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Home My WebLink About207-054C:\Users\grgluyas\AppData\Local\Microsoft\Windows\INetCache\Content.Outlook\R97USUAM\2024-11-26_22201_KRU_1J-158_ProductionProfile_Transmittal.docx DELIVERABLE DISCRIPTION Ticket # Field Well # API # Log Description Log Date 22201 KRU 1J-158 50-029-23356-00 Production Profile 26-Nov-24 DELIVERED TO Company & Address DIGITAL FILE # of Copies LOG PRINTS # of Prints CD’s # of Copies 1 AOGCC Attn: Natural Resources Technician 333 W. 7th Ave., Suite 100 Anchorage, Ak. 99501-3539 Delivered By: CPAI Sharefile ______________________________ _____________________________________ Date received Signature ______________________________ ______________________________________ PLEASE RETURN COPY VIA EMAIL TO: DIANE.WILLIAMS@READCASEDHOLE.COM READ CASED HOLE, INC., 4141 B STREET, SUITE 308, ANCHORAGE, AK 99503 PHONE: (907)245-8951 E-MAIL : READ-Anchorage@readcasedhole.com WEBSITE : WWW.READCASEDHOLE.COM 207-054 T39852 12-10-2024 Gavin Gluyas Digitally signed by Gavin Gluyas Date: 2024.12.10 12:47:09 -09'00' • II Histo File Cosr Pa e Image Pro~ect We ry g 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. ~Q ~- Q~~-~- Well History File Identifier II I( I~I ~ I I I I II II I Or anizing (done) 9 Two-sided II I II' ~II I~ II I II III H ^ Rescan Needed RE AN DIGITAL DATA OVERSIZED (Scannable) Color Items: Diskettes, No. ~ ^ Maps: p Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: 3 Q ~~ Project Proofing III II'II) II II) I I III BY: Maria Date: O Q ~S~ Scanning Preparation ~ x 30 =~_ + c~~ = TOTAL PAGES~ (Count does not include cover sheet) ,/~/~ BY: Maria ~ Date: /~ O/~ ~ ~ ~S~ ~~e. Production Scanning """"""" ' Stage 1 Page Count from Scanned File: ~~? (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ,_f~YES NO BY: Maria Date: /~ ~ d Q~ /s/ ( ~/ I~ ~ ~ -i Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: ~S~ Scanning is complete at this point uniess rescanning is required. III II II I~ I II ~( I III ReScanned II I II'I II I I III II III BY: Maria Date: ~S~ his file: Quality Checked (II II IIII III II'I III Comments about t ~ 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA ALASK~L AND GAS CONSERVATION COMMIS N REPORT OF SUNDRY WELL OPERATIONS ~. operations Pertormed: Abandon r Repair w ell r" Rug F~rforations r Stimulate ('" Other ~, Isolate B sand ARer Casing r Pull Tubing ~ Perforate New Wol r Waiver ~ Time Extension r Change Approved Program r Operat. Shutdow n r Pbrforate r Re-enter Suspended Well r 2. Operator Name: 4. Current Well Status: ``~5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ Exploratory r 207-054 3. Address: Stratigraphic r Service r ti,,API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23356-00 7. Property D~sign~tion: ~ 8. Well Name and Number: \ ADL 25660, 25661, 25663 1J-158 9. Field/Pool(s): ~ Kuparuk River Field /West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 12268 feet Plugs (measured) 7750 true vertical 3301 feet Junk (measured) None Effective Depth measured 12259 feet Packer (measured) 7311 true vertical 3300 feet (true vertucal) 3226 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20 121 121 0 0 SURFACE 3350 12 3395 2153 0 0 D-SAND LEM 282 6.6 7585 3273 0 0 PRODUCTION 7850 7.625 7890 3323 0 0 B LINER SLOTS 4718 6.5 12259 3300 ~~~~~`'~~ p 8 2010 Perforation depth: Measured depth: Slots 7895'-8697'; 8954'-11089'; 11212'-11626'; 11841'-12214' .~U~. True Vertical Depth: 3323'-3305'; 3321'-3320'; 3309'-3289'; 3293'-3302' r ~~~~ C,p~(11SS,ttl11 ~ Alaska (dal ~~ irrar~o~s Tubing (size, grade, MD, and TVD) 3.5, L-80, 7309 MD, 3226 TVD Packers & SSSV (type, MD, and TVD) SEAL ASSY -BAKER "GBH" - 22 LOCATING SEAL ASSY @ 7311 MD and 3226 TVD NIPPLE - Camco "DS" 2.875" Nipple @ 485 MD and 485 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: f F: ( t ~N uf-,i tip! ~ x}. i tl.~ 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 24 0 0 934 197 Subsequent to operation 1013 1913 149 953 212 13. Attachments Well Class after proposed work: Copies of Logs and Surveys run Exploratory r Development ~ Service r . Well Status after work: Oil ~ Gas r WDSPL Daily Report of Well Operations X GSTOR r WAG r GASINJ r WINJ ~" SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A contact Bob ristensen/Dar ell Hum hre Printed Name R ert .Christen n Title Production Engineering Specialist Signature ~ Phone: 659-7535 Date ~Q // pp°~~ ~ © (y CJ ~/ Form 10-404 Revised 7/2009 ., RBDMS JUL 0 ~ r `? ~=~~ o r ~~~/~ Submit Original Only • 1 J-158 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary Install IBP to isolate the B Sand. Producer 1J-158 was POP'd 3/11/10 after a RWO to convert the well to permanent gas lift. Almost immediately, the well had an MBE with offset injector 1J• 160. The 1J-160 B lateral was isolated 4/11/10 after logging identified the B sand as the offending lateral. Since then, several attempts have been made to de-water 1J-158. The de- watering process has taken longer than expected and sand production has caused plant upsets and ultimately led to a downhole plug that is blocking inflow. Recommend a CTU FCO of the mainbore and then isolate the B Sand in 1J-158 until the MBE can be remediated between this well pair. 06/24/10 SET BAKER 2.5 IBP AT 7750 CTMD, WELL IS FREEZE PROTECTED, TURNED OVER TO DSO. 07/05/10 Well retruned to service Conoco`Phillips Ald>k:1, InC- KUP 1J-158 ell Attributes ax An le 8 MD TD Wellbore APIIUWI FielO Name Well Status Intl (°) MD (ftKB) Act Btm (ftKB) 500292335600 WEST SAK PROD 95.77 11,176.18 12,268.0 ~mment H23 (ppm) iSV: NIPPLE 20 Dale Annotation 7/10/2009 Last WO: Entl Date KBGrd ((t) 2/27/2010 43.01 Rig Release Date 6/21/2007 notation Ist Tag: DepN (ftKB) Entl Date Annotation Rev Reason: GLV C/O Last Motl ... Imosbor Entl Date 3/27/2010 asin Strin s sing Description INDUCTOR String 0... 20 String ID ... 19.124 Top (ftKB) 41.0 Bet Depth If... 121.0 Set Depth (TVD) ... 121.0 String Wt... 94.00 String ... K-55 String Top Thrd .sing Description JRFACE String 0... 103/4 Btring ID 9.950 Top (ftKB) 45.3 Bet Depth (f... 3,395.0 Set Depth ITVD) ... 2,153.8 Btring Wt... 45.50 String ... L-80 String Top Thrtl BTC .sing Descrlpton ~ODUCTION String 0... 75/8 String ID .. 6.875 Top (ftKB) 40.6 Bet Depth (f... 7,890.2 Set Depth ITVD) ... 3,322.4 Btring Wt... 29.70 Skiing ... L-80 String Top ThrO BTC-mod iaing Deacri ption SAND LEM String 0... 4 1/2 String 10 ... 4.000 Top (ftKB) 7,303.6 Set Depth (f... 7,585.1 Bet Depth (TVD) ... 3,273.1 String Wt... 12.60 String ... L-80 String Top ThrC IBT wing Description LINER SLOTS String 0... 41/2 String ID ... 3.476 Top (ftKB) 7,541.4 Bet Depth (f... 12,259.0 Bet Depth (TVD) ... 3,300.9 String Wt... 11.60 String ... L-80 String Top Thrtl BTC finer Details Top Depth ITVD) Top Intl Nomi. ... Well Conflp, Mulliole Lsbrale - 1J-153. 3232010 10,55.03 AM Schematic - AcNal HANGER, 3fi CONDUCTOR, 41121 NIPPLE, 485 Heal Trace, 61 TUBING, 2,997 GAS LIFT, 4 937 GAS LIFT, zne NIPPLE, 7.222 GAUGE.7272 LOCATOR, 7,309 SEAL ABBY, 7,311 D-SAND LEM, 7,3o4~7.sfis D SAND HANGER, 7,440-7 680 PRODUCTION, ~ a ] s9o ~ I sLOrs. ],895-6,697 ~ ' ' SLOTS, 8.954-11.069 • •• 1 sLOrs. ^ ^ ^ 11,212-71626~^ ^. SLOTB, 11 8/1-12.214 • •. 8 LINER sLOrs. 7.541-12,259 TD (1 J-158), 12,268 , ,.~,ny vent„puo„ ~.,,,,y .,_. ,,.,,,,y ,~. ,,.P,,.,..,, ..~.,.~,...,,......~..,~ ....................a...... ,.-....,, ... _-....e ._,. ...._ TUBING 3 1/2 2.992 35.9 7,337.3 3,231.5 9.30 L-80 EUE Srd Com le tlon Det alts Top (ftKB) Top Depth (TVD) (ftN8) Top Intl (°) Item Description Comment Nomi... ID (1^) 35.9 35.9 -0.04 HANGER Vetco Gray 11" x 4 1/2" Hanger w! 4.909" MCA Top Conn. Made up on 3.900 68.7 68.7 0.26 XO -Reducing 4 1/2"IBTM Box x 3 1/2" Srd Pin Cross over 2.992 485.3 485.1 3.86 NIPPLE Camco "DS" 2.875" Nipple 2.875 7,221.9 3,207.6 77.67 NIPPLE Camco "DS" 2.812" Nipple 2.812 7,264.8 3,216.8 77.64 XO -Enlarging 3 1/2" Srd Pin x 4 1/2"IBTM Box Cross over Sub 2.992 7,271.9 3,219.8 79.79 GAUGE 4 1/2"Guardian Gauge Carrier 3.958 7,309.0 3,226.5 79.89 LOCATOR Baker 5.5" Locator Sub 3.880 7,310.7 3,226.8 79.90 SEAL ASSY Baker "GBH" - 22 Locating Seal Assy w/ 2' space out off nogo 3.820 Other In Hole Wireline retrievable lu s, valves, um s fish, etc. Top (fD(B) Top Depth (TVD) (nNB) Top Intl (°) Description Comment Run Date ID (in) 41 41.0 0.01 Heat Trace HEAT TRACE 2/23/2010 0.000 Perforations 8 Slots Top (ftKB) Btm (ftKB) Top (TVD) (ftKB) Btm (TVD) (ftKB) Zone Data Bhot Dens leh"' Type Comment 7,895 8,697 3,323.1 3.305.3 WS B, 1J-158 69/2007 32.0 SLOTS AIt SLOT/BLANK, 2.5" long x .125" @ 4 circumf rows, staggered 18 deg. 8,954 11,089 3,320.7 3,319.7 WS A4, 1J-158 69/2007 32.0 SLOTS Alt SLOT/BLANK, 2.5" long x .125" @ 4 dreumf rows, staggered 18 deg. 11,212 11,626 3,309.2 3,288.5 WS B, 1J-158 69/2007 32.0 SLOTS Alt SLOT/BLANK, 2.5" long x.125" @ 4 circumf rows, staggered 18 deg. 11,841 12,214 3,292.5 3,302.0 WS 8, 1J-158 69/2007 32.0 SLOTS Alt SLOT/BLANK, 2.5" long x .125" @ 4 circumf rows, staggered 18 deg. IStn ITOp IftKBl IRKB) I I(°) I Make I MoCat I MI Serv I Type Type (inl T IP tool Run Date ICOm... u;~ + ~,~~ ~ ;. 4 -. ~a ~~. ~r~te R`. ,~ i MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc l__J Page 1 of 2 Schwartz, Guy L (DOA) ..,_ __... _ _ From: Packer, Brett B [J.Brett.Packer@conocophillips.com] Sent: Thursday, March 25, 2010 10:34 AM To: Schwartz, Guy L (DOA) Subject: RE: 1J-158 RWO (PTD 207-054} Guy,. The wellhead issues on 1 J-158 are as follows: It has a Vetco 13-5/8" multi-bowl horizontal wellhead with a 10-3/4" hanger installed inside a 13-5/8" x 10-3/4" reducer bushing. These wellheads were designed with the reducer bushing so that the 11"stack could be used. during workovers to pull the hanger and completion meanwhile leaving the reducer bushing in place. The reducer bushing-has two sets of packoffs, upper & lower, to seal off from the produced fluids that exit through the side port of the horizontal wellhead. Prior to the workover, we had our guys test the packoffs on the reducer bushing and the hanger, our tests indicated that the upper reducer bushing packoffs were good butthe lower reducer bushing. packoffs failed, so I had the procedure originally written to use the 13-5/8" stack and pull & replace the reducer bushing during the workover. But just prior to workover, I had the Vetco hand double check-and. pressure test the packoffs, and he specifically told us that they passed, so the procedure was revised to use the 11" stack (to save money): after being assured that we didn't need to change the reducer bushing. Well, come to find out at the end of the workover, we couldn't get a test on the lower packoffs and we knew we had to change the seducer bushing. A# that point, we had the 11" stack on the well and. there was no way to pull the reducer bushing through the smaller stack, so we had to swap stacks. We secured the well by installing a BPV, ND the BOPS, and-installing,the tree. We had two barriers in-place during the ND-of the BOP, with KWF in the hole and a BPV, as well as a good test on the hanger packoffs and upper reducer bushing packoffs. We had to back- the rig. off the weA enough to remove the 11 "stack- from the cellar and- bring in-the 13-5/8" stack. Then we had to rig back upon the well with the 13-5/8" stack, do a BOP test, pull the hanger and reducer bushing to the floor, swap out the reducer bushing, and re-land. it. Following. this, all packoff tests passed. If you have any more questions; don't hesita#e to-give me a call. Brett Backer ~DrilX'ng ~G 4AlelZr `WorfQver Engineer 'kl1vrk# {907) 265-684.f Celr'# (907)230-8-377 Fromr Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska,gov} Sent: Thursday, March 25, 2010 9:12 AM To; Packer,- Brett B Subest~ 17-158 RWO ~PTD 207-054): Brett, Can- you- elaborate on-the issues late in-the workover for me? I am reading the 404 and caFl't quite understand what is going on with the hanger seals failing multiple times. l know the 11-" BOP stack was swapped to the 13 5/8"... why again?? Guy Schwartz 3!25!20.1(} Page 2 of 2 Senior Petroleum Engineer AOGCC 793-1226- (office) 444-3433 (cell) 3/25./201 Q STATE OF ALASKA I~, ~ ~ AND GAS CONSERVATION COMMIS~I ~RT OF SUNDRY WELL OPERATIONS 1. Operations Performed: '~~~IB~c~""w ell plug Pbrforations ~'" Stimulate ~ Other ~` Install Gas Lift ~ ;X +~iaSkr , Alter Ca9ir~1 Pull Tubing Perforate New Pbol Waiver completion ~ Time Extension °' :~. ~ M Change Approved Rogram ~"` Operat. Shutdow n ~ Perforate "'" Re-enter uspended Well ~" Twsf.~ 2. Operator Name: 4. Current Well Status: Permit to Drill Number: ConocoPhillips Alaska, Inc. Development ~ Exploratory """` 207-054 3.2~!•r~ 3. Address: \ Stratigraphic ~°" Service API Number: P. O. Box 100360, Anchorage., Alaska 99510 50-029-23356-00 7. Property De~signa'tiDn: ~ 8. Well Name and Number: ADL 25660, 25661, 25663 ~ 1J-158 9. Field/Pool(s): ~ Kuparuk River Field /West Sak Oil Pool 10. Present Well Condition Summary: Total Depth measured 12268 feet Plugs (measured) None true vertical 3301 feet Junk (measured) None Effective Depth measured 12259 feet Packer (measured) 7541 true vertical 3300 feet (true vertucaq 3266 Casing. Length Size MD ND Burst Collapse CONDUCTOR 80 20 121 121 SURFACE ' 3350 10.75 3395 2153 PRODUCTION 7850 7.625 7890 3323 B LINER SLOtS 4718 4.5 12259 33l)0 Perforation depth: Measured depth: 7895'-8697', 8954'-11089', 11212'-11626', 11841'-12214' True Vertical Depth: 3323'-3305', 3321'-3320', 3309'-3289', 3293'-3302' Tubing (size, grade, MD, and TVD) 3.5, L-80, 7337 MD, 3232 TVD Packers & SSSV (type, MD, and TVD) HRD ZXP Liner top packer , 7541' MD, 3266' TVD ;HRD ZXP packer @ 7313' MD, 3227' TVD NIPPLE - Camco "DS" 2.875" Nipple @ 485 MD and 485 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation si Subsequent to operation si 13. Attachments .Well Class after proposed work: Copies of Logs and Surveys run Exploratory ~"" Development Service . Well Status after work: .Oil ~` Gas "" WDSPL Daily Report of Well Operations XXX " GSTOR WAG ` GASINJ WINJ SPLUG 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: none Contact Brett Packer t~ 265-6845 Printed Name Brett Packer Title Wells Engineer Phone: 265-6845 Date Signature ,%~ ~~, v~- ~~~ ~~Z 3 ~ D ~. -. , RBDMS MAR ~~~ 2010 c~- ~ ~-~' • r~ Form 10-404 Revised 7/2009 Submit Original Only ~/~/o .~ ,. i Conrscc.~iPhiili~~ ,,'~~ ~'~ I~ x W all Config: Multiple La[erel~ 56 ~ 'tu ~ , i _.I 9 S hamat A~. u:, HANGER. 36 ~' 41-'121 NIPPLE. 485 Hea~. Traca.4a rUI31NG. 2.597 SURFACE, 453.395 GAS LIFT, 4.,93] GAS LIFT, ].tie NIPPLE. ].222 - GAUGE, ].212 - SEAL ASSV, ],311 PRODUCTION, ,~ ` 41].850 ~ ' SLOTS. - ],855-8,69] _"" ..~ ~ ~ SLOTS, _ W t 6.95011,089 ~ ~ ..~ SLOTS. ~ .:°. ~ I ~ '. 11,212-11,626 ti'! i ~+~' SLOTS. r I - 11,84t~12.214~ BLINER - - + ,~ ~ SLOTS. \ ],541-12.259 ~ TD (1 J-158). 12,268 - 1J-158 Attributes _~_ _ Max Angle 8r MD ~TD ! - _ 'e APUl1Wl (Field Name I Well Statu Iucl ~' 'MD (ftK8) (Act Bhn (ftK8) 1292335600 IWESI SAK PROD 9E-// ~ 71,176.18 12.268.0 I mt H28 (ppnll Data Annotaton 'End Date ~KB-Grd (ft) Rig Release Dete~ NIPPLE °0 7/1012009 (Last WO. 2127/2010 43.01 I 6121/2007 [ion Depth (ftK8) 11 End Date Annotation Last Mod .../End Date eg I Rev Reason~ WORKOVER ~ Imos bor it 3/1/2010 rig Strings Des ption !~St g O. SIn g ID Top (ftK8) Set D pth (f... Set Depth (ND) .. St ing Wt:.. Str rig ... String Top ThM ucroR zo ~ 11 o2a a1.o 121.a 121.0 94oD K-s5 ~ Descn ption (String O .. ~~ Slr g ID Top (ftK8) Set Depth (t... Set Depth (ND) ... String Wt._ String ... String Top Thrd 1CE 10 3!4 1. .i0 45.3 3,395.0 2.753.8 45-60 L 80 BTC Description String 0... String ID .. . Top (ftK8) Set Depth (i... Set Depth (ND) ... String Wt... String ... String Top Thrd UCTION 7518 6.875 40.6 7,590.2 3,322.4 29.70 L-80 BTC-motl _ Description String 0... String ID ... Top (ftK8) Set Depth (t... Set Depth (ND) ... String Wt... String ... String Top Thrd ID LEM 41/2 4.fi0G 7,303.6 7,585.1 3,273.1 1260 L-80 IBi Description String 0... String ID .. . Top (ftK8) Set Depth (t... Set Depth (ND) ... String Wt... String ... String Top Thrd iR SLOTS 4112 3A76 7,541.4 12259.0 3.3009 11.60 L-80 BTC r Details _._ I (Top Depth ' ~ INDI Too Incl Nomi... 7,541.4 3,266.0 80 83' PACKED: - "HRD" ZXP Liner Top Packer 5.5" X 7 63"( 6-55" OD 5.750 7,560.4 3,269.0( 80.691 NIPPLE "RS" Packoff Seal Nipple 5.5"(6.04" OD z 4.88" ID) 4.880 7,563.3 3,269.5. 80.67 HANGER FIexLDCk liner Hanger 6.5" X 7.6"(6.59" OD x 4.86" 4.86D 7,573.1 3,271 1 80.60 SBE 190-07 Casing Seal Bore Ext (G.OS" OU x 4.75" ID) 4 750 /.593.3 a2 /4.5 80.46 XO I:'.U5I IIPJ3 ~ XO Bushing (S JI" OD x 392" IU) 3920' ubin g tnn s escnpuon Shing ._ String Top Thrd t.- set D t... ti e str .. -y'D Top 1 set D) . Bt ~ 161NG ~ 3 1 2 ~ r I 5 9 ] 30 ? 331 3 3 231 S ~ L 80 EUE Brd omple tion De - tails :- Top Dep t __ _. (ND) Top Incl Nomi... .p (ft1C6); (flxe) (°I Item Description Comment ID (in) 35.9 35.9 -0.04 HANti~ER Vetco Gray 11" x 4 1/2" Hanger w/ 4.909" MCA Top Conn. Matle up on 3.900 68.7 68.7 0.26 --_ XO - I?rtlucmg 4 1/2" IBT M Box x 3 1/2" 8rtl Pin Cross over 2.992 485.3 485.1 3.86 NIPPLE Camco "DS" 2.875" Nipple 2.875 7,221.9 3,207.6 77.67 NIPPLE. Camco "US" 2.812" Nipple -W/ RHC Plug installed 2.875 7,264.8 3,216.8 77.64 XO - L-.ale rgmg 3 1/2" 8rtl Pin x 4 V2" IBTM Box Cross over Sub 2.992 7,271.9 3,219.8 79.79 GAUGE 4 1/2" Guardian Gauge Carrier 3-958 7, 309.0( 3,226.5, 79.89 LOCATOR Baker5.5"Locator Sub 3.880 7,310.11 3,226.8 79.90 SEAL ASS'Y Baker "GBH" - 22 Locating Seal Assy w/ 2' space out off nogo 3.820 Rher I n Hole ( Wiretine retrievable valves, pumps fish~etc~ _, ~lugs, __ _ Top Depth'. _ . (TVO) Top Incl .p (ftK8) (ft Ke) (°) De -I t <:~n Comment Run Date ID (in) 41 41.0 0.01 I-teal 'i HEAf (RACE 2/23/2010 0.000 erfora tions & Slots ' Shot Top (TVD) Btrn {TVD'i ~ Dens ,p (ftK8) 1 Bim (ftK8) (ftK8) (flKBj Zone Data (sh-~ Type Comment 7,895 8,697 3,323.1 3,305.3 WS B, 1J-158 6/9/2007 320 SLOTS Alt SLOT/BLANK 25" long x .125" @ ', 4 circumf rows, staggered 18 deg. 8,954 11,089 3,320.7 3,379.7 WS A4, 1J-158 6/9/2007 32.0 SLOTS Alt SLOT/BLANK 2S" long x .125" @ 4 circumf rows, staggered 18 deg. 11,212 11,626 3,309.2 :!,286.5 WS B, 1J-158 6/9/2007 32.0 SLOTS Alt SLOT/BLANK, 25" long x .125" @ 4 circumf rows, staggered 18 deg. 11,841 12,214 3,292.5 3,302.D WS B, 1J-158 6/9/2007 32.0 SLOTS Alt SLOT/BLANK, 25" long x .125" @ 4 circumf rows, staggered 18 deg. otes: General 8 Safet End Date Annotation 21/2007 (NOTE:MULTI-LAIL-FL>,L WELL-1J-158 (B-SAND), 1J-158L7 (D-SAND) 21/2008 NOTE: VIEW SCHEMATIC w/Alaska Schematic9.0 1/2010 (NOTE: WORKOVER 2i'>7/2010 CONVERSION FROM ESP TO GAS LIFT 1J-158 Pre and Post Rig Events DATE SUMMARY 12/3/09 PRE RWO T-POT (PASSED ), T-P~T (PASSED ), UT-POT (.PASSED ), U~POT PASSED ), LT-POT. (FAILED ), LT-PPPOT (FAILED ), IC-POT (PASSED ), IC- PPPOT .PASSED ), FT-LDS ALL NORMAL. 1/4/10 MEASURED SBHP @ 7150' SLM (1674 psi ). GRADIENT @ 1300' SLM (977 psi) & GRADIENT @ 100' SLM(545 psi ). COMPLETE. 1/24/10 BULLHEADED 90 BBL OF DIESEL DOWN THE IA AT 2 BPM. PUMP PRESSURE GRADUALLY INCREASED FROM 750 PSI TO 1000 PSI, SHUT IN THE IA. BULLHEADED 50 BBL OF DIESEL DOWN THE TUBING AT 2 BPM. PUMP PRESSURE GRADUALLY INCREASED FROM 950 PSI TO 1075 PSI. 1/28/10 BLEED T 8~ IA , 30 MIN EACH VERIFIED FLUIDS TO SURFACE. 3/3/10 PULLED B&R f/ RHC @ 7221' RKB. DETERMINED ORIENTATION OF GLM #2 POCKET @ 3:00 LOOKING DH. PULLED VALVES @ 4936' & 7177 RKB. ATTEMPTED SET GLVs @ SAME, POOR ACTION & THICK FLUID. IN PROGRESS. 3/4/10 DISPLACED TBG WITH DSL. SET 5/16" OV @ 717T, GLV @ 4936' RKB. PULLED RHC BODY @ 7221' RKB. COMPLETE. i ~~ ConocoPhillps Time Log & Summary LYalWiew Wab RepoRing Report Well Name: 1J-158 Rig Name: NORDIC 3 Job Type: RECOMPLETION Rig Accept: 2/10/2010 2:00:00 AM Rig Release: 2/27/2010 4:30:00 PM Time Lo s Date From To Dur S. De th E. De th Phase Code Subcode T' Comment. 2/10/2010 2a hr summary Completed 1J 135 program. Move Nordic Rig 3 off of 1J 135. 00:00 01:00 1.00 COMPZ MOVE MOB P Move Nordic Rig 3 off of 1J 135 Well Slot. Move Rig over the skid for the 13 5/8" BOP Stack. Accept Nordic Ri 3 at 02:00 hours, 02/10!2010. 01:00 05:00 4.00 COMPZ MOVE MOB P Nipple down 13 5/8" Stack from stump on rig and set on skid. Mover over the Skid with the 11" BOP Stack. Pick up 11"Stack and set on ri stum . 05:00 08:00 3.00 COMPZ MOVE MOB P Back Rig off of the 11" BOP skid and spot in front of 1J 158 Well slot. Lay double mats and continue to prep Well Slot. S of ri over well. 08:00 13:30 5.50 COMPZ RPEQPI RURD P Spot equip. RU hardlines. RU cellar hoses & load its. 13:30 15:00 1.50 COMPZ WELCTI KLWL P RU lubricator. Pull BPV. Pressures IA 300 psi Tubing 350 psi. OA 20 si. 15:00 17:00 2.00 COMPZ WELCTL KLWL P Start Qumping down tubing takin returns from IA to kill tank. Pump 4 BPM w/ 300 psi pump pressure, 350 psi IA pressure. Pumped 310 bbls shut down, guage kill tank and take pressures. Kill tank had 127 bbls. SITP 150 psi, IA 160 psi. Pumped another 75 bbls and returns were 8.6# all SW. SD blow down lines. 17:00 18:30 1.50 COMPZ WELCTL P Bullhead 110 bbls. down the Tubing at 4.0 b m/340 si. 18:30 21:00 2.50 COMPZ WELCTL P Monitor WelFand attempt to read stabilized SITP. Un-load pellets of salt. 21:00 22:00 1.00 COMPZ WELCTI P Thaw out line going to Tiger Tank. 22:00 00:00 2.00 COMPZ WELCTI P Circulate Well down the Tubing at 2.5 bpm/160 psi. Take returns to Rig Pits. Gas to surface. Route returns to Tiger Tank. Discuss plan forward with Anchorage Engineer to plan on wei htin u . 2111 /2010 Circulate and kill Well w/9.8 ppg Brine, Set BPV and Blanking Plug. ND Tree. Daily Fluid Loss = 356 bbls, Cum Fluid Loss = 445 bbls Page 1 of 16 a `Tune. Lo s bat From To Dur S. De th E. th "Phase Code Subcode T Comment 00:00 07:30 7.50 COMPZ WELCTL CIRC P Finish circulating Well. Shut in and monitor. SITP = 120 psi and stable. IA also 120 psi. Calculate kill weight fluid at 9.23 ppg. Order out Vac Truck from MI with 9.6 ppg Brine. Build fluid in rig Pits from 8.6 ppg up to 9.6 07:30 10:00 2.50 COMPZ WELCTL CIRC P Line up to circulate well over to 9.6 ppg Brine. ICP 250 @ 4 BPM. Pumped 345 bbls 9. ppg brine until returns of 9.6 ppg. SI blow down lines Check well for pressure. Bled pressure to 0 psi and small flow back to gas buster. Flowed back 8 bbls in 45 min. well dead 10:00 12:00 .2.00 COMPZ WELCTL NUND P Blow down lines and ND cellar lines. O en tubin weH flowin a ain. 12:00 14:30 2.50 COMPZ WELCTL KLWL P Continue to monitor well. Bled off IA, and tbg. SI to monitor pressures while wt u its to 9.8 14:30 18:00 3.50 COMPZ WELCTL KLWL P RU circulating lines and PT to 2500. Pumped 108 bbls down tubing lost 104 bbls. Switched and pumped 181 bbls down IA lost 34 bbls. 4 BPM w/180 psi. SI monitor well. Static. Total losses for the da 356 bbls. 18:00 20:00 2.00 COMPZ WELCTL MPSP P Attempt to set BPV. However tubing side has slight flow. Allow Tubing and IA to U-Tube. Monitor. Pump 20 bbls of 9.8 ppg down Tubing.. Set BPV. 20:00 20:30 0.50 COMPZ WELCTL SFTY P PJSM. Nipple down Production Tree. Discussed hand and body placement, use of proper tools, overhead loads. 20:30 23:30 3.00 COMPZ WELCTL NUND P Nipple down Production Tree and remove Bonnet. 23:30 00:00 0.50 COMPZ WELCTL NUND P Begin to Nipple up 11" BOP Stack. 2/12/2010 Test BOPE at 250/5,000 psi. Pull BP/BPV. Pull Tubing Hanger free. Pump hot 9.8 ppg Brine down IA. Lay down Tubin Han er. Dail fluid loss = 145 bbls. Cum loss = 590 bbls. 00:00 09:30 9.50 COMPZ WELCTL NUND P Finish nipple up XO Flange and BOP Stack. Install 2 3/8" Pipe Rams in top section. Install Riser. Normally have 4 rnen in cellar to NU & ND, only 3 now because of present crew count. 09:30 16:00 6.50 COMPZ WELCTL BOPE P Test 11" BOPE 250/5000 /annular 250/3500 psi. Witnessing of test waived b Chuck Scheive 2-9-2010. 16:00 18:00 2.00 COMPZ WELCTL NUND P BD test equip. MU retrieving tool, pulled test plug, pulled BPV._MU Xover onsafe valve. MU landin 't. Page 2 of 16 Time Lo s Date From To Dur S. De th E De th Phase Code Subcode T Comment 18:00 20:00 2.00 COMPZ RPCOM THGR P Back out lock down screws. Attempt to pull Tubing Hanger free with 210K. Rig up and apply steam heat to Wellhead. Pulled Tubing Han er free with 160K: Pulled Tubin Han er to floor with 105K. 20:00 21:30 1.50 GOMPZ RPCOM CIRC P Pumped 190 bbls of hot 9.8 ppg Brine down IA at 4.0 b m/140 si. 21:30 22:00 0.50 COMPZ RPCOM OWFF P Flow check Well. Observe slight flow from IA. Flow stopped. Observe slow fluid dro . 22:00 22:30 0.50 COMPZ RPCOM SFTY P PJSM to lay down Tubing Hanger and RU to lay down 4 1/2" ESP Completion. Discussed pinch oints, work area, sus ended loads. 22:30 00:00 1.50 COMPZ RPCOM PULD P Start to lay down Tubing Hanger and Landing Joint. Hydraulic hose burst going to Top Drive. Remove hose and safe out. Clean up work area on Floor. Finish laying down Tubing Hanger and Landing Joint. (inspected Hanger and found damaged and flatten threads . Approximately a -2"wide section inside BPV profile. Damage mast likely caused from repeated CT, S-Line, and E-Lines runs in and out of Well. 2/13/2010 Single down 4 1/2" ESP Completion. Lay down ESP Assembly. Daily Fluid Loss = 33 bbls. Cum Loss = 623 bbls. 00:00 21:30 21.50 7,231 0 COMPZ RPCOM PULL P Pull and sin le down 4 1/2", 12.6 Ib/ft, L-80, IBTM Tubing while spooling ESP Cable. Shut down, strap and unload pipe shed after each row. Lay down a total of a Tubing Hanger on a full Joint , 230 Joints of Tubing, and 1 ea GLM Assembly. Recovered 3 ea Protectolizers, 2 ea Flat Guards, and 12 ea Stainless Steel Bands. (Note: left 3 ea SS Bands in hole. Discussed the +/- of making a separate fishing trip to attempt recovery of the lost bands with Anchorage Engineer. Decision made to continue with next step in planned ro ram . 21:30 00:00 2.50 COMPZ RPCOM PULD P ESP Assembly at surface. Break down, inspect, and lay down ESP sections per Centrilift Service Rep. Motor burnt. 2/14/2010 Make-up Clean Out BHA. Single in with 3 1/2" grill Plpe. Found possible sand or junk at 7,563-ft. Unable to make an further hole. Start TOH. Dail Fluid Loss = 353 bbls. Cum Loss = 976 bbls Page 3 of 16 ~~ Time Lo s Date Frorn To Dur S. De th E. De th Phase Code Subcode T Comment 00:00 05:30 5.50 0 COMPZ RPCOM RURD P Clear and Clean Rig Floor. Load out ESP sections in shipping boxes. Re-count ESP Clamps and clear Pipe Shed. Rig up to handle BHA and 3 1/2" Drill Pipe. Install Wear Bushing. Bring 3 1/2" Tubing and remainder of BHA needed into Pipe Shed. Tall same. 05:30 14:00 8.50 5,322 5,322 COMPZ RPEOPI PULD P Make-up Clean Out BHA. RIH on 3 1/2' Drill Pipe, PU from pipe shed. to 5,322'. 14:00 15:30 1.50 5,322 5,322 COMPZ RPCOM OTHR P Shut down, secured well. PJSM w/crane operator. Remove ESP . cable and spooler from rig floor while crane was availble. 15:30 19:30 4.00 5,322 7,563 COMPZ RPEOPI PULD P Continue to PU 3 1/2" drill pipe and RIH from 5,322' to 7367'. Up wt 120K Dwn wt 45K, Est. circulation w!3 BPM @ 675 psi. Continue RIH with no problems down to 7,563-ft., which is 10-ft above the Seal Bore Receptacle. Tagged up. Attempt to make further hole. Increase pump rate to 4.0 bpm/1,100 psi. Pull up hole. RIH and tagged up at 7,559-ft. Lost hole. Tried once again to make hove. No-jay. Pulled up hole and tried to work back dawn. Lost 30 more feet. Now at - 7,529-ft. Had 8K over pull. Lay down 2 Joints. Discussed plan forward with Anchorage Engineer. (decision made to POOH and run the 2 3/8" x 3 1/2" clean out strin 19:30 00:00 4.50 7,529 187 COMPZ RPEOPI TRIP P Drop Dart and open Pump Out Sub.. 81ow down Top Drive. Trip ouf with 3 1/2" Drill Pipe standing back in Derrick. (loading Pipe Shed with 2 3/8" Drill Pi e. Tall same . 2/15/2010 Plck up 2 3/8" Clean Out String. Continue RIH with 3 1/2" Drill Plpe. Clean out to 7,625-ft. POOH, standing back 3 1/2" Drill Pipe. Lay down the 2 3/8" Drill Pipe. Lay down BHA #2. Daily Fluid Loss =345 bbls. Cum Loss = 1,321 bbls 00:00 04:30 4.50 187 0 COMPZ RPEOPI PULD P Lay down BHA #1 The last 20 feet of the BHA was plugged with formation sand. Clear sand from BHA. Rig down handling equipment. Clean Rig Floor. Finish loading Pipe shed with 2 3/8" PAC Drill Pi e. 04:30 08:30 •4.00 0 COMPZ RPEOPI TRIP P Rig up equipment to handle 2 3/8" PAC Drill Pi e. Make up 2 3/$" Mule Shoe. Single in with 53 jts of 2 3/8" PAC Drill Pi a from Pi a Shed. 08:30 12:00 3.50 COMPZ RPEOPI TRIP P Switch running tools over for 3 1/2" drill pipe. Start running drill pipe from derrick. Page 4 of 16 r~ Time c g "Date From - To Dur S. De th E. De th Phase`' Code _ Subcode T Comment 12:00 13:00 1.00 7,404 7,543 COMPZ RPEQPI WASH P With mule shoe @ 7404',Established circualtion w/ 40 bbls. 3 BPM, 810 psi. Lowered in hole to 7501',Closed bag and established reverse circulation 3 BPM @ 60 psi. Lowered pressure on bag and washed down to 7543' with no returns. Lost 111 bbls Burin this rocedure. 13:00 15:00 2.00 7,543 7,607 COMPZ RPEQPI WASH P SD pump, opened bag. Pumped conventional down tubing. 4 BPM 1290 psi washing down to 7607' (12' below SBE). While. working pipe up and down, pumped 40 bbl sweep 3# bbl Ftowvisc Plus. Returns were only 50 to 60%. SD pump,. lined up and pumped 70 bbls down tubing and annulus @ 46PM w/90 psi. FP 140 psi. SD pump. Pulled 5 studs to 7114'. Lost total of 216 bbls during clean out. 15:00 16:00 1.00 7,114 7,625 COMPZ RPEQPI OTHR P Monitor well for 30 min. let possible sand settle. Ran back in hole to 7625' na fill. 16:00 19:30 3.50 7,625 1,669 COMPZ RPEOPI TRIP P Trip out with 3 1/2" Drill Pipe standin back in Derrick. 19:30 22:00 2.50 1,669 0 COMPZ RPEQPI PULD P Change out handling equipment to handle 2 3/8" PAC Drill Pipe. Single down 2 3/8" Drill Pipe in Pipe Shed. La down BHA #2. 22:00 00:00 2.00 0 COMPZ RPEQPI PULD P Change out handling equipment to handle 3 1/2" Drill Pipe. Make up BHA #3 as follows: 4 112" Bukl Nose Wash Nozzle, XO, 3 ea Joints of IBTM Tubing, XO, 1 ea 3 1/2" EUE 8rd Tubing, XO, 4 3/4" Lubricated Bumper Sub, 4 3/4" Oil Jar, 3 1!2" Pum Out Sub. 2/16/2010 RIH with BHA #3. Wash Sand Bridges from 7,345-ft down to top of SBR at 7,571-ft,dmd. Clean out sand from inside of SBR to "NO-GO at 7,593-ft. TOH with 3 1!2" Drill Pipe and lay down BHA #3. Daily Fluid LOss = 365 bbls. Cum to Date = 1686 bbls. 00:00 04:00 4.00 0 7,345 COMPZ RPEQPI TRIP P Trip in with BHA #3 and 31/2" -Drill Pipe from Derrick. PUW = 110K. SOW = 50K. Page 5 of 16 Time L' s Date From To bur S. De th E De th Phase Code Subcode T `Comment 04:00 06:30 2.50 7,345 7,575 COMPZ RPEQPI WASH P Continue RIH. Started taking weight at 7,345-ft. Set down at 7,361-ft. Bring pump on line at 2.0 bpm/680 psi. Wash down to 7,433-ft. PUH with normal string weight. Continue down to _7,500-ft. Had to increase pump rate to 2.5 bpm/1150 psi to get through sand bridges. Set down again at 7,571-ft, (top of Seal Bore Receptacle, Driller's measured depth). Made two more attempts to enter same. (decide to dean up sand above before continuing to enter SBR). PUH and set back 5 stands. Park Nozzle at 7,122-ft. Down squeeze IA at 4.0 bpm/120 psi. Volume pumped 70 bbls. Bring pump off tine, slowly. Leave Well shut in with 40 psi and let pressure bleed off into "D" Lateral. 06:30 11:00 4.50 7,122 7,593 COMPZ RPEQPI WASH P Leave Welt shut in for 2 hours. Open Well with an estimated 15 - 20 psi. Observe a slight flow then no flow. RIH with the 5 stands from the Derrick. Clear down to 7,575-ft (dry tag). Set down at same spot as before. Bring pump on line at 2.0 bpm/700 psi and attempt to enter the SBR. Also tried at 1.0 bpm/400 psi and at 3.0 bpm/1,330 psi. After several attempts at 3.0 bpm nozzle entered. Wash inside of SBR down to "NO-GO" at 7,593-ft. Pull out with a slight drag. Re-enter SBR with little difficulty. Clear down to "NO-GO". Pull back up to 7,113-ft. and ark nozzle. 11:00 14:00 3.00 7,113 7,593 COMPZ RPEQPI WASH P Down squeeze IA at 4.0 bpm/125 psi. Volume pumped, 70 bbls. Let set for 2 hrs with 70 psig Final shut in pressure. Open up well with 20 si .RIH with no fill to . 14:00 1$:00 4.00 7,593 3,089 COMPZ RPEQPI TRIP P POOH slowly for the first 20 stands f/ 7,593' t/ 3,089' MD 18:00 19:30 1.50 3,089 3,089 COMPZ RIGMNT RGRP P Slip and Cut drill line (84-ft). Inspect Draw Works. 