Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
204-012
_ e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. dO 1f 0 1 ~ Well History File Identifier D Two-sided 1111/111111 III II III Organizing (done) D Rescan Needed 1111111111111111111 RE~N ~Olor Items: D Greyscale Items: DIGITAL DATA ~skettes, No. , D Other, NolType: OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Poor Quality Originals: D Other: OVERSIZED (Non-Scannable) D Logs of various kinds: NOTES: Date "3 I c¡ } tJ~ , 1 D Other:: BY: ~ 151 lliP 1111111111111' "III YJ1L ~3 Project Proofing BY: ~ Date Ò I~ d- + 151 Scanning Preparation BY: Date: 3 = TOTAL PAGES (Count does not include cover 151 Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in scanrng1preparation: ¡,ÁES ~ Date:3/q oCo If NO in stage 1, page(s) discrepancies were found: YES NO 151 mP NO BY: Stage 1 BY: Maria Date: 151 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned II I II 1/1111I11 ,,1/1 BY: Maria Date: 151 Comments about this file: Quality Checked "I "111I11I" I1II1 1 0/6/2005 Well History File Cover Page.doc THE STATE Alaska Oil and Gas OF 7 OfA LAsKA Conservation Commission if GOVERNOR SEAN PARNELL � *h. 333 West Seventh Avenue Op, 4 3., Anchorage, Alaska 99501 -3572 Main: 907.279.1433 Fax: 907.276.7542 John McMullen SCANNED JAN 2 3 2013, Engineering Team Leader 1a- BP Exploration (Alaska), Inc. a© P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 01 -17B Sundry Number: 312 -453 Dear Mr. McMullen: 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, Daniel T. Seamount, Jr. Commissioner 1 .2 ‘ t f `-' DATED this ay of December, 2012. Encl. • STATE OF ALASKA • RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION NOV 3 0 2012 APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 AOGCC 1. Type of Request: ❑ Abandon ® Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic 204 -012 3. Address: ® D evelopment ❑ Service 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519 -6612 50- 029 - 20289 -02 -00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU 01 -17B Will planned perforations require a Spacing Exception? ❑ Yes No 9. Property Designatior 10. Field / Pool(s): ADL 028329 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured). 11057' 9016' 11022' 9024' 9875' None Casing Length Size MD TVD Burst Collapse Structural Conductor 119' 20" 119' 119' 1530 520 Surface 2704' 13 -3/8" 2704' 2704' 5380 2670 Intermediate 9020' 9 -5/8" .9020' 8569' 6870 5080 Production Liner 2225' 3 - 1/2" x 3 - 3/16" x 2 - 7/8" 8827' - 11057' 8399' - 9016' Scab Liner 5790' 7" 2901' - 8691' 2901' - 8279' 7240 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9773' - 11007' 8996' - 9028' 4-1/2",126#/5-1/2",17#x4-1/2-,126# 13Cr -80 / N -80 8685' / 8757' - 8896' Packers and SSSV Type: 7" x 4 - 1/2" Baker S - packer Packers and SSSV 8484' / 8094' 9 - 5/8" x 5 - 1/2" Baker SAB packer MD (ft) and TVD (ft): 8774' / 8353' 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ® BOP Sketch ❑ Detailed Operations Program ❑ Exploratory ❑ Stratigraphic ® Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation January 1, 2013 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ® Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Matt Ross, 564 -5782 Printed Name: John Ml 4 en Title: Engineering Team Leader mail: att.Ross @bp.com Signature: �� f / 4 Phone: 564 -4711 Date: 1 t. X3 ( Z . 7 Commission Use Only Conditions of -approval: Notify Commission so that a representative may witness Sundry Number �) Z: ❑ Plug Integrity EdOP Test ❑ Mechanical Integrity Test 0 Location Clearance Other: * 350o pS „ 'o? -7 3 l 9 Spacing Exception Required? ❑ Yes u No Subsequent Form Required: `t/ —1 167 ? RBD S DEC 1 3 201* APPROVED BY / l/ Z 1 1 Approved By: COMMISSIONER THE COMMISSION Date: c I nap rC°T E Approved application is valid for 12 months from the date of approval Submit In Duplicate • • • To: Alaska Oil & Gas Conservation Commission From: Matthew Ross bp CTD Engineer Date: November 29, 2012 Re: 01 -17B Sundry Approval Sundry approval is requested to plug the 01 -17B perforations as part of drilling the 01 -17C coiled tubing sidetrack. History of 01 -17B. Well 01 -17B was drilled as a CTD sidetrack & completed in February, 2004. The well produced from zone 2B. Perforations were added in January, 2005 with excellent production until the well was shut in for a production casing leak in October, 2006. The well was returned to production with a rig work over in April, 2008. The well reached marginal production in late 2010, and several end of life add perforations were added, and plugs set between 2011 and year to date. The current well's high GOR combined with its history of solids production have led to its low on time production. Reason for sidetrack. 01 -17B is no longer a competitive well due to high GOR. The proposed sidetrack will access a target in Zone 2C & 2Bu. Proposed plan for 01 -17C is to drill a through tubing sidetrack with a Coiled Tubing Drilling rig on or around February 1 2013. The existing perforations will be isolated by a 3- 3/16" packer whip stock & the primary liner cement job. The sidetrack, 01 -17C, will exit the existing 3- 3/16" liner and kick off in Zone 4 and land in Zone 1B then invert into Zone 4. This sidetrack will be completed with a 2 -3/8" chrome liner in the production interval. The following describes the work planned and is submitted as an attachment to Form 10 -403. A schematic diagram of the proposed sidetrack is attached for reference. • . Pre -Rig Work: • (scheduled to begin an 1 2013) 1. S SBHP survey. 2. S Pull LTP from 8827' MD. 3. S Drift for 3- 3/16" packer whipstock to 9300' MD. 4. S Drift for new top of liner to 8837' MD. 5. F Load & kill well. Perform injection step rate test & freeze protect well. 6. E Set 3- 3/16" packer whipstock at 9,200' MD. 7. F MIT -T to 1000psi. 8. D PPPOT -T 9. V PT MV, SV, WV. 10. 0 Bleed wellhead, production, flow, and GL lines down to zero and blind flange. rqk 11. O Remove wellhouse, level pad. Rig Work: (scheduled to begin Feb 1 2013) 1. MIRU and test BOPE to 250 psi low and 3,500 psi high. 2. Mill 2.74" window at 9,200' and 10' of rathole. Swap the well to PowerVis. 3. Drill build: 3.25" OH, 608' (19.4° deg /100 planned) with resistivity. 4. Drill lateral: 3.25" OH, 1445.6' (12° deg /100 planned) with resistivity. 5. Run Triple Combo Open Hole Logs. 6. Run 2 -3/8" 13Cr liner leaving TOL at 8,820' MD. 7. Pump primary cement leaving TOC at 8,820' MD, 13 bbls of 15.8 ppg liner cmt planned. 8. Perform liner cleanout with mill, motor and MCNL /GR /CCL log. 9. Test liner lap to 2,400 psi. 10. Perforate liner per asset instructions (- 200'). 11. Freeze protect well to 2500' TVD 12. Set BPV, RDMO. Post -Rig Work: 1. Re- install wellhouse, flowline and pull BPV. 2. Set liner top packer if needed with slickline & test to 2,400psi. 3. Perform nitrogen lift with ASRC test separator. Matthew Ross CTD Engineer 564 -5782 CC: Well File Joe Lastufka • TREE= CJW • AltNOTES: WELL ANGLE > 70° 9598' "• D = GRAY 0 1 -17 B SSHOWN ON TBG SC SCAB m NTIAL VIELLBORE NOT ACTUATOR NTIAL KB. ELEV = 73' BF. ELEV = 27A1' 1 KOP= 4438' 2198' H4- 12 "FESX MP, D =3.813° Max Angle = 103° @ 1103 I 2330' H9- 518" FO COLLAR Datum AC= 9446' 2455' H9-5/8 FO COLLAR DatumTVD= 8800' SS GAS LFT MAPDFiELS 120' CONDUCTOR, 94#, H-40, 13 = 19.124" 1 119' ST I ID TVD I DEV I TYPE VLV I LATCH' FORT DATE 4 2865 2865 1 WAG RK DONE 0 05/02/08 1 13 -3/8" CSG, 72#, N-80, D = 12.347" H 2704' rr 3 5224 5182 24 KBG2 BK SO 0 05/02/08 9-5/8" X 7" BKR ZXP LIP w / 11' TEBK, D = 6.290" H 2901' • 10 2 7042 6806 27 KBG2 BK DMY 0 04/28/08 1 1 1 8378 8000 26 KBG2 BK DIN 0 04/28/08 19-5/8" X 7" BKR FLEX LOCK DR HGR, D = 6.330" 2919' � • ► „4 4 8453' 4-1/2° HES X NP, 13= 3.813" 1 Minimum ID = 2.377" @ 10115' ►; '�; 3 -3116" X 2 -7t8" XO ; ► ►_, 8484' 7° X 4-12" BKR S-3 PKR, D = 3.875" • •*$ 8518' H4- 12"FESXNP,D =3.813" 1 17" MARKB3JOINT H $ • ■ 4 8653' H7" X 5-1/2° PORTED XO, D = 4.892° 1 T CSG, 26#,13CR 80 VAM TOP, H 8653' ; r 8685' H4 -12" F.AJLESHOE, 13= 3.958°1 .0383 bpf, D = 6276' r 8891' 9518" X 5-12° UNIQUE OVERSHOT 1 1 4-1/2" TBG, 12.6#, 13CR -80 —1 8685' i j I 8757' H 5-1/T BAKER SBR ASSY 1 VAM TOP, _0152 bpf, D = 3.958" 8774' H9-5/8" X 5 -12" BKR SAB PKR, D = 4.0" I 15 -1/2" CSG, 17#, L -80 BTC-M, .0232 bpf, D = 4.892' H NM' 8780' Hs-5/8" MLLOUT EXTENSION, D = ? 1 1 5-12" TBG, 17#, N-80, .0232 bpf, D = 4.892' H 8774' 8786' H6 -5/8" X 4-12° XO, D = 3.958" ( PTA CI 8827' H3-1/2" KB LTP, ID= 2.390" (07/09/11)1 1 8837 —13.7" BKR DEPLOY ME3NT SLV,13 = 2.972' 1 I DB NP (Ii134tD CT LNIi) 1 13 -1i2' LW, 8.81 #, STL, .0081 bpf, D = 2.880° H Mgr I 1 885T H3-12" HES X NP, D = 2.813' 1 14 -12" TBG -14 12.6#, N-80, .0152 bpf, D = 3.958" H $896' 8889 H3-1/2" X 3-3/16" XO, D = 2.786' 1 8896' H4 -1/2" WLEG (BEMPO CT LM) I 9-5/8" CSG, 47 #, N-80, RSTSM H 95, D = 8.681" - 9 020 • • • , • • • I I • ,•••••4 CEMENT RAMP ~OW (01 -178 ) 9020 • ►�i i�i�i� PERFORATION SUMMARY ► iii • • • • • • REF LOG: SWS MEMORY CNJGRICCL ON 02/08/04 ► • � • • � • • ANGLE AT TOP FERF: 79° @ 9773' '.****V • i . , • ■ Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opr✓Sqz DATE 0•�•�•�• 2" 6 9773 - 9787 0 04/01/11 ■ iii ► 2" 6 9798 - 9822 0 03/21/11 '4.4 ��i• i » i i i ` 2" 6 9949 - 9974 C 01/24/05 2" 6 10450 -10650 C 02/08/04 2" 6 10888 -10913 C 0123/05 ` 2" 6 10982 -11007 C 01/23/05 'i i I 9875' H3 -3/16" CEP (07/10/11) \ 13 -3/16' LNR, 6.2#, L -80 TO, .0076 bpf, 13 = 2.805" H 10115' I ... 2-7/8" LNR, 6.16#, L -80 FL4S, .0058 bpf, D = 2.441° I--I 11057' 1 DATE REV BY COL8434TS DATE REV BY °GWE NTS PRUDHOE BAY UNIT 01/22/96 ROWAN 35 INITIAL COMPLETION 07/28/11 LLV PJC SET CBP(07/10/11) WFiL: 01 -17B 01/24/06 N3S CTD SIDETRACK (01 -17A) 07/28/11 LLY PJC FISH- F4(R BA3,4 PfT (7/9/11) HERMIT ND: " 02/09/04 NORDIC 1 CTD SIDETRACK (01 -17B) 0728/11 LLY PJC PULL/ RESET KB LIP (7/9/11) AR No: 50- 029 - 20289 -02 04/30/08 N2S MO 08/08/11 JNJ PJC CEP CORRECTION (7/9/11) SEC 8, T10N, R15E, 646' F W.. & 1901' FTL 04/02/11 SJW/PJC BP/ PF32F (03131- 4/01/11)) 0228/12 AY/ PJC PERF CORRECTION 9798' 06/14/11 MMS/PJC PULL 13P(6/3/11) BP Ecploration (Alaska) • TREE= CM/ • SAF�IOTES: WELL ANGLE> 70° AN 9598' **' WH.U-EAD GRAY 01 -1 7C S HOWN ON TBG LW *" WRAC NHE LLBORE NOT ACTUATOR = BAKER C NTIAL KB. E-EV = 73' BE ELEV = 27.41' 2198' 1H4 -112" I-E.S X NF, D= 3.813" KOP= 4438' Max Angle = 103° @ 1103 I 2330' I- 19-5/8 FO COLLAR Datum ND = 9446' Datum ND = 8800' SS 2455' H9-5/8" FO COLLAR GAS LFT MAN RELS 120' CONDUCTOR, 94#, H-40, D = 19.124" H 119' 174 ST 1 KU 1 ND 1 DEV 1 TY PE VLV LATCH 1 PORT DATE 4 2865 2865 1 PAC RK DOI& 0 05/02/08 1 13 -3/8" CSG, 72#, N-80, D = 12.347" H 2704' 3 5224 5182 24 KBG2 BK SO 0 05/02/08 19 -5/8" X 7" BKR ZXP LIP w / 11' I133K, D = 6.290" H 2901' ■ al. 2 7042 6806 27 KBG2 BK l2NY 0 04/28/08 i 1 8378 8000 26 KBG2 BK DMY 0 04/28/08 19 -5/8" X 7" BKR FLEX LOCK LNR HGR, D = 6.330" H 2919' ■ 8453• H4 -1/2° FES X MP D = 3.813° I Minimum ID = 2.377" @ 10115' ► ; it 3 -3/16" X 2 -7/8" XO ► ► � �� 8484' T X 4-1/2" BKR S-3 PKF; D = 3.875" 17" MARKff2 H 8626' :1414 • 8618' H4 -1/2" HE S X NP, D = 3.813" 1 i �: 8653' 7" X 5-1/2" PORTED XO, D = 4.892' 1 7" CSG, 26#,13CR 80 VAM TOP, 8653' ' r . 8685' 4 -1/2" MU HOE, 13= 3.958" .0383 bpf, D = 6.276" � 1 8691• 9-5/8" X 5-1/2" MOUE OVERSHOT 1 4-1/2" TBG, 12.6#, 13CR.80 -- I 8685' I 8757' H 5 -1/2' BAKE32SBRASSY 1 VAM TOP, .0152 bpf, 13= 3.958" 8774' H9-5/8" X 5-1/2" BKR SAB PKR,13 = 4.0" 1 I15 -1/2" CSG, 17 #, L -80 BTC-M, .0232 bpf, D = 4.892' 8 691' C4 ►�, H 8780' —16-5/8" Wi_LOUT E7CTE3VSDN, D = ? 1 1 5-1/2" TBG, 17 #, N-80, .0232 bpf, 13= 4.892' H 8774' CI Est 8786' — I6 -5I X 4 -112° X0,13 = 3.958" 1 LTP set by slickline , 8827' — 13 -1/2" KB LTP, 13 = 2.390' To remove' e Ton of;ner& Top ofcem ent@ 8,820'M D 8837' — 13T BKR DEFLOYME3dT SLV, D= 2.972' 1 8$43' H4 -1/2" CAMCO DB-6 NP(B9iND CT LNR) 1 13 -1/2° LNR, 8.81 #, STL, .0081 bpf, D = 2.880" H 8889' 1 I 885T H3-"T HFS x NP, D = 2.813' 1 14 -1Q" TBG -NPC, 12.6#, N-80, .0152 bpf, 13 = 3.958" H 8896' 4 I I 1 1 8889' H3-1/2" X 3-3/16" X0,13 = 2.786' 1 8896' H4 -1/2" WLEG (BERN) CT LNR) I 1 9-5/8" CSG, 47 #, N.80, RSTSM95, D = 8.681 " —1 —9020 I : e : e: I T i ∎•••∎ •�•�• CEIE TT RAMP WINDOW (01 -17B) 9020 PERFORATION SUMMARY ► . •�•�• ► • � • � • • s • • • •• • TD T D 6 11,253 6' REF LOG: SWS MBNDRY CNJGR/CCL ON 02/08/04 11 � / ANGLE AT TOP PF32F: 79° 9773' ► ii L_ Note: Refer to Production DB for historical pert darts •••••. ••■ SIZE SPF NIERVAL Opn/Sgz DATE ►���e��� ∎ + - 3-3 /16" packer whi�siDck 6 9,200'14D 2" 6 9773 - 9787 0 04/01/11 ► ► * i � i � i � 2" 6 9798 -9822 0 03/21/11 ■i %i •••• // ` 2" 6 9949 - 9974 C 01/24/05 2" 6 10450 -10650 C 02/08/04 2" 6 10888 -10913 C 01/23/05 ` 2" 6 10982 -11007 C 01/23/05 . I 9875' H3 -3/16" CBP(07/10/11) 1 ` 13- 3/16" LNR, 6.2#, L -80 TCI, .0076 bpf, ID = 2.805" —1 10115' 1 •i• 12 - 7/8" L•2, 6.16#, L -80 FL4S, .0058 bpf, D = 2.441" H 11057' I ' DATE REV BY COMMENTS DATE REV BY ODARvE TS PRUDHOE BAY UNIT 01/22/96 ROWAN 351NTIAL COMPLETION 07/28/11 LLV PJC SET CBP (07/10/11) WELL: 01 -17B 01124/06 N3S CTD SIDETRACK (01 -17A) 07/28/11 LLY PJC FISH- RR ELEMENT (7/9/11) FERRET No: ( `1 040120 02/09/04 NORDIC 1 CTD SIDETRACK (01 -17B) 07/28/11 LLV PJC PEAL/ RESET KB LTP (7/9/11) API No: 50- 029 - 20289 -02 04/30/08 N2S IZUYO 08/08/11 JNL/ PJC CEP CORRECTION (7/9/11) SEC 8, T1ON, R15E, 646' NIL & 1901' FNL 04/02/11 SJW /PJC BP/ P133F (03/31- 4/01/11)) 02/28/12 AY/ PJC FIBRE CORRECTION @ 9798' 06/14/11 MMS/PJC PULL BP(6/3/11) BP Exploration (Alaska) NORDIC CTD UNIT # 2 C / p I R EEL / MANIFOLD DIAGRAM . —1 2" MII „\ C. Calista O l ti I Driller Gauge je ' " M iB ••.. . '4," Manual Choke CIRCULATING MANIFOLD — MMa y MM9 MM 18 0)1 S' a S v I MM 15 a ;a e' s 10/612012 3 � - I SLB Transducer k - ��_.... .4+MM6 PVI Sensor • '*4 1 .. .s MM . • t e ; sn.. ` I —. Baker Choke MM13 MM4 WM - 1 . 5 . MANUAL KILL SIDE MANUAL VALVE CHOKE SIDE I :nustcmnEh MANUAL VALVE es. • KILL HCR I Rev Clr Line A.„. „-- CHOKE HCR I A /Alr Blow down * .•. . MMtb ..• J g ; r — rB1BIBlWr� e 8 I 11 T: Choke Um, I Coiled Tubing — I` _ f klrJfllR ruts 4Y'� BMMBM...: _111MBaMYk I Be rChoka KR Line --. or I I MP2 i MPI '• I ~ I/' _ �: R ° I ,/ I- KM Llne I J \:. BOP 18 r I HP 11 HP 18 .. Trandueere COILED TUBING I e , - \ BOP 17 / I a } - , CIRCULATING SYSTEM I FO „ +s 0. / 1 f1ll,�Jt r /JJ /1 I- e HP 18 I I HP14 P19 HP 8 I I -�� To Inner Reel 1 ` Alk Valve HP 15 — HP7 MPS HP4 HP3 IT HP 13 I I / • _ ___+ I HP12 HP2 HP HP 18 / / -- I cement lire N2 \ SLB �'� - '- _ I CHOKE MANIFOLD I P17 d NI N a/ CM 85 MOS 1 ��* ., 1�� 1 Gauge - I CM '•M CHOKE LINE BUS _ � �• I • Test Pump Inlet — CM 30 / „ s_ 1 P CM3 / ION . : I H• awe POI e. I Flow R HC' = on 4WeV '. Bloek CMI4 CMI.0 CM24 - CMB 1111P.=1! ei2 PB2 liquid "�'. I CMB CMB _ - leg is NI I — Baker Choke Llne I 10 hg I- from wal - -� - - CM73 ' h I :: I 8,PASS LINE — CM2 _ f o I CM26 a.o CM21 , I N — CM4 vouoi Ci 5I ±I I ± , v •, s r, ^ :s re .o (.._. HE ,,,,r.wietIvi:-,4....,, A lA< -- CM18 CM19 ! �: : CM27 // j pw-I TIGER TANK . ._',.._ ' az. / ` I STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSIII REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations Ell Stimulate Other 0 LINER TOP PACKER Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ISI Exploratory ❑ — 204 -0120 {,3. Address: P.O. Box 196312 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 ' 50- 029 - 20289 -02 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028329 PBU 01 -17B 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 11057 feet Plugs (measured) 9875 feet true vertical 9016.1 feet Junk (measured) UNKNOWN feet Effective Depth measured 11022 feet Packer (measured) 2901. 8484 8774 8827 feet true vertical 9024.21 feet (true vertical) 2901. 8094 8353 8404 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 101.1# H-40 33 - 111 33 - 111 1650 650 Surface 2672' 13 -3/8" 72# L -80 32 - 2704 32 - 2704 5380 2670 Production 2281' 9 -5/8" 47# R -S -95 29 - 2310 29 - 2310 8150 5080 Production 6710' 9 -5/8" 47# N -80 2310 - 9020 2310 - 8569 6870 4760 Production 5743' 7" 26# 13CR80 2901 - 8653 2901 - 8245 7240 5410 Liner 2225' 3- 1/2 "X3- 3/16 "X2 -7/8" 8832 - 11057 8404 - 9016 Liner 9.3/6.2/6.16# L -80 Perforation depth: Measured depth: SEE ATTACHED - _ - 6 - True Vertical depth: .. _ - Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 23 - 8685 23 - 8274 5 -1/2" 17# N -80 8757 - 8786 8338 - 8363 4 -1/2" 12.6# N -80 8786 - 8896 8363 - 8460 Packers and SSSV (type, measured and true vertical depth) 7" BKR ZXP LTP 2901 2901 3 -1/2" Baker S -3 Packer 8484 8094 5 -1/2" Baker SAB Packer 8774 8353 3 -1/2" Baker 45 KB Packer ( Fry 8404 12. Stimulation or cement squeeze summary: ;t :,a '? Intervals treated (measured): Treatment descriptions including volumes used and final pressure: It : i;, '; ''' P ty • cidyllfi. (,iifliliiSS10(1 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 828 17,318 47 179 Subsequent to operation: 1,669 14,390 132 912 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development IO P Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE] GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Nam • = Lastu a A i j Title Petrotechnical Data Technologist I Signatur: wilt 1 / Phone 564 -4091 Date 8/3/2011 Form 10 t. Rovicod e/ -110 Mims AUG 04 Z011 KI&L„ / , 1.4/ r j riginal Only 01 -17B 204 -012 • . PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 01 -17B 2/8/04 PER 10,450. 10,650. 9,060.34 9,055.61 01 -17B 1/23/05 APF 10,888. 10,913. 9,040.14 9,038.35 01 -17B 1/23/05 APF 10,982. 11,007. 9,032.18 9,027.51 01 -17B 1/24/05 APF 9,949. 9,974. 9,016.87 9,021.5 01 -17B 2/22/08 BPS 8,809. 11,007. 8,383.45 9,027.51 01 -17B 4/30/08 BPP 8,809. 11,007. 8,383.45 9,027.51 01 -17B 3/31/11 APF 9,798. 9,822. 9,000.27 9,004.2 01 -17B 3/31/11 BPS 9,900. 11,007. 9,010.51 9,027.51 01 -17B 4/1/11 APF 9,773. 9,787. 8,995.63 8,998.28 01 -17B 6/5/11 BPP 9,900. 11,007. 9,010.51 9,027.51 01 -17B 7/9/11 BPS 9,875. 11,007. 9,008.94 9,027.51 AB ABANDONED PER PERF • APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • 01 -17B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY _�� _ fF9 a } 3 3 7-s _ s .«'�. ...a<' ' `�'- �� �,�" `� =xa2G '� �.; 'sue „�� '<`a 7/8/2011 ***WELL SHUT IN ON ARRIVAL* ** (assist coil) ATTEMPT TO FISH PKR ELEMENT W/ BLB & 3 PRONG 3.75” WIRE GRAB FROM LNR TOP PKR @ 8831' SLM. NO RECOVERY. 'RIH W/ 3 -1/2" BLB & 3 PRONG 2.62" WIRE GRAB. ** *JOB CONTINUED ON 7/9/11 * ** 7/8/2011. CTU #9 w / 1.75" ct Job scope: Pull liner top packer, set CIBP, and re -set liner top :packer. RIH with 4" GS and jars to pull liner top packer.At surface packer has been recovered have tool service check packer for NORM. Packer checked out 'clean.There is one element left in hole. RU slickline and attempt to fish element. i ** *Job continued on 09 July 11 * ** 7/9/2011 ' CTU #9 w/ 1.75" CT: Job Scope: Pull LTP, Set CIBP, Reset LTP: Continued from 08 July 11: Second SL wire grab unsuccessful to 8980' SLM. SL RIH with 2.62" wire 1 grab BHA to deviation at 9602' SLM - unsuccessful. Rig down SL. MU and RIH with BTT venturi BHA. Unable to get thru liner top with venturi POOH. At surface venturi is ;full of hydrates. RIH w / slb logging tools & 2.70" DJN for a drift. Log up from 9999' to !9650' flag @ 9800'. At surface confirmed good data. MU and RIH with HES MSST and MAP Oil Tools CIBP. Set CIBP at 9875' corr. ** *Job continued on 10 July 11 * ** 7/9/20114 ** *JOB CONTINUED FROM 7/8/11 * ** (assist coil) TWO ATTEMPTS TO FISH PKR ELEMENT @ 8980' SLM W/ BLB & 2.62" WIRE GRAB. NO RECOVERY. R/D 1 ** *WELL TURNED OVER TO SLB COIL * ** • • 7/10/2011i CTU #9 w/ 1.75" CT: Job Scope: Pull LTP, Set CIBP, Reset LTP: Continued from ;08 July 11: Confirm CIBP set. MU and RIH with 45 KB liner top packer. Set LTP / ?Top of LTP is at 8827.26' CTM / Prefom a MIT -T starting pressure 3045 psi lost 28 psi in the first 15 mins / lost 11 psi in the second 15 mins MIT -T PASSED. POOH & freeze protect well w / 38 bbls of 50/50 methanol.Ball has been recovered. Cut 50' of 'coil for pipe management. RDMO «« Job complete »» } FLUIDS PUMPED BBLS 108 1 %KCLW /SL 151 50/50 McOH 259 TOTAL WELLHEAD = 4-1/1 GRAY 0 -� " C ROME SCAB NR WELLBORE ACTUATOR = BAKER C NOT SHOWN ON SCHEMATIC" KB. ELEV = 73' BF. ELEV = 27.41' 1 f 2198' 1 HES X NIP, ID = 3.813" 1 KOP = 4438' I Max Angle = 103° @ 11030' 2330' I - 19 - 5/8" FO COLLAR' Datum MD = 9446' 2455' H9-5/8" FO COLLAR I Datum TV = 8800' SS GAS LIFT MANDRELS 120" CONDUCTOR, 94 #, H -40, ID= 19.124" H 119' A ST MD ND DEV TYPE VLV LATCH PORT DATE 4 2865 2865 1 MMG RK DOME 0 05/02/08 1 13 -3/8" CSG, 72 #, N -80, ID = 12.347" H 2704' 3 5224 5182 24 KBG2 BK SO 0 05/02/08 19 -5/8" X 7" BKR ZXP LTP w / 11' TIEBK, ID = 6.290" I-1 2901' ■ ■ 2 7042 6806 27 KBG2 BK DMY 0 04/28/08 �I �t 1 8378 8000 26 KBG2 BK DMY 0 04/28/08 19 -5/8" X 7" BKR FLEX LOCK LNR HGR, ID = 6.330" H 2919' J I ! - 8453' H4 -1/2" HES X NIP, ID = 3.813" I Minimum ID = 2.377" @ 10115' 3-3/16" X 2 -7/8" XO �_�►� 8484' I 7" X 4 1 /2" BKR S 3 PKR, ID = 3.875" 8518' H4 -1/2" HES X NIP, ID = 3.813" MARKER JOINT H 8626' 8653' 1 - I 7" X 5 -1 /2" PORTED XO, ID = 4.892" 7" CSG, 26 #, 13CR -80 VAM TOP, 8653' r .0383 bpf, ID = 6.276" 8655' - {4 - 1(2" MULESHOE, ID = 3.958 "I P, 8691' H9-5/8" X 5 -1/2" UNIQUE OVERSHOT 1 4 -1/2" TBG, 12.6 #, 13CR -80 8685' ll I 8757' H5 -1/2" BAKERSBRASSY I VAM TOP, .0152 bpf, ID = 3.958" 8774' H 9 -5/8" X 5 -1/2" BKR SAB PKR, ID = 4.0" I 15-1/2" CSG, 17 #, L -80 BTC-M, .0232 bpf, ID = 4.892" H 8691' ■4 I■ $7$Q' -I 6 -5/8" MILLOUT EXTENSION, ID = ? I I5 -1/2" TBG, 17 #, N-80, .0232 bpf, ID = 4.892" 1 - 1 8774' 8786' 1 - - 5/8" X 4 -1/2" XO, ID = 3.958" e E;,.. 8827' H3-1/2" KB LTP, ID = 2.390" (07/09/11)1 $$37' H3.7" BKR DEPLOYMENT SLV, ID = 2.972" 1 I 8843' I-I4 -1/2" CAMCO DB -6 NIP (BEHIND CT LNR) I 13-1/2" LNR, 8.81 #, STL, .0081 bpf, ID = 2.880" I 8889' 885 I _1 3 - 1/ 2" HES X NIP, ID = 2.813" I I4 -1/2" TBG -NPC, 12.6 #, N -80, .0152 bpf, ID = 3.958" I-1 8896' 8889' H3-1/2" X 3- 3/16" XO, ID = 2.786" I 8896' H4 -1/2" WLEG (BEHIND CT LNR) I 19-5/8" CSG, 47 #, N -80, RSTSM -95, ID = 8.681" H -9020 I-- Oii• . K•:*: • ii • • ■�•i∎ i�ii� ►♦•••♦ • •♦•••• I PERFORATION SUMMARY • • •• • CEMENT RAMP WINDOW (01 -178) 9020' REF LOG: SWS MEMORY CNL /GR/CCL ON 02/08/04 ••••••■ � •••� • ANGLE AT TOP PERF: 79° @ 9773' ► 9785' --13 3/16" CIBP (07/10/11) Note: Refer to Production DB for historical perf data ••••••. SIZE SPF INTERVAL Opn /Sqz DATE •♦••••1.� ►•�•••�- ....•, ► •' • •' ? FISH PKR ELEMENT (07 /09/11) 1 •2" 6 9773 - 9787 0 04/01/11 ►�•�•. ► ∎• � • • 2" 6 9798 9822 C 03/21/11 tjt.. „4 !..!j!j jo 2" 6 9949 - 9974 C 01/24/05 ff__ N y l 10115' H3-3/16" X 2 -7/8 X0,10 = 2.377 I 2" 6 10450 - 10650 C 02/08/04 2" 6 10888 - 10913 C 01/23/05 ` 2" 6 10982 - 11007 C 01/23/05 4∎ ∎j / \ 11023' -I PBTD 1 1 3- 3/16" LNR, 6.2 #, L -80 TCII, .0076 bpf, ID = 2.805" 1-I 10115' I ` 12 -7/8" LNR, 6.16 #, L -80 FL4S, .0058 bpf, ID = 2.441" 1-1 11057' .1, DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/22/96 ROWAN 3f ORIGINAL COMPLETION 04/02/11 SJW /PJC IBP/ PERF (03/31- 4/01/11)) WELL: 01 -17B 01/24/06 N3S CTD SIDETRACK (01 -17A) 06/14/11 MMS /PJC PULL IBP (6/3/11) PERMIT No: x 2040120 02/09/04 NORDIC 1 CTD SIDETRACK (01 -17B) 07/28/11 LLV PJC SET CIBP (07/10/11) API No: 50- 029 - 20289 -02 04/30/08 N2S RWO 07/28/11 LLV PJC FISH - PKR ELEMENT (7/9/11) SEC 8, T1 ON, R15E, 646' FWL & 1901' FNL 05/04/08 JLJ /PJC GLV C/0 & PULL CAT(05 /02/01 )07/28/11 LLV PJC PULL / RESET KB LTP (7/9/11) 05/09/08 ?/ PJC DRLG DRAFT CORRECTIONS BP Exploration (Alaska) OPERABLE: Producer 01 -17B (PTD 440120) Tubing Integrity Restored • Page 1 of 2 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIIntegrityCoordinator @bp.com] �Z�I �l Sent: Tuesday, May 24, 2011 7:57 PM \t":1615 � To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS5 Operator; AK, OPS PCC EOC TL; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; Yeager, Kevin E Cc: King, Whitney; Arend, Jon (NORTHERN SOLUTIONS LLC); Stechauner, Bernhard Subject: OPERABLE: Producer 01 -17B (PTD #2040120) Tubing Integrity Restored All, Producer 01 -176 (PTD #2040120) passed a TIFL on 05/10/2011 confirming integrity of the tubing. An OA Repressurization test was conducted from 5/13 to 5/18 and the OA pressure increased 34 psi /day making it manageable by bleeds. The well has been reclassified as Operable and may be brought online when convenient for operations. Thank you, Mehreen Vazir (Alternate. Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells *AWED JUN :11 20i1 Well Integrity Office: 907.659.5102 Email: AKDCWeIIIntegrityCoordinator @BP.com From: AK, D &C Well Integrity Coordinator Sent: Sunday, May 01, 2011 3:41 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS5 Operator; AK, OPS PCC EOC TL; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; Daniel, Ryan Cc: King, Whitney; Stechauner, Bernhard Subject: UNDER EVALUATION: Producer 01 -17B (PTD #2040120) Sustained casing pressure on the IA All, Producer 01 -17B (PTD #2040120) has been found to have sustained casing pressure on the IA. The wellhead pressures were tubing /IA/OA = 500/2260/600 on 4/28/11. The well has been reclassified as Under Evaluation and may be brought on -line for further diagnostics. The plan forward is: 1. DHD: TIFL 2. Slickline: DGLVs and MIT -IA pending TIFL results A TIO plot and wellbore schematic have been included for reference. « File: 01 -17 TIO 05- 01- 11.doc» « File: 01- 17B.pdf» Thank you, 5/25/2011 OPERABLE: Producer 01 -17B (PTD1140120) Tubing Integrity Restored • Page 2 of 2 Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIIntegrityCoordinator @BP.com 5/25/2011 UNDER EVALUATION: Producer O1 (PTD #2040120) Sustained casing *sure on the IA Page 1 of 2 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIIlntegrityCoordinator © bp.com] � � 1�,1 I( Sent: Monday, May 02, 2011 1:06 PM To: Regg, James B (DOA) • Subject: RE: UNDER EVALUATION: Producer 01 -17B (PTD #2040120) Sustained casing pressure on the IA Jim, We will be conducting a pack off test on the inner casing hanger and attempt to re- energize the seals. We will monitor OA BUR post -pack off test to assess manageability of the IAxOA communication. Regards, Mehreen From: Regg, James B (DOA) [mailto:jim.regg @alaska.gov] Sent: Monday, May 02, 2011 11:49 AM To: AK, D &C Well Integrity Coordinator Subject: RE: UNDER EVALUATION: Producer 01 -17B (PTD #2040120) Sustained casing pressure on the IA appears to be issues with OA as well - at least that is what I am interpreting from frequent pressure bleeds and repressurization tp pre -bleed pressure in short -term. What are your plans to assess the OA pressures? Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 3 ZU�I 907 - 793 -1236 J U From: AK, D &C Well Integrity Coordinator [mailto: AKDCWeIIlntegrityCoordinator @bp.com] Sent: Sunday, May 01, 2011 3:41 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS FS1 OSM; AK, OPS FS1 Facility OTL; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 DS5 Operator; AK, OPS PCC EOC TL; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; Cismoski, Doug A; AK, RES GPB East Wells Opt Engr; Daniel, Ryan Cc: King, Whitney; Stechauner, Bernhard Subject: UNDER EVALUATION: Producer 01 -17B (PTD #2040120) Sustained casing pressure on the IA All, Producer 01 -17B (PTD #2040120) has been found to have sustained casing pressure on the IA. The wellhead pressures were tubing /IA/OA = 500/2260/600 on 4/28/11. The well has been reclassified as Under Evaluation and may be brought on -line for further diagnostics. The plan forward is: 1. DHD: TIFL 2. Slickline: DGLVs and MIT -IA pending TIFL results A TIO plot and wellbore schematic have been included for reference. «01 -17 TIO 05- 01- 11.doc» «01- 17B.pdf» 5/2/2011 UNDER EVALUATION: Producer 011B (PTD #2040120) Sustained casing *sure on the IA Page 2 of 2 Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWeIIIntegrityCoordinator @BP.com 5/2/2011 PBU 01 -17B PTD #2040120 5/1/2011 TIO Pressures Plot wt m -1t7 4.000 - • 3.000 - Tby H I— IA —a— OA 2,OGa 00A —� 000A On 1.000 • 02/05/11 02/12/11 02/19/11 02/26/11 03)05/11 03/12/11 03/19/11 03/26/11 04/02/11 04/09/11 04/16/11 04/23/11 04/30/11 TREE = 4- 1/16" CNV SAFETY WELL ANGLE> 70 @ 9598' • WELLHEAD = GRAY * * *CHRO & SCAB LNR ** *ORIGINAL WELLBORE ACTUATOR = BAKER C 01-117B NOT SHOWN ON SCHEMATIC *** KB. ELEV = 73' BF. ELEV = 27.41' KOP= 4438' , I 2198' I-{4 -1/2" HES X NIP, ID = 3.813" I Max Angle = 103° @ 11030' Datum MD = 9446' 2330' H9-5/8" FO COLLAR I Datum TV D = 8800' SS r 2455' H9-5/8" FO COLLAR 1 120" CONDUCTOR, 94 #, H-40, ID = 19.124" I 119' GAS LIFT MANDRELS 13-3/8" CSG, 72 #, N-80, ID = 12.347" H 2704' HA 4 2865 2865 1 MMG RK DOME 0 05/02/08 19 -5/8" X 7" BKR ZXP LTP w / 11' TIEBK, ID = 6.290" I---I 2901' 3 5224 5182 24 KBG2 BK SO 0 05/02/08 9-5/8" X 7" BKR FLEX LOCK LNR HGR, ID = 6.330" I 2919' 2 7042 6806 27 KBG2 BK DMY 0 04/28/08 I ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 8378 8000 26 KBG2 BK DMY 0 04/28/08 8453' 1 14 -1/2" HES X NIP, ID = 3.813" I Minimum ID = 2.377" @ '10115' D F • 3-3/16" X -7/8" XO . ►/►j 8484' 1-17" X 4 -1/2" BKR S-3 PKR, ID = 3.875" I 1111 1 7' MARKER JOINT H 8626' 8518' 14 -1/2" HES X NIP, ID = 3.813" I � � ► • • ► 8653' H7" X 5 -1/2" PORTED XO, ID = 4.892" 1 7" CSG, 26 #, 13CR -80 VAM TOP, --1 8653' �� 8685' 1-1 -112" MULESHOE, ID = 3.958 "I .0383 bpf, ID = 6.276" 8691' I- 19 -5/8" X 5 -112" UNIQUE OVERSHOT I 4 -1/2" TBG, 12.6 #, 13CR -80 -I 8685' i I 8757' HI 5 -1/2" BAKER SBRASSY 1 VAM TOP, .0152 bpf, ID = 3.958" 111 �� ��� 8774' H9-5/8" X 5-1/2" BKR SAB PKR, ID = 4.0" 5 -1/2" CSG, 17 #, L -80 BTC-M, .0232 bpf, ID = 4.892" I-I 8691' L 8780' 1-16 -5/8" MILLOUT EXTENSION. ID = ? 1 15 -1/2" TBG, 17 #, N -80, .0232 bpf, ID = 4.892" I-{ 8774' 8786' - 16 -5/8" X 4 -1/2" XO, ID = 3.958" I e k,2 8832' J--13-1/2" KB LNR TOP PKR, ID = 2.390" 1 8837' - 13.7" BKR DEPLOYMENT SLV, ID = 2.972" 8843' H4-1/2" CAMCO DB -6 N (BEHIND CT LNR) ( 13 -1/2" LNR, 8.81 #, STL, .0081 bpf, ID = 2.880" I 8889' 885T 1-13 - 11 2 " HES X N IP, ID = 2. 813" 4 -1/2" TBG -NPC, 12.6 #, N -80, .0152 bpf, ID = 3.958" H 8896' 8889' I- 13 -1/2" X 3- 3/16" XO, ID = 2.786" 1 8896' H4 -1/2" WLEG (BEHIND CT LNR) I 9 -518" CSG, 47 #, N -80, RSTSM -95, ID = 8.681" H -9020 :.; Kin , 4 t, *4 •.. I ... ♦•• ■•• PERFORATION SUMMARY ►�. • CEMENT RAMP WINDOW (01 -17B) 9020' REF LOG: SWS MEMORY CNL /GR/CCL ON 02/08/04 •• i s s. � ANGLE AT TOP PERF: 79 @ 9773' *.•.�.`� Note: Refer to Production DB for historical perf data �. *.�•.•.•. `. '. ` 9900' -1 BOT IBP (03/31!11) SIZE SPF INTERVAL Opn /Sqz DATE ! *..� ►... 2" 6 9773 -9787 0 04/01 /11 . 2" 6 9798 - 9822 0 03/21/11 ' 4 M :� _ : _ 4 / 10115' -'13- 3/16" X 2 -7/8" XO, ID = 2.377" 1 2" 6 9949 - 9974 C 01/24/05 2" 6 10450 - 10650 C 02/08/04 2" 6 10888 - 10913 C 01/23/05 2" 6 10982 - 11007 C 01/23/05 +. - • ■ 1 11023' H PBTD 1 3- 3/16" LNR, 6.2 #, L -80 TCII, .0076 bpf, ID = 2.805" I 1 ` / 2 -7/8" LNR, 6.16 #, L -80 FL4S, .0058 bpf, ID = 2.441 H 11057' : � mor DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/22/96 ROWAN 3t ORIGINAL COMPLETION 04/02/11 SJW /PJC IBP / PERF (03/31- 4/01/11)) WELL: 01 -17B 01/24/06 N3S CTD SIDETRACK (01 -17A) PERMIT No: P O40120 02/09/04 NORDIC 1 CTD SIDETRACK (01 -17B) AR No: 50- 029 - 20289 -02 04/30/08 N2S RWO SEC 8, T1 ON, R15E, 646' FWL & 1901' FNL 05/04/08 JLJ /PJC GLV C/O & PULL CAT(05 /02/08) 05/09/08 ?/ PJC DRLG DRAFT CORRECTIONS BP Exploration (Alaska) STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSI REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate 0 Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development el Exploratory ❑ i- 204 -0120 3. Address: P.O. Box 196612 Stratigraphic El Service ❑ 6. API Number: Anchorage, AK 99519 -6612 "• 50- 029 - 20289 -02 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028329 " PBU 01 -17B 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 11057 feet Plugs (measured) 9900 feet true vertical 9016.1 feet ,, r4 (measured) None feet APR Effective Depth measured 11022 fee Packer (measured) 2901, 8484 8774 8832 feet true vertical 9024.21 feet (true vertical) 2901, 8094 8353 8404 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 101.1# H -40 33 - 111 33 - 111 1650 650 Surface 2672' 13- 3/8 "72# L -80 32 - 2704 32 - 2704 5380 2670 Production 2281' 9 -5/8" 47# R -S -95 29 - 2310 29 - 2310 8150 5080 Production 6710' 9 -5/8" 47# N -80 2310 - 9020 2310 - 8569 6870 4760 Liner 57' 3 -1/2" 9.3# L -80 8832 - 8889 8404 - 8454 10160 10530 Liner 1226' 3 -1/2" 6.2# L -80 8889 - 10115 8454 - 9044 Liner 942' 2 -7/8" 6.16# L -80 10115 - 11057 9044 - 9016 13450 13890 Perforation depth: Measured depth: SEE ATTACHED - _ True Vertical depth: _ _ _ Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 23 - 8685 23 - 8274 5 -1/2" 17# N -80 8757 - 8786 8338 - 8363 4 -1/2" 12.6# N -80 8786 - 8896 8363 - 8460 Packers and SSSV (type, measured and true vertical depth) 7" BKR ZXP LTP 2801 2901 3 -1/2" BKR S -3 PKR" 4 8094 5 -1/2" BKR SAB PKR \ 74 8353 3 -1/2" KB LNR TOP PK ��•'+! M% 8832 8404 12. Stimulation or cement squeeze summary: r � ;, Intervals treated (measured): coo's' a a te',,,, Treatment descriptions including volumes used and final pressure: Ot5146 00101 -- 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 792 34,366 32 1,727 Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development El , Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil El Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE, GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Na - Lastu a , Title Data Manager Signatu : NM 1 4 hone 564 -4091 Date 4/11/2011 Form 1081 Rovicod 10/ 4::4l •. ' '' 1 3 ��yy Submit Originol Only 01 -17B 204 -012 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 01 -17B 2/8/04 PER 10,450. 10,650. 9,060.34 9,055.61 01 -17B 1/23/05 APF 10,888. 10,913. 9,040.14 9,038.35 01 -17B 1/23/05 APF 10,982. 11,007. 9,032.18 9,027.51 01 -17B 1/24/05 APF 9,949. 9,974. 9,016.87 9,021.5 01 -17B 2/22/08 BPS 8,809. 11,007. 8,383.45 9,027.51 01 -17B 4/30/08 BPP 8,809. 11,007. 8,383.45 9,027.51 01 -17B 3/31/11 BPS 9,900. 11,007. 9,010.51 9,027.51 01 -17B 3/31/11 APF ✓ 9,798. 9,822. 9,000.27 9,004.2 01 -17B 4/1/11 APF ✓ 9,773. 9,787. 8,995.63 8,998.28 AB ABANDONED PER PERF APF ADD PERF RPF REPERF • BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • 01 -17B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 3/31/2011'CTU 9, 1.75" , 0.134 wall CT. Open up well and RIH with PDS GR CCL in 2.20" carrier and 2.25" JSN to 10,400 ft. Log up to 9670ft. POOH Good data confirmed at surface, +15' correction. RIH with BOT Inflatable Bridge Plug, Set plug at 9900' corrected depth to center of element. Make up and run in hole (! with 24ft of 2" PJ2006 HMX guns at 6 spf.(Gun Run #1) Perforate from 9798 ft - 9822ft. POOH. ** *Job continued on 4/1/11 * ** { 4/1/2011 CTU 9, 1.75" , 0.134 wall CT. * *Continued from 3/31/11 ** At surface with gun run #1 , confirmation that guns fired. Run in hole with SLB GR/CCL !Good data at surface, +4' correction. RIH with SLB TCP 2" 6SPF -60 degree phase E PJ2006 HMX gun, Shoot from 9773 - 9787', pooh Well freeze protected l ** *Job Complete * ** I � FLUIDS PUMPED BBLS 145 2% KCL W/ 0.6% SAFE LUBE 194 60/40 McOH 339 TOTAL TREE = 4 -1/16" CM/ SAFETYOES: WELL ANGLE> 70° @ 9598' WELLHEAD = GRAY ** *CHROME TBG &SCAB LNR ** *ORIGINAL WELLBORE ACTUATOR = BAKER C 01 1 7 g NOT SHOWN ON SCHEMATIC"'* KB. ELEV = 73' BF. ELEV = 27.41' 1 l KOP = 4438' 2198' H4 -1/2" HES X NIP, ID = 3.813" 1 Max Angle = 103° @ 11030' Datum MD = 9446' 2330' 1-19 -5/8" FO COLLAR' Datum TVD = 8800' SS r 2455' 1 - - 5/8" FO COLLAR' 120" CONDUCTOR, 94 #, H -40, ID = 19.124" H 119' GAS LIFT MANDRELS I 13 -3/8" CSG, 72 #, N-80, ID= 12.347" H 2704' I--A ST MD 'ND DEV TYPE VLV LATCH PORT DATE 4 2865 2865 1 MMG RK DOME 0 05/02/08 19 -5/8" X 7" BKR ZXP LTP w/ 11' TIEBK, ID = 6.290" 1-1 2901' 3 5224 5182 24 KBG2 BK SO 0 05/02/08 19 -518" X 7" BKR FLEX LOCK LNR HGR, ID = 6.330" I 2919' 2 7042 6806 27 KBG2 BK DMY 0 04/28/08 �. 1 1 1 _ 8378 8000 26 KBG2 BK DMY 0 04/28/08 ► � 8453' . 1 - 14 - 1/2" HES X NIP, ID = 3.813" I Minimum ID = 2.377" @ 10115' : ; F 3-3/16" X 2 -7/8" XO i ►�1 1.�� 8484' -1 7" X 4 -1/2" BKR S-3 PKR, ID = 3.875" 17" MARKER JOINT H 8626' 11: 8518' 1-14 -1/2" HES X NIP, ID = 3.813" I 4 ►� 8653' 1 X 5-1/2" PORTED XO, ID = 4.892" 1 7" CSG, 26 #, 13CR -80 VAM TOP, 8653' ; r 8685' H4 -1/2" MULESHOE, ID = 3.958 "f .0383 bpf, ID = 6.276" L 8691' I - 19 - 5/8" X 5 -1 /2" UNIQUE OVERSHOT 1 4-1/2" TBG, 12.6 #, 13CR -80 - 8685' II I 8757' H5-1/2" 5 -1/2" BAKER SBR ASSY I VAM TOP, .0152 bpf, ID = 3.958" 8774' H9-5/8" X 5 -1/2" BKR SAB PKR, ID = 4.0" 1 15 -1/2" CSG, 17 #, L -80 BTC-M, .0232 bpf, ID = 4.892" H 8691' 8780' J - 16 - 5/8" MILLOUT EXTENSION, ID = ? 15-1/2" TBG, 17 #, N-80, .0232 bpf, ID = 4.892" 1-1 8774' 8786' - 16 - 5/8" X 4 -1/2" XO, ID = 3.958" I i 1 8832' - 13 - 1/2" KB LNR TOP PKR, ID = 2.390" 1 1 8837' -f 3.7" 2" CAMCO DB B KR DEPLOYMENT SLV, ID = 2.972" 1 8843' - 14 -1/-6 NIP (BEHIND CT LNR) 13 -1/2" LNR, 8.81 #, STL, .0081 bpf, ID = 2.880" f 8889' 8857' - 1/ HES X NIP, ID = 2.813" 14 -1/2" TBG -NPC, 12.6 #, N-80, .0152 bpf, ID = 3.958" H 8896' 8889' - 13 - 1/2" X 3-3/16" XO, ID= 2.786" I 8896' I - 1 4 -1/2" WLEG (BEHIND CT LNR) 1 19 -5/8" CSG, 47 #, N-80, RSTSM -95, ID = 8.681" H - 9020 f - �•• �:: �����! Oi�i� i�i�i• 4 iii∎ .44414 PERFORATION SUMMARY • • •� • � � � CEMENT RAMP WINDOW (01-17B) 9020' 114440 •�•• • REF LOG: SWS MEMORY CNL /GR/CCL ON 02/08/04 *••.. • • ANGLE AT TOP PERF: 79° @ 9773' •�•�• Note: Refer to Production DB for historical perf data � . ♦������■ ` 9900' - BOT BP (03/31/11) 1 � SIZE SPF INTERVAL Opn /Sqz DATE �•�•�•�••••••••∎ 2" 6 9773 - 9787 0 04/01/11 ✓ � ► • i • i • i 2" 6 9798 - 9822 0 03/21/11 � • � • J •iii / 10115' -13-3/16" X 2 -7/8" XO, ID = 2.377" f 2" 6 9949 - 9974 C 01/24/05 2" 6 10450 - 10650 C 02/08/04 2" 6 10888 - 10913 C 01/23/05 ` 2" 6 10982 - 11007 C 01/23/05 •�•� 11023' Pup PD I 13- 3/16" LNR, 6.2 #, L -80 TCII, .0076 bpf, ID = 2.805" H 1 f ` 12 -7/8" LNR, 6.16 #, L -80 FL4S, .0058 bpf, ID = 2.441" H 11057' �i. 41r DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/22/96 ROWAN 3f, ORIGINAL COMPLETION 04/02/11 SJW /PJC IBP / PERF (03/31- 4/01/11)) WELL: 01 -17B 01/24/06 N3S CTD SIDETRACK (01 -17A) PERMIT No: ° 2 040120 02/09/04 NORDIC 1 CTD SIDETRACK (01 -17B) API No: 50- 029 - 20289 -02 04/30/08 N2S RWO SEC 8, T1 ON, R15E, 646' FWL & 1901' FNL 05/04/08 JLJ /PJC GLV C/O & PULL CAT(05 /02/08) 05/09/08 ?/ PJC DRLG DRAFT CORRECTIONS BP Exploration (Alaska) STATE OF ALASKA 6~0d AL,~A OtL AND GAS CONSERVATION COM~SION ~ `*' ~', ~tli~ ~ ~ 2008 REPORT OF SUNDRY WELL OPERATION~i~.~~ ~.~,, `,, t,J~~ ,_y„ry 1. Operations Performed: ''~"' `'~~ ~g ^ Abandon ®Repair Well ~ ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well Alt asing ®Pull Tubing , ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. , ®Development ^ Exploratory 204-012 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20289-02-00 ' 7. KB Elevation (ft): KBE = 73', 9• Well Name and Number: PBU 01-17B' 8. Property Designation: 10. Field /Pool(s): ADL 028329 - Prudhoe Bay Field / Prudhoe Bay Pool - 11. Present well condition summary Total depth: measured 11057 ~ feet true vertical 9016 - feet Plugs (measured) None Effective depth: measured 11022 ,feet Junk (measured) None true vertical 9024 ~ feet Casing Length Size MD ND Burst Collapse Structural Conductor 119' 20" 119' 119' Surface 2704' 13-3/8" 2704' ___...,~Z04'__.,.,.- 5380 2670 Intermediate 9416' 9-5/8" 9020' 8569' 6870 5080 Production Liner 2225' 3-1/2" x 3-3/16" x 2-7/8" 8832' - 11057' 8404' - 9016' Scab Liner 5790' 7" 2901' - 8691' 2901' - 8279' 7240 5410 c~~,~r~ED JUN '~ S 2U08 Perforation Depth MD (ft): 10450' - 10650' Perforation Depth ND (ft): 9060' - 9056' 4-1/2", 12.6# 13Cr-80 8896' Tubing Size (size, grade, and measured depth): 5.112" 17# x 4-1l2", 12fi# N-AO Packers and SSSV (type and measured depth): 7" x 4-112" Baker'S-3' packer 8484' 9-5/8" x 5-1/2" Baker'SAB' packer 8774' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: Cut and pull tubing from 8688'. Run 7" (26#, 13Cr-80, BTC-M) scab liner. Cement w/ 175 bbls Class 'G' (983 cu ft / 847 sx). Clean out and run new Chrome tubin . 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: 0 0 0 Subsequent to operation: 1045 40506 44 860 1373 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ^ Exploratory ®Development ^ Service ® Daily Report of Well Operations 16. Well Status after work: ® Well Schematic Diagram ®Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A ff C.O. Exempt: Contact Travis Peltier, 564-4511 308-017 Printed ame Sondra Stewman Title Drilling Technologist S nature Prepared By Name/Number. Phone 564-4750 Dated `q' ~Z,®~Sondra Stewman, 564-4750 Form 10-4 evised 04/2006 ORIGINAL r~aornsaFl,~~~s,ooa Submit Original Only ~~~ F= WEILHEAD = GRAY _ _ ACTUATOR= __ BAKERC KB. ELEV = 73' BF. ELEV = 27.41' KOP = 4438' Max Angle = 103° @ 11030' Datum MD = 9446' Datum TV D = 8800' SS ~20" CONDUCTOR, 94#, H-40, ID = 19.124" ~-~ 119' 13-3/8" CSG, 72#, N-80, ID = 12.347" 2704' 9-5/8" X 7" BKR ZXP LTP w / 11' TIEBK, ID = 6.290" 2901' 9-5/8" X 7" BKR FLEX LOCK LNR HGR, ID = 6.330" 2919' Minimum ID = 2.377" @ 10115' 3-3/16" X 2-7/8" XO 7" MARKERJOINT ~ $E 7 CSG, 26#, 13CR-80 VAMTOP, -~ 8653• .0383 bpf, ID = 6.276" 4-1/2" TBG, 12.6#, 13CR-80 8685" VAM TOP, .0152 bpt, iD = 3.958" 5-1 /2" CSG, 17#, L-80 BTC-M, .0232 bpf, ID = 4.892" 8691' 5-1l2" TBG, 17#, N-80, .0232 bpf, ID = 4.892" $774' ~3-1/2" LNR, 8.81#, STL, .0081 bpf, ID=2.880-1/2" LNR, 8.81#, STL, .0081 bpf, ID=2.880 $$$9" 4-1/2" TBG-NPC, 12.6#, N-80, .0152 bpf, ID = 3.958" 8896' PERFORATION SUMMARY REF L OG: SWS MEMORY CNL/GR/CCL ON 02/08!04 ANGLEATTOPPERF: 80° @ 9949' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2 6 9949 - 9974 O 01!24!05 2 6 10450 - 10650 O 02/08104 2 6 10888 - 10913 O 01/23/05 2 6 10982 - 11007 O 01/23/05 9-5/8" CSG, 47#, N-80, RSTSM-95, ID = 8.681" 9860" 10115' ~-~ 3-3116" X 2-7/8" XO, ID = 2.377" 11023' H ~~ 3-3/16" LNR, 6.2#, L-80 TCII, .0076 bpf, ID = 2.805-L~10115~ 2-7/8" LNR, 6.16#, L-80 FL4S, .0058 bpf, ID = 2.441" -~ DATE REV BY COMMENTS DATE REV BY COMMENTS 01/22/96 WAN3 ORIGINAL COMPLETION 01!24106 N3S CTDSIDETRACK(01-17A) 02/09/04 NORDIC 1 CTDSIDETRACK(01-17B) 04/30/08 N2S RWO 05/04/08 JLJ/PJC GLV GO & PULL CAT(05/02108 05/09/08 ?! PJC DRLG DRAFT CORRECTIONS O 1~ 1 7 B f NOT ON SCHEMATICR;EORIG~VAL WELLBORE 219$' I- j4-1/2" HES X Nom, ~ = 3.813" 2330' ~5/8" FO COLLAR 2455' 9-518" FO COLLAR GAS LIFT MANDRELS ST MD TVD OEl/ TYPE VLV LATCH PORT DATE 4 2865 2865. 1 MMG RK DOME 0 05!02/08 3 5224 5182 24 KBG2 BK SO 0 05!02/08 2 7042 6806 27 KBG2 BK DMY 0 04/28/08 1 8378 8000 26 KBG2 BK DMY 0 04/28/08 $453J~ 4-1 /2° HES X NP, iD = 3.813" i 8484' 7" X 4-112" BKR S-3 PKR ID = 3.875" 8518" 4-1/2" HES X NP, ®= 3.813" $653' 7" X 5-112" PDRTED XO, ~ = 4.892" 8685' 4-112" MULESHOE, D = 3.958 8691" 9-518" X 5-112" UNIQUE OVERSHOT $757' S-112" BAKER SBR ASSY 8774" 9-5/8" X 5-1/2" BKR SAB PKR ~ = 4.0" 8780" 6-518" M~LOUT EXTENSION, ID = ? 8786" 6-518" X 4-1/2" XO, ID = 3.958" 8832" 3-i12" KB LNR TOP PKR ~ = 2.390" 883T 3.7" BKR DEPLOYMENT SLV, ~ = 2.972" $$43' 4-112" CAMCO DB-6 NAB (B9~iND CT LNR) 8$57' 3-112" HES X NIP, ~ = 2.813" $$$9' ~3-1i2" X 3-3/16" XQ ID = 2.786-1i2" X 3-3/16" XQ ID = 2.786" $$96' 4-1/2" WLEG (BBiIND CT LNR) CEMENT RAMP WINDOW (01-176) 9020' PRUDHOE BAY UNff WELL: 01-178 PERMfT No: 2040120 API No: 50-029-20289-02 SEC 8, T10N, R15E, 646' FWL & 1901' FNL BP 6rpioration (Alaska) Digital Well File • • Well: 01-17 Well History Well Date Summary 01-17B 2/21/2008 ***WELL S/1 ON ARRIVAL*** RIH W/ 4.25" CENT & S-BAILER. ***CONT JOB ON 2/22/08*** 01-17B 2/22/2008 ***CONT JOB FROM 2/21/08*** DRIFT 5 1/2" TBG W/ 4.25" CENT & S-BAILER, SD ~ 8696' SLM. S-BAILER EMPTY. '-L51~TFT 5 1 " & 4 1 / " TB ~ W/ x.80" NT & -BAI R. SD ~ 8804' SLM. S-BAILER EMPTY._ CALIPER TUBING FROM 8814' SLM TO SURFACE -GOOD DATA SET 3 1/2" CAT STANDING VALVE, 2.81" C~3 8809' SLM. LRS MIT-T TO 3000, PASSED. ***ON WEATHER HOLD, WELL S/I, DSO NOTIFIED*** 01-176 2/22/2008 T/I/O = 700/0/0 ***MIT-T PASSED to 3000psi*** Pumped 3bbls meth, 27bbls crude. SL set plug. 27.6bbls crude to fluid pack, and pressure up. Tubing lost 200psi 1st 15min, 40psi 2nd 15min, for a total of 240psi in 30min. Bled tubing to 550. FWHP's = 550/0/0 01-176 2/23/2008 ***WELL S/I ON ARRIVAL*** I~l1MPFl~ inn I RS F 4 > >ETG ON TOP OF 3 1/9" CAT STANDING VALVE ~ 8809' SLM W/ 3" DUMP BAI~$ ***CONT JOB ON 2/24/08*** 01-176 2/24/2008 ****CONTJOB FROM 2/23/08**** DUMPED 1- 50LBS BAG OF SLUGGETS ON TOP OF 3 1/2" CAT STANDING VALVE C~3 8809' SLM TOTAL SLUGGETS DUMPED THIS JOB: 150 LBS. TOP OF SLUGGETS C~3 8795' SLM. ***WELL S/I ON DEPARTURE, NOTIFY DSO*** 01-17B 2/27/2008 ****WELL SHUT IN ON ARRIVAL**** INITIAL T/I/0 = 400/0/0 (E-LINE JET CUT). CUT 5-1/2" TUBING AT 8688', MIDDLE OF FULL JOINT BETWEEN SBR AND NIPPLE. FINAL T/I/O AFTER CUT = 1100/0/0. ****JOB IN PROGRESS AND CONTINUED ON 28-FEB-2008 WSR**** 01-176 2/28/2008 ***JOB CONTINUED FROM 27-FEB-2008*** (E-LINE JET CUT 5.5" TUBING). RIG DOWN E-LINE, DRIVE BACK TO SHOP. FINAL T/I/O: 1100/0/0. ***JOB COMPLETE*** 01-176 3/3/2008 T/I/0=1250/0/0 Circ-out/ MIT OA Passed to 2000 psi/ Freeze Protected Flow Line (Pre-RWO) Circ-out - Pumped 5 bbls neat methanol spear, 878 bbls 9.8# brine and 40 bbls diesel down TBG taking returns up IA to jumper line to flow line. Let u-tube for freeze protect. Bled pressures down to 0 psi. Freeze protected Flow Line with 5 bbls neat methanol, 20 bbls crude and 5 bbls neat methanol (tail), freeze protected jumper loop also. MIT OA passed on third attempt. Pumped 3.6 bbls crude total on all test. OA lost 100 psi in first 15 minutes and 20 psi in second 15 minutes. For a total of 120 psi in 30 minutes. Bled all pressures to 0/0/0 psi. Well SI with wing and SSV closed, all other casing valves open to gauges at departure. Tagged OA and wing valve along with notifying DSO of results. FWHP's=0/0/0 01-17B 3/5/2008 T/IA/OA= 0/0/0 Temp=cold PPPOT-T (PASS) PPPOT-IC (PASS) (PRE RWO) PPPOT-T RU 2 HP bleed tools onto THA 50 psi to 0 psi, flush void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 5000/ 15 minutes, 4950/ 30 minutes. Bleed void to 0 psi, RD test equipment, re installed Alemite cap. Cycle and torque LDS "Standard" all move free with no bent pins. PPPOT-IC RU 2 HP bleed tools onto IC test void 0 psi, flushed void until clean returns achieved. Cycle and torque LDS "Standard" several are tight but all move free with no bent pins. Pressure void to 3500 psi for 30 minute test, 3400/ 15 minutes, 3400/ 30 minutes. Bleed IC void to 0 psi. RD test equipment re- installed Alemite caps. 01-17B 3/10/2008 Set 5 1/8" Gray BPV pre rig. T/I/O = 0/0/0 01-17B 3/30/2008 Pulled 5" Gray BPV 601 #. Thru tree so wirline can set dummy valve to fix broken control line needle valve. T/I/0=0/0/0 http://digitalwellfile.bpweb.bp. com/WIInfo/Reports/ReportViewer. aspx Page 1 of 3 6/11/2008 Digital Well File 01-176 3/30/2008 ***WELL SHUT IN ON ARRIVAL*** (replace broken c/line needle valve) SET 5-1/2" CA.DSSSV (TWO SETS REG PKG / 68" x 3.00" MIN ID) AT 2209' MD. REPLACE BROKEN C/LINE NEEDLE VALVE ON TBG HEAD ADAPTER. PULLED 5-1/2" CA.DSSSV FROM 2209' MD. ***LEFT WELL S/I*** DSO NOTIFIED 01-17B 4/13/2008 T/I/0=0/0/0. Set 5 1/8" Gray BPV #606. thru tree, pre rig. 1-2' ext used. Tag at 108". 01-17B 4/21/2008 T/I/0=0/0/0; Removed 3-1/8" Gray OA valve from front of well and replaced it with 3-1/8" McEvoy valve and mounted it on the back side of well for 2ES; RX-35 Gasket and longer studs to replace old ones; ***Complete*** (Best/Wortham) 01-176 4/22/2008 T/I/0=0/0/0. MOVE I/A VALVE TO BACK SIDE OF TREE PULL VR PLUG FROM BACK INSTALL ON FRONT.ATTEMPTED TO INSTALL O/A VALVE ON BACK SIDE,BUT UNABLE TO INSTALL GRAY 3" VALVE, (FLANGE SIZE DIFFERENT FROM TAP BLIND). 01-176 4/22/2008 T/1/0=0/0/0; Set 5-1/8" Gray "K" BPV #606 thru tree for 2ES for BOPE test; 1-2' ext. used, tagged C~3 108"; Cameron to set test dart; ***Complete*** (Best/Wortham) 01-176 4/23/2008 T/I/0=0/0/0; Pull 5-1/8" Gray "K" BPV #606 thru stack for 2ES Decompletion; 4-5' ext. used, tagged C~ 66" ***Complete*** (Best/Wortham) 01-176 4/30/2008 T/I/0=0/0/0; Pull 4-1/16" CIW "H" TWC #255 thru tree post tree test for 2ES; 1-2' ext. used, tagged @ 96" ***Complete*** 01-176 5/2/2008 T/I/O=0/0/0 Pulled 4 1/16" CIW H BPV #251 @ 108" 1-2" ext.used..post-rig..job complete 01-17B 5/2/2008 *** WELL SI ON ARRIVAL *** (post nvo) PULLED RAI I /ROD FROM 8489' SLNL PULLED BK-DGLV FROM ST#3 @ 5209' SLM &DCR SHEAR VLV FROM ST#4 @ 2851' SLM. SET GENERIC GL DESIGN IN SAME. PULLED RHC PLUG BODY FROM 8497' SLM. RAN 10' 3 1/2" P- BAILER TO 8799' SLM. REC. -1/2 GAL SLUGGITS & SEVERAL PIECES OF RUBBER & METAL. RAN 10' 3" P-BAILER TO 8802' SLM...NO RETURNS. FN MARKS ON BAILER BTM. PULLED 3 1/2" CAT STANDING VALVE FROM 8803' SLM.....RIH W/ 2.25 CENT & S-BAILER EGRESS/ CONT ON 04-03-08 WSR *** 01-17B 5/2/2008 ***WELL SI ON ARRIVAL *** (post rwo) PULLED BALUROD FROM 8489' SLM. PULLED BK-DGLV FROM ST#3 ~ 5209' SLM &DCR SHEAR VLV FROM ST#4 C 2851' SLM. SET GENERIC GL DESIGN IN SAME. PULLED RHC PLUG BODY FROM 8497' SLM. RAN 10' 3 1/2" P- BAILER TO 8799' SLM. REC. -1/2 GAL SLUGGITS & SEVERAL PIECES OF RUBBER & METAL. RAN 10' 3" P-BAILER TO 8802' SLM...NO RETURNS. FN MARKS ON BAILER BTM. PULLED 3 1/2" CAT STANDING VALVE FROM 8803' SLM.....RIH W/ 2.25 CENT & S-BAILER *** JOB IN PROGRESS/ CONT ON 04-03-08 WSR *** 01-17B 5/3/2008 *** CONT FROM 04-02-OS WSR*** (post rwo) DRIFTED W/ 2.25 CENT & S-BAILER. STOPPED DUE TO DEV. @ 9649' SLM. BAILER M/T. PERFORMED SBHPS AS PER PROGRAM. GOOD DATA. RDMO *** WELL LEFT SI, DSO NOTIFIED OF WELL STATUS *** 01-176 5/3/2008 *** CONT FROM 04-02-08 WSR*** (post rwo) DRIFTED W/ 2.25 CENT & S-BAILER. STOPPED DUE TO DEV. C~? 