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208-011
• ®rganiZ/ng (done) RESC olor Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: „~,a,a iiiimimiiium DIGITAL DATA ^ Diskettes, No. ^ Other, No/Type: Re.~a~~e~ea iiiuiiiiiii~imu OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: BY• ~ Maria Date: ~ ~ U I ,l D /s~ r n r Pro"ect Proofing J III II'I() II III II III BY: Maria Date: / D ~s~ ti P x 30 ~ = ~ ~~ + ~~ =TOTAL PAGES ~ on repara Scanning _ . _ _ . (Count does not include cover heet) ,~ ~ ~ BY: Maria Date: /~~ ~s~ ~!~~~ ~~- Production Scanning Stage 1 BY: Stage 7 BY: Page Count from Scanned File: 1~~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: / YES NO Maria Date: ~ V ~ D ~s~ If NO in stage 1, page(s) discrepancies were found: YES NO Maria Date: /s u i ~~ ^i n i u u i e ou Scanning is complete at this point unless rescanning is required. ~teScanned ill 111111 IIIII II III BY: Maria Date: /s~ Comments about this file: Quality Checked III 111111 III II'I III 10/6!2005 Well History File Cover Page.doc • „�'��\�V/7, ,s, — i AT E t % STATE OF ALASKA • . AL, A OIL AND GAS CONSERVATION COMM ,ON tik-% 0 TS 1 (4 (u-' • APPLICATION FOR SUNDRY APPROVALS JAN 0 6 2014 20 AAC 25.280 1.Type of Request: Abandon r Rug for Redrill r• Perforate New Pool r Repair w ell r- Change AglagQ r Suspend fl Rug Perforations r.. Perforate E Pull Tubing r Time Extension r Operational Shutdown fl Re-enter Susp.Well r Stimulate r" Alter casing r Other: I— 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska, Inc. • Development N" Exploratory r 208-011 • 3.Address: 6.API Number: Stratigraphic r Service 17• P. O. Box 100360,Anchorage,Alaska 99510 50-103-20559-01 • 7.If perforating, 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No 17 • ► CD3-316A • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 372105,372104 • Colville River Field/Fiord Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 12515 • 6716 • 12505'• 6715' • none none Casing Length Size MD ND Burst Collapse CONDUCTOR 78 16 114' 114' SURFACE 2708 9.625 2745' 2476' INTERMEDIATE 11646 7 11680' 6725' - LINER SLOTTED 956 4.5 12505' 6716' - Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11661-11740, 11940-11980,12100-12382. 6724-6729,6728-6722,6718-6714 4.5 L-80 11555 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft) PACKER-BAKER PREMIER PACKER • MD=10824 TVD=6541 INJECTION VALVE . MD=2125 TVD=2020 12.Attachments: Description Summary of Proposal P. 13. Well Class after proposed work: Detailed Operations Program fl BOP Sketch Exploratory Stratigraphic r Development r Service14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: 3/1/2014 Oil l Gas l WDSPL r Suspended P. 16.Verbal Approval: Date: VVINJ r GINJ r WAG r Abandoned r" Commission Representative: GSTOR fl SPLUG l 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mick Davasher @ 265-6870 Email: Mick.J.Davasherna conocophillips.com Printed Name Mick Dava her Title: Wells Engineer Signature lryt Phone:265-6870 Date I/ 2/ ZO! / Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ?j\1*— CD03 Plug Integrity BOP Test `Mechanical Integrity Test r Location Clearance r"' RBDMS MAY I 0 2014 Other: 80/, �s/• 1-0 350 P p5/ Spacing Exception Required? Yes 111No [ Subsequent Form Required: /0 — 40 (� APPROVED BY ,/ Approved by: 6y4 /04e.„ ...____ COMMISSIONER THE COMMISSION Date: /— / T -111 Approved appOak at'^nn � 1 m nths from the date of approval. Form 10-403(Revise 10/2012) K ?IQ, 111011 Submit Form and Attachments in Duplicate REG JAN © i 2014 ConocoPhillips AOGCC Alaska P.O. BOX 100360 ANCHORAGE,ALASKA 99510-0360 January 2nd, 2014 State of Alaska Alaska Oil &Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Re: Sundry Permit—Request to plug back well for Rotary Side Track Dear Sir/Madam: ConocoPhillips Alaska, Inc. hereby re-applies for an Application for Sundry Approval to plug back well CD3-316A(PTD#: 208-011) in order to prepare the well for an upcoming rotary sidetrack.'A Sund was • - iousl _•• .-d for and •ranted (Sundry Number:312-491 approved 1-16-2013) •u •ue to scheduling, the drilling rig was no a• e o ge o e well within e mon p- •• e Sundry was valid for. The objective of the proposed CD3-316A Plug Back is to prepare the well for a rotary side track planned for the first half of 2014. CD3-316A was originally completed in 2008 as a Kuparuk injector. The proposed side track will be competed as a Nechelik producer(with a selective to produce the Kuparuk if present). The sidetrack procedures will be covered in a separate Application for a Permit to Drill CD3-316B. The attached plug back proposal illustrates the plan forward. If you have any questions or require any further information, please contact me at 265-6870. Sincerely, Mick Davasher Wells Engineer CPAI Drilling and Wells fe je��cf /e...�Q frevovc, . Coo otvcrtd. Nor /l eed� ?,5Q/' -' %4 CD3-316A Permit to Drill #: 208-011 The objective of this procedure is to abandon the current perforations and to setup the well for a rotary side track, starting mid-March 2014. The latest SBHP data obtained on 12/27/2012 was 3,636 psi @ 6,451' TVD. Worst case maximum anticipate surface pressure during this work, with a full column of diesel is estimated to be 1,288 psi. Well Suspend Procedure: Slickline: 1. RIH and drift tubing to the A-1 inj valve at 2125' RKB. Pull A-1. 2. Drift tubing to nipple at 10,885' to confirm tubing is open. 3. RIH with tandem gauges and obtain 30 min SBHP as deep as possible. PUH 100' TVD and obtain another 30 min SBHP. 4. Brush and flush the nipple at 10,885' RKB and also confirm the ability to pump into the well. 5. Pull the 1" DV from mandrel at 10,710' RKB. Leave pocket open. Coiled Tubing: 6. RIH and set 3.75" cement retainer in XN nipple at 10,885' RKB. (OK to use alternative but ensure that there is a check valve in the retainer to prevent cement from backflowing after unstung.). DO NOT unsting from retainer once set. 7. Inject seawater at various injection rates/pressures to confirm injectivity. 8. Begin pumping 96 bbls of 15.8 ppg class G cement through the retainer and into the formation. After pumping 52 bbls of cement away unsting from retainer and lay in 17 bbls of cement, taking 1:1 returns from tubing. After the 17 bbls have been layed in open the IA casing valve and squeeze another 17 bbls into the casing through the mandrel at 10,710' RKB. Ensure a 1:1 (in:out) ratio when squeezing into the IA. After squeezing cement into the IA POOH and rig down. Cement tops should be near 9880' RKB in both the tubing and the IA. Slickline: 9. Notify AOGCC inspector 24 hours prior to these next few steps. 10. RIH and tag top of cement plug. 11. MIT the production casing (MIT-IA) to 2000 psi and document for 30 minutes. MIT the production tubing (MIT-T) to 2000 psi and document for 30 minutes. These steps are required by the AOGCC so properly document on the CPAI MIT form. 12. RIH with tubing punch and punch a hole in the tubing at the top of the cement tag. Confirm hole in the tubing by circulating fluid from tbg to IA. If unable to circulate, PUH 500' and punch tubing again. 13. Begin circulating 290 bbls of KWF (from SBHP taken in step 3 above) down the tubing and up the IA followed by 60 bbls of diesel (or crude) freeze protect. U-tube and equalize the tubing and IA. E-line: 14. RIH with tubing cutter and cut the 4.5"tubing at +/- 3300' RKB. Cutter type isn't critical as we're not overshotting this stub. 15. If unable to confirm positive cut move uphole 15' and cut again. 16. RDMO. CD3-316A Pre and Post Plug Back for Redrill Current Completion Proposed Pre Rise ST P&A i L L H 1.)Drift and Pull A-1 In) Camco Ball-0 Nipple l 2,125 KB Valve. wFA-1 Injection Valve 2.}Drift and 68F 9 55/8'4010 L-80 Casing a,2,745'KBJ nipple @ 10,885'KB. Tubing, 3,)Pull DMY from mandrel @ 10,711'KB. Circ.Holes _ ,,, .t 4.)Set cement retainer in nipple @ 10,885' /j, 44 KB. Ha0!burton X Nipple @ 10,428'KB NE 5.)Pump 52 bbls class G `/�� cement through retainer. Baker Gauge Carrier n:10,519'KB �/ ja 6.}Unsung and lay in 17 bbis of cement into tubing. GLM: --- Pre:DMY @ 10.711'KB 7.)Open IA and displace 17 Post cemented open pocket @'10,711'KB r irr A bbis of cement into the IA. r I ;' NOTE; TOC in both IA and Baker Premier Packer g.10,824'KB tubing is estimated to be @ 9,880'KB. I I " '-in• —we- 8.)Tag tint top and PT. / Provide AOGCC 24 hrs 0 lill XN Nipple Cr; 10,885'KB notice prior. Alt 91 Punch tubing hole above !. _ �: /��. TOC and circ.in KWF. 4 5"12.604 L-83 Tubing:g'11.550'KB ��,//a l +, 'Alreline En:ry Gude it 11,555'KB % ,,-I/ 14.5 Cut tubing @ approx. 3,300'KB. I�I I 7'26#L-80 Casing @ 11,680'KB , ir, Illlil f/// /�/r IlillI IIIIII i� Illlll I1I1Ii �� �1� IIIII. / IIII1! �yOf // Illltl Fiord KupanJk Slots ��r��//rr / 11,940'-11.98D'KB I///.I 4,40 tilill 12,100'-12.382'KB //// �l�l�! pet / illll!' ,.1,/,;:, 0 illlllt €IIIII3I f // II ! // irZ',/*/' 'I� 'I'' 4.5"Slotted Liner ?12,505'KB ,//// � ' •�� T:'r 1-?^513 Doyon 19 CD3-316A Abandonment Procedures: The proposed scope of work for this sundry application includes: 1. MIRU Doyon 19 Rig. 2. Test 7" casing, 7" casing pack off and BPV through inner annulus to 2,000psi for 10 minutes, chart pressure test. 3. Test tree adaptor to 5,000 psi. 4. Pull BPV. 5. Circulate diesel freeze protect over to 9.6 ppg kill weight brine through tree and monitor flow for 30 minutes. 6. Set BPV and test through inner annulus to 1,500 psi for 10 minutes. 7. Set blanking plug. 8. Nipple down tree. 9. Nipple up BOPE and test with 4.5"x 7"test joints to 3,500 psi. 10. Remove blanking plug and BPV. 11. Pull 4-1/2"tubing (pre-cut at+/- 3,300' MD). 12. Pressure test lower rams with 3.5" and 5"test joints. 13. Run CIBP on 5"drill pipe and set at+/- 3,200' MD. Pressure test to 2,500 psi. 14. Run in hole with mechanical casing cutting on 5" drill pipe and cut casing at+/-3,100' MD. 15. Flush 7"x 9-5/8" annulus with KWF 16. Swap 3.5"x 6"VBR to 7" casing rams and pressure test. 17. Pull 7" casing to surface and lay down the same. 18. Swap 7" casing rams to 3.5"x 6"VBR and pressure test. 19. Pull 7" casing out with spear and lay down. 20. RIH in hole with 3.5" cement stinger and set cement kick off plug from the top of bridge plug to 200 ft within the surface casing. 21. P/U directional drilling BHA and RIH. Tag TOC and pressure test surface casing and kick off plug to 3,500 psi. 22. Drill out 20' new formation and perform LOT. WNS CD3-316A Conocx ' ''hips �y Well Attributes Max Angle&MD TD • Alaska Inc. ,,,k Wellbore API/UWI Field Name Well Status Inc'F) MD(MB) Act Btm(ftKB) L„ u+,llp, )� 501032055901 FIORD KUPARUK INJ 99.61 11,972.40 12,515.0 Comment H2S(ppm) Date Annotation End Date KB-Grd(ft) Rig Release Date '' SSSV:WRDP Last WO: 36.63 2/122008 Well Config'.-CD3-316A,12/6/2010 1012:35 AM Schematic-Actual Annotation Depth(ftKB) End Date Annotation Last Mod...End Date Last Tag: I Rev Reason:RESET INJ VLV Imosbor 12/6/2010 Casrin HANGER.32 - Casinging DescStnptiongs String 0... String ID...Top(ftKB) Set Depth(f...Set Depth(ND)...String Wt..String...String Top Thrd CONDUCTOR 16 15.250 36.0 114.0 114.0 62.50 H-40 Welded e_- Insulated Casing Description String 0... String ID...Top(11KB) Set Depth(f».Set Depth(TVD)_.String Wt-..String...String Top Thrd SURFACE 95/8 8.835 36.3 2,744.8 2,476.2 40.00 L-80 MBTC Casing Description String 0... String ID...Top(11KB) Set Depth(f...Set Depth(TVD)...String Wt...String...String Top Thrd INTERMEDIATE _ 7 _ 6.276 34.1 11,679.7 6,725.4 26.00 L-80 MBTC CONDUCTOR Casing Description String 0... String ID_.Top(11KB) Set Depth(f--.Set Depth(TVD)...String Wt...String...String Top Thrd Insulated. LINER SLOTTED 4 12 3.958 11,549.5 12,505.0 6,715.7 12.60 L-80 SLHT 36-114 Liner Details Top Depth (TVO) Top Incl Nomi... --- Top(Po(B) (MKS) (1 Item Description_ Comment ID(In) 11,549.5 6,717.0 83.16 SLEEVE BAKER LINER SETTING SLEEVE 5.070 VALVE,2,126 NIPPLE,2,125 =' 11,562.4 6,718.5 83.06 NIPPLE RS NIPPLE 4.875 11,565.8 6,718.9 83.03 HANGER BAKER'DG'FLEXLOCK LINER HANGER 4.853 G` 11,575.7 6,720.1 82.96 XO BUSHING 3.830 Tubing Strings Tubing Description String 0... String ID...Top(5KB) Set Depth(1...Set Depth(TVD)...String Wt.String... String Top Thrd . TUBING 41/2 3.958 31.9 11,556.1 I 6,717.8 12.60 L-80 IBT ' Completion Details Top Depth SURFACE, , (TVD) Top Incl Nomi... 36-2,745 Top(ftKB) (ftKB) (°) Item Description Comment ID(in) 31.9 31.9 -0.05 HANGER FMC TUBING HANGER 3.970 2,125.4 2,020.0 35.81 NIPPLE CAMCO BAL-0 NIPPLE-TOP PORT IS PLUGGED(CONTROL PORT), 3.812 NIPPLE,10.428 E ONLY BALANCE PORT AVAILABLE ,,,,,_, 10,427.9 6,422.9 71.36 NIPPLE HALLIBURTON X NIPPLE 3.813 10,519.1 6,451.7 72.25 GAUGE BAKER GAUGE CARRIER 3.970 10,824.2 6,541.0 74.50 PACKER BAKER PREMIER PACKER 3.875' GAUGE,10,519-- ® 10,885.1 6,557.3 74.50 NIPPLE I-(ALLIBURTON XN NIPPLE 3.725 11,555.1 6,717.7 83.12 WLEG 'BAKER WIRELINE GUIDE 3.950 Other In Hole ireline retrievable plugs,valves,pumps,fish,etc.) Top Depth (TVD) Top Incl Top(IBB) (ftKB) r) Description Comment Run Date ID(in) ---- 2,125.4 2,020.0 35.81 VALVE A-1 INJECTION VALVE(HYS-443) 12/52010 1.250 Perforations&Slots INJECTION. Shot 10.710 Top(TVD) Btm(TVD) Dens _-- Top(ftKB)Btm(ftKB) (ftKB) (ftKB) Zone Date (sh... Type Comment 11,661.0 11,740.0 6,723.5 6,729.0 2/9/2008 32.0 Slots Alternating solid/slotted pipe 11,940.0 11,980.0 6,727.7 6,722.4 2/9/2008 32.0 Slots Alternating solid/slotted pipe 12,100.0. 12,382.0 6,717.5' 6,713.9 2/9/2008 32.0 Slots Alternating solid/slotted pipe PACKER, 10.824 Notes:General&Safety End Date Annotation -- 2/18/2008 NOTE WELL SIDETRACKED 11/42009 NOTE:VIEW SCHEMATIC w/Alaska Schemetic9.0 NIPPLE 10885- [ fT. WLEG,11,555 --- :--rt t N • 11111=i. ;C: -., NTERMEDIATE, I I -- 3411,680 v - t I 1 slot. Mandrel Details 11661-11 740Top Depth Top Port -.,ei;# (ND) Incl OD Valve Latch Sue TRO Run Stn Top(ftKB) (ftKB) r) Make Model (in) Sery Type Typo (In) (psi) Run Date Com... ;I I 1 10,710.5 6,507.8 72.54 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.05/112008 Slots, 1 e 11,940-11,980 1 e 53:1 1 =- S% a1 1 al hi 12,100.12,382 D)t t kh LINER SLOTTED, J I. 11,549-12,505 CD3-3168,), TD(CD312.515 12.515 1 , OF 741, THE STATE la 1 S o f Con ery Lion Commission itt GOVERNOR SEAN PARNELL 333 West Seventh Avenue rh' OF ALASY' Anchorage, Alaska 99501 -3572 Main: 907.279.1433 Fax: 907.276.7542 Tyson Wiese N� FEB 2 6 2013 Wells Engineer SC ConocoPhillips Alaska, Inc. P.O. Box 100360 ✓ D t Anchorage, AK 99510 C 1 Re: Colville River Field, Fiord Oil Pool, CD3 -316A Sundry Number: 312 -491 Dear Mr. Wiese: 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, aA Cathy P. Voerster Chair DATED this 1(1 d y of January, 2013. Encl. STATE OF ALASKA � R ECEIVED A�(A OIL AND GAS CONSERVATION COMM ` ON DEC 31 012 ' • APPLICATION FOR SUNDRY APPROVALS ` " s /1161 (3 20 AAC 25.280 AOGCC 1`. Type of Request: Abandon r Plug for Redrill r' • Perforate New Pool r Repair well r Change Approved Program r Suspend r Plug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdow n r Re -enter Susp. Well r Stimulate r Alter casing Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r Exploratory r 208-011' 3. Address: Stratgraphic r Service p". 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20559 -01 - 7. If perforating, 8. Well Name and Number: What Regulation or Conservation Order govems well spacing in this pool? Will planned perforations require spacing exception? Yes r No CD3 -316A • 9. Property Designation (Lease Number): po Lotb 10. Field /Pool(s): ADL 372105, 364474. 37 10 ‘ � Colville River Field / Fiord Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12515 • 6716 none none Casing Length Size MD TVD Burst Collapse CONDUCTOR 78 16 114' 114' SURFACE 2708 9.625 2745' 2476' INTERMEDIATE 11646 7 11680' 6725' LINER SLOTTED 956 4.5 12505' 6716' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): -11661-11740, 11940 - 11980, 12100 -12382 6724 - 6729,6728 -6722, 6718 -6714 4.5 L - 11555 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER PREMIER PACKER . MD= 10824 TVD= 6541 INJECTION VALVE • MD =2125 TVD =2020 12. Attachments: Description Summary of Proposal Fl • 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 1/14/2013 Oil r Gas r WDSPL r Suspended f 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tyson Wiese © 263 -4250 Email: Tvson.M.Wiesee.conocoohillips.com Printed Name T , on les Title: Wells Engineer `31- WI- Signature `\ Phone: 263 -4250 Date Commission Use Only Sundry Number:5I27-99 r Conditions of approval: Notify Commission so that a representative may witness Plug Integrity Ji -'BOP Test 1 V Mechanical Integrity Test r Location Clearance r 4 3500 P s Se' / RBDMS JAN 2 81013 Other: 1 ( n n . 43ft ' N 0f:�'7 Tn.? r 4 %k c vc� j, Spacing Exception Required? Yes El No Z Subsequent Form Required: G d 4/67- J APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: �� / Approved application is valid for 12 months from the date of approval. O 1 f1 A/ 012) p ! / 13 Submit Form and Attachments in Duplicate ,-i e • • CD3 -316A Permit to Drill #: 208 -011 The objective of this procedure is to abandon the current perforations and to setup the well for a rotary side track, starting mid January 2013. Well Suspend Procedure: Slickline: 1. RIH and drift tubing to the A -1 inj valve at 2125' RKB. Pull A -1. 2. Drift tubing to nipple at 10,885' to confirm tubing is open. 3. RIH with tandem gauges and obtain 30 min SBHP as deep as possible. PUH 100' TVD and obtain another 30 min SBHP. 4. Brush and flush the nipple at 10,885' RKB and also confirm the ability to pump into the well. 5. Pull the 1" DV from mandrel at 10,710' RKB. Leave pocket open. Coiled Tubing: 6. RIH and set 3.75" cement retainer in XN nipple at 10,885' RKB. (OK to use alternative but ensure that there is a check valve in the retainer to prevent cement from backflowing after unstung.). DO NOT unsting from retainer once set. 7. Inject seawater at various injection rates /pressures to confirm injectivity. 8. Begin pumping 96 bbls of 15.8 ppg class G cement through the retainer and into the formation. After pumping 52 bbls of cement away unsting from retainer and lay in 17 bbls of cement, taking 1:1 returns from tubing. After the 17 bbls have been layed in open the IA casing valve and squeeze another 17 bbls into the casing through the mandrel at 10,710' RKB. Ensure a 1:1 (in:out) ratio when squeezing into the IA. After squeezing cement into the IA POOH and rig down. Cement tops should be near 9880' RKB in both the tubing and the IA. Slickline: 9__Natifx AOGCC inspector 24 hours prior to these next few steps 10. RIH and tag top of cement plug. 11. MIT the production casing (MIT -IA) to 2000 psi and document for 30 minutes. MIT the production tubing (MIT -T) to 2000 psi and document for 30 minutes. These steps are required by the AOGCC so properly document on the CPAI MIT form. 12. RIH with tubing punch and punch a hole in the tubing at the top of the cement tag. Confirm hole in the tubing by circulating fluid from tbg to IA. If unable to circulate, PUH 500' and punch tubing again. 13. Begin circulating 290 bbls of KWF (from SBHP taken in step 3 above) down the tubing and up the IA followed by 60 bbls of diesel (or crude) freeze protect. U -tube and equalize the tubing and IA. E -line: 14. RIH with tubing cutter and cut the 4.5" tubing at +/- 3300' RKB. Cutter type isn't critical as we're not overshotting this stub. 15. If unable to confirm positive cut move uphole 15' and cut again. 16. RDMO. 1 C Onc�i , T-4 well rh ur Tti sv'irct (Vell 1v4$ fld „ ,c , '0 &M o.)/ ve r'i' )eot,o n .S(j�O�,� i f o, h4f J e e11 cl�f4'fed , I AerPf��, kc�'�� j � i' I w ell a! cfn injettof ; ,r c/ef (r r7(' , ieng r TU i fiv4i 1 fc�l 1914, ✓ 4 r / /bI? 3'0 4 he c41 //P/ 401/k 04'1” f-- - 071 - ,.��d f<<A? /cum 74,) /0/ • • Doyon 19 CD3 -316A Abandonment Procedures: The proposed scope of work for this sundry application includes: 1. MIRU Doyon 19 Rig. 2. Test 7" casing, 7" casing pack off and BPV through inner annulus to 2,000psi for 10 minutes, chart pressure test. 3. Test tree adaptor to 5,000 psi. 4. Pull BPV. 5. Circulate diesel freeze protect over to 9.6 ppg kill weight brine through tree and monitor flow for 30 minutes. 6. Set BPV and test through inner annulus to 1,500 psi for 10 minutes. 7. Set blanking plug. 8. Nipple down tree. 9. Nipple up BOPE and test with 4.5" x 7" test joints to 3,500 psi. 10. Remove blanking plug and BPV. 11. Pull 4 -1/2" tubing (pre -cut at +/- 3,300' MD). 12. Pressure test lower rams with 3.5" and 5" test joints. 13. Run 0BP on 5" drill pipe and set at +/- 3,200' MD. Pressure test to 2,500 psi. 14. Run in hole with mechanical casing cutting on 5" drill pipe and cut casing at +/- 3,100' MD. 15. Flush 7" x 9 -5/8" annulus with KWF 16. Swap 3.5" x 6" VBR to 7" casing rams and pressure test. 17. Pull 7" casing to surface and lay down the same. 18. Swap 7" casing rams to 3.5" x 6" VBR and pressure test. 20. RIH in hole with 3.5" cement stinger and set cement kick off plug from the top of bridge plug to 200 ft within the surface casing. 21. P/U directional drilling BHA and RIH. Tag TOC and pressure test surface casing and kick off plug to 3,500 psi. 22. Drill out 20' new formation and perform LOT. fAijei— r - WNS CD3 -316A Conocorhillips Well Attributes Max Angle & MD TD Alaska Inc. Wellbore API /UWI Field Name Well Status Inc! (°) MD (ftKB) Act Btm (ftKB) canom,,tos 501032055901 FIORD KUPARUK INJ 9961 11,972.40 12,515.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date ••- WellConfia: - CD3316A,12l8/201010:12:35AM SSSV: WRDP Last WO: 36.63 2/12/2008 Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: Rev Reason: RESET INJ VLV Imosbor 12/6/2010 Casing Strings -SAN 37 - - Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.250 36.0 114.0 114.0 62.50 H-40 Welded Insulated Cas Description i 0... Stl ... Top (IIKB) Set Depth (f,.. Set Depth ( TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.835 3 6.3 2,744.8 2,476.2 40.00 L-80 MBTC C asing Description SStrtring nn 0... String ing ID ... Top (11K Set De (1 ... Set De ( TVD) ... String Wt... String ... String T Thrd INTERM EDIATE 7 6.276 ID 34. 11 6 26.00 L-80 M CONDUCTOR Casing Description String 0... String ID ... Top (8IKB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd lnsulatea, LINER SLOTTED 4 1/2 3.958 11,549.5 12,505.0 6,715.7 12.60 L-80 SLHT 38-114 Liner Details Top Depth (TVD) Top Inc! Top (ftKB) (ftKB) (°) Item Description Comment ID (in) RE 11,549.5 6,717.0 83.16 SLEEVE BAKER LINER SETTING SLEEVE 5.070 VALVE. 2,125 NIPPLE. 2.125 3 r 11,562.4 6,718.5 83.06 NIPPLE RS NIPPLE 4.875 ME 11565.8 6,718.9 83.03 HANGER BAKER DG' FLEXLOCK LINER HANGER 4.853 Mir 11,575.7 6,720.1 82.96 XO BUSHING 3.830 i . . Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd TUBING 41/2 3.958 31.9 11,556.1 6,717.8 12.60 L -80 IBT Completion Details Top Depth SURFACE,_ , (TVD) Top loci 5004... 38 - 2'745 Top (ftKB) (ftKB) r) Rem Description Comment ID (in) 31.9 31.9 -0.05 HANGER FMC TUBING HANGER 3.970 2,125.4 2,020.0 35.81 NIPPLE CAMCO BAL-O NIPPLE - TOP PORT IS PLUGGED (CONTROL PORT), 3.812 NIPPLE. 10,428 _ ONLY BALANCE PORT AVAILABLE r 10,427.9 6,422.9 71.36 NIPPLE HALLIBURTON X NIPPLE 3.813 10,519.1 6,451.7 72.25 GAUGE BAKER GAUGE CARRIER 3.970 10,824.2 6,541.0 74.50 PACKER BAKER PREMIER PACKER 3.875 GAUGE, 10,519 10,885.1 6,557.3 74.50 NIPPLE HALLIBURTON XN NIPPLE 3.725 E. l 11,555.1 6,717.7 83.12 WLEG BAKER WIRELINE GUIDE 3.950 Other In Hole ireline retrievable plugs, valves, pumps, fish, etc.) . Top Depth (TVD) Top Inc! W Top (ftKB) (RKB) (1 Description Comment Run Date ID (in) 2,125.4 2,020.0 35.81 VALVE A -1 INJECTION VALVE (HYS-443) 12/5/2010 1.250 Perforations & Slots INJECTION, Shot 10,710 Top(TVD) Btm (TVD) Dens Top (fIKB) Btm (ftKB) ((KB) (6/KB) Zone Date (sh•.• Type Comment 11,661.0 11,740.0 6,723.5 6,729.0 2/9/2008 32.0 Slots Altemating solid/slotted pipe 11,940.0 11,980.0 6,727.7 6,722.4 2/9/2008 32.0 Slots Alternating solid/slotted pipe 12,100.0 12,382.0 6,717.5 6,713.9 2/9/2008 32.0 Slots Alternating solid/slotted pipe PACKER, 10,824 Notes: General & Safety "' End Date Annotation 2/18/2008 NOTE: WELL SIDETRACKED 11/4/2009 NOTE: VIEW SCHEMATIC w /Alaska Schematic9.0 NIPPLE, 10.885 i W. W. mi WLEG, 11,555 j m I NTERMEDIATE, 1 1 3411,880 1 ' Slots, Mandrel Details 11.881-11,740 Top Depth Top Port (TVD) Inc( OD Valve Latch Site TRO Run Stn Top )BKB) (RKB) (°) Make Model (in) Sere Type Type (!n) (psi) Run Date Com... 1 10,710.5 6,507.8 72.54 CAMCO KBG-2 1 GAS LIFT DMY BK 0.000 0.0 5/11/2008 sloe, I! i r 11,940-11,980 1 1 (I ■ Slots, s .1 12.100 - 12.382 a r LINER i SLOTTED. 11,549-12.505 TD ( CD3.318A), CD3 12,515 0 i CD3 -316A Pre and Post Plug Back for Redrill Current Completion Proposed Pre Rici ST P &A i , L 1'} Drift and Pull A -1 in) Valve. Cameo Ball -O Nipple `a 2,125' KB w:.A -1 Injection Valve 2.) Drift and B &F OW 9 5f8' 40# L -d0 Casing a 2,745' KB nipple? 10,885' KB. Tubing 3.) Pull DMY from mandrel g 10,711' KB. Circ. Hk,. 4.) Set cement retainer in nipple 10,885' /' , diir KB. 0 4 -t: I L,.rton X Nipple Cd, 10,428' KB = �.) pump 52 bbls class G '1).,..) � s red cement through retainer. II 4 baker Gauge Gamier g. 10,519' Kb Gi U_ 311111_ 6.) unsung and lay in 17 or bbls of cement into tubing. GUN' =re: DMY g 10.711' KB 4004,74 7.) Open IA and displace 17 ='ost .: r' e°ted open pocket Ci2 10,711' KB bbis of cement into the IA. 1 ,MIIIIIIII■ 4 _ NOTE: TOC in both IA and Baker Premier Packer a 10,824' KB ... tubing is estimated to be @ 4. � 07 11 9.880' KB. 8.) Tag cmt top and PT. � Provide AOGCC 24 hrs II 4 XN Nipple g 10,885' KB Dement notice prior. Retainer R,,�.� �fJ 9.) Punch tubing hale above Aiiim -.0.--- � r , 1 TOC and kirk. in KWF. � f 5" 12.60# L -20 Tubing ,V. 11.550' KB ( \ — Wireline En:nj Guide a 11,555' KB %/ 10.) Cut tubing g approx. Fe 3,300' KB. I I 7' 26# L -80 Casing gig 11.580' KB sir I I i : r / I rdkSlots .� % 11,661'1' —11,740' KB � 1J. We" , 0 11,940' — 11,980' KB � 1 I FioPO ; " 1" ; rd — 12.382' KB ..A, 000 . I , e/// / • I f' "'r // I / A---." ti,...i � � 4,„, 4.5" Slotted Liner g 12,505' KB ��� r-I TW 1-3-2013 • • Page 1 of 1 Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. file: //F: \Daily_Document_ Record \Procedures_Instructions \FW INTENT PLUG for RE - DRI... 4/6/2012 • MEMORANDUM To: Jim Regg ~~~~ ~3~I ~a P.I. Supervisor FROM: John Crisp Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, March 22, 2010 SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD3-316A COLVILLE RIV FIORD CD3-316A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv 4 Comm Well Name: COLVILLE RIV FIORD CD3-316A API Well Number: 50-103-20559-01-00 Inspector Name: John Crisp Insp Num: mitJCr100227175856 Permit Number: 208-011-0 Inspection Date: 2/26/2010 Rel Insp Num: MITOP000002945 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well CD3-316A Type Ill G TVD 6541 ~ IA 2502 3005 ~ 2990 2990 P.T.D 2080110 TypeTCSt ~ SPT Test psi 1635 ~ QA 528 563 557 557 Interval 4YRTST ~ p~F P ~ Tubing 3034 3034 3034 3034 Notes:.4 bbl pumped for test. F Monday, March 22, 2010 Page 1 of 1 DATA SUBMITTAL COMPLIANCE REPORT 2/1/2010 Permit to Drill 2080110 Well Name/No. COLVILLE RIV FIORD CD3-315A Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20559-01-00 MD 12515 ND 6716 Completion Date 2/12/2008 Completion Status 1-OIL Current Status WAGIN IC Y ' REQUIRED INFORMATION Mud Log No Samples No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: GR / RES /DENS / NEUTR (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / i y e rviearrrm~ rvumurr ryame scale meals NO Start Stop LM R@C@IVeCI GOmments D C Lis 15951 ~nduction/Resistivity 11550 12514 Open 2/28/2008 LIS Veri, GR, ROP, FET, RPX, RPS, RPM, RPD w/PDS and Tif graphics ~ g -i Induction/Resistivity 25 Blu 11650 12484 Open 2/28/2008 MD Vision Service 8-Feb- 2008 og Cement Evaluation 5 Col 10248 11485 , Case 5/5/2008 MCNL, GR, CCL, CBL 9- ~ Feb-2008 ED C Pds 16191 ment Evaluation 10248 11485 Case 5/5/2008 MCNL, GR, CCL, CBL 9- / Feb-2008 ~'ED D Asc Directional Survey 36 12515 Open 5/7/2008 ~ Directional Survey 36 12515 Open 5/7/2008 D D Asc Directional Survey 36 11407 Open 5/7/2008 PB 1 ~pt Directional Survey 36 11407 Open 5/7/2008 PB 1 '~D C 16237~Induction/Resistivity 6017 11690 Open 5/7/2008 Graphics EWR in PDF, EMF and CGM in ND and MD D C Lis 16238/Induction/Resistivity 6017 11407 Open 5/7/2008 PB1 EWR plus Graphics og , Induction/Resistivity 25 Col 4794 6727 Open 5/7/2008 ND DGR, EWR, ALD, CTN Log Induction/Resistivity 25 Col 4794 11690 Open 5/7/2008 MD ROP, DGR, EWR, ~ ALD, CTN ~g Induction/Resistivity 25 Col 4794 11407 Open 5/7/2008 P61 MD ROP, DGR, EWR, ALD, CTN DATA SUBMITTAL COMPLIANCE REPORT 2/1 /2010 Permit to Drill 2080110 Well NameiNo. COLVILLE RIV FIORD CD3-316A Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20559-01-00 '~ 'C~~~~~ ~a~C L/ IL/GVVD ""' `°`u' '- ""` 'vu v,L ` d ' g Lo Col 25 Induction/Resistvity 4794 6771 Open 5/7/2008 P61 ND ROP, DGR, EWR, ALD, CTN pt LIS Verification 2710 11690 Open 5/22/2008 LIS Veri, NPHI, RPS, FONT, NCNT, RPM, DRHO, RPX, FET, RHOB, GR, RPD, ROP D C Lis 16294~duction/Resistivity 2710 11690 Open 5/22/2008 LIS Veri, NPHI, RPS, FCNT, NCNT, RPM, DRHO, RPX, FET, RHOB, GR, RPD, ROP r Rpt LIS Verification 2710 11407 Open 5/22/2008 LIS Veri, NPHI, NCNT, RHOB, RPS, DRHO, FET, RPD, RPX, RPM, FCNT, i GR, ROP ~ ED C Lis ~ 16295`~Induction/Resistivity 2710 11407 Open 5/22/2008 PB 1 LIS Veri, NPHI, NCNT, RHOS, RPS, DRHO, FET, RPD, RPX, RPM, FCNT, GR, ROP Well Cores/Samples Information: Name Sample Interval Set Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? / N Daily History Received? Chips Received? "Y7'Id-'~ Formation Tops Y / N Analysis `fi' III Received? • Comments: DATA SUBMITTAL COMPLIANCE REPORT 2/112010 Permit to Drill 2080110 Well Name/No. COLVILLE RIV FIORD CD3-316A Operator CONOCOPHILLIPS ALASKA INC API No. 50-103-20559-01-00 MD 12515 ND 6716 Completion Date 2/12/2008 Completion Status 1-OIL Current Status WAGIN UIC Y Compliance Reviewed By: __ _ ~? ____ Date: ~~~~ ~ 1 ~_~ I~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ~ 6. Permit to Drill Number: 208-011 ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD3-316A 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG Q 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20559-01 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^ or Continuation ^ or Final ~ 308-127 4/16/2008 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 359" 359 totals (bbls): 2008 / 2nd 0 0 0 0 0 2008 / 3rd 0 0 0 0 0 2008 / 4th 0 0 0 0 0 009 / 1st 31422 100 0 31522 30 1/11/2009 2/14/2009 CD3-305, CD3-115 Total Ending Report is due on the 20th volume 31422 100 359 31881 30 Ex: of the month following the final month of the quarter (bbls): . April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarkaand Approved Substances Description(s): *freeZe rotect volumes ct to the best of my knowledge. I hereby certify that the foregoing is t r ue nd co rr e a / ~ / ~ ~ ~ / ~ ?( 7 ~2'~ Ort C Si t D t fi-+ ! /+~ .~ gna ure: a e: .. _ Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265-6120 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate t Regarding 4 year state witnessed~TIA's on CD3 pad Regg, James B DOA ~ __ ~-~_~~~t~(..~ From: Regg, James B (DOA) ~ ~~~ Sent: Wednesday, June 10, 2009 12:51 PM To: 'NSK Problem Well Supv' Cc: Fleckenstein, Robert J (DOA) Subject: RE: Regarding 4 year state witnessed MITIA's on CD3 pad ~i (e . .~-° ~b Zo 5 -u41 •' ZisCU --U ~ Z- 2t,'~~ c? i r: Your request to defer MITs at Colville River Unit CD3 pad until February 2010 is approved. The agreement to test in summer was driven by weather considerations and efficiency at CPAI's request. Testing the below listed wells in February 2010 will still accomplish the requirement to test at least every 4 years. We will make the necessary changes in our database to reflect a new due date of February 28. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 _ _ .. From: NSK Problem Well Supv [mailto:n1617@conocophillips.com] Sent: Tuesday, June 09, 2009 2:28 PM To: Regg, James B (DOA) Cc: NSK Problem Well Supv; NSK Well Integrity Proj; ALP DS Lead and Simops Coord; Maunder, Thomas E (DOA) Subject: Regarding 4 year state witnessed MITIA's on CD3 pad Jim, By prior agreement with the Commission, Alpine CD3 pad is due for 4 year state witnessed MITIA's in July of 2009. Due to the remote location of that pad, the only available way to perform the MIT's during July would be to use a small triplex pump. The small triplex pumps have a 3 bbl capacity of fluid on board. With 8 wells to test on that pad, that would require to refill the triplex tank several times during the testing, possibly extending the testing time from 1 day to 2 or even 3 days, pending diesel availability. ConocoPhillips requests the testing cycle of CD3 to be deferred until February of 2010 when the pad is accessible with a larger pump by ice road. In reviewing our records of test dates, CD3-108 (PTD 205-033) has the oldest test date of 09-29-06. The other wells have more recent tests than that date (see table below). All of the wells will still be in compliance in February. February would become the new test month for CD3 and 2010 would be the start of the 4 year cycle. CD3-110 (PTD 205-041) last tested on 01/12/07 - AoGCe ~"`~~~ tI iZlzz,/o7 CD3-112 (PTD 206-032) last tested on 04/28/07 ~- ~~~ w~~"„ems 4-~z~~o ~ CD3-114 (PTD 207-033) last tested on 04/02/08 - ~~~ ~'~~"~55 ~(Z~ z~~ CD3-118 (PTD 208-025) last tested on 03/07/09 - Ac~C-C-c ,,v'~ss 3~-~~z,c~~ag CD3-302 (PTD 206-010) last tested on 07/19/07 _ ~c~ u1~~s ~)t~2,c,r] `,~ 6I~~(~~ CD3-316A (PTD 208-011) last tested on 05/16/08 ~ /~6 C'C i,,~ a-l-re3S S~I~Z~~ CD3-305 (PTD 208-193) tentatively scheduled to have initial witnessed test on 6/13/09. Please let me know if you have any questions and if this is acceptable. Brent Rogers/Martin Walters 6/10/2009 ~.~cl~~( r Regarding 4 year state witnesse~ITIA's on CD3 pad ~ Page 2 of 2 Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 6/10/2009 i CRU CD3-110 PTD 205-041 6/9/2009 TT(1 Preccnrec s • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^~ 6. Permit to Drill Number: 208-011 ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD3-316A 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG ~ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20559-01 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g, Field: Initial Disposal ^ or Continuation ^~ or Final ^ 308-127 4/16/2008 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 359* 359 totals (bbls): 2008 / 2nd 0 0 0 0 0 2008 / 3rd 0 0 0 0 0 2008 / 4th 0 0 0 0 0 Zoos/1st 31422 100 0 31522 30 1/11/2009 2/14/2009 CD3-305, CD3-115 Total Ending Report is due on the 20th volume 31422 100 359 31881 30 of the month following the final month of the quarter. Ex: (bbls): April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): *freeZe rotect volumes correct to the best of my knowledge. n g is true nd 1 hereby certify that the foregoi a ( ~ ~ / ~ Signature: ~~hF. ~. l}~ Date: ~ ~, ('~ Printed Name: G. L. Alvord Title: Alaska Drilling Manager Phone Number: (907) 265-6120 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate .- • • ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 Apri16, 2009 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: 9 ~ ~~, ~~, APF~ ~ 2005 _ : ° ~ 0~1 Cis C~~s® C~ issi~~ hQr ~Q~-iii ~_3 ~ (~ ~ Enclosed please fmd a spreadsheet with a list of wells from the Coville River Unit (CRU). Each of these wells was found to have a void in the conductor. These voids were filled with 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 Apri15~', 2009. 