19:30 21:30 2.00 3,089 186 COMPZ RPEOPI TRIP P Continue to trip out with 3 1/2" Drill Pipe, standing back in Derrick. BHA #3 to surface. 21:30 22:30 1.00 186 0 COMPZ RPEQPI PULD P Lay down BHA #3. Inspect 4 1/2" Wash Nozzle. No marks. Clear and Clean Floor. 22:30 23:30 1.00 0 COMPZ RPEQPI PULD P Rig up Floor to handle LEM Assembly. Perform final LEM Assembl ins ection. 23:30 00:00 0.50 COMPZ RPEQPI SFTY P PJSM. Discuss using proper tools, hand and body placement, overhead loads. Page 6 of 16 r i Time Lo s Date From -To Dur S. De th E. De th Phase Cade Subeode T Commer-t 2/17/2010 24 hr Summary Unable to enter Mainbore Lateral. It is assumed that the Mule Shoe is hanging up on the D-Sand Lateral Window. TOH. Lay down assemblies. Inspect Mule Shoe. MS shows signs of scars and scuff marks from attempting to work passed the Window. Make up Assemblies again. However Run #2 has a "bent joint" included ~ust above the Seal Assembl .Dail Fluid Loss = 164 bbls. Cum Fluid Loss = 1,850 bbls. 00:00 02:30 2.50 0 0 COMPZ RPEQPI PULD P Make up Seal Assembly and LEM Assembly. Make up ZXP Packer . Make up inner string, including MDW Tool. 02:30 03:00 0.50 0 293 COMPZ RPEQPI TRIP P RIH with one stand. Perform MWD Pulse Test. Good. 03:00 11:00 8.00 293 7,345 COMPZ RPEQPI TRIP P Trip in with LEM Assembly and 3 1/2" Drill Pi a from Derrick. 11:00 11:30 0.50 7,345 7,345 COMPZ RPEQPI OTHR P MU TD and Establish parameters 110k up wt, 55k do wt. PP @ 350 si 2 b m. 11:30 13:30 2.00 7,345 7,450 COMPZ RPEQPI TRIP P RIH to 7,450' and Tag, Attempt to work down -changing oreintation multi le times -still unable to et ast 7,450' 13:30 14:00 0.50 7,450 7,450 COMPZ RPEQPI OTHR P low down top drive 14:00 19:30 5.50 7,450 294 COMPZ RPEQPI TRIP P POOH f/ 7,350' MD w/110k up wt. LEM Assembl at surface 19:30 21:00 1.50 294 0 COMPZ RPEQPI PULD P Lay down inner string including MWD. Lay down ZXP Assembly. Lay down LEM Assembly. (marked both DB Nipple Assemblies as to their proper running order before laying down). Lay down Seal Section. Inspect same. Found several scarred and scuffed areas on the side of the Mule Shoe. Also a few dings on the lip of the Mule Shoe wwere noticed. No evidence of any sand on the seals of the Seat Assembly or on any of the other com anents. 21:00 00:00 3.00 0 294 COMPZ RPEQPI PULD P Bring 4 1/2" 12.61b/ft L-80 IBTM x ST-L XO Tubing Joint (bent Jt) into Pipe Shed and tally. Make up Seal Assembly on the 4 1/2" "bent" Joint. Pick-up LEM Assembly. Pick up ZXP Assembly. Make up inner string ineludin MWD Tool. 2/1$/2010 Ass #2 on 3 1/2" Drill Pi e. Tagged up at 7,450-ft. Attempt to work down several times. No-joy. POOH. Lay down LEM Assy. Pick up Polish Mill BHA. and trip in with 3 1/2" Drill Pipe to 5,550-ft. Dail Fluid Loss = 243 bbls. Cum Fluid Loss = 2,093 bbls. 00:00 02:30 2.50 0 293 COMPZ RPEQPI TRIP P Make up and trip in with Lem Assembly on 3 1/2" Drill Pipe from Derrick. 02:30 03:00 0.50 293 293 COMPZ RPEQPI OTHR P Shallow pulse test MWD -Good - Blow down To Drive. 03:00 11:00 8.00 293 7,345 COMPZ RPEQPI TRIP P RIH w/ LEM BHA #2 on 3 1/2 DP from 293' to 7,345' MD. Page7of16 r~ Time L Date From To Dur S De th E. De th Phase Code Subcode T Comment 11:00 11:30 0.50 7,345 7,345 COMPZ RPEQPI OTHR P Gather Parameters: 110k up wt, 55k do wt. Pump pressure @ 350 psig 2 b m. 11:30 13:30 2.00 7,345 7,450 COMPZ RPEQPI PACK P RIH to 7,450' -Tag up. Attempt to work down -changed orientation mutiple times and still not able to get thru. POOH to 7,350'. 13:30 14:00 0.50 7,350 7,350 COMPZ RPEQPI OTHR P Blow down top drive 14:00 18:00 4.00 7,350 295 COMPZ RPEOPI TRIP P POOH from 7,350' MD w/ 110k up wt. to LEM BHA #2 18:00 20:00 2.00 295 0 COMPZ RPEQPI PULD P Lay down LEM BHA #2. Inspect Mule Shoe on Seal Assembly. Same as before, scuffed, scared, and a few small nicks. 20:00 20:45 0.75 0 0 COMPZ RPEQPI PULD P Rig up floor and handling equipment to handle next BHA. 20:45 21:00 0.25 0 0 COMPZ RPEQPI SFTY P PJSM. Descussed next BHA components. Hand and finger lacement, communications. 21:00 22:00 1.00 0 221 COMPZ RPEQPI PULD P Make up BHA #5 as follows: 4 1/8" Bull Nose, XO Sub, XO Sub, 2 ea Jts Z 7/8" PAC Drill Collars, XO Sub, XO Sub, 4 5/8" String MIII. 1 ea Jt 2 7/8" PAC Drill Collar, XO Sub, 5 1/4" Stabilizer Mill, 1 Stand of 3 1/2" Drill Pipe, Bumper Sub, Oil Jar, Pump Out Sub. Total Len th = 221.48-ft. 22:00 00:00 2.00 221 5,550 COMPZ RPEOPI TRIP P Trip in with BHA #5 and 3 1!2" Drill Pipe from Derrick to 5,550-ft. PUW = 77K. SOW = 60K. 2/19/2010 Dress LEM Window. TOH and lay down Mill Assy. Perform Weekly BOP Test. Make up LEM Assembly w/MWD, Run #3. Dail Fluid Loss = 180 bbls. Cum Fluid Loss to Date = 2,273 bbls. 00:00 01:00 1.00 5,550 7,452 COMPZ RPEQPI TRIP P Continue to TIH. Establish parameters as follows: PUW = 100K, SOW = 77K, RTW = 85K, Torque = 3K with 30 RPMs. With no RPMs, ease on down through Hook Hanger and tag with the 4 5/8" String Mill at 7,452-ft kb. Page8of16 ~~ Time. L s Date- From To Dur S. De th E. De th Phase Code Subcode T Comment 01:00 04:00 3.00 7,452 7,593 COMPZ RPEQPI MILL P Bring pump on line at 0.7 bpm/60 psi. RPMs = 30. Lightly polish past the LEM Window with the 4 5!8" String Mill with no problems in 3 minutes. Pull back through with 15K over pull. Re-polish down and back ream times 3. Now have 5K over pull. Re-polish and back ream times 3 again. Now have no over pull. Make a final down/up pass with no RPMs. Good. Continue back down and tag the Window with the 5 1/4", Stabilizer Mill at same depth, 7,452-ft. Increase RPMs to 50 and dress past the Window with 5 - 8K torque in 15 minutes. Continue down to 7,460-ft with no torque. Back ream with rotation with 3 - 5K torque. Repeat four times with very minimal torque. Stop rotation. Make a final down/up pass with no RPMs. Good. Continue down to the NO-Go in the Seal Bore Receptacle at 7,593-ft with no roblems. 04:00 05:30 1.50 7,593 7,593 COMPZ RPEOPI TRIP P Pull 3 Stands and park Bull Nose above Hook Hanger. Shut down- Pump and wait for ~30 minutes to allow for any mill fillings or any possible sand to settle out. Ran back to NO-GO once again at 7,593-ft (no rotation/no pump) with no roblems 05:30 10:00 4.50 7,593 221 COMPZ RPEOPI TRIP P Trip out with 3 1/2" Drill Pipe from 7,593' MD 10:00 11:00 1.00 221 0 COMPZ RPEOPI PULD P Lay down. milling BHA -Lower mill showed signs of milling and upper mill had good milling signs on the lower side and minimal on the top side. 11:00 12:00 1.00 0 0 COMPZ RPEOPI OTHR P Change out to 3 1/2 DP equipment and Pull wear rin . 12:00 21:00 9.00 0 0 COMPZ RPEOPI BOPE P Set test lu and fill ROPE Conduct week) BOP test 250/2,500 psig. 24 hr notice was given @ 0725 hrs on 2-18-10 and Witness of test by AOGCC was waived by Lou Grimaldi @ 0805 hrs on 2-19-10. Good test. Rig down test equipment. Pull Test Plug. Set Wear Bushin . 21:00 21:15 0.25 0 0 COMPZ RPEOPI SFTY P PJSM. Picking up LEM Assembly. Discussed team work and good communications. Also .discussed the resent weather conditions. 21:15 23:15 2.00 294 294 COMPZ RPCOM PULD P Pick up new Seal Assembly. Make up LEM Assembly. Make up ZXP Packer Assembly. Install inner strip , includin MWD Tool. Page 9 of 46 Time to s Date From To Dur S. De th E De th Phase Code Subeode 7 Comment 23:15 00:00 0.75 294 390 COMPZ RPEQPI PULD P Run one stand of 3 1/2" Drill Pipe from Derrick. Perform MWD pulse test. Goad. 2/20/2010 Trip in w/LEM Assy on 3 1/2" Drill Pipe. Set and test LEM Assembly. Release Setting Toot and POOH. Lay down Setting Tool and Inner String w/MWD Tool. Rig up to pick up 2 3/8" x 3 1/2" Clean Out String. Make up 2 3/8" Mule Shoe and start picking up 2 3/8" Drill Pipe. Daily Fluid Loss = 324 bbls. Cum Fluid Loss = 2,597 bbls. 00:00 06:30 6.50 390 7,359 COMPZ RPEOPI TRIP P Trip in with LEM Assembly on 3 1/2" Drill Pipe from the Derrick from 7,359' M D. 06:30 12:00 5.50 7,359 7,585 COMPZ RPEQPI OTHR P Establish Parameters: 2.5 bpm @ 500 psig. RIH and Tag @ 7,440' +/- Top of Hook hanger. PU and orient from 17 degrees LHS to 121 degrees RHS. Slack off thru Hook hanger with no tag -Tagged up @ 7,577' MO w/ mule shoe w/orient @ 48 degrees LHS, PU and SO -tag same - 110k up wt, 60k do wt. continue to work with 13k SO wt and work down to 7,581' MD. Not able to get past. PU and orient to 27 degrees LHS and work down from 7,577' -fell thru 7,582' -continue down to 7,585' with mule shoe and latch LEM @ 7,441' MD -Orient moved from 27 degrees LHS to 4 degrees LHS. Un latch and relatch. -Returns dropped from 16% to 7%. 12:00 13:30 1.50 7,585 7,263 COMPZ RPEQPI PACK P Drop 1.75" OD Ball and chase with 36 bbls @ 2 bpm @ 400 psig and seat ball. Pressure to 2,000 psig and activate puher tool and set ZXP packer @ 7,313' w/ top of setting sleeve @ 7,303' MD. Release Hydrualic running tool @ 3,300 psi. PT Inner annulus @ 2,500 psig for 5 minutes -good test. Pull setting tool from acker ass 7,303' to 7,263' 13:30 17:30 4.00 7,263 7,263 COMPZ RPEQPI OTHR T Suspend operations due to phase 3 weather. Standby with crews and monitor well until Roads and Pads cleared 1J access road. 17:30 20:30 3.00 7,263 31 COMPZ RPEOPI TRIP P POOH from 7,263'. Standing back 3 1/Z" Drill Plpe in Derrick. PUW = 95K 20:30 21:30 1.00 31 0 COMPZ RPEQPI PULD P Setting. Tools and inner string w/MWDTooI at surface. Lay down same. 21:30 22:15 0.75 0 0 COMPZ RPEQPI PULD P Clear and clean Floor. Rig up handling equipment topick up 2 3!8" PAC Drill Pi e. 22:15 22:30 0.25 0 0 COMPZ RPEQPI SFTY P PJSM. Picking up 2 3/8" Drill Pipe. Discussed hand and body lacement. Overhead loads. Page 10 of 16 Time L s Date From To Dur S. De th E. De` th Phase Gode Sutxode. T `Comment 22:30 00:00 1.50 0 675 COMPZ RPEQPI PUTS P Make up 2 3/8" Mule Shoe. Pick up 2 3/8" PAC Drill Pipe from Pipe Shed. 2/21/2010 RIH with 2 3/8" x 3 1/2" Clean Out Strin to 12 250'. Pump 2 ea 20 bbls Hi-Vis Sweeps and attempted to chase to surface. Fluid loss at 2.5 bpm. Start to lay down 3 112" Drill Pipe. Daily Fluid Loss - 747 bbls. Cum Fluid Loss to Date = 3,344 bbls. 00:00 03:30 3.50 675 5,265 COMPZ RPEQPI PUTS P Continue to single in with 2 3/8" Drill Pipe from Pipe Shed (total 164 jts). Sto to chap a handlin a ui ment. 03:30 04:00 0.50 5,265 5,265 COMPZ RPEQPI OTHR P Rig up to handle 3 1/2" Drill Pipe. 04:00 06:00 2.00 5,265 7,806 COMPZ RPEOPI TRIP P Continue RIH with clean out string. Pick up XO, Bumper Sub, and Oil Jars. Begin tripping in with 3 1/2" Drill Pi a from Derrick 7,806'. 06:00 06:30 0.50 7,806 7,806 - COMPZ RPEQPI CIRC P Fill Drill pipe @ 3 bpm @ 2,200 psig w/ 24 bbls rior to RIH. 06:30 07:30 1.00 7,806 8,506 COMPZ RPEQPI TRIP P Continue to RIH with drill pipe from derrick from 7,806' to 8,506' and be in takin wt. 07:30 08:00 0.50 8,506 8,506 COMPZ RPEQPI OTHR P Gather Parameters: 1,700 psi @ 3 b m, 2k free for ue 15 r m. 08:00 12:00 4.00 8,506 10,229 COMPZ RPEQPI FCO P Continuie to Clean out fill from 8,506' to 10,229' and ran out of down wt. POOH w/ 4 stds to 9,842' and add 3 stds of 4 3/4" OD DC's. to 10,119' MD. 12:00 18:00 6.00 10,229 12,250 COMPZ RPEQPI FCO P Continuie to Clean out fill from 10,229' MD. to 12,250' MD. 18:00 20:30 2.50 12,250 12,250 COMPZ RPEQPI CIRC P Pum 1-20 bbl 776 Lube sweep and chase with 70 bbls and pump a second 20 bbl 776 sweep. Pump rate 4.0 bpm/3,100 psi. Return rate ~1.5 bpm. Loss rate 2.5 bpm. Total bbls pumped 612. No sign of either Sweep. End B-Sand Lateral clean out. Blow down To Drive. 20:30 00:00 3.50 12,250 10,456 COMPZ RPEQPI PUTS P Monitor Well. Begin to single down 3 1/2" Drill Pipe to Pipe Shed. Lay down 10 joints. Stop to flow cheek Well. Continue to single down 31/2" Drill Pipe. Clear 3 1/2" Drill Pipe from Pi a Shed as needed. 2/22/2010 Complete laying down 3 1/2" and 2 3/8" Drill Pipe. Daily fluid Loss = 349 bbls. Cum Fluid Loss = 3,693 bbls. 00:00 05:00 5.00 10,456 7,355 COMPZ RPEQPI PUTB P Continue to single down 3 1!2" Drill Pipe. Lay down 9 ea 4 3/4" Drill Collars. Resume laying down 3 1/2" Drill Pipe. Clear Pipe Shed as needed. (Also continue to load Pipe Shed with 3 1/2" Com letion Tubin Page 11 of 16 l r~ t_ S Date From To Dur S. De th E: De th Phase Code Subcode T -Comment 05:00 07:00 2.00 7,355 7,355 COMPZ RPEQPI C1RC P Park Mule Shoe at 7,355-ft. Rig up to Reverse Circulate. Pump 20 bbl 776 tube pill and Reverse Circulate 312 bbls at 3.0 bpm/60 psi. "Weak" returns to surface. SI annulus and flush DP w/ 40 bbls @ 1,710 psig. SI DP w/ 80 si . 07:00 12:00 5.00 7,355 7,355 COMPZ RPEQPI OWFF P Monitor SIWP for equalization. Bleed down from 80 psig to 10 psig. Open up well and observe on trip tank - 10 bbl gain. Continue to Load 3 1/2 Completion string in pipe shed while waiting for well toe ualize. 12:00 14:30 2.50 7,355 5,322 COMPZ RPEQPI PULD P POOH laying down 3 1/2 DP f/ 7,355' to 5,322' w/ 58k a wt. 14:30 15:00 0.50 5,322 5,810 COMPZ RPEQPI TRIP P RIH with DP from derrick from 5,322' to 5,810' 15:00 15:30 0.50 5,810 5,810 COMPZ RPEQPI SFTY P Held PJSM on slipping and cutting drill line along with draw works ins ection. 15:30 16:30 1.00 5,810 5,810 COMPZ RPEQPI RGRP P Slip and cut 84' of drill line and ins ect draw works. 16:30 17:00 0.50 5,810 5,485 COMPZ RPEQPI PULD P POOH laying down 3 1/2 DP from 5,810' to 5,485'. 17:00 18:00 1.00 5,485 5,485 COMPZ RPEQPI OWFF T Standby with crews and monitor well waitin for Phase 3 weather to clear. 18:00 00:00 6.00 5,485 445 COMPZ RPEQPI PULD P Continue to POOH with the remaining 3 1/2 Drill Pipe. Pump Out Sub, Oil Jars, Lubricated Bumper Sub, X-O and 164 Jts of 2 3/8 PH-6 H dril Tubin . 2/23/2010 Continue POOH, lay down shoe. RU & Run 3 1/2" Completion string with tech wire & heat trace. Total fluid loss for the da = 26 BBLS. Cum Fluid Loss = 3,719 bbls. 00:00 01:00 1.00 445 0 COMPZ RPEQPI PUTS P Completed laying down 2 3/8" PAC Drill Pi a in Pi a Shed. 01:00 11:00 10.00 0 0 COMPZ RPCOM OTHR P Pull Wear Bushing. Clear and Clean Floor. Rig up Floor to handle 3 1/2" Completion Equipment and Tubing. Load all Completion equipment, Cannon Clamps and spot (wire and Heat traces ools. 11:00 13:00 2.00 0 165 COMPZ RPCOM PULD P Break down seal assy x 4 1/2" IBTx 3 1/2 8rd. cross over. PU and MU seal assy on 1 jt of 4 1/2" IBT Tubing and RIH. MU 41/2" IBT x EUE 8rd cross over pup jts on Gaurdian Gauge carrier and RIH. Tie in I-Tec wire and hang sheave. MU 4 1/2" IBTx 3 1/2 8rd cross over and 10' x 3 1/2" EUE 8rd Pup joint and RIH to 165' M D. 13:00 20:00 7.00 165 4,341 COMPZ RPCOM RCST P Be in Pickin up and RIH w/ 3 1/2", 9.3#, L-80 EUE 8rd Tubing, installing Cannon X-Cplg clamps on every connection from 165' MD to 4341'. Page 12 of 16 r1 Time Lo s Date From To _ Dur S. De th E. De ttt' Phase Code Subcode T Comment 20:00 00:00 4.00 4,341 5,132 COMPZ RPCOM RCST P Continue run 3 1/2" completion string picking up Neat trace, installing Cannon X-Cplg clamps. Observed fluid loss at 26 BBLS for the day. UP WT - 160K 50 WT - 150K 2/24!2010 Continue run 3 1/2" completion string from 5132' to 7338. Space out installing pup.Attempted to test lower seals on hanger -failed. Install BPV. ND 11" BOP stack. Notified AOGCC of upcoming ops. Total fluid loss for the da = 44 BBLS. Cum Fluid Loss = 3,763 bbls. 00:00 08:00 8.00 5,132 7,265 COMPZ RPCOM PULD P Continue run 3 1/2" completion string with Neat trace, installing Cannon X-Cplg clamps, from 5132' - 7,265'. UP WT - 75K SO Wf - 50K 08:00 09:30 1.50 7,265 7,341 COMPZ RPCOM HOSO P RIH f/ 7,264' to 7,322' see seals start into SBE @ 16' in on jt 227 and NoGo'd out @ 7,314' w/ 3' in on jt 228 w/mule shoe @ 7,340.62'. POOH and lay down 3 jts. MU landing joint to Hanger and joint, MU X-O and 2' Spae out pup joint. Mu to string and finish installing Cannon clam s u to 2' Pu 'oint. 09:30 13:30 4.00 7,304 7,304 COMPZ RPCOM OTHR P Install Penetrators and Make final splice in Heat trace and I-tec wire. Gauge reading after 1,600 psig @ 63.8° F. 13:30 14:00 0.50 7,304 7,304 COMPZ RPCOM CIRC P Pump 25 bbls 9.8 ppg Brine w/ 1% by volume CRW-132 and chase w/ 64 bbls 9.8 ppg Brine @ 3 bpm @ 200 si . 14:00 14:30 0.50 7,304 7,338 COMPZ RPCOM OTHR P Insert seals into SBE @ 7,323' and floated seals into SBE to 7,338' MD. 14:30 15:30 1.00 7,338 7,338 COMPZ RPCOM THGR P Land Hanger and Verify alignment of side port, RILDS. PT Top hanger seals to 5,000 psig -good test. L 15:30 19:30 4.00 7,338 7,338 COMPZ RPCOM THGR T BOLDS and Pull hanger to rig floor, seals ulled out 85k up wt. Change out lower hanger seals and RIN and insert seals w/ 45k do wt. Land hanger and Verify side port alignment, RILDS. Test Top hanger seals to 5,000 psig for 10 minutes - Good test. Test lower seals @ 5 000 si for 10 minutes -Failed test. Called Town Engr and discuss options -decided to Set TWC and test against Blind Rams for Metal to Metal test. Lay down landing jt, Install TWC and fill BOP above Blind rams. Pressure Test @ 250 psig and had slow leak off increase to 5,000 psig and bled off. Bleed off pressure and attempt to re-test -- failed. Pull TWC. Install BPV. Page 13 of 16 i Time Lo s Date From To Dur S. De th E'. De th Phase Code Subcode T Comment 19:30 20:00 0.50 7,338 7,338 COMPZ RPCOM SFTY T Held PJSM. Discuss safety & hazard recognition issues. Discuss procedure to nipple down BOP's and nipple up tree & test same. Notified AOGCC of upcoming operation to re air tubin han er. 20:00 00:00 4.00 7,338 7,338 COMPZ RPCOM NUND T Nipple down 11" BOP stack, set back on stand in cellar. Change out u er VBR's. 2/25/2010 NU tree. Install BPV. Move rig off of well. Remove 11" BOP stack from cellar. Install 13 5/8" BOP Stack. Spot rig over 1J-158. Nipple down tree. Install blanking plug. NU 13 5/8" BOP stack. Tighten cap on annular. RU to test BOP's. Total fluid loss for the da = 0 BBLS. Cum Fluid Loss = 3,763 bbls. 00:00 03:30 3.50 7,338 7,338 COMPZ RPCOM NUND T Prep tree. Nipple up tree and perform void test to 5000 PSI. Fill with disel and test, Upper seals only. Pull TWC. Install BPV. 03:30 05:00 1.50 7,338 7,338 COMPZ RPCOM MOB T Continue prep location, rig and cellar for move off of well. Wrap tree for keeping same warm during BOP swa . 05:00 06:30 1.50 7,338 7,338 COMPZ RPCOM MOB T Move rig off of well. Pull 11" BOP stack out and set on stand. 06:30 11:00 4.50 7,338 7,338 COMPZ RPCOM OTHR T PU 13 5/$" BOP and Stack up. Set back 11:00 13:00 2.00 7,338 7,338 COMPZ RPCOM RURD T Move rig over well and set down. Berm u and re are to rocede. 13:00 14:30 1.50 7,338 7,338 COMPZ RPCOM NUND T ND Tree and Adapter. Install Blankin lu for test. 14:30 15:00 0.50 7,338 7,338 COMPZ RPCOM SFTY T Held PJSM. Discuss safety & hazard recognition issues. Discuss procedure to nipple up BOP's & test cam . Notifi .d AD ~ oft . t. 15:00 00:00 9.00 7,338 7,338 COMPZ RPCOM NUND T NU 13 5/8 ROPE, tighten cap on annular after element had been chan ed out reviousl . 2/26/2010 Complete NU of BOP stack. RU & Test BOP's to 250 / 2500 PSI. Witness of test waived by AOGCC rep Jeff Jones. Rig up and pull tbg hanger to rig floor. Change out lower bushing assembly on hanger and retest same. Resplice I -wire, and test same. Make up and re-land tubing hanger. Drop ball & Rod. Pressure test tubing and IA as per program. Pressure down IA to shear SOV at 2400 PSI. Install BPV. ND BOP stack breaking each flange for set back on skid. Total fluid loss for the da = 85 BBLS. Cum Fluid Loss = 3,848 bbls. 00:00 01:00 1.00 7,338 7,338 COMPZ RPCOM NUND T Continue NU 13 5/8 BOPE. 01:00 06:30 5.50 7,338 7,338 COMPZ RPCOM BOPE T Test BOP's, including choke manifold and valves. test manuals and HCR's, and all floor safety valves. perform Koomey test. Initial 200 PSI gained in 23 Secs, with full 3000 PSI in 1 in 58 secs. 6 nitrogen bottles with avg 2500 PSI. Witness of test waived by AOGCC rep Jeff Jones. 06:30 07:30 1.00 7,338 7,338 COMPZ RPCOM MPSP T Pull Blanking plug and HBPV 07:30 09:00 1.50 7,338 7,338 COMPZ RPCOM OTHR T MU landing joint and RU to Circulate, BOLDS Page 14 of 16 • Time, Lo s Date From To Dur S. De th E. De th Phase Code Subcode T Comment 09:00 16:00 7.00 7,338 7,304 COMPZ RPCOM HOSO T Fill TBG with charge pump, Unland Hanger @ 150k and Pull seals from SBE @ 75 to 85k. Pull hanger to floor -Outer bushing had damage to the O-rings and Metal seal. Test Heat trace -Good, Test I-tec wire above penetrator -failed, Test below penetrator -failed, Check splice - parted, I-tec wire below splice test good - 1,600 psi and 63 degrees. Disconnect heat trace and break out hanger joint, mouse hole hanger jt and change out outer bushing. Install New outer bushing and MU to TBG string. RIH and reconnect Heat Trace -Test Good - 48 gig olms, 76 gig olms, and 52 gig olms. Re-splice -tec wire and test -1,600 psi and 63 de rees. 16:00 16:30 0.50 7,304 7,338 COMPZ RPCOM CIRC T Pump 25 bbls CRW 132 1% by volume CI 9.6 ppg and chase w/ 64 bbls 9.8 brine. 16:30 17:00 0.50 7,338 7,338 COMPZ RPCOM OTHR T Lower TBG and stab seals into SBE, Land han er, RILDS. 17:00 18:00 1.00 7,338 7,338 COMPZ RPCOM THGR T Test Lower TBG hanger void @ 250/5,000 for 10 minutes -Lower seals passed. Test upper TBG hanger void @ 250/5,000 for 10 minutes - U er seals assed. 18:00 23:00 5.00 7,338 7,338 COMPZ WELCTI PRTS P Drop roller stem ball and rod. Steam thaw frozen choke & kill lines. RU to PT TBG @ 3,000 psig for 15 minutes,observed no flow from the IA. Bleed back to 1700 psig and PT IA @ 3,000 psig far 3p minutes. Bleed off IA and TBG to 0 psig. Pressure up on IA and shear SOV @ 4,937' @ 2400 PSI to shear, observing flow in the tubing. Allow preesure to bleed off. Rig down & pull landing joint. Install BPV as per Vetco re . 23:00 23:30 0.50 0 0 COMPZ WELCTI SFTY P Held PJSM with crew. Discuss safety & hazard recognition issues. Discuss procedure to nipple down BOP stack. 23:30 00:00 0.50 0 0 COMPZ WELCTI NUND P Nipple down 13 5/8" BOP stack. Make breaks on all flanges. Prep to mount on skid, greasing all valves and rin rooves. 2/27/2010 Continue ND 13 5/8" BOP stack. Perform megger test. NU Tree & test same. Secure well. Prep rig for move. 00:00 04:00 4.00 0 0 COMPZ WELCTL NUND P Continue nipple down 13 5/8" BOP stack. Make breaks on all flanges. Prep to mount on skid, greasing all valves and rin rooves. 04:00 04:30 0.50 0 0 COMPZ WELCTI NUND P Perform final megger test on I-wire & heat trace as er Centrilift re . Page 15 of 16 f Time Lo s Date From To Dur S.,De th E'. De th Phase Gode Subc~de T Comment ~ 04:30 08:00 3.50 0 0 COMPZ WELCTL NUND P Nipple up tree as per Vetco rep. and '~, PT Void- and Tree @ 250 / 5,000 si . - ood tests. 08:00 08:30 0.50 0 0 COMPZ WELCTL MPSP P Pull test plug 08:30 09:00 0.50 0 0 COMPZ WELCTL SFTY P Held PSM with LRS and rig crew on Freeze protecting well and PT lines rior to um in . 09:00 10:30 1.50 0 0 COMPZ WELCTL CIRC P RU Little Red Services and PT lines @ 2,500 psig. Pump 100 bblS of diesel down IA @ 2 bpm @ 750 psig ICP and FCP @ 1,050 psig. RD LRS 10:30 12:30 2.00 0 0 COMPZ WELCTL OTHR P Tie TBG into IA and allow well to U-tube FP for 2 hrs. Final SIP = 275 psig TBG, 200 psig on IA and 0 psig on OA. 12:30 13:00 0.50 0 0 COMPZ WELCTL MPSP P Lubricate in 4" H-BPV and Secure well. La down Lubricator 13:00 16:30 3.50 0 0 COMPZ MOVE OTHR P Dress Tree and blow down cellar pump lines in Prep for rig move. Back rig off 1 J-158 and remove mats and containment from around cellar. RU super sucker and clean cellar. Hand over well to 1 J Pad operator - Greg Whitehead. Release Nordic Rig 3 @ 16:30 hrs on 2-27-10 Page 16 of 16 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 22, 2009 Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Gas Lift Survey: 1J -158 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rafael Barreto, Halliburton Wireline Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1J -158 Digital Data in LAS format 1 CD Rom 50- 029 23356 -00 N n 2 7 2009 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline Perforating Attn: Rafael Barreto 6900 Arctic Blvd. O()- --6)5-<( V9 of Anchorage, Alaska 99518 Office: 907- 273 -3527 Fax: 907-273-3535 rafael b arreto @hal l iburton. com Date: NOV n 5 71111q Signed: ';!asks fail Gas Cons. Commission Anchloron,s 2~ ~~.~ DATA SUBMITTAL COMPLIANCE REPORT 6/22/2009 Permit to Drill 2070540 Well Name/No. KUPARUK RIV U WSAK 1J-158 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23356-00-00 MD 12268 TVD 3301 Completion Date 6/20/2007 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: GR/RES (data taken from Logs Portion of Master Well Data Maint Well Log information: Log/ Electr Data Digital Dataset Log Log Run Intervai OH / i pe meairrmi rvumoer Name aca~e mea~a no ~cart stop ~n rcecervea comments ED D Asc Directional Survey 0 12268 Open 8/23/2007 Rpt 15507 LIS Verification 3371 12268 Open 10/3/2007 LIS Veri, GR, FET, RPS, I ROP ~ n ED C Lis 15507 I duction/Resistivity 3371 12268 Open 10/3/2007 LIS Veri, GR, FET, RPS, ROP w/graphics og Induction/Resistivity 25 Col 121 12268 Open 5/5/2009 MD ROP, EWR, DGR 7- Jun-2007 og Induction/Resistivity 25 Col 121 3300 Open 5/5/2009 ND EWR, DGR 7-Jun- ~ 2007 ' C 17989 ~ee Notes 0 0 Open 5/5/2009 EWR logs in CGm, EMF and PDS graphics Well CoreslSamples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ~ ~ DATA SUBMITTAL COMPLIANCE REPORT 6/22/2009 Permit to Drill 2070540 Well Name/No. KUPARUK RIV U WSAK 1J-158 Operator CONOCOPHIL~IPS ALASKA INC MD 12268 ND 3301 Completion Date 6/20/2007 Completion Status 1-OIL Current Status 1-OIL ADDITIONAL IPFORMATION ~ Well Cored? Y~I Daily History Received? ~ N Chips Received? ~ Formation Tops ~tN ~~ Analysis Y / N Received? API No. 50-029-23356-00-00 UIC N Comments: Compliance Reviewed By: I~ Date: ~r~'( J b~--~~ • ~ ~ ~ ~I~~~, ~..,~~ ~'~~~1D/~~'~"~'~1I, 'Toa State of Alaska Alaska Oil and Gas Conservation Comnn. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluaxion Logs: 1J-158+L1 l~ay 1, 2009 AK-MW-5034555 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Bryan Burinda, Sperry Drilling, Arctic Blvd., Anchorage, AK 99518 1J-158+L1 2" x 5" MD RESISTNITY & GAMMA RAY Logs: 1 Color Log 50-029-23356-00,60 2" x 5" TVD RESISTNITY & GAMMA RAY Logs: 1 Color Log 50-029-23356-00,60 Digital Log Images 2 CD Rom 50-029-23356-00,60 PLEASE ACKNOWLEDGE RECEIPT BY SIGNII~IG AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF; Sperry Drilling Attn: Bryan Burinda 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-273-3536 F~: 907-273-3535 BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Bryan.Burinda@halliburton.com , , -0~ y ~ ~ ~ q~ - T~~te: " Signed ~\ ~~ ~~`~~~ ~"~ l ~~ ~`~ ~.~~,~-~ ~~ V ; ~~ ,~ ~ ^ t ~ Ct~n ~ . . ocoPhsllips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 November 27, 2008 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: . Q~ ! a~~ ~ ~° ~~ 1 ~ Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. Cement was pumped October 30, 2008 and the corrosion inhibitor/sealant was pumped November 7 and Novemberl7, 2008. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call MJ Loveland or Perry Klein at 907-659-7043, if you have any questions. Sincerely, ~ Perry Klein ConocoPhillips Well Integrity Proj ects Supervisor ~ • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field r,~.s Well fVame PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitod sealant date ft bbls ft a~ 1 F-18A 204-167 15' S" 2.50 44" 10/30/2008 27.2 11/7/2008 1E-16$ 204-200 15" NA 15" NA 3.4 11/7/2008 1 E-17 205-074 13" NA 13" NA 5.53 11 /7/2008 1J-123 207-070 15" NA 15" NA 3.4 11/7/2008 1 J-14 200-200 16" NA 16" NA 1.27 11 /7/2008 1J-152' 206-016 3' NA 3' NA 19.55 11/17/2008 7 J-158 207-054 6' NA 6' NA 27.2 11 R/2008 1 J-162 Z 7-080 15" NA 15" NA 2.55 11 /7/2008 1J-166 205-198 12" NA 12" NA 8.5 11/7/2008 1 J-168 205-060 10" NA 10" NA 3.82 11 /7l2008 1J-170 206-062 8" NA 8" NA 1 11l7/2008 1J-174 207-143 24" NA 24" NA 17 11/7/2008 1J-178 207-121 12" NA 12" NA 5.95 11/7/2008 ~ ~ ~ • • ~OI'14CQ~'11~~I~JS May 24, 2008 Tom Maunder, P.E. Senior Petroleum Engineer State of Alaska, Oil & Gas Conservation Commission 33 W. 7~' Ave. Ste. 100 Anchorage, AK 99501 Robert Buchholz / Robert Christensen Production Engineering Tech. Greater Kuparuk Unit , NSK-69 PO Box 196105 Anchorage, AK 99519-6105 Phone:(907)659-7535 Faac: 659-7314 @~~~.s~IV~,- 'Fa MAY 2 g 20G~~ Alaska Oif c~ Gas Cons. Com ~.u::$~ Anchorage Dear Mr. Maunder, ConocoPhillips Alaska, Inc. has changed the artificial lift method in the West Sak 1J-158 and 1J-158L1 multilateral oil production wells. Enclosed you will find 10-404 Reports of Sundry Well Operation recording the change in artificial lift method to GL (Gas lifted) due to a failed ESP (Electrical Submersible Pump). If you have any questions regarding this matter, please contact myself or Robert Buchholz at 659-7535. Sincerely, ~ Robert D. Christensen Attachments ~cS~- -o~~ ~ , . _~ , , ~ , , ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS t. operations Performed: Abandon ^ Repair Well ~ Plug Pe~forations ~ Stimulate ^ Other Q ESP to G~ ~ ` Alter Casing ^ Pull Tubing ^ Pertorate 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 Numb er: ~j~ ConocoPhillips Alaska, lnC. Development ~' ExAloratory ^ ~ 207-054~/ , ~'f87 3. Address: Strati ra hic g p ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 - 50-029-23356-00 '. 7. KB Elevation (ft): 9. Well Name and Number. RKB 121' ' , 1J-158 • 8. Property Designation: , ~ ~ 10. Field/Pooi(s): ALK 25660`, 25661, 25663 , Kuparuk River Field % WesYSak Oil Pool •- . 11: Present Well Condition Summary: ~ "~ " ~ : ' ; . `Total Depth measured 1°2268' ' ,,. feet - true vertical ~~301' • '+' f~;et . Plugs (measured) , Effective Depth measured ` 12259 feet Junk (measured) true vertical 3300 feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 12T 20" 121' 121' SURFACE 3272' 10-3/4" 3393' 2153' PRODUCTION 7769' 7-5/8" 7890' 3322' D-SANDWINDOW 1' 7-5/8" ' " - 7444' ' 3250` ~~p~~'~C~ ' ` m G 8-SAND SLOTfED LINER 4718 4-1/2 , 12259 3301 . ' . ' ' ' ' ' ' ~AY ~' g z~Q~ Perforation depth: Measured depth: 7895 ; 8954 -8697 -11089 ; 11212 -11626 ; 11841'-12214' true vertical depth: 3323'-3305; 3321'-3320'; 3309'-3289 ; 3293'-3302~ ~iasfca Oil ~, ~as C~ns. Camrtiission ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~6r~cs~~a~a~~ ~~ ~ ~~ ~ Tubing (size, grade, and measured depth} 4-1/2" , L-80, 7231' MD. Packers & SSSV {type & measured depth) D-SAND BAKER PAYZO NE L-1 ECP PKR = 758T no SSSV no SSSV 12. Stimulation or cement squeeze summary: :. Intervals treated (measured) wA Treatment descriptions including volumes used and finalpressure: 13. Representative Daily Average Production or Injection Data Qil-Bbi Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operafion 806 ' 780 29 178 229 Subsequenfito operation 1959 • 501 42 909 245 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: Oil^~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby ceRify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A contact Bob Christensen / Bob Buchholz Printed Name Robert D. Chr stense Titie Production Engineering Technician Signature /~ ~ D'Z Phone: 265-6471 Date r~~ ~~~ ~~ •~ ~~5 ~ ~~ : ` ~ S~• ~ , ~~ ~- ~~~., ,~ti~v ~~ e`~ 2~0~ ~/ Form 10-404 Revised 04/2006 : Submit O:yy~+~~rltY~-'~~?4 ~ ~ ~ 1 J-158 DESCRIPTION OF WORK COMPLETED ~ SUMMARY Date Event Summary -. p5/19/08 WeIF Fteturned to production as a gas lifted oil producer i35/09/08 PULLED 1" SOV @ 2135' RKB. REPLACED WITH 5/16" ORIFICE. PULLED 4.5" SLIP CATCHER @ 2399' WLM. JOB COMPLETE. 05/03/08 PULL ESP PUMP 48" Cc~ 2880' WLM. SET 4 1/2" SLIP STOP C-SUB Ca~ 2308' WLM. JOB IN West Sak 1J-158 (PTD# 207-0~4) Report of Conversion to Gaslift Page 1 of 1 ~ ~ Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, May 06, 2008 1:55 PM To: 'NSK Problem Well Supv'; Regg, James B(DOA) Cc: NSK Well integrity Proj; NSK West Sak Prod Engr; CPF1 DS Lead Techs Subject: RE: West Sak 1 J-158 (PTD# 207-054) and 1 J-158L1 (PTD# 207-055) Report of Conversion to Gaslift Martin, When you send in the 404, be sure to send in on for 1 J-158L1 as well. Tom Maunder, PE AOGCC From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Monday, May 05, 2008 1:35 PM To: Maunder, Thomas E(DOA); Regg, lames B(DOA) Cc: NSK Well Integrity Proj; NSK Problem Well Supv; NSK West Sak Prod Engr; CPFi DS Lead Techs Subject: West Sak 1J-158 (PTD# 207-054) Report of Conversion to Gaslift «1J-158 Wellbore Schematic.pdf» Tom/Jim, West Sak ESP producer (PTD# 207-054) experienced an ESP pump failure on 03/01/08 due to solids production. A second pump was installed on 04/20/08 and even though the motor was operational, the pump system failed to lift fluids to surface. Our immediate plan is to convert the well to gaslift to allow it to clean up and then evaluate the possibility of returning to ESP as a means of artificial lift. This well was permitted with gaslift as a back-up so our intent is to submit a 10-404 after wellwork is complete. Attached is the most recent wellbore schematic. Please contact me at your convenience if you have questions or comments. Martin Martin Walters / Brent Rogers Problem Wells Supervisor ConocoPhillips Alaska Inc. Office 907-659-7224 CeII 907-943-1720 / 1999 Pager 907-659-7000 #909 5/6/2008 ~ LJ ConocaPhil6ps ~ .. ,. - . . We11DOn 500 Commen i~~~rinin I nlnmic _ ~J_tSA d~NONE HANGER,36 CONDUCTOR GAS LIFT. 2,135 suRFncf DlscMrge Sub, 7,095 PACKOFf, 7,112 PUMP, 7.121 XO INTAKE, 7,189 SEAL. 7.1 eo MOTOR. 