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198-071
XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial They are available in the original file and viewable by direct inspection. /~" ~'/ File Number of Well History File PAGES TO DELETE RESCAN scanning project. Complete Color items - Pages: Grayscale, halftones, pictures, graphs, charts - Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of vadous kinds Other COMMENTS: Scanned by: Beverly Mildred Dareth~owell [] TO RE-SCAN Notes: Re-Scanned by: Beverly Mildred Daretha Nathan Lowell Date: ~si .1/40 OF 7'4 17y,' • yw\� _cv THE STATE Alaska Oil and Gas �� ofl ALASKA Conservation Commission , - GOVERNOR SEAN PARNELL 333 West Seventh Avenue * Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 'OIL Daniel Beardon %WED Drilling Engineer l _ Q (7/ ConocoPhillips Alaska Inc. V P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Tarn Oil Pool, 2N-323 Sundry Number: 313-519 Dear Mr. Beardon: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ( k4ft4- -- Cathy P. F erster Chair, Commissioner DATED this'd day of October, 2013. Encl. • • I 'RECEIVED STATE OF ALASKA ,ot, OCT 0 3,201;3 ALASKA OIL AND GAS CONSERVATION COMMISSION OZ /d g L3 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon[ lv Plug for Redrill el„ Perforate New Pool❑ Repair Well❑ Change Approved Program 0 Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing El Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing© Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska Inc. Exploratory ❑ Development Q. 198-071 • 3.Address: Stratigraphic ❑ Service El 6.API Number: P.O.Box 100360,Anchorage,Alaska 50-10320258 4 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No El 2N-323• 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 380054 ‘ Kuparuk River Field Tarn Oil Pool • 11. PRESENT WELL CONDITION SUMMARY-Doyon 14' Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 9553' • 5412' . 9530' • 5397' . Casing Length Size MD TVD Burst Collapse Structural Conductor 76' 16" 108' 108' 1640 670 Surface 3428' 9-5/8" 3461' 2299 5750 3090 Intermediate Production 8726' 7" 8760' 4878' 7240 5410 Liner 770' 4-1/2" 9530' 5397' 8440 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9060-9080,9130-9170 5081-5095,5129-5156 4-1/2" 12.6#NSCT 8761 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker CSR at 8760'MD I• Baker CSR at 4877'TVD• 12.Attachments: Description Summary of Proposal El 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development El• Service ❑ 14. Estimated Date for 1-Jan-14 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended [ $a 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned [.. ■ Commission Representative: GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Daniel Bearden Email j.daniel.bearden(a7,cop.com Printed Name Daniel Bearden Title Drilling Engineer Signature pai te07 Phone 907-263-4864 Date A , 04 ,^01 COMMISSION USE ONLY 'kt L Conditions of approval: Notify Commission so that a representative may witness Sundry Number: `3 1 Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: ,Z a ,7 ri-5 t /--c) 5 572 a p 5 l Spacing Exception Required? Yes ❑ No Subsequent Form Required: 1 l g APPROVED BY Approved by: �� COMMISSIONER THE COMMISSION Date: /0— /0 '1 Submit Form and Form 10-403(Revised 10/2012) Approved ORIGINAL pl' ion is valid for 12 months from the date of approval. Attachments in Duplicate �iF ►�,,/1, ,� � RBDMS OCT 11 / b / x113 0 • RECEIVED ' ConocoPhillips Alaska, Inc. Post Office Box 100360 Nov'Anchorage,Alaska 99510-0360 1C 01� ConocoPhillips Telephone 907-276-1215 AOGCC October 1st, 2013 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage,Alaska 99501 Re: Sundry Permit--Request to Rig Abandon 2N-323 and Plug for Re-Drill Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Sundry Permit to perform Rig Abandonment operations on well 2N-323 with the intention to abandon the motherbore and drill a rotary sidetrack to relocafel a well out of a swept area. The anticipated i date tor this work is January 2014 using Nabors YE"ng. In a Sundry approved September 27,2013(#313-451), prior to Nabors 9ES rig move onto 2N pad, pre-rig work will include spotting 15.8 ppg cement plugs below and above the seal bore assembly,testing the tubing and IA integrity, and cutting the 4- 1/2"tubing at 3,900' MD. This Sundry Request covers the rig abandonment of pulling the 4-1/2"tubing from 3,900' MD, installing a bridge plug, and cutting and pulling the 7"casing—150'below the surface casing shoe. The rig will then pump a 17.0 ppg cement kick off plug for sidetracking operations. A separate PTD will be requested to cover Sidetrack operations which include drilling 8-1/2" intermediate section which will be cased with 7"and cemented. The production interval will penetrate the Tarn Bermuda Reservoir and will be drilled with 6-1/8" hole, and cased and cemented with 3-1/2"liner. The anticipated start date for the re-entry and plug setting operations is January 1st,2014. Nabors 9ES will perform the work. This operation is planned following the pre-rig abandonment work approved in Sundry number 313-451. The sidetracking procedures will be covered in a separate Application for a Permit to Drill 2N-323A. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Application attachments include: 1. Form 10-403 2. Proposed Rig re-entry and abandonment program 3. 2N-323 Current Schematic 4. 2N-323 Pre-Rig Abandonment Schematic 5. 2N-323 Rig Abandonment/Set up for Sidetrack Schematic 6. Pre-Rig abandonment procedures approved in Sundry#313-451 Application information already on file with 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. 3. Diagram of riser set up. If you have any questions or require further information, please contact Daniel Bearden at 263-4864 or Chip Alvord at 265-6120. Ster y Daniel B den Drilling Engineer Attachments: cc: 2N-323 Well File/Sharon Allsup Drake ATO 1530 Liz Jolley ATO 1568 Chip Alvord ATO 1570 the Su di git ` 45 / 'sP�r Td J�,.- I I con up, , Walter Car O 20 dco / 4/1761 P e d 40f dC fry/fie Cot lS 1,r� G k 'to? 6v"-- LL Alf 'Vvlve Of ,'t' tVern " ktrc/, 4h// 4 i, e f/4a �� �^ell /195 wri11C 1,r-- an, re,lqi 5/10V id ui/c: or r; fiVOawctr��rec j fr6,n rhi� M1, ,4• /i/% • • Nabors 9ES 2N-323 Abandonment Procedure The proposed scope of work for this sundry application includes: 1. MIRU Nabors 9ES onto 2N-323. 2. Test 7"casing, 7"casing pack off and BPV through inner annulus to 2,000 psi for 10 minutes, chart PT. 3. Test tree adaptor to 5,000 psi, pull CIW"H" BPV. 4. Circulate diesel freeze protect out through the tubing cut at-3,900' MD w/hot SWI swapping over to 10 ppg kill weight mud through tree,taking returns to tiger tank. 5. Set BPV and test through inner annulus to 2,000 psi. 6. Set blanking plug& ND tree. 7. Notify AOGCC field inspector 24 hours prior to BOPE test. 8. Nipple up BOPE and test to 250/3500 psi. 9. Remove blanking plug and BPV. 10. Pull &lay down 4-1/2"tubing (pre-cut at-3,900 MD). 11. Run 7" casing scraper to-3,800' MD 12. Run 7" Baker CIBP on 4" DP and set at-3,700' MD. PT to 2,500 psi 13. Pressure test lower rams with 3.5" (cement stinger) and 4" (drillpipe)test joints. 14. Run in hole with mechanical casing cutter on 4" drillpipe and cut casing at 3,650' &3,300' MD. 15. Flush 7"x 9-5/8"annulus with 10.0 ppg mud taking returns to tiger tank. 16. Swap 3.5"x 6" rams to 7" casing rams and pressure test to 250/3500 psi. 17. Pull 7"casing to surface and lay down. RIH with jars and retrieve casing stub at bottom. 18. Swap 7" casing rams to 3.5"x 6" rams and pressure test. 19. RIH with 3.5" cement stinger and set cement kick off plug from the top of bridge plug to 200' inside the surface shoe. Cement open hole and into existing 9-518" surface casing from +1-3,700' MD to 3,260' MD (440' of fill) with Class G + Adds @ 17.0 ppg. Assume 100% excess in the open hole and 0%excess inside surface casing. Plug: (3,700' 3,460')x 0.3941 ft3/ft x 2.00(100% excess)=189 ft3 in open hole (3,460' -3260')x 0.4257 ft3lft x 1.00(0% excess)= 852 ft3 inside surface csg Total volume=189 ft3+85.2 ft3=274.2 =>272 Sx @ 1.010 ft3/sk System: 272 Sx Class G§17.0 PPG 20. P/U directional drilling BHA and RIH. Tag TOC and pressure test surface casing and KO plug to 2,300 psi. 21. Dress off cement kickoff plug and control drill to below surface casing shoe. 22. Drill out 20' of new formation and perform FIT/LOT. 23. Ready to move into drilling phase under new PTD. 24. Begin new PTD. Begin two-week BOPE testing cycle. • • 2N-323 Current Schematic t KUP 2N-323 ConocoPhillips Well Attributes Max Angle&MD TD M1, _ Vie More AWAIT Feld Name Well Status Inc'(`) 90)44190 Act Strn(hN8) Gampr�+e'am 50.J32V25&^JJ TARN PARTICIPATING AREA PROD 93.31 2:.0:.5'. 9.5530 ... er---/- r .. -ett -W-r.ene..,e r, ... `tom,.wr' =w...,s s,.:ni.. Rroant 5SSV.Ni:PLE 69 10:21:20',77 1401 WO 3595 4.24:998 -f.'Ki,TL.,,,,a Annotation - Depth .) End. • oOtion Last Mod_End Date Last Tag.R58 9.1710 1.25.9011 Re r Reururl.WELL RE0.9W 00600 1,124:1012 Casing Strings -`" -131111 Casing Descripto- suing O... sting ID..Top(KIM) set Depth If set Depth(ND) sting VP sutra. string Top Thrd CONDUCTOR 19 5.102 32.5 108.0 108.0 WELDED - Casing Deseeption Sting 0... Siting ID...Top lie) set Depth If Set Depth(TVD)...-Sting Wt...string..Sting Top Thrd SURFACE II 91 8.835 32.5 3.450.7 2298.8 du nu 1-2+7 PT Casing Dnnrnp6on 'String 0... sting ID_.Top(RIB) Set Depth(f.Std Depth(ND)...string Wt.Suing. String Top Thrd lig ":011 PRODUCTION 7 8.276 27.5 9,529.8 5397.0 2800 1.01 BIC-0.0D 794 5- '8161 Tubing Strings Tubing Desonp8on string O._ Stnng ID..Top(ftK8) Set Depth If Set Depth(ND)...string Wt.sting. String Top mid • I ROBING 4'2 3'_358 24.0 2.790.8 4.877.6 '2 ND 1-80 NS'.0 Completion Details Top Depth fTVD) Top MC Ron. `fit Top(M(8) (Me/ (`) hem Desenption Garment 1D On) 4.0 242 .046 MANGER FMC 0E91 5N1 IU8d4G HANGER 4.500 Ci.711DtiCron.� 959.9 558.1 10.89 NIPPLE CAMCU Ot3 NIPPLE 3.875 41iCa • 8.6994 4.837.5 50.03 SLEEVE-C BAKER CMU SLIDING SLEEVE re'3.8'.2 CAMCO DB PROF ILL 3.810 8,752.5 4,8 72.2 48.74 NIPPLE CAM CO D8 NIPPLE NO GO 3.750 II 8.759.8 4.877.0 48.55 SEAL A550 BAKED 89-07 CASING SEAL ASSEMBLY 3.8:15 f4'1,-E HO Perforations&Slots Snot al Top(ND)Stn(1V0) Dens Top IRKS)81m TRIM) d9L91 (4818) Zone Dan (sh._. Type Conment RE 90606 9.9809 5X1.3 5.094.9 TARN 43. 11>222000 6-0APE1F 27;8'PJ,60 DEG PHASE 29.323 9.130.0 9.170E 5.1289 5-15565-5.279423 6120'1999 4.0 IPERF 25'NC 614.180 deg ph .r z' Stimulations 8 Treatments Boman • Min Top Max e5n Top Depth Depth Depth Depth (ND) (TVDI (hdC81 IKKB) Mall ( ) Type Dam Careen* 9090.0 9 on 0 5,081.3 5,034.9 FRAC "t24,211081ARN13P RAC WIT-12560 092230560819Zr CARBOLN E:2404 LEFT IN 5518,11 PPA ON FORMATION(3496 881 or SW. Notes:General&Safety End Sate Annotator 11;22'2010 NOTE:Vv«Schemete on Alnsko Schethate.LT .90MACE A : 1 334,411 at v_EC005 16'09 'Ana)1 f1, lit ,---` ®'' 111.1 )9 e° ` k� I Mandrel Details ?op Depth Top Pat 1709? Ind OD Vaee Latch Sine 1R0 Run Sin 109)883) /868) (`) Make Model (in) set Type Type Iii) 1p•,) Run Date Cont. P.709.0 48442 49.7)CAMCO KG13-2-IS 1 GAS LIFT 07 LIT 0.250 0.0 12.5210:03 PERT, 1,30-9.170 1 9.9940TON Txa,6-C tT4g,L-i 53C Tg.9993 • • 2N-323 Nabors 9ES Rio Abandonment Schematic Tarn 2N-323 Rig Abandonment COnocoPhilli 9 s � -9 '+ROC Gen V Bearden 09/19/13 16"Existin. Cemented Conduct. 16"62.6#H-40 108'MD Existing 9-518"Weatherford Gemoco Stage Collar ci i 1,800` (be aware when tripping in ia,out) - 17.0 ppg cement plug TOC 3, e0'MD Existing Surface Casino: iii —7"Casing Cut#2 @--3,3 0'MD 9-5/8"40#L-80 BTC -t--""- 17.0 ppg ��l 3,460'MD/2,299'ND a©62° Cement 7 4 0 ?f 'i l f� G( � Kickoff Plug _��. O —7"Casing Cut#1 @– ,650'MD CIBP @–3,700'M 3i3 — S €' _. Cut 4.5"Tubing @ 3,900'MD Tubing: 4-'/z'12.6#L-80 NSTC �z+ dryt/In ' ,• Well loaded from top of cement plug with 150 bbls kv1 corrosion inhibited-12.2 ppg KWF. 313 7-t 00 4 / 5'Tubing Punches @ TOC V J E&APlu2�6bW15fC3 i ft 4 gbEgF 10 asi1oY 74-00 I Original TOC 15.9 ppg @+1-8,000'MD ? -. Baker CMU Sliding Sleeve(Closed)8699'MD 111 7I Cameo KBG•2-LS 1"GLV w!BTM latch 8710' MD Cameo DB Nipple 8753'MD(tD=3.75"i Baker 80-47 Seal Assembly 8760'MD iii:.N i i i::i :Set iu04TX00 .*BObt!'MQ':.L._'_, . t[ie i� >:ps a. F 1 y..Nw .ar i ato , ^ :• tl�b 8 '30%9170:I1D� ate- l v> !. . I . _ 859 psi 5 140'TVO 10.T • .Bermuda Pore Pressure(7129/11).2, p @ peg.i Existing 7"x 4-'/z"Monobore Completion: 7"26#L-80 BTCM 4.5"12.64 L-80 NSCT 9,530'MD/5.397'ND • • Pre-Rig Abandonment Work Approved in Sundry#313-451 Objectives The objective of this procedure is to abandon the existing Bermuda interval and set up the well for a rig rotary sidetrack. The rig will sidetrack from just below the surface casing shoe. In preparation for the sidetrack this work will be completed to isolate the formation from the wellbore, load the well with inhibited fluid, and a d cut the tubing at 3,900' RKB. Procedure Slickline: 1. Drift tubing, Tag fill. 2. Obtain SBHP as deep as possible, then 100' TVD uphole. 3. Pump short injectivity test to ensure adequate cement rates are achievable. 4. Set Plug in DB-Nipple at 8753' 5. Pull 1" OV from station at 8710', set 1" DV in same. 6. Shift sliding sleeve at 8699' to OPEN position. 7. Circulate 294 bbl diesel down tubing taking returns from IA to adjacent producer. a. 294 bbl = Calculated volume of tubing and annulus to 8699'. 8. Combo MIT to 2500 psi. 9. Pull plug from DB Nipple at 8753', keeping sliding sleeve in OPEN position. E-Line: 1. Run Caliper& CCL log from seal assembly to surface. Coiled Tubing: 1. RIH & set a 3-3/8" Baker inflatable cement retainer(w/internal check valve to prevent fluid flow from below when un-stung) or Weatherford FH one-trip retainer near the nipple at 8753'. 2. RIH and sting into retainer. 3. Confirm open hole will take fluid by pumping 50 bbl of SW. 4. Pump 25 bbs of 15.8 ppg Class G cement through retainer down to perfs. Un-sting from retainer. PUH above open CMU sliding sleeve. Open surface IA casing valve, close tubing side choke, and begin taking returns from the IA. Pump an additional 20 bbl of cement, taking all returns from the IA. After the 20 bbls has been pumped, close IA at surface and begin pulling out of hole, laying in 20 bbls of cement in the 4.5" tubing. 5. After cement has been pumped and equipment washed up, lay in diesel freeze protect in tubing from 2000' to the surface. 6. Notify AOGCC Inspector (659-2714; 659-3607 pager) of timing of post-cement plug tag & PT. Slickline: 1. Tag TOC at-7430' MD. 2. PT tubing to 2000 psi, PT IA to 2000 psi, record results. E-Line: 1. RIH with tubing punch to 200' MD above top of cement (avoiding cement stringers) and punch holes in tubing 2. Circulate in 150 bbls of corrosion inhibited -12.2 ppg mud (as determined from SBHP in slickline step#2) followed by 100 bbls of diesel. Jumper IA to tubing and let diesel u-tube. 3. RIH w/Jet Cutter and cut 4.5" tubing -3900' MD (confirm depth w/ CCL to not cut in the middle of a connection) 4. Pressure up (or bleed off) to confirm communication has been made. RDMO. -tea ', \�� �% THE STATE Alaska Oil and Gas °fALAS� Conservation Commission . GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage,Alaska 99501-3572 Main:907.279.1433 Fax:907.276.7542 Daniel Beardon Drilling Engineer ConocoPhillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field,Tarn Oil Pool,2N-323 Sundry Number: 313-451 Dear Mr.Beardon: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision,or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair,Commissioner DATED this?/ day of September,2013. Encl. III • RECEWED AUG 21 2013 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION AOGCC APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1.Type of Request Abandon❑ Plug for Redrill El Perforate New Pod 0 Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations p Perforate❑ Put Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well 0 Stimulate❑ Alter Casing❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Dr1i Ntinber. ConocoPhilips Alaska Inc. Exploratory ❑ Development El 198-071 3.Address: Stratigraptic ❑ Service ❑ 6.API Number: 1,5 P.O.Box 100360,Anchorage,Alaska 50-10320258-oo "t 7.11 pertoralktg: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? WI8 planned perforations regtke a spacing exception? Yes ❑ No❑ 2N-323 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 380054 I Kuparuk River Field Tarn Oil Pool 11. PRESENT WELL CONDITION SUMMARY-Doyon 14' Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 9553' 5412' 9530' 5397' Casing Length Size MD TVD Burst Collapse Structural Conductor 76' 16" 108' 108' 1640 670 Surface 3428' 9-5/8" 3461' 2299 6750 s 3090 Intermediate Production 8726' 7" 8760' 4878' 7240 5410 Liner 770' 4-112" 9530' . 5397' 8440 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9060-9080,9130-9170 5081-5095,5129-5156 4-1/2" 12.65 NSCT 8761 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker CSR at 8760'MD I Baker CSR at 4877'TVD 12.Attachments: Description Summary of Proposal El 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphlo❑ Development el Service ❑ 14.Estimated Date for 1-Oct-13 15.Well Status after proposed work: Commencing Operations: OIl ❑ Gas ❑ WDSPL ❑ Suspended d 16.Verbal Approval. Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ . Commission Representative: GSTOR 0 SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Daniel Bearden Email j.danlel.beardercoo.Cotn Printed Name Daryl Bearden Title Drilling Enarreer Signahxe p---.0 �., c_ Phone 007-263 4864 Date / (r 2 0I ......__ COMMISSION USE ONLY 1/1►�/K!, Conditions of epprovat: Notify Commission so that a representative may wtiness rt Number: 513 "r. 60) Plug BOP Test❑ Mechanical Integrky Test ❑ Location Clesaa nce ❑ Other. Spaces Exception Required? Yes ❑ No [ Subsequed Form Required /0 4.0 APPROVED BY ? Approved try. COMMISSIONER THE CO ItiSSION Date: 7` 2-7 -f,7 Submit Form and Form IO-403 51 IN20 t2) Approved application Is valid for 12 months from the date of approval Attachments In Duplicate 1 DUPLICATE . • • ConocoPhillips Alaska,Inc. I Post Office Box 100360 " Anchorage,Alaska 99510-0360 AUG 2 1 2113 ConocoPhillips Telephone 907-276-1215 August 20th,2013 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue,Suite 100 Anchorage,Alaska 99501 Re:Sundry Permit--Request to Pre-Rig Abandon 2N-323 and Plug for Re-Drill Dear Sir or Madam: • ConocoPhillips Alaska, Inc.hereby applies for a Sundry Permit to perform pre-rig abandonment operations on well 2N-323 with the intention to isolate the perforations,tubing,and inner annulus with 15.8 ppg Class G, cut the tubing and cap the cement with KWF and diesel freeze protect. Drilling operations expected to commence on January 1M,2014 will perform a rig abandonment of pulling the 4-1/2"tubing and cutting and pulling the 7"casing-100' below the surface casing shoe. The rig will then pump a cement kick off plug for sidetracking operations. Sidetrack operations include drilling 8-1/2" intermediate section which will be cased with 7"and cemented. The production Interval will penetrate the Tam Bermuda Reservoir and will be drilled with 6-1/8"hole, and cased and cemented with 3-1/2"liner. Nabors 9ES will perform the work. A separate Rig Abandonment Sundry will be requested soon. The sidetracking procedures will be covered in a separate Application for a Permit to Drill 2N-323A. Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Application attachments Include: 1. 2N-323 Current Schematic 2. Form 10-403 3. Proposed Pre-Rig Abandonment program 4. 2N-323 Proposed Pre-Rig Abandonment Schematic 5. Proposed Rig Abandonment program 6. 2N-323 Proposed Rig Abandonment Schematic Application information already on file with 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. 3. Diagram of riser set up. If you have any questions or require further information, please contact Daniel Bearden at 263-4864 or Chip Alvord at 265-6120. S rely, &IL-- I D niel Bearden Drilling Engineer Attachments: cc: 2N-323 Well File/Sharon Ailsup Drake ATO 1530 Liz Jolley ATO 1568 Chip Alvord ATO 1570 1 • • Sundry Application Proposed Pre-Rig Abandonment Program Objectives The objective of this procedure is to abandon the existing Bermuda interval and set up the well for a rig rotary sidetrack. The rig will sidetrack from just below the surface casing shoe. In preparation for the sidetrack this work will be completed to isolate the formation from the wellbore, load the well with inhibited fluid, and cut the tubing at 3,900' RKB. Procedure Siickline: 1. Drift tubing,Tag fill. 2. Obtain SBHP as deep as possible,then 100'TVD uphole. 