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 416/2009 Well Name PTD # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al CD3-301 206-020 9" NA 9" NA 0.85 4/5/2009 CD3-302 206-010 5" NA 5" NA 0.43 4/5/2009 CD3-303 208-013 9" NA 9" NA 1.70 4/5/2009 CD3-305 208-193 8" NA 8" NA 0.85 4/5/2009 CD3-316A 208-011 26" NA 26" NA 8.93 4/5/2009 CD3-107 206-189 34" NA 34" NA 11.05 4/5/2009 CD3-108 205-033 10" NA 10" NA 1.26 4/5/2009 CD3-109 205-059 9" NA 9" NA 2.13 4/5/2009 CD3-110 205-041 4" NA 4" NA 0.43 4/5/2009 CD3-111 206-030 5" NA 5" NA 0.85 4/5/2009 CD3-112 206-032 3" NA 3" NA 0.43 4/5/2009 CD3-113 207-004 14" NA 14" NA 1.28 4/5/2009 CD3-114 207-033 5" NA 5" NA 0.85 4/5/2009 CD3-115 209-006 8" NA 8" NA 1.28 4/5/2009 CD3-117 209-026 6" NA 6" NA 0.43 4/5/2009 CD3-118 208-025 8" NA 8" NA 0.85 4!5/2009 STATE O~ ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR LIISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ~ 6. Permit to Drill Number: 208-011 ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD3-316A 2. Address: 4b. Well Status: Oil ^ Gas ^ WAG Q 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20559-01 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ^ or Continuation ^~ or Final ^ 308-127 4/16/2008 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bblS): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 359* 359 totals (bbls): 2008 / 2nd 0 0 0 0 0 2008 / 3rd 0 0 0 0 0 2008 / 4th 0 0 0 0 0 2009 / 1st Total End~ns Report is due on the 20th volume 0 0 359 359 0 of the month following the final month of the quarter. Ex: (bbls>: April 20 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): *freeze protect volumes is true and correct to the best of my knowledge. I hereby certify that the foregoing ^^ Signature: /C`F. t. a'l- Date: ~ ~y`(°t Printed Name: G. C. Alvord Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6120 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^~ 6. Permit to Drill Number: 208-011 ConocoPhillips Alaska, Inc. Development ^ Exploratory ^ 7. Well Name: CD3-316A 2. Address: 4b. Well Status: Oil ^ .Gas ^ WAG Q 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20559-01 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: g. Field: Initial Disposal ^~ or Continuation ^ or Final ^ 308-127 4/16/2008 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 359* 359 totals (bbls): 2008 / 2nd 0 0 0 0 0 2008 / 3rd 0 0 0 0 0 2008 / 4th 2009 / 1st Total Ending Report is due on the 20th volume 0 0 359 359 0 of the month following the final month of the quarter. Ex: (bbis): Apri120 for the first quarter, July 20 for the second quarter, 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): *freeZe rotect volumes rrect to the best of my knowledge. I hereby certify that the foregoing is true and c o // Signature: ~~ ~ W~ Date: l.,a(~~, (^,8 Printed Name: G. C. Alvord Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6120 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF ANNULAR. DISPOSAL 1. Operator: 4a. Well Class: Stratigraphic ^ Service ^ 6. Permit to Drill Number: 208-011 ConocoPhillips Alaska, Inc. Development ~ Exploratory ^ 7. Well Name: CD3-316A 2. Address: 4b. Well Status: Oil ~ Gas ^ WAG ^ 8. API Number: P. O. Box 100360, Anchorage, Alaska GINJ ^ WINJ ^ WDSPL ^ 50-103-20559-01 3. (Check one box only) 5a. Sundry number: 5b. Sundry approval date: 9. Field: Initial Disposal ~ or Continuation ^ or Final ^ 308-127 4/16/2008 Colville River Field 10. (h)(1) drilling mud, drilling (h)(2) drill rig wash (h)(3) Other Commission Volume (bbls): Number of Disposal Disposal Source Wells: cuttings, reserve pit fluids fluids and drill rig approved substances (include days Beginning Dates: Ending Dates: cement-contaminated domestic waste water descriptions in block 12) disposal drilling mud, completion occurred fluids, formation fluids and any necessary water added Previous 359* 359 totals (bbls): 2008 / 2nd 0 0 0 0 0 2008 / 3rd 2008 / 4th 2009 / 1st Total Ending Report is due on the 20th volume 0 0 359 359 0 (bbls): of the month following the final month of the quarter. Ex: April 20 for the first quarter July 20 for the second quarter 11. Attach: Disposal Performance Data: Pressure vs. Time ^ Step Rate Test ^ , , October 20 for the third quarter, and January 20 for the Other (Explain) ^ fourth quarter. 12. Remarks and Approved Substances Description(s): *freeze rotect volumes onl I hereby certify that the foregoin 'true and correct to the best of my knowledge. '7 ~t $ ~p ~ ~ ~~~~~-~`--~- - Signature: J Date: Printed Name: Randy Thomas Title: Kuparuk Drilling Team Leader Phone Number: (907) 265-6830 Form 10-423 Rev. 2/2004 INSTRUCTIONS ON REVERSE SIDE Submit in Duplicate • MEMORANDUM TO: Jim Regg ~ ~ /Z,~/~~ P.I. Supervisor I FROM: Jeff Jones Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, May l9, 2008 SGBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC CD3-316A COLVILLE RIV FIORD CD3-316A Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv~l~ Comm Well Name: COLV[LLE RN FIORD CD3-3t6A API Well Number: 50-1 03-205 59-0 1-00 Inspector Name: Jeff Jones Insp Num: mitJJ080517121953 Permit Number: 208-01 t-0 ~ Inspection Date: Si1612008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Nlin. Well ~cDS-3ib.a',TypeInj D 6sai ~ IA z6s '~ t96o ! 1930 ! tsr _ _ __ _ ~~~~ I yp ~ p 1635.2 - ~~ ~~ 670 ~~~~680 I 68a ~ 688 P.T. I, aoaollo T eTest SPT j Test si OA , ~ __ Interval ~TAL ~ P!F P -- Tubing'. sso sso ~, sso ! sso NOteS' Estimated 3 BBLS diesel pumped. Monday, May 19, 2008 Page I of I ~ ~ WELL LOG TRANSMITTAL To: State of Alaska May 20, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Data: CD3-316A PBl AK-MW-555131 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 Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted CD Rom with verification listing. API#: 50-103 -205 59-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 3~,,, ~_ ~;~ ~ ~- _~ _a. ~~€ Date Signed: ao~ -oar ~~ ~ ~}~. ~ ~ WELL LOG TRANSMITTAL To: State of Alaska May 20, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Data: CD3-316A AK-MW-555131 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention o£ Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1 LDWG formatted CD Rom with verification listing. API#: 50-103-20559-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Ala~ska:99518 _~ ~ , ._ ~- ~" --~. ~~; ~, Dafe Signed: STATE OF ALASKA RECEIVE® MAY ~ ~ ~~~~ ALASKA OIL AND GAS CONSERVATION COMMISSION glaska Oil & Gas Cons. REPORT OF SUNDRY WELL OPERATIONS an~tinP.,~~ ~. Operations Performed: Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Other 0 ~J Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension ^ Change Approved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well ^ ~b~-.Z,/'~ 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 208-011 3. Address: Stratigraphic ^ Service^' 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20559-01 ` 7. KB Elevation (ft): 9. Well Name and Number: 36.3'KB CD3-316A ` 8. Property Designation: 10. Field/Pool(s): ADL 372104,372105 Colville River Unit / Fiord Oil Pool 11. Present Well Condition Summary: Total Depth measured 12515' feet true vertical 6716' ~ feet Plugs (measured) Effective Depth measured feet Junk (measured) true vertical feet Casing Length Size MD ND Burst Collapse Structural CONDUCTOR 114' 16" 114' SURFACE 2708' 9-5/8" 2744' INTERMEDIATE 11647' 7" 11680' SLOTTED LINER 956' 4-1/2" 12505' Perforation depth: Measured depth: true vertical depth: Tubing (size, grade, and measured depth) 4-1/2" , L-80, 11556' MD. Packers &SSSV (type & measured depth) Baker Premier Packer Packer = 10824' SSSV= BAL-O SSSV= 2124' 12. Stimulation or cement squeeze summary: Intervals treated (measured) F S ~ Treatment descriptions including volumes used and final pressure: ~ ~ ~~08 ' ~A~ 13. Representative Daily Average Production or Injection Data flats Ot 15t ErifBCtiOn: 5!12/08 Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 4773 3107 725 Subsequent to operation 6221 268 331 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run _ Exploratory ^ Development ^ Service^ " Daily Report of Well Operations _ 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: 308-125 contact Jack Walker Printed Name Title Production Engineer , p ~ Signature ~"~°~~~~`~+G<-~/~ ~~a ~ ~ ~ ~ Phone 265-6268 Date ~~~ 9' ~b Form 10-404 Revised 04/2004 ~ ~ ~ ~ ~ A ~ ~ ~~'~ ~ Submit O ' ' I Onl ~~r/~;v WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501-3539 RE: MWD Formation Evaluation Logs: CD3-316+A+APB1 Apri129, 2008 AK-MW-555131 CD3-316+A+APBl 2" x 5" MD TC Logs: 1 Color Logs 50-103-20559-00,01,70 2" x 5" TVD TC Logs: 1 Color Logs 50-103-20559-00,01,70 Digital Log Images: 1 CD Rom 50-103-20559-00,01,70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchor~ag~, Alaska~~518 z -~~ ~, -- ;~.~ ; 1. , Date 1 Signed: 1 .s~ t~~3~ ~vg"c~ ~t /(~ ~-3 ~- 11~3~s • • 12-Apr-08 AOGCC Attn: Christine Mahnken 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well CD3-316A Dear Dear Sir/Madam: Enclosed are 2 survey hard copy(s) and a disk with the *.PTT and *.PDF files. Tie-on Survey: 10,226.76' MD Window /Kickoff Survey: 10,275.00' MD (if applicable). Projected Survey: 11,690.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TR~!-NSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 Date Signed Please call me at 273-3534 if you ha a any questions or concerns. Regards, Timothy Allen Survey Manager Attachment(s) z~~~ ~~ l ~- i 12-Apr-08 ~AOGCC .Attn: Christine Mahnken X33 W. 7th Ave. Suite 100 ~4nchorage, AK 99501 Re: Distribution of Survey Data for Well CD3-316A PB1 Oear Dear SirJMadam: inclosed are 2 survey hard copy(s~ and a disk with the *.PTT and *.PDF files. Tie-on Survey: 5,941.98' MD Window /Kickoff Survey: 6,017.00' MD (if applicable) Projected Survey: 11,407.00' MD PLEASE ACKNOWLEDGE RECEIIPT BY SENDING AN EMAIL TO Timothy.Allen@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services .Attn: Timothy Allen 6900 Arctic Blvd. Anchorage, AK 99518 , ~ ~ ~ ~ ~ „ ~ Date ~ ~'~~ Signed ~~~YW~ please call me at 273-3534 if you gave any questions or concerns. Regards, ~'imothy Allen Survey Manager .4#ttachment(s) ~o~-c~r~ 04/30/08 • ~~~~~~' Schlumberger-DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 Attn: Beth Well Job # Log Description N0.4682 Company: Field: Color Date BL Prints Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8367. Thank you. Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Alpine CD STATE OF ALASKA 4l~ ALASKA OIL AND GAS CONSERVATION COMMISSION E~EIVED APR 0 8 2008 ANNULAR DISPOSAL APPLICATION /~laska 0+1 & Gas Cons. Commissi0tl 20 AAC 25.080 Anchorage 1. Operator 3. Permit to Drill Name: 207-177, 2f}8-E~'11 ConocoPhillips Alaska 4. API Number: 'r 50-103-20559-00-101 2. Address: 5. Well ~' P.O. Box 100360, Anchorage, Alaska CD3-316A 6. Field: Colville River Field 7. Publicly recorded wells 8. Stratigraphic description: a) QII wells within one-quarter mile: a) Interval exposed to open annulus: ~~ ~ 110, CD3-303, CD3-113, CD3-302 CD3-107, CD 09, CD 3 Torok and Seabee formation, shale, siltstone and sandstone ~ ~ ~ 3~~°Oi'3 '~ ~M.~ `~ ~ C'~CLt~t,~~ ~ F'~ ~o.~ S~ b) Waste receiving zone: ` Q ~ ~'S `Y°vJ ~i b) water wells within one mile: (~t- Sand layers below the C30 marker in the Seabee formation None ~y c) Confinement: • The Schrader Bluff formation provides an upper barrier and marine shales and claystones of the Albian Torok Formation provide a lower barrier 9. Depth to base of permafrost: 10. Hydrocarbon zones above waste receiving zone: approximately 1650' MD / 1600' TVD None • 11. Previous volume disposed in annulus and date: 12. Estimated slurry density: 13. Maximum anticipated pressure at shoe: None densities range from diesel to 12#/gal 2318 14. Estimated volume to be disposed with this request: 15. Fluids to be disposed: 35,000 bbls. Types of waste may be drilling mud, drilling cuttings, reserve pit fluids, cement- completion fluids, diesel, formation fluids associated with the contaminated drilling mud 16. Estimated start date: , act of drilling a well, drill rig wash fluids, cement rinsate, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and other 15-Apr-o8 substances that the commissioner determines on application are wastes associated with the act of drillin a well permited under 20 AAC 25.005. 17. Attachments: Well Schematic (Include MD and TVD) 0 Cement Bond Log (if required) ^ FIT Records w/LOT Graph Q Surf. Casing Cementing Data^ Other^ previous authorization for new product cleanup fluids for CD1 and CD2 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signature: /~~ ~ ~ l ~, ~+ Title: ~7y'lila_~X14 I Pc~.- ~a~ ~~ Printed Phone Name: Chip Alvord Number: 265-6120 417!2008 Commission Use Only Conditions of approval: ~~~'~Ot~S~n4C~0~~ f ~©`~~~~~ +o~~ LOT review and approval ~~ ~ L( ~ i b t f d S ,d~~~~ roval number JO !~~ A :J orm requ re u sequen : . _ pp ~ A roved b : APPROVED BY COMMISSIONER THE COMMISSION Date:'-(~ 6 pp y Form 10-403RD Rev. 6/200 I STRUCTIONS ON REVERSE ub . i1; in licat ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 ConocoPhillips RECEIVE Apri17, 2008 Alaska Oil and Gas Conservation Commission 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501-3539 APR 0 8 2008 Alaska Ctil & Gas Cons. Commission Anchorage Re: Application for Sundry Approval for Annular Disposal of Drilling Waste on well CD3-316A Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby requests that CD3-316A 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 CD3-316A approximately April 17, 2008. We currently have volume available in the permitted annulus on CD3-302, but the limit may be reached before ending the CD3 drilling season. Please find attached form 10-403RD and other pertinent information as follows: 1. Annular Disposal Transmittal Form 2. Pressure Calculations for Annular Disposal 3. Summary of wells on Pad 4. Plan View of Adjacent Wells 5. Surface Casing Description 6. Surface Casing Cementing Report & Daily Drilling Report during cement job 7. Casing and Formation Test Integrity Report (LOT at surface casing shoe). 8. Intermediate Casing Description 9. Intermediate Casing Cementing Report & Daily Drilling Report during cement job 10. Formation LOT on 9-5/8" x 7" casing annulus 11. List of wells on CD3 pad and the lateral distance from the surface casing shoe. 12. Information regarding wells within 1/4 mile radius at AOGCC: CD3-109, CD3-110, CD3-107, CD3-302, CD3- 113 13. Information regarding remaining wells within'/4 mile radius included in sundry package: CD3-303: Currently we are drilling the intermediate section. The complete information for CD3-303 will be submitted with the next application for annular disposal. 14. Copy of previous authorization (CD1 and CD2) for disposal of new prod uct cleanup fluids such as cement rinsate, and mud and brine pit rinse from mixing operations The initial annular LOT (15.9 ppg) occurred at a lower equivalent mud weight than the casing shoe test (18.0 ppg LOT). Therefore we conclude that waste will not migrate above the confining zone provided we do not inject with sustained surface pressures that will cause pressures at the surface shoe to be in excess of the shoe FIT/LOT. To complete the well information to date for CD3, I have also included CD3-118 and CD3-114. If you have any questions or require further information, please contact Liz Galiunas at 265-6247; Chip Alvord can also be reached by calling 265-6120. Sincerel , Liz Galiunas Drilling Engineer .i • ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 cc: CD3-316A Well File Chip Alvord Anadarko Sharon Allsup-Drake ATO-1577 ATO-1530 ConocoPhillips Annulus Disposal Transmittal Form -Well CD3-316A AnCTCC Reeulations. 20 AAC 25.OR0 (hl 1 Desi ation of the well or wells to receive drillin wastes: CD3-316A 2 The depth to the base of freshwater aquifers and permafrost, i There are no USDW aquifers in the Colville River Unit. resent. Estimated base of Permafrost = 1600' TVD RKB ` 3 A stratigraphic description of the interval exposed to the open The Schrader Bluff formation provides an upper barrier and annulus and other information sufficient to support a marine shales and claystones of the Albian Torok Formation commission fording that the waste will be confined and will provide a lower barrier. Calculated water salinities of the not come to the surface or contaminate freshwater. Cretaceous and older stratigraphic sections range from 15000 to 18000 mg/1. (Ref. AOGCC Conservation Order No. 443, 4 A list of all publicly recorded wells within one-quarter mile See attached map indicating wells within t/4 mile. There are and all publicly recorded water wells within one mile of the no water wells within 1 mile. well to receive drillin waste. 5 Identify the types and maximum volume of waste to be Types of waste may be drilling mud, drilling cuttings, reserve disposed of and the estimated density of the waste slurry. pit fluids, cement-contaminated drilling mud, completion fluids, diesel, formation fluids associated with. the act of drilling a well, drill rig wash fluids, domestic waste water, any added water needed to facilitate pumping of drilling mud or drilling cuttings, and any other fluids associated with drilling a well. Densities range from diesel to 12#/gal. Maximum volume to be pumped is 35,000 bbls. 6 A description of any waste sought to be determined as drilling Cement rinsate, mud plant rinse fluid generated by rinsing waste under (h)(3) of this section. tanks and equipment after producing drilling/completion fluid (see included note from CD 1 &2 authorization). 7 An estimate of maximum anticipated pressure at the outer Maximum anticipated pressure at the outer casing shoe during casing shoe during annular disposal operations and disposal operations is 2318 psi. See attached calculation calculations showin how this value was determined. a e. 8 Details that show the shoe of the outer casing is set below the See attached: cementing reports, LOT /FIT reports and base of any freshwater aquifer and permafrost, if present, and casing reports. cemented with sufficient cement to provide zone isolation: 9 Details that show the inner and outer casing strings have See attached casing summary sheet and calculation. pages. sufficient strength in collapse and burst to withstand antici ated ressure of dis osal o erations: 10 The downhole pressure obtained during a formation integrity See attached LOT/FIT report. test conducted below the outer casin shoe. 11 Identification of the hydrocarbon zones, if any above the N/A de th to which the inner casin is cemented. 12 The duration of the disposal operation, not to exceed 90 days. N!A 13 Whether drilling waste has previously been disposed of in the N/A annular space of the well and, if so, a summary of the dates of the disposal operations, the volumes of waste disposed of, and the wells where the drilling waste was generated. 14 The well(s) where the drilling waste to be disposed of was or CD3-303, CD3-107L1, CD3-115, CD3-117, CD3-305, will be enerated. CD3-306 15 If the operator proposes not to comply with a limitation N/A established in (d) of this section, an explanation of why coin liance would be im rudent. 16 Any additional data required by the commission to confirm N/A containment of drillin waste. Version LO - Jan'OS 4,888 = ( 2,476 * 0.052 * MWm~ ) + 1500 - (0.4337 * 2,476 ) ~burst85% - PHydrostatic +PApplied - PForma[ion MWmax = 34.7 PPg Surface Casing Strin Size 9.625 in Weight 40 ppf Grade L 80 rburst100% 5,750 pst Pburstss% 4,888 psi Depth of Shoe 2,476 ft FIT/LOT @ Shoe 18 ppg or 2,318 psi FIT/LOT for Annulus 15.9 ppg Max Surf. Pressure 1,500 psi YIaximum Fluid Density avoid Collapse of 2nd Casing String Pcollapse85% - PHydrostatic +PApplied - PGasGradient - PHeader 4,599 = ( 6,461 * 0.052 * M Wm~ ) + 1,500 - (0.0700 * 6,461) - 1,000 MWmax = 13.5 PPg 2nd Casing Strin Size 7 in Weight 26 ppf Grade L 80 rcollapse100% 5,410 psi Pcollapse85% 4,599 psi Top of Cement 6,461 ft Gas Gradient 0.07 psi/ft Max Surf. Pressure 1,500 psi Header Press 1,000 psi Maximum Anticipated Pressure at Surface Casing Shoe Pmax allowable =Shoe TVD Depth * .052 * Shoe FIT/LOT Pmax allowable = ( 2,476 * .052 * 18 ) Pmax allowabte - 2,318 psi This is the value for the Injection Permit "Maximum Anticipated Pressure at Shoe". Pressure Calculations for Annular Disposal (for submital with Annulaz Disposal Application) Assumptions Maximum injection pressure of 1,500 psi Maximum density of the injection fluid is 12.0 ppg Pore pressure at the 9 5/8" casing shoe is 0.434 psi/ft Gas/Fluid Gradient in tubing/casing annulus 0.07 psi/ft Header Pressure (for wells on gas lift) 1,000 psi Maximum Fluid Density to avoid Burst of Surface Casing Well CD3-316A Date 4/7/2008 SURFACE CASING SHOE SEPARATION FROM CD3-316 CD3-316 x Y Surface Casino Shoe ASP 4 Coordinates NAD 27: 388868.2 6Sn~3548.0 ells Details ~ AOGCC Ann. Disp. Permit # ermit Date Source well Ann. Vol. ** tart Date nd Date rs ante from Object well* Surtace csg. Shoe X Coord. Surtace csg. Shoe Y Coord. Surt LOT (ppg) Surface casing TVD (ft) Annular LOT (ppg) omments CD3 168 y I I5C2 °~~4~+3QD 3 0004986.4 17.1 2431 E'~ 9 nal fcr annr,lar dis~nsal CD3-109 y 306-020 1/20/2006 CD3-110, CD3-111, CD3-112, CD3-307, CD3-302 6463 5 1/20/2006 3/4/2007 -1233 388917.3 6004780.2 18.0 2414 16.0 Extended to 70000bb1, ex 03/17/07 CD3-1!0 y . _ 1212 388563.7 6004720.7 10.7 24',9 1 Iov; s,~fii-e shoe lesl -- CD3-111 v s07-Obti 2r21rZU07 CD3-114, GD3-301 [0674 3/20/2007 4~[ [Ori% ! 1565 387821.0 6004710.6 17 4 2aFa 1a a CD3 U2 ~ 307902 v1v2(i07 CD3-113 CD3-107/c.D35c~ 1200 1/22/2007 1x'2007 1683 387A08.8 6004382.6 180 2485 1r 1 CD3 ~,,_ - i - 4~z ~ ~ u~ ~ vs,~! ~ 3 a~t ~ ~. I 1 ~ f ,wl 1 ~ ti ns ~ ~l CD3-302 v 30P-U3r u~;hIC;. CD3-113, CD3-118, 1,C3 3n3 1349E 2'12%2'3Ci8 ~ 3 ",801 , 4 nC1.441,p 9 1E.1 2596 5.0 CD3-I13 ?-[ig, „20'20G? LS-31n L' i13A ;t19n4 1:14: r I~"~ - 1'~- ;a?S ~6.3 ;:'J3-114 incluie.f _ l 1GG8~ 687024] 61.0 7D1 8 1x,_4 2485 --- '4,2 Low c~lrface shoe tint t,Ga ~~0 i v I ~ -541 rJ 5 16.2 X493 15 1 E ~~,r1 , ~ shy,, tc ;~ '~1GA included 30P8G 2 ~;C1 ",a3.0 19.0 2x76 16.9 (:17? ~V3 inel I .eri - 1274 390051 ~ - 1 '. ~4B8 G1.c~~~l tl, t ~n~.l dnllr~; ~'~-1lii. nL:lli~E'.l1 ~ 2415 ~~, R,Y~iri ~-i 13-';25.J IIj.E L4p~I ~~F? I~U1~Sl f1'li,(: tillli(: lE'tit --~ - t ' Lateral distance in feet, between surface casing shoes; in the X-Y plane '* As of April 4, 2008 Note that this sheet is not the definitive record for annular disposal volumes `~ Calculatlon McNOd: Minimum CUrvaNre r,.- E^°r5,~tem: ISCWSA Project: Western North Slope ConoeoPhillips ScanMeNOtl Trav.CPlnderNOM site Error Surtxe: Elli tical COnlc CD3 Fiord Pad CD3-316A Warning Me[hotl: Rules Bash Geotletic DaOrm: North Amerlwn Datum 1983 Well: CD3-316 Magnetlc Motld: BGGM]OBI Wellbore: CD3-316A Quarter M i I e View Grountl Level: 13.20 axe. co3-31e~Oas.~n~uoy°n1s~ CD3-316A NorihinylASP Y: 6003554.04 Fasting/ASF' X: 1528103.39 q~q ~ ' q " 9 __ N v'O~ G qe ti. p~ GO3. Ca A O d Bj n ~~ ~ ? 2200 wo ~ -0 ~j qrL p~^ G 9 5/8" x 121 4" 1~ 1650 c 0 l 5/8" x 12 1/4 " ~ ~~ qo ^ - ~ 1100 - - _ - - " • 5/ 121/4 ~ 9 5/8" x 121/4"% 9 5/8" x 1 /4" ~ ~ / P \ O ~ ~ Z 518" x 12 1/4" 3 30 ~ ~~ 9 5 /8" x 12114" ~ Cp 550 ~ - va - ---- ' x 121/4" ' /~ k -.. J .. ,.,.._.- ,.. ~ M M r V J .~.~.. .,.:~..~n.,,,,,,. o,~,„ " ~ °` ° ~ • ., 9-5/8' x - 9-5/8 ~ ....a " x 12-1/4" TD 9 5/8" x 12 1/4" -:.-~. 0 _ ~ tT 12-1/4" x 9-5/8" ~~ qq~ ~9- 12-1/4" ~ ~Q~ ~ roQ' co ~~ "' -550 o W 0 w U -2200 -1650 -1100 -550 0 550 1100 1650 2200 West(-)/East(+) (550 ft/in) ConocoPh i l l i s p Casing Detail 9 5/8"Surface Casin_g Well: CD3-316 Date: 1 /18/2008 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB to Landing Ring 36.30 FMC Gen V Hanger 1.89 36.30 Jts 3 to 70 68 Jts 9-5/8" 40# L-80 BTC Csg 2625.95 38.19 Halliburton Float Collar 1.49 2664.14 Jts 1 to 2 2 Jts 9-5/8" 40# L-80 BTC Csg 76.89 2665.63 Ray Oil Tools "Silver Bullet" Float Shoe 2.25 2742.52 9 5/8" Shoe @ 2744.77 TD 12 1/4" Surface Hole 2755.00 12 1/4" hole 2755' MD 2483' TVD 9 5/8" csg shoe 2745' MD - 2476' TVD TOTAL BOWSPRING CENTRALIZERS - 41 1 per jt on Jt #1 - #14 (stop ring on Jt #1 & 3 ) and over collars on jts# 16,18,20 ,22,24,26,28,30, 32, 34, 36, 38, 40, 42, 44, 46, 48, 50, 52, 54, 56, 58, 60, 62, 64, 66 68 74 joints in the pipe shed.70 jts to run -Last 4 jts out Use Best-o-Life 2000 pipe dope All joints drifted - 8.781" MU torque ~ 9000 ft/Ibs Remarks: Up Wt - 180 k Dn Wt -140 k Block Wt - 75k Supervisor: D. Burley/L. Hill ~~ Cement Detail Report CD3-316 . ,. Surface Casing Cement iCement Details _ ____ _ ~ Description _ Cementing Start Date Cementing End Date Wellbore Name Surface Casing Cement 1/18/2008 05:03 1/18/2008 06:30 CD3-316 Comment Cement Stages _ ___-- _ _- _ _ - - - ' 'Stage # 1 - ---' -- - -- - - -_ _ __- Description Objective Top (ftKB) ~ - ---- Bottom (ftKB) Full Return? Cmnt Rtrn (... Top Plug? Btm Plug? Surface Casing Cement 36.0 2,744.0 Yes 85.0 Yes Yes O (start) (bbllmin) Q (end) (bbl/min) O (avg) (bbl/min) P (final) (psi) P (bump) (psi) Recip? Stroke (ft) Rotated? Pipe RPM (rpm) 6 4 6 460.0 1,000.0 Yes 20.00 No Depth tagged (ftKB) Tag Method Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) Comment 30 bbls Biazon water w/ nut plug marker 5 bbls water -test lines 4000 psi drop bottom plug 50 bbls 10.5 ppg Mud Push @ 5 bpm /151 psi Lead: 318 bbls - 10.7 ppg G cement Tail: 50 bbls 15.8 ppg G Displaced with 182 bbls 9.9 ppg mud at 8.0 bpm. Cement Fluids 8 Additives _ _ __ _ Fluid Fluid Type Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Amount (sacks) ' Class Volume Pumped (bbl) Lead Cement 36.0 2,244.0 383 G 316.0 Yield (fP/sack) Mix H2O Ratio (gal/sa... Free Water (%) Density (Iblgal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 4.63 20.72 10.70 Additives Additive Type Concentration Conc Unit label Fluid ___ _ _ ___ _ ___ - _ __ Fluid Type Fluid Description Estimated Top (ftKB) _ _ _ _ _ Est Btm (ftKB) Amount (sacks) Volume Pumped (bbl) Class Tail Cement 2,244.0 2,744.0 .234 G 49.0: Yield (ft'/sack) Mix H2O Ratio (gallsa... Free Water (%) Density (Iblgal) Plastic Viscosity (cp) Thickening Time (hrs) CmprStr 1 (psi) 1.17 5.10 15.80 Additives Additive Type Concentration Conc Unit label Page 1/1 Report Printed: 4/4/2008 S Security Level: Development ~ Daily Drilling Report ,.~ -. -~; ;~4" CD3-316 Report Number: 8 . . • ., Rig: DOYON 19 Report Date: 1/18/2008 `AFE Type Network/ID # Total AFE+Sup 10206127 9,745,000.00 Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) CD3-316 Development NANUQ KUPARUK 3.06 8.0 0.00 2,755.0 2,755.0 Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 3,067.20 51,800.63 427,190.20 1,513,855.63 Actual Start Date Original Spud Date AFE Dur Total (days) Projected Job Duration (days) Job Days Ahead (days) Projected Job End Date 1 /11 /2008 1 /15/2008 26.51 Last Casing String Next Casing OD (in) Next Casing Set Depth (ftKB) Surface, 2,744.8ftK6 7 9,183.00 Ops and Depth @ Morning Report 24hr Forecast Picking up 4" DP. PU BHA and RIH. Cut DL. Drill shoetrack + 20'. FIT. Change Mud system and drill. Last 24hr Summary Ran 9 5/8" casing to 2,744'. Circu lated. Cemented casing with 85 Bbls return to surface. Tested casing 3,500 psi for 30 min. OK. Nippled down riser. Nippled up BOP. Picked up test plug and tested Hydril 250/2500 psi. Tested rams, Kill and Choke valves, and floor valves 250/3500 psi. Tested recovery time on closing unit. Test witinessed by Chuck Scheve AOGCC. Set wear ring and picked up 4" DP standin back in derrick. General Remarks Weather Head Count Clear 47.0 Supervisor Title Dave Burley, Rig Supervisor Rig Supervisor Larry Hill, Rig Supervisor Rig Supervisor Time Lo Start End Dur Time Depth Start Dept End Time Time (hrs) Phase Op Code OpSub-Code P-N-T Trbl Code Trbl Class. (ftKB) (ftKB) Operation 00:00 01:00 1.00 SURFAC CASING RNCS P .585.0 1,555.0 Run 9 5/8" 40# L-80 BTCM casing from 585'to 1,555'. PUW 145 SOW 120 01:00 01:30 0.50 SURFAC CASING CIRC P 1,555.0 1,555.0 Stage pumps up to 5 bpm - CBU - FCP=210 psi 01: 3:00 1.50 SURFAC CASING RNCS P 1,555.0 2,745.0 Run 9 5/8" 40# L-80 BTCM casing from 1,555'to 2,708'to 1,555'. MU FMC fluted mandrel hanger and LJ -land casing with shoe @ 2744.77', FC @ 2664.14' PUW 180 SOW 133 03:00 03:30 0.50 SURFAC CEMENT RURD P 2,745.0 2,745.0 Lay down fill up tool - MU Cement head and lines 03:30 04:45 1.25 SURFAC CEMENT CIRC P 2,745.0 2,745.0 Stage pumps up to 7 bpm -circulate and condition mud for cementing -FCP=260 psi PUW '176 SOW 150 -Held pre-job Safety and Opts meeting with Dowell and crew Latest BOP Test Data Date Comment 1/18/2008 Picked u test lu and tested H dril 250/2500 si. Tested rams Kill and Choke valves and floor valves 250/3500 si. Tested Page 113 Report Printed: 1/21/2008'. r Security Level: Development -~ ~ ~ Daily Drilling Report Y, - •~'~ ~ u1 I :'- ~~; CD3-316 Report Number: 8 ..° Report Date: 1/18/2008 Rig: DOYON 19 Time Lo Stag End Dur ~- Time Depth Start Depth End Time Time (hrs) Phase Op Code MENT OpSub-Code DISP P-N-T P Trbl Code Trbl Class. (ftKB) 745 0 2 (ftKB) 745.0 2 Operation Cement 9 5/8" csg as follows: Pumped 04:45 06:45 2.00 SURFAC CE , . , 30 bbis Biazon water w/ nut plug for marker -switched to Dowell -Pumped 5 bbls water -Test lines to 4000 psi - Dropped btm plug -Mixed & pumped 50 bbis of 10.5 ppg MudPush @ 5 bpm / 151 psi -Mixed 8~ pumped 10.7 ppg Lead slurry (AS 3 Lite) @ 7.5 bpm / 225 psi - Observed nut plug marker @ Shakers ~ 300 bbis pumped -Pumped down surge can (318 bbis total) -Switched over to tail slurry Pumped 50 bbls 15.8 ppg Class G w/ additives) @ 5.5 bpm @ 180 psi -Dropped top plug wd 20 bbis water f/ Dowell -Switched to rig pumps & displaced w/182 bbis - 9.9 ppg mud @ 8.0 bpm / 350 - 560 psi for first 175 bbls - slowed pump to 4.0 bpm for last 7 bbis / 460 psi -Bumped plug w/ 1000 psi - Checked floats OK - CIP @ 0630 hrs.- Reciprocated pipe untifl cast 81 bbis of mud displaced - Fug circulation throughout jt~ wd 85 10.7 ppg cmt returns to surface 06:45 07:30 0.75 SURFAC CASING DHEQ P 2,745.0 2,745.0 RU and test 9 5/8" casing to 3500 psi for 30 minutes -blow down & RD lines ,8:30 07:b 1 00 SURFAC CASING RURD P 2,745.0 0.0 RD cement head, elevators, LD landing . . . joint, casing bales and mousehole 08:30 10:30 2.00 SURFAC CASING NUND P 0.0 0.0 ND flowline and riser and speedhead - ~ NU FMC Unihead -test M/M seals to 1000 psi for 10 minutes 10:30 14:00 3.50 SURFAC WELCTL NUND P 0.0 0.0 NU Bop stack, riser and flowline 14:00 19:45 75 5 SURFAC WELCTL BOPE P 0.0 0.0 Picked up test plug and tested Hydril . 250/2500 psi. Tested rams, Kill and Choke valves, and floor valves 250/3500 psi. Tested recovery time on closing unit. Test witinessed by Chuck Scheve AOGCC. 19:45 20:45 1.00 SURFAC DRILL RURD P 0.0 0.0 Laid down Test plug. Set wear bushing. Rigged up to PU 4" DP. 20:45 00:00 3.25 SURFAC DRILL PULD P 0.0 0.0 Picked up 81 jts 4" drill pipe from pipeshed and stood back in derrick Mud Check Data - ' YP Calc Gel (f Os) Gel (10m) Gel (30m) HTHP Filt Density Temp Solids, Corr. Type Depth (ftKB) Dens (Ib/gal) Vis (s/qt) PV Calc (cp) (Ibf/700f1=) (Ibfl100fY) (Ibf/100ft') (Ibf/100ft) MBT (Ib/bbl) , (mU30min) pH (°F) (%) 9 3 9 5 . . Spud Mud 2,755.0 9.70 43 9.0 10.000 6.0 8.0 11.000 10.5 in'ection Fluid Fluid Source From Lease (bbl) - Destination > Note . Diesel 38.0 CD3-316 to CD3-113 Other 527.0 Same Water 190.0 Same Water Based Mud 1473.0 Same Drill Strn s: BHA No. 1 -Surface / Bit Run No. 1 - 12 1/4in, Hu hes Christensen , MX-1 , 5125718 Depth In (ftKB) Depth Out (ftKB) TFA (incl Noz) (ink Nozzles (132") IADC Bit Dull String V11t {10001bf) 114.0 2,755.0 0.75 16/18/12/16 2-5-WT-G-E-2-NO-TD 44 Page 2/3 Report Printed: 1/21/2008 r Security Level: Development ~ 7 -` Daily Drilling Report {~; Y:~ ;:~;. ~ ~~~''~~~~~ CD3-316 ` , Report Number: 8 ~ 4 ~ Rig: DOYON 19 Report Date: 1/18/2008 Drill Strin Com onents Jts Item Description OD (in) ID (in) Top ConnSz (in) ~ Top Thread Cum Len (ft) ; Motor with Stabilizer 8 4.947 6 5/8 H 90 30.62 Float Sub 7 7/8 3.000 6 5/8 H 90 33.02 Stabilizer 8 2.875 6 5/8 H 90 39.75 XO Sub 8 3.250 6 5/8 Reg 42.17 MWD (DM) 7.99 3.000 6 5/8 Reg 51.24 MWD (HCIM) 7.98 1.920 6 5/8 Reg 59.84 MWD (TM) 8.02 3.250 6 5/8 H 90 69.44 UBHO 8 3.500 6 5/8 H 90 71.79 NMDC 7 1/2 2.813 6 5/8 H 90 102.77 NMDC 7 3/4 2.813 6 5/8 H 90 133.51 Drilling Jars -Mechanical 7 3/4 2.750 4 1/2 IF 168.83 24 HWDP 5 3.000 4 1/2 IF 894.33 Wellbores - Wellbore; Name Wellbore APIIUWI _ CD3-316 501032055900 :Section. Size {in) Ad Top (ftKB) Act Btm (ftKB) Start Date End pate INTRM1 8 3/4 PROD 1 6 1 /8 COND1 36 36.0 114.0 1/2/2008 1/3/2008 SURFAC 12 1 /4 49.5 114.0 1 /16/2008 Cement Surface Casin Cement -Started 1/18!2008 Type Wellbore Cemented String Cement Evaluation Results casing CD3-316 Surface, 2,744.8ftK6 Stg No. Description Top (ftKB) Bottom (ftKB) Q (end) (bbl/... P (£nal) (psi) 1 Surface Casing Cement 36.0 2,744.0 4 460.0 Fluid Class Amount (sacks) V {bbq Density (Ib/gal) ` Yield (ft'lsadc) , Est T op (ftKB) Est Btni (ftKB) Lee Went G 383 316.0 10.70 4.63 36.0 2,244.0 Tail t,~ment G 234 49.0 15.80 1.17 2,244.0 2,744.0 Pressure Test Data Item Tested Date Pres (psi) Failed? Comment Hydril ANB/BNB, 1/18/2008 1/18/2008 0.1 No Picked up test plug and tested 14:00, <CI?> Hydril 250/2500 psi. Tested rams, Kill and Choke valves, and floor valves 250/3500 psi. Tested recovery time on closing unit. Test witinessed by Chuck Scheve AOGCC. Page 3/3 Report Printed: 1/21/2008 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD3-316 Rig: Doyon 19 Date: 1/18/2008 Volume Input Volume/Stroke Pum Rate: Drilling Supervisor: D. Burley / L. Hill Pump used: #2 Mud Pump ~ Strokes • 0.1000 Bbls/Strk • 7.0' strk/min Type of Test: casing shoe Test LOT/Frr • Pumping down annulus and DP. ~ Casin Test Pressure In te rit Test Hole Size: 8-3/4" ~ Casin Shoe De th Hole De th Pum in Shu t-in Pum in Shut-in RKB-CHF: 36.3 Ft 2,745 Ft-MD 2,476 Ft-TVD 2,775 Ft-MD 2,490 Ft-TVD Strks si Min si Strks si Min si Casina Size and De scription: 9-s/s" 40#/Ft L-80 BTC ~ 0 0 0 3570 0 0 0 1100 Casin Test Pressure Int e rit Tes t 2 120 1 3570 2 50 0.25 1070 Mud Weight: 9.9 ppg Mud Weight: 9.5 ppg 4 300 2 3570 4 110 0.5 1020 Mud 10 min Gel: 42.0 Lb/100 Ft2 Mud 10 min Gel: 23.0 Lb/100 Ft2 6 520 3 3560 6 300 1 990 Test Pressure: 3,500 psi Rotating Weight: 125 Lbs 8 800 4 3560 8 470 1.5 92 Rotating Weight: 74,000 Lbs Blocks/Top Drive Weight: 70 Lbs 10 1010 5 3560 10 650 2 90 Blocks/Top Drive Weight: 74,000 Lbs Desired PIT EMW: 18.0 ppg 12 1210 6 3560 12 830 2.5 880 Estimates for Test: 2.7 bbls Estimates for Test: 1094 si 0.9 bbls 14 1430 7 3560 14 970 3 870 ~ ~ 16 1660 8 3560 16 1100 3.5 850 EMW =Leak-off Pressure + Mud Weight = 1100 PIT 15 Second 18 1910 9 3560 4 835 + 9.5 0.052 x TVD 0.052 x 2476 but-in Pressure, si 20 2150 10 3550 4.5 825 EMW at 2745 Ft-MD (2476 Ft-TVD) = 18.0 1070 22 2410 15 3540 5 815 Lost si durin 40 test held 24 2650 20 3530 5 5 810 aooo p g , . 98 9 f t t % re 1 2 3530 6 800 . pre o es ssu . 26 29 0 5 " • ~•• •••••-_-• 28 3190 30 3530 6.5 800 3500 30 3440 7 795 31 3570 7.5 790 3000 8 790 8 5 785 . w z5oo ~ 9 785 ~ 5 9 78 . w zooo 10 78 a 1500 1000 500 0 4 5 2 0 2 5 30 0 1 ~~ Barrel 2 s -f-LEAK O 3 FF TEST 0 5 S 10 1 hut-In tim O PIT Poi e, M nt inute s Vol PUm ume ed Volume Bled Back Volume Pum ed Volume Bled Back CASING T EST - s s s s Comments: Tested casing after bumping plugs on cement job ConacoP'~tli s Casing Detail 7" Casing Well: CD3-316 Date: 2/3/2008 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Doyon 19 RKB 34.05 FMC Gen V Hanger 1.60 34.05 Jts 3 to 275 273 Jts 7" 26# L-80 BTCM Csg 11556.82 35.65 Halliburton Float Collar .97 11592.47 Jts 1 to 2 2 Jts 7" 26# L-80 BTCM Csg 84.13 11593.44 Ray Oil Tools "Silver Sullet" Float Shoe 2.09 11677.57 7"Shoe @ 11679.66 TD 8 3/4" Hole 11690.00 8-3/4" Hole 11,690' MD / 6726 'TVD 7" Shoe @ 11,679.66 ' MD / 6726' TVD Total Centralizers: 47 Straight blade centralizer one per jt on jts # 1-14 Straight blade centralizer one per jt on jts. # 210,211,212 Straight blade centralizer one per jt on every other joint Starting @ # 214 to 272 Top Kuparulc -' MD 'TVD 285 joints in shed - 275 total jts. to run Last 10 jts. out Use Run & Seal i e do e Remarks: tJp Wt - 375 k Dn Wt -150 k Block Wt - 75k Supervisor: D. Lutrick/D: Mickey - _ __ _ - Cement Detail Report CD3-316 Intermediate Casing Cement ':,Cement Details '' _`~ ',Description Cementing Stari Date Cementing End Date Wellbore Name Intermediate Casing Cement 2/4/2008 01:00 2/4/2008 02:00 CD3-316APB1 -- -_ Comment Cemented 7" casing as follows: Pump 5 bbls CW-100 -Test lines to 3700 psi -Pump 35 bbls CW-100 @ 3.2 bbls/min @ 350 psi -Pump 40 bbls MudPush @ 12.5 ppg @ 4.2 bbls/min @ 450 psi -Dropped btm plug -Mix & pump 48 bbls (226 sks) 15.8 ppg tail slurry (Class G w/ .2% D046, .25% D065, .25% D800,.18% D167) @ 4.6 bbls/min @ 285 psi -Drop top plug w/ 20 bbls water f/ Dowell -Switched over to rig pumps & displaced w/ 422 bbls 9.8 mud @ 6 I bbls/min @ 460 psi ~ slowed pumps to 3.5 bbls/min @ 440 for the last 32 bbls -Bumped plug w/ 1000 psi - CIP @ 0325 hrs. -Checked floats OK -Full (returns through job -Reciprocated pipe until PU wt. was beginning to be excessive (40 bbls into displacement) I! ~. - ___ _ - - _ -- - 1 I Cement Stages __ _ _.._ _ _ - Siage # <Stage Number?