7.193 ~AUGE.7.227 Central¢er.7.229 HANGER, 7,4a0 D SAND WINDOW D SAND WINDOW ~, PACKER, 7,541 ' NIP, 7.560 .,I HANGER, 7,563 ~, i SBE, 7,573 ` XO Bushirg, 7,593 ~i D SAND HANGAR PRODUCT ION ~: ~ ~ N^ ll „ ~, ,~ ll SHOE. 12.257 I ~ B SANO SLOTTED LINER iD (iJ-158), 12,268 LINER Last WO: h (MCB) Entl Date Annob[bn 112.0 ~%28/2008 Rev Reason: SET ESP, PACKOFF ASSV 1 J-158 _Ilnatlan (') Tobl D~pth (ftl(B) .77 12,268.0 I (R) Rig ReNSw Dab 43.01 6/2 i /2007 End Dab 3/29/2008 ~ 7,095.0 Discharge Sub ~UNIQUE DISCHARGE SUB - 6/19/2007 ~ ~ 7.112.0 PACKOFF i.610 SET PACKOFf ASSV WITH KOBE K.O. AND CHECK(OAL=100' K.O. 36" 4I20/2008 FROM F.N CHECK 84' FROM F.N.~TESTED GOOD.SET TBG STOP set 6/19/2007 7 121.0 PUMP - -. ~4 1/2' ESP PUMP OAL= 47' 8' GOOD TEST. NO SLIP STOP REQUIRED FOR ~4/20I2008 THIS PUMP ~ 7 169.0 XO IN7AKE PERFORATED CROSSOVER INTAKE SCREEN TTC ESPCP 6119I2007 7 180.0 SEAL -UPPERILOWER TANOEM SEAL BSB3DB FER HL H6 SSSCV SBISB PFSA 6119/2007 ~ 7,193.0 MOTOR MOTOR 418 HP KMH 2610 v/ 98 AMP 6/19/2007 7,227.0 GRUGE A-WELL 1-PUMP SENSOR 6/19/2007 7,229.0 Cenhalizer MOTOR CENTRAUZER 6/19(2007 7,440.0 HANGER D-SAND BAKER MODEL HOOK HANGER (INSIDE CSG) - 6/17f2007 5.600 __ 7,541.0 PACKFR B-SAND HRD ZXP LINER PACKER 6/9/2007 SS00 7,560.0 NIP B-SAND RS PACKOFP SEAL NIPPLE 61912007 4.880 7,563.0 HANGER ~B-SAND FLEXLOCK UNER 619I2007 4.060 7,573.0 SBE 8-SAND 190-47 CASING SEAL BORE EXTENSION 6l9I2007 4750 ~,593.0 XO Bushing ~8-SAND CROSSQVER BUSHING ~ 619/2007 3.920 12,257A SHOE B-SAND BTC SIWER BULLET FLOAT SHOE 619/2007 3.958 s.. Shot Gku.. Top (7VD) Btm (ND) D~ns Shot ToD (ftK8) Bbn (11KB) 7.895.0~ 8,697.0~ (MKB) (~B) Typ~ Zorre (sho[... Total D~b 3,323.1 ~ 3.305.3~SLOTS WS B. 32.0 25,664~6/9l2007 Comm~nt Altema6ng slotted%solid pipe,2.5" ~ 1J-158 long z 125' @ 4 circumferential rows, staggered 18 deg. _- _ 8.954.0 71,089.0 __ _ . _ '_ __. _ _ . - ___- - _ 3,920.7 3,3197 SLOTS ~WS A4, 32D ~ 6/9I2007 _. ._ _ AltamaGng slottedlsolid qpa,2.9' iJ-158 long x 125' @ 4 circumferential rows, staggared 18 deg - 11,212.0 17,826.0 3,3092 3.288.5~§LOTS WS B, 32.0 13,248 Bl9/2007 ~Altemating slottad/solid pipe2.5" 1J-15B long x.125" (a~ 4 circumferential rows, staggered 18 deg. 71.841.0 12,214.0~ 3,292.5~ 3,302.O~SLOTS ~WSB. 32.011.9366/9/2007 Altematingslottad/solidpipe,2.5' 1J-158 long x.125" ~ 4 circumferential , roWS, Staggefed 18 deg. End Dab Annobtbn 6/21/2007 NOTE: MULTI-LATERAL WELI - iJ-158 (8-SAND), 1J-i58L1 (D-SAND) ~ To: State of Alaska • i WELL LOG TRANSMITTAL Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~` Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs 1J-158 September 7, 2007 AK-MW-503455~ 1 LDWG formatted CD Rom with verification listing. API#: 50-029-233 56-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 ~~ r~ _._ ..._ ~ ,_::., _- , ~~ ~ __ ` _ Date: - -•'~- ~ . ~ . _. ,._ .,_ i ~ Signed: ~C~~ -~`J y ~ ~ 5 S ~ ~- • • 31-J u I-07 AOGCC Librarian 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-158 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 40.55' MD Window / Kickoff Survey 0.00' MD (if applicable) Projected Survey: 12,268.00' 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 °1~ ~~ Si ned ~ ~ Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ao~- osY \J '" r +- Cont~COPh ~ I I ~ p5 August 1, 2007 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7'" Avenue Suite 100 Anchorage, Alaska 99501 • Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 ~ g ~e ~,~;.w~'" ~~ ~ Ct'~ G ~ ~ ~~i~`a ~ ~~ 2~U~ t~,~~Yt'tiL1 ~ ~ €~~ s.~a . :;~~~.e ?J°~t~~'s~' ,~C°~'i ~~" .~E.~. ~ +°, Subject: Well Completion Reports for 1 J-158 and 1 J-158L1 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations of the Kuparuk West Sak wells 1J-158 and 1J-158L1. If you have any questions regarding this matter, please contact me at 265-6830 or Dennis Hartwig at 265-6862. Sincerely, ~ ~~ ~~ ~ R. Thomas Kuparuk Drilling Team Leader CPAI Drilling CJJ/~ G'~- ~ RT/skad . ~~' ~" a~ • STATE OF ALASKA ~ ~ `~ ~ 2d~~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT afil~ L`0~~~~; ~~m`~fa~'~~ 1a. Well Status: Oil O~ Gas Plugged ~ Abandoned Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Comptetions: 1b. Well Class: Development Q/ - Exploratory ^ Service ^ Stratigraphic Test^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., or Aband.: June 20, 2007 r 12. Permit to Drill Number: 207-054 /~ 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: May 24, 2007 ~ 13. API Number: 50-029-23356-00 ~ 4a. Loca6on of Well (Governmental Section): Surface: 2055' FSL, 2550' FEL, Sec. 35, T11N, R10E, UM ' 7. Date TD Reached: June 7, 2007 f 14. Well Name and Number: 1J-158 - Top of Productive Horizon: 597' FSL, 2249' FEL, Sec. 34, T11 N, R10E, UM 8. KB (ft above MSL): Ground (ft MSL): 121' MSL ~ 15. Field/Pool(s): Kuparuk River Field Total Depth: 1533' FSL, 1852' FEL, Sec. 3, T10N, R10E, UM 9. Plug Back Depth (MD + ND): 12259' MD / 3300' TVD West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): SurFace: x- 558659 ' y- 5945867 ~ Zone- 4 10. Total Depth (MD + ND): r 12268' MD ! 3301' TVD ' 16. Property Designation: ALK 25660, 25661, 25663 TPI: x- 553693 y- 5944371 Zone- 4 Total Depth: x- 554129 - - 5940031 i Zone- 4 11. SSSV Depth (MD + ND): none 17. Land Use Permit: 470, 471, 472 18. Directional Survey: Yes Q No~ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (ND): 2127' ND 21, Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): GR/RES 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING SIZE Wf. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD pULLED 20" x 34" 78.6# H-40 41' 121' 41' 121' 42" 25o sx AS 1 10.75" 45.5# L-80 41' 3393' 41' 2153' 13.5" 569 sx Class G, 18o sx Class G 7.625" 29.7# L-80 41' 7890' 41' 3323' 9.875" 35o sx Class G 4.5" 11.6# L-80 7541' 12259' 3266' 3300' 6.75" slotted liner 23. Open to production or injection? Yes / No If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Pertoration Size and Number): SIZE DEPTH SET (MD) PACKER SET 4.5" 7231' 7541' slotted liner from 7598'-7895', 8696'-8953', 11211'-11626', 11840' - 12214' MD 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED n/a 26. PRODUCTION TEST Date First Production July 23, 2007 ' Method of Operation (Flowing, gas lift, etc.) ESP oil - shares production with 1J-158L1 Date of Test 7/24/2007 Hours Tested 14 hours Production for Test Period --> OIL-BBL 1218 ' GAS-MCF 142 WATER-BBL 46 CHOKE SIZE 19% GAS-OIL RA7lo 148 Flow Tubing press. 263 psi Casing Pressure not available Calculated 24-Hour Rate -> OIL-BBL 1986 ' GAS-MCF 294 WATER-BBL 79 OIL GRAVITY - API (corr) not available 27. CORE DATA Conventional Core(s) Acquired? Yes No / Sidewall Cores Acquired? Yes ~ No / If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. ~,.<.. "YG~~. ~.~~$~ ,, i ~~~ NONE ~ ~ ~ `;:~~,. Form 10-407 Revised Z/2007 ~RIC~~~~~ CONTINUED ON REVERSE SIDE ~~MS ~L au~ ~ ~ zoo7 ,/~ S ~f' °~ ~ ~`~~ ~~ ~~7 G ~ ~ 28. GEOLOGIC MARKERS (List all formations and markers encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ~ Yes ~ No If yes, list intervals and formations tested, Pe~maf~ost - Top SurfaCe surfaCe briefly summarizing test results. Attach separate sheets to this form, if Pefmafrost - BottOm 1655' 1507' (est.) needed, and submit detailed test information per 20 AAC 25.071. T-3 3300' 2127' K-15 3300' 2127' Ugnu C 5690' 2809' Ugnu B 6120' 2931' Ugnu A 6280' 2977' K-13 6645' 3075' West Sak D 7440' 3249' West Sak C 7708' 3294' West Sak B 7845' 3316' N/A Formation at total depth: West Sak B 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, slotted liner detail sheet 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. ContaCt: Derlnis Hartwig @ 265-6862 Printed Name Ran Thomas Ttle: Drillinq Team Leader ~ / +-, / a Signature hone ~~p'~ / Date l ~ o ,ro INSTRUCTIONS 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 7a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 ~ ~ Halliburton Company Survey Report i ~ Halliburton Company Survey Report Cumpany: GotlacoF?hillipSAl~sk~.[iiG I~a~_ :- ~f~C2QCl7 Time: €i9.~C F4 .` ' Page: °-~ ~~Ia: Kupar€~k Riuer Urtit ;. C~rdinate~lE)Rrefcr~~ce , Weth, i,1-1 58, Tr~e Narth ? > '' !S~t~ : '~ KUpar~k'~~) P~d ', ~ . ' -~: : ~ '~e~et~cal (1'YA~'RefereneE ;, '4J-15$:=1 21.~ ' ~' i'~ SW~1~: ~ ~- 9J-"~5~ ; . . ~ ' _ :5ec#an~VS}~tei"eren~ V4~t~tl (p,QQ N,(I.Ob~ ~8Q-flt~}~zi~ ~ ~ ~~~ ~ ;'Wellp~th'; '1J-'-~8 :; : : ; ;. Survey Ca~~lation Me4hod::. ' Minimur~l Curwa[uie :.', I')bz Q 1acEe . ; Survey 14ID; I~scl ~in %' „TVD Sys Ti~D N/S ' ~4'' ' 1l~apN Mxp~ ' Todwl ~ ~ = ~ E. fk ,: ~ . deg ~ieg ft ?,. _ . _ .~ ft ' ' ft ft ' iE ~ y~ _ ft= . ... ~; ~ ' ~ ..~~,: ,'~ ~~,. _ I 2590.76 71.82 281.82 1919.69 1798.14 231.98 -1277.93 5946088J1 557379.32 MWD+IFR-AK-CAZ-SC 2686.55 70.94 282.83 1950.27 1828.72 251.35 -1366.61 5946107.39 557290.50 MWD+IFR-AK-CAZ-SC 2782.07 72.57 282.24 1980.18 1858.63 271.04 -1455.16 5946126.38 557201.80 MWD+IFR-AK-CAZ-SC 2877.07 73.81 279.86 2007.65 1886.10 288.46 -1544.41 5946143.11 557112.43 i MWD+IFR-AK-CAZ-SC 2972.68 73.64 279.45 2034.45 1912.90 303.85 -1634.89 5946157.79 557021.84 MWD+IFR-AK-CAZ-SC 3067.67 73.89 280.82 2061.01 1939.46 319.90 -1724.66 5946173.14 556931.95 MWD+IFR-AK-CAZ-SC 3162.70 74.27 283.40 2087.08 1965.53 339.08 -1814.00 5946191.61 556842.47 MWD+IFR-AK-CAZ-SC 3257.92 72.08 283.73 2114.64 1993.09 360.45 -1902.60 5946212.29 556753.72 MWD+IFR-AK-CAZ-SC 3351.70 74.15 283.93 2141.87 2020.32 381.90 -1959.73 5946233.06 556666.44 MWD+IFR-AK-CAZ-SC 3405.17 73.81 283.03 2156.63 2035.08 393.88 -2039.71 5946244.65 556616.37 MWD+IFR-AK-CAZ-SC 3468.81 73.46 281.99 2174.56 2053.01 407.11 -2099.32 5946257.41 556556.67 MWD+IFR-AK-CAZ-SC , 3564.25 73.70 280.55 2201.54 2079.99 425.00 -2189.10 5946274.60 556466.76 MWD+IFR-AK-CAZ-SC I ; 3659.14 73.18 280.10 2228.59 2107.04 441.30 -2278.58 5946290.21 556377.16 MWD+IFR-AK-CAZ-SC i 3753.81 72.91 279.58 2256.20 2134.65 456.78 -2367.80 5946304.98 556287.83 MWD+IFR-AK-CAZ-SC i 3847.72 72.86 280.25 2283.83 2162.28 472.23 -2456.21 5946319.75 556199.31 MWD+IFR-AK-CAZ-SC 3944.00 73.09 280.55 2312.02 2190.47 488.85 -2546.76 5946335.66 556108.64 MWD+IFR-AK-CAZ-SC ~ 4037.89 73.23 280J2 2339.22 2217.67 505.43 -2635.08 5946351.55 556020.21 MWD+iFR-AK-CAZ-SC ; 4133.01 73.04 281.55 2366.82 2245.27 523.01 -2724.39 5946368.43 555930.77 MWD+IFR-AK-CAZ-SC 4227.91 73.43 282.00 2394.19 2272.64 541.56 -2813.35 5946386.28 555841.68 MWD+IFR-AK-CAZ-SC 4322.58 73.30 282.19 2421.29 2299.74 560.56 -2902.04 5946404.60 555752.85 MWD+IFR-AK-CAZ-SC ' 4415.25 73.36 280.99 2447.88 2326.33 578.40 -2989.01 5946421.75 555665.76 MWD+IFR-AK-CAZ-SC 4510.57 73.80 278.55 2474.83 2353.28 593.91 -3079.10 5946436.56 555575.55 MWD+IFR-AK-CAZ-SC j 4606.55 73.63 274.02 2501.75 2380.20 603.99 -3170.65 5946445.93 555483.93 MWD+IFR-AK-CAZ-SC ; 4702.16 73.11 271.03 2529.12 2407.57 608.03 -3262.16 5946449.25 555392.40 MWD+IFR-AK-CAZ-SC 4797.79 73.42 268.95 2556.66 2435.11 608.01 -3353.74 5946448.52 555300.84 MWD+IFR-AK-CAZ-SC 4892.90 73.37 265.36 2583.85 2462.30 603.49 -3444.75 5946443.29 555209.88 MWD+IFR-AK-CAZ-SC 4988.37 73.50 262.95 2611.07 2489.52 594.17 -3535.77 5946433.27 555118.94 MWD+IFR-AK-CAZ-SC 5083.68 73.42 258.91 2638.21 2516.66 579.77 -3625.98 5946418.17 555028.86 MWD+IFR-AK-CAZ-SC ; 5178.68 73.76 257.31 2665.05 2543.50 561.00 -3715.15 5946398J0 554939.84 MWD+IFR-AK-CAZ-SC ~ 5273.36 73.24 255.35 2691.95 2570.40 539.55 -3803.35 5946376.56 554851.82 MWD+IFR-AK-CAZ-SC i 5368.57 73.85 252.57 2718.92 2597.37 514.32 -3891.10 5946350.65 554764.28 MWD+IFR-AK-CAZ-SC 5463.49 73.74 248.68 2745.42 2623.87 484.09 -3977.06 5946319.75 554678.56 MWD+IFR-AK-CAZ-SC I 5557.90 73.42 244.77 2772.12 2650.57 448.31 -4060.24 5946283.34 554595.68 MWD+IFR-AK-CAZ-SC ~ 5654.15 73.82 241.51 2799.27 2677.72 406.59 -4142.60 5946240.98 554513.64 MWD+IFR-AK-CAZ-SC i 5749,16 73.55 239.50 2825.96 2704.41 361.70 -4221.96 5946195.48 554434.64 MWD+IFR-AK-CAZ-SC ' 5844.60 73.29 235.52 2853.20 2731.65 312.58 -4299.10 5946145J6 554357.90 MWD+IFR-AK-CAZ-SC ~ i 5939.81 73.63 232.32 2880.32 2758.77 258.84 -4372.85 5946091.45 554284.57 ~ MWD+IFR-AK-CAZ-SC 6034.10 73.36 229.38 2907.11 2785.56 201.77 -4442.95 5946033.85 554214.93 MWD+IFR-AK-CAZ-SC 6129.69 73.69 226.49 2934.22 2812.67 140.36 -4511.00 5945971.92 554147.37 MWD+IFR-AK-CAZ-SC 6224.52 73.23 222.91 2961.23 2839.68 75.76 -4574.93 5945906.82 554083.95 MWD+IFR-AK-CAZ-SC i, I 6319.01 73.42 218.91 2988.35 2866.80 7.37 -4634.19 5945837.98 554025.23 MWD+IFR-AK-GAZ-SC ~ 6413.76 73.39 214.12 3015.43 2893.88 -65.58 -4688.20 5945764.61 553971.79 MWD+IFR-AK-CAZ-SC ; ; 6509.66 75.19 210.04 3041.40 2919.85 -14379 -4737.21 5945686.04 553923.40 MWD+IFR-AK-CAZ-SC 6604.80 75.75 206.01 3065.28 2943.73 -225.07 -4780.47 5945604.43 553880.78 MWD+IFR-AK-CAZ-SC 6699.18 74.82 202.34 3089.26 2967.71 -308.33 -4817.85 5945520.89 553844.05 MWD+IFR-AK-CAZ-SC 6794.20 75.66 198.65 3113.48 2991.93 -394.38 -4850.01 5945434.60 553812.57 MWD+IFR-AK-CAZ-SC 6890.73 77.51 193.66 3135.89 3014.34 -484.54 -4876.11 5945344.25 553787.17 MWD+IFR-AK-CAZ-SC 6985.94 77.17 191.20 3156.75 3035.20 -575.25 -4896.10 5945253.39 553767.89 MWD+IFR-AK-CAZ-SC I 7080.84 77.63 190.05 3177.46 3055.91 -666.28 -4913.18 5945162.25 553751.52 MWD+IFR-AK-CAZ-SC I ; 7174.92 77.69 190.10 3197.56 3076.OT -756J6 -4929.25 594507L64 553736.15 MWD+IFR-AK-CAZ-SC i i 7271.33 77.64 189.81 3218.16 3096.61 -849.53 -4945.54 5944978.76 553720.60 MWD+IFR-AK-CAZ-SC ~ ~ 7367.36 80.06 189.38 3236.73 3115.18 -942_42 -4961.24 5944885.76 553705.62 MWD+IFR-AK-CAZ-SC ~ ~ ~ Halliburton Company Survey Report Company: CnnacoPhtl~€ps~}kiasl€~ h~ . I)at~ 7/3t2t?t17 ~~, Time f}9f36:t}+t ; = Pag~: 3 :: ~ _ 'FS~d: ' Kuparuk k2iver~lnii ` -, ' _ . - ", " ~~ " Ca=~rihuat~IE}Reiere~e~ ' Wetl: ~,~-1a8, True htorth ' -;:- f .,~ ~ E ~ Sate:. . ' KuparUk i.k.P~d , , Vcrti+eat {~'U) R~~erenee, . ; ' '[J-? 58:' i 21.a - ' Well. ' ~,t~'~ ~ ,f :.~ . , :,: ', c 'S} Refere~ ?_ . e~e€iun c ~ t~ .._ W } ,0.4~d~,184.CiQAz i N eI1(U.UU ;iFµ~Q ~ :T1g.~~AVQ:. ~~~~~! _ , .. , M .T. 1~ ~n ~ A' " '.. f3~~~~ Sw'a~~'a~~ tiS~l~~~i ''.~ y ~ ~q^ ~ ( ~ /~~ IYi~~~~u~ ll~~~~~ ; _ L))i ~~~Fi Survey ~~. hID- ~~ ~ iucl ~_ A~im ~~ T~?U ~~ ~ys1'VD ` 1~TIS ~ ~E1~4' 1~3aprN . ~ M~~ T~1 E;~ ~ ~ '~~~deg '~~~ ~ft ' ft _ _ ~ ~~ ft ft ~~ _ :ft ft ~~~,. , . ~ ~... ~ 7462.53 80.33 185.38 3252.94 3131.39 -1035.41 -4973.28 5944792.69 553694.30 MWD+IFR-AK-CAZ-SC i 7556.51 80.72 182.44 3268.42 3146.87 -1127.88 -4979.60 5944700.99 553688.71 MWD+IFR-AK-CAZ-SC ', 7652.68 80.03 180.18 3284.50 3162.95 -1222.66 -4981.77 5944605.40 553687.28 MWD+IFR-AK-CAZ-SC i 7747.48 79.99 177.91 3300.94 3179.39 -1316.01 -4980.21 5944512.08 553689.56 MWD+IFR-AK-CAZ-SC 7842.41 81.78 178.80 3315.98 3194.43 -1409.69 -4977.52 5944418.42 553692.98 MWD+IFR-AK-CAZ-SC 7899.12 82.64 179.39 3323.67 3202.12 -1465.87 -4976.64 5944362.26 553694.30 MWD+IFR-AK-CAZ-SC 7991.83 88.96 180.64 3330.46 32Q8.91 -1558.28 -4976.67 5944269.86 553694.99 MWD+IFR-AK-CAZ-SC I 8085.54 94.77 180.15 3327.41 3205.86 -1651.90 -4977.31 5944176.25 553695.08 MWD+IFR-AK-CAZ-SC i 8179.00 93.04 177.35 3321.04 3199.49 -1745.11 -4975.28 5944083.06 553697.84 MWD+IFR-AK-CAZ-SC j I i 8274.06 91.80 170.47 3317.02 3195.47 -1839.49 -4965.20 5943988J8 553708.64 MWD+IFR-AK-CAZ-SC 8367.28 92.73 167.98 3313.34 3191.79 -1930.99 -4947.79 5943897.43 553726.77 MWD+IFR-AK-CAZ-SC 8461.20 93.22 168.81 3308.46 3186.91 -2022.86 -4928.92 5943805.71 553746.35 MWD+IFR-AK-CAZ-SC ~ I 8556.35 90.88 167.66 3305.06 3183.51 -2115.95 -4909.54 5943712.79 553766.46 MWD+IFR-AK-CAZ-SC ~ I 8649.87 89.58 168.74 3304.68 3183.13 -2207.48 -4890.41 5943621.41 553786.29 MWD+IFR-AK-CAZ-SC 8742.67 88.84 168.88 3305.96 3184.41 -2298.51 -4872.40 5943530.53 553805.01 MWD+fFR-AK-CAZ-SC 8835.57 82.96 170.64 3312.60 3191.05 -2389.65 -4855.93 5943439.53 553822.18 MWD+IFR-AK-CAZ-SC 8929.94 84.95 172.72 3322.54 3200.99 -2482.50 -4842.36 5943346.80 553836.48 MWD+IFR-AK-CAZ-SC 9023.50 87.92 175.41 3328.36 3206.81 -2575.36 -4832.71 5943254.03 553846.85 MWD+IFR-AK-CAZ-SC ~ 9117.52 93.66 173.38 3327.06 3205.51 -2668.88 -4823.53 5943160.60 553856.76 MWD+IFR-AK-CAZ-SC ~ 9211.52 91.80 170.37 3322.59 3201.04 -2761.81 -4810.26 5943067.77 553870.75 MWD+IFR-AK-CAZ-SC ! 9301.25 88.90 165.36 3322.04 3200.49 -2849.50 -4791.41 5942980.25 553890.28 MWD+IFR-AK-CAZ-SC 9393.25 92.36 165.44 3321.03 3199.48 -2938.51 -4768.22 5942891.43 553914.16 MWD+IFR-AK-CAZ-SC i 9491.73 91.80 167.36 3317.45 3195.90 -3034.16 -4745.08 5942795.97 553938.04 MWD+IFR-AK-CAZ-SC ; 9586.73 89.95 170.25 3316.00 3194.45 -3127.33 -4726.64 5942702.96 553957.20 MWD+IFR-AK-CAZ-SC 9679.74 90.63 174.70 3315.53 3193.98 -3219.51 -4714.47 5942610.88 553970.10 MWD+IFR-AK-CAZ-SC 9774.09 89.83 177.97 3315.15 3193.60 -3313.66 -4708.44 5942516.80 553976.86 MWD+IFR-AK-CAZ-SC ~ 9867.88 90.01 178.32 3315.28 3193.73 -3407.40 -4705.40 5942423.09 553980.63 MWD+IFR-AK-CAZ-SC 9961.49 90.82 179.38 3314.60 3193.05 -3500.98 -4703.52 5942329.53 553983.23 MWD+IFR-AK-CAZ-SC ' 10054.96 92.61 179.30 3311.81 3190.26 -3594.40 -4702.45 5942236.13 553985.04 MWD+IFR-AK-CAZ-SC 10147.98 91.00 178.47 3308.88 3187.33 -3687.35 -4700.64 5942143.21 553987.57 MWD+IFR-AK-CAZ-SC 10241.31 88.04 175.33 3309.66 3188.11 -3780.52 -4695.59 5942050.09 553993.34 MWD+IFR-AK-CAZ-SC 10336.54 8977 179.22 3311.48 3189.93 -3875.60 -4691.07 5941955.05 553998.61 MWD+IFR-AK-CAZ-SC ~ j 10430.58 90.26 177.92 3311.46 3189.91 -3969.61 -4688.72 5941861.08 554001.68 MWD+IFR-AK-CAZ-SC ~ 10524.17 91.74 173.90 3309.82 3188.27 -4062.93 -4682.05 5941767.82 554009.08 MWD+IFR-AK-CAZ-SC ~ 10617.46 88.29 173.05 3309.80 3188.25 -4155.60 -4671.45 5941675.25 554020.40 MWD+IFR-AK-CAZ-SC ~ 10710.77 90.20 174.91 3311.03 3189.48 -4248.38 -4661.66 5941582.56 554030.91 MWD+IFR-AK-CAZ-SC ~ 10803.76 88.90 176.41 3311.76 3190.21 -4341.09 -4654.63 5941489.91 554038.67 MWD+IFR-AK-CAZ-SC ~ 10899.91 87.36 176.78 3314.89 3193.34 -4437.02 -4648.92 5941394.04 554045.12 MWD+IFR-AK-CAZ-SC ~ 10990.80 87.23 176.72 3319.18 3197.63 -4527.66 -4643.77 5941303.45 554050.97 MWD+IFR-AK-CAZ-SC ~ i 11084.70 91.93 177.18 3319.87 3198.32 -4621.40 -4638.78 5941209.76 554056.70 MWD+IFR-AK-CAZ-SC 11176.19 95.77 180.38 3313.73 3192.18 -4712.64 -4636.83 5941118.55 554059.36 MWD+IFR-AK-CAZ-SC 11271.15 94.40 181.39 3305.31 3183.76 -4807.21 -4638.29 5941023.98 554058.63 MWD+IFR-AK-CAZ-SC 11364.55 95.33 181.87 3297.39 3175.84 -4900.23 -4640.94 5940930.95 554056.71 MWD+IFR-AK-CAZ-SC 11460.04 93.72 177.56 3289.85 3168.30 -4995.40 -4640.46 5940835.80 554057.93 MWD+IFR-AK-CAZ-SC 11552.45 88.78 175.32 3287.84 3166.29 -5087.57 -4634.73 5940743.68 554064.38 MWD+IFR-AK-CAZ-SC i 11646.78 91.12 176.39 3287.92 3166.37 -5181.65 -4627.91 5940649.67 554071.93 MWD+IFR-AK-CAZ-SC i 11741.64 88.60 176.11 3288.15 3166.60 -5276.30 -4621.70 5940555.08 554078.87 MWD+IFR-AK-CAZ-SC ~ 11833.86 86.49 175.57 3292.10 3170.55 -5368.18 -4615.02 5940463.26 554086.27 MWD+IFR-AK-CAZ-SC I ~ 11928.08 87.60 177.27 3296.96 3175.41 -5462.09 -4609.15 5940369.41 554092.87 MWD+IFR-AK-CAZ-SC ~ i ~ 12021.40 87.91 175.88 3300.62 3179.07 -5555.17 -4603.58 5940276.38 554099.17 MWD+IFR-AK-CAZ-SC 12114.59 89.27 172.67 3302.91 3181.36 -5647.85 -4594.28 5940183.78 554109.18 MWD+IFR-AK-CAZ-SC 12203.60 91.50 173.16 3302.31 3180.76 -5736.17 -4583.31 5940095.56 554120.85 MWD+IFR-AK-CAZ-SC / 12268.00 91.50 _ 173.16 3300.63 ~ 3179.08 -5800.09 -4575.64 5940031.71 ~ 554129.01 ~ PROJECTED to TD ~ ~ Ca-~c~coPhillip-s Time Log Summary VrelNlew LYeb RePo~Ym9 ` ~~, r~,`~~ ~ s.: ' ~ a \.:~ ?El'c; " '~ ":!~ „~. ,,,7 ~ .~ ~, a§~,_.. Well Name: 1J-158 Job Type: DRILLING ORIGINAL > ,. , m~ 1.' : ~`~~~~0\~. ` ~~ . . ~~~~~~: .~ ~~ . ~ ~, ; ..~ ~a~~`~:~. F ri~ C'~iri E: `~~.~, ~ Sub',,, ~` , _~~C~s~ `~`~`~ ~~~ °~~~~v.?:;. 05/23/2007 04:00 06:00 2.00 0 0 MIRU MOVE DMOB P Complete cleaning pits. Move rockwasher. Remove cuttings tanks. Prep rig for move. Skid rig floor. Crew Chan e 06:00 12:00 6.00 0 0 MIRU MOVE MOB P Raise stomperjack pads. Move pit system off of matting boards. Move Sub Com lex around corner to 1J-158. 12:00 14:00 2.00 0 0 MIRU MOVE PSIT P Spot Sub complex over well 1J-158. S ot it com lex next to sub. 14:00 18:00 4.00 0 0 MIRU MOVE RURD P Lower Stomperjack pads. Level rig. Skid rig floor into position. Spot & rig up Rockwasher complex & cuttings tanks. Berm sub, pits, and rockwasher complexes. Rig up steam, air, hydraulic and water lines. Pull surface riser ro rig floor. Rig accepted @ 1800 HRS as per rig acceptance checklist. 18:00 00:00 6.00 0 0 MIRU MOVE RURD P Nipple up diverter stack & system. Make up hydraulic lines from Koomey system. Load 300 BBLS of Spud mud into pits. Load pipe shed with 5" drill i e. 05/24/2007 00:00 01:45 1.75 0 0 MIRU MOVE RURD P Install & adjust flowlines. Turn and adjust diverter stack. Install 3" valves on starting head. load another 300 BBLS of Spud mud onto pit system. Continue load 5" DP in i e shed. 01:45 02:15 0.50 0 0 MIRU DRILL OTHR P Perform Diverter function test. Observed Knife valve fully open @ 10 seconds. Witness of test waived by AOGCC re Jeff Jones. 02:15 02:30 0.25 0 0 MIRU DRILL RURD P install mousehole in rotary table. Install bushings. Change out drill pipe elevators. Clean & clear rig floor. Continue load shed with 5" DP. 02:30 02:45 0.25 0 0 MIRU DRILL SFTY P Held PJSM with crew. Discuss safety & hazard recognition issues. Discuss procedure for picking up and racking back 5" drill i e in derrick. 02:45 06:00 3.25 0 0 MIRU DRILL OTHR P Pick up 5" drill pipe from shed. make up full stands and rack back same in derrick. Obtain SLM. Crew Chan e 06:00 09:00 3.00 0 0 MIRU DRILL OTHR P Continue pick up 5" Drill piope from shed and rack back a total of 55 Stands. Obtain SLM. ~ ~ 05/24/2007 09:00 09:15 0.25 0 0 MIRU DRILL OTHR P Pull Mousehole from rotary table & lower landing in cellar around surface riser. 09:15 10:15 1.00 0 0 MIRU DRILL OTHR P RIH with 2 stands of DP to verify bottom @ 114'. Rack back 1 stand. perform diverter funtion test, & Koome draw down test. 10:15 10:45 0.50 0 0 MIRU DRILL OTHR P Remove all DP thread protectors from rig floor. Clean & clear rig floor area. Pull e ui ment to ri floor for BHA #1. 10:45 11:00 0.25 0 0 MIRU RIGMN SFTY P Held PJSM with crew & GBR reps. Discuss safety & hazard recognition issues. Discuss procedure to install StabRite casing handling system in derrick. 11:00 12:00 1.00 0 0 MIRU RIGMN RURD P Install StabRite casing handling s stem in derrick. 12:00 16:15 4.25 0 0 MIRU RIGMN RURD P Continue instali StabRite casing handling system in derrick. Attach all hydraulic lines, and perform function test. Ri down control lines from unit. 16:15 16:45 0.50 0 0 MIRU DRILL RURD P Rig up Sperry Sun Gyro unit & line. Install sheaves. 16:45 17:00 0.25 0 0 MIRU DRILL SFTY P Held PJSM with crew. Discuss safety & hazard recognition issues. Discuss rocedure to make u 13 1/2" BHA #1. 17:00 18:00 1.00 0 0 SURFA DRILL PULD P Make up BHA#1, 13 1/2" Drilfing BHA with 8" SperryLobe Motor assembly. Crew Chan e 18:00 20:00 2.00 0 0 SURFA DRILL PULD P Continue make up BHA#1, 13 1/2" Drilling BHA with 8" SperryLobe Motor assembly as per DD & MWD reps. Total BHA length = 356.31'. Install Corrosion ring in top of first stand of HWDP. 20:00 21:00 1.00 0 114 SURFA DRILL OTHR P Flood conductor & lines with water. Pum throu h BHA to veri no leaks. 21:00 00:00 3.00 121 250 SURFA DRILL DDRL P Spud well @ 2100 HRS. Drill 13 1/2" hole from 121' - 250' MD. TVD = 250'. Gyro as per DD. ADT = 2.84 HRS. Bit = 2.84 HRS 05/25/2007 00:00 06:00 6.00 250 636 SURFA DRILL DDRL P Continue Directional drill 13 1/2" Surface hole from 250' - 636' MD. TVD - 635'. ADT = 3.52 HRS. AST = 2.55 HRS Crew Chan e 06:00 12:00 6.00 636 1,062 SURFA DRILL DDRL P Continue Directional dril! 13 1!2" Surface hole from 636' - 1062' MD. ND - 1047'. ADT = 3.64 HRS. AST = 3.11 HRS 12:00 18:00 6.00 1,062 1,490 SURFA DRILL DDRL P Continue Directional drill 13 1/2" Surface hole from 1062' - 1490' MD. ND - 1414'. ADT = 3.46 HRS. AST = 3.15 fiRS Crew Chan e 18:00 00:00 6.00 1,490 2,061 SURFA DRILL DDRL P Continue Directional drill 13 1/2" Surface hole from 1490' - 2061' MD. ND - 1747'. ADT = 3.15 HRS. AST = 2.48 HRS ~ ~ 05/26/2007 00:00 06:00 6.00 2,061 2,630 SURFA DRILL DDRL P Continue Directional drill 13 1/2" Surface hole from 2061' - 2630' MD. ND - 1931'. ADT = 4.25 HRS. AST = 1.71 HRS. Crew Chan e 06:00 12:00 6.00 2,630 2,978 SURFA DRILL DDRL P Continue Directional drill 13 1/2" Surface hole from 2630' - 2978' MD. ND - 2035'. ADT = 3.21 HRS. AST = 1.51 HRS. 12:00 1730 5.50 2,978 3,405 SURFA DRILL DDRL P Continue Directional drill 13 1/2" Surface hole from 2978' - 3405' MD. TVD - 2156'. ADT = 2.63 HRS. AST = 1.43 HRS. Surface hole TD'd. 1730 18:00 0.50 3,405 3,300 SURFA DRILL CIRC P Lay down single. Reciprocate & rotate drill string while CBU @ 700 GPM's - 1980 PSI. UP WT = 160K, SO WT = 92K, ROT WT = 120K. BROOH 3 stands. Crew Chan e 18:00 21:45 3.75 3,300 2,064 SURFA DRILL CIRC P Continue BROOH at drilling rate from 3300' - 2064' at 750 GPM - 1980 PSI. 70 RPM's with 8K tor ue. 21:45 23:00 1.25 2,064 1,874 SURFA DRILL REAM P Circulate 7 condition hole while pulling slow from 2064' - 1874'. Pumps @ 750 GPM - 1980 PSI. 70 RPM's with 8K tor ue. 23:00 00:00 1.00 1,874 1,400 SURFA DRILL REAM P Attemptto POOH on elevators, observing up to 35K overpult, and swabbing issues. Continue BROOH slow from 1589' - 1400'. Hole cleaning u ood on shakers. 05/27/2007 00:00 00:30 0.50 1,400 1,304 SURFA DRILL REAM P Continue BROOH from 1400' - 1304'. Observed shakers cleaned up good, and ood hole conditions. 00:30 01:30 1.00 1,304 353 SURFA DRILL TRIP P POOH on elevators from 1304' - 353'. Observed proper hole fill and good hole conditions with no swabbin issues. 0130 03:45 2.25 353 0 SURFA DRILL PULD P Breakout & lay down Flex drill collars & jars. Rack back 3 stands of 5" HWDP. Continue breakout & lay down remainin BHA. 03:45 04:15 0.50 0 0 SURFA DRILL OTHR P Clean & clear rig floor area of mud and tools. 04:15 06:00 1.75 0 0 SURFA CASINC RURD P Lay down elevators, bales. Make up Franks Fill up tool. Pick up bales, and rig up all casing running equipment as er GBR re s. Crew Chan e 06:00 06:30 0.50 0 0 SURFA CASIN( RURD P Continue rig up all casing running equipment. Held PJSM with crew & GBR reps. Discuss safety & hazard recognition issues. Discuss procedure to pick up and run 10 3/4" casing as ~ ~ 05/27/2007 06:30 12:00 5.50 0 2,007 SURFA CASINC RNCS P Make up 10 3/4" Shoe joint, FC joints with Bakerloc. Fill pipe & check floats. Floats held. Continue make up & run 10 3/4" casing filling each joint & installing bowspring centralizers as per well plan.. Make up torque = 8200 Ft/Ibs. Obtain T& D parameters as per rig engineer. Observed trouble getting casing string in hole at 1637' continuing to wash each joint down with 40 SPM - 200 PSI to 2007'. 12:00 18:00 6.00 2,007 2,869 SURFA CASIN( RNCS P Continue run 10 3/4" casing from 2007' - 2869', washing down with 60 SPM - 295 PSI. Install turbolizers as per well plan. Obtain T&D parameters as per ri en ineer. Crew Chan e 18:00 19:00 1.00 2,869 3,361 SURFA CASINC RNCS P Continue run 10 3/4" casing from 2869' - 3361', washing down with 60 SPM - 295 PSI. Install turbolizers as per well plan. Obtain T&D parameters as er ri en ineer. 19:00 20:15 1.25 3,361 3,393 SURFA CASIN( RNCS P Make up fluted hanger as per Vetco Gray rep. Install 47' landing joint. RIH land casing hanger in bowl. Rig down Franks Fill up tool. Blow down Top drive & lines. Make up 10 3/4" cement head as per powell rep. UP WT = 220K, SO WT = 128K. 20:15 22:15 2.00 3,393 3,393 SURFA CEME CIRC P Circulate, bringing pump up in stages from 2 BPM - 6 BPM with 270 PSI. Reciprocate casing string in 20 ft strokes. Circulate a totai of 4500 strokes to observe pre cement mud properties of 9.1 PPG, 60 Visc, YP = 15 with Gels @ 2/3. Adding water to returns at 20-40 BBLS / HR. No losses observed while circulating. SIMOPS: Held PJSM with crew, truck drivers and Dowell reps. Designate S ill Cham ion for ~ob. 22:15 00:00 1.75 3,393 3,393 SURFA CEME~ DISP P Turn Rig over to Dowell. Pump 10 BBLS of 8.3 PPG CW100, PerForm pressure test on lines to 3000 PSI. Good test. Continue pump 40 BBLS of 8.3 PPG CW100 @ 5 BPM - 300 PSI. Continue pump 50 BBLS of 10.5 PPG MudPush II @ 5 BPM - 300 PSI. Drop Bottom plug. Start pumping 451 BBLS of 10.7 PPG Lead cement at 22:56 HRS @ 7 BPM - 500 PSI. Observed good reciprocation in casing string with UP WT - 220K, SO WT - 148K. 05/28/2007 00:00 00:15 0.25 3,393 3,393 SURFA CEME~ DISP P Continue with Surface cement job pumping 79 BBLS of 12 PPG Tail Cement @ 6 BPM - 576 PSI. Drop Top plug. Pump 20 BBLS of water to flush lines,. ~ ~ 05/28/2007 00:15 01:30 1.25 3,393 3,393 SURFA CEME~ DISP P With rig pumps, displace cement pumping at 6 BPM - 260 PSI. Observed good reciprocation of casing string until movement indicated setting hanger in bowf 73 BBLS into displacement. Observed returns decrease to 20% from 27%. Monitor shakers for MudPush II indication slowing pumps to 3 BPM - 480 PSI until bumping plug with 297 BBLS pumped, Bump plug @ 2950 strokes as calculated. No MudPush II or cement returns observed at surface. Pressure to 950 PSI, hold 5 minutes. Bleed pressure and check floats. Floats held. 01:30 02:45 1.25 0 0 SURFA CEME~ RURD P Held PJSM with crew. Discuss nipple down procedures. Blow down all lines. Rig down cement head & lines. Back out & lay down landing joint & crossover. Rig down casing running equipment. Notify AOGCC & rig en ineer of cement'ob erformance. 02:45 03:15 0.50 0 0 SURFA WELCT OTHR P Clean & clear rig floor area. Send tools out. 03:15 06:00 2.75 0 0 SURFA WELCT NUND P Nipple down Diverter system. Breakout diverter line. Lay down Riser. Load pipe shed with 27 joints of 1" Hydril pipe for performing cement top 'ob. Stra i e. Crew Chan e 06:00 12:00 6.00 0 0 SURFA CEMEt~ F2URD T Continue nipple down diverter system and starting head. Attempt to RIH with 1" hydril pipe through the fluted hanger, observing not successful. With rig welder, cut a slot in the conductor for side entry. Make up and RIH with 1" Hydril working down 17 joints to a depth of 510'. Pipe would go an further. 12:00 12:30 0.50 0 0 SURFA CEME~ SFTY T Held PJSM with crew, Dowell cementers, Co. Rep, and TP. Disuss safety & hazard recognition issues. Discuss procedure for pumping top ~ob. 12:30 14:15 1.75 0 0 SURFA CEME~ DISP T Rig up Dowell. Pressure test lines to 1000 PSl. Establish circulation rate with water @ 1 BPM - 300 PSI. Pump 35 BBLS - 350 PSI, and FCP with 53 BBLS um ed = 350 PSI. 14:15 15:30 1.25 0 0 SURFA CEME~ DISP T Mix & pump 79 BBLS of 10.7 PPG ArticSet lite III cement. Pump @ 1 BPM fro a FCP of of 450 PSI & full cement returns. Cement job witnessed b AOGCC re Bob Noble. 1530 18:00 2.50 0 0 SURFA CEME~ RURD T Clear & flush all lines. RD Dowell. Pull & lay down 1" Hydril pipe. Crew Chanpe. ~ 05/28/2007 18:00 18:30 0.50 0 0 SURFA CEME~ RURD T Continue pull & lay down 1" hydril i e. 1830 19:30 1.00 0 0 SURFA RPCOh NUND P Held PJSM. Discuss Nipple up of well head. Nipple up wellhead & test Grayloc seal ring to 5000 PSI as per Vetco Gray rep. Test witnessed by Driller. 19:30 00:00 4.50 0 0 SURFA WELCT NUND P Nipple up BOP stack & lines. SIMOPS: Clean mud pits for taking on mud for Intermediate hole section as per MI rep. Load test joints in shed, clean & clear floor area. 05/29/2007 00:00 01:30 1.50 0 0 SURFA WELC NUND P Continue nipple up BOP's. Change out saver sub on To Drive. 