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Home My WebLink About203-1107. Property Designation (Lease Number): 1. Operations Performed: 2. Operator Name: 3. Address: 4. Well Class Before Work:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): Susp Well Insp Install Whipstock Mod Artificial Lift Perforate New Pool Perforate Plug Perforations Coiled Tubing Ops Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown 11. Present Well Condition Summary: Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 16. Well Status after work: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. OIL GAS WINJ WAG GINJ WDSPL GSTOR Suspended SPLUG Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: Mill CIBP Intermediate Intermediate Intermediate Scab Liner x Liner Liner 1540 4020 5410 11780 Surface 520 Total Depth Effective Depth measured true vertical feet feet feet feet measured true vertical measured measured feet feet feet feet measured true vertical Plugs Junk Packer Measured depth True Vertical depth feet feet Perforation depth Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a.Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Well Class after work: Exploratory Development Service StratigraphicDaily Report of Well Operations Copies of Logs and Surveys Run Electronic Fracture Stimulation Data Sundry Number or N/A if C.O. Exempt: 13b. Pools active after work: Sr Pet Eng:Sr Pet Geo: Form 10-404 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Sr Res Eng: Due Within 30 days of Operations Mill CIBP DSR-3/22/23WCB 11-27-2023 RBDMS JSB 032323 Sundry Number Milled CIBP is shown correctly on the new WBS, below. -WCB of Ty �w\��7,',v THE STATE Alaska Oil and Gas ti ►` �`�M of/�, T Conservation Commission ,AsKA s} ==__- 1._ 333 West Seventh Avenue •' �2WALKERAnchorage, Alaska 99501-3572 pti,,, � GOVERNOR BILL 9 Main 907.279.1433 Op. ALAS"" Fax 907.276 7542 5(014E9} www.aogcc alaska.gov Aras Worthington Wells Engineer BP Exploration (Alaska), Inc. . ca-0-3______11 O P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU D-04B Sundry Number: 315-470 Dear Mr. Worthington: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster /* Chair DATED this ay of August, 2015 Encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMII ON APPLICATION FOR SUNDRY APPRO .5 , 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend 0 Perforate ❑ Other Stimulate 0 Alter Casing 11 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well•lilf Re-enter Susp Well 0 Other ('Ct-rrtr1/ eloA/y 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: , 5. Permit to Drill Number: 203-110 • 3, Address: P.O.Box 196612 Anchorage,AK Exploratory ❑ Development H 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20056-02-00 • 7. If perforating: 8. Well Name and Numb What Regulation or Conservation Order governs well spacing in this pool? �4• 4,. Will planned perforations require a spacing exception? Yes ❑ No ® • PBU D-04B •,,,-. ,- ,f',� ls. 9. Property Designation(Lease Number): 10. Field/Pools: -.U I; 0 :_1;, 2 01':; ADL 0028285• PRUDHOE BAY,PRUDHOE OIL • Dj.5 g/411.5 11. PRESENT WELL CONDITION SUMMARY AOG Cr Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 11900 ' 9039 ' 11694 9047 11694 Casing Length Size MD TVD Burst collapse Structural Conductor See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Surface 2150 16"658 H-40 34-2184 34-2184 0 0 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type• 4-1/2"BOT 3H Perm Packer Packers and SSSV MD(ft)and ND(ft): 6814, 6029 No SSSV Installed No SSSV Installed 12 Attachments: Description Summary of Proposal H 13.Well Class after proposed work: BOP Sketch 0 Detailed Operations Program 0 Exploratory 0 Stratigraphic 0 Development EL • Service 0 14.Estimated Date for Commencing Operations: 15. Well Status after proposed work: Oil El • Gas 0 WDSPL 0 Suspended 0 16.Verbal Approval: Date: WINJ ❑ GINJ 0 WAG 0 Abandoned 0 Commission Representative: Op Shutdown 0 GSTOR 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Worthington,Aras J Email Aras.Worthington@bp.com Printed Name Worthington,Aras J Title Wells Engineer Signature � �o�s Phone +1 907 564 4102 Date COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: 315-970 Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance 0 Other: / Spacing Exception Required? Yes 0 No 13 Subsequent Form Required: / 0 —4 o4- APPROVED BYTHE _ Approved by: COMMISSIONER COMMISSION Date: 9...6_4S In_ E/(1/5 RBDMS AUG 1 4 2015 ,� t -c,c Submit Form and Form 10-403 Revised 5/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate1170 - Ze m L N 0 C CLo 0 CD CO 0 V • 0 0 000008008 N M N LO ti CO N 7 Cr) CC) O V' CO N e- N- t` m N e- CD CO CO N CO I- to CO Cr CCS M O M e- CC) CO CO 00 LC) N O Cr) e- e- N N N- M LO O e- O CO e- • N N N N ti CD CD W CO N CO 0 H LO O CO Cr) CO • e- ctM NNNO N ON- M N M M M N O O e- N CD CD CO N 4.1 a) 1.000 [t vt co e- O 00 e- N co Co co CC) N CM CD a) N N N M 'I' I� CO 0) - O e- CA e- N N N N CO CO CO N CD C.) MM I I I I I I 4a W Q 0 ct M NrN N N O M N. to O r• MolMMMNNCOCOCDMN CD • O 12 = I-• a O O O 0000 O O O as cp ~ ZC?00 www cZ *k N *k CO CCj •� NMN COcoLo � (004e- e- O e- CO CO N N N CN CV U N• N � MO' � ~ I` NC61.61 e- e- t N ti CO co st e- e- N N▪ O Cf) CC) N CA e- N N 0) CC) C N O e- M M C.') CO -- O M e- N- J e- r- N N N CO cr N W W W ww O 00 Q Q Q W w w w -• 00 ° M22 U W W X Z ZOCILLU WWWW Z Z m W W W W W W W m m O 001; 11-- Z_ Z Z Z D D U U (nZ � � � -il- H C3 CO • M N N- O ti a p. N M O c', co M • M O �7 Nr to a• 00000) 0) O. O �- cD c„) f- '- cA CoCo0 'rCO a • rnaoi000i0oirn 0 cc W 0 0 0 co Z W H H OJ a W gg Y " 0 o 0 0 W Y Y 0_ 2 J U Y �O OO O� co Co J J J a s fn W m 0 0 0 0 - - U 0 0 J W W ? O _i00 J m II I 2 0 1_ 0 00 0 W w w Z O Z v▪ m 22 2 Oc) f) NV) fan RS Q 0 0. Q O L O O fn O O O cy CO 00 N- f0 M • Ca 0 CO 0 0 0 L a. m cc mJ I H OI- a J d LL g 2 O fn fn cn cn cn a) a. 0 0 0 c .2 ti cc cc cc cn aawwwa. mQQaaam a 0 0 m 0. m I 0000 � c') > O • O • W z } N N (\I N O W J.I 0 1) N U- TO, ma• rnrnNNvao Z W O UJ 0 W tL O CO CO m 0 :7 D z w J J a O W W a a 0 a m fn LL. LL lL Cr) a cc 0 E l0 Zmmmmmm d' c c m 000000 o.. d a � J O OO W 0 m 00000 a s 03 03 U- nfn0` 1:e bp D-04 OOA x 000A Cement Job Intervention Engineer Aras Worthington (907) 564-4102 Production Engineer Denise Bailey (907) 564-4749 History D-04B was drilled in 2004 and completed with 450' of perforations in Z2A. The cement job went according to plan and liner lap test passed. The well was producing at 51,000 GOR when perforations were added to increase oil rate. The first adperf was done in 06/2007 when 75' of perforations were shot and initial GOR was 18,000 and quickly climbed to 49,000. The second one was done in 09/10 when 60' of perforations were added towards the heel. Initial GOR was 18,000 but three months later it came back to 50,000. Both times the gas rates stayed at -20 mmscfd and it is difficult to say if the oil increase was due to the adperf or it was recharge after several months of shut-in time. After the 9/10 adperf WC decreased from 30% to 0% significantly suggesting that the offtake moved closer to the heel which is -10' TVD higher in the structure. A Prosper model indicated that it was unlikely to be physically capable of producing 20 mmscfd in the 5000' long 2-3/8" liner. A PPROF run in August 2013 indicated all of the oil was flowing from the bottom two perforations & 2/3 of the gas. A CIBP was set to shut off the toe perforation. This improved the performance of the well and it became a full time well until late 2014 when it became a cycle well due to being the v weakest well of the triple (with D-05 & D-30C). In May 2015, a OMIT- OAxOOA and MIT-000A failed with bubbling in the cellar/conductor. Objective This cement job is to repair the 000A x Conductor leak and make this well operable. Cement will be circulated down the OOA, around the 16" "curtain string" and up the 000A. The OOA and 000A will then be fully cemented to surface. Procedural steps Fullbore 1. Pump diesel down the OOA and establish circulation up the 000A. 2. Pump Class G cement down the OOA until good cement returns are achieved from the 000A. DHD 1. Perform diagnostics as necessary to verify that the leak from the 000A to Conductor has been successfully remedied/sealed off. TREE= 6-3/8"CNV WELLI'EAD- ItEVOY D-O 4 B 16"CIRCULATION CASINGNOTE:WELL S _ TING NOT CEMENTS) - ACTUATOR= BAKER C ---.-.-_..--.-__.. , "`BOTTOM 2 VLVS IN COMM NTIAL KB.BJ _ 57.77' I ✓ 1 I BF.E EV= 40.17 1 KOP= 2818' , i gg - Max Angle= 96"_7,, 11877' ' ; Datum MD= 10412' t• i g _ 2030' _15-1/2'OTS ROM SSSV NP,D=4.562" Datum TVD= 8800'SS 1 5-1/2"TBG, 17#,L-80,.0232 bpf,D=4.892" 2169' J"-' , + 2169' -{5-1/T X 3-1/2"XO,D=2.992" 116'CSG,65#,H-40 -I 2199' �_, :%,I TOP OF 7"X 10-3/4"TACK LNR H 2213' SI 1 ,.d. • 10, 20°CSG,133/94#,K-55/H-40 H 2298' 1 111,1 2415' H10-3/4"X 9-5/8'XO,ID=8.681' 10-3/4'CSG,55#,N-80,D=12.615' H 2415' R F' ESTMA 1 d)CEf 47' - 2980'-6968''/ �I x GAS LFT MANDRELS a1," a ST MD TVD`DEV TYPE VLV ILATCHl PORTS DATE FCC j- 4493' F ' 4' 3222 3202 23 FM-10 DMY BK' + 0 jl I /, 13-3/6'CSG,68/61#,NT-80,D=12.415" - 4494' I x 3 5899 5353 r 41 RIC SO BK 20 08/02/13 I 2 6526 5813 r 43 FM-D CMY BK 0 01/22/031 1 6649 5903 M'(42 FMiO OBK 0 01/22/03 'Minimum IQ = .92�" 6882 I j 'NOTE STA 4 LATCH BRA OFF(ALL PARTS RBCOVEREq itt I TOP OF 2-3/8" LINER ; 6739' -13-1/2"OTS XA SLD SLV,0=2.750" J _ 6789' 'BOT G TBG SEAL ASSY 6812' -1 "BOTR(R,D=2750" 6655 -I3-1/2"OTSXNP,D=2.750" 6876' -2.7"BDOYSLV,D=2.0' 6887' -13-1/2'OT1SXD=2.7 }II, x 3-1/2'TBG,9.3#,L-80,.0087 bpf,D I=2.992" H 6920' '� 6920' --13 1/2"WLEG,D BEHIND =2.992" CT LNR A 'A, A 1 6931' -1 EL&v TT LOG xX/XX/Xx'' 7"LNR,26#,L-80,.0382 bpf,D=6.276" --I 6968' —I '4 1 5-1/2"LNR,17#,L-80,.0232 bpf,0=4-892' --I -10360 r MLLOUT WINDOW(0-048) 10350'-10354' PERFORATION SUMMARY r( •i:4 REF LOG:SYVS M3ulORY Crl/GWOCI ON 04/07/04 '44• ANGLE AT TOP FERE 74'@ 10630' •% 4l14Note:!Defer to Production DB for historical perf data , . SEE SPF INTERVAL Opn/Sgz SHOT .O7 ,I`lele",I,I, Nb 1.56" 6 10630-10660 0 09/05/10 4.‘" 1.56" 6 10680-10710 0 09/04/10 ,s� ,4 N 11694'CTM 1-2-3/8"WFT CEP 1-9/16" 6 10775-10800 0 06/22/07 � �+►�1 (08/09/13) 1-9/16" 6 10860-10910 0 06/22/071-11/16" 6 11230-11560 0 04/08/04 1-11/16" 6 11730-11850 C 04/08104 11866' - PBTD I Alpi 2-3/8"LNR,4.7#,L-80,.0039 bpf,13=1.995" - 11900' ' lasso li DATE REV BY COMMENTS DATE REV BY coe uNTS PRLAHOE BAY LNT 07/28/70 INITIAL DRILL® 10/25/101IVEC/AGF GLV CJO(10/13110) WILL: D-048 11/76 RYVO? 06/19/13 MSS/JMJ GLV CORRI T10N(01/13/04) PERMIT No: 2031100 01/04/88 SIDETRACK(D-04A) ;08/27/13 ALMVM7 SET 2-3/8"WFT CEP(08109/13) API Na: 50-029-20056-02 04/08/04 KAK CTD SIDETRACK(D-048) 05/13/15 MJCIJMD SSSV TY R3 COP,RE(TION SEC 23,T11N,R13E, 1800'F1'&.&1067'Fa. 06126/08 CS/PJC PERFORATIONS(06/22107) !05/14/15 CFR/PJC EST CEMENT 9-5/8"X 7" 09107/10'F 4-VSV ADPER S(09/05/10) 05/17/15 RC81 PJC TREE 00 BP Exploration(Alaska) 2 e 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. c1Q'3 - 1 L () Well History File Identifier Page Count from Scanned File: 6 Ó (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: L YES ~ DateS/IO/Oc:' Stage 1 If NO in stage 1, page(s) discrepancies were found: Organizing (done) D Two-sided ""11/111111"1111 RESCAN DIGITAL DATA ~skettes, No. I D Other, No/Type: D Color Items: D Greyscale Items: D Poor Quality Originals: D Other: NOTES: Date '6l0 J ()~ I f BY: ~ Project Proofing BY: ~ Scanning Preparation BY: Date: Production Scanning Stage 1 BY: BY: Maria Date: Scanning is complete at this point unless rescanning is required. D Rescan Needed 1111111111111111111 OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) D Logs of various kinds: D Other:: MP ,;"11111I "1111111 Ü1 P Od--- Isl + d.v~ = TOTAL PAGES (Count does not include cover sheet) Isl 11I111111111/111111 NO YES Isl wtf NO Isl 111111/111111111111 ReScanned BY: Maria Date: Isl Comments about this file: 1111111111111111111 Quality Checked 1111111111111111111 10/6/2005 Well History File Cover Page.doc bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 �. Post Office Box 196612 Anchorage, Alaska 99519 -6612 March 06, 2011 a,03— J' Mr. Tom Maunder CEIVE Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 Ai Ce & ebs Com C:a (a: S$Iof Subject: Corrosion Inhibitor Treatments of GPB D Pad "''�"�s' Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from D Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Jerry Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Date: 03/04/11 Corrosion • Initial top Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # of cement , pumped cement date inhibitor sealant date ft bbls ft na gal D -01 A 1970780 50029200540100 NA N/A NA N/A 1/31/2011 ...000....., D-03A 2001340 50029200570100 NA 14 NA 100.30 1/19/2011 D -04B 2031100 50029200560200 NA 4 NA 56.10 2/19/2011 D -05 1700060 50029200580000 NA 0 NA trace 1/19/2011 D -06A 1970430 50029201480100 NA 0.5 NA 3.40 1/7/2011 D -07B 2051810 50029201620200 NA 0.5 NA 3.40 1/7/2011 D -08A 2021230 50029203720100 NA 0.5 NA 3.40 2/9/2011 D -09A 1990850 50029203810100 NA 0.7 NA 3.40 1/19/2011 0-10 1790530 50029203890000 NA 2.3 NA 8.50 3/2/2011 D -11 B 2100770 50029204350100 NA 3.5 NA 23.80 1/6/2011 D -12 1800150 50029204430000 NA 1.3 . NA 5.10 1/15/2011 D -13A 2000810 50029204490100 NA 0.5 NA 2.55 3/31/2010 D -14A 1961530 50029204500100 NA 0.2 NA 0.85 1/15/2011 D -15A 1972120 50029204610100 NA 0.2 NA 0.85 1/15/2011 • D -16A 2090250 50029206830100 NA 0.1 NA 0.85 2/20/2011 0-17B 2021110 50029206920200 NA 1 NA 3.40 2/19/2011 D -18A 2011030 50029206940100 NA 5.4 NA 34.00 2/20/2011 D -19B 2011120 50029207070200 NA 0.8 NA 3.40 2/19/2011 D -20 1820440 50029207800000 NA 0.5 NA 1.70 2/19/2011 D -21 1820520 50029207880000 NA 0.2 NA 3.40 2/10/2011 D -22C 2081210 50029207370300 NA 0.2 NA 0.85 2/10/2011 D -23A 1961880 50029207380100 NA 13.5 NA 93.50 3/1/2011 D -24 1852990 50029215060000 NA 0.9 NA 6.80 1/8/2011 D -25A 2000240 50029215220100 NA 6 NA 32.30 1/15/2011 D -26B 2060980 50029215300200 NA 0.8 NA 3.40 2/19/2011 0-27A 2051930 50029215430100 NA 0.3 NA 1.70 2/10/2011 D -28B 2090890 50029215560200 NA 0.3 NA 1.70 2/10/2011 0-29 1852530 50029214700000 NA 13.3 NA 27.20 1/16/2011 D -30B 2061840 50029226460200 NA 2.2 NA 13.60 12/25/2010 D-31A 1960950 50029226720100 NA 3.3 NA 27.20 1/19/2011 0-33 _ 1960360 - 50029226520000 NA 2.2 NA 18.70 1/8/2011 STATE OF ALASKA ALAS AND GAS CONSERVATION COMMIS~1 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 ~ Re-enter Suspended Weli ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ^~ Exploratory ^ ~ 203-1100 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number. Anchorage, AK 99519-6612 \ 50-029-20056-02-00 8. Property Designation (Lease Number) : ~ 9. Well Name and Number: ~ ADLO-028285 PBU D-04B 10. Field/Pool(s): ~ PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 11900 feet Plugs (measured) None feet true vertical 9038.92 feet Junk (measured) None feet Effective Depth measured 11865 feet Packer (measured) 6812 true vertical 9042.59 feet (true vertical) 6028 Casing Length Size MD TVD Burst Collapse Conductor 30" SURFACE - 80 SURFACE - 80 Surface 2298 20" 133/94# K-55/H-40 SURFACE - 2298 SURFACE - 2298 2320 1500 Intermediate 2199 16" 65# H-40 SURFACE - 2199 SURFACE - 2199 2630 1020 Liner 4745 7"26# L-80 2213 - 6958 2213 - 6143 7240 5410 Liner 5024 2-3/8"4.7# L-80 6876 - 11900 6078 - 9039 11200 11780 Liner 3392 5-1/2" 17# L-80 6958 - 10350 6143 - 8813 7740 6280 Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 5-1/2" 17# L-80 SURFACE - 2169 .SURFACE - 2169 3-1/2" 9.3# L-80 2171 - 6921 2171 - 6114 Packers and SSSV (type, measured and true vertical depth) 7" BOT PKR 6812 6028 ~~M~ kf~ ~~~;` 12. Stimulation or cement squeeze summary: ;~~t15510ft t Intervals treated (measured): ~ , ,~ ~,' , ,~ Y; ', ~ ~ ~ ~~~ aVtsl Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^ ~ Service ^ Daily Report of Well Operations X 16. Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ 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 Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 9/7/2010 ~~ ...-w~ ~.~.~ ~u ~i~w~ \ lufJlll/~~7 JCr V'~ W~ ~ .~wnm vnyuiai vuiy 5-i3 i® D-04B 203-110 PFRF OTTOC:NMFNT U Sw Name Perf Operation Code Operation Date Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base D-04B PER 4/7/04 11,230. 11,560. 9,044.71 9,046.74 D-04B PER 4/7/04 11,730. 11,850. 9,046.49 9,043.88 D-04B PER 6/22/07 10,775. 10,800. 9,040.3 9,040.73 D-04B PER 6/22/07 10,860. 10,910. 9,041.77 9,043.01 D-04B APF 9/4/10 10,680. 10,710. 9,035.86 9,038.2 D-046 APF 9/5/10 10,630. 10,660. 9,025.11 9,032.32 AB ABANDONED PER PERF APF ADD PFRF 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 • • D-04B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 9/4/2010FCTU #9 w/ 1.5" CT Scope: Add perfs RD at SWS after pipe repair. Road to D Pad. MIRU. Fill CT w/ KCI/drift w/ 1 ~ 1.0" ball. RIH w/ SLB Gr, CCL to 10900. PUH paint flag @ 10800'. cont log to ~ ' 10400 @ 45 fpm. Pooh. Good data 19.5' correction. RIH w/ 30' x 1.56" 6 spf power jet pert qun and perforate 10680-1071,0', POH. RIH w/ 30' x 1.56" 6 [ ;spf power jet pert gun #2 _ 9/5/2010 CTU #9 w/ 1.5" CT Continued from WSR 09-04-10 Scope: Add perfs Continue RIH w/ pert gun #2. Perforate 10630-10660'. _FP wellbore w/ McOH. RDMO to 15-31 **Job Complete** FLUIDS PUMPED BBLS 157 1 % KCL 30 50/50 METH 187 Total TREE = 6" CIW WELLHEAD = McEVOY ACTUATOR.=, • CNV OTIS KB. ELEV = 72' BF. ELEV = 40.12' KOP = 2818' Max Angle = 96° @ 11877' Datum MD = 10412' Datum ND = 8800' SS I o-~~z- i ~V, 1 i~, L-80, .0232 bpf, ID = 4.892" 16" CSG, 65#, H-40 TOP OF 7" X 10-314" TIEBACK LNR 20" CSG, 133194#, K-55tH-40 10-3/4" CSG, 55#, N-80, ID = 12.615" FOC 13-3/8" CSG, 68161#, NT-80, iD = 12.415" SAFETY N~S: 16" CIRCULATION CASING STRING NOT D 04 B CBVIBVT TTOM 2 VLVS IN COMM. MAX OOOA PT ~ =1200 PSi. ORIGINAL WELLBORE NOT SHOWN ON DIAGRAM. 2030' 5-1/2" OTIS ROY SSSV NIP, ID = 4.562" 2169' S-1/2" X 3-112" XO, ID = 2.992" 5' 10-3/4" X 9-5/8" XO, ID = 8.681" ra S i i~r nna tinQA c ST MD ND DEV TYPE VLV LATCH PORT DATE 4* 3228 3202 23 FMHO DMY BK* 0 3 2 5899 6526 5353 5813 41 43 FMHO FMHO SO DMY BK BK 20 0 04/19/04 01/22/03 1 6649 5903 42 FMHO DMY BK 0 01!22103 Minimum ID = 1.920" @ 6882' TOP OF 2-318" LINER 3-112" TBG, 9.3#, L-80, .0087 bpf, ID = 2.992" 7" LNR, 26#, L-80, .0382 bpf, ID = 6.276" PERFORATION SUMMARY REF LOG: SWS MEMORY CNL/GR/CCL ON 04107!04 ANGLE AT TOP PERF: 89° @ 10775' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-9116" 6 10775 - 10800 O 06/22/07 1-9/16" 6 10860 - 10910 O 06/22!07 1-11/16" 6 11230-11560 O 04/08/04 1-11/16" 6 11730 - 11850 O 04/08/04 5-1/2" LNR, 17#, L-80, .0232 bpf, ID = 4.892" I `rvv 1 t ~ 1 A ~ LA 1 cH tSKVKtN VFF (ALL PARTS RECOVER®) 673 3-112" OTIS XA SLD SLV, ID = 2.750" 6789' BOT G TBG SEAL ASSY~ " 6 1 ' - 7 BOT PKR, ID = 2.750' $ 2 " 68 ' " 3-1/2 OT1S X NIP, ID = 2.750 55 , " ' 2.7 6876 BKR DEPLOYMENT SLV, ID = 2.0" 1/2" OTIS X NI 8$87' - 3 - P, ID = 2.75 8920' 3-112" WLEG, ID=2.99 BEHIND CT LNR 6931' ELMD TT LoG xwxwxx? ^: ~ 2-318" LNR, 4.7#, L-80, .0039 bpf, ID = 1.995" ( 11866' I-) PBTD PRUDHOE BAY UNff WELL: D-046 PERMIT No:2031100 API No: 50-029-20056-02 SEC 23, T11 N, R13E, 1800' FNL & 1067' FEL BP Exploration (Alaska) MILLOUT WINDOW 10350' - 10354' ~chlumt~erger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth NO. 5481 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Dace BL Color CD y 03/02/10 0 1 1 _ _ G L G 2/16/10 02/10/10 02/14/10 02/14/10 1 1 1 1 i 1 _ _ 02/24/10 02/11/10 1 1 1 1 1 02/27/10 1 1 1 '~~ ~ 'i-C7~_ 03/01/10 03/06/10 03/05/10 03/05/10 1 1 1 1 1 1 1 _ 02/1 / 1 0 1 10 01/17/10 04!07/04 07/21/07 1 1 1 1 1 1 1 01/31/10 12/19/09 1 2 1 1 „~ ~rN~~~nnvn t„~asKa~ inc. -- Petruteclinical Data Center LR2-1 Alaska Data & Consulting Services 90U E Benson Blvd. 2525 Gambell Street, SuAs 400 Anchorage, AK 99503-2838 (~ Log Description 03/10/10 Well Job p • • .- -~._ MICROFILMED 03/0112008 DO NOT PLACE _' , °~ ~,,, ~,. ANY NEW MATERIAL UNDER THIS PAGE F:~LaserFiche\C~rPgs_Inserts~Microfilm Marker.doc .-- ..".~ -.'.,........~_.. - 09/10/07 Scblumbergøp NO. 4406 Si;I~NNED Sf? 1 B 2007 /' 0 ~ OJ-~B·l¥~ .fJ Ù<Q Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Prudhoe Bay Endicott . CD L D J b# e 0 og I escnptlon uate BL Color 17-14 N/A JEWELRY/SBHP HIiV\.- J~t..[ -IIAf. 08/17/07 1 MPC-10 11767137 MEM INJ PROFILE . }Tl'~ /'"Jr, _(")1<' 08/13/07 1 17-01 11824337 SBHPS/JEWELRY LOG 1'lJ(', -05K 08/15/07 1 P2-30 11686776 PRODUCTION PROFILE 19 ~ - f")O¡.~ 08/25/07 1 L 1-31 11865639 LDL /"1..... ,- .- 08/14/07 1 P2-10 11846804 PRODUCTION PROFILE 19(¡ -1'A,=- 08/17/07 1 17-03A N/A JEWELRY/SBHP I C '.:J- - /JJ 1_ 08/17/07 1 C-26 11824342 LDL IA'Í( - IL./~ 08/22/07 1 15-07C 11594517 SBHP SURVEY .:.:If'I?-.- ol1.q 08/23/07 1 D-04B 11591451 SBHP SURVEY :11"\'7,. - I () 08/24/07 1 P2-24 11865643 PRODUCTION PROFILE 101'11'" - (v-.<K 08/21/07 1 P2-03 11855502 PRODUCTION PROFILE ¡'1,,: - ~t../ 08/19/07 1 09-44 11855501 SBHP/JEWELRY l()¡f'l -I ~ ~ 08/16/07 1 09-23 11824337 SBHP/JEWELRY 1"7f4 - N- 08/16/07 1 2-52/S-41 11846807 PRODUCTION PROFILE 14. - (")q ':l 08/18/07 1 F-08A 11638646 US IT !) ",..q - 0 06/28/07 1 02-16C 11628790 SCMT ~')r-Í\7t5 08/24/07 1 L2-32 11695060 RST Ù~(\.I""'~ -1~"+- ... Ii', 14/~ OS/23/07 1 1 L5-09 11492259 RST ¡CI{")-I!5i.I ~ I<~/':J. 11/11/06 1 1 02-12B 11767132 MCNL ,c)()"'.} -~~Í( .... llÇ~J"'" 06/21/07 1 1 18-09B 11366500 MCNL¡Ä~_ ~.s :It l."'Ç"41C) 1 0/23/06 1 1 G-14A 11485777 MCNL 1'1~ -f'\~'" 'it I.<:'L/!:lA 11/27/06 1 1 05-20B 10942220 MCNL ?:fnu~':'J?¿1 .. 1."\<'/:::1/ 06/26/05 1 1 WI! . PLEASE ACKNOWLEDGE RECEIPT BY SI~~!N~",~~P~P)J~Ir\PNE COpy EACH TO: BP Exploration (Alaska) Inc. ~.w, t ;, ~t· ¡ \ø' II.": ¡\.~l Petrotechnical Data Center lR2-1 !!_, ~.c " _.~ I 900 E. Benson Blvd. Anchorage, Alaska 99508 C;EP 1 1\ /Q07 Alaska Data & Consulting Services 2525 Gambell Street. Suite 400 """',,,,. A"Z.Jl.. '''~'''' ATTN: Beth I Received by: ^---- Date Delivered: "'\ ..... ..... ("n" I. ,011 11 I1UJicn /\laSl\rJ, {Ji, t;~ tJ~J::, _Ji), ,) · STATE OF ALASKA . ALA Ä Oil AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS D D o 1 . Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 8. Property Designation: 72 KB ADLO-028285 11. Present Well Condition Summary: Total Depth Effective Depth Casing Conductor Surface Intermediate Liner Liner Liner Perforation depth: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development P Stratigraphic I?~C"\!"'" Ju, Stimulate D Other;¡ O,'J Waiver D Time Extension D ~ & GlJ$ ! Re-enter Suspended Well D 411" 5. Permit to Drill Number: 203-1100 r Exploratory Service 9. Well Name and Number: ~ ?--~*"~ " ,"" .. 6. API Number: 50-029-20056-02-00 . PBU D-04B . 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool measured 11900 / feet Plugs (measured) None true vertical 9038.92 . feet Junk (measured) None measured 11865 / feet SCANNED JULO 5 2007 true ve rtical 9042.59 / feet Length 80' 2298' 2199' 4745" 5024' 3392' Size 30" 20" 133/94# K-55/H-40 16" 65# H-40 7" 26# L-80 2-3/8" 4.7# L-80 5-1/2" L-80 Measured depth: 11230 - 11850 True Vertical depth: 9044.71 - 9044 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): MD Surface - 80' Surface 2298' Surface - 2199' 2213' - 6958' 6876' - 11900' 6958' - 10350' - - 5-1/2" 17# 3-1/2" 9.3# 7" BOT PKR o o o Treatment descriptions including volumes used and final pressure: 13. Oil-Bbl 404 SHUT IN Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations x Representative Daily Average Production or Injection Data Gas-Me! Water-Bbl Casing Pressure 22874 179 0 o 0 0 15. Well Class after oroposed work: Exploratory Development W 16. Well Status after proposed work: Oil W Gas WAG TVD Surface - 80' Surface - 2298' Surface - 2199' 2213' - 6143' 6078' - 9039' 6143' - 8813' - - L-80 L-80 Burst Collapse 2320 1500 2630 1020 7240 5410 11200 11780 7740 6280 SURFACE - 2169' 2171' - 6921' 6812 o o o RBDMS BFl JUL 082007 Tubing pressure 1297 o Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Gary Preble Signature Form 10-404 Revised 04/2006 WINJ WDSPl Title Data Management Engineer Phone 564-4944 Date 6/26/2007 ð-rt{3 SUbmit~ ~/ . . D-04B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 6/21/2007 Drift/Tag/Mem GR/CCUAdperf. CTU #9. MIRU. MU and RIH with BHA #1 - Drift with 1.75" OD x 12.57' L. Tag TD at 11,843' ctmd. Bottom perf at 11,850'. Sticky bottom. Flag pipe 40' off bottom. POOH. ****Continued on 6/22/07 WSR**** 6/22/2007 Drift/Tag/Mem #9. ***Continued from 6/21/07 from drift run. MU and RIH with BHA #2 - SLB mem GR/CCL logging tools. Log interval 11 ,300' - 10,400' ctmd. Flag pipe at 10,885 & 10,775'. POOH. Tie log in to Sperry MWD dated 4/5/2004. Make + 18' depth shift. MU BHA # 3- SLB 25' 1606PJ TCP and RIH to flag, correct depth to 10920.1' for bottom shot. Drop ball, Perforate interval 1 0885' - 10910' got good indication that guns fired. POOH, all shots fired. MU and RIH BHA # 4 - SLB 25' 1606PJ TCP guns for 2nd perf run. Drop aluminum ball. Guns fired POOH. MU and RIH BHA # 5 - SLB 25' 1606PJ TCP guns for 3rd perf run. Shoot interval 10775' -10,800'. POOH. Pump 90 bbls diesel down backside to assist well POP. At surface - ASF. ***Continued on 6/23/07 WSR*** 6/23/2007 Drift/Tag/Mem GR/CCUAdperf. CTU #9. ***Continued from 6/22/07 WSR*** Perforating complete. Blow reel down with N2. RDMO. Notify Pad operator of well status and ready to POP. ***Job Complete*** Road to shop. Start pipe swap. FLUIDS PUMPED BBLS 27 50/50 METHANOL 90 DIESEL 138 1 % KCL 475 TOTAL e e <963-110 l'3is"~r WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 April 27, 2006 RE: MWD Formation Evaluation Logs D-04B, 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 D-04B: LAS Data & Digital Log Images: 50-029-20056-02 1 CD Rom <:903 -lID Ii ( l~1- 5' /I~l() (p c.,~ t-~ ~~ DATA SUBMITTAL COMPLIANCE REPORT 4/24/2006 Permit to Drill 2031100 Well Name/No. PRUDHOE BAY UNIT D-04B Operator BP EXPLORATION (ALASKA) INC Sf(,.¿ ^ ~AJ), i API No. 50-029-20056-02-00 MD 11900 ~ TVD 9039 /' Completion Date 4/8/2004 ~ Completion Status 1-01L Current Status 1-01L UIC N Mud Log No Samples No Direction~~ ----- . REQUIRED INFORMATION DATA INFORMATION Types Electric or Other Logs Run: SGRC Combined GR & EWR, MGR 1 CCL 1 CNL Well Log Information: (data taken from Logs Portion of Master Well Data Maint Log/ Electr li- Digital Dataset Ty Med/Frmt Number Name ::--- D Asc Directional SUNey ~ C Lis 13636 Gamma Ray W Directional SUNey fiD D J:H7J...1j 12991 Gamma Ray Rpt 12991 LIS Verification Log Neutron 2 Blu Interval .~ OH/ Start Stop CH Received Comments 4123/2004 10272 11900 Open 2/22/2006 Rap NGP 4/23/2004 9875 11878 2/3/2005 GRlROP 9875 11878 2/3/2005 GRlROP 6590 11864 2/3/2005 cnllmem gr/ccl Log Log Run Scale Media No Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments ADDITIONAL INFORMß.!0N Well Cored? ~ Daily History Received? ~ ()/N .~ß Chips Receive~ y /11.1 - Formation Tops Analysis Received? ~ ----~---_. Comments: Compliance Reviewed By: , t / ~ I Date: ;, ~ ~fp ) WELL LOG TRANSMITTAL ;203, 1(0 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 RE: . MWD Formation Evaluation Logs D-04'\B The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: February 17, 2006 1 Z:>lJÔ II Rob I(alish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 D-04A: LAS Data & Digital Log Images: 50-029-20056-02 1 CD Rom ~.. ~~ 15-23A (PTD #2031110) Classified as Problem Well ') Subject: 15-23A (prD #2031110) Classified as Problem Well From: "Reeves, Donald F" <ReevesDf@bp.com> Date: Thu, 09 lun 2005 12:45:50 -0800 To: "Cahalane, Ted WI' <CahalaTW@bp.com>, "Rossberg, R Steven" <RossbeRS@bp.com>, "NSU, ADW Well Operations Supervisor" <NSUADWWellOperationsSupervisor@bp.com>, "GPB, Wells Opt Eng" <GPBWellsOptEng@bp.com>, "AOGCe Jim Regg (E-lnail)" <jim_regg@admin.state.ak.us>, "AOGCC Winton Aubert (E-mail)" <winton_aubert@admin.state.ak.us>, "NSU, ADW WL & Completion Supervisor" <NSUADWWL&CompletionSupervisor@.bp.coln>, "GPB, EOe Specialists" <GPBEOCSpecialists@bp.com>, "GPB, FS3 Area Mgr" <GPBFS3TL@bp.com>, "GPB, FS3 DS Ops Lead" <GPBFS3DSOpsLead@bp.com> cc: "NSU, ADW Well Integrity Engineer" <NSUADWWellIntegrityEngineer@bp.com>, "Winslow,. Jack L." <Lyonsw@bp.COlTI> ) All, Well 15-23A (PTD #2031110) has sustained casing pressure on the IA and has been classified as a Problem well. The TIO pressures on 6/4/05 were 2080/2080/350. The well failed a TIFL on 6/3/05. The plan forward for this well is as follows: 1. DHD: TIFL - FAILED 2. SL: Change out OGL V 3. DHD: Re-TIFL Attached is a wellbore schematic. Please call if you have any questions. «15-23A.pdf» Thanks, Donald Reeves - Filling in for Anna Dube Well Integrity Engineer (907) 659-5102 (907) 659-5100, 1154 pgr Content-Description: 15-23A.pdf 15-23A.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 6/21/2005 8:35 AM 'ELLHEA 0 :::: MCEV OY -- CTLJA TOR::: OTIS ~- 3. ELEV ::-~ 57' ~EV-:;-~:¡; Jp:::: 4074' ax Angle::: 91 @ 11647' :1tum MD = 9782' :Üurn TVD::: 8800' SS 13-3/8" CSG, 68#, L-80, ID::: 12.415" Minimum ID = 3.725" @ 8829' 4..1/2" HES XN NIPPLE I HES EZSV I 19-5/8" CSG, 47#, L-80, ID::: 8.681" I ." LNR, 29#, L-80, .0371 bpf, ID::: 6.184" I PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 96 @ 9928' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2 7/8" 6 9928 - 9953 0 01/22/05 27/8" 6 9970 - 10020 0 01/22/05 27/8" 6 10090 - 10140 0 01/22/05 2-1/2" 4 10330 - 10460 0 07/27/03 2-1/2" 4 10510-10560 0 07/27/03 2-1/2" 4 10610 - 10690 0 07/27/03 2-1/2" 4 10950 - 11030 0 07/27/03 2-1/2" 4 11100-11260 0 07/27/03 2-1/2" 4 11370-11770 0 07/27/03 2-1/2" 4 11820-11870 0 07/27/03 2-1/2" 4 11900 - 11950 0 07/27/03 2-1/2" 4 12030 - 12120 0 07/27/03 ) 1 I SAFETY NOTES: 4-1/2" CHROME TBG. WAIVER CANCELED 02/02/04 ) - -1 4-1/2" HES X NIP, ID = 3.813" I ST MD 4 3200 3 5870 2 7997 1 8696 GAS LIFT MANDRELS DEV TYÆ VLV LATCH 1 KBG--2 DOME BK 35 KBG-2 DOME BK 31 KBG-2 DOME BK 31 CAMCO SO BK PORT DATE 16 09/02/03 16 09/02/03 16 09/02/03 20 07/27/04 TVD 3139 5809 7936 8635 -i 9-5/8" X 7" BKR ZXP LNR TOP PKR, ID = 6.276" I MILLOUT WINDOW 4074' - 4090' 7" X 4-1/2" BKR ZXP PKR, ID::: 4. I PBTD 1-1 12182' 1 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID= 3.958" l--i 12268' DATE REV BY COMMENTS DATE REV BY COMMENTS 12/25/91 ORJGINAL COM PLETION 12/02/04 JLWITLP WAIVER CANCELED 07/29/03 DAC/KK RIG SIDETRACK (15-23A) 01/22/05 JLG/PJC A DÆRFS 09/12/03 CMO/TLP DATUM MD & ÆRF ANGLE 12/25103 TJP/TLP WAIV ER SA FE1Y NOTE 02/04/04 CMO/TLP ÆRF ANGLE CORRECTION 07/27/04 JLJ/TLP GL V C/O PRUDHOE BA Y UNIT WELL: 15-23A ÆRMIT No: 2031110 API No: 50-029-22225-01 SEC 22, T11 N, R14E, 3641.4' FEL & 2937.84' F\ BP Exploration (Alas ka) /Jò '- I () ('0 7r~ o ) ~J ~ ( J~ 01/24/05 Schlumberger NO. 3318 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay ~ /- e 0 og escnption ate ue me rm s ( G-12B 10715391 MCNL 03/21/04 1 ~ 't 5-3SIB .1..0 :? - ¡ CPt 10728396 MCNL 04/03/04 1 (<.. D-04B 10715393 MCNL 04/07/04 1 DS 18-13A 10715395 MCNL 04/16/04 1 5 K-10B 10715402 MCNL 05/16/04 1 DS 02-15A 10715404 MCNL 05/18/04 1 " DS 2-33A 10670016 MCNL OS/23/04 1 ? DS 07 -03A 10715406 MCNL 06/03/04 1 qz DS 07 -29C 10715407 MCNL 06/04/04 1 E-15B 10861913 MCNL 06/05/04 1 .i. DS 18-27C 10715410 MCNL 06/13/04 1 {t E-24B 10861916 MCNL 06/20/04 1 9 DS 18-31 10715413 MCNL 07/05/04 1 0 K-09C 10861920 MCNL 07/16/04 1 if C-17B 10715418 MCNL 08/10/04 1 4 C-39 10715421 MCNL 08/19/04 1 (Prints~ only-Job not complete) WII J b # L D D BI r Color P . t CD ;~):/j j--új-\ d;'!;-Io.