> Description Objective Top (ftKB) Boitom (ftKB) Full Return? lCmnt Rtrn (... (Top Plug? Btrn Plug? Intermediate Casing 10,550.0 1,168.0 Yes Yes Yes Cement I Q (start bbllmin Q end bbl/min Q av bbUmin P final si :~P bum sr Reci 'Stroke (ft) (Rotated?Pipe RPM (rpm) (6 ) ( ) (4 ) ( g) (6 ) ( 440.0 ( 1P000.0 - Yes - No I' __ -- -- - - - !Depth tagged (ftKB) Tag Method 'Depth Plug Drilled Out To (ftKB) Drill Out Diameter (in) I Comment - - C_ement Fluids ~ Addftives Fluid 'Fluid Type .Fluid Description Estimated Top (ftKB) Est Btm (ftKB) Tail Cement ' i 10,550.0 ~i 11,680.0 , Yield ft'/ allsa... Free Water / iMix H2O ~Densrty(Ib/gal) 1 16 5 10 - --- 15.80 __-_ Addltlves - ,Additive 'Type 'Fluid Loss Control ' D167 Additive 'Type -- - Retarder D800 Additive Type Antifoam D046 --- Additive - - -_ Type Dispersant D065 -- _ _ - - Amount (sacks) Class Volume Pumped (bbl) 226 G 48.0 Plastic Viscosity (cp) ',Thickening Time (hrs) mprStr 1 (psi) I __ ! - - - _ _ --- ~ I - -- - 'Concentration iiConc Unit label %BWOW -- -- Concentration Conc Unit label %BWOW - --- ,Concentration Conc Unit label %BWOW - -_ - Concentration iConc Unit label %BWOW - - -- - J - Page 1/1 - - Report Printed: 2/5/2008' - _ - Security Level: Development Daily Drilling Report CD3-316 Report Number: 25' tig: DOYON 19 Report Date: 2/4/2008 ':, AFE Type - NetworWlD # _ _ Total AFE+Sup _ _ _ _ ii 10206127 _ - _ _ - - ---- _ _ _ _ - 9,745,000.00' ', Wellbore Well Type Field Name DFS (days) DOL Depth Progress (ft) Depth Start (ftKB) Depth End (ftKB) 'CD3-316APB1 Development FIORD KUPARUK 20.06 25.0 0.00 11,690.0 11,690.0 i Daily Mud Cost Cumulative Mud Cost Daily Cost Total Cumulative Cost 2,808.84 598,918.93 796,772.84 6,209,784.93 cted Job Duration (days) Job Days Ahead (days) Projected Job End Date Actual S1 /11/2008 - Original SP5/2008 AFE Dur 26t51days) 'Proje - - _ -- - --- - .Last Casing String I Next Casing OD (in) Next Casing Set Depth (ftKB) Intermediate, 11,680.OftKB Ops and Depth @ Morning Report 24hr Forecast .Change over to FloPro Drill 6 1/8" horizontal section .Last 24hr Summary I Circ & condition mud for cmtjob -PJSM - Cmt 7" csg w/ 226 sxs Class G @ 15.8 ppg -Displace cmt w/ 20 bbls water i~ 422 bbls 9.8 ppg mud -Bump plug 8 '.check floats OK -Test csg to 3500 psi for 30 mins. - RD f/ cmtjob -Set pack-off & test to 5000 psi -Change rams & test - MU BHA & RIH to 11,409' - S&C drill ',line -Wash down f/ 11,409' to 11,430' -- - _ _- - _ _r- 'General Remarks (Weather 'Head Count Supernsor Donnie Lutrir F., Rig Supervisor Don Micl.ey. Rig Supervisor Randy De>:I~r. Rig Supen~isor Time Lod ~tdrt End Cur Tick I. Time i Time ~. (hrs) Phase ~ --.-__. r N-T° ,- L_- - _.-_---1.---Op Code OpSutrCode i, i 00:00'01:00 !I 1.00 INTRM2 '.CEMENT CIRC P i i --- - -- - - ---- _ -- _ _ ' 01:00!01:15 0.251NTRM2 CEMENT SFTY P '01:1503:30 2.251NTRM2 CEMENT DISP P 03:304:15 0.75 INTRM2 '04:15 05:00 0.75 INTRM2 ~~~05:00 06:00 1.00',INTRM2 ' ~ 06:00 ,07:301 - 1.50 INTRM2 07:30 {! 08:30 1.00 INTRM2 -- _ - (Rig Supervisor Rig Supervisor Rig Supervisor I ,_ D! ~ t1 ~c,~t Depth End Trail Code Trbl Class_ ~ Ittrcr~f ~ `{ftKB) ~- OpereUOn - ' _ - _ ' 11,680.0 11,680 OlContinue circulate and conditon mud at 5 ~ it bpm at 480 psi. Reciprocate pipe. Up ', wt= 330k Dn wt=150k. -- -- - - ' 11,680.0. 11,680.0 PJSM on cementing 7" csg. 11,680.0' 11,680.0 Cemented 7" casing as follows: Pump 5 ~~ bbls CW-100 -Test lines to 3700 psi - ! Pump 35 bbls CW-100 @ 3.2 bbls/min 350 psi -Pump 40 bbls MudPush ' 12.5 ppg @ 4.2 bbls/min @ 450 psi - ' ~~ Dropped btm plug -Mix & pump 48 bbls ~, ' (226 sks) 15.8 ppg tail slurry (Class G w/ .2% D046, .25% D065, .25% ', D80Q.18% D167) @ 4.6 bbls/min @ 285. I psi -Drop top plug w/ 20 bbls water f/ Dowell -Switched over to rig pumps & ~i displaced w/ 422 bbls 9.8 mud @ 6 ', ' bbls/min @ 460 psi & slowed pumps to 3.5 bbls/min @ 440 for the last 32 bbls - ' i ~~ Bumped plug w/ 1000 psi - CIP @ 0325 hrs. -Checked floats OK -Full returns ', through job -Reciprocated pipe until PU i wt. was beginning to be excessive (40 i ', bbls into displacement) I-13/-35 we / SW@ 15 mph / Vis.10 miles 51.0 Title ' CASING DHEO P CASING RURD P CASING ~OTHR iP WELCTL - EORP -' ~- - P WELCTL BOPE P I ' - - ~, - - - 11,680.0 11,680.0, RU and test 7" csg to 3500 psi for 30 ' ~ min. (Good test) - 11,680.O~i 11,680.0 RD casing and cement equipment 0.0' 0.0 Pull thin wear bushing. Install 7" pack-off ~ and test to 5000 psi. I 0.0 0.0 PJSM. Change top pipe rams from 7" to ~~ 0.0 - 0.01 3?" x 6 VBR's. -__ RU and test upper VBR's with 4" and 4?" test jts to 250 -3500 psi. (Good test) -- - - _ _ - 09:00 09:30 I 0.50 INTRM2 WELCTL OTHR P 0.0 0 0 Pull test plug. Install wear bushing. 08:30 09:00 0.50' - - I' ' - - - - - - - -- INTRM2 RIGMNT SVRG ' P ! 0.0 0.0 Service top drive and accumulator ~ 'i _ 'system. - - _ i--- - - _ _ _ _ -~ _ ---- Latest BOP Test Data -- - _-- _ Date _ Comment _' ' 1/3U~~U08 _ __iTested annluar to 250 & 2500 psi -All other componets 250.& 3500 psi -witnessing of test waived by AOGCC ~_ - - - _ -- Page 112 Report Printed: 2/5/2008 Daily Drilling Report CD3-316 __ _ - _ Security Level: Development Report Number: 25 tig: DOYON 19 -- Time t_og ~I Tire Pine l t_r.,~ Phase t Op Code -~ JySuu-Goue ',0930',12:00 2.50 INTRM2 ',DRILL PULD Report Date: 2/4/2008 rnr~~ r,,n s._~r I o,Y~ F~,.. - - F"~ T 7rGi vvue - tibF v~aa-,. l`h3~ ,. Y~.d/ l Lperation -- `"- ' P 0.0 376.0 PU Powerdrive. MU bit. Surface test Powerdrive at 210 gpm - 500 psi. MU P MWD PWD NMFC' XO enscope, s, I ', ' ' HWDP and jars to 376' .12:00 14:30 2.50iINTRM2 -DRILL TRIP P 1 ~' ~ 376.0 2,000.O~RIH f/ 376'to 2000' -picking up 4" DP f/ pipe shed ~ 14.30 16.00 1.50 INTRM2 DRILL ~,OTHR ( _ _ P ~ 2,000.0 2,000 0 Shallow test MWD 230 gpm @ 100 psi - - 16:00 19:15 3.25 INTRM2 DRILL TRIP P 2,000.0 5,409.0 Continue RIH f/ 2000'to 5409' - plcking up 4" DP f/ pipe shed -fill pipe every 20 stds 3.00'( INTRM2 -- DRILL TRIP _ P - ~ -- - _ 11,409.0 Continue RIH w/ DP f/derrick f/ 5409' to ~I, ~ 5,409.0 I - -- - I 11409' -filling pipe every 20 stds. ,22.15'.23:45', 1.50 INTRM2 RIGMNT SVRG P 11,409 0 11,409.0' PJSM on cut & slip drill line -Cut & slip drill line 90' 23:45 - - - .00:00 0.25 INTRM2 - - '.DRILL REAM I ~P - - -- --- --- -- - - ---- 11,409.0 11,430.0 Wash down f/ 11,409'to 11,430' @ 210 9Pm @ 1620 psi ' ' _ - Mud Check Data _ ~ - - - Type Dcpthffl;, r~,r: ~ I~;ali .i,i k;u PVCaIC(cp) F ~'ul (I1~J~f i O~1 ~1 ,,) -- Gel (1nR,.i ;~,I r30m) i-._- Hl HF Fill Der u_; I F:rnp .~ius, Corr ~,ibfli'n') ~ Qbr11~'~ti'i IIIt~1cDFt~) M B~ftlb:bbil r I ~ur,lni pH 'F) (/) " 0 LSND 11,690.0' 9.80 43 9.0 19.000 _ 1y.0i 7.z 9.5, 76.0 9.5 8.0 13.0. 15.00 l ~ - -~_- _ In eCtlOn FlUld 1 - __ I _ _._ _ ' _ _ _ - lwd ~ `Source_ I __~_ - _ Destination _ i _ rrom lease.{bbl) ( ©ie ~ - - Diesel -- , _ P _ _ ~ 45.0 CD3-316 freeze rotect Drilling Mud WBM CD3-316 1915.0 CD1-19 (Drilling Mud WBM 14.0 CD3-316 Annular LOT Fresh Water - - 300.0 CD3-316 Annular flush _ _- T - - _ __ _ -- _ _- Wellbores Wellbore Name I Wellbore API;U Wl CD3-316AP81 501032055971 SedFOn ~ s¢e (in) ~ -A"cf Ta"p (ft Erid Date tarrDate K ( - - Act Btm ftKa _ - T 'INTRM2 -__ 8 3/4 10,275.0 2/2/2008 11,690.0 1 30/2008 PROD 1 -_ --- 11,690.0 2/4/2008 _ - -- - '.Cement .Intermediate Casin Cement -Started x_214/2008 9 ~., i _ _ ,Type Wellbore Cemented String (, Cement Evaluation Results 'casing CD3-316APB1 ',Intermediate, 11, 680.OftK6 Stg No. bescription '.Top (ftKB) .Bottom (ftK6) Q (end) (bbl/... P (final) (psi) Intermediate Cas ing Cement 10,550.0 1,168.0 4 440.0 Fwld ~ crass _TAmounc (sa " ~ Est aim (~) v (btit)4 ~ ens~ry (1 1 80 vieid (~'~~ psi rop (n1 Tail Cement G 226 8 1 5 680.0'I 0)550.0 i 1.16 Page 212 Report Printed: 2/5/2008 PRESSURE INTEGRITY TEST CONOCOPHILLIPS Alaska, Inc. Well Name: CD3-316 Rig: Doyon 19 Date: 2/4/2008 Drilling Supervisor: Lutrick /Mickey Pump used: ,Cement Unit ~ Volume Input Barrels ~ Pump Rate: 0.1000 ~ Bbls/Strk ~ i 0.8 Bbl/min ~ Type of Test: Annulus Leak Off Test for Disposal Adequacy ~ Pumping down annulus. ~ Casin Test Pressure In tegrity Test Hole Size: 8-3/4" ~ Casing Shoe Depth Hole Depth Pum pin Shut-in Pumpin Shut-in RKB-CHF: 34.1 Ft 2,744 Ft-MD 2,476 Ft-TVD 10,550 Ft-MD 6,460 Ft-TVD Bbls psi Min psi Bbls psi Min psi Casing Size and Description: 9-5/8" 40#/Ft L-80 BTC 'i ~ 0 0 50 0 664 Chan es for Annular Ade uac Test Pressure Int e rit Test 1 0.5 117 0.25 617 uter casing shoe test results in comments Mud Weight: 9.8 ppg 2 1 147 0.5 595 Description references outer casing string. Inner casing OD: 7.0 In. 3 1.5 189 1 581 ize is that drilled below outer casing. 4 2 227 1.5 timated TOC for Hole Depth. 5 2.5 271 2 5 Enter inner casing OD at right Desired PIT EMW: 16.0 ppg 6 3 302 2.5 566 8 psi 0.9 bbls Estimates for Test: 79 7 3.5 337 3 555 __ '~ . ~ 8 4 376 3.5 553 EMW =Leak-off P ressure + Mud Weight = 779 PIT 15 Second 9 4.5 405 4 550 0.052 x TVD 0.0 52 x 2476 + ~'8,~, ~ Shut-in Pressure, ps i 10 5 439 4.5 546 E MW at 2744 Ft-MD (2476 Ft-TV D) = 1 5.9 ~ ~~-'1 617 15 5.5 472 5 543 -- taoo - _- _ - - - -- ~ 20 6 506 5.5 535 25 6.5 538 6 530 - - - - - ~ - - 30 7 564 6.5 530 - -- - - 7.5 594 7 530 ~ 8 620 7.5 530 - 8 5 653 8 530 . w R 9 683 8.5 529 ~ - - _ __ _ __ 9.5 708 9 527 ~ N - - ~~ ~ ~ -- 10 734 9.5 52 500 ~ - -- - 10.5 756 10 5 ~ - - 11 779 _- - _ a 11.5 766 -- - 12 747 - _. 12.5 709 - - _ __ 13 691 -- _ - - - 13.5 684 14 680 0 8 1 0 1 2 1 4 1 6 0 5 10 15 20 25 3 0 0 ~~ 2 CASING 4 TEST 6 Barrel s t LEAK-O FF TEST Shut-In time, Minutes O PIT Point Volume PUm ed Volume Bled Back Vol PU ume m ed Vol Bled ume Back s s s s Comments: 9 5/8" Surface casing FIT = 18.0 ppg Tnm and: St~anraon, Yc~u h<zve r~c~uc~stad t~ dispose ref "necr-prraduct" r" ~=.-,n ,:~ fluids from the z C7L't 1II e mixitzg c~P mud and cement at Alga.na as well a^, the clean up Elztid resulting from cl o,~ninq out the ta:i3cs at the mud ~ilant in preparation far u~z~g oil base mud.. TYi e C:c~:;unissian has previously ~laprav~;cl c3i5pc~szng of the °zieW produet" clean up CI~:iCis via arnul~r disposal at ['~ 1 pacl, Dine to the geal~sgical. setting aC Alpine. Glass l anc3 Class 2 disposal options are limited, Fhill;~,ps, pxedecessor, x~~.CA, had esLaY33isYecl the 1 im~t~ta,on of iii spaaa`l options to Lhe Cc~zszms~ion's sari s'.'~ctirar, ar*.cl anr_~alar dis~asal wrs~5 approved as tt~e practi~:al. anal environmental alternative. In these requeses. tYie ~-raste fluids are n© iii : i•erert that previously approved BrC~ aro the result. of the onc3ang clevelc~~!mer~: acti~7.%s:~~ at r~ipine. The C:c~mmi~sioiners have authox.i.~ecl me to send yA~ the ~ message, By copy of r_h:s emaiY Phill.aps ie authorized to clispase ref ci.ean up fluids as described 'in your. cr^,~ l Pleaae eaIl with any guesta,orzs, 't'orn ~.=~incler, PE ~~-. Petroleum Engineer A4GGC A3;F Env Goord wrote: ~ dear Mi". Maunder, } A.~ noted ire Lhe att.at::zed email.., "1*om Mans~,n pxev:iously requested > az~t.:zori,zatior, to dispose of new-prgduct cleat up fluids such. as cement rir!sate, aad nzu~i ar,ci ti7tiiie pit rimes from mixar~q ~ncrations via annular in;ect,ion ir. perm~.t:teci wells ar the Alpine CD2 Drill :Mire. As noted Y}~l~r, y ~+OG a}~provecl such disposal at tY:e CDl Drill Site in 7 999, based an ~.he integral relationship of the mud mixa.ng Imca~~l,ity and the on-site trilling ope:~atiarz. t Phillips would. like to cv~xt.nuing purszzincr this requ~:st. 5igriifidant clew:. out of hanks a.t the mud mixing facility. msst Decor in .preparation far the } tcz~tparary use of oil based mud. prr~ducts alt Alpine 4n tkz~ c:c~ma,ng months. the availability aL annular disposal as ara sapt.i.an fc+r tank rinse fluids and r similar wastes wau~id gxeatly facilatata this procesv. f'P`ypically, rouCne > rinses are beneficially reused, however, there is a cancerxi about the potential quantity cif fluid that eould be generatedt3uring thin large scale ~ clean up process..) 'i,~nks ar. the msrd raaxirig facilaty may contain either rzew and used znud > products... '~houg:Y r_z~see in concoct wir.h used prvdzicts moor be injectec9 in ~ the permiLt.ed class .I ;.: dsnasal, well. iCL31 9r'+} , rinses a~f new prbct:ct:; would. > po~entially be rautecl to the Glassz cl?sr,osa? well two-02}, where there is > a diLti.GUlty marzagirq 5elids content. The class Y well. is a cxir,i.r...z? ~ tift:_.linc for facility infra~tz'ucture, bevy the t9.is~~c.,sa:1. 1r,c.at.ion f4~ X11 Clnmestic effluent, and it is a prority'to prevent any compromise to Chic disposal facliCy. Annular disposal. presents a preferrPrl waste management alternaCve in tas case. ~_ • 7'han~c yQU ve_-y much for your: ~ansderaL'icin of this request. P1[*~~. do nraz > 1:c~itate L`G~ ~417.C+c1C! 1~lE' Or ttty i'~11:G'~nr'71~~ ;J'1'cq [?7.1 nr phpne at ~J07} ~']o=42Q~] if yflta have c~t~PStiCrns or need add.t:.ana1: information, 3 Shaman Donnelly > t~lpi_ne ~?field Envir~srunerital Cr~oranaLOr ~ t9Q7a f~70-92t}(3 -_-~-; Ft~x*.~rart3ecl by AIsP env Coosc~lPPt'd on 11IG2101 Y.2:5a I~MI ~~-~~~ } ALP Env C:csrJrd c?£i93iI~3. 1~:4~ PN > 'I'o: to.~,.maunder(~admin.5tak~.a`K.u~ ~c: ~ubjectz lzequest Go Tnjec~ Cement ~ansate at CD2 Dear Mr. Maunder.- In~ectic~n ai s_em~nt rinsdte and c~.ean-up fluids from mud and. brir7e mixini~ t~peratons at tae Alpiie muff plant fac:iliCy info ~,pg>.roved annular c3i spasal c~perat~ins a~as grartCed by one Alaska Ui.l Anel +;~as conser~.~ati©u Comt~~a~siori ~ 4~1CGCC} in the Mareh 1'l, 1999 letter ;rom I~4)GCC tc> De~ug ~'hesCx~ pf' P.kCO Alaska. .-ic. , rsrrfia Phillips Alaska. Inc. (k',A,T7 . ''L'h~ approval via crrartteci tci 3 PAS spec .ti.c_a11y fc~r Rlpi,r~~ Dri.17 Sire CDl zrrd a~.~L~oxi~ec: ~rnl~~me~ up to > :iS, D00 barrels thrauJY~ the annular space, } pA'~ request tkiat ~tii,~ approval k~e extericied Ga d~ri.l.ling aneratxons ar_ Alpine ~ Drall Site C~~. Cement mixincr operat.i.ox:s fcsr setting :surface canc~uc:tor:: > wla. bF r.~king Flag ~t the Grind .and Ir4je~t fac;il_t~y w~tich is cyx:~:r.etil.ly g attactse~- to CYie c3rillirig rice at CD2. G~pcal7t cs3rn~l a-z,cart at the ccrnentinc~ in ~ of 'thee c4:i~ir.r.tors, the lines t~nc3 rmaxinq rank will have .to be .rinsed and the > rinaate dispaaed of. PAI reque3t apprCrv~l L'tr i:ljert rhis rir.s~t~~, anc3 atYiar~ clee;~_u~, :,-~,;rt Cbe mud ar~d Mr.n~ mixing onr.~rati~n:~, into tYka annual a spade t~f approved:.. welly located at Drill Site t:L~2. y 7 ff ycu h~sv~ any guotati.ans please. cantact me ~t ~7Q-4200. Tt)i~: I+~~l'SSOT'l Al~ain~ Field Erivranmental Compliance tplTl~rl~urldBr:vCf • Note to File CD3-316A (208-011...308-127) ColviNe River Unit (Fiord-Kuparuk) GonocoPhillips Alaska, Inc ConocoPhiflips has made application for annular disposal for the subject well. This document examines the pertinent infom~aton for the weft and recommends approval. of ConocoPhillips' request. --The surface casing for this well was set in CD3-316 {207-177). No unusual events were reported while drilling the surface hole of the well. --Surface casing was cemented to surface. No problems were reported. Approximately 85 bbls of cement was circulated to surface. The net cement remaining in the surface hole was 83°/a XS of the calculated hale volume. -- On the initial leak off test, the pressure rises relatively smoothly to 18.0 EMW. Minimal fluid was pumped in. The pressure declined during the observation period to about 15.6 EMW. The initial leak off indicates that the surface casing shoe is well cemented. --The intermediate hole was redrilled due to poor sand thickness in the Kuparuk. The original penetration was plugged bads and CD3-316A drilled off the cement plug at 6017' md. No problems are reported drilling either intermediate hole. The 7° casing was run and successfully cemented. Full returns were noted and the using was reciprocated. --An infectivity test doom 9-518" x 7A annulus was conducted. Pressure steadily increases until the break at 15.9 EMW. The pressure declined with additional pumping to 15.1 EMW. During the observation period, the pressure declined to 13.9 EMW. The lower EMW of the pump in test indicates that the planned disposal should be conducted at EMWs below that of the shoe integrity. --CPA provided a listing of all surface casing shoes within'!; mile radius of CD3-316A. No wells are nearby. The surface shoe of CD3-302 is closest about 920' distant. C©3- 107/307 is about 1030' distant. 4 other wells are over 1200' distan#. Examination of the cementing information did not reveal anything to preclude granting CPAI's request. Based on examination of the submitted infomtation, I recommend approval of ConocoPhillips' request for the subject well. (a'~"'"~' - C Tom Maunder, PE Sr. Petroleum Engineer April 15, 2008 G:\common\tommaunder\Well Infarmation\By Subject\A~uiutaz Disposal\Q80415--CD3- 316A.doc • Note to File CRU CD3-316A (PTD 2080110) April 15, 2008 Re: ConocoPhillips' Application for Sundry Approval for Annular Disposal of Drilling Wastes within Well CD3-316A Request ConocoPhillips requests approval to dispose of waste fluids generated through drilling operations by injection into the annulus surrounding the 7" casing within well CD3-316A. Recommendation Approve ConocoPhillips' request. Conclusions 1. The 9-5/8" surface casing shoe is set in this well at 2,475' measured depth (-2,427' true vertical depth subsea, or "TVDSS"), near the base of a 180-foot thick shale interval that persists throughout the area. This inerval will provide confinement to prevent upward migration of injected waste. 2. There appears to be a sufficient volume of siltstone and sandy siltstone open to the surrounding the 7" casing within this well to accept the proposed injected fluids. 3. The lower confining layer is sufficiently thick and laterally persistent to ensure injected materials remain within the target disposal interval. 4. There are no potential USDWs in this area. 5. Correlative rights will be protected. 6. The proposed disposal injection operations will not affect potential oil or gas reservoirs. 7. The area most strongly impacted by the proposed annular disposal activities will be limited to a radius of less than 120' from the wellbore. Discussion CPAI's application was reviewed along with records from. nearby wells CD3-307, CD3-113, CD3- 113PH, and CD3-114. The discussion that follows is based on well logs and the mud log from CD3-114. An index map is provided in Figure 1, below. Drilling wastes will be disposed in an open annulus that extends downward from the 9-5/8" surface casing shoe, which is set at 2,745' measured depth (-2,427' TVDSS), to the top of cement for the 7" casing string, which is estimated to lie at about 10,550' measured depth (-6,424' TVDSS). This annulus spans the boundaries between Sections 3, 4 and 5 of T12N, RSE, UM, and lies about 3 miles from the current boundary of the CRU (see Figure 1). The section of open annulus that will most likely accept the injected waste fluids is a 64-foot thick portion of the Seabee formation that extends from 2,808' to 2,868' measured. depth (-2,521' and -2,569' TVDSS). This interval contains several 1- to 3-foot thick beds of siltstone and sandy siltstone that are separated by clay and claystone. The aggregate thickness of the siltstone and sandy siltstone beds is about 19'. The apparent siltstone that lies immediately beneath the 9-5/8" casing shoe of CD3-316A is likely an artifact caused by circulating and cementing. Correlative sediments in the offset exploratory wells consist only of shale, clay or claystone. C~N~~D~NT~AL ~~~~~ ~~s s~o~~ • CD3-316A April 15, 2008 Note to File Page 2 of 4 The 9-~/8" surface casing shoe lies near the base of a 180-foot thick interval that is dominated by mudstone, clay and shale and is continuous throughout the area. This interval will provide upper confinement for the disposed fluids. Beneath the most likely injection interval is a 360-foot thick zone of claystone, shale and siltstone that is also continuous throughout the area. This interval, which lies between 3,060' and 3,310' measured depth (-2,650' and -2,830' TVDSS), will provide lower confinement for injected wastes. D3-302 3' 3-302PB2 CD3-307 eme Top CD3-302PB1 Ce en Top CD3-113P Open ~t Annulus ~~ ent Ce a _Top CD3-114 CD3-316 PH CD 316 Likely '/4 Mile Disposal ,~, ~ o s-; Radius Interval ~ ~J i V ~ i ~ E~~ ~ ~~.~. Buffer Figure 1. Indez Map In vicinity of Drill Site CD3, the base of permafrost occurs at about -1,250' TVDSS, which is about 1,200' above the top of the proposed injection interval. Conclusion 3 of Area Injection Order 30, which governs the Fiord Oil Pool, states that there are no USDWs beneath the permafrost within the Colville River Unit or the proposed affected area. CD3-114 is the only well that was mudlogged on Drill Site CD3. In CD3-114, methane was first encountered at 1,115' measured depth (about -1,050' TVDSS). So, the entire proposed disposal zone likely contains some methane gas. The shallowest oil show encountered in well CD3-114 was observed at 6,050' measured depth (-4,413' TVDSS), about 3,500' below the likely receptor beds for the injected material. This show consisted only of 10% dull yellow sample fluorescence and a slow pale yellow sample cut in solvent. The mud logging portrays this show as being of "trace" quality. So, at Drill Site CD3 the likely disposal interval does not contain potentially commercial hydrocarbons. CD3-316A Note to File Cotlflnulg Strata • April 15, 2008 Page 3 of 4 Correlation Depth GR(SGRC) <MD 10 api ~:3i i TVDSS> GR Yello~:v Gray Sand Silt Clay • ~~ Surface Casing 2800 Most Likely Receptor Strata for Disposed Fluids 2900 Fro 3000 3100 Confining Strata ,, ~ Figure 2. CD3-316A Well Log for Affected Intervals The chart presented in Figure 3, below, provides an estimate of the subsurface volume around CD3-316A that will be affected by the proposed annular disposal operations. There are about 18' of porous siltstone and sandy siltstone beds within the likely disposal interval, according to a count using the gamma ray curve from CD3-316A. Porosity well logs were run across the proposed disposal interval in CD3-316A. Inspection of the neutron and density porosity logs for the likely disposal interval suggests an average porosity of about 28% for the siltstone and sandy siltstone beds. Based on these values, the proposed 3200 ~~ 3300 ' Resis Porosity RT RHOB(SBD2) ohmm 200.000 .65 g/cc 2.65 P1POR • CD3-316A April 15, 2008 Note to File Page 4 of 4 annular injection activities will directly affect the receptor beds only to a radius of less than 120' from the wellbore, as indicated below. Injected Fluid vs Affected Radial Distance CD3-316A Wellbore (assumes 18' aggregate inject"an zone tfiickness and 28% porosity) 300 _ __ ~i 250 v 0 a 3 ~0 e 0 e ~ 150 w b ~a ' -- __-~ v 100 a __ - - - ~ - - Bi ~ -_ -_ - - _ 50 a - i 0 0 5,000 10,000 15,000 20,000 25,000 30,000 35,000 Amount of Injected Fluid (barrels) Figure 3. Radial Distance Potentially Impacted by CD3-316A Injection Summary The limited volume of rock that will be affected by this proposed disposal injection program likely contains methane gas, is situated beneath about 1,250' of permafrost, and is bounded above and below by continuous layers of shale, claystone, clay and siltstone. There are no freshwater aquifers present, nor are there any potentially commercial hydrocarbons within the proposed injection interval beneath CD3-Pad. The open annulus that will be used for disposal injection lies inside the Colville River Unit, well away from any external property lines, so correlative rights will not be a concern. I recommend ap oval of this annular disposal project. Steve Davies ~~~ ~~ Senior Petroleum Geologist ~:~~~ v v ~ • k ~~ ~_~ ~ .~"~ :~~1 i..~ C~.,f~gt.~ E ~~ Ll zt. E~~.~ t.~ ~a il~-1 ALA-SSA OII, AI~TD GAS CO1~T5ERQATIOI~T COl-II~IISSIOPIT Chip Alvord Alpine Drilling Team Leader ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CD3-316A Sundry Number: 308-127 Dear Mr. Alvord: SARAH PAtIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907)276-7542 Enclosed is the approved Application for Sundry Approval relating to annular disposal of drilling wastes in the above-referenced well. Please note that any disposal into the surface/production casing annulus of a well approved for annular disposal must comply with the requirements and limitations of 20 AAC 25.080. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next .working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Dan T. Seamount _,/ Chair DATED this day of April, 2008 Encl. ~ r y ~~ y 1 ,~ ~ ;~ + aJ ' v ~''` ~ ~ a = p 1 i_.~j 1 6~~ ~ p g ) ~~ , 1 C01~5~RQ~ ATI01~1T C ~ Ip~ Jack Walker Production Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510 Re: Colville River Field, Fiord Oil Pool, CD3-316A Sundry Number: 308-125 Dear Mr. Walker: SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 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 ff it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this ~ day of April, 2008 Encl. Daniel T. Seamount, Jr. Chair ~o5r-(~jl !- ~~~~9~ 'S'c~i~ d,~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION '' 9 1 TI N F R NDRY APPROVAL ~`~ ~~~ APPL CA O O SU c~ 200 20 AAC 25.280 ~ ~_ 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ Waive Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension ^ Change approved program ^ PuII Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Driil Number: ConocoPhillips Alaska, Inc. Development ~ Exploratory ^ 208-011 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20559-01 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? Yes No ^~ CD3-316A 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ADL 372104, 372105 • 36.3'KB Colville River Unit / Fiord 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): 12515' 6716' Casing Length Size MD TVD Burst Collapse CONDUCTOR 114' 16" 114' SURFACE 2708' 9-5/8" 2744' INTERMEDIATE 11647' 7" 11680' SLOTTED LINER 956' 4-1/2" 12505' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4-1 /2" L-80 11556' Packers and SSSV Type: Packers and SSSV MD (ft) Baker Premier Packer Packer = 10824' SSSV= BAL-O k/,rC~•.ti, -rr ~ %ev1•~- ~~ D 1' SSSV= 2124' 13. Attachments: Description Summary of Proposal ~ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service '^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: April 15, 2008 Oii ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG Q GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jack Walker Printed Name ~Gi-L:,~ ~-t ~-~ ~~--/ Title: Production Engineer ~,~. fj"`~~.~~-- Signature "riti 1 Phone 265-6268 Date '•*~ '~ b~ Commission Use Onl Sundry Number: 3Q8'~• f Conditions of approval: Notify Commission so that a representative may witness ~ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ~ Location Clearance ^ Other. s'~~~~ ~~, /~P~? ~ 2009 Subsequent Form Required: ~.,,1t1 ~ ~ ~~ '+ APPROVED BY /~ ~( ~ ~ Approved by: M I CO ( U THE COMMISSION Date: Form 10-403~F~e~d 06/2006 it in Du~ to ~~, ~ ~ o$ ConocoPhillips April 7, 2008 Mr. Dan Seamount, Commissioner Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Re: Request for Sundry Approval Colville River Field, Fiord Oil Pool, well CD3-316A Permit to Drill 208-011 Dear Chairman Seamount: Jack Walker Production Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360, ATO 1740 Anchorage, AK 99510-0360 phone 907 265-6268 ~~ qp cFi ~a ~F ~~~' ,goo d ',tS, ~' ConocoPhillips Alaska, Inc. (CPAI) as operator of the Colville River Unit is requesting approval to convert '~ CD3-316A (permit 208-011) to a WAG injector. The well was completed as a producer but was designed as a WAG injector in the Fiord Oil Pool, and a cement bond log indicated good cement on February 9, 2008. The conversion is planned for early April, 2008. Static bottomhole pressure measurement is planned before starting injection. Enclosed please find a 10-403, the Sundry application, for CD3-316A. Please call meat 265-6268 if you have any questions. Jack Walker Production Engineer ConocoPhillips Alaska Inc. ~ ~ I~C~ICAL INTEGRITY :Z.~ORT - ~ . a O~S-O ~ BUD u.'-.:~ : ``~S-~~ QPER ~ FZELD C.~pr ~... ~ ~~ .c a ~~~~... - ~~~a-O ~ hrT.T. NtTMBER c.~3-?,\~~ TD : \, X515 ?~ ~N ALL DAT ~ ~~~ ~ TVD ; ?BTD : \~SO.S ?ID x'11 S '~'VD .. _ Casing : '1~ ~ Shoe : 11(v~ t1D ~1a ~ TVD ; LV : ?~D -'='ti~7i :._.,e~ :~~~~~~ Shoe : \x505 '~ ~~15~ TT1T ; TGr . 11S~1 '`~ toil\'1 ~':D .:~o~~~ ~ ~~~r~ ?ac.KeT ~D~6~ :~ TVD; Cet aL ~~SSb and ~0 1~$,, ; =ole s~Le ~~ PeTfs to .- - ~ « ~ ~ 4 ~ t ' ~ . r z a s o ~ t c~c,- so ~hS ~a.:ulas ?ress Test: .? i 5 ain SO min Comments : ~'.51p\rc ~s~R c) ~ ~~~.~5 ~ ~ ~ ~5~~ 3SOO~ ~c 3~ ~-~J~ ~ . a~~a-OSs w~~ N+~ '~'CH1~uIC?i. ZNTEGR?"?'~' -PART #2 ~ ~11~~~5 Cement Volumes :_ Amt. Liner Csg ~s~ DV ~1'"S~o fc ` f C.mt :rol to cover ,ate \`~ b~\ys~~~c~~,,~~-~n CS~V~C` ShCXc'~t~ 3O~c~~S r Ihearetical TOC ~ 103.SQ ~° 3C7~ XS SOS ~ ~ ~r~to Cement Bond Log (Yes or No) ~E S In AOGCC File ~~ S - C5L Evaluation, zone agave perfs ~~ C~X~~T~- ~'~~, ~"`~C~ Production 'Log: Type CO~i~LJS s.Ot~S ?arm s1_ Part 12: M S-ZS z E.valuati an L i ~~ CD3-316 (Permit 208-011) Concert to Service • .- Maunder, Thomas E {DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, April 09, 2008 2:41 PM To: 'Walker, Jack A'; Smyth, Robin J.(Schlumberger Oilfield Services} Cc: Haas, Jeanne L; Galiunas, Elizabeth C Subject: RE: CD3-31~(~' Convert to Service Not a problem Jack. It is all part of the review. We all want the data to be correct. Regards, Tom Maunder, PE AOGCC Page 1 of 2 From: Walker, Jack A [mailto:Jack.A.Walker@conocophillips.com] Sent: Wednesday, April 09, 2008 1:17 PM To: Smyth, Robin J.(Schlumberger Oilfield Services) Cc: Maunder, Thomas E (DOA); Haas, Jeanne L; Galiunas, Elizabeth C Subject: RE: CD3-3i6 (Permit 208-011) Convert to Service Robin, The CD3-316 well was sidetracked before casing and cementing, and renamed CD3-316A. run 9-Feb-2008 has an incomplete well name and incorrect API number on the log header. very important, could you please have the log corrected as follows: 1. Change well to CD3-316A 2. Change API number to 50-103-20559-01 3. Delete well schematic just below logging tool schematic. Thank you, Jack The GR/CCL/CBL As these records are PS to Tom: We cased, cemented, and CBL'ed the CD3-316A sidetrack only. The log is for the correct well, but the log header is incorrect as you pointed out. Thanks for catching this, and please accept my apology for any confusion. From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Wednesday, April 09, 2008 11:55 AM To: Walker, Jack A Cc: Galiunas, Elizabeth C; Howard D Okland Subject: RE: CD3-316 (Permit 208-011) Convert to Service Jack, am reviewing the sundry. In the text of your message, you correctly refer to CD3-316A. The information in the header of the log is not correct. Schlumberger lists CD3-316 and does not have -01 in the API number. I believe the differences are something that need to be corrected. Call or message with any questions. Tom Maunder, PE AOGCC From: Walker, Jack A [mailto:]ack.A.Walker@conocophillips.com] Sent: Monday, April 07, 2008 10:31 AM To: Maunder, Thomas E (DOA) 4/9/2008 y CD3-316 (Permit 208-O1 l) Co~ert to Service Page 2 of 2 • Cc: taaliunas, Elizabeth C Subject: CD3-316 {Permit 208-Oil) Convert to Service Tom, Jeanne is bringing a sundry request today to your offices for CD3-316A (permit 208-011) far conversion from production to injection. it was completed as a producer, but we des~ned it as an injector antiapating the need. Enclosed is a CBL. Please call me with any questions. Jack Walker ConocoPhillips Alaska, Inc. Western North Stope Development 907-265-6268 «CD3-316_SCMT 9FEB08_PRINT1.zip» 4/9/2008 CD3-316 (Permit 208-011) Convert to Service Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, April 09, 2008 11:55 AM To: 'Walker, Jack A' Cc: Galiunas, Elizabeth C; 'Howard D Okland' Subject: RE: CD3-316 (Permit 208-011 }Convert to Service Jack, am reviewing the sundry. In the text of your message, you correctly refer to CD3-316A. The information in the header of the log is not correct. Schlumberger lists CD3-316 and does not have -01 in the API number. I believe the differences are something that need to be corrected. Call or message with any questions. Tom Maunder, PE AOGCC From: Walker, lack A [mailto:Jack.A.Walker@conocophillips.com] Sent: Monday, April 07, 2008 10:31 AM To: Maunder, Thomas E (DOA) Cc: Galiunas, Elizabeth C Subject: CD3-316 {Permit 208-011) Convert to Service Tom, Jeanne is bringing a sundry request today to your offices for CD3-316A (permit 208-011 }far conversion from production to injection. It was completed as a producer, but we designed it as an injector anticipating the need. Enclosed is a CBL. Please caA me with any questions. Jack Walker ConocoPhil6ps Alaska, lnc. Western North Slope Development 907-265-6268 «CD3-316_SCMT_9FEB08_PRi NT1.zip» 4/9/2008 CD3-316 (Permit 208-011) ConYert to Service Page 1 of 2 Maunder, Thomas E (DOA) From: Walker, Jack A [Jack.A.Walker@conocophillips.com] Sent: Monday, April 07, 2008 11:55 AM To: Maunder, Thomas E (DOA) Subject: RE: CD3-316 (Permit 208-011) Convert to Service Would like to begin injecting about the 18th, pending simultaneous operations on the pad with Doyon 19. Jack From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, April 07, 2008 11:02 AM To: Walker, Jack A Subject: RE: CD3-316 (Permit 208-011) Convert to Service I know it helps get the data into the right place. Key point is you all being aware of whether the well is formally a producer or injector. There shouldn't be an issue with the physical well construction or integrity demonstration, just need to keep the paperwork straight. When would you hope to begin injection? Tom From: Walker, Jack A [mailto:Jack.A.Walker@conocophillips.com] Sent: Monday, April 07, 2008 10:56 AM To: Maunder, Thomas E (DOA) Subject: RE: CD3-316 (Permit 208-011} Convert to Service Thanks, Tom. I really like this permit process for pre-produced injectors. Jack From: Maunder, Thomas E (DOA) [mailto:tom.maunder@aiaska.gov] Sent: Monday, April 07, 2008 10:53 AM To: Walker, Jack A Cc: Galiunas, Elizabeth C; Allsup-Drake, Sharon K Subject: RE: CD3-316 (Permit 208-011) Convert to Service Jack, Thanks for the CBL. I have not seen the sundry. Working with the drilling people, the permit is obtained for an injector since that is what the well will ultimately be. That lets us (AOGCC) assure that the integrity assessments (bond log and MIT) are specified. Since it is not unusual for CPAI to "pre-produce" injection wells for various time periods, the wells are completed as producers to eliminate production volumes being reported for an injection well. This greatly simplifies the data transmittal and reconciliation process over here. When the desired pre- production period is nearing completion, submitting the sundry to convert finishes the process. Given the recent permit #, it would appear that the production period for CD3-316A may not have been long. Call or message with any questions. Tom Maunder, PE AOGCC From: Walker, Jack A [mailto;Jack.A.Walker@conocophillips.oom] Sent: Monday, April 07, 2008 10:31 AM 4/9/2008 CD3-316A (PTD 208-011) SSSV Variance ~ Page 1 of 3 Regg, James B (DOA) From: NSK Well Integrity Proj [N1878@conocophillips.com] Sent: Tuesday, March 11, 2008 6:19 PM To: Regg, James B (DOA) Cc: NSK Well Integrity Proj Subject: FW: CD3-316A (PTD 208-011) SSSV Variance Jim, CD3-316A (PTD 208-011) was SI at 10:00 am today. With cooperation from Doyon 19, they were able to set and test a WRDP. Please let me know if you have any questions. MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 From: ALP DS Lead/Simops Coord Sent: Tuesday, March 11, 2008 4:16 PM To: NSK Well Integrity Proj; ALP Ops Maint Supt Cc: Cavwey, Von; Brake, Jared M Subject: RE: CD3-316A (PTD 208-011) SSSV Variance MJ, CD3-316 Was shut in at 10:00 AM this morning, Wireline, with the cooperation of the drilling representatives on Doyon 19, were able to set a WRDP and test it. The well was brought back on at 15:30 PM. We are currently working on a process to prevent this situation from happening again. Rich Ligenza/Rick Alexander ALP DS Lead/Simops Coord 670-4017 943-1169 From: NSK Well Integrity Proj Sent: Tuesday, March 11, 2008 3:51 PM To: ALP DS Lead/Simops Coord; ALP Ops Maint Supt Cc: Cawvey, Von; NSK Well Integrity Proj; Brake, Jared M Subject: FW: CD3-316A (PTD 208-011) SSSV Variance RichlWarren. Here is the response from the State. Please let me know when the well is shut in and when the SSSV is installed 3/12/2008 CD3-316A (PTD 208-011) SSSV Variance • Maunder, Thomas E (DOA) From: Regg, James B (DOA) Sent: Tuesday, March 11, 2008 11:33 AM To: NSK Well Integrity Proj Cc: Maunder, Thomas E (DOA) Subject: RE: CD3-316A (PTD 208-011) SSSV Variance Attachments: 01 _SafetyValveSysGuide. pdf MJ - Page 1 of 2 As discussed by phone this morning, well. CD3-316A should be shut_n until a SSSV can be installed. Please respond when the well is shut in or the SSSV is installed. Our guidance allows a well to continue operating "not_I_onger than 15 days" without a SSSV for "routine well work" (see attached excerpt from our SVS guidance, specifically paragraph C}. Included in routine well work would be flowing for some time to clean up the well, which 15 days should be more than sufficient. Based on what you describe below, it appears the well flow is cleaned up and producing better than expected. It is unfortunate that the rig moved onto an adjacent well on or about March 1, blocking access to CD3-316A, and will not likely depart until late March. Our policy does not make provisions for allowing a well to continue producing under these circumstances (nor was it the intent of the 15 day grace period), and that should have been recognized early on by the field personnel. Initially you and I understood that the 15 days had not yet elapsed, but that was later corrected to indicate the well was placed on production 2/21/08. The well is in violation of this allowed timeframe for operating a well without aSSSV -today is day 19. This comes on the heels of a letter the Commission sent to ConocoPhillips on February 6, 2008 outlining regulatory concerns, and specifically noting several concerns at Alpine and Alpine satellite fields. ConocoPhillips senior managers met with Commissioner Foerster and myself on February 15 to discuss the concerns raised in that letter and were assured they would be addressed; ConocoPhillips is preparing a response. Timing is likely a factor (2/15 discussion and CD3-316A circumstance) but certainly does not negate the field personnel's responsibility for complying with our regulatory requirements. It would be appropriate to remind the field personnel about the requirements when removing a SSSV from the well. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: NSK Well Integrity Proj [mailto:N1878@conocophillips,com] Sent: Monday, March 10, 2008 4:48 PM To: Regg, James B (DOA) Cc: Maunder, Thomas E (DOA); NSK Well Integrity Proj Subject: CD3-316A (PTD 208-011) SSSV Variance Jim, Alpine well CD3-316A (PTD 208-011) is a pre produced injector. It was brought on line 2/21/08 without the WRPD installed to allow the well to clean up from drilling. The original plan was to flow the well for a few days. However after exceptionally good wells tests (> 5000 BOPD), Operations would like to leave the well online. Drilling Rig Doyon 19 is currently on CD3-118 and blocking access to install the WRDP in CD3-316A. 3/12/2008 CD3-316A (PTD 208-011) SSSV Variance Page 2 of 2 The well is currently manned (by ExPro) 24 hours per day with hourly walk around and pressure checks. ConocoPhillips requests approval to keep the well online without the SSSV until Doyon 19 moves out of the way (estimated move date March 27th). Thank you MJ Loveland Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Office (907) 659-7043 Cell (907) 943-1687 3/12/2008 ConocoPhillips February 22, 2008 Commissioner State of Alaska Alaska Oii & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Well Completion Reports for CD3-316 and CD3-316A Dear Commissioner: P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-265-6120 Cono~oPhiNips Alaska, Inc. submits the attached Well Completion Reports for the recent drilling operations on the Alpine well CD3-316 and CD3-316A. If you have any questions regarding this matter, please contact me at 265-6120. Sincerely, ,1~ _ ~.. G. C. Alvord Alpine Drilling Team Leader CPAI Drilling and Wells GCA/skad c. c. alvord Alpine brisling Team Leader Drilling & Wells c7~~'O( STATE OF ALASKA ~ FED 2 2 2008 ALASKA OIL AND GAS CONSERVATION COMMISSION ~ ~ 8 ~O~i_1S. COTT1~il8Sl~t1 WELL COMPLETION OR RECOMPLETION REPOI~~`t ~-~It~: t ~;,~, ,; w, 1a. Well Status: Oil ^ Gas Plugged Abandoned Suspended ^ 20AAC 25.105 20AAC 25.110 GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other ^ No. of Completions: 1b. Well Class: Development Q Exploratory ^ Service ^ Stratigraphic Test ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Date Comp., Susp., orAband.: February 12, 2008 12. Permit to Drill Number: 208-011 3. Address: P. O. Box 100360, Anchorage, AK 99510-0360 6. Date Spudded: January 25, 2008 13. API Number: S0-103-20559-01 4a. Location of Well (Governmental Section): Surface: 1311' FSL, 972' FEL, Sec. 5, T12N, R5E, UM 7. Date TD Reached: February 8, 2008 14. Well Name and Number. 'CD3-316A /CD3-316AP61 Top of Productive Horizon: 1410' FSL, 1580' FWL, Sec. 3, T12N, R5E, UM 8. KB (ft above MSL): 9 B i•27~d}~S Ground (ft MSL): i3.y BPMSL 15. Field/Pool(s): Colville River Field Total Depth: 848' FSL, 2480' FEL, Sec. 3, T12N, R5E, UM 9. Plug Back Depth (MD + ND): 12505' MD / 6715' TVD , Fiord Oil Pool 4b. Location of Well (State Base Plane Coordinates): Surface: x- 388071.5 y- 6003807 Zone- 4 10. Total Depth (MD + ND): • 12515' MD / 6716' ND 16. Property Designation: ADL 3721oa; 372105 TPI: x- 395903 y- 6003793 Zone- 4 Total Depth: x- 397116 • - 6003213 • Zone- 4 11. SSSV Depth (MD + ND): SSSV @ 2124' MD / 2019' ND 17. Land Use Permit: LAS 2112 18. Directional Survey: Yes Q No ^ (Submit electronic and printed information per 20 AAC 25.050) 19. Water Depth, if Offshore: N/A (ft MSL) 20. Thickness of Permafrost (ND): 1500' TVD ' 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): ~(f v}'~ ~jG'~/9 ~~i ~r~a GR/ Res/ Dens / Neutr ~$• ~ 7"'~ F~ s.=•'~' 22. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE CEMENTING RECORD AMOUNT CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.5# H-40 36' 114' 36' 114' 24" Portland Type III 9-5/8" 40# L-80 36' 2745' 36' 2476' 12.25" 383 sx Class G, 234. sx Class G 7" 26# L-80 36' 11680' 36' 6726' 8.75" 226 sx Class G 4.5" 12.6# L-80 11549' 12505' 6717' 6715' 6.125" slotted liner 23. Open to production or injection? Yes / No If Yes, list each 24. TUBING RECORD Interval open (MD+ND of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET 4.5" 11556' 10824' alternating solid /slotted liner: 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11661'-11740', 11940'-11980', 12100'-12382' MD DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED r kick-off plug 10135'-10896' 293 sx Class G Lj,/~'y~ ~ 1 ~ isolation plug 10896'-11407 208 sx Class G ~r ~~ ~ ~ ' F F ' C? ~ -~ l 26. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) waiting on facility hook-up Date of Test Hours Tested Production for Test Period -> OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing press. psi Casing Pressure Calculated 24-Hour Rate -> OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY -API (corn) 27. CORE DATA Conventional Core(s) Acquired? Yes No ~ Sidewall Cores Acquired? Yes No ~ ` If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. ;~i '; t;~ NONE ~'' z ~ ~~` • ~ ~a~ Form 10-407 Revised 2/2007 CONTINUED ON REVERSE SIDE 7- 2.7.x8 ~~ i 28. GEOLOGIC MARKERS (List all formations and ma s encountered): 29. FORMATION TESTS NAME MD TVD Well tested? ~ Yes ~ No If yes, list intervals and formations tested, Permafrost -Top Surface Surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost -Bottom 1529' MD 1500' TVD needed, and submit detailed test information per 20 AAC 25.071. K-3 4742' 3894' K-2 5001' 4077' ALB 97 8347 5733' NANUO 9213' 6016' Top HRZ 10564' 6465' Kuparuk 11146' 6628' N/A CD3-316AP61 TD 11407' 6771' Formation at total depth: Kuparuk 30. LIST OF ATTACHMENTS Summary of Daily Operations, Directional Survey, slotted liner detail sheet 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Liz G8liunas @ 265-6247 Printed Name Chi Alvord Title: WNS Drilling Team Lead ` / / Date ~l u(z o Ph - Si one ~ S gnature ~ _ ~ (L. P INSTRUCTIONS Sharon Allsup-Drake General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas injection, water injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 2/2007 ConocoPhrllfp Alasl~~i, »c. rn`s_a1 ~ - (32-11556, OD:4.500, ID:3.958) TERMEDIATE (33-11680, OD:7.000, Wt:26.00) GAUGE costs-tos2o, OD:4.500) PACKER - 10824-10825, OD:5.970) NIP :10885-10886, OD:5.000) W LEG ttsas-ttsss, OD:4.930) SLEEVE :11549-11562, OD:6.400) - -~-~ Tubing String"-TUBING _ -- - Size ~ Top L I Bottom _' _ TVD Wt ! Grade I_ Ttlread_ _ 4 500 I 32 _ -- _ I 11556 11556 12.60 ~ L JO _ I IBT - ry '.Perforations Summa [~ ALPINE CD3-316 API: 501032055900 - - - - Well T e: SVC An le TS: de SSSV Type: WRDP Orig Completion: Angle @ TD: deg @ Annular Fluid: Last W/O: Rev Reason: NEW WELL, GLV Go, Pull RHC, set WRDP Reference Lo Ref Lo Date: Last U date: 2/18/2008 Last Ta TD: 12505 ftK6 Last Tag Date: Max Hole Angle: -. _ Easing String -ALL STRINGS - - Descri lion Size To 0 deg @ ottom _ TVD - -- Wt -- Grade hreao CONDUCTOR 16.000 0 114 114 62.50 H-40 WELDED INTERMEDIATE 7.000 33 11680 11680 26.00 L-80 MBTC SURFACE 9.625 36 2744 2744 40.00 L-80 MBTC SLOTTED LINER 4.500 1154.9 12505 12505 12.60 L-80 SLHT __ ' Interval TVD Zone Status Ft SPF Date T e Comment 11661 - 11740 11661 - 11740 79 32 2/9/2006 Slots Alternatin solid/slotted i 11940 - 11980 11940 -11980 40 32 2/9/2008 Slots Altematin solid/slotted i e 12100 -123_82 1_2100 -12382 - -- Gas Lift Mandrels/Valves St i MD i TVD ~ Man Mfr I Man Type I _ 2.82 32 2/9/2006 _ Slots -- _ V Mfr I V Type I V OD I Latch I Port Alternating_solid/slotted p~e_ - - _ _ _I I TR© I Date Run I Cmnt 1 10710 10710 CAMCO KBG-2 OV 1.0 BK 0.375 0 2/14/2008 1 ~. uuH~ rvrr i v v..va- a ~n b.. - _ -_ ~ - - Otf~er (plugs, equip., etc.) -COMPLETION ___ _ -- De th TVD T Descri lion ID 32 32 - HANGER FMC TUBING HANGER 3.900 2124 2124 SSSV CAMCO BAL-O NIPPLEw/PACKOFF 2.5" ID- TOP PORT IS PLUGGED 3.812 (CONTROL PORT). ONLY BALANCE PORT AVAILABLE 10824 10824 PACKER BAKER PREMIER PACKER 3.875 10885 10885 NIP HALLIBURTON'XN' NIPPLE 3.725 11546 11546 WLEG BAKER WIRELINE GUIDE 3.950 NIP :11562-11566, OD:6.070) r~ Steve - Here is the additional data for CD3-316A, permit #208-011 Alternating solid /slotted liner from: 11661'-11740' MD 6726'-6729' TVD 8 spf .25 wide 11940'-11980' MD 6728'-6722' TVD 8 spf .25 wide 12100'-12382' MD 6717'-6714' TVD 8 spf 25 wide Bel is the additic 9322'-9 ' MD 9543'-9548' 10011'-10016' MD 10171'-10177' MD 10363'-10368' MD 10524'-10528' MD 10715'-10720' MD 10997'-11002' MD 11310'-11315' 11524'-11 ' MD 1199 ' 001' MD mal data for 3S-08C, permit a 5844'-5844' TVD 1 spf 5847'-5847' TVD 1 s 5868'-5868' TVD spf '-5864' T 1 spf 5863'- VD 1 spf 5862'- 62' 1 spf 5 -5860' TVD spf 863'-5863' TVD 1 s 5861'-5861' TVD 1 spf 5856'-5856' TVD 1 spf 5870'-5870' TVD 1 spf ~207- ole .5" hole .5" hole .5" hole .5" hole .5" hole .5" hole .5" hole "hole 5" h .5" hole Time Lo s Date From To Dur S. De th- E_ Depth_Ph~se Code-_ . Suhcode _ T COM _ 01/24/2008 00:00 00:30 0.50 9,408 9,408 INTRM1 CEME CIRC P Circulate and condition mud at 600 m at 2840 si. 00:30 00:45 .0.25 9,408 9,408 INTRMI CEME SFTY P PJSM on setting cement plug. 00:45 01:15 0.50 9,408 9,408 INTRM1 CEME DISP P Test lines to 2000 psi. Dowell pumped 25 bbls H2O, 43 bbls (207 sks) 15.8 cement, 3.5 bbls H2O and rig displaced with 82 bbls mud to balance lu .Blow down cement line. 01:15 02:30 1.25 9,408 8,452 INTRM1 CEME TRIP P POH on trip tank with 10 stds drill pipe to 8452'. 02:30 03:15 0.75 8,452 8,452 INTRM1 CEME CIRC X CBU at 600 gpm at 2520 psi. 03:15 04;45 1.50 8,452 6,928 INTRM1 CEME TRIP X POH on trip tank from 8452' to 6928'. 04:45 05:15 0.50 6,928 6,928 INTRM1 CEME CIRC X Spot 30 bbls hi-gel pill. 05:15 05:30 0.25 6,928 6,452 INTRM1 CEME TRIP X POH on trip tank with 5 stds drill pipe to 6452'. 05:30 06:30 1.00 6,452 6,452 INTRM1 CEME CIRC X Circulate and condition mud at 425 m at 1270 si. 06:30 07:00 0.50 6,452 6,452 INTRM1 CEME DISP X Tested lines to 2500 psi. Dowell pumped 25 bbls H2O, 50.8 bbls (288 C ~ ~ _ ~ ~ ~ ~O ` 1 ~ sks) 17 ppg cement, 3.5 bbls H2O and the rig displaced with 52 bbls mud to balance lu . 07:00 08:00 1.00 6,452 5,499 INTRM1 CEME TRIP X POH on trip. tank with 10 stds drill pipe to 5499'. 08:00 09:00 1.00 5,499 5,499 INTRM1 CEME CIRC X Circulate hole clean at 500 gpm at 1200 si. 09:00 12:00 3.00 5,499 930 INTRM1 CEME TRIP X POH on trip tank from 5499' to 3?" tbg at 930'. Pum ed d 'ob at 5976'. 12:00 13:00 1.00 930 930 INTRM1 CEMEI~ RURD X Rigged up to lay down tubing. PJSM 13:00 15:00 2.00 930 0 INTRM1 CEME PULD X POOH laying down tubing from 930' to surface. 15:00 15:15 0.25 0 0 INTRM1 CEME RURD X Rigged down tubing tools. 15:15 19:00 3.75 0 293 INTRM1 DRILL PULD X Picked up BHA and loaded nuke source. RIH with 1 stand and shallow tested tools. 19:00 20:15 1.25 293 2,747 INTRM1 DRILL TRIP X RIH from 293' to 2,747. 20:15 21:45 1.50 2,747 2,747 INTRM1 RIGMN' SVRG P Slipped and cut drilling line. Serviced To Drive. 21:45 23:00 1.25 2,747 4,076 INTRM1 DRILL PULD X RIH picked up 4"from pipe shed from 2,747 to 4,076'. 23:00 00:00 1.00 4,076 5,505 INTRMI DRILL TRIP X RIH from 4,076'to 5,505'. 01/25/2008 00:00 00:15 0.25 5,505 5,695 INTRM1 DRILL TRIP X RIH from 5,505' to 5,695'. 00:15 01:45 1.50 5,695 6,017 INTRM1 DRILL REAM X Washed and reamed from 5,695' to 6,017. Drilled cement stringers and cement from 5,855'. r~: ~{1 T `t ?i~ ____.._._.~.. -~..- ___. _- ___-_""""_.~__....._.._~.._..r Time Logs _ -- - _-- __-._-- -- Date From To Dur S. De th E. De th Phase Code Suhcode T _ COM 01/25/2008 01:45 12:00 10.25 6,017 6,552. INTRM2 DRILL KOST X Kicked off well and Drilled 8 3/4" hole w/ motor f/ 6,017' to 6,552' MD 5,121' TVD ADT 6.99 hrs RT 2.70 hrs ST 4.29 hrs WOB -18/20 RPM 100 GPM 650 @ 2930 psi String wt. PU 195 SO 145 Rot 170 Torque on/off btm.- 12,000/11,000 3 ( "' ~ ~ \ ft/Ibs ECD 10.35 KOP 6,017 0142 Hours 1/25!08. 12:00 00:00 12.00 6,552 7,408 INTRM2 DRILL Drilled 8 3/4" hole w/ motor f/ 6,552' to 7,408' MD 5,428' TVD ADT 8.64 hrs RT 5.89 hrs ST 2.75 hrs WOB -18/22 RPM 100 GPM 650 @ 2800 psi String wte PU 185 SO 145 Rot 165 Torque on/off btm.-12,000/11,000 ft/Ibs ECD 10.3 01/26/2008 00:00 12:00 12.00 7,408 8,298 INTRM2 DRILL DDRL X Drilled 8 3/4" hole w/ motor f/ 7,408' to 8,298' MD 5,716' TVD ADT 8.65 hrs RT 7.21 hrs ST 1.44 hrs WOB - 18/22 RPM 100 GPM 650 @ 3160 psi String wt. PU 192 S0 145 Rot 166 Torque on/off btm.- 12,500/11,500 fUlbs ECD 10.56 12:00 00:00 12.00 8,298 9,459 INTRM2 DRILL DDRL X Drilled 8 3/4" hole w/ motor f/ 8,298' to 9,459' MD 6,090' TVD ADT 9.15 hrs RT 7.32 hrs ST 1.83 hrs WOB - 18/24 RPM 100 GPM 650 @ 2400 psi String wt. PU 195 SO 145 Rot 168 Torque on/off btm.- 13,000/12,000 fUlbs ECD 10.58 0 INTRM2 DRILL 01/27/2008 00:00 12:00 12.00 9,459 10,455 INTRM2 DRILL DDRL X Drilled 8 3/4" hole w/ motor f/ 9,459' to 10,455' MD 6,435' TVD ADT 7.24 hrs RT 5.41 hrs ST 1.83 hrs WOB - 18/24 RPM 100 GPM 650 @ 3490 psi String wt. PU 200 SO 152 Rot 176 Torque on/off btm.- 12,000/11,000 ft/Ibs ECD 10.57 12:00 00:00 12.00 10,455 11,338 INTRM2 DRILL DDRL X Drilled 8 3/4" hole w/ motor f/ 10,455' to 11,338' MD 6,746' TVD ADT 8.59 hrs RT 7.72 hrs ST .97 hrs WOB - 15/20 RPM 100 GPM 650 @ 3500 psi String wt. PU 208 SO 164 Rot 180 Torque on/off btm.-11,500/10,000 ft/Ibs ECD 10.48 _ ~ ~~,ge 5 ct ?~~ ~! Time Logs ___ ' _ ----- --- From To Dur S Depth E. De t_h Pha e Code Subcode T COM.._ ____ <Date 01/28/2008 _ 00:00 00:30 0.50 11,338 11,407 INTRM2 DRILL DDRL X Drilled 8 3!4" hole w/ motor f/ 11,338' to 11,407 MD 6,772' TVD ADT .56 hrs RT .56 hrs ST 0.0 hrs WOB - 15/22 RPM 100 GPM 600 @ 3550 psi String wt. PU 210 SO 154 Rot 180 Torque on/off btm.-12,000/10,000 ft/Ibs ECD 10.50 00:30 02:00 1.50 11,407 11,407 INTRM2 DRILL CIRC X Circulate hole clean at 650 gpm - 3640 si -100 r ms. Obtain SPR's. 02:00 03:45 1.75 11,407 10,455 INTRM2 DRILL TRIP X POH with pump at 550 gpm - 2790 psi -100 rpms from 11,407' to 10,455'. Check flow. Blow down. 03:45 14:45 11.00 10,455 292 INTRM2 DRILL TRIP X POH on trip tank From 10,455' to 292'. 14:45 17:45 3.00 292 0 INTRM2 DRILL PULD X Downloaded LWD. Removed nukes and laid down BHA. 17:45 18:15 0.50 0 0 INTRM2 CEME RURD P PJSM and rigged up to pickup cement strip . 18:15 20:15 2.00 0 997 INTRM2 CEME PULD P Picked up and RIH 32 jts 3.5" tubing with muleshoe to 997'. 20:15 21:15 1.00 997 1,946 INTRM2 CEME PULD P Singled in 4" DP from pipe shed to 1,946'. 21:15 00:00 2.75 1,946 6,707 INTRM2 CEME TRIP P RIH with stands from derrick from 1,946' to 6,707'. 01/29/2008 00:00 02:00 2.00 6,707 11,278 INTRM2 CEME TRIP P Continue RIH w/ 4" DP from 6707' to 11,278'. 02:00 04:00 2.00 11,407 11,407 INTRM2 CEME CIRC P Break circulation. Wash from 11,278' to 11,407'. Circulate and condition mud at 650 gpm -3400 psi. Held PJSM for settin4 cement plugs while circulatin . 04:00 04:30 0.50 11,407 11,407 INTRM2 CEME- PLUG P Dowell pumped 5 bbls H2O. Tested lines to 3000 psi. Pumped 15 bbls H2O, 43 bbls 15.8 ppg cement (208 sks) and 4.5 bbls H2O. Rig displaced with 102 bbls 9.8 mud to balance lu . 04:30 05:15 0.75 11,407 10,896 INTRM2 CEME TRIP P OH on trip from 11,407'to 10.896'. 05:15 07:00 1.75 10,896 10,896 INTRM2 CEME CIRC P Circulate out cement contaminated mud at 12 b m - 2100 si. 07:00 07:45 0.75 10,896 10,896 INTRM2 CEME PLUG P Dowell pumped 5 bbls H2O. Tested lines to 3000 psi. Pumped 15 bbls H2O, 52 bbls 17.0 ppg cement (293. sks) and 4.5 bbls H2O. Rig displaced with 96 bbls 9.8 mud to balance lu . 07.45 08:30 0.75 10,896 10,135 INTRM2 CEME TRIP P n trip tank from 10,896' to 08:30 10:15 1.75 10,135 10,135 INTRM2 CEME CIRC P Circulate out cement contaminated mud at 12 bpm - 1980 psi -Flow ck static blow down TD 10:15 17:15 7.00 10,135 997 INTRM2 CEME TRIP P POOH on TT f/ 10,1.35' to 9468° - Pumped dry job - Bolw down TD - Continue POOH on TT f/ 9468' to 997 - Flow ck static 17:15 17:45 0.50 997 997 INTRM2 CEME OTHR P RU to LD 31/2', tbg stinger ?ncac• 9 rf 2:] j Time Logs -- _ - __ _ -- - _- -- _ Date From To Dur S. De th E. Depth Phase Code Subcode T COM __ 01!29/2008 17:45 18:00 0.25 997 997 INTRM2 CEME~ SFTY P PJSM on laying down 31/2" tbg 18:00 19:30 1.50 997 0 INTRM2 CEME PULD P Pull & LD 3 1/2' tbg stinger (32 jts) - RD 19:30 20:00 0.50 0 0 INTRM2 WELCT OTHR P Pull wear bushing -Set test plug 20:00 00:00 4.00 0 0 INTRM2 WELC BOPE P RU & test BOPE - Testedannular to 250 & 2500 psi -Choke manifold valves -top pipe rams - TD IBOP's - Dart & floor safety valves to 250 & 3500 si 01/30/2008 00:00 02:00 2.00 0 0 INTRM2 WELCT BOPE P Continue to test BOPE. Test manual choke and kill lines and lower pipe rams. MU 5" test jt and test upper pipe rams. LD test jt. Test blind rams. All test 250 psi - 3500 psi. Witness of the test was waived by AOGCC rep John Cris . 02:00 02:45 0.75 0 0 INTRM2 WELC OTHR P Install wear bushing. Blow down all test a ui ment. 02:45 04:30 1.75 0 81 INTRM2 DRILL PULD P MU bit, motor and MWD assembly. Chan a out motor kick late. 04:30 05:00 0.50 81 81 INTRM2 DRILL OTHR T Upload MWD. Would not initialize. 05:00 05:30 0.50 81 81 INTRM2 DRILL PULD T Change out pulser. 05:30 06:00 0.50 81 81 INTRM2 DRILL OTHR P Upload MWD. 06:00 06:45 0.75 81 721 INTRM2 DRILL TRIP P Shallow test MWD. OK. RIH with HWDP and 'ars. 06:45 08:00 1.25 721 2,624 INTRM2 DRILL TRIP P RIH with 20 stds 5" DP to 2624'. Fill i e and blow down, 08:00 08:15 0.25 2,624 2,624 INTRM2 RIGMN SFTY P PJSM on slip and cut drilling line. 08:15 10:30 2.25 2,624 2,624 INTRM2 RIGMN SVRG P Slip and cut drilling line. Service top drive. 10:30 14:30 4.00 2,624 9,952 INTRM2 DRILL TRIP P RIH f/ 2624' to 2812' w/ BHA & 5" DP - Chnage handling equipment. to 4" - Continue RIH f/ 2812' to 9952' -took wt. 14:30 15:15 0.75 9,952 10,168 INTRM2 DRILL REAM P Wash down f/ 9952' to 1016_ 8, (tag cmt - 550 gpm @ 2950 psi w/ 50 m's 15:15 16:45 1.50 10,168 10,275 INTRM2 DRILL OTHR P Polish off cmt plug f/ 10,168' to 10,275' - 550 m 3100 si w/ 50 m's 16:45 00:00 7.25 10,275 10,568 INTRM2 DRILL KOST P Time drill 8 3/4" hole w/ motor off cmt I f/ 10 275' to 10 29T WOB 15/20 k -GPM 550 @ 3100 psi Drill 8 3/4" hole w/ motor f/ 10,29T to 10568° MD 6467 ND WOB 15/ 20 RPM 80 GPM 550 @ 3250 psi String wt. PU 200 SO 150 Rot 175 Tor ue on/off btm - 10,000/8,500 ft/Ibs -- - - -- -- _ Page=. 1 ~l cf 20 _~ ~1 Time Logs ____ ,_ _ ___ __ _ Dare From To Dur _ S. Depth E. Depth Phase Code Subcod~ T COM. 01/31/2008 00:00 10:15 10.25 10,568 11,199. INTRM2 DRILL DDRL P Drill 8 3/4" hole w/ motor fL 10,568' to 11,199' MD 6643' TVD ADT=6.49 hrs ART=5.14 hrs AST=1.35 WOB 15/ 20 RPM 80 GPM 550 @ 3210 psi String wt. PU 200 SO 150 Rot 175 Tor ue on/off btm -10,000/8,500 ft/Ibs 10:15 10:45 0.50 11,199 11,199 INTRM2 DRILL DDRL T Trouble shoot MWD failure with no success. Only data to surface was resistivi 10:45 12:30 1.75 11,199 10,523 INTRM2 DRILL TRIP T Flow check (static) POOH w/ pump & backreaming f/ 11,199' to 10,523' - 550 gpm @ 2500 psi w/ 80 rpm's -flow check static 12:30 14:15 1.75. 10,523 10,332 INTRM2 DRILL CIRC T Circ 2 X btms up @ 600 gpm @ 2980 psi w/ 80 rpm -standing back 2 stds DP to 10,332' -flow check static 14:15 21:45 7.50 10,332 2,740 INTRM2 DRILL TRIP T POOH on TT f/ 10,332' to 2740' (4" DP hole took ro er fill 21:45 00:00 2.25 2,740 719 INTRM2 DRILL. TRIP T Changeover to 5" handling equipment - Continue POOH w/5" DP on TT f/ 2740' to 719'. (top of HWDP) Flow check static 02/01/2008 00:00 00:30 0.50 719 81 INTRM2 DRILL TRIP T POH on trip tank with HWDP. jars and NMFC's. 00:30 02:00 1.50 81 0 INTRM2 DRILL PULD T Download MWD. LD MWD tools, motor and bit. Bit had one plugged nozzle. 02:00 02:45 0.75 0 81 INTRM2 DRILL PULD- T MU bit, motor and back-up MWD tools. 02:45 03:45 1.00 81 81 INTRM2 DRILL OTHR T Upload and orient MWD. 03:45 04:45 1.00 81 719 .. INTRM2 DRILL TRIP T RIH with 1 std HWDP. Shallow test MWD. Continue RIH w/HWDP and 'ars. 04:45 11:00 6.25 719 11,094 INTRM2 DRILL TRIP T RIH w/ 22 stds 5" DP. Change elevators. Continue RIH with 4" DP to 11,094'. 11:00 12:00 .1.00 11,094 11,199 INTRM2 DRILL REAM T Break circulation. Wash and ream from 11,094' to 11,199'. 12:00 00:00 12.00 11,199 11,622 INTRM2 DRILL DDRL P Drill 8 3/4" hole w/ motor f/ 11,199' to 11;622' MD 6725' TVD ADT - 8046 hrs =ART - .66 hrs AST - 7.8 hrs ECD-10.0 ppg WOB 15/20 RPM 80 GPM 550 @ 3000 psi Torque on/off btm.-12,000/11,000 ft/Ibs P~y~. 9'f cf Zu ~ Time Logs _ _ _ From To Dur S De th E. De th-Phase Ccde Subcgde T COM _ _ _ Dace _ __ 02/02/2008 _ 00:00 01:00 1.00 11,622 11,690 INTRM2 DRILL DDRL P Drill 8.3/4" hole w/ motor f/ 11,622' to 11 690' MD 6727' TVD ADT - 0.77 hrs =ART - 0.0 hrs AST - 0.77 hrs ECD- 11.0 ppg WOB 20 RPM 80 GPM 550 @ 2800 psi String wt. PU 220 SO 140 Rot 175 Torque on/off btm.- 12,000/11,000 ft/Ibs 01:00 04:30 3.50 11,690 11,094 INTRM2 DRILL CIRC P .Circulate 3 bottoms up at 525 gpm - 2450 psi - 80 rpms. Set back one stand every 30 min to 11,094'. Check flow static 04:30 05:45 1.25 11,094 10,522 INTRM2 DRILL WPRT P POH with pump from 11,094' to 10,522' at 525 gpm - 2450 psi - 80 r ms. Check flow static 05:45 06:15 0.50 10,522 11,655 INTRM2 DRILL WPRT P RIH from 10,552'to 11,665'. 06:15 06:30 0.25 11,655 11,690 INTRM2 DRILL WPRT P Break circulation. Wash and ream from 11,655'to 11,690'. 06:30 08:45 2.25 11,690 11,474 INTRM2 DRILL CIRC P Circulate 2 bottoms up at 525 gpm - 2600 psi - 80 rpms. Increase mud wt to 9.8 ppg. Set back one stand every 30 min to 11,474' 08:45 09:00 0.25 11,474 11,665 INTRM2 DRILL TRIP P RIH from 11,474'to 11,665'. 09:00 09:30 0.50 11,665 11,690 INTRM2 DRILL REAM P Wash and ream from 11,665' to 11,670'. Tight hole. Set back stand.. MU sin le. Wash and ream to 11,690'. 09:30 09:45 0.25 11,690 11,690 INTRM2 DRILL CIRC P Spot WBSP and. CLP to bit. 09:45 12:00 2.25 11,690 11,554 INTRM2 DRILL TRIP P POH spotting tube pill across formation from 11,690' to 11,554' - 3.5 BPM @ 670 psi - PU wt 225 SO wt. 145 -Flow check (static) blow down TD 12:00 19:15. 7.25 11,554 2,740 INTRM2 DRILL TRIP P POOH on TT f/ 11,554' to 2740' (top 5" DP) -Pumped dry job @ 9474' - worked through tight spots @ 7840' & 3400' -Flow check 2740' -static 19:15 21:45 2.50 2,740 174 INTRM2 DRILL TRIP P Change over to 5".handling equipment -Continue POOH on TT f/ 2740'to 719' (top of HWDP) -Flow check (static) - SB HWDP & LD jars f/ 719' to 174' 21:45 23:45 2.00 174 0 INTRM2 DRILL PULD P LD NMDC's -Pull up & break bit while down loading MWD - LD MWD & motor 23:45 00:00 0.25 0 0 INTRM2 DRILL OTHR P Clean up & clear rig floor 02/03/2008 00:00 01:00 1.00 0 0 INTRM2 WELCT EQRP P PJSM. Chan a to i e rams from 3?"x6" VBR's to 7" i e. 01:00 01:30 0.50 0 0 INTRM2 WELCT OTHR P Pull wear bushing: Set test plug. 01:30 02:00 0 50 0 0 INTRM2 WELC BOPE P RU test a ui ment. t . to 250-3500 si. Good test. Pa~,e: 12 c;f ~ ~ Time Logs _ _ _ _ ,Date From To Dur_ 5: De^th E Decth,Phase :. Code . Subcode T CON1 __ _ _ _ 02/03/2008 02:00 02:30 0.50 0 0 INTRM2 WELC OTHR P RD test equipment. Set thin wear bushin . 02:30 03:45 1.25 0 0 INTRM2 CASIN RURD P Rig up 7" csg running equipment. 03:45 04:00 0.25 0 0 INTRM2 CASIN( SFTY P PJSM with all personnel on running 7" cs . 04:00 07:30 3.50 0 2,751 INTRM2 CASIN RNCS P Run 7" 26# L-80 BTCM as follows: FS( Ray Oil Tools Silver Bullet) 2 jts. csg - FC (Halliburton Super Seal) 2 jts, csg ( First four jts. made up w/ BakerLoc - fill pipe & check floats) 61 jts csg (65 'ts total to 2751' 07:30 08:00 0.50 2,751 2,751 INTRM2 CASIN CIRC P Circulate 1 pipe volume at 5 bpm - 360 si. 08:00 12:30 4.50 2,751 6,550 INTRM2 CASINC RNCS P Continue running 7" 26# L-80 BTCM cs f/ 2751' to 6550' 155 'ts total 12:30 13:30 1.00 6,550 6,550 INTRM2 CASINC CIRC P Establish circ & stage pump up to 4.5 BPM -Circ btms up +ICP 490 psi FCP 420 si 13:30 18:00 4.50 6,550 10,378 INTRM2 CASIN RNCS P Continue running 7" 26# L-80 BTCM csg f/ 6550'to 10378' - PU wt. 315 SO wt. 150 18:00 20:00 2.00 10,378 10,378 INTRM2 CASIN CIRC P Establish circ & stage pump up to 4.5 BPM -Circ btms up + ICP 630 @ 2 BPM -FCP 550 si 4.5 BPM 20:00 21:30 1.50 10,378 11,680 INTRM2 CASINC RNCS P Finish running 7" 26# L-80 BTCM csg f/ 10,378' to 11,646' (275 jts total) - PU FMC fluted hanger & landing jt -Land csg in wellhead on fluted hanger w(FS 11,679.66' & FC 11,592.47 21:30 22:00 0.50 11,680 11,680 INTRM2 CEME~ RURD P LD fill up tool -Blow down TD - MU Cmt head & lines 22:00 00:00 2.00 11,680 11,680 INTRM2 CEME~ CIRC P Establish circ @ 1 BPM & stage pump up to 5 BPM @ 590 psi -Circ & condition for cmt'ob 02/04!2008 00:00 01:00 1.00 11,680 11,680 INTRM2 CEME CIRC P Continue circulate and conditon mud at 5 bpm at 480 psi. Reciprocate i e. U wt= 330k Dn wt=150k. 01:00 01:15 0.25 11,680 11,680 INTRM2 CEME~ SFTY P PJSM on cementing 7" csg. s Time Logs - Date From To _. Dur ____-.- S. De th_ E. De~th_ Phase Code Subcode _ T COM _ __ 02/04/2008 01:15 03:30 2.25 11,680 11,680 INTRM2 CEME DISP P Cemented 7" casing as follows: Pump 5 bbls CW 100 -Test lines to 3700 psi - Pump 35 bbls CW--100 @ 3.2 bbls/min @ 350 psi -Pump 40 bbls MudPush @ 12.5 ppg @ 4.2 bbls/min @ 450 psi -Dropped btm plug -.Mix & pump 48 bbls (226 sks) 15.8 ppg tail slurry (Class G w/ .2% D046, .25% D065, .25% D800,.18% D167) @ 4.6 bbls/min @ 285 psi -Drop top plug w/ 20 bbls water f/ Dowell -Switched over to rig pumps & displaced w/ 422 bbls 9.8 mud @ 6 bbls/min @ 460 psi & slowed pumps to 3.5 bbls/min @ 440 for the last 32 bbls -Bumped plug w/ 1000 psi - CIP @ 0325 hrs. -Checked floats OK -Full returns through iob - Reciprocated i e until PU wt. was beginning to be excessive 40 bbls into dis lacement 03:30 04:15 0.75 11,680 11,680 INTRM2 CASIN DHEQ P RU and test 7" csg to 3500 psi for 30 min. Good test 04:15 05:00 0.75 11,680 11,680 INTRM2 CASINC RURD P RD casing and cement equipment. 05:00 06:00 1.00 0 0 INTRM2 CASINC OTHR P Pull thin wear bushing. Install 7" ack-off and test to 5000 si. 06:00 07:30 1.50 0' 0 INTRM2 WELC EQRP P PJSM. Change top pipe rams from 7" to 3~" x 6 VBR's. 07:30 08:30 1.00 0 0 INTRM2 WELC BOPE P RU and test upper VBR's with 4"and 4?" test 'ts to 250 -3500 psi. (Good test 08:30 09:00 0.50 0 0 INTRM2 WELC OTHR P Pull test plug. Install wear bushing. 09:00 09:30 0.50 0 0 INTRM2 RIGMN SVRG P Service top drive and accumulator s stem. 09:30 12:00 2.50 0 376 INTRM2 DRILL PULD P PU Powerdrive. MU bit. Surface test Powerdrive at 210 gpm - 500 psi. MU Periscope, MWD, PWD, NMFC's, XO, HWDP and'ars to 376'. 12:00 14:30 2.50 376 2,000 INTRM2 DRILL TRIP P RIH f/ 376' to 2000' -picking up 4" DP f/ i e shed 14:30 16:00 1.50 2,000 2,000 INTRM2 DRILL OTHR P Shallow test MWD - 230 gpm @ 100 si 16:00 19:15 3.25 2,000 5,409 INTRM2 DRILL TRIP P Continue RIH f/ 2000' to 5409' - picking up 4" DP f/pipe shed -fill pipe eve 20 stds 19:15 22:15 3.00 5,409 11,409 INTRM2 DRILL TRIP P Continue RIH w/ DP f/derrick f/ 5409' to 11409' - fillip i e eve 20 stds. 22:15 23:45 1.50. 11,409 11,409 INTRM2 RIGMN SVRG P PJSM on cut & slip drill line -Cut & sli drill line 90' 23:45 00:00 0.25 11,409 11,430 INTRM2 DRILL REAM P Wash down f/ 11,409' to 11,430' @ 210 m 1620 si 02/05/2008 00:00 00:30 0.50 11,430 11,577 INTRM2 DRILL REAM P Continue to wash down from 11430' to 11577 (tag top of cmt) @ 210 gpm & 1620 si • • Time Logs ____ __ _ e__ T COM _ __ Date From To Dur S De th E. De th..Phas ._ Code Subcod 02/05/2008 00:30 03:30 3.00 11,577 11,690 INTRM2 CEMEf` _ _ DRLG _ P Clean out cmt & wiper plugs f/ 10,577 to 11,593' (top of FC) drill FC & cmt to 11,678' (top of FS) -drill out FS to 11,980' & clean out rat hole to 11,690' 03:30 03:45 0.25 11,690 11,710 INTRM2 DRILL DRLG P Drill 6 1/8" hole f/ 11,690' to 11,710' MD - 6726' TVD ADT .25 hrs ECD 10.4 ppg RPM 85 WOB 2/5 GPM 210 @ 1600 si 03:45 04:45 1.00 11,710 11,710 INTRM2 DRILL CIRC P Circ hole clean for FIT - 235 gpm @ 1920 si w/ 90 r m 04:45 05:30 0.75 11,710 11,710 INTRM2 DRILL FIT P RU & erform FIT to 12.5 ppg EMWw/ 1020 psi w/ 9.6 ppg mud @ 6726' TVD - RD -Blow down lines 05:30 07:00 1.50 11,710 11,710 PROD1 DRILL CIRC P Change well over f/ 9.6 ppg LSND to 9.2 ppg FloPro @ 235 gpm @ 1940 psi w/ 90 rpm -Clean up @ shakers & monitor well - sli ht oozin 07:00 12:00 5.00 11,710 11,800 PROD1 DRILL DDRL P Drill 6 1/8 "horizontal section f/ 11,710' to 11,800' MD 6732' TVD ADT 2.17 hrs. ECD - 10.4 ppg WOB 5/10 RPM 83/100 GPM 235 @ 1930 psi String wt. PU 190 SO 145 Rot 165 Torque on/off btm. - 9,000/8,000 ft/Ibs Well static on connections " Note- Drilled out btm of Kup. C @ 11 740' - Attem tin to bulid an le 12:00 20:45 8.75 11,800 11,905 PROD1 DRILL DDRL P Drill 6 1/8" horizontal section f/ 11,800' to 11,905' MD 6728' TVD ADT - 8.75 hrs ECD-10.49 ppg WOB 2/8 k RPM 80 GPM 235 @ 1940 psi String wt. PU 190 SO 145 Rot 167 Torque on/off btm.- 9,000/8,000 fUlbs. Well static on connections Attempting to build angle to get back into Kup C - No success Discission made to tri for motor 20:45 22:00 1.25 11,905 11,599 PROD1 DRILL CIRC T Circ btms up for sample @ 235 gpm @ 1900 psi -std back 4 stds to 1599' - Flow Ck Static 22:00 23:00 1.00 11,599 10,647 PROD1 DRILL TRIP T POOH w/pump f/11,599' to 10,647' @ 210 m 1460 si -Flow ck Static 23:00 00:00 1.00 10,647 10,647 PROD1 DRILL CIRC T Circ & bump mud wt. to 9.4 ppg for tri mar in 235 m 1800 si 02!06/2008 00:00 01:30 1.50 10,647 10,647 PROD1 DRILL CIRC T Circulate and increase mud wt: to 9.4 ppg for trip - 235 gpm / 1800 psi - seroice ri -flow check well, static 01;30 10:00 8.50 10,647 376 PROD1 DRILL TRIP T POOH on trip tank from 10,647' to 376' -flow checked well @ 662' for 10 min., static 10:00 10:30 0.50 376 96 PROD1 DRILL TRIP T Stand back HWDP and tVM flex DC's ~_ r= psi: 15 cf 2:) j • _Time Lo s -- 9 - -- ------ - -- Date From To Dur 5 De th E De th Phase Code Subcode T COM _ 02/06/2008 10:30 14:15 3.75 96 366 PROD1 DRILL PULD T LD MWD -Periscope -power drive & bit -Down load tools & load for next run - MU BHA #7 -bit - motor w/ 1.83 bend -Periscope -MWD - RIH w/ NM flex DC's -Jars & HWDP to 366' 14:15 17:15 3.00 366 6,066 PROD1 DRILL TRIP T RIH w/ BHA #7 on 4" DP f/ 366' to 6066' 17:15 17:45 0.50 6,066 6,066 PROD1 RIGMN SVRG T Monitor well on TT -Service rig - Chan a li hts in derrick 17:45 20:45 3.00 6,066 11,759 PROD1 DRILL TRIP T Continue RIH f/ 6066' to 11,759' - strin took wt. 20:45 00:00 3.25 11,759 11,905 PROD1 DRILL REAM T Orient motor to high side -attempt to slide in hole f/ 11,759' -unable to slide - Wash & ream f/ 11759' to 11,905' - hole packing off w/ 235 gpm @ 1970 siw/60 RPMw/Oto7kWOB 02/07/2008 00:00 10:00 10.00 11,905 11,969 PROD1 DRILL DDRL P Time Drill 6 1/8 "horizontal section w/ motor f/ 11,905' to 11,969' MD 6729' TVD ADT 10.11 hrs. ART 0 AST 10.11 hrs. ECD 10.4 ppg WOB 1/7 RPM 0 GPM 235 @ 1940 psi String wt. PU 195 SO 145 Rot 165 Tor ue on/off btm. -10,500/8,500 ft/Ibs 10:00 12:00 2.00 11,969 11,996 PROD1 DRILL DDRL P Drill 6 1/8 "horizontal section w/ motor f/ 11,969' to 11,996' MD 6729' TVD ADT 0.51 hrs. ART 0.21 AST 0.30 hrs. ECD 10.4 ppg WOB 2/12 RPM 40 GPM 240 @ 2040 psi String wt. PU 195 SO 145 Rot 165 Tor ue on/off btm. -10,500/8,500 ft/Ibs 12:00 22:15 10.25 11,996 12,327 PROD1 DRILL DDRL P Drill 6 1/8" horizontal section w/motor f/ 11996' to 12,327' MD - 6708' TVD ADT- 5.72 hrs =ART- 2.87 hrs AST- 2.85 hrs. ECD-10.56 ppg WOB 5/10 k RPM 30 GPM 223 @ 2080 psi String Wt. PU 200 SO 135 Rot 165 Torque on/off btm.- 11,000/10,500 ft/Ibs Made MADD pass f/ 11,975' to 12,026' & f/ 12,192 to 12,553' Hol - - BPH loss r e 22:15 00:00 1.75 12,327 12,327 PROD1 DRILL OTHR T Lost returns 12 327' -Slow pump rate to 1.5 bbl/min -Mix LCM pill - 25#/bblsfine nut plug & medium dynared -Pump pill @ 1.5 bbls/min - Lost 337 bbls 9.2 FloPro to formation Time Logs - __- ~ Date From To D ur 5 De th E. De th Phase Code Subcode T COM ~ 02/08/2008 00:00 00:30 _ 0.50 12,327 12,327 _ PROD1 __ DRILL OTHR T Continue to pump 25 LB/BBL LCM pill. Established returns. Staged um to 231 GPM 2000 si 00:30 10:15 9.75 12,327 12,515 PROD1 DRILL DDRL P Drill 6 1/8" horizontal section w/motor f/ 12,327' to 12,515' MD - 6,714' TVD - TD. ADT- 6.41 hrs, ART- 2.59 hrs, AST- 3.82 hrs, ECD-10.56 ppg. WOB 2/10 k RPM 30 GPM 235 @ 2350 psi String Wt. PU 195 SO 135 Rot 170 - Torque on/off btm.-11,000/10,000 ft/Ibs 10:15 12:00 1.75 12,515 12,515 PROD1 DRILL CIRC P Circulate BU @ 235 GPM, 2040 PSI 50 - 80 RPM Losses to well midni ht -noon 647 bbls of 9.3 Flo- ro 12:00 16:00 4.00 12,515 11,688 PROD1 DRILL TRIP P Flow check well, slight breathing - static in 5 minutes -POOH from 12,515' to 11,688' - 235 gpm / 1830 psi / 40 rpm -Obtain MAD pass log as requested -164' total @ 100 fph - wiped tight spots clean @ 12,405' and . 11,745' - no other problems -losses ave - 70 b h 16:00 17:30 1.50 11,688 11,688- PROD1 DRILL CIRC P Circulate and strip LCM from mud - 210 gpm ! 1700 psi / 50 rpm -Mud wt. in & out @ 9.3 ppg -Flow check well - static losses @ 8-10 bph Dro hallow drift 17:30 18:45 1.25 11,688 10,732 PROD1 DRILL TRIP P Continue POOH f/11,688' to 10,732' w/ pump @ 147 gpm @ 900 psi - PU wt. 195 - SO wt. 155 -Blow down TD 18:45 19:00 0.25 10,732 10,732 PROD1 DRILL OTHR P Monitor well on TT -static losses @ 16.5 BPH 19:00 00:00 5.00 10,732 4,638 PROD1 DRILL TRIP P Continue POOH on TT f/ 1.0,732' to 4,638' Lost 504 bbls 9.2 FloPro f/noon to midni ht 02/09/2008 00:00 02:30 2.50 4,638 366 PROD1 DRILL TRIP P Continue POOH. on TT f/ 4,638' to 366' - Monitor well 651' losses 30 b h 02:30 03:45 1.25 366 0 PROD1 DRILL PULD P LD HWDP ,jars, NM flex DC's, MWM, periscope, bit and motor -clean up rig floor 03:45 04:15 0.50 0 0 COMPZ RPCOh RURD P RU to run 41/2" Liner-Monitor well on TT -Losses 19 b h 04:15 04:30 0.25 0 0 COMPZ RPCOh SFTY P Held pre-job Safety and Opts meeting with crew Pa:;n 1? of ~: ~ ~ Time Logs Date From To Dur S. De fh,.E. De th_.Phase Code-- Subcode . T COM -- - -- - 02/09/2008 04:30 05:30 1.00 0 925 COMPZ RPCOh PULD P RU & Run 4 1/2", 12.6#, L-80 SLHT liner as follows: Baker guide shoe - 3 jts blank - 7 jts slotted. (32 slots/ft x 2 1/4" x 1/8"slots) - 3 jts blank -1 jt slotted 32 slots/ft x 2 1/4" x 1/8" slots) 5 jts blanks - 2 jts. slotted 32 slots/ft x 2 1/4" x 1/8" slots) - 2 jts blank - 23 'ts total 05:30 07:30 2.00 925 955 COMPZ RPCOti PULD P PU Baker Flex-Lock Liner hanger assembly - PU Schlumberger SCMT_ tools and MU to han er assembl - MU hanger assembly-Liner and hanger -total liner 955.55' -Mix Pal Mix & fill liner tie back -wait on PalMix to set u 07:30 16:00 8.50 955 12,505 COMPZ RPCOti RCST P RIH w/liner on 4" DP f/ 955'. tag btm @ 12515' Pull up to setting depth @ 12,505' -top of liner @ 11,548,45' , Loss rate 15 BPH 16:00 18:00 2.00 12,505 11,512 COMPZ RPCOb CIRC P Establish circulation and pump drill pipe volume @ 4 bpm / 700 psi -Drop liner-setting ball & pump down to seat - Pressure up to 800 psi -pressure up to 2100 psi to set liner hanger -Slack off to 95 K to confirm hanger set OK - Bleed off pressure -Pull up to 225 k OK -Slack off to 110 k -Pressure up to 3500 psi to release f/liner -Pull running tool free f/ liner & pull up to 11,512' 18:00 20:45 2.75 11,512 10,180 COMPZ EVALW DLOG P POOH w/pump & run SCMT f! 11,512' to 10 180' - 2.5 bbls/min @ 580 psi - Blow down TD '20:45 21:30 0.75 10,180 9,229 COMPZ DRILL TRIP P POOH on TT f/ 10,180' to 9229' 21:30 21:45 0.25 9,229 9,132 COMPZ EVAL DLOG P POOH f/ 9229' to 9132' -Run SCMT - Pump 2.5 bbls/min @ 510 psi -Blow down TD Log run to evaluate 7" cmt job com lete 21:45 00:00 2.25 9,132 6,448 COMPZ DRILL TRIP P Continue POOH w/ liner running tool & SCMT f/ 9132' to 6848' Lost 404 bbls 9.2 FloPro last 24 hrs. 02/10/2008 00:00 03:30 3.50 6,448 78 COMPZ RPCO TRIP P Continue POOH w/liner running tool & SCMT f/ 6848' to 78' 03:30 04:30 1.00 78 0 COMPZ RPCOh RURD P I_D Schlumberger SCMT logging tools and Baker Liner han er runnin tool 04:30 06:00 1.50 0 0 COMPZ RIGMN SVRG P PJSM, Cut and slip drill line. service To Drive and Drawworks 06:00 06:45 0.75 0 0 COMPZ RPCOti OTHR P Pull wear bushing -set retrievable Com letion wear bushin Fa;{c 1 S rt 2 Time Logs _ _ _ Date From To Dur S,_D_e th E_ D~th_Phase-.,.Code Subcede _T COM ___ 02/10/2008 06:45 08:15 1.50 0 0 COMPZ RPCOCV OTHR P Move Completion equipmenYto rig floor - RU to run Completion -Monitor well, static losses 10 BPH 08:15 08:30 0.25 0 0 COMPZ RPCOti SFTY P Held Pre-job Safety and Opts meeting with crew and Baker hands 08:30 10:30 2.00 0 1,030 COMPZ RPCOCV RCST P Run 4 1/2" completion (all tbg & pups 41/2" 12.6# IBTMod tbg except gauge carrier assy and 4 joints of 4 1/2" ST-L tbg.) as follows: WLEG - pup jt. - Fluted locator sub - pup jt.