01:30 02:30 1.00 0 0 SURFA WELC NUND P Remove 9 5/8" rams & install 7 5/8" rams in BOP stack. 02:30 03:45 1.25 0 0 SURFA WELCT BOPE P Rig up testjoint & plug. Fill stack & lines with test water. RU test chart recorder. 03:45 06:00 2.25 0 0 SURFA WELC7 BOPE P Test BOP"s with 7 5/8", 5", and 4" test joints. Test to 250 / 3000 PSI. Crew Chan e 06:00 10:45 4.75 0 0 SURFA WELCT BOPE P Continue test BOP stack, choke manifold. Test All floor valves, and dart valve. perfom Koomey test with 200 PSI increase in 36 secs, and a fult charge in 3 minutes, 36 seconds. Avg bottle prssure on 5 Nitrogen bottles = 2300 PSI. Witness of test waived by AOGCC Lou Grimaldi. 10:45 12:00 1.25 0 0 SURFA WELCT BOPE P Rig down all testing equipment & lines. Blow down lines and choke manifo-d. Clean & clear ri floor. 12:00 13:00 1.00 0 0 SURFA WELC BOPE P Install wear bushing & record ID of 12 1 /4". 13:00 17:30 4.50 0 0 SURFA CASINC RURD NP Held PJSM with rig crew, CPAI safety rep, TP, CO man, Franks rep & GBR reps. Discuss saftey 7 hazard recognition issues and procedures to function test Stab Rite equipment. Pull tool sto rig floor. Install flush mounted slips, and control units. Trouble shoot elevator sensor issues. 17:30 18:00 0.50 0 0 SURFA CASIN RURD NP Remove inserts and guides. Rig down elevators. Crew Chan e 18:00 20:30 2.50 0 0 SURFA CASINC RURD NP Continue with Stab Rite function operation. Install new set of elevators. Pick up a joint of 10 3/4" casing, and set into flush mounted slips. pick up another joint, and simulate make up usin stab rite e ui ment. 20:30 22:30 2.00 0 0 SURFA CASINC RURD NP Rig down all Stabrite equipment, sending out control units. Place Flushmounted slips on rig floor for future casing run. Install rotary tabie bushinqs. ~ ~ 05/29/2007 22:30 23:30 1.00 0 0 INTRM1 DRILL PULD P Pull tools to rig floor for BHA. make up elevators & link tilt assembly on top drive. 23:30 00:00 0.50 0 0 INTRM1 RIGMN' SVRG P Service Top drive & drawworks. 05/30/2007 00:00 00:15 025 0 0 INTRM1 DRILL SFTY P Held PJSM with crew & Sperry Sun reps. Discuss safety & hazard recognition issues. Discuss procedure for makin u 9 7/8" BHA. 00:15 03:15 3.00 0 358 INTRM1 DRILL PULD P Make up 8HA #2. 9 7/8" Bit & Geo-pilot assembly. Plug in and upload MWD assembly . Continue MU flex DC's and jars. Total BHA length = 357.82' 03:15 06:00 2.75 358 1,881 INTRM1 DRILL TRIP P Trip in hole with BHA #2, picking up 5" DP from shed to 1881' MD. Crew Chan e 06:00 08:00 2.00 1,881 3,213 INTRM1 DRILL TRIP P Continue trip in hole picking up 5" DP from 1881' - 3213' MD. Fill drill string eve 25 stands. 08:00 09:15 1.25 3,213 3,305 INTRM1 DRILL CIRC P Break Circulation, trip in and wash down to 3305' tagging float equipment. UP WT = 145K, SO WT = 110K, ROT WT = 120K. Continue CBU conditionin mud for casin test. 09:15 10:30 1.25 3,305 3,305 INTRM1 DRILL DHEQ P POOH to 3274', laying down a single of DP. Blow down Top Drive. held PJSM on performing casing test. Rig up test lines, circulate through, and close pipe rams. Perform casing test to 3000 PS! for 30 minutes, record on chart. Blow down and rig down test lines. 10:30 12:00 1.50 3,305 3,350 INTRM1 CEME~ COCF P Make up single trip in and drill float equipment & shoe track. Pumps @ 650 GPM's - 2050 PSI, 60 RPM's with 8K ft/Ibs of tor ue. 12:00 14:00 2.00 3,350 3,405 INTRM1 CEMEI~ COCF P Continue drill float equipment & shoe track. Drill 20' of new hole from 3405' - 3425' MD. 14:00 14:15 0.25 3,405 3,425 INTRM1 DRILL DDRL P Drill 20' of new hole from 3405' - 3425' MD 14:15 14:45 0.50 3,425 3,425 INTRM1 DRILL CIRC P Displace well with new LSND mud at 550 GPM's - 1220 PSI with 90 RPM's. 14:45 16:15 1.50 3,425 3,425 INTRMI DRILL LOT P Held PJSM with crew & Co. REP. Discuss safety & hazard recognition issues, and procedure for performimg LOT. Rig up lines with chart recorder. Perform LOT to 16.2 PPG EMW with 8.9 PPG mud in hole. 10 minute bleed pressure from 820 PSI to 220 PSI. Bleed all pressure, blow down & rig down lines. Establish circulation & obtain baseline ECD = 9.36 PPG. 16:15 18:00 1.75 3,425 3,686 INTRM1 DRILL DDRL P Directional drill 9 7/8" hole from 3425' - 3686' MD. ND = 2235'. ADT = 1.26 HRS. ECD = 9.9 PPG. Crew Chanqe ~ ~ 05/30/2007 18:00 00:00 6.00 3,686 4,539 INTRM1 DRILL DDRL P Directional drill 9 7/8" hole from 3686' - 4539' MD. ND = 2513'. ADT = 3.29 HRS. ECD = 10.4 PPG. 05/31/2007 00:00 06:00 6.00 4,539 5,586 INTRM1 DRILL DDRL P Directional drill 9 7/8" hole from 4539' - 5586' MD. TVD = 2780'. ADT = 4.01 HRS. ECD = 10.45 PPG. Crew Chan e 06:00 12:00 6.00 5,586 6,384 INTRM1 DRILL DDRL P Directional drill 9 7/8" hole from 5586' - 6384' MD. TVD = 3006'. ADT = 3.91 HRS. ECD = 10.6 PPG. 12:00 18:00 6.00 6,384 7,108 INTRM1 DRILL DDRL P Directional drill 9 7/8" hole from 6384' - 7108 MD. TVD = 3186'. ADT = 3.72 HRS. ECD = 11.1 PPG. Crew Chan e 18:00 00:00 6.00 7,108 7,489 INTRM1 DRILL DDRL P Directional drill 9 7/8" hole from 7108' - 7489' MD. ND = 3259'. ADT = 3.70 HRS. ECD = 10.7 PPG. Total of 24' of concretions drilled. 06/01/2007 00:00 04:45 4.75 7,489 7,900 INTRM1 DRILL DDRL P Directional drill 9 7/8" hole from 7489' - 7900 M D. ND = 3323'. ADT = 3.27 HRS. ECD = 10.91 PPG. 04:45 06:00 1.25 7,900 7,900 INTRM1 DRILL CIRC P Circulate a 30 BBL sweep around and condition mud at drilling rates. Reciprocate & rotate drill string. Observed little or increase in cuttings u on return of swee . Crew chan e 06:00 06:30 0.50 7,900 7,900 INTRM1 DRILL CIRC P Continue circulate out sweep as above. Pre for BROOH. 0630 12:00 5.50 7,900 4,639 INTRM1 DRILL REAM P BROOH at drilling rates from 7900' - 4639'. 12:00 16:00 4.00 4,639 3,308 INTRM1 DRILL REAM P Continue BROOH at drilling rates from 4639' - 3308'. Obsrerved good hole conditions. Pulled 5 stands under shoe at 3 minutes / stand to aid hole cleaning as we observed possible ballin u. Hole cleaned u ood. 16:00 17:15 1.25 3,308 3,308 INTRM1 DRILL CIRC P Circulate a 30 BBL sweep around and condition mud at drilling rates. Reciprocate & rotate drill string. Observed little or increase in cuttings u on return of swee . 17:15 17:30 0.25 3,308 3,308 INTRM1 DRILL OWFF P Monitor well - static. 17:30 18:00 0.50 33,080 3,308 INTRMI DRILL TRIP P Pump dry job. Drop Mud Dog pipe wiper, and install stripping rubbers. Crew chan e. 18:00 21:00 3.00 3,308 357 INTRM1 DRILL TRIP P Continue POOH laying down 5" DP. Observed 7 BBL fluid loss to hole on tri out. 21:00 23:30 2.50 357 0 INTRM1 DRILL PULD P Breakout & lay down BHA #2. plug in and download MWD assembly Inspect & rade bit to 3/2/BT/A/X/IMIT/TD. 23:30 00:00 0.50 0 0 INTRM1 DRILL OTHR P Clean & clear rig floor of toofs and mud. Prep for casing equipment & ullin WB. 06/02/2007 00:00 00:15 0.25 0 0 IINTRM1 DRILL OTHR P Rig up test joint. BOLDS, & pull wear ~ ~ 06/02/2007 00:15 03:30 3.25 0 0 INTRM1 CASIN( RURD P Held PJSM with crew. Discuss rig up for running casing. Rig up all casing equipment to run 7 5/8" casing with Stab Rite tools as per GBR & Franks reps. Circulate over top of hole, monitoring well for a 9 BBL loss during RU. 03:30 06:00 2.50 0 414 INTRM1 CASINC RNCS P Held PJSM with crew, GBR & Franks rep. Discuss safety & hazard recognition issues. Discuss running 7 5/8" casing procedure utilizing Stab Rite sytem & flush mounted slips. Make up shoe tack joints with baker loc. MU Torque = 8K ft/Ibs. Fill casing with mud & Check floats - good. Continue RIH with casing to 414', installing Bowspring centralizers and h droforms as lanned. Crew Chan e 06:00 10:45 4.75 414 3,393 INTRM1 CASIN RNCS P Held PJSM with crew coming on tour while continue to run casing, running to 3393'. Fill every joint and obtain full circulation every 15 joints. Obtain T&D arameters and er ri en ineer. 10:45 11:30 0.75 3,393 3,393 INTRM1 CASINC CIRC P Circulate at the 10 3/4" shoe with pumps @ 5 BPM - 330 PSI. 11:30 18:00 6.50 3,393 6,889 INTRM1 CASIN( RNCS P Continue to run casing from 3393' - 6889'. Fill every joint and obtain full circulation every 15 joints. obtain T&D parameters and per rig engineer. Crew Chan e 18:00 21:00 3.00 6,889 7,890 INTRM1 CASINC RNCS P Continue to run casing from 6889' - 7890', installing pups for proper space out on rig floor. Fill every joint and obtain full circulation every 15 joints. obtain T&D parameters and per rig engineer. Observed 35 BBL total fluid loss on run in hole with casing. SIMOPS: Spot Dowell & rig up to erform cement 'ob. 21:00 22:45 1.75 7,890 7,890 INTRM1 CASIN RURD P Rig down casing running equipment. Pull flush mounted slips and control box. Make up 7 5/8" cement head with plugs previously loaded as per powell rep. Make up cement lines. Work casing string periodically to ensure free movement in string while rigging uo. UP WT = 205K. SO WT = 128K. ~ ~ 06/02/2007 22:45 00:00 1.25 7,890 7,890 INTRM1 CEME~ CIRC P Circulate with rig to condition mud for pre cement conditions with 9.1 PPG, Visc = 53, PV = 15, YP = 15 and gels at 5/8. Reciprocate casing string with good movement in 25' strokes. While circulating, held PJSM with entire crew, Dowell, & vac truck drivers. Discuss safety & hazard recognition issues. Discuss cementing procedure & desi nate a s ill cham ion for ~ob. 06/03/2007 00:00 01:00 1.00 7,890 7,890 INTRM1 CEME~ DISP P Turn rig over to Dowell. Pump 10 BBLs of 8.3 CW00. Pressure test lines to 3000 PSI. Good test. Continue pump 40 BBLS CW100, and 50 BBLS of MudPushll. Drop plug. Pump 140 BBLS of Deepcrete tail cement @ 6.0 BPM at 520 PSI. Drop Plug, and flush with 5 BBIs of water. Observed good reciprocation of casing string in 30 foot increments. 01:00 02:15 1.25 7,890 7,890 INTRM1 CEME~ DISP P Turn over to rig. Displace cement with 8.5 MOBM at 6.2 BPM - 750 PSI. Continue reciprocate casing string, setting casing on depth with 296 BBLS pumped. UP WT = 205K, SO WT -128k. Set in place with 80K downweight. Observed bumping plug with a total of 352.15 BBLS pumped - 3504 pump stiokes. Continue pressure to 1250 PSI. Hold 5 minutes. CIP @ 01:58 HRS. Floats held. Bleed all ressures. 02:15 03:30 1.25 0 0 INTRM1 CASIN( OTHR P Nipple down BOP stack and raise. Rig down Dowell cementers. Rig down lines & cement head. Suck out MOBM in casing for installation of slips & cut. SIMOPS: Load pipe shed with 4" Drill i e. 03:30 06:00 2.50 0 0 INTRM1 CASIN OTHR P Install 7 5/8" casing slips with 50K tension in string. Weight indicator @ 155K. Rig up Wachs pneumatic casing cutter. Cut casing as per Vetco ra re . Install ackoff. Crew Chan e 06:00 09:15 325 0 0 INTRM1 CASIN( DHEQ P Nipple up BOP's. Test Flange to 5000 PSI. Continue Nipple up flowlines. Rig up and test pack-off to 3800 PSI. Rig up liones on 10 3/4" x 7 5/8" annulus for annular flush. SIMOPS: Load pipe shed with 4" Drill i e. 09:15 11:15 2.00 0 0 INTRM1 CASIN DHEQ P Pressure test lines to 1500 PSI. Rig up lines to pump. With rig pump, perform annular injectivity test observing 13.2 PPG EMW. Continue pumping flushing annulus with 150 BBLs of water @ 2 BPM with FCP - 740 PSI. Record on chart. ~ ~ 06/03/2007 11:15 12:00 0.75 0 0 INTRM1 DRILL RURD P Lay down long bales on top drive. Install short bales & attach link tilt assembly. Pick up 5" DP elevators. Make up wear bushing, RIH install same. RILDS. Lay down testjoint & runnin tool. 12:00 12:30 0.50 0 0 INTRM1 DRILL RURD P Install mousehole in rotary table. pull bags of thread protectors to rig floor. Heid PJSM. Discuss laying down 5" Drill i e from derrick. 12:30 14:30 2.00 0 0 INTRM1 DRILL RURD P Lay down 5" DP from derrick. SIMOPS: Freeze protect 10 3/4" x 7 5/8" annulus with 80 BBLS of diesel. Held PJSM with Little Red. Rig up and test lines to 1400 PSI. ICP =2 BPM - 630 PSI, & FCP = 2 BPM - 750 PSI. 14:30 15:00 0.50 0 0 INTRM1 RIGMN RGRP T Remove link tilt cylinder from top drive for re air. 15:00 16:15 1.25 0 0 INTRM1 DRILL RURD P Continue lay down 5" Drill pipe from derrick. SIMOPS: Cleanin its. 16:15 16:45 0.50 0 0 INTRM1 RIGMN RGRP T Install repaired link tilt cylinder on top drive. 16:45 18:00 1.25 0 0 INTRM1 DRILL RURD P Continue lay down 5" DP from derrick for a total of 153 'oints. Crew Chan e 18:00 18:30 0.50 0 0 INTRM1 DRILL RURD P Clean & clear rig floor area. Rig up to PU 4" DP. Continue load shed with 4" drill i e. SIMOPS: Cleanin its. 18:30 2130 3.00 0 0 INTRM1 RIGMN SVRG P Held PJSM with crew. Discuss safety & hazard recognition issues. Discuss procedure to change out saver sub. Change out saver sub and bell guide on Top Drive. Install 4" XT - 39 Saver sub. 21:30 22:00 0.50 0 0 INTRM1 DRILL RURD P Change out all handling equipment from 5" to 4". SIMOPS: Cleanin its. 22:00 00:00 2.00 0 0 INTRM1 DRILL RURD P Held PJSM. Discuss picking up 4" DP and rack back. Begin picking up four stands of 4" HW drill pipe. Make up and rack back 7 stands of 4 3/4" Hybrid stands. ( 2 x 4 3/4" HWDP, & 1 x 4" DP . Obtain SLM. 06/04/2007 00:00 02:00 2.00 0 0 INTRM1 DRILL RURD P Continue make up and rack back 8 stands of 4 3/4" Hybrid stands. ( 2 x 4 3/4" HWDP, & 1 x 4" DP). Total of 15 stands. Obtain SLM. 02:00 06:00 4.00 0 0 INTRM1 DRILL RURD P Continue pick up 87 joints of 4" drill pipe racking back stands in derrick. Crew Chan e 06:00 08:00 2.00 0 0 INTRM1 DRILL RURD P Continue pick up and rack back 4" DP. Obtain SLM. 08:00 09:15 125 0 0 INTRM1 DRILL PULD P Clean & clear rig floor area. Send thread protectors out. Instatl mouse hole. Pull tools to rig floor for BHA. SIMOPS: Weld strap on Stabrite system while picking up jewelry for BHA. 06/04/2007 09:15 11:45 2.50 0 371 INTRM1 DRILL PULD P Held PJSM with crew & Sperry Sun reps. Make up 6 3/4" Bit, & GeoPilot BHA as per DD & MWD. Totai BHA len th = 371.41'. 11:45 12:00 0.25 371 371 INTRM1 DRILL PULD P Perform shallow pulse test with 280 GPM - 100 PSI. Good test. 12:00 18:00 6.00 371 5,243 INTRM1 DRILL TRIP P Trip in hole with BHA #3, picking up singles from shed from 371' - 5243' MD. Fill drill string every 25 stands. Crew chan e. 18:00 21:30 3.50 5,243 7,774 INTRM1 DRILL TRIP P Continue trip in hole picking up singles from 5243' - 7774'. Fill drill string every 25 stands. 21:30 22:30 1.00 7,774 7,774 INTRM1 DRILL CIRC P Circulate bottoms up plus to ensure good mud properties of 8.5 PPG, Visc = 67, PV - 13, YP - 15, and Gels @ 11/13 for casin & LOT. 2230 23:30 1.00 7,774 7,774 INTRM1 DRILL PULD P Pick up remaing DP (7-stands) and rack back in derrick. 23:30 00:00 0.50 7,774 7,774 INTRM1 RIGMN SVRG P Held PJSM with crew. Discuss safety & hazard recognition issues. Discuss procedure to Slip & cut dril~ing line. Hang blocks and slip & cut drilling line. 06/05/2007 00:00 00:45 0.75 7,774 7,774 INTRM1 RIGMN SVRG P Continue Slip & cut 114' of drilling line. Hang blocks and slip & cut drilling line. 00:45 01:15 0.50 7,774 7,774 INTRM1 RIGMN SVRG P Service top drive, and crown section. 01:15 02:30 1.25 7,774 7,774 INTRM1 DRILL DHEQ P Rig up and test 7 5/8" casing to 3000 PSI for 30 minutes. Bleed pressure and RD lines. 02:30 05:30 3.00 7,774 7,900 INTRM1 CEME COCF P Wash Down to tag Float equipment @ 7802' MD. Obtain Geopilot parameters. Drill float equipment & shoe track. 05:30 07:00 1.50 7,802 7,920 INTRM1 DRILL CIRC P Circulate bottoms up in preparation of LOT. 07:00 07:30 0.50 7,900 7,920 INTRM1 DRILL DDRL P Drill 20' of new hole from 7900' - 7920'. MD Crew Chan e. 07:30 08:15 0.75 7,920 7,920 INTRM1 DRILL LOT P Perform LOT w/ 8.4 ppg MW, 1050 psi 3323' ND= 14.5 EMW. 08:15 12:00 3.75 7,920 8,517 PROD1 DRILL DDRL P Directional drill "B" lateral. Max gas 50 units. Pumped a 30 bbl sweep while drilling @ 8720', slight increase in cuttin s. 12:00 18:00 6.00 8,517 9,240 PROD1 DRILL DDRL P Directional dritl "B" lateral. Max gas 50 units. 18:00 00:00 6.00 9,240 9,592 PROD1 DRILL DDRL P Directional drill "B" lateral. Max gas 50 units. 06/06/2007 00:00 06:00 6.00 9,592 9,992 PROD1 DRILL DDRL P Directional drill "B" lateral. Max gas 30 units. 06:00 12:00 6.00 9,992 10,679 PROD1 DRILL DDRL P Directional drill "B" lateral. Max gas 50 units. 12:00 18:00 6.00 10,679 11,352 PROD1 DRILL DDRL P Directional drill "B" lateral. Max gas 61 units. ~ ~ 06/06/2007 18:00 00:00 6.00 11,352 11,935 PROD1 DRILL DDRL P Directional drill "B" lateral. Max gas 60 units. 06/07/2007 00:00 04:15 4.25 11,935 12,268 PROD1 DRILL DDRL P Directional drill "B" lateral. Max gas 60 units. Pumped a 30 bbl weighted high vis sweep (10 ppg/ 180 vis) while drilling f/ 12177' to TD 12268'. 04:15 05:00 0.75 12,268 12,268 PROD1 DRILL CIRC P Circulate bottom's up. Rotate 120 rpm w/ 7-8k ft Ib torque. Pumping 345 gpm w/ 3550 si. 05:00 12:45 7.75 12,268 7,881 PROD1 DRILL REAM P Backream out of the hole to the casing shoe. Rotate 120 rpm w/ 7000 ft Ibs of torque. Pumping 345 gpm w/ 3550 si. 12:45 14:15 1.50 7,881 7,881 PROD1 DRILL CIRC P Circulate while reciprocate pipe 85'. Pump a 30 bbls weighted hi vis sweep (10 ppg/ 180 vis), only a slight increase in cuttings. Circulated a ttoal of 710 bbls. 14:15 15:00 0.75 7,881 7,881 PROD1 RIGMN SVRG P Inspect saver sub. Service crown sheaves and to drive. 15:00 18:00 3.00 7,881 11,650 PROD1 DRILL TRIP P Trip in the hole. ran out of down wt @ 11650'. 18:00 19:00 1.00 11,650 12,268 PROD1 DRILL REAM P Ream in the hole. Rotate 50 rpm w/ 6-7000 ft Ibs torque. Pumping 127 m. 19:00 22:15 3.25 12,268 12,268 PROD1 DRILL CIRC P Circulate four bottom's up. Pump a 30 bbls weighted hi vis sweep (9.3 ppg, 180 vis), slight increase in cuttings. Pump 345 gpm w/ 3500 psi. Rotate 120 rpm w/ 7000 ft Ibs of torque. ECD's 11.1 ppg. Hold a PJSM wJ truck drivers while circulating for the displacement. Pump a total of 1500 bbls. 22:15 23:30 1.25 12,268 12,268 PROD1 DRILL CiRC P Displace the 8.5 ppg MOBM, with 8.4 ppg SFOBM. Pump 345 gpm w/ 3500 psi. ECD's 11.18 ppg. Rotate 120 rpm w/ 6000 ft Ibs of torque initial, 7000 ft Ibs final. 23:30 23:45 0.25 12,268 12,268 I PROD1 DRILL OWFF P Obtain SPR's. Monitor well for flow, 23:45 00:00 0.25 12,268 11,993 PROD1 DRILL TRIP P POOH on elevators. Monitor well on trip tank. Obtain PU and SO wYs every 5 stands. PU wt 210k, no slack off wt. 06/08l2007 00:00 00:15 0.25 11,993 11,807 PROD1 DRILL TRIP P POOH on elevators. Monitorwell on trip tank. Obtain PU and SO wYs every 5 stands. PU wt 210k, no slack off wt. Hole not takin ro er fill. SLM. 00:15 02:15 2.00 11,807 10,589 PROD1 DRILL TRIP P Pump out of the hole. Pumping 253 gpm w/ 2050 psi. Obtain PU and SO wYs eve 5 stands. SLM. 02:15 05:15 3.00 10,589 7,890 PROD1 DRILL TRIP P Pull out of the hole, monitor well on the trip tank. Record PU and SO wYs every 5 stands. SLM. Drop a 1-7/8" rabbit w/ 100' of slickline Ca~ 8996'. ~ ~ 06/08/2007 05:15 05:45 0.50 7,890 7,890 PROD1 DRILL CIRC P Pump a 15 bbl dry job (10.3 ppg, 60 vis). Cahse dry job w/ 10 bbls. Pump 206 gpm w/ 1200 psi. Blow down top drive and clean floor. 05:45 06;00 0.25 7,890 7,683 PROD1 DRfLL TRIP P Continue to pull out of the hole, monitor well on the trip tank. SLM. Record PU and So wYs every 10 stands inside of casin . 06:00 10:15 4.25 7,683 371 PROD1 DRILL TRIP P Continue to pull out of the hole, monitor well on the trip tank. SLM. Record PU and So wYs every 10 stands inside of casing. No correction on SLM. 10:15 '11:00 0.75 371 93 PROD1 DRILL PULD P Stand back 2 stands of 4" HWDP (includes jars), stand back a stand of 4-3/4" flex drill collars. 11:00 11:45 0.75 93 93 PROD1 DRILL OTHR P Download Sperry Sun MWD. 11:45 12:45 1.00 93 0 PROD1 DRILL PULD P Lay down BHA #3. 12:45 13:15 0.50 0 0 PROD1 DRILL OTHR P Clean and clear rig floor. 13:15 13:45 0.50 0 0 COMPZ CASIN( RURD P Rig up to run 4-1/2" slottted liner f/ the "B" lateral. 13:45 14:00 0.25 0 0 COMPZ CASIN( SFTY P Hold PJSM on running the slotted liner. 14:00 16:30 2.50 0 4,460 COMPZ CASIN RNCS P Run 4-1/2" 11.6 ppf L-80 BTC slot and blank liner er detail. 16:30 18:15 1.75 4,460 4,731 COMPZ CASIN RNCS P PU/MU Baker seal bore extension and flex lock liner han er with inner strin . 18:15 18:30 0.25 4,731 4,731 COMPZ CASINC OTHR P Break off the crossover off of the jars 3-1/2" IF in x xt 39 box . 18:30 19:00 0.50 4,731 4,731 COMPZ CRSIN( RURD P Rig down GBR casing running too-s. La down tools from the floor. 19:00 00:00 5.00 4,731 10,360 COMPZ CASIN RUNL P Run 4-1/2" 11.6 ppf BTC L-80 sloUblank liner in the hole on 4" drill pipe. Record PU and So wYs every 10 stands. Note: String wt 108k with liner only made up, 70k is TD wt. Note : Record PU and SO and Rot wt and torque above she: PU 145k, SO wt 100k, rot wt 112k, rotating 40 rpm w/ 4000 ft Ibs. Note: 2 stands below shoe: PU wt 145k, SO wt 95k, rot wt 118k, rotating wt 118k, rotating torque 4500 ft Ib w/ 40 r m. 06/09/2007 00:00 00:15 025 10,360 10,547 COMPZ CASIN( RUNL P Run 4-1/2" 11.6 ppf BTC L-80 sloUblank liner in the hole on 4" drill pipe. Record PU and SO wYs every 10 stands. Note: Ran out of down wt @ 10470' rotated stand 62 down to 10545'. Run on elevators stand 63 and 64, rotate stand 65 f/ 10731' to 10820'. The rest of the trip was all run on elevators. ~ 06/09/2007 00:15 01:15 1.00 10,547 10,915 COMPZ CASINC RUNL P Run 4-1/2" 11.6 ppf BTC L-80 sloUblank liner in the hole on 4" HW drill pipe. Record PU and SO wYs every 10 stands. Note: Run on elevators stand 63 and 64, rotate stand 65 f/ 10731' to 10820'. The rest of the trip was all run on elevators. 01:15 03:45 2.50 10,915 12,268 COMPZ CASINC RUNL P Run 4-1/2" 11.6 ppf BTC L-80 slobblank liner in the hole on hybrids ( 4" HW drill pipe &(2) 5" DC's. Record PU and SO wt's every 10 stands. Note: All was RIH on elevators. 03:45 04:30 0.75 12,268 12,258 COMPZ CASIN( OTHR P Tag bottom, PU and space out to place liner top on depth. PU wt 220k, SO wt 95k. Drop 1-3/4" ball, pump down @ 3 bpm w/ 510 psi. Ball on seat w/ 890 strokes. Pressure up to 1900 psi to set flex lockliner hanger, increase pressure to 3000 psi to activate pusher tool and set ZXP, slack off 25k, continue to pressure up to 4000 psi to neutralize pusher tool. Bleed off ressure. 04:30 04:45 0.25 12,258 12,258 COMPZ CASINC DHEQ P Pressure test ZXP packer to 2500 psi f/ 5 min. OK. Bleed off ressure. 04:45 05:00 0.25 12,258 7,530 COMPZ DRILL TRIP P Pull and stand back a stand of hybrids, pull 20' on next stand. PU wt 195k, SO wt 130k. 05:00 05:15 0.25 7,530 7,530 COMPZ DRILL SFTY P PJSM on displacing well back to MOBM 8.4+, 56 vis. 05:15 06:00 0.75 7,530 7,530 COMPZ DRILL CIRC P Displace well f/ 8.4 ppg SFOBM to 8.4+ MOBM. Recip 73'. Pumping 462 m w/ 3200 si. 06:00 06:45 0.75 7,530 7,530 COMPZ DRILL CIRC P Take slow pump rates w/ both pumps. Monitor well, static. Pump 15 bbl dry 'ob. Blow down to drive. 06:45 07:00 0.25 7,530 7,260 COMPZ DRILL TRIP P Drop the Haggard Mud Dog ID wiper. Pull out of the hole on elevators. 07:00 07:15 0.25 7,260 7,260 COMPZ DRILL SFTY P Man down drill with the Kuparuk Fire department. Simulate rescue of person in the pipe shed. Drill over 0805 am. 07:15 11:30 4.25 7,260 0 COMPZ DRILL TRIP P Continue to pull out of the hole with runnin tools for the "B" lateral liner. 11:30 12:30 1.00 0 0 COMPZ DRILL PULD P Make breaks and lay down Baker running tools and inner string. Did not recover the Haggard ID mud dog ID wiper. Calculated fill 55.4 bbis, actual 60.5 bbls. 12:30 13:00 0.50 0 0 COMPZ DRILL OTHR P Clear and clean rig floor. 13:00 13:15 0.25 0 0 PROD2 STK OTHR P Pre job safety meeting on PU/MU ~ 06/09/2007 13:15 14:15 1.00 0 139 PROD2 STK PULD P PU/MU Baker milling assembly . Lay down to the shed. PU Whipstock assembl , attach mills. 14:15 15:00 0.75 139 185 PROD2 STK PULD P MU Sperry Sun MWD. Orient same. 15:00 15:30 0.50 185 185 PROD2 STK OTHR P Upload MWD. 15:30 16:15 0.75 185 475 PROD2 STK PULD P MU Baker bumper sub, dp crossover, and 3 stands of Hybrids (1 jt 4" HWDP w/ 2 jts of 5" x 2-9/16" ID Drill collar). Drift all pipe picked up due to Haggard ID wiper was not located from last trip out of the hole. 16:15 16:30 0.25 475 475 PROD2 STK OTHR P Fill pipe. Shallow pulse test MWD. Good. 16:30 18:00 1.50 475 1,977 PROD2 STK TRIP P Trip in the hole with the Baker 7-5/8" Windowmaster whipstock. Drift all pipe picked up due to Haggard ID wiper was not located from last trip out of the hole. 18:00 23:15 5.25 1,977 6,103 PROD2 STK TRIP P Trip in the hole with the Baker 7-5/8" Windowmaster whipstock on 40 stands of 4" w/ super sliders, then 20 stands of 4" slick DP. Fill pipe every 25 stands. Drift all pipe picked up due to Haggard ID wiper was not located from last tri out of the hole. 23:15 23:45 0.50 6,103 6,471 PROD2 STK TRIP P Continue trip in the hole with the Baker 7-5/8" Windowmaster whipstock on 4 stands of HWDP. Drift all pipe picked up due to Haggard ID wiper was not located from last trip out of the hole. 23:45 00:00 0.25 6,471 6,735 PROD2 STK TRIP P Trip in the hole with the Baker 7-5/8" Windowmaster whipstock on Hybrids (a jt of 4" HWDP w/ 2 jts of 5" x 2-9/16" DC's). Stand 67 made up . Drift all pipe picked up due to Haggard ID wiper was not located from last trip out of the hole. SO wt 125k, PU wt 150k. 06/10/2007 00:00 00:30 0.50 6,735 6,788 PROD2 STK OTHR P Establish circulation. MAD pass logging 125 ft per hour. 273 gpm w/ 2000 psi. Gamma interva16570' to 6620'. 00:30 01:00 0.50 6,788 7,492 PROD2 STK TRIP P Trip in the hole with the Baker 7-5/8" Windowmaster whipstock on Hybrids (a jt of 4" HWDP w/ 2 jts of 5" x 2-9/16" DC's). Drift all pipe picked up due to Haggard ID wiper was not located from last trip out of the hole. Found the wiper in the 6th Hybrid (stand #70) SO wt 125k, PU wt 150k. ~ 06/10/2007 01:00 02:30 1.50 7,492 7,541 PROD2 STK OTHR P Establish circulation. Pumping 273 gpm w/ 2000 psi. PU wt 170k, SO wt 125k. Orient whipstock face to 17 deg left. Five foot measurement in the hole to the top of the ZXP packer @ 7541' (48-1/2' in on stand #76). Set down 20k, PU to 210k- anchor is set: Slack off a~l wt to shear bolt. Work several times. Shear bolt, then PU wt 150k. 02:30 05:45 3.25 7,443 7,455 PROD2 STK WPST P Mill a window in the 7- 5/8" casing. Pump a 20 bbls sweep (10 ppg/ 180 vis). Rotate 90 rpm w/ 4-7 k ft Ibs of tor ue. Pum in 329 m w/ 2550 si. 05:45 07:15 1.50 7,455 7,475 PROD2 STK WPST P Drill new formation. 12' of full guage ~/ hole (6-3/4"). TOW 7443' (3250' ND) Hole angle ~ ~ 80.27 deg. BOW 7455' (3252' ND) Hole angle 80.27 de . 07:15 08:00 0.75 7,475 7,430 PROD2 STK CIRC P PU then circulate @ 7430'. Pump a 30 bbl sweep (10 ppg, 200 vis). Rotate 50 r m w/ 4000 ft Ib of tor ue. 08:00 08:15 0.25 7,430 7,475 PROD2 STK OTHR P Slack off through window w/ out pumps and with out rotation. Saw 4-6k drag on the face of the whipstock, both directions. 08:15 08:30 0.25 7,475 7,430 PROD2 STK OTHR P Monitor well. Static. 08:30 09:00 0.50 7,430 7,430 PROD2 STK CIRC P Pump a dry job. Blow down top drive 09:00 12:30 3.50 7,430 195 PROD2 STK TRIP P Pull out of the whole with the milling assembly. Hole took proper dis lacement. 12:30 13:30 1.00 195 0 PROD2 STK PULD P Lay down Baker milling assembly and Sperry Sun MWD (change out pulsar). Upper mill was guaged to be full 6-3/4". 13:30 14:00 0.50 0 0 PROD2 STK OTHR P Clear and clean rig floor. 14:00 14:45 0.75 0 0 PROD2 STK OTHR P Pickup and make up wash tool. Flush BOP ram cavities after milling o eration. 14:45 15:30 0.75 0 0 PROD2 WELCT OTHR P Make up testjoint. Rig up testing e ui ment. 15:30 21:00 5.50 0 0 PROD2 WELCT BOPE P 14 day BOPE test. Witness of test by AOGCC inspector John Crisp. Test upper pipe rams (3-1/2 x 6" variables) with 4", 4-1/2" and 5" test joint. Test blind rams and annular to 250 psi low and 3000 psi high. Hold each test f/ 5 min. Test all valves f/ the choke manifold, kill line and choke line the same. Test floor vlaves, top drive IBOP automatic and manual the same. Test accumulator. i ~ 06/10/2007 21:00 21:30 0.50 0 0 PROD2 WELCT OTHR P Puil test plug. Install Vetco Gray wear bushing with 9" ID, 13-3/8" OD, 38" len th. 21:30 22:15 0.75 0 0 PROD2 WELC OTHR P Blow down top drive, choke line and kill line. Ri down testin e ui ment. 22:15 22:30 0.25 0 0 PROD2 DRILL SFTY P Pre job safety meeting on PU/MU BHA #5. 2230 00:00 1.50 0 65 PROD2 DRILL PULD P PU/MU BHA #5. 06/11/2007 00:00 0030 0.50 65 92 PROD2 DRILL PULD P Continue to PU/MU BHA #5. 00:30 0130 1.00 92 92 PROD2 DRILL OTHR P Upload to Sperry Sun MWD. 01:30 02:00 0.50 92 369 PROD2 DRILL TRIP P RIH w/ BHA #5. 02:00 02:30 0.50 369 369 PROD2 DRILL OTHR P Shallow test MWD and GeoPilot. Rotate 30 rpm w/ 1000 ft Ibs of torque. Rot wt 85k. 02:30 06:00 3.50 369 7,304 PROD2 DRILL TRIP P Trip in the hole w/ BHA #5. Record PU and SO wt's every 5 stands. Fill pipe every 20 stands. Calculated dis lacement 53 bbis, actual 43 bbis. 06:00 06:30 0.50 7,304 7,304 PROD2 DRILL CIRC P Fill pipe. Blow down top drive. 06:30 08:00 1.50 7,304 7,304 PROD2 RIGMN SVRG P Slip and cut 98' of 1-3/8" drilling line. 08:00 08:30 0.50 7,304 7,304 PROD2 RIGMN SVRG P Service top drive, blocks, and drawworks. 08:30 09:15 0.75 7,304 7,475 PROD2 DRILL TRIP P Continue trip in the hole to 7430', then slow through the window (7443'-7455'). Window was clean--. After through the window, started pumping @ 345 gpm w/ 2900 psi. Rotated 60 rpm w/ 6000 ft Ib of tor ue. Ta ed bottom 7475'. 09:15 12:00 2.75 7,475 7,705 PROD2 DRILL DDRL P Directionat drill "D" lateral. Max gas 60 units. 12:00 18:00 6.00 7,705 8,056 PROD2 DRILL DDRL P Directional drill "D" lateral. Max gas 25 units. 18:00 00:00 6.00 8,056 8,780 PROD2 DRILL DDRL P Directional drill "D" lateral. 06/12/2007 00:00 06:00 6.00 8,780 9,368 PROD2 DRILL DDRL P Directional drill "D" lateral. 06:00 12:00 6.00 9,368 10,211 PROD2 DRILL DDRL P Directional drill "D" lateral. Max gas 78 units. 12:00 18:00 6.00 10,211 11,065 PROD2 DRILL DDRL P Directional drill "D" lateral. Max gas 68 units. 18:00 22:15 4.25 11,065 11,447 PROD2 DRILL DDRL P Directional drili "D" lateral. 22:15 00:00 1.75 11,447 11,447 PROD2 DRILL OTHR T Attempt to orient Geopilot and change deflection from 69 deg. Change choke on geopilot skid from a 16 to a 28. Reboot surface and downhole computers. Try another mud pump. Send commands, wait on results. ~ ~ 06/13/2007 00:00 01:00 1.00 11,447 11,461 PROD2 DRILL OTHR T Attempt to orient Geopilot and change deflection from 69 deg. Change choke on geopilot skid from a 16 to a 28. Reboot surface and downhole computers. Try another mud pump. Send commands, wait on results. Directional drill "D" lateral. 01:00 06:00 5.00 11,461 8,527 PROD2 DRILL REAM T Backream out of the hole. Record PU and SO wYs every 5 stands in open hole. @ 11461': PU wt 170k, SO wt 80k, Rot 120 rpm w/ 6k ft Ibs of torque, 3300 psi. @ 9640': PU wt 160k, SO wt 85k, Rot 120 rpm w/ 5-6k ft Ibs of torque, 3240 psi. 06:00 07:15 1.25 8,527 7,871 PROD2 DRILL REAM T Backream out of the hole. Record PU and SO wYs every 5 stands in open hole. 07:15 08:00 0.75 7,871 7,400 PROD2 DRILL TRIP T Pull out of the hole to above the window (TOW 7443'- BOW 7455'). PU wt 150k, SO wt 105k. 08:00 08:45 0.75 7,400 7,400 PROD2 DRILL CIRC T Establish circulation. Pump a 20 bbl weighted sweep (10 ppg/ 180 vis). Circulate 400 bbis total. Slight increase of cutting at the shakers. Max as 46 units. Cleanin ri floor. 08:45 09:00 0.25 7,400 7,400 PROD2 DRILL OWFF T Monitorwell, OK. Continue cleaning ri floor. 09:00 0930 0.50 7,400 7,400 PROD2 DRILL CIRC T Pump a 20 bbl dry job. Blow down top drive. 09:30 12:00 2.50 7,400 840 PROD2 DRILL TRIP T Continue to POOH w/ BHA #5 to change out 5200 series Sperry Sun GeoPilot TL 055. PU wt 145k, SO wt 105k. Record PU and SO wt's every 10 stands in cased hole. 12:00 13:00 1.00 840 0 PROD2 DRILL TRIP T Continue POOH. Record PU and SO wYs every 10 stands. PU wt 90k, SO wt 90k. Visual inspect GeoPilot, break off the bit. Calculated fill 46, actual fill 54.5 bbis. 13:00 13:45 0.75 0 91 PROD2 DRILL OTHR T Download MWD. 13:45 14:30 0.75 91 91 PROD2 DRILL PULD T Changeout the GeoPilot, make up same bit. 14:30 15:00 0.50 91 91 PROD2 DRILL OTHR T Upload MWD. 15:00 15:30 0.50 91 369 PROD2 DRILL CIRC T Trip in the hole. 15:30 16:00 0.50 369 369 PROD2 DRILL OTHR T Shallow pulse test MWD and res onse from GeoPilot. 16:00 16:30 0.50 369 369 PROD2 RIGMN SVRG P Service rig, drawworks, crown and blocks. 16:30 17:30 1.00 369 369 ~ PROD2 RIGMN RGRP T Repair low lube pressure on top drive. • ~ ' Time L. s ~ Dafa ~rom ~o . °~~~ ~~E)u€. ~~ . S. ~e ~ th-~ E.'