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Home My WebLink About207-121• Ilmac~e Pircaject Well ITli~tc~lry IMile ~a~er ~'ac~e XI-{VZE 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 ~ - ~ ~ ~ Well History File Identifier Organizing (done> Two-sided III II~III (I III II ~~~ RE AN DIGITAL DATA Color Items: Diskettes, No.' ^ Greyscale Items: ^ Other, No/Type: ^ Poor Quality Origina{s: ^ Other: Re,~a~~eeaea uuuuiuiiuuii OVERSIZED (Scannable) ^~ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ ~ ' ~©g /s/ Project Proofing III II'III IIIII II III BY: Maria Date: I /s/ Scanning Preparation ~_ x 30 = + ~ =TOTAL PAGES (Count does not include cover sheet) BY: Maria Date: /s/ '' III IIIIII IIIII II III Production Scanning Stage 7 Page Count from Scanned File: ~~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ,~,~ YES NO BY: Maria Date: ~ ~' ~ ~ ~ ~ /s/ Q ,~ Stage 7 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III II'I II I II II II III ReScanned BY: .Maria Date: /s/ Comments about this file: Quality Checked III II~III III IIII III 10/6!2005 Well History File Cover Page.doc 7--:‘-,L � Aw .i t. St . — 333 Wes, Seventh A�er�E K,,,, ( ()�' 12 •!4`i2 SEAN \R1\F,L1. Anc'norace. Alaska 99501-3572 MJ Loveland EO AUL �� Well Integrity Project S-- ConocoPhillips Alaska, Inc. 1 �i P.O. Box 100360 ��7 Anchorage, AK 99510 Re: Kuparuk River Field, West Sak Oil Pool, 1J-178 Sundry Number: 314-313 Dear Ms. Loveland: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, orthe next working day if the 23rd day falls on a holiday or weekend. Sincerely, /°)764, Cathy . Foerster Chair i-4L DATED this day of May, 2014. Encl. RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAY 13 ,20: APPLICATION FOR SUNDRY APPROVALS 14" 20 AAC 25.280 AOGC 1.Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re-enter Susp.Well r Stimulate r Alter casing r Other:OA Cmt Shoe (7 • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. Exploratory r Development F 207-121 3.Address: Stratigraphic r Service 6.API Number: P. O. Box 100360,Anchorage,Alaska 99510 50-029-23368-00 ' 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No F' Kl'cl_ 1J-178 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL25661,ADL25662,ADL25663,ADL385172 • Kuparuk River Field/West Sak Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 17083 3263 • Casing Length Size MD TVD Burst Collapse CONDUCTOR l,- 79 20 122' 1122' 1530 520 SURFACE 3624 13.375 3667' 2199' 5020 2260 INTERMEDIATE 8940 9.625 8980' 3280' 5750 3090 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8960'-17002' ' 4.5 L-80 7294 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) Baker MLZXP liner Top packer , 8416'MD, 3199'TVD No SSSV no SSSV 12.Attachments: Description Summary of Proposal , (i.- 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development Po Service r 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 6/1/2014 Oil rii Gas r WDSPL r Suspended r 16.Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: MJ Loveland/Martin Walters Email: n1878@cop.com Printed Name Loveland Title: Well Integrity Project Signature .� j�% i Phone:659-7043 Date:54g)14 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness 3kg—k,"3\3 Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r Other: Spacing Exception Required? Yes ❑ No / Subsequent Form Required: /D — 4 O 4-- APPROVED BY Approved by:ae. �G� COMMISSIONER THE COMMISSION Date -2-2--14(A roved aR IGiclrnths from th to of approval. Form 10-403(Revised 10/2012) pp p i \ I` 41,4b13 of Submit Form and Attachments in Duplicate U2- = 5/zi/J4l��y F BCMS MAY 2 3 201.1-* s lory MAY 1 2014 ConocoPhillips AoGCC Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 May 9, 2014 Commissioner Foester Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Foester: Enclosed please find the 10-403 Sundry from ConocoPhillips Alaska, Inc. for well 1J- 178, PTD 207-121 to pump a surface casing cement shoe. Please call MJ Loveland or Martin Walters at 659-7043 if you have any questions. Sincerely, /47—_// MJ Loveland ConocoPhillips Well Integrity Projects Supervisor ConocoPhillips Alaska,Inc. West Sak Well 1J-178 (PTD 207-121) SUNDRY NOTICE 10-403 REQUEST 05-03-14 The purpose of this Sundry Notice is to notify the AOGCC of ConocoPhillips Alaska, Inc., intent to pump a cement shoe in the surface casing on West Sak packerless ESP well 1J-178. A surface casing cement shoe was not pumped when the wells was drilled in 2007. The cement shoe is required in order to perform a pressure test to confirm production casing and surface casing barriers. With approval, the OA cement shoe will require the following general steps: 1. Pump cement designed for a 1000' linear shoe in the OA. 2. Displace cement with freeze protection fluids 3. Wait 72 hours on cement 4. MITOA to 1800 psi and/or establish LLR. 5. Submit 10-404 to AOGCC. WI Project Supervisor 5/9/2014 rKUP 1J-178 Conocor111lIips1if Well Attributes Max Angle&MD TD • Wellbore API/UWI Field Name Well Status Incl(°) MD(ftKB) Act Btm(ft68) Alaska.Inc 500292336800 WEST SAK PROD 92.12 14,204.90 17,083.0 ConocnftWups Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date Well ConfiE:MULTIPLE LATERALS-1J-178,423/20114-02:39 PM SSSV:NONE 40 8/8/2010 Last WO: -- 44.34 11/16/2007 Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: _ Rev Reason:FORMAT UPDATE Imosbor 4/23/2011 Tubing Hanger, , -Casing Strings36 - - -..- $ Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD) -String Wt...String String Top Thrd CONDUCTOR 20 19.124 43.2 122.0 122.0 95.50 I-I-40 WELDED Casing Description String 0... String ID...Top(ItKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd C 7. Casing 133/8 12.415 43.1 3,666.7 2,198.9 68.00 1-80 BTC Casing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt...String...String Top Thrd 1 INTERMEDIATE 95/8 8.835 40.4 8,980.0 3,279.9 40.00 L-80 BTC-M Casing Description String 0... String ID...Top(ftKB) Set Depth(/...Set Depth(ND)...String Wt...String... String Top Thrd B-SAND LINER 51/2 4.950 8,415.7 17,046.2 3,261.2 15.50 L-80 BTC Liner Details �=,. Top Depth (TVD) Top Incl Nonni... Top(ftKB) (ftKB) r Item Description Comment ID(in) 8,415.7 3,199.4 79.87 PACKER BAKER MLZXP LINER TOP PACKER 7.010 CONDUCTOR, 8,436.9 3,203.3 80.31 HANGER BAKER FLEX LOCK LINER HANGER 7.020 43.1 7,z 8,442.2 3,204.2 80.32)(0 BUSHING CROSSOVER BUSHING 4.920 8,443.6 3,204.4 80.32 SBE BAKER SEAL BORE EXTENSION 4.750 PATCH.1,980 II Casing Description String 0... String ID...Top(ftKB) Set Depth(8...Set Depth(TVD)...String Wt...String...String Top Thrd ESP Liner RAM Seal Bore 41/2 3.958 8,359.0 I 8,453.7 3,206.1 12.60 L-80 Hyd 521 MANDREL - Diverter _ __ ___ , It Liner Details NI Top Depth IND) Top Inc! Nonni... PATCH,2,008 Top(ftKB) (ftKB) (•) Item Description Comment ID(in) 8,359.0 3,189.3 79.52 DIVERER Seal Bore Diverter-length above collet f/RAM Hanger 7.550 8,362.0 3,189.8 79.54 DIVERTER 'Seal Bore Diverter,-Length below collet,4-1/2"IBT Pin down 3.680 8,417.1 3,199.7 79.88 NIPPLE 4-1/2"Camco"DB-6"Nipple w/3.562'No-Go Profile 3.562 8,424.1 3,200.9 79.92 ANCHOR MLHR Production Anchor 4-1/2"IBT Box up(Above Collet) 3.910 8,428.5 3,201.8 80.29 ANCHOR MLHR Production Anchor 4-12"IBT Pin Dn(Below Collet) 3.910 SURFACE. 43.3,667 - 8,450.5 3,205.6 80.34 SEAL ASSY Baker 4.5"Seal Assy.w/4.5"STL box up O.D.4.75"I.D.3.88" 3.880 Tubing Strings Tubing Description String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd TUBING 41/2 3.958 35.8 7,294.0 2,968.1 12.60 L-80 IBTM DISCHARGE, - 7,149 Completion Details MI Top Depth (TVD) Top Incl Nonni... NB. Top(MB) (KB) r) Item Description Comment ID(in) INTAKE,7,232 7,149.0 2,939.0 77.43 DISCHARGE Unique Pressure Discharge Sub 3.833 SEAL,7,242 Ilr MOTOR,7.286 7,231.7 2,956.6 77.95 INTAKE TTC Crossover w/Screen Intake(5.13"O.D.) 0.000 SENSOR, 7.290 7,242.3 2,958.9 78.01 SEAL Lower Tandem Seal Section GSB3DB FER HL SSCV SB/SB PFSA CL5 0.000 CENTRALIZER, Liner RAM sea1111� - 1', 7,256.1 2,961.8 78.10 MOTOR Motor 418 HP KMHG 0.000 Bore Diverter, \ - ..j 7,290.0 2,967.1 76.80 SENSOR A-Well I pump guage(4.5"O.D.) 0.000 8.3548,454 \ NTERMEDIATE, - 7,292.0 2,967.6 76.82 CENTRALIZER Motor Centralizer(5.875"O.D.) 3.958 40-8.980 8,960-11,833 Slots, Other In Hole(Wireline retrievable plugs,valves,pumps,fish,etc.) Slots, Top Depth 11,83516,657 Slots, IND) Top Incl 16,82417,002i Top(ftKB)- (ftKB) (•) _ Description Comment Run Date ID(in) DSAND I 1,980.0 1,645.6 65.49 PATCH 4.5"ER PACKER,SPACER PIPE,SNAP LATCH ASSY; 5/10/2009 2.250 8.30417.027 OAL=31'2", SET ACROSS GLM @ 1994' 2,008.0 1,657.6 66.80'PATCH WEATHERFORD 2.5"ER PACKER OAL=4.08' 4/26/2009 2.375 Perforations&Slots Shot Top(TVD) Btm(ND) Dens 49 Top(ftKB)Btm(CKB) (ftKB) (ftKB) Zone Date lah••• Type Comment / 8,960.0 11,833.0 3,278.7 3,278.5 WS B,1J-178 10/25/2007 32.0 Slots 2.5"x.125,4 circumferential rows/ft 3" centers staggered 18 deg,3' non-slotted ends 11,835.0 16,657.0 3,278.5 3,251.7 WS B,1J-178 10/25/2007 32.0.Slots 2.5"x.125,4 circumferential rows/ft 3" centers staggered 18 deg,3' 1 non-slotted ends t I J 16,829.0 17,002.0 3,254.0 3,259.1 WS B,1J-178 10/25/2007 32.0 Slots 2.5"x.125,4 circumferential rows/ft 3" �, centers staggered 18 deg,3' non-slotted ends dotes:General&Safety . End Date Annotation ®- 12/82007 NOTE:MULTI-LATERAL ESP WELL 1J-178(BSAND),1J-178L1(D-SAND) H 10/13/2008 NOTE:VIEW SCHEMATIC w/Alaska Schematic9.0 1 1/5/2009 NOTE:PATCH LEAKING @ 1982'&2011'ELMD I Mandrel Details _ Top Depth Top Port 1 _` (ND) Incl OD Valve Latch Size TRO Run _ Ste Top(ftKB) (ftKB) r) Make _ Model (in) Sere Type Type On) (Psi) Run Date Com... 1 1,993.6 1,651.5 66.13 CAMCO KBMG 1 ESP PATCH BEK-5 0.000 0.0 10/31/2008 Wash 1 1 Out - - I I MaI I .:3I I I I B-SANILINER Q41 , TO(1J-178), 17,083 • ~~. A, F _~ l ~~ xy~Y, y., Y e ~,. a ~s. r~ ~ ~ MICROFILMED 6/30/2010. DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon ^ Repair Well ^ Plug Pertorations ~ Stimulate ^ Other Q Tubing patch, . Alter Casin g^ Pull Tubing ^ Perforate New Pool ~ cnvert well to Waiver ^ Time E~ension ^ gaslift Change Approved Program ~ Operat. Shutdown^ Perforate ~ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: COnOCOPhillips Alaska, It1C. Development ~^ ~ Exploratory ^ 207-121 ~ 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-029-23368-00 ~ 7. KB Elevation (ft): 9. Well Name and Number: RKB 44' 1 J-178 ' 8. Property Designation: * 10. Field/Pool(s): ALK 25661% 25662 % 25663 / 385172 Kuparuk River Field / West Sak Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 17083' ' feet true vertical 3263' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 20" 122 122' SURFACE 13-3/8" 3667 2199' INTERMEDIATE 9-5/8" 8980 3280' ~~~ ~ ~~~ ~ B SAND LINER 5-1/2" 17,046' 3261' JUN ~ 8 Z009 Perforation depth: Measured depth: 8960-11833; 11835-16657; 16829-17002 '~~~S~a p~l &~aa~ C~t1~, ~p~p~~~SlQtl pn~hd~~ true vertical depth: 3278-3278; 3278-3252; 3254-3259 ~ Tubing (size, grade, and measured depth) 4-1/2", L-80, 7294' Weatherford retrievable patch from 1976'-2011' (2.25" ID) Packers & SSSV (type & measured depth) Packerless ESP No SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) N/q "~ ~ ,a n~ ~~C\`. S~ ~~ ~~ ~O ~`~'~a~9~~~~r ~~ ~ ~ ~~ ~ ~ ,JL , /~~~ li~ Treatment descriptions including volumes used and final pressure: f~ . 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ~~ Service ^ Daily Report of Well Operations _X 16. Well Status after proposed work: Oil ~^ ~ Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Brent Rogers/Martin Walters Printed Name Brent Rogers Title Problem Wells Supervisor Signature Phone 659-7224 Date 6/5/2009 Form 10-404 Revised 04/2004 ~~~~ ~~ ~,~~~ ~t ~ '~009 ./~'~ ~ • ~'. z~ ~ ~~ Submit O~~~nl~~ a ~ ~ ~ 1 J-178 ~ DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 03/22/09 RIH AND LATCH BAKER PATCH 1960' CTMD.PULLED PATCH UP HOLE 100' AND RIH AGAIN PUMPED OFF PATCH @ ESTIMATED 1900' CTMD.WELL SHUT IN AND READY FOR SLICKLINE. 03/23/09 PULLED BAKER "45" KB PATCH FROM 1935' SLM. 03/25/09 04/14/09 04/26/09 05/10/OS RUN #1. RIH W/ JSN AND CLEAN TUBING DOWN TO TOP OF SLIP-STOP ~ 7145' CTMD. RUN #2. RIH AND PULLED SLIP-STOP FROM TOP OF PACKOFF ASSEMBLY @ 7187' CTMD. RETURN IN AM TO PULL PACKOFF ASSEMBLY AND DOWN HOLE PUMP RIH WITH DOWNHOLE TEST TOOL AND TESTED MOTOR @ 7240' CTMD. TEST TOOL SHOW THAT MOTOR WAS TURNING FROM THE PINS THAT WAS SHEAR ON TEST TOOL. SET LOWER ELEMENT OF A 4.5" WEATHERFORD TUBING PATCH. MID ELEMENT SET A1 ' ~ SET 4 1/2" WEATHERFORD ER PKR SPACER PIPE SNAP LATCH ASSY @ 2011' RKB (OAL= 32' 2" MIN ID 2.25") WITH HES 3.59" DPU.***** NOTE: TOTAL LENGHT OF THE WHOLE PATCH ASSM, UPPER ER PKR, SPACER PIPE, STINGER & LOWER ER = 05/11/09 Summary RAN 4 1/2" ER TEST TOOL TO TOP OF PATCH @ 1947' SLM. MITT TO 2500 PSI, PASS. JOB COMPLETE. MITT passed. Initial T/I/0=1700/1000/125. Start MITT T/I/0=2500/1000/125, 15 min T/I/0=2390/1000/125, 30 min T/I/0=2350/1000/125. Pulled Baker one run patch. Pulled the ESP pump and tested the motor. Test tool shows that the motor was not the failure mechanism. Set a Weatherford retrievable patch over the mandrel from 1976' - 2011'. Set the test tool in the top ER packer and performed a passing ITT. Converted the well to gas lift production instead of ESP production. Page 1 of 2 Maunder, Thomas E (DOA) From: NSK Prod Engr Specialist [n1139@conocophillips.com) Sent: Wednesday, April 08, 2009 11:30 AM To: Maunder, Thomas E (DOA) Cc: ANsup-Drake, Sharon K Subject: RE: 1 J-178 (207-121) Tom - I thought you were looking for work in between those dates. Here is what I have: 2/1/09-MITT -Failed. OBTAINED TXIA LLR - .4 gpm @ 3000 psi. Initial T/I/O = 1100/1000/150. Pressured up TBG with 6 bbls diesel to 3000 psi. 15 min reading = 275011000/150. 30 min reading = 2620/1000.150. Pressured back up to 3000 psi using 20 gal diesel for an estimated leak rate of .667 gal per min at 3000 psi. 15 min reading = 2850/1000/150. 30 MIN READING = 275011000/150. Pressured back up to 3000 psi using 12 gal diesel for an estimated leak rate of .4 gal per min at 3000 psi. 15 min reading = 2875/1000/150. 30 min reading = 2800/1000/150. Final T/I/O = 1200/975/125. 2/25/09-MITT -PASSED. Initial T/I/O = 775/1000/130. Pressured up tubing to 1000 psi with 2 bbl diesel. 15 min T/I/O = 100011000/130. 30 min T/I/O = 1000/1000/130. Pressured up tubing to 2000 psi with 4 bbls diesel. 15 min T/I/O = 1930/1000/130. 30 min T/I/O = 1 91 0/1 00011 30. Pressured up tubing to 3000 psi with 2 bbl diesel. 15 min T/I/O = 2910/1000/130. 30 min T/I!O = 2880/1000/130. Bled down tubing. Final T!I/O = 800/1000/130. Bob Christensen / Darrell Humphrey ConocoPhillips Alaska, Inc. Production Engineering Specialist '.~ ~ ! .3;.1~.;, r~~ ~ ~~1~ Office (907) 659-7535 NSK-69 Pager (907) 659-7000 (924) From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, April 08, 2009 11:24 AM To: NSK Prod Engr Specialist Cc: Allsup-Drake, Sharon K Subject: RE: iJ-178 (207-12i) Thanks Darrell. I presume you weren't able to find any work information for 2/1 - 2/25? Tom From: NSK Prod Engr Specialist [mailto:n1139@conocophillips.com] Sent: Wednesday, April 08, 2009 11:23 AM To: Maunder, Thomas E (DOA) Cc: Allsup-Drake, Sharon K Subject: RE: 1J-178 (207-121) Tom- It is my understanding that this patch work is not complete yet and is scheduled for next week. I have C.C'd Sharon on this and she will review and reply accordingly. Thanks, Bob Christensen / Darrell Humphrey ConocoPhillips Alaska, Inc. 6/5/2009 Page 2 of 2 • Production Engineering Specialist Office (907) 659-7535 NSK-69 Pager (907)659-7000 (924) From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, April 08, 2009 8:35 AM To: NSK Prod Engr Specialist; NSK West Sak Prod Engr subject: iJ-178 (207-121) Bob, Darrell, et al, I am reviewing a 404 submitted by Guy Schwartz in early March. It is stated that a patch was replaced. The work summary covers 10/26!08 - 2/1/09 which appears to cover the initial patch placement and then diagnostics when they are unable to get a pressure test. The last entry is 2/25/09 that states "MITT passed". Does someone have additional operations information between 2/1/09 - 2125/09? Thanks in advance. Call or message with any questions. Tom Maunder, PE AOGCC 6/5/2009 1 J-178 (PTD 207-121) Proposed plan forward Page 1 of 1 Maunder, Thomas E (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Tuesday, March 24, 2009 11:13 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: NSK Problem Well Supv Subject: 1J-178 (PTD 207-121) Proposed plan forward Tom, Jim West Sak ESP producer 1 J-178 (PTD 207-121) was reported that the ESP would not restart following a tubing patch set across the GLM @ 1994'. At this time, the failure mechanism for the ESP is undetermined but is not suspected to be a motor failure. The plan forward is to pull the tubing patch, pull the ESP pump, reinstall the tubing patch across the damaged GLM, then gaslift the well through the pump intake. Once the well has been returned to production, well test data and IA FL's will be used to determine patch integrity. A 10-404 will be submitted for the new patch installation and for the change in lift service for both 1J-178 & 1J-178L1. Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 6/5/2009 ~~~ ~~~~IVE~ ~^~~ ~ ~~IP STATE OF ALASKA ~/IAR ~ ~ ~~0~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA~~I~`~ ~~~ ~~'~~• ~p~missi~n 1. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ~ Stimulate ~ Other ~/ replace patch 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 Drili Number: COnoCOPhlllips Alaska, InC. Development ~ Exploratory ^ 207-121 / 3. Address: Stratigraphic ^ Service ^ 6. API Number. P. O. Box 100360, Anchora e, Alaska 99510 50-029-23368-00 7. KB Elevation (ft): 9. Well Name and Number: RKB 122', 40' RKB 1 J-178 8. Property Designation: 10. Field/Pool(s): ADL 25661, 25662, 25663, 385172 Kuparuk River Field / West Sak Oil Pool 11. Present Well Condition Summary: Total Depth measured 17083' feet true vertical 3263' feet Plugs (measured) Effective Depth measured 17044' feet Junk (measured) true vertical 3261' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 80' 20" 120' i2Q' SURFACE 3624' 13-3/8" 3664' 2203' INTERMEDIATE 8940' 9.625" 8980' 3280' LINER 8631' 5.5" 17046' 3260' Perforation depth: Measured depth: slotted liner from 8436'-1 7046' true vertical depth: 3203'-3261' t` ~ ~ t ~- ~ v~: ~ -.:*; ~i~ ., ,r't~.' L~r{.ai,zt^` .i-~ t,~ . ~ Tubing (size, grade, and measured depth) 4.5", L-80, 7294' MD. PaCkers & SSSV (type 8~ measured depth) Baker MLZXP liner pkr, Baker SBE @ 8416', 8444' no SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured) not applicab/e Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water•Bbl Casin Pressure Tubin Pressure Prior to well operation SI -- Subsequent to operation SI - 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 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 Guy Schwartz @ 265-6958 Printed Name Guy Schwartz Title Wells Engineer Ph 265 6471 D t ~°~''~~ l Signature one: - a e , Pre ared b Sharon Allsu Orake 263-4612 Form 10-404 Re~ised 04/2006 \\~ ~~ „ i~ ~~_ ~~~-~~ ~. ~ ~~0~ ~~,~~~ubmit Original Only 1J-178 Well Work Summary DATE SUMMARY 10/26/08 PERFORMED FILL CLEAN O O SLIP STOP @ 7177 CTMD, 2ND RU~TH BAKER BHA, PULLED SLIP STOP FROM 7177 CTMD, WILL RTN IN A.M. TO PULL PACKOFF & PUMP. 10/27/08 LATCHED INTO PACKOFF @ 7177 CTMD, T07AL OF 'I2 JAR KICKS PULLING 20K OVER, PULLED PACKOFF & PUMP TOGETHER, SET IN DEPLOYMENT FLANGE IN TREE, TOTAL LENGTH APPROX 54 FT. READY FOR S/L. 10/28/08 PULLED PACKOFF ATTATCHED TO ESP FROM DEPLOYMENT FLANGE (OAL=58.36'). RAN NEW TTCPCP (OAL=43.45') TO 2200' SLM. WELL READY FOR COIL TO PUSH DOWNHOLE. 10/29/08 COIL TUBING UNIT 8. ATTEMPT TO SET ESP AND PACKOFF AT 7226' WITH BAKER HIPP TRIPPER. RATTLE DOWN ESP. RIH W/ PACKOFF, HIPP TRIP DOWN MULTIPLE TIMES BUT UNABLE TO GET PRESSURE TEST. PULL OUT OF HOLE WITH PACKOFF, 30K# OVERPULL. PACKOFF CAME BACK FULL OF SAND AND KOBE LOOKS OK. SEAL RUBBERS APPEAR TO HAVE BEEN SEATED. BACK IN AM TO CLEAN OUT AND TRY AGAIN. 10/30/08 COIL UNIT 8. TUBING WASH FROM 6500' TO TAG ON TOP OF ESP AT 7224' WITH SLICK DIESEL, RETURNS TO FORMATION. SL TO REPLACE SOV. 10/30/08 SET SLIPSTOP CATCHER @ 2069 SLM'. PULLED SOV @ 1993' RKB, VALVE ERORED IN HALF. RAN POCKET PUNCH TO GLM @ 1993' RKB, TATTLE TAIL INDICATES POCKET IS CLEAR, IN PROGRESS. 10/31/08 SET 2000# TBG SHEAR SOV @ 1993' RKB. TEST W/ D&D HOLE FINDER FAILED. REPLACED SOV @ 1993' RKB W/ 1"DV( EXT. PACKING) IN PROGRESS. 11/3/08 SET D&D TEST TOOL @ 2069' SLM. COULD NOT GET TBG TO TEST INDICATING POCKET IS WASHED OUT, PULLED EXT.PACKING DV @ 1993' RKB. PULLED CATCHER, HAD REMAINING PARTS FROM SOV. JOB SUSPENDED. 11/21/08 DRIFT TBG TO 4103' SLM, RUN CALIPER SURVEY FROM 3800' SLM TO 0'. *"JOB COMPLETE"`** 11/24/08 WASHED TO 7193', SET PACK OFF AND SLIP STOP, LEFT WELL SHUT IN AND FREEZE PROTECTED. READY FOR E-LINE. 12/5/08 SET A BAKER 4.5" 30' SINGLE SET PATCH FROM 1982' - 2012' ACROSS GLM AT 1994,', PSI TEST TUBING TO 20Q0 PSI. TEST FAILED. 12/14/08 AC-EVAL, MIT-T ( FAILED), LLR 9 GAL PER MIN @ 1290 PSI. 12/15/08 AC EVAL, LEAK DETECT. 12/17/08 LEAK DETECT. 12/19/08 LEAK DETECT 1/4/09 LOGGED A LEAK DETECTION LOG TO LOCATE T X IA LEAK. PATCH FROM 1982'-2012' WAS FOUND TO BE LEAKING. NO FLOW DETECTED BELOW PATCF(. 1/18/09 TAG TOP OF 4 1/2" BAKER KB PKR @ 1951' SLM. 1/19/09 PULLED BAKER KB PATCH (OAL=36' 1" ) FROM 1982' - 2012' ELM ACROSS GLM.BRUSH AND FLUSHED THIS AREA WITH 30 BBL'S DIESEL. 1/27/09 SET A 4.5" 30' BAKER SINGLE SET PATCH FROM 1982'-2012' ELEMENT TO ELEMENT ACROSS LEAKING GLM AT 1993. PATCH OD: 3.7", PATCH MIN ID: 2.37" PRESSURED TESTED TUBING TO 2000 PSI. TEST FAILED. 1/29/09 T FL @ 264FT. PATCH LEAK DETECT 2/1/09 MITT - FAILED. OBTAINED TXIA LLR -.4 GPM @ 3000 PSI. 2/25/09 MITT - PASSED. ~ • 1 J-178 DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 01/27/09 02/25/09 SET A 4.5" 30' BAKER SINGLE SET PATCH FROM 1982'-2012' ELEMENT TO ELEMENT ACROSS LEAKING GLM AT 1994. PATCH OD: 3.7", PATCH MIN ID: 2.37" MITT - PASSED. Initial T/I/O = 775/1000/130. Pressured up tubing to 1000 psi with 2 bbl diesel. 15 min T/I/O = 1000/1000/130. 30 min T/I/O = 1000/1000/130. Pressured up tubing to 2000 psi with 4 bbls diesel. 15 min T/I/O = 1930/1000/130. 30 min T/I/O = 1910/1000/130. Pressured up tubing to 3000 psi with 2 bbl diesel. 15 min T/I/O = 2910/1000/130. 30 min T/I/O = 2880/1000/130. Bled down tubing. Final T/I/O = 800/1000/130. Summary Set and tested tubing patch from 1982'-2012' across leaking gaslift mandrel at 1994'. __ _ _ . _ __ _ _ _. _ _. - -- _ _ - --- - _ Lta ~ • ~ ~ ~ ~ 1 ~/ ~ i.J ~~3~~ ~~-~~ ~~ STATE OF ALASKA (VIJ~~ ,.~ ~ ?QQ~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~ REPORT OF SUNDRY WELL OPERATIO(~5~~ ~°~ 1. Operations PerFormed: andon ^ Repair Weil ~ Plug Perforations ~ Stimulate ~ Alter sing ^ Pull Tubing ^ Perforate New Pool ~ Waiver ^ Tim Change Approved Progra ^ Operat. Shutdown ^ Perfocate ^ Re-enter Susp Gas Con~. Cammis~io~ r . ~.~-~4 ~J~i~ nsion ^ Q~~C-~ Well ^ ~.~ ~~ 2. Operator Name: 4. Carrent Well Status 5. Permit to Drill Number: ConocoPhillips Alaska, Ina o8v~~opment ~ ~ior~tory ^ 207-121 3. Address: ' stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alask 99510 50-029-23368-00 7. KB Elevation (ft): 9. Well Nam and Number. RKB 44' 1J-178 8. Property Designation: 10. Fiel ool(s): ADL0025661/0025662/0025663/0385172 " Kupa k River Field / West Sak Oil Pool 11. Preser~t Well Condition Summary: Total Depth measured 17083' feet true vertical 3263' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ~ ND Burst Collapse Structural CONDUCTOR 20" 122 122' SURFACE 13-3/8" 3667 2199' INTERMEDIATE 9-5/8" 8980 3280' .~~~~~~~~~~ M k ~ , e3 r ~~~ ~a~ _~. ~ 4 _-~ . _ ~~~~~,~ --- _-_____~ . - Perforation depth: Measured depth: 8960-11833; 11835-1 57; 16829-17002 true vertical depth: 3278-3278; 327$-3 2; 3254-3259 "ubing (size, grade, and measured depth) 4_~ f~'f, L-80, 7 4' Baker Siri e Set Patch from 1982-2012 (2.37" IC?} 'ackers & SSSV (type & measured depth) Packei'less 5P No SSSV 12. Stimulation or cement squeeze summary: ~3 ~~~~ '~` ~~,,,~_~~,. Intervals treated (measured) N/A ~--~-~ TreatmeM descriptions including volumes us and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin su~e Tubin Pressure Prior to well operation N/A N/A N/A N1A N/A Subsequent to operation N/A N/A N/A N/A N/A 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys r_ Exploratory ^ Development 0 Service ^ Daily Report of Well Operat' ns _X 16. Well Status after proposed work: ~ Ga~ WAG~ GINJ ^ WINJ ^ SPL ^ 17. I hereby certify that the f egoing is true and correct to the best of my knowledge. sundry Number or WA it C.o. Exempt: ' ~ Contact M~(rtin Walters Printed Name I1~artin Walters Title Signature y',~.~/`~'„ ~---~/J „ /f _ j~^ Phone Problem Wells Supervisor 659-7224 Date 3/1 ~ Form 10-404 Revised 04J2004 ~~ Submit Original Only . ~ C~noeoPttilti~s ~ ~ ~ at,.,_.u , ~ j _.weBCanfi~:_MUS14EkA.C~~s L1]e~Tis'ou55:a~2i ___ ._ ..$tlkmeI~S~.ACwal Tubirg Henger. ~ ~.._: "~ !~'AF.~,.: I ~ ~~~.;fl PATCH. 1.984 ESP~ MANDREL,- 1.996 SURFACE, <3-3,66] DISCHARGE, __ _. ].is9 INTAKE ],232 PUMP ],219~ SEAL, 7.242 MOTOR ],256 \ SENSOR, 7290 :EMRALIZER ] 292 RAM SealBOre \ Div2rtdr 8,359 845M1 ITERMEDIATE 60 8 980 9o~s, 8.9fi0~11.e33 SIO!s, 1~.835-~6.85] ~ i ~ i I ~_~ ~_ I I ti ' ' .~ - ,.. ~ , - 6-SAND LINEr7.~ I 8.416-17.066 TO(iJ-178). _ 1 ].083 KUP End Data 1 J-178 e&MD TD (ftKB) Act Btrn (ftKB) 14,204 90 17,083.0 ~Grtl(fl) '~Rig Release Date 44.34 '~ il/16/2007 ''~EnC Date MD i 1/5l2009 ICasirg Dascription - -~~String 0... String ID ... Top (ftK6) Se1 Dept~ (f... 5et Dapth (ND) ... String Wt... 5tring ... SMng Top Thrd ~CONDUCTOR I 20 ~i 19.124 432 122.0 122D i 95.50 I H-00 ~Casing Dascription I Sbing 0... ~String ID ._ Top (kKB) Set Depth ~f... Sat Dapth (N~) ... '.String Wt... String ... String Top Thrd SURFACE 133l8 12.415 43.1 3,666J 2,198.9 ~i 68.00 L-80 BTC I Casing Deseription String 0... String ID ... Top (kKB) Set Depth (i... Set Dapth (ND) ... IString Wt... String ... Stnng Top Thrd INTERMEDIATE 95/8 8.835 40.4 8,980.0 3,279.9 40.00 L-80 BTC-M IiCasing Description String 0... Sbing ID ._ Top (HKB) Set Dep[h (i... Se~ Dapth (ND) ... String Wt... String ... String Top Thrtl BSAND LINER ~ S 1/2 ~, 4.950 8,415J 17,0462 3,2612 15.50 L-80 8TC Liner Details , ~TopDapth', (ND) '~, Top Incl ~ P ( ) (~KB) T ~ (e~ Item Oascription Comment ID (in) 8,415.7 3,199 4 ' 79.87 PACKER Baker 7" X 9-5/S" MLZXP Liner Hanger Packer O.D. 8.43"/ I.D. 7.01". 7.010 I Com # 29633-0023 8,436.9~ 3,203.3~ 80.31 HANGER Baker"Flex-LOCk" Hanger Section O.D. 8.32" / ID. 7A2" ` 7.020 8,4422I 3,2042~ 80.32~X0 BUSHING Crossover Bushing 7" Hytl 563 X 5-t/2" Hyd 563 OD. 7.67" / I.D. 4.62" 4.620 8,443.6 3,204.4 ~ ._ _ _ ._ _ _ _ . 80.32 SBE Baker "Seal Bore Extension" O.D. 627" / I.D. 4J5". Com # 4J50 I H02-43317-A1 Casin Dascri g ption - IStrin 0... IStrin ID._ T I I g g op (ftK8) Set Dapth (t... Set Dapth (ND) ... String Wt... String ... 'String Top Thrd I RAM Seal Bore 4 V2 3.940 8,359.0 8,453J 3,206.1 12.60 L-80 I Hyd 521 Diverter ~ ~I Tubing Strings _ jTubin Descri g ption ~ String O._ ~~String ID ... Top (ftKB) Sat Depth (f... Set Depth (ND) ... String Wt... String ...~ S[ring Top T~N 'TUBING 47/2 3.958 35.8 7,294.0 2,968.1 12.60 L-80 IBT-m Com letion Det ails Top Depih (ND~ Top Incl ~'. T p(fM(g~ (ftK61 (°) Item Desniption I Comment ID (in) , . . - ..- .. . ..- ~-- ~ ---- - 7.149.0 2.939.0~ 77.43~ DISCHARGE Unique Pressure Discharge Sub 3.S60I - 7,231J 2,956.6 _ 77.95 INTAKE TTC Cwssover w/ Screen Intake (5.13" O.D.) 0.000 --._ _ 7,242.3 2,958.9 -_ __.. -_ _ . _ _ 78.01 SEAL Lower Tandem Seal Section GS83D8 FER HL SSCV SB/SB PFSA CLS 0.000 7,256.1 2,961.8 78.10 MOTOR Motor 418 HP KMHG ~ 0.000 ' 7290_0~ 2967.1 76.80 SENSOR ~A-Well I pump guage (45" O.D.) 0.000 Z292.0~, 2.967.6 ~ ~CENTRALIZER MotorCeNralizer(5.875'O.U.) -_ 3.958 76.82 -_ _ ... ._ i OPher in Hoee ( ~i Top Depth Worelme retrievable plugs, valves, pumps, fish, etc.j - --._ _-- I P To HKB ( ~ (°) Description Comment RunDat ID(in) 1,982.0 1,646 4~ 65.59 ~ PATCH I BAKER 45" SINGLE SET PATCH (OAL 30') 12/5/2008 ~ 2.375 7,219A 2,954.0 j 77.S7~PUMP ~ TTC ESP PUMP ASSEMBIY (OAL 43A5), D8D PACKOFF t01292008 0.000 ..._ _ I I ASSEMBLY & SLIP STOP ~ _.. ._. ____ _ _'- PerForations - _ _ - - __ __. - ... . . . ._..__~_.___ . . __ - . _. Shoi _-_._. I I I Dens Top (ND) Bim (iVD) Top (flK6) Bbn (ftKB) ~, (ftKB) (flK6) Zone _ _ _ Date (sh... Type_ CommerN ~ 8,960.0 71,833 0, ' 3,278J 3,2785 WS B, 7J-178 10/25l2007 32.0 Slots 2.5"x .125, 4 circumfereNial rows/h 3" ' cerners staggered 18 deg, 3' ~ non-slotted ends ____ _ ' 11,835.0~ 16,6570 _.-_ _ . _- _ 3278.5 3,251JWS6,1J-1~8 10/25/2007 32.OSIots 2.5"x.125,4circumferentialrows/h3" ~ I centers staggered 18 deg, 3' , nonsioned ends _ _~._ 16,829.OI 17,002.0 __. -._ _ 3,254.0 3,259_1 WS B, 1J-178 10252007 32A Slots 2.5"x .125, 4 circumierential rows/fl 3" centers staggered 18 tleg, 3' non-slottetl ends Notes: General 8 Safety Entl Date ; I Annota~ion ~ , iZ812007 INOTE: MULTI-LATER4L ESP WELL 7J-778 (8-SAND). iJ-178L7 (DSAND) I1 011 3/20 08 NOTE~ VIEW SCHEMATIC w/Alaska Schematic9.0 I __ -_ _ _ _ _ _ __-._ 1/S/2009 NOTE: PATCH LEAKWG a~ 1982' 8 2011' ELMD II . ._-. _. . . .__ _.. . . _ I .__ _. Mandrel Details ' Top Dep~h ~ Top . i ... .. _.. _ .. _ . . .... PoA I _ . _ _" (fVD) Incl OD Valve Latch Size 7R0 Run' Sin To (ftKB) (nKe) (°) Maka MoAel (in) Serv Typa Type (~) (psi~ Run Date Comm... 1 7,993.6 1,65t5 66.13 CAMCO~KBMG 1 ESP OPEN BEK-5 0 00 10/31/2008 ~ Washetl - I i ~~ - i ~ . I ~~ ! DATA SUBMITTAL COMPLIANCE REPORT 12/1 /2008 Permit to Drill 2071210 Well Name/No. KUPARUK RIV U WSAK 1J-178 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23368-00-00 MD 17083 TVD 3263 REQUIRED INFORMATION Completion Date 11/14/2007 Completion Status 1-OIL Current Status 1-OIL UIC N Mud Log No Samples No Directional S DATA INFORMATION Types Electric or Other Log s Run: GR/RES Well Log Information: Log/ Electr Data Digital Dataset T e Med/Frmt Number Name - ED~ D Asc --- - _ _- Directional Survey ~Rpt Directional Survey pt LIS Verification ED C Lis 15967 Induction/Resistivity i ~g Induction/Resistivity induction/Resistivit y II ED C 15997 Induction/Resistivity Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y Chips Received? 'f7'I~ Analysis Y/ N Received? (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments 41 17083 Open 1/16/2008 41 17083 Open 1/16/2008 3631 17083 Open 2/29/2008 LIS Veri, FET, RPD, RPM, RPS, RPX, GR, ROP 3631 17083 Open 2/29/2008 LIS Veri, FET, RPD, RPM, RPS, RPX, GR, ROP 25 Col 120 3262 Open 3/7/2008 TVD ROP, DGR, EWR 22- Oct-2007 25 Col 120 17083 Open 3/7/2008 TVD ROP, DGR, EWR 22- Oct-2007 3631 17083 Open 3/7/2008 TVD and MD Logs in CGM, EMF, and PDF graphics Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? ~~ Formation Tops t '// N Comments: DATA SUBMITTAL COMPLIANCE REPORT 12/1 /2008 Permit to Drill 2071210 Well Name/No. KUPARUK RIV U WSAK 1J-178 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-23368-00-00 MD 17083 ND 3263 Completion Date 11/14/2007 Completion Status 1-OIL Current Status 1-OIL UIC N Compliance Reviewed By: __ Date: COI'10 P co hifiips Alaska P.0. 