( t~-¡-¿ i 9S'-(fi;. 2tJ}- í i?f#l- :?6-t -Ij .J.k""t-~ "1,. It) J;i}1 ('l?J.&1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 /- / Aí3//0.s' I / Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-283 ATTN: Beth Date Delivered: ) ) ¿;)OS-)/O WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Warman ~33 West 701 Avenue, Suite 100 Anchorage, Alaska 99501 February 2,2005 RE: MWD Fornlatiol1 Evaluation Logs: D-04B, AK -MW - 3001826 1 LDWG fonnatted Disc with verification listing. API#: 50-029-20056-02 fFl~qql PLEASE ACKNOWLEDGE RECEIlyr BY SIGNING AND RETURNING A COpy Oli' THE TRANSMITTAL LETTER TO THE ATTENTION OIi': 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 Date: 7-þf5 l ~cLLiff~ .. PBU D-04 & D-13 ) ?Ti) pJf). ~:b-I(O êoO-- 62> f Su~ject: PBU D-04 & D-13. From: John Crisp <john_crisp@admin.state;ak.u~ Date:Fri,290ct200403:33:22-080o.·.: ....... .. . . '.:. t~~ )~~f:R¢ggF9i@L rêgg@adirtìiL:~~~t~·~·~:;H~~;~¡f~~>~:~~~,t~~~lI{!lff.~:~;;"Ú~,~~&~*i.~:~j,~'~~H~$:0;i~:Th~~DfLi:l!f~}l1:~;¿\- Hi Jim, I stopped @ PBU D Pad to check the status of the D Pad problem wells on my way to witness BOP test on 7ES on Z Pad. D-04 is shut in wi SSV closed & freeze protect sign on flow line. The cellar on D-04 is frozen & I could see no oil in cellar. D-13 is producing wi 1500 psi. tubing pressure. IA has 500 psi & if gauge is correct the OA is @ 0 psi. Small amount of oil or freeze protect coming from conductor. D-13 has waiver posted. 11'\ I,.,n ,..,/'\" .. -, STATE OF ALASKA'). ALASKA vJL AND GAS CONSERVATION COM"'¡lvSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: a Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 1800' SNL, 1067' WEL, SEC. 23, T11N, R13E, UM Top of Productive Horizon: 1703' NSL, 1499' EWL, SEC. 13, T11N, R13E, UM Total Depth: 990' NSL, 2145' EWL, SEC. 13, T11N, R13E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- _~?~090 ._. y- ._5959?01___ Zone-.. ASP~_ TPI: x- _ 656?80 _._ y- __ 596275~_ Zone- _ AS~ Total Depth: x- 657242 Y- 5962057 Zone- ASP4 - 18. Directional Survey a Yes 0 No One Other 5. Date Comp., Susp., or Aband. 4/8/2004 6. Date Spudded 4/2/2004 7. Date T. D. Reached 4/4/2004 8. KB Elevation (ft): 72' 9. Plug Back Depth (MD+ TVD) 11865 + 9043 10. Total Depth (MD+ TVD) 11900 + 9039 11. Depth where SSSV set (Nipple) 2030' MD 19. Water depth, if offshore N/A MSL 1b. Well Class: a Development 0 Exploratory o Stratigraphic Test 0 Service 12. Permitto Drill Number 203-110 13. API Number 50- 029-20056-02-00 14. Well Name and Number: PBU D-048 15. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Ft Ft 16. Property Designation: ADL 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: SGRC Combined GR & EWR, MGR / CCL / CNL 22. CASING, LINER AND CEMENTING RECORD ':: ÇA$ING.· ClC, ¡' ,I , , 1'1 ,'" ,.' '1'"'' li'.' ,.., '. " §FTIING [)E~;rH¡!MDI~, :~~T1iiIt'J<?IQEA~~I:WQlllli."Hci>Ü~!:";:, I: i,':!"',,il ':;, I:,", i.J '" "!'I,~",,'/I,,: ~,.':~'" "". .,' I, II I SIZE,I ',,' VV~.:PE~,FT. ""GRÄOE '1:>"IIJOP',IIBoTTOMI!:'l'oPI'III'I, 'BO:rTOM"II,I,'II;IIS'ZI:.I<,',: 'Ii",: ,ii! See Attached Description 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 1.56" Gun Diameter, 6 spf MD TVD MD TVD 11230' . 11560' 9045' - 9047' 11730'-11850' 9046'· 9044' ,"" ,"., '¡."},I" ...·."AI. M. Q,..·.,U.'.,N;1i..,...' '11,'1, ."'," 'I il,:":: II':'" ...' I ·'··.·.1 'I. .' '" Pl:ILl£D' ,', '24(' " : ,.1 I,: ..." .' ", ..". " ' .:",' ,:,'tÓeING !RECOR'O,i " ",'.. I . "I .1. .1. ",' ':'. ,.,,, ,.', I.' .,',., I,' SIZE DEPTH SET (MD) PACKER SET (MD) 5-1/2",17#, L-80 2171' 3-1/2",9.3#, L-80 2171' - 6921' 6813' :~$JIII!"""I:.!.'~šo.F'~§~Y~~;'þEM'$~1:~q~E§Z~;'ETª."i '1'.1" I.' . .', ...... .'..... DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protected with 26 Bbls of MeOH GAs-McF 831 WATER-BBL 109 CHOKE SIZE I GAS-OIL RATIO 1760 4,695 OIL GRAVITY-API (CORR) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (atta Submit core chips; if none, state "none". ""a:.:;:;. 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): April 23, 2004 Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL 4/30/2004 4 TEST PERIOD -+ 344 Flow Tubing Casing Pressure CALCULATED ........ OIL-BBL Press. 220 1 ,018 24-HoUR RA TE7 2 062 None I'Y~ :~:_____l Form 10-407 Revised 12/2003 GAs-McF 4,985 WATER-BBL 654 ORIGINAL CONTINUED ON REVERSE SIDE r 1::1 V· Et'ssary). MAY 1 0 2004 A'aska Oil & Gas Cons. Commission Anchorage IG 'üy .. ~ SFl, MA1 11 ~~ '~.nu~; 28. ) 29. ') FORMATION TESTS GEOLOGIC MARKERS NAME MD TVD Include 'and briefly summarize test results. List inteNals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 23SB 10400' 10465' 8861' 8921' None 22TS 21TS 1 0539' 8978' ,RECEI\/E[) MAY 1 0 2004 .A'lska Oil & Gas Cons. l;tlrm:h¡~~:SIOf¡ Anchorage 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 DS-(J PBU DM04B Well Number 203M110 Permit No. / 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 Thomas McCarty, 564-4378 ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, ObseNation, 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 inteNal). 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 ") ) WELL NAME: D-04B 22. Attachment - Casing, Liner and Cementing Record Casing Setting Depth MD Setting Depth TVD Hole Size Wt. Per Ft. Grade Top Bottom Top Bottom Size Cementing Record 3D" Conductor Surface 80' Surface 80' 150 sx Permafrost 20" 133# /94# K-55 I H-40 Surface 2298' Surface 2298' 26" 4500 sx Permafrost 16" 65# H-40 Surface 2199' Surface 2199' 19-1/2" Uncemented 13-3/8" 68# / 61# K-55 / H-40 Surface 4494' Surface 4258' 17-1/2" 1500 sx Class 'G' 10-3/4" x 9-5/8" 55.5# / 47# N-80 Surface 8740' Surface 7502' 12-1/4" 4995 sx Class 'G' 7" 26# L-80 2213' 6958 2213' 6143' 8-1/2" 680 sx Class 'G' 5-1/2" 17# L-80 6958' 10350' 6143' 8813' 8-1/2" 1150 sx Class 'G' 2-3/8" 4.7# L-80 6876' 11900' 6078' 9039' 2-3/4" x 3" 53 sx Class 'G' Legal Well Name: 0-04 Common Well Name: 0-04 Spud Date: 6/9/1970 Event Name: REENTER+COMPLETE Start: 2/20/2004 End: 4/8/2004 Contractor Name: NORDIC CALISTA Rig Release: 4/8/2004 Rig Name: NORDIC 1 Rig Number: N1 :HoUrs . Task 3/29/2004 00:00 - 02:30 2.50 MOB P PRE Rig released from E-39a at 00:00 hrs, 3/29/2004, Clean cutting box and pits, Prepare to scope derrick down in preparation of moving to D-04a 02:30 - 02:45 0.25 MOB P PRE Safety Meeting (PJSM) on moving rig off E-39 02:45 - 03:00 0.25 MOB P PRE Move off E-39. Conducted Pad Inspection with E-Pad Operator 03:00 - 07:30 4.50 MOB P PRE Travel to D-04a 07:30 - 08:30 1.00 MOB P PRE Spot rig in front of D-04. Place boards and drip liners around cellar. 08:30 - 10:00 1.50 MOB P PRE PJSM. Scope up mast. 10:00 - 11 :30 1.50 MOB N WAIT PRE Wait on Little Red Hot Oil. Tubing pressure is 1,700 psi. Tubing pressure at 17:00 on 3/28/04 was zero. 11 :30 - 12:30 1.00 MOB N WAIT PRE Wait for KCI. 12:30 - 14:00 1.50 MOB N WAIT PRE Bull head 10 bbls MeOH, 290 bbls 2% KCI, 10 bbls MeOH w/ LRS pump truck. RD LRS. 14:00 - 16:00 2.00 MOB P PRE PJSM for moving rig over well. Move rig over D-04. Rig spotted over well at 16:00. Rig accepted at 12:00 PM on 3/29/04. Note: 4 hours backed out for waiting on well kill operations. 16:00-18:15 2.25 BOPSU P PRE ND tree cap. Studs badly rusted. Cut studs off. 18:15 - 20:00 1.75 BOPSU P PRE Remove XO on bottom of BOP. NU BOP. Open IA/OA P = 289/278psi 20:00 - 00:00 4.00 BOPSU P PRE Pressure test BOP. Chuck Shevie w/ AOGCC waved the witnessing of the BOP PT. 250/3500 psi for 5min each. Cir out MEOH in CT to cutting box. Called Grease Crew to service Swab Valve. Service Swab Valve 3/30/2004 00:00 - 03:30 3.50 BOPSU P PRE Finish BOP test. 03:30 - 04: 15 0.75 BOPSU P PRE Check well, P= +-100 psi, Blow down to pit, died, Conducted PJSM on BHA handling on Sperry and BTT tools. 04: 15 - 04:30 0.25 BOPSU P PRE Checked well, small blow. LEL at 90% MU BTT and Sperry's tools on Catwalk. Install 3 Pip Tags in BOT WS 04:30 - 04:50 0.33 BOPSU P PRE RU to fluid pack well bore. Blowed back 5 bbls to pit. Lined out tree and rig valves 04:50 - 05:25 0.58 BOPSU P PRE Fluid packing wellbore w/2%KCL, Q= 6.5bpm, Caught fluid at 40 bbl pumped, Red Qp to 5.6bpm P=1556 psi Vp 184 bbl, SD 05:25 - 06:00 0.58 BOPSU P PRE Monitor well OK, Keeping hole full while PU tool 06:00 - 06:30 0.50 WHIP N DFAL WEXIT PU BOT WS BHA 06:30 - 06:45 0.25 WHIP N DFAL WEXIT PJSM with day crew for PU whipstock BHA. 06:45 - 07:45 1.00 WHIP N DFAL WEXIT Continue making up whipstock BHA. MU whipstock to MWD. Check scribe. MU orienter, MHA. 07:45 - 08:30 0.75 WHIP N DFAL WEXIT RIH to 2,775'. Shallow hole test MWD. MWD not pulsing. Circulate additional 15 bbls to ensure clean KCI in coil. Still not pulsing. 08:30 - 09:00 0.50 WHIP N DFAL WEXIT POOH to change MWD. MWD started pulsing on the way out of the hole. 09:00 - 09:20 0.33 WHIP N DFAL WEXIT RIH to 2,775'. SHT. MWD not pulsing. 09:20 - 09:50 0.50 WHIP N DFAL WEXIT POOH to change pulser. 09:50 - 10:15 0.42 WHIP N DFAL WEXIT Change out pulser. Inspect whipstock. 10:15 - 10:50 0.58 WHIP N DFAL WEXIT RIH. 10:50 - 11 :00 0.17 WHIP N DFAL IWEXIT Shallow hole test at 1 bpm. 11 :00 - 13:00 2.00 WHIP N DFAL WEXIT RIH to 9,900 ft, Correct depths to Top of Whipstock at 9,887 ft 13:00 - 13:54 0.90 WHIP N DFAL WEXIT Tie-in at Sag River from 9,950 ft Qp = 0.94 bpm; Pp =1 ,399psi Printed: 4/12/2004 11 :33:20 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: D-04 D-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 2/20/2004 Rig Release: 4/8/2004 Rig Number: N1 Spud Date: 6/9/1970 End: 4/8/2004 . .- ..",. Code · NPT (-3 ft Correction) Cir 1:1 RI Hand relog at 10,200 ft Confirm Tie-In at 10200 ft (Corrected + 1 ft) Mechanical at 10168 ft Electrical 1 0225 ft RIH to setting depth 10,350' TOW. PU wt = 31k Orient TF 76L, TF 167L, Re-orient TF TF 140 R, both Sperrys machines Set WS using 2.00bp P = 4000 psi Sheared at 2200 psi, Break cir, tool set Pumped up survey, 175R. Could be less than 176R when tool set PU 31k, 150lbs lighter RIH tagged wi 1500 Ibs, POOH with BOT Setting tool. No overpull off bottom or at tailpipe or X nipples. Clean trip out of hole. LD Backer setting tool. All pins sheared. No marks on tool. MIU cementing BHA with big hole nozzle for pumping cement past whipstock. PIT CTC and check welded connecter for wear. OK. BHA = 8.0 ft. RIH with cementing stinger BHA. RIH past packer at 6812' and upper X nipple at 6855'. Stack full weight on lower X nipple at 6887', [ 6880' CTD]. RIH and stack full wt 3 times. Pull up above packer with no overpull at packer or upper X nipple. DPRB WEXIT Increase pump to 2.8 bpm, RIH, stack wt at 6880'. No increase in pump press. Work up and down several times jetting with down jet nozzle. 5-10K overpulll. Stacking full wt. Broke thru. Pushing something downhole. Stop 10ft deeper at 6890' CTD. Talk to office engineer. Decide to try to push fish to bottom. RIH and stack full wt on fish at 6890'. Circ at 2.8 bpm, 5-10K overpulls, Clean pick up thru upper X nipple and Packer. Continue to work on fish with 2.0" nozzle BHA. No progress. DPRB WEXIT Close choke, bullhead at 3.0 bpm, 2100 psi, RIH while bull heading and did not see fish. continue to bullhead at 3 bpm and RIH at 80 fpm. DFAL WEXIT RIH with cementing nozzle BHA while bullheading at 3.0 bpm, 2100 psi. RIH at 80 fpm, No indication of fish or debris. RIH past whipstock depth of 10,350' with no weight loss. RIH and set down 2000# at 10,620 ft. Pick up free. Whipstock is not in place. Top of fish now at 10,620'. DFAL WEXIT Pull up above tailpipe and packer at 6812' to ensure no debris above BHA. No overpulls or any indication of debris around tailpipe or jewelry. Talk to office engineer and decide to pump 17 PPG Cement for cement whipstock. Order 17 PPG Cement for Cement whipstock. 23 bbls. 2 Baker whipstocks left in hole. Top of second whipstock at 10,620'. DFAL WEXIT Wait on 17 PPG Cement and DS UCA cement testing. Pull cementing BHA above tailpipe up to 6700', RIH to 10600'. Top of fish at 10,620'. No Debris seen in 5-1/2" liner. DFAL WEXIT Pull up above tailpipe and packer again. RIH to 10600'. Liner appears clean. Whipstock appears to be setting with top at 10,620'. Pull to 6700', no overpulls. RIH thru 7" liner and into 3/30/2004 13:00 - 13:54 0.90 WHIP N DFAL WEXIT 13:54 - 14:00 0.10 WHIP N DFAL WEXIT 14:00 - 14:12 0.20 WHIP N DFAL WEXIT 14:12 -14:18 0.10 WHIP N DFAL WEXIT 14:18 - 14:50 0.53 WHIP N DFAL WEXIT 14:50 - 15:00 0.17 WHIP N DFAL WEXIT 15:00 - 17:00 2.00 WHIP N DFAL WEXIT 17:00 - 18:00 1.00 WHIP N DFAL WEXIT 18:00 - 19:15 1.25 ZONISO N DFAL WEXIT 19:15-20:45 1.50 WHIP N DFAL WEXIT 20:45 - 21 :40 0.92 WHIP N 21 :40 - 22:00 0.33 WHIP N 22:00 - 23:00 1.00 WHIP N 23:00 - 00:00 1.00 STWHIP N 3/31/2004 00:00 - 01 :00 1.00 WHIP N 01 :00 - 02:00 1.00 WHIP N Printed: 4/12/2004 11 :33:20 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 0-04 0-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 2/20/2004 Rig Release: 4/8/2004 Rig Number: N1 Spud Date: 6/9/1970 End: 4/8/2004 5-1/2" liner to 7000', clean. Wait on cement delivery and UCA sample testing. DS has cement sample in UCA, Wait on sample test before pumping cement. SAFETY MEETING. Review procedure, hazards and mitigation for pumping cement. Circ. 40 bbls 2% KCL water as pre-flush for 5-1/2" liner. 2.5 bpm, 3700 psi, full returns. Press test cement line. OK. Stage 5 bbls water. Stage 23 bbl, 17.0 PPG, G Cement, 1.5 bpm, 3000 psi, 17.3 ppg in density, Full returns. Stop pump at 23.1 bbls, Clean cement line. Displace cement with 2# Siozan water using rig pump, 2.1 bpm, 2700 psi. Lay in cement from 10,610' - 10,430', one for one, at 1.61 bpm, pull at 70 fpm, Up Wt = 42K, Lay in Close choke at 10,430' [above perfs] and squeeze cement away to 1000 psi, 2.5 bbls squeezed, lay in at 1000 psi using adjustable choke, one for one in 5-1/2" liner, full returns. 