9649' SLM. BAILER M/T. PERFORMED SBHPS AS PER PROGRAM. GOOD DATA. RDMO ***WELL LEFT SI, DSO NOTIFIED OF WELL STATUS *** 01-176 5/3/2008 *** CONT FROM 04-02-08 WSR *** (post rwo) DRIFTED W/ 2.25 CENT & S-BAILER. STOPPED DUE TO DEV. C 9649' SLM. BAILER M/T. PERFORM SBHPS AS PER PROGRAM. GOOD DATA. RDMO *** WELL LEFT SI, DSO NOTIFIED OF WELL STATUS *** 01-176 5/9/2008 ***WELL S/I ON ARRIVAL***(sbhps) TAGGED 3 1/2 KB LNR TOP PKR @ 8816' SLM/ 8832' MD (+16' CORRECTION TO MD) ***CONT. ON 5/10/08 WSR*** 01-17B 5/10/2008 ***CONT. FROM 5/09/08 WSR***(sbhps) RAN PETRADAT GAUGES AS PER PROGRAM, GOOD DATA ***WELL S/I ON DEPARTURE*** 01-176 5/17/2008 ASRC Unit #2 MIRU **job in progress** 01-17B 5/18/2008 ASRC Unit #2 complete rig up, POP @ reduced choke, **job in progress** 01-17B 5/19/2008 ASRC Unit #2 continue flowing at a reduced choke setting **job in progress** http://digitalwellfile.bpweb.by.com/WIInfo/Reports/ReportViewer. aspx Page 2 of 3 6/11/2008 Digital Well File 01-17B 01-176 01-176 5/20/2008 5/21 /2008 5/23/2008 01-176 01-176 01-176 5/23/2008 5/24/2008 5/27/2008 01-176 5/28/2008 01-17B 5/29/2008 Print Date: 6/11/2008 • • ASRC Unit #2 continue new well kick off ASRC Unit #2, Test well, rig down. T/I/0=1320/1170/850. Temp=Hot. Bleed IA & OA to < 1000 psi (eval IA x OA post-RWO). IA FL ~ 4930'. OA FL ~ 42'. Bled IAP from 1170 psi to 880 psi in 2 hours. BIe Z5 rom 850 to 150 psi in 1 hour. Gas to fluid. Monitored 30 minutes. No change in IAP. OAP increased 90 psi. Final WHPs=1320/880/240 T/I/O = 1190/830/465. TEMP =Hot. Monitor WHPs post POP (eval IAxOA comm. TP decreased 130 psi overnight, IAP decreased 50 psi overnight, OAP increased 225 psi overnight. T/I/O = 1320/860/640. Temp =Hot. Monitor WHPs and AL post POP (eval IAxOA comm. No AL Line. TP increased 130 psi overnight, IAP increased 30 psi overnight, OAP increased 175 psi overnight. T/I/0= 1320/860/700. Temp= Hot. Monitor WHPs & AL post POP (eval IAxOA comm. No AL line. TP & IAP unchanged. OAP increased 60 psi in two days. T/I/0=1360/830/700. Temp=Hot. Monitor WHPs & AL post POP. No A/L line. TBGP increased 40 psi, IAP decreased 30 psi, & OAP unchanged overnight. T/I/0=1380/850/710. Temp=Hot. Monitor WHPs & AL post POP (eval IAxOA comm. No A/L line. TBGP increased 20 psi, IAP increased 20 psi,and OAP increased 10 psi overnight. Page 1 of 1 Page 3 of 3 http://digitalwellfile.bpweb.bp.com/WIInfo/Reports/ReportViewer.aspx 6/11/2008 • • BP EXPLORATION Operations Summary Report Legal Well Name: 01-17 Common Well Name: 01-17 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 2ES Date From - To Hours ! Task Code NPT __~ 4/21/2008 ~ 00:00 - 03:00 ~ 3.00 ~ MOB ~ P 03:00 - 16:30 13.50 MOB P 16:30 - 00:00 7.50 RIGU P 4/22/2008 100:00 - 03:00 3.001 RIGU ~ P 03:00 - 05:00 2.00 WHSUR P 05:00 - 10:30 5.50 WHSUR P 10:30 - 12:00 1.50 WHSUR P 12:00 - 13:30 1.50 WHSUR P 13:30 - 19:00 ~ 5.50 ~ BOPSUq P 19:00 - 00:00 5.001 BOPSUq P 4/23/2008 ~ 00:00 - 06:00 ~ 6.00 ~ BOPSU F( P 06:00 - 07:00 1.00 BOPSU P 07:00 - 08:30 1.50 BOPSU P 08:30 - 09:00 I 0.501 PULL I P 09:00 - 10:30 I 1.501 PULL I P 10:30 - 11:00 I 0.501 PULL I P 11:00 - 16:30 I 5.501 PULL ~ P Page 1 of 6 ~ Spud Date: 3/13/1978 Start: 4/21 /2008 End: I Rig Release: 4/30/2008 Rig Number: Phase I', Description of Operations PRE PJSM. Move shop, out buildings and cuttings tank to 01-176. Prep sub for move to 01-17B. Clean up around well head and load out materials. PRE PJSM. Move sub from P2-32 to 01-17B. PRE PJSM. MIRU sub on 01-17B. Start moving camp and pits from P2-32 to 01-17. Set sub unit down. Raise derrick. Rig up floor. Bridal down. Pin up top drive. Hang bridal lines. Spot outbuildings, camp, shop and pits. Build berms. PRE PJSM. Continue to rig up primary unit. Rig up pits and outbuildings. Spot cuttings box and build up berm. DECOMP Hold pre-spud meeting. Rig accept at 0300 hours. Rig up DSM. Pull BPV. Bring 9.8 ppg brine into pits. DECOMP PJSM. Circulate out diesel freeze protect. -Circulate wellbore to 9.8 ppg brine. -Wellbore taking fluid @ 20 bph. DECOMP PJSM. RU DSM lubricator and install BPV and dry rod Blanking DECOMP Perform Infectivity Test on Production Casina. , -Pump 16 bbls to fill backside. -Inject 1 bpm ~ 280 psi, 2 bpm ~ 500 psi, 3 bpm ~ 720 psi, 4 bpm @ 1000 psi. -Total of 32 bbls lost for test (16 bbls to fill and 16 bbls injected) DECOMP PJSM w/ Cameron. Bleed all voids and ND tree and adapter flange. -Screw in XO to tubing hanger w/ 18-1/4 turns. Remove XO. -NU BOP and install Riser. -Continue to fill IA during ND/NU. -Wellbore taking fluid C~ 15 bph. DECOMP PJSM. Change out top rams from 3-1/2" x 6" VBRs to 4-1/2" x 7" VBRs. -Install secondary kill line on OA. -Fill stack and check for leaks. -Kill line unibolt connection leaking. Blow down line and change out brass ring. Reinstall kill line. DECOMP Test B P w / 3500 psi high. -Test Upper Pipe Rams with 4-1/2" and 7" test jts. -Witness of test waived by AOGCC Rep Bob Noble. -Test witnessed by WSL Mark Staudinger and NTP Jon Castle. DECOMP PJSM. Rig down testing equipment and blow down. DECOMP PJSM. Dry rod out blanking plug. RU DSM lubricator and pull BPV. -Rig down DSM. DECOMP Make up XO and screw landing jt into hanger. -Back out LDS. -Pull hanger free ~ 210k lbs. - u anger to floor. Tbg wt = 160k w/blocks. DECOMP Displace brine in wellbore from 9.8 ppg to 9.6 ppg C~? 294 gpm, 200 psi. -Monitor well for 10 minutes -Loss Rate = 18 bph. DECOMP PJSM. Lay down landing joint and hanger. -Change out elevators. DECOMP Lay down 5-1/2" 17# N-80 BTC tubing to 2220' and lay down BAL-0 Valve. rnmea: till wzuua ll:l l:Ll AM • • BP EXPLORATION Page 2 of 6 Operations Summary Report Legal Well Name: 01-17 Common Well Name: 01-17 Spud Date: 3/13/1978 Event Name: WORKOVER Start: 4/21/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/30/2008 Rig Name: NABOBS 2ES Rig Number: Date From - To ' Hours I Task Code NPT -- - - 4/23/2008 11:00 - 16:30 5.50 i PULL P 16:30 - 22:00 I 5.501 PULL I P 23:00 - 00:00 1.00 BOPSUF~ P 4/24/2008 00:00 - 02:00 2.00 CLEAN P 02:00 - 05:00 3.00 CLEAN P 05:00 - 06:00 I 1.001 CLEAN I P 06:00 - 07:00 1.00 CLEAN P 07:00 - 08:00 1.00 CLEAN P 08:00 - 11:30 3.50 CLEAN P 11:30 - 12:30 1.00 CLEAN P 12:30 - 14:00 1.501 CLEAN P 14:00 - 16:00 2.00 CLEAN P 16:00 - 17:00 1.00 CLEAN P 17:00 - 18:00 1.00 CLEAN P 18:00 - 19:30 1.50 CLEAN P Phase '~, Description of Operations DECOMP -Rig down spooling unit for control line. -27 clamps recovered. DECOMP PJSM. Continue to lay down 5-1/2" tubing from 2220' to cut joint ~ 8688'. -Recovered 206 full jts, 1 BAL-0 Valve, 1 Sliding Sleeve, 1 DB-5 Nipple, and 1 cut joint strapped ~ 20.44'. -Continue to lose an average of 6 bph while LD tubing. DECOMP PJSM. Rig down csg equipment and clean and clear rig floor. DECOMP om lete BOP Test w/4" Test Joint. -Test Lower Pipe Rams to 250 psi low/ 3500 psi high. -Test witnessed by WSL Mark Staudinger and NTP Jon Castle. DECOMP PJSM. Install wear ring. Pick up and make up Cleanout BHA. DECOMP PJSM. Single in hole with DP from 317' to 3126'. -Take weight 20-25k Ibs ~ 3126'. DECOMP Break circulation C~ 294 gpm, 240 psi. -Run through tight spot and did not take any weight. DECOMP Continue to single in hole with DP to 4268'. -Take weight 20-25k C~3 4268' DECOMP Break circulation, hole packing off. -Could not go down. -Pick up and pump hi-vis sweep. -Rotate and recip pipe ~ 296 gpm, 560 psi, 90 RPM, 1 k ft-Ib TO. -Lots of bi chunks of rubber back to surface. DECOMP Continue to RIH from 4268' to 8680'. DECOMP Wash and rotate over 5-1/2" stub C~ 8680' to 8695'. -Dress of 6" of stub. -355 gpm ~ 1460 psi. 80 rpm with 4-5k ft-Ibs TO. -Up Wt = 165k, Dn Wt = 150 k, Rot Wt = 160k. DECOMP Circulate hi-vis sweep C~ 507 gpm, 2501 psi. -Rotate and reciprocate till clean returns. DECOMP PJSM. POH from 8695' to 317'. DECOMP Lay down cleanout BHA. DECOMP PJSM. Pick up 9-5/8" RTTS tool. DECOMP RIH to 3003' with RTTS. 19:30 - 21:00 I 1.501 CLEAN I P 21:00 - 23:00 2.00 CLEAN P 23:00 - 00:00 1.00 CASE P 4/25/2008 00:00 - 00:30 0.50 CASE P 00:30 - 10:00 9.50 CASE P 10:00 - 11:00 1.00 CASE P 11:00 - 12:30 1.50 CASE P 12:30 - 14:30 I 2.001 CASE I P DECOMP ~ Pressure test 9-5/8" casin above RTTS to 3500 psi for 30 minutes - oood. DECOMP POH with RTTS and lay down tool. DECOMP PU csg tools and rig up to run 7" scab liner. DECOMP PJSM. Continue to rig up 7" csg tools. DECOMP PJSM. RIH with 7" L-80 26# BTC-M Scab Liner. -Drop ball onto Insert Landing Collar Seat and fill with 10' of sand. -RIH to 5762' and pick up Baker hanger and packer. DECOMP Circulate pipe volume ~ 193 gpm, 132 psi. -Rig down casing tools. DECOMP RIH w/DP from 5869' to 8670'. -Up Wt = 210k, Dn Wt = 190k DECOMP PJSM. Pick up cement head and rig up cement lines. -Establish circulation ~ 424 gpm, 1618 psi. -Up Wt = 235k, Dn Wt = 190k. Printed: 6/10/2008 11:11:21 AM • • BP EXPLORATION Operations Summary Report Legal Well Name: 01-17 Common Well Name: 01-17 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 2ES Date From - To Hours Task Code NPT 4/25/2008 12:30 - 14:30 2.00 CASE P 14:30 - 17:30 ~ 3.00 ~ CASE ~ P Start: 4/21 /2008 Rig Release: 4/30/2008 Rig Number: Page 3 of 6 ~ Spud Date: 3/13/1978 End: Phase Description of Operations DECOMP -Swallow stub w/overshot C~ 8681'. -Observe 1st shear w/15k @ 8685'. -Observe 2nd shear C~ 8693'. -Bottom out on overshot C~ 8695'. -Pick up to neutral weight plus 4' to 8691'. DECOMP Circulate with 9.6 brine, returns ~ 95 degrees. PJSM w/SLB cementers. -Switch to SLB Pumps. Pressure test lines to 4500 psi. -Pump 20 bbls 11 ppg mud push, followed by ]75 bbls of 15.8 -Switch to rig pumps, drop plug and displace with rig pumps. -Bump plug on calculated strokes. -Pressure up to 2900 psi to set hanger and set down 75k. -Pressure up to 3600 psi to set LTP. -Pressure up to 4200 psi and held for 5 minutes. -Bleed off and check floats - ok. -Pick up 70k, rotate right 15 turns, pressure up to 1000 psi, then pull running tool out of liner. CIP C~? 17:00 hrs. 17:30 - 18:00 I 0.501 CASE I P 18:00 - 18:30 0.50 CASE P 18:30 - 20:30 2.00 CASE P 20:30 - 22:00 1.50 CLEAN P 22:00 - 00:00 2.00 CLEAN P 4/26/2008 00:00 - 01:30 1.50 CLEAN P 01:30 - 06:00 4.50 WHSUR P 06:00 - 06:30 0.50 WHSUR P 06:30 - 09:00 2.50 WHSUR P 09:00 - 10:00 1.00 WHSUR P 10:00 - 11:00 1.00 WHSUR P 11:00 - 14:00 I 3.00 I CLEAN I P 14:00 - 14:30 I 0.501 CLEAN I P 14:30 - 15:30 1.00 CLEAN P 15:30 - 16:30 1.00 CLEAN P 16:30 - 19:30 3.00 CLEAN P 19:30 - 20:30 1.00 CLEAN P 20:30 - 21:00 0.50 CLEAN P DECOMP ~ Circulate cement out ~ 625 gpm, 1880 psi. DECOMP PJSM. Rig down cement head and blow down lines. DECOMP PJSM. POH from 2898' and lay down liner running tool. -Flush out BOP stack. DECOMP PJSM. Pick up and make up 7" cleanout BHA. DECOMP RIH from 297' to 2724'. -Pick up storm packer and set 99' below RKB. DECOMP ~ Test Storm Packer to 1000 psi for 30 minutes - DECOMP PJSM. Nioole down BO stac c an set ac c in -Nipple down tubing head and replace 9-5/8" packoff. -Nipple up new tubing head. DECOMP Test packoff to 5000 psi for 30 minutes -good. DECOMP PJSM. Nipple up BOP's. DECOMP Test tubing spool flange to 250 si low / 3500 si hi h - ood. DECOMP PJSM. Pick up Storm Packer running tool. -RIH and release storm packer -POH and lay down running tool and packer. DECOMP PJSM. RIH from 2724' to 8471'. -Tag cement @ 8471'. DECOMP Drill cement from 8471' to 8575'. -400 gpm ~ 2380 psi. 80 RPM @ 4-5k ft-Ibs TO. WOB = 10k -UP = 170k, DN = 140k, ROT = 150k DECOMP Circulate hi-vis sweep around C~ 400 gpm, 2300 psi. DECOMP Pressure test casin to 3500 si for 30 minutes - ood. DECOMP Drill cement and float equipment from 8575' to 8654' -Tag 7" x 5.5" XO at 8654' -300 gpm C~3 1500 psi. 60 rpm w/ 4-5k ft-Ibs TO. WOB = 10-15k. -UP = 165k, DN = 140k, ROT = 150k DECOMP Circulate hi-vis sweep C~3 480 gpm, 3100 psi. DECOMP PJSM. Service drawworks, top drive, and crown. Printetl: 6/10/2008 11:11:21 AM • • BP EXPLORATION Page 4 of 6 Operations Summary Report Legal Well Name: 01-17 Common Well Name: 01-17 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 2ES Start: 4/21 /2008 Rig Release: 4/30/2008 Rig Number: Spud Date: 3/13/1978 End: Date From - To Hours Task Code ~ NPT 4/26/2008 21:00 - 00:00 3.00 CLEAN P I 4/27/2008 00:00 - 01:00 1.00 CLEAN P 01:00 - 03:00 2.00 CLEAN P 03:00 - 06:30 3.50 CLEAN P 06:30 - 11:30 5.00 CLEAN P 11:30 - 15:00 3.50 ~ CLEAN ( P 15:00 - 16:30 I 1.501 CLEAN I P 16:30 - 19:30 3.00 CLEAN P 19:30 - 20:00 0.50 CLEAN P 20:00 - 23:00 3.00 CLEAN P 23:00 - 00:00 1.00 CLEAN P 4/28/2008 00:00 - 00:30 0.50 CLEAN P 00:30 - 01:30 1.00 CLEAN P 01:30 - 05:00 3.50 CLEAN P 05:00 - 06:00 1.00 CLEAN P 06:00 - 08:00 2.00 CLEAN P 08:00 - 11:00 3.00 CLEAN P 11:00 - 12:30 1.50 CLEAN P 12:30 - 13:30 I 1.001 CLEAN 1 P 13:30 - 17:00 3.50 CLEAN P 17:00 - 18:00 1.00 CLEAN P 18:00 - 20:30 I 2.501 CLEAN 1 P Phase Description of Operations DECOMP PJSM. POH from 8604' to 297'. -Change out elevators. DECOMP PJSM. Lay down 7" Cleanout BHA. DECOMP PJSM. Pick up and make up 4-3/4" Milling BHA. DECOMP RIH from 483' to 8604' DECOMP Tag TOC ~ 8653'. Drill cement, sand and insert landing collar to 8666' ~ 4 bpm, 760 psi. -80 rpm with 5k ft-Ibs TO. -UP = 173k, DN = 143k, ROT = 160k -Wash down and to ~ 8713' -take 10k Ibs down weight DECOMP Mill from 8713'to 8716' C~ 160 gpm, 750 psi. -100 rpm with 5-7k ft-Ibs TO. WOB = 7k Ibs -UP = 175k, DN = 140k, ROT = 160k. Aluminum over shakers from 8713' to 8716' - at 8716' (Top of PBR Slick Jt.) started torqueing up & making no headway. Further research points to the PBR slick jt.being 3.813" ID. DECOMP Circulate high-vis sweep around ~ 330 gpm, 2600 psi. -Rack back 2 stands, blow down Top Drive and remove blower hose. DECOMP Slip and cut 1500' of new drilling line. DECOMP Service top drive, drawworks, and crown. DECOMP PJSM. POH from 8604' to 483'. DECOMP PJSM. Laydown 4-3/4" Milling BHA. -Boot baskets contained about 1 gallon of cement, sand, metal and aluminum shavings. DECOMP PJSM. Laydown 4-3/4" Milling BHA. DECOMP PJSM. Pickup 3-3/4" Cleanout BHA. DECOMP RIH to 8605' DECOMP Wash down through PBR Slick Jt ~ 8716' with no problem ~ 4 bpm, 850 psi. -Continue washing down to 8806' -taking weight. -Pull up & rotate @ 80 RPM. Indicators tell us we are milling on junk. Keep pumps ~ 1 BPM, 100 psi and control mill junk to 8807'. -Wash down to 8816'., taking no weight. -UP = 175k, DN = 145k, ROT = 160k DECOMP Circulate Hi-vis sweep around C~ 8 bpm, 3000 psi. DECOMP POH from 8791' to 484'. DECOMP Lay down 3-3/4" Cleanout BHA. -Recovered -2 gallons of course sand, cement, and assorted metal in boot baskets. DECOMP Pick up and make up 3-5/8" Reverse Circulating Junk Basket BHA. DECOMP PJSM. RIH from 493'to 8520'. DECOMP Wash down from 8520' to 8816" ~ 142 gpm, 640 psi. -80 rpm ~ 4k ft-Ibs TO. -Drop ball to activate RCJB. Pump @ 200 gpm, 2500 psi. -Work RCJB down to top of CAT Standing Valve (~ 8821'. DECOMP Pump hi-vis sweep and displace 9.6 ppg brine with clean seawater C~ 300 gpm, 4000 psi. -Saw some sluggits over shakers in sweep. -Drop ball and rod to open Pump-out Sub - opened ~ 2200 Printed: 6/10/2008 11:11:21 AM • • BP EXPLORATION Page 5 of 6 Operations Summary Report Legal Well Name: 01-17 Common Well Name: 01-17 Spud Date: 3/13/1978 Event Name: WORKOVER Start: 4/21/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/30/2008 Rig Name: NABOBS 2ES Rig Number: I I NPT ' Phase Description of Operations Date From - To Hours Task ' Code 4/28/2008 18:00 - 20:30 2.50 CLEAN P DECOMP psi. -Pump hi-vis sweep around ~ 590 gpm, 3020 psi. -Returns were clean when sweep came around. 20:30 - 00:00 3.50 CLEAN P DECOMP PJSM. POH, laying down drill pipe from 8800' to 4414'. 4/29/2008 00:00 - 03:00 3.00 CLEAN P DECOMP PJSM. POH, laying down drill pipe to 483'. 03:00 - 05:30 2.50 CLEAN P DECOMP PJSM. Lay down RCJB and boot baskets. -Recovered aluminum and sluggits in boot baskets. -RCJB 1/4 full of pieces of steel, aluminum, and brass. Steel of unknown origin. -Clean and clear floor of Baker tools. 05:30 - 08:00 2.50 BUNCO RUNCMP PJSM. Rig up 4-1/2" TQ Turn Equipment. Prepare to run 4-1/2" Completion. 08:00 - 22:00 14.00 BUNCO RUNCMP PJSM. Make up and run 4.5" 12.6# 13Cr80 VAM TOP Tubing to 8694'. -TO Turn connections to 4440 ft-Ibs. -UP Wt = 125k, DN Wt = 112k 22:00 - 23:30 1.50 BUNCO RUNCMP Tag N~o-G^C~3 8694'. Pick up 10' and space out with 2.07', 9.82', 9.81', and 7.84' (top pup). -Pick up Tubing Hanger and landing joint. -Land tubing and RILDS 23:30 - 00:00 0.50 BUNCO RUNCMP PJSM. Rig up circ lines to Reverse Circulate Corrosion Inhibitted Seawater. 4/30/2008 00:00 - 02:00 2.00 BUNCO RUNCMP Reverse Circulate 105 bbls clean seawater treated with corrosion inhibitor, followed by 155 bbls clean seawater ~ 3 bpm. 02:00 - 04:00 2.00 BUNCO RUNCMP Drop ball and rod. Pressure test tubin to 3500 si for 30 min.-_ o -Bleed to 1500 psi and hold. -Pressure test IA to 3500 si for 30 min - ood. -Bleed off annulus, then tubing. -Pressure up IA and shear DCR valve ~ 2550 psi. -Pump both ways to confirm open. 04:00 - 05:00 1.00 BUNCO RUNCMP D in T -Test from above and below to 1000 psi for 5 minutes.. -B'low down surface equipment. 05:00 - 06:30 1.50 BOPSU P RUNCMP Change out upper rams to 3-1/2" x 6" Variables. 06:30 - 08:00 1.50 BOPSU P RUNCMP PJSM. Nipple Down BOP's. 08:00 - 11:30 3.50 WHSUR P RUNCMP Nipple up adapter flange and test packoff to 5000 psi for 30 minutes -good. -Nipple up tree and test to 5000 psi for 10 minutes- good. 11:30 - 13:00 1.50 WHSUR P RUNCMP Rig up DSM lubricator and test to 250 psi for 5 minutes -good. -Pull TWC -Rig down DSM. 13:00 - 14:00 1.00 WHSUR P RUNCMP Rig up Little Red Hot Oil Unit. 14:00 - 17:30 3.50 WHSUR P RUNCMP Pump 150 bbls diesel down IA with Little Red (~ 84 gpm, 640 psi. -Allow diesel to U-tube through tree for 2 hours. 17:30 - 18:30 1.00 WHSUR P RUNCMP RU DSM lubricator and install BPV. -Test from below to 1000 psi -good. 18:30 - 19:30 1.00 WHSUR P RUNCMP Rig down DSM and Little Red. 19:30 - 20:00 0.50 WHSUR P RUNCMP Secure well with flanges, bull plugs with needle valves, and pressure gauges. Printed: 6/10/2008 11:11:21 AM BP EXPLORATION Page 6 of 6 Operations Summary Report Legal Well Name: 01-17 Common Well Name: 01-17 Spud Date: 3/13/1978 Event Name: WORKOVER Start: 4/21/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 4/30/2008 Rig Name: NABOBS 2ES Rig Number: Date ~ From - To ', Hours Task 'Code NPT Phase Description of Operations 4/30/2008 19:30 - 20:00 0.50 WHSUR P RUNCMP -Release rig from operations on 01-17B ~ 20:00 on 4/30/08. Printed: 6/10/2008 11:11:Ll AM BP EXPLORATION Page 1 of 3 Wellbore Equipment Report Legal Well Name: 01-17B Spud Date: 3/13/1978 Common Well Name: 01-17B Report #: 1 Report Date: 4/29/2008 Event Name: WORKOVER Start: 4/21/2008 End: Assemb ly Name: TUBING Install D ate: 4/29/2008 Suspen ded From:SURFACE EQUIPM ENT @ (ft) Pull Dat e: TMD Co rrection: (ft) Final St ring Wei ght: (Ib) Landed TMD: 8,684.82 (ft) Landed Weight: 112,000 (Ib) ) om. Sizq Component I Description ~ # Jts I.D. O.D. Weight Grade Length Top Set Manufacturer Model # ~ Connection Gomments (in) (in) (in) (Ibfft) (ft) (ft) 1 23.0 4.50 TUBING HANGER 1 0.8 23.0 VETCO ACME 4.50 TUBING PUPJOINT 1 12.6 13CR80 2.4 23.9 TCII 4.50 TUBING JOINTS 1 12.6 13CR80 37.4 26.3 SUMITOMO VAM TOP 4.50 TUBING PUPJOINT 12.6 13CR80 29. 63.8 VAM TOP 4.50 TUBING JOINTS 5 12.6 13CR80 2,085.2 93.4 SUMITOMO VAM TOP 4.50 TUBING PUPJOINT 1 12.6 13CR80 19.7 2,178.6 VAM TOP 4.50 X NIPPLE 1 12.6 9CR 1.2 2,198.4 HALLIBURTON TCII 4.50 TUBING PUPJOINT 1 12.6 13CR80 9.8 2,199.6 TCII 4.50 TUBING JOINTS 1 12.6 13CR80 645.41 2,209.4 SUMITOMO VAM TOP 4.50 TUBING PUPJOINT 1 12.6 13CR80 9.9 2,854.8 VAM TOP 4.50 GAS LIFT MANDRE 1 9.1 2,864.7 SCHLUMBERGER TCII 4.50 TUBING PUPJOINT 1 12.6 13CR80 9.8 2,873.9 TCII 4.50 TUBING JOINTS 5 12.6 13CR80 2,330.6 2,883.81 SUMITOMO VAM TOP 4.50 TUBING PUPJOINT 1 12.6 13CR80 9.8 5,214.4 VAM TOP 4.50 GAS LIFT MANDRE 1 9CR 6.7 5,224.2 SCHLUMBERGER TCII 4.50 TUBING PUPJOINT 1 12.6 13CR80 9.8 5,231.0 TCII 4.50 TUBING JOINTS 4 12.6 13CR80 1,790.9 5,240.91 SUMITOMO VAM TOP 4.50 TUBING PUPJOINT 1 12.6 13CR80 9.8 7,031.8 VAM TOP 4.50 GAS LIFT MANDRE 1 9CR 6.7 7,041.7 SCHLUMBERGER TCII 4.50 TUBING PUPJOINT 1 12.6 13CR80 9.7 7,048.4 TCII 4.50 TUBING JOINTS 3 12.6 13CR80 1,310.3 7,058.2 SUMITOMO VAM TOP 4.50 TUBING PUPJOINT 1 12.6 13CR80 9.8 8,368.5 VAM TOP 4.50 GAS LIFT MANDRE 1 9CR 6.7 8,378.4 SCHLUMBERGER TCII 4.50 TUBING PUPJOINT 1 12.6 13GR80 9.8 8,385.1 TCII 4.50 TUBING JOINTS 1 12.6 13CR80 38.4 8,395.0 SUMITOMO VAM TOP 4.50 TUBING PUPJOINT 1 12.6 13CR80 19.8 8,433.5 VAM TOP 4.50 X NIPPLE 1 12.6 9CR 1.2 8,453.3 HALLIBURTON TCII 4.50 TUBING PUPJOINT 1 12.6 13CR80 9.8 8,454.6 TCII 4.50 TUBING PUPJOINT 1 12.6 13CR80 19.7 8,464.4 VAM TOP 4.50 PACKER (PERMAN 1 4.0 8,484.1 BAKER TCII 4.50 TUBING PUPJOINT 1 12.6 13CR80 9.7 8,488.2 TCII 4.50 TUBING PUPJOINT 1 12.6 13CR80 19.7 8,497.9 VAM TOP 4.50 X NIPPLE 1 12.6 9CR 1.21 8,517.7 HALLIBURTON TCII Printed: 6/10/2008 11:11:11 AM Printed: 6/10/2008 11:11:11 AM BP EXPLORATION Wellbore Equipment Report Legal Well Name: 01-17B Spud Date: 3/13/1978 Common Well Name: 01-17B Report #: 1 Report Date: 4/29/2008 Event Name: WORKOVER Start: 4/21/2008 End: Remarks Ran 210 joints of 4 1/2", 12.6 #, 13CR-80, VAM-TOP tubing. The tubing hanger has 4 1/2" ACME lifting threads on top. Jet Lube Seal Guard thread compound was used and tbg was torque /turned to 4440 ft-Ibs. No.4 GLM MMG 4.5" X 1.5" has DCR Shear with RKP Latch No.3 GLM KBG2-1 R 4.5" X 1" has Dummy Valve with BK Latch No.2 GLM KBG2-1 R 4.5" X 1" has Dummy Valve with BK Latch No.1 GLM KBG2-1 R 4.5" X 1" has Dummy Valve with BK Latch An RHC-M plug is installed in the "X" Nipple at 8518'. Plug install - 3.813" SBR Slick Joint from previous completion located @ 8718.94' with ID = 3.813" Ported 7" x 5.5" XO located C~ 8654'. NO-GO Collar on Muleshoe bottomed out on XO and pulled up 10' for space out. Bottom of muleshoe located C~ 8684.82'. Pulling Tools: Rod and ball - 2" SB RHC-M Plug - 4 1/2" GS BK Latches - 1 1/4" JDC RKP Latches - 1 5/8" JDS All Connections Below Packer are Baker-Locked. Replaced Joint #121, originally 38.72' with extra jt strapped ~ 40.77' due to galled threads. Replaced Collar on Jt # 168. Made up correctly after collar changed out. Page3of3 Printed: 6/10/2008 11:11:11 AM Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, February 19, 2008 8:14 AM To: 'Peltier, Travis M' Cc: Hobbs, Greg S (ANC) Subject: RE: 01-17B {204Pre-rig Work Travis, ~' ~ You and your counterparts have more information as to when is best to severe the pipe. Good luck with the work. Tom Maunder, PE AOGCC From: Peltier, Travis M [mailto:Travis.Peltier@bp.com) Sent: Tuesday, February 19, 2008 7:48 AM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC) ~'~~ FEB ~ 2(~~ Subject: RE: 01-178 (204Pre-rig Work (,f~ _ ©~ i1 Tom, ~ ~~ ~ - '" D Y ~O'_~ 1J ~v ~~ 7 I recently had a discussion with some of my RWO counterparts, and they discussed the need to having apre-rig jet cut performed pre-rig so that we can better monitor our annuli for pressure and circulate in our killweight fluids before operations begin. I am looking to get permission to change our pre-rig work operations back to the original plan that was filed with the Sundry. Thanks for the help. -T Pre-rig~rep work: Proposed) S 1 Drift tubing for caliper survey and tubing cut to 8900' MD. Caliper tubing from surface to 8900' MD. Set Liner Top Test Plug (LTTP) at 8832' MD on 4-1/2" KB Packer. Dump 10' sluggits on top of plug. E 2 Jet cut 5-'/2" tubing @ 8688' MD (Ref original completion tubing tally). Jet cut desired to be in the middle of the full joint between SBR and upper Camco nipple. F 3 Circulate well with ~9.8 ppg NaCL brine and cap with diesel thru the cut. MITOA to 2000 psi. Bleed WHPs to 0 psi. Establish injection pressures @ 1 bpm and 2bpm for scab liner cement design. Na CMIT required due to PC leak. O 4 Set a BPV in the tubing hanger. O 5 Remove the wellhouse & flow line. Level the pad as needed for the rig. Proposed Procedure; 1. MIRU Nabors 2ES. ND tree. NU and test ROPE to 250 psi low, 3500 psi high. Circulate out freeze protection fluid and circulate well to clean 9.8 pgg brine. 2. Pull and LD 5 112" tubing string. 2/19/2008 Pre-Ric Work Request: (Current) S 1 Drift tubing for caliper survey and tubing cut to 8900' MD. Caliper tubing from surface to 8900' MD. Set Liner Top Test Plug (LTTP) at 8832' MD on 4-1/2" KB Packer. Dump 10' sluggits on top of plug. O 4 Set a BPV in the tubing hanger. O 5 Remove the wellhouse & flow line. Level the pad as needed for the rig. Proposed Procedure: 3, MIRU Nabors 2ES. ND tree. NU and test BOPE to 250 psi low, 3500 psi high. Circulate out freeze protection fluid and circulate well to clean 9.8 pgg brine. 2. MfRU SLB SWS, jet cut 5-1l2" tubing at 8688' MD (Ref original completion tubing tally}. Jet cut desired to be in the middle of the full joint between SBR and upper Camco nipple. Circulate weN with ~9.8 ppg NaCL brine thru the cut. Establish injection pressures @ 1 bpm and 2bpm for scab liner cement design. 3. Pull and LD 5 1/2" tubing string.... From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, February O5, 2008 1:18 PM To: Peltier, Travis M Cc: Hobbs, Greg S (ANC) Subject: ItE: 01-17A (195-182) and 01-17B (204-112) Pre-rig Work Travis, Thanks for the update. I do not see any issue moving the cut to be done with the rig aver the well. Nothing further is needed. I will place a copy of this message in the well files. Please include the permit to drill numbers in the message line. Also note, the according to the Convention employed at the Commission, until the window is milled a(I work is considered to occur in 01-17A. Call or message with any questions. Tom Maunder, PE AOGCC From: Peltier, Travis M [mailto:Travis.Peltier@bp.com] Sent: Tuesday, February 05, 2008 12:10 PM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC) Subject: 01-17B Pre-rig Work Tom, Upon further review of the 01-17B RWO, we cannot do a pre-rig jet cut as set out in the original application without violating our two barriers policy. I am looking for approval to change my order of operations to those fisted below. I moved the jet cut to a rig work jet cut, and will perform the same testing as would have been done in pre- rig work. Thanks. 2/19/2008 '~_ V 1 `" 1/ L l l d-11~' YY Vlll ~ 1 K~V J Vl J -Travis Peltier ADW Drilling Engineer (907)564-4511 Pre-rigprea work: (CURRENT) S 1 Drift tubing for caliper survey and tubing cut to 8900' MD. Caliper tubing from surface to 8900' MD. Set Liner Top Test Plug (LTTP) at 8832' MD on 4-1/2" KB Packer. Dump 10' sluggits on top of plug. E 2 Jet cut 5-%2" tubing @ 8688' MD (Ref original completion tubing tally). Jet cut desired to be in the middle of the full joint between SBR and upper Camco nipple. F 3 Circulate well with ~9.8 ppg NaCL brine and cap with diesel thru the cut. MITOA to 2000 psi. Bleed WHPs to 0 psi. Establish injection pressures @ lbpm and 2bpm for scab liner cement design. No CMIT required due to PC leak. O 4 Set a BPV in the tubing hanger. O 5 Remove the wellhouse & flow line. Level the pad as needed for the rig. Proposed Procedure: 1. MIRU Nabors 2ES. ND tree. NU and test ROPE to 250 psi low, 3500 psi high. Circulate out freeze protection fluid and circulate well to clean 9.8 pgg brine. 2. Pull and LD 5 1/2" tubing string. Pre-Ri~Work Request: (PROPOSED) S 1 Drift tubing for caliper survey and tubing cut to 8900' MD. Caliper tubing from surface to 8900' MD. Set Liner Top Test Plug (LTTP) at 8832' MD on 4-1/2" KB Packer. Dump 10' sluggits on top of plug. O 4 Set a BPV in the tubing hanger. O 5 Remove the wellhouse 8~ flow line. Level the pad as needed for the rig. Proposed Procedure: 1. MIRU Nabors 2ES. ND tree. NU and test BOPE to 250 psi low, 3500 psi high. Circulate out freeze protection fluid and circulate well to clean 9.8 pgg brine. 2. M}RU SLB SWS, jet cut 5-1/2" tubing at 8688' MD (Ref original completion tubing fatly). Jet cut desired to be in the middle of the full joint between SBR and upper Camco nipple. Circulate well with ~9.8 ppg NaCL brine thru the cut. Establish injection pressures @ lbpm and 2bpm for scab liner cement design. 