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: • ~~~-Gay -5-~7g 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 Klem ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field n~•e Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1 F-18A 204-167 15' 5" 2.50 44" 10/30/2008 27.2 11 /7/2008 1E-16$ 204200 15" NA 15" NA 3.4 11/7/2008 1 E-17 205-074 13" NA 13" NA 5.53 11/7!2008 1J-122 207-070 15" NA 15" NA 3.4 11/7/2008 1J-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 1J-158 207-054 6' NA 6' NA 27.2 11/7/2008 1J-162 2 7-080 15" NA 15" NA 2.55 11/7/2008 1J-166 205-198 12" NA 12" NA 8.5 11/7/2008 1J-168 205-060 10" NA 10" NA 3.82 11R/2008 1 J-170 206-062 8" NA 8" NA 1 11 /7/2008 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 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs: 1 J-178+L 1 AK-MW-5160500 February 22, 2008 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1J-178+L1 2" x 5" MD Resistivity & Gamma Ray Logs: 1 Color Log 50-029-23368-00,60 2" x 5" TVD Resistivity & Gamma Ray Logs: 1 Color Log 50-029-23368-00,60 Digital Log Images: 1 CD Rom 50-029-23368-00,60 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 Date: ~. Signed: + • WELL LOG TRANSMITTAL To: State of Alaska February 18, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Data 1J-178 AK-MW-516050 1 LDWG formatted CD Rom with verification listing. API#: 50-029-23368-00 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 ,a ~~ ~a ~ ~~ ~ ~ ~? ~~ Date: Signed: ~o~-~a ~ ~ ~ ~ ~~ • ConocoPhillips January 15, 2008 • Randy Thomas Kuparuk Drilling Team Leader Drilling & Wells. P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6830 ~~~I~~~ Commissioner JAN 1 5 2008 State of Alaska Alaska Oil & Gas Conservation Commission Alaska Oil & Gas Cons. Commission 333 West 7th Avenue Suite 100 Anchorage Anchorage, Alaska 99501 Subject: Well Completion Reports for 1 J-178 and 1 J-178L1 Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Well Completion Reports for the Kuparuk West Sak multi-lateral 1J-178 and 1J-178L1. If you have any questions regarding this. matter, please contact me at 265-6830 or Pat Reilly at 265-6048. Sincerely, \. R. Thomas Kuparuk Drilling Team Leader CPAI Drilling RT/skad STATE OF ALASKA ~ ~Q~ ~ ~~~'~ ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPOI~~`'`~- commission 1a. Well Status: Oil ^ Gas Plugged Abandoned Suspended 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. WelfClass: " `""`~""" Development 0 ~ Exploratory ^ Service ^ Stratigraphic Test^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., ~ orAband.: November 14, 2007 12. Permit to Drill Number: 207-121 / ~ 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: October 6, 2007 ~ 13. API Number: 50-029-23368-00 ' 4a. Location of Well (Governmental Section): Surface: 1647' FSL, 2452' FEL, Sec. 35, T11N, R10E, UM ' 7. Date TD Reached: October 21, 2007 ~ 14. Well Name and Number: 1J-178 ' Top of Productive Horizon: 1006' FSL, 1639' FEL, Sec. 3, T10N, R10E, UM 8. KB (ft above MSL): 40.4' RKB Ground (ft MSL): 121.9' AMSL 15. Field/Pool(s): Kuparuk River Field Total Depth: 1855' FNL, 1508' FEL, Sec. 15, T10N, R10E, UM 9. Plug Back Depth (MD + ND): 17044' MD / 3261' TVD West Sak Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558760 ~ y- 5945459 Zone- 4 10. Total Depth (MD + ND): ~ 17083' MD / 3263' TVD ~ 16. Property Designation: ~'~25661, 25662, 25663, 385172 TPI: x- 554346 y- 5939506 Zone- 4 Total Depth: x- 554549 ~ - 5931367 Zone- 4 11. SSSV Depth (MD + ND): ~~' none ~.ji~ ' 7. Land Use Permit: 471, 217, 472, 2181 18. Directional Survey: Yes ^/ 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): 1536' 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 WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 34" 78.6# H-40 40' 120' 40' 120' 42" 347 sx AS 1 13.375" 68# L-80 40' 3664' 40' 2203' 16" 843 sx AS Lite, 223 sx DeepCRETE 9.625" 40# L-80 40' 8980' 40' 3280' 12.25" 599 sx Class G 5.5" 15.5# L-80 8415' 17046' 3199' 3260' 8.5" 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" 7294' none slotted liner from 8436'-17046' MD 3203'-3261' ND - 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED na 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) waiting on facility hook-up Date of Test Hours Tested Production for Test Period -> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corn) 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. ..:.-,. ~G~'PLIy'fi01`1 ( NONE r ) Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE ~E(~ L~ G ~~ .~f G r 28. GEOLOGIC MARKERS (List all formations and mark encountered): 29. FORMATION TESTS NAME MD TVD Well tested? Yes ~ No If yes, list intervals and formations tested, Permafrost -Top ground Surface ground surface - briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1758' 1536' needed, and submit detailed test information per 20 AAC 25.071. T-3 3600' 2185' K15 3600' 2185' Ugnu C 6080' 2720' Ugnu B 6511' 2810' Ugnu A 6957' 2900' K13 7740' 3061' West Sak D 8365' 3190' West Sak C 8700' 3247' West Sak B 8935' 3277 N/A Formation at total depth: West Sak B ~ 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, slotted liner detail sheets 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Pat Reilly @ 265-6048 Printed Na Rand mas Title: Drilling Team Leader Signature -----8h~e 2-6~~ ~ j ~ Date (~(3 ~°~ 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 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 ~~ KRU 1 J-178 Co114C4PhllipS Al~tSka, Inc. .... ~~1~a -- --- -_ _ -- - API: 500292336800 Well T e: PROD An le TS: de TUBING SSSV Type: NONE Orig 11/14/2007 Angle @ TD: 87 deg @ (o-7zsa, soo oD:a Com letion: , . ID:3.958) ~ Annular Fluid: Last W/O: Rev Reason: NEW WELL PUMP (7234-7256, OD3.800) SEAL (7242-7249, OD:5.130) SEAL (7249-7256, OD:5.130) MOTOR (7256-7289, OD:5.620) GAUGE pzaa7zsz, OD:4.500) RAM SB Diverter (a3s2-e3ss, OD:8.360) HANGER (8437-8442, OD:8.320) TERMEDIATE (o-fisao, OD:9.625, W1:40.00) - ~~ i _ . .-~ -~~ < +.. Reference Lo : 40' RKB Ref Lo Date: last U ate: 12/8/2007 Last Ta TD: 17083 ftK6 Last Tag Date: Casin Strin -ALL STRI Max Hole Angle: 92 NGS deg ~ 14205 '~ Descri tion Size To Bottom TVD Wt Grade Thread CONDUCTOR 20.000 0 120 120 94.00 H-40 WELDED SURFACE 13.375 0 3664 2203 68.00 L-80 BTC INTERMEDIATE 9.625 0 8980 3280 40.00 L-80 BTCM D-SAND LINER TOP 4.500 8354 8366 3190 12.60 L-80 BTC/HYD 521 D-SAND WINDOW 10.000 8365 8366 3190 0.00 B-SAND LINER 5.500 8415 17046 3261 15.50 L-80 BTC/HYD 521 Tubing String- TUBING i Size I Top 4.500 0 Perforations Summary i Bottom 729a i TVD 2970 i VVr 1260 _ i Grade __ I L 30 _ Thread IBTM mterva~ I vu cone slams rt srr uace i e commem 8960 - 11833 3279 - 3279 WS B 2873 32 10/25/2007 Slots 2.5'k .125, 4 circumferential rows/ft 3" centers staggered 18 de , 3' non-slotted ends 11835 - 16657 3279 - 3252 WS B 4822 32 10/25/2007 Slots 2.5'k .125, 4 circumferential rows/ft 3" centers staggered 18 de , 3' non-slotted ends 16829 - 17002 3254 - 3260 WS B 173 32 1 Q/25/2007 Slots 2.5'k .125, 4 circumferential rows/ft 3" centers staggered 18 deg. 3' non-slotted ends Gas Lift MandrelsNalves ___' St MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Viv Cmnt 1 1993 1651 CAMCO KBMG SOV 1.0 BEK-5 0.000 2000 11/14/200 'Other (plugs, a ui ., et c.) -COMPLETION De h ND T e Descri lion ID 36 36 HANGER VETCO GRAY TUBING HANGER 3.900 7149 2939 SUB UNIQUE PRESSURE DISCHARGE SUB 3.833 7231 2956 XO INTAKE TTC CROSSOVER w/SCREEN INTAKE 0.000 7234 2957 PUMP TTC ESP PUMP ASSEMBLY (OAL 40.03') , D&D PACKOFF ASSEMBLY, 0.000 & SLIPSTOP set 11/12/2007 7242 2959 SEAL UPPER TANDEM SEAL SECTION GSB3DB FER HL SSCV SB/SB PFSA 0.000 CL5 7249 2960 SEAL LOWER TANDEM SEAL SECTION GS63DB FER HL SSCV SB/SB PFSA 0.000 CL5 7256 2962 MOTOR 418 HP KMHG MOTOR 0.000 7289 2969 GAUGE A-WELL 1 PUMP GAUGE 0.000 7292 2969 Centralizer MOTOR CENTRALIZER 0.000 8354 3188 RAM D-SAND LINER RAM HANGER 8.360 Han er 8362 3190 RAM SB D-SAND LINER RAM SEAL BORE DIVERTER, CAMCO DB-6 NIPPLE 3.680 Diverter w/3.562" NO GO PROFILE @8417' & BAKER SEALASSEMBLYw/3.88" ID @ 8451' - TOP IN COMPLETION TUBING, BOTTOM @ 8454' IN D-SAND LINER Other (plugs a ui , et c.) - B-SAND LINER _ ----_ De ih TVD T e Descri uon ID 8416 3199 PACKER B-SAND BAKER MLZXP LINER TOP PACKER 7.010 8437 3203 HANGER B-SAND BAKER FLEX-LOCK HANGER 7.020 8442 3204 XO Bushing B-SAND CROSSOVER BUSHING 7" TO 5.5" 4.920 8443 3204 SBE B-SAND BAKER SEAL BORE EXTENSION 4.750 17n4.5 3981 SHC1F R-SANn SII VFR Rl II I FT SHnF 4.950 .General Notes. 1/l i~ I NOTE: MULTI-LATERAL ESP WELL 1J-178 (B-SANDI. 1J-178L1 (D-SANDI ~ ~ ~ w ° ~ ~~ 1~ m m 111 p 111 ~ > 11 y ~ ~ 11 ~~m N ~ 7 ~ + 111 f>F 39yh ~ 11 1111 is7 ~ 1111 11 ~ 1 Z ~ !Q~ ~ ~ ~~ ~ ,~ 1 a ~ y~ as IIII Q C y ~ IIII F IIII I :.NO I I IIIII 0 ohm .. a~~ ,., N ~~ 11111 ~ 11111 T o C as s ~ '~° 1111 .. ~ c Ilfl 1 l D ~ ~ ~ ~o Nr a ~ ~ ~,~ 1111 p 1 F~ VIII IIIII p „ 11111 a o oss.~~~ y ,~ :' ano E p U .]a m ~m a a m m s m a pp F~ 1111 un G IIII _ 1 l I v IIIII tl~ Q N N 3 .. ~e ,-, '~ U ~., ~ ~ - 00 IIIII _s I III I . L ~ T~ m ~ F C7 ' '' II11 Iltl 1 „ ~, l m--~~ N Q 'Q ~S~ ,..,,,aa aaappp ~ '~ 0 0 0 1111 1 a w'+~~o c 11111 ^' I III 1 -. ~.. -. W y y y m ~ s s .~ $~$~ I III I 1111 1111 1 O~Q~,~s_ s E .7 ~ N m N V q Bil °o l r N h a.~a. e.~.~ IIIII IIIII ~ 1111 ~" IIII I r 'T" m ~ ~' VII SS9 I ~ 1111 gs gs IIII ~~^ ~-"~ ti~ Iill 1111 IIII ~ m c Illl VIII C1 flifi M ~ 1111 ~~ m3 s IIII IIII IIII I I I IIII a d - .. m ~ 1111 Illi d ~~ a c m S~ III I ~ ~ ~ ~ 8 " a ~ ~ Ilfl 111 i 1 ~ ~ # ~w ~s ~d ~ 3p ~~ q c~ - P ~ ~ ~ ~~ ~ > ~q am ~b Y ~ a.~Mp W O ~ q~ ~0. s ~ ~Q ~< x m m a r~1 s a °~ c~ ~o ~ N [-~ r c ~ U r ~ ~ mn ~ , 0.F7a F r$m II / ~ ~m M o~ ~ ... o° 3 "a N v i e a ~ ~ aaem ac~ x 9 r~ Ay m s ss ~s u v3 :n D a- = o W N F :~ m ~ a ~ . a ~ g ~ '^ R° ' ~ G m Q h ~~ ~ Sa a 3~ s as N x o~ ~~ n+ ~ ~~ ~ ~~ °m vv O ~ ~ o a '~ ~n d' v ~ a k eze ° N .. U V m m ~e _ ~ . ^,! ° o N _ M N m ./ ~onocaPhillips Alaska f "B" Lateral Liner Detail ~' Well: 1J-178 Conoc~ ~ hl lips 5.5" Slotted and Blank Liner. Date: 1oi25io7 Rlaska, Inc:. Rig: Doyon 15 Supervisors: Mike Thornton/ Granville Rizek Depth Jt Number N Jtsof Well Equipment Description and Comments .,. Page 1 ~~,: Length Tops 5" DP to Surtace =_> 8402.74 2.27 Baker Liner settin tool Does not sta in hole 10.73 8405.01 E~B~er:7":X~-S/~'~::::ML~PU~er: HBn er P1~~4~~" ~. ~..;~ !~~"/~:~~:fl'~.::<;%, 21.24 8415.74 Baker "Flex-Lock" Han er Section O.D. 8.32" / I.D. 7.02" 5.27 8436.98 Crossover Bushin 7" H d 563 X 5-1/2" H d 563 O.D. 7.67" / I.D. 4.92" 1.42 8442.25 Baker "Seal Bore Extension" O.D. 6.27" / I.D. 4.75" 19.64 8443.67 Crossover Pu 5-1/2" H d 563 X 5-1/2" H d 521 O.D. 6.08" / I. D. 4.89" 3.89 8463.31 Jts 191 to 202 12 Jts 5-1 /2" 15.5 f L=8D H dril 521 Blank Casin 492.53 8467.20 Jts 121 to 190 70 Jts 5-1 /2" 15.5 f L-80 H dril 521 Slotted Casin 2873.63 8959.73 ~€~! Sub 5-112" M" d 52.1: X 5-1!12" BTCM 1.50 11833.36 Jts 50 to 120 71 Jts 5-1/2" 15.5 f L-80 'BTCM'- Slotted cs with'tor ue rin s 3048.36 11834.86 Jts 9 to 49 41 Jts 'S-1 /2" 15.5 f L-80 BTC Slotted Casin 1774.07 14883.22 Jts 5 to 8 4 Jts 5-1/2" 15.5 f L-80 BTC Blank Casin 171.95 16657.29 Jts 1 to 4 4 Jts 5-1'/2" 15.5 f L-80 BTC Slotted Casin 173.26 16829.24 5-1/2" 15.5 f L-80, BTC Blank Casin 42.04 17002.50 5-1/2" Silver Bullet Shoe 1.70 17044.54 Bttm of Shoe:===> 17046.24 17046.24 17046.24 17046.24 B Lat TD 17 083' M D/ 3 262' TVD 17046.24 5-1/2" Shoe 17 046.24' MD / 3 260' TVD Rat Hole 36.76' 17046.24 17046.24 17046.24 17046.24 MLZXP Oriented to 3 de .Left of hi h side. 17046.24 17046.24 To of ZXP to to of Helix inside to of liner = 10.72' 17046.24 To of ZXP to HR collet Profile inside to of liner = 12.46' 17046.24 To of ZXP to ML Anchor collet Profile = 12.79' 17046.24 17046.24 17046.24 Ran out of do wt 13775' MD. Rotated to bttm. 17046.24 Hole Fluids: 50/50 SFOBM 8.6 from TD to Window 8~ 17046.24 -- 50/50 SFOBM 8.8 w/ 3% - 776 tube from window to surface. 17046.24 Remarks: Up Wt 240 k Tor ue Instructior Tor ue H d 521= 5800 ft-Ibs BTCM w/for rin s= 5000 ft-Ibs on wt 87 k BTCM ~ 3200 ft-Ibs Av 10 'ts to diamonds Rot Wt 170 k Total Foota a of each = 3366' of H d 521, 3048' of BTCM w/ Tor Rin s, 2161' of BTCM Block Wt 7o k Centrilizers :Run= 5.5" X 8-1/4" S iral lider er 'oint floatin on Joints #1 thru # 190 =Total ran 190 Tor ue Rin s In : 50 thru 120 =Total used 71 Rot Torque 17 k ft Ib Halliburton Company Survey Report ('ompany: ConocoPhillips Alaska Inc . Iritc 11/27/200? lime: 14:18:34 Pa~~c I I~icld: Kuparuk River Unit Co -~irdinate(NE)Retere~ncc: Well: 1J-178, Tr ue North Site Kuparuk 1J Pad ~~c rtical('T~'D}Rc fcr•cnce: 1J-178: 122-0 ~~ell: 1J-178 Sec tion I~'S)Refer ence: Well (O.OON,00 0E180.OOAzi) 14'eitpath: 1J-17ts Su~ey Calculatio n ,Method: Minimum Curva ture I)b: Oracle __ Field: Kuparuk River Unit - - - North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: 1 J-178 Slot Name: Well Position: +N/-S -460.41 ft Northing: 5945459.03 ft Latitude: 70 15 41.730 N +E/-W -33.10 ft Easti ng : 558760.45 ft Longitude: 149 31 29.970 W Position Uncertainty: 0.00 ft Wellpath: 1J-178 Drilled From: Well Ref. Point 50-029-23368-00 Tie-on Depth: 41.02 ft Current Datum: 1 J-178: Height 122.02 ft Above System Datum: Mean Sea Level i Magnetic Data: 10/4/2007 Declination: 23.15 deg Field Strength: 57620 nT Mag Dip Angl e: 80.79 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 41.02 0.00 0.00 180.00 Survey Program for Definitive Wellpath Date: 10/13/2006 Validated: No Version: 6 Actual From To Survey Toolcode Tool Name ft ft 120.00 461.00 1J-178 gyro (120.00-461.00) CB-GYRO-SS Camera based gyro single shot 509.47 17083.00 1J-178 IIFR+MS+SAG (509.47-170 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey ----- - - ~1D Intl ~zim T~'l) SvsT`D N!S E(GV ~iapN 11apF: Tool ft deg deg ft ft ft ft ft ft 41.02 0.00 0.00 41.02 -81.00 0.00 0.00 5945459.03 ~ 558760.45 ' TIE LINE I 120.00 0.26 234.52 120.00 -2.02 -0.10 -0.15 5945458.92 558760.30 CB-GYRO-SS 211.00 0.40 300.81 211.00 88.98 -0.06 -0.59 5945458.96 558759.86 CB-GYRO-SS 272.00 1.08 235.87 271.99 149.97 -0.27 -1.25 5945458.75 558759.21 CB-GYRO-SS 353.00 2.79 230.37 352.94 230.92 -1.96 -3.40 5945457.04 558757.07 CB-GYRO-SS 461.00 5.45 227.40 460.66 338.64 -7.11 -9.20 5945451.85 558751.31 CB-GYRO-SS 509.47 6.31 225.80 508.87 386.85 -10.52 -12.80 5945448.41 558747.73 MWD+IFR-AK-CAZ-SC 559.36 7.64 220.50 558.39 436.37 -14.96 -16.92 5945443.94 558743.65 MWD+IFR-AK-CAZ-SC 603.70 8.65 219.21 602.28 480.26 -19.78 -20.94 5945439.09 558739.66 MWD+IFR-AK-CAZ-SC 698.86 13.31 219.82 695.68 573.66 -33.75 -32.49 5945425.03 558728.23 MWD+IFR-AK-CAZ-SC 794.04 18.42 222.67 787.20 665.18 -53.23 -49.71 5945405.42 558711.16 MWD+IFR-AK-CAZ-SC 888.85 20.31 221.82 876.64 754.62 -76.51 -70.83 5945381.98 558690.22 MWD+IFR-AK-CAZ-SC 983.21 24.55 220.58 963.84 841.82 -103.62 -94.52 5945354.69 558666.76 MWD+IFR-AK-CAZ-SC 1078.96 28.76 223.00 1049.40 927.38 -135.59 -123.18 5945322.50 558638.35 MWD+IFR-AK-CAZ-SC 1174.06 31.93 221.50 1131.46 1009.44 -171.16 -155.45 5945286.68 558606.35 MWD+IFR-AK-CAZ-SC 1269.33 37.13 221.46 1209.92 1087.90 -211.61 -191.21 5945245.96 558570.92 MWD+IFR-AK-CAZ-SC ~ 1364.51 42.44 222.60 1283.04 1161.02 -256.81 -232.00 5945200.44 558530.49 MWD+IFR-AK-CAZ-SC 1459.30 46.59 221.38 1350.62 1228.60 -306.21 -276.43 5945150.70 558486.45 MWD+IFR-AK-CAZ-SC 1552.28 48.68 222.35 1413.27 1291.25 -357.36 -322.28 5945099.20 558441.00 MWD+IFR-AK-CAZ-SC 1648.96 53.41 224.04 1474.04 1352.02 -412.12 -373.75 5945044.04 558389.97 MWD+IFR-AK-CAZ-SC 1742.85 55.34 221.44 1528.73 1406.71 -468.18 -425.52 5944987.59 558338.64 MWD+IFR-AK-CAZ-SC 1838.57 59.05 221.58 1580.58 1458.56 -528.42 -478.83 5944926.95 558285.80 MWD+IFR-AK-CAZ-SC 1932.77 63.28 221.05 1626.00 1503.98 -590.39 -533.29 5944864.56 558231.83 MWD+IFR-AK-CAZ-SC 2028.87 67.78 219.41 1665.80 1543.78 -657.16 -589.75 5944797.35 558175.90 MWD+IFR-AK-CAZ-SC 2124.17 71.39 219.09 1699.04 1577.02 -726.31 -646.25 5944727.77 558119.95 MWD+IFR-AK-CAZ-SC 2219.07 70.40 220.30 1730.10 1608.08 -795.31 -703.52 5944658.33 558063.23 MWD+IFR-AK-CAZ-SC 2313.37 72.04 223.27 1760.46 1638.44 -861.86 -763.01 5944591.32 558004.26 MWD+IFR-AK-CAZ-SC 2410.17 70.25 224.40 1791.75 1669.73 -927.94 -826.44 5944524.76 557941.35 MWD+IFR-AK-CAZ-SC 2504.67 70.09 224.83 1823.80 1701.78 -991.22 -888.88 5944461.00 557879.42 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: COnOCOPhillips Alaska Ind. Date: 11/27/2007 fimc: 14.18.34 Pale 2 Ficld: Kuparuk River Unit Co-ordinate(NE)Refcrcncc: Well: 1J-172, True North Silc: KupaniklJPad Vertieal(TVD)Refercncc 1J-178: 122.0 ~~cll: 1J-17~~ Section(VS)Reference: Well (O OON.O.OOE,180.OOAzi) ~lcllpaih: 1J-178 SurveyCakulatiou 1lcthod: Minimum Curvature Ilh: Oracle ~unc~ alt) Incl Azim L~,~ Sr, "f~~D V{S E/W tilap~ MapF. Tool ft deg deg ft ft ft ft ft ft -- -~ 2598.97 69.44 222.91 1856.42 1734.40 -1055.00 -950.20 5944396.75 557818.61 MWD+IFR-AK-CAZ-SC 2694.89 70.99 223.77 1888.89 1766.87 -1120.64 -1012.14 5944330.63 557757.18 MWD+IFR-AK-CAZ-SC 2790.25 71.46 222.99 1919.58 1797.56 -1186.26 -1074.15 5944264.54 557695.69 MWD+IFR-AK-CAZ-SC 2885.93 71.24 219.79 1950.19 1828.17 -1254.26 -1134.08 5944196.08 557636.30 MWD+IFR-AK-CAZ-SC 2980.37 71.44 222.61 1980.41 1858.39 -1321.58 -1193.01 5944128.31 557577.90 MWD+IFR-AK-CAZ-SC 3075.16 72.37 221.82 2009.85 1887.83 -1388.31 -1253.55 5944061.12 557517.89 MWD+IFR-AK-CAZ-SC 3170.67 69.57 221.94 2040.99 1918.97 -1455.53 -1313.82 5943993.43 557458.15 MWD+IFR-AK-CAZ-SC 3268.78 69.20 223.19 2075.53 1953.51 -1523.16 -1375.93 5943925.33 557396.58 MWD+IFR-AK-CAZ-SC 3358.68 68.17 223.48 2108.21 1986.19 -1584.07 -1433.41 5943863.97 557339.58 MWD+IFR-AK-CAZ-SC 3455.06 71.60 223.03 2141.35 2019.33 -1649.98 -1495.41 5943797.59 557278.10 MWD+IFR-AK-CAZ-SC 3550.41 73.07 222.32 2170.28 2048.26 -1716.78 -1556.99 5943730.32 557217.05 MWD+IFR-AK-CAZ-SC 3636.97 73.49 223.09 2195.19 2073.17 -1777.70 -1613.22 5943668.97 557161.31 MWD+-FR-AK-CAZ-SC 3661.67 72.99 223.33 2202.31 2080.29 -1794.93 -1629.41 5943651.61 .557145.25 MWD+IFR-AK-CAZ-SC 3758.49 74.64 224.26 2229.30 2107.28 -1862.04 -1693.76 5943584.01 557081.43 MWD+IFR-AK-CAZ-SC 3854.40 78.78 225.10 2251.34 2129.32 -1928.40 -1759.38 5943517.15 557016.34 MWD+IFR-AK-CAZ-SC 3950.08 79.41 224.08 2269.44 2147.42 -1995.30 -1825.34 5943449.74 556950.91 MWD+IFR-AK-CAZ-SC 4043.04 78.18 222.23 2287.51 2165.49 -2061.82 -1887.71 5943382.74 556889.07 MWD+IFR-AK-CAZ-SC 4138.64 78.70 220.68 2306.67 2184.65 -2132.01 -1949.71 5943312.07 556827.62 MWD+IFR-AK-CAZ-SC 4232.15 78.14 221.29 2325.44 2203.42 -2201.16 -2009.79 5943242.46 556768.09 MWD+IFR-AK-CAZ-SC 4327.26 77.64 221.52 2345.39 2223.37 -2270.91 -2071.29 5943172.24 556707.14 MWD+IFR-AK-CAZ-SC 4422.00 77.00 221.04 2366.19 2244.17 -2340.37 -2132.27 5943102.31 556646.71 MWD+IFR-AK-CAZ-SC 4519.14 78.07 221.17 2387.15 2265.13 -2411.84 -2194.63 5943030.37 556584.92 MWD+IFR-AK-CAZ-SC 4611.70 78.84 221.13 2405.68 2283.66 -2480.13 -2254.30 5942961.62 556525.78 MWD+IFR-AK-CAZ-SC 4707.09 77.32 221.85 2425.38 2303.36 -2550.04 -2316.13 5942891.24 556464.51 MWD+IFR-AK-CAZ-SC 4801.83 78.21 222.43 2445.46 2323.44 -2618.69 -2378.25 5942822.11 556402.93 MWD+IFR-AK-CAZ-SC 4897.49 77.51 222.55 2465.57 2343.55 -2687.66 -2441.42 5942752.66 556340.31 MWD+IFR-AK-CAZ-SC 4993.09 76.81 222.88 2486.82 2364.80 -2756.14 -2504.65 5942683.70 556277.62 MWD+IFR-AK-CAZ-SC 5086.68 78.19 223.99 2507.08 2385.06 -2822.49 -2567.47 5942616.87 556215.33 MWD+IFR-AK-CAZ-SC 5182.99 77.19 223.13 2527.61 2405.59 -2890.67 -2632.31 5942548.19 556151.03 MWD+IFR-AK-CAZ-SC 5278.13 77.41 221.99 2548.53 2426.51 -2959.03 -2695.09 5942479.34 556088.79 MWD+IFR-AK-CAZ-SC 5373.74 77.91 221.58 2568.96 2446.94 -3028.68 -2757.32 5942409.22 556027.11 MWD+IFR-AK-CAZ-SC ~ 5468.32 78.28 222.56 2588.47 2466.45 -3097.37 -2819.33 5942340.05 555965.64 MWD+IFR-AK-CAZ-SC 5563.34 77.31 223.46 2608.56 2486.54 -3165.28 -2882.68 5942271.65 555902.83 MWD+IFR-AK-CAZ-SC 5657.36 77.78 224.94 2628.84 2506.82 -3231.10 -2946.68 5942205.35 555839.35 MWD+IFR-AK-CAZ-SC 5753.79 77.99 224.13 2649.08 2527.06 -3298.31 -3012.81 5942137.63 555773.76 MWD+IFR-AK-CAZ-SC 5848.95 76.50 223.63 2670.08 2548.06 -3365.20 -3077.14 5942070.25 555709.96 MWD+IFR-AK-CAZ-SC 5944.60 77.63 223.78 2691.50 2569.48 -3432.59 -3141.55 5942002.36 555646.08 MWD+IFR-AK-CAZ-SC ~ 6039.74 78.05 222.08 2711.54 2589.52 -3500.69 -3204.89 5941933.78 555583.28 MWD+IFR-AK-CAZ-SC 6134.96 77.75 221.04 2731.50 2609.48 -3570.35 -3266.66 5941863.64 555522.07 MWD+IFR-AK-CAZ-SC 6229.51 78.28 221.23 2751.13 2629.11 -3640.01 -3327.50 5941793.52 555461.77 MWD+IFR-AK-CAZ-SC 6323.38 77.27 221.98 2771.01 2648.99 -3708.61 -3388.41 5941724.45 555401.40 MWD+IFR-AK-CAZ-SC ~ 6418.54 78.27 221.27 2791.17 2669.15 -3778.13 -3450.19 5941654.46 555340.18 MWD+IFR-AK-CAZ-SC 6513.62 78.25 221.92 2810.51 2688.49 -3847.74 -3511.99 5941584.37 555278.93 MWD+IFR-AK-CAZ-SC 6608.71 79.03 222.11 2829.24 2707.22 -3917.01 -3574.38 5941514.63 555217.08 MWD+IFR-AK-CAZ-SC 6704.24 78.21 222.35 2848.09 2726.07 -3986.35 -3637.33 5941444.80 555154.69 MWD+IFR-AK-CAZ-SC 6798.95 78.42 221.98 2867.27 2745.25 -4055.10 -3699.59 5941375.58 555092.97 MWD+IFR-AK-CAZ-SC 6894.64 77.89 221.30 2886.92 2764.90 -4125.09 -3761.81 5941305.11 555031.30 MWD+IFR-AK-CAZ-SC i 6989.88 77.99 221.07 2906.82 2784.80 -4195.18 -3823.14 5941234.55 554970.52 MWD+IFR-AK-CAZ-SC i 7085.13 78.54 221.48 2926.19 2804.17 -4265.27 -3884.66 5941163.99 554909.56 MWD+IFR-AK-CAZ-SC 7180.90 77.63 220.36 2945.96 2823.94 -4336.07 -3946.04 5941092.72 554848.74 MWD+IFR-AK-CAZ-SC 7275.43 78.22 220.68 2965.74 2843.72 -4406.34 -4006.10 5941021.99 554789.24 MWD+IFR-AK-CAZ-SC 7370.73 77.76 219.19 2985.57 2863.55 -4477.81 -4065.93 5940950.06 554729.97 MWD+IFR-AK-CAZ-SC ~ Halliburton Company Survey Report ---- Company: ConocoPhlliips Alaska Inc. Datr. 11127/2007 7imc: 14:18:34 P;~;;c: 3 Field: Kuparuk River Unit <_'u-o rdinate(NE}Referencc Welly 1J-178, True North Site: Kuparuk 1J Pad ~crtical(ll~D)Referencc 1J-178:1<2.0 Well: 1J-178 Scctiun f~~SlReference: Well (0.1)~ON,O.OOE,130.OOAzi) Wellpath: 1J-178 Survc} CalciEtation~Iet6od: Minimum CuNature Ilb: Oracle Survey MD Incl ~zim f~D SysT~'D \/S F.i~1 MupN 11upF. ~I'nnl ft deg deg ft ft ft ft ft ft 7466.43 78.90 215.50 3004.93 2882.91 -4552.31 -4122.77 5940875.13 554673.72 MWD+IFR-AK-CAZ-SC 7562.06 77.64 212.99 3024.37 2902.35 -4629.70 -4175.46 5940797.34 554621.64 MWD+IFR-AK-CAZ-SC 7656.57 78.46 211.65 3043.94 2921.92 -4707.84 -4224.89 5940718.82 554572.83 MWD+IFR-AK-CAZ-SC 7752.10 78.55 209.33 3062.98 2940.96 -4788.50 -4272.39 5940637.80 554525.97 MWD+IFR-AK-CAZ-SC 7847.12 77.84 205.55 3082.43 2960.41 -4871.03 -4315.24 5940554.95 554483.76 MWD+IFR-AK-CAZ-SC 7940.83 77.44 202.14 3102.50 2980.48 -4954.74 -4352.24 5940470.96 554447.42 MWD+IFR-AK-CAZ-SC 8035.94 77.12 198.22 3123.44 3001.42 -5041.80 -4384.24 5940383.66 554416.10 MWD+IFR-AK-CAZ-SC 8132.06 77.95 195.15 3144.20 3022.18 -5131.69 -4411.18 5940293.57 554389.87 MWD+IFR-AK-CAZ-SC 8233.54 78.19 191.58 3165.18 3043.16 -5228.27 -4434.13 5940196.82 554367.68 MWD+IFR-AK-CAZ-SC 8328.73 79.33 187.24 3183.74 3061.72 -5320.35 -4449.38 5940104.63 554353.15 MWD+IFR-AK-CAZ-SC 8424.32 79.92 183.50 3200.96 3078.94 -5413.95 -4458.18 5940010.98 554345.08 MWD+IFR-AK-CAZ-SC 8518.94 80.48 180.82 3217.07 3095.05 -5507.12 -4461.69 5939917.80 554342.30 MWD+IFR-AK-CAZ-SC 8614.35 80.68 179.37 3232.69 3110.67 -5601.24 -4461.84 5939823.69 554342.88 MWD+IFR-AK-CAZ-SC 8708.81 79.93 179.78 3248.60 3126.58 -5694.34 -4461.15 5939730.60 554344.29 MWD+IFR-AK-CAZ-SC 8803.85 82.29 180.00 3263.28 3141.26 -5788.23 -4460.97 5939636.72 554345.21 MWD+IFR-AK-CAZ-SC ~ 8899.21 84.78 179.51 3274.02 3152.00 -5882.98 -4460.57 5939541.99 554346.35 MWD+IFR-AK-CAZ-SC 8955.70 86.33 179.70 3278.40 3156.38 -5939.30 -4460.18 5939485.68 554347.18 MWD+IFR-AK-CAZ-SC 8973.97 86.57 179.32 3279.53 3157.51 -5957.53 -4460.02 5939467.45 554347.48 MWD+IFR-AK-CAZ-SC 9070.67 86.94 177.34 3285.00 3162.98 -6054.03 -4457.21 5939370.99 554351.04 MWD+IFR-AK-CAZ-SC 9165.46 89.23 177.57 3288.17 3166.15 -6148.67 -4453.00 5939276.40 554355.99 MWD+IFR-AK-CAZ-SC 9261.34 89.35 178.73 3289.36 3167.34 -6244.49 -4449.91 5939180.61 554359.83 MWD+IFR-AK-CAZ-SC 9356.09 89.78 178.71 3290.08 3168.06 -6339.21 -4447.79 5939085.92 554362.68 MWD+IFR-AK-CAZ-SC 9451.83 91.20 180.20 3289.26 3167.24 -6434.94 -4446.88 5938990.21 554364.34 MWD+IFR-AK-CAZ-SC 9547.90 90.71 180.77 3287.66 3165.64 -6530.99 -4447.69 5938894.16 554364.28 MWD+IFR-AK-CAZ-SC 9643.30 89.90 180.63 3287.15 3165.13 -6626.38 -4448.86 5938798.77 554363.86 MWD+IFR-AK-CAZ-SC 9738.49 90.59 179.02 3286.74 3164.72 -6721.57 -4448.57 5938703.60 554364.89 MWD+IFR-AK-CAZ-SC 9830.78 90.46 177.81 3285..90 3163.88 -6813.82 -4446.02 5938611.39 554368.16 MWD+IFR-AK-CAZ-SC 9927.54 90.34 178.43 3285.22 3163.20 -6910.52 -4442.84 5938514.72 554372.09 MWD+IFR-AK-CAZ-SC 10021.67 90.83 179.54 3284.26 316224 -7004.63 -4441.17 5938420.63 554374.49 MWD+IFR-AK-CAZ-SC 10116.70 89.78 180.00 3283.75 3161.73 -7099.66 -4440.79 5938325.62 554375.62 MWD+IFR-AK-CAZ-SC 10212.58 89.41 181.88 3284.43 3162.41 -7195.52 -4442.36 5938229.76 554374.79 MWD+IFR-AK-CAZ-SC 10307.59 90.71 181.55 3284.33 3162.31 -7290.48 -4445.21 5938134.79 554372.69 MWD+IFR-AK-CAZ-SC 10402.30 89.84 181.72 3283.88 3161.86 -7385.15 -4447.91 5938040.11 554370.73 MWD+IFR-AK-CAZ-SC 10497.94 90.46 180.32 3283.63 3161.61 -7480.77 -4449.61 5937944.49 554369.77 MWD+IFR-AK-CAZ-SC 10591.93 90.03 178.06 3283.22 3161.20 -7574.75 -4448.28 5937850.53 554371.83 MWD+IFR-AK-CAZ-SC 10686.86 89.66 175.78 3283.48 3161.46 -7669.53 -4443.18 5937755.80 554377.67 MWD+IFR-AK-CAZ-SC 10782.18 90.52 177.72 3283.33 3161.31 -7764.69 -4437.78 5937660.69 554383.82 MWD+IFR-AK-CAZ-SC 10877.56 91.14 179.83 3281.95 3159.93 -7860.04 -4435.74 5937565.38 554386.60 MWD+IFR-AK-CAZ-SC 10972.31 90.21 179.70 3280.83 3158.81 -7954.78 -4435.35 5937470.65 554387.73 MWD+IFR-AK-CAZ-SC 11067.15 90.52 178.32 328023 3158.21 -8049.60 -4433.71 5937375.86 554390.10 MWD+IFR-AK-CAZ-SC 11162.84 89.78 175.90 3279.98 3157.96 -8145.16 -4428.89 5937280.34 554395.67 MWD+iFR-AK-CAZ-SC 11254.95 89.97 175.15 3280.18 3158.16 -8236.99 -4421.70 5937188.58 554403.58 MWD+IFR-AK-CAZ-SC 11352.31 89.78 175.70 3280.39 3158.37 -8334.04 -4413.94 5937091.61 554412.10 MWD+IFR-AK-CAZ-SC 11447.12 90.21 175.72 3280.40 3158.38 -8428.58 -4406.85 5936997.13 554419.93 MWD+IFR-AK-CAZ-SC 11542.63 89.97 177.12 3280.25 3158.23 -8523.90 -4400.88 5936901.87 554426.63 MWD+IFR-AK-CAZ-SC 11637.62 90.15 180.24 3280.15 3158.13 -8618.85 -4398.69 5936806.94 554429.56 MWD+IFR-AK-CAZ-SC 11732.85 90.83 180.91 3279.34 3157.32 -8714.07 -4399.65 5936711.73 554429.35 MWD+IFR-AK-CAZ-SC 11828.01 90.15 179.99 3278.52 3156.50 -8809.23 -4400.40 5936616.58 554429.35 MWD+IFR-AK-CAZ-SC 11922.58 90.21 180.45 3278.23 3156.21 -8903.80 -4400.76 5936522.02 554429.72 MWD+IFR-AK-CAZ-SC ~ 12017.79 9021 180.26 3277.88 3155.86 -8999.00 -4401.35 5936426.82 554429.87 MWD+IFR-AK-CAZ-SC 12112.66 90.65 179.98 3277.17 3155.15 -9093.87 -4401.55 5936331.97 554430.41 MWD+IFR-AK-CAZ-SC 12208.61 90.40 179.77 3276.29 3154.27 -9189.82 -4401.34 5936236.04 554431.37 MWD+IFR-AK-CAZ-SC 12302.41 91.57 178.82 3274.67 3152.65 -9283.59 -4400.19 5936142.28 554433.26 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Comp~n~~: ConocoPhillips Alaska Inc. llnfc 11127!2047 'l'ime 14:18:34 P:+~r. -t E`ield: Kuparuk River Uni[ Co-o rdinate(NE)Referencc: Well: 1J-172, True North Site: Kuparuk 1J Pad Vertical (f~ D) Reference: 1J-178: 122.0 ~~cll: 1J-173 Section (~'S)Reference: Well (O OON.Q OOE130.OOAzi) ~~ellpath: 1J-178 ~urce} Calculation Alethod: Minimum Curvature I>b: Orade tiunc~ ~7D Inc! Azim TVD SysTVD V/S E/VV ~lapA ~lapE `Cool ft deg deg ft ft ft ft ft ft 12399.22 90.89 178.62 3272.60 3150.58 -9380.35 -4398.02 5936045.55 554436.18 MWD+IFR-AK-CAZ-SC 12494.67 90.03 177.23 3271.83 3149.81 -9475.74 -4394.57 5935950.20 554440.37 MWD+IFR-AK-CAZ-SC 12589.29 90.09 176.50 3271.73 3149.71 -9570.21 -4389.39 5935855.78 554446.29 MWD+IFR-AK-CAZ-SC i 12684.25 90.59 175.27 3271.17 3149.15 -9664.92 -4382.58 5935761.13 554453.84 MWD+IFR-AK-CAZ-SC 12779.85 89.47 174.41 3271.12 3149.10 -9760.13 -4373.98 5935666.00 554463.18 MWD+IFR-AK-CAZ-SC i 12874.35 89.78 175.82 3271.73 3149.71 -9854.29 -4365.93 5935571.92 554471.96 MWD+IFR-AK-CAZ-SC 12968.37 88.36 177.03 3273.26 3151.24 -9948.11 -4360.07 5935478.16 554478.55 MWD+IFR-AK-CAZ-SC 13063.31 89.29 177.90 3275.21 3153.19 -10042.93 -4355.87 5935383.38 554483.49 MWD+IFR-AK-CAZ-SC 13158.65 90.46 180.41 3275.42 3153.40 -10138.25 -4354.47 5935288.08 554485.64 MWD+IFR-AK-CAZ-SC 13254.30 89.90 182.32 3275.12 3153.10 -10233.87 -4356.75 5935192.46 554484.11 MWD+IFR-AK-CAZ-SC ~ 13349.24 89.60 182.09 3275.53 3153.51 -10328.74 -4360.40 5935097.57 554481.19 MWD+IFR-AK-CAZ-SC 13444.03 90.46 183.34 3275.48 3153.46 -10423.42 -4364.89 5935002.87 554477.44 MWD+IFR-AK-CAZ-SC 13539.28 88.61 182.14 3276.25 3154.23 -10518.55 -4369.44 5934907.72 554473.63 MWD+IFR-AK-CAZ-SC 13633.40 88.92 180.68 3278.28 3156.26 -10612.62 -4371.76 5934813.64 554472.05 MWD+IFR-AK-CAZ-SC 13726.75 90.34 180.55 3278.88 3156.86 -10705.96 -4372.76 5934720.31 554471.78 MWD+IFR-AK-CAZ-SC 13823.94 90.46 180.22 3278.21 3156.19 -10803.14 -4373.41 5934623.13 554471.88 MWD+IFR-AK-CAZ-SC 13919.07 91.64 180.52 3276.46 3154.44 -10898.25 -4374.03 5934528.02 554472.01 MWD+IFR-AK-CAZ-SC ~ 14012.01 91.82 180.71 3273.66 3151.64 -10991.15 -4375.02 5934435.14 554471.74 MWD+IFR-AK-CAZ-SC 14109.60 91.32 179.16 3270.98 3148.96 -11088.70 -4374.91 5934337.60 554472.61 MWD+IFR-AK-CAZ-SC ~ 14204.90 92.12 178.04 3268.12 3146.10 -11183.92 -4372.59 5934242.40 554475.68 MWD+IFR-AK-CAZ-SC 14298.90 90.89 174.93 3265.65 3143.63 -11277.70 -4366.83 5934148.68 554482.17 MWD+IFR-AK-CAZ-SC 14394.10 90.58 175.96 3264.43 3142.41 -11372.59 -4359.27 5934053.86 554490.47 MWD+IFR-AK-CAZ-SC 14488.12 89.66 178.25 3264.23 3142.21 -11466.48 -4354.52 5933960.02 554495.95 MWD+IFR-AK-CAZ-SC 14582.68 89.66 179.90 3264.80 3142.78 -11561.03 -4352.99 5933865.50 554498.22 MWD+IFR-AK-CAZ-SC 14680.14 90.96 180.86 3264.27 3142.25 -11658.48 -4353.64 5933768.06 554498.33 MWD+IFR-AK-CAZ-SC 14774.56 91.45 180.70 3262.28 3140.26 -11752.87 -4354.92 5933673.67 554497.78 MWD+IFR-AK-CAZ-SC 14869.66 90.64 180.14 3260.55 3138.53 -11847.95 -4355.62 5933578.59 554497.83 MWD+IFR-AK-CAZ-SC ~ 14965.74 90.03 179.55 3259.99 3137.97 -11944.03 -4355.36 5933482.53 554498.84 MWD+IFR-AK-CAZ-SC 15060.43 89.16 179.60 3260.66 3138.64 -12038.71 -4354.66 5933387.86 554500.28 MWD+IFR-AK-CAZ-SC 15156.42 90.22 179.41 3261.18 3139.16 -12134.69 -4353.83 5933291.90 554501.86 MWD+IFR-AK-CAZ-SC 15251.42 90.71 178.92 3260.40 3138.38 -12229.68 -4352.44 5933196.94 554503.98 MWD+IFR-AK-CAZ-SC i 15347.26 89.97 179.15 3259.84 3137.82 -12325.51 -4350.83 5933101.14 554506.34 MWD+IFR-AK-CAZ-SC 15441.49 90.21 178.52 3259.69 3137.67 -12419.71 -4348.91 5933006.95 554508.99 MWD+IFR-AK-CAZ-SC 15537.87 90.21 177.79 3259.33 3137.31 -12516.04 -4345.81 5932910.66 554512.85 MWD+IFR-AK-CAZ-SC 15633.96 89.78 176.82 3259.34 3137.32 -12612.03 -4341.29 5932814.73 554518.11 MWD+IFR-AK-CAZ-SC 15729.50 90.15 178.30 3259.40 3137.38 -12707.48 -4337.23 5932719.32 554522.93 MWD+IFR-AK-CAZ-SC j 15823.94 90.34 179.63 3259.00 3136.98 -12801.90 -4335.52 5932624.92 554525.37 MWD+IFR-AK-CAZ-SC 15919.53 90.77 179.80 3258.07 3136.05 -12897.48 -4335.04 5932529.35 554526.59 MWD+IFR-AK-CAZ-SC 16014.30 91.20 180.38 3256.44 3134.42 -12992.24 -4335.19 5932434.61 554527.18 MWD+IFR-AK-CAZ-SC I 16108.61 91.20 180.77 3254.47 3132.45 -13086.52 -4336.14 5932340.33 554526.97 MWD+IFR-AK-CAZ-SC ~ 16204.26 89.35 178.34 3254.01 3131.99 -13182.16 -4335.40 5932244.71 554528.46 MWD+IFR-AK-CAZ-SC 16298.40 90.77 179.05 3253.91 3131.89 -13276.27 -4333.25 5932150.63 554531.34 MWD+IFR-AK-CAZ-SC 16393.66 90.34 179.89 3252.99 3130.97 -13371.52 -4332.37 5932055.40 554532.96 MWD+IFR-AK-CAZ-SC i 16487.66 89.72 179.33 3252.94 3130.92 -13465.52 -4331.73 5931961.42 554534.33 MWD+IFR-AK-CAZ-SC 16583.11 90.77 178.56 3252.53 3130.51 -13560.95 -4329.97 5931866.01 554536.84 MWD+IFR-AK-CAZ-SC i 16677.99 90.40 178.15 3251.56 3129.54 -13655.78 -4327.25 5931771.21 554540.30 MWD+IFR-AK-CAZ-SC 16772.95 88.61 178.31 3252.38 3130.36 -13750.69 -4324.32 5931676.34 554543.97 MWD+IFR-AK-CAZ-SC 16868.68 87.93 179.10 3255.27 3133.25 -13846.35 -4322.15 5931580.71 554546.88 MWD+IFR-AK-CAZ-SC 16962.83 88.49 179.64 3258.21 3136.19 -13940.45 -4321.12 5931486.63 554548.65 MWD+IFR-AK-CAZ-SC 17057.95 87.25 180.66 3261.75 3139.73 -14035.50 -4321.37 5931391.59 554549.14 MWD+IFR-AK-CAZ-SC ~ 17083.00 87.25 180.66 3262.95 ' 3140.93 -14060.52 -4321.66 5931366.57 ~ 554549.05' MWD+IFR-AK-CAZ-SC Corto~caPhiiips Time Log Summary WefNiew Web Retsarttng ---_ - Well Name: 1 J-178 Job Type: DRILLING ORIGINAL '~; Time Logs Date From To Dur S. De th E De th Phase Code Subcode T COM 10/04/2007 15:00 16:15 1.25 0 0 MIRU MOVE RURD P _ Prepare to move rig f/ 1J-176 to 1 J-178. Smae side of pad. Blow down steam, and water lines. Disconnect air, steam, water and mud lines. 