79.80 SEAL ASSY BAKER Seal Assembly 3.890 ��jii Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(ND)...Wt/Len(I...Grade Top Thread B LINER HH 41/2 3.688 5,046.1 5,296.0 3,648.4 11.60 L-80 Liner Details Nominal ID ar 1 Top(ftKB) Top(ND)(ftKB) Top Inc)(°I Item Des Com (in) 5,046.1 3,604.0 78.67 HANGER Baker Model B1 Hook Hanger-above 4.500 5,062.9 3,607.3 78.58'HANGER 'Baker Model B1 Hook hanger-below 4.500 V 5,118.4 3,618.4 78.27 ECP Baker Payzone External Csg PKR 4.500 Casing Description OD(in) ID in To ftKB Set Depth(ftKB) Set Depth B LINER LEM;4,836.95,191.6 _ 9 P ( ) P(ftKB) p (ND)...Wt/Len(I...Grade Top Thread g;_._. A LINER Slotted 4 1/2 3.476 5,149.7 10,040.4 3,746.2 11.60 L-80 Buttress Liner Details Nominal ID e LINER HH;5,096.1-5,296.0 Top(ftKB) Top(ND)(ftKB) Top Incl(°) Item Des Com (in) 111. 5,149.7 3,624.8 78.64 PACKER "HRD"Liner top packer 5.500 INTERMEDIATE;40.4-5,920.05,168.6 3,628.4 79.20 NIPPLE "RS"Packoff Seal Nipple 4.870 5,171.0 3,628.8• 79.28 HANGER FlexLock Liner Hanger 5.510 5,180.4 3,630.6' 79.56 SBE 190-47 Casing Seal bore extension 4.750 - - 5,200.1 3,634.0 80.15 XO BUSHING Cross Over Bushing 3.930 - 9,993.7 3,745.8 89.36 ECP Swell Packer Rubber Element 3.476 - Tubing Strings Tubing Description String Ma...ID(in) Top(ftKB) Set Depth(ft..Set Depth(ND)(...Wt(lb/ft) Grade Top Connection TUBING 41/2 3.958 35.8 4,707.5 3,533.0 12.60 L80 IBT-mod ! i- - Completion Details Nominal ID Top(ftKB) Tap(ND)(ftKB) Top Incl Cl Item Des Com (in) - 1 1 35.8 HANGER VETCO GRAY TUBING HANGER, Drifted 3.885" 3.900 _ 515.9 513.6 12.36 NIPPLE CAMCO DB Nipple 3.875"NO GO PROFILE 3.875 4,631.5 3,510.8 71.27 SLEEVE-C BAKER MODEL CMU.Profile 3.812"CAMCO"DB". 3.812 (CLOSED 10/20/2006) - 1 _ 4,679.1 3,525.3 73.50 LOCATOR LOCATOR 3.990 4,680.8 3,525.8 73.60 SEAL ASSY BAKER GBH-22 SEAL ASSEMBLY:Size 192-47. 3.880 SLOTS;5,923.0-9087.0 - 1 !_ Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Top(ND) Top Incl 1 I - Top(ftKB) (kKB) (°) Des Com Run Date ID(in) 1 _ 4,631.0 3,510.7 71.25 ISO SLEEVE SET ISO SLEEVE ACROSS SLEEVE AT 4631' 9/2/2015 2.250 _ @ _ 4,730.0 3,538.6 76.27 ISO SLEEVE TYPE II ISO SLEEVE IND SAND LAT 6/9/2015 2.500 5,047.0 3,604.1 78.66 TYPE I TYPE I DIVERTER IN B SAND LAT 6/9/2015 3.000 DIVERTER - - 5,049.8 3,604.7 78.65 PLUG 3.652"DB PLUG W/PRONG AND FISH NECK 6/8/2015 0.000 PROFILE A LINER Slotted;5,149.7- 10,040.41 KUP 111 1J-102 ConocoPhillips l'kd..ftY ••• 1,1-102 5/18/2016 8 08 07 AM Vertical schematic(actual) HANGER,358 i Perforations&Slots Shot Dens Top(ND) Btm(ND) (shoal Top(ftKB) Btm(ftKB) (ftKB) (ftKB) Zone Date ft) Type Com -M.CONDUCTOR;40.0-120.0- 5,923.0 9,987.0 3,741.5 3,745.7 WS A2,WS 9/10/2006 32.0 SLOTS All Perfs in this well: NIPPLE;515.9 _ A3,1J-102 Alternating solid/slotted I pipe-0.125"x2.5"@ 4 SURFACE;42.5-2,642.8 rorowwss,, en centers cial adjacent 3" GAS LIFT;2769.2 staggered 18 degrees,3' non-slotted ends GAS LIFT;4,486.4AMA I_ Mandrel Inserts ISO SLEEVE;4,631.0 a �I ti SLEEVE-C;4,631.4 on Top(ND) Valve Latch Port Size TRO Run Top(ftKB) (ftKB) Make Model OD(in) Sem Type Type (in) (psi) Run Date Corn 1 2.7892 2,362.7 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 10/3/2006 LOCATOR;4,679.1 RAMS_ 2 4,486.5 3,458.1 CAMCO KBMG 1 GAS LIFT DMY BK-5 0.000 0.0 9/9/2015 SEAL ASSY:4,680.6 +. Notes:General&Safety End Date Annotation I1), 12/27/2007 NOTE:MULTI-LATERAL WELL: 1J-102(A-SAND),1J-102L1(B-SAND),1J-102L2(D-SAND) ISO SLEEVE;4,730.0 : - 10/16/2008 NOTE:VIEW SCHEMATIC w/9.0 7/3/2014 NOTE: EXTERNAL SLEEVE(.500 X 65)WELDED ON SC FROM 425'TO 53.8' 9/18/2015 NOTE:FuIlBore MBE treatment per design placing"290 bbls 3%KCL/4 mil Crystal Seal slurry 9/18/2015 NOTE: into formation(3795#of CS) 11/14/2015 NOTE: concentration of 0.28 ppg 11/14/2015 NOTE:FuIlBore MBE treatment per design Placed 2310#of 1-2-4 mesh Crystal Seal slurry 4/26/2016 NOTE:FuIlBore Crystal Seal B MBE treatment.Placed 2970#of 1-2-4 mesh 0J17 4/26/2016 NOTE:Crystal Seal slurry @ average 0.27 ppg concentration D LINER LEM;4,672.7-4,888.2 D LINER HH',4727.2-4,984.9 TYPE I DIVERTER,5047.0 017 11 PLUG:5,049.8 1'. i' 6 LINER LEM;4,836.9-5,191.6 ;�e� B LINER HH;5,048.1-55,298.0 'mak INTERMEDIATE;40.4-5,920.0 SLOTS,5,923.0-9,987.0 A LINER Slotted;5149.7- 10,040.41 KUP 1J-102L1 Conac�illips Well Attribu Max Ang I D TD Alaska.Inc, » Wellbore API/UWI Field Name Wellbore Status ncl(°) MD(ftKB) Act Btm(ftKB) Care,,,oph47 PS 500292331760 WEST SAK INJ 94.63 10,743.74 12,242.0 • ..° Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1J-102L1,5/18/20168.0&31 AM SSSV:NIPPLE 100 8/14/2012 Last WO: 44.29 10/4/2006 ..._verocal stamaac,(a9tuan. Annotation Depth(ftKB) End Date Annotation last Mod By End Date f Last Tag: Rev Reason:QC smsmith 10/26/2015 �`-' HANGER;35.8 Ie1 I .l Casing Stnngs 0 1111 ,1111111 ' Casing Description OD(in) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth)TVD)...Wt/Len(1...Grade Top Thread B LINER Slotted 4 1/2 3.476 5,244.9 12,093.4 3,585.2 11.60 L-80 Buttress -es°".CONDUCTOR;40.0-120.0- Thread NIPPLE;515.9 Liner Detail$... Nominal ID SURFACE;42.5-2,642.8- Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) a 5,244.9 3,607.4 93.51 SLEEVE Baker HR Liner setting sleeve 5.750 GAS LIFT,2,769.2 4M:- II5,303.1 3,604.1 92.97 XO BUSHING Hydril 521 XO Joint 3.960 GAS LIFT,4,486.4 Perforations&Slots am ISO SLEEVE,4,631.0 � Shot SLEEVE-C,4,631.4, !''l Dens 11. Top(ftKB) Btm(ftKB) Top(ND) Btm(TVD) (shots/ (ftKB) (ftKB) Zone Date ft) Type Com LOCATOR;4,679.1 mow 5,308.0' 12,058.0 3,603.9 3,584.7 WS B,WS C, 9/22/2006 32.0 SLOTS All Perfs in this well: SEAL ASSY;4,680.8 1J-102L1 Alternating solid/slotted I'i'' pipe-0.125'x2.5"@ 4 circumferential adjacent 1: rows,3"centers I50 SLEEVE;4,730.0 - staggered 18 degrees,3' non-slotted ends 5,328.0 5,333.0 3,603.0° 3,602.7 WS A2,WS 9/2/2015 6.0 IPERF 2in Powerflow HSD, A3,1J-102 2006FP,6SPF Notes:General&Safety End Date Annotation a 10/6/2006 NOTE:MULTI-LATERAL WELL:1J-102(A-SAND),1J-102L1(B-SAND),1J-102L2(D-SAND) D LINER LEM,4,672.73,866.2 . , 10/16/2008 NOTE:VIEW SCHEMATIC w/9.0 7/3/2014 NOTE: EXTERNAL SLEEVE(.500 X 65)WELDED ON SC FROM 42.5'TO 53.8' D LINER HH;4,727.2-4,964.9 INTERMEDIATE;40.4-5,920.0 B LINER LEM;4,836.9-5,191.6 6 LINER HH;5,046.1-5,296.0 IPERF;5,328.0-5,333.0 SLOTS;5,308.0-12,058.0 8 LINER Slotted;5,244.8- 12,093.4 • • • 1J-102L1 DTTMS.JOBTYP SUMMARYOPS 4/26/16 MISC. Performed fuilbore Crystal Seal MBE treatment @—1-3 bpm into MBE. CAPACITY Placed 2970#of 1-2-4 mesh Crystal Seal slurry @ average 0.27 ppg SUSTAINMENT concentration, Slurry was left underdisplaced w/41 bbls SW&35 bbls diesel. Note: will attach treatment report once available. 5/15/16 MISC. Clean out ice and slush from 400' down to 1,856'. Continue RIH performing CAPACITY a Fluff n' Stuff untilizing SSW w/Safelube down coil and backside. Clean SUSTAINMENT down to near lockup at 10,124' CTMD. No indications of CrystalSeal bridges or fill seen. Well freeze protected. ***Job complete*** , oFTit • • • ow.-\\1%%i sA THE STATE Alaska Oil and Gas ������i�l� ofA lAsKA Conservation Commission fit - = 333 West Seventh Avenue / GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 .,n ti. pF Q, Main: 907.279.1433 ALAS- Fax: 907.276.7542 www.aogcc.alaska.gov John Peirce Sr. Wells Engineer ivov ConocoPhillips Alaska, Inc. b 2015 Q 6 — ( I I P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1J-102L1 Sundry Number: 315-660 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, Cathy P. oerster Chair DATED this of October, 2015 Encl. RBDMS NOV 0 2 2015 STATE OF ALASKAIIII • 4111,SKA OIL AND GAS CONSERVATION COMMISSION , APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown r Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Crystal Seal MBE Treatment(rI,. 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development r 206-111 3.Address: Stratigraphic r Service 6.API Number: P.O.Box 100360,Anchorage,Alaska 99510 50-029-23317-60 7.If perforating, What 8.Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No I KRU 1J-102L1 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 25661,25662 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): 12242- 3582 _ 12091'. 3584' • none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20 120' 120' SURFACE 2600 10.75 2643' 2252' k INTERMEDIATE 5007 7.625 5920' 3741' B LINER SLOTTED 6849 4.5 12093' 3584' 0C- 2 1 2015 AOCICC Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): slotted liner from 5308'-12058' . 3604'-3585' 4.5 L80 4708 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-ZXP LINER TOP PACKER MD=4673 TVD=3524 . PACKER-ZXP LINER TOP PACKER MD=4837 TVD=3562 , PACKER-"HRD"LINER TOP PACKER MD=5150 TVD=3625 NIPPLE-CAMCO DB NIPPLE MD=516 TVD=514 • 12.Attachments: Description Summary of Proposal F 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service 1• 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 11/15/2015 OIL r WINJ p.4 WDSPL r Suspended r 16.Verbal Approval: Date: GAS r WAG r GSTOR r SPLUG r Commission Representative: GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: John Peirce @ 265-6471 Email: John.W.Peirce@conocophillips.com Printed Name John Peirce Title: Sr.Wells Engineer Signature ,64.': y1+ Phone:265-6471 Date LQ(aoac Commission Use Only J Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3/6 - (Q Co U Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Spacing Exception Required? Yes ❑ No [I Subsequent Form Required: d c _4 U /r APPROVED BY / �Q /�� Approved by4/1S -74t7ed COMMISSIONER THE COMMISSION Date: ! —215) 1 V� ccam� a plication is valid for 12 months fro the date of approval. cJ S it F rm�a}nd�f Form 10-403 Revised 5/2015 R I I N A L <b /Q/4 3/15— , ip*(1 " BDM i �+t` 2015 1 � • • 1J-102L1 to 1J-159L1 B Sand MBE Treatment Proposal 1J-102 Tri-Lat injector was drilled & completed in 2006 with laterals in West Sak A, B, & D sands. On 3/2/08, a 1J-102 MBE occurred to offset producer 1J-159. A 4/23/08 1J-102 main-bore (PROF saw all PWI entering 1J-102L1. A 2008 1J-102L1 (PROF RIH stuck the BHA in the B Diverter. After lengthy fishing to retrieve all of the fish, a B Iso-Sly was set 9/28/08 before diagnosing the B MBE location. 1 J-102 was on PWI to A & D sands only until 2015. On 6/8/15, a Plug was set at 5081' RKB to isolate the A lat, then a B Diverter and a D Iso-Sly were set 6/9/15. A 6/10/15 IPROF in 1J-102L1 to 11109' MD found a heel MBE at -5350' RKB at the first slotted joint below the B LEM. On 9/18/15, a fullbore Crystal Seal job was pumped -3 bpm (per 10-403 Sundry Approval #315-449) to fill the B MBE. A total of 3,795 lbs of 4 mm Crystal Seal was displaced to the MBE resulting in final net treating pressure gain of 640 psi. This job took the largest Crystal Seal volume ever pumped to treat any West Sak MBE. On 9/23/15, 1J-102L1 was returned to PWI, but on 10/4/15 offset producer 1J-159 pressure & temperature rapidly increased indicating that the MBE treatment fromlJ-102L1 to 1J-159 had failed. The MBE volume is probably quite large and will need more Crystal Seal to seal it. A fullbore Crystal Seal Retreatment is proposed to seal the B MBE to return 1E-102L1 to PWI. V Procedure: Pumping: 1) Fullbore pump a -10 bbl Inj test with Seawater to -3 bpm to verify good injectivity. Continue pumping Crystal Seal Slurry down tubing made with 4 mm mesh Crystal Seal at 0.25 ppg in Seawater to seal the B MBE. Hold constant -3 bpm Crystal Seal treatment rate to monitor MBE treatment response and possible Crystal Seal screenout during slurry pumping. If screenout develops, attempt to pump 80 bbls of Diesel Flush down tubing to displace Crystal Seal to B MBE. Tubular volume is 81 bbls from surface to MBE. If screenout is not seen, but 1000 psi max WHP target has been reached, swap to 35 bbls Diesel to FP to 2000' TVD followed by SD. RD. Coil Tubing: 2) RIH with 2" OD Jet Swirl Nozzle BHA to get through 2.25" ID CMU Iso-Sly (already set) to jet through Crystal Seal to as deep as possible to shear / mechanically break all Crystal Seal remaining in the liner. POOH w/CT. RD. Put 1J-102L1 on PWI to evaluate results of the B MBE treatment for a period long enough to verify a successful B MBE treatment exists before executing remaining work. 3) RIH with IPROF BHA on CT to pass through 2.25" ID CMU Iso-Sly. Memory log down and up passes to verify the B MBE is sealed or still taking PWI. Wait 2 hours and then log a cool back pass. POOH with CT. RD CTU. Return 1J-102L1 to PWI service. If no indication of a B MBE, normal up PWI to all 3 laterals as follows: 4) RIH & pull the 2.25" ID Iso-Sly (from leaky CMU Sleeve) at 4631' RKB. 5) RIH & pull the 'D' Iso-Sly set across the D LEM at 4730' RKB to open the D lat to PWI. 6) RIH & pull the 'B' Diverter set in the B LEM at 5047' RKB. 7) RIH & pull Prong and 3.562" Plug set at 5081' to open the A lat to PWI. 8) RIH & set 2.25" ID Iso-Sly in CMU Slv at 4631' RKB to isolate leaky CMU Slv. Perform MIT-IA to verify good set integrity of Iso-Sly prior before returning 1J-102 to PWI service to all 3 laterals. t KUP INJ • 1J-102L1 ConocoPhillips Welt Attributes Max Angle&MD TD Alaska.Inc . Wellbore API/UWI Field Name Wellbore Status ncl("1 MD IRKS) Act Elm(ftKB) tlrtf+0exipt9Yc 500292331760 WESTSAK INJ 94.63 10,743.74 - 12,242.0 -•• Comment H25(ppm) Date Annotation End Date KB-Grd(It) Rig Release Date 13-102L1,9715120152;594e PM SSSV:NIPPLE 100 811412012 Last WO: 44.29 104/2006 Vertical schematic(actual) Annotation Depth(ftKB) End Date Annotation Last Nod By End Date Last Tag: Rev Reason:GLV C/O lehall( 9l13t2015 ..............................HANGER;359.,._ ..,. Will • y■ sung Strings 7 T �... Casing Description OD(in) ID(In) Top(ftKB) Set Depth(ftKB) Set Depth(TVO)...WtfLen(I...Grade Top Thread ��� B LINER Slotted 4 1/2 3.476 5,244.9 12.093.4 3,585.2 11.60 L-80 Buttress -ti'�CONDU TOR:40.0-120.0- Thread NIPPLE;515.9 .GLiner Details • Nominal ID SURFACE;425-2,642P- Top(ftKB) Top(TVD)(NKB) Top!nal)") kern Des Com ON 5,244.9 3.607.4 93.51 SLEEVE Baker HR Liner setting sleeve 5.750 GAS LIFT,2,789.2 �. 5,tion 3.604.1 92.97 XO BUSHING Hydril 521 X0 Joint 3.960 GAS LIFT;4,486.4 perforations&Slots ISO SLEEVE;4,631 0 Shot SLEEVE-C.4.631.11 Top(TVD) Bim(TVD) Dens (shots/1 Top(ItKH) Bite(1tK3) (ttK6) (nKB) Zone Date t)) Type Com .5.308.0 12.058.0 3,5039 3,584.7 WS B,WS C. 9/22/2006 32.0 SLOTS All Peds in this well: LOCATOR.4,879.1 1J-102L1 Alternating solid/slotted SEAL ASSY:4,680.8 '�� pipe-0.125 z25"�4 circumferenclal adjacent rows,3"centers L <1: staggered 18 degrees,3' ISO SLEEVE;4 730.D '...I�1 .I`ll non-slotted ends Notes:General&Safety End Date Annotation 10±6:2006 NOTE:MULTI-LATERAL WELL:iJ-102(A-SAND).1J-102L1(B-SAND),1J-102L2(U-SAND) 10(16.2008 NOTE:VIEW SCHEMATIC w/9-0 7,3!2014 NOTE:EXTERNAL SLEEVE(.500 X65)WELDED ON SC FROM 42.5'TO 53.8' D LINER LEM.4.872.7-4,886.2 ..;�. D LINER HH.4,727.2-4,984.9 INTERMEDIATE;40.4-5.920.0 B LINER NN'5.046.1-5.296 0 B LINER LEM.4.838.95.151.8 _lillilliii_ _ I_ SLOTS;5,308.0-12.058.0 B LINER Slaked,5,264.8- 12.093AZ STATE OF ALASKA AAA OIL AND GAS CONSERVATION COMIDSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown r Performed: Sus end Perforate p p` Other Stimulate Alter Casing Change Approved Program " Rug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other:Crystal Seal MBE Treatm4y 2.Operator Name: 4.Well Class Before Work: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 206-111 3.Address: 6.API Number: Stratigraphic r Service P. O. Box 100360,Anchorage,Alaska 99510 50-029-23317-60 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 25661,25662 KRU 1J-102L1 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 12242 feet Plugs(measured) 5050 true vertical 3582 feet Junk(measured) none Effective Depth measured 12091 feet Packer(measured) 4673,4837, 5150 true vertical 3584 feet (true vertical) 3524, 3562, 3625 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20 120 120 SURFACE 2600 10.75 2643 2252 INTERMEDIATE 5007 7.625 5047 3741 B LINER SLOTTEI 6849 4.5 12093 3584 Perforation depth: Measured depth: slotted iner from 5308'-12058', perfs 5328'-5333' True Vertical Depth: 3604'-3585', 3602-3602' )r. i 2 1 2013 AOGC Tubing(size,grade,MD,and TVD) 4.5, L80,4708 MD, 3533 TVD C Packers&SSSV(type,MD,and TVD) PACKER-ZXP LINER TOP PACKER @ 4673 MD/3524 TVD PACKER-ZXP LINER TOP PACKER @ 4837 MD/3562 TVD PACKER-'HRD' LINER TOP PACKER @ 5150 MD/3625 TVD NIPPLE-CAMCO'DB' NIPPLE @ 516 MD/514'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): not applicable 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 1000 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 r Exploratory r Development r Service 17 Stratigraphic r Copies of Logs and Surveys Run r 16.Well Status after work: Oil r Gas r WDSPL r Printed and Electronic Fracture Stimulation Data r GSTOR r WINJ 17 WAG r GINJ r SUSP r 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: 315-449 Contact John Peirce(,265-6471 Email John.W.Peirce(a�conocophillips.com Printed Name John Peirce Title Sr. Wells Engineer Signature fooetiv .... Phone:265-6471 Date �� /wQ/� ..ice (L `V' L is/2Z �— RBDM&�OCT 2 2 2015 Form 10-404 Revised 5/2015 (0,-0745 Submit Original Only • y KUP INJ • 1J-1021_1 f ConocoPhillips ® Well Attributes Max Angle 8 MD TD Alaska,Inc. /Wellbore API/OWl Field Name Wellbore Status rax (•) MD(11651) Act Bim(HKB) CMCWTRieps J 500292331760 WEST SAK INJ 94.63 10743.74 12242.0 ••• Comment 925(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date 13-10211,9/15201555948PM SSSV:NIPPLE 100 8/14/2012 Last WO: 44.29 10/4/2006 Vernal schematic(actual) Annotation Depth(ttKB) End Data Annotation Last Mad By End Date ........................... .. Last Tag Rev Reason:GLV C/O lehallf 9/13/2015 •HANGER;35.8.. 11 #) Casing Strings ' ' ' ' ' ' ' " ' ' 1 ' I C'" ,Casing Description OD(In) ID(In) Top(1165) Set Depth(tt6B) Set Depth(TVD)...Wt/Len(I...Grade Top Thread '1111�I 1'�'' B LINER Slotted 4 1/2 3.476 6,244.9 12.093.4 3,585.2 11.60 L-83 Butted M7 CONDUCTOR;40.0-120.0- NIPPLE:515.9 Liner Details Nominal ID SURFACE;42.5-2,642.6— Top(HKB) Top(TVD)(HKB) Top Incl p) Hem Des Com (In) 5,244.9 3,607.4 93.51 SLEEVE Baker HR Liner setting sleeve 5.750 GAS LIFT,2,789.2 1: 5,303.1 3,604.1 92.97 X0 BUSHING Hydril 521 XO Joint 3.960 GAS LIFT;4,4654 Perforations&Slots Shot ISO SLEEVE;4,631 0-, Dens SLEEVE-C.4,631.4 • L I Top(ND) Bt.(TVD) (shots/f Top(HKB) Btin(HKB) (ttKB) (f1KB) Zone Date I) Type Com 5,308.0 12,058.0 3,603.9 3,584.7 WS B,WS C. 9/222006 ' 32.0 SLOTS Al)Perfs in this well: LOCATOR;4,679.I 1J-1021_1 Alternating solid/slotted SEAL ASSY:4,680 8 Pipe-0.125"x2.5"g4 �` circumferential adjacent rows,3"centers itn. ��.. staggered 18 degrees,3' ISO SLEEVE:4,7300 ill j.1 non-slotted ends • Notes:General&Safety End Date Annotation 10/6/2006 NOTE:MULTI-LATERAL WELL:1J-102(A-SAND),1J-102L1(B-SAND),tJ-1021_2(D-SAND) 10/16/2008 NOTE:VIEW SCHEMATIC w/9.0 Y 732014 -NOTE:EXTERNAL SLEEVE(.500X 65)WELDED ON SC FROM 42.5'TO 53.8' 0 LINER LEM,4.672.7-4,886.2 - D LINEN HH,4,727.2-4.984.5, INTERMEDIATE:40.4-5,920.0 B LINER I/O 5046.1-5,2960 t. B LINER LEM.4,838.9-5,151.8 --114-- 71 I IT- I-_ SLOTS:5,308.0-12,058.0 I _' — I—_ B-,AER Slotted',5244 8. 1205341 1J-102L1 WELL EVENTS SUMMARY DATE SUMMARY 9/2/2015 FCO ice plug from 40'to 75'. Peforate MBE interval in B Lateral from 5,328'to 5,333' RKB with SLB 2 inch Powerflow HSD guns (2006FP-6SPF, EHD 0.45", 4.5" PEN). Verified ASF. Next, set a 2.25" ID ISO-Sleeve at leaky CMU @ 4,631' RKB. Well left freeze protected and shut in. Well is now ready for Crystal Seal job Pinholed coil tubing @ 2,315'while POOH no spills. Will cut coil tubing in morning. 9/8/2015 BRUSH n' FLUSH TBG TAG ISO SLEEVE @ 4631' RKB, IN PROGRESS. 9/9/2015 SET 4 1/2 HOLE FINDER/CATCHER SUB ASSEMBLY @ 4631' RKB, PULLED DV @ 4486' RKB, LOADED TBG & IA WITH INHIBITED SEAWATER & DIESEL FREEZE PROTECT, SET DV @ 4486' RKB MIT IA PASS, PULLED HOLE FINDER ASSEMBLY @ 4631' RKB. COMPLETE. 9/17/2015 INJECTIVITY TEST W/SMI PUMPED10 BBLS@1BPM PUMPED 10 BBLS @ 2BPM PUMPED 80 BBLS @ 3BPM FREEZE PROTECT TBG W/35 BBLS DIESEL JOB COMPLETE 9/18/2015 Pumped fullbore MBE treatment per design placing —290 bbls 3% KCL/4 mil Crystal Seal slurry into formation (3795#of CS). Displaced gel with 80 bbls diesel. Well left shut in. Note: Do not put on injection or bring offset producer online until after 06:00, 9/19. 9/21/2015 Injectivity test, 40 bbls dsl down tbg @ 1 bbl/min pressured up to 200 psi,job complete 10/5/2015 FREEZE PROTECT WELL W/2 BBL METHANOL 100% DOWN F/L FOLLOWED BY 38 BBL DIESEL DOWN TBG JOB COMPLETE 10/8/2015 LOG 24 ARM CALIPER SURVEY FROM 4650' TO SURFACE. LOG CORRELATED TO TUBING DETAIL RECORD DATED 03 OCT 2006. DATA SENT TO ANCHORAGE FOR FURTHER PROCESSING. JOB COMPLETE. ['TD 2-e7 4.—// Loepp, Victoria T (DOA) From: Peirce,John W <John.W.Peirce@conocophillips.com> Sent: Monday,October 12,2015 11:25 AM To: Loepp,Victoria T(DOA) Cc: Allsup-Drake, Sharon K Subject: Re: 1J-102L1 Crystal Seal Retreat 10-403 Sundry Follow Up Flag: Follow up Flag Status: Flagged Victoria, On 9/18/15 we treated 1J-102L1 with 3,795 lbs of Crystal Seal in an to attempt to seal off a targeted West Sak B Sand MBE(per 10-403 Sundry Approval#315-448). Unfortunately post-job surveillance indications are that this treatment has so far failed to seal off the B MBE. Thus,we would like to pump another batch of Crystal Seal slurry by the end of this year to try to seal off the MBE. We believe this is a large feature such that we may just need to pack it with more Crystal Seal in order to gain a successful treatment. Question: Would it be OK with AOGCC to plan and execute a fullbore pumped Crystal Seal retreatment under Sundry Approval #315-448,or should I submit another 10-403 to get a retreatment approval by AOGGC before pumping the retreatment? We pumped 5 Crystal Seal treatments during 9/18—9/23/15(at: 1J-102L1, 1E-102, 1C-190, 1E-119,and 1E-105L1). The 1J-102L1 job is the only treatment that looks like it needs a retreat(so far). We are hopeful that our other treatments will continue to appear successful. However, it is not uncommon that some of these wells may require a retreat should our initial efforts to seal the MBE's be unsuccessful. We will be submitting 10-404's on the treatments listed soon as possible. Regards, John Peirce Sr Wells Engr SCANNED CPAI Drilling&Wells (907)-265-6471 office 1 • r\":01F Ty s THE STATE Alaska Oil and Gas ofALAS Conservation Commission Witt=-_- - 333 West Seventh Avenue vettit GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 *h,, Main: 907.279 1433 ALAS*... Fax: 907.276 7542 ti � 1f-���� www.aogcc alaska.gov SCM4BEV John Peirce a D ' I I I Sr. Wells Engineer ConocoPhillips Alaska, In P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, KRU 1J-102L1 Sundry Number: 315-449 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, Cathy P Foerster Chair DATED this 2- day of July, 2015 Encl. STATE OF ALASKA ,SKA OIL AND GAS CONSERVATION COMMISSION • APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1 Type of Request. Abandon r Rug Perforations r Fracture Stimulate r Pull Tubing r Operations Shutdown r Suspend r Perforate r Other Stimulate r Alter Casing r Change Approved Program r Plug for Redrill r Perforate New Pool r Repair Well r Re-enter Susp Well r Other Crystal Seal MBE Treatment ,,F.'. 2.Operator Name 4 Current Well Class 5 Permit to Drill Number ConocoPhillips Alaska, Inc. ' Exploratory r Development r 206-111 ' 3 Address6 API Number Stratigraphic r Service . P O. Box 100360,Anchorage,Alaska 99510 50-029-23317-60 • 7 If perforating, What 8 Well Name and Number Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No p. / KRU 1J-102L1 . 9 Property Designation(Lease Number) 10 Field/Pool(s) ADL 25661,25662 . 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) 12242 _ 3582 . 12091' - 3584' • none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20 120' 120' SURFACE 2600 10.75 2643' 2252' ! e INTERMEDIATE 5007 7.625 5920' 3741' RECEIVED B LINER SLOTTED 6849 4.5 12093' 3584' n r JUL * a 2015 DI -1I 44!s AOGCC Perforation Depth MD(ft) Perforation Depth TVD(ft) Tubing Size Tubing Grade Tubing MD(ft) slotted liner from 5308'-12058' i 3604'-3585' 4.5 L80 4708 Packers and SSSV Type Packers and SSSV MD(ft)and TVD(ft) PACKER-ZXP LINER TOP PACKER MD=4673 TVD=3524 PACKER-ZXP LINER TOP PACKER MD=4837 TVD=3562 PACKER-"HRD"LINER TOP PACKER MD=5150 TVD=3625 NIPPLE-CAMCO DB NIPPLE MD=516 TVD=514 12 Attachments: Description Summary of Proposal r 13 Well Class after proposed work Detailed Operations Program r BOP Sketch r Exploratory E Stratigraphic r Development E Service P• 14.Estimated Date for Commencing Operations 15 Well Status after proposed work: 8/1/2015 OIL r WINJ r - WDSPL r Suspended r 16 Verbal Approval Date GAS r• WAG r GSTOR r SPLUG r Commission Representative GINJ r Op Shutdown r Abandoned r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Contact John Peirce @ 265-6471 Email John W Peirce@conocoohillips corn Printed Name John Peirce Title Sr. Wells Engineer Signature Phone:265-6471 Date 17/2 2, S-- Commission Commission Use Only Sundry Number. Conditions of approval Notify Commission so that a representative may witness 316-'1-111 l Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other Spacing Exception Required? Yes ❑ No [/ Subsequent Form Required: /Q —Lj U 4 4,/ Q APPROVED BY Approved by / COMMISSIONER THE COMMISSION Date 7-2-4 "/5 VrL 7_/ //5----A VQa a I v lL 12 months from the date of approval. Submit Form and Form 10-403 Revised 5/2015 77Fi ? 3S Attach nts iDuplicate -74-74 ,--- RBDMS� AUG - 2 2015 Et KUP INJ 1J-102L1 f ConocoPhillips i Well Attributes Max Angle&MD TD Alaska,Inc. Wellbore API/UWI Field Name Wellbore Status ncl El MD(ftKB) Act Btm(SKS) r=aomnalg, 500292331760 WEST SAK INJ 94.63 10,743.74 12,242.0 ... M1 Comment H25(ppm) Date Annotation End Date KB-Grd(ft) -Rig Release Date 1J-102Lt.6/1020152:47:31 PM SSSV:NIPPLE Last WO: 44.29 10/4/2006 Vertical achemattd(actual) Annotation Depth(ftKB) End Date Annotation Last Mod By End Date Last Tag: Rev Reason:PULL ISO SLEEVES,SET PLUG& hipshkf 6/10/2015 ..............".HANGER;35.8. ... 1414I DIVERTERS Casing Strings -A.hI CONDUCTOR;400.120 _ 1 'y ., B LINER Slotted aWu Casing Description OD(In) ID(in) Top(ftKB) Set Depth(ftKB) Set Depth(TVD)... Wt/Len(I...Grade Top Thread 4 1/2 3.476 5,244.9 12,093.4 3,585.2 11.60 L-80 Buttress 0•• Thread NIPPLE.515.9 W Liner Details I Nominal ID Top(ftKB) Top(TVD)(ftKB) Top Incl(°) Item Des Com (in) SURFACE;425-2.6428— 5,244.9 3,607.4 93.51 SLEEVE Baker HR Liner setting sleeve 5.750 GAS LIFT;2,789.2 5,303.1 3.604.1 92.97 XO BUSHING Hydril 521 XO Joint 3.960 GAS LIFT;4.486.4 Perforations&Slots Shot SLEEVE-C;4.631.4 4 1 Dens Top(TVD) Btm(TVD) (shots/f Top(ftKB) Blot(ftKB) (51(12) (ftKB) Zone Date t) Type Com LOCATOR;4,679.1 5,308.0 12,058.0 3,603.9 3,584.7 WS B,WS C, 9/22/2006 32.0 SLOTS All Perfs in this well: SEAL ASSY;4,680.8 - '4 1J-102L1 Alternating solid/slotted pipe-0.125"x2.5"@ 4 circumferencial adjacent I. t rows,3"centers c I�' staggered 18 degrees,3' TYPE II DIVERTER,4,730.0 =-11 non-slotted ends i-- l 1 ii Notes:General&Safety End Date Annotation 10/6/2006 NOTE:MULTI-LATERAL WELL:1J-102(A-SAND),1J-102L1(B-SAND),1J-102L2(D-SAND) 10/16/2008 NOTE:VIEW SCHEMATIC w/9-0 s 7/3/2014 NOTE:EXTERNAL SLEEVE(.500 X 65)WELDED ON SC FROM 42.5'TO 53.8' "IWif LINER LEM;4,672.7-4.866.2 if ,`-'. D LINER HH;4,727.2-4,984.9, 'aM':. B LINER LEM,4,836.9,5191.6 8 LINER HH;6046 1-5,296.0 I /) INTERMEDIATE;40.4,5920.0 11 —I I- -I 1- -I 1— —i - -i —i i- -! 1.- I 1 -i - I— _I — SLOTS;5,308.0-12,058.0 —i I— B LINER Stilted;5244.8- 12,093.4 • 1J-102L1 to 1J-159L1 B Sand MBE Treatment Proposal 1J-102 Tri-Lat injector was drilled & completed in 2006 with laterals in West Sak A, B, & D sands. On 3/2/08, a 1J-102 MBE occurred to offset producer 1J-159. A 4/23/08 1J-102 main-bore IPROF saw all PWI entering 1J-102L1. A 2008 1J-102L1 IPROF RIH stuck the BHA in the B Diverter. After lengthy fishing to retrieve all of the fish, a B Iso-Sly was set 9/28/08 (before diagnosing the B MBE location). 1J-102 was on PWI to A & D sands only until 2015. On 6/8/15, a Plug was set at 5081' RKB to isolate the A lat, then a B Diverter and a D Iso-Sly were set 6/9/15. An 6/10/15 IPROF in in 1J-102L1 to 11109' MD found a robust `heel' MBE at -5350' RKB at the first slotted joint below the B LEM. Note, the top of B lat plop & drop liner is -197' out in OH lateral below the B LEM (per 9/22/06 Liner Detail). A fuilbore Crystal Seal treatment to seal the B MBE is proposed to return 1V-102L1 to PWI. Procedure: E-line: 1) RIH with 5' perf gun on dual tractors to shoot 6 spf, 60 deg ph large hole perfs at 5328 - 5333' RKB. This perfs the middle of the first 4.5" slotted joint near the MBE at -5350' to allow better CrystalSeal entry through slotted liner to the B MBE. Fire gun. POOH. RD. Coil Tubing: 2) RIH & set 2.25" ID Iso-Sly in CMU Slv at 4631' RKB to isolate leaky CMU Sly for Crystal Seal job. Perform MITIA to verify good Iso-Sly set integrity. Pumping: 3) Fullbore pump -100 bbl Step Rate Inj Test (SRIT) with Seawater to 4 bpm to verify good injectivity. Select a steady treatment rate to hold constant during Crystal Seal treatment to monitor MBE treatment response, and possible Crystal Seal screenout during slurry pumping. After SRIT, continue FB pumping Crystal Seal Slurry stages at constant rate (target 3 - 4 bpm) to the B MBE. Pump all slurry concentrations using only 4 mm mesh Crystal Seal in 3% KCL Water, starting with 0.10 ppg slurry pumped down tubing. Volume of each stage is TBD during pumping based on treating pressure responses noted during pumping. Ramp stages at: 0.10, 0.15, 0.20, to a maximum of 0.25 ppg, or (if needed) swap to pumping Flush if indication of imminent screen out develops during slurry pumping. If screenout development is noted, attempt to pump 80 bbls of Diesel Flush down tubing to displace all Crystal Seal from well to the B MBE. Tubular volume = 81 bbls (surface to MBE). If screenout has not been seen, but it is time to call Flush, pump at least 35 bbis Diesel to FP to 2000' TVD, then SD. RD. Coil Tubing: 4) RIH with 2" OD Jet Swirl Nozzle BHA (to get through 2.25" ID CMU Iso-Sly set in step 2) on either 1.5", 1.75", or 2" OD CT (best CT OD option TBD) to jet through Crystal Seal down to as deep as possible to shear and mechanically break all Crystal Seal remaining in the liner. POOH w/CT. RD. Put 1J-102L1 on PWI to evaluate results of the B MBE treatment for a period long enough to verify that a successful B MBE treatment has been achieved prior to executing step 6 and beyond. 5) RIH with Slim (PROF BHA on CT to pass through 2.25" ID CMU Iso-Sly (set in step 2). Memory log down and up passes to verify if the B MBE is sealed off or still taking PWI. Wait 2 hours and then log II' a cool back pass. POOH with CT. RD CTU. Return 1J-102L1 to PWI service. If months have passed without obvious indications of a B MBE treatment failure, proceed to normal up the well to resume PWI to all 3 laterals as follows: Coil Tubing: 6) RIH & pull the 2.25" ID Iso-Sly (from leaky CMU Sleeve) at 4631' RKB. 7) RIH & pull the 'D' Iso-Sly set across the D LEM at 4730' RKB to open the D lat to PWI. 8) RIH & pull the `8' Diverter set in the B LEM at 5047' RKB. 9) RIH & pull Prong and 3.562" Plug set at 5081' to open the A lat to PWI. 10) RIH & set 2.25" ID Iso-Sly in CMU Slv at 4631' RKB to isolate leaky CMU Slv. Perform an MITIA to verify good set integrity of Iso-Sly prior to returning 1J-102 to PWI service. Return 1J-102 to PWI service to all 3 laterals. WELL LOG TRANSMITTAL 210.0 2-Ce II. DATA LOGGED PROACTIVE DIAGNOSTIC SERVICES, INC. 7/L6/207 K. BENDER To: AOGCC r EA Makana Bender 333 West 7th Avenue J U L 0 7 LUL; Suite 100 Anchorage, Alaska 99501 r"' (907) 793-1225 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: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245-8952 sCANNELT, 1) Injection Profile 10-Jun-15 1J-102 L1 Color Log/CD 50-029-23317-60 2) Signed : 6,„46,4_ 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: PDSANCHORAGEAMEMORYLOG.COM WEBSITE:WWW.MEMORYLOG.COM D\Achives\MasterTemplateFiles\Templates\Distnbuhon\TransmittalSheets\ConocoPhillips_Transm,t docx Image Project Well History File Gover 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. p~Q ~ - ~ ~ ~_ Well History File Identifier Organizing (done) RES AN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: BY: Maria _ Project Proofing BY: Maria _ Scanning Pre~pa-ration BY: M/ aria l „~o.ced iuumuuuuiu DIGITAL DATA Diskettes, No. ^ Other, No/Type: Date: Date: Liuiuuiiiiiiuii ~P Production Scanning ` ~~ IIIIIIIIIIIIIIIIII Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: _~YES NO BY: Maria Date: , I ~ ©O /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO • t BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II II I (I II I I III ReScanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked III IIIIII III (I'I () ~_ x 30 = ~~~ + _~ =TOTAL PAGES~~ ll II I (Count does not include cover sheet) Date- Ll__ ~1~~ /s/ Re,~a~~eeae~ ouioiiiiuiiuu OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: P P 1 01612 0 0 5 Well History File Cover Page.doc i _, ~- ae ~F t. ~i. -,~. ~ „~,.,,, ~ r V . ~,w„ ~° ~_`'~ i s;~ ~ ~ ~ "~'' -tom ~' ' MICROFILMED 6/30/2010 DO NDT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporazy Internet Files\OLK9\Microfilm_Mazker.doc ~~~ STATE OF ALASKA j[J~ Q ~, ~Q(~9 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATI~o~i ~ Gas ~OfiS. /;nrr,n,«~~„~ 1. operations Performed: Abandon ^ Repair Well ^~ Plug Perforations ^ Stimulate ^ OtI~IG~f9i';3~ Install Iso Sleeve Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ - Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2.Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc.' Development ^ Exploratory ^ 206-111 3. Address: Strati ra hic g p ^ Service ~ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23317-60 7. KB Elevation (ft): 9. Well Name and Number: RKB 121' ~ 1J-102L1 - 8. Property Designation: 10. Field/Pooi{s): ADL 25661& 25662 Kuparuk River Field /West Sak Oil Pool ` 11. Present Well Condition Summary: Total Depth measured 1185' ~v `~~ feet true vertical 37 3 5~~ feet Plugs (measured; 1 Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 20" 120' 120' 1,530' 520' SURFACE 10-3/4" 2,681' 2,323' 5,210' 2,480' INTERMEDIATE 7-5/8" 5,920' 3,780' 6,890' 4,790' B SAND LINER 4-1 /2" 12,093' 3,585' 7,780' 6,350` Perforation depth: Measured depth: 5308' - 12058' .:a~J~fi~c'~~~ s' 1.~1h~E {. 4, ~~~' true vertical depth: 3585' - 3604' Tubing (size, grade, and measured depth) 4-1/2:, L-80, 4706' (3.81" OD, 2.25" ID, CMU Isolation Sleeve at 4631') Packers &SSSV (type & measured depth) Loc Seal Assbly 4681', D-SAND LEM 4673', B-SAND LEM 4837', HRD Liner Top Packer 5150' SSSV = Camco DB Nipple 516' 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicable 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 NA NA NA NA NA Subsequent to operation NA NA NA NA NA 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service ^`~ Daily Report of Well Operations X 16. Well Status after work: C^ Ga~ WAG^ GINJ ^ WINJ Q WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or wA if c.o. Exempt: contact Martin Walters Printed Name Martin Walters Title Problem Wells Supervisor Signature ~~~ Phone: 659-7224 Date 5/31 /2009 6 Martin Walters 659-7224 ~. ~i~Cv ~ 0 2009 ~ l4 ~ ~~ e~-G Form 10-404 Revised 04/2006 Submit Origin gr ~ ~ 1J-102 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summa 5/24/2009 5/27/2009 5/27/2009 MITIA- failed; State witnessed (Robert Noble) Initial T/I/0= 564/880/166; Rigged up to IA with LRS and attempted to pressure up IA with no success. pumped 11.6bbls. Final T/I/0= 564/880/166 IDENTIFY LEAK @CMU 4631' RKB W/ HOLE FINDER. ATTEMPT TO CLOSE & OPEN CMU BUT UNABLE TO ENGAGE IN (BOTH DIRECTIONS) SET 4' 3" 3.82.OD, 2.60 ID, CMU ISO SLEEVE @ 4606' SLM, MIT-IA 2500# (PASS), JOB IN PROGRESS. MITIA (passed): Pre T/IA/OA = 560/2350/220, Initial T/IA/OA = 560/2500/240, 15 minute T/IA/OA = 575/2450/200, 30 minute T/IA/OA = 575/2450/200 PULLED ISO SLEEVE FROM CMU (a~ 4631' RKB. BRUSH CMU @ 4631' RKB. ATTEMPT TO OPEN CMU (UNABLE TO ENGAGE). SET 3.81" CMU ISO SLEEVE ON DB LOCK (2.83 NOGG, 2.25 MIN ID, 4' 6" LONG) @ 4631' RKB. MIT-IA 2500# (PASS), JOB COMPLETE. Y ~e>r DATA SUBMITTAL COMPLIANCE REPORT 9/17/2008 Permit to Drill 2061110 Well Name/No. KUPARUK RIV U WSAK 1J-102L1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23317-60-00 MD 12242 TVD 3582 Completion Date 10/4/2006 Completion Status 1-OIL Current Status 1WINJ U Y REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR/Res, Dens/Neu (data taken from Logs Portio n of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Typ Med/Frmt Number -- ----- Name --------- Scale Media No Start Stop CH Received Comments pt 14216 ----- LIS Verification ----- 2606 12242 Open -- 11/9/2006 - --- ROP, GR, FET Lis 14216 ~y .