- 15 jts tbg - XN nipple -1 jts. tbg - pup jt. -Baker Premier packer.- pup jnt. 2 jts. tbg - pup jt. -Camco GLM w/shear valve - pup jnt. - 2 jts tbg - xo - 2 jts ST-L tbg. - pup jnt. -gauge carrier - pup jnt - to 1030' 10:30 11:15 0.75 1,030 1,030 COMPZ RPCOti DHEO P Attach encapsulated control line to gauge -pressure test connection to 7000 si for 10 mins. 11:15 11:30 0.25 1,030 1,030 COMPZ RPCO SFTY P Held PJSM on running control & installin Cannon clam s 11:30 00:00 12.50 1,030 9,435 COMPZ RPCOh RCST P Continue RIH w/ 4 1/2" completioin - 2 jts. 4 1/2" 12.6# L-80 STL tbg - XO(STL x IBT) HES X nipple -191 jts 41 /2" 12.6# L-80 I BTM tbg - to 9435' - PU Camco Bal-O ni le 02/11/2008 00:00 00:30 0.50 9,435 9,435 COMPZ RPCOti RCST P Attach single control line to Bal-O Landing Nipple -test control line and fittin to 5000 si 00:30 06:15 5.75 9,435 11,559 COMPZ RPCOh RCST P Continue RIH w/ 4 1/2", 12.6# L-80 IBTM tbg -Locate TOL with shear out pins and no-go sub - PU and MU s ace out u s and 'oints 06:15 07:15 1.00 11,525 11,525 COMPZ RPCO OTHR P MU wear bushing retrieving tool -RIH - Pullwear bushing - LD retrieving toot - stri wear bushin out 07:15 09:30 2.25 11,525 11,556 COMPZ RPCOti RCST P MU FMC tubing hanger -strip control lines through hanger -test each tie back fitting to 5000 psi -land hanger in wellhead w/ WLEG @ 11,556' - XN nipple @ 10,885' ,packer @ 10,824', GLM @ 10,710', Baker gauge carrier @ 10,519', X nipple @10,428', Bal-O ni le 2,125' 09:30. 10:30 1.00 11,556 11,556 COMPZ RPCOh DHEO P RILDS - LD LJa -Install TWC - MU LJb -test hanger M/M seals to 5000 si - ood 10:30 13:45 3.25 11,556 0 COMPZ RPCOti NUND P Clean floor drip pans - ND flowline - ND BOPE & Set back - LD mouse hole - chan a elevators to 4" DP 13:45 16:30 2.75 0 0 COMPZ RPCOh NUND P Terminate control lines for SSSV & Baker down hole pressure gauge through well head - (Change out saver sub in TD & work on grab heads - RU sgeeze manifold & line on rig floor ... while Baker & FMC working on wellhead _Time Logs __ _-- - _- __-- Date From To Dur. .- 5. Depth E. Depth Phase Code Sribc_ode T COM _ ~ 02/11/2008 16:30 17:30 1.00 0 0 COMPZ RPCOh NUND P NU tree & test tree to 5000 psi OK - Pull TWC 17:30 22:30 5.00 0 0 COMPZ RPCOti CIRC P MU hardlines to wellhead - PJSM w/ crew on displacement -Establish Circ -test lines to 2500 psi -Pumped 40 bbls High-Vis brine pill followed by 11D bbls. 93.ppg brine -Switch to Dowell - Test lines to 2500 psi -Pumped -198 bbls 9.2 ppg inhibited brine followed by 221 bbls diesel (tbg vol + 1600' annular voulme ) 22:30 00:00 1.50 0 0 COMPZ RPCO PACK P RU lubricator & drop packer setting ball/roller bar assembly - RD lubricator - Test lines to 5000 psi - Pressrue up on tb to 4800 si to set acker & test tb for 30 mions. 02/12/2008 00:00 00:30 0.50 0 0 COMPZ RPCOh DHEQ P Tested Annulus to 3500 si for 30 min. Test ood. 00:30 01:15 0.75 0 0 COMPZ RPCOh DHEQ P Bleed pressure in tubing and sheared out valve in GLM. Blew down lines. 01:15 03:00 1.75 0 0 COMPZ RPCOh RURD P Set BPV with lubraator. Rigged down lines and secured well. 03:00 10:30 7.50 0 0 COMPZ DRILL PULD P Laid down 219 jts 4" DP from derrick to i eshed via mousehole. 10:30 12:00 .1.50 0 0 COMPZ DRILL RURD P Changed saver sub and rigged down. Rig released to move @ 1200 hrs 2/12/08. f~.l ~i l: iU !i~ ~~ Halliburton Company Survey Report Cun;pang: ConecoPhillips Alaska Inc. I)atc ?!15!2008 Time: 16:08.56 1'a~c I Field: Colville River Unit Cb-o rdinate(NE) Reference: Well: CD3-316, True North Site: Fiord CD3 Vertical (TVD) Reference: CD3-316 49.5 • 'I Well: CD3-316 ~~ cllpath: CD3-316A Section (VS) Reference:.... Well (O.OON,O.OOE,93.34Azi) Survey Calculation Method: Minimum Curvature Db: t~racle Field: Colville River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: CD3-316 Slot Name: 50-103-20559-00 Well Position: +N/-S -86.18 ft Northing: 6003806.84 ft Latitude: 70 25 9.633 N +E/-W -415.41 ft Easting : 388071.48 ft Longitude: 150 54 42.572 W Position Uncertainty: 0.00 ft Wellpath: CD3-316A Drilled From: CD3-316AP61 50-103-20 559-01 Tie-on Depth: 10226.76 ft Current Datum: CD3-316 Height 49.50 ft Above System Datum: Mean Sea Level ( Magnetic Data: Field Strength: 1/15/2008 57584 nT Declination: 22.35 deg Mag Dip Angle: 80.75 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 36.30 0.00 0.00 93.34 Survey Program for Definitive Wellpath Date: 2/15/2008 Validated: No Version: 2 Actual From To Survey Toolcode Tool Name ft ft 81.00 442.00 CD3-316 Gyro (81.00-442.00) (1 CB-GYRO-SS Camera based gyro single shot 511.39 6017.00 CD3-316 MWD+SAG+IIFR+CA+MS (51 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6017.00 10275.00 CD3-316AP61 MWD+SAG+IIFR+CA+MS MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 10275.00 11648.83 CD3-316A IIFR Halliburton (102 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 11730.57 12446.62 CD3-316A IIFR SChl umberger (11 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey ~1D Incl Azim I~VU Sps CVD \/5 F:n~~ ,MapN MapE -Cool ft deg deg ft ft ft ft ft ft _. 36.30 0.00 0.00 36.30 -13.20 ~ _ 0.00 0.00 _ - _ 6003806.84 • 388071.48 • _ TIE LINE 81.00 0.50 96.00 81.00 31.50 -0.02 0.19 6003806.82 388071.67 CB-GYRO-SS 170.00 0.75 89.00 169.99 120.49 -0.05 1.16 6003806.77 388072.64 CB-GYRO-SS 261.00 0.47 186.50 260.99 211.49 -0.41 1.72 6003806.40 388073.19 CB-GYRO-SS 352.00 0.85 238.00 351.99 302.49 -1.14 1.10 6003805.68 388072.56 CB-GYRO-SS 442.00 2.10 210.00 441.95 392.45 -2.92 -0.29 6003803.92 388071.15 CB-GYRO-SS 511.39 2.79 213.39 511.28 461.78 -5.43 -1.85 6003801.44 388069.54 MWD+IFR-AK-CAZ-SC 570.41 3.42 203.43 570.21 520.71 -8.25 -3.35 6003798.64 388068.01 MWD+IFR-AK-CAZ-SC 661.03 4.81 186.49 660.60 611.10 -14.50 -4.85 6003792.41 388066.41 MWD+IFR-AK-CAZ-SC 750.35 7.04 183.45 749.44 699.94 -23.69 -5.60 6003783.24 388065.52 MWD+IFR-AK-CAZ-SC 842.09 9.94 173.87 840.17 790.67 -37.18 -5.09 6003769.75 388065.83 MWD+IFR-AK-CAZ-SC ~ 937.40 13.85 161.21 933.43 883.93 -56.17 -0.54 6003750.69 388070.10 MWD+IFR-AK-CAZ-SC 1032.37 14.69 158.37 1025.47 975.97 -78.12 7.56 6003728.62 388077.87 MWD+IFR-AK-CAZ-SC 1127.59 13.77 159.22 1117.77 1068.27 -99.94 16.03 6003706.68 388086.01 MWD+IFR-AK-CAZ-SC 1222.36 14.55 151.34 1209.67 1160.17 -120.93 25.74 6003685.54 388095.41 MWD+IFR-AK-CAZ-SC ~ 1317.17 16.66 143.19 1300.99 1251.49 -142.27 39.60 6003664.00 388108.94 MWD+IFR-AK-CAZ-SC 1412.12 18.90 133.16 1391.42 1341.92 -163.69 58.98 6003642.29 388128.00 MWD+IFR-AK-CAZ-SC 1507.41 23.04 123.18 "1480.41 1430.91 -184.47 85.87 6003621.12 388154.56 MWD+IFR-AK-CAZ-SC 1559.89 24.40 117.74 1528.46 1478.96 -195.14 104.06 6003610.18 388172.59 MWD+IFR-AK-CAZ-SC 1602.63 24.66 113.37 1567.34 1517.84 -202.79 120.06 6003602.29 388188.47 MWD+IFR-AK-CAZ-SC 1697.43 26.02 104.09 1653.05 1603.55 -215.70 158.40 6003588.81 388226.61 MWD+IFR-AK-CAZ-SC 1792.80 27.17 94.65 1738.37 1688.87 -222.56 200.41 6003581.32 388268.51 MWD+IFR-AK-CAZ-SC 1888.04 29.60 91.16 1822.16 1772.66 -224.80 245.61 6003578.40 388313.67 MWD+IFR-AK-CAZ-SC 1983.30 33.48 91.98 1903.33 1853.83 -226.18 295.41 6003576.27 388363.44 MWD+IFR-AK-CAZ-SC 2079.19 35.22 92.57 1982.50 1933.00 -228.34 349.47 6003573.31 388417.46 MWD+IFR-AK-CAZ-SC 2174.01 36.44 91.96 2059.37 2009.87 -230.53 404.93 6003570.29 388472.87 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report C~ Companc: ConocoPhillips Alaska Inc . Date: 2/15!2008 I imr. 16:08:56 Page: .. i icld: Cglville River Unit Co-ordinate(NE) Reference: Well: CD3-316, True North i Site Fiord CD3 Vertic al (TVD) Reference: GD3-316 4g-5 ~~cll: CD3-316 Sectio n (VS) Reference: Well (O.OON,O.OOE,93.34Azi) ~Veftpath: CD3-316A Survey Caknlali an,Method: Minimum Curva ture Uh: Oracle Surrey h1D Inc! ~zim ~f~'D S~s'f~'U YlS E/~~ 11apA MapE fool ft deg deg ft ft ft ft ft ft _ -- -- -- 2269.16 38.15 90.67 2135. 06 2085.56 -231. 84 462.56 6003568.11 388530.48 MWD+IFR-AK-CAZ-SC I 2363.95 41.92 92.60 2207. 63 2158.13 -233. 62 523.50 6003565.42 388591.37 MWD+IFR-AK-CAZ-SC 2458.85 46.27 92.62 2275. 77 2226.27 -236. 62 589.45 6003561.43 388657.26 MWD+IFR-AK-CAZ-SC 2553.85 46.29 92.52 2341. 43 2291.93 -239. 70 658.04 6003557.32 388725.79 MWD+IFR-AK-CAZ-SC 2651.34 44.92 93.02 2409. 63 2360.13 -243. 06 727.61 6003552.91 388795.31 MWD+IFR-AK-CAZ-SC 2704.98 44.85 92.93 2447. 63 2398.13 -245. 03 765.42 6003550.38 388833.07 MWD+IFR-AK-CAZ-SC 2802.18 44.58 92.59 2516. 71 2467.21 -248. 32 833.72 6003546.07 388901.32 MWD+IFR-AK-CAZ-SC 2897.15 43.64 92.37 2584. 89 2535.39 -251. 18 899.76 6003542.22 388967.30 MWD+IFR-AK-CAZ-SC 2992.64 44.46 90.72 2653. 53 2604.03 -252. 97 966.13 6003539.44 389033.62 MWD+IFR-AK-CAZ-SC 3087.84 45.30 89.92 2720. 99 2671.49 -253 .34 1033.30 6003538.06 389100.78 MWD+IFR-AK-CAZ-SC 3182.71 45.12 89.12 2787. 82 2738.32 -252 .78 1100.63 6003537.61 389168.10 MWD+IFR-AK-CAZ-SC 3277.79 45.17 88.59 2854. 88 2805.38 -251 .43 1168.01 6003537.95 389235.49 MWD+IFR-AK-CAZ-SC 3373.17 44.62 88.62 2922. 45 2872.95 -249 .79 1235.31 6003538.58 389302.80 MWD+IFR-AK-CAZ-SC 3468.38 43.93 88.09 2990. 62 2941.12 -247 .88 1301.75 6003539.49 389369.26 MWD+IFR-AK-CAZ-SC 3563.25 44.42 88.83 3058. 66 3009.16 -246 .11 1367.84 6003540.27 389435.36 MWD+IFR-AK-CAZ-SC 3658.36 44.29 93.15 3126 .69 3077.19 -247 .25 1434.29 6003538.13 389501.78 MWD+IFR-AK-CAZ-SC 3754.06 45.60 93.35 3194 .42 3144.92 -251 .09 1501.78 6003533.29 389569.20 MWD+IFR-AK-CAZ-SC 3849.23 44.53 94.10 3261 .64 3212.14 -255 .46 1569.01 6003527.91 389636.35 MWD+IFR-AK-CAZ-SC 3943.00 46.46 90.01 3327 .38 3277.88 -257 .82 1635.81 6003524.55 389703.10 MWD+IFR-AK-CAZ-SC 4040.11 45.70 89.75 3394 .74 3345.24 -257 .67 1705.76 6003523.64 389773.04 MWD+IFR-AK-CAZ-SC 4134.95 45.63 89.57 3461 .02 3411.52 -257 .27 1773.60 6003523.03 389840.87 MWD+IFR-AK-CAZ-SC 4229.67 44.98 88.84 3527 .64 3478.14 -256 .34 1840.92 6003522.95 389908.19 MWD+IFR-AK-CAZ-SC 4324.82 43.90 90.25 3595 .57 3546.07 -255 .80 1907.53 6003522.49 389974.80 MWD+IFR-AK-CAZ-SC 4418.82 44.56 90.29 3662 .93 3613.43 -256 .11 1973.10 6003521.20 390040.35 MWD+IFR-AK-CAZ-SC 4514.22 43.47 93.03 3731 .54 3682.04 -258 .01 2039.35 6003518.30 390106.56 MWD+IFR-AK-CAZ-SC 4609.36 44.47 93.58 3800 .01 3750.51 -261 .83 2105.29 6003513.50 390172.43 MWD+IFR-AK-CAZ-SC 4704.64 44.82 91.94 3867 .81 3818.31 -265 .05 2172.16 6003509.28 390239.24 MWD+IFR-AK-CAZ-SC 4799.98 45.45 90.12 3935 .06 3885.56 -266 .26 2239.72 6003507.06 390306.77 MWD+IFR-AK-CAZ-SC 4895.36 45.17 89.98 4002 .14 3952.64 -266 .31 2307.53 6003505.98 390374.56 MWD+IFR-AK-CAZ-SC 4990.35 44.85 89.30 4069 .30 4019.80 -265 .89 2374.71 6003505.40 390441.73 MWD+IFR-AK-CAZ-SC 5085.67 46.17 90.93 4136 .10 4086.60 -266 .04 2442.70 6003504.23 390509.71 MWD+IFR-AK-CAZ-SC 5180.97 45.52 91.68 4202 .48 4152.98 -267 .60 2511.05 6003501.65 390578.02 MWD+IFR-AK-CAZ-SC 5276.20 44.85 90.78 4269 .61 4220.11 -269 .05 2578.59 6003499.18 390645.53 MWD+IFR-AK-CAZ-SC 5371.27 45.55 92.74 4336 .60 4287.10 -271 .13 2646.01 6003496.10 390712.90 MWD+IFR-AK-CAZ-SC 5466.29 45.16 91.99 4403 .37 4353.87 -273 .92 2713.56 6003492.29 390780.39 MWD+IFR-AK-CAZ-SC 5561.86 44.50 91.16 4471 .15 4421.65 -275 .77 2780.91 6003489.43 390847.70 MWD+IFR-AK-CAZ-SC 5656.91 43.93 90.69 4539 .27 4489.77 -276 .84 2847.18 6003487.36 390913.95 MWD+IFR-AK-CAZ-SC 5752.06 45.69 91.53 4606 .78 4557.28 -278 .15 2914.22 6003485.05 390980.95 MWD+IFR-AK-CAZ-SC 5846.97 45.07 90.82 4673 .44 4623.94 -279 .54 2981.76 6003482.65 391048.46 MWD+IFR-AK-CAZ-SC 5941.98 44.09 90.47 4741 .11 4691.61 -280 .29 3048.44 6003480.90 391115.12 MWD+IFR-AK-CAZ-SC 6017.00 45.50 91.74 4794 .35 4744.85 -281 .32 3101.29 6003479.08 391167.94 MWD+IFR-AK-CAZ-SC 6073.22 45.61 87.82 4833 .72 4784.22 -281 .16 3141.41 6003478.64 391208.05 MWD+IFR-AK-CAZ-SC 6134.37 46.87 86.76 4876 .02 4826.52 -279 .07 3185.52 6003480.07 391252.19 MWD+IFR-AK-CAZ-SC 6229.61 50.12 86.09 4939 .12 4889.62 -274 .61 3256.70 6003483.46 391323.41 MWD+IFR-AK-CAZ-SC 6324.52 54.18 89.16 4997 .36 4947.86 -271 .56 3331.55 6003485.38 391398.30 MWD+IFR-AK-CAZ-SC 6419.55 56.63 88.57 5051 .31 5001.81 -270 .01 3409.75 6003485.76 391476.51 MWD+IFR-AK-CAZ-SC 6515.29 59.82 85.93 5101 .72 5052.22 -266 .07 3491.03 6003488.48 391557.82 MWD+IFR-AK-CAZ-SC 6610.07 63.25 85.03 5146 .89 5097.39 -259 .50 3574.07 6003493.81 391640.96 MWD+IFR-AK-CAZ-SC 6705.12 67.17 84.63 5186 .74 5137.24 -251 .72 3660.00 6003500.30 391726.98 MWD+IFR-AK-CAZ-SC 6800.32 69.70 83.29 5221 .73 5172.23 -242 .39 3748.03 6003508.30 391815.13 MWD+IFR-AK-CAZ-SC 6895.50 70.70 82.70 5253 .97 5204.47 -231 .47 3836.91 6003517.89 391904.16 MWD+IFR-AK-CAZ-SC 6990.39 70.03 81.93 5285 .85 5236.35 -219 .52 3925.48 6003528.51 391992.89 MWD+IFR-AK-CAZ-SC 7085.51 69.36 80.94 5318 .86 5269.36 -206 .24 4013.69 6003540.47 392081.29 MWD+IFR-AK-CAZ-SC • Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. [hate: 2!15/2008 Timc: 16:08:56 Pa^e: 3 Field: Colville River Unit Cu-ordinate(NE)Referencc: Well: CD3-316, True North Site: Fiord CD3 ~crticaS('I'VD) Reference: CD3-316 49.5 Wetto- CD3-316 - Section fVS) Reference: Well (O.OON;O.OOE,93.34Azi) N'ellpath: CD3-316A Survey Cakulation Alethod: ivtinimuin Curvature llb: Oracle Sun°ey 11D" Inci Azim TVD Sys "f~U V/S EIW MapN ~1apE Ibol ft deg deg ft ft ft ft ft ft 7180.62 71.02 82.77 5351.10 5301.60 -193.57 4102.27 6003551.81 392170.03 MWD+IFR-AK-CAZ-SC ~ 7275.43 70.35 81.98 5382.46 5332.96 -181.70 4190.95 6003562.35 392258.87 MWD+IFR-AK-CAZ-SC 7370.81 70.40 82.21 5414.49 5364.99 -169.34 4279.93 6003573.37 392348.03 MWD+IFR-AK-CAZ-SC 7465.93 70.61 83.25 5446.24 5396.74 -157.99 4368.88 6003583.38 392437.12 MWD+IFR-AK-CAZ-SC 7561.19 72.18 83.36 5476.63 5427.13 -147.47 4458.54 6003592.55 392526.93 MWD+IFR-AK-CAZ-SC 7656.02 71.64 82.98 5506.07 5456.57 -136.75 4548.04 6003601.93 392616.57 MWD+IFR-AK-CAZ-SC 7750.96 70.89 82.06 5536.57 5487.07 -125.05 4637.19 6003612.29 392705.87 MWD+IFR-AK-CAZ-SC 7846.18 71.48 83.30 5567.28 5517.78 -113.57 4726.58 6003622.43 392795.42 MWD+IFR-AK-CAZ-SC ~ 7941.29 71.03 84.11 5597.84 5548.34 -103.69 4816.10 6003630.96 392885.07 MWD+IFR-AK-CAZ-SC 8036.49 70.56 83.83 5629.16 5579.66 -94.25 4905.51 6003639.07 392974.60 MWD+IFR-AK-CAZ-SC 8131.54 70.36 83.54 5660.95 5611.45 -84.39 4994.54 6003647.58 393063.76 MWD+IFR-AK-CAZ-SC 8226.67 70.71 84.42 5692.65 5643.15 -74.99 5083.74 6003655.65 393153.08 MWD+IFR-AK-CAZ-SC 8322.09 69.94 83.03 5724.78 5675.28 -65.17 5173.04 6003664.13 393242.52 MWD+IFR-AK-CAZ-SC 8417.54 70.94 83.31 5756.73 5707.23 -54.47 5262.35 6003673.48 393331.97 MWD+IFR-AK-CAZ-SC 8512.61 71.34 83.87 5787.47 5737.97 -44.43 5351.75 6003682.18 393421.50 MWD+IFR-AK-CAZ-SC 8607.78 71.06 83.15 5818.14 5768.64 -34.25 5441.26 6003691.02 393511.15 MWD+IFR-AK-CAZ-SC 8702.97 70.81 84.19 5849.23 5799.73 -24.33 5530.68 6003699.60 393600.70 MWD+IFR-AK-CAZ-SC 8798.35 70.28 84.46 5881.00 5831.50 -15.44 5620.18 6003707.15 393690.31 MWD+IFR-AK-CAZ-SC 8893.80 70.36 83.87 5913.14 5863.64 -6.30 5709.58 6003714.94 393779.84 MWD+IFR-AK-CAZ-SC 8988.81 70.62 83.65 5944.87 5895.37 3.44 5798.61 6003723.34 393868.99 MWD+IFR-AK-CAZ-SC 9084.64 69.95 83.47 5977.20 5927.70 13.55 5888.25 6003732.11 393958.77 MWD+IFR-AK-CAZ-SC 9179.94 73.65 83.54 6006.96 5957.46 23.79 5978.19 6003741.00 394048.84 MWD+IFR-AK-CAZ-SC 9275.36 73.10 83.15 6034.26 5984.76 34.39 6069.00 6003750.23 394139.79 MWD+IFR-AK-CAZ-SC 9370.48 72.25 82.46 6062.59 6013.09 45.76 6159.09 6003760.25 394230.03 MWD+IFR-AK-CAZ-SC 9465.52 71.78 82.20 6091.93 6042.43 57.82 6248.68 6003770.97 394319.78 MWD+IFR-AK-CAZ-SC 9560.37 71.25 82.93 6122.00 6072.50 69.47 6337.88 6003781.27 394409.14 MWD+IFR-AK-CAZ-SC 9655.48 70.30 82.57 6153.32 6103.82 80.80 6426.96 6003791.26 394498.38 MWD+IFR-AK-CAZ-SC 9750.76 69.30 82.06 6186.22 6136.72 92.75 6515.58 6003801.89 394587.16 MWD+IFR-AK-CAZ-SC 9846.06 68.64 83.02 6220.42 6170.92 104.30 6603.77 6003812.12 394675.51 MWD+IFR-AK-CAZ-SC 9941.05 69.05 83.08 6254.70 6205.20 115.02 6691.71 6003821.51 394763.59 MWD+IFR-AK-CAZ-SC 10036.58 68.77 83.85 6289.08 6239.58 125.17 6780.26 6003830.33 394852.28 MWD+IFR-AK-CAZ-SC 10131.57 69.11 83.87 6323.21 6273.71 134.65 6868.40 6003838.49 394940.54 MWD+IFR-AK-CAZ-SC 10226.76 69.96 83.90 6356.49 6306.99 144.15 6957.07 6003846.66 395029.34 MWD+IFR-AK-CAZ-SC 10275.00 70.03 84.26 6373.00 6323.50 148.82 7002.16 6003850.65 395074.48 MWD+IFR-AK-CAZ-SC 10331.42 71.07 86.13 6391.78 6342.28 153.28 7055.17 6003854.31 395127.55 MWD+IFR-AK-CAZ-SC 10388.90 71.07 86.31 6410.43 6360.93 156.86 7109.42 6003857.08 395181.85 MWD+IFR-AK-CAZ-SC 10484.22 71.78 90.64 6440.81 6391.31 159.26 7199.72 6003858.13 395272.16 MWD+IFR-AK-CAZ-SC 10579.03 72.44 95.33 6469.95 6420.45 154.56 7289.79 6003852.07 395362.14 MWD+IFR-AK-CAZ-SC 10623.38 72.58 95.72 6483.28 6433.78 150.48 7331.90 6003847.37 395404.18 MWD+IFR-AK-CAZ-SC 10674.41 73.39 95.98 6498.21 6448.71 145.51 7380.44 6003841.67 395452.64 MWD+IFR-AK-CAZ-SC 10769.17 73.29 96.19 6525.38 6475.88 135.89 7470.71 6003830.69 395542.74 MWD+IFR-AK-CAZ-SC 10863.59 74.50 96.07 6551.57 6502.07 126.20 7560.90 6003819.66 395632.78 MWD+IFR-AK-CAZ-SC 10959.69 74.51 95.59 6577.24 6527.74 116.79 7653.03 6003808.87 395724.74 MWD+IFR-AK-CAZ-SC 11054.97 74.44 94.16 6602.74 6553.24 108.99 7744.50 6003799.70 395816.08 MWD+IFR-AK-CAZ-SC 11150.12 73.59 92.50 6628.95 6579.45 103.68 7835.81 6003793.02 395907.29 MWD+IFR-AK-CAZ-SC 11244.27 73.22 97.84 6655.86 6606.36 95.55 7925.63 6003783.55 395996.98 MWD+IFR-AK-CAZ-SC 11293.12 74.89 101.48 6669.28 6619.78 87.67 7971.93 6003774.97 396043.14 MWD+IFR-AK-CAZ-SC 11339.54 75.91 102.76 6680.98 6631.48 78.23 8015.84 6003764.88 396086.91 MWD+IFR-AK-CAZ-SC 11388.02 77.36 106.73 6692.19 6642.69 66.23 8061.45 6003752.19 396132.32 MWD+IFR-AK-CAZ-SC 11434.68 79.50 108.82 6701.55 6652.05 52.27 8104.97 6003737.59 396175.63 MWD+IFR-AK-CAZ-SC 11483.04 82.81 111.57 6708.99 6659.49 35.77 8149.80 6003720.42 396220.21 MWD+IFR-AK-CAZ-SC 11530.23 83.31 114.49 6714.69 6665.19 17.45 8192.91 6003701.45 396263.03 MWD+IFR-AK-CAZ-SC • Halliburton Company Survey Report Company: ConocePhillips Alaska Inc. Datc: 2115!2008 l'imc 16~(7f3~56 Pa~c ~ fichl: Colville River Unit Co-ordinate(NE} ReBerencr: V~Jell`. CD3-316. True North Site: Fiord CD3 ~'crtical(TVD)Reference: GD3-31649.5. Nell: CD3-316 tiectio n IVS)Reference: WeII (O.OON,O.OOE,93.34Azi) Wellpath: CD3-316A surveyCakiilationSicthud: Minimum Curva ture lln: Oracle Survey iV1~ Inet- Azim TVD S}S ~I"~"D \!S E1W Mup~' ~1apF. fool ft deg deg ft ft ft ft ft ft 11578.04 82.94 115.03 6720.41 6670.91 -2.43 8236.01 6003680.93 396305.82 MWD+IFR-AK-CAZ-SC 11625.46 86.54 118.70 6724.76 6675.26 -23.77 8278.12 6003658.97 396347.60 MWD+IFR-AK-CAZ-SC 11648.83 88.20 120.19 6725.83 6676.33 -35.24 8298.45 6003647:19 396367.76 MWD+IFR-AK-CAZ-SC 11730.57 87.81 119.45 6728.68 6679.18 -75.86 8369.32 6003605.51 396438.01 MWD+IFR-AK-CAZ-SC 11824.06 90.65 119.96 6729.94 6680.44 -122.18 8450.51 6003557.99 396518.48 MWD+IFR-AK-CAZ-SC 11907.94 90.21 119.00 6729.31 6679.81 -163.46 8523.53 6003515.62 396590.87 MWD+IFR-AK-CAZ-SC 11940.65 95.53 118.48 6727.67 6678.17 -179.16 8552.16 6003499.49 396619.26 MWD+IFR-AK-CAZ-SC 11972.40 99.61 116.61 6723.49 6673.99 -193.72 8580.06 6003484.53 396646.93 MWD+IFR-AK-CAZ-SC 12000.01 95.60 117.79 6719.83 6670.33 -206.22 8604.39 6003471.66 396671.08 MWD+IFR-AK-CAZ-SC 12095.60 87.46 118.94 6717.28 6667.78 -251.58 8688.40 6003425.04 396754.39 MWD+IFR-AK-CAZ-SC 12191.70 93.47 119.73 6716.50 6667.00 -298.64 8772.14 6003376.74 396837.40 MWD+IFR-AK-CAZ-SC 12287.78 89.59 114.97 6713.94 6664.44 -342.74 8857.41 6003331.37 396922.00 MWD+IFR-AK-CAZ-SC 12382.51 90.41 122.04 6713.94 6664.44 -387.92 8940.60 6003284.95 397004.49 MWD+IFR-AK-CAZ-SC 12446.62 88.77 121.72 6714.40 6664.90 -421.78 8995.04 6003250.29 397058.41 MWD+IFR-AK-CAZ-SC I • 12515.00 88.77 121.72 6715.86 6666.36 -457.72 9053.19 6003213.48 . 397116.01 ~ PROJECTED to TD • Halliburton Company Survey Report • Comp:~nc: ConocoPhillipsAlaskalnc. uarc: 2/15/200A Time: 16:09:39 Pale: Field: Colville River Unit Co -ordinate(NE)R eference: Well: CD3-316. True North Site: Fiord CD3 ~c rtical(TVD}Referencc CD3-31649.5 Well: CD3-316 Sec fion (VS) Reference: Well (O.OON,O.OOE93.34Azi) Wellpath: CD3-316APB1 Su rrey Calculation Method: MinimumCt~nrature 1)b; Oracle - _ _ --_ Field: Colville River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Well: CD3-316 Slot Name: 50-103-20559-00 Well Position: +N/-S -86.18 ft Northing: 6003806.84 ft Latitude: 70 25 9.633 N +E/-W -415.41 ft Easting : 388071.48 ft Longitude: 150 54 42.572 W Position Uncertainty: 0.00 ft Wellpath: CD3-316AP61 Drilled From: CD3-316 50-103-20559-71 Tie-on Depth: 5941.98 ft Current Datum: CD3-316 Height 49.50 ft Above System Datum: Mean Sea Level Magnetic Data: 1/15/2008 Declination: 22.35 deg Field Strength: 57584 nT Mag Dip Angle: 80.75 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 36.30 0.00 0.00 93.34 Survey Program for Definitive Wellpath Date: 2/15/2008 Validated: No Version: 6 Actual From To Survey Toolcode Tool Name ft ft 81.00 442.00 CD3-316 Gyro (81.00-442.00) (1 C B-GYRO-SS Camera based gyro single shot 511.39 5941.98 CD3-316 MWD+SAG+IIFR+CA+MS (51 MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC 6017.00 .11368.57 CD3-316APB1 MWD+SAG+IIFR+ CA+MS MWD+IFR-AK-CAZ-SC MWD+IFR AK CAZ SCC Survey -- - - !YfD Incl Azim f~ D Sys TVD N/S E/~1 MapN ylnpf: l'nol ft deg deg ft ft ft ft ft ft ? ___ __ 36.30 0.00 0.00 36.30 -13.20 0.00 0.00 6003806.84 388071.48 TIE LINE 81.00 0.50 96.00 81.00 31.50 -0.02 0.19 6003806.82 388071.67 CB-GYRO-SS 170.00 0.75 89.00 169.99 120.49 -0.05 1.16 6003806.77 388072.64 CB-GYRO-SS 261.00 0.47 186.50 260.99 211.49 -0.41 1.72 6003806.40 388073.19 CB-GYRO-SS 352.00 0.85 238.00 351.99 302.49 -1.14 1.10 6003805.68 388072.56 CB-GYRO-SS 442.00 2.10 210.00 441.95 392.45 -2.92 -0.29 6003803.92 388071.15 CB-GYRO-SS 511.39 2.79 213.39 511.28 461.78 -5.43 -1.85 6003801.44 388069.54 MWD+IFR-AK-CAZ-SC 570.41 3.42 203.43 570.21 520.71 -8.25 -3.35 6003798.64 388068.01 MWD+IFR-AK-CAZ-SC 661.03 4.81 186.49 660.60 611.10 -14.50 -4.85 6003792.41 388066.41 MWD+IFR-AK-CAZ-SC 750.35 7.04 183.45 749.44 699.94 -23.69 -5.60 6003783.24 388065.52 MWD+IFR-AK-CAZ-SC 842.09 9.94 173.87 840.17 790.67 -37.18 -5.09 6003769.75 388065.83 MWD+IFR-AK-CAZ-SC 937.40 13.85 161.21 933.43 883.93 -56.17 -0.54 6003750.69 388070.10 MWD+IFR-AK-CAZ-SC 1032.37 14.69 158.37 1025.47 975.97 -78.12 7.56 6003728.62 388077.87 MWD+IFR-AK-CAZ-SC ~ 1127.59 13.77 159.22 1117.77 1068.27 -99.94 16.03 6003706.68 388086.01 MWD+IFR-AK-CAZ-SC 1222.36 14.55 151.34 1209.67 1160.17 -120.93 25.74 6003685.54 388095.41 MWD+IFR-AK-CAZ-SC 1317.17 16.66 143.19 1300.99 1251.49 -142.27 39.60 6003664.00 388108.94 MWD+IFR-AK-CAZ-SC 1412.12 18.90 133.16 1391.42 1341.92 -163.69 58.98 6003642.29 388128.00 MWD+IFR-AK-CAZ-SC 1507.41 23.04 123.18 1480.41 1430.91 -184.47 85.87 6003621.12 388154.56 MWD+IFR-AK-CAZ-SC 1559.89 24.40 117.74 1528.46 1478.96 -195.14 104.06 6003610.18 388172.59 MWD+IFR-AK-CAZ-SC 1602.63 24.66 113.37 1567.34 1517.84 -202.79 120.06 6003602.29 388188.47 MWD+IFR-AK-CAZ-SC i 1697.43 26.02 104.09 1653.05 1603.55 -215.70 158.40 6003588.81 388226.61 MWD+IFR-AK-CAZ-SC 1792.80 27.17 94.65 1738.37 1688.87 -222.56 200.41 6003581.32 388268.51 MWD+IFR-AK-CAZ-SC ~ 1888.04 29.60 91.16 1822.16 1772.66 -224.80 245.61 6003578.40 388313.67 MWD+IFR-AK-CAZ-SC 1983.30 33.48 91.98 1903.33 1853.83 -226.18 295.41 6003576.27 388363.44 MWD+IFR-AK-CAZ-SC 2079.19 35.22 92.57 1982.50 1933.00 -228.34 349.47 6003573.31 388417.46 MWD+IFR-AK-CAZ-SC 2174.01 36.44 91.96 2059.37 2009.87 -230.53 404.93 6003570.29 388472.87 MWD+IFR-AK-CAZ-SC 2269.16 38.15 90.67 2135.06 2085.56 -231.84 462.56 6003568.11 388530.48 MWD+IFR-AK-CAZ-SC 2363.95 41.92 92.60 2207.63 2158.13 -233.62 523.50 6003565.42 388591.37 MWD+IFR-AK-CAZ-SC • Halliburton Company Survey Report Company: ConocoPhillips Ala5k2 lnC. I?rtr. 2/1512008 I'imc: 16:09:39 Na~c: 2 Field: ColvilleRiver Unit Co-u rdin;~tc(NE)Referencc Well: CD3-316, True North Site: Fiord CD3 Vertical (Fb~Dj Reference CD3-316 49.5 ~~ell: CD3-316 Section (VS) Reference: Wetl (O.OON,O.OOE,93.34Azi) N'ellpalh: CD3-316AP61 Survey Calculation ~letho4: Minimum Curvature' llh: Oracle ti u rvcy MD incl ~iim TVD SysT~D 1iti E/W ti1apN ~~iapE Tool ft deg ' deg ft ft ft ft ft ft 2458.85 46.27 92.62 2275.77 2226.27 -236.62 589.45 6003561.43 388657.26 MWD+IFR-AK-CAZ-SC 2553.85 46.29 92.52 2341.43 2291.93 -239.70 .658.04 6003557.32 388725.79 MWD+IFR-AK-CAZ-SC 2651.34 44.92 93.02 2409.63 2360.13 -243.06 727.61 6003552.91 388795.31 MWD+IFR-AK-CAZ-SC 2704.98 44.85 92.93 2447.63 2398.13 -245.03 765.42 6003550.38 388833.07 MWD+IFR-AK-CAZ-SC 2802.18 44.58 92.59 2516.71 2467.21 -248.32 833.72 6003546.07 388901.32 MWD+IFR-AK-CAZ-SC 2897.15 43.64 92.37 2584.89 2535.39 -251.18 899.76 6003542.22 388967.30 MWD+IFR-AK-CAZ-SC 2992.64 44.46 90.72 2653.53 2604.03 -252.97 966.13 6003539.44 389033.62 MWD+IFR-AK-CAZ-SC 3087.84 45.30 89.92 2720.99 2671.49 -253.34 1033.30 6003538.06 389100.78 MWD+IFR-AK-CAZ-SC 3182.71 45.12 89.12 2787.82 2738.32 -252.78 1100.63 6003537.61 389168.10 MWD+IFR-AK-CAZ-SC 3277.79 45.17 88.59 2854.88 2805.38 -251.43 1168.01 6003537.95 389235.49 MWD+IFR-AK-CAZ-SC 3373.17 44.62 88.62 2922.45 2872.95 -249.79 1235.31 6003538.58 389302.80 MWD+IFR-AK-CAZ-SC 3468.38 43.93 88.09 2990.62 2941.12 -247.88 1301.75 6003539.49 389369.26 MWD+IFR-AK-CAZ-SC 3563.25 44.42 88.83 3058.66 3009.16 -246.11 1367.84 6003540.27 389435.36 MWD+IFR-AK-CAZ-SC 3658.36 44.29 93.15 3126.69 3077.19 -247.25 1434.29 6003538.13 389501.78 MWD+IFR-AK-CAZ-SC 3754.06 45.60 93.35 3194.42 3144.92 -251.09 1501.78 6003533.29 389569.20 MWD+IFR-AK-CAZ-SC 3849.23 44.53 94.10 3261.64 3212.14 -255.46 1569.01 6003527.91 389636.35 MWD+IFR-AK-CAZ-SC 3943.00 46.46 90.01 3327.38 3277.88 -257.82 1635.81 6003524.55 389703.10 MWD+IFR-AK-CAZ-SC 4040.11 45.70 89.75 3394.74 3345.24 -257.67 1705.76 6003523.64 389773.04 MWD+IFR-AK-CAZ-SC 4134.95 45.63 89.57 3461.02 3411.52 -257.27 1773.60 6003523.03 389840.87 MWD+IFR-AK-CAZ-SC 4229.67 44.98 88.84 3527.64 3478.14 -256.34 1840.92 6003522.95 389908.19 MWD+IFR-AK-CAZ-SC 4324.82 43.90 90.25 3595.57 3546.07 -255.80 1907.53 6003522.49 389974.80 MWD+IFR-AK-CAZ-SC 4418.82 44.56 90.29 3662.93 3613.43 -256.11 1973.10 6003521.20 390040.35 MWD+IFR-AK-CAZ-SC 4514.22 43.47 93.03 3731.54 3682.04 -258.01 2039.35 6003518.30 390106.56 MWD+IFR-AK-CAZ-SC 4609.36 44.47 93.58 3800.01 3750.51 -261.83 2105.29 6003513.50 390172.43 MWD+IFR-AK-CAZ-SC 4704.64 44.82 91.94 3867.81 3818.31 -265.05 2172.16 6003509.28 390239.24 MWD+IFR-AK-CAZ-SC 4799.98 45.45 90.12 3935.06 3885.56 -266.26 2239.72 6003507.06 390306.77 MWD+IFR-AK-CAZ-SC 4895.36 45.17 89.98 4002.14 3952.64 -266.31 2307.53 6003505.98 390374.56 MWD+IFR-AK-CAZ-SC 4990.35 44.85 89.30 4069.30 4019.80 -265.89 2374.71 6003505.40 390441.73 MWD+IFR-AK-CAZ-SC 5085.67 46.17 90.93 4136.10 4086.60 -266.04 2442.70 6003504.23 390509.71 MWD+IFR-AK-CAZ-SC 5180.97 45.52 91.68 4202.48 4152.98 -267.60 2511.05 6003501.65 390578.02 MWD+IFR-AK-CAZ-SC 5276.20 44.85 90.78 4269.61 4220.11 -269.05 2578.59 6003499.18 390645.53 MWD+IFR-AK-CAZ-SC 5371.27 45.55 92.74 4336.60 4287.10 -271.13 2646.01 6003496.10 390712.90 MWD+IFR-AK-CAZ-SC 5466.29 45.16 91.99 4403.37 4353.87 -273.92 2713.56 6003492.29 390780.39 MWD+IFR-AK-CAZ-SC 5561.86 44.50 91.16 4471.15 4421.65 -275.77 2780.91 6003489.43 390847.70 MWD+IFR-AK-CAZ-SC 5656.91 43.93 90.69 4539.27 4489.77 -276.84 2847.18 6003487.36 390913.95 MWD+IFR-AK-CAZ-SC 5752.06 45.69 91.53 4606.78 4557.28 -278.15 2914.22 6003485.05 390980.95 MWD+IFR-AK-CAZ-SC 5846.97 45.07 90.82 4673.44 4623.94 -279.54 2981.76 6003482.65 391048.46 MWD+IFR-AK-CAZ-SC 5941.98 44.09 90.47 4741.11 4691.61 -280.29 3048.44 6003480.90 391115.12 MWD+IFR-AK-CAZ-SC 6017.00 45.50 91.74 4794.35 4744.85 -281.32 3101.29 6003479.08 391167.94 MWD+IFR-AK-CAZ-SC 6073.22 45.61 87.82 4833.72 4784.22 -281.16 3141.41 6003478.64 391208.05 MWD+IFR-AK-CAZ-SC 6134.37 46.87 86.76 4876.02 4826.52 -279.07 3185.52 6003480.07 391252.19 MWD+IFR-AK-CAZ-SC 6229.61 50.12 86.09 4939.12 4889.62 -274.61 3256.70 6003483.46 391323.41 MWD+IFR-AK-CAZ-SC 6324.52 54.18 89.16 4997.36 4947.86 -271.56 3331.55 6003485.38 391398.30 MWD+IFR-AK-CAZ-SC 6419.55 56.63 88.57 5051.31 5001.81 -270.01 3409.75 6003485.76 391476.51 MWD+IFR-AK-CAZ-SC 6515.29 59.82 85.93 5101.72 5052.22 -266.07 3491.03 6003488.48 391557.82 MWD+IFR-AK-CAZ-SC 6610.07 63.25 85.03 5146.89 5097.39 -259.50 3574.07 6003493.81 391640.96 MWD+IFR-AK-CAZ-SC 6705.12 67.17 84.63 5186.74 5137.24 -251.72 3660.00 6003500.30 391726.98 MWD+IFR-AK-CAZ-SC 6800.32 69.70 83.29 5221.73 5172.23 -242.39 3748.03 6003508.30 391815.13 MWD+IFR-AK-CAZ-SC 6895.50 70.70 82.70 5253.97 5204.47 -231.47 3836.91 6003517.89 391904.16 MWD+IFR-AK-CAZ-SC 6990.39 70.03 81.93 5285.85 5236.35 -219.52 3925.48 6003528.51 391992.89 MWD+IFR-AK-CAZ-SC 7085.51 69.36 80.94 5318.86 5269.36 -206.24 4013.69 6003540.47 392081.29 MWD+IFR-AK-CAZ-SC 7180.62 71.02 82.77 5351.10 5301.60 -193.57 4102.27 6003551.81 392170.03 MWD+IFR-AK-CAZ-SC Halliburton Company Survey Report Company: ConocoPhillips Alaska Inc. Ficld: Colville River Unit Site: Fiord CD^ WeIL CD3-316 Wellpath: CU3-316APB1 Survev MD Incl ~zim 1~'D SysT4D ft deg deg ft ft 7275.43 70.35 81.98 5382.46 5332.96 7370.81 70.40 82.21 5414.49 5364.99 7465.93 70.61 83.25 5446.24 5396.74 7561.19 72.18 83.36 5476.63 5427.13 7656.02 71.64 82.98 5506.07 5456.57 7750.96 70.89 82.06 5536.57 5487.07 7846.18 71.48 83.30 5567.28 5517.78 7941.29 71.03 84.11 5597.84 5548.34 8036.49 70.56 83.83 5629.16 5579.66 8131.54 70.36 83.54 5660.95 5611.45 8226.67 70.71 84.42 5692.65 5643.15 8322.09 69.94 83.03 5724.78 5675.28 8417.54 70.94 83.31 5756.73 5707.23 8512.61 71.34 83.87 5787.47 5737.97 8607.78 71.06 83.15 5818.14 5768.64 8702.97 70.81 84.19 5849.23 5799.73 8798.35 70.28 84.46 5881.00 5831.50 8893.80 70.36 83.87 5913.14 5863.64 8988.81 70.62 83.65 5944.87 5895.37 9084.64 69.95 83.47 5977.20 5927.70 9179.94 73.65 83.54 6006.96 5957.46 9275.36 73.10 83.15 6034.26 5984.76 9370.48 72.25 82.46 6062.59 6013.09 9465.52 71.78 82.20 6091.93 6042.43 9560.37 71.25 82.93 6122.00 6072.50 9655.48 70.30 82.57 6153.32 6103.82 9750.76 69.30 82.06 6186.22 6136.72 9846.06 68.64 83.02 6220.42 6170.92 9941.05 69.05 83.08 6254.70 6205.20 10036.58 68.77 83.85 6289.08 6239.58 10131.57 69.11 83.87 6323.21 6273.71 10226.76 69.96 83.90 6356.49 6306.99 10321.68 70.10 84.61 6388.91 6339.41 r ~Q 10416.83 69.32 84.05 6421.91 6372.41 1'^ 10512.12 69.69 83.52 6455.27 6405.77 10607.68 69.30 83.96 6488.74 6439.24 10703.16 68.77 84.65 6522.91 6473.41 10798.43 70.27 86.09 6556.24 6506.74 10893.69 69.49 85.55 6589.01 6539.51 10988.84 69.89 84.77 6622.04 6572.54 11083.82 69.77 84.65 6654.79 6605.29 11179.23 68.95 84.52 6688.42 6638.92 11274.73 68.55 83.87 6723.03 6673.53 11368.57 68.53 83.38 6757.36 6707.86 11407.00 ~ 68.53 83.38 6771.43 6721.93 17atc: 2/1 512 008 Time: '16:09:39 Paec: 3 Co-ordiu;rte(VE) Reference: Well: CD3-316. True North ~'crtical l I'~ D) Reference: CD3-31G 49.5 Section IBS) t2eference: Well (O.OON,O.OOE 93 34Azi) sunev calculation Method: Minimum Curvature llr,: Oracle _ __~ -- ti E/R' MapN ft ft ft -181.70 4190.95 6003562.35 -169.34 4279.93 6003573.37 -157.99 4368.88 6003583.38 -147.47 4458.54 6003592.55 -136.75 4548.04 6003601.93 -125.05 4637.19 6003612.29 -113.57 4726.58 6003622.43 -103.69 4816.10 6003630.96 -94.25 4905.51 6003639.07 -84.39 4994.54 6003647.58 -74.99 5083.74 6003655.65 -65.17 5173.04 6003664.13 -54.47 5262.35 6003673.48 -44.43 5351.75 6003682.18 -34.25 5441.26 6003691.02 -24.33 5530.68 6003699.60 -15.44 5620.18 6003707.15 -6.30 5709.58 6003714.94 3.44 5798.61 6003723.34 13.55 5888.25 6003732.11 23.79 5978.19 6003741.00 34.39 6069.00 6003750.23 45.76 6159.09 6003760.25 57.82 6248.68 6003770.97 69.47 6337.88 6003781.27 80.80 6426.96 6003791.26 92.75 6515.58 6003801.89 104.30 6603.77 6003812.12 115.02 6691.71 6003821.51 125.17 6780.26 6003830.33 134.65 6868.40 6003838.49 144.15 6957.07 6003846.66 153.08 7045.84 6003854.25 161.90 7134.65 6003861.74 171.56 7223.38 6003870.07 181.32 7312.35 6003878.49 190.17 7401.07 6003886.01 197.37 7490.02 6003891.87 203.88 7579.23 6003897.05 211.41 7668.14 6003903.25 219.63 7756.92 6003910.13 228.06 7845.80 6003917.23 237.06 7934.35 6003924.90 246.76 8021.15 6003933.29 250.88 8056.67 6003936.88 ~tapE Tool ft 392258.87 MWD+IFR-AK-CAZ-SC 392348.03 MWD+IFR-AK-CAZ-SC 392437.12 MWD+IFR-AK-CAZ-SC 392526.93 MWD+IFR-AK-CAZ-SC 392616.57 MWD+IFR-AK-CAZ-SC 392705.87 MWD+IFR-AK-CAZ-SC 392795.42 MWD+IFR-AK-CAZ-SC 392885.07 MWD+IFR-AK-CAZ-SC 392974.60 MWD+IFR-AK-CAZ-SC 393063.76 MWD+IFR-AK-CAZ-SC 393153.08 MWD+IFR-AK-CAZ-SC 393242.52 MWD+IFR-AK-CAZ-SC 393331.97 MWD+IFR-AK-CAZ-SC 393421.50 MWD+IFR-AK-CAZ-SC 393511.15 MWD+IFR-AK-CAZ-SC 393600.70 MWD+IFR-AK-CAZ-SC 393690.31 MWD+IFR-AK-CAZ-SC 393779.84 MWD+IFR-AK-CAZ-SC 393868.99 MWD+IFR-AK-CAZ-SC 393958.77 MWD+IFR-AK-CAZ-SC 394048.84 MWD+IFR-AK-CAZ-SC 394139.79 MWD+IFR-AK-CAZ-SC 394230.03 MWD+IFR-AK-CAZ-SC 394319.78 MWD+IFR-AK-CAZ-SC 394409.14 MWD+IFR-AK-CAZ-SC 394498.38 MWD+IFR-AK-CAZ-SC 394587.16 MWD+IFR-AK-CAZ-SC 394675.51 MWD+IFR-AK-CAZ-SC 394763.59 MWD+IFR-AK-CAZ-SC 394852.28 MWD+IFR-AK-CAZ-SC 394940.54 MWD+IFR-AK-CAZ-SC 395029.34 MWD+IFR-AK-CAZ-SC 395118.22 MWD+IFR-AK-CAZ-SC 395207.14 MWD+IFR-AK-CAZ-SC 395296.00 MWD+IFR-AK-CAZ-SC 395385.10 MWD+IFR-AK-CAZ-SC 395473.93 MWD+IFR-AK-CAZ-SC 395562.97 MWD+IFR-AK-CAZ-SC 395652.26 MWD+IFR-AK-CAZ-SC 395741.27 MWD+IFR-AK-CAZ-SC 395830.15 MWD+IFR-AK-CAZ-SC 395919.15 MWD+IFR-AK-CAZ-SC 396007.82 MWD+IFR-AK-CAZ-SC 396094.74 MWD+IFR-AK-CAZ-SC 396130.32 PROJECTED to TD ~a~nacciPhilli~s Liner Detail 41/2" Slotted and Blank Liner i Well: CD3-316 Date: 219/2008 DEPTH Jt Number Num of Jts COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH TOPS Top Of Liner 11549.45 Baker 5" x 7" Liner Settinng Sleeve 12.95 11549.45 RS Nipple 3.42 11562.40 Baker 5 " X 7" "DG" Flexlock Liner Hanger 9.90 11565.82 XO Bushing 5" BTC x 4'/" SLHT 1.81 11575.72 Pup jt 4'/" SLHT 3.77 11577.53 Jts 22 to 23 2 Jts 4'/z', 12.6#, L-80, SLHT BLANK PIPE 80:08 11581.30 Jts 20 to 21 2 Jts 4'/z", 12.6#, L-80, SLHT SLOTTED LINER 78.68 11681.38 Jts 15 to 19 5 Jts 4'/z", 12.6#, L-80, SLHT BLANK PIPE 200.10 11740.06 Jts 14 to 14 1 Jts 4'/z", 12.6#, L-80, SLHT SLOTTED LINER 40.01 11940.16 Jts 11 to 13 3 Jts 4'/z", 12.6#, L-80, SLHT BLANK PIPE 120.44 11980.17 Jts 4 to 10 7 Jts 4'/z', 12.6#, L-80, SLHT SLOTTED LINER .281.47 12100.61 Jts 1 to 3 3 Jts 4'/z", 12.6#, L-80, SLHT BLANK PIPE 119.97 12382.08 Baker Guide Shoe 2.95 12502.05 12505.00 Total liner - 955.55' Remarks: Use Run-NSeal pipe dope. Up11Vt-210k Dn Wt-150k D. Burley/D. Mickey i ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert~admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us; Tom_Maunderr~admin.state.ak.us OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: ConocoPhillips Alaska Alipne 02/12/08 D. Mickey Packer Depth Pretest Initial 15 Min. 30 Min. Well CD3-316 Type Inj. ND 6,540' Tubing 2,500 3,000 3,000 3,000 Interval P.T.D. Type test P Test psi 3500 Casing 3,500 3,500 3,500 P/F P Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. ND Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waist G =Gas I =Industrial Waistewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I = IndialTest 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 9/1/05 MIT CD3316.x1s 02/27/oa ~~~~~~ Schlumberger-DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 Attn: Beth No. asos Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Alpine t Color Well Job # Log Description Date BL Prints CD CD3-316A 40016538 OH MWD EDIT 02/08/08 1 1 c90~1 / ~~ ~ ~ .<~k - ~. C ,, t i ~ t Ji ~t SIGNED: DATE: Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8367. Thank you. • ~~ ~~-- ~ ~„_,,,~ ,~ ~ ~ ~ ~ ~ ~.,,/ SARAN PALIN, GOVERNOR ALASKA OIL A1~TD GA$ 333 W 7th AVENUE, SUITE 100 CO1~T5~RQA7'I011T COI-II-IISSIOl~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jack Walker Staff Production Engineer ConocoPhillips Alaska, Inc. PO Box 100360 Anchorage, AK 99510-0360 Re: Colville River Field, Fiord Oil Pool, CD3-316A Sundry Number: 308-049 Dear Mr. Walker: Enclosed is the unapproved Application for Sundry Approval (Form 10-403) relating to the above referenced well. We are returning this Application for Sundry Approval unapproved since it is not needed. CPAI has not submitted Form 10-407 [Well Completion ...] initially completing the well. If it is desired to produce the well prior to any injection, then it is proper to list the well as a development well when that report is filed. Form 10-403 should be filed at such time that the well will be converted to injection service. If you have any questions, contact Tom Maunder, PE at 793-1250. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this ~ day of February, 2008 cc: Ms. Sharon Alsup-Drake, CPAI Encl. • ~~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~° ~B ~ ~ ~~Q~ APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 alas~Ca col ~ Gak ~tt~,. ~ommt~si~ll~ 1. Type of Request: Abandon ^ Suspend ^ Operational Shutdown ^ Perforate ^ `~ft8~ (other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ r` Time Extension ^ Convert Change approved program ^/ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ~ to producer 2. Operator Name: 4. Current Well Class: 5. Permit to D ' Number: ConocoPhillips Alaska, InC. Development ^ Exploratory ^ 208-0 ' 3. Address: Stratigraphic ^ Service Q 6. API tuber: P. O. Box 100360, Anchorage, Alaska 99510 50-10 205 -01 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Num r• where ownership or landownership changes: Spacing Exception Requires? Y@S ^ NO ^~ CD3-316A 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool( ADL 372104; 372105 ~ RKB 36' Colville Riv Fi / Oi Pool 12. PRESENT WELL CONDITI ON SUM RY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs ( asured): J nk (measured): 15140 6774 12505 6716 Casing Length Size MD D Burst Collapse CONDUCTOR 114 16" 114 SUR. CASING 2708 9-5/8" 2743 2475 PROD. CASING 11646 7" 11680 67 Slotted Liner 956 4-1/2" 125 16 Perforation Depth MD (ft): Perf tion De th TVD ): Tubing Size: Tubing Grade: Tubing MD (ft): no perforations no erfo lions 4-1 /2" L-80 11556 Packers and SSSV Type: ackers and S SV MD (ft) Baker Premier Packer Packer depth = 10824'MD Surface-controlled, wireline retrievable SSS SSSV depth = 2125'MD 13. Attachments: Description Summary of Proposal 14. Well Class after proposed work: Detailed Operations Program ^ BOP Ske Exploratory ^ Development ^~ Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: February 15, 2008 Oil ^~ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true a d correct to the best of my knowledge. Contact: Jack Walker Printed Name Jack Walker Title: Staff Production Engineer Signature Phone 265-6268 Date 2/12/08 Commission Use Only Sundry Num b er: i i pp ~~ J ~ ~ ~ Conditions of approval: Noti Commission so that a representa ve may w tness t C Plug Integrity ^ BO Test ^ Mechanical Integrity Test ~ Location Clearance ^ Other: S ~~~: ~~~ ~ ~ 2~~~ Subsequent F rm Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403 Revised 06/2006 S bmit in Duplicate Summary of Proposal CD3-316A Pre-Injection Production 10-403 Attachment February 12, 2008 CD3-316A was permitted as a service well in the Fiord Oil Pool of the Colville River Field. Prior to injection, a production period is requested for CD3-316A. Production of CD3-316A is proposed until injection support is needed for a well planned to be drilled in the future. Bottomhole pressure measurements are proposed before and after the production period. A wireline-retrievable, surface-controlled subsurface safety valve is planned for installation in CD3- 316A. ~ r l ~t g ~~ ¢ F. 4`T .J n-6 L..f t.,9 L. ~`3 '^..e~~ ~,J ~ -j ~ ~`~ ~ ['~.J ATIASSA OIL AHD (irA-~ COHSER'QA7'IO1~T COM1~II55IO1~T Chip Alvord WNS Drilling Team Lead Conoco Phillips Alaska Inc. PO Box 100360 Anchorage, AK 99510-0360 SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Colville River Field, Fiord Oil Pool, CD3-316A Conoco Phillips Alaska Inc. Permit No: 208-011 Surface Location: 1310 FSL, 971 FEL, SEC. 5, T12N, R5E Bottomhole Location: 1590' FNL, 451 FEL, SEC. 10, T12N, R5E Dear Mr. Alvord: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (CRU CD3-316 A PH) and API number (50-103-20559-71) from records, data and logs acquired for well CRU CD3-316A. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field in ec or at (907) 659-3607 (pager). `'Cha~~~ ~qnU qY~ - ~g~.- DATED this ~ day of D~nber, ~ ~ ~` cc: Depar ent of Fish & Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. STAT-E OF ALASKA ALASKA OIL AND GAS CONSERVATION COM ISSION JAN 2 4 20Q8 PERMIT TO DRILL ~~~p~aska 0ii & Gas Cons. Commissil~n 20 AAC 25.005 Anrfioraae 1 a. Type of Work: Drill ^ Re-drill ~ Re-entry ^ 1 b. Current Well Class: Exploratory Development Oil ^ Stratigraphic Test ^ Service 0 Development Gas ^ Multiple Zon~ Single Zone ^ 1 c. Specify if well is proposed for: Coalbed Methane ^ Gas Hydrates ^ Shale Gas ^ 2. Operator Name: ConocoPhillips Alaska, Inc. 5. Bond: ~ Blanket Single Well Bond No. 59-52-180 11. Well Name and Number: CD3-316A/CD3-316A P61 3. Address: P.O. Box 100360 Anchorage, AK 99510-0360 6. Proposed Depth: MD: 15669' TVD: 6695' 12. Field/Pool(s): Colville River Field 4a. Location of Well (Governmental Section): Surface: 1310 FSL; 971 FEL; Sec. 5 , T 12 N R 5 E 7. Property Designation: ADL 372104, 372105. Fiord Kuparuk Oil Pool Top of Productive Horizon: 4023 FNL. 3256 FEL, Sec.3 , T 12 N R 5 E 8. Land Use Permit: LAS2112 13. Approximate Spud Date: Actual 111512008 Total Depth: 1590` FNL. 451 FEL, Sec. 10 , T 12 N R 5 E 9. Acres in Property: 2560 14. Distance to Nearest Property: +4 mi fram ADL391 25 > s,K,~ ~'~~ ~2~ e 4b. Location of Well (State Base Plane Coordinates): Surface: x- 3$$071.4$ y- 6003806.84 .Zone- 4 10. KB Elevation (Height above GL): 36.3 RKBL, 49.5 MSL 15. Distance to Nearest Well within Pool: CD3-107 3019' at 11350' MD /• L`F 16. Deviated wells: Kickoff depth: 400 & 6050' MD Maximum Hole Angle: 90° deg 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.os5) Downhole: 3029 psig Surface: 2359 psig - 18. Casing Program i S f Setting Depth Quantity of Cement Size icat ons peCl Top Bottom c. f. or sacks Hole Casing Weight Grade Coupling Length MD TVD MD TVD (including stage data) 8.75" 7" 26# L-80 BTCM 11632 37 37 11669 6729 218 sx Class G, 183 Sx class G for K2 4.5" 12.6# L-80 IBT-M 11484 32 32 11516 6725 tubing 6.125" 4.5" 12.6# L-80 SLHT 140 11519 6725 11659 6695 Slotted Liner 19 PRESENT WELL CONDITION SUMMARY (To be completed for Redrill and Re-Entry Operations) Total Depth MD (ft): 9408 Total Depth TVD (ft): 7211 Plugs (measured) 5850 Effective Depth MD (ft): 5850 Effective Depth TVD (ft): 4675 Junk (measured) Casing Length Size Cement Volume MD ND Conductor/Structural 77 16" pre-installed 114 114° Surface 2,710 9-5/8" 383 sx ASLite, 234 sx 15.8 G 2747 2,484.00 Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): 20. Attachments: Filing Fee ^ BOP Sketc Drilling Progra ~ Time v. Depth Plot ^ Shallow Hazard Analysis Property Plat ^ Diverter Sketct^ Seabed Repor^ Drilling Fluid Program ^ 20 AAC 25.050 requirements^ 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact L. Gatiunas Printed Name C. Alvord Title WNS Drilling Team Lead Signature I O fLii( Phon 265-6120 Date 1 I~.IZo off/ ' L. (~ ~ ~- L. litrna Commission Use Only Permit to Drill /~ Number: ~~ "(/~~ API Number: ~--p 50- ~~'3 ' Z ~ 5.7 / ~ d~ Permit Ap royal Date: , See cover letter for other requirements Conditions of approval : If box is checked, well may not be used to explore for, test, or produce co bed met ne, gas hydrates, or gas contained in shales: \T~ LQ3"Ct~-C~>~G\i~"l `O Samples req'd: Yes ~ ~d ~ Mud log req'd: Yes ^ No Other: 2 Cf'1~ >, ~,~ ~\ ~~ ~~~ t _ ~ H2S measures: Yes ~ ~t/o ^ Dire tional svy req'd: es [~No APPROVED BY THE COMMISSION ~' ~i-/~ DATE: ,COMMISSIONER Form 10-401 Revised 12/2005 ~.~ ~ ~ Submit in Duplicate,. !•aYv15 i ConocoPhillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907-276-1215 January 23, 2008 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 ~onac© hili s ©© ~a ~ / dT~~ Y A~~~~~ l~il ~ ~~~ C~n~f tinl~~~6!~~ Anchars~~e Re: Application for change of Approved Program: Re-drill CD3-316 (Permit no. 207-177) Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Permit to change the approved program for CD3-316. The intended start date for the re-drill is 1/24/2008. Operations for CD3-316A began on January 15th, 2008 with Doyon 19 and on January 22th TD was reached and no Kuparuk C sand was found. It was decided to plug back the existing well bore with cement, and sidetrack to another out board location north-east of the orginal landing location (CD3- 316A). The pilot hole will be abandoned with an abandonment plug (to cover the Nechelik sand) and one kick off plug (see sundry application submitted 1-23-08 for more information). A mud gap will be left between the kick off plug and the abandonment plug. The well, CD3-316A, will be kicked off at approximately 6,050' MD and another pilot hole drilled to assure the presence of the Kuparuk C sand. If found, the pilot hole (CD3-316A PB1) will be plugged back with one abandonment plug plus a kickoff plug (see schematic). The well then be re-landed in the Kuparuk C sand horizontally (CD3-316A). After setting 7" intermediate casing, the horizontal section will be drilled and the well completed as slotted liner producer. The well will be flowed back to mitigate formation damage and then be closed in awaiting completion of well work for the well to begin production. The K2 (Qannik) sand will be considered a significant hydrocarbon bearing zone (since it was encountered while drilling CD3-316). The plan is to pump lead cement to over the Kuparuk sand, then open a stage tool and pump a second cement job to isolate the K2 sand with 500' of cement above and below the interval. This will leave a mud gap between the two stages. The 8-3/4" original plugged back hole will maintain the name CD3-316. Once re-drilled, the new sidetracked pilot hole will become CD3-316A PB1 with an API extension -71 and the final wellbore will be called CD3-316A with API extension of -01. 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. A proposed drilling program 3. A drilling fluids program summary. 4. Proposed plug back schematic 5. Proposed completion schematic 6. Pressure information as required by 20 ACC 25.035 (d)(2). 7. Directional drilling/collision avoidance information as required by 20 ACC 25.050 (b). Information pertinent to the application that is presently on file at the AOGCC: 1. Diagrams of the BOP equipment, diverter equipment and choke manifold lay out as required by 20 ACC 25.035 (a) and (b). 2. A description of the drilling fluids handling system. If you have any questions or require further information, please contact Liz Galiunas at 265- 6247 or Chip Atvord at 265-6120. Sincerely, 1 Liz Gali s Drilling ngineer Attachments cc: CD3-316A Well File /Sharon Allsup Drake ATO 1530 Chip Alvord ATO 1577 Vern Johnson ATO 1702 Jack Walker ATO 1740 s CD3-316A 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) 8-3/4" Hole / 7" Casing Interval Event Risk Level Miti ation Strate Abnormal Pressure in low BOPE drills, Keep mud weight above 9.6 ppg. Surface Formations Check for flow during connections and if needed, >2000' TVD increase mud wei ht. Lost circulation Low Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitoring, weighted swee s. Abnormal Reservoir low Well control drills, increased mud weight. No Pressure mapped faults occur within 700' of the planned wellbore. Hydrogen Sulfide gas Low ~ HZS drills, detection systems, alarms, standard well control ractices, mud scaven ers 6-1 /8" Hole /Horizontal Production Hole Event Risk Level Miti ation Strate Lost circulation moderate Reduced pump rates, reduced trip speeds, real time equivalent circulating density (ECD) monitoring, mud rheolo ,lost circulation material Hole swabbing on trips Moderate Reduced trip speeds, Pump out to 7" shoe, mud properties, proper hole filling, pumping out of hole, real time equivalent circulating density (ECD) monitorin ,wei hted swee s. Abnormal Reservoir Medium BOPE drills, Keep mud weight above 8.8 ppg. Pressure Check for flow during connections and if needed, increase mud weight. Well control drills, increased mud wei ht. Hydrogen Sulfide gas Low HZS drills, detection systems, alarms, standard well control ractices, mud scaven ers J ORIGINAL ~ ~ Fiord : CD3-316A Procedure 1. Pick up and run in hole with 8-3/4" drilling BHA. (LWD Program: GR/RES/DENS/NEUT/PWD) 2. Kick off old wellbore at +/- 6050' MD and drill 8-3/4" hole to intermediate to new pilot location of 11497' MD / 6809' TVD. 3. Assuming Kuparuk C sand is found, POOH and pickup cement stinger. RIH and lay 15.8 ppg class C cement plug from TD of 11497' MD to 11097' MD. ,~ 4. Lay 17 ppg cement kick off plug from 11097' MD to 10697' MD. Pick up to 10697' MD and circulate hole clean. POOH and lay down cement stringer. 5. Pick up and run in hole with 8'/" drilling BHA and kick off from 10897' MD. 6. Drill 8 3/<" hole down to casing point in the Kuparuk C sand +/- 11669' MD. (LWD Program: GR/RES/DENS/NEUT/PWD) 7. Run and cement 7" casing as per program. Carry out a leak off test down the 9-5/8" x 7" casing annulus to confirm the fracture pressure referenced to the casing shoe. Freeze protect casing annulus and casing. 8. BOPE test to 3500 psi. 9. Run drilling assembly. Pressure test casing to 3500 psi. Drill out and perform formation integrity test to 12.5 ppg EMW. Minimum acceptable leak off for drilling ahead is 11.0 ppg EMW. 10. Drill 6-1/8" horizontal section to well TD (LWD Program: GR/RES/PWD). 11. Circulate the hole clean and pull out of hole. 12. Run lower completion of 4-'/z", 12.6# L-80 SLHT blank and slotted liner and liner hanger. 13. Run upper completion of 4-'/z, 12.6#, L-80 tubing with BAL-O landing nipple, permanent pressure gauge, packer, 1 GLMs with dummy valve in mandrel, XN profile and wireline entry guide. Land hanger. 14. Install 2 way check and pressure test hanger seals to 5000 psi. Nipple down BOP. 15. Install tubing head adapter assembly. Pressure test adapter assembly to 5000 psi. Remove 2 way check. 16. Circulate tubing to diesel and install freeze protection in the annulus. 17. Drop ball and rod, set packer and test tubing and annulus to 3500 psi / 30 mins. 18. Set BPV and secure well. Move rig off. Post rig well work will include pulling the ball and rod assembly. ORIGINAL ~ ~ Well Proximity Risks: Directional drilling /collision avoidance information as required by 20 ACC 25.050 (b) is provided in following attachments. There are no existing well proximity risks from the KOP of 6050' MD to TD in CD3- 316A or CD3-316A PB1. Drilling Area Risks: There are no high-risk events (e.g. over-pressures zones) anticipated. Lost circulation: Faulting and low reservoir pressure within the Kuparuk reservoir section is considered to be the most likely cause of lost circulation. Standard LCM material and well bore strengthening pills are expected to be effective in dealing with lost circulation. 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 Pumping Operations: Incidental fluids developed from drilling operations on well CD3-316A will be injected into a permitted annulus on CD3 pad or the class 2 disposal well on CD1 pad. The CD3-316A surface/intermediate casing annulus will be flushed with 300 bbls of fresh water prior to freeze protecting with diesel to 2000' TVD. The significant hydrocarbon zones are the Kuparuk and the Qannik reservoir. There will be 500' of cement fill above the top of the Kuparuk and Qannik reservoirs. Upon completion of CD3-316A form 10-403, Application for Sundry Operations, will be filed. Annular pumping of fluids occurring due to drilling operations, per regulation 20 AAC 25.080, could then begin once properly permitted. As stated above, any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's 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) * (2747') + 1,500 psi = 3214 psi Pore Pressure = 1,086 psi Therefore Differential = 3214 - 1086 = 2128 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: OD Wt (ppf) Grade Range Connection Type Collapse 85% of Collapse Burst 85% of Burst 9-5/8" 40 L-80 3 BTC 9,090 psi 1,717 psi 5,750 psi 2,992 psi 7" 26 L-80 3 BTC-Mod 5,410 psi 4,599 psi 7,240 psi 6,154 psi ORIGINAL ~ ~ DRILLING FLUID PROGRAM Intermediate hole to 7" casin oint-8'/" Production Hole Section - 61/8" Density 9.6 - 9.8 PP9 8.8 PP9 PV 10 - 25 10 -15 YP 15 - 25 25 -30 Funnel Viscosity Initial Gels 4 - 8 10-15 10 minute gels <18 12-20 API Filtrate 4 - 12 cc/30 min NA HPHT Fluid Loss at 160 (drilling) 12-14 cc/30 min PH 9.0 -10.0 9.0-9.5 KCL 6% Intermediate Hole Section: d~ 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 reservoir 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 wellbore stability. Production Hole Section The horizontal production interval will be drilled with a M-I Flo-Pro drill-in fluid. The base fluid will consist of 6% KCI, with ± 30PPB calcium carbonate bridging material to minimize formation damage. Flo-Vis Polymer and Dual-Flo starch will be used for viscosity and fluid loss control respectively. ORIGINAL CD3-316 Plugback Schematic (1-23-08) CD3-316 RKB-GL=36.3' 9.6 ppg drilling mud i f KOP +/-8,051 Top Nechelik Res +/-9186' MD Updated 1/22/08 Acutal surveys ~ Wellhead 6" Conductor to 114' " 40 ppf L-80 BTCM Surface Casing '55' MD / 2483' TVD rented to surface Plug #2:600' Kick off olua Too at +l- 5850' MD 17 ooa. Plug #1 • +/- 500' Too (aa +/-8871' MD 15.8 ooa Pilot Hole @ +/- 39 deg TD at +/- 9408' MD / 7211 ND < ~~~~~~ CD3-316A PB1 Plugback Schematic CD3-316A PB1 Updated 1 /22/08 RKB - GL = 36.3' Sperry Directional plan: - - wp06 - ~` Wellhead 16" Conductor to 114' 9-5/8" 40 ppf L-80 BTCM Surface Casing @ 2755' MD / 2483' TVD cemented to surface 9.6 ppg drilling mud in hole 10697 KOP +/-10886' ~~:_ ~ Plua #2:400' Kick off alua Top at 400 +/-10697' MD 17 uoa. 11097 „. . Top Kuparuk Reservoir at 400 Plug #1 : +l- 400' Toa (a~ +/-11097' MD +/_11300' MD !6729' TVD ' i'E'....: ~ 15.8 ooa Pilot Hole @ +/- 39 deg TD at +/- 11497' MD / 6809 TVD ' ^~RIGINAL Completion Schematic Planned CD3 - 316A Fiord Kuparuk Injector Completion 1-23-08 16" Insulated Conductor to Sperry Sun -114' Directional Plan WP06 1 /23108 3 3.812" BAL-O Landing nipple for wireline retrievable SSSV (DB profile) with one line plugged. 9-5/8" 40 ppf L-80 BTCM Surface Casing 2755' MD / 2483' ND Uooer Completion: Too MD ~/Q 4-'/" 12.6 ppf L-80 IBT Mod Tubing !t€~-! 1) Tubing Hanger 32' 32' 2) 4-''/z" 12.6 #/ft IBT-M Tubing 3) 4-'/~' BAL-O with one port plugged (3.812") 2091' 2000' 4) 4-''/z" 12.6 #/ft IBT-M Tubing 5) 4-''/z" X Nipple (3.813") Cement to +/- 4500' 6) Crossover 4-''/z" IBT-M to STL MD / 3722' ND 7) 2 jts 4 ''/z" ST-L 8) 10' pup ST-L '° Qannik interval top +/- 9) 4''/z" Baker Gauge/gauge 10600' 6464' 5000' MD / 4076' TVD 10) 10' pup ST-L 11) 2 jts ST-L Stage 12) Crossover to 4 ''/z" IBT-M to STL ' cementing tool 13) 4 ~/i 12.6 #/ft IBT Tubing (2 jts) +/- 5512' MD / 14) Camco KBG-2 GLM (3.833" ID) 10800' 6559' 4387' ND With dummy valve 15) 4?/~' 12.6 #!ft IBT-M Tubing (2 jts) 16) Baker Premier Packer at 70 deg 10850' 6576' 17) 4-''/z" 12.6 #/ft IBT-M Tubing 1 jt 18) HES No-Go XN (3.725") @ 70 deg 10900' 6593' 19) 4-''/i' 12.6 #/ft IBT-M Tubing 20) BOT Stinger w/fluted WLEG/ pup/shear sub 11516' 6725' Stung into tie extension 10' off bottom of at 11529' Lower Completion: Too MD T D Item 21) Baker 5" x 7" Flexlock Liner Hanger 11519' 6725' 5 22) 4-'/i' 12.6 #/ft, SLHT Tubing +/- 3 jts 23) 4 '/z" 12.6 #/ft, SLHT liner w/ blank across shale and slots across sand 24) Baker Shoe 15659' 6695' Top of cement g 10550' MD / 6473' ND \'~~ 4-'/~' 12.6#/ft L-80 SLHT Mod Slotted liner Pattern: (+/- 300' above Packer) 32 slots / ft, 2 '/," x 1/8" slots Kuparuk 11588' MD / 6729' ND 7" 26 ppf L-80 BTC Mod Production Casing @ +/-90° 11669' MD, 6729' ND TD 6-118" hole 15669' MD / 6695' ND '??IGINAL • CD3-316A 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 in Csg Setting Depth MD/TVD ft Fracture Gradient lbs. / al Pore pressure si ASP Drilling si 16 114 / 114 10.9 52 53 9 5/8 2755 / 2483 14.5 1125 1623 7" / TD 11669 / 6729 16.0 3044 - 2359 N/A 15669 / 6695 16.0 3029 - N/A NOTE: The Doyon 19 5000 psi BOP equipment is adequate. Test BoF~'s to SUUU 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]D 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 ASP CALCULATIONS Drilling below conductor casing (16") ASP = [(FG x 0.052) - 0.1 ] D =[(10.9x0.052)-0.1]x114=53 psi OR ASP =FPP - (0.1 x D) = 1123 - (0.1 x 2483') = 874 psi 2. Drilling below surface casing (9 5/8") ASP = [(FG x 0.052) - 0.1] D _ [(14.5 x 0.052) - 0.1] x 2483 = 1623 psi OR ASP =FPP - (0.1 x D) = 3044 - (0.1 x 6729') = 2371 psi Drilling below intermediate casing (7") ASP =FPP - (0.1 x D) = 3029 - (0.1 x 6695) = 2359 psi ORIGINAL • Cementing Program: • 7" Intermediate Casing run to 11669' MD / 6729' TVD Cement from 11669' MD to 10550 +/-' MD (minimum 300' MD above top of packer depth) with Class G + adds @ 15.8 PPG. Assume 40% excess annular volume. Tail: (11669' -10550') X 0.1503 ft3/ft X 1.4 (40% excess) = 235.5 ft3 annular vol. 80' X 0.2148 ft3/ft = 17.2 ft3 shoe joint volume Total volume =235.5 + 17.2 = 252.7 ft3 => 218 Sx @ 1.16 ft3/sk System: 218 Sx Class G + 0.2% D046 antifoamer, 0.25% D065 dispersant, 0.25% D800 retarder and 0.18% D167 fluid loss additive @ 15.8 PPG yielding 1.16 ft3/sk Second Stage: Cement from ports in a ES stage collar set 500' below the KZ interval to +/- 500' above the K2 interval with Class G + additives @ 15.8 ppg. Assume 40% excess annular volume Lead: (5512'- 4500') X 0.1503 ft3/ft X 1.4 (40% excess) = 212.9 ft3 annular vol Total Volume = 212.9 ft3 => 183 Sk @ 1.17 ft3/sk System: 183 Sx Class G + 0.2% D046 antifoamer, 0.3% D065 dispersant and 1% 5002 accelerator @ 15.8 PPG yielding 1.17 ft3/sk l ~~~ Calculation Method: Minimum Curvature Error System: ISCWSA ~''~ Scan Method: Trav. Cylinder North Project: Western North Slope ConocoPhillips Errors~naoe Enip<ioalcon;o Site: CD3 Fiord Pad Warning Me[had: Rules Based Geoaetie oamm: Nortn American oamm 1983 Well: Rig: CD3-316 Magnetic Model: BGGM2(107 Wellbore: Plan: CD3-316A Ground Level: 0.00 RK©: Plan: CD3-316 (36.3+13.2) ~ 4450ft (Doyon 19 (36.9+13.20 CD3-316Awp06 NorthinglASP Y: 6003554.04 ' EaslinglASP X: 1x28103.39 109 14000 ~a3 - ~ 10 ~'~ ~~~ 10 Off" i I ~~ G~~1 C~„~ 10500 ~ - - ~, ~~ 01 ~, ~;;, C~"'o ~~ ,~ ~ 7000 _ I ~ 3-3~~ n CO v o z 3500 - - - ~ ~~~ .-. ~ ~~ o ~' 0 _ - ~ D3-316wp05 Heel - 6 a ~QO aTi . - ~6Q' ~ GQ~ i _rn -3500 _ ~ - _ - _ _. CD3-316wp05 Toe M M 0 ~ --. _ _- - V~ .-__-___ -. _.. -14000 -10500 -7000 -3500 0 3500 7000 10500 14000 West(-)/East(+) (3500 ft/in) ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD3 Fiord Pad Rig: CD3-316 Plan: CD3-316A Plan: CD3-316Awp06 Standard Proposal Report 23 January, 2008 H,ALLIE3URT01\i Sp®rry Driiling S~rvic~~ ORIGINAL r~~ -.Q-~ r~OC~'~~'n~ w„ stem: ISCWSA Scan Trav. Cylintler North Errnr urtace Elliptical conic Warning Method: Rules Based Western North Slope M Grodeti`~at°'n: NorthA'neri°an~at°^'1987 Magnetic Model: 6GGM2007 CD3 Fiord Pad C ~ D3 316Aw 06 Rig: CD3-316 Ground Level: 0.00 RKB: Plan: CD3316 (36.3+13.2) @ 49.SOtt (Doyon 19 (36.3+13.2)) Plan: CD3-316A NorthinglASP Y: 6003554.04 EastinglASP X: 1528103.39 CD3-316Aw 06 p rn ~ ~ 2000 , "0 ~ I i~ O I ~ ~ __ ~ ' " " 0 _ _ " " -- 7 x 8-3/4 _ T ~ 9-5/8 x 12-1 /4 T1~ - O ~ N `~' ~ CD3-316wp05 Heel + ~ ~ ~ o ~ ~ ~P~Q ` ~~ z -2000 ~ -_ ~ O ~ G ~ o ~ - ~ 4-1/2" x 6-1/8" ~ ~ U CD3-31 ~ 6wp05 Toe -4000 0 2000 4000 6 i 000 8000 ~ 10000 12000 West(-)/East(+) (2000 ft/in) 0 _a , _ ~ 10 20 o N 2500 `. ~,~ ~~ 9-5/8" x 12-1 /4" TD ~ ~ I N ~ ~ OHO ~ I ~Q U ~^ ~ 5000 _ h°o ~ ~ D 0 ~, 5 e g L ', /~~ \~J ~ ~ ~ ~t~6 C° ~ 4-1 /2" x 6-1 /8" ~ O G I ~ °CD3-316wp05 (Heel 7500 - -- -- - - i- - - -_ CD3-316wp05 Toe ~- - -2500 - 0 2500 5000 ~- 7500 10000 a ~i 12500 ORIGINAL ~onocoPhifiips ..a..~~,~Error System ~~~ISGWSA u~~-,u~c Scan Method: Trav. Cylinder North Error Surtace: Ellipt'c I Gonic Warning Method: Rules Based Geodetic Datum: North American Datum 1983 Magnetic ModN: BGGM2997 Ground level: 0.00 RKB: Plan: CD3J16 (36.3+13.2) ~ 49.50ft (Doyon 19 NorthinglASP Y: 6003554.04 EastinglASP X: 1528103.39 Western North Slope CD3 Fiord Pad D3-316Aw 0 Rig: CD3-316 Plan: CD3-316A 2)) : - 3/4" 7" 8 __-_ i 1 4 1 /2" 6 ~ o D x - - x - o ~ ~ rn ~ ~ w ~ o " _-- CD3-316wp ~ 05 Toe c~ 8-3/4 O o`° CD3-316wp05 Heel - o Q '' Q~ D ~~ ~ ^ rn i~ '~ /8" 7000 7500 8000 8500 9000 9500 10000 10500 11000 11500 • Database: EDM v16 Prod Company: ConocoPhillips(Alaska) Inc. -WNS Project: Western North Slope Site: CD3 Fiord Pad Well: Rig: CD3-316 Wellbore: Plan: CD3-316A Design: CD3-316Awp06 ConocoPhillips Standard Proposal Report Local Co-ordinate Reference: Well Rig: CD3-316 TVD Reference: Plan: CD3-316 (36.3+13.2) @ 49.50ft (Doyon 19 MD Reference: Plan: CD3-316 (36.3+13.2) @ 49.50ft (Doyon 19 North Reference: True Survey Calculation Method: Minimum Curvature , Project Western North Slope. North Slope Alaska, United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Site CD3 Fiord Pad Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Slot Radius: Well Rig: CD3-316 Well Position +N/-S 0.00 ft Northing: +E/-W 0.00 ft Easting: Position Uncertainty 0.00 ft Wellhead Elevation Wellbore Plan: CD3-316A Magnetics Model Name Sample Date BG G M2007 1 /23/2008 6,003,634.02 ft Latitude: 1,528,520.01 ft Longitude: 0" Grid Convergence: 6,003,554.04 ft Latitude: 1,528,103.39ft Longitude: ft Ground Level: 70° 25' 9.315 N 150° 54' 41.768 W -0.86 ° 70° 25' 8.467 N 150° 54' 53.950 W 0.00 ft Declination Dip Angle Field Strength 22.34 80.75 57, 584 Design CD3-316Awp06 , Audit Notes: Version: Phase: PLAN Tie On Depth: Vertical Section: Depth From (TVDJ +N/-S +E/-W 36.30 0.00 0.00 __ Plan Sections - Measured Vertical TVD Depth Inclination Azimuth Depth System +N/-S +E/-W (ft) (°) (°) lft) ft (ft) (ft) 10,886.00 70.02 83.30 6,588.03 6,538.53 205.82 7,578.67 11,277.93 79.19 110.18 6,693.77 6,644.27 160.01 7,949.36 11,278.28 79.19 110.18 6,693.83 6,644.33 159.89 7,949.68 11,669.72 90.50 135.30 6,729.50 6,680.00 -49.58 8,274.00 15,669.74 90.50 135.30 6,694.50 6,645.00 -2,gg2.g2 11,087.33 10,886.00 Direction (°) 104.62 Dogleg Build Turn Rate Rate Rate (°MOOft) (°/100ft) (°1100ft) 0.00 0.00 0.00 7.00 2.34 6.86 0.00 0.00 0.00 7.01 2.89 6.42 0.00 0.00 0.00 Tool Face (°) 0.00 74.49 0.00 67.21 0.00 ~I 1/23/2008 12:04:31PM Page 2 COMPASS 2003.16 Build 42F ~~~~~~ ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD3 Fiord Pad Rig: CD3-316 Plan: CD3-316A CD3-316Awp06 .v ~7@~''~''~/ ~"'~~~IR"1 ~f'V~~~S s ~ Clearance Summary ~' Anticollision Re ort p ~ ~"` 23 January, 2008 I~ Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad -Rig: CD3-316 -Plan: CD3-316A -CD3-316Awp06 Well Coordinates: 6,003,554.04 N, 1,528,103.39E (70° 25' 08.47" N, 150° 54' 53.95" W) 3+13 2 19 36 . )) ( . Datum Height: Plan: CD3-316 (36.3+13.2) @ 49.50ft (Doyon Scan Range: 10,886.00 to 15,669.74 ft. Measured Depth. Scan Radius is 1,763.34 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 42F Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 HAL~.IBURTCIIV 8rp®rry Driliing IBervics~ ConocoPhillips(Alaska) Inc. -WNS HALLI BURTON Western North Slope Anticollision Report for Rig: CD3-316 -CD3-316Awp06 Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad -Rig: CD3-316 -Plan: CD3-316A -CD3-316Awp06 Scan Range: 10,886.00 to 15,669.74 ft. Measured Depth. Scan Radius is 1,763.34 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name -Design (ft) (ft) (ft) (ft) ft CD3 Fiord Pad Plan: CD3-305 -Plan: CD3-305 -CD3-305wp03 15,267.76 1,429.74 15,267.76 1,218.93 13,275.00 6.782 Centre Distance Pass -Major Risk Plan: CD3-305 -Plan: CD3-305 -CD3-305wp03 15,518.46 1,444.31 15,518.46 1,203.98 13,600.00 6.010 Clearance Factor Pass -Major Risk Rig: CD3-316 -Plan: CD3-316APB1 -CD3-316APB1w FAIL -Major Risk Rig: CD3-316 -Plan: CD3-316AP61 -CD3-316APB1w FAIL -Major Risk --'q~ i1J Survey tool program From To Survey/Plan Survey Tool (ft) (ft) 81.00 442.00 CB-GYRO-SS 511.39 6,050.00 MWD+IFR-AK-CAZ-SC 6,050.00 10,886.00 MWD+IFR-AK-CAZ-SC 10,886.00 15,669.74 CD3-316Awp06 MWD+IFR-AK-CAZ-SC Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor =Distance Between Profiles / (Distance Between Profiles -Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 23 January, 2008 - 12:13 Page 2 of 4 COMPASS HALLIBURTON ConocoPhillips(Alaska) Inc. -WNS Western North Slope Anticollision Report for Rig: CD3-316 -CD3-316Awp06 Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to Plan: CD3-316 (36.3+13.2) @ 49.50ft (Doyon 19 (36.3+13.2)). Northing and Easting are relative to Rig: CD3-316. Coordinate System is US State Plane 1983, Alaska Zone 4. Central Meridian is -150.00°, Grid Convergence at Surface is: -0.86 °. Ladder Dln~ .....r V J ~~ 1 1500- 0 O ~f7 O t~ t4 1 ~~~- Q} ~7 C O 500- Q1 C • i 1 • 0 i i i i i i i i i i i i i i i ~ i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i i ~ i i i i i i ~ i i i ~ i i i ~ i i i i i i i ~ i i i i i i i ~ i i i i i i i i i i i i i i i i i i i i i i i i i i i ~ i i i ~ i i i ~ i i i i i i i i i i i ~ i i i i i i i ~ ~ i i i i i i i i i i i i i i i i i i I I 1 ~ ~ 3000 6000 9000 1000 15000 Measured Depth (3000 ftlin~ ig: an: , Rig: CD3-316, Rig: CD3-316, CD3-316 Rig Surve CD3-1D8, CD3-10$, CD3-108 V14 CD3.1D8, CD3-108, Plan: CD3-1D8 (wp06}kr16 CD3-109, CD3-109, CD3-1D9 V5 CD3-109, CD3-109, CD3-1D9wpD6 ~f3 CD3.110, CD3-110, CD3-110 V1? CD3-110, CD3-110, CD3.110wp06 V1 CD3-111, CD3-111 , CD3.111 V7 CD3-111, CD3.111, CD3-111wp02 ~1 CD3-111, CD3-111 L1, CD3-111L1 V1 CD3-112, CD3.112, CD3-112 tt3 CD3.112, CD3-112, CD3-112wp03 V3 CD3.113, CD3-113, CD3-113 VB CD3-113, CD3-113, CD3-113PBtwp03 V13 CD3-114, CD3-114, CD3-114 V14 CD3-3D7, CD3.107, CD3-1D7 V7 CD3-307, CD3-3D7,CD3-3D7 V4 CD3-307. CD3-3D7, Plan: CD3-107 (wp01) V4 CD3-3D7, Plan: CD3-1D7A, CD3.107AwpD1 V1 Plan: CD3-1D6, Plan: CD3-1D6, Plan: CD3-106 (w Plan: CD3-115, Plan: CD3-115, CD3-115wpD3 V4 Plan: CD3-117, Plan: CD3-117, CD3-117wp02 x+16 Plan: CD3-11$, Plan: CD3-118, CD3.118wp02 V$ Plan: CD3-304, Plan: CD3-3D4, CD3-3D4wpD7 kJ2 Plan: CD3-304, Plan: CD3-304PB1, CD3-304PB1 Plan : C D 3-305 ,Plan : C D3.305 , C D 3-305 w p03 V5 w „. _ . ..., ~, -.. o ., . _ . .. r, ., ~ . o ,. r. ~ -.. a ........ . .. .. ..., 23 January, 2008 - 12:13 Page 3 of 4 COMPASS ConocoPhillips(Alaska) Inc. -WNS HALLIBURT~N Western North Slope Anticollision Report for Rig: CD3-316 -CD3-316Awp06 Clearance Factor Plot: Measured Depth versus Separation(Clearance) Factor ~' ~" 10.04 - 8. ~ 5 ~- -~ c .SU _.~ o ~ u~ tai ` ' ~' ~ 6.~5 o ~ $ C 5.00 0 _ . ~ ~ co ~' Q ~ ~r ^ '~ I. _5 4.00 0 1500 3000 ~SUD n004 7500 9000 14500 12G04 135U0 15000 Ib500 18004 ~~ M easurer~ ^epth (3000 ftJln) $ Rig: GD3-316, Plan:GD3-316APB1 ,GD3-316APB1wp0 Rig: CD3-316, Rig: CD3-316, CD3-316 Rig Surtreys W CD3-10$, CD3-108, CD3-10$ V14 GD3-108, C03-108, Plan: GD3-108 I;wp06)tir1~ CD3-109, CD3-109, CD3-109 V5 GD3.109, CD3-1D9, CD3-109wp06 'J3 GD3-110, CD3-110, CD3-110 V12 • CD3-110, CD3-110, CD3-110wp06 V1 CD3-11 1, CD3.111 ,CD3-111 V7 CD3-11 1, GD3-111 ,CD3-111 wp02 1!1 CD3-11 1, CD3-111 L1, G03-1 11 L1 V1 GD3-112, CD3-112, CD3.112 V3 CD3-112, CD3.112, CD3-112wp03 ~F3 GD3-113, CD3-113, CD3.113 ~r16 CD3-113, CD3.113. CD3.113 PB1wp03 V13 CD3.114, CD3-114, GD3-114 V14 CD3-307, CD3-107, CD3 -1 D7 V7 CD3-307, CD'3-307, CD3-307 V4 CD3-307, CD3-307, Plan: CD3-1 D7 I;wp01)V4 CD3-307, Plan: GD3-107 A, CD3-107Awp01 V1 Plan: CD3-106, Plan: CD3-106, Plan: CD3-106 (wp01j` Plan: CD3.115, Plan: GD3-115, CD3-115wp03 V4 Plan: CD3-117, Plan: CD3-117, CD3.117wp02 V16 Plan: CD3-11 $, Plan: CD3-11$, CD3-118wp02 V8 Plan: GD3.304, Plan: CD3.304, GD3-304wp07 ~2 Plan: GD3-304, Plan: CD3-304PB1 ,CD3-304P B1wp07 Plan: CD3-305, Plan: CD3.305, CD3-305wp03 V5 pin-f'11'k_`k7R Ain f`r1Q_'k7R f`rl'2-21RPG iwnnd kfR 23 January, 2008 - 12:13 Page 4 of 4 COMPASS • • • ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD3 Fiord Pad Rig: CD3-316 Plan: CD3-316APB1 Plan: CD3-316APB1wp06 Standard Proposal Report 23 January, 2008 HALL.IBU~TQN Sperry Grilling Servic®~ ORIGINAL r~ C Ph lh yst A Bran Met od: Tr ylinder North Error Surtara: Elliptical Gonic Warning Method: Rules Based Western North Slope onnco ~ S p Geodetic Datum: North American Datum 1983 Magnetic Model: BGGM2007 CD3 Fiord Pad t• D3 316APB1 wp Rig: CD3-316 Ground Level: 0.00 RKB: Plan: CD3J16 (35.3+13.2) @ 49.SOrt (Doyon 19 (36.3+13.2 Plan: CD3-316APB1 )) NorthinglASP Y: 6003554.04 EastinglASP X: 1528103.39 CD3-316APB1w 06 p ~ 1500 CD3-316AP61wp06 T2 O CD3-316APB1wp06 T1 ~ " ' x 12-1 /4 TD 9-5/8 ~ ~ ~ w Z I~ 1 T N ~ 63 ~ 7 ~ ~ i~ -1500 - ~ ~ ° ~ M 0 U -- ~ ~ 0 1500 3000 4500 6000 7500 9000 West(-)/East(+) (1500 ft/in) 0~ 10 C 20 O O 2500 - - - ---- ~ - DO ~~ 9-5/8" x 12-1 /4" TD - --- a~ 0 ~ o~ U ~Q ~ 5000 - --~ao ~ > ~ ~~ ~e5 J ~~ i ~ 0 , 0 ^ O ~ ~ " ~~ V CD3-316AP61wp06 T1 I 4 OH TD, ~G CD3-316AP61wp06 T2 7500 - - - - -- - _--- - - _ - - - -2500 0 2500 5000 7500 0 1.0000 ~d4Y1o~Error Syslem~ ISCWSA ~~~~~~~~ ~onocoPhi!lips Swn Method: Trav. Cylinder North Error surface: Elliptical conic Western North Slope Warning Method: Rules Based Geodetic Oatum: North American Datum 1983 Magnetic MOdel: BGGM2007 CD3 Fiord Pad Rig: CD3-316 Ground Level: 0.00 ~ Plan: CD3-316AP61 RKB: Plan: CD3-316 (36.3+13.2) ~ 49.SOft (Doyon 19 (36. +13.2)) NoRhinglASP Y: 6003554.04 EastinglASP X: 1528103.39 - - r - __ _ _ I ~D3-316APB1w 06 0 4800 ~~ h o h ~ ~~ ^o 0 0 5400 - ~ - 0 c ^° a - -- -- _ _ ~ 000 ~, a I .~-. c'' 8-3/4" OI a,=- I i ~~6600~ ___ I - - ---- 7 -- -~- I c~ _ - co C'_ CD3-316APB1wp06 T1 as • L 7200 ~ -3/4" OH TD ~~ ~ ___ __ _ - ! -- CD3-316APB1wp06 T ~ --- -- .`pg ~Q- ,~>\~o ;~ 7800 - I ' ' ~ ~~ - ~ 1 - -- _~ - - ~ 3000 3600 4200 4800 5400 6000 6600 7200 7800 Vprtir_al SPr_ti~n at RR_09° (600 ff/inl ~'• ~ ~ ConocoPhillips ~~~~~"'~""~~ Standard Proposal Report Database: EDM v16 Prod Local Co-ordinate Reference: Well Rig: CD3-316 Company: ConocoPhillips(Alaska) Inc. -WNS TVD Reference: Plan: CD3-316 (36.3+13.2) @ 49.50ft (Doyon 19 Project: Western North Slope MD Reference: Plan: CD3-316 (36.3+13.2) @ 49.50ft (Doyon 19 Site: CD3 Fiord Pad North Reference: True Well: 'Rig: CD3-316 Survey Calculation Method: Minimum Curvature Wellbore: Plan: CD3-316APB1 Design: CD3-316APB1wp06 Project Western North Slope, North Slope Alaska, United States Map System: US State Plane 1983 System Datum: Mean Sea Level Geo Datum: North American Datum 1983 Using Well Reference Point Map Zone: Alaska Zone 4 Using geodetic scale factor Site CD3 Fiord Pad ~... ., a , ~~... Site Position: Northing: 6,003,634.02ft Latitude: 70° 25' 9.315 N From: Map Easting: 1,528,520.01 ft Longitude: 150° 54' 41.768 W Position Uncertainty: 0.00 ft Slot Radius: 0" Grid Convergence: -0.86 ° Well Rig: CD3-316 Well Position +N/-S 0.00 ft Northing: 6,003,554.04 ft Latitude: 70° 25' 8.467 N ~, +E/-W 0.00 ft Easting: 1,528,103.39 ft Longitude: 150° 54' 53.950 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: O.OOft II Wellbore _ _ _ _ Plan: CD3-316APB1 __ ri Magnetics Model Name Sample Date Declination Dip Angle Field Strength BG G M20 07 1 /23/2008 22.34 80.75 57, 584 Design CD3-316AP61wp06 Audit Notes: ~ Version: Phase: PLAN Tie On Depth: 6,050.00 Vertical Section: Depth From.(TVD) +N/S +EI-W Directio n (ft) (ft) (ft) (°) 36.30 0.00 0.00 88.09 J - ___ Plan Sections Measured Vertical TVD Dogleg Build Turn Depth Incl ination Azimuth Depth System +N/-S +E/-W Rate Rate Rate Tool Face (ft) (°) (°) (ft) ft (ft) (ft) (°/100ft) (°/100ft) (°/100ft) (°) 6,050.00 45.76 91.97 4,817.37 4,767.87 -282.12 3,124.91 0.00 0.00 0.00 0.00 6,682.61 70.02 83.30 5,151.58 5,102.08 -254.79 3,655.28 4.00 3.83 -1.37 -19.34 11,299.98 70.02 83.30 6,729.50 6,680.00 251.19 7,965.07 0.00 0.00 0.00 0.00 11,497.36 62.12 83.30 6,809.50 6,760.00 272.21 8,144.11 4.00 -4.00 0.00 -180.00 1/23/2008 11:16:41AM Page 2 ~ _ C COMPASS 2003.16 Build 42F tGp\~(~E Operator. ConoeoPhillips(Alaska) Inc. -WNS Grid Correction: -0.86 Job No: #N/A Field: Western North Slope Magnetic Declination: 22.34 AFE No: #N/A Well: CD3-316Awp06 (AND 27) Plan Dip: 80.75 API No: #N/A Rig: #N/A Dogleg per: 100 f' North Reference: TRUE Surface Loeaflon Original VS Plane: 104.62 Parent Well: Rig: CD3-376 X: 388071.48 ft Vfew VS Plane: 104.62 RKB Height: 49.50 rt Y: 6003806.84 ft Meas. Incl. TRUE Subsea RKB Local ASP or Grid Dogleg Original Tool Build Turn Course Drilled Depth (h) Angle (deg) Azi. (deg) TVD (})) TVD (h) N(+)/S(-) Itt) E(+)/W(-) (ft) N~+)/S(-) Lat. (Y) E(+)/W(-) Dep. (X) Severity (°/100 ft) VS (105°) (#) Iffl Face (deg) (°/100 fi) (°/100 ff) Length (fi) Distance (H) 0 Commen}s 100.00 0.