1.65 bpm, 70 fpm, Top of cement left at 9750'. Pull to safety at 9300', pull slow with minimum pump. Wait for cement to settle for 30 minutes, before cleaning out to 10,250 ft. RIH and cleanout cemen, RIH at 25 fpm, 2.1 bpm, 1700 psi, Found top of cement at 9800 ft. cleanout cement to 10,250 ft. POH. Make three passes thru 7". Continue to POH. Trap 500 psi wellhead pressure. Flush BOP stack. Blow back reel and prepare to cut 100' coil. Cut coil. Install coil connector, Pull test to 30k and PT to 3500 psi. wac. PU dummy window milling BHA and RIH to 3500' to verify BHA wouldn't hang on EUE 8rd collars. NO Problem. LD dummy window mill and PU cement pilot BHA. DS cement sample in UCA had 4000 psi compressive strength at 1500 hrs, 9 hrs in UCA. RIH to 10190 Tie in (correction + 10'). RI H tag at 10272'. Up wt 35K, Dn Wt 15K, Drill cement 1.9 bpm at 3650 psi, TF = 0 deg, high side. Drill with 1000# was, 200 psi motor work and steady 50 FPH. Drilled to 10,300 ft. Cement drilling to easy. WAIT WEXIT Wait on cement for 2 hours and see if it drills slower. WEXIT Drilling 2.74" high side pilot hole in cement. Cement is harder. 3300-3650 psi, 1.8 bpm, 20L TF, 1500-2000# WOB, 35-40 FPH. Drilled to 10,344'. WEXIT Orient TF to 160R. WEXIT Drilllowside ramp for window. 3300-3500 psi, 1.8 bpm, 146R TF, 1200-2000 WOB, 40 FPH, Drilled to 10,350' WEXIT Pump 30 bbl high viscosity sweep and POH for window milling 3/31 /2004 01 :00 - 02:00 1.00 WHIP N DFAL WEXIT 02:00 - 04:00 2.00 STWHIP N DFAL WEXIT 04:00 - 04: 15 0.25 STWHIP N DFAL WEXIT 04: 15 - 04:45 0.50 STWHIP N DFAL WEXIT 04:45 - 05:05 0.33 STWHIP N DFAL WEXIT 05:05 - 05:50 0.75 STWHIP N DFAL WEXIT 05:50 - 06:20 0.50 STWHIP N DFAL WEXIT 06:20 - 06:50 0.50 STWHIP N DFAL WEXIT 06:50 - 09:00 2.17 STWHIP N DFAL WEXIT 09:00 - 09:30 0.50 STWHIP N DFAL WEXIT 09:30 - 10:15 0.75 STWHIP N DFAL WEXIT 10: 15 - 11 :00 0.75 STWHIP N DFAL WEXIT 11 :00 - 12:30 1.50 STWHIP N DFAL WEXIT 12:30 - 14:15 1.75 STWHIP N DFAL WEXIT 14:15 - 15:30 1.25 STWHI P N DFAL WEXIT 15:30 - 17:30 2.00 STWHIP P WEXIT 17:30 - 17:50 0.33 STWHIP P WEXIT 17:50 - 18:40 0.83 STWHIP P WEXIT 18:40 - 21 :00 21 :00 - 22:10 2.33 STWHIP N 1.17 STWHIP P 22: 1 0 - 22:40 22:40 - 22:50 0.50 STWHIP P 0.17 STWHIP P 22:50 - 00:00 1.17 STWHIP P Descri ptiOrl:QfÖperåtions . .... Printed: 4/12/2004 11 :33:20 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 0-04 0-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 2/20/2004 Rig Release: 4/8/2004 Rig Number: N1 Spud Date: 6/9/1970 End: 4/8/2004 Hours· DesÖriptiônof()þeräti6ns: ' 3/31/2004 22:50 - 00:00 1.17 STWHIP P 4/1/2004 00:00 - 01 :20 1.33 STWHIP P 01 :20 - 01 :30 0.17 STWHIP P 01 :30 - 02:15 0.75 STWHIP P WEXIT WEXIT WEXIT WEXIT 02:15 - 04:10 1.92 STWHIP P 04: 10 - 04:45 0.58 STWHIP P 04:45 - 05:00 0.25 STWHIP P 05:00 - 05:20 0.33 STWHIP P 05:20 - 06:00 0.67 STWHIP P 06:00 - 13:30 7.50 STWHIP P 13:30 - 14:30 1.00 STWHIP P 14:30 - 16: 15 1.75 STWHIP P 16:15 - 19:30 3.25 STWHIP P 19:30 - 19:50 0.33 STWHIP P 19:50 - 20:00 0.17 STWHIP P 20:00 - 21 :00 1.00 STWHIP P WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT 21 :00 - 22:30 1.50 STWHIP P WEXIT 22:30 - 00:00 1.50 STWHIP P WEXIT 4/2/2004 00:00 - 02:10 2.17 STWHIP P WEXIT 02:10 - 02:20 0.17 STWHIP P WEXIT 02:20 - 03: 10 0.83 STWHIP P WEXIT 03:10 - 04:55 1.75 STWHIP P WEXIT 04:55 - 05:05 0.17 STWHIP P WEXIT 05:05 - 08:00 2.92 STWHIP P WEXIT 08:00 - 10:00 2.00 STWHIP P WEXIT BHA. POH with 2.74" pilot hole milling BHA. 1.7 bpm, 2600 psi. SAFETY MEETING. Review procedure, hazards and mitigation for C/O motor and mill. UO 1.75 deg motor and diamond mill. M/U 2.5 deg WF fixed bend motor and 2.74" HC diamond window mill. BHA = 61.56 ft. RIH with BHA #4, 2.5 deg motor and 2.74" HC window mill. Shallow hole test Sperry tools. OK. RIH. Stop at 9950', log down with GR and tie-in, Added 7' CTD. Orient TF to 140R. RIH with no pump. Tag TD at 10,351 '. Pick up 2 ft. Pump at 1.8 bpm. RIH and tag TD at 10,350 ft. Flag CT. Pick up 1 ft to 10,349.0 ft and start time milling procedure. Milling lowside window off of cement whipstock. 1.8 bpm, 2950 psi, 150R TF, Mill as per procedure. Mill in accordance with milling schedule as outlined in the cement whipstock RP. Milling 1.7 bpm, 3120 psi, 2950 psi FS, Up Wt 36K, Dn Wt 13K. Mill from 10349 to 10344.5. Stacking Attempt to mill. Stacking unable to make progress. Decided to POH to look at mill. POH. Mill in good shape. Swirlled scratch marks on bit box. Look like bit box was rotating against window. RIH with new mill and 2.5 deg WF motor. Log tie-in with GR at 9950'. Added 11 ft to CTD. Orient TF to 140R. RIH and tag TD at 10,354'. RIH thru 4 ft of window with no problem. Milling window with 2.74" HC diamond window mill and 2.5 deg WF motor. 1.7 bpm, 3200 psi, 150R TF, 4700# WOB. Exit window at 10,355 ft. Start milling formation. Top of window at 10,350'. Bottom of window at 10,355'. Milling formation. 1.7 bpm, 3350 psi, 160R TF, 4-5K WOB, slow Rap. Milled to 10358 ft. Milling formation. 1.7 bpm, 3350 psi, 170R TF, 4-5K WOB, 4 FPH, Milled to 10,6365 ft. 10ft of formation. Circulated 30 bbl high viscosity sweep. Back ream up thru top of window clean, RIH clean and back ream window area a second time, clean. Window looks good. POH with window milling BHA. 1.7 bpm, 3400 psi. SAFETY MEETING. Review procedure, hazards and mitigation for cIa motor and mill. UO 2.5 deg motor and window mill. M/U 2.73" CTC WF Taper mill and 1.75 deg WF motor, check orienter, OK. BHA = 62.27'. RIH with BHA #6, WF CTC 2.73" Taper mill and 1.75 deg motor to dress window. Orient TF to 160R. RIH with Taper mill. Stall 3 times at bottom of window at 10,354 ft. Ream past bottom of window OK. Ream to TD of 10,365'. Backream at 145R. Swap well to reconditioned FloPro while reaming window. Back ream at 180R, 145L and dry tag. No problem. POH Printed: 4/12/2004 11 :33:20 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 0-04 0-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 2/20/2004 Rig Release: 4/8/2004 Rig Number: N1 Spud Date: 6/9/1970 End: 4/8/2004 4/2/2004 10:00 - 10:30 0.50 DRILL P PROD1 LD Crayola mill BHA and PU 2.3 motor HCC bicenter bit. 10:30 - 12:50 2.33 DRILL P PROD1 RIH tag 10358 correct +7'. 12:50 - 13:15 0.42 DRILL P PROD1 Orient 13:15 - 14:10 0.92 DRILL P PROD1 Directionally drill Build section in Zone 2. 1.6 bpm, 3780 psi.,3590 psi = FS, TF 75R, Rap 20+ fph, PVT 302 bbls, Drill to 1 0389'. 14:10 - 14:15 0.08 DRILL P PROD1 Orient 1 click. 90R. 14:15 - 14:45 0.50 DRILL P PROD1 Directionally drill 1.6 bpm, 3730 psi.,3590 psi = FS, TF 90R, Rap 20+ fph, PVT 299 bbls. Drill to 10399'. 14:45 - 14:50 0.08 DRILL P PROD1 Orient. 170 R 14:50 - 16:30 1.67 DRILL P PROD1 Directionally drill 1.6 bpm, 3800 psi.,3590 psi = FS, TF 105R, Rap 40+ fph, PVT 299 bbls WOB 1.1 K. Drill to 10437'. 16:30 - 19:25 2.92 DRILL P PROD1 Continue to Drill Build section, 1.7 bpm, 3740 psi.,3590 psi = FS, TF 40R, Rap 20-40 fph, PVT 298 bbls, WOB 1.1 K. Drilled to 10,500'. 19:25 - 19:35 0.17 DRILL P PROD1 Wiper trip to window, clean hole. 27K Up Wt, 13K Down Wt. RIH. Clean hole. 19:35 - 21 :00 1.42 DRILL P PROD1 Drilling Build Section. 1.7 bpm, 3630-4000 psi, 70R, 60 FPH, 50 deg incl, Drilled to 10,570'. 21 :00 - 21 :30 0.50 DRILL P PROD1 Orient TF to 20L. Orienter working great, click for click in 35 deg. DLS hole. 21 :30 - 22:25 0.92 DRILL P PROD1 Drilling Build Section. 1.75 bpm, 3630-4200 psi, 20L, 100 FPH, 70 deg incl, Drilled to 10,640'. 22:25 - 22:45 0.33 DRILL P PROD1 Wiper trip to window, clean hole. 28K Up Wt, 13K Down Wt. RIH. Clean hole. 22:45 - 23:00 0.25 DRILL P PROD1 Orient TF to 60L. 23:00 - 00:00 1.00 DRILL P PROD1 Drilling Build Section. 1.6 bpm, 3530-4000 psi, 50L, 80 FPH, 84 deg incl, Drilled to 10,690'. 4/3/2004 00:00 - 00: 15 0.25 DRILL P PROD1 Drilling build section in Zone 2. 1.6 bpm, 3600-4000 psi, 50L, 80 FPH, Drilled to 10,700'. 00:15 - 02:45 2.50 DRILL P PROD1 POH for Lateral BHA. Pull thru window clean. Wash up and down in 7" liner two times. No overpull in 7". POH. Circ. at full rate while POH to surface. Did see additional cuttings on shaker with BHA at surface. 02:45 - 03:00 0.25 DRILL P PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for C/O BHA. 03:00 - 04:20 1.33 DRILL P PROD1 C/O BKR MHA, Press test CTC, C/O Sperry MWD probe, check orienter, adjust motor to 1.0 deg bend, C/O Bit. 04:20 - 06: 10 1.83 DRILL P PROD1 RIH with BHA #8, Lateral MWD BHA with 1.1 deg motor and re-conditioned HC 2.7 x 3.0" bi-center Bit #6. SHT Sperry tools and orienter. RIH. Ordered New FloPro for Lateral section. 06:10 - 06:40 0.50 DRILL P PROD1 Log GR tie-in at 9951'. Correction +8'. 06:40 - 07:00 0.33 DRILL P PROD1 RIH and tag at 10700' 07:00 - 07:05 0.08 DRILL P PROD1 Orient. 07:05 - 10:20 3.25 DRILL P PROD1 Directionally drill at 1.56 bpm @ 3670 psi, 500 WOB, TF 81 R, Rap 70, Drill to 10858'. Swap to new mud. 10:20 - 10:55 0.58 DRILL P PROD1 Wiper to window no problems. 10:55 - 12:40 1.75 DRILL P PROD1 Directionally drill at 1.7 bpm @ 3540 psi, 3200 FS 1300 WOB, TF122L, Rap 150'+, Drill to 10940. Having trouble building. Change TF60L continue to drill at 1.73650 psi. Drill to 11000'. PVT 312 bbls 12:40 - 15:00 2.33 DRILL P PROD1 Wiper to tail pipe. POH at max pump rate (.3 bpm thru window Printed: 4/12/2004 11:33:20 AM ) Legal Well Name: 0-04 Common Well Name: 0-04 Spud Date: 6/9/1970 Event Name: REENTER+COMPLETE Start: 2/20/2004 End: 4/8/2004 Contractor Name: NORDIC CALISTA Rig Release: 4/8/2004 Rig Name: NORDIC 1 Rig Number: N1 . .·[)esöriptiohöf Oþerations·· 4/3/2004 12:40 - 15:00 2.33 DRILL P PROD1 and cement ramp). RIH 1.7 bpm, except thru window. Tag at 11,000'. No additional recovery noted at bottoms up. PVT 310 bbls. 15:00-15:15 0.25 DRILL P PROD1 Orient.20R. Seen evidence of HOT staining in 10,900' sample. Drill to 11020'. Orient 90R. 15: 15 - 16:25 1.17 DRILL P PROD1 Directionally drill to 11083 ,Orient 75R. 16:25 - 16:33 0.13 DRILL P PROD1 Directionally drill 1.8/1.8 @ 3600 psi. 1.3K WOB, Drill to 11,123.' 16:33 - 16:55 0.37 DRILL P PROD1 Orient to 45L 16:55 - 17:00 0.08 DRILL P PROD1 Directionally drill 1.8/1.8 @ 3600 psi. 1.4 K WOB, Drill to 11 ,150'. 17:00-18:10 1.17 DRILL P PROD1 Wiper to window. Clean hole. RIH clean. 18:10 - 18:55 0.75 DRILL P PROD1 Drilling Lateral in Z2. 1.7/1.7 bpm, 3300 - 3800 psi, 19R, 88 deg incl, Drilled to 11,190'. 18:55 - 19:35 0.67 DRILL P PROD1 Orient TF to 140L, only getting 10 deg clicks. 19:35 - 20:15 0.67 DRILL P PROD1 Drilling Lateral in Z2. 1.7 / 1.7 bpm, 3300 - 3800 psi, 140L, 92 deg incl, Getting a lot of reactive torque, TF changing 90 deg. Drilled to 11,206'. 20: 15 - 22:00 1.75 DRILL P PROD1 Drilling Lateral in Z2. 1.8/ 1.8 bpm, 3400 - 3900 psi, 50L, 92 deg incl, Drill with very light WOB to get consistant TF at 80L. 20 FPH with low wt. 120 fph with normal WOB. Drilled to 11,261'. 22:00 - 23: 10 1.17 DRILL P PROD1 Orient around to 100L. Only getting 10 deg clicks. 23: 10 - 00:00 0.83 DRILL P PROD1 Drilling Lateral in Z2. 1.7/1.7 bpm, 3400 - 3900 psi, 100L, 92 deg incl, Getting 90 deg. reactive torque again. Drilled to 11280'. 4/4/2004 00:00 - 00:40 0.67 DRILL P PROD1 Drilling Lateral in Zone 2, 1.7/1.7 bpm, 3400-3900 psi, 100L, 92 deg incl, 50 fph, Drilled to 11,300'. 00:40 - 03:30 2.83 DRILL P PROD1 Wiper tip to tailpipe, Clean hole, clean window, jet 7" liner, no indication of fill. RIH. Lost one hour for spring day light savings 03:30 - 04:00 0.50 DRILL P PROD1 Log GR tie-in at 9951 ft, added 18 ft to CTD. 04:00 - 04:20 0.33 DRILL P PROD1 RIH to TD. Clean hole to TD. Tagged TD at 11,310'. 04:20 - 04:40 0.33 DRILL P PROD1 Drilling Lateral in Zone 2, 1.7/1.7 bpm, 3500-4000 psi, 90L, 92 deg incl, 50 fph, Drilled to 11,332'. 04:40 - 05:30 0.83 DRILL P PROD1 Orient around to 11 OL. Slow due to 10 deg clicks. Not getting all clicks. Did not get last 20 clicks. 05:30 - 07:30 2.00 DRILL P PROD1 POH for failed orienter. 07:30 - 08:30 1.00 DRILL P PROD1 Change out orienter and bit. Bit was ringed on pilot, called trip a bit trip, would not have been able to drill much further, Dial motor up to 1.3 degree. 08:30 - 10:30 2.00 DRILL P PROD1 RIH. Tag top of liner once. RIH to 9,950'. 10:30 - 10:50 0.33 DRILL P PROD1 Tie-in log correction +4'. 10:50 - 11 :20 0.50 DRILL P PROD1 RIH tag at 11333'. 11 :20 - 11 :45 0.42 DRILL P PROD1 Orient 120L. Getting 20 degree per click. 11 :45 - 12:30 0.75 DRILL P PROD1 Drilling at 1.6/ 1.6 bpm at 3800 psi, FS= 3400psi, 2.4K WOB, TF= 93L, 150 Rap, drill to 11435' 12:30 - 12:40 0.17 DRILL P PROD1 Orient 1 click. 12:40 - 12:50 0.17 DRILL P PROD1 Directionally drill with 1.6/ 1.6 bpm, @ 3780 psi, FS = 2520 4k WOB, 150+ ROP, Up Wt 29K, Dn Wt 14K,. Drill to 11480'. 12:50 - 14:20 1.50 DRILL P PROD1 Wiper to window. Start new mud. Short trip 100'. With new mud at bit POH to window. Clean trip no overpulls or set-downs. Printed: 4/12/2004 11 :33:20 AM ) ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 0-04 0-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 2/20/2004 Rig Release: 4/8/2004 Rig Number: N1 Spud Date: 6/9/1970 End: 4/8/2004 4/4/2004 14:20 - 14:45 0.42 DRILL P PROD1 Orient. 14:45 - 15:30 0.75 DRILL P PROD1 Directionally drill with 1.7/1.7 bpm, @ 3340 psi, FS = 3170 1.6k WOB, 150+ Rap, Up Wt 29K, Dn Wt 14K,. Drill to 11635'. 15:30 - 17:00 1.50 DRILL P PROD1 Wiper to window. Clean trip. 1.8 BPM at 3725 psi. Pump up sample 11.550 & 11600.' Tag at 11635. 17:00 - 17:35 0.58 DRILL P PROD1 Orient. Drill to 11670. Orient 110 L. 17:35 - 17:50 0.25 DRILL P PROD1 Directionally drill with 1.7/1.7 bpm,@ 3660 psi, FS = 3170 3k WOB, 150+ Rap, Up Wt 29K, Dn Wt 14K,. Drill to 11729'. 17:50 - 17:55 0.08 DRILL P PROD1 Orient 1 click. 65L 17:55 - 18:20 0.42 DRILL P PROD1 Directionally drill with 1.7/1.7 bpm, @ 3600 psi, FS = 3170 4k WOB, 150+ Rap, Up Wt 29K, Dn Wt 14K, Rap 150+, Drilled to 11,763'. 18:20 - 18:40 0.33 DRILL P PROD1 Orient to 90L 18:40 - 18:50 0.17 DRILL P PROD1 Drilling Lateral in Zone 2. 1.7 11.7 bpm, 3420-3800 psi, 90L, 91 deg Incl, 150 fph, 2000# WOB, Drilled to 11,800'. 18:50 - 19:55 1.08 DRILL P PROD1 Wiper trip to 9950'. Clean hole. 28K up wt at window. 19:55 - 20:15 0.33 DRILL P PROD1 Log GR tie-in at 9951'. Added 11 ft to CTD. 20:15-21:15 1.00 DRILL P PROD1 RIH. Clean trip to bottom. Tagged bottom at 11807'. 21 :15 - 22:45 1.50 DRILL P PROD1 Drilling Lateral in Zone 2. 1.7 11.7 bpm, 3420-3800 psi, 90R, 95 deg Incl, 100 fph, 2000# WOB, Drilled to TD of 11,900'. 22:45 - 00:00 1.25 DRILL P PROD1 Wiper trip to window. Clean hole. 28K at window. Pull up to 9950 ft for final Tie-in with GR. 4/5/2004 00:00 - 00: 15 0.25 DRILL P PROD1 Log final GR tie-in at 9951 ft. Added 7 ft to CTD. 00:15 - 01:10 0.92 DRILL P PROD1 RIH. Went thru window clean. RIH to TO clean. Dwn wt = 13.5 K at 11850'. Tagged Final TD at 11,900 ft. 01:10 - 04:45 3.58 DRILL P PROD1 POH to run 2-3/8" liner. Hole in good condition to run liner. Jet 7" liner from 6970-6920' at max rate. Work bit up and down 2 times in this interval to clean 7" liner. No indication of fill in 7" liner. Continue to POH. Flag CT at 6800' EOP and 5200' EOP for depth control while RIH with liner. POH to surface at 80% with pump rate of 1.7 bpm, to chase any solids out of hole. 04:45 - 05:45 1.00 DRILL P PROD1 UO MWD BHA. Recover 100% of BHA. 05:45 - 06:15 0.50 CASE P CaMP Cut off Kendall CT connecter. Weld on SWS CT Connecter using GBR welder. Pull test with 35K, and press test CTC with 3500 psi. 06:15 - 07:30 1.25 CASE P CaMP Insert dart [0.94" aD] and circ to drift coil and CTC. 07:30 - 08:30 1.00 CASE P CaMP Prep floor for running 2-3/8" liner. 08:30 - 08:45 0.25 CASE P CaMP PJSM 08:45 - 17:50 9.08 CASE P CaMP Run 2-3/8, L-80, STL, liner. Drift each STL connection after MIU with 1.90" drift. All connections drifted fine, no tight connections. Run 160 jts, 2-3/8", 4.7#, L-80, STL solid liner with Baker float and deployment equipment. Drifting added about 3 hours. 