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Home My WebLink About202-126 Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~0;2, - ~:l.0 Well History File Identifier Organizing (done) D Two-sided 1111111111111111111 ~escan Needed 1111111111111111111 RES CAN ~olor Items: 0 Greyscale Items: DIGITAL DATA ~iskettes No. :3 0 Other, No/Type: OVERSIZED (Scannable) 0 Maps: 0 Other Items Scannable by a Large Scanner 0 Poor Quality Originals: OVERSIZED (Non-Scannable) 0 Other: 0 Logs of various kinds: Scanning Preparation BY: Helen éa~~) 3 x 30 = c¡ () 0 Other::;.. . I . :J Date:q ;),q 6lf Isl vvt I , 1 ,1111111111111111111 Date ~. ~q oq.- /5/ WVr + ~ <6 = ,TOTAL PAGES} I ~ (Count d¿es not7;lude cover sheet) ,.. p Date:q Mf. ~llllilllllll-ll~ NOTES: BY: Helen~ Project Proofing BY: Helen ~ Production Scanning Stage 1 Page Count from Scanned File: tie (Count does include cover sheet) Page Count Matches Number in Scan~ing Preparation: V YES .. í Helen Gi.0 Date:q '91 01- /5/ If NO in stage 1 page(s) discrepancies were found: YES NO NO Stage 1 BY: Wtp BY: Helen Maria Date: Isl 1III1111I111111111 Scanning is complete at this point unless rescanning is required. ReScanned 111111111"11111111 BY: Helen Maria Date: Isl Comments about this file: Quality Checked 1111111111111111111 8/24/2004 Well History File Cover Page. doc . STATE OF ALASKA ALI O:A OIL AND GAS CONSERVATION COMOSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell L Rug Perforations E Perforate E Other f Alter Casing E Pull Tubing E Stimulate - Frac (rI Waiver f" Time Extension E Change Approved Program Operat. Shutdow n E Stimulate - Other E Re -enter Suspended Well j`" 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development l••" Exploratory I-- 202 -126 3. Address: 6. API Number: ®® Stratigraphic [ Service P. O. Box 100360, Anchorage, Alaska 99510 50 103 20424 - 00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 380075 ' 4. CD2-41 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): r none Colville River Field / Alpine Oil Pool 11. Present Well Condition Summary: Total Depth measured 13024 feet Plugs (measured) none true vertical 7219 feet Junk (measured) none Effective Depth measured 13024 feet Packer (measured) 9083 true vertical 7219 feet (true vertical) 7018 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 114 114 SURFACE 2518 9.625 2554 2366 PRODUCTION 9497 7 9532 7197 Perforation depth: Measured depth: open hole from 9532' 13024' SCANNED APR 2 2 2013 True Vertical Depth: 7197' -7219' Tubing (size, grade, MD, and TVD) 4.5, L -80, 9205 MD, 7083 TVD Packers & SSSV (type, MD, and TVD) PACKER - BAKER S -3 PACKER @ 9083 MD and 7018 TVD CAMCO BAL-0 NIPPLE @ 2008 MD and 1943 TVD 12. Stimulation or cement squeeze summary: Intervals treated (measured): 9532' 13024' • Treatment descriptions including volumes used and final pressure: l OD C 1 346800# of 16/20 carbolite 13. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 1443 3608 113 -- 251 Subsequent to operation 1690 5798 165 — 257 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run Exploratory E Development J Service E Stratigraphic 16. Well Status after work: _Oil I✓ Gas E WDSPL 1 Daily Report of Well Operations XXX GSTOR E VVINJ E WAG [ GINJ r SUSP E SPLUG E 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: 313 -059 Contact Robert Blaknev Ca) 265 -6417 Email Robert.G.Blakney@),conocophillips.com Printed Name Robert Blakne Title Completion Engineer Signature / Phone: 265 -6417 Date 1311.3 ii8 D�1S APR 0 4 no Ail t� F Form 10 -404 Revised 12/2012 `, `f,9�� Submit Original Only CD2-41 Well Work Summary DATE SUMMARY • • 3/9/2013 PULLED WRDP (HRS -280) @ 2008' RKB. SET CAT SV @ 9192' RKB. PT'd. PULLED OV @ 8860' RKB. SEAWATER CIRC -OUT COMPLETE. LRS REMAINED ON LOCATION TO FINISH FREEZE PROTECT. IN PROGRESS 3/10/2013 SET DV @ 8860' RKB. MIT -IA @ 3500 PSI = PASSED. MIT -T= @ 3500 PSI = PASSED. PULLED CAT SV @ 9192' RKB. SET FRAC SLV (2.73" ID) COMPLETE. 3/14/2013 Performed C -sand fracture stimulation using 25# linear /cross - linked gel placing 346,800# of16/20 carbolite behind pipe (99% of design) flushing to completion. Well freeze protected with 32 bbls of diesel. Removed treating line from well and secured equipment for the night. Will return in A.M. to rig down and move to well #39. 3/16/2013 PULLED FRAC SLEEVE @ 2008' RKB. GAUGE & BRUSH TBG TO 3.77" TO 9192' RKB. SET CATCHER (OAL= 37 "/ 3.78" NO -GO) @ 9192' RKB. IN PROGRESS. 3/21/2013 PULLED DV's @ 7139' & 8860' RKB. SET HIGH FLOW !/4" OV @ 8860' & 3/16" GLV (TRO= 1841) @ 7139' RKB's. IN PROGRESS. 3/24/2013 PULLED DV f/ STA.1 @ 3934' RKB, SET 3/16 GLV (TRO 1868) @ SAME. PULLED CATCHER, SET FRAC SLEEVE f/ BAL -O @ 2008' RKB. READY FOR FLOW BACK. 4/2/2013 PULLED FRAC SLV @ 2008' RKB. SET WRDP (HVS -265) @ 2008' RKB. PASSED CLOSURE TEST. REOPENED. COMPLETE. y . WNS • CD2 -41 ConocoPhi lips N Well Attributes Max Angle & Mo TD Alaska, Itlr, y, Wellbore API/UWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) lonoat lips i. 501032042400 ALPINE PROD 92.03 9,821.55 13,024.0 Comment H2S (ppm) Date Annotation End Date KB (ft) Rig Release Date -•' SSSV: WRDP Last WO: 43.56 6/30/2002 Well Confip: HORCONTAL - 002 -01, 3/15/2013 8'.14'14 AM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: 9,561.0 2/16/2008 Rev Reason: OPEN HOLE FRAC osborl 3/15/2013 Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 14.688 37.0 114.0 114.0 109.00 H - 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd HANGER. 33 I SURFACE 9 5/8 8.921 36.9 2,554.4 2,366.4 36.00 J - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 1 PRODUCTION 7 6.276 35.2 9,531.9 7,196.7 26.00 L - 80 BTCM :., Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd :; OPEN HOLE 6 1/8 6.125 9,532.0 13,024.0 7,219.1 ' Tubing Strings Tubing Description String 0... String ID... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 4 1/2 I 3.958 I 33.1 I 9,204.6 I 7,082.6 12.60 I L -80 I IBTM CONDUCTOR. Completion Details 37 -114 Top Depth (TVD) Top Inc! Nomi... ---- ...... . Top (RKB) (RKB) ( °) Item Description Comment ID (18) 33.1 33.1 0.76 HANGER FMC TUBING HANGER 4.500 NIPPLE. 2008 _ Ill ; 2,007.8 1,942.8 31.44 NIPPLE CAMCO BAL-0 NIPPLE 3.812 w aDP, 2.995 8,974.3 6,954.9 52.22 SLEEVE -C BAKER CMD SLIDING SLEEVE w/X PROFILE, CLOSED 8/2/2002 3.813 9,082.8 7,017.8 56.46 PACKER BAKER S-3 PACKER 3.875 9,086.6 7,019.9 56.54 MILLOUT BAKER S-3 MILLOUT EXTENSION 4.500 9,191.8 7,075.8 58.65 NIPPLE HES XN NIPPLE 3.725 9,203.2 7,081.9 59.30 WLEG BAKER WIRELINE GUIDE 3.958 Other In Hole ireline retrievable plugs, valves, pumps, fish, etc.) Top Depth , \ w (TVD) Top Inc! Top (ftKB) (RKB) (1 Description Comment Run Date ID (in) 2,007.8 1,942.8 31.44 WRDP CAMCO WRDP -2 (HVS -268) 3/4/2008 2.125 SURFACE, _____,A , Stimulations & Treatments 37 -2,554 �' Bottom Min Top Mu Btm Top Depth Depth IIII Depth Depth TVD (ftKB) (ftKB) (KB) (ftKB) Type Date Comment GAS LIFT, 9,532.0 13,024.0 7,196.7 7,219.1 OPEN HOLE 3/14/2013 C -SAND FRAC USING 25# 3,934 FRAC LINEAR /CROSS- LINKED GET, 346,800# 16/20 CARBOLITE BEHIND PIPE (99 %OF DESIGN) all ir FLUSHING TO COMPLETION 9,532.0 13,024.0 7,196.7 7,219.1 OPEN HOLE 2/5 /2008 C -SAND FRAC PLACED 102,978# OF 16/30 FRAC BADGER SAND IN OPEN HOLE Notes: General & Safety End Date Annotation 9/2/2010 NOTE: VIEW SCHEMATICS w /Alaska Schlnatic9.0 GAS LIFT, _ l 7,139 i. GAS LIFT, l'�- -• 8860 _ .1 SLEEVE -C, _ # ' , 8,974 PACKER. 9,083 �"" S'�^ MILLOUT, 9,007 NIPPLE. 9.192- IN Mandrel Details Top Depth Top Port g ,,, (TVD) Intl OD Valve Latch Size TRO Run W 20 9,203 - N... Top (ftKB) (RKB) (1 Make Model (in) Sery Type Type (In) (psi) Run Date Com... 1 3,933.9 3,361.4 44.19 CAMCO KBG-2 1 GAS LIFT DMY BK -2 0.000 0.0 2/2/2008 11:00 2 7,139.0 5,654.8 44.54 CAMCO KBG-2 1 GAS LIFT DMY BK -2 0.000 0.0 2/2/2008 4:00 3 8,860.0 6,879.4 45.62 CAMCO KBG-2 1 GAS LIFT OV BK -2 0.250 0.0 3/3/2008 11:00 PRODUCTION, 35 -9,532 OPEN HOLE .• , FRAC, 9,532 I I o TD, . OPEN HOLE FRAC, 9,532 OPEN HOLE, 9, 13,024 TD, 13,024 F • • w \�\ I //7 6, THE STATE Alaska Oil and aS - ®f Conservation C issi n GOVERNOR SEAN PARNELL 333 West Seventh Avenue Op Anchorage, Alaska 99501 -3572 F ALAS Main: 907.279.1433 Fax: 907.276.7542 Robert Blakney �A 0 6 2��3 Completion Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 L Q a 1 d4 Re: Colville River Field, Alpine Oil Pool, CD2 -41 Sundry Number: 313 -059 Dear Mr. Blakney: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ( /9 Cathy P. oerster Chair DATED this 1 day of February, 2013. Encl. RECEIVED • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION FEB 0 6 2013 APPLICATION FOR SUNDRY APPROVALS f L/14 / �� 20 MC 25.280 1. Type of Request: Abandon r Plug for Redd' I". Perforate New Pool r Repair well r Change Approved FYogram r Suspend r Rug Perforations r Ferforate r MD Tubing r Time Ectension r Operational Shutdown r Re -enter Susp. Well r Stimulate I`,7 . After casing r Other: i 2. Operator Name: 4. Current WeN Class: 5. Permit to Drill Number ConocoPhillips Alaska, Inc. Development w - Exploratory r 202 - 126 3. Address: . Stratigraphic r Service r S. API Number P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20424 - 00 7.1f perforating, What 8. Well Name and Number. Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing except? Yes r No W CD2 t. 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL 380075 • ColvNle River Field 1 Alpine ON Pod . 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): - 13024 7219 •13024' 7219' none none Casing Length Size MO TVD Burst Collapse CONDUCTOR 77 16 114' 114' SURFACE 2518 9.625 2554' 2366' PRODUCTION 9487 7 9532' 7197' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): - open hole from 9532'- 13024'- 7197' 4.5 L - 9205 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER S -3 PACKER - MD= 9083 TVD= 7018 SSSV -CAMCO WRDP-2 ` MD= 2008 TVD=1943 12. Attachments: Description Summary of R . ri 13. WeN Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic I Development Jv - Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed wank: 3/1/2013 Oil F - Gas r VVDSPL r Suspended r 16. Verbal Approval: Date: WNJ r GIN.) r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Robert Blakney 6 265 -6417 Email: Rob erLG Blakneyeticonocooh ft0S.con Printed Name be gy Title: Completion Engineer / s / Signature Phone: 265 -6417 Date Commission Use Only Sundry Number, ( Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance E e Other. R BDMS FEB 15 2 013 f ' Spacing Exception Required? Yes ❑ No (j Subsequent Form Required: /0 — 40 4.. 1 i APPROVED BY 2 r ✓ App oved b .� �/ 4!�l4 C. , b 4 1� a' "N - . _., , � 3r _ Date: Form 10-403 (Revised 10/2012) 171.--F: Submit Form and Attachments in Duplicate N AL Zvi3f /3 � ti' ORIGI �/� • • CD2-41 Sundry Application Drilling for CD2 -41 was completed in June of 2002 targeting the C Sand formation. The well was completed with 4.5" tubing. It was initially hydraulically fractured in 2008, placing —103,000#'s of 16/30 Badger Sand. We intend to re- stimulate the C Sand formation with a single stage treatment placing —350,000#'s of 16/20 CarboLite. If the stimulation is successful we anticipate an increased production of 205 bpd in 2013. Proposed Procedure: Schlumberaer Pumping Services: (C Sand) 1. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. 2. Ensure all Pre -frac Well work has been completed and confirm the tubing and annulus are filled with a freeze protect fluid to 2,000' TVD. 3. Ensure the 10 -403 Sundry has been reviewed and approved by the AOGCC. 4. MIRU 7 clean insulated Frac tanks, with a berm surrounding the tanks that can hold a single tank volume plus 10 %. Load tanks with 100° F seawater (approx. 3150 are required for the treatment with breakdown, maximum pad, and 450 bbls usable volume per tank). 5. Ensure lift plan is reviewed and signed prior to RU of Frac equipment requiring lifts. 6. MIRU Stinger Tree Saver Equipment and SLB Frac Equipment. 7. PT Surface lines to 8,000 psi using a Pressure test fluid. 8. Test IA Pop off system to ensure lines are clear and all components are functioning properly. 9. Pump the 240 bbl breakdown stage (25# linear gel, WF125) according to the attached excel SLB pump schedule. Bring pumps up to maximum rate of 40 BPM as quick as possible, pressure permitting. Slowly increase annulus pressure from 2,500 psi to 3,500 psi as the tubing pressures up. Ensure sufficient volume is pumped to Toad the well with Frac fluid, prior to shut down. 10. Perform a hard shut down, Obtain ISIP and fluid efficiency estimates. 11. Pump the Frac job by following schedule @ 40bpm with a maximum expected treating pressure of 3500 psi. Stage 1 • 600 bbls YF125ST Pad • 221 bbls YF125ST w/ 2 ppa 16/20 Carbolite • 408 bbls YF125ST w/ 4 ppa 16/20 Carbolite • 357 bbls YF125ST w/ 4 ppa 16/20 Carbolite • 688 bbls YF125ST w/ 7 ppa 16/20 Carbolite • Flush with 60 bbls of linear fluid (WF125) and freeze protect • Total Sand: Approx. 350,000 Ibs 16/20 Carbolite 12. Monitor the surface pressure fall -off at the end of the job for 30 minutes, if the well does not screen out. 13. RDMO SLB Equipment. Freeze Protect the tubing and wellhead if not able to complete following the flush. 14. Well is ready for Post Frac well prep for flowback (Slickline and possibly CTU). RB • • 15. Flowback will be initiated through Expro until the fluids clean up at which time it will be turned over to production. (initial flowback fluids to be taken to appropriate disposal well until they are clean enough for production.) Cement Evaluation of CD2-41 and wells within 1 /4 mile of CD2 -41 CD2 - 41: 7" Casing cement job was pumped on 6/30/2002 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 9.3 ppg brine. The plug was bumped at 1200 psi and the floats held. The casing was pressure tested to 3500 psi and held for 30 minutes. CD2 - 50: 7" Casing cement job was pumped on 3/16/2002 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 9.3 ppg brine. The plug was bumped and floats held. CD2 - 464: 7 5/8" Casing cement job was pumped on 6/9/2008 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 10.1 ppg mud. The plug was bumped at 1200 psi and the floats held. CD2-58: 7 casing cement job was pumped on 5/30/2003. A 15.8 ppg Class G cement was pumped and displaced with 9.8 ppg mud. Did not bump plug but received full returns. The casing was pressure tested to 3500 psi and held for 30 minutes. CD2 - 48: 7" Casing cement job was pumped on 6/7/2002 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced at 5.6 bpm. The plug was bumped at 1000 psi and the floats held. CD2 - 38: 7" Casing cement job was pumped on 9/2/2002 as designed, indicating competent cement operations. The cement pumped was 15.8 ppg Class G cement, displaced by 9.7 ppg mud. The plug was bumped at 1400 psi and the floats held. Summary Based on engineering evaluation of the wells referenced in this application, ConocoPhillips has determined that this well can be successfully fractured within its design limits. It has also been determined that the frac will not adversely affect wells within a % mile radius or any other nearby well. RB • Stimulation Surface Rig -Up 4) 131mi Tattle Tale Tan k 49� y (((111 • Minimum pressure rating on all surface treating lines 10,000 psi • Main treating line PRV is set to 95% of max treating pressure • IA parallel PRV set to 3500 psi — • Frac pump trip pressure setting are staggered and set co below main treating line PRV • Tree saver used on all fracs rated for 15,000 psi. la —F-81-**" N m d w Ai L ;E dwnd U Pap Off Tank :}11 0 ; Pump Truk Pop-at 1 ar* rr r� I _ T e`u c O Fra;, Pomp d:. P:W1p pp ,�v Qt ht 3::, I C� N roq Pump FrayPump N r<J Frd: Pump RB .. . • • Stimulation Tree Saver OPEN POSITION CLOSED POSITION . .....-, .., FRAC IRON -' comorTfor4 il 4 ' . : ,‘,- ai r : .,,, :, pi OPF RATED ,„; ''' 1.0...g...ems( • MASTER VAI la '1//: gr ''''''' . • g . •`4 I 0) ., ; • ' ITTiri - 041 . = , , MANUAL OPERATED ' " ' ,. MAME? VALRI g.ERTmt „/ 0......., • \\ W) ,..._., Stinger , Stinger \ ) , , , ,... MANDREL .11, . .... ., ....„ \_„.. . „. , y VL NT k t , * 1'811.0-- VALVT. . . ,E 04.. : . . FLOW TEE AND WENT VALVE' WE tifiLAD .1 VAT VES V/- gpg % . aPtts = ' : I Bat,. HAD " I VALVES g 1 - .. C't OST D ... — __ ouAn AC PBOT ;: • ,,,, S L RY EN PEACE IN TUBING , ' • • 1 • The universal tool is rated for 15,000 psi and has 84" of stroke. • Tool ID 2.25" down 4 '/2 tubing and 1.75" down 3 1/2 tubing. • Max rate with 2.25" mandrel is 60 bpm and with 1.75" mandrel 36 bpm RB • • . (_25• i CD2 -1 6p1.32PB1 GU1 - §Y• • . •••••••',.......".....:;,;%::.......•'•••:••:.... •••.‘ j .• . ! .:: : • •• ••• 0 0336 ' CD2 30 CD2 =2$1:" :,'• `" w: }� /•• ' y • ` • . y.• •' :• ., 18-8.1:^,} • • :,... ..,.,:. : •I,. •. '. „Fe►% • :.. .,.,..... CD2 -34 • • .... •t•�••. .y /4., .•• • 1:r� ii ....,..........--7.:z0.2-',.: �/ '` • '�..'•; • 154., -44PB • • • '"_ :; ,,: :... • .• •tY. 7 ::r:•. CD2 29 /' •• • • • is 5 i ;4 ::' 50PB}: :: 60, I + T • • "' %:' ,:, •'' L' : ': � ALPINE 1 CD2 - : • D2 05 �•• ,{ •.. • • 2P.B1 • . 'G112. A0 61 CD2�6L12 -46 Legend • • • =43PB1 + :: CD: Well • , Suspended • + • C ®Z -+- P + A • • �' i ALPINE 1 • + Service T • Producer • • CDi2 -42 :. L • Observation C • • Injection SW • . D2 -4O : '• ♦ Injection: SAPW � -33A : : t CD2 -39 ♦ Injection. PW T y CD2 -467 , =1 Injection: MWAG • + • ACTIVE INJ, MG • • ACTIVE, INJ, IWAG CD2 -38 1 ACTIVE, INJ, GAS • CD2 -41 • ACTIVE, INJ, DG • • D2 -470 1 NE�/E 1 • ACTIVE, INJ, <Null> • 1 ` CD2 -46? + 8 4 Disposal • • t A ' , 1/4 Mile Radius • D2 56 C 47 , D2 58L1 C ��• CO2-55 C�2 ✓ is Conoco Phillips • GD2 -60PB1 :•, • • • CD2 -41 Fracture Radius • `• CD2 -43 • • "• N CONFIDENTIAL • CD2 -56L1 • CD4 -304 CD4 -16 • o o. zs o.s • • • • • n ': { • A Miles • FracProgram2013.mod CSR 1 -10 -2012 • • • WNS CD2 -41 ConocoPhillips Oh Well Attributes Max Angle & MD TD A1dS6a,lil +: Walther* APIArW1 Field Name Well Slaws Inst ('I MD (ft KB) Act Min (RPM 501032042400 ALPINE PROD 92.03 9,821.55 13,024.0 "" Comment 1125 (ppm) Date Annotation (End Dale KB -Ord (ft) Rig Release Date WO Coop 110 RIDNTAC •GD241, 10.40172.78 - .N PL SSSV: WRDP Last WO: 43.56 6/30/2002 Schematic- Acluai Annotation Depth (XKB) End Date Annotation Last Mod ... End Dale Last Tag: 9,561.0 2/16/2008 Rev Reason: WELL REVIEW osbotl 1312013 Casing Strings Casing Description String 0... String lD ... Top)ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String... String Top Thrd CONDUCTOR 16 14.688 37.0 114.0 114.0 109.00 H-40 WELDED ,, a Coning Deuriplion String 0... String b... Top (RKa) Set Depth (1... Set Dnpth )TVD)... String WI... String String Top Thrd KAUvER.S '� � , SURFACE 9 518 8.921 36 2 2 3 6 . 00 J -55 8TC S" Caning Description 1 Slring 0... String ID ... Top (RKB) Sat Depth (I... Set Depth (TVD) _. String Wt.. String .. String Top Thrd '� PRODUCTION 7 6.276 352 9,531.9 7,196.7 26.00 L BTCM Casing Description String 0... String l0... Top (XKB) Sat Depth (t... Set Depth (TVD)_. String WI.. String._ String Top Thrd C . OPEN HOLE 6 118 6.125 9,532.0 13,024.0 7,219.1 1 Tubing Strings L.`a..,, e,, � � Tubing Description ing0... 'String Top(XKB) Set Depth (L.. set Depth)ND) „. String Wt..- String_. Tap Thrd TUBING I Str 4 1/2 Str 3.958 ( 33.1 I 9,204.6 I 7,082.6 I 12.60 I L -80 'String IBTM cor,DO id O R. Completion Details 3 Ta p De ( ND) Top t ool NOmt... Top 1X (RKB) I) I tem Doacr Continent 109/1 3 33.1 0.76 BANGER FMC TUBING HANGER 4 WAALE. 2000 2,00 1,942.$ 3 NIPPLE CAMCO BAL D NIPPLE 3. WA OP 2009 ��, 8 6,954.9 52.22 SLEEVE -C BAKER CMO SLIDING SLEEVE wM PROFILE, CLOSED 8/'22002 3.813 9,082.8 7,017.8 56.46 PACKER BAKER S-3 PACKER 3.875 j 9,086.6 7,019.9 56.54 MILLOUT BAKER S -3 MILLOUT EXTENSION 4.500 f 9,191.8 7,075.8 58.65 NIPPLE HES XN NIPPLE 3.725 9,203.2 7,081.9 59.30WLEG BAKER WIRELINE GUIDE 3.958 Other In Hole Wireline retrievable plugs, valves, pumps, fish, etc.) Top Depth (ND) Top loci Top MB) (MT/ 0 Description Commerk Run Dale ID {In) 2,007.8 1,942.8 31.44 WRDP CAMCO WRDP -2 (HVS -268) 3/4/2008 2.125 `ORFAOE Ili Stimulations & Treatments 31 - .^ SI Bottom M in Top Atae Btm Top Depth Depth Depth Depth (TVD) (ND) (RKB) MB) BM) MB) Type Data Comment GAS rFT 9,532.0 13,024.0 7,195.7 7,219.1 FRAC 2/512008 C -SAND FRAC PLACED 102,978# OF 16/30 9 3; ----- - - - - -- BADGER SAND IN OPEN HOLE Notes: General & Safety i End Date Annalaiion ■ 9/212010 NOTE: VIEW SCHEMATICS w /Alaska Schmatic9.0 I GAS LIFT, 7,139 I I ill GAS LIFT Qa50 C t gg SOTFIT T , 1 n ■ 5, ■ 6 PACKER, 0063 y --‘ ' to 9, II PRE 9,192 I : :, Mandrel Details Top Depth Top Pod (ND) loci OD Valve Latch Size TRO Run Stn Top (MB) (RIOT) PI Flake Model (in) Sew Type Type (In) (poll Ron Date Com... 1 3,933.9 3,361.4 44.19 CAMCO K60 -2 1 GAS LIFT DMY BK -2 0.000 0.0 2/2/2008 11:00 2 7,139.0 5,654.8 44.54 CAMCO KBG -2 1 GAS LIFT DMY BK -2 0.000 0. 2/2/2008 4:00 I 3 8,860.0 6,879.4145.62 CAMCO KBG -2 1 GAS LIFT OV BK -2 0.2501 0.0 3/3/2008 11:00 PROOUCTrOti, 35 9.532 FRAC. FER H LE. I ea e. is OCE. 1 TD INon • CD2 -41 Apline C Frac Model • F rac Design Job Description Step Pump Fluid Name Step Gel Prop. Prop. • Name Rate Fluid Conc. Type and Mesh Conc. (bbl /min) Volume (lb/mgal) (PPA) (gal) Pad 40.0 YF125ST 25200 25.0 0.00 2.0 PPA 40.0 YF125ST 9267 25.0 16/20 C -Lite 2.00 4.0 PPA 40.0 YF125ST 17149 25.0 16/20 C -Lite 4.00 4.0 PPA 40.0 YF125ST 15005 25.0 16/20 C -Lite 4.00 7.0 PPA 40.0 YF125ST 28916 25.0 16/20 C -Lite 7.00 Flush 40.0 YF125ST 6667 25.0 0.00 Fluid Totals 102204 gal of YF125ST • Proppant Totals 349600 lb of 16/20 C -Lite 1 Model Results Initial Fracture Top TVD - 7142.0 ft Initial Fracture Bottom ND - 7212.0 ft Propped Fracture Half- Length - 434.3 ft • EOJ Hyd Height at Well - 157.7 ft Average Propped Width - 0.349 in • Disclaimer Notice: — This model was generated using vendor supplied modeling • software and is based on engineering estimates of reservoir properties. ConocoPhillips is providing these model results as an informed prediction of actual results. Because of the inherent limitations in assumptions required to generate this model, and for other reasons, actual results may differ from the model results. • Conoco Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 April 01, 2011 RECEIVED Commissioner Dan Seamount Wks ks t l� �S Cans. �3 a11S31= Alaska Oil & Gas Commission APR ►'1 ` :ii1z:i3of8gB 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 O.)---- 1 Al Y� Commissioner Dan Seamount: Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement 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. The corrosion inhibitor /sealant was pumped March 13 -15 and March 27 -28, 2011. 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, MJ Loveland 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) Alpine Field Date 04/01/2011 CD2 PAD Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name API # PTD # cement pumped cement date inhibitor sealant date ft bbls ft gal CD2 -14 50103203900000 2011770 4" n/a 16" n/a 5.4 3/14/2011 CD2 -16 50103204260000 2021440 4" n/a 14" n/a 3.6 3/14/2011 CD2 -17A 50103204060100 2051700 4" n/a 14" n/a 3.6 3/14/2011 CD2 -24 50103203770000 2010950 6" n/a 14" n/a 3.4 3/15/2011 CD2 -25 50103204180000 2020740 4" n/a 14" n/a 3.9 3/28/2011 CD2 -26 50103203970000 2012320 4" n/a 16" n/a 2.7 3/27/2011 CD2 -33B 50103203810200 2011250 4" n/a 15" n/a 2.7 3/27/2011 CO2-41 50103204240000 2021260 4" Na 14" Na 4.3 3/28!2411 CD2 -50 50103204150000 2020490 8" n/a 16" n/a 3.5 3/27/2011 CD2 -51 50103204410000 2022490 5'10" 0.80 15" 3/21/2007 3.9 3/27/2011 CD2 -56 50103204980000 2041500 SF n/a 15" n/a 3.8 3/27/2011 CD2 -58 50103204570000 2030850 6" n/a 6" n/a 3.5 3/28/2011 CD2 -59 50103205050000 2042480 6" n/a 6" n/a 5 3/27/2011 CD2 -60A 50103205110100 2091150 6" n/a 6" n/a 5.25 3/27/2011 CD2 -74 50103205910000 2081970 10'9" 1.20 9" 3/26/2011 1.7 3/27/2011 CD2 -76 50103206030000 2090980 32" n/a 32" n/a 9.7 3/27/2011 CD2 -78 50103206010000 2090660 6" n/a 6" n/a 1.7 3/27/2011 CD2 -466 50103205760000 2080950 8" n/a 17" n/a 3.4 3/27/2011 1 • RECEIVE® STATE OF ALASKA MAR 2 6 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATICca pii 8~ Gas Cons. Commission 1. Operations Performed: Abandon ^ Repair Well ^ Ptug Perforations ^ Stimulate ^~ Other ~ ~ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConoCOPhilllps Alaska, InC. Development ^~ Exploratory ^ 202-126 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchora e, Alaska 99510 50-103-20424-00 ' 7. KB Elevation (ft): ~ 9. Well Name and Number: RKB 52' CD2-41 8. Property Designation: 10. Field/Pool(s): ADL 380075 ~ Colville R'sver Field 1 Alpine Oil Pool ' 11. Present Well Condition Summary: Total Depth measured 13024' feet true vertical 7219' feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 114' 16" 114' SURFACE 2502' 9-5/8" 2554' PRODUCTION 9480' 7" 9532' OPEN HOLE 3492' 6-1/8" 13024' ~~~~I APR ~ 20Q8 Perforation depth: Measured depth: true vertical depth: Tubing (size, grade, and measured depth) 4-1/2" , L-80, 9204' MD. Packers 8~ SSSV (type & measured depth) Packer =Baker S-3 Packer = 9083' SSSV= SSSV SSSV= 2008' 12. Stimulation or cement squeeze summary: Intervals treated (measured) Treatment descriptions including volume s 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 2190 2679 1 290 Subsequent to operation 3530 8800 25 334 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development 0 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: 307-373 Contact Printed Name Tim Schneider Title: Production Engineer Signature '~, ^ ~~~ Phone 265-6859 Date Fo 4/ 04 ^ R I i -, ~ ~ A ~ ~ ~ ` Submit Ori~ n y ~ /` • • CD2-41 Stimulation Results Summary of stimulation job: 2-03-08: Pump frac in one stage: The frac ramped from 2-15 ppa; 1125 bbls slurry. A screen out occurred 82 bbls into the 225 bbl flush Frac: AIR-40 BPM, AIP- psi, ISIP-2257 psi, 102,978 lbs. 16/30 Badger sand placed. Well test: 3/5/08: 3530 bopd, 25 bwpd, 8.8 mmcfpd, 334 WHP • • t,~,~ ~ f ~ ~ ~ ~ ~ ~~ ~ ~ ~i j ,- ~~~ ~ SARAH PAUN, GOVERNOR L_-~ t.~` ~S''IfA OIII ~17~w7 333 W 7th AVENUE, SUITE 100 C01~TSERQA'1`IOK COI•'InIISSIOIQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Tim Schneider Production Engineer Conoco Phillips Alaska, Inc PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Alpine Oil Pool, CD2-41 Sundry Number: 307-373 ,~~~~ ~~~ ~ ~ ~flQ~ Dear Mr. Schneider: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has -been requested. DATED this .day of December, 2007 Encl. ~v~ (~0~ ,~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~ ~ ~ ~.~Q~ APPLICATION FOR SUNDRY APPROVAf~ska ~i~ ~ Gas ~~n~. Cammi~szon 20 AAC 25.280 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waiver ^ Other ^ Alter casing ^ Repair well ^ Plug Pertorations ^ Stimulate ^/ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development Q ' Exploratory ^ 202-126 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20424-00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Y2S NO Q ~ CD2-41 - 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 380075 ' RKB 52' ~ Colville River Field /Alpine Oil Pool 12. PRESENT WELL CONDITI ON SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13024' - 7219' ' Casing Length Size MD TVD Burst Collapse CONDUCTOR 114' 16" 114' SURFACE 2502' 9-5/8" 2554' PRODUCTION 9480' 7" 9532' OPEN HOLE 3492' 6-1l8" 13024' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4-1/2" L-80 9204' Packers and SSSV Type: Packers and SSSV MD (ft) Packer= Baker S-3 Packer= 9083' SSSV= Camco BAL-O SSSV= 2008' 13. Attachments: Description Summary of Proposal Q 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q , Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: February 5, 2008 Oil ~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tim Schneider Printed Name Tlrn eider Title: Production Engineer ~ Signature / Phone 265-6859 Date /ZY ~-(j Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness -~p °~ °T Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: hk.~ ~y h~~ K; ~~~ ~ k- , Gy b ~~~~t~ APPROVED BY ~~ ^ /~~e Approved by: CO MIS IONER THE COMMISSION Date: Form 10-403 Revised 06/2006 ~ ~~ ~ A L E%~ ~ emit in Duplicate ~ ~9d ~ ~z ~ rR ~7 • • Overview: CD2-41: A hydraulic fracture treatment will be performed in the openhole horizontal section to ~ establish communication vertically and longitudinally through the Alpine "C" sand. This will increase the wells production rate and reserves. A coil cleanout will only be performed should it be necessary post-frac. Procedure: 1. MIRU 8 clean insulated frac tanks with a berm surrounding the tanks that holds the tank volume plus 10%. Load tanks with seawater from the injection system (approximately 2500 bbls are required for the treatment) 2. Rig up Schlumberger equipment and stab Tree Saver. (Test tree saver seals to expected pressure using warm diesel to assure seal integrity in tubing hanger). 3. Pressure test surface lines to 9500 psi 4. Pump the 100 bbl Breakdown with SchlumbergePs YF125ST fluid system. Bring pumps up to maximum rate ASAP. 5. Pump the following schedule at 40 BPM with a maximum pressure of 6000 psi, add breaker as per lab results. Maintain 2000-3000 psi on the IA during the treatment. • 100 bbls YF125ST Pad • 100 bbls YF125ST w/ 2 ppa 16/30 White Sand • 170 bbls YF125ST w/ 4 ppa 16/30 White Sand • 250 bbls YF125ST w/ 7 ppa 16/30 White Sand • 40 bbls YF125ST w/12 ppa 16/30 White Sand Repeat treatment above 4 times. • Flush the last stage with linear YF125ST and freeze protect Total Sand: 450,000 lbs. 6. Monitor the surface pressure fall-off at the end of the job for 30 min (or until closure is verified} if the well does not screen out. 7. Rig down equipment, (and prep for next well frac after evaluation by Engineering) move off location. FCO if required with slick diesel. ~ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 11, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West ih Avenue, Suite 100 Anchorage, AK 99501 ¡CANNED ~?R 2 1 7.Q\H -\~\p ~b~ Dear Mr. Maunder: Sorry for the inconvenience, however it was observed that a spreadsheet sent to you and dated 3/31/07 was incomplete. Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). It was noticed that Alpine well CD2-404 was unintentionally left out of spreadsheet dated 3/31/07. Please find enclosed updated spreadsheet, and replace. 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. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, M.;;::f/~---'/ ConocoPhillips Well Integrity Project Supervisor ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date ft bbls ft Clal CD2-1 205-118 4" na 4" na 2 2/18/2007 CD2-2 205-1 09 6" na 6" na 2.5 2/18/2007 C02-404 206-054 6" na 6" na 1.8 3/22/2007 CD2-7 203-187 16" na 16" na 7.5 2/17/2007 CD2-9 202-129 22" na 22" na 10.5 2/17/2007 C02-12 203-073 16" na 16" na 7.5 2/17/2007 C02-14 201-177 4" na 4" na 2 2/17/2007 C02-15 201-159 12" na 12" na 5.7 2/17/2007 C02-16 202-144 11 '7" 1.6 4" 4/16/2003 1 318/2007 C02-17 205-017 18' 2.5 4" 4/16/2003 1 3/8/2007 C02-18 203-151 36" na 36" na 17 2/17/2007 C02-19 202-112 11'5" 1.6 4" 4/16/2003 1.5 318/2007 C02-21 204-245 6" na 6" na 2.5 2/18/2007 C02-22 202-092 13'6" 1.8 4" 4/16/2003 1.5 3/8/2007 C02-24 201-095 6" na 6" na 1 318/2007 C02-26 201-232 10'5" na 4" 4/16/2003 1 3/8/2007 C02-28 202-217 29" na 29" na 11 3/8/2007 C02-30 203-135 8" na 8" na 3 318/2007 C02-31 204-082 15" na 15" na 6 3/8/2007 C02-32 202-029 8'6" 1.2 4" 4/16/2003 1 3/8/2007 C02-33 201-125 7' 1.0 4" 4/16/2003 1 3/8/2007 CD2-34 202-126 4' 0.6 4" 4/16/2003 1 3/8/2007 C02-37 202-211 29" na 29" na 13.8 2/18/2007 C02-38 202-171 18" na 18" na 8.5 2/18/2007 C02-39 201-160 34" na 34" na 16.2 2/18/2007 C02-44 202-165 13" na 13" na 6.2 2/18/2007 C02-46 202-082 7'4" 1.0 12" 4/16/2003 5.7 2/18/2007 C02-47 201-205 25" na 25" na 11.9 2/18/2007 C02-48 202-108 10'6" 1.4 7" 4/16/2003 3.3 2/18/2007 C02-49 201-249 9'11" 1.3 8" 4/16/2003 3.5 2/18/2007 CO2-53 204-089 4" na 4" na 2 2/18/2007 CO2-54 204-178 8" na 8" na 3.7 2/18/2007 CO2-55 203-118 13" na 13" na 6 2/18/2007 CO2-57 204-072 8" na 8" na 1 3/8/2007 CO2-58 203-085 6" na 6" na 1 3/8/2007 CO2-59 204-248 6" na 6" na 1.5 3/8/2007 C02-60 205-068 6" na 6" na 1 3/8/2007 Alpine Field March 31,2007 . . ~ ConocoPhillips Alaska )'\''0 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 .5i March 31, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 sCANNED APR 0 9 2007 J,,ð 0-.