3. Pump short injectMty test to ensure adequate cement rates are achievable. 4. Set Plug in DB-Nipple at 8753' 5. Pull 1" OV from station at 8710', set 1" DV in same. 6. Shift sliding sleeve at 8699'to OPEN position. 7. Circulate 294 bbl diesel down tubing taking returns from IA to adjacent producer. a. 294 bbl= Calculated volume of tubing and annulus to 8699'. 8. Combo MIT to 2500 psi. 9. Pull plug from DB Nipple at 8753', keeping sliding sleeve in OPEN position. E-Line: 1. Run Caliper&CCL log from seal assembly to surface. Colled Tubing: 1. RIH &set a 3-3/8" Baker inflatable cement retainer(w/internal check valve to prevent fluid flow from below when un-stung)or Weatherford FH one-trip retainer near the nipple at 8753'. 2. RIH and sting into retainer. 3. Confirm open hole will take fluid by pumping 50 bbl of SW. 4. Pump 25 bbs of 15.8 ppg Class G cement through retainer down to perfs. Un-sting from retainer. PUH above open CMU sliding sleeve. Open surface IA casing valve, close tubing side choke, and begin taking returns from the IA. Pump an additional 20 bbl of cement,taking all returns from the IA. After the 20 bbls has been pumped, close IA at surface and begin pulling out of hole, laying in 20 bbls of cement in the 4.5"tubing. 5. After cement has been pumped and equipment washed up, lay in diesel freeze protect in tubing from 2000'to the surface. 6. k• i> AOG n: •ector 659-2714.659-3607 •a_er of timin, of •ost-cement plug tag& PT. Siickline: 2-4- hvt✓S aCjdnvl- .t 'lD/-1 cC 1. Tag TOC at-7430' MD. 2. PT tubing to 2000 psi, PT IA to 2000 psi, record results. E-Line: 1. RIH with tubing punch to 200' MD above top of cement(avoiding cement stringers)and punch holes in tubing 2. Circulate in 150 bbls of corrosion inhibited-12.2 ppg mud(as determined from SBHP in slickline step#2)followed by 100 bbis of diesel. Jumper IA to tubing and let diesel u-tube. 3. RIH wi Jet Cutter and cut 4.5"tubing-3900' MD(confirm depth w/CCL to not cut in the middle of a connection) 4. Pressure up(or bleed off)to confirm communication has been made. RDMO. L 0 • 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 1/ 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 teps 1 and 2. 3. When S F ` s 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 • s 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. .,.• ,r r , r ,,.. 1__..-- T--- \T`TT 7 TT TTDTTT DT T T!3 ..DV T1D T A/4/1(111 OF Tk • • ' 101"S ��j,�s� THE STATE Alaska Oil and Gas 7 f — LA ° S KA Conservation Commission �T I GOVERNOR SEAN PARNELL 333 West Seventh Avenue (4' gP Anchorage, Alaska 99501-3572 ALAS �y Main: 907.279.1433 pNNED � 2 1.01 SCAFax: 907.276.7542 Daniel Beardon Drilling Engineer ConocoPhillips Alaska, Inc. g,,,0 7/ P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Tarn Oil Pool, 2N-323 Sundry Number: 313-451 Dear Mr. Beardon: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, P-4e_a4, Cathy P. oerster Chair, Commissioner DATED this Z/ day of September, 2013. Encl. Ilk • • _, . , ' STATE OF ALASKA : P ' ALASKA OIL AND GAS CONSERVATION COMMISSION tT 1ie I (3 APPLICATION FOR SUNDRY APPROVALS ,, � ._ •' 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill El, Perforate New Pool❑ Repair Well❑ Change Approved Program 0 Suspend❑ Plug Perforations El. Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate 0 Alter Casing❑ Other: 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: ConocoPhillips Alaska Inc. Exploratory ❑ Development Ila • 198-071 i 3.Address: Stratigraphic ❑ Service © 6.API Number: k3 P.O.Box 100360,Anchorage,Alaska 50-10320258-o0 $` 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No [] 2N-323" 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL 380054. Kuparuk River Field Tarn Oil Pool 11. PRESENT WELL CONDITION SUMMARY-Doyon 14• Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 9553' - 5412' , 9530' - 5397' . Casing Length Size MD TVD Burst Collapse Structural Conductor 76' 16" 108' 108' 1640 670 Surface 3428' 9-5/8" 3461' 2299 5750 3090 Intermediate Production 8726' 7" 8760' 4878' 7240 5410 Liner 770' 4-1/2" 9530' 5397' 8440 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9060-9080,9130-9170 - 5081-5095,5129-5156 4-1/2" 12.6#NSCT 8761 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Baker CSR at 8760'MD I Baker CSR at 4877'ND, 12.Attachments: Description Summary of Proposal El 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0- Service ❑ 14.Estimated Date for 1-Oct-13 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended D. 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge, Contact Daniel Bearden Email i.daniel.bearden(a�cop.com Printed Name Daniel Bearden Title Drilling Engineer n Signature Phone 907-263-4864 Date COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ( _ 145 1 Plug Integrity BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ 1 Other: FiSDA/9 OCT 1 0 2 Spacing Exception Required? Yes ❑ No II Subsequent Form Required: /0 r 407- APPROVED BY Approved by: 44'-•—• COMMISSIONER THE COMMISSION Date: 1—7,7 /3 Submit Form and Form 10-403 evised 10/2012) Approved OIINAL i o is alid for 12 months from the date of approval. Attachments in Duplicate „2, \cb 1/`F gii,3 '`t� • , • . .t ' t „... _ ConocoPhillips Alaska, Inc. ,, Post Office Box 100360 ' , , Anchorage,Alaska 99510-0360 ConocoPhillips Telephone 907-276-1215 'A' August 20th, 2013 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Sundry Permit--Request to Pre-Rig Abandon 2N-323 and Plug for Re-Drill Dear Sir or Madam: ConocoPhillips Alaska, Inc. hereby applies for a Sundry Permit to perform pre-rig abandonment operations on well 2N-323 with the intention to isolate the perforations, tubing, and inner annulus with 15.8 ppg Class G, cut the tubing and cap the cement with KWF and diesel freeze protect. Drilling operations expected to commence on January 1st, 2014 will perform a rig abandonment of pulling the 4-1/2"tubing and cutting and pulling the 7"casing —100' below the surface casing shoe. The rig will then pump a cement kick off plug for sidetracking operations./Sidetrack operations include drilling 8-1/2" intermediate section which will be cased with 7"and cemented. The production interval will penetrate the Tarn Bermuda Reservoir and will be drilled with 6-1/8" hole, and cased and cemented with 3-1/2" liner. Nabors 9ES will perform the work. A separate Rig Abandonment Sundry will be requested soon. The sidetracking procedures will be covered in a separate Application for a Permit to Drill 2N-323A. ' Please find attached the information required by 20 ACC 25.005 (a) and (c) for your review. Application attachments include: /' vL r Con w'. 7J�{ Le 1/ 1. 2N-323 Current Schematic / ? imp ttr Cyr aid 2. Form 10-403 to Ili f 3. Proposed Pre-Rig Abandonment program a Gil` op. 30 0 4. 2N-323 Proposed Pre-Rig Abandonment Schematic L _ '<el * f,•�, t 5. Proposed Rig Abandonment program , 4 f' /V eq �'Vr Q // 6. 2N-323 Proposed Rig Abandonment Schematic 10 ri y�,�.tf n: 4tf Application information already on file with the AOGCC: �n r4l4 Y �����,,� / 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. 3. Diagram of riser set up. If you have any questions or require further information, please contact Daniel Bearden at 263-4864 or Chip Alvord at 265-6120. Si rely, t� �Da ' I Bearden Drilling Engineer Attachments: cc: 2N-323 Well File/Sharon Allsup Drake ATO 1530 Liz Jolley ATO 1568 Chip Alvord ATO 1570 i • 2N-323 Current Schematic KUP 2N-323 ConocoPhillips Well Attributes Max Angle&MD TD Wel800r{MUMS F.Id Ram/ Well Status Inol(9 IMD TRIM a Bun 1868) 501 C256V0 I ARN PARTICIPATING AREA PROD 63.31 2,934,5' 9.5530 5059.NIPPLE 50 10.202007 Last WO: 35.09 4.1411000 *. emanKt as Annotation a •84•r) .ran Annotation Lest _.7 nd Dan Last Tay:RKB 9,173.0 0252011 Rue Raasvn.SMELL REVIEW ostort 1,24:2012 Casing De SVings .FY:e•_- Casing Description String 0 String 1D..Top MK/31 Set[hpMff.set Deem(iW)_.string VR..string_sump Top thrd CONDUCTOR 15 ':5052 325 1080 1080 WELDED .. Casing Description string O_ Suing ID._Top dt106) sa Depth It Set Depth(T9D)...string Wt..sing-.-String Top Thrd SURFACE 95.18 8.835 21,5 3,450.1 2198.5 40 O L-80 ETC ,,. Casing Deacnpkn String 0... String ID..,Top(h(E) Set Depth d.set Depth(190) _SInng Wt..String...String To TMd PRODUC I ION 7 5.210 21.5 9.52.9 8 53975 20 0 480 B1 C-MOD 1 7014 5`61 8760' Tubing Strings tubing Desuiption Stung 0.. sting ID Top 0eK81 Set Depth 0 set Deem(DWI !String Wt_!suing.. sing Top Tied TUBING 4'✓2 3.'.1`18 240 8,1508 4.8'1.6 1250 0-80 745 IC 3 Completion Details Top Depth (TVD) Top 810 Komi.. >W: Top p.(8I t8K8) 19 Item Desuip8on Comment 10 09) 24.0 240 -0.40 11ANGER FMC GEN V SM TUBd4G HANGER I 4.500 CDrmuC Tt _, 559.9 558.1 10.89 NIPPLE CAMCO DB NIPPLE 3.815 WI 8.699.4 4.837.5 50.03 SLEEVE-C BAKER CMU SLIDING SLEEVE w.'3.812 CAMCO DB PROFILE 3.810 8,752.5 4.872.2 48.74 NIPPLE CAMCO DB NIPPLE NO GO 3.750 8.759.8 4.877.0 48.56 SEAL ASSY BAKER 80.41 CASING SEAL ASSEMBLY ''3 879 N' 500 I Perforations&Slots Shot Top(NW Ban(ND) Dens Top WKS)81m f848) dd9B1 WWI tone Dan lsh-- Type Comment 9.0600 9080.0 5,081.3 5,094.9 TARN T3. 10/2212008 6.0 APERF 2 718"PJ,60 DEG PHASE _ J __ 2N-323 9,130.0 9.170.0 5,1289 5.155.6 S-5,2N-323 62001998 401PERF 25'HO 877,..180 deg ph Stimulations&Treatments Bottom Bin Tap Mat Stn Tp Dpth Depth Depth Depth OVD) 74681 (46® IRK 1 mica) ) 0") Type Date Coronae/ 9.060 0 9080 0 5 081.3 5,094.9 FR41, 90.24'1)30 1 APN la FRAC wYF 125ST DEL.23066416:20 1,051000)11 2404 LEFT IN W8.11 PRA ON FORMATION 34116 BBL OF SW. Notes:General&Safety End Date Amotaaan I; 1622'2010 NOTE'.View Sd*emal(c w:'AIaIk4 S menwtic9 0 plat-A:E . ]}1161 � .' it StadW.0 5699 r- 1W,:,-- _ Mandrel Details NMI �� T Depth tl port 1501 Intl tl OD Yalw Latch 111.6 TRO Ron Stn Top OW.8) MKS) 49 Make Mode (inl sent Type Type (1*) MO Ron Date Co....e I 8,709.8 4.844.2 49.11 CAMCO KGB-2-LS 1 GAS LIT OV 8TM 0.250 0.0 12•5130/19 - _ Ng W was awe 1ta.rg 6760.9-9.630-�__._ it 7.964 f Sundry Application Proposed Pre-Rig Abandonment Program Obiectives The objective of this procedure is to abandon the existing Bermuda interval and set up the well for a rig rotary sidetrack. The rig will sidetrack from just below the surface casing shoe. In preparation for the sidetrack this work will be completed to isolate the formation from the wellbore, load the well with inhibited fluid, and cut the tubing at 3,900' RKB. Procedure Slickline: 1. Drift tubing, Tag fill. 2. Obtain SBHP as deep as possible, then 100' TVD uphole. 3. Pump short injectivity test to ensure adequate cement rates are achievable. 4. Set Plug in DB-Nipple at 8753' 5. Pull 1" OV from station at 8710', set 1" DV in same. 6. Shift sliding sleeve at 8699' to OPEN position. 7. Circulate 294 bbl diesel down tubing taking returns from IA to adjacent producer. a. 294 bbl = Calculated volume of tubing and annulus to 8699'. 8. Combo MIT to 2500 psi. 9. Pull plug from DB Nipple at 8753', keeping sliding sleeve in OPEN position. E-Line: 1. Run Caliper& CCL log from seal assembly to surface. Coiled Tubing: 1. RIH &set a 3-3/8" Baker inflatable cement retainer(w/internal check valve to prevent fluid flow from below when un-stung) or Weatherford FH one-trip retainer near the nipple at 8753'. 2. RIH and sting into retainer. 3. Confirm open hole will take fluid by pumping 50 bbl of SW. 4. Pump 25 bbs of 15.8 ppg Class G cement through retainer down to perfs. Un-sting from retainer. PUH above open CMU sliding sleeve. Open surface IA casing valve, close tubing side choke, and begin taking returns from the IA. Pump an additional 20 bbl of cement, taking all returns from the IA. After the 20 bbls has been pumped, close IA at surface and begin pulling out of hole, laying in 20 bbls of cement in the 4.5" tubing. 5. After cement has been pumped and equipment washed up, lay in diesel freeze protect in tubing from 2000' to the surface. 6. Noti AOGCC Inspector(659-2714; 659-3607 pager) of timing of post-cement plug tag & PT. Slickline: Z-Q" h rs ti C e b y t/(--e . Tag TOC at—7430' MD. 2. PT tubing to 2000 psi, PT IA to 2000 psi, record results. E-Line: 1. RIH with tubing punch to 200' MD above top of cement (avoiding cement stringers) and punch holes in tubing 2. Circulate in 150 bbls of corrosion inhibited —12.2 ppg mud (as determined from SBHP in slickline step#2) followed by 100 bbls of diesel. Jumper IA to tubing and let diesel u-tube. 3. RIH w/Jet Cutter and cut 4.5"tubing —3900' MD (confirm depth w/CCL to not cut in the middle of a connection) 4. Pressure up (or bleed off) to confirm communication has been made. RDMO. S 2N-323 Pre-Rig Abandonment Schematic Tarn 2N-323 Pre-Rig Abandonment ConocoPhillips FMC Gen V Bearder 08/19:'13 16"Existing Cemented Conductor: 16"62.6#H-40 108'MD A , Camco DB nipple 560'MO(:D=3.875") Existing 9-5/ 'Weatherford Gemoco Stage Collar @ 1,800' (be aware when tripping in&out) 100 bbls diesel freeze protect swapped on top of KWF. Existing Surface Casino: 9-518"40#L-80 BTC 3,460'MD 1 2.299'TVD 62' IICut 4.5"Tubing @-3,900'MD for Rig to POOH Tubing: Well loaded from top of cement plug with 150 bbd, 4-%''12.6#L-80 NSTC :: corrosion inhibited-12.2 ppg KWF _.. .----4.5"Tubing Punches @ 200'aboveTOC IP Original TOC 15.8 ppg 1ff+l-8,000'MD — Baker CMU Sliding Sleeve(Closed)8699'MD 1111 (ID=3.810') Cameo KBG-2-LS 1"GLV wI BIM latch 8710' °".J MD Cameo DB Nipple 8753'MD !r] Baker 80.47 Seal Assembly 8780'MO , 9 !ivd T3 5; i D1RQ "„" .i: k , r; :41,. i , 0 4, ,! rt D .. ,,,,; ,-„:, , -;'., - :: siRa 8d 9�17D fA : Cs ; i� ! rr . a , � . . .. . . si 5140`TV1) 10.7 Bermuda Pore Pressure(7/29/11):2,859 p :ppg........ ........... ............. 1 ► gxdstina 7”x 4-1/2"Monobore Completion: 7"26#L-80 BTCM 4.5" 12.6#L-80 NSCT 9,530'MD 15,397'TVD • • Proposed Rig Abandonment Program Nabors 9ES 2N-323 Rig Abandonment Procedure The proposed scope of work for the forthcoming sundry application includes: 1. MIRU Nabors 9ES onto 2N-323. 2. Test 7"casing, 7"casing pack off and BPV through inner annulus to 2,000 psi for 10 minutes, chart PT. 3. Test tree adaptor to 5,000 psi. 4. Pull BPV. 5. Circulate diesel freeze protect out through the tubing cut at-3,900' MD, swapping over to 11 ppg kill weight mud through tree,taking returns to tiger tank. 6. Set BPV and test through inner annulus to 2,000 psi. 7. Set blanking plug. 8. Nipple down tree. 9. Notify AOGCC field inspector 24 hours prior to BOPE test. 10. Nipple up BOPE and test to 250/3500 psi with 4.5"test joint. 11. Remove blanking plug and BPV. 12. Pull & lay down 4-1/2"tubing (pre-cut at-3,900 MD). 13. Run 7"casing scraper to-3,800' MD 14. Run 7" Baker CIBP on 4" DP and set at-3,700' MD. PT to 2,500 psi 15. Pressure test lower rams with 3.5"(cement stinger) and 4" (drillpipe)test joints. 16. Run in hole with mechanical casing cutter on 4"drillpipe and cut casing at 3,650' &3,300' MD. 17. Flush 7"x 9-5/8"annulus with 9.8 ppg kill weight brine taking returns to tiger tank. 18. Swap 3.5"x 6" rams to 7"casing rams and pressure test to 250/3500 psi. 19. Pull 7"casing to surface and lay down. RIH with jars and retrieve casing stub at bottom. 20. Swap 7"casing rams to 3.5"x 6" rams and pressure test. 21. RIH with 3.5"cement stinger and set cement kick off plug from the top of bridge plug to 200 ft inside the surface shoe. 22. P/U directional drilling BHA and RIH. Tag TOC and pressure test surface casing and kick off plug to 2,500 psi. 23. Displace 9.8 ppg brine to 10.3 ppg LSND mud system 24. Dress off cement kickoff plug and control drill to below surface casing shoe. 25. Drill out 20' of new formation and perform FIT/LOT. 26. Ready to move into drilling phase under new PTD. 27. Begin new PTD. Begin two-week BOPE testing cycle. • • 2N-323 Nabors 9ES Rig Abandonment Schematic Tarn 2N-323 Rig Abandonment ConocoPhillips FMC Gen V Bearden 08l19?13 16"Existin• Cemented C•n• t• 16"62.6#H-40 108'MD Existing 9-58'Weatherford Gemoco Stage Collar @ 1,800' (be aware when tripping in&out) �— 17.0 ppg cement plug TOC©3,260'MD gxlsting.Surface Casing: 7"Casing Cut#2 @—3,300' MD 9-518"40#1-80 BTC 17.0 ppg 3,460'MD/2.299'TVD @ 62° Cement Kickoff Plug 7"Casing Cut#1 @—3,650'MD - CIBP @—3,700'MD • Cut 4.5"Tubing @—3,900'MD • 11 ppg KCl f4aCi kitty, Tubing: 4-W 12,6#L-80 NSTC '4 —100 bbis diesel freeze protect swapped on top of KWf. 110, a Well loaded from top of cemr°nt plug with 150 bbis corrosion Inhibited-12.2 ppg KWI 4.s"Tubing Punches is TOC Original TOC 15.8 ppg @+1-8.000'MD Baker CMU Sliding Sleeve(Closed)8699'MD (1D=3.810") Cameo KBG-2-LS 1"GLV w!BTM latch 8710' MD Cameo DB Nipple 8753'MD(10=3.75") _ Baker 80.47 Seal Assembly 8760'MO 1, d6tmvdaB�Si 309170 A1D _.dam .. . .. Bermuda Pore Pressure 7/29(11 :2 859 psi 5,140`TVD 10.7 p ( ) P ppg Existing 7"x 4-Y2"Monobore Comotetion: 7"26#L-80 BTCM 4.5"12.6#L-80 NSCT 9,530'MD/5,397'TVD • • 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. ., .� ,,r. T-__.__----- _..\1•77 7 TAT'TUTTT DT T ICI «D i TIT)T fl 1411111') Or Ti �w�� \ \I % %i�s� THE STATE Alaska Oil Gas of Commission Conservation GOVERNOR SEAN PARNELL. 333 West Seventh Avenue wk OFALAS1P Anchorage, Alaska 99501 -3572 �� l Main: 907.279.1433 SUN 2 1 Fax: 907.276.7542 Martin Walters Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. P.O. Box 100360 O q Anchorage, AK 99510 Re: Kuparuk River Field, Tarn Oil Pool, 2N -323 Sundry Number: 313 -309 Dear Mr. Walters: 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, / Cathy P. F erster Chair DATED thi of June, 2013. Encl. STATE OF ALASKA 07" 6 APVIp AL/RA OIL AND GAS CONSERVATION COM SION , .\ ? L ': I r> 2 013 APPLICATION FOR SUNDRY APPROVALS O' 20 AAC 25.280 /-\( )t,,--a C 1. Type of Request: Abandon r Rug for Redrill r Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Rug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdown r Re -enter Susp. Well r Stimulate r Alter casing r Other: Conductor Extension l 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development r 4 Exploratory r 198 -071 3. Address: , Stratigraphic r Service 6. API Number , P. O. Box 100360, Anchorage, Alaska 99510 50- 103 - 20258 -00, 7. If perforating, What 8. Well Name and Number: Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require spacing exception? Yes r No r 2N - 323 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0380054 • Kuparuk River Field / Tarn Oil Pool - It PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): - 9553 - 5412 Casing Length Size MD ND Burst Collapse CONDUCTOR 76 16 108' 108' 1640 630 SURFACE 3428 9 -5/8 3461' 2299' 5750 3090 PRODUCTION 9502 7 9530' 5397' 7240 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9060 -9080, 9130 -9170 • 5081 -5094, 5129 -5155 4.5 L -80 8760 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) SEAL ASSY - BAKER 80 -47 CASING SEAL ASSEMBLY • MD= 8760 TVD= 4877 CAMCO DV NIPPLE • MD = 560 TVD = 558 12. Attachments: Description Summary of Proposal r 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Stratigraphic r Development r • Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 7/1/2013 Oil r• Gas r WDSPL r Suspended r 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Martin Walters / MJ Loveland Email: N1878(a cop.com Printed Name Martin Walters Title: Well Integrity Projects Supervisor Signature ,'A'1- Phone: 659 -7043 Date: 06/16/13 Commission Use Only Sundry Number: 3 3 3c Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test r Mechanical Integrity Test r Location Clearance r w 3 :\ Other: RBDMS JUN 2 6 2(M Spacing Exception Required? Yes ❑ No Subsequent Form Required: /L _ A g 7 APPROVED BY -2/— �� Approved by: P 27,-(-, MISSION TH eVISSION Date: L. � Ja i�ativii IS Jaliil l ar � 2 I'I10AtIT5�i�i tlic�at2 OI aNNfOVa Form 10 -403 (Revi d 10/2012) / � ORIGINAL Submit Form and Attachments in Duplicate 10-1"),e ...eaff-fti..5 H IV I lt. v i.' ConocoPh A{ C. Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 June 16, 2013 Commissioner Dan Seamount Alaska Oil and Gas Conservation Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Commissioner Seamount: Enclosed please find the 10 -403 Application for Sundry Approvals for ConocoPhillips Alaska, Inc. well 2N -323, PTD 198 -071 conductor extension. Please contact Martin Walters or MJ Loveland at 659 -7043 if you have any questions. Sincerely, //i.,. Martin Walters ConocoPhillips Well Integrity Projects Supervisor • • Conoco Phillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 ConocoPhillips Alaska, Inc. Kuparuk Well 2N -323 (PTD 198 -071) SUNDRY NOTICE 10 -403 APPROVAL REQUEST June 16, 2013 This application for Sundry approval for Kuparuk well 2N -323 is to extend the conductor to original height so as to stabilize tree and prevent any corrosion to SC. At some point during normal operations the conductor subsided about 12 ". With approval, the conductor extension will require the following general steps: 1. Remove landing ring from conductor if necessary. 