17:50 - 18:20 0.50 CASE P CaMP Circ Dart again thru coil to check drift 1 capacity. Dart on seat at 39.4 bbls. 18:20 - 18:40 0.33 CASE P COMP MIU BKR CTLRT. MIU injecter head. BHA total length = 5029 ft. 18:40 - 19:45 1.08 CASE P CaMP RIH with 2-3/8" liner on CT. RIH at 100 fpm, 0.2 bpm, 1800 psi. Stop at flag at 5200' EOP. Correct -10 ft CTD. Up wt above window was 37K. 19:45 - 20:20 0.58 CASE P CaMP Run thru window with no wt loss, RIH at 50 fpm, 18K down wt, Printed: 4/12/2004 11 :33:20 AM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 0-04 0-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 2/20/2004 Rig Release: 4/8/2004 Rig Number: N1 Spud Date: 6/9/1970 End: 4/8/2004 NPT 4/5/2004 19:45 - 20:20 0.58 CASE P CaMP 20:20 - 20:50 0.50 CASE P COMP 20:50 - 00:00 3.17 CASE P CaMP 4/6/2004 00:00 - 00: 15 0.25 CEMT P COMP 00: 15 - 00:50 0.58 CEMT P CaMP 00:50 - 01 :50 1.00 CEMT P CaMP 01 :50 - 03:10 1.33 CEMT P CaMP 03:10- 03:45 0.58 CEMT P CaMP 03:45 - 10:00 6.25 CEMT I P CaMP 10:00 - 10:15 10:15 - 10:30 .COMP COMP 0.25 CEMT P 0.25 CEMT P I I 0.3 bpm, 1700 psi, RIH clean to TD. Tag TD at 11,882' CTD. Pick up and tag 5 times at the same depth. Corrected TD is 11,900 ft. Liner is on bottom. 41 K up wt. PBTD [top of latch collar is at 11,865 ft. Insert 5/8" steel ball and displace with FloPro. 1.8 bpm, 3563 psi, Slow pump to 0.4 bpm at 28 bbls. Ball on seat at 29.7 bbls, sheared at 3600 psi, Pick up free at 20K, CT is free from liner. Top of liner deployment sleeve is at 6,875 ft, inside 3-1/2" tailpipe. Circ. well to 2% KCL water with friction reducer [double slick]. Clean rig pits. Rig up SWS cementing equipment. Circ. at 2.2 bpm, 1950 psi, full returns. Slow pump to .75 bpm at 400 psi while waiting for with Slick KCL water to surface. 2.0 bpm = 1850 psi. Mix 30 bbls of 1.5 PPB Biozan water in pill pit to displace cement. SAFETY MEETING. Review procedure, hazards and mitigation for pumping liner cement job. Press test cement line. Prep to pump cement. Cement at weight at 00:30 hrs. Stage 11.0 bbls, 15.8 PPG, G Cement with Latex, 1.8 bpm, 2800 psi. Isolate cement pump. Purge cement line with Biozan water. Insert Baker Dart in coil. Zero in/out totalizers, Displace dart/cement with 1.5 PPB Biozan water. 2.1 bpm, 3750 psi, full returns, 10 bbls displacement, 2.2 bpm, 3100 psi, full returns, 30 bbls displacement, CT capacity = 39.4 bbls, Slow pump to 1.5 bpm, 1.5 bpm, 850 psi, full returns, Ball on seat at 39.6 bbls, Sheared at 2900 psi. 2.1 bpm, 2000 psi, full returns, Zero out totalizer at 47.9 bbls displacement [cmt at shoe]. 2.1 bpm, 2400 psi, full returns, 50 bbls displacement, slight loss of returns, 0.2 bpm, slow pump 1.6 bpm, 2500 psi, full returns, 54 bbls displ, 1.6 bpm, 2540 psi, full returns, 57 bbls displacement, slow pump at 57.5 bbls to 1 bpm. Bumped plug at 58.5 bbls displacement. Calculated displacement = 58.9 bbls. Hold 1500 psi press on LWP. Solid press. Bleed press, Check floats, OK. Out totalizer had 10.5 bbls return of 11 ppls pumped past shoe. Cement Job went well. No problems. Cement Sample in UCA. POH with CT. Replace coil voidage only, pump 0.40 bpm, 60 psi, POH at 100 FPM. Layout Baker tools. Closed Master Valve. Jet stack to clean out cuttings. Closed swab valve. Perform weekly BOPE pressure and function test. Witness waived by AOGCC inspecter John Spalding. Prep floor for running cleanout BHA. PJSM for running Hydril tubing ( Discuss issues associated Printed: 4/12/2004 11 :33:20 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: . Date 4/6/2004 4/7/2004 0-04 0-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 2/20/2004 Rig Release: 4/8/2004 Rig Number: N1 Spud Date: 6/9/1970 End: 4/8/2004 [)esèriptiörtof<:)p'èrcltions with new derrickman. Driller with assist intiallly in derrick and TP will operate rig) Good team work. M/U 1.875" mill, motor, MHA and 166 jts of 1" CSH. Flush BHA with 12bbls of KCL water to ensure motor is not plugged-off from rust in 1" CSH tbg. M/U injector & changeout depth tracking wheel. RI H with cleanout BHA on CT - clean all the way to PBTD tagged 2x @ 11868'. POOH with cleanout BHA circ @ 1.0bpm/2100psi. Dump ca. 30bbls of cement contaminated KCL water. OOH. PJSM. SIB injector. Drop 1/2" ball & open up circ sub. R/B 83stds of 1" CSH & L/D cleanout motor/mill. PJSM on P/U & RIH CNL logging tools & 1" CHS tbg. Initialize & test logging tools. P/U tool into rig floor. Load neutron source into tool. M/U logging BHA #12 with SWS MCNL/CCL/GR logging tool, lower MHA, XO, 83stds of 1" CSH tbg, XO & upper MHA. M/U injector. RIH with SWS MCNL/CCL/GR logging tool. Log down from 6600 ft at 60 fpm. Circ. at 0.3 bpm, 480 psi. Slow to 30 fpm logging speed at 10,100 ft. Pump 12 bbl FloPro high vis perf pill. Tag PBTD at 11,868'. Log up at 60 fpm in drilled hole section. Lay in High vis new FloPro pill. Log up to 6600 ft. POH. SAFETY MEETING. Review procedure, hazards and mitigation for Laying out 1" CSH in singles and standing back in doubles. Layout 21 jts of 1" CSH in singles. Stand back rest of CSH in doubles. SAFETY MEETING. Review procedure, hazards and mitigation for recovery of SWS Memory CNL/GR tool. UO SWS memory logging tools. Download Data, Good Data. Fax log to Anc. Office. Tied-in PBTD from Logging tag was 11,866 ft, TOL= 6,878 ft. Pressure test liner lap for 30 min. Chart and record test. Good test. 2100 psi initial and 2040 psi final. SAFETY MEETING. Review procedure, hazards and mitigation for running SWS 1.56" perforating guns. M/U 30jts of 1.56" HSD 6spf 1606PJ guns & blanks with BCF firing system. Held PJSM for P/U 1" CSH. M/U lower disconnect, XO, 73stds of 1" CSH tbg & upper MHA. Conduct safety jVvalve drill while M/U 1" CSH. M/U injector. RIH with perforating BHA#13 circ perf pill @ min rate. Up wt check @ 6850' = 17k. RIH in Inr @ 50fpm & tag PBTD 2x @ 11874'. Pull to P/U wt & correct CTD to 11866' (PBTD as per MCNL log). CaMP PUH to ball drop postion @ 11859'. CaMP Pump a total of 7bbls perf pill ahead. Load 1/2" steel ball. Blow ball into CT with 3 bbls perf pill behind. Position guns for btm shot @ 11850'. Chase ball @ 0.95bpm/2700psi. From... To' Hours Task 10: 15 - 10:30 0.25 CEMT P CaMP 10:30 - 17:45 7.25 CLEAN P CaMP 17:45 - 18:30 0.75 CLEAN P COMP 18:30 - 19:00 0.50 CLEAN P CaMP 19:00 - 21 :05 2.08 CLEAN P CaMP 21 :05 - 23:35 2.50 CLEAN P CaMP 23:35 - 00:00 0.42 CLEAN P CaMP 00:00 - 00:30 0.50 CLEAN P CaMP 00:30 - 03:00 2.50 CLEAN P CaMP 03:00 - 03:15 0.25 EVAL P CaMP 03: 15 - 03:30 0.25 EVAL P CaMP 03:30 - 06:00 2.50 EVAL P CaMP 06:00 - 06:20 0.33 EVAL P CaMP 06:20 - 08:30 2.17 EVAL P CaMP 08:30 - 10:00 1.50 EVAL P CaMP 10:00 - 10:30 0.50 EVAL P CaMP 10:30 - 10:45 0.25 EVAL P CaMP 10:45 - 15:15 4.50 EVAL P CaMP 15:15 - 15:30 0.25 EVAL P CaMP 15:30 - 15:45 0.25 EVAL P CaMP 15:45 - 16:30 0.75 CEMT P COMP 16:30 - 16:45 0.25 PERF P CaMP 16:45 - 18:30 1.75 PERF P CaMP 18:30 - 18:45 0.25 PERF P CaMP 18:45-21:15 2.50 PERF P CaMP 21:15-23:10 1.92 PERF P CaMP 23:10 - 23:15 23: 15 - 00:00 0.08 PERF P 0.75 PERF P Printed: 4/12/2004 11 :33:20 AM ) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ······Date 0-04 0-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 2/20/2004 Rig Release: 4/8/2004 Rig Number: N1 Spud Date: 6/9/1970 End: 4/8/2004 4/8/2004 00:00 - 00:30 From ~To Hours DesCriþtion'of ()pêtâtiüns' 00:30 - 01 :10 0.50 PERF N FLUD CaMP 0.67 PERF P CaMP 01: 10 - 01 :50 0.67 PERF P CaMP 01 :50 - 02:20 0.50 PERF P COMP 02:20 - 03: 15 0.92 PERF P CaMP 03:15 - 03:45 0.50 PERF P CaMP 03:45 - 04: 15 0.50 PERF P CaMP 04: 15 - 09:00 4.75 PERF P CaMP 09:00 - 09:15 0.25 PERF P CaMP 09:15 - 12:00 2.75 PERF P CaMP 12:00 - 12:30 0.50 WHSUR P CaMP 12:30 - 14:00 1.50 WHSUR P CaMP 14:00 - 16:00 2.00 RIGD P POST 16:00 - 18:00 2.00 RIGD P POST Slow to 0.4bpm/850psi @ 30bbls. Ball not on seat after 44bbls away. RBIH to 11858'. PUH very slowly & ramp up to 4200psi with no indications of ball seating or guns firing. Reposition btm shot @ 11850'. Bring on pumps to 1.15bpm/3200psi & can still hear ball rolling in reel house - the earleir 0.95bpm was not able to circ ball thru CT reel (rate was limited due to hi circ pressures from long 1 "CSH). Chase ball thru gooseneck. Continue chasing ball @ 1 bpm/3000psi. Observe ball hit 10bbls earlier & guns firing with quick pressure spike to 3200psi & out-rate reduction followed by sudden pressure drop to 2900psi. Pump additional 1 Obbls & confirmed guns fired. Perforated interval = 11230' - 11560', 11730' - 11850'. POOH with perf gun BHA @ 50fpm pumping down the CT @ 0.4bpm/850psi. POOH to 10000'. SID pump & flowcheck well for 30 mins - well stable. POOH with perf gun BHA @ 50fpm pumping down the CT @ OAbpm/750psi. POOH to 6850'. Continue POOH with perf guns @ 60fpm pumping across the WHD @ 0.5bpm with 50psi WHP. OOH. SID pump & flowcheck well for 30 mins - well stable. Meanwhile held PJSM for UD 1" CSH & AAR for safety jVvalve drill. SIB injector. LID upper MHA & 1" CSH tbg in singles. SAFETY MEETING. Review procedure, hazards and mitigation for laying out fired perf guns. Layout 30 SWS, 1.56" PJ perf guns, all shots fired. Guns were loaded at 6 SPF. All shots fired. M/U SWS nozzle BHA. M/U injecter head. RIH with nozzle on CT to 2000 ft. Lay in 26 bbls MEOH to surface. Close Master and Swab valves. Blow coil back to pits with air. Clean rig pits and cutting tank. PJSM. Secure Coil. RID guide arch. Lower injecter head in pipe bay. N/D BOP. N/U & PT tree cap. Rig released @ 18:00 on 4/8/2004. Printed: 4/12/2004 11 :33:20 AM ) ) 17-Apr-04 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well D-04 B Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: 10,322.43' MD Window / Kickoff Survey: 10,346.00' MD (if applicable) Projected Survey: 11,900.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services AUn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date 2) ~~'I Signed 1~~ Q~j Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager ~a) -/10 AUachment(s) Halliburton Sperry-Sun North Slope Alaska BPXA PBU WOA D Pad D-04B Job No. AKMW3001826, Surveyed: 4 April, 2004 Survey Report 16 April~ 2004 Your Ref: API 500292005602 Surface Coordinates: 5959201.00 N, 654090.00 E (70017'43.6124" N, 148045'08.0886" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 959201.00 N, 154090.00 E (Grid) Surface Coordinates relative to Structure Reference: 3570.54 N, 1999.31 E (True) Kelly Bushing Elevation: 72.00ft above Mean Sea Level Kelly Bushing Elevation: 72.00ft above Project V Reference Kelly Bushing Elevation: 72.00ft above Structure Reference spea-tr"y-sul'1 [fRILLING SERVices A Halliburton Company .,r. DEFINITIVE --7 ----' Survey Ref: svy4254 Halliburton Sperry-Sun Survey Report for PBU_WOA D Pad - D-04B Your Ref: API 500292005602 Job No. AKMW3001826, Surveyed: 4 April, 2004 BPXA North Slope Alaska Measured True 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) 10322.43 23.300 64.910 8715.56 8787.56 3565.84 N 2539.27 E 5962818.15 N 656555.63 E -1464.50 Tie On Point MWD Magnetic 10346.00 23.000 64.760 8737.23 8809.23 3569.78 N 2547.65 E 5962822.26 N 656563.93 E 1.297 -1462.92 Window Point 10377.61 14.590 92.770 8767.19 8839.19 3572.23 N 2557.25 E 5962824.91 N 656573.48 E 38.336 -1459.42 10407.85 19.600 131.520 8796.17 8868.17 3568.67 N 2564.88 E 5962821.50 N 656581.18 E 40.197 -1452.13 10435.31 21.290 158.110 8821.96 8893.96 3560.97 N 2570.20 E 5962813.92 N 656586.66 E 34.090 -1442.77 '~ 10465.78 28.040 181.200 8849.69 8921.69 3548.64 N 2572.12 E 5962801.62 N 656588.83 E 38.238 -1431.57 10498.37 39.110 185.950 8876.81 8948.81 3530.70 N 2570.89 E 5962783.66 N 656587.97 E 34.888 -1417.58 10532.06 46.930 197.900 8901 .46 8973.46 3508.35 N 2565.99 E 5962761.22 N 656583.53 E 33.455 -1402.08 10566.41 51.940 214.430 8923.88 8995.88 3485.15 N 2554.43 E 5962737.78 N 656572.45 E 39.274 -1389.70 1 0596.19 61.350 206.520 8940.26 9012.26 3463.71 N 2541.93 E 5962716.10 N 656560.39 E 38.573 -1379.32 10632.63 74.880 201.070 8953.82 9025.82 3432.83 N 2528.40 E 5962684.94 N 656547.49 E 39.621 -1361.78 10662.45 77.960 190.340 8960.84 9032.84 3404.97 N 2520.58 E 5962656.93 N 656540.24 E 36.462 -1343.44 10700.39 87.190 181.730 8965.74 9037.74 3367.63 N 2516.66 E 5962619.52 N 656537.09 E 33.122 -1315.10 10741.75 88.070 183.660 8967.45 9039.45 3326.35 N 2514.72 E 5962578.21 N 656536.00 E 5.125 -1282.40 10775.38 89.030 187.710 8968.31 9040.31 3292.91 N 2511.39 E 5962544.70 N 656533.35 E 12.373 -1256.92 10817.10 88.940 184.900 8969.05 9041.05 3251.45 N 2506.81 E 5962503.16 N 656529.62 E 6.738 -1225.58 10876.92 89.210 171.010 8970.02 9042.02 3191.82 N 2508.94 E 5962443.59 N 656532.97 E 23.221 -1175.52 10922.52 86.660 160.290 8971.66 9043.66 3147.74 N 2520.21 E 5962399.75 N 656545.15 E 24.148 -1132.94 10961.92 88.590 152.730 8973.30 9045.30 3111.66 N 2535.89 E 5962364.00 N 656561.57 E 19.786 -1094.40 10995.12 90.350 146.400 8973.61 9045.61 3083.06 N 2552.70 E 5962335.74 N 656578.96 E 19.788 -1061.32 11028.43 93.430 152.730 8972.51 9044.51 3054.37 N 2569.56 E 5962307.41 N 656596.40 E 21.122 -1028.16 11065.67 92.020 159.580 8970.73 9042.73 3020.37 N 2584.58 E 5962273.72 N 656612.12 E 18.759 -991.69 -~/ 11097.49 87.100 164.860 8970.98 9042.98 2990.09 N 2594.29 E 5962243.65 N 656622.45 E 22.677 -961.31 11136.87 86.840 158.180 8973.06 9045.06 2952.81 N 2606.75 E 5962206.63 N 656635.67 E 16.952 -923.63 11167.07 90.090 155.720 8973.87 9045.87 2925.04 N 2618.57 E 5962179.11 N 656648.05 E 13.494 -894.10 11197.22 92.110 159.760 8973.29 9045.29 2897.15 N 2629.98 E 5962151.46 N 656660.04 E 14.978 -864.71 11226.33 90.090 153.610 8972.73 9044.73 2870.44 N 2641.50 E 5962124.99 N 656672.10 E 22.232 -836.22 11259.09 93.340 147.980 8971.75 9043.75 2841.87 N 2657.47 E 5962096.75 N 656688.65 E 19.835 -803.66 11295.47 92.020 145.340 8970.05 9042.05 2811.51 N 2677.44 E 5962066.81 N 656709.24 E 8.106 -767.34 11326.02 90.960 138.610 8969.26 9041.26 2787.47 N 2696.24 E 5962043.16 N 656728.53 E 22.293 -736.86 16 April, 2004 - 14:04 Page 20f4 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for PBU_WOA D Pad - D-04B Your Ref: API 500292005602 Job No. AKMW3001826, Surveyed: 4 April, 2004 BPXA North Slope Alaska Measured True 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) 11362.15 89.210 131.630 8969.20 9041.20 2761.89 N 2721.72 E 5962018.10 N 656754.52 E 19.916 -701.29 11407.22 88.770 124.080 8970.00 9042.00 2734.25 N 2757.27 E 5961991.20 N 656790.64 E 16.777 -658.26 11449.39 89.380 116.870 8970.68 9042.68 2712.88 N 2793.59 E 5961970.58 N 656827.38 E 17.156 -619.93 11493.01 89.030 108.250 8971.29 9043.29 2696.16 N 2833.83 E 5961954.69 N 656867.96 E 19.776 -583.15 11532.20 86.310 101.930 8972.88 9044.88 2685.97 N 2871.61 E 5961945.28 N 656905.94 E 17.543 -553.13 11573.47 85.870 93.840 8975.70 9047.70 2680.33 N 2912.36 E 5961940.47 N 656946.80 E 19.586 -525.14 .-- 11619.43 87.980 86.460 8978.17 9050.17 2680.21 N 2958.22 E 5961941.30 N 656992.65 E 16.678 -498. 