~` 93.98 50.50 100.00 -0.04 0.37 •6003806.79 •388071.85 0.00 0.36 200.00 0.51 706.66 150.50 200.00 -0.20 1.28 6003806.62 388072.75 0.12 1.28 a 175 -0.04 72.68 100.00 100.00 CB-GYRO-SS (1) 300.00 0.57 216.42 250.49 299.99 -0.73 1.41 6003806.09 388072.87 0.88 1.54 ;t 143 0.06 109.76 100.00 200.00 400.00 1.48 217.22 350.48 399.98 -2.16 0.33 6003804.67 388071.78 0.91 0.86 i 2 0.91 0.80 100.00 300.00 500.00 2.68 212.95 450.41 499.91 -5.15 -1.72 6003801.72 388(169.68 1.21 -0.38 ~ -10 1.20 -4.27 100.00 400.00 MWD+IFR-AK-CAZ-SC (2) 600.00 3.83 196.58 550.25 599.75 -10.31 -3.95 6003796.59 388067.38 1.47 -7.23 # -47 1.15 -16.37 100.00 500.00 700.00 5.78 184.88 649.89 699.39 -18.53 -5.33 6003788.39 388065.87 2.17 -0.49 -33 1.95 -11.70 100.00 600.00 800.00 8.58 177.47 749.10 798.60 -31.00 -5.43 6003775.92 388065.59 2.94 2.56 -22 2.80 -7.41 100.00 700.00 900.00 12.25 165.23 847.45 846.95 -48.72 -2.39 6003758.16 386068.35 4.27 9.97 - -37 3.67 -12:24 100.00 800.00 1000.00 14.40 159.30 944.76 994.26 -70.61 4.77 6003736.16 388075.73 2.54 22.37 -35 2.75 -5.93 100.00 900.00 1100.00 14.04 158.96 1041.69 1091.19 -93.57 13.46 6003713.08 388083.53 0.37 36.63 -167 -0.36 -0.34 100.00 1000.00 1200.00 14.34 153.72 1138.65 1188.15 -115.94 23.41 6003690.56 388093.15 1.46 57.91 -81 0.30 -5.84 100.00 1100:00 1300.00 16.26 144.51 1235.11 1284.61 -138.39 37.14 6003667.91 388106.54 2.97 70.86 -54 1.92 -8.61 100.00 1200.00 1400.00 18.59 134.31 1330.54 1380.04 -160.93 56.68 6003645.08 388125.74 3.83 95.46 it -58 2.33 -10.20 100.00 1300.00 1500.00 22.70 123.83 1424.13 1473.63 -182.82 84.14 6003622.77 388152.86 5.51 127.55 -47 4.11 -10.48 100.00 1400.00 1600.00 24.64 713.64 1515.75 1565.25 -201.93 119.28 6003603.14 388187.72 4.52 166.38 N. -69 1.94 -10.79 100.00 1500.00 1700.00 26.04 103.83 1606.16 7655.66 -215.54 159.71 6003588.92 388227.94 4.42 208.94 # -76 1.40 -9.81 100.00 1600.00 1800.00 27.35 94.37 1695.54 1745.04 -222.55 203.95 6003581.25 388272.07 4.44 253.51 -77 1.31 -9.46 100.00 1700.00 1900.00 30.09 91.27 1783.24 1832.74 -224.85 251.93 6003578.23 388320.01 3.12 300.52 -30 2.74 -3.10 100.00 1800.00 2000.00 33.78 92.09 1868.09 1977.59 -226.42 304.79 6003575.86 388372.84 3.72 352.07 7 3.69 0.82 100.00 1900.00 2100.00 35.49 92.43 1950.37 1999.87 -228.67 361.58 6003572.77 388429.59 1.72 407.58 7 1.71 0.34 100.00 2000.00 2200.00 36.91 91.60 2031.06 2080.56 -230.74 420.60 6003569.81 388488.57 1.50 465.22 -19 1.42 -0.83 100.00 2100.00 300.00 39.37 91.33 2109.70 2159.20 -232.31 482.34 6003567.31 388550.27 2.47 525.35 -4 2.46 -0.27 100.00 2200.00 400.00 43.57 92.67 2184.62 2234.12 -234.62 548.50 6003564.01 388616.40 4.28 589.95 12 4.20 1.28 100.00 2300.00 2500.00 46.28 92.58 2255.42 2304.92 -237.81 619.04 6003559.76 388686.88 2.71 659.01 t 0 2.71 -0.03 100.00 2400.00 2600.00 45.64 92.75 2324.93 2374.43 -241.16 690.85 6003555.34 388758.63 0.65 729.34 169 -0.64 0.17 100.00 2500.00 2700.00 44.86 92.94 2395.33 2444.83 -244.68 761.78 6003550.75 388829.50 0.79 798.86 170 -0.78 0.19 100.00 2600.00 2755.00 44.71 92.76 2434.37 2483.87 -246.61 800.47 6003548.24 388868.16 0.36 836.79 -140 -0.27 -0.33 55.00 2655.00 9-5/8"x 12-1/4"TD 2800.00 44.59 92.60 2466.38 2515.88 -248.09 832.06 6003546.29 388899.73 0.37 867.73 ? -137 -0.27 -0.36 45.00 2700.00 2900.00 43.66 92.32 2538.16 2587.66 -251.08 901.62 6003542.26 388969.23 0.95 935.79 # -168 -0.93 -0.28 100.00 2800.00 3000.00 44.52 90.66 2609.99 2654.49 -252.88 971.17 6003539.41 389038.75 1.44 1003.55 -54 0.86 -1.66 100.00 2900.00 3100.00 45.28 89.82 2680.82 2730.32 -253.17 1041.76 6003538.06 389109.32 0.96 1071.92 -38 0.76 -0.84 100.00 3000.00 3200.00 45.13 89.02 2751.28 2800.78 -252.45 1112.72 6003537.71 389180.28 0.59 1140.40 -705 -0.15 -0.80 100.00 3700.00 3300.00 45.04 88.60 2821.89 2871.39 -250.98 1183.57 6003538.12 389251.09 0.31 1208.54 -107 -0.09 -0.42 100.00 3200.00 3400.00 44.43 88.47 2892.93 2942.43 -249.18 1253.87 6003538.86 389321.47 0.62 1276.16 -177 -0.bl -0.73 100.00 3300.00 3500.00 44.09 88.34 2964.54 3014.04 -247.24 1323.64 6003539.76 389391.26 0.35 1343.18 # -165 -0.34 -0.13 100.00 3400.00 3600.00 44.35 90.50 3036.21 3085.71 -246.54 7393.37 6003539.41 389460.99 1.53 1410.47 ~ 81 0.26 2.16 100.00 3500.00 3700.00 44.86 93.24 3107.42 3156.92 -248.83 1463.54 6003536.06 389531.12 1.99 1478.95 ~ 76 0.51 2.74 100.00 3600.00 3800.00 45.08 93.71 3178.16 3227.66 -253.12 1534.08 6003530.72 389607.59 0.40 1548.29 57 0.22 0.47 100.00 3700.00 3900.00 45.56 91.85 3248.48 3297.98 -256.56 1605.10 6003526.21 389672.54 1.41 1617.88 # -71 0.48 -1.86 100.00 3800.00 4000.00 46.01 69.86 3318.22 3367.72 -257.63 1676.75 6003524.07 389744.18 1.50 7687.48 k -73 0.45 -1.99 100.00 3900.00 4100.00 45.66 89.64 3387.89 3437.39 -257.31 1748.49 6003523.31 389815.91 0.38 1756.81 ~k -156 -0.35 •0.22 100.00 4000.00 4200.00 45.18 89.07 3458.08 3507.58 -256.51 1819.71 6003523.04 389887.13 0.63 1825.53 # -140 -0.48 -0.57 100.00 4100.00 4300.00 44.18 89.88 3529.19 3578.69 -255.87 1890.02 6003522.63 389957.44 1.15 7893.40 # 151 -1.00 0.87 100.00 4200.00 4400.00 44.43 90.28 3600.75 3650.25 -255.96 7959.87 6003521.49 390027.28 0.37 1961.01 48 0.25 0.40 100.00 4300.00 4500.00 43.63 92.61 3672.65 3722.15 -257.71 2029.34 6003518.70 390096.72 1.81 2028.67 117 -0.80 2.33 100.00 4400.00 G Meas. Incl. TRUE Subsea RKB Local ASP or Grid Dogleg Original Tool Build Twn Course Drilled Depth (h) Angle (deg) Azi. (deg) TVD (fl) TVD (U) N)+)/Sl-) (f1) E(+)/W(-) (K) NI+)/S)-) La T. (Y) E(+)/W(-) Dep. (X) Severity (°/100 ft) VS (705°) (U) Face (deg) (°/100 ft) (°/100 h) Length (fl) DisTance (f T) 0 Comments 4600.00 44.37 93.53 3744.59 3794.09 -261.43 2098.70 6003513.94 390166.02 0.98 2096.73 @ 47 0.74 0.92 100.00 4500.00 4700.00 44.80 92.02 3815.81 3865.31 -264.82 2168.81 6003509.49 390236.07 1.14 2765.42 -68 0.43 -1.57 100.00 4600.00 4800.00 45.45 90.12 3886.37 3935.87 -266.14 2239.66 6003507.11 390306.89 1.50 2234.31 r, -65 0.65 •1.90 100.00 4700.00 4900.00 45.75 89.95 3956.71 4006.21 -266.19 2370.74 6003506.00 390377.96 0.32 2303.10 =i -758 -0.30 -0.17 100.00 4800.00 5000.00 44.98 89.47 4027.34 4076.84 -265.83 2387.53 6003505.29 390448.75 0.38 2371.50 -117 -0.17 -0.48 100.00 4900.00 5100.00 46.07 91.04 4097.40 4146.40 -266.15 2452.88 6003503.90 390520.08 1.56 2440.63 ?i 46 1.09 1.57 100.00 5000.00 5200.00 45.39 91.50 4167.20 4276.70 -267.74 2524.46 6003501.24 390591.64 0.76 2510.29 154 -0.68 0.46 100.00 5100.00 5300.00 45.02 91.28 4237.66 4287.16 -269.46 2595.41 6003498.45 390662.55 0.40 2579.37 # -157 -0.37 -0.22 100.00 5200.00 5400.00 45.43 92.51 4308.10 4357.60 -271.81 2666.35 6003495.04 390733.45 0.96 2648.62 65 0.41 7.23 100.00 5300.00 5500.00 44.93 91.70 4378.58 4428.08 -274.42 2737.23 6003491.36 390804.39 0.76 2717.86 .+ -131 -0.50 -0.87 100.00 5400.00 5600.00 44.27 90.97 4449.79 4499.29 -276.06 2807.43 6003488.67 390874.45 0.84 2786.20 dr -142 -0.bb -0.73 100.00 5500.00 5700.00 44.73 97.08 4521.11 4570.61 -277.31 2877.51 6003486.37 390944.50 0.47 2854.33 10 0.46 0.11 100.00 5600.00 5800.00 45.38 91.17 4591.75 4641.25 -278.70 2948.27 6003483.92 397015.24 0.65 2923.15 6 0.65 0.09 100.00 5700.00 5900.00 44.52 90.63 4662.53 4712.03 -279.81 3018.91 6003481.74 391085.85 0.94 2991.78 -756 -0.86 -0.54 100.00 5800.00 6000.00 45.18 91.46 4733.42 4782.92 -281.10 3089.42 6003479.40 397156.34 0.88 3060.34 42 0.66 0.83 100.00 5900.00 6100.00 47.65 91.07 4802.36 4851.86 -282.70 3161.84 6003476.71 391228.72 2.49 3130.81 -7 2.47 -0.39 100.00 6000.00 MWD+IFR-AK-CAZ-SC (3) 6200.00 51.45 89.43 4867.23 4916.73 -283.00 3237.91 6003475.27 391304.78 4.00 3204.50 -19 3.80 -1.64 100.00 6100.00 6300.00 55.28 87.96 4926.89 4976.39 -281.14 3378.12 6003475.92 391385.00 4.01 3281.64 li -18 3.83 -1.47 100.00 6200.00 6400.00 59.11 86.61 4981.06 5030.56 -277.14 3402.06 6003478.66 391468.99 3.99 3361.85 # -17 3.83 -1.35 100.00 6300.00 6500.00 62.96 85.37 5029.48 5078.98 -271.01 3489.31 6003483.49 391556.33 4.00 3444.73 -16 3.85 -1.24 100.00 6400.00 6600.00 66.82 84.21 5071.91 5121.41 -262.77 3579.47 6003490.37 391646.60 4.00 3529.89 -15 3.86 -1.16 100.00 6500.00 6700.00 70.02 83.30 5108.69 5158.19 -252.65 3671.89 6003499.10 391739.17 3.31 3616.76 # -15 3.20 -0.91 100.00 6600.00 6800.00 70.02 83.30 5142.85 5192.35 -241.69 3765.23 6003508.66 391832.66 0.01 3704.31 90 0.00 0.00 100.00 6700.00 6900.00 70.02 83.30 5177.02 5226.52 -230.72 3858.57 6003518.23 391926.15 0.01 3791.86 90 0.00 0.00 100.00 6800.00 7000.00 70.02 83.30 5211.19 5260.69 -219.76 3951.91 6003527.79 392019.65 0.01 3879.41 90 0.00 0.00 100.00 6900.00 7100.00 70.02 83.30 5245.36 5294.86 -208.79 4045.25 6003537.35 392113.14 0.01 3966.96 90 0.00 0.00 100.00 7000.00 7200.00 70.02 83.30 5279.53 5329.03 -197.83 4138.59 6003546.91 392206.63 0.01 4054.51 - 90 0.00 0.00 100.00 7100.00 7300.00 70.02 83.30 5313.70 5363.20 -186.86 4237.93 6003556.48 392300.13 0.01 4142.06 90 0.00 0.00 100.00 7200.00 7400.00 70.02 83.30 5347.87 5397.37 -175.90 4325.27 6003566.04 392393.62 0.01 4229.61 90 0.00 0.00 100.00 7300.00 7500.00 70.02 83.30 5382.04 5431.54 -164.93 4418.61 6003575.60 392487.11 0.01 4317.16 90 0.00 0.00 100.00 7400.00 7600.00 70.02 83.30 5416.21 5465.71 -153.97 4511.95 6003585.17 392580.61 0.01 4404.71 - 90 0.00 0.00 100.00 7500.00 7700.00 70.02 83.30 5450.38 5499.88 -143.00 4605.29 6003594.73 392674.10 0.01 4492.26 90 0.00 0.00 100.00 7600.00 7800.00 70.02 83.30 5484.55 5534.05 -132.04 4698.63 6003604.29 392767.59 0.01 4579.81 # 90 0.00 0.00 100.00 7700.00 7900.00 70.02 83.30 5518.72 5568.22 -121.07 4791.97 6003613.85 392861.09 0.01 4667.36 90 0.00 0.00 100.00 7800.00 8000.00 70.02 83.30 5552.89 5602.39 -110.11 4885.31 6003623.42 392954.58 0.01 4754.91 # 90 0.00 0.00 100.00 7900.00 8100.00 70.02 83.30 5587.05 5636.55 -99.14 4978.64 6003632.98 393048.07 0.01 4842.46 90 0.00 0.00 100.00 8000.00 8200.00 70.02 83.30 5621.22 5670.72 -88.18 5077.98 6003642.54 393741.57 0.01 4930.07 90 0.00 0.00 100.00 8100.00 8300.00 70.02 83.30 5655.39 5704.89 -77.21 5165.32 6003652.10 393235.06 0.01 5017.56 - 90 0.00 0.00 100.00 8200.00 8400.00 70.02 83.30 5689.56 5739.06 -66.25 5258.66 6003661.67 393328.55 0.01 5105.11 90 0.00 0.00 100.00 8300.00 8500.00 70.02 83.30 5723.73 5773.23 -55.28 5352.00 6003671.23 393422.05 0.01 5192.66 90 0.00 0.00 100.00 8400.00 8600.00 70.02 83.30 5757.90 5807.40 -44.32 5445.34 6003680.79 393515.54 0.01 5280.21 90 0.00 0.00 100.00 8500.00 8700.00 70.02 83.30 5792.07 5841.57 -33.35 5538.68 6003690.35 393609.04 0.01 5367.76 #. 90 0.00 0.00 100.00 8600.00 8800.00 70.02 83.30 5826.24 5875.74 -22.39 5632.02 6003699.92 393702.53 0.01 5455.30 ;p 90 0.00 0.00 100.00 8700.00 8816.84 70.02 83.30 5831.99 5881.49 -20.54 5647.74 6003701.53 393718.27 0.05 5470.05 # 90 0.00 0.00 16.84 8716.84 CD3-316wp04 Heel 8900.00 70.02 83.30 5860.41. 5909.91 -11.42 5725.36 6003709.48 393796.02 0.01 5542.85 90 0.00 0.00 83.16. 8800.00 9000.00 70.02 83.30 5894.58 5944.08 -0.46 5818.70 6003719.04 393889.52 0.01 5630.40 90 0.00 0.00 100.00 8900.00 9100.00 70.02 83.30 5928.75 5978.25 10.51 5912.04 6003728.61 393983.07 0.01 5717.95 r= 90 0.00 0.00 100.00 9000.00 9200.00 70.02 83.30 5962.92 6012.42 21.47 6005.38 6003738.17 394076.50 0.01 5805.50 # 90 0.00 0.00 100.00 9100.00 9300.00 70.02 83.30 5997.08 6046.58 32.44 6098.72 6003747.73 394170.00 0.01 5893.05 90 0.00 0.00 100.00 9200.00 9400.00 70.02 83.30 6031.25 6060.75 43.40 619206 6003757.29 394263.49 0.01 5980.60 ii 90 0.00 0.00 100.00 9300.00 9500.00 70.02 83.30 6065.42 6114.92 54.36 6285.40 6003766.86 394356.98 0.01 6068.75 # 90 0.00 0.00 100.00 9400.00 9600.00 70.02 83.30 6099.59 6149.09 65.33 6378.74 6003776.42 394450.48 0.01 6755.70 90 0.00 0.00 100.00 9500.00 9700.00 70.02 83.30 6133.76 6183.26 76.29 6472.07 6003785.98 394543.97 0.01 6243.25 # 90 0.00 0.00 100.00 9600.00 9800.00 70.02 83.30 6167.93 6217.43 87.26 6565.41 6003795.54 394637.46 0.01 6330.80 # 90 0.00 0.00 100.00 9700.00 J ~+.~ ~'` I Meas. Incl. TRUE Subsea RKB Local ASP or Grid Dogleg Odginai "~~.e Tool Build Turn Course Drilled Depth (ff) Angle Ide9) Azi. (deg) TVD (ffl TVD (ff) N(+)/S(-) (fi) E(+)/yy(.) (ff) N(+)/SI-) Lai. (Y) E(+)/W(-) Dep. (~ Severity (°/100 ft) VS (105°) (H) Face (deg) (°/100 fi) (°/100 ff) Length (ft) Distance (ff) Comments 9900.00 70.02 83.30 6202.10 6251.60 98.22 6658.75 6003805.11 394730.96 0.01 6418.35 90 0.00 0.00 100.00 9800.00 10000.00 70.02 83.30 6236.27 6285.77 109.19 6752.09 6003814.67 394824.45 0.01 6505.90 90 0.00 0.00 100.00 9900.00 10100.00 70.02 83.30 6270.44 6319.94 120.15 6845.43 6003824.23 394917.94 0.01 6593.45 90 0.00 0.00 100.00 10000.00 10200.00 70.02 83.30 6304.61 6354.11 131.12 6938.77 6003833.79 395011.44 0.01 6681.00 90 0.00 0.00 100.00 10100.00 10300.00 70.02 83.30 6338.78 6388.28 142.08 7032.11 6003843.36 395104.93 0.01 6768.55 90 0.00 0.00 100.00 10200.00 10400.00 70.02 83.30 6372.95 6422.45 153.05 7125.45 6003852.92 395198.42 0.01 6856.10 :~ 90 0.00 0.00 100.00 10300.00 10500.00 70.02 83.30 6407.12 6456.62 164.01 7218.79 6003862.48 395291.92 0.07 6943.65 ?t 90 0.00 0.00 100.00 10400.00 10600.00 70.02 83.30 6441.28 6490.78 174.98 7312.13 6003872.05 395385.41 0.01 7031.20 # 90 0.00 0.00 100.00 10500.00 10700.00 70.02 83.30 6475.45 6524.95 185.94 7405.47 6003881.61 395478.90 0.01 7118.75 # 90 0.00 0.00 100.00 10600.00 10800.00 70.02 83.30 6509.62 6559.12 196.91 7498.81 6003891.17 39557240 0.01 7206.30 # 90 0.00 0.00 100.00 10700.00 10886.00 70.02 83.30 6539.01 6588.51 206.34 7579.08 6003899.39 39565280 0.01 7281.59 lk 90 0.00 0.00 86.00 10786.00 KOP;7 DLS 10900.00 70.28 84.31 6543.76 6543.26 207.76 7592.17 6003900.62 395665.91 7.04 7293.90 ~i 75 1.86 7.21 14.00 10800.00 MWD+IFR-AK-CAZ-SC (4) 11000.00 72.33 91.37 6575.85 6625.35 211.29 7686.75 6003902.73 395760.54 6.99 7384.52 74 2.05 7.06 100.00 10900.00 11100.00 74.62 98.27 6604.32 6653.82 203.21 7782.21 6003893.22 395855.86 7.00 7478.93 72 2.29 6.90 100.00 11000.00 11200.00 77.12 105.02 6628.76 6678.26 183.62 7877.11 6003872.20 395950.46 7.01 7575.70 70 2.50 6.75 100.00 11100.00 11277.93 79.19 110.18 6644.77 6694.27 160.55 7949.77 6003848.05 39602277 7.00 7651.84 68 2.66 6.62 77.93 11177.93 11278.28 79.19 110.18 6644.83 6694.33 160.43 7950.10 6003847.93 396023.09 2.32 7652.18 90 0.00 0.00 0.35 11178.28 11300.00 79.79 111.61 6648.79 6698.29 152.82 7970.05 6003840.01 39604292 7.04 7673.41 67 2.76 6.58 21.72 11200.00 11400.00 82.59 118.11 6664.12 6713.62 111.28 8059.64 6003797.14 396131.88 7.01 7770.58 i 67 2.80 6.50 100.00 11300.00 11500.00 85.48 124.52 6674.53 6724.03 59.61 8144.55 6003744.19 396216.01 7.00 7865.79 66 2.89 6.41 100.00 11400.00 11600.00 88.43 130.89 6679.84 6729.34 -1.43 8223.50 6003681.98 396294.03 7.01 7957.59 65 2.95 6.37 100.00 11500.00 11669.72 90.50 135.30 6680.49 6729.99 -49.05 8274.39 6003633.60 396344.20 6.99 8018.85 +? 65 2.97 6.33 69.72 11569.72 7"x 8-3/4"-CD3-316wp05 Heel 11700.00 90.50 135.30 6680.23 6729.73 -70.57 8295.69 6003611.76 396365.18 0.03 8044.89 90 0.00 0.00 30.28 11600.00 11800.00 90.50 135.30 6679.36 6728.86 -141.65 8366.03 6003539.63 396434.44 0.01 8130.89 90 0.00 0.00 100.00 11700.00 11900.00 90.50 135.30 6678.48 6727.98 -212.73 8436.37 6003467.51 396503.70 0.01 8216.89 90 0.00 0.00 100.00 11800.00 12000.00 90.50 135.30 6677.61 6727.11 -283.80 8506.70 6003395.39 39657296 0.01 8302.89 is 90 0.00 0.00 100.00 11900.00 12100.00 90.50 135.30 6676.74 6726.24 -354.88 8577.04 6003323.26 39664223 0.01 8388.89 ~S 90 0.00 0.00 100.00 12000.00 12200.00 90.50 135.30 6675.87 6725.37 -425.96 8647.38 6003251.14 396711.49 0.01 8474.89 90 0.00 0.00 100.00 12100.00 12300.00 90.50 135.30 6674.99 6724.49 -497.04 8717.71 6003179.01 396780.75 0.01 8560.89 90 0.00 0.00 100.00 12200.00 12400.00 90.50 135.30 6674.12 6723.62 -568.11 8788.05 6003106.89 396850.01 0.01 8646.89 # 90 0.00 0.00 100.00 12300.00 12500.00 90.50 135.30 6673.25 6722.75 -639.19 8858.39 6003034.76 396919.27 0.01 8732.89 90 0.00 0.00 100.00 12400.00 12600.00 90.50 135.30 6672.38 6721.88 -710.27 8928.72 6002962.64 396988.54 0.01 8818.89 ~ 90 0.00 0.00 100.00 12500.00 12700.00 90.50 135.30 6671.50 6721.00 -781.34 8999.06 6002890.51 3971157.80 0.01 8904.89 90 0.00 0.00 100.00 12600.00 12800.00 90.50 135.30 6670.63 6720.13 -852.42 9069.40 6002818.39 397127.06 0.01 8990.89 ~i 90 0.00 0.00 100.00 12700.00 12900.00 90.50 135.30 6669.76 6719.26 -923.50 9139.73 6002746.26 397196.32 0.01 9076.89 90 0.00 0.00 100.00 12800.00 13000.00 90.50 135.30 6668.89 6718.39 -994.58 9210.07 6002674.14 397265.58 0.01 9162.89 90 0.00 0.00 100.00 12900.00 13100.00 90.50 135.30 6668.01 6717.51 -1065.65 9280.41 6002602.01 397334.85 0.01 9248.89 90 0.00 0.00 100.00 13000.00 13200.00 90.50 135.30 6667.14 6716.64 -1136.73 9350.74 6002529.89 397404.11 0.01 9334.89 k 90 0.00 0.00 100.00 13100.00 13300.00 90.50 135.30 6666.27 6715.77 -1207.81 9421.08 6002457.76 397473.37 0.01 9420.89 ~? 90 0.00 0.00 100.00 13200.00 13400.00 90.50 135.30 6665.39 6714.89 -1278.89 9491.42 6002385.64 39754263 0.01 9506.89 * 90 0.00 0.00 100.00 13300.00 13500.00 90.50 135.30 6664.52 6714.02 -1349.96 9561.75 6002313.51 397611.89 0.01 9592.89 90 0.00 0.00 100.00 13400.00 13600.00 90.50 135.30 6663.65 6713.15 -1421.04 9632.09 6002241.39 397681.16 0.01 9678.89 90 0.00 0.00 100.00 13500.00 13700.00 90.50 135.30 6662.78 6712.26 -1492.12 9702.43 6002169.26 397750.42 0.01 9764.89 # 90 0.00 0.00 100.00 13600.00 13800.00 90.50 135.30 6661.90 6711.40 -1563.19 9772.77 6002097.14 397819.68 0.01 9850.89 90 0.00 0.00 100.00 13700.00 13900.00 90.50 135.30 6661.03 6710.53 -1634.27 9843.10 6002025.01 397888.94 0.01 9936.89. 90 0.00 0.00 100.00 13800.00 14000.00 90.50 135.30 6660.16 6709.66 -1705.35 9913.44 6001952.89 397958.20 0.01 10022.89 1= 90 0.00 0.00 100.00 13900.00 14100.00 90.50 135.30 6659.29 6708.79 -1776.43 9983.78 6001880.76 398027.47 0.01 10108.89 T 90 0.00 0.00 100.00 14000.00 14129.43 90.50 135.30 6659.03 6708.53 -1797.34 10004.48 6001859.53 398047.85 0.03 10134.20 # 90 0.00 0.00 29.43 14029.43 CD3-316wp04 Toe 14200.00 90.50 135.30 6658.41 6707.91 -1847.50 10054.11 6001808.64 398096.73 0.01 10194.89 r 90 0.00 0.00 70.57 14100.00 14300.00 90.50 135.30 6657.54 6707.04 -1918.58 10124.45 6001736.51 398165.99 0.01 10280.89 it 90 0.00 0.00 100.00 14200.00 14400.00 90.50 135.30 6656.67 6706.17 -1989.66 10194.79 6001664.39 398235.25 0.01 10366.89 # 90 0.00 0.00 100.00 14300.00 14500.00 90.50 135.30 6655.80 6705.30 -2060.73 10265.12 6001592.26 398304.51 0.01 10452.89 90 0.00 0.00 100.00 14400.00 14600.00 90.50 135.30 6654.92 6704.42 -2131.81 10335.46 6001520.14 398373.78 0.01 10538.89 ~ 90 0.00 0.00 100.00 14500.00 14700.00 90.50 135.30 6654.05 6703.55 -2202.89 10405.80 6001448.01 398443.04 0.01 10624.89 it 90 0.00 0.00 100.00 14600.00 i Meas. Incl. TRUE Subsea RKB Local ASP or Grid Dogleg Original '~~c~ Tool Build Turn Course Drilled Depth (h) Angle (deg) Azi. (deg) ND (ft) TVD (ft) N(+1/Sl-) (#) E(+)/W(.) (K) N~+~/S~-) Lat. (Y) E(+)/W(-) Dep. (X) Severi}y (°/100 ftl VS (105°) (R) Pace (deg) (°/100 ft) (°/100 M) Length (ti) Distance (ff) 0 Comments 14800.00 90.50 135.30 6653.18 6702.68 -2273.97 10476.13 6001375.89 398512.30 0.01 10770.88 90 0.00 0.00 100.00 14700.00 14900.00 90.50 135.30 6652.30 6701.80 -2345.04 10546.47 6001303.76 398581.56 0.01 10796.88 90 0.00 0.00 100.00 14800.00 75000.00 90.50 135.30 6651.43 6700.43 -2416.12 10616.81 6001231.64 398650.83 0.01 10882.88 90 0.00 0.00 100.00 14900.00 15100.00 90.50 135.30 6650.56 6700.06 -2487.20 10687.14 6001159.51 398720.09 0.01 10968.88 90 0.00 0.00 100.00 15000.00 15200.00 90.50 135.30 6649.69 6699.79 -2558.28 10757.48 6001087.39 398789.35 0.01 11054.88 # 90 0.00 0.00 100.00 15100.00 15300.00 90.50 135.30 6648.81 6698.31 -2629.35 10827.82 6001015.26 398858.61 0.01 11140.88 # 90 0.00 0.00 100.00 15200.00 15400.00 90.50 135.30 6647.94 6697.44 -2700.43 10898.15 6000943.14 398927.87 0.01 71226.88 # 90 0.00 0.00 100.00 15300.00 15500.00 90.50 135.30 6647.07 6696.57 -2771.51 10968.49 6000871.01 398997.14 0.01 17312.88 # 90 0.00 0.00 100.00 15400.00 15600.00 90.50 135.30 6646.20 6695.70 -2842.58 11038.83 6000798.89 399066.40 0.01 17398.88 90 0.00 0.00 100.00 15500.00 15669.74 90.50 135.30 6645.59 6695.09 -2892.15 11087.88 6000748.59 399174.70 0.01 17458.86 # 90 0.00 0.00 69.74 15569.74 CD3-316wpO5Toe • O ('''~ 6 • • Operator: ConoeoPhillips(Alaska) Inc. -WNS Grid Cortection: -0.86 Job No: #N/A Field: Western North Slope Magnetic Declination: 22.34 AFE No: #N/A Well: CD3-316AP61wp06 (NAD27) Plan Dlp: 80.75 API No: #N/A Rlg: #N/A Dogleg per: 100 ft North Reference: TRUE Surface Location Original VS Plane: 88.09 Parent Well: Rig: CD3-316 X 388071.48 ft Vlew VS Plane: 88.09 RKB Height: 49.50 ft Y: 6003806.84 tt Meas. Incl. TRUE Subsea RKB Local ASP or Grid Dogleg Original Tool Build Turn Course Drilled Depth (H) Angle (deg) Azi. (deg) TVD (fi) TVD (ff) N(+(/S(-) (ft~ E(+)/W(.) (ft) N(+I/$(-) Lat. (Y) E(+)/W(-) Dep. (~ Severity (°/100 ft) VS (BB°) (R) `~ fl1 face (deg) (°/100 ft~ (°/100 K) Length (ff) Distance (ff) 0 Comments 100.00 0.55 93.98 50.50 100.00 -0.04 0.37 6003806.79 386071.85 0.00 0.37 # 200.00 0.51 106.66 150.50 200.00 -0.20 1.28 6003806.62 368072.75 0.12 1.27 # 115 -0.04 12.68 100.00 100.00 CB-GYRO-SS (1) 300.00 0.57 216.42 250.49 299.99 -0.73 1.41 6003806.09 38807287 0.88 1.38 # 143 0.06 109.76 100.00 200.00 400.00 1.48 217.22 350.48 399.98 -2.16 0.33 6003804.67 388071.78 0.91 0.26 2 0.91 0.80 100.00 300.00 500.00 2.68 212.95 450.41 499.91 -5.15 -1.72 6003801.72 368069.68 1.21 -1.89 # -10 1.20 -4.27 100.00 400.00 MWD+IFR-AK-CAZ-SC (2) 600.00 3.83 196.58 550.25 599.75 -10.31 -3.95 6003796.59 388067.38 1.47 -4.29 # -47 1.15 -16.37 100.00 500.00 700.00 5.78 184.88 649.89 699.39 -18.53 -5.33 6003788.39 386065.87 2.17 -5.94 -33 1.95 -11.70 100.00 600.00 800.00 8.58 177.47 749.10 798.60 -31.00 -5.43 6003775.92 388065.59 2.94 -6.46 -22 2.80 -7.41 100.00 700.00 900.00 12.25 165.23 847.45 896.95 -48.72 -2.39 6003758.16 388066.35 4.27 -4.01 -37 3.67 -12.24 100.00 800.00 1000.00 14.40 159.30 944.76 994.26 -70.61 4.71 6003736.16 368075.13 2.54 2.35 # -35 2.15 -5.93 100.00 900.00 1100.00 14.04 158.96 1041.69 1091.19 -93.57 13.46 6003713.08 388083.53 0.37 10.33 # -167 -0.36 -0.34 100.00 1000.00 1200.00 14.34 153.12 1138.65 1188.15 -115.94 23.41 6003690.56 388093.15 1.46 19.54 # -81 0.30 -5.84 100.00 1100.00 1300.00 16.26 144.51 1235.11 1284.61 -138.39 37.14 6003667.91 388106.54 2.97 32.51 # -54 1.92 -6.61 100.00 1200.00 1400.00 18.59 134.31 1330.54 1380.04 -160.93 56.68 6003645.08 386125.74 3.83 51.29 # -58 2.33 -10.20 100.00 1300.00 500.00 22.70 123.83 1424.13 1473.63 -182.82 84.14 6003622.77 38815286 5.51 78.00 # -47 4.11 -10.48 100.00 1400.00 600.00 24.64 113.64 1515.75 1565.25 -201.93 119.28 6003603.14 388187.72 4.52 112.49 # -69 1.94 -10.19 100.00 1500.00 700.00 26.04 103.83 1606.16 1655.66 -215.54 159.71 6003588.92 368227.94 4.42 152.44 # -76 1.40 -9.81 100.00 1600.00 00.00 27.35 94.37 1695.54 1745.04 -222.55 203.95 6003581.25 388272.07 4.44 196.42 -77 1.31 -9.46 100.00 1700.00 900.00 30.09 91.27 1783.24 1832.74 -224.85 251.93 6003578.23 388320.01 3.12 244.30 `i -30 2.74 -3.10 100.00 1800.00 000.00 33.78 92.09 1868.09 1917.59 -226.42 304.79 6003575.86 388372.84 3.72 297.08 7 3.69 0.82 100.00 1900.00 00.00 35.49 92.43 1950.37 1999.87 -228.67 361.58 6003572.77 388429.59 1.72 353.76 # 7 1.71 0.34 100.00 2000.00 200.00 36.91 91.60 2031.06 2080.56 -230.74 420.60 6003569.81 388488.57 1.50 412.68 li. -19 1.42 -0.83 100.00 2100.00 00.00 39.37 91.33 2109.70 215920 -232.31 482.34 6003567.31 388550.27 2.47 474.33 -4 2.46 -0.27 100.00 2200.00 0.00 43.57 92.61 2184.62 2234.12 -234.62 548.50 6003564.01 388616.40 4.28 540.38 rr 12 4.20 1.28 100.00 2300.00 2500.00 46.28 92.58 2255.42 2304.92 -237.81 619.04 6003559.76 388686.88 2.71 610.77 .'r 0 2.71 -0.03 100.00 2400.00 2600.00 45.64 92.75 2324.93 2374.43 -241.16 690.85 6003555.34 388758.63 0.65 682.43 # 169 -0.64 0.17 100.00 2500.00 2700.00 44.86 92.94 2395.33 2444.83 -244.68 761.78 6003550.75 388629.50 0.79 753.20 t 170 -0.78 0.19 100.00 2600.00 2755.00 44.71 92.76 2434.37 2483.87 -246.61 800.47 6003548.24 388868.16 0.36 791.81 -140 -0.27 -0.33 55.00 2655.00 9-5/8"x 12-1/4"TD 2800.00 44.59 92.60 2466.38 2515.88 -248.09 832.06 6003546.29 388899.73 0.37 823.34 # -137 -0.27 -0.36 45.00 2700.00 2900.00 43.66 92.32 2538.16 2587.66 -251.08 901.62 6003542.26 388969.23 0.95 892.75 # -168 -0.93 -0.28 100.00 2800.00 3000.00 44.52 90.66 2609.99 2659.49 -252.88 971.17 6003539.41 389038.75 1.44 962.21 -54 0.86 -1.66 100.00 2900.00 3100.00 45.28 89.82 2680.82 2730.32 -253.17 1041.76 6003538.06 389109.32 0.96 1032.74 # -38 0.76 -0.84 100.00 3000.00 3200.00 45.13 89.02 2751.28 2800.76 -252.45 1112.72 6003537.71 389180.28 0.59 1103.68 # -105 -0.15 -0.80 100.00 3100.00 3300.00 45.04 88.60 2821.89 2871.39 -250.98 1183.51 6003538.12 369251.09 0.31 1174.49 if -107 -0.09 -0.42 700.00 3200.00 3400.00 44.43 88.47 2892.93 2942.43 -249.18 1253.87 6003538.86 389321.47 0.62 1244.87 -171 -0.61 -0.13 100.00 3300.00 3500.00 44.09 88.34 2964.54 3014.04 -247.24 1323.64 6003539.76 389391.26 0.35 1314.66 =t -165 -0.34 -0.13 100.00 3400.00 3600.00 44.35 90.50 303621 3085.71 -246.54 1393.37 6003539.41 389460.99 1.53 1384.38 # 81 0.26 2.16 100.00 3500.00 3700.00 44.86 93.24 3107.42 3156.92 -248.83 1463.54 6003536.06 389531.12 1.99 1454.43 # 76 0.51 2.74 100.00 3600.00 3800.00 45.08 93.71 3178.16 3227.66 -253.12 1534.08 6003530.72 389601.59 0.40 1524.79 # 57 0.22 0.47 100.00 3700.00 3900.00 45.56 91.85 3248.48 3297.98 -256.56 1605.10 6003526.21 389672.54 1.41 1595.66 -71 0.48 -1.86 100.00 3800.00 4000.00 46.01 89.86 3318.22 3367.72 -257.63 1676.75 6003524.07 369744.18 1.50 1667.24 # -73 0.45 -1.99 100.00 3900.00 4100.00 45.66 89.64 3387.89 3437.39 -257.31 1748.49 6003523.31 369815.91 0.38 1738.94 # -156 -0.35 -0.22 100.00 4000.00 4200.00 45.18 89.07 3458.08 3507.58 -256.51 1819.71 6003523.04 389887.13 0.63 1810.15 # -140 -0.48 -0.57 100.00 4100.00 4300.00 44.18 89.88 3529.19 3578.69 -255.87 1890.02 6003522.63 389957.44 1.15 1880.44 # 151 -1.00 0.81 100.00 4200.00 4400.00 44.43 90.28 3600.75 3650.25 -255.96 1959.87 6003521.49 390027.28 0.37 1950.25 # 48 0.25 0.40 100.00 4300.00 4500.00 43.63 92.61 3672.65 3722.15 -257.71 2029.34 6003518.70 390096.72 1.81 2019.62 117 -0.80 2.33 100.00 4400.00 Meas. Incl. TRUE Subsea RKB Local ASP or Grid Dogleg Original lc Tool Build ium Course Drilled Depth (h) Angle (deg) Azi. (deg) TVD (tl) TVD (f!) N(+~/5(-) (ft~ E(+)/yy(-) (ft) N(+~/S(-) Lat. (Y) E(+)/W(-) Dep. (X) Severity (°/100 ft) VS (88°) (R) (8 !f.! Face (deg) (°/100 ft) (°/100 H) Length (f}) Distance (ft) 0 Comments 4600.00 44.37 93.53 3744.59 3794.09 -261.43 2098.70 6003513.94 390166.02 0.98 2088.82 41 0.74 0.92 100.00 4500.00 4700.00 44.80 92.02 3815.81 3865.31 -264.82 2168.81 6003509.49 390236.07 1.14 2158.78 -68 0.43 -1.51 100.00 4600.00 4800.00 45.45 90.12 3886.37 3935.87 -266.14 2239.66 6003507.11 390306.89 1.50 2229.54 - -65 0.65 -1.90 100.00 4700.00 4900.00 45.15 89.95 3956.71 4006.21 -266.19 2310.74 6003506.00 390377.96 0.32 2300.58 -158 -0.30 -0.17 100.00 4800.00 5000.00 44.98 89.47 4027.34 4076.84 -265.83 2381.53 6003505.29 390448.75 0.38 2371.34 # -117 -0.17 -0.48 100.00 4900.00 5100.00 46.07 91.04 4097.40 4146.90 -266.15 2452.88 6003503.90 390520.08 1.56 2442.64 ?? 46 1.09 1.57 100.00 5000.00 5200.00 45.39 91.50 4167.20 4216.70 -267.74 2524.46 6003501.24 390591.64 0.76 2514.14 n 154 -0.68 0.46 100.00 5100.00 5300.00 45.02 91.28 4237.66 4287.16 -269.46 2595.41 6003498.45 39066255 0.40 2584.99 # -157 -0.37 -0.22 100.00 5200.00 5400.00 45.43 92.51 4308.10 4357.60 -271.81 2666.35 6003495.04 390733.45 0.96 2655.81 ~- 65 0.41 1.23 100.00 5300.00 5500.00 44.93 91.70 4378.58 4428.08 -274.42 2737.23 6003491.36 390804.29 0.76 2726.57 a -131 -0.50 -0.81 100.00 5400.00 5600.00 44.27 90.97 4449.79 4499.29 -276.06 2807.43 6003488.67 390874.45 0.84 2796.67 ~'! -142 -0.66 -0.73 100.00 5500.00 5700.00 44.73 91.08 4521.11 4570.61 -277.31 2877.51 6003486.37 390944.50 0.47 2866.67 =t 10 0.46 0.11 100.00 5600.00 5800.00 45.38 91.17 4591.75 4641.25 -278.70 2948.27 6003483.92 391015.24 0.65 2937.35 ~ 6 0.65 0.09 100.00 5700.00 5900.00 44.52 90.63 4662.53 4712.03 -279.81 3018.91 6003481.74 391085.85 0.94 3007.91 # -156 -0.86 -0.54 100.00 5800.00 6000.00 45.18 91.46 4733.42 4782.92 -281.10 3089.42 6003479.40 391156.34 0.88 3078.34 # 42 0.66 0.83 100.00 5900.00 6050.00 45.76 91.97 4768.49 4817.99 -282.17 3125.05 6003477.79 391191.94 1.37 3113.91 32 1.16 1.02 50.00 5950.00 KOP; 4 DLS 6100.00 47.65 91.07 4802.77 4852.27 -283.13 3161.43 6003476.29 391228.30 4.00 3150.24 x -19 3.78 -1.80 50.00 6000.00 MWD+IFR-AK-CAZ-SC (3) 6200.00 51.45 89.43 4867.64 4917.14 -283.43 3237.51 6003474.84 391304.37 4.00 3226.26 ~# -19 3.80 -1.64 100.00 6100.00 6300.00 55.28 87.96 4927.30 4976.80 -281.58 3317.71 6003475.49 391384.59 4.01 3306.48 r1 -18 3.83 -1.47 100.00 6200.00 6400.00 59.11 86.61 4981.47 5030.97 -277.58 3401.65 6003478.23 391468.58 3.99 3390.51 -17 3.83 -1.35 100.00 6300.00 6500.00 62.96 85.37 5029.89 5079.39 -271.44 3488.91 6003483.06 391555.92 4.00 3477.92 ;i -16 3.85 -1.24 100.00 6400.00 6600.00 66.82 84.21 5072.32 5121.82 -263.21 3579.06 6003489.94 391646.19 4.00 3568.30 ~ -15 3.86 -1.16 100.00 6500.00 6682.61 70.02 83.30 5102.70 5152.20 -254.85 3655.41 6003497.75 391722.66 4.01 3644.89 N -15 3.87 -1.10 82.61 6582.61 6700.00 70.02 83.30 5108.64 5158.14 -252.94 3671.65 6003498.82 391738.91 0.05 3661.18 it 90 0.00 0.00 17.39 6600.00 800.00 70.02 83.30 5142.81 5192.31 -241.97 3764.98 6003508.38 39183241 0.01 3754.83 90 0.00 0.00 100.00 6700.00 900.00 70.02 83.30 5176.98 5226.48 -231.01 3858.32 6003517.94 391925.90 0.01 3848.48 :i 90 0.00 0.00 100.00 6800.00 000.00 70.02 83.30 5211.15 5260.65 -220.04 3951.66 6003527.51 392019.39 0.01 3942.14 43 90 0.00 0.00 100.00 6900.00 100.00 70.02 83.30 5245.32 5294.82 -209.08 4045.00 6003537.07 392112.89 0.01 4035.79 fit 90 0.00 0.00 100.00 7000.00 200.00 70.02 83.30 5279.49 5328.94 -198.11 4138.34 6003546.63 392206.38 0.01 4129.44 ,`i 90 0.00 0.00 100.00 7100.00 00.00 70.02 83.30 5313.66 5363.16 -187.15 4231.68 6003556.19 392299.87 0.01 4223.09 ~ 90 0.00 0.00 100.00 7200.00 0.00 70.02 83.30 5347.83 5397.33 -176.19 4325.02 6003565.76 392393.37 0.01 4316.75 s 90 0.00 0.00 100.00 7300.00 00.00 70.02 83.30 5382.00 5431.50 -165.22 4418.36 6003575.32 392486.86 0.01 4410.40 90 0.00 0.00 100.00 7400.00 00.00 70.02 83.30 5416.17 5465.67 -154.26 4511.70 6003584.88 392580.35 0.01 4504.05 # 90 0.00 0.00 100.00 7500.00 0.00 70.02 83.30 5450.34 5499.84 -143.29 4605.04 6003594.44 392673.85 0.01 4597.71 # 90 0.00 0.00 100.00 7600.00 7800.00 70.02 83.30 5484.51 5534.01 -132.33 4698.38 6003604.01 392767.34 0.01 4691.36 # 90 0.00 0.00 100.00 7700.00 00.00 70.02 83.30 5518.68 5568.18 -121.36 4791.72 6003613.57 392860.83 0.01 4785.01 90 0.00 0.00 100.00 7800.00 8000.00 70.02 83.30 5552.84 5602.34 -110.40 4885.06 6003623.13 392954.33 0.01 4878.66 ff 90 0.00 0.00 100.00 7900.00 8100.00 70.02 83.30 5587.01 5636.51 -99.43 4978.40 6003632.69 393047.82 0.01 4972.32 ~ 90 0.00 0.00 100.00 8000.00 8200.00 70.02 83.30 5621.18 5670.68 -88.47 5071.74 6003642.26 393141.32 0.01 5065.97 90 0.00 0.00 100.00 8100.00 8300.00 70.02 83.30 5655.35 5704.85 -77.50 5165.07 6003651.82 393234.81 0.01 5159.62 90 0.00 0.00 100.00 8200.00 8400.00 70.02 83.30 5689.52 5739.02 -66.54 5258.41 6003661.38 393328.30 0.01 5253.28 90 0.00 0.00 100.00 8300.00 8500.00 70.02 83.30 5723.69 5773.19 -55.57 5351.75 6003670.95 393421.80 0.01 5346.93 =i 90 0.00 0.00 100.00 8400.00 8600.00 70.02 83.30 5757.86 5807.36 -44.61 5445.09 6003680.51 393515.29 0.01 5440.58 90 0.00 0.00 100.00 8500.00 8700.00 70.02 83.30 5792.03 5841.53 -33.64 5538.43 6003690.07 393608.78 0.01 5534.24 ~i 90 0.00 0.00 100.00 8600.00 8800.00 "70.02 83.30 5826.20 5875.70 -22.68 5631.77 6003699.63 393702.28 0.01 5627.89 t 90 0.00 0.00 100.00 8700.00 8900.00 70.02 83.30 5860.37 5909.87 -11.71 5725.11 6003709.20 393795.77 0.01 5721.54 # 90 0.00 0.00 100.00 8800.00 9000.00 70.02 83.30 5894.54 5944.04 -0.75 5818.45 6003718.76 393889.26 0.01 5815.19 ~ 90 0.00 0.00 100.00 8900.00 9100.00 70.02 83.30 5928.71 5978.21 10.22 5911.79 6003728.32 393982.76 0.01 5908.85 90 0.00 0.00 100.00 9000.00 9200.00 70.02 83.30 5962.88 6012.38 21.18 6005.13 6003737.88 394076.25 0.01 600250 90 0.00 0.00 100.00 9100.00 9300.00 70.02 83.30 5997.04 6046.54 32.15 6098.47 6003747.45 394169.74 0.01 6096.15 90 0.00 0.00 100.00 9200.00 9400.00 70.02 83.30 6031.21 6080.71 43.11 6191.81 6003757.01 394263.24 0.01 6189.81 # 90 0.00 0.00 100.00 9300.00 9500.00 70.02 83.30 6065.38 6114.88 54.08 6285.15 6003766.57 394356.73 0.01 6283.46 # 90 0.00 0.00 100.00 9400.00 9600.00 70.02 83.30 6099.55 6149.05 65.04 6378.49 6003776.13 394450.22 0.01 6377.11 ~ 90 0.00 0.00 100.00 9500.00 9700.00 70.02 83.30 6133.72 6183.22 76.01 6471.83 6003785.70 394543.72 0.01 6470.77 # 90 0.00 0.00 100.00 9600.00 _~ Meas. Incl. TRUE Subsea RKB Local ASP or Grid Dogleg Original - Tool Build turn Course Drilled Depth (H) Angle (deg) Azi. (deg) TVD (ft) TVD (ff) N(+)/S(-) (fi) E(+)/W(-) (H) N(+)/S(-) Laf. (Y) E(+)JyV(-) Dep. (X) Severity (°/100 ft) VS (88°) (H) Pace (deg) (°/100 ft) (°/100 K) Length (ft) Distance (fl) 0 Comments 9800.00 70.02 83.30 6167.89 6277.39 86.97 6565.17 6003795.26 394637.21 0.01 6564.42 90 0.00 0.00 100.00 9700.00 9900.00 70.02 83.30 6202.06 6251.56 97.94 6658.50 6003804.82 394730.70 0.01 6658.07 90 0.00 0.00 100.00 9800.00 10000.00 70.02 83.30 6236.23 6285.73 108.90 6751.84 6003614.39 394824.20 0.01 6751.72 r; 90 0.00 0.00 100.00 9900.00 10100.00 70.02 83.30 6270.40 6319.90 119.87 6845.18 6003823.95 394917.69 0.01 6845.38 90 O.CO 0.00 100.00 10000.00 10200.00 70.02 83.30 .6304.57 6354.07 130.83 6938.52 6003833.51 395011.18 0.01 6939.03 ~t 90 0.00 0.00 100.00 10100.00 10300.00 70.02 83.30 6338.74 6388.24 141.80 7031.86 6003843.07 395104.68 0.01 7032.68 # 90 0.00 0.00 100.00 10200.00 10400.00 70.02 83.30 6372.91 6422.41 152.76 7125.20 6003852.64 395198.17 0.01 7126.34 90 0.00 0.00 100.00 10300.00 10500.00 70.02 83.30 6407.07 6456.57 163.73 7218.54 6003862.20 395291.66 0.01 7279.99 90 0.00 0.00 100.00 10400.00 10600.00 70.02 83.30 6441.24 6490.74 174.69 7311.88 6003871.76 395385.16 0.01 7313.64 90 0.00 0.00 100.00 10500.00 10700.00 70.02 83.30 6475.41 6524.91 185.66 7405.22 6003881.32 395478.65 0.01 7407.29 3 90 0.00 0.00 100.00 10600.00 10800.00 70.02 83.30 6509.58 6559.08 196.62 7498.56 6003890.89 39557214 0.01 7500.95 1# 90 0.00 0.00 100.00 10700.00 10900.00 70.D2 83.30 6543.75 6593.25 207.58 7591.90 6003900.45 395665.64 0.01 7594.60 # 90 0.00 0.00 100.00 10800.00 11000.00 70.02 83.30 6577.92 6627.42 218.55 7685.24 6003910.01 395759.13 0.01 7688.25 90 0.00 0.00 100.00 10900.00 11700.00 70.02 83.30 6612.09 6661.59 229.51 7778.58 6003919.57 39585262 0.01 7781.91 90 0.00 0.00 100.00 11000.00 71200.00 70.02 83.30 6646.26 6695.76 240.48 7871.92 6003929.14 395946.12 0.01 7875.56 ?' 90 0.00 0.00 100.00 11100.00 11299.98 70.02 83.30 6680.42 6729.92 251.44 7965.24 6003938.70 396039.59 0.01 7969.19 r 90 0.00 0.00 99.98 11199.98 CD3-316APB1wpOb T1 11300.00 70.02 83.30 6680.43 6729.93 251.44 7965.26 6003938.70 396039.61 40.52 7969.21 90 0.00 0.00 0.02 11200.00 11400.00 66.02 83.30 6717.85 6767.35 262.26 8057.34 6003948.13 396131.84 4.00 8061.60 180 -4.00 0.00 100.00 11300.00 11497.36 62.12 83.30 6760.41 6809.91 272.47 8144.28 6003957.04 396218.93 4.01 8148.84 780 -4.01 0.00 97.36 11397.36 &3/4"OH-CD3-316APB1wpObT2 ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD3 Fiord Pad Rig: CD3-316 Plan: CD3-316APB1 CD3-316APB1wp06 C:~ :~~~'~'~/ f'1~~11'7~ ~E3~''1i/IGE3S ~, Clearance Summary Anticollision Report --°' 23 January, 2008 Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad -Rig: CD3-316 -Plan: CD3-316AP61 -CD3-316AP61wp06 Well Coordinates: 6,003,554.04 N, 1,528,103.39E (70° 25' 08.47" N, 150° 54' 53.95" W) Datum Height: Plan: CD3-316 (36.3+13.2) @ 49.50ft (Doyon 19 (36.3+13.2)) Scan Range: 6,050.00 to 11,497.36 ft. Measured Depth. Scan Radius is 1,346.11 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Geodetic Scale Factor Applied Version: 2003.16 Build: 42F Scan Type: GLOBAL FILTER APPLIED: All wellpaths within 200'+ 100/1000 of reference Scan Type: 25.00 H,A-L.1..1 BURTG7h1 Sperry Driliing Service: ConocoPhillips(Alaska) Inc. -WNS HALLIBURTON Anticollision Report for Rig: CD3-316 -CD3-316APB1wp06 Western North Slope Trav. Cylinder North Proximity Scan on Current Survey Data (North Reference) Reference Design: CD3 Fiord Pad -Rig: CD3-316 -Plan: CD3-316APB1 -CD3-316AP61wp06 Scan Range: 6,050.00 to 11,497.36 ft. Measured Depth. Scan Radius is 1,346.11 ft . Clearance Factor cutoff is Unlimited. Max Ellipse Separation is Unlimited Measured Minimum @Measured Ellipse @Measured Clearance Summary Based on Site Name Depth Distance Depth Separation Depth Factor Minimum Separation Warning Comparison Well Name - Wellbore Name -Design (ft) (ft) (ft) (ft) ft CD3 Fiord Pad Rig: CD3-316 -Plan: CD3-316A -CD3-316Awp06 F AIL -Major Risk Rig: CD3-316 -Plan: CD3-316A -CD3-316Awp06 F AIL -Major Risk Rig: CD3-316 -Rig: CD3-316 -CD3-316 Rig Surveys ® F AIL -Major Risk Rig: CD3-316 -Rig: CD3-316 -CD3-316 Rig Surveys ® ~~ F AIL -Major Risk O Rig: CD3-316 -Rig: CD3-316 -CD3-316P61 wp04 ® F AIL -Major Risk /V V ! Survey tool program From To Survey/Plan Survey Tool ~ 81.00 442.00 CB-GYRO-SS 511.39 6,050.00 MWD+IFR-AK-CAZ-SC 6,050.00 11,497.36 CD3-316AP61wp06 MWD+IFR-AK-CAZ-SC Ellipse error terms are correlated across survey tool tie-on points. Calculated ellipses incorporate surface errors. Separation is the actual distance between ellipsoids. Distance Between centres is the straight line distance between wellbore centres. Clearance Factor =Distance Between Profiles / (Distance Between Profiles -Ellipse Separation). All station coordinates were calculated using the Minimum Curvature method. 23 January, 2008 - 11:32 Page 2 of 4 COMPASS HALLIBURTON Anticollision Report for Rig: CD3-316 -CD3-316APB1wp06 Direction and Coordinates are relative to True North Reference. Vertical Depths are relative to Plan: CD3-316 (36.3+13.2) @ 49.50ft (Doyon 19 (36.3+13.2)). Northing and Easting are relative to Rig: CD3-316. Coordinate System is US State Plane 1983, Alaska Zone 4. Central Meridian is -150.00°, Grid Convergence at Surface is: -0.86 °. Ladder d I .