2. Examine surface casing for any corrosion damage. 3. Extend the conductor to starter head and fill the void with cement and top off with sealant. 4. File 10 -404 with the AOGCC post repair. NSK Well Integrity Projects Supervisor KUP _ 2N -323 Conoco Phillips '. -4 I Well Attributes Max Angle & MD TD Inc Wellbore API/UWI Field Name Well Status Inc' ( °) MD (RKB) Act Btm (ftK8) Aiaska, `II �«ncoPran,ps 501032025800 TARN PARTICIPATING AREA PROD 63,37 2,934.51 9,553.0 Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) ' Rig Release Date -- Well Conk; - - 29-323 1/24/2012 1:39.26 PM SSSV: NIPPLE 60 10212007 Last WO: 35.09 4/24/1998 , .Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: RKB 9,173.0 7/25/2011 Rev Reason: WELL REVIEW osborl 1/24/2012 Casing Strings e1 Casing Description String 0... String ID ... Top (kKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd : HANGER,24 ,, CONDUCTOR 16 15.062 32.5 108.0 108.0 WELDED AK Casing Description String 0... String ID ... Top (ftKB) Set Depth (t.-. Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.835 32.5 3,460.7 2,298.8 40.00 L - 80 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (L-. Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 27.5 9,529.8 5,397.0 26.00 L -80 BTC -MOD 7"x4 5" @ 8760' Tubing Strings Tubing Description String 0 String ID ... Top (1166) Set Depth (L..ISet Depth (TVD) . String Wt.. String ... String Top Thrd TUBING 41/2 3.958 24.0 1 8,760.8 I 4,877.6 12.60 L-80 NSTC Completion Details Top Depth -- - - - - -- --- (TVD) Top Incl Nomi... anit Top (RKB) (R(B) (°) Item Description Comment ID (In) I 24.0 24.0 -0.46 HANGER FMC GEN V 5M TUBING HANGER 4.500 CONDUCTOR, 559.9 558.1 10.89 NIPPLE CAMCO D8 NIPPLE 3.875 33 8,699.4 4,837.5 50.03 SLEEVE -C BAKER CMU SLIDING SLEEVE w/ 3.812 CAMCO DB PROFILE 3.810 8,752.5 4,872.2 48.74 NIPPLE CAMCO DB NIPPLE NO GO 3.750 8,759.8 4,877.0 48.56 SEAL ASSY BAKER 80 -47 CASING SEAL ASSEMBLY 3.875 NIPPLE, 560 Perforations & Slots IF - Shot Top (ND) Btm (TVD) Dens T op (ftKB) Btm (RKB) (RKB) (ftKB) Zone Date (eb••• Type Comment 9,060.0 9,080.0 5,081.3 5,094.9 TARN T3, 10222008 6.0 APERF 2 7/8" PJ, 60 DEG PHASE 2N -323 9,130.0 9,170.0 5,128.9 5,155.6 S -5, 2N -323 6/20/1998 4,0 IPERF 2.5" HC, BH, 180 deg ph Stimulations & Treatments Bottom Min Top M. Btm Top Depth Depth Depth Depth (TVD) (TVD) (ftKB) (ftKB) (RKB) (ftKB) Type Date Comment 9,060.0 9,080.0 5,081.3 5,094.9 FRAC 10/24/2008 TARN T3 FRAC wYF125ST GEL, 2306608 16/20 CARBOLITE; 240# LEFT IN WB, 11 PPA ON FORMATION 3496 BBL OF SW Notes: General & Safety End Date Annotation 11/22.2010 NOTE: View Schematic w/ Alaska Schematic9.0 ■ SURFACE, 33 -3,461 SLEEVE -C, 8,699 1 GAS LIFT. 8.710 NIPPLE, 8,753 -1 _ SEALASSY, 8,760 / \ APERF, _ Mandrel Details 9.060 -9,08 FRAC 9 , 06 0 I Top Depth Top Port (TVD) Inc! OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) (°) Make Model (In) Sery Type Type (!n) (pal) Run Date Com... 1 8,709.8 4,844.2 49.77 CAMCO KGB -2 -LS 1 GAS LIFT OV BTM 0250 0.0 12/5/2009 IPERF, 9,130.9170 PRODUCTION Tx4.5" 8760', 27 -9,530 j , TD, 9553 • Page 1 of 1 Regg, James B (DOA) ~ ~ ~~ ~~~ ~ From: NSK Problem Well Supv [n1617@conocophillips.com] Sent: Friday, November 20, 2009 10:02 AM ~~ f l~ ~ ~l e` f To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA) Cc: NSK Problem Well Supv Subject: 2N-323 (PTD 198-071) Report of failed TIFL Attachments: 2N-323 schematic.pdf Tom, Jim, Guy Kuparuk gas lifted producer 2N-323 (PTD 198-071) failed a diagnostic TIFL on 11/19/09. The well was shut in , prior to the test. The TIO prior to the test was 1890/1700%590. A leakin- g Z~LV is suspected. Slick line will trou es oo the leak and repair if possible. Attached is a schematic and a 90 day TIO plot. Please let me know if you have any questions. Brent Rogers/Martin Walters Problem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 ~,, 11/27/2009 KRU 2N-323 PTD 1980710 11 /20/2009 TIO Pressures soD. 3D00. 2D0. 3000. 3000.. .. ~~^, , 3000. 0. 0. 0. 0. De ?f„ 0. MINOR TIME MAJOR TIME WEEK PICK TIHE:IS-N OV-09`16:09:22 TI~G N~HE DESCRIPTION ~ '~,` ! +"~ ~ s-'PEST ZY-2N92D2-323 FLOW TUBING CHOKE 77????? SCRATCH 7 FLOW TUBING PRESSURE 7?????? SCRATCH_7 FLOW TUBING TEMP ??????? PI-2N5306-323 GL CASING PRESSURE ??????? ??????? ??????? SCRATCH_7 INNER ANNULUS PRES ??????? ~' SCRATCH_7 OUTER ANNULUS PRES ??????7 ~;~ , +02160:00:00 7tNS15-NOV-09 16:09 DRILLSITE WELL PREV WELL 2n 323 NEXT WELL ENTRY T`r'!?F. OPERATOR OPERATOR VERIFIED :;YSTEM AUTO ENTRY ~ BOTH • WELL NAM WLKRU2N-323 n--~ KU P __ rrt~ F~{'~ ~OtiO~~~~'"! ~ II r Well Attributes _ _ W Ilb eAPIIUWI Field Name Well Status 01032025800 (TARN PARTICIPATING AREA ~PROD C ent H2S (ppm) Date Ann lotion End [ - '. -- SSSV: NIPPLE 60 10/21/2007 Last W0: __ Deli co_ rs - s Am rrarw ntual -_ A tat on __- Depth (ftK8) End Date Annotation Last TaO- SLM 9,187.0 8/12/2009 Rev Reason: GLV C/O ('acinn Sfrinnc CONDUCTOR. 108 NIPPLE. SURFACE. GAS LIFT, 8,710 NIPPLE, 8,753 c+ i' PRODUCTION, _, _ 8,760 ~ ."„~ - ' I XO, 8,760 ~~. SEAL ASSV, ~ I ' 8,760 1 = ir- __ l APERF, ~ 9,060-9,090 4 - FRAC, 9,060 a ~ ~ i t IPERF, ' 9,130-9,170 SHOE, 9,528 PRODUCTION, 9,530 TD. 9.553 Tubin Strin_ s g St g OD i 5 1nng ID T Set Depth Set Depth (TV D) String Wt '. Stri Tubing De piton (^) i (I~) ', Top (RKB) (h KB) It2KB) (Ibs/h) Gra TUBING 41/2 3.958' I 0.0 8,760.0 __._. 4,877.1 _. , 12.60 L-80 ~. ____ __-. _._..__ Other In Hole (All Jewelry: ~ .._ Tubin Run_& Retrievable, Fish, etc.) -_ -_ _ - -_ Top ~epth (ND) Top Incl Too (RKBI (ttKB) (°) Descriotion Comment x 2N-323 _ lax Angle & MD _ TD_ cl (°) MD (ttKB) Act 8tl (ftK8) 63.37 2,934.51 9553.0 KBGId (tt) Rig R I ase Date 35.09 4/24/1998 Last Mod By End Data Imosbor 7/10/2009 Casing Description Si 'uig OD lin) String ID (in) Top (ftK8) Set Depth (RKB) Set Deptli (ND) (ftK8) String Wt (Ibs/R) String Orade String Top Thrd CONDUCTOR 16 15.062 0.0 108.0 108.0 WELDED SURFACE 9 5/8 8.697 0.0 3,460.0 2,298.5 40.00 L-80 BTC PRODUCTION 7 6.059 0.0 8,760.0 4,877.1 26.00 L-80 BTC MOD PRODUCTION 41/2 3.958 8.760.0 9,530.0 5,3972 12.60 L-80 NSCT Thrtl Top (ND) Btm (ND) Dons Top (ftK8) Btm (RKB) (RKB) (RKB) Zone Date iah... Type Comment 9,060 9,080 5,081.3 5,094.9 TARN T3, 10/22/2008 6.0 APERF 2 7/8" PJ, 60 DEG PHASE 2N-323 Stimulations 8 Treatments Bottom Min Top Mez etm lop Depth Depth Dopth Depth (ND) (ND) (RKB) (ftK8) (ttKB) (RKB) Type Date Comment 9,060.0 9,080.0 5,081.3 5,094.9 FRAC 10/24/2008 TARN T3 FRAC wYF125ST GEL, 230660# 1 CARBOLIE; 240# LEFT IN WB, 11 PPA ON FORMATION 3496 BBL OF SW. +L 1' 5Z5~~~~ - 1'G-C~(sp~; r 4G4~'~ ~, 2N-323 (PTD 198-071) Report of~ed TIFL • Page 1 of 1 Regg, James B (DOA) From: NSK Problem Well Supv [n1617@conocophillips.com] ~~?~~q I ~~ Sent: Sunday, July 05, 2009 4:17 PM ~ To: Maunder, Thomas E(DOA); Regg, James B(DOA) Cc: Schwartz, Guy L(DOA); NSK Problem Well Supv Subject: 2N-323 (PTD 198-071) Report of failed TIFL Attachments: 2N-323 schematic.pdf; 2N-323 90 day TIO plot.jpg Tom, Jim / Kuparuk gas lifted producer 2N-323 (PTD198-071) failed a diagnostic TIFL on 07/04/09. The well was shut in at the time of the test. The TIO prior to the test was 1620 75 480. A leaking GLV is suspected. Slickiine wiT-' troubleshoot the GLV's and repair if possible. ~ Attached is a schematic and 90 day TIO plot. '/ Please let me know if you have any questions. Brent Rogers/Martin Walters Probiem Wells Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7224 Pager (907) 659-7000 pgr. 909 «2N-323 schematic.pdf» «2N-323 90 day TIO plot.jpg» `° ..+'_t',<k>'k'~~si.~ `"(t'.' ~ _ ~'~lf'~. J 7/24/2009 KRU 2N-323 PTD 198-071 7/5/2009 TIO Pressures T/UO Plot - 2N-323 1500 N 1000 a 500 ............................................................. . ...................... _ _ ,.., ~ - --,, , ~ i~ ' ( -._. 1 il II~~ i~ I I I I~~i.' - - t1 JI II I i, ................ ....'a:.:^.::~:.'........'y.............................. .,r~..........1. ....~~,: .j''. ...,..:'5...................... .~.... .~i ..... 0 ~++++ 05-Apr-09 18-Apr-09 01-May-09 14-May-09 27-May-09 Date 09-Jun-09 22-Jun-09 200 150 a E a~ 100 ~ Y O t V 50 0 ~ ~ 7 ~' I % ~~ i~~ 01 /08/09 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 :_~.'~,;,~-~ wY'~~...~_. ~J~~~: ~r ,~ ATTN: Beth Wel I Job # Log Description NO. 5035 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD • i Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. n ~; F, .. • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION *, j REPORT OF SUNDRY WELL OPERATI(,~5 ,~..: , _. 1. Operations Pertormed: Abandon ^ Repair Well ^ Plug Pertorations ^ Stimulate Q Other ^ Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extension Change Approved Program ^ Operat. Shutdown^ Perforate Q • Re-enter Suspended Well ^ 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConOCOPhllllps Alaska, InC. Development ^~ Exploratory ^ 198-071 ! ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50-103-20258-00. 7. KB Elevation (ft): 9. Well Name and Number: RKB 28', Pad 121' 2N-323 ' 8. Property Designation: 10. Field/Pool(s): ADL 380054 Kuparuk River Field / Tarn Oil Pool - 11. Present Well Condition Summary: Total Depth measured 9553' ~ feet true vertical 5412' feet Plugs (measured) Effective Depth measured 9437' feet Junk (measured) true vertical 5336' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 108' 16" 108' 108' SURFACE 3432' 9-5/8" 3460' 2299' PRODUCTION 8732' 7" 8760' 487' PRODUCTION 770' 4-1/2" 9530' 5397' Perforation depth: Measured depth: 9060'-9080', 9130'-9170' true vertical depth: 5081'-5095', 5129'-5156' r%rr'~L~4>9~1~1 ~1~~~~' ~ ~ ~vUt,, Tubing (size, grade, and measured depth) 4.5", L-80, 8760' MD. Packers & SSSV (type & measured depth) no packer Camco'DS' nipple @ 560' 12. Stimulation or cement squeeze summary: Intervals treated (measured) 9060'-9080' 230660# 16/20 carbolite, 240 # left in wellbore, Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation 433 2272 841 -- 246 Subsequent to operation 293 681 983 -- 515 14. Attachments 15. Well Class after work: Copies of Logs and Surveys run _ Exploratory ^ Development ^~ Service ^ Daily Report of Well Operations _X 16. Well Status after work: Oil Gas^ WAG^ GINJ^ WINJ ^ WDSPL^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or Nia, if C.O. Exempt: none Contact John Peirce @ 265-6471 Printed Name John Peirce Title Wells Group Engineer Signature ~ _ Phone: 265-6471 1~~ 1A , g Date 1. Pre a b h n Allsu -Drake 263-4612 Form 10-404 Revised 04/2006 Submit Original Only I t y ~. s `~ i '~ S ~ ~ ~ ~ .,-tom r~/~/' 2N-323 Well Work Summary DATE SUMMARY 10/17/08 GAUGED TBG TO 3.80" TO ~IPPLE @ 8740' WL, 8763' RKB. TAGG BOTTOM WITH 3 NT (p~ EST 9172' RKB SET 3.75" DB PLUG AND PRONG @ 8763' RKB. PULLED OV @ 8710' RKB. READY LOAD WELL. 10/19/08 LOADED TBG AND to WITH DSL. SET DV @ 8710' RKB. MITT & IA 3500 PSI. GOOD. _PULLED PRONG AND PLUG BODY 8753' RKB. READY TO PUMP SAND PLUG. 10/20/08 PERFORM SAND PLUG, RIH WITH 3.79 SWEDGE, TAGGED DB NIPPLE @ 8753, CORRECTED DEPTH. 2ND RUN TAGGED FILL @ 9202 RKB, PUMPED 850 POUNDS SAND, WAIT 1-HOUR, TAGGED SAND TOP @ 9107 RKB, FREEZE PROTECTED WELL, TURNED OVER TO S/L. 10/21/08 TAG SAND TOP @ 9114' RKB. DUMP BAIL SLUGGETS TO 9111' RKB. DRIFTED TO W/20' X 2.80" DMY GUN TO TD W/ NO PROBLEMS. WELL READY FOR E- LINE PERF. 10/22/08 PRE FRAC PERFORATIONS. INTERVAL 9060 - 9080 WITH 2 7/8" POWERJET 0.36" DIAMETER 27.7 IN PENETRATION, 60 DEG PHASING, 6 SHOTS PER FOOT. TAGGED STICKY BOTTOM AT 9110 FT. 10/24/08 Frac pumped to completion Tarn T3 layer, with YF125ST gel and total of 230660# of 16/20 Carbolite 240# left in WB with 11 PPA on formation 3496 BBL of SW. An average pressure of 2540 psi. ISIP= 1370 psi, 10 min pressure = 1238 psi. (EST BHP=2050 psi) flushed with 138 bbls including 39 bbls diesel FREEZE PROTECTION, Problems with FracCat computers during job. 10/25/08 PREFORMED POST FRAC FCO. TAGGED SAND AT 9064' CTMD WASHED DOWN TO 9387' CTMD USING SLICK DIESEL AND DIESEL GEL, HAD BETTER THAN ONE FOR ONE RETURNS, LEFT WELL SHUT IN AND FREEZE PROTECTED WITH 40 BBL SLICK DIESEL. EST. 240' RAT HOLE. READY FOR SLICK LINE 10/26/08 ATTEMPTED TO TAG FILL, HUNG UP @ 8713' WLM. IN PROGRESS 10/27/08 TAGGED FILL @ 9010' WLM. SET CATCHER @ 8753' RKB. ATTEMPT TO PULL DV @ 8710' RKB, IN PROGRESS. 10/28/08 ATTEMP TO PULL DV @ 8710' RKB, NO SUCCESS. IN PROGRESS. 10/29/08 UNABLE TO PULL 1" DMY VLV @ 8710' RKB. TOOLS UNABLE TO FUNCTION DUE TO SAND. ALSO SUSPECT VALVE HAD SAND PACKED ON TOP OF LATCH. BAILED FORMATION SAND FROM 8736' TO 8740' SLM. PULLED CATCHER SUB @ 8741' SLM. JOB SUSPENDED. 10/31/08 PERFORM FCO FROM 8600' CTMD TO 8800' CTMD USING SLICK-DIESEL AND DIESEL GEL.WASH ACROSS GLM AND JETTED TUBING WHILE HOLDING 1 FOR 1 ON RETURNS. WELL SHUT AND READY FOR SLICKLINE. 11/01/08 DRIFT TBG TO 3.70" TO 8900' SLM. ATTEMPT TO PULL DMY @ 8710' RKB. TOOLS FOULED DUE TO SAND. IN PROGRESS. 11/02/08 PULLED DMY _ 8710' RKB. REPLACED WITH 1/4" ORIFICE (BTM LATCH). GOOD TEST ON VALVE. JOB COMPLETE. 11/05/08 POST-FRAC FLOW BACK ATTEMPTED, S/L REQUESTED TROUBLESHOOT POSSIBLE ICE OR PLUGGED OV: TAGGED FILL @ 8984' SLM (PERFs 9060- 9170). UNABLE TO PUMP INTO WELL. BLED TBG DOWN, IA DROPPED, OV NOT PLUGGED. OPENED L/G TO IA, TBG PRESS RISING. COMPLETE. ., , Conocc>Phiilips SSSV~NIPPLE I 60 i 7/1/2008 (Last WO' 35.09 ~' 4124/1998 ) Annotation ~ De h ftKB End Date 1 _ Annotation End Date I Last Tag: SLM 9,010 0 1 10/272008 (Rev Reason: PERF, FRAC, POST FCO TAG ~ 10/31/2008 Casing Strings _ _ String OD Str ng ID Sat Depth Set Depth (ND) String Wt ' Stnng ~ Casing Description I (inl (~nl (ftKB) (IbsHt) Grade__ String TOp Thrd Top (kKB) I (ftKB) CONDUCTOR 16 15.062 0.0 708.0 108.0' WELDED '. (SURFACE 95/8 8.697 0.0 3,460.0 2,298.5 40.00'L-80 BTC !PRODUCTION 7 6.059 ~' 0.0 8,760.0' 4,877.1 26.00 L-80 BTC MOD 'PRODUCTION 4 1/2 3.9581 8,760.0 9,530.0 5,397.2 12.60 L-80 NSCT ~. _._ __ ,Tubing Strings. __ String OD String ID __ _ ___ Set Depth Set Depth (TVD) String yvl String Tubing Description (in1 (in) ftKB) (ftKB) (kKB) (Ibskt) Grada String Top Thrd To p ( _ __ _ TUBING 41/2 3.5581 0.0 8,760.0 4,877.1 12.60 L-80 NSTC Other In Hole Ali Jewel : Tubi n Run $ Retrievable, Fish, etc. Top Depth'. (ND) Top Top (ftKB) (kKB) ', Inc! (°) Description Comment Run Dale ID (in) 560.0 558.2 10.89 NIPPLE 'Camco'DB' Nipple for SCSSV 4S" EUE 8rd Box 4/24/1998 3.875 8,699.0 I 4,837.2 50.04 SLEEVE-C Baker Sliding Sleeve CMU w/3.812 Camco'DB' profile 70/192008 3.810 8,710.0 4,844.3 49.77 GAS LIFT CAMCO/KGB-2-LS/1/DMY/BTM///Comment: STA1 70/19!2008 3.650 8,753.0 4,872.5 48.73 NIPPLE Camco 3.75" DB Nipple 4/24/7998 3.750 8.760.0 4 877.7 48.56 XO ,PROD CSG XO 7 x 4.5 423/1998 4.500 8,760 0 4.877.1 ~'~ 48.56 SEAL ASSY ~ Baker 7" Casing Seal Assembly size 80-07 424/1998 3.875 9,528.0 5,395.8 48.63'~ SHOE 'FLOAT SHOE 4/24/1998 3.875 ' Perforations -- -_ ---- -- Shot Top(ND) etm (fVD) Dens Top (ftKB) Bhn (kKB) (ftKB) (kKB) Zone Date (sh°~ Type Comment 9,060.0.. 9,080.0 5,081.3 5,094.9 TARN T3, 10/22/2008 6.0 APERF 2 7/8" PJ, 60 DEG PHASE 2N-323 9.130.0 ~ 9,170.0 5,128.9 !Stimulations $ Treatme 5,155.6 nts 6/20/1998 4.0 (PERF 2.5" HC. BH, 180 tleg ph €- ' Min Top Max Bim .Top Depth ~~. Bonom Depth ~i : '', Depth Depth ~ (ND) ' (ND) 'i '. (ftKB) (kKB) (ftKB) (kKB) Type Date Comment 9,060.0 9,080.0 5,081.3 5,094.9 FRAC 70/24/2008 TARN T3 FRAC wYF125ST GEL, 2 306 6011 1 6/2 0 CARBOLIE; 240# LEF T IN WB, 77 PPA ON FORMATION 3496 BBL OF SW. r; i ~„ _ _- o , -,-~' ~1~~~~~~ Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ,,,, ~r,. ~~`.~3~1~~~ .1llL ~ 2008 Log Description NO. 4775 Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Kuparuk Date BL Color CD 07/10/08 2W-04 12061711 INJECTION PROFILE ja 06/24/08 1 1 1L-20A 10215099 PRODUCTION PROFILE ~QU '~ 06/26/08 1 1 1 G-05 12080389 LDL ~p 06/27/08 1 1 3B-10 12061714 INJECTION PROFILE °I' - ~ / °- 06/27/08 1 1 2L-327 12061715 SBHP SURVEY U 06/28/08 1 1 1J-109 12080390 SBHP SURVEY / ( 06/28/08 1 1 2N-323 12061716 SBHP SURVEY 'fir m- ~ 06/28/08 1 1 2X-15 12080392 SBHP SURVEY C 06/29/08 1 1 2N-303 12061717 SBHP SURVEY 06/29/08 1 1 2L-309 12061718 SBHP SURVEY ` 06/29/08 1 1 2X-14 12080391 SBHP SURVEY / 06/29/08 1 1 2X-11 12080393 SBHP SURVEY c( j 06/29/08 1 1 iG-09 12080401 INJECTION PROFILE V ~- J /(~ ~ 07/05/08 1 - - 1 2H-05 12080396 SBHP SURVEY L"~.~- 06/30!08 1 1 2H-12 12080395 SBHP SURVEY a~ 06/30/08 1 1 2H-11 12080394 SBHP SURVEY / 06/30/08 1 1 1D-07 12080398 SBHP SURVEY - ,( 07/02!08 1 1 2N-341 12061720 SBHP SURVEY p 06/30/08 1 1 3C-15 11982441 USIT - (~ / (p 07/04/08 1 1 2W-10 11982445 INJECTION PROFILE `6 - (p 07/08/08 1 1 1 L-19 12061724 PRODUCTION PROFILE J D -6 07/10/08 1 1 2W-02 11982446 INJECTION PROFILE - ,g 07/09/08 1 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. r~'~~ ~ .! • • . . Conoc;¡;"illips Alaska REe!.\VED SEP 1 2 2007 . ion ~'8sk8 on & Gas Cons. Comrmss Anchor898 P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 September 07, 2007 Mr. Tom Maunder Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 SCANNED SEP 1 2 Z007 O\~/o'1l '\ \.1." 'biÞ ~\~ Dear Mr. Maunder: Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with a 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 on September 5,2007. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call M.J. Loveland at 907-659-7043, if you have any questions. Sincerely, \7~/- ~ ¿Arend ConocoPhillips Well Integrity Field Supervisor . . ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 9/7/2007 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitorl Well Name PTD# cement pumped cement date inhibitor sealant date ft bbls ft gal 2N-320 199-001 4" n/a 4" n/a 2 9/5/2007 2N-321 198-173 6" n/a 6" n/a 2 9/5/2007 2N-323 198-071 1" n/a 1" n/a 1 9/5/2007 2N-325 198-163 10" n/a 10" n/a 2 9/5/2007 2N-326 200-155 9" n/a 9" n/a 3.5 9/5/2007 2N-337 206-163 6" n/a 6" n/a 1 9/5/2007 2N-339 198-100 8" n/a 8" n/a 2.5 9/5/2007 2N-341 198-103 3" n/a 3" n/a 1 9/5/2007 2N-342 207-068 18" n/a 18" n/a 4.5 9/5/2007 2N-343 198-092 4" n/a 4" n/a 2 9/5/2007 2N-345 204-034 9" n/a 9" n/a 3.5 9/5/2007 '.'......-.~ Schlumbel'gel' lL1r-o~( ¡I.MNED JUN 2 1 7Jjfj7 6C,.~n 06/14/07 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth NO. 4300 0J (\ 'HI "1 !;, 'þ lJ U. Com¡1åny: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 p~ Field: Kuparuk Well Log Description Color CD Job# Date BL 2M-16 11629024 SBHP SURVEY 06/06/07 1 2N-306 11629025 SBHP SURVEY 06/06/07 1 2H-07 11638870 PRODUCTION PROFILE 06/07/07 1 2N-323 11629027 SBHP SURVEY 06/08/07 1 2N-313 11629027 SBHP SURVEY 06/08/07 1 2M-29 11638871 SBHP SURVEY 06/08/07 1 1C-104 11638872 LDL 06/08/07 1 1 G-08A 11629026 PRODUCTION PROFILE 06/09/07 1 2N-308 11638874 SBHP SURVEY 06/09/07 1 2M-10 11629031 SBHP SURVEY 06/10/07 1 1A-27 11638876 PRODUCTION PROFILE 06/10/07 1 2M-12 11629030 SBHP SURVEY 06/10/07 1 2L-311 11638881 SBHP SURVEY 06/11/07 1 2N-317 11638878 SBHP SURVEY 06/11/07 1 2B-08 11629032 INJECTION PROFILE 06/11/07 1 1 H-08 11638882 INJECTION PROFILE 06/12/07 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation CommiSsion TO: THRU' Dan Seamount, ¢,~/--E~/o Commissioner Blair Wondzell, ~ P. I. Supervisor ~,~(o'~ FROM' John Crisp,~//,/u~ C,, SUBJECT: Petroleum I~pector DATE: July 20, 2000 Safety Valve Tests Kuparuk River Unit Tarn Field 2N & 2L Pads July 20, 2000: I traveled to Phillips Alaska's Kuparuk River Unit Tarn Field to witness the semi-annual Safety Valve System tests on Pads 2N & 2L. Testing went well with only one failure on 2L Pad witnessed. No failures were witnessed on 2N Pad. The AOGCC test report is attached for reference. SUMMARY: I witnessed the semi'annual SVS tests on KRU's Tarn Pads 2N & 2L. 2N Pad, 9 wells, 18 components tested. No failures. 2L Pad, 6 wells, 12 components tested. 1 failure. 8% failure rate. Attachments: SVS Tarn KRU 2N & 2L 7-20-00jc CC;, NON-CONFIDENTIAL SVS Tarn KRU 2N & 2L 7-20-00jc.d°c Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Inc Operator Rep: Ernie Bamdt AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/pad: Tam, Kuparuk River, 2N Separator psi: LPS 94 HPS 7/20/00 Well Permit Separ Set L/P Test Test Test Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code GAS or 2N-307 1990170 2N-308 1990100 94 70 65 P P OIL 2N-309 1990210 2N-313 1980910 94 70 70 P P OIL 2N-315 1981900 2N-317 1981430 94 70 70 P P OIL 2N-319 1981970 2N-320 1990010 94 70 65 P P OIL 2N-321A 1981730 ~. 