~.tu.,,1: ti/ ~,,, 2606 12242 Open ROP, GR, FET ED D Asc Directional Survey 5040 12242 Open 11/9/2006 ~og Induction/Resistivity 25 Col 120. 3582 Open 3/24/2008 TVD DGR, EWR 21-Sep- ~ 2006 .Cog Induction/Resistivity 25 Col 120 12242 Open 3/24/2008 MD ROP, DGR, EWR 21- Sep-2006 ~,, ~~ ~B~ C Lis 16048 Induction/Resistivity 2606 12242 Open 3/24/2008 LIS Veri, GR, RPX, FET, RPS, RPD, RPM, ROP C 16048 See Notes 0 0 Open 3/24/2008 TVD and MD logs in PFD, CGm and EMF graphics Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y ~N Chips Received? ~~ Analysis `Y"1'I~ Received? Comments: Interval Start Stop Sent Received Daily History Received? Formation Tops Sample Set Number Comments ~N ~iN ~; DATA SUBMITTAL COMPLIANCE REPORT 9/17/2008 Permit to Drill 2061110 Well Name/No. KUPARUK RIV U WSAK 1J-102L1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23317-60-00 MD 12242 -TVD- 3582 ~ ~ Completion Date 10/4/2006 Completion Status 1=OIL Current Status 1 WINJ UIC Y ____ Compliance Reviewed By: Date: Ll 1 /lJU • 11V1~.4tVt1 Vli 1L t lug vu~ av au• j ... ., .. .~ ,.. ~.~.. - -~p- - -- Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, August 27, 2007 9:52 AM To: 'NSK West Sak Prod Engr'; Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPF1 Prod Supt; Hollar, Eric Andrew; Rodgers, James T Subject: RE: LPP/SSV defeated on 1E-112, 1J-102, 1J-127, 1J-164, 1J-180 Thanks Hai, While we will file this information in the main wellbore file, it is probably appropriate to list the lateral permit numbers for completeness. Call or message with any questions. Tom Maunder, PE AOGCC From: NSK West Sak Prod Engr [mailto:n1638@conocophillips.com] Sent: Sunday, August 26, 2007 8:59 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: CPF1 DS Lead Techs; CPFi Prod Supt; NSK West Sak Prod Engr; Hollar, Eric Andrew; Rodgers, James T Subject: RE: LPP/SSV defeated on 1E-112, 1J-102, iJ-127, iJ-164, iJ-180 Tom /Jim, The LPP/SSV's on all of the West Sak DS1E and DS1J wells are now back in service as their wellhead injection pressures have increased to above 500 psi. The following wells had been defeated; permit to drill numbers are also listed. I ~niasn't sure if yo~~ wanted the permit to drill number for the mainbore only or the laterals as we!I so included both. WELL ID Permit to Drill No. 1 E-112 204-091 (MAINBORE), 204-092 (L1), 204-093 (L2} --=~ 1J-102 206-110 (MAINBORE), 206-111 (L1), 206-'112 (L2) 1J-105 207-027 (MAINBORE), 207-028 (L1), 207-029 (L2) 1J-127 206-047 (MAINBORE), 206-048 (L1), 206-049 (L2) 1J-160 207-015 (MAiP~IBORE), 207-016 (L1), 207-017 (L2) 1J-164 205-144 (MAINBORE}, 205-145 (L1), 205-146 (L2) 1J-180 206-150 (MAINBORE), 206-151 (L1) Note: '1J-105 and '1J-160 were defeated in early July 2007, before the CPF1 ESD, because they were new injectors (notification for these wells was sent 7/9/2007). Let me know if you have any questions. Regards, Hai Hunt Hai Hunt /Pete Nezaticky /Eric Hollar NSK Vilest Salc Production Engineer ConocoPhillips Alaska, Inc. Phone: (907) 659-7061 Fax: (907} 659-7749 Email: n1638@ConocoPhiflips.com 8!27/2007 ~ ~ RECEIVED MAR 1 3 2007 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska OII & CiBS COn$. Commission REPORT OF SUNDRY WELL OPERATIONS Anchorage 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other: 0 ~ +~ Alter Casing ^ Pull Tubing ^ Pertorate New Pooi ^ Waiver ^ Time Extension , ^ ~'~~ Change Approved Program ^ Operat. Shutdown^ Perforate ^ ~~a Re-enter Suspended Well ^ /3,/G'~ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number. ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 206-111 / 3. Address: Strati ra hic g p ^ Service ~ ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23317-60 7. KB Elevation (ft): 9. Well Name and Number. RKB 121' 1J-102L1 8. Property Designation: 10. Field/Pool(s): ADL 25661' & 25662'. Kuparuk River Field /West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 12242' feet true vertical 3582' feet Plugs (measured) .Effective Depth measured 12091' feet Junk (measured) true vertical 3585 feet .Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 140' 20" 140' 140' SURFACE 2602' 10-3/4" 2642' 2254' INTERMEDIATE 5880' 7-5/8" 5920' 3741' B-SAND LINER 6849' 4-1/2" 12093' 3585' Perforation depth: Measured depth: Slotted Liner 5308' - 12 058' true vertical depth: 3604' - 3585' Tubing (size, grade, and measured depth) 4-1/2" , L-80, 4708' MD . Packers &SSSV (type & measured depth) no packer SSSV=NIP SSSV= 516' - 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 1539 2216 97 861 360 Subsequent to operation ~ 1838 986 5 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service Daily Report of Well Operations X 16. Well Status afterproposed work; Oil^ Gas^ WAG^ GINJ^ ~WINJ Q WDSPL^ 17. Chereby certify that the foregoing is true and correct to the best of my knowledge. SundryNumber or N/A if C.o. Exempt: 306-380. contact Bob Christensen /Bob Buchholz Printed Name be D. Chri tensen Title Production Engineering Technician Signature ~ - Phone 659-7535 Date. ~~q JQ # ~i ~~ MAID ~ ~ 20D"l Form 10-404 Revised 04!2004 4 ~ ~ ~ ~E ~ s Pte, ~ 3. /G .a`7 r "'~~ Submit Ori ' ~`,~ 1J-102L1 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 02/20/07 Commenced Water Injection Service SARAH PAL/N, GOVERNOR 333 W. 7`" AVENtiE, SliITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-75423 Robert Buchholz Production Engineering Technician ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1J-102L1 Sundry Number: 306-380 Dear Mr. Buchholz: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907} 659-3607 (pager). 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this la day of December, 2006 Encl. aUCo ~-lVt ~ ~z/~~~~~ -o ~~ ®~+ (~ ~~ ~~~~T ~FALASKA ~ ~h. I''~E~~~~~'"°` ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~ ~ ~ 2~O6 APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 Alaska Oil & Gas Cons. Ct~fnmissian 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ~ Other • Q Alter casing ^ Repair well ^ Plug Pertorations ^ Stimulate ^ Time Extension ^ Chan e a roved ro ram g pp p g ^ Pull Tubing ^ Perforate New Pool ^ Producer to Re-enter Suspended Well ^ Injector 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhilljps Alaska, Inc. Development ~ Exploratory ^ 206-111 ~ ~ 3. Address: Stratigraphic ^ Service ^ 6. API Number: ~ P. O. Box 100360, Anchorage, Alaska 99510 50-029-23317-60 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Y2S ^ NO ^~ 1J-102L1 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 25661'& 25662' ~ RKB 121' Kuparuk River Field !West Sak Oil Pool 12. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12242' 3582' • 12091' 3585' Casing Length Size MD TVD Burst Collapse CONDUCTOR 140' 20" 140' 140' SURFACE 2521' 10-3/4" 2642' 2254' INTERMEDIATE 5799' 7-5/8" 5920' ~~r ~R B-SAND LINER 6849' 4-1/2" 12093' 3585' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Slotted Liner 5308' - 12058' 3604' - 3585' 4-1 /2" L-80 4708' Packers and SSSV Type: j ~ `- 1~ Packers and SSSV MD (ft) \b z.~ i ~ ~ ~.~~ ~~~ ~ SSSV= NIP SSSV= 516' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: January 14, 2007 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^~ - WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Bob Christensen /Bob Buchholz Printed Name Robert W. Buchholz Title: Production Engineering Technician Signature ~ Phone 659-7535 Date /Z `3 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representat ive may witness Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other. Subsequent Form Required: ~.,ITI~` APPROVED BY A 3 Approved by: SSIONER THE COMMISSION ' Date: !~' ~0 Form 10-403 Revised 06/2006 Submit in Duplicate _ .~. '~..1- i /a/~ • 1J-102L1 DESCRIPTION SUMMARY OF PROPOSAL ConocoPhillips Alaska Inc. requests approval to begin Water Injection service in West Sak Tri- lateral Well 1J-102L1. Plans are to pre-produce well for 30 days in order to recover Oil based drilling fluids prior to putting the well on injection. Lateral 1J-102L1 will provide pressure support for the West Sak B sands. The 10-3/4" Surface casing (2642' and / 2254' tvd) was cemented with 389 bbls AS Lite followed by 76 bbls DeepCRETE. The 7-5/8" Intermediate casing (5920' and / 3741' tvd) was cemented with 350 sx DeepCRETE. The injection tubing/casing annulus is isolated via the following: Upper D sand ZXP 5-1/2" x 7- 5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 4673' and / 3524' tvd, Upper B sand ZXP 5-1/2" x 7-5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 4837' and / 3562' tvd, and an Upper A sand ZXP 5-1/2" x 7-5/8" Liner Top Packer with 190-47 Casing Sealbore Receptacle located @ 5150' and / 3625' tvd. The top of West Sak D sand was found at 4730' and / 3539' tvd. The top of West Sak B sand was found at 5047' and / 3604' tvd. The top of West Sak A sand was found at 5876' and / 3735' tvd. 4 ~r KRU 1 J-102L1 .t~ ~r~~c~c~~~lips ~,~~s~a ~r~~, . __ ~ ~~~.-- tr Q ~~~~ e MEC:iA.NICAL INTEGRITY REPORT ~ -`i~ .°UD L:.== : ~ ~j~s-U~ OPER ~ FIELD C,~~~ ~ ~~©cs~'C'~~L -- ~v~ =..c ..~~~._..~ . '°l~-~c~ ;.ALL Nur~~.R ~ ~-~C~ ~- - ~~. --~..~ ~~LL DAT_=- TD : ?~.. TVD ; ?BTD : ~ID Casi~g:_ '~`~~~ Shoe: 5 ~~ ~ .3-~..~T~~ DV: ~~ '-~ ..:~e_ . Shoe: '~ T`JT ; ~'C~ ?•~ =moo; ~= . ~i~~~~~ ~acicer '~ ole S~~e ana ~~Cc~?~=C~ L INTEGRTTY - P4..RT #1 n::ulus ?ress Test: _~ ; 15 nin ~0 min Ccc.~ents i '~'CHP NIC~~, INTEGRITY - PART # Z ~.-~~ \+117 ~b \S Cement Volumes :- Amt. Liner ~ ~ CsQ ~~ Sti. DV N1~ c Cmt -rot to cover oers C ~a0?m`FS j~ e~~os~~`--~w~~o~.3 ~a ~i~ ~ ~~ Sit { -=:eoretical TCC ~ ~~ ~ ~S ~~C, '~ ~\~~ rlllJ~, Cement Bond Log (Yes or No) ~LS In AOGCC File ~~S C3L Evaluation, cone move pens ~C.~cCSr~~~.~.~ ~c.~R~~~1~_ ?roducti on Log: Tine CONC_LJSIONS: ?art r l ?art f~ ` ~ S :h~. T~ ; Set at 1.3 ,d. ~ T4-'?i "„~ ~ ~ar~g t0 t,Va1L'atZOn Maunder, Thomas E (DOA) From: Thomas Maunder [tom maunder@admin.state.ak.us] Sent: Tuesday, December 12, 2006 11:04 AM To: NSK Prod Engr Tech Cc: Allsup-Drake, Sharon K Subject: Re: 1J-102, et al conversion ao~-~~~ Bob, Looking at your reply, I believe that the depths you give for the L2 window are not correct. According to the operations summary the window top is the same as the sand tops given in the same line. Would you confirm please? Call or message with any questions. Tom Maunder, PE ~; l~ ~~rM~C~~Z~~\ ~~~~~ AOGCC - c~ po~ NSK Prod Engr Tech wrote, On 12/7/2006 6:16 AM: `~,~ ~~„ /~ _ . /~~ /V l >Here what I found: > >7-5/8" sing: > Top 40'md (40' tvd), Bottom = 5920' (3741' tvd), Length = 5880', >common to 1 3 wellbores. >7-5/8" casin Windows: > 1J-102L2 op @ 4937' md (3582' tvd), D sand top found @ 4730'md (3539' >tvd) > 1J-102L1 To @ 5047' md (3604' tvd), B sand top found @ 5047'md (3604' >tvd) > 1J-102 (Mother ellbore), A sand top found @ 5876' md (3735' > tvd ) > >Per your suggestion, we ill start including window depths in the >"Description Summary of P posal" page as we do not have enough room on >the 10-403 proper. > >I have forwarded your suggesti n on the liner top packers to Sharon >Allsup-Drake for consideration. pparently this question has come up in >the past. We currently provide th's information in the "Description >Summary of Proposal" page. > >Sorry for the confusion. >Bob Christensen . ~ ; r~ ~~~~~ >ConocoPhillips Alaska, Inc. ;~t ,'"kb~~~~" % ~~'~~ ~ ~~ >Greater Kuparuk Area >Production Engineering Technician >Office (907) 659-7535 NSK-69 >Pager (907) 659-7000 (924) > > >-----Original Message----- >From: Thomas Maunder [mailto:tom maunder@admin.state. k.us] >Sent: Wednesday, December 06, 2006 9:04 AM >To: NSK Prod Engr Tech >Subject: 1J-102, et al conversion > > >Bob and Bob, >I am looking at the sundries for converting iJ-102 and the late als to >injection. A couple of questions, > >1. The length of the 7-5/8" casing is listed at 5799', but the set 'ng >depth is 5920'. There seems to be a disconnect here. Based on the R 1 Maunder, Thomas E (DOA) From: NSK Prod Engr Tech [n1139@conocophillips.com] Sent: Thursday, December 07, 2006 6:16 AM To: Thomas Maunder Cc: Allsup-Drake, Sharon K Subject: RE: 1J-102, et al conversion Tom, Here's what I found: 7-5/8" casing: Top = 40'md (40' tvd), Bottom = 5920' (3741' tvd), Length = 5880', common to all 3 wellbores. 7-5/8" casing Windows: 1J-102L2 Top @ 4937' md (3582' tvd), D sand top found @ 4730'md (3539' tvd) 1J-102L1 Top @ 5047' md (3604' tvd), B sand top found @ 5047'md (3604' tvd) 1J-102 (Mother wellbore), A sand top found @ 5876' md (3735' tvd) Per your suggestion, we will start including window depths in the "Description Summary of Proposal" page as we do not have enough room on the 10-403 proper. I have forwarded your suggestion on the liner top packers to Sharon Allsup-Drake for consideration. Apparently this question has come up in the past. We currently provide this information in the "Description Summary of Proposal" page. Sorry for the confusion. Bob Christensen ConocoPhillips Alaska, Inc. Greater Kuparuk Area Production Engineering Technician Office (907) 659-7535 NSK-69 Pager (907) 659-7000 (924) -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Wednesday, December 06, 2006 9:04 AM To: NSK Prod Engr Tech Subject: 1J-102, et al conversion Bob and Bob, I am looking at the sundries for converting 1J-102 and the laterals to injection. A couple of questions, 1. The length of the 7-5/8" casing is listed at 5799', but the setting depth is 5920'. There seems to be a disconnect here. Based on the RKB height, I think the Iength of casing should be about 5880'. Can you reconcile? 2. According to the 407, the tvd setting depth of the 7-5/8" casing is 3741' tvd. On the -Ll 403 the tvd depth is listed as 3592' and on the -L2 403 the tvd depth is listed as 3533'. According to the calculations done over here -L1 window is at 5047' md, 3604' tvd and -L2 window is at 4730' md, 3539' tvd. Are these the window tops? I know our respective depths are close. On future applications, it may make sense to have a line that lists the full intermediate casing string with another line that has the specifics of the window. What do you think? 3. On each sundry, it is indicated that there is no packer in the 1 well. While technically there isn't a packer, the LEM ZXP liner top packer at 4672' is the functional equivalent. You might check with the drilling or production engineers about the specifics. Thanks in advance for looking into these questions. I look forward to your reply. All in all, the construction looks good. The bond log is excellent. Just need to clarify these points and recommending approval should not be a problem. Tom Maunder, PE AOGCC 2 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND BOG 1a. Well Status: Oil ^ ~ Gas Plugged Abandoned Suspended WAG ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ No. ofCompletions_ Other_ i15 Glass Development ~ Exploratory ^ Service ^ StratigraphicTest^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., oraband.: October 4, 2006 12. Permit to Drill Number: 206-111 / 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: - i3 g(~ A 006 t!•/ 13. API Number: ~ 50-029-23317-60 4a. Location of Well (Governmental Section): Surface: 2245' FSL, 2446' FEL, Sec. 35, T11 N, R10E, UM ~ 7. Date TD Reached: September 20, 2006 14. Well Name and Number: 1J-102L1 At Top Productive Horizon: 1690' FSL, 562' FEL, Sec. 35, T11 N, R10E, UM 8. KB Elevation (ft): 40' RKB 15. Field/Pool(s): Kuparuk River Field Total Depth: 217' FNL, 599' FEL, Sec. 11, T10N, R10E, UM 9. Plug Back Depth (MD + ND): 12091' MD / 3584' ND West Sak Oil P001 ~ 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558761 y- 5946057 - Zone- 4 10. Total Depth (MD + ND): ~ 12242' MD / 3582' ND 16. Property Designation: ADL 25661 & 25662 TPI: x- 560649 y- 5945516 Zone- 4 Total Depth: x- 560676 ° - 5938331 - Zone- 4 11. Depth where SSSV set: none 17. Land Use Permit: ALK 471 8~ 2177 18. Directional Survey: Yes ^/ No ^ 19. Water Depth, if Offshore: N/A feet MSL 20. Thickness of Permafrost: 3628' MD 21. Logs Run: ?' (t/w~- c'sW 1rpy7 rl70 / ~tid~/~ ~b ~ /~• /'f O(o GR/Res, Dens/Neu 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 62.6# H-40 40' 120' 40' 120' 42" 300 sx AS 1 10.75" 45.5# L-80 40' 2643' 40' 2252' 13.5" 389 bbls AS Lite, 76 bbls DeepCRETE 7-5/8" 29.7# L-80 40' 5920' 40' 3741' 9-7/8" 350 sx DeepCRETE 4.5" 11.6# L-80 5244' 12093' 3607' 3584' 6.75" slotted liner 23. Perforations open to Production (MD + ND of Top and Bottom 24. TUBING RECORD Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET tubing in original wellbore none slotted liner from 5595' to 11512' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production not available Method of Operation (Flowing, gas lift, etc.) waiting on facility hook-up Date of Test Hours Tested Production for Test Period -> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corr) 27. CORE DATA 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". ~~ I,~~ ; ~~ 2006 ; NONE L,o/ ti ~ ~ ~~ ~ pit ~,e~.._._~ Form 10-407 Revised 12/2003 CONTINUED ON REVERSE ~~ ~/~f'f~v(° c~~ C~ ~~~~~ ~i~~~d s za. zs. GEOLOGIC MARKERS FORMATION TESTS 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". 1 J-102L1 West Sak B 5047 3604' ' N/A 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: Pat Reilly @ 265-6048 Printed Nam Ran Title: Greater Kuaaruk Area Drillino Team Leader ~ f (t 3 f® d / " Signature -,tee ~ ~ 6 -~ 3 ~ Date INSTRUCTIONS Prepared by Sharon Allsup-Drake 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 10-407 Revised 12/2003 021CIN/aL ~-Ialliburton Company Survey Report Company: ConocoPhillips Alaska Inc: Datc: 10/16(2006 Timc: 15.46:05 Pagc: I Field: Kuparuk River Unit Co-ordinatc(NE) Rcfercncr. Well: 1 J-102, True North Site: Kuparuk 1J Pad Vertical(T'VD) Re ference: 1J-102L1: 121.3 Well: 1J-102 Section (VS)Refer ence: Well (O OON,O.OO E,180.OOAzi) Wellpath: 1J-102L1 Survey Calculation Method: Minimum Curvature Dh: Oracle Field: Kuparuk River Unit North Slope Alaska ~ United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate Sy stem: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Well: 1 J-102 Slot Name: Well Position: +N/-S 137.61 ft Northing: 5946057.02 ft Latitude: 70 15 47.611 N i j +E/-W -27.19 ft Easting : 558761.69 ft Longitude: 149 31 29.798 W Position Uncertainty: 0.00 ft - ~ Survey __ Mll Incl ~cim TVll SysT1-'D N(S E/W ~~tapA ylapf, fool ft deg deg ft ft ft ft ft ft 40.30 0.00 0.00 40.30 -81.00 0.00 0.00 5946057.02 ' 558761.69 - TIE LINE j 121.00 0.45 106.20 121.00 -0.30 -0.09 0.30 5946056.93 558761.99 CB-GYRO-SS 220.00 0.78 44.56 219.99 98.69 0.28 1.15 5946057.31 558762.84 CB-GYRO-SS 320.00 4.66 32.21 319.86 198.56 4.21 3.79 5946061.26 558765.45 CB-GYRO-SS j 420.00 8.21 30.63 419.22 297.92 13.79 9.60 5946070.88 558771.18 CB-GYRO-SS 520.00 12.54 26.87 517.56 396.26 29.63 18.15 5946086.78 558779.60 CB-GYRO-SS ~ 620.00 15.71 25.57 614.52 493.22 51.53 28.90 5946108.77 558790.18 CB-GYRO-SS 720.00 18.93 27.89 709.98 588.68 78.08 42.34 5946135.43 558803.41 CB-GYRO-SS 820.00 23.00 33.80 803.35 682.05 108.67 60.80 5946166.15 558821.64 CB-GYRO-SS 869.87 23.17 37.49 849.23 727.93 124.55 72.19 5946182.12 558832.90 MWD+IFR-AK-CAZ-SC 964.72 24.49 38.35 935.99 814.69 154.78 95.75 5946212.53 558856.22 MWD+IFR-AK-CAZ-SC 1058.43 24.67 42.44 1021.21 899.91 184.45 121.00 5946242.39 558881.23 MWD+IFR-AK-CAZ-SC 1153.43 24.88 48.25 1107.48 986.18 212.39 149.29 5946270.55 558909.31 MWD+IFR-AK-CAZ-SC 1248.76 26.13 49.54 1193.52 1072.22 239.36 180.23 5946297.76 558940.03 MWD+IFR-AK-CAZ-SC 1342.77 27.89 48.40 1277.28 1155.98 267.40 212.42 5946326.04 558972.00 MWD+IFR-AK-CAZ-SC 1439.09 31.30 50.15 1361.02 1239.72 298.40 248.49 5946357.32 559007.82 MWD+IFR-AK-CAZ-SC 1535.84 30.64 50.08 1443.98 1322.68 330.32 286.69 5946389.54 559045.77 MWD+IFR-AK-CAZ-SC 1631.24 32.51 50.90 1525.25 1403.95 362.09 325.23 5946421.61 559084.06 MWD+IFR-AK-CAZ-SC 1723.25 36.09 52.10 1601.25 1479.95 394.35 365.82 5946454.17 559124.39 MWD+IFR-AK-CAZ-SC 1821.35 41.06 53.68 1677.92 1556.62 431.20 414.61 5946491.40 559172.88 MWD+IFR-AK-CAZ-SC 1916.57 44.73 53.28 1747.67 1626.37 469.77 466.68 5946530.37 559224.65 MWD+IFR-AK-CAZ-SC 2010.97 45.69 55.27 1814.17 1692.87 508.88 521.07 5946569.90 559278.72 MWD+IFR-AK-CAZ-SC 2105.87 45.73 56.87 1880.44 1759.14 546.79 577.43 5946608.25 559334.78 MWD+IFR-AK-CAZ-SC j ', 2201.01 47.60 61.41 1945.75 1824.45 582.23 636.82 5946644.15 559393.89 MWD+IFR-AK-CAZ-SC ', 2293.68 46.11 65.63 2009.14 1887.84 612.39 697.30 5946674.78 559454.12 MWD+IFR-AK-CAZ-SC 2391.30 46.49 70.60 2076.60 1955.30 638.67 762.75 5946701.57 559519.36 MWD+IFR-AK-CAZ-SC ~I 2486.23 45.57 74.98 2142.53 2021.23 658.90 827.98 5946722.30 559584.42 MWD+IFR-AK-CAZ-SC ~ 2581.48 43.53 80.15 2210.42 2089.12 673.33 893.17 5946737.23 559649.50 MWD+IFR-AK-CAZ-SC Wellpath: 1J-102L1 Drilled From: 1 J-102 500292331760 Tie-on Depth: 5040.59 ft Current Datum: 1 J-102L1: Height 121.30 ft Above System Datum: Mean Sea Level Magnetic Data: 8/25/2006 Declination: 23.82 deg Field Strength: 57608 nT Mag Dip Angle: 80.80 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 40.30 0.00 0.00 180.00 Survey Program for Definitive Wellpath Date: 10/16/2006 Validated: No Version: 4 Actual From To Survey Toolcode Tool Name ft ft 121.00 820.00 1J-102PB1 gyro (121.00-820.00) CB-GYRO-SS Camera based gyro single shot 869.87 5040.59 1J-102PB1 (869.87-8124.27) (3) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5046.00 12148.86 1 J-102L1 (5046.00-12148.86) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC -Ialliburton Company i Survey Report Company: ConocoPhillipsAlaska Inc. Date: 10/16/2006 "1"imc: 15:46:05 Page:_ Field: Kuparuk River Unit Co-ordinate (NE) Reference: WeII: 1J-102, True North Site: Kuparuk 1J Pad Verticab(TVD) Reference: 1J-102L1: 121 .3 Well: 1J -102 Sectio n (VS) Reference: Well (O.OON,O.OOE,180.OOAzi) ' 1~`ellpath: 1 J -102L1 Surve y Calc ulation Method: Minimum Curv ature Db: Oracle Survc~' -- - iy1D lncl 9zim 'I'U'D Sys T1~ D N/S F./1V MapN NtapE Too! ft deg deg ft ft ft ft ft ft 2602 .96 43.39 80 .76 2226. 01 __ 2104 .71 _ _ _ 675 .78 907. 74 5946739 .80 559664.04 _ -- MWD+IFR-AK-CAZ-SC 2692 .50 43.33 80 .12 2291. 12 2169 .82 685 .99 968. 36 5946750 .48 559724.58 MWD+IFR-AK-CAZ-SC j 2789 .32 41.08 80 .53 2362. 83 2241 .53 696 .92 1032. 48 5946761 .91 559788.60 MWD+IFR-AK-CAZ-SC 2883 .45 39.91 82 .89 2434. 42 2313 .12 705 .75 1092. 95 5946771 .21 559849.00 MWD+IFR-AK-CAZ-SC 2978 .49 42.09 87 .64 2506. 16 2384 .86 710 .84 1155. 05 5946776 .78 559911.05 MWD+IFR-AK-CAZ-SC 3072 .35 42.28 89 .81 2575. 71 2454 .41 712 .24 1218. 06 5946778 .67 559974.04 MWD+IFR-AK-CAZ-SC 3164 .88 43.18 96 .30 2643. 71 2522 .41 708 .87 1280. 68 5946775 .79 560036.68 MWD+IFR-AK-CAZ-SC 3260 .78 43.19 102 .29 2713. 67 2592 .37 698 .28 1345. 39 5946765 .71 560101.46 j MWD+IFR-AK-CAZ-SC 3353 .79 43.31 108 .49 2781. 44 2660 .14 681 .38 1406. 77 5946749 .29 560162.97 MWD+IFR-AK-CAZ-SC 3447 .64 44.63 113 .39 2849. 00 2727 .70 658 .07 1467. 58 5946726 .46 560223.95 MWD+IFR-AK-CAZ-SC j 3541 .79 46.90 119 .91 2914. 72 2793 .42 627 .78 1527. 77 5946696 .65 560284.36 MWD+IFR-AK-CAZ-SC 3636 .01 48.89 126 .24 2977. 92 2856 .62 589 .62 1586. 25 5946658 .95 560343.14 MWD+IFR-AK-CAZ-SC 3729 .21 49.70 132 .74 3038. 74 2917 .44 544 .72 1640. 70 5946614 .47 560397.94 MWD+IFR-AK-CAZ-SC 3823 .40 49.11 138 .38 3100. 06 2978 .76 493 .70 1690. 75 5946563 .85 560448.38 MWD+IFR-AK-CAZ-SC 3916 .77 49.70 146 .22 3160. 87 3039 .57 437 .67 1734. 03 5946508 .17 560492.09 MWD+IFR-AK-CAZ-SC 4010 .22 51.80 150 .91 3220. 01 3098 .71 375 .94 1771. 71 5946446 .74 560530.25 MWD+IFR-AK-CAZ-SC ~ 4104 .27 55.02 157 .51 3276. 11 3154 .81 307 .98 1804. 45 5946379 .04 560563.51 MWD+IFR-AK-CAZ-SC 4198 .08 57.40 161 .80 3328. 29 3206 .99 234 .90 1831. 51 5946306 .18 560591.13 MWD+IFR-AK-CAZ-SC ~ 4291 .04 62.13 164 .89 3375. 10 3253 .80 157 .97 1854. 46 5946229 .45 560614.69 MWD+IFR-AK-CAZ-SC 4384 .47 65.15 169 .96 3416. 60 3295 .30 76 .30 1872. 63 5946147 .93 560633.49 MWD+IFR-AK-CAZ-SC 4474 .72 66.68 173 .83 3453. 44 3332 .14 -5 .25 1884. 23 5946066 .48 560645.72 MWD+IFR-AK-CAZ-SC 4566 .87 68.47 176 .21 3488. 59 3367 .29 -90 .10 1891. 61 5945981 .70 560653.77 MWD+IFR-AK-CAZ-SC 4664 .00 72.68 180 .95 3520. 91 3399 .61 -181 .62 1893. 83 5945890 .20 560656.70 MWD+IFR-AK-CAZ-SC 4759 .55 77.88 181 .97 3545. 18 3423 .88 -273 .97 1891. 47 5945797 .85 560655.06 MWD+IFR-AK-CAZ-SC 4848 .85 77.69 181 .35 3564. 07 3442 .77 -361 .21 1888. 94 5945710 .60 560653.21 MWD+IFR-AK-CAZ-SC 4942 .22 78.44 182. 65 3583. 38 3462 .08 -452 .50 1885. 75 5945619 .29 560650.73 MWD+IFR-AK-CAZ-SC 5040 .59 78.70 180. 15 3602. 88 3481 .58 -548 .88 1883. 40 5945522 .90 560649.13 MWD+IFR-AK-CAZ-SC 5046 .00 78.67 180. 20 3603. 94 3482 .64 -554 .19 1883. 38 5945517 .60 560649.16 MWD+IFR-AK-CAZ-SC 5113 .59 86.48 180. 65 3612. 67 3491 .37 -621 .16 1882. 88 5945450 .63 560649.18 MWD+IFR-AK-CAZ-SC 5163 .77 93.34 180. 98 3612. 75 3491 .45 -671 .30 1882. 17 5945400 .49 560648.86 MWD+IFR-AK-CAZ-SC 5207 .76 94.13 179. 27 3609. 88 3488 .58 -715 .20 1882. 07 5945356 .60 560649.10 MWD+IFR-AK-CAZ-SC 5255 .90 93.33 180. 32 3606. 75 3485 .45 -763 .23 1882. 24 5945308 .57 560649.65 MWD+IFR-AK-CAZ-SC 5300 .29 93.02 181. 61 3604. 29 3482 .99 -807 .55 1881. 50 5945264 .26 560649.25 MWD+IFR-AK-CAZ-SC 5349 .15 92.09 182. 31 3602. 11 3480 .81 -856 .33 1879. 83 5945215 .47 560647.96 MWD+IFR-AK-CAZ-SC 5394 .41 87.96 182. 35 3602. 09 3480 .79 -901 .54 1877. 99 5945170 .25 560646.47 MWD+IFR-AK-CAZ-SC 5441 .54 88.28 182. 94 3603. 64 3482 .34 -948 .60 1875. 81 5945123. 18 560644.67 MWD+IFR-AK-CAZ-SC 5488. 73 89.01 182. 82 3604. 76 3483 .46 -995 .71 1873. 44 5945076. 05 560642.67 MWD+IFR-AK-CAZ-SC I~ 5538 .15 91.24 183. 77 3604. 65 3483 .35 -1045 .05 1870. 60 5945026. 70 560640.21 MWD+IFR-AK-CAZ-SC 5582 .97 93.81 183. 55 3602. 67 3481 .37 -1089 .73 1867. 74 5944982. 00 560637.70 MWD+IFR-AK-CAZ-SC 5632. 24 91.85 183. 67 3600. 24 3478 .94 -1138 .84 1864. 65 5944932. 87 560634.99 MWD+IFR-AK-CAZ-SC 5676. 75 90.44 183. 07 3599. 35 3478 .05 -1183 .26 1862. 03 5944888. 44 560632.72 MWD+IFR-AK-CAZ-SC 5770. 91 92.66 182. 77 3596. 80 3475 .50 -1277 .26 1857. 24 5944794. 41 560628.66 MWD+IFR-AK-CAZ-SC 5819. 42 93.58 183. 19 3594. 16 3472 .86 -1325 .63 1854. 72 5944746. 03 560626.52 MWD+IFR-AK-CAZ-SC 5864. 71 90.80 184. 76 3592. 43 3471 .13 -1370 .77 1851. 58 5944700. 87 560623.73 MWD+IFR-AK-CAZ-SC 5915. 12 90.56 185. 08 3591. 84 3470 .54 -1421 .00 1847. 26 5944650. 62 560619.80 MWD+IFR-AK-CAZ-SC 5955. 41 88.78 182. 51 3592. 07 3470 .77 -1461 .19 1844. 59 5944610. 41 560617.45 MWD+IFR-AK-CAZ-SC 6005. 98 89.82 181. 25 3592. 68 3471 .38 -1511 .73 1842. 93 5944559. 86 560616.19 MWD+IFR-AK-CAZ-SC I 6051. 13 89.82 180. 26 3592. 83 3471 .53 -1556 .87 1842. 34 5944514. 72 560615.94 MWD+IFR-AK-CAZ-SC 6100. 51 89.87 179. 04 3592. 96 3471 .66 -1606 .25 1842. 64 5944465. 35 560616.63 MWD+IFR-AK-CAZ-SC 6143. 17 89.42 178. 95 3593. 22 3471 .92 -1648 .90 1843. 39 5944422. 71 560617.71 MWD+IFR-AK-CAZ-SC 6190. 98 90.31 180. 88 3593. 34 3472 .04 -1696 .71 1843. 46 5944374. 91 560618.15 MWD+IFR-AK-CAZ-SC 6236. 47 91.18 180. 95 3592. 75 3471 .45 -1742 .19 1842. 73 5944329. 43 560617.78 MWD+IFR-AK-CAZ-SC ~Ialliburton Company ,~, Survey Report Compan}: ConocoPhillips Alaska lnc. Date: 10/16/2006 Time: 15:46:05 Page: 3 Field: Ku paruk River Uni t Caordinate(NE) Reference: Well: 1J-102, TrueNorth Site: Kuparuk 1J Pad Vertical (TVD)Reference: 1J-102L1: 121 .3 Well: 1J -102 Sectiaai (VS) Reference: Well (OAON,O. OOE,180.OOAzi) ~Vellpath: 1J -102L1 Survey Calculati on ylethod: MihiEnum Curv ature Db: Oracle Survey -- - __ ;~1D Iucl Azim TVD Sys "TVD N/S E/W IV1apr VIapE Tool ', ft deg de g ft ft ft ft ft ft 6281.97 90.08 182 .03 3592. 25 3470.95 -1787 .67 1841.55 5944283 .95 560616.96 MWD+IFR-AK-CAZ-SC ! 6329.71 90.61 182 .28 3591. 96 3470.66 -1835 .38 1839.75 5944236 .23 560615.53 MWD+IFR-AK-CAZ-SC 6375.83 90.31 180 .79 3591. 59 3470.29 -1881 .48 1838.52 5944190 .13 560614.66 MWD+IFR-AK-CAZ-SC 6423.63 90.86 180 .42 3591. 10 3469.80 -1929 .27 1838.01 5944142 .34 560614.53 MWD+IFR-AK-CAZ-SC 6471.46 91.75 180 .71 3590. 01 3468.71 -1977 .09 1837.54 5944094 .52 560614.43 MWD+IFR-AK-CAZ-SC 6516.90 90.83 181 .26 3588. 99 3467.69 -2022 .51 1836.76 5944049 .10 560614.00 MWD+IFR-AK-CAZ-SC 6564.19 89.63 182 .52 3588. 80 3467.50 -2069 .77 1835.20 5944001 .83 560612.81 MWD+IFR-AK-CAZ-SC 6609.71 90.33 182 .87 3588. 81 3467.51 -2115 .24 1833.06 5943956 .35 560611.02 MWD+IFR-AK-CAZ-SC 6703.95 89.75 180 .90 3588. 75 3467.45 -2209 .42 1829.96 5943862 .16 560608.66 MWD+IFR-AK-CAZ-SC 6796.92 91.05 181 .64 3588. 10 3466.80 -2302 .37 1827.90 5943769 .21 560607.33 MWD+IFR-AK-CAZ-SC 6843.65 88.57 180 .07 3588. 25 3466.95 -2349 .08 1827.20 5943722 .49 560606.99 MWD+IFR-AK-CAZ-SC j 6891.36 89.05 180 .00 3589. 24 3467.94 -2396 .78 1827.17 5943674 .80 560607.34 MWD+IFR-AK-CAZ-SC 6941.63 90.30 178 .83 3589. 53 3468.23 -2447 .05 1827.69 5943624 .54 560608.24 MWD+IFR-AK-CAZ-SC ~ 6985.70 91.14 179 .22 3588. 98 3467.68 -2491 .11 1828.44 5943580 .49 560609.34 MWD+IFR-AK-CAZ-SC 7038.04 91.98 179 .02 3587. 55 3466.25 -2543 .42 1829.24 5943528 .19 560610.55 MWD+IFR-AK-CAZ-SC 7079.22 92.78 178 .82 3585. 84 3464.54 -2584 .56 1830.02 5943487 .07 560611.64 MWD+IFR-AK-CAZ-SC 7126.83 92.96 179 .78 3583. 46 3462.16 -2632 .11 1830.60 5943439 .53 560612.60 MWD+IFR-AK-CAZ-SC 7173.13 91.24 179 .95 3581. 76 3460.46 -2678 .37 1830.71 5943393 .27 560613.07 MWD+IFR-AK-CAZ-SC 7220.24 90.31 179 .85 3581. 12 3459.82 -2725 .48 1830.79 5943346 .17 560613.51 MWD+IFR-AK-CAZ-SC 7268.00 89.61 181 .18 3581. 16 3459.86 -2773 .23 1830.36 5943298 .42 560613.46 MWD+IFR-AK-CAZ-SC 7317.62 88.28 180 .45 3582. 07 3460.77 -2822 .84 1829.65 5943248 .82 560613.14 MWD+IFR-AK-CAZ-SC 7361.02 88.95 180 .23 3583. 12 3461.82 -2866 .23 1829.40 5943205 .43 560613.22 MWD+IFR-AK-CAZ-SC 7409.35 89.88 179 .60 3583. 61 3462.31 -2914 .55 1829.47 5943157 .11 560613.67 MWD+IFR-AK-CAZ-SC 7455.12 88.49 178 .96 3584. 26 3462.96 -2960 .31 1830.04 5943111 .36 560614.60 MWD+IFR-AK-CAZ-SC 7503.85 87.81 179 .37 3585. 84 3464.54 -3009 .01 1830.75 5943062 .68 560615.69 MWD+IFR-AK-CAZ-SC 7549.10 90.06 177 .36 3586. 68 3465.38 -3054 .23 1832.04 5943017 .47 560617.34 MWD+IFR-AK-CAZ-SC 7597.25 89.44 177 .54 3586. 89 3465.59 -3102 .33 1834.19 5942969 .39 560619.85 MWD+IFR-AK-CAZ-SC 7643.08 90.00 177 .14 3587. 11 3465.81 -3148 .11 1836.31 5942923 .64 560622.34 MWD+IFR-AK-CAZ-SC 7690.45 90.82 177 .68 3586. 77 3465.47 -3195 .43 1838.45 5942876 .34 560624.85 MWD+IFR-AK-CAZ-SC 7737.48 91.61 177 .98 3585. 78 3464.48 -3242 .42 1840.23 5942829 .37 560626.99 MWD+IFR-AK-CAZ-SC 7785.05 90.22 178 .22 3585. 02 3463.72 -3289 .95 1841.81 5942781 .86 560628.94 MWD+IFR-AK-CAZ-SC 7831.35 90.63 178 .48 3584. 67 3463.37 -3336 .23 1843.14 5942735 .59 560630.63 MWD+IFR-AK-CAZ-SC ~ I 7879.58 89.79 177 .82 3584. 50 3463.20 -3384 .44 1844.70 5942687 .41 560632.57 MWD+IFR-AK-CAZ-SC i 7924.95 90.31 178 .43 3584. 46 3463.16 -3429 .78 1846.18 5942642 .08 560634.41 MWD+IFR-AK-CAZ-SC 8017.86 91.73 179 .80 3582. 80 3461.50 -3522 .66 1847.62 5942549 .22 560636.57 MWD+IFR-AK-CAZ-SC 8066.44 91.67 179 .80 3581. 36 3460.06 -3571 .22 1847.79 5942500 .67 560637.11 MWD+IFR-AK-CAZ-SC 8111.58 89.14 180 .15 3581. 04 3459.74 -3616 .36 1847.81 5942455 .54 560637.49 MWD+IFR-AK-CAZ-SC ! 8163.36 90.00 179 .38 3581. 43 3460.13 -3668 .13 1848.02 5942403 .77 560638.10 MWD+IFR-AK-CAZ-SC 8206.49 90.99 180 .44 3581. 06 3459.76 -3711 .26 1848.09 5942360 .65 560638.51 MWD+IFR-AK-CAZ-SC 8256.85 92.29 180 .37 3579. 62 3458.32 -3761 .60 1847.73 5942310 .32 560638.54 MWD+IFR-AK-CAZ-SC 8297.15 91.42 181 .86 3578. 31 3457.01 -3801 .87 1846.95 5942270 .05 560638.07 MWD+IFR-AK-CAZ-SC 8349.86 92.10 182 .65 3576. 69 3455.39 -3854 .51 1844.88 5942217. 39 560636.41 MWD+IFR-AK-CAZ-SC 8391.89 89.14 184 .34 3576. 24 3454.94 -3896 .45 1842.31 5942175 .44 560634.18 MWD+IFR-AK-CAZ-SC 8487.64 90.43 184 .98 3576. 60 3455.30 -3991 .88 1834.54 5942079 .96 560627.14 MWD+IFR-AK-CAZ-SC 8544.70 92.47 185 .22 3575. 15 3453.85 -4048 .70 1829.47 5942023 .11 560622.52 MWD+IFR-AK-CAZ-SC 8579.69 90.84 182 .85 3574. 14 3452.84 -4083 .58 1827.00 5941988. 21 560620.33 MWD+IFR-AK-CAZ-SC 8628.68 88.53 180 .78 3574. 41 3453.11 -4132 .54 1825.45 5941939. 25 560619.16 MWD+IFR-AK-CAZ-SC 8674.84 87.59 181 .28 3575. 98 3454.68 -4178 .67 1824.62 5941893. 12 560618.69 MWD+IFR-AK-CAZ-SC 8723.13 88.14 181 .13 3577. 77 3456.47 -4226 .91 1823.61 5941844. 87 560618.05 MWD+IFR-AK-CAZ-SC 8768.72 88.84 180 .97 3578. 98 3457.68 -4272 .48 1822.77 5941799. 31 560617.57 MWD+IFR-AK-CAZ-SC 8816.73 87.28 179. 75 3580. 60 3459.30 -4320 .46 1822.47 5941751. 33 560617.65 MWD+IFR-AK-CAZ-SC 8862.02 86.17 177 .72 3583. 19 3461.89 -4365 .66 1823.47 5941706. 14 560619.00 MWD+IFR-AK-CAZ-SC 8908.89 86.29 177 .82 3586. 27 3464.97 -4412 .39 1825.29 5941659. 43 560621.18 MWD+IFR-AK-CAZ-SC ~ ~Ialliburton Company ~, Survey Report Company : ConocoPhiltipsAlaska Inc. Date: 10/16/2006 'l'ime: 15:46:05 Page: 4 Field: Kuparuk RiverUni t Co-or dinate ('VE) Reference: Well: 1J-10 2, True North Site: Kuparuk 1J Pad Vertical (TVD)'Reference: 1J-102L1: 121.3 Well: 1J -102 Sectio n (VS) Reference: Well (O.OON;QOOE,180.OOAzi) ~Vellpath: 1J -102L1 Survey Calcnlation Method: Minimum C urvat ure Dh: Oracle Survey _- _ _ ', J1D lncl Azim "TVD SysTVD N/S _ E/1V MapN MapE Tool ', ft deg deg ft ft ft ft ft ft 8955 .17 87.29 178 .26 3588. 86 3467.56 -4458 .57 1826. 87 5941613 .27 560623 .12 MWD+IFR-AK-CAZ-SC 9002 .91 88.64 176 .55 3590. 56 3469.26 -4506 .23 1829. 03 5941565 .63 560625 .65 MWD+IFR-AK-CAZ-SC 9049 .06 89.01 175 .34 3591. 50 3470.20 -4552 .25 1832. 29 5941519. 64 560629. 28 I MWD+IFR-AK-CAZ-SC 9096 .46 90.61 175 .47 3591. 66 3470.36 -4599 .50 1836. 09 5941472 .43 560633. 44 MWD+IFR-AK-CAZ-SC 9140 .86 90.64 174 .87 3591. 18 3469.88 -4643 .74 1839. 83 5941428 .23 560637. 52 MWD+IFR-AK-CAZ-SC 9193 .51 91.05 174 .59 3590. 40 3469.10 -4696 .16 1844. 66 5941375. 85 560642. 77 MWD+IFR-AK-CAZ-SC 9236 .87 90.27 176 .59 3589. 90 3468.60 -4739 .39 1848. 00 5941332. 65 560646. 44 MWD+IFR-AK-CAZ-SC 9328 .50 88.29 179 .85 3591. 05 3469.75 -4830 .95 1850. 84 5941241. 13 560650. 00 I MWD+IFR-AK-CAZ-SC 9424 .34 90.18 180 .67 3592. 33 3471.03 -4926 .77 1850. 41 5941145. 31 560650. 31 MWD+IFR-AK-CAZ-SC 9517 .70 90.80 179 .83 3591. 53 3470.23 -5020 .13 1850. 00 5941051. 96 560650. 63 MWD+IFR-AK-CAZ-SC 9567 .14 91.85 179 .88 3590. 39 3469.09 -5069 .55 1850. 13 5941002. 55 560651. 14 MWD+IFR-AK-CAZ-SC 9612 .38 91.59 179 .75 3589. 03 3467.73 -5114 .77 1850. 27 5940957. 33 560651. 64 MWD+IFR-AK-CAZ-SC ~ 9706 .43 90.97 181 .58 3586. 93 3465.63 -5208 .79 1849. 18 5940863. 32 560651. 28 MWD+IFR-AK-CAZ-SC 9794 .20 89.50 180 .11 3586. 57 3465.27 -5296 .54 1847. 89 5940775. 57 560650. 67 MWD+IFR-AK-CAZ-SC 9812 .24 88.28 180 .60 3586. 92 3465.62 -5314 .58 1847. 78 5940757. 53 560650. 70 MWD+IFR-AK-CAZ-SC 9906 .97 87.24 180 .00 3590. 62 3469.32 -5409 .23 1847. 28 5940662. 89 560650. 95 MWD+IFR-AK-CAZ-SC 9999 .87 88.99 179 .10 3593. 68 3472.38 -5502 .08 1848. 01 5940570. 06 560652. 40 MWD+IFR-AK-CAZ-SC 10093 .48 88.73 176 .43 3595. 54 3474.24 -5595 .59 1851. 66 5940476 .59 560656 .78 MWD+IFR-AK-CAZ-SC 10187 .31 86.31 177 .41 3599. 60 3478.30 -5689 .19 1856. 70 5940383. 04 560662. 55 MWD+IFR-AK-CAZ-SC I 10280 .20 86.01 181 .32 3605. 82 3484.52 -5781 .84 1857. 72 5940290. 40 560664 .30 MWD+IFR-AK-CAZ-SC 10373 .50 87.75 181 .53 3610. 90 3489.60 -5874 .97 1855. 41 5940197 .27 560662 .71 MWD+IFR-AK-CAZ-SC 10466 .42 91.10 180 .78 3611. 84 3490.54 -5967 .86 1853. 53 5940104. 38 560661 .56 MWD+IFR-AK-CAZ-SC 10559 .17 89.09 180 .02 3611. 68 3490.38 -6060 .60 1852. 89 5940011. 65 560661 .64 MWD+IFR-AK-CAZ-SC 10652 .07 91.15 180 .18 3611. 49 3490.19 -6153 .49 1852. 72 5939918. 