16:15 16:30 0.25 0 0 MIRU MOVE SFTY P PJSM on skidding rig floor. 16:30 17:15 0.75 0 0 MIRU MOVE SKID P Skid rig floor to moving position. 17:15 17:30 0.25 0 0 MIRU MOVE SFTY P PJSM for laying out herculite for the rock washer and the it com lex. 17:30 20:00 2.50 0 0 MIRU MOVE MOB P Lay herculite and mats for the pit com lex and rock washer. 20:00 22:00 2.00 0 0 MIRU MOVE MOB P Move pits out of the way towards 1 J-178. 22:00 23:30 1.50 0 0 MIRU MOVE MOB P Lift stomper feet. Move and set rig over the hole. Set stom er feet. 23:30 00:00 0.50 0 0 MIRU MOVE MOB T Move pits towards rig complex. Had a spill of 3/4 gallons of hydraulic oil while moving pit complex. Fixing hose on it module. 10/05/2007 00:00 02:00 2.00 0 0 MIRU MOVE MOB P Fixing hose on pit module after having a 3/4 gallon hydraulic oil spill (into secondary containment). Finish moving pit complex towards rig com lex and mate to ether. 02:00 02:15 0.25 0 0 MIRU MOVE SFTY P PJSM on skidding rig floor to drilling osition. 02:15 03:30 1.25 0 0 MIRU MOVE MOB P Skid rig floor to drilling position. Install hand rails and stairs. 03:30 05:00 1.50 0 0 MIRU MOVE RURD P RU steam, air and water lines under the floor and between modules. Berm up the Sub and cellar area. Hook up Pit to Sub interconnects. 05:00 06:00 1.00 0 0 MIRU MOVE RURD P Lift up braces in the pipe shed. Spot change house. Let Beaver slide back out into drilling position. Install drain plugs in centrifugal pumps. Plug the kill line. MU flow line to the pits. MU mud and vacuum lines to the pits. U date well si n. 06:00 06:45 0.75 0 0 MIRU MOVE RURD P Finish lowering Beaver slide back out into drilling position. Spread out herculite for the rockwasher and cuttin s boxes. 06:45 07:30 0.75 0 0 MIRU MOVE MOB P Move and spot the rock washer up alon the it com lex. ( _ _ Wage 1 ~t ~~ ~~ Time Logs COM _ Date From To bur S D e th E. De th Phase Code Subcode T 10/05/2007 07:30 08:00 0.50 _ 0 0 _ MIRU MOVE RURD _ P Put cuttings boxes in place. Berm up around rockwasher and cuttings boxes. Note: Rig accepted @ 0800 hrs 10/5/2007 on well 1J-178. 08:00 13:45 5.75 0 0 MIRU WELCT NUND P Ni le up Diverter system: Install riser, hook up hydraulic lines on knife valve and annular. Rig up flow line, install chain binders on riser to center up, RU 16"diverter line, secure same. Install spill containment at the end of diverter line. Clean drip pan. Offload 600 bbls of 8.7 ppg mud f/ the mud plant to the its. 13:45 14:15 0.50 0 0 MIRU RIGMN SFTY P PJSM on slipping the 1-3/8" drilling line all the way around and installing a news ool of line. 14:15 15:15 1.00 0 0 MIRU RIGMN SVRG P Due to high winds, rig up chains in the derrick to keep drilling line from whipping around. Pitwatcher cleaning it #5. 15:15 18:00 2.75 0 0 MIRU RIGMN SVRG P Slip new 1-3/8"drilling line around (approx 1800'). Stop and check each time the splice comes around through the blocks and crown. 18:00 18:30 0.50 0 0 MIRU RIGMN SVRG P Remove the chains from in the derrick which were used to keep the drilling line rou ed u . 18:30 19:00 0.50 0 0 MIRU RIGMN SVRG P Adjust the brakes on the drawworks. 19:00 19:15 0.25 0 0 MIRU DRILL SFTY P Pre job safety meeting on picking up drill i e. 19:15 19:45 0.50 0 0 MIRU DRILL PULD P Pickup/Makeup/ stand back in the derrick 5"drill i e. 19:45 20:00 0.25 0 0 MIRU DRILL OTHR NP High line tripped off. Start rig engines. 20:00 22:30 2.50 0 0 MIRU DRILL PULD P Pickup/Makeup/ stand back in the derrick 5"drill pipe. A total of 27 stands were made up. A total of 61 stands of 5"drill pipe in the derrick now, lus 2 stands of 5" HWDP. 22:30 23:30 1.00 0 0 MIRU WELCT ROPE P Function test the 21-1/4" Diverter system w/ 16" knife valve and diverter line. Witness of test waived by AOGCC inspector Bob Noble. Annular closed in 33 seconds, knife valve opened in 16 seconds. Koomey test: initial pressure 3000 psi, after closure 1800 psi, 200 psi buildup in 45 seconds, full charge achieved in 2 min 26 seconds. 5 bottle average 2300 asi on the nitro en backu . 23:30 00:00 0.50 0 0 SURFA DRILL PULD P Latch up a stand of 5" HWDP, break a single off, PU/MU jars to the stand of HWDP. 10/06/2007 00:00 00:30 0.50 0 0 SURFA DRILL PULD P PU/MU jars to the stand of HWDP, then stand back in the derrick. ~g~ 2 n~ ~3 Time Logs_ __ Da e From To Dur S. De th E. De th Phase Code Subcode T COM __ , 10/09/2007 15:00 18:00 3.00 3,666 3,666 SURFA CEME DISP P Turn over to Dowell cementers. Pressure test lines to 3500 PSI. Good test. Pump a total of 50 BBLS of CW100, 50 BBLS MudPush II. Drop bottom plug, pump 573 BBLS of 10.7 Lead cement, followed by 100.5 BBLS of 12.0 PPG Tail cement. Drop top plug. Pump 20 BBLS of H2O. Continuing to reciprocate casin strip with ood free movement. Crew Chan e 18:00 19:45 1.75 3,666 3,666 SURFA CEME DISP P With rig pumps, displace cement with 9.2 PPG mud, pumping at 7 BPM - 310 PSI with full returns and reciprocation. Observed Mud Push at surface in 2200 strokes, and cement at surface in 3180 Strokes indicating 142 BBLS of cement returns to surface. Observed casing movement lessened and stuck hanger off of bowl 3'. Continued pumping to slow down to 3 BPM at 4100 strokes bumping plug at 4379 strokes as planned with 440 PSI, increasing pressure to_1150 PSI. Hold 5 minutes, bleed pressure and check floats, floats held. CIP at 1917 HRS. 19:45 20:45 1.00 0 0 SURFA CEME PULD P Rig down cement head & lines. Blow down all lines. Rig down Dowell cementin crew. 20:45 22:00 1.25 0 0 SURFA CASIN NUND P Nipple down Diverter system and lift anular & knife valve. Inspect position of casing collar. Slack off to position collar under landing ring fro setting of emergency slips as per Vetco Gray re . 22:00 00:00 2.00 0 0 SURFA CASIN( RNCS T Rig up hydraulicjacks, and jack casing into position for setting of slips. set slips as per Vetco Gray reps with no overpull. Rig up with welder. Obtain Hot work permit. Cut casing stump 7" for ni le u . 10/10/2007 00:00 02:30 2.50 0 0 SURFA CASIN( NUND T Lay down cut off joint, landing joint & hanger. Continue cleaning pits. Continue nipple down diverter system. Clean out cellar box. 02:30 05:00 2.50 0 0 SURFA CASINC NUND T Dress casing stump. Weld starter head. Wrap same and allow tro cool. Load MWD tools in pipe shed. Continue cleanin its. 05:00 05:30 0.50 0 0 SURFA CASINC NUND T Allow starter head to cool. Grease choke manifold valves, and BOP stack to re for BOP test. 05:30 06:00 0.50 0 0 SURFA CASINC NUND P Continue allow starter head to cool. Pick up 99 joints of 5" DP racking back stands in derrick, drifting DP to 2.85". Crew Chan e J J Time Logs _ __ __ Date Frorn To Dur 5 D th E. Depth Phase _ Code Subcode T COM 10/10/2007 06:00 09:30 3.50 0 0 SURFA CASIN NUND P Continue pick up a total of 99 jnts of 5" DP drifting to 2.85", and racking back stands in derick. Pull mousehole from rota table. 09:30 12:00 2.50 0 0 SURFA CASIN NUND P Continue to allow starter head to cool. Drain gear oil and change filters in Top Drive. Serfvice blocks, TD, draw works. Rotate ODS kick back roller on draworks 180 degrees. Remove surface equiopment from cellar. Clean & service centrifu e. 12:00 15:00 3.00 0 0 SURFA CASINC NUND P Continue to allow starter head to cool. Pull subs, and handling tools for BHA to rig floor. Perform Derrrick inspection. Clean & organize rig floor. Prep cellar for NU BOP's. Perform weld repair on 3" cement line. Dressed shaker for intermediate hole section. 15:00 15:30 0.50 0 0 SURFA CASINC NUND T Make up weld on adapter, and test same to 1800 PSI - 15 minutes as per Vetco Gra re . 15:30 17:00 1.50 0 0 SURFA CASINC NUND P Nipple up wellhead orienting for flowline as per Vetco rep. Test hold down flange to 5000 PSI - 15 minutes. Obtain ood RKB measurements. 17:00 18:00 1.00 0 0 SURFA WELC NUND P Nipple up BOP stack, choke & kill lines. Pressure test mud pump pop offs. Crew Chan e 18:00 23:00 5.00 0 0 SURFA WELCT NUND P Contiinue nipple up BOP stack, kill & choke lines. Install flow ni le & line. 23:00 00:00 1.00 0 0 SURFA WELCT BOPE P Install test plug and joint. Rig up lines, test chart and test BOP stack, choke manifold valves to 300 PSI low, and 3000 PSI high test. Witness of test waived b AOGCC re John Cris . 10/11/2007 00:00 06:00 6.00 0 0 SURFA WELC BOPE P Continue test BOP stack, choke manifold valves, floor valves to 250 PSI low, and 3000 PSI high test. Test with 5", 5 1/2" and 9 5/8" test joints. Perform Koomey test. First 200 PSI in 42 seconds with full pressure at 2:38 Minutes. Avg pressure in nitrogen botles = 2300 PSI. Install wear bushing. Witness of test waived by AOGCC re John Cris .Crew Chan e 06:00 07:30 1.50 0 0 SURFA WELCT BOPE P Rig down all test equipment. Blow down Choke manifold, Top drive & lines. Clean & clear ri floor. 07:30 07:45 0.25 0 0 SURFA DRILL SFTY P Held PJSM with crew, DD &MWD reps. Discuss safety & hazard recognition issues. Discuss procedure to make u 12 1/4" BHA. 07:45 08:30 0.75 0 36 SURFA DRILL PULD P Make up BHA #2, 12 1/4" assembly with a Security FMFH3634ZZ bit, and 9600 series Geo-Pilot. Make up MWD assembl . ~~ ~ ~ ~ Page 7 ~a~t ~ • i Time Logs Date From To Dur S De th E. De th Ph e Code Subcode T COM _ 10/11/2007 08:30 09:15 0.75 36 36 SURFA DRILL PULD P Plug in and Upload MWD assembly. 09:15 09:30 0.25 36 367 SURFA DRILL PULD P Continue make up remaining BHA picking up Non MAg flex drill collars and 5" HWDP with drilling jars. Total BHA len th = 367.19'. 09:30 12:00 2.50 367 3,501 SURFA DRILL TRIP P Trip in hole with BHA #2 from 367' - 3501' MD. Observed proper displacement. Perform shallow pulse test @ 1308' MD with 890 GPM's - 1440 PSI. Fill drill string every 25 stands. 12:00 13:00 1.00 3,501 3,566 SURFA DRILL REAM P Establish parameters with pumps @ 750 GPM's - 1550 PSI. Wash down from 3501' - 3566'. UP WT = 160K, SO WT = 100K, ROT WT = 125K. Circulate 6200 strokes in preparation for casin test. 13:00 15:15 2.25 3,566 3,566 SURFA DRILL DHEQ P Rig up lines, and equipment for casing test. perform casing test to 3000 PSI, holding for 30 minutes recorded on chart. Good test. Bleed pressure, and ri down test a ui ment. 15:15 17:15 2.00 3,566 3,664 SURFA DRILL DRLG P Wash & rotate down to tag float equipment and drill float equipment and shoe track from 3566' - 3664' MD. Pumps @ 675 PSI - 1190 PSI. 100 RPM's with 9K TO. 17:15 17:30 0.25 3,664 3,695 SURFA DRILL DRLG P Continue drill open hole from 3664', and 20' of new hole to 3695' MD. TVD = 2211'. 17:30 18:00 0.50 3,695 3,695 SURFA DRILL CIRC P Circulate & condition mud, while reciprocating and rotating drill string. Rig up vac trucks. Held PJSM with crew, Mud engineers, vac truck drivers. Designate spill champion. Discuss safety & hazard recognition issues. Discuss procedure to displace well wityh 8.9 PPG LSND mud. Crew Chan e 18:00 19:30 1.50 3,695 3,695 SURFA DRILL CIRC P Continue circulating, while reciprocating & rotating drill string displacing well with $.9 PPG LSND mud with pumps at 655 GPM's - 1110 PSI. 19:30 20:00 0.50 3,695 3,695 SURFA DRILL CIRC P Continue circulating to program MWD negative pulsar to record & send data. Unsuccessful, observing real time data only, and not recorded data sent up. Obtain Clean hole baseline ECD at 9.25 PPG. 20:00 20:30 0.50 3,695 3,695 SURFA DRILL TRIP P Pull and lay down 2 singles of DP to get up ion the shoe. Blow down Top Drive. Rig up lines and equipment for LOT test. ------ , I'a~ys~ ~ oaf ~`~_. Time Loc,~s_ _ _ _ Date From To Dur S. De th E. Depth Phase Code Subcode T COM _ _ 10/13/2007 13:30 14:15 0.75 8,226 7,685 INTRM1 _ DRILL TRIP T Stand back 1 stand. POOH on elevators from 8208' - 7685' MD. Monitor well through trip tank. Observed improper displacement with hole swabbin . 14:15 15:15 1.00 7,685 7,210 INTRM1 DRILL TRIP T Pump out of hole from 7685' - 7210' MD, with 176 GPM's - 340 PSI. Observed assembly overpulling up to 40K over. 15:15 18:00 2.75 7,210 5,972 INTRM1 DRILL REAM T BROOH from 7210' - 5972' MD-with 1000 GPM's - 2740 PSI. Observed steady torques from 15k spiking to 27K re ularl .Crew Chan e 18:00 21:00 3.00 5,972 3,790 INTRM1 DRILL REAM T Continue BROOH from 5972' - 3790' MD with 1000 GPM's - 2150 PSI. Observed steady torques from 15k spiking to 27K regularly. Attempt to Pump out of hole with no rotation due to possible BHA damage indicated from excessive high torque values. We were able to pull a few stands and had to go back to rotating 70 RPM's and um in at drillin rates. 21:00 00:00 3.00 3,790 3,650 INTRM1 DRILL REAM T Observed assembly packed off at 3790', with no flow. (2 stands below shoe) Stop pumps, work drill string. Pump assembly into shoe track. Attempt to gain circulation, but pumping fluid away at 1/2 BBL / minute. Continue work drill string at the shoe, until packoff broke free. Stage pumps up steady from 100 GPM's to gain full circulation @ 900 GPM's. Pump a total of 5 bottoms up, observing hole exceessively unloading cuttings, Clay & shale across shakers. Observed mud weights to 9.9 PPG with 104 visc coming out. Continue pump until clean and able to gain full rotation at 120 RPM's with steady torque at 5 - 11 K ft./Ibs, with mud weights as planned at 9.1 PPG 46 visc in, and 9.3 PPG 54 visc comin out. Hole cleanin u . s fi'age 1 ~ ref ~9 C~ • Time Logs _ _ Date From To Dur 5 Depth E. De th Ph e Code Subcode T COM 10/14/2007 00:00 02:00 2.00 3,650 3,650 INTRM1 DRILL CIRC T Continue pump until clean and able to gain full rotation at 120 RPM's with steady torque at 5 - 11 K ft./Ibs, and free movement in drill string without packing off issues. Circulate clean until mud weights as planned at 9.1 PPG 46 visc in, and 9.3 PPG 54 visc coming out. Hole cleaned up. Observed cuttings packed off scalper shaker trough. Shut down 1/2 HR to clean all cuttings underneath shakers for free movement of mud flow. Calculted a total of 50 BBLS of mud um ed awa Burin ack off issues. 02:00 02:15 0.25 3,650 3,650 INTRM1 DRILL OWFF T Monitor well -static. 02:15 06:00 3.75 3,650 615 INTRM1 DRILL TRIP T Attempt to pull out of hole on elevators. observed hole swabbing. BROOH with no torque issues. Attempt numerous times to POOH on elevators with no success due to swabbing issues. Continue BROOH. Pumnps 2 580 GPM's - 500 PSI. Crew Chan e 06:00 06:30 0.50 615 364 INTRM1 DRILL TRIP T Continue BROOH, pulling to BHA. Pumnps @ 580 GPM's - 500 PSI. Observed ro er hole dis lacement.. 06:30 07:00 0.50 364 0 INTRM1 DRILL PULD T Continue pump out of hole. We had to pump NM Flex drill out of hole as well, as the assembly was still packed off and would not straight pull. Observed over ull of 50K. 07:00 10:30 3.50 0 0 INTRM1 DRILL PULD T POOH with BHA. Assembly pulled free when Welded Blade stabilizer through the wear bushing. Inspect & gauge welded blade stabilizer. Observed mionimal clay and in gauge. No damage. Continue POOH with MWD assembly, in good condition. Smart stabilizer in gauge & fairly clean of cuttings. Observed Geo-Pilot with oil draining from it. Inspect & gauge bit. Observed two broken blades, missing. Gauged to - 8/8/BB/N/X/BT/HP. Plug in and download MWD assembl . 10:30 11:45 1.25 0 0 INTRM1 RIGMN SVRG T Service Top Drive, blocks, crown section & drawworks. Discuss options and findin s with ri en ineer. 11:45 12:30 0.75 0 55 INTRM1 DRILL PULD T Pull handling subs & XO's to floor. Make up BHA 33. make up Geo-Pilot assembly with Security FMFX553 bit. Continue make u MWD assembl . 12:30 13:15 0.75 55 55 INTRM1 DRILL PULD T Plug in and upload MWD assembly. P~gt~ 3'1 ctf ~~ ~~ n I l Time Logs _ _______ _ Date From To D ur S De th E De th Phase Code Subco de TCOM _ 10/14/2007 13:15 14:00 _ 0.75 55 367 INTRM1 DRILL __ PULD T Continue make up remaining BHA #3. Picking up HWDP & flex drill collars.Total len th of BHA = 367.97'. 14:00 16:00 2.00 367 3,603 INTRM1 DRILL TRIP T Trip in hole from 367' - 3603' MD. Observed proper displacement. Fill string every 25 stands. Perform shallow pulse test with pumps @ 907 GPM's- 1030 PSI. Rotate drill string to break in Geo-Pilot bearin s as er DD. 16:00 17:30 1.50 3,603 3,603 INTRM1 RIGMN SVRG T Rig up and change out saver sub on top drive. Continue monitor well - static. 17:30 18:00 0.50 3,603 4,077 INTRM1 DRILL TRIP T Continue trip in hole from 3603' - 4077'. Fill drill strin .Crew Chan e 18:00 00:00 6.00 4,077 8,030 INTRM1 DRILL REAM T Observed drill string taking weight, indicating cuttings beds. Attempt to work through. Rig up and begin washing and rotating drill string from 4077' - 8030'. Observed good displacement, with no torque & drag issues, other than assembly continual) takin wei ht. 10/15/2007 00:00 00:45 0.75 8,030 8,226 INTRMI DRILL REAM T Continue wash & rotate drill string from 8030' - 8226' MD. Obtain drilling parameters. Pumps at 1020 GPM's - 2710 PSI. RPMs - 120 with 14K torque. Tag bottom with little bit weight, picking up, and repeat observing possible broken blades on bottom. Observe torque smoothed out with 120 RPM's & 12-16K ft/Ibs. Work assembly to set on bottom to begin drilling with good parameters, and no issues. Observed calculated clean hole ECD at 9.42 PPG. 00:45 06:00 5.25 8,226 8,781 INTRM1 DRILL DDRL P Directional drill 12 1/4" Intermediate hole from 8226' - 8781' MD. TVD = 3261'. ADT = 3.75 HRS. Bit HRS = 3.75. ECD = 9.91 PPG. Crew Chan e 06:00 08:30 2.50 8,781 8,983 INTRM1 DRILL DDRL P Directional drill 12 1/4" Intermediate hole from 8781' - 8983' MD. TVD = 3280'. ADT = 1.75 HRS. Bit HRS = 5.50. ECD = 9.80 PPG. Start sweep in hole ~ust before TD 8983'. 08:30 12:00 3.50 8,983 8,453 INTRM1 DRILL REAM P BROOH from TD @ 8983' - 8453' MD. Back ream rates at 10-20 fUminute. Pumps at 900 GPM's - 2460 PSI. RPM's - 125 with 17K TO. Obtain T&D parameters as per rig engineer with ro er dis lacement. C~ ~~ I Time Logs_ _ Date From To Dur S De th E. Depth Phase Code Subcode T COM 10/15/2007 12:00 18:00 6.00 8,453 7,000 INTRM1 DRILL REAM P Continue BROOH from 8453' - 7000' MD. Back ream rates at 10-20 ft/minute. Pumps at 1020 GPM's - 2460 PSI. RPM's - 125 with 17K TO. Obtain T&D parameters as per rig engineer with proper displacement. UP WT = 195K, SO WT = 98K, ROT WT = 143K. 18:00 00:00 6.00 7,000 4,935 INTRM1 DRILL REAM P Continue BROOH from 7000' - 4935' MD. Back ream rates at 10-20 ft/minute. Pumps at 1010 GPM's - 1760 PSI. RPM's - 125 with 17K TQ. Obtain T&D parameters as per rig engineer with proper displacement. UP WT = 175K, SO WT = 105K, ROT WT = 130K. Note: Rig blacked out and dro ed off Hi h Line ower 23:45 10/16/2007 00:00 03:00 3.00 4,935 3,590 INTRM1 DRILL REAM P Continue BROOH from 4935' - 3590' MD, inside shoe. Back ream rates at 10-20 ft/minute. Pumps at 1010 GPM's - 1575 PSI. RPM's - 125 with 15K TQ. Obtain T&D parameters as per rig engineer with proper displacement. UP WT = 175K, SO WT = 105K, ROT WT = 130K. 03:00 04:45 1.75 3,590 3,590 INTRM1 DRILL CIRC P Reciprocate & rotate drill string while pump Hi vsc sweep at 1020 GPM's 1575 PSI. Pump a total of 5 bottoms up to ensure the hole is clean. Monitor well. 04:45 05:45 1.00 3,590 3,590 INTRM1 RIGMN SVRG P Slip & cut Drilling Line. 05:45 06:00 0.25 3,590 3,590 INTRM1 DRILL CIRC P Pump 60 BBLs of Steel Lube pill, followed b d 'ob. Crew Chan e 06:00 06:15 0.25 3,590 3,590 INTRM1 DRILL OWFF P Monitor well. Static 06:15 07:00 0.75 3,590 3,590 INTRM1 DRILL CIRC P Spot 60 bbl Steel Lube pill at 3,600' md, followed by 35 bbl mud and 20 bbl dry job, followed by 10 bbl mud. Blow down TD. 07:00 08:30 1.50 3,590 376 INTRM1 DRILL TRIP P POOH of elevators from 3,600-376' md, monitorin fill on the Tri tank. 08:30 09:45 1.25 376 50 INTRM1 DRILL PULD P LD BHA, PU single HWDP, stand back HWDP, LD Jars and 3 flec DCs. 09:45 10:45 1.00 50 30 INTRM1 DRILL PULD P Download MWD 10:45 11:45 1.00 30 0 INTRM1 DRILL PULD P Continue LD BHA #3, break bit and ins ect. LD WB. 11:45 12:00 0.25 0 0 INTRM1 DRILL OTHR P Clear and clean rig floor. Prep to run cs . 12:00 13:45 1.75 0 0 INTRM1 CASIN( RURD P PU and RU casing tools. PU csg head. ~~ ~ F~a~~: 13 of 49 i Time_Lo9s __ - --- - _-_ -- _-- - Date From To Dur S. De th E. D th Phase Code Subcode T COM _ 10/17/2007 10:30 12:15 1.75 8,980 8,980 INTRM1 CEME DISP P Displace w/ 8.4 ppg MOBM. Pumping 7.0 bpm w/ 300 psi initial and 880 psi final before slowing down pumps to 3 bpm after 653.8 bbls pumped. Pumping 3 bpm w/ 640 psi and 19% flow, Did not bump plug after pumping max of 668.1 bbls of 8.4 ppg MOBM. Reciprocated pipe w/ 30' strokes working down to 5' strokes as cement rounded shoe, Stopped pipe on depth after 44.0 cement around shoe due to pipe getting tight, Had good returns thru out job w/ no observed losses. CIP @ 12:10 hrs 10/17/2007. Shoe @8,980' MD ! 3,280' TVD, Float collar 8,890'. 12:15 12:30 0.25 INTRMI CEME OTHR P Bleed off Pressure and Check Floats - OK 12:30 13:30 1.00 INTRM1 CASINC RURD P ND stack, PU on casing to 265K (Calc neutral wt. was 190K . 13:30 15:30 2.00 INTRM1 CASINC OTHR P Set emergency slips with casing in 75K of tension. Slack off on casing to b-ock weight. Make casing cut and LD stub, LD Csg equipment and RU for annular flush. 15:30 17:30 2.00 INTRMI CASIN( OTHR T Attempt to install Pack off - No Good, Wait on pulling tool & make same, Pull Pack off & ins ect same - OK. 17:30 18:00 0.50 INTRM1 DRILL OTHR P Install 9-5/8" pack off, move 14 stands of DP to the ODS (off driler side). Finish cleanin its. 18:00 19:15 1.25 INTRM1 WELCT BOPE P NU ROPE. PU MWD tools and put in the pipe shed. Test 9-5l8" PO to 2,500 psi (80% of 9-5/8" csg collapse ratin . -Test ood. 19:15 20:15 1.00 INTRM1 WELCT BOPE P Continue to NU BOPS. 20:15 23:15 3.00 INTRM1 DRILL PULD P PU and rabbit (2.86" drift) 30 stands of Super Slider pipe and stand back. Perform Infectivity test to 15.9 ppg EMW (computer calculated). Flushed the annulus with 240 bbl of fresh water at 1.0 bbl/min and 690-710 surface ressure. 23:15 23:45 0.50 INTRM1 DRILL OTHR P Set WB. 23:45 00:00 0.25 INTRMI DRILL OTHR P Clear and clean rig floor. Continue to clean mud its. 10/18/2007 00:00 00:15 0.25 0 0 INTRM1 DRILL OTHR P Continue to clean rig floor and clean mud its. 00:15 01:30 1.25 0 137 INTRM1 DRILL PULD P PJSM, Pick up BHA #4, Make up Bit, GeoPilot w/ Flex, MWD, HOC, NM Float sub & 1 NMDC. 01:30 02:30 1.00 137 137 INTRM1 DRILL PULD P Upload MWD Time Logs _____ _ _ _ _ __ Date From To Dur S. De th E. pe th Phase Code Subcode T COM 10/18/2007 02:30 03:00 0.50 137 350 INTRM1 DRILL PULD P _ Continue to pick up BHA #4, Make up 2 NMDC's, Jars, Remove corrosion rin , RIH w/ HWDP 03:00 03:30 0.50 350 350 INTRM1 DRILL PULD P Shallow test MWD - OK, Pump rate 650 gpm @ 1500 psi, 37% F-ow, 30 RPM, 2K TQ. 03:30 06:00 2.50 350 3,200 INTRM1 DRILL PULD P Single in Drill pipe from pipe shed f/ 350' to 3200', Drift pipe w/ 2.86" Drift while ickin u i e. 06:00 08:00 2.00 3,200 5,389 INTRM1 DRILL PULD P Continue to PU 5" DP from the shed (159 joints total). Note; Rigged up Little Red Service and Freeze Protected 13-3/8" x 9-5/8" Annulus with 140 bbls diesel at rate of .85 bpm final ressure of 850 si. 08:00 08:30 0.50 5,389 5,389 INTRM1 DRILL CIRC P Break circ and establish drilling arameters, shallow test MWD - ok 08:30 10:00 1.50 5,389 8,624 INTRM1 DRILL TRIP P TIH to 8,624' and with BHA #4, filling drill i e eve 25 stands. 10:00 10:30 0.50 8,624 8,886 INTRM1 DRILL REAM P Break circ and wash down to the top of the Float Collar at 8,886' with 615 gpm, 146 spm, 2,600 psi, PU= 180K, S0= 95K, ROT= 132, TQ on/off = 10,000 ft-Ib. 10:30 11:00 0.50 8,886 8,806 INTRM1 CASIN DHEQ P Circ and condition mud for casing test. 11:00 11:30 0.50 8,806 8,806 INTRM1 DRILL OTHR P Service rig and top drive. 11:30 12:30 1.00 8,806 8,806 INTRM1 CASIN DHEQ P Test and chart 9-5/8" casing test for , 30 min. RD testin a ui ment. 12:30 14:00 1.50 8,806 8,980 INTRM1 CASINC OTHR P Drill out float equipment from 8,886' - 8,980' 3,280' tvd 14:00 14:30 0.50 8,983 9,003 INTRM1 DRILL DDRL P Drill 20' of new formation to 9,003' and 3,281' tvd . 14:30 15:15 0.75 9,003 9,003 INTRMI DRILL CIRC P Circ and condition mud for LOT Raise mud wt. f/ 8.2 to 8.3 15:15 16:00 0.75 9,003 9,003 INTRM1 DRILL LOT P Perform FIT to 17.7 ppg EMW with 8.3 ppg MOBM and 716 psi surface ressure. Clean ECD = 9.82 16:00 18:00 2.00 9,003 9,287 PROD1 DRILL DDRL P Drill ahead 9,287' and (3,286' tvd) with Max as = 78 units. 18:00 00:00 6.00 9,287 10,160 PROD1 DRILL DDRL P Drill from 9,287' and - 10,160' (3,283' tvd 10/19/2007 00:00 06:00 6.00 10,160 11,098 PROD1 DRILL DDRL P Drill 10,160' - 11,098' md. (3,280'tvd). WOB 5-12K, 120 RPN, 690 gpm, 3,100 psi. PU= 200, S0= 92, ROT= 138 ECD=10.37, Max Gas= 138 units ART= 4.12 hr 06:00 11:30 5.50 11,098 12,043 PROD1 DRILL DDRL P Drill 11,098' - 12,043' md. (3,277' tvd). WOB 8-12K, 120 RPN, 681 gpm, 3,380 psi. PU= 210, S0= 73, ROT= 139 ECD=10.65, Max Gas= 150 units ADT= 2.80 hr i ~~ij~ '9 ~ 4i ~~ y Time Logs _ _ _ Date From To Dur 5 Depth E. De th PhaSe Code Subcode T COM 10/19/2007 11:30 12:00 0.50 12,043 12,043 PROD1 DRILL DDRL P Monitor well after H2S alarm sounds (verified it was false). Check flow (Possible Mild flow) circulate bottoms up. No gas cut mud, Monitor well - Static. 12:00 18:00 6.00 12,043 13,038 PROD1 DRILL DDRL P Drill 12,043' -13,038' md. (3,276' tvd). WOB 3-10K, 120 RPN, 680 gpm, 3,540 psi. PU= 225, S0= 73, ROT= 139, TQ on/off= 17,000/15,000 ft-Ib ECD=11.7, Max Gas= 150 units ADT= 3.54 hr 18:00 00:00 6.00 13,038 14,039 PROD1 DRILL DDRL P Drill 13,038' - 14,039' md. (3,271' tvd). W06= 10K, 120 RPN, 650 gpm, 3,450 psi. PU= 235, S0= 73, ROT= 138, TO on/off= 18,000/17,000 ft-Ib ECD=11.41, Max Gas= 125 units ADT= 3.41 hr 10/20/2007 00:00 01:00 1.00 14,039 14,039 PROD1 DRILL CIRC T High-Line power outage. Switched to rig generators but had to wait while restarting computers in the MWD unit and to recover data, before roceedin . 01:00 07:00 6.00 14,039 14,800 PROD1 DRILL DDRL P Drilt ahead 14,039' 14,800' (3,260'). ECD= 11.68 07:00 13:00 6.00 14,800 15,195 PROD1 DRILL DDRL P Drill ahead 14,800' 15,195' (3,261'). ECD= 11.70 13:00 15:45 2.75 15,195 15,468 PROD1 DRILL DDRL P Drill ahead 15,195' 15,468' (3,260'). ECD= 11.97 15:45 18:00 2.25 15,468 15,468 PROD1 DRILL CIRC P Circulate and condition mud to lower ECDs after having 25K overpull at connection (290K). Pump a 35 bbl Hi-Vis seep and CBU. PU after cleanin hole was 265K. 18:00 19:00 1.00 15,468 15,518 PROD1 DRILL DDRL P Drill ahead 15,468' 15,518' (3,259'). ECD= 11.91 19:00 00:00 5.00 15,518 16,038 PROD1 DRILL DDRL P Drill ahead 15,518' 16,038' (3,256'). ECD= 11.97 10/21/2007 00:00 06:00 6.00 16,038 16,325 PROD1 DRILL DDRL P Drill ahead 16,038' to 16,235' (3,258') tvd. ECD= 11.80 06:00 12:00 6.00 16,325 16,770 PROD1 DRILL DDRL P Drill ahead 16,325' to 16,770' (3,250' tvd). ECD= 11.91 Concretions 16,430' - 16,435'. 12:00 12:30 0.50 16,770 16,799 PROD1 DRILL DDRL P Drill ahead 16,770' to 16,799' and 3,250' tvd .ECD= 11.98 12:30 13:30 1.00 16,799 16,799 PROD1 DRILL CIRC P Circ and condition mud to reduce ECDs. Before ECDs= 11.98, After= 11.82 EMW. 13:30 18:00 4.50 16,799 17,083 PROD1 DRILL DDRL P Drill ahead 16,799' to 17,083' and (3,256' tvd). ECD= 11.90 Concretion 16,997-17,000' 18:00 21:30 3.50 17,083 17,083 PROD1 DRILL CIRC P Circulate and condition mud at 17,073', 565 gpm, 3,100 psi, 120 rpm and 21,000 ft-Ib. Pump 40 bbl Hi-Vis sweep with no significant cutting return increase. CBU 3x. . I Time Logs Date From To Dur 5 De th E De th Pha e Code Subcode T COM 10/21/2007 21:30 21:45 0.25 17,083 16,707 PROD1 DRILL REAM P BROOH from 17,083' - 16,707' and at 600 gpm, 3,400 psi, 120 rpm and 21,000 ft-Ib of for ue. 21:45 22:45 1.00 16,707 16,707 PROD1 DRILL OWFF P Monitor well. Observed flow and monitored with the trip tank. Well was flowin at 6 bbl/hr. 22:45 23:00 0.25 16,707 16,707 PROD1 DRILL CIRC NP Circ at 16,707' and at 600 gpm, 3,350 psi, 120 rpm, and 21,000 ft-Ib of torque. Start weighting up from 8.4 - 8.6 ppg. Contacted pad operator and had them shut in injector wells 1J-156 and 1 J-160. 23:00 23:30 0.50 16,707 17,073 PROD1 DRILL TRIP NP RIH from 16,707' to 17,083' md. 23:30 00:00 0.50 16,707 17,083 PROD1 DRILL CIRC NP Circ at 17,083' and at 585 gpm, 3,300 psi, 120 rpm, and 22,000 ft-Ib of torque. Start weighting up from 8.4 - 8.6 ppg. Saw +/-30% increase in cuttings between 3 - 5,000 strokes (4,500 stks = btms up). Final Malin = MWout = 8.6 10/22/2007 00:00 00:30 0.50 16,707 17,083 PROD1 DRILL CIRC NP Circ at 17,083' and at 585 gpm, 3,300 psi, 120 rpm, and 22,000 ft-Ib of torque. Start weighting up from 8.4 - 8.6 ppg. Saw +/-30% increase in cuttings between 3 - 5,000 strokes (4,500 stks = btms up). Final Malin = MWout = 8.6 00:30 01:45 1.25 17,083 17,083 PROD1 DRILL CIRC NP Observed well flowin at +/- 1/2 bbl/hr. Circ wel- at 17,083' and at 585 gpm, 3,300 psi, 120 rpm and 22,000 ft-Ib. Malin = MWout = 8.6 ppg. Observed well for 20 min, - no flow. 01:45 02:00 0.25 17,083 16,972 PROD1 DRILL TRIP P POOH one stand to 16,972' on elevators. PU= 295K. 02:00 02:30 0.50 16,972 16,972 PROD1 DRILL OWFF P Monitor well on Trip tank -static. 02:30 05:30 3.00 16,972 15,470 PROD1 DRILL REAM P BROOH from 16,972' to 15,470' tmd at 600 gpm, 120 rpm. ECDs = 12.1 ppg initially, reduced flow to 600 gpm with 11.63 - 11.8 ppg ECD. Lost 18 bbl while BROOH. 05:30 06:00 0.50 15,470 15,470 PROD1 DRILL OWFF NP Monitored well, flowing at 12 bbl/hr. Continued to monitor and flow went to zero. Monitored well static. 06:00 12:00 6.00 15,280 12,500 PROD1 DRILL REAM P Continue BROOH from 15,280' - 12,500' tmd. 12:00 18:00 6.00 12,500 9,100 PROD1 DRILL REAM P Continue BROOH from 12,250' - 9,100' tmd. 18:00 18:15 0.25 9,100 8,980 PROD1 DRILL REAM P Continue BROOH from 9,100' - 8,980' tmd. NOTE: total losses while BROOH= 194 bbl. ~. ~ .. ~.~._...._. . ~'<q~ 1 ~ to f ~ r__. I ~~ I Time Logs _ _ Date From To Dur S. De th E. De th Phase Code Subcode T COM 10/22/2007 18:15 20:30 2.25 8,980 8,980 PROD1 DRILL CIRC P Circ Btms up at shoe with 680 gpm, 2,980 psi, 120 rpm, 15,500 ft-Ib and ECD= 10.45. Circ 3+ Btms up (total stks= 16,500). SO at the shoe before /after= zero / 5,000 Ib, PU at the shoe before /after= 218 / 225K Ib. 20:30 21:30 1.00 8,980 8,980 PROD1 DRILL OWFF NP .Well flowin /breathing. Monitor well on the trip tank. Well became static. Total trip tank volume while monitorin = 0.5 bbl. 21:30 21:45 0.25 8,980 8,905 PROD1 DRILL OWFF P Blow down TD and continue to monitor well.