3. Pull and LD 5 112" tubing string.... 2/19/2008 • • ~-~ - w<.. - ~~; ~. s.;,:. ~ri MICROFILMED 03/0112008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs_InsertslMicrofilm_Marker.doc • ~, a ~E t S~ q ~ ~ q ~ ,r' i f F 4 „; f yy t , L..,t ~ V + ~ i .t ~. ~ A 'Y\ ~ ~.,~t r i i , 55 t '!! Jy^ CO1~T5ER A~TIO CO1~II-IIDS5 Ip1~ Greg Hobbs Senior Drilling Engineer BP Exploration Alaska • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 PO Box 196612 Anchorage, Alaska 99519-6612 ~"~ ~ /~ Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU O 1-17B Sundry Number: 308-017 Dear Mr. Hobbs: `~~ c ~ ~A~ ~ ~~ Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Cathy P. Foerster Chairman DATED thisZZ day of January, 2008 Encl. ~ RECEI\I STATE OF ALASKA ~ ~j ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~ ~A~ 1 6 ~~~8 APPLICATION FOR SUNDRY APPROV~~ka Oil & Gas Gflns. Carnm~sl~i~~ 20 AAC 25.280 ~nr_hnrana 1. Type of Reques t ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension pp ~~ ~t'171" Alter Casing ® epair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well YY ^ Change Approved Program Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 204-012 , 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20289-02-00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 01-17B Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028329 ` KBE = 73' ~ Prudhoe Bay Field / Prudhoe Bay Pool t2. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11057 - 9016- 11022 - 9024 - None None Casin Len h ize MD TVD Burst Colla se Stru ural Condu or 119' 20" 119' 11 ' Surfa 2704' 13-3/8" 2704' 2704' 5380 2670 Intermediate 9416' 9-5/8" 9020' 8569' 6870 5080 Production Liner 2225' 3-1/2" x 3-3/16" x 2-7/8" 8832' - 11057' 8404' - 9016' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10450' - 10650' 9060' - 9056' 5-1/2" 17# x 4-1/2" 12.6# N-80 8896' Packers and SSSV Type: 9-5/8" x 5-1/2" Baker'SAB' packer Packers and SSSV MD (ft): 8774' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: March 15, 2008 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Travis Peltier, 564-4511 Printed Name Greg Ho s Title Senior Drilling Engineer ^- Prepared 6y Name/Number: Signature Phone 564-4191 Date f /6 Terrie Hubb-e, 564-4628 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ,~^ ' ^ Plug Integrity I~OP Test ^ Mechanical Integrity Test ^ Location Clearance ~©~ ~,I~ ~` Other: 7J{.~ ®V "'~S ~ t.~~ ~ '~S Subsequent Form Required: ~®~-.~ APPROVED BY ZZ ~~ A roved B : COMMISSIONER THE COMMISSION Date ~ Form 10-403 Revised 06 006 ~~'~., ,IAN ~ ~ 2006 ORIGINAL Submit In Duplicate • • by cr,,~,~ 01-17B Rig Workover Scope of Work: Pull 5 1/2" L-80 completion, run 7" scab liner from -8600' to 3000' and cement to 9-5/8" PC. Update Gray wellhead to New Standard, including change out of 9 5/8" pack-offs, run 4-'/2" Chrome completion. MASP: 2317 psi Well Type: Producer Estimated Start Date: March 15, 2008 Pre-rig prep work: S 1 Drift tubing for caliper survey and tubing cut to 8900' MD. Caliper tubing from surface to 8900' MD. Set Liner Top Test Plug (LTTP) at 8832' MD on 4-1/2" KB Packer. Dump 10' sluggits on to of lu E 2 Jet cut 5?/2" tubing @ 8688' MD (Ref original completion tubing tally). Jet cut desired to be in the middle of the full 'oint between SBR and u er Camco ni le. F 3 Circulate well with ~9.8 ppg NaCL brine and cap with diesel thru the cut. MITOA to 2000 psi. Bleed WHPs to 0 psi. Establish injection pressures @ 1 bpm and 2bpm for scab liner cement. design. No CMIT re uired due to PC leak. O 4 Set a BPV in the tubin han er. O 5 Remove the wellhouse & flow line. Level the ad as needed for the ri . Proposed Procedure: 1. MIRU Nabors 2ES. ND tree. NU and test BOPE to 250 psi low, 3500 psi high protection fluid and circulate well to clean 9.8 pgg brine. 2. Pull and LD 5 1/2" tubing string. 3. Cleanout 9-5/8" casing to the cut and dress-off stub. 4. Run 7" scab liner with 5-1/2"overshot to 3000'. 5. Cement 7" scab liner. 6. Run new 4-112" Chrome tubing completion with packer at 8500'. 7. Displace the IA to packer fluid and set the packer. 8. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 9. Set BPV. ND ROPE. NU and test tree. RDMO. Circulate out freeze • GRAY GENN ViIELLHEAD= GRAY ACTUATOR = AXELSON KB. ELEV = 73' BF. ELEV = KOP = 4438' NAstx A 103 ~ 11030' Datum ND = 9257' Datum TVD = 8800' SS 01-17B Current 13-3/8" CSG, 7218, N•80, ID =12.347" I~ 2~Q4' 15-1 /2" TBG, 170, N-80, .0232 bpf, ID = 4.892' I Minimum ID = 2.372" ~ 10136' TOP OF 2-7/8" LINER 3-1/2" LNR, 8.8111, STL, .0081 bpf, ID = 2.880" I~ 8889' 4.1/2" TBG-NPC, 12.8f1, N-80, .0152 bpf, ID = 3.958" PERFORATION SUMMARY REF LOG: SWS N8IAORY CNUGWCCL ON 02/08104 ANGLEATTOPPERF: 80 ~ 9949' Note: Refer to Ploduction DB for historical perf data SIZE SPF INTERVAL OpNSgz DATE 2 6 9949 -9974 O 0124!05 2 6 10450 - 10650 0 02108/04 2 8 10888 - 10913 0 01 /23/06 2 6 10982 -11007 O 01/23105 9-518" CSG, 475, N-80, ID = 8.681" I-j 9860' NOTES: 2209' I- j 5-1/7' ca-nnCO BAL-O ssSV NIP, ID = 4.562" I 2330' 9-5/8" FO COLLAR 2455' 9-5/8" FO COLLAR 8581' H 5-1/2" CANICO SLN~NG SLV, ID = 4.43T' I $~' 5-1!2" CAMCO DB-5 LANDING NIP, ID = 4.313" 8767' 5-1/2" BAKER SBRASSY 8774' 9-5/8" X5-1/2" BKR SAB PKR, ID = 4.0" 8786' 5-1/2"X4-1/2" XO 8832' H 4-1 /2" KB LNR TOP PKR, ID = 2.390" I $837' 3.7" BKR DEPLOY MENT SLV, ID = 3.0" $843' 4-1/2" CAMCO DB-6 NIP (BEHIND CT LNR) 8$57' 3-1/2" HES X N~, O = 2.813" 888$' 3-1 /2" X 3-3/16" XO, ID = 2.880' 8$96' H4-1/2" WLEG (BEFNND CT LNR) ~CEMEMRAN~WINDOW 9020' 10115' I-13-3/1 B" X 2-7/8" XO, ID = 2.440" I 2-7/8" LNR, 6.41<, L-80, .0058 bpf, ID = 2.44" 10345' 3-3/16" LNR, 8.2A, L-80, .0078 bpf, ID = 2.805" 10115' 2-7/8" LNR 6.161, L-80, .00.55 bpf, ID = 2.377" 11057' DATE REV BY COMMENTS DATE REV BY C06181EWTS 01f22l88 ORIGINAL COMPLETKiN 11109/06 AMSlTLH PERF SYBMOL ADDED 01124108 CTDSIDhTRACK(Ot-iTA~ 1?A5106 SKBIfLH WANERSFTY NOTE DELETED 02/0!104 JDIN/KAK CTDBIDETWICK(01-17th 11f~104 DFRlRP 9-5Jg' CSG ~ 9860' 01R4N5 BMbNIPJC ADPERF 03/16J06 RPHfTLH WANBt SAFETY NOTE PBTD PRUDHOE BAY UN(T WELL: 01-17B PERMT No: 2040120 API No: 50-029.20289-02 SEC 8, T10N, R15E, 1408.68' FEL 8338268' FNL ~ L'xpbntion (Alaska) r W13.LHEAD = GRAY ACTUATOR = AXELSON KB. ELEV = 73' BF. ELEV = KOP = 4438' Max Angle = 103 ®11030' Datum MD = 9297' Datum ND = 8800' SS 13-3/8" CSG, 72#, N-80, ID = 12.34T' ~-{ 2704' ~Y NOTES: 1-17 B RWC~ Cass LiR Msrldreb ST MD V VLV LAT RT DATE 3 2 1 i 2330' 9-5/8" FO COLLAR 3~Q' 7" x 9-5/8" Lirror Top Rnrwnlnfinw _lawetrv /Fv~h.Ainn f21 Ma\ MD eseri 'on 4 2200 41/2" X NIP, ID = 3.813" 3 8485 41/2" X NIP, ID = 3.813" 2 8500 4112" x T' Production Packer 1 8520 41/2" X NIP, ID = 3.873" 4 f /T' Tuba~g, f 2.811, f SCR, ID = 3.958"H 8684' ', 7" Sesb Liner, 2611, L-80, O = 8.278" 2 x 10' Pups. 5-1 /z", 17s, L-eo 8884' 8666' 5-1/2" Unque Machine Overshot 8888' 5-1 /2" TBG, 1711, N-80, .0232 bpf, ID = 4.892" 8788' Minimum ID ~ 2.372" ~ 10136' TOR OF 2-7/8" LINER ~ 3-1/2" LNR, 8.8111, STL, .0081 bpf, ID = 2.880" ~ 12.811, N-80, .0152 bpf, ID = 3.958" H 8898' PERFORATION SUMMARY REF LOG: SWS MEMORY CNUGR/CCL ON 02108104 ANGLE AT TOP PERF: 80 ~ 9949' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz DATE 2 6 9949 -9974 O 0124/05 2 6 10450 - 10660 O 02/08104 2 6 10888 - 10913 O 01!23105 2 6 10962 - 11007 O 01!23!05 9-5/8" CSG, 47#, N-80, RSTSM-95, ID = 8.881" 8886' H5-1rr x 7" Ported XO 8888' S-1/2" Tubing Stub 8774' 9-518" X 5-1/2" BKR SAB RCR, ID = 4.0" 8788' 5-1 /2" X 41/2" XO 8832' 3-1/2" KB LNR TOP PKR, ID = 2.390" $$3'/' 3.7" BKR DEPLOYMENT SLV, ID = 3.0" 8843' 4-1/2" CAMCO DB-6 NIP (BEH~iD CT LNR) 8$57' 3-1/2" HES X NIP, O = 2.813"~ 8889' 3-1 /2" X 3-3H 6" XO, ID = 2.880" $8$$' H41/T 1AlLEG~(BEFAN~D CT LNI~ CENEM RAMP WIf~OW 9020' I 10118' I~ 3-3/16" X 2-7/8" XO, ID = .0058 bpf, ID = 2.44" 10345' 3-3/16" LNR, 8.211, L-80, .0078 bpf, ID = 2.805" 10115' 2-7/8" LNR, 8.161!, L-80, .0055 bpf, O = 2.377" DATE REV BY COMMENTS DATE REV BY COMI~+ffS 01122188 ORIGINAL COMPLETK)N 11/09/06 AMS/TLH PERF SYBMDL ADDED 01fZ4108 CTDSIOEiRACK(01-17A) 12J0'.~106 SKBIRH W A N ERSFTY NOTEDH.ETED 02108/04 JDM/KAK CTD~DEfRACK 01-17~ _ __ _ 11/29104 DFRfTLP 9-518" CSG ~ 9860' 01R4/D5 BAlIcN1PJC ADPERF 03!16106 RPHfTLH WANER SAFETY NOTE 11022' H STD PRUDHOE BAY UNR HVELL: 01-17B P82MT No: 2040120 API No: 50-029-20289.02 T10N, R15E, 1406.68' FEL 83362.68' FNL BP 6tpbratk~n (Alaska) R.L~~~ v '-û ,Å,UG 0 8 2006 Schlumberger ~.-a Oif & Gas Cons. Corr~ NO. 3883 Anchorage êJt/l-c (d Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth " " íí\í§) . , \ r \ I~ -- .- r\~'''''E.') :\\.)\1 .... :-jv!c.,. .' Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay WII CI b# L D BL CD e Jo og Description ate o or NK-43 11211388 PROD ._ vv/uE~ I 04/02106 1 NK-22A 10568415 PROD PROFILE W/DEFT 02/26/03 1 L4-12 N/A WFLlLDL 05/09/06 1 L2-21A 10670034 MEM PROD PROFILE 09/20/04 1 13-06A 11217266 INJECTION PROFILE 07/12/06 1 01-17B 11209602 MEM PROD PROFILE 04/27/06 1 09-08 11296705 INJECTION PROFILE 07/21/06 1 09-19 11296704 INJECTION PROFILE 07/20/06 1 09-25 11296703 INJECTION PROFILE 07/19/06 1 04-09 11211398 INJECTION PROFILE 04/28/06 1 04-10 11211380 INJECTION PROFILE 03/23/06 1 17-21 11223104 PROD PROFILE W/DEFT 03/22/06 1 18-03B 11057071 SBHP 12/02/05 1 X-15A 11212877 US IT 07/18/06 1 J-01 B 11511430 USIT 07/24/06 1 15-12A 11221595 US IT 07/25/06 1 Z-14B 11217268 USIT 07/29/06 1 S-400 10987564 CH EDIT PDC-GR OF USIT 01/26/06 1 D-03A 11217269 USIT 07/31/06 1 05-28A 11217267 USIT 07/28/06 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consultrng Services 2525 Gambell Street. Suite 400 Anchorage, AK 99503-2838 A TIN: Beth 08/01/06 . . Sc~lIn~ePg8P NO. 3868 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 A TTN: Beth Jj} !..,.JL. Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 é)o"I-o/J Field: Prudhoe Bay WI! J b# D D CI CD e 0 Log escriptlon ate BL o or 01-17B 11209602 MCNL 04/27/06 1 1 D-25A "6" 6V6 USIT 1 D-25A 11212869 USIT 06/18/06 1 D.S. 04-31 11243929 SCMT 06/14/06 1 L5-28 11212867 USIT 06/15/06 1 2-18/L-16 11212871 SCMT 06/20/06 1 L5-28 11212872 SCMT 06/25/06 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth 06/26/06 e e e e WELL LOG TRANSMITTAL 804 - tJr~ /3wO~ February 16, 2006 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: MWD Fonnation Evaluation Logs 01-17B, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 ,.;~~.".< Ol-17B: LAS Data & Digital Log Images: 50-029-20289-02 1 CD Rom " ,:j A ~.A OLP ~. '; Vd'ð q Mm.-ck DATA SUBMITTAL COMPLIANCE REPORT 2/6/2006 Permit to Drill 2040120 Well Name/No. PRUDHOE BAY UNIT 01-17B Operator BP EXPLORATION (ALASKA) INC .~ v.¿ J I Jo~ .ÀJ!\\ 1 API No. 50-029-20289-02-00 MD 11057./' TVD 9016 /' Completion Date 2/9/2004 ./ Completion Status 1-01L Current Status 1-01L UIC N Mud Log No Samples No Directio REQUIRED INFORMATION ~..~--~~--~--_.--~"".__.._"-~------ -~---~~ DATA INFORMATION Types Electric or Other Logs Run: SGRC Combined GR & EWR, MGR / CCL / CNL Well Log Information: (data taken from Logs Portion of Master Well Data Maint Log/ Data f I ~ I I I Rpt ! +EtJ I ~. Electr Digital Dataset Med/Frmt Number Name 12733 Neutron . Log Log Run Interval OH/ Scale Media No Start Stop CH Received Comments 25 Blu 1 8518 10948 9/22/2004 COMPENSATED NEUTRON LOG/MEMORY CCLlGRlCNL 8980 11057 3/18/2004 8980 11057 3/18/2004 25 8518 1 0948 9/22/2004 COMPENSATED NEUTRON LOG/MEMORY CCLlGRlCNL 8681 11 007 9/14/2004 GRlEWR4/ROP 8681 11 007 9/14/2004 GRlEWR4/ROP Sample . Set Sent Received Number Comments ''\ &N Daily History Received? i Y /N Formation Tops D Pdt (}h¡; Directional Survey Directional Survey C '~h\~ 12733 Neutron D hl) 12769 Gamma Ray If 01\ è,,,,,J,1.1 '- tj~ 12769 LIS Verification Well Cores/Samples Information: Name Interval Start Stop ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received? -"'I I I~ Analysis ~ Received? ._._----~- Comments: Permit to Drill 2040120 MD 11057 ----~~ ^--,---_."- Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 2/6/2006 Well Name/No. PRUDHOE BAY UNIT 01-17B Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20289-02-00 TVD 9016 Completion Status 1-01L Current Status 1-01L UIC N Completion Date ·-fo- 2/9/2004 Date: _ I ç-- F~ ~ ~J~---~ - . -- p.- . . _ STATE OF ALASKA _ ALAS~IL AND GAS CONSERVATION CO~SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Repair Well 0 PluQ PerforationsD Stimulate 0 OtherD Abandon 0 Alter Casing 0 Pull Tubing 0 Perforate New Pool D WaiverO Time ExtensionO Change Approved ProgramO Operation Shutdown 0 Perforate IKJ Re-enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Œ] ExploratoryO 204-0120 3. Address: P.O. Box 196612 6. API Numbe Anchorage, Ak 99519-6612 Stratigraphic D Service 0 50-029-20289-02-00 7. KB Elevation (ft): 9. Well Name and Number: 73.00 01-17B 8. Property Designation: 10. Field/Pool(s): ADL-028329 Prudhoe Bay Field I Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 11057 feet true vertical 9016.1 feet Plugs (measured) None Effective Depth measured 11022 feet Junk (measured) None true vertical 9024.2 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 20" 101.1# H-40 32 - 111 32.0 - 111.0 1650 650 LINER 57 3-1/2" 9.3# L-80 8832 - 8889 8403.8 - 8454.2 10160 10530 LINER 1226 3-3/16" 6.2# L-80 8889 - 10115 8454.2 - 9043.7 LINER 21 2-7/8" 6.5# L-80 10115 - 10136 9043.7 - 9047.0 10570 11160 LINER 921 2-7/8" 6.16# L-80 10136 - 11057 9047.0 - 9016.1 13450 13890 PRODUCTION 2306 9-5/8" 47# R-S-95 29 - 2335 29.0 - 2334.9 8150 5080 PRODUCTION 6685 9-5/8" 47# N-80 2335 - 9020 2334.9 - 8569.3 6870 4760 SURFACE 2673 13-3/8" 72# L·80 31 - 2704 31.0 - 2703.9 4930 2670 Perforation depth: Measured depth: 9949 - 9974,10450 -10650,10888 -10913,10982 - 11007 True vertical depth: 9016.87 - 9021.5, 9060.34 - 9055.61,9040.14 - 9038.35, 9032.18 - 9027.51 Tubing ( size, grade, and measured depth): 5-1/2" 17# N-80 @ 27 - 8786 4-1/2" 12.6# N-80 @ 8786 - 8896 Packers & SSSV (type & measured depth): 5-112" Baker SAB Packer @ 8832 3-1/2" Baker KB Top Packer @ 8774 12. Stimulation or cement squeeze summary: RBDMS 8FL FEB 2 8 2005 Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Mct Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 538 18.5 9 0 2170 Subsequent to operation: 693 21.3 9 0 2065 14. Attachments: 15. Well Class after proposed work: Exploratory 0 Development ŒI Service D Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations_ ! OilŒJ GasO WAG 0 GINJO W1NJO WDSPLO Prepared by Garry Catron (907) 564-4657. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact Garry Catron NIA Printed Name Garry Catron Title Production Technical Assistant Signature 1'\ rl~ " r,·l/;-:;. Phone 564-4657 Date 2/24/05 1\ Form 10-404 Revised 4/2004 UkIGlr\~¡\L . . 01-178 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 01/23/05 Perforate 10888'-10913' 6 SPF, 10982'-11007' 6 SPF 01/24/05 Perforate 9949'-9974' 6 SPF FLUIDS PUMPED BBLS 65 1 % KCL 125 60/40 Methonal / Water 190 TOTAL Page 1 ~NOTES: :TREE = ' WELLHEAD = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum lVD = GRAY GEN II GRAY AXELSON 73' . 01-178 4438' 103 @ 11030' 9297' 8800' SS 2209' - 5-1/2" CAMCO BAL-O SSSV NIP, ID = 4.562" - 9-5/8" FO COLLAR I - 9-5/8" FO COLLAR I 13-3/8" CSG, 72#, N-80, ID= 12.347" I 2704' 8591' -1 5-1/2"CAMCO SLIDING SLV, ID=4.437" 1 8666' - 5-1/2" CAMCO DB-5 LANDING NIP, ID = 4.313"1 8757' - 5-1/2" BAKER SBR ASSY I 8774' - 9-5/8" X 5-112" BKR SAB PKR, ID = 4.0" 8786' - 5-1/2" X 4-1/2" XO I 15-1/2" TBG, 17#, N-80, .0232 bpf, ID = 4.892" I 8786' Minimum ID = 2.372" @ 10136' TOP OF 2-7/8" LINER 3-1/2" KB LNR TOP PKR, ID = 2.390" I 3.7" BKR DEPlOYMENT SLV, ID=3.0" 4-112" CA MCO DB-6 NIP (BEHIND CT LNR) 8832' 8837' 8843' 8857' -13-1/2" HES X NIP, ID = 2.813" I I 3-1/2" LNR, 8.81#, STL, .0081 bpf, ID = 2.880" I 8889' - 3-1/2" X 3-3/16" XO, ID = 2.880" I 8889' 14-1/2" TBG-NPC, 12.6#, N-80, .0152 bpf, ID = 3.958" 8896' 8896' -14-1/2" WLEG (BEHIND CT LNR) ÆRFORA TION SUMMARY REF LOG: SWS MEMORY CNLlGRlCCL ON 02/08/04 ANGLE AT TOP PERF: 80@9949' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2 6 9949 - 9974 0 01/24/05 2 6 10450 - 10650 0 02/08/04 2 6 10888 - 10913 0 01/23/05 2 6 10982-11007 0 01/23/05 CEMENT RAMP WINDOW 9020' 19-5/8" CSG, 47#, N-80, RSTSM-95, ID = 8.681" 9860' 12-7/8" LNR, 6.4#, L-80, .0058 bpf, ID = 2.44" I 10345' 13-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.805" 12-7/8" LNR, 6.16#, L-80, .0055 bpf, ID = 2.377" I DATE REV BY COMMENTS 01/22/96 ORIGINAL COMPLETION 01/24/06 CTD SIDETRACK (01-17A) 02/09/04 JDM/KA CTD SIDETRACK (01-17B) 11/29/04 DFRlTLP 9-5/8" CSG @ 9860' 01/24/05 BMcNlPJ ADPERF DA TE REV BY COMMENTS PRUDHOE BA Y UNrr WELL: 01-17B PERMrr No: 2040120 API No: 50-029-20289-02 SEe 8, T10N, R15E, 1406.68' FEL & 3362.68' FNL BP Exploration (Alaska) . . . . ~ot(JO /2- WELL LOG TRANSMIITAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: "R.::c1bin ~rm .... 333 West 7111 Avenue, Suite 100 Anchorage, Alaska 99501 September 08, 2004 RE: MWD Formation Evaluation Logs 01-17B, AK-MW.;,2890057 1 LDWG formatted Disc with verification listing. API#: 50-029-20289-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Dme1# RECEIVED SEP 'Î .: 2004 f\!aska 0" & Gas Cons. CommiS3Í01'I Anr;horoge · STATE OF ALASKA e ALASKA ~L AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 181 Oil DGas D Plugged D Abandoned D Suspended DWAG 1b. Well Class: 20AAC 25.105 20AAC 25.110 181 Development D Exploratory DGINJ DWINJ D WDSPL No. of Completions One Other D Stratigraphic Test D Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 2/9/2004 204-012 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 1/31/2004 50- 029-20289-02-00 4a. Location of Well (Governmental Section): 7. Date ToO. Reached 14. Well Name and Number: Surface: 2/6/2004 P8U 01-178 191' SNL, 646' EWL, SEC. 08, nON, R15E, UM 8. KB Elevation (ft): 15. Field 1 Pool(s): Top of Productive Horizon: 1190' NSL, 1471' WEL, SEC. 06, T10N, R15E, UM KBE = 73' Prudhoe Bay Field 1 Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 1222' NSL, 2581' WEL, SEC. 06, T10N, R15E, UM 11022 + 9024 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 697962 y- 5940712 Zone- ASP4 11057 + 9016 Ft ADL 028329 TPI: x- 695805 y- 5942038 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 694694 y- 5942041 Zone- ASP4 (Nipple) 2209' MD 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey 181 Yes DNo N/A MSL 1900' (Approx.) 21. Logs Run: SGRC Combined GR & EWR, MGR/CCL/CNL 22. CASING, LINER AND CEMENTING RECORD ~.............. CASING V..iT.PERF'T' ··ii ~ETTING ~mu"IG OEPTH'tIIP HOWIË SIZE éAADE TOP I BOTTOM ToP BOTTOM SIZE puÜ:.eDi 20" 94# H-40 Surface 119' Surface 119' 30" 250 sx Arcticset 13-3/8" 72# N-80 Surface 2704' Surface 2704' 17-1/2" 5800 sx Permafrost II 9-5/8" 47# N-80 / RS & SM-95 Surface 9020' Surface 8908' 12-1/4" 960 sx Class 'G' 3-1/2" x 3-3/16" x 2-7/8" 8.81# /6.3# /6.16# L-80 1 FL4S 8832' 11057' 8404' 9016 3-3/4" 121 sx Class 'G' 23. Perforations open to Production (MD + TVD of To,e and 24.··i ii i ·IJt:I!l'I~ .·......·./ii···. Bottom Interval, Size and Number; if none, state' none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 6 spf 5-1/2", 17#, N-80 x 8896' 8774' MD TVD MD TVD 4-1/2", 12.6#, N-80 10450' - 10650' 9060' - 9056' !25{ Acib,·..· i DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protected with 35 Bbls MeOH 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): March 11, 2004 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF W A TER-BBL CHOKE SIZE I GAS-OIL RATIO 3/22/2004 6.2 TEST PERIOD ... 140 5,437 -0- 56.5° 38,767 Flow Tubing Casing Pressure CALCULATED .. OIL-BBL GAs-McF WATER-BBL OIL GRAVITY-API (CORR) Press. 2118 75 24-HoUR RATE 543 21,046 -0- 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core c~;.jtnnnp. !':tate "none". t\ ' ¡,:n"T"'~J 1 t ..,. '.;,' ~.-~, ì tJ, None! ¿J.il~{,5 I mPÚCAIT ?, '~nR. ¡ ~. ¡ ·w· "-::.II ~ f '~~('i; ~ ; I· L:::..~,.-~....::::::J Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE (j V'? /- 28. GEOLOGIC MARKERS NAME MD Shublik A 9035' Shublik B 9058' Shublik C 9080' Sadlerochit I Zone 4B 9131' Zone 4A 9315' Zone 3 9394' Zone 2C 9507' Zone 28 9824' 24P 9936' 23P 10017' 22N 10399' 22P 10420' 29. ~ FORMATION TESTS Include and briefly summarize test results. List intervals tested, TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". 8582' None 8600' 8617' 8656' 8785' 8837' 8914' 9004' 9015' 9029' 9057' 9058' ~:DL\ 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble Title Technical Assistant Date 03-;<'3· PBU 01-17B Well Number 195-182 Permit No. I A roval No. 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. Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Mary Endacott, 564-4388 ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 e e . BP Page 1 of 14 Operations Summary Report . Legal Well Name: 01-17 Common Well Name: 01-17 Spud Date: 3/13/1978 Event Name: REENTER+COMPLETE Start: 1/14/2004 End: Contractor Name: NORDIC CALISTA Rig Release: 2/9/2004 Rig Name: NORDIC 1 Rig Number: N1 Date I From - To Hours Task Code NPT i Phase Description of Operations I ...... .-. __on .. - .... h n___ f--~--- 1/23/2004 15:30 - 17:30 2.00 MOB P PRE Rig released from 05-41A @ 15:50Hrs on 01/23/2004. Secure & hang BOP stack. SIB injector. 17:30 - 23:30 6.00 MOB N WAIT PRE W. O. -44F weather to RDMO. 23:30 - 00:00 0.50 MOB N WAIT PRE Temperature at 23:53 is -38 degrees F. Will monitor temperature for 1 hour prior to lower wind walls. 1/24/2004 00:00 - 01 :30 1.50 MOB N WAIT PRE Monitor temperature. Temperature dropped to -41 degrees F. Continue to service injector. 01 :30 - 02:30 1.00 MOB N WAIT PRE Temperature -38 degrees F. 02:30 - 02:40 0.17 MOB P PRE PJSM for removing goose neck from injector and racking injector in box. 02:40 - 06:00 3.33 MOB P PRE Remove goose neck and stand injector in box. Prepare to move rig off well and lower wind walls. RlU tarps & warm hydraulics. 06:00 - 06:15 0.25 MOB P PRE PJSM for moving rig off well. 06:15 - 07:00 0.75 MOB P PRE Jack-up, pull rig off well & set down. Clean up location & conduct post operations pad inspection. 07:00 - 08:00 1.00 MOB P PRE Install tilt rams. 08:00 - 08: 15 0.25 MOB P PRE PJSM for for lowering windwalls. 08: 15 - 09:30 1.25 MOB P PRE Unpin & lower wind walls. 09:30 - 09:45 0.25 MOB P PRE PJSM for lowering mast. 09:45-10:15 0.50 MOB P PRE Scope down & lower mast. 10: 15 - 11 :30 1.25 MOB P PRE PJSM. Jack-up rig & move rig down to pad entrance. 11:30-11:45 0.25 MOB P PRE Held pre-move safety meeting with crew, security, tool services & CPS. Review route, power line, and flow line crossings. CPS measured rig height. Measurement matches placard. 11 :45 - 14:30 2.75 MOB P PRE Move rig from DS#05 to DS#01. Line up to 01-17 well & set down. 14:30 - 15:00 0.50 MOB P PRE Conduct pre-operations pad inspection with DSO. Install dikes around tree & place rig mats in front of well. 15:00 - 00:00 9.00 MOB N WAIT PRE WO wind to subside prior to raising windwalls. Winds @ 18mph steady with 25mph gusts. Meanwhile repair valves in pit room, inspect derrick & hold pre-operations safety meeting. 1/25/2004 00:00 - 06:00 6.00 MOB N WAIT PRE Wait on wind to stabilize below 20 mph. Wind speed 15 mph gusting to 25 mph. 06:00 - 07:00 1.00 MOB N WAIT PRE Wind stabilize below 20mph. Prep to raise mast. 07:00 - 07:15 0.25 MOB P PRE PJSM. Review procedure, hazards & mitigation for raising mast. 07: 15 - 08:30 1.25 RIGU P PRE Raise mast. Wind P/U above 20mph. Decide not to raise windwalls. Ajacent DS & ODS wells are far apart from 01-17A- thus will move rig onto well, N/U BOPE while waiting on winds to calm down prior to raising the windwalls. 08:30 - 08:45 0.25 MOB P PRE PJSM for backing rig over well. Review rig back over well procedure, hazards & mitigation. 08:45 - 11 :30 2.75 MOB P PRE Prep to move rig over well. Jack up rig. Remove tree cap, companion valve on tree flowcross & secure cellar. Hang BOP stack on blocks. 11 :30 - 12:30 1.00 MOB P PRE Back rig over well & set down. Wind stabilize below 20mph. 12:30 -14:00 1.50 BOPSUF P PRE N/U BOPE. Grease crew service tree valves. 14:00 - 14:15 0.25 RIGU P PRE PJSM. Review procedure, hazards & mitigation for raising windwalls. 14:15 -15:30 1.25 RIGU P PRE Raise windwalls & secure guy wires. Secure tilt rams in storage frame. 15:30 - 15:45 0.25 RIGU P PRE PJSM. Review procedure, hazards for P/U injector & stabing Printed: 2/16/2004 9:43:41 AM It e Page 2 of 14 BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-17 01-17 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Hours Task; Code I NPT : Start: Rig Release: Rig Number: I Phase I I Perform initial BOPE pressure/function test. AOGCC test witness waived by Chuck Scheve. Blind ram test failed. Pull blind rams and replace seals. While replacing seals, bring fishing tools up to rig floor. Replace seals in blind rams. Complete BOP test. MU baker CTC. Pull test to 35,000 Ibs. Schlumberger primary computer not booting up. Wait on computer repair. Pump 4 bbls of 1 % KCL water into coil. Drop dart. Pump dart and fill coil with 1 % KCI. Dart landed at 54.5 bbls. PT inner reel valve and CTC. Unsecure well. Fill hole. WHP = Opsi, lAP = 140psi, OAP = 138psi, & FL is disconnected. PJSM. M/U fishing BHA#1 with Baker 4" GS spear, Bowen up/down jar, 2 jts of PH6 tbg & MHA. Stab injector on well. RIH with fishing BHA #1 to 8800' taking FP MeOH to tiger tank. Up wt check = 39k, Down Wt = 27k. Continue RIH to TOF tagged @ 8832'. P/U & confirm liner engagement with 50k up wt breaking over to 39k after jar lick. Retag @ set down on TOF 3x & P/U with jar licks @ 41 k (or fish slipping off). P/U liner @ 40k. POOH with liner fish pumping across the wellhead. OOH. PJSM. SIB injector. LID BHA #1 & observe no fish. Inspect "GS" spear - nothing amiss. M/U fishing BHA#2 with same Baker 4" GS spear, Bowen up/down jar, 2 jts of PH6 tbg & MHA. Stab injector on well. RIH with fishing BHA #2 to 8800'. Up wt check = 38k, Down Wt = 25k. Continue RIH circ @ 1bpm to TOF tagged @ 8832'. Set down on fish, P/U & RBIH to 8831'. Flush TOF with 1 bpm for 2mins. Set down on fish. SID pump & P/U with 41 k breaking over to 38k after jar lick. RBIH a bit faster & set down 3x. P/U to 41 k, jars go off & wt drop back to 38k. Jar down on fish 2x & retry - same results. Set down on TOF & P/U 3x with jar licks @ 40k - fish still slipping off. Set down again & jar down. P/U to 40k & jar up. Pull a bind @ 40k & bring on pumps @ 1 bpm to see if we can circ thru cut & pull free - fish slipped off. Give Up!. Set down on fish prior to POOH. DPRB DECOMP POOH with fishing BHA pumping across the wellhead. DPRB DECOMP OOH. PJSM. SIB injector. LID GS Spear & observe no fish. Inspect "GS" spear - still no unusal marks. Observe pin-hole in little jerks hydraulic hose. Use Farr power tong while W.O. replacement hose for little jerks. M/U fishing BHA#3 w/new Baker 4" GS spear (spray-painted white), same Bowen up/down jar, 2 jts of PH6 tbg & MHA. C/O packoff dies. Drop power tong direction control pin/knob in hole while M/U injector. Date I From - To ----.:.