76 560662 .20 MWD+IFR-AK-CAZ-SC 10743 .74 94.63 182 .55 3606. 87 3485.57 -6245 .00 1850. 55 5939827. 25 560660. 74 MWD+IFR-AK-CAZ-SC 10840 .67 93.23 178 .66 3600. 22 3478.92 -6341 .68 1849. 53 5939730. 58 560660. 47 MWD+IFR-AK-CAZ-SC ~ 10934 .25 92.18 180 .08 3595. 80 3474.50 -6435 .14 1850. 56 5939637. 13 560662 .23 MWD+IFR-AK-CAZ-SC 11025 .16 90.51 181 .36 3593. 67 3472.37 -6526 .01 1849. 41 5939546. 26 560661. 80 MWD+IFR-AK-CAZ-SC 11120 .16 93.44 183 .82 3590. 39 3469.09 -6620 .84 1845. 13 5939451. 41 560658. 25 MWD+IFR-AK-CAZ-SC 11215 .61 90.63 184 .99 3587. 01 3465.71 -6715 .94 1837. 80 5939356. 27 560651. 66 MWD+IFR-AK-CAZ-SC 11309 .38 87.35 184 .68 3588. 66 3467.36 -6809 .35 1829. 90 5939262. 81 560644. 49 MWD+IFR-AK-CAZ-SC 11403 .60 86.38 179 .19 3593. 81 3472.51 -6903 .34 1826. 72 5939168. 81 560642. 05 MWD+IFR-AK-CAZ-SC 11493 .93 89.68 176 .36 3596. 92 3475.62 -6993 .52 1830. 23 5939078. 66 560646. 26 MWD+IFR-AK-CAZ-SC 11591 .66 91.89 175 .37 3595. 58 3474.28 -7090 .98 1837. 27 5938981. 27 560654. 06 MWD+IFR-AK-CAZ-SC 11686 11780 .43 .31 91.82 91.63 176 178 .70 .64 3592. 3589. 51 69 3471.21 3468.39 -7185 -7279 .47 .23 1843. 1847. 82 64 5938886. 5938793. 84 13 560661. 560665. 35 90 MWD+IFR-AK-CAZ-SC MWD+IFR-AK-CAZ-SC 11874 .01 92.63 181 .69 3586. 20 3464.90 -7372 .85 1847. 37 5938699. 52 560666. 36 MWD+IFR-AK-CAZ-SC 11965 .99 90.26 180 .89 3583. 88 3462.58 -7464 .77 1845. 30 5938607. 59 560665. 01 MWD+IFR-AK-CAZ-SC 12056 .83 88.72 177 .71 3584. 69 3463.39 -7555 .59 1846. 41 5938516. 80 560666. 82 MWD+IFR-AK-CAZ-SC 12148 .86 91.34 177 .58 3584. 65 3463.35 -7647 .53 1850. 19 5938424. 89 560671. 32 MWD+IFR-AK-CAZ-SC 12242 .00 91.34 177 .58 3582. 47 3461.17 -7740 .56 1854. 12 5938331. 90 560675. 98 ~ PROJECTED to TD Time Logs Date From To Dtlr S. De th E. De th Phase Code: Subcode T COM 08/16/2006 06:00 12:00 6.00 MIRU MOVE MOB P Continue to move & spot pit complex. Level rig and pit complex. Lower stompers in cellar. Rig released to Summer Maintenance schedule @ 1200 HRS. 12:00 00:00 12.00 MIRU RIGMN RGRP P Summer Maintenance. Details in Non Well Activit re ort. 08/24!2006 18:00 00:00 6.00 MIRU WELCT NUND P Rig accepted @ 1800 HRS as per Doyon 15 Rig acceptance checklist. Nipple up diverter system & diverter lines, and check lock downs as per Vetco Rep. Install signs on location for rig on diverter. Check & trim all herculite. Pull hand tools, tongs, elevators and slips to rig floor. Load mud pits with 1 load of spud mud from plant. Load & strap 5" DP &HWDP into shed. Load BHA into pipe shed. Inspect & adjust brakes on draw works. 08/25/2006 00:00 02:30 2.50 MIRU DRILL RURD P Install signs on location for rig on diverter. Check & trim all herculite. Pull hand tools, tongs, elevators and slips to rig floor. Load mud pits with 1 load of spud mud from plant. Strap 5" DP & HWDP in shed. Load BHA into pipe shed. Inspect & adjust brakes on draw works. Install mouse hole in rotary table for ickin u DP. 02:30 03:00 0.50 MIRU DRILL SFTY P Held PJSM with entire crew and Varco representative. Discuss safety issues and procedure for picking up 5" DP and racking back same. Discuus training on new ST-80 Iron roughneck while PU DP. 03:00 06:00 3.00 MIRU DRILL PULD P Pickup 63 joints (21 stands) of 5" drill pipe from shed. Rack back in derrick. NOTE: Varco rep on rig floor training hands on operation of new ST-80 iron roughneck. Pick up 20 joints of 5" HWDP with 8" Drilling jars, and rack back in derrick. Crew Change. Note: Rig crews attending SIMS training @ KOC. 06:00 06:15 0.25 MIRU DRILL RURD P Calibrate Block Height for MWD. 06:15 07:00 0.75 MIRU DRILL PULD P Continue to pick up 5" HWDP and rack back stands in derrick. Total of 7 Stands. 07:00 08:45 1.75 MIRU DRILL RURD P Pull mouse hole from rotary table. Pick up 8" Dailey drilling jar, and make up to 5" HWDP double, rack in derrick. Ins ect saver sub. Page 2 of 69 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 08/25/2006 08:45 09:15 0.50 MIRU RIGMN RGRP P Clean & clear rig floor area. Rig up to change out saver sub on Top Drive. Held PJSM -discuss safety issues and procedure for changing out saver sub. Discuss hazards and record on HR card. 09:15 11:30 2.25 MIRU RIGMN RGRP P Change out saver sub on Top Drive. 11:30 12:00 0.50 MIRU DRILL OTHR P Pick up 1 stand of DP from derrick. RIH tag bottom @ 106' RKB, Indicating 14' of cement to drill. 12:00 12:30 0.50 MIRU WELCT BOPE P Function test 21 1/4" Diverter system. Check all lines & valves. Hydril closed in 33 seconds, Knife valve in 3 seconds. Accumulator system pressure = 2900 PSI. 5 bottle nitogen pressure avg = 2400 PSI. All gas alarms tested. Witness of test waived b Chuck Sheave with AOGCC. 12:30 13:15 0.75 MIRU WELCT BOPE P Perform Accumulator draw down test. Pressure from 2900 PSI, to 1600 PSI when closed. 33 seconds for 200 PSI increase with full Accumulator pressure back @ 2 minutes, 12 seconds. 13:15 14:00 0.75 MIRU WELCT BOPE P Flood all lines & diverter system. Perform surface equipment test on all equipment & lines to 2500 PSI. Low ressure test 500 PSI. 14:00 14:45 0.75 MIRU DRILL RURD P Held PJSM. Discuss safety issues and procedure for rigging up Halliburton Gyro survey unit. Spot & Rig up unit with sheaves to ri floor. 14:45 16:15 1.50 SURFA DRILL PULD P Make up BHA#1. 13 1/2" drilling assembly with 13 1/2" Hughes MX-1 PDC bit with 1 x 13, and 3 x 20 jets for a TFA of 1.050 Sq in" (1.70') SperryDrill Lobe 4/5 - 5.3 stage 28.85' & HWDP to s ud. 16:15 16:30 0.25 106 120 SURFA DRILL DRLG P RIH with drilling assembly. Tag and wash from 106' - 120' MD. Observe cement returns. 16:30 17:30 1.00 120 220 SURFA DRILL DDRL P Spud & directional drill 13 1/2" surface hole from 120' - 220' MD(100'). TVD = 220'. UP WT = 92K, SO WT = 80K, ROT WT = 80K. 50 RPM's. Pumps @ 450 GPM's - 700 PSI. 750 PSI on bottom. Max gas = 18.1 units. Bit Hrs _ .77, AST = .77 HRS. Total Jar Hrs = 74.45. Mud wt = 9.0 PPG, Visc = 320, YP = 63, Gels 39/59/67 17:30 18:00 0.50 220 30 SURFA DRILL TRIP P POOH with drilling assembly from 220' to 30' for make up of remaining BHA. Crew than e. 18:00 19:00 1.00 30 122 SURFA DRILL PULD P Pick up 3 Non Mag Flex drill collars. 92.03' from i r shed. Page 3 of 69 Time Logs -Date From To Dur ;5: De th E. De th Phase:• Code Subcode T COM 08/25/2006 19:00 00:00 5.00 220 570 SURFA DRILL DDRL P Continue driectional drill 13 1/2" surface hole from 220' - 570' MD(350'). TVD = 563'. UP WT = 108K, SO WT = 105K, ROT WT = 105K. WOB = 10-30K. 50 RPM's. Pumps @ 525 GPM's - 1250 PSI. 1300 PSI on bottom. Max gas = 0 units. Bit Hrs = 3.27, ADT = 2.50 Hrs, AST = 2.10 HRS. ART = .40 Total Jar Hrs = 76.95. Mud wt = 9.0 PPG, Visc = 320, YP = 63, Gels @ 39/59/67. Obtain Gyro surve s 121' and 220'. 08/26/2006 00:00 04:00 4.00 570 905 SURFA DRILL DDRL P Continue driectional drill 13 1/2" surface hole from 570' - 905' MD(335'). TVD = 874'. UP W T = 114K, SO WT 111 K, ROT WT = 11 OK. WOB = 10-20K. 90 RPM's. Pumps @ 700 GPM's - 1850 PSI. 1950 PSI on bottom. Max gas = 0 units. Bit Hrs = 5.52, ADT = 2.25 Hrs, AST = 2.00 HRS. ART = .25 Total Jar Hrs = 79.20. Mud wt = 9.4 PPG, Visc = 280, YP = 60, Gels 39/59/67. Crew Chan e 04:00 04:45 0.75 905 905 SURFA DRILL SRVY P Run Gyro surveys at depths of 220', 320', 420', 520', 620', 720', and 820'. WLOH & rig down Halliburton gyro unit. 04:45 06:00 1.25 905 1,041 SURFA DRILL DDRL P Continue driectional drill 13 1/2" surface hole from 905' - 1041 MD(136'). TVD = 1008'. UP WT = 122K, SO WT = 115K, ROT WT = 120K. WOB = 20-25K. 90 RPM's. Pumps @ 600 GPM's - 1700 PSI. 1800 PSI on bottom. Max gas = 10 units. Bit Hrs = 6.44, ADT = 3.17 Hrs, AST = 2.10 HRS. ART = 1.07 Total Jar Hrs = 80.12. Mud wt = 9.3 PPG, Visc = 300, YP = 63, Gels @ 39/59/67. Survey @ 964.72 MD, TVD - 936', INC = 24.49 De , AZ - 38.35 De .Crew Chan e 06:00 12:00 6.00 1,041 1,634 SURFA DRILL DDRL P Continue driectional drill 13 1/2" surface hole from 1041' - 1634' MD(593'). TVD = 1529'. UP WT = 142K, SO WT = 121 K, ROT WT = 130K. WOB = 20-30K. 90 RPM's. Pumps @ 650 GPM's - 1950 PSI. 2280 PSI on bottom. Max gas = 42 units. Bit Hrs = 10.06, ADT = 3.62 Hrs, AST = 2.24 HRS. ART = 1.38 Total Jar Hrs = 83.74. Mud wt = 9.3 PPG, Visc = 300, YP = 63, Gels @ 39/59/67. Survey @ 1631.24 MD, TVD - 1525.25', INC = 32.51 Deg, AZ - 50.90 De . Page 4 of 69 G.,,.,, r„ n~ ~~ c north G rlohth Phaco (:nria ~uhrnde T CC~M vac 08/26/2006 ~ ~vni 12:00 ~ v 18:00 ~..w 6.00 v..r ~.. .. ~ 1,634 ~...... .. ... 2,262 ............:. SURFA ......._ DRILL -__---- DDRL P - - Continue driectional drill 13 1/2" surface hole from 1634' - 2262' MD(628'). TVD = 1986'. UP WT = 146K, SO WT = 125K, ROT WT = 135K. WOB = 20-30K. 90 RPM's. Pumps @ 650 GPM's - 2000 PSI. 2350 PSI on bottom. Max gas = 42 units. Bit Hrs = 12.72, ADT = 2.66 Hrs, AST = 1.40 HRS. ART = 1.26 Total Jar Hrs = 86.40. Mud wt = 9.4 PPG, Visc = 300, YP = 63, Gels @ 39/59/67. Survey @ 2201.01 MD, TVD - 1945.75', INC = 47.60 Deg, AZ - 61.41 De .Crew Chan e 18:00 22:00 4.0~ 2,262 2,652 SURFA DRILL DDRL P Continue driectional drill 13 1/2" surface hole from 2262' - 2652' MD(390'). TVD = 2259'. UP WT = 160K, SO WT = 122K, ROT WT = 135K. WOB = 20-25K. 90 RPM's. Pumps @ 700 GPM's - 2350 PSI. 2500 PSI on bottom. Max gas = 40 units. Bit Hrs = 15.10, ADT = 2.38 Hrs, AST = 1.22 HRS. ART = 1.16 Total Jar Hrs = 88.78. Mud wt = 9.4 PPG, Visc = 300, YP = 63, Gels @ 39/59/67. Survey @ 2602.96 MD, TVD - 2226.01', INC = 43.39 Deg, AZ - 80.76 Deg. Obtain last survey on bottom. 22:00 00:00 2.00 2,652 1,965 SURFA DRILL REAM P BROOH from 2652' -1965' (687'). pumps @ 700 GPMs - 2300 PSI. 90 RPM's with 3-5K torque. Pull slow for 4 stands at 10 ft/ minute allowing for good bottoms up. Then increase pulling speed to 35 - 40 ft/minute. Decrease pump rates to 600 GPMs- 2000 PSI @ 2000'. Observe good hole conditions. 08/27/2006 00:00 02:00 2.00 1,965 791 SURFA DRILL REAM P Continue BROOH from 1965' - 791' {1174'). Pumps @ 500 GPMs - 1650 PSI. 90 RPM's with 3-5K torque. Pulling speed @ 45 - 50 ft/minute. Decrease pump rates to 500 GPMs- 1350 PSI @ 1300'. Observe good hole conditions. 02:00 02:15 0.25 791 791 SURFA DRILL PULD P Clean, breakout & lay down 13 1/2" Ghost reamer. 02:15 04:45 2.50 791 66 SURFA DRILL TRIP P Continue POOH on elevators from 791' - 66' racking back 5" HWDP & drilling jars (655'), and laying down 3 - 8" Non Mag Flex drill collars (93.03'). Breakout & lay down 8" Non Mag UBHO sub (3.38'), and 8" Non mag Flaot Sub (2.41'). Observing good hole conditions with ro er hole fill. Page 5 of'69 Time Logs .._~_ c>..~__a.. -r rnnn -UdIC 08/27/2006 I-IVI11 04:45 IV 05:15 VW 0.50 v. vc ul 66 ~..~ 0 SURFA DRILL PULD P -- Continue POOH break out & lay down remaining BHA. Lay down 8" MPT w/ DIR (24.97'), 8" Non Mag pressure drop sub (2.03'), 8" Integral Blade Stabilizer (6.99'), *" SperyDrill Lobe 4/5 - 5.3 stg Mud motor (28.85'), and 13 1!2" Hughes MX-1 Bit. Inspect & gauge bit to 2/1/BT/I/E/1/16/ER/TD 05:15 05:45 0.50 0 0 SURFA DRILL PULD P Clean & clear Floor area. Lay down tools. 05:45 06:00 0.25 0 0 SURFA CASIN( RURD P Rig up to run 10 3/4 casing. Rig up to make dummy run with casing hanger & landin 'oint. Crew Chan e 06:00 08:00 2.00 0 0 SURFA CASIN( RURD P Continue rig up to run 10 3/4" casing strin .. 08:00 08:15 0.25 0 0 SURFA CASIN( SFTY P Held PJSM with crew &GBR casing service. Discuss Safety issues and rocedure for runnin 10 3/4" Casin . 08:15 12:00 3.75 0 1,250 SURFA CASINC RNCS P Make up 10 3/4" shoe joint with Weatherford Model 303 Sure Seal Float shoe (1.75'), and 2 joints 10 3/4 45.5# L80 casing (79.88') Weather Model 402 Sure Seal Float Collar (1.42'). Check floats -Good. Continue run 10 3/4" casing filling every joint with Franks fill up tool. Circulate 2 'oints down after eve 10 ran. 12:00 14:45 2.75 1,250 2,642 SURFA CASIN( RNCS P Continue run 10 3/4" casing filling every joint with Franks fill up tool. Circulate 2 joints down after every 10 ran. Circulate down joints # 63 & 64 (2514' - 2596'). Pick up landing joint with vetco Gray casing hanger. Change out anti rotation handling sub. Land 10 3/4" casing with hanger. Shoe de th = 2642.83' MD TVD = 2252'. 14:45 15:15 0.50 2,642 2,642 SURFA CEMEf~ RURD P Rig down GBR casing crew. Clean & clear floor of all running tools. Reci rocate casin strin . 15:15 16:15 1.00 2,642 2,642 SURFA CEME~ RURD P Rig up and install 10 3/4" cement head in landin 'oint. Ri u lines. 16:15 16:30 0.25 2,642 2,642 SURFA CEMEI~ CIRC P Break circulation @ 4 BPM- 130 PSI. UP WT = 190K, SO WT = 130K. Increase pump rate to 5 BPM - 190 PSI. Observed O ring failed in cement head. Shut down um s, land han er. 16:30 18:00 1.50 2,642 2,642 SURFA CEMEI~ RURD T Rig down cement head & change out O ring in cement head. Make up cement head & lines. Crew Chan e. Page 6 of 69 Time Logs -- r-...-., r.. n.~. ~+ n....+h G no.,+ti DF.oco f'r.rlc, ~iihrnr{a T C:(~M UcllC 08/27/2006 Plum 18:00 iu 20:00 vui 2.00 .~. vc ui 2,642 2,642 SURFA CEMEf~ - CIRC P -- Circulate & condition mud to pre cement properties of 9.6 PPG, Visc = 50, PV = 22, YP = 15, with Gels @ 6/8. Reciprocate casing string. UP WT = 195K, SO WT = 140K. Held PJSM with entire rig team, truck drivers and cement crew. Discuss safety issues, hazard recognition and procedure to rig u and um surface cement ~ob. . 20:00 22:30 2.50 2,642 2,642 SURFA CEME~ CIRC P Turn rig over to Dowell Schlumberger cement crew. Pump 5 BBIs fresh water to flush lines. Pressure test lines to 3500 PSI -good test. Pump 50 BBIs of 8.3 PPG CW100 @ 6 BPM - 150 PSI. Pump 50 BBLS of 10.5 PPG MudPush II with Red Dye @ 5 BPM - 180 PSI. Drop bottom plug. Continue pump 389.4 BBLS of 10.7 PPG Lead cement @ 6.2 BPM - 225 PSI. Stop movement of casing string, and land in hanger 320 BBLS into pumping Lead cement. Pump 76 BBLS of 12.0 PPG Tail cement @ 5.6 BPM - 275 PSI. Drop Top Plug. Pump 20 BBLS of fresh water for rinse & flush. Reciprocate casing string. UP WT = 220K, SO WT = 145K. 22:30 23:30 1.00 2,642 2,642 SURFA CEME~ DISP P Turn over to rig pumps. Displace cement job with 9.6 PPG mud, observing red dye to surface @ 125 strokes into displacement. Observe cement @ surface @ 1258 Strokes in to displacement. Pumps @ 7 BPM for 1175 stks. 6 BPM for 1380 stks, slowing to 5 BPM to 2148stks. Slow pumps to 3.5 BPM - 500 PSI to observe plugs bumped @ 2246 strokes, (226.17 BBLS). pressure to 1150 PSI. Hold pressure 5 minutes. Bleed pressure & check floats. Floats held. CIP @ 2300 HRS, Reciprocated csg 10'-15' until 66 bbls cement around shoe, then csg got tight and land same on hanger, Had 99.3 bbls good cement to surface. 23:30 00:00 0.50 2,642 0 SURFA CEMEf~ RURD P Rig down cement lines on rig floor. Rig down cement head, blow down all lines. Clean & flush all lines & valves & cement a ui ment. 08/28/2006 00:00 01:45 1.75 0 0 SURFA CEMEf~ RURD P Rig down cement head & lines. Flush Diverter riser & flow lines with rinsate from truck. Page 7 of S9 I ', i- '-.----._.'. r :.r..._ n r~_._aU, r_ n....ati nti.-...,, r~..,~., G~hnr.Ae T,...,: (`CIAA I uaic 08/28/2006 nivui. 01:45 ~~,.. 04:00 vw 2.25 .~. ~.., .... 0 ~....., .., 0 ~ ......,.. SURFA ......... WELCT .....__---.. NUND .. P ----- Nipple down Diverter system. Remove Riser, and nipple down lines outside. Rig down long bales on top drive. Lay down spiders. Rig off of Hi -Line power and on Cat power @ 0330 HRS, to remove all Diverter equipment, and install wellhead a ui ment. 04:00 06:00 ' 2.00 0 0 SURFA WELCT NUND P Continue nipple down Diverter system. Rinse Annular & lines with rinsate using vac truck. Remove Diverter system adapter flange as per Vetco Gray rep. SIMOPS: Work on Top drive Shot Pin assembly and Brake. Varco re on ri floor. 06:00 08:15 2.25 0 0 SURFA RPCOh NUND P Clean out cellar box, Install Vetco Gray well head as per rep. Rig up & test wellhead seal to 5000 PSI, for 15 minutes - ood test. C8:15 C8:45 0.50 0 0 SURFA l^!ELCT NUND P !nsta!! dcub!e block dri!!ing ~~alve for annular. 08:45 12:00 3.25 0 0 SURFA WELCT NUND P Held PJSM with crew. Discuss safety issues and procedure for nippling up BOP's. Nipple up BOP's .Crew Chan e 12:00 18:00 6.00 0 0 SURFA WELCT NUND P Held PJSM with crew. Discuss safety issues and procedure for nippling up BOP's. Continue Nipple up BOP's . Install Koomey lines, kill lines, and choke line. Install 3 1/2" VBR's in top set of rams, and 7 5/8" rams in lower set of rams. SIMOPS: Begin changing Saver sub on To Drive. 18:00 20:30 2.50 0 0 SURFA WELCT OTHR P Continue change out saver sub on Top Drive. Remove 4 1/2 IF sub, Install 4" XT39 sub. Load pipe shed with 120 'oints of 4" XT39 drill i e. Stra same. 20:30 00:00 3.50 0 0 SURFA DRILL PULD P Held PJSM with crew. Discuss safety issues and procedure for picking up 4" DP and building stands & racking in derrick. Pick up 40 joints of 4" DP from pipe shed. Note: New crew being trained on proper operation of new ST80 iron rou hneck. Crew Chan e 08/29/2006 00:00 04:00 4.00 0 0 SURFA DRILL PULD P Held PJSM with crew. Discuss safety issues and procedure for picking up 4" DP and building stands & racking in derr!ck. Pick up 80 joints of 4" DP from pipe shed. Crew Change Rabbit 4" w/ 2.33" rabbit. 04:00 06:00 2.00 0 0 SURFA WELCT BOPE P UD 4 stands of 5" HWDP. Rig up & test BOP's. Test 4-1/2" IF floor safety valve and dart valve to 250 psi low and 3000 si hi h. Hold each test 5 min. 06:00 08:00 2.00 0 0 SURFA WELCT NUND P PJSM, then PU and install riser, install flowline and ad'ust turnbuckles. 08:00 09:00 1.00 0 0 SURFA WELCT OTHR P RU to test BOPE. Fill stack w/ water. Page. 8 of B9 Time Lo s Date From - To Dur S. De th E. De th Phase Code ' Subcode T COM 08/29/2006 09:00 16:15 7.25 0 0 SURFA WELCT BOPE P Test ROPE to 250 psi low and 3000 psi high. Tested bottom pipe rams w/ 7-5/8" test jt. Test upper pipe rams (3-1/2" x 6") w/ 4" dp & 5" dp. Test annular w/ 4" dp. Tested all valves on choke manifold and kill and choke valves. Tested top drive IBOP. Witness of test waived by AOGCC inspector Chuck Sheave. 16:15 17:30 1.25 0 0 SURFA WELCT OTHR P Rig down testing equipment. Pull test plug. Install Vetco/Gray wear ring (10.75" OD x 9.9" ID, length 4.92'). Blow down choke manifold and till and choke lines. _._~ 17:30 17:45 0.25 0 SURFA DRILL SFTY P PJSM on PU/MU BHA #2. 17:45 20:45 3.00 0 446 SURFA DRILL PULD P PU/MU BHA #2 to 446'. MU Hughes 9-7/8" EP5848 bit w/ (3) 20/32 and (1) 12/32 iiuzzie, 7" Speriydrlii iGbe 7/8-6 stage motor w/ 1.5 deg bend, nm float sub, welded blade stabilizer, MWD DM HOC, MWD Gamma/Res/PWD, MWD TM HOC, (3) 6-7/8" NM drill collars, (3) 5" HWDP, Drilling jar (6.2" OD), (5) 5" HWDP. 20:45 21:45 1.00 446 2,452 SURFA DRILL TRIP P RIH w/ BHA #2 f/ 446' to 2452'. Total of 21 stands of Weatherford 5" dp in hole. Installed Ghost reamer on top of stand #4. 21:45 22:15 0.50 2,452 2,452 SURFA DRILL OTHR P Change elevators to 4". Install bell vide f/ 4" d on to drive. 22:15 23:00 0.75 2,452 2,548 SURFA DRILL CIRC P Make top drive connection on stand #22. Fill pipe. Circulate bottom's up. Pumping 140 spm w/ 1850 psi. Pump 2200 strokes. Rotate 50 rpm w/ 5-6k ft Ibs for ue. Shallow test MWD. 23:00 23:45 0.75 2,548 2,548 SURFA DRILL DHEO P Test 10-3/4" 45.5 ppf, L-80 BTC to 3000 si. Chart test and hold f/ 30 min. 23:45 00:00 0.25 2,548 2,559 SURFA CEMEI~ CIRC P MU top drive to stand #23. Establish circulation. PU wt 145k, SO wt 110k, Rot wt 128k. Rotate 50 rpm w/ 5-6k ft Ib torque, pumping 149 spm (633 gpm) w/ 1970 psi off bottom, 2040 psi on bottom. Prepare to drill wiper plugs and then float collar 2559.78' 08/30/2006 00:00 01:45 1.75 2,652 2,672 SURFA CEMEf~ DRLG P MU top drive to stand #23. Establish circulation. PU wt 145k, SO wt 110k, Rot wt 128k. Rotate 50 rpm w/ 5-6k ft Ib torque, pumping 149 spm (633 gpm) w/ 1970 psi off bottom, 2040 psi on bottom. Drill wiper plugs and then float collar @ 2559.78', cement, FS 2642', rat hole to 2652', then 20' new hole to 2672' (2276' TVD). Drill w/ 10k WOB. Bit hrs .12 hrs, jar hrs 39.08 hrs. Page 9 of 69 Time Logs n.... O n....ah C C1....ih oH..,~., f`.,.~lo G.~hnnrlo T ~CI~A U iilC 08/30/2006 rivni 01:45 ~v 02:15 vw 0.50 v.:vc u~ 2,672 ~.~ 2,672 SURFA CEMEf~ CIRC P -- Circulate and displace mud to new 9.0 ppg LSND. Circ BU after displacement.Pumping 150 spm (634 gpm) w/ 1660 psi. Baseline clean hole ECD is 9.27 02:15 02:45 0.50 2,672 2,645 SURFA CEMEf~ LOT P Stand back stand # 24 after drilling 27' to 2672'. Perform LOT w/ 9.1 ppg mud. 502 psi, csg shoe @ 2642' (2252' TVD). EMW = 13.4 PPG. Hrs on bit .12 hrs 02:45 03:00 0.25 2,645 2,645 INTRM1 DRILL OTHR P Bleed off pressure. Blow down top drive. Threads on saver sub are ailed. 03:00 06:00 3.00 2,645 2,672 INTRM1 DRILL OTHR T Change out saver sub on top drive. Check cor.nectiens which were screwed into. Replace top jt on stand #23, replace top and bottom jts of stand # 24. Corrected i e tall . 06:00 08:00 2.00 2,672 2,829 I INTRM1 DRILL DDRL P Drilling 9-7/8" intermediate from 2672' (2276' TVD) to 2829' (157`) (`L391` I VD) Bit hours= .99, Jar hours= 39.97, AST=.00 hrs, ART=.87 hrs, ADT=.87 hrs, WOB= 10-15k, 60-80 rpm, Mtr rpm 210-214, 636-650 gpm @ 1750-1770 psi on bottom and 1700 psi off bottom. Torque = 5k ft-Ibs on botttom and 4-5k ft-Ibs off bottom. ECD= 9.42 ppg. P/U = 140-145k, S/O = 115-120k, Rot= 130k w/ pump off. 08:00 09:00 1.00 2,829 2,829 INTRM1 DRILL OTHR T Trouble shoot surface equipment (Mud pump, etc.). Having problems getting detection f/ surveys. Clean suction screens on both mud pumps. Lower pressure in discharge pulsation dampners. SPR's: #1 @ 20 spm = 120 psi, 30 spm = 180 psi. #2 mp @ 20 s m = 120 si, 30 s m = 180 si. 09:00 09:15 0.25 2,829 2,829 INTRMI DRILL OTHR T Mode switch MWD tool. Appears to be workin . 09:15 12:00 2.75 2,829 3,160 INTRM1 DRILL DDRL P Drilling 9-7/8" intermediate from 2829' (2391' TVD) to 3160' (331') (2640' TVD) Bit hours= 2.94, Jar hours= 41.92, AST=.1.11 hrs, ART=..84 hrs, ADT= 1.95 hrs, WOB= 5-15k, 80 rpm, Mtr rpm 214, 650 gpm @ 1770-2000 psi on bottom and 1700-1950 psi off bottom. Torque = 4-5k ft-Ibs on botttom and 4-5k ft-Ibs off bottom. ECD= 9.4-9.5 ppg~. I'/U = 145-160k, S/O = 115-120k, Rot= 130-135k w/ um off. Page 10 of 69 'Time Lo s Date From To Dur S. ~De th E. De th Phase Code Subcode T COM 08/30/2006 12:00 18:00 6.00 3,160 3,888 INTRM1 DRILL DDRL P Drilling 9-7/8" intermediate from 3160' (2640' TVD) to 3888' (331') (3143' TVD) Bit hours= 6.62, Jar hours= 45.60, AST= 2.63 hrs, ART=1.05 hrs, ADT= 3.68 hrs, WO6= 10-15k, 80 rpm, Mtr rpm 205-214, 623-650 gpm @ 1970-2350 psi on bottom and 1940-2300 psi off bottom. Torque = 4-5k ft-Ibs on botttom and 4-5k ft-Ibs off bottom. ECD= 9.6-9.84 ppg. Gas units = 14. P/U = 155-160k, S/O = 120-125k, Rot= 135-140k w/ pump off. Pump 25 bbls hi vis sweep while drilling @3679' (3092' TVD), no noticable increase in cuttin s. 18:00 00:00 6.00 3,888 4,480 INTRM1 DRILL DDRL P Drilling 9-7/8" intermediate from 3888' (3143' TVD) to 4480' (592') (3457' TVD) Bit hours= 10.35, Jar hours= 49.33, AST= 2.41 hrs, ART=1.32 hrs, ADT= 3.73 hrs, WOB= 10-20k, 80 rpm, Mtr rpm 208-211, 636-640 gpm @ 2280-2590 psi on bottom and 2280-2390 psi off bottom. Torque = 4-6k ft-Ibs on botttom and 4-5k ft-Ibs off bottom. ECD= 9.84-9.97 ppg. Gas units = 14 P/U = 153-158k, S/O = 127-125k, Rot= 135-140k w/ pump off. SPR @ 4145' (3299' TVD) #1 mp @ 20 spm = 190 psi, 30 spm=250 psi, #2mp @ 20spm=190 psi, 30 spm=260 Pump 25 bbls hi vis sweep while drilling @ 4425' (3433' TVD), no noticable increase in cuttin s. 08/31/2006 00:00 06:00 6.00 4,480 4,892 INTRM1 DRILL DDRL P Drilling 9-7/8" intermediate from 4480' (3457' TVD) to 4892' (412') (3564' TVD) Bit hours= 14.6, Jar hours= 53.58, AST= 2.03 hrs, ART=2.22 hrs, ADT= 4.25 hrs, WOB= 10-22k, 80-90 rpm, Mtr rpm 208-211, 636-640 gpm @ 2590-2700 psi on bottom and 2400-2600 psi off bottom. Torque = 5-6k ft-Ibs on botttom and 4-5k ft-Ibs off bottom. ECD= 10.29-10.02 ppg. P/U = 160-155k, S/O = 125-122k, Rot= 140-135k w/ um off. 06:00 12:00 6.00 4,892 5,406 INTRM1 DRILL DDRL P Drilling 9-7/8" intermediate from 4892' (3564' TVD) to 5406' (514') (3660' TVD) Bit hours= 18.54, Jar hours= 57.52, AST= 1.39 hrs, ART=2.55 hrs, ADT= 3.94 hrs, WOB= 15-20k, 90 rpm, Mtr rpm 210-206, 636-625 gpm @ 2670-2480 psi on bottom and 2590-2200 psi off bottom. Torque = 4-7k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 9.87-9.79 ppg. Avg gas 100 units. P/U = 155k, S/O = 125-120k, Rot= 135k w/ um off. Page 11 of 69 '.7 .Time Lo s' Date From To Dur S; De th E. De th Phase Gode Subcode T GOM 08/31/2006 12:00 18:00 6.00 5,406 5,922 INTRM1 DRILL DDRL P Drilling 9-7/8" intermediate from 5406' (3660' TVD) to 5922' (516') (3742' TVD) Bit hours= 22.47, Jar hours= 61.45, AST= 1.02 hrs, ART=2.91 hrs, ADT= 3.93 hrs, WOB= 15-20k, 90 rpm, Mtr rpm 211-214, 642-650 gpm @ 2720-2800 psi on bottom and 2600-2710 psi off bottom. Torque = 4-7k ft-Ibs on botttom and 5-7k ft-Ibs off bottom. ECD= 9.80-10.4 ppg. Avg gas 30 units. P/U = 155-150k, S/O = 120-115k, Rot= 135k w/ um off. 18:00 18:15 0.25 5,922 5,926 INTRM1 DRILL DDRL P Drilling 9-7/8" intermediate from 5922' (3742'. TVD) to 592Fi' (4') (3742'. TVD) Bit hours= 22.50, Jar hours= 61.48, AST= .03 hrs, ART= O.Ohrs, ADT= .03 hrs, WOB= 15-20k, 90 rpm, Mtr rpm 214, 650 gpm @ 2800 psi on bottom and 2710 psi oir bottom. Torque = 4-7k ft-Ibs on botttom and 5-7k ft-Ibs off bottom. ECD= 10.4 ppg. P/U = 155k, S/O = 115k, Rot= 135k w/ um off. 18:15 19:00 0.75 5,926 5,833 INTRM1 DRILL CIRC P Set back a stand. SPR's and Pump Hi vis weighted sweep (10 ppg, 250 vis), while backreaming slow f/ 5926' to 5833'. Pumping 650 gpm w/ 2800 psi, rotating 90 rpm w/ 7k ft Ib torque. No noticable increase in cuttin s. 19:00 00:00 5.00 5,833 3,390 INTRM1 DRILL REAM P Continue backreaming out of hole f/ 5833' to 3390. Pumping 650 gpm w/ 2800- 2200 psi. ECD's 11.01 max. ECD's @ 3390' 10.44 ppg. Pulling @ 40-45 ft/min. 09/01/2006 00:00 00:30 0.50 3,390 3,000 INTRM1 DRILL REAM P Continue backreaming out of hole f/3390 to 3000'. Pumping 650 gpm w/ 2200-1800 psi. ECD's 10.44 max. Pullin 40-45 ft/min. 00:30 01:30 1.00 3,000 2,800 INTRM1 DRILL REAM P Hole unloading lots of clay. Continue backreaming out of hole f/3000' to 2800'. Pumping 650 gpm w/ 1800 psi. ECD's 10.44 max. Slowed pulling s eed to 15 ft/min. 01:30 02:15 0.75 2,800 2,520 INTRM1 DRILL REAM P Continue backreaming out of hole f/2800' to 2520'. Pumping 650 gpm w/ 1800- 1600 psi. ECD's 10.44 to 9.8 ppg. Increased pulling speed to 35-45 ft/min. 02:15 03:30 1.25 2,520 2,520 iNTRM1 DRILL CIRC P Circ to clean up iiiud in casing. Initial ECD's 9.8 ppg, final 9.32 ppg. Circ @ 650 gpm w/ 1600 psi while working pipe. Rotating 60 rpm. Circ 9.7 ppg 245vis sweep, follow till mud in good shape to run casing. Final MW 9.0= in and out. 03:30 04:00 0.50 2,520 2,520 INTRM1 DRILL OWFF P Monitor well. OK. Pump dryjob, blow down to drive. Page 12 of 69 Time Lo s Date From To Dur S. De th E. De th . Phase Code. Subcode T COM 09/01/2006 04:00 04:15 0.25 2,520 2,454 INTRM1 DRILL TRIP P Pull and stand back last stand of 4" dp, remove crossover. Change elevators to 5" 04:15 05:30 1.25 2,454 450 INTRM1 DRILL TRIP P POOH/stand back 5" dp f/ 2454' to 450'. La ed down 9-7/8" host reamer. 05:30 06:00 0.50 450 80 INTRM1 DRILL TRIP P Stand back 3 stands of 5" HWDP w/ "ars.. L/D Flex dc's. 06:00 06:45 0.75 80 80 INTRM1 DRILL OTHR P Download Sperry Sun MWD. 06:45 08:00 1.25 80 0 INTRM1 DRILL PULD P Finish L/D BHA #2. 08:00 09:00 1.00 0 0 INTRM1 DRILL OTHR P Rig up and pull wear bushing. 09:00 09:15 0.25 0 C INTRM1 CASIN( SFTY P PJSM on rigging up to run 7-5/8" intermediate casin . 09:15 10:45 1.50 0 0 INTRM1 CASIN( RURD P Rig up to run 7-5/8" casing w/GBR casin tools and Frank's fillu tool. 10:45 11:00 0.25 0 0 INTRM1 CASIN( SFTY P PJSM on running 7-5/8", 29.7 ppf, L-80 BTC casing w/ rig crew and GBR casin crew. 11:00 15:30 4.50 0 2,640 INTRM1 CASIN( RNCS P Run 7-5/8" casing: MU Weatherford model 303 float shoe, 2 jts , Weatherford model 402 float collar, 18 jts, One joint f/ "B" sand window, 6 jts, a 20' pup, one jt f/ "D" sand window, then to jt # 62 in hole to 2640'. Ran tandem rise(TR2) centralizers 3/2 jts on first 30 jts. Then run TR2 centralizers on collars of #31 to #54. Ran total of 62 tandem rise and 28 sto s. 15:30 15:45 0.25 2,640 2,640 INTRM1 CASIN( CIRC P Circ BU (101 bbls) @ 2645' (inside 10-3/4" casing). Circ 4-6 bpm w/ 230-330 si. 15:45 19:30 3.75 2,640 5,890 INTRM1 CASIN( RNCS P Continue running 7-5/8" 29.7 ppf L-80 BTC-mod casing f/ 2640' to 4750' (jt # 111), break circ, run casing f/ 4750' to 5115' (jt # 120), break circ, run casing f/ 5115' to 5840' (jt # 137, break circ, run casin f/ 5840' to 5890' 't # 138 . 19:30 19:45 0.25 5,890 5,926 INTRM1 CASIN( RNCS P MU Jt # 139, circulate jt down to 5926'. 19:45 20:30 0.75 5,926 5,926 INTRM1 CEME~ RURD P Remove Frank's fillup tool, blow down to drive, install Dowell cement head. 20:30 22:45 2.25 5,926 5,926 INTRM1 CEMEt~ CIRC P Circulate prior to cementing. Circulate @ 6 bpm w/ 380 psi. PU wt 200k and SO wt 140k after circ. Circulated total of 740 bbls prior to cementing. Held PJSM w/ cementing crew and APC truck drivers while circulating. Mud properties before : 8.9ppg, 44 vis, 9/17 PV/YP. Mud properties after conditioning : 8.9ppg, 40 vis, 9/15 PV/YP. Reci i e 5' er min, 30' stroke. Page 13 of 69 t tme ~a s Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/01/2006 22:45 00:00 1.25 5,926 5,926 INTRM1 CEMEf~ OTHR P Dowell, pump 10 bbls CW100, test lines to 3500 psi, pump @ 5 bpm w/ 220- 330 psi (40 bbls CW100), mix and pump @ 5 bpm w/ 320-220 psi (72.6 bbls MudPush II) @ 11.0 ppg, drop bottom plug, mix and pump @ 4.4 bpm w/ 235-100 psi (138.9 bbls DeepCrete) @ 12.5 ppg, drop top plug, Dowell kick out plug w/ 5 bbl water. Reci i e 5'/min, 30' stroke. 09/02/2006 00:00 00:45 0.75 5,926 5,920 INTRM1 CEMEf~ DISP P Displace cement with rig pumping 8.9ppg OBM @ 6 bpm until last 9 bbls then slow down to 3 bpm. Initial pressure 100_psi, final @ 3bpm was 850 psi. Bump plug @ calc strokes (2602) w/ 1400 psi. CIP @ 0045 hrs 9/2/2006. Continue recip 7-5/8" casing 5'/min 30' stroke while dispiacii g ceme~ t w/ OBM. Recip until last 25 bbls pumped. Final PU wt 170k, SO wt 100-110k. Float shoe 5920'. 00:45 02:15 1.50 5,920 5,920 INTRM1 CEMEf~ RURD P Bleed off pressure, check floats, OK. Blow down cement line. hang cement hose in derrick. Remove Dowell cement head. Drain stack. Vacum out landin 't. 02:15 02:30 0.25 5,920 5,920 INTRMI DRILL OTHR P PJSM on picking up stack and setting slips w/ Vetco Gray and Tourpusher and crew. 02:30 03:00 0.50 5,920 5,920 INTRM1 WELCT NUND P Break Vetco Gray multibowl, PU BOP stack. 03:00 04:30 1.50 5,920 5,920 INTRMI WELCT OTHR P Install Vetco Gray 7-5/8" slips. Slack off on slips w/ 180k on weight indicator. Blocks = 70k. Cut off 7-5/8" casing. dress cut on jt # 138. Lay down landin 't w/ 11' cutoff f/ 't # 138. 04:30 05:00 0.50 5,920 5,920 INTRMI WELCT OTHR P Install Vetco Gray packoff. Tighten lockdown screws to 580 ft lbs. 05:00 06:15 1.25 0 0 INTRM1 WELCT NUND P Set BOP's and Vetco Gray multibowl back down. Tighten break on multibowl. 06:15 06:45 0.50 0 0 INTRM1 WELCT BOPE P Testing 7-5/8" packoff and break on Vetco/Gray Multibowl to 250 psi low and 3850 si hi h f/ 10 min each. OK. 06:45 08:45 2.00 0 0 INTRM1 DRILL LOT P Continue laying down casing tools. RU & perForm LOT on 10-3/4" x 7-5/8" Annulus. EMW of fluid in annulus is 9.7 ppg (11.Oppg mudpush li and 8.36ppg CW100, 9.0 ppg mud). 200 psi @ TVD of 2252' at the 10-3/4" casing shoe = 11.4 ppg EMW. After test, pump 30 bbls fresh water to flush annulus of ossible cement. 08:45 09:15 0.50 0 0 INTRMI DRILL OTHR P Install Vetco Gray wear bushing. 10.5" OD, 6-7/8" ID x 3.45" Ion . Page 14 of 69 • .Time Logs Date From To Dur S. be th E.; De th Phase Code Subcode T COM 09/02/2006 09:15 10:00 0.75 0 0 INTRM1 WELCT NUND P Nipple up flowline, install and tighten turnbuckles on BOP stack. 10:00 10:15 0.25 0 0 INTRM1 DRILL SFTY P PJSM on picking up Weatherford 4" drill pipe w/ Western Well Tools super sliders from i e shed. 10:15 11:15 1.00 0 0 INTRM1 DRILL PULD P PU/MU/RIH Weatherford 4" drill pipe w/ Western Well Tools super sliders. Flush 10-3/4" x 7-5/8" annulus w/ 120 bbls water 2.5 b m w/ 670 si. 11:15 13:00 1.75 0 0 INTRM1 DRILL PULD P PU/MU/RIH Weatherford 4" drill pipe w/ Western Well Tools su er sliders. 13:00 16:15 3.25 0 3,720 INTRM1 DRILL PULD P Continue PU/MU/RIH Weatherford 4" drill pipe w/ Western Well Tools super siiders. Totai of 120 jts (40 stands) of 4" pipe w/super sliders picked up a rox 3720' 16:15 16:45 0.50 3,720 3,720 INTRM1 DRILL CIRC P Pump @ 4bpm w/ 360 psi to clean out drill pipe. Note: Little Red pumping 80 bbls of diesel into 10-3/4" x 7-5/8" annulus f/ freeze protection. Pressure test to 2500 psi. pump @ 2bpm w/ 1000 psi. Final ressure 750 si after um in . 16:45 18:00 1.25 3,720 2,883 INTRM1 DRILL TRIP P POOH wet w/ 4" drill pipe w/ super sliders, rack back on off driller's side of derrick. 9 stands out @ 1800 hrs, approx depth 2883'. All mud its are cleaned. 18:00 18:30 0.50 2,883 2,325 INTRM1 DRILL TRIP P Continue POOH wet w/ 4" dp w/super sliders f/ 2883' to 2325'. Rack on off driller's side. 18:30 19:00 0.50 2,325 2,325 INTRM1 DRILL CIRC P Crew change, pump dry job. Blow down to drive. 19:00 21:00 2.00 2,325 0 INTRM1 DRILL TRIP P Continue POOH wet w/ 4" dp w/super sliders f/ 2325' to all 40 stands out of hole. Rack on off driller's side. 21:00 23:15 2.25 0 0 INTRM1 DRILL OTHR P Getting 4" dp in pipe shed, strap and read to PU. 23:15 23:30 0.25 0 0 INTRM1 DRILL SFTY P PJSM on picking up 5" DC's and 4" HWDP to build H brids. 23:30 00:00 0.50 0 0 INTRM1 DRILL PULD P PU/MU Hybrids (2 jts of Weatherford (5" OD x 2/58" ID) DC's w/ jt of 4" HWDP on top). MU in mouse hole, stand back in derrick on driller's side. Rabbit w/ 2.33" OD rabbit. 4 stands of total of 15 to be picked up, in derrick midni ht. 09/03/2006 00:00 02:15 2.25 0 0 INTRM1 DRILL PULD P Continue PU/MU Hybrids (2 jts of Weatherford (5" OD x 2/58" ID) DC's w/jt of 4" HWDP on top). MU in mouse hole, stand back in derrick on driller's side and off driller's side. Rabbit w/ 2.33" OD rabbit. 10 stands on driller's side, 5 stands on off driller's side. Page 15 of 69 • Time. Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/03/2006 02:15 03:00 0.75 0 0 INTRM1 DRILL PULD P Pu/MU/ Standback in derrick 4 stands of Weatherford 4" HWDP. 03:00 04:45 1.75 0 126 INTRM1 DRILL PULD P PU/MU BHA # 3: Security 6-3/4" FMF 36412 bit w/ (3) 21/32's (TFA 1.015), SperrySun geoPilot 5200 (ser # TL019}, geoppilot flex collar, SperrySun 4-3/4" DIR, smart stab, gamma/res, pwd, tm hoc, nm flaot sub, welded blade stab, (1) 4-3/4" NM DC. to 126' 04:45 05:15 0.50 126 51 INTRM1 DRILL OTHR P Upload MWD tools. 05:15 06:00 0.75 51 285 INTRM1 DRILL PULD P Continue PU/MU BHA #3: PU (2) 4-3/4" nm DC's, x-e, (I) 4" HWDP, DNT 'ars, 1 4" HWDP to 285'. 06:00 06:15 0.25 285 285 INTRMI DRILL DHEO P Pulse test MWD tool. Pumping 300 gpm w/ 1300 psi. Break in seals on eoPilot. 06:15 12:00 5.75 285 3,752 INTRM1 DRILL PULD P PU/MU 111 jts of 4" dp f/ shed. Rabbit to 2.33". 12:00 13:15 1.25 3,752 4,409 INTRM1 DRILL PULD P Continue PU/MU BHA #3: DNT jars, then rest of 4" dp in pipe shed to 4409'. Back on Hi-Line ower 1300 hrs. 13:15 13:30 0.25 4,409 4,409 INTRM1 DRILL OTHR P Lower skate ramp on rig floor,remove thread protectors, clear and clean rig floor. 13:30 14:15 0.75 4,409 5,724 INTRMI DRILL TRIP P RIH f/ 4409' to 4771' (3547' TVD), fill pipe. Pumping 300 gpm w/ 2470 psi, 30 rpm, 3-4k ft Ib torque. Continue RIH to 5724' 3711' TVD . 14:15 15:45 1.50 5,724 5,800 INTRM1 DRILL CIRC P While CBU @ 300 gpm w/ 2850 psi, 50 r m, to ed strin ers 5800'. 15:45 16:00 0.25 5,800 5,800 INTRMI DRILL SFTY P PJSM on tripping in hole. 16:00 16:15 0.25 5,800 5,818 INTRM1 CEME~ COCF P MU stand, cleanout to 5818'. 16:15 17:00 0.75 5,818 5,818 INTRM1 RIGMN SFTY P PJSM on changing out drilling line. 17:00 21:45 4.75 5,818 5,818 INTRM1 RIGMN OTHR P Change out 1-3/8" drilling line. Install new line on drum. 21:45 22:15 0.50 5,818 5,818 INTRM1 RIGMN SVRG P Service top drive and drawworks. 22:15 22:45 0.50 5,818 5,818 INTRM1 RIGMN OTHR P Calibrate block height on TOTCO and Sperry Sun computers. TOTCO rep hel ed to ex lain rocedure. 22:45 23:45 1.00 5,818 5,818 INTRM1 CASIN( DHEQ P Test casing to 3000 psi f/ 30 min. Chart test. 23:45 00:00 0.25 5,818 5,832 INTRM1 DRILL CIRC P Establish circulation w/ 298 gpm, 2310 psi, rot 100 rpm w/ 3-4k ft Ib torque. PU wt 150, SO 115k, Rot 125k. Drill f/ 5818' to to of FC 5832'. 