- static. 21:45 22:15 0.50 8,905 8,905 PROD1 DRILL OWFF P Hang blocks and PJSM for Cut and Sli .Continue to monitor well on TT. 22:15 23:30 1.25 8,905 8,905 PROD1 RIGMN' SVRG P Cut and slip 115' of DL. Inspect brakes on drawworks. 23:30 00:00 0.50 8,905 8,905 PROD1 RIGMN SVRG P Service rig - TD, drawworks, Blks and Crown. 10/23/2007 00:00 00:15 0.25 8,905 8,905 PROD1 RIGMN SFTY P Pre job safety meeting on changing saver sub on the to drive. 00:15 02:00 1.75 8,905 8,905 PROD1 RIGMN' SVRG P Change out the saver sub on the top drive. Chan a dies on the rabber. 02:00 13:30 11.50 8,905 17,083 PROD1 DRILL REAM P Ream in the hole. Pumping 110 gpm w/ 380-550 psi. Rotate 40-70 rpm w/ 15- 24k ft Ibs of torque. Record PU and SO wt's, Rotating wt's and torque every 5 stands. Note: Lost 13 bbls of MOBM on trip in. 13:30 17:00 3.50 17,083 17,083 PROD1 DRILL CIRC P Circulate and condition mud. Circulate a bottom's up, then pump a 40 bbl sweep (8.6 ppg, 240 vis), with no increase in cuttings. Circulate a total of 3 bottom's up. Then pumping 550 gpm w/ 3350 psi, rotating 125 rpm w/ 24k ft Ibs of torque. 250k PU wt, 137k rotating wt, and SO wt only 72k (block wt after circulatin . 17:00 17:15 0.25 17,083 17,083 PROD1 DRILL OWFF P Monitor well (static). 17:15 19:00 1.75 17,083 17,083 PROD1 DRILL CIRC P Displace to 8.6 ppg SFOBM. Pumping 575 gpm w/ 3620 psi. Rotate 120 rpm w/ 23k ft Ibs of torque. Rot wt 140k, Rot torque 25-26k ft Ibs w/ pumps off. PU wt 280k Note: Lost 31 bbls of mud while dis lacin to SFOBM. 19:00 19:15 0.25 17,083 16,992 PROD1 DRILL OWFF P Monitor well, slight flow. 19:15 00:00 4.75 16,992 13,663 PROD1 DRILL TRIP P Pump out of the hole, pumping 165 gpm w/ 390 psi. Record PU and SO wt's every 5 stands. SLM. Drop a 2.34" rabbit w/ 165' of wire tail 16612'.. PU wt 260k, SO wt none, Rot wt 145k w/ 21 k ft Ibs of for ue. _ ~_ ~ P.~t~e ?~ ~i# ~g ~ Time Logs _ __ _ _ __ Date From To __D_ur _ SDP,pth E. Depth Phase Code Su_bcode T COM __~ 10/24/2007 00:00 06:30 6.50 13,663 8,980 PROD1 DRILL TRIP P Pump out of the hole, pumping 170 gpm w/ 390 psi. Record PU and SO wt's every 5 stands. SLM. PU wt 240k, SO wt none, Rot wt 140k w/ 16-18k ft Ibs of torque. Note: Calculated fill 71.11, actual fill 73 bbls. 06:30 06:45 0.25 8,814 PROD1 DRILL CIRC P Obtain minimal flow rates for MWD detection. Appears to be 325 gpm w/ 910 si. 06:45 08:30 1.75 8,980 8,980 PROD1 DRILL CIRC P Pump a 40 bbl high vis sweep, follow w/ 1510 bbls =total of 1550 bbls pumped. Pump rate 590 gpm w/ 2670 psi. Rotate 120 rpm w/ 16k ft Ibs of torque. PU wt 220k, SO wt 80k, Rot wt 140k. These numbers are after circulatin . 08:30 09:00 0.50 8,814 8,814 PROD1 DRILL OWFF P Monitor well (static). 09:00 09:30 0.50 8,980 8,814 PROD1 DRILL TRIP P Pull 2 stands. 09:30 09:45 0.25 8,814 8,814 PROD1 DRILL SFTY P PJSM on PU/MU/Stand back in the derrick 5" HWDP. 09:45 11:30 1.75 8,814 PROD1 DRILL PULD P Install floor safety valve. Monitor well on the trip tank while pickup/makeup 15 stands of 5"drill pipe from the pipe shed using the mouse hole, then stand back same in the derrick. Observed well to be static for the first 30 minutes, then then gained 1 bbt over the next hr while ickin u i e. 11:30 11:45 025 8,814 8,814 PROD1 DRILL OWFF P Monitor well (Slight flow). 11:45 12:00 0.25 8,814 8,910 PROD1 DRILL TRIP P Trip in the hole. 12:00 13:45 1.75 8,910 8,910 PROD1 DRILL CIRC P Circulate, pumping 600 gpm w/ 2900 psi. Rotate 120 rpm w/ 15k ft Ibs of torque. Pump a 40 bbf high vis sweep, then weight up SFOBM f/ 8.6 ppg to 8.8 ppg, add 776 tube. PU wt 175k, SO wt 115k after addin 776 tube. 13:45 15:00 1.25 8,910 8,910 PROD1 DRILL OWFF P Monitor well on the trip tank. After 15 min: showed gain rate @ 2.4 bph. After 30 min: gain rate of .8 bph. After 45 min: gain rate of no gain. Monitor well w/ trip pump off and showed very sli ht flow. 15:00 15:15 0.25 8,910 8,719 PROD1 DRILL TRIP P POOH. 15:15 16:15 1.00 8,719 8,799 PROD1 WELCT OTHR P Observe well (static). MU Baker FJ~ retrievamatic storm packer f/ 9-5/8" casing. RIH and set w/element 80' from surface, top @ 69' from surface, and the 8-1/2" bit 8799'. 16:15 16:45 0.50 8,799 0 PROD1 WELCT BOPE P Test the storm packer w/ 500 psi f/ 5 min. OK. Bleed off. Release from acker, POOH .~ ~~ ~ day 2~t of ~9~ ~~ v Time Logs _ ___ _ ___ D te_ Fro_m To Dur S. De th E. D th Phase Code Subcode T COM __ 10/24/2007 16:45 19:00 2.25 0 0 PROD1 WELCT OTHR P Rig up to test 13-5/8" BOPE. Drain stack, pull wear bushing. PU 4-1/2" test jt, MU Vetco Gray test plug, install test plug. Open annulus valve. Fill stack w/water, circ and fill choke manifold. Ri u chart recorder. 19:00 00:00 5.00 0 0 PROD1 WELC BOPE P Test BOPE. Witness of test by AOGCC inspector Lou Grimaldi. Test annular to 250 psi low and 3000 psi high w/ 4-1 /2" test jt. Hold each test f/ 5 min. Test upper pipe rams (3-1/2" x 6" variables) w/ 4-1/2" test jt. Test to 250 psi low and 3000 psi high, holding each test 5 min. Test upper and lower IBOP on the top drive, to 250 psi low and 3000 psi high, holding each test 5 min. Test floor IBOP to 250 psi low and 3000 psi high. Hold each test f/ 5 min. Testing valves on the choke manifold same as above. Testing kill line valves, same wa . 10/25/2007 00:00 01:45 1.75 0 0 PROD1 WELCT BOPE P Continue test of BOPE (14 day interval). Witness of test by AOGCC inspector Lou Grimaldi. Test annular to 250 psi low and 3000 psi high w/ 4-1/2" test jt. Hold each test f/ 5 min. Test upper pipe rams (3-1/2" x 6" variables) w/ 4-1/2" test jt. Test to 250 psi low and 3000 psi high, holding each test 5 min. Test upper and lower IBOP on the top drive, to 250 psi low and 3000 psi high, holding each test 5 min. Test floor IBOP to 250 psi low and 3000 psi high. Hold each test f/ 5 min. Testing valves on the choke manifold same as above. Testing kill line valves, same way.Test accumulator with 3000 psi starting pressure, 1500 psi after closure, 200 psi build up in 50 seconds, full charge in 3 min 55 seconds. 5 bottles of nitrogen average 2275 psi. Valve #3 in the choke manifold failed to test. Valve #3 is a redundant valve fora 3000 psi choke manifold. Will be repaired after this well (approved by AOGCC rep Lou Grimaldi . 01:45 03:00 1.25 0 0 PROD1 WELCT OTHR P Rig down testing equipment. Pull test plug, drain stack, install wear bushing. blow down kill and choke lines and choke manifold. 03:00 03:15 0.25 0 0 PROD1 WELCT SFTY P PJSM on retrieving Baker storm aaker. ~~f~ "~ Cl'f ~ ~~ Time Logs _ __ Date From To Dur S. Depth E. D th Phase Code Subcode T COM __ __._ ~ 10/25!2007 03:15 04:30 1.25 0 8,730 PROD1 WELCT OTHR P Screw into storm packer @ 69' from rig floor, check for pressure on drill string. No preesure. Pull Baker EA retrievamatic to the rig floor while monitorin annulus. 04:30 05:00 0.50 8,730 8,700 PROD1 WELCT OTHR P Make breaks and laydown Baker Oil Tools 9-5/8" Retrievamatic (storm acker . 05:00 06:00 1.00 8,700 8,795 PROD1 DRILL CIRC P MU stand and top drive connection. Record minimum pump rate f/MWD detection. Detection @ 270 gpm w/ 830 psi. Circulate BU+ (circulated 552 bbls) while pumping 390 gpm w/ 1540 psi. PU wt 180k, SO wt 110k. Rotate 120 rpm w/ 10k ft Ibs of torque. Rotating wt 135k. Lost 24 bbls while circulating. Note: Tested rig floor safety valve to 250 psi and 3000 psi. Test 5 min each. Chart test. 06:00 07:15 1.25 8,795 8,795 PROD1 DRILL OWFF P Monitor well. Record gains every 10 min. First 10 min = 10.2 bph (1.7 bbls), next was 4.8 bph (.8 bbls), next 2.4 bph (.4 bbls), next 1.8 bph (.3 bbls), next 1.8 bph (.3 bbls), next was no ain. Total ain in 1 hr= 3.5 bbls. 07:15 09:15 2.00 8,795 7,863 PROD1 DRILL TRIP P POOH a stand (hole swabbing), pump out of the hole. Pumping 169 gpm w/ 400 si. Rotate 70 r m. 09:15 13:45 4.50 7,863 350 PROD1 DRILL TRIP P POOH w/ BHA #4. Record PU and SO wt's every 10 stands. Hole took proper displacement. Continue SLM. No corrections. Found rabbit on top of 'ars. 13:45 15:00 1.25 350 62 PROD1 DRILL TRIP P Stand back 1 stand of HWDP, PU a single and stand back stand #2 HWDP, UD jars, stand back flex collars. 15:00 15:45 0.75 62 62 PROD1 DRILL OTHR P Download MWD. 15:45 16:45 1.00 62 0 PROD1 DRILL PULD P Remove pulsar and TM. Lay down HOC, MWD and Geo flex collar, break and la down bit. 16:45 17:30 0.75 0 0 COMPZ CASIN RURD P Rig up GBR to run "B" lateral s-1 /2" com letion. 17:30 17:45 0.25 0 0 COMPZ CASIN SFTY P PJSM on running liner. 17:45 18:00 0.25 0 0 COMPZ CASIN OTHR P Bring Baker Oil Tools Equipemnt to - the floor. 18:00 00:00 6.00 0 6,100 COMPZ CASIN( RNCS P Run 5-1/2" 15.5 ppf BTC and hyd 521 slotted/blank liner. Record PU and SO wt's every 10 jts. PU wt 120k, SO wt 100k. Running speed 90'/min to start, then ro ressed to 20'/min. ~~.. __ ~ Pa€~~ 2~ c~~ ~9 ` I n Time Logs D to FromTo Dur S. De th E. De th Phase Code Subcode T COM 10/26/2007 00:00 02:00 2.00 6,100 6,900 COMPZ CASIN RNCS P Continue to run 5-1/2" 15.5 ppf BTC and hyd 521 slotted/blank liner. Record PU and SO wt's every 10 jts. PU wt 125k, SO wt 100k. Running s eed 20'/min. 02:00 03:00 .1.00 6,900 6,900 COMPZ CASINC OTHR NP Because of improper dispalcement (not enough returns). MU floor crossover, then top drive. Rotate liner and work up (swabbing), and down (Pushing mud away) to try and get proper displacement. No change. Rotate @ 40 rpm w/ 5k ft Ibs of torque. Rotating weight 120k. PU wt 125k, SO wt 100k. Break crossover and top drive off and put crossover back on floor safe valve. 03:00 05:45 2.75 6,900 8,600 COMPZ CASINC RNCS P Continue to run 5-1/2" 15.5 ppf BTC and hyd 521. slotted/blank liner. Record PU and SO wt's every 10 jts. PU wt 120k, SO wt 100k. Tried running speed of 10'/min for a while with no improvemnet of displacement. Then continued to run liner at 40'lmin, then 110'/min with better displacement returns. Note: Calculated dispalcement 50.6 bbls for 15.5 ppf, actual 18 bbls, Loss of 32.6 bbls. 05:45 07:45 2.00 8,600 8,641 COMPZ CASINC OTHR P Rig up Baker small tongs. MU Sperry Sun slim MWD and orient to Baker MLZXP packer. MU Flexlock hanger and Baker MLZXP packer to the 5-1/2" liner strip . 07:45 08:30 0.75 8,641 8,641 COMPZ CASIN OTHR P Shallow test Sperry Sun MWD. Pumping 125 gpm w/ 710 psi. Good test. 08:30 10:00 1.50 8,641 11,017 COMPZ CASINC RUNL P Trip in the hole w/the 5-1/2" slotted/blank BTC and hydril 521 liner on 5" drill pipe. Record PU and SO wt's every 10 stands in casing, every 5 stands in open hole. Record just before exit shoe and right after exit shoe the rotating torque and rotating wt. 10:00 10:30 0.50 11,017 11,017 COMPZ CASINC OTHR P Shallow test Sperry Sun MWD. Pumping 125 gpm w! 710 psi. Good test. 10:30 12:30 2.00 11,017 13,775 COMPZ CASIN RUNL P Trip in the hole w/the 5-1/2" slotted blank BTC and hydril 521 liner on 5"drill pipe. Record PU and SO wt's every 5 stands in open hole. Ran out of down wt 13775'. ~~_._..W. ®® ~ ~ P~~~ .?3 of ~9 Time Logs Date From To Dur S De th E De th Ph Code Subcode T COM 10/26/2007 12:30 17:00 4.50 13,775 17,083 COMPZ CASINC RUNL __ P _ Rotate the 5-1 /2" "B" lateral slot/blank liner in the hole w/ 5"drill string consisting of 37 stands blank, 30 stands w/super sliders, 17 stands of 5" HWDP, then 6 stands slick drill pipe to tag bottom 10' deep by liner tally. Record PU and SO wt's every 5 stands. Total fluid lost on liner run (liner and dp) was 62 bbls. On bottom: PU wt 240k, SO wt 87k, Rot wt 170k, rotatin for ue 17k ft lbs. 17:00 18:00 1.00 17,083 17,046 COMPZ CASINC OTHR P Work string up and down to orient the lug of the MLZXP packer. Pumping 126 gpm w/ 1070 psi. With shoe @ 17046.24' and 180k slight tension on the string. Oriented to have the lug rofile inside 3 de left of hi hside. 18:00 19:00 1.00 17,046 17,046 COMPZ CASIN OTHR P Drop the 1-3/4" setting ball. Pump down @ 2-1 /2 bpm w/ 750 psi till on seat @ 119.98 bbls. Pressure up to 2000 psi to set the flex lock han er. Slack off 50k to verify hanger set. Continue to pressure up to 2500 psi to activate the pusher tool and set the MLZXP liner to Continue to pressure up to 3000 psi to release running tool. Then pressure to 3900 psi to neutralize the pusher tool. Bleed off the pressure, PU to verify release. OK. Slack back off to tag the top of acker. 19:00 19:30 0.50 17,046 17,046 COMPZ CASINC DHEO P Close the top pipe rams and test by pumping through the kill line, the MLZXP packer. Pressure to 2500 ~,i and hold f/ 5 miriutes. Chart test. Bleed off pressure and open the top i e rams 3-1/2" x 6" . 19:30 20:00 0.50 17,046 8,400 COMPZ CASINC OTHR P PU 8' then slack off to verify setting depth of liner top packer and shoe. Liner top packer @ 8415.74', and the 5-1/2" shoe bottom @ 17046.24'. Pull and set back a stand. 20:00 21:00 1.00 8,400 8,400 COMPZ CASINC CIRC P Circulate bottom's up by pumping 400 gpm w/ 1160 psi. Lost 7 bbls while circulating. Circulated a total of 482 bbls. Obtain SPR's. 21:00 21:45 0.75 8,400 8,400 COMPZ CASIN OTHR P Monitor well. Breathing: first 10 min gained @ 1.5 bph, next 10 min @ 1.2 b h. 21:45 22:15 0.50 8,400 7,750 COMPZ CASIN< RUNL P Pull 4 stands of 5" drill pipe, then 3 stands of 5" HWDP. Incorrect fill, swabbin . 22:15 22:30 0.25 7,750 7,750 COMPZ CASINC OTHR P Monitor well. Static. 22:30 23:30 1.00 7,750 6,900 COMPZ CASINC RUNL P Pump out of the hole, pumping 168 m w/ 310 si. Pultin seed 90'/min. ~'~g~ 2~ ref ~~ ~ '' ~'. Time Logs ___ _ _ Date From To Dur S Depth E Depth Phase Code Subcode T COM __ __ 10/26/2007 23:30 23:45 0.25 6,900 6,900 COMPZ CASINC OTHR P Monitor well. Static_ 23:45 00:00 0.25 6,900 6,600 COMPZ CASINC RUNL P Pump out of the hole, pumping 168 m w/ 310 si. Pullin seed 90'/min. 10/27/2007 00:00 01:30 1.50 6,600 5,500 COMPZ CASIN< RUNL P Pump out of the hole, pumping 168 m w/ 310 si. Pullin seed 90'/min. 01:30 01:45 0.25 5,500 5,500 COMPZ CASINC OTHR P Monitor well-- static. 01:45 05:00 3.25 5,500 81 COMPZ CASINC RUNL P POOH on elevators, monitor well on the trip tank. Record PU and SO wt's every 10 stands. Note: Calculated fill f/entire trip 88.25, actual 90.5 for a loss of 2.25 bbl. 05:00 05:30 0.50 81 81 COMPZ CASINC OTHR P Monitor well-- static. Clean floor. Bring Baker blue small ton s to the floor. 05:30 06:30 1.00 81 0 COMPZ CASINC OTHR P Making service breaks on Baker HR running tool and inner string including S er Sun MWD. La down same. 06:30 07:00 0.50 0 0 COMPZ CASIN OTHR P Clear and clean floor. 07:00 08:15 1.25 0 0 PROD2 STK PULD P Break down a stand of 5" HWDP and lay down into the pipe shed. Bring Baker whi stock tools to the ri floor. 08:15 11:15 3.00 0 167 PROD2 STK PULD P PJSM. PUlMU Baker Milling assembly, then lay down to the pipe shed. PU Baker whipstock assembly. Orient MWD to the face of the whipstock (Highside). Orient anchor lug below the whipstock to 13 deg right of the whipstock (this makes the whipstock 13 deg left of the lug). Orientation by Rig Supervisor, DD, MWD, Baker.PU milling assembly and bolt up to whipstock w/ 35k shear bolt. Unloader set to shear @ 6k overpull. MU MWD then orient MWD to the face of the whi stock Hi hside . 11:15 11:45 0.50 167 167 PROD2 STK OTHR P Downlaod MWD 11:45 12:15 0.50 167 329 PROD2 STK PULD P Continue to PU/MU Baker milling BHA BHA #5 . 12:15 12:30 0.25 329 329 PROD2 STK CIRC P Shallow test MWD. Pumping 450 gpm w/ 720 m. Good test. 12:30 18:00 5.50 329 7,178 PROD2 STK WPST P Trip in the hole with the 9-5/8" whipstock assembly on 5"drill string consisting of 37 stands of slick drill pipe, 30 stands of super sliders, 5 stands slick dp, then make a connection on first stand of 5" HWDP. 18:00 19:00 1.00 7,178 7,266 PROD2 STK OTHR P Make a top drive connection. MADD pass. Pumping 500 gpm w/ 1880 psi. GR sensor depth 7046' to 7133'. Bit de th 7178' to 7266'. 19:00 20:00 1.00 7,266 8,370 PROD2 STK WPST P Continue in the hole with the Baker whi stock on 5" HWDP. ~. ~a~~ 2~ ~rf A~3 ~~~ ~~ Time Logs Date______ From To Dur S. De th E_Depth Phase Code Subcode T COM 10/27/2007 20:00 20:30 0.50 8,370 8,402 PROD2 STK OTHR P MU a single of drill pipe, make a top drive connection. Pumping 470 gpm w! 2140 psi. PU wt 210k, SO wt 115k. Orient the whipstock starting from 41 Ri ht to 17 Left of hi h side. 20:30 22:15 1.75 8,402 8,426 PROD2 STK WPST P MU stand 86 with single still in the string. Make a top drive connection. Pumping 470 gpm w/ 2140 psi. PU wt 210k, SO wt 115k. Work pipe and orientation self oriented to 17-20 Right prior to latch. Latch in @ (8425.79') and pull test to 230k {20k overpull), slack off to 80k (30k down). MWD and whipstock face went from 20 Right to 6 left of high side. After shearing bolt: PU wt 200k, SO wt 110k, Rotating wt 150k .Note; After shearing mills free from whipstock MWD showed 15 left of highside but this was after the bolt sheared. PU 10' to confirm sheared free f/ whipstock. Top of window to be 8365'. 22:15 23:00 0.75 8,365 8,355 PROD2 STK CIRC P After picking mills up 10' to 8355', displace well f/ 8.8 ppg SFOBM to 8.7 ppg MOBM. Pumping 606 gpm w/ 3000 psi. After pumping 382 bbls, start millin o erations. 23:00 00:00 1.00 8,365 8,367 PROD2 STK WPST P .Begin milling window in 9-5/8" 40 ppf L-80 casing @ 8365'. Pumping 606 gpm w/ 3000 psi. Rotate 60 rpm w/ 10k ft Ibs of torque. PU wt 200k, SO wt 110k, Rot wt 150k. 10/28/2007 00:00 07:00 7.00 8,367 8,407 PROD2 STK WPST P Continue milling window in 9-5/8" 40 ppf L-80 casing, TOW @ 8365' (79.55 deg) (6 deg left of highside). BOW @ 8381.62'. Pumping 606 gpm w/ 3000 psi. Rotate 100 rpm w/ 12-13k ft Ibs of torque. PU wt 200k, SO wt 110k, Rot wt 150k. Note: Pump a 40 bbl sweep while milling @ 8381'.(8.8 ppg/ 200 vis) with medium increase in cuttin s. 07:00 08:15 1.25 8,407 8,407 PROD2 STK OTHR P Check and cleanup window. Work mills through window.While pumping @ 446 gpm w/ 1620 psi, pump a 40 bbls 8.8 ppg 210 vis sweep. Work mills across window. Window in good condition. Obtain SPR's. 08:15 08:30 0.25 8,407 8,407 PROD2 STK OTHR P Monitor well- static. 08:30 10:15 1.75 8,407 7,390 PROD2 STK TRIP P Attempt to pull on elevators, hole swabbing. Pump out of the hole. Hole fill correct. 10:15 10:30 0.25 7,390 7,116 PROD2 STK TRIP P Pull out of the hole. The hole took ro er dis lacement. 10:30 10:45 0.25 7,116 7,116 PROD2 STK OTHR P Monitor the well- static. ~~€~e ~~ raf ~~ Time Logs ~ _ _ T COM ~ Date From To Dur S De th E. De th Ph se Code Subcod e 10/28/2007 10:45 11:00 0.25 7,116 7,116 PROD2 STK __ __ CIRC P Pump a dry job. Blow down the top drive. 11:00 13:15 2.25 7,116 268 PROD2 STK TRIP P Pull out of the hole. The hole took ro er dis lacement. 13:15 13:45 .0.50 268 106 PROD2 STK PULD P Lay down BhA. Stand back the HWDP wears. 13:45 14:15 0.50 106 106 PROD2 STK OTHR P Download Sperry Sun MWD. 14:15 15:00 0.75 106 0 PROD2 STK PULD P Lay down BHA #5: Window mill under guage a 1/4", lower mill and upper mill is full ua a 8.5" . 15:00 15:30 0.50 0 0 PROD2 STK PULD P Clean and clear rig floor of all milling tools. 15:30 16:00 0.50 0 0 PROD2 STK OTHR P Flush the BOP stack. 16:00 17:00 1.00 0 77 PROD2 DRILL PULD P MU BHA #6: MU bit #5, geopilot, geo flex, MWD, HOC. 17:00 17:30 0.50 77 77 PROD2 DRILL OTHR P Upload MWD 17:30 18:00 0.50 77 353 PROD2 DRILL PULD P Continue to PU/MU BHA #6. 18:00 18:30 0.50 353 353 PROD2 DRILL OTHR P Shallow test MWD. Pumping 510 gpm w/ 930 psi. Rotate 30 rpm breaking in seals on eo ilot. 18:30 18:45 0.25 353 353 PROD2 DRILL OTHR P Blow down top drive and kill line. 18:45 20:00 1.25 353 2,539 PROD2 DRILL TRIP P RIH w/ BHA #6 on 5"drill pipe. Record PU and SO wt's eve 10 stands. 20:00 20:15 0.25 2,539 2,730 PROD2 DRILL TRIP P Install ghost reamer on the top of stand #23, MU stand 24, Make top drive connection on #25. PU wt 180k, SO wt 110k. 20:15 20:45 0.50 2,730 2,730 PROD2 DRILL CIRC P Fill pipe. Rotate 30 rpm to break in seals on the geopilot w/ 3k ft Ibs of torque.. Pump 500 gpm w/ 1230 psi. Rot wt 115k. Test MWD-OK. 20:45 21:30 0.75 2,730 5,110 PROD2 DRILL TRIP P Trip in the hole w/ BHA #6. Record PU and SO wt's eve 10 stands. 21:30 21:45 0.25 5,110 5,110 PROD2 DRILL CIRC P Fill pipe. Rotate 30 rpm to break in seals on the geopilot w/ 6-7k ft Ibs of torque.. Pump 210 gpm w/ 400 psi. Rot wt 125k. 21:45 22:30 0.75 5,110 7,488 PROD2 DRILL TRIP P Trip in the hole w/ BHA #6. Record PU and SO wt's eve 10 stands. 22:30 22:45 0.25 7,488 7,488 PROD2 DRILL CIRC P Fill pipe. Rotate 30 rpm to break in seals on the geopilot w/ 9k ft Ibs of torque.. Pump 210 gpm w/ 530 psi. Rot wt 125k. 22:45 23:15 0.50 7,488 8,345 PROD2 DRILL TRIP P Trip in the hole w/ BHA #6. Record PU and SO wt's eve 10 stands. 23:15 23:45 0.50 8,345 8,345 PROD2 DRILL CIRC P Fill pipe. Rotate 30 rpm to break in seals on the geopilot w/ 11 k ft Ibs of torque.. Pump 210 gpm w! 540 psi. Rot wt 130k. Blow down top drive. Note: Calculated displacement 74.5, actual displacement 76.2 f/ loss of 1.7 bbl. ~_ ®. ®. ~.~_« m ~'aga 2~ ~f ~~ Time Logs _ Date From To Dur S. De th E. De th Ph e Code Subco__de T COM _ 10/31/2007 22:00 23:00 1.00 14,621 15,002 PROD2 DRILL TRIP P Trip back into the hole. Rotate 50 rpm w/ 20k ft Ibs of torque. Pumping 84 gpm w/ 500 psi. Pu wt 255k, SO wt 72k Block wt), Rotatin wt 145k. 23:00 00:00 1.00 15,002 15,175 PROD2 DRILL DDRL P Directional drill "D" lateral 11/01/2007 00:00 06:00 6.00 15,175 15,857 PROD2 DRILL DDRL P Directional drill "D" lateral. 06:00 12:00 6.00 15,857 16,428 PROD2 DRILL DDRL P Directional drill "D" lateral. Pumped a 30 bbls hi vis sweep (8.8 ppg/ 180 vis) while drilling @ 16048'. Slight increase in cuttings. Pump a 30 bbls high vis sweep while drilling @ 16428' (8.7 / 240 vis . 12:00 13:00 1.00 16,428 16,428 PROD2 DRILL CIRC P Circ until high vis sweep is out of the hole. Backream @ 2.5'/min f/ 16428' to 16325' while rotating 120 rpm w/ 22k ft Ibs of torque. Slight increase in cuttings. Pumping 605 gpm w/ 3380 si. Rotatin wei ht 125k. 13:00 16:30 3.50 16,428 16,653 PROD2 DRILL DDRL P Directional drill "D" lateral. 16:30 17:30 1.00 16,653 16,653 PROD2 RIGMN RGRP T Repalce valve and seat in # 2 mud pump. Backream out to 16590' while working on pump. Pumping 462 gpm w/ 2160 psi, #1 mud pump. Pulling 2'/min. Rotate 120 rpm w/ 21 k ft Ibs of for ue. Rotatin wt 130k. 17:30 18:00 0.50 16,653 16,712 PROD2 DRILL DDRL P Directional drill "D" lateral. 18:00 21:00 3.00 16,712 17,083 PROD2 DRILL DDRL P Directional drill "D" lateral. 21:00 00:00 3.00 17,083 16,915 PROD2 DRILL CIRC P Obtain SPR's. Pump a 30 bbl sweep (8.8 ppg/ 200 vis). Backream out of the hole slow while circulating sweep out of the hole, then another BU. Pulling speed 1-2'/min. Pumping 600 gpm to 550 gpm w/ initial 3460 psi and 12 ppg ECD's to mostly 550 gpm w/ 2930 psi and 11.7 ppg ECD's. Rotate 120 rpm w/ 22-23k ft Ibs of torque. PU wt 275k, SO wt 72k (block wt), Rot wt 145k. 11/02/2007 00:00 00:30 0.50 16,915 16,905 PROD2 DRILL CIRC P Backream out of the hole slow while circulating another BU. Pulling speed 2'/min. Pumping 550 gpm w/ 3180-2930 psi and 11.7 ppg ECD's. Rotate 120 rpm w/ 22-23k ft Ibs of torque. PU wt 275k, SO wt 72k (block wt ,Rot wt 145k. 00:30 04:30 4.00 16,905 15,500 PROD2 DRILL REAM P Backream out of the hole. Pulling speed 20'/min. Pumping 550 gpm w/ 3180-2930 psi and 11.7 ppg ECD's. Rotate 120 rpm w/ 22-23k ft Ibs of torque. PU wt 275k, SO wt 72k (block wt ,Rot wt 145k. Page 2 caf ~9 Time Logs _ _ _ _ __ __ Date From To Dur S. De th E De th Phase Code Subcode T COM _ 11/03!2007 06:45 08:15 1.50 11,769 11,769 PROD2 RIGMN' SVRG T While changing the swivel packing/washpipe. Circulate 130 gpm w/ 460 gpm using a headpin and 2" cementin hose. 08:15 08:30 0.25 11,769 11,769 PROD2 DRILL OTHR T Rig down the 2" hose, break the head in. 08:30 18:00 9.50 11,769 17,083 PROD2 DRILL TRIP P Resume reaming in the hole. Pumping 168 gpm w/ 500 to 750 psi. Rotate 55 rpm w/ 17 to 23k ft Ibs of torque. At TD: PU wt 260k, SO wt 72k (block wt), Rot wt (w/pumps on) 125k, Rot wt (w/pumps off 165k. Rotating torque (w/pumps) 23k ft Ibs, Rot torque (w/o pumps) 24-25k ft Ibs. Note: While trip in the hole: Calculated displacement 71.16 bbls, actual 61.2 bbls =loss of 10 bbls. 18:00 20:45 2.75 17,083 17,083 PROD2 DRILL CIRC P Circulate 400 bbls (open hole volume), then pump a 40 bbls sweep (8.6 ppg/ 265 vis). Circulate sweep to surface. Pumping 500 gpm w/ 2750 psi. Reciprocate 80'. Rotate 120 rpm w/ 22k ft Ibs of torque while pumping. Rotating torque with pumps off =25k ft lbs. PU wt 260k, SO wt 72k (block wt). Rotating wt while pumping is 165k. ECD's while pumping 500 gpm = 11.7 ppg. Final circulating rate of 500 gpm w/ 2680 psi. Rotating 120 rpm w/ 21 k ft Ibs of torque. PU wt 260k, SO wt block wt, Rotating wt 165k. Torque w/ pumps off= 24-25k ft Ibs. Final ED's of 11.47 20:45 21:00 0.25 17,083 17,083 PROD2 DRILL SFTY P PJSM on displacement white still circulating 500 gpm w/ 2610 psi. Reciprocate 80'. Rotating 120 rpm w/ 22k ft Ibs of torque. ECD's 11.7 ppg. Rotatin wt 130k. 21:00 23:00 2.00 17,083 17,083 PROD2 DRILL CIRC P Displace 8.4 ppg MOBM to 8.4 ppg SFOBM. Reciprocate 80'. Rotate 120 rpm w/ 21 k ft Ibs of torque. Pumping 500 gpm w/ 2450 psi. PU wt 170k, SO wt =block wt, Rotating wt 138k. Torque w/ pumps off is 21 k ft Ibs. ECD's 10.54 23:00 23:15 0.25 17,083 16,904 PROD2 DRILL OTHR P Obtain slow pump rates. Pull out two stands to 16904'. Monitor well static. 23:15 23:30 0.25 16,904 16,809 PROD2 DRILL TRIP P POOH on elevators. Hole appears to be swabbing while pulling pipe. Static hole when not movin . 23:30 00:00 0.50 16,809 16,619 PROD2 DRILL TRiP P Pump out of the hole. Pulling 70-90'/min. Pumping 190 gpm w/ 500 psi. PU wt 270k, SO wt is block wt. Monitoring hole via Active Mud System. Record PU and SO values eve 5 stands in o en hole. _ ~ ~~~ ~~® Pay 31 of 43 .r L~ Time Logs _u ___ _ Date _ From To bur S Depth E De th Phase Code Subcode T COM 11/04/2007 00:00 06:00 6.00 16,619 11,484 PROD2 DRILL TRIP P Pump out of the hole. Pulling 70-90'/min. Pumping 190 gpm w/ 500 psi. PU wt 270k, SO wt is block wt. Monitoring hole via Active Mud System. Record PU and SO values eve 5 stands in o en hole. 06:00 10:45 4.75 11,484 8,159 PROD2 DRILL TRIP P Pump out of the hole. Pulling 70-90'/min. Pumping 195 gpm w/ 500 to 400 psi. PU wt 270 to 235k, SO wt is block wt to 90k. Monitoring hole via Active Mud System. Record PU and SO values every 5 stands in open hole. Note: On trip out f/ 17083' to 8159': Calculated fill 77.52 bbls, actual 105 bbls for a loss of 27.48 bbls. '~/ 10:45 12:15 1.50 8,159 8,069 PROD2 DRILL CIRC P Reciprocate 90'. Displace to 8.8 ppg/ 65 vis SFOBM w/ 3% 776 lubricants. Pumping 475 gpm w/ 1760 psi. Rotate 120 rpm w/ 12k torque. PU wt 215k, SO wt 90k. Noted a significant increase in cuttings after pumping 361 bbls. Continued to pump till 8.8 ppg SFOBM was all the way to the surface. PU wt 170k, SO wt 115k, Rotating wt 130k, Rot torque 9k After 8.8 ppg SFOBM was to surface, increased the flow rate to 550 gpm w/ 2480 psi. No increase in cuttin s. Circulated a total of 763 bbls. 12:15 12:30 0.25 8,069 8,069 PROD2 DRILL OWFF P Monitor well- static. 12:30 12:45 0.25 8,069 7,873 PROD2 DRILL TRIP P Pull out of the hole. Appeared to be swabbin . 12:45 14:00 1.25 7,873 6,447 PROD2 DRILL TRIP P Pump out of the hole. Pulling 90'/min. Pumping 169 gpm w/ 400 psi. PU wt 170k, SO 115k. Monitoring hole via Active Mud System. Record PU and SO values every 10 stands in cased hole. 14:00 14:15 0.25 6,447 6,447 PROD2 DRILL OWFF P Monitor well- static. 14:15 17:45 3.50 6,447 350 PROD2 DRILL TRIP P Pull out of the hole on elevators and the trip tank.. Record PU and SO wt's every 10 stands. Lay down the ghost reamer (1/16" under the original 8-3/8" measurement . 17:45 18:15 0.50 350 350 PROD2 DRILL OWFF P Monitor well at the BHA- static. Crew change. Clean rig floor. Note: Trip f/ 8159' to the BHA: Calculated displacement 65.7 bbls, Actual 71 bbls. Loss of 5.4 bbls. 18:15 19:00 0.75 350 58 PROD2 DRILL PULD P Lay down BHA #6. Monitor well on the tri tank. 19:00 20:15 1.25 58 58 PROD2 FISH PULD P Download Sperry Sun MWD. ~~ ~ _ Fage 3~ of Time Logs _ _ Date From To Dur S. De th E. De th Phase Code Subcode T COM _ _ 11/04/2007 20:15 _ 21:00 0.75 58 0 PROD2 DRILL PULD P Continue to lay down BHA #6. Monitor well on the tri tank. Grade the bit. 21:00 21:15 0.25 0 0 PROD2 FISH PULD P Clear floor of subs and handling tools. 21:15 22:15 1.00 0 0 COMPZ FISH PULD P Pickup to the floor: Baker tools f/ BHA #7 (Whipstock retrieval). Blind rams functioned while out of the hole. 22:15 22:30 0.25 0 0 COMPZ FISH SFTY P PJSM on PU/MU BHA #7. 22:30 00:00 1.50 0 99 COMPZ FISH PULD P PU/MU BHA #7, orient circulating port on the box of the retrieval hook w/ MWD highside (MWD will correct f! hole bein 72.64 de ri ht of MWD 11/05/2007 00:00 00:30 0.50 99 99 COMPZ FISH PULD P PU/MU BHA#7. Install pulsar. MU HOC. 00:30 01:15 0.75 99 99 COMPZ FISH PULD P Upload MWD. 01:15 01:45 0.50 99 219 COMPZ FISH PULD P PU/MU BHA #7. 01:45 02:00 0.25 219 313 COMPZ FISH TRIP P Trip in a stand of 5"drill pipe. Shallow pulse test MWD. 330 gpm w/ 3260 si. Detection 250 m. 02:00 03:15 1.25 313 313 COMPZ FISH CIRC T Trouble shoot excessive pressure while circulating. 85 gpm w/ 440 psi. 126 gpm w/ 760 psi, 168 gpm w/ 760 psi, 210 gpm w/ 1800 psi. 252 gpm w/ 2200 psi. 294 gpm w/ 2670 psi. 336 gpm w/ 3260 psi. 378 gpm w/ 3900 si. PU wt 90k, SO wt 90k. 03:15 04:00 0.75 313 34 COMPZ FISH CIRC T POOH to 34'. Pump through one jt of 5" HWDP and the retrieving hook. Pumped 200 gpm w/ 320 psi, 250 gpm w/ 460 psi, 300 gpm w/ 670 psi, 350 gpm w/ 940 psi, 400 gpm w/ 1170 psi. A ears to be ok-normal. 04:00 05:15 1.25 34 55 COMPZ FISH CIRC T Break connection at the float sub. Check float-OK. RU 4-1/2" headpin and 2" circ hose. Pump 200 gpm w1 670 si. A ears ok. 05:15 05:30 0.25 55 106 COMPZ FISH CIRC T Break and lay down bumper sub. Circ through HOC. Pumping 200 gpm w/ 1130 psi, 300 gpm w/ 1990 psi, 400 m w/ 2850 si. 05:30 06:00 0.50 106 106 COMPZ FISH RURD T Blow down top drive and cement hose. Han 2" hose in the derrick. 06:00 08:00 2.00 106 106 COMPZ FISH PULD T Lay down MWD. MU top drive on the float sub. perform pumping test. 100 gpm w/ 80 psi, 200 gpm w/ 290 psi, 300 gpm w! 660 psi, 400 gpm w/ 1280 .psi, 450 gpm w/ 1560 psi. PU/MU MWd. Perform pumping test: 100 gpm w/ 120 psi, 200 gpm w/ 1170 psi vibration in the MWD . 08:00 08:15 0.25 110 110 COMPZ FISH RURD T Blow down the top drive. 08:15 09:00 0.75 110 82 COMPZ FISH PULD T Lay down Sperry Sun MWD (RLL). ~- ~. ~~ ~ i Pa 33 ~s"" ~~ , t ~J j Time Logs _ _ __ pate From To Dur S. De th E. De th Phase Code Subcode T COM 11/06/2007 03:15 04:45 _ 1.50 6,575 5,150 COMPZ FISH TRIP P Pull out of the hole on elevators. Hole not takin correct fill. 04:45 05:00 0.25 5,150 5,150 COMPZ DRILL OWFF P Monitor well- slight flow to static. 05:00 05:30 0.50 5,150 4,775 COMPZ FISH TRIP P Pump 4 stands out of the hole. Pum in 126 m w/ 175 si. 05:30 06:00 0.50 4,775 4,400 COMPZ FISH TRIP P Pull out of the hole on elevators. After breathng subsided, the hole is taking ro er fill. 06:00 10:00 4.00 4,400 280 COMPZ FISH TRIP P Continue to pull out of the hole w/ whipstock retrieval BHA #7. Monitor the well on the tri tank. 10:00 14:00 4.00 280 0 COMPZ FISH PULD P Lay down the whipstock retrieval hook assembly. Check orientation of the whipstock w/the anchor. Note: Calculated fill 87.12 bbls, actual 90 bbls for the entire tri . 