74 11667.49 94.660 79.430 8977.06 9049.06 2686.10 N 3005.85 E 5961948.16 N 657040.15 E 20.169 -476.24 11711.94 91.050 70.460 8974.84 9046.84 2697.63 N 3048.67 E 5961960.56 N 657082.72 E 21.727 -461.12 11743.89 91.230 67.120 8974.21 9046.21 2709.18 N 3078.44 E 5961972.72 N 657112.25 E 10.467 -453.51 11776.78 90.790 60.090 8973.63 9045.63 2723.79 N 3107.88 E 5961987.93 N 657141.39 E 21.413 -448.59 11811.35 89.820 53.590 8973.44 9045.44 2742.69 N 3136.80 E 5962007.42 N 657169.92 E 19.010 -447.48 11843.50 94.040 54.990 8972.36 9044.36 2761.44 N 3162.89 E 5962026.70 N 657195.61 E 13.828 -447.88 11877.43 96.150 61.500 8969.34 9041 .34 2779.22 N 3191.60 E 5962045.07 N 657223.96 E 20.096 -445.97 11900.00 96.150 61.500 8966.92 9038.92 2789.93 N 3211.33 E 5962056.18 N 657243.45 E 0.000 -443.43 Projected Survey 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 145.000° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11900.00ft., The Bottom Hole Displacement is 4253.97ft., in the Direction of 49.01r (True). - 16 April, 2004 - 14:04 Page 3 of4 DrillQuest 3.03.06.002 North Slope Alaska Comments Measured Depth (ft) 10322.43 10346.00 11900.00 Halliburton Sperry-Sun Survey Report for PBU_WOA D Pad - D-04B Your Ref: API 500292005602 Job No. AKMW3001826, Surveyed: 4 April, 2004 BPXA Station Coordinates TVD Northin9s Eastings ~) ~) ~) 8787.56 8809.23 9038.92 3565.84 N 3569.78 N 2789.93 N Survey toollJroaram for D-048 Fro m Measured Vertical Depth Depth (ft) (ft) 0.00 8788.93 1 0322.43 0.00 7535.66 8787.56 Comment 2539.27 E 2547.65 E 3211.33 E Tie On Point Window Point Projected SUNey ~ To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) AK-1 BP _HG (D-04) BP High Accuracy Gyro (D-04A) MWD Magnetic (D-04B) ~ 16 April, 2004 - 14:04 Dril/Quest 3.03.06.002 8788.93 10322.43 11900.00 7535.66 8787.56 9038.92 Page 4 of4 TREE: W8..LHEAD : ACTUATOR: KB. ELEV: BF. ELEV : KOP: Max Angle : 2030' ID: 2.750" Minimum ID = 2-318" 1.907" @ 6869' PINID MlLLOUT WINOOW 8740',8796' ÆRFORA llON SUMMA RY REF LOG: SWS MEIIIIORY CNUGRlCCL OF 04/07/04 ANGLEA TTOP ÆRF: 90 DEG@ 11,230' Note: Refer to Production DB for historical perf data SIZ E SPF INTERV AL 0 1.56 6 11,230', 11,560' 1.56 6 11,730',11.850' P8ID 2-318" Liner, 4.7#, L-80, .0067 bpf, ID: 1.995" OOMl'v1ENTS CTD HORIZONTA L SIŒTRA. FRUDHOE SAY UNIT W8..L: D..o48 PERJVIITNo: 203-110 API No: 50,029,20056-02 SEC23,T1.1N. R13E BP Exploration (Alas ka) ~ a. Type of work 0 Drill II Redrill ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519·6612 4. Location of well at su rface x = 654090, Y = 5959201 1800' SNL, 1067' WEL, SEC. 23, T11N, R13E, UM At top of productive interval x = 656465, Y = 5962773 1722' NSL, 1384' EWL, SEC. 13, T11N, R13E, UM At total depth x = 657184, Y = 5961985 919' NSL, 2086' EWL, SEC. 13, T11 N, R13E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 028305,3194' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 10350' MD Maximum Hole An Ie 18. Casing Program Size Ca in 2-318" lUl71\- ¿pl/'/ ¿'OO3 . STATE OF ALASKA . ALAS~ AND GAS CONSERVATION COM ION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool KBE = 72' Prudhoe Bay Field I Prudhoe 6. Property Designation Bay Pool ADL 028285 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number / D-04B 9. Approximate spud dat¥ 07/04/03 / Amount $200,000.00 14. Number of acres in property 15. Pr~sed depth (MD and TVD) 2560 11850' MD I 8975' TVDss o 17. Anticipated pressure {s?20 MC 25.035 (e) (2)} 90 Maximum surface 2341 psig, At total depth (TVD) 8800' I 3221 psig Setting Depth To Bottom MD TVD TVD 6870' 6073' 8975' 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 Hole 2.7" x3" 4L4S 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 8740' 10-3/4" x 9-518" 4745' 7" 3824' 5-1/2" Open: 10448' - 10474', Sqzd: 10566' - 10590' true vertical Open: 8903' - 8927', 8951' - 8961', 9035' - 9053', 9057' - 9070' Sqzd: 9012' - 9035' III Filing Fee 0 Property Plat II BOP Sketch 0 Diverter Sketch II Drilling Program III Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report II 20 AAC 25.050 Requirements Contact Engineer NameINumber: Mark Johnson, 564-5666 Prepared By NameINumber: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is true , correct to the best of my knowledge Signed Mark Johnson J1~ O. ¡~ Title CT Drilling Engineer Casing Structural Conductor Surface Intermediate Production Liner Casing Scab Liner Liner Perforation depth: measured 20. Attachments 10800 feet 9229 feet 10745 feet 9178 feet Length Cemented Plugs (measured) JUN 1 8 2.003 Junk (measured) 1\ ,<'t _n 'y." ,¡'~ r Ifj ft g~, l"''llArf'"'" "'de. TVD Size 80' 2298' 2199' 4494' 150 sx Permafrost 4500 sx Permafrost Uncemented 1500 sx Class 'G' 80' 2298' 2199' 4494' 80' 2298' 2199' 4258' 30" 20" 16" 13-3/8" 4995 sx Class 'G' 680 sx Class 'G' 1150 sx Class 'G' 10500' - 10510', 10590' - 10610', 8740' /' 2213' - 6958' 6958' - 10789' 10614' - 10628' 7502' 2213' - 6143' 6143' - 9219' API Numþey 50- 029-2'aú56-02 Samples Required 0 Yes .~ No Hydrogen Sulfide Measures ~ Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K .~_ Othe~í-e.S ~"'g (.t t) E te' ~ S" 0 D pl.'..', __-; /f-, \ ( \ ~ rc', Commissione Rev.,.,. 13ft JUN 2 0 2003 Date Submit In Triplicate . . BP D-04B Sidetrack Summary of Operations: Well D-04A is scheduled for a through tubing sidetrack with the SLB/Nordic 2 Coiled Tubing Drilling rig on ~7/4/O3. The sidetrack, D-04B, will exit-eut-ofthe existing 5 Yz" line/from a cement ramp window and target Zone 2 reserves. The existing 5 Yz" liner perfs are gassed out and will be abandoned with a cement plug (form .,/ 10-403 already submitted). The following describes the planned sidetrack. A schematic diagram of the proposed sidetrack is attached for reference. Pre CTD Summary (phase 1) / 1) Slickline -Drift tubing. Dummy gas lift valves. Pressure test IA to 2500 psi. - already done . 2) Service Coil- P&A wellbore with ~ 18 Bbl of 17 ppg cement. WOe. PT to 1000 psi. Wellbore abandonment is complete. CTD Sidetrack Summary (Dhase 2) 1) MIRV CTD rig. 2) Mill 2.74" OD cement ramp window at 10350' md. 3) Drill 2.70 x 3.0" bicenter openhole sidetrack to ~ 11850' TD with MWD/gamma ray. .,/ 4) ~, 3/8" liner completion. Top ofliner will be at 6870' md in 3 Yz" tubing tail. Cement liner with . bls of 15.8 ppg cement. 5) erforate. 6) RDMO. / Mud Program: · Phase 1: 8.4 ppg seawater · Phase 2: 8.5 ppg used Flo Pro or biozan for milling, new Flo Pro for drilling. / 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: · A 2 3/...'(,:)' lid cemented liner completion from 6870' to TD at 11850'. The liner cement volume is planned to be t/::..,. bls of 15.8 ppg class G. Perforate liner as per Asset instructions. 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 90 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · MWD Gamma Ray log will be run over all of the open hole section. · A CNL/GR/CCL cased hole log is optional after the liner has been run and cemented. . . lIazards ~ · PBU D pad is not an IDS pad. Maximum recorded H2S was 20 ppm from well D-21. No IDS measurements have been taken for well D-04B due to lack offulltime production since 1993. All IDS monitoring equipment will be operational. · One small fault crossing is anticipated at 11270' md. Lost circulation risk is considered "medium" so LCM material will be on location as a contingency. Reservoir Pressure · Res. press. is estimated to be 3221 psi at 8800'ss (7.0 ppg EMW). Max. suñace pressure with gas (0.10 psi/ft) to suñace is 2341 psi. / MOJ 6/18/03 ·~'.f ,,"{f'~L b ~.-.- --;;;...--- P .,-- -~. ~,~ . . ENGINEERING DATA SHEET NO._ OF_ SUBJECT BASED ON BUDGETIAFE NO. FILE NO. ENGINEER DEPT. APP'VL DATE ¡oS loo~ L~OJ ~g70' ~ V- ,OL , /ð.5:: /oo'iO , rSAG- '" 9<¡5S f " cr 2.0 W I.. Err- TSAG- 99 ')) 2 'U;,.., oH 0.0031. ( -¿, ~) 3 - 2.37); _ 1t<¡S'0" /o-¿$o - S:Z'2.)( /. i= 7,.3 16'l~ Ir 'I. ". / ( 'l. ~ 2* y 5' 'l- Iqf } 01"50 -/oz..<$o I.f, nZ. - 2.175 ::=' ,. !Qz7 _/~I>ò 7õG-k-v¡ (Ó~~,.;-£.. ~ ~ rtx:.. ~ ns .afl ~ I~"SO CMlerA- eJ: ~J.) /" IO~)Ù "'" t. 'B 0.2. 'I.:; ß" \"',~ \ \ "-.,--" \\~-- ~\ \0~-- \ \ \ I ,~)O I AK 2337·1 (11100) TREE = WEU..I-£A 0 = ACTUATOR = KB. REV = BF. REV = KOP= Max Angle = D3tum M) = D3tum lVo = 6" CrN M;BI OY aN OTIS 72' 40.12' 2818' 46 @ 8685' 10414' 8800' SS -'i¡Jet D-04A fj\~' 5-1/2"TBG, 17#, L-BO, 0.0232 bpf,lo =4.89Z' TOP OF 3-1/2" TOO TOP OF 7" LIIR 10-314" COO, 55#, N-BO, 10 = 12.615' TOP OF 9-518" COO 13-318" COO, 68#, NT-80, 10 = 12.415" Minimum ID = 2.750" @ 6855' OTIS SLIDING SLEEVE 3-1/2" TBG, 9.3#, L-80, .0087 bpf, ID = 2.99Z' 7" LNR, 26#, L-80, .0382 bpf, 10 = 6276" H I TOP OF 7" LIIR H 6920' 6958' 6958' 7" LNR. 26#, L-80, .382 bpf, 10 = 6276" I TOP OF 5-1/2" LIIR H PERFORATION SUMMð.RY REF LOG: BHCS ON 12/26/87 - CBT ON 01/02188 A~LEATTOPPERF: 23 @ 10448' I\t)te: Refer to A"oduction DB for histJrical perf data SIZE SA= INTERVAL Opn/Sqz DATE 2-1/8" 4 10448' - 10474' 0 12/29/92 2-1/2" 4 10500' - 10510' 0 04/21/96 4" 4 10566' - 10590' S 11/20/91 2-1/8" 4 10590' - 10610' 0 01/23/92 2-1/8" 4 10614' - 10628' 0 11/23/91 9-5/8" CSG,47#, L-80, 10= 8.681" 5-1IZ' LIIR, 17#, L-BO, 0.0232 bpf, 10 = 4.89Z' ¡s!NO~' 2030' 5-1 f2" OTIS ROY SSSV NP, 10 = 4.562" 2169' 5-1f2" X 1f2" XO GAS LIFT MANDRELS ST Mo lVo lEI TYPE VLV LATCH PORT DAlE 4 3228 3132 24 HMO R< 3 5899 5283 41 FM-IO R< 2 6526 5742 43 FM-IO R< 1 6648 5832 41 FM-IO R< 6789' BOT G TBG SEAL ASSY 6812' 7" BOTPKR. 10= 2.750" 6855' 3-1 f2" OTIS X NIP, to = 2.750" 6887' 3-1f2" OTIS X NIP, ID = 2.750" 6920' 3-1f2"lBG TAL, WLB3 6931' HRtvOTTLOGNOTAVALABLE MIlLOUT WlrÐON 8740' - 8796' 10305' Mð. R<ER JOINT 10745' 10789' DATE REV BY COM'.llENTS Dð. lE REV BY COMM:NTS 11/76 ORIGINAL COMJLETION 01/04/88 SIDETRACK COMA.E11ON 01/24/01 SIS-QAA COMlERTID TO CAMI AS 03/08/01 SIS-LG ANAL 02/01/02 RNlTP CORRB:;TIONS FRLOHOE SA Y UNT wa.L: [).04A PERMrrNo: 187-1250 API No: 50-029-20056-01 SEC23, T11N, R13E BP Exploration (Alas ka) TREE = 6" CrN . D-04B ~ NOTES: WB.LHEAO - McEVOY ACTUATOR = aN OTIS KB. B.EV = 72' Proposed CTO Sidetrack BF. B.EV = 40.12' ~~~E,fÇ) KOP= 2818' 2030' LI5-1/2" OTIS ROY SSSV NIP, 10 = 4.562" I Max Angle = 46 @ 8685' e Datum M) = 10414' ? 2169' 5-1/2" X 1/2" XO I Datum lVO = 8800' SS I 5-1/2" TBG, 17#, L-80, 0.0232 bpf, D = 4.892" 2169' ~ GAS LFT MANORB-S ST M) lVO DEV TYÆ VLV LATCH PORT DATE I TOP OF 3-1/2" TBG 2169' ~ J 4 3228 3132 24 FM-tO RK I TOP OF 7" LNR 2213' Y 3 5899 5283 41 FMHO RK 2 .6526 5742 43 FMHO RK 10-3/4" CSG, 55#, N-80, Ð = 12.615" 2415' ~ 1 6648 ~32 41 Ftd-IO RK I TOP OF 9-5/8" CSG 2415" r- "- "i 2415' 10-3/4" X 9-5/8" XO I 13-3/8" CSG, 68#, NT-80, D = 12.415" ~ -~-1 4493' HFOCI 4494' I 6739' 3-1/2" OTIS SLIDING SLævE. XA, Ð = 2.750" 1""'-"1 !L 1 6789' BOT G TBG SEAL ASSY I I I Minimum ID = 2.750" @ 6855' :8: - 6812" 7" BOT PKR. Ð = 2.7SO" I 0::::::.. I OTIS SLIDING SLEEVE I 6855" 3-1/2" OTIS X NIP, Ð = 2.750" I Top of 2-3/8" liner 6f70'1 T 688T 3-1/2" OTIS X NIP, Ð = 2.750" I I 3-112" TBG, 9.3#, l-80, .0087 bpf, Ð = 2.992" 6920" I 6920" 3-1/2" TBG TAL, WlEG I I 7" lNR, 26#, l-80, .0382 bpf, Ð = 6.276" H 6958" I ~ ~ I 6931" H B.M) IT lOG NOT A V AIlABlE I I TOP OF 7" lNR 6958' ~ I 7" lNR, 26#, l-80, .382 bpf, Ð = 6.276" 6968' - - I TOP OF 5-1/2" lNR 6968' 9-518" CSG, 47#, l-80, D = 8.681" 10928' MUOUT WINOOW 8740' - 8796' ~~ I - ""'. 1 0150' Top of Cement PERFORATION SUMMARY REF lOG: BHCS ON 12/26/87 - CBT ON 01/02/88 MARKER JOM I ANGLE AT TOP PERF: 23 @ 10448' 10305' Note: Refer to Production DB for historical perf data ðt.$"O , TOC. fIA SIZE SPF INTERV Al OpnlSqz DATE 10350' H Cement Rarrp Window I 2-1/8" 4 10448' - 10474' isolated proposed 2-1/2" 4 10500' - 10510' isolated proposed 4" 4 10566' - 10590' '-----'" '-----'" ' 1 isolated proposed L 2-1/8" 4 10590' - 10610' is olated proposed I 2-1/8" 4 10614' - 10628' is olated proposed 2-3/8" cmt'ed and perfed I 11850' I I PBTD H 10745" 5-1/2"lNR, 17#, l-80, 0.0232 bpf, Ð = 4.892" H 10789" I DATE REV BY COM\f3llTS DATE REV BY COM\1ENTS PRUDHOE SAY UNrr 11/76 ORIGl'Lð.l COMPlETION wal: D-04A 01104/88 SIDETRAa< COMPlETION PERMfTNo: 187-1250 01/24101 SIS-QAA CONVERTED TO CAtfV AS API No: SO-029-20056-01 03108101 SlS-lG Fl'Lð.l SEe 23, T11 N, R13E 02101102 RNITP CORRECTIONS BP Exploration (Alaska) Plan: PI"" 115 (D-04IPt.Nl5 0-048) erulad 8y: 8ri Potni. Date: 5/ mlad Information: Oi'~(;l. (gOT) 2t!7·()613 Baker Hughes I~;!'~~!r [~~6~f~~~q·f;OrTI Azimuths to True North Magnetic North: 25.81< Magnetic Field Strenth: 57539n T Di8at;gI~i~g&J; Model: BGGM2oo2 T l LEGENO - o.~ ¡p.o<) ~:.s~1. PIon'" ObP BP Amoco WWUPA'hI Dn'AlL. -- ..... ...ltaoOH02 -.. 10Ma.l1 83so-:] ":.1 8400-j ..¡ ..¡ 84503 .; ..j 8500j , .... 'j ~c 8550i 8600"': " ~ ......; = 8650J !87ood ..J 1:1 .. :j 2 8900 :1 ...: 8950 J :~ 9000] .; 9050] ..¡ 9100 ~ . ¡ !';r:f-r"¡"r:r:'¡";"'r"f'¡"''-¡'''!'i: "r"!""'¡"!'"!"""!'T:rT'rr 2600 2700 2800 2000 3000 3 Ù)O 3200 3300 3400 3500 3600 West(-)/East(+) [100ft/In] 4000"~~ "j 3~ 3800: ...¡ ..j 3700j 38OO-j ...¡ ui 'ë3500j æ ., ..¡ 340(}ooo.' o ~ ~ 33OOJooo ... ~ ...... j + 32001 ....... .'¡ .c ::; 1:: 3100: o ~ Z1 _ 300(}ooo:; "-"', . ~ i' 2900 J ~ ::ill' ..j 02800'000 U) ,,¡ 2700:..J 2600j ..~ I ..i 2500,j",,',',"" -1 2400} . ~ 23001 "rT1 1600 ..... - =: æ ¡:¡r .... -- TIe_.Dt w...: IIN111111"'11... Tt.Nft v.o.:.:: : ~ ~ ....... .... .... .... REFERENCE INFORMATION Co-otdnat. (r-.ue:¡ Reference: Well Centre: 0-04, True North Vertical (TVD Reference: System: Mean Sea Level ~~h~=~ ~'?'04~~'~~'~) 72.00 CatcutatIon Method: Minimum Curvature -....... ... _ ... All ",. .... ............ Wac. v-.. I .......,...,. M.,. ane.... un.... .....aT .... 0... -1......,. ,........... .fa ..,.It MnIAO ........ .... '17.N -1....... I ......... ...." n.oo ..,..,. ~ 2M1A. .... ,,,.00 ....... · .......... ,..... "ToM ",*-:IT UT..... 2NLeT :t2.OO '20'" ........0 · 'M1a." ..... 17..," ...... aMI.4I ...,.... 0.00 ...00 -1...... · ,...... ........... ..,.... ,.,.,. 2.,.0 :t2.OO ..... -1SH..,. , tl7MlS .,........ ..,.... UH,T. :un.sa :u.oo..... ..:au... · "......IS .......... ...,...,. IOU... 2.17.... ,2.00 ...... .......u · tt....U ..... ...... '1'7:1.... :100I.47 ....ao 12.00 ...00 _'010._ .. ............. .... ...,.,. 211.... I.....,. ':LOO 110.00 ......,. TNŒTOETAlLS "".... "'"" 0,00 3211,14 253," 0.00 2125,011 24.21,901 0.00 3311.5' 2100,11 g:gg ~t::~ =:: 0.00 3227.1' 3301,""' 1II~:gg I=~ m~:¡: 11I15,00 2121.06 315002 "- g:~1 0.0.9 F.... 2 0-048 F.... 3 0418 F.... 5 D,.o,eF..... 0-ð48F..... 0-ð48111 D-ð48TH MMCn'A11ONe TVD .D......... 1nI.'" "Is.u.n ftP ..,...... 111..... KOP ..,...., ..1H4.M :I .'".n......... .. .....» ......,.... . U1I... 111M.U . U1I.II ..11M.ü ., 1171." 1tMl.2S . ..n..... 1t1M.2:1 . ""'M 11...... TD . 2100 2200 2300 2400 'Tr1"TT",' , 1700 1800 1900 2000 , .! t ~ "'·T"]""r·1 '··'TTTTT'·.,.