09/04/2006 00:00 02:15 2.25 5,832 5,926 INTRM1 CEMEf~ COCF P Drill FC @ 5832', cement, FS top @ 5918.5, rat hole to 5926'. 300- 325 gpm 2400-2650, rotate 100 rpm w/ 5k ft Ib for ue. Page 16 of 69 • Time Logs Date From To Dur 'S: De th E. De th Phase 'Code 5ubcode T COM 09/04/2006 02:15 02:30 0.25 5,926 5,946 INTRM1 DRILL DDRL P Drill 20' new hole f/ 5926' to 5946'. Drill w/ 4-6k wob, 300 gpm w/ 2800 psi, rotate 100 rpm w/ 4k ft Ib torque. ART = .10 hrs. Jar # 0043 = 84.67 hrs, Jars 0019 = 175.41 hrs 02:30 03:45 1.25 5,946 5,946 INTRM1 DRILL CIRC P Backream twice, then stand a stand back and finish circulating 480 bbls till hole clean (2BU+). Circ 309 gpm w/ 2400 psi, rotate 90 rpm w/ 3-4k ft Ib torque. Obtain baseline f/ ECD's/PWD. 9.75 w/ clean hole-8.8 mud 03:45 04:45 1.00 5,946 5,946 INTRM1 DRILL LOT P Perform LOT. Shoe @ 5920' (3741' TVD), 8.8 ppg mud wt, 1080 psi applied pressure =Leak off @ 14.4 04:45 06:00 1.25 5,946 6,035 PROD1 DRILL DDRL P Drilling 6-3/4" production A2 lateral f! 5946' (3744' TVD) to 6035' (89') (3750' TVD) Bit hours= .95, Jar (#141-0019) hours= 179.91, Jar (#1471-0043) hours = 89.17, Accelerators (#1447-1034) = 179.91 hrs, ART= 0.85hrs, WO6= 6-8k, 90 rpm, 310 gpm @ 2600 psi on bottom and 2400 psi off bottom. Torque = 5k ft-Ibs on botttom and 4k ft-Ibs off bottom. ECD= 9.67 ppg. P/U = 150k, S/O = 115k, Rot= 125k w/ um off. 06:00 12:00 6.00 6,035 6,751 PROD1 DRILL DDRL P Drilling 6-3/4" production A2 lateral f/ 6035' (3750' TVD) to 6751' (716') (3721' TVD) Bit hours= 5.45, Jar (#141-0019) hours= 170.76, Jar (#1471-0043) hours = 90.02, Accelerators (#1447-1034) = 180.76 hrs, ART= 4.5 hrs, WOB= 2-8k, 90-130 rpm, 310-347 gpm @ 2600-2880 psi on bottom and 2400-2800 psi off bottom. Torque = 5-7k ft-Ibs on botttom and 4-5k ft-Ibs off bottom. ECD= 9.67-10.25 ppg. P/U = 150-155k, S/O = 115-108k, Rot= 125k w/ um off. 12:00 18:00 6.00 6,751 7,403 PROD1 DRILL DDRL P Drilling 6-3/4" production A2 lateral f/ 6751' (3721' TVD) to 7403' (652') (3731' TVD) Bit hours= 10.12, Jar (#141-0019) hours= 185.43, Jar (#1471-0043) hours = 94.69, Accelerators (#1447-1034) = 185.43 hrs, ART= 4.67 hrs, WOB= 4-10k, 130 rpm, 347-350 gpm @ 2780-3000 psi on bottom and 27202950 psi off bottom. Torque = 5-6k ft-Ibs on botttom and 4-5k ft-Ibs off bottom. ECD= 10.16-10.3 ppg. P/U = 155-160k, S/O = 115-100k, Rot= 125-120k w/ um off. Page 17 of 69 Time Logs 09/04/2006 18 00 00:00 u 6.00 7,403 t1 7,979 ~~~ PROD1 DRILL DDRLVV P Drilling 6-3/4" production A2 lateral f/ 7403' (3731' TVD) to 7979' (576') (3724' TVD) Bit hours= 14.6, Jar (#141-0019) hours= 189.91, Jar (#1471-0043) hours = 99.17, Accelerators (#1447-1034) = 189.91 hrs, ART= 4.48 hrs, WOB= 2-10k, 130 rpm, 350 gpm @ 3000-3250 psi on bottom and 2950-3250 psi off bottom. Torque = 5-6k ft-Ibs on botttom and 4-5k ft-Ibs off bottom. ECD= 10.3-11.01 ppg. P/U = 155-160k, S/O = 100-95k, Rot= 125-122k w/ um off. 09/05/2006 00:00 01:15. 1.25 7,979 8,159 PROD1 DRILL DDRL P Drilling 6-3/4" production A2 lateral f/ 7979' (3724' TVD) to 8159' (180') (3731' TVD) Bit hours= 15.33, Jar (#141-0019) hours= 190.64, Jar (#1471-0043) hours = 99.9, Accelerators (#1447=1034) = 190.64 hrs, ART= .73 hrs, WO6= 2-10k, 130 rpm, 350 gpm @ 3250 psi on bottom and 3250 psi off bottom. Torque = 5-6k ft-Ibs on botttom and 4-5k ft-Ibs off bottom. ECD= 10.3-11.01 ppg. Avg gas 20 units.P/U = 155-160k, S/O = 100-95k, Rot= 125-122k w/ pump off. 01:15 01:30 0.25 8,159 8,159 PROD1 DRILL REAM T PJSM on backreaming out of hole f/ sidetrack. 01:30 02:30 1.00 8,159 7,780 PROD1 DRILL REAM T Backream out of hole f/ 8159' (3731' TVD) to 7780' (TVD= 3731') f/ sidetrack. Out of A2 sands. Pumping 350 gpm w/ 3200 psi, rotating 130 rpm w/ 4k ft Ib torque. PU wt 160k, SO wt 100k. Pulling speded 40-45 ft/min. ECD's were 11.01 ppg, final ECD's 10.48 02:30 06:15 3.75 7,780 7,675 PROD1 DRILL REAM T Troughing f/ openhole sidetrack @ 7780' 7800'. Pumping 350 psi w/ 3000 psi. Rotate 120 rpm w/ 5-6k ft Ib torque. ECD's 10.11 ppg. WOB 0-2k. Set back a stand. 06:15 08:30 2.25 7,675 7,710 PROD1 DRILL REAM T Trough f/ 7675' to 7710' (3734' TVD) f/ o en hole sidetrack. 08:30 10:30 2.00 7,710 7,757 PROD1 DRILL OTHR T Time drill f/ 7710' to 7757' (3733' TVD). 350 gpm w/ 3000 psi. Rotate 120 rpm w/ 5-6k ft Ib for ue. ECD's 1011 10:30 11:00 0.50 7,757 7,757 PROD1 DRILL OTHR T Lost Hi-line power. Start engines. Start shakers and air compressors. Start mud um s, re ain circulation. Page 18 of 69 Time Logs .. n n__a~, r_ n,._u., nom,.,.,. r..a.. 6~F,nnAo T !`CIAA Udle 09/05/2006 rlUlli 11:00 Iv 12:00 LJUI 1.00 .~. vc ui 7,757 ~-. ~. ur 7,825 n PROD1 DRILL OTHR T -- Drilling sidetrack hole 6-3/4" production A2 lateral f/ 7757' (3733' TVD) to 7825' (68') (3732' TVD) Bit hours= 18.12, Jar (#141-0019) hours= 193.43, Jar (#1471-0043) hours = 102.69, Accelerators (#1447-1034) _ 1193.43 hrs, ART= 2.79 hrs-- includes time drilling & troughing, WOB= 2-8k, 130 rpm, 350 gpm @ 3150-3250 psi on bottom and 3080-3170 psi off bottom. Torque = 5-6k ft-Ibs on botttom and 4-5k ft-ibs off bottom. ECD= 10.5-10.24 ppg. P/U = 160-162k, S/O = 95-105k, Rot= 125k w/ pump off. 12:00 13:00 1.00 7,825 8,159 PROD1 DRILL OTHR T Drilling sidetrack hole 6-3/4" production A2 lateral f/ 7825' (3732' TVD) to 8159' (334') (3741' TVD) Bit /~L.1 A ~ !1 L......r- hours=i9.i2, Jar~+ri~ri-v019 ~~~u~~- 194.43, Jar (#1471-0043) hours = 103.69, Accelerators (#1447-1034) _ 1194.43 hrs, ART= 1 hrs, WOB= 2-8k, 130 rpm, 350-310 gpm @ 3250-2800 psi on bottom and 3170-2710 psi off bottom. Torque = 5-6k ft-Ibs on botttom and 4-5k ft-Ibs off bottom. ECD= 10.3-9.98 ppg. P/U = 160k, S/O = 100k, Rot= 125k w/ um off. 13:00 17:30 4.50 8,159 8,401 PROD1 DRILL DDRL P Drilling 6-3/4" production A2 lateral f/ 8159' (3741' TVD) to 8401' (242') (3739' TVD) Bit hours= 21.88, Jar (#141-0019) hours= 197.19, Jar (#1471-0043) hours = 106.45, Accelerators (#1447-1034) = 1197.19 hrs, ART= 2.76 hrs, WO6= 8-14k, 130 rpm, 350 gpm @ 3400 psi on bottom and 3400 psi off bottom. Torque = 5-7k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 9.98-10.6 ppg. P/U = 160-165k, S/O = 100k, Rot= 125k w/ um off. 17:30 18:30 1.00 8,401 8,160 PROD1 DRILL TRIP T Geopilot is drilling left when it says it is drilling right. Pump out of hole f/ 8401' to 8160', taking check shot surveys. Pumping 340 gpm w/ 3000 si. PU wt 160k, SO wt 100k. 18:30 18:45 0.25 8,160 8,160 PROD1 DRILL SFTY T Elevators contacted platform (Diving board) @ derrick board. Picked board u 6-8". Checkout board. OK. 18:45 19:15 0.50 8,160 7,875 PROD1 DRILL TRIP T Continue pumping out f/ 8160' to 7875'. Pum in 340 m w/ 3000 si. 19:15 20:30 1.25 7,875 6,660 PROD1 DRILL TRIP T Pull out of hole on elevators f/ 7875' to 6660' wet while mixing a dry job. PU wt 165k, SO wt 109k. 20:30 21:00 0.50 6,660 6,660 PROD1 DRILL CIRC T Monitor well. Pump dry job, line up on tri tank. Check crown-o-matic. Page 19 of 59 Time Logs n r~_1_•~ r n..._~~. n~....,,. r,.d(, C~,Mn`a1o T !'.r1dA uaio 09/05/2006 r ivn i 21:00 i v 00:00 vw 3.00 v. v 6,660 1.,977 PROD1 DRILL --- TRIP T - - POOH f/ 6660' to 1977'. Record PU and SO wt's every 5 in open hole and every 10 stands in cased hole. PU wt 115k, SO wt 105k. 09/06/2006 00:00 01:00 1.00 1,977 348 PROD1 DRILL TRIP T POOH f/ 1977' to 348'. Record SO wt's eve 10 stands in cased hole. 01:00 01:45 0.75 348 92 PROD1 DRILL TRIP T Standback HWDP and BHA #3 to S er Sun MWD tools. 01:45 02:30 0.75 92 92 PROD1 DRILL OTHR T Plug in, download data f/MWD. Break bit. 02:30 04:00 1.50 92 0 PROD1 DRILL PULD T L/D Geopilot ser # TL019, PU GeoPilot # TL018, change out directional collar, MU new bit. 04:00 04:45 0.75 0 92 PROD1 DRILL OTHR T Upload Sperry Sun MWD tools. 04:45 05:15 0.50 92 348 PROD1 DRILL TRIP T RIH w/ BHA #4, f/ 92' to 348'. 05:15 09:30 4.25 348 5,900 PROD1 DRILL TRIP T Continue RIH w/ BHA #4 f/ 348' to 5900'. 09:30 10:00 0.50 5,900 5,900 PROD1 DRILL CIRC T Fill pipe. Circ 280 gpm (66 spm) w/ 2010 si. Pum ed 48 bbls. 10:00 10:15 0.25 5,900 5,900 PROD1 DRILL OTHR T Monitor well. Blow down top drive. 10:15 10:30 0.25 348 348 PROD1 DRILL OTHR T Shallow test MWD tools. Break in seals on geopilot. Send downlink to eo ilot. 10:30 13:00 2.50 5,900 5,900 PROD1 RIGMN SVRG P Change out saver sub on top drive. Service ri . 13:00 14:15 1.25 5,900 7,600 PROD1 DRILL TRIP T RIH w/ BHA #4 from 5900' to 7600'. 14:15 14:30 0.25 7,600 7,600 PROD1 DRILL CIRC T Fill pipe. Break circulation. 14:30 15:30 1.00 7,600 7,640 PROD1 DRILL DDRL T Trough for open hole sidetrack #2. Trough 7600' to 7640'. Pumping 350 gpm w/ 3100 psi. Rotate 130-150 rpm w/ 5k ft Ib for ue. 15:30 17:30 2.00 7,640 7,640 PROD1 DRILL DDRL T Attempt to sidetrack @ 7640'. Survey showed no sidetrack. Start over @ 7640' time drillin . 17:30 18:00 0.50 7,600 7,600 PROD1 DRILL CIRC T Time drill f/ 7600'. No detection w/ MWD while time drilling. Loss of pump pressure over time. Totco showed #2 mp --82 psm @ 1430 hrs= 3250 psi, @ 1800 hrs 2550 psi. Difference of 700 si. 18:00 19:00 1.00 7,600 7,600 PROD1 DRILL OTHR T Check pumps and surface equipment for loss of ressure. All OK. 19:00 22:15 3.25 7,600 3,784 PROD1 DRILL TRIP T POOH wet w/ BHA #4, looking for washout. Found washout in Daily DNT drilling jars (ser # 147-10019). Hole in bod 16.6' down f/ box. 22:15 00:00 1.75 3,784 3,784 PROD1 DRILL PULD T Lay down Daily DNT drilling jars (ser # 147-10019). Hole in body 16.6' down f/ box. Clean floor. PU/MU Daily jars (ser # 147-10005). Rabbit'ars to 1.62" Page 20 of 69 Time Logs LJcIICt 09/07/2006 f fV~ll 00:00 IV 00:30 CJU6. -: 0.50 V. vc w 3,784 vc iii 3,940 ~ PROD1 DRILL PULD T - Lay down Daily accelerators (ser # 1447-71034), PU Accelerators (ser # 1447-1003 w/ 77.54 hrs). Rabbit jars to 1.62" 00:30 01:00 0.50 3,940 3,940 PROD1 DRILL CIRC T Make up top drive, circ w/ # 1 mp @ 350 gpm (83 spm) w! 2500 psi 31% flow, #2 mp 350 gpm (83 spm) w/ 2600 pis 31% flow. Downlink, OK. MWD ood detection. 01:00 02:15 1.25 3,940 5,922 PROD1 DRILL TRIP T RIH w/ BHA #5 (number change after chan in out 'ars f/ 3940' to 5922'. 02:15 02:30 0.25 5,922 5,922 PROD1 DRILL CIRC T Fill pipe. Circ 82 spm w/ 2950 psi on Totco, 31 % flow. 02:30 03:30 1.00 5,922 7,600 PROD1 GRILL TRIP T RIH f/ 5922' to 7500'.Fill pipe. 03:30 05:30 2.00 7,600 7,646 PROD1 DRILL REAM T Time drill, 2 min per 1" f/ 7640' to 7644'., then 1 min per 1". f/ 7644' to 7646'. Toolface 145L, 80% deflection. 83 spm (350 gpm), w/ 3250 psi. Rotate 130 r m. PU wt 145k, SO wt 110k. 05:30 06:00 0.50 7,646 7,663 PROD1 DRILL REAM T Trying to sidetrack #2 f/ 7640', pumping 83 spm vv/ 3250 psi, 140 rpm, 80% deflection. 85 spm (358 gpm) w/ 3300 psi. WOB 2k. Rotate 130 rpm w/ 5k for ue. ECD's 10.32 06:00 06:30 0.50 7,663 7,690 PROD1 DRILL REAM T Drilling f/ 7663' to 7690', survey, no sidetrack. 85 spm (358 gpm w/ 3300 si. Rotate 130 r m w/ 5k ft Ib for ue. 06:30 08:45 2.25 7,600 7,640 PROD1 DRILL REAM T Troughing and time drill f/ 7600' to 7640. 350 gpm, 3250 psi. 130 rpm w/ 5k ft Ib torque. Sidetrack #2 7600' 3737' TVD . 08:45 12:00 3.25 7,640 7,970 PROD1 DRILL DDRL T Drilling 6-3/4" production (sidetrack #2) A2 lateral f/ 7640' (3737' TVD) to 7970' (330') (3736' TVD) Bit hours= 2.45, Jar (#141-0005) hours= 2.45, Jar (#1471-0043) hours = 108.9, Accelerators (#1447-1033) = 79.99 hrs, ART= 2.45 hrs, WOB= 2-6k, 105-130 rpm, 345-350 gpm @ 3000-3100 psi on bottom and 2880-3010 psi off bottom. Torque = 4-6k ft-Ibs on botttom and 4-5k ft-Ibs off bottom. ECD= 10.13-10.28 ppg. Avg gas 80 units.P/U = 150k, S/O = 100k, Rot= 125k w/ um off. Page 21 of 69 Time Logs uate 09/07/2006 rrvrn 12:00 r u 16:30 vw 4.50 o. uc ~~ ~ 7,970 `. ~c ~~ ~ 8,401 ~ ~ ~a~~ PROD1 ~~u4 DRILL DDRL T Drilling 6-3/4" production (sidetrack #2) A2 lateral f/ 7970' (3736' TVD) to 8401' (431'} (3734' TVD) Bit hours= 6.01, Jar (#141-0005) hours= 6.01, Jar (#1471-0043) hours = 112.46 Accelerators (#1447-1033) = 83.55 hrs, ART= 3.56 hrs, WOB= 2-8k, 110-130 rpm, 350 gpm @ 3020-3120 psi on bottom and 3050-2940 psi off bottom. Torque = 5-6k ft-Ibs on botttom and 4-6k ft-Ibs off bottom. ECD= 10.13-10.26 ppg. Avg gas 40 units.P/U = 155k, S/O = 95k, Rot= 125-120k w/ pump off. Started running Western Well Tools su er sliders 8162'. 16:30 18:00 1.50 8,401 8,508 PROD1 DRILL DDRL P Drilling 6-3/4" production A2 lateral f/ 8401' (3734' TVD) to 8508' (107') (3736' TVG) Bit i~ours= 7.03, Jar (#141-0005) hours= 7.03, Jar (#1471-0043) hours = 113.48 Accelerators (#1447-1033) _ 84.57 hrs, ART= 1.02 hrs, WOB= 2-8k, 110-130 rpm, 350 gpm @ 3020-3120 psi on bottom and 3050-2940 psi off bottom. Torque = 5-7k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 10.26-10.36 ppg. Avg gas 33 units.P/U = 155k, S/O = 95k, Rot= 125-120k w/ um off. 18:00 00:00 6.00 8,508 9,025 PROD1 DRILL DDRL P Drilling 6-3/4" production A2 lateral f/ 8508' (3736 TVD) to 9025(517') (3735' TVD) Bit hours= 11.42, Jar (#141-0005) hours= 11.42, Jar (#1471-0043) hours = 117.87 Accelerators (#1447-1033) = 88.96 hrs, ART= 4.39 hrs, WOB= 2-8k, 110-120 rpm, 350 gpm @ 3290-3450 psi on bottom and 3200-3450 psi off bottom. Torque = 5-7k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 10.26-10.95 ppg. Max gas 147 units.P/U = 155-165k, S/O = 95-100k, Rot= 125-120k w/ um off. Page 22 of 69 .Time Logs Ud[e 09/08/2006 rfU(It 00:00 i V 06:00 vui 6.00 o. vc ui 9,025 ~-. vc .n. 9,430 ~,a ~uo~ PROD1 ".~...., DRILL ~v~~~_~ DDRL P _._... Drilling 6-3/4" production A2 lateral f/ 9025' (3735 TVD) to 9430'(405') (3734.5' TVD) Bit hours= 16.15, Jar (#141-0005) hours= 16.15, Jar (#1471-0043) hours = 122.6 Accelerators (#1447-1033) = 93.69 hrs, ART= 4.73 hrs, WOB= 2-8k, 110 rpm, 350 gpm @ 3420-3450 psi on bottom and 3300-3400 psi off bottom. Torque = 5-6k ft-Ibs on botttom and 4-5k ft-Ibs off bottom. ECD= 10.92-11.01 ppg. Max gas 147 units.P/U = 165-170k, S/O = 95k, Rot= 120-122k w/ pump off. Pumped a 30 bbls hi vis sweep (225), while drillin 9401'- 9430'. 06:00 06:30 0.50 9,430 9,430 PROD1 DRILL CIRC P Finish circulating sweep out of hole. Slight increase in cuttings. Geoic~gist in town suggested to continue drilling f! 9430', down thru A2 sands. 06:30 10:30 4.00 9,430 9,846 PROD1 DRILL DDRL P Drilling 6-3/4" production A2 lateral f/ 9430' (3734.5 TVD) to 9846' (416') (3734.5' TVD) Bit hours= 19.28, Jar (#141-0005) hours= 19.28, Jar (#1471-0043) hours = 125.73 Accelerators (#1447-1033) = 96.82 hrs, ART= 3.13 hrs, WOB= 2-10k, 110-130 rpm, 345-350 gpm @ 3420-3980 psi on bottom and 3230-3840 psi off bottom. Torque = 5-7k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 11.01-11.68 ppg. Avg gas 30 units. P/U = 170-172k, S/O = 95k, Rot= 120k w/ pump off. Pumped 40 bbls hi weight- hi vis sweep (10.8 ppg, 225 vis) while drilling 9750'-9846. 10:30 11:15 0.75 9,846 9,846 PROD1 DRILL CIRC P Finish circulating sweep out of hole. Slight increase in cuttings. Survey @ 9753'. Geologist suggested pulling back and sidetrack well a ain +/- 9200'. 11:15 12:15 1.00 9,846 9,191 PROD1 DRILL TRIP T POOH f/ 9846' to 9191' to sidetrack well. 12:15 13:00 0.75 9,191 9,210 PROD1 DRILL REAM T Trough f/ 9191' to 9210' for sidetrack #3. 13:00 13:15 0.25 9,210 9,219 PROD1 DRILL DDRL T Time drill f/ 9210' to 9219'. Rotate w/ 130 rpm, 80% deflection, TF 160L. Pum in 350 m. 13:15 13:30 0.25 9,219 9,210 PROD1 DRILL DDRL T Pull back, check sidetrack w/ ABI on geopilot. OK. Sidetracked well @ 9210'. Page Z3 of 69 C~ .Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/08/2006 13:30 18:00 4.50 9,210 9,730 PROD1 DRILL DDRL T Drilling 6-3/4" production (Sidedtrack #3) A2 lateral f/ 9210' (3734.5 TVD) to 9730' (539') (3736' TVD) Bit hours= 22.88, Jar (#141-0005) hours= 22.88, Jar (#1471-0043) hours = 129.33 Accelerators (#1447-1033) = 100.42 hrs, ART= 3.60 hrs, WOB= 2-6k, 110 rpm, 331-350 gpm @ 3310-3700 psi on bottom and 3240-3600 psi off bottom. Torque = 6-7k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 10.32-11.08 ppg. Avg gas 30 units. P/U = 165-170k, S/O = 100-95k, Rot= 120k w/ um off. 18:00 22:45 4.75 9,846 10,337 PROD1 DRILL DDRL P Drilling 6-3/4" production (Sidetrack #3) A2 lateral f/ 9846' (3747' TVD) to 10337' (491') (3741' TVD) Bit hours= 26.83, Jar (#141-0005) hours= 26.83, Jar (#1471-^043) hours = 133.28 Accelerators (#1447-1033) = 104.37 hrs, ART= 3.23 hrs, WOB= 2-6k, 110 rpm, 350 gpm @ 3700-3870 psi on bottom and 3600-3780 psi off bottom. Torque = 6-7k ft-Ibs on botttom and 6k ft-Ibs off bottom. ECD= 11.15-11.2 ppg. P/U = 170k, S/O = 90-85k, Rot= 122-120k w/ um off. 22:45 00:00 1.25 9,730 9,846 PROD1 DRILL DDRL T Drilling 6-3/4" production (Sidetrack #3) A2 lateral f/ 9730' (3736' TVD) to 9846' (116') (3747' TVD) Bit hours= 23.6, Jar (#141-0005) hours= 23.6, Jar (#1471-0043) hours = 130.05 Accelerators (#1447-1033) = 101.14 hrs, ART= 1.37 hrs, WO6= 2-6k, 110 rpm, 344 gpm @ 3700 psi on bottom and 3600 psi off bottom. Torque = 6k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 11.08-11.15 ppg. P/U = 170k, S/O = 95-92k, Rot= 120-122k w/ um off. Page 24 of 69 • Time Logs c+ n.:'..a4. C n,...4~, oti., !'`..`le Ci iF.rnrlr~ T r:(lAA -ua~e 09/09/2006 r~wu 00:00 i v 06:00 uw 6.00 ". vc ~~~ 10,337 ~.c 10,877 PROD1 DRILL DDRL P - Drilling 6-3/4" production (Sidetrack #3) A2 lateral f/ 10337' (3741' TVD) to 10877' (540') (3733' TVD) Bit hours= 31.29, Jar (#141-0005) hours= 31.29, Jar (#1471-0043) hours = 137.74 Accelerators (#1447-1033) = 108.83 hrs, ART= 4.46 hrs, WOB= 2-8k, 110 rpm, 350 gpm @ 34150-3980 psi on bottom and 4050-3910 psi off bottom. Torque = 6-7k ft-Ibs on botttom and 6-7k ft-Ibs off bottom. ECD= 11.23-11.56 ppg. P/U = 173-190k, S/O = 85-78k, Rot= 122-120k w/ pump off. Pumped weighted hi vis sweep (10.8 ppg, 225 vis) while drilling @ 10,499'-1-590'. Slight increase in cuttin s returns. 06:00 07:15 1.25 10,877 i i,025 ~ FROD1 DRILL DDRL P Driiiing 6-3/4" productio~~ (Sidetrack #3) A2 lateral f/ 10877' (3733' TVD) to 11025' (148') (3779' TVD) Bit hours= 32.22, Jar (#141-0005) hours= 32.22, Jar (#1471-0043) hours = 138.67 Accelerators (#1447-1033) = 109.76 hrs, ART= .93 hrs, WOB= 4-7k, 110 rpm, 350 gpm @ 3980 psi on bottom and 3910 psi off bottom. Torque = 7k ft-Ibs on botttom and 6-7k ft-Ibs off bottom. ECD= 11.23-11.56 ppg. Avg gas 35 units. P/U = 190k, S/O = 78k, Rot= 120k w/ um off. 07:15 08:30 1.25 11,025 10,035 PROD1 DRILL TRIP P POOH f/ 11025' to 10035'. 08:30 12:00 3.50 10,033 8,724 PROD1 DRILL REAM P Backream out of hole f/ 10035' to shoe @ 8724'. Pumping 350 gpm w/ 3570 psi. Rotate @ 130 rpm w/ 7k torque. ECD's 10.83 12:00 18:00 6.00 8,724 5,817 PROD1 DRILL REAM P Continue backreaming out of hole f/ 8724' to shoe @ 5920', then to 5817'. Pumping 350 gpm w/ 2800 psi. Rotate @ 130 rpm w/ 6k torque. ECD's 9.89 ppg. Pulling speed 40-45 ft/min. Tight s of 10035'. 18:00 19:30 1.5Q 5,817 5,817 PROD1 DRILL CIRC P MU top drive, pump 40 bbls hi vis his wt sweep (10.8ppg, 200 vis). Recip 5817' to 5720'. Rotate 100 rpm w/ 6k ft Ib torque, pump 350 gpm w/ 2850 psi. Pump surface to surface. PU wt 140k, SO wt 119kahen 2 BU. 19:30 21:00 1.50 5,817 5,815 PROD1 RIGMN SVRG P Service top drive and traveling equipment, crown. Inspect top drive. Re air broken tie wire on swivel. 21:00 23:00 2.00 5,815 10,035 PROD1 DRILL TRIP P Trip in hole f/ 5815' to 10035' (3768' TVD). Fill pipe every 20 stands purring 5.5 bpm w/ 1700 psi. Record PU and SO wt's eve 5 stands in o en hole. Page Z5 of 69 ~~ Time Loos UdlC 09/09/2006 f IUUI 23:00 IV 00:00 vul 1.00 v. vc u., 10,035 vv ui 10,035 PROD1 DRILL CIRC P -- Establish circulation. Rotate @ 100 rpm w/ 6k ft Ib torque. Pumping 350 gpm w/ 3600 psi. Pump 40 bbls hi vis hi wt swee 10.8 , 200 vis . 09/10/2006 00:00 00:30 0.50 10,035 10,035 PROD1 DRILL CIRC P Establish circulation. Rotate @ 100 rpm w/ 6k ft Ib torque. Pumping 350 gpm w/ 3600 psi. Pump 40 bbls hi vis hi wt swee 10.8 , 200 vis). 00:30 00:45 0.25 10,035 10,035 PROD1 DRILL SFTY P PJSM on displacement f/ 8.8 ppg OBM to 8.7 ppg SFOBM. Continue circulating while conducting meeting. Total of 510 bbls um ed. 00:45 01:15 0.50 10,035 10,035 PROD1 DRILL CIRC P Displace 8.8ppg OBM w/ 8.7 ppg SFOBM. Pump 245 bbls, follcw w! 20 bbls dry job (10.8 ppg), then chase lines w/ 10 bbls. 01:15 01:45 0.50 10,035 10,035 PROD1 DRILL OWFF P Monitor well, OK. Blow down top drive. I PJSM on POOH to run 4-1/2" liner. Drop 2-5/16" hollow rabbit w/ 120' wire on stand #65. 01:45 06:00 4.25 10,035 2,147 PROD1 DRILL TRIP P POOH f/ 10035' (3668' TVD) to 2147'. PU and SO wt's @ 2147' : 107k up, 107k down. 06:00 08:15 2.25 2,147 92 PROD1 DRILL TRIP P Continue trip out w/ BHA #5 f/ 2147' to 92', to run 4-1/2" A2 liner. 08:15 09:00 0.75 92 92 PROD1 DRILL OTHR P Download Sperry Sun MWD tools. 09:00 10:15 1.25 92 0 PROD1 DRILL PULD P UD BHA #5. 10:15 11:00 0.75 0 0 COMPZ CASIN( OTHR P Clean and clear rig floor. RU to run 4-1/2" 11.6 ppg, L-80, BTC slotted and blank liner. 11:00 11:15 0.25 0 0 COMPZ CASIN( SFTY P PJSM on running 4-1/2" 11.6 ppf, L-80 BTC slotted/blank liner. 11:15 16:00 4.75 0 4,857 COMPZ CASIN( RNCS P RIH w/ 4-1/2" slotted liner per detail. Run 3-1/2" 9.3 ppf L-80 EUE 8rd (orange peeled end), x-o, x-o, 4-1/2" Easy Well Solutions Swell Packer, then 4-1/2" 11.6 ppf L-80 BTC slots and blanks. Run 31 slots (1309.01') and 83 blanks (3472.64'), 4-1/2" pup jt, x-o bushing, 190-47 casing seal bore extension to 4857' 16:00 16:30 0.50 4,857 4,857 COMPZ CASIN( RNCS P PU/MU Baker "HRD" ZXP liner top packer assembly. GBR casing tongs locked up and damaged Flex Lock liner hanger, while trying to torque to 7900 ft lbs. 16:30 17:30 1.00 4,857 4,857 COMPZ CASIN( OTHR T Remove GBR power tongs f/liner han er assembl . 17:30 18:00 0.50 4,857 4,857 COMPZ CASIN( OTHR T UD Baker liner hanger assembly to send to Deadhorse to have Flex-Lockliner han er than ed out. Page 26 of 69 Time Logs I ~ n r~__a~ c n,...aa.- nti,.,.,, r'+,..-~., ~ `:C~ ~hnn.~lo T ~`~IAA 'vdlC 09/10/2006 CWI1~ 18:00 Lu 21:15 vw 3.25 v. vc .~~... 4,857 4,857 COMPZ CASINC - - WOEQ T -- - Waiting on Baker hanger. Hanger sent to Baker Machine shop to remove Flex lock hanger and apply another. Clear and clean rig floor. RU GBR backu set of ton s. 21:15 21:30 0.25 4,857 4,857 COMPZ CASIN( OTHR T Load baker liner hanger assembly into i e shed. 21:30 22:00 0.50 4,890 4,890 COMPZ CASIN( RNCS T PU/ MU Baker hanger assembly to 7000 ft Ib torque. Check brass screws. RIH to 4890'. 22:00 22:45 0.75 4,890 4,890 COMPZ CASIN( OTHR P Mix gel (PAL Mix) to pour in liner top tie back extension. Allow el to set u . 22:45 23:00 0.25 4,890 4,900 COMPZ CASIN( OTHR P RIH w/ Baker liner hanger assembly to 4900'. Chan e elevators f/ 3-1/2" to 4". 23:00 00:00 1.00 4,900 5,920 COMPZ CASINC RUNL P RIH w/ 4-1/2" slotted/blank liner f/ 4900' to 5900'. Run on 4" dp w/super sliders. Run 11 stands till midnight. Record PUwt 128k, SO wt 105k, Roate wt 115k. Roate @ 25 rpm w/ 3-4k ft Ib torque. Circ 3 bpm w/ 250 psi w/18% flow. 09/11/2006 00:00 04:30 4.50 5,920 10,058 COMPZ CASIN( RUNL P RIH w/ 4-1/2" slotted/blank liner on 4" drill pipe f/ 5900' to 10058'. Run on 4" dp w/ super sliders. Run 36 stands total, then 4 stands 4" HWDP, then 15 stands hybrids [(2) 5" DC's w/ (1) 4" HWDP on top], then PU single HWDP. Record PU and SO wt's every 5 stands in open hole. Rabbit to 2.33" f/ 20th stand of super sliders to stand 36, then all 4 HWDP, 15 hybrids and single HWDP. Break circ every 20 stands. Circ @ 5900' 3 bpm w/ 250 psi. PU wt 128k, SO wt 105k. Rotate @ 20 rpm w/ 3-4k ft Ib torque. Rotating weight 115k. Circ @ 7700' 3 bpm w/ 350 si. PU wt 150k, SO wt 100k. 04:30 05:00 0.50 10,058 10,040 COMPZ CASIN( OTHR P Work liner f/ 10058 to 10030'. Record PU and SO wt's. Beginning PU wt 215k, SO wt 105k. After working twice the PU wt was 205k, SO wt 112k. Drop 1-3/4" ball and set pipe on depth w/top of liner @ 5149.6' and bottom of 3-1/2" shoe joint @ 10040.39' while circulating ball down @ 3 bpm w/ 500 si. 05:00 05:30 0.50 10,040 5,150 COMPZ CASIN( OTHR P Pressure up to 1600 psi, set down, Pick back up to mark, pressure to 2500 psi, slack off to 70k (top drive wt), liner set. Pressure to 3900 psi and release liner. PU 5', break off single. PU wt 180-185k. SO wt 142k. 05:30 05:45 0.25 5,150 5,150 COMPZ CASIN( DHEQ P Pressure test packer and annulus to 1000 si f/ 5 min. Chart test. 05:45 06:00 0.25 5,150 5,150 COMPZ CASIN( OTHR P Pick up, slack off to tag top of liner w/ do s. Page 27 of 69 Time Logs I.. .~ r r~., _a4, ri t....... real. 6~h.,nrlo T (~.~1hA. r:UBIe 09/11/2006 f IUIII 06:00 IU 06:45 IJUI. ~ 0.75 7. uc ul 5,150 ~. vc u~ 5,039 COMPZ CASIN( RUNL P Pull and set back a stand wet.to 5039'. 06:45 07:30 0.75 5,039 5,039 COMPZ CASIN( CIRC P Circulate bottoms up @ 5 bpm w/ 800 si. Pum ed 150 bbls. 07:30 08:00 0.50 5,039 4,946 COMPZ CASIN( RUNL P Pull and set back a stand wet.to 4946'. 08:00 08:30 0.50 4,946 4,946 COMPZ CASIN( CIRC P Pipe was pulling wet. Pumped 30 bbls dry job. Blow down top drive and kill line. 08:30 11:00 2.50 4,946 0 COMPZ CASIN( RUNL P Continue POOH w/ Baker liner running tool. Cleaning and inspecting 4" Western Well Toolssuper sliders on wa out. 11:00 11:45 C:75 0 0 COMPZ CASIN( OTHR P Break and lay down Baker liner runnin tool. 11:45 12:30 0.75 0 0 COMPZ CASIN( OTHR P Clear and clean rig floor after POOH w/ A2 liner runnin tools. 12:30 13:15 0.75 0 0 I COMPZ EVALVI~ SFTY P PJSM w/ Schlumberger wireline on RU and running USIT. Safety meeting w/ both ri crews. 13:15 14:30 1.25 0 0 COMPZ EVALV~ RURD P Rig up Schlumberger wireline. MU toolstrin .. 14:30 15:45 1.25 0 0 COMPZ EVALVI~ OTHR T RIH w/USIT and tractor to 200'. Trouble shoot problem w/ tools string. POOH change sub. RIH to 200'. Same roblem. POOH, chan e out SONDE. 15:45 17:15 1.50 0 5,120 COMPZ EVALV~ ELOG P RIH w/Schlumberger USIT and Schlumberger tractor. RIH to 4750', tractor f/ 4750' to 5120'. 17:15 18:45 1.50 5,120 0 COMPZ EVALV~ ELOG T Trouble w/USIT toolstring. Touble shoot problem. POOH to continue troubleshooting toolstring. Found bad telemet cartid a Brains . 18:45 19:30 0.75 0 5,120 COMPZ EVALV~ ELOG T RIH w/ Schlumberger USIT and tractor to 4850', tractor f/ 4850' to 5120'. 19:30 21:00 1.50 5,120 0 COMPZ EVALVI~ ELOG P Begin logging up. Logged to 2700'. POOH. Identified top of cement @ 2885'. Note: 10-3/4" shoe @ 2642.83'. TOC is 242.17' below 10-3/4" shoe. Well was flushed and freeze protected w/ 80 bbls diesel on 9/2/2006. 21:00 22:00 1.00 0 0 COMPZ EVALV~ RURD P Rig down Schlumberger wireline. 22:00 22:30 0.50 0 0 COMPZ WELCT OTHR P Pull Vetco gray wear bushing. 22:30 00:00 1.50 0 0 COMPZ WELCT BOPE P Set Vetco Gray test plug. PJSM. RU to test BOPE. 09/12/2006 00:00 06:30 6.50 0 0 COMPZ WELCT BOPE P Test BOPE (2 week test). Test witnessed by AOGCC inspector John Spaulding. Test all to 250 low f/ 5 min, then to 3000 si hi f/ 5 min. Chart test. 06:30 08:00 1.50 0 0 COMPZ WELCT OTHR P Rig down BOPE testing equipment. Pull test plug. Install Vetco Gray wear bushing.Blow down kill line, choke line, choke manifold and to drive. Page 28 of 69 Time Lo s Date From To` Dur S. De th E. De th Phase .Code Subcode T COM 09/12/2006 08:00 09:00 1.00 0 0 PROD2 FISH SFTY P PJSM on picking up BHA #6 (Whipstock f/ "B" lateral). Pull all tools to ri floor. 09:00 09:30 0.50 0 0 PROD2 FISH PULD P Breakout & lay down Smart Stabilizer & PWD assembl . 09:30 11:00 1.50 0 200 PROD2 FISH PULD P PU/MU BHA #6 (Whipstock & mills f/ 'B" lateral). Make up Baker Seal assembly w/ No-Go (1.92'), 4 3/4" Unloader Sub (5.18'), 2 -joints of 3 1!2" DP (62.30'), 3 1/2" Flex Joint (6.50'), Double Pin Crossover (2.28'), 7 5/8" Bottom Trip Anchor (3.23'), 3 1/2" Shear Disconnect (1.69'), 4 3/4" Drain Sub (1.49'), Debris Sub with Cup (2.0'), 7 5/8" Whipstock Slide (14.45'), 6.156" Starting Mill (1.08'), 6.313" Lower Mill (5.57'), 6 3/4" Upper watermelon mill (5.83'), 1 -joint 3 1/2" HWDP (29.80'), 4 3/4" Fioat sub 2.33`. 11:00 12:00 1.00 200 250 PROD2 FISH PULD P Make up 4 3/4" MWD assembly (46.02'). Orient MWD to whipstock face. Plug in and download MWD assembl . 12:00 13:30 1.50 250 250 PROD2 FISH PULD P Continue download & orient MWD to whipstock face. Observe bad Float in Float sub, Chan e out same. 13:30 14:00 0.50 250 485 PROD2 FISH PULD P Complete make up BHA with 4 3/4" Bumper Jar (7.73'), Crossover Sub (2.99'), and 3 -stands of Hybrid Drill Collars (278.43'). Total BHA = 485.03'. Total BHA after setting whipstock = 379.78'. 14:00 14:30 0.50 485 485 PROD2 FISH PULD P Make Top Drive connection .Rig up to perform Pulse test on MWD assembly. Pumps @ 300 GPM - 890 PSI. Good test. 14:30 18:00 3.50 485 3,477 PROD2 FISH TRIP P Trip in hole with BHA #6 at 3 -minutes / stand as per Baker Rep, and Co. Rep from 485' - 3477'. Fill Drill String every 25 stands. Crew Chan e. Page 29 of 69 >Time Lo s Date From To Dur S. De th E: De th Phase Code Subcode T COM 09/12/2006 18:00 21:30 3.50 3,477 5,149 PROD2 FISH TRIP P Continue trip in hole with BHA #6 at 3 - minutes /stand as per Baker Rep, and Co. Rep from 3477' - 5149'. Fill Drill String every 25 stands. Perform MAd PAss survey as per Geo from 4320' - 4380' MD, with pumps @ 295 GPM's - 1675 PSI. Pick up 1 single of drill pipe for setting whipstock. Make TD connection and orient whipstock face @ 14 Deg Left of High Side as per DD, and Co. Rep. Pumps @ 300 GPM's - 1680 PSI. UP WT = 170K, SO WT = 139K. Locate top of A lateral liner @ 5149' MD, observe seals going into liner top & set down 20K to observe BTA set. Pick up to 10K over ensuring BTA set. Slack off to 35K below downweight and observe bolt shear. Pick up to neutral. Slowly rotate dri!! string observing free rotation with 60 RPM's - 4K for ue. 21:30 00:00 2.50 5,047 5,058 PROD2 FISH MILL P Mill window in the 7 5/8" casing from 5047' - 5058' (11') with 290 GPMs - ~`~"'~ 1900 PSI. WOB = 2-3K, 80 RPM's, J with 3-6K torque. Observe good kick off with mills, no high torque or hanging u issues. 09/13/2006 00:00 01:00 1.00 5,058 5,070 PROD2 FISH MILL P Continue Mill window from 5047' - -- 5059' (12'), and then open hole from 5059' - 5070' as per Baker rep. Pumps @300 GPM's - 1900 PSI. 80 RPM's with 4-5K torque. Work window observin clean hole conditions. 01:00 02:00 1.00 5,070 5,070 PROD2 FISH CIRC P Pump 35 BBLs of Hi Visc sweep @ 300 GPM's - 1900 PSI. Observe good Iron returns in swee . 02:00 02:30 0.50 5,070 5,070 PROD2 FISH CIRC P Monitor well -static. Work mills through window area with no rotation or pump as per Baker rep, Good hole conditions. Pum d 'ob. 02:30 06:00 3.50 5,070 0 PROD2 FISH TRIP P POOH with BHA #6, Whipstock mills & MWD assembly from 5070' to surface. Crew Chan e 06:00 07:00 1.00 0 0 PROD2 FISH PULD P Continue POOH breakout & lay down MWD and milling assembly. Lay down 6.156" Starting Mill (1.08'), 6.313" Lower Mill (5.57'), 6 3/4" Upper watermelon mill (5.83'), 1 -joint 3 1/2" HWDP (29.80'), 4 3/4" Float sub (2.33'), and 4 3/4" MWD assembly (46.02'). Inspect and gauge upper watermelon mill to full au eat 6 3/4". 07:00 07:30 0.50 0 0 PROD2 FISH PULD P Clean & clear rig floor of all milling tools and OBM. Page 30 of 69 ~ • Time. Lo s Date From To: Dur S. De th E. De th .Phase .Code - Subcode T COM 09/13/2006 07:30 08:30 1.00 0 0 PROD2 DRILL OTHR P Make up Stack washing tool and RIH to flush stack of all metal cuttings from milling. Function rams, HCR's, and manual valves while flushing. Blow down all lines, and To Drive. 08:30 09:00 0.50 0 0 PROD2 DRILL OTHR P Breakout & lay down Stack washing tool. prepare rig floor for MU BHA #7. Hold PJSM with crew, DD &MWD reps. Discuss safety issues and procedure for making up 6 3/4" driling assembl ,BHA #7. 09:00 12:00 3.00 0 3,496 PROD2 DRILL PULD P Make up 6 3/4" Smith bit MDT52 9.84') with 6 x 13's jets for a TFA of .778 sq. in. on a 5" GperryDrill 6/7-6A stg w/ ABI motor (32.02°), 4 3/4" Non MAg Float sub (2.33'), 4.870" Welded Blade Stabilizer (5.22'), 4 314" MWD terminating sub (1.85'), 4 3/4" GammaiRes (24.52'}, MWD Directional (8.56'), 4 3/4" PWD (10.82'), 4 3/4" TM HOC (11.10'), 3 -Non MAg Flex Drill Collars (93.28'), Crossover Sub (2.99'), 1-jnt of 4" HWDP (30.67'), 4 3/4" Dailry Drilling jars (31.96'), 1-jnt of 4" HWDP (30.68'), 48 jnts of 4" XT39 DP (1498.26'), Crossover sub (2.97'), Agitator (8.75'), Shock Sub (8.30'), Crossover sub (3.00'), 48 jnts of 4" XT39 DP (1500.26'), Dailey DNT Mechanical jars (32.24'), 2 jnts of 4" XT39 DP 962.32'), Accelerator jar (31.14'), and 2 jnts of 4" Xt39 DP (62.50'). Total BHA #7 = 3496.58'. perform Shallow pulse test on MWD with pumps @ 245 GPMs- 1100 PSI. Good test. 12:00 15:15 3.25 3,496 4,960 PROD2 DRILL TRIP P Trip in hole with 4" DP from 3496' - 4960'. 15:15 15:45 0.50 4,960 4,960 PROD2 DRILL TRIP P Fill drill string with mud, check pump pressures and MWD assembly. Held "Man down drill". 15:45 16:00 0.25 4,960 4,960 PROD2 RIGMN SFTY P Held PJSM with rig crew. Discuss Safety issues and procedure for sli in and cuttin drillin line. 16:00 17:30 1.50 4,960 4,960 PROD2 RIGMN SVRG P Slip & cut 110' of drilling line. Inspect and adjust brakes on draw works. Service Top drive, Blocks and crown section. Inspect shot pin asembly on TD. rage 31 of 69 Time Lo' s Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/13/2006 17:30 18:00 0.50 4,960 5,062 PROD2 DRILL TRIP P Continue trip in hole with 4" DP to 5000' MD. Fill drill string Obtain SPR's, and orient tool face on drill string to 15 degrees left of high side for passing through window area @ 5047' - 5059' MD. Observe no issues going through window and continue TIH to tag @ 5062' MD. Wash down to 5070'. Crew Chan e 18:00 00:00 6.00 5,062 5,279 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 5070' - 5279' MD (209'). TVD = 3606'. Pumps @ 300 GPMs - 3150 PSI. RPMs = 70-80, WOB = 2-10K, Torque on = 5K, Torque Off btm = 3K, UP WT = 138K, SO WT = 110K, ROT WT = 125K,. ADT = 3.16 HRS, AST = 2.09 HRS, ART = 1.07 HRS. Total Bit HRS = 3.16 HRS. Total Jar HRS #14710043 = 141.83 HRS. Total Jar HRS # 14710005 = 35.38 HRS. ACC HRS = 112.92. MAx gas observed = 134 units, ECD = 9.48 PPG. Observed drilling Concretions @ 5077'-5079', 5101'-5106', 5122'-5129', 5146'-5150', 5160'-5168', 5182'-5185', 5200'-5204', for a total of 33'. Survey @ 5207.76 MD, INC = 93.83 DEG, AZ = 179.27 DEG, 3610.26 TVD. Mud WT = 8.85 PPG Visc = 62, YP = 18, PV = 16. Gels = 16/26/34 09/14/2006 00:00 06:00 6.00 5,279 5,396 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 5279' - 5396' MD (117'). TVD = 3599'. Pumps @ 300 GPMs - 3320 PSI. RPMs = 70-80, WOB = 2-6K, Torque on = 5K, Torque Off btm = 4K, UP WT = 135K, SO WT = 110K, ROT WT = 125K,. ADT = 7.41 HRS, AST = 4.30 HRS, ART = 3.11 HRS. Total Bit HRS = 7.41 HRS. Total Jar HRS #1471 0043 = 146.08 HRS. Total Jar HRS # 14710005 = 39.63 HRS. ACC HRS = 117.08. Max gas observed = 98 units, ECD = 9.55 PPG. Observed drilling Concretions @ 5286'-5298, 5300'-5313',5337'-5346',5385'-5395' for a total of 44'. Survey @ 5394.41 MD, INC = 87.96 DEG, AZ = 182.35 DEG, 3602.10 TVD. Mud WT = 8.8 PPG Visc = 61, YP = 18, PV = 16. Gels = 17/25. Crew Chan e Page 32 of 69 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T GOM 09/14/2006 06:00 12:00 6.00 5,396 5,748 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 5396' - 5748' MD (352'). TVD = 3599'. Pumps @ 300 GPMs - 3350 PSI. RPMs = 70-90, WOB = 2-6K, Torque on = 5K, Torque Off btm = 4K, UP WT = 140K, SO WT = 112K, ROT WT = 125K,. ADT = 7.41 HRS, AST = 4.30 HRS, ART = 3.11 HRS. Total Bit HRS = 10.90 HRS. Total Jar HRS #14710043 = 149.57 HRS. Total Jar HRS # 14710005 = 43.12 HRS. ACC HRS = 120.66. Max gas observed = 29 units, ECD = 9.80 PPG. Observed drilling Concretions @ 5435'-5441', 5465'-5473', 5478'-5490' , 559 9'-5604',5650'-5657', for a total of 38'. Survey @ 5676.75 MD, INC = 90.44 DEG, AZ = 183.07 DEG, 3599.35 TVD. Mud VVT = 8.85 PPG Vigr_. = 60; YP = 18, PV = 16. Gels = 16/24. Obtain Slow pump rates @ 5730' MD, TVD - 3603'. #1 pump @ 20 SPM - 470 PSI, 30 SPM - 740 PSI. #2 pump @ 20 SPM - 430 PS1, 30 SPM - 730 PSI. 12:00 18:00 6.00 5,748 5,987 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 5748' - 5987' MD (239'). TVD = 3591'. Pumps @ 300 GPMs - 3450 PSI. RPMs = 80, WOB = 2-6K, Torque on = 5K, Torque Off btm = 4K, UP WT = 145K, SO WT = 110K, ROT WT = 124K,. ADT = 3.60 HRS, AST = 2.42 HRS, ART = 1.18 HRS. Total Bit HRS = 14.50 HRS. Total Jar HRS #14710043 = 153.17 HRS. Total Jar HRS # 14710005 = 46.72 HRS. ACC HRS = 124.26. Max gas observed = 64 units, ECD = 9.72 PPG. Observed drilling Concretions @ 5815'-5833', 5842'-5858', 5878'-5881',590 5'-5914',5947'-5950',5954'-5963', for a total of 58'. Survey @ 5955.41' MD, INC = 88.78 DEG, AZ = 182.51 DEG, 3592.07 TVD. Mud WT = 8.85 PPG Visc = 60, YP = 18, PV = 16. Gels = 16/24. Obtain Slow pump rates @ 6020' MD, TVD - 3592'. #1 pump @ 20 SPM - 490 PSI, 30 SPM - 840 PSI. #2 pump @ 20 SPM - 480 PSI, 30 SPM - 750 PSI. Crew Chan e Page 33 of 69 Time Lo "s Date From To Dur S. De th E. De th . Phase Code Subcode T COM 09/14/2006 18:00 00:00 6.00 5,987 6,308 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 5987'- 6308' MD (321'). TVD = 3590'. Pumps @ 300 GPMs - 3400 PSI. RPMs = 80, WOB = 2-6K, Torque on = 5K, Torque Off btm = 4K, UP WT = 145K, SO WT = 110K, ROT WT = 122K,. ADT = 3.14 HRS, AST = .74 HRS, ART = 2.40 HRS. Total Bit HRS = 17.64 HRS. Total Jar HRS #14710043 = 156.31 HRS. Total Jar HRS # 14710005 = 49.86 HRS. ACC HRS = 127.40. Max gas observed = 161 units, ECD = 9.8 PPG. Observed drilling Concretions @ 6000'-6005' , 6047'-6056' , 6073'-6086' , 611 7'-6127',6133'-6135',6145'-6150', for a total of 44'. Survey @ 6190.88' MD, INC = 90.31 DEG, AZ = 180.88 DEG, '593.34 TVD. Mud WT = 8.85 PPG Visc = 60, YP = 18, PV = 16. Gels = 16/24. 