14:00 14:30 0.50 0 0 COMPZ FISH PULD P Lay down subs and handling tools. Clean and clear rig floor. Shut the blind rams. 14:30 15:00 0.50 0 0 COMPZ FISH PULD T PU/MU MWD from BHA #7. MU a joint of 5" drill pipe and the stack washing tool. Run in the hole to 93'. Flow test MWD. Pumping 300 gpm w/ 310psi, pumping 400 gpm w/ 490 psi, pumping 450 gpm w/ 750 psi. Pull out of the hole and stand back in the derrick. 15:00 15:15 0.25 0 0 COMPZ FISH SFTY T Pre job safety meeting on PU/MU BHA #8 (Reverse circ junk basket and ma nets 15:15 17:00 1.75 0 56 COMPZ FISH PULD T PU/MU BHA # 8. (8-1/2" OD Reverse circ'unk basket and two ma nets 17:00 23:00 6.00 56 8,360 COMPZ FISH TRIP T Run in the hole w/ BHA # 8 on the 5" drill string (6 stands slick, 30 stands w/super sliders, 35 stands slick, 17 stands of 5" HWDP, then a stand of 5" slick to work f/ TOW (8365') to the top of the MLZXP liner top f/ the "B" lateral (8415.74')) PU wt 210k, SO wt 125k, Rotating wt 165k, Rotating 30 rpm w/ 8k ft Ibs of for ue. 23:00 23:15 0.25 8,360 8,365 COMPZ FISH TRIP T Drop the 1" ball to shift the reverse circ basket. MU stand # 89 and pump ball down. Pumping 5 bpm w/ 590 psi, 6.5 bpm w/ 920 psi, 7 bpm w/ 950 psi. Ball on seat after um in 120 bbls. 23:15 00:00 0.75 8,365 8,415 COMPZ FISH CIRC T Increase pump rate to 8 bpm w/ 2660 psi. PU wt 210k, SO wt 125k, Rot wt 150k down and 180K up. Rotate 30 rpm w/ 8k ft Ibs of torque. Work 8360' to 8415' .Rotate f/ 8360' to 8409', then slack off to to to of liner 8415'. Page ~~ ~+~~9 ~~ Time Logs _- - - _---- -- Date From To COM J Dur S De th E. De th Phase Code Subcode T 11/07/2007 00:00 _ 00:45 0.75 8,415 8,360 COMPZ FISH CIRC _, T Pumping 8 bpm w/ 2660 psi. PU wt 210k, SO wt 125k, Rot wt 150k down and 180K up. Rotate 30 rpm w/ 8k ft Ibs of torque. Work 8360' to 8415' . Rotate f/ 8360' to 8409', then slack off to tag top of liner @8415'. Worked across the interval for a total of 5 times. 00:45 01:15 0.50 8,360 8,360 COMPZ FISH CIRC T Break off and set back stand #89, drop the 2-1/8" ball rod. Pump ball to seat w/initial rate of 202 gpm w/ 1090 psi. Increase pumps to 253 gpm w! 1560 psi. Once the pump out sub is o ened. Shut down. 01:15 02:00 0.75 8,360 8,360 COMPZ DRILL OWFF T Obtain SPR's. Monitor well. 02:00 06:00 4.00 8,360 5,381 COMPZ FISH TRIP T Pump out of the hole. Pumping 42 spm w 500 psi. Pulling 30-40'/min. Monitor displacement on the active pit system. Calculated fill to this point is 40.3 bbls, actual is 52 bbls. 06:00 07:00 1.00 5,381 5,070 COMPZ FISH TRIP T Pump out of the hole. Pumping 30 spm w 190 psi. Pulling 50-70'/min. Monitor displacement on the active pit s stem. 07:00 07:15 0.25 5,070 5,070 COMPZ FISH OTHR T Monitor well- static. Blow down the top drive. 07:15 10:00 2.75 5,070 53 COMPZ FISH TRIP T Pull out of the hole on elevators: Monitor hole on the trip tank. Record PU and SO wt's every 10 stands. Calculated fill for entire trip is 89.22 bbls, actual fill was 98.5 bbls. Lost 9.28 bbls to hole on the tri . 10:00 11:00 1.00 53 0 COMPZ FISH PULD T Lay down BHA #8. 2.5 gallons of formation debris in reverse junk basket. 1 coffee cup of metal shavin son strip ma nets. 11:00 11:30 0.50 0 0 COMPZ FISH PULD T Lay down subs and handling tools for BHA #8. Clear and clean floor. Shut the blind rams. 11:30 12:15 0.75 0 0 COMPZ CASINO RURD P Rig up to run the Baker Seal Bore Diverter. 12:15 12:30 0.25 0 0 COMPZ CASIN( SFTY P Pre job safety meeting on running the Seal Bore Diverter. 12:30 15:15 2.75 0 151 COMPZ CASIN RNCS P PU/MU/RIH with the Seal Bore Diverter assembly to 151'. Oriented the Seal bore PU Seal Bore Diverter and the MLZX production Anchor. Note: The Diverter Window is 50.1 deg to the right of the anchor lug. The MLZXP in the hole is 3 deg left of high side, therefore the diverter window will end u 47.1 de ri ht of hi h side. 15:15 15:30 0.25 151 139 COMPZ CASIN( RUNL P PU/MU MWD with a 30' single and 10' pup jt. Break off the single, Make up the 10' pup, then make a top drive connection. Pull out of the hole to 139' w ~. i §~age 36 of ~9 t Time Logs __ __ _ Date From To _ Dur S De~thi E. De th Phase Code Subcode T COM _ 11/08/2007 00:00 01:30 1.50 8,379 8,379 COMPZ CASINC OTHR T Pumping at varies rates to acquire detection w/ Sperry Sun MWD. Cycle pumps to try to mode switch. No Success. 325 gpm (77 spm) w/ ??? psi. 338 gpm w/ 1560 psi. No Pulse-No Detection. 01:30 06:00 4.50 8,379 4,061 COMPZ CASINC RUNL T Pump out of the hole w/the Seal Bore Diverter. Pumping 40 spm initial then to 20 s m 85 m w/ 200 si. 06:00 06:15 0.25 COMPZ CASINC OTHR T Monitor the well- static. 06:15 07:45 1.50 4,061 4,061 COMPZ CASINC RUNL T Pull out of the hole on elevators. Monitor well on the trip tank. Pulling s eed 20-30'/min 07:45 08:00 0.25 4,061 4,061 COMPZ CASINC OTHR T Monitor the well- static. Blow down the to drive. Install stri in rubbers. 08:00 11:30 3.50 4,061 151 COMPZ CASINC RUNL T Pull out of the hole on elevators. Monitor well on the trip tank. Lay down two string magnets. Pulling speed 40-60'/min. Note Calculated fill 84.26 bbls, actual 84.5 bbls. 11:30 12:15 0.75 151 141 COMPZ CASINC OTHR T POOH to 141', Download MWD. 12:15 12:45 0.50 141 141 COMPZ CASINC OTHR T Break the hang off collar, remove the pulsar, install a new pulsar, make up the han off collar. 12:45 13:15 0.50 141 141 COMPZ CASINC OTHR T Upload Sperry Sun MWD. 13:15 13:45 0.50 141 248 COMPZ CASIN RUNL T Trip in the hole. Shallow pulse test MWD. Pumping 250 gpm w/ 400 psi. Good detection. 13:45 18:00 4.25 248 7,271 COMPZ CASIN RUNL T Trip in the hole with the Baker Seal Bore diverter assembly. Record PU and SO wt's every 10 stands. Fill pipe every 25 stands. Fill pipe @ 2529'- pumping 250 gpm w/ 520 psi, PU wt 115k, SO wt 105k. Fill pipe @ 4911'- pumping 250 gpm w/ 630 psi, PU wt 140k, SO wt 100k. Fill pipe @ 7271'- pumping 250 gpm w/ 800 psi, PU wt 165k, So wt 110k. Good detection and pulses every time pipe was filled. RIH on the 5" drill string. Note: The Diverter Window is 50.1 deg to the right of the anchor lug. The MLZXP in the hole is 3 deg left of high side, therefore the diverter window will end up 47.1 deg right of high side. Note: The 5"drill string will consist of: 6 stands slick, 30 stands w/super sliders, 35 stands slick, then 16 stands of HWDP= 87 stands + 75.85' on another stand of HWDP (stand # 88 ~ P~~r ~~ rah ~~ w l~ Time Lo s 8_ _. Date From To Dur 5_Depth E De th Phase Code Subcode__ T_ COM J 11/08/2007 18:00 19:15 1.25 7,271 8,295 COMPZ CASINC RUNL T Continue to RIH w/the Seal bore diverter assembl on the 5"drill strip . 19:15 19:30 0.25 8,295 8,375 COMPZ DRILL TRIP T Make a top drive connection w/ stand # 86 in the hole, #87 out. Obtain PU wt 205k, SO wt 130k with pump rate of 250 gpm (59 spm) 940 psi. Obtain PU 210k, SO wt 130k with out the pumps. MWD showing 59 right of hi hside. RIH stand # 87. 19:30 20:00 0.50 8,375 8,241 COMPZ CASINC RUNL P Make a top drive connection on stand # 88, pump 250 gpm w/ 940 psi, MWD still showing 59 right. Slack off and observe taking weight @ 76' in (Collet profile @ 8428.53')(8453.73' -mule shoe of seals), Set down 40k to 87k(79' in) on the weight indicator. MWD showing 50 right of highside. PU to 285k (75k overpull) (72' in ). Slack off to 120k. Pump 425 gpm (101 spm) w/ 2240 psi to try and release FJD running tool. PU to 230k- not released. Slack off to 110k, then increase pumps to 450 gpm (106 spm) w/ 2520 psi. PU to 230k-still not released. Slack off to 100k, then pump 475 gpm w/ 2860 psi. PU with 200k. Continue to pull stand # 88 out and rack it back while um in 475 m w/ 2860 si.. 20:00 20:45 0.75 8,241 7,875 COMPZ CASIN RUNL P Pump four more stands of 5" HWDP out of the hole. Pumping 475 gpm w/ 2860 si. 20:45 21:00 0.25 7,875 7,875 COMPZ CASINC CIRC P Finish circulating a bottom's up. 440 bbls um ed 475 m w/ 2860 si. 21:00 22:30 1.50 7,875 0 COMPZ WELCT OTHR P PU/MU Baker 9-5/8" "EA Retrievamatic- storm packer". RIH on two singles of 5" dp and set w/ Center of packer element @ 76.41' (top of retrievamatic @ 63.97'). Tail of the Seal bore running tool @ 7957'. Lay down two singles and running tool. Test the annulus to 500 psi f/ 5 min - OK. 22:30 22:45 0.25 0 0 COMPZ WELCT OTHR P Pull Vetco Gray wear bushing. 22:45 23:30 0.75 0 0 COMPZ WELCT OTHR P Ri u to test BOPE. 14 day test. Fill stack with water. Witness of test waived by AOGCC inspector Jeff Jones. 23:30 00:00 0.50 0 0 COMPZ WELCT BOPE P Test annular w/ 4-1/2" test joint. Test against choke line HCR, kill line Demco valve, floor dart valve. Test to 250 psi low and 3000 psi high. Hold each test 5 min. Chart test. Ra~~ ~~ 0~4~ • Time Logs _ __ Date _ From To Dur S. Depth E. Depth Phase Code Subcode T COM 11/09/2007 00:00 05:30 5.50 0 0 COMPZ WELCT ROPE P Finish testing ROPE (14 day test). Witness of test waived by AOGCC inspector Jeff Jones. Test w! 4-1 /2" test joint: Top pipe rams (3-1/2" x 6" variables) and floor safety valve, both valves on the kill line and choke line, top drive manual and IBOP valve. Test upper pipes rams w/ 5" test joint: Test all valves on the choke manifold. Test accumulator: 3000 psi initial ,after closing 1500 ps. 200 psi build up in 49 seconds, full charge in 3 min 18 seconds. Test the blind rams. All tests to 250 psi high and 3000 psi low. Chart tests. Gas alarms tested. 05:30 06:30 1.00 0 0 COMPZ WELCT OTHR P Rig down testing equipment. Drain the stack, pull the test plug, set Vetco wear bushing. Blow down choke manifold and choke and kill lines. 06:30 06:45 0.25 0 0 COMPZ RIGMN' SFTY P PJSM on slipping and cutting drilling line. 06:45 08:15 1.50 0 0 COMPZ RIGMN' SVRG P Slip and cut 161' of 1-3/8"drilling line. Inspect brake linkage, brake bands for even and or excessive wear. 08:15 08:45 0.50 0 0 COMPZ RIGMN' SVRG P Service the top drive, blocks, and crown. 08:45 09:15 0.50 0 0 COMPZ RIGMN SVRG P Adjust the brakes on the drawworks. 09:15 09:30 0.25 7,810 COMPZ WELCT SFTY P Pre job safety meeting on 09:30 10:00 0.50 0 64 COMPZ WELC OTHR P MU retrieving tools and two joints of 5" drill pipe with a floor safety valve to retrieve the Baker "EA retrievamatic storm aaker. 10:00 10:45 0.75 64 7,810 COMPZ WELCT OTHR P Screw into the Baker "EA retrievamatic" storm packer. Check for pressure. Pull free. Pull to the rig floor, break and la down same. 10:45 11:00 0.25 7,810 7,810 COMPZ CASIN OTHR P Monitor the well- static. 11:00 12:30 1.50 7,810 7,810 COMPZ CASIN< CIRC P Circulate bottom's up. Pumping 350 gpm w/ 1590 psi.. Circulated 472 bbls. Pu wt 200k, SO wt 125k. 12:30 12:45 0.25 7,810 7,810 COMPZ CASIN( OTHR P Monitor well- static. 12:45 13:30 0.75 7,810 7,600 COMPZ CASIN RUNL P Pull out of the hole 3 stands of 5" HWDP. Hole a ears to be swabbin . 13:30 16:00 2.50 7,600 5,961 COMPZ CASIN RUNL P Pump out of the hole. Pumping 210 gpm w/ 670 psi. PU wt 150k, SO wt 100k. Monitor well on the activice s stem. 16:00 16:15 0.25 5,961 5,961 COMPZ CASIN( RUNL P Monitor well- static. 16:15 21:00 4.75 5,961 72 COMPZ CASIN RUNL P Pull out of the hole on elevators. Pulling speed 80'/min. Monitor well on the tri tank. ®~~_ • n U Time Logs _ Date From To Dur 5_Depth E. De th Phase Code Subcode T GOM ____ 11/10/2007 06:45 0 7:30 0.75 8,446 8,401 COMPZ CASIN( RUNL P Pick up to snap out. Snap out occured with weight indicator reading 275k (70k over) and 80' in on jt. Pick up to 40' in (8401'). Start pumping 5 bpm and rotating with 152k rotating weight, 30 rpm w/ 6-9k ft Ibs of torque. Rotate while slacking off @ 7'lmin. Turn off the pumps again @ 57' in (8418'). Continue rotating while slacking off w/ 155k rot weight. Tag up w/ 84.75' in (8445.75'). With indications of 10k set down @ 85.25' in (8446.26'). Shut down the rotary. Set down 30k to snap in (100k on the weight indicator) with 86' in (8447.01'). Continue to slack off 40k set down (90k on the indicator) with 87.5' in (8448.51'). Pick up to snap out: Snap out occured w/ 265k on the weight indicator (60k over). Pull out of the hole w/ PU wt 210-220k. Pull stand # 88 out of the hole (Shoe above the diverter). Run in the hole to exit the shoe again past the diverter ramp. RIH 40' in 8401.01' . SO wt 135k. 07:30 07:45 0.25 8,401 8,326 COMPZ CASIN( RUNL P Pull out of the hole on elevators to 8360', POOH, UD the single 5"drill i e, 07:45 08:00 0.25 8,326 8,326 COMPZ CASIN( OTHR P Monitor well- static. Install air slips and stri in rubbers. 08:00 10:45 2.75 8,326 6,381 COMPZ CASIN RUNL P Pump out of the hole w/ Baker "Dummy run" RAM Hanger. Pumping 220 gpm w/ 710 psi. Monitor well on active mud s stem. 10:45 11:00 0.25 6,381 6,381 COMPZ CASIN OTHR P Pull stripping rubbers and air slips. Monitor well- static.. Install stripping rubbers and air sli s. 11:00 11:30 0.50 6,381 5,905 COMPZ CASIN RUNL P Putl out of the hole on elevators, monitoring well on the trip tank. A ears to be swabbin .. 11:30 12:30 1.00 5,905 4,859 COMPZ CASIN( RUNL P Continue to pump out of the hole w/ Baker "Dummy run" RAM Hanger. Pumping 220 gpm w/ 710- 550 psi. Monitor well on active mud s stem. 12:30 12:45 0.25 4,859 4,859 COMPZ CASINC OTHR P Pull stripping rubbers and air slips. Monitor well- static.. Install stripping rubbers and air sli s. 12:45 13:15 0.50 4,859 4,383 COMPZ CASINC RUNL P Pull out of the hole on elevators, monitoring well on the trip tank. A ears to be swabbin .. 13:15 18:15 5.00 4,383 295 COMPZ CASIN RUNL P Continue to pump out of the hole w/ Baker "Dummy run" RAM Hanger Assembly. Pumping 220 gpm w/ 550- 210 psi. Monitor well on active mud. s stem. ~~ ~2 csf 49 • i I Time Logs _ _ _ 'Date From To Dur 5 De th E De th Phase Code Subcode T COM ' 11/10/2007 18:15 18:45 0.50 295 107 COMPZ CASINO RUNL P Pull the last two stands of slick 5" drill i eon elevators. 18:45 19:00 0.25 107 107 COMPZ CASIN( OTHR P Blow down top the top drive. 19:00 20:00 1.00 107 0 COMPZ CASIN( OTHR P Break and lay down the Baker 6.25" bumper sub, Baker 9-5/8" x 6-5/8" "RAM Hanger, 6-5/8" ported crossover w/ 4-1/2" pup jt, 4-1/2" hyd 521 x 4-1/2" BTC crossover, then the Shoejt (4-1/2" BTC blank jt w/ 4-1/2" x 5-1/2" crossover and 5-1/2" uide shoe . 20:00 20:30 0.50 0 0 COMPZ CASIN OTHR P Clean rig floor. 20:30 21:15 0.75 0 0 COMPZ CASINO RURD P Rig up to run the 4-1 /2" slotted/blank liner f/the "D" lateral using the Baker RAM hanger. Lay down Sperry Sun short tools (HOC) from the pipe shed via ri floor to beaver slide. 21:15 21:45 0.50 0 0 COMPZ CASIN( SFTY P Pre job safety mmeting on the liner run. 21:45 00:00 2.25 0 3,322 COMPZ CASIN( RNCS P Run the 4-1/2" slot/blank liner f/ the "D" lateral per the detail. Monitor returns on the trip tank. Jt # 77 in the hole @ midnight. Recod PU and SO wt's er the Ri En ineer. 11/11!2007 00:00 04:45 4.75 3,322 8,333 COMPZ CASIN( RNCS P Continue to run the 4-1/2" slot/blank liner f/the "D" lateral per the detail f/ jt # 77 to jt # 196. Monitor returns on the trip tank. Recod PU and SO wt's per the Ri En ineer. 04:45 05:15 0.50 8,333 8,333 COMPZ CASIN( OTHR P MU rig floor crossovers. Make a top drive connection to obtain PU wt 120k, SO wt 93k, rotating 30 rpm w/ 4500 ft Ibs of torque, Rot wt 102k. PU rotating wt 115k, SO rotating @ 10'/min w/ 102k. 05:15 05:30 0.25 8,333 8,628 COMPZ CASIN( RNCS P Continue to run the 4-1/2" slotlblank liner f/the "D" lateral per the detail f/ jt # 196 to jt # 203. Monitor returns on the trip tank. Recod PU and SO wt's er the Ri En ineer. 05:30 07:00 1.50 8,628 8,689 COMPZ CASIN RNCS P Make up the ported x-o, then PU The RAM hanger, MU inner string, MU the RAM Hanger, RIH, make up the Baker bum er sub and RIH, 07:00 07:30 0.50 8,689 8,774 COMPZ CASIN( RUNL P Run the first stand of 5"drill string. Make a top drive connection to obtain PU wt 125k, SO wt 95k, rotating 30 rpm w/ 5000 ft Ibs of torque, Rot wt 100k. PU rotating wt 115k, SO rotating @ 10'/min w/ 102k. Circulate 5 b m 210 m w/ 290 si. e ~ ~~€~~ ~S3 tzf 4~ • Time Logs_ _ ___ Date From To Dur 5 Depth E Depth Phase Code Subcode T COM 11/11/2007 07:30 11:45 4.25 8,774 14,581 COMPZ CASINC RUNL P Continue to RIH w/ the 4-1/2" 11.6 ppf, L-80 BTC & Hyd 521 slot/blank liner f! the "D" lateral, on the 5"drill string. Record PU and SO wt's every 5 stands, per the Rig Engineer. Fill pipe @ 11059' pumping 5 bpm w/ 490 psi. Fill pipe @ 14390' pumping 210 gpm w/ 650 psi. Note: The 5"drill string will consist of: 6 stands slick, 30 stands w/super sliders, 35 stands slick, then 16 stands of HWDP= 87 stands + 31.83' single drill pipe, then another stand of HWDP stand # 88 . 11:45 12:00 0.25 14,581 14,676 COMPZ CASIN RUNL P Rotate in the hole w/ the liner due to insufficient SO wt. Rotate 30 rpm w/ 8-10k ft fbs of torque. PU wt 182k, SO wt 72k. 12:00 15:15 3.25 14,676 16,942 COMPZ CASINC RUNL P Continue to rotate in the hole w/ the liner due to insufficient SO wt. Record PU and SO wt's every 5 stands, per the Rig Engineer. Depth 16942': No pumps/no rotation PU wt 240k, SO wt 105k. RIH w/stand 87 and PU &RIH w/single, MU stand 88. Rotate 30 rpm w/ 9-11 k ft Ibs of torque, PU wt 200k, SO wt 148k. Set top drive limit to 13k ft-Ibs. Calculated displacement 79.17 bbl, actual 72.5 bbls. 15:15 15:45 0.50 16,942 17,027 COMPZ CASIN RUNL P Pump 210 gpm w/ 830 psi and start rotating stand 88 in. Pumps off 54' in on stand 88 (shoe at 16,996.8', ported sub at 8364.6'). By 80' in rotation decreased to 10rpm at 13k ft-Ibs w/ 130k down. Continue to 86' in by which point top drive stalled. Set down to 110k (20k setdown). Turn top drive off, slowly release torque. PU, see bumper sub open at 210k, snap-out at 260k (50k snap-out) w/ minimal PU after snap-out. Set down w/ no rotation to 95k. PU, bumper sub open at 210k and continue to PU at 220k w/ no overpull (RAM was not snapped in). Set down to 80k. PU, bumper sub open at 210k and snap out at 250k (40k snap-out). Set down to 80k to same mark as previous set down. PU, bumper sub open at 210k and continue to 220k (10k overpull). Set down to 80k. n~~o 4~ ~f ~~ • • Time Logs ___ _ _ _ _ _ Date From To Dur S De th E. De th Phase Code Subcode T COM 11/11/2007 15:45 17:15 1.50 8,514 8,430 COMPZ CASIN CIRC P Break off top drive, drop ball, and make up top drive. Pump 29/32" ball to seat, 84 gpm w/ 300 psi. Ball on seat after 160bb1 pumped. Pressure up to 3500psi, bleed off. PU, see bumper sub at 210k and continue to 230k (not released). Set down to 80k. Pressure up to 3500psi, bleed off. PU, see bumper sub at 210k and continue to 235k and hold for several seconds, weight dropped off to 210k (released). Pull entire stand 88 out (bottom of inner string at 8369.7'), RIH to 20' in on stand 88 (bottom of inner string at 8389.7', expected sealbore diverter tag at 8381.9'). Pull entire stand 88 back out plus another 8' of the single, RIH and set down 9k 10' in on stand 88 (bottom of inner string at 8379.7). PU and stand back stand 88. 17:15 17:30 0.25 8,430 8,338 COMPZ CASIN OTHR P UD single. MU top drive and pressure to 4400 si to shear ball seat. 17:30 19:30 2.00 8,338 8,338 COMPZ CASINC CIRC P Circulate 280 gpm w/ 740 psi. Pump a total of 747 bbls. 19:30 21:30 2.00 8,338 7,600 COMPZ CASINC RUNL P Pull out of the hole, Laying down 5" HWDP. Monitor well on the tri tank. 21:30 21:45 0.25 7,600 7,600 COMPZ CASIN( OTHR P Observe well- static. 21:45 23:30 1.75 7,600 6,868 COMPZ CASINC RUNL P Continue to pull out of the hole, Laying down 5" HWDP. Monitor well on the tri tank. 23:30 23:45 0.25 6,868 6,868 COMPZ CASINC CIRC P Pump a 20 bbl dry job (10 ppg/194 vis- using safe Carb 250-1400 pounds--28 sx), chase w/ 10 bbls. Drop Haggard ID pipe wiper (1-3/4" OD float tube). Blow down the to drive. 23:45 00:00 0.25 6,868 6,800 COMPZ CASIN RUNL P Continue to pull out of the hole, Laying down 5" HWDP. Monitor well on the tri tank. 11/12/2007 00:00 06:00 6.00 6,800 1,950 COMPZ CASINC RUNL P Continue to pull out of the hole, Laying down 5" HWDP, 5" w/super sliders, and 5" slick dril- pipe. Monitor well on the tri tank. 06:00 08:00 2.00 1,950 100 COMPZ CASINC RUNL P Continue to pull out of the hole, Laying down 5" HWDP, 5" w/super sliders, and 5" slick drill pipe. Monitor well on the tri tank. 08:00 08:15 0.25 100 100 COMPZ CASINC OTHR P Remove super sliders and hardware from the floor. Clear floor. 08:15 08:30 0.25 100 100 COMPZ CASIN SFTY P Pre job safety meeting for laying down Baker running tools and inner string f/ the RAM han er f/the "D" lateral. ~~. ~~~~ ~ ~z, ~~ i • Time Logs _ _ _ _ _ Date From To Dur S. Depth E Depth Phase Code Subcode T COM _ 11/12/2007 08:30 09:45 1.25 100 0 COMPZ CASIN( OTHR P Lay down Baker running tool. Monitor well on the trip tank. Retrieve the Haggard ID wiper. Calculated fill 85.41 bbis, actual 95 bbls- f/ a 10 bbl loss while POOH. 09:45 10:00 0.25 0 0 COMPZ DRILL OTHR P Pull the mouse hole. Remove the drain line and install a bull plug. Set mouse hole in the rotary table. Monitor well on the tri tank. 10:00 10:15 0.25 0 0 COMPZ DRILL SFTY P Pre job safety meeting on laying down 5"drill pipe from the derrick using the mouse hole. 10:15 12:00 1.75 0 0 COMPZ DRILL PULD P Lay down 5"drill pipe from the derrick. 12:00 13:00 1.00 0 0 COMPZ DRILL OTHR P Clear floor of Baker tools, GBR tools and drillin tools host reamer 13:00 14:15 1.25 0 0 COMPZ DRILL PULD P Continue to lay down 5"drill pipe from the derrick. Monitor well on the trip tank. 14:15 15:15 1.00 0 0 COMPZ RIGMN SVRG P Service rig, top drive and drawworks. 15:15 18:00 2.75 0 0 COMPZ DRILL PULD P Continue to fay down 5"drill pipe from the derrick. Monitor well on the trip tank. (37 stands Payed down-- 36 stands left to la down. 18:00 20:45 2.75 0 0 COMPZ DRILL PULD P Continue to lay down 5"drill pipe from the derrick. Monitor well on the trip tank.No gain or loss while laying down dp f/derrick. Note: 22 stands of 5"drill pi-pe left in the derrick. 20:45 21:15 0.50 0 0 COMPZ DRILL OTHR P Remove mouse hole f/ the rotary table. Pull Vetco/Gra 's wear bushin . 21:15 21:45 0.50 0 0 COMPZ DRILL OTHR P Clear and clean rig floor. 21:45 23:00 1.25 0 0 COMPZ RPCO RURD P Change elevators, prepare casing tongs. PU tools for HOWCO slickline, brin Centralift tools to the floor. 23:00 23:30 0.50 0 84 COMPZ RPCO RCST P PU TTC crossover w/ screen intake,. 4-1 /2" 12.6 ppf IBT-m L-80 pup joint, MU first two joints of 4-112" 12.6 ppf, L-80 IBT-m tubin . 23:30 23:45 0.25 84 84 COMPZ RPCOh SFTY P Pre job safety meeting w/ HOWCO slickline. 23:45 00:00 0.25 84 84 COMPZ RPC06 PULD P Install TTC x-o/pump eye, gas separator, Pump 63 stage FC 6000 (High volume Middle Tandem), Pump 53 stage FC6000 (High Volume Middle Tandem and set inside the strin . i a _ ~ ~ _~ ~ ~'a~g~ ~ cif ~ • Time Logs _ _ _Date From To _ _Dur__._ S_Depth E. Depth Phase Code Subcode T COM 11/13/2007 00:00 00:45 0.75 84 84 COMPZ RPCOh PULD P Finish making up the TTC x-o/pump eye, gas separator, Pump 63 stage FC 6000 (High volume Middle Tandem), Pump 53 stage FC6000 (High Volume Middle Tandem), HV Bolt on discharge Head 2-3/8", X-O 2-3/8" to 2-7/8", 2-7/8" pinto pin spacer pipe, Bow spring 450 TTC, nip tbg 2.88- 8 rd EUE x 12" J55, Hanger Rece tical, Polishbore/ Fishin neck. 00:45 01:00 0.25 84 84 COMPZ RPCO RURD P Rig up HOWCO slickline. Using .125" wire, 8' of 2-5/8" stem, and LSS. Usin 4-1/2 GS 01:00 01:45 0.75 84 84 COMPZ RPCO SLKL P Howco slickline Install TTC x-o/pump eye, gas separator, Pump 63 stage FC 6000 (High volume Middle Tandem), Pump 53 stage FC6000 (High Volume Middle Tandem), HV Bolt on discharge Head 2-3/8", X-O 2-3/8" to 2-7/8", 2-7/8" pinto pin spacer pipe, Bow spring 450 TTC, nip tbg 2.88- 8 rd EUE x 12" J55, Hanger Receptical, Polishbore/ Fishing neck.Overall length 48.03'. HOWCO slickline install D&D stinger, 2-7/8" dart type check valve, 2-7/8" EUE 8rd spacer pipe, Kobe Knock out, D&D packoff assembly. Overall length 10.29'. Howco slickline RIH w/ D&D test tool. then POOH. 01:45 02:45 1.00 84 84 COMPZ RPCO DHEQ P Rig up the 4-1/2"IBT X-O to 4-112" IF with a headpin, fill w/water, test to 1000 psi f/ 15 min. Good test- lost 20 psi first 5 min, then held steady f/ 10 more minutes.. Rig down headpin and test hose. 02:45 03:00 0.25 84 84 COMPZ RPCO SLKL P Howco slickline retrieve the D&D test tool. RIH and set the Slip stoplfubing sto . Ri down HOWCO slick line. 03:00 03:15 0.25 84 0 COMPZ RPCO RCST P MU the 4-1/2" 12.6 ppf L-80 IB-m pup jt, Unique pressure discharge sub, and 4-1 /2" 12.6 ppf L-80 IBT-m pup joint. Stand back the stand of completion arts: 101.05' 03:15 03:30 0.25 0 0 COMPZ RPCO SFTY P Pre job safety meeting on running the 4-1/2" ESP com letion. 03:30 05:00 1.50 0 37 COMPZ RPCOb PULD P PU motor, attatch the mtr centralizer, service motor pumping CL-5 oil to fill. Attatch the 1/4 stainless cable to the A-Well pump guage. Install six 1-1/4" stainless steel bands on the motor, securin the 1/4" ca illa tube. ~~ ~ag~ 4~ of A9 l J Time Logs __ _ __ _ _ _____ Date From To Dur S. De th E. De th Phase Code Subcode T COM 11/13/2007 _ 05:00 06:00 1.00 37 49 COMPZ RPCOti PULD P PU Upper and Lower Tandem seal section. Install coupling. Bolt seal section to motor section. Service seal section. Used (1) 5.875" Protecttolizer gauard on motor and (2) on pump, lus 2 5.625" flat uards. 06:00 10:15 4.25 49 72 COMPZ RPCO RURD P Rig up the Centralift sheave f/ the 1.40" diameter ESP cable. Perform continuity test (good). Install 5.13" screen intake and connect stainless cap tube to discharge port, banding while RIH. (6 Stainless steel bands used on motor assembly). String ESP over sheave and continuit test. 10:15 12:00 1.75 72 974 COMPZ CASIN( RNCS P Run 2 joints of 4-1/2", 12.6 Ib/ft, L-80 IBT-M SCC tubing, PU/MU Pressure discharge sub, continue running Tbg and checking continuity every 30 joints. Record SO weights every 10 joints, starting at #50 and monitor dis lacement on the tri tank. 12:00 18:00 6.00 974 4,745 COMPZ CASIN RNCS P Continue runing 4-1/2"tbg completion checkin continui eve 30'oints. 18:00 22:00 4.00 4,745 7,294 COMPZ CASIN( RNCS P Contunue running 4-1 /2" tubing completion to 7,294', checking continuity every 30 joints and monitoring displacement on TT. (hole took proper fill while running Tbg). NOTE: 208 Canon clamps, an 20 flat SS bands used on ESP cable. 22:00 22:30 0.50 7,294 7,294 COMPZ CASIN( RNCS P Remove air slips, PU tubing hanger and orient roduction ort. 22:30 22:45 0.25 7,294 7,294 COMPZ CASIN RURD P RD power tongs and casing equipment, monitor well -static. Turn on Automatic hole fill to monitor trip tank during cable splice. Continuity test ood. 22:45 00:00 1.25 7,294 7,294 COMPZ CASINC OTHR P Install Penetrator, measure, cut and s lice ESP cable to enetrator. 11/14/2007 00:00 02:00 2.00 7,294 7,294 COMPZ RPCOM1 OTHR P Continue to splice ESP cable 02:00 02:30 0.50 7,294 7,294 COMPZ RPCO DHEQ P Connect ESP cable and Penetrator. Test continuit - ood. 02:30 03:15 0.75 7,294 0 COMPZ RPCOI~ HOSO P Drain stack, land tbg hanger, RILDS and install BPV. 03:15 03:45 0.50 0 0 COMPZ RPCO PULD P LD landing joint. Test lower hanger seals and void space to 250 psi -Low and 5,000 si - Hi h. 03:45 05:30 1.75 0 0 COMPZ RPCOh NUND P Disconnect Kill and Choke lines, ND stack. Clean and clear rig floor and clean dri an. 05:30 06:15 0.75 0 0 COMPZ RPCOh DHEQ P Perform final continuity test per Centrilift technician -good. Change out Saver sub and Upper/lower IBOPs valves. • 18-Dec-07 AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1J-178 Dear Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 41.02' MD Window /Kickoff Survey: 0.00' MD (if applicable) Projected Survey: 17,083.00' 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 ~ (Q ~arr~ ~..~ ~ Signed Please call me at 273-3534 if you have any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) ~~~-~ ~~ • • a a ~ o o SARAH PAUN GOVER NOR 7~T ~1 ~-~t7~~7~T ~~ ~ ~ 333 W. 7th AVENUE, SUITE 100 CO„SrjRQ~ii01` ~;Q~II,~SIO~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX {907) 276-7542 Randy Thomas Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Kuparuk River Field, West Sak Oil Pool, 1J-178 ConocoPhillips Alaska, Inc. Permit No: 20?-121 Surface Location: 1647' FSL, 2452' FEL, SEC. 35, TI 1N, R10E, UM Bottomhole Location: 1855' FNL, 1507' FEL, SEC. 15, T10N, R10E, UM Dear Mr. Thomas: Enclosed 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). Si cerely, ~~ John K. Norman Chairman DATED this2~day of September, 2007 cc: Department of Fish 8t; Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Conoco~illips Alaska Post Office Box 100360 Anchorage, Alaska 99510-0360 Randy Thomas Phone (907)265-6830 Email: Randy.L.Thomas@conocophillips.com September 7, 2007 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 GG1 V G® E p o 7 2007 ,laskn qil & Gas Cons. Commission Anchorage Re: Applications for Permit to Drill, West Sak Producer, 1J-178 and iJ-178 L1 Dear Commissioners: ConocoPhillips Alaska, Inc. hereby applies for Permits to Drill for an onshore producer well, a horizontal '° well in the West Sak "B"and ~~D" sands. The main bore of the well will be designated 1J-178, and the lateral bore of the well will be designated iJ-i78L1. 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-178 is September 21, 2007. If you have any questions or require any further information, please contact Pat Reilly at 265-6048. Sincerely, Randy Thomas Greater Kuparuk Area Drilling Team Leader STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL ~'~``~I±~-~-1 20 AAC 25.005 ~~~I d 7 2~(l7 ~iuvl4a) ~~~ ~~. ~,as Cnns• Commission t~ncht~r~t~Q 1 a. Type of Work: 1 b. Current Well Class: Exploratory Development Oil ^/ r 1c. Specify if well is proposed for: Drill Q ~ Re-drill ^ Stratigraphic Test ^ Service ^ Development Gas ^ Coalbed Methane ^ Gas Hydrates ^ Re-entry ^ Multiple Zone^ Single Zone ^ Shale Gas ^ 2. Operator Name: 5. Bond: ~ Blanket Single Well 11. Well Name and Number: ConocoPhillips Alaska, Inc. Bond No. 59-52-180 1J-17&' ~ 3. Address: 6. Proposed Depth: 12. Field/Pool(s): P.O. Box 100360 Anchorage, AK 99510-0360 MD: 17073' '` TVD: 3282' ~ Kuparuk River Field 4a. Location of Well (Governmental Section): 7. Property Designation: Surface: 1647' FSL, 2452' FEL, Sec. 35, T11 N, R10E, UM '~ ADL 25661, 25662, 25663385172 West Sak Oil Pool Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 801' FSL, 1627' FEL, Sec. 3, T10N, R10E, UM ALK 471, 217, 472, 2181 9/21/2007 Total Depth: 9. Acres in Property: 14. Distance to ~/~~t 1855' FNL, 1507' FEL, Sec. 15, T10N, R10E, UM 2560 Nearest Property: -• r(- 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Surface: x- 558760 y- 5945459 ~ Zone- 4 (Height above GL): 121' AMSL j feet Well within Pool: 1J-158L1 , 288' @ 122E 16. Deviated wells: Kickoff depth: 500' ft. 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Maximum Hole Angle: 91 ° deg Downhole: 1421' psig ~ Surface: 1057 psig ~ 18. Casing Program S e ifi tions Setting Depth Quantity of Cement Size p c ca Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 42" 20" x 34" 78.6# H-40 Welded 80' 40' 40' 120' ~ 120' ~ 347 sx AS 1 16" 13-3/8" 68# L-80 BTC 3607' 40' 40' 3647' , 2200' - 720 sx AS Lite, 220 sx DeepCRETE 12.25" 9-5/8" 40# L-80 BTCM 9095' 40' 40' 9135' . 