. tFi Fh~~ -'~ ~ Code : Su~cod~ . : _ . . ~ ~ ,.., '~ CC~ 06/13/2007 17:30 21:00 3.50 369 7,400 PROD2 DRILL TRIP T Trip in the hole w/ BHA #6. Record PU and SO wYs every 10 stands. Fill pipe every 25 stands. PU wt 102k, SO wt 100k. 21:00 22:15 1.25 7,400 7,400 PROD2 RIGMN SVRG P Change out the saver sub on the top drive. Change out gate, seat and bonnet to body "O" ring seal on 3" Demco valve used to isolate cement line on mud manifold. 22:15 23:45 1.50 7,400 7,400 PROD2 RIGMN RGRP T Electrician and crew change pressure indicator from gear oil pump to the PLC on the top drive. Monitor well on the tri tank. 23:45 00:00 0.25 7,400 7,495 PROD2 DRILL TRIP T Continue to trip in the hole w/ BHA #6. Record PU and SO wYs every 5 stands in open hole. Fill pipe every 25 stands. Rotate slow (30 rpm) to break in seals on the eo ilot. 06/14/2007 00:00 00:30 0.50 7,495 7,806 PROD2 DRILL TRIP T Trip in the hole w/ BHA #6. Tag up @ 7806'. 00:30 0130 1.00 7,774 8,055 PROD2 DRILL REAM T Pick up and make a top drive connection. Ream f/ 7774' to 8055'. Rotate 50 rpm w/ 5000 ft Ibs of torque. Pump 240 m w/ 1640 si. 01:30 02:00 0.50 8,055 8,430 PROD2 DRILL REAM T Run 4 stands. Record PU and SO wYs eve 5 stands. 02:00 02:30 0.50 8,430 8,430 PROD2 DRILL TRIP T Circulate while backreaming f/ 8430' to 8340' and try to clean hole. Circulate 320 bbis. Shakers showed that the casing was dirty. Pumping 345 gpm w/ 3070 psi. Rotate 60 rpm w/ 5-6000 ft Ibs of torque. Initial ECD was 10.55 p , final 10.36 02:30 02:45 0.25 8,430 8,711 PROD2 DRILL TRIP T Continue to trip in the hole w/ BHA #6. Ran 3 stands. 02:45 03:00 0.25 8,711 8,900 PROD2 DRILL REAM T Ream 2 stands in the hole. 03:00 04:30 1.50 8,900 10,960 PROD2 DRILL TRIP T RIH. Fill pipe @ 10776'. Record PU and SO wt's eve 5 stands. 04:30 05:15 0.75 10,960 11,461 PROD2 DRILL REAM T Ream in the hole to TD. Pumping 168 gpm w/ 1450 psi. Rotate 50 rpm w/ 6000 ft Ibs of tor ue. 05:15 06:00 0.75 11,461 11,546 PROD2 DRILL DDRL P Survey and orient GeoPilot. Directional drili "D" lateral w/ BHA #6. 06:00 11:00 5.00 11,546 12,261 PROD2 DRILL DDRL P Directional drill "D" lateral. Max gas 43 units. 11:00 12:45 1.75 12,261 12,261 PROD2 DRILL CIRC P Take final survey @ TD. Acquire SPR's. Pump a 30 bbls weighted high vis sweep (10 ppg/ 220 vis). Rotate 120 rpm w/ 7-8k ft Ibs of torque. Rot wt 118k. Pumpng 345 gpm w/ 3750 psi. Reciprocate f/ 12261' to 12180'. ECD's 11.76 ppg. Pump a total of 608 bbis. Slight increase in cuttin s. 12:45 13:00 0.25 12,261 12,261 PROD2 DRILL OWFF P Monitor well for flow, OK. : Page 20 uf 28 ' ~ ~ • 06/14/2007 13:00 18:00 5.00 12,261 9,558 PROD2 DRILL REAM P Backream out of the hole. Rotate 120 rpm w/ 6-7k ft Ibs of torque. Pumping 345 gpm w/ 3700 initial to final of 3150 psi @ 9558'. Record ECD's every 10 stands ECD of 10.71 ppg @ 9558'. SLM. 18:00 21:00 3.00 9,558 7,586 PROD2 DRILL REAM P Backream out of the hole. Rotate 120 rpm w/ 7-5k ft Ibs of torque. Pumping 345 gpm w/ 3150 initial to final of 2920 psi @ 8246'. Record ECD's every 10 stands. SLM. 21:00 21:30 0.50 7,586 7,401 PROD2 DRILL TRIP P POOH on elevatros through the window (TOW 7443', BOW 7455') to 7401'. Note: Calculated fill 27 bbls, actual fill 28 bbls. SLM. 21:30 23:30 2.00 7,401 7,401 PROD2 DRILL CIRC P Circulate to clean up cuttings inside of the 7-5/8" casing. Pump a 41 bbls weighted hi vis sweep (10 ppg/ 190 vis). Cire sweep surface to surface + 3 BU. Reciprocate from 7401' to 7307'. Rotate 120 rpm w/ 4-5k ft Ibs of torque. Pumping 350 gpm w/ 2870 psi. Initial ECD was 10.12 ppg, final 9.99 23:30 00:00 0.50 7,401 8,243 PROD2 DRILL TRIP P Trip in the hole on elevators. 06/15/2007 00:00 02:00 2.00 8,243 12,178 PROD2 DRILL TRIP P Trip in the hole on elevators. 02:00 06:30 4.50 12,178 12,261 PROD2 DRILL CIRC P Make a top drive connection. Rotate 120 rpm w/ 7-8k ft Ibs. Pumping 345 gpm w/ 3700 psi. Reciprocate f/ 12175' to 12261'. Pump a weighted hi vis sweep (10 ppg/ 200 vis) surface to surface + 4 BU.Initial ECD's were 11.36 ppg, final 11.2 ppg. Hold PJSM on displacement to 8.4 ppg solids free oil base mud. Circulated a total of 1762 bbls. 06:30 07:45 125 12,261 12,261 PROD2 DRILL CIRC P Displace f/ 8.4+ MOBM to 8.4 ppg SFOBM. Rotating 120 gpm w/ 7-8k ft Ibs of torque. Pumping 345 gpm w/ 3830 si. Rotatin wt 125k. 07:45 08:00 0.25 12,261 12,261 PROD2 DRILL OWFF P Observe well for fiow. Ok. 08:00 08:15 0.25 12,261 12,261 PROD2 DRILL SFTY P PJSM on tripping out of the hole. 08:15 09:00 0.75 12,261 11,244 I PROD2 DRILL TRIP P Pull out of the hole on elevators, wet. 09:00 09:15 025 11,244 11,244 PROD2 DRILL CIRC P Pump a 19 bbl dry job (mixed powder caicium chloride) , chase w/ 10 bbls. 9.7 ppg/70 vis. Pumping 162 gpm w/ 1000 si. 09:15 12:00 2.75 11,244 7,401 PROD2 DRILL TRIP P Trip out w/ BHA #6. Dropped a 1-7/8" rabbit w/ bit 9933'. 12:00 12:15 0.25 7,401 7,401 PROD2 DRILL OWFF P Observe we~l for flow. OK. ~ • ~_T-~e;~: ~ ~a ~ ~- , 'D~te ':.: Fto~s. To~ ;." ` : l3ur. ~. €~e tF~ E~ th: E', ase ' f;ode ' Subcod~ :'~. = CQM '. 06/15/2007 12:15 16:45 4.50 7,401 371 PROD2 DRILL TRIP P Continue POOH w/ BHA #6. Found 1-7/8" rabbit on the 'ars. 16:45 17:00 0.25 371 371 PROD2 DRILL SFTY P PJSM on laying down BHA #6. 17:00 17:45 0.75 371 91 PROD2 DRILL PULD P UD BHA#6. Note: Calculated fill 71.7 bbis,actual 80.5 bbls at 1800 hrs. 17:45 18:15 0.50 91 91 PROD2 DRILL OTHR P Download Sperry Sun MWD. 18:15 18:45 0.50 91 0 PROD2 DRILL PULD P Finish laying down BHA #6. 18:45 19:15 0.50 0 0 PROD2 DRILL PULD P Lay down subs and equipment f/ BHA #6. Clear floor. Shut biind rams. 19:15 19:45 0.50 0 0 COMPZ CASINC RURD P Rig up to run 4-1/2" slotted liner. 19:45 20:00 0.25 0 0 COMPZ CASINC SFTY P PJSM on running "D" lateral 4-1/2" sloUblank liner 11.6 f. 20:00 21:45 1.75 0 4,549 COMPZ CASIN( RNCS P PU/MU "D" lateral 4-1/2" 11.6 ppf L-80 BTC sloUblank liner. 21:45 22:00 0.25 4,549 4,616 COMPZ CASINC RNCS P MU 5-1/2" Recepticle joint and Baker liner settin sleeve. 22:00 22:30 0.50 4,616 4,616 COMPZ CASINC RURD P Clean and clear floor. UD GBR casing runnin tools. 22:30 Q0:00 1.50 4,616 5,650 COMPZ CASIN< RUNL P RIH w/ liner on 4" drill string. 4 stands of slick drill pipe, then will run 40 stands of 4" drill pipe w/ super sliders. 11 total stands in the hole @ midni ht. 06/16/2007 00:00 05:00 5.00 5,650 12,193 COMPZ CASIN RUNL P RIH w/ liner on 4" drili string. 4 stands of slick drill pipe, then 40 stands of 4" drill pipe w/ super sliders, then 16 stands of slick drill pipe, 4 stands of 4" HWDP, 15 stands of hybrids (2 jts of 5" DC's & 1 jt 4" HWDP), then 3 stands of slick 4" drill pipe. Record PU and SO and rotating weighYs and torque according to Rig Engineer's directions.PU wt 215 to 220k, SO wt 80k, Rotating wt 140k, rotating torque 9500 ft Ibs. 05:00 0530 0.50 12,193 12,251 COMPZ CASINC RUNL P Make top drive connection on stand 82. Rotate 30' in the hole w/ 30 rpm and 9500 ft bls of torque. PU wt 215k, SO wt 85k. Continue in hole, tag bottom 4' deep @ 12265'. Pickup and position top of iiner @ 7640.46' (shoe 12251'. 05:30 06:00 0.50 12,251 7,606 COMPZ CASINC OTHR P Break a single, drop a 29/32" ball. Pump ball down @ 3 bpm w/ 550 psi. Ball on seat with 652 strokes pumped. Pressure to 3000 psi to release liner, slack off, PU and observe PU wt to be 190K, SO observed to be 122k. Pressure to 4150 to shear circulating sub.Puil stand #82 out of the hole. PU wt 190k, SO wt 122k. ~ ~ ~ ~ i • ~ • 06/19/2007 03:30 04:30 1.00 0 0 COMPZ RPCOh PULD P Pickup Centralift equipment to the floor. RU. 04:30 04:45 0.25 0 0 COMPZ RPCOh SFIY P Pre job safety meeting on Picking up first componets of completion, setting um with Halliburton wireline. 04:45 05:30 0.75 0 85 COMPZ RPCOh PULD P MU/RIH perforated crossover with pup, 2 joints of 4-1/2" 12.6 ppf IBT-m L-80 tubing, 4-1/2" pup jt, Unique discharge sub, and 4-1/2" u 't. 05:30 05:45 0.25 85 85 COMPZ RPCOh PULD P PU Pump. Set pump eye, gas seperator, and high volume middle tandem pump inside the 4-1/2" tubing the rota table. 05:45 06:00 0.25 85 85 COMPZ RPCOb RURD P RU Halliburton slickline. Crew Change 06:00 06:30 0.50 85 85 COMPZ RPCO OTHR P Make up pump sections, lower into 4-1 /2" tb . 06:30 06:45 0.25 85 85 COMPZ RPC06 PULD P Halliburton wireline test fit D&D stinger, 2-7/8" Dart check valve, 2-7l8" spacer pipe Kobe Knock out, D& D packoff assembly. Cheveron seals messed u. Chan e out seals. 06:45 07:15 0.50 85 85 COMPZ RPCOti OTHR P Lower pump assembly with wireline. 07:15 08:30 1.25 85 85 COMPZ RPCOh OTHR P Halliburton wireline run the D&D stinger, 2-7/8" Dart check valve, 2-7/8" spacer pipe Kobe Knock out, D& D packoff assembly. Fili tubing. Test to 1000 psi f/ 15 min. Set Siip stop. Monitor weil. 08:30 08:45 0.25 85 85 COMPZ RPCO OTHR P RD halliburton Slickline unit. 08:45 12:00 3.25 85 85 COMPZ RPCOh PULD P Make up motor, Upper & lower tandem, Check rotation of motor & pump components with tubing crossover.Good free movement.Fill Motor, and sea! sections. Fiil Bearing XO. Attach ESP cable & control line. Perform olari test. 12:00 14:30 2.50 85 85 COMPZ RPCOh PULD P Continue fill Motor, and seal sections. Fill Bearing XO. Attach ESP cable 8~ control line. Perform polarity test. Monitor well through trip tank. No Iosses. 14:30 18:00 3.50 85 3,290 ~ COMPZ RPCOti RCST P Held PJSM with crew & Baker reps.Discuss safety & hazard recognition issues. Discuss running procedure,and positioning of clamps. Trip in hole with 4 1/2" production tubing installing Cannon Clamps on every collar. Perform megger test every 10 stands. Run to 3290'. Record T&D parameters as per rig engineer. Observed proper displacement in hole. Crew change . • 06/19/2007 18:00 22:45 4.75 3,290 7,200 COMPZ RPCOh RCST P Continue trip in hole with 4 1/2" production tubing from 3290' - 7231' ' installing Cannon Clamps on every collar. Perform megger test every 10 stands. record T&D parameters as per rig engineer. Observed proper dis lacement in hole. 22:45 23:15 0.50 7,200 7,200 COMPZ RPCOA RCST P Make up vetco gray hanger with landin 'oint. 23:15 00:00 0.75 7,200 7,200 COMPZ RPCOh OTHR P Install penetrator sub in hanger. Rig up to splice ESP cable as per Weatherford, and Baker re s. 06/20/2007 00:00 05:30 5.50 7,200 7,200 COMPZ RPCOh OTHR P Slice ESP cable as per Baker centrilift . rep. Attach ESP cable to pentrator, and clamp off same. Simops: Clean drip pan, Clean & clear floor of tools and euipment. prep cellar for nipple down. Perform Derrick Ins ection. 05:30 06:00 0.50 7,200 7,200 COMPZ RPCOh RCST P Perform Megger test on ESP line ~ before landing hanger. Drain BOP ' Stack, Blow down lines. Crew Chan e I~ 06:00 07:00 1.00 7,200 7,231 COMPZ RPCOh RCST P Land Tubing hanger on depth, and I RILDS. UP WT = 140K, SO V1/t = ', 100K. Rig up, test upper & lower seals '~ as per Vetco Gray rep to 5000 PSI. ' Back out & la down landin 'oint. I 07:00 07:15 0.25 7,231 7,231 COMPZ RPCOh OTHR P Install BPV. I 07:15 12:00 4J5 0 0 COMPZ RPCOti NUND P Finish blow down ali lines. Held PJSM ' with crew. Discuss safety & hazard , recognition issues. Discuss Nipple ' down BOP's. Nipple down BOP stack ' & lines. 12:00 14:30 2.50 0 0 COMPZ RPCO NUND P Nipple up Vetco Gray 5K Tree. Make up Lubricator. Pull BPV. Install TWC. Test void to 5000 PSI - 10 minutes. Fill tree with Diesel and test tree to 5000 PSI - 10 Minutes. pull TWC with Lubricator. SIMOPS: RU Little Red Services. Rig down Mudline & secondary Kill @ Pits / Sub interconnect. 14:30 15:00 0.50 0 0 COMPZ RPCOh SFTY P Heid PJSM with crew & Little Red reps. Discuss safety & hazard recognition issues. Discuss freeze protect procedure. Designate Spill Champion. r / • • 06/20/2007 15:00 18:00 3.00 0 0 COMPZ RPCOh FRZP P With Litle Red. test lines to 1000 PSI. ICP - 1 BPM - 200 PSi. Attempt to pump at higher rate observing fluid losses 20-40%. Continue maintain 1 BPM rate obtaining 1 for 1 returns pumping down annulus with pump pressure @ 475 PSI. Prepare rig floor for Skid, Shut down air, water, and steam to rig floor. Prep celiar for move. Lowwer strongbacks in pipe shed for floor skid. Note: Rig off of Hiline power 1540 HRS. Crew Chan e 18:00 20:30 2.50 0 0 COMPZ RPCOh FRZP P Continue pumping down annulus at 1 BPM with no losses. Pump pressure 475 - 500 PSI. Pump a total of 360 BBLS observing 6.9 PPG diesel returns with FCP - 2 BPM - 575 PSI. Shut in well. Record shut in pressure at OA = 120 PSI, IA = 350 PSI, & tubin at 350 PSI. 20:30 21:00 0.50 0 0 COMPZ RPCOh OTHR P Secure well. Rig down Little Red Services. Blow down, and rig down lines. Blow down Poorboy Degasser, flush same. Clean its. 21:00 22:00 1.00 0 0 COMPZ RPCOR OTHR P With lubricator. Install BPV as per Vetco rep. Rig down Lubricator. remove secondary annulus valves. Install Com anion flan es & valves. 22:00 00:00 2.00 0 0 DEMOB MOVE DMOB P Clean pits. Skid rig floor. Disconnect water, air, Hydraulic, and steam lines. Prep Pits, and sub complex for move. Rig released at Midnight for summer maintenance. ~ • 1J-158 'B' Sand Liner Detail We11: 1J-158 ~" . 4-1/2" Stotted and Blank Liner Date: 6/9/2007 ~~nc~coPhil[ips Rtaska, ina DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN .~; . _ . . : Page 1 LENGTH TOPS _ 7527.19 4" DP to Surface =_> 7527.19 ~ 7527.19 7527.19 Crossover 4" XT-39 Box x 3-1/2" IF Pin 2.99 7527.19 Liner Runnin Tool 3-1/2" IF" Does not sta in hole , 11.23 7530.18 "HRD" ZXP Liner Top Packer 5.50" X 7.63" 19.01 7541.41 "RS" Packoff Seal Nipple 5.5" (4.88" ID x 6.04" OD) 2.85 7560.42 FlexLock Liner Hanger (4.86" ID x 6.59" OD) 9.82 7563.27 190-47 Casing Seal Bore Ext. 4.75"ID x 6.05" OD 20.23 7573.09 XO Bushing 3.92" ID, 5.97" OD 1.39 7593.32 Pup Jt. - 4-1/2", 12.6 ppf, L-80, BTC 3.85 7594.71 ~ts 103 to 10 7 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 296.61 7598.56 ,1ts 84 to 102 19 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 801.76 7895.17 .lts 7s to 83 6 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 257.00 8696.93 ,lts 2s to 77 50 Jts 4-1/2",19.6 ppf, L-80, B~C Slotted Casing 2135.37 8953.93 ~ts 25 to 27 3 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 122.28 11089.30 .lts 15 to 24 10 Jts 4-1/2",11.6 ppf, L-80, BTC Slotted Casing 414.76 11211.58 .lts 10 to 14 5 Jts 4-1/2", 11.6 ppf, L-80, BTC Blank Casing 214.27 11626.34 .lts 1 to 9 9 Jts 4-1/2",11.6 pPf, L-80, BTC Slotted Casing 373.36 11840.61 4-1/2", 11.6 ppf, L-80, BTC Blank Ca~ing 43.35 12213.97 4-1/2" BTC Silver Bullet Float Shoe 1.68 12257.32 Btfm of Tait =_> 12259.00 TD 6 3/4" hole @ 12,268' MD / 3,300' TVD 4-1/2" Shoe @ 12,259' MD / 3,300' ND Intermediate 7- 5l8 Shoe @ 7,890' MD/ 3,323' TVD Total Parts used: 96 Spirogliders Run 1 spiroglider per jt floating f/ Jt#1 thru Jt#102 (4.5" X 6.5") Installed Torque rings in # 70 Thru #109 Total of 40 DO NOT RUN SPIROGLIDERS ON CONSTRICTOR JOINTS Total of 6 Constrictor Packers ran @ 91838', 11646', 11196', 11087', 8946', 8694'. Ran total of 22 jts Blank= 935.19' and 88 jts Slotted= 3725.25' , Slots are Up Wt 220K w/ (32) 2.5" long x.125" @ 4 Circumferential adjacent rows, 3" Centers Dn Wt 95K staggered 18 deg., 3 ft. non-slotted ends Block Wt 70K Used Run-N-Seal thread compound on all connections. Drifted casing to 3.875" w/ feflon rabbit. Supervisors: Mike Thornton / Granville Rizek ~ ~ IVIEMORANDl1M State of Al~ska s4laska Oi6 and Gas Conservation Commission TO: Jim Regg ~~~~ ~~4,~~; ~ DATE: May 28> 2007 P. I. Supervisor ~i FROM: Bob Noble Petroleum Inspector SUBJECT: Cement Top Job CPA, KRU 1 J-158 PTD 207-054 Mav 28, 2007: Fred Herbert called telling me that they did not get cement to surface on the surface pipe cement job on well KRU 1 J-158 and that they would be doing a top job. I witnessed the rig run 510' of 1" tubing (conductor depth is 80'). Schlumberger pumped 53 bbl's of water followed by 10.7# cement. They got cement to surface at 63 bbl's. They stopped pumping cement when it got to weight (10.7#), for a total of 79 bbl's of cement pumped. Summarv: I witnessed them run 510' of 1" tubing and the pumping of 79 bbl's of cement. I saw the cement come to surface and that it weighed 10.7#. Attachments: none Confidential 2007-0528_KRU_1J-1~8_surf csg_topjob_bn.doc ~ ~ 4 ~~~ r~,. ~.~ ~: ~ ~ ~`~~°~, ~~ .~~ ~~~~ ~t ~. ~ ~~~,~~ ~~. ~..~ ~ '~ ~ a'~`t . ~ t.r t ~ ~ ..,~ _ ~,~ ~ ~..~ c ~~ ~..~ ~ AL~S~iA ~IL ~1~TD Gr~S COI~TSERQA7`I011T COl-II~IISSIOI~T Randy Thomas Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 SARAH PAUN, GOVERNOR 333 W. 7thAVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, West Sak Oil Pool, 1J-158 ConocoPhillips Alaska, Inc. Permit No: 207-054 Surface Location: 2056' FSL, 2250' FEL, SEC. 35, T11N, R10E, UM Bottomhole Location: 1533' FSL, 1864' FEL, SEC. 3, T10N, R10E, UM Dear Mr. Thomas: Enciosed is the approved application for permit to drill the above referenced development 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. 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 petroleum field inspector at (907) 659-3607 (pager). Sincerel Dan T. Seamount Commissioner DATED this ~d day of April, 2007 cc: Department of Fish 8v Game, Habitat Section w/ o encl. Department of Environmental Conservation w/ o encl. • • ~ ~onoco h ~ I I i s p Alaska Post OfFce Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone(907)265-6830 Email: Randy.L.Thomas@conocophillips.com April 24, 2007 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Applications for Permit to Drill, West Sak Producer, i]-158, 1J-158 Li Dear Commissioners: ~~~~~v~~ AI~~ 2 5 20~7 ~{asi~a'Jil ~C Gas Cons. Co+runission Anchorage ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore producer well, a horizontal t well in the West Sak "B" and'~D" sands. The main bore of the we~l will be designated 1J-158, and the lateral bore of the well will be designated iJ-158L1. ° Please find attached for the review of the Commission forms 10-401 and the information required by 20 ACC 25.005 for each of these well bores. The expected spud date of 1J-158 is May 15, 2007. If you have any questions or require any further information, please contact Dennis Hartwig at 265-6862. Sincerely, ~, ~ ~ v~.:~-------_ Randy Thomas Greater Kuparuk Area Drilling Team Leader ~ STATE OF ALASKA • ~ ALASKA OIL AND GAS CONSERVATION COMMISSION '--(~.3v PERMIT TO DRILL 20 AAC 25.005 ~~ ~~ivED k~'~; ~ ~ ZQ~7 ~,~~~ka ~~i F~ Gas Cons. Comm-ssion AnrhnraeP_ ____ 1a. Type of Work: Drill ^~ / Re-drill ^ Re-entry ^ 1b. Current Well Class: F~cploratory Development Oil Q - Stratigraphic Test ^ Service ^ Development Gas ~ Multiple Zone^ Single Zone ~ 1c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 ' 11. Well Name and Number: 1J-158 ~ 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 12231' ` ND: 3300' ° 12. Field/Pool(s): Kuparuk River Field 4a. Location of Well (Governmental Section): Surtace: 2056' FSL, 2550' FEL, Sec. 35, T11N, R10E, UM ~ 7. Property Designation: ADL 25660, 25661, 25663 West Sak Oil Pool , Top of Productive Horizon: 433' FSL, 2257' FEL, Sec. 34, T11 N, R10E, UM 8. Land Use Permit: ALK 470, 471, 472 13. Approximate Spud Date: 5/15/2007 Total Depth: ~ 1533' FSL, 1864' FEL, Sec. 3, T10N, R10E, UM ' 9. Acres in Property: 2560 14. Distance to Nearest Property: < 1 mile 4b. Location of Well (State Base Plane Coordinates): SurfaCe: x- 558659 ' y- 5945867 ~ Zone- 4 10. KB Elevation ~~'~d(~L. (Height above GL): 4O' RKB V f et ~, 15. Distance to Nearest well within Pool: 1J-168L2 , 1024' - 16. Deviated wells: Kickoff depth: 300 ~ ft. Maximum Hole Angle: 96° de9 17. Maximum Anticipated Pressures in psig (see 2o AAC 25.035) Downhole: 1567 psig •- Surface: 1201 psig ' 18. Casing Program S ifi ti Setting Depth Quantity of Cement Size peC Ca ons Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD ND MD ND (including stage data) 42" 20"x34" 94# K-55 Welded 80' 28' 28' 121' - 121' 260 cf ArcticCrete 13.5" 10.75" 45.5# L-80 BTC 3393' 28' 28' 3393' - 2152' ~ 590 sx AS Lite, 180 sx DeepCRETE 9.875" 7.625" 297# L-80 BTCM 8023' 28' 28' 8023' - 3324' 380 sx DeepCrete 6.75" 4.5" 11.6# L-80 BTC 4682' 7549' 3261' 12231' - 3300' - slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Tota! Depth MD (ft): Total Depth ND (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth ND (ft): Junk (measured) Casing Length Size Cement Volume MD ND Cond uctor/Structu ral SurFace Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee Q BOP Sketch Drilling Program ~ Time v. Depth Plot ~ Shallow Hazard Analysis ~ Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q/ 20 AAC 25.050 requirements Q 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. COnteCt Dennis Hartwig @ 265-6862 Printed Name Randy Thomas ritie Drilling Team Leader Signature ~'~~` ` Phone t~ ~ ~,~ 5~ Date ~ t~~ Y~V h n All k Commission Use Only Permit to Drill Number: ~C.~ ~"~'J ~ API Number: G~ ~/ /~~ 50- C%~~'-! ^ ~ ~~`J f~ "~--C...; Permit Ap roval Date: ~ ~ See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained in shales: Q" Samples req'd: Yes ^ No Q Mud !og req'd: Yes ^ No [v~'~ Other: ~~~ ~S ~ i?~~'~.~~..}- H2S measures: Yes ~ No [~` Directional svy req'd: Yes [] No ^ 3G APPROVED BY THE COMMISSION / DATE: , COMMISSIONER Form 10-401 Revised 12/2005 ~ Submit in Duplicat ~ ~~~~7 ~~>/oJ ~~ ~~? -1 tion for Permit to Drill, WeA 1J-158 • Revision No.O Saved: 23-Apr-07 Permit It - West Sak Well #1J-158 Producer •~~~~ ~.. „ Application for Permit to Drill Document .~,,~, II~'It~ ~II IIAax~mia~ we~~ ~v~u~ Table of Contents 1. Well Name ................................................................................................................. 2 Requirements of 20 AAC 25.005 (fl ....................................................................................................... 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 ........................................... 4 Requirements of 20 AAC 25.005 (c)(5) .................................................................................................. 4 6. Casing and Cementing Program ............................................................................ 4 Requirements of 20 AAC 25.005(c)(6) ................................................................................................... 4 7. Diverter System Information ................................................................................... 4 Requirements of 20 AAC 25.005(c)(7) ................................................................................................... 4 8. Drilling Fluid Program ............................................................................................. 4 Requirements of 20 AAC 25.005(c)(8) ................................................................................................... 4 Surface Hole Mud Program (extended bentonite) .................................................................................. 5 Intermediate Hole Mud Program (LSND) ............................................................................................... 5 Lateral Mud Program (MI VersaPro Mineral OilBase) ........................................................................... 5 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 ~ ~ ~ ~ ~ ~ ~ ~ 1J-158 PERMIT IT Page 1 of 8 Printed.~ 23 Apr-07 ~ Ap~tion for Permit to Drill, Well 1J-158 Revision No.O Saved: 23-Apr-07 12. Evidence of Bonding ............................................................................................... 6 Requirements of 20 AAC 25.005 (c)(12) ................................................................................................ 6 13. Proposed Drilling Program ..................................................................................... 6 Requiremenfs of 20 AAC 25.005 (c)(13) ................................................................................................ 6 14. Discussion of Mud and Cuttings Disposal and Annular Disposal ....................... 7 Requirements of 20 AAC 25.005 (c)(14) ................................................................................................ 7 15. Attachments ............................................................................................................. 8 Attachment 1 Directional Plan ................................................................................................................ 8 Attachment 2 Drilling Hazards Summary ............................................................................................... 8 Attachment 3 Cement Loads and CemCADE Summary ....................................................................... 8 Attachment 4 Well Schematic ............................................................................................................... 8 Attachment 5 1/4 Mile Radius Effect for Injector ... ...................................................................8 1. Well Name Requirements of 20 AAC 25.005 (fl Each well must be identified by a unique name designated by the operator and a unique API number assigned by the commission under 20 AAC 25.OS'0(b). For a well with multiple well branches, each branch must similarly be identiFed by a unique name and API number by adding a su~x to the name designated for the well by the operator and to the number assigned to the well by the commission. The well for which this Application is submitted will be designated as 1J-158. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commrssion and identiFed in the application: (2) a plat identifyinct the property and the property's owners and showing (A)the coordinates of the proposed location of the well at the surface, at the top of each objective formation, and at total depth, referenced to governmenta! section lines. (8) 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 de~pth of the well at the top of each objective formation and at total depth; Location at Surface 2 056' FSL, 2 550' FEL, Section 35, T11N, R10E ~ ASP Zone 4 NAD U Coordinates ~ RKB Elevation 121.0' AMSL Northings: 5,945,867 ' Eastings: 558,659 Pad Elevation 81.0' AMSL Location at Top of Productive Interval West Sak "B" Sand 433' FSL, 2,257' FEL, Section 34, T11N, R10E ~ ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 8,023 Northings: 5,944,207 Eastings: 553,687 Toral Vertical De th, RKB: 3,324 Total Vertical De th, SS: 3 203 Location at Total De th 1 533` FSL, 1,864' FEL, Section 03, T10N, R10E ASP Zone 4 NAD 27 Coordinates Measured De th, RKB: 12 231 - Northings: 5,940,031 Eastings: 554,116 Total Vertical De th, RKB: 3,300 ~ Total Vertical De th SS: 3 179 1J-158 PERM/T IT Page 2 of 8 Printed: 23-Apr-07 ~~~'~~~~~.~~~.~, 1~_J and (D) other information required by 20 AAC 25.050(b); ~ation for Permit to Drill, Well 1 J-158 Revision No.O Saved: 23-Apr-07 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated, the application for a Permit to Drill (Form 10-401) must (1) include a plat drawn to a suitable scale, showing the path of the proposed wellbore, induding all adjacent wellbores within 200 feet of any portion of the proposed well; Please see Attachment 1: Directional Plan and (2) for all wells within 200 feet of the proposed weilbore (A) list the names of the operators of those wells, 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 (e) state that the applicant is the only affected owner. The Applicant is the only affected owner. 3. Blowout Prevention Equipment Information Requirements of 20 AAC 25.005(c)(3) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (3) a diagram and description of the blowout prevention equipment (BOPE) as required by 20 AAC 25.035, 20 AAC 25.036, or 20 AAC 25.037, as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1J-158. For all operations the stack will be equipped with 3-1/2" to 6" variable bore rams in the uppermost ram cavity, blind rams in the middle cavity, and 7-5/8" rams in the lowermost cavity. See attached diagram entitled ~~Doyon 15 West Sak 2004 3ksi BOP Configuration" for clarification. Upon initial nipple up, and at intervals of no more than 14 days thereafter, a test plug will be set below the lowermost rams, the annular preventer will be tested to 1,500 psi and the blind rams and upper rams will be tested to 3,000 psi. (This test will test the shell and end connections of the lowermost ram). The lowermost rams will be closed and tested to 3,000 psi on a 7-5/8" OD. 4. Drilling Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for a Permit to Dri/l must be accompanied by each of the following items, except for an item a/ready on fi/e with the commrssion and identified in the application: (4) information on drilling hazards, induding (A) the maximum downhole press~re that may be encountered, criteria used to determine if, and maximum potential surface pressure based on a methane gradient; The expected reservoir pressures in the West Sak sands in the 1J area vary from 0.44 to 0.47J psi/ft, or 8.5 to 9.0 ppg EMW (equivalent mud weight). These pressures are predicted based on actual bottom hole pressure data from Nearby West Sak wells The maximum potential surface pressure (MPSP) based on the above maximum pressure gradient, a methane gradient (0.11), and the deepest planned vertical depth of the West Sak B sand formation is 1,201 psi, calculated thusly: MPSP =(3,335 ft ND)(0.47 - 0.11 psi/ft) = i,201 psi .~ (8) data on potential gas zones; The well bore is not expected to penetrate any gas zones. and (C) data concerning potential causes of ho(e problems such as abnormally geo-pressured strata, lost circulation zones, and zones that have a propensity for differential sticking; Please see Attachment 2: 1J-158 Drilling Hazards Summary. ~ 1J-158 PERMIT /T Page 3 of 8 Printed: 23-Apr-07 ~ t ~~~~~r~6..• u A~tion for Permit to Drill, Well 1J-158 Revision No.O Saved: 23-Apr-07 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(5) An application for a Permit to Drill must be accompanied by each of the fo/lowing items, except for an item already on file with the commission and identified in the application: (5) a description of the procedure for conducting formation integrity tests, as required under 20 AAC 25.030(~; 1.7-158 will be completed with 7-5/8" intermediate casing landed at the top of the West Sak 6 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. 6. Casing and Cementing Program Requirements of 20 AAC 25.005(c)(6) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and ide~~tified in the application: (6) a complete proposed casing and cementing program as required by 20 AAC 25, 030, and a description of any slotted liner, pre- perforated liner, or;screen to be instal~~ '~ _ `~ Casing and Cementing Program See also Attachment 3: Cement Summary Hole Top Btm Csg/Tbg Size Weigh Length MD/'TVD MD/TVD OD in (in t/bfft Grade Connection ft ft ft Cement Pro ram 20 x 34 42 94 K55 Welded 80 28 / 28 80 / 80 Cemented to surFace with 260 cf ArcticCRETE BTC Cemented to Surface with 10-3/4 13-1/2 45.5 L-80 special 3,393 28 / 28 3,393 /2,152 590 sx ASLite Lead, drift 180 sx DeepCRETE Tail Cement Top planned @ 7-5/8 9-7/8 29.7 L-80 BTCM 8,023 28 / 28 8,023 / 3,324 4,975' MD / 2,4so' ND. Cemented w/ 380 sx Dee CRETE 4-1/2 6-3/4" B Sand 11.6 L-80 BTC 4,682 7,549 / 12,231 / 3,300 Slotted- no cement SlOtted Lateral (1J-158) 3 1 6-3/4" D Sand 11.6 L-80 BTC 4,776 7,449 / 12, 25 / 3,228 Slotted- no cement slotted Lateral (1J-158 li) 3 250 4 1/2 NA 12.6 L-80 IBTM 7,350 28 /28 7,350 / 3,110 Production Tubing tubin # 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and ide,~tified in the application: (7) a diagram and a'escription of the diverter system as required by 20 AAC 25.035, unless this requirement is waived by the commission under 20 AAC 25.035(h)(2); A 21-1/4", 2000 psi annular with a 16" diameter diverter line will be the diverter system used in the drilling of iJ-158. Please see diagrams of the Doyon 15 diverter system on file with the Commission. 