09/15/2006 00:00 06:00 6.00 6,308 6,869 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 6308' - 6869' MD (561'). TVD = 3591'. Pumps @ 300 GPMs - 3500 PSI. RPMs = 80, WOB = 2-6K, Torque on = 5K, Torque Off btm = 4K, UP WT = 142K, SO WT = 105K, ROT WT = 125K,. ADT = 3.35 HRS, AST = .77 HRS, ART = 2.58 HRS. Total Bit HRS = 20.99 HRS. Total Jar HRS #14710043 = 159.66 HRS. Total Jar HRS # 14710005 = 53.21 HRS. ACC HRS = 130.75. Max gas observed = 188 units, ECD = 10.0 PPG. Observed drilling Concretions @ 6310'-6312',6802'-6808', for a total of 8'. Survey @ 6843.65' MD, INC = 88.57 DEG, AZ = 180.07 DEG, 3588.26 TVD. Mud WT = 8.9 PPG Visc = 75, YP = 19, PV = 17. Gels = 20/28. Obtain Slow pump rates @ 6869' MD, TVD - 3590'. #1 pump @ 20 SPM - 540 PSI, 30 SPM - 810 PSI. #2 pump @ 20 SPM - 550 PSI, 30 SPM - 820 PSI. Crew Chan e Page 34 of 69 `Time Logs 09/15/2006 06 00 12:00 v 6.00 6,869 7,151 L11 PROD2 DRILL DDRLMV P Directional Drill 6 3/4' hole in the B Lateral from 6869' - 7151' MD (282'). TVD = 3581'. Pumps @ 300 GPMs - 3450 PSI. RPMs = 80, WOB = 5-8K, Torque on = 5K, Torque Off btm = 4K, UP WT = 150K, SO WT = 106K, ROT WT = 126K,. ADT = 3.21 HRS, AST = .99 HRS, ART = 2.22 HRS. Total Bit HRS = 24.20 HRS. Total Jar HRS #14710043 = 162.87 HRS. Total Jar HRS # 14710005 = 56.42 HRS. ACC HRS = 133.96. Max gas observed = 148 units, ECD = 9.75 PPG. Observed drilling Concretions @.7115'-7127', for a total of 12'. Survey @ 7126.83' MD, INC = 92.96 DEG, AZ = 179.78 DEG, 3583.46 TVD. Mud WT = 8.9 PPG Visc = 75, YP = 19, PV = 17. Gels = 2U/LO. 12:00 18:00 6.00 7,151 7,402 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 7151'-7402' MD (251'). TVD = 3584'. Pumps @ 300 GPMs - 3510 PSI. RPMs = 80, WOB = 5-8K, Torque on = 5K, Torque Off btm = 5K, UP WT = 151 K, SO WT = 107K, ROT WT = 128K,. ADT = 3.35 HRS, AST = .90 HRS, ART = 2.58 HRS. Total Bit HRS = 27.68 HRS. Total Jar HRS #14710043 = 166.35 HRS. Total Jar HRS # 14710005 = 59.90 HRS. ACC HRS = 137.44. Max gas observed = 152 units, ECD = 9.98 PPG. Observed drilling Concretions @ 7199'-7214', 7245'-7247', 7266'-7273',737 6'-7384',7394'-7415', for a total of 43'. Survey @ 7361.02' MD, INC = 88.95 DEG, AZ = 180.23 DEG, 3583.12 TVD. Mud WT = 8.75 PPG Visc = 63, YP = 21, PV = 17. Gels = 16/27. Obtain Slow pump rates @ 7432' MD, TVD - 3588'. #1 pump @ 20 SPM - 590 PSI, 30 SPM - 870 PSI. #2 pump @ 20 SPM - 600 PSI, 30 SPM - 870 PSI. Crew Chan e Page 35 of 69 Time Los Date From To -:bur. S. De th E. De th Phase Code ' Subcode T COM 09/15/2006 18:00 00:00 6.00 7,402 7,714 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 7402'-7714' MD (312'). TVD = 3586'. Pumps @ 300 GPMs - 3620 PSI. RPMs = 80, WOB = 2-8K, Torque on = 5K, Torque Off btm = 5K, UP WT = 150K, SO WT = 105K, ROT WT = 122K,. ADT = 2.99 HRS, AST = .29 HRS, ART = 2.70 HRS. Total Bit HRS = 30.67 HRS. Total Jar HRS #14710043 = 169.34 HRS. Total Jar HRS # 14710005 = 62.89 HRS. ACC HRS = 140.43. Max gas observed = 197 units, ECD = 10.01 PPG. Observed drilling Concretions @ 7457'-7466',7487'-7495',7563'-7576', for a total of 30'. Survey @ 7643.08' MD, INC = 90.00 DEG, AZ = 177.14 DEG, 3587.11 TVD. Mud WT = 8.75 PPG Visc = 69, YP = 21, PV = 19. Gels = 26/33. Obtain Slow pump rates @ 7432' MD, TVD - 3588'. #1 pump @ 20 SPM - 590 PSI, 30 SPM - 870 PSI. #2 pump @ 20 SPM - 600 PSI, 30 SPM - 870 PSI. 09/16/2006 00:00 02:45 2.75 7,714 7,714 PROD2 RIGMN RGRP NP Pull 1 stand. Monitor wel -static. Install Safety Valve in drill string. Work drill string periodically while change out Saver Sub on Top Drive. Observed no well control issues while C/O saver sub. 02:45 06:00 3.25 7,714 8,016 PROD2 DRILL DDRL P Directional Drili 6 3/4' hole in the B Lateral from 7714' - 8016' MD (302'). TVD = 3583'. Pumps @ 300 GPMs - 3670 PSI. RPMs = 80, WOB = 2-6K, Torque on = 6K, Torque Off btm = 5K, UP WT = 150K, SO WT = 100K, ROT WT = 122K,. ADT = 1.60 HRS, AST = .33 HRS, ART = 1.27 HRS. Total Bit HRS = 32.27 HRS. Total Jar HRS #14710043 = 170.94 HRS. Total Jar HRS # 14710005 = 64.89 HRS. ACC HRS = 141.54. Max gas observed = 158 units, ECD = 10.28 PPG. Observed drilling Concretions @ 7849'-7853', for a total of 4'. Survey @ 8017.86' MD, INC = 91.73 DEG, AZ = 179.80 DEG, 3582.80 TVD. Mud WT = 8.75 PPG Visc = 69, YP = 21, PV = 19. Gels = 26/33. Obtain Slow pump rates @ 8091' MD, TVD - 3588'. #1 pump @ 20 SPM - 620 PSI, 30 SPM - 900 PSI. #2 pump @ 20 SPM - 630 PSI, 30 SPM - 920 PSI. Crew Chan e Page 36 of 69 i ime r~o s .Date From To Dur S. De th E: be th Phase Code Subcode T COM ' 09/16/2006 06:00 12:00 6.00 8,016 8,321 PROD2 DRILL DDRL P hole in the B Directional Drill 6 3/4 Lateral from 8016' - 8321' MD (305'). TVD = 3579'. Pumps @ 300 GPMs - 3700 PSI. RPMs = 90, WOB = 5-8K, Torque on = 6K, Torque Off btm = 5K, UP WT = 150K, SO WT = 105K, ROT WT = 123K,. ADT = 3.84 HRS, AST = .98 HRS, ART = 2.86 HRS. Total Bit HRS = 36.11 HRS. Total Jar HRS #14710043 = 174.78 HRS. Total Jar HRS # 14710005 = 68.33 HRS. ACC HRS = 145.87. Max gas observed = 145 units, ECD = 10.15 PPG. Observed drilling Concretions @ 8045'-8048', 8082'-8086', 8092'-8118',819 0'-8210',8300'-8303', for a total of 56'. Survey @ 8297.15' MD, INC = 91.42 DEG, AZ = 181.86 DEG, 3578.31 TVD'. Mud WT = 8.8 PPG Visc = 62, YP = 20, PV = 16. Gels = 25/26. 12:00 18:00 6.00 8,321 8,630 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 8321'-8630' MD (309'). TVD = 3569'. Pumps @ 322 GPMs - 4150 PSI. RPMs = 80, WOB = 8-10K, Torque on = 7K, Torque Off btm = 6K, UP WT = 160K, SO WT = 100K, ROT WT = 125K,. ADT = 3.58 HRS, AST = .84 HRS, ART = 2.74 HRS. Total Bit HRS = 39.69 HRS. Total Jar HRS #14710043 = 178.36 HRS. Total Jar HRS # 14710005 = 71.91 HRS. ACC HRS = 149.45. Max gas observed = 217 units, ECD = 10.12 PPG. Observed drilling Concretions @ 8322'-8326', 8341'-8343', 8348'-8350' , 852 5'-8534' , 8535'-8543', 8547'-8550', 8605'-8 609', for a total of 32'. Survey @ 8628.68' MD, INC = 88.53 DEG, AZ = 180.78 DEG, 3574.41 TVD. Mud WT = 8.8 PPG Visc = 62, YP = 20, PV = 16. Gels = 25/26. Obtain Slow pump rates @ 8653' MD, TVD - 3574'. #1 pump @ 20 SPM - 580 PSI, 30 SPM - 920 PSI. #2 pump @ 20 SPM - 580 PSI, 30 SPM - 850 PSI. Crew Chan e Page 37 ®t 6y Time Logs ~ r.., _ r__~ r_ n.._ o n....~~. ~ n,, ...u. r~~.,.:;. r`..rl.~ C~~hnn~-io T (:('1M !J[1lC 09/16/2006 riU11J 18:00 I V 00:00 vu~ 6.00 v.. vc to 8,630 ~. vc 8,933 PROD2 DRILL DDRL P - Directional Drill 6 3/4' hole in the B Lateral from 8630'-8933' MD (303'). TVD = 3960'. Pumps @ 310 GPMs - 3960 PSI. RPMs = 90, WOB = 2-8K, Torque on = 7K, Torque Off btm = 6K, UP WT = 158K, SO WT = 98K, ROT WT = 120K,. ADT = 4.17 HRS, AST = .53 HRS, ART = 3.64 HRS. Total Bit HRS = 43.86 HRS. Total Jar HRS #14710043 = 182.53 HRS. Total Jar HRS # 14710005 = 76.08 HRS. ACC HRS = 153.62. Max gas observed = 250 units, ECD = 10.30 PPG. Observed drilling Concretions @ 8565'-8670', 8672'-8689' , 8699'-8704', 870 7'-8719',8729'-8737', for a total of 47'. Survey @ 8768.72' MD, INC = 88.84 DEG, AZ = 180.97 DEG, 3578.98 TVD. ~,^,ud WT = 8.8 PPG Visc = 63, YP = 19, PV = 17. Gels = 30/33. 09/17/2006 00:00 06:00 6.00 8,933 9,170 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 8933'-9170' MD (237'). TVD = 3592'. Pumps @ 310 GPMs - 3720 PSI. RPMs = 90, WOB = 2-8K, Torque on = 7K, Torque Off btm = 6K, UP WT = 160K, SO WT = 98K, ROT WT = 122K,. ADT = 3.69 HRS, AST = .58 HRS, ART = 3.11 HRS. Total Bit HRS = 47.55 HRS. Total Jar HRS #14710043 = 186.22 HRS. Total Jar HRS # 14710005 = 79.77 HRS. ACC HRS = 157.31. Max gas observed = 159 units, ECD = 10.40 PPG. Observed drilling Concretions @ 8998'-9004', 9055'-9059', 9060'-9070',913 3'-9147',9150'-9160'„ for a total of 44'. Survey @ 9140.86' MD, INC = 90.64 DEG, AZ = 174.87 DEG, 3591.18 TVD. Mud WT = 8.75 PPG Visc = 63, YP = 19, PV = 17. Gels = 25/30. Crew Chan e Page 38 of 69 Time Lo s ~_~.~. ~~....... ~,.:,,, c~,~,.,,ao T rnnn uate - 09/17/2006 riven 06:00 iv 12:00 vu. 6.00 o. ~.c ~~~ 9,170 ~. ~~ ~~~ 9,472 ~ ~~a~~ PROD2 DRILL DDRL P -- Directional Drill 6 3/4' hole in the B Lateral from 9170' - 9472' MD (302'). TVD = 3599'. Pumps @ 315 GPMs - 4000 PSI. RPMs = 90, WOB = 2-8K, Torque on = 7K, Torque Off btm = 6K, UP WT = 170K, SO WT = 109K, ROT WT = 122K,. ADT = 3.71 HRS, AST = .85 HRS, ART = 2.86 HRS. Total Bit HRS = 51.26 HRS. Total Jar HRS #14710043 = 189.93 HRS. Total Jar HRS # 14710005 = 83.48 HRS. ACC HRS = 161.02. Max gas observed = 122 units, ECD = 10.55 PPG. Observed drilling Concretions @ 9392'-9397',9443'-9450',9459'-9461', for a total of 14'. Survey @ 9424.34' MD, INC = 90.18 DEG, AZ = 180.67 DEG, 3592.33 TVD. Mud WT = 8.75 PPG Visc = 62, YP = 21, PV = 16. Gels = 17/27. 12:00 18:00 6.00 9,472 9,879 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 9472'-9879' MD (407'). TVD = 3588'. Pumps @ 315 GPMs - 4071 PSI. RPMs = 80, WOB = 8-10K, Torque on = 8K, Torque Off btm = 7K, UP WT = 175K, SO WT = 92K, ROT WT = 122K,. ADT = 3.57 HRS, AST = .81 HRS, ART = 2.76 HRS. Total Bit HRS = 54.83 HRS. Total Jar HRS #14710043 = 1 93.50 HRS. Total Jar HRS # 14710005 = 87.05 HRS. ACC HRS = 164.59. Max gas observed = 133 units, ECD = 10.58 PPG. Observed drilling Concretions @ 9469'-9484',9526'-9540', 9810'-9815',985 0'-9852', for a total of 36'. Survey @ 9794.20' MD, INC = 89.50 DEG, AZ = 180.11 DEG, 3586.57 TVD. Mud WT = 8.75 PPG Visc = 62, YP = 21, PV = 16. Gels = 17/27. Obtain Slow pump rates @ 9872' MD, TVD - 3586'. #1 pump @ 20 SPM - 670 PSI, 30 SPM - 970 PSI. #2 pump @ 20 SPM - 660 PSI, 30 SPM - 1070 PSI. Crew Chan e page 39 of 69 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/17/2006 18:00 19:00 1.00 9,879 9,880 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 9879'-9880' MD (1'). TVD = 3588'. Pumps @ 315 GPMs - 4071 PSI. RPMs = 80, WOB = 8-10K, Torque on = 8K, Torque Off btm = 7K, UP WT = 175K, SO WT = 92K, ROT WT = 122K,. ADT = .08 HRS, AST = 0 HRS, ART = .08 HRS. Total Bit HRS = 54.91 HRS. Total Jar HRS #14710043 = 193.58 HRS. Total Jar HRS # 14710005 = 87.13 HRS. ACC HRS = 164.67. Max gas observed = 133 units, ECD = 10.58 PPG. Observed drilling Concretions @.9879', for a total of 1'. Survey @ 9794.20' MD, INC = 89.50 DEG, AZ = 180.11 DEG, 3586.57 TVD. Mud WT = 8.75 PPG Visc = 62, YP = 21, PV = 16. Gels = 17/27. Obtain Slow pu~~~p rates @ 9872' nfn TVD - 3586'. #1 pump @ 20 SPM - 670 PSI, 30 SPM - 970 PSI. #2 pump @20 SPM-660PS1, 30 SPM-1070 PSI. 19:00 20:45 1.75 9,880 9,880 PROD2 DRILL CIRC T Observed drilling ROP stopped. Could not gain differential pressure. Work drill string and different pump rates to attempt to gain any ROP. No success. Suspect failed mud motor. Pump 35 BBLS of HI VISC weighted sweep, at 310 GPM's - 3850 PSI. Reciprocate & rotate drill string while pump sweep. UP WT = 175K, SO WT = 92K, ROT WT = 122K with 7K torque. Observed 50% increase in cuttings when sweep returned. 20:45 21:45 1.00 9,880 9,375 PROD2 DRILL REAM T Monitor well -static. BROOH for 5 stands @ 25 ft/min from 9880' - 9375' MD. Observe good hole conditions. Monitor well -static. 21:45 00:00 2.25 9,375 6,405 PROD2 DRILL TRIP T Continue POOH on elevators from 9375' - 8936' MD, wet string. Observe good hole conditions and proper hole fill. Monitor well -static, pump 20 BBL dry job, 10.8 PPG, and continue POOH from 8936' - 6405' MD, again with good hole conditions observed with ro er hole fill 09/18/2006 00:00 03:15 3.25 6,405 1,995 PROD2 DRILL TRIP T Continue POOH from 6405' - 5059'. Pull slow through Window area to 5047' No issues with BHA going through window. Continue POOH from 5047' - 1995'. record T& D parameters as er ri en ineer. Page 40 of 69 Time Logs 09/18/2006 03:15 04:15 U 1.00 1,995 ~~ 1,995 111 PROD2 DRILL OTHRyV T Observed drip pan under rotary table with plugged drains. OBM from drill string would not drain away. Obtain permit, and clean all drains and drip an. 04:15 06:00 1.75 1,995 97 PROD2 DRILL TRIP T Continue POOH from 1955' - 97 MD. Record T&D parameters. Break out, rack back 3 -Non Mag Flex Drill Collars (93.28'), Crossover Sub (2.99'), 1-jnt of 4" HWDP (30.67'), 4 3/4" Dailey Drilling jars (31.96'), 1-jnt of 4" HWDP (30.68'), 48 jnts of 4" XT39 DP (1498.26'), Crossover sub (2.97'), Agitator (8.75'.), Shock Sub (8.30'), Crossover sub (3.00'), 48 jnts of 4" XT39 DP (1500.26'), Dailey DNT Mechanical jars (3224'), 2 jnts of 4" XT39 DP 962.32'), Accelerator jar (31. i4 ), and 2 juts of 4" Xt39 DP (62.50').plug into MWD asembly. Crew Chan e 06:00 07:00 1.00 97 97 PROD2 DRILL PULD T Download MWD assembly. PJSM with crew & Sperry Sun reps. Discuss safety issues and procedure for laying down BHA. 07:00 09:00 2.00 97 0 PROD2 DRILL PULD T Continue POOH, breakout & lay down BHA #7, laying down 6 3/4" Smith bit MDT52 9.84') with 6 x 13's jets for a TFA of .778 sq. in. on a 5" SperryDrill 6/7-6.0 stg w/ ABI motor (32.02'), 4 3/4" Non Mag Float sub (2.33'), 4.870" Welded Blade Stabilizer (5.22'), 4 3/4" MWD terminating sub (1.85'), 4 3/4" Gamma/Res (24.52'), MWD Directional (8.56'), 4 3/4" PWD (10.82'), 4 3/4" TM HOC (11.10'). inspect & grade bit to 1/6/BT/G/X/2/CT/DTF. Observed proper hole fill on TOH. 09:00 09:15 0.25 0 0 PROD2 DRILL OTHR T Clean & clear rig floor of OBM & tools. 09:15 09:30 0.25 0 0 PROD2 DRILL SFTY T Held PJSM with crew and Sperry Sun reps. Discuss safety issues and procedure for making up BHA #8, Geo-Pilot Assembl . 09:30 10:45 1.25 0 90 PROD2 DRILL PULD T Make up BHA #8. Make up 6 3/4" Security FMF3641Z PDC long gauge bit (1.29'} with 3 x 21 jets for a TFA of 1.015 sq. in., 5 1/4" 5200 Series Geo-pilot TL-043 (16.18'), 4 3/4' Non Mag Geo-pilot Flex Collar (11.54'), 4 3/4" MWD DM HOC (8.56'), 4 3/4" Smart Stabilizer (3.60'), 4 3/4" MWD Gamma/Res (24.57'), 4 3/4" PWD 10.82' 4 3/4" TM HOC 11.10' . 10:45 12:30 1.75 90 90 PROD2 DRILL PULD T Plug in and Upload MWD assembly. Continue Clean ri floor of OBM. Page 41 of 65 • >Time Lo s .Date From To Dur S. De th E. De th Phase .Code Subcode T COM 09/18/2006 12:30 13:30 1.00 90 2,160 PROD2 DRILL PULD T Continue make up BHA #8, Make up 4 3/4" Non mag float sub (2.33'), 4 3/4" Welded Blade stabilizer {5.22'), 3 - Non Mag Flex Drill Collars (93.28'), Crossover (2.99'), 1-jnt of 4" HWDP (30.67'), 4 3/4" Dailey Drilling jars (31.96'), 1-jnt of 4" HWDP (30.68'), and 4" XT 39 drill i e to 2160' MD. 13:30 14:30 1.00 2,160 2,160 PROD2 DRILL OTHR T Screw into Top Drive and fill drill string. Attempt to perform Shallow pulse test on BHA -failed. Repeat attempts. Pumps @ 250 GPM's. Blow down TD and ri u to POOH for failed tools. 14:30 16:00 1.50 2,160 90 PROD2 DRILL TRIP T POOH from 2160' - 90' MD. Rack back 4 3/4" Non mag float sub (2.33'}, 4 3/4" Welded Blade stabilizer (5.22'), 3 - Non Mag Flex Drill Collars (93.28'), Crossover (2.99'), 1-jnt of 4" HWDP (30.67'), 4 3/4" Dailey Drilling jars (31.96'), 1-jnt of 4" HWDP (30.68'), and 4" XT 39 drill i e to 2160' MD. 16:00 16:45 0.75 90 90 PROD2 DRILL OTHR T Plug in and download MWD assembly. Clean & clear rig floor of OBM from wet tri . 16:45 18:00 1.25 90 0 PROD2 DRILL PULD T Spin & clear OBM mud from Geo-pilot assembly. Breakout & lay down Make up 6 3/4" Security FMF3641Z PDC long gauge bit (1.29') with 3 x 21 jets for a TFA of 1.015 sq. in., 5 1/4" 5200 Series Geo-pilot TL-043 (16.18'), 4 3/4' Non Mag Geo-pilot Flex Collar (11.54'). lay down Geo-pilot & battery pack. Crew Chan e. 18:00 18:45 0.75 0 90 PROD2 DRILL PULD T PJSM with new rig crew. Discuss safety issues and procedure for making up BHA #9. Make up Make up 6 3/4" Security FMF3641Z PDC long gauge bit (1.29') with 3 x 21 jets for a TFA of 1.015 sq. in., 5 1/4" 5200 Series Geo-pilot TL-043 (16.18'), 4 3/4' Non Mag Geo-pilot Flex Collar (11.54'), 4 3/4" MWD DM HOC (8.56'), 4 3/4" Smart Stabilizer (3.60'), 4 3/4" MWD Gamma/Res (24.57'), 4 3/4" PWD 10.82' 4 3/4" TM HOC 11.10' . 18:45 19:15 0.50 90 90 PROD2 DRILL PULD T Plug in and upload MWD assembly. 19:15 19:45 0.50 90 90 PROD2 DRILL PULD T Pull back up hole to the bit. Change out b s as per Co. Rep. h^ake up 6 3/4" Security FMF3642 PDC bit (1.29') with 3 x 21 jets for a TFA of 1.015 Sq In. Page 42 of 69 _Time Lo s I .~ c, r._:_a~. r n....aL, nti...,,. r..,a., G~h..nrlo T ('~lM vaiC 09/18/2006 rives ~ 19:45 i v 21:15 vu~ 1.50 .,. vo ~~ ~ 90 120 PROD2 DRILL PULD T - - Make up 4 3/4" Non mag float sub (2.33'), 4 3/4" Welded Blade stabilizer (5.22'), 3 -Non Mag Flex Drill Collars (93.28'). 1 stand of 4" DP. Perform Shallow pulse test on MWD assembly with pumps @ 300 GPM's - 2100 PSI. Good test. 21:15 22:15 1.00 120 120 PROD2 RIGMN SVRG T Inspect & Service Top Drive. Inspect mounting plates on motor for TD. ti hten bolts. 22:15 00:00 1.75 120 3,760 PROD2 DRILL TRIP T Continue trip in hole from 120' - 3940'. Make up remaining BHA with 37 stands of 4" DP (3467.56'), Crossover sub (2.97'), Dailey DNT Mechanical jars (32.24'), 2 jnts of 4" XT39 DP (62.32'), Accelerator jar (31.14'), and 2 juts of 4" Xt39 DP (62.50'). Total BHA = 3940.53'. 09/19/2006 00:00 06:00 6.00 3,760 7,035 ~ PROD2 DRILL TRIP T l.ontlnUe trip iii h6ie with BHA#9 fri~m 3760' - 5047'. Pump to verify Geo-pilot deflection at zero. Work Drill string through window area, observing haging up on Bit & Stabilizers. Continue TIH, tagging, hanging up & firing jars in spots @ 5253', 5470' and different areas to 7035' MD. Screw into Top drive @ 5470' pumping and observing deflection at 125%. Send commands to zero defletion. Continue trip in hole having to ream in spots from 5047' - 7035' MD, until observe needing to pump almost every stand. Pumps @ 315 GPM's - 2150 PSI, 50 RPM's with 5K for ue. Crew than e 06:00 06:30 0.50 7,035 7,410 PROD2 DRILL TRIP T Continue trip in hole 7035' - 7410' MD on elevators. Observed continued han in u with over ull. 06:30 11:45 5.25 7,410 9,880 PROD2 DRILL REAM T Wash & ream each stand from 7410' - 9880' MD. Pumps @ 330 GPM's - 3100 PSI. 5-8K WOB, with 90-100 RPM's. ROT WT = 120K. Page 43 of 69 Time Lo s Date From To Dur S: De th E. De th Phase Code Subcode T COM 09/19/2006 11:45 12:00 0.25 9,880 9,884 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 9880'- 9884' MD (4'). TVD = 3588'. Pumps @ 345 GPMs - 3430 PSI. RPMs = 110, WOB = 2-8K, Torque on = 9K, Torque Off btm = 8K; UP WT = 172K, SO WT = 92K, ROT WT = 122K,. ADT = .15 HRS, Total Bit HRS = .15 HRS. Total Jar HRS #14710043 = 198.73 HRS. Total Jar HRS # 14710005 = 87.28 HRS. ACC HRS = 164.92. Max gas observed = 43 units, ECD = 11.1 PPG. Survey @ 9812.24' MD, INC = 88.28 DEG, AZ = 180.60 DEG, 3586.92 TVD. Mud WT = 8.8 PPG Visc = 70, YP = 21, PV = 17. Gels = 28/30. Obtain Slow pump rates @ 9844' MD, TVD - 3586'. #1 pump @ 20 SPM - 570 PSI, 30 SPM - 820 PSI. #2 pump @ 20 SPM - 570 PSI, 30 SPM - 830 PSI. 12:00 18:00 6.00 9,884 10,501 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 9884'- 10501' MD (617'). TVD = 3613'. Pumps @ 340 GPMs - 3650 PSI. RPMs = 110, WOB = 2-10K, Torque on = 8K, Torque Off btm = 8K, UP WT = 185K, SO WT = 85K, ROT WT = 121 K,. ADT = 425 HRS, Total Bit HRS = 4.25 HRS. Total Jar HRS #14710043 = 202.98 HRS. Total Jar HRS # 14710005 = 91.53 HRS. ACC HRS = 169.07. Max gas observed = 82 units, ECD = 11.2 PPG. Observed drilling Concretions @ 9920'-9923',10336'-10339',10426'-1043 0', for a total of 10'. Survey @ 10466.42' MD, INC = 91.10 DEG, AZ = 180.78 DEG, 3611.83 TVD. Mud WT = 8.8 PPG Visc = 69, YP = 21, PV = 17. Gels = 28/30. Obtain Slow pump rates @ 9844' MD, TVD - 3586'. #1 pump @ 20 SPM - 570 PSI, 30 SPM - 820 PSI. #2 pump @ 20 SPM - 570 PSI, 30 SPM - 830 PSI. Crew Chan e Page 44 of 69 Time Logs rhto Frnm Tn Rur ~ flanth. F-._{lanth Phaca 'Gnrle SubeOde T COM 09/19/2006 18:00 00:00 v 6.00 10,501 11,020 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 10501'-11020' MD (519'). TVD = 3593'. Pumps @ 340 GPMs - 3610 PSI. RPMs = 110, WOB = 8-10K, Torque on = 9K, Torque Off btm = 8K, UP WT = 185K, SO WT = 75K, ROT WT = 120K,. ADT = 4.59 HRS, Total Bit HRS = 8.99 HRS. Total Jar HRS #14710043 = 207.57 HRS. Total Jar HRS # 14710005 = 96.12 HRS. ACC HRS = 173.66. Max gas observed = 162 units, ECD = 11.93 PPG. Observed drilling Concretions @ 10982'-10984',10994'-10995',11052'-11 063',11128'-11130', for a total of 1E'. Survey @ 10934.25' MD, INC = 92.18 DEG, AZ = 180.08 DEG, 3595.80 TVD. Mud WT = 8.9 PPG Visc = 68, YP = 19, PV = 17. Gels = 30/31. 09/20/2006 00:00 06:00 6.00 11,020 11,626 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 11020' - 11626' MD (606'). TVD = 3592'. Pumps @ 340 GPMs - 3300 PSI. RPMs = 100, WOB = 8-10K, Torque on = 9K, Torque Off btm = 7K, UP WT = 185K, SO WT = 75K, ROT WT = 120K,. ADT = 4.18 HRS, Total Bit HRS = 13.17 HRS. Total Jar HRS #14710043 = 211.75 HRS. Total Jar HRS # 14710005 = 100.30 HRS. ACC HRS = 177.84. Max gas observed = 145 units, ECD = 11.57 PPG. Observed drilling Concretions @ 11052'-11063',11128'-11130',11309'-11 314',11393'-11402', for a total of 27'. Survey @ 11591.66' MD, INC = 91.89 DEG, AZ = 175.37 DEG, 3595.58 TVD. Mud WT = 8.8 PPG Visc = 68, YP = 19, PV = 17. Gels = 30/31. Pump Hi Visc weighted sweep @ 11400' MD, observe 75% increase in cuttings on shakers when returned. Obtain Slow pump rates @ 11153' MD, TVD - 3590'. #1 pump @ 20 SPM - 620 PSI, 30 SPM - 890 PSI. #2 pump @ 20 SPM - 620 PSI, 30 SPM - 890 PSI. Crew Chan e Page 45 of 69 Time Logs ~° ~ ~-- -- -r_ r,.._ c~ n....aw ~ n,,..+H o~.,..,, r~.,ao CI Ih.-nao T C`(l~A 1./[IlC 09/20/2006 f I VI11 06:00 I v 12:00 vul 6.00 v, vc al I 11,626 ~. va. ii ~.. 11,907 ~....i ~awv~. PROD2 vv.wv DRILL ...-~~~~~ DDRL P _ _._. Directional Drill 6 3/4' hole in the B Lateral from 11626'-11907' MD (281'). TVD = 3586'. Pumps @ 340 GPMs - 3775 PSI. RPMs = 80-120, WOB = 2-8K, Torque on = 9K, Torque Off btm = 7K, UP WT = 190K, SO WT = 85K, ROT WT = 120K,. ADT = 4.77 HRS, Total Bit HRS = 17.94 HRS. Total Jar HRS #1471 0043 = 216.52 HRS. Total Jar HRS # 14710005 = 105.07 HRS. ACC HRS = 182.61. Max gas observed = 69 units, ECD = 11.53 PPG. Observed drilling Concretions @ 11724'-11738',11744'-11762', for a total of 32'. Survey @ 11874.01' MD, INC = 92.63 DEG, AZ = 181.69 DEG, 3586.20 TVD. Mud WT = 8.8 PPG Visc = 68, YP = 19, PV = 17. Gels = 30/31. 12:00 16:00 4.00 11,907 12,242 PROD2 DRILL DDRL P Directional Drill 6 3/4' hole in the B Lateral from 11907'-12242' MD (335'). TVD = 3580'. Pumps @ 340 GPMs - 3750 PSI. RPMs = 80-130, WOB = 2-12K, Torque on = 9K, Torque Off btm = 7K, UP WT = 210K, SO WT = 85K, ROT WT = 120K,. ADT = 1.79 HRS, Total Bit HRS = 19.73 HRS. Total Jar HRS #14710043 = 218.31 HRS. Total Jar HRS # 14710005 = 106.86 HRS. ACC HRS = 184.40. Max gas observed = 79 units, ECD = 11.45 PPG. Observed drilling Concretions @ 11985'-11987',12138'-12143',12163'-12 165', for a total of 9'. Survey @ 12148.86' MD, INC = 91.34 DEG, AZ = 177.58 DEG, 3584.64 TVD. Mud WT = 8.8 PPG Visc = 68, YP = 19, PV = 17. Gels = 30/31. Obtain Slow pump rates @ 12075' MD, TVD - 3584'. #1 pump @ 20 SPM - 660 PSI, 30 SPM - 920 PSI. #2 pump @ 20 SPM - 650 PSI, 30 SPM - 910 PSI. Observe 23 deg dogleg @ 12152', and then MWD trouble. Decision to call TD in lateral. 16:00 16:15 0.25 12,242 12,184 PROD2 DRILL REAM P Back ream out of hole from 12242' -12184'. pumps @ 340 GPM's - 3750 PSI, 100 RPMs, with for ue 8K. 16:15 16:30 0.25 12,184 12,094 PROD2 DRILL TRIP P POOH on elevators from 12184'- 12094'. UP WT = 210K, SO WT = 90K. 16:30 18:00 1.50 12,094 12,094 PROD2 DRILL CIRC P Pump 40 BBLS Hi Visc weighted sweep, 10.7 PPG, 200 Visc, @ 330 GPM's - 3780 PSI. Reciprocate & rotate drill string at 100 RPM's with 8K torque. Monitor well -static. Crew Chan e. Page 46 of 69 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/20/2006 18:00 21:00 3.00 12,094 10,750 PROD2 DRILL REAM P BROOH from 12094' - 11430'. Attempted to POOH on elevators, observed tight hole, continue BROOH from 11430' - 10750'. Pumps @ 340 GPM's - 3600 PSI. 100 RPM's. Circulated strokes = 2 btms up, before attem t POOH on elevators. 21:00 22:00 1.00 10,750 10,200 PROD2 DRILL TRIP P POOH on elevators from 10750' - 10200'. Observe good hole conditions and proper hole fill. Monitor well - static. 22:00 00:00 2.00 10,200 7,900 PROD2 DRILL TRIP P Pump dry job. Blow down TD & lines. Continue POOH on elevators from 10200' - 7900' MD. Observe good hole conditions and ro er hole fill. 09/21/2006 00:00 02:15 2.25 7,900 4,972 PROD2 DRILL TRIP P Continue POOH on elevators from 7900' - 4972' MD. Observe good hole conditions and ro er hole fill. 02:15 03:30 "1.25 4,972 4,972 PROG2 DRILL CiRC P Circuiate 40 BBL Hi Visc weigted sweep (10.8 PPG - 170 Visc) @ 3410 GPM's - 2600 PSI. 100 RPM's with 5K torque. Reciprocate 7 rotate drill string while pump. Observed no significant increase in cuttings on return of swee . 03:30 05:15 1.75 4,972 4,972 PROD2 RIGMN SVRG P Slip & cut 105' of drilling line. Inspect & adjust brakes on draw works. Ins ect & service To Drive. 05:15 06:00 0.75 4,972 6,000 PROD2 DRILL TRIP P Trip back in hole from 4972' - 6000' MD. Observe proper hole fill. Observed no issues when BHA going through window area. UP WT = 145K, SO WT = 105K. Obtain T&D parameters as er ri en ineer. Crew Chan e 06:00 09:15 3.25 6,000 9,942 PROD2 DRILL TRIP P Continue trip in hole from 6000' - 9942' MD. Obtain T&D parameters as per rig engineer. Every 5 stands in open hole. Observed good hole conditions, filling drillin drill strip eve 25 stands. 09:15 12:00 2.75 9,942 11,709 PROD2 DRILL REAM P Ran out of downweight. Make Top Drive connection. Fill drill string. Wash & ream from 9942' - 11709'. Pumps @ 126 GPM - 1000 PSI & 60 RPM's 12:00 12:30 0.50 11,709 12,094 PROD2 DRILL REAM P Continue wash & ream in hole from 11709' - 12094' MD. Pumps @ 126 GPM - 1000 PSI & 60 RPM's 12:30 14:15 1.75 12,094 12,094 PROD2 DRILL CIRC P Establish Circulation rates of 340 GPM's- 4000 PSI. 140 RPM's, and pu~~~p a Weigh ted Hi Visc ~~;eep. Reciprocate & rotate drill string while pumping. UP WT = 124K, SO WT = 104K, ROT WT = 112K. Circulate swee + 2 Btms u until clean. Page 47 of &9 Time Lo s Date From To Dur S. De th E. De th Phase Gode Subcode T COM 09/21/2006 14:15 15:00 0.75 12,094 12,094 PROD2 DRILL CIRC P Rig up and displace production hole section to 8.9 PPG SFMOBM, 350 BBLS. Chase with 25 BBL Dry job. Calculated top of SFMOBM = 4500' MD 15:00 15:15 0.25 12,094 12,094 PROD2 DRILL TRIP P Monitor well -static. Drop 2 1/4" drift with tail wire in DP. 15:15 18:00 2.75 12,094 8,162 PROD2 DRILL TRIP P POOH on elevators from 12094' - 8162' MD. Observed good hole conditions and no overpufl issues.Observed ro er hole fill. Crew Chan e 18:00 20:00 2.00 8,162 4,980 PROD2 DRILL TRIP P Continue POOH with BHA #9 from 8162' - 4980'. observed no issues going throuh window area with BHA. Monitor well -static. 20:00 20:30 0.50 4,980 3,940 PROD2 DRILL TRIP P Continue POOH from 4980' - 3940' . Stand back Accelerator jar (31.14'), and 2 jnts of 4" Xt39 DP (62.50'). Pull 2 1/4" Crift from assembly, and drop in remainin BHA with tail wire. 20:30 22:00 1.50 3,940 295 PROD2 DRILL TRIP P Continue POOH from 3940' - 295' MD. Racking back 37 stands of 4" DP (3467.56'), Crossover sub (2.97'), Dailey DNT Mechanical jars (32.24'), 2 'nts of 4" XT39 DP 62.32' . 22:00 22:45 0.75 295 97 PROD2 DRILL PULD P Continue POOH breakout & lay down 4 3/4" Welded Blade stabilizer (5.22'), 3 -Non Mag Flex Drill Collars (93.28'), Crossover (2.99'), 1-jnt of 4" HWDP (30.67'), 4 3/4" Dailey Drilling jars (31.96'), 1-jnt of 4" HWDP (30.68'), and 4" XT 39 drill i e 22:45 23:15 0.50 97 97 PROD2 DRILL PULD P Plug in and download MWD asembly. prepare rig floor for next run with 4 1/2" liner. 23:15 00:00 0.75 97 25 PROD2 DRILL PULD P Continue POOH, Breakout & lay down 4 3/4" MWD terminating sub (1.85'), 4 3/4" Gamma/Res (24.52'), MWD Directional (8.56'), 4 3/4" PWD 10.82' , 4 3/4" TM HOC 11.10' . 09/22/2006 00:00 00:15 0.25 25 0 PROD2 DRILL PULD P Continue POOH breakout & lay down 6 3/4" Security FMF3641Z PDC long gauge bit (1.29') with 3 x 21 jets for a TFA of 1.015 sq. in., 5 1/4" 5200 Series Geo-pilot TL-043 (16.18'), 4 3/4' Non Mag Geo-pilot Flex Collar (11.54'). lay down Geo-pilot & battery pack, 4 3/4" Non mag float sub (2.33'). Inspect & au e bit to 1/1/BT/A/X/I/NO/DTF. 00:15 00:45 0.50 0 0 COMPZ CASIN( RURD P Clean & clear rig floor area. Send tools out. Rig up liner running tools for 4 1/2" Slotted liner. Pick up Tongs, elevators, and sli s. Page 48 of 69 • Time Logs Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/22/2006 00:45 01:30 0.75 0 0 COMPZ CASIN( SFTY P Held PJSM with rig crew, GBR rep, and BOT rep. Discuss safety issues and procedure for picking up 4 1/2" slotted liner. Open blind rams and monitor well -static. 01:30 06:00 4.50 0 6,402 COMPZ CASIN( RNCS P Make up 4 1/2" Siver Bullet Shoe (1.67'), 1 - jnt of 4 1/2" 12,6# IBT blank (31.17'), and 4 1/2" XO pup to BTC (2.06'). Continue make up 4 1/2" Slotted /Blank liner as per detail. Run from surface to 6402' MD. Obtain T&D parameters as per rig engineer. MU TQ = 4500 Ft/Ibs. MU TQ w/ TQ rings = 5K FT/LBs. Observe no issues as Shoe passing through window area. Crew Chan e 06:00 07:00 1.00 6,402 6,857 COMPZ CASIN( RNCS P Continue run 4 1/2" Slotted liner from 6402' - 6857'. Observed proper hole fill. ivo o en hoie issues. 07:00 07:30 0.50 6,857 6,857 COMPZ CASIN( RNCS P Change elevators & power tongs. Make up 5 1/2" Hydril 521 x 4 1/2" BTC XO bushing (1.42') with 4 1/2" BTC pup (3.80'), 1 joint of 5 1/2" Hydri! 521 Blank (36.60'), 5 1/2" Hydril 521 pup (8.98'), and BOT "HR" liner setting sleeve (12.64'), with running tool & XO (6.44',2.99'). Rig down GBR casing equipment. Clean & clear floor area for TIH w/ DP. 07:30 12:00 4.50 6,857 11,700 COMPZ CASIN( RUNL P obtain Up/DN weights with liner. UP WT = 125K, SO WT = 95K. ROT WT = 109K. TIH with 4 1/2" Slotted liner on DP form 6857' - 10600' MD. Running speed as per BOT rep. Rotate liner in hole from 10600' - 11700' MD at 20 RPM's-5Kt . 12:00 13:15 1.25 11,700 12,093 COMPZ CASIN( RUNL P Continue RIH with Slotted liner rotating liner from 11700' - 12093' MD. 25 RPM's - 7K for ue. Set liner on de th. 13:15 14:15 1.00 12,093 12,093 COMPZ CASIN( OTHR P Drop 29/32" Ball, pumping @ 2.5 BPM, observing ball landed and pressuring up to 3500 PSI. Continue pressure to 4000 PSI, releasing liner setting tool with the top @ 5244' MD. Bleed all pressures. Pull up to observe wei ht loss and free from liner. 14:15 14:30 0.25 5,244 4,947 COMPZ CASIN( RUNL P POOH with DP from 5244' - 4947' MD. Observe wet drill strin . 14:30 15:00 0.50 4,947 4,947 COMPZ CASING CIRC P Circulate bottoms up @ 300 GP"al's - 1075 PSI. Monitor well -static. 15:00 15:30 0.50 4,947 4,947 COMPZ CASIN( RUNL P Pump dry job. Blow dow TD & lines. Dro 1.93" drift in DP with tail wire. 15:30 18:00 2.50 4,947 0 COMPZ CASIN( RUNL P POOH with DP from 4947' -surface. Inspect, breakout and lay down BOT runnin tools. A!I ood. Crew Chan e. 18:00 19:00 1.00 0 0 COMPZ CASIN( RUNL P Finish laying down running tools. Clean & clear ri floor area. . Page 49 of 69 • .Time Lo s Date From' To Dur S. De th E. De th Phase Code Subcode T COM 09/22/2006 19:00 19:45 0.75 0 0 COMPZ RIGMN RGRP T Change out HI -LOW valve for draw works drum clutch. Pull tools to flooe for Whi stock retrieval run. 19:45 21:45 2.00 0 0 COMPZ RIGMN SVRG P Change out saver sub on Top Drive. 21:45 22:30 0.75 0 0 COMPZ STK PULD P Make up Baker retrieving hook assembly. make up Retrieving hook (7.50'), 1-jnt of 4" HWDP (37.28'), 4 3/4" Bumper jar (7.73'), 4 3/4" Oil Jar (11.15'), crossover sub (2.99') and 3 stands of h brid ush i e 278.43' . 22:30 00:00 1.50 0 2,600 COMPZ STK TRIP P Trip in hole with retrieving assembly from surface to 2600' MD. Observe ro er hole fill. 09/23/2006 00:00 02:15 2.25 2,600 5,052 COMPZ STK TRIP P Continue TIH with BOT whipstock retrieving tool from 2600 - 5052'. UP WT = 140K, SO WT = 100K. Observed ro er hole fill on TIH. 02:15 05:00 2.75 5,052 5,052 COMPZ STK CIRC P Locate wash port in tool joint to the slot in whipstock. Wash slot with pumps @ 5 BPM - 1650 PSI. Continue to wash & attempt to engage slot with hook. repeat attempts to engage working string in 1/4 turn increments. Wash slot numerous times to observe hooking Whiopstock pulling 50K over allowing jars to bleed. Slack off and re-cock jars, pulling to 75K over to fire jars and observe assembly free with 8K added wei ht or dra . 05:00 05:15 0.25 5,052 4,960 COMPZ STK OWFF P Pull 1 stand slow observing fluid falling in well bore, and rack back 1 stand. Make To Drive connection. 05:15 06:00 0.75 4,960 4,960 COMPZ STK TRIP P Circulate bottoms up at 5.5 BPM - 1000 PSI as per BOT rep. Monitor well - static. Crew chan e 06:00 06:30 0.50 4,960 4,960 COMPZ STK CIRC P Pump dry job, blow down Top Drive & lines. 06:30 10:00 3.50 4,960 337 COMPZ STK TRIP P POOH with Whipstock Retrieving assembly and whipstock from 4960' - 337'. Observed proper hole fill. No swabbin . 10:00 12:00 2.00 337 0 COMPZ STK PULD P Brekaout & lay down Fishing BHA. Lay down Retrieving hook (7.50'), 1-jnt of 4" HWDP (37.28'), 4 3/4" Bumper jar (7.73'), 4 3/4" Oil Jar (11.15'), crossover sub (2.99') and rack back 3 stands of hybrid push pipe (278.43'). Continue breakout & iay down Whipstock assembly with jewelry and s ace out i e. 12:00 12:30 0.50 0 0 COMPZ STK PULD P Continue POOH breakout & lay down Whipstock assembly with jewelry and space out pipe. Observed seal in good shape on seal assembly. Whipstock slide was in ood sha e. Page 50 of &9 Time Logs Date From To Dur S. De th E. De th Phase Code- Subcode T COM 09/23/2006 12:30 13:00 0.50 0 0 COMPZ STK PULD P Clean & Clear Rig Floor area and send tools out. 13:00 13:15 0.25 0 0 COMPZ CASIN( RURD P Rig up to run Hook Hanger assembly. Rig up Tongs and elevators. Pull e ui ment to ri floor. 13:15 13:30 0.25 0 0 COMPZ CASIN( SFTY P Held PJSM with crew, GBR, BOT & Sperry Sun reps. Discuss safety issues and procedure for making up Hook Han er assembl . 13:30 15:00 1.50 0 259 COMPZ CASIN( PUTB P Make up Hook hanger asembly. make up 7 5/8" x 4 1/2" Baker Model B-1 HH for LEM (16.71', 6.12'), 4 1/2" pup (3.85'), 4 1/2" Blankjnt (39.86'), 4 1/2" pup (5.75'), baker Payzone External Casing Packer (13.06'), 4 1/2" Pup (3.06'), 4 1/2" Pup (3.80'), 2 - jnts Slotted liner (86.68'), 4 1/2" Crossover jnt (42.71'), and 4 1/2" Bent joint 28 25' . Tota! BHA = 25$.93' 15:00 15:30 0.50 259 259 COMPZ CASIN( PUTB P make up Sperry Sun MWD Slim Hole assembly and orient MWD to Hook han er hook. 15:30 16:15 0.75 259 259 COMPZ CASIN( PUTB P Rig down all casing running equipment. Clean & clear rig floor area of OBM. RU to TIH with DP. 16:15 17:30 1.25 259 2,300 COMPZ CASIN( RUNL P Trip in hole with Hook hanger assembl from 259' - 2300'. 17:30 17:45 0.25 2,300 2,300 COMPZ CASIN( RUNL P Perform Shallow pulse test on MWD tools. Good test. 17:45 18:00 0.25 2,300 2,438 COMPZ CASIN( RUNL P Continue TIH with B lateral Hook Haanger assembly from 350 - 2438'. Crew Chan e 18:00 20:30 2.50 2,438 5,047 COMPZ CASIN( RUNL P Continue TIH with B Lateral Hook Han er Assembl from 2438' - 5047'. 