3288' ~ 560 sx DeepCRETE 8.5" 5.5" 15.5# L-80 BTCM 8443' 8629' 3227' 17072' - 3281' ~ slotted liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured) Effective Depth MD (ft): Effective Depth TVD (ft): Junk (measured) Casing Length Size Cement Volume MD TVD Conductor/Structural Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ^ BOP Sketch^ Drilling Program^/ Time v. Depth Plot Shallow Hazard Analysis Property Plat ^ Diverter Sketch ^ Seabed Report ^ Drilling Fluid Program Q 20 AAC 25.050 requirements ^/ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Pat Reilly @ 265-6048 Printed Name _ ._ Randy Thomas Title Drilling Team Leader Signature , "~ ~- Phone ~- Date t ~ S 6~ 3a ;...,,71`7 cx. ~, 1, ~ _. e 7 ._ , _ r-_ - , : h nAl D k Commission Use Only Permit to Drill API Number: Permit Approval See cover letter Number: ~Q~ ~ ~L- ~ 2 / D 50- oZ~^ 2 J~tP~ ~~ Date: • ~ ~ for other requirements Conditions Of approval : If box is checked, well may not be used to explore for, test, or produce Coalbed me ane, gas hydrates, or gas contained in shales: N ~ ' ^ ' o ( d: Yes ^ No Mud log req Samples req d: Yes ~ ' ~ ' No ^ d: Yes [ ~~~t`~~-~c~,-- -- H2S measures: Yes ^ No [t~ Directional svy req Other: 'j li~,'L(~, D~f APPROVED BY THE COMMISSION DATE: !! // •/ V~Y~~~~~ ,COMMISSIONER 7 J Form 10-401 Revised 12/2005 ~ ~ ~ ^°t ~ ~~~ ~~ ~ Su it in Duplicate :.. _ ~:. ~~1~i7 ~~/l °7 Ap~on for Permit to Drill, Well 1 J-178 Revision No.0 Saved: 7-Sep-07 Permit It -West Sak Well #1J-178 """ r.^ i~t Application for Permit to Drill Document r. ~~~~~ fA p x i rtti i a~ y~~ll value Table of Contents 1. Well Name ...................................................................................................... ........ 2 Re uirements o 20 AAC 25.005 ..............................::.............:..... 2 q .f (fl .......................................................... 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 FIuid Program ............................................................................ ............ 4 .... Requirements of 20 AAC 25.005(c)(8) ..........................................................................:.............................. 4 Surface Hole Mud Program (extended bentonite) ......................................................................................... 4 Intermediate Hole Mud Program (LSND) .................................................................................................... 5 Lateral Mud Program (MI VersaPro Mineral Oil Base) B, D sand laterals .................................................... 5 9. Abnormally Pressured Formation Information ........................................................... 5 Requirements of 20 AAC 25.005 (c)(9) .....................:......................................................................e.:...:..:.. 5. 10. Seismic Analysis ......................................................................................................... 5 Requirements of 20 AAC 25.005 (c)(10) ...................................................................................................:.. 5 11. Seabed Condition Analysis .......................................................................................... 5 Re uirements o 20 AAC 25.005 c 11 ..........................:............ 5 q .f O( ) ............................................................... 1J-178 PERMIT IT Page 1 of 7 Printed: 7-Sep-07 - 1 ~~ ~lication for Permit to Drill, Well 1J-178 Revision No.O Saved: 7-Sep-07 12. Evidence of Bonding ................................................................................................... 6 Re uirements o 20 AAC 25.005 c 12 .................. 6 q f ()( ) .................................................................................... 13. Proposed Drilling Program ......................................................................................... 6 Re uirements o 20 AAC 25.005 c 13 .......;.......::......:,... 6 q .f O( ) .......................................................................... 14. Discussion of Mud and Cuttings Disposal and Annular Disposal .................................. 7 Requirements of 20 AAC 25.005 (c)(14) ....................................................................:......;..........:..........:.... 7 15. Attachments ............................... ............................................................................ 7 Attachment 2 Directional Plan .......................................................................................;...............:.......... 7 Attachment 3 Drilling Hazards Summary .................................................................................,..:.............. 7 Attachment 4 CemCADE Summary .......................:..........................................................................:.......... 7 Attachment 5 Well Schematic .........................................................................................;.:.....;:...;...........:. 7 1. Well Name Requirements of 20 AAC 25.005 (f) -Each tii~ell must be identtfred ~y a unigzre name designated by the operator and ce unique A1'1 number assicned iw the commission zander 20 AAC 2S.©40{Er). ~%'or c~ well wzth m~rlti~le well ]ranches, each branch rraustszmz1ar11~ he identified by a arnt~~ue name and,~~'1~narrnher~ b~~ adding a suJ~zr to the name designated for the well h-y the aherator ceracf to the a.zrmher czssigraed to ihf~ -well 13y tJ~e commission. The well for which this Application is submitted will be designated as 1 J-178. 2. Location Summary Requirements of 20 AAC 25.005(c)(2) .4n appiiz~ation for a Perrnil to Drill must be accornpanred by each of the, follo~cing items, exet~rt for art item alreau'v an;ile will. tlae corninission and ident€€ffed in tlae apllticatiora: (2) a plat identifying the properti~ and the propertt~',r owr2er-s and sbo~ro~ing (A)che coor~d=Hates of the Proposed location of the ;veil at thz surface at the io~r of each objective forrnatu~n, and at total depth, refcreneed to gauernzner~tal section lines. td) the coordinates of the prol~tosed location of Ehe well at the sarrface, r~ftreneed to the spate plane coordinate s}~stern,for the staCe as maintained hy~ the Natiorat~l Geodetic Suruet% in the .National C3ceartic and Atmosplzertc Adminirtrrtlion, G) the proposed depth of tlae well at the top of each objecif~=e formation arzd at total depth; Location at Surface 1,647' FSL, 2,452' FEL, Section 35, T11N, R10E ASP~Zone 4 NAD 27 Coordinates RKB Elevation 121' A1V1SL North~ings: 5,945,459 Eastings: 558,760 Pad Elevation 81' AMSL Location at Top of Productive Interval (West Sak "B" Sand) 801' FSL, 1,627' FEL, Section 3, T10N, R10E ASP Z 4 NAD 27 C di Measured Depth, RKB: 9,135 one oor nates Northings: 5 939 301 Eastin s: 564 360 Total Vertical Depth, RKB: 3,289 , g , , Total Vertical Depth, SS: 3,168 Location at Total Depth 1,855' FNL, 1,507' FEL, Section 15, T10N, R10E ASP Z 4 NAD 27 C di Measured Depth, RKB: 17,073 one oor nates Northings: 5 931 367 Eastin s: 554 550 Total Vertical Depth, RKB: 3,282 , , g , Total Vertical Depth, SS: 3,161 and {I)) other znfcrrrnation required by '0,9AC 25.o51}fhl: '?.21GINAL 1J-178 PERMIT IT Page 2 of 7 Printed: 7-Sep-07 • Ap~n for Permit to Dtill, Well 1J-178 Revision No.O Saved: 7-Sep-07 Requirements of 20 AAC 25.050(b) If a well is to be intentionally deviated the czpplicaiian jor a Permit to IJe•ill ("Form 1 fJ-9Q11 rrtttst (l) include a plat, drenvn to a suitahie scale, showing the path of the proposed wellbore, iru;ltiding all adjacent welfbores within 2Q0 feet of any prat^tion-<?fthepa•aFzos~ditiell; Please see Attachment L• Directional Plan and (2) for all a+e11s within 200 feet of the proposed wellbore (A) list the names of the operators of those ~roells, to the extent that those names are knorovn nr discoverable in publa'e records, oral s/ta~w that eaa:h Warned aperator° lacac been fitrrislaed a copy gfthe application by e~ertifred rrtail; or (23) 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 fzrr a PErmit to Dr"ill rr.Ttst be accotrzprznied by each of thefollowing iterrts, except for an item already on file with tlae commission aru2 identified in the application:. (3) a diagram cznd descr^iptiaaa of the blowozat pr^evr-ration eclzarpntent (BC1P£t') as raruired hti 2t) ~4C 2 4.Q35, 20 AAG 25.(l3(~, ar ~0 AAC 2.1.03', as applicable; An API 13-5/8" x 5,000 psi BOP stack (RSRRA) will be utilized to drill and complete well 1J-178. 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 9-5/8" rams in the lowermost cavity. 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 rains 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 9-5/8" OD. This well is planned with a119 5/8" 40# intermediate casing. Drag modeling indicates that the 9 5/8" casing will be adequate. However, if actual drag data indicates the need for 10 3/4" 73.2# weight pipe on top of the 9 5/8", we will install 10 3/4" rams prior to running the intermediate casing. 4. Drilling.Hazards Information Requirements of 20 AAC 25.005 (c)(4) An application for• a Permit to -rill rntast he accompanied by each of the,f rllcnti°ing iterns, except far ara item udready an file with the commission ar.d ident~ed in the application: (41 information ar^a drilliz~ag haatzrds, includir^ag (A) tha maximum c~~rovr.hale pressure that nary be eruourztereca; criteria used to determine it and maximum potential surface pressure based on a methane ~"adienl,' f The expected reservoir pressure in the West Sak sands in the 1J-178 area is 0.43 psi/ft, or 83 ppg EMW (equivalent mud weight). The maximum potential surface pressure (MPSP) is 1,155 psi. 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 3,304'. The MPSP is: MPSP- _ (3,304 ft)(0.43 - 0.11 psi/ft) =1,057 psi {231 data on potential ras zones; The well bore is not expected to penetrate any gas zones. and (~} data caneerraing potentiaal causes of hole problems such as abnormally gea-pressured strata, lost cfi-culation zones, and zones #Isat have a pt-opensity fnr^ di ferential sticking: Please see Attachment 2: 1J-178 Drilling Hazards Summary. 1J-178 PERMIT lT Page 3 of 7 ('~ ~ ~ ~ ~ Printed: 7-Sep-07 • ~lication for Permit to Drill, Well 1J-178 Revisiori No.O Saved: 7-Sep-07 5. Procedure for Conducting Formation Integrity Tests Requirements of 20 AAC 25.005 (c)(S) An application^a,for a permit tca Drill must be accompanied by each of fhe foliowir^ag items, except for an itL'rPd already art fzie frith the commission atul identified ire the application: (5) a description. of the procredure for conducting formation integrity tests, as required under 20 AAC 25, tJ3q%~; 1J-178 will be completed with 9-5/8" casing landed at the top of the West Sak "B" 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 AAC25.005(c)(6) An applii ution for et 1'errrait to Brill must he aecotrapanted b}-~ each rtf the foilcrwdng hems, kept for art item alrerrc'ti can 'fife with the eurnmission and identified in the application: (6) a complete prapose~l casing and cementing prograrra as required fry- 20 AAC 25.030, arut a descriptigrz of airy slotted liner, pre p~~orated liner, orscr^~nTo77e ivtstatled,' Casing and Cementing Program ~~_ ~,.~ See also Attachment 3. Cement Summary Hole Top Btm Csg/Tbg Size Weight Length MD/TVD MD/TVD OD (in) (in) (7b/ft) Grade Connection t) (ft) (ft) Ce 20" 40" 62.5 H-40 Welded 80 40' / 40' 120' / 120' Cemented f Cemex 13-3/8" 16" 68 L-80 BTC 3,607 40' / 4D' 3,647' / 2,200' 7zo sX 220 ~r .Cement 7 9-5/8" 12-1/4" 40 L-80 BTCM 9,095 40' / 40' 9,135' / 3,288' M~ i2,~o 560 5-1/2 8-1/2" B Sand Lateral 15.5 L-80 BTCM 8 443 8 629' / 3 227' 072' / 3 1'I 281' Slo slotted (1J-178) , , , , , 4-1/2 slotted 8-1/2" D Sand Lateral (1J-178 Ll) 11.6 L-80 BTCM 8,539 8529' / 3,211' 17,06&' / 3,212' Stoned- no cement 7. Diverter System Information Requirements of 20 AAC 25.005(c)(7) .4n appliccitic~n,for a Permit to I?riil must be accompanied [~y each Uf tfae folz'owing itei~as, exceptfor- un item al`readv ora file with the commission and ider~atfed in the u?.plieation. (~j a dPugram and description of the di Herter system as required l?t% 2<J ~24C 25. (335, unCers th s rE yuiremerat is u~airt~d by the co~a~anisston unc~,'r~ 2q AAC 25.Ct:'S(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 1J- 178. 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 far a Permit to frill must be acrornpunied by each of the follola%ing t<;ms, except,frr an item aireudv on file with the corranaissian and idert&fic:d in the application: {~) a drilling fluid program, irachtiding a diarrum and description ~f the drilling fluid system, as required by 20.A.AC ?5:033.? Drilling will be done with muds having the following properties over the listed intervals: Surface Hole Mud Program (extended bentonite) Spud to Base of Permafrost Base of Permafrost to Surface Casing Point Initial Value Final Value Initial Value Final Value Density (ppg) 8.S 9.2 9.2 9.6 Funnel Viscosity 150 250 200 300 (seconds) `?RtGINAL 1J-178 PERMIT 1T Page 4 of7 Printed: 7-Sep-07 A Ap~on for Permit to Drill, Well 1J-178 Revision No.O Saved: 7-Sep-07 Yield Point 50-70 50-70 30-50 30-50 (eP> Plastic Viscostiy 20-45 20-45 15-20 15-20 ~lbiloo sfl px 8.5-9.0 8.5-9.0 8.5-9.0 8.5-9.0 API Filtrate (cc / 30 min)) NC-8.0 NC-8.0 5.0-7.0 ! 5.0-7.0 *9.6 ppg if hydrates are encountered - Intermediate Hole Mud Program (LSND) 13-3/8"Casing Shoe to Intermediate Casin Point Initial Value Densi (ppg) 9.0-9.4 Funnel Viscosity (seconds) 45-60 Plastic Viscostiy (lb/100 s~ 12 Y8 Yield Point (cP) 26-3 5 API Filtrate (cc / 30 min)) 4-6 Chlorides (mg/I) <500 pH 9.0-9.5 MBT <20.0 Value Densi (ppg) 8.4 - 8.6 " Plastic Viscostiy 15-25 (lb/100 s~ Yield Point (cP) 18 28 HTHP Fluid loss (ml/30 min @ <4.0 200psi & 1 SO° Oil /Water Ratio 80:20 Electrical Stability >600 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 (c)(9) An application faJr~ a Prnsrit to iJr~~ill mast he accorrapanied by each of the,Jo?lowing itertzs, Peceptfor art item alr°eady orz file ~+ith the cornmissior~a card idenr~~ed in the application: (9) for an ezpZoratorY or stratigraphic test well, a tzab~ulaiion setting ozrt tli~e depths of predicted abnormally gco-presstared strata as required by 2~ AAC 25.(133(f); Not applicable: Application is not for an exploratory or stratigraphic test well. 10. Seismic Analysis Requirements of 20 AAC 25.005 (c)(10) Are application for a fern^ait to L?rill must he accocr2panied by each of the following items, ~rc~ pt, for art itenc already on~le with the currarraissa`on and identified in the application: {I0) fur un exploratory vr•.rtratigraphic test well, a cea mic refr^ac•tfon or reflection analysis as required by 20 A;IC ~ 5. o61{aj; Not applicable: Application is not for an exploratory or stratigraphic test well. 11. Seabed Condition Analysis Requirements of 20 AAC 25.005 (c)(I1) An application fhr• a Permit to Drill rnrrst he accompanied fiy eacFt of the jollou~ing iterras, except for an item already »r~a file with the commissior~r sand identifzc d in the application: (11), for a well drilled from an offsl2ore platform, rr~aobtle bottvrn fo2rnded str cacture, jack-up rig, or floating drilling vessel, an artalycis of seabed conditions as required by ZD AAC ' ~. o%1(h): Not applicable: Application is not for an offshore well. 1J-178 PERMIT IT Page 5 of 7 (`~ ("~ j ^ I ~ ~ f Pnnted.~ 7-Sep-07 Lateral Mud Program (MI VersaPro Mineral. Oil Base) B, D sand laterals - C] ~lication for Permit to Drill, Well 1J-178 Revision No.O Saved: 7-Sep-07 12. Evidence of Bonding Requirements of 20 AAC 25.005 (c)(12) AY'E atJt?iXCRriU72 1'-1Y a ~~£;37fliC t€t .t)Ytii F7fltb5t ~e aCCG+IY1~7tIYl6ed ity E'aCt2 Of te~tE fOIIOYYiJ2~" iCe77iS, E'a-CE'(Jt~OT' an Ztefn aiYeC~dy OF1 f lie 14`tZit the Co71?7T173S70n anz~idenfifred irz the a~pticatiln: (I2) evidence sho v+~dng that the requa~ er~at^,~cs of 2Cl A~2C 25. J2 i ~73utaiJing}have been rr~ei; Evidence oflionding for ConocoPhillips Alaska, Inc. is on file with the Commission. 13. Proposed Drilling Program Requirements of 20 AAC 25.005 (c)(13) I An a~plicatian,for zl Perrrait to I~rilX must f~eaccornpanied try e~sch of the fvHowin it~rrrs, except fbr an ite.~ta calYeady on fide witlz the cananais~lczn and idetat~eit in tlae a~~licaP."can: The proposed drilling program is listed below. Please refer also to Attachment 4, Well Schematics. 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. Insta1121-1/4" Annular with 16" diverter line and function test. 3. Spud and directionally drill 16" hole to casing point at +/- 3,647' MD / 2,200' TVD. as per directional plan. Run - MWD tools as required for directional monitoring. 4. Run and cement 13-3/8", 68#, 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 his before test. 6. PU 12-1/4" 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. i 8. Directionally drill to 9-5/8" casing point at 9,135' MD / 3,288 TVD, the progosed top of the B sand. 9. Run 9-5/8", 40# L80, BTC Mod casing to surface. Pump cement and displace with mud (top of cement to be 6,046' r MD / 2,708' TVD-(500' above Ugnu formation). 10. Install wellhead x 9-5/8" packoff and test to 5000 psi. Il. Flush 13-3/8" x 9-5/8" annulus with water, followed by diesel. 12. PU 8-1/2"drilling assembly, with MWD, and LWD logging tools. RIH to top of cement. Pressure testcasing to .3,000 psi for 30 minutes and record results. Clean out cement to top of float equipment. Re-test casing if cement is tagged more than 100 feet above the float collar 13. Dri11 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. ~~I~;~~ 14. Directionally dri118-1/2".hole to TD at+/_ 17,072' MD / 3,281' TVD as per directional plan. Q~<''a 15. POOH, back reaming out of lateral. POOH. ` 16. PU and run 5-1/2" slotted liner. 17. Land liner, set liner hanger @ +/- 8,629' MD / 3,227' TVD. POOH. ~ - Note: Remaining operations are covered under the IJ--178 LI Application for Permit toDrill, and are provided here. for information only. 18. Run and set Baker WindowMaster whipstock system,. at window point of 8,529' MD / 3,21.1' TVD, the top of the <`D" sand. 19. Mi118-1/2" window. POOH. 1J-178 PERMIT IT /~ ~ ~ Page 6 of 7 Printed: 7-Sep-07 Ap~n for Permit to Drill, Well 1 J-178 Revision No.O Saved: 7-Sep-07 20. Pick up 8-1/2" drilling assembly with LWD and MWD and PWD. RIH. 21. Drill to TD of "D" sand lateral at 17,068' MD /3,212' TVD, as per directional plan. 22. POOH, back reaming out of lateral. POOH, 23. RIH with whipstock retrieval tool. Retrieve whipstock and POOH. 24. PU and RIH with the Baker seal bore diverter. 25. PU and run 4-1/2" slotted liner on Baker RAM hanger. 26. RIH and land RAM hanger in Baker seal bore diverter.. 27. Release hanger running tool, POOH, laying down drill pipe as required. 28. PU ESP completion as required and RIH to depth. Land tubing. Set BPV. 29. Nipple down BOPE, nipple up tree and test. Pull BPV. 30. Freeze protect well with diesel by pumping into 4-1/2" x 9-5/8" annulus, taking returns from tubing and allowing to .equalize. (If the schedule and equipment availability allows, the We11s Group will freeze protect the well post rig). 31. Set BPV and move rig off. - 32. Rig up wire line unit. Pull BPV. 33. Set gas lift valves in mandrels. Use ESP to clean up well. 34. Place well on production. 14. Discussion of Mud and Cuttings Disposal and Annular Disposal Requirements of 20 AAC 25.005 (c)(14) An applzcation for a Permit tv Urill m;rstc be accon~apanfed hp each of tFae foTloK~irzg iterras, exceptfor' an item aireczdy on,fzle tit~ith the comrtzzsszor^z and itletatified in tl~te applurztiora.• {I4) a getaeral descript;ora t~f how the operator plans to dzspos~e of drilling mut7 artd c~t~ftings and a staienaent ~j w/tethe€~ the operator intends to rer~z~est authorizatic+n ututer° 2t} .~2C; 25. C1R0_ jor an anrtti!ar disposal operation irz the x~~ tl.,• 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 1•E-, 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 ds and roads in the Kuparuk area in accordance. with a permit from the State of Alaska. ~; e-ti~v ,~ ~ ~ ~~~ ~ UJ:~~~ p4~ ~,.,, t (~c,~' ~~'~~ ConocoPhillips Alaska may in-the future request authorization for the use of this well for annular disposal `'~ `-''y~~ operations. ~ / l~ 15. Attachments Attachment 1 Directional Plan Attachment 2 Drilling Hazards Summary Attachment 3 CemCADE Summary Attachment 4 Well Schematic 1J-178 PERMIT IT Page 7 of 7 Printed: 7-Sep-07 Gl~AL • ~ ConocoPhillips ~~~ Plan: 1J-178 (wp03) Sperry Drilling Services Proposal Report -Geographic 02 August, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-178 (Q3 Phase 2) -Slot 1J-178 1J-178 Local Coordinate Origin:. entered on Well Plan 1J-178 (03 Phase 2) -Slot 1J Viewing Datum: Doyon 15 RKB @ 121.OOft (Doyon 15 (40+81)) TVDs to System: N North Reference: True Unit System: API - US Survey Feet HALLS TAN Sperry ~riiling Services OR!61t~1.AL HALLIBURTON Sperry Drilling Services -4500 -4000 -3500 -3000 -2500 -2000 -1500 j c -1000 f.._~ -soo Q -0 ~ 500 r i, ~ > r ~ 1000 1 ~ 1500 3000 SHL- 1647' FSL, 2452' FEL - Sec35-T11 N-R10E Project: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1 J-178 (Q3 Phase Wellbore: 1 J-178 Plan: 1J-178 (wp03) WELL DETAllS: Plan IJ-178 (Q3 Phase 2) NAD 1927 (NADCON CONUS) Alaska Zone 04 Ground Level: 81.00 +N/-S +&-W Northing Fasting Latitude Longitude Slot 0.00 0.00 5945459.03 558760.45 70°IS'41.73N 149°3l'29.97W IJ-178 ANNOTATIONS ND MD Annotation 40.00 40.00 SHL: 1647' FSL, 2452' FEL- Sec35-T11N-R10E 2934.07 7143.00 Begin Pump Tangent 78° INC @ 7143' MD, 2934' ND 2975.36 7343.00 End Pump Tangent @ 7343' MD, 2975' ND 3288.61 9135.02 9 5/8" Casing @ 9135' MD, 3289' ND: 801' FSL, 1627' FEL - SecA3-T10N 3293.20 12517.23 PA Boundary @ 12517' MD, 3293' ND: 2580' FNL, 1499' FEL - Sec10-T1( 3281.70 17072.84 BHL @ 17073' MD, 3282' ND: 1855' FNL, 1507' FEL - Sec15-T10N-R10E FORMATION TOP DETAILS No. TVDPath NDSS MDPath Formation 1 1536.20 1415.2 1747.83 Pfrost 2 1638.99 1517.99 1953.78 T3 3 1932.85 1811.85 2827.11 K15 4 2139.62 2018.62 3462.22 T3+550 5 2810.88 2689.88 6546.57 Ugnu C 6 2874.57 2753.57 6854.92 Ugnu B 7 2936.02 2815.02 7152.42 Ugnu A 8 3078.91 2957.91 7841.46 K 13 9 3211.29 3090.29 8529.21 W Sak D 10 3256.79 3135.79 8798.33 W Sak C 11 3284.73 3163.73 9090.44 W Sak B CASING DETAILS No MD ND NDss Name Size 7 3647.68 2200.00 2079 13 3/8" 13-3/8 2 9135.02 3288.61 3167.61 9 5/8" 9-5/8 3 17072.84 3281.70 3160.7 51/2" 5-1/2 ~r~s~~~t~ 10° 2300 9 5/8" Casing ~ 9135' MD, 3289' ND: 801' FSL, 1627' FEL - Sec03-T10N-R10E p,0 Begin Pump Tangent 78° INC ~ 7143' MD, 2934' ND PA Boundary @ 12517' MD, 3293' ND: 2580' FNL, 1499' FEL - Sec10-T10N-R10E ho°o° Plrast roo^o^o ' End Pump Tangent ~ 7343' MD, 2975' ND ° i --T3-- - p~ , i ,b ' i i i ~ - -y- - - - '~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - o --K15 - - - - - - - - - - ~~ - - - - - - - - r - - - - - - - - - - - --T3+550------- ~-~"---- o-------- i ----- -.-------- -~~- i r ~ ~ o° r ~ I° .~ .' .~ m Ugnu C 13 3/8" ~ ' ~ _ __ __ __ ° _ _~ -~----------- -- ------------°Q - ° _ _ <n ==UgnuA-------------------------- -~--~--~0>-~--------~----------- ---------------~---- -~---~-- -=----------------------------------- --- ------ -- ° ° i WSakD ~ °o ° ° ° ~ ~ 9 5/8" ° 5 1/2" ' n WSakB 3 w r 5000 -lliiiiiiiiiiiiiiiiiiiiiii~~~~~~~~~~~~~~1...~1~..11. 0 500 1000 1500 2000 2500 3000 3500 4000 4500 5000 5500 6000 6500 7000 7500 8000 8500 9000 9500 10000 10500 11000 11500 12000 12500 13000 13500 14000 Vertical Section at 180.00° (1500 ft/in) ~.-' ConocoPhillips Alaska HALLIBURTON Sperry Driliitng Services -1000 -1500 -2000 -2500 P!~Cct: Kuparuk River Unit Site: Kuparuk 1J Pad Well: Plan 1J-178 (Q3 Phase Wellbore: 1 J-178 Plan: 1J-178 (wp03) ELL DETAILS: Plan ~Q3 Phase ®j~D 1927 (NADCON CONUS) Alaska Zone 04 Ground Level: 81.00 +N/-S +E/-W Northing Easting Latittude Longitude Slot 0.00 0.00 5945459.03 558760.45 70°15'41.73N 149°31'29.97W 1J-178 REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Plan iJ-178 (03 Phase 2) -Slot 1J-178, True North Vertical (TVD) Reference: Doyon 15 RKB (~ 121.OOfl (Doyon 15 (40+81)) Measuretl Depth Reference: Doyon 15 RKB (~ 121.OOft (Doyon 15 (40+81)) Calculation Method: Minimum Curvature i[{L: 164T FSL, 2452' FEL - Sec35-TI IN-Rl OE TVD -5500 I1-I7R ~1B D_Top 10~^_?-07 - - C -6000 " O u7 9 5/8 - - - -6500 + 11-178 ~1B_B_TI (5 __071 _ _ -7000 0 -7500 IJ-178VIB B T^(x'_07 __ s o -8000 8500 u-ns eta B Ts is ,_;n7 - - - - - -9000 IJ-178 Iv1B B T4 (5/22/07 _ _ -I1000~ - I1-198 MB_B_TS (5122/07) _ -11500 -12500 I I-178 ~iB_B 761`='_071_ _ _ -13000 -14000 T M Azimuths to True North Magnetic North: 23.24° Magnetic Field Strength: 57614.7nT Dip Angle: 80.79° Date: 8/2/2007 IJ-178 MB_B Toe (5/?2/07) _ _ _ Model: BGGM2007 U-178 (wp03) -7000 -6500 -6000 -5500 -5000 -4500 -4000 -3500 -3000 -2500 -2000 -1500 -1000 -500 0 500 1000 1500 2000 2500 ;000 ;500 3000 4500 5000 5500 West(-)/East(+) (1750 ft/in) ti's ConocoPhillips Alaska EEL - Sec03-TI ON-R 101: CASING DETAILS FEL-Sec10.T10N-RlOE No MD TVD NDss Name Size 1 3647.68 2200.00 2079 13 3/8" 13-3/8 2 9135.02 3288.61 3167.61 9 5/8" 9-5/8 a 317072.84 3281.70 3160.7 5 1/2" 5-1/2 ANNOTATIONS MD Annotation 40.00 SHL: 1647' FSL, 2452' FEL - Sec35-711 N-R10E 43.00 Begin Pump Tangent 78° INC ~ 7143' MD, 2934' TVD 43.00 End Pump Tangent ~ 7343' MD, 2975' ND 35.02 9 5/8" Casing ~ 9135' MD, 3289' TVD: 801' FSL, 1627' FEL - Sec03-T10N-R10E 17.23 PA Boundary (r~ 12517' MD, 3293' TVD: 2580' FNL, 1499' FEL - Sec10-T10N-R10E 72.84 BHL ~ 17073' MD, 3262' ND: 1855' FNL, 1507' FEL - Sec15-T10N-R10E ORIGINAL ~-' Halliburton Company HALLIBURTON COt1000PIlI~~ pSkS Compass Proposal Report -Geographic Sperry Drilling Services Database: .Sperry EDM .11 Local Co-ordinate Reference: Well Plan 1J-178 (Q3 Phase 2) -Slot 1J-178 Company: ConocoPhillips Alaska, Inc. ND Reference: Doyon 15 RKB @ 121.OOft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 RKB @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Flan 1J-178 (Q3 Phase 2) Survey Calculation Method: Minimum Curvature Wellbore: 1 J-178 Design: 1J-178 (wp03) Project Kuparuk River Unit. North Slope Alaska, U nited States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Well Plan 1J-178 (Q3 Phase P) -Slot 1J-178 Well Position +N/-S 0.00 ft Northing: 5,945,459.03 ft Latitude: 70° 15' 41.730" N +E/-W 0.00 ft Easting: 558,760.45ft Longitude: 149° 31' 29.970" W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 81.OOft Wellbore 1J-178 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2007 8/2/2007 23.24 80.79 57,615 Design 1J-178 (wp03) Audit Notes: Version: Phase: PL_aN Tie On Depth: 40.00 Vertical Section: Depth From (TVD) (ft) 40.00 +N/-5 +E/-W (ft) (ft) 0.00 0.00 Direction (°) 180.00 8/2/2007 11:37:23AM Page 2 of 11 COMPASS 2003.11 Build 48 ~~~t ~s~ / Halliburton Company HALLIBURTON COIIOCO~I1~~Ip5 Compass Proposal Report -Geographic Alaska Sperry Drilling Services Database: .Sperry EDM .11 Local Co-ordinate Reference: Well Plan 1J-178 (Q3 Phase 2) -Slot 1J-178 Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 RKB @ 121.OOft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 RKB @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-178 (Q3 Phase 2) Survey Calculation Method: Minimum Curvature Wellbore: IJ-178 Design: IJ-178 (wp03) Plan Summary Measured Dogleg Build Turn Depth Inclination Azimuth TVD TVDSS +NI-S +E/-W Rate Rate Rate TFO (ft) (°) (°) (ft) (ft) (ft) (ft) (°/100ft) (°/100ft) {°/100ft) (') 40.00 0,00 0.00 40.00 -81.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 179.00 0.00 0.00 0.00 0.00 0.00 0.00 500.00 6.00 222.00 499.63 378.63 -7.78 -7.00 3.00 3.00 0.00 222.00 2,125.00 71.00 222.00 1,704.26 1,583.26 -719.86 -648.17 4.00 4.00 0.00 0.00 3,647.68 71.00 222.00 2,200.00 2,079.00 -1,789.78 -1,611,53 0.00 0.00 0.00 0.00 3,850.08 78.08 222.26 2,253.92 2,132.92 -1,934.36 -1,742.31 3.50 3.50 0.13 2.06 7,343.68 78.08 222.26 2,975.53 2,854.53 -4,464.23 -4,041.07 0.00 0.00 0.00 0.00 8,529.27 80.00 180.00 3,211.30 3,090.30 -5,524.01 -4,449.12 3.50 0.16 -3.56 -91.67 8,729.27 80.00 180.00 3,246.03 3,125.03 -5,720.98 -4,449.12 0.00 0.00 0.00 0.00 8,895.93 85.00 180.00 3,267.78 3,146.78 -5,886.16 -4,449.12 3.00 3.00 0.00 0.00 9,105.02 85.00 180.00 3,286.00 3,165.00 -6,094.45 -4,449.12 0.00 0.00 0.00 0.00 9,135.02 85.00 180.00 3,288.61 3,167.61 -6,124.34 -4,449.12 0.00 0.00 0.00 0.00 9,270.67 8y.97 175.45 3,296.94 3,175.94 -6,259.58 -4,443.73 4.00 2.19 -3.36 -57.00 9,309.59 87.97 175.45 3,298.32 3,177.32 -6,298.35 -4,440.65 0.00 0.00 0.00 0.00 9,410.78 89.64 179.14 3,300.43 3,179.43 -6,399.39 -4,435.87 4.00 1.65 3.64. 65.65 9,835.78 89.64 179.14 3,303.10 3,182.10 -6,824.33 -4,429.46 0.00 0.00 0.00 0.00 9,911.99 90.40 179.14 3,303.07 3,182.07 -6,900.53 -4,428.31 1.00 1.00 0.00 0.00 10,535.05 90.40 179.14 3,298.70 3,177.70 -7,523.50 -4,418.91 0.00 0.00 0.00 0.00 10,613.70 89.62 179.15 3,298.69 3,177.69 -7,602.15 -4,417.74 1.00 -1.00 0.02 179.03 11,435.39 89.62 179.15 3,304.20 3,183.20 -8,423.72 -4,405.54 0.00 0.00 0.00 0.00 11,536.83 90.63 179.13 3,303.98 3,182.98 -8,525.15 -4,404.01 1.00 1.00 -0.02 -0.90 12,735.93 90.63 179.13 3,290.80 3,169.80 -9,724.04 -4,385.88 0.00 0.00 0.00 0.00 12,773.46 91.01 179.14 3,290.26 3,169.26 -9,761.57 -4,385.31 1.00 1.00 0.01 0.34 14,435.79 91.01 179.14 3,261.10 3,140.10 -11,423.45 -4,360.24 0.00 0.00 0.00 0.00 14,615.57 89.21 179.14 3,260.77 3,139.77 -11,603.20 -4,357.53 1.00 -1.00 0.00 179.85 15,536.28 89.21 179.14 3,273.50 3,152.50 -12,523.72 -4,343.72 0.00 0.00 0.00 0.00 15,585.75 89.70 179.14 3,273.97 3,152.97 -12,573.18 -4,342.98 1.00 1.00 0.00 0.17 17,072.85 89.70 179.14 3,281.70 3,160.70 -14,060.10 -4,320.70 0.00 0.00 0.00 0.00 8/2/2007 11:37:23AM Page 3 of 11 COMPASS 2003.11 Build 48 Q~~~~~~L ~-' Halliburton Company COt1000~'ll~~lp5 Compass Proposal Report -Geographic HALLIBURTON Sp®rry Drilling Services Database: .perry EDM .11 Local Co-ordinate Reference: Well Plan 1J-178 (Q3 Phase 2) -Slot 1J-178 Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 RKB @ 121.OOft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 RKB @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-178 (Q3 Phase 2) Survey Calculation Method: Minimum Curvature Wellbore: 1 J-178 ~ Design: 1 J-178 (wp03) Planned Survey 1J-17° (v~O3) Map Map MD Incl Azimuth TVD (ft) TVDSS +N/-S +E!