--... ... ....... .... ... --. .n.._____ ..-.---- 1/25/2004 15:30 - 15:45 0.25 RIGU P PRE 15:45 - 17:30 1.75 RIGU P PRE 17:30 - 18:00 0.50 BOPSUF P PRE 18:00 - 18:30 0.50 BOPSUF P PRE 18:30 - 00:00 5.50 BOPSUF P PRE 1/26/2004 00:00 - 01 :00 1.00 BOPSUF P PRE 01 :00 - 02:00 1.00 FISH P DECOMP 02:00 - 04:15 2.25 FISH N WAIT DECOMP 04:15 - 05:00 0.75 FISH P DECOMP 05:00 - 05:30 0.50 FISH P DECOMP 05:30 - 07:00 1.50 FISH P DECOMP 07:00 - 08:35 1.58 FISH P DECOMP 08:35 - 08:45 0.17 PULL P DECOMP 08:45 - 10:15 1.50 FISH P DECOMP 10:15 - 10:45 0.50 FISH P DECOMP 10:45 - 11:10 0.42 FISH N DPRB DECOMP 11:10-12:30 1.33 FISH N DPRB DECOMP 12:30 - 12:35 0.08 FISH N DPRB DECOMP 12:35 - 13:25 0.83 FISH N DPRB DECOMP 13:25 - 14:45 14:45 -16:00 1.33 FISH 1.25 FISH N N 1/14/2004 2/9/2004 N1 Spud Date: 3/13/1978 End: Description of Operations ..._._____._______._____._._n._ n......._ ....__.__.__ __.__. mn_ _..___...____ CT. P/U injector from stabbing box. M/U guide arch & stab CT into injector head. Meanwhile RlU hardline to tiger tank & PIT to 4000psi. Spot cuttings tank & outside trailers. Rig accepted @ 15:00 Hrs on 01-25-04. Prep to P/test BOPE. Crew change. Prepare to test BOPE. PJSM for testing BOPE. Printed: 2/16/2004 9:43:41 AM e Page 3 of 14 BP Operations Summary Report Legal Well Name: 01-17 Common Well Name: 01-17 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date I From - To ! Hours Task 1/26/2004 14:45 - 16:00 16:00 - 18:00 18:00 - 19:30 19:30 - 20:00 ........... .--00- . Code I N PT I Phase .._~_....._..._._~ ! N DPRB DECOMP N RREP DECOMP 1.25 FISH 2.00 FISH 1.50 FISH 0.50 FISH N N DPRB DECOMP DPRB DECOMP 20:00 - 21:15 1.25 FISH N DPRB DECOMP 21 :15 - 21:45 0.50 FISH N DPRB DECOMP 21 :45 - 23:45 2.00 FISH N WAIT DECOMP 23:45 - 00:00 0.25 FISH N DPRB DECOMP 1/27/2004 00:00 - 00:30 0.50 FISH N DPRB DECOMP 00:30 - 01 :00 0.50 FISH N DPRB DECOMP 01 :00 - 01 :45 0.75 FISH N DPRB DECOMP 01:45 - 04:00 2.25 FISH N DPRB DECOMP 04:00 - 05:30 1.50 FISH N DPRB DECOMP 05:30 - 07:00 1.50 FISH N DPRB DECOMP 07:00 - 08:00 1.00 FISH N DPRB DECOMP 08:00 - 09:30 1.50 FISH N DPRB DECOMP 09:30 - 10:00 0.50 FISH N DPRB DECOMP 10:00 - 10:30 0.50 FISH N DPRB DECOMP 10:30 -11:00 0.50 FISH N DPRB DECOMP 11 :00 - 11: 15 0.25 FISH N DPRB DECOMP 11:15 -12:00 0.75 FISH N DPRB DECOMP 12:00 - 13:00 1.00 FISH N DPRB DECOMP 13:00 - 13:50 0.83 FISH N DPRB DECOMP 13:50 - 14:30 0.67 FISH N DPRB DECOMP 14:30 - 14:50 0.33 FISH N DPRB DECOMP 14:50 - 15:20 0.50 FISH N DPRB DECOMP Start: Rig Release: Rig Number: Spud Date: 3/13/1978 End: 1/14/2004 2/9/2004 N1 Description of Operations _n____. . _.". . _0" ___n._ ------- Pin is steel ca. 5" long & knob ca. 9/16" OD. Changeout little jerks hyd hose. Drain BOP stack. SIB BHA#3. Cycle rams & did not see pin. Decide to make a fishing/drift run to ensure the pin fell thru TOL. RIH with fishing BHA #3. PU= 38K, SO=25.6K at 8,800'. Tag fish at 8,831'. PU to 41K and popped free. Set down at 8,831' and circulate at 3 bpm. PU to 8,800' circulating. Set down at 8,831'. Shut down pump and PU to 40.5K Ibs. Popped free. Set down and jar down. PU and pop free at 40.5K. Repeat w/ same results. Set down. Pump 3.2 bpm, 2,000 psi. Shut down pump and pick up slowly to 40.5K. Pop free again. POOH. Pull back injector and circulate coil. LD fishing BHA. Fish not recovered. No wear on GS spear. Wait on eline crew. Eline crew on location. Prepare chemical cutter. Prepare chemical cutter and test eline tools. PJSM for rigging up wireline sheeves and PU chemical cutter. Discuss hazards and mitigations for chemical cutter. RU eline sheeves. PU tools to rig floor. RIH w/2 1/8" chemical cutter. Set down at 9,043'. PU for tie in pass. Tie in to liner top. 300 Ib weight bobble at 8,940' and 8,930'. Run in hole. Set down at 8,930'. Attempt to work past several times. Pull into 5 1/2" tubing. RIH. Set down at 8,880'. POOH w/ chemical cutter. Bottom centralizer is packed with hard paraffin like substance that is preventing the centralizer from collapsing. RD eline. Call for jet blaster nozzle. Discuss plan forward with Anchorage. Plan to run jet blaster nozzle to clean out 27/8" liner and fishing neck. While waiting on jet blaster PU 8 joints of CSH and flush with water to clean out pipe. LD CSH. Wait on Schlumberger jet blaster. PJSM for PU BHA. MU Schlumberger jet blaster, disconnect, 8 joints CSH, MHA, CTC. MU injector. RIH jet blaster to 8500'. Continue RIH @ 20fpm, circ@ 1.12bpm/2250psi. Set down @ 8570' (sliding sleeve). SID pump & roll thru. Continue RIH blasting @ 1.25bpm to 88001. Up wt check = 34k, Run-in wt = 24k. Set down on TOL tagged 88331. P/U & SID pump. Flag pipe & reset CTD to 8831'. Wash down from top of 2-7/8" Inr to 9060' @ 5fpm, blasting @ 1.33bpm/3160psi. Wash up from 9060' to TOL @ 5fpm, blasting @ 1.37bpm/3290psi. Wash down from TOL to 9060' @ 1 Of pm , blasting @ 1.36bpm/3150psi. Pump 24bbls of 1 # bio pill. Getting back large pieces of asphathene over the shakers. Wash up from 9060' to TOL @ 10fpm, blasting @ Printed: 2/16/2004 9:43:41 AM e BP Page 4 of 14 Operations Summary Report Legal Well Name: 01-17 Common Well Name: 01-17 Spud Date: 3/13/1978 Event Name: REENTER+COMPLETE Start: 1/14/2004 End: Contractor Name: NORDIC CALISTA Rig Release: 2/9/2004 Rig Name: NORDIC 1 Rig Number: N1 I Hours I Date I From -To Task Code I NPT Phase Description of Operations 1 1/27/2004 14:50 - 15:20 0.50 FISH N DPRB DECOMP 1.37bpm/3120psi. Jet across TOL area @ 2fpm & 1.35bpm/3080psi. 15:20 - 18:15 2.92 FISH N DPRB DECOMP Wash up from TOL into the 5-1/2" tbg @ 13fpm, blasting @ 1.35bpm/3080psi. Paint EOP flag @ 8480' & continue POOH jet blaster @ 52fpm chasing bio pill out @ 1.36bpm/3180psi. 18:15 -19:00 0.75 FISH N DPRB DECOMP OOH. PJSM. SIB injector. RIB 1-1/4" CSH & LID jet blaster BHA. 19:00 - 19:30 0.50 FISH N DPRB DECOMP PJSM for R/U SWS Eline & running string shoUchemical cutter. Review MSDS for BrF3 & HAlHM for eline jobs. 19:30 - 19:50 0.33 FISH N DPRB DECOMP R/U SWS Eline sheeves & P/U 13' string shot & CCL tools to rig floor. M/U tools. From eeL to top string shot = 2.7'. 19:50 - 20:15 0.42 FISH N DPRB DECOMP RIH with SWS 1.7" OD string shot BHA on eline. 20:15 - 20:35 0.33 FISH N DPRB DECOMP Log CCL & tie-into TOL @ 8827'. Position CCL @ 9042.3'. Arm & shoot string shot from 9045' to 9058'. Lost 23Lbs of string wt & felt shot impact on cable & arm-meter. Log off CCL to 8945'. 20:35 - 21 :05 0.50 FISH N DPRB DECOMP POOH with SWS string shot BHA on eline. 21 :05 - 21 :35 0.50 FISH N DPRB DECOMP OOH. LID string shot. M/U chemical cutter & CCL tools. From CCL to chemical cutter = 13'. From Anchor dogs to chemical cutter = 7'. 21 :35 - 23:00 1.42 FISH N DPRB DECOMP RIH with SWS 2-1/8" OD chemical cutter BHA on eline. 23:00 - 23: 15 0.25 FISH N DPRB DECOMP Log CCL & tie-into TOL @ 8827'. Position CCL @ 9042'. Arm & shoot chemical cutter @ 9055'. Lost 30Lbs of string wt & felt shot impact on surface meter. Log off eeL to TOL. 23:15 - 00:00 0.75 FISH N DPRB DECOMP POOH with SWS string shot BHA on eline. 1/28/2004 00:00 - 01 :00 1.00 FISH N DPRB DECOMP RID SWS Eline. Inspect chemical cutter - indicates a clean cut profile. Discuss with ANC & decide to eliminate the extra GS spear run & make an ITCO spear run. 01 :00 - 01: 15 0.25 FISH N DPRB DECOMP PJSM for P/U Itco fishing BHA. 01 :15 - 02:20 1.08 FISH N DPRB DECOMP PJSM. M/U fishing BHA#5 with ITCO spear, 4" GS bait sub, Bowen up/down jar, 4jts of 2-3/8" DCs, accelerator & MHA. Stab injector on well. 02:20 - 03:55 1.58 FISH N DPRB DECOMP RIH with fishing BHA #5 to 8700'. Up wt check = 38k, Down Wt = 27k. Continue RIH to TOF tagged @ 8827'. Get 1 jar lick down. 03:55 - 04:00 0.08 FISH N DPRB DECOMP P/U & confirm liner engagement with 40k up wt. Cork jar & retag TOF. Set down 2x on TOF with 2 down jar licks. P/U liner @ 39k. 04:00 - 05:20 1.33 FISH N DPRB DECOMP POOH with liner fish pumping across the wellhead. 05:20 - 06:00 0.67 FISH P DECOMP OOH. PJSM. SIB injector. LID BHA #5 with recovered cut 2-7/8" liner assembly. Norm testing retrieved pipe. 06:00 - 08:00 2.00 FISH P DECOMP PJSM with day crew for LD liner. LD 6 joints 2 7/8" liner and one 29.25' cut joint. 08:00 - 08:15 0.25 STWHIP P WEXIT PJSM for PU BHA. 08:15 - 08:50 0.58 STWHIP P WEXIT PU used D331 mill, straight motor, MWD w/ directional gamma, MHA, CTC. 08:50 - 10:15 1.42 STWHIP P WEXIT RIH. 10:15 - 15:00 4.75 STWHIP P WEXIT Log tie in pass from 8,680' to 8,850' and 8,990' to 9,0501. Went passed liner stub w/o indication. Tagged at 9,080'. PU above stub and run back in hole. Did not see liner top again and tagged at 9,080'. PU above stub. Shut down pump and RIH. Tag liner stub at 9,040'. PU and start pumping. Attempt to go past sub again, tagged at 9,040'. Displace well to clean 1% KCI. Printed: 2/16/2004 9:43:41 AM e Page 5 of 14 BP Operations Summary Report Legal Well Name: 01-17 Common Well Name: 01-17 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date I From - To Hours: Task : Code! NPT 1 --.--.-----, -.--.---.-- -.--- .-. ...-. 1/28/2004 15:00 - 16:30 16:30 - 16:45 16:45 - 17:15 17:15 - 17:35 _.___.....__. __..___.______ t--_i....__.__... . 1.50 STWHIP P 0.25 STWHIP P 0.50 STWHIP P 0.33 STWHIP P 17:35 - 17:50 17:50 - 20:30 0.25 STWHIP P 2.67 STWHIP P 20:30 - 20:45 0.25 STWHIP P 20:45 - 22: 15 1.50 STWHIP P 22: 15 - 22:25 22:25 - 23:25 23:25 - 00:00 0.17 STWHIP P 1.00 STWHIP P 0.58 STWHIP P 1/29/2004 0.58 STWHIP P 00:00 - 00:35 Start: Rig Release: Rig Number: I Phase 1/14/2004 2/9/2004 N1 Spud Date: 3/13/1978 End: Description of Operations h_.._ _ _ .. ___. _...__. _ WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT 00:35 - 00:45 0.17 STWHIP P WEXIT 00:45 - 01 :05 0.33 STWHIP P WEXIT 01:05 - 01:15 0.17 STWHIP P WEXIT 01:15 - 03:10 1.92 STWHIP P WEXIT 03: 1 0 - 03:25 0.25 STWHIP P WEXIT 03:25 - 04:00 0.58 STWHIP P WEXIT 04:00 - 04:45 0.75 STWHIP P WEXIT 04:45 - 05:45 1.00 STWHIP P WEXIT 05:45 - 08:00 2.25 STWHIP P WEXIT 08:00 - 11: 15 3.25 STWHIP P WEXIT 11:15 -11:50 0.58 STWHIP P WEXIT 11:50-12:10 0.33 STWHIP P WEXIT ....... ....... --....-.. --- POOH. PJSM for LD BHA. LD BHA. Cut off Baker CTC. MU DS eTC. Pull test to 35,000 Ibs, PT to 3,500 psi. MU nozzle, stinger, disconnect, XO, CTC. RIH nozzle BHA & see CT EOP flag @ 8970.7' - should be @ +/-9010.6'. Correct CTD (+39.9') to 9010.6'. Continue RIH & tag up @ 9087'. Note that top of cut 2-7/8" liner is 9040' ELMD. Review cementing options with ANC & agree to pump cmt in 2 stages with nozzle @ 9080'. PJSM with all personnel concerning cementing operations. Meanwhile park nozzle @ 9080' & circ @ 2bpm/800psi. Batch mix 8bbls 17ppg class-G cmt with additives for 1 st job. Cmt to wt @ 21 :40hrs. Flush/PT lines to 4k. Pump 8bbls cmt slurry @ 2.0/2.0bpm & 1600psi. Close inner reel valve & clean lines. Chase with KCL @ 2.0/2.0bpm & 1650psi. Pump out 3bbls of cmt past nozzle & lay-in 5bbls of cmt 1: 1 to TOC @ 8970'. POOH to safety @ 8600'. Circ @ min rate while W.O.C. to swap out. RBIH @ 75fpm circ @ 2.0/2.0bpm & 1130psi jetting down to 9080'. PUH to 8600'. Meanwhile batch mix 15bbls 17ppg class-G cmt with additives for 2nd job. Cmt to wt @ 23:50hrs. RBIH & park nozzle @ 9080'. Flush/PT lines to 4k. Pump 14.9bbls cmt slurry @ 2.0/2.0bpm & 1800psi. Close inner reel valve & clean lines. Chase with KCL @ 2.5/2.5bpm & 2250psi. Pump out 7bbls of cmt past nozzle & lay-in 7.9bbls of cmt 1:1 to TOC @ 8738'. Cmt in place @ 00:35Hrs. POOH to safety @ 8600'. Pump down 30bbls of bio pill & chase to nozzle. Meanwhile got back ca. 18bbls of contaminated cmt from 1 st job - telling we were very close to a hard btm @ 9080'. RBIH @ 18fpm circ @ 2.9/2.9bpm & 1450psi jetting down to 8876'. Make 2 more up/down passes washing tbg profiles. POOH jetting uphole & washing tbg profiles @ 2.9bpm. Got back very little contaminated cmt from 2nd job. OOH. PJSM. LID Cement nozzle BHA. M/U swizzle stick & jet BOP stack. LIO swizzle stick & SIB injector. PJSM. M/U cement milling BHA #8 with 3.80" HC D331 mill, 2-7/8" WF motor with 1.25deg ABH, Sperry GR-DIR MWD & orienter, 2 jts of 2-3/8" PH6 tbgs & WF MHA (OAL = 127.12'). Scribe tools. Install WF CTC. Pull test to 35k. P/test MHA & CTC to 3500psi. M/U injector. RIH cement milling BHA #8. SHT MWD @ 1000' - pulsing off & on. Troubleshoot MWD & rectify pulses. Continue RIH. WOC to gain compressive strength. Cement at 4,000 psi compressive strength. Tie in. +7' correction. RIH and tag cement stringer at 8,899'. Wash down to 8,914' at Printed: 2/16/2004 9:43:41 AM e Page 6 of 14 BP Operations Summary Report Legal Well Name: 01-17 Common Well Name: 01-17 Event Name: REENTER+COMPLETE Start: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: ~ate____ i~~_-~~_\~~~ ·:rask :, COd~.J ~PT : ~~as_~L___ ______~es_:~iPtion of~_~~ration=-_______ 1/29/2004 220 fph. Pull up hole and wait on cement. Mill hard cement from 8,920' to 9,000' at 150 R of HS at 20 fph. Continue milling hard cement with bio-KCL from 9000' to 9008" with 150R TF, 2.6/2.6bpm, 2200/2580psi, 15fph ave consistent ROP. Finish LS cement pilot hole. Orient TF to 30L for HS cement ramp. Mill 12' cement ramp in hard cement from 9008' to 9020' with 20-30L TF, 2.6/2.6bpm, 2250/2580psi, 15fph ave consistent ROP. PUH to 8750' @ HS TF, 2.5bpm, 2250psi & 60fpm. Log up GR from 8750'. Subtract l' from CTD. Paint EOP flag @ 8500'. POOH cement milling BHA#8. OOH. SIB injector. Flush BHA. R/B 2jts of 2-3/8" PH6 tbg. LID 1.25deg ABH motor & D331 mill. M/U window milling BHA #9 with 3.80" HC DP0088 mill, 2-7/8" WF 3deg fixed motor, Sperry GR-DIR MWD & orienter, 2 jts of 2-3/8" PH6 tbgs & WF MHA (OAL = 126.97'). Scribe tools. M/U injector. RIH window milling BHA #9. SHT MWD @ 4500' - OK. Continue RIH. Continue RIH window milling BHA #9. Correct -31 @ the flag. Tag up @ 8719'. P/U & kick-on pumps & roll thru. Continue RIH & tag 9-5/8" csg wall @ 9020'. PUH & orient TF to 30L. SID pump. RBIH & tag csg wall @ 9020'. Check TF - @ 15L. Establish freespin @ 2250psi. Paint flag & P/U 1'. Begin extended time milling schedule. Mill from 9019' to 9020' with HS TF, 2.6/2.6bpm, 2270psi. Continue extended time milling schedule. Start seeing WOB at 9,020.6'. Time mill to 9,021.0'. Lost #1 mud pump. Switch to #2 pump and got a click. Pressure is up to 3,600 psi. Pick up into pilot hole and orient around. Pressure still 1300 psi higher. Swap back to pump #1. Pressure 3,600 psi. Pull into 5 1/2" tubing, pressure still high. Orient and pressure came back down to 2,300 psi. RIH w/o pump. Tag at 9,020.9'. PU and bring on pump. TF 10L. Tag lightly at 9,020.9'. Pick up one foot and start window milling time schedule over. Mill to 9,021.6'. Bleed IA to 10 psi and OA to 150 psi. Continue extended time milling schedule. Mill to 9025' with 10L-HS TF, 2.6/2.6bpm, 2300/2750psi & 3-4k WOB. Getting good amount of metal shavings on ditch magnets. Mill to 9026.2' with 1 0-20L TF, 2.6/2.6bpm, 2850psi & 4-5k WOB. Continue time milling to 9027' with 20-30L TF, 2.6/2.6bpm, 2950psi, 1fph & 5-6k WOB. Observe pressure dropping to 2750psi, WOB dropping to 4k & TF walking back to 15L. Stall @ 9027.4'. P/U & establish freespin @ 2450psi. Ease back into milling & break into formation. TOW = 9020'; BOW = 9027'. Mill formation to 9036' with 10-20L TF, 2.6/2.6bpm, 2450/2650psi, 1 Of ph ave ROP & 4k WOB. 11 :50 - 12:10 0.33 STWHIP P WEXIT 12:10 -13:30 1.33 STWHIP P WEXIT 13:30 - 18:00 4.50 STWHIP P WEXIT 18:00 - 18:40 0.67 STWHIP P WEXIT 18:40 - 18:50 0.17 STWHIP P WEXIT 18:50 - 19:45 0.92 STWHIP P WEXIT 19:45 - 19:55 0.17 STWHIP P WEXIT 19:55 - 20:45 0.83 STWHIP P WEXIT 20:45 - 22:00 1.25 STWHIP P WEXIT 22:00 - 22:30 0.50 STWHIP P WEXIT 22:30 - 23:00 0.50 STWHIP P WEXIT 23:00 - 00:00 1.00 STWHIP P WEXIT 1/30/2004 00:00 - 00:45 0.75 STWHIP P WEXIT 00:45 - 01 :00 0.25 STWHIP P WEXIT 01 :00 - 06:00 5.00 STWHIP P WEXIT 06:00 - 09:00 3.00 STWHIP P WEXIT 09:00 - 10:45 1.75 STWHIP P WEXIT 10:45 - 18:00 7.25 STWHIP P WEXIT 18:00 - 22:50 4.83 STWHIP P WEXIT 22:50 - 00:00 1.17 STWHIP P WEXIT 1/31/2004 00:00 - 01 :30 1.50 STWHIP P WEXIT 01 :30 - 02:15 0.75 STWHIP P WEXIT 1/14/2004 2/9/2004 N1 Spud Date: 3/13/1978 End: Printed: 2/16/2004 9:43:41 AM e e BP OperationsSummary Report Page Tof 14 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-17 01-17 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: Rig Release: Rig Number: 1/14/2004 2/9/2004 N1 Spud Date: 3/13/1978 End: Date From - To Hours Task Code NPT! Phase Description of Operations i ._...__..h . ". .. ....--.... -.-..-.. -- n__________ ...-..-.... .--....-..-.. .. ...... ...---...-- -.-...-....-.---.. . - ..... ...___..__ __n _. ...__..____.._..__...._....____..._._..._._. ___ 1/31/2004 02:15 - 02:30 0.25 STWHIP P WEXIT Backream rat hole & window from 9036' to 9015' with 1 OL TF, 2.6/2.6bpm, 2450psi, 65fph ave ROP & 4k WOB. 02:30 - 04:10 1.67 STWHIP P WEXIT Paint EOP flag @ 85001 & POOH window milling BHA#9. 04:10 - 04:45 0.58 STWHIP P WEXIT OOH. SIB injector. Flush BHA. RIB 2jts of 2-3/8" PH6 tbg. LID 3deg fixed motor & DP0088 mill. Mill gauge 3.80" go / 3.79" no-go & wear on mill face indicates that center crossed the csg wall. 04:45 - 05:15 0.50 STWHIP P WEXIT M/U window dressing BHA #10 with 3.79" WF diamond crayola mill, 2-7/8" WF 2.25deg ABH motor, Sperry GR-DIR MWD & orienter, 2 jts of 2-3/8" PH6 tbgs & WF MHA (OAL = 127.5'). Scribe tools. M/U injector. 05: 15 - 07:30 2.25 STWHIP P WEXIT RIH window dressing BHA #10. SHT MWD @ 4500' - OK. Continue RIH. Correct to 8,500' EOP, -1.5'. Tie in to GR, +1'. RIH w/o pumping. Tag at 9,029'. 07:30 - 11 :30 4.00 STWHIP P WEXIT Bring on pump, TF 45R. Orient to 31 L. Reduce rate. Set down at 9,027'. PU w/ overpull. PU w/ overpull and repeat. PU w/5K overpull and check TF, 31L. SD pump. RIH and tag at 9,027'. PU 4' and bring up pump. TF 8L. Tag at 9,027' and stall motor. PU and dress window at 11 L. Stalling at 9,027'. Ream down through bottom of window from 9,027' to 9,029' at 11 L TF. Back ream window from 9,029' to 9,018' at 11 L. Back ream window at 27R. Tag bottom at 9,036'. Orient around to 49L. Back ream window. Drift w/o pump. Orient 25L, start new mud down coil. Back ream window. 11 :30 - 13:00 1.50 STWHIP P WEXIT POOH while displacing to reconditioned flo pro. 13:00 - 14:00 1.00 STWHIP P WEXIT Clean pits. 14:00-15:15 1.25 STWHIP P WEXIT LD crayola milling BHA. Mill gauged 3.78". 15:15-16:00 0.75 DRILL P PROD1 PU drilling BHA. 16:00 - 16:40 0.67 DRILL P PROD1 Change CTC. Pull test to 35 Kips and PT to 3,500 psi. 16:40 - 18:15 1.58 DRILL P PROD1 RIH. SHT MWD and orienter. RIH. 18:15-18:45 0.50 DRILL P PROD1 Log down GR from 8720'. Subtract 4' from CTD. RIH to 8950'. 18:45 - 18:50 0.08 DRILL P PROD1 Orient TF to 15L. RIH & tag TD @ 9035'. 18:50 - 19:55 1.08 DRILL P PROD1 Drill to 9045' with 20L TF, 2.6/2.6bpm, 3300/3480psi, 14fph ave ROP. TF roll to 30R. 19:55 - 20:10 0.25 DRILL P PROD1 Orient TF around to 50L. 20: 10 - 00:00 3.83 DRILL P PROD1 Drill Shublik to 9080' with 50-70L TF, 2.6/2.6bpm, 3250/3550psi, 15fph ave ROP. 2/1/2004 00:00 - 05:30 5.50 DRILL P PROD1 Orient & drill Shublik to 9150' with 50-75L TF, 2.6/2.6bpm, 3000/3450psi, 15fph ave ROP. Get a drilling break @ 9150'. 05:30 - 06:00 0.50 DRILL P PROD1 Orient & drill to 9170' with 60L TF, 2.6/2.6bpm, 3100/3550psi, 45fph ave ROP. 06:00 - 11 :50 5.83 DRILL P PROD1 Drill to 9,350' at 2.5/2.5 3,000/3,280 psi. 11:50-12:10 0.33 DRILL P PROD1 Wiper trip to window. 12:10 - 12:20 0.17 DRILL P PROD1 Orient to 77L. 12:20 - 18:25 6.08 DRILL P PROD1 Drill to 9442' with 2.5/2.5 3,200/3,400 psi 10 - 30 fph average ROP. 18:25 - 19:25 1.00 DRILL P PROD1 Drill to 9446' with 70L TF, 2.5/2.5bpm, 3000/3250psi, 4fph ave ROP. Penetrated Zone-3 @ 9395' & expect to penetrate Zone-2 @ +/- 9500'. Decide to POOH due to very slow ROP. 19:25 - 20:55 1.50 DRILL P PROD1 Paint EOP flag @ 8500' & POOH drilling BHA#11. 20:55 - 21 :40 0.75 DRILL P PROD1 OOH. SIB injector. Flush & LID BHA. Bit gauge 8/6/1 with a partially rung-out nose. 21 :40 - 00:00 2.33 BOPSUF P PROD1 PJSM. Grease master & swab valves & perform weekly BOPE Printed: 2116/2004 9:43:41 AM - e BP Page 8 of 14 Operations Summary Report Legal Well Name: 01-17 Common Well Name: 01-17 Spud Date: 3/13/1978 Event Name: REENTER+COMPLETE Start: 1/14/2004 End: Contractor Name: NORDIC CALISTA Rig Release: 2/9/2004 Rig Name: NORDIC 1 Rig Number: N1 I I Date I ,. Code ¡ NPT Phase Description of Operations From - To : Hours' Task _____n__ .... --...--.- .......... ...n.... ..._____ .....-.... "-." ..... ........... _.. ....n. .___._______.._. .___.nnn__._.__._ _______._.___._______._ 2/1/2004 21 :40 - 00:00 2.33 BOPSUF P PROD1 pressure/function test. AOGCC test witness waived by John Crisp. 2/2/2004 00:00 - 03: 15 3.25 BOPSUF P PROD1 Continue weekly BOPE pressure/function test. P/test inner reel valve. 03: 15 - 04:20 1.08 DRILL P PROD1 PJSM. M/U drilling BHA #12 with rebuilt HYC DS49 bit, 1.37deg bend motor, GR-DIR MWD, orienter & MHA. Scribe tools. M/U injector. Plan to drill thru zone-3 before P/U EWR. 04:20 - 06:00 1.67 DRILL P PROD1 RIH BHA #12. SHT MWD @ 4500' - OK. RIH to EOP flag. Subtract 5.7' from CTD. Continue RIH & tag TD @ 9447'. 06:00 - 06:20 0.33 DRILL P PROD1 Orient TF to 90L. 06:20 - 11 :00 4.67 DRILL P PROD1 Drill 9,025' at 2.45/2.45 3,340 psi, TF 80 - 90L. Drilling break at 9,508'. 11:00 - 12:45 1.75 DRILL P PROD1 Pull off bottom. Pin hole in coil at 9,435' EOP. SD pump. Pull into tubing. POOH. Change out shaker motor while POOH. 12:45 - 13:30 0.75 DRILL P PROD1 LD BHA. 13:30 - 14:44 1.23 DRILL N RREP PROD1 Pump 2 bbls of diesel back into coil for FP. Prepare to blow down reel. 14:44 - 18:30 3.77 DRILL N RREP PROD1 Pump 60 bbls of fresh water to flush reel. Blow down reel with N2. Install internal CTC. 18:30 - 19:00 0.50 DRILL N RREP PROD1 Crew change & PJSM for spooling back CT to reel. 19:00 - 21:30 2.50 DRILL N RREP PROD1 Pull test internal CTC - OK. Pull & spool back CT to reel. Secure & prep reel for shipment. 21 :30 - 21:45 0.25 DRILL N RREP PROD1 PJSM with Peak crew on CT reel swap. 21:45 - 00:00 2.25 DRILL N RREP PROD1 P/U & lower reel to Peak double drop trailer. Replace reel drive bushings. P/U replacement reel into reel house & align drive pins & bushing. 2/3/2004 00:00 - 04:00 4.00 DRILL N RREP PROD1 PJSM. RlU hardline to inner reel valve. Slip grapple into CT & pull test. Pull CT over pipe shed with winch & stab into injector. 04:00 - 13:00 9.00 DRILL N RREP PROD1 PJSM. C/O injector gripper blocks and packoff. Nothing found out of spec. 13:00 - 13:30 0.50 DRILL N RREP PROD1 Install CTC. 13:30 - 15:00 1.50 DRILL N RREP PROD1 Pull test and PT CTC. Nordic 1 off NPT at 1500 hrs 15:00 - 16:30 1.50 DRILL P PROD1 PU drilling BHA w/ bicenter bit and RES tool. Upload MWD. 16:30 - 16:50 0.33 DRILL P PROD1 RIH Shallow hole test MWD @ 4501' 16:50 - 18:50 2.00 DRILL P PROD1 Tie in at 8735' to 8765' (-4' correction) 18:50 - 19:10 0.33 DRILL P PROD1 Tighten bolts on reel. 19:10 - 19:33 0.38 DRILL P PROD1 RIH through cement window Tagged at 9446 ft went through to 9463' 19:33 - 19:45 0.20 DRILL P PROD1 Sticky at 9446 ft.RIH to 94631 Back ream 9463 ft to clean hole up. Unable to get below 9460' Bit change at 9446' (DS100 to DS 49) Vp =284 bbl Qp = 2.83bpm Pp = 3149 psi 19:45 - 21 :00 1.25 DRILL P PROD1 WR to bottom at drilled TF of 61 L from 9440' to 9525 ft at 50 to 60 fph Orient TF as per drilled while WR to bottom. 21:00 - 21:15 0.25 DRILL P PROD1 Orient TF to 0 to 30L. 21:15 - 21:55 0.67 DRILL P PROD1 Drilling TF 29L. Qp = 2.43 bpm, Cir @ 1: 1; Vp = 284 bbl 21 :55 - 22:00 0.08 DRILL P PROD1 Orient TF from 30L to 30R 22:00 - 00:00 2.00 DRILL P PROD1 Drilling @ TF 15 to 30 R. Qp = 2.48/2.57, Pp = 3303 psi on btm; ROP = 50 fph Depth at 2400 hr is 9615 ft 2/4/2004 00:00 - 01 :07 1.12 DRILL P PROD1 Drilling @ TF 30 to 50 R. Qp = 2.53/2.65, Pp = 3340 psi on btm; ROP = 48- 50 fph. Vp = 281 bbl. Last 3 surveys DLS = 24.9 deg/100ft. Drilled to 9,665 ft. 01 :07 - 02:40 1.55 DRILL P PROD1 POOH to change bend on motor. Vi = 281 bbl 02:40 - 02:50 0.17 DRILL P PROD1 PJSM on changing the motor setting/AKO. Vp =227 bbl Printed: 2/16/2004 9:43:41 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: e e Page 9 of 14 BP Operations Summary Report . 01-17 01-17 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 ¡ i ¡ From - To Hours; Task ¡Code NPT' i ____--._____u ___. .____.__._ .....