·r ~·Ti··r·r·'·~··J··'·T·t··rt··¡'·~··'·T"r"'TTi·f·r·!"'n+·t·'··n+·, rn··b·'·'··d·r·rr· . -1800-1750 -1700 -1650-1600 -1550 -1500-1450-1400 -1350 -1300-1250-1200 -1 150-1100-1050-1000 Vertical Section at 145.00· [50ft/In] . . bp BP Baker Hughes INTEQ Planning Report INTEQ Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 Site: PB D Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: 5955590.34 ft From: Map Easting: 652165.06 ft Position Uncertainty: 0.00 ft Ground Levet: 0.00 ft Latitude: 70 17 Longitude: 148 46 North Reference: Grid Convergence: 8.492 N 6.316 W True 1.16 deg Well: D-04 Slot Name: 04 D-04 Well Position: +N/-S 3571.20 ft Northing: 5959200.95 ft Latitude: 70 17 43.612 N +EI-W 1997.41 ft Easting : 654089.66 ft Longitude: 148 45 8.099 W Position Uncertainty: 0.00 ft Wellpath: Plan#5 D-04B 500292005602 Current Datum: 8: 04 11/5/1999 11:48 Magnetic Data: 5/12/2003 Field Strength: 57539 nT Vertical Section: Depth From (TVD) ft 0.00 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 D-04A 10348.03 ft Mean Sea Level 25.81 deg 80.81 deg Direction deg 145.00 Height 72.00 ft Targets D-04B Polygon3.1 0.00 3298.14 2528.67 5962550.00 656550.00 70 18 16.045 N 148 43 54.364 W -Polygon 1 0.00 3298.14 2528.67 5962550.00 656550.00 70 18 16.045 N 148 43 54.364 W -Polygon 2 0.00 2823.39 2754.00 5962080.01 656785.00 70 18 11.375 N 148 43 47.799 W -Polygon 3 0.00 2808.85 3218.84 5962075.00 657250.01 70 1811.230 N 148 4334.246 W -Polygon 4 0.00 2593.88 3214.43 5961860.00 657250.00 70 18 9.116N 148 43 34.377 W -Polygon 5 0.00 2693.92 2726.34 5961950.01 656760.00 70 18 10.102 N 148 43 48.607 W -Polygon 6 0.00 2752.19 2567.49 5962005.00 656600.00 70 18 10.675 N 148 43 53.238 W -Polygon 7 0.00 3300.09 2433.68 5962550.00 656455.00 70 18 16.064 N 148 43 57.134 W D-04B Fault 1 0.00 2825.05 2428.94 5962075.00 656460.00 70 1811.392 N 148 43 57.277 W -Polygon 1 0.00 2825.05 2428.94 5962075.00 656460.00 70 18 11.392 N 148 43 57.277 W -Polygon 2 0.00 2940.89 3121.51 5962205.01 657150.00 70 18 12.529 N 148 43 37.082 W D-04B Fault 2 0.00 3386.59 2605.51 5962640.00 656625.00 70 18 16.915 N 148 43 52.123 W -Polygon 1 0.00 3386.59 2605.51 5962640.00 656625.00 70 18 16.915 N 148 43 52.123 W -Polygon 2 0.00 3205.79 2641.81 5962460.00 656665.00 70 18 15.136 N 148 43 51.066 W D-04B Fault 3 0.00 3169.47 2706.08 5962425.00 656730.00 70 18 14.779 N 148 4349.192 W -Polygon 1 0.00 3169.47 2706.08 5962425.00 656730.00 70 18 14.779 N 148 4349.192 W -Polygon 2 0.00 3009.08 2722.80 5962265.00 656750.00 70 18 13.201 N 148 43 48.707 W D-04B Fault 5 0.00 2625.67 2639.92 5961880.00 656675.00 70 18 9.431 N 148 43 51.127 W -Polygon 1 0.00 2625.67 2639.92 5961880.00 656675.00 70 18 9.431 N 148 43 51.127 W -Polygon 2 0.00 2466.85 3311.85 5961735.00 657350.00 70 18 7.866 N 148 43 31.538 W D-04B Fault 6 0.00 3227.16 3307.44 5962495.00 657330.00 70 18 15.344 N 148 43 31.657 W -Polygon 1 0.00 3227.16 3307.44 5962495.00 657330.00 70 18 15.344 N 148 4331.657 W -Polygon 2 0.00 2466.85 3311.86 5961735.00 657350.01 70 18 7.866 N 148 4331.538 W D-04B Fault 4 0.00 3155.52 2410.71 5962405.00 656435.00 70 18 14.643 N 148 4357.805 W -Polygon 1 0.00 3155.52 2410.71 5962405.00 656435.00 70 18 14.643 N 148 43 57.805 W -Polygon 2 0.00 2849.23 2469.45 5962100.00 656500.00 70 18 11.630 N 148 43 56.095 W ObP . BP Baker Hughes INTEQ Planning Report . ~--_._-- INTRQ D-048 T3.1 8970.00 3394.40 2517.64 5962646.00 656537.00 70 18 16.992 N 148 43 54.685 W D-048 T3.4 8975.00 2721.06 3159.02 5961986.00 657192.00 70 18 10.367 N 148 43 35.991 W Annotation 10348.03 8739.10 TIP 10350.00 8740.91 KOP 10364.00 8754.02 3 10404.00 8792.37 4 10479.00 8862.33 5 10694.23 8970.06 6 10794.23 8970.29 7 11044.23 8971.79 8 11094.23 8972.14 9 11850.00 8975.49 TO Plan: Plan #5 Date Composed: 5/12/2003 Landing 5 feet shallower, keep TO same as Plan #3 Version: 2 Principal: Yes Tied-to: From: Definitive Path Plan Section Information 10348.03 22.97 64.75 8739.10 3570.12 2548.37 0.00 0.00 0.00 0.00 10350.00 22.96 64.73 8740.91 3570.45 2549.06 0.64 -0.51 -1.02 217.96 10364.00 18.31 73.66 8754.02 3572.23 2553.65 40.00 -33.19 63.81 150.00 10404.00 16.14 117.30 8792.37 3571.45 2564.67 32.00 -5.42 109.08 120.00 10479.00 28.66 175.31 8862.33 3548.40 2575.56 32.00 16.68 77.35 90.00 10694.23 90.00 216.58 8970.06 3391.14 2507.22 32.00 28.50 19.17 45.00 10794.23 89.74 184.58 8970.29 3298.74 2472.53 32.00 -0.26 -32.00 269.50 11044.23 89.60 154.58 8971.79 3055.66 2517.24 12.00 -0.06 -12.00 269.65 11094.23 89.60 160.58 8972.14 3009.47 2536.30 12.00 0.00 12.00 90.00 11850.00 90.00 69.89 8975.49 2719.90 3150.79 12.00 0.05 -12.00 270.00 Survey 10348.03 22.97 64.75 8739.10 3570.12 2548.37 5962822.30 656564.12 -1462.78 0.00 0.00 TIP 10350.00 22.96 64.73 8740.91 3570.45 2549.06 5962822.64 656564.81 -1462.65 0.64 217.96 KOP 10364.00 18.31 73.66 8754.02 3572.23 2553.65 5962824.52 656569.35 -1461.49 40.00 150.00 3 10375.00 16.82 84.25 8764.50 3572.88 2556.89 5962825.24 656572.58 -1460.16 32.00 120.00 MWD 10400.00 15.93 112.73 8788.53 3571.91 2563.67 5962824.41 656579.38 -1455.48 32.00 109.90 MWD 10404.00 16.14 117.30 8792.37 3571.45 2564.67 5962823.96 656580.39 -1454.52 32.00 82.54 4 10425.00 17.45 140.26 8812.50 3567.68 2569.28 5962820.30 656585.07 -1448.79 32.00 90.00 MWD 10450.00 21.71 160.67 8836.08 3560.42 2573.21 5962813.12 656589.16 -1440.59 32.00 67.99 MWD 10475.00 27.62 173.71 8858.80 3550.28 2575.38 5962803.03 656591.53 -1431.04 32.00 48.72 MWD 10479.00 28.66 175.31 8862.33 3548.40 2575.56 5962801.15 656591.75 -1429.40 32.00 36.85 5 10500.00 33.71 183.88 8880.30 3537.56 2575.58 5962790.31 656591.99 -1420.51 32.00 45.00 MWD 10525.00 40.31 191.43 8900.26 3522.69 2573.50 5962775.40 656590.22 -1409.51 32.00 37.65 MWD 10550.00 47.28 197.13 8918.30 3505.96 2569.19 5962758.59 656586.25 -1398.29 32.00 31.61 MWD 10575.00 54.47 201.66 8934.07 3487.70 2562.72 5962740.20 656580.15 -1387.04 32.00 27.49 MWD 10600.00 61.80 205.43 8947.26 3468.26 2554.22 5962720.60 656572.06 -1376.00 32.00 24.62 MWD 10625.00 69.22 208.72 8957.62 3448.03 2543.86 5962700.16 656562.11 -1365.37 32.00 22.63 MWD . . lB.. IIAJœIt IIUGHU ----_.~-- INTRQ bp BP Baker Hughes INTEQ Planning Report 10650.00 211.69 8964.94 5962679.28 656550.51 -1355.36 32.00 21.26 MWD 10675.00 214.48 8969.09 5962658.38 656537.48 -1346.18 32.00 20.39 MWD 10694.23 216.58 8970.06 5962642.54 656526.1>5 -1339.78 32.00 19.93 6 10700.00 214.73 8970.06 5962637.78 656523.38 -1337.87 32.00 269.50 MWD 10725.00 89.91 206.73 8970.08 3364.98 2491.09 5962616.05 656511.06 -1327.60 32.00 269.50 MWD 10750.00 89.85 198.73 8970.13 3341.94 2481.44 5962592.82 656501.89 -1314.26 32.00 269.51 MWD 10775.00 89.78 190.73 8970.21 3317.78 2475.09 5962568.54 656496.03 -1298.12 32.00 269.52 MWD 10794.23 89.74 184.58 8970.29 3298.74 2472.53 5962549.44 656493.86 -1283.98 32.00 269.55 7 10800.00 89.73 183.89 8970.32 3292.98 2472.10 5962543.68 656493.56 -1279.51 12.00 269.65 MWD 10825.00 89.71 180.89 8970.44 3268.00 2471.06 5962518.69 656493.03 -1259.65 12.00 269.65 MWD 10850.00 89.70 177.89 8970.57 3243.01 2471.33 5962493.71 656493.81 -1239.02 12.00 269.67 MWD 10875.00 89.68 174.89 8970.71 3218.06 2472.91 5962468.80 656495.90 -1217.68 12.00 269.68 MWD 10900.00 89.66 171.89 8970.85 3193.23 2475.79 5962444.03 656499.28 -1195.69 12.00 269.70 MWD 10925.00 89.65 168.89 8971.00 3168.59 2479.96 5962419.48 656503.96 -1173.11 12.00 269.72 MWD 10950.00 89.64 165.89 8971.15 3144.19 2485.42 5962395.21 656509.92 -1149.99 12.00 269.73 MWD 10975.00 89.62 162.89 8971.32 3120.12 2492.15 5962371.28 656517.14 -1126.41 12.00 269.75 MWD 11000.00 89.61 159.89 8971.48 3096.43 2500.13 5962347.76 656525.60 -1102.43 12.00 269.77 MWD 11025.00 89.60 156.89 8971.65 3073.19 2509.34 5962324.72 656535.28 -1078.11 12.00 269.79 MWD 11044.23 89.60 154.58 8971.79 3055.66 2517.24 5962307.36 656543.54 -1059.23 12.00 269.81 8 11050.00 89.60 155.27 8971.83 3050.44 2519.68 5962302.18 656546.10 -1053.54 12.00 90.00 MWD 11075.00 89.60 158.27 8972.01 3027.47 2529.54 5962279.42 656556.42 -1029.07 12.00 90.00 MWD 11094.23 89.60 160.58 8972.14 3009.47 2536.30 5962261.56 656563.55 -1010.45 12.00 89.97 9 11100.00 89.60 159.89 8972.18 3004.03 2538.25 5962256.17 656565.61 -1004.88 12.00 270.00 MWD 11125.00 89.60 156.89 8972.36 2980.79 2547.46 5962233.13 656575.29 -980.56 12.00 270.00 MWD 11150.00 89.60 153.89 8972.53 2958.07 2557.87 5962210.62 656586.17 -955.97 12.00 270.03 MWD 11175.00 89.60 150.89 8972.70 2935.92 2569.46 5962188.72 656598.20 -931.19 12.00 270.05 MWD 11200.00 89.61 147.88 8972.88 2914.41 2582.19 5962167.47 656611.37 -906.26 12.00 270.07 MWD 11225.00 89.61 144.88 8973.05 2893.59 2596.03 5962146.95 656625.63 -881.27 12.00 270.09 MWD 11250.00 89.62 141.88 8973.21 2873.53 2610.93 5962127.19 656640.95 -856.29 12.00 270.11 MWD 11275.00 89.63 138.88 8973.38 2854.27 2626.87 5962108.27 656657.28 -831.37 12.00 270.13 MWD 11300.00 89.63 135.88 8973.54 2835.88 2643.80 5962090.23 656674.57 -806.59 12.00 270.15 MWD 11325.00 89.64 132.88 8973.70 2818.39 2661.66 5962073.11 656692.79 -782.03 12.00 270.17 MWD 11350.00 89.65 129.88 8973.85 2801.87 2680.42 5962056.98 656711.88 -757.73 12.00 270.19 MWD 11375.00 89.67 126.88 8974.00 2786.35 2700.01 5962041.86 656731.78 -733.78 12.00 270.21 MWD 11400.00 89.68 123.88 8974.14 2771.87 2720.39 5962027.81 656752.46 -710.23 12.00 270.22 MWD 11425.00 89.69 120.88 8974.28 2758.48 2741.50 5962014.86 656773.83 -687.16 12.00 270.24 MWD 11450.00 89.70 117.88 8974.41 2746.22 2763.28 5962003.04 656795.86 -664.62 12.00 270.26 MWD 11475.00 89.72 114.88 8974.54 2735.11 2785.67 5961992.39 656818.47 -642.67 12.00 270.27 MWD 11500.00 89.73 111.88 8974.66 2725.19 2808.62 5961982.95 656841.61 -621.39 12.00 270.29 MWD 11525.00 89.75 108.88 8974.77 2716.48 2832.05 5961974.72 656865.22 -600.81 12.00 270.30 MWD 11550.00 89.77 105.88 8974.88 2709.01 2855.90 5961967.75 656889.22 -581.01 12.00 270.32 MWD 11575.00 89.79 102.88 8974.97 2702.80 2880.12 5961962.03 656913.55 -562.04 12.00 270.33 MWD 11600.00 89.80 99.88 8975.06 2697.87 2904.62 5961957.60 656938.15 -543.94 12.00 270.34 MWD 11625.00 89.82 96.88 8975.15 2694.22 2929.35 5961954.47 656962.95 -526.77 12.00 270.35 MWD 11650.00 89.84 93.88 8975.22 2691.88 2954.24 5961952.63 656987.88 -510.58 12.00 270.36 MWD 11675.00 89.86 90.88 8975.28 2690.84 2979.21 5961952.10 657012.87 -495.40 12.00 270.37 MWD 11700.00 89.88 87.88 8975.34 2691.10 3004.21 5961952.88 657037.85 -481.28 12.00 270.38 MWD 11725.00 89.90 84.88 8975.39 2692.68 3029.16 5961954.97 657062.76 -468.26 12.00 270.38 MWD 11750.00 89.92 81.89 8975.43 2695.56 3053.99 5961958.36 657087.52 -456.38 12.00 270.39 MWD 11775.00 89.94 78.89 8975.46 2699.74 3078.63 5961963.04 657112.08 -445.66 12.00 270.39 MWD 11800.00 89.96 75.89 8975.48 2705.20 3103.03 5961969.00 657136.35 -436.14 12.00 270.40 MWD 11825.00 89.98 72.89 8975.49 2711.92 3127.10 5961976.22 657160.28 -427.85 12.00 270.40 MWD 11850.00 90.00 69.89 8975.49 2719.90 3150.79 5961984.68 657183.80 -420.79 12.00 270.40 TO . . Nordic 2 CTD BOP Detail - CT Injector Head -- Stuffing Box (Pack-Off), 10,000 psi Working Pressure cr - 7" Riser Methanol Injection Otis 7" WLA Quick Connect - 7-1/16" ID, 5000 psi working pressure Ram Type Dual Gate BOPE Annular BOP (Hydril),7-1/16" ID 5000 psi working pressure Manual over Hydraulic 8 I Blind/Shear I I 2" Combi Pipe/Slip I Kill line check valve or HeR --wr:)- Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to StandpipE manifold Flanged Fire Resistant Kelly Hose to Dual Choke Manifold I I 7-1/16" ID, 5000 psi working pressure Ram Type Dual Gate BOPE I TOT I Manual over Hydraulic 23/8" x 3 1/2" VBRs 2" Combi Pipe/Slip XO Spool as necessary 2 flanged gate valves Full production christmas tree Inner Annulus MOJ 9/15/02 Outer Annulus p055070 DATE 4/4/2003 CHECK NO. 055070 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT NET 4/4/2003 INV# CK040103M PERMIT TO DRILL EE \) -{}\b H RECEI ED JUN 1 8 2 03 Alaska Oil & Gas C, .' on~. CommIssion Anchorage . THE ATTACHED CHECK IS IN PAYMENT fOR ITEMS DESCRIBED ABOVE. TOTAL ~ . u' 0 5 50? 0 u' I: 0 ~ ~ 2 0 ~ 8 c¡ 51: 0 ~ 2 ? 8 c¡ b ul . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMlTT AL LETTER WELL NAME PTD# CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well-, Permit No, API No. . (If API number Production should continue to, be reported as last two (2) digits a function' of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(t), all (PH) records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Rev: 07110/02 aj ody\templates PTD#: 2031100 Administration o o Appr Date . 6/19/2003 Engineering Appr . Date 6/19/2003 Geology Appr RPC Date 6/19/2003 Company BP EXPLORATION (ALASKA) INC Well Name: PRUDHOE BAY UNIT D-04B Program DEV Well bore seg Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Initial ClasslType DEV 11-01L GeoArea 890 Unit 11650 On/Off Shore ~ Annular Disposal 1 Pß(fT)iUee attache~_ . _ _ . . _ . . . . . . . . . . . . . _ _ _ . . . _ . _ _ _ _ . _ . . _ . . . . .Yßs. . _ _ _ . _ _ _ _ _ . . . . . . . . _ _ . . . . . _ . . _ _ _ _ _ _ _ . . . . . . . . . . _ _ _ _ _ . _ . . . . . . _ . _ _. _ _ _ . . . . . . . 2 _Leasßnumber .appropriat.e. _ . . . . _ . . . . _ . . _ _ _ . . _ _ _ . . . . . . . . _ _ _ . . . . Yßs. _ _ _ _ . . . . . _ . _ . . . . . _ _ _ _ _ . . . . . . . _ . . . . . _ _ . . . _ _ . _ . . _ . . . . _ . . 3 _U_nique weltnarnß_a[1d Ollmb_er _ _ _ _ _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _Yßs _ _ _ _ _ . _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ . . _ . . _ _ _ _ _ 4 WelUocatßd inad_efine~,pool. . . . . . . . . _ _ . . . . . _ _ . . . . . _ . _ Yßs _ _ _ _ _ . . . . . . . _ . _ _ _ _ _ _ . . . _ . . . . . _ . . . . . _ _ _ _ _ _ . _ . . _ _ ....... _ _ _ _ . . . . . _ 5 WeJUocated proper _distance_ from driJling unitb_ound_ary_ . . . . . . . . _ _ _ . . _ _ . . . . . _ _ . Yßs _ . . . . . . _ _ _ _ _ _ . . _ . . . . . . _ _ _ _ . _ . _ _ . _ _ . . . . _ _ _ _ _ _ _ . . . _ _ . . . . _ _ _ _ _ . . . . . 6 WeUlocatßd pr.oper _distance. from otber wells_ . _ . . . . . . . _ _ _ _ _ . _ _ . . . . Yßs _ _ . . . . . . _ . . _ _ . . _ _ . . . . . . . . . _ _ _ _ _ _ . _ . . . . . . . . . _ _ _ _ _ _ . . . . . . . . . . . _ _ _ _ _ _ . . . . 7 .SJJtfjcientjlcreaQ.e_available in_drilliOQ.lInie . . _ _ . . . . _ . . _ _ _ . . . . . _ . _ Yßs. _ _ _ _ . . . . . . . . _ _ _ _ _ . . . . . . . _ _ _ _ _ . . _ . _ _ . . _ _ . _ _ _ _ _ _ . _ _ . . 8 Jtdßviated, is. wellbore platincJu~ed . . . . _ _ _ _ _ _ _ . . _ _ . _ _ _ _ _ _ . . _ . . . . . . . .YßS . _ _ _ . . . . _ . . . . . _ . _ _ . _ _ . _ . _ . _ _ _ .. ... _ . . _ . . . . . . _ _ _ _ _ . . . . . . _ . . 9 .O,per.ator only affected party _ . . . . . . _ . _ _ . _ _ _ _ _ _ _ _ . . _ . . _ . . . _ Yßs _ . _ _ _ _ _ _ . _ . . . . . _ _ _ _ _ _ _ _ . . . _ . . _ _ _ _ . _ . . _ . . _ . _ . _ . . _ . . _ . _ _ . . _ _ _ . . _ . . . . 10 _O,perator bas_apprQpriate_bond inJorce _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Y!3S _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ . _ 11 P!3rmit. c.ao be issued witbout co.nserva.tion order _ _ _ _ _ . . . . . . . . . . . _ _ _ . _ . . . . . Y!3S _ _ _ . . . . _ . . . . _ _ _ _ _ . . . . _ . . . _ _ _ _ _ _ . . . _ . _ _ . . . . _ _. ...... _ _ _ _ . . _ . . . 12 P!3rmit c.a[1 be iSSlIed wjtbout ad.ministratille_apprQvaL _ . . _ . . . . . . . . _ _ _ .Y!3S _ _ _ . . . . . . . . _ _ _ _ _ _ _ _ . . . . . . . . _ _ _ _ _ _ _ _ . _ _ _ _ . . . . _ _ _ _ _ _ . . . . _ _ . _ _ . . _ . . . _ . . 13 Can permit be approved before 15-day wait Yes 14 WelUocatßd within area and_strata .authorized by_lojectioo Ord!3r # (putlO# in.cQrnrn!3ots) (For_ _NA _ _ . . . . . . . . . _ . _ _ _ . . . . . . . . _ _ _ _ _ _ _ . . . . . _ . _ _ _ . _ _ . _ . . . _ _ _ . . . . . . . 15 _AJlwells.witl1in.1lÜoile_area_ofreviewid!3otified(F.orservjC!3J..~e[lonly>- _ _ _ _ _ _ _ _ _ _.. _ _ _NA _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _.. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _.. _ _ _ __ 16 Pre-produ.ced. iojector; ~uration.of pre-,pro~uctioo l!3sS than 3 montbs.