-W Northing Easting DLSEV Vert Section (ft) (°) (°) [ft) (ft) (ft) (ft) (ft) (°I100ft) (ft) 40.00 0.00 0.00 40.00 -81.00 0.00 0.00 5,945,459.03 558,760.45 0.00 0.00 SHL: 1647' FSL, 2452' FEL - Sec3 5-T11 N-R1 OE 100.00 0.00 0.00 100.00 -21.00 0.00 0.00 5,945,459.03 558,760.45 0.00 0.00 200.00 0.00 0.00 200.00 79.00 0.00 0.00 5,945,459.03 558,760.45 0.00 0.00 300.00 0.00 0.00 300.00 179.00 0.00 0.00 5,945,459.03 558,760.45 0.00 0.00 400.00 3.00 222.00 399.95 278.95 -1.95 -1.75 5,945,457.07 558,758.71 3.00 1.95 500.00 6.00 222.00 499.63 378.63 -7.78 -7.00 5,945,451.20 558,753.51 3.00 7.78 600.00 10.00 222.00 598.64 477.64 -18.12 -16.31 5,945,440.79 558,744.28 4.00 18.12 700.00 14.00 222.00 696.44 575.44 -33.56 -30.22 5,945,425.24 558,730.50 4.00 33.56 800.00 18.00 222.00 792.54 671.54 -54.04 -48.66 5,945,404.61 558,712.22 4.00 54.04 900.00 22.00 222.00 886.49 765.49 -79.45 -71.54 5,945,379.03 558,689.54 4.00 79.45 1,000.00 26.00 222.00 977.83 856.83 -109.68 -98.75 5,945,348.60 558,662.57 4.00 109.68 1,100.00 30.00 222.00 1,066.11 945.11 -144.56 -130.16 5,945,313.48 558,631.44 4.00 144.56 1,200.00 34.00 222.00 1,150.89 1029.89 -183.93 -165.61 5,945,273.83 558,596.30 4.00 183.93 1,300.00 38.00 222.00 '1,231.78 1110.78 -227.60 -204.93 5,945,229.86 558,557.32 4.00 227.60 ', 1,400.00 42.00 222.00 1,308.37 1187.37 -275.36 -247.94 5,945,181.77 558,514.69 4.00 275.36 1,500.00 46.00 222.00 1,380.29 1259.29 -326.97 -294.41 5,945,129.80 558,468.63 4.00 326.97 1,600.00 50.00 222.00 1,447.19 1326.19 -382.19 -344.12 5,945,074.21 558,419.35 4.00 382.19 1,700.00 54.00 222.00 1,508.74 1387.74 -440.74 -396.84 5,945,015.25 558,367.10 4.00 440.74 1,747.83 55.91 222.00 1,536.20 1415.20 -469.83 -423.04 5,944,985.96 558,341.13 4.00 469.83 Pfrost 1,800.00 58.00 222.00 1,564.65 1443.65 -502.33 -452.30 5,944,953.23 558,312.12 4.00 502.33 1,900.00 62.00 222.00 1,614.64 1493.64 -566.68 -510.24 5,944,888.44 558,254.70 4.00 566.68 1,953.78 64.15 222.00 1,638.99 1517.99 -602.31 -542.32 5,944,852.56 558,222.89 4.00 602.31 T3 2,000.00 66.00 222.00 1,658.47 1537.47 -633.46 -570.37 5,944,821.20 558,195.10 4.00 633.46 2,100.00 70.00 222.00 1,695.92 1574.92 -702.35 -632.40 5,944,751.84 558,133.61 4.00 702.35 2,125.00 71.00 222.00 1,704.26 1583.26 -719.86 -648.17 5,944,734.20 558,117.98 4.00 719.86 2,200.00 71.00 222.00 1,728.68 1607.68 -772.56 -695.62 5,944,681.14 558,070.95 0.00 772.56 2,300.00 71.00 222.00 1,761.24 1640.24 -842.83 -758.88 5,944,610.39 558,008.24 0.00 842.83 2,400.00 71.00 222.00 1,793.80 1672.80 -913.09 -822.15 5,944,539.64 557,945.53 0.00 913.09 2,500.00 71.00 222.00 1,826.35 1705.35 -983.36 -885.42 5,944,468.89 557,882.82 0.00 983.36 2,600.00 71.00 222.00 1,858.91 1737.91 -1,053.62 -948.69 5,944,398.14 557,820.11 0.00 1,053.62 2,700.00 71.00 222.00 1,891.47 1770.47 -1,123.89 -1,011.95 5,944,327.39 557,757.39 0.00 1,123.89 2,800.00 71.00 222.00 1,924.02 1803.02 -1,194.15 -1,075.22 5,944,256.64 557,694.68 ,.0.00 1,194.15 2,827.11 71.00 222.00 1,932.85 1811.85 -1,213.21 -1,092.38 5,944,237.45 557,677.68 0.00 1,213.21 K15 2,900.00 71.00 222.00 1,956.58 1835.58 -1,264.42 -1,138.49 5,944,185.89 557,631.97 0.00 1,264.42 3,000.00 71.00 222.00 1,989.14 1868.14 -1,334.69 -1,201.76 5,944,115.14 557,569.26 0.00 1,334.69 3,100.00 71.00 222.00 2,021.69 1900.69 -1,404.95 -1,265.02 5,944,044.39 557,506.55 0.00 1,404.95 3,200.00 71.00 222.00 2,054.25 1933.25 -1,475.22 -1,328.29 5,943,973.64 557,443.84 0.00 1,475.22 3,300.00 71.00 222.00 2,086.81 1965.81 -1,545.48 -1,391.56 5,943,902.88 557,381.13 0.00 1,545.48 3,400.00 71.00 222.00 2,119.36 1998.36 -1,615.75 -1,454.83 5,943,832.13 557,318.41 0.00 1,615.75 3,462.22 71.00 222.00 2,139.62 2018.62 -1,659.47 -1,494.19 5,943,788.11 557,279.40 0.00 1,659.47 T3+550 3,500.00 71.00 222.00 2,151.92 2030.92 -1,686.01 -1,518.09 5,943,761.38 557,255.70 0.00 1,686.01 8/2/2007 11:37:23AM Page 4 of 11 COMPASS 2003.11 Build 48 COtl000~11~~Ip5 Halliburton Company HALLIBURTON Alaska Compass Proposal Report -Geographic gp®rry Drilling 8®rvic~ Database: .Sperry EDM .11 Local Co-ordinate Reference: \^dell Plan 1J-178 (Q3 Phase 2) -Slot 1J-178 Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 RKB @ 121.OOft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 RKB @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-178 (Q3 Phase 2) Survey Calculation Method: Minimum Curvature Wellbore: 1J-178 Design: 1J-178 (wp03) Planned Survey 1J-172 (wp03> Map Map MD Incl Azimuth TVD (ft) TVDSS +NI-S +E/-W Northing Easting pLSEV Vert Section (ft) (°) (°) (ft) (ft) (ft) 1ft1 (ft) ('1100ft) Iftl 3,600.00 71.00 222.00 2,184.48 2063.48 -1,756.28 -1,581.36 5,943,690.63 557,192.99 0.00 1,756.28 3,647.68 71.00 222.00 2,200.00 2079.00 -1,789.78 -1,611.53 5,943,656.90 557,163.09 0.00 1,789.78 13 318" 3,700.00 72.83 222.07 2,216.24 2095.24 -1,826.72 -1,644.83 5,943,619.71 557,130:08 3.50 1,826.72 3,800.00 76.33 222.20 2,242.83 2121.83 -1,898.20 -1,709.49 5,943,547.73 557,065.99 3.50 1,898.20 3,850.08 78.08 222.26 2,253.92 2132.92 -1,934.36 -1,742.31 5,943,511.32 557,033.45 3.50 1,934.36 3,900.00 78.08 222.26 2,264.23 2143.23 -1,970.51 -1,775.16 5,943,474.92 557,000.89 0.00 1,970.51 4,000.00 78.08 222.26 2,284.89 2163.89 -2,042.92 -1,840.96 5,943,402.00 556,935.67 0.00 2,042.92 4,100.00 78.08 222.26 2,305.54 2184.54 -2,115.34 -1,906.75 5,943,329.08 556,870.44 0.00 2,115.34 4,200.00 78.08 222.26 2,326.20 2205.20 -2,187.75 -1,972.55 5,943,256.16 556,805.22 0.00 2,187.75 4,300.00 78.08 222.26 2,346.85 2225.85 -2,260.17 -2,038.35 5,943,183.25 556,739.99 0.00 2,260.17 4,400.00 78.08 222.26 2,367.51 2246.51 -2,332.58 -2,104.15 5,943,110.33 556,674.76 0.00 2,332.58 4,500.00 78.08 222.26 2,388.16 2267.16 -2,404.99 -2,169.95 5,943,037.41 556,609.54 0.00 2,404.99 4,600.00 78.08 222.26 2,408.82 2287.82 -2,477.41 -2,235.75 5,942,964.49 556,544.31 0.00 2,477.41 4,700.00 78.08 222.26 2,429.47 2308.47 -2,549.82 ~ -2,301.55 5,942,891.57 556,479.09 0.00 2,549.82 4,800.00 78.08 222.26 2,450.13 2329.13 -2,622.24 -2,367.35 5,942,818.65 556,413.86 0.00 2,622.24 4,900.00 78.08 222.26 2,470.78 2349.78 -2,694.65 -2,433.15 5,942,745.73 556,348.64 0.00 2,694.65 5,000.00 78.08 222.26 2,491.44 2370.44 -2,767.07 -2,498.95 5,942,672.81 556,283.41 0.00 2,767.07 5,100.00 78.08 222.26 2,512.09 2391.09 -2,839.48 -2,564.75 5,942,599.90 556,218.18 0.00 2,839.48 5,200.00 78.08 222.26 2,532.75 2411.75 -2,911.90 -2,630.55 5,942,526.98 556,152.96 0.00 2,911.90 5,300.00 78.08 222.26 2,553.40 2432.40 -2,984.31 -2,696.34 5,942,454.06 556,087.73 0.00 2,984.31 5,400.00 78.08 222.26 2,574.06 2453.06 -3,056.72 -2,762.14 5,942,381.14 556,022.51 0.00 3,056.72 5,500.00 78.08 222.26 2,594.71 2473.71 -3,129.14 -2,827.94 5,942,308.22 555,957.28 0.00 3,129.14 5,600.00 78.08 222.26 2,615.37 2494.37 -3,201.55 -2,893.74 5,942,235.30 555,892.06 0.00 3,201.55 5,700.00 78.08 222.26 2,636.02 2515.02 -3,273.97 -2,959.54 5,942,162.38 555,826.83 0.00 3,273.97 5,800.00 78.08 222.26 2,656.68 2535.68 -3,346.38 -3,025.34 5,942,089.47 555,761.60 0.00 3,346.38 5,900.00 78.08 222.26 2,677.33 2556.33 -3,418.80 -3,091.14 5,942,016.55 555,696.38 0.00 3,418.80 6,000.00- 78.08 222.26 2,697.99 2576.99 -3,491.21 -3,156.94 5,941,943.63 555,631.15 0.00 3,491.21 6,100.00 78.08 222.26 2,718.64 2597.64 -3,563.63 -3,222.74 5,941,870.71 555,565.93 0.00 3,563.63 6,200.00 78.08 222.26 2,739.30 2618.30 -3,636.04 -3,288.54 5,941,797.79 555,500.70 0.00 3,636.04 6,300.00 78.08 222.26 2,759.95 2638.95 -3,708.45 -3,354.34 5,941,724.87 555,435.47 0.00 3,708.45 6,400.00 78.08 222.26 2,780.61 2659.61 -3,780.87 -3,420.14 5,941,651.95 555,370.25 0.00 3,780.87 6,500.00 78.08 222.26 2,801.26 2680.26 -3,853.28 -3,485.93 5,941,579.04 555,305.02 0.00 3,853.28 6,546.57 78.08 222.26 2,810.88 2689.88 -3,887.00 -3,516.57 5,941,545.08 555,274.65 0.00 3,887.00 Ugnu C 6,600.00 78.08° 222.26 2,821.92 - 2700.92 -3,925.70 -3,551.73 5,941,506.12 - 555,239.80 0.00 3,925.70 6,700.00 78.08 222.26 2,842.57 2721.57 -3,998.11 -3,617.53 5,941,433.20 555,174.57 0.00 3,998.11 6,800.00 78.08 222.26 2,863.23 2742.23 -4,070.53 -3,683.33 5,941,360.28 555,109.35 0.00 4,070.53 6,854.92 78.08 222.26 2,874.57 2753.57 -4,110.29 -3,719.47 5,941,320.23 555,073.53 0.00 4,110.29 Ugnu B 6,900.00 78.08 222.26 2,883.88 2762.88 -4,142.94 -3,749.13 5,941,287.36 555,044.12 0.00 4,142.94 7,000.00 78.08 222.26 2,904.54 2783.54 -4,215.35 -3,814.93 5,941,214.44 554,978.89 0.00 4,215.35 7,100.00 78.08 222.26 2,925.19 2804.19 -4,287.77 -3,880.73 5,941,141.52 554,913.67 0.00 4,287.77 7,143.00 78.08 222.26 2,934.07 2813.07 -4,318.91 -3,909.02 5,941,110.17 554,885.62 0.00 4,318.91 Begin Pump Tangent 78° INC @ 7143' MD, 2934' ND 8/2/2007 11:37:23AM Page 5 of 11 COMPASS 2003.11 Build 48 .i~~!GINAL Halliburton Company HALLIBURTON COt'tOCOPI't1~~p5 Com ass Pro osal Re ort - Geo ra hic p P P 9 P Sperry Drilling Services Database: .Sperry EDM .11 Local Co-ordinate Reference: Well Plan 1J-178 (Q3 Phase 2) -Slot 1J-178 Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 RKB @ 121.OOft (Doyon 15 (40+81)) Project: I<uparuk River Unit MD Reference: Doyon 15 RKB @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: -True Well: Plan 1J-178 (Q3 Phase 2) Survey Calculation Method: ` P,linimum Curvature Wellbore: 1 J-178 Design: 1J-178 (wp03) Planned Survey 1J-173 (~~~p03) Map MD Inc! Azimuth TVD (ft) TVDSS +N/-S +E~-W Northing (ft) (°) (°) (ftl (ft) lft) 1ft) 7,152.42 78.08 222.26 2,936.02 2815.02 -4,325.73 -3,915.22 5,941,103.30 Ugnu A 7,200.00 78.08 222.26 2,945.85 2824.85 -4,360.18 -3,946.53 5,941,068.60 7,300.00 78.08 222.26 2,966.50 2845.50 -4,432.60 -4,012.33 5,940,995.69 7,343.00 78.08 222.26 2,975.38 2854.38 -4,463.74 -4,040.62 5,940,964.33 End Pump Tangent @ 7343' MD, 2975' ND 7,343.68 78.08 222.26 2,975.53 2854.53 -4,464.23 -4,041.07 5,940,963.83 7,400.00 78.03 220.25 2,987.18 2866.18 -4,505.65 -4,077.40 5,940,922.13 7,500.00 77.98 216.67 3,007.98 2886.98 -4,582.23 -4,138.22 5,940,845.09 7,600.00 77.97 213.09 3,028.82 2907.82 -4,662.45 -4,194.14 5,940,764.44 7,700.00 78.00 209.51 3,049.65 2928.65 -4,746.01 -4,244.95 5,940,680.49 7,800.00 78.09 205.94 3,070.37 2949.37 -4,832.60 -4,290.45 5,940,593.56 7,841.46 78.13 204.45 3,078.91 2957.91 -4,869.31 -4,307.72 5,940,556.73 K13 7,900.00 78.21 202.36 3,090.91 2969.91 -4,921.89 -4,330.48 5,940,503.97 8,000.00 78.39 198.79 3,111.20 2990.20 -5,013.55 -4,364.88 5,940,412.06 8,100.00 78.60 195.23 3,131.15 3010.15 -5,107.24 -4,393.54 5,940,318.16 8,200.00 78.86 191.67 3,150.70 3029.70 -5,202.60 -4,416.34 5,940,222.62 8,300.00 79.16 188.12 3,169.77 3048.77 -5,299.30 -4,433.20 5,940,125.81 8,400.00 79.50 184.57 3,188.29 3067.29 -5,396.95 -4,444.05 5,940,028.09 .8,500.00 79.88 181.03 3,206.19 3085.19 -5,495.20 -4,448.86 5,939,929.81 8,529.27 80.00 180.00 3;211.30 3090.30 -5,524.01 -4,449.12 5,939,901.00 W Sak D -1J-178 MB_D_Top (05122/07) 8,600.00 80.00 180.00 3,223.58 3102.58 -5,593.67 -4,449.12 5,939,831.35 8,700.00 80.00 180.00 3,240.95 3119.95 -5,692.15 -4,449.12 5,939,732.88 8,729.27 80.00 180.00 3,246.03 3125.03 -5,720.98 -4,449.12 5,939,704.06 8,798.33 82.07 180.00 3,256.79 3135.79 -5,789.19 -4,449.12 5,939,635.86 W Sak C 8,800.00 82.12 180.00 3,257.02 3136.02 -5,790.85 -4,449.12 5,939,634.20 8,895.93 85.00 180.00 3,267.78 3146.78 -5,886.16 -4,449.12 5,939,538.90 8,900.00 85.00 180.00 3,268.13 3147.13 -5,890.22 -4,449.12 5,939,534.84 9,000.00 85.00 180.00 3,276.85 3155.85 -5,989.84 -4,449.12 5,939,435.24 9,090.44 85.00 180.00 3,284.73 3163.73 -6,079.94 x,449.12 5,939,345.15 W Salo B 9,100.00 85.00 180.00 3,285.56 3164.56 -6,089.46 -4,449.12 5,939,335.63 9,105.02 85.00 180.00 3,286.00 3165.00 -6,094.45 -4,449.12 5,939,330.63 9,135.02 85.00 180.00 3,288.61 3167.61 -6,124.34 -4,449.12 5,939,300.75 9 5/8" Casi ng @ 9135' MD, 3289' TVD: 801' FSL, 1627' FEL - Sec03-T10N-R10E - 9 5/8" 9,200.00 86.42 177.82 3,293.48 3172.48 -6,189.12 -4,447.88 5,939,235.99 9,224.64 86.96 176.99 3,294.90 3173.90 -6,213.70 -4,446.76 5,939,211.42 1J-178 MB_B_Heel (5!22/07} Map Fasting DLSEV Vert Section lft) {°I100ft) (ft) 554,879.48 0.00 4,325.73 554,848.44 0.00 4,360.18 554,783.22 0.00 4,432.60 554,755.17 0.00 4,463.74 554,754.72 0.00 4,464.23 554,718.72 3.50 4,505.65 554,658.51 3.50 4,582.23 554,603.22 3.50 4,662.45 554,553.07 3.50 4,746.01 554,508.25 3.50 4,832.60 554,491.27 3.50 4,869.31 554,468.92 3.50 4,921.89 554,435.24 3.50 5,013.55 554,407.32 3.50 5,107.24 554,385.26 3.50 5,202.60 554,369.16 3.50 5,299.30 554,359.07 3.50 5,396.95 554,355.03 3.50 5,495.20 554,355.00 3.50 5,524.01 554,355.54 0.00 5,593.67 554,356.31 0.00 5,692.15 554,356.54 0.00 5,720.98 554,357.07 3.00 5,789.19 554,357.08 2.94 5,790.85 554,357.83 3.00 5,886.16 554,357.86 0.00 5,890.22 554,358.63 0.00 5,989.84 554,359.34 0.00 6,079.94 554,359.41 0.00 6,089.46 554,359.45 0.00 6,094.45 554,359.68 0.00 6,124.34 554,361.43 4.00 6,189.12 554,362.73 4.01 6,213.70 9,270.67 87.97 175.45 3,296.94 9,300.00 87.97 175.45 3,297.98 9,309.59 87.97 175.45 3,298.32 3175.94 -6,259.58 -4,443.73 5,939,165.57 554,366.12 3176.98 -6,288.80 -4,441.41 5,939,136.37 554,368.68 3177.32 -6,298.35 -4,440.65 5,939,126.82 554,369.51 4.00 6,259.58 0.00 6,288.80 0.00 6,298.35 8/2/2007 11:37:23AM Page 6 of 11 COMPASS 2003.11 Build 48 CR161NAL ConocoPhillips Alaska Halliburton Company Compass Proposal Report -Geographic HALLIBt_tRT®N Sp®rry Dril{ing S®rv{ces Database: .Sperry EDM .11 Local Co-ordinate Reference: ~^dell Plan 1J-178 (Q3 Phase 2) -Slot 1J-178 Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 RKB @ 121.OOft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 RKB @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-178 (Q3 Phase 2) Survey Calculation Method: Minimum Curvature Wellbore: 1J-178 Design: 1J-178 (wp03) Planned Survey 1J-173 (wp03) Map Map MD Inc! Azimuth TVD (ft) TVDSS +N/-S +E/_yy Northing Easting DLSEV Vert Section In) (°) (°) (ft) (ft) (ft) (ft) (ft) (°I100ft) (ft) 9,400.00 89.46 178.74 3,300.35 3179.35 -6,388.61 -4,436.07 5,939,036.62 554,374.79 4.00 6,388.61 9,410.78 89.64 179.14 3,300.43 3179.43 -6,399.39 -4,435.87 5,939,025.84 554,375.08 4.01 6,399.39 9,500.00 89.64 179.14 3,300.99 3179.99 -6,488.59 -4,434.52 5,938,936.66 554,377.12 0.00 6,488.59 9,600.00 89.64 179.14 3,301.62 3180.62 -6,588.58 -4,433.01 5,938,836.69 554,379.40 0.00 6,588.58 9,700.00 89.64 179.14 3,302.25 3181.25 -6,688.57 -4,431.51 5,938,736.73 554,381.69 0.00 6,688.57 9,800.00 89.64 179.14 3,302.88 3181.88 -6,788.55 -4,430.00 5,938,636.77 554,383.98 0.00 6,788.55 9,835.78 89.64 179.14 3,303.10 3182.10 -6,824.33 -4,429.46 5,938,601.00 554,384.80 0.00 6,824.33 1J-178 MB_B_T1 (5!2 2!07) 9,900.00 90.28 179.14 3,303.14 3182.14 -6,888.54 -4,428.49 5,938,536.81 554,386.27 1.00 6,888.54 9,911.99 90.40 179.14 3,303.07 3182.07 -6,900.53 -4,428.31 5,938,524.82 554,386.54 1.00 6,900.53 10,000.00 90.40 179.14 3,302.45 3181.45 -6,988.53 -4,426.98 5,938,436.84 554,388.56 0.00 6,988.53 10,100.00 90.40 179.14 3,301.75 3180.75 -7,088.51 -4,425.47 5,938,336.88 554,390.85 0.00 7,088.51 10,200.00 90.40 179.14 3,301.05 3180.05 -7,188.50 -4,423.97 5,938,236.92 554,393.13 0.00 7,188.50 10,300.00 90.40 179.14 3,300.35 3179.35 -7,288.49 -4,422.46 5,938,136.96 554,395.42 0.00 7,288.49 10,400.00 90.40 179.14 3,299.65 3178.65 -7,388.47 -4,420.95 5,938,037.00 554,397.71 0.00 7,388.47 10,500.00 90.40 179.14 3,298.95 3177.95 -7,488.46 -4,419.44 5,937,937.04 554,400.00 0.00 7,488.46 10,535.05 90.40 179.14 3,298.70 3177.70 -7,523.50 -4,418.91 5,937,902.00 554,400.80 0.00 7,523.50 1J-178 MB_B_T2 (5/2 2/07) 10,600.00 89.75 179.15 3,298.61 3177.61 -7,588.45 -4,417.94 5,937,837.07 554,402.28 1.00 7,588.45 10,613.70 89.62 179.15 3,298.69 3177.69 -7,602.15 -4,417.74 5,937,823.38 554,402.59 1.00 7,602.15 10,700.00 89.62 179.15 3,299.27 3178.27 -7,688.43 -4,416.45 5,937,737.11 554,404.54 0.00 7,688.43 10,800.00 89.62 179.15 3,299.94 3178.94 -7,788.42 -4,414.97 5,937,637.15 554,406.81 0.00 7,788.42 10,900.00 89.62 179.15 3,300.61 3179.61 -7,888.41 -4,413.48 5,937,537.19 554,409.07 0.00 7,888.41 11,000.00 89.62 179.15 3,301.28 3180.28 -7,988.39 -4,412.00 5,937,437.22 554,411.34 0.00 7,988.39 11,100.00 89.62 179.15 3,301.95 3180.95 -8,088.38 -4,410.52 5,937,337.26 554,413.60 0.00 8,088.38 11,200.00 89.62 179.15 3,302.62 3181.62 -8,188.37 -4,409.03 5,937,237.30 554,415.87 0.00 8,188.37 11,300.00 89.62 179.15 3,303.29 3182.29 -8,288.35 -4,407.55 5,937,137.34 554,418.13 0.00 8,288.35 11,400.00 89.62 179.15 3,303.96 3182.96 -8,388.34 -4,406.06 5,937,037.37 554,420.40 0.00 8,388.34 11,435.39 89.62 179.15 3,304.20 3183.20 -8,423.72 -4,405.54 5,937,002.00 554,421.20 0.00 8,423.72 1J-178 MB_B_T3 (5122/07) 11,500.00 90.26 179.14 3,304.27 3183.27 -8,488.33 -4,404.57 5,936,937.41 554,422.67 1.00 8,488.33 11,536.83 90.63 179.13 3,303.98 3182.98 -8,525.15 -4,404.01 5,936,900.60 554,423.51 1.00 8,525.15 11,600.00 90.63 179.13 3,303.29 3182.29 -8,588.31 -4,403.06 5,936,837.45 554,424.96 0.00 8,588.31 11,700.00 90.63 179.13 3,302.19 3181.19 -8,688.29 -4,401.55 5,936,737.49 554,427.25 0.00 8,688.29 11,800.00 90.63 179.13 3,301.09 3180.09 -8,788.28 -4,400.03 5,936,637.53 554,429.54 0.00 8,788.28 11,900.00 90.63 179.13 3,299.99 3178.99 -8,888.26 -4,398.52 5,936,537.58 554,431.84 0.00 8,888.26 12,000.00 90.63 179.13 3,298.89 3177.89 -8,988.24 -4,397.01 5,936,437.62 554,434.13 0.00 8,988.24 12,100.00 90.63 179.13 3,297.79 3176.79 -9,088.22 -4,395.50 5,936,337.66 554,436.42 0.00 9,088.22 12,200.00 90.63 179.13 3,296.69 3175.69 -9,188.21 -4,393.98 5,936,237.70 554,438.71 0.00 9,188.21 12,300.00 90.63 179.13 3,295.59 3174.59 -9,288.19 -4,392.47 5,936,137.74 554,441.01 0.00 9,288.19 12,400.00 90.63 179.13 3,294.49 3173.49 -9,388.17 -4,390.96 5,936,037.79 554,443.30 0.00 9,388.17 12,500.00 90.63 179.13 3,293.39 3172.39 -9,488.15 -4,389.45 5,935,937.83 554,445.59 0.00 9,488.15 12,517.23 90.63 179.13 3;293.20 3172.20 -9,505.38 -4,389.19 5,935,920.60 554,445.99 0.00 9,505.38 PA Boundary @ 1251 7' MD, 3293' TVD: 2580' FNL, 1499' F EL - Sec10-T10N-R10E 12,600.00 90.63 179.13 3,292.29 3171.29 -9,588.14 -4,387.93 5,935,837.87 554,447.88 0.00 9,588.14 12,700.00 90.63 179.13 3,291.19 3170.19 -9,688:12 -4,386.42 5,935,737.91 554,450.18 0.00 9,688.12 8/2/2007 11:37:23AM Page 7 of 11 COMPASS 2003.11 Build 48 )RIGINAL ~-''' Halliburton Company HAiLi..IBURTON C011000~'11~~p5 Com ass Pro osal Re ort - Geo ra hic P P p 9 P Sperry Drilling Services Database: Sperry EDM .11 Local Co-ordinate Reference: Well Plan 1J-178 (Q3 Phase 2) -Slot 1J-178 Company: ConocoPhillips Alaska, Inc. TVD Reference: Doyon 15 RKB @ 121.OOft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 RKB @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-178 (Q3 Phase 2) Survey Calculation Method: (( Minimum Curvature Wellbore: 1 J-178 Design: 1J-178 (wp03) Planned Survey 1J-178 (wn03) Map Map MD Incl Azirnuth TVD (ft) TVDSS +NI-S +E~_yy Northing Easting DLSEV Vert Section (ft) (°) (°) (ftl (ft) (ft) (ft) (ft) (°I100ft) (ft1 12,735.93 90.63 179.13 3,290.80 3169.80 -9,724.04 -4,385.88 5,935,702.00 554,451.00 0.00 9,724.04 1J-178 MB_B_T4 (5/22/07) 12,773.46 91.01 179.14 3,290.26 3169.26 -9,761.57 -4,385.31 5,935,664.48 554,451.86 1.00 9,761.57 12,800.00 91.01 179.14 3,289.80 3168.80 -9,788.10 -4,384.91 5,935,637.96 554,452.47 0.00 9,788.10 12,900.00 91.01 179.14 3,288.04 3167.04 -9,888.07 -4,383.40 5,935,538.01 554,454.76 0.00 9,888.07 13,000.00 91.01 179.14 3,286.29 3165.29 -9,988.04 -4,381.89 5,935,438.06 554,457.04 0.00 9,988.04 13,100.00 91.01 179.14 3,284.54 3163.54 -10,088.02 -4,380.39 5,935,338.11 554,459.33 0.00 10,088.02 13,200.00 91.01 179.14 3,282.78 3161.78 -10,187.99 -4,378.88 5,935,238.16 554,461.62 0.00 10,187.99 13,300.00 91.01 179.14 3,281.03 3160.03 -10,287.96 -4,377.37 5,935,138.21 554,463.91 0.00 10,287.96 13,400.00 91.01 179.14 3,279.27 3158.27 -10,387.94 -4,375.86 5,935,038.26 554,466.20 0.00 10,387.94 13,500.00 91.01 179.14 3,277.52 3156.52 -10,487.91 -4,374.35 5,934,938.32 554,468.49 0.00 10,487.91 13,600.00 91.01 179.14 3,275.76 3154.76 -10,587.88 -4,372.84 5,934,838.37 554,470.77 0.00 10,587.88 13,700.00 91.01 179.14 3,274.01 3153.01 -10,687.86 -4,371.33 5,934,738.42 554,473.06 0.00 .10,687.86 13,800.00 91.01 179.14 3,272.25 3151.25 -10,787.83 -4,369.83 5,934,638.47 554,475.35 0.00 10,787.83 13,900.00 91.01 179.14 3,270.50 3149.50 ' -10,887.80 -4,368.32 5,934,538.52 554,477.64 0.00 10,887.80'. 14,000.00 91.01 179.14 3,268.75 3147.75 -10,987.78 -4,366.81 5,934,438.57 554,479.93 0.00 10,987.78 14,100.00 91.01 179.14 3,266.99 3145.99 -11,087.75 -4,365.30 5,934,338.62 554,482.22 0.00 11,087.75 14,200.00 91.01 179.14 3,265.24 3144.24 -11,187.72 -4,363.79 5,934,238.67 554,484.50 0.00 11,187.72' 14,300.00 91.01 179.14 3,263.48 3142.48 -11,287.70 -4,362.28 5,934,138.73 554,486.79 0.00 11,287.70 14,400.00 91.01 179.14 3,261.73 3140.73 -11,387.67 -4,360.78 5,934,038.78 554,489.08 0.00 11,387.67 14,435.79 91.01 179.14 3,261.10 3140.10 -11,423.45 -4,360.24 5,934,003.00 554,489.90 0.00 11,423.45 1J-178 MB_B TS (5/2 2107) 14,500.00 90.36 179.14 3,260.33 3139.33 -11,487.65 -4,359.27 5,933,938.82 554,491.37 1.00 11,487.65 14,600.00 89.36 179.14 3,260.57 3139.57 -11,587.63 -4,357.76 5,933,838.86 554,493.65 1.00 11,587.63 14,615.57 89.21 179.14 3,260.77 3139.77 -11,603.20 -4,357.53 5,933,823.30 554,494.01 1.00 11,603.20 14,700.00 89.21 179.14 3,261.93 3140.93 -11,687.61 -4,356.26 5,933,738.90 554,495.93 0.00 11,687.61 14,800.00 89.21 179.14 3,263.32 3142.32 -11,787.59 -4,354.76 5,933,638.95 554,498.21 0.00 11,787.59 14,900.00 89.21 179.14 3,264.70 3143.70 -11,887.57 -4,353.26 5,933,539.00 554,500.49 0.00 11,887.57.. 15,000.00 89.21 179.14 3,266.08 3145.08 -11,987.55 -4,351.76 5,933,439.04 554,502.77 0.00 11,987.55 15,100.00 89.21 179.14 3,267.47 3146.47 -12,087.53 -4,350.26 5,933,339.09 554,505.05 0.00 12,087.53 15,200.00 89.21 179.14 3,268.85 3147.85 -12,187.51 -4,348.76 5,933,239.13 554,507.33 0.00 12,187.51 15,300.00 89.21 179.14 3,270.23 3149.23 -12,287.49 -4,347.26 5,933,139.18 554,509.61 0.00 12,287.49 15,400.00 89.21 179.14 3,271.62 3150.62 -12,387.47 -4,345.76 5,933,039.22 554,511.89 0.00 12,387.47 15,500.00 89.21 179.14 3,273.00 3152.00 -12,487.45 -4,344.26 5,932,939.27 554,514.17 0.00 12,487.45 15,536.28 89.21 179.14 3,273.50 3152.50 -12,523.72 -4,343.72 5,932,903.00 554,515.00 0.00 12,523.72 1J-17$ MB_B_T6 (5/22/07) 15,585.75 89.70 179.14 3,273.97 3152.97 -12,573.18 -4,342.98 5,932,853.56 554,516.13 1.00 12,573.18 15,600.00 89.70 179.14 3,274.04 3153.04 -12,587.43 -4,342.76 5,932,839.31 554,516.45 0.00 12,587.43 15,700.00 89.70 179.14 3,274.56 3153.56 -12,687.42 -4,341.27 5,932,739.34 554,518.73 0.00 12,687.42 15,800.00 89.70 179.14 3,275.08 3154.08 -12,787.40 -4,339.77 5,932,639.38 554,521.01 0.00 12,787.40 15,900.00 89.70 179.14 3,275.60 3154.60 -12,887.39 -4,338.27 5,932,539.42 554,523.29 0.00 12,887.39 16,000.00 89.70 179.14 3,276.12 3155.12 -12,987.38 -4,336.77 5,932,439.46 554,525.56 0.00 12,987.38 16,100.00 89.70 179.14 3,276.64 3155.64 -13,087.37 -4,335.27 5,932,339.49 554,527.84 0.00 13,087.37 16,200.00 89.70 179.14 3,277.16 3156.16 -13,187.35 -4,333.78 .5,932,239.53 554,530.12 0.00 13,187.35 16,300.00 89.70 179.14 3,277.68 3156.68 -13,287.34 -4,332.28 5,932,139.57 554,532.40 0.00 13,287.34 16,400.00 89.70 179.14 3,278.20 3157.20 -13,387.33 -4,330.78 5,932,039.60 554,534.67 0.00 13,387.33 16,500.00 89.70 179.14 3,278.72 3157.72 -13,487.32 -4,329.28 5,931,939.64 554,536.95 0.00 13,487.32 8/?J2007 11:37:23AM Page 8 of 11 COMPASS 2003.11 Build 48 • ConocoPhiilips Alaska Halliburton Company Compass Proposal Report -Geographic • HALLIBURTON Sperry Drilling S®rvices Database: Sperry EDM .11 Local Co-ordinate Reference: Well Plan 1J-178 (Q3 Phase 2) -Slot 1J-178 Company: ConocoPhillips Alaska, Inc. ND Reference: Doyon 15 RKB @ 121.OOft (Doyon 15 (40+81)) Project Kuparuk River Unit MD Reference: Doyon 15 RKB @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True 'I Well: Plan 1J-178 (Q3 Phase 2) Survey Calculation Method: :Minimum Curvature 1 Wellbore: 1 J-178 Design: 1J-178 (wp03) Geologic Targets 1J-178 TVD NDSS Target Name +N/-S +E/-W Northing Easting (ft) (ft) -Shape ft ft (ft) (ft) 3,294.90 1J-178 MB_B_Heel (5/22/07) -5,524.01 -4,449.12 5,939,901.00 554,355.00 - Polygon Point 1 0.00 0.00 5,939,901.00 554,355.00 Point2 -1,300.32 19.66 5,938,601.00 554,384.80 3,303.10 1J-178 MB_B_T1 (5/22/07) -6,824.33 -4,429.46 5,938,601.00 554,384.80 - Polygon Point 1 0.00 0.00 5,938,601.00 554,384.80 Point 2 -699.17 10.55 5,937,902.00 554,400.80 3,211.30 1J-178 MB_D_Top (05/22/07) -5,524.01 -4,449.12 5,939,901.00 554,355.00 - Point 3,261.10 1J-178 MB_B_T5 (5/22/07) -11,423.45 -4,360.24 5,934,003.00 554,489.90 - Polygon Point 1 0.00 0.00 5,934,003.00 554,489.90 Point 2 -1,100.27 16.52 5,932,903.00 554,515.00 3,290.80 1J-178 MB_B_T4 (5/22/07) -9,724.04 -4,385.88 5,935,702.00 554,451.00 - Polygon Point 1 0.00 0.00 5,935,702.00 554,451.00, Point 2 -1,699.42 ` 25.64 5,934,003.00 554,489.90 3,281.70 1J-178 MB_B_Toe (5/22/07) -14,060.10 -4,320.70 5,931,367.00 554,550.00 - Point 3,298.70 1J-178 MB_B_T2 (5/22107) -7,523.50 -4,418.91 5,937,902.00 554,400.80 - Polygon Point 1 0.00 0.00 5,937,902.00 554,400.80 Point 2 -900.22 13.38 5,937,002.00 554,421.20 3,273.50 1J-178 MB_B_T6 (5122/07) -12,523.72 -4,343.72 5,932,903.00 554,515.00 - Polygon Point 1 0.00 0.00 5,932,903.00 554,515.00 Point 2 -1,536.37 23.02 5,931,367.00 554,550.00 3,304.20 1J-178 MB_B_T3 (5/22107) -8,423.72 -4,405.54 5,937,002.00 554,421.20 - Polygon Point 1 0.00 0.00 5,937,002.00 554,421.20 Point 2 -1,300.32 19.66 5,935,702.00 554,451.00 Prognosed Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) (") (~~> 3,647.68 2,200.00 13-3/8 16 9,135.02 3,288.61 9-5/8 12-1 t4 17,072.84 3,281.70 5-1 /2 8-1/2 8/2/2007 11:37:23AM Page 10 of 11 COMPASS 2003.11 Build 48 • • ~' Halliburton Company HAI~LIBURTON COIlOCO~'11~I1~35 Compass Proposal Report -Geographic glas{~ Sperry Drilling S®rvi~es Datahase: Sperry EDM .11 Local Co-ordinate Reference: ~^/eII Plan 1J-178{Q3 Phase 2) -Slot 1J-178 Company: ConocoPhillips Alaska, Ina TVD Reference: Doyon 15 RKB @ 121.OOft (Doyon 15 (40+81)) Project: I<uparuk River Unit MD Reference: Doyon 15 RKB @ 121.OOft (Doyon 15 (40+81)) Site: I<uparuk 1J Pad North Reference: True Well: Plan 1J-178 (Q3 Phase 2) Survey Calculation Method: P,4inimum Curvature Wellbore: IJ-178 Design: iJ-178 (wp03) Planned Survey 1J-178 (wp03) Map Map MD Inc! Azimuth ND (ft) NDSS +N/-S +E/-W Northing Easting DLSEV Vert Section (ft) (~) (') (ft) (ft) (ft) (ft) (ft) (°1100ft) (ft) 16,600.00 89.70 179.14 3,279.24 3158.24 -13,587.30 -4,327.79 5,931,839.68 554,539.23 0.00 13,587.30 16,700.00 89.70 179.14 3,279.76 3158.76 -13,687.29 -4,326.29 5,931,739.71 554,541.51 0.00 13,687.29 16,800.00 89.70 179.14 3,280.28 3159.28 -13,787.28 -4,324.79 5,931,639.75 554,543.79 0.00 13,787.28 16,900.00 89.70 179.14 3,280.80 3159.80 -13,887.27 -4,323.29 5,931,539.79 554,546.06 0.00 13,887.27 17,000.00 89.70 179.14 3,281.32 3160.32 -13,987.25 -4,321.79 5,931,439.82 554,548.34 0.00 13,987.25 17,072.85 l 89.70 179.14 3,281.70 ~ 3160.70 -14,060.10 -4,320.70 5,931,367.00 554,550.00 0.00 14,060.10 BHL @ 17073' MD, 3282' TVD: 1855' FNL, 1507' FEL - Sec15-T10N-R10E - 5 1/2" - 1J-178 MB_B_Toe ( 5!22/07) ~ 8/2/2007 11:37:23AM Page 9 of 11 COMPASS 2003.11 Build 48 ~GI~L • • Halliburton Company ConoeoPhiilips Compass Proposal Report -Geographic Alaska HALLIE3URTON Sperry Drilling Services Database: ,Sperry EDM .11 Local Co-ordinate Reference: V':~ell Plan 1J-178 (Q3 Phase 2) -Slot 1J-178 Company: ConocoPhillips Alaska, Inc. ND Reference: Doyon 15 RKB @ 121.OOft (Doyon 15 (40+81)) Project: Kuparuk River Unit MD Reference: Doyon 15 RKB @ 121.OOft (Doyon 15 (40+81)) Site: Kuparuk 1J Pad North Reference: True Well: Plan 1J-178 (Q3 Phase 2) Survey Calculation Method: fvlinimum Curvature Wellbore: 1J-178 Design: 1J-178 (wp03) Prognosed Formation Intersection Points Measured Depth Inclination Azimuth ND TVDSS +N/-E (ft) +E/-W (ft) (ftl (°) (°) (ft) (ft) Name 1,747.83 55.91 222.00 1,536.20 -469.83 -423.04 Pfrost 1,953.78 64.15 222.00 1,638.99 -602.31 -542.32 T3 2,827.11 71.00 222.00 1,932.85 -1,213.21 -1,092.38 K15 3,462.22 71.00 222.00 2,139.62 -1,659.47 -1,494.19 T3+550 6,546.57 78.08 222.26 2,810.88 -3,887.00 -3,516.57 Ugnu C 6,854.92 78.08 222.26 2,874.57 -4,110.29 -3,719.47 Ugnu B 7,152.42 78.08 222.26 2,936.02 -4,325.73 -3,915.22 Ugnu A 7,841.46 78.13 204.45 3,078.91 -4,869.31 -4,307.72 K 13 8,529.21 80.00 180.00 3,211.29 -5,523.96 -4,449.12 W Sak D 8,798.33 82.07 180.00 3,256.79 -5,789.19 -4,449.12 W Sak C 9,090.44 85.00 180.00 3,284.73 -6,079.94 -4,449.12 W Sak B Pian Annotations Measured Vertical Local Coor dinates Depth Depth +N/-S +E/-W Comment lft) tft) (ft) (ft) 40.00 40.00 0.00 0.00 SHL: 1647' FSL, 2452' FEL - Sec35-T11N-R10E 7,143.00 2,934.07 -4,318.91 -3,909.02 Begin Pump Tangent 78° INC @ 7143' MD, 2934' TVD 7,343.00 2,975.38 -4,463.74 -4,040.62 End Pump Tangent @ 7343' MD, 2975' TVD 9,135.02 3,288.61 -6,124.34 -4,449.12 9 5/8" Casing Q 9135' MD, 3289' TVD: 801' FSL, 1627' FEL - Sec03-T10N-R' 12,517.23 3,293.20 -9,505.38 -4,389.19 PA Boundary @ 12517' MD, 3293' TVD: 2580' FNL, 1499' FEL - Sec10-T10N- 17,072.84 3,281.70 -14,060.08 -4,320.70 BHL @ 17073' MD, 3282' TVD: 1855' FNL, 1507' FEL - Sec15-T10N-R10E 8/2/2007 11:37:23AM Page 11 of 11 ORIGINAL COMPASS 2003.11 Build 48 • ConocoPhillips Alaska Plan: 1 J-178 (wp03) Sperry Drilling Services Anticollision Summary 03 August, 2007 ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan 1J-178 (Q3 Phase 2) 1 J-178 Local Coordinate Origin: entered on Well Plan 1J-178 (03 Phase 2) -Slot 1J Viewing Datum: Doyon 15 RKB @ 121.OOft (Doyon 15 (40+81)) TVDs to System: N North Reference: True Unit System: API - US Survey Feet HAL.LIBIJRTAN Sperry Drilling 8®rvices nR161N4L SURVEY PROGRAM Uate: 2007-08-02700:00:00 Validated: Yes Version: Depth FromDepth To Survey/Plan Tool 40.00 1000.00 IJ-178 (wp03) CSGYRO-SS 1000.0017072.58 IJ-178 (wp03) MWD+IFR-Ali-CAZ-SC 1 J-168 1J-176 (wp05) \ 1J-174 (wp09) _ _ _ _~ ,~ ~I z7o 1J-166 !o 180 _ WSP-11 so _ 1J-133 1J-135 1J-136 Traveling Cylinder Azimuth (TFO+AZI) (°~ vs Centre to Centre Separation X200 ft/iu~ NAD 27 ASP Zone 4 : WELL DETAILS: Plan 1J-178 (03 Phase 2) Ground Level: 81.00 +N/-S +FJ-W Northing Easting Latittude Longitude Slot 0.00 0.00 5945459.03 558760.45 70°15'41.73N 149°31'29.97W 1J-176 REFERENCEINFORMATION Co-ordinate (N/E) Reference: Well Plan 1J-178 (Q3 Phase 2) -Slot 1J-178, True North Vertical (TVD) Reference: Doyon 15 RKB ~ 121.OOft (Doyon 15 (40+81)) Section (VS) Reference: Slot - 1J-178(O.OON, O.OOE) Measured Depth Reference: Doyon 15 RKB @ 121.OOtt (Doyon 15 (40+81)) Calculation Method: Minimum Curvature COMPANY DETAILS: ConocoPhillips Alaska, Inc. Engineering Calculation Method: Minimum Curvature Error System: ISCWSA Scan Method: Trav. Cylinder North Error Surtace: Elliptical Conic Warning Method: Rules Based WSP-07 1J-127 II 1 \ ~ WSP-08 I ( 1J-122 (~ = ,WSP-09 From Colour To MD 40 250 250 500 500 750 750 1000 1000 1250 1250 1500 1500 1750 1750 2000 2000 2500 2500 3000 3000 4000 4000 5000 5000 6000 6000 7750 7750 8000 8000 8250 8250 8500 8500 17000 ANTI-COLLISION SETTINGS Interpolation Method: MD Interval: SOStations Depth Range From: 40.00 To 17073.41 Maximum Range:1903.34143926331 Reference: Plan: 1J-178 (wp03) 1J-176 (wp05) ~~ ~ 1801 1J-180 Travelling Cylinder Azimuth (TFO+AZd) ~°) vs Centre to Centre Separafion (30 ft/inJ B 8520.2] 8000 180.00 3211]0 -552401 )449.12 3.50 -9167 9 BJ292J 8000 1&1.00 324603 -SJ2098 -4449 t2 0.00 000 1}178 MB_QTop (O:il22N7) 10 889593 8500 180.00 326].)8 -3866.16 -4449.12 3.00 000 11 9105.02 85 00 180.00 3286 00 -6094.45 4149.12 0.00 12 9135.02 85.00 180.00 328861 -612434 -4449.12 000 0.00 000 13 9270.67 8]97 1]545 32%.94 -625956 -4443.)3 4.00 -SJ.00 id 9309.59 BT97 175 d5 32%32 -62%.35 -414065 0.00 15 9410.]8 89.61 1)9.14 3300A3 -63%.39 -4435.8) 4.00 0.00 6565 i6 98%.JB 68.64 1]9.14 3303.10 EB24.33 4429.46 0.00 17 %1199 90.40 1]9.14 3303.0] 6900.53 -442631 1.00 000 000 1}1]8 MB_B_Ti IS%2L0]) 181053503 %.40 1]9.14 32%.]0]52350 -M18.91 0.00 0.00 1J-1 ]6 MB_B_T2 (522)01) 1910813.)0 89.62 1]9.15 329869 -]602.15 -441 JJ4 100 201143539 8962 1)9.15 3304.20 -841372 -4405.54 000 1]90) 000 1}178 MB_B T3 (Y22M]) 11 1153983 90.63 1]9.13 330390 -8525.15 -M0401 100 22 12]3593 90.63 1]9.13 3390.80 -9]2001 -0385.88 0.00 A% 0.00 1}178 MB_B_T4 (5'2210]) 2312]]]46 91.01 1)9.14 3290.26 -9]615] -1385.31 1.00 2d 14435.)9 9101 1]9.14 3261.10-11423.45 -1360.21 0.00 0.31 0.00 1J-178 MB_B_TS (5'32)07) 2514615.5) 89.21 1]9.14 3260.]] -11603.20 -435)53 100 26 15536.28 89.21 1]9.14 32]350-12523]2 -4343.Y2 000 1]985 000 1}1]8 MB B_T6 (5122/07) 2] 15585.)5 89.]0 1]9.14 31]397 -125)3.16 -434298 100 28170]2.85 89.10 1]9.14 3281.]0-14060.10 -4320.]0 000 0.1] 0.00 1J-178 MB_B_T°e (5122/0]) SECTION OETRILs s« Mo in< Bzi rvo +ws +Er-w oLe9 TF.c° vs°~ T.r9°1 i mao °ao °a0 4o ao aa0 °a0 a.ao °ao z 3o0.ao 0.00 o.ao 300.00 000 000 000 °a° 3 500.00 6.00 222.00 4%.63 -J>e -700 300 21200 n2s.a6 n.ao 2zz.oo 17o4.zs 7196s 64a.n ago aoa 5 364)60 ]100 22100 2200.00 -1)89]8 -161153 000 000 6 385008 ]BOB 222.26 225392 -1934 J6 -1]4131 3.50 206 ] 130.168 ]808 22128 29)553 -4464.23 -40410] 000 000 C Hallibu o rton m a P n Y Anticollision Report Company: ConocoPhillips Alaska Inc. Date: 8/3/2007 Time: 19.25:51 Yage: 1 Field: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Co-ordinate (NE) Reference: Well: Plan 1J-178, True North ReferenceVl'ell: Plan 1J-178 Verfical(TVD)Referencc Doyon 15 (40+81) 12 1.0 Referenceyy'ellpath: PIan:1J-178 Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference Reference: Plan: 1 J-178 (wp03) & NOT PLANNED PR Interpolation Method: MD IntervaL• 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 40.00 to 17072.58 ft Scan Method: Trav Cylinder North Maximum Radius: 1903.26 ft Error Surface: Ellipse + Casing Casing Points MD TV D Diameter Hole Size Name ft ft in in 3831.60. 