20:30 21:45 1.25 5,047 5,296 COMPZ CASIN( RUNL P Attempt to run Shoe through window and observed tagging up on the A Lateral Crossover @ 5200'. Repeat attempts 4 times rotating string 1/4 RH turns to finally observe shoe into open hole. UP WT = 170K, SO WT = 140K. Page 51 of 69 Time Lo s bate From To Dur S. De th E. De th Phase Code Subcode T COM 09/23/2006 21:45 22:45 1.00 5,296 5,296 COMPZ CASIN( OTHR P Pick up single DP. Continue RIH to 15' above Window. Pump to orient Hook to 26 Deg left. Slack off, observe Hook engaged window and MWD indicated set down @ 9 Deg Right. Pull up to orient 180 Degrees out, and slack off to tag Crossover in B Lat Setting Sleeve on depth @ 5303' MD. Pull back up above window, and re-orient Hook to 23 Deg, Left. Slack off observing Hook engaged window once again, and corrected MWD toolface indicated 12 Deg right on the final set down w/ 30K set down on Hook. Pumps @ 117 GPM - 1000 PSI. Found Bottom of window and hooked hanger @ 5062.87' MD (2.87' low). Drop 29/32" ball down drill string and ~~~ F" ~~~ ' ~ °PM - 1000 c. ~a~e vri~~ ~ Numps @ ~.~ PSI until observed ball landed. 22:45 00:00 1.25 5,296 5,296 COMPZ CASIN( OTHR P With ball seated, pressure to 2800 PSI, to release setting tool and inflate ECP @ 5118.45' MD. Allow pressure to bleed to 2000 PSI. Hold 10 Minutes. Pressure to 2800 PSI observing 1.2 strokes or .14 BBIs to inflate as per BOT rep. Mule shoe @ 5296.01' MD = 7' from crossover. 09/24/2006 00:00 00:45 0.75 5,060 5,060 COMPZ CASIN( RUNL P Bleed all pressures. Rack back 1 stand, and lay down single joint. Pump Dry Job. Momitor well -static. Blow down To drive & lines. 00:45 03:15 2.50 5,060 90 COMPZ CASIN( RUNL P POOH with setting tools from 5060' - surface. Observe ro er hole fill. 03:15 04:15 1.00 90 0 COMPZ CASIN( RUNL P Breakout & lay down Running & setting tools for Hook Hanger assmy. La down Slim hole MWD assembl . 04:15 05:00 0.75 0 0 COMPZ CASIN( OTHR P Clean & clear rig floor area. Held PJSM with crew. Discuss Safety issues and procedure for making up B lateral LEM tools. 05:00 06:00 1.00 0 369 COMPZ CASIN( RUNL P MU 4 1/2" Bent joint (43.25') with Seals Assembly (3.25'). Run 2 joints of 4 1/2" 12.6 L80 IBT TBG (62.17'), Camco DB-6 Nipple with 3.563" ID profile (1.55'), Pup jnt (9.80'), LEM assembly (35.17'),Pup Jnt (3.83'), XO Bushing (1.44'), 109-47 Casing Seal Bore receptacle (19.69'), 7 5/8" ZXP Liner Top PKR (19.08') and running & setting tools with XO.. Total BHA = 369.05' Crew Chan e 06:00 07:00 1.00 369 369 COMPZ CASIN( RUNL P Continue MU remaining LEM assembly. rig down casing running tools. Clean & clear rig floor of OBM & tools. Page 52 of S9 • Time Lo s Date From To Dur S. De th E. De th,l'hase Code Subcode T COM 09/24/2006 07:00 12:00 5.00 369 5,191 COMPZ CASIN( RUNL P TIH with LEM runing assembly 25-30 ft/minute as per BOT rep from 369' - 5128'. Make Top Drive connection, observe seals going through B lateral Hook Hanger with 20k drag, latching up on depth as planned with seals @ 5191.65' MD. Top of ZXP PKR at 4837.00' MD. 12:00 13:00 1.00 5,191 4,837 COMPZ CASIN( RUNL P Drop 1 3/4" ball, allowing to fall chasing it with pumps @ 2.5 BPM - 250 PSI. Observed ball seated. pressuring to 4000 PSI to release setting tool. Pick up to verify free movement,. and Close annular bag. Pressure down annulus to 1000 PSI for 10 Minutes. Good test. All pressures and tests recorded on chart. 13:00 13:15 0.25 4,837 4,800 COMPZ CASIN( RUNL P Pull running & setting tool out of packer top, and rig down aii pressure test a ui ment. 13:15 14:00 0.75 4,800 4,800 COMPZ CASIN( CIRC P Circulate bottoms up with pumps at 7 BPM - 1200 PSI. Monitor well -static. Pum d 'ob. 14:00 14:15 0.25 4,800 4,800 COMPZ CASIN( OTHR P Blow down Top drive and lines. Prep ri floor for POOH. 14:15 16:15 2.00 4,800 0 COMPZ CASIN( RUNL P POOH from 4800' to surface with running & setting tools. Observe proper hole fill. 16:15 17:00 0.75 0 0 COMPZ CASIN( RUNL P Breakout, inspect and lay down running & setting tools as per BOT re 17:00 17:15 0.25 0 0 PROD3 STK PULD P Clear & clean floor area from OBM. Lay down tools. Pull all tools to floor for whi stock run. 17:15 18:00 0.75 0 0 PROD3 STK PULD P Held brief PJSM. Discuss picking up whipstock assembly with seals & s ace out i e. Crew Chan e 18:00 19:30 1.50 0 497 PROD3 STK PULD P Mu Whipstock assembly. Pick up Seals with No-Go (4.21'), 4 3/4" Unloader sub (5.19'), 3 1/2" pup joint (11.85'), 2 -joints of 3 1/2" drill pipe (62.30'), 4 3/4" Double pin blanking sub (1.02'), 7 5/8" Bottom Trip Anchor (3.23'0, 4 3/4" Shear Disconnect (2.63'), 4 5/8" Drain sub (1.03'), 4 11/16" Debris barrier sub (1.88'), 7 5/8" Whipstock slide (15.45'), MU 6.156" Starting Mill (1.10'), 6 5/16" Lower mill (5.5'), 6 3/4" Upper mill (5.84°), 1 joint of 3 1/2" HWDP 29.78' . 19:30 20:30 1.00 497 497 PROD3 STK PULD P Make up 4 3/4" Float sub (2.35'), MWD assembly (56.32') and orient MWD to Whi stock face. 20:30 21:00 0.50 497 497 PROD3 STK PULD P Plug in and upload MWD assembly. Page 53 of 69 Time Lo s bate From To Dur S. De th E. De th Phase Gode, - Subcode T COM 09/24/2006 21:00 21:30 0.50 497 497 PROD3 STK PULD P Continue make up 4 3/4" Bumper jar (7.73'), Crossover sub (2.99'), and 3 stands of 4" Hybrid push pipe 278.43' .Total BHA = 496.54', 21:30 21:45 0.25 497 497 PROD3 STK TRIP P Run 1 stand of drill pipe & perform shallow pulse test on MWD. Good test with um s 300 GPM-1000 PSI. 21:45 22:15 0.50 497 620 PROD3 STK TRIP P Pick up 2 stands of Hybrid push pipe. Blow down Top drive & lines. Held PJSM with crew & WWT rep. Discuss saftey issues and procedure for moving Su er Sliders on each 'oint of DP. 22:15 00:00 1.75 620 1,433 PROD3 STK TRIP P TIH with 7 5/8" Whipstock assembly, 2 minutes per stand as per BOT rep from 496' - 1433' MD. Move each s;.~per slider up 1 ft from last position to prevent wear on DP. Observe proper hole fill on TIH. On/~~nnn~ ~J LV/LVVV n0:00 V n4:00 ^.00 ~ 433 4 516 IPROD2 FISI-I TRIP P r' ;ntlnU° TIH With 7 5/8" \~nllpSt.^,Ck assembly, 2 minutes per stand as per BOT rep from 1433' - 4516 MD. Move each super slider up 1 ft from last position to prevent wear on DP. Observe ro er hole fill on TIH. 04:00 04:45 0.75 4,516 4,556 PROD2 FISH OTHR P Perform MAD PASS as per geoligist from 4516' - 4556' Bit depth with pumps at 300 GPM's - 2000 PSI. Observed Lo at 2' Dee from Ian. 04:45 05:30 0.75 4,556 4,837 PROD2 FISH TRIP P Continue TIH with 7 5/8" Whipstock assembly, 2 minutes per stand as per BOT rep from 4556' - 4837' MD. Observe ro er hole fill on TIH. 05:30 06:00 0.50 4,837 4,837 PROD2 FISH OTHR P Make Top drive Connection. Pumps at 300 GPM's - 2100 PSI. Orient Whipstock face @ 13 Deg Left of High Side as per BOT rep, and Sperry Sun DD. Observe seal going into liner top at 4837'. Set down to set trip anchor @ 12K, and pick up to verify set with 1 OK overpull. Set down 35K to shear bolt. Pick up to neutral position and rotate drill string free with 5K torque. Whipstock top = 4730.5' MD. D Sand top = 4730' as per Geologist. Crew Chan e 06:00 _. 11:15 ____ 5.25 4,730 4,771 PROD3 FISH MILL P _ Mill window from 4730' - 4743' in 3.75 _ HRS, Continue to mill open hole to 4771' in 1.6 HRS. AVG ROP = 3.47 ~~--`, ~ ~ ft/hr in the window area. Gauged open hole = 16' below window. Pumps @ 300 GPM's - 1900 PSI. UP WT = 143K, SO WT = 113K, ROT WT = 127K. 100 RPM's with 2-8K torque. WOB = 2-5K. Pump 40 BBL sweep at bottom of window. Page 54 of 69 • Time Lo s Date From To Dur S, De th E. De th Phase Code Subcode T COM 09/25/2006 11:15 12:15 1.00 4,771 4,771 PROD3 FISH MILL P Pump 40 BBL Hi Visc weighted sweep at 4771' MD, while working mills through window area until cleaned up. Work window without pumps, window clean in and out. 12:15 13:00 0.75 4,771 4,771 PROD3 FISH MILL P Monitor well -static. Pump dry job. Blow down To Drive & lines. 13:00 14:45 1.75 4,771 496 PROD3 FISH TRIP P POOH from 4730' - 390'. Observe proper hole fill. SIMOPS: Test Choke manifold & floor valves for scheduled BOP test while POOH. All tests recorded on chart. 14:45 16:30 1.75 496 0 PROD3 FISH PULD P Stand back 3 -stands of Hybrid push pipe (278:43'): Breakout& !ay down Milling BHA. Lay down 6.156" Starting Mill (1.10'), 6 5/16" Lower mill (5.5'), 6 3/4" Upper mill (5.84'), 1 joint of 3 1/2" HWDP (29.78'), 4 3/4" Float sub (2.35'). Plug in and download M'v'VD assembly. Rack Back MWD assembly (56.32') in derrick, Lay down 4 3/4" Bumper jar (7.73'), Crossover sub (2.99'). Inspect & gauge upper mill to full au e of 6 3/4". 16:30 18:00 1.50 0 0 PROD3 FISH OTHR P Make up BOP Stack washing tool. Flush BOP stack while functioning HCR valves and manuals, Functioned all rams, & annular bag. Blow down all lines. Lay down stack washing assembl .Crew Chan e 18:00 21:45 3.75 0 0 PROD3 WELCT BOPE P Pull Wear Bushing. Rig up to complete scheduled BOP test. Install test joint, test plug & test BOP's & Top Drive valves. Perform Accumulator test. First 200 PSI = 50 secs, full charge = 3 min-20 sec. AVG for 5 Nitrogen bottles pressure = 2950 PSI. Rig down all test e ui ment. 21:45 22:00 0.25 0 0 PROD3 DRILL PULD P Clean & clear floor area. Send tools out, and pull tools to floor for next BHA. 22:00 22:15 0.25 0 0 PROD3 DRILL OTHR P Blow down Top Drive and all lines. Line up Choke manifold valves, and Stack valves. 22:15 22:45 0.50 0 0 PROD3 DRILL SFTY P Held PJSM with new crew, Sperry Sun DD &MWD reps. Discuss safety issues and procedure for making up BHA #12, 6 3/4" Geo-pilot drilling assembl . 22:45 00:00 1.25 0 0 PROD3 DRILL PULD P Make up 6 3/4" Drilling assembly. Make up 6 3/4" Security PDC FMF 36142 bit (1.30') with 3x21 jets for a TFA of 1.015 sq. in., 5200 Seies Geo-Pilot Assembly (16.18'), 4 3/4" Non MAg Geo Pilot Flex collar 11.55'). Page 55 of 69 Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/26/2006 00:00 01:30 1.50 30 87 PRGD3 DRILL PULD P Continue make up 4 3/4" Directional HOC (8.56'), 5 1/4" Smart Stabilizer (3.59'), 4 3/4" Gamma/Res (24.51'), 4 3/4" PWD (10.79'), 4 3/4" TM HOC 10.61' .Chan e out Pulsar & Float. 01:30 02:00 0.50 87 87 PRGD3 DRILL PULD P Plug in and download MWD assembly. 02:00 03:00 1.00 87 372 PRGD3 DRILL PULD P Continue make up 4 3/4" Welded blade Stabilizer (4.62'), 3 - jnts Non Mag Flex Drill Collars (93.28'), Crossover (2.99'), 1 - jnt of 4" HWDP (30.67'), 4 3/4" Dailey Hyd Combo Drilling jars (28.82'), and 4 - jnts of 4" HWDP 122.75'). Total BHA = 372.57'. 03:00 03:15 0.25 372 465 PRGD3 GRILL OTHR P RIH with 1 stand of DP. Perform Shallow pulse test & break in of Geo-Pilot. 03:15 05:15 2.00 465 4,683 PRGD3 DRILL TRIP P TIH with BHA #12, 6 3/4" Geo-Pilot Griiiirig asser~ibiy frum 465' - 460 Fill drill string every 25 stands. Observe ro er hole fill. 05:15 06:00 0.75 4,683 4,683 PRGD3 RIGMN SVRG P PJSM with crew. Discuss safety issues and procedure for Slip & Cut. Slip & Cut drilling line. Inspect & service Top Drive. Inspect Brakes on draw works. 06:00 07:45 1.75 4,683 4,683 PRGD3 RIGMN SVRG P PJSM, then continue to cut and slip 102' of 1-3/8" drillin line. 07:45 08:15 0.50 4,683 4,683 PRGD3 RIGMN SVRG P Service top drive. 08;15 08:30 0.25 4,683 4,770 PRGD3 DRILL TRIP P Trip in hole f/ 4683' to 4770' with out pumps on or rotating thru window. Top of window @ 4730'. Bottom of window 4743'. 08:30 12:00 3.50 4,770 5,177 PRGD3 DRILL DDRL P Drilling 6-3/4" production D lateral f/ 4770' to 5177' (407') (3566' TVD) Bit hours= 2.11, Jar (#140-01019) hours= 2.11, ART= 2.11 hrs, WO6= 4-12k, 40-110 rpm, 310-282 gpm @ 2030-1860 psi on bottom and 2000-1800 psi off bottom. Torque = 3-6k ft-Ibs on botttom and 4-5k ft-Ibs off bottom. ECD= 10.01- 9.9 ppg. Avg gas 45 units. P/U = 145-150k, S/O = 110-105k, Rot= 120-125k w/ u m s off. 12:00 15:30 3.50 5,177 5,620 PRGD3 DRILL DDRL P Drilling 6-3/4" production D lateral f/ 5177' to 5620' (443') (3539' TVD) Bit hoursm 5.0, Jar (#140-01019) hours= 5.0, ART= 2.89 hrs, WOB= 4-12k, 110- 130 rpm, 282-345 gpm @ 1860-2410 psi on bottom and 1800-2400 psi off bottom. Torque = 4-5k ft-Ibs on botttom and 4-6k ft-Ibs off bottom. ECD= 10.31-10.04 ppg. Avg gas 55 units. P/U = 150k, S/O = 105-100k, Rot= 120k w/ um s off. Page 56 of 69 .Time Logs n..a:. ~.,,..., r,. n... e _n.,.,+h ~ n.,.,•h oh~~o r`.,ao C. ~hrni-lo T ! :(l~A 09/26/2006 15:30 17:30 2.00 5,620 5,805 PROD3 DRILL DDRL P Drilling 6-3/4" production D lateral f/ 5620' to 5805' (185') (3537' TVD) Bit hours= 6.01, Jar (#140-01019) hours= 6.01, ART= 1.01 hrs, WOB= 6-10k, 130 rpm, 345-336 gpm @ 2450-2370 psi on bottom and 2400-2320 psi off bottom. Torque = 5-6k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 10.16-10.04 ppg. Avg gas 55 units. P/U = 152k, S/O = 100k, Rot= 120k w/ um s off. 17:30 18:00 0.50 5,805 5,613 PROD3 DRILL TRIP T POOH f/ 5805' to 5613' to sidetrack hole. Had a 17 deg dogleg in previous hole. 18:00 19:30 1.50 5;613 5;640 PROD3 DRILL DDRL T Trough hole f/ 5613' to 5640'. Pumping @ 344 gpm w/ 2500 psi. Rotate 130 r m w/ 5-6k ft Ib for ue. 19:30 20:30 1.00 5,640 5,805 PROD3 DRILL DDRL T Drilling 6-3/4" production D lateral f/ 5640' to 5805' (165') (???' TVD) Bit hours= 6.83, Jar (#140-01019) hours= 6.83, ART= .82 hrs, WOB= 6-10k, 130 rpm, 345-336 gpm @ 2450-2370 psi on bottom and 2400-2320 psi off bottom. Torque = 5-6k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 10.16-10.04 ppg. Avg gas 55 units. P/U = 152k, S/O = 100k, Rot= 120k w/ um s off. 20:30 00:00 3.50 5,805 6,015 PROD3 DRILL DDRL P Drilling 6-3/4" production D lateral f/ 5805' to 6015' (210') (3532' TVD) Bit hours= 9.03, Jar (#140-01019) hours= 9.03, ART= 2.2 hrs, WOB= 6-10k, 100-80 rpm, 344-340 gpm @ 2400-2530 psi on bottom and 2380-2520 psi off bottom. Torque = 5-6k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 10.0 ppg. Max gas 33 units. P/U = 150-152k, S/O = 102k, Rot= 120k w/ pumps off. Pumped a 10.7 ppg, 180 vis sweep while drilling @ 6006'. A 15% estimated increase in cuttings observed the shakers. Page 57 of B9 Time Lo s Date From To Dur S. De th E. De th Phase Code - Subcode T COM 09/27/2006 00:00 06:00 6.00 6,015 6,814 PROD3 DRILL DDRL P Drilling 6-3/4" production D lateral f/ 6015' to 6814' (799') (3524' TVD) Bit hours= 13.08, Jar (#140-01019) hours= 13.08, ART= 4.05 hrs, WOB= 4-8k, 120-110 rpm, 340-330 gpm @ 2420-2660 psi on bottom and 2350-2600 psi off bottom. Torque = 6-7k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 10.0-10.37 ppg. Max gas 60 units. P/U = 155-158k, S/O = 102k, Rot= 120k w/ pumps off. Pumped a 10.7 ppg, 180 vis sweep while drilling @ 6530'. No significant increase in cuttings. A 6' Concretion ~ endi~ ~g @ G015', then a 3' concretion was drilled @ 6181' to 6184'. 06:00 12:00 6.00 6,814 7,495 PROD3 DRILL DDRL P Drilling 6-3/4" production D lateral f/ 6814' to 7495' (681') (3518' TVD) Bit hours= 17.38, Jar (#140-01019) hours= 17.38, ART= 4.3 hrs, WOB= 6-8k, 90-130 rpm, 305-336 gpm @ 2660-2340 psi on bottom and 2600-2280 psi off bottom. Torque = 6-7k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 10.24-10.37- ppg. AVG gas 75 units. P/U = 155-165k, S/O = 102-95k, Rot= 120k w/ pumps off. 12:00 18:00 6.00 7,495 8,395 PROD3 DRILL DDRL P Drilling 6-3/4" production Dlateral f/ 7495' to 8395' (900') (3521' TVD) Bit hours= 21.32, Jar (#140-01019) hours= 21.32, ART= 3.94 hrs, WOB= 6-10k, 130 rpm, 330-347 gpm @ 2580-2880 psi on bottom and 2500-2820 psi off bottom. Torque = 6-7k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 10.38 -10.79 ppg. AVG gas 55 units. P/U = 165k, S/O = 95k, Rot= 120k w/ pumps off. Pumped a 30 bbl Hi vis (180) weighted (10.7 ppg) sweep while drilling @ 8344'. A 10-15% increase in cuttings noticed when sweep was back at shakers. A 2' concretion was drilled @ 8116' to 8118'. Page 58 of 69 • ~ Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T COM 09/27/2006 18:00 00:00 6.00 8,395 9,102 PROD3 DRILL DDRL P Drilling 6-3/4" production D lateral f/ 8395' to 9102' (707') (3519' TVD) Bit hours= 26.04, Jar (#140-01019) hours= 26.04, ART= 4.72 hrs, WO6= 8-10k, 130 rpm, 340-348 gpm @ 2840-3200 psi on bottom and 2790-3170 psi off bottom. Torque = 6-8k ft-Ibs on botttom and 5-6k ft-Ibs off bottom. ECD= 10.79-10.93 ppg. AVG gas 55 units. P/U = 165-167k, S/O = 95-92k, Rot= 95-125k w/ pumps off. Pumped a 30 bbl Hi vis (180) weighted (10.7 ppg) sweep while drilling @.8999'. A 15% increase in cuttings noticed when sweep was back at shakers. A 8' Concretion was drilled f/ 8712' to 8720', then a 18' Concretion was drilled f1872i' to 8739', t hen a 12' Co~~cretion was drilled f/ 8991' to 9003'. 09/28/2006 00:00 03:30 3.50 9,102 9,490 PROD3 DRILL DDRL P Drilling 6-3/4" production D lateral f/ 9102' to 9490' (388') (3524.28' TVD) Bit hours= 28.54, Jar (#140-01019) hours= 28.54, ART= 2,5 hrs, WOB= 6-10k, 130 rpm, 340-348 gpm @ 3150-3250 psi on bottom and 3050-3170 psi off bottom. Torque = 7-8k ft-Ibs on botttom and 6-7k ft-Ibs off bottom. ECD= 10.8-11.54 ppg. Max gas 183 units. P/U = 165-170k, S/O = 92-88k, Rot= 125-120k w/ pumps off. Pumped a 30 bbl Hi vis (200) weighted (10.8 ppg) sweep while drilling @ 9400' (3523' TVD). An approximate 25% increase in cuttings noticed when sweep was back at shakers. A 3' Concretion was drilled f/ 9176' to 9179', then a 11' Concretion was drilled f/ 9293' to 9304'. Page 59 of &9 Timelo s Date From To = Dur S. De th E. De th' Phase Code Subcode T COM 09/28/2006 03:30 04:45 1.25 9,490 9,599 PROD3 DRILL DDRL P Drilling 6-3/4" production D lateral f/ 9490' to 9599' (109') (3520' TVD) Bit hours= 29.12, Jar (#140-01019) hours= 29.12, ART= .58 hrs, WOB= 6-10k, 130 rpm, 340-348 gpm @ 3150-3250 psi on bottom and 3050-3170 psi off bottom. Torque = 7-8k ft-Ibs on botttom and 6-7k ft-Ibs off bottom. ECD= 10.8-11.54 ppg. Max gas 183 units. P/U = 165-170k, S/O = 92-88k, Rot= 125-120k w/ pumps off. A 4' concretion was drilled f/ 9555' to 9559'. When the Concretion @ 9555' was drilled, it caused an 11 deg dogleg in the well (9 deg/100' build and 5 deg turn ri ht . 04:45 05:00 0.25 9,599 9,466 PROD3 DRILL TRIP T Survey check shot @ 9564'. POOH f/ 9599' to 9466' for sidetrack because of an 11.01 deg dogleg in hole (9 deg per hundred build and 5 de turn ri ht . 05:00 06:30 1.50 9,466 9,490 PROD3 DRILL DDRL T Trough hole f/ 9466' to 9490'. Pumping 340 gpm w! 3100 psi. Rotating 130 r m w/ 6500 ft Ib for ue. 06:30 08:30 2.00 9,490 9,599 PROD3 DRILL DDRL T Drilling 6-3/4" production D lateral f/ 9490' to 9599' (109') (3528' TVD) Bit hours= 30.98, Jar (#140-01019) hours= 30.98, ART= 1.86 hrs, WOB= 6-8k, 110 rpm, 340 gpm @ 3200 psi on bottom and 3120 psi off bottom. Torque = 7-8k ft-Ibs on botttom and 6-7k ft-Ibs off bottom. ECD= 11.33 ppg. Max gas 183 units. P/U = 170k, S/O = 85k, Rot= 120k w/ um s off. 08:30 12:00 3.50 9,599 10,076 PROD3 DRILL DDRL P Drilling 6-3/4" production D lateral f/ 9599' to 10076' (477') (3530' TVD) Bit hours= 33.46, Jar (#140-01019) hours= 33.46, ART= 2.48 hrs, WOB= 4-8k, 130 rpm, 340-348 gpm @ 3330-3480 psi on bottom and 3280-3400 psi off bottom. Torque = 7-9k ft-Ibs on botttom and 6-7k ft-Ibs off bottom. ECD= 10.43-10.96 ppg. Avg gas 60 units. P/U = 170-175k, S/O = 85-80k, Rot= 120-118k w/ um s off. Page 64 of 69 Time Logs VtlLC 09/28/2006 r"IVUi 12:00 I V 18:00 vul 6.00 .+. ~c u~ 10,076 ~ 10,822 PRODS DRILL DDRL P Drilling 6-3/4" production D lateral f/ 10076' to 10822' (746') (3516' TVD) Bit hours= 37.77, Jar (#1 40-01 01 9) hours= 37.77, ART= 4.31 hrs, WO6= 4-10k, 80-130 rpm, 293-345 gpm @ 2690-3670 psi on bottom and 2600-3560 psi off bottom. Torque = 7-9k ft-Ibs on botttom and 7k ft-Ibs off bottom. ECD= 10.6-11.2 ppg. Avg gas 75 units. P/U = 175-180k, S/O = 80-75k, Rot= 120-118k w/ pumps off. Pumped a 20 bbl Hi Weight, Hi vis sweep while drilling @ 10645'. Slight increase in cuttin s noted shakers. 18:00 00:00 6.00 10,822 11,698 PRODS DRILL DDRL P 09/29/2006 00:00 03:00 3.00 11,698 12,095 PROD3 DRILL DDRL P Drilling 6-3/4" production D lateral f/ ~ 11698' to 12095' (397') (3506' TVD) Bit hours= 42.74, Jar (#140-u1019) hours= 42.74, ART= 1.63 hrs, WOB= 8-12k, 90 rpm, 280-290 gpm @ 2640-2900 psi on bottom and 2620-2590 psi off bottom. Torque = 9-10k ft-Ibs on botttom and 8-9k ft-Ibs off bottom. ECD= 11.1-11.50 ppg. Max gas 230 units. P/U = 195-198k, S/O = 75k, Rot= 120k w/pumps off. Pumped a 20 bbl Hi Weight (10.8 ppg), Hi vis (200) sweep while drilling 12050'. 03:00 04:45 1.75 12,095 11,741 PRODS DRILL CIRC P Pump 20 bbls hi vis (200), hi wt (10.8 ppg) to inside casing while roating 130 rpm w/ 9k ft Ib torque. Pumping 337 gpm w/ 3700 psi. Recip pipe f/ 12095' to 12000' until sweep inside of casing, then continue backreaming to 11749', till sweep out of hole. Circ total of 712 bbls. 04:45 05:30 0.75 11,741 12,095 PRODS DRILL REAM P Ream from 11741' back to bottom @ 12095'. No down weight without rotation. Pump 280 gpm w/ 2575 psi. Rotate 100 rpm w/ 8k ft Ib torque. ECD's 11.12 ppg. Pumped a total of 149 bbls while reaming back to bottom. 05:30 07:45 2.25 12,095 10,650 PRODS DRILL TRIP P POOH L/D single 4" dp, continue POOH 15 stands to 10650', hole taking proper displacement. No problems. Record PU and SO wt's eve 5 stands. 07:45 08:00 0.25 10,650 10,650 PRODS DRILL OWFF P Monitor well. Clean rig floor. Hole takin a small amount of fluid. 08:00 08:15 0.25 10,650 10,650 PRODS DRILL CIRC P Pump dryjob. 08:15 09:15 1.00 10,650 10,200 PRODS DRILL TRIP P POOH f/ 10650' to 10200'. Tight spot 10200'. Work i e. Page 61 of 69 Time Los - Date From To Dur S. De th E. De th Phase .Code Subcode T COM 09/29/2006 09:15 10:30 1.25 10,200 9,654 PROD3 DRILL REAM P Backream out of hole f/ 10200' to 9654'. Pumping 340 gpm w/ 3320 psi, rotating 120 rpm w/ 7k ft Ib torque. Pulling 45 ft per min. Record PU and SO wt's eve 5 stands. 10:30 12:00 1.50 9,654 8,560 PROD3 DRILL REAM P Backream out of hole every other stand f/ 9654' to 8560'. Pumping 340 gpm w/ 3320 psi, rotating 120 rpm w/ 7k ft Ib torque. Pulling 45 ft per min. Record PU and SO wt's every 5 stands. 12:00 16:30 4.50 8,560 4,965 PROD3 DRILL REAM P Backream out of hole every other stand f/ 8560' to 4965'. Pumping 340 gpm w/ 3320 psi, rotating 120 rpm w/ 7k ft Ib torque. Pulling 45 ft per min. Record PU and SO wt's every 5 stands. 16:30 16:45 0.25 4,965 4,683 PROD3 DRILL TRIP P Pull 3 stands f/ 4965' to 4683'. No pumping or rotatioi; wh ile pulli~ y- these stands throu h window. 16:45 17:00 0.25 4,683 4,683 PROD3 DRILL OWFF P Monitor well. Static. 17:00 18:00 1.00 4,683 4,683 PROD3 DRILL CIRC P Pump 30 bbl hi vis (200), hi wt (10.8 ppg) sweep and circulate 3 bottom's up (4250 strokes/ 427 bbls). Pumped @ 345 gpm w/ 2750 psi. Rotate 120 rpm w/ 4-5 k ft/Ib torque. Observed hole losses of 8b h. 18:00 19:15 1.25 4,683 4,683 PROD3 RIGMN SVRG P Service rig and top drive. Crown and blocks serviced. Measure windwall pin ockets for wall b derrick board. 19:15 23:45 4.50 4,683 10,309 PROD3 DRILL TRIP P Trip in hole f/ 4683' to 10309'. Record PU and SO wt's every 5 stands. Fill i e after 25 stands. 23:45 00:00 0.25 10,309 10,402 PROD3 DRILL REAM P Start reaming in the hole f/ 10309'. No Down weight. Ream to 10402'. Pumping 85 gpm w/ 600 psi. Rotate 50 rpm w/ 7-8k ft Ib torque. Running speed 20-30 ft/min. Record PU and SO wt's eve 5 stands. 09/30/2006 00:00 04:00 4.00 10,402 12,095 PROD3 DRILL REAM P Continue reaming in the hole f/ 10402' to 12095'. No Down weight. Ream to 10402'. Pumping 85 gpm w/ 600 psi. Rotate 50 rpm w/ 7-8k ft Ib torque. Running speed 20-30 ft/min. Record PU and SO wt's eve 5 stands. 04:00 05:30 1.50 12,095 12,095 PROD3 DRILL CIRC P Pump 23 bbl Hi vis (140), hi wt (10.8 ppg) sweep. Circ total of 7250 strokes (725 bbls). Held PJSM vv/truck drivers and crew prior to displacement to SFOBM. Pump @ 340 gpm w/ 4000 si. ECD's 12.1. 05:30 05:45 0.25 12,095 12,095 PROD3 DRILL OWFF P Monitor well. OK. Take SPR's w/ 8.8 ppg OBM in hole @ 12095' (3501' TVD). Page 62 of 69 ~ Time Lo s Date From To Dur S. De th E De th Phase Code Subcode T COM 09/30/2006 05:45 06:45 1.00 12,095 12,095 PROD3 DRILL CIRC P Displace "D" lateral open hole from 8.8 ppb OBM to 8.7 ppg SFOBM. Pump 340 gpm w/ 3800-3600 psi. Rotate 130 rpm w/ 7-9k ft Ib's torque. Pumped 345 bbls SFOBM, follow w/ 24 bbls dry job, chase w/ 6 bbls OBM. 06:45 07:00 0.25 12,095 12,065 PROD3 DRILL PULD P Break off single 4" HWDP. UD jt. Drop 2.32" rabbit w/ wireline 100' lus. 07:00 10:15 3.25 12,065 4,700 PROD3 DRILL TRIP P POOH on elevators f/ 12065' to 4700' to run 4-1/2" PLOP and Drop liner. Record PU and SO wt's every 5 stands in o en hole. Above window. 10:15 10:30 0.25 4,700 4,700 PROD3 DRILL OWFF P Monitor well. Static. -_ 10:30 12:15 1.75 4,700 372 PROD3 DRILL TRIP P Continue POOH f/ 4700' to BHA @ 372'. Record PU and S0 wt's every 10 stands in cased hole. 12:15 14:00 1.75 372 92 PROD3 DRILL PULD P UD HWDP, jars and flex collars to f e Slled. 14:00 14:30 0.50 92 92 PROD3 DRILL OTHR P Sperry Sun download MWD tools. Clean and clear ri floor. 14:30 15:30 1.00 92 0 PROD3 DRILL PULD P UD MWD tools, break bit. UD Sperry Sun GeoPilot. 15:30 16:15 0.75 0 0 COMPZ CASIN( RURD P RU casing running tools while laying down subs f/ BHA # 12. 16:15 16:30 0.25 0 0 COMPZ CASIN( SFTY P PJSM on running 4-1/2" Plop and drop liner f/ "D" lateral 16:30 18:00 1.50 0 1,285 COMPZ CASIN( RNCS P Running 4-1l2" Plop and drop slotted and blank liner f/ "D" lateral to 1285'. Record PU and SO wt's every 20 jts in casin . 18:00 23:00 5.00 1,285 7,151 COMPZ CASIN( RNCS P Continue running 4-1/2" Plop and drop slotted and blank liner f/ "D" lateral f/ 1285' to 7151'. Record PU and SO wt's every 20 jts in casing, every 10 jts in open hole. With all the liner in the hole: PU wt 122k, SO wt 93k. Rot wt 105k. Rotating 25 rpm w/ 4-5k ft Ib torque, PU wt= 115k, SO wt 103k. 23:00 00:00 1.00 7,151 8,185 COMPZ CASIN( RUNL P Run 4-1/2" slotted/blank liner as a Plop and drop in the "D" lateral. Run liner on 4" DP f/ 7151' to 8185'. Run 3 stands slick, then start w/ 4" dp w/ super sliders. Record PU and SO wt's eve 5 stands in o en hole. 10/01/2006 00:00 02:30 2.50 8,185 12,081 COMPZ CASIN( RUNL P Run 4-i/2" slotted/blank liner as a Plop and drop in the "D" lateral. Run liner on 4" DP f/ 8185' to 12081'. Run 31 stands 4" dp w/ super sliders, 4 stands 4" HWDP, then 15 stands of Hybrids ((2) 5" DC's and one 4" HWDP). Record PU and SO wt's every 5 stands in o en hole. Page 63 of 69' Time Los Date From To Dur S. De th E. De th Phase `Code Subcode T COM 10/01/2006 02:30 02:45 0.25 12,081 12,092 COMPZ CASIN( OTHR P Rotate liner @ 12081'. Without rotating: PU wt 215k, SO wt 93k. Rotating wt 155k. Rotate @ 25 rpm w/ 8k ft Ibs torque. While rotating: PU wt 180k, SO wt 135k. 02:45 03:00 0.25 12,092 12,092 COMPZ CASIN( OTHR P PU/MU single 4" HWDP, rotate and tag bottom @ 12095', PU and L/D single. Drop 29/32" ball. Make up top drive. 03:00 03:45 0.75 12,092 12,081 COMPZ CASIN( CIRC P Rotate and PU string to set shoe @ 12081.34'. Pump ball down @ 3bpm w/ 500 psi f/ 26 bbls, then slow to 2 bpm w/ 320 psi till ball on seat (411 strokes). Pressure to 3000 psi, to release liner, set down to 110k (30k), PU and string wt was 170k (loss of 45k liner weight). PU 10', pressure to 3875 si to blow ball seat. 03:45 04:i5 v.50 4,929 4,730 ~ CCMPZ~ CASIN( RU^JL P POOH wet 2 stands of Hybrids. Make up top drive, pull 3rd stand out. Strap stand in. 04:15 04:45 0.50 4,730 4,730 COMPZ CASIN( CIRC P Circ and rotate to clean key slot in whipstock. Pump 80 spm w/ 1525 psi. Rotate 40 rpm w/ 4k ft Ibs torque. Pump a total of 197 bbls. 8.6 ppg mud wt. 04:45 05:00 0.25 4,730 4,730 COMPZ CASIN( RUNL P Monitor well. Static. Pump dry job. 05:00 06:00 1.00 4,730 2,996 COMPZ CAS1N( RUNL P Blow down top drive. POOH f/ 4730' to 2996' 06:00 08:00 2.00 2,996 0 COMPZ CASIN( RUNL P Continue POOH w/ liner running tools f/ "D" lateral. 08:00 08:30 0.50 0 0 COMPZ CASIN( OTHR P Break and UD Baker tools to pipe shed. 08:30 09:15 0.75 0 0 COMPZ CASIN( OTHR P Clear and clean rig floor. UD casing runnin tools, subs, ets. 09:15 09:30 0.25 0 0 COMPZ FISH SFTY P PJSM on picking up Baker Whipstock retieval hook assembl . 09:30 10:00 0.50 0 59 COMPZ FISH PULD P MU BHA to retieve whipstock. MU hook to a single 3-1/2" HWDP, bumper 'ars, oil 'ars, x-o. 10:00 10:30 0.50 59 425 COMPZ FISH TRIP P PU 3 stands hybrids as part of BHA and a sin le stand of 4" su er sliders. 10:30 10:45 0.25 425 425 COMPZ RIGMN SFTY P PJSM on cutting drilling line. 10:45 12:15 1.50 425 425 COMPZ RIGMN SVRG P Slip and cut 126' of 1-3/8" drilling. line. 12:15 15:00 2.75 425 4,736 COMPZ FISH TRIP P Continue RIH w/ Baker whipstock retrieval assembly. Ran 35 super slider stands, 4 stands HWDP and 8 stands H brids, then sin le HWDP. 15:00 15:30 0.50 4,736 4,736 COMPZ FISH CIRC P Break circ @ 3bpm w! 400 psi. PU wt 170k, SO wt 135k. 15:30 15:45 0.25 4,736 4,736 COMPZ FISH FISH P Found slot and hooked @ 4735.5'. Pulled 90k over to 260k. Page 64 of 69 Time. Logs n~+o ~r~,., T~ Iliir c no..rh F::Ilanth Phaca (:nrle Snhrnrla T CdM ~.o.~ 10/01/2006 ~ ~~~~~ 15:45 ~~ 16:00 ~..., 0.25 .,....,, .,, 4,736 ~.. ~., ... 4,726 .....,.., COMPZ _--- FISH ------- TRIP P PU and L/D single HWDP. 16:00 16:45 0.75 4,726 4,660 COMPZ FISH CIRC P Pull stand up and circ @ 4660'. Circ bottom's up @ 8 bpm w/ 2140 psi. Pum 200 bbls. 16:45 17:00 0.25 4,660 4,660 COMPZ FISH OTHR P Monitor well. Static. 17:00 17:30 0.50 4,660 4,660 COMPZ FISH CIRC P Pump 25 bbls dry job, drop 2.32" rabbit. Blow down to drive. 17:30 18:00 0.50 4,660 3,370 COMPZ FISH TRIP P POOH w/ whipstock assembly f/ 4660' to 3370' 18:00 21:00 3.00 3,370 0 COMPZ FISH TRIP P POOH w/ whipstock retieval BHA and whipstock assembly. 15 bbls over talc on tri out. 21:G0 21:30 0.50 0 0 _- CCP,~PZ FISH PULD P UD Baker Fishing assembly (Hooking assembl 21:30 22:30 1.00 107 0 COMPZ FISH PULD P UD Whipstock assembly: Whipstock, circ sub, anchor, debris sub, 2 jts of 3-1/2" HV`JDP, safety shear sub, unloader sub, 15' 3-1/2" pup, no go and seals. 22:30 23:00 0.50 0 0 COMPZ FISH PULD P Cleaning rig floor and UD Baker tools. Hole takin 6.5 b h. 23:00 23:00 0.00 0 0 COMPZ CASIN( RURD P RU casing tools to run 4-1/2" Hook Han er. 23:00 23:15 0.25 0 0 COMPZ CASIN( SFTY P PJSM on PU Hook Hanger assembly f/ "D" lateral 23:15 00:00 0.75 0 30 COMPZ CASIN( PUTB P PU/MU 4-1/2" Slot/blank hook hanger assembl 10/02/2006 00:00 02:30 2.50 30 266 COMPZ CASIN( OTHR P MU Sperry Sun MWD up to Baker hook han er, orient same. 02:30 02:45 0.25 266 266 COMPZ CASIN( DHEQ P Shallow test MWD w/ 100 gpm w/ 490 si. 02:45 05:45 3.00 266 4,875 COMPZ CASIN( RUNL P RIH w/ hook hanger on 4" dp. Use 35 stands w/ super sliders, 4 stands 4" HWDP, then hybrids ((2) 5" DC's w/ one 4" HWDP). Top of window is @ 4730', Bottom of window @ 4743'. Tagged up on no go (x-o bushing) in "B" lateral 4875'. 05:45 07:00 1.25 4,875 4,875 COMPZ CASIN( RUNL P On fourth attempt to exit window w/ 4-1/2" bent joint w/ mule shoe, we did exit window. Run to 4875'. 07:00 07:30 0.50 4,875 4,963 COMPZ CASIN( CIRC P Continue RIH w/ hook hanger assembly f/ 4875' to 4963'. Circulate 100 gpm w/ 890 psi. Orient hook hanger to hook window. PU wt 170k, SO wt 140k. Page S5 of 69 1 I Time Lo s Date From To Dur S. De th E. De th Phase ' Code Subcode T COM 10/02/2006 07:30 08:00 0.50 4,963 4,985 COMPZ CASIN( OTHR P Slack off and hook window, unhook, rotate 180 deg to pass through w/ hook hanger, slack off and tag no go (crossover bushing in Plop and drop assembly @ 4995'), PU above window, orient to hook window (oriented to 17 Left, when hooked went to 3 left), set down 30k on hook. PU wt 170k, SO wt 147k. 08:00 08:45 0.75 4,985 4,985 COMPZ CASIN( OTHR P Drop 29/32" ball, circ down to seat w/ 125 gpm w/ 1050 psi for 250 stokes, then to 85 gpm till on seat @ 40.46 bbls pumped. Pressure to 1450 psi, hold, continue to increase pressure to 2800 psi (opening ECP, dropping to 1570 psi. Increase pressure to 2800 psi w/ 3 strokes (.301 bbls). PU to 170k. 08:45 09:00 0.25 4,718 4,668 COMPZ CASIN( RUNL P POOH and stand back a stand.Pump d 'ob. Blow down to drive. 09:00 11:45 2.75 4,668 0 COMPZ CASIN( RUNL P POOH w/ Baker Hook Hanger running tools. 11:45 13:15 1.50 0 0 COMPZ CASIN( OTHR P Break and UD Baker running tools. 13:15 14:00 0.75 0 0 COMPZ CASIN( OTHR P Clean and clear rig floor while laying down Baker tools and subs. 14:00 14:30 0.50 0 0 COMPZ CASIN( SFTY P PJSM on running 4-1/2" LEM for "D" lateral. 14:30 16:00 1.50 0 204 COMPZ CASIN( PUTB P PU/MU LEM assembly f/ "D" lateral to 204'. 16:00 18:00 2.00 204 3,600 COMPZ CASIN( RUNL P RIH w/ LEM f/ 204' to 3600' on 4" drill strin . 18:00 19:15 1.25 3,600 4,866 COMPZ CASIN( RUNL P Continue RIH w/ LEM on 4" drill string f/ 3600' to 4866'. LEM sna ed in 19:15 19:30 0.25 4,866 4,866 COMPZ CASIN( OTHR P Set down 30k, Pull to 230k and snap out. RIH and latch in w/ 30k on LEM. PU to 180k. Drop 1-3/4" ball. PU wt 192k, SO wt 125k. 19:30 19:45 0.25 4,866 4,866 COMPZ CASIN( CIRC P Circ ball to seat. Pump 3 bpm w/ 400 psi ,then to 2 bpm w/ 260 psi. Ball on seat 32.7 bbls. 19:45 20:30 0.75 4,866 4,866 COMPZ CASIN( OTHR P Pressure to 2500 psi, hold, then increase to 4000 psi to neutralize pusher tool, slack off to 115k to release HRD setting tool. Break off top drive. Test annulus to 1000 psi f/ 5 min., chart test. 20:30 20:45 0.25 4,866 4,574 COMPZ CASIN( RUNL P After LEM set and released: PU wt 170k, SO ~n~t 140k. POOH to 4574' 20:45 21:00 0.25 4,574 4,574 COMPZ CASIN( CIRC P Pump dry job, blow down top drive. 21:00 23:15 2.25 4,574 0 COMPZ CASIN( RUNL P POOH w/ LEM running tools f/ 4574' to surface. 23:15 00:00 0.75 0 0 COMPZ CASIN( OTHR P UD Baker LEM running tools. Page 66 of 69 Time Logs Rata Frnm Tn nur S nenth E Deoth Phase. Code Subcode T COM 10/03/2006 00:00 00:45 0.75 0 0 COMPZ CASIN( OTHR P UD Baker LEM running tools. 00:45 01:15 0.50 0 0 COMPZ CASIN( OTHR P Clean and clear rig floor. Monitor well via tri tank and hole fill um . 01:15 01:45 0.50 0 0 COMPZ RPCOti OTHR P Pull Vetco/Gray wear bushing. Hole takin 2 b h. 01:45 02:15 0.50 0 0 COMPZ RPCON RURD P PJSM, Rig up to run 4-1/2" completion, GBR casing crew and e ui ment. 02:15 02:30 0.25 0 0 COMPZ RPCOti SFTY P PJSM on running 4-1/2" 12.6 ppf L-80 IBT-mod completion. GBR casing crew, Baker completion supervisor, tour usher and ri su ervisor. 02:30 03:15 0.75 0 65 COMPZ RPCOI~ RCST P PU Baker 4-3/4" seal assembly, Made up 1 jt 4-1/2" 12.6 ppg L-80 IBT-mod tubing, then 4-1/2" pup on CMU did not make u correct. 03:15 04:45 1.50 65 65 COMPZ RPCOti PULD T Break out CMU assembly w/ pup, hreak and L/D hnttprr; hnwip, PI I/n/lu another 4-1/2" 12.6 ppf L-80 IBT-mod pup which did not make up correct again. UD 1 st joint and replace w/ jt # 150 (same length 31.07'). Make up pup jt 6.17', then make up CMU. Torque tubing to 2500 ft Ib torque to middle makeup mark. Probably overtorqued collar of 1 st jt. Collar was hot. Pin end of pup jt screwed in ast make u mark. 04:45 06:00 1.25 65 600 COMPZ RPCO(~ RCST P Continue MU 4-1/2" completion. Checking torque and MU. 2500 ft Ib seems to be optimum torque on 4-1/2" IBT-M. Check make up mark on every connection (4-3/8" MU thread loss on 't . 06:00 09:45 3.75 600 4,713 COMPZ RPCOh RCST P Continue MU 4-1/2" completion. Run f/ 600' to 4672' (top of LEM ZXP packer (LEM Tally)). Locate @ 4683.66' (11.01' inside ZXP (LEM Tally)), Tubing detail =4686.01'. Checking torque and MU. 2500 ft Ib seems to be optimum torque on 4-1/2" IBT-M (4-3/8" thread loss). Note: Tagged 2.35' deeper by tubing tall numbers. 09:45 10:30 0.75 4,713 4,627 COMPZ RPCOh HOSO P UD 3 joints (149, 148, 147), leaving jt # 146 in hole. PU 7.80' 4-1/2" 12.6 ppf L-80 IBT-mod tubing pup drifted to 3.91". Rabbit Vetco Gray hanger and u to 3.885". 10:30 10:45 0.25 4,627 4,635 COMPZ RPCOI~ HOSO P MU 7.80' 4-1/2" 12.6 ppf L-80 IBT-mod tubing pup drifted to 3.91". MU jt # 147. 10:45 11:15 0.50 4,635 4,708 COMPZ RPCOti HOSO P MU Vetco Gray hanger w/ pup, then landing joint. RIH and land hanger. Install BPV, RILDS. Page 67 of 69 l Time Lo s Date From To Dur S. De 'th E. De th Phase Code Subcode T COM 10/03/2006 11:15 12:00 0.75 0 0 COMPZ DRILL OTHR P Clean and clear rig floor, laying down casing equipment, subs and Baker tools. 12:00 12:30 0.50 0 0 COMPZ DRILL RURD P RU to laydown 4" drill string f/derrick, usin mousehole. 12:30 12:45 0.25 0 0 COMPZ DRILL SFTY P PJSM on laying down 4" drill string f/ derrick, usnin mousehole in stack. 12:45 18:00 5.25 0 0 COMPZ DRILL PULD P Lay down 4". Layed down 15 stands of hybrids ((2) 5" DC's w/ a single 4" HWDP), 4 stands 4" HWDP, then 30 stands of slick drill i e. 18:00 00:00 6.00 0 0 COMPZ DRILL PULD P Lay down 37 stands of 4" slick drill pipe. Note: 15 slick stands + 40 stands w/ su er sliders left to be Ia ed down. 10/04/2006 00:00 08:30 8.50 0 0 COMPZ DRILL PULD P Lay down 15 stands 4" slick dp + 40 stands w/ su er sliders . 