8. Drilling Fluid Program Requirements of 20 AAC 25.005(c)(8) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (8) a drilling fluid program, including a diagram and description of the drilling fluid system, as required by 20 AAC 25.033; Drilling will be done with muds having the following properties over the listed intervals: 1J-158 PERMIT IT Page 4 of 8 ~ ~ ~ ~ ~ ~~~ ~~ ~ ~ Printed: 23-Apr-07 ~ Surface Hole Mud Program (extended bentonite) ~ation for Permit to Drill, Well 1J-158 Revision No.O Saved: 23-Apr-07 S ud to Base of Permafrost Base of Permafrost to 10-3/4" Casin Point Initia/ Va/ue Final Value Initial Value Fina/ Va/ue Density (ppg) 8,9 9,2 9.5 9.6 Funne/ Viscosity 150 250 200 300 (seconds Yield Point 50 70 30 50 (cP) P/astic Viscostiy 20 45 15 20 Ib/100 s PH 8.5 9.0 8.5 9.0 AP/ Filtrate NC 8 0 5 0 7 0 (cc / 30 min)) . . . *9.6 ppg if hydrates are encountered ~' Intermediate Hole Mud Program (LSND) 10-3/4" Csg Shoe to 7-5/8" Csg Point Value Density (ppg) 8.8 - 8.9 Funnel Viscosity 45-60 seconds) Plastic Viscostiy 12 - 18 (Ib/100 s fl Yield Point 26 - 35 (cP AP/ Filtrate 4 - 6 (cc / 30 min) Chlorides (mg/I) <500 pH 9.0 - 9 S MBT <20.0 ~ Lateral Mud Program (MI VersaPro Mineral Oil Base) A/B/D sand laterals Value Density (ppg) 8~4 or as needed ~ Plastic Viscostiy (Ib/100 s 12 - 19 Yield Point (cP) ~ $ _ 28 Oil / Water Ratio 80 / 20 Electrical >600 Stabilit 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. 9. Abnormally Pressured Formation Information Requirements of 20 AAC 25.005 (cJ(9) An application for a Permit to Drill must be accompanied by each of the following items, except for an item already on file with the commission and identified in the application: (9) for an exploratory or stratigraphic test well, a tabulation setting out the depths of predicted abnormally geo-pressured strata as required by 20 AAC 25.033(~; 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 Drill must be accompanied by each of the following items, except for an item already on file with the commission and identrfied in the application: (10) for an exploratory or stratigraphic test well, a seismic refraction or reflection analysis as required by 20 AAC 25.06i (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 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: 1J-158 PERMIT IT Page 5 of 8 ~ ~ ~ ~ ~ ~ Pnnted: 23-Apr-07 Q ~ ~~ A~tion for Permit to Drill, Well 1 J-158 Revision No.O Saved: 23-Apr-07 (11) for a well drilled from an offshore platform, mobile bottom-founded structure, jack-up rig, or floating drilling vessel, an anatysis of seabed conditions; as required by 20 AAC 25.061(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 Permit 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 app~ication: (12) evidence showing that the requirements of 20 AAC 25.025 {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 4, Well Schematic. 1. Excavate cellar, install cellar box, set and cement 20" x 34" insulated conductor to +/- 121' RKB. Install landing ring on conductor. 2. Move in / rig up Doyon Rig 15. Install 21-1/4" Annular with 16" diverter line and function test. ~ 3. Spud and directionally drill 13-1/2" hole to casing point at +/- 3,393' MD / 2,152' ND as per directional plan. Run MWD tools as required for directional monitoring. 4. Run and cement 10-3/4", 45.5#, L80, BTC casing to surface. Displace cement with mud and, pressure test casing to 2500 psi for 30 minutes and record results. Perform top job if required. 5. Remove diverter system, install and test 13-5/8" x 5,000 psi BOP's as described above in Section 3 above and test to 3,000 psi (annular preventer to 1500 psi). Notify AOGCC 24 hrs before test. 6. PU 9-7/8" bit and 6-3/4" drilling assembly, with MWD, LWD & PWD. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar. 7. Drill out cement and between 20' and 50' of new hole. Perform formation integrity test to leak off, recording results. (ECD's modeled to be less than 11.0 ppg) 8. Directionally drill to 7-5J8" casing point at 8,023' MD / 3,324' TVD, the prognosis top of the A2 sand. 9. Run 7-5/8", 29.7# L80, BTC Mod casing to surface. Pump cement and displace with mud (top of cement to be 4,975' MD / 2,590' TVD if Ugnu C formation is oil bearing. Top of cement to be 500 feet (MD) above shallowest oil bearing sand.). Pressure test casing to 3,000 psi for 30 minutes and record results. 10. Install wellhead x 7-5/8" packoff and test to 5000 psi. 11. Flush 10-3/4" x 7-5/8" annulus with water, followed by diesel. 12. PU 6-3/4" PDC Bit and 4-3/4" drilling assembly, with MWD, and LWD logging tools. RIH, clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar 13. Drill out cement and between 20' and 50' of new hole. Displace hole to lateral drilling mud. Perform formation integrity test to leak off, recording results. (Expected ECD's in 6-3/4" lateral modeled to be less than 12.5 ppg). 14. Directionally drill 6-3/4" hole to TD at +/- 12,231' MD / 3,300' ND as per directional plan. 15. POOH, back reaming out of lateral to 7-5/8" shoe. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 16. If injector, RU and run the USIT log from the shoe of the 7 5/8' casing to the shoe of the 10 3/4" casing. 1J-158 PERM/T /T Page 6 of 8 ~ ~~ Printed:23-Apr-07 ~~ ~~'~~~~~ ~ tion for Permit to Drill, Well 1 J-158 Revision No.O Saved: 23-Apr-07 17. PU and run 4-1/2" slotted liner. 18. Land liner, set liner hanger @+/- 7,549' MD / 3,261' TVD. POOH. ~~ ~`S ~ Note: Remaining operations are covered under the i)-158L1 Application for Permit to Drill, and are provided here for information only. 19. Run and set Baker WindowMaster whipstock system, at window point of +/-7,449' MD / 3,250' IVD, the top of the B sand. 20. Mill 6-3/4" window. POOH. 21. Pick up 6-3/4" drilling assembly with LWD and MWD and PWD. RIH. 22. Drill to TD of D sand lateral at +/- 12,225 MD / 3,228' TVD, as per directional plan. 23. POOH, back reaming out of lateral to window. TIH to bottom & displace to solids-free oil based mud. POOH on elevators. 24. PU and run 4-1/2" slotted liner. 25. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 26. RIH, until liner hanger is just above window. Orient hanger to window and land hanger. 27. Release hanger running tool. POOH. 28. POOH, laying down drill pipe as required. 29. PU ESP completion with with backup gaslift as required and RIH to depth. Land tubing. Set BPV. 30. Nipple down BOPE, nipple up tree and test. Pull BPV. 31. Freeze protect well with diesel. 32. Set BPV and move rig off. 33. Rig up wire line unit. Pull BPV. 34. Circulate out well with diesel through the ESP 35. Set gas lift valves in mandrels. Operate well on gas lift until ESP facilities are ready. 36. Replace gas lift valves with blank dummy valves. 37. Place well on production with ESP. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) 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 identifred in the application: (14) a general descrrption of how the operator plans to dispose of driUing mud and cuttings and a statement of whether the operator intends to request authorization under 20 AAC 25.080 for an annular disposal operation in the well.; Waste fluids generated during the drilling process will be disposed of either by pumping authorized fluids ~ into a permitted annulus on 1J 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 lJ 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. 1J-958 PERMIT lT Page 7 of 8 Printed: 23-Apr-07 ~ ~r ~~~~~~°~~.~_~ • A~tion for Permit to Drill, Well 1 J-158 Revision No.O Saved: 23-Apr-07 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 Cement Loads and CemCADE Summary Attachment 4 Well Schematic Attachment 5% Mile Radius Scan 1J-158 PERM/T /T Page 8 of 8 Printed: 23-Apr-07 ~~~~~°~;~ r~ ~ ~ ; ~ ~ ~ • ConocoPh ~ I I ~ ps Alaska ~ Plan: 1 J-158 (wp09) Sperry Drilling Services Proposal Report - Geographic 10 April, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-158 - Slot 1J-158 1J-158 Local Coordinate Origin: Viewing Datum: TVDs to System: North Reference: Unit System: Centered on Well Plan 1J-158 - Slot 1J-158 D15 (40+g1) @ 121.OOft (D15 (40+g1)) N - True API - US Survey Feet ' L1 ~ Sperry Drilling gervic~s ~~~~~~~~~~._ ~ ~ MA4LV@l.tqTON O~MMnO w4 P....erm~ebn . SHL: 2056' FSL, 2550' FEL - Sec3&T11 N-R10E 10d 7000 7500 -anosF---------- - ~50o I _ 7~ _ ' ' _ _ _ _ _ _ _ _ _ _ c ?Opp BHL ~ 12231' MD, 3300' ND: 1533' FSL, 1864' FEL - Sec03T10N-R10E ~ 10 3l4" . -~„t------,r- ~----BeginPump7angent80°Inc@7249'MD.3214'NQ----------------------------------,--------------------- 00~000 . i i ° _______________Y-EndPumpTangent~7449'MD.3250'ND__________________________~ -~~~.-,,..~----- ~- , r-------------------- t 3`sOp 7 5/8" Casing 8024' MD, 3324' ND: 433' FSL, 225T FEl - Sec34-T11 N-R10E ~ <00 0 45^_,~O ~3• o ~ 3 ,o -_;~^~s---- --~ --g------ ----- ---------,r-------- -- ----- --------------------- ~"J _~~n~~a----- - - - -a~-- ----~~------ - -/=-- -----------------------------'------------------------ ~ _ _ ' ~9~ ~ _ ' _ _ ' _ _ _ _ _ ~ _ ~ _ ~ ~ _ _ ' ' ' _ _ _ ' _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ o_ _ _ _ _ _ ' _ _ _ _ _ _ _ o _ ~ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ' _ _ _ _ _ ~ 7 O ~~ _ ` - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ _ N -KiJ_____ ~ ~ -~~___p____`_~_ ~ _ _ _ _ _ _ _ _ - _ ~ i nc O ,' _________~_ _ .~,r_I__17fSSL~1~pp3)____________ ~___ _________________ ____'_ ~200 _-.~.NSakD ro ,' ___'_ __________ ______«_' _ ______ ________-_____'___ ____ = ~ _ _ t = _ _ _ _ _ _ ' ,-^ws.:k~________________,' ~ ~ . -1Ji56(wp~09j ~ vVSaka a °o ~ $ i ~o ~o 3600 `'' 4 V2" 1 J-158 (wp09) Top D 7 5/8" ' I I 4~~~ I I ~ I 11~ I I i 1 I 4400 1J-158 L7 T2 (wp09) 1J-158 L1 T8 (wp09)~ 1J-158 L7 TB (wp09) i 1J-158 L1 T71 (wp09) i i 1J-158 L1 TS (wp09) 1J-158 L7 T7 (wP09) 1J-158 L1 T9 (wp09) 7J-15811 Toe (wP09) 1200 -800 -400 0 400 800 1200 1600 2000 2400 ^_200 3200 3600 4000 4400 4800 5200 5600 6000 6400 68~0 720~ 7600 8000 Vertical Section at 180.OOd (1000 Win) ~~I~INA~ MAlLiE3U RTON Project: Kuparuk River Unit WEI-LDETAQS: Plan 1J-158 __._.__.._.__.. o~,,,~,g ,,,d ...___.._ . F,,.,,,.~,o„ ite: 1 J Pad c~o~ e s~.oo E°a~"°u°" Well: Plan 1J-158 +N/-S +E-W Northing Fasting Longitude Slot Wellbore: Plan 1 J-158 0.00 0 00 5945617 85 1698690 83 70° 15' 44.686 N ' 979 W Plan: 1 J-158 (wp09) REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Plan iJ-158, True NoAh 2000 Venical (TVD) Reference: Doyon 75 (40+81) @ 121.OOft (DOyon 15 (40+81)) Measured Depth Reference: Doyon 15 (40+81) @ 121.OOft (DOyon 75 (40+81)) Calculation Method: Minimum CurvaWre 1750 1500 CASING DETAILS 1250 TVD TVDSS MD Size Na~ne 2151.72 2030.72 3393.43 10-3/4 10 3/4" 3323.87 ,202.87 8023.61 7-5/8 7 5/8" ]000 3300.17 3179.17 12230.63 4-1/2 41l2" S 750 rv 0 SOO rv a N d ry " N ~ 6 Q ~ 25~ a ~ / ~ N ~ o 0 - ° N o 1 2'r ~ " V ^ 0 a 22 10 3/4 250 a 3p~ ~ i ~ -250 i ~ ~Sd ~ ~ -500 ~ ~95d SFII,: 2056' FSL, 2550' FEL - Sec35-TI1N-RlOE -~so ~9od U-156 Becin Pump Tane t- ---- ° ' ' ' -- ge [nc @ 7249 MD, 3214 7 VD gin Pump Tangent 80 -1000 U-1~8 D Toplup0 ~ - - - - _ _ - 33~p -- -- End Pump Tangen[ @ 7449' MD, 3250' ND -1250 Isod -I500 7 5/8"- - - ---------- 7 5;8" Casing 80_'4' MD, 3324' ND~. 431' FSL, Z'_57' FEL - Sed4- TI I N-RI08 ~-1750 175d o -2000 O II-1~3B_T'_~~~p0 ---- ~-2250 llOd + ~-2500 0 z-2750 U-LS ~fB_B_CP~ i-'I 4 - - t l7td 3-30pp IJ-1S8'~iB B CP63-?1 03- - - O ~ -.i2$~ 174d -3500 1J-I~R\-0F3 f3 CP'. :-'I 4- - 175d -3750 179d ~0~ U-7 ~S ~IB B C'PS 3_21 i7 - -4250 -4500 t7-t5s \B B CP9?-_t G3 _ -4750 -5000 -5250 177d -550o i1-~~s~i[3 [a c~t~ii ,-,i r -5750 q ~~2~ I J-1$8 B Toe (wp0 )- - - - ~ - - - - - - - - - - - BHL @ 12231' MD, 3300' TVD-. 1533' FSL, 1864' FEL - Sec03-TI ON-RI OE ' -6000 i ~ ~ T M Azimuths to True North Magnetic North: 24.57° -6250 11-158 (wP09) Magnetic Field Strength:57564.9nT 6500 Dip Angle: 8075° - Date: 11 /18/2004 - Model: BGGM2006 -6750 -6000 -5750 -5500 -5250 -5000 -4750 -4500 -4250 -4000 -3750 -3500 -3250 -3000 -2750 -2500 -2250 -2000 -1750 -I500 -1250 -1000 -750 -500 -250 0 250 500 'I50 ]000 West(-)/East(+) (1000 ft/in) ~~!rl~!,~.L ConocoPhillips Alaska ~ Halliburton Company Compass Proposal Report - Geographic • . HA,LL! URTON 8p~rry Drilling Bervices . ~._ ~ Ku aruk River Llnit North Slope Alaska, United States :z~ ~' -. . . ~~~rue~4 w~-.-~-° - ww~aui .. . - ~u ,;~ ~s '~. 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 Audit Notes: Version: 12 Phase: PLAN Tie On Depth: ~ - ~ ~G ~ ~ _-_~ ~7~ ~ Ijk~,~ , ~ ~ = , - ~~ _ ~i 4di + i ~ i i i - ~i iG~ ~~i i = M - ~~<,;i!,!. _ .~.:, : ~~N, ~. 40.00 0.00 0.00 180.00 40.00 4/10/2007 9:22:34AM Page 2 of 10 COMPASS 2003.11 Build 48 .~~~~~•~~~,}~~ ?y...~~'~,~'. {~, 1?,.M Well Position +N/-S 0.00 ft Northing: 5,945,866.77 ft Latitude: 70° 15' 45.747" N +E/-W 0.00 ft Easting: 558,658.89 ft Longitude: 149° 31' 32.833" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 81.OOft ConocoPhiltips Alaska ~ ~ Halliburton Company Compass Proposal Report - Geographic t-~~LL~ec ~'oN Sperry Drilling Services -- 0.00 . 0.00 - _ 0.00 ~ _ 40.00 - ~ -81.00 - ~- . = 0.00 .00 ~ , 0.00 a _; 0.00 .00 - 0.00 300.00 0.00 0.00 300.00 179.00 0.00 0.00 0.00 0.00 0.00 0.00 702.06 10.05 277.00 700.00 579.00 4.29 -34.91 2.50 2.50 0.00 277.00 1,629.31 47.14 277.00 1,500.00 1,379.00 57.44 -467.77 4.00 4.00 0.00 0.00 1,729.31 47.14 277.00 1,568A2 1,447.02 66.37 -540.53 0.00 0.00 0.00 0.00 2,270.82 73.55 284.00 1,833.82 1,712.82 155.03 -998.03 5.00 4.88 129 14.88 2,338.02 73.55 282.32 1,852.85 1,731.85 169.71 -1,060.79 2.40 0.00 -2.50 -90.00 4,396.57 73.55 282.32 2,435.79 2,314.79 590.96 -2,989.61 0.00 0.00 0.00 0.00 6,964.02 74.06 194.00 3,151.79 3,030.79 -585.40 -4,882.46 3.30 0.02 -3.44 -89.65 7,194.03 79.71 188.79 3,203.99 3,082.99 -804.86 -4,926.57 3.30 2.45 -2.27 -42.58 7,249.31 79.71 188.79 3,213.86 3,092.86 -858.60 -4,934.88 0.00 0.00 0.00 0.00 7,449.31 79.71 188.79 3,249.59 3,128.59 -1,053.07 -4,964.94 0.00 0.00 0.00 0.00 7,575.58 79.71 185.00 3,272.15 3,151.15 -1,176.39 -4,979.86 2.95 0.00 -3.00 -90.00 7,822.23 84.75 179.03 3,305.51 3,184.51 -1,420.44 -4,988.37 3.15 2.04 -2.42 -50.00 8,022.23 84.75 179.03 3,323.81 3,202.81 -1,619.57 -4,985.00 0.00 0.00 0.00 0.00 8,298.04 93.05 171.76 3,329.11 3,208.11 -1,894.01 -4,962.86 4.00 3.01 -2.64 -41.36 8,344.05 93.05 171.76 3,326.66 3,205.66 -1,939.49 -4,956.27 0.00 0.00 0.00 0.00 8,389.58 91.23 171.75 3,324.96 3,203.96 -1,984.51 -4,949.75 4.00 -4.00 -0.01 -179.80 8,564.58 91.23 171.75 3,321.20 3,200.20 -2,157.66 -4,924.64 0.00 0.00 0,00 0.00 8,727.84 86.18 167.61 3,324.89 3,203.89 -2,318.15 -4,895.42 4.00 -3.09 -2.54 -140.69 8,839.06 86.18 167.61 3,332.30 3,211.31 -2,426.54 -4,871.61 0.00 0.00 0.00 0.00 8,976.06 91.11 170.00 3,335.55 3,214.55 -2,560.84 -4,845.03 4.00 3.60 1.75 25.90 9,126.06 91.11 170.00 3,332.64 3,211.64 -2,708.53 -4,818.99 0.00 0.00 0.00 0.00 9,203.73 91.81 171.39 3,330.66 3,209.66 -2,785.15 -4,806.43 2.00 0.90 1.79 63.20 9,410.51 91.81 171.39 3,324.13 3,203.13 -2,989.50 -4,775.48 0.00 0.00 0.00 0.00 9,659.19 91.13 173.78 3,317.74 3,196.74 -3,236.00 -4,743.40 1.00 -0.27 0.96 105.75 9,897.91 91.13 173.78 3,313.02 3,192.02 -3,473.27 -4,717.54 0.00 0.00 0.00 0.00 10,172.04 89.48 179.01 3,311.54 3,190.54 -3,746.75 -4,700.32 2.00 -0.60 1.91 107.48 10,395.33 89.48 179.01 3,313.55 3,192.55 -3,970.00 -4,696.46 0.00 0.00 0.00 0.00 10,835.07 88.14 174.82 3,322.66 3,201.66 -4,408.90 -4,672.81 1.00 -0.31 -0.95 -107.81 10,939.92 88.14 174.82 3,326.06 3,205.06 -4,513.26 -4,663.36 0.00 0.00 0.00 0.00 11,148.63 96.12 177.28 3,318.30 3,197.30 -4,721.15 -4,648.99 4.00 3.82 1.18 17.08 11,240.93 96.12 177.28 3,308.46 3,187.46 -4,812.83 -4,644.64 0.00 0.00 0.00 0.00 11,387.52 90.29 176.67 3,300.26 3,179.26 -4,958.91 -4,636.91 4.00 -3.98 -0.42 -174.02 11,937.52 90.29 176.67 3,297.48 3,176.48 -5,507.98 -4,604.97 0.00 0.00 0.00 0.00 12,035.48 89.31 176.69 3,297.82 3,176.82 -5,605.77 -4,599.30 1.00 -1.00 0.02 178.77 12,230.67 89.31 176.69 3,300.17 3,179.17 -5,800.62 -4,588.03 0.00 0.00 0.00 0.00 4/10/2007 9:22:34AM Page 3 of 10 COMPASS 2003.11 Build 48 ~"~~~1~~~,~1 ~ ~ -_ , - ;'~~~~~ ~ _ 1J-158'~~ 09 ~ ~~~~ - I ~ ~, ~ --- ~ -_ _ - , , ~~ ~~ ~, . ~ ~ ~ ,: ~' ~ +~~ ~ ~ - ~~ . /~ ~ ...-,,,,~~ ry k~ i~!... ~'~ ..ar,~,~6PA. _;::,-.-.. „~~x.lY~, ,-.--.z.... . ....... ..., ..,, ~ ~_ .~ .i~. .. ~~~. ~ ~, .,-.i __,.,,. `..,, ...._. 40.00 0.00 0.00 40.00 -81.00 0.00 0.00 5,945,866.71 558,658.89 ~ 0.00 0.00 ; SHL 2056' FSL, 2550' FEL - Sec35-T11N-R10E 100.00 0.00 0.00 100.00 -21.00 0.00 0.00 5,945,866.71 558,658.89 0.00 0.00 200.00 0.00 0.00 200.00 79.00 0.00 0.00 5,945,866.71 558,658.89 0.00 0.00 300.00 0.00 0.00 300.00 179.00 0.00 0.00 5,945,866.71 558,658.89 0.00 0.00 400.00 2.50 277.00 399.97 278.97 0.27 -2.17 5,945,866.96 558,656.72 2.50 -0.27 500.00 5.00 277.00 499.75 378.75 1.06 -8.66 5,945,867.71 558,650.23 2.50 -1.06 600.00 7.50 277.00 599.14 478.14 2.39 -19.46 5,945,868.95 558,639.41 2.50 -2.39 700.00 10.00 277.00 697.97 576.97 4.24 -34.56 5,945,870.68 558,624.30 2.50 -4.24 702.06 10.05 277.00 700.00 579.00 429 -34.91 5,945,870.72 558,623.95 2.50 -4.29 800.00 13.97 277.00 795.78 674.78 6.77 -55.14 5,945,873.05 558,603.71 4.00 -6.77 900.00 17.97 277.00 891.90 770.90 10.12 -82.44 5,945,876.19 558,576.38 4.00 -10.12 1,000.00 21.97 277.00 985.87 864.87 14.28 -116.33 5,945,880.09 558,542.46 4.00 -14.28 1,100.00 25.97 277.00 1,077.23 956.23 19.23 -156.64 5,945,884.72 558,502.12 4.00 -19.23 1,200.00 29.97 277.00 1,165.53 1044.53 24.95 -203.18 5,945,890.07 558,455.54 4.00 -24.95 1,300.00 33.97 277.00 1,250.34 1129.34 31.40 -255.73 5,945,896.11 558,402.95 4.00 -31.40 1,400.00 37.97 277.00 1,331.26 1210.26 38.56 -314.01 5,945,902.81 558,344.62 4.00 -38.56 1,500.00 41.97 277.00 1,407.88 1286.89 46.38 -377.76 5,945,910.14 558,280.82 4.00 -46.38 1,600.00 45.97 277.00 1,479.84 1358.84 54.84 -446.65 5,945,918.07 558,211.87 A.00 -54.84 1,629.31 47.14 277.00 1,500.00 1379.00 57.44 -467.77 5,945,920.49 558,190.73 4.00 -57.44 1,672.09 47.14 277.00 1,529.10 1408.10 61.26 -498.90 5,945,924.07 558,159.58 0.00 -61.26 Pfrost 1,700.00 47.14 277.00 1,548.08 1427.08 63.75 -519.21 5,945,926.41 558,139.25 0.00 -63.75 1,729.31 47.14 277.00 1,568.02 1447.02 66.37 -540.53 5,945,928.86 558,117.91 0.00 -66.37 1,800.00 50.56 278.17 1,614.52 1493.52 73.41 -593.28 5,945,935.49 558,065.11 5.00 -73.41 1,866.77 53.81 279.18 1,655.46 1534.46 81.38 -645.42 5,945,943.05 558,012.92 5.00 -81.38 K15 1,900.00 55.42 279.65 1,674.70 1553.70 85.81 -672.14 5,945,947.27 557,986.16 5.00 -85.81 2,000.00 60.30 280.97 1,727.88 1606.88 100.99 -755.42 5,945,961.80 557,902.78 5.00 -100.99 2,100.00 65.18 282.16 1,773.67 1652.67 118.82 -842.48 5,945,978.95 557,815.60 5.00 -118.82 2,200.00 70.08 283.26 1,811.72 1690.72 139.18 -932.65 5,945,998.60 557,725.27 5.00 -139.18 2,270.82 73.55 284.00 1,833.82 1712.82 155.03 -998.03 5,946,013.95 557,659.78 5.00 -155.03 2,300.00 73.55 283.27 1,842.08 1721.08 161.63 -1,025.23 5,946,020.33 557,632.54 2.40 -161.63 2,338.02 73.55 282.32 1,852.85 1731.85 169.71 -1,060.79 5,946,028.13 557,596.92 2.40 -169.71 2,400.00 73.55 282.32 1,870.40 1749.40 182.39 -1,118.86 5,946,040.36 557,538.75 0.00 -182.39 2,500.00 73.55 282.32 1,898.72 1777.72 202.85 -1,212.56 5,946,060.09 557,444.91 0.00 -202.85 2,600.00 73.55 282.32 1,927.03 1806.03 223.32 -1,306.25 5,946,079.82 557,351.06 0.00 -223.32 2,629.56 73.55 282.32 1,935.41 1814.41 229.37 -1,333.95 5,946,085.66 557,323.32 0.00 -229.37 T3 2,700.00 73.55 282.32 1,955.35 1834.35 243.78 -1,399.95 5,946,099.55 557,257.22 0.00 -243.78 2,800.00 73.55 282.32 1,983.67 1862.67 264.24 -1,493.65 5,946,119.29 557,163.37 0.00 -264.24 2,900.00 73.55 282.32 2,011.99 1890.99 284.71 -1,587.35 5,946,139.02 557,069.53 0.00 -284.71 3,000.00 73.55 282.32 2,040.31 1919.31 305.17 -1,681.05 5,946,158.75 556,975.68 0.00 -305.17 3,100.00 73.55 282.32 2,068.62 1947.62 325.64 -1,774.74 5,946,178.48 556,881.83 0.00 -325.64 3,200.00 73.55 282.32 2,096.94 1975.94 346.10 -1,868.44 5,946,198.21 556,787.99 0.00 -346,10 3,300.00 73.55 282.32 2,125.26 2004.26 366.56 -1,962.14 5,946,217.94 556,694.14 0.00 -366.56 4/10/2007 9:22:34AM Page 4 of 10 COMPASS 2003.11 Build 48 ~ ~ ~ ~ ti~.«+~ t I~~~~ a ~ ~4 ' . ~ ~-` Halliburton Company FIALLIBURTC?N ConocoPhill'~~S Compass Proposal Report - Geographic 5perry Drilling 8~rvice~ ConocoPhillips Alaska ~ i Halliburton Company Compass Proposal Report - Geographic ALLIBURT Sperry Drilling Services ~' ~ . 1 J-158 ! 09 ~~ , _ ~ ~~ ~ ~ ~ - ~ _ _ , ' ~ h - - - ~ . ~~ ~ .~ ' .~ ~ti ~~. ~ ,,. ~ ~~ G' G . 3,393.43 73.55 282.32 2,151.72 203072 385.68 -2,049.68 5,946,236.38 556,606.47 ~ 0.00 -385.68 Casing Pt - 10 3/4" 3,400.00 73.55 282.32 2,153.58 2032.58 387.03 -2,055.84 5,946,237.67 556,600.30 0.00 -387.03 3,500.00 73.55 282.32 2,181.90 2060.90 407.49 -2,149.54 5,946,257.40 556,506.45 0.00 -407.49 3,600.00 73.55 282.32 2,210.21 2089.21 427.95 -2,243.23 5,946,277.14 556,412.61 0.00 -427.95 3,700.00 73.55 282.32 2,238.53 2117.53 448.42 -2,336.93 5,946,296.87 556,318.76 0.00 -448.42 3,800.00 73.55 282.32 2,266.85 2145.85 468.88 -2,430.63 5,946,316.60 556,224.91 0.00 -468.88 3,900.00 73.55 282.32 2,295.17 2174.17 489.35 -2,524.33 5,946,336.33 556,131.07 0.00 -489.35 4,000.00 73.55 282.32 2,323.48 2202.48 509.81 -2,618.03 5,946,356.06 556,037.22 0.00 -509.81 4,100.00 73.55 282.32 2,351.80 2230.80 530.27 -2,711.72 5,946,375.79 555,943.38 0.00 -530.27 4,200.00 73.55 282.32 2,380.12 2259.12 550.74 -2,805.42 5,946,395.52 555,849.53 0.00 -550.74 4,300.00 73.55 282.32 2,408.44 2287.44 571.20 -2,899.12 5,946,415.25 555,755.69 0.00 -571.20 4,396.57 73.55 282.32 2,435.79 2314.79 590.96 -2,989.61 5,946,434.31 555,665.06 0.00 -590.96 4,400.00 73.55 282.20 2,436.76 2315.76 591.66 -2,992.82 5,946,434.98 555,661.84 3.28 -591.66 4,500.00 73.57 278.76 2,465.06 2344.06 609.11 -3,087.12 5,946,451.69 555,567.42 3.30 -609.11 4,600.00 73.59 275.32 2,493.32 2372.32 620.87 -3,182.30 5,946,462.71 555,472.16 3.30 -620.87 4,700.00 73.61 271.88 2,521.56 2400.56 626.89 -3,278.03 5,946,467.99 555,376.39 3.30 -626.89 4,800.00 73.63 268.44 2,549.75 2428.75 627.16 -3,373.96 5,946,467.51 555,280.48 3.30 -627.16 4,900.00 73.65 265.00 2,577.92 2456.92 621.68 -3,469.74 5,946,461.28 555,184.75 3.30 -621.68 5,000.00 73.67 261.56 2,606.05 2485.05 610.45 -3,565.02 5,946,449.32 555,089.56 3.30 -610.45 5,100.00 73.69 258.12 2,634.15 2513.15 593.53 -3,659.48 5,946,431.66 554,995.25 3.30 -593.53 5,200.00 73.71 254.68 2,662.22 2541.22 570.97 -3,752.75 5,946,408.37 554,902.16 3.30 -570.97 5,300.00 73.73 251.24 2,690.25 2569.25 542.85 -3,844.52 5,946,379.54 554,810.63 3.30 -542.85 5,400.00 73.75 247.80 2,718.25 2597.25 509.27 -3,934.44 5,946,345.26 554,720.98 3.30 -509.27 5,474.82 73.77 245.23 2,739.17 2618.17 480.64 -4,000.31 5,946,316.13 554,655.34 3.30 -480.64 Ugnu C 5,500.00 73.77 244.36 2,746.21 2625.21 470.35 -4,022.19 5,946,305.67 554,633.55 3.30 -470.35 5,600.00 73.79 240.92 2,774.14 2653.15 426.23 -4,107.46 5,946,260.89 554,548.63 3.30 -426.23 5,700.00 73.81 237.48 2,802.04 2681.04 377.07 -4,189.93 5,946,211.09 554,466.55 3.30 -377.07 5,800.00 73.83 234.04 2,829.91 2708.91 323.04 -4,269.32 5,946,156.45 554,387.60 3.30 -323.04 5,900.00 73.85 230.60 2,857.74 2736.74 264.34 -4,345.32 5,946,097.17 554,312.06 3.30 -264.34 6,000.00 73.87 227.16 2,885.54 2764.54 201.18 -4,417.68 5,946,033.46 554,240.20 3.30 -201.18 6,023.40 73.88 226.36 2,892.03 2771.03 185.78 -4,434.06 5,946,017.93 554,223.95 3.31 -185.78 Ugnu B 6,100.00 73.89 223.72 2,913.30 2792.30 133.79 -4,486.12 5,945,965.54 554,172.29 3.30 -133.79 6,200.00 73.91 220.28 2,941.03 2820.03 62.40 -4,550.40 5,945,893.66 554,108.57 3.31 -62.40 6,251.56 73.92 218.51 2,955.31 2834.31 24.12 -4,581.85 5,945,855.13 554,077.44 3.31 -24.12 Ugnu A 6,300.00 73.93 216.84 2,968.73 2847.73 -12.72 -4,610.29 5,945,818.08 554,049.28 3.30 12.72 6,400.00 73.95 213.40 2,996.39 2875.39 -91.31 -4,665.57 5,945,739.07 553,994.62 3.31 91.31 6,500.00 73.97 209.96 3,024.02 2903.02 -173.08 -4,716.04 5,945,656.91 553,944.79 3.31 173.08 6,600.00 73.99 206.52 3,051.62 2930.62 -257.75 -4,761.52 5,945,571.91 553,899.98 3.31 257.75 6,700.00 74.01 203.08 3,079.18 2958.18 -344.99 -4,801.83 5,945,484.36 553,860.35 3.31 344.99 6,747.81 74.02 201.44 3,092.34 2971.34 -387.53 -4,819.24 5,945,441.69 553,843.27 3.31 387.53 K13 6,800.00 74.03 199.64 3,106.71 2985.71 -434.51 -4,836.85 5,945,394.58 553,826.04 3.31 434.51 4/10r1007 9:22:34AM Page 5 of 10 COMPASS 2003.11 Build 48 ~ ~ ~ ~ j ~ ~ ~ ~ 6,900.00 74.05 196.20 3,134.20 3013.20 -525.98 -4,866.43 6,964.02 74.06 194.00 3,151.79 3030.79 -585.40 -4,882.46 7,000.00 74.94 193.17 3,161.40 3040.40 -619.11 -4,890.61 7,100.00 77.39 190.89 3,185.32 3064.32 -714.06 -4,910.83 7,194.03 79.71 188.79 3,203.99 3082.99 -804.86 -4,926.57 7,200.00 79.71 188.79 3,205.05 3084.05 -810.66 -4,927.47 7,249.31 79.71 188.79 3,213.86 3092.86 -858.60 -4,934.88 Begin Pum p Tangent 80° Inc @ 7249' MD, 321 4' ND - 1J-158 Begin Pump Tangent 7,300.00 79.71 188.79 3,222.92 3101.92 -907.89 -4,942.50 7,400.00 79.71 188.79 3,240.78 3119.78 -1,005.13 -4,957.53 7,424.15 79.71 188.79 3,245.09 3124.09 -1,028.61 -4,961.16 WSakD 7,449.31 79.71 188.79 3,249.59 3128.59 -1,053.07 -4,964.94 End Pump Tangent @ 7449' MD, 3250' ND 7,452.06 79.71 188.71 3,250.08 3129.08 -1,055.75 -4,965.36 1J-158 (wp09) Top D 7,500.00 79.71 187.27 3,258.64 3137.64 -1,102.46 -4,971.91 7,575.58 79.71 185.00 3,272.15 3151.15 -1,176.39 -4,979.86 7,600.00 80.20 184.40 3,276.40 3155.40 -1,200.36 -4,981.83 7,700.00 82.24 181.97 3,291.66 3170.66 -1,299.02 -4,987.31 7,721.17 82.67 181.46 3,294.44 3173.44 -1,320.00 -4,987.94 W Sak C 7,800.00 84.29 179.56 3,303.39 3182.39 -1,398.31 -4,988.64 7,822.23 84.75 179.03 3,305.51 3184.51 -1,420.44 -4,988.37 7,900.00 84.75 179.03 3,312.63 3191.63 -1,497.87 -4,987.06 7,993.61 84.75 179.03 3,321.19 3200.19 -1,591.07 -4,985.48 W Sak B- 1J-158 L1 MB CP2 3121t07 8,000.00 84.75 179.03 3,321.78 3200.78 -1,597.44 -4,985.37 8,022.23 84.75 179.03 3,323.81 3202.81 -1,619.57 -4,985.00 8,023.61 84.79 178.99 3,323.94 3202.94 -1,620.95 -4,984.97 7 5/8" Casi ng - 433' FSL, 2257' F EL - Sec34-T11 N-R10E - 7 5!8" 8,100.00 87.09 176.97 3,329.35 3208.35 -1,697.09 -4,982.29 8,120.29 87.70 176.44 3,330.27 3209.27 -1,717.33 -4,981.13 1J-158 L1 MB CP1 3t21/07 8,200.00 90.10 174.34 3,331.80 3210.80 -1,796.75 -4,974.72 8,298.04 93.05 171.76 3,329.11 3208.11 -1,894.01 -4,962.86 8,300.00 93.05 171.76 3,329.00 3208.00 -1,895.95 -4,962.58 8,344.05 93.05 171.76 3,326.66 3205.66 -1,939.49 -4,956.27 8,389.58 91.23 171.75 3,324.96 3203.96 -1,984.51 -4,949.75 8,400.00 91.23 171.75 3,324.73 3203.73 -1,994.82 -4,948.25 8,500.00 91.23 171.75 3,322.59 3201.59 -2,093.76 -4,933.91 8,564.58 91.23 171.75 3,321.20 3200.20 -2,157.66 -4,924.64 1J-158 L1 T2 (wp09) 8,600.00 90.13 170.85 3,320.78 3199.78 -2,192.67 -4,919.28 5,945,302.89 553,797.17 3.31 525.98 5,945,243.35 553,781.60 3.31 585.40 5,945,209.59 553,773.72 3.30 619.11 5,945,114.49 553,754.24 3.30 714.06 5,945,023.58 553,739.21 3.30 804.86 5,9~15,017.77 553,738.36 0.00 810.66 5,944,969.78 553,731.32 0.00 858.60 5,9A4,920.43 553,724.09 0.00 907.89 5,944,823.09 553,709.81 0.00 1,005.13 5,944,799.59 553,706.37 0.00 1,028.61 5,944,775.10 553,702.78 0.00 1,053.07 5,944,772.41 553,702.38 2.95 1,055.75 5,944,725.66 553,696.20 2.95 1,102.46 5,944,651.67 553,688.83 2.95 1,176.39 5,944,627.69 553,687.04 3.15 1,200.36 5,944,529.00 553,682.33 3.15 1,299.02 5,944,508.02 553,681.86 3.15 1,320.00 5,944,429.71 553,681.78 3.15 1,398.31 5,944,407.60 553,682.22 3.15 1,420.44 5,944,330.18 553,684.13 0.00 1,497.87 5,944,237.00 553,686.44 0.00 1,591.07 5,944,230.64 553,686.59 0.00 1,597.44 5,944,208.52 553,687.14 0.00 1,619.57 5,944,207.14 553,687.17 4.00 1,620.95 5,944,131.03 553,690.45 4.00 1,697.09 5,944,110.80 553,691.77 4.01 1,717.33 5,944,031.44 553,698.80 4.00 1,796.75 5,943,934.28 553,711.41 4.00 1,894.01 5,943,932.34 553,711.71 0.00 1,895.95 5,943,888.86 553,718.35 0.00 1,939.49 5,943,843.89 553,725.23 4.00 1,984.51 5,943,833.60 553,726.80 0.00 1,994.82 5,943,734.78 553,741.92 0.00 2,093.76 5,943,670.96 553,751.68 0.00 2,157.66 757.31 4.00 2,192.67 ~ 4/10/2007 9:22:34AM Page 6 of 10 COMPASS 2003.11 Build 48 ~ ~ ~ ~ ~ IF~~~ / Halliburton Company HALLI URTON COIlOCO~'11~~Ip5 Compass Proposal Report - Geographic q~as~ Sperry DrElling Services l~ COI'lOCO~'tiI11pS Alaska Halliburton Company Compass Proposal Report - Geographic . HALLISi.1RTCJN Sperry Driliing Sarvices 8,700.00 87.04 168.32 3,323.25 3202.25 -2,290.97 -4,901.22 5,943,537.85 553,776.14 4.00 2,290.97 8,727.84 86.18 167.61 3,324.89 3203.89 -2,318.15 -4,895.42 5,943,510.72 553,782.15 4.01 2,318.15 8,800.00 86.18 167.61 3,329.70 3208.70 -2,388.47 -4,879.97 5,943,440.53 553,798.14 0.00 2,388.47 8,834.49 86.18 167.61 3,332.00 3211.00 -2,422.08 -4,872.59 5,943,406.98 553,805.79 0.00 2,422.08 1J-158 L1 MB B Heel 3/21/U7 8,839.06 86.18 167.61 3,332.30 3211.31 -2,426.54 -4,871.61 5,943,402.53 553,806.80 0.00 2,426.54 8,900.00 88.37 168.67 3,335.20 3214.20 -2,486.11 -4,859.10 5,943,343.07 553,819.77 4.00 2,486.11 8,976.06 91.11 170.00 3,335.55 3214.55 -2,560.84 -4,845.03 5,943,268.45 553,834.42 4.00 2,560.84 9,000.00 91.11 170.00 3,335.08 3214.08 -2,584.41 -4,840.87 5,943,244.91 553,838.76 0.00 2,584.41 9,100.00 91.11 170.00 3,333.14 3212.15 -2,682.88 -4,823.51 5,943,146.60 553,856.89 0.00 2,682.88 9,126.06 91.11 170.00 3,332.64 3211.64 -2,708.53 -4,818.99 5,943,120.98 553,861.61 0.00 2,708.53 1J-158 L1 T5 (wp09) 9,200.00 91.78 171.32 3,330.78 3209.78 -2,781.47 -4,806.99 5,943,048.15 553,874.17 2.00 2,781.47 9,203.73 91.81 171.39 3,330.66 3209.66 -2,785.15 -4,806.43 5,943,044.47 553,874.76 2.00 2,785.15 9,300.00 91.81 171.39 3,327.62 3206.62 -2,880.29 -4,792.02 5,942,949.45 553,889.91 0.00 2,880.29 9,400.00 91.81 171.39 3,324.46 3203.46 -2,979.12 -4,777.05 5,942,850.76 553,905.65 0.00 2,979.12 9,410.51 91.81 171.39 3,324.13 3203.13 -2,989.50 -4,775.48 5,942,840.39 553,907.30 0.00 2,989.50 1J-158 L1 T6 {wp09) 9,500.00 91.57 172.25 3,321.49 3200.49 -3,078.04 -4,762.75 5,942,751.96 553,920.72 1.00 3,078.04 9,600.00 91.29 173.21 3,319.00 3198.00 -3,177.21 -4,750.10 5,942,652.90 553,934.14 1.00 3,177.21 9,659.19 91.13 173.78 3,317.74 3196.74 -3,236.00 -4,743.40 5,942,594.16 553,941.30 1.00 3,236.00 9,700.00 91.13 173.78 3,316.93 3195.94 -3,276.56 -4,738.98 5,942,553.65 553,946.04 0.00 3,276.56 9,800.00 91.13 173.78 3,314.96 3193.96 -3,375.96 -4,728.15 5,942,454.35 553,957.64 0.00 3,375.96 9,897.91 91.13 173.78 3,313A2 3192.02 -3,473.27 -4,717.54 5,942,357.13 553,969.00 0.00 3,473.27 1J-958 L1 T7 (wp09) 9,900.00 91.12 173.82 3,312.98 3191.98 -3,475.35 -4,717.32 5,942,355.06 553,969.24 1.96 3,475.35 10,000.00 90.52 175.73 3,311.55 3190.55 -3,574.92 -4,708.21 5,942,255.57 553,979.12 2.00 3,574.92 10,100.00 89.92 177.64 3,311.17 3190.17 -3,674.74 -4,702.42 5,942,155.80 553,985.69 2.00 3,674.74 10,172.04 89.48 179.01 3,311.54 3190.54 -3,746.75 -4,700.32 5,942,083.82 553,988.35 2.00 3,746.75 10,200.00 89.48 179.01 3,311.79 3190.79 -3,774.70 -4,699.83 5,942,055.87 553,989.05 0.00 3,774.70 10,300.00 89.48 179.01 3,312.69 3191.69 -3,874.69 -4,698.11 5,941,955.92 553,991.56 0.00 3,874.69 10,395.33 89.48 179.01 3,313.55 3192.55 -3,970.00 -4,696.46 5,941,860.63 553,993.95 0.00 3,970.00 1J-158 L1 T8 (wp09) 10,400.00 89.47 178.97 3,313.59 3192.59 -3,974.67 -4,696.38 5,941,855.96 553,994.07 0.99 3,974.67 10,500.00 89.16 178.01 3,314.78 3193.78 -4,074.62 -4,693.74 5,941,756.04 553,997.48 1.00 4,074.62 10,600.00 88.86 177.06 3,316.51 3195.51 -4,174.52 -4,689.44 5,941,656.19 554,002.56 1.00 4,174.52 10,700.00 88.55 176.11 3,318.77 3197.77 -4,274.31 -4,683.49 5,941,556.46 554,009.29 1.00 4,274.31 10,800.00 88.25 175.16 3,321.56 3200.56 -4,373.98 -4,675.88 5,941,456.86 554,017.68 1.00 4,373.98 10,835.07 88.14 174.82 3,322.66 3201.66 -4,408.90 -4,672.81 5,941,421.97 554,021.01 1.00 4,408.90 10,900.00 88.14 174.82 3,324.77 3203.77 -4,473.53 -4,666.96 5,941,357.39 554,027.37 0.00 4,473.53 10,939.92 88.14 174.82 3,326.06 3205.06 -4,513.26 -4,663.36 5,941,317.69 554,031.28 0.00 4,513.26 1J-158 L1 T9 (wp09j 11,000.00 90.44 175.53 3,326.80 3205.80 -4,573.12 -4,658.30 5,941,257.88 554,036.80 4.00 4,573.12 11,100.00 94.26 176.70 3,322.70 3201.70 -4,672.79 -4,651.53 5,941,158.28 554,044.34 4.00 4,672.79 11,148.63 96.12 177.28 3,318.30 3197.30 -4,721.15 -4,648.99 5,941,109.94 554,047.26 4.00 4,721.15 4/10/2007 9:22:34AM Page 7 of 10 COMPASS 2003.11 Build 48 ~f~~~~~~ ~ ~ ~ ~ 11,200.00 96.12 177.28 3,312.82 3191.82 -4,772.17 -4,646.57 5,941,058.95 554,050.08 0.00 4,772.17 11,240.93 96.12 177.28 3,308.46 3187.46 -4,812.83 -4,644.64 5,941,018.31 554,052.33 0.00 4,812.83 11,300.00 93.77 177.03 3,303.36 3182.37 -4,871.59 -4,641.72 5,940,959.57 554,055.71 4.00 4,871.59 11,387.52 90.29 176.67 3,300.26 3179.26 -4,958.91 -4,636.91 5,940,872.31 554,061.19 4.00 4,958.91 11,400.00 90.29 176.67 3,300.20 3179.2~ -4,971.37 ~,636.19 5,940,859.85 554,062.01 0.00 4,971.37 11,500.00 90.29 176.67 3,299.69 3178.69 -5,071.20 -4,630.38 5,940,760.08 554,068.60 0.00 5,071.20 11,600.00 90.29 176.67 3,299.19 3178.19 -5,171.03 -4,624.57 5,940,660.31 554,075.18 0.00 5,171.03 11,700.00 90.29 176.67 3,298.68 3177.68 -5,270.86 -4,618.76 5,940,560.54 554,081.77 0.00 5,270.86 11,800.00 90.29 176.67 3,298.18 3177.18 -5,370.69 -4,612.96 5,940,460.76 554,088.35 0.00 5,370.69 11,900.00 90.29 176.67 3,297.67 3176.67 -5,470.52 -4,607.15 5,940,360.99 554,094.94 0.00 5,470.52 11,937.52 90.29 176.67 3,297.48 3176.48 -5,507.98 -4,604.97 5,940,323.56 554,097.41 0.00 5,507.98 1J-158 L1 T11 (wp09) 12,000.00 89.67 176.68 3,297.50 3176.50 -5,570.35 -4,601.35 5,940,261.22 554,101.52 1.00 5,570.35 12,035.48 89.31 176.69 3,297.82 3176.82 -5,605.77 -4,599.30 5,940,225.82 554,103.84 1.00 5,605.77 12,100.00 89.31 176.69 3,298.60 3177.60 -5,670.18 -4,595.57 5,940,161.45 554,108.07 0.00 5,670.18 12,200.00 89.31 176.69 3,299.80 3178.80 -5,770.01 -4,589.80 5,940,061.68 554,114.62 0.00 5,770.01 r12,230.67 89.31 176.69 3,300.17 ~ 3179.17 -5,800.62 -4,588.03 5,940,031.08 554,116.63 0.00 5,800.62 BHL 1533' FS~, 1864' FEL - Sec03-T10N-R10E - 4 1/2" -1J -158 Toe (wp09) 4/10/"L007 9:22:34AM Page 8 of 10 COMPASS 2003.11 Build 48 s ~ ~ ~. ~ ~ ~ ~ ~~ ~ % ~ ~ ~ rx jq ~s2;v ~ y~ 4 ~'4W u t Y. C~..