___ ____. __._.. .. Date 2/4/2004 02:50 - 03:15 03:15 - 04:41 04:41 - 05:26 05:26 - 05:50 05:50 - 06:00 06:00 - 06:30 06:30 - 06:45 06:45 - 08:45 08:45 - 09:00 09:00 - 10:15 10:15 -11:15 11: 15 - 11 :30 11 :30 - 13:30 13:30 - 15:00 15:00 - 16:00 16:00 - 17:30 17:30 - 17:40 17:40-18:10 18:10 -18:46 18:46 - 19:09 19:09 - 19:30 19:30 - 20:48 20:48 - 21 :14 21:14 -21:56 21:56 - 22:14 22:14 - 23:05 23:05 - 00:00 2/5/2004 00:00 - 01 :45 01:45 - 03:41 0.42 DRILL P 1.43 DRILL P 0.75 DRILL P 0.40 DRILL P 0.17 DRILL P 0.50 DRILL P 0.25 DRILL P 2.00 DRILL P 0.25 DRILL P 1.25 DRILL P 1.00 DRILL P 0.25 DRILL P 2.00 DRILL P 1.50 DRILL P 1.00 DRILL P 1.50 DRILL P 0.17 DRILL P 0.50 DRILL P 0.60 DRILL P 0.38 DRILL P 0.35 DRILL P 1.30 DRILL P 0.43 DRILL P 0.70 DRILL P 0.30 DRILL P 0.85 DRILL P 0.92 DRILL P 1.75 DRILL P 1.93 DRILL P Phase PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Start: 1/14/2004 Rig Release: 2/9/2004 Rig Number: N1 Spud Date: 3/13/1978 End: Description of Operations .._,. ... .... .-.. .." ____ ..._. __. ___. __m_ ....._._......____. ._________._ Change AKO from 1.37 to 1.04 RIH to 8745 to tie-in Tie-in GR marker (-4.5 ft correction) 8745 ft to 8773 ft RIH to 9665' Vp = 277 bbl Orient TF to 90 to 100 R Drilling TF @ 88 to 11 OR, Qp = 2.64/2.81 bpm, Pp = 3582psi on btm, Vp= 276 bbl. ROP = 50 fph. Drilled to 9685 ft. Orient TF around to 90R. Orienter working well. Drilling upper Zone 2. 2.5/2.5 bpm, 33250 - 4000 psi, 50 fph, 81 deg, 95R TF, Drilled to 9,7751. Orient TF to 70R. Drilling upper Zone 2. 2.5/2.5 bpm, 33250 - 4000 psi, 50 fph, 81 deg, 75R TF, Drilled to 9,840'. Wiper trip to window. Clean hole. RIH. Orient TF to 150L. Drilling Zone 2. 2.5/2.5 bpm, 33250 - 4000 psi, 40 fph, 87 deg, 150 TF, Drilled to 9,890'. Drilling 24N shale, slow drilling. 2.5/2.5 bpm, 33250 - 4000 psi, 25 fph, 87 deg, 150 TF, Drilled to 9,902 ft. Stacking wt in 24N shale. Coil not sliding. New FloPro on location. Wiper trip before swapping to new FloPro. Clean hole. RIH. Swap to new FloPro at 9,902 ft. Drilling Zone 2, 24N Shale with new FloPro. 2.5/2.5 bpm, 2900 - 3600 psi, 170L, 84 deg. Drilled to 9945 ft. Orient TF to 120L. Drilling Zone 2, 2.5/2.5 bpm, 2900 - 3600 psi, 120L, 81 deg. Drilled to 9,955 ft. Drilling Zone 2, 2.5/2.5 bpm, 2900 - 3600 psi, 120L, 81 deg. Drilled to 9988 ft Drilling Zone 2, 2.5/2.5 bpm, 2900 - 3820 psi, 84 to 120L, 81 deg. Drilled to 9998 ft Orient TF to 75L. Mud swap finished Drilling Zone 2, 2.5/2.5 bpm, Pp = 2,900 to 3,820 psi, TF@ 90L. Drilling lower section 24N and into 23P transtion zone. Slow drilling due to stacking up hole and on bottom Vp = 310 bbl. Depth = 10,020ft Having trouble getting wt. to bit transfer, Stacking, PUH with wiper trip to tie-in (coming up). CoilCat shows 60% at this trouble area (10020 ft) Tie-in coming up from 9195 ft (Corrected -1 ft) RIH after tie-in Tagged bottom, TF at 79L. Drilling, Q = 2.65/2.70 bpm; Pp=3,000 /3,465 psi, Vp = 303 bbl Drilled 16 ft without stacking. Started to stack and lose pump differentail. Top of 23P at 10,030' MD / 8,962' TVDss. Drilling at 10,056 ft. ROP inc to 100 fph Drilling in 23P Q = 2.67 /2.79 bpm, Pp = 3,000/3,552 psi, TF@ 90 L. ROP = 90 fph Drilled from 10,056 ft to 10,095 ft Drilling in 23P 2.67 /2.79 bpm, Pp = 3,000/3,340 psi, TF@ 90 to 110 L. ROP = 90 fph. Vp = 298 bbl. Drilled from 10095 ft to 10,176 ft. ROP ave = 45 fph. Unable to get the required BR & TR. Pump up survey, POOH to PU higher AKO setting Printed: 2/16/2004 9:43:41 AM e e Page 10 of 14 BP Operations Summary Report . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-17 01-17 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 i 1 Date From - To , Hours · Task Code I NPT ! Phase ---... ......--... ... .. u.______ ¡ 2/5/2004 03:41 - 06:05 2.40 DRILL P PROD1 06:05 - 06:15 0.17 DRILL P PROD1 06: 15 - 08:25 2.17 DRILL P PROD1 08:25 - 08:40 0.25 DRILL P PROD1 08:40 - 09:40 1.00 DRILL P PROD1 09:40 - 10:00 0.33 DRILL P PROD1 10:00-10:15 0.25 DRILL P PROD1 10:15 -11:15 1.00 DRILL P PROD1 11:15-12:10 0.92 DRILL P PROD1 12:10 - 12:30 0.33 DRILL P PROD1 12:30 - 13:30 1.00 DRILL P PROD1 13:30 - 14:15 0.75 DRILL P PROD1 14:15 - 14:50 0.58 DRILL P PROD1 14:50 - 16:45 1.92 DRILL P PROD1 16:45 -17:10 0.42 DRILL P PROD1 17:10 - 17:30 0.33 DRILL P PROD1 17:30 - 18:30 1.00 DRILL P PROD1 18:30 - 19:35 1.08 DRILL P PROD1 19:35 - 21 :30 1.92 DRILL P PROD1 21 :30 - 21 :45 0.25 DRILL P PROD1 21 :45 - 22:00 0.25 DRILL N SFAL PROD1 22:00 - 22:50 0.83 DRILL P PROD1 22:50 - 23:25 0.58 DRILL N DFAL PROD1 23:25 - 00:00 0.58 DRILL N DFAL PROD1 2/6/2004 00:00 - 00:45 0.75 DRILL N DFAL PROD1 00:45 - 01 :15 0.50 DRILL P PROD1 01:15 - 01:30 0.25 DRILL P PROD1 01 :30 - 02:05 0.58 DRILL P PROD1 02:05 - 02:18 0.22 DRILL P PROD1 02:18 - 03:00 0.70 DRILL P PROD1 03:00 - 03:08 0.13 DRILL P PROD1 03:08 - 03:51 0.72 DRILL P PROD1 03:51 - 04:08 0.28 DRILL P PROD1 04:08 - 04:30 0.37 DRILL P PROD1 Start: 1/14/2004 Rig Release: 2/9/2004 Rig Number: N1 Spud Date: 3/13/1978 End: Description of Operations --------.---.....- ....- .. _.... .... .... .. ._._n u. .._~___.____.._.. .... OOH, vp = 239 bbl bbl (59 bbl) JSA, Handle BHA, Set AKO setting to 1.69 , PU DS 49 RIH and down load EWR memory. MU tools and injector head RIH with MWD/RES BHA with 1.69 deg motor and 3.75" DS49 bit. Shallow hole test. RIH. Went thru window clean. RIH to TD. Tag TD at 10,184 ft. Correct Depth to 10,176 ft. Orient TF to 30L. Drilling Z2 in 23 P clean sand. 2.5/2.5 bpm, 2900 - 3600 psi, 45L, 90 fph, 88 deg, Drilled to 10,244 ft. Drilling Z2 in 23 P clean sand. 2.5/2.5 bpm, 2900 - 3600 psi, 55L, 90 fph, 88 deg, Drilled to 10,255 ft. Orient TF to 80L. Drilling Z2 in 23 P clean sand. 2.5/2.5 bpm, 2900 - 3600 psi, 70L, 100 fph, 90 deg, Drilled to 10,350 ft. Landed well at 10,240 ft at 8983 ft TVDSS as per Geo. Wiper trip to window. Clean hole. Pull thru window and up to 8735 ft. Log GR Tie-in at 8712 ft. Added 16 ft to CTD. RIH. Reamed down across shales at 9960 ft at 6 fpm, RIH clean and tag TD of 10,362 ft. Drilling Z2 in 23 P clean sand. 2.5/2.5 bpm, 3000 - 3600 psi, 95L, 110 fph, 88 deg, Drilled to 10,440 ft. Drilling Z2 in 23 P clean sand. 2.5/2.5 bpm, 3000 - 3600 psi, 70L, 110 fph, 86 deg, Drilled to 10,482 ft. Wiper trip to window, ream shales from 10,020 - 9,820'. Clean up to window. Pull up thru window to 8850 ft. RIH thru window OK. RIH thru shales with no problems. RIH to TD. Orient TF to 45R. Drilling Z2 in 23 P clean sand. 2.5/2.5 bpm, 3100 - 3600 psi, 45R, 120 fph, 92 deg, Drilled to 10,526 ft. POH to adjust motor down to 1.04 deg motor. Pull thru window OK. Flag CT at 8,0001 EOP. POH. JSA, change out motor and set AKO to 1.04 deg, MU Bit RR9 and download EWR tool. Set counters, RIH to 1872 ft Sheared 1 bolt on reel, Replaced bolts/nuts RIH and shallow hole test MWD at 4,520 ft. Orienter Failed test POOH to change out Orienter Start NPT time Change out Orienter. RIH to 4,520, Shallow hole tested orienter, (ok) RIH at min flowrate to 8,740 ft Tie-in at 8740 ft down (+6 ft correction) RIH and tagged bottom at 10,527 ft Orient TF to 30 R Drilling Vp = 244 bbl Q = 2.60/2.64 bpm ROP = 130 fph Orient TF to 3R Drilling Vp = 244 bbl Q = 2.60/2.64 bpm ROP = 130 fph Drilled 10,580' to 10,650 ft Orient TF around to 60 R Drilling TF at 50 to 60R. Vp = 239 bbl Q = 2.53/2.61 bpm ROP Printed. 2/16/2004 9A3A1 AM e Page 11 of 14 BP Operations Summary Report = 80 to 130 fph Wiper trip to window @ 9,060 ft. PO RIH at 10670 ft Drilling TF @ 53R, Q = 2.46/2.57 bpm, Pp = 3,000/3,385 psi, WOB = 5k ROP = 100 fph. Vp = 231 bbl, Drilled to 10,700 ft. Orient TF to 70R. Drilling Z2, 2.5/2.5 bpm, 3150 - 3800 psi, 93 deg, 85L, Drill slow thru thin shales. Drilled to 10,780 ft. Ordered new FloPro to enhance drilling. Drilling Z2, 2.5/2.5 bpm, 3150 - 3800 psi, 92 deg, 60R, Drill slow thru thin shales. Drilled to 10,820'. Stacking weight. Wiper trip to window. 36K up wt. Had motor work / overpull in shales at 9830-10030'. Clean to window. RIH clean thru shales. RIH clean to TD. Swap to new FloPro. Drilling Z2 with new FloPro, starting at 10,820'. 2.7/2.7 bpm, 3200 - 3800 psi, 96 deg, 60R, Very slow drilling in shales. Stacking weight, even with new FloPro with 4% L T. Drilled to 10,866 ft. PROD1 Drilling Z2 Shales with new FloPro, 2.7/2.7 bpm, 3000 - 3600 psi, 97 deg, 90L, Slow drilling in shales from 10835-10870 ft. Stacking weight, even with new FloPro with 4% LT. Drilled to 10,906 ft. Orient TF to 60L. Drilling Z2, 2.7/2.7 bpm, 3100 - 3700 psi, 93 deg, 30L, 90 fph, Drilled to 10,955 ft. Wiper trip to 9,070 ft due to bit stacking Orient TF to 30R RIH Tagged at 10955' Drilling with negative wt. @ 29L TF. Q = 2.64/2.77 bpm; Pp 3100/3400 psi; Vp = 294 bbl. Making 30 ft wiper trips to get the last 10ft hole. Drilled to 11050 CTMD Let WOB drill off Wiper trip to tie-in following TD of well Pulled to 8,745 ft Tie in, from 8,745' to 8,758.5 ft Corrected +10 ft) to 8,768.5 ft RIH to confirm TD. Tagged bottom of window at 9,027' PU and RIH 1 st time. RIH and tagged TD at 11,057' Confirmed w/ Sperry Sun POOH. Flagged at 6,700' and 8,700' EOP PJSM, Handle BHA, Download Res Tool Finished Res Downloading, LD drilling BHA Prep rig floor to run liner. SAFETY MEETING. Review Procedure, hazards and mitigation for running liner. M/U 2-7/8" Float equipment and 29 jts of 2-7/8", FL4S liner with turbos, M/U LSL sub and fill liner. M/U 39 jts of 3-3/16", Tell with turbos, XO, 1 jt. of 3-1/2" STL liner, Howco X nipple, 3-1/2" Pup jt, 3-1/2" pup jt and 3.70" OD Baker Deployment sleeve with 3.0" ID. Total length of liner = 2,219.62 ft. M/U Baker CTLRT. COMP Cut off SWS CTC. M/U Baker CTC, Pull and pressure test connector. M/U injecter head. Total BHA = 2,228.72 ft. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 01-17 01-17 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 ··Date From - To ! Hours ¡ Task Code NPT ¡ Phase 1 I ---.-. - ..- - ...-----.- 2/6/2004 04:08 - 04:30 0.37 DRILL P PROD1 04:30 - 06:00 1.50 DRILL P PROD1 06:00 - 06:30 0.50 DRILL P PROD1 06:30 - 06:50 0.33 DRILL P PROD1 06:50 - 10:00 3.17 DRILL P PROD1 10:00 - 11 :45 1.75 DRILL P PROD1 11:45 - 13:40 1.92 DRILL P PROD1 13:40 - 15:40 2.00 DRILL P PROD1 15:40 - 17:00 1.33 DRILL P 17:00 -17:10 0.17 DRILL P PROD1 17:10 -18:15 1.08 DRILL P PROD1 18:15 - 20:05 1.83 DRILL P PROD1 20:05 - 08:12 12.12 DRILL P PROD1 08:12 -11:09 2.95 DRILL P PROD1 11 :09 - 00:00 12.85 DRILL P PROD1 2/7/2004 00:00 - 00:30 0.50 DRILL P PROD1 00:30 - 00:50 0.33 DRILL P PROD1 00:50 - 01 :55 1.08 DRILL P PROD1 01 :55 - 04:30 2.58 DRILL P PROD1 04:30 - 06:00 1.50 DRILL P PROD1 06:00 - 07:00 1.00 DRILL P PROD1 07:00 - 07:30 0.50 CASE P COMP 07:30 - 07:45 0.25 CASE P COMP 07:45 - 10:00 2.25 CASE P COMP 10:00 - 12:00 2.00 CASE P COMP 12:00 - 12:45 0.75 CASE P Start: 1/14/2004 Rig Release: 2/9/2004 Rig Number: N1 Spud Date: 3/13/1978 End: Description of Operations ...._.u....._._____..___ _..___.. ....' .___n Printed: 2/16/2004 9:43:41 AM e Page 12 of 14 BP Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: I Date I From - To 01-17 01-17 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Hours ¡ Task Code NPT Start: Rig Release: Rig Number: Phase 1/14/2004 2/9/2004 N1 Spud Date: 3/13/1978 End: -..--- --------... 2/7/2004 12:45 - 13:45 13:45 - 15:30 15:30 - 16:00 16:00 - 16:45 16:45 - 17:00 17:00 - 17:40 17:40 -18:15 18:15 -18:55 18:55 - 20:30 20:30 - 22:15 22:15 - 22:30 22:30 - 00:00 2/8/2004 00:00 - 02:00 02:00 - 03:36 03:36 - 04: 10 ......... ___ n 1.00 CASE P ------ . COMP 1.75 CASE P COMP 0.50 CASE P COMP 0.75 CASE P COMP COMP 0.25 CEMT P COMP 0.67 CEMT P COMP 0.58 CEMT P 0.67 CEMT P COMP 1.58 CEMT P 1.75 CEMT P COMP COMP 0.25 EVAL P 1.50 EVAL P COMP COMP 2.00 EVAL P COMP COMP 1.60 EVAL P COMP 0.57 EVAL P Description of Operations .... ---.------------ -------... .. ... ....... .------ RIH with liner on CT. Circ at 0.4 bpm, 700 psi. Stop at flag on CT at 6600' EOP. Shoe at 8826 ft. Correct -13 ft. Up wt = 40K. RIH, went thru window clean, RIH at 70 fpm, circ. 0.35 bpm at 1080 psi, Dwn Wt = 24.5K. Ran thru shales at 10000 ft clean. RIH. Sat down at 10795', 108331. Sat down full wt at 10867' several times. Pull up hole 200 ft. RIH sat down at 10832', 10866', 10897', 10930', 10963', 10995', 11022' and 11,056 Landed liner shoe at TD of 11,056'. Set down 5 times at same depth. Liner is on bottom. Insert 5/8" steel ball and displace with FloPro at 2.1 bpm, 2400 psi. Ball on seat at 47.1 bbls, sheared at 4000 psi. Pick up coil free at 33K. Sat down wt on coil. Circulate well to 2% KCL water with friction reducer. Recover FloPro and send to MI mud plant for reconditioning. 3.0 bpm, 2200 psi, full returns. SAFETY MEETING. Review procedure, hazards and mitigation to mix and pump liner cement job. Circulate well to 2% KCL water while batch mixing cement. Cement to weight at 1530 Hrs. Press test cement line. Stage 3.0 bbls water ahead. Stage 25.1 bbls, 15.8 PPG, G Cement with Latex, 2.0 bpm, 2000 psi. Isolate real, Ship Biozan water to cementers, Vac cement from hardline. Insert BKR Dart in coil. Displace cement with 2# Biozan water at 3.0 bpm, 2800 psi. Zero out totalizer at 49 bbls. Slow pump to 1.57 bpm at 54 bbls displacement. 1150 psi. Dart on liner wiper plug at 57.3 bbls, LWP sheared at 3550 psi. Displace LWP at 3.0 bpm, 3300 psi, slow to 2.2 bpm at bbls, 63 bbls, 3100 psi, cement was packing off at 3 bpm, Slow to 1.0 bpm, 1700 psi, at 70 bbls. Bumped plug at 72.0 bbls, 0.30 bbls early. Hold 2300 psi press test for 5 min. Open choke and check floats. 22.7 bbls returned of 25.1 pumped. Open choke, check valves holding. Sting out of liner top at 34K. POH, replace coil voidage only, 5.48 bbls/1 000 ft. OOH, LD BOT CTLRT. PU 2.3" mill, motor 2 jts 1-1/4" CSH PJSM on PU Memory CNLlGR tool and rad. source PU SWS Memory CNLlGR carrier, 74 jts (37 stds) 1-1/4" CSH, DS Motor head assy, Stab injector. RIH. Cement sample at 0115 hrs @ 650 psi compressive strength. Started 40 bbl125 bbl LSRV Perf pill down CT. No evidence of cement at liner top or in liner from motor. Qmax through CNL tool is 1.5 bpm Logging down from 8,600 ft to 11,022 ft with MCNL/GR Per pill at motor Logging up from 11,022 ft to 8,760 ft w/ MCNLlGR at 60 fpm 40 bbl perf pill out of liner at 8800 ft. POOH Qp = 1.00 bpm. Qmax = 1.2 bpm . Printed: 2/16/2004 9:43:41 AM tit e Page 13 of 14 BP Operations Summary Report Legal Well Name: 01-17 Common Well Name: 01-17 Event Name: REENTER+COMPLETE Start: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date J~~o~ - ~_~__!:__~~urs Task Code L~PT : Pha~_~ i 2/8/2004 04: 1 0 - 05:30 1.33 EVAL P COMP 05:30 - 06:00 06:00 - 07:30 07:30 - 07:45 COMP COMP COMP 0.50 EVAL 1.50 EVAL 0.25 EVAL P P P 07:45 - 08:30 08:30 - 11 :00 COMP WAIT COMP 0.75 EVAL 2.50 EVAL P N 11:00 -13:00 2.00 EVAL COMP P 13:00-13:15 0.25 PERF COMP P 13:15-15:30 2.25 PERF COMP P 15:30 - 17:00 COMP 1.50 PERF P 17:00 - 18:30 1.50 PERF COMP P 18:30 - 20:00 1.50 PERF P COMP 20:00 - 20: 1 0 0.17 PERF P COMP 20:10 - 21:30 1.33 PERF P COMP 21 :30 - 21 :45 0.25 PERF P COMP 21:45-22:15 0.50 PERF P COMP 22: 15 - 22:50 0.58 PERF P COMP 22:50 - 23:55 1.08 PERF P COMP 23:55 - 00:00 0.08 PERF P COMP 2/9/2004 00:00 - 00:15 0.25 RUNCOIIP COMP 00:15 - 02:20 2.08 RUNCOIIP COMP 1/14/2004 2/9/2004 N1 Spud Date: 3/13/1978 End: Description of Operations -..----......-.-- -... ..-- ---- POOH with MCNLlGR Logging tool. Cement at 2,000 psi compressive strength at 0400 hrs POOH standing CSH back in the derrick (37 stds) Finish POOH standing CSH back in the derrick. SAFETY MEETING. Review Procedure, hazards and mitigation for recovering SWS Memory CNLlGR/CCllogging tools. Recover logging tools. FAX CNLlGR log to town GEO. Wait on Geology to study CNLlGR log and determine perforating interval. Told to perforate in the deepest part of the lateral from 10,450 - 10,650 ft, 200 ft of perfs, 6 SPF, 2" PJ. Pressure test liner lap for 30 min. Liner lap failed pressure test. Held press at 1000 psi, slight leak at 1500 psi, fast leak at 2000 psi. SWS lab UCA sample at 2000 psi at 0400 hrs. Will run Baker liner top packer after perforating. Load Perf guns in pipe shed while press testing liner lap. SAFETY MEETING. Review procedure, hazards and mitigation for running SWS 2" perf guns. Run SWS 2" PowerJet Perf guns at 6 SPF. 10 guns total. M/U SWS firing head and hyd disc. Run 35 stds of CSH, XO, hyd disc, check valves and eTC. Total length = 2,396 ft. RIH with perf guns on CSH workstring. Circ. 0.5 bpm at 280 psi. RIH clean thru top of liner at 8,837 ft. Tag TD and get up wt at 11,016.5 ft. Add 5.5 ft to CTD to correct depth to 11,022' PBTD from tie-in Memory CNLlGR/CCL log of 02/08/04. Pump 11 bbls of new FloPro perf pill, 150,000 cp, with 2% LT. Pull to perforating depth of 10,650 ft. Insert 5/8" AL ball and displace with 2% KCL water. Displace with 1.7 bpm, 1900 psi. Circ FloPro to circ sub, RIH and lay in new flopro from 10800'. Position bottom perf at 10,652 ft and pump ball on seat at 0.5 bpm, 420 psi. Ball on seat at 57.0 bbls. Firing head sheared at 3000 psi. PERFORATED 10,450 - 10,650 FT. POOH with perforating BHA PJSM on standing 1-1/4" CSH in derrick POOH standing back 35 std CSH in derrick PJSM on handling perf guns POOH LD 2" spent guns, All shots fired. Some pressure trapped between firing head and top shot Off loaded guns to SWS trailer RU nozzle BHA to jet BOP stack Jetted BOP stack with KCL fluid PJSM on PU BOT Liner Top Packer PU BOT Liner Top Packer RIH at 80 fpm WT check at 87600 ft = 36k up. Pp inc at 8837.3. SD pump, open Baker choke. RIH, loc sub tagged at 8843.2 ft Set down 10k to a depth of 8845.2 ft. PUH and Printed: 2/1612004 9:43:41 AM e e Page 14 of 14 BP Operations Summary Report Legal Well Name: 01-17 Common Well Name: 01-17 Event Name: REENTER+COMPLETE Start: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 1 Rig Number: Date I From - To I Hours! Task I Code I NPT I Phase I __u.. .-.!. n;.. . _u '._L.. ..._..n .... ; _ ......._.. _....-._. 2/9/2004 00:15 - 02:20 2.08 RUNCOI/p COMP 02:20 - 03:06 0.77 RUNCOI/p COMP 03:06 -- 04:40 1.57 RUNCOI P COMP 04:40 - 05:00 0.33 RUNCOI P COMP 04:36 - 05:30 0.90 WHSUR P COMP 05:30 - 07:00 1.50 WHSUR P COMP 07:00 - 07:15 0.25 RIGD P POST 07:15 -- 10:00 2.75 RIGD P POST 10:00 - 12:00 2.00 RIGD P POST 12:00 - 14:00 2.00 RIGD P POST 1/14/2004 2/9/2004 N1 Spud Date: 3/13/1978 End: Description of Operations n_..._ . ._nn ---------..- . .__u.._ dropped 5/8" ball and lanched Displace 5/8" ball at 2 bpm @ 813 psi 40 bbl. Stung into deployment sleeve at 8837 ft and setdown 10 k at 9945.2 ft. Confirmed. PU 1.2 ft to 8839 ft and allow ball to fall. PU and Set L TP with 2500 psi. PU set, PT annulus to 2000 psi. OK. Released annulus pressure and pressure up on CT to 4000 psi to release from L TP PUH released POOH with setting tools LD L TP setting tools, PU nozzle to freeze protect RIH to 2000 ft (Rig manifold outside froze up) Freeze protect 5.5" tubing with 35 bbls MEOH. Pull to 100 ft, stop and circ 100% MEOH to surface. POH. Close Master Valve. SAFETY MEETING. Review procedure, hazards and mitigation for pumping N2 into coil and displacing fluid from coil. Pump 5 bbls MEOH. Pump N2 with SWS N2 unit. Bleed down coil pressure to Tiger tank. Cut off CTC. Pull end of coil to reel and secure the coil for a reel swap. NID BOPE. N/U tree cap and pressure test. Well is shut in and freeze protected. RELEASED RIG AT 1400 HRS, 02/09/04. TOTAL OF 14 DAYS, 23 HOURS FROM RIG ACCEPT TO RELEASE. Will move rig to NK - 12C. The following rig operations will be on NK-12C report dated 2-9-04 Rpt #1 Printed: 2/16/2004 9:43:41 AM . . f)oLj-o/~ 24-Feb-04 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well 1-178 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 8,980.00' MD 9,016.00' MD 11,057.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager AUachment(s) RECEIVED f "' '" 1 0 0j1u~ ;1 ~;'" <0.: {J L.U JL} (''', .., ('<{1' (" C^mm~.> ,;;;Ii:: ,.·dl"", \,i, ml""";!1,!í.1 RBDMS RD MAR 3 Ò )ðð4 Halliburton Sperry-Sun North Slope Alaska BPXA PBU EOA DS 01 01-17B Job No. AKMW0002890057, Surveyed: 6 February, 2004 Survey Report 23 February, 2004 Your Ref: API 500292028902 Surface Coordinates: 5940712.30 N, 697961.74 E (70014' 31.7243" N, 148024' 03.8863" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 940712.30 N, 197961.74 E (Grid) Surface Coordinates relative to Structure Reference: 1237.27 S, 689.40 E (True) Kelly Bushing Elevation: 73.00ft above Mean Sea Level Kelly Bushing Elevation: 73.00ft above Project V Reference Kelly Bushing Elevation: 73.00ft above Structure Reference SI=J'Elr-"r-"':J-SUI! DFULL..TNG . seAvu:::es A Halliburton Company DEFINITIVE e e Survey Ref: svy4161 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 01 - 01-17B Your Ref: API 500292028902 Job No. AKMW0002890057, Surveyed: 6 February, 2004 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8980.00 28.750 327.000 8461.34 8534.34 1138.04 N 1531.40 W 5941809.73 N 696400.98 E 1864.54 Tie On Point MWD Magnetic 9016.00 29.130 327.390 8492.84 8565.84 1152.68N 1540.84 W 5941824.12 N 696391.16 E 1.178 1879.18 Window Point 9027.50 35.420 325.000 8502.56 8575.56 1157.77 N 1544.26 W 5941829.12 N 696387.60 E 55.801 1884.40 9066.44 40.530 311.930 8533.30 8606.30 1175.51 N 1560.19 W 5941846.43 N 696371.22 E 24.411 1906.22 e 9106.16 38.330 299.110 8564.03 8637.03 1190.15 N 1580.59 W 5941860.54 N 696350.44 E 21.203 1930.85 9143.49 39.580 288.140 8593.09 8666.09 1199.50 N 1602.03 W 5941869.32 N 696328.76 E 18.758 1954.23 9175.42 41.230 281.380 8617.41 8690.41 1204.75 N 1622.02 W 5941874.03 N 696308.64 E 14.657 1974.61 9205.91 45.370 276.790 8639.60 8712.60 1208.01 N 1642.66 W 5941876.76 N 696287.92 E 17.051 1994.76 9239.74 48.020 282.260 8662.82 8735.82 1212.11 N 1666.91 W 5941880.22 N 696263.57 E 14.130 2018.54 9269.66 50.130 290.540 8682.43 8755.43 1218.51 N 1688.56 W 5941886.04 N 696241.77 E 22.056 2040.90 9299.08 49.960 297.410 8701.34 8774.34 1227.66 N 1709.14 W 5941894.65 N 696220.95 E 17.905 2063.42 9335.78 48.280 307.280 8725.39 8798.39 1242.44 N 1732.55 W 5941908.82 N 696197.16 E 20.830 2090.84 9369.40 47.580 303.930 8747.92 8820.92 1256.97 N 1752.83 W 5941922.81 N 696176.51 E 7.684 2115.31 9401.07 47.930 297.060 8769.23 8842.23 1268.85 N 1773.01 W 5941934.15 N 696156.02 E 16.092 2138.60 9432.15 46.870 287.540 8790.29 8863.29 1277.53 N 1794.12 W 5941942.27 N 696134.69 E 22.791 2161.41 9462.72 46.340 282.610 8811.30 8884.30 1283.31 N 1815.56 W 5941947.49 N 696113.11 E 11.844 2183.32 9497.11 48.810 274.860 8834.52 8907.52 1287.12 N 1840.61 W 5941950.64 N 696087.96 E 18.11 0 2207.72 9536.90 54.890 270.800 8859.09 8932.09 1288.62 N 1871.84 W 5941951.32 N 696056.70 E 17.254 2236.78 9566.72 61.940 271.680 8874.70 8947.70 1289.18 N 1897.22 W 5941951.21 N 696031.32 E 23.775 2260.13 9598.42 69.690 272.920 8887.68 8960.68 1290.35 N 1926.09 W 5941951.62 N 696002.42 E 24.706 2286.91 9629.66 75.070 279.440 8897.14 8970.14 1293.57 N 1955.66 W 5941954.07 N 695972.78 E 26.303 2315.18 e 9659.77 80.260 284.900 8903.58 8976.58 1299.78 N 1984.39 W 5941959.52 N 695943.90 E 24.712 2343.91 9687.90 80.790 290.540 8908.21 8981.21 1308.23 N 2010.81 W 5941967.27 N 695917.27 E 19.865 2371.46 9718.57 80.790 296.350 8913.12 8986.12 1320.27 N 2038.57 W 5941978.58 N 695889.20 E 18.699 2401.71 9749.91 79.820 302.520 8918.41 8991.41 1335.44 N 2065.47 W 5941993.04 N 695861.92 E 19.651 2432.47 9777.58 78.940 307.460 8923.51 8996.51 1351.03 N 2087.74 W 5942008.03 N 695839.24 E 17.833 2459.19 9809.32 80.350 312.040 8929.22 9002.22 1370.99 N 2111.74 W 5942027.36 N 695814.73 E 14.873 2489.29 9833.38 82.730 314.680 8932.76 9005.76 1387.33 N 2129.03 W 5942043.24 N 695797.01 E 14.684 2511.79 9863.06 87.310 316.970 8935.33 9008.33 1408.53 N 2149.63 W 5942063.89 N 695775.86 E 17.239 2539.29 9898.32 85.990 316.970 8937.39 9010.39 1434.26 N 2173.65 W 5942088.98 N 695751.17 E 3.744 2571.79 23 February, 2004 - 8:26 Page 2 of 5 DrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 01 - 01-17B Your Ref: API 500292028902 Job No. AKMW0002890057, Surveyed: 6 February, 2004 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9933.37 81.150 316.790 8941 .32 9014.32 1459.67 N 2197.45 W 5942113.76 N 695726.72 E 13.818 2603.96 9966.18 78.850 315.030 8947.01 9020.01 1482.88 N 2219.93 W 5942136.37 N 695703.64 E 8.777 2634.01 9996.41 80.180 310.800 8952.52 9025.52 1503.11 N 2241.69 W 5942156.02 N 695681.35 E 14.445 2662.18 10027.88 80.350 305.870 8957.84 9030.84 1522.34 N 2266.01 W 5942174.61 N 695656.53 E 15.449 2692.27 10057.58 81.500 303.580 8962.53 9035.53 1539.05 N 2290.12 W 5942190.68 N 695631.99 E 8.542 2721.12 e 10087.07 82.110 299.530 8966.73 9039.73 1554.32 N 2314.99 W 5942205.29 N 695606.73 E 13.750 2750.08 10140.73 80.790 295.830 8974.71 9047.71 1578.97 N 2361.97 W 5942228.69 N 695559.12 E 7.249 2803.04 10170.13 83.080 292.830 8978.84 9051.84 1590.96 N 2388.49 W 5942239.98 N 695532.30 E 12.757 2832.14 10200.16 86.700 288.070 8981.51 9054.51 1601.40 N 2416.50 W 5942249.69 N 695504.02 E 19.862 2861.97 10227.52 88.990 284.020 8982.54 9055.54 1608.95 N 2442.77 W 5942256.55 N 695477.56 E 16.995 2889.01 10255.06 91.100 276.790 8982.52 9055.52 1613.92 N 2469.84 W 5942260.80 N 695450.37 E 27.346 2915.72 10286.93 88.900 271.330 8982.52 9055.52 1616.18 N 2501.61 W 5942262.22 N 695418.55 E 18.470 2945.60 10322.43 88.900 265.870 8983.20 9056.20 1615.31 N 2537.08 W 5942260.43 N 695383.11 E 15.377 2977.55 10343.83 89.320 261.420 8983.54 9056.54 1612.94 N 2558.34 W 5942257.50 N 695361.92 E 20.884 2995.94 10378.39 89.070 255.830 8984.02 9057.02 1606.13 N 2592.21 W 5942249.80 N 695328.25 E 16.189 3023.97 10407.48 88.370 252.650 8984.67 9057.67 1598.23 N 2620.19 W 5942241.17 N 695300.48 E 11.191 3046.21 10443.36 84.930 244.020 8986.77 9059.77 1585.03 N 2653.45 W 5942227.10 N 695267.58 E 25.851 3071.05 10476.90 86.290 236.490 8989.34 9062.34 1568.45 N 2682.46 W 5942209.76 N 695239.02 E 22.749 3090.63 10504.02 92.610 234.220 8989.60 9062.60 1553.04 N 2704.76 W 5942193.77 N 695217.13 E 24.760 3104.59 10527.59 97.000 238.560 8987.63 9060.63 1540.04 N 2724.30 W 5942180.27 N 695197.93 E 26.142 3117.03 10558.71 93.570 244.200 8984.76 9057.76 1525.21 N 2751.49 W 5942164.73 N 695171.14 E 21.144 3135.68 10589.04 91.280 245.080 8983.48 9056.48 1512.23N 2778.87 W 5942151.03 N 695144.11 E 8.088 3155.26 e 10622.65 90.840 252.650 8982.85 9055.85 1500.12 N 2810.19 W 5942138.11 N 695113.12E 22.557 3178.80 10652.24 90.130 253.890 8982.60 9055.60 1491.61 N 2838.53 W 5942128.85 N 695085.02 E 4.829 3201.10 10685.86 92.600 258.820 8981.80 9054.80 1483.68 N 2871.18 W 5942120.07 N 695052.59 E 16.397 3227.56 10710.14 93.660 260.580 8980.48 9053.48 1479.35 N 2895.03 W 5942115.11 N 695028.86 E 8.453 3247.50 10743.11 93.200 261.180 8978.50 9051.50 1474.13 N 2927.53 W 5942109.04 N 694996.51 E 2.291 3274.95 10777.13 91.630 258.820 8977.07 9050.07 1468.23 N 2961.00 W 5942102.26 N 694963.21 E 8.327 3303.00 10808.02 92.950 257.940 8975.84 9048.84 1462.01 N 2991.23 W 5942095.25 N 694933.15 E 5.134 3327.98 10844.45 97.090 260.760 8972.65 9045.65 1455.30 N 3026.88 W 5942087.61 N 694897.68 E 13.733 3357.68 10877.36 97.710 263.050 8968.41 9041 .41 1450.71 N 3059.19 W 5942082.17 N 694865.51 E 7.153 3385.22 10907.66 92.860 260.050 8965.62 9038.62 1446.27 N 3089.02 W 5942076.95 N 694835.80 E 18.798 3410.56 10942.88 93.570 256.000 8963.64 9036.64 1438.98 N 3123.41 W 5942068.76 N 694801.62 E 11.657 3438.88 10973.80 98.330 252.830 8960.44 9033.44 1430.72 N 3153.02 W 5942059.73 N 694772.23 E 18.464 3462.44 11009.00 102.470 256.710 8954.08 9027.08 1421.63N 3186.41 W 5942049.76 N 694739.09 E 15.994 3489.10 23 February, 2004 - 8:26 Page 3 of5 DrillQuest 3.03.05.005 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 01 - 01-17B Your Ref: API 500292028902 Job No. AKMW0002890057, Surveyed: 6 February, 2004 North Slope Alaska Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) 11030.03 103.440 260.410 8949.37 9022.37 11057.00 103.440 260.410 8943.10 9016.10 Local Coordinates Northings Eastings (ft) (ft) Global Coordinates Northings Eastings (ft) (ft) 1417.56 N 1413.19 N 3206.50 W 3232.36 W 5942045.16 N 5942040.12 N 694719.12 E 694693.38 E All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 294.370° (True). Magnetic Declination at Surface is 25.517° (25-Jan-04) Based upon Minimum Curvature type calculations, at a Measured Depth of 11 057.0Oft., The Bottom Hole Displacement is 3527.78ft., in the Direction of 293.615° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings ~ ~ ~) Comment 8980.00 9016.00 11057.00 8534.34 8565.84 9016.10 1138.04 N 1152.68 N 1413.19 N 1531.40 W 1540.84 W 3232.36 W Tie On Point Window Point Projected Survey Dogleg Vertical Rate Section (0/100ft) BPXA Comment 17.755 3505.72 0.000 3527.48 Projected Survey e e 23 February, 2004 - 8:26 Page 4 of 5 DrillQuest 3.03.05.005 North Slope Alaska Survey toolproqram for 01-178 From Measured Vertical Depth Depth (ft) (ft) 0.00 8980.00 0.00 8534.34 To Measured Vertical Depth Depth (ft) (ft) 8980.00 11057.00 8534.34 9016.10 Halliburton Sperry-Sun Survey Report for PBU_EOA DS 01 - 01-17B Your Ref: API 500292028902 Job No. AKMW0002890057, Surveyed: 6 February, 2004 BPXA Survey Tool Description BP Conventional Magnetic - CB-MAG-MS (01-17) MWD Magnetic (01-17B) e e 23 February, 2004 - 8:26 Page 5 of 5 DrillQuest 3.03.05.005 5-1/2" T8G-NPC, 17#, N.80, .0232 bpf, ID" 4.892" 4-1/2" TBG-NPC 4-1/2" CAMCO DB-6 NIP (BEHIND LNR), FERFORA TJON SUMI'#.RY REF LOG: SWS MEMORY CNL/GR!CCL OF 218104 ANGLE AT TOP PffiF: 85 DEG @ 10,450" Note: Refer to Production DB for historical perf data tzE SA" NTffiVAL 2 10450 - 10650' 6 9-518" CSG, 47#, ID 8.681" 2-7/8" LNR, 6.4#, L-BO, .0058 bpf, ID" 2.44" 211)4~' 5-1/2" CAMCO BAL-O SSSV NIPR..E, IrÞ 4.562 D "4.437" 10"4.313" 9·5/8" X 5·112" BAKERSAB PKR, 10" 4.000" XO 5-1/2" X 4-112" co MI'v1ENTS posed CTO Sidetrack D Horizontal Sidetrack PRUOHOE8AY UNIT WELL: 01-178 PffiMIT !