2250.00 13.375 16.000 13 3/8" 9134.74 3288.61 9.625 12.250 9 5/8" 17072.57 3281.70 5.500 8.500 51/2" Plan: 1J-178 (wp03) Date Composed: 5/22/2007 Version: 5 Principal: Yes Tied-to : From Well Ref. Point Summary - - - - - _ - _ - - <______________________ Offset Wellpath ----- -----------------> Reference Offset Ctr-Ctr No-Go Allo~~able Site Nell ~Vcllpath D1D ~4D Distance ?area De~~iation Warning ft ft ft ft ft Kuparuk 1J Pad 1J-127 1J-127 V7 321.92 325.00 158.81 6.03 152.78 Pass: Major Risk Kuparuk 1J Pad 1J-127 1J-127L1 V3 321.92 325.00 158.81 5.90 152.91 Pass: Major Risk Kuparuk 1J Pad 1J-127 1J-127L1P61 V3 321.92 325.00 158.81 6.14 152.67 Pass: Major Risk Kuparuk 1J Pad 1J-127 1J-127L2 V2 321.92 325.00 158.81 5.90 152.91 Pass: Major Risk Kuparuk 1J Pad 1J-127 1J-127PB1 V2 321.92 325.00 158.81 6.14 152.67 Pass: Major Risk Kuparuk 1J Pad 1J-127 1J-127P62 V2 321.92 325.00 158.81 6.14 152.67 Pass: Major Risk Kuparuk 1J Pad 1J-133 1J-133 V3 286.99 275.00 158.31 5.65 152.66 Pass: Major Risk , Kuparuk 1J Pad 1J-133 Plan 1J-133 L1 V4 40.00 40.00 158.05 No Offset Stations Kuparuk 1J Pad 1J-133 Plan 1J-133 V1 40.00 40.00 158.05 No Offset Stations Kuparuk 1J Pad 1J-135 1J-135 V2 371.01 375.00 176.90 6.92 169.98 Pass: Major Risk Kuparuk 1 J Pad 1 J-135 1 J-135L1 V3 371.01 375.00 176.90 6.55 170.35 Pass: Major Risk Kuparuk 1J Pad 1J-135 1J-135L1PB1 V4 371.01 375.00 176.90 6.55 170.35 Pass: Major Risk Kuparuk 1J Pad 1J-136 1J-136 V2 367.56 375.00 190.10 6.52 183.58 Pass: Major Risk Kuparuk 1 J Pad 1 J-136 1 J-136L1 V3 367.56 375.00 190.10 6.36. 183.73 Pass: Major Risk Kuparuk 1J Pad 1J-136 1J-136L1PB1 V3 367.56 375.00 190.10 6.52 183.58 Pass: Major Risk Kuparuk 1J Pad 1J-136 1J-136L1PB2 V4 367.56 375.00 190.10 6.52 183.58 Pass: Major Risk Kuparuk 1J Pad 1J-136 1J-136PB1 V5 367.56 375.00 190.10 6.52 183.58 Pass: Major Risk Kuparuk 1J Pad 1J-137 1J-137 V2 311.74 300.00 203.28 6.18 .197.10 Pass: Major Risk Kuparuk 1J Pad 1J-137 1J-137L1 V2 311.74 300.00 203.28 6.18 197.10 Pass: Major Risk Kuparuk 1J Pad 1J-137 1J-137L1P61 V2 311.74 300.00 203.28 6.18 197.10. Pass: Major Risk Kuparuk 1J Pad 1J-137 1J-137L1PB2 V2 311.74 300.00 203.28 6.18 197.10 Pass: Major Risk Kuparuk 1J Pad 1J-14 1J-14 V13 726.79 700.00 190.62 10.54 180.08 Pass: Major Risk Kuparuk 1J Pad 1J-156 1J-156 V4 310.55 300.00 460.49 5.90 454.58 Pass: Major Risk Kuparuk 1J Pad 1J-156 1J-156L1 V2 310.55 300.00 460.49 5.77 454.71 Pass: Major Risk Kuparuk 1J Pad 1 J-156 1 J-156L1 P61 V4 310.55 300.00 460.49 6.01 454.47 Pass: Major Risk Kuparuk 1J Pad 1J-156 1J-156L2 V2 310.55 300.00 460.49 5.77 454.71 Pass: Major Risk Kuparuk 1J Pad 1J-158 1J-158 V6 8428.91 12268.00 253.89 1 83.04 70.84 Pass: Major Risk Kuparuk 1J Pad 1 J-158 1 J-158L1 V3 8421.04 12261.00 262.94 1 89.58 73.36 Pass: Major Risk Kuparuk 1J Pad 1J-166 1J-166 V6 334.54 325.00 239.37 5.92 233.44 Pass: Major Risk Kuparuk 1J Pad 1J-166 1J-166L1 V4 334.54 325.00 239.37 5.79 233.57 Pass: Major Risk Kuparuk 1 J Pad 1 J-166 1 J-166L1 PB1 V4 334.54 325.00 239.37 5.79 233.57 Pass: Major Risk Kuparuk 1J Pad 1J-166 1J-166L2 V2 334.54 325.00 239.37 5.79 233.57 Pass: Major Risk - Kuparuk 1J Pad 1J-166 1J-166L2PB1 V2 334.54 325.00 239.37 5.79 233.57 Pass: Major Risk Kuparuk 1 J Pad 1 J-168 1 J-168 V6 405.84 400.00 200.06 7.57 192.49 Pass: Major Risk Kuparuk 1J Pad 1J-168 1J-168L1 V4 405.84 400.00 200.06 7.44 192.62 Pass: Major Risk Kuparuk 1J Pad 1J-168 1J-168L2 V3 405.84 400.00 200.06 7.44 192.62 Pass: Major Risk Kuparuk 1J Pad 1J-168 1J-168L2PB1 V2 405.84 400.00 200.06 7.44 192.62 Pass: Major Risk Kuparuk 1J Pad 1J-170 1J-170 V3 286.99 275.00 161.52 5.65 .155.87 Pass: Major Risk Kuparuk 1J Pad 1J-170 iJ-170L1 V2 ~ 286.99 275.00 161.52 5.52 156.00 Pass: Major Risk Kuparuk 1J Pad 1J-170 1J-170L2 V2 286.99 275.00 161.52 5.52 156.00 Pass: Major Risk Kuparuk 1J Pad 1J-170 1J-170PB1 V2 286:99 275.00 161.52 5.65 155.87 Pass: Major Risk Kuparuk 1J Pad 1J-170 1J-170P62 V2 286.99 275.00 161.52 5.65 155.87 Pass: Major Risk Kuparuk 1J Pad 1J-180 1J-180 V4 274.59 275.00 41.15 5.17 35.98 Pass: Major Risk Kuparuk 1J Pad 1J-180 1J-180L1 V3 274.59 275.00 41.15 5.02 36.14 Pass: Major Risk Kuparuk 1J Pad 1J-180 1J-180L1P61 V1 274.59 275.00 41.15 5.17 35.98 Pass: Major Risk Kuparuk 1J Pad 1J-180 1J-180P61 V1 249.59 250.00 40.67 No Offset Errors ORIGINAL ~alliburton Com an P Y Anticollision Report Company: ConocoPhillips Alaska Inc. Date: 8/3/2007 Time: 19:25:51 Page: 2 Field: Kuparuk River Unit Reference Site: Kuparuk 1J Pad Co-ordinate (NE) Reference: Well: Plan 1J-178, Tr ue North Reference ~~"ell: Plan 1J-178 Vertical (TVD) Reference: Doyon 15 (40+81) 12 1.0 Reference~tiellpath: PIan:1J-178 Db: Oracle Summary <---------- -- ------- Offset Wellpath ------ - --------------> Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpath ~1D MD Distance Area Deviation Warning ft ft ft ft ft Kuparuk 1J Pad 1J-182 1J-182 V3 886.64 875.00 92.69 16.76 75.93 Pass: Major Risk Kuparuk 1J Pad 1J-182 1J-182L1 V8 886.64 875.00 92.69 16.61 76.09 Pass: Major Risk Kuparuk 1J Pad 1J-182 1J-182L1PB1 V5 886.64 875.00 92.69 16.61 76.09 Pass: Major Risk Kuparuk 1J Pad 1J-184 1J-184 V6 649.51 625.00 118.34 9.64 108.70 Pass: Major Risk Kuparuk 1J Pad 1J-184 1J-184L1 V6 649.51 625.00 118.34 9.48 108.86 Pass: Major Risk Kuparuk 1J Pad Plan 1J-123 Plan 1J-123 Kuparuk Pr 40.00 40.00 202.03 No Offset Stations Kuparuk 1J Pad Plan 1J-124 Plan 1J-124 L1 V1 Plan 322.74 325.00 188.55 6.39 182.16 Pass: Major Risk Kuparuk 1J Pad Plan 1J-124 Plan 1J-124 V3 Plan: 1 322.74 325.00 188.55 6.55 182.00 Pass: Major Risk Kuparuk 1J Pad Plan 1J-129 Plan 1J-129 V3 40.00 40.00 147.21 No Offset Stations Kuparuk 1J Pad Plan 1J-130 Plan 1J-130 V3 40.00 40.00 145.84 No Offset Stations Kuparuk 1J Pad Plan 1J-132 1J-132 V3 40.00 40.00 151.31 No Offset Stations Kuparuk 1J Pad Pian 1J-173 1J-73 Kuparuk Producer 40.00 40.00 100.16 No Offset Stations Kuparuk 1J Pad Plan 1J-174 Plan: 1J-174 V2 Plan: 691.10 700.00 77.75 11.92 65.83 Pass: Major Risk Kuparuk 1J Pad Plan 1J-174 Plan: 1J-174L1 V1 Plan 691.10 700.00 77.75 11.92 65.83 Pass: Major Risk Kuparuk 1J Pad Plan 1J-176 Plan 1J-176 L1 V1 Plan 988.82 1000.00 49.40 18.42 30.98 Pass: Major Risk Kuparuk 1J Pad Plan 1J-176 Plan 1J-176 V1 Plan: 1 988.82 1000.00 49.40 18.42 30.98 Pass: Major Risk Kuparuk 1J Pad Plan 1J-178 Plan: 1J-178 L1 V3 Pla 7350.00 7350.00 0.00 0.00 0.00 FAIL: No Errors Kuparuk 1J Pad Plan 1J-Q14 (BM) 1J-014 B Lateral V1 41.00 28.00 216.72 No Offset Stations Kuparuk 1J Pad Plan 1J-015(60) 1J-Q15 D Lateral VO PI 288.00 275.00 247.92 No Offset Errors Kuparuk 1J Pad Rig: 1J-122 Plan 1J-122 L1 V1 Plan 310.80 300.00 216.61 6.43 210.18 Pass: Major Risk Kuparuk 1J Pad Rig: 1J-122 Plan 1J-122 L2 V1 Plan 310.80 300.00 216.61 6.43 210.18 Pass: Major Risk Kuparuk 1J Pad Rig: 1J-122 Plan 1J-122 V4 Plan: 1 310.80 300.00 216.61 6.59 210.03 Pass: Major Risk Kuparuk 1J Pad Rig: 1J-122 Rig 1J-122 L1 VO 211.99 200.00 218.20 4.41 213.79 Pass: Major Risk Kuparuk.1J Pad Rig: 1J-122 Rig 1J-122 L2 V0 211.98 200.00 218.25 4.44 213.82 Pass: Major Risk Kuparuk 1J Pad Rig: 1J-122 Rig 1J-122 VO 310.80 300.00 216.65 5.96 210.70 Pass: Major Risk Kuparuk 1J Pad Rig: 1J-122 Rig 1J-122PB1 V3 310.80 300.00 216.65 5.96 210.70 Pass: Major Risk Kuparuk 1J Pad WSP-07 WSP-07 V2 344.25 350.00 206.03 9.15 196.88 Pass: Major Risk Kuparuk 1J Pad WSP-O8 WSP-08 V3 358.72 350.00 185.12 11.22 173.90 Pass: Major Risk Kuparuk 1J Pad WSP-09 WSP-09 V2 345.70 350.00 181.85 7.99 173.86 Pass: Major Risk Kuparuk 1J Pad WSP-10 WSP-10 V2 362.53 350.00 197.60 7.96 189.64 Pass: Major Risk Kuparuk 1J Pad WSP-11 WSP-11 V2 395.48 400.00 228.70 8.35 220.35 Pass: Major Risk n~~lpl4l. `` J~ ,..~ ~.,._.' ConocoPhifiips Alaska ConocoPhillips Alaska, Inc. Kuparuk River Unit Kuparuk 1J Pad Plan: 1J-178 L1 (wp03) 1/4 Mile Pool Scan Sperry Drilling Services August 3, 2007 V i~ HALLIBIJRTON Drilling and Formation Evaluation • HALLIBURTON Project: Kuparuk River Unit ~WELLDETAILS: PIan1J-17a(Q3Phase2) Site: Kuparuk 1J Pad Ground Level: 81.00 Sperry Orillir-g Services Well: Plan 1J-178 Q3 Phase 2 +N/-S +E/-W Northing Easting Latittude Longitude Slot ( ) 0.00 0.00 5945459.03 558760.45 70°15'41.73N 149°31'29.97W 1J-178 Wellbore: 1 J-178 L1 Plan: 1J-178 L1 (wp03) REFERENCEINFORMATION Co-ortlinate (N/E) Reference: Well Plan 1J-178 (03 Phase 2) -Slot 1 J-178, True North Vertical (TVD) Reference: Doyon 15 RKB (8J 121.OOft (Doyon 15 (40+81)) Section (VS) Reference: Slot- iJ-178(O.OON, O.OOE) Measuretl Deplh Reference: Doyon 15 RKB (~ 12i.00ft (Doyon 15 (40+81)) Calculation Method: Minimum Curvature C O O O N s C 0 .s 0 ORI -10000 -9000 -8000 -7000 -6000 -5000 -4000 -3000 -?UUU -1000 u tuuv wvv ~~~~ Y~JC West(-)/East(+) (2000 ft/in) ~ ConocoPhillips ~sk~ ~ • ao .e/ M M , r '•;. MOON N M ~ ~ (n .- O ~ ~ ch O ZM~u> ~ ao M J ~ _ Q ~ N O M ~ W N~ O ~ ~ p N (,~ 1- M M Op Z ' ~ ~ Q pooo O M ~' m d -7 U ~oo~~ ~ map J N M M O ' ~ ~ ~ O O N i r IOW ~ T M00~ O `~ ~ - _ ` Z ~ N M _ _ _ _ _ N yj o L C ~ D f h C D dad ~ ; ~~n ~ Y Y ~ J J ~ m G~com 2 a.a=~~-~ YYae'--~- ,~,g ~~ O° ~o° .. ci- m c ` h _ J Q~ a ~ g a' o = ' r _.---.. z°j Q.~ ~ ~ a 0 ~ \ a ~ C ~u m 0 O ~ U = a J ~~ i i O . ~ J r r •~Y .-, J ~ Cv0 M ~ ` .-. .- O ~ M O ~ ~- `i \ ` Q co ~ 3 ------_ r ~ cV - ~ 3 v M ~ ~ ti ~ ~ ~ O 3 J 3 `~. -------- ORIGINAL O ~ m ~ ~ ~ r ~ J ~ O i ~ ~ ~ N i ~ J 1 /~ ~ ~ W~ r W ~ J ~ ~ r ~ r .~ r i _. ~ i ~ ice/ ~ ,~ Closest in POOL ~,.m,.~ s'~`oJ ClosestA roach: Reference Well: 1J-178 L1 w 03 Plan Offset Well: 1J-158 L1 Coords. - Coords. - ASP ASP 3-D ctr-ctr Horizontal Subsea Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS ° Distance. Distance Difference De th Incl. An le TRUE Azi. ND E + /W _ 180° Comments Comments De th Incl. An le TRUE Azi. ND E + AN _ 180 L in Distance (287.56 ft) in POOL POOL Min Distance (287.56 ft) in % (8529.27 - 17068.2 POOL (8529.27 - 17068.2 MD) to MD) to 1J-158 L1 1J-178 L1 (wp03) Plan (7442 - 287.56 286.51 24.567467 8529.27 80 180 3090.292 5939900.2 554354.9 5524.029 (7442-12261 MD) 12261 88.84 173.96 3114.86 5940030 554099.4 5392.289 12261 MD) ClosestA roach: Reference Well: 1J-178 L1 w 03 Plan - Offset Well: 1J-180 L1 Coords. - Coords. - ASP ASP 3-D ctr-ctr Horizontal Subsea Meas. Subsea N(+)/S(-) View VS ° Meas. D th An le Incl TRUE Azi Subsea ND N(+)/S(-) E + /W - View VS 180° Comments Distance. Distance Difference De th Incl. An le TRUE Azi. ND E + /W _ 180 Comments e . . P L Min Distance (1177.34 ft) in POOL (8529.27 - 17068.2 POOL Min Distance (1177.34 ft) in MD) to 1 J-180 L1 POOL (8529.27 - 17068.2 MD) to (10047 - 17779.08 1J-178 L1 (wp03) Plan (10047 -! 1177.34 -1175.65 63.136985 15700 89.63 179.14 3082.253 5932733.2 554518.9 12692.09 MD) 14544.71 92.15 178.86 3145.39 5932763.7 555694.2 12631.84 17779.08 MD) ClosestA roach: Reference Well : 1J-17 8 L1 w 03 Plan Offset Well: 1J -156L2 Coords. - _ Coords. - ASP ASP 3-D ctr-ctr Horizontal Subsea Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS ° Distance. Dlstaiace Difference De th Incl. An le TRUE Azi. ND E + /W _ 180° Comments De ih Incl. An le Comments TRUE Azi. ND E + /W - 180 POOL Min Distance I (1338.98 ft) in POOL POOL Min Distance (1338.98 ft) in (8529.27 - 17068.2 POOL (8529.27 - 17068.2 MD) to ~ MD) to 1J-156L2 1J-178 L1 (wp03) Plan (5698 - 1338.98 -1334.2 113.05151 10975 89.73 179.15 3107.891 5937456.5 554410.8 7968.073 (5698-12566 MD) 12566 92.4 185.29 3220.942 5937481.6 555744.8 7953.515 12566 MD) ClosestA roach: Reference Well : 1J-17 8 L1 03 Plan Offset Well: 1J -160 L2 Coords. - Coords. - ASP ASP 3-D ctr-ctr Horizontal Subsea Meas. Subsea N(+)/S(-) View VS t ° C Meas. An le De th Incl Subsea N(+)/S(-) View VS ND E + AN(_) (180° Comments TRUE Azi Distance. Distance Oifferenco De th Incl. An le TRUE Azi. ommen s ) ND E +)/W(- 180 . . P L Min Distance (1864.2 ft) in POOL POOL Min Distance (1864.2 ft) in (8529.27 - 17068.2 POOL (8529.27 - 17068.2 MD) to MD) to 1J-160 L2 1J-178 L1 (wp03) Plan (8387 - 1864.2 1864.08 -20.97116 8529.27 80 180 3090.292 5939900.2 554354.9 5524.029 (8387-13067 MD) 13067 91.88 179.77 3069.321 5939890 552490.8 5519.613 13067 MD) ClosestA roach: Reference Well: 1J-17 8 L1 w 03 Plan Offset Well:. 1J -176 L1 w 05 Coords. - Coords. - ASP ASP 3-D ctr-ctr Horizontal Subsea Meas. Subsea N(+)/S(-) View VS Meas. Subsea N(+)/S(-) View VS ° Distance. Distance Difference Depth Incl. Angle TRUE Azi. ND E(+ /t/y(_) (180° Comments Depth Incl. Angle Comments TRUE Azi. ND E(+)/W - (180 POOL Min Distance (1824.43 ft) in POOL (8529.27 - 17068.2 POOL Min Distance (1824.43 ft) in MD) to 1J-176 L1 POOL (8529.27 - 17068.2 MD) to (wp05) (10347 - 1 J-178 Lt (wp03) Plan (10347 - 1824.43 1823.75 -49.97653 8975 91.55 178.67 3111.509 5939455.9 554364 5968.399 17729.66 MD) 10322 82.88 179.38 3061.53 5939402.7 552541 6045.97 17729.66 MD) POOL Summary.xls 8/3/2007 2:38 PM ~J 1~-178 ~'illing Hazards ~mmary (SEE WELL PLAN AND ATTACHMENTS FOR DETAILED DISCUSSION OF THESE RISKS) Surface Hole 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 ,~,- f Driltreat. Running Sands and Low Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Hole swabbing on trips Moderate Trip speeds, proper hole filling (use of trip sheets , um in out Intermediate Hole Hazard Risk Level Miti ation Strate Intermediate close Low The separation is vertical. Use geologic crossin with 1E-170 control to revent collision. Running Sands and Low Maintain planned mud parameters, Gravels Increase mud weight, use weighted swee s. Gas Hydrates Low Control drill, reduced pump rates, reduced drilling fluid temperatures, additions of Driltreat. Stuck Pipe Low Good hole cleaning, pre-treatment with lost circulation material, stabilized BHA, decreased mud wei ht Abnormal Reservoir Low BOP training and drills, increased mud Pressure wei ht. Lost circulation Low Reduced um rates, mud rheolo , LCM Hole swabbing on trips Moderate , Trip speeds, proper hole filling (use of trip sheets. , um in out Pr~duc_ti~n Hele Hazard Risk Level Miti ation Strate Abnormal Reservoir Pressure Low Stripping drills, shut-in drills, increased mud wei ht. Stuck Pipe Low Good hole cleaning, PWD tools, hole o ener runs, decreased mud wei ht Lost Circulation Low Reduced um rates, mud rheolo , LCM Hole Swabbing on Trips Moderate ~% Trip speeds, proper hole filling (use. of trip sheets , um in out, backreamin n ~ 1J-178 Drilling Hazards Summary ~'°t 9/7/2007 9:49:00 AM CemCADE Preliminary Job Design 13 3/8" Surface Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 15 Location: West Sak Client: ConocoPhillips Alaska, Inc. Revision Dater 9/7/2007 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 265-6336 Mobile: (907) 952-0445 email: mtorrieCslb.com < TOC at Surface Previous Csg. < 20", 91.5# casing at 80' MD < Base of Permafrost at 1,748' MD (1,536' TVD) < Top of Tail at 2,847' MD < 13 3/8", 72.0# casing in 16" OH TD at 3,647 MD (2,200' 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 2,847 MD. Lead Slurry Minimum pump time: 310 min. (pump time plus 120 min.) ARCTICSET Lite @ 10.7 ppg - 4.45 ft3/sk 1.0190 ft3/ft x (80') x 1.00 (no excess) = 81.5 ft3 0.4206 ft3/ft x (1748' - 80') x 3.50 (250% excess) _ 2455.5 ft3 0.4206 ft3/ft x (2847' - 1748') x 1.35 (35% excess) = 624 ft3 81,5 ft3 + 2455.5 ft3+ 624 ft3 = 3161 ft3 3161 ft3 / 4.45 ft3/sk = 710.3. sks Round up to 720 sks Have 320 sks of additional Lead on location for Top Out stage, if necessary. Tail Slurry Minimum pump time: 230 min. (pump time plus 120 min.) DeepCRETE C 12.0 ppg - 2.47 ft3/sk 0.4206 ft3/ft x (3647 - 2847') x 1.35 (35% excess) = 454.2 ft3 0:8315 ft3/ft x 80' (Shoe Joint) = 66.5 ft3 454.2 ft3 + 66.5 ft3 = 520.7 ft3 520.7 ft3/ 2.47 ft3/sk = 210.8 sks Round up to 220 sks BHST = 47`F, Es#imated BHCT = 70~. (BHST calculated using a gradient of 2.6`F/100 ft. below the permafrost) PUMP SCHE-DUCE Pump Rate Stage Stage Time Cumulative Stage Volume Time (bpm) (bbl) (min) (mint CW 100 5 50 10.0 10.0 Drop Bottom Plug 15.0 25.0 MudPUSH II 6 50 8.3 .33.3 Lead Slurry 7 571 81.6 114.9 Tail Slurry 6 97 16.2 131.1 Drop Top Plug 8.0 139.1 Water 5 20 4.0 143.1 Switch to Rig Pum s 5.0 148.1 Displacement 7 488 69.7 2.17.8 Slow Rate 3 20 6.7 224.5 MUD REMOVAL Recommended Mud Properties: 8.8 ppg, Pv < 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 = 20-25 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. ~R!GINAL i t n~ CemCADE Preliminary Job Design 9.6~~" Intermediate Casing Preliminary Job Design based on limited input data. For estimate purposes only. Rig: Doyon 15 Location: West Sak Client: ConocoPhillips Alaska, Ina Revision Date: 9/7/2007 Prepared by: Maureen Torrie Location: Anchorage, AK Phone: (907) 276-1215 Mobile: (907) 952-0445 email: mtorrie@slb:com Previous Csg. < 13 3/8", 72.0# casing at 3,647 MD < Top of Tail at 6,046' MD I t < 9 5/8", 40.0# casing in 12 1/4" OH TD at 9,135' MD (3,288' TVD) Volume Calculations and Cement Systems Volumes are based on 25% excess. Tail slurry is designed for 500' MD above Ugnu C formation - (Ugnu C at 6546' MD, TOC at 6046' MD, 3089' MD annular length). Tail Slurry Minimum thickening time: 280 min. (Pump time plus 120 min.) DeepCRETE @ 12.5 ppg - 2.25 ft3/ft 0.3132 ft3/ft x 3089' x 1.25 (25% excess) = 1209.3 ft3 0.4257 ft3/ft x 80' (Shoe Joint) = 34.1 ft3 1209.3 ft3 + 34.1 ft3 = 1243.4 ft3 1243.4 ft3/ 2.25 ft3/sk = 552.6 sks Round up to 560 sks .BHST = 76~, Estimated BHCT = 60~. (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) (bbll (min) tminl CW 100 5 50 10.0 10.0 Drop Bottom Plug 1.0.0 20.0 MudPUSH I'I 5 50 10.0 30.0 Tail Slurry 5 224 44.8 74.8 Drop Top Plug 10.0 84.8 Water 5 20 4.0 88.8 Switch to Rig Pum s 5.0 93.8 Displacement 7 647 92.4 186.2 Slow Rate 3 20 6.7 192.9 MUD REMOVAL Recommended Mud Properties: 9.8 ppg, Pv < 15, TY < 15. As thin and light as possible to aid in mud removal during cementing. Spacer Properties: 11.0 ppg MudPUSH" II, Pv = 19-22, TY = 22-29 Centralizers: Recommend 1 per joint across zones of interest for proper cement placement. OR161NAL ~~a1y~.I.rr./~~ ~V ~~~ V / ~~~ ~+~ 1 Wellhead 1 Tubing 1 Tree: 13-318" z 4112", 5,000 psi Conocol'hil lips Insulated Conductor: 20" 94# K-55 x 34" 0.312 WT +l- 80' 2007 West Sak Producer with Rotating self-Aligning Multilateral (RAMT^") System Dual lateral Completion 1J-178 HB DLP WP 03 GLM, Camco, 4112" x 1" KBMG, set ~ <67 deg, +l- 2200' MD 13-318" Casing Shce, 68#, L-80, BTC ~ 3647' MD, 2200' TVD racing slang 4112" 12.6x, L-80, IB7M 3.958" ID, 3.83J" Drin 7" X 1-618" RAM Nanper 6.960" Literal Dnn ID 3.688" Malnbon Onn ID Epui~ment Soecifications 7" X 9-518" RAM Junction Malnbore Drift: 3.68" Lateral Dnn: s.eo^ RAM Hanger/Seal Bore Dlvener OD: 8.375" Overall Length of RAM Junction: 38.3 n Seal Bore Diverter Running Tool: FJD RAM Hanger Running Tool: HRD-E 4112" Lateral Entry Module LEM OD: 6.99" Mainlrore Drin wlo Diveners: 3.68" Main[are Drin w/ Isolation Diverter: 2.50" Lateral Drift wl "FB" Diverter: 3.68" OD of Dlverters: 3.68" +l- 7485 MD -Bottom of Motor Centralizer ~Centralift 418 HP KMHFER with FC6000 Pump D-Sand Casing Exit 8/529' MD, 3211' TVD 'D' Sand Lateral / 4112" 11.6a, BTC. L-80 Stoned Dmr 3.662" DB Nlpple X 9-61a" RAM Seal Bon ISBDI whh 3.66" Sal Bon ML Produallon Anehor 4112" 12.Bp IBTM Tuhing 7" X 9-618" MLZXP Llner Nanper Paoker get al +I. 9,630' swbon ReeePtaol• 1.76"ID 8aa1 Assembly 1.76" Seal OD 1.876" ID iira+~ XYG ES Baker Oil Tools m t t IA ^FB"wvener ~~ D1b1Y Ilna 4516' ML ToraoeMaster Packer talletl'n LEMI (1 II tl- LEMI ~_ PoaiUVe LatMir,9 CoNN Intlicates tertect Locrion nap W6naD ON Poi five Localirg CoIIN Orienti,g profile Igrenwlk gkemm.nt r LrY w rat ONe,ter zR Lahrr Isolation luu pert ~mD Upper Beals Seal Bore ter Lelerr laolalien Dive,tx Bnap lN6nap OUt ].6B" 10 PorNve Locrina Gollel Lateral Access W n,bw Ipfe TkmT,u,q gwm,l a' Vo Lalerr laolation Lower heals s spar uBw for nnnmg >na pum (sera inaiae RPM xr Bm<Diverml ng amener8 /-112" Guide Shoe, 8.80" OD 4112" Casing Shoe, 11.6#, L-80 BTCM ~ 17068' MD, 3212' TVD 'B' Sand Lateral 6-112" 16.6N, BTC, L-00 Slotted Dmr ~--/~- 9S18" Casing Shoe, 40.0#, L-80 BTC ~ 9135' MD, 3288' ND, 84 deg inc As Planned 6-112" Eooentnc Guide Shoe 5712" Casing Shoe, 15.5#, L-80 BTCM ~ 17072' MD, 3281' ND • • TRANSMITTAL LETTER CHECKLIST WELL NAME y~-~.-~C r~ ~~~ PTD# ~ ~ '' / ~~ Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well , (If last two digits in permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both welt name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception.. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name. Qf weiD until after ~Compan~Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. SCo~anX Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 7/13/2007 • • ^^ ^: ' ~ o ~ c. , ~ y ~ M' ~ ~ ( N' (6 Q' ' 'S Q ~. ' o: o ~ ~ E. ~3 I . v ~ ai, ~ ~ m' ~ t ~ ~, 3' L, a, ~, 3. ~ c; II ~, o' m ~ a ~: I O y J c Vl' tp//' t p~ N' ~~ t d r M' (/A w o, _~ o, v, ~ = 0 ~ O ~ ~: ~ O. ~ L ~ ~ ~ ~ ~ i j. O p. ~ a N ~ O ~ . y. N ~ y O ~ QJ: ~ L, . ~ . C C. , m O _ O ~ i . O ~ i ~ ~ ~ ~ ~ ~~ , ~ 4 : _~ Oi c. r m' ~, a w ~ ' : O ' ~ . 3 ~: ~: : 3 N: (V V j ~ m• ~ L' N, ~ O' J• ~ N• N• y: _ ~ ~ ~ c: ~, ~ ~ ~ ~ I ~ ~ ~ ~~ c. ~ L. ~, ~ N d. ~ ~ a ~ O, y ! N. X. N. ~, S. W. a I ao 'c Q' a: v o. a ~ ~: n ~ v' ~ I j ~ ~ n y' y 3 , m w' ~ 3' a y. m, m. z ~; H ~ Y. M 3, r v. a n ~ a o o ~ ~ ~: , ~ , . . z: a ~ N. 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To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically , organize this category of information. 1J-178 (1).tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Feb 12 11:54:03 2008 Reel Header Service name .............LISTPE Date . ...................08/02/12 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS writing Library. Tape Header Service name .............LISTPE Date . ...................08/02/12 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS writing Library. Physical EOF Comment Record TAPE HEADER Kuparuk River unit, west sak MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 2 JOB NUMBER: MW-000516050 LOGGING ENGINEER: R. FRENCH OPERATOR WITNESS: F. HERBERT SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD scientific Technical services Scientific Technical Services 1J-178 500292336800 ConocoPhillips Alaska, Inc. Sperry sun 12-FEB-08 MWD RUN 3 MWD RUN 4 MW-000516050 MW-000516050 R. FRENCH B. HENNINGSE F. HERBERT M. THORNTON 35 11N l0E 1647 2452 .00 122.02 81.00 Page 1 ~o~-- ~a ~ ~ ~~~~ U 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1J-178 (1).tapx OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 13.375 3665.0 12.250 13.375 3665.0 8.500 9.625 8980.0 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY - NO DATA ARE PRESENTED. 5. MWD RUNS 2-4 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 (G P). 6. DEPTH SHIFTING OF MWD DATA WAS WAIVED PER E-MAIL, DATED 12/16/04, FROM MIKE WERNER OF CONOCOPHILLIPS ALASKA, INC. TO R. KALISH OF SPERRY DRILLING SERVICES. MWD DATA ARE CONSIDERED PDC. 7. MWD RUNS 1-4 REPRESENT WELL 1J-178 WITH API#: 50-029-23368-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 17083'MD/3263'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (X- SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. File Header Service name... .......STSLIB.001 Service Sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/02/12 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 Page 2 • EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE FET RPD RPM RPS RPX GR ROP 17-178 (1).tapx clipped curves; all bit runs merged. .5000 START DEPTH 3631.0 3631.0 3631.0 3631.0 3631.0 3639.5 3675.0 STOP DEPTH 17033.0 17033.0 17033.0 17033.0 17033.0 17078.5 17083.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD BIT RUN NO MERGE TOP 2 3631.0 3 8226.0 4 8983.0 REMARKS: MERGED MAIN PASS. MERGE BASE 8226.0 8983.0 17083.0 Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Loging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service Order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD FPH 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3631 17083 10357 26905 3631 17083 ROP MWD FPH 0 2782.97 267.795 26805 3675 17083 GR MWD API 19.93 119.68 66.1448 26859 3639.5 17078.5 RPX MWD OHMM 3.67 2000 42.2492 26683 3631 17033 RPS MWD OHMM 0.35 2000 45.179 26683 3631 17033 RPM MWD OHMM 0.06 2000 43.2435 26683 3631 17033 Page 3 i 17-178 (1).tapx RPD MWD OHMM 1.97 2000 45.7365 26683 3631 17033 FET MWD HR 0.11 87.4 0.856025 26683 3631 17033 First Reading For Entire File..........3631 Last Reading For Entire File...........17083 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/12 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.002 Physical EOF File Header service name... .....STSLI6.002 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/12 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 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 RPD 3631.0 8182.5 RPM 3631.0 8182.5 RPS 3631.0 8182.5 RPX 3631.0 8182.5 FET 3631.0 8182.5 GR 3639.5 8190.0 ROP 3675.0 8226.0 LOG HEADER DATA DATE LOGGED: 13-OCT-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8226.0 TOP LOG INTERVAL (FT): 3675.0 BOTTOM LOG INTERVAL (FT): 8226.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 73.0 MAXIMUM ANGLE: 79.4 Page 4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 4 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth Units. .. .. ..... Datum specification Block sub-type...0 TOOL NUMBER 163686 63122 12.250 3665.0 Fresh water Gel 9.00 59.0 9.7 400 .0 2.100 72.0 1.317 118.8 2.200 72.0 2.000 74.0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FPH 4 1 68 4 2 GR MwD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MwD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 3631 8226 5928.5 9191 3631 8226 ROP MWD020 FPH 0 2782.97 268.459 9103 3675 8226 GR MwD020 API 19.93 119.68 63.7827 9082 3639.5 8190 Page 5 17-178 (1).tapx 17-178 (1).tapx RPX MWD020 OHMM 3.67 2000 12.4057 9073 3631 8182.5 RPS MWD020 OHMM 0.35 1100.48 12.163 9073 3631 8182.5 RPM MWD020 OHMM 0.06 1187.09 13.0643 9073 3631 8182.5 RPD MWD020 OHMM 1.97 2000 18.7772 9073 3631 8182.5 FET MWD020 HR 0.11 87.4 1.2319 9073 3631 8182.5 First Reading For Entire File..........3631 Last Reading For Entire File...........8226 File Trailer Service name... .......STSLIB.002 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/12 Maximum Physical Record..65535 File TyE~e ................L0 Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLI6.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/12 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 8183.0 8939.0 RPD 8183.0 8939.0 RPM 8183.0 8939.0 RPS 8183.0 8939.0 RPx 8183.0 8939.0 GR 8190.5 8946.5 OP 8227.5 8983.0 $ LOG HEADER DATA DATE LOGGED: 15-OCT-07 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 74.11 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 8983.0 TOP LOG INTERVAL (FT): 8226.0 BOTTOM LOG INTERVAL (FT): 8983.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG Page 6 • 17-178 (1).tapx MINIMUM ANGLE: 78,2 MAXIMUM ANGLE: 86.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 163686 EWR4 ELECTROMAG. RESIS. 4 63122 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 3665.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 9.00 MUD VISCOSITY (S): 48.0 MUD PH: 9,2 MUD CHLORIDES (PPM): 250 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.600 72.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.156 102.3 MUD FILTRATE AT MT: 1.800 72.0 MUD CAKE AT MT: 1.900 72.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name Service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FPH 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading Page 7 17-178 (1).tapx DEPT FT 8183 8983 8583 1601 8183 8983 ROP MWD030 FPH 4.8 372.17 175.857 1512 8227.5 8983 GR MWD030 API 42.12 118.34 78.1972 1513 8190.5 8946.5 RPX MWD030 OHMM 6.24 74.58 19.8899 1513 8183 8939 RPS MWD030 OHMM 7.23 174.81 31.3057 1513 8183 8939 RPM MwD030 OHMM 8.09 194.68 35.4364 1513 8183 8939 RPD MWD030 OHMM 9.34 170.4 35.6321 1513 8183 8939 FET MwD030 HR 0.21 39.49 2.68751 1513 8183 8939 First Reading For Entire File..........8183 Last Reading For Entire File...........8983 File Trailer Service name... .......STSLIB.003 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/12 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 Service Sub Level Name... Version Number. ........1.0.0 Date of Generation.......08/02/12 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.003 comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8947.0 17078.5 ROP 8984.5 17083.0 RPD 8985.0 17033.0 RPM 8985.0 17033.0 RPS 8985.0 17033.0 RPx 8985.0 17033.0 FET 8985.0 17033.0 LOG HEADER DATA DATE LOGGED: 21-OCT-07 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 17083.0 TOP LOG INTERVAL (FT): 8983.0 Page 8 1.7-178 (1).tapx BOTTOM LOG INTERVAL (FT): 17083.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 86.9 MAXIMUM ANGLE: 92.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216262 EWR4 ELECTROMAG. RESIS. 4 10505932 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 8980.0 BOREHOLE CONDITIONS MUD TYPE: Mineral Oil Base MUD DENSITY (LB/G): 8.45 MUD VISCOSITY (S): 65.0 MUD PH: ,0 MUD CHLORIDES (PPM): 28000 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .000 .O MUD AT MAX CIRCULATING TERMPERATURE: 134.600 .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: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FPH 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MwD040 HR 4 1 68 28 8 Page 9 17-178 (1).tapx First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 8947 17083 13015 16273 8947 17083 ROP MWD040 FPH 2.76 1477.55 276.062 16186 8984.5 17083 GR MWD040 API 26.12 101.26 66.3425 16264 8947 17078.5 RPX MWD040 OHMM 9.03 2000 61.1719 16097 8985 17033 RPS MWD040 OHMM 10.51 2000 65.0923 16097 8985 17033 RPM MWD040 OHMM 8.84 2000 60.9877 16097 8985 17033 RPD MWD040 OHMM 5.1 2000 61.8817 16097 8985 17033 FET MWD040 HR 0.12 3.37 0.472021 16097 8985 17033 First Reading For Entire File..........8947 Last Reading For Entire File...........17083 File Trailer Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/12 Maximum Physical Record..65535 File TyL~e ................L0 Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/02/12 0rigin ...................sTS Tape Name. .... ........UNKNOWN continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Reel Trailer Service name .............LISTPE Date. ...................08/02/12 Ori9in ...................5T5 Reel Name. .... ........UNKNOWN continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS Writing Physical EOF Physical EOF End Of LIS File Library. scientific Technical services Library. 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