- \ d--~ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells ITom the Alpine field (ALP). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void subsequently was filled with a corrosion inhibiter engineered to prevent water ITom 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. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, ~~C Jerry Dethlefs ConocoPhillips Well Integrity Proj Supervisor Attachment .~ . . >- ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTO# cement pumped cement date inhibitor sealant date ft bbls ft gal C02-1 205-118 4" na 4" na 2 2/18/2007 C02-2 205-109 6" na 6" na 2.5 2/18/2007 C02-7 203-187 16" na 16" na 7.5 2/17/2007 C02-9 202-129 22" na 22" na 10.5 2/17/2007 C02-12 203-073 16" na 16" na 7.5 2/17/2007 C02-14 201-177 4" na 4" na 2 2/17/2007 C02-15 201-159 12" na 12" na 5.7 2/17/2007 C02-16 202-144 11 '7" 1.6 4" 4/16/2003 1 3/8/2007 C02-17 205-017 18' 2.5 4" 4/16/2003 1 3/8/2007 C02-18 203-151 36" na 36" na 17 2/17/2007 C02-19 202-112 11'5" 1.6 4" 4/16/2003 1.5 3/8/2007 C02-21 204-245 6" na 6" na 2.5 2/18/2007 C02-22 202-092 13'6" 1.8 4" 4/16/2003 1.5 3/8/2007 C02-24 201-095 6" na 6" na 1 3/8/2007 C02-26 201-232 10'5" na 4" 4/16/2003 1 3/8/2007 C02-28 202-217 29" na 29" na 11 3/8/2007 C02-30 203-135 8" na 8" na 3 3/8/2007 C02-31 204-082 15" na 15" na 6 3/8/2007 C02-32 202-029 8'6" 1.2 4" 4/16/2003 1 3/8/2007 C02-33 201-125 7' 1.0 4" 4/16/2003 1 3/8/2007 C02-34 202-126 4' 0.6 4" 4/16/2003 1 3/8/2007 C02-37 202-211 29" na 29" na 13.8 2/18/2007 C02-38 202-171 18" na 18" na 8.5 2/18/2007 C02-39 201-160 34" na 34" na 16.2 2/18/2007 C02-44 202-165 13" na 13" na 6.2 2/18/2007 C02-46 202-082 7'4" 1.0 12" 4/16/2003 5.7 2/18/2007 C02-47 201-205 25" na 25" na 11.9 2/18/2007 C02-48 202-108 10'6" 1.4 7" 4/16/2003 3.3 2/18/2007 C02-49 201-249 9'11" 1.3 8" 4/16/2003 3.5 2/18/2007 CO2-53 204-089 4" na 4" na 2 2/18/2007 CO2-54 204-178 8" na 8" na 3.7 2/18/2007 CO2-55 203-118 13" na 13" na 6 2/18/2007 CO2-57 204-072 8" na 8" na 1 3/8/2007 CO2-58 203-085 6" na 6" na 1 3/8/2007 CO2-59 204-248 6" na 6" na 1.5 3/8/2007 C02-60 205-068 6" na 6" na 1 3/8/2007 Alpine Field March 31,2007 . . ~ ConocoPhillips Alaska {/! .ú ~~ 1, ~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 i~~f~~ÆI i~ ;il, i~~ iÆ;oo~, 'C:MOO.~($,~ßn A'f~;í7if \1iI' i5f crE;f !Ji!m~. ¡;;;OOmð15mrr ,tm9l1ì1 March 24, 2007 ~~""}'f,*,1W"I'~'''''''. Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 SCANNE[~ MAR 2 8 2007 f).Þé).- ~~ Dear Mr. Maunder: :-...~,~'..",,,>~..,,...,,,,,,,,, Enclosed please find a spreadsheet with a list of wells from the Alpine field (ALP). Some of these wells were found to have a void in the conductor by surface casing annulus. The voids that were greater than 3 feet were first filled with cement to a level of approx. 1.0 foot. The remaining volume of annular void respectively was coated with a corrosion inhibiter, RG2401 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. The cement top-fill operation was completed on March 21 st, 2007. Schlumberger Well Services mixed 15.7 ppg Arctic set I in a blender tub. The cement was pumped into the conductor bottom and cemented up via a hose run to the existing top of cement. The corrosion inhibitor sealant was pumped in a similar manner March 21 st - 22n , 2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Jerry Dethlefs or M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, \]7# ;:: Arend· ConocoPhillips Well Integrity Field Supervisor -~ Attachment . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Alpine Field March 24,2007 Initial top of Well Name PTD # cement ft Final top of Cement top off cement date ft Corrosion RG casing filler inhibitor! sealant vol. date al . . ConocoPhillips Alaska Inc. Suñace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Alpine Field March 24,2007 Well Name PTD# Initial top of Vol. of cement cement um ed ft bbls Final top of Cement top off cement date ft Corrosion RG casing filler inhibitor! sealant vol. date al e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marlœr.doc )1 ~~-~~V\ DATA SUBMITTAL COMPLIANCE REPORT 8/2/2004 Permit to Drill 2021260 Well Name/No. COLVILLE RIV UNIT CD2-41 Operator CONOCOPHILLlPS ALASKA INC ~p ~ ¿ ,{ J.. J "'" A..~ ~ API No. 50-103-20424-00-00 MD 13024 ,/ TVD 7219 ----- Completion Date 7/31/2002 .r Completion Status 1-01L Current Status 1-01L UIC N ------~---~-----'--~ ------------ -- REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes -~----- >--~-------- DATA INFORMATION Types Electric or Other Logs Run: GRlRes Well Log Information: (data taken from Logs Portion of Master Well Data Maint) ...,-.. Log/ Electr Data Digital Dataset Type Med/Frmt Number Name Log Log Run Scale Media No Interval OH / Start Stop CH Received Comments -----"----_.- A Directional Survey Log is required to be submitted. This record automatically created from Permit to Drill Module on: 6/17/2002. ~D Directional Survey 0 13024 Open 8/14/2002 .7 ¡:p\. ~' Directional Survey 0 13024 Open 8/14/2002 Tl-:f1-..... ~76 LI~ion J ....J-...! ~ 2533 12925 J:1JSé ~ 11 /6/2002 ~ Directional Survey 0 13024 Open 8/14/2002 MWD L5P D Directional Survey 0 13024 Open 8/14/2002 MWD ~ D Directional Survey 0 448 Open 8/14/2002 GYRO ðPt Directional Survey 0 448 Open 8/14/2002 GYRO ~ LIS Verification 2533 12925 Case 11/6/2002 ;{:g ~ée Notes 15 8M 9150 11700 Case 1/20/2004 Flow Pack Profile Log Pressure 15 8M 9150 11700 Case 1/20/2004 Flow Pack Profile --Log L- Temperature 15 8M 9150 11700 Case 1/20/2004 Flow Pack Profile '7D D Las t71 Spinner 9150 11700 Case 1/20/2004 (¡ ED D Las 12371 Temperature 9150 11700 Case 1/20/2004 ; ED D Las 2371 Pressure 9150 11700 Case 1/20/2004 ----~-"--~'--~--- Well Cores/Samples Information: Name Start Stop Sent Received Sample Set Number Comments Interval Permit to Drill 2021260 MD 13024 TVD 7219 Well Cored? ADDITIONAL INFORMATION y~ Chips Received? - Y I N Analysis Received? Comments: ~-- Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 8/2/2004 Well Name/No. COLVILLE RIV UNIT CD2-41 Operator CONOCOPHILLlPS ALASKA INC API No. 50-103-20424-00-00 Completion Date 7/31/2002 Completion Status 1-01L Current Status 1-01L UIC N Daily History Received? (YJN &N Formation Tops ~ Date: -----~~-------~ ~---~~-~----._---~,--_._--- ...._...\ )4' ~l~;~q== STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal 0 or Continuation 0 or Final 0 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added Previous totals (bbls): 2003 1 2nd 3900 100 2003 I 3rd 19560 100 2003 14th 7863 100 20041 1st 0 0 Total Ending Volume (bbls): 31323 300 Signature: Printed Name: Randy Thomas Form 10-423 Rev. 2/2004 4a. Well Class: Stratigraphic 0 Service 0 Development 0 Exploratory 0 4b. Well Status: Oil 0 Gas 0 WAGD GINJ 0 WINJ 0 WDSPL 0 5a. Sundry number: 5b. Sundry approval date: 303-081 (h)(3) Other Commission approved substances (include descriptions in block 12) 4/28/2003 Volume (bbls): Number of days disposal occurred 6. Permit to Drill Number: 7. Well Name: 202-126 CD2-41 8. API Number: 50-103-20424-00 9. Field: Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: ~ 377* 377 0 4000 5 6/26/2003 6/30/2003 CD2-20 0 19660 21 7/1/2003 7/27/2003 CD2-20, CD2-55 0 7963 7 12/25/2003 12/31/2003 CD2-10, CD2-43 0 0 0 ~ 377 32000 11. Attach: Disposal Performance Data: Pressure vs. Time 0 Other (Explain) 0 12. Remarks and Approved Substances Description(s): * Freeze protect volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. '\ '--¡' ~ ~ Step Rate Test 0 Date: Title: Kuparuk Drilling Team Leader INSTRUCTIONS ON REVERSE SIDE 33 Report ;s due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. 7('B(oy Phone Number: (907) 265-6830 Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation 0 or Final D 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added Previous totals (bbls): 2003 / 2nd 3900 2003 / 3rd 19560 2003 / 4th 7863 20041 1st 0 Total Ending Volume 31323 (bbls): 100 100 100 0 300 4a. Well Class: Stratigraphic D Service D Development 0 Exploratory D 4b. Well Status: Oil 0 Gas D WAGD GINJ D WINJ D WDSPL D 5a. Sundry number: 5b. Sundry approval date: 303-081 (h)(3) Other Commission approved substances (include descriptions in block 12) 4/28/2003 Volume (bbls): Number of days disposal occurred 6. Permit to Drill Number: 7. Well Name: 202-126 CD2-41 8. API Number: 50-103-20424-00 9. Field: Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: 377* 377 0 4000 5 6/26/2003 6/30/2003 CD2-20 0 19660 21 7/1/2003 7/27/2003 CD2-20, CD2-55 0 7963 7 12/25/2003 12/31/2003 CD2-10, CD2-43 0 0 0 .'~ 377 32000 Pressure vs. Time D * Freeze protect volumes I hereby certify that the foregoing is true and correct to the best of my knowledge. ~CA ~~~ - ~-4? \ .0 -",",-~.) 11. Attach: Disposal Performance Data: Other (Explain) D 12. Remarks and Approved Substances Description( s): Signature: Printed Name: Form 10-423 Rev. 9/2003 Step Rate Test D Date: Title: C\ ~ t '-\ \'e ..~-- L~....-, INSTRUCTIONS ON REVERSE SIDE 33 Report ;s due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. '1 ({ 6(0'1 Phone Number: 2bS- 6Z ~o Submit in Duplicate STATE OF ALASKA ALASKA Oil AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 377* 377 0 4000 5 6/26/2003 6/30/2003 C02-20 0 19660 21 7/1/2003 7/27/2003 C02-20, CO2-55 0 7963 7 12/25/2003 12/31/2003 C02-10, C02-43 ~ 1. Operator: ConocoPhillips Alaska, Inc. 2. Address: P. O. Box 100360, Anchorage, Alaska 3. (Check one box only) Initial Disposal D or Continuation of Disposal 0 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash cuttings, reserve pit fluids fluids and drill rig cement-contaminated domestic waste water drilling mud, completion fluids, formation fluids and any necessary water added 4a. Well Class: Stratigraphic D Service D Development 0 Exploratory 0 4b. Well Status: Oil [2] Gas 0 WAGD GINJ D WINJ D WDSPL D 5a. Sundry number: 5b. Sundry approval date: 303-081 (h)(3) Other Commission approved substances (include descriptions in block 12) 4/28/2003 Volume (bbls): Number of days disposal occurred Previous totals (bbls): 2003 / 2nd 3900 100 19560 100 7863 100 2003 I 3rd 2003 14th YYYY /0# Total Ending Volume (bbls): 31323 300 377 32000 11. Attach: Disposal Performance Data: Other (Explain) D 12. Remarks and Approved Substances Description( s): Pressure vs. Time 0 Step Rate Test 0 * Freeze protect volumes I hereby certify that the foreqoing is true and correct to the best of my knowledge. '~~.~ \~~ ~-J..>" ~~~~.. Signature: Date: 'ù ,.. \~ \ ~-. w.-u;J Printed Name: Title: [:,w""" ~ (LA 1)1) C....." 0/1)""1) 11\1~TQIIr.TI()I\I~ ()I\I Q¡::\I¡::R~¡:: ~lnF 6. Permit to Drill Number: 7. Well Name: 202-126 C02-41 8. API Number: 50-103-20424-00 9. Field: Colville River Field Disposal Disposal Source Wells: Beginning Dates: Ending Dates: ~- 33 Report ;s due on the 20th of the month following the final month of the quarter. Ex: April 20 for the first quarter, July 20 for the second quarter, October 20 for the third quarter, and January 20 for the fourth quarter. \ (4 (oc.( Phone Number: -z,r 6-8)0 Submit in Duclicate ids CÆJ -II' IllÁ:LL LOG TRANSMil1 AL ProActive Diagnostic Services, Inc. To: AOGCC 333 West 7th Ave. Ste. 100 Anchorage, AK 99501-3539 RE: Distribution - Final Print(s) âO~ -Jd (P The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : . Joey Burton I Jeni Thompson ProActive Diagnostic Services, Inc. P. O. Box 1369 Stafford, TX 77497 WELL loG TyPE DATE Open Hole Cd 2-41 12-10-03 Res. Eva!. CH Mech. CH Caliper Survey Signed: -- ~(,- ~ j~,\-'~) '-~" ~-Al"- Print Name: DIGITAL OR CD-ROM 1 1 J ~ .~ T- \ 1CD MYLAR / SEPIA FILM 1 BLUE LINE PRINT(S] 1 REPORT OR BLUE LINE 1 Rpt or 1 Color PRoACTivE DÎAGNOSTic SERvicES, INC., PO Box 1 }69 STAffoRd IX 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com '~~'Y\~ 1 1 Date: RECEIVED Jf~N 2 G 2004 Alaska Oil & Gas Cons. CoInmÎfJirJn Anchorage c9 6d-~ 1:1t Annular Disposal during the third quarter of 2003: h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes CD2-41 19560 100 0 19660 377 4000 24037 June 2003 July 2003 CD2-20, CD2-55 3S-17A 2133 100 0 2233 361 4659 7253 June 2003 July 2003 3S-19 Hansen 1 2498 100 0 2598 0 115278 117876 January July 2003 Hansen 1, Hansen lA 2002 CD2-38 29522 100 0 29622 389 0 30011 July 2003 Sept 2003 CD2-40, CD2-30, CD2-55 IB-20 36655 100 0 36755 0 0 36755 July 2003 Sept 2003 1B-102, 1B-101 CD2-23 22140 100 0 22240 377 0 22617 Sept 2003 Sept 2003 CD2-18, CD2-55 Total h(l) Total h(2} Total h(3} Well Name Volume Volume Volume CD2-46 31393 100 0 CD2-22 30773 100 0 Total Volumes into Annuli for which Disposal Authorization Expired during the third quarter 2003: Freeze Protect Total Volume Fluids Injected Volume 371 380 375 Start Date End Date Source Wells 0 31864 31253 32000 Status of Annulus Open, Freeze Protected Open, Freeze Protected CD2-48 31525 100 Open, Freeze Protected April 2003 May 2003 February March 2003 2003 December February 2002 2003 CD2-51, CD2-12 CD2-08, CD2-36, CD2- 51 CD2-45, CD2-35, CD2- 08, CD2-28 ,( RECEIVED OCT 2 3 2003 Alaska Oil & Gas Cons. Commission AnchDrag£ ~Od -\ Ð-(P Annular Disposal during the second quarter of 2003: h(l) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes 3S-10 9972 100 0 10072 388 21204 31664 March April 3S-21,3S-08,3S-23 2003 2003 1C-22 21553 100 0 21653 0 27044 48697 March May lC-190, lC-174, lC-178, lC-19 2003 2003 Puviaq #1 5063 100 0 5163 0 4731 9894 March April Puviaq 1 ( 2003 2003 CD2-46 31393 100 0 31493 371 0 31864 April May 2003 CD2-51, CD2-12 2003 3S-16 31006 100 0 31106 357 0 31463 April May 2003 3S-23,3S-17,3S-06,3S-16 2003 Hansen 1 47382 100 0 47482 0 67796 115278 January June 2003 Hansen, Hansen 1 A 2002 1C-19 31325 100 0 31425 0 0 31425 May 2003 June 2003 lC-184, lC-170, lC-172 3S-0SB 31610 100 0 31710 290 0 32000 May 2003 June 2003 3S-24, 3S-03, 3S-19 CD2-19 30860 100 0 30960 377 0 31337 May 2003 June 2003 CD2-58, CD2-52 CD2-41 3900 100 0 4000 377 0 4377 June 2003 June 2003 CD2-20 3S-17 A 4559 100 0 4659 361 5020 5020 June 2003 June 2003 3S-19 Total Volumes into Annulifor which Disposal Authorization Expired during the second quarter 2003: ( Freeze Protect Total Volume Start End Source Wells Total h(l) Total h(2) Total b(3) Fluids Injected Date Date Well Name Volume V olume Volume Volume Status of Annulus CD2-17 17709 100 0 372 18181 Open, Freeze Protected May 2002 Feb 2003 CD2-08, CD2-48, CD2- 46 CD2-32 31337 100 0 379 31816 Open, Freeze Protected June 2002 July 2002 CD2-19, CD2-41, CD2- 23 CD2-50 31530 100 0 370 32000 Open, Freeze Protected July 2002 Sept 2002 CD2-41, CD2- 38 1D-11 32102 100 0 235 32437 Open, Freeze Protected May 2002 June 2002 1 D-l 03 1C-1S 32251 100 0 373 32724 Open, Freeze Protected June 2002 July 2002 1 C-l 04 ConocoPhillips Alaska, Inc. Suñace Casing by Conductor Annulus Cement Top-Off Alpine Field, CD-1 CD-2 WELLS DEPTH VOLUME TYPE SACKS ¡ BBLS Cement \<;. S.r ()~(q--_.1 CD1-1 2.25' 0.3 WI 1.8 ,,;)'Cù-\~) CD1-2 4' 0.6 WI 3.6 \<;~'-r~O CD1-3 10' 1.4 MI 8.5 ¡dOO--\.~ '( CD1-4 7.33' 1 P 6.0 \~c:,- \ð~ 1 CD1-5 4' 0.6 MI 3.6 : ;y::¡:)-O~ 3> CD1-6 10.42' 1.4 GI 8.5 \ "c;- a'\L\ CD1-16 14.33' 2 WI 12.1 d(jD~' \ \..\ ç CD1-17 8.75' 1.2 P 7.2 dO\-aù~ CD1-21 13' 1.8 MI 10.9 \<;"t- )S;) CD1-22 1.83' 0.3 P 1.8 , \~~-()Co ~ ~OO- \ \0 CD1-23 15.42' 2.1 MI 12.7 . \ ~"-t,)) c.. CD 1-24 2' 0.3 P 1.8 d c:::Þ'.tf:) '6 " CD 1-25 5.66' 0.8 P 4.8 ;Xl::r-~<o CD1-27 18.83' 2.6 P 15.7 dC)D-\~" CD1-28 6.75' 1 P 6.0 \"~-\oY. CD1-32 8.33' 1.2 P 7.2 .,...JaQ::.Ç>~3 CD 1-34 41.83' 5.7 P 34.4 \c;s-\\) CD1-36 16.75' 2.3 WI 13.9 d-C::£Y:OO~~-,. CD 1-38 3.5' 0.5 P 3.0 \~ ~- \\<; CD1-42 5.83' 0.8 MI 4.8 "d.Ch>"-~~:\~ CD2-16 11.66' 1.6 INJ 9.7 d~\:)\t6 CD2-17 18' 2.5 INJ 15.1 .. ;)()if-\ ~ d CD2-19 11.66' 1.6 P 9.7 - Jt>d-t~f\) CD2-22 13.5' 1.8 INJ 10.9 död~')'-\; CD2-25 27.25' 3.7 P 22.3 .. JD \ -"ð~? CD2-26 10.42' 1.4 INJ 8.5 ~~ ")~ CD2-32 8.5' 1.2 INJ 7.2 ðO \ -\)~ CD2-33 -, 7' 1 P 6.0 ðO\ -" ~ \ CD2-34 4' 0.6 P 3.6 ~d- JOd-:-\d-_~ CD2-41 11.83' 1.6 P 9.7 d-Od-"O . CD2-46 7.42' 1 INJ 6.0 ------ ------ ¿,o-:J--\r;/1:J --CD2-48 10.33' 1.4 INJ 8.5 _._---_._-~- ---- :)0\ - 'd'1C1 CD2-49 9.33' 1.3 INJ 7.8 ; )Od-\)~ CD2-50 1.66' 0.25 P 1.5 " d-O \... \ d- '-\ .db\ -\ ð 5 ConocJPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 April 23, 2003 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West th Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Alpine field (CRU). Each of these wells was found to have a void in the conductor by surface casing annulus. The voids were filled with cement to the top of the conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place. In the fall of2002, CDI-23 was reported to have a "wobbly" tree. The top of cement was measured at 15- feet below the top of the conductor. Plans were made to stabilize the wellhead by top-filling cement later in the winter when the ice road to Alpine had been installed. Since that is considerable effort and expense for pumping a small load of cement, a survey was made of each conductor to see if voids were present. A list of 34 wells was put together that would need additional cement. The top-fill operation was started on April 15th and was completed on April 16th, 2003. Dowell- Schlumberger batch-mixed Arctic Set I cement to 15.7 ppg in a blender. The cement was pumped via high-pressure hose into the conductor. The cement was brought to the top of conductor on each well. The blender/pump and hose worked down the line, filling the identified wells until the list was completed. The attached spreadsheet presents the well name, top of cement depth prior to filling, and the number of sacks used on each conductor. Please call MJ Loveland or Nina Woods at 907-659-7224, or me at 659-7043 if you have any questions. Sincerely, Jerry Dethlefs ConocoPhillips Problem Well Supervisor Attachment Alpine tJerllent lOp HII Subject: Alpine Cement Top Fill Date: Wed, 23 Apr 2003 17:38:26 -0800 From: "Jerry C Dethlefs" <Jerry.C.Dethlefs@conocophillips.com> To: Tom Maunder <tom_maunder@admin.state.ak.us> CC: "n1617" <n1617@conocophillips.com> Tom: Attached is a letter and spreadsheet with the data mentioned in the previous email. Thanks for the relief on all the Sundry's! Let me know if you need additional information. Jerry Dethlefs Problem Well Supervisor ConocoPhillips Alaska(See attached file: AOGCC ALPINE cement top outs 04-16-03.xls)(See attached file: Cement Top Fill AOGCC Letter 04-23-03.doc) Tom Maunder <tom_maunder@admin.state.ak.us> 04/23/2003 12:51 PM To: Jerry C Dethlefs/PPCO@Phillips cc: Subject: Re: Sundry's for topping off cement Hi Jerry, I agree Jerry that individual404's aren't necessary. Send a "global document" with the information you list. There should also be some sort of introduction that describes why you did what you did and how you did it. Tom Jerry C Dethlefs wrote: > Tom: Last week we had a cement crew go down the line at Alpine, top filling > the conductors with cement. I believe 34 wells were treated. Chuck Scheve > and John Crisp were notified but declined to witness when we told them what > we were doing. Some time past we had agreed to submit a 10-404 for this > kind of work. Due to the number of these, is a 10-404 needed on each well? > I don't want to commit the time to doing this if it is not necessary; > 10-404's are time consuming to prepare. Would a list of the jobs suffice, > or something similar? We have the well numbers, depth to cement top, and > sacks used to fill the void. My proposal would not affect future > submissions of 10-404's for this work. What do you think? Thanks! > > Jerry Dethlefs (See attached file: tom_maunder.vcf) 1of2 4/24/2003 7:55 AM Alpine cement .'op Fill . . ~.. . Name: AOGCC ALPINE cement top outs 04-16-03.xls ~AOGCC ALPINE cement top outs 04-16-03.xls Type: EXCEL File (application/msexcel) , ; Encoding: base64 -'--"""-~--'-"--'- ...--.----.....----..--...----.......-.. Name: Cement Top Fill AOGCC Letter 04-23-03.doc- '[]cement Top Fill AOGCC Letter 04-23-03.doc Type: WINWORD File (application/msword) Encoding: base64 - - . ! Tom Maunder <tom maunder@admin.state.ak.us> ' Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 2of2 4/24/2003 7:55 AM 86: CD.2-41 Annular Disposal Application (' Subject: Re: CD2-41 Annular Disposal Application Date: Man, 17 Mar 2003 08:27:44 -0900 From: "Vernon T Johnson" <Vern.Johnson@conocophillips.com> To: Tom Maunder <tom_maunder@admin.state.ak.us> Tom, I checked and could not find any record of the cement volume to surface for CD2-41. I suspect it is a matter documentation missing in our DIMS database. If we did not get cement to surface, there would have been additional operations to run a top job. I have asked Dowell to round up a copy of their cementing records, and I will forward them when I get them. Vern Johnson 907 -265-6081 (w) 907 -265-1515 (fax) 907-748-3906 (Cell) Vern .Johnson@conocophillips.com Tom Maunder <tom_maunder@admin.state.ak.us> 03/15/2003 12:54 PM To: Vernon T Johnson/PPCO@Phìllips cc: Subject CD2-41 Annular Disposal Application Vern, In the packet for CD2-41, I have not been able to find an information regarding getting cement to surface. Could you check the records and see if you have the volume circulated?? Thanks. Tom (See attached file: tom_maunder. vct) ( Tom Maunder <tom_maunder@admin.state.ak.us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 1 of 1 4/22/20034:32 PM CD2-41 Surface Cement Job . . Subject: CD2-41 Surface Cement Job Date: Mon, 17 Mar 2003 16:21 :21 -0900 From: ''Vernon T Johnson" <Vern.Johnson@conocophillips.com> To: Tom Maunder <tom_maunder@admin.state.ak.us> Tom, See the attached file showing the volume of cement pumped and the volume of cement circulated to surface. Let me know if there is anything else you need. Vern Johnson 907-265-6081 (w) 907-265-1515 (fax) 907-748-3906 (Cell) Vern .Joh nson@conocophillips.com ----- Forwarded by Vernon T Johnson/PPCO on 03/17/200303:17 PM ----- Michael W Martin 03/17/200301:08 PM To: Vernon T Johnson/PPCO@Phillips cc: Subject: CD2-41 Surface Cement Job Vern, Attached is the treatment report from the surface cement job. On the report it was noted that 114 bbls of cement was circulated to surface out of 287 bbls of lead pumped. The design called for 300% xs in the P-Frost or 490 sacks (387 bbls) - the job actually only pumped 365 sacks (287 bbls). I'm not sure of the reason for the change. If you need more information, give me another shout. Thanks, Mike (See attached file: CD2-41wrs.pdf) ~. .........~~ " ",._----""-"._.,,,.,_..;-''',,..,''',,.......,,---,.,,,,....._-''--'''''''''''''.''.'''--1 "f Name: CD2-41wrs.pdf j ¡ 0 CD2-41wrs.pdfl Type: Acrobat (application/pdf)! flEncoding: base64! .-".,.,.,"'., n',., -, "" -""",'''~'''' ,., -. . .. -. - . -.. --. '- , , '" ,., -... - , ,. ., " ,.., '_,,""'" ",'''' ,--".. ;," ," "'" ' """,., ." ., , '. ,~ 1 of 1 3/18/20037:03 AM Scblumbl'ler Customer Cementing Service Report I Well I I Field PHILLIPS-ALPINE I Location (legal) I [' Formation NamelType C40 I State/Province CD2 41 Alpine County Well Master: Rig Name North Slope 0630426729 Drilled For Alaska API I UWI: Service Via DOYON 19 Oil Well Class Well Type Development Plastic Vh cp Land Offshore Zone New Drilling Fluid Type Spud Mud Max. Density 9.6 Ib/gal 40 Service Line Job Type Cem Surface Casing Max. Allowed Ann. Pressure WellHead Connection Cementing Max. Allowed Tubing Pressure 3500 psi Service Instructions psi Double cement hea Provide Equipment,Materials And Personel To Cement Surface Casing As Instructed By Donnie LutricklScott Reynolds. TREATMENT # 2011-0548 Allocation $48,446.00 Material Cost $1813.63 Field Estimate $73,761.42 CasinglTubing Secured ~ Lift Pressure: 1 Hole Volume Circulated prior to Cementing~ psi No. Centralizers: Pipe Rotated 0 35 Pipe Reciprocated~ Bottom Plugs: Top Flugs: Double Cement Head Twe: Job Scheduled For: Arrived on location: Leave Location: 6/23/2002 Date 2002-Jun-23 22:45 2002-Jun-24 3:30 23:30 Time Pressure I, JOb~~~~~42131 i I Schlumberger Location Job Start 1 ! Prudhoe Bay, AK 2002-Jun-24~ Bit Size I Well MD Well TVD I 12.1 in I 2,562 ft 2,395 ft . BHST I BHCT Pore Press. Gradient I 60 of I 60 of Casing/Liner Size, in Weight, Ib/tt Deviation BHP Depth, ft 2552 Depth, psi 9.63 psi/ft Grade Thread 36 J55 Tubing/Drill Pipe Size, in Weight, Ibltt Grade Thread Top, ft Perf()fations/Qþen.Hole Bottom, ft spf No. of Shots Total Interval ft bbl 197.2 bbl Casing Tools Shoe Type: Float Shoe Depth: 2552 ft Stage Tool Type: Stage Tool Depth: Collar Type: Collar Depth: Treat Down Casing Tubing Vol. 24 hr clock psi 2002-Jun-24 1:03 -22 2002-Jun-24 1:03 2002-Jun-24 1:03 -22 2002-Jun-24 1:03 -19 2002-Jun-24 1:03 2002-Jun-24 1:04 -20 2002-Jun-24 1:05 -20 2002-Jun-24 1:06 -21 2002-Jun-24 1:07 -24 2002-Jun-24 1:08 -22 2002-Jun-24 1:09 -22 2002-Jun-24 1 :10 -11 2002-Jun-24 1 :10 2002-Jun-24 1 :10 -3 2002-Jun-24 1 :11 256 2002-Jun-24 1 :12 9 2002-Jun-24 1 :13 655 2002-Jun-24 1:14 3494 2002-Jun-24 1:14 2002-Jun-24 1:14 3488 2002-Jun-24 1:15 3364 2002-Jun-24 1 :15 -3 Jun 24,2002 WRS3 v3.302-SR Rate CMT DENS CMTSTGVOL CMT VOL 0 bbl/min Ib/gal bbl bbl 0 0.0 7.26 0.0 0.0 0 0.0 7.26 0.0 0.0 0 0.0 7.25 0.0 0.0 0 0.0 7.26 0.0 0.0 0 0.0 7.26 0.0 0.0 0 0.0 7.26 0.0 0.0 0 0.0 7.25 0.0 0.0 0 0.0 7.25 0.0 0.0 0 0.0 7.25 0.0 0.0 0 0.7 7.25 0.1 0.1 0 0.8 7.25 0.2 0.2 0 4.0 7.25 1.7 1.7 0 0.0 7.25 5.0 5.0 0 0.0 7.24 5.1 5.1 0 0.0 7.24 5.1 5.1 0 0.0 7.23 5.1 5.1 0 0.0 7.23 5.1 5.1 0 0.0 7.25 5.1 5.1 0 Displacement 190.5 bbl Casing Vol. ft Float 2465 ft 0 Diameter Packer Type in Packer Depth ft Annular Vol. OpenHole Vol 142.4 bbl Squeeze Job Squeeze Type Tool Type: 1.5 bbl Tool Depth: Tall Pipe Size: ft in Tail Pipe Depth: Sqz Total Vol: Message ft bbl 0 Safety Meeting 00:45 0 0 Nutplug by Rig 0 0 0 0 0 0 0 Start H2O Ahead 0 0 0 0 0 Pressure Test 0 0 0 Page 1 of 4 Well I Field ¡Service Date Customer IJOb Number CD2 #41 Alpine 02175-Jun-24 PHILLlPS-ALPINE I 2201042131 Date Time Pressure Rate I CMT DENS CMT STG VOL CMT VOL 0 0 Message 24 hr clock psi bbl/min Ib/gal bbl bbl 0 2002-Jun-24 1 :15 ¡DroP Bottom Plug 2002-Jun-24 1:16 9 0.0 7.24 5.1 5.1 0 0 2002-Jun-24 1:16 Reset Total, Vol = 5.24 bbl 2002-Jun-24 1:16 15 0.4 8.51 5.2 5.2 0 0 2002-Jun-24 1:17 13 0.4 8.52 0.2 5.4 0 0 2002-Jun-24 1:17 Batch MudPUSH XL 2002-Jun-24 1:17 14 0.4 8.72 0.3 5.5 0 0 2002-Jun-24 1:18 11 0.1 13.01 0.4 5.7 0 0 2002-Jun-24 1:19 13 0.4 11.67 0.8 6.0 0 0 2002-Jun-24 1 :19 Start MudPUSH XL 2002-Jun-24 1 :19 129 2.4 11.11 1.1 6.4 0 0 2002-Jun-24 1:20 442 4.8 10.55 3.3 8.6 0 0 2002-Jun-24 1 :21 645 6.7 11.28 9.6 14.8 0 0 2002-Jun-24 1:22 694 7.4 10.38 16.5 21.8 0 0 2002-Jun-24 1:23 682 7.4 10.43 23.9 29.1 0 0 2002-Jun-24 1:24 616 7.0 10.46 31.0 36.2 0 0 2002-Jun-24 1:25 408 5.5 10.53 37.6 42.8 0 0 2002-Jun-24 1:26 449 5.5 11.46 43.1 48.4 0 0 2002-Jun-24 1:26 Batch Lead Slurry 2002-Jun-24 1:26 9 0.4 9.74 45.9 51.2 0 0 2002-Jun-24 1:27 2 0.4 9.93 46.0 51.2 0 0 2002-Jun-24 1:28 -2 0.4 9.86 46.4 51.6 0 0 2002-Jun-24 1:28 -3 0.4 10.54 46.5 51.7 0 0 2002-Jun-24 1:28 Reset Total, Vol = 46.51 bbl 2002-Jun-24 1:28 255 3.6 10.55 0.3 52.1 0 0 2002-Jun-24 1:28 Remark 2002-Jun-24 1:28 Start Mixing Lead Slurry 2002-Jun-24 1:28 256 3.8 10.55 0.8 52.6 0 0 2002-Jun-24 1:29 286 3.9 10.77 2.1 53.8 0 0 2002-Jun-24 1:30 797 7.2 10.58 7.7 59.4 0 0 2002-Jun-24 1 :31 874 7.5 10.72 15.0 66.8 0 0 2002-Jun-24 1:32 852 7.5 10.67 22.6 74.3 0 0 2002~Jun-24 1:33 863 7.5 10.73 30.1 81.8 0 0 2002-Jun-24 1:34 832 7.5 10.73 37.6 89.4 0 0 2002-Jun-24 1:35 852 7.5 10.71 45.1 96.9 0 0 2002-Jun-24 1:36 815 7.5 10.73 52.7 104.4 0 0 2002-Jun-24 1:37 808 7.5 10.72 60.2 111.9 0 0 2002-Jun-24 1:38 812 7.5 10.72 67.7 119.5 0 0 2002-Jun-24 1:39 809 7.5 10.72 75.3 127.0 0 0 2002-Jun-24 1:40 796 7.5 10.75 82.8 134.5 0 0 2002-Jun-24 1 :41 799 7.5 10.74 90.4 142.2 0 0 2002-Jun-24 1:42 793 7.5 10.75 98.0 149.7 0 0 2002-Jun-24 1:43 785 7.5 10.74 105.5 157.2 0 0 2002-Jun-24 1:44 788 7.5 10.74 113.0 164.8 0 0 2002-Jun-24 1:45 770 7.5 10.74 120.5 172.3 0 0 2002-Jun-24 1:46 786 7.5 10.73 128.1 179.8 0 0 2002-Jun-24 1:47 778 7.5 10.74 135.6 187.3 0 0 ----- 2002-Jun-24 1:48 774 7.5 10.76 143.1 194.9 0 0 2002-Jun-24 1:49 791 7.5 10.76 150.7 202.4 0 0 2002-Jun-24 1:50 764 7.5 10.74 158.2 209.9 0 0 ~--,-- 2002-Jun-24 1 :51 784 7.5 10.74 165.7 217.5 0 0 2002-Jun-24 1:52 770 7.5 10.75 173.4 225.1 0 0 2002-Jun-24 1:53 766 7.5 10.73 180.9 232.6 0 0 2002-Jun-24 1:54 778 7.5 10.75 188.4 240.2 0 0 Jun 24,2002 WRS3 v3.302-SR Page 2 of 4 Well I Field Iservice Date Customer I Job Number CO2 #41 I Alpine ' 02175-Jun-24 PHILLlPS-ALPINE 2201042131 Date Time Pressure Rate CMT DENS CMT STG VOL CMT VOL 0 0 Message 24 hr I clock psi bbl/min Ib/gal bbl bbl 0 2002-Jun-24 1:55 775 7.5 10.74 196.0 247.7 0 0 2002-Jun-24 1:56 792 7.5 10.75 203.5 255.2 0 0 2002-Jun-24 1:57 780 7.5 10.74 211.0 262.8 0 0 2002-Jun-24 1:58 770 7.5 10.73 218.5 270.3 0 0 2002-Jun-24 1:59 760 7.5 10.73 226.1 277.8 0 0 2002-Jun-24 2:00 793 7.5 10.73 233.6 285.3 0 0 2002-Jun-24 2:01 811 7.5 10.74 241.1 292.9 0 0 2002-Jun-24 2:02 804 7.5 10.75 248.6 300.4 0 0 2002-Jun-24 2:03 807 7.5 10.75 256.2 307.9 0 0 2002-Jun-24 2:04 839 7.5 10.74 263.8 315.6 0 0 2002-Jun-24 2:05 883 7.5 10.74 271.3 323.1 0 0 2002-Jun-24 2:06 890 7.5 10.76 278.9 330.6 0 0 2002-Jun-24 2:07 354 4.6 11.18 285.3 337.1 0 0 2002-Jun-24 2:07 End Lead Slurry 2002-Jun-24 2:07 -14 0.2 10.95 287.3 339.0 0 0 2002-Jun-24 2:07 -13 0.3 10.48 287.3 339.1 0 0 2002-Jun-24 2:07 Start batch Tail 2002-Jun-24 2:08 -15 0.4 10.14 287.4 339.1 0 0 2002-Jun-24 2:09 -17 0.3 13.81 287.8 339.5 0 0 2002-Jun-24 2:09 -14 0.3 14.57 287.9 339.6 0 0 2002-Jun-24 2:09 Reset Total, Vol = 287.87 bbl 2002-Jun-24 2:09 161 2.7 15.91 0.4 340.0 0 0 364 sacks Lead 2002-Jun-24 2:09 Start Mixing Tail Slurry 2002-Jun-24 2:10 576 3.7 15.76 1.2 340.8 0 0 2002-Jun-24 2:11 786 5.3 15.70 6.1 345.8 0 0 2002-Jun-24 2:12 838 5.6 15.98 11.5 351.1 0 0 2002-Jun-24 2:13 801 5.6 15.81 17.1 356.7 0 0 2002-Jun-24 2:14 790 5.6 15.88 22.7 362.3 0 0 2002-Jun-24 2:15 745 5.6 15.83 28.2 367.9 0 0 2002-Jun-24 2:16 762 5.6 15.88 33.9 373.5 0 0 2002-Jun-24 2:17 804 5.8 15.84 39.6 379.2 0 0 2002-Jun-24 2:18 759 5.8 15.85 45.4 385.0 0 0 2002-Jun-24 2:19 753 4.8 17.09 50.7 390.3 0 0 2002-Jun-24 2:19 1 0.0 17.11 50.9 390.5 0 0 244 sacks Tail 2002-Jun-24 2:19 End Tail Slurry 2002-Jun-24 2:20 -0 0.0 13.01 50.9 390.5 0 0 2002-Jun-24 2:20 Drop Top Plug 2002-Jun-24 2:20 -2 0.0 13.01 50.9 390.5 0 0 2002-Jun-24 2:20 -0 0.0 13.01 50.9 390.5 0 0 2002-Jun-24 2:20 Start 20 H2O Behind 2002-Jun-24 2:21 542 6.0 11.36 3.1 393.6 0 0 2002-Jun-24 2:22 528 6.8 9.86 9.4 399.9 0 0 2002-Jun-24 2:23 504 6.8 8.80 16.2 406.7 0 0 2002-Jun-24 2:23 -14 0.0 8.53 20.2 410.7 0 0 2002-Jun-24 2:23 End H2O Behind 2002-Jun-24 2:24 -18 0.0 8.69 20.2 410.7 0 0 2002-Jun-24 2:24 Rig Pumps To Displace 2002-Jun-24 2:24 -28 0.0 8.70 20.2 410.7 0 0 2002-Jun-24 2:25 -30 0.0 8.68 20.2 410.7 0 0 2002-Jun-24 2:53 Plug Bumped 1705 Strks @ 02:40 2002-Jun-24 2:53 -33 0.0 -0.03 20.2 410.7 0 0 2002-Jun-24 2:54 -34 0.0 -0.03 20.2 410.7 0 0 2002-Jun-24 I 2:54 End Job Jun 24,2002 WRS3 v3.302-5R Page 30f 4 ." Well I Field ¡Service Date Customer [JOb Number CD2 #41 I Alpine 02175-Jun-24 PHILUPS-ALPINE 2201042131 I Date Time Pressure Rate CMT DENS CMT STG VOL CMT VOL 0 0 Message 24 hr clock psi bblfmin Ibfgal bbl bbl 0 0 2002-Jun-24 12:54 -32 0.0 -0.03 20.2 I 410.7 0 0 Post Job Summary Slurry Average Pump Rates, N2 Mud bpm Maximum Rate Total Slurry Volume of Fluid Injected. bbl Mud Spacer N2 6.5 7.5 339 I Breakdown Fluid Volume 0 46.5 Maximum Final Treating Pressure Summary, psi Average Bump Plug to Breakdown Density 890 504 650 1050 L bblL Displacement Mix Water Temp I ~ Cement Circulated to Surface? Volume 190.5 bbl 70 of D Washed Thru Perfs To Schlumberger Supervisor Ib/gal 114 bbl Avg. N2 Percent Designed Slurry Volume % 625 bbl ft Customer or Authorized Representative Lutrick, Donnie Doughten, Steven 0 Circulation Lost ~ Job Completed Jun 24.2002 WRS3 v3.302-5R Page 4 of 4 ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 Conoc~hillips March 7, 2003 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: Application for Sundry Approval for Annular Disposal of DrillinJJ Waste on well CD2-41 Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CD2-41 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 ACC 25.080. It is intended to begin annular disposal operations on CD2-41 approximately April 15, 2003. Please find attached form 10;.403 and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Surface Casing Description 4. Surface Casing Cementing Report & Daily Drilling Report during cement job 5. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 6. Intermediate Casing Description 7. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 8. Formation LOT on 9-5/8" x 7" casing annulus 9. Plan View of Adjacent Wells 10. List of wells on CD2 pad and the lateral distance from the surface casing shoe. Further details regarding wells on CD2 pad within I.4 mile radius should be on file at the AOGCC. If you have any questions or require further information, please contact Vern Johnson at 265-6081, or Chip Alvord at 265-6120. ~reIY~ v-- --.. Vern Joh son Drilling Engineer OJ!tr 1°> cc: CD2-41 Well File Chip Alvord Nancy Lambert Sharon Allsup-Drake A TO-868 Anadarko ATO-1530 RECEIVED MAR 11 2003 Alaska or. & Gas Cori$. Conuni8lion Andlorage Re-enter suspended well - Time extension - Stimulate - Variance - Perforate - 6. Datum elevation (DF or KB feet) RKB 52.7' MSL feet 7. Unit or Property name ~n D~ ;;z~ St? lY~ Annular Injection STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon - Suspend - Alter casing - Repair well - Change approved program - 2. Name of Operator ConocoPhillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 1974' FNL, 1514' FEL, Sec. 2, T11N, R4E, UM At top of productive interval 2067' FNL, 1186' FEL, Sec. 11, T11N, R4E, UM At effective depth At total depth 22' FNL, 540' FWL, Sec. 13, T11N, R4E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: 13024 7219 13024 7219 measured true vertical Length 80' 2517' 9495' Casing Conductor Surface Production Size 16" 9.625" 7" Operational shutdown - Plugging - Pull tubing - 5. Type of Well: Development _X Exploratory - Stratigraphic - Service - (asp:371724,5974383) (asp: 371965, 5969005) (asp: 373637, 5965742) feet feet feet feet Plugs (measured) Junk (measured) Cemented 12 cu yds Portland Type III 361 sx AS IIIL. 243 sx Class G 125 sx Class G Perforation depth: measured open hole completion from 9532' - 13024' true vertical Tubing (size, grade and measured depth) 4.5",12.6#, L-80 @ 9205' Colville River Unit 8. Well number CD2-41 9. Permit number I approval number 202-126 10. API number 50-103-20424-00 11. Field I Pool Colville River Field/Alpine Oil Pool Measured Depth 114' 2554' 9532' True vertical Depth 114' 2366' 7196' RECEIV I) f ~ r. D .., .~ I'sn ,,¡t! \ ! i Packers & SSSV (type & measured depth) Baker S-3 packer @ 9083', Camco Bal-O SSSV @ 2008' Alm;kz !' .& 13. Attachments Description summary of proposal_XX 14. Estimated date for commencing operation April 15, 2003 16. If proposal was verbally approved Detailed operations program - 15. Status of well classification as: BOP sketch - Oil_X Name of approver Date approved Service - 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed /J ¿ /Î" P Chip Alvord /~- ¿~ LJC/\... Title: Alpine Drilling Team Leader Gas- Suspended - Questions? Call Vern Johnson 265-6081 Date 311t , D 3 Prepared by Sharon Allsup-Drake FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval no. "? ð Ø} Plug integrity - BOP Test - Location clearance - _\ - \' C\ <-")0 Z)""" -0 0 Mechanical.lntegrityTest- Subsequent form required 10- ~~~~~~~ \.a.\'è}'''>-fð~' Date f/¿ tt6~ Approved by order of the Commission ~ 12--~~ Commissioner "'. ...... .... ... .........-. .......-... (' Note to File( s) CD2-23 (202-134.. .303-080) CD2-19 (202-112...303-083) CD2-38 (202-171.. .30-082) CD2-41 (202-126.. .303-081 ) Colville River Unit (Alpine) ConocoPhillips Alaska, Inc Phillips has made application for annular disposal in the subject wells. The pertinent information for the wells has been examined and the following determinations made. SURFACE HOLE AND SURFACE CASING --No unusual events were reported while drilling the surface holes of any well. --Surface casing in all wells was cemented to surface. The attachments to the applications note that various amounts of cement were circulated from the wells. The actual pumped volumes were reviewed using the spreadsheet and the XS volumes left in the hole.were calculated to range from a low of 500/0 to a high of 150%. INITIAL lEAKOFF TESTS --Initialleakoff tests were conducted on all wells. It was not possible to pump into any well with slightly more than 16 ppg EMW applied. --The leak off pressure plot of CD2-23 is offset to the left of the casing pressure plot. The leak off plot does exhibit essentially linear response when pumping begins in contrast to the casing pressure plot. Beyond 10 strokes the casing pressure shows linear response and the slope of the linear section is similar to that of the leak off plot. It appears that some amount of air was in the mud present in the casing or drill pipe during the casing test --The leak off pressure plots ofCD2-38 and CD2-41 essentially overlay the casing test pressure plot. --The leak off pressure plot of CD2-19 lies slightly beneath the casing pressure plot. PRODUCTION HOLE AND PRODUCTION CASING --No unusual events were reported while drilling any 8-1/2" hole section. --7" casing was successfully run and cemented in each well. SUBSEQUENT INJECTION TESTS M:\tommaunder\Well Information\By Subject\Annular Disposal\030422-CD2 AD.doc --Subsequent injectivity tests were done down the 9-5/8" x 7" annuli of each well. In each case the formation failures were lower than the than the stabilized 81 pressures from the initialleakoff tests. PROXIMATE WELLS Proximity analyses to identify any wells within 1/4 mile radius were performed for each well. CD2-23 CD2-19 CD2-38 CD2-41 There are 15 existing wells within 1/4 mile of the surface casing shoe. The nearest well is CD2-15, 205' distant. Annular disposal has been approved and successfully. conducted in 11 of the wells including CD2-15. Annular disposal is recommended for the other wells analyzed in this document. There are 23 existing wells within 1/4 mile of the surface casing shoe. The nearest well is CD2-28, 153' distant. Annular disposal has yet to be requested in CD2-28, although there is nothing in the LOT information that would preclude approving such a request. Annular disposal has been approved and successfully conducted in 11 of the remaining wells and is recommended for the 3 other wells analyzed in this document. There are 20 existing wells within 1/4 mile of the surface casing shoe. The nearest well is CD2-36, 173' distant. Annular disposal has yet to be requested in CD2-36, although there is nothing in the LOT information that would preclude approving such a request. Annular disposal has been approved and successfully conducted in 11 of the wells and is recommended for the 3 other wells analyzed in this document. There are 23 existing wells within 1/4 mile of the surface casing shoe. The nearest well is CD2-38, 279' distant. CD2-38 is analyzed in this document and is recommended for annular disposal. Annular disposal has been approved and successfully conducted in 13 of the wells and is recommended for the 3 other wells analyzed in this document. Based on examination of the submitted information, I recommend approval of Phillips' requests for the subject wells. ~1YZ~ Tom Maunder, PE Sr. Petroleum Engineer April 22, 20Q2 M:\tommaunder\Well Infonnation\By Subject\Annular Disposal\030422-CD2 AD.doc ( Annular Disposal Transmittal Form a. Designation of the well or wells to receive drilling wastes. CD2-41 b. The depth to the base of freshwater aquifers and There are no USDW aquifers in the Colville River permafrost, if present. Unit. Base of Permafrost = 1552' TVD (RKB) c. A stratigraphic description of the interval exposed to the open annulus and other information sufficient to support a commission finding that the waste will be confined and will not come to the surface or contaminate freshwater. The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Lower Cretaceous Torok Formation provide a lower barrier. Calculated water salinities of the Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/I. (Ref. AOGCC Conservation Order No. 443, March 15, 1999) d. A list of all publicly recorded wells within one- See attached map indicating wells within 1/4 mile. quarter mile and all publicly recorded water There are no water wells within 1 mile. wells within one mile of the well to receive drilling waste. e. Identify the types and maximum volume of Types of fluids can be mud, diesel, cement, and waste to be disposed of and the estimated density water. Maximum volume to be pumped is 35,000 of the waste slurry. bbls. f. An estimate of maximum anticipated pressure at Maximum anticipated pressure at casing shoe the outer casing shoe during annular disposal during disposal operations is 1906 psi. See operation and calculations showing how this attached calculation page. value was determined. g. Details that show the shoe of the outer casing is See attached cementing reports, LOT /FIT reports, set below the base of any freshwater aquifer and and casing reports. permafrost, if present, and cemented with sufficient cement to provide zone isolation. h. Details that show the inner and outer casing See attached casing summary sheet and calculation strings have sufficient strength in collapse and page. burst to withstand anticipated pressure of disposal operations. i. Any additional data required by the Commission NA to confirm containment of drilling wastes. CD2-41 Pressure Calculations for Annular Disposal . DETAILS: ~ '- '- () () "0 "O m co Q) .J::. .J::. '~ ëñ a. 0 0 Q) 8 0 c C'\, 0 'ëi) C'\, co + + Ü ~ E := ~ () .ëi) LO a. a. I "'"" ~ ~ ci ci ~ () () co co (!) (!) <=:9-5/8" 36 lb/ft, J-55 BTC casing @ 2554 ft MD (2366 ft TVD) Pburst = 3520 psi, @ 85%: Pburst85% = 2992 psi .......... .... .... ".. "fö'ë Z Z Estimated Top of Cement @ 8840 ft MD (6865 ft TVD) (7" csg x 8-1/2" Open hole annulus) Q) c :ë ::J .... := ~ Q) ~ C I 'ëi) ~ co Ü <=:4-1/2" 12.6 lb/ft L-80 tubing to 9205 ft MD := I' L ~ <=:7" 26 lb/ft, L-80, BTC casing @ 9532 ft MD (7196 ft TVD) P collapse = 5410 psi, @ 85%: P collapse85% = 4598 psi ~ ASSUMPTIONS: . Maximum injection pressure, P Applied = 1500 psi . Maximum density of injection fluid is 12.0 ppg. . Pore pressure at 9-5/8" casing shoe is 0.4525 psi/ft . Injection gas pressure is 0.1 psi/ft + 2000 psi header pressure CALCULATIONS: Maximum pressure at 9-5/8" shoe: Pmax = PHydrostatic + P Applied - PPormation Pmax = 12.0 (0.052) (2366)+ 1500 - 0.4525 (2366) Pmax = 1906 psi Maximum fluid density to burst 9-5/8" casing: Pburst85% = PHydrostatic + P Applied - PPormation 2992 = MWmax (0.052) (2366) + 1500 - 0.4525 (2366) MWmax = 20.8 ppg Maximum Fluid Density to Collapse 7" Casing: P collapse85% = PHydrostatic + P Applied - P GasGradient - PHeader 4598 = MWmax (0.052) (6865) + 1500 - (0.1) (6865) - 2000 MW max = 16.2 ppg ß ( Casing Detail 9 518" Surface Casing (lJPHILLlPS Alaska, Inc. ~ A Subsidiary of PHilLIPS PETROLEUM COMPANY Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Jts 3 to 60 Doyon 19 RKB to LDS FMC Gen V Hanger 9-5/8" 36# J-55 BTC Csg Davis Lynch Float Collar 9-5/8" 36# J-55 BTC Csg Davis Lynch Float Shoe 58 Jts Jts 1 to 2 2 Jts 9- 5/8" shoe @ TD 12 1/4" Surface Hole RUN TOTAL 35 BOWSPRING CENTRALIZERS - 1 per jt on Jt #1 - #12 (On stop rings of Jt #1 & #2) #14,16,18,20,22,24.26,28,30,32,34,36,38, 40, 42, 44, 46, 48, 50, 52,54, 56 & 58 68 joints total in shed - 60 joints total to run Last 8 joints stay out. # 61 thru # 68. Use API Mod Best 0 Life Artie Grade Csg Compound. Remarks: Up Wt - K Ibs Dn Wt - K Ibs Block Wt 75K Ibs Well: CD2-41 Date: 6/23/2002 LENGTH 36.90 2.19 2428.11 1.51 84.03 1.69 Supervisor: Reynolds/Lutrick DEPTH TOPS 36.90 39.09 2467.20 2468.71 2552.74 2554.43 2564.43 ~~ ~ ~~ ConocoPhillips Alaska Cementing . Report Legal Well Name: CD2-41 Common Well Name: CD2-41 Event Name: ROT - DRILLING Hole Size: TMD Set: Date Set: Csg Type: Csg Size: Primary 12.250 (in) 2,553 (ft) 6/24/2002 Surface Casing 9.625 (in.) Cmtd. Csg: OPEN HOLE Cement Co: Dowell Schlumberger Page 1 of 3 Report #: Start: Spud Date: 6/22/2002 1 Report Date: 6/24/2002 6/22/2002 End: 7/31/2002 Cement Job Type: Primary Squeeze Open Hole Hole Size: sa TMD: (ft) sa Date: sa Type: Squeeze Casing Hole Size: TM D Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Cementer: Steve Doughten Cmtd. Csg: Rot Time Start:: Time End:: RPM: Rec Time Start:23:00 Time End: 00:45 SPM: 1 Type: Cement Casing Volume Excess %: 100.00 Meas. From: 160 Time Circ Prior To Cementing: 1.75 Mud Circ Rate: 336 (gpm) Mud Circ Press: 350 (psi) Plug Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: (ft) (ft) Pipe Movement Pipe Movement: Reciprocating Init Torque: (ft-Ibf) Stroke Length: 3.0 (ft) Avg Torque: (ft-Ibf) Drag Up: (Ibs) Max Torque: (ft-Ibf) Drag Down: (Ibs) Start Mix Cmt: 01 :26 Start Slurry Displ: 02:21 Start Displ: 02:21 End Pumping: 02:40 End Pump Date: 6/24/2002 Top Plug: Bottom Plug: Disp Avg Rate: 8.00 (bbllmin) Disp Max Rate: 8.00 (bbl/min) Bump Plug: Press Prior: (psi) Press Bumped: (psi) Press Held: (min) Float Held: Mud Data Returns: 100 Total Mud Lost: (bbl)"",. ( Cmt Vol to Surf: (bbl») Ann Flow After: Mixing Method: Density Meas By: Type: Density: (ppg) Visc: (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type: PVIYP: (cp)/ (lb/100ft2) Gels 10 sec: (lb/100ft2) Gels 10 min: (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: (ppg) Volume: (bbl) Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: (OF) To: (ft) Description: MUDPUSH XL Class: Cmt Vol: (bbl) Density: 12.50 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Purpose: PRI MARY Mix Water: (gal) Foam Job: N Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) CF) Pressure (psi) (psi) Printed: 9/1212002 3:06:20 PM ~,. ~ ~ ConocoPhillips Alaska Cementing Report Page 2 of 3 Legal Well Name: CD2-41 Common Well Name: CD2-41 Event Name: ROT - DRILLING Report #: Start: Spud Date: 6/22/2002 1 Report Date: 6/24/2002 6/22/2002 End: 7/31/2002 Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Slurry Data Fluid Type: LEAD Slurry Interval: (ft) Water Source: Stage No: 1 Slurry No: 2 of 4 To: (ft) Description: ARCO WASH Class: Cmt Vol: (bbl) Density: 8.40 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Purpose: PRIMARY Mix Water: (gal) Foam Job: N Temperature: CF) Temperature: CF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) (OF) Stage No: 1 Slurry No: 3 of 4 Description: ASLite Class: To: 2,000.00 (ft) Cmt Vol: 284.0 (bbl) Density: 10.70 (ppg) Yield: 4.42 (ft3/sk) Slurry Vol:361 (sk) Water Vol: (bbl) Other Vol: 0 Purpose: PRIMARY Mix Water: (gal) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: (OF) Temp (OF) (OF) Pressure (psi) (psi) Slurry Data Fluid Type: TAIL Description: Slurry Interval: 2,553.00 (ft)To: 2,018.00 (ft) Cmt Vol: 50.0 (bbl) Water Source: LAKE Slurry Vol:243 (sk) Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Trade Name D-46 D-65 s001 Class: G Density: 15.80 (ppg) Yield: 1.17 (ft3/sk) Water Vol: 29.0 (bbl) Other Vol: 0 Purpose: TAIL Mix Water: 20.70 (gal) Foam Job: N Temperature: CF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: (OF) Type DEFOAMER DISPERSANT Units 0.20 %BWOC 0.30 %BWOC 2.00 %BWOC Temp (OF) (OF) Pressure (psi) (psi) % BWOC % BWOC % BWOC Printed: 9/12/2002 3:08:20 PM ~~ œ ~ ConocoPhillips Alaska Cementing Report Page 3 of 3 Legal Well Name: CD2-41 Common Well Name: CD2-41 Event Name: ROT - DRILLING Report #: Start: Spud Date: 6/22/2002 1 Report Date: 6/24/2002 6/22/2002 End: 7/31/2002 Casing Test Shoe Test Liner Top Test Test Press: 2,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: N Pressure: (ppge) Tool: N Open Hole: (ft) Hrs Before Test: Liner Lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N Log/Survey Evaluation IntètþretationSummary CBL Run: N Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: N Hrs Prior to Log: N Cement Top: (ft) How Determined: TOC Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: N Printed: 9/12/2002 3:08:20 PM Phillips Alaska, Inc. Daily DriUing Report I JOB NUMBER EVENT CODE 124 HRS PROG TMD I TVD I DFS ODR 563.0 2,563.0 2,373.0 1.85 FIELD NAME I OCS NO. AUTH MD I DAILY TANG Alpine 13,018.0 0.00 ACCIDENTS LAST 24 HRS. ? DAILY INT WIO MUD NO Diverter system 0.00 24 HR FORECAST DATE OF LAST SAFETY MEETING DAILY TOTAL Cement surface. NU and test BOPE. Drill out. LOT. 6/23/2002 117,272 LITHOLOGY I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE 998E11 LAST SURVEY: DATE TMD INC AZlM LASTCASING I NEXT CASING 6/23/2002 2,499.51 44.330 180.320 (in) @ (ft) (in) @ DENSITY(ppg) I 9.60 I PP I IECD 19.60 I MUD DATA I DAILY COST I 0.00 FV PVIYP GELS WUHTHP FCIT.SOL OILlWAT %Sarid/MBT Ph/pM PflMf 129 11/34 32/38 14.4/ 3/ / 0.2/20.0 8.8/ 0.05/0 t" , I .~ WELL NAME CD2-41 SUPERVISOR RIG NAME & NO. Reynolds / Lutrick doyon1@ppco.co Doyon 19 CURRENT STATUS BHA NO. I 1 I BHA WT. BELOW JARS STRING WT. UP BHA 1 HOLE CONDITIONS STRING WT. DN STRING WT. ROT ITEM..DESCRIPTION NOJT.$ 1 1 1 1 1 1 1 2 1 1 1 3 1 23 BIT MXCI NAVIDRILL M1C SNMDC NMSTAB SNMDC MWD W/FLOA T UBHO NMDC NMSTAB NMDC CROSSOVER HWDP JARS HWDP LENGTH 1.00 27.80 9.92 5.63 9.40 30.35 3.27 61.71 5.54 30.83 3.65 90.47 32.69 687.77 0.0. 12.250 12.125 8.125 12.125 8.125 8.000 8.000 8.062 12.250 8.063 8.062 5.000 6.250 5.000 BITS SERIAL NO. JETS OR TFA 6003983 10/12/12/18// BIT / RUN SIZE MANUF. TYPE 1/ 12.250 HTC MXC1 BIT / RUN WOB RPM GPM 11 / / BIT OPERATIONS PRESS P BIT HRS Page 1 of 2 REPT NO. IDA TE 3 6/23/2002 I CUM. TANG 0.00 CUM INTANG WI MUD 0.00 CUM COST WI MUD 457,061 AUTH. 3,750,606 LAST BOP PRES TEST (ft) I CUMCOST I CI CéI H2S 40 0.00 LIME ES TORQUE / UNITS I BIT NO. I 1 BHA LENGTH 1,000.03 CONN$IZE ..CØNN;f¥PE 2.875 2.875 2.875 1.920 3.000 2.875 2.875 2.875 3.000 3.000 2.250 3.000 DEPTH IN DATE IN I-O-D-L-B~G-O-R 114.0 6/22/20022-1-WT-H-E-1-EC-TD 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 563.0 11.60 2,563.0 220.95 M.D. INCL. AZIMUTH 2,074.90 33.590 169.240 2,170.29 36.640 171.190 2,265.45 38.820 172.920 SURVEY DATA T.V.D. N/S CUM E1W CUM SECTION M.D. 2,000.04 -270.92 251.93 357.73 2,361.11 2,078.07 -324.99 261.22 409.78 2,453.70 2,153.33 -382.66 269.24 464.42 2,499.51 INCL. AZIMUTH T.V.D. N/S CUM E1W CUM SECTION 41.270 176.390 2,226.56 -443.91 274.93 521.11 44.440 180.000 2,294.44 -506.83 276.85 577.49 44.330 180.320 2,327.18 -538.87 276.76 605.70 OPERATIONS SUMMARY PHASE DESCRIPTION SURFAC Dr i II 1 2 1/4" d ire C t ion a I h 0 I e fro m 2000 I to 2563' ADT - 6.7 hrs ART - 3.0 hrs AST - 3.7 hrs SURFAC P u m phi - vis s wee p. C ire h 0 lee I e an. SURFAC PO H to 1000 '. No pro b Ie m s. R I H toT D. SURFAC P u m phi - vis s wee p. C ire h 0 I e C I e an. FROM TO HOURS CODE TROUBLE SUB 00:00 08:30 8.50 DRILL P DRLG 08:30 09:00 0.50 DRILL P 09:00 12:00 3.00 DRILL P 12:00 13:30 1.50 DRILL P CIRC WIPR CIRC Printed: 9/12/2002 3:12:55 PM WELL NAME FROM TO 13:30 15:30 15:30 18:00 18:00 19:00 19:00 19:30 19:30 22:30 HOURS 2.00 2.50 1.00 0.50 3.00 CD2-41 CODE DRILL P DRILL P CASE P CASE P CASE P 22:30 23:00 0.50 CASE P 23:00 00:00 1.00 CASE P (' Phillips Alaska, Inc. Daily Drilling Report ¡JOB NUMBER EVENT CODE 124 HRS PROG TMD ODR 563.0 2,563.0 TROUBLE SUB TRIP TRIP RURD SFTY RUNe RURD CIRC Page 2 of 2 I TVD I DFS I REPT NO. IDA TE 2,373.0 1.85 3 6/23/2002 OPERATIONS SUMMARY PHASE DESCRIPTION SURFAC P 0 H. S t d b a e k H W D Pan d jar s . SURFAC L D B H A. C I ear f I 0 0 r. SURFAC RUt 0 run 9 5/8" c s 9 . SURFAC P J S M 0 n run n i n 9 e s 9 . SURFAC R I H wI 6 0 j t s 9 5/8" c s g. M U and I a n 9 e r wI s h 0 I e at 2553'. SURFAC R D fill up too I. B low do W n top d r i v e. M U e em en t head. SURFAC C ire and eon d it ion mud. 24 HR SUMMARY: Drill 12 1/4" hole from 2000' to 2563'. Cond mud. Wipertrip to 1000' Cond mud. POH LD BHA. RIH w/9 5/8" csg to 2553'. COMPANY PHILLIPS Doyon ARCA DSR BHI Fuel TYPE CD2-32 ITEM UNITS gals NO. SERVICE USAGE 1,049 CD2-41 PERSONNEL DATA NO. HOURS COMPANY 3 MI 26 Dowell 5 Sperry-Sun 4 Mise 1 MATERIALS 1 CONSUMPTION ON HAND ITEM 6,932 Water UNITS bbls REMARKS SUPPORT CRAFT TYPE NO. 2 3 3 1 USAGE 670 Printed: 9/12/2002 3:12:55 PM Phillips Alaska, Inc. Daily Drilling Report II JOB NUMBER I EVENT CODE 124 HRS PROG TMD I1VD I DFS ODR 20.0 2,583.0 2,387.0 2.85 I FIELD NAME I OCS NO. AUTH MD I DAILY TANG Alpine 13,018.0 0.00 ACCIDENTS LAST 24 HRS.? DAILY INT WIO MUD 0.00 DATE OF LAST SAFETY MEETING DAILY TOTAL Drill 8 1/2" hole 6/23/2002 232,230 I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE AUTH. 16.01 998E11 3,750,606 LAST SURVEY: DATE TMD INC AZlM I LAST CASING I NEXT CASING LAST BOP PRES TEST 6/23/2002 2,499.51 44.330 180.320 9.625 (in) @ 2,553.0 (ft) 7.000 (in) @ 9,687.0 (ft) 6/24/2002 DENSITY(ppg) I 9.60 I PP I I ECD 19.911 MUD DATA I DAILYCOST I 0.00 I CUM COST I 0.00 FV PVIYP GELS WUHTHP FCIT.SOL OIUWAT %Sand/MBT Ph/pM Pf/Mf CI Ca H2S LIME ES 54 11/17 9/18 14.2/ 2/ / 0.1/20.0 10.1/ 0.24/0 80 "=' ~ .~ WELL NAME CD2-41 SUPERVISOR I RIG NAME & NO. Reynolds / Lutrick I doyon1@ppco.co Doyon 19 CURRENT STATUS Drilling ahead @ 3307' MD 24 HR FORECAST UTHOLOGY Ii3HA NO. I 2 I BHA WT. BELOW JARS STRING WT. UP BHA 1 HOLE CONDITIONS STRING WT. DN STRING WT. ROT ITEM DESCRIPTION NO JTS 1 1 1 1 1 3 1 3 1 23 1 3 BIT DP-0912 PDC NAVIDRILL M1XP NMSTAB GAMMA SUB MWD W/FLOA T DPCSNM CROSSOVER HWDP JARS HWDP CROSSOVER HWDP LENGTH 1.00 23.03 4.45 27.21 22.08 88.87 1.67 90.47 32.69 687.77 1.37 91.99 O.D. 8.500 8.375 8.125 6.750 6.750 4.500 6.250 5.000 6.250 5.000 6.500 4.000 BIT I RUN 2/ SIZE MANUF. 8.500 HTC BI~ljS TYPE SERIAL NO. JETS OR TFA DP0912 7000566 12/12/12/12/121 BIT I RUN 2/ GPM BIT OPERATIONS PRESS P BIT HRS 24Hr DIST 24Hr ROP CUM HRS CUM DEPTH CUM ROP 20.0 20.0 OPERATIONS SUMMARY PHASE DESCRIPTION SURFAC C ire and con d it ion mud. SURFAC P J SM. Do well t est e d I i n est 0 3500 psi. P u m p e d 4 0 viscosified nut plug spacer, drop bottom plug, 50 bbls mudpush, 284 bbls 10.7 ppg lead and 50 bbls 15.8 ppg tail, drop top plug, and 20 bbls H2 O. Rig displaced w/ 171 bbls mud. Bumped plug. Floats OK. Unable to reciprocate csg more than 3 I witout hanging up. Suspect csg cplg hanging up at base of the conductor. SURFAC R D c e men the a d. L D L J . SURFAC N D d i v e r t e r s y s t em. SURFAC Ins t a II F M C well h e ad. WOB / RPM / TO HOURS CODE TROUBLE SUB 00:00 00:30 0.50 CASE P CIRC 00:30 03:00 2.50 CEMENT P PUMP 03:00 04:00 1.00 CEMENT P 04:00 05:30 1.50 WELCTL P 05:30 06:30 1.00 CASE P RURD NUND NUND Page 1 of2 I REPT NO. IDA TE 4 6/24/2002 I CUM. TANG 0.00 CUM INTANG WI MUD 0.00 CUM COST WI MUD 689,291 TORQUE I UNITS I BIT NO. I 2 BHA LENGTH 1,072.60 CONN SIZE CONN TYPE I.D. 2.875 1.920 1.920 2.875 2.875 3.000 2.250 3.000 2.500 2.562 DEPTH IN DATE IN I-O-D-L-B-G-O-R 2,563.0 6/24/2002 O-O-EC-A-D-I-NO-PR Printed: 9/12/2002 3:13:45 PM ~ ~ .\~j WEll NAME CD2-41 Page 2 of 2 Phillips Alaska, Inc. Daily Drilling Report I JOB NUMBER I EVENT CODE 124 HRS PROG I TMD ODR I 20.0 2,583.0 FROM TO HOURS CODE TROUBLE SUB 06:30 07:00 0.50 WAlTON N :EQIP ORDR 07:00 08:00 1.00 WELCTL P 08:00 12:00 4.00 WELCTL P 12:00 12:30 12:30 14:30 14:30 17:00 17:00 18:00 18:00 19:30 19:30 20:00 20:00 21:00 21 :00 22:00 0.50 2.00 2.50 1.00 1.50 0.50 1.00 1.00 DRILL P DRILL P DRILL P RIGMNT P DRILL P CASE P CASE P CEMENT P 22:00 23:00 1.00 CASE P 23:00 23:30 0.50 CEMENT P 23:30 00:00 0.50 DRILL P NUND BOPE PULD PULD TRIP RSRV TRIP CIRC DEQT DSHO CIRC FIT CIRC I TVD I DFS I REPT NO. IDA TE 2,387.0 2.85 4 6/24/2002 OPERATIONS SUMMARY PHASE DESCRIPTION SURFAC Well he a d a Ii 9 n men t pin 9 mar k son con d u c tor not oriented correctly. Standby for construction ere w to verify well head alignment for proper flowlin e installation. SURFAC NU BOPE. SURFAC Ins t a II t est pi u g. T est BOP E to 250 - 5000 psi w / annular to 3500 psi. Witness of the test was wai ved by AOGCC. SURFAC R U s h 0 r t b a I e san d 0 Pel e vat 0 r s . SURFAC M U and s t d b a c k 57 j t s 4" 0 P . SURFAC M U B H A. R I H w / H W 0 Pan d jar s fr 0 m d e rr i c k . SURFAC Cut and s lip d rill i n 9 I i n e . SURFAC P U and R I H w / 4 2 j t s 4" 0 P t 0 2 4 4 5 I . SURFAC C ire and con d it ion mud. SURFAC T est c s 9 to 2500 psi for 30m in. 0 K. SURFAC 0 rill 0 u t c em e nt, f loa t e qui p men tan d 20' new h 0 I e to 2583' SURFAC C ire and con d it ion mud. SURFAC Per for me d 1 6.0 p p gEM W FIT. INTRM1 0 i s p I ace well to 9.5 P p 9 L S NOm u d . 24 HR SUMMARY: Cement 9 5/8" csg. NU diverter, NU and test BOPE. RIH w/ BHA. Test csg to 2500 psi. Drill cement and 20' new hole. FIT to 16 ppg. Displace mud. COMPANY PHILLIPS Doyon ARCA DSR BHI ITEM Fuel TYPE CD2-32 SERVICE UNITS gals NO. 1,869 CD2-41 USAGE 1,196 PERSON.NEL.......ÐATA NO. HOURS COMPANY 3 MI 25 Dowell 5 Sperry-Sun 4 Misc 1 SERVICE NO. 2 3 2 HOURS MATERIALS 1 CONSUMPTION ON HAND ITEM 5,736 Water UNITS bbls USAGE ON HAND 670 REMARKS SUPPORT CRAFT TYPE REMARKS NO. Printed: 9/12/2002 3:13:45 PM Well Name: Drilling Supervisor: CD2-41 I Rig: Donald Lutrick PRESSURE INTEGRITY TEST PHilliPS Alaska, Inc. Doyon 19 I Date: 6/24/2002 I Volume Input VolumelStroke Pump used: I #2 Mud Pump I... Strokes ... 0.1010 Bbls/Strk ... ... Pumping down annulus and DP. ... Type of Test: Casing Shoe Leak Off Test Hole Size: 18-1/2" I... . Casing Shoe Depth RKB-CHF: 36.0 Ft 2,553 Ft-MD 2,373 Ft-TVD Casina Size and Description: 19-5/8" 36#/Ft )-55 BTC Casina Test Mud Weight: 9.6 ppg Mud 10 min Gel 17.0 Lb/100 Ft2 Test Pressure 2,500 psi Rotating Weight (Pumps off 135,000 Lbs BlockslTop Drive Weight: 75,000 Lbs Estimates for Test: 1.6 bbls Hole Depth 2,583 Ft-MD 2,387 Ft- TVD I... Pressure IntearitvTes1 Mud Weight: 9.6 ppg Mud 10 min Gel: 17.0 Lb/100 Ft2 Rotating Weight (Pumps off): 135,000 Lbs BlockslTop Drive Weight: 75,000 Lbs Desired PIT EMW: 16.0 ppg Estimates for Test: 790 psi I... 0.5 bbls I... EMW = Leak-off Pressure + Mud Weight = 790 9 6 0.052 x TVD 0.052 x 2373 + . EMW at 2553 Ft-MD (2373 Ft-TVD) = 16.0 ppg 3000 . 2500 - 2000 - w 0:: ::::» ~ 1500- W 0:: 0.. 1000 - 500 - 0 0 2 Barrels ~CASING TEST ~LEAK-OFF TEST Comments: PIT 15 Second Shut-in Pressure, psi 785 - Lost 55 psi during test, held - = 97.8% of test pressure. ~jjjJ¡J JI. A-~ ~~ 3 4 0 5 10 15 20 25 Shut-In time, Minutes 0 PIT Point Casing Test Pumping Shut-in Strks psi Min psi 0 20 0 2525 2 50 1 2500 4 190 2 2500 6 360 3 2500 8 520 4 2500 10 710 5 2500 12 860 6 2500 14 1000 7 2500 16 1160 8 2500 18 1340 9 2500 20 1530 10 2475 22 1750 15 2475 24 1960 20 2470 26 2200 25 2470 28 2430 30 2470 30 2600 30 Volume Bled Back 2.8 tibls Volume Pumped 3.0 tibls Pump Rate: 0.5 Bbl/min ... Pressure Integrity Tes1 Pumping Shut-in Strks psi Min psi 0 0 0 790 1 15 0.25 785 2 '1E:> 90 0.5 780 3 ø 180 1 770 4 \OÙ 280 1.5 760~, 5 lJv 340 2 760 6 /9Ò400 2.5 755 7 ~O460 3 755 8 G Ù520 3.5 750 9 ~Ò 600 4 750 10 (00 660 4.5 745 11 0Ò720 5 745 12 '1<)790 5.5 740 6 740 6.5 740 7 740 7.5 735 8 735 8.5 735 9 730 9.5 73h 10 73 Volume Pumped 1.2 tibls Volume Bled Back 1 .0 tsbls Phillips Alaska, Inc. Casing Detail 7" Intermediate Casinq Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN Jts 3 to 224 Jts 1 to 2 Remarks: 222 Jts 2 Jts Up Wt = Doyon 19 RKB to LOS FMC 11" X 7" Hanger 7" 26# L-80 SrCM Csg 7" Davis Lynch Float Collar 7" 26# L-80 STCM Csg 7" Davis Lynch Float Shoe 1 straight blade centralizer per jt # 1 thru # 16 #'s 164, 165, & 166 then every other jt fl #168 to # 222. Total Centralizers: 47 238 joints in pipe shed - 224 jts. to run - last 14 joints stay out Top of Alpine - 9340' MD -7144' TVD Use Best-o-Life 2000 pipe dope On Wt = Block Wt= 75K (' 7" shoe @ 8-1/2" TO Supervisor: Mickey / Lutrick Well: CD2-41 Date: 6/28/2002 LENGTH 35.20 1.65 9413.34 1.42 78.55 1.72 DEPTH TOPS 35.20 36.85 9450.19 9451.61 9530.16 9531.88 9555.00 (' ( /PHI~LlPS'~ W .~~ ConocoPhillips Alaska Cementing Report Page 1 of2 Legal Well Name: CD2-41 Common Well Name: CD2-41 Event Name: ROT - DRILLING Report #: Start: Spud Date: 6/22/2002 2 Report Date: 6/30/2002 6/22/2002 End: 7/31/2002 Cement Job Type: Primary Hole Size: TM D Set: Date Set: Csg Type: Csg Size: Primary 8.500 (in) 9,532 (ft) 6/30/2002 Intermediate Casing/Li 7.000 (in.) Squeeze Casing Hole Size: TMD Set: Date Set: Csg Type: sa TMD: sa Date: Cmtd. Csg: Cementer: Jim Thompson Hole Size: Top Set: BTM set: Plug Date: Plug Type: Drilled Out: Cmtd. Csg: Pipe Movement: Reciprocating Squeeze Open Hole Hole Size: sa TMD: (ft) sa Date: sa Type: Cmtd. Csg: Production Casing Cement Co: Dowell Schlumberger Cmtd. Csg: Pipe Movement Plug (ft) (ft) Rot Time Start:: Time End:: RPM: Rec Time Start:03:30 Time End: 07:30 SPM: 3 Init Torque: (ft-Ibf) Stroke Length: 20.0 (ft) Avg Torque: (ft-Ibf) Max Torque: (ft-Ibf) Drag Up: 325,000 (Ibs) Drag Down: 150,000 (Ibs) Stage No: 1 of 1 Type: Cement Casing Start Mix Cmt: 07:35 Disp Avg Rate: 5.50 (bbl/min) Returns: 100 Volume Excess %: 40.00 Start Slurry Displ: 07:35 Disp Max Rate: 6.00 (bbl/min) Total Mud Lost: (bbl) Meas. From: Start Displ: 07:43 Bump Plug: Y Cmt Vol to Surf: (bbl) Time Circ Prior End Pumping: 09:00 Press Prior: 760 (psi) To Cementing: 3.00 End Pump Date: 6/30/2002 Press Bumped: 1 ,200 (psi) Ann Flow After: N Mud Circ Rate: 231 (gpm) Top Plug: Y Press Held: 10 (min) Mixing Method: Mud Circ Press: 650 (psi) Bottom Plug: Y Float Held: Y Density Meas By: Type: Non-Disp. LS Density: 9.6 (ppg) Vise: 42 (s/qt) Bottom Hole Circulating Temperature: (OF) Displacement Fluid Type: Brine PVIYP: 8 (cp)/19 (lb/100ft2) Gels 10 sec: 7 (lb/100ft2) Gels 10 min: 13 (lb/100ft2) Bottom Hole Static Temperature: (OF) Density: 9.3 (ppg) Volume: 337.00 (bbl) Stage No: 1 Slurry No: 1 of 3 Slurry Data Fluid Type: FLUSH Slurry Interval: (ft) Water Source: To: (ft) Description: ARCo wash Class: Cmt Vol: 20.0 (bbl) Density: 8.30 (ppg) Yield: (ft3/sk) Slurry Vol: (sk) Water Vol: (bbl) Other Vol: 0 Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid Loss Pressure: Time Compressive Strength 1: Compressive Strength 2: Temperature: (OF) Temperature: (OF) Temperature: CF) (OF) Purpose: PRe- Flush Mix Water: (gal) Foam Job: N Temp (OF) (OF) Pressure (psi) (psi) Printed: 9/12/2002 3:09: 17 PM ¡;HI~LlPS'~ m .