2~5 1980710 94 70 70 P e OIL 2N-325 1981630 2N-329 1980670 94 70' 70 P P OIL 2N-331 1981170 2N-335 1982040 94 70 70 P P OIL 2N-337A 1981220 2N-339 1981000 2N-341 1981030 94 70 65 P P OIL 2N-343 19809201 2N-345 1981130 2N-347 2000630 94 70 60 P P OIL Wells: 9 Components: 18 Failures: 0 Failure Rate: 0.0% E3 ~o ~av Remarks: 7/27/00 Page 1 of 1 SVS Tarn KRU 2N 7-20-00jc.xls Alaska Oil and Gas Conservation CommiSsion Safety Valve System Test Report Operator: Phillips Alaska Inc Operator Rep' Emie Bamdt AOGCC Rep' John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: Tarn, KuParuk River, 2L Separator psi: LPS 94 HPS 7/20/00 Well Permit Separ Set L~ Test Test Test Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code GASorC~C[~ 2L-305 1982400 94 70 60 P 4 ~ OIL 2L-307 1982560 94 70 70 P P O~ 2L-313 1982190 94 70 65 P P O~ 2L-315 1982180 94 70 70 P P O~ 2L-321 1982620 2L-323 1982510 2L-325 1982090 94 70 65 P P O~ 2L-329A 1982250 800 700 700 P P GAS Wells: 6 Components: 12 Failures: 1 Failure Rate: 8.0% [---] 90 Day Remarks: 7/27/00 Page 1 of 1 SVS Tam KRU 2L 7-20-00jC.xls Well Compliance Report File on Left side of folder · 198'07'1~0 KUPARUK'~ U ~'"'"2~323 5'0'Fi'03220258200 ............ ~0 _ MD 09553-' TVD05412 ~'oompletionDate: ~4/24/98 Completed Status: 1-OIL Current: T Name Interval Sent Received T/C/D D 8448 ~ SPERRY MPT/GR/EWR4/CNP/SLD OH L DGR/CNP/SLD-MD ~f~AL 3480-9553 ~ 7-~ ~ ~'~" OH L DGR/EWR4-MD ~/~AL 3480-9553 OH L DGR/EWR4-TVD b~Ag 3208-5412 OH L DSI ~AL 3460-9500 OH L STATPRES~EM ~AL 9150 ~l%O[q~ CH 5 R SRVY CALC ~0-9553. OH T 8387 ~~ SCHLUM DS~MS OH Daily Well Opr//ff~ -- ~/g h/~ Was the well cored? yes~.~_.. Comments: 6/10/98 6/10/98 7/!/~ 7~8/98 7/8/98 7~8/98 7/8/98 7/8/98 7/8/98 6/11/98 6/11/98 T 7/24/98 7/24/98 8/3/98 8/5/98 6/11/98 6/11/98 Are Dry Ditch Samples Required? yes (~___~And Recei~07~? ~ Analysis Description Receive~3--yes-mm~- Sa~- Monday, May 01, 2000 Page 1 of 1 Analysis of Horizontal Stress within 2N-323 Prediction of Annular Injection Disposal Zone Tarn Development Michael J. Faust ARCO Alaska, Inc. Dipole Sonic (DSI) and Bulk Density logs were used to calculate four elastic modulus curves for this well from 3350 ft. MD to 9500 ft. MD. The following equations were used to generate the modulus curves: Young's Modulus = E = Density * (Ve)2 Bulk Modulus = K = Density *(gp)2 Shear Modulus = G = Density * Vs2 Poisson's Ratio = P = (Vp)2- 2(Vs)2 2[(Vp)2- (Vs)2] Using these curves and standard elastic equations to estimate horizontal stress, two curves were generated to show the in-situ horizontal stress. Fracturing of the reservoir should occur first at the minimum horizontal stress. Two such curves are plotted, with Hor2 being the most reliable prediction given the available data. Also plotted for reference is a pore pressure gradient of 0.44 psi/ft and the overburden pressure gradient of 1.0 psi/ft. Based on this analysis from dynamic measurements of the elastic moduli, we believe that the most likely place for annular injected drilling fluids to go is the sandy interval from 3900 ft to 3918 ft MD. Assuming that we have a 3 ft net sand interval with 15% porosity, and an irreducible water saturation of 30%, we estimate that 35,000 BBL of fluid would displace a circular volume with a radius of 480' from the injection wellbore. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 27, 1999 Ms. Wendy Mahan ' Natural Resource Manager Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Kuparuk Area Annular Injection, Second Quarter, 1999 Dear Ms. Mahan: Please find reported below volumes injected into surface casing by production casing annuli during the second quarter of 1999, as well as total volumes injected into annuli for which injection authorization expired during the second quarter of 1999. Annular hzjection during the second quarter of1999: h(1) h(2) h(3) Total for Previous New Well Name Volume Volume Volume Quarter Total Total 1C-15 34380 100 0 32195 16795 48990 2L-313 3779 100 0 3879 I 8654 12533 CDI-19 33933 100 0 [' 34033[ 0 34033 1C-25 34216 100 0 t 34316 0 34316 CD1-40 12071 100 0 , 12171 t 0 12171 1C-23 ~ 9505 100 0 , 9605t~ 0 9605 Total Volumes into Annuli for which b~jection Authorization Expired during the quarter I i i , Total J Total h(1) Total h(2) · Total h(3) I Volume Well Name Volume Volume Volume Injected Status of Annulus 1D-10 35473 100 i 0 35573 Open, Freeze Protected 2N-323 32696 100 I 0 32796 Open, Freeze Protected 2N-343 17895 100 i 0 17995 Open, Freeze Protected i 2N-329 !~ 9 100 ~i 0 109 Open, Freeze Protected Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader Ms. Wendv Mahan AOGCC Second Quarter 1999 Annular Injection Report Page Two CC' Mike Zanghi Paul Mazzolini Randy Thomas Kuparuk Environmental: Engel / Snodgrass Momson and Winfree Sharon Allsup-Drake Well Files WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs August 12, 1998 2N-323, AK-~MM-80190 1 LDWG formatted Disc with verification listing. API#: 50-103-20258-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPY OF THE TRANSMITTAL LETTER TO THE ATrENTION OF: Sperry-Sun Drilling Service Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Division of Dresser Industries, Inc. ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 July 31, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2N-323 (Permit No. 98-71) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on Tam 2N-323. If there are any questions, please call 263-4603. Sincerely, P. Mazzolini Tarn Drilling Team Leader PM/skad AU¢ 5 1998 AJaska 0il & Gas Cons. Commission Anchorage ' " STATE OF ALASKA " ' ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL [~ GAS E~ SUSPENDED [] ABANDONED~ SERVICE [~] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 98-71 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-103-20258 4 Location of well at surface .: , ,~..m.....,~.~..~ ~ 9 Unit or Lease Name 68' FNL, 792' FEL, Sec. 03, TDN, RTE, UM Kuparuk River Unit At Top Producing Interval ~ .', i~: ~ 10 Well Number 2166' FNL, 1770' FEL, Sec. 33, T10N, RTE, UM ~ ~p}r:[?~ ~!. 2N-323 1927' FNL, 2091' FEL, Sec. 33, T10N, RTE, UM Kuparuk River Field 5 Elevation in feet (indicate KB, DF, etc.) I 6 Lease Designation and Sedal No. Tam Oil Pool RKB 28', Pad 121'I ADL 380054 ALK 4602 12 Date11 -Apr-98Spudded 13 21Date-Apr-98T'D' Reached 14 24-Apr-98Date Comp., Susp. or Aband. 15 WaterNADepth, if offshorefeet MSL 16 No.1 of Completions 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of permafrost 9553' MD & 5412' TVD 9437' MD & 5336' TVD YES xLz_] NO U NA feet MD 1050 APPROX 22 Type Electdc or Other Logs Run DipoleSonic/FMS, GR/Res 0 R i 23 CASING, LINER AND CEMENTING RECORD SE'II'lNG DEPTH MD CASING SIZE VVT GRADE TOP BTM HOLE SIZE CEMENT RECORD - 16" 62.58# H-40 SURF. 108' 24" 10 yds High Eddy 9.625" 40# L-80 SURF. 3460' 12.25" 690 sx Class G, 480 sx AS III 7' 26# L-80 SURF. 8760' 8.5' 420 sx Class G 4.5" 12.6# L-80 8760' 9530' 8.5" (included above) :24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 4.5' 8761' 8760' (CSR) 9130'-9170' MD 5129'-5156' TVD 4 spf 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9130'-9170' injected 174217# of prop into the formation w/9.9# ppa of #12/18 at the perfs 27 PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 7~8/98I Test Production Date of Test Hours Tested PRODUCTION FO] OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 7/19/98 6.00 TEST PERIOI' 2] ]0 735 3 176I 472 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 425 0 24-HOUR RATE: 7860 3714 12 39° 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. N/A Form 10-407 Submit in duplicate Rev. 7-]-80 CONTINUED ON REVEI-~SE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Total pump volumes for this event: Category 1. 9049 Category 2. 100 Category 3. 0 Total: 9149 Top Reservoir (T3) 8990' 5034' Total to Date: 9149 Base Reservoir (T2) 9258' 5216' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Drilling Reports, Directional Survey, As-Builts 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~ (/ ~ Prepared by Name/Number Sharon AIIsup-Drake/263-4612 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 5/14/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:2N-323 WELL_ID: AK9405 TYPE: AFC: AK9405 STATE:ALASKA AREA/CNTY: NORTH SLOPE WEST FIELD: KUPARUK RIVER UNIT SPUD:04/ll/98 START COMP: RIG:DOYON RIG 141 WI: 0% SECURITY:0 API NUMBER: 50-103-20258-00 BLOCK: FINAL: 04/08/98 (D1) TD: 0'( SUPV: 04/09/98 (D2) TD: 0'( SUPV: 04/10/98 (D3) TD: 0'( SUPV:BP 0) 0) 0) 04/11/98 (D4) TD: 1188'(1188) SUPV:BP 04/12/98 (DS) TD: 2085'(897) SUPV:BP 04/13/98 (D6) TD: 3386'(1301) SUPV:BP MW: 0.0 VISC: MOVING RIG FROM CD2-35 0 PV/YP: 0/ 0 APIWL: 0.0 Tear down rig, move camp and pipe shed from CD2-35 to 2N-323. Remove windwalls from derrick and lay down derrick. MW: 0.0 VISC: INSTALL WINDWALLS 0 PV/YP: 0/ 0 APIWL: 0.0 Move subbase, derrick, motor complex, pits, pumps, motors and boilers from CD2-35 to 2N-323. Spot and connect components and rasie derrick. Install windwalls. MW: 10.1 VISC: 96 PV/YP: 13/52 DRILLING 12.25" SURFACE HOLE APIWL: 11.2 Accept rig @ 1200 hrs 4/10/98. N/U diverter system. Function test diverter. Pre-spud meeting. MW: 10.5 VISC: 101 PV/YP: 18/32 CIRCULATING OUT GAS APIWL: 8.8 Spud well and directionally drill 12.25" hole from 108' to 1188' MW: 11.3 VISC: 68 PV/YP: 26/41 DRILLING 12.25" SURFACE HOLE APIWL: 6.4 Directionally drill 12.25" hole from 1188' to 1337' Background gas increased to 1800 units. Circulate out gas and raise mud weight to 10.9. Drill from 1337' to 1351'. BU gas went up to 2000 units. Raise mud weight to 11.1 ppg. Drill from 1351' to 1373'. Circulate out gas. Raise mud weight to 11.3 ppg. Drill from 1373' to 1404'. No apparent additional gas loading from drilling ahead. Control drill from 1404' to 2085' MW: 11.0 VISC: 72 PV/YP: 26/30 FINISHING SHORT TRIP APIWL: 5.2 Control drill 12.25" hole from 2085' to 2116'. Hole tight from 1304' to 1509' Wiped until free. Control drill from 2116' to 2704' Circulate out gas. Control drill from 2704' to 3386'. Reduce mud weight to 11.0 ppg. 04/14/98 (D7) TD: 3386'( SUPV:RWS o) MW: 10.9 VISC: 75 PV/YP: 25/29 NIPPLING DOWN DIVERTER APIWL: 4.8 Drilled from 3386' to 3480' Pump hi-vis sweep and circ hole clean. Observe well, pump dry job. RIH with 9-5/8" casing. Pump cement. 04/15/98 (D8) TD: 3386'( SUPV:RWS o) MW: 10.5 VISC: 47 PV/YP: 18/23 RIH W/DRLG ASSY APIWL: 5.0 CBU. Lost circulation, packed off at casing hanger. Flowline and riser plugged w/clabbered mud, unplug. Circ and condition mud to 10.9 ppg. NU diverter system. NU BOPE and test to 250/3500 psi. 04/16/98 (D9) TD: 3530'(144) SUPV:RWS MW: 9.5 VISC: 46 PV/YP: 12/ 0 DRILLING APIWL: 7.8 Drilled cement and stage tool from 1502-1520' Drilled cement from 3125' to 3460' float shoe. Drill from 3465' to 3500' FIT 16.0 ppg EMW. Drilled from 3500' to 3530' MD. 04/17/98 (D10) TD: 5092'(1562) SUPV:RWS MW: 9.6 VISC: 52 PV/YP: 18/18 PREP F/SHORT TRIP @ 5494' APIWL: 6.8 Perform FIT 2313', 16.0 ppg EMW. Drilled from 3530' to 4999'. Perform LOT ~ 3021', 16.6 ppg EMW. Drilled from 4999' to 5092' 04/18/98 (Dll) TD: 6515'(1423) SUPV:RWS MW: 9.6 VISC: 55 PV/YP: 15/27 APIWL: 4.8 DRILLING Drilled from 5092' to 6515' Pump hi vis sweep. Pump dry job. POH to shoe, most drag occurring in casing. 04/19/98 (D12) TD: 7906'(1391) SUPV:RWS MW: 9.7 VISC: 52 PV/YP: 16/21 DRILLING @ 8204' Drilled from 6515'-7906' APIWL: 4.4 04/20/98 (D13) TD: 9175'(1269) SUPV:RWS MW: 9.8 VISC: 51 PV/YP: 16/20 DRILLING @ 9512' APIWL: 4.0 Continue drilling from 7906'-8462' Sweep hole. Short trip to 7423'. Drilled from 8462'-9175' 04/21/98 (D14) TD: 9553' (378) SUPV:RWS MW: 9.8 VISC: 53 PV/YP: 15/22 PREP F/CSG WIPER TRIP APIWL: 4.0 Continue drilling from 9175'-9553' Short trip to shoe, monitor well. Pump hi-vis sweep. RIH w/FMS-DSI-GR-SP. Date: 5/14/98 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 3 04/22/98 (D15) TD: 9553'( 0) SUPV:RWS MW: 9.9 VISC: 57 PV/YP: 20/23 RUNNING CASING APIWL: 3.8 Continue running logs. RIH to TD, no fill. Install test plug, install 7" rams - test to 2500~. Run 4.5" casing. 04/23/98 (D16) TD: 9553'( 0) SUPV:RWS MW: 8.5 VISC: 0 PV/YP: 0/ 0 RUNNING 4.5" COMPLETION TBG AP IWL: 0.0 run 7" x 4.5" tapered casing string. Pump cement. 04/24/98 (D17) Tm: 9553'( 0) SUPV:RWS MW: 0.0 VISC: 0 PV/YP: 0/ 0 RIG RELEASED, MOVING TO 2N APIWL: 0.0 Install 9.625"x 7" packoff and test to 5000~. RIH w/4.5" completion tubing. Freeze protect well. N/D BOPs. N/U tree and test to 5000%. End of WellSummary for Well:AK9405 Prepared by: S. ALLSUP-DRAKE ARCO Alaska, Inc. KUPARUK RIVER UNIT ,k, WELL SERVICE REPORT '' K1(2N-323(W4-6)) WELL JOB SCOPE JOB NUMBER 2N-323 PERFORATE, PERF SUPPORT 0522981856.3 DATE DALLY WORK UNIT NUMBER 06/20/98 RUN B.P./PERFORATE/PRESSURE/TEMP SURVEY DAY OPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 1 YESI YES SWS-JOHNSON SCHWEN DERMAN FIELD AFC# CC# Signed ESTIMATE K85098 180KN U2TN Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann Initial Outer Ann I Final Outer Ann 100 PSI 250 PSI 0 PSI 0 PSI 750 PSII 750 PSI DALLY SUMMARY RAN HALLIBURTON EZ DRILL SV BRIDGE PLUG AND SET @ 9390'. TESTED CSG TO 2500 PSI, GOOD. PERFORATE 4-1/2" LINER F/9130' TO 9170' W/2-1/2" HC/BH/4 SPF/180 DEG PHASING 2 SPF 90 DEG CCW F/HIGH SIDE, 2 SPF 90 DEG CW F/ HIGH SIDE. RAN PRESSURE TEMP SURVEY AT MID PERF DEPTH. TIME LOG ENTRY 08:30 MIRU SWS (JOHNSON AND CREW) TGSM, PRESSURE TESTING W/LRS. MU HALLIBURTON 4-1/2" (3.65"©D) EZ DRILL SV BRIDGE PLUG AND 1-11/16" GUN GR TOOL.TL= 21' 10:00 WATED FOR DSO TO DELIVER BLEED BACK TANK. 11:30 RIH 9200' RKB TIE IN W/SPERRY SUN ROP/DGR/EWR4 MWD LOG DATED 4/21/98. TAGGED DOWN AT 9407' RKB PICK UP AND RETAG SAME. SET TOP OF BRIDGE PLUG AT 9390' RKB AND FIRED SETTING CHARGE, HAD GOOD SURFACE INDICATIONS. POH W/SETTING TOOL. 14:30 AT SURFACE RD LURICATOR AND BREAK DOWN SETTING TOOL. 15:00 RIGGED UP LRS TO COMPANION VALVE AND PRESSURE TESTED CASING FOR 30 MIN. TO 2500 PSI BLED TO 2425 PSI, GOOD TEST. 15:30 17:00 20:30 23:00 RD LRS. MU # 1 PERF GUN ASSEMBLY 2-1/2" HC/BH/4 SPF/180 DEG PHASING/2 SPF 90 DEG CCW F/HIGH SIDE, 2 SPF 90 DEG CW F/HIGH SIDE. 20' GUN. (20' GUN/CCL)TL=25' RIH UNABLE TO GET PAST 1730' RKB (MAX ANGLE 1800') POH. ADD 6'WT BAR, RIH NO PROBLEMS. TIE IN AND PERFORATE SLIGHTLY OVERBALANCED F/9150'- 9170' RKB (20'). POH. AT SURFACE RD LUBRICATOR ALL SHOTS FIRED. MU # 2 PERF GUN SAME AS ABOVE. RIH TIE IN AND PERFORATE F/9130'-9150' RKB (20'). POH. AT SURFACE RD LUBRICATOR ALL SHOTS FIRED. MU PRESSURE TOOL. (CPLS/CGRS/WT,WT) TL= 33' RIH AND TIE IN.STOP TOOL @ 9150' RKB MID PERF DEPTH. RECORD PRESSURE AND TEMP FOR 30 MIN. POH. 02:00 AT SURFACE RD. LEAVE WELL SHUT IN. I WELL JOB SCOPE JOB NUMBER 2N-323 FRAC, FRAC SUPPORT 0625982011.11 DATE DAILY WORK UNIT NUMBER 07/01/98 INITIAL FRAC DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON SUPERVISOR I YES YES DS-GALLEGOS CHAN EY FIELD AFC# CC# Signed ESTIMATE K85098 180KNU2TN Initial Tbg Press Final Tbg Press Initial Inner Ann Final Inner Ann I Initial Outer Ann I Final Outer Ann 500 PSI 1500 PSI 500 PSI 500 PSII 50 PSII 300 PSI DALLY SUMMARY INITIAL FRAC COMPLETED.SCREENED OUT EARLY. MAXIMUM PRESSURE 5850 PSI & F.G. (.64). INJECTED 174217 LBS OF I PROP INTO THE FORM W/9.9# PPA OF #12/18 @ THE PERF'S. UNABLE TO FREEZE PROTECT TBG[Frac-Refrac] I TIME LOG ENTRY 07:00 10:00 10:20 12:00 MIRU DOWELL FRAC EQUIP, LRS HOT OIL UNIT, & APC VAC TRUCKS. HELD SAFETY MEETING (18 PEOPLE ON LOCATION). PT'D BACKSIDE LINES AND EQUIP TO 4000 PSI, RAISED THE INNER CSG PRESSURE AS REQUIRED. SET TREESAVER AND PT'D HIGH PRESSURE LINES TO 7800 PSI. PUMP DATAFRAC W/50# DELAYED XL GW @ 5 TO 10 BPM. SLURRY VOLUME PUMPED 251 BBLS. MAXIMUM PRESSURE 4000 PSI & ENDING PRESSURE 2000 PSI. SHUT DOWN AND OBTAINED ISlP OF 1277 PSI W/F.G. @ 69). MONITORED WHTP FOR CLOSURE. CLOSURE TIME 12 MINS @ 840 PSI. PAD VOLUME = 200 BBLS. PUMP BREAKDOWN W/50# DELAYED XL GW @ 30 BPM. SLURRY VOLUME PUMPED 620 BBLS. USED 8664 LBS OF #20/40 PROP FOR SCOURING. MAXIMUM PRESSURE 3900 PSI AND ENDING PRESSURE 2500 PSI STEPPED RATE DOWN AT END OF STAGE AND SHUT DOWN. OBTAINED ISlP OF 1002 PSI W/F.G. (.64). PULSED FOR CLOSURE DETERMINATION. 13:25 PUMP PRE PAD W/20# GW @ 20 BPM. SLURRY VOLUME PUMPED 450 BBLS. MAXIMUM AND ENDING PRESSURE 1900 PSI. 13:45 PUMP FRAC W/50# DELAYED XL GW @ 20 BPM.SCREENED OUT EARLY. MAXIMUM PRESSURE 5850 PSI. TOTAL SLURRY VOLUME PUMPED 1234 BBLS. PUMPED 214743 LBS OF PROP ( 18497 LBS OF #20/40 & 196246 LBS OF #12/18), INJECTED 174217 LBS OF PROP INTO THE FORMATION W/9.9# PPA OF #12/18 @ THE PERF'S. LEFT 40526 LBS OF PROP IN THE WELLBORE AND EST TOP OF FILL TO BE @ 4700' W/A ESTIMATED BHP OF 2300 PSI. UNABLE TO FREEZE PROTECT TBG. 15:30 17:00 STARTED R/D. DEPRESSURED THE INNER CSG BACK TO 500 PSI AND R/D LRS HOT OIL UNIT. REMOVED TREESAVER (ALL CUPS RETURNED). TIME 18:00 LOG ENTRY R/D COMPLETED AND DOWELL LEAVING LOCATION. WELL SECURED AND NOTIFIED DSO OF STATUS. 'c~CR~P13ON PER K~1~-_~c1029 ACS a, pp DESCRIPTION NOTES: I. COORDINATES SHOWN ARE A.S.P. ZONE 4, N.A.O. 27, ELEVAtiONS SHOWN ARE 8RITISH PETROLEUM MEAN SEA LEVEL. ALL DISTANCES ARE TRUE. 2. BASIS OF LOCATIONS AND ELEVATIONS ARE O.S. 2-M NORTH AND 7-10-6 MONUMENTS PER LOUNSBURY & ASSOCIATES. ,T. CONDUCTORS ARE L OCA TED WI THIN PROTRACTED SECTION J, TOWNSHIP 9 NORTH, RANGE 7 EAST, UMIA T MERIDIAN. 4. DATE OF SURVEY: 4/7/98, FIELD BK: L98-27, pp. 41-44; L98-JO, pp. 66. 5. DRILL SITE 2-N GRID NORTH IS ROTATED 13130'00' WEST FROM A.S.P. ZONE 4 GRID NORTH. MAP (Not To Stole) JI$ i J21 ~ J2J ~ J25 ~ J29 ! Sec. 3, T. 9 N., R. 7 E. A. $. P. s LA TI TUDE L ONGI TUDE 'Y' 'X' 5, 91 I, 973. 74 5,9II, 946. 76 5, 9I 1, 940. 05 5,911,955.27 5,911,919.74 460, 94 7. 05 460, 829. 75 460, 800. 69 460, 77I. 63 460, 7I J. 19 70' I0' IJ. 6Jl' 70' I0° IJ. J60' 70' I0° 13.29J' 70' I0' IJ. 224' 70' I0' IJ. 088' I50' 18' 51. 492' 150' 18' 54.886' 150' 18' 55. 727' 150' 18' 56.568' 150' 18' 58.259' SURVEYOR'S C£R TIFICA TE I HEREBY CERTIFY THAT I ~WI PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY DONE BY ME OR UNDER MY DIRECT SUPERVISION ,aND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF' APRIL 7. 1998. · ~'~ LO UNSBURY C/l~. & ASSOCIATES. INC. ARCO Alaska, Inc. ~ K621409 4/08/98 AREA: 2N MODULE: XX UNIT: 02 DRILL SITE 2N (TARN) WELL CONDUCTORS //,315, ,321, 525,-525 & ,329 AS-BUILT LOCATIONS CEA-D2NX-621409 [ mEET: 2 ]REV:. 