(For_service well onJy) . .NA . . . _ _ . . . . . . . . . . . . . _ . . . . _ _ _ _ . . _ _ _ . . . _ _ . . . . . _ _ _ . . . _ . _ 17 .ACMP.Fïnding.ofCon$i$t.eocy_has bee_nJssued_forJbis pr.ojecl. . . _ . _ _ _ _ . . . . .Yßs. . _ _ _ _ _ . . _ _ _ . . . . _ . . . _ . _ _ . _ _ . _ _ . _ _ _ _ _ . . . . _ _ . _ _ _ _ . _ _ _ . . . . . _ . _ _ _ _ . . . . . _ 18 .C_ooductor stringpJovided _ . . . . . . _ . . . . . . _ _ _ _ _ _ _ _ _ _ . . . _ . . . .NA _ . . _ _ . . . . . . . . . . _ . . . . _ _ _ . . . . . . _ _ _ _ _ _ _ . . . . . . . . _ . . _ _ _ . . . . . _ . . 19Surfacß .casing_pJotec.ts alLknown USDWs _ _ . . . . . . . . . _ _ . . . . _ . . . NA . _ _ _ _ _ _ _ _ _ _ . . . . . . . . _ . _ . . . . . . . _ . _ _ _ . . . . . . . . . _ _ _ _ _ . _ . 20 _CMTv.oladequ_ateJo circ.utate_on.cooductor_& SUJtC$g _ . . . . _ . _ _ _ . _ _ _ _ _ . . . . . _ . . NA _ _. _ . . . _ . . . . . _ . _ _ _ _ . . . _ _ _ _ _ _ . . . . . . _ . . . . _ _ _ _. _... _ _ _ _ _ . . . . _ 21 _CMTvoladequateJotie-inlong.stri[1gtosurfcsg.. _. . . _ . . . . . _ . . _ . _ _ _ _NA _ _ _. _ . _ . . . _ _ _ . . . . . . . . _ _ _ _ _ _ _ _ . . . . . . . . _ . . _ _ _ _. . . . . _ . _ _ _ _. . . . . . . 22 _CMTwill cover.aJl koow_n,pro_ductive borizon.s. . . . . . . . . _ _ _ _ . . . . . . Yßs _ . _ _ _ _ _ _ _ . . . . . . . _ _ _ _ . _ . _ _ . _ _ . _ _ _ . _ . . . . _ . . _ _ _ . . . _ _ . _ . _ .. _ _ _ _ _ . _ . . . . _ _ 23 _C_asiog desigos ad.eç¡ua_te f.or C,T~ B&permafr.osl. _ . . . _ _ . . _ _ _ _ _ . . _ . . . . . . . Yßs. _ _ _ . _ . . . . _ . . . _ _ _ . _ . . . . . . . . _ . . _ _.. _ _ _ _ _ . _ _ . . . . . . . . . _ . _ _ . . . . . . . _ 24 .Adequat.eJankage_oJ re_serve pit _ _ _ _ _ _ _ _ _ . _ . . . . . _ . . . _ _ _ _ _ _ _ . . . _ _ . . .Yßs. _ _ _ _ . . CTDU.. . _ _ _ _ _ _ _ . . . . . . _ _ _ _ _ _ . . . . . . . . _ . . . . _ . . . . . _ _ _ . . . . . . . . 25 Ita.re-~rill~ has_a_ to:403 for abandonme_nt beßO apPJoved _ _ . _ . . . . _ . . _ _ _ . . . . . _ _ _ Yßs _ _ _ . . _ . . . . . . . . _ . . . . _ _ _ _ _ _ _ . _ . . . _ . . _ . . . . . . _ . _ . . _ _ _ . . _ . _ 26 _Adequjlt.e.VIlellbore separatioJ1_pro,posed. _ _ _ _ _ _ _ _ _ . _ _ _ _ . _ . _ _ _ _ _ _ _ _ _ _ . . . _ _ Yßs _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ . _ _ . _ . . _ _ _ _ _ _ . _ . . . . _ _ _ 27 Itdjverterreq.uiJed. does jt meßt. regulatioos _............. _ _ _ _ _ _ _ _ . . . . . . .NA . . _ _ _ . . Sidetrack.. . _ _ . _ . _ . _ _ _ _ . _ . _ _ . . . . . _ . . . . _ . _ _ _ _ _ . . . . . . _ . . _ _ _ _ _ . . . . . . _ 28 _DJilliog fluid. program sc.hematic.& equiplistadequat.e. . . . . . . . _ _ _ _ _ _ _ _ _ _ . . . _ _ . . Y!3s. _ _ _ _ . . Max MW.8,5. ppg, _ _ . . . . . . _ _ . _ _ _ _ _ _ . . . . . . . _ . _ . . _ _ _ _ . . . . . _ . . . _ _ _ _ . . _ . . _ 29 _SOPEs,.d.o.they meet.regulatioo . . . _ . . _ _ _ _ _ _ _ _ . . . . _ . . _ _ . . _ _ _ . . . . . _ . Y!3S _ _ _ _ . . . . . . . . _ _ _ _ .. ..... _ _ _ _ _ _ _ _ . . . . . . . . . . . . _ . . _ . _ . . . _ _ _ . _ _ _ _ . . . . . . 30 .S.OPE_press raiiog appropriate;.testto.(put psig [ncomments). _ . . . . . . . _ _ _ _ _ . . . _ _ Yßs _ . . . _ _ _ Test t.o3500.psi. _MS~ 23.4:1 psk . _ . _ _ _ . . . . _ . _ _ _ _ _ _ _ _ . . . . . . . . _ _ _ _ . . . . . . 31 .C.hokemanifold complies w/APtR~-53 (May 84) . . . . . . . _ . _ _ . _ _ _ _ _ . . . . Yßs. . . _ _ . . . . . . _ _ . _ _ _ _ . . _ . . . . _ . _ . _ . . . . _ _ _ . _ . . . . . . . . . . . . . _ . _ _ _ . . . _ . . _ . . 32 Work will occur without.operatio_n .sbutdo.w.n . . . . . . . . . . . . . . . _ _ _ _ _ _ _ . . _ . . . Y!3S . . . _ . . . . . . . . _ _ _ _ _ . . . . . . . . . _ _ _ . . . . . _ _ _ _ _ _ . . . . . . . . . . 33 Is presence. Qf H2S gas_ probable. . . . . _ _ _ _ _ _ _ . _ . . . . . _ . . _ _ _ . _ _ _ . . . . . _ . . No_ _ _ . . . . . _ . _ . . . _ _ . . . _ _ . . . . . . . . . _ _ _ _ _ _ _ _ . . . . . _ . . . . . . _ . _ . . . . . . _ _ _ _ _ _ _ . . . . . . . 34 MecbanicalCQod,ilioo .of wells within AOR verified. (Foaervice wßIJ only) _ . _ . . . _ . . .NA. _ _ . _ _ _ _ . . . . .. . _ _ _ _ _ . _ . . . _ _ _ _ _ . _ _ _ . . . . _ . _ _ _ _ _ _ _ _ . . _ _ . . . . . . . 35 Pß(fT)it.c.aobeisslIedwlohydrogensulfidemeas.ures_... _ _ _... _ _ _ _ _. _ _....... No_·. _ _ _...... _.._ 36 Data. PJeS!i!oted on potential oveJpressurß .ZOne» _ _ _ _ _ . _ _ _ . . . . . _ .. NA _ _ _ . . . . . . . . _ _ 37 _Sßismic.analysjs Qf shallow gas.ZQoes_ . . _ _ . . . . . . . . _ _ _ . _ . . . . _ _ _NA _ _ . . . . _ _ _ _ _ _ . 38Sßabed .condjtioo slIrvey.(if off-shore) . _ . _ _ . . . _ _ _ _ _ . _ _ _ . . _ _ _ . . _ . . . . .NA _ _ _ _ . . . . . . _ . . _ _ _ _ _ . 39 _ CQnta_ct narn_e/phoneJor.we!i!kly progress_reports [exploratory .only]. . _ _ _ _ _ _ . . . . .NA . . _ _ _ . . . . . . . . . _ _ . . _ . . . . . . _ _ ~ ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - ~ ~ ~ - - - - - - - - - - - - - - - ~ - - - - - - - - - - ~ - - - - - - - - Geologic Commissioner: on Date: Engineering Commissioner: Date ~~~~ Public Commissioner ~..i .,.,...~ ~.~.~ Date ó w( I ~ ( D 11-; 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. e e ó<tD3 - /(0 Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Jan 27 09:36:48 2005 :i/ J )..cr1l Reel Header Service name........... ..LISTPE Date...... .............. .05/01/27 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.................... .05/01/27 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 D-04B 500292005602 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 27-JAN-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 3 MW0003001826 B. JAHN LAULE / WHIT MWDRUN 4 MW0003001826 B. JAHN LAULE / WHIT MWDRUN 6 MW0003001826 B. JAHN LAULE / WHIT JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 7 MW0003001826 B. JAHN LAULE / WHIT MWD RUN 8 MW0003001826 B. JAHN LAULE / WHIT # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 23 llN 13E 1800 1067 MSL 0) 72.00 24.65 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 2.740 3.500 6920.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE e e NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . 3. THIS WELL WAS DRILLED OFF OF A WHIPSTOCK, THE TOP OF WHICH WAS POSITIONED AT 10350'MD/8740'TVDSS. 4. MWD RUNS 1 - 8 COMPRISED DIRECTIONAL WITH NATURAL GAMMA RAY (PCG) UTILIZING SCINTILLATION DETECTORS. THE PURPOSE OF RUN 1 WAS TO TIE-IN THE SGRC AND POSITION THE WHIPSTOCK. NO PROGRESS WAS MADE ON RUNS 2 AND 5. UPHOLE SGRC DATA WERE MERGED WITH RUN 3 DATA. 5. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A GAMMA RAY RUN IN D-04A ON 26 DECEMBER 1987. THESE DIGITAL DATA WERE PROVIDED BY W. TIFENTAL(SIS/BP) ON 20 JANUARY 2005. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 6. MWD RUNS 3, 4, 6 - 8 REPRESENT WELL D-04B WITH API#: 50-029-20056-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11900'MD/8967'TVDSS. SROP SGRD $ SMOOTHED RATE OF PENETRATION WHILE DRILLING. SMOOTHED NATURAL GAMMA RAY. File Header Service name.... .........STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/01/27 Maximum Physical Record. .65535 File Type. .............. .LO 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 $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 9875.5 10274.0 STOP DEPTH 11878.5 11902.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 9875.5 9911.0 9915.5 9920.5 9924.5 9929.5 9932.5 9938.5 9947.0 9951.0 9955.5 9972.0 9984.5 9987.0 9993.0 9997 . 5 GR 9876.0 9911.5 9916.0 9921. 0 9924.5 9929.5 9932.5 9938.0 9947.5 9951.0 9955.5 9972 . 5 9985.0 9987.5 9994.0 9997.5 e e 10248.5 10249.5 10262.0 10265.5 10271.5 10278.0 10286.0 10288.0 10293.5 10303.0 10314.5 10326.0 10338.5 10345.5 10347.5 10349.5 10351.5 11878.5 $ 10248.0 10249.5 10261. 5 10265.0 10271.0 10277.5 10285.5 10287.0 10293.0 10302.0 10314.0 10324.5 10338.0 10344.5 10346.5 10348.0 10349.5 11876.0 # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ BIT RUN NO 3 4 6 7 8 MERGE TOP 9876.0 10354.0 10365.0 10700.0 11334.0 MERGE BASE 10354.0 10365.0 10700.0 11334.0 11900.0 # 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 DEPT ROP MWD GR MWD Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Nsam Rep 1 68 1 68 1 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9875.5 11902.5 10889 4055 9875.5 11902.5 ROP MWD FT/H 0.02 499.91 110.499 3258 10274 11902.5 GR MWD API 16.66 298.74 44.5581 3512 9875.5 11878.5 First Reading For Entire File......... .9875.5 Last Reading For Entire File.......... .11902.5 File Trailer Service name.. ...........STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/01/27 Maximum Physical Record..65535 File Type................ LO Next File Name. ...... ....STSLIB.002 Physical EOF File Header e Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.. . ... .05/01/27 Maximum Physical Record..65535 File Type.... . . . . . . . . . . . .LO Previous File Name. . . . . . .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 e header data for each bit run in separate files. 3 .5000 START DEPTH 9876.0 10350.5 STOP DEPTH 10328.0 10354.0 # 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 PCG $ BOTTOM) TOOL TYPE Natural gamma ray # 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 01-APR-04 Insite Memory 10354.0 9876.0 10354.0 23.0 30.3 TOOL NUMBER TLG015 2.740 6920.0 KCl Water 8.30 .0 .0 14000 .0 .000 .000 .000 .000 .0 154.0 .0 .0 e e 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 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD030 MWD030 Nsam 1 1 1 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9876 10354 10115 957 9876 10354 ROP MWD030 FT/H 0.07 0.95 0.555 8 10350.5 10354 GR MWD030 API 18.65 298.74 67.2557 411 9876 10328 First Reading For Entire File......... .9876 Last Reading For Entire File.......... .10354 File Trailer Service name..... ... .....STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/01/27 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. . . . . . .05/01/27 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 header data for each bit run in separate files. 4 .5000 START DEPTH 10328.5 10354.5 STOP DEPTH 10339.0 10365.0 # 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: 01-APR-04 Insite Memory 10365.0 10354.0 10365.0 23.0 30.3 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCG Natural gamma ray TOOL NUMBER TLG015 e e $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 2.740 6920.0 # 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: KCL Water 8.30 .0 .0 14000 .0 .000 .000 .000 .000 .0 158.6 .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. ....0 Logging Direction............. ....Down Optical log depth units....... ....Feet Data Reference Point.......... ....Undefined Frame Spacing..................... 60 .1IN Max frames per record... ..........Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD040 GR MWD040 Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Nsam 1 1 1 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10328.5 10365 10346.8 74 10328.5 10365 ROP MWD040 FT/H 0.02 8.4 3.73545 22 10354.5 10365 GR MWD040 API 21.72 27.65 22.78 22 10328.5 10339 First Reading For Entire File......... .10328.5 Last Reading For Entire File.......... .10365 File Trailer Service name... ..... .....STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..05/01/27 Maximum Physical Record. .65535 File Type... . . . . . . . . . . . . . LO Next File Name. . . . . . . . . . .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name. . . e version Number.......... .1.0.0 Date of Generation.. . ... .05/01/27 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. 6 .5000 START DEPTH 10339.5 10365.5 STOP DEPTH 10676.0 10700.0 # 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 PCG $ BOTTOM) TOOL TYPE Natural gamma ray # 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 03-APR-04 Insite Memory 10700.0 10365.0 10700.0 14.6 78.0 TOOL NUMBER TLG015 3.000 6920.0 Flo Pro 8.70 .0 9.4 27000 6.0 .000 .000 .000 .000 .0 141.7 .0 .0 e e Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD060 GR MWD060 Units FT FT/H API Size 4 4 4 Code Offset o 4 8 Channel 1 2 3 Nsam Rep 1 68 1 68 1 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10339.5 10700 10519.8 722 10339.5 10700 ROP MWD060 FT/H 0.34 148.07 54.8592 670 10365.5 10700 GR MWD060 API 18.02 157.61 34.7545 674 10339.5 10676 First Reading For Entire File......... .10339.5 Last Reading For Entire File.. ........ .10700 File Trailer Service name.... .........STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/01/27 Maximum Physical Record. .65535 File Type.. ....... ...... .LO Next Filè Name.... ...... .STSLIB.005 Physical EOF File Header Service name...... ...... .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......05/01/27 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 $ 5 header data for each bit run in separate files. 7 .5000 START DEPTH 10676.5 10700.5 STOP DEPTH 11310.0 11334.0 # 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: 04-APR-04 Insite Memory 11334.0 10700.0 11334.0 86.8 93.3 # TOOL STRING (TOP TO VENDOR TOOL CODE PCG $ BOTTOM) TOOL TYPE Natural gamma ray TOOL NUMBER TLG013 # e e BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.000 6920.0 # 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: Flo Pro 8.60 .0 9.5 26500 8.2 .000 .000 .000 .000 .0 167.0 .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. ....0 Logging Direction............ .....DoWD 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 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD070 MWD070 Nsam 1 1 1 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10676.5 11334 11005.3 1316 10676.5 11334 ROP MWD070 FT/H 1. 36 483.66 114.328 1268 10700.5 11334 GR MWD070 API 19.61 198.09 55.6758 1268 10676.5 11310 First Reading For Entire File.... ......10676.5 Last Reading For Entire File.... .......11334 File Trailer Service name............ .STSLIB.005 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .05/01/27 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...... .05/01/27 e 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 GR ROP $ 6 e header data for each bit run in separate files. 8 .5000 START DEPTH 11310.5 11334.5 STOP DEPTH 11876.0 11900.0 # 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 PCG $ BOTTOM) TOOL TYPE Natural gamma ray # 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 04-APR-04 Insite Memory 11900.0 11334.0 11900.0 85.9 96 .2 TOOL NUMBER TLG013 3.000 6920.0 Flo Pro 8.60 .0 9.5 30000 8.4 .000 .000 .000 .000 .0 171.2 .0 .0 4 e e Name Service Order Units Size Nsam Rep Code Offset Cha=el DEPT FT 4 1 68 0 1 ROP MWD080 FT/H 4 1 68 4 2 GR MWD080 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11310.5 11900 11605.3 1180 11310.5 11900 ROP MWD080 FT/H 3.7 499.91 151.666 1132 11334.5 11900 GR MWD080 API 16.66 56.47 30.0716 1132 11310.5 11876 First Reading For Entire File.... ......11310.5 Last Reading For Entire File...........11900 File Trailer Service name. ........... .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation.......05/01/27 Maximum Physical Record..65535 File Type... . . . . . . . . . . . . . LO Next File Name.. ...... ...STSLIB.007 Physical EOF Tape Trailer Service name......... ... .LISTPE Date. . .. . . . . . ..... .... . . .05/01/27 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. . . . . . . . . . . . . . . . . . . . .05/01/27 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