~~ ConocoPhillips Alaska Cementing Report Page 2 of2 Legal Well Name: CD2-41 Common Well Name: CD2-41 Event Name: ROT - DRILLING Report #: Start: Spud Date: 6/22/2002 2 Report Date: 6/30/2002 6/22/2002 End: 7/31/2002 Stage No: 1 Slurry No: 2 of 3 Slurry Data Fluid Type: Mud Push XL Slurry Interval: (ft) To: (ft) Water Source: Description: Cmt Vol: 50.0 (bbl) Slurry Vol: (sk) Class: Density: 12.50 (ppg) Yield: (ft3/sk) Water Vol: (bbl) Other Vol: 0 Purpose: SPACER Mix Water: (gal) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid Loss: (cc) Fluid loss Pressure: Temperature: (OF) Temperature: (OF) Temperature: (OF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) (OF) Stage No: 1 Slurry No: 3 of 3 Slurry Data Fluid Type: PRIMARY Description: Slurry Interval: 9,532.00 (ft)To: 8,840.00 (ft) Cmt Vol: 25.0 (bbl) Water Source: Slurry Vol:125 (sk) Class: G Density: 15.80 (ppg) Yield: 1.16 (ft3/sk) Water Vol: (bbl) Other Vol: 0 Purpose: PRIMARY Mix Water: (gal) Foam Job: N Test Data Thickening Time: Free Water: (%) Fluid loss: (cc) Fluid loss Pressure: Temperature: (OF) Temperature: CF) Temperature: CF) Time Compressive Strength 1: Compressive Strength 2: Temp (OF) (OF) Pressure (psi) (psi) (OF) Casing Test Shoe Test Test Press: 3,500 (psi) For: 30 (min) Cement Found between Shoe and Collar: N Pressure: (ppge) Tool: N Open Hole: (ft) Hrs Before Test: Liner lap: Pos Test: (ppge) Neg Test: (ppge) Hrs Before Test: Cement Found on Tool: N Tool: N Tool: N Log/Surv.ey Evaluation CBl Run: N Under Pressure: (psi) Bond Quality: Cet Run: Bond Quality: Temp Survey: N Hrs Prior to log: N Cement Top: (ft) How Determined: TOe Sufficient: N Job Rating: If Unsuccessful Detection Indicator: Remedial Cementing Required: Number of Remedial Squeezes: N Printed: 9/12/2002 3:09: 17 PM Phillips Alaska, Inc. Daily Drilling Report I' JOB NUMBER I EVENT CODE 124 HRS PROG TMD I TVD I DFS CD2-41 ODR 9,555.0 7,201.0 8.85 I RIG NAME & NO. I FIELD NAME IOCS NO. AUTH MD I DAILY TANG I doyon1@ppco.co Doyon 19 Alpine 13,018.0 0.00 ACCIDENTS LAST 24 HRS. ? DAILY INT WIO MUD 0.00 DATE OF LAST SAFETY MEETING DAILY TOTAL 6/23/2002 152,865 I JAR HRS OF SERVICE I BHA HRS SINCE INSP I LEAKOFF AFE AUTH. 16.01 998E11 3,750,606 LAST SURVEY: DATE TMD INC AZlM I LAST CASING I NEXT CASING LAST BOP PRES TEST 6/28/2002 9,472.17 75.930 161.600 9.625 (in) @ 2,553.0 (ft) 7.000 (in) @ 9,687.0 (ft) 6/24/2002 DENSITY(ppg) I 9.30 I PP I I ECD I I MUD DATA I DAILY COST I 0.00 I CUM COST I 0.00 FV PVIYP GELS WUHTHP FCIT.SOL OILJWAT %Sand/MBT Ph/PNl Pf/Mf CI Ca H2S LIME ES / / / / I / / WELL NAME SUPERVISOR Mickey / Lutrick CURRENT STATUS Rig released 24 HR FORECAST UTHOLOGY f Page 1 of2 I REPT NO. IDA TE 10 6/30/2002 I CUM. TANG 0.00 CUM INTANG WI MUD 0.00 CUM COST WI MUD 1,640,056 OPERATIONS SUMMARY FROM TO HOURS CODE TROUBLE SUB PHASE 00:00 03:00 3.00 CASE P RUNe INTRM1 03:00 03:30 0.50 CASE P 03:30 07:00 3.50 CEMENT P 07:00 09:00 2.00 CEMENT P 09:00 11 :00 2.00 CEMENT P 11 :00 14:00 3.00 CMPL TN P 14:00 15:30 1.50 WELCTL P 15:30 16:30 1.00 CMPLTNP 16:30 17:00 0.50 WELCTL P 17:00 19:00 2.00 CASE P 19:00 19:30 0.50 CMPLTN P 19:30 20:30 1.00 CMPL TN P 20:30 21 :00 0.50 CMPL TN P DESCRIPTION Continue running 7" 26# L-80 MBTC casing 224 jt s. total - MU landing joint - land casing in wellhe ad on mandrel hanger w/ shoe @ 9532' FC @ 94 50 I RD casing equipment & MU cement head Est. circulation - Begin circulating @ 2 BPM - Ha d brine leak from pit #6 to active pits - Circulate & condition mud - staging pumps up to 5.5 BPM @ 650 psi - Held PJSM Cement 7" casing - Pump 5 bbls. Arco wash - Te st lines to 3500 psi - Pump 15 bbls Arco wash - Pump 50 bbls Mud push spacer @ 12.5 ppg - drop btm plug - Mix & pump 25 bbls Class G wi additi ves @ 15.8 ppg - drop top plug w/ 20 bbls water f/ Dowell - switch to rig pumps & displace cemen t w/ 337 bbls. 9.3 bbls brine - bumped plug w/ 12 00 psi - floats held - CIP @ 0900 hrs - full retur ns throughout job RD cemnt lines & head - LD landing joint - Pull t hin wall wear bushing - set & test pack off to 50 00 psi - Change top pipe rams back to 3 1/2" X 6 OTHR INTRM1 CIRC INTRM1 PUMP INTRM1 OTHR INTRM1 RUNT NUND NUND NUND DEQT FRZP RURD NUND SUSPEN R U & run kill s t r i n g - 2 1 s t d s 4" 0 P ( 2 0 0 5 . 2 2 ') X 0 (4" XT 39 x 4 1/2" IBT), 1 jt 4 1/2" 12.6# L-80 IBT tbg , 4 1/2" tbg hanger - landed kill string w/ tbg hanger wI OE @ 2085' RKB SUSPEN N 0 BOP E . SUSPEN NUt r e e and t est t 0 5 0 0 0 psi. SUSPEN Pull T we. SUSPEN R U I i n est 0 t r e e. R U 0 0 well. T est I i n est 0 3 5 0 0 P si. Test 7" csg to 3500 psi for 30 min. OK. SUSPEN F r e e z e pro t e c t t b g I ann u Ius wit h die s e I . SUSPEN B low d 0 w n I i n e s. Ins t a II B P V wit h I u b r i cat 0 r . SUSPEN Rem 0 V e e x t r a ann u Ius val V e. S e cur ewe II. Rei e a s e rig at 2100 hrs Printed: 9/12/2002 3:10:28 PM WELL NAME CD2-41 ( Phillips Alaska, Inc. Daily Drilling Report TMD 9,555.0 I JOB NUMBER I EVENT CODE \24 HRS PROG I ODR ( Page 2 of 2 I TVD I DFS I REPT NO. IDA TE 7,201.0 8.85 10 6/30/2002 24 HR SUMMARY: RIH w/7" csg. Circ and condition mud. Cement csg. RIH w/4" DP to 2085'. ND BOP. NU tree. Test csg to 3500 psi. Freeze protect well. Release rig at 2100 hrs. COMPANY PHILLIPS Doyon AReA DSR BHI ITEM Fuel Water, Drilling CD2-32 SERVICE UNITS gals bbls 2,299 CD2-41 PERSONNEL DATA NO. HOURS COMPANY 2 MI 25 Dowell 5 Sperry-Sun 4 FMC 1 USAGE 490 MATERIALS 1 CONSUMPTION ON HAND ITEM 5,610 Water, Potable REMARKS SUPPORT CRAFT TYPE SERVICE NO. 3 2 4 1 HOURS UNITS bbls USAGE ON HAND -450 Printed: 9/12/2002 3:10:28 PM CASING AND PRESSURE INTEGRITY TEST PHilliPS Alaska, Inc. Doyon 19 Date: 7/1/2002 I Volume Input Pump used: I Cement Unit I... Barrels ... ... Pumping down annulus. ... Well Name: Drilling Supervisor: CD2-41 Rig: Don Mickey Type of Test: Annulus Leak Off Test for Disposal Adequacy Hole Size: 18-1/2" r... Casing Shoe Depth RKB-CHF: 35.2 Ft 2,553 Ft-MD 2,373 Ft-TVD CasinQ Size and Description: 19-5/8" 36#/Ft J-55 BTC ChanQes for Annular AdeQuacv Tes Enter outer casing shoe test results in comments Casing Description references outel casing string Hole Size is that drilled below outer casing. Use estimated TOC for Hole Depth. Enter inner casing 00 at right. Hole Depth 8,840 Ft-MD 6,862 Ft- TVD I... Pressure InteQritvTes1 Mud Weight: 9.6 ppg Inner casing 00 7.0 In. Desired PIT EMW: Estimates for Test: I... EMW = Leak-off Pressure + Mud Weight = 646 9 6 0.052 x TVD 0.052 x 2373 + . EMW at 2553 Ft-MD (2373 Ft-TVD) = 14.8 1000 - w IX: ::) ~ 500- W IX: 0.. 0 0 6 Barrels 8 10 2 4 ~CASING TEST ~LEAK-OFF TEST Comments: 9 5/8" shoe FIT to 16.1 pp~ ( prJ ~\> \ \\ Q \ ~L2y 12 15.0 ppg 666 psi 0.5 bbls I... PIT 15 Second Shut-in Pressure, psi 525 14 0 5 10 15 20 25 Shut-In time, Minutes 0 PIT Point Bbls/Strk ... Pump Rate: 0.5 Bbl/min ... Casing Tes1 Pumping Shut-in Bbls psi Min psi Pressure Integrity Tes1 Pumping Shut-in Bbls psi Min psi 0.5 71 0 540 1.5 81 0.25 525 2 101 0.5 515 2.5 116 1 510 3 136 1.5 505.~ 3.5 152 2 500 4 177 2.5 500 4.5 207 3 500 5 242 3.5 495 5.5 283 4 495 6 333 4.5 495 6.5 384 5 490 7 439 5.5 490 7.5 495 6 490 8 550 6.5 485 8.5 601 7 485 9 646 7.5 485 9.5 611 8 480 10 596 8.5 480 10.5 586 9 480 11 576 9.5 48~ 11.5 576 10 47 12 576 30 Volume Volume Volume Volume Pumped Bled Back Pumped Bled Back 0.0 ~bls _~bIS 12.0 ~bls --~bls Name CD2-41 -257.84 -1597 -1500 -1250 -tOOO -750 -SOO -250 -0 -250 -SOO -750 -tOOO -1250 -1500 -1597 WEll.. DETAILS ANTI-COLLISION SETIINGS COMPANY DETAILS PbiIIips Alaska Inc. &gioeeriog Kuparuk WEUPATH DETAILS CD2-41 +N/-S +F/-W Northing Easting Latilude Longitude Skit 371723.84 70"2O'17.689N 151°02'27.148W N/A Doyon 19 COO4I: 52.25ft Interpolation Method:MD Interval: 1.00 Depth Range From: 2554.00 To: 2555.00 Maximum Range: 1498.77 Reference: Defmitive Survey Rig: Ref. Datum: V.Section Angle 32.02 5974383.33 CalcuJation MeIhod: Mmim.nn Curvature mor System: ISCWSA Scan MeIhod: Horizontal Plane mor Smace: Elliptical + Casing Wammg MeIhod: Rules Based Origin Origin +N/.S +F/.W ~::¥VO 0.00 0.00 0.00 151.85° 0 From Cõlour 0 200 400 600 800 1000 1250 1500 1750 2000 2500 3000 4000 5000 6000 7000 8000 9000 ToMD 200 400 600 800 1000 1250 1500 1750 2000 2500 3000 4000 5000 6000 7000 8000 9000 11000 ~ 1/4 Mile Radius of CD2-41 ... 9-5/8" Csg Pt (@ 2354' MD /2366' TVD) Reference Azimuth Angle [deg] vs Centre to Centre Separation [500ft/in] SURFACE CASING SHOE SEPARATION FROM CD2-41 CD2-41 X Y Surface Casing Shoe ASP 4 Coordinates: 371990.58 5973802.52 Distance Suñace Suñace csg. Cement Casing Ann. Vol. from Object csg. Shoe X Shoe Y Wells .¡ Permit # Permit Date Report Tally No. of LOT Source well Start Date End Date well* Coord. Coord. CD2-35** --- x x 1 --- --- ---- 387 372312.31 5974017.68 CD2-24, CD2-33, CD2-33A, CD2-42 301-140 6/1/2001 x x 2 CD2-15 33992 6/1/2001 10/10/2001 912 371098.46 5973992.48 CD2-33 (+A&B), CD2-39, CD2-24 301-186 7/13/2001 x x 2 CD2-14, CD2-15 33999 7/16/2001 10/9/2001 1642 370630.11 5974721.81 CD2-33 B*** --- ----- x x 4 ---- ----- ---- 1837 370155.64 5973886.23 CD2-39'¡ 301-281 10/9/2001 x x 2 CD2-15, CD2-47, CD2-44 29945 10/10/2001 9/16/2002 398 372350.61 5973633.17 CD2-14 301-288 10/9/2001 x x 2 CD2-45, CD2-47, CD2-32 31073 11/13/2001 3/5/2002 1178 372202.47 5974960.87 "'~'''- CD2-15 301-308 11/6/2001 x x 2 CD2-50, CD2-25, CD2-44 31652 3/6/2002 9/21/2002 1655 370832.00 5974984.02 CD2-47 301-322 12/3/2001 x x 2 CD2-34, CD2-26 27349 12/17/2001 1/20/2002 913 371231.72 5973294.19 CD2-45 >/ 301-345 12/13/2001 x x 2 CD2-49, CD2-17 22991 1/20/2002 2/19/2002 776 372765.13 5973853.74 CD2-34 302-069 3/4/2002 x x 2 CD2-13, CD2-37 22842 10/17/2002 11/28/2002 664 371803.06 5974439.79 CD2-26 302-068 3/4/2002 x x 2 CD2-44, CD2-29, CD2-13 29626 9/7/2002 10/17/2002 776 371798.52 5974554.55 CD2-49 ¡ 302-070 3/4/2002 x x 2 CD2-50, CD2-46, CD2-22 27960 4/22/2002 5/28/2002 784 371252.38 5974065.93 CD2-17 302-122 4/10/2002 x x 2 CD-48, CD2-08 18181 5/29/2002 2/7/2003 870 371774.00 5974645.00 CD2-32 302-119 4/30/2002 x x 2 CD2-19, CD2-41, CD2-23 31113 6/14/2002 7/23/2002 856 371295.61 5974302.38 CD2-41, CD2-19, CD2-16, CD2-50"" 302-121 4/30/2002 x x 2 CD2-38 32000 7/24/2002 9/7/2002 535 371665.21 5974227.65 CD2-25 x x 2 NA 784 371594.00 5974479.00 CD2-46 -./ 302-273 9/20/2002 x x 2 NA 0 588 371694.80 5974310.85 CD2-22 302-274 9/20/2002 x x 2 CD2-08, CD2-36 13152 2/7/2003 2/20/2003 f 821 371678.61 5974562.30 CD2-28, CD2-35a, CD2-48 302-275 9/20/2002 x x 2 CD2-45, CD2-08 32000 12/10/2002 2/4/2003 365 371631.74 5973736.14 CD2-19 x x 2 NA 0 927 372284.88 5974681.33 CD2-41 x x 2 NA 0 0 371990.58 5973802.52 CD2-23 x x 2 NA 0 1609 371013.17 5975080.67 CD2-16 x x 2 NA 0 1094 372460.34 5974790.01 CD2-38 / x x 2 NA 0 279 372033.86 5973527.13 ~. CD2-44 ;¡ x x 2 NA 0 528 372034.57 5974328.53 CD2-29 x x 2 NA 0 1278 372652.44 5974896.02 CD2-13 x x 2 NA 0 2092 372658.78 5975785.31 CD2-37 x x 2 NA 0 1019 371569.79 5972874.47 CD2-28 x x 2 NA 0 938 372139.80 5974728.95 CD2-08 x x 2 NA 0 1920 372655.88 5975603.76 CD2-36 ..¿ x x 2 NA 0 295 371861.00 5973538.00 * Lateral distance in feet, between surface casing shoes, in the X-V plane ** CD2-35 was drilled from an ice pad in early 1998. The 9-5/8" x 7" annulus has not been permitted for annular disposal. ***CD2-33 B was a delineation well with a window milled out of 9-5/8" casing at 3840' MD (3062' TVD), shoe depth shown indicates window depth. It has not been permitted for annular disposal. **** As of 21-Feb-03 ( ~ PHilliPS Alaska, Inc. m. A Subsidiary of PHILLIPS PETROLEUM COMPANY ( Post Office Box 100360 Anchorage, Alaska 99510-0360 G. C. Alvord Phone (907) 265-6120 Fax: (907) 265-6224 November 7, 2002 Commissioner Cammy Oechsli Taylor Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for CD2-41 (202-126) Dear Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Alpine well CD2-41. If you have any questions regarding this matter, please contact me at 265-6120 or Vem Johnson at 265-6081. Sincerely, .¡{JL ~ G. C. Alvord Alpine Drilling Team Leader P AI Drilling GCA/skad RECEIVED NOV 1 3 2002 Alaska Oil & Gas Gons. Commission Anchorage ( ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Suspended 0 Service 0 ~ \ ,,\.,~. ~ ) j~' l~ (ASP: 371724,5974383) (ASP: 371965, 5969005) ~ ",1:.:1Þ.l:QZ- t I~,ZJ£,=,;,:, ;,'.."~~,,,,~,;;';:f':;~~;::.,;':!,,:,,';..,..,,r;~ , .> Oil 0 Gas 0 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface Abandoned 0 1974'FNL, 1514'FEL,Sec.2,T11N, R4E, UM At Top Producing Interval 2067' FNL, 1186' FEL, Sec. 11, T11N, R4E, UM At Total Depth 22' FNL, 540' FWL, Sec. 13, T11N, R4E, UM (ASP: 373637, 5965742) 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. RKB 37' feet ADL 380075 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. June 22,2002 July 29,2002 July 31,2002 " 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 13024' MD /7219' TVD 13024' MD /7219' TVD YES 0 No 0 22. Type Electric or Other Logs Run GR/Res 23. Classification of Service Well 7. Pennit Number 202-126/ 8. API Number 50-103-20424-00 9. Unit or Lease Name Colville River Unit 10. Well Number CD2-41 11. Field and Pool Colville River Field Alpine Oil Pool 15. Water Depth, if offshore 16. No. of Completions N/ A feet MSL 20. Depth where SSSV set SSSV @ 2008' MD CASING SIZE WT. PER FT. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD TOP BOTTOM Surface 114' Surface 2554' Surface 9532' 21. Thickness of Pennafrost 1577' MD AMOUNT PULLED 42" 12.25" CEMENTING RECORD 12 cu yds Portland Type III 361 sx AS III Lite, 243 sx Class G 125 sx Class G HOLE SIZE GRADE H-40 J-55 L-80 16" 62.5# 36# 26# 9.625" 8.5" 7" 4.5" TUBING RECORD DEPTH SET (MD) 9205' PACKER SET (MD) 9083' 24. Perforations open to Production (MD + TVD of Top and Bottom and interval, size and number) 25. SIZE open hole completion from 9532' - 13024' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A NOV 1 32002 masD 011.& Gas Gons. Commission Anchoraoe 26. 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) October 14, 2002 Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF W A TER-BBL 1 0/22/2002 12 hours Test Period> 1983 1980 0 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF W A TER-BBL press. 324 psi 1452 24-Hour Rate> 3966 3980 0 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core'chips. N/A RBOMS BFl NOV I 8 2002 Form 10-407 Rev. 7-1-80 j~Mu~q<ðN fI~VijR~E S~DE GAS-OIL RATIO 1257 CHOKE SIZE 97% OIL GRAVITY - API (corr) not available RECEIVED / Glj Submit in duplicate 29. 30. ( GEOLOGIC MARKERS FORMATION TESTS MEAS.DEPTH TRUE VERT. DEPTH Include interval tested, pressure data, all fluids recovered and gravity. GOR, and time of each phase. NAME CD2-41 Top Alpine D Top Alpine C 9298' 9342' 7127' 7145' R'BErHlVED NOV 1 32002 AJaslàt QU& Gas Gons. Commission Anchorage 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey 32. I hereby certify that the following is true and correct to the best of my knowledge. Questions? Call Vern Johnson 265-6081 Signed .,,4,Æ. "'-- 0tZ... Chip Alvord Title Alpine Drillinq Tearn Leader Date Il(e:( OJ-. Prepared by Sharon Allsup-Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 1 0-407 ( ~~ TfI"iI ~~ ( Page 1 of 6 PHILLIPS ALASKA INC. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-41 CD2-41 ROT - DRILLING doyon1 @ppco.com Doyon 19 . Sub Hours Code Code Phase Date From -To 6/21/2002 15:00 - 21 :00 6.00 MOVE MOVE MOVE 21 :00 - 00:00 3.00 WELCTL NUND SURFAC 6/22/2002 00:00 - 01 :00 1.00 WELCTL BOPE SURFAC 01 :00 - 01 :30 0.50 DRILL SFTY SURFAC 01 :30 - 02:00 0.50 DRILL REAM SURFAC 02:00 - 03:30 1.50 DRILL PULD SURFAC 03:30 - 00:00 20.50 DRILL DRLG SURFAC 6/23/2002 00:00 - 08:30 8.50 DRILL DRLG SURFAC 08:30 - 09:00 0.50 DRILL CIRC SURFAC 09:00 - 12:00 3.00 DRILL WIPR SURFAC 12:00 - 13:30 1.50 DRILL CIRC SURFAC 13:30 - 15:30 2.00 DRILL TRIP SURFAC 15:30 - 18:00 2.50 DRILL TRIP SURFAC 18:00 - 19:00 1.00 CASE RURD SURFAC 19:00 - 19:30 0.50 CASE SFTY SURFAC 19:30 - 22:30 3.00 CASE RUNC SURFAC 22:30 - 23:00 0.50 CASE RURD SURFAC 23:00 - 00:00 1.00 CASE CIRC SURFAC 6/24/2002 00:00 - 00:30 0.50 CASE CIRC SURFAC 00:30 - 03:00 2.50 CEMENT PUMP SURFAC 03:00 - 04:00 04:00 - 05:30 05:30 - 06:30 06:30 - 07:00 1.00 CEMENT RURD SURFAC 1.50 WELCTL NUND SURFAC 1.00 CASE NUND SURFAC 0.50 WAlTON ORDR SURFAC Start: 6/22/2002 Rig Release: 7/31/2002 Rig Number: Spud Date: 6/22/2002 End: 7/31/2002 Group: Description of Operations PJSM. Move motor and pit complexes. Jack f loor. Raise feet and wind walls. Move ig to CD2-41. Spot and level rig. Jack floor into p lace. Spot motor and pit complexes. NU diveter, riser, flowline, turnbuckles and mousehole. Take on spud mud. PU std of HWDP. Tag ice at 45'. Function te st diverter system. Witness of test was waiv ed by AOGCC rep Lou Gramaldi. Prespud meeting with all hands. MU 12 1/4" bit. Clean out conductor wI std 0 f HWDP. MU BHA. Drill 12 1/4" directional hole from 114' to 20 00'. Conductor was out of plumb by 1 to 2 d egrees to the south causing the well bore to cross the close approach hardline @ +1- 440 '. Corrective slides positioned the well bore path so it was diverging from the close appr oach hardline. Gyro single shots were take n every 30' of stand drilled. ADT - 11.6 hrs ART - 2.8 hrs AST - 8.8 hrs Drill 12 1/4" directional hole from 2000' to 2 563'. ADT - 6.7 hrs ART - 3.0 hrs AST - 3 .7 hrs Pump hi-vis sweep. Circ hole clean. POH to 1000'. No problems. RIH to TD. Pump hi-vis sweep. Circ hole clean. POH. Std back HWDP and jars. LD BHA. Clear floor. RU to run 9 5/8" csg. PJSM on running csg. RIH wI 60 jts 9 5/8" csg. MU and langer wi s hole at 2553'. RD fill up tool. Blow down top drive. MU ce ment head. Circ and condition mud. Circ and condition mud. PJSM. Dowell tested lines to 3500 psi. Pum ped 40 viscosified nut plug spacer, drop bot tom plug, 50 bbls mudpush, 284 bbls 10.7 P pg lead and 50 bbls 15.8 ppg tail, drop top plug, and 20 bbls H2O. Rig displaced wi 171 bbls mud. Bumped plug. Floats OK. Unable to reciprocate csg more than 3' witout hangi ng up. Suspect csg cplg hanging up at base of the conductor. RD cement head. LD LJ. ND diverter system. Install FMC well head. Well head alignment ping marks on conducto r not oriented correctly. Standby for constru c t ion ere w to v e r if y well h e a d a I i g n m en t for Printed: 8/20/2002 10:53:04 AM (~. TjTfi ~ ( PHILLIPS ALASKA INC. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-41 CD2-41 ROT - DRILLING doyon1 @ppco.com Doyon 19 Sub Hours Code Code Phase Date From - To 6/24/2002 06:30 - 07:00 07:00 - 08:00 08:00 - 12:00 0.50 WAlTON ORDR SURFAC 1.00 WELCTL NUND SURFAC 4.00 WELCTL BOPE SURFAC 12:00 - 12:30 0.50 DRILL PULD SURFAC 12:30 - 14:30 2.00 DRILL PULD SURFAC 14:30 - 17:00 2.50 DRILL TRIP SURFAC 17:00 - 18:00 1.00 RIGMNT RSRV SURFAC 18:00 - 19:30 1.50 DRILL TRIP SURFAC 19:30 - 20:00 0.50 CASE CIRC SURFAC 20:00 - 21 :00 1.00 CASE DEQT SURFAC 21 :00 - 22:00 1.00 CEMENT DSHO SURFAC 22:00 - 23:00 1.00 CASE CIRC SURFAC 23:00 - 23:30 0.50 CEMENT FIT SURFAC 23:30 - 00:00 0.50 DRILL CIRC INTRM1 6/25/2002 00:00 - 19:00 19.00 DRILL DRLG INTRM1 19:00 - 20:00 1.00 DRILL CIRC INTRM1 20:00 - 22:30 2.50 DRILL WIPR INTRM1 22:30 - 23:00 0.50 DRILL REAM INTRM1 23:00 - 00:00 1.00 DRILL DRLG INTRM1 6/26/2002 00:00 - 15:00 15.00 DRILL DRLG INTRM1 15:00 - 15:30 0.50 RIGMNT RGRP INTRM1 15:30 - 00:00 8.50 DRILL DRLG INTRM1 6/27/2002 00:00 - 02:30 2.50 DRILL DRLG INTRM1 02:30 - 04:00 1.50 DRILL CIRC INTRM1 04:00 - 07:30 3.50 DRILL WIPR INTRM1 07:30 - 08:00 0.50 DRILL REAM INTRM1 08:00 - 00:00 16.00 DRILL DRLG INTRM1 6/28/2002 00:00 - 02:00 2.00 DRILL DRLG INTRM1 02:00 - 03:00 1.00 DRILL CIRC INTRM1 Page 2 of 6 Start: 6/22/2002 Rig Release: 7/31/2002 Rig Number: Spud Date: 6/22/2002 End: 7/31/2002 Group: Description of Operations proper flowline installation. NU BOPE. Install test plug. Test BOPE to 250 - si w/ annular to 3500 psi. Witness of st was waived by AOGCC. RU short bales and DP elevators. MU and std back 57 jts 4" DP. MU BHA. RIH w/ HWDP and jars from 5000 P the te derrick Cut and slip drilling line. PU and RIH w/ 42 jts 4" DP to 2445'. Circ and condition mud. Test csg to 2500 psi for 30 min. OK. Drill out cement, float equipment and 20' ne w hole to 2583' Circ and condition mud. Performed 16.0 ppg EMW FIT. Displace well to 9.5 ppg LSND mud. Dril18 1/2" hole f/ 2583' to 4982' - 4110' TV D -ADT - 13.1 hrs AST - .3 hrs ART- 12.8 hrs. Pump hi-vis sweep. Circ hole clean. POH to shoe. No problems. RIH to 4887'. Precautionary ream from 4887' to 4982'. Drill 8 1/2" hole f/ 4982' to 5078' - 4176' TV D -ADT.5 hrs. ART- .5 Dril18 1/2" hole f/ 5078' to 7081'. Circ with #1 mud pump while replacing 2 sue tion valves on #2 mud pump. Dril18 1/2" hole f/ 7081' to 7815'. (TVD - 61 40') ADT - 16.1 hrs ART - 13.7 hrs AST- 2.4 hrs Dril18 1/2" hole f/ 7815' to 8036' MD 6284 'TVD ADT 2.2 hrs. ART 1.1 hrs AST 1.1 hrs Pump hi-vis sweep & circulate hole clean for wiper trip - 13 BPM @ 2800 psi - R&R pipe 110RPM Wiper trip f/ 8036' to 4887' - hole in good c ondition - monitor well (static) - RIH fI 4887 , to 7940' Wash & Ream f/ 7940' to 8030' - circulate hi vis sweep Dril18 1/2" hole f/ 8036' to 9207'. 7075' - T VD. ADT-10.7 hrs ART-6.0 hrs AST-4.7 hr s Dril18 1/2" hole fl 9270' to 9280'. ADT - 1.2 hrs, ART - .4 hrs, AST - .8 hrs. Finished slide at 9275'. Backreamed hole 20' with top drive inadvertantly in reverse. Made conne ction and drilled to 9280' while rotating pip e to MU any loose connections. Circulate btms up Printed: 8/20/2002 10:53:04 AM ~. TfTiI ~ PHILLIPS ALASKA INC. Operations Summary Report Legal Well Name: CD2-41 Common Well Name: CD2-41 Event Name: ROT - DRILLING Contractor Name: doyon1 @ppco.com Rig Name: Doyon 19 Date From - To Hours Code Sub Phase Code 6/28/2002 03:00 - 07:30 4.50 DRILL TRIP INTRM1 07:30 - 09:00 1.50 DRILL TRIP INTRM1 09:00 - 10:00 1.00 DRILL REAM INTRM1 10:00 - 00:00 14.00 DRILL DRLG INTRM1 6/29/2002 00:00 - 02:00 2.00 DRILL DRLG INTRM1 02:00 - 04:00 2.00 DRILL CIRC INTRM1 04:00 - 10:00 6.00 DRILL TRIP INTRM1 10:00 - 12:30 2.50 DRILL PULD INTRM1 12:30 - 14:30 2.00 CASE OTHR INTRM1 14:30 - 15:30 15:30 - 18:30 1.00 CASE RURD INTRM1 3.00 CASE RUNC INTRM1 6/30/2002 18:30 - 19:00 19:00 - 22:30 22:30 - 00:00 00:00 - 03:00 0.50 CASE CIRC INTRM1 3.50 CASE RUNC INTRM1 1.50 CASE CIRC INTRM1 3.00 CASE RUNC INTRM1 03:00 - 03:30 03:30 - 07:00 0.50 CASE OTHR INTRM1 3.50 CEMENTCIRC INTRM1 07:00 - 09:00 2.00 CEMENT PUMP INTRM1 Page 3 of 6 Start: 6/22/2002 Rig Release: 7/31/2002 Rig Number: Spud Date: 6/22/2002 End: 7/31/2002 Group: Description of Operations POOH & check connections on drill pipe. 1 j t each on #1 and #2 std loose. RIH f/ 5550' to 9184' Wash & ream f/ 9184' to 9280' - Circulate h i-vis sweep Drill 8 1/2" hole f/ 9280' to 9540' (TVD - 72 00') ADT - 7.4 hrs, ART - .8 hrs, AST - 6.6 hrs Drill 8 1/2" hole f/ 9540' to 9555' MD - 7201 'TVD ADT- 1.1 ART- 0 AST- 1.1 *Note: unable to make assembly drill - contact Dri lIing engineer & geologist - decision made t 0 pull out & set casing - proposed TD was 9 671' MD - 7210' TVD Pump hi-vis sweep - - Circulate hole clean @ 13 BPM - R&R pipe 110 PPM POOH to run 7" casing - @ 42 stds out - beg an to check remaining breaks on 4" DP Handle BHA - std back 5" HWDP & jars - LD NMCS DP, stab, MWD, Motor, & bit * Note: found thrust bearing on motor damaged LD 8" NMDC f/ derrick Pull wear bushing - Set test plug wI test joi nt - Change top pipe rams fl 3 1/2" x 6" to 7 " - test rams to 5000 psi - pull test plug & t est joint - set thin wall wear bushing RU to run 7" casing - Held PJSM Start runing 7" 26# L-80 MBTC casing - MU shoe track (float shoe - 2 jts. - float collar - 1 jt.) BakerLoc 1st. 4 connections - check floats - RIH to 2552' Circ and condition mud. (1 csg volume) RIH wI 7" csg to 6340'. Circ and condition mud at 4 bpm. Continue running 7" 26# L-80 MBTC casing 2 24 jts. total - MU landing joint - land casing in wellhead on mandrel hanger wI shoe @ 9 532' FC @ 9450' RD casing equipment & MU cement head Est. circulation - Begin circulating @ 2 BPM - Had brine leak from pit #6 to active pits - Circulate & condition mud - staging pumps up to 5.5 BPM @ 650 psi - Held PJSM Cement 7" casing - Pump 5 bbls. Arco wash - Test lines to 3500 psi - Pump 15 bbls Arc 0 wash - Pump 50 bbls Mud push spacer @ 1 2.5 ppg - drop btm plug - Mix & pump 25 bbl s Class G wI additives @ 15.8 ppg - drop to p plug wI 20 bbls water f/ Dowell - switch to rig pumps & displace cement wI 337 bbls. 9 .3 bbls brine - bumped plug wI 1200 psi - fl oats held - CIP @ 0900 hrs - full returns thr oughout job Printed: 8/20/2002 10:53:04 AM ( ~. ~ ~ ( PHILLIPS ALASKA INC. Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-41 CD2-41 ROT - DRILLING doyon1 @ppco.com Doyon 19 Sub Hours Code Code Phase Date From - To 6/30/2002 09:00 - 11 :00 2.00 CEMENTOTHR INTRM1 11 :00 - 14:00 3.00 CMPL TN RUNT SUSPEN 14:00 - 15:30 1.50 WELCTL NUND SUSPEN 15:30 - 16:30 1.00 CMPL TN NUND SUSPEN 16:30 - 17:00 0.50 WELCTL NUND SUSPEN 17:00 - 19:00 2.00 CASE DEQT SUSPEN 19:00 - 19:30 0.50 CMPL TN FRZP SUSPEN 19:30 - 20:30 1.00 CMPL TN RURD SUSPEN 20:30 - 21 :00 0.50 CMPL TN NUND SUSPEN 7/24/2002 14:00 - 18:30 4.50 MOVE MOVE MOVE 18:30 - 19:00 0.50 MOVE RURD RIGUP 19:00 - 21 :30 2.50 MOVE RURD RIGUP 21 :30 - 22:30 1.00 CMPL TN CIRC DECOMP 7/25/2002 22:30 - 00:00 00:00 - 01 :00 01 :00 - 04:00 1.50 WELCTL NUND DECOMP 1.00 WELCTL NUND DECOMP 3.00 CMPL TN PULL DECOMP 04:00 - 07:30 3.50 WELCTL BOPE DECOMP 07:30 - 11 :30 4.00 DRILL PULD INTRM1 11 :30 - 12:00 0.50 DRILL TRIP INTRM1 12:00 - 16:30 4.50 DRILL TRIP INTRM1 16:30 - 17:30 1.00 CEMENT COUT INTRM1 Page 4 of 6 Start: 6/22/2002 Rig Release: 7/31/2002 Rig Number: Spud Date: 6/22/2002 End: 7/31/2002 Group: Description of Operations RD cemnt lines & head - LD landing joint - P ull thin wall wear bushing - set & test pack off to 5000 psi - Change top pipe rams back to 3 1/2" X 6" RU & run kill string - 21 stds 4" DP ( 2005.2 2') XO (4" XT 39 x 4 1/2" IBT), 1 jt 4 1/2" 1 2.6# L-80 IBT tbg , 4 1/2" tbg hanger - land ed kill string wI tbg hanger wI OE @ 2085' R KB NO BOPE. NU tree and test to 5000 psi. Pull TWC. RU lines to tree. RU Dowell. Test lines to 3 500 psi. Test 7" csg to 3500 psi for 30 min. OK. Freeze protect tbgl annulus with diesel. Blow down lines. Install BPV with lubricator. Remove extra annulus valve. Secure well. R elease rig at 2100 hrs Move rig fl CD2- 23 - Spot & level rig - jack floor into place - spot motor & pit complex - hook ups service lines & safety equip. Pull BPV- Install outter valve on tbg X 7" an nulus - * Accept rig @ 1830 hrs RU hard lines to tbg & annulus - spot tank f or displacement PJSM - Test casing to 3000 psi for 10 mins - Displace freeze protect diesel wI 9.3 ppg brine - pumped 76 bbls @ 5 BPM @ 330 psi - RD down lines Install TWC - NO tree - NU BOPE NU BOPE MU landing jt. B - engage tbg hanger - Back out LDS - Pull hanger to floor - LD langing jt. - tbg hanger - 1 jt 4 1/2" tbg & XO - POO H & std back kill string (21 stds 4" drill pip e) Set test plug - test BOPE - Pipe rams, blind rams, choke & kill line valves, choke manif old valves, floor & top drive safety valves t 0 250 psi & 5000 psi - Hydril to 250 psi & 3 500 psi - AOGCC waived witnessing of test - pull test plug - set wear bushing M UB H A # 3 - c h a n g e 0 u t mot 0 r s & s tab - M U MWD - up load & load RA sources - RIH wI NM flex DC's, HWDP & jars to 394' PU 1 jt DP f/ shed -RIH to 421' - shallow te st MWD Continue RIH picking up 4" Dp f/ shed (78 jt s total) to 9335' - tagged up C I 0 c e men t s t r i n g e r s f I 93 3 5 I to 9 3 8 5' - P u I I back to 9363' Printed: 8/20/2002 10:53:04 AM ~~ TfTii ~ ( PHilliPS ALASKA INC. Operations Summary Report Legal Well Name: CD2-41 Common Well Name: CD2-41 Event Name: ROT - DRILLING Contractor Name: doyon1 @ppco.com Rig Name: Doyon 19 Date From - To Hours Code Sub Phase Code 7/25/2002 17:30 - 20:30 3.00 DRILL CIRC INTRM1 20:30 - 21 :30 1.00 CASE DEOT INTRM1 21 :30 - 00:00 2.50 CEMENT DSHO INTRM1 7/26/2002 00:00 - 02:00 2.00 CEMENT DSHO INTRM1 02:00 - 02:30 0.50 DRILL DRLG INTRM1 02:30 - 03:30 1.00 DRILL CIRC INTRM1 03:30 - 04:00 0.50 DRILL FIT INTRM1 04:00 - 00:00 20.00 DRILL DRLH PROD 7/27/2002 00:00 - 12:00 12.00 DRILL DRLH PROD 12:00 - 00:00 12.00 DRILL DRLH PROD 7/28/2002 00:00 - 12:00 12.00 DRILL DRLH PROD 12:00 - 00:00 12.00 DRILL DRLH PROD 7/29/2002 00:00 - 09:30 9.50 DRILL DRLH PROD 09:30 - 12:30 3.00 DRILL CIRC PROD 12:30 - 18:30 6.00 DRILL TRIP PROD 18:30 - 20:00 1.50 DRILL CIRC PROD 20:00 - 00:00 4.00 DRILL TRIP PROD 7/30/2002 00:00 - 01 :00 1.00 DRILL TRIP PROD 01 :00 - 03:00 2.00 DRILL PULD PROD Page 5 of 6 Start: 6/22/2002 Rig Release: 7/31/2002 Rig Number: Spud Date: 6/22/2002 End: 7/31/2002 Group: Description of Operations PJSM - Change well over f/ 9.3 brine to 9.4 ppg OBM - Pump 40 bbls water wI 110 gals Safe-surf 0 - 40 bbls hi vis OBM pill - 9.4 P pg OBM RU & test 7" casing to 3500 psi for 30 mins. RD C/O hard cmt f/ 9385' to 9448' - drill wiper plugs & FC @ 9450' & hard cmt f/ 9451' to 9 459' Continue C/O hard cement f/ 9459' to 9531' - Drill out shoe f/ 9531' to 9532' - C/O rat h ole to 9955' Drill 20' new hole f/ 9555' to 9575' Circulate hole clean for FIT - 5 BPM @ 1950 psi RU & perform FIT to 12.5 ppg EMW w/ 9.4 p pg mud wI 1160 psi - RD Dril16 1/8" hole f/ 9575' to 10268' MD 7203 'TVD Past 24 hrs. ADT 12.1 hrs. ART- 6. 1 hrs. AST- 6.0 hrs. Drill 6 1/8" hole f/ 10,268' to 10,864' MD 7 211' TVD ADT- 9.1 hrs. AST- 1.3 hrs. A RT- 7.8 hrs. Drill 6 1/8" hole f/ 10,864' to 11,434' MD 7 216' TVD ADT- 8.6 hrs. ART- 7.2 hrs. AS T- 1.4 hrs. Pumped 30 bbls hi-vis sweep @ 11273' - no excessive cuttings observed @ s hakers * Held surprise kick drill on PM cr ew - good response from crew Dril16 1/8" hole f/ 11434' to 11980' MD 721 7' TVD ADT- 9.2 ART- 7.9 hrs. AST- 1.3 hrs. Note: Seepage losses increased @ 11 870' - added MI mix II fine to control Dril16 1/8" hole f/ 11,980' to 12,534' MD 7 214' TVD ADT 9.5 hrs. ART- 8.7 hrs. AST - .9 hrs. Note: Pumped Low /Hi vis sweep @ 12,534' Drill 6 1/8" hole f/ 12534' to 13024' MD 721 8' TVD ADT- 7.98 hrs ART- 7.25 hrs AST-.73 Pump hi-vis sweep & circulate hole clean for trip @ 5 BPM @ 2650 psi - R&R pipe - moni tor well (static) POOH f/ 13024' to 8695' - Pumped 45 stds out of hole @ 3 BPM Circulate bottoms up @ 8695' Monitor well(s tatic) Continue POOH f/ 8695' to 1726' - Monitori ng well on trip tank Continue POOH fr/ 1726' to 110' - std back HWDP, jars & flex DC's Down load RA sources f/ MWD & down load d ata - LD MWD, XO's ,motor &bit Printed: 8/20/2002 10:53:04 AM ( ( ~~~ r¡v,. ~~ PHilliPS Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: CD2-41 CD2-41 ROT - DRILLING doyon1 @ppco.com Doyon 19 Sub Hours Code Code Phase Date From - To 7/30/2002 0.50 CMPL TN OTHR CMPL TN 03:00 - 03:30 03:30 - 04:30 04:30 - 13:30 1.00 CMPLTN OTHR CMPLTN 9.00 CMPL TN RUNT CMPL TN 13:30 - 14:30 1.00 CMPL TN RUNT CMPL TN 14:30 - 18:30 4.00 CMPL TN RUNT CMPL TN 18:30 - 19:30 1.00 CMPL TN RURD CMPL TN 19:30 - 21 :00 1.50 CMPL TN SEaT CMPL TN 21 :00 - 00:00 3.00 CMPL TN NUND CMPL TN 7/31/2002 00:00 - 01 :00 1.00 CMPL TN NUND CMPL TN 01 :00 - 01 :30 0.50 CMPL TN RURD CMPL TN 01 :30 - 03:30 2.00 CMPL TN FRZP CMPL TN 03:30 - 04:30 1.00 CMPL TN PCKR CMPL TN 04:30 - 06:30 2.00 CMPL TN DEaT CMPL TN 06.:30 - 07:30 1.00 CMPL TN OTHR CMPL TN 07:30 - 10:00 2.50 CMPL TN OTHR CMPL TN 10:00 - 10:30 0.50 RIGMNT RGRP CMPL TN 10:30 - 13:30 3.00 CMPLTN OTHR CMPL TN 13:30 - 14:00 0.50 CMPLTN OTHR CMPL TN Start: 6/22/2002 Rig Release: 7/31/2002 Rig Number: Spud Date: 6/22/2002 End: 7/31/2002 Group: Description of Operations PU stack washer & flush SOP stack - Pull w ear bushing RU to run completion - PJ8M Run 4 1/2" completion: WLEG - pup jt. - XN nipple/RHC plug installed - 2 jts. 4 1/2" 12. 