20F 1 LEGEND "°' ~'~" ' · FUTURE CONDUCTOR L OCA TION~ N ~CINI~ MAP LOUNSBURY & ASSOCIATES. INC. E~N~ P~NE~ SURV~O~ ~E& 2N ~U~: XX UNIT: D2 k~GO Alaska, Inc. ~ ~ ~o~~o~ ~. ~, ~. LK6214D9 4/08/98 CEA-D2NX-6214D9 1 OF 2 1 ir ~1 SURVEY CALCULATION AND FIELD WORKSHEE I Job No. 0450-97209 Sidetrack No. Page 1 · -= [I.r~ =- I :~--~ Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - #141 Field TARN DEVELOPMENT FIELD Well Name & No. TARN DRILLSITE 2N/323 Survey Section Name Definitive Survey BHI Rep. RANDY LANTZ WELL DATA Target TVD (F'r) Target Coord. N/S Slot Coord. N/S -67.57 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SS~- Target Description Target Coord. E/W Slot Coord. E/W -792.13 Magn. Declination 27.110 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft[~ 30m~ 10m~ Vert. Sec. Azim. 297.47 Magn. to Map Corr. 27.110 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (F-l') (FT) (FT) (FT) (Per ~00 FT) Drop (-) Left (-) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIE IN POINT 11-APR-98 MWD 171.80 0.79 325.60 171.80 171.79 1.04 0.98 -0.67 0.46 0.46 9 1/2" M1C 1.5 DEG AKO 11 -APR-98 MWD 256.86 1.51 309.50 85.06 256.84 2.66 2.17 -1.87 0.92 0.85 11 -AP R-98 MWD 348.46 3.10 316.15 91.60 348.36 6.18 4.73 -4.51 1.76 1.74 11-APR-98 MWD 442.32 5.93 314.49 93.86 441.92 13.23 9.96 -9.73 3.02 3,02 -1.77 11-APR-98 MWD 524.51 9.52 310.03 82.19 523.35 23.92 17.31 -17.97 4.43 4,37 -5.43 11-APR-98 MWD 621.86 13.28 306.61 97.35 618.76 42.83 29.16 -33.11 3.92 3.86 -3.51 11 -AP R-98 MWD 715.53 18.04 305.27 93.67 708.93 67.83 43.96 -53.60 5.10 5.08 -1.43 11-APR-98 MWD 807.11 23.11 302.50 91.58 794.64 99.81 61.81 -80.35 5.64 5.54 -3.02 11 -APR-98 MWD 889.58 24.88 304.02 82.47 869.98 133.17 80.22 -108.39 2.27 2.15 1.84 11-APR-98 MWD 988.39 30.00 304.32 98.81 957.65 178.37 105.79 -146.04 5.18 5.18 0.30 11 -APR-98 MWD 1074.86 35.03 302.84 86.47 1030.54 224.58 131.45 -184.77 5.89 5.82 -1.71 12-AP R-98 MWD 1167.75 36.59 302.31 92.89 1105.87 278.71 160.71 -230.57 1.71 1.68 -0.57 12-APR-98 MWD 1264.38 40.42 300.44 96.63 1181.48 338.72 191.99 -281.94 4.14 3.96 -1.94 12-APR-98 MWD 1356.26 43.10 299.30 91.88 1250.01 399.85 222.45 -335.01 3.03 2.92 -1.24 12-APR-98 MWD 1448.00 48.70 297.49 91.74 1313.83 465.69 253.72 -392.96 6.27 6.10 -1.97 12-APR-98 MWD 1543.74 53.31 296.76 95.74 1374.06 540.08 287.62 -459.17 4.85 4.82 -0.76 13-APR-98 MWD 1631.96 56.56 297.42 88.22 1424.73 612.27 320.51 -523.45 3.73 3.68 0.75 12-APR-98 MWD 1728.76 59.42 298.07 96.80 1476.04 694.34 358.72 -596.08 3.01 2.95 0.67 12-APR-98 MWD 1824.07 63.10 294.95 95.31 1521.87 777.87 395.97 -670.85 4.81 3.86 -3.27 12-APR-98 MWD 1916.34 62.06 295.03 92.27 1564.36 859.70 430.57 -745.09 1.13 -1.13 0.09 12-APR-98 MWD 2004.86 60.89 294.34 88.52 1606.63 937.38 463.06 -815.75 1.49 -1.32 -0.78 13-APR-98 MWD 2099.67 62.04 296.28 94.81 1651.92 1020.60 498,67 -891.04 2.17 1.21 2.05 13-APR-98 MWD 2192.43 60.80 295.95 92.76 1696.30 1102.04 534.52 . -964.18 1.37 -1.34 -0.36 = [!.r~'- I~[~--~ Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - #141 Field TARN DEVELOPMENT FIELD Well Name & No. TARN DRILLSiTE 2N/323 Survey Section Name Definitive Survey BHI Rep. RANDY LANTZ ~llr~l~ WELL DATA Target'I'VD (FT) Target Coord. N/S Slot Coord, N/S -67.57 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SSD Target Description Target Coord. E/W Slot Coord. E/W -792.13 Magn. Declination 27.110 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft[~ 30m~ 10m~ Vert, Sec. Azim. 297.47 Magn. to Map Corr. 27.110 Map North to: OTHER SURVEY DATA -- Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (-t-) Right (+) Comment Type (F'r) (DD) (DD) (FT) (FT) (FT) (FT) (Per tOO FT) Drop (-) Left (-) 13-APR-98 MWD 2285.82 61.83 297.91 93.39 1741.13 1183.96 571.63 -1037,21 2.15 1.10 2.10 13-APR-98 MWD 2377.42 60.71 297.78 91.60 1785.16 1264.28 609.15 -1108.24 1.23 -1.22 -0.14 13-APR-98 MWD 2471.85 61.76 296.17 94.43 1830,60 1347,04 646.69 -1182.01 1.86 1.11 -1.70 13-APR-98 MWD 2564.09 60,97 295.86 92.24 1874.81 1427.98 682.20 -1254,76 0.91 -0.86 -0.34 13-APR-98 MWD 2658.20 61,67 299.04 94,11 1919.98 1510,52 720.26 -1328.01 3,06 0,74 3.38 -- 13-APR-98 MWD 2751.81 61.21 299.15 93.61 1964.73 1592.71 760,24 -1399.85 0,50 -0.49 0.12 13-APR-98 MWD 2844.13 60.24 299.54 92.32 2009.88 1673.19 799.70 -1470,05 1.11 -1.05 0.42 13-APR-98 MWD 2934.53 63,37 299,51 90.40 2052.58 1752,81 838.96 -1539.37 3.46 3,46 -0.03 -- 13-APR-98 MWD 3028.74 61.97 300,90 94.21 2095.84 1836,40 881,06 -1611.70 1,98 -1.49 1.48 13-APR-98 MWD 3121,34 61,72 298.38 92,60 2139.54 1917.98 921,43 -1682.65 2,41 -0,27 -2.72 13-AP R-98 MWD 3210.93 61.93 299,10 89,59 2181,84 1996.93 959.40 -1751.89 0.75 0.23 0.80 13-APR-98 MWD 3306,73 61.60 298,05 95.80 2227.16 2081.31 999.77 -1826.01 1,03 -0.34 -1.10 -- 13-AP R-98 MWD 3399,45 62,63 295.69 92,72 2270.53 2163.25 1036.80 -1899.11 2.51 1,11 -2,55 17-APR-98 MWD 3497.52 62.30 291.41 98.07 2315.88 2249,98 1071.54 -1978.80 3,88 -0.34 -4.36 6 3/4" M1XL 1,2 DEG AKO 17-AP R-98 MWD 3587.42 62.10 289.41 89.90 2357,81 2328,90 1099.27 -2053,33 1,98 -0.22 -2,22 17-APR-98 MWD 3685,46 62.40 290,26 98.04 2403.46 2414,89 1128.71 -2134,94 0,83 0,31 0,87 -- 17-APR-98 M~VD 3777.33 62,41 290.72 91.87 2446.02 2495.71 1157.21 -2211.21 0.44 0.01 0,50 17-APR-98 MWD 3870,02 62.47 290.61 92.69 2488,91 2577,30 1186.21 -2288,10 0,12 0.06 -0.12 -- 17-APR-98 MWD 3964,25 61.75 300.15 94,23 2533.06 2660,39 1221.83 -2363.23 8.98 -0.76 10.12 17-APR-98 MWD 4057,07 61,84 299.19 92.82 2576,93 2742.13 1262,32 -2434.30 0.92 0.10 -1.03 -- 17-APR-98 MWD 4148,16 62.01 300.61 91,09 2619.80 2822.42 1302.38 -2503.97 1.39 0.19 1,56 -- 17-APR-98 MWD 4242.63 62.33 299,60 94.47 2663.91 2905.88 1344,29 -2576.25 1.00 0,34 -1.07 17-APR-98 MWD 4331.37 62.52 301.36 88.74 2704,99 2984.42 1384.18 -2644.03 1.77 0,21 1,98 17-APR-98 MWD 4425.99 62,95 300,61 94.62 2748,34 3068.37 1427.48 -2716.14 0.84 0,45 -0.79 i ........................................................ Hig L;ontractor & No. Doyon Drilling Co. - #141 Field TARN DEVELOPMENT FIELD II f Well Name & No. TARN DRILLSITE 2N/323 Survey Section Name Definitive Survey BHI Rep. RANDY LANTZ , '~ WELL DATA Target TVD (F'r) Target Coord. N/S Slot Coord. N/S .... -_6__7:5_7. .......... Grid Correction 0.000 Depths, Mon~.ur~d From: ['{KB iXI M~,'~LI I O~3[ Target Description Target Coord. E/W Slot Coord. E/W -792,13 Magn. Declination 27.110 Calculation Method MINIMUM CURVATURE 'Target Direction (OD) Build\Walk\DL per: lO0ft~ 30m~ lOm~] Vert. Sec. Azim, 297.47 Magn. to Map Corr. 27,110 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical _ Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (F'r) (FT) (F'T) (F-T) (Per ~00 F'r) Drop (-) Left (-) 1 7-APR-98 MWD 4521,70 63.35 300.19 95.71 2791.56 3153.65 1470.69 -2789,79 0,57 0.42 -0.44 . -- 17-APR-98 MWD 4611.21 62.01 298.50 89.51 2832.65 3233.13 1509.67 -2859.10 2.25 -1.50 -1.89 ,, 17-APR-98 MWD 4707.77 60.24 296.70 96.56 2879,28 3317.68 1548.85 -2934.02 2.45 -1.83 -1.86 ,,. 17-APR-98 MWD 4799.99 60,67 295.73 92,22 2924.75 3397,88 1584.29 -3006.00 1.03 0,47 -1.05 17-APR-98 MWD 4891.64 61.22 295.18 91.65 2969.26 3477.95 1618,72 -3078.33 0.80 0.60 -0.60 17-APR-98 MWD 4984.73 61.68 296.94 93.09 3013.75 3559.69 1654.64 -3151.79 1.73 0.49 1.89 18-APR-98 MWD 5078.04 61.82 296.26 93.31 3057.92 3641.88 1691.45 -3225.28 0.66 0.15 -0.73 -18_APR_98 MWD 5169.40 59.56 294.47 91.36 3102.64 3721,48 1725.58 -3297.25 3.01 -2.47 -1.96 ,- 18-APR-98 MWD 5263.88 59.97 295.59 94.48 3150.22 3803.03 1760.12 -3371.21 1.11 0.43 1.19 18-APR-98 MWD 5355.27 60.26 295.17 91,39 3195.76 3882,21 1794.08 -3442.80 0.51 0,32 -0.46 18-APR-98 MWD 5448.58 60.45 294.78 93.31 3241.91 3963.23 1828.32 -3516.31 0.42 0.20 -0.42 18-APR-98 MWD 5540.09 60.69 294.00 91.51 3286.88 4042.82 1861.23 -3588.90 0.79 0.26 -0.85 18-APR-98 MWD 5632.85 60.42 296.64 92.76 3332.48 4123.53 1895.77 -3661.91 2.50 -0.29 2.85 18-APR-98 MWD 5726.21 60.66 295.24 93.36 3378.40 4204.78 1931.33 -3735.01 1.33 0,26 -1.50 18-APR-98 MWD 5818.80 60.98 297.01 92.59 3423.54 4285.60 1966.92 -3807.58 1.70 0,35 1.91 18-APR-98 MWD 5912.83 61.61 296,71 94.03 3468.71 4368.07 2004.18 -3881.16 0.73 0.67 -0.32 18-APR-98 MWD 6007,05 61.82 296.48 94.22 3513.35 4451.03 2041.33 -3955.35 0,31 0.22 -0.24 18-APR-98 MWD 6099.80 61.28 298.19 92.75 3557.54 4532.57 2078.77 -4027.79 1.72 -0.58 1.84 -- 18-APR-98 MWD 6192.52 61.86 298.13 92.72 3601,68 4614.10 2117.25 -4099.68 0.63 0.63 -0.06 18-APR-98 MWD 6285.37 02.48 297.88 92.85 3645.03 4696.21 2155.80 -4172.17 0.71 0.67 -0.27 18-APR-98 MWD 6377.29 63.16 296.82 91.92 3687.02 4777.98 2193.37 -4244.80 1.26 0.74 -1.15 18-APR-98 MWD 6470.80 62.33 298.13 93.51 3729.84 4861.10 2231.72 -4318.55 1.53 -0.89 1.40 19-APR-98 MWD 6562.20 62.80 298.29 91.40 3771.95 4942.21 2270.06 -4390.04 0.54 0.51 O. 18 19-APR-98 MWD 6654.60 61.59 298.96 92.40 3815.06 5023,93 2309.21 -4461.78 1.46 -1.31 0.73 I I ii ii ii I i~ dull V I,, i ~Pi, i..~,~UI.J~ I 1~,,/1~ ~I~iU I I1..1=,1~ vii ~I tl~,~;ll II..I.= I Job No. 0450-97209 Sidetrack No. Page 4 ~ · ~ [ !1~ '- I ::(--"~ Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - #141 Field TARN DEVELOPMENT FIELD Well Name & No. TARN DRILLSITE 2N/323 Survey Section Name Definitive Survey BHI Rep. RANDY LANTZ ~J~Jl"~~ WELL DATA Target TVD (ET) Target Coord. N/S Slot Coord. N/S -67.57 Grid Correction 0.000 Depths Measured From: RKB ~ MSL~ SSI-1 Target Description Target Coord. E/W Slot Coord. E/W -792.13 Magn. Declination 27.110 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 10Oft~ 30m~ 10mo Vert. Sec. Azim. 297.47 Magn. to Map Corr. 27.110 Map North to: OTHER SURVEY DATA Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) / S(-) E(+) / W(-) DL Build (+) Right (+) Comment Type (FT) (DD) (DD) (FT) (FT) (FT) (FT) (Per ~00 FT) Drop (-) Left (-) i 9-AP R-98 MWD 6746.47 61.70 298.86 91.87 3858.69 5104.75 2348.30 -4532.55 0.15 0.12 -0.11 19-AP R-98 MWD 6839.29 61.91 298.70 92.82 3902.54 5186.53 2387.68 -4604.25 0.27 0.23 -0.17 i 9-APR-98 MWD 6931.52 62.37 299.52 92.23 3945.64 5268.04 2427.35 -4675.49 0.93 0.50 0.89 19-APR-98 MWD 7024.65 62.60 299.69 93.13 3988.67 5350.58 2468.16 -4747.30 0.30 0.25 0.18 19-APR-98 MWD 7118.98 61.79 298.39 94.33 4032.67 5433.98 2508.66 -4820.25 1.49 -0.86 -1.38 ___ 19-APR-98 MWD 7210.08 62.00 299.46 91.10 4075.59 5514.31 2547.53 -4890.58 1.06 0.23 1.17 19-APR-98 MWD 7301.29 62.01 298.26 91.21 4118.40 5594.82 2586.40 -4961.11 1.16 0.01 -1.32 -- 19-APR-98 MWD 7397.68 61.62 297.36 96.39 4163.93 5679.78 2626.04 -5036.26 0.92 -0.40 -0.93 -- 19-APR-98 MWD 7490.93 62.18 296.49 93.25 4207.85 5762.04 2663.28 -5109.60 1.02 0.60 -0.93 19-APR-98 MWD 7583.15 62.52 296.97 92.22 4250.65 5843.72 2700.03 -5182.58 0.59 0.37 0.52 19-APR-98 MWD 7675.97 62.77 296.87 92.82 4293.30 5926.15 2737.35 -5256.06 0.29 0.27 -0.11 -- 19-APR-98 MWD 7767.57 61.05 296.66 91.60 4336.43 6006.95 2773.74 -5328.21 1.89 -1.88 -0.23 ___ 19-AP R-98 MWD 7859.00 61.31 297.77 91.43 4380.50 6087.06 2810.38 -5399.45 1.10 0.28 1.21 __ -- 20-APR-98 MWD 7951.42 61.42 296.13 92.42 4424.80 6168.17 2847.14 -5471.75 1.56 0.12 -1.77 -- 20-APR-98 MWD 8044.88 60.99 296.88 93.46 4469.81 6250.06 2883.69 -5545.05 0.84 -0.46 0.80 ~ 20-APR-98 MWD 8138.30 61.39 294.76 93.42 4514.84 6331.87 2919.33 -5618.73 2.03 0.43 -2.27 __ 20-AP R-98 MWD 8230.81 58.87 295.14 92.51 4560.91 6412.01 2953.17 -5691.46 2.75 -2.72 0.41 20-APR-98 MWD 8323.46 56.96 295.96 92.65 4610.12 6490.46 2987.02 -5762.28 2.19 -2.06 0.89 20-APR-98 MWD 8414.79 54.29 295.42 91.33 4661.68 6565.79 3019.69 -5830.20 2.96 -2.92 -0.59 -- 20-APR-98 MWD 8509.31 52.35 296.56 94.52 4718.14 6641.57 3052.90 -5898.33 2.27 -2.05 1.21 -- -- 20-APR-98 MWD 8603.46 51.05 296.54 94.15 4776.49 6715,44 3085.93 -5964.43 1.38 -1.38 -0.02 20-APR-98 MWD 8696.36 50.10 298.39 92.90 4835.49 6787.20 3119.01 -6028.10 1.85 -1.02 1.99 --. 20-APR-98 MWD 8788.83 47.86 298.38 92.47 4896.18 6856.95 3152.18 -6089.47 2.42 -2.42 -0.01 -- 20-APR-98 MWD 8882.09 46.41 299.06 93.26 4959.62 6925.29 3185.02 -6149.42 1.64 -1.55 0.73 I ~ '""")IdrtVC! U/-~L.I~,,tJI..J-~ I IUI~I /-~l~ll.J rlc;~,u ¥¥~,~nn, onr-,- i JobNo. 0450-97209 Sidetrack No. Page 5 · -' Il[r-I-' I =f:--"~ Company ARCO ALASKA, INC. Rig Contractor & No. Doyon Drilling Co. - #141 Field TARN DEVELOPMENT FIELD I Well Name & No. TARN DRILLSITE 2N/323 Survey Section Name Definitive Survey BHI Rep. RANDY LANTZ I~i~"L~ WELL DATA Target TVD (F'r) Target Coord. N/S Slot Coord. N/S -67.57 Grid Correction 0.000 Depths Measured From: RKB ~ MSL ~ SS~] Target Description Target Coord. E/W Slot Coord. E/W -792.13 Magn. Declination 27.110 Calculation Method MINIMUM CURVATURE Target Direction (DD) Build\Walk\DL per: 100ft~ 30mr-1 10mi-] Vert. Sec. Azim. 297.47 Magn. to Map Corr. 27.110 Map North to: OTHER SURVEY DATA -- Survey Survey Incl. Hole Course Vertical Total Coordinate Build Rate Walk Rate Date Tool Depth Angle Direction Length TVD Section N(+) /S(-) E(+) /W(-) DL Build (+) Right (+) Comment Type (F'r) (DD) (DD) (FT) (FT) (FT) (FT) (Per 400 FT)Drop (-) Left (-) 20-APR-98 MWD 8974.63 46.99 299.71 92.54 5023.08 6992.60 3218.07 -6208.10 0.81 0.63 0.70 20-APR-98 MWD 9067.62 47.03 299.33 92.99 5086.49 7060.57 3251.58 -6267.29 0.30 0.04 -0.41 20-APR-98 MWD 9157.77 47.30 298.99 90.15 5147.78 7126.65 3283.79 -6325.02 0.41 0.30 -0.38 21 -AP R-98 MWD 9251.75 47.43 299.15 93.98 5211.44 7195.76 3317.39 -6385.45 0.19 0.14 0.17 21 -APR-98 MWD 9344.47 47.98 298.46 92.72 5273.83 7264.33 3350.43 -6445.55 0.81 0.59 -0.74 21 -APR-98 MWD 9438.34 48.35 297.55 93.87 5336.44 7334.26 3383.27 -6507.30 0.82 0.39 -0.97 21 -APR-98 MWD 9508.17 48.63 297.65 69.83 5382.72 7386.56 3407.49 -6553.64 0.42 0.40 0.14 21-APR-98 MWD 9553.00 48.63 297.65 44.83 5412.35 7420.20 3423.11 -6583.44 0.00 0.00 0.00 Projected Data - NO SURVEY -- --. -- -- GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11366 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 7/24/98 Field: Tarn Pool (Reservoir Analysis Logs) Well Job # Log Description Date BL RF Sepia Floppy Disk KRU 2N-323 ~"~ .~ ©'-~ i STATIC PRESS/TEMP SURVEY 980620 I 1 KRU 2N-329 ~ ~ ~.~(~'~i STATIC PRESS/TEMP LOG 980626 I I Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. DATE: WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs 2N-323, July 8, 1998 AK-MM-80190 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' ,Mi Turker, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, )~nchorage, AK 99518 2N-323: 2" x 5" MD Resistivity, & Gamma Ray Logs: 50-103-20258-00 2" x 5" TVD Resistiviw & Gamma Ray Logs: 50-103-20258-00 2" x 5" MD Neutron & Density. Logs: 50-103-20258-00 2" x 5" TVD Neutron & Densiw Logs: 50-103-20258-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (907) 563-3256 ° Fax (907) 563-7252 A Division of Dresser Industries, inc. WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs July 1.1998 _,N-32.~, AK-MM-80190 1 LDWG formatted Disc with verification listing. API#: 50-103-20258-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACH]gD COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Ali Turker 5631 Silverado Way, Suite G. .Anchorage, Alaska 99518 ,- Date: Si~mled: ~m-2 /~~ Note: This Data replaces all previous MWD Digital Data for well (2N-323). 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 ° Fax (907) 563~7252 A D/v/sion of Dresser Inoustries, Inc. 6/11/98 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 11244 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Tarn Pool (Open Hole) Well Job # Log Description Date BL RF Sepia LIS Tape KRU 2N-323 ~1~ ~o'~<~'-'~ 98234 DSI/FMS 980421 I I I SIGNED: DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. To: WELL LOG TRANSMITTAL State of Alaska )daska Oil and Gas Conservation Comm. Attn.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs June 10,1998 2N-323, AK-MM-80190 I LDWG formatted Disc with verification listing. API#: 50-103-20258-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Ali Turker 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 5631 Silverado Way, Suite G · Anchorage1 Alaska 99518 ° (907) 563-3256 ° Fax (907) 563-7252 A Division of Dresser Industries, Inc, TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 May 14, 1998 Mr. Mike Zanghi Drill Site Development Supervisor ARCO Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Re: Tarn wells 2N-323, 2N-329, 2N~343 annular disposal requests Dear Mr. Zanghi: Pursuant to reviewing the additional geologic information, leak-off test data and cementing information presented today, the Commission is satisfied that sufficient data has been submitted to determine that the waste will be contained in a suitable receiving zone and the disposal will not contaminate freshwater, cause drilling waste to surface, impair the mechanical integrity of the well used for disposal, damage a producing or potentially producing formation or impair the recovery of oil or gas from a pool. Therefore, your request for annular injection into wells 2N-323, 2N-329 and 2N-343 is approved. David W. John~~ Chairman ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 May12,1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 2N-323 Dear Mr. Commissioner: Enclosed please find LOT plots and the casing detail sheets for Kupamk Well 2N-323. These forms are to satisfy AOGCC's request for information on this well prior to ARCO beginning annular disposal operations. If there are any questions, please call 265-1492. Sincerely, F. C. Johnson Drilling Engineer Kupamk Drill Site Development FCJ/skad cc: Blair Wondzell CSG DETAIL 9-5/8" SURFACE CSG WELL: 2N-323 DATE: 4/13/98 ARCO ALASKA, INC. 1 OF 1 PAGES · # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH TOPS 9-5/8" Landing Joint w/adapter 35.00 -2.50 1 FMC 9-5/8" Csg Hgr 1.60 32.50 44 Joints 9-5/8", 40#, L-80, BTC Casing (Jts 51 - 88) 1443.43 34.10 1 Baker-locked Joint of 9-5/8", 40~ L-80 Casing (Lock Joint 38.67 1477.53 1 Weatherford 9-5/8" '751E' Stage Tool 2.78 1516.20 1 Baker-locked Joint of 9-5/8", 40# L-80 Casing CLock Joint 38.75 1518.98 41 Joints 9-5/8", 40#, L-80, BTC Casing (Jts 4 thru 50) 1785.93 1557.73 1 Collar Joint 9-5/8", 40~ L-80 Casing (Jt #3 38.11 3343.66 1 Float Collar 1.47 3381.77 1 Baker-locked Joint of 9-5/8", 40~ L-80 Casing (Jr ~ 39.06 3383.24 1 Shoe Joint, 9-5/8", 40~, BTC Casing (Jt #1 36.68 3422.30 1 Float Shoe 1.70 3458.98 Bottom of casing string i 3460.68 . ~_ Remarks: Baker-Locked float shoe, float collar and first 3 joints. Ran centralizers on first 14 cnxns, one on every third joint above that to surface, and one each above and below stage tool. Baker-Locked stage tool and 1 jt each above and below it. DOYON 141 Drilling Supervisor: R. W. SPRINGER CASING AND LEAK-OFF FRACTURE TESTS Well Name: TARN 2N-323 Supervisor: R.W. SPRINGER Date: 4/16/98 Casing Size and Descriptio 9 5/8", 40#, L-80, BTC Casing Setting Depth: 3461' TMD Mud Weigh 9.50 ppg 2310' TVD EMW = Leak-off Pressure (P + MW 0.052 x TVD LOT =720 psi / (0.052 x 2310 ft) + 9.5ppg = 15.5 Hole Depth (md)= 3500' Fluid Pumped = 2.42 b Fluid bled back= 1.5 bbls. Pump output = .101 bps 900 800 700 60O UJ 500 I~. 400 3OO 2OO lO0 LEAK-OFF TEST _ CASING TEST Ill 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 STROKES CASING AND LEAK-OFF FRACTURE TESTS Well Name: TARN 2N-323 Supervisor: R.W. SPRINGER Date: 4/17/98 Casing Size and Descriptio 9 5/8", 40#, L-80, BTC Casing Setting Depth: 3461' TMD Mud Weigh 9.50 ppg 2316' TVD EMW = Leak-off Pressure (P + MW rg~ 0.052 x TVD ! ¢-~ FIT =780 psi/(0.052 x 2310 ft) + 9.5ppg = 16.0 pHole Depth (md)= 3530' Fluid Pumped = .8 bbls Fluid bled back= .8 bbls. Pump output = .101 bps 9OO 800 700 60O UJ 500 EL 400 30O 200 ~ LEAK-OFF TEST --B-- CASING TEST 100 0 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 STROKES CASING AND LEAK-OFF FRACTURE TESTS Well Name: TARN 2N-323 Supervisor: R.W. SPRINGER Date: 4/17/98 Casing Size and Description 9 5/8", 40#, L-80, BTC Casing Setting Depth: 3461' TMD Mud Weight 9.50 ppg 2316' TVD EMW = Leak-off Pressure (PL + MW 0.052 x TVD LOT=950psi/(.052x3019 ft) + 9.6ppg = 15.6 ppg Hole Depth (md)= 4999' Fluid Pumped = 2.42 b Fluid bled back= 2.25 bbls. Pump output = .101 bps UJ 12oo 11oo lOOO ! !/ 900 / ) 8oo / SHUT DOWN PUMP - / MONITOR SHUT IN PRESSURE 400 / 300 / 200 / ~ LEAK-OFF TEST lOO/ --B-- CASING TEST - / o 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 32 34 36 38 40 STROKES ANNULAR INJECTION TEST Well Name: TARN 2N-323 Date: 4/25/98 Supervisor: R.W. SPRINGER Casing Size and Description 9 5/8",40#,L-80,BTC x 7",26# L-80,BTC-MOD ANN Casing Setting Depth: 3461' Mud WeighS.5SW/6.8DS ppg LOT = TMD 2316' TVD EMW = Leak-off Pressure (PL + MW 0.052 x TVD Hole Depth (md)= 4999' Fluid Pumped = 317 bbls Fluid bled back= 0.00 bbls. Pump output = .25 - 2.0 BPM tl.I 100 0 ~ -e--~/~ I qJE(;TIO ~1TE ST , 90O 800 7OO 600 500 400 30O 200 100 0 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30 MINUTES ARCO Al~slm, Inc. April 14, 1998 Blair Wondzell, P. E. State of Alaska Alaska Oil and Gas Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Change of Stage Collar Depth KRU 2N 323 Permit No. 98-071 Dear Blair, This letter confirms our telephone conversation this morning, wherein ARCO Alaska, Inc. requests that the permitted setting depth for the stage tool in the 9-5/8" surface casing be changed to better accommodate the conditions in this well. At present, the permitted depth is 500' MD below the base of the Permafrost. However, because we experienced a significant increase in gas units at the base of the Permafrost, possibly hydrates, we recommend that the stage collar depth be changed to 200' below the base. This will enhance the likelihood of a successful cement job in the surface hole of this well. We appreciate your verbal concurrence on this issue, and will proceed accordingly. Sincerely, Contract Drilling Engineer ARCO Alaska, Inc. Cc: Fred Johnson, ARCO Alaska, Inc. Paul Mazzolini, ARCO Alaska, Inc. RECEIVED ARCO Alaska, Inc. , ¢tru¢l~re Tar~ Or.3l Site 2N 'Well: 323 :. : :Y~el¢ :rarr P. 6valop~ert~ Fr.ld Lcco!~on : I~rth Slope. Alas~al , 1 ' 4.0C ,~c~ I :Zoo i 1 7. gl I~¢_c.;n Turn [o Ta'c. ct ace J ~ 25.76 OL5:4.00 d¢9 per 100 j WELL PROFILE DATA ..... P~'nt ..... I M3 Irc D"r ',~CP 253.~ C.~ End ~ ~ui~da !~7.~ ~1,~ ~2,~ lI~.~ ~7,17 -~,E+ ~.~1 4.03 ~ of ~3~ 922~.1a ~oc 2~7~g 51gg.QE ~7.~ff -~&9~ 7172.2G 0.~ · ~-' 800 -.I 4- 2000 1 ,3200 360~ V 4~C - ~00 ~ ._ 55GU , ~1 ~3 .=las.= .aermafrasi~I~ · 4g..sgrCp We~t Sc~( 57.5~ £0C ! ! , o APR 1 4 19 8 <- West (feet') 0~3 EK]O0 540D ~800 42C~ 3EO0 ~ODI3 2400 ; ."GO 1230 6QO ~ 630 ._ Eccjin Angle 59,09 SuHo~'e I~catlon: :~3,09 ! 6B' ~L, 792' r~ D~: 5,,~ deg per 100 ft EOD ~7.0g , ~c. 3. T~N, R7E T~ TA~ - ki~d T~rn Furma~ur ~ Base ~a~ TO- 7 Casing ~ ~ · i i i i i '1" ! 1" i i i ! ! i i" i i i ' i' i i i [ i i i · i i i 800 ~' 2'30 160C 2000 24;c 2833 32o3 56'00 ~h.nco ~00 H~O0 Verticci Section (feet)-> Az:mufh 297,47 with re{erence O.OO N, 0.00 E from t .;- L TONY KNOWLE$, GOVERNOR ~I,ASKA OIL AND GAS CONSERVATION COMMISSION April 8. 