• Ya+.ru . / Halliburton Company HALt_IBURTOIV ConocoPhillips compass Proposal Report - Geographic q~~ Sperry Drilling Sarvice~ ~ ~ 3,313.55 1J-158 L1 T8 (wp09) -3,970.00 -4,696.46 5,941,860.63 553,993.95 - Point 3,300.17 1J-158 Toe (wp09) -5,800.62 -4,588.03 5,940,031.08 554,116.63 - Point 3,332.00 1J-158 L1 MB_B Heel 3/21/07 -1,054.58 -4,958.68 5,944,773.64 553,709.05 - Polygon Point 1 0.00 0.00 5,944,773.64 553,709.05 Point 2 -681.93 18.19 5,944,091.94 553,732.55 3,250.08 1J-158 (wp09) Top D -1,054.81 -4,972.05 5,944,773.30 553,695.69 - Point 3,324.13 1J-158 L1 T6 (wp09) -2,989.50 -4,775.48 5,942,840.39 553,907.30 - Point 3,332.64 1J-158 L1 T5 (wp09) -2,708.53 -4,818.99 5,943,120.98 553,861.61 - Point 3,326.06 1J-158 L1 T9 (wp09) -4,513.26 -4,663.36 5,941,317.69 554,031.28 - Point 3,213.86 1J-158 Begin Pump Tangent -858.60 -4,934.88 5,944,969.78 553,731.32 - Point 3,297.48 1J-158 L1 T11 (wp09) -5,507.98 -4,604.97 5,940,323.56 554,097.41 - Point 3,321.20 1J-158 L1 T2 (wp09) -2,157.66 -4,924.64 5,943,670.96 553,751.68 - Point 3,330.27 1J-158 L1 MB_CP1 3/21/07 -1,736.50 -4,940.49 5,944,091.94 553,732.55 - Polygon Point 1 0.00 0.00 5,944,091.94 553,732.55 Point 2 -421.36 40.85 5,943,670.96 553,776.68 3,321.20 1J-158 L1 MB_CP2 3/21/07 -2,157.86 -4,899.64 5,943,670.96 553,776.68 - Point 3,313.02 1J-158 L1 T7 (wp09) -3,47327 -4,717.54 5,942,357.13 553,969.00 - Point 3,393.43 2,151.72 10-3/4 13-1/2 8,023.61 3,323.94 7-5/8 9-7/8 12,230.66 3,300.17 4-1/2 6-3l4 4/10/2007 9:22;34AM Page 9 of 10 COMPASS 2003.11 Build 48 ~~~~~~~.~ x. ; , . , . .~.. ~. ~ { ~~ _. ~ ~' Halliburton Company HALLI URT COI'lOCO~'11~~1~5 Compass Proposal Report - Geographic Sperry Drilling S~+rvices ~ ~ 1,672.09 47.14 277.00 1,529.10 61.26 -498.90 Pfrost 1,866.77 53.81 279.18 1,655.46 81.38 -645.42 K15 2,629.56 73.55 282.32 1,935.41 229.37 -1,333.95 T3 3,393.43 73.55 282.32 2,151.72 385.68 -2,049.68 Casing Pt 5,474.82 73.77 245.23 2,739.17 480.64 -4,0~~.31 Ugnu C 6,023.40 73.88 226.36 2,892.03 185.78 -4,434.06 Ugnu B 6,251.56 73.92 218.51 2,955.31 24.12 -4,581.85 Ugnu A 6,747.81 74.02 201.44 3,092.34 -387.53 -4,819.24 K 13 7,424.15 79.71 188.79 3,245.09 -1,028.61 -4,961.16 W Sak D 7,721.17 82.67 181.46 3,294.44 -1,320.00 -4,987.94 W Sak C 7,993.61 84.75 179.03 3,321.19 -1,591.07 -4,985.48 W Sak B ~, ~y ~ ~i. - y -_ ~ ~~ _ :~~, , m: iHr~~~c~ ~~ ~ _' _ , , , ~ ~~~°.' ~N. _ ' ~~ ~~~EqG~' ~~~~ , ~ ~ ~. , _ ~~ 40.00 40.00 0.00 0.00 SHL 2056' FSL, 2550' FEL - Sec35-T11 N-R10E 7,249.31 3,213.86 -858.60 -4,934.88 Begin Pump Tangent 80° Inc @ 7249' MD, 3214' ND 7,449.31 3,249.59 -1,053.08 -4,964.95 End Pump Tangent Q 7449' MD, 3250' ND 8,023.61 3,323.94 -1,620.95 -4,984.97 7 5/8" Casing - 433' FSL, 2257' FEL - Sec34-T11N-R10E 12,230.66 3,300.17 -5,800.61 -4,588.03 BHL 1533' FSL, 1864' FEL - Sec03-T10N-R10E 4/10/2007 9:22:34AM Page 10 of 10 COMPASS 2003.11 Build 48 ~ ~ ,~-~ ~~-~ ~ ,~•- ~ ~ p~<; ~ ~/ Halliburton Company HALLIBLtRTOttiI ConocoPhillips Compass Proposal Report - Geographic q~}~ Sperry DrillinQ Servicee ~ • • ConocoPh ~ I I ~ ps Alaska • Plan: 1 J-158 (wp09) Sperry Drilling Services Anticollision Summary 10 April, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-158 1 J-158 Local Coordinate Origin: Centered on Well Plan 1J-158 - Slot 1J-158 Viewing Datum: D15 (40+g1) @ 121.OOft (D15 (40+g1)) TVDs to System: N North Reference: True Unit System: API - US Survey Feet L 1 u~T~ 3perry Drilling $ervices ~ ~!~~~~~~ ~ ~ . • SURVEY PROGRAM ConOtoPhillips Alaska, Int. Date: 2007-0.t-11TOO:U0:00 Validated: Yes Version: t2.11UU Engineering Calculation Method: Minimum Curvature DepthFmmDepthTo Sune~/Plao Ta~l EfrofSystem: ISCWSA 10A0 fl13.00 1J-158 (e~p09) C&GYRO-SS Scan Method: Trev. Cylinder North A13.IN1 22G9.RJ 1J-ls8(N'p09) MWD+~FR-AK-CAZSC EfrofSurface: EllipticalCOnit 8863.OU 12230.33 1J-158 (w'p09) MWD+IFR-AK-CAZSC Wafning Method: Rules Based 1 J-160 270 PIan1J-UgnuDisposal ,J168 ~ iJ `~0 ~' ~j, ~ ~ ~~-0y 1J-109 i 3Q ~y 1J-154 ~ V~ ~ 'l jT ~_ ~ - .~.'~~1J.10 1J-701 i\~ ~, '.d.'i~i~ ,s'~ ~~ '' r~~, _ _ - - - - ~ ~.:: - yr ~ '-- 210 .- i ~ 1`~ iJ-173Pilot(wp06) -' ~'`~. ; a~ `'I,~ iJ-162 (wp05) ~ ` .-.~. ' _ 1J-i66 100 ~ - ~1.i-t7CPgSUrveys 1J-1741wp05) 1J-176(wp02) Travelling Cylinder Azimuth (TFO+AZI) ~°~ vs Centre to Centre Separation ~200 R/in~ NAD 27 ASP Zone C: WELL DETNLS: Plan 7J-158 Ground Level: 87.00 .N/S .EI.W Northing Easting Latittude Longitutle SIM 0.00 0.00 5465866.71 558658.89 70°75'45.747N 149°37'72.833W 1J-158 REFERENCEINFORMATION Co-ortlinate (N/E) Reference: Well Plan 1J-158 - Slot 7J-158, True North Vertical (ND) Reference: Di5 (d0+81) ~,d 121.00(t (075 (10~81)) Section (V5) RMerence: Slot - 1J-15B(O.OON, O.OOE) Measuretl Depth Reference: D~ 5(40+01) @ 721.00(t (015 (4M81~) Calculation Method: Minimum Curvafure ~ ' ~.~.~~~~ ~~o,.roN. i ~r~x ~~ n~wo» ii~x ~~ n tm~~ ~r~sa~~.sc.ws~ ~i~x ~~ n c~~ ~i~ ~~*etwos~ tit5e~fislwWl v.~se ~i .~ ~ i..ms~ ~ c~~ ANTI-COLLISION SETTINGS IMerpolation Method: MD Interval: SOStations Depth Range From: 40.00 To 12237.02 Maximum Range:1419.702500535 Reference: Plan: 1J-158(wp09) iJ-156 ~ Tra. ellioR Cylindcr Aiimuth (TFO+AZq ~°~ rs Centre to Ceotre Scparafion ~30 fUio~ ~~~~~~t r.~ CO!'IOCOPIIII I I p5 Nlaska ~ • Halliburton Company Anticollision Report Filter type: NO GLOBAL FILTER: Using user defined selection & filtering criteria Interpolation Method: MD Interval 25.OOft Error Model: Depth Range: Unlimited Scan Method: Results Limited by: Maximum center-center distance of 1,419.10ft Error Surtace: Warning Levels evaluated at: 0.00 Sigma HALLIBURT 9perry Driiting Services ISCWSA Trav. Cylinder North Elliptical Conic 40.00 813.00 1J-158 (wp09) (1J-158) CB-GYRO-SS Camera based gyro single shot 813.00 2,269.84 1J-158 (wp09) (1J-158) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 8,863.00 12,230.33 1J-158 (wp09) (1J-158) MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC CC - Min centre to center distance or covetgenY point, SF - min separation factor, ES - min ellipse separation 4/10/2007 9:36:51AM Page 2 of 6 COMPASS 2003.11 Bui(d 48 ~~~ ~~~+~~~~ ~ ~' V$ L . 4 #'t~ 4 , ~ ~ . ~-' Halliburton Company HALLiBURTON COt1QCO~l1~~Ip5 Anticollision Report p,~~ Sperry Drilling Service~ CC - Min centre to cente~ distance or covergent point, 5F - min separation factor, ES - min ellipse separation 4/10/2007 9:36:51AM Page 3 of 6 COMPASS 2003.11 Build 48 ~~~~~;~~:~~~~~_ ~ ~ Halliburton Company HALLIBU TOIV ConocoPhillips Anticollision Report q~S~ Sperry Drilling Servicea 1J-03 - 1J-03 - 1J-03 154.88 150.00 141.63 2.55 139.07 Pass - Major Risk 1J-09 - 1J-09 - 1J-09 331.44 325.00 100.42 5.88 94.53 Pass - Major Risk 1J-10 - 1J-10 - 1J-10 430.47 425.00 61.37 8.03 53.34 Pass - MajorRisk 1J-101 - 1J-101 - 1J-101 384.43 375.00 241.86 8.12 233.74 Pass - Major Risk 1J-101 - 1J-101 L1 - 1J-101 L1 384.43 375.00 241.86 8.12 233.74 Pass - Major Risk 1J-101 - 1J-101 L1 PB1 - 1J-101 L1 PB1 384.43 375.00 241.86 8.12 233.74 Pass - Major Risk 1J-101 - 1J-101 L2 - 1J-101 L2 384.43 375.00 241.86 8.12 233.74 Pass - Major Risk 1J-101 - 1J-101PB1 - 1J-101PB1 384.43 375.00 241.86 8.12 233.74 Pass - Major Risk 1J-102 - 1J-102 - 1J-102 224.69 225.00 217.57 4.32 213.25 Pass - Major Risk 1J-102 - 1J-102 L1 - 1J-102 L1 224.69 225.00 217.20 4.61 212.59 Pass - Major Risk 1J-102 - 1J-102 L2 - 1J-102 L2 224.69 225.00 217.57 4.32 213.25 Pass - Major Risk 1J-102 - 1J-102 L2 PB1 - 1J-102 L2 PB1 224.69 225.00 217.57 4.32 213.25 Pass - Major Risk 1J-102 - 1J-102 L2 PB2 - 1J-102 L2 PB2 224.69 225.00 217.20 4.61 212.59 Pass - Major Risk 1J-102 - 1J-102 PB1 - 1J-102 P61 224.69 225.00 217.20 4.61 212.59 Pass - Major Risk 1J-102 - 1J-102 PB2 - 1J-102 P62 224.69 225.00 217.20 4.61 212.59 Pass - Major Risk 1J-102 - 1J-102 P63 - 1J-102 PB3 224.69 225.00 217.20 4.61 212.59 Pass - Major Risk 1J-109 - 1J-109 - 1J-109 174.16 175.00 146.98 3.68 143.30 Pass - Major Risk 1J-109 - 1J-109 P61 - 1J-109PB1 174.16 175.00 146.98 3.57 143.41 Pass - Major Risk 1J-109 - Plan 109a L1 - 1J-109a L1 (wp02) 186.99 175.00 147.25 3.96 143.29 Pass - Major Risk 1J-109 - Plan 1J-109a - 1J-109a (wp02) 186.99 175.00 147.25 3.96 143.29 Pass - Major Risk 1J-109 - Plan 1J-109a L2 - 1J-109a L2 (wp02) 186.99 175.00 147.25 3.96 143.29 Pass - Major Risk 1J-115 - 1J-115 - 1J-115 357.49 350.00 190.10 7.69 182.42 Pass - Major Risk 1J-115 - 1J-115L1 - 1J-115L1 357.49 350.00 190.10 7.69 182.42 Pass - Major Risk 1J-115 - 1J-115L1 P61 - 1J-115L1 PB1 357.49 350.00 190.10 7.69 182.42 Pass - Major Risk 1J-115 - 1J-115L1PB2 - 1J-115L1P62 357.49 350.00 190.10 7.69 182.42 Pass - Major Risk 1J-115 - 1J-115L2 - 1J-115L2 357.49 350.00 190.10 7.69 182.42 Pass - Major Risk 1J-115 - 1J-115L2P61 - 1J-115L2P61 357.49 350.00 190.10 7.69 182.42 Pass - Major Risk 1J-115 - 1J-115L2P62 - 1J-115L2PB2 357.49 350.00 190.10 7.69 182.42 Pass - Major Risk 1J-115 - 1J-115P61 - 1J-115PB1 357.49 350.00 190.10 7.69 182.42 Pass - Major Risk 1J-115 - 1J-115PB2 - 1J-115PB2 357.49 350.00 190.10 7.69 182.42 Pass - Major Risk 1J-115 - 1J-115P63 - 1J-115P63 357.49 350.00 190.10 7.69 182.42 Pass - Major Risk 1J-115 - 1J-115P64 - 1J-115P64 357.49 350.00 190.10 7.69 182.42 Pass - Major Risk 1J-152 - 1J-152 - 1J-152 465.31 450.00 140.11 9.87 130.24 Pass - Major Risk 1J-152 - 1J-152 L1 - 1J-152 L1 465.31 450.00 140.18 9.87 130.32 Pass - Major Risk 1J-152 - 1J-152 L2 - 1J-152 L2 465.31 450.00 140.18 9.87 130.32 Pass - Major Risk 1J-152 - 1J-152 L2 PB1 - 1J-152 L2 P61 465.31 450.00 140.18 9.87 130.32 Pass - Major Risk 1J-152 - 1J-152 PB1 - 1J-152 P61 465.31 450.00 140.18 9.87 130.32 Pass - Major Risk 1J-152 - 1J-152 PB2 - 1J-152 PB2 465.31 450.00 140.11 9.87 130.24 Pass - Major Risk 1J-154 - 1J-154 - 1J-154 588.18 575.00 83.30 12.69 70.60 Pass - Major Risk 1J-154 - 1J-154 L1 - 1J-154 L1 588.18 575.00 83.30 12.69 70.60 Pass - Major Risk 4J-154 - 1J-154 L2 - 1J-154 L2 588.18 575.00 83.30 12.69 70.60 Pass - Major Risk 1J-156 - 1J-156 - 1J-156 1,429.72 1,400.00 57.34 28.98 28.36 Pass - Major Risk 1J-156 - 1J-156L1 - 1J-156L1 1,429.72 1,400.00 57.34 28.98 28.36 Pass - Major Risk 1J-156-1J-156L1P61-1J-156L1PB1 1,429.72 1,400.00 57.34 28.98 28.36 Pass-MajorRisk 1J-156 - 1J-156L2 - 1J-156L2 1,429J2 1,400.00 57.34 28.98 28.36 Pass - Major Risk 1J-159 - 1J-159 - 1J-159 436.33 425.00 23.49 9.38 14.11 Pass - Major Risk 1J-159 - 1J-159 L1 - 1J-159 L1 436.33 425.00 23.49 9.38 14.11 Pass - Major Risk 1J-159 - 1J-159 L1 PB1 - 1J-159 L1 PB1 436.33 425.00 23.49 9.38 14.11 Pass - Major Risk 1J-159 - 1J-159 L1 P62 - 1J-159 L1 P62 436.33 425.00 23.49 9.38 14.11 Pass - Major Risk 1J-159 - 1J-159 L2 - 1J-159 L2 436.33 425.00 23.49 9.38 14.11 Pass - Major Risk 1J-159 - 1J-159 P61 - 1J-159 P61 436.33 425.00 23.49 9.38 14.11 Pass - Ma'or Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min eilipse separation 4/10/2007 9:36:51AM Page 4 of 6 COMPASS 2003.1 ? Build 48 ~~'~~~~~~~_ Conoco hillips Alaska ~ ~ Halliburton Company Anticollision Report HALLIBURTON ~perry Drillinp ~ervices Ku aruk 1J Pad _ __ ~ ' ~ _~ ~ ~~ ~ ~ _ - ~~ ~6 _ 1J-164 - 1J-164 - 1J-164 555.50 550.00 144.10 11.98 132.11 Pass - Major Risk 1J-164 - 1J-164 L1 - 1J-164 L1 555.50 550.00 144.10 11.98 132.11 Pass - Major Risk 1J-164 - 1J-164 L2 - 1J-164 L2 555.50 550.00 144.10 11.98 132.11 Pass - Major Risk 1J-164 - 1J-164 L2 P61 - 1J-164 L2 P61 555.50 550.00 144.10 11.98 132.11 Pass - Major Risk 1J-166 - 1J-166 - 1J-166 433.10 425.00 182.55 9.33 173.23 Pass - Major Risk 1J-166 - 1J-166 L1 - 1J-166 L1 433.10 425.00 182.55 9.33 173.23 Pass - Major Risk 1J-166 - 1J-166 L1 PB1 - 1J-166 L1 P61 433.10 425.00 182.55 9.33 173.23 Pass - Major Risk 1J-166 - 1J-166 L2 - 1J-166 L2 433.10 425.00 182.55 9.33 173.23 Pass - Major Risk 1J-166 - 1J-166 L2 P61 - 1J-166 L2 PB1 433.10 425.00 182.55 9.33 173.23 Pass - Major Risk 1J-168 - 1J-168 - 1J-168 6,520.26 6,600.00 180.69 118.67 62.02 Pass - Major Risk 1J-168 - 1J-168 L1 - 1J-168 L1 6,520.26 6,600.00 180.69 118.67 62.03 Pass - Major Risk 1J-168 - 1J-168 L2 - 1J-168 L2 6,520.26 6,600.00 180.69 119.25 61.44 Pass - Major Risk 1J-168 - 1J-168 L2 P61 - 1J-168 L2 PB1 6,520.26 6,600.00 180.69 119.24 61.45 Pass - Major Risk 1J-170 - 1J-170 - 1J-170 Rig Surveys 528.15 525.00 257.46 11.46 246.00 Pass - Major Risk 1J-170 - 1J-170 L1 - 1J-170 L1 Rig Surveys 528.15 525.00 257.46 11.46 246.00 Pass - Major Risk 1J-170 - 1J-170 L2 - 1J-170 L2 Rig Surveys 528.15 525.00 257.46 11.46 246.00 Pass - Major Risk 1J-170 - 1J-170 PB1 - 1J-170 PB1 528.15 525.00 257.46 11.46 246.00 Pass - Major Risk 1J-170 - 1J-170 PB2 - 1J-170 PB2 Rig Surveys 528.15 525.00 257.46 11.46 246.00 Pass - Major Risk Plan 1J-107 - Plan 1J-107 - 1J-107 (wp03) 335.22 325.00 158.03 7.04 150.99 Pass - Major Risk Plan 1J-107 - Plan 1J-107 L1 - 1J-107 L1 (wp03) 335.22 325.00 158.03 7.04 150.99 Pass - Major Risk Plan 1J-107 - Plan 1J-107 L2 (wp03) - 1J-107 L2 ~ 335.22 325.00 158.03 7.04 150.99 Pass - Major Risk Plan 1J-112 Kuparuk Prelim - 1J-12 E Lateral - 1J 345.84 350.00 158.25 7.32 150.93 Pass - Major Risk Plan 1J-112 Kuparuk Prelim - 1J-12 Pilot - 1J-12 1 345.84 350.00 158.25 7.32 150.93 Pass - Major Risk Plan 1J-112 Kuparuk Prelim - Plan 1J-12 W Later 345.84 350.00 158.25 7.32 150.93 Pass - Major Risk Plan 1J-150 (Ugnu Disposal) - Plan 1J-UgnuDispc 390.48 375.00 180.30 7.29 173.01 Pass - Major Risk Plan 1J-158 - 1J-158 L1 - 1J-158 L1 (wp09) 7,425.00 7,425.00 0.00 0.60 -0.60 FAIL - No Errors Plan 1J-162 - 1J-162 - 1J-162 (wp05) 756.32 750.00 104.38 16.53 87.85 Pass - Major Risk Plan 1J-162 - 1J-162 L1 - 1J-162 L1 (wp05) 756.32 750.00 104.38 16.53 87.85 Pass - Major Risk Plan 1J-162 - 1J-162 L2 - 1J-162 L2 (wp05) 756.32 750.00 104.38 16.53 87.85 Pass - Major Risk Plan 1J-173 Kuparuk - 1J-73 E Lateral - 1J-73 E L 442.80 450.00 321.69 9.45 312.25 Pass - Major Risk Plan 1J-173 Kuparuk - 1J-73 Kuparuk - 1J-73 W L 442.80 450.00 321.69 9.45 312.25 Pass - Major Risk Plan 1J-173 Kuparuk - 1J-73 Pilot - 1J-173 Pilot (~ 442.80 450.00 321.69 9.45 312.25 Pass - Major Risk Plan 1J-174 (Q1 Phase 2) - 1J-174 - 1J-174 (wp0: 358.92 350.00 340.94 7.57 333.38 Pass - Major Risk Plan 1J-174 (Q1 Phase 2) - 1J-174 L1 - 1J-174 L1 358.92 350.00 340.94 7.57 333.38 Pass - Major Risk Plan 1 J-176 (Q2 Phase 2) - 1 J-176 - 1 J-176 (wp0: 358.58 350.00 381.06 7.67 373.39 Pass - Major Risk Plan 1J-176 (Q2 Phase 2) - 1J-176 L1 - 1J-176 L1 358.58 350.00 381.06 7.67 373.39 Pass - Major Risk Plan 1 J-178 (Q3 Phase 2) - 1 J-178 - 1 J-178 (wp0: 346.97 350.00 421.01 7.45 413.56 Pass - Major Risk Plan 1J-178 (Q3 Phase 2) - 1J-178 L1 - 1J-178 L1 346.97 350.00 421.01 7.45 413.56 Pass - Major Risk Rig: 1J-103 - 1J-103 - 1J-103 311.55 300.00 202.56 6.67 195.89 Pass - Major Risk Rig: 1J-103 - 1J-103 L1 - 1J-103 L1 311.55 300.00 202.61 6.67 195.94 Pass - Major Risk Rig: 1J-103 - 1J-103 L1 P61 - 1J-103 L1 PB1 311.55 300.00 202.56 6.67 195.89 Pass - Major Risk Rig: 1J-103 - 1J-103 L2 - 1J-103 L2 311.55 300.00 202.61 6.67 195.94 Pass - Major Risk Rig: 1J-103 - 1J-103P61 - 1J-103P61 311.55 300.00 202.56 6.67 195.89 Pass - Major Risk Rig: 1J-103 - 1J-103P62 - 1J-103PB2 311.55 300.00 202.56 6.67 195.89 Pass - Major Risk Rig: 1J-103 - 1J-103PB3 - 1J-103PB3 311.55 300.00 202.56 6.67 195.89 Pass - Major Risk Rig: 1J-105 - 1J-105- 1J-105 311.48 300.00 178.12 6.67 171.46 Pass - Majot Risk Rig: 1J-105 - 1J-105 - 1J-105 (wp05) 335.42 325.00 177.18 7.05 170.13 Pass - Major Risk Rig: 1J-105 - 1J-105 L1 - 1J-105 L1 (wp05) 335.42 325.00 177.18 6.92 170.26 Pass - Major Risk Rig: 1J-105 - 1J-105 L2 - 1J-105 L2 (wp05) 335.42 325.00 177.18 6.92 170.26 Pass - Major Risk Rig: 1J-105 - 1J-105 P61 - 1J-105 PB1 311.48 300.00 178.12 6.67 171.46 Pass - Major Risk Rig: 1J-118 - 1J-118 - 1J-118 334.~2 325.00 233.20 7.17 226.03 Pass - Ma'or Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 4/10/2007 9:36:51AM Page 5 of 6 COMPASS 2003.11 Build 48 ~~~~~~,y~ ~E, ~ ~ , ~G f4 ~ ~~ar.--~ ~\ i ~, s~~'~: X S e.-...~ ConocoPhillips Alaska ~ ~ Halliburton Company Anticollision Report HALLIBURTON Sperry D~illing S~rvices Rig: 1J-118 - 1J-118 L1 - 1J-118 L1 334.02 325.00 233.20 7.17 226.03 Pass - Major Risk Rig: 1J-118 - 1J-118 L2 - 1J-118 L2 334.02 325.00 233.20 7.17 226.03 Pass - Major Risk Rig: 1J-118 - 1J-118 PB1 - 1J-118 PB1 334.02 325.00 233.20 7.17 226.03 Pass - Major Risk Rig: 1J-118 - 1J-118 P62 - 1J-118 P62 334.02 325.00 233.24 7.17 226.07 Pass - Major Risk Rig: 1J-160 - 1J-160 - 1J-160 520.42 525.00 38.19 11.22 26.97 Pass - Major Risk Rig: 1J-160 - 1J-160 L1 - 1J-160 L1 520.42 525.00 38.19 11.22 26.97 Pass - Major Risk Rig: 1J-160 - 1J-160 L1 - 1J-160 L1 (Drill Out) 524.01 525.00 38.27 11.42 26.85 Pass - Major Risk Rig: 1J-160 - 1J-160 L1 P61 - 1J-160 L1 (Drill Ou~ 524.01 525.00 38.27 11.42 26.85 Pass - Major Risk Rig: 1J-160 - 1J-160 L1 PB1 - 1J-160 L1 P61 520.42 525.00 38.19 11.22 26.97 Pass - Major Risk Rig: 1J-160 - 1J-160 L2 - 1J-160 L2 520.42 525.00 38.19 11.22 26.97 Pass - Major Risk Rig: 1J-160 - 1J-160 L2 - 1J-160 L2 (wp09) 598.13 600.00 43.64 12.95 30.69 Pass - Major Risk WSP-02 - WSP-02 - WSP-02 350.14 350.00 181.39 6.72 174.67 Pass - Major Risk WSP-03 - WSP-03 - WSP-03 360.76 350.00 198.30 9.15 189.15 Pass - Major Risk WSP-04 - WSP-04 - WSP-04 372.18 375.00 227.64 7.37 220.27 Pass - Major Risk WSP-15 - WSP-15 - WSP-15 369.24 375.00 187.15 8.89 178.27 Pass - Major Risk WSP-1S - WSP-1S - WSP-1S 400.00 400.00 207.20 11.74 195.45 Pass - Major Risk WSP-20 - WSP-20 - WSP-20 612.27 600.00 149.58 15.04 134.54 Pass - Major Risk CC - Min centre to center distance or covergent point, SF - min separation factor, ES - min ellipse separation 4/10/2007 9:36:51AM Page 6 of 6 COMPASS 2003.11 Build 48 ~~~~~~,~~~~~~~ ~:'~ s~.. ~ 1J-158~rillin~ Hazards S~nmar_y (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) 13-1/2" Open Hole / 10-3/4" Casing Interval Hazard Risk Level Miti ation Strate Broach of Conductor Low Monitor cellar continuously during interval. Gas Hydrates Moderate Control drill, Reduced pump rates, Reduced ~' drilling fluid temperatures, Additions of Driltreat. Running Sands and Low Maintain planned mudparameters, Increase Gravels mud weight, use weighted sweeps. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out Wellbore Collision with Moderate Adhere to Directional Program, Directional Existing wells Driller to update Traveling cylinder diagrams for every survey. 9-7/8" Open Hole / 7-5/8" Casing Interval Hazard Risk Level Miti ation Strate Running Sands and Low Maintain planned m.ud parameters, Increase Gravels mud wei ht, use weighted sweeps. Gas Hydrates Low Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of Driltreat. Stuck Pipe Low Good hole cleaning, PWD tools, pre-treatment with lost circulation material, stabilized BHA, decreased mud weight Abnormal Reservoir Low BOP training and drills, increased mud weight. Pressure Lost circulation Low Reduced pump rates, mud rheology, LCM Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets), pumping out 6-3/4" O en Hole / 4-1/2" Liner Interval Hazard Risk Level Miti ation Strateg Abnormal Reservoir Low Stripping drills, shut-in drills, increased mud Pressure weight. Stuck Pipe Low Good hole cleaning, PWD tools, hole opener runs, decreased mud weight Lost Circulation Low Reduced pump rates, mud rheology, LCM Hole Swabbing on Trips Moderate Trip speeds, proper hole filling (use of trip sheets),pumping out, backreaming Wellbore Collision with Moderate Adhere to Directional Program, Directional Existing wells Driller to update Traveling cylinder diagrams for every survey and monitor well to well proximities. 1J-158 Drilling HazardsSummary ~' ~+, ~~:, y r~ ~~ prepared by Dennis D. Hartwig . p ~ ~ ~'4~ ~ ~ 4/16/2007 9:31 AM ~~ _. ~ ~~ R *...~ ~ ~ • ~' Schl[~mberger =~~mC}~-DE P~-~limin~ry Job de~ic~n ~ ~ ; , ~ 1~ 3/4" Su'rfac~ '~~'' ,~i r ~~ Preliminary Job Design ~based on limited input data. For estimate purposes onry, Rig: Doyon 141 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 4/23/2007 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445 email: mtorrie@slb.com < TOC at Surface Previous Csg. < 20", 91.5# casing at 80' MD < Base of Permafrost at 1,672' MD (1,655' TVD) ~ Top of Tail at 2,593' MD < 10 3/4", 45.5# casing in 13 1/2" OH TD at 3,393' MD (2,152' TVD) ~ Mark of Schlumberger Volume Calculations and Cement Systems Volumes are based on 250% excess in the permafrost and 35% excess below the permafrost. The top of the tail slurry is designed to be at 2,593' MD. (800' above the shoe) Lead Slurrv Minimum pump time: 270 min. (pump time plus 120 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 1.3644 ft3/ft x(80') x 1.00 (no excess) = 109.2 ft3 0.3637 ft3/ft x(1672' - 80') x 3.50 (250°/a excess) = 2026.5 ft3 0.3637 ft3/ft x(2593' - 1672') x 1.35 (35% excess) = 452.2 ft3 109.2 ft3 + 2026.5 ft3+ 452.2 ft3 = 2587.9 ft3 2587.9 ft3 / 4.45 ft3/sk = 581.6 sks Round up to 590 sks Have 290 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurrv Minimum pump time: 200 min. (pump time plus 120 min.) DeepCRETE @ 12.0 ppg - 2.47 ft3/sk 0.3637 ft3/ft x(3393' - 2593') x 1.35 (35% excess) = 392.8 ft3 0.5400 ft3/ft x 80' (Shoe Joint) = 43.2 ft3 392.8 ft3 + 43.2 ft3 = 436 ft3 436 ft3/ 2.47 ft3/sk = 176.5 sks Round up to 180 sks BHST = 43~, Estimated BHCT = 62~. (BHST calculated using a gradient of 2.6~/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time ~bpm~ (bbp (min) (min) CW 100 5 50 10.0 10.0 Drop Bottom Plug 15.0 25.0 MudPUSH II 5 50 10.0 35.0 Lead Slurry 7 468 66.9 101.9 Tail Slurry 6 79 13.2 115.1 Drop Top Plug 8.0 123.1 Water 6 20 3.3 126.4 Switch to Rig Pum s 5.0 131.4 Displacement 6 269 44.8 176.2 Slow Rate 3 30 10.0 186.2 MUD REMOVAL Recommended Mud Properties: 9.6 ppg, P~ < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 10.5 ppg MudPUSH* II, P~ = 17-21, TY = 25-30 Centralizers: Recommend 2 per joint across zones of interest for proper cement placement. ~~'~~~~~~~ ~ ~ ~ Schlumberg~r CemCAD E*well cementing recommendation for 10 3/4 Intermediate Operator : CPAI Well Country : USA Fieltl State : Alaska Prepared for . Location Proposal No. : V1 (wp09) Service Point Date Prepared : March 23, 2007 Business Phone FAX No. Prepared by : Maureen Torrie Phone : 1-907-265-6336 E-Mail Atldress : mtorrieQslb.com 1J-158 DLP West Sak Prudhoe Bay ~907~659-2434 (907-659-2538 ~isclaimer Notice: This information is presentetl in good faith, but no warranty is given by and Schlumberger assumes no liability for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and treatment. The results depend on input data provided by the Operator and estimates as to unknown data and can be no more accurate than the model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring I well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notify the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required to perfarm these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. ~ Mark of Schlumberger ~~~~~~~~~ +r- i Client : CPAI Well : 1J-158 DLP String : 10 3/4 Intermediate District : Prudhoe Bay Country : USA Loadcase : 1034 Surface Section 1: well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 3393.4 ft BHST : 46 degF Bit Size : 13 1/2 in Previous String MD OD Weight ID ft in Ib/ft in 80.0 20 94.0 19.124 Landing Collar MD : 3313.4 ft Casing/liner Shoe MD : 3393.4 ft ~~~I[~~rg~r Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread __ (ft) (in) (ft) (Ib/ft) (in) (psi) (psi) 3393.4 10 3/4 40.0 45.5 9.950 L-80 2270 4230 BTC Special Mean OH Diameter : 13.500 in Mean Annular Excess : 138.3 % Mean OH Equivalent Diameter: 16.567 in Total OH Volume : 883.5 bbl (including excess) Caliper and Hole Size Data MD Caliper Excess Equiv. Diam. ft in % in 1672.0 13.500 250.0 18.681 3393.4 13.500 35.0 14.338 1J-758cement.chv;04-23-2007; LoadCase1034Surface;Versionwcs-cem45_89 Page 2 ~.. b '~ i ~~ ~ G ~ a~~ ~ ~ ~ Client : CPAI Well : 1J-158 DLP String : 10 3/4 Intermediate District : Prudhoe Bay Country : USA Loadcase : 1034 Surface Max. Deviation Angle : 74 deg Max. DLS : 5.011 deg/100ft MD ft Directional Survey Data ND Deviation Azimuth ft de de Dogleg Sev. de /100ft 0.0 0.0 0.0 0.0 0.000 40.0 40.0 0.0 0.0 0.000 100.0 100.0 0.0 0.0 0.000 200.0 200.0 0.0 0.0 0.000 300.0 300.0 0.0 0.0 0.000 400.0 400.0 2.5 277.0 2.500 500.0 499.7 5.0 277.0 2.500 600.0 599.1 7.5 277.0 2.500 702.1 700.0 10.1 277.0 2.499 800.0 795.8 14.0 277.0 4.002 900.0 891.9 18.0 277.0 4.000 1000.0 985.9 22.0 277.0 4.000 1100.0 1077.2 26.0 277.0 4.000 1200.0 1165.5 30.0 277.0 4.000 1300.0 1250.3 34.0 277.0 4.000 1400.0 1331.2 38.0 277.0 4.000 1500.0 1407.9 42.0 277.0 4.000 1600.0 1479.8 46.0 277.0 4.000 1629.3 1500.0 47.1 277.0 3.990 1672.1 1529.1 47.1 277.0 0.000 1700.0 1548.1 47.1 277.0 0.000 1729.3 1568.0 47.1 277.0 0.000 1800.0 1614.5 50.6 278.2 4.997 1866.8 1655.5 53.8 279.2 5.011 1900.0 1674.7 55.4 279.6 4.982 2000.0 1727.9 60.3 281.0 5.006 2100.0 1773.7 65.2 282.2 4.993 2200.0 1811.7 70.1 283.3 5.004 2270.8 1833.8 73.6 284.0 4.999 2300.0 1842.1 73.6 283.3 2.400 2338.0 1852.8 73.6 282.3 2.396 2400.0 1870.4 73.6 282.3 0.000 2500.0 1898.7 73.6 282.3 0.000 2600.0 1927.0 73.6 282.3 0.000 2629.6 1935.4 73.6 282.3 0.000 2700.0 1955.3 73.6 282.3 0.000 2800.0 1983.7 73.6 282.3 0.000 2900.0 2012.0 73.6 282.3 0.000 3000.0 2040.3 73.6 282.3 0.000 3100.0 2068.6 73.6 282.3 0.000 3200.0 2096.9 73.6 282.3 0.000 3300.0 2125.2 73.6 282.3 0.000 3393.4 2151.7 73.6 282.3 0.000 iJ-158cementciw;04-23-20~7; LoadCase7034Surface;Versionwcs-cem45_89 ~~~I~~~r~~r Page 3 F~~~~~~~~~ ~ i ~ Client : CPAI Well : 1J-158 DLP String : 10 3/4 Intermediate District : Prudhoe Bay Country : USA Loadcase : 1034 Surface Formation Data MD Frac. Pore Name Lithology ft Ib/ al Ib/ al 1672.0 12.50 8.20 Permafrost Sandstone 1867.0 12.50 8.20 K15 Sandstone 2629.6 12.50 8.20 T3 Sandstone 4000.0 12.50 8.20 Casin Point Sandstone Geothermal Temperature Profile MD TVD Temperature Gradient ft ft de F de F/100ft 0.0 0.0 25 0.0 1672.0 1529.0 30 0.3 3373.0 2145.9 46 1.0 4000.0 2323.5 51 1.1 ft o- 0 0 0 ~- degF Temperature ~ c c ~ c u c ,... a ~ c ~ ~ r. o ~ 0 o ~ ~ 5 ~ c~ ~ a ~ c c C N Hori. Departure 5 Page 4 1J-158 cement.cfw ; 04-23-2007 ; LoadCase 1034 Surface ; Version wcs-cem45_89 Schluma~rg~r Q~IGI~AL (x 1000) ft ~ Client : CPAI Well : 1J-158 DLP String : 10 3/4 Intermediate District : Prudhoe Bay Country : USA Loadcase : 1034 Surface Section 2: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :3383.4 ft Casing Shoe :3393.4 ft NB of Cent. Used :106 NB of Floating Cent. :41 ~ Schluma~r~~r Centralizer Placement Bottom MD Nbr. Cent. / Cent. Name Code Min. STO @ Depth ft Joint % ft 2513.4 62 1/1 S1104610-10 3/4-6-46 36.5 1673.4 (3/16")B 3393.4 44 2/1 S1104610-10 3/4-6-46 79.1 2523.4 3/16" B Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min. OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force in in Ibf Ibf S1104610-10 3/4-6- 10 3/4 15.874 11.874 No Houma 13.500 708.15 1450.02 (1) - Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications ft O ~ 0 0 0 N O v % deg 40 - oeviaM1On ~ I -C' ~-!-~ ~ ~~-- I I ! i ~ I '~, ' ""~. ' ....................I ..._ i.._4.......'..._....;. ....: ~ I ~ ~ _.. ~ .~.... e _.,I .. i .. . Deviatan O V O ~ O ~ O ~ O F- ~ 0 o ry 0 ~ ` ~ ~ N N N Fbri. Departure Page 5 1J-158cement.cfw;04-23-2007; LoadCase1034Surface:Versionwcs-cem45_89 ~ ~ ~ ~ F ~ f t ~ Pipe Standoff (x 1000)ft ~ ~ Client : CPAI N Well : 1J-158 DLP ~~~~~~~~~ ~~ String : 103/4lntermediate District : Prudhoe Bay Country : USA Loadcase : 1034 Surface Section 3: fluid description Mud DESIGN Fluid No: 1 Density : 9.60 Ib/gal Rheo. Model : BINGHAM P~ : 15.000 cP At temp. : 80 degF Ty : 30.00 Ibf/100ft2 Gel Strength : 76.85 Ibf/100ft2 MUD Mud Type : WBM Job volume : 298.7 bbl Water Type : Fresh VOLUME FRACTION Solids : 95.0 % Oil : 0.0 % Water : 5.0 % CW100 DESIGN Fluid No: 2 Density : 8.33 Ib/gal Rheo. Model : HERSCHEL B. k : 6.68E-3 Ibf.s^n/ft2 At temp. : 80 degF n : 0.177 Ty :O.OOIbf/100ft2 Gel Strength : (Ibf/100ft2) Job volume : 50.0 bbl MUDPUSH II DESIGN Fluid No: 3 Density : 10.50 Ib/gal Rheo. Model : BINGHAM P~ : 23.000 cP At temp. : 80 degF Tv : 30.00 Ibf/100ft2 Gel Strength : (Ibf/100ft2) Job volume : 50.0 bbl DeepCRETE DESIGN Fluid No: 4 Density : 12.00 Ib/gal Rheo. Model : HERSCHEL B. k : 2.06E-3 Ibf.s^n/ft2 At temp. : 70 degF n : 0.998 Ty :9.261bf/100ft2 Gel Strength : (Ibf/100ft2) DESIGN BLEND Name : G Dry Density : 199.77 Ib/ft3 Sack Weight : 94 Ib BASE FLUID Type : Fresh water SLURRY Mix Fluid : 8.343 gal/sk Yield : 2.49 ft3/sk Porosity : 44.9 % Density :8.321b/gal Job volume : 77.7 bbl Quantity : 175.42 sk Solid Fraction : 55.1 % Base Fluid : 8.103 gal/sk 1J-158cement.cfiv;04-23-20~7; LoadCase1034Surface;Versionwcs-cem45_89 Page 6 ~~~~'~~.~L ~ Client : CPAI Well : 1J-158 DLP String : 10 3/4lntermediate District : Prudhoe Bay Country : USA Loadcase : 1034 Surface ~ Sc~I~~r~~r ASL DESIGN Fluid No: 6 Density : 10.70 Ib/gal Rheo. Model : HERSCHEL B. k : 2.22E-3 Ibf.s^n/ft2 At temp. : 80 degF n : 0.998 Ty :11.741bf/100ft2 Gel Strength : (Ibf/100ft2) DESIGN BLEND Name : G Dry Density : 199.77 ib/ft3 Sack Weight : 94 Ib BASE FLUID Type : Fresh water SLURRY Mix Fluid : 20.722 gal/sk Yield : 4.45 ft3/sk Porosity : 62.3 % Density :8.321b/gal Job volume : 461.0 bbl Quantity : 582.24 sk Solid Fraction : 37.7 % Base Fluid : 20.153 gal/sk iJ-158cement.cfw;04-23-20D7; LoadCase7034Surface;Versionwcs-cem45_89 Page 7 ~~ 8 w.,,a' ~ G 1C S ~~ ~ ~ Client : CPAI ~I ~ Well : iJ-158 ~LP ~~ rg~r ~ String : 10 3/4lntermediate District : Prudhoe Bay Country : USA Loadcase : 1034 Surface Section 4: fluid sequence Job Objectives: To cement from the shoe to 800' above with DeepCRETE(12.0), and bring ASL to surface. Original fluid Mud 9.60 Ib/gal P~ : 15.000 cP Tv : 30.00 Ibf/100ft2 Displacement Volume 318.7 bbl Total Volume 957.3 bbl TOC 0.0 ft Name Volume bbl Ann. Len ft Top ft Fluid Sequence Density Ib/ al Rheology CW100 50.0 0.0 8.33 k:6.68E-31bf.s^n/ft2 n:0.177 Tv:0.001bf/100ft2 MUDPUSH 11 50.0 0.0 10.50 P~:23.000 cP Tv:30.00 Ibf/100ft2 ASL 461.0 2593.4 0.0 10.70 k:2.22E-31bf.s^n/ft2 n:0.998 Tv:11.741bf/100ft2 DeepCRETE 77.7 800.0 2593.4 12.00 k:2.06E-31bf.s^n/ft2 n:0.998 Tv:9.261bf/100ft2 Water 20.0 3105.4 8.32 k:2.22E-31bf.s^n/ft2 n:0.998 Tv:11.741bf/100ft2 Mud 298.7 0.0 9.60 P~:15.000 cP Tv:30.00 Ibf/100ft2 Static Security Checks : Frac 7 psi at 80.0 ft Pore 10 psi at 80.0 ft Collapse 2052 psi at 3313.4 ft Burst 4230 psi at 0.0 ft Cs .Pum out 36 ton Section 5: pumping schedule Name Flow Rate (bbl/min) Volume (bbl) Pumping Schedule Stage Time Cum.Vol (min) (bbl). Inj. Temp. de F Comments CW100 5.0 10.0 2.0 10.0 80 Pause 0.0 0.0 10.0 0.0 80 Pressure Test and Drop Bottom Plug CW100 5.0 40.0 8.0 50.0 80 Pause 0.0 0.0 5.0 0.0 80 Drop wiper Plug MUDPUSH II 5.0 50.0 10.0 50.0 80 ASL 7.0 461.0 65.9 461.0 80 DeepCRETE 6.0 77.7 12.9 77.7 80 Pause 0.0 0.0 5.0 0.0 80 Drop Top Plug Water 6A 20A 3.3 20.0 80 Pause 0.0 0.0 5.0 0.0 80 Switch to Rig Pump Mud 6.0 266.7 44.5 266.7 80 Mud 3.0 30.0 10.0 296.7 80 Total 03:01 955.3 bbl hr:mn Dynamic Security Checks : Frac 7 psi at 80.0 ft Pore 1 psi at 80.0 ft Collapse 2053 psi at 3313.4 ft Burst 4017 psi at 0.0 ft 1J-158 cement.ciw; 04-23-2007; LoadCase 1~34 Surface; Version wcs-cem45_89 Page 8 ~,~ ~i~ ~ ~ ~ ~ ~. ~~ ~ ~ Client : CPAI Well : iJ-158 DLP String : 103/4lntermediate District : Prudhoe Bay Country : USA Loadcase : 1034 Surface ft 8 o~ ~ 0 0 0 N O O O V 0 0 0 ~o ~ Schiumher~~r IWc,3al 10 12 14 ~ Hin. Hydrostatic ~~ 0 N - Max. Dynartic ~ A4n. D9nartic '~.. - Frac . .._...