\b: AR No: 5O-029~20289-02 SECB T1 ON R15E 1406.68 Hi. 3362.68 FNL ElP Exploratil)n . . FRANK H. MURKOWSKI, GOVERNOR AI1ASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mary Endacott CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe bay Unit PBU 01-17B BP Exploration (Alaska), Inc. Pennit No: 204-012 Surface Location: 191' SNL, 646' EWL, Sec. 08, TI0N, R15E, UM Bottomhole Location: 1264' NSL, 2561' WEL, Sec.06, TlON, RI5E, UM Dear Ms. Endacott: Enclosed is the approved application for pennit to redrill the above development well. This pennit to redrill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the tenns and conditions of this pennit may result in the revocation or suspension of the pennit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, BY ORDER ?f THE COMMISSION DATED thisLf- day of January 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. VJClI\- II t 3 [7-00tj- 1a. Type of work o Drill II Redrill 11 b. Current Well Class o Exploratory III Development Oil o Multiple Zone ORe-Entry o Stratigraphic Test o Service o Development Gas o Single Zone 2. Operator Name: 5. Bond: a Blanket o Single Well 11. Well Name and Number: BP Exploration (Alaska) Inc. Bond No. 2S 100302630-277 PBU 01-17B .,/ 3. Address: 6. Proposed Depth: 12. Field / Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 10965 TVD 8919 Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): 7. Property Designation: Pool Surface: ADL 028329 191' SNL, 646' EWL, SEC. 08, T10N, R15E, UM 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: / 1005' NSL, 918' WEL, SEC. 06, T10N, R15E, UM January 19,2004 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 1264' NSL, 2561' WEL, SEC. 06, T10N, R15E, UM 2560 23,400' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation 15. Distance to Nearest Well Within Pool Surface: x-697962 y-5940712 Zone-ASP4 (Height above GL): KBE = 73' feet 01-32A is 1192' away at 9030' MD 16. Deviated Wells: 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Kickoff Depth 9034 ft Maximum Hole Angle 0 Downhole: 3275 psig Surface: 2200 /psig 105 18.···Casing.··f'-'rográrn i ."" i.i· .......... ... i~U~ntity otP(:)!'J'\ønt Sizé Tii :()l'I'Ii .. ~~.k>~cksr Hole Casino Weicht Grade Couolino Lenoth MD TVD MD TVD · Io¡{ i11!Í iii'! ~ (~...... 3-3/4" 3-3/16' x 2-7/8' 6.2# / 6.5# L-80 CIII STL 2125' 8840' 8338' 10965 8919' 93 sx Class '13-,.....' " ~. -c L- I" . ""II'1JIII U Q '),." '"-- "'VU',I -.':'"' a... ^ ~~' "'~.; .:¡t, "i\n 19. '.' ... . '.. . /............... . -. -·_·.·.··7-·..···_·~.. -................. ............. . . .............. ..' ... .......... ..' ~·<·i· F>BE:$ENTVVELL CONDITION SUMMARY (To becompletedJor RedriIIANDREr'enb'YOpØrations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): I Effective Depth MD (ft): Effective Depth TVD (ft):1 Junk (measured): 10345 9055 None 10331 9054 9860 ,i,. ii·.··· ..,......< .< ...;.·..i ¡. «ii :,,'< ·.,Vfl;,l.<····· i.i· i '0I"V11? ii C::tr"l"'h ,ro:ol Conductor 119' 20" 250 sx Arcticset 119' 119' ~ '- 2704' 13-3/8" 5800 sx PF 11 2704' 2704' te 9416' 9-5/8" 960 sx Class 'G' 9416' - 8908' PrnnlJr.tinn Liner 1514' 2-7/8" 115 sx LARC 8831' - 10345' 8403' - 9055' Perforation Depth MD (ft): 9635' - 10320' IPerfOration Depth TVD (ft): 9003' - 9053' 20. Attachments !HI Filing Fee !HI BOP Sketch !HI Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report !HI Drilling Fluid Program !HI 20 MC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mary Endacott, 564-4388 Printed Name Mary Endacott Title CT Drilling Engineer Thomas McCarty, 564-4378 ~l71;.lÜ j vf1·;1¡l/l ~f; {( II <f:¡i04 Prepared By Name/Number: Sionature Phone 564-4388 Date Terrie Hubble, 564-4628 I .M: // Commission Use Only Permit To Drill 2.D_~-ð/.2. I API Number: I ¡ermit Approval T See cover letter for Number: 1..9S-1'8T 50- 029-20289-02-00 Date: other requirements Conditions of Approval: Samples Required DYes ~No Mud Log Required DYes ~No Hydrogen Sulfide Measures ~Yes DNo Directional Survey Required ~Yes DNo Other: Teç t- f..o P E to ~S"OO (35.l, Original Signed By / /;1/d1 Sarah Palin BY ORDER OF Aooroved Bv: THE COMMISSION Date Form 10-401 Revised 12/2003 ' s'ubmi( In Duplicate STATE OF ALASKA ALASKA ceAND GAS CONSERVATION COASION PERMIT TO DRILL 20 MC 25.005 / e BP 1-17B CTD Sidetrack e Phase 1 Operations: Prep Work: · Integrity pressure test OA, IA &tbg, wellhead seals & Xmas tree valves. · Set CIBP in 2 7/8" liner · Cut and pull liner above TOC · lay in cement ramp / Phase 2 Operations: Mill pilot hole, window, Drill and Complete sidetrack. Mud Program: · Phase 1: Seawater/1 % KCI ß · Phase 2: Mill with seawater I Y2lb biozan, drill with Solids Free Flo-Pro (8.6 cyppg) Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: I . 33/1eTCII x 2Yg" STl from 10965~~~.~9J9'ss) to 8,840'MD (-8,338'ss). . The liner will be cemented wit~?S with a planned TOC at Tal within the 4%" tailpipe. Parent Well Casinas Hole Size Burst (psi) Collapse (psi) 13 3/8" 72# N-80 5380 2670 9%" 47#, N-80 6870 4750 2 7/8" 6.4#, L-80 10570 11160 Sidetrack CasinQs 3-3/16" 6.2#, L-80, TCII- Prod LNR 3.75 8520 7660 2%" 6.5#, L-80, STL - Prod LNR 3.75 10570 11170 Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. / · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plan. Max. planned hole angle is 104°. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. · 01-17B will be approximately 1192' ctr-ctr away from we1l1-32A at 9030' md / · 01-17B will be approximately 23,400' from the unit boundary, (Prudhoe Bay Unit) logging · MWD Gamma Ray and Resistivity will be run in the open hole section. · Memory CNl will be run inside the liner. Hazards / · H2S has not recently been measured on 1-17A. 140ppm is the maximum measured on the pad. · The risk of a lost circulation event is considered low, no faults will be crossed however the wellpath passes close to a fault. Reservoir Pressure · Res. press. is estimated to be 3275 psi at 8800'ss (7.1 ppg emw). · Max. surface pressure with gas (0.12 psi/ft) to surface is 2200 psi. / GRAY GEN II GRAY AXELSON 73' SAFETY NOTES 4438' 91 @ 10173' 9375' 8800' SS 2209' 5-1/2" CAMCO BAL-O SSSV NIPPLE, ID= 4.562 4-1/2" ìBG-NFC, 12.6#, N-80, .0152 bpf, ID= 3.958" 2-1/8 2 2-1/8 NA NA ÆRFORA TION SUMMARY REF LOG: BHCS ON 3/24/78 ANGLE AT TOP ÆRF: 79 @ 9635' Note: Refer to Production DB for historical perf data SPF INTERVAL Opn/Sqz DA T 4 9635-9645 4 9795-9804 4 9805-9815 4 10170-10220 4 10240 10320 PRUDHOE SA Y UNIT WELL: 01-17B ÆRMIT No: API No: 50-029-20289-01 SECB T10N R15E 1406.68 FEL 3362.68 FNL BP (Alaska) Amoco Magnetic Field Strength: 57592n1 Dip Angle: 80.860 Date: 11812004 Model: bggm2003 LEGEND Plarr Plan #4 (01..17/Pfan #4 01-178) Created By: Brij Potnís Date: 1/8/2004 WSlLPATH DETAILS Pa1"$nt Welipath: 01-11 Tie 011 MOl 8386.00 Rig: Rw.D..tum: V.sectron An.", 294.37> Nordic 1 2&:11513(1/199611:12 ~~~~ o.~~ ~~~= 2300 , , . 2200 , , 2100 "': 2000 , "':" , , , , , , , =j \\ 1900 " , \ , , 170 011 '\ \ , ' c',', ::'1600 " :I 'ew ï:': f -..., ~ ',"". 140 - . ':, 8 .--", , ~1300 \-- ,- -- ~ ' ' , " , , " 7 1200 '""' 1100, , ' , . , 1000 .,' ,., '.,' :.', 900 -::~ , , , 800 ~~r~ 700 , , ~^ "OM ':=^ '" 600 ",,'. .M ". '^^ ^^ ^^M MM , .M ~^M REFERENCE INFORMATION 73_00 .,w,. m.~~ Tf,.,,,, 8371J.U st\66.iXi 1'11' 1150&.210034,.<KI I('H> 81141.n 0084,Qi) ) 81,\.21,!11191$4.oo .$ QijjI~U 1t~!I4.«I 5 ItN¡æ:.81 8»4.<1<1 $ 8823.929474.(11) 7 "18.44 IJ101M1 $ ",11.11:1 $061.00 II 1!S7Va10(l1/.1iG"O 1<) 1I1I7$.2$10Ui,!J<I'i1 1I1I'8.'21w,¡41,00 U U87.281031l-1,00 n 886Q..14100'U,!)U U U65,1I.510711;oa 1JI. 88U,1jf10811..!H1 16 11\1:1:&.411111&41.60 17 $U$.~ 10.e5.00 TD 7700 7800' 8000 J:: .... ~8400 III Q 'i .~ 8600 t: QI >- ¡ 8800 .... 8900 9000 9100 9200 1300 1400 1500 1600 1700 1800 19002000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 4000 4100 4200 4300 4400 Vertical Section at 294.37° e BP-GDB e Baker Hughes INTEQ Planning Report BP Amoco . :.-. .:" I Company: Date: 1/8/2004 Time: 13:44:35 '. -;: ': :~:. ::::. ..... Page: 1 Fietd: Prudhoe Bay Co-ordinate(NE) Reference: ~~~~~1:-~:a~~~~.~Z~~i:' m Site: PBDS,01 ',.: Vertical (TVD) Reference: Well: 01-17. . ~: Section (VS) Reference: Well (0.00N,0.OÒE;294;37Azi) Well path:; Plad#4 01-17B .:,.-.->.:. ',' ::::x'" Survey Calculation Method: '" Minimum Curvature /;:"Db: Oracle .- Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2003 Site: PB DS 01 TR-10-15 UNITED STATES: North Slope Site Position: Northing: 5941932.14 ft Latitude: 70 14 43.905 N From: Map Easting: 697237.60 ft Longitude: 148 24 24.004 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.50 deg Well: 01-17 Slot Name: 17 01-17 Well Position: +N/-S -1237.07 ft Northing: 5940713.68 ft Latitude: 70 14 31.738 N +E/-W 692.28 ft Easting : 697961.98 ft Longitude: 148 24 3.878 W Position Uncertainty: 0.00 ft Wellpath: Plan #4 01-17B Drilled From: 01-17 Tie-on Depth: 8886.00 ft Current Datum: 29: 175/30/199611:12 Height 73.00 ft Above System Datum: Mean Sea Level Magnetic Data: 1/8/2004 Declination: 25.54 deg Field Strength: 57592 nT Mag Dip Angte: 80.86 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 33.00 0.00 0.00 294.37 Targets ..__.'_._-_...~..._. .. .... '·'---"'1 j\l ap Map <-- Latitude -~, <- Longitude --> I Name I>escription TVD +NiiS +E/-W Northing Easting Deg Min Sec "'. ".. Deg,:,Min See Dip. Dir. ft .'. ft ft . ft. ft "'----.---...-. - - ....-i'····. 01-17B Polygon 0.00 1093.62 -1593.90 5941765.00 696340.00 70 14 42.492 N 148 24 50.221 W -Polygon 1 0.00 1093.62 -1593.90 5941765.00 696340.00 70 14 42.492 N 148 24 50.221 W -Polygon 2 0.00 1378.96 -1564.40 5942051.00 696362.00 70 14 45.298 N 148 24 49.365 W -Polygon 3 0.00 1518.13 -2177.99 5942174.00 695745.00 70 14 46.665 N 148 25 7.207 W -Polygon 4 0.00 1651.56 -2687.69 5942294.00 695232.00 70 14 47.976 N 148 25 22.029 W -Polygon 5 0.00 1559.02 -3049.26 5942192.00 694873.00 70 14 47.065 N 148 25 32.542 W -Polygon 6 0.00 1500.42 -3445.96 5942123.00 694478.00 70 14 46.487 N 148 25 44.076 W -Polygon 7 0.00 1261.88 -3391.20 5941886.00 694539.00 70 1444.141 N 148 25 42.481 W -Polygon 8 0.00 1387.01 -2784.67 5942027.00 695142.00 70 14 45.374 N 148 25 24.847 W -Polygon 9 0.00 1413.69 -2543.88 5942060.00 695382.00 70 14 45.637 N 148 25 17.845 W -Polygon 10 0.00 1279.94 -2098.21 5941938.00 695831.00 70 14 44.323 N 148 25 4.886 W 01-17B Target 4.6 8919.00 1455.28 -3213.05 5942084.00 694712.00 70 14 46.044 N 148 25 37.303 W 01-17B Target 4.1 8920.00 1329.24 -2032.89 5941989.00 695895.00 70 14 44.808 N 148 25 2.987 W 01-17B Target 4.5 8925.00 1467.76 -3192.72 5942097.00 694732.00 70 1446.167 N 148 25 36.712 W 01-17B Target 4.4 8966.00 1512.59 -2957.44 5942148.00 694966.00 70 14 46.608 N 148 25 29.872 W 01-17B Target 4.3 8968.00 1505.82 -2623.49 5942150.00 695300.00 70 14 46.543 N 148 25 20.161 W 01-17B Target 4.2 8976.00 1458.98 -2439.64 5942108.00 695485.00 70 14 46.083 N 148 25 14.815 W Annotation r .~'-- --¥--- -----. - I I\1D TVD ~. :: ::-... .. ft ft .. ,". .::.~.' . ... ... ...... ..::~::(':: "::" ... - . -- 8886.00 8378.53 TIP 9034.00 8508.21 KOP 9084.00 8547.55 3 e BP-GDB e Baker Hughes INTEQ Planning Report Company: BP Amoco Field:';' Prudhoe Bay'" Si'te:, PB DS 01 ,Well:' 01-17 Wellpath: Plan #4 Annotation 'MD TVJ> ft fr 9184.00 8621.69 4 9284.00 8693.31 5 9384.00 8762.81 6 9474.00 8823.92 7 9701.00 8918.44 8 9861.00 8941.70 9 10091.00 8973.68 10 10151.00 8976.29 11 10341.00 8968.52 12 10391.00 8967.26 13 10641.00 8966.14 14 10711.00 8965.85 15 10811.00 8955.18 16 10941.00 8925.40 17 10965.00 8919.38 TD ptan: Plan #4 '. ' ._._-~~_._- --...------ . ... .. . . ... . . Date: 1ï8ï~004 '-:,,: ",Time: 13:44:35"" P~2e: C()-ordinatc(NE) Reference: Well: 0,1-17. True North' ,,' : Vertiçål (TVD) Reference: System:'Mean Sea Level, : ,"H1 ~~W:;~~~1u~:t~:e~:;hOd: :~lil~~~?~~~~~~;.:4.37~b: . :::·,"·:Sl.":: Principal: Yes Plan Section Information 1 MD ,',hid Azim TVD +N/-S ,:f!!;/-W i ft ,.,._'~~g deg ft ft ::',ft --- ----. ...._._._~._.. 8886.00 27.75 325.00 8378.53 1101.15 -1506.54 8980.00 28.75 327.00 8461.34 1138.03 -1531.41 9020.00 29.17 327.43 8496.34 1154.32 -1541.89 9034.00 34.77 327.43 8508.21 1160.56 -1545.88 9084.00 41.41 321.77 8547.55 1185.60 -1563.82 9184.00 43.58 299.72 8621.69 1228.92 -1614.51 9284.00 45.60 278.48 8693.31 1251.40 -1680.15 9384.00 46.97 299.20 8762.81 1274.62 -1747.78 9474.00 47.98 280.89 8823.92 1297.09 -1809.61 9701.00 82.03 280.89 8918.44 1335.41 -2008.68 9861.00 81.50 305.14 8941.70 1396.82 -2153.30 10091.00 83.00 270.35 8973.68 1465.05 -2366.94 10151.00 92.00 270.35 8976.29 1465.42 -2426.82 10341.00 92.62 293.16 8968.52 1503.82 -2611.46 10391.00 90.27 287.64 8967.26 1521.23 -2658.29 10641.00 90.23 257.63 8966.14 1532.59 -2905.18 10711.00 90.23 249.23 8965.85 1512.65 -2972.21 10811.00 102.05 251.35 8955.18 1479.16 -3065.64 10941.00 104.28 267.21 8925.40 1455.62 -3189.55 10965.00 104.76 270.14 8919.38 1455.09 -3212.77 Survey r-------S1D, fL:' 8886.00 8900.00 8925.00 8950.00 8975.00 -...-.---.---...... .........'..............""......"... ",In;~g Az~~" ":, Sys ~VD_,::::\;.::C N~~>~,-: 27.75 325.00 8378.53 1101.15 27.90 325.31 8390.91 1106.51 28.16 325.85 8412.98 1116.20 28.43 326.38 8434.99 1126.04 28.70 326.90 8456.95 1136.02 8980.00 9000.00 9020.00 9025.00 9034.00 9050.00 9075.00 9084.00 327.00 327.22 327.43 327.43 327.43 325.43 322.67 321.77 1138.03 1146.14 1154.32 1156.43 1160.56 1168.36 1180.95 1185.60 8461.34 8478.85 8496.34 8500.66 8508.21 8521.18 8540.74 8547.55 28.75 28.96 29.17 31.17 34.77 36.87 40.20 41.41 E/W ,:,> ,,:' ft -1506.54 -1510.28 -1516.92 -1523.52 -1530.10 -1531.41 -1536.65 -1541.89 -1543.25 -1545.88 -1551.06 -1560.21 -1563.82 Date Composed: Version: Tied-to: '2,', , .i. Qracle " ---- 1/8/2004 4 From: Definitive Path DLS Build Turn:,": deg/10OO deg/1 OOft ~~~~ 2,2ft 0.00 0.00 0.00 1.46 1.06 2.13 1.17 1.05 1.07 40.00 40.00 0.00 15.00 13.29 -11.32 15.00 2.17 -22.05 15.00 2.01 -21.24 15.00 1.38 20.72 15.00 1.11 -20.34 15.00 15.00 0.00 15.00 -0.33 15.16 15.00 0.65 -15.13 15.00 15.00 0.00 12.00 0.33 12.01 12.00 -4.71 -11.04 12.00 -0.01 -12.00 12.00 0.00 -12.00 12.00 11.81 2.12 12.00 1.72 12.20 12.00 2.01 12.22 M~pN",/ 5941774.82 5941780.08 5941789.59 5941799.25 5941809.06 5941811.04 5941819.00 5941827.04 5941829.12 5941833.18 5941840.84 5941853.19 5941857.74 MapE ft 696427.13 696423.25 696416.36 696409.50 696402.66 696401.30 696395.85 696390.39 696388.98 696386.24 696380.86 696371.38 696367.65 .' ··--..-------------·..-·-1 Target I TFO dèli 0.00 44.31 26.56 0.00 330.00 270.00 270.00 92.00 268.00 0.00 93.00 270.00 0.00 88.00 247.00 270.00 270.00 10.00 80.00 80.00 VS , ,ft 1826.65 1832.26 1842.31 1852.38 1862.49 1864.52 1872.63 1880.79 1882.89 1887.00 1894.93 1908.46 1913.66 DLS deg/1 000 0.00 1.46 1.46 1.46 1.46 'TFO' deg ----- 0.00 TIP 44.31 MWD 44.04 MWD 43.57 MWD 43.10 MWD Tool,: 1.46 1.17 1.17 40.00 40.00 15.00 15.00 15.00 42.64 MWD 26.56 MWD 26.37 MWD 360.00 MWD 0.00 KOP 330.00 MWD 331.62 MWD 333.78 3 Company: BP Amoco , Field: Pfudhoe,Bay« ~~~:' ,~~:~S (~1~,:,;,::" Well Jåth:(j~¡:>lan #4:01-178 Survey MD ,ft 9100.00 9125.00 9150.00 9175.00 9184.00 9200.00 9225.00 9250.00 9275.00 9284.00 9300.00 9325.00 9350.00 9375.00 9384.00 9400.00 9425.00 9450.00 9474.00 9475.00 9500.00 9525.00 9550.00 9575.00 9600.00 9625.00 9650.00 9675.00 9700.00 9701.00 9725.00 9750.00 9775.00 9800.00 9825.00 9850.00 9861.00 9875.00 9900.00 9925.00 9950.00 9975.00 10000.00 10025.00 10050.00 10075.00 10091.00 10100.00 10125.00 10150.00 10151.00 10175.00 Ind deg 41.47 41.79 42.37 43.22 43.58 43.63 43.93 44.47 45.26 45.60 45.56 45.70 46.09 46.70 46.97 46.94 47.07 47.42 47.98 48.13 51.88 55.63 59.38 63.13 66.88 70.63 74.38 78.13 81.88 82.03 81.85 81.71 81.60 81.53 81.49 81.49 81.50 81.51 81.55 81.62 81.73 81.88 82.06 82.28 82.53 82.81 83.00 84.35 88.10 91.85 92.00 92.10 -~_._---- Azi!h dèg 318.14 312.52 306.99 301.61 299.72 296.24 290.83 285.51 280.31 278.48 281.84 287.08 292.28 297.39 299.20 295.91 290.79 285.70 280.89 280.89 280.89 280.89 280.89 280.89 280.89 280.89 280.89 280.89 280.89 280.89 284.53 288.31 292.10 295.89 299.68 303.47 305.14 303.02 299.23 295.44 291.65 287.86 284.08 280.30 276.53 272.76 270.35 270.35 270.35 270.35 270.35 273.23 e BP-GDB e Baker Hughes INTEQ Planning Report ':SY~:~VD 8559.54 8578.24 8596.80 8615.15 8621.69 8633.28 8651.33 8669.26 8686.99 8693.31 8704.51 8721.99 8739.40 8756.65 8762.81 8773.73 8790.78 8807.76 8823.92 8824.59 8840.65 8855.43 8868.86 8880.88 8891.45 8900.50 8908.02 8913.96 8918.30 8918.44 8921.81 8925.38 8929.01 8932.68 8936.37 8940.08 8941.70 8943.77 8947.46 8951.12 8954.74 8958.30 8961.80 8965.20 8968.51 8971.70 8973.68 8974.67 8976.31 8976.32 8976.29 8975.43 ::NiS'f' ' :,:: fP '/' 1193.70 1205.50 1216.20 1225.76 1228.92 1234.09 1240.99 1246.42 1250.35 1251.40 1253.41 1257.87 1263.91 1271.51 1274.62 1280.03 1287.27 1293.02 1297.09 1297.23 1300.85 1304.66 1308.65 1312.79 1317.07 1321.47 1325.98 1330.57 1335.22 1335.41 1340.63 1347.63 1356.17 1366.22 1377.75 1390.69 1396.82 1404.58 1417.36 1428.71 1438.59 1446.95 1453.76 1458.99 1462.62 1464.62 1465.05 1465.11 1465.26 1465.41 1465.42 1466.16 . . .... . . .. .... . " Date: 1/8/2004 Ti11Ïè: :13:44:35 , < Co-ordinate(NE) Reference: «'W~II: 01-17~TrueNorth'"" " ;.1', X:::i~:t([~~~e:~~~::ce: :'m::;!';'!~lt~(~~~~~0~0~~~2~~~~i~i)" Survey Calculationl\iethod:}.:< M!nimum C~rvature Db: :~0 ».. EJW< "ff" -1570.63 -1582.30 -1595.17 "1609.19 -1614.51 -1624.25 -1640.10 -1656.65 -1673.83 -1680.15 -1691.40 -1708.69 -1725.58 -1742.00 -1747.78 -1758.14 -1774.92 -1792.34 -1809.61 -1810.34 -1829.14 -1848.94 -1869.64 -1891.16 -1913.40 -1936.28 -1959.69 -1983.53 -2007.70 -2008.68 -2031.85 -2055.58 -2078.79 -2101.38 -2123.25 -2144.31 -2153.30 -2164.76 -2185.93 -2207.89 -2230.57 -2253.85 -2277.65 -2301.85 -2326.36 -2351.07 -2366.94 -2375.88 -2400.82 -2425.82 -2426.82 -2450.79 , )"lapN ft ' 5941865.66 5941877.15 5941887.51 5941896.69 5941899.70 5941904.62 5941911.10 5941916.09 5941919.57 5941920.45 5941922.17 5941926.17 5941931.77 5941938.94 5941941.89 5941947.03 5941953.83 5941959.11 5941962.73 5941962.85 5941965.98 5941969.27 5941972. 70 5941976.28 5941979.97 5941983.77 5941987.66 5941991.62 5941995.64 5941995.80 5942000.42 5942006.78 5942014.71 5942024.17 5942035.12 5942047.50 5942053.40 5942060.85 5942073.07 5942083.84 5942093.12 5942100.87 5942107.05 5942111.64 5942114.62 5942115.98 5942115.99 5942115.81 5942115.30 5942114.80 5942114.78 5942114.90 MapE ft 696360.63 696348.66 696335.51 696321.24 696315.84 696305.97 696289.95 696273.26 696255.99 696249.64 696238.34 696220.94 696203.90 696187.29 696181.43 696170.93 696153.97 696136.40 696119.03 696118.30 696099.41 696079.52 696058.72 696037.11 696014.76 695991.77 695968.25 695944.30 695920.02 695919.04 695895.74 695871.83 695848.41 695825.57 695803.40 695782.01 695772.87 695761.20 695739.71 695717.45 695694.53 695671.04 695647.07 695622.74 695598.15 695573.39 695557.52 695548.58 695523.64 695498.65 695497.65 695473.67 VS ft 1923.21 1938.71 1954.85 1971.57 1977.71 1988.72 2006.00 2023.32 2040.59 2046.78 2057.86 2075.45 2093.33 2111.42 2117.97 2129.64 2147.91 2166.15 2183.56 2184.28 2202.91 2222.51 2243.01 2264.32 2286.35 2309.01 2332.19 2355.80 2379.74 2380.70 2403.97 2428.47 2453.14 2477.86 2502.54 2527.06 2537.78 2551.43 2575.98 2600.67 2625.40 2650.06 2674.54 2698.75 2722.57 2745.91 2760.54 2768.71 2791.49 2814.32 2815.24 2837.38 DLS'" deg/10aft 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 12.00 'fFO deg 270.00 272.72 276.93 281.03 284.98 270.00 272.52 276.42 280.24 283.93 92.00 89.65 85.98 82.36 78.84 268.00 270.24 273.74 277.19 0.00 360.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 360.00 0.00 93.00 92.49 270.00 270.31 270.87 271.43 271.98 272.52 273.04 273.56 274.06 274.54 0.00 0.00 360.00 0.00 88.00 · ........ . .. . · ....... ... · . ....... .. ........ . ... . · ......... . ..... . ............ ..... · ....... . . .. . ....... .... ·:··xT:::·..· ." :~:.. :": · ...... . .. . · ....... ... ~çl~,:!!:i;l' ' ,"Tool MWD MWD MWD MWD 4 MWD MWD MWD MWD 5 MWD MWD MWD MWD 6 MWD MWD MWD 7 MWD MWD MWD 91.95 91.40 90.84 90.28 89.72 MWD MWD MWD MWD MWD MWD MWD· 8 MWD MWD MWD MWD MWD MWD 9 MWD MWD MWD MWD MWD MWD MWD MWD MWD 1Ú MWD MWD MWD 11 MWD e BP-GDB e Baker Hughes INTEQ Planning Report .. _ . ___n.__ ---..-... .. - -.- --.- .. . ..-- ...-.... ... ... Coml'an)': BP Amoco Datc: 1/8/2004 Timc: 13:44:35 I'a!:e: 4 I'icld: Prudhoe Bay Co-ordinaU~(.'I; E) Refercncc: Well: 01-17, True North SUc: PB DS 01 Vt'rtical (TV » Rcfcrcnce: System: Mean Sea level Well: 01-17 Section (VS) Reference: Well (0.00N,0.00E,294.37Azi) Wellpalh: Plan #4 01-17B Surve~' Calculation :\1e1hod: Minimum Curvature 1)11: Oracle .. .-- ---...--.--.-.. --...... . . .. ... ....-.--.-... -- .on n.____.._ ..... .-...........-.-.. n. .... ......_ _.__...._n__.......___. Survey ..---.- .-. ... . . .. .___._,._.__.__n .. :\11) Incl Azim Sys TV ) :'\i/S ~:/W :\Iap:-.i :\lapE VS I>I.S TI'O Tool ft deg deg ft ft ft ft ft ft deg/100ft deg .. .....--.....-----.---. ......-.--...---.---. .. . .....-...--,.-.----. -.-... ......---.---... .. - . 