1998 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Mike Zanghi Drill Site Development Supv. ARCO Alaska. Inc. PO Box 100360 Anchorage. AK 99510-0360 Rc~ Kuparuk River Unit 2N 323 ARCO Alaska. Inc. Permit No 98-71 Sur. Loc.: 68'FNL. 792'FEL. SEC. 3. T09N. R07E. UM Btmholc Loc: 1830' FNL. 2290'FWL. SEC 33. T10N.R07E. UM Dear Mr. Zanghi: Enclosed is thc approved application for permit to drill thc above referenced well. Thc Commission grants a waiver of thc shale density requirements of 20 AAC 25.033(c)(2)(D). Annular disposal of drilling waste will not bc approved until sufficient data is submitted to ensure that thc requirements of 20 AAC 25.080 arc met. Annular disposal of drilling wastes will be contingent of obtaining a well cemented surface casing confirmed bva valid Formation Integrity Test (FIT) - cementing records. FIT data. and any CQLs must be submitted to thc Commission prior to thc start of disposal operation. Thc permit to drill docs not cxcmpt you from obtaining additional pcrmits rcquircd bx' law from other governmental agencics, and docs not authorize conducting drilling operations until all other rcquircd pcrmitting dctcrminations arc made. Bloxvout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below thc surface casing shoe must be given so that a representative of thc Commission max' witness the test. Notice max' be given bv contacting thc Commission petroleum field inspector on the North Slope pager at . . David W. Johnston Chairman BY ORDER OF THE COMMISSION dlt',enclosures Department of' Fish & Game. t[:tbitat Section xvo encl. Department oi' Environment Conservation x~' o encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. TypeofWork Drill X Redrill [-'[I lb. TypeofWell Exploratory [~ StratigraphicTest [~ Development Oil X Re-Entry F" Deepen r-I Service r- Development Gas [~ SingleZone X Multiple Zone r' 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 28', Pad 121' feet Kuparuk River Unit 3. Address 6. Property Designation Tarn Pool P. O. Box 100360, Anchorage, AK 99510-0360 ALK 4802 ADL 380054 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 68' FNL 792' FEL Sec 3 T9N R7E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 2,081' FNL 1,796' FEL Sec 33 T10N R7E, UM 2N 323 #U-630610 At total depth 9. Approximate spud date Amount 1,830' FNL 2,290' FWL Sec 33 T10N R7E, UM 4/10/98 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line ARCO Tarn #3 (P x A) MD 9,829' 1,796' @ target feet 1 mile feet 2,560 TVD 5,286' feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth 400' feet Maximum hole angle 64° Maximum surface 1,835 psig At total depth (TVD) 2,425 psig 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 20" 16" Welded 80' 28' 28' 108' 108' 230 sx+ Permafrost Cement 12¼" 9-5/8" 40 ppf L-80 BTC 3,681' 28' 28' 3,403' 2,500' 690 sx G, 380 sx AS3L +60 sx 8Y2" 7" 26 ppf L-80 BTC-Mod 8,830' 28' 28' 8,829' 4,852' 500 sx G 81/2'' 4W' 12.6 ppf L-80 NSCT 1,000' 8,829' 4,490' 9,829' 5,286' (included above) 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Structural Length Size Cemented ~e~..~.(t ; ~"~'~:V~[ "i' ~e Vertical depth Conductor Surface ' loe u 2' Perforation depth: ,~t~eea Sv~rr~cda, 20. Attachments Filing fee X Property plat [~. BOP Sketch X Diverter Sketch X Drilling program X Drilling fluid program X Time vs depth plot E~. Refraction analysis ~-~ Seabed report ['-; 20 AAC 25.050 requirements X 21. I hereby certify that ,hl fo,~,T is fe and correct to the best of my knowledge Signed !~[ ,J, / ._,~,.~ ~, Title Drill Site Development Supv. /..) ~'~'~ Commission Use Only Permit Number ~VAPI nu,Cber ,...... I Approval date ij I C~)(~K.~'' I See cover letter for ~'~- ~'/ I 5p-,,~/~., ..-..2..~ ~__.,~ ~¢' I '~ b I- !~ I other requirements Condition's of approval - Sa'mple~'required [~ Y-es ~ No Mud]C'grequ~red F~ Yes [~-No Hydrogen sulfide measures DYes 'J~ NO Directional survey required ~ Yes [-- No Required workingpressureforBOPE [~ 2M [-" 3M ~, 5M [" 10M r~ 15M Other: "~,~'~" ~'O ~ '~) ~ ~'00 p Original Signea ,~:~ Dav, d W, Johnston by order of Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 . in triplicate Alaska Spacing Rules 5,280' 2,640' 2,640' 40' 2N 323 WELLBORE SCHEMATIC and CEMENT DESIGN 16" Conductor Casing at 135' MD / RKB permaf rost'~'~.i:i:!:i: 1,250' TVD Stage Collar 1,75O' MD Top of West Sak 1,200' TVD Base of West Sak 1,800' TVD 9-5/8" Surface Casing at 3,403' MD / RKB Top of Cement at 8,400' MD / RKB 7" Production Casing at ...... ...... .:.:.:.:.:.: 8,829' MD / RKB i:i:i:i:i:i: Production Casing at 9,829' MD / RKB :':5:: :.:.:.: .... :::::::. ,-.-. :i:i:i:!: 12~" Hole 8~" Hole ......-..... ......-.-... ......-..... ........-... ............ ......-.-... Conductor Casing Size / Hole Size Depth: 135' MD Top of Cement Surface Excess Calculated: 100% RKB 16" in 20" hole Volume Calculations: (135 If) (0.7854 cf/if) (2.00) = 212 cf (212 cf) /(0.93 cf/sx) = 228 sx Slurry Volume: 212 cf or ARCTICSET I 230 sx Slurry Weight 15.7 ppg rounded Slurry Yield 0.93 cf/sx Surface Casing Size / Hole Size Depth: 3,403' Top of Cement 0' Stage Collar: 1,750' Excess Calculated: 45% Stage 1 400% Stage 2 BHT (Static): 70-0 F BHT (Circ): 70-0 F Stage 1: Volume (1,653 l0 (0.3132 cf/If) (1.45) = 751 cf shoe joint vol 30 sx + (751 cO /(1.15 cf/sx) = 682 sx System: (Class G cement + 1% SI(CaCI2) + 0.3% D65 (disp.) + 0.2% D46 (defoamer) Slurry Volume: 785 cf or 690 sx Slurry Weight 15.8 ppg rounded Slurry Yield 1.15 cf/sx Thickeninc, I Time 3.5 - 4.5 hours 9-5/8" in 12-1/4" hole Surface Casing Stage 2: Volume (1,350 If) (0.3132 cf/If) (4.00) = 1,691 cf Lead (1,691 cf) /(4.42 cf/sx) = 380 sx (400 If) (0.3132 cf/10 (1.45) = 56 cf Tail (56 cf) /(0.93 cf/sx) = 60 sx System: Lead (Arctic Set 3 Lite cement + 3.5% D44 (NaCI) + 30% D53 (gyp) + 50% D124 (spheres) + 1% SI(CaCI2) + 1.5% D79 (ext.) + 0.4% D46 (defoamer) Tail (Arctic Set 1 cement ) Lead Slurry Volume: 1,691 cf or 380 sx Slurry Weight 10.5 ppg rounded Slurry Yield 4.42 cf/sx Thickening Time 6.0+ hours Tail Slurry Volume: 56 cf or 60 sx Slurry Weight 15.7 ppg rounded Slurry Yield 0.93 cf/sx Thickening Time 3.5 - 4.5 hours Production Casing Size ! Hole Size Depth: 9,829' Top of 4-1/2" casing 8,829' Top of Cement 8,400' Excess Calculated: 75% BHT (Static): 160-0 F BHT ( Circ): 130-0 F Volume around 7 " (429 If) (0.1268 cf/if) (1.75) = 95 cf Volume around 4-1/2" (1,000 If) (0.2836 cf/if) (1.75) = 496 cf 592 cf shoe joint vol 6 sx + (592 cf) /(1.20 cf/sx) = 499 sx 7" and 4-1/2" in 8-1/2" holel System: (Class G cement + 2 gps D600 (latex) + 0.1 gps D135 (stabilizer) + 0.1 D47 (defoamer) + 3% D53 (Gyp) + 0.7% D65 (disp) + 0.15% D800 (retarder) Slurry Volume: 592 cf or 500 sx Slurry Weight 15.8 ppg rounded Slurry Yield 1.20 cf/sx Thickenin~l Time 3.5 - 4.5 hours 4/2/98 ARCO Alaska, Inc. GENERAL DRILLING AND COMPLETION PROCEDURE KUPARUK RIVER FIELD - INJECTOR KRU 2N 323 11. ND BOPE and install production tree. 12. Shut in and secure well. 2N 323 MLP,04/03/98, v. 1 1. Move in and rig up Doyon 141. 2. Install diverter system. 3. Drill 12~A'' hole to 9-5/8" surface casing point (3,403'+ MD 2,500' TVD) according to the directional plan. 4. Run and cement 9-5/8" casing, using stage collar placed approximately 500' MD below the base of the permafrost. Use light weight lead cement in the first stage. 5. Install and test BOPE to 3,500 psi. Test casing to 2,000 psi. AOGCC Casing Test Pressure: (minimum is 1,500 psig) or Min. Test: Csg depth (TVD) * 0.25 psi/fi = (2,500' TVD) * (0.25 psi/fi) = 625 psi Maximum Test: 70% of Min. Yield Strength = (0.70) * (5,750 psi) = 4,025 psi 6. Drill out cement and 20' of new hole. Perform leak off test to 16.0 ppg EMW. This establishes a frac gradient equivalent. 7. Drill 8Y2" hole to TD (9,829' MD 5,286' TVD) according to directional plan. Run LWD logging equipment with density and porosity tools. Note: If significant hydrocarbon zones are present above the Tarn, sufficient cement will be pumped for isolation in accordance with 20 AAC 25.030(d)(3)(C). 8. Run and cement 7" L-80 BTC Csg X 4Y2" L-80 NSCT tapered production casing string with Baker casing seal receptacle at crossover point. 9. Pressure test casing to 3,000 psi. AOGCC Casing Test Pressure: (minimum is 1,500 psig) or Min. Test: Csg depth (TVD) * 0.25 psi/ft = (5,286' TVD) * (0.25 psi/fi) = 1,322 psi Maximum Test: 70% of Min. Yield Strength = (0.70) * (7,240 psi) = 5,070 psi Maximum Test: 70% of Min. Yield Strength = (0.70) * (8,440 psi) = 5,910 psi 10. Run 41/2'' L-80 NSCT completion assembly. Sting into polished seal bore with seal assembly and pressure test tubing and annulus to 3,000 psi. ARCO Alaska, Inc. 13. Clean location and RDMO in preparation for perforating. AOGCC Casing Testing Regulation 20 AAC 25.030. (g) Pressure Testing of Casing and Casing Surveys. (1) with the exception of structural and conductor casing, before drilling out the casing or liner after cementing, all casing, liners, and liner laps must be tested to a surface pressure of 1500 psig, or 0.25 psi/ft multiplied by the true vertical depth of the casing shoe, whichever is greater; however, surface pressure must not subject the casing to a hoop stress that will exceed 70 percent of the minimum yield strength of the casing. If the pressure declines more than 10 percent in 30 minutes, or if there are indications of improper cementing, such as lost returns, cement channeling, or mechanical failure of equipment, corrective measures must be taken. (2) when, in the commission's discretion, casing is subjected to prolonged actual drilling operations the casing must be pressure tested, calipered or otherwise evaluated by a method approved by the commission. (3) for injection wells, a cement bond Icg must be obtained following the primary cementing of all casing that is 9-5/8 inches or less in diameter, and sufficient notice of pressure tests required by (1) of this subsection must be given, so that a representative of the commission may witness the test. 2N 323 MLP,04/03/98, v. 1 ARCO Alaska, Inc. DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, AND DRILLING AREA RISKS Well KRU 2N 323 Drillincl Fluid Properties: Density PV YP Funnel Vis Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" surface casin¢ 9.5-1 O.2 ppg 15-35 25-50 130-150* 10-25 15-40 5-7 9.5-10 +_10% Drill out to TD 9.8 - 10.2 ppg 12-24 15-30 45-60 2-6 4-8 4-6 through Tarn 9.0-10 <11% Drillincl Fluid System: Triple Derrick Shale Shakers Desander, Desilter, Mud Cleaner Centrifuge Degasser IPit Level Indicator (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 130-150 sec/qt to drill gravel beds Drilling fluid practices will be in accordance with the regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: Maximum anticipated surface pressure (MASP) while drilling the 8-1/2" production hole is calculated using a surface casing leak-off of 13.5 ppg EMW (0.70 psi/ft) and a gas gradient of 0.11 psi/ff. This shows that formation breakdown would occur at a surface pressure of 1,750 psi. Therefore ARCO will test the BOP equipment to 3,000 psi after setting surface casing. MASP = (2,500 ft)(0.70 - 0.11) = 2,551 psi Based on offset well data, reservoir pressures in the Tarn sands in the vicinity of 2N pad are expected to be -2,400 psi (0.50 psi/ft). Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 10.0 ppg can be predicted as the maximum mud weight needed to safely drill in this formation, assuming a TVD of 4,970'. 2N 323 MLP, 04/02/98, v.1 ARCO Alaska, Inc. Well Proximity Risks: The nearest well to 2N 323 is the plugged and abandoned ARCO Tarn #3 about one mile to the north. This is the first well to be drilled on this new drillsite. Drillinq Area Risks: The primary risk in the 2N 323 drilling area is shallow gas below the permafrost. Therefore the surface hole will need to be drilled with weighted mud (9.5- 10.0 ppg) to avoid underbalancing the hole. Another observed problem in the area is lost circulation at arround 3,300' TVD and in the Tarn formation. Careful analysis of pressure data from offset wells shows that a mud weight of 10.0 ppg will provide sufficient overpressure to safely drill, trip pipe, and cement the well. The 9-5/8" casing shoe will be tested to leak-off, or to a maximum equivalent mud weight of 16.0 ppg upon drilling out of the casing. Annular Pumping Operations: Incidental fluids developed from drilling operations will be hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for an open annulus.) The open annulus will be left with a non-freezing fluid during any extended shut down (> 4 hr) in pumping operations. The 2N 323 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations on significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover the formation with significant hydrocarbons. We request that 2N 323 be permitted for annular pumping of fluids occurring as a result of drilling operations, per regulation 20 AAC 25.080. 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. Please reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 200' vertically below the base of the West Sak into the heart of the shales. 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) * (2,500') + 1,500 psi Max Pressure = 3,060 psi 2N 323 MLP, 04/02/98, v.1 ARCO Alaska, Inc. This pressure is conservative, since frictional losses while pumping have not been taken into consideration. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 19.-5/8" 40 L-80 3 BTC 3,090 psi 2,627 psi 5,750 psi 4,888 psi 7" 26 L-80 3 BTC-M 5,410 psi 4,599 psi 7,240 psi 6,154 psi 41/=" 12.6 L-80 3 NSCT 7,500 psi 6,375 psi 8,440 psi 7,174 psi Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). 2N 323 MLP, 04/02/98, v. 1 (-ID) ,08 ~ les Eldld uozonaNoo B~d ;dd igg ,,g [ :INI'I tlall:la^la OO ,,9 ~ ~IA'IVA ~I:IIN)! OI-lrlVSaAH ) elM !sd 00~ ,,9 L I:l~lJ.N~A~ll:id I:lV-lnNNV elM !sd O00'ig clSIAI -IlI:IQAH ,,% I.;~ I OU!IMOI-I lellnO ,,9 I./M -IOOdS DNl-I-~ll:la clM !sd O00'ig ,?A I.g L~, L uo,~oa o!leuJoqos JOlJOA!a ARCO KRU 2N 323 DOYON 141 13-5/8" 5,000 PSI BOP COMPONENTS 1 F 3" 5,000 psi WP OCT MANUAL GATE KILL LINE 3" 5,000 psi WP Shaffer GATE VALVE w/hydraulic actuator / 1 / DSA 13-5/8" 5,000 psi WP x 11" 3,000 psi WP \ I I 13-5/8" 5,000 psi WP, HYDRIL Type GK ANNULAR PREVENTER w/companion flange to bell nipple DOUBLE 13-5/8" 5,000 psi WP, HYDRIL Magnum BOP w/pipe rams on top and blind rams on bottom CHOKE LINE ~1~~o psi W P OCT ~J~ MANUAL GATE VALVE 13-5/8" 5,000 psi WP DRILLING SPOOL '~~ w/two 3" 5,000 psi WP outlets SINGLE 13-5/8" 5,000 psi WP, HYDRIL MPL BOP w/pipe ICreoted by iones FOF; M PrestridgeJ Dote plotted : 2-Apr-9~ Plot Reference is 323 Version i~', Coo~inotes ore in feet reference slot True Ve~icol Depth~~ RK~ (Do~on 14 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 Torn Drill Site 2N Well : 523 Development Field Location : North Slope, laska RKB Elevation: 149' ISURFACE LOCATION:I 68' FNL, 792' FEL SEC. 3, T9N, RTE KOP TVD=400 TMD=400 DEP=O ~.oo 297 47 AZIMUTH )TS~la TARGET LOCAT ON ' . . ~ i ~o~,~.~, ~,~,,,, I 7082' iT0 m^prz~m~ 1.00 ~ J SEC. 35, TION, RTE ~..~. 12.00 BEGIN TURN TO TARGET ~ TARGET ***Plane of Proposal*** 17.91 TVD=894 TMD=900 DEP=64 -~- TVD=5019 TD LOCATION: I ~ TMD=9214 23.79 DLS: 5.00 deg per 100 ft I 1830' FNL, 2290' FELi ~. OEP=70B2 i SEC. 53 TION, R7E [ ~ NORTH 3267 29.72 · ' ' ~ WEST 6284 55.67 41.63 47.60 53.58 9 5/8" CASING PT 1-VD=2500 TMD:3403 DEP=1846 ~~"~' ~.. AVERAGE ANGLE 64.31 DEG ¢ooo 3500 3000 2500 2000 1500 1000 500 0 500 TARGET TVD=5019 TMD=9gI4 DEP=70§;8 TD - CASING PT TVD=5286 TMD=9829 DEP=?636 0 400 800 1200 1600 2000 2400 2800 3200 3600 4000 4400 4800 5200 5600 6000 6400 6800 7200 7600 8000 Vertical Section (feet) -> Azimuth 297.47 with reference 0.00 N, 0.00 E from slot #323 <- West (feet) 7000 6~00 6000 s~oo 5000 4500 ,000 ~soo ~000 2soo 2000 ,500 1000 soo 0 800 Creoted by jones For: M Prestridge Dote plotted: 2-Apr-S§ Plot. Reference is 52,1 Version ~3. [ J Coordinates are in feet reference slot ~325. [ ARCO Alaska, I c. Structure : Torn Drill Site 2N Well : 323 Field : Torn Development Field Locotion : North Slope, Alosko 1 ~oo 200 lOOO 800 600 I 4-00 '-4--- ,+-- 200 0 200 4-0O 600 8OO lOOO <- West (feet) 4-200 4-000 ,5800 ,5600 ,54-00 ,5200 `5000 2800 2600 2400 2200 2000 1800 1600 14-00 1200 1000 800 600 4-00 200 0 200 4-00 "-. 3000 .. -,,. 2900 -~ 2800 '-... "-.. 2700 "--. 2600 5100 ............ 3000 ~900 ....................... ~z____ 28002700 ~ ,.,,~ 26OO ....... a__ 2400 '- 2400 .. '"-., 2300 "-.~ 2200 -.. '"'"., 2000 '"'-.. 1900 '"-.. 1800 "-...1700 2300 '-. 2200 2100 --.. 1500 ......................... 1900 '"-. 1300 ';L;'.' ,:~::..~,;~,,,,~.~, ' ............... 1700 1 500 "-.. 11 O0 ;.~,~ ,~,~:,t!:;..~ ' ........... 1 '""""' 900 ..... ..~ ',~ ~ ~~.~, ~~~~' ............ ~ ..... ~o- ...................... ~/00 ~ ~000 ............. ' ~00 .............. ~00 ~ .... - ......=' ~Oo~Oo~~oo~00 .___~ ...... ' .......~ .......-' ....."'"-~'""'"~'""~'"" ~000/~O~/~Off~O 14-00 1200 1000 -- t i [ ] i i i i i t i i i i i i i i i i i i s i i i i i ] i i t [ i i i i i I i i i i i i ] 4200 4000 ..3800 3600 ...'3400 .3200 .3000 2800 2600 2400 2200 2000 1800 1600 14.00 1200 1000 800 600 400 200 0 200 4-00 <- West (feet) 80O 60O 400 I Z 0 200 o ...q. 200 4OO 6OO 800 1 ooo ANCO Alaska, Structure : Tarn Drill Site 2N Well : Fled : Tarn Development Field Location : North Slope, AlaskaJ WELL ..... Point MD Ir~ Tie on 0.00 0.00 End of Turn 400.00 0.00 KOP 900.00 15.00 End of Build/Turn 2558.73 64.51 Target 2N-L (P) 18-Feb 921`5.75 64..51 End of Hold 9628.74 64.31 T.D. & End of Hold 9828.74 64.51 PROFILE DATA Dir TVD North East V. Sect Dog/1 O0 0,00 0.00 0.00 0.00 0.00 0.00 310,00 400.00 0.00 0.00 0.00 0.00 310.00 894.31 41.83 -49.85 63.53 3.00 296.93 2133.90 550.68 -9.57.09 1085.46 3.00 296.9`5 5019.20 3266.70 -628`5.81 7082.20 0.01 296.93 5199.13 3436.07 -6617.24 74-56.17O.O0 296.93 5285.84 3517.69 -6777.92 7636.38 0.00 52O 33O 340 E NORTH 350 32000 1 0 210 260O 3O 310 Created by janes For: M Prestridge] Oote platted : 2-Apr--g8 Plot Reference is ,:323 Version -~3. Coordinates are in feet reference slot ~323. True Ve~col Depths~ RKB (Ooyon 141)] 1700 4O 500 29O 7O 280 8O 27O O0 5OO 9O 26O lO0 25O 110 240 1100 1 10C 190 180 170 3200 160 150 140 130 120 Normal Plane Travelling Cylinder - Feet All depths shown are Measured depths on Reference Well ARCO Alaska, Inc. Tarn Drill Site 2N 323 slot #323 Tarn Development Field North Slope, Alaska PROPOSAL LISTING INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref = 323 Version #3 Our ref : prop2849 License : Date printed : 2-Apr-98 Date created : 27-Feb-98 Last revised : 2-Apr-98 Field is centred on n70 12 49.742,w150 18 33.414 Structure is centred on nT0 10 13.955,w150 18 32.772 Slot location is n70 10 13.290,w150 18 55.720 Slot Grid coordinates are N 5911939.777, E 460800.935 Slot local coordinates are 67.57 S 792.13 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North ARCO Alaska, Inc. Tarn Drill Site 2N, 323 Tarn Development Field,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C O O R D I N A T E S 0.00 0.00 0.00 0.00 0.00 N 0.00 E 100.00 0.00 310.00 100.00 0.00 N 0.00 E 200.00 0.00 310.00 200.00 0.00 N 0.00 E 300.00 0.00 310.00 300.00 0.00 N 0.00 E 400.00 0.00 310.00 400.00 0.00 N 0.00 E 500.00 3.00 310.00 499.95 1.68 N 2.01 W 600.00 6.00 310.00 599.63 6.73 N 8.01 W 700.00 9.00 310.00 698.77 15.11 N 18.01 W 800.00 12.00 310.00 797.08 26.83 N 31.97 W 900.00 15.00 310.00 894.31 41.83 N 49.85 W 1000.00 17.91 307.40 990.20 59.49 N 71.98 W 1100.00 20.84 305.50 1084.53 79.16 N 98.69 W 1200.00 23.79 304.06 1177.03 100.80 N 129.89 W 1300.00 26.75 302.92 1267.45 124.33 N 165.50 W 1400.00 29.72 301.99 1355.54 149.70 N 205.43 W 1500.00 32.69 301.21 1441.06 176.83 N 249.56 W 1600.00 35.67 300.56 1523.78 205.66 N 297.78 W 1700.00 38.65 299.99 1603.46 236.10 N 349.94 W 1800.00 41.63 299.49 1679.90 268.06 N 405.92 W 1900.00 44.62 299.04 1752.88 301.47 N 465.55 W 2000.00 47.60 298.65 1822.20 336.23 N 528.67 W 2100.00 50.59 298.28 1887.67 372.25 N 595.11 W 2200.00 53.58 297.95 1949.11 409.42 N 664.69 W 2300.00 56.57 297.64 2006.35 447.64 N 737.22 W 2400.00 59.56 297.35 2059.24 486.82 N 812.49 W 2500.00 62.55 297.08 2107.63 526.83 N 890.30 W 2558.73 64.31 296.93 2133.90 550.68 N 937.09 W 3000.00 64.31 296.93 2325.22 730.77 N 1291.62 W 3403.14 64.31 296.93 2500.00 895.30 N 1615.51 W 3500.00 64.31 296.93 2541.99 934.83 N 1693.32 W 4000.00 64.31 296.93 2758.77 1138.89 N 2095.03 W 4500.00 64.31 296.93 2975.55 1342.95 N 2496.74 W 5000.00 64.31 296.93 3192.32 1547.00 N 2898.44 W 5500.00 64.31 296.93 3409.10 1751.06 N 3300.15 W 6000.00 64.31 296.93 3625.88 1955.12 N 3701.86 W PROPOSAL LISTING Page 1 Your ref = 323 Version #3 Last revised ~ 2-Apr-98 Dogleg Vert Deg/100ft Sect 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 KOP 3.00 2.56 3.00 10.21 3.00 22.95 3.00 40.74 3.00 63.53 3.00 91.31 3.00 124.08 3.00 161.74 3.00 204.19 3.00 251.32 3.00 302.99 3.00 359.07 3.00 419.39 3.00 483.80 3.00 552.12 Begin Turn to Target 3.00 624.16 3.00 699.73 3.00 778.61 3.00 860.58 3.00 945.44 6500.00 64.31 296.93 3842.65 2159.18 N 4103.56 W 0.00 4636.89 7000.00 64.31 296.93 4059.43 2363.24 N 4505.27 W 0.00 5087.44 7500.00 64.31 296.93 4276.21 2567.30 N 4906.98 W 0.00 5537.98 8000.00 64.31 296.93 4492.98 2771.36 N 5308.68 W 0.00 5988.52 8500.00 64.31 296.93 4709.76 2975.41 N 5710.39 W 0.00 6439.07 3.00 1032.94 3.00 1085.46 EOC 0.00 1483.08 0.00 1846.35 9 5/8" Casing Pt 0.00 1933.63 0.00 2384.17 ~- -,, }~z~,.