--~ ~~ 1 ~00- O C O .~ (~ ~Q~- Q Q7 a--~ a} C7 O ~~~- a-- !` a ---------- I I I -----I----- I I I ---------- I I I ---------- I I I ---------- -----~--- 1 I I ~ I I I - - - - -I - - - _ - ~ I I I I I I I - - - - -I - - - - - I I I I 1 I I I - - - _ _I - - - - - I I I I ~ I I I - _ _ _ -I - - - - - I I I I ~ I I I - _ _ -I - - - - - ~ I I I ~ I I I - _ _ - -I - - - ~ 1 I I ~ I I I - - - - -I _ _ _ _ _ I I I I ~ I I I _ _ _ - _I - - - - - I I I I I I I I - - - - -I - - - - - I I I I I I I I - - - - -I - - - I I I I I I I I - - - - -I - - - - - I I I I I I I I - - - - -I - - - I 1 I I ~ I I I _ - - - -I - _ _ - - I I I I ~ I I I - - - _ _I - - - - - I I I I I I I I - - - - -I - - - - - I I I I I I - - _ -I - - - - - I I I I I I I I _ _ - - -I - - - - - I I I I I I I I - - - - -I - - - 1 I I I ~~y} ~~yy1~y ~} 1~} ~} 1~} q 1 ~} ~ ~} LVV~ ~4Jll~ ~VV~ VO~~ ~4J~OV Measured Depth ~2Q00 ftJin) ConocoPhillips(Alaska) Inc. -WNS Western North Slope CD3-108, CD3-108, CD3-108 V14 CD3-10$, CD3-108, Plan: CD3.108 (wp06) VB CD3.109, CD3-109, CD3.109 V5 CD3-109, CD3-109, CD3-109wp06 ~{3 CD3-110, CD3.110, CD3-110 V12 CD3.11D, CD3-110, CD3-110wp06 V1 CD3-111, CD3-111 ,CD3-111 '~7 CD3-111, CD3-111 ,CD3-111w p02 ~l2 CD3.111, CD3-111 L1, CD3-111L1 V1 CD3-112, CD3.112, CD3-113 ~3 CD3-112, CD3.113, CD3-112wp03 V3 CD3-113, CD3-113, CD3-113 1r1B CD3.113, CD3-113, CD3-113P@1wp03 V13 CD3.114, CD3-114, CD3-114 V14 CD3-307, CD3.107, CD3-1D7 k/7 cD3-3o7, cD3-3o7, cD3.3o7 V4 CD3-307, CD3-307. Plan: CD3.107 (ulpD 1) V4 CD3.307, Plan: CD3.107A, CD3-107Awp01 V1 Plan: CD3-106, Plan: CD3-106, Plan: CD3-106 (w Plan: CD3-115, Plan: CD3-115, CD3-115wp03 V Plan: CD3.117,Plan: CD3.117,CD3-117wp02 ~ Plan: CD3-118, Plan: CD3-118, CD3.118wp02 V8 Plan: CD3.304, Plan: CD3.304, CD3.304wp07 tit2 Plan: CD3.304, Plan: CD3.304P91, CD3-304PB1 Plan: CD3-305, Plan: CD3-305, CD3-305wp03 V5 Rig: CD3.316, Plan: CD3-316A, CD3.316A.wp06 q} 23 January, 2008 - 11:32 Page 3 of 4 COMPASS ConocoPhillips(Alaska) Inc. -WNS HALLIBURTON Western North Slope Anticollision Report for Rig: CD3-316 -CD3-316APB1wp06 Clearance Factor Plot: Measured Depth versus Separation(Clearance) Factor I U.UU 8.75 .50 0 u~ c~i `-~ b.25 0 U ca c 5.00 0 [o Q ~ 3.73 2.5u U.UC $ -- ~" __ ~ ~• ~- -~- ~' ~' '~ ~' -~' ~' 0 1000 2000 3000 a•OOU SUOU 0000 7000 8000 4000 IOOOU IIGOG I^_DOU ~~ Measured Depth (2000 ftJin) '~ ~- Rig: CD3-318, Rig: CD3-316, CD3-316 Rig Surveys Va CD3-1a8, CD3-1a8, CD3-1a8 V14 CD3-108, CD3.1D8, Plan: CD3.108 (wp08)~+16 CD3-109, CD3-109, C03-109 V5 CD3-109, CD3-109, CD3-1 D9wp08 k!3 CD3-110, CD3-11a, CD3-110 U13 CD3-110, CD3-110, CD3.11awp08 Vt CD3-11 1, CD3-111 ,CD3-111 V7 CD3.11 1 , CD3.111 ,CD3-111 wp02 V2 CD3-11 1, CD3-111 L1, CD3-111 L1 V1 CD3-113, CD3-113, CD3-112 1r3 CD3-112, CD3-112, CD3-112wp03 4t3 CD3.113, CD3-113, CD3-113 U16 CD3-113, CD3-113, CD3-113P@1wp03 V13 CD3.114, CD3-114, CD3-114 V14 CD3-307, CD3-107, CD3-107 V7 CD'3-307, CD3-307, CD3-307 V4 CD'3-307, CD3-3D7 ,Plan :CD3-107 (wpD t) V4 CD3-307, Plan: CD3-107 A, CD3-1D7Wupa1 V1 ~~ Plan: CD3-1D8, Plan: CD3-1a8, Plan: CD3-1 a6 (wpD1) Plan: CD3-115, Plan: CD3-115, CD3-115wp03 V4 Plan: CD3-117, Plan: CD3-117, CD3-117wpo3 ~r16 Plan: CD3.118, Plan: CD3-118, CD3-118wp03 ~+S Plan: CD3-3a 4, Plan: CD3-304. CD3-304wp07 V2 Plan: CD3-304, Plan: CD3.304P@1, CD3.3a4PB1wp07 Plan: CD3-305, Plan: CD3-3a5, CD3-305wp03 V5 Rig :CD3-316 ,Plan :CD3 -316A, CD3-316 Fuupo 6 W al„•rnn-?+R a~„~rn~-~~~ rn~.n~aaal,,,,,nak,s~ 23 January, 2008 - 11:32 Page 4 of 4 COMPASS ~ ~ TRANSMITTAL LETTER CHECKLIST WELL NAME C~2GC C'1~ .~^'~~~ Development Service Exploratory Strati ra hic Test g P Non-Conventional Well FIELD: ~~ i~~E Z~y~ ~ ~~~ POOL: ~ \ O~ ~` Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last t di i i wo g ts n API number permit No. ,API No. 50- - - are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be c early differentiated in both ll ~ ~D 3 '~/( ~ we name ( ~ PI PH) and API number (50- /6~ - 2aS~ - ~~') from records, data and logs acquired for well ~,~(,L ~~.3-,3/,~/,~Ef SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throu h tar et zones. Non-Conventional Well Please note the followin s ecial condition of this g P permit: production or production testing of coal bed methane is not allowed for (name of well) until after (Comaany Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Comuany Namel must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1/l 1/2008 WELL PERMIT C HECKL{$'( Field & Pool COi.VILLE RIVER, FIORD OIL -120120 Well Name: COLVILLE RIV FIORD CD3-316A Program SER Well bore seg PTD#:2080110 C ompany CQNOCOPHILLIPS ALASKA INC Initial Class>Type SER I PEND GeoArea 890 Unit 50360 On1Oif Shore On Annular Disposal ^ Administration ~1 Permit_fee adaphed - - - - - - - - - - - - - - - - NA ~2 Leasenymberappropnate________________________________ ________Yes_-_ - - - - - - - - - - - - _-_Surfas~lopationinAAL3721Q4,topprodint andTRinAD1372105 I 3 UnigOewell_nameandnumber ----- - - -- -- -- Yes_ ._-_----__--___- -- - -- -- - -- - ----- --- 4 Weli located n_a_definadpopl- - - - - - - - - - - - - - - _ - _ - _ _ - - - - - -Yes _ _ _ --- - -- - -- -- _ - - _ CQLVILLE-RIVER,-FIQRQ QIL_-12Q120,-governed-by CO 569._ . _ - , _ - - _ _ - _ 5 ~ Welt_located proper distance from drilling unit-boundary- _ - - _ - - _ - - - _ - -yes - - _ - - - Conservation OMe_r Np. 569 pontains np s -acin restrictions with res echo dr-illin knit boundaries. R 9 p 9 - -- 'I6 Well located properdistancefrom ptherwells- - _ , _ - - - - - - _ - _ - - - - , - yeg - - - - - Conseryation Order Np.-569 has no interwell-spacing-restrictions- - - '7 Su6icientapreage available in_ttrilling unil_ - - - _ - - - - - - - - - - - - - - - - - _ vas _ - - - - - - - - - - - conservation Order No. 562 has no interwell_spapingrestrictions, Wellborewill be-more than 500' from 8 If_deviated, is_wellbore plat-inclgded - - - - - - - - - - - - - - - - _ - - - _ - _ - -Yes - _ _ - - _ - - external property line whereownership prlandownershp-changes._ - - - - - - ------- 9 Operator poly affepted party - - - - - - - - - - - - - - -Yes - - ------ - - - j 10 Ope[atorhas_appropriatetZOndinforpe----------------------- -------- Yes - - --------------------------------------------- 11 Pe[mitpapbeissuerlwithoutcnnservatipnprdQr------------------- - ---- --------Yes---- ------- ------------------ Appr Date 1 12 Permit can be issued without adminislralive_approval , - _ - - _ - - - - - - - - - - - - - - -Yes _ _ _ - _ _ - - ~ 4! 3 an permitbe approved befpre 15•daywait_ - - - - - _ - - - - - - vas - - - - - --- -- - - - --- - - - - - - - - - - ~ 14 WQiI located within area and strata authprized by Inleption Order # (put 10# in-comments)_(For NA_ - - _ -- - - - AiO-30, issued July 25, ZQ06 - - 15 Allwells-within 1/d-mile area of review identified (For servieewell poly) - - - - - _ _ - - _ Yes - _ _ _ _ -Fiord 1 - - - - - - - - - - - - - - - - - ------ 16 P1Q-prpduced injaCtpr; duration of pr$~roduetipp less than 3 mpnths_ (Fpr-service well poly) _ _ -No- _ _ - - -------- ----- ----- ---- -- -- _ _ _ Fiord wells- ar@ typipaliy flpwed back fpr Doty a f@vt days for glean up, - - - _ - _ - - 17 Nonconven,gas-cpnfiprms tQ A$31,05,03QQ.1.A),Q.2.A-D) - - - - - - - - - - - - - -- - - - - - - - - NA- - - - - -- - - - - - - --------------- -------------------------------------- Engineering ; 18 Conduptorstring_provided-_-_--__---___---------__-- --_--- NA-__- ----- - -- ----- ___cpnduptpr_set-in CD3.316(247.177)------------------ - - --------- 19 Surface casingprptecis all_knownUSDWs _ _ _ - _ - - - - - - - - - - - - - - - - - - NA_ - _ - -- - ------------- _ _ - No aquifers, AIQ 1$A, cpnGusion 3.- _ - - _ - _ - - - ------ ~ 20 CMT voi adequate tp circulate-on cpnductpr& surf_csg - - - - - - - - - _ _ - - NA- - ----------------------------- - _ - Surface pacing set in CD3.316. _ - _ - _ _ - - _ - - _ - _ 21 CMT voladequate-tp tie-in long string to surf csg- - - - - - - - - - - - - - - - - - - - - - - - - - - No_ - - _ - ------------ _ - -Annular disposal may beproposed. - _ _ _ - _ - _ _ - - - _ - _ _ ----- 22 CMT willpoverallknowr-productivehorizons_____________________ __-___--hto -__ ---------------- .._Slpttedlinercpmplet[onplanned,_-__-___--_________ -------- ~ 23 CasingdesgnsadequateforQ,TB&permafcost---------------- --_-- --Yes---- -------------------- --- ~ 24 Adequate tankage_ortesarvepit - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - Yes . - . _ ---------------------------- -- - - - - - -- - - _ Rig equipped with steel pits. No reserve pft planned.- Ali waste-tp approved annuli prdisppsalwelt(s).- . _ _ - - - 'I ?5 If a-re•d[ili, has_a 10~4031or abandpnment been approved _ - - _ _ - - - _ - - - - - - - Yes _ - _ - _ _ _ 308-026 _ - _ _ _ - _ - - _ - - - - - 26 Adequate wellbore saparation_proposed- - _ - - - - - - - - - - - - - - - - _ - _ -Yes - - - _ ----- ----- ---- ---- ---- - -Proximity analysis performed, Nearest segment is abandpned portion-of CD3-316 and paths diverge. - _ - _ - - _ - 27 if dive(ter-required, does itmeetregulations- - - - - - - - - - - - - - - - - - - - - - - - - - - NA_ - - _ - - - 6pP stapk_Will already-be in place, - - _ - _ _ ------------- I 2 28 Drilling fluid-program schemaife & equp list adequate- - - - - - - - - - - - - - - - - - - - -Yes _ _ -------------------------- Maximum expected formatipn pressure 8,7_EMW._ Mud weighs planned 8,8 ppg o[ as needed 12D0$ TEM 11 29 BOP)`s,-do theymeetregulatipn - - - - - - - - - - - - - Y~ - - , _ - - - _ - - - - "~~ „ 0 OPE-press .rating appropriate; test to_(put psig in cpmments)- - - - - - - - - - - - - - - - -Yes _ _ - - - - - - ----------------------------- ----------------------- _ _ _ MASP palpulaled at 2359psi, 3500_psi-BOP test-planned. - - - - - - ` ' 31 Choke-manifpld epmplies w1API_RP-53 (May 84) - - - - - - - - Yes - - - - - _ - --- -- - - - - - - - - - - - - - - - - 32 Wprkwillpccurwithputnperationshutdown__-_-___---__--_ __-_-__Yes---- - - - - - - - - - - - - - - - - - ---------------------- ------- 33 IspresenpeofH2Sgasprobable__------------------------ ---_---_ No-__-- ---------------------------------------- --_H2Shasnotbeenreppr#eda#cQ3.-Righassensors_andalarms,____-_---_-,_ 34 Mechanical cpndit[on of wells within AQR verified (Fpr_service well poly) - - - - - - - - - _ Yes _ - _ ---- -- - _ _ _ Np AQR issues, _ - - - - ---------------------------------- Geology 35 Permitean be issued wlo hydrogen-sulfide measures- - - - - - - - - - - - - - - - - - - - - - - - - Yes - _ - _ -------- _ _ _ None expected,-but H2$ and_gas detectors will be used duringdrilling, Mitigation measures-in Hazards Summary- 36 Data_presanted on Rotential pverRressurezpnes - - - - - - - - - - - - - - - - - - - _ - - - Yes _ - . _ _ _ Expected reservoirpressure is 8,7-ppg EMW; will be dtilied with 8.8 PP9 mud. Appr Date 37 Seismicanaiysisofshallpwgas_zones______-__----__--__ NA _ _ _ _ _ _ - _ _ ----------- SFD 1124/2008 38 __ Seakadcpnditionsuryey_(ifoff-shore)----------------------- _------- --__- --- --Nq__-- -____- _ _ - __ - -- --- -- -- -- -- - -- -- ____--_----- - ------ 39 Contaptnamelphoneforweekty-p_rogressreppds[exploratprypnly)-------- ---------IyA---- ---------------------------------------------- -------------.--- ------ -- -- --- -- - - Geologic Commissioner. Date: Engineering Date a .c Com i s tonelr~ i tuner Date Re-drill of CD 3.316 seeking to find reservoir quality sand. Pilot hole will be drilled. If successful, then a horizontal wellbore will ba drilled. / ; s~ ~ (~ (! t/Velt History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. • cd3-316a.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon Mar 31 15:22:14 2008 Reel Header Service name .............LISTPE Date . ...................08/03/31 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. scientific Technical services Tape Header Service name .............LISTPE Date . ...................08/03/31 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. Physical EOF Comment Record TAPE HEADER Alpine MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA MWD RUN 2 JOB NUMBER: MW-000555131 LOGGING ENGINEER: J. BOBBITT OPERATOR WITNESS: D. BURLEY MWD RUN 5 JOB NUMBER: MW-000555131 LOGGING ENGINEER: A. MENEZES OPERATOR WITNESS: D. LUTRICK SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: scientific Technical services CD3-316A 501032055901 Conoco Phillips Alaska Inc. Sperry Sun 31-MAR-08 MWD RUN 3 MWD RUN 4 MW-000555131 MW-000555131 A. MENEZES A. MENEZES D. LUTRICK D. LUTRICK 5 12N 5E 3969 0 971 0 Page 1 • cd3-316a.tapx ELEVATION (FT FROM MSL 0) KELLY BUSHING: .00 DERRICK FLOOR: 49.50 GROUND LEVEL: 13.20 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.750 9.625 2744.0 2ND STRING 8.750 9.625 2744.0 3RD STRING 8.750 9.625 2744.0 PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY AND IS NOT PRESENTED. 4. MWD RUN 2-3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WHILE DRILLING (PWD), DRILLSTRING DYNAMICS SENSOR (DDSr), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AZIMUTHAL LITHO-DENSITY (ALD), AND ACOUSTICALIPER (ACAL). 5. MWD RUNS 4-5 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WHILE DRILLING (PWD), AND DRILLSTRING DYNAMICS SENSOR (DDSr). 6. SNP2 NOT PRESENTED DUE TO SENSOR MALFUNCTION. 7. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT CONOCO-PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR DRILLSITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 8. THIS WELL KICKED OF FROM CD3-316APB1 AT 10275' MD/6372' TVD. 9. MWD RUN 1-5 REPRESENTS THE WELL CD3-316A WITH API#:50-103-20559-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11690MD/6727'TVD. MWD SERVICES FOR THE PRODUCTION SECTION WILL BE PROVIDED BY A DIFFERENT CONTRACTOR. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. Page 2 cd3-316a.tapx SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. DENSLIDE = NON-ROTATED INTERVALS REFLECTING DENSITY SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 8.75" MUD WEIGHT: 9.6- 9.7 PPG MUD SALINITY: 300 PPM CHLORIDES FORMATION WATER SALINITY: 14,545 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY, WHICH ARE BOTH SMOOTHED TO A 1.1 FT WINDOW. ALL DATA HAS A GAP FILL OF 5 FT APPLIED. File Header Service name... .......STSLIB.001 service sub Level~Name... version Number. ........1.0.0 Date of Generation.......08/03/31 Maximum Physical Record..65535 File Type ................L0 Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped DEPTH INCREMENT: .5000 FILE SUMMARY curves; all bit runs merged. PBU TOOL CODE START DEPTH NPHI 2710.5 RPS 2710.5 STOP DEPTH 10275.0 11635.5 Page 3 n LJ cd3-316a.tapx FCNT 2710.5 10275.0 NCNT 2710.5 10275.0 RPM 2710.5 11635.5 DRHO 2710.5 10275.0 RPX 2710.5 11635.5 FET 2710.5 11635.5 RHOB 2710.5 10275.0 GR 2710.5 11643.5 RPD 2710.5 11635.5 ROP 2755.5 11690.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED L~ DEPTH) --- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 2710.5 6016.5 MWD 3 6017.0 10275.0 MWD 4 10275.5 11199.0 MWD 5 11199.5 11690.0 REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units ......... ............ Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MWD CP30 4 1 68 4 2 NCNT MWD CP30 4 1 68 8 3 RHOB MWD G/CC 4 1 68 12 4 DRHO MWD G/CC 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HR 4 1 68 36 10 GR MWD API 4 1 68 40 11 ROP MWD FPH 4 1 68 44 12 NPHI MWD PU 4 1 68 48 13 Name Service Unit Min Max Mean Nsam DEPT FT 2710.5 11690 7200.25 17960 FCNT MWD CP30 525.89 3730.66 1012.41 15130 NCNT MWD CP30 100793 189066 132115 15130 Page 4 First Reading 2710.5 2710.5 2710.5 Last Reading 11690 10275 10275 L r~ ~ _~ cd3-316a.tapx RHOB MWD G/CC 0.321 3.107 2.39484 15130 2710.5 10275 DRHO MWD G/CC -2.785 0.328 0.0486803 15130 2710.5 10275 RPD MWD OHMM 0.14 2000 9.45691 17851 2710.5 11635.5 RPM MWD OHMM 0.19 1164.2 6.45791 17851 2710.5 11635.5 RPS MWD OHMM 0.25 936.37 5.72759 17851 2710.5 11635.5 RPX MWD OHMM 0.49 860.93 5.44197 17851 2710.5 11635.5 FET MWD HR 0.18 100.68 1.18421 17851 2710.5 11635.5 GR MWD API 54.57 436.24 129.679 17867 2710.5 11643.5 ROP MWD FPH 0 619.06 159.499 17870 2755.5 11690 NPHI MWD PU 11.6 60.19 34.5105 15130 2710.5 10275 First Reading For Entire File..........2710.5 Last Reading For Entire File...........11690 File Trailer Service name... .......STSLIB.001 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/31 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/31 Maximum Physical Record..65535 File Type ................Lo Previous File Name.......ST5LI6.001 comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY header data for each bit run in separate files. 2 .5000 VENDOR TOOL CODE NPHI FCNT NCNT GR RHOB RPS FET RPD DRHO RPM RPX ROP LOG HEADER DATA START DEPTH 2710.5 2710.5 2710.5 2710.5 2710.5 2710.5 2710.5 2710.5 2710.5 2710.5 2710.5 2755.5 STOP DEPTH 6016.5 6016.5 6016.5 6016.5 6016.5 6016.5 6016.5 6016.5 6016.5 6016.5 6016.5 6016.5 Page 5 • cd3-316a.tapx DATE LOGGED: 22-JAN-08 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 39.4 MAXIMUM ANGLE: 47.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 242567 EWR4 ELECTROMAG. RESIS. 4 127479 CTN COMP THERMAL NEUTRON 185457 ALD Azimuthal Litho-Den 224808 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.750 DRILLER'S CASING DEPTH (FT): 2744.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 9.60 MUD VISCOSITY (S): 39.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 4.250 75.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.320 143.0 MUD FILTRATE AT MT: 7.900 75.0 MUD CAKE AT MT: 6.200 75.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing ........ ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units ......... .. ......... Datum specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 Page 6 cd3-316a.tapx FONT MwD020 CP30 4 1 68 4 2 NCNT MWD020 CP30 4 1 68 8 3 RHOB MWD020 G/CC 4 1 68 12 4 DRHO MWD020 G/CC 4 1 68 16 5 RPD MwD020 OHMM 4 1 68 20 6 RPM MWD020 OHMM 4 1 68 24 7 RPS MWD020 oHMM 4 1 68 28 8 RPX MWD020 OHMM 4 1 68 32 9 FET MWD020 HR 4 1 68 36 10 GR MWD020 API 4 1 68 40 11 ROP MWD020 FPH 4 1 68 44 12 NPHI MwD020 PU 4 1 68 48 13 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 2710.5 6016.5 4363.5 6613 2710.5 6016.5 FCNT MWD020 CP30 525.89 2313.83 872.978 6613 2710.5 6016.5 NCNT MWD020 CP30 100793 170777 125998 6613 2710.5 6016.5 RHOB MWD020 G/cc 0.321 3.107 2.30146 6613 2710.5 6016.5 DRHO MWD020 G/CC -2.785 0.311 0.0308008 6613 2710.5 6016.5 RPD MWD020 OHMM 0.14 2000 11.8896 6613 2710.5 6016.5 RPM MWD020 OHMM 0.19 1164.2 4.88575 6613 2710.5 6016.5 RPS MWD020 OHMM 0.25 936.37 4.56383 6613 2710.5 6016.5 RPX MWD020 OHMM 0.49 860.93 4.35811 6613 2710.5 6016.5 FET MwD020 HR 0.18 61.26 1.29734 6613 2710.5 6016.5 GR MWD020 API 60.05 200.16 121.543 6613 2710.5 6016.5 ROP MWD020 FPH 0 619.06 227.56 6523 2755.5 6016.5 NPHI MWD020 Pu 16.56 60.19 37.6776 6613 2710.5 6016.5 First Reading For Entire File..........2710.5 Last Reading For Entire File...........6016.5 File Trailer Service name... .......sTSLI6.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/31 Maximum Physical Record..65535 File TyC~e ................L0 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.......08/03/31 Maximum Physical Record..65535 File Type ................Lo Previous File Name.......STSLiB.002 comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. Page 7 • cd3-316a.tapx BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPX 6017.0 10275.0 GR 6017.0 10275.0 NPHI 6017.0 10275.0 ROP 6017.0 10275.0 RPS 6017.0 10275.0 FET 6017.0 10275.0 RHOB 6017.0 10275.0 FONT 6017.0 10275.0 RPD 6017.0 10275.0 NCNT 6017.0 10275.0 DRHO 6017.0 10275.0 RPM 6017.0 10275.0 LOG HEADER DATA DATE LOGGED: 28-JAN-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 45.6 MAXIMUM ANGLE: 73.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 242567 EWR4 ELECTROMAG. RESIS. 4 127479 CTN COMP THERMA L NEUTRON 185457 ALD Azimuthal L itho-Den 224808 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.750 DRILLER'S CASING DEPTH (FT): 2744.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 9.70 MUD VISCOSITY (S): 41.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 280 FLUID LOSS (C3): •0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 2.200 73.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.172 143.0 MUD FILTRATE AT MT: 2.800 73.0 MUD CAKE AT MT: 2.900 72.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): Page 8 • cd3-316a.tapx TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MWD030 CP30 4 1 68 4 2 NCNT MWD030 CP30 4 1 68 8 3 RHOB MWD030 G/CC 4 1 68 12 4 DRHO MWD030 G/CC 4 1 68 16 5 RPD MWD030 OHMM 4 1 68 20 6 RPM MWD030 OHMM 4 1 68 24 7 RPS MwD030 OHMM 4 1 68 28 8 RPx MwD030 OHMM 4 1 68 32 9 FET MWD030 HR 4 1 68 36 10 GR MwD030 API 4 1 68 40 11 ROP MWD030 FPH 4 1 68 44 12 NPHI MWD030 Pu 4 1 68 48 13 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6017 10275 8146 8517 6017 10275 FCNT MWD030 CP30 756.64 3730.66 1120.68 8517 6017 10275 NCNT MWD030 CP30 117323 189066 136865 8517 6017 10275 RHOB MWD030 G/CC 1.994 2.75 2.46734 8517 6017 10275 DRHO MWD030 G/CC -0.036 0.328 0.0625628 8517 6017 10275 RPD MwD030 OHMM 3.88 31.78 7.14056 8517 6017 10275 RPM MWD030 OHMM 3.64 34.67 6.79888 8517 6017 10275 RPS MWD030 OHMM 3.63 30.59 6.50978 8517 6017 10275 RPx MWD030 OHMM 3.66 31.61 6.36962 8517 6017 10275 FET MwD030 HR 0.27 100.68 0.742235 8517 6017 10275 GR MwD030 API 54.57 204.5 117.12 8517 6017 10275 ROP MWD030 FPH 5.79 280.73 128.447 8517 6017 10275 NPHI MWD030 PU 11.6 43.82 32.0515 8517 6017 10275 First Reading For Entire File..........6017 Last Reading For Entire File...........10275 File Trailer service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/31 Maximum Physical Record..65535 File Type ................Lo Page 9 • cd3-316a.tapx Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/31 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.003 comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RPD 10275.5 11144.5 RPX 10275.5 11144.5 RPM 10275.5 11144.5 FET 10275.5 11144.5 RPS 10275.5 11144.5 GR 10275.5 11153.0 RoP 10275.5 11199.0 LOG HEADER DATA DATE LOGGED: 31-]AN-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 71.1 MAXIMUM ANGLE: 74.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 216262 EWR4 ELECTROMAG. RESIS. 4 96540 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.750 DRILLER'S CASING DEPTH (FT): 2744.0 BOREHOLE CONDITIONS MUD TYPE: Fresh Water Gel MUD DENSITY (LB/G): 10.00 MUD VISCOSITY (S): 9.0 MUD PH: 10.0 Page 10 • cd3-316a.tapx MUD CHLORIDES (PPM): 350 FLUID LOSS (C3): .0 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F ) MUD AT MEASURED TEMPERATURE (MT): 1.200 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .664 132.0 MUD FILTRATE AT MT: 1.600 70.0 MUD CAKE AT MT: 2.100 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..... .....0 Data specification Block Type .....0 Logging Direction ............ .....DOwn Optical log depth units...... .....Feet Data Reference Point ......... .....undefined Frame Spacing....... ....... .....60 .lIN Max frames per record ........ .....undefined Absent value ................. .....-999 Depth Units ................. ..... Datum Specification Block sub -type...0 Name Service order units size N sam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MwD040 OHMM 4 1 68 16 5 FET MwD040 HR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MWD040 FPH 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10275.5 11199 10737.3 1848 10275.5 11199 RPD MWD040 OHMM 4.21 61.3 10.9569 1739 10275.5 11144.5 RPM MWD040 OHMM 3.61 56.38 10.0541 1739 10275.5 11144.5 RPS MWD040 OHMM 2.89 20.24 6.50825 1739 10275.5 11144.5 RPX MWD040 OHMM 2.63 14.05 5.43554 1739 10275.5 11144.5 FET MWD040 HR 0.45 82.21 1.10224 1739 10275.5 11144.5 GR MWD040 API 117.08 436.24 213.844 1756 10275.5 11153 ROP MWD040 FPH 1.22 216.22 107.053 1848 10275.5 11199 First Reading For Entire File..........10275.5 Last Reading For Entire File...........11199 File Trailer service name... .......STSLI6.004 Service Sub Level Name... version Number...........1.0.0 Page 11 cd3-316a.tapx Date of Generation.......08/03/31 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.005 Physical EOF File Header Service name... .......STSLI6.005 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/31 Maximum Physical Record..65535 File Type. ............Lo Previous File Name.......STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE START DEPTH RPX 11145.0 RPM 11145.0 RPD 11145.0 RPS 11145.0 FET 11145.0 GR 11153.5 ROP 11199.5 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 EWR4 ELECTROMAG. U header data for each bit run in separate files. 5 .5000 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: 5 STOP DEPTH 11635.5 11635.5 11635.5 11635.5 11635.5 11643.5 11690.0 RAY RESIS. 4 Page 12 02-FEB-08 Insite 6.02 Memory 73.2 88.2 TOOL NUMBER 242567 127479 8.750 2744.0 Fresh water Gel • cd3-316a.tapx MUD DENSITY (LB/G): 9.70 MUD VISCOSITY (S): 44.0 MUD PH: 9.5 MUD CHLORIDES (PPM): 400 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEGF ) MUD AT MEASURED TEMPERATURE (MT): .900 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .524 125.0 MUD FILTRATE AT MT: 1.960 70.0 MUD CAKE AT MT: 2.200 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..... .....0 Data Specification Block Type .....0 Logging Direction ............ .....DOwn Optical log depth units...... .....Feet Data Reference Point ......... .....undefined Frame Spacing....... ....... .....60 .lIN Max frames per record ........ .....undefined Absent value ................. .....-999 Depth Units ................ ..... Datum Specification Block sub -type...0 Name Service order units size N sam Rep Code offset Cha nnel DEPT FT 4 1 68 0 1 RPD MWD050 OHMM 4 1 68 4 2 RPM MWD050 OHMM 4 1 68 8 3 RPS MWD050 OHMM 4 1 68 12 4 RPX MWD050 OHMM 4 1 68 16 5 FET MwD050 HR 4 1 68 20 6 GR MWD050 API 4 1 68 24 7 ROP MwD050 FPH 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 11145 11690 11417.5 1091 11145 11690 RPD MWD050 OHMM 4.08 115.58 10.5082 982 11145 11635.5 RPM MwD050 OHMM 3.75 63.16 7.71948 982 11145 11635.5 RPS MWD050 OHMM 3.03 35.52 5.3972 982 11145 11635.5 RPX MWD050 OHMM 2.42 29.61 4.70661 982 11145 11635.5 FET MwD050 HR 0.75 26.48 4.40082 982 11145 11635.5 GR MWD050 API 65.69 283.15 142.904 981 11153.5 11643.5 ROP MWD050 FPH 2.48 261.68 75.4061 982 11199.5 11690 First Reading For Entire File..........11145 Last Reading For Entire File...........11690 File Trailer Page 13 • cd3-316a.tapx Service name... .......STSLIB.005 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/03/31 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.006 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/03/31 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. .. ...............08/03/31 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Page 14 cd3-316apbl.txt Sperry-Sun Drilling Services LIS Scan Utility $Revision• 3 $ LisLib $Revision: 4 $ Mon Apr 07 09:41:47 2008 Reel Header Service name .............LISTPE Date . ...................08/04/07 0ri9in ...................STs Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. Tape Header Service name .............LISTPE Date . ...................08/04/07 Origin ...................STS Tape Name. .... ........UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Physical EOF Comment Record TAPE HEADER Alpine MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER OPERATOR WITNESS MWD RUN 2 MW-000555131 J. BOBBITT D. BURLEY scientific Technical services Library. scientific Technical services CD3-316AP61 501032055970 Conoco Phillips Alaska Inc. Sperry Sun 28-MAR-08 MWD RUN 3 MW-000555131 A. MENEZES D. LUTRICK SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 5 12N 5E 3969 0 971 0 .00 49.50 13.20 Page 1 ci~-~~ ~! ~~~ C5 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: cd3-316apbl.txt OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.750 9.625 2744.0 8.750 9.625 2744.0 a 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY AND IS NOT PRESENTED. 4. MWD RUN 2-3 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), PRESSURE WHILE DRILLING (PWD), DRILLSTRING DYNAMICS SENSOR (DDSr), COMPENSATED THERMAL NEUTRON POROSITY (CTN), AZIMUTHAL LITHO-DENSITY (ALD), AND ACOUSTICALIPER (ACAL). 5. SNP2 NOT PRESENTED DUE TO SENSOR MALFUNCTION. 6. MWD DATA ARE CONSIDERED PDC PER DISCUSSION OF ALPINE LOGGING REQUIREMENTS AT CONOCO-PHILLIPS/VENDOR MEETING HELD ON 26 SEPTEMBER 2001. DOUG KNOCK (CPAI) CONFIRMED THAT THIS WOULD ALSO BE THE CASE FOR DRILLSITES 3 AND 4 WELLS IN A PHONE CONVERSATION WITH BUSTER BRYANT (SDS) ON 27 APRIL 2005. 7. THIS WELL KICKED OF FROM CD-316 AT 6017' MD, 4794' TVD. 7. MWD RUN 1-3 REPRESENTS THE WELL CD3-316APB1 WITH API#:50-103-20559-71. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11407'MD/6771'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA S HALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP SPACING) . TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. Page 2 ~ • cd3-316apbl.txt SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. DENSLIDE = NON-ROTATED INTERVALS REFLECTING DENSITY SENSOR DEPTHS. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 8.75~~ MUD WEIGHT: 9.6- 9.7 PPG MUD SALINITY: 300 PPM CHLORIDES FORMATION WATER SALINITY: 14,545 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE ALL DATA CURVES ARE SMOOTHED TO A STEP OF 0.5 FT, WITH A WINDOW OF 0.6 FT, EXCEPT FOR ROP AND GAMMA RAY, WHICH ARE BOTH SMOOTHED TO A 1.1 FT WINDOW. ALL DATA HAS A GAP FILL OF 5 FT APPLIED. File Header Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/07 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSL26.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH NPHI 2710.5 11312.0 NCNT 2710.5 11312.0 RHOB 2710.5 11326.0 RPS 2710.5 11354.5 DRHO 2710.5 11326.0 FET 2710.5 11354.5 RPD 2710.5 11354.5 RPX 2710.5 11354.5 RPM 2710.5 11354.5 FCNT 2710.5 11312.0 GR 2710.5 11362.0 ROP 2755.5 11407.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH Page 3 S MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MWD 2 MWD 3 REMARKS: MERGED MAIN PASS. cd3-316apbl.txt MERGE TOP MERGE BASE 2710.5 6016.5 6017.0 11407.0 Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing ........ ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD CP30 4 1 68 4 2 NCNT MWD CP30 4 1 68 8 3 RHOB MWD G/CC 4 1 68 12 4 DRHO MWD G/CC 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HR 4 1 68 36 10 GR MWD API 4 1 68 40 11 ROP MWD FPH 4 1 68 44 12 NPHI MWD PU 4 1 68 48 13 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2710.5 11407 7058.75 17394 2710.5 11407 FONT MWD CP30 525.89 3730.66 1003.18 17204 2710.5 11312 NCNT MwD cP30 100793 189066 131857 17204 2710.5 11312 RHOB MWD G/CC 0.321 3.13 2.40283 17232 2710.5 11326 DRHO MWD G/CC -2.785 0.328 0.0479221 17232 2710.5 11326 RPD MWD OHMM 0.14 2000 9.32228 17289 2710.5 11354.5 RPM MWD OHMM 0.19 2000 6.37103 17289 2710.5 11354.5 RPS MWD OHMM 0.25 936.37 5.64286 17289 2710.5 11354.5 RPX MWD OHMM 0.49 860.93 5.38528 17289 2710.5 11354.5 FET MWD HR 0.18 100.68 0.952272 17289 2710.5 11354.5 GR MwD API 52.02 454.68 128.998 17304 2710.5 11362 ROP MWD FPH 0 619.06 165.73 17304 2755.5 11407 NPHI MwD Pu 11.6 60.19 34.9991 17204 2710.5 11312 First Reading For Entire File..........2710.5 Last Reading For Entire File...........11407 File Trailer Service name .............STSLIB.001 Page 4 cd3-316apbl.txt service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/07 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.002 Physical EOF File Header service name... .......STSLIB.002 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/07 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSL26.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 2710.5 6016.5 RPx 2710.5 6016.5 NPHI 2710.5 6016.5 RPS 2710.5 6016.5 GR 2710.5 6016.5 DRHO 2710.5 6016.5 FONT 2710.5 6016.5 RPD 2710.5 6016.5 NCNT 2710.5 6016.5 RPM 2710.5 6016.5 RHOB 2710.5 6016.5 ROP 2755.5 6016.5 LOG HEADER DATA DATE LOGGED: 22-JAN-08 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 39.4 MAXIMUM ANGLE: 47.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 242567 EWR4 ELECTROMAG. RESIS. 4 127479 CTN COMP THERMA L NEUTRON 185457 Page 5 cd3-316apbl.txt BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.750 DRILLER'S CASING DEPTH (FT): 2744.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 9.60 MUD VISCOSITY (s): 39.0 MUD PH: 9.1 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3): 9.6 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 4.250 75.0 MUD AT MAX CIRCULATING TERMPERATURE: 2.320 143.0 MUD FILTRATE AT MT: 7.900 75.0 MUD CAKE AT MT: 6.200 75.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units... .........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FONT MWD020 CP30 4 1 68 4 2 NCNT MWD020 CP30 4 1 68 8 3 RHOB MWD020 G/CC 4 1 68 12 4 DRHO MWD020 G/CC 4 1 68 16 5 RPD MWD020 OHMM 4 1 68 20 6 RPM MWD020 OHMM 4 1 68 24 7 RPS MWD020 OHMM 4 1 68 28 8 RPX MWD020 OHMM 4 1 68 32 9 FET MWD020 HR 4 1 68 36 10 GR MWD020 API 4 1 68 40 11 ROP MWD020 FPH 4 1 68 44 12 NPHI MWD020 Pu 4 1 68 48 13 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2710.5 6016.5 4363.5 6613 2710.5 6016.5 FCNT MWD020 CP30 525.89 2313.83 872.978 6613 2710.5 6016.5 Page 6 • • cd3-316apbl.txt NCNT MWD020 CP30 100793 170777 125998 6613 2710.5 6016.5 RHOB MWD020 G/CC 0.321 3.107 2.30146 6613 2710.5 6016.5 DRHO MWD020 G/CC -2.785 0.311 0.0308008 6613 2710.5 6016.5 RPD MWD020 OHMM 0.14 2000 11.8896 6613 2710.5 6016.5 RPM MWD020 OHMM 0.19 1164.2 4.88575 6613 2710.5 6016.5 RPS MWD020 OHMM 0.25 936.37 4.56383 6613 2710.5 6016.5 RPX MWD020 OHMM 0.49 860.93 4.35811 6613 2710.5 6016.5 FET MwD020 HR 0.18 61.26 1.29734 6613 2710.5 6016.5 GR MWD020 API 60.05 200.16 121.543 6613 2710.5 6016.5 ROP MWD020 FPH 0 619.06 227.56 6523 2755.5 6016.5 NPHI MWD020 Pu 16.56 60.19 37.6776 6613 2710.5 6016.5 First Reading For Entire File..........2710.5 Last Reading For Entire File...........6016.5 File Trailer Service name... .......STSLIB.002 service sub Level Name... version Number.. ........1.0.0 Date of Generation.......08/04/07 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/07 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sTSLI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH RHOB 6017.0 11326.0 RPS 6017.0 11354.5 RPD 6017.0 11354.5 RPx 6017.0 11354.5 DRHO 6017.0 11326.0 NPHI 6017.0 11312.0 FET 6017.0 11354.5 RPM 6017.0 11354.5 GR 6017.0 11362.0 NCNT 6017.0 11312.0 ROP 6017.0 11407.0 FCNT 6017.0 11312.0 Page 7 • • cd3-316apbl.txt LOG HEADER DATA DATE LOGGED: 28-7AN-08 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 45.6 MAXIMUM ANGLE: 73.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 242567 EWR4 ELECTROMAG. RESIS. 4 127479 CTN COMP THERMAL NEUTRON 185457 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.750 DRILLER'S CASING DEPTH (FT): 2744.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 9.70 MUD VISCOSITY (S): 41.0 MUD PH: 9.3 MUD CHLORIDES (PPM): 280 FLUID LOSS (C3): 4.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 2.200 73.0 MUD AT MAX CIRCULATING TERMPERATURE: 1.172 143.0 MUD FILTRATE AT MT: 2.800 73.0 MUD CAKE AT MT: 2.900 72.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units ................ ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 Page 8 cd3-316apbl.txt FONT MWD030 cP30 4 1 68 4 2 NCNT MWD030 CP30 4 1 68 8 3 RHOB MWD030 G/CC 4 1 68 12 4 DRHO MWD030 G/CC 4 1 68 16 5 RPD MwD030 OHMM 4 1 68 20 6 RPM MWD030 OHMM 4 1 68 24 7 RPS MWD030 OHMM 4 1 68 28 8 RPX MWD030 OHMM 4 1 68 32 9 FET MWD030 HR 4 1 68 36 10 GR MWD030 API 4 1 68 40 11 ROP MWD030 FPH 4 1 68 44 12 NPHI MwD030 Pu 4 1 68 48 13 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 6017 11407 8712 10781 6017 11407 FCNT MwD030 CP30 713.87 3730.66 1084.47 10591 6017 11312 NCNT MWD030 CP30 116759 189066 135516 10591 6017 11312 RHOB MwD030 G/CC 1.994 3.13 2.46595 10619 6017 11326 DRHO MWD030 G/CC -0.037 0.328 0.0585844 10619 6017 11326 RPD MwD030 OHMM 1.5 1811.72 7.732 10676 6017 11354.5 RPM MWD030 OHMM 1.57 2000 7.29106 10676 6017 11354.5 RPS MWD030 OHMM 2.45 534.79 6.31123 10676 6017 11354.5 RPX MWD030 OHMM 2.18 31.61 6.02154 10676 6017 11354.5 FET MwD030 HR 0.27 100.68 0.738527 10676 6017 11354.5 GR MWD030 API 52.02 454.68 133.61 10691 6017 11362 RoP MWD030 FPH 0 280.73 128.32 10781 6017 11407 NPHI MWD030 Pu 11.6 49.68 33.3266 10591 6017 11312 First Reading For Entire File..........6017 Last Reading For Entire File...........11407 File Trailer service name... .......STSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/04/07 Maximum Physical Record..65535 File Type ................L0 Next File Name...........STSLIB.004 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/04/07 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Writing Library. Reel Trailer scientific Technical Services Service name .............LISTPE Date . ...................08/04/07 Origin ...................STs Page 9 • cd3-316apbl.txt Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Page 10