10200.00 92.20 276.23 8974.49 1468.22 -2475.68 5942116.30 695448.73 2860.91 12.00 88.10 MWD 10225.00 92.29 279.23 8973.51 1471.58 -2500.44 5942119.01 695423.90 2884.84 12.00 88.22 MWD 10250.00 92.37 282.23 8972.50 1476.23 -2524.97 5942123.01 695399.25 2909.11 12.00 88.33 MWD 10275.00 92.45 285.23 8971.44 1482.16 -2549.24 5942128.30 695374.84 2933.66 12.00 88.46 MWD 10300.00 92.52 288.23 8970.36 1489.35 -2573.15 5942134.86 695350.75 2958.41 12.00 88.58 MWD 10325.00 92.58 291.24 8969.25 1497.78 -2596.66 5942142.67 695327.03 2983.30 12.00 88.71 MWD 10341.00 92.62 293.16 8968.52 1503.82 -2611.46 5942148.31 695312.08 2999.27 12.00 88.85 12 10350.00 92.20 292.16 8968.14 1507.28 -2619.75 5942151.56 695303.69 3008.26 12.00 247.00 MWD 10375.00 91.02 289.40 8967.44 1516.15 -2643.12 5942159.81 695280.11 3033.20 12.00 246.96 MWD 10391.00 90.27 287.64 8967.26 1521.23 -2658.29 5942164.49 695264.81 3049.11 12.00 246.88 13 10400.00 90.27 286.56 8967.22 1523.87 -2666.89 5942166.91 695256.14 3058.04 12.00 270.00 MWD 10425.00 90.27 283.56 8967.10 1530.37 -2691.03 5942172.76 695231.84 3082.71 12.00 269.99 MWD 10450.00 90.27 280.56 8966.98 1535.59 -2715.47 5942177.34 695207.27 3107.13 12.00 269.98 MWD 10475.00 90.26 277.56 8966.86 1539.52 -2740.16 5942180.62 695182.49 3131.24 12.00 269.97 MWD 10500.00 90.26 274.55 8966.75 1542.16 -2765.02 5942182.61 695157.58 3154.97 12.00 269.95 MWD 10525.00 90.26 271.55 8966.64 1543.49 -2789.98 5942183.28 695132.59 3178.26 12.00 269.94 MWD 10550.00 90.25 268.55 8966.52 1543.51 -2814.97 5942182.65 695107.60 3201.04 12.00 269.93 MWD 10575.00 90.25 265.55 8966.41 1542.23 -2839.94 5942180.71 695082.68 3223.25 12.00 269.91 MWD 10600.00 90.24 262.55 8966.31 1539.64 -2864.80 5942177.47 695057.90 3244.83 12.00 269.90 MWD 10625.00 90.24 259.55 8966.20 1535.75 -2889.49 5942172.94 695033.32 3265.72 12.00 269.89 MWD 10641.00 90.23 257.63 8966.14 1532.59 -2905.18 5942169.36 695017.72 3278.70 12.00 269.87 14 10650.00 90.23 256.55 8966.10 1530.58 -2913.95 5942167.12 695009.01 3285.86 12.00 270.00 MWD 10675.00 90.23 253.55 8966,00 1524.13 -2938.10 5942160.05 694985.03 3305.20 12.00 270.00 MWD 10700.00 90.23 250.55 8965.90 1516.43 -2961.88 5942151.72 694961.46 3323.69 12.00 269.98 MWD 10711.00 90.23 249.23 8965.85 1512.65 -2972.21 5942147.67 694951.24 3331.54 12.00 269.97 15 10725.00 91.89 249.53 8965.59 1507.72 -2985.31 5942142.40 694938.27 3341.44 12.00 10.00 MWD 10750.00 94.84 250.05 8964.13 1499.10 -3008.73 5942133.17 694915.09 3359.21 12.00 10.01 MWD 10775.00 97.79 250.58 8961.38 1490.73 -3032.12 5942124.19 694891.93 3377.07 12.00 10.04 MWD 10800.00 100.75 251.11 8957.35 1482.63 -3055.43 5942115.48 694868.84 3394.96 12.00 10.09 MWD 10811.00 102.05 251.35 8955.18 1479.16 -3065.64 5942111.74 694858.73 3402.82 12.00 10.18 16 10825.00 102.33 253.04 8952.22 1474.98 -3078.66 5942107.22 694845.82 3412.97 12.00 80.00 MWD 10850.00 102.82 256.08 8946.78 1468.48 -3102.18 5942100.11 694822.48 3431.71 12.00 80.36 MWD 10875.00 103.27 259.12 8941.13 1463.25 -3125.96 5942094.26 694798.84 3451.22 12.00 81.02 MWD 10900.00 103.68 262.18 8935.31 1459.30 -3149.95 5942089.68 694774.97 3471.44 12.00 81.71 MWD 10925.00 104.06 265.24 8929.31 1456.65 -3174.07 5942086.39 694750.93 3492.31 12.00 82.42 MWD 10941.00 104.28 267.21 8925.40 1455.62 -3189.55 5942084.96 694735.48 3505.99 12.00 83.15 17 /10950.00 104.47 268.31 8923.16 1455.28 -3198.26 5942084.39 694726.78 3513.78 12.00 80.00 MWD 10965.00 104.76 270.14 8919.38 1455.09 -3212.77 5942083.81 694712.28 3526.92 12.00 80.27 TO e Nordic 1 bighole All Measurements are from top of Riser ~ Q) (/) .- a: top of bag bttm of bag middle of slips Blind/Shears middle of pipes middle of flow cross Mud Cross middle of blind/shears middle of pipe/slips Flow Tee .....;y.: ................ / ......................... / .......................... / ......................... e 1/8/2004 BAG 7 1/16" 5000psi TOTs 71/16" 5000psi Mud Cross 71/16" 5000psi TOTs 71/16" 5000psi e 055201 DATE !f\JVO¡CE / CREDIT MEMO DESCR~PT:O¡\I VENDOR DiSCOUNT ¡, 11/25/2003 PR 111803K I I PERMIT TO DRILL FEES ~ AITßJ;¡-¡!ED CHECK is iN PAYI¡f¡EN, FOR .TEIVIS DESCRIBED ABOVE. GROSS - DÞTE 11/25/2003 56-389 412 CHECK r\!o. 055201 !\~ET o 5 5 2 0 1! BP PRUDHOE BAY UNIT PO SOX 196612 ANCHORAGE, AK 99519-6612 >AY: ~n D "' i" i ,!" ,. " ., 'OTHE )RDER )F: ALASKA OIL & GAS CONSERVATION COMMISSION 333 W 7TH AVENUE SUITE 100 ANCHORAGE, AK 99501-3539 COf\!SOL!DATED COMMERGU\LACCOU¡\jT ~ DATE " November 25, 2003 i ÞdViC~UNT r-·------------í ! *******$100.00*******1 J 1110 5 5 20 .111 I: 0 '-t ~ 2 0 ~ 8 g 51: 0 * 2 7 B g b liD NOï ~ELLÚ~f:RMIT Çitt~CKLlST Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 PTD#:2040120 Company BP EXPLORATION (ALASKA) INC Initial ClasslType Administration 1 P_ermit fee attaçhe~ Yes 2 Lease_number _ap¡:¡ropriate_ YeS 3 _U_n[que welt name_and ol!mb_er Yes_ 4 WelllQcated ¡n_aßefine~pool. Yes 5 Well IQcated proper _d [stan ce_ from driJling unitb_ound_a!:y_ Yes 6 WelllQcated pr.operdistance from otber wells_ Yes 7 .SuffiçienLaçreage_ayailable in.dJilliog unjt Yes 8 Itdeviated. js wellbQre platincJu_ded Yes 9 Operator onlY' affeçted party _ N9 10 _Operator bas_appropr[ate-'~ond [nJorce Yes _ 11 Permit c_an be [sSl!ed wjtbQut co.nservation order _ Yes Appr Date 12 Permit can be [sSl!ed wjtbQut ¡¡¡dministratille_appr9val Yes RPC 1/12/2004 13 Can permit be approved before 15-day wait Yes 14 WelllQcated within area and_strata authorized by_lojectioo Ord_er # (puUOfi incornmeotsJ-(For_NA 15 _AJI we IJs_with in Jl4JlJile_area_ot reyiew jdeot[fied (F9r servjcewell onlY') _ _ _NA _ 16 Pre-produced injector;duratiQn.of pre-pro~uGlioo tess_ th¡¡¡n 3 montbs (For_service well QnJy) NA 17 ACMP finding ofConsi,stencyhas beenjssued_forJbis project _ _ _ NA __ Engineering Appr Date WGA 1/13/2004 Geology Appr RPC Date 1/12/2004 Well Name: PRUDHOE BAY UNIT 01-17B DEV /1-0IL GeoArea 890 Unit o o Program DEV On/Off Shore On Well bore seg Annular Disposal 11650 e- - -- 18 CÞnductor string.prQvided 19S_urfacecasing pJotecJs all known USDWs 20 _CMT vol adeQuateJo tirc_utateoJl.cond_uçtor_ 8. su_rtc,sg 21 _CMT vol adeQ u.ateJo tie-in long _string tosu rf csg_ 22 _CMT will coyer.aJl known "pro_ductiye borizon_s_ 23 Casing designs ¡¡¡d_eç uaJe f9r C,T, B& Rermafrost 24 AdequateJ¡¡¡n_kageoJ re_serve pit 25 ItaJe-~rilt has_a_ to-403 tQr abandon_ment been apPJoved 26 A~equate_we!lbore sep¡¡¡ratjoJl.proP9se~_ 27 Itdjver:ter Jequired. dQes jt meet regulations 28DJiUiog flujd ¡:¡rogram schematic & e~uip listadequate. 29 _BOPEs._d_o .they meet regulatioo 30 BOPE.press raJiog ¡¡¡pproÞriate; .test to .(puJ psig in_comments). 31 .C_hoke manifold çQmplies w/APt R~-53 (May 64). 32 WQrk willocc_ur withoutoperatjonsbutdown_ 33 Is ¡:¡resence_ of H2S gas_ ¡:¡rOQable_ 34 Mecha.nlcaLcoodjt[On9f wells within ,ð.OR yerified (For_s_ervjc;e well only) 35 Permit c.an be issued wlQ hydrogen. s_ulfide rneas.ures _ 36 _D_ata_preseoted on_ ¡:¡ote_ntial oveJ :)res.s!,Jre _zone,s_ 37 .Seisrnlc_analysjs Qf sballow gas_z90es_ 38 _Se¡¡¡be~ _condjtioo survey _(if Qff-sh_ore) 39 _ CQnta_ct namelphQneJQr_weekly progressre¡:¡oJt$ [ex¡:¡IQrato!:Y _onlYl NA NA NA NA Yes Yes Yes CTDU._ Yes 1/08/20M. _YeS _ _ __ NA Sidetraçk. Yes M¡¡¡x MW8,8 ¡:¡pgc Yes Yes Testt03500. ¡:¡si. MS~ 2200 psi._ Yes Yes Yes NA No NA NA NA NA e Geologic Commissioner: Date ()i<s Date: Engineering Commissioner: Public ~-A'? Commissioner g r Date '/I/y 1/ 13/"'- e e 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. Sperry-Sun Drtlting Services LIS Scan Utility e ~ 'I-O/l- $Revision: 3 $ LisLib $Revision: 4 $ Tue Sep 07 15:51:48 2004 )d--1&1 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/09/07 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... .UNKNOWN Continuation Number..... .01 Previous Reel Name... . . . .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name... ......... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/09/07 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name. . . . . . . . . . . . . . . .UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002890057 B. JAHN S. KOLSTAD 1 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 6 MW0002890057 B. JAHN S. KOLSTAD 1 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 9 MW0002890057 B. JAHN R. WHITLOW 1 # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) 1-17B 500292028902 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 07-SEP-04 MWD RUN 3 MW0002890057 B. JAHN S. KOLSTAD 1 MWD RUN 5 MW0002890057 B. JAHN S. KOLSTAD/J MWD RUN 7 MW0002890057 B. JAHN S. KOLSTAD 1 MWD RUN 8 MW0002890057 B. JAHN R. WHITLOW 1 MWD RUN 10 MW0002890057 B. JAHN R. WHITLOW 1 8 ION 15E 191 RECEtVtD ('CD "j' .., 0f\(\ A \.h...! ¡....!J-; 646 l~askaOil& Gas Con&.eomm_n M~ KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: e 73.00 e # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 4.125 4.500 8896.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . 3. THIS WELL WAS DRILLED OFF OF A CEMENT RAMP IN THE 1-17A WELLBORE. THE TOP OF THE WINDOW IS AT 9020'MD AND THE BOTTOM IS AT 9027'MD. 4. MWD RUNS 1 - 6 WERE DIRECTIONAL; AND DUAL GAMMA RAY (GM) I UTILIZING GEIGER-MUELLER TUBE DETECTORS. THESE RUNS WERE TO CLEAN OUT; TIE-IN; MILL THE WINDOW; AND BUILD ANGLE. NO PROGRESS WAS MADE ON MWD RUN 4. 5. MWD RUNS 7 - 10 COMPRISED DIRECTIONAL; GM; AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4(EWR4). 6. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED- HOLE GAMMA RAY RUN ON 8 FEBRUARY 2004. THESE LOG DATA WERE PROVIDED BY K. COONEY (SIS/BP) ON 30 AUGUST 2004. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 1 - 10 REPRESENT WELL 1-17B WITH API#: 50-029-20289-02. THIS WELL REACHED A TOTAL DEPTH(TD)OF 11057'MD/8943'TVDSS. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SPACING) . SEMP = SMOOTHED PHASE SPACING) . SEDP = SMOOTHED PHASE SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ SHIFT-DERIVED RESISTIVITY ( SHALLOW SHIFT-DERIVED RESISTIVITY (MEDIUM SHIFT-DERIVED RESISTIVITY (DEEP File Header Service name............ .STSLIB.OOl Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .04/09/07 Maximum Physical Record. .65535 File Type..............._ Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX $ 1 e and clipped curves; all bit runs merged. .5000 START DEPTH 8681.5 9023.5 9492.5 9492.5 9492.5 9492.5 9492.5 STOP DEPTH 11007.0 11052.0 11020.0 11020.0 11020.0 11020.0 11020.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ----- BASELINE DEPTH 8681.5 8682.0 8686.0 8698.0 8701.0 8704.0 8715.0 8726.5 8736.5 8746.0 8751.5 8769.5 8774.5 8778.0 8791. 5 8794.0 8807.0 8821. 0 8826.5 8830.5 8836.5 8843.5 8847.5 8854.0 8857.5 8876.5 8891.0 8918.5 8930.0 8958.0 8968.5 8997.0 9000.5 9023.5 9030.5 9036.0 9043.0 9062.0 9072.5 9080.5 9090.5 9101.0 9112.5 GR 8680.0 8680.5 8684.0 8697.0 8699.5 8702.5 8713.0 8724.5 8734.5 8742.0 8749.0 8767.0 8772 . 0 8777.0 8790.0 8793.0 8806.5 8820.0 8827.0 8831.0 8836.0 8841.5 8845.0 8851.0 8854.5 8874.5 8890.0 8917.5 8929.0 8957.0 8968.0 8998.5 9000.5 9021.5 9026.5 9034.5 9040.5 9061.5 9073.0 9079.5 9091.5 9102.5 9109.0 9122.5 9125.0 9132.5 9140.5 9147.5 9161.5 9171.0 9176.0 9180.0 9186.5 9193.0 9200.5 9208.5 9220.5 9226.5 9238.5 9245.5 9257.0 9260.0 9265.0 92 94 . 0 9300.0 9311.5 9323.5 9331.0 9363.0 9392.5 9406.0 9413 . 5 9418.5 9431.5 9513.5 9548.5 9563.0 9568.5 9573.5 9598.0 9604.0 9614.5 9617.5 9625.5 9631. 0 9638.5 9695.5 9711.0 9727.5 9735.0 9739.5 9750.5 9756.5 9780.5 9789.5 9803.0 9809.5 9824.5 9895.5 9902.0 9919.5 9935.0 9948.5 9957.0 9968.0 9978.5 9991.5 9997.0 10002.5 10014.5 10024.5 9119._ 9124.0 9132.5 9141. 0 9148.0 9161. 5 9171.0 9176.0 9180.5 9186.0 9190.5 9198.5 9207.5 9220.0 9227.5 9238.0 9245.0 9257.0 9261.0 9266.0 92 96.5 9301. 5 9314.0 9326.0 9333.5 9366.0 9391.0 9405.0 9412.5 9417.5 9431.5 9516.5 9553.0 9568.0 9574.5 9578.5 9601.0 9607.0 9618.0 9620.5 9627.5 9632.5 9639.0 9693.5 9708.5 9724.5 9736.0 9741.0 9750.5 9757.0 9780.0 9792.0 9806.0 9813.0 9829.5 9898.0 9903.5 9922.0 9937.0 9951.5 9959.5 9973.0 9978.0 9988.0 9992.0 9998.5 10010.0 10024.5 e 10030.5 10062.0 10076.5 10092.0 10107.0 10109.0 10112.5 10123.0 10167.5 10187.0 10205.5 10214.0 10247.5 10267.0 10300.5 10321.0 10343.5 10374.5 10382.5 10397.5 10403.5 10408.0 10417.0 10433.5 10449.0 10455.0 10462.0 10473.5 10486.0 10494.5 10510.0 10514.0 10529.5 10541.5 10569.0 10600.0 10613.0 10672.5 10714.0 10720.0 10723.0 10742.5 10759.5 10776.5 10788.5 10811.0 10823.5 10832.5 10841.0 10850.0 10857.0 10863.5 10880.0 10882.0 10907.0 10912.5 10917.5 10927.0 11052.0 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD 10027. ø 10057.5 10073.0 10088.5 10101.5 10103.0 10108.5 10115.5 10160.5 10180.5 10198.5 10206.5 10241.5 10261.5 10294.0 10317.5 10339.5 10372.5 10383.5 10400.0 10407.0 10413.0 10421.0 10435.0 10452.0 10458.5 10466.0 10476.0 10491.0 10497.5 10514.0 10516.5 10534.5 10544.5 10570.5 10599.0 10613.0 10673.5 10713.0 10720.5 10726.0 10743.5 10762.0 10780.5 10791. 5 10814.5 10827.0 10835.5 10843.5 10853.5 10861.0 10865.5 10884.0 10887.5 10912.0 10918.0 10922.5 10932.0 11057.0 BIT RUN NO 1 3 5 6 7 MERGE TOP 8680.0 8992.5 9036.0 9448.0 9526.0 - MERGE BASE 8992.0 9035.5 9448.0 9525.5 9665.5 MWD MWD MWD $ e 9665.5 10176.0 10532.0 10176.0 10532.0 11057.0 e 8 9 10 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type.. ................0 Data Specification Block Type.....O Logging Direction.. .............. . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8681.5 11052 9866.75 4742 8681.5 11052 ROP MWD FT/H 0.01 4315.81 78.9495 4058 9023.5 11052 GR MWD API 15.6 501. 52 58.8499 4652 8681.5 11007 RPX MWD OHMM 5.16 70.17 17.6054 3056 9492.5 11020 RPS MWD OHMM 5.73 93.03 20.5169 3056 9492.5 11020 RPM MWD OHMM 6.28 98.75 22.4271 3056 9492.5 11020 RPD MWD OHMM 7.23 764.04 29.1927 3056 9492.5 11020 FET MWD HOUR 0.2 35.73 2.27182 3056 9492.5 11020 First Reading For Entire File......... .8681.5 Last Reading For Entire File.......... .11052 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/09/07 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... ....04/09/07 Maximum Physical Record..65535 File Type............... .LO Previous File Name...... ~SLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR $ 2 e header data for each bit run in separate files. 1 .5000 START DEPTH 8680.0 STOP DEPTH 8992.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM $ BOTTOM) TOOL TYPE Dual GR # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.... ...... ........0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined 28-JAN-04 Insite 4.3 Memory 8898.0 8710.0 8898.0 .0 .0 TOOL NUMBER 93091 3.760 2704.0 Water 8.30 55.0 9.5 10000 .0 .000 .000 .000 .000 .0 162.6 .0 .0 Frame SPaCing...........~....... 60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT GR MWD010 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 API 4 1 68 4 2 Name Service Unit DEPT FT GR MWD010 API Min 8680 30 Mean 8836 69.7899 Nsam 625 625 Max 8992 150.86 First Reading For Entire File........ ..8680 Last Reading For Entire File.......... .8992 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/09/07 Maximum Physical Record. .65535 File Type............ ... .LO Next File Name.. ........ .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..04/09/07 Maximum Physical Record. .65535 File Type.. ............. .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 e First Reading 8680 8680 Last Reading 8992 8992 header data for each bit run in separate files. 3 .5000 START DEPTH 8992 .5 9021.5 STOP DEPTH 9008.0 9035.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): 31-JAN-04 Insite 4.3 Memory 9036.0 8898.0 9036.0 HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: e # TOOL STRING (TOP TO VENDOR TOOL CODE GM $ BOTTOM) TOOL TYPE Dual GR # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record.... ....... ..Undefined Absent value.............. ....... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD030 GR MWD030 Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code Units FT FT/H API e .0 .0 TOOL NUMBER 93091 3.800 2704.0 Water 8.50 55.0 9.5 13000 .0 .000 .000 .000 .000 .0 170.0 .0 .0 Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8992.5 9035.5 9014 87 8992.5 9035.5 ROP MWD030 FT/H 0.01 12.25 6.14793 29 9021. 5 9035.5 GR MWD030 API 48.28 113.93 89.1287 32 8992.5 9008 First Reading For Entire File......... .8992,5 Last Reading For Entire File.......... .9035.5 File Trailer service name....... .... .~SLIB.003 service Sub Level Name... Version Number.. ........ .1.0.0 Date of Generation...... .04/09/07 Maximum Physical Record. .65535 File Type............... .LO Next File Name....... ....STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/09/07 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 4 e header data for each bit run in separate files. 5 .5000 START DEPTH 9008.5 9036.0 STOP DEPTH 9420.0 9448.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM $ BOTTOM) TOOL TYPE Dual GR # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: 01-FEB-04 Insite 4.3 Memory 9448.0 9036.0 9448.0 39.6 50.1 TOOL NUMBER 72829 4.125 8896.0 Water Based 8.70 55.0 9.5 25000 .0 .000 .0 .000 123.8 MUD FILTRATE AT MT. MUD CAKE AT MT: .000 .000 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units........ ...Feet Data Reference Point............. .Undefined Frame Spacing................ .... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Service Order Units FT FT/H API Size 4 4 4 Nsam 1 1 1 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD050 MWD050 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9008.5 9448 9228.25 880 9008.5 9448 ROP MWD050 FT/H 0.01 1065.44 38.4459 825 9036 9448 GR MWD050 API 22.04 501.52 80.4257 824 9008.5 9420 First Reading For Entire File.... ..... .9008.5 Last Reading For Entire File...... .... .9448 File Trailer Service name......... ... .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/09/07 Maximum Physical Record. .65535 File Type............... .LO Next File Name......... ..STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number...... .... .1.0.0 Date of Generation...... .04/09/07 Maximum Physical Record. .65535 File Type. .............. .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ e 5 - header data for each bit run in separate files. 6 .5000 START DEPTH 9420.5 9448.5 STOP DEPTH 9497.5 9525.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM $ BOTTOM) TOOL TYPE Dual GR # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing......... ........... .60 .1IN Max frames per record........ .... . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 02-FEB-04 Insite 4.3 Memory 9526.0 9448.0 9526.0 46.3 48.8 TOOL NUMBER 72829 3.750 8896.0 Flo Pro 8.80 55.0 8.5 25000 .0 .000 .000 .000 .000 .0 120.2 .0 .0 Depth Datum , e UnJ.ts. . . . . . . . . . . . . . . . . . . . . . . Specification Block sub-type...O - Name Service Order DEPT ROP MWD060 GR MWD060 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code Offset o 4 8 Channel 1 2 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9420.5 9525.5 9473 211 9420.5 9525.5 ROP MWD060 FT/H 0.78 68.4 23.4889 155 9448.5 9525.5 GR MWD060 API 18.49 32.16 25.1325 155 9420.5 9497.5 First Reading For Entire File......... .9420.5 Last Reading For Entire File.......... .9525.5 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/09/07 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name....... ..... .STSLIB.006 Service Sub Level Name... Version Number..... ..... .1.0,0 Date of Generation. ..... .04/09/07 Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPM RPS RPX RPD GR ROP $ 6 header data for each bit run in separate files. 7 .5000 START DEPTH 9494.5 9494.5 9494 . 5 9494 . 5 9494 . 5 9498.0 9526.0 STOP DEPTH 9633.0 9633.0 9633.0 9633.0 9633.0 9620.0 9665.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : 04-FEB-04 Insite 4.3 Memory e 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 VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.............. ....0 Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units....... ... .Feet Data Reference Point............. .Undefined Frame Spacing.................. ...60 .1IN Max frames per record......... ....Undefined Absent value.................... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 9660.0 9526.0 9660.0 54.9 75.1 TOOL NUMBER 78012 178425 4.125 8896.0 Water 8.80 55.0 8.5 25000 .0 Based .100 .050 .170 .190 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD070 FT/H 4 1 68 4 2 GR MWD070 API 4 1 68 8 3 RPX MWD070 OHMM 4 1 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 FET MWD070 HOUR 4 1 68 28 8 Name Service Unit Min Max Mean Nsam e 60.0 125.0 60.0 60.0 First Reading Last Reading 9494. e DEPT FT 9665.5 9580 343 9494 . 5 9665.5 ROP MWD070 FT/H 1.17 191.13 45.0511 280 9526 9665.5 GR MWD070 API 21.3 40.14 28.7247 245 9498 9620 RPX MWD070 OHMM 11.82 70.17 35.445 278 9494 . 5 9633 RPS MWD070 OHMM 16.29 93.03 44.6476 278 9494 . 5 9633 RPM MWD070 OHMM 19.16 98.75 50.4552 278 9494 . 5 9633 RPD MWD070 OHMM 27.01 764.04 89.4959 278 9494 . 5 9633 FET MWD070 HOUR 0.65 35.73 9.26727 278 9494 . 5 9633 First Reading For Entire File......... .9494.5 Last Reading For Entire File. ......... .9665.5 File Trailer Service name.. .......... .STSLIB.006 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .04/09/07 Maximum Physical Record. .65535 File Type.... ........... .LO Next File Name.......... .STSLIB.007 Physical EOF File Header Service name............ .STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/09/07 Maximum Physical Record..65535 File Type............. ...LO Previous File Name...... .STSLIB.006 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX ROP $ 7 header data for each bit run in separate files. 8 .5000 START DEPTH 9620.5 9633.5 9633.5 9633.5 9633.5 9633.5 9666.0 STOP DEPTH 10132.5 10144.0 10144.0 10144.0 10144.0 10144.0 10176.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 05-FEB-04 Insite 4.3 Memory 10176.0 9660.0 10176.0 78.8 87.3 # e TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O - TOOL NUMBER 78012 178425 4.125 8896.0 Water 8.80 55.0 8.5 25000 .0 Based .120 .060 .170 .190 60.0 131.0 60.0 60.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD080 FT/H 4 1 68 4 2 GR MWD080 API 4 1 68 8 3 RPX MWD080 OHMM 4 1 68 12 4 RPS MWD080 OHMM 4 1 68 16 5 RPM MWD080 OHMM 4 1 68 20 6 RPD MWD080 OHMM 4 1 68 24 7 FET MWD080 HOUR 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 9620.5 10176 9898.25 1112 9620.5 10176 ROP MWD080 FT/H 0.41 381.17 57.2705 1021 9666 10176 GR MWD080 API 19.41 186.64 75.843 1025 9620.5 10132.5 RPX MWD080 OHMM 6.41 43.26 19.8518 1022 9633.5 10144 RPS MWD080 OHMM 9.77 50.04 22.8925 1022 9633.5 10144 RPM MWD080 OHMM 11.98 54.2 24.9073 1022 9633.5 10144 RPD MWD080 OHMM 14.64 718.99 33.3698 1022 9633.5 10144 FET MWD080 HOUR 0._ 5.77 - 1.56608 1022 9633.5 10144 First Reading For Entire File... ...... .9620.5 Last Reading For Entire File. ......... .10176 File Trailer Service name.. .......... .STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/09/07 Maximum Physical Record. .65535 File Type....... ........ .LO Next File Name......... ..STSLIB.008 Physical EOF File Header Service name............ .STSLIB.008 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/09/07 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.007 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPM RPS RPD FET RPX ROP $ 8 header data for each bit run in separate files. 9 .5000 START DEPTH 10133.0 10144.5 10144.5 10144.5 10144.5 10144.5 10176.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. # STOP DEPTH 10487.0 10499.5 10499.5 10499.5 10499.5 10499.5 10532.0 05-FEB-04 Insite 4.3 Memory 10532.0 10176.0 10532.0 88.9 92.6 RESIS. 4 TOOL NUMBER 78012 178425 BOREHOLE AND OPEN HOLE DRILLER'S CASING DATA- BIT SIZE (IN): CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.......... .... ....0 Data Specification Block Type.....O Logging Direction.... ............ . Down Optical log depth units.......... .Feet Data Reference Point...... ....... . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 3.750 8896.0 Flo Pro 8.60 60.0 9.2 23000 8.8 .080 .050 .200 .130 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD090 FT/H 4 1 68 4 2 GR MWD090 API 4 1 68 8 3 RPX MWD090 OHMM 4 1 68 12 4 RPS MWD090 OHMM 4 1 68 16 5 RPM MWD090 OHMM 4 1 68 20 6 RPD MWD090 OHMM 4 1 68 24 7 FET MWD090 HOUR 4 1 68 28 8 Name DEPT ROP GR RPX RPS RPM RPD FET Service Unit FT MWD090 FT/H MWD090 API MWD090 OHMM MWD090 OHMM MWD090 OHMM MWD090 OHMM MWD090 HOUR Min 10133 5.6 18.96 6.09 7.56 8.82 9.09 0.2 Max 10532 227.76 78.77 21.11 20.34 20.47 27.97 7.45 First Reading For Entire File......... .10133 Last Reading For Entire File.. ........ .10532 Mean 10332.5 118.08 29.7031 11.6845 12.7686 13.3616 13.2042 1. 47058 Nsam 799 712 709 711 711 711 711 711 e 79.0 135.3 60.0 50.0 First Reading 10133 10176.5 10133 10144.5 10144.5 10144.5 10144.5 10144.5 Last Reading 10532 10532 10487 10499.5 10499.5 10499.5 10499.5 10499.5 e File Trailer Service name............ .STSLIB.008 service Sub Level Name... Version Number........ ...1.0.0 Date of Generation. ......04/09/07 Maximum Physical Record..65535 File Type... ... ......... .LO Next File Name.......... .STSLIB.009 Physical EOF File Header Service name... ......... .STSLIB.009 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/09/07 Maximum Physical Record..65535 File Type............... .LO Previous File Name...... .STSLIB.008 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 9 - header data for each bit run in separate files. 10 .5000 START DEPTH 10487.5 10500.0 10500.0 10500.0 10500.0 10500.0 10532.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): STOP DEPTH 11012.0 11025.0 11025.0 11025.0 11025.0 11025.0 11057.0 06-FEB-04 Insite 4.3 Memory 11057.0 10532.0 11057.0 90.1 103.4 RESIS. 4 TOOL NUMBER 78012 178425 3.760 8896.0 Water Based 8.60 MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: e 55.0 9.3 24000 .0 e .120 .000 .080 .140 .0 140.0 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units....... ... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record..... ... .... .Undefined Absent value............ ......... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD100 FT/H 4 1 68 4 2 GR MWD100 API 4 1 68 8 3 RPX MWD100 OHMM 4 1 68 12 4 RPS MWD100 OHMM 4 1 68 16 5 RPM MWD100 OHMM 4 1 68 20 6 RPD MWD100 OHMM 4 1 68 24 7 FET MWD100 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10487.5 11057 10772 . 3 1140 10487.5 11057 ROP MWD100 FT/H 0.12 4315.81 115.714 1050 10532.5 11057 GR MWD100 API 15.6 177.2 48.5506 1050 10487.5 11012 RPX MWD100 OHMM 5.09 27.72 14.5777 1051 10500 11025 RPS MWD100 OHMM 5.72 32.38 16.9777 1051 10500 11025 RPM MWD100 OHMM 6.28 35.92 18.6478 1051 10500 11025 RPD MWD100 OHMM 7.23 42.49 19.827 1051 10500 11025 FET MWD100 HOUR 0.28 9.36 1.74205 1051 10500 11025 First Reading For Entire File......... .10487.5 Last Reading For Entire File.......... .11057 File Trailer Service name....... .... ..STSLIB.009 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .04/09/07 Maximum Physical Record. .65535 File Type........ ....... .LO Next File Name......... .~SLIB.010 e Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/09/07 Origin.................. .STS Tape Name............ ....UNKNOWN Continuation Number. ... ..01 Next Tape Name.......... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/09/07 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name........ ....... .UNKNOWN Continuation Number..... .01 Next Reel Name....... .., .UNKNOWN Comments............. ....STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