6# L-80 1ST tbg - Saker 8-3 packer assembl y w/ mill out extension - 2 jts. 4 1/2" 12.6# L-80 1ST tbg - Saker CMD sliding sleeve ase mbly (in closed position) 2 jts. 4 1/2" 12.6 # L-80 1ST tbg - Camco GLM assembly w/ du mmy - 39 jts. 4 1/2" 12.6# L-80 1ST tbg - C am co GLM assembly w/ dummy - 73 jts. 4 1/ 2" 12.6# L-80 1ST tbg - Camco GLM assembl y w/ dummy - 44 jts. 4 1/2" 12.6# L-80 1ST t bg - Cameo SAL-O S8SV Total # jts. in hole 162 of 207 to run RU control line equip on rig floor - connect control lines to 8S8V & test to 5000 psi Continue running 4 1/2" completion - 207 jts total MU hanger and landing joint A, connect and test control lines to 5000 psi. Total of 53 S 8 bands installed. Land hanger, RILDS, LD LJa, install TWC. MU LJb, test hanger seals to 5000 psi, LD L J b. ND SOPE, install adapter flange and tree, te rminate SS8V controle lines. NU and test tree and adapter flange to 5000 psi. Pull TWC, RU circulating lines to wellhead. Test lines to 4000 psi, pumped 30 bbls of mi neral oil and 270 bbls of diesel @ 3.0 bpm, maintained back pressure schedule with cho ke on circulating manifold. RD hardline to tree, RU lubricator and dropp ed setting ball and rod. RU hardline to tree. Set packer and tested tubing to 3500 psi, bl ed to 3300 psi in 30 min. Tested 7" x 4 1/2" annulus to 3500 psi, bled to 3340 psi in 30 min. Sled and cleared lines, RD hard pipe a nd circ manifold. RU FMC lubricator and set SPV, Rd lubricat 0 r. LD excess 4" drill pipe from derrick. Inspect and repair broken springs on Iron R oughneck. Continue to lay down excess drill pipe, 152 joints total. Clean rig floor and police location, released rig @ 1400 hrs. ,. Printed: 8/20/2002 10:53:04 AM (' ( BAKER HUGHES INTEQ ======> ALPINE CD2-41 IFR Corrected Alaska State Plane VSect. Plane = l' Coordinates Measured Angle Azimuth TVD-RKB TVD X Y N/-S E/-W DLS SVY# Depth deg deg ft Subsea ft ft ft ft deg/100 ft 1 0.00 0.00 0.00 0.00 -52.00 371723.83 5974383.31 0.00 0.00 0.00 2 86.00 0.70 182.00 86.00 34.00 371723.80 5974382.79 -0.53 -0.02 0.81 3 176.00 0.60 182.00 175.99 123.99 371723.75 5974381.77 -1.55 -0.05 0.11 4 267.00 0.40 134.00 266.99 214.99 371723.95 5974381.07 -2.24 0.16 0.49 5 358.00 0.75 72.00 357.98 305.98 371724.74 5974381.02 -2.28 0.95 0.73 6 448.00 2.10 63.00 447.96 395.96 371726.79 5974381.92 -1.35 2.98 1.52 7 485.43 2.56 59.40 485.35 433.35 371728.13 5974382.63 -0.61 4.31 1.29 8 574.94 3.55 80.83 574.74 522.74 371732.61 5974384.01 0.85 8.77 1.67 9 664.77 4.75 84.77 664.33 612.33 371739.07 5974384.69 1.63 15.22 1.37 10 755.84 5.87 87.29 755.01 703.01 371747.49 5974385.11 2.19 23.63 1.26 11 842.56 7.89 89.12 841.10 789.10 371757.87 5974385.23 2.50 34.01 2.34 12 935.53 9.34 92.76 933.02 881.02 371771.78 5974384.73 2.23 47.92 1.67 13 1030.35 11.59 96.47 1026.26 974.26 371788.91 5974383.00 0.79 65.08 2.48 14 1125.32 14.17 98.62 1118.83 1066.83 371809.83 5974379.83 -2.03 86.05 2.76 15 1218.07 15.46 105.14 1208.50 1156.50 371832.90 5974374.51 -6.96 109.21 2.27 16 1314.15 15.58 116.34 1301.10 1249.10 371856.67 5974365.03 -16.03 133.14 3.12 17 1408.69 16.23 129.03 1392.05 1340.05 371878.08 5974350.71 -29.99 154.79 3.73 18 1503.22 17.16 138.15 1482.61 1430.61 371897.33 5974331.68 -48.70 174.36 2.94 19 1600.11 18.63 149.01 1574.83 1522.83 371914.43 5974307.46 -72.62 191.87 3.76 20 1694.86 21.25 157.38 1663.91 1611.91 371928.34 5974278.39 -101.46 206.27 4.08 21 1789.83 24.72 161.60 1751.34 1699.34 371940.64 5974243.44 -136.20 219.16 4.04 22 1882.14 27.82 164.55 1834.11 1782.11 371951.81 5974204.16 -175.29 231.00 3.64 23 1978.93 30.41 168.23 1918.67 1866.67 371962.06 5974158.22 -221.05 242.02 3.25 24 2074.90 33.59 169.24 2000.04 1948.04 371971.12 5974108.19 -270.92 251.93 3.36 25 2170.29 36.64 171.19 2078.07 2026.07 371979.50 5974053.98 -324.99 261.22 3.41 26 2265.45 38.82 172.92 2153.33 2101.33 371986.55 5973996.19 -382.66 269.24 2.55 27 2361.11 41.27 176.39 2226.56 2174.56 371991.19 5973934.85 -443.91 274.93 3.46 28 2453.70 44.44 180.00 2294.44 2242.44 371992.05 5973871.92 -506.83 276.85 4.33 29 2499.51 44.33 180.32 2327.18 2275.18 371991.42 5973839.88 -538.87 276.76 0.54 30 2630.75 44.02 180.40 2421.30 2369.30 371989.30 5973748.46 -630.33 276.19 0.24 31 2726.21 44.01 180.60 2489.95 2437.95 371987.60 5973682.16 -696.65 275.61 0.15 32 2821.31 43.98 180.36 2558.37 2506.37 371985.93 5973616.13 -762.71 275.05 0.18 33 2916.51 44.26 180.77 2626.71 2574.71 371984.16 5973549.88 -828.98 274.40 0.42 34 3011.99 44.39 181.59 2695.02 2643.02 371981.65 5973483.22 -895.68 273.03 0.62 35 3107.28 44.67 180.59 2762.95 2710.95 371979.26 5973416.45 -962.49 271.76 0.79 36 3202.63 44.84 180.95 2830.66 2778.66 371977.22 5973349.35 -1029.62 270.85 0.32 37 3298.10 43.80 179.65 2898.96 2846.96 371975.74 5973282.68 -1096.31 270.50 1.45 38 3393.84 43.60 179.24 2968.18 2916.18 371975.26 5973216.54 -1162.45 271.14 0.36 39 3489.53 43.62 179.54 3037.47 2985.47 371974.84 5973150.54 -1228.45 271.84 0.22 40 3584.90 43.27 178.22 3106.71 3054.71 371975.02 5973084.97 -1294.02 273.12 1.02 41 3680.72 43.11 178.75 3176.57 3124.57 371975.64 5973019.40 -1359.58 274.85 0.41 42 3775.21 42.99 178.23 3245.62 3193.62 371976.25 5972954.90 -1424.06 276.55 0.40 43 3869.16 43.08 178.23 3314.29 3262.29 371977.15 5972890.80 -1488.14 278.53 0.10 44 3966.56 44.22 180.86 3384.77 3332.77 371976.53 5972823.59 -1555.36 279.05 2.20 45 4062.32 44.30 181.20 3453.35 3401.35 371974.20 5972756.80 -1622.18 277.85 0.26 46 4158.31 43.90 180.97 3522.29 3470.29 371971.80 5972690.05 -1688.97 276.59 0.45 47 4253.80 43.79 180.34 3591.16 3539.16 371969.93 5972623.94 -1755.11 275.83 0.47 48 4349.50 43.53 180.55 3660.39 3608.39 371968.30 5972557.89 -1821 . 18 275.32 0.31 49 4444.98 43.67 180.62 3729.53 3677.53 371966.51 5972492.08 -1887.02 274.64 0.16 50 4540.34 43.35 180.71 3798.69 3746.69 371964.64 5972426.46 -1952.67 273.88 0.34 51 4636.18 45.21 180.46 3867.31 3815.31 371962.83 5972359.58 -2019.57 273.20 1.95 52 4731.71 45.50 180.28 3934.44 3882.44 371961.24 5972291.64 -2087.54 272.76 0.33 ( 53 4826.95 45.57 180.19 4001.15 3949.15 371959.82 5972223.69 -2155.51 272.48 0.10 54 4922.23 45.75 180.19 4067.74 4015.74 371958.44 5972155.56 -2223.65 272.26 0.19 55 5017.10 45.96 180.21 4133.82 4081.82 371957.05 5972087.50 -2291.73 272.02 0.22 56 5113.50 45.52 179.74 4201.10 4149.10 371955.91 5972018.48 -2360.77 272.05 0.57 57 5208.84 45.28 179.35 4268.04 4216.04 371955.30 5971950.60 -2428.65 272.59 0.38 58 5304.55 45.41 178.82 4335.31 4283.31 371955.24 5971882.53 -2496.72 273.68 0.42 59 5399.77 45.29 178.84 4402.23 4350.23 371955.48 5971814.79 -2564.45 275.06 0.13 60 5495.57 45.38 177.93 4469.57 4417.57 371956.25 5971746.67 -2632.56 276.98 0.68 61 5590.63 45.56 177.48 4536.23 4484.23 371957.81 5971678.92 -2700.27 279.69 0.39 62 5686.28 45.53 177.68 4603.22 4551.22 371959.54 5971610.68 -2768.48 282.58 0.15 63 5781.19 45.42 177.35 4669.78 4617.78 371961.33 5971543.04 -2836.08 285.51 0.27 64 5876.64 45.37 176.83 4736.80 4684.80 371963.64 5971475.13 -2903.95 288.96 0.39 65 5972.39 44.72 176.80 4804.45 4752.45 371966.26 5971407.43 -2971.61 292.72 0.68 66 6067.83 43.82 177.56 4872.79 4820.79 371968.41 5971340.85 -3038.15 296.01 1.09 67 6163.33 43.40 179.26 4941.94 4889.94 371969.13 5971274.99 -3103.99 297.84 1.30 68 6258.97 43.07 179.11 5011.62 4959.62 371968.95 5971209.48 -3169.49 298.77 0.36 69 6354.56 43.77 181.16 5081.06 5029.06 371967.68 5971143.81 -3235.19 298.61 1.65 70 6450.04 43.57 181.13 5150.12 5098.12 371965.25 5971077.93 -3301.10 297.29 0.21 71 6543.69 43.39 180.50 5218.07 5166.07 371963.24 5971013.52 -3365.54 296.37 0.50 72 6639.21 43.00 180.25 5287.71 5235.71 371961.71 5970948.17 -3430.92 295.94 0.45 73 6734.44 42.76 180.13 5357.49 5305.49 371960.40 5970883.38 -3495.72 295.73 0.27 74 6830.63 41.98 179.23 5428.56 5376.56 371959.66 5970818.57 -3560.54 296.09 1.03 75 6925.15 41.29 179.22 5499.20 5447.20 371959.45 5970755.78 -3623.33 296.94 0.73 76 7020.29 44.29 180.34 5569.01 5517.01 371958.59 5970691.17 -3687.95 297.17 3.25 77 7116.09 43.71 180.11 5637.93 5585.93 371957.20 5970624.64 -3754.50 296.90 0.63 78 7211.57 44.49 180.91 5706.49 5654.49 371955.48 5970558.23 -3820.94 296.31 1.00 79 7307.18 44.42 180.92 5774.74 5722.74 371953.28 5970491.31 -3887.89 295.24 0.07 80 7403.15 44.05 180.84 5843.50 5791.50 371951.12 5970424.40 -3954.83 294.21 0.39 81 7495.01 43.77 180.24 5909.68 5857.68 371949.44 5970360.72 -4018.54 293.61 0.55 82 7593.59 44.62 181.44 5980.36 5928.36 371947.27 5970292.04 -4087.24 292.60 1.21 83 7689.67 44.14 180.82 6049.03 5997.03 371944.81 5970224.89 -4154.43 291.27 0.67 84 7784.91 43.50 180.61 6117.75 6065.75 371942.87 5970158.98 -4220.37 290.45 0.69 85 7880.64 45.11 181.12 6186.25 6134.25 371940.73 5970092.16 -4287.22 289.43 1:72 86 7974.17 44.62 181.31 6252.54 6200.54 371938.21 5970026.24 -4353.19 288.03 0.54 87 8071.39 44.26 180.80 6321.97 6269.97 371935.81 5969958.23 -4421.23 286.78 0.52 88 8166.70 43.87 180.64 6390.45 6338.45 371933.85 5969891.97 -4487.51 285.95 0.43 89 8261.54 44.92 181.24 6458.22 6406.22 371931.64 5969825.67 -4553.85 284.86 1.19 90 8356.81 44.22 180.70 6526.09 6474.09 371929.38 5969758.85 -4620.70 283.72 0.84 91 8452.60 43.34 180.71 6595.25 6543.25 371927.44 5969692.61 -4686.97 282.91 0.92 92 8547.96 45.77 181.23 6663.19 6611.19 371925.17 5969625.76 -4753.86 281.77 2.58 93 8641.57 46.66 181.47 6727.97 6675.97 371922.44 5969558.24 -4821.42 280.17 0.97 94 8737.02 46.16 181.14 6793.78 6741.78 371919.69 5969489.17 -4890.54 278.60 0.58 95 8834.46 45.59 180.91 6861.62 6809.62 371917.26 5969419.27 -4960.47 277.35 0.61 96 8867.66 45.96 180.40 6884.78 6832.78 371916.59 5969395.49 -4984.26 277.07 1.57 97 8899.28 47.36 179.47 6906.48 6854.48 371916.23 5969372.50 -5007.26 277.10 4.92 98 8929.40 49.13 177.82 6926.53 6874.53 371916.38 5969350.03 -5029.72 277.64 7.16 99 8962.98 51.36 176.95 6948.01 6896.01 371917.13 5969324.23 -5055.50 278.82 6.93 100 8994.49 53.25 176.18 6967.27 6915.27 371918.20 5969299.33 -5080.39 280.32 6.30 101 9024.74 54.79 175.27 6985.05 6933.05 371919.62 5969274.89 -5104.80 282.14 5.64 102 9056.10 55.89 174.50 7002.88 6950.88 371921.48 5969249.17 -5130.49 284.44 4.05 103 9091.54 56.64 173.42 7022.56 6970.56 371924.09 5969219.81 -5159.80 287.55 3.30 104 9120.33 57.12 171.67 7038.29 6986.29 371926.81 5969195.86 -5183.71 290.67 5.36 105 9154.89 58.00 170.21 7056.83 7004.83 371930.92 5969166.99 -5212.51 295.27 4.38 106 9186.97 58.79 169.44 7073.65 7021.65 371935.29 5969140.02 -5239.40 300.10 3.20 107 9216.25 60.04 167.99 7088.54 7036.54 371939.81 5969115.22 -5264.12 305.03 6.03 108 9250.01 61.96 166.97 7104.91 7052.91 371945.72 5969086.30 -5292.94 311.43 6.27 109 9281.95 63.47 165.23 7119.55 7067.55 371952.07 5969058.64 -5320.49 318.25 6.77 110 9311.54 65.11 164.29 7132.39 7080.39 371958.65 5969032.80 -5346.21 325.26 6.24 111 9344.39 67.37 163.24 7145.62 7093.62 371966.56 5969003.81 -5375.08 333.67 7.48 112 9376.00 69.59 162.47 7157.22 7105.22 371974.76 5968975.57 -5403.17 342.34 7.38 ( ( 113 9407.10 71.74 161.91 7167.52 7115.52 371983.26 5968947.48 -5431.11 351.32 7.12 114 9440.79 73.90 161.97 7177.47 7125.47 371992.72 5968916.72 -5461.71 361.29 6.41 115 9472.17 75.93 161.60 7185.63 7133.63 372001.70 5968887.79 -5490.49 370.77 6.57 116 9492.94 77.59 161.56 7190.39 7138.39 372007.76 5968868.51 -5509.67 377 .15 7.99 117 9588.62 85.26 157.24 7152.652 7204.652 372038.467 5968779 -5598.13 410.454 9.174 118 9631.61 89.2 153.69 7154.729 7206.729 372055.623 5968739.65 -5637.178 428.28 12.329 119 9680.23 91.35 148.21 7154.496 7206.496 372078.49 5968696.77 -5679.662 451.878 12.107 120 9725.38 91.23 146.45 7153.479 7205.479 372102.202 5968658.36 -5717.658 476.242 3.906 121 9777.73 91.72 146.05 7152.132 7204.132 372130.527 5968614.36 -5761.171 505.317 1.208 122 9821.56 92.03 146.92 7150.698 7202.698 372154.087 5968577.43 -5797.694 529.504 2.106 123 9872 91.85 146.94 7148.99 7200.99 372180.867 5968534.72 -5839.939 557.012 0.359 124 9917.33 91.72 146.12 7147.578 7199.578 372205.204 5968496.5 -5877.733 581.999 1.831 125 9968.17 90.68 145.29 7146.513 7198.513 372233.121 5968454.03 -5919.724 610.638 2.617 126 10015.75 90.55 145.16 7146.003 7198.003 372259.584 5968414.49 -5958.804 637.774 0.386 127 10064.74 90.55 147.2 7145.532 7197.532 372286.149 5968373.33 -5999.5 665.039 4.164 128 10110.06 90.25 147.74 7145.216 7197.216 372309.861 5968334.71 -6037.709 689.408 1.363 129 10157.71 88.65 148.13 7145.673 7197.673 372334.461 5968293.91 -6078.087 714.703 3.456 130 10204.29 87.35 149.32 7147.299 7199.299 372357.943 5968253.71 -6117.872 738.869 3.783 131 10254.9 87.66 149.37 7149.502 7201.502 372382.975 5968209.78 -6161.368 764.649 0.62 132 10300.4 88.09 149.29 7151.189 7203.189 372405.496 5968170.28 -6200.477 787.842 0.961 133 10351.68 88.46 149.06 7152.733 7204.733 372431.004 5968125.83 -6244.492 814.107 0.849 134 10393.96 88.77 148.42 7153.755 7205.755 372452.316 5968089.32 -6280.623 836.04 1.682 135 10445.47 88.95 150.25 7154.78 7206.78 372477.819 5968044.58 -6324.92 862.305 3.569 136 10493.65 89.32 150.15 7155.507 7207.507 372501.042 5968002.38 -6366.724 886.247 0.796 137 10542.33 88.46 152.09 7156.45 7208.45 372523.815 5967959.37 -6409.339 909.752 4.359 138 10585.47 88.77 152.09 7157.493 7209.493 372543.348 5967920.92 -6447.45 929.939 0.719 139 10637.94 89.26 151. 69 7158.395 7210.395 372567.271 5967874.23 -6493.724 954.658 1.205 140 10684.68 89.51 151.45 7158.897 7210.897 372588.815 5967832.75 -6534.825 976.909 0.741 141 10732.88 89.88 151.67 7159.153 7211.153 372611.041 5967789.98 -6577.207 999.863 0.893 142 10780.86 90.12 151.49 7159.153 7211 .153 372633.151 5967747.4 -6619.405 1022.698 0.625 143 10827.59 90.55 151.23 7158.88 7210.88 372654.844 5967706.01 -6660.416 1045.096 1.075 144 10872.92 89.75 152.4 7158.761 7210.761 372675.567 5967665.7 -6700.37 1066.505 3.127 145 10922.74 90.12 152.7 7158.818 7210.818 372697.773 5967621 .1 -6744.581 1089.471 0.956 146 11019.99 88.95 153.48 7159.607 7211.607 372740.295 5967533.64 -6831.296 1133.483 1 .446 147 11114.32 89.69 153.1 7160.727 7212.727 372781.243 5967448.67 -6915.553 1175.878 0.882 148 11210.67 88.58 153.63 7162.181 7214.181 372822.952 5967361.83 -7001.667 1219.067 1.277 149 11306.79 89.2 154.08 7164.043 7216.043 372863.816 5967274.85 -7087.935 1261.413 0.797 150 11402.29 90.12 153.72 7164.61 7216.61 372904.356 5967188.39 -7173.695 1303.426 1.034 151 11498.29 90.92 153.09 7163.739 7215.739 372945.856 5967101.83 -7259.532 1346.401 1.061 152 11593.93 90.06 152.68 7162.921 7214.921 372987.982 5967015.97 -7344.657 1389.99 0.996 153 11689.41 88.89 153.35 7163.796 7215.796 373029.843 5966930.16 -7429.736 1433.312 1.412 154 11781.93 89.26 153.24 7165.289 7217.289 373069.995 5966846.82 -7512.376 1474.884 0.417 155 11879.7 90 153.01 7165.921 7217.921 373112.693 5966758.87 -7599.584 1519.08 0.793 156 11974.69 90.8 153.3 7165.257 7217.257 373154.131 5966673.4 -7684.335 1561.974 0.896 157 12069.66 89.2 152.85 7165.257 7217.257 373195.679 5966588 -7769.007 1604.977 1.75 158 12164.99 89.75 152.45 7166.131 7218.131 373238.019 5966502.6 -7853.676 1648.772 0.713 159 12260.34 90.68 152.3 7165.773 7217.773 373280.778 5966417.38 -7938.155 1692.983 0.988 12355.81 91.72 152.1 7163.774 7215.774 373323.843 5966332.2 -8022.586 1737.498 1. 1 09 12450.49 90.55 151.52 7161.898 7213.898 373367.126 5966248.01 -8106.018 1782.216 1.379 12547.39 90.99 151.14 7160.596 7212.596 373412.15 5966162.22 -8191.029 1828.7 0.6 12642.481 89.14 150.95 7160.488 7212.488 373456.753 5966078.24 -8274.23 1874.734 1.956 12735.981 87.85 150.48 7162.944 7214.944 373501.071 5965995.95 -8355.75 1920.453 1 .468 12830.76 89.08 151.18 7165.483 7217.483 373545.827 5965912.44 -8438.478 1966.63 1 .493 12929.16 89.69 150.77 7166.539 7218.539 373592.088 5965825.6 -8524.514 2014.37 0.747 12958.481 89.69 150.52 7166.698 7218.698 373606.022 5965799.81 -8550.069 2028.743 0.853 13024 89.69 150.52 7167.052 7219.052 373637.284 5965742.23 -8607.105 2060.986 0 .x ~ ( 75.07 Vert. See ft 0.00 0.52 1.54 2.25 2.35 1.60 0.98 -0.09 -0.32 -0.16 0.44 1.90 4.81 9.42 16.32 27.42 43.18 63.51 88.84 118.81 154.53 194.49 241.03 291.57 346.23 404.38 465.90 528.75 560.66 651.73 717.76 783.52 849.49 915.83 982.28 1049.08 1115.50 1181 .46 1247.27 1312.70 1378.17 1442.55 1506.57 1573.58 1640.05 1706.49 1772.32 1838.10 1903.64 1968.98 2035.58 2103.25 ( 2170.95 2238.82 2306.63 2375.41 2443.09 2511.01 2578.60 2646.62 2714.32 2782.53 2850.13 2918.04 2985.77 3052.34 3118.10 3183.44 3248.88 3314.44 3378.56 3443.66 3508.20 3572.81 3635.44 3699.84 3766.12 3832.27 3898.88 3965.48 4028.90 4097.27 4164.09 4229.72 4296.24 4361.84 4429.52 4495.49 4561.49 4627.99 4693.95 4760.49 4827.66 4896.39 4965.95 4989.63 5012.55 5034.97 5060.76 5085.69 5110.16 5135.96 5165.42 5189.51 5218.60 5245.81 5270.86 5300.12 5328.16 5354.39 5383.87 5412.60 ( ( 5441.21 5472.55 5502.04 5521.70 5129.6 5172.44 5221.03 5266.03 5318.11 5361.73 5411.95 5457.06 5507.6 5554.86 5603.61 5648.79 5696.33 5742.81 5793.32 5838.75 5889.95 5932.15 5983.6 6031.75 6080.42 6123.55 6176.01 6222.74 6270.94 6318.92 6365.65 6410.98 6460.79 6558.02 6652.31 6748.61 6844.65 6940.09 7036.05 7131.67 7227.12 7319.6 7417.34 7512.31 7607.25 7702.57 7797.91 7893.36 7988.02 8084.9 8179.98 8273.43 8368.16 8466.54 8495.85 8561.35 c51od.. /~t.o 13-Aug-02 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD2-41 GYRO Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD , M D (if applicable) 0.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager RECEIVED AUG 1 ¿¡ 2002 Alaska Oil & Gas Cons. Commission Anchorage Attachment( s) ~ 'õ' - J~Fi \¡lTMfY,: J ~ :.. I ~ C() Kuparuk/Colville North Slope, Alaska Alpine CD-2, Slot CD2-41 CD2-41 Gyro Job No. AKF022100, Surveyed: 29 July, 2002 SURVEY REPORT 12 August, 2002 Your Ref: API 501032042400 Surface Coordinates: 5974383.33 N, 371723.84 E (70020' 17.6892" N, 151002' 27.1477" W) Kelly Bushing: 52.25ft above Mean Sea Level !5~'-'I'Y-SLJr1 DAtLLtNG $E;AVtCES A Halliburton Company Survey Ref: svy9931 Sperry-Sun Drilling Services Survey Report for CD2-41 Gyro Your Ref: API 501032042400 Job No. AKF022100, Surveyed: 29 July, 2002 . North Slope, Alaska Kuparuk/Colville Alpine CD-2 Meëtsllroc! Sub-Seët Vertical Local Coordinates Global Coordinates Dogleg Vertical DCfJth Il1cl. Azilll. Dcpth Depth Northings Eastings Northings Eastings Rate Soction Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 0.00 0.000 0.000 -52.25 0.00 0.00 N 0.00 E 5974383.33 N 371723.84 E 0.00 Tolerable Gyro 86.00 0.700 182.000 33.75 86.00 0.53 S 0.02W 5974382.81 N 371723.81 E 0.814 0.45 176.00 0.600 182.000 123.74 175.99 1.55 S 0.05W 5974381.79 N 371723.76 E 0.111 1.34 267.00 0.400 134.000 214.74 266.99 2.24 S 0.16 E 5974381.09 N 371723.96 E 0.490 2.05 358.00 0.750 72.000 305.73 357.98 2.28S 0.95E 5974381.04 N 371724.75 E 0.730 2.46 448.00 2.100 63.000 395.71 447.96 1.35 S 2.98E 5974381.93 N 371726.80 E 1.516 2.60 All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 52.25' MSL. Northings and Eastings are relative to 1974' FNL, 1514' FEL. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 1974' FNL, 1514' FEL and calculated along an Azimuth of 151.850° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 448.00ft., The Bottom Hole Displacement is 3.27ft., in the Direction of 114.325° (True). Survey tool program for CD2-41 Gyro From To Measured Vertical Measured Vertical Depth Depth Depth Depth ~) ~ ~ ~ Survey Tool Description 0.00 0.00 448.00 447.96 Tolerable Gyro 12 August, 2002 - 13:23 Page 20'2 DrillQuest 2.00.08.005 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitve Re: Distribution of Survey Data for Well CD2-41 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD , M D (if applicable) 13,024.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) aOd-'/d~ 13-Aug-02 RECE\VED AUG ,\ l~ ZOO2. AlaakaOi\& Gas Cons.Commis Ancborage ~ 1) '. I JEF 1\.- V= ro ct. RBDMS BFL AI"", ,(it) ?, '-!~ 2ípì'J -0°'../(. KuparuklColville North Slope, Alaska Alpine CD-2, Slot CD2-41 CD2-41 Job No. AKZZ22100, Surveyed: 29 July, 2002 SURVEY REPORT 12 August, 2002 Your Ref: API 501032042400 Surface Coordinates: 5974383.33 H, 371723.84 E (70020' 17.6892" H, 151002' 27.1477" W) Kelly Bushing: 52. 25ft above Mean Sea Level <,~ spe'-''-'Y-!8U'' DAILL.tNG SSAVlc:es A Halliburton Company Survey Ref: svy9952 Sperry-Sun Drilling Services . Survey Report for CD2-41 Your Ref: API 501032042400 Job No. AKZZ22100, Surveyed: 29 July, 2002 North Slope, Alaska Kuparuk/Colville Alpine CD..2 McasUl CU Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 442>00 2.100 63.000 395.71 447.96 1.35 S 2.98 E 5974381.93 N 371726.80 E 2.00 AK-(j BP. IFR-AK 485.43 2.560 59.400 433.10 485.35 0.61 S 4.31 E 5974382.65 N 371728.14 E 1.289 2.57 574.94 3.550 80.830 522.49 574.74 0.85N 8.77E 5974384.03 N 371732.62 E 1.670 3.39 664.77 4.750 84.770 612.08 664.33 1.63 N 15.22 E 5974384.70 N 371739.08 E 1.372 5.74 755.84 5.870 87.290 702.76 755.01 2.19 N 23.63 E 5974385.12 N 371747.50 E 1.256 9.21 842.56 7.890 89.120 788.85 841.10 2.50 N 34.01 E 5974385.24 N 371757.89 E 2.343 13.84 935.53 9.340 92.760 880.77 933.02 2.23N 47.92 E 5974384.74 N 371771.80 E 1.666 20.64 1030.35 11.590 96.470 974.01 1026.26 0.79N 65.08 E 5974383.00 N 371788.92 E 2.4 76 30.01 1125.32 14.170 98.620 1066.58 1118.83 2.03 S 86.05 E 5974379.83 N 371809.85 E 2.763 42.39 121807 15.460 105.140 1156.25 1208.50 6.968 109.21 E 5974374.50 N 371832.92 E 2.271 57.66 1314.15 15.580 116.340 1248.85 1301.10 16.038 133.14 E 5974365.02 N 371856.69 E 3.117 76.95 1408.69 16.230 129.030 1339.80 1392.05 29.99 S 154.79 E 5974350.69 N 371878.09 E 3.735 99.47 1503.22 1 7. 160 138.150 1430.36 1482.61 48.70 S 174.36 E 5974331.65 N 371897.34 E 2.937 125.20 1600.11 18.630 149.010 1522.58 1574.83 72.62 S 191.87 E 5974307.43 N 371914.44 E 3.757 154.55 1694.86 21.250 157.380 1611.66 1663.91 101.46 S 206.27 E 5974278.36 N 371928.35 E 4.083 186.77 1789.83 24.720 161.600 1699.09 1751.34 136.20 S 219.16E 5974243.40 N 371940.64 E 4.043 223.49 1882.14 27.820 164.550 1781.86 1834.11 175.29 S 231.00 E 5974204.12 N 371951.81 E 3.643 263.53 1978.93 30.410 168.230 1866.42 1918.67 221.05 8 242.02 E 5974158.17 N 371962.04 E 3.252 309.08 2074.90 33.590 169.240 1947.79 2000.04 270.92 8 251.93 E 5974108.14 N 371971.10 E 3.360 357.73 '>-~~ 2170.29 36.640 171.190 2025.82 2078.07 324.99 8 261.22 E 5974053.92 N 371979.46 E 3.406 409.78 2265.45 38.820 172.920 2101.08 2153.33 382.668 269.24 E 5973996.12 N 371986.50 E 2.547 464.42 2361.11 41.270 176.390 2174.31 2226.56 443.91 8 274.93 E 5973934.78 N 371991.13 E 3.464 521 . 11 2453.70 44.440 180.000 2242.19 2294.44 506.83 8 276.85 E 5973871.84 N 371991.98 E 4.330 577.49 2499.51 44.330 180.320 2274.93 2327.18 538.87 8 276.76 E 5973839.80 N 371991.34 E 0.544 605.70 2630.75 44.020 180.400 2369.05 2421.30 630.33 8 276.19 E 5973748.37 N 371989.20 E 0.240 686.07 2726.21 44.010 180.600 2437.70 2489.95 696.65 8 275.61 E 5973682.06 N 371987.49 E 0.146 744.28 2821.31 43.980 180.360 2506.12 2558.37 762.71 8 275.05 E 5973616.03 N 371985.81 E 0.178 802.26 2916.51 44.260 180.770 2574.46 2626.71 828.98 S 274.40 E 5973549.78 N 371984.02 E 0.420 860.38 3011.99 44.390 181.590 2642.77 2695.02 895.68 8 273.03 E 5973483.11 N 371981.50 E 0.615 918.54 3107.28 44.670 180.590 2710.70 2762.95 962.49 8 271.76 E 5973416.33 N 371979.09 E 0.792 976.85 12 August, 2002 - 13:23 Page 20(8 Dril/Quest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for CD2-41 Your Ref: API 501032042400 Job No. AKZZ22100, Surveyed: 29 July, 2002 North Slope, Alaska Kuparuk/Colville Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 3202.03 441340 180.9S0 2778.41 2830.66 1029.62 S 270.85 E 5973349.23 N 371977.04 E 0.320 1 03S.G1 3298.10 43.800 179.650 2846.71 2898.96 1096.31 S 270.50 E 5973282.55 N 371975.54 E 1 .446 1094.25 .~ 3393.84 43.600 179.240 2915.93 2968.18 1162.45 S 271.14 E 5973216.41 N 371975.05 E 0.362 1152.87 3489.53 43.620 179.540 2985.22 3037.4 7 1228.45 S 271.84 E 5973150.41 N 371974.63 E 0.217 1211.40 3584.90 43.270 178.220 3054.46 3106.71 1294.02 8 273.12 E 5973084.83 N 371974.78 E 1.020 1269.81 3680.72 43.110 178.750 3124.32 3176.57 1359.58 8 274.85 E 5973019.25N 371975.40 E 0.414 1328.43 3775.21 42.990 178.230 3193.37 3245.62 1424.06 S 276.55 E 5972954.75 N 371975.99 E 0.397 1386.09 3869.16 43.080 178.230 3262.04 3314.29 1488.14 S 278.53 E 5972890.64 N 371976.88 E 0.096 1443.52 3966.56 44.220 180.860 3332.52 3384.77 1555.36 S 279.05 E 5972823.43 N 371976.24 E 2.201 1503.03 4062.32 44.300 181.200 3401.10 3453.35 1622.18 S 277.85 E 5972756.64 N 371973.90 E 0.262 1561.38 4158.31 43.900 180.970 3470.04 3522.29 1688.978 276.59 E 5972689.88 N 371971.49 E 0.449 1619.68 4253.80 43.790 180.340 3538.91 3591.16 1755.11 8 275.83 E 5972623.76 N 371969.60 E 0.471 1677.64 4349.50 43.530 180.550 3608.14 3660.39 1821.188 275.32 E 5972557.71 N 371967.96 E 0.311 1735.65 4444.98 43.670 180.620 3677.28 3729.53 1887.02 S 274.64 E 5972491.89 N 371966.16 E 0.155 1793.38 4540.34 43.350 180.710 3746.44 3798.69 1952.678 273.88 E 5972426.26 N 371964.28 E 0.342 1850.91 4636.18 45.210 180.460 3815.06 3867.31 2019.57 8 273.20 E 5972359.38 N 371962.45 E 1.949 1909.58 4731.71 45.500 180.280 3882.19 3934.44 2087.54 8 272.76 E 5972291.43 N 371960.85 E 0.332 1969.30 4826.95 45.570 180.190 3948.90 4001.15 2155.51 S 272.48 E 5972223.48 N 371959.41 E 0.100 2029.10 4922.23 45.750 180.190 4015.49 4067.74 2223.65 S 272.26 E 5972155.35 N 371958.02 E 0.189 2089.07 -~- 5017.10 45.960 180.210 4081.57 4133.82 2291.738 272.02 E 5972087.28 N 371956.62 E 0.222 2148.99 5113.50 45.520 179.740 4148.85 4201.10 2360.778 272.05 E 5972018.25 N 371955.46 E 0.575 2209.87 5208.84 45.280 179.350 4215.79 4268.04 2428.65 8 272.59 E 5971950.37 N 371954.84 E 0.385 2269.98 5304.35 45.410 178.820 4282.92 4335.17 2496.58 8 273.67 E 5971882.43 N 371954.76 E 0.418 2330.39 5399.77 45.290 178.840 4349.98 4402.23 2564.45 8 275.06 E 5971814.55 N 371954.99 E 0.127 2390.88 5495.57 45.380 177.930 4417.32 4469.57 2632.56 8 276.98 E 5971746.42 N 371955.74 E 0.682 2451.84 5590.63 45.560 177.480 4483.98 4536.23 2700.27 S 279.69 E 5971678.67 N 371957.30 E 0.387 2512.82 5686.28 45.530 177.680 4550.97 4603.22 2768.48 8 282.58 E 5971610.42 N 371959.02 E 0.153 2574.33 5781.19 45.420 177.350 4617.53 4669.78 2836.088 285.51 E 5971542.78 N 371960.79 E 0.274 2635.32 5876.64 45.370 176.830 4684.55 4736.80 2903.958 288.96 E 5971474.86 N 371963.08 E 0.391 2696.79 5972.39 44.720 176.800 4752.20 4804.45 2971.61 S 292.72 E 5971407.15 N 371965.69 E 0.679 2758.21 12 August, 2002 - 13:23 Page 3 0'8 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for CD2.41 Your Ref: API 501032042400 Job No. AKZZ22100, Surveyed: 29 July, 2002 North Slope, Alaska Kuparuk/Colville Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inel. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 60G7.83 t13.í320 177.560 4820.54 4872.79 3038.15 S 296.01 E 5971340.56 N 371967.83 E 1.095 2818.43 6163.33 43.400 179.260 4889.69 4941 .94 3103.99 S 297.84 E 5971274.70 N 371968.53 E 1.304 2877.35 .- 6258.97 43.070 179.110 4959.37 5011.62 3169.49 S 298.77 E 5971209.19 N 371968.34 E 0.361 2935.54 6354.56 43.770 181 .160 5028.81 5081.06 3235.19 S 298.61 E 5971143.51 N 371967.06 E 1.646 2993.39 6450.04 43.570 181.130 5097.87 5150.12 3301.10 S 297.29 E 5971077.62 N 371964.61 E 0.211 3050.89 6543.69 43.390 180.500 5165.82 5218.07 3365.54 S 296.37 E 5971013.22 N 371962.59 E 0.501 3107.27 6639.21 43.000 180.250 5235.46 5287.71 3430.92 S 295.94 E 5970947.85 N 371961.05 E 0.446 3164.71 6734.44 42.760 180.130 5305.24 5357.49 3495.72 S 295.73 E 5970883.07 N 371959.72 E 0.266 3221.75 6830.63 41 .980 179.230 5376.31 5428.56 3560.54 S 296.09 E 5970818.25 N 371958.97 E 1.027 3279.07 6925.15 41.290 179.220 5446.95 5499.20 3623.33 S 296.94 E 5970755.45 N 371958.75 E 0.730 3334.83 7020.29 44.290 180.340 5516.76 5569.01 3687.95 S 297.17 E 5970690.84 N 371957.87 E 3.253 3391.92 7116.09 43.710 180.11 0 5585.68 5637.93 3754.50 S 296.90 E 5970624.30 N 371956.47 E 0.628 3450.47 7211.57 44.490 180.910 5654.24 5706.49 3820.94 S 296.31 E 5970557.88 N 371954.74 E 1.004 3508. 77 7307.18 44.420 180.920 5722.49 5774.74 3887.89 S 295.24 E 5970490.96 N 371952.53 E 0.074 3567.30 7403.15 44.040 180.840 5791.26 5843.51 3954.83 S 294.21 E 5970424.05 N 371950.35 E 0.400 3625.83 7495.01 43.770 180.240 5857.44 5909.69 4018.52 S 293.61 E 5970360.37 N 371948.66 E 0.540 3681.71 7593.59 44.620 181.440 5928.12 5980.37 4087.23 S 292.60 E 5970291.69 N 371946.48 E 1.210 3741.82 7689.67 44.140 180.820 5996.79 6049.04 4154.42 S 291.27 E 5970224.54 N 371944.00 E 0.673 3800.43 7784.91 43.500 180.610 6065.51 6117.76 4220.36 S 290.45 E 5970158.62 N 371942.05 E 0.689 3858.18 ''''-' 7880.64 45.110 181 .120 6134.01 6186.26 4287.21 S 289.43 E 5970091.79 N 371939.89 E 1.722 3916.65 7974.17 44.620 181.310 6200.30 6252.55 4353.18 S 288.03 E 5970025.86 N 371937.36 E 0.543 3974.15 8071.39 44.260 180.800 6269.72 6321.97 4421.23 S 286.78 E 5969957.84 N 371934.95 E 0.522 4033.57 8166.70 43.870 180.640 6338.20 6390.45 4487.51 S 285.95 E 5969891.58 N 371932.98 E 0.426 4091.62 8261.54 44.920 181.240 6405.97 6458.22 4553.85 S 284.86 E 5969825.27 N 371930.75 E 1.192 4149.59 8356.81 44.220 180.700 6473.84 6526.09 4620.70 S 283.72 E 5969758.45 N 371928.47 E 0.836 4208.00 8452.60 43.340 180.710 6543.00 6595.25 4686.97 S 282.91 E 5969692.20 N 371926.53 E 0.919 4266.05 8547.96 45.770 181.230 6610.94 6663.19 4753.86 S 281.77 E 5969625.34 N 371924.24 E 2.577 4324.49 8641.57 46.660 181.470 6675.72 6727.97 4821.42 S 280.17 E 5969557.82 N 371921.49 E 0.969 4383.30 8737.02 46.160 181.140 6741.53 6793.78 4890.54 S 278.60 E 5969488.74 N 371918.74 E 0.581 4443.50 8834.46 45.590 180.910 6809.37 6861.62 4960.47 S 277.35 E 5969418.84 N 371916.29 E 0.609 4504.57 12 August, 2002 - 13:23 Page 4 0'8 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for CD2-41 Your Ref: AP/501032042400 Job No. AKZZ22100, Surveyed: 29 July, 2002 North Slope, Alaska Kuparuk/Colville Alpine CD-2 MeZJsured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 8867.66 4~i960 180.400 6832.53 6884.78 4984.26 S 277.08 E 5969395.06 N 371915.61 E 1.566 4525.42 8899.28 47.360 179.470 6854.23 6906.48 5007.26 S 277.10 E 5969372.07 N 371915.24 E 4.917 4545.71 8929.40 49.130 177.820 6874.28 6926.53 5029.72 S 277.64 E 5969349.60 N 371915.40 E 7.157 4565.76 8962.98 51.360 176.950 6895.76 6948.01 5055.50 S 278.82 E 5969323.80 N 371916.14 E 6.933 4589.06 8994.49 53.250 176.180 6915.02 6967.27 5080.39 S 280.32 E 5969298.89 N 371917.21 E 6.302 4611.71 9024.74 54.790 175.270 6932.80 6985.05 5104.80 S 282.14 E 5969274.45 N 371918.61 E 5.643 4634.09 9056.10 55.890 174.500 6950.63 7002.88 5130.49 S 284.44 E 5969248.72 N 371920.48 E 4.047 4657.83 9091.54 56.640 173.420 6970.31 7022.56 5159.80 S 287.55 E 5969219.37 N 371923.08 E 3.302 4685.13 9120.33 57.120 171.670 6986.04 7038.29 5183.71 S 290.68 E 5969195.41 N 371925.80 E 5.357 4707.69 9154.89 58.000 170.210 7004.58 7056.83 5212.51 S 295.27 E 5969166.53 N 371929.90 E 4.381 4735.25 9186.97 58.790 169.440 7021 .40 7073.65 5239.40 S 300.10 E 5969139.56 N 371934.26 E 3.200 4761.24 9216.25 60.040 167.990 7036.29 7088.54 5264.12 S 305.03 E 5969114.77 N 371938.77 E 6.033 4785.36 9250.01 61.960 166.870 7052.66 7104.91 5292.93 S 311.46E 5969085.84 N 371944.71 E 6.385 4813.80 9281.95 63.470 165.230 7067.30 7119.55 5320.48 S 318.30 E 5969058.18 N 371951.08 E 6.571 4841.32 9311.54 65.110 164.290 7080.14 7132.39 5346.20 S 325.31 E 5969032.35 N 371957.65 E 6.238 4867.31 9344.39 67.370 163.240 7093.37 7145.62 5375.06 S 333.72 E 5969003.34 N 371965.56 E 7.476 4896.72 9376.00 69.590 162.470 7104.97 7157.22 5403.16 S 342.39 E 5968975.10 N 371973.75 E 7.380 4925.59 9407.10 71.740 161.910 7115.27 7167.52 5431.10 S 351.37 E 5968947.01 N 371982.25 E 7.119 4954.45 9440.79 73.900 161.970 7125.22 7177.47 5461.70 S 361.34 E 5968916.25 N 371991.70 E 6.414 4986.14 9472.17 75.920 161.600 7133.38 7185.63 5490.48 S 370.82 E 5968887.31 N 372000.68 E 6.537 5015.98 9492.94 77.590 161.560 7138.14 7190.39 5509.66 S 377.20 E 5968868.03 N 372006.74 E 8.043 5035.91 9588.62 85.260 157.240 7152.41 7204.66 5598.12 S 410.49 E 5968779.01 N 372038.51 E 9.174 5129.61 9631.61 89.200 153.690 7154.48 7206.73 5637.17 S 428.32 E 5968739.66 N 372055.66 E 12.329 5172.45 9680.23 91.350 148.210 7154.25 7206.50 5679.65 S 451.92 E 5968696.78 N 372078.53 E 12.107 5221.04 9725.38 91.230 146.450 7153.23 7205.48 5717.65 S 476.28 E 5968658.37 N 372102.24 E 3.906 5266.04 9777.73 91.720 146.050 7151.89 7204.14 5761.16 S 505.36 E 5968614.37 N 372130.57 E 1.208 5318.12 9821.56 92.030 146.920 7150.45 7202.70 5797.68 S 529.54 E 5968577.44 N 372154.13 E 2.106 5361.73 9872.00 91.850 146.940 7148.74 7200.99 5839.93 S 557.05 E 5968534.73 N 372180.91 E 0.359 5411 .96 9917.33 91.720 146.120 7147.33 7199.58 5877.72 S 582.04 E 5968496.51 N 372205.24 E 1.831 5457.07 9968.17 90.680 145.290 7146.27 7198.52 5919.71 S 610.68 E 5968454.04 N 372233.16 E 2.617 5507.61 12 August, 2002 - 13:23 Page 50f8 Dril/Quest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for CD2-41 Your Ref: API 501032042400 Job No. AKZZ22100, Surveyed: 29 July, 2002 North Slope, Alaska Kuparuk/Colville Alpine CD-2 MC<Jsurcd Sub-Sc<J Vertical Local Coordinates Global Coordinates Oogley Vertical Depth Inet. Azil11. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 10015.75 90.550 145.160 7145.76 7198.01 5958.79 S 637.81 E 5968414.50 N 372259.62 E 0.386 5554.87 10064.74 90.550 147.200 7145.29 7197.54 5999.49 S 665.08 E 5968373.34 N 372286.19 E 4.164 5603.61 10110.06 90.250 147.740 7144.97 7197.22 6037.70 S 689.45 E 5968334.72 N 372309.90 E 1.363 5648.80 10157.71 88.650 148.130 7145.43 7197.68 6078.07 S 714.74 E 5968293.92 N 372334.50 E 3.456 5696.33 10204.29 87.350 149.320 7147.05 7199.30 6117.86 S 738.91 E 5968253.73 N 372357.98 E 3.783 5742.81 10254.90 87.660 149.370 7149.26 7201.51 6161.36 S 764.69 E 5968209.79 N 372383.01 E 0.620 5793.33 10300.40 88.090 149.290 7150.94 7203.19 6200.46 S 787.88 E 5968170.29 N 372405.53 E 0.961 5838.75 10351.68 88.460 149.060 7152.49 7204.74 6244.48 S 814.15E 5968125.84 N 372431.04 E 0.849 5889.95 10393.96 88.770 148.420 7153.51 7205.76 6280.61 S 836.08 E 5968089.34 N 372452.35 E 1.682 5932.16 10445.47 88.950 150.250 7154.53 7206.78 6324.91 S 862.34 E 5968044.60 N 372477.86 E 3.569 5983.61 10493.65 89.320 150.150 7155.26 7207.51 6366.71 S 886.28 E 5968002.39 N 372501.08 E 0.796 6031.76 10542.33 88.460 152.090 7156.20 7208.45 6409.33 S 909.79 E 5967959.38 N 372523.85 E 4.359 6080.43 10585.47 88.770 152.090 7157.25 7209.50 6447.44 S 929.98 E 5967920.93 N 372543.39 E 0.719 6123.55 10637.94 89.260 151.690 7158.15 7210.40 6493.71 S 954.70 E 5967874.24 N 372567.31 E 1.205 6176.01 10684.68 89.510 151.450 7158.65 7210.90 6534.81 S 976.95 E 5967832.76 N 372588.85 E 0.741 6222.75 10732.88 89.880 151.670 7158.91 7211.16 6577.19 S 999.90 E 5967789.99 N 372611.08 E 0.893 6270.95 10780.86 90.120 151.490 7158.91 7211.16 6619.39 S 1022.74 E 5967747.41 N 372633.19 E 0.625 6318.93 10827.59 90.550 151.230 7158.63 7210.88 6660.40 S 1045.13 E 5967706.02 N 372654.88 E 1.075 6365.66 10872.92 89.750 152.400 7158.52 7210.77 6700.36 S 1066.54 E 5967665.71 N 372675.61 E 3.127 6410.98 10922.74 90.120 152.700 7158.57 7210.82 6744.57 S 1089.51 E 5967621.11 N 372697.81 E 0.956 6460.80 11019.99 88.950 153.480 7159.36 7211.61 6831.28 S 1133.52 E 5967533.66 N 372740.33 E 1.446 6558.02 11114.32 89.690 153.100 7160.48 7212.73 6915.54 S 1175.92 E 5967448.68 N 372781.28 E 0.882 6652.32 11210.67 88.580 153.630 7161.94 7214.19 7001.65 S 1219.11 E 5967361.84 N 372822.99 E 1.277 6748.62 11306.79 89.200 154.080 7163.80 7216.05 7087.92 S 1261.45 E 5967274.86 N 372863.85 E 0.797 6844.66 11402.29 90.120 153.720 7164.36 7216.61 7173.68 S 1303.46 E 5967188.40 N 372904.39 E 1.034 6940.10 11498.15 90.920 153.090 7163.49 7215.74 7259.40 S 1346.38 E 5967101.97 N 372945.83 E 1.062 7035.92 11593.93 90.060 152.680 7162.67 7214.92 7~i44.64 S 1390.03 E 5967015.98 N 372988.02 E 0.995 7131.68 11689.41 88.890 153.350 7163.55 7215.80 7¿29.72 S 1433.35 E 5966930.17 N 373029.88 E 1.412 7227.13 11781.93 89.260 153.240 7165.04 7217.29 7 12.36 S 1474.92 E 5966846.83 N 373070.04 E 0.417 7319.61 11879.70 90.000 153.010 7165.67 7217.92 7599.57 S 1519.12 E 5966758.88 N 373112.73 E 0.793 7417.35 12 August, 2002 ~ 13:23 Page 60f8 DriflQlIest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for CD2-41 Your Ref: API 501032042400 Job No. A KZZ221 00, Surveyed: 29 July, 2002 North Slope, Alaska Kuparuk/Colville Alpine CD-2 Me ZI S u rc cf Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azil1l. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) r/1 OOft) 11974.69 90.800 153 300 7165.01 7217.26 7684.32 S 1562.01 E 5966673.41 N 373154.17 E 0.896 7512.31 12069.66 89.200 152.850 7165.01 7217.26 7768.99 S 1605.02 E 5966588.02 N 373195.72 E 1.750 7607.26 .-. 12164.99 89.750 152.450 7165.89 7218.14 7853.66 S 1648.81 E 5966502.61 N 373238.06 E 0.713 7702.58 12260.34 90.680 152.300 7165.53 7217.78 7938.14 S 1693.02 E 5966417.39 N 373280.82 E 0.988 7797.92 12355.81 91.720 152.100 7163.53 7215.78 8022.57 S 1737.54 E 5966332.21 N 373323.88 E 1.109 7893.37 12450.49 90.550 151.520 7161.65 7213.90 8106.00 S 1782.26 E 5966248.02 N 373367.17 E 1.379 7988.02 12547.39 90.990 151.140 7160.35 7212.60 8191.02 S 1828.74 E 5966162.23 N 373412.19 E 0.600 8084.91 12642.48 89.140 150.950 7160.24 7212.49 8274.22 S 1874.77 E 5966078.25 N 373456.79 E 1.956 8179.99 12735.98 87.850 150.480 7162.70 7214.95 8355.74 S 1920.49 E 5965995.96 N 373501.11 E 1 .468 8273.44 12830.76 89.080 151.180 7165.24 7217.49 8438.46 S 1966.67 E 5965912.46 N 373545.87 E 1 .493 8368.16 12929.16 89.690 150.770 7166.29 7218.54 8524.50 S 2014.41 E 5965825.62 N 373592.13 E 0.747 8466.55 12958.48 89.690 150.520 7166.45 7218.70 8550.06 S 2028.78 E 5965799.82 N 373606.06 E 0.853 8495.86 13024.00 89.690 150.520 7166.81 7219.06 8607.09 S 2061.03 E 5965742.24 N 373637.32 E 0.000 8561.36 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 52.25' MSL. Northings and Eastings are relative to 1974' FNL, 1514' FEL. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 1974' FNL, 1514' FEL and calculated along an Azimuth of 151.850° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13024.00ft., The Bottom Hole Displacement is 8850.42ft., in the Direction of 166.534° (True). 12 August, 2002 - 13:23 Page 70f8 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for CD2-41 Your Ref: AP/501032042400 Job No. AKZZ22100, Surveyed: 29 July, 2002 . Kuparuk/Colville North Slope, Alaska Alpine CD-2 Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment ~ 13024.00 7219.06 8607.09 S 2061.03 E Projected Survey Survey tool program for CD2-41 From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 448.00 0.00 448.00 447.96 13024.00 447.96 Tolerable Gyro (CD2-41 Gyro) 7219.06 AK-6 BP _IFR-AK (CD2-41) 12 August, 2002 - 13:23 Page 8 0'8 DrillQuest 2.00.08.005 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD2-41 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 'MD (if applicable) 13,024.00' MD aoa_/d'-o 13-Aug-02 Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED AUG 1 L¡ 2002 Alaska Oil & Gas Q)ns.Commisston Anchorage $ 'à '-. , I ~ () ~~ 'Ç~: Kuparuk/Colville North Slope, Alaska Alpine CD-2, Slot CD2-41 CD2-41 MWD Job No. AKMW22100, Surveyed: 29 July, 2002 SURVEY REPORT 12 August, 2002 Your Ref: API 501032042400 Surface Coordinates: 5974383.33 N, 371723.84 E (70020' 17.6892" N, 151002'27.1477" W) Kelly Bushing: 52.25ft above Mean Sea Level .- !!IpI!'-''-'Y-!!IU'' DFULLtNGSeAVIc:e~ A Halliburton Company Survey Ref: svy9953 Sperry-Sun Drilling Services . Survey Report for CD2.41 MWD Your Ref: API 501032042400 Job No. AKMW22100, Surveyed: 29 July, 2002 North Slope, Alaska Kuparuk/Colville Alpine CD.2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 448.00 2.100 63.000 395.71 447.96 1.35 S 2.98E 5974381.93 N 371726.80 E 2.60 MWD Magnetic 485.43 2.560 58.570 433.10 485.35 0.608 4.31 E 5974382.66 N 371728.14 E 1.319 2.56 574.94 3.550 80.260 522.49 574.74 0.91 N 8.74E 5974384.09 N 371732.60 E 1.682 3.32 664.77 4.750 84.710 612.08 664.33 1.72 N 15.19 E 5974384.79 N 371739.06 E 1.382 5.65 755.84 5.870 87.220 702.76 755.01 2.30N 23.60 E 5974385.22 N 371747.47 E 1.256 9.11 842.56 7.890 89.190 788.85 841.10 2.60N 33.98 E 5974385.34 N 371757.86 E 2.345 13.74 935.53 9.340 93.360 880.77 933.02 2.24 N 47.89 E 5974384.76 N 371771.76 E 1.697 20.61 1030.35 11 .590 96.910 974.01 1026.26 0.65N 65.03 E 5974382.86 N 371788.87 E 2.467 30.11 1125.32 14.170 98.960 1066.58 1118.83 2.31 S 85.99 E 5974379.55 N 371809.77 E 2.759 42.60 1218.07 15.460 105.560 1156.25 1208.50 7.40S 109.11 E 5974374.07 N 371832.81 E 2.288 58.00 1314.15 15.580 116.610 1248.85 1301.10 16.61 S 132.99 E 5974364.44 N 371856.53 E 3.075 77.39 1408.69 16.230 129.240 1339.80 1392.05 30.66 S 154.58 E 5974350.03 N 371877.87 E 3.718 99.96 1503.22 17. 160 138.650 1430.36 1482.61 49.49 S 174.03 E 5974330.87 N 371897.00 E 3.020 125.74 1600.11 18.630 149.300 1522.58 1574.83 73.53 S 191.38 E 5974306.53 N 371913.93 E 3.696 155.12 1694.86 21.250 157.710 1611.66 1663.91 102.45 8 205.62 E 5974277.38 N 371927.68 E 4.093 187.34 1789.83 24.720 162.030 1699.09 1751.34 137.278 218.28 E 5974242.34 N 371939.74 E 4.060 224.02 1882.14 27.820 164.850 1781.86 1834.11 176.43 S 229.87 E 5974202.99 N 371950.66 E 3.619 264.01 1978.93 30.410 168.700 1866.42 1918.67 222.27 S 240.57 E 5974156.98 N 371960.58 E 3.301 309.48 2074.90 33.590 170.520 1947.80 2000.05 272.29 S 249.71 E 5974106.81 N 371968.85 E 3.462 357.89 2170.29 36.640 171.380 2025.82 2078.07 326.47 8 258.32 E 5974052.49 N 371976.54 E 3.239 409.72 2265.45 38.820 173.300 2101.08 2153.33 384.188 266.06 E 5973994.66 N 371983.29 E 2.602 464.26 2361 .11 41.270 176.780 2174.31 2226.56 445.47 S 271.33 E 5973933.28 N 371987.51 E 3.469 520.79 2453.70 44.440 180.240 2242.19 2294.44 508.40 8 272.91 E 5973870.34 N 371988.01 E 4.263 577.02 2499.51 44.330 179.980 2274.93 2327.18 540.44 S 272.85 E 5973838.30 N 371987.41 E 0.464 605.24 2630.75 44.020 180.600 2369.05 2421.30 631.89 S 272.39 E 5973746.87 N 371985.38 E 0.405 685.66 2726.21 44.010 180.950 2437.70 2489.95 698.22 S 271.49 E 5973680.57 N 371983.35 E 0.255 743.71 2821.31 43.980 180.770 2506.12 2558.37 764.27 8 270.50 E 5973614.55 N 371981.23 E 0.135 801.48 2916.51 44.260 181.010 2574.46 2626.71 830.53 S 269.47 E 5973548.31 N 371979.06 E 0.343 859.42 3011.99 44.390 182.730 2642.77 2695.02 897.21 8 267.29 E 5973481.68 N 371975.74 E 1.266 917.18 3107.28 44.670 181.770 2710.70 2762.95 963.98 S 264.67 E 5973414.97 N 371971.98 E 0.765 974.82 12 August, 2002 - 13:23 Page 2 0'8 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for CD2.41 MWD Your Ref: API 501032042400 Job No. AKMW22100, Surveyed: 29 July, 2002 North Slope, Alaska Kuparuk/Colville Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 3202.63 44.840 181.690 2778.41 2830.66 1031.08 S 262.64 E 5973347.91 N 371968.81 E 0.188 1033.03 3298.10 43.800 179.910 2846.72 2898.97 1097.77 S 261.70 E 5973281.24 N 371966.73 E 1.698 1091.39 3393.84 43.600 179.740 2915.93 2968.18 1163.91 8 261.90 E 5973215.11 N 371965.80 E 0.242 1149.80 3489.53 43.620 179.420 2985.22 3037.47 1229.91 S 262.39 E 5973149.11 N 371965.15E 0.232 1208.22 3584.90 43.270 177.820 3054.46 3106.71 1295.47 S 263.96 E 5973083.53 N 371965.60 E 1.211 1266.77 3680.72 43.110 178.380 3124.32 3176.57 1361.028 266.14 E 5973017.96 N 371966.66 E 0.433 1325.59 3775.21 42990 178.360 3193.37 3245.62 1425.49 8 267.97 E 5972953.46 N 371967.39 E 0.128 1383.30 3869.16 43.080 178.150 3262.04 3314.29 1489.58 S 269.93 E 5972889.35 N 371968.25 E 0.180 1440.73 3966.56 44.220 180.770 3332.53 3384.78 1556.79 S 270.54 E 5972822.14 N 371967.71 E 2.195 1500.29 4062.32 44.300 181.230 3401.11 3453.36 1623.62 S 269.38 E 5972755.34 N 371965.40 E 0.346 1558.65 4158.31 43.900 181.030 3470.04 3522.29 1690.408 268.06 E 5972688.59 N 371962.94 E 0.441 1616.92 4253.80 43.790 180.350 3538.91 3591.16 1756.54 8 267.26 E 5972622.4 7 N 371961.02 E 0.507 1674.86 4349.50 43.530 180.480 3608.14 3660.39 1822.61 S 266.78 E 5972556.42 N 371959.41 E 0.287 1732.89 4444.98 43.670 180.650 3677.29 3729.54 1888.45 S 266.14E 5972490.60 N 371957.63 E 0.191 1790.64 4540.34 43.350 181.240 3746.45 3798.70 1954.108 265.05 E 5972424.98 N 371955.43 E 0.542 1848.00 4636.18 45.210 180.390 3815.06 3867.31 2021.00 S 264.11 E 5972358.11 N 371953.34 E 2.037 1906.55 4731.71 45.500 179.900 3882.19 3934.44 2088.96 S 263.94 E 5972290.16 N 371952.00 E 0.475 1966.39 4826.95 45.570 180.410 3948.90 4001.15 2156.93S 263.75 E 5972222.20 N 371950.66 E 0.389 2026.24 4922.23 45.750 180.580 4015.50 4067.75 2225.08 S 263.17 E 5972154.08 N 371948.90 E 0.228 2086.04 5017.10 45.960 180.530 4081.57 4133.82 2293.15 S 262.51 E 5972086.02 N 371947.08 E 0.225 2145.75 5113.50 45.520 179.990 4148.85 4201.10 2362.198 262.19 E 5972017.00 N 371945.58 E 0.608 2206.48 5208.84 45.280 179.620 4215.79 4268.04 2430.07 8 262.42 E 5971949.12 N 371944.65 E 0.374 2266.44 5304.35 45.410 179.200 4282.92 4335.17 2498.01 S 263.12 E 5971881.18 N 371944.19 E 0.341 2326.67 5399.77 45.290 179.200 4349.98 4402.23 2565.89 8 264.07 E 5971813.30 N 371943.98 E 0.126 2386.97 5495.57 45.380 178.190 4417.32 4469.57 2634.00 8 265.62 E 5971745.17 N 371944.36 E 0.756 2447.76 5590.63 45.560 177.720 4483.99 4536.24 2701.73 S 268.04 E 5971677.41 N 371945.62 E 0.400 2508.61 5686.28 45.530 177.920 4550.98 4603.23 2769.95 8 270.64 E 5971609.15 N 371947.05 E 0.153 2569.99 5781.19 45.420 177.790 4617.53 4669.78 2837.57 S 273.17 E 5971541.50 N 371948.43 E 0.152 2630.81 5876.64 45.370 177.280 4684.56 4736.81 2905.46 S 276.09 E 5971473.57 N 371950.19 E 0.384 2692.05 5972.39 44.720 177.320 4752.21 4804.46 2973.15 S 279.29 E 5971405.84 N 371952.22 E 0.679 2753.23 12 August, 2002 - 13:23 Page 3 0'8 Dril/Quest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for CD2-41 MWD Your Ref: API 501032042400 Job No. AKMW22100, Surveyed: 29 July, 2002 North Slope, Alaska Kuparuk/Colville Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastlngs Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 6067.83 43.820 177.840 4820.55 4872.80 3039.71 S 282.10 E 5971339.24 N 371953.90 E 1.017 2813.25 6163.33 43.400 179.880 4889.70 4941.95 3105.56 S 283.42 E 5971273.38 N 371954.09 E 1.538 2871.93 ,,- 6258.97 43.070 179.100 4959.38 5011.63 3171.07 S 284.00 E 5971207.87 N 371953.55 E 0.657 2929.96 6354.56 43.770 181.270 5028.81 5081.06 3236.76 S 283.78 E 5971142.19 N 371952.21 E 1.724 2987.78 6450.04 43.570 180.950 5097.88 5150.13 3302.68 S 282.50 E 5971076.30 N 371949.80 E 0.312 3045.30 6543.69 43.390 180.400 5165.83 5218.08 3367.11 S 281.74 E 5971011.89 N 371947.94 E 0.447 3101.75 6639.21 43.000 180.070 5235.47 5287.72 3432.49 S 281.47 E 5970946.52 N 371946.55 E 0.472 3159.28 6734.44 42.760 180.090 5305.25 5357.50 3497.29 S 281.38 E 5970881.73 N 371945.35 E 0.252 3216.37 6830.63 41 .980 179.520 5376.31 5428.56 3562.12 S 281.60 E 5970816.92 N 371944.46 E 0.904 3273.63 6925.15 41.290 179.730 5446.96 5499.21 3624.91 S 282.01 E 5970754.12 N 371943.80 E 0.745 3329.19 7020.29 44.290 180.560 5516.77 5569.02 3689.53 S 281.83 E 5970689.52 N 371942.52 E 3.208 3386.08 7116.09 43.710 180.560 5585.68 5637.93 3756.08 S 281.18E 5970622.99 N 371940.73 E 0.605 3444.45 7211.57 44.490 181.310 5654.25 5706.50 3822.51 S 280.10 E 5970556.58 N 371938.50 E 0.983 3502.51 7307.18 44.420 181.260 5722.49 5774.74 3889.46 S 278.59 E 5970489.68 N 371935.86 E 0.082 3560.83 7403.15 44.040 181 .140 5791.26 5843.51 3956.38 S 277.19 E 5970422.78 N 371933.31 E 0.405 3619.18 7495.01 43.770 180.400 5857.45 5909.70 4020.08 S 276.34 E 5970359.11 N 371931.36 E 0.631 3674.94 7593.59 44.620 181.640 5928.13 5980.38 4088.79 S 275.11 E 5970290.44 N 371928.96 E 1.230 3734.94 7689.67 44.140 180.970 5996.80 6049.05 4155.97 S 273.57 E 5970223.29 N 371926.28 E 0.698 3793.45 7784.91 43.500 180.740 6065.51 6117.76 4221.90 S 272.59 E 5970157.38 N 371924.17 E 0.692 3851.12 '- 7880.64 45.110 181.740 6134.02 6186.27 4288.75 S 271.13 E 5970090.57 N 371921.57 E 1.833 3909.37 7974.17 44.620 181.660 6200.31 6252.56 4354.70 S 269.18 E 5970024.66 N 371918.48 E 0.527 3966.60 8071.39 44.260 180.930 6269.72 6321.97 4422.75 S 267.64 E 5969956.65 N 371915.78 E 0.643 4025.87 8166.70 43.870 180.660 6338.21 6390.46 4489.03 S 266.72 E 5969890.40 N 371913.72 E 0.454 4083.88 8261.54 44.920 181.260 6405.97 6458.22 4555.37 S 265.60 E 5969824.08 N 371911.48 E 1.192 4141.84 8356.81 44.220 180.770 6473.84 6526.09 4622.22 S 264.42 E 5969757.27 N 371909.15E 0.819 4200.23 8452.60 43.340 180.890 6543.00 6595.25 4688.48 S 263.46 E 5969691.02 N 371907.05 E 0.923 4258.20 8547.96 45.770 181.330 6610.95 6663.20 4755.37 S 262.15 E 5969624.17 N 371904.61 E 2.569 4316.56 8641.57 46.660 181.680 6675.72 6727.97 4822.93 S 260.38 E 5969556.65 N 371901.68 E 0.988 4375.29 8737.02 46.160 181 .440 6741.54 6793.79 4892.03 S 258.50 E 5969487.59 N 371898.61 E 0.555 4435.34 8834.46 45.590 181.250 6809.38 6861.63 4961.96 S 256.85 E 5969417.70 N 371895.77 E 0.601 4496.22 12 August, 2002 - 13:23 Page 4 0(8 DríllQLJest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for CD2-41 MWD Your Ref: API 501032042400 Job No. AKMW22100~ Surveyed: 29 July~ 2002 North Slope, Alaska Kuparuk/Colville Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) r/1 OOft) 8867.66 45.960 180.650 6832.53 6884.78 4985.75 S 256.46 E 5969393.92 N 371894.97 E 1.709 4517.00 8899.28 47.360 179.740 6854.23 6906.48 5008.74 S 256.38 E 5969370.93 N 371894.50 E 4.897 4537.24 ~ 8929.40 49.130 178.040 6874.29 6926.54 5031.21 S 256.82 E 5969348.4 7 N 371894.56 E 7.229 4557.26 8962.98 51.360 177.050 6895.77 6948.02 5057.00 S 257.93 E 5969322.66 N 371895.23 E 7.017 4580.52 8994.49 53.250 176.480 6915.03 6967.28 5081.89 S 259.34 E 5969297.75 N 371896.21 E 6.166 4603.13 9024.74 54.790 174.540 6932.80 6985.05 5106.29 S 261.26 E 5969273.32 N 371897.71 E 7.269 4625.55 9056.10 55.890 174.790 6950.64 7002.89 5131.97 S 263.66 E 5969247.60 N 371899.67 E 3.568 4649.33 9091.54 56.640 173.780 6970.32 7022.57 5161.30 S 266.59 E 5969218.23 N 371902.10 E 3.177 4676.57 9120.33 57.120 172.050 6986.05 7038.30 5185.22 S 269.57 E 5969194.25 N 371904.67 E 5.302 4699.07 9154.89 58.000 170.440 7004.59 7056.84 5214.05 S 274.01 E 5969165.36 N 371908.61 E 4.684 4726.58 9186.97 58.790 169.810 7021.40 7073.65 5240.96 S 278.70 E 5969138.36 N 371912.84 E 2.977 4752.52 9216.25 60.040 168.130 7036.30 7088.55 5265.70 S 283.52 E 5969113.55 N 371917.24 E 6.528 4776.61 9250.01 61.960 166.930 7052.67 7104.92 5294.53 S 289.90 E 5969084.61 N 371923.12 E 6.481 4805.04 9281.95 63.470 165.030 7067.31 7119.56 5322.07 S 296.78 E 5969056.96 N 371929.53 E 7.092 4832.57 9311.54 65.110 164.440 7080.15 7132.40 5347.79 S 303.80 E 5969031.13 N 371936.11 E 5.826 4858.55 9344.39 67.370 163.830 7093.38 7145.63 5376.71 S 312.02 E 5969002.07 N 371943.83 E 7.087 4887.93 9376.00 69.590 162.970 7104.98 7157.23 5404.88 S 320.42 E 5968973.76 N 371951.75 E 7.465 4916.74 9407.10 71 .740 162.350 7115.27 7167.52 5432.89 S 329.17 E 5968945.60 N 371960.02 E 7.165 4945.56 9440.79 73.900 162.110 7125.22 7177.47 5463.54 S 338.99 E 5968914.79 N 371969.32 E 6.447 4977.22 9472.17 75.920 161.700 7133.39 7185.64 5492.34 S 348.40 E 5968885.83 N 371978.23 E 6.560 5007.05 9492.94 77.590 161.480 7138.15 7190.40 5511.52 S 354.79 E 5968866.54 N 371984.29 E 8.106 5026.98 9588.62 85.260 158.070 7152.41 7204.66 5600.21 S 387.49 E 5968777.31 N 372015.47 E 8.756 5120.60 9631.61 89.200 154.070 7154.49 7206.74 5639.44 S 404.90 E 5968737.79 N 372032.21 E 13.051 5163.41 9680.23 91.350 148.790 7154.26 7206.51 5682.12 S 428.14 E 5968694.71 N 372054.72 E 11.725 5212.01 9725.38 91 .230 147.180 7153.24 7205.49 5720.40 S 452.07 E 5968656.04 N 372077.99 E 3.575 5257.04 9777.73 91.720 146.870 7151.89 7204.14 5764.30 S 480.56 E 5968611.65 N 372105.72 E 1.107 5309.19 9821.56 92.030 147.790 7150.46 7202.71 5801.17 S 504.20 E 5968574.38 N 372128.73 E 2.214 5352.86 9872.00 91.850 148.110 7148.75 7201.00 5843.90 S 530.95 E 5968531.20 N 372154.75 E 0.728 5403.15 9917.33 91.720 147.150 7147.34 7199.59 5882.17 S 555.21 E 5968492.52 N 372178.34 E 2.136 5448.34 9968.17 90.680 146.310 7146.27 7198.52 5924.66 S 583.09 E 5968449.56 N 372205.50 E 2.629 5498.96 12 August, 2002 - 13:23 Page 5 0'8 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for CD2-41 MWD Your Ref: API 501032042400 Job No. AKMW221001 Surveyed: 29 JulYI 2002 North Slope, Alaska Kuparuk/Colville Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Inel. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 10015.75 90.550 146.4 70 7145.76 7198.01 5964.29 S 609.43 E 5968409.49 N 372231.15 E 0.433 5546.32 10064.74 90.550 148.280 7145.29 7197.54 6005.54 S 635.84 E 5968367.79 N 372256.85 E 3.694 5595.16 '- 10110.06 90.250 149.060 7144.98 7197.23 6044.26 S 659.40 E 5968328.68 N 372279.75 E 1.844 5640.41 10157.71 88.650 149.500 7145.43 7197.68 6085.22 S 683.74 E 5968287.31 N 372303.39 E 3.482 5688.01 10204.29 87.350 150.910 7147.06 7199.31 6125.61 S 706.88 E 5968246.52 N 372325.82 E 4.116 5734.54 10254.90 87.660 150.960 7149.26 7201.51 6169.81 S 731.44 E 5968201.91 N 372349.63 E 0.620 5785.09 10300.40 88.090 150.790 7150.95 7203.20 6209.53 S 753.57 E 5968161.82 N 372371.07 E 1.016 5830.55 10351.68 88.460 150.300 7152.49 7204.74 6254.16 S 778.77 E 5968116.77 N 372395.51 E 1.197 5881.80 10393.96 88.770 150.480 7153.51 7205.76 6290.90 S 799.66 E 5968079.67 N 372415.76 E 0.848 5924.05 10445.47 88.950 151.790 7154.54 7206.79 6336.01 S 824.52 E 5968034.15 N 372439.85 E 2.567 5975.55 10493.65 89.320 1 51 . 140 7155.27 7207.52 6378.33 S 847.53 E 5961991.44 N 372462.13 E 1.552 6023.72 10542.33 88.460 152.880 7156.21 7208.46 6421.30 S 870.37 E 5967948.08 N 372484.24 E 3.986 6072.39 10585.4 7 88.770 152.510 7157.25 7209.50 6459.62 S 890.16 E 5967909.42 N 372503.36 E 1.119 6115.51 10637.94 89.260 151.890 7158.15 7210.40 6506.03 S 914.62 E 5967862.60 N 372527.03 E 1.506 6167.97 10684.68 89.510 151.840 7158.66 7210.91 6547.25 S 936.66 E 5967821.02 N 372548.36 E 0.545 6214.71 10732.88 89.880 151.720 7158.91 7211.16 6589.72 S 959.45 E 5967778.16 N 372570.42 E 0.807 6262.91 10780.86 90.120 151.770 7158.91 7211.16 6631.98 S 982.17 E 5961735.52 N 372592.41 E 0.511 6310.89 10827.59 90.550 151.590 7158.64 7210.89 6673.12 S 1004.34 E 5967694.01 N 372613.87 E 0.998 6357.62 10872.92 89.750 152.680 7158.52 7210.77 6713.19S 1025.52 E 5967653.58 N 312634.37 E 2.983 6402.94 10922.74 90.120 153.330 7158.58 7210.83 6757.58 S 1048.14 E 5967608.81 N 372656.22 E 1.501 6452.75 11019.99 88.950 153.470 7159.37 7211.62 6844.538 1091.68 E 5967521.12 N 372698.27 E 1.212 6549.96 11114.32 89.690 153.730 7160.49 7212.74 6929.028 1133.62 E 5967435.93 N 372738.76 E 0.831 6644.24 11210.67 88.580 154.660 7161.94 7214.19 7015.75 S 1175.55 E 5967348.50 N 372779.20 E 1.503 6740.50 11306.79 89.200 154.590 7163.80 7216.05 7102.58 S 1216.74 E 5967260.98 N 372818.90 E 0.649 6836.49 11402.29 90.120 154.580 7164.37 7216.62 7'J88.83 S 1257.72 E 5967174.03 N 372858.40 E 0.963 6931.88 11498.15 90.920 154.180 7163.50 7215.75 7275.26 8 1299.17 E 5967086.91 N 372898.36 E 0.933 7027.64 11593.93 90.060 153.230 7162.68 7214.93 7361.138 1341.60 E 5967000.33 N 372939.31 E 1.338 7123.36 11689.41 88.890 153.740 7163.56 7215.81 7446.56 S 1384.22 E 5966914.18 N 372980.47 E 1.337 7218.80 11781.93 89.260 153.670 7165.05 7217.30 71529.50 S 1425.20 E 5966830.56 N 373020.02 E 0.407 7311.26 11879.70 90.000 153.300 7165.68 7217.93 7616.98 S 1468.85 E 5966742.34 N 373062.17 E 0.846 7408.98 12 August, 2002 - 13:23 Page 60f8 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services . Survey Report for CD2-41 MWD Your Ref: API 501032042400 Job No. AKMW22100, Surveyed: 29 July, 2002 North Slope, Alaska Kuparuk/Colville Alpine CD-2 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 11974.69 90.800 153.650 7165.02 7217.27 7701.97 S 1511.27 E 5966656.64 N 373103.13E 0.919 7503.93 12069.66 89.200 153.650 7165.02 7217.27 7787.07 S 1553.42 E 5966570.83 N 373143.82 E 1.685 7598.85 ~> 12164.99 89.750 153.250 7165.89 7218.14 7872.34 S 1596.03 E 5966484.84 N 373184.96 E 0.713 7694.14 12260.34 90.680 153.210 7165.53 7217.78 7957.47 S 1638.97 E 5966398.99 N 373226.44 E 0.976 7789.46 12355.81 91.720 152.930 7163.53 7215.78 8042.57 S 1682.20 E 5966313.16 N 373268.21 E 1.128 7884.89 12450.49 90.550 152.580 7161.66 7213.91 8126.72 S 1725.53 E 5966228.28 N 373310.10 E 1.290 7979.53 12547.39 90.990 152.400 7160.36 7212.61 8212.66 S 1770.29 E 5966141.59 N 373353.38 E 0.491 8076.42 12642.48 89.140 152.290 7160.25 7212.50 8296.88 S 1814.42 E 5966056.62 N 373396.06 E 1.949 8171.50 12735.98 87.850 151.420 7162.70 7214.95 8379.30 S 1858.51 E 5965973.47 N 373438.73 E 1.664 8264.97 12830.76 89.080 151.790 7165.24 7217.49 8462.64 S 1903.57 E 5965889.36 N 373482.36 E 1.355 8359.71 12929.16 89.690 151.710 7166.30 7218.55 8549.32 S 1950.14 E 5965801.90 N 373527.44 E 0.625 8458.10 12958.48 89.690 150.830 7166.46 7218.71 8575.03 S 1964.23 E 5965775.96 N 373541.09 E 3.001 8487.42 13024.00 89.690 150.830 7166.81 7219.06 8632.24 S 1996.16 E 5965718.21 N 373572.04 E 0.000 8552.93 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to RKB = 52.25' MSL. Northings and Eastings are relative to 1974' FNL, 1514' FEL. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from 1974' FNL, 1514' FEL and calculated along an Azimuth of 151.850° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13024.00ft., The Bottom Hole Displacement is 8860.03ft., in the Direction of 166.979° (True). -------------._-"-- 12 August, 2002 - 13:23 Page 70'8 Dri/lQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for CD2-41 MWD Your Ref: API 501032042400 Job No. AKMW221 00, Surveyed: 29 July, 2002 . Kuparuk/Colville North Slope, Alaska Alpine CD-2 Comments ~.:.. Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 13024.00 7219.06 8632.24 S 1996.16 E Projected Survey Survey tool program for CD2-41 MWD From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 448.00 0.00 448.00 447.96 13024.00 447.96 Tolerable Gyro (CD2-41 Gyro) 7219.06 MWD Magnetic (CD2-41 MWD) .-. 12 August, 2002 - 13:23 Page 80f8 DrillQuest 2.00.08.005 aoa~/at.o (Id -¡~ WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7ili Avenue, Suite 100 Anchorage, Alaska 99501-3539 October 25, 2002 RE: MWD Formation Evaluation Logs - CD2-41, AK-MW-22100 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Rob Kalish, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted CD Rom with verification listing. API#: 50-103-20424-00. RECEIV"ED fJ. OV 0 6 n""I'I./). , f..t.J~;L Alaska 01'; & Gas Gons. Comminion Ancboæ.ge ~~!Æ~Œ :'} !Æ~!Æ~[«!Æ A.ßA~KA. OIL AND GAS CONSERVATION COHMISSION / i / / f / j TONY KNOWLES, GOVERNOR 333 w. -¡rn AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (90~27~7542 Vem Johnson Drilling Team Leader Phillips Alaska, Inc. PO Box 100360 Anchorage AK 99510-0360 Re: Colville River Unit CD2-41 Phillips Alaska, Inc. Permit No: 202-126 Surface Location: 1974' FNL, 1514' FEL, Sec. 2, T11N, R4E, UM Bottomhole Location: 23' FNL, 539' FWL, Sec. 13, TIIN, R4E, UM Dear Mr. Johnson: Enclosed is the approved application for permit to drill the above development well. The permit to drill does not exempt you from obtaining additional permits or approvals 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. A weekly status report is required from the time the. well is spudded until it is suspended or plugged and abandoned. The report should be a generalized synopsis of the week's activities and is exclusively for the Commission's internal use. 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. Please note that any disposal of fluids generated from this drilling operation which are pumped down the surface/production casing annulus of a well approved for annular disposal on CD2 pad must comply with the requirements and limitations of 20 AAC 25.080. Approval of this pennit to drill does not authorize disposal of drilling waste in a volume greater than 35,000 barrels through the annular space of a single well or to use that well for disposal purposes for a period longer than one year. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ~. {k~'U/ Cammy. echsli Tayl°0' Chair BY ORDER OF THE COMMISSION DATED thisM day of June, 2002 cc: Department ofFish & Game, Habitat Section w/o encI. Department of Environmental Conservation w/o encl. Stratigraphic Test Development Oil X Single Zone X Multiple Zone 10. Field and Pool Colville River Field Alpine Oil Pool $200,000 15. Proposed depth (MD and TVD) 13016' 2560 , 7252' TVD 17. Anticipated pressure (see 2~C 25.035(e)(2») Maximum surface 2557 psig At total depth (TV D) Title Drilling Team Leader Commission Use Only I Approval date I.. tq 1M I See cov. er !etter for l./! V'" Ot~lrements ~ Mud lòg requi ed Yes 0 Directional survey required @ No 5M 10M 15M 1 a. Type of Work STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 b Type of Well Exploratory Service Development Gas 5. Datum Elevation (OF or KB) OF 52' 6. Property Designation ADL 380075 7. Unit or property Name 2. Drill X Re-Entry Name of Operator Phillips Alaska, Inc. Address P. O. Box 100360, Anchorage, AK 99510-0360 Location of well at surface feet Redrill Deepen 3. 4. 197~FNL, 1514' FEL, Sec. 2,T11N, R4E,UM At target (=7" casing point) Colville River Unit 8. Well number 2366' FNL, 1029' FEL, Sec. 11, T11 N, R4E, UM At total depth 23' FNL, 539' FWL, Sec. 13, T11N, R4E, UM 12. Distance to nearest 13. Distance to nearest well Property line CD2-42. 1514 FNL 380075 feet 11.7' at 400' / 16. To be completed for deviated wells CD2-41 9. Approximate spud date 06/25/2002 14. Number of acres in property Feet Kickoff depth 89.68° feet Maximum hole angle 450' 18. Casing program Setting Depth size Specifications Top Bottom Hole Casing Weight Grade Coupling Length MD TVD MD TVD 42" 16" 62.5# H-40 Weld 77' 37' 37' 114' 114' 12.25" 9.625" 36# J-55 BTC 2533' 37' 37' 2570 2395' 8.5" N/A 7" 4.5" 26# L -80 12.6# L-80 BTC-M 9649' IBT-mod 8180' 37' 32' 37' 32' 9686' 8212' 7227' 7022' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical feet feet Plugs (measured) Effective depth: measured true vertical feet feet Junk (measured) Casing Size Cemented Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 20. Attachments Filing fee X Property plat Drilling fluid program X Time vs depth plot BOP Sketch Refraction analysis Diverter Sketch Seabed report 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed þi. ()Z .L~~~er / .2 6 I ~6.1 n/~3 - 2. ð 7' z 'I Conditions of approval Samples required Yes Hydrogen sulfide measures Yes @ Required working pressure for BOPE 2M 3M Other: T -e.S t- Bo P Eft,; ~(9 0 y? ç-_¿f . p¿,¡r tð Me. ts.O'lf>S (h.) t!-)/ dL\J~e.", V"eetAAi-f-.~~t- Approved by Ongln::41 Slgn~d Ry Commissioner Form 10-401 Rev. 7-24-89 Cammy Oechsli Taylor wMve.d. by order of the commission ~C1A- Ic/ll/"'- ,J.-tr" - b( /'8 11. Type Bond (see 20 AAC 25.025) Statewide Number #59-52-180 Amount feet 3258 at psig 7200' TVD.SS Quantity of cement (include stage data) Pre installed 498 Sx Arcticset III L & 230 Sx Glass G 137 Sx Class G Tubing MeaBF£EIVEDal depth JUN 1 3 2002 AlaskaOit&GasCons. Commission Anchorage Drilling program X 20 AAC 25.050 requirements X Date r;fnfo2- Date & j qb~ , Submit in triplicate J j l. CD2-41 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) .12-1/411 Hole /9-5/8" Casina Interval Event Risk Level Conductor Broach Low Well Collision Low Gas Hydrates Low Running Sands and Gravel Low Abnormal Pressure in Surface Formations >2000' TVD Lost Circulation Low Low ,8-1/2" Hole /7" Casina Interval Event Risk Level Abnormal Pressure in low Surface Formations >2000' TVD Lost circulation Low Hole swabbing on trips Moderate Abnormal Reservoir Pressure low Hydrogen Sulfide gas Low Mitigation Strategy Monitor cellar continuously during interval. Gyro single shots as required Monitor well at base of permafrost, increased mud weight, decreased mud viscosity, increased circulating times, controlled drilling rates, low mud temperatures Maintain planned mud parameters, Increase mud weight, use weighted sweeps. increased mud weight Reduced pump rates, mud rheology, lost circulation material, use of low density cement slurries Mitigation Strategy BOPE drills, Keep mud weight above 9.6 ppg. Check for flow during connections and if needed, increase mud weight. Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted sweeps. Well control drills, increased mud weight. No mapped faults occur within 700' of the planned wellbore. H2S drills, detection systems, alarms, standard well control practices, mud scavengers .6-1/8" Hole / Horizontal Production Hole Event Risk Level Lost circulation Low Hole swabbing on trips Moderate Abnormal Reservoir Pressure Medium j' Hydrogen Sulfide gas Low M itigation Strate~y Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheology, lost circulation material Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECI)) monitoring, weighted sweeps. / BOPE drills, Keep mud weight above 8.9 ppg. Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud weight. H2S drills, detection systems, alarms, standard well control practices, mud scavengers ~ ..~/G. '^AL Alpine: CD2-41 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Procedure Move on Doyon 19. / Drill 12 %" hole to the surface casing point as per the directional plan. Run and cement 9 5/8" surface casing. / Install and test BOPE to minimum 5000 psi. Pressure test casing to 2500 psi. Drill out 20' of new hole. Perform leak off test. Drill 8 %11 hole to the intermediate casing point in the Alpine Sand. (LWD tools, GR/RES/PWD) / Run and cement 7" casing as per program. Top of cement + 550 feet MD above Alpine reservoir. Carry out a leak off test down the 9-5/811 x r casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus. Pressure test casing to 3500 psi. .,,/ / Run +/- 2000' 4-1/2" tbg. circulation string with tubing hanger. Install 2 way check and pressure test hanger seals to 5000 psi. Circulate diesel freeze protect. Nipple down BOP. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. Set back-pressure valve and secure well. Temporarily suspend CD2-41. Rig down and move off Doyon 19. Move on with Doyon 19. Install BOPE and test to 5000 psi. Pull circulation string / Run drilling assembly. Swap fluid to oil based mud. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.5 ppg EMW. Drill 6-118" horizontal section to well TD. (LWD: GR/RES/PWD) Contingency - set open hole isolation equipment if required (due to unconsolidated formation or wellbore having moved out ~}he Alpine reservoir sand). Run 4-%", 12.6 #, L-80 tubing with SSSV nipple, gas lift mandrels, sliding sleeve and production packer. Land hanger. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remo~e 2 way check. Drop ball and set packer. Test tubing and tubing-casing annulus separately to 3500 PSi~O mins. Rig up slickline and shift sliding sleeve. Reverse circulate diesel freeze protect to annulus and diesel to tubing Set BPV and secure well. Move rig off. J,qIGINAI.. Well Proximity Risks: Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. CD2-42 will be the closest well to CD2-41, 10.7' at 400' MD. Accounting for survey tool inaccuracies, the ellipse separation between these wells will be 7.7' at 400. MD. Drillina Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. / Lost circulation: Faulting within the Alpine reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material has proved effective in dealing with lost circulation in previous development wells. Additional care and attention will be given to the higher potential of inducing a kick when drilling horizontally as opposed to vertically. Good drilling practices will be stressed to minimize the potential of taking swabbed kicks. Annular Pumpina Operations: / Incidental fluids developed from drilling operations on well CD2-41 will be injected into a permitted annulus / on CD2 pad or the class 2 disposal well on CD1 pad. Incidental fluids to include oil based mud using mineral oil as the base fluid. The CD2-41 surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The only significant hydrocarbon zone is the Alpine reservoir and there will be 500' of cement fill above the top of the Alpine as per regulations. I / We request that CD2-41 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. As stated ß-bove, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. / There will be no USDW1s open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set near the base of the Schrader Bluff Formation (C-40). These 450-500. thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow in other areas. The maximum volume of fluids to be pumped down the annulus of this well will not exceed 35,000 bbl without the specific permission of the AOGCC. Fluid densities will range from diesel to a maximum of 12.0 ppg for drilling fluid wastes. Using 12.0 ppg fluid and the rig's specified maximum pumping pressure of 1,500 psi for annular injection, the maximum pressure at the surface casing shoe is estimated by: Max Shoe Pressure = (12.0 ppg) * (0.052) * (Surf. Shoe TVD) + 1,500 psi = (12.0 ppg) * (0.052) * (2395') + 1,500 psi = 2,995 psi = 1 ,084 psi / Pore Pressure Therefore Differential = 2995 - 1084 = 1911 psi. The internal casing pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and intermediate casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 850/0 of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 36 J-55 3 BTC 2,020 psi 1,717 psi 3,520 psi 2.992 psi / 7" 26 L-80 3 BTC-Mod 5,410 psi 4.599 psi 7,240 psi 6,154 psi / JrG \A~ CD2-41 DRilLING FLUID PROGRAM Density PV YP Funnel Viscosity Initial Gels 10 minute gels API Filtrate HPHT Fluid Loss at 160 PH Electrical Stability Oil/water ratio SPUD to Intermediate hole to 7" 9-5/8"surface casing casing point - 8 Y2" point - 12 1A" 8.8 - 9.6 ppg ./ 20 - 60 100 - 200 9.6 - 9.8 ppg 1 0 - 25 15 - 25 / 4-8 <18 NC - 10 cc / 30 min 4 - 12 cc/30 min (drilling) 8.5 -9.0 9.0 -10.0 Suñace Hole: Production Hole Section - 6 1/8" 9.1 ppg 15 -20 18 -25 NA 9-12 NA 4.0-5.5 NA +800Vts 80/20 A standard high viscosity fresh water / gel spud mud is recommended for the surface interval. Keep flowline viscosity at :t 200 sec/qt while drilling and running casing. Reduce viscosity prior to cementing. Maintain mud weight < 9.6 ppg by use of solids control system and dilution where necessary. Intermediate Hole Section: Fresh water gel/polymer mud system. Ensure good hole cleaning by pumping regular sweeps and maximizing fluid annular velocity. There is potential for lost circulation, particularly after the Alpine is penetrated. Maintain mud weight at or below 9.8 ppg and be prepared to add loss circulation material. Good filter cake quality, hole cleaning and maintenance of low drill solids (by diluting as required) will all be important in maintaining well bore stability. Production Hole Section: The horizontal production interval will be drilled with a 80/20 oil/water ratio M-I Versa-Pro mineral oil based drill-in fluid. The base fluid will consist of high flashpoint (>200 F) mineral oil with 25% by weight calcium chloride as the internal phase. Calcium carbonate bridging material will be added to minimize formation damage. Ji/GINAL Colville River Field CD2-41 Production Well Completion Plan j - 1 I j ¡ ¡ La..! IIIIli\ Ji!li¡ 16" Conductor to 114' Updated 06/10/01 4-1/2" Camco SAL-O SSSV Nipple (3.812" ID) at 2000' TVD=2189' MD Isolation Sleeve with DS-6 No-Go Lock (3.812" 00) run in profile Dual 1/4" x 0.049" s/s control lines 9-5/8" 36 ppf J-55 STC Surface Casing @ 2570' MD 12395' TVD cemented to surface /' Camco KBG-2 GLM (3.909" ID) at 3400' TVD for E Dummy with 1" BK-2 Latch 4-1/2" 12.6 ppf L-80 IBT Mod. R3 tubing run with Jet Lube Run'n'Seal pipe dope Start thermal centralizers..( 1 per joint from 4500' TVD to 2400' TVD Camco KBG-2 GLM (3.909" ID) at 5700' TVD for E Dummy with 1" BK-2 Latch Camco KBG-2 GLM (3.909" ID) 2 joints above sliding sleeve E Dummy with 1" BK-2 Latch WRDP-2 SSSV (2.125"ID) w/DS-6 No-Go Lock (3.812" OD) - to be installed later Packer Fluid mix: Diesel in tubing and annulus Completion MD TVD Tubing Hanger 32' 32' 4-1/2", 12.6#/ft, 1ST-Mod Tubing Camco SAL-O SSSV Nipple 2071' 2000' End thermal centralizers 2577' 2400' 4-1/2", 12.6#/ft, 1ST-Mod Tubing Camco KSG-2 GLM (3.909" ID) 3978' 3400' 4-1/2", 12.6#/ft, IBT-Mod Tubing Start thermal centralizers. 5798' 4500' (1 per joint) Camco KSG-2 GLM (3.909" 10) 7198' 5700' 4-1/2", 12.6#/ft, 1ST-Mod Tubing Camco KSG-2 GLM (3.909" ID) 8890' 6909' 4-1/2" tubing joints (2) Saker 4-1/2" CMD sliding sleeve 9000' 6982' with 3.813 'X' Profile 4-1/2" tubing joint (2) Baker S3 Packer 9100' 7041' with millout extension 4-1/2" tubing joints (2) HES "XN" (3.725" 10)-612 inc 9200' 7094' 4-1/2" 10' pup joint WEG 9212' 7099' Baker S3 Packer at +/- 9100' MD Well TD at 130161 MD I 7252' TVD r /1 TOC @ +/- 8900' MD (>550' MD above top Alpine C) ""............~-.- ......., ~.,- Top Alpine C at 9455' MD / 7190' TVD ~~....~<:....._-~._~~ 7" 26 ppf L -80 BTC Mod Production Casing @ 9686' MD 17227' TVD @ 872 0 1[G:NA~ i i i I I.] I~l~ It 1II11j TOC @ +/- 8900' MD (550' MD above top Alpine) ( ( Colville River Field CD2-41 Production Well Completion Plan Formation Isolation Contingency Options 16" Conductor to 114' 4-1/2" Camco BAL-O SSSV Nipple (3.812" 10), WRDP-2 SSSV (2.25" 10) and DB-6 No-Go Lock (3.812" OD) with dual 1 /4" x 0.049" s/s control line @ 2000' TVD 9-5/8" 36 ppf J-55 BTC Surface Casing @ 2570' MD 12395' TVD cemented to surface Camco KBG-2 GLM (3.909" 10) at 3400' TVD for E Dummy with 1" BK-2 Latch 4-1/2" 12.6 ppf L-80 IBT Mod. R3 tubing run with Jet Lube Run'n'Seal pipe dope Start thermal centralizers. 1 per joint from 4500' TVD to 2400' TVD Camco KBG-2 GLM (3.909" 10) at 5700' TVD for E Dummy with 1" BK-2 Latch Camco KBG-2 GLM (3.909" 10) 2 joints above sliding sleeve E Dummy with 1" BK-2 Latch Baker 4-1/2" CMD sliding sleeve with 3.813 'X' Profile set 2 joints S3 packer Baker 83 Packer set at +/- 9100' MD Updated 06/11/02 (A) Banzai ECP Assembly - Baker ZXP Packer (4.75" ID) - Baker HMC Liner Hanger - XO to IBT-Mod - blank 4-1/2" joints (TBD) - Cementing Valve - Baker Payzone ECP (mud inflated) -Landing Collar - 4-1/2" joint (1- 2) blank - Guide Shoe ~j Open Hole Scab J iner - Baker Payzone ECP (cement inflated) - 4-1/2" joints (TBD) blank tbg - Baker Payzone ECP (cement inflated) - Baker Model XL-1 0 ECP (anchor) - Muleshoe I Entry Guide (C) Open Hole Bridge Plug Assembly - Baker Payzone ECP (cement inflated) -XO -Float Collar - 4-1/2" Float Shoe Well TD at 130161 MDI 71521 TVD ,-,,-,,,,:.,«<-, , . , , . . , , , , , . I!üð. ~. . , . , . M 'III . , . , , , '1..... ",..... / . V\I~ ¡':~ f\: @ @ ): . ~ fXl." lXI~ ... ". "v : 7" 26 ppf L-80 BTC Mod Production Casing @ 9686' MD 17227' TVD @ 872 J1IG,fNA~ CD2-41 PRESSURE INFORMATION AND CASING DESIGN (per 20 ACC 25.005 ( c ) (3,4) and as required in 20 ACC 25.035 (d) (2)) The following presents data used for calculation of anticipated surface pressure (ASP) during drilling of this well: Casing Size Csg Setting Fracture Pore pressure ASP Drilling (in) Depth Gradient (Ibs. / (psi) (psi) MDfTVD(ft) gal) 16 114/114 10.9 52 53 9 5/8 2570 I 2395 14.2 1084 1529 7" 9686 I 7227 16.0 3270 2557 .,/ N/A 13016 I 7252 16.0 3282 N/A . NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BOP's to minimum 3500 psi. PROCEDURE FOR CALCULATING ANTICPATED SURFACE PRESSURE (ASP) ASP is determined as the lesser of 1) surface pressure at breakdown of the formation casing seat with a gas gradient to the surface, or 2) formation pore pressure at the next casing point less a gas gradient to the surface as follows: 1) ASP = [(FG x 0.052) - 0.1]0 Where: ASP = Anticipated Surface pressure in psi FG = Fracture gradient at the casing seat in Ib/gal 0.052 = Conversion from Ib./gal to psi/ft 0.1 = Gas gradient in psi/ft D = true Vertical depth of casing seat in ft RKB OR 2) ASP = FPP - (0.1 x D) Where; FPP = Formation Pore Pressure at the next casing point 1. ASP CALCULATIONS Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1] D = [(10.9 x 0.052) - 0.1] x 114 = 53 psi OR ASP = FPP - (0.1 x D) = 1084 - (0.1 x 2395') = 845 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1] D = [(14.2 x 0.052) - 0.1] x 2395 = 1529 psi OR ASP = FPP - (0.1 x D) = 3270 - (0.1 x 7227') = 2547 psi 3. Drilling below intermediate casing (7") ASP = FPP - (0.1 x 0) / = 3282 - (0.1 x 7252') = 2557 psi .. :J J G I ^'A L . I I V~, ( ~ Alpine, CD2-41 Well Cementina Reauirements 9 5/8" Surface Casing run to 2570' MD /2395' TVD. Cement from 2570' MD to 2070' (500' of fill) with Class G + Adds @ 15.8 PPG, and from 2070' to surface with Arctic Set Lite 3. Assume 300% excess annular volume in permafrost and 500k excess below the permafrost. Lead slurry: System: Tail slurry: System: (20701-1577') X 0.3132 fe/ft X 1.5 (50% excess) = 231.6 ft3 below permafrost 1577' X 0.3132 fe/ft X 4 (300% excess) = 1975.7 ft3 above permafrost Total volume = 231.6 + 1975.7 = 2207.3 fe => 498 Sx @ 4.44 ft3/sk -- 498 Sx ArcticSet Lite 3 @ 10.7 PPG yielding 4.44 fe/sk, Class G + 30% 0053 thixotropic additive, 0.6% 0046 antifoamer, 1.5% 0079 extender, 1.5% S001 accelerator, 50% 0124 extender and 9% BWOW1 0044 freeze suppressant 500' X 0.3132 fe/ft X 1.5 (50% excess) = 234.9 fe annular volume 80' X 0.4341 fe/ft = 34.7 fe shoe joint volume Total volume = 234.9 + 34.7 = 269.6 ft3 => 230 Sx @ 1.17 fe/sk / 230 Sx Class G + 0.2% 0046 antifoamer, 0.3% 0065 dispersant and 1 % S001 accelerator @ 15.8 PPG yielding 1.17 fe/sk 7" Intermediate Casing run to 9686' MD 17227' TVD Cement from 9686' MO to +/- 8900' MO (minimum 550' MO above top of Alpine formation) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Slurry: System: (9686' - 8900') X 0.1268 ft3/ft X 1.4 (40% excess) = 139.5 ft3 annular volume 80' X 0.2148 fe/ft = 17.2 fe shoe joint volume / Total volume = 139.5 + 17.2 = 156.7 fe => 137 Sx @ 1.15 fe/sk / 137 Sx Class G + 0.2% 0046 antifoamer, 0.25% 0065 dispersant, 0.25% 0800 retarder and 0.18% 0167 fluid loss additive @ 15.8 PPG yielding 1.15 fe/sk 1 By Weight Of mix Water, all other additives are BWOCement OR I ¡ AL ~~~-~-''::''';:"4 C/'êQted by m!o:Me! For: V Johnson i Dete plotted: 30-Moy-2002 ' Plot Reference is CD2-41 Version#\l. ! Coordinates are ÌI'\ feet reference slot /141. 1 True Vertical Depths ore reference RKB (Doyon 19).1 .. IIf&'Iø INT"IQ ~==o:o= ----- Point ----- KOP Build/Turn 3/100 West Sak Base Permafrost C-40 9 5/8 ¡EOC C-30 !C-20 I jK-3 K-2 Albian-97 Begin Final Albian-96 Casing Pt. Bld/Tm LCU Miluveach A ¡Alpine D I ¡Alpine C I ¡Target - Csg pt I IEOC ¡TO - Csg pt. I ! pH rp i -----1 Phillips Alaska, Inc. Structure: CD#2 Well: 41 Location: North Slope. Alaska Field: Alpine Field -----~----------- PROFILE COMMENT DATA MO 450.00 950.00 1072.07 1 577. 1 3 2312.84 2570.44 2573.94 2584.43 3109.45 4592.09 4907.10 8748.80 8866.96 9012.70 9150.46 9343.78 9393.39 9454.67 9685.74 9953.51 --1-3016.33 f>" ~ Inc 0.00 10.00 13.34 19.36 37.23 44.32 44.42 44.42 44.42 44.42 44.42 44.42 44.42 51.50 58.50 68.64 71.28 74.55 87.00 89.68 89.68 92.00 92.00 99.56 146.18 175.12 179.84 1 79.89 1 79.89 179.89 179.89 179.89 179.89 1 79.89 172.97 167.60 161.29 159.83 158.08 Î 51.87 151.87 151.87 Dir NO 450.00 947.47 1067.00 1552.00 2200.00 2395.00 2397.51 2405.00 2780.00 3839.00 4064.00 6808.00 6892.40 6990.00 7069.00 7155.00 7172.00 7190.00 7227.00 7234.76 7252.00 North 0.00 -1.52 -4.23 -80.71 -407.80 -575.68 -578.13 -585.4 7 -952.92 -1990.57 -2211.04 -4899.74 -4982.44 -5090.25 -5201.30 -5367.63 -5411.58 -5466.23 -5672.30 -5908.33 -8609.43 East 0.00 43.50 67.98 180.22 268.10 274.98 274.99 275.00 275.68 277.60 278.00 282.97 283.12 290.21 309.45 356.1 7 371.68 392.72 489.16 6 Î 5.32 2059.16 <'"PHILLIPS' ~ riØ . -=-:;II ~ ~ ~ V. Sect 0.00 5.25 10.05 95.89 429.33 597.18 599.62 606.94 973.08 2007.06 2226.75 4905.93 4988.34 5096.36 5208.66 5378.39 5423.50 5479.76 5693.36 5939.35 8754.51 Oeg/1001 I O.OO! I 2.00' 3.00 j.OO 3.00 3.00 3.00 0.00 0.00 0.00 0.00 0.00 0.00 6.00 ----6.00 6.001 6.00 6.00 6.00 1.00 0.00 /-~. -, Craoted by b"'1chOel For: V Johnson Dote plotted: 3; -loIay-2002 Plot Reference ia C02-41 v.1Iiot119. Coordinataa are in teet reference 8bt 141. Tru. V...tioal )opt,. are roh>renco RKB (Doyon - .... - UfI'1!:(,I 2500 2000 Phillips Alaska, Inc. ....... --- .A !"pHíwps~ '!!œ1 ~--~'-'--------'."-"'-'--"-_._---'--"------_._- Structure: CD#2 Field: Alpine Field Well: 41 Location: North Slope. Alaska! I East (feet) -> 1500 500 2000 2500 3000 3500 4000 0 500 1000 1500 1000 KOP ~Uild/Turn 3/100 SURFACE LOCATION: Bose Permafrost 19'74' FNL, 1514' FEL SEC. 2, T11 N, R4E ,",C-40 ------.--.--- j 19 5/8 Cosi!1g Pt. . Eot C.-3~ .. C-20 - 0 - 500 '-1000 175.07 AZIMUTH 5693' (TO TARGET) ..1500 *"'*Plane of Proposal"''''''' .. K-3 .. K-2 \ f - 2000 - 2500 - .3000 - 3500 (/) 0 r:: - 4000 - :::J ........... ..... - 4500 CD CD - "-" - 5000 I V - 5500 - 6000 .. 6500 - 7000 - 7500 - 8000 ..8500 - 9000 TRUE .,.-.-----.-.- AlbiO!1.-97 : Begin Final Bld/Tr!1 .. Alblon...96 , LCU MiI~veoch A . ~~rn~ fb Target - Csg pt TARGET LOCATION: 2366' FNL, 1029' FEL SEC, 11, T11N, R4E D -. Csg pt. TO LOCATION: 23' FNL, 539' FWL SEC. 13, T11 N, R4E Created oy mlc:hoet For: V Johnson: Dahl p:otted : 3O-1Icy-2002 Plot ~,..-. i. CDZ-04-1 VeBIM'9. Coo~ ani ;" 11t!! _co oIot 141. ;T"", Verticol Dep!lnl <n ref..- - (Poyer : .JP - unIX) 0 - 400- BOO - 1200. 1600- 2000- 2400-' ,-... Q; Q) 2800 - - '-'" ..c +- 3200 - a. Q) 0 0 3600 -. 0 t Q) 4000 - > Q) :J 4400 - !... I- I 4800 - V 5200 - 5600- 6000 - 6400 - 6800 - 7200 - 7600 400 Phillips Alaska, Inc. ~~ "~i "' Structure: CD#2 Field: Alpine Field Well: 41 Location: North Slo~. , RKB Elevation: 52' 175.07 AZIMUTH 5693' (TO TARGET) *"'*Plane of Proposal*** KOP .. 2.00 4.00 .. 6.00 DL5: 2.00 deg per 100 ft .. 8.00 BUi!d/Turn 3/100 . 14.1 2 West Sak It 15.01 15.51 16.54 DLS: 3.00 deg per 100 ft 18.00 19.80 Base Permofrost 21.85 24.10 26.48 28.98 31.55 34.19 C-40 39.60 9 5/8 Casing f't. mé G.-30 C-20 TANGENT ANGLE 44.42 DEG / Albian-97 6I:m!gisFinal Bld/Trn . 7i1~~196 DLS: 6.00 deg per 100 ft ..4 ~~. Target - Cag pt ~ iV"'''~~ 0 400 1 600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 6400 800 1200 Vertical Section (feet) -> Azimuth 175.07 with reference 0.00 N, 0.00 E from slot #41 CrO<:tad by m¡thco, For: V Johneon Dote plotted: 3O-l4oy-2oo2 Plot RoI.,...,co Is C02-41 ~#9. , Co0<61W1'ie1 ~ i~ ""'I ~ .1ol141. I ' 'Tr... V.rtioal Dtpth8 Crt .- RI<!I (Doyon 19).' : .,.,.. , ; .... ' 1N"I't:Q Structure: CDI2 fleld : AlpIne fleld Well: 41 ~HI~LlP~ f£CiJ Phillips Alaska, Inc. LocatIon: North Slope. ...--.",--..---.-------...-___...1 30 20 I 10 10 20 30 East (feet) -> 40 50 60 70 80 90 100 110 120 I 130 ,300 .500 , 600 . 700 t 800 t 900 ~10".0.O . \~.mb '5œD IV\. 500 "':O-¡"'O C8l. ~O. 2. '500 3~OO 3500 - 60 ~ ~2oeðlt!r300- ------.--~4000 4500 - *.5400 '----..-.52~ 53u¡Jl~.. 5Q .5500 , {¡¡) - - 40 ,.. 600 700 * * 900 .", '" 1200 - 30 .. 1 300 - 20 .300 .500 600 ~ 1400 - 10 ,..'/00 ;p3.oQ 700, 800 . 00 1000 -, 0 -, -tII- '- - "',,"; ÕO-O'. - - .+. - - - - ....... - , ---------:~O~------ - 10 ---~~~~'",., W - ..20 C -.. "".1300 - :r , % - .~o '::;- (1) (1) -.. .......... iii 1100 " 1600 & A 300 ! vOO /800 .t~OO.to~OO f/.'SOO ~ 00 .30.0 CfJ:> .,,600 .'700 .900 .,6sm '. 1200 ~.Q.O . ;/00 ~'"~ ~.'700 ",300 '. ~ "'":60:700 ~~.. BOO 800 " ' 900 .1400, ~OO '. 1100 ~ 1300 :.. 1800 1000 \ ~ '%- -110 ,*..9.()~ ~ '04000 : <0 "'0~ : so .'....'.'~'.60 I V &> 70 - 80 - 90 .300 -100 .500' .. f 1 :O~OO '''',300 ',.700 I ,.700 ~OO~O ~~ ~. 1500 .~ ~ % -120 0 C"'Qho~ Ì>'/ m;Ql\Qei For: V Johnson Date piolmo : JQ-May-2002 Pio< -- ',. CI>2-41 V....W9. Coordinates cre ;11 ~ refere~ slot ,~ 1. ~Tr\Ie Vertkci Depth. are reterenœ RKB (Doyct1 19).: . .£ : r ------- ----.- ---- .~------ h____----- ---------- - -----------------------.---- -- : ¡PhIllIpS Alaska, Inc. I ! L- __~~I_~_:__~lpine Field ._--_:~c~_~o_n.:- ~o_~~- Slope. Alaskc, Structure: CD{l2 Well: 4' ~. "PHI-LLlP$' rfl1j . I NU:Q '10 I 120 130 140 I 150 160 170 East (feet) -> 180 190 200 210 I 220 230 240 I 250 I 260 270 I 0 - 10 0)... "', ", 1300 """"'" ",,* 1400 " , " \' ... ... \' ... ... ... \' '\ 1500 ... ,- \ \ \ \ \ \ \ ~ \ 1200 ~"""',\"J600 250J \ \ \\~ \ ~600 \\1700 ~ -,." \ ~'-... \ ~ -150 13Ò¡¡ ~ \ -- 20 - 30 -- 40 - 50 - 60 ..J200 -- 70 .. J ~OO - 80 (f 0 C -- 90 :r .GD- --:::- (þ --100 ~ ......... -11{] I V -120 -130 ~ -.1100 -160 ~ - ~ -170 ~~180 ~ "!U. ..~ ~) -"4bO -190 OR I 'I. C/'O<Ited by....,- For: V JohIlBon Dete ø- , JO-May-2002 I Plet Rtforonce 18 CP241 -n#9. Coo_too en in r..t roI- 1101 ",. T",. YortiOQj OOptÞ. are rolerlnce RK8 (Ooyo<: 18). .. ...... 1N1~ 40 80 120 ~~~~8~ I ~ . ~."...,. - 160 I 'i'1200 % If 1200 '" 2100 '* .1.800 1500 . ... 1200 ~ ~ 1200 .. 1500 ~ 21.00 ~ 1;500 j¡. 18DO I) 2.400 œ Phillips Alaska, Inc. Structure: CDil Fleld : Alpine Fleld LocatIon: North .1 Well: 41 200 280 East (feet) -> 320 360 400 440 480 £lÐ '" 1800 .£lÐ.- 200 1800~ "-~50 :240 ~ 1500 ~~ " \'~ ~'-...., \". ...... ~ -280 ' , ~ 1800 - \ ~1500 ~ -320 '\ ~,.".""". ~ "'-~ - '\: ~ ~"~-360 ' ~ ' '1500 - ~ 2100 iI\,.,. 180°.. ..... ° .. ~'- 400 "':-. 180 ~ - \ " ....'. '. ... .1800 ~- '.~ , . I \~. . -~ I ~ ::\ I I , I I I ¡ I 240 I '¡¡; 1500 ~ 2400' '~ 1800 I I I I I ~ 2400 I I 1 I I I I I I ,. I I . I ",2700 I I I I I I I I I I I 'I i, : ' I I ~ 2700 ÇJ % % II> 1800 ~ "PHILLIP~ r¿m 520 600 680 560 640 720 -160 ~ 0 -~ C - ~ ~- ~ ~)-~ : œ - ~ -560 ~_. -600 I V \- \ \ \'00 ~ :780 \\ -800 'to - 840 --640 -680 .-720 ~ --.880 0 Cnraled by m:",- For: V Johnson Dote 9- : 3O-May-2002 ' f'Iol RoI._co .. CI)2-4, -#9. ~ Coon:Ø~ata ore In feet re!erencl s:ct "'1. ( ,y- V.nö<oI Do¡>t~. ..,. ,..,...."". R~B (~ 19).' , atE : @'r:ØJ I & I I ... 2100¡~10 ~ . 2~ f.~'00 I ~ 3300 , 2700 "27<000 @ oj, 3600 III' 3000 / @ /'"0 ~ \ . 4800 \ k iNTI!:Q 1200 800 1000 I (§>4/ A::\ /"5100 &/--5400 & @ 600 400 200 . 3900 .;. 4200 . 4500 ~ 5400 ¡ 5700 " --_. o_..u...u_. -,...'w.---..-.-,- -..---..-.....,..,..-"-----...--.- .. --~-'--'-'-_._--'-"----- ~HIWP~ ~ . Phillips Alaska, Inc. Structure: CDI2 FIeld: Alpine Fleld Well: 41 LocatIon: North Slope. Alaska 0 East (feet) - > 200 ~ 400 600 800 1 000 1200 1 400 1 600 1800 2000 2200 ~..'~%...'G>...~' '~~' ~, '.,' , ..' , '~' , , , ~80a 2700+ "-J\ . 00 ---,,~~~O 21~~::~~..3.~'00 \2.\3Ó~~ . 2700~'~:..0.00 ..., '~O 700 .~: ::: .;2700 : - 2400* 2400 3300, .. '.,,3000 - I .. ..', -1400 t 3300 ~ 3600'. .2. 70,0 \ \-. ' - .. 3600 \lMJ ,- f ' ' I . 2400 I I ~ 360Q , I I ~.3 00: , + 3900 ~ 2700 ... 2700 .3900 .* 2700 -1600 3300 .. <%- '-1600 3900 ~.'300Q 4200 . '"OO~OO '\ ¡¡.4200 - 2000 ~ 330,0 - 2200 ~ ~ 2400 5100 (/) 0 c: - :r I I I ~ 42 0, I I I I - I .330,0+ 4500 I I I f ~ 4800 I I I I I . 3600+ 5100 I I I I ~ 5400, I I I I I : . + 5700 . 3900 I : I I 1 ~ 6000 I I I I . 4~~OOO . 4800 If¡ 3300 . 3300 II' 5100. ,,-.,. -+. (t) (t) - .......... /11,3600 I V .. 5400' \ '. .57:03600 .36\ '''', 6000 ., 3900 '" \ .. 6300 ~3900 \' . " .. 6600 , ßR -.3000 3900. - 3200 ~- - 3400 - 3600 - 3800 .. 4200 - 4000 '. 6900 - 4200 .. 4200 -',4500 ~ % ~ - 4400 ~ § OR I I I Ix;a 1~HIWP8'~ (ilfj - Phillips Alaska, Inc ° For: V Johnson Data ~- , JO-loIoy-2002 Plot Refo"",co '. CÐ2-41 v-r>#9. . Coord11>Qtes 010 In feet~. .Iet 141- rruo v.rtiool OoJ>th ore .._ne. R~B (DO)'O" 19).. , .£ ! IN'I~Q 1200 300 300 900 600 0 ~~ I 'W ~ I I ~100 i 5400 ...54~ . 15700 00\\ * 39:0 \ . t6000 \' ~6:.s00 . 420p I '" 6600 : I I I } .. t 6900 ;.~ * 5700 .. 6000 .. 6300 ~ 6600 @ ~ ~ 7200 iÞ 4800 t 5100 .. 5400 .. 5700 .. 60~0 00 Structure: CDi2 Well: 41 Field: Alpine Field Location: North Slope. Alaska East (feet) -> 600 900 1800 2100 2400 2700 3000 3300 3600 3900 3300 1200 1500 '~\ ~6~~90; \ \ ~ . 6300 . 3900 \ .. 4200 \. 6600 tID. ~' '~4< ' '~ . 4200 \ . 6900 .. 4500 - 3600 '450~..200 ~ . 4800 - 390C "''''' \ ~ : 4200 . 4800 \ 4500 '~100.À ::: \.¡ ~ 5400 5750. ~ " 4200 .. 6900 . 4500 .. 7200 .. 4500 .. 4800 *' 4800 *; 5100 .5100 '.5400 ~ 5400 '.5700 - 5700 (/) ~- 0 c: - - 6000 :f' - -+. (1) - 6300 (1) - -... I - 6600 V - 6900 7200 - 7500 ÌI! 6000 iI, 5700 ÌIt 6.300 ~ 6000 '" 6600 . 6300 @ãj '11 6900 -7800 .. 7200 ",8100 - 8400 7200 ~ 'V - 6700 \% % - 9000 ( Pllillips Alaska, Inc. . . - ~ 'PHILLIPS' Cr.o:..J ~ m"h"'¡ For: V Johnson Dat<I p- : JO-IoIGy-2002 Plot Ro""",.. it CD2-41 v.....,nf9. eo..,.¡'"",1n ora ¡n feet ...."""'" slot '41. T,.. VorIiool Depth. ora refete... RKB (Doyor. 19)': IIU .... : -- IN"I'EQ Structure: CDN2 Fleld : AlpIne Fleld Well: 41 Location: North Slope. 280 10@ 20 30 40 (£1 50 60 70 80 270 90 100 110 ....---@ GY 120 1:30 ~~~--_._~ -m 140 .....lË.l. $>~ , 150 .10.0.0. 20Ø1000 ' ' 6Qoo Æ<' 190 }8Q:,1i1 1 70 ...~ & (ý t!Jð ~ Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well 00 Phillips Alaska, Inc. CD#2 41 slot #41 Alpine Field North Slope, Alaska PROPOSAL L,ISTING by Baker Hughes INTEQ Your ref: CD2.-41 V'~rsion#9 Our ref: prop4443 License: Date pdnted : 31'..May-2002 Date created: 31-0'an-2001 Last r.""vised : 31-May-2002 Field is centred on n70 20 37.100,w150 51 37.53 Structure is centred <In n70 20 37.100,w151 142.976 Slot locati<Jn is n70 20 17.689,w151 2 27.148 Slot Grid coordinates are N 5974383.315, E 371723.831 Slot local ccordinat.Js are 19'73.53 S 1512.36 W proj ecti<Jl'l type: alaska- Zone 4 , Spheroid: Clarke .- 1866 Reference North is True North Phillips Alaska, Inc. CD#2,41 Alpine Field, North Slope, Alaska loJeasured Inclin Azimuth True Vert Depth Degrees Degrees Depth 0.00 0.00 100.00 0.00 200.000.00 300.00 0.00 400.00 0.00 450.000.00 S50.00 2.00 650.004.00 750.00 6.00 850.00 8.00 950.00 10.00 1000.00 11.34 1072.07 13.34 1100.0014.12 1131.01 15.00 1200.0015.01 1300.00 15.51 1400.00 16.54 1500.00 18.00 1577.13 19.36 1600.00 1.9.80 1700.00 21.85 1800.00 24.10 1900.00 26.48 2000.00 28.98 92.00 95.62 99.56 100.78 102.00 110.00 121.26 131.49 140.33 146.18 14'1. '16 153.91 159.02 163.27 166.86 0.00 92.00 92 .00 92.00 92 .00 0.00 100.00 200.00 300.00 '~OO. 00 92.00 92 .00 92.00 92.00 92.00 450.00 549.98 649 .84 749.45 848.70 947.47 996 . 60 1067.00 1094.14 1124.15 1190.79 128'1.29 1383.42 1478.93 15S2 . DO 1573 .55 1667.03 1759.10 1849.51 1938.03 2100.00 31.55 169.92 2024.39 2200.00 34.19 172.55 2108.38 2300.00 36.88 174.85 2189.75 2312.84 37.23 175.12 2200.00 2400.00 39.60 176.88 2268.29 2500.00 42.36 2570..~4 44.32 2573.94 44.42 2584.43 44.42 3000.00 44.42 3109.45 44.42 3500.0t) 44.42 4000.()t) 44.42 4500.00 44.42 4592.09 44.42 4907.10 44.42 5000. 00 ,~4 . '~2 5500.00 44.42 6000.00 44.42 6500.00 44.42 1.'78.613 1'79.84 179.89 J.79.89 179.89 2343.77 2395.0t) 2397.51 2405.00 2701.82 179.89 2780.00 179.89 3058.96 179.89 3416.09 179.89 3773.22 179.89 3839.00 179.89 4064.00 179.89 4130.36 179.89 4487.49 179 . B 9 '1844 . 62 179.89 5201.76 7000.00 44.42 179.89 7500.00 44.42 179.89 8000.00 44.42 179.89 8500.00 44.42 179.89 8748.80 44.42 179.89 5558.89 5916.02 62'73 .16 6630.29 6808.00 RECTANGULAR COORDINATES O.OON O.GON a.OON O.OON O.OON O.OON 0.06S 0.24S 0.55S 0.97S 1. 52 5 2.158 4.23S 5.40S 6.948 11..85S 23.228 39.59S 60. noS 80.'118 87.138 118.185 153.963 194.38S 239.34S 288.70S 342.345 40().0~~S 407.808 461.828 527 . 345 575.685 578.135 585.478 876.32S 952.923 1226.258 1576.195 1926.12S 1990.578 2211..043 2276.065 2626.005 2975.93S 3325.875 3675.803 4025.745 4375.685 ,1n5.615 4899.748 O.OOE 1. 74E 6.97E 15.68P. 27 . 86E 43.50E 52 . '73E 67.98E 74.50B 82. 14E 99.27E 122.88E 144.97£ 165.50E 180.22£ 184.39E 201. 62£ 217. lIE 230. SSE 242.77E 252.86E 261.08£ 267.42£ 268.10E 271. 85E 274.37£ 27,1..98£ 27.1.99E 275.00E 275. 5,~\E PROPOSAL LISTING Page 1 Your ref: CD2-41 Version#9 k~st revised: 31-¡.'øy-200: GRID COORDS Easting Northing GEOGRAPHIC COORDINATE'" n.OOE O.OOE 0.00£ O.OOE O.OOE 371723.83 5974383.31 n70 20 17.69 w151 2 2'1.15 371723.83 5974383.31 niD 20 17.69 \'1151 22"/.15 371723.83 59701383.31 n70 20 17.69 w151 2 27.15 371723.83 5974383.31 niO 20 17.69 w151 227.15 371723.83 5974383.31 n70 20 17.69 w151 2 27.15 371723.83 5974333.31 n70 20 17.69 w151 2 27.15 371725.57 5974383.22 n70 20 17.69 w151 2 27.10 371730.80 5974382.95 n70 20 17.69 w151 2 26.94 371739.50 5974382.50 n70 20 1'1.68 ",'151 2 26.69 371751.67 5974381.87 n70 20 17.68 wI51 226.33 37176'1.29 5974381.06 n70 20 17.67 w151 2 25.88 371776.51 5974380.27 n70 20 17.67 w151 2 25.61 371791. 72 5974377.94 n70 20 17.65 w151 2 25.16 371798.23 5974376.66 n70 20 17.64 w151 2 24.97 3'11805.84 5974374.99 n70 20 17.62 w151 2 24.75 371822.88 5974369.79 n70 20 17.57 w151 2 24.25 371.846.29 59'74358.02 n70 20 17.46 w151 2 23.56 371868.10 5974341.28 n70 20 17.30 w151 2 22.91 371888.26 5974319.62 1'170 20 17 .09 w151 .2 22.31 371902.64 59'74299.58 n70 20 16.90 w151 2 21.88 371906.71 5974293.08 n70 20 16.83 w151 2 21.76 371923.40 5974261. 76 n70 20 16.53 w151 2 21.26 371938.29 597,n25.72 n70 20 16.18 w151 :I 20.81 371951.34 5974185.07 n70 20 15.78 w151 .2 20.40 371962.50 59741.39.92 n70 20 15.34 w151 2 20.06 371971.75 5974090.40 n70 20 14.85 w151 .2 19.76 371979.07 5974036.64 !l70 20 14.32 w151 2 19.52 371984.4:1 5973978.79 n70 20 13.75 w151 2 19.34 371984.97 5973971.07 n70 20 13.68 w151 2 19.32 37J.987.81 5973917.00 n70 20 13.15 wI51 2 19.21 371989.22 5973851.45 n70 20 12.50 w151 219.13 371989.02 5973803.1.2 n70 20 12.03 w151 2 19.11 371988.98 5973800.67 n7D 20 12.00 w151 2 19.11 371988.87 5973793.32 n70 20 11.93 w151 2 19.11 371984.49 5973502.54 n70 20 09.07 w151 2 19.1.0 275.68E 3'11983.34 5973425.95 n70 20 08.32 w151 2 19.09 276.18E 3'71.979.22 5973152.67 n70 20 05.63 w1.51 2 19.08 276.83E 3'11973.96 59"12802.80 n70 20 02.19 w151 2 1.9.05 277.48E 371968.69 5972452.93 L,70 19 58.75 w151 2 19.03 277.60£ 3'71967.72 5972388.50 n'70 19 58.11 ",'151 219.03 278.00£ :n8.12£ 278.77£ 279.42E 280.06E 280.718 281.36E 282.00E 282.65E 282.97£ 371964.40 59721613.07 n70 19 55.94 w151 2 19.02 371963.,~2 5972103.06 n70 19 5~¡.30 w151 2 19.01 371.958.15 5971.753.20 n70 19 51..86 w151 2 18.99 371.952.88 59'11403.33 n70 19 48.42 w151 2 18.97 371947.61. 5971053.46 n70 19 44.93 w151 2 18.95 3'11942.34 5970703.59 n70 19 41.54 w151 2 18.93 371.937.07 5970353.72 n70 19 38.10 w1.51 2 18.91 37:l931.80 5970003.85 n70 19 34.66 w151 2 18.89 3'11926.53 5969653.98 n70 19 31.21 w151 2 18.87 .371.923.91 5969479.89 n70 19 29.50 w151. 2 18.86 All data in feet unless otherwise stated. Calculat.ion uses minimum rJtu:vat.ure method. Coordinates fuxn slot #41 and 1'VD ¡'rom RltB (Doyon 19) (52.00 Ft above mean sea level). Bottom hole distance is 8852.27 on azimuth 166.55 degrees £rmn ",'ellhead. Total Dogleg for wellpath is 110.52 degrees. V.z:rt:i.cal secti.on Ü; £r.om wellhead on azimuth 175.07 degrees. Grid is ala,ska _. Zone 4. Grid coordinates in FEET and c.omputed using the Clar.'ke -- 1866 spher.oid Presented by Baker Hughe~' INTEQ Phillips Alaska, Inc. CD#2,41 Alpine Field,North Slope, Alaska Measured Inclin Azimuth True Vert Depth Degrees Degrees Depth 3866.96 44.42 8900.00 45.98 9000.00 50.87 9012.70 51.50 9100.00 55.91 9150.46 58.50 9200.00 61.07 9300.00 66.32 9343.78 68.64 9393.39 '7l.28 9400.00 '7l.63 159.64 9454.67 74.55 158.08 9500.00 76.99 156.82 9600.00 82.37 154.13 9685.74 87.00 151.87 9685.76 87.00 9785.76 88.00 9885.76 89.00 9953.51 89.68 10000.00 89.68 179.89 178.18 173.52 172.97 169.47 6892 .40 6915.68 6982 .04 6990.00 7041.67 167.60 165.88 162.63 161.29 159.83 7069.00 7093.93 7138.23 7155.00 71 72 .00 7174.10 7190.00 7201.1.1 7219.06 7227.00 151.87 7227.00 151.87 7231.36 151.87 7233.98 151.87 7234.76 151.87 7235.02 10500.0089.68 151.87 7237.84 11000.00 89.68 151. 87 7240.65 11500.00 89.68 151.87 7243.47 12000.00 89.68 151.87 7246.28 12500.00 89.68 151.87 7249.09 13000.00 89.68 13016.33 89.68 13 016.35 89.68 151.87 7251. 91 151. 87 7252.00 151.87 7252.00 RECTANGULAR COORDINATES 4982.448 5005.885 5080.428 5090.255 5159.74S 5201. 305 5242.97S 5329.198 5367.638 5411. 588 5417 .46S 5466.238 5506.818 5596.27S 5672.308 5672.323 5760.438 5848.598 5908.33S 5949.338 6390.288 6831.238 7272 .188 7713.138 8154.08S 8595.02S 8609.43S 8609. MS 283.12£ 283.52£ 289.05£ 290.21£ 301. OlE 309.45£ 319.27E 343.64£ 356. 