~ _.... ~ ~8 N - Hydrostabc ~ a . ',~, '', ~ i ~ .....i.._.. o ~ 0 0.3 0.6 0.9 1.2 j Pumped Volume (bbl) (x 1000) (.._ ~ . e...... . . p C ~ ~0.' _. . ._._...._. T : = O I U ln O ;_ ~ ..! C C . . ,,, '~, , Q . ~....... ,. .... ~. O Fluid Sequence Dynamic Well Security Pumped Volume (bbl) (x 1000) ~ a ~ M a ~ ~ ~ fT~-I~I ~-~-I ITI II 0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1.0 1.1 Pumped Volume (bbl) (x 1000) m rn 9 N N~ 7 N N ~ O ~ ~-' C C Q ... ..__..._ _ __- _ - _-- - 0 0.1 0.2 0.3 0.4 0.5 0.6 0.7 0.8 0.9 1.0 1.1 Pumped Volume (bbl) (x 1000) Page 9 1J-15Bcementcfw;04-23-2007; LwdCase1034Surface;Versionwcs-cem45 89 a~eG~~~~~ ~ •'' Schlumberger _~~~~~aE ~~~~~~~~~~~~~~$~~~~ ~ -~~ ~ 7 62~_ In~ermedia#~ Casin ! ~: , Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 141 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Date: 4/23/2007 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445 email: mtorrie@slb.com Previous Csg. < 10 3/4", 45.5# casing at 3,393' MD < Top of Tail at 4,975' MD < 7 5/8", 29.7# casing in 9 7/8" OH TD at 8,023' MD (3,324' ND) Volume Calculations and Cement Svstems Volumes are based on 25% excess. Tail slurry is designed for 500' MD above the Ugnu C(5475' - 500' = 4975' TOC, 3048' MD annular length). Tail Slurry Minimum thickening time: 230 min. (Pump time plus 120 min.) DeepCRETE @ 12.5 ppg - 2.25 ft3/ft 0.2148 ft3/ft x 3048' x 1.25 (25% excessj = 818.4 ft3 0.2578 ft3/ft x 80' (Shoe Joint) = 20.6 ft3 818.4ft3+20.6ft3= 839.Oft3 839.0 ft3/ 2.25 ft3/sk = 372.9 sks Round up to 380 sks BHST = 73~', Estimated BHCT = 59~. (BHST calculated using a gradient of 2.6`F/100 ft. below the permafrost) PUMP SCHEDULE Pump Rate Stage Stage Time Cumulative Stage Volume Time ~bpm~ (bbl) (min) (min) CW 100 6 50 8.3 8.3 Drop Bottom Plug 10.0 18.3 MudPUSH II 6 50 8.3 26.6 Tail Slurry 6 152 25.3 51.9 Drop Top Plug 10.0 61.9 Water 6 20 3.3 65.2 Switch to Rig Pum s 5.0 70.2 Displacement 6 315 52.5 122.7 Slow Rate 3 30 10.0 132.7 MUD REMOVAL Recommended Mud Properties: 8.9 ppg, P~ < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Ensure that 10 min Gel Strength is as low as possible prior to job. Spacer Properties: 11.0 ppg MudPUSH* II, P~ = 19-22, TY = 22-29 Centralizers: Recommend 1 per joint across zones of interest and 2 per joint over the bottom 25 joints to ensure proper placement. ~~~~~~~~ ~~~.~ ~ ~ Schiumberger CemCAD E*well cementing recommendation for 7 5/8 Intermediate Operator : CPAI Well : 1J-158 DLP Country : USA Field : West Sak State : Alaska Preparedfor . Location . Proposal No. : V1 (wp09) Service Point : Prudhoe Bay Date Prepared : Mareh 23, 2007 Bus+ness Phone :(907) 659-2434 FAX No. : (907) 659-2538 Prepared by Phone E-Mail Adtlress Maureen Torrie 1-907-952-0445 mtorrieQslb.com ~isclaimer Notice: This informaiion is presentetl in good faith, but no warranty is given by and Schlumberqer assumes no liabiliry for advice or recommendations made concerning results to be obtained from the use of any product or service. The results given are estimates based on calculations produced by a computer model including various assumptions on the well, reservoir and ireatment. The results depend on input data provided 6y the Operator and estimates as to unknown data and can be no more accurate than ihe model, the assumptions and such input data. The information presented is Schlumberger's best estimate of the actual results that may be achieved and should be used for comparison purposes rather than absolute values. The quality of input data, and hence results, may be improved through the use of certain tests and procedures which Schlumberger can assist in selecting. The Operator has superior knowledge of the well, the reservoir, the field and conditions affecting them. If the Operator is aware of any conditions whereby a neighboring well or wells might be affected by the treatment proposed herein it is the Operator's responsibility to notity the owner or owners of the well or wells accordingly. Prices quoted are estimates only and are good for 30 days from the date of issue. Actual charges may vary depending upon time, equipment, and material ultimately required ta perform these services. Freedom from infringement of patents of Schlumberger or others is not to be inferred. ~ Mark of Schlumberger Q~R~~~~:~-~. ~ ~ Client : CPAI Well : 1J-158 DLP String : 7 5/8 Intermediate District : Prudhoe Bay Country : USA Loadcase : 7581ntermediate Section 1: well description Configuration : Casing Stage : Single Rig Type : Land Mud Line : 0.0 ft Total MD : 8023.6 ft BHST : 77 degF Bit Size : 9 7/8 in Previous String MD OD Weight ID ft in Ib/ft in 3393.0 10 3/4 45.5 9.950 Landing Collar MD : 7943.0 ft Casing/liner Shoe MD : 8023.0 ft ~~~I~~r~~r Casing/Liner MD OD Joint Weight ID Grade Collapse Burst Thread (ft) (in) (ft) (Ib/ft) (in) (psi) (psi) 8023.0 7 5/8 40.0 29.7 6.875 L-80 4790 6890 BTC 1J-158cement.ctw;04-23-2007; LoadCase7581ntermediate;Versionwcs-cem45_89 Page 2 o~~~~~~:~~ ~ ~ Client : CPAI ~c[~I~6~rg~r Well : 1J-158 DLP String : 7 5/8 Intermediate District : Prudhoe Bay Country : USA Loadcase : 7581ntermediate Mean OH Diameter Mean Annular Excess Mean OH Equivalent C Total OH Volume Max. Deviation Angle Max. DLS : 9.875 i n : 25.0 % ~iameter : 10.361 in : 482.9 bbl (including excess) : 85 deg : 5.011 deg/100ft MD ft Directional Survey Data ND Deviation Azimuth ft de de Dogleg Sev. de /100ft 0.0 0.0 0.0 0.0 0.000 40.0 40.0 0.0 0.0 0.000 100.0 100.0 0.0 0.0 0.000 200.0 200.0 0.0 0.0 0.000 300.0 300.0 0.0 0.0 0.000 400.0 400.0 2.5 277.0 2.500 500.0 499.7 5.0 277.0 2.500 600.0 599.1 7.5 277.0 2.500 702.1 7Q0.0 10.1 277.0 2.499 800.0 795.8 14.0 277.0 4.002 900.0 891.9 18.0 277.0 4.000 1000.0 985.9 22.0 277.0 4.000 1100.0 1077.2 26.0 277.0 4.000 1200.0 1165.5 30.0 277.0 4.000 1300.0 1250.3 34.0 277.0 4.000 1400.0 1331.2 38.0 277.0 4.000 1500.0 1407.9 42.0 277.0 4.000 1600.0 1479.8 46.0 277.0 4.000 1629.3 1500.0 47.1 277.0 3.990 1672.1 1529.1 47.1 277.0 0.000 1700.0 1548.1 47.1 277.0 0.000 1729.3 1568.0 47.1 277.0 0.000 1800.0 1614.5 50.6 278.2 4.997 1866.8 1655.5 53.8 279.2 5.011 1900.0 1674.7 55.4 279.6 4.982 2000.0 1727.9 60.3 281.0 5.006 2100.0 1773.7 65.2 282.2 4.993 2200.0 1811.7 70.1 283.3 5.004 2270.8 1833.8 73.6 284.0 4.999 2300.0 1842.1 73.6 283.3 2.400 2338.0 1852.8 73.6 282.3 2.396 2400.0 1870.4 73.6 282.3 0.000 2500.0 1898.7 73.6 282.3 0.000 2600.0 1927.0 73.6 282.3 0.000 2629.6 1935.4 73.6 282.3 0.000 2700.0 1955.3 73.6 282.3 0.000 2800.0 1983.7 73.6 282.3 0.000 2900.0 2012.0 73.6 282.3 0.000 3000.0 2040.3 73.6 282.3 0.000 3100.0 2068.6 73.6 282.3 0.000 3200.0 2096.9 73.6 282.3 0.000 3300.0 2125.2 73.6 282.3 0.000 3393.4 2151.7 73.6 282.3 0.000 3400.0 2153.6 73.6 282.3 0.000 3500.0 2181.9 73.6 282.3 0.000 3600.0 2210.2 73.6 282.3 0.000 3700.0 2238.5 73.6 282.3 0.000 1J-158 cement.ciw ; 04-23-2007 ; LoadCase 758 lntermediate ; Version wcs-cem45_69 Page 3 ~ ~ ~ ~ ~ ~f' .~°'~ ' ~ ~ Client : CPAI Sc~l~~rg~r Well : iJ-158 DLP String : 7 5/8 Intermediate District : Prudhoe Bay Country : USA Loadcase : 7581ntermediate Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. 3800.0 2266.8 73.6 282.3 0.000 3900.0 2295.2 73.6 282.3 0.000 4000.0 2323.5 73.6 282.3 0.000 4100.0 2351.8 73.6 282.3 0.000 4200.0 2380.1 73.6 282.3 0.000 4300.0 2408.4 73.6 282.3 0.000 4396.6 2435.8 73.6 282.3 0.000 4400.0 2436.7 73.6 282.2 3.375 4500.0 2465.0 73.6 278.8 3.299 4600.0 2493.3 73.6 275.3 3.300 4700.0 2521.5 73.6 271.9 3.300 4800.0 2549.7 73.6 268.4 3.300 4900.0 2577.9 73.7 265.0 3.301 5000.0 2606.0 73.7 261.6 3.301 5100.0 2634.1 73.7 258.1 3.301 5200.0 2662.2 73.7 254.7 3.302 5300.0 2690.2 73.7 251.2 3.302 5400.0 2718.2 73.8 247.8 3.302 5474.8 2739.2 73.8 245.2 3.297 5500.0 2746.2 73.8 244.4 3.320 5600.0 2774.1 73.8 240.9 3.303 5700.0 2802.0 73.8 237.5 3.303 5800.0 2829.9 73.8 234.0 3.304 5900.0 2857.7 73.8 230.6 3.304 6000.0 2885.5 73.9 227.2 3.304 6023.4 2892.0 73.9 226.4 3.282 6100.0 2913.3 73.9 223.7 3.312 6200.0 2941.0 73.9 220.3 3.305 6251.6 2955.3 73.9 218.5 3.297 6300.0 2968.7 73.9 216.8 3.315 6400.0 2996.4 73.9 213.4 3.306 6500.0 3024.0 74.0 210.0 3.306 6600.0 3051.6 74.0 206.5 3.306 6700.0 3079.2 74.0 203.1 3.307 6747.8 3092.3 74.0 201.4 3.296 6800.0 3106.7 74.0 199.6 3.318 6900.0 3134.2 74.1 196.2 3.307 6964.0 3151.8 74.1 194.0 3.303 7000.0 3161.4 74.9 193.2 3.308 7100.0 3185.3 77.4 190.9 3.302 7194.0 3204.0 79.7 188.8 3.297 7200.0 3205.0 79.7 188.8 0.000 7249.3 3213.8 79.7 188.8 0.000 7300.0 3222.9 79.7 188.8 0.000 7400.0 3240.8 79.7 188.8 0.000 7424.1 3245.1 79.7 188.8 0.000 7449.3 3249.6 79.7 188.8 0.000 7452.1 3250.1 79.7 188.7 2.862 7500.0 3258.6 79.7 187.3 2.957 7575.6 3272.1 79.7 185.0 2.954 7600.0 3276.4 80.2 184.4 3.147 7700.0 3291.6 82.2 182.0 3.151 7721.2 3294.4 82.7 181.5 3.131 7800.0 3303.4 84.3 179.6 3.157 7822.2 3305.5 84.8 179.0 3.145 iJ-158cement.ciw;04-23-2007; LoadCase7581ntermediate;Versionwcs-cem45_69 Page 4 a ~'`~ ~~ ~ r~'' ~ ~°,, 1.~~{~~! ~`- U Client : CPAI Well : 1J-158 DLP String : 7 5/8 Intermediate District : Prudhoe Bay Country : USA Loadcase : 7581ntermediate Directional Survey Data MD TVD Deviation Azimuth Dogleg Sev. ft ft de ) de de /100ft 7900.0 3312.6 84.8 179.0 0.000 7993.6 3321.2 84.8 179.0 0.000 8000.0 3321.8 84.8 179.0 0.000 8022.2 3323.8 84.8 179.0 0.000 8023.6 3323.9 84.8 179.0 4.093 ~ Schlum6er~~r MD ft Frac. Ib/ al Formation Data Pore Name Lithology Ib/ al 5475.0 12.50 8.20 Ugnu C 6023.4 12.50 8.20 Ugnu B 6251.6 12.50 8.40 Ugnu A 6747.8 12.50 8.20 K-13 7424.2 12.50 8.60 West Sak D 7721.2 12.50 8.60 West Sak C 7993.6 12.50 8.60 West Sak B 8024.0 12.50 8.60 TD Geothermal Temperature Profile MD TVD Temperature Gradient ft ft de F de F/100ft 0.0 0.0 25 0.0 1672.0 1529.0 30 0.3 4675.0 2514.5 56 1.2 8023.0 3323.9 77 1.6 8023.6 3323.9 77 1.6 8024.0 3324.0 77 1.6 fl o, 0 0 0 rn degF Temperature 0 ~ c c ~ ~ ' 0 o ~ 0 ~ ~ x ~ n c ~ ~ m Hori. Departure Page 5 1J-158 cement.cfw; 04-23-2007 ; LoadCase 758lntermediate ; Version wcs-cem45_89 QREGI~~~~ ~ (x 1000) ft ~ i Client : CPAI Well : iJ-158 DLP String : 7 5/8 Intermediate District : Prudhoe Bay Country : USA Loadcase : 7581ntermediate Section 2: centralizer placement Top of centralization :0.0 ft Bottom Cent. MD :8013.0 ft Casing Shoe :8023.0 ft NB of Cent. Used :108 NB of Floating Cent. :0 S~hlum6erg~r Centralizer Placement Bottom MD Nbr. Cent. / Cent. Name Code Min. STO @ Depth ft Joint °/a ft 4983.0 0 0/0 0.0 5000.1 5383.0 10 1/1 7-5/8 TR 76TR 39.3 5003.0 5663.0 14 2/1 7-5/8 TR 76TR 92.5 5403.0 7023.0 34 1/1 7-5/8 TR 76TR 72.4 5983.0 8023.0 50 2/1 7-5/8 TR 76TR 92.7 8023.0 Centralizer Description Centralizer Tests Cent. Name Code Casing Max. Min. OD Rigid Origin Hole Size Running Restoring OD OD (in) (in) Force Force in in Ib Ibf 7-5/8 TR 76TR 7 5/8 10.500 8.700 No Weatherford 9.875 375.00 3168.00 (1) - Centralizer performance data is based on tests by WEATHERFORD as per the current API 10D specifications Page 6 1J-158cement.c(w;0423-2D~7; LoatlCase7581Nermediate:Versionwcs~cem45_89 Q~IGII~~L ~ ~ Client : CPAI ~~I~f~~~rg~r Well : iJ-158 DLP String : 7 5/8 Intermediate District : Prudhoe Bay Country : USA Loadcase : 7581ntermediate Section 3: fluid description Mud DESIGN Fluid No: 1 Density : 8.90 Ib/gal Rheo. Model : HERSCHEL B. k : 1.13E-2 Ibf.s^n/ft2 At temp. : 80 degF n : 0.517 Ty :6.471bf/100ft2 Gel Strength : 21.35 Ibf/100ft2 MUD Mud Type : WBM Job volume : 344.7 bbl Water Type : Fresh VOLUME FRACTION Solids : 95.0 % Oil : 0.0 % Water : 5.0 % CW100 DESIGN Fluid No: 2 Density : 8.32 Ib/gal Rheo. Model : HERSCHEL B. k : 6.68E-3 Ibf.s^n/ft2 At temp. : 80 degF n : 0.177 Ty :O.OOIbf/100ft2 Gel Strength : (Ibf/100ft2) Job volume : 50.0 bbl MUDPUSH II DESIGN Fluid No: 3 Density : 11.00 Ib/gal Rheo. Model : HERSCHEL B. k : 4.67E-2 Ibf.s^n/ft2 At temp. : 80 degF n : 0.359 Tv :9.671bf/100ft2 Gel Strength : (Ibf/100ft2) Job volume : 50.0 bbl DeepCRETE DESIGN Fluid No: 4 Density Rheo. Model : HERSCHEL B. k At temp. : 70 degF n Tv Gel Strength DESIGN BLEIVD Name : G Dry Density : 199.77 Ib/ft3 Sack Weight : 94 Ib BASE FLUID Type : Fresh water SLURRY Mix Fluid : 7.558 gal/sk Yield : 2.25 ft3/sk Porosity : 44.9 % Density :8.321b/gal : 12.50 Ib/gal : 1.10E-2 Ibf.s^n/ft2 : 0.823 : 0.94 Ibf/100ft2 : (Ibf/100ft2) Job volume : 149.4 bbl Quantity : 372.79 sk Solid Fraction : 55.1 % Base Fluid : 7.418 gal/sk iJ-158 cementcfw; 04-23-2007; LoadCase 7581ntermediate; Versi~n wcs-cem45_69 Page 7 o~~~~~.~~ ~ ~ Client : CPAI Well : 1J-158 DLP String : 7 5/8 Intermediate District : Prudhoe Bay Country : USA Loadcase : 7581ntermediate ~~~I~~rg~r Section 4: fluid sequence Job Objectives: To isolate the Ugnu C by bringing cement 500' above the formation top (@ 5475.0' MD, 2,739.2' ND). TOC = 4975' Original fluid Mud 8.90 Ib/gal k: 1.13E-2 Ibf.s^n/ft2 n: 0.517 Tv : 6.47 Ibf/100ft2 Displacement Volume 364.7 bbl Total Volume 614.1 bbl TOC 4975.0 ft Fluid Sequence Name Volume Ann. Len Top Density Rheology bbl ft ft Ib/ al CW100 50.0 1150.0 2779.3 8.32 k:6.68E-31bf.s^n/ft2 n:0.177 Tr:0.001bf/100ft2 MUDPUSH II 50.0 1045.8 3929.2 11.00 k:4.67E-2 Ibf.s^n/ft2 n:0.359 Tv:9.67 Ibf/100ft2 DeepCRETE 149.4 3048.0 4975.0 12.50 k:1.10E-21bf.s^n/ft2 n:0.823 Tr:0.941bf/100ft2 Water 20.0 7507.4 8.32 k:6.94E-31bf.s^n/ft2 n:0.281 Tv:0.071bf/100ft2 Mud 344.7 0.0 8.90 k:1.13E-2 ibf.s^nift2 n:0.517 Tr:6.47 Ibf/100ft2 Static Security Checks : Frac 40S psi at 3393.0 ft Pore 73 psi at 3393.0 ft Collapse 4481 psi at 7943.0 ft Burst 6880 psi at 3929.2 ft Cs .Pum out 39 ton Section 5: pumping schedule Name Flow Rate (bbl/min) Volume (bbl) Pumping Schedule Stage Time Cum.Vol (min) (bbl). Inj. Temp. de F Comments CW100 5.0 10.0 2.0 10.0 80 Pause 0.0 0.0 10.0 0.0 80 Pressure test lines CW 100 5.0 40.0 8.0 50.0 80 Pause 0.0 0.0 5.0 0.0 80 Drop bottom plug MUDPUSH II 6.0 50.0 8.3 50.0 80 DeepCRETE 6.0 149.4 24.9 149.4 80 Pause 0.0 0.0 5.0 0.0 80 Drop top plug Water 5.0 20.0 4.0 20.0 80 Pause 0.0 0.0 5.0 0.0 80 Switch to rig Mud 7.0 314.7 45.0 314.7 80 Mud 3.0 30.0 10.0 344.7 80 Total 02:07 614.1 bbl hr:mn Dynamic Security Checks : Frac 108 psi at 8023.0 ft Pore 43 psi at 7424.2 ft Collapse 4422 psi at 140.0 ft Burst 6331 psi at 0.~ ft Page 8 7J-758cement.ciw;a4-23-2007; LoadCase7581ntermediate;Versionwcs-cem45_89 . > ~ ~ ~ ~ : ~: k:,.~'i ~.. ~~~~~°'~~~~ ~ ~ Client : CPAI Well : 1J-158 DLP String : 7 5/8lntermediate District : Prudhoe Bay Country : USA Loadcase : 7581ntermediate ft 8 o~ ~ O O M 0 0 0 ~ o~ 0 0 X .N ao ui y ~ a` ~ o° • ~ch~u~b~rg~r IWgal 10 12 14 I._~ i l _ 0 250 500 750 Pumped Volume (bbl) - Nin. Fydrostatic -~ °o ~p - Max. Dynartic - A4n. D~nartic - Frac ~ ~o - Pof0 ~y V ~ Fiydrostatic a a . ~, . ~ . ~~., . x> > N I O 0 100 200 300 400 500 600 700 Pumped Volume (bbl) Deoth = 6880 ft v m o~ ~ N N~ 7 N N ~ O a~ c c a Pumped Volume (bbl) Page 9 1J-158cement.ciw;04-23d007; LwdCase7581ntermediate;Versionwcs-cem45_89 ~~~~~~~~~ ,# Fluid Sequence • Client : CPAI Well : 1J-158 DLP String : 7 5/8lntermediate District : Prudhoe Bay Country : USA Loadcase : 7581ntermediate Section 6: WELLCLEAN II Simulator ft % % 0 50 100 0 100 o~ - Std Betw. Cent. - Mud Contarmation - Cement Coverage - Uncontaminated Slurry 0 O O M O O O ~ O O O W- Fluid Sequence Cement Coverage Fluids Concentrations ~ z° ~ dS00 d500 5000 5000 5900 5500 ~ sooa S baoo = 2 o s5oo s~oo 0 7004 7040 7500 ~500 8000 8000 0 ~•.4ud ~ MUDPUSH II ~ '~~Jater ~ CVJ100 ~ DeepCRETE ~ deg Schlumaerg~r Uncontaminated Slurry Deviation Risk Mud on the Wan ~ i ~ a500 5000 5500 -- boao =- S L o s3oo 0 ~ooo 7500 8000 ~ High ~ Low ~ Medum 0 None iJ-158cement.cfw;04-23-2007; LoadCase7581ntermediate;Versionwcs-cem45_89 Page 10 Q~IGIf~AL . . Wellhead / Tnbing Head / Tree, 103/4" x~ ~ ~ ~ . ~ 4_%" 5,000 ksi ~ ~ .~ O ~ Insulated~ Conductor .~ Tubing String: 4-1/2", 12.6 #, L-8Q IBTM, n Casing, 20", 94#, K55 x ~ ~ - 520" OD Connections 34", 0312" WT @ ~~ +/- 80' MD ~ ~ ~ . . ~ ~ (1) 3.875" DB nipple set+/- 500' D~ v~ 103/4", 45.5#, L-8Q BTC ~ @ 3,393' MD / 2,152' TVD ~~ . . @ 73.5 degrees . ~ 1D 16" hole ' Top nf Ugnu G @ -~ 5,475' MD!'i2,739' TVD ~ A ~ ~ F v~ v~ "d A ~ o e~ ya. ~ n A ~ ~ z r' ~ ~ ~ r+ 4 r+ ~ m Top of Wes1 Sak D@ 7,449' MD ! 3,250' TVD -- ---~ (1) Gas Lift Mandrel, CAMCO 4-1/2" x 1" Model KMBG w/ dummy valve, @< 69 deg Electric Snbmersible Pnmp, Centrilift 418 HP motor, with FC6000 wireline deployed pnmp. ~- Bottom et 7,350' MD, 3,230' TVD ~ 158 Ll "D" Sand Window ~ ~ //~~ @ 7,449' MD / 3,250' TVD ~ ~ 80 degrees \~"D" Liner, 4-1/2", 11.6#, L80, BTCM `' ~jTpp 6l~ WeSL ~aak $~ ~ ~ ~~ B Sand Liner, 4-1/2", I 1.6# L80, BTCM ? 994~ MD f3 442' TVD ~ o; '_ ~~ ' - ~ Seal bore and ZRP packer for B liner . ~, o ~ ~ ~ 7,549' MD, 3,265' TVD ~ ~g o b b= s a ~' ~ ~ ~ ~ ~ 7-5/8", 29J#, L-80, BTCM, Csg ~ ' ~ ' b o '~~ y ~v A Uo ~. . ~ . . . @8.024 MD/3,3?A TVD @ 85 degrees TD 9-7/8" hole . . . 1J-158 LI: 6-3/4" "D" sand lateral TD 12,225' MD / 3,228' TVD Angle 89 degrees 1J-158: 6-3/4" B sand lateral ~ TD 12,231' MD / 3,300' TVD ~ Angle 89 degrees ~ • CQ110C0~'11~~Ip5 Alaska ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Mile Pool Scan Sperry Drilling Services nPri~ ii, Zoo~ HALLIBURT~N Drilling and Fermaeion Evaluation P ~ ~ ~ ~~, ~' ~ ~ ~ . ~ ~~. ~~ ~. • Closest in POOL ~ ClosestA roach: Reference Well: 1J-158 L1 w 9 Plan Offset Well: 1J-768 L2 Coords. - Coords. - ASP ASP 3-Dctrct ~._.~v,t:ai Sab9~~ Meas. Subsea N(+)/S(-) ViewVS Meas. Subsea N(+)~S(-) VewVS Distance )r,7~ _ifEer~ ;=:-_ De lh Incl. M le TRUE Azi. ND E+/yy - 180° Comments De h Incl. M le TRUE Azi. TVD E+/yy _ 180° Comments m is ance ~ POOL Min Distance (1024.18 ft) in POOL (1024.18 R) in POOL (7424 • 7222529 MD) (7424 - 1222529 MD) l0 1J-158 L7 (wp09) l0 1J-768 L2 (6783 - Plan (6783 - 72959 1024.1 Si5 5~3E3<` 7424.15 79.71 18879 3724.358 5944799.1 553706 1028.643 12959 MD) 675974 7523 347.55 3098.96 59457822 553992.3 -16624 MD) ClosestA roach: Reference Well: 1J-158 L1 w 9 Plan Offset Well: 1J-160 L2 Coortls. - ~ Coords. - ~ ASP ASp 3-D ctr-ctr I~ori~cr;zz<7 i>.;Eas~ Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) Yew VS . Distance. i)~.si~t `)i°rmrr ~r~;e De h Incl. M le TRUE Azi. ND E+/W - 780° Comments De h Incl. An le TRUE Azi. ND E+~yy _ 180° Commente m is ance POOL Min Distance (1239.17 ft) in POOL (1239.77 R) in POOL - Q424 - 1222529 MD) (7424 • 7222529 MD lo iJ-158 Li (wp09) lo iJ-160 ~2 (8387 - Plan (8367 - 73067 1239.1 _;5.1d3'r"-~: 7700 88.63 181.98 3149.973 5944526.1 553680.6 1307.505 13067M0) 8365.39 80.12 18923 3094.83 5944548.9 552442.9 1229J2 MD) ClosestA roach: Reference Well: 1J-158 L1 w 9 Plan Offset Well: 1J-156L2 Coortls. - Coords. - ASP ASP 3•D ctr~Xr Nari_7 __~.. Meas. Subsea N(~)/S(-) Vew VS Meas. Subsea N(+)/S(-) View VS Distanee - I- -- De h Incl. M le TRUE Azi. ND E+/W - 180° Comments De h Incl. M le TRUE Azi. ND E+/yy- 780 Comments m i ance . POOL Min Dislance (1625.68 ft) in POOL (1625.65 ft) in POOL (7424 - 1222529 MD) . . (7424 - 1 2725 29 MD) lo iJ-158 L7 (wp09) to 1J-156L2 (5697- Plan (5697. 12566 7625.6 - i xtzs b ' : 1222529 89.43 176.82 3707.094 59400302 554116 5800.654 12566 MD) 10007.3 91.09 1802 3257.83 5940036.3 5557347 5845.62 MD) POOL Summary Templale.~s 4/11/2007 10:54 AM ~~~~~~~~ ~ f ~ ~ '~ ' ~ ' ` "`~ €a..,~ ~. < a . _ s ~ ~ ~' Prqect: Kuparuk River Unit ~O~O~'II' 5 Site: Kuparuk 1J Pad ~ Well: Pian 1J-158 !'Jaska Wellbore: 1J-158 Plan: 1J-158 (wp09) I-~lAL~EBIlRTON ~ , Bp~ev~y DNllinp Ssrvlosa , ~~iC+z~oorvimsiao+eill ,.,,, r~o,m~~a:as ~~~. EaspnglFSF %: 558658.89 CASING DETAILS No MD ND NDss Name Size 1 3393.43 2151.72 2030.7210 3/4" 103/4 2 8023.61 3323.94 3202.94 7 5/8" 7-5/8 3 12230.66 3300.17 3179.17 4 1/2" 4-1/2 10 3/4" 7 5/8~ i .~ , ~~ ~' - 4 1 /2" - _ 1J-158 L1 (wp i/ ~ 1J-156L2~ J-158(wp09) 1J-156L1 / ' / _ . / ............ . - . . .; 1J-168 L2 1J-168 L1 ~ ~ ~ ~ ~ ~ ~ ~ ia l b-~.~ ~s ; i g Zl2 ~ a ?. ~. '~ ~s~ ~ ~ ~ S~ ~S ~s"~ s~9 y r~ ~~ ~ ~'~~ Z~ . cl! ~,.' Project: KuparukRiverUnit I CASINGDETAILS ~ ~ ~OI]LIII'MS Site: KuparukiJPad C - ~ O~ ~ ~ ~ F+ Welt: Plan 1J-158 No MD ND NDss Name Size Alaska Wellbore: 1J-158 1 3393.43 2151.72 2030.72 10 3/4" 103/4 ~ Plan: 1J-158 (wpo9) " 7-5/S Z 8023.61 3323.94 3202.94 7 5/S w °~ ~ GroundLevel: 81.00 3 12230.66 3300.17 3179.17 41/2" 4-1/2 ~ HALLIBURTON RKB: D15~40+87)~721.OOft~D15(dM81~) NoRhinglASP V: 5945866.71 Sp~r!'y 01'illiny Sarv/cp Easti~ylASP X: SSB658.89 ~ -_ . . _-___._ _ . . .__.- ,-_ -_ ,,_ .. 1J-168 1 i " 6000 _ _.. _ _._ . _.. ... - - I 1J-168 L2 ' ~ ~ 3000 ; ~ 'c ~ ' ' I j ,. o ~ 0 n ....._.. ...... _... _ .__ __ + C O 2 t I i I o -3000 ~ ~ I I 1J-160 L2 I _ -- - 1J-158 (wp09) I ~ ~ ~ -6000 I -- 1J-160 L1 _ _ __ __ - - 1J•158 L1 (wp09~....... ....... . ~~I I I ,, _ 1J•156L2 I ~ I I -9000 , I -- 1J-756LA~- -~ i . I -15000 -12000 -9000 -6000 -3000 0 3000 6000 9000 West(-~1East(+) (3000 N/in) . • ~ ~ ~~~(5~~~'~~~. ~~~~~~$ ~:~~~~L~S~ ~VEI,L rANtE ~~1~ ~ ~°.~~ ~~~ P'I'D# ~-~ ~' ~ ~ ~ ~` Development Service Exploratory Sta-atigraphic ~'est Non-Conventioaal Wetl Circle 4ppropriate Letter / Paragraphs to be dneluded in Transmittal Letter ~ ~ ~ CHECK ~ ADD-ONS T'EXT FOR APPROVAL LETTER ; Vb'HAT ~ (OPTIONS) i ' APPLIES ~ ~ I ~ I MliLTI LATERAL ' The permit is for a new we(Ibore segment of existing ~ ~ ~ wefl ~~ (If last two digits ~n i Permit ~to. , A.PI ~fo. ~0- - - i API number are ; ~ I ;' between 60-69) ; Production shoutd continue to be reported as a function of the i ~ original API number sta.ted above. i ~ ~ i ~ P[LOT E[OLE ~[n accordance with 20 A.AC 2~.00~(~, all records, data and logs ~ ; ; acquired for the pilot hole must be c(early differentiated in both ~ i ; well name ( PF~ and API number ~ ; I'' (50- - -~ from records, data and lo~s ~ ,' f acquired for well ~ ~ SPACING ' EXCEPTION ; i' i ~ The permit is approved subject to full compliance with 20 AAC ~ ~ 2~A». Approval to perforate and produce / in~ect is continoent i I upon issuance of a conservation order approving a spacing j j exception. assumes the ~ i liability of any protest to the spacing exception that may occur. i i i DRY D[TCH ~ ~ A1[ dry ditch sample sets subrnitted to the Commission must be in ; i SA!~iPLE I no greater than 30' sample intervals from be(ow the permafrost or ~ ! I from where samptes are Frst caught and 10' samp(e intervals j ; ~ through target zones. ; ~ ; Please note the following speciai condition of this permi*_: ~ ; Non-Conventional ~ i production or production testing of coa! bed methane is not allowed ~ i~' z~l ~ for (name of welll until after (Companv Name) has designed and ! ~ ~ implemented a water well testing program to provide baseline data I j ; on water quality and quantity. (Compan,y Name) must contact the ; ~ Commission to obtain advance approval of such water well testing ! ~ program. ~ Rev: ('Z~i06 C:! jody~transmittal_checkfist ~ ~ ^^ ~ ~ , ~ ~ ~ ~ ~ ~ ~ ; ~ ~ ~ ~ ; a~; ~ ~ ~ ~; ~ ~ ~ ~ a°'i a , , ~ o. y y . . , , . ~ . , ~ ~ ~ ~ ~ ~ ~ N, ~ ~ ~ ~ . ~ ~ , ~ N 0 ~ ~ ~ ~ ~ ~ ~ ~ , ~ , ~ ~ ~ ~ , . , ~ ~ ~ ~ ~ , ~ , , ~ , , , ~ ~ ~ , . ~ , ~ C~ ~ ~ ~ ~ ~ ~ ~ , ~ O ~ i ~ , ~ , ~ , , ~ , ~~ ~ , ~ ~ , ~ ~ ~ ~ Q ~ , N ~ ~ O~ ~ ~ ~ . ~ ~ ~ ~ ~1 ~ ~ ~ ~ ~ ~ , ~ ~ ~ ~ m ~ ~~ ~ ~ ~ ~~~ ' ~ , , ~ U~ , ~ ~ ~ , , , ~ ~ ~ ~ ~ ~ ~ , ~ ~ ~ ~ °~ ~ a p ~ ~ ~. , ~ ~ , ~3; ~ ~ ~ ~ . -o, , , ~ , ; ~ ~ ~' ~ E c a , , , , 3 ~, ~ , , v, ~ ~ O , ~ y , , ~ ~, N , ~ g; ~ ~ ~ ~ ~ , a rn , , ~ , , , o a ~ ~ a v p L ~ , ~ ~ O~ ~, ~ ~ ~ ~ ~ , , ~ ~ ~ ~ ~ ~ , . ~ ~ ~~ ' ~ ~~ ~ OD ~ ~ , , ~ ~ , ~ a N~ ~ ~ N 3 W tn , c i, , ~ ~ , ~ N, - ° m, ~ ~ p O , t 1° , o' a o~i' ~' i a. 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No special effort has been made to chronologically _ organize this category of information. 0 • • ~ 17158006072007ssN.txt Sperry-5un Drillin9 Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Sep 06 09:38:04 2007 Reel Header Service name .............LISTPE ~ate . ...................07/09/06 Ori 9in ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing ~ibrary, scientific Technical services Tape Header Service name .............LISTPE ~ate . ...................07/09/06 Origin ...................sTs Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Comment rtecord TAPE HEADER Kuparuk River unit west sak MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MWD RUN 2 706 NUMBER: w-0005034555 LOGGING ENGINEER: B. HENNINGSE OPERATOR WITNESS: M. THORNTON # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD scientific Technical services 1~-158 500292335600 ConocoPhillips Alaska Inc. sperry ~rilling services 05-SEP-07 MWD RUN 3 w-0005034555 R. FRENCH M. THORNTON 35 11N lOE 2055 2550 121.55 81.00 Page 1 ~o"~-- C~~-/ ~ t S S~~ . ~ 171580060720075sN.txt OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 9.875 10.750 3393.0 2ND STRING 6.750 7.625 7890.0 3RD STRING 4TH STRING # REMARKS: ~ 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (ND). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 4. MWD RUNS 2& 3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE-WHILE-DRILLING (PWD), AND GEO-PILOT ROTARY STEERABLE BHA (GP). 5. 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. 6. MWD RUNS 1-3 REPRESENT WELL 1J-158 WITH API#: 50-029-23356-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12268'MD/3301' ND. 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). $FXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). File Header Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/09/06 Maximum Physical rtecord..65535 File Type. ............LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD ~epth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH Page 2 ~ • 1.7158006072007ssN.txt GR 3371.0 12219.0 RPD 3380.0 12226.0 FET 3380.0 12226.0 RPS 3380.0 12226.0 RPM 3380.0 12226.0 RPx 3380.0 12226.0 ROP 3405.5 12268.0 $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MwD 2 3371.0 7900.0 MwD 3 7900.0 12268.0 $ # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Log~ing Direction .................Down optical log depth units...........Feet Data rteference Point ..............undefined Frame Spacing....... ............60 .1zN Max frames per record .............undefined absent value ......................-999 Depth Units. . .. .. ..... ~atum specification Block sub-type...0 Name service order units size wsam rtep 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 Servi ce Unit Min Max Mean Nsam Reading Reading DEPT FT 3371 12268 7819.5 17795 3371 12268 RPD MWD OHMM 0.48 2000 41.7901 17693 3380 12226 RPM MwD OHMM 0.06 2000 32.9562 17693 3380 12226 RPS MwD OHMM 1.35 2000 32.8241 17693 3380 12226 RPx MwD OHMM 1.55 2000 36.7385 17693 3380 12226 FET Mw~ HOUR 0.12 99.89 1.27299 17693 3380 12226 GR MwD API 21.11 124.62 67.3168 17697 3371 12219 ROP MwD FT/H 3.6 1535.71 241.636 17726 3405.5 12268 First Reading For Entire File..........3371 ~ast Reading For Entire File...........12268 Page 3 ~ • 1~158006072007SSN.txt File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......07/09/06 Maximum Physical Record..65535 File Type ................~0 Next File Name...........STSLIB.002 Physical EOF File Header Service name... .,.....STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/09/06 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 for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 3371.0 7866.0 FET 3380.0 7849.5 rtPx 3380.0 7849.5 RPS 3380.0 7849.5 RPM 3380.0 7849.5 RPD 3380.0 7849.5 ROP 3405.5 7900.0 $ # LOG HEADER DATA DATE LOGGED: O1-JUN-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 72.13 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 7900.0 TOP LOG INTERVAL (FT): 3405.0 BOTTOM LOG INTERVAL (FT): 7900.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 72.9 MAXIMUM ANGLE: $2.7 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 053516 EWR4 ELECTROMAG. RESIS. 4 81390 $ # BOREHOLE AND CASING DATA Page 4 • ~ 17158006072007ssN.txt OPEN HOLE BIT SIZE (IN): 9.$75 DRILLER'S CASING DEPTH (FT): 3393.0 # BOREHOLE CONDITIONS MUD TYPE: Native/Spud Mud MUD DENSITY (LB/G): 9.10 MUD VISCOSITY (S): 58.0 MUD PH: 9,5 MUD CHLORIDES (PPM): 200 FLUID LO55 (C3): 4.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 2.000 72.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.280 116.6 MUD FILTRATE AT MT: 3.000 72.0 MUD CAKE AT MT: 2.400 72.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # ~ata Format specification Record Data Record Type... ..........0 ~ata Specification Block Type.....0 Log~ing Direction .................DOwn optical log depth units...........Feet ~ata tteference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. . .. .. ..... Datum specification Block sub-type...0 -vame service order units size Nsam rtep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3371 7900 5635.5 9059 3371 7900 RPD MWD020 OHMM 0.48 2000 18.3899 8940 3380 7849.5 RPM MWD020 OHMM 0.34 2000 16.2641 8940 3380 7849.5 RP5 MWD020 OHMM 1.35 169.18 15.0902 8940 3380 7849.5 RPx MWD020 OHMM 2.5 1936.54 14.3083 8940 3380 7849.5 FET MwD020 HOUR 0.15 95.53 0.969692 8940 3380 7849.5 GR MWD020 API 21.11 115.39 65.985 8991 3371 7866 RoP Mw~020 FT/H 3.91 1535.71 261.837 8990 3405.5 7900 Page 5 ~ ~ 171580060720075sN.txt First Reading For Entire File..........3371 ~ast Reading For Entire File...........7900 File Trailer Service name... .......STSLIB.002 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/09/06 Maximum Physical Record..65535 File TyC~ e ................LO Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/09/06 rwaximum 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: 3 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH RPX 7850.0 RPD 7850.0 RPM 7850.0 FET 7850.0 RPS 7850.0 GR 7866.5 oP 7900.5 $ # 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: # STOP DEPTH 12226.0 12226.0 12226.0 12226.0 12226.0 12219.0 12268.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EwR4 Electromag Resis. 4 Page 6 07-JUN-07 Insite 72.13 Memory 12268.0 7900.0 12268.0 82.6 95.8 TOOL NUMBER 64001 159439 ~ LJ ~ 171580060720075sN.txt $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.750 DRILLER'S CASING DEPTH (FT): 7890.0 # BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LBjG): 8.45 MUD VISCOSITY (S): 60.0 MUD PH: .Q MUD CHLORIDES (PPM): 22000 FLUID LOSS (C3): 6.3 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: .000 112.0 MUD FILTRATE AT MT: .000 .O MUD CAKE AT MT: .000 .O # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: # ~ata Format specification Record Data Record Type... ..........0 ~ata specification Block Type.....0 Log~iny Direction .................DOwn optical log depth units...........Feet ~ata Reference Point ..............undefined Frame Spacing....... ............60 .1zN Max frames per record .............undefined Absent value ......................-999 Depth Units. . .. .. ..... ~atum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7850 12268 10059 8837 7850 12268 RPD Mw~030 OHMM 5.87 2000 65.6902 8753 7850 12226 RPM MWD030 OHMM 0.06 2000 50.0049 8753 7850 12226 RP5 MWD030 OHMM 5.42 2000 50.9368 8753 7850 12226 rtPx MWD030 OHMM 1.55 2000 59.648 8753 7850 12226 FET MwD030 HOUR 0.12 99.89 1.58277 8753 7850 12226 GR MwD030 API 24.27 1 24.62 68.6922 8706 7866.5 12219 Page 7 ~ • 17158006072007ssN.txt RoP Mw~030 FT/H 3.6 414.37 220.849 8736 First Reading For Entire File..........7850 ~ast Reading For Entire File...........12268 File Trailer Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 ~ate of Generation.......07/09/06 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF Tape Trailer Service name .............LISTPE ~ate . ...................07/09/06 Origin ...................5T5 Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer Service name .............LISTPE ~ate . ...................07/09/06 Origin ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Physical EOF End Of LIS File 7900.5 12268 scientific Technical services scientific Technical services Page 8