08:30 10:00 1.50 0 0 COMPZ DRILL PULD P Lay down thread protectors. Clear and clean rig r'ioor. iviove i i stands 5" uP in derrick f/ off driller's side to driller's side while cleaning drip pan under rig floor. Total of 21 stands 5" dp in derrick + 2 stands 5" HWDP + stand w/ 'ars. 10:00 10:45 0.75 0 0 COMPZ DRILL PULD P L/D Mousehole, subs, lifting subs, elevators, test plugs, etc. not needed on ri an more. 10:45 11:00 0.25 0 0 COMPZ DRILL OTHR P Blow down all surface equipment and um s. 11:00 15:00 4.00 0 0 COMPZ RPCOti NUND P Nipple down 13-5/8" BOPE. Cleaning its. 15:00 15:45 0.75 0 COMPZ RPCOI~ NUND P NU Vetco Gray tree. Install actuator on horizontal tree. 15:45 16:00 0.25 0 0 COMPZ RPCOh OTHR P Rig up to test tree. 16:00 16:15 0.25 0 0 COMPZ RPCOh DHEO P Test tree to 5000 psi. Chart test f/ 10 minutes. 16:15 16:45 0.50 0 0 COMPZ RPCOh SFTY P PJSM w/little Red on freeze protection/ displacement to diesel. Test lines to 3000 si. 16:45 19:30 2.75 0 0 COMPZ RPCOh FRZP P Freeze protect/ displace well by pumping down 7-5/8" x 4-1 /2" annulus. CMU open @ 4631'. Taking returns from tubing to pits. Monitor rates, pressures and return volume to pits. 11 bbls to fill well. 16 bbls pumped to get returns to pits. Pumped a total of 217 bbls diesel. Calc volume surface to surface is 'i92 bbis. Did not loose over a bbl on displacement. start @ 1bpm w/ 200 psi, when pumping @ 2.5 bpm appeared to be losing 1/3 bbl. Pumped @ 2bpm till diesel @ CMU w/ 600 psi, then increase rate to keep about 500 si. Final rate 4 b m w/ 475 si. Page 68 of 69 Time: Lo s Date From To Dur S. be th E. De th Phase Code Subcode T COM 10/04/2006 19:30 20:00 0.50 0 0 COMPZ RPCOti FRZP P Rig down and blow down freeze rotection a ui ment and hoses. 20:00 20:45 0.75 0 COMPZ RPCOh NUND P Cleaning pits, Remove double valve on inner annulus, install companion flange and guage. Remove fittings on Actuated valve, install guages. Tubing pressure 200 psi. 7-5/8" x 4-1/2" ann pressure= 225 psi. 10-3/4" x 7-5/8" ressure = 175 si. 20:45 00:00 3.25 0 0 COMPZ RPCOh OTHR P PU lubricator, Install BPV w/ Vetco/Gray. Secure well. Continue cleaning pits. Blow down steam to sub module. R/D mud lines, water lines and steam lines between modules. Cleaning pits, preparing to clean cellar. Tubing pressure 200 psi. 7-5/8" x 4-1/2" ann pressure= 225 psi. 10-3/4" x 7-5/8" ressure = 175 si. Page f 9 of 69 • 08-Nov-06 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1 J-102L1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 5,040.59' MD Window /Kickoff Survey: 5,046.00' MD (if applicable) Projected Survey: 12,242.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date Si ned ~ ~ r ~~ ~ Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~uC~ - lL l • ~4'~LL L®G ~I'IZ~'YS19'ti~'T ~I: T®: State of Alaska November 6, 2006 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7`" Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data: 1J-102, PB 1, PB2, PB3, Ll, L2, L2 PBl & L2 PB2 AK-MW-4559176 1 LD~UG formatted CD Rom with verification listing. APIA: 50-029-23317-00, -?0, -71, -72, -60, -61, -?3 & -74. PLEASE ACKNOWLEDGE RECEIPT BY SIGrI'vG AND RETLRYIlYG a COPY OF THE. TR~vS1~IITT:~L LETTER TO THE ATTENTION OF: Sperry Drilling Sen~ices Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: ,~ l i ~, .~ Signed: v7J~' ~' ~ ~ ~'' ~c~IJ ! J ° tot ! ~ ~~ 1 , ~~~ ~b~ 'ii ~ ~ ~~,' i Randy Thomas Greater Kuparuk Area Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUfTE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, West Sak Oil Pool, 1J-102L1 ConocoPhillips Alaska, Inc. Permit No: 206-111 Surface Location: 2245' FSL, 2446' FEL, SEC. 35, T 11 N, R 10E, UM Bottomhole Location: 359' FSL, 583' FEL, SEC. 11, TION, R10E, UM Dear Mr. Thomas: Enclosed is the approved application for permit to drill the above referenced service well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. The permit is for a new wellbore segment of existing well KRU 1J-102, Permit No 206-110 API No. 50-029-23317-00. Injection should continue to be reported as a function of the original API number stated above. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission/ ;s~etroleum field inspector at (907) 659-3607 (pager). /~ No DATED this~day of August, 2006 cc: Department of Fish 8s Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA Z ~~~ " ~~ ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 ,lllL ~ 6 2006 Alaska Oil & Gas Cans. Cftrrtmisslon 1a. Type of Work: Drill ^~ Re-drill ^ Re-entry ^ 1b. Current Well Class: Exploratory Development Oil ^ Stratigraphic Test ^ Service ^~ Development Gas ^ Multiple Zone^ Single Zone Q 1c. Specify if well is propo DI'~~@ Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillipsAlaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: 1J-102L1 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 12492' • TVD: 3582' 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surface: 2245' FSL, 2446' FEL, Sec. 35, T11N, R10E, UM 7. Property Designation: ADL 25661 & 25662 West Sak Oil Pool Top of Productive Horizon: 1664' FSL, 549' FEL, Sec. 35, T11 N, R10E, UM 8. Land Use Permit: ALK 471 & 2177 13. Approximate Spud Date: 8/22/2006 Total Depth: 359' FNL, 583' FEL, Sec. 11, T10N, R10E, UM ~ 9. Acres in Property: 2560 14. Distance to Nearest Property: > 2 miles 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558761 y- 5946057 ' Zone- 4 10. KB Elevation (Height above Gi_): 40' RKB feet 15. Distance to Nearest Well within ool: ypge , ~D 16. Deviated wells: Kickoff depth: 5185 ft. Maximum Hole Angle: 92° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 1637 psig Surface: 1237 psig 18. Casing Program S ecifications Setting Depth Quantity of Cement Size p Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD TVD (including stage data) 42" 20" x 34" 94# K-55 Welded 80' 40' 40' 108' 108' 260 cf ArcticCRETE 13.5" 10.75" 45.5# L-80 BTC 2618' 40' 40' 2646' 2243' ~ 490 sx AS Lite, 180 sx DeepCRETE 9-7/8" 7-5/8" 29.7# L-80 BTCM 5979' 40' 40' 5988' , 3755' 350 sx DeepCRETE 6.75" 4.5" 12.6# L-80 IBTM 7307' 5185' 3621' 12492' . 3582' ~ see above 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ~,~ BOP Sketch ^ Drilling Program / Time v. Depth Plot ^ Shallow Hazard Analysis Q Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program 0 20 AAC 25.050 requirements ^/ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Pat Reilly @ 265-6048 Printed Name Randy Thomas Title Greater Kuparuk Area Drilling Team Leader Signature \ ~.f "~--~ i -~ ~ ~ Phone Z G 5- ~ ~, S U Date 7 ~Z s /p(a Pre h n All u - Commission Use Only Permit to Drill Number: Z.~(p /~/ API Number: /~ 5o-Q Z~}'~ ~ ~ ~ ~ - (~d Permit Approval Date: . ~ ~ See cover letter for other requirements Conditions of approval : If box is checked, well m of be used to explore for, test, or produce coalbed m ane, gas hydrates, or gas contained in shales: 'eS~ ~P ~„TGS ~~~ Samples req'd: Yes ^ No ~ u log req'd: Yes ^ No Other: ~~`` ~~ ~ H2S measures: Yes ^ No ^~ Di I svy req'd: Yes ~ No ^ PPROVED BY THE COMMISSION ~~/_ DATE: ,COMMISSIONER ~. Form 10-401 Revised 12/2005 ~ ~ ~ ~ ~~ ~ ~ v V ~ Submit in Duplicate Appli~for Permit to Drill, Well 1J-102 L1 Revision No.O Saved: 24-Jul-06 Permit It -West Sak Well #1J-102 L1 •~~~# ~., App/ication for Permit to Dri// Document +~k ,, tl~~c'V~ell M~ x i m i a g V~ell Va14B Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (t) ....................................................................................................... 2 2. Location Summary ................................................................................................... 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. Drilling 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 ............................................................................ 3 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Drilling Fluid Program ............................................................................................. 4 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 4 Lateral Mud Program (MI VersaPro Mineral Oil Base) ........................................................................... 4 9. Abnormally Pressured Formation Information ..................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .................................................................................................. 5 10 . Seismic Analysis ..................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ................................................................................................ 5 11 . Seabed Condition Analysis ..................................................................................... 5 Requirements of 20 AAC 25.005 (c)(11) ................................................................................................ 5 12 . Evidence of Bonding .............................................................................................. 5 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 5 ORIGINAL 1J-102L1 PERMIT IT Page 1 of 6 Printed: 24-Jul-06 • AppliL~for Permit to Drill, Well 1 J-102 L1 Revision No.O Saved: 24-Jul-06 13. Proposed Drilling Program .................................................................................... 5 Requirements of 20 AAC 25.005 (c)(13) ................................................................................................ 5 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 6 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 6 15. Attachments ............................................................................................................. 6 Attachment 1 Directional Plan ................................................................................................................ 6 Attachment 2 Drilling Hazards Summary ............................................................................................... 6 Attachment 3 Well Schematic ................................................................................................................ 6 1. Well Name Requirements of 20 AAC 25.005 (1) Each wel/ must be idertti~ed by a unique name designated by the operator and a unique API number assigned by the commission under 2fI AAC 25. Q40(b). Far awet/ with multiple we// branches, each branch must similarly be identified by a unique nante and API number by adding a suffix to the name designated for the wail by the operator and to the number assigned to the weft by the commission, The well for which this Application is submitted will be designated as iJ-102 Li. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An app/ication for a Permit to Dri/I must be accampanied by each of the foAfowing items, except for an item afready on file with the commission and identified in the application: (2) a plat identifying the property and the property's owners and showing (A)che coordinates of the proposed /ocation of the we!/ at the surface, at the top of each objective formation, and at tota/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 total depth; Location at Surface 2245' FSL & 2446' FEL -Sec 35 - T11N - R10E ASPZone 4 NAD 27 Coordinates RKB Elevation 108' AMSL Northings: 5,946,057 Eastings: 558,761 Pad Elevation 81' AMSL Location at Top of Productive Interval West Sak ~~B" Sand 1664' FSL & 549' FEL -Sec 35 - T11N - R10E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 5,185 Northings: 5,945,491 Eastings: 560,662 Total l/ertica/De th, RKB.• 3 621 Total t/erticalDe th, SS.• 3,500 Location at Total De th 359' FNL & 583' FEL -Sec 11 - T10N - R10E ASP Zone 4 NAD 27 Coordinates MedSUred De th, RKB.• 12,492 Northings: 5,938,189 Eastings.• 560,693 Total ~ertica/De th RKB; 3,582 Total ~ertica/ De th, SS.• 3,461 and (DJ other information required by 20 AAC 25,1150(b), 1J-102L1 PERMIT lT Page 2 of 6 Printed: 24-Jul-O6 Appli~or Permit to Drill, Well 1J-102 L1 Revision No.O Saved: 24-Jul-06 Requirements of 20 AAC 25.050(b) If a wet/ is to be intentional/y deviated, the application for a Permit to t7ril/ (Form 1II-401) must (I) include a p/at, drawn to a suitable scale, sho~.ing the path of the proposed we/lbore, including all adjacent we!/bores w/thin 200 feet ofany portian of the proposed wel% Please see Attachment 1: Directional Plan and (2) for al/ we!/s witfain Z00 feet of the proposed we/Ibore (AJ Gst the names of the operators of those we/Is, 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) state that the applicant is the on/y 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 fot/owing items, except for an item a/ready on file wr"th the commission and identified in the app/r"cation; (3) a diagram and description of the blowout prevention equipment (BOPS) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicab/e; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1J-102 L1. Please see information on Doyon 15 blowout prevention equipment placed on file with the Commission. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application far a Permit to Drill must be accompanied 6y each of the fo!/owr"ng items, except for an item already on file with the commission and identified in the application: (mil) informatr"on on drilling hazards, inc/udng (A) the maximum downho% pressure that maybe encountered, crr""ten"a used to determine r"t, and maximum potentia! surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the 1J area are 0.45 psi/ft, or 8.7 ppg EMW (equivalent mud weight). Pressures are predicted based on the undisturbed West Sak pressure gradient. 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 1,237 psi, calculated: MPSP =(3,638 ft TVD)(0.45 - 0.11 psi/ft) =1,237 psi (e) data on patentia! gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning patentia/ causes of ho% problems such as abnormally geo pressured strata, lost circalotion zones, and zones that have a propensity for differential sticking; Please see Attachment 2: 1J-102 L1 Drilling Hazards Summary. 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An app/ication for a Permit to Dri/l must be accompanied by each of the fa//owing items, except for an item a/ready an fir/e with the commission and identified in the application: (5) a description of the procedure far conducting formation integrity tests, as required under 20 AAC 25.030(t~,• The parent wellbore, iJ-102, will be completed with 7-5/8" 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 with the ~~Formation Integrity Test Procedure" that ConocoPhillips Alaska placed on file with the Commission. 1J-102L1 PERMIT IT Page 3 of 6 Printed: 24-Jul-06 Applicr~or Permit to Drill, Well 1J-102 L1 Revision No.O Saved: 24-Jul-06 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An app/icatian for a Permit to Dri// must be accompaMed by each of the fo/%wing items, except for an item a/ready on file with the commission and identified in the application; (6) a complete proposed casing and cementing program as required by 20 AAC 25.030, and a description of any slotted /iner, pre- perforated /iner, or sereen to be installed; Casing and Cementing Program Hole Top Btm Csg/Tbg Size Weigh Length MD/TVD MD/TVD OD in in t Ib/ft Grade Connection ft ft ft Cement Pro ram 4-1/2 6-3/4" A Sand 12.6 L-80 IBTM 8,403 5,285 / 3,638 13,688 / 3,728 Slotted- no cement ter l (iJ-102) J - ra a __ __ _ 4-1/2 ~ lotted 6-3/4" B Sand Lateral (1J-102 Li) 12.6 L-80 IBTM 7,307 5,185/ 3,621 12,492 / 3,582 Slotted- no cement - 12.6 L-80 IBTM 7 322 551 4 865/ 3 12 187 / 3 509 - o ce Slotted Lateral (iJ-102 L2) , , , , , 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An appGcatr"on for a Permit to Drift must be accompanied by each of the fallowr"ng items, except for an r`tem a/ready on file with the commr`ssr"on and identified in the application: (7) a diagram and description of the diverter system as required by 20 AAC 25.035, un/ess this requirement is waived by the commission under 20 AAC 25.035(hJ(2); No diverter system will be utilized during operations on 1J-102 L1. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An app/r'cation for a Permit to Dr/t! must be accompan/ed by each of the following items, except for an item already an file with the commission and identified in the application. (8) a dri/ling fluid program, me/uding a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: Lateral Mud Program (MI VersaPro, Mineral Oil Base) Value Densit pp 8.6 Plastic Viscosity Ib/100 s 15 - 25 Yield Point cP 18 28 HTHP Fluid loss (ml/30 min <4 0 @ 200psi & . 150° Oil /Water Ratio 70 / 30 Electrical Stabilit 650-900 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 Rig 15. 1J-102L1 PERMlT IT Page 4 of 6 Printed: 24-Jul-06 ~,~ ORIGINAL Applic~or Permit to Drill, Well 1 J-102 L1 Revision No.0 Saved: 24-Jul-06 9. 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 commr`ssian and identified in the application; (9) for an exploratory or stmt/graphic test weft, a tabulation setting out the depths of predicted abnormal/y geo pressured strata as required by 20 AACZS, d33(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) An application for a Permit to Drif/ must be accompanied by each of the following items, except for an item a/ready on fi/e with the conanvssian and identified in the application; (Ill) for an exploratory ar stratigraphic test well, a seismic refraction or reflection analysis as required by ZQ AAC 2s. 061(a); Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(11) An application for a Permit to Dril/ must be accompanied by each of the follotvirtg items, except for an item already on fete with the commission and identified r`n the application; (ZY) for a well dri/led from an ol5`shore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vess% an analysis afseabed conditions as required by Zll AAC25. (I61(b); Not applicable: Application is not for an offshore well. 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) An application for a Pernut to Drill must be accompanied by each of the following items, except for an item already on fife with the commission and identified in the application. (12) evidence showing that the requirements of20AAC25.lJZS {Bonding}have been met; Evidence of bonding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. 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 is listed below. Please refer also to Attachment 3, Well Schematic. Note: Previous operations are covered under the 1J-102 Application for Permit to Drill. 1. Run and set Baker WindowMaster whipstock system, at window point of 5,185' MD / 3,621' TVD, the top of the B sand. 2. Mill 6-3/4" window. POOH. 3. Pick up 6-3/4"drilling assembly with LWD and MWD and PWD. RIH. 4. Drill to TD of B sand lateral at 12,492' MD / 3,582' TVD, as per directional plan. 5. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 6. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 7. PU and run 4-1/2"slotted liner. 8. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 9. Release hanger running tool. POOH. 1J-102L1 PERMIT IT Page 5 of 6 ---yyy f ~ ~ Printed. 24-Jul-O6 i Applic~or Permit to Drill, Well 1J-102 L1 Revision No.0 Saved: 24-Jul-06 10. Make up junction isolation / re-entry assembly (Lateral Entry Module or LEM) and RIH to depth. Orient and set packer atop assembly and release from assembly. POOH. 11. POOH and prepare to drill the "D" sand lateral 1J-102L2. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An app/ication fcrr a Permit to Dri/l music be accompanied by each of the foflawing items, except for an item already on file with the commission and identified in the app/ication: (Y4) a genera! description of how the operator plans to dispose of drilling mud and cuttr"ngs and a statement of whether the operator intends to request authorization under 20 AAC 25. tJBIJ for an annuiar dispasa/ operation in ti7e wet/.,• Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids into a permitted annulus on iJ 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 1J Pad, hauled to the Prudhoe Bay Grind and Inject Facility for temporary storage and eventual processing for injection down an approved 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. ConocoPhillips Alaska may in the future request authorization for the use of this well for annular disposal operations. 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 Well Schematic 1J-102L1 PERMIT IT Page 6 of 6 Printed: 24-Jul-06 ORIGINAL • ConocoPhillips Alaska ConocoPhillips Alaska Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-102 -Slot 1J-102 1J-102 L1 Plan: 1J-102 L1 (wp07) Proposal Report 20 May, 2006 A~~ Sperry Drilling Service ORIGINAL Project: Kuparuk River Unit CASING DETAILS Site: Kuparuk 1J Pad Well: Plan 1J-102 No MD TVD TVDss Name Size Wellbore: 1J-102 L1 1 120.00 120.00 -1 20" 20 Plan: 1J-102 L1 (wp07) 2 2645.82 2243.00 2122 10 3/4" " 10-3/4 3 5185.48 3621.06 3500.06 TO 7 5/8 W7-5/8 412492.53 3582.00 3461 41/2" 41/2 -400 3600 4000 FORMATION TOP DETAILS No7VDPath TVDSS MDPath Formation 1 1533.00 1412 1644.52 Base Perm 2 1671.00 1550 1833.69 T3 3 1962.00 1841 2246.77 K15 4 2243.00 2122 2645.82 T3 + 560 5 2987.00 2866 3690.24 Ugnu C 6 3230.00 3109 4065.23 Ugnu B 7 3311.00 3190 4209.74 Ugnu A 8 3417.00 3296 4430.93 K13 16" 9 3551.00 3430 4665.07 Wsak D 10 3592.00 3471 5047.31 Wsak C 11 3621.07 3500.07 5185.53 Wsak B 0° 10° L1 : TOW @ 5185ft MD, 3621ft TVD ?o° ' L1 : BOW, 5197ft MD, 3623ft TVD 30° i i _ _ _ _ _ 9 _ _ _ _ _ _ _ _ _ _ _ _ _ _~_ _ _ '_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ _ _ _ _ _ _ - _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ - Oe - , _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ L _ _ - - _ _ _ 1' _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __',1o3i4•• ____-__ ~,'_____ r'~ L1:End30'RatholeBuild@5°/100ftto94°Inc- 5227ftMD,3627ftTVD___________________ ______ ,' ,' L1 : BHL @ 12493ft MD, 3582ft TVD - 4112" - - - - - - - - - - - - - r - - - i 45° ' ~ i i i i' i ~ i'/ 1J-102 LZ(wp0 1J-102 L1(wp0 i ,' L1 : Begin GeoSteer in B-Sand 5431ft MD, 3638ft TVD ~ -- -T- --------- ----------------------------- -------'~---r------------ h~ -- -- - ------- ------- _,,,- \ ~ _ - -' . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _~ _ _ ~_ 1J-102 L1 T5 (Tce) (wp07 _ ---- -'o--- ~-'-- ~ _ ~ J _ _ _ _ _ _ _ _ _ _ _ _ _ < _~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _I_ _ _ _ 1 _ _ _ _ _ _ _ _ _ _ _ _ _ _^~ _ _ _ _ / _ ~ O C ~ _ ° ' i i ~ i i Wsak B ~ 1J-102 L1 T1 (wp07 0 1J-102 L7 T2 (wp07 i 1J-102 L1 T3 (wp07 i i 1J-102 L1 T4 (wp07 1J-102(wp07 HALLIBURTON Sperry Draping 5etvicas -800 -400 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 Vertical Section at 180.00' (1000 ft/in) ConocoPhillips Alaska 5200 5600 6000 6400 6800 7200 7600 8000 8400 8800 10 3l4" o 0 ~~ ~ ° ~ ° ,~50 175° L1:TOW~5185ftMD,3621ftN ________________________________ L7 :BOW, 5197ft MD, 3623ft N , - ' ' L1 : End 30' Rathole Build ~ 5°/100ft to 94° Inc - 5227ft MD, 3627ft D L1: Begin GeoSteerin B-Sand 5431ft MD,3638ft N -2520 1J-102 L1 DD Poly @ 95%(wp07) ~ -2880 DD Polygon Describes a corridor 100' wide with a 50'+/-allowance E/W from the I ~ proposed wellbore. i -3240 ~ I o O I ' o I -3600 + I L ~ I I. Z 1J-102 L1 Geo Poly (wp07) ~ -3960 Geo Polygon portrays the maximum positional ~ uncertainty , @ 95% confidence, if actual wellpath is at I -4320 outer edge of Red DD polygon. - - - -- --Y- ' i I -4680 I i I I -5040 I I Project: Kuparuk River Unit ' Site: Kuparuk 1J Pad -saoo Well: Plan 1J-102 I Wellbore: 1J-102 L1 ' Plan: 1J-102 L1 (wp07) -5760 I -6 -7200 T M~~muths to Tree IJo-;n Magnetic North: 23.88° Magnetic Field Strength: 57604.OnT Dip Angle: 80.80° Date: 7/1 /2006 Model: BGGM2006 CASING DETAILS No MD TVD TVDss Name Size 1 120.00 120.00 -1 20" 20 2 2645.82 2243.00 2122 10 3/4" 10-3/4 3 5185.48 3621.06 3500.06 7 5/8" TOW5/8 4 12492.53 3582.00 3461 4 1/2" 4-1/2 ----------- 1J-102 L1 T1(wp07 _ _ _ _ _ _ _ 1J-102 L1 T2 (wp07 I I I ___________ 1J-102 L1 T3 (wp07 I I I 1 1 I ~____________ 1J-102 L1 T4(wp07 I I I I i #-iALLfBL1RTC}N 1 Sperry Drilllny Ssrvlc~s ~0° I I ~" ConocoPhillips I Alaska t i I 1J-102 L1 TS(Toe)(wp07 ~8° ' --, a v2" -~' J- - - - - - - L1 : BHL ~ 12493ft MD, 3582ft ND - 4 1/2~ -2160 -1800 -1440 -1080 -720 -360 0 360 720 1080 1440 1800 2160 2520 2880 3240 3600 3960 4320 ~.-' ~ Halliburton Energy Services ~ ~„~~~,~,~~~TQRI ~©t'K)CQ~11~~IpS Planning Report -Geographic ° ~---.~______..~__~,a,..~~.. ~~~ rtlli Barrett Alaska Database: EDM 2003.11 b48 Company: ConocoPhillips Alaska Inc. Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-102 Wellbore: 1 J-1:02 L1 Design: 1J-102 L1 (wp07) Sperry D rrg es Local Co-ordinate Reference: Well Plan 1J-102 -Slot 1J-102 TVD Reference: Doyon 15 Plan @ 121.OOft (Doyon 15 (81+40)) MD Reference: Doyon 15 Plan @ 121.OOft (Doyon 15 (81+40)) North Reference: True Survey Calculation Method: Minimum Curvature Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor - - __ _ ~ Well Plan 1J-102-Slot 1J-102 Well Position +N/-S 0.00 ft Northing: 5,946,056.80 ft +E/-W 0.00 ft Easting: 558,761.70 ft Position Uncertainty 0.00 ft Wellhead Elevation: ft m Latitude: 70° 15' 47.609" N Longitude: 149° 31' 29.797" W Ground Level: 81.OOft -_ Wellbore -_ 1J-102 L1 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2006 7/1/2006 23.88 80.80 57,604 Design 1J-102 L1 (wp07) Audit Notes: Version: 10 Phase: PLAN Tie On Depth: 5,185.47 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction (ft) (ft) Ift) (°) 40.00 0.00 0.00 180.00 Plan Summary Measured Vertical Dogleg Build Turn Depth Inclination Azimuth Depth +N/-S +E/_Vy Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) 5,185.47 80.00 183.00 3,621.06 -580.64 1,896.96 0.00 0.00 0.00 0.00 5,197.47 81.91 183.00 3,622.95 -592.48 1,896.34 15.90 15.90 0.00 0.00 5,227.47 81.91 183.00 3,627.17 -622.14 1,894.78 0.00 0.00 0.00 0.00 5,430.75 92.01 184.13 3,637.94 -824.47 1,882.17 5.00 4.97 0.56 6.40 5,987.69 92.01 184.13 3,618.41 -1,379.63 1,842.10 0.00 0.00 0.00 0.00 6,076.51 91.10 179.78 3,616.00 -1,468.34 1,839.07 5.00 -1.02 -4.90 -101.75 6,085.37 90.99 180.12 3,615.84 -1,477.20 1,839.08 4.00 -1.23 3.81 107.91 8;331.10 90.99 180.12 3,577.00 -3,722.59 1,834.48 0.00 0.00 0.00 0.00 8,379.19 89.21 179.39 3,576.92 -3,770.67 1,834.69 4.00 -3.71 -1.50 -157.90 9,109.38 89.21 179.39 3,587.00 -4,500.75 1,842.41 0.00 0.00 0.00 0:00 9,130.33 90.05 179.43 3,587.14 -4,521.70 1,842.63 4.00 4.00 0.19 2.73 10,621.61 90.05 179.43 3,585.94 -6,012.91 1,857.36 0.00 0.00 0.00 0.00 10,635.76 89.48 179.42 3,586.00 -6,027.06 1,857.50 4.00 -4.00 -0.10 -178.60 10,662.05 89.95 180.36 3,586.13 -6,053.35 1,857.55 4.00 1.78 3.58 63.57 11,926.15 89.95 180.36 3,587.27 -7,317.42 1,849.57 0.00 0.00 0.00 0.00 11,992.54 90.57 177.78 3,586.97 -7,383.79 1,850.65 4.00 0.94 -3.89 -76.45 12,492.54 90.57 177.78 3,582.00 -7,883.39 1,870.02 0.00 0.00 0.00 0.00 5/20/2006 2:30:09PM Page 2 of 7 4 ~~y~~' , - ~ a COMPASS 2003.11 Build 50 ~'' ~ H E i ~ llib t S r - " ur nergy erv ces a on HAt~l.Ie~t~~'tC7N Ct~CiOCQ ~ 1t~~1~35 Planning Report -Geographic ----~~-----~ ~~_.__ -~-~- Alaska terry arming S~-rrnces Database: _EDM_2003.11_b48 Local Co-ordinate Reference: Well Plan 1J-102 -Slot 1J-102 Company: ConocoPhillips Alaska Inc. ND Reference: Doyon 15'Plan @ 121.OOft (Doyon 15 (81+40)) Project: Kuparuk River Unit MD Reference: Doyon 15 Plan @ 121.OOft (Doyon 15 (81+40)) Site: Kuparuk 1 J Pad North Reference: True Well: Plan 1J-102 Survey Calculation Method: Minimum Curvature Wellbore: 1J-102 L1 Design: 1J-102 L1 (wp07) Planned Survey 1J-102 L1 (wp07) Map Map MD Inclination Azimuth ND SSND +N/-S +E/.yy Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) 5,185.47 80.00 183.00 3,621.06 3,500.06 -580.64 1,896.96 5,945,491.04 560,662.95 L1 : TOW @ 5185.48' MD, 3621.06' ND : 1664 .Oft FSL 8~ 549.2' FEL -Sec 35 -T11 N - R10E - Wsak B - 7 5/8" TOW 5,197.47 81.91 183.00 3,622.95 3,501.95 -592.48 1,896.34 5,945,479.20 560,662.42 L1 : BOW, 5197.48' MD, 3622.95' ND 5,200.00 81.91 183.00 3,623.30 3,502.30 -594.98 1,896.21 5,227.47 81.91 183.00 3,627.17 3,506.17 -622.14 1,894.78 L1 : End 30' Rathole B uild @ 5°/100ft to 94° In c - 5227.48' MD, 3627.17' ND 5,300.00 85.51 183.41 3,635.11 3,514.11 -694.10 1,890.75 5,400.00 90.48 183.96 3,638.61 3,517.61 -793.81 1,884.34 5,430.75 92.01 184.13 3,637.94 3,516.94 -824.47 1,882.17 L1 : Begin GeoSteer in B-Sand 5430.76' MD, 3637.94' ND 5,500.00 92.01 184.13 3,635.51 3,514.51 -893.50 1,877.19 5,600.00 92.01 184.13 3,632.01 3,511.01 -993.18 1,869.99 5,700.00 92.01 184.13 3,628.50 3,507.50 -1,092.86 1,862.80 5,800.00 92.01 184.13 3,624.99 3,503.99 -1,192.54 1,855.60 5,900.00 92.01 184.13 3,621.49 3,500.49 -1,292.21 1,848.41 5,987.69 92.01 184.13 3,618.41 3,497.41 -1,379.63 1,842.10 6,000.00 91.88 183.53 3,617.99 3,496.99 -1,391.90 1,841.28 6,076.51 91.10 179.78 3,616.00 3,495.00 -1,468.34 1,839.07 1J-102 L1 T 1 (wp07) 6,085.37 90.99 180.12 3,615.84 3,494.84 -1,477.20 1,839.08 6,100.00 90.99 180.12 3,615.59 3,494.59 -1,491.82 1,839.05 6,200.00 90.99 180.12 3,613.86 3,492.86 -1,591.81 1,838.85 6,300.00 90.99 180.12 3,612.13 3,491.13 -1,691.79 1,838.64 6,400.00 90.99 180.12 3,610.40 3,489.40 -1,791.78 1,838.44 6,500.00 90.99 180.12 3,608.67 3,487.67 -1,891.76 1,838.23 6,600.00 90.99 180.12 3,606.94 3,485.94 -1,991.75 1,838.03 6,700.00 90.99 180.12 3,605.21 3,484.21 -2,091.73 1,837.82 6,800.00 90.99 180.12 3,603.48 3,482.48 -2,191.72 1,837.62 6,900.00 90.99 180.12 3,601.75 3,480.75 -2,291.70 1,837.41 7,000.00 90.99 180.12 3,600.02 3,479.02 -2,391.69 1,837.21 7,100.00 90.99 180.12 3,598.29 3,477.29 -2,491.67 1,837.00 7,200.00 90.99 180.12 3,596.56 3,475.56 -2,591.66 1,836.80 7,300.00 90.99 180.12 3,594.83 3,473.83 -2,691.64 1,836.59 7,400.00 90.99 180.12 3,593.10 3,472.10 -2,791.63 1,836.39 7,500.00 90.99 180.12 3,591.37 3,470.37 -2,891.61 1,836.18 7,600.00 90.99 180.12 3,589.64 .3,468.64 -2,991.60 1,835.98 7,700.00 90.99 180.12 3,587.91 3,466.91 -3,091.58 1,835.78 7,800.00 90.99 180.12 3,586.19 3,465.19 -3,191.57 1,835.57 7,900.00 90.99 180.12 3,584.46 3,463.46 -3,291.55 1,835.37 8,000,00 90.99 180.12 3,582.73 3,461.73 -3,391.54 1,835.16 8,100.00 90.99 180.12 3,581.00 3,460.00 -3,491.52 1,834.96 8,200.00 90.99 180.12 3,579.27 3,458.27 -3,591.50 1,834.75 8,300.00 90.99 180.12 3,577.54 3,456.54 -3,691.49 1,834.55 8,331.10 90.99 180.12 3,577.00 3,456.00 -3,722.59 1,834.48 1J-102 L1 T 2 (wp07) 8,379.19 89.21 179.39 3,576.92 3,455.92 -3,770.67 1,834.69 5,945,476.70 560,662.31 5,945,449.53 560,661.10 5,945,377.54 560,657.63 5,945,277.80 560,651.99 5,945,247.12 560,650.07 DLSEV Vert Section (°/100ft) (ft) 0.00 580.64 15.90 592.48 0.00 594.98 0.00 622.14 5.00 694.10 5.00 793.81 5.00 824.47 5,945,178.06 560,645.62 0.00 893.50 5,945,078.34 560,639.21 0.00 993.18 5,944,978.62 560,632.79 0.00 1,092.86 5,944,878.90 560,626.38 0.00 1,192.54 5,944,779.17 560,619.96 0.00 1,292.21 5,944,691.72 560,614.33 0.00 1,379.63 5,944,679.45 560,613.61 4.99 1,391.90 5,944,603.00 560,612.00 5.00 1,468.34 5,944,594.14 560,612.08 4.00 1,477.20 5,944,579.52 560,612.16 .0.00 1,491.82 5,944,479.54 560,612.74 0.00 1,591.81 5,944,379.57 560,613.31 0.00 1,691.79 5,944,279.60 560,613.89 0.00 1,791.78 5,944,179.62 560,614.46 0.00 1,891.76 5,944,079.65 560,615.04 0.00 1,991.75 5,943,979.67 560,615.61 0.00 2,091.73 5,943,879.70 560,616.19 0.00 2,191.72 5,943,779.73 560,616.76 0.00 2,291.70 5,943,679.75 560,617.34 0.00 2,391.69 5,943,579.78 560,617.92 0.00 2,491.67 5,943,479.80 560,618.49 0.00 2,591.66 5,943,379.83 560,619.07 0.00 2,691.64 5,943,279.86 560,619.64 0.00 2,791.63 5,943,179.88 560,620.22 0.00 2,891.61 5,943,079.91 560,620.79 0.00 2,991.60 5,942,979.94 560,621.37 0.00 3,091.58 5,942,879.96 560,621.94 0.00 3,191.57 5,942,779.99 560,622.52 0.00 3,291.55 5,942,680.01 560,623.09 0.00 3,391.54 5,942,580.04 560,623.67 0.00 3,491.52 5,942,480.07 560,624.25 0.00 3,591.50 5,942,380.09 560,624.82 0.00 3,691.49 5,942,349.00 560,625.00 0.00 3,722.59 5,942,300.92 560,625.58 4.00 3,770.67 5/20/2006 2:30:09PM Page 3 of 7 COMPASS 2003.11 Build 50 •~~~~~ ,~,,,.,~ C©t10COP~'1t~It~S Alaska Database: EDM 2003:11 b48 Company: ConocoPhillips Alaska Inc. Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-102 Wellbore: 1J-102 L1 Design: 1 J-102 L1 (wp07) Halliburton Energy Services l-f.A1~.Ik,.fBURTDN Planning Report -Geographic - ° _~..._.._~ ~n'Y Drilli~ ~rvlaas Local Co-ordinate Reference: Well Plan 1J-102 -Slot 1J-102 TVD Reference: Doyon 15 Plan @ 121.OOft (Doyon 15 (81+40)) MD Reference: .:Doyon 15 Plan @ 121.OOft (Doyon 15 (81+40)) North Reference: True Survey Calculation Method: Minimum Curvature Planned Survey 1J-102 L1 (wp07) Map Map MD Inclination Azimuth TVD SSTVD +NI-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 8,400.00 89.21 179.39 3,577.20 3,456.20 -3,791.48 1,834.91 5,942,280.12 560,625.96 0.00 3,791.48 8,500.00 89.21 179.39 3,578.58 3,457.58 -3,891.46 1,835.97 5,942,180.16 560,627.80 0.00 3,891.46 8,600.00 89.21 179.39 3,579.97 3,458.97 -3,991.45 1,837.02 5,942,080.19 560,629.64 0.00 3,991.45 8,700.00 89.21 179.39 3,581.35 3,460.35 -4,091.43 1,838.08 5,941,980.23 560,631.48 0.00 4,091.43 8,800.00 89.21 179.39 3,582.73 3,461.73 -4,191.42 1,839.14 5,941,880.26 560,633.31 0.00 4,191.42 8,900.00 89.21 179.39 3,584.11 3,463.11 -4,291.40 1,840.20 5,941,780.30 560,635.15 0.00 4,291.40 9,000.00 89.21 179.39 3,585.49 3,464.49 -4,391.39 1,841.25 5,941,680.34 560,636.99 0.00 4,391.39 9,100.00 89.21 179.39 3,586.87 3,465.87 -4,491.37 1,842.31 5,941,580.37 560,638.83 0.00 4,491.37 9,109.38 89.21 179.39 3,587.00 3,466.00 -4,500.75 1,842.41 5,941,571.00 560,639.00 0.00 4,500.75 1J-102 L1 T3 (wp07) 9,130.33 90.05 179.43 3,587.14 3,466.14 -4,521.70 1,842.63 5,941,550.05 560,639.38 4.00 4,521.70 9,200.00 90.05 179.43 3,587.08 3,466.08 -4,591.37 1,843.31 5,941,480.40 560,640.61 0.00 4,591.37 9,300.00 90.05 179.43 3,587.00 3,466.00 -4,691.36 1,844.30 5,941,380.42 560,642.38 0.00 4,691.36 9,400.00 90.05 179.43 3,586.92 3,465.92 -4,791.36 1,845.29 5,941,280.45 560,644.15 0.00 4,791.36 9,500.00 90.05 179.43 3,586.84 3,465.84 -4,891.35 1,846.28 5,941,180.47 560,645.91 0.00 4,891.35 9,600.00 90.05 179.43 3,586.76 3,465.76 -4,991.35 1,847.27 5,941,080.50 560,647.68 0.00 4,991.35 9,700.00 90.05 179.43 3,586.68 3,465.68 -5,091.34 1,848.25 5,940,980.53 560,649.45 0.00 5,091.34 9,800.00 90.05 179.43 3,586.60 3,465.60 -5,191.34 1,849.24 5,940,880.55 560,651.22 0.00 5,191.34 9,900.00 90.05 179.43 3,586.52 3,465.52 -5,291.33 1,850.23 5,940,780.58 560,652.99 0.00 5,291.33 10,000.00 90.05 179.43 3,586.44 3,465.44 -5,391.33 1,851.22 5,940,680.60 560,654.76 0.00 5,391.33 10,100.00 90.05 179.43 3,586.36 3,465.36 -5,491.32 1,852.21 5,940,580.63 560,656.52 0.00 5,491.32 10,200.00 90.05 179.43 3,586.28 3,465.28 -5,591.32 1,853.20 5,940,480.65 560,658.29 0.00 5,591.32 10,300.00 90.05 179.43 3,586.20 3,465.20 -5,691.31 1,854.18 5,940,380.68 560,660.06 0.00 5,691.31 10,400.00 90.05 179.43 3,586.12 3,465.12 -5,791.31 1,855.17 5,940,280.70 560,661.83 0.00 5,791.31 10,500.00 90.05 179.43 3,586.04 3,465.04 -5,891.30 1,856.16 5,940,180.73 560,663.60 0.00 5,891.30 10,600.00 90.05 179.43 3,585.96 3,464.96 -5,991.30 1,857.15 5,940,080.75 560,665.37 0.00 5,991.30 10,621.61 90.05 179.43 3,585.94 3,464.94 -6,012.91 1,857.36 5,940,059.15 560,665.75 0.00 6,012.91 10,635.76 89.48. 