17£ 371. 68£ 373.86£ 392.72£ 409.57£ 450.41E 489.16£ PROPOSAL LISTING Pag", 2 Your ref: CD2-41 Version#9 Last revised: 31-May-2002 GRID COORDS Easting Northing GEOGRAPHIC COORDINATES 371922.67 5969397.21 n70 19 28.69 w151 2 18.86 371922.67 5969373.77 n70 19 28.46 w151 218.84 371926.93 5969299.15 n70 19 27.72 w151 :;; 18.68 371927.93 5969289.30 n70 1927.63 w151 218.65 371937.55 5969219.64 n70 19 26.94 w151 2 18.33 371945.28 5969177.95 n70 19 26.54 w151 2 18.09 371954.40 5969136.13 n70 19 26.13 w151 2 17 .80 371977.31 5969049.52 n70 19 25.28 w151 2 17.09 371989.18 5969010.87 n70 19 24.90 w151 2 16.72 372003.95 5968966.67 n70 19 24.47 w151 2 16.27 372006.02 5968960.76 n70 19 24.41 w151 2 16.20 372024.06 5968911.67 n70 19 23.93 w151 2 15.65 372040.22- 5968870.82 n70 19 23.53 w151 2 15.16 372079.54 5968780.69 n70 19 22.65 w151 213.97 372116.99 5968704.02 n70 19 21.90 w151 2 12.84 489.1'7£ 372117.00 5968704.00 n'70 19 21.90 w151 2 12.84 536.26E 372162.60 5968615.12 n70 19 21.04 w151 2 11.46 583.39E 372208.22 5968526.18 n70 19 20.17 w151 2 10.09 615.32£ 372239.14 5968465.91 n70 19 19.58 w151 2 09.16 637.24£ 372260.36 5968424.55 n70 19 19.18 w151 2 08.52 372488.55 5967979.71 n70 19 14.84 w151 2 01.64 372716.75 5967534.88 n70 19 10.51 w151 1 54.76 372944..95 5967090.0,4 n70 19 06.17 w151 1 47.88 3731'73.15 5966645.21 n70 19 01.83 w151 1 41..00 373401.34 5966200.38 n70 18 57.50 w151 1 34.12 373629.54 5965755.54 n70 1853.16 w151 127.25 373636.99 5965741.01 n70 18 53.02 w151 1 27.02 373637.00 5965741.00 n70 18 53.02 w151 1 27.02 All data in feet unless <,thet"Wise st.ated. Calculat.ion uses minimum rmrvature method. Coordinat"s from slot. #41 and 1'VD f.rom RKB (Doyon 19) (5.2.00 pt above mean sea level). Bottom hole dista.nce is 8852.27 em azimuth 166.55 degrees from wellhead. Total Dogleg for weJ.lpath is 110.52 degrees. Vertical sc~(jtion is fn>Io wellhead on azimuth 175.07 degrees. Grid is alaska - Zone 4. Grid coordinates in FEE:T and computed using the Clax-Jœ - 1.866 spheroid Presented by Baker Hughes INTEQ 872.94E 1108.65E 1.344.35E 1580.06E 1815. '76E 2051.46E 2059. 1.6£ 2059.17£ Phillips Alaska, Inc. CD# 2, 41 Alpi¡-¡e Fi",ld,North Slope, Alaska PROPOS.r..L LISTING Page 3 Your ref: CD2 -,n Vers iO:l#9 Last revised: 31-May-2002 COID.'TIents in wellpa th ---------- -----,----- - ---- - - ------------- MD Rectangular Coords. Comment - _.- - -- - - - - ---- - -- --_.- --- - -- -- ---- --- - - --- -,--- - --- -- -- -- -- ----- ---- ---- - - -- -- -- ---- ---- --- - ---- ---- ---- ----- T \iD 450.00 450.00 D. DON O. OOE KOP 950.00 947.47 1.528 ,13 .50E Build/Turn 3 !l00 1072.07 1067.00 4.23S 67. 98E \\'est Sak 1577.13 1552.00 80.71S 180.22E Base Permafrost 2312.84 2200.00 407.808 268.10E C-4C 2570.44 2395.00 575.68S 274.98E 9 5/8" Casing Pt. 2573.94 2397.51 578.13S 274.99E EOC 2584.43 2405.00 585.47S 275. DOE C-30 3109.45 2780.00 952.92S 275.68E C-20 4592.09 3839.00 1990.5ÎS 277.60E K-3 4907.10 4064.00 2211.048 278.00E K-2 8748.80 6808.00 4899.745 282.97E Albian-97 8866.96 6892.40 4982.445 283 .12E Begin Final Bld/'Ern 9012.70 6990.00 5090.258 290.21E Albian-96 9150.46 7069.00 5201.308 309.45E LCU 9343.78 7155.00 5367.635 3,)6.17E Miluveach A 9393.39 7172 .00 5411. 58S 371.63E Alpine D 9,154.67 7190.00 5466.238 392 . "l2E Alpin.a C 9685.74 722'7.00 5672.305 489.16E: Target - Csg pt 9685.76 7227.00 5672.328 489.17E CD2-41 Heel Rvsd 5pm 29-May-02 9953.51 7234.76 ')908.335 615.32E EOC 13016.33 7252.00 8609.438 2(),)9.16E TD - Csg pt, 13016.35 7252.00 8609.448 2059.17E CD2-41 Toe Rvsd 5pm 29-May-02 Casing positions in strinu 'A' ~. ~M _M~_- -.--.- - .---- -_."~ _. _.._--- --, .--. .'..._- .--., .----.-. -- - - "..- --_. ---- -.- ...- ---- -.- --.- --.- TQP MD Top 'rVD Hec:tanguV.lr C<."')ord.$. Bot]lolD Bc;,t 'l'\lD Rectangular Coords. Casing 0.00 0.00 575.688 5672.328 --- - -.--- - ---- ~._-- ---- --...- -- - - ----.-- ---- -----. .__.- - - --- -..--- ---- -.-- -- ---- -...-- - --- ---.- .-- -- -- --. .--- - --- - .-.--- - - - - ...."..--- 274.98E 9 5/8" Casing 489.17E 7" Casing 0.00 0.00 O.DON O. DON O.OOE 2570.44 2395.00 O.OOE 9685.76 7227.00 Targets associated with thi s wellpa th -_.- -.'-'--"",---"--,- ---.---.--- ----,- --.- - -- ---- --- .-.- -.-.. - '0. -.- '-..-.... .-- _..- _.~.._,.- ---.. - ,- -."...- ---- - ..-- Targ,=t name Geo¡;rraphic Location T.V.D. CD2-41 H'~el Rvsd 5pIlt 372117.000,5968704.000,0.0000 7227.00 CD2-41 Toe Rvsd 5prn 373637.000,5965741.000,2.0000 7252.00 5672 .328 8609.44S Rectangular Coordinat€s 489.1"1E 15.-0ct.-1997 2059.17E 15-0ct.-1997 Revised --.-.- ----- --.-.- - _.~ - ,---- - ,- -- -,-- _.- --- _.~-- _.- -- ---- -_._.~ -_.~- --_.- - --,-- - -"~,- -- -- - --- ---- _ON -- - --- -. -- -, -- -- - _._- --- --- --- Phillips Alaska, Inc. CD#Z 41 slot #41 Alpine Fielã North Slope, Alaska t S()MMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref: CD2-4.1 Version#9 Our ref: prop4443 I.JÌcense : Date printed: 31-May-Z002 Date created: 31--,J'an-.2001 Cast revised: 31-May-2002 Field is centred on n70 20 37.100, w150 51 37.53 Struct.ure is centred on n70 20 37.100, w151 1 42.976 Slot lr>cation is n70 20 17.6$9,w151 2 27.148 Slot Grid coordinates are N 5974383.315, E 371723.831 Slot local cOOl:dinates are 1973.53 S 1512.36 W P:nJjection type: alaska ,- Zone 4, Spheroid: Clarke ,- 1866 Reference North is True North Object wellpath MWD <0-.8757 '>,,1."1 ,CD#2 MWD w/IFR <0 - 14580'>,,47,CD#.2 PMSS <0-1.1984'>, ,35,CD#2 MWD <8371 - 12651'>,,39,CD#,: MWD <0 - 9113'>,,39PB1,CD#2 MWD wi IFR <0-- '?'??' >, ,45, CD#2 MWD <0.-8595'>" 32PB1,CD#2 MWD <7712 - 11720'>, ,32,CDil2 MWD W/IFR .:6007 15355'>, ,33A,CD#2 MWD w/IFR <0 ,- 21464'>,,33,CD#2 MWD w/IFR <3794 - 1307fJ'>, ,33B,CD#2 MWD <0-111374 '>., 49,CDlÞ2 MWD <485 - 719 ':>" 26PBl,CD#2 Composite Survey <:0-490'>,,26PB2,CD#2 MWD <0-11238 '>" 26,CD#2 NWD <0-11056'>" 14,CD#2 MWD <6701 .- 8')55'>,,:~4,CD#2 MWD <:0-7562'>, ,34PBl,CD#2 MWD <0-11994 '>., 25,CD#2 M\~D <0..12278':>,,15 PB1, CD#2 M'\\'D .<11.806 - 13776' >, ,15 1'E2, CIl~2 MWD <13450 ".14161'>,,15,Cl)il2 MWD <0-10054'>, ,24PH,CD#2 M'\~D <8715 .. 14301'>,,24,CD#2 MWD <0-9507 ':>, ,42PH,CD#2 MWD <8480 -- 13138' >, ,.42,CD#2 :!@,lD <0-11000 ':>" 46,CD#2 MWD <752-7927':>" 50PB1,CD#2 MWD <6756 .- 1.l624'>,,50,CD#2 MWD <0-11134 '>" 22,CD#2 MWD <O'-???'~', ,48,CD#2 PMSS <0-7170':>, ,N(~ve ill,Neve #1 PMSS <1805 -- 9940'>, ,AlplA,Alpine #1 PMSS <0",3161'>, ,Alpl,.~lpine #1 1'M8S <1868-8850'>, ,Alp1B, Alpine #1 Closest approach with 3-D Mininmm Distance meth<Jd Last revised Distance M.D. Di'llerging fro)m M.D. 20-.Ma:r-,2002 240.1 100.0 525.0 8'-Feb-2002 60.1 200.0 12940.0 30-Nov-2001 54.4 675.0 675.0 1-0ct-2001 16.1 400.0 12880.0 12-Sep-2001 16.1. 400.0 400.0 26-Nov-'2001 38.9 300.0 300.0 IS'-NaI'-2002 89.6 500.0 500.0 lS-Mar-2002 89.6 500.0 500.0 1.9-'Aug-2001 7'7.5 612" 5 612.5 18-Sep-2001 77.5 612.5 612.5 18--Sep-2001 77.5 612.5 6D.S 20-'F,~b-;3002 80.0 100.0 9092.1 7-;Tan-2002 140.9 562.5 562.5 8-Jan-2002 140.7 487.5 487.5 6-Feb-2002 149.9 200.0 200.0 2.-0ct..2001 269.7 400.0 9052.4 15.-,Jan-2002 70.0 100.0 6640.0 26-Dec--2001 70,0 100.0 1030.9 159.7 575.0 80ao,o 259.8 100.0 100.0 259.8 100.0 100.0 259.8 100.0 100.0 169.6 400.0 400.0 169.6 4.00.0 400.0 9.6 100.0 100.0 9.6 100.0 9454.7 50.1. 100.0 8420.0 89.2 300.0 300.0 89.2 .300.0 9171..7 185.6 675.0 11080.0 69.9 400.0 400.0 3201.4 1.1.760.0 11760.0 2929.7 3760.0 3760.0 3534.8 4020.0 4020.0 3679.7 3560.0 11720.0 30-0ct,-2001 30-.0ct.2001 1B-,Jnn-200!. 26-Jun-,2001 27-,May-2001 2-Jul"200l 16-Nay-2002 3-Hay--2002 1.3-Nay-2002 30-l>!ay-2002 31-Nay-2002 16-Dec-1999 21-Sep-1999 21-.Sep'.' 1999 21-S¿)p..1999 Phillips Alaska, Inc.. CD#2 41 slot #41 Alpine Field North Slope, Alaska 3 -D M I N I MUM D 1ST Þ. N C E C LEA RAN C ERE P 0 R T INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref: CD2-41 Version#9 Our ref: prop4443 License: Date printed: 31--May'-2002 D!lte oreated : 31-,1an"2001 Last revised: 31-1;lay-2002 Field is centred on n70 20 37.100, w150 51 37.53 StructuI:e is cent. red on n70 20 37.100,w151 l42.976 Slot lOGéltion is n70 20 17.639 ,w15J. 2 27.148 Slot Gr.id c'1O:r.dinates cU'e N 5974383.315, E 371723.831 Slot local coordinates are 1973.53 S 1512.361'1 Projection type: alaska -- Zone 4, Spheroid: Clarke 1866 Reference North is 'rrue North Report is limited to clearances: less than 1000 feet Proxirnities will incorporat.,= ellipses - when survey tools are defined for both wells. Ellipse separè1tion in r~,verse brackets, e.g. )10.2(, where available. Objer.,t. wellpath DECREASING CLEARMJCgS of less than 1000 f'Eet are indicated by an '3.sterisk, e.g. 487.4* MWD <0-8757';", , 17,CD#2 CD2-53 Vers#5" 53,CD#2 M\"ID w/IFR <0 - 14580'>,,47,CD#2 CD2-35A Version#5, ,35,CD#2 PMSS <0-11984'>, ,35,CD#2 CD2--56 Versicm#2, ,56,CDtI2 MWD <8371 -. 12651'>,,39,CD#2 MWD <0 -. 9113'>,,39PB1.,CD#2 MWD w/IFR <D-- í'?,?' >" 45 ,CD#2 CD2-29 V~~r~~ion#41 J29¡CD#2 CD2-18 Ve:[s#4, , H1,CD#2 MWD <0-8595'>, ,32PB1,CD#2 m-ID <7712 - 11720' >" 3 2, CD#2 MWD W¡H'R <6007 - 15355'>, ,33A,CD#2 MWD w/IFP. <0 21464 '>, ,33,CD#2 Mv.'D w/IF'R <3794 - 13078'>, ,33B,CD#2 MIND <0-1.18'74'>, ,49,CD#2 CD2..12 Version#3" 12,CD#2 MWD <485 - 719' >, , 26PB1, CD#2 Composi te Survey <0-490' ;,., ,26PB2, CD#2 MWD <0'-1.1238'>,,26,CD#2 CD:j-.43 Le>;#1 Vers#2,,43,CD#2 CD2 -44 Vers#4., , 44, CD#2 CD2-9 Vers#4,,9,CD#2 CD2..10 Version#3" 10,CD#2 CD2 -.7 Version#3" 7, CD#2 CD2-8 Vers#4, ,8,CD#2 CD2 -5 Versicm#5" 5, CD#2 CD2-55 Vers#3" 55,CD#2 C!J2-54 Vers#5" 54,CD#2 CD2-28 Vers#6" 28,CD#2 CD2 -57 Vers#3" 57, CD#2 CD2 -58 Vers#3" 58, CD#2 CD2-52 Vers#5" 52 ,CD#2 CD2.-13 Version#3" 13,CD#2 ClOSE!st approach with 3..D Minimum Distance method I,ast revised Distance M.D. Diverging froro M.D. 20-Mar-2002 ) 23 6.4 ( 600.0 600.0 9-Apr-2001 )llB.l{ 300.0 13016.3 8-Feb-2002 )57.5( 300.0 13016.3 1.S-Apr-2002 )3902.4( 12720.0 1.2720.0 30-Nov-2001 )49.2( 71.2.5 12700.0 9-Apr.-2001 )148.0( 300.0 1.2060.0 l-Oc:t-2001 )L\.O( 400.0 13016.3 1.2-Sep..2001 ) 13.0 ( 400.0 ,100.0 26.-Nov-200l )36.0( 300.0 11060.0 1.3-Mar...2002 )1l6.3( 537.5 11.980.0 )227.5( 400.0 400.0 )85.4( 612.5 612:5 )85.,1( 612.5 612.5 )71.5( 637.5 9936.6 )71.5( 637.5 637.5 )71.5( 637.5 6120.0 )78.9( 200.0 9114.4 )286.2( 575.0 575.0 )135.8( 575.0 575.0 )137.0( 487.5 487.5 )148.4( 200.0 7260.0 )18.1( 300.0 300.0 )28.0( 300.0 130.16.3 )317.6( 400.0 400.0 )308.0( 300.0 300.0 )338.0( 300.0 9423.4 )328.0( 300.0 300.0 }358.0( :\00.0 300.0 )138.2( 300.0 13016.3 )128.1( 300.0 13016.3 )127.9{ 300.0 300.0 )157.4( 400.0 13016.3 )O.O( 13016.3 13016.3 )106.0{ 550.0 1677.8 )277.0( 487.5 487.5 15-Mar"2002 19-Aug-2001 1S..Sep-2001 1.8-Sep-2001 20-.Feb-2002 13-1;!ar-2002 ... -Jan-2002 8-Jan..2002 6-F'e.b-2002 8--May-2001 9-l,pr-2001 9-Apr'.'2001 9-Apr.-2001 9-'Ap~...2001 9-Apr-'2001 19-;Jun-2001 9...Apt'-2001 9-Apr.- 2001 9-Apr"200l 9-Apr-2001 9-Apr-2001 9'-Ap~.--2001 9-.Apr- 2001 CD2-1ó Version#5,,161CD#2 M\l1D <0-11056'>" 14,CD#2 CD2-30 \'",rs#5,. 30,CD#2 CD2-31 V",rs#5" 31,CD#2 CD2-51 \lers#5" 51,CD#2 CD2-34 Version#9" 34,CD#2 MWD <6701 - 8755'>,,3'1,CD#2 MW'D <0-7562'>" 34PB1,CD#2 MWD <0-11994 '>" 25,CD#2 MWD <0-12278'>,,15 PBl,CD#2 MWD <11806 - 13776'>, ,15 PB2,CD#2 MWD <13450 - 14161'>,,15,CD#2 CD2-20 Version#5, ,20,CO#2 MV.'D <0-10054' >" 24PH, CD#2 M'i~D <8715 - 14301'>,,24,CO#2 CD2-38 Version#3, ,38,CD#2 CD2-37PB1 V",rsion#4" 37PB1, CD#2 MWD <0-9507'>, ,42PH,CD#2 MWD <13480 - 13138'>,,42,CD#2 CD2 -40 Version#3" 40, CD#2 CD2-23 Vers#14" 23,CD#2 CD2-19 Version#6" 19,CD#2 MWD <0-11000'>" 46,CO#2 MWD <752-7927'>, ,50P.Bl,CD#2 MWD <6756 - 11624' >" 50, CD#2 CD2-22 Version#6, ,22,CD#2 MVID <0-11134'>" 22,CD#2 CD2 -48 Version#5" 43, CD#2 MWD <0-7??'>, ,48,CD#2 PMSS <1805 - 9940'>, ,AlplA, Alpin;;J #1 PMSS <0..3161'>, ,Alpl,Alpin.;ò #1 PMSS <186S-8S50'>, ,AlplB, Alpine #1 PMSS <0-7170'>"Neve ill,Neve #1 9-Apr-2001 2-0ct-2001 8-Jun-200l 9-Apr-2001 9 -Apr-2001 26-Dec-2001 15-Jan-2002 26-Dec-2001 26-Apr-20G2 30-0ct-200l 30-0ct-200l 30-0ct.-20Gl 14-Mar-2001 l8-Jun-200l 26-Jun-200l 9-Apr-2001 l2-Jul-2001 27-May-2001 2-Jul-200l 9-Apr-200l 28-Nay-2002 30-May-2002 l5-May-2002 3-May-2002 I3-May-2002 I5-l>!ay-2002 30-May-2002 23.'May-2002 31-May-2002 21-Sep-.1.999 21-Sep-.1.999 21-Sep-.1999 16-Dec-1999 ) 247.0 ( ) 256.3 í ) 106.8 ( ) 96.2 í ) 98.0 í ) 58.8 ( ) 68.9; ) 68. 9 í )155.0{ ) 257.4 í ) 257.4 ( )257..1{ ) 206.4. í ) 166.4 ( ) 166.4 í ) 24.4 ( )14.6 í ) 7.7 ( ) 7.7 ( ) 4.7 ( ) 177.5 í )214.7 í ) 48.1 í ) 85.4 ( ) 56.8 í ) 186.2 ( ) 180.1 í ) 67.9 ( ) 66.7 ( )2835.1 ( )3497.8( ) 3648 . 5 ( )3065.7 ( 487.5 487.5 475.0 575.0 300.0 970.0 1041.2 .1. 04.1. 2 662.5 450.0 450.0 450.0 512.5 462.5 462.5 900.0 850.0 475.0 475.0 475.0 400.0 737.5 400.0 450.0 9215.7 575.0 775.0 300.0 462.5 3800.0 4060.0 3580.0 11840.0 487.5 9052.4 4"75.0 575.0 300.0 8000.0 6720.0 1041 . 2 5380 .0 450.0 450.0 450.0 512.5 462.5 462.5 12 52 0 . 0 11960.0 475.0 9484.9 9407.8 400.0 7840.0 8480.0 450.0 9216.7 5') 5.0 11080.0 13016.3 462.5 3800.0 4060.0 11860.0 11840.0 ( Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 June 10,2002 RECEIVED Alaska Oil and Gas Conservation Commission 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501 Re: Application for Permit to Drill CD2-41 JUN 1 3 2002 AlaSkaOü ¡Gas Cons. CommiSSion And\oragt Dear Sir or Madam: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore production well ~om the Alpine CO2 drilling pad. The intended spud date for this well is June 25, 2002. It is intended that Doyon Rig 19 drill the well. /' The well CD2-41 will be drilled to penetrate the Alpine sand horizontally. 7" casing will then be run and cemented in place. The rig will be moved to another well on the pad,~ and will return to CD2-41 to drill out the 7" float equipment and 6-1/8" horizontal section. The horizontal section will be drilled with oil based mud usin~ineral oil as the base fluid. CD2-41 will be completed as an open hole producer. At the end of the work program the well will be shut in awaiting surface connection. Note that it is planned to drill the surface hole without a diverter. There have been 38 ,/ wells drilled on CD1 pad and 18 wells drilled on CO2 pad with no significant indication of gas or shallow gas hydrates. All of the wells on CO2 have surface casing shoes within a 1600' radius of the planned surface casing shoe of CD2-41. /' Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Pertinent information attached to this application includes the following: 1. Form 10-401 APPLICATION FOR Permit to Drill per 20 ACC 25.005 (a). 2. Fee of $100 payable to the State of Alaska per 20 ACC 25.005 (c) (1). 3. A proposed drilling program, including a request for approval of annular pumping operations. 4. A drilling fluids program summary. 5. Proposed completion diagram. 6. Proposed completion diagram with open hole isolation options. 7. Pressure information as required by 20 ACC 25.035 (d)(2). 8. Directional drilling / collision avoidance information as required by 20 ACC 25.050 (b). 9. (Diagram of riser setup which replaces diverterY // Information pertinent to this application that is presently on file at the AOGCC is: '\' Diagrams of the BOP equipment, diverter equipment and choke manifold layout as required by 20 ACC 25.035 (a) and (b). . A description of the drilling fluids handling system. If you have any questions or require further information, please contact Vern Johnson at 265-6081 or Chip Alvord at 265-6120. ~eIY~ -V~ ¿ Vern JOhn'n- Drilling Engineer Attachments cc: CD2-41 Well File / Sharon Allsup Drake Chip Alvord Cliff Crabtree Meg Kremer Nancy Lambert Lanston Chin ATO 1530 ATO 868 ATO 848 ATO 844 Anadarko - Houston Kuukpik Corporation e-mail: Tommy_Thompson @ anadarko.com .RHII..JL.IRS tXLA$KA>;tNC. ~LPINEIDr$8URSEMENTACCOÚNT< P,O.§b)( 1p3240 Anchorage; AK. 99510~3240 70-2322/719 249015875 ,(' 0990337 PAY TO THE ORDER OF: STATE OF ALASKA AOGCC 3$:rw. 7TH AVENUE, SUITE 100 MA Y 3 1, 2002 *** VOID AFTER 90 DAYS *** ".., ~ BANK = ONE. - EXACTLY **********100 DOLLARS AND 00 CENTS $********100.00 TRACE NVMBER 249015875 cYd~ ~~- ., 1I'2~gQl. SH?SIIII .:07...£:1 2822b': DHHO:1 :1 ? III RECEIVED JU~1 "1 3 2002 -. - {2. C"onc ('^rt'ftmi~810ì Alaska Oil & \Jas o. uu""'- AnchOrage CHECK 1 STANDARD LETTER DEVELOPMENT </ DEVELOPMENT REDRILL EXPLORATION INJECTION WELL INJECTION WELL REDRILL Rev: 5/6/02 C\jody\templates ( TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~D Z - Lf ( CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL (If API number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNULAR DISPOSAL INTO ANNULUS OF ANOTHER WELL ON SAME PAD ~' SP ACING EXCEPTION "CL DE" The permit is for a new wellbore segment of existing well ~ Permit No, API No. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). Please note that an disposal of fluids generated. . . Enclosed is the approved application for permit to drill the above referenced well. The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. WELL PERMIT CHECKLIST COMPANY /4/)) //5 WELL NAME C/) 2.. ...- ~ / PROGRAM: Exp - Dev -X Redrll- Setv - Wellbore seg - Ann. disposal para req ~ FIELD & POOL /ZO/60 INITCLASS /)p,1/ J-L>/I GEOLAREA ~7~ UNIT# <C>'~bt"J ON/OFFSHORE ^/[) ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . Ç) N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y \ N 3. Unique well name and number. .. . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y J N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N ~~PR Dj\ T~ 12. Permit can be issued without administrative approval.. . . . . Y N (// 6//7¡'t:>2- 13. Can permit be approved before 15-day wait.. . . . . . . . . . \JI N I ENGINEERING 14. Conductor string provided. . . . . . . . . . . . . . . . . . . ~N /vl( @ 1/4 15. Surface casing protects all known USDWs. . . . . . . . . . . N 16. CMT vol adequate to circulate on conductor & surf csg. . . . . . ~ . . 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . Y ~ 4D ,¥plA td (Z,r l&v{z'l" 18. CMT will cover all known productive horizons. . . . . . . . . . ~. N 19. Casing designs adequate for C, T, B & permafrost. . . . . . . N () 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N V ~_IN- I c¡ 21. If a re-drill, has a 10-403 fo.r abandonme~t been approved. . . ~}J/1t 22. Adequate wellbore-separatlon proposed:-. . . . . . . . . .-. . (:f/ N f. J...,d 23. If diverter required, does it meet regulations. . . . . . . . .. * Y N D ì 1/ ~ er W'to( V R-7 V'~væç 1'- . 24, Drilling fluid program schematic & equip list adequate. . . . . ~.. N 25. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . - N -L f APPR DATE 26. BOPE press rating appro.priate; test to "5500 psig. N ¡VtÇ.f 2557 fS/, ~ c~ '-(R~ 3$'00 VS~'. W4k-" (P111/0z... 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N 28. Work will occur without operation shutdown. . . . . . . . . . . N 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y(ff 30. Permit can be issued wlo hydrogen sulfide measures. . . . . éÞ N 31. Data presented on potential overpressure zones. . . . . . . JrN 11 J, A , 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y / -- , ~fR DATI; 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . N tjfG- ~¡/}/ ô~ 34. Contact namelphone for weekly progress reports [exploratory only N ANNULAR DISPOSAL 35. With proper cementing records, this plan r (A) will contain waste in a suitable receiving zone; . . . . . . . Y N (B) will not contaminate freshwater; or cause drilling waste. .. Y N to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. .~~ N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: RPctft'J JDH ~ COT WGAW(.k DTS ô~lllO~ GEOLOGY ) APPR DATE 11(- ;;/; 7/t' ~ Comments/Instructions: G:\geology\permits\checklist.doc Well H ¡story File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPEN.DIX. No special "effort has been made to chronologically organize this category of information. a Q9-;õ1 ~ I fa 7 fp Spe~r~'-Sun Drilling Services LIS Sea" U::ili::y SRevisior.: 3 S ~is~ib SRevisioî.: 4 S ~OD Oc:: l4 :5:l8:83 2082 Reel Header Service name............ .LISTPE Ða::e. . . . . . . . . . . . . . . . . . . . .02/10/14 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation ~umber..... .01 Previous Reel Name...... . UNKNOWN Comments. . . . . . . . . . . . . . . . . STS LIS Writing Library. Scientific Technical Services Tape Header Service name......... ... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .02/10/14 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name. ..... .""" ...UNKNOWN Continuation Number......01 Previous Tape Narne.......UNKNOWN Comments.. .......,. ......STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Colville River Unit (Alpine) MWD /MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA CD2-41 501032042400 PHILLIPS Alaska, Inc. Sperry Sun 14-0CT-02 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 AK-MW-22100 R. KRELL S. REYNOLDS MWDRUN 3 AK-MW-22100 R. KRELL D. MICKEY # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLJOR: GROUND LEVEL: 2 llN 4E 1974 1514 MSL 0) .00 52.25 15.90 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION S:~ING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 9.625 2553.0 8.500 7.000 9532.0 # REMARKS: ALL DEPTHS ARE MEASURED DEP:HS (MD) UNLESS OTHERWISE STATED. L. MWD RUN 1 IS DIRECTIONAL ONLY AND ARE NOT PRESENTED. ~ . MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) ~T:~:=:~G ~E:GE~ ~~E::ER ~~3E ~E~E:::~S, ;..!~= ;::~:-=-FcJ!.:AGKE~=:= ~\h:v'''E :<.ESIST:\'::Y ?~..:'..SE ~ E~.~~~' . 4. r-f\\: :<':'::1, :3 :S =:REC::JKz,.::" \o;::~ DL';.::" GAloW.J.. RA":." ,::>GR) ~~:~:::NG GE:GER MüE~LE:<. TUBE DETECTORS, E::"ECTROY~GNETIC WAVE RES:STIVIT":." PHASE 4 (EWR4\, COMPENSATES TEERY~.::" NEUTRON POROSITY (CTN), AND STABILIZED LITH-DENSITY (S::..::». r: GAMMA ~~Y LOGGED BERING CASING FROM 2334' MD, 2352' TVD, TO 2553' MD, 2365' TVD. 6. GAMMA RAY LOGGED BEHIND CASING FROM 9524' MD, 7196' TVD, TO 9532' MD, 7198' TVD. RESISTIVITY DATA LOGGED BEHIND CASING FROM 9515' MD, 7195' TVD TO 9532' MD, 7198' TVD. NUCLEAR DATA LOGGED BEHIND CASING TO 9532' MD, 7198' TVD. 7. CHLORIDES REPORTED AS WHOLE MUD CHLORIDES FOR OIL BASED MUD ON MWD RUN 3. 8. NO NUCLEAR TVD LOGS DUE TO MINIMAL VERTICAL DEPTH CHANGE ON MWD RUN 3. 9. MWD CONSIDERED PDC PER THE DISCUSSION OF REQUIREMENTS FOR ALPINE DATED 09/26/01. ALL MWD LOG HEADER DATA RETAINS THE ORIGINAL DRILLER'S DEPTH REFERENCES. 10. MWD RUNS 1 - 3 REPRESENT WELL CD2-41 WITH API # 50-103-20424-00. THIS WELL REACHED A TOTAL DEPTH OF 13024' MD, 7219' TVD. SROP = SMOOTHED RATE OF PENETRATION SGRC = SMOOTHED GAMMA RAY COMBINED SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( EXTRA SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( SHALLOW SPACING) SEMP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( MEDIUM SPACING) SEDP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY ( DEEP SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME SBD2 = SMOOTHED BULK DENSITY (LOW-COUNT BIN) SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) TNPS = SMOOTHED THER}~.L NEL'TRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE; SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT CTNA = RATE CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE ENVIRONMENTAL PARAMETERS L'SED IN PROCESSING THE NEUTRON LOG DATA: HOLE SIZE: 6.125" MUD WEIGHT: 8.9 - ::.C ?PG !~UD F: ~ ':'R..; 'IE S';:'.::":K:T~' : 3E,OOO P?M =~:;I: JENS::::": :::HLCRIDES =::)R..:.v~-'=:OK W';:'.T=::R S;'.::"':I,:TY: 1.OC - 1.'-'- ..,;, -'..., Y";'.TR::": DE!\SITY: G/ce ~:THOLOGY: S;'JCSTONE ~ File neaáe~ Service name.......... ...STSLIB.OCl Service Sub ::"'eve~ Name... Version Numbe~.......... .1.0.0 Date of Gene~ation. ..... .02/10/14 Maximum Phys~çal Record. .65535 File Type............ ....LO Previous File Name. ......STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPX RPS RPM RPP FET ROP NCNT FCNT RHOB DRHO PEF NPHI $ 1 25,000 P?~ CELORIDES 2.65 clipped curves; all bit runs merged. .5000 START DEPTH 2533.5 2543.0 2543.0 2543.0 2543.0 2543.0 2563.5 9522.0 9522.0 9522.0 9522.0 9522.0 9522.0 STOP DEPTH 12973.0 12980.0 12980.0 12980.0 12980.0 12980.0 13024.0 12925.0 12925.0 12940.5 12940.5 12940.5 12925.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA PBU TOOL MWD MWD $ SOURCE CODE BIT RUN NO MERGE TOP 2 2533.5 3 9555.5 MERGE BASE 9555.0 13024.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type. ....0 Logging Direc~ion.... .... ........ . Down Optical ::"'og depth units.. ... ... ...Feet Data Reference Point... ... ... .....Undefineå Frame Spacing..................... 60 . lIN Max frames pe= record............ .Undefined Absent value.. . . . . . . . . . . . . . . . . . . . . -999 Depth Units.. . . . . . . . . . . . . . . . . . . . . . Datum Specifiçation Block sub-type...O Name Service Oráer Units Size Nsam Rep Code C:fset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS !'~::: ::;H!'~ ~ - 68 :iE ::; RPM K',~: OHI~~ .ç ... 68 L~ E RPD !wr~~= OHM¥. 4 - 68 24 FET l.fY;:: ER .o; - 68 ;:8 8 NPHI HíC . ~ - 4 - 68 32 9 FONT !'1KL: CF3C' I 68 36 2.C .. ~ NONT MWl; CP30 4 - 68 40 : Î RHOB MWD GlOM 4 ... 68 44 ....: DRHO M"'wD GICM 4 ... 68 48 1..5 PEF MWD BIE 4 ::. 68 52 14 First Last Name Serv~ce Uni~ Min Max Mean Nsarn Reading Reading DEPT FT 2533.5 13024 7778.75 20982 2533.5 13024 ROP MWD FT/E 0.08 518.49 140.555 20922 2563.5 13024 GR MWD API 29.44 409.55 96.5006 20880 2533.5 l2973 RPX MWD OHMM 0.18 1181.66 10.3309 20875 2543 12980 RPS MWD OHt-1M 0.09 1182.45 9.74392 20875 2543 12980 RPM MWD OHMM 0.06 2000 11.2476 20875 2543 12980 RPD MWD OHMM 0.08 2000 12.2119 20875 2543 12980 FET MWD HR 0.17 653.62 3.23383 20875 2543 12980 NPHI MWD PU-S 14.85 39.64 20.6912 6807 9522 12925 FCNT MWD CP30 177.97 1060.56 684.784 6807 9522 12925 NCNT MWD CP30 14949.9 34450.4 28747.4 6807 9522 12925 RHOB MWD G/CM 1. 31 2.99 2.293 6838 9522 12940.5 DRHO MWD G/CM -0.93 0.88 0.0502764 6838 9522 :12940.5 PEF MWD B/E 0.58 12.64 1. 53964 6838 9522 12940.5 First Reading For Entire File..........2533.5 Last Reading For Entire File...........13024 File Trailer Service name.............STSLIB.001 Service Sub Level Name... Version Number... ........1.0.0 Date of Generation.......02/10/14 Maximum Physical Record..65535 File Type................ LO Next File Narne...........STSLIB.002 Physical EOF File Header Service name.. ... ....... .STSLIB.002 Service Sub Level Name... Version Number. ....... ...1.0.0 Date of Generation.......02/10/14 Maximum Physical Record..65535 File Type................ L<) Previous File Name. ..... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMAR":' VENDOR TOOL CODE GR RPX RPS FET RPD RPM ROP $ 2 header data for each bit run in separate files. 2 .5000 START DEPTH 2533.5 2543.0 2543.0 2543.0 2543.0 2543.0 2563.5 STOP DEPTH 9523.5 9515.5 9515.5 9515.5 9515.5 9515.5 9555.0 # LOG BEADEF !)~~Th DATE LOGGED: SOFTí\ARE S~RFAC::: s:. ::-~7-..:r:: \.ERS:: cn~ : DOW~EOLE S:F:W~~E VERSION: DATA TYPE (XEMJ~Y O~ REAL-TIME) : TD DR!~~ER =--...- . TOP LOG I~TER\'h.:' F':'): BOTTOX LOG :::N':'ERVJ...:' ; FT) : BIT ROTATING SPEES ,RPM;: :: :=-E ::\ ==-= ::;.~: ::: =~': , ~2G r~:: r~ : I -1'J1\: ;:...~.~ ~:..:::: : MAXIMUM F.NGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING 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 .1IN Max frames per record. ........ ....Undefined Absent value...................... -999 Depth Units.. . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 2~-JUK-O: :=:s:..-:e 66.3- Memory 9555.0 41.3 7ï.6 TOOL NUMBER PB00219HWRGV6 PBOO219HWRGV6 8.500 9532.0 LSND 9.60 42.0 9.0 450 4.8 1.400 .727 1. 200 2.500 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 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 Name Service Unit DEPT FT ROP MWD020 FT/H Min 2533.5 0.08 Max 9555 518.49 Mean Nsam 6044.25 14044 177.256 13984 ( .;. C': . 5 72.0 145.0 68.0 68.0 First Reading 2533.5 2563.5 Last Reading 9555 9555 GR Þf~J~:C A?: 35.74 .çC9.55 :'20.039 ::'396: :533.':: 9523_~ RP>: Mi\D82C OHl'0: 0.::'8 25. e7 5.21814 13946 2543 9515.: R?S MWJG20 OH~ 0.09 24.66 :.20::'62 13946 2543 95:'5.5 R?~: ~fi\J:2C OH~~ 0.:':' 3:'~.92 :.35267 13946 ~ :::;,L ~ 95::'5.5 ?~?D !>~C22: OHM!': C.OS 200C -.64849 13946 25~3 95.:'5.5 FET M1\JC2C EF. C.l: 39.58 ::'.659189 13946 2543 9515.5 Fi~st Readi~g F8~ Entire File........ ..2533.5 Last Reading Fo~ Entire File.......... .9555 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number....... ... .1.0.0 Date of Generation...... .02/10/14 Maximum Physical Record. .65535 File Type...... .... ..... .LO Next File Name..... ......STSLIB.003 Physical EOF File Header Service name...... .......STSLIB.003 Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......02/10/14 Maximum Physical Record..65535 File Type................ LO Previous File Name.. .....STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPX RPM FET RPS PEF NPHI FCNT NCNT RHOB DRHO GR ROP $ 3 header data for each bit run in separate files. 3 .5000' START DEPTH 9516.0 9516.0 9516.0 9516.0 9516.0 9522.0 9522.0 9522.0 9522.0 9522.0 9522.0 9524.0 9555.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY STOP DEPTH 12980.0 12980.0 12980.0 12980.0 12980.0 12940.5 12925.0 12925.0 12925.0 12940.5 12940.5 12973.0 13024. C 29-JUL-02 Insite 4.05.5 66.37 Memory 13024.0 85.3 92.0 TOOL NUMBER PB00261HAGR4 E:K:;, .; S:": E~ECTROV~G. RESIS. 4 STABILIZED L::EC JEK -~1- ~_L' COM? THERY~:" NEUTRON f B::R.E:E8'~E Al~= =;.s=!~.:; JA~¡"'- 2?E!, EO::: =:: S:::s ',=!\~: C~S=NG DEPTH (FT): DR:~:E~'S f BORE~O:E CON2:T:O!JS ~:.}~) ::.P=:: MUD DENS=T~ ¡:"E/G): MUD VISCOS=T~ \S): MUD PH: MUD CHLORIDES \PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing................. ....60 .1IN Max frames per record....... ......Undefined Absent value...................... -999 Depth Units....................... Datum Specification Block sub-type...O PEOC261EAGR4 FBOC239NL4 PBOC239NL4 c.~~~ Cil Baseè 9.00 68.0 .0 36000 2.8 .000 .000 .000 .000 .0 156.0 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 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 NPHI MWD030 PU-S 4 1 68 32 9 FCNT MWD030 CP30 4 1 68 36 10 NCNT MWD030 CP30 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 BIE 4 1 68 52 14 First Last Name Service Un~~ Min Max Mean Nsam Reading Reading DEFT FT 9516 13024 11270 7017 9516 13024 ROP MWD030 FT/E 1. 08 292.34 66.5803 6938 9555.5 13024 GR MWD030 API 29.44 61.95 48.799 6899 9524 12973 RPX MWD030 OHMJV: 5.75 1181.66 20.6214 6929 9516 12980 RPS MWD030 OHMK 8.71 1182.45 18.8862 6929 9516 12980 RPM MWD030 OHMM 0.06 2000 23.1123 6929 9516 12980 RPD MWD030 OHMM 0.28 1907.83 20.9942 6929 9516 12980 FET MWD030 HR 0.49 653.62 8.41582 6929 9516 12980 NPHI MWD030 PU-S 14.85 39.64 20.6912 6807 9522 12925 FCNT MWD030 CP30 177.97 1060.56 684.784 6807 9522 12925 NCNT MWD030 CP30 14949.9 34450.4 28747.4 6807 9522 12925 RHOB MV\~C3C G/C~ - - - 2 99 ;:: 293 6E3E 9522 ::'29~C ::; DR..~C MWDC3C G / C!\o~ -....' c- ,""', 88 C :;502764 6835 9522 :294 C .... -,) v PEF M"v\"DC3C 3/£ 56 ' ~ 64 53964 683S 9522 :'29~() - -'-<... - - F~~s: Read~ng For E~:~re File........ ..9516 Las: Reading Fc~ E~:~~e File........ ...13024 File Traile~ Service name............ .STSLIB.OO3 Service Sub Level Name... Version Number.......... .1.G.0 Date of Generation...... .02/10/14 MaximUIT. Physical Recorå..65535 File Type................ La Next File N~~e..... ......STSLIB.OO4 Physical EOF Tape Trailer Service name... ... .......LISTPE Da t e . . . . . . . . . . . . . . . . . . . . . 02/10/14 Origin................. ..STS Tape Name................UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.............LISTPE Date....... ..............02/10/14 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................UNKNOWN Continuation Number......Ol Next Reel Name...........UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File