~-:V ~1 ~J 0.00 2834.72 0.00 3285.26 o.oo ~.~ .... .~. 9000.00 64.31 296.93 4926.54 3179.47 N 6112.10 W 0.00 6889.61 9213.72 64.31 296.93 5019.19 3266.69 N 6283.80 W 0.00 7082.19 TARGET 9213.73 64.31 296.93 5019.20 3266.70 N 6283.81 W 0.01 7082.20 2N-L (P) lS-Feb-9S 9500.00 64.31 296.93 5143.31 3383.53 N 6513.80 W 0.00 7340.16 9628.74 64.31 296.93 5199.13 3436.07 N 6617.24 W 0.00 7456.17 ~O~0~% ~ ~ ~ (~--~,~J~4.- 9828.74 64.31 296.93 5285.84 3517.69 N 6777.92 W 0.00 7636.38 TD - 7" Casing Pt All data is in feet unless otherwise stated. Coordinates from slot #323 and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 7636.38 on azimuth 297.43 degrees from wellhead. Total Dogleg for wellpath is 64.76 degrees. Vertical section is from wellhead on azimuth 297.47 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N, 323 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref = 323 Version Last revised = 2-Apr-98 Comments in wellpath MD TVD Rectangular Coords. Comment 400.00 %00.00 0.00 N 0.00 E KOP 900.00 894.31 41.83 N 49.85 W Begin Turn to Target 2558.73 2133.90 550.68 N 937.09 W EOC 3403.14 2500.00 895.30 N 1615.51 W 9 5/8" Casing Pt 9213.72 5019.19 3266.69 N 6283.80 W TARGET 9213.73 5019.20 3266.70 N 6283.81 W 2N-L (P) 18-Feb-98 9828.74 5285.84 3517.69 N 6777.92 W TD - 7" Casing Pt Casing positions in string Top MD Top TVD ~ectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 3403.14 2500.00 895.30N 1615.51W 9 5/8" Casing 0.00 0.00 0.00N 0.00E 9828.?4 5285.84 3517.69N 6777.92W 7" Casing Targets associated with this we11path Target name Geographic Location T.V.D. Rectangular Coordinates Revised 2N-L (P) 18-Feb-98 454534.400,5915238.000,0.0000 5019.20 3266.?0N 6283.81W 6-Aug-97 ARCO Alaska, Inc. Tarn Drill Site 2N, 323 Tarn Development Field,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A Depth Degrees Degrees Depth C 00 R D PROPOSAL LISTING Page 1 Your ref : 323 Version #3 Last revised : 2-Apr-98 N G U L A R Dogleg Vert I N A T E S Deg/100ft Sect 0.00 0.00 0.00 0.00 67.57 S 792.13 W 0.00 0.00 100.00 0.00 310.00 100.00 67.57 S 792.13 W 0.00 0.00 200.00 0.00 310.00 200.00 67.57 S 792.13 W 0.00 0.00 300.00 0.00 310.00 300.00 67.57 S 792.13 W 0.00 0.00 400.00 0.00 310.00 400.00 67.57 S 792.13 W 0.00 0.00 500.00 3.00 310.00 499.95 65.89 S 794.13 W 3.00 2.56 600.00 6.00 310.00 599.63 60.85 S 800.14 W 3.00 10.21 700.00 9.00 310.00 698.77 52.46 S 810.14 W 3.00 22.95 800.00 12.00 310.00 797.08 40.75 S 824.10 W 3.00 40.74 900.00 15.00 310.00 894.31 25.74 S 841.98 W 3.00 63.53 1000.00 17.91 307.40 990.20 8.08 S 864.11 W 3.00 91.31 1100.00 20.84 305.50 1084.53 11.59 N 890.81 W 3.00 124.08 1200.00 23.79 304.06 1177.03 33.22 N 922.02 W 3.00 161.74 1300.00 26.75 302.92 1267.45 56.75 N 957.63 W 3.00 204.19 1400.00 29.72 301.99 1355.54 82.12 N 997.56 W 3.00 251.32 1500.00 32.69 301.21 1441.06 109.26 N 1041.69 W 3.00 302.99 1600.00 35.67 300.56 1523.78 138.08 N 1089.90 W 3.00 359.07 1700.00 38.65 299.99 1603.46 168.52 N 1142.07 W 3.00 419.39 1800.00 41.63 299.49 1679.90 200.49 N 1198.04 W 3.00 483.80 1900.00 44.62 299.04 1752.88 233.90 N 1257.68 W 3.00 552.12 2000.00 47.60 298.65 1822.20 268.66 N 1320.80 W 3.00 624.16 2100.00 50.59 298.28 1887.67 304.67 N 1387.24 W 3.00 699.73 2200.00 53.58 297.95 1949.11 341.84 N 1456.82 W 3.00 778.61 2300.00 56.57 297.64 2006.35 380.07 N 1529.34 W 3.00 860.58 2400.00 59.56 297.35 2059.24 419.24 N 1604.61 W 3.00 945.44 KOP Begin Turn to Target 2500.00 62.55 297.08 2107.63 459.26 N 1682.42 W 3.00 1032.94 2558.73 64.31 296.93 2133.90 483.11 N 1729.22 W 3.00 1085.46 EOC 3000.00 64.31 296.93 2325.22 663.20 N 2083.74 W 0.00 1483.08 3403.14 64.31 296.93 2500.00 827.73 N 2407.63 W 0.00 1846.35 9 5/8" Casing Pt 3500.00 64.31 296.93 2541.99 867.26 N 2485.45 W 0.00 1933.63 4000.00 64.31 296.93 2758.77 1071.31 N 2887.16 W 0.00 2384.17 4500.00 64.31 296.93 2975.55 1275.37 N 3288.86 W 0.00 2834.72 5000.00 64.31 296.93 3192.32 1479.43 N 3690.57 W 0.00 3285.26 5500.00 64.31 296.93 3409.10 1683.49 N 4092.28 W 0.00 3735.80 6000.00 64.31 296.93 3625.88 1887.55 N 4493.98 W 0.00 4186.35 6500.00 64.31 296.93 3842.65 2091.61 N 4895.69 W 0.00 4636.89 7000.00 64.31 296.93 4059.43 2295.66 N 5297.40 W 0.00 5087.44 7500.00 64.31 296.93 4276.21 2499.72 N 5699.10 W 0.00 5537.98 8000.00 64.31 296.93 4492.98 2703.78 N 6100.81 W 0.00 5988.52 8500.00 64.31 296.93 4709.76 2907.84 N 6502.52 W 0.00 6439.07 9000.00 64.31 296.93 4926.54 3111.90 N 6904.22 W 0.00 6889.61 9213.72 64.31 296.93 5019.19 3199.12 N 7075.93 W 0.00 7082.19 TARGET 9213.73 64.31 296.93 5019.20 3199.13 N 7075.94 W 0.01 7082.20 2N-L (P) 18-Feb-98 9500.00 64.31 296.93 5143.31 3315.96 N 7305.93 W 0.00 7340.16 9628.74 64.31 296.93 5199.13 3368.50 N 7409.36 W 0.00 7456.17 9828.74 64.31 296.93 5285.84 3450.12 N 7570.04 W 0.00 7636.38 TD - 7" Casing Pt All data is in feet unless otherwise stated. Coordinates from SE Corner of Sec. 34, T10N, RTE and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 7636.38 on azimuth 297.43 degrees from wellhead. Total Dogleg for wellpath is 64.76 degrees. Vertical section is from wellhead on azimuth 297.47 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N,323 Tarn Development Field,North Slope, Alaska ~ROPOSAL LISTING Page 2 Your ref = 323 Version #3 Last revised = 2-Apr-98 Comments in we11path MD TVD Rectangular Coords. Comment 400.00 400 00 67 57 S 792.13 W KOP 900.00 894 31 25 74 S 841.98 W Begin Turn to Target 2558.73 2133 90 483 11 N 1729.22 W EOC 3403.14 2500 00 827 73 N 2407.63 W 9 5/8" Casing Pt 9213.72 5019 19 3199 12 N 7075.93 W TARGET 9213.73 5019 20 3199 13 N 7075.94 W 2N-L (P) 1S-Feb-98 9828.74 5285 84 3450 12 N 7570.04 W TD - 7" Casing Pt Casing positions in string Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 67.57S 792.13W 3403.14 2500.00 827.73N 2407.63W 9 5/8" Casing 0.00 0.00 67.57S 792.13W 9828.74 5285.84 3450.12N 7570.04W 7" Casing Targets associated with this we11path Target name Geographic Location T.V.D. Rectangular Coordinates Revised 2N-L (P) 18-Feb-98 454534.400,5915238.000,0.0000 5019.20 3199.13N 7075.94W 6-Aug-97 ARCO Alaska, Inc. Tarn Drill Site 2N,323 Tarn Development Field,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A Depth Degrees Degrees Depth C O O R D PROPOSAL LISTING Page 1 Your ref = 323 Version Last revised : 2-Apr-98 N G U L A R Vert Ellipse Semi Axes Minor I N A T E S Sect Major Minor Vert. Azi. 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 0.00 0.00 N/A 100.00 0.00 310.00 100.00 0.00 N 0.00 E 0.00 0.26 0.26 0.15 N/A 200.00 0.00 310.00 200.00 0.00 N 0.00 E 0.00 0.52 0.52 0.30 N/A 300.00 0.00 310.00 300.00 0.00 N 0.00 E 0.00 0.78 0.78 0.45 N/A 400.00 0.00 310.00 400.00 0.00 N 0.00 E 0.00 1.04 1.04 0.60 N/A 500.00 3.00 310.00 499.95 1.68 N 2.01 W 2.56 1.32 1.31 0.75 310.00 600.00 6.00 310.00 599.63 6.73 N 8.01 W 10.21 1.66 1.58 0.90 310.00 700.00 9.00 310.00 698.77 15.11 N 18.01 W 22.95 2.14 1.86 1.05 310.00 800.00 12.00 310.00 797.08 26.83 N 31.97 W 40.74 2.82 2.16 1.21 310.00 900.00 15.00 310.00 894.31 41.83 N 49.85 W 63.53 3.73 2.48 1.37 310.00 1000.00 17.91 307.40 990.20 59.49 N 71.98 W 91.31 4.89 2.83 1.55 309.21 1100.00 20.84 305.50 1084.53 79.16 N 98.69 W 124.08 6.33 3.21 1.74 308.21 1200.00 23.79 304.06 1177.03 100.80 N 129.89 W 161.74 8.07 3.62 1.94 307.18 1300.00 26.75 302.92 1267.45 124.33 N 165.50 W 204.19 10.13 4.06 2.18 306.21 1400.00 29.72 301.99 1355.54 149.70 N 205.43 W 251.32 12.54 4.52 2.45 305.31 1500.00 32.69 301.21 1441.06 176.83 N 249.56 W 302.99 15.32 5.01 2.75 304.51 1600.00 35.67 300.56 1523.78 205.66 N 297.78 W 359.07 18.48 5.52 3.10 303.78 1700.00 38.65 299.99 1603.46 236.10 N 349.94 W 419.39 22.04 6.04 3.50 303.12 1800.00 41.63 299.49 1679.90 268.06 N 405.92 W 483.80 26.00 6.58 3.96 302.53 1900.00 44.62 299.04 1752.88 301.47 N 465.55 W 552.12 30.38 7.12 4.46 301.99 2000.00 47.60 298.65 1822.20 336.23 N 528.67 W 624.16 35.18 7.66 5.03 301.51 2100.00 50.59 298.28 1887.67 372.25 N 595.11 W 699.73 40.39 8.20 5.65 301.07 2200.00 53.58 297.95 1949.11 409.42 N 664.69 W 778.61 46.00 8.73 6.32 300.67 2300.00 56.57 297.64 2006.35 447.64 N 737.22 W 860.58 52.02 9.25 7.05 300.30 2400.00 59.56 297.35 2059.24 486.82 N 812.49 W 945.44 58.41 9.74 7.83 299.96 2500.00 62.55 297.08 2107.63 526.83 N 890.30 W 1032.94 65.16 10.21 8.66 299.65 2558.73 64.31 296.93 2133.90 550.68 N 937.09 W 1085.46 69.25 10.48 9.17 299.48 3000.00 64.31 296.93 2325.22 730.77 N 1291.62 W 1483.08 100.12 12.47 13.01 298.67 3403.14 64.31 296.93 2500.00 895.30 N 1615.51 W 1846.35 128.45 14.28 16.55 298.30 3500.00 64.31 296.93 2541.99 934.83 N 1693.32 W 1933.63 135.26 14.71 17.40 298.21 4000.00 64.31 296.93 2758.77 1138.89 N 2095.03 W 2384.17 170.47 16.95 21.80 297.94 4500.00 64.31 296.93 2975.55 1342.95 N 2496.74 W 2834.72 205.72 19.19 26.21 297.76 5000.00 64.31 296.93 3192.32 1547.00 N 2898.44 W 3285.26 240.98 21.42 30.62 297.64 5500.00 64.31 296.93 3409.10 1751.06 N 3300.15 W 3735.80 276.26 23.65 35.04 297.55 6000.00 64.31 296.93 3625.88 1955.12 N 3701.86 W 4186.35 311.54 25.88 39.45 297.48 6500.00 64.31 296.93 3842.65 2159.18 N 4103.56 W 4636.89 346.83 28.11 43.87 297.42 7000.00 64.31 296.93 4059.43 2363.24 N 4505.27 W 5087.44 382.13 30.34 48.29 297.38 7500.00 64.31 296.93 4276.21 2567.30 N 4906.98 W 5537.98 417.42 32.57 52.71 297.34 8000.00 64.31 296.93 4492.98 2771.36 N 5308.68 W 5988.52 452.72 34.80 57.13 297.31 8500.00 64.31 296.93 4709.76 2975.41 N 5710.39 W 6439.07 488.02 37.03 61.55 297.28 9000.00 64.31 296.93 4926.54 3179.47 N 6112.10 W 6889.61 523.32 39.26 65.97 297.25 9213.72 64.31 296.93 5019.19 3266.69 N 6283.80 W 7082.19 538.41 40.21 67.86 297.25 9213.73 64.31 296.93 5019.20 3266.70 N 6283.81 W 7082.20 538.41 40.21 67.86 297.25 9500.00 64.31 296.93 5143.31 3383.53 N 6513.80 W 7340.16 558.63 41.49 70.39 297.23 9628.74 64.31 296.93 5199.13 3436.07 N 6617.24 W 7456.17 567.72 42.06 71.53 297.23 9828.74 64.31 296.93 5285.84 3517.69 N 6777.92 W 7636.38 581.84 42.95 73.30 297.22 All data is in feet unless otherwise stated. Coordinates from slot #323 and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 7636.38 on azimuth 297.43 degrees from wellhead. Vertical section is from wellhead on azimuth 297.47 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N, 323 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : 323 version #3 Last revised : 2-Apr-98 POSITION UNCERTAINTY SUMMARY ..... ========================= Depth Position Uncertainty From To Survey Tool Error Model Major Minor Vert. 0 9829 ARCO (H.A. Mag) User specified 581.84 42.95 73.30 1. Ellipse dimensions are half axis. 2. Casing dimensions are not included. 3. Ellipses are calculated on 2.58 standard deviations. 4. Uncertainty calculations start at drill depth zero. 5. Surface position uncertainty is not included. 6. Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trak manual. Comments in wellpath MD TVD Rectangular Coords. Comment 400.00 400.00 0.00 N 0.00 E KOP 900.00 894.31 41.83 N 49.85 W BeginTurn to Target 2558.73 2133.90 550.68 N 937.09 W EOC 3403.14 2500.00 895.30 N 1615.51 W 9 5/8" Casing Pt 9213.72 5019.19 3266.69 N 6283.80 W TARGET 9213.73 5019.20 3266.70 N 6283.81 W 2N-L (P) 18-Feb-98 9828.74 5285.84 3517.69 N 6777.92 W TD - 7" Casing Pt Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 3403.14 2500.00 895.30N 1615.51W 9 5/8" Casing 0.00 0.00 0.00N 0.00E 9828.74 5285.84 3517.69N 6777.92W 7" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 2N-L (P) 18-Feb-98 454534.400,5915238.000,0.0000 5019.20 3266.70N 6283.81W 6-Aug-97 ARCO Alaska, Inc. Tarn Drill Site 2N, 323 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : 323 Version Last revised : 2-Apr-98 Measured Inclin Azimuth True Vert R E C T A N G U L A R Dogleg Vert G R I D C O 0 R D S Depth Degrees Degrees Depth C O O R D I N A T E S Deg/100ft Sect Eastlng Northing 0.00 0.00 0.00 0.00 0.00N 0.00E 0.00 0.00 460800.93 5911939.78 100.00 0.00 310.00 100.00 0.00N 0.00E 0.00 0.00 460800.93 5911939.78 200.00 0.00 310.00 200.00 0.00N 0.00E 0.00 0.00 460800.93 5911939.78 300.00 0.00 310.00 300.00 0.00N 0.00E 0.00 0.00 460800.93 5911939.78 400.00 0.00 310.00 400.00 0.00N 0.00E 0.00 0.00 460800.93 5911939.78 500.00 3.00 310.00 499.95 1.68N 2.01W 3.00 2.56 460798.94 5911941.47 600.00 6.00 310.00 599.63 6.73N 8.01W 3.00 10.21 460792.96 5911946.54 700.00 9.00 310.00 698.77 15.11N 18.01W 3.00 22.95 460783.00 5911954.98 800.00 12.00 310.00 797.08 26.83N 31.97W 3.00 40.74 460769.10 5911966.76 900.00 15.00 310.00 894.31 41.83N 49.85W 3.00 63.53 460751.30 5911981.86 1000.00 17.91 307.40 990.20 59.49N 71.98W 3.00 91.31 460729.26 5911999.63 1100.00 20.84 305.50 1084.53 79.16N 98.69W 3.00 124.08 460702.66 5912019.43 1200.00 23.79 304.06 1177.03 100.80N 129.89W 3.00 161.74 460671.57 5912041.22 1300.00 26.75 302.92 1267.45 124.33N 165.50W 3.00 204.19 460636.08 5912064.93 1400.00 29.72 301.99 1355.54 149.70N 205.43W 3.00 251.32 460596.29 5912090.50 1500.00 32.69 301.21 1441.06 176.83N 249.56W 3.00 302.99 460552.30 5912117.85 1600.00 35.67 300.56 1523.78 205.66N 297.78W 3.00 359.07 460504.24 5912146.92 1700.00 38.65 299.99 1603.46 236.10N 349.94W 3.00 419.39 460452.23 5912177.62 1800.00 41.63 299.49 1679.90 268.06N 405.92W 3.00 483.80 460396.42 5912209.87 1900.00 44.62 299.04 1752.88 301.47N 465.55W 3.00 552.12 460336.97 5912243.58 2000.00 47.60 298.65 1822.20 336.23N 528.67W 3.00 624.16 460274.03 5912278.65 2100.00 50.59 298.28 1887.67 372.25N 595.11W 3.00 699.73 460207.78 5912315.00 2200.00 53.58 297.95 1949.11 409.42N 664.69W 3.00 778.61 460138.39 5912352.52 2300.00 56.57 297.64 2006.35 447.64N 737.22W 3.00 860.58 460066.07 5912391.11 2400.00 59.56 297.35 2059.24 486.82N 812.49W 3.00 945.44 459991.01 5912430.66 2500.00 62.55 297.08 2107.63 526.83N 890.30W 3.00 1032.94 459913.41 5912471.07 2558.73 64.31 296.93 2133.90 550.68N 937.09W 3.00 1085.46 459866.74 5912495.15 3000.00 64.31 296.93 2325.22 730.77N 1291.62W 0.00 1483.08 459513.17 5912677.02 3403.14 64.31 296.93 2500.00 895.30N 1615.51W 0.00 1846.35 459190.15 5912843.18 3500.00 64.31 296.93 2541.99 934.83N 1693.32W 0.00 1933.63 459112.54 5912883.10 4000.00 64.31 296.93 2758.77 1138.89N 2095.03W 0.00 2384.17 458711.92 5913089.17 4500.00 64.31 296.93 2975.55 1342.95N 2496.74W 0.00 2834.72 458311.29 5913295.24 5000.00 64.31 296.93 3192.32 1547.00N 2898.44W 0.00 3285.26 457910.66 5913501.32 5500.00 64.31 296.93 3409.10 1751.06N 3300.15W 0.00 3735.80 457510.04 5913707.39 6000.00 64.31 296.93 3625.88 1955.12N 3701.86W 0.00 4186.35 457109.41 5913913.47 6500.00 64.31 296.93 3842.65 2159.18N 4103.56W 0.00 4636.89 456708.78 5914119.54 7000.00 64.31 296.93 4059.43 2363.24N 4505.27W 0.00 5087.44 456308.16 5914325.61 7500.00 64.31 296.93 4276.21 2567.30N 4906.98W 0.00 5537.98 455907.53 5914531.69 8000.00 64.31 296.93 4492.98 2771.36N 5308.68W 0.00 5988.52 455506.91 5914737.76 8500.00 64.31 296.93 4709.76 2975.41N 5710.39W 0.00 6439.07 455106.28 5914943.84 9000.00 64.31 296.93 4926.54 3179.47N 6112.10W 0.00 6889.61 454705.65 5915149.91 9213.72 64.31 296.93 5019.19 3266.69N 6283.80W 0.00 7082.19 454534.41 5915238.00 9213.73 64.31 296.93 5019.20 3266.70N 6283.81W 0.01 7082.20 454534.40 5915238.00 9500.00 64.31 296.93 5143.31 3383.53N 6513.80W 0.00 7340.16 454305.03 5915355.99 9628.74 64.31 296.93 5199.13 3436.07N 6617.24W 0.00 7456.17 454201.87 5915409.05 9828.74 64.31 296.93 5285.84 3517.69N 6777.92W 0.00 7636.38 454041.62 5915491.47 All data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #323 and TVD from RKB (Doyon 141) (149.00 Ft above mean sea level). Bottom hole distance is 7636.38 on azimuth 297.43 degrees from wellhead. Total Dogleg for wellpath is 64.76 degrees. Vertical section is from wellhead on azimuth 297.47 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ ARCO Alaska, Inc. Tarn Drill Site 2N,323 Tarn Development Field,North Slope, Alaska PROPOSAL LISTING Page 2 Your ref : 323 Version #3 Last revised : 2~Apr-98 Comments in wellpath MD TVD Rectangular Coords. Comment 400.00 400.00 0.00N 0.00E KOP 900.00 894.31 41.83N 49.85W Begin Turn to Target 2558.73 2133.90 550.68N 937.09W EOC 3403.14 2500.00 895.30N 1615.51W 9 5/8" Casing Pt 9213.72 5019.19 3266.69N 6283.80W TARGET 9213.73 5019.20 3266.70N 6283.81W 2N-L (P) 18-Feb-98 9828.74 5285.84 3517.69N 6777.92W TD ~ 7" Casing Pt Casing positions in string 'A' ============================== Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 3403.14 2500.00 895.30N 1615.51W 9 5/8" Casing 0.00 0.00 0.00N 0.00E 9828.74 5285.84 3517.69N 6777.92W 7" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 2N-L (P) 18-Feb-98 454534.400,5915238.000,0.0000 5019.20 3266.70N 6283.81W 6-Aug-97 ARCO Alaska, I, ~.... Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 3, 1998 David W. Johnston, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Re: Application for Permit to Drill KRU 2N-323 Surface Location: 68' FNL 792' FEL Sec 3 T9N R7E, UM Bottom Hole Location: 1,830' FNL 2,290' FWL Sec 33 T10N R7E, tiM Dear Commissioner Johnston, ARCO Alaska, Inc. hereby files this Application for Permit to Drill its first onshore development well in the Tarn area, KRU 2N 323, located approximately seven miles southwest of the Kupamk River Unit's 2M Drillsite. The drilling order of the wells has changed since the first application submitted required a spacing exception. This well will be accessed via a new gravel road originating at 2M Pad. It will be drilled and evaluated using Doyon Rig 141. If the well is commercial, it will completed with Doyon 141 also. This is the first of approximately 20 wells to be drilled to Tarn objectives during 1998. Attached find the information required by 20 AAC 25.005(c) and 20 AAC 25.061. This well will reach total depth at a point that is within 500' of a quarter section line in the middle of Section 33. However, consistent with 20 AAC 25.055(a)(3), the perforated interval is greater than the 500' from the quarter section line (see attached diagram and directional calculations). There will be no reserve pit for this well. All waste drilling mud and cuttings generated during the drilling of this well will be either stored temporarily onsite or hauled to an approved Class II injection well inside the Kuparuk River Unit. If not handled inside the KRU, they will be taken to the Prudhoe Bay Field for temporary storage and eventual processing for injection down an approved disposal well. The TD of this well will be in the Tam formation' which is similar in depth to the Kuparuk Formation. H2S has not been encountered in this region in any stratum shallower than the Lisburne Formation. Therefore, ARCO has not included an H2S contingency plan with this Application and requests an exemption from the H2S requirements. However, all drilling mud, cores and produced fluids exiting the wellbore will be monitored for detectable levels of H2S ARC(~:~ ~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany David W. Johnston Application for Permit to Drill Page 2 KRU 2N-323 exception to the shale density requirement in 20 AAC 25.033(e, 2, D). The shale density technique does not work well in Alaska due to the variable composition of the shales, and the chemical used in the shale density determination is listed as an exceptional health hazard. The following are ARCO's designated contacts for reporting responsibilities to the Commission: 1) Weekly Status Report Fred Johnson, Drilling Engineer 265-1492 2) Completion Report (20 AAC 25.070) Fred Johnson, Drilling Engineer 265-1492 3) Geologic Data and Logs Doug Hastings, Geologist (20 AAC 25.071) 265-6967 If you have questions or require additional information, please contact Fred Johnson at the number above or myself at 265-6206 in our Anchorage office. SinCerely, / Mik~~ Drilling 8~lta6hntendent Kuparuk Drillsite Development Attachments cc: KRU 2N-323 Well File · WELL PERMIT CHECKLIST COMPANY _.~'~(~ WELL NAME/'~_.'~?.~. ~-%~-.,°-3 FIELD&POOL__ INI-f CLASS ~/~ ~-L~ -'/"" ~:~: 2 GEOL AREA ~" ?' _,,~ ADMINISTRATION ENGINEERING PROGRAM: exp D dev~redrll [] serv I-1 wellbore seg [ ann. disposal para reg~ UNIT# ON/OFF SHORE O ~ I 4 5 6. 7 8 9 10 tl 12 13. REMARKS li'rrr~filllumbertee attached appropriate' ~Y' N ............................................................................................... ease . ,.,.,,,.,, · Unique well name and nurr~ber. . . ~.~,2~- .~.~/~..~ .... Well located in a defined pool .............. Well located proper distance from drilling unil boundary. <:~'. . Well located proper distance from other wells ......... S,,fficienl acreage available in drilling ,,nit . N .,~~ ..... ~~_ ~ "/"'__.~ .... ~___~ ___~,,,~..'_~_. ~_..,.~,~_~ .............. If devialed, is wellbore ptat included ' . Operator or'fly affected party Operator has appropriate bond in force.. (_.~N l-.~ernfil can be issued witl~out conservalion order'. ~N ..... Permit can be issued without administrative approval N (.;a~ permit be approved before 15-day wait ...... N ......... 14 Conductor string provided ....... ~ N 15 S~rface casing protects all known USDWs ..... ~ N 16 CMT vol adequale to circulate on conductor & surf csg .... N 17. CMl" vol adequate to tie-in long string to surf csg ...... Y N 18 CM'! will cover all known productive horizons .......... ~ N 19. Casing designs adequate for C, 'f. B & permafrost . . (~_.,N 20 Adequate tankage or reserve pit ................ 21. I1 a re-dlill, has a 10-403 for abandor~ment been approved.. Y N 22. Adequate wellbore separation proposed .......... ~ N 23 If diverter required, does it meet regulations . . 24 Drilling fluid pro.q, rarn schematic 8, eq~,p list adequate 25 BC')PE.,.;. do ltiey rneet regulatior, 26. BOPE press rating appropriate' test lo ...~OO_psig. 27. Choke manifold complies w/APl RP-53 (May 84) ...... 28 Work will occur without operation shutdown ........ B N 29 Is presence of H:.S gas probable .... N N GEOLOGY 30 Per'nfit can be issued w/o hydrogen sulfide measures. . . Y ~. ,..- 31 Data presenled on polential ov~rpressl.,'e zones . . 32. Semmic analysis ol shallow gas zones ...... / N r .......... 33. Seabed condition survey (if off-shore) ........... / Y N ~ ~~ 34 Contacl,,ar,,e/phor,eforwe, klypr'ogressrepqr, s / Y N lexploratory only] GEOt. OGY ENGINEERING' COMMISSION: Commentsllnstructio'ns' co -m~::-~ ..... =~=::z~=.z-r-,::: :: :,.: :.:- Well 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. * ALASKA COMPUTING CENTER * . * . ............................ * * ....... SCHLUMBERGER ....... * . ............................ * COMPANY NAME : ARCO ALASKA INC. WELL NAME : KRU 2N-323 FIELD NAME : TARN POOL BOROUGH : NORTH SLOPE STATE : ALASKA API NUM~ER : 50-103-20258-00 REFERENCE NO : 98234 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-JUN-1998 12:36 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/06/ 4 ORIGIN : FLIC REEL NAME : 98234 CONTINUATION # : PREVIOUS REEL : CONk4ENT : ARCO ALASKA INC, KRU 2N-323, TARN POOL, API #50-103-20258-00 **** TAPE H~ER **** SERVICE NAME : EDIT DATE : 98/06/ 4 ORIGIN · FLIC TAPE NAME : 98234 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT · ARCO ALASKA INC, KRU 2N-323, TARN POOL, API #50-103-20258-00 TAPE HEADER TARN POOL OPEN HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: RUN 1 98234 D. PALMER RAY SPRINGER TOWNSHIP: RANGE: FNL : FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING KRU 2N-323 501032025800 ARCO ALASKA INC. SCHLUMBERGER WELL SERVICES 3-JUN-98 RUN 2 RUN 3 .......... 3 9N 7E 68 2290 149.00 149.00 121.00 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12. 250 9. 625 3460.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-JUN-1998 12:36 3RD STRING PRODUCTION REMARKS: STRING CONTAINED HEREIN IS THE MODIFIED LDWG FORMATTED DATA ACQUIRED ARCO ALASKA'S 2N-323 WELL. THE ONLY WIRELINE DATA ACQUIRED BY SCHLUMBERGER WAS THE FORMATION MICRO SCANNER (FMS) , AND DIPOLE SONIC (DSI). THE GAMMA RAY ACQUIRED WITH THE DIPOLE SONIC IS THE PRIMARY DEPTH CONTROL FOR THIS WELL. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/06/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NTJMBER: 1 EDITED OPEN HOLE MAIN PASS Ail tool strings; Depth shifted and clipped curves; all runs merged; no cased hole data. DEPTH INCREMENT: O. 5000 FILE SUMMARY LDWG TOOL CODE DAS FMS $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 9500.0 3360.0 9552.0 3460.0 BASELINE DEPTH $ MERGED DATA SOURCE LDWG TOOL CODE $ REMARKS: .......... EQUIVALENT UNSHIFTED DEPTH .......... DAS FMS RUN NO. PASS NO. MERGE TOP MERGE BASE THIS FILE CONTAINS THE MODIFIED LDWG FORMATTED MAIN LOG DATA ACQUIRED FOR 2N-323. THIS DATA HAS BEEN CLIPPED FOR INVALID DATA BEFORE FIRST READING AND AFTER LAST READING. NO CLIPPING HAS BEEN DONE TO SEPARATE OPEN HOLE FROM CASED HOLE DATA. THE DIPOLE SONIC DT COMPRESSIONAL AND DT SHEAR WERE RELABELED AT THE ANCHORAGE COMPUTING CENTER. LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-JUN-1998 12:36 PAGE: $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 52 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 19 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUM~ NUFiB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1116986 O0 000 O0 0 1 1 1 4 68 0000000000 DT DAS US/Fill6986 O0 000 O0 0 1 1 1 4 68 0000000000 DTSH DAS US/F 1116986 O0 000 O0 0 1 1 1 4 68 0000000000 SCRADAS 1116986 O0 000 O0 0 1 1 1 4 68 0000000000 SP DAS MV 1116986 O0 000 O0 0 1 1 1 4 68 0000000000 GR DAS GAPI 1116986 O0 000 O0 0 1 1 1 4 68 0000000000 C13 FMS IN 1116986 O0 000 O0 0 1 1 1 4 68 0000000000 C24 FMS IN 1116986 O0 000 O0 0 1 1 1 4 68 0000000000 TENS DAS LB 1116986 O0 000 O0 0 1 1 1 4 68 0000000000 TEND DAS LB 1116986 O0 000 O0 0 1 1 1 4 68 0000000000 AZ FMS DEG 1116986 O0 000 O0 0 1 1 1 4 68 0000000000 DEV FMS DEG 1116986 O0 000 O0 0 1 1 1 4 68 0000000000 RB1 FMS DEG 1116986 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 4-JUN-1998 12:36 PAGE: DEPT. 9552.000 DT. DAS -999.250 DTSH. DAS SP.DAS -999.250 GR.DAS -999.250 Cl3.FMS TENS.DAS 5714.000 TEND.DAS 1311.959 AZ.FMS RB1.FMS 0.650 DEPT. 3360.000 DT. DAS -999.250 DTSH.DAS SP.DAS -999.250 GR.DAS 51.531 C13.FMS TENS.DAS 2880.000 TEND.DAS 1078.863 AZ.FMS RB1.FMS -999.250 -999. 250 SCRA. DAS 7. 861 C24. FMS 296. 922 DEV. FMS -999.250 SCRA.DAS -999.250 C24.FMS -999.250 DEV. FMS -999.250 8. 850 48. 618 -999.250 -999.250 -999.250 ** END OF DATA ** * * * * FILE TRAILER * * * * FILE NAME : EDIT .001 SERVICE · FLIC VERSION : O01CO1 DATE · 98/06/ 4 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE · 98/06/ 4 ORIC-IN · FLIC TAPE NAME : 98234 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC, KRU 2N-323, TARN POOL, API #50-103-20258-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/06/ 4 ORIGIN · FLIC REEL NAME : 98234 CONTINUATION # : PREVIOUS REEL : COMFiENT · ARCO ALASKA INC, KRU 2N-323, TARN POOL, API #50-103-20258-00 Sperry-Sun Drilling Services LIS Scan Utility Tue Aug 11 14:04:19 1998 Reel Header Service name ............. LISTPE Date ..................... 98/08/11 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Li Services Tape Header Service name ............. LISTPE Date ..................... 98/08/11 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services ~BC E,~~C Technical AUG 1 Z 1998 oil & Gas C~ns. Comm~n Anchorage Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT, TARN POOL MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: MWD RUN 2 AK-M~-80190 R. KRELL R. SPRINGER ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 2N-323 501032025800 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES il-AUG-98 3 09N 07E 68 792 148.90 147.40 121.00 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 9.625 3460.0 8.500 9553.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 3. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4),COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO-DENSITY (SLD) . 4. SLD SLIDES DENOTED SLD DEPTHS DURING SLIDE INTERVALS. 5. MWD RUNS 1 AND 2 REPRESENT WELL 2N-323 WITH AN API#: 50-102-20258-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9553'MD, 5412'TVD. 6. ****THIS DATA REPLACES THE REDISTRIBUTION OF 6/22/98, AND IS THE THIRD**** ****DISTRIBUTION OF DIGITAL DATA FOR THIS WELL. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY-SANDSTONE MATRIX, FIXED HOLE SIZE. SBDC = SMOOTHED BULK DENSITY COMPENSATED. SCOR = SMOOTHED STANDOFF CORRECTION. SNPE = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR. SNNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATES. SNFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATES. PARAMETERS USED IN NUCLEAR LOG PROCESSING: HOLE SIZE: 8.5" MUD WEIGHT: 9.50 TO 9.85 PPG MUD SALINITY: 1000 PPM CHLORIDES FORMATION WATER SALINITY: 19149 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY 2.65 G/CC MATRIX: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/08/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. .5000 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE NPHI GR FCNT NCNT FET RPD RPM RPS RPX PEF DRHO RHOB ROP $ START DEPTH 3372.0 3415 0 3444 5 3444 5 3444 5 3444 5 3444 5 3444 5 3444 5 3454 5 3454 5 3454 5 3468 5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 3415.0 3443 5 3452 3455 3508 3510 3512 3571 3573 3574 3584 3608 3611 3619 3635 3638 3640 3642 3656 3658 3667 3669 3677 3684 3693 3718 3725 3748 GR 3420 5 3449 0 3455 5 3458 5 3512 5 3514 5 3515 5 3574 0 3575 0 3576 5 3587 0 3611 5 3614 5 3622 5 3637 5 3639 0 3641 0 3643 5 3656 0 3658 0 3667 5 3670 0 3675 5 3682 0 3692 0 3717 0 3724 0 3747 0 STOP DEPTH 9456.0 9500.5 9456.0 9456.0 9481.0 9481.0 9481.0 9481.0 9481.0 9489.5 9489.5 9489.5 9552.0 EQUIVALENT UNSHIFTED DEPTH -- 3758 3776 3782 3785 3790 3810 3817 3821 3836 3845 3854 3863 3875 3885 3887 3889 3890 3897 3898 3902 3904 3907 3918 3920 3953 3955 3957 3959 3961 3991 3995 4046 4049 4050 4053 4054 4056 4058 4060 4064 4074 4078 4095 4115 4118 4269 4481 4484 4488 4633 4634 4635 4638 4642 4768 4801 4804 4809 4811 4813 3760 5 3779 5 3786 5 3791 5 3795 0 3812 5 3820 5 3823 0 3841 0 3850 0 3859 0 3866 5 3878 5 3888 5 3891 0 3894 0 3895 5 3900 5 3903 0 3906 0 3908 0 3911 5 3921 5 3925 0 3956.0 3957 0 3961 0 3963 0 3964 0 3996 0 4000 0 4050 0 4053 0 4055 5 4057 5 4060 0 4061 0 4063 0 4066 0 4067 5 4076 0 4079 5 4099 0 4120 0 4122 0 4272 5 4485 5 4488 5 4490 5 4638 0 4640 0 4641 5 4643 0 4646 0 4773 0 4805 5 4808 5 4812 0 4815 0 4815 5 4814 5 4821 5 4823 0 4829 0 4838 0 4843 0 4844 5 4852 0 4854 5 4858 5 4863 0 4867 0 4868 5 4876 5 4878 0 4880 5 4915 0 4917 5 4929 0 5059 5 5073 5 5080 5 5103 0 5104 0 5106 0 5109 5 5121 5 5123 5 5132 5 5162 5 5165 0 5174 0 5179 5 5183 5 5215 0 5218 5 5224 5 5356 5 5362 5 5364 0 5365 0 5406 0 5408 0 5409 5 5426 5 5444 0 5446 0 5463 0 5470 0 5471 0 5472 5 5498 0 5508 5 5510 5 5526 5 5555 5 5558 5 5559 5 5641 0 5653 0 4817 4825 4827 4832 4841 4847 4847 4852 4855 4861 4867 4870 4871 4880 4883 4885 4917 4919 4932 5061 5076 5083 5105 5107 5108 5111 5126 5129 5138 5166 5169 5175 5180 5186 5219 5221 5226 5358 5366 5367 5368 5407 5409 5411 5429 5444 5447 5464 5471 5472 5473 5500 5510 5513 5529 5556 5559 5561 5642 5652 5654 5655 5657 5662 5665 5672 5684 5688 5690 5693 5694 5694 5702 5706 5708 5709 5713 5718 5722 5725 5729 5750 5760 5767 5768 5772 5775 5776 5778 5794 5809 5812 5818 5820 5824 5827 5847 5855 5866 5873 5880 5897 5910 5911 5916 5919 5920 5927 5931 5932 5951 5957 5960 5962 5972 5987 5997 6000 6004 6007 5654 5655 5656 5663 5666 5672 5685 5689 5689 5692 5694 5695 5701 5704 5707 5709 5713 5718 5720 5725 5729 5751 5762 5766 5768 5772 5775 5776 5778 5794 5809 5812 5820 5821 5824 5827 5846 5852 5867 5875 5880 5897 5909 5910 5916 5919 5920 5926 5929 5931 5951 5957 5961 5962 5973 5986 5997 5999 6003 60O5 6018 0 6021 0 6023 5 6030 0 6041 0 6044 0 6059 0 6077 0 6078 0 6080 0 6083 0 6084 5 6091 5 6094 5 6098 5 6100 5 6136 5 6144 0 6147 0 6163 0 6165 0 6169 5 6175 5 6180 5 6182 0 6189 5 6192 0 6195 5 6197 0 6207 5 6297 5 6300 0 6301 5 6303 0 6305 0 6308 0 6310 0 6314 5 6319 5 6321 5 6341 5 6343 0 6344 5 6346 5 6348 0 6361 0 6362 5 6368 0 6370 0 6391 5 6393 0 6396 0 6401 5 6403 0 6404 0 6414 0 6415 5 6419 5 6423 5 6430 0 60 60 60 60 60 60 60 60 60 60 60 60 60 60 60 61 61 61 61 61 6167 6168 6174 6178 6181 6187 6193 6196 6197 6206 6296 6298 6299 6300 6301 6304 6305 6312 6316 6318 6340 6342 6343 6346 6347 6361 6362 6366 6369 6391 6394 6398 6402 6404 6406 6412 6413 6419 6421 6428 16 5 19 5 22 0 3O 0 41 0 43 5 59 5 76 5 79 0 81 0 83 0 84 5 93 0 93 5 99 0 O0 0 35 0 43 0 46 5 65 5 5 5 5 5 0 0 5 0 5 0 0 5 5 5 5 0 5 0 5 5 5 0 5 0 0 0 5 5 0 5 0 0 5 5 0 0 0 0 0 5 6434 0 6513 5 6517 5 652 6 0 6528 5 6532 0 6566 5 6572 5 6584 0 6606 5 6617 0 6629 5 6632 5 6669 0 6670 5 6674 5 6685 5 6699 0 6705 5 6712 5 6714 5 6718 0 6719 0 6720 5 6724 5 6730 5 6734 0 6740 5 6745 0 6749 5 6755 5 6761 5 6767 0 6769 0 6773 0 6774 0 6783 5 6785 0 6788 0 6790 0 6794 5 6797 0 6801 0 6803 0 6805 5 6807 5 6810 5 6814 5 6815 5 6818 0 6824 0 6826 5 6828 5 6829 5 6831 0 6833 0 6834 0 6874 5 6875 0 6877 0 64 65 65 65 65 65 65 65 65 66 66 66 66 66 66 66 66 66 67 67 67 67 67 67 67 67 67 6740 6743 6747 6754 6760 6767 6767 6770 6772 6780 6782 6787 6788 6793 6795 6800 6802 6806 6807 6809 6813 6813 6815 6822 6824 6825 6827 6828 6829 6832 6870 6871 6875 31 0 10 0 13 0 25 5 29 0 32 0 65 5 75 5 84 5 04 5 14 5 26 5 31 5 69 5 70 0 74 0 85 0 96 0 O4 0 12 0 13 5 17 0 17 5 19 5 23 0 30 0 33 0 0 0 0 5 0 0 5 5 0 5 0 0 5 5 0 0 0 5 5 5 0 5 5 5 0 5 0 5 5 5 0 0 5 6878 0 6879 5 6881 0 6887 5 6901 5 6914 0 6956 5 7012 5 7027 0 7031 0 7051 5 7055 0 7071 0 7O75 5 7080 5 7089 5 7095 5 7124 5 7161 0 7191 0 7202 5 7262 0 7263 0 7264 0 7265 5 7267 0 7267 5 7268 5 7273 0 7275 5 7316 0 7501 0 7531 5 7546 5 7579 5 7581 0 7584 0 7586 0 7588 0 7608 0 7610 0 7614 0 7691 0 7692 5 7696 0 7705 0 7715 0 7720 5 7723 0 7727 5 7731 0 7749 5 7753 0 7754 5 7763 0 7766 5 7769 0 7770 5 7781 0 7783 5 6876 6878 6880 6886 6901 6912 6955 7011 7027 7030 7051 7052 7069 7075 7079 7088 7095 7123 7158 7190 7201 7261 7262 7263 7264 7265 7266 7267 7270 7273 7314 7498 7528 7542 7580 7582 7585 7586 7588 7606 7608 7611 7688 7691 7694 7702 7711 7718 7721 7726 7728 7741 7746 7750 7756 7761 7762 7763 7775 7777 7792 0 7800 5 7802 0 7807 5 7815 5 7825 0 7848 0 7871 0 7873 0 7879 5 7891 5 7912 5 7919 0 7934 0 7944 5 7947 5 7951 5 7953 0 7957 5 7980 0 8008 5 8011 0 8014 0 8024 0 8026 0 8100 5 8103 5 8105 5 8114 0 8126 5 8191 0 8194 5 8196 5 8201 0 8226 5 8230 5 8232 0 8251 0 8298 0 8301 0 8304 0 8307 0 8309 5 8311 0 8314 0 8318 0 8325 0 8327 5 8331 5 8336 5 8337 0 8341 5 8343 0 8345 0 8346 5 8349 0 8352 5 8354 5 8370 5 8377 0 7786 5 7794 5 7797 0 7805 5 7813 0 7822 0 7845 0 7865 5 7869 0 7875 0 7888 0 7908 0 7914 5 7928 5 7940 0 7941 5 7947 0 7949 0 7951 0 7978 5 8004 0 8007 0 8010 5 8017 5 8021 5 8096.0 8100 0 8102 5 8110 5 8121 5 8186 0 8190 0 8192 0 8196 0 8224 5 8227.5 8228 5 8247 0 8294 0 8296 0 8299 0 8301 5 8305 0 8307 0 8309 0 8312 0 8320 5 8322 5 8326 0 8331 0 8332.5 8335 5 8336 5 8338 5 8340 5 8344 5 8348 5 8352 5 8363 0 8369 5 8881 8888 8890 8891 8915 8922 8931 8936 8943 8945 8946 8960 8962 8965 8967 8970 8972 8975 8977 8979 8981 8982 8989 8991 8994 8995 9000 9007 9008 9014 9021 9023 9028 9031 9034 9037 9039 9041 9042 9044 9051 9053 9054 9055 9057 9060 9064 9067 9076 9080 9085 9088 9093 9100 9103 9105 9111 9113 9117 9118 8878 5 8887 5 8888 0 8889 5 8911 5 8919 5 8927 0 8932.0 8939.5 8941 5 8943 0 8957 5 8959 5 8961 5 8963 0 8965 0 8968 0 8971 5 8972 5 8975 0 8976 5 8979 0 8987 0 8988 5 8991 5 8993 5 8996 5 9001 5 9003 5 9008 5 9017 0 9018 5 9023 0 9027 5 9030 5 9031 5 9034 0 9036 0 9037 0 9039 0 9045 5 9047 0 9050 5 9051 5 9054 5 9056 5 9059 5 9062 0 9072 0 9075 0 9080 5 9084 0 9091 5 9096 0 9098 0 9101 5 9107 0 9109 0 9112 5 9113 5 9127 9129 9131 9132 9135 9140 9150 9152 9157 9168 9170 9173 9176 9182 9190 9193 9196 9199 9202 9204 9206 9209 9210 9212 9215 9216 9217 9220 9223 9226 9230 9231 9234 9243 9246 9248 9250 9253 9261 9264 9265 9268 9272 9274 9289 9293 9297 9300 9307 9310 9312 9316 9372 9386 9394 9411 9419 9426 9431 9440 9121 9123 9125 9127 9130 9134 9145 9147 9152 9161 9165 9168 9172 9178 9185 9187 9191 9194 9196 9199 9201 9203 9205 9207 9209 9211 9212 9214 9219 9222 9224 9226 9230 9239 9242 9244 9246 9249 9257 9260 9262 9265 9267 9268 9284 9286 9293 9296 9304 9309 9310 9314 9370 9382 9389 9405 9415 9422 9429 9435 8380 0 8383 0 8388 0 8400 0 8403 0 8410 0 8414 5 8475 0 8477 5 8479 5 8513 0 8516 5 8521 0 8524 5 8527 5 8598 0 8599 5 8601 0 8611 0 8613 5 8614 5 8629 0 8643 0 8649 5 8662 0 8673 5 8676 0 8677 5 8685 5 8688 5 8690 5 8703 5 8707 0 8710 0 8712 5 8714 5 8718 0 8720 0 8722 0 8724 5 8737 5 8752 5 8789 0 8796 0 8797 0 8802 0 8803 5 8809 0 8812 0 8816 5 8817 5 8819 5 8835 0 8836 5 8842 5 8846 5 8853 5 8859 0 8860 0 8880 0 8372 5 8376 0 8378 5 8399 0 8402 5 8405 5 8408 5 8472 0 8474 0 8476 5 8511 0 8515 0 8519 0 8522 5 8526 0 8595 0 8597.5 8599 0 8607 0 8610 0 8613 0 8628 5 8640 0 8646 5 8659 0 8671 0 8674 5 8677 0 8684 0 8685 0 8688 0 8699 5 8706 0 8707 5 8710 5 8712 0 8715 5 8717 0 8721 0 8722 5 8735 0 8752 0 8788 5 8794 5 8796 0 8801 0 8802 5 8808 0 8810 5 8813 0 8813 5 8816 0 8831 0 8833 5 8838 5 8843 0 8851 0 8856 5 8858 0 8877 5 9442 9444 9445 9447 9461 9462 9475 9475 9477 9552 MERGED DATA SOURCE PBU TOOL CODE MWD REMARKS: 9436 5 9439 5 9443 0 9444 0 9462 5 9464 5 9474 5 9476 0 9478 0 9553 0 BIT RUN NO MERGE TOP MERGE BASE 2 3480.0 9553.0 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 ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD API 4 1 68 ROP MWD FT/H 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHM~ 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 NCNT MWD CNTS 4 1 68 FCNT MWD CNTS 4 1 68 RHOB MWD G/CC 4 1 68 DRHO MWD G/CC 4 1 68 PEF MWD BARN 4 1 68 NPHI MWD P.U. 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max DEPT 3372 9552 GR 40.0501 227.128 ROP 12.9082 611.296 RPX 1.107 2000 RPS 1.123 2000 RPM 1.1368 2000 RPD 1.1012 2000 FET 0.5269 71.5092 Mean Nsam 6462 12361 120.5 12172 129. 922 12168 4. 89735 12074 5.30213 12074 5.71271 12074 8.88085 12074 1.58671 12074 First Reading 3372 3415 3468 5 3444 5 3444 5 3444 5 3444 5 3444 5 Last Reading 9552 9500.5 9552 9481 9481 9481 9481 9481 NCNT 2088 3824.14 2735.63 12024 FCNT 414 1129.48 682.608 12024 RHOB 1.6217 2.9186 2.32309 12071 DRHO -0.09 0.5421 0.0605679 12071 PEF 1.3294 9.5456 2.12296 12071 NPHI 14.5001 64.3936 36.6302 12169 3444.5 3444.5 3454.5 3454.5 3454.5 3372 9456 9456 9489.5 9489.5 9489.5 9456 First Reading For Entire File .......... 3372 Last Reading For Entire File ........... 9552 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/08/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/08/11 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH NPHI GR FCNT NCNT FET RPD RPM RPS RPX PEF DRHO RHOB ROP $ 3375.5 3420 5 3450 0 3450 0 3450 0 3450 0 3450 0 3450 0 3450 0 3458 0 3458 0 3458 0 3472 5 LOG HEADER DATA STOP DEPTH 9456 0 9501 5 9456 0 9456 0 9482 0 9482 0 9482 0 9482 0 9482 0 9490 5 9490 5 9490 5 9553.0 DATE LOGGED: S O FTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 SLD STABILIZED LITHO DEN CNP COMPENSATED NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMS) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 21-AP R- 98 5.07 5.46 MEMORY 9553.0 3480.0 9553.0 48.6 63.4 TOOL NUMBER P0996NP6 P0996NP6 P0996NP6 P0996NP6 8.500 8.5 LSND 9.80 51.0 9.5 1300 4.0 2.800 1.600 2.600 3.000 52.2 Name Service Order DEPT GR MWD 2 RPX MWD 2 RPS MWD 2 RPM MWD 2 RPD MWD 2 ROP MWD 2 FET MWD 2 NPHI MWD 2 FCNT MWD 2 NCNT MWD 2 RHOB MWD 2 DRHO MWD 2 PEF MWD 2 Units Size Nsam Rep FT 4 1 68 API 4 1 68 OHM~ 4 1 68 OHM~ 4 1 68 OHMM 4 1 68 OHMM 4 1 68 FT/H 4 1 68 HOUR 4 1 68 P.U. 4 1 68 CNTS 4 1 68 CNTS 4 1 68 G/CC 4 1 68 G/CC 4 1 68 BARN 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Min Max DEPT 3375.5 9553 GR 40.0501 227.128 RPX 1.0933 2000 RPS 1.113 2000 RPM 0.9234 2000 RPD 1.1012 2000 ROP 12.9082 611.296 FET 0.5269 71.5092 NPHI 14.5001 64.3936 FCNT 414 1129.48 NCNT 2088 3824.14 RHOB 1.6217 2.9186 DRHO -0.09 0.5421 PEF 1.3294 9.5456 Mean Nsam 6464.25 12356 120.58 12163 4.89732 12065 5.29937 12065 5.70626 12065 8.3014 12065 129.76 12162 1.5699 12065 36.6306 12162 682.782 12013 2735.66 12013 2.32314 12066 0.0607455 12066 2.12284 12066 First Reading 3375.5 3420.5 3450 3450 3450 3450 3472.5 3450 3375.5 3450 3450 3458 3458 3458 Last Reading 9553 9501.5 9482 9482 9482 9482 9553 9482 9456 9456 9456 9490.5 9490.5 9490.5 First Reading For Entire File .......... 3375.5 Last Reading For Entire File ........... 9553 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 98/08/11 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 98/08/11 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Services Reel Trailer Service name ............. LISTPE Date ..................... 98/08/11 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Services Library. Library. Scientific Scientific Technical Technical Physical EOF Physical EOF End Of LIS File