179.42 3,586.00 3,465.00 -6,027.06 1,857.50 5,940,045.00 560,666.00 4.00 6,027.06 1J-102 L1 T4 (wp07) 10,662.05 89.95 180.36 3,586.13 3,465.13 -6,053.35 1,857.55 5,940,018.71 560,666.26 4.00 6,053.35 10,700.00 89.95 180.36 3,586.17 3,465.17 -6,091.29 1,857.31 5,939,980.77 560,666.31 0.00 6,091.29 10,800.00 89.95 180.36 3,586.26 3,465.26 -6,191.29 1,856.68 5,939,880.78 560,666.46 0.00 6,191.29 10,900.00 89.95 180.36 3,586.35 3,465.35 -6,291.29 1,856.05 5,939,780.79 560,666.61 0.00 6,291.29 11,000.00 89.95 180.36 3,586.44 3,465.44 -6,391.29 1,855.42 5,939,680.80 560,666.76 0.00 6,391.29 11,100.00 89.95 180.36 3,586.53 3,465.53 -6,491.29 1,854.79 5,939,580.81 560,666.91 0.00 6,491.29 11,200.00 89.95 180.36 3,586.62 3,465.62 -6,591.28 1,854.16 5,939,480.82 560,667.06 0.00 6,591.28 11,300.00 89.95 180.36 3,586.71 3,465.71 -6,691.28 1,853.53 5,939,380.83 560,667.21 0.00 6,691.28 11,400.00 89.95 180.36 3,586.80 3,465.80 -6,791.28 1,852.90 5,939,280.84 560,667.36 0.00 6,791.28 11,500.00 89.95 180.36 3,586.89 3,465.89 -6,891.28 1,852.26 5,939,180.85 560,667.51 0.00 6,891.28 11,600.00 89.95 180.36 3,586.98 3,465.98 -6,991.28 1,851.63 5,939,080.86 560,667.66 0.00 6,991.28 11,700.00 89.95 180.36 3,587.07 3,466.07 -7,091.27 1,851.00 5,938,980.87 560,667.80 0.00 7,091.27 11,800.00 89.95 180.36 3,587.16 3,466.16 -7,191.27 1,850.37 5,938,880.88 560,667.95 0.00 7,191.27 11,900.00 89.95 180.36 3,587.25 3,466.25 -7,291.27 1,849.74 5,938,780.89 560,668.10 0.00 7,291.27 11,926.15 89.95 180.36 3,587.27 3,466.27 -7,317.42 1,849.57 5,938,754.74 560,668.14 0.00 7,317.42 11,992.54 90.57 177.78 3,586.97 3,465.97 -7,383.79 1,850.65 5,938,688.39 560,669.74 4.00 7,383.79 12,000.00 90.57 177.78 3,586.90 3,465.90 -7,391.25 1,850.94 5,938,680.93 560,670.08 0.00 7,391.25 12,100.00 90.57 177.78 3,585.91 3,464.91 -7,491.17 1,854.81 5,938,581.05 560,674.74 0.00 7,491.17 12,200.00 90.57 177.78 3,584.91 3,463.91 -7,591.09 1,858.69 5,938,481.18 560,679.39 0.00 7,591.09 12,300.00 90.57 177.78 3,583.92 3,462.92 -7,691.01 1,862.56 5,938,381.30 560,684.04 0.00 7,691.01 5/20/2006 2:30:09PM Page 4 of 7 COMPASS 2003.11 Build 50 ~~~~~ ~Halliburton Energy Services ~Qt"14Ca~~'11~~1pS Planning Report -Geographic Alaska Database: _EDM_2003.11_b48 Company: ConocoPhillips Alaska Inc. Project: Kuparuk River Unit Site: Kuparuk 1J Pad WeII: Plan 1J-102 Wellbore: 1J-102 L1 Design: 1J-102 L1 (wp07) Planned Survey 1J-102 L1 (wp07) HAL.LtBEJFTt3tV Sperry ~iriiltng Services Local Co-ordinate Reference: Well Plan 1J-102 -Slot 1J-102 TVD Reference: Doyon 15 Plan @ 121.OOft (Doyon 15 (81+40)) MD Reference: Doyon 15 Plan @ 121.OOft (Doyon 15 (81+40)) North Reference: True Survey Calculation Method: Minimum Curvature Map Map ' MD Inclination Azimuth TVD SSTVD +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 12,400.00 90.57 177.78 3,582.92 3,461.92 -7,790.93 1,866.43 5,938,281.42 560,688.69 0.00 7,790.93 12,492.54 90.57 177.78 3,582.00 3,461.00 -7,883.39 1,870.02 5,938,189.00 560,693.00 0.00 7,883.39 L1 : BHL @ 12492.53' MD, 3582.00' TVD :359.0' FNL 8 583 .6' FEL - Sec 11 - T10N - R 10E - 41/2" -1J-1 02 L1 T5 (Toe) (wp07) 5/20/2006 2:30:09PM Page 5 of 7 COMPASS 2003.11 Build 50 ' ~ ~ ti- Halliburton Energy Servic es HA~~~suRTOni ~QI~IQCC~~'11E~tS Planning Report -Geographic ~~- ~~~~~ ~ ~~ Sperry DrillFng Servlcea Database: EDM 2003.11 b48 Local Co-ordinate Reference: Well Plan 1J-102 -Slot 1J-102 Company: ConocoPhillips Alaska Inc. TVD Reference: Doyon 15 Plan @ 121.OOft (Doyon 15 (81+40)) Project: Kuparuk River Unit MD Reference: Doyon 15 Plan @ 121.OOft (Doyon 15 (81+40)) Site: KuparuK 1J Pad North Reference: True Well: Plan 1J-102 Survey Calculation Method: Minimum Curvature Wellbore: 1J-102 L1 Design: 1 J-102 LY (wp07) -- Geologic Targets 1J-102 L1 TVD Target Name +N/-S +E/-W Northing Easting (ft) -Shape ft ft (ft) (ft) 3,616.00 1J-102 L1 DD Poly @ 95% (wp0 7) -577.42 1,866.74 5,945,494.02 560,632.71 - Polygon Point 1 -50.00 0.00 5,945,493.63 560,582.72 Point 2 -50.11 -11.46 5,945,482.17 560,582.70 Point 3 -50.37 -41.16 5,945,452.47 560,582.67 Point 4 -61.55 -292.00 5,945,201.58 560,573.45 Point 5 -74.77 -456.80 5,945,036.69 560,561.51 Point 6 -78.92 -565.61 5,944,927.87 560,558.21 Point 7 -77.67 -890.53 5,944,603.00 560,562.00 Point 8 -77.66 -909.52 5,944,584.01 560,562.16 Point 9 -82.26 -3,144.78 5,942,349.00 560,575.00 Point 10 -81.83 -3,240.58 5,942,253.21 560,576.18 Point 11 -74.33 -3,922.94 5,941,571.00 560,589.00 Point 12 -73.81 -3,973.15 5,941,520.80 560,589.91 Point 13 -67.72 -4,610.06 5,940,884.01 560,600.97 Point 14 -67.34 -4,649.30 5,940,844.78 560,601.66 Point 15 -59.24 -5,449.25 5,940,045.00 560,616.00 Point 16 -60.74 -5,548.07 5,939,946.18 560,615.27 Point 17 -85.33 -6,155.00 5,939,339.13 560,595.42 Point 18 -85.46 -6,306.35 5,939,187.80 560,596.47 Point 19 -46.73 -7,305.58 5,938,189.00 560,643.00 Point 20 53.28 -7,306.36 5,938,189.00 560,743.00 Point 21 14.54 -6,307.13 5,939,187.80 560,696.47 Point 22 14.67 -6,155.78 5,939,339.13 560,695.42 Point 23 39.26 -5,548.85 5,939,946.18 560,715.27 Point 24 40.77 -5,450.03 5,940,045.00 560,716.00 Point 25 32.67 -4,650.08 5,940,844.78 560,701.66 Point 26 32.28 -4,610.85 5,940,884.01 560,700.97 Point 27 26.19 -3,973.93 5,941,520.80 560,689.91 Point 28 25.67 -3,923.72 5,941,571.00 560,689.00 Point 29 18.18 -3,241.36 5,942,253.21 560,676.18 Point 30 17.75 -3,145.56 5,942,349.00 560,675.00 Point 31 22.35 -910.30 5,944,584.01 560,662.16 Point 32 22.34 -891.31 5,944,603.00 560,662.00 Point 33 21.08 -566.39 5,944,927.87 560,658.21 Point 34 25.23 -457.58 5,945,036.69 560,661.51 Point 35 38.46 -292.78 5,945,201.58 560,673.45 Point 36 49.64 -41.94 5,945,452.47 560,682.67 Point 37 49.90 -12.24 5,945,482.17 560,682.70 Point 38 50.00 -0.39 5,945,494.02 560,682.71 3,616.00 1J-102 L1 T1 (wp07) -1,468.34 1,839.07 5,944,603.00 560,612.00 - Point 3,587.00 1J-102 L1 Geo Poly (wp07) -577.42 1,866.74 5,945,494.02 560,632.71 - Polygon Point 1 -65.72 0.12 5,945,493.63 560,567.00 Point 2 -98.53 -1,000.38 5,944,493.00 560,542.00 Point 3 -120.72 -3,203.48 5,942,290.00 560,537.00 Point 4 -121.42 -5,598.78 5,939,895.00 560,555.00 Point 5 -150.98 -6,311.64 5,939,182.00 560,531.00 Point 6 -116.73 -7,305.03 5,938,189.00 560,573.00 Point 7 128.29 -7,306.95 5,938,189.00 560,818.00 Point 8 84.10 -6,304.47 5,939,191.00 560,766.00 Point 9 96.54 -5,608.48 5,939,887.00 560,773.00 Point 10 54.30 -3,203.85 5,942,291.00 560,712.00 Point 11 41.34 -507.41 5,944,987.00 560,678.00 Point 12 67.29 -0.53 5,945,494.02 560,700.00 3,582.00 1J-102 L1 T5 (Toe) (wp07) -7,883.39 1,870.02 5,938,189.00 560,693.00 - Point 5/20/2006 2:30:09PM Page 6 of 7 COMPASS 2003.11 Build 50 ORiGI;ti'AL ~.-~' ~ Halliburton Energy Services ~ HA~I~.~suarc>Int CCyt10GUPI"1tII1~JJ5 Planning Report -Geographic ------ ~,-, .____,.~,_. Alaska Sperry Drilling Services Database: _EDM_2003.11_b48 Local Co-ordinate Reference: Well Plan 1J-102 -Slot 1J-102 Company: GonocoPhillipsAlaska {nc. TVD Reference: Doyon 15 Plan @ 121.OOft (Doyon 15 (81+40)) Project: Kuparuk River Unit MD Reference: Doyon 15 Plan @ 121.OOft (Doyon 15 (81+40)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-102 Survey Calculation Method: Minimum Curvature Wellbore: 1J-102 L1 Design: 1J-402 L1 (wp07) 3,577.00 1J-102 L1 T2 (wp07) -3,722.59 1,834.48 5,942,349.00 560,625.00 - Point 3,586.00 1J-102 L1 T4 (wp07) -6,027.06 1,857.50 5,940,045.00 560,666.00 - Point 3,587.00 1J-102 L1 T3 (wp07) -4,500.75 1,842.41 5,941,571.00 560,639.00 - Point Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) (") (") 120.00 120.00 20 20 2,645.82 2,243.00 10-3/4 13-1/2 5,185.48 3,621.06 7-5/8 9-7/8 12,492.53 3,582.00 4-1/2 6-3/4 Prognosed Form ation Intersection Points Measured Vertical Depth Inclination Azimuth Depth +N/-E +E/-W Ift) (°) (°) (ft) (ft) (ft) 1,644.52 41.31 39.85 1,533.00 355.99 271.36 1,833.69 45.35 42.00 1,671.00 453.76 355.93 2,246.77 45.04 64.21 1,962.00 629.18 588.66 2,645.82 45.38 80.79 2,243.00 705.73 860.12 3,690.24 45.94 126.94 2,987.00 644.07 1,563.71 4,065.23 53.91 149.24 3,230.00 430.99 1,750.57 4,209.74 57.96 156.46 3,311.00 324.52 1,804.97 4,430.93 64.85 166.33 3,417.00 140.72 1,866.25 4,865.07 77.00 180.00 3,551.00 -268.15 1,904.44 5,047.31 77.00 181.51 3,592.00 -445.70 1,902.10 5,185.53 80.00 183.00 3,621.07 -580.70 1,896.95 Name Base Perm T3 K15 T3 + 550 Ugnu C Ugnu B Ugnu A K13 Wsak D Wsak C Wsak B 5/20/2006 2:30:09PM Page 7 of 7 COMPASS 2003.11 Build 50 ~~~~ • • ConocoPhillips Alaska ConocoPhillips Alaska Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-102 1 J-102 L1 1 J-102 L1 (wp07) Anticollision Report 21 May, 2006 H~iLLI~URTC~NI Sperry Qri[ling Services ~ ~ t a ~ °~d Z C a o H - OQ V _ E3cmm L N o rn E v - ''= ~ E_NU ~C o ~~E~Wv U p {- y 4 ~O U~ ~t w`~w °o 'Cf ~ O N N C O W ~ t E N AW3 N V 0 c N~ ~ n ~ ~3 ~a o !~ J ~ r A a ~ O9o Q m ~ ~? w ~? n 9 < C O10 C C C ~ N Oxm a wm Q N C O ~ Z p~ 3 S W O N 2? + o Op eN~o N o ~ Z 2re~ w EF«~ a z pa~^ O ~~~.. N ~_ J 'CN C4 U .t. E K N F~ fLLEd orn'-d m m m ~ on:~ ~s :: n c g UU N /~ vv yae O~ C._ U~P s,y3: FUSE d ~ 9, _ FyE z ~F v. e3 E$$Y O' n o _ ; o ~ ~ ~ ~ a c0 „~,. 3 3 3 3 g h_ f- i- ~= F r p J J J J J o A :0 F r r r ~ r O N Vi w°ea~am°n e°+umi,m r~'~,nmonan.mi M jooi oiN a~owNOO~fi r~riri ri wi ~ n~nm ~~~nnaa°u°m °u ~~~ ~ LL C G O b G ~ D O N O t V o n b o ~ C 0 V ~ d ~ o m o 0 0 0 0 0 0 0 0 0 0 0 0 0 0 U ~ oo' noviaoaoaoaacae ' Q o ° up.~ir o~e~a a~irnnna~oo v> O N O '~ z ~~ man nmmnw O ~ F mmmmmwwm mmmmmm N N ~ N N 0') O O ~~~~~~~~~~.-~~~~.-~ ~ N Zo~i ~iNmmnH~o~r~riri ri ri ~E.. +77bm~~~n~vmiN000 nn ro YYtO ` °om1dme°o°m°oa°o~a°+o"nmo a ~~« ~~MMMM~~M~~n~M~~M Y ~~ ~ ~ n ~ ~ M M d V V~ emi n~ ~ ~ ro g N m p A n r A r~ ~m r A 0 o U M N C mmmmmmmmmmmmmmmmm a i Orrr~nm~rommro~m~n ~n~~ n ova v,~ r F n~u~nmmmmm °irv fn~NnaNmnmm~~~~~~~~ O O cQ ~ N C 0 0 0 0 0 0 0 0 0 0 0 0 0 0 O O O O O N O~ O~ O O O O O O O O O N O O ~ O~ O` N I~ O N~ O O O O O O O O N ~ ~ N N f~ ~ ~ ~ N N N M O~ (O I~ m m ~ ~ N U I i I I I 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ~ o ~n o ~n o ~n o ~n 0 0 0 0 0 0 0 0 0~ N ~n r o N~ r o N ~n 0 0 0 0 0 0 0 O ~ ~ ~ ~ N N N th O~ (D t~ a0 W~ °m 0 t. V. r .~ t °+ t Z N 2= ~ 0 0 oG O iCWr c°e «@J=~~ z __ g 4 ~aoau a `mom ~E f a c ~ O =c~cE o ~ o Z 30NOf w iuuii oo U ~ ~ c C K ~~bd~ W ` ` ` W R~'KKK C K WON~q 3~?°9 'gOgci C C d o d N m `o > m U ~ • / Halliburton Energy Services ConocoPh ill~ps Anticollision Report Alaska Company: ConocoPhillips Alaska Inc: Local Co-ordinate Reference: Project: Kuparuk River Unit TVD Reference: Reference Site: Kuparuk 1J Pad MD Reference: Site Error: O.OOft North Reference: Reference Well: Plan 1J-102 Survey Calculation Method: Well Error: O.OOft Output errors are at Reference Wellbore 1J-102 L4 Database: Reference Design: 1 J-102 L1 (wp07) Offset TVD Reference: • HALLIBURTQN Sperry Drilling Services Well Plan 1 J-102 -Slot 1 J-102 Doyon 15 Ptah @ 121.OOft (Doyon 15 (81+40)) Doyon 15 Plah @ 121:OOft (Doyon 15 (81+40)) True: Minimum Curvature 2.00 sigma _EDM_2003:11_b48 Reference Datum Reference 1J-102 L1 (wp07) Filter type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Interpolation Method: MD Interval SO.OOft Error Model: ISCWSA Depth Range: 5,185.47 to 12,492.54ft Scan Method: Trav. Cylinder North Results Limited by: Maximum center-center distance of 1,445.25ft Error Surface: Elliptical Conic Warning Levels evaluated at: 0.00 Sigma Survey Tool Program - - - Date 5/21/2006 From To ', (ft) (ft) Survey (Wellbore) Tool Name Description 40.00 800.00 1J-102 (wp07) (1J-102) CB-GYRO-SS Camera based gyro single shot 800.00 5,185.47 1J-102 (wp07) (1J-102) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 5,185.47 12,492.50 1J-102 L1 (wp07) (1J-102 L1) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 5/21/2006 11:02:37AM Page 2 of 4 COMPASS 2003.11 Build 50 Halliburton Ener Services 9Y ConocoPh illips Anticollision Report Alaska Company: ConocoPhillips Alaska Inc. Local Co-ordinate Reference: Project: Kuparuk River Unit ND Reference: Reference Site: Kuparuk 1J Pad MD Reference: Site Error: O:OOft North Reference: Reference Well: Plan 1J-102 Survey Calculation Method: Well Error: O.OOft Output errors are at Reference Wellbore 1J-102 Li Database: Reference Design: 1J-102 L1 (wp07) Offset ND Reference: HALE.IBtJRT01t~[ Sperry Drilling Services Well Plan 1J-102 -Slot 1J-102 Doyon 15 Plan @ 121.OOft (Doyon 15 (81+40)) Doyon 15 Plan @ 12LOOft (Doyon 1 S (81+40)) True Minimum Curvature 2.00 sigma _EDM_2003.11_b48 Reference Datum Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well -Wellbore -Design (ft) (ft) (ft) (ft) Kuparuk 1J Pad 1J-14 - 1J-14 - 1J-14 7,308.23 4,600.00 738.41 138.51 626.39 Pass -Major Risk 1 J-152 - 1 J-152 - 1 J-152 Out of range 1 J-152 - 1 J-152 L1 - 1 J-152 L1 Out of range 1 J-152 - 1 J-152 L2 - 1 J-152 L2 Out of range 1J-152 - 1 J-152 L2 PB1 - 1J-152 L2 PB1 Out of range 1J-152 - 1J-152 P61 - 1J-152 P61 Out of range 1J-152 - 1J-152 PB2 - 1J-152 PB2 Out of range 1 J-154 - 1 J-154 - 1 J-154 Out of range 1 J-154 - 1 J-154 L1 - 1 J-154 L1 Out of range 1 J-154 - 1 J-154 L2 - 1 J-154 L2 Out of range 1J-159 - 1J-159 - 1J-159 5,992.27 4,700.00 1,050.44 113.42 939.39 Pass -Major Risk 1J-159 - 1J-159 L1 - 1J-159 L1 5,992.85 4,700.00 1,050.30 113.19 939.56 Pass -Major Risk 1J-159 - 1J-159 L1 PB1 - 1J-159 L1 PB1 5,992.85 4,700.00 1,050.35 113.63 939.16 Pass -Major Risk 1J-159 - 1J-159 L1 PB2 - 1J-159 L1 P62 5,992.85 4,700.00 1,050.30 113.90 938.85 Pass -Major Risk 1 J-159 - 1 J-159 L2 - 1 J-159 L2 5,755.64 4,450.00 1,052.21 107.62 948.10 Pass -Major Risk 1J-159 - 1J-159 PB1 - 1J-159 PB1 5,992.27 4,700.00 1,050.44 113.30 939.51 Pass -Major Risk Plan 1 J-102 - 1 J-102 - 1 J-102 (wp07) 5,199.97 5,199.98 0.28 0.60 -0.32 FAIL - No Errors Plan 1J-102 - 1J-102 L2 - 1J-102 L2 (wp07) 5,197.96 5,199.98 56.09 0.50 55.62 Pass- No Errors Plan 1J-103 - 1J-103 - 1J-103 (wp03) -North Heel 9,629.32 11,019.86 1,331.72 239.55 1,096.73 Pass -Major Risk Plan 1J-103 - 1J-103 L1 - 1J-103 L1 (wp03) -North Hee 9,628.84 11,008.37 1,320.31 253.58 1,067.70 Pass -Major Risk Plan 1J-103 - 1J-103 L2 - 1J-103 L2 (wp03) -North Hee 8,058.93 9,450.00 1,250.67 198.46 1,053.20 Pass -Major Risk Plan 1J-105 -Plan 1J-105 - 1J-105 (wp02) Out of range Plan 1J-107 -Plan 1J-107 - 1J-107 (wp02) Out of range Plan 1 J-109 -Plan 1 J-109 - 1 J-109 (wp05) Out of range Plan 1J-111 -Plan 1J-111 - iJ-111 (wp03) Out of range Plan 1J-133 - 1J-133 - 1J-133 (wp06) 8,170.16 5,100.00 1,204.93 169.98 1,069.17 Pass -Major Risk Plan 1J-133 - 1J-133 L1 - 1J-133 L1 (wp06) 8,170.16 5,100.00 1,204.93 169.98 1,069.18 Pass -Major Risk Plan 1J-135 -Plan 1J-135 -Plan 1J-135 (wp01) 8,644.82 5,500.00 988.33 185.03 831.33 Pass -Major Risk Plan 1J-136 - 1J-136 - 1J-136 (wp04) 12,481.86 8,950.00 204.79 33.94 204.10 Pass -Minor 1/200 Plan 1J-136 - 1J-136 L1 - 1J-136 L1 (wp04) 12,481.86 8,950.00 204.79 33.94 204.10 Pass -Minor 1/200 Plan 1 J-137 - 1 J-137 - J-137 (wp05) 12,466.97 8,699.97 920.30 313.69 612.20 Pass -Major Risk Plan 1J-137 - 1J-137 L1 - 1J-137 L1 (wp05) 12,466.97 8,699.97 920.30 313.69 612.20 Pass -Major Risk Plan 1 J-156 - 1 J-156 - 1 J-156 (wp05) Out of range Plan 1J-156 - 1J-156 L1 - 1J-156 L1 (wp05) Out of range Plan 1 J-156 - 1 J-156 L2 - 1 J-156 L2 (wp05) Out of range Plan 1J-158 - 1J-158 - 1J-158 (wp03) Out of range WSP-1 S -WSP-1 S -WSP-1 S Out of range CC -Min centre to center distance or covergent point, SF -min separation factor, ES -min ellipse separation 5/21/2006 11:02:37AM Page 3 of 4 COMPASS 2003.11 Build 50 -102L1~rillinq Haz ammar (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) Production Hole Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low Stripping drills, shut-in drills, increased mud wei ht. Stuck Pipe Low Good hole cleaning, PWD tools, hole o ener runs, decreased mud wei ht Lost Circulation Low Reduced um rates mud rheolo , LCM Hole Swabbing on Trips .Moderate Trip speeds, proper hole filling (use of trip sheets , um in out, backreamin ~~ 1J-102L1 Drilling Hazards Summary 7/14/2006 10:36 AM G"7 z 20" 94.0# x 34" Insulated Conductor, K-55, set at +l- 80' 10-314" x 4.1/2" Wellhead, 5,000 psi 10.3/4", 68#, BTC ~~ Shoe set @ 2646' MD, 2243' TVD / Tubing String 4.1/2" 12.6#, L-80, IBTM 3.958" ID, 3.833" Drift 5-112" X 7-518" ZXP Liner Top Packer w/ Hold Seal Assembly Downs 4.75" Seal OD Tubing, 4.1/2", 12.6#, IBTM, Special Drift to +/- 500' 3.875" DB Nipple, for Possible SSSV, +/- 500' GLM, Camco KBG-2, 4-112" X 1", 25 deg, 1,200 ft MD GLM, Camco KBG-2, 4-112" X 1", 70 deg, +/- 1 jt above sliding sleeve CMD Sliding Sleeve, w/ 3.81" DB Nipple, 72 deg, +l- 1 jt above seals Casing Sealbore Receptacle, 20' Length Lateral Entry Module(LEM) D-sand Window t 4865' MD, 3551' TVD ' 4-112" 11.6# L-80 Slotted Liner Swivel Liner Every Other Joint ConocoPhillips West Sak 7-5/8" Injector 1 J-102 Tri-Lateral Completion 'D' Sand Lateral Bent Joint 3-112" Guide Shoe 4-112" Liner Shoe, 11.6#, L-80 BTC Set ~ 12187' MD, 3509' TVD 4-112" X 7-518" Seal Bores Model'B' HOOK Hanger 3.68" ID 5-112" X 7-518" ZXP Liner Top Packer wl Hold Downs Lateral Entry Module (LEM) Assembly ~--- 5-112" X 7-518" ZXP Liner Top Packer with Hold Downs Casing Sealbore Receptacle 4.75" ID Orienting Profile ./ Automatic Alignment of LEM Positive Latching Collet ~~ Indicates Correct Location Seal Bore for Lateral Isolation - 3.68" ID Access Window Positive Lateral Access Via Thru-Tubing Diverter Seal Bore for Lateral Isolation - 3.68" ID Isolation Seal Asembly 4.75" Seal OD 3.875" Seal ID Casing Sealbore Receptacle 20' Length Seal Assembly 4.75" Seal OD 3.68" As Planned ri~~ NKItIGj8E5 Baker Oil Tools Late ral Entrv Module (LEMI With Diverters and Isolation Lateral Access Diverter Lateral IsolaBOn Diverter GS Running Tool String Installed Installed (3.00" Lateral Drift) (2.50" ID Mainbo re Drift) 'GS' Profile for Coil Connector I /Running/Retrieving ~ (1.00' Length) i I . Snap lNSnap OUt I / Positive Locating ti rBack Presswe Valve Collet I (1.80' Length) Lateral Isolation ~~ r Flow-Thru Swivel Seals ~. (1.25' Length) / Lateral Diverter ~'~ I ~ /Hydraulic Ramp - D50' Le g h Isolation/ Mainbore ~ (1 n t ) Diverter Sleeve ~/ GS Spear ~~ (1.50' Length) Lateral Isolation Wintry Module(LEM) , 6.85 tt Approx. B-sand Window 'Jars may be required or deep applications at 5185' MD, 3621' TVD 'B' Sand Lateral 4-112" 11.6# L-80 Slotted Liner Swivel Liner Every Other Joint 3-112" Bent Joint 4-112" 12.6# Tubin~:___------'i\ 3.833" Drift 3.958" ID r 5-112" X 7518" ZXP/ Liner Top Packer with Hold Downs i 5-112" X 7518" Liner Hanger I Packer Assembly at Flex Lock +1- 5300' MD Liner Hanger Casing Sealbore Receptacle, 20' Length ® Baker Hughes 2005. TRIs tlocument may not be reproducetl or tllstrlbutetl, In whole or In part, In any loan or by any means electronic or mechanical, Inclutling photocopying, recortling, or by any Information storage and retrieval system now known or hereafter Inventetl, without written permission from Baker Hughes Inc. Seal Assembly 4.75" Seal OD 'A' Sand Undulating Lateral 4-112" 11.6# L-80 Slotted Liner Every Other Joint 4-112" Eccentric / .Guide Shoe ) _ 3-112" Guide Shoe ~~ 4-1/2" Liner Shoe, 11.6#, L- TC Set ~ 12492' 2' TVD 3.562" DB Nipple ~ \ ~ \~ \ ~/{ Seals I Ny deviated 18.5' Diverter Length 18.5' Sleeve LengM roltJenathl. Equipment Specifications 4-112" X 7-518" HOOK Hanger Mainbore Drift: 5.32" Mainbore Drift, with diverter: 4.63" Lateral Drift, no diverter or LEM: 3.88" Lateral Drift, wl diverter, no LEM: 3.88" LaterallMainbore Diverter OD: 6.75" 4-112" Lateral Entry Module Mainbore Drift: 3.65" Mainbore Drift, wl isolation sleeve: 2.50" Lateral Drift, wl coil diverter: 3.00" OD of Diverter and Sleeve: +l- 3.89" Diverter and Sleeve Length: +l- 18.5' 4-1/2" Casing Shoe, 11.6#, L-80 BTC Set @ 13688' MD, 3728' TVD 7-5/8" 40# Casing, L-80, BTCM, Set at ~ 5988' MD, 3755' TVD owv nua: (84 deg) West Bak 7-51a" TrI-lateral Completion -Injector rData: JYI 21,3008 Dawn BY~ ReWSIOn Ne.: Y Marc D. Kuck 2 • • • TRANSMITTAL LETTER CHECKLIST WELL NAME K/2~C ~ d ' ~D 2- L..., f PTD# 2. D~ - / ~ Development / Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER I WHAT (OPTIONS) ~ APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well /~/~ GC. /~ ~' l D "2_, , (If last two digits in pec-rnit o, ~Olo-/~~ API No. 50~~" Z Q~. - 33[7_ API number are between 60-69) ould continue to be reported as a function of the I original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 2.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in ~ SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed ~ Well for (name of well) until after (Company NameZhas designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing rogram. Rev: 1 i25l06 C:\jodyltransmittal_checklist ELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER, WEST SAK OIL • 490150 Well Name: KUPARUK RIV U WSAK 1J-102L1 Program SER Well bore seg ~ PTD#:2061110 Company CONOCOPHILLIPS ALASKA INC Initial ClasslType SER ! PEND GeoArea 890 Unit 11160 OnlOff Shore On Annular Disposal ^ Administration 1 Permit_fee attached- . - . - - - - - - - - . - - - - NA- _ - West Sak BSand mul#ilate[al-well branch; fee waived per 20 AAC 25.005 a .- O 2 Lease numberappropriate----------------_ -_____-_----- _______Yes___ __.-..--..-_._-_._-_ -- - - 3 Uniquewell-name andnumbe[___--_______________________ _________Yes--- -_---------_ 4 Well located in a_defined pool- . - - - - - Yes - - - - _ - Kuparuk River, West_Sak Oil Pool - 49015Q, governed-b CO 4066- - - y - 5 Well located proper distance from drilling unit_boundary_ _ - - - - - Yes Well is more than- 500 feet from an external property line . . .. . . . .. . . . .. . . . . . . . . . . . . . .. . .... . 6 Well located proper dis#ance from other wells- - - - - - - .. - - - Yes - - - - CO 4066, Rule 3:- no restrictions as-to well spacing except that no_pay shall be opened in a well closer - _ , _ _ _ 7 Sufficient acreage available in_drillinq unit- - - - - _ - - Yes - - - -than 500 feet to-an external_p_rope[ty1ine where ownership-or landownership changes- - - - - - - - - - - - - - - - - -- 8 If deviated,is_wellboreplat-included_______-.___--.----_-__ __--.__-Yes--- -----------___-______--------.------.------_.--.--____ 9 Ope[atoronlyaffectedparty_______________________ - Yes--- ---._- - - - 10 Ope[atorhasappropriate_bondinforce- -- ------ -- ------ --- ~---Yes--- ---- - -....----- --- ----------- ----- ------ -- ...--------- --~- 11 Pemlitcanbeissuedwithoulconservationorder__--------------- --- Yes--- ------- --------- --------------------.---------------------- _--.- Appr Date 12 Permit-eanbe issued withoutadminist[alive-appr_ovel______________ _________Yes___ -_--.__....,-___-..__________--_-_.-__..__--_-....-....-.--.--..._.-- SFD 7127!2006 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized by Injection Order # (put10# in_comments).(For_ Yes - - _ - _ . -Area Injection Order No._ 26 . .. . . . ......... . . . . . . . . . . . . . 15 All wells within 1!4-mile area of review identified (For service well only)- - - - - - - - - - - - - - -Yes _ _ - _ . _ . WSP,3, WSP,9, WSP-1i, WSP-13,-KRU 1 J-159 and laterals- ..... - _ _ - - - - - - - - _ - - - _ _ - - - - 16 Pre-produced injector- duration of pr_e production less than 3 months (For_service well only) .Yes - - - - - _KRU 1J-Pad, injection wells are_typieally pre-produced 30.45 days for cleanup.- 17 Nonconyen,gasconformstoAS31,05,030Q.1.A),(j.2.A-D)__---------- ---------NA____ _-,__--------_--_-____-______________-___-_------_--. -- Engineering 18 Conductor string_p_rovided- ----------------__-------__ ________-NA____ ----ConductcrsetiniJ-102_(206-110),_______---_-----_----------- u-ace casing-protectsa-nown- s________-_._--_ -.____NA___ __-Al.aqu.ersexempted,40CFR_147.102_(b)(3)-------------------------------- - - 20 CMT-voladequate_tocirculale_onconductor&surf-csg--------------- ---------NA-___ ____Surf_acecasing set in iJ-102.----.____-__________________,___.-_--_-------__-_ 21 CMT-voladequate_totie-in long string to surfcsg___________________ _______NA___ _---Production-casingse-tin-1J-102.________-___,__,_-----_----_.----------- 22 CMT-will coverall knownproductiye horizons- - - - - - - - _ - - - - - - - - - - - - - - - - - - - - No- - - - _ _ Slotted liner completion planned.- - - _ - - - - - - _ - _ - _ . - _ _ _ _ _ _ _ _ _ _ _ _ 23 Casing designs adequate for C, T, B &_ permafrost- - - _ _ . - ... - - _ _ . - - _ NA- - - - - Original well_met design specifications, NA fpr slo#ted line[-- - - - - - - - - -- - - - - 24 Adequate tankage-or reserve pit _ - - - - - - - - . _ _ . - - - . _ .Yes - Rig is-equipped with steel-pits. _ No reserve-p_itplanned, All waste to approye_d annulus or disposal well.- - - - - 25 tf a-re-drill, has_a 1.0-403 for abandonment been approved - - - - - - - - _ - NA_ -- - - -- - 26 Adequate wellbore_separalion-proposed- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Yes _ - - _ - - -Proximity analysis performed, Nearest well segment-is- A2 lateral,15' -150' tvd deeper.. - - _ - . - .. - - . _ 27 If_diverter required, does it meet regulations- - - - - - - - - - - - - - - - NA- - - - . - . -BOP stack-will already_be in place, - . - - - - - - _ -------------------------------------- Appr Date 28 Drilling fluid-program schematic & equip listadequate. _ .. _ _ - - Yes _ - . - - . Maximum expected formation pressure 8,7-EMW.- Planned MW,-8.6 ppg or as needed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ TEM 812/2006 29 BOPEs, do they meet- regulation . - - - Yes - - - - - - - - 30 BOPE.press rating appropriate; test to_(pu_t prig in comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ - - - - - MASP calculated at 1237 psi. 3K stack arrangement and BOP test pressure_planned. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 31 Choke_manifoldcomplieswlAPI-RP-53 (May 84)---_------- Yes--- ------------------------------ -- - - - - 32 Work willoccurwithoutoperationshutdown___-__----__________ _________Yes--- ---------_--_,__-__________,__-----.---------_- -- - 33 Is presence-of H2S gas prebable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _____ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ - _ _ ... H2S has n9tbeen reported at 1J_pad._ Rig is egs~ipped.with sensors and alarms, - - - - - _ - - - - _ - - 34 Mechanical-condition of wells within AOR verified (Forse[vice well only) - - - - - - - - - - - - - -Yes - - - No isolation issues identifed for wells in AOR.- - Geology 35 Pe[mit.ean be issued w/o hydrogen-sulfide measures - - - , - - _ - - - - - . - -Yes _ .. - No H2S has been measured in-W Sak wells drilled south from 1J-Pad. Rig has sensors and_alarms.- - - - - - 36 _D_ata-presented on potential overpressure zones _ - - - - - - - - - Yes - - - - - - -Expected res.-pressure is ~8.7ppg EMUV; will be drilled with 8.6 ppgoil,based.mud, Mud weight will be - - Appr Date 37 Seismic analysis of shallow gas-zones. - _ - - - - -- - - -- - - - - - NA_ adjusted as needed.. _ _ ... _ .. - - SFD 7/2712006 38 Seabed condition survey-(ifoff-shore)_____________________--_ _--_---_NA_-- --.- 39 Contact namelphone for weekly_progress reports-[exploratory only] - - - - - - - - - - - - - - - - - NA- - - - _ _ _ _ _ Geologic Engineering tic Date: Date Date West Sak B sand in ector, This is one of the well branches from tri-lateral in ection well KRU 1J•102. SFD 1 1 Commissioner: C inner ~missi nner. (~ • • • We{I 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 Nistory 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 calegory of information. Sperry-Sun Dri~ng Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Nov 03 09:29:13 2006 Reel Header Service name .............LISTPE Date .....................06/11/03 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library Tape Header Service name .............LISTPE Date .....................06/11/03 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Comment Record TAPE HEADER Kuparuk River Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 2 JOB NUMBER: MW0004559176 LOGGING ENGINEER: B. HENNINGSE OPERATOR WITNESS: M. THORNTON • Scientific Technical Services Scientific Technical Services 1J-102L1 500292331760 ConocoPhillips Alaska, Inc. Sperry Drilling Services 03-NOV-06 MWD RUN 7 MWD RUN 8 MW0004559176 MW0004559176 R. FRENCH R. FRENCH G. RIZEK G. RIZEK MWD RUN 10 JOB NUMBER: MW0004559176 LOGGING ENGINEER: R. FRENCH OPERATOR WITNESS: G. RIZEK SURFACE LOCATION SECTION: 35 TOWNSHIP: 11N RANGE: l0E FNL: FSL: 2245 FEL: 2446 FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: 121.30 GROUND LEVEL: 81.00 WELL CASING RECORD OPEN HOLE CASING ~C~~ - ~ 1 l ~ ~~~a~~ DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: BIT SI~(IN) 9.875 6.750 SIZE (IN) DEPTH (FT) 10.750 2642.0 7.625 5046.0 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. THIS WELLBORE WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 5046' MD/3603'TVD, WITHIN THE RUN 2 INTERVAL OF THE 1J-102 PB1 WELLBORE. THE WHIPSTOCK WAS POSITIONED, THE WINDOW WAS MILLED, AND A BIT OF RAT HOLE WAS DRILLED DURING MWD RUN 7. ONLY SROP DATA ARE PRESENTED FOR THIS RUN. 4. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2,8,10 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND PRESSURE WHILE DRILLING (PWD) MWD RUN 10 ALSO INCLUDED GEO-PILOT ROTARY STEERABLE BHA (GP) NO PROGRESS WAS MADE ON MWD RUN 9. 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM M. WERNER (CPAI) TO R. KALISH (SDS). MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1,2,7,8,10 REPRESENT WELL 1J-102 L1 WITH API#:50-029-23317-60. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12242'MD/3582'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.000 Comment Record • FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 2606.0 RPX 2630.0 FET 2630.0 RPS 2630.0 RPD 2630.0 RPM 2630.0 ROP 2652.5 all bit runs merged. STOP DEPTH 12185.0 12191.5 12191.5 12191.5 12191.5 12191.5 12242.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD BIT RUN NO MERGE TOP MERGE BASE 2 2606.0 5046.0 7 5046.5 5070.0 8 5070.0 9880.0 10 9880.0 12242.0 REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2606 12242 7424 19273 2606 12242 RPD MWD OHMM 0.07 2000 40.4116 19124 2630 12191.5 RPM MWD OHMM 0.09 2000 40.8586 19124 2630 12191.5 RPS MWD OHMM 2.05 2000 40.7393 19124 2630 12191.5 RPX MWD OHMM 2.11 2000 36.4671 19124 2630 12191.5 FET MWD HOUR 0.14 322.43 1.37567 19124 2630 12191.5 GR MWD API 20.76 127.52 66.435 19159 2606 12185 ROP MWD FT/H 0.04 1098.43 191.122 19180 2652.5 12242 r1 L_~ First Reading For Entire File..........2606 Last Reading For Entire File...........12242 File Trailer Service name .............STSLIB.001 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name .............STSLIB.002 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY • for each bit run in separate files. VENDOR TOOL CODE START DEPTH STOP DEPTH GR 2606.0 5046.0 RPM 2630.0 5046.0 RPS 2630.0 5046.0 RPD 2630.0 5046.0 FET 2630.0 5046.0 RPX 2630.0 5046.0 ROP 2652.5 5046.0 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 BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA 31-AUG-06 Insite 72.13 Memory 5046.0 2652.0 5046.0 39.9 82.9 TOOL NUMBER 216265 96540 OPEN HOLE BIT SIZE (I~ 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 TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order DEPT RPD MWD020 RPM MWD020 RPS MWD020 RPX MWD020 FET MWD020 GR MWD020 ROP MWD020 9.875 • 2642.0 Fresh Water Gel 9.10 58.0 9.1 450 4.4 1.500 84.0 1.140 113.0 1.650 84.0 1.800 84.0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 OHMM 4 1 68 4 2 OHMM 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 HOUR 4 1 68 20 6 API 4 1 68 24 7 FT/H 4 1 68 28 8 Name Service Unit Min Max Mean Nsam DEPT FT 2606 5046 3826 4881 RPD MWD020 OHMM 1.26 2000 22.722 4833 RPM MWD020 OHMM 1.54 1743.45 14.3228 4833 RPS MWD020 OHMM 2.05 129.28 11.4364 4833 RPX MWD020 OHMM 2.11 62.61 9.86795 4833 FET MWD020 HOUR 0.14 81.01 1.40913 4833 GR MWD020 API 20.76 126.62 65.9858 4881 ROP MWD020 FT/H 2.98 1098.43 210.703 4788 First Reading For Entire File..........2606 Last Reading For Entire File...........5046 First Reading 2606 2630 2630 2630 2630 2630 2606 2652.5 Last Reading 5046 5046 5046 5046 5046 5046 5046 5046 File Trailer Service name............~SLIB.002 • Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH ROP 5046.5 5070.0 LOG HEADER DATA DATE LOGGED: 12-SEP-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 5070.0 TOP LOG INTERVAL (FT}; 5046.0 BOTTOM LOG INTERVAL (FT) 5070.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: .0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 5046.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G) 8.90 MUD VISCOSITY (S): 66.0 MUD PH: .0 MUD CHLORIDES (PPM): 26000 FLUID LOSS (C3) 3.2 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: 114.000 .0 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 • First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5046.5 5070 5058.25 48 5046.5 5070 ROP MWD070 FT/H 1.92 47.44 16.2785 48 5046.5 5070 First Reading For Entire File..........5046.5 Last Reading For Entire File...........5070 File Trailer Service name .............STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 8 0 DE PTH INCREMENT: .500 FI LE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 5046.5 9823.5 FET 5046.5 9829.0 RPX 5046.5 9829.0 RPS 5046.5 9829.0 RPM 5046.5 9829.0 RPD 5046.5 9829.0 ROP 5070.5 9880.0 LO G HEADER DATA DATE LOGGED: 17-SEP-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 9880.0 TOP LOG INTERVAL (FT) 5070.0 BOTTOM LOG INTERVAL (FT) 9880.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 78.7 MAXIMUM ANGLE: 94.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 156430 EWR4 Electromag Resis. 4 130908 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 5046.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S) 63.0 MUD PH: .0 MUD CHLORIDES (PPM): 22000 FLUID LOSS (C3) 2.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 128.9 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record...~......Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD080 OHMM 4 1 68 4 2 RPM MWD080 OHMM 4 1 68 8 3 RPS MWD080 OHMM 4 1 68 12 4 RPX MWD080 OHMM 4 1 68 16 5 FET MWD080 HOUR 4 1 68 20 6 GR MWD080 API 4 1 68 24 7 ROP MWD080 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5046.5 9880 7463.25 9668 5046.5 9880 RPD MWD080 OHMM 0.07 2000 49.2744 9566 5046.5 9829 RPM MWD080 OHMM 0.09 2000 55.7227 9566 5046.5 9829 RPS MWD080 OHMM 7.35 2000 55.874 9566 5046.5 9829 RPX MWD080 OHMM 3.31 2000 49.7339 9566 5046.5 9829 FET MWD080 HOUR 0.16 3 22.43 1.27734 9566 5046.5 9829 GR MWD080 API 36.45 1 27.52 66.4369 9555 5046.5 9823.5 ROP MWD080 FT/H 0.1 514.8 178.572 9620 5070.5 9880 First Reading For Entire File..........5046.5 Last Reading For Entire File...........9880 File Trailer Service name .............STSLIB.004 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 Maximum Physical Record..65535 File Type ................LO Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9824.0 12185.0 RPX 9829.5 12191.5 RPD 9829.5 12191.5 . RPM 9829 12191.5 FET 9829.5 12191.5 RPS 9829.5 12191.5 ROP 9880.5 12242.0 LO G HEADER DATA DATE LOGGED: 20-SEP-06 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 68.18 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) 12242.0 TOP LOG INTERVAL (FT) 9880.0 BOTTOM LOG INTERVAL (FT) 12242.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.4 MAXIMUM ANGLE: 94.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 178505 EWR4 Electromag Resis. 4 159439 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) 6.750 DRILLER'S CASING DEPTH (FT) 5046.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.80 MUD VISCOSITY (S) 68.0 MUD PH: .0 MUD CHLORIDES (PPM): 16500 FLUID LOSS (C3) 2.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 1 24.3 MUD FILTRATE AT MT: .000 .0 MUD CAKE AT MT: .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type ..................0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing .....................60 .lIN Max frames per record .............Undefined Absent value ......................-999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 e. ~ R ~ • RPD MWD100 OHMM 1 68 4 2 RPM MWD100 OHMM 4 1 68 8 3 RPS MWD100 OHMM 4 1 68 12 4 RPX MWD100 OHMM 4 1 68 16 5 FET MWD100 HOUR 4 1 68 20 6 GR MWD100 API 4 1 68 24 7 ROP MWD100 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9824 12242 11033 4837 9824 12242 RPD MWD100 OHMM 6.83 187.88 40.5625 4725 9829.5 12191.5 RPM MWD100 OHMM 6.1 176.58 37.9079 4725 9829.5 12191.5 RPS MWD100 OHMM 5.7 1538.98 40.0708 4725 9829.5 12191.5 RPX MWD100 OHMM 5.37 1553.37 36.8149 4725 9829.5 12191.5 FET MWD100 HOUR 0.17 43.21 1.54051 4725 9829.5 12191.5 GR MWD100 API 34.18 120.54 66.8953 4723 9824 12185 ROP MWD100 FT/H 0.04 441.37 198.608 4724 9880.5 12242 First Reading For Entire File..........9824 Last Reading For Entire File...........12242 File Trailer Service name .............STSLIB.005 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......06/11/03 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date .....................06/11/03 Origin ...................STS Tape Name ................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE Date .....................06/11/03 Origin ...................STS Reel